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169-120
ExxonMobil Production Coinpany F. 0. Fox 196601 Anchorage, Alaska 99519-6601 901561 5331 I eiephone August 4, 2014 R-2014 OUT -157 RECEIVED AUG 0 6 2014 AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 RE: Final Location Clearance • Point Thomson Unit (PTU) #1 (PTD 176-085) • PTU #2 (PTD 177-064) • PTU #3 (PTD 178-005) • Staines River State #1 • West Staines State #18-9-23 (PTD 169-120) • West Staines State #2 (PTD 175-002) • Alaska State C-1 (PTD 180-046) Dear Commissioner Foerster, SCANNED ElonMobil Production By letter dated May 18, 2007, the Alaska Oil and Gas Conservation Commission (Commission) advised ExxonMobil that ten wells in the Point Thomson area did not meet the Commission's requirements for plugged and abandoned wells. The Commission further noted that permits to drill cannot be issued to an operator that is in violation of a Commission regulation pertaining to drilling, plugging or abandonment of a well. In addition to the seven wells listed above, the Commission's May 2007 letter addressed Challenge Island #1 (PTD 180-090), Alaska State J-1 (PTD 183-045), and PTU #4 (PTD 179- 080). Challenge Island was operated by another party, and we understand remedial work there has been completed. ExxonMobil has pursued remedial and final abandonment work on the ExxonMobil operated wells identified in the May 2007 letter. Visual inspections of all sites were conducted in 2007 and comprehensive inspections of the nine Exxon MobiI-operated wells were conducted in winter 2008/09. Remedial work was completed on the J-1 and PTU #4 wells in 2009 and 2012, respectively, and final reports were submitted to the Commission. During the winter 2013/14, final remedial or plugging and abandonment work on the seven subject wells was completed. A final report of Well Completion for the Plugging and Abandonment of each well was submitted to your office on May 14, 2014, followed by the summer well site debris clean- up reports submitted July 18, 2014. Cathy Foerster 2 August 4, 2014 All well remedial and abandonment work on the nine ExxonMobil operated wells was conducted in accordance with approved Applications for Sundry Approvals, some of which received modifications as the work progressed. Timely notices were provided to the Commission so inspection of the work could be performed at the Commission's discretion. The PTU #4 well file on the AOGCC website contains a final location clearance. With respect to work to close the reserve pit and conduct contaminated site cleanup work at WSS #18-9-23 and WSS #2 and incorporation of the PTU #3 and C-1 locations into the Point Thomson Project gravel infrastructure, our understanding is that receipt of final location clearance is not required at this time in order to be in compliance with plugging and abandonment requirements. Given the unique history of these nine sites in view of the Commission's May 2007 letter, ExxonMobil respectfully requests the Commission to either approve final location clearance or otherwise confirm to ExxonMobil that it has met AOGCC requirements with respect to the plugging and abandonment of these wells and do not represent an impediment to approval of permits to drill for ExxonMobil. If you have any questions or require additional information, please contact me at (907) 564-3773. Sincerely, Irene T. Garcia SSHE Manager ExxonMobil Production Company P. 0. Box 196601 Anchorage, Alaska 99519-6601 907 5615331 Telephone July 18, 2014 R-2014 OUT -156 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 RE: Abandoned Well Site Cleanup Reports • Point Thomson Unit (PTU) #1 (PTD 176-085) • PTU #2 (PTD 177-064) • PTU #3 (PTD 178-005) • West Staines State (WSS) #18-9-23 (PTD 169-120) • West Staines State #2 (PTD 175-002) • Alaska State C-1 (PTD 180-046) Dear Commissioner Foerster, REC "' pt r JUL 21 201''4 �©GC ' ' E*onMobil Production Well remediation was conducted at the six wells referenced above this past winter in compliance with AOGCC Sundry approvals. As required by the Sundry approvals, a Report of Well Completion for the Plugging and Abandonment of each well (10-407 form) was submitted to your office May 14, 2014. Following breakup, summer debris cleanup activities were conducted at four of the well sites the last week of June. AOGCC field inspectors concluded that it was not necessary to visit these sites following the cleanup work and instead asked that we provide the attached cleanup reports and site photos for PTU #1, PTU#2, WSS #18-9-23 and WSS #2. PTU #3 and Alaska State C-1 are on active pads associated with the Point Thomson Project so debris cleanup at those locations is not warranted. Please note ExxonMobil is currently working with the Alaska Departments of Environmental Conservation and Natural Resources to close the reserve pit on the WSS #2 and to address contaminated gravel on the WSS #18-9-23 and #2 locations. If you have any questions or require additional information, please contact me at (907) 564-3773. Sincerely, Irene T. Garcia SSHE Manager Attachments Summary of Point Thomson Unit (PTU) #1 Activities PTU #1 (PTD No. 176-085); Sundry No. 313-600 and Sundry No. 314-206 (modification) A Report of Well completion for the plugging and abandonment of PTU#1 was submitted 5/14/2014 to AOGCC. The well is plugged and abandoned in compliance with the Sundry approvals. Following the winter well remediation, summer debris cleanup activities were conducted the last week of June. Debris was collected and transported to Deadhorse for appropriate disposal. Photos are provided below. PTU #1 prior to debris removal PTU #1 post debris removal. Debris was collected in supersacks (shown in center of picture) and transported back to Deadhorse for appropriate disposal. Page 2 Abandoned Well Site Cleanup Report July 18, 2014 PTU #1 removing pipe PTU #1 post pipe removal Page 3 Abandoned Well Site Cleanup Report July 18, 2014 ................ ............... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ad PTU #1 looking south post cleanup. Debris collected in supersacks (seen at left of picture) was transported back to Deadhorse for appropriate disposal PTU #1 aerial view looking north east post debris cleanup. Page 4 Abandoned Well Site Cleanup Report July 18, 2014 Summary of Point Thomson Unit (PTU) #2 Activities PTU #2 (PTD No. 177-064); Sundry No. 313-601 and Sundry No. 314-158 (modification) A Report of Well completion for the plugging and abandonment of PTU#2 was submitted 5/14/2014 to AOGCC. The well is plugged and abandoned in compliance with the Sundry approvals. Following the winter well remediation, summer debris cleanup activities were conducted the last week of June. Debris was collected and transported to Deadhorse for appropriate disposal. Photos are provided below. •.YIY. �Y�� .� Mir r irk �. rte.-., `.� ''=+�►� � +� �: - e PTU #2 Well location conducting debris cleanup. PTU #2 Well location post debris cleanup. Page 5 Abandoned Well Site Cleanup Report July 18, 2014 PTU #2 looking west post debris cleanup. PTU #2 looking southwest post debris cleanup. Page 6 Abandoned Well Site Cleanup Report July 18, 2014 Summary of West Staines State (WSS) #18-9-23 Activities WSS #18-9-23 (PTD No. 169-120); Sundry No. 313-604 A Report of Well completion for the remedial abandonment of WSS #18-9-23 was submitted 5/14/2014 to AOGCC. The well is plugged and abandoned in compliance with the Sundry approvals. Following the winter well remediation, summer debris cleanup activities were conducted the last week of June. Debris was collected and transported to Deadhorse for appropriate disposal. Photos are provided below. WSS #18-9-23 well location prior to debris cleanup. WSS #18-9-23 well location post debris cleanup. Page 7 Abandoned Well Site Cleanup Report July 18, 2014 WSS #18-9-23 Looking south east post cleanup. Debris was collected in supersacks (shown in center of picture) and transported back to Deadhorse for appropriate WSS #18-9-23 looking south west post cleanup. Page 8 Abandoned Well Site Cleanup Report July 18, 2014 Summary of West Staines State (WSS) #2 Activities WSS #2 (PTD No. 175-002); Sundry No. 313-606 A Report of Well completion for the remedial abandonment of WSS#2 was submitted 5/14/2014 to AOGCC. The well is plugged and abandoned in compliance with the Sundry approvals. Following the winter well remediation, summer debris cleanup activities were conducted the last week of June. Debris was collected and transported to Deadhorse for appropriate disposal. Photos are provided below. WSS #2 well location prior to debris cleanup. WSS #2 well location post debris cleanup. Page 9 Abandoned Well Site Cleanup Report July 18, 2014 Schwartz, Guy L (DOA) From: Rob Dragnich <rob@rgdragnichllc.com> Sent: Wednesday, June 04, 2014 8:29 AM To: Schwartz, Guy L (DOA) Cc: Winter, Cassondra E Subject: Point Thomson Remediation Follow -Up Review Hi Guy, As you know, ExxonMobil had an extremely successful well remediation and abandonment program this past winter and completed work on 7 welk Plante are to do the stick l2qcking work and obtain AOGCC site clearance inspections in June. We would be happy to review the past season's work with you if desired. Our suggested timing for this would be after the stick picking effort. Are you interested in such a review and, if so, would you be available sometime during July 8-10 timeframe? Regards, Rob Dragnich Consultant to ExxonMobil Production Company R.G. Dragnich, LLC rob@rgdragnichllc.com 907-830-4796 SCS Nov 18 2014 16 E 1 1v As ST B -� -r -, •�----"+^^ •y �_e o. 0.60' � .; '� ,�� •,� � s 4 IN C7k _ f . I . `',� � ®._ -_ 1 ' . _>.. s, �` � a.'P--1..81._ Q�� •Qe�� �..o e v� c �� � ,Y3' � �e' ° r .1• -. `..r - I w i _ k 1rw';'`�$. .. 'tI^ 1a 1 r�p ' ® �'>�o I® _ Q® �i..".•`,p �,�_ a ��v y Ia ,a to tb 4"� _JF•^r%a4� I6.. `a. Alai , .i••n.1� es Ir 'i' z• i u ( » r. 1st � ' i 1 , i 8 _ 7n. 1"a _- 25 wast, #a n+�jcl No; 29 i 7A U � as ..� of � - —.._.. n.�—� I v �• -- '' i' ® ®o _34as ! At � 1 . z .I 18 11 12 : /""i V .. _- s e � i n � - 1r r, n ` e 14 13 17 t 18 81 x2 x! t4 H I ``I µ� '� z7 x1 t4 a3_ 24 fa.,> sow q • •• _ . '^811. _ •i` z{ i _ �� W•'t• s! - $ �'�- St. .`.r ,� rs t w. 'Y „ .•a� ' at ii It �,:..•; it to �y1 � ���r .. -•�,� .-,,,V t\) g at�� � 1 wa. ...._._� � a�•Tf � t . �. �- ..aa..: .+`•- ...aa• .f� .,...�'' .�,---•.ti,�. -n.. .,» `, .!••'i }� ,fit- y* STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: 1 b. Well Class: Development ❑ Exploratory ❑✓ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ExxonMobil Oil Corporation 5. Date Comp., Susp., or Aband.: 4/4/2014 12. Permit to Drill Number: 169-120 ' 3. Address: P.O. Box 196601, Anchorage, AK 99519-6601 6. Date Spudded: NIA 13. API Number: 50-089-20001-0000 - 4a. Location of Well (Governmental Section): Surface: Top of Productive Horizon: Total Depth: 7. Date TD Reached: NIA 14. Well Name and Number: West Staines State #18-9-23 8. KB (ft above MSL): GL (ft above MSL): 15. Field/Pool(s): Wildcat 9. Plug Back Depth(MD+TVD): >3' below tundra level 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 451694. y- 5899985 • Zone- TPI: x- y- Zone- Total Depth: x- y- Zone- 10. Total Depth (MD + TVD): 13329 ft - 16. Property Designation: ADL 28380 ' 11. SSSV Depth (MD + TVD): N/A 17. Land Use Permit: LO/NS 09-007 18. Directional Survey: Yes ❑ No ❑./ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost MD/TVD: 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): N/A I 22.Re-drill/Lateral Top Window MDTFVD: N/A 23. See Attached Work Summary CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 24. Open to production or injection? Yes ❑ No ❑✓ If Yes, list each interval open (MD+TVD of Top and Bottom; Perforation Size and Number): RECEIVED MAY 2 7 2014 25. NIA TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 26. NIA ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was ing d during ion? Yes No dINTERVAL (raulic MD) AMOUNT AMOUNT ANDtKIND OF MATERIAL USED❑ DEPTH 27. NIA PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period -11111. Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate -.0. Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): 28. CORE DATA NIA Conventional Core(s) Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No ❑ 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. SCAMM NOV 18 2014 RBCMS MAY 2 7 1 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE '�ti I'yS,kli�rnit original only fry 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? [] Yes __:7L No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, Permafrost - Top N/A N/A and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: 31. List of Attachments: Work Summary, Post P&A Well Schematic, Photographic documentation of the well before and after the work. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tom Juranek (832)624-5940 Email: tom.ajuraneKDexxonmobil.com Printed Name: Irene T. Garcia Title: SSHE Manager Signature: - t �� L (��� Phone: (907)564-3773 Date: 5/14/2014 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. Item 1 b: Classification of Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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 4b: TPI (Top of Producing Interval). Item 8: 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 13: 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 28. 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 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. Form 10-407 Revised 10/2012 STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION • WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 2] Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: 1 b. Well Class: Development ❑ Exploratory ❑✓ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ExxonMobil Oil Corporation 5. Date Comp., Susp., or Aband.: 4/4/2014 12. Permit to Drill Number: 169-120 3. Address: P.O. Box 196601, Anchorage, AK 99519-6601 6. Date Spudded: N/A 13. API Number: 50-089-20001-00-00 4a. Location of Well (Governmental Section): Surface: Top of Productive Horizon: Total Depth: 7. Date TD Reached: N/A 14. Well Name and Number: West Staines State #18-9-23 8. KB (ft above MSL): GL (ft above MSL): 15. Field/Pool(s): Wildcat 9. Plug Back Depth(MD+TVD): >3' below tundra level 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- y- 70.137559 Zone- TPI: x- y- Zone- Total Depth: x- y- Zone- 10. Total Depth (MD + TVD): 13329 ft. 16. Property Designation: ADL 28380 11. SSSV Depth (MD + TVD): N/A 17. Land Use Permit: LO/NS 09-007 18. Directional Survey: Yes ❑ No Q (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: (ft MSL) 20. Thickness of Permafrost MD/TVD: 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: 23. See Attached Work Summary CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 24. Open to production or injection? Yes ❑ No Q If Yes, list each interval open (MD+TVD of Top and Bottom; Perforation Size and Number): CEIV 1•• r MAY 15 2014 AOGG�-: 25. N/A TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 26. NIA ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. N/A PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate —.0. Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No ❑ 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. RBr- MS MAY 15 20 4 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only Jr� 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: 31. List of Attachments: Work Summary. Post P&A Well Schematic, Photographic documentation of the well before and after the work. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tom Juranek (832)624-5940 Email: tOm.a. Uranek exxonmobil.com Printed Name: Irene T. Garcia Title: SSHE Manager 2-� Signature: CJ LGo`-� Phone: (907)564-3773 Date: 5/14/2014 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. Item 1 b: Classification of Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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 4b: TPI (Top of Producing Interval). Item 8: 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 13: 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 28. 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 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. Form 10-407 Revised 10/2012 ExxonMobil Production Company P. 0. Box 196601 Anchorage, Alaska 99519-6601 907 5615331 Telephone May 14, 2014 R -2014 -OUT -127 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 E*(onMobil Production Re: Well Completion Report Well Abandonment: West Staines State 18-9-23 (PTD No. 169-120) Sundry No. 313-604 Dear Commissioner Foerster, MAY 15 2014 AOGCC ExxonMobil hereby submits the Report of Well Completion for the remedial abandonment work on the subject well. The well is plugged and abandoned as described in the Sundry approval of the well including removal of the wellhead and casing to at least 3' below tundra level and installation of identification marker plate. Attached please find two original copies of the following: • AOGCC Form 10-407: Well Completion or Recompletion Report and Log; • Work Summary; • Post P&A Well Schematic; and • Photographic documentation of the well before and after the work If you have any questions or require additional information, please contact me at (907)564-3773 or Tom Juranek at (832)624-6940. Sincerely, Irene T. Garcia SSHE Manager ITG:ed:bt Attachments: AOGCC Form 10-407: Well Completion or Recompletion Report and Log Work Summary Post P&A Well Schematic Photographic Documentation of the Well Before and After the Work POINT THOMSON 'PRODUCTION ExxonMobil Oil Corporation West Staines State #18-9-23 Final Well Schematic API #: 50-089-20001 PTD #: 169-120 Well marker Cement in 9-5/8" cas from 21,004' to s�ij Cement in 9-5/8" x 13-3/from ±1,004'to surface 9-5/8" casing punched at ±984'-1,004'& ±9 9-5/8" casing punched at +1,330'-1,350' (no circulation) TOC in 9-5/8" casing at 9,838' Top of 7" liner at 9,848' Retainer at 9&9%- at TOC at 10,422' Retainer at 10,472' TOC at 11,450' BP at 11,497' BP at 11,743' 30 Sx cement plug frc 12,350'- 12,409' Retainer at 12,409' Perforations 12,512'- 12,795' squeezed with 120 sx EZ drill BP at 12,869' 7" liner at 13,004' 6" and 5-15/16" hole to 13,329' ±3' below tundra 30" structural at 32' BGL cmt'd w/ 176 sx - 9-5/8" CIBP at ±145' with ±2.45" hole milled thru it. 20" @ 303', cemented to surface 10.6 ppg 13-3/8" DV Tool at 1,385' CaCI brine Tagged TOC in 9-5/8" at ±1,433' (on top of CIBP) BP in 9-5/8" at 2,000' with 25 sx on top 13-3/8", 61#, H-40 at 2,105'. Cemented with 700 sx G in stage 1, 1,200 sx fondu fly ash with 30% salt through DV 9.7 Tool for stage 2. Good returns at surface. ppg mud 9-5/8": 2,409' of 47#, Soo -95 7,700' of 43#, Soo -95 Cemented with 420 sx G Perforations 9,998'- 10,020', 4spf, squeezed with 100 sx class G through retainer 30 sx plug on retainer Perforations 10,570'- 10,590', 4 spf, squeezed with 110 cu.ft. cement 30 sx plug placed on top of BP/Retainer Perforations 11,650' - 11,675', 4 spf Perforations 11,675' - 11,715', 4spf Perforations 11,763'- 11,782', 4spf Perforations 12,512'- 12,525', 4spf Perforations 12,525'- 12,537', 4spf Perforations 12,630'- 12,650', 4spf Perforations 12,680'- 12,700', 4spf Perforations 12,780'- 12,795', 4spf 2 sx cement on top of EZ drill Cement plug in 7" from 12,900'- 13,078' 7": 2,032.8', 29#, Soo -95 1,100.6', 29#, Soo -95 3,156' total with hanger, shoe and collar Cemented with 400 sx G Squeezed 4 times with 5542 sx G total West Staines State #18-9-23 Summary of Work Activities 25 -Feb MI equipment move snow. Notified AOGCC of plans to start P&A of this well on March 7 2014. 26 -Feb Continue moving snow and leveling location. 27 -Feb SD due to weather. 28 -Feb Clearing snow after storm. 1 -Mar HSM. Cleaning and removing and leveling pad. 2 -Mar HSM. Cleaning and leveling location, start staging equipment. 3 -Mar HSM. Cleaning and leveling location, continue staging equipment, laying liners and building containments. 4 -Mar HSM. Cleaning and leveling location, continue staging equipment, laying liners and building containments. 5 -Mar HSM. Cleaning and leveling location, continue staging equipment, laying liners and building containments. 6 -Mar HSM, staging equipment laying liners and building containments. 7 -Mar HSM, staging equipment laying liners and building containments. 8 -Mar HSM, staging equipment laying liners and building containments. 9 -Mar HSM, staging equipment laying liners and building containments. 10 -Mar SD due to weather -35 degrees. 11 -Mar HSM, start MIRU equipment 50% complete. SDFN. 12 -Mar HSM, Continue MIRU equipment, building containments. 13 -Mar HSM, Continue moving equipment, NU BOP, build containments. Clean MI SWACO tank. Notify AOGCC of intent to test BOP on 3-16-2014. SDFN. 14 -Mar HSM, Building containments, spot accumulator and associated equipment, rig up lines to pumps, WH, reverse skid, pop-off line on 9-5/8" x 13-3/8" annulus to tank, building scaffolding around WH. SDFN. 15 -Mar HSM, Wrap scaffolding for heat control, Hook up accumulator lines, function test remote BOP panels, Test and set popoff at 1400# on 9-5/8" annulus, pump 0.8 bbls down 9-5/8" annulus held 1060# 5 min. bleed off. Received 225 bbls power vis. Preformed shell test on all lines and outside valves 250# low and 4000 for 5 min. bleed down. SDFN. 16 -Mar HSM, PU coil injector, SD due to Polar bear sighting 0700 to 0840 evacuate to secure area, finish PU injector and lubricator, Start BOP test, tested full body, HCR and manual, MI SWACO chokes and valves, coil lower blind sheers, Quad slips -pipes, coil reel valves all to a low of 250# and a high of 8000# with less than 20# leak off in 5 min. Heat calcium chloride water to 100 Degrees. SDFN. 17 -Mar HSM, Continue testing BOPE, test Combi blind/shears, BOP blinds BOP, blind/shears, kill HCRs, manual kill valves, and all block valves low of 250# and high of 8000# for five minutes less than 20# loss. ND lub and coil BOPE, break out 11" DSA, PU retrieving tool pull test plug, PU Stripper and lub PU, BHA consisting of Dual Back pressure valve, Jars, Disconnect, Dual circulation valve. SDFN. 18 -Mar HSM, finish PU BHA and test repaired leaks in tools, NU lubricator, Pump up 9-5/8" to 1100 and hold, Test against wellbore to 2500#, SLB lost packing in pump. Pump warm oil in coil, start MI power vis fluid 112 degrees into coil, back up pump going down, froze fluid in top of reel. RD lub and injector head, cover coil with tarps and put heaters on to warm up. SDFN. 19 -Mar HSM, reverse pumped slick water through coil to tank, MU/NU lubricator, test MM and freeze protect w/diesel. Mechanic repacked pump, eqpt maintenance, tested pump, heated &circulated Power Vis to 120deg. SDFN. 20 -Mar HSM, pumped heated diesel to warm coil, displaced coil w/drilling slickwater, began circ 3.8 bpm @ 2400psi, fluid temp 114deg. Tagged cement @36'CTD. SD after losing pump packing @3:50. Milled 64' cement(6 ft/hr avg). Repacked pump, found ice in oiler line, placed heater oiler/pump. SDFN. 21 -Mar HSM, pumped heated diesel to warm coil, displace coil w/drilling slickwater, began circ 4.2bpm, 3900psi, 139deg fluid at start. Drilled 45' <9hrs. Avg 5.5' p/hr. Final circ psi 4300 @4.1, fluid temp 145deg. Circulated 10bbls FW into slickwater to decrease temp/decrease viscosity. SDFN. West Staines State #18-9-23 Summary of Work Activities 23 -Mar HSM, ND Milling BHA and NU setting tool for funnel and test 2500lbs, GT. RIH & Set funnel. ND setting tool and NU 2.45" mill bit & BHA assembly and test 200/2500lbs GT. Had trouble getting through the BOPs, finally worked out way througn BOPS and tagged plug through funnel and picked up 6', freeze protected and SDFN. 24 -Mar HSM, pumped heated diesel to warm coil, tagged plug at 144.7'. Milled through plug in 2 hours and 45 minutes. Made 3 passes back and forth, POOH. ND drill bit BHA and NU wash nozzle. Freeze protect and SDFN. 25 -Mar Test BOPS. Good Test. EPA inspectors showed up at 230 pm, performed walkaround and gave us a good report. 26 -Mar HSM, circulated diesel and warm coil, RIH to 1433' and circulate out diesel pumped 155 bbls of 10.6 KCL, RD wash nozzle and RU 19/16" guns 2 spf RIH and sat down in top of funnel, POOH and made adjustment to a double knuckle joint above the guns, RBIH to 1350' and fired guns, could not circulate. POOH re- loaded guns RBIH to 1,003.6" shot guns and got some communication, pumped 16 bbls in 9 5/8 x 13 3/8 annulus then plugged off. Freeze protect and SDFN. 27 -Mar HSM, pressured up 9 5/8" to 2500psi and held, no circulation, bled off, pumped 4 bbls 70deg CaCI on OA and applied 500psi, held 5 minutes, no communication, bled off. MU 20'ft puncher to RIH. Attempted to PT lubricator and noted communication with OA. Open OA to tank &established returns to tank at max rate 1.8 @2100 psi coil. Circulated out diesel with 106 bbl CaCI. RIH w/20' punch 953-973', perf &POOH, establish injection 4.5 bpm @600psi, SI wait for cement. MIRU cement, PT lines, est inj rate with 20 FW ahead, pump 150bbi 15.7ppg Schlumberger Arctic set, clean cement returns to surface after 140bbls, shut in well, flush lines, RDMO cement, SDFN@ 23:50. 28 -Mar Commence RD of all equipment to be re -located to WSS #2. Equipment rigged down and moved (Little Red Hot Oil, Schlumberger Coil, Pump & Reverse Pump Skid, M.I. Swaco Mud Unit, 400 bbl Tanks, Tiger Tanks, and misc. equipment). Estimated 70% of equipment rigged down and moved. 29 -Mar Continue RD of all equipment and containment's from WSS 18-9-23 over to WSS #2. Completed RD of BOP stack and re -located. Commence clean up of location and preparation to excavation of well head. 30 -Mar Continue packaging up containment's and cleaning up location. 31 -Mar Commence excavation around well head. 1 -Apr Completed excavation around well head. Completed cutting conductor from well head and removed cement. Rigged up Wachs Saw to be ready to remove well head on April 2, 2014. 2 -Apr Completed Wachs Saw of well head and removed from excavation. Trimmed 20", 13 3/8" & 9 5/8" casing down to conductor pipe. Ran 1" tbg. into 9 5/8" casing to est. 15' tag cmt top. Ready to top off cement on 4/3/2014. SDFN. 3 -Apr HSM, MIRU Schlumberger cement truck Pump and filled 9-5/8" casing and conductor string. RD Schlumberger and SDFN. 4 -Apr HSM, took pictures of casing topped off with cement, weld idiification plate on casings. Back filled around wellbore. SDFN. Final Report on Well. WSS #18-9-23 As Found WSS #18-9-23 Coil Tubing Operations A. 11 diL :� WSS #18-9-23 Wellhead Cut Off !ter s ,��..c ;y WSS #18-9-23 All Strings Topped Off A., $.W" a ,,wRs �t t. "3? t .c... ,gip At 40 �"+... � �� Ms '�� � '� • a X Fes' .x s s. ,„� '�s,.� M,; ,44 44 �°*�s ' � t,"' -ti R� `mss :* � �� � "# .� y ,_•'�,,.�• - "M�'_,a► , ,. �„ y '" s "'�Il� � i^ .r e wr ia' 0 Below Tundra WSS #2 Looking west to east post cleanup. Debris was collected in supersacks (seen in center of picture) and transported back to Deadhorse for appropriate disposal. WSS #2 Debris collection awaiting transport to Deadhorse. Page 10 Abandoned Well Site Cleanup Report July 18, 2014 Schwartz, Guy L (DOA) From: Peterson, James M /C <james.m.peterson@exxonmobil.com> Sent: Monday, April 07, 2014 3:52 PM To: Dennis Collins; Greene, Timothy L; Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Cc: Winter, Cassondra E; Farrar, Kendall N; Juranek, Tom A; Hawthorne, Brian K; Emmett, Cody; Cox, Mirick T; Denman, Erika /C; Bill Penrose; Dragnich, Rob /EXT; bob.hagberg@solstenxp.com; shane.mcgeehan@solstenxp.com; Steve Lewis Subject: RE: West Stains St. 18-09-23_ Daily Report . PT -r-> /(,c(,(Z0 ExxonMobil West Stains St. 18-09-23 Daily Report: st 4/06/2014 P&A Complete, No further reports. 4-05-2014 No Activity. 4-04-2014 HSM, took pictures of casing topped off with cement, weld identification plate on casings. Back filled around wellbore. SDFN 4/03/2014 HSM, MIRU Schlumberger cement truck Pump and fill 9-5/8" casing and 32" conductor pipe RD Schlumberger and SDFN. James (Jim) Peterson ExxonMobil Workover Supervisor North Slope Cell: 907-891-5838 Cell: 281-610-6630 Email: iames.m.oeterson(@exxonmobil.com Email: leyvapeterson@aol.com 4/02/2014 Completed Wachs Saw of well head and removed from excavation. Trimmed 20", 13 3/8" & 9 5/8" casing down to 32" conductor pipe. Ran 1" tbq. into 9 5/8" casing to -est. 15' tag cmt top Ready to top off cement on 4/3/2014. SDFN 4/01/2014 Completed excavation around well head. Completed cutting 32" casing from well head and removed cement. Rigged up Wachs Saw to be ready to remove well head on April 2, 2014. 1 3/31/2014 Commence excavation around well head. 3/30/2014 Continue packaging up containment's and cleaning up location. 3/29/2014 Continue RD of all equipment and containment's from WSS 18-9-23 over to WSS #2. Completed RD of BOP stack and re -located. Commence clean up of location and preparation to excavation of well head. 3/28/2014 Commence RD of all equipment to be re -located to WSS #2. Equipment rigged down and moved (Little Red Hot Oil, Schlumberger Coil, Pump & Reverse Pump Skid, M. I. Swaco Mud Unit, 400 bbl Tanks, Tiger Tanks, and misc. equipment). Estimated 70% of equipment rigged down and moved. 3-27-2014 HSM, pressured up 9 5/8" to 2500psi and held, no circulation, bled off, pumped 4 bbls 70deg CaCI on OA and applied 500psi, held 5 minutes, no communication, bled off. MU 20'ft puncher to RIH. Attempted to PT lubricator and noted communication with OA. Open OA to tank &established returns to tank at max rate 1.8 @2100 psi coil. Circulated out diesel with 106bbl CaCI. RIH w/20' punch 953 973'. perf &POOH, establish injection 4.5 bpm @600psi, SI wait for cement. MIRU cement, PT lines, est inj rate with 20 FW ahead, pump 150bbl 15.7ppg Schlumberger Arctic set, clean cement returns to surface after 140bbls , shut in well, flush lines, RDMO cement, SDFN@ 23:50. 3-26-2014 HSM, RIH with wash nozzle, tagged soft @1433 :j ou iesel with 10.6# CaCI, POOH, MU 20' Schlumberger tubing puncher , RIH to 1350' & perforated, unable to circulate through annulus, POOH, MU/RBIH with 20' puncher to 1000' and pert, some communication established, initial pump in rate 1.3bpm with minimal returns up 13 3/8", lost returns after 15 bbls, shut down at 2500psi, no returns. Will reperf higher on 3-27, SDFN 3-25-2014 HSM, began BOP testing 8:00 am, EPA site visit @15:30, completed BOP testing 18:30. SDFN. 3-24-2014 HSM, circulated heated diesel through coil to tank, swapped to drilling fluids , tagged, began milling 09:56, milled through plug @12:40, No pressure below plu , ream and sweep through plug, POOH, MU wash nozzle, prep for BOP testing 3-25-14. 3-23-2014 HSM, broke out drilling tools, MU/RIH centralizer funnel and tagged @ 145.1CTD, pumped to release from running tool, POOH, MU pilot mill/motor, freeze protect, SDFN. 3-22-2014 HSM, pumped heated diesel through coil to tank, swapped to drilling fluids and began milling 08:40, tagged cement @129.8 CTD milled 13.9' @17:30, recovered metal fines and blue paint in cutings, ON Plug, freeze protected, conditioned drilling fluids, SDFN. Total cement milled 123 ft. 3-21-2014 HSM, pumped heated diesel through coil to tank, swapped to drilling fluids and began milling 08:30, tagged cement @99' GL, milled 45' @17:30, freeze protected, conditioned drilling fluids, SDFN. 3-20-2014 HSM, pumped heated diesel through coil to tank, swapped to drilling fluids and began milling 08:30, tagged cement @36' CTD, milled 64' cement before shutting down @15:45 due to lost pump, freeze pro ected, repalre pump, SDFN. 3-19-2014 HSM, RU to coil and reversed out 12.5 bbls slick water to tank, freeze protected coil with diesel, repaired packing on Schlumberger pump, performed maintenance on egpt, heated drilling fluids tank to 130deg. SDFN ' Tim Greene Wellwork Supervsior ExxonMobil BTPO-Pt Thomson, AK Ofc 281.654.8820 Lync 832.624.3265 Mbl 281.732.1469 From: Greene, Timothy L Sent: Saturday, March 22, 2014 6:15 AM To: 'Schwartz, Guy L (DOA)'; 'DOA AOGCC Prudhoe Bay' Cc: 'Dennis Collins (drecollins1953(cbyahoo.com)'; Winter, Cassondra E; Farrar, Kendall N; Juranek, Tom A; Hawthorne, Brian K; Emmett, Cody; Cox, Mirick T; Denman, Erika /C; 'Bill Penrose'; Dragnich, Rob /EXT; 'bob. hag berg@solstenxp.com'; 'shane.mcgeehan@solstenxp.com'; Peterson, James M /C Subject: RE: West Stains St. 18-09-23 Daily Report From: Greene, Timothy L Sent: Thursday, March 20, 2014 10:04 PM To: Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Cc: Dennis Collins (drecollins1953(cDyahoo.com); Winter, Cassondra E; Farrar, Kendall N; Juranek, Tom A; Hawthorne, Brian K; Emmett, Cody; Cox, Mirick T; Denman, Erika /C; Bill Penrose; Dragnich, Rob /EXT; agbery; gym; shane.mcgeehanCa_solstenxp.c ;Peterson, James M /C Subject: RE: West Stains St. 18-09-23 Daily Report ExxonMobil West Stains St. 18-09-23 Daily Report: 3-21-2014 HSM, pum luids and began milling 08:30, tagged cement @99' GL, milled 45' @17:30, freeze protected, conditioned n In DFN. 3-20-2014 HSM, pumped heated dies rough coil to tank, swapped to drilling fluids and be ing 08:30, tagged cement @36' CTD, milledent before shutting down ue to lost pump, freeze protected, repaired pump, SDFN. 3-19-2014 HSM, RU to coil and reversed o 5 bbls slick water to tank, freeze pro coil with diesel, repaired packing on Schl erger pump, performed maintenance on egpt, heate ing fluids tank to 130deg. SDFN Tim Greene Wellwork Supervsior ExxonMobil BTPO-Pt Thomson, AK Ofc 281.654.8820 Lync 832.624.3265 Mbl 281.732.1469 Pt Thomson Mobile 907.891.5839 From: Peterson, James M /C Sent: Wednesday, March 19, 2014 1:17 PM To: Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Cc: Dennis Collins (arccollins1953(q-)yahoo.con ); Winter, Cassondra E; Farrar, Kendall N; Greene, Timothy L; Juranek, Tom A; Hawthorne, Brian K; Emmett, Cody; Cox, Mirick T; Denman, Erika /C; Bill Penrose; Dragnich, Rob /EXT; bob. hag berq(q�solstenxp.corn; shane.mcgeehan6c�solstenxp.com Subject: RE: West Stains St. 18-09-23 Daily Report ExxonMobil West Stains St. 18-09-23 Daily Report - 3 -18-2014 HSM, finish PU BHA and test repaired leaks in tools, NU lubricator, Pump up 9-5/8" to 1100 and hold, Test against wellbore to 2500#, SLB lost packing in pump. Pump warm oil in coil, start MI power vis fluid 112 degrees into coil, back up pump going down, froze fluid in top of reel. RD lub and injector head, cover coil with tarps and put heaters on to warm up. SDFN 3-17-2014 HSM, Continue testing BOPE, test Combi blind/shears, BOP blinds BOP, blind/shears, kill HCRs, manual kill valves, and all block valves low of 250# and high of 8000# for five minutes less than 20# loss. ND lub and coil BOPE, break out 11" DSA, PU retrieving tool pull test plug, PU Stripper and lub PU, BHA consisting of Dual Back pressure valve, Jars, Disconnect, Dual circulation valve. SDFN 3-16-2014 HSM, PU coil injector, SD due to Polar bear sighting 0700 to 0840 evacuate to secure area, finish PU injector and lubricator, Start BOP test, tested full body, HCR and manual, MI SWACO chokes and valves, coil lower blind sheers, Quad slips -pipes, coil reel valves all to a low of 250# and a high of 8000# with less than 20# leak off in 5 min. Heat calcium chloride water to 100 Degrees. SDFN. Will finish BOP testing 3-17-2014. 3-15-2014 HSM, Wrap scaffolding for heat control, Hook up accumulator lines, function test remote BOP panels, Test and set pop off at 1400# on 9-5/8" annulus, pump 0.8 bbls down 9-5/8" annulus held 1060# 5 min. bleed off. Performed shell test on all lines and outside valves 250# low and 4000# bleed down. SDFN 3-14-2014 HSM, Building containments, spot accumulator and associated equipment, rig up lines to pumps, WH, reverse skid, popoff line on 9-5/8" x 13-3/8" annulus to tank, building scaffolding around WH. SDFN . Daily Report: 3-13-2014 HSM, Continue moving equipment, NUBOPE, build containments. Clean MI SWACO tank. Notify AOGCC of intent to test BOPE on 3-16-2014. SDFN. Daily Report 3-12-2014 HSM, MIRU spotting equipment, NDWH removed old 5k packoff, installed new 10k isolation sleeve, and packoff, install 10k tubing head, tested lower seals to 5K, good test. SDFN ExxonMobil West Stains St. 18-09-23 Daily Report 3-11-2014 HSM, Start moving in rigging up equipment 50% complete. Regards, James (Jim) Peterson ExxonMobil Workover Supervisor Cell: 281-610-6630 Email.- Email: mail:Email: leyvapeterson(cD_aol. com Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, March 14, 2014 4:07 PM To: 'Juranek, Tom A' Cc: Collins, Dennis /C; Greene, Timothy L; Peterson, James M /C; Farrar, Kendall N; Winter, Cassondra E; Cox, Mirick T; Dragnich, Rob /EXT; Denman, Erika /C; Bill Penrose (bill@solstenxp.com) Subject: RE: Addendum to Procedures for West Staines State #18-9-23 (PTD 069-120, Sundry 313-604), West Staines State #2 (PTD 175-002, Sundry 313-606), Staines River State #1 (PTD 179-001, Sundry 313-605), and Point Thomson Unit #1 (PTD 176-085, Sundry 313-600) Tom, Thanks for the amended PT procedures. This new lower "master valve " will take care of the concerns that were identified. You have approval to pressure test (2500 psi) against the 9 5/8" casing for W Staines State #18-9-23 for verification of flange breaks during routine BHA change -outs . All the other following P & A wells must have the new 11" test valve installed. I will print out the attached addendums and add them to our well file. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office NN From: Juranek, Tom A [mailtc - ranek@exxonmobil.com] Sent: Friday, March 14, 2014 1:14 PM To: Schwartz, Guy L (DOA) Cc: Collins, Dennis /C; Greene, Timothy L; Peterson, James M /C; Farrar, Kendall N; Winter, Cassondra E; Cox, Mirick T; Dragnich, Rob /EXT; Denman, Erika /C; Bill Penrose ( ;,�,u, p.co+ ) Subject: Addendum to Procedures for West Staines State #18-9-23 (PTD 069-120, Sundry 313-604), West Staines State #2 (PTD 175-002, Sundry 313-606), Staines River State #1 (PTD 179-001, Sundry 313-605), and Point Thomson Unit #1 (PTD 176-085, Sundry 313-600) Guy, Following up on our discussion in your office on Tuesday, March 11, 1 am sending you addendums to our procedures concerning our BOP pressure testing. Attached are addendums for each of the remaining wells that we are planning to work on this winter season. Please let me know if these addendums are approved or if you need further information or clarification. In addition, we are also seeking permission to deviate with our BOP testing on the WSS #18-9-23 as we did on the PTU #2 (BOP test against our test plug with break tests of only 2,500 psi against the 9-5/8" casing) until the "Testing Valve" arrives and can be installed and tested. We have located and are mobilizing the extra 11" 10k ram that we will use as our "Testing Valve". However, we will most probably have moved our Coiled Tubing Unit to the WSS #18-9-23 and be ready for operations 2-3 days prior to the valve arriving. Once we have the Testing Valve, we will follow the addendums. Please respond on approval of the addendums and for the deviation until the testing valve arrives. I appreciate your time on Tuesday and your assistance to make our remediation campaign a success. Please let me know if you have any questions or need anything further. Thanks, Tom luranek Subsurface Engineering Advisor EMPC Global Engineering -Houston Subsurface Engineering & Operations Support CORP -EMB -30211 Lync Phone: 832-624-6940; Fax: 713-656-7353; Whone: 832-596-5406 email: tom.a.iuranek@exxonrr WEST STAINES STATE #18-9-23 Sundry # 313-604 API # 50-089-20001 APTD#: 169-120 Addendum - Pressure Testing Procedures (Refer to wellhead and BOP diagram below) Initial BOP test and subsequent 7 -day BOP tests: 1. Close the 11" 10k "Testing Valve" and pressure test from the testing valve to the choke manifold to 8,000 psi. 2. Close Drilling Spool Gate Valves and "Testing Valve" and Pressure Test the CT BOP rams to 8,000 psi as per SLB Procedure (Note: 11" equipment are tree valves and not BOPS) a. SLB Combi BOPS b. SLB Quad BOPS 3. Close the 11" 10k "Test Valve" and pressure test across the broken connection. a. Prior to Drilling of surface plug (cement and/or CIBP), test to 8,000 psi. b. After verifying no pressure below plugs, test to 3,000 psi. 11", 10k Rams Used as Tree Valves DSA -11" 10k X 4" 10k 11" 10k SPACER SPOOL 11" 10k DRILUING SPOOL WITH 2" 10k MANUAL GATE VALVES 11" 10k SWAB VALVE W/ BLIND/SHEAR RAMS 11" 10k MASTER VALVE W/ STRAIGHT BLIND RAMS 11" 10k TESTING VALVE W/ STRAIGHT BLIND RAMS (RAM BODY AND RAMS INSTALLED UPSIDE DOWN) 4-1/16", 10K Coil BOP System Poe-'wIP D SLB Combi BOP's 1., or o jj�s9 THE STATE Alaska Oil and Gas #.. fALASI�:A - „� a.�_ ' ° Cse>iai Ynissi®n GOVERNOR SEAN PARNELL 333 West Seventh Avenue O *^ Q� Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Irene T. Garcia S`pNNED (SAY ® 2014 SSHE Manager ExxonMobil Oil Corporation PO Box 196601 1.,(0 Anchorage, AK 99519 Re: Wildcat Field, Wildcat Pool, West Staines State #18-9-23 Sundry Number: 313-604 Dear Ms. Garcia: Enclosed is the approved proved 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, Cathy P. 'oerster Chair DATED this day of December, 2013. Encl. RECEIVED STATE OF ALASKA �i� NOV 9 2013 �, ALASKA OIL AND GAS CONSERVATION COMMISSION i 2./2O(13 Ito APPLICATION FOR SUNDRY APPROVALS AOGCC 1 20 AAC 25.280 1.Type of Request: Abandon[ Plug for Redrill ❑ Perforate New Pool❑ Repair Well❑ Change Approved Progran❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other. _Well Remediation n • • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ExxonMobil Oil Corporation Exploratory Q • Development ❑ 169-120 3.Address: Stratigraphic ❑ Service ❑ • 6.API Number: PO Box 196601,Anchorage,AK 99519-6601 50-089-20001 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ElNo 0West Staines State#18-9-23 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 28380 ' Wildcat 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13,329 - 13,329 ' 0 0 Many plugs,see schematic None Casing Length Size MD TVD Burst Collapse Structural 32' 30" 32' 32' Conductor 268' 20" 303' 303' 1,530 520 Surface 2,070' 13-3/8" 2,105' 2,105' 3,090 1,540 Intermediate Production 10,052' 9-5/8" 10,087' 10,087' 7,510 5,600 - Liner 3,156' 7" 13,004' 13,004' 8,600 5,890 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 0 • Stratigraphic❑ Development❑ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: February 1,2014 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑Q • Commission Representative: GSTOR ❑ SPLUG El 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tom Juranek 713-656-4225 Email tom.a.juranek@exxonmobil.com Printed Name Irene T.Garcia Title SSHE Manager Signature jrkx j // O� G'v: Phone 907-5643773 Date /fit s.-713......_ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Cr -- CsLo1{ Plug Integrity [ BOP Test lEr. Mechanical Integrity Test 0 Location Clearance y[�]o""---Zo/L-( Other: 7 . ee6 /9 3` ig°P "L s _ / �J /� I -,�- Oof .+� G G S G !og •E i cCe ,/J lam(,.- • 1� eta cru-.+ e- Pc / SpacingException Required? Yes 0 No Subsequent Form Required: —y o 7 �� RBDMS 4A,AY 0 9 2014 / APPROVED BY // Approved by: .�// / ( COMMISSIONER THE COMMISSION Date: /2 Z. �3 ^ RlfG IIALedto ofa / Submit Fop andForm 10 403(Revised 10/2012) Appr e 1 Mont from the date of approval. � A hments in Du licate j ExxonMobil Production Compa,., RECEIVE) P.0.Box 196601 Anchorage,Alaska 99519-6601 NOV 1 9 2013 907 561 5331 Telephone EkonMobil AOGCC Production November 15, 2013 R-2013-OUT-022 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Re: Application for Sundry Approval Well Remediation:West Staines State#18-9-23(PTD No. 169-120) Dear Commissioner Foerster, ExxonMobil hereby applies for Sundry Approval to perform remedial plugging and abandonment work on the subject well. The work is described in more detail on the attached Summary Procedure. The general procedure will be: i 1. Drill through the surface cement plug and bridge plug at 150'. 2. Circulate out diesel from the 9-5/8"casing from 150'to±1,950'. 3. Perforate 9-5/8"casing and circulate out diesel from the 9-5/8"x 13-3/8"annulus. 4. Fill the 9-5/8"and 9-5/8"x 13-3/8"annulus with cement. 5. Cut off the wellhead and all casing strings at least 3' below the natural tundra level. 6. Top off the 9-5/8"casing and all annuli with cement. 7. Install a well identification marker plate and backfill the excavation with gravel. Attached please find the following documents supporting this Application: • Sundry Application Form 10-403 • Proposed Work Procedure including before and after wellbore diagrams Please note following the winter 2013-14 well remedial work, ExxonMobil plans to conduct further site rehabilitation at this location in the winter of 2014-15, which will include removing some gravel and preparing the site for ultimate revegetation. We will plan to discuss location clearance with the AOGCC in light of the additional work planned. If you have any questions or require additional information, please contact me at (907) 564-3773 or Tom Juranek at 713-656-4225. Sincerely, ji.44-4 14,1-Ce.-6K---' Irene T. Garcia SSHE Manager Attachments: • Sundry Application Form 10-403 • Proposed Work Procedure including before and after wellbore diagrams POINT THOMSON 114 PRODUCTION WEST STAINES STATE #18-9-23 WELL HISTORY AND ABANDONMENT PROCEDURE Affected Wells and API/APTD Numbers: West Staines State#18-9-23 API# 50-089-20001 APTD#: 169-120 Background: The West Staines State#18-9-23 well was drilled in 1970. The well was plugged and abandoned on August 13, 1970, but requires the removal of+1,950' of diesel in the 9-5/8" casing, removal of diesel in the 9-5/8" x 13-3/8"annulus and removal of the wellhead to at least three feet below ground level consistent with current AOGCC regulations. In order to access and remove the diesel in the 9-5/8" casing, a cement plug currently extending from ±10' to 150' and a bridge plug at 150'will need to be drilled through. The current well schematic is attached to this procedure. The Maximum Anticipated Surface Pressure (MASP) is 0 psi as the reservoir section of the well is effectively isolated and no pressure was found during a wellhead inspection in 2009. However, in an abundance of caution and because the top cement plug will be penetrated, the work will be performed assuming a "worst case" scenario of the highest anticipated surface pressure(±7,900 psi) encountered below the surface plug based upon Thomson Sand reservoir pressures. Therefore, the wellhead will be upgraded to 10k psi rating and BOPs and the Coil Tubing Unit will be rated to 10,000 psi. OBJECTIVE: • Drill through the surface cement plug and bridge plug at 150'. • Circulate out diesel from the 9-5/8" casing from 150' to ±1,950'. • Perforate 9-5/8" casing and circulate out diesel from the 9-5/8" x 13-3/8" annulus. • Fill the 9-5/8"casing and 9-5/8"x 13-3/8" annulus with cement. • Cut off the wellhead and all casing strings at least 3' below the natural tundra level. • Top off the 9-5/8" casing and all annuli with cement. • Install a well identification marker plate and backfill the excavation with gravel. The proposed abandonment will be supported by on-site equipment and materials such as excavator, camp, fuel, and other essential elements of remote operations. The following well abandonment program is planned: 1. Insure all necessary permits and applications are in place. Notify AOGCC at least 10 days before operations begin. 2. MI and prepare location. Record pressures on the 9-5/8" casing and annuli. Bleed off any found pressure. 3. Remove the 13-5/8" 5K psi cap and marker post. Measure the depth to the cement in the 9-5/8" casing (expect+10'). Install isolation sleeve into the tubing head. Install new 13- 5/8" 5K psi x 11" 10 ksi tubing head. his will increa'se the pressure rating of the wellhead to 10K psi. e,t. ZSG° p 5� 4. Notify AOGCC of planned BOP testing and confirm steps to be witnessed throughout operation. WEST STAINES STATE#18-9-23 Abandonment Procedure pi a °OCA POINT THOMSON r4 PRODUCTION 5. Install 10k psi BOP consisting of 11" 10k double BOP with blinds over blind/shear rams, 11" 10k flow cross with 2" 10k manual gate valves, and 11" 10k x 4" 10k double studded adaptor. Test the BOPs to 8,000 psi. 6. Rig Up the Coiled Tubing unit and test the CT BOPs to 8,000 psi. 7. Drill out the surface cement plug to the CIBP at±150'. 8. Drill a hole through the CIBP. 9. Run in hole through the CIBP to the cement plug at approximately±1,950'. Circulate out diesel from the 9-5/8" casing. 10. Perforate the 9-5/8" casing at±1,400' to establish circulation down the 9-5/8" casing and up the 9-5/8"x 13-3/8" annulus. If unable to circulate, perforate ±100' higher until circulation is achieved. 11. Circulate out diesel from the 9-5/8"x 13-3/8" annulus. 12. Circulate cement into the 9-5/8" x 13-3/8" annulus. 13. Fill the 9-5/8" casing with cement from ±1,950' to surface. 14. Rig down the Coiled Tubing Unit. 15. Excavate deep enough to allow removal of the wellhead at least 3' below original tundra level. 16. Cut and remove the wellhead using a Wachs saw. 17. Cut all strings flush and top off the 9-5/8" casing and annuli with cement as required. 18. Level casing stub using a grinder. Weld marker plate (±30" OD)with well information across all casing strings. Marker plate to contain the following information bead welded onto it: West Staines State#18-9-23 ExxonMobil Oil Corporation PTD# 169-120 API # 50-089-20001 19. Backfill cellar with gravel. Mound the gravel (5-10')to compensate for summer thawing and settling as per AOGCC guidance. 20. Clean up location. Transport all wastes and site clean-up debris to Deadhorse for disposal at approved waste disposal sites in accordance with ExxonMobil Waste Management Plan. WEST STAINES STATE#18-9-23 Abandonment Procedure PA O2 o42 POINT THOMSON PRODUCTION erik N ExxonMobil Oil Corporation West Staines State#18-9-23 Current Well Schematic API#: 50-089-20001 PTD#: 169-120 Wellhead A section with blind flange&marker post on too RKB=63'MSL=15.5'above bradenhead I �� �i 30"structural at 32'cemented with 176 sx cement0 :1it„ r Diesel in 9-5/8"casing from 0'-10' h4 30"cemented with 176 sx cement :, ,* Diesel in 13-3/8"x 9-5/8"annulus from 1,472'to surface k4,4, ,r o o c BP in 9-5/8"at 150'with 50 Sx fondu to 10',diesel on top 0_, m + Diesel e 20"@ 303',cemented to surface to e, e, Diesel in 9-5/8"casing from 150'-1,950'± 13-3/8"DV Tool at 1,385' LON a.-- CP..1 t i,. Cement in 13-3/8"x 9-5/8"annulus from 1,472'-______- a ,f 'T�,c. 2,105' t 4l BP in 9-5/8"at 2,000'with 25 sx on top(PB-1,950') 13-3/8",61#,H-40 at 2,105' Q.•. 13-3/8"cemented with 700 sx Gin stage 1,1,200 sx fondu flyash with 30%salt through DV Tool for stage 2.Good returns at surface 9.7 PPB d Lm1J :i TOC in 9-5/8"casing at 9,838' Top of 7"liner at 9,848' 'PrTtliiN■ Retainer at 9,898' -' 5 "--••, 9-5/8"at 10,087' `• ' '' 4.1(91' 9-5/8":2,409'of 47#,Soo-95 i 7,700'of 43#,Soo-95 r.11. ` Cemented with 420 sx G :1+ ta k.' Perforations 9,998'-10,020',4spf,squeezed with 100 sx class :R; '' '- ',4 G through retainer TOC at 10,422' S ,A;4,,,s ,� 30 sx plug on retainer Retainer at 10,472' :1 10.= �y _ -a Perforations 10,570'-10,590',4 spf,squeezed with 110 cu.ft.cement Zr" '4,- TOC at 11,450' " Q4,`? , r-447,,;„,ire 30 sx plug placed on top of BP/Retainer y� a,''rsl BP at 11,497' 11.-= ' ". • tiPerforations 11,650'-11,675',4 spf :* r ".�• Perforations 11,675'-11,715',4spf BP at 11,743' Perforations 11,763'-11,782',4spf 30 Sx cement plug from ' r',y hi 12,350'-12,409' At ,;y4 .fir.' Retainer at 12,409' -� w a_ Perforations 12,512'-12,525',4spf Perforations 12,512'-12,795'squeezed with 120 sx :. _ Perforations 12,525'-12,537,4spf q �r�' Perforations 12,630' 12,650',4spf t 4192 Perforations 12,680 12,700',4spf "' :.*1'..‘ t .*a'.. , Perforations 12,780'-12,795',4spf Z'ryr • 2 sx cement on top of EZ drill EZ drill BP at 12,869' • �- ' ; Cement plug in 7"from 12,900'-13,078' 7"liner at 13,004' -4;041-',4: , • 7":2,032.8',29#,Soo-95 it 1,100.6',29#,Soo-95 - 6"and 5-15/16"hole to 13,329' $ 3,156'total with hanger,shoe and collar Cemented with 400 sx G Squeezed 4 times with 5542 sx G total WEST STAINES,STATE'#18-9-23 Current Sketch el. POINT THOMSON PRODUCTION ExxonMobil Oil Corporation West Staines State#18-9-23 Proposed Post P&A Well Schematic API#: 50-089-20001 PTD#: 169-120 Well m. 'tundra RKB=63'MSL=15.5'above bradenhead Cement in 9-5/8"casing gill ; 'Ir. 5$ from 2,000' to surface ^a# t� 30"structural at 32'BGL cmt'd w/176 sx i. Cement in 9-5/8"x 13-3/8"annulus ��� 20"@ 303',cemented to surface from ±1,400" to surface 13-3/8"DV Tool at 1,385' 9-5/8"casing punched at+1,400' mi• BP in 9-5/8"at 2,000'with 25 sx on top 13-3/8",61#,H-40 at ,, 13-3/8"cemented with 700 sx G in stage 1,1,200 sx fondu flyash with 30%salt through DV Tool for stage 2.Good 9.7 returns at surface ppg mud TOC in 9-5/8"casing at 9,838' Top of 7"liner at 9,848' :: . Ell i Retainer at n ono, 9-5/8"at 9-5/8":2,409'of 47#,Soo-95 7,700'of 43#,Soo-95 Cemented with 420 sx G - Perforations 9,998'-10,020',4spf,squeezed with 100 sx TOC at 10,422' class G through retainer 30 sx plug on retainer Retainer at 10,472' = Perforations 10,570'-10,590',4 spf,squeezed with 110 cu.ft. • cement s TOC at 11,450' IIIIII 30 sx plug placed on top of BP/Retainer BP at 11,497' 1-► C _ Perforations 11,650'-11,675',4 spf Lo Perforations 11,675'-11,715',4spf BPat11,743' }►� « Perforations 11,763'-11,782',4spf 30 Sx cement plug from ,: 12,350'-12,409' + • '3rt:, Retainer at 12,409' Perforations 12,512'-12,525',4spf Perforations 12,525'-12,537',4spf Perforations 12,512'-12,795'squeezed with 120 sx �:- Perforations 12,630'-12,650',4spf - Perforations 12,680'-12,700',4spf Perforations 12,780'-12,795',4spf IR�J' : 2 sx cement on top of EZ drill EZ drill BP at 12,869' ` `` ,� } , Cement plug in 7"from 12,900'-13,078' e'er' 4+(:a T liner at 13,004' , c.0,;041%,fi '2: 7":2,032.8',29#,Soo-95 ;,,,k.: Z 1,100.6',29#,Soo-95 " "` "z� 3,156'total with hanger,shoe and collar • 6"and 5-15/16"hole to 13,329' Cemented with 400 sx G Squeezed 4 times with 5542 sx G total WEST STAINES STATE#18-9-23 Propoosed Sketch , • POINT THOMSON 16 PRODUCTION BOP Configuration N, ti ' ..-!:F 1 •. . 1-1 SII Injector tread for 2`' coiled tubing. 44% Dual pack-off -- 4.06" ID, 10k Lubricator as needed I6' &8' sections} Iu_ .� - I °1 ,.t° l Blind I `. la $hear �. � � SLB Quad BOP, 10k Itf l q ¢+ Slips 04 l n l Pipe j 7 f - SIB Combi BOP, 10k ,.- . .--— 11", lOkx41/16 10k x-o< -- (flange to be used for BHA changes) • ` 11°, 10k Spacer Spool,3 ft � — 117, 10k Flow gots 10 ft ". nen • 11 ..., 11.1 l t' k Al Ind Ram * i1= •:hoir, 511 1 1.. -:... U ,ad/Shear Ram 'lip '!__- Vilellheadsto be upgraded to 10 k service WEST STAINES STATE#18-9-23 Planned BOP Assembly Page 1 of 1` Schwartz, Guy L (DOA) From: Juranek,Tom A <tom.a juranek@exxonmobil.com> Sent Wednesday, December 04, 2013 12:47 PM To: Schwartz, Guy L(DOA) Cc: Dragnich, Rob/EXT; Denman, Erika/C Subject: RE: PT-1 PT-2 and Staines River State#1 Attachments: j WSS#18-9-23kolation Sleeve.pdf Guy, The PTU #1, #2, #3 were all heritage Exxon wells with McEvoy (now Cameron) wellheads. They are all configured similarly and be using the same extended packoff to upgrade. 1 The WSS#2 and SRS#1 are heritage Mobil wells with FMC wellheads. Conceptually, they will be upgraded similarly to the Cameron wellheads (replace 5k psi Tubing Head with 10k psi Tubing Head and use upgraded seals to isolate the 5k portion of the wellhead). I don't have a good diagram of the FMC seals/wellhead. Please let me know if I need to get one from FMC to forward to you. The WSS#18-9-23 is an older version heritage Mobil well with a Vetco (now GE) wellhead. This was a multibowl design which didn't lend itself to a similar upgrade as Cameron or FMC. Instead an isolation sleeve had to be designed and built specifically for this wellhead. A diagram of their isolation sleeve is attached. Please let me know if you have further questions or need anything further. Tom Juranek From: Schwartz, Guy L(DOA) [mailto:guy__schwartz alaska.gov] Sent: Wednesday, December 04, 2013 2:04 PM To: Juranek,Tom A Subject: PT-1 PT-2 and Staines River State #1 Tom, From what I read these wells(PT-1, PT-2 and Staines River St.#1) are also using the same type of extended packoff in order to upgrade to 10K? Is the same packoff being used? What about West STaines ST.#18-9-23? That appears to have a different isolation sleeve into the existing tubing head. If so please forward the diagrams for that for our files. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 1 e AI% POINT THOMSON5„�SURFACEPRODUCTION ,..N c N 6 RI EXXONMOBIL PRODUCTION COMPANY Isolation Sleeve Schematic • • o 11", 10k flange GE (Gray) Wellhead Seat for Test Plug . . .WSS.1.8-9-2 3 • • I • i.e./ ::: . • , •• • : • . i . . . • • • __...., • • - . : .� 1,x: . .13 5, 8 5k flange •. : : • Isolation Sleeve (c ) • s 1 9 5/8" Mandrel Hanger (existing) Lai • WEST STAINES STATE#18-9-23 Abandonment Procedure Page 14 of 22 West Staines State 18-9-23 Mates N!out*vat an op.n.ndad Gray Wellhead Point Thomson Well West Staines Stats S1b.0!-23 4-if —� 4-1/1r -OP moan"she 13 SAI"elk. 0 0 o,wr , 1 • 2r 'al lei „-,.,- -,., 1.1 o vIv ia-c•a� • W.Staines State 18-9 23 insp.Procedure STATE OF ALASKA • AOKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon+ ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Other El Inspection Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdowft❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ExxonMobil Oil Corporation Development ❑ Exploratory 12 169 - 120 3. Address: PO Box 196601 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 - 6601 50 089 - 20001 — t(5)000 7. Property Designation (Lease Number): 8. Well Name and Number: Y ADL 28380 West Staines State # 18 - 9 - 23 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A Wildcat 11. Present Well Condition Summary: Total Depth measured 13,329 feet Plugs measured 10 - 150 feet . true vertical 13,329 feet Junk measured N/A feet Effective Depth measured Surface feet Packer measured N/A feet true vertical Surface feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural 32' 30" 32' 32' N/A N/A Conductor 268' 20" 303' 303' 1,530 520 Surface 2,070' 13 -3/8" 2,105' 2,105' 3,090 1,540 Intermediate N/A N/A N/A N/A N/A N/A Production 10,052' 9 -5/8" 10,087' 10,087' 7,510 / 8,150 5,600 / 7,100 Liner 3,156' 7" 13,004' 13,004' 8,600 5,890 Perforation depth Measured depth N/A feet SCANNED ApR i_ 9 2013 True Vertical depth N/A feet Tubing (size, grade, measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth) N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): None Treatment descriptions including volumes used and final pressure: No treatment 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A 0/0 0 Subsequent to operation: N/A N/A N/A 0/0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Well Photographs Explorator't v Development❑ Service ❑ Stratigraphic ❑ Daily Report of Well Operations See Attachment 16. Well Status after work: Abandoned Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313 - 081 Contact Tom Juranek (713 - 656 -4225) Email tom.a.iuranekexxonmobil.com Printed Name William Hanenberg Title Alaska SSH&E Manager Signature 441 ,,,,"` - Phone 907 - 564 -3773 Date 3/27/2013 Form 10-40 +1: vised 10/201 " Submit Origins On 4/9 A PR 16 2013 , , Y /6./� „4001:: Y �6 4 ExxonMobil Production Coney • Joint Interest U.S. P. 0. Box 196601 Anchorage, Alaska 99519 -6601 907 561 5331 Telephone 907 564 3789 Facsimile EkonMobil Production April 9, 2013 Mr. Guy Schwartz Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Report of Well Operations ExxonMobil Oil Corporation West Staines State #18 -9 -23 PTD No. 169 -120 Sundry No. 313 -081 Dear Mr. Schwartz: ExxonMobil hereby submits a Report of Sundry Well Operations for inspection work conducted on the West Staines State #18 -9 -23 (WSS #1) well. The well is plugged and abandoned. The inspection work was to confirm there is no internal pressure and to collect data necessary to perform remedial actions on the well pursuant to earlier communications between ExxonMobil and the Alaska Oil and Gas Conservation Commission. Zioo •4 Attached please find: Y. /C - Form 10 -404: Report of Sundry Well Operations Inspection Summary Photographic documentation of the well before and after the work Please contact Tom Juranek at 713 - 656 -4225 or William Hanenberg at 907 - 564 -3773 if you have any questions. Sincerely, ws0, William J. Hanenberg WJH:blc Attachments A Division of Exxon Mobil Corporation • • West Staines State #18 -9 -23 Operations Summary March 16, 2013 Attempts to check for internal pressure on the West State #18 -9 -23 well in 2009 were unsuccessful due to incompatible wellhead connections. This inspection was intended _ to both check and verify a lack of internal pressure and gather data necessary for further remedial work. Attached is a summary work activities and photographs. March 11, 2013 Arrived on location, spotted equipment and cleaned up gravel from just around wellhead. March 12, 2013 Completed excavation around well head, removed 2" bull plug on 9 5/8" & installed graylock cross -over flange. March 13, 2013 Installed 3" valve on 9 -5/8 ", installed pressure gauge with bleed off valve, opened 9 -5/8" production casing - Found 0 psi and drained an estimated 4 gals of diesel. Rigged up Cudd Hot Tap equipment, carried out hot tap and found 0 psi on intermediate . casing w /no liquid return. March 14, 2013 Rigged down hot tap equipment, replaced top flange bolts with new ones, re- located 9 -5/8" casing valve. March 15, 2013 GE arrived on location. Re- located equipment, heater and connex to block wind to allow work on well head. Pulled top flange to open well head for inspection. GE carried out inspection, replaced top flange. Loaded tool connex and heater, transfer to PTU 4. March 16, 2013 Installed needle valve on 9 5/8" outlet, locked out valves, wrapped well head with • herculite, level gravel and snow pile on location pad. Project complete. • • 0 West Staines #18 -9 -23 As Found i . `' kr 'P4. ii. ) i t wi � dr ' :.: t ' i • , 0 ,1 a 2 • . !:: Ct •••. .' to *16 ' • . ' 1 i 7 - ,':„. - . . w, • 4 A flow. ' Production Casing 0 ps w ci si v . . ii . , r , .41, .10. , lit 4:' 'I I OW -' - fe • . ..,..., ... '4 t 11'4 i I ig ' s 1 4 ♦ 4 0 r j de ! r r . w ♦ ,a itii -. ' r I , . 0 4 i i._. ek ii,„ I s W 41 1 L .I II P I Hot Tap Machine t - '1F+M, t r Z i ilk 1 r " .._. _ ; ■ t 9 -5/8" x 13 -3/8" = => 0 psi found A / � yy }}}��� ``` ,,,������!!! �� ft 4► -, Y ' ' .mow R r T c_ . ti , y� .* ' , ... ,7 _ - a .fir ti . *#.+ may, ■ t . :, .. s e .. �1►; v • ++� boa ..... West Staines #18 -9 -23 As Left 4 1_ . ,, 1/4, , . . for - \ - , 1 A ., f y . ;*, -;.... ' f , ri. .$ t ' 1 - . - , 4 , - * . N � '— ar s Y `' "i ty. t F • . r , 14rx . ysir, * � j ¢ . e I • f „. • ' r., t '!„#.4' ( ♦ ' '. is �i .♦ ' • • w \ ,, �� „ -, THE STATE - Alaska it and Gas °f ALASIKI 1 Conservation Commission "t _ =_� =_ GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF Q. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 SCANNED MAR 1 1 20 3 Fax: 907.276.7542 William J. Hanenberg H L SSHE Manager ExxonMobil Oil Corporation l bCf4 L- P.O. Box 196601 Anchorage, AK 99519 -6601 Re: Exploratory Field, Exploratory Pool, West Staines State #18 -9 -23 Sundry Number: 313 -081 Dear Mr. Hanenberg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this "day of February, 2013. Encl. 0 • RECEIVED EIVED STATE OF ALASKA `) J 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION I ! o ,PZJ APPLICATION FOR SUNDRY APPROVALS h( 20 AAC 25.280 1. Type of Request: Abandoi❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspen4j Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdowi❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Well Remediation in • 2. Operator Name: 4. Current Well Class: 5. Permit to Dill Number: ExxonMobil Oil Corporation Exploratory El Development ❑ 169 - 120 ' 3. Address: Stratigraphic 111 Service 1=1 6. API Number PO Box 196601, Anchorage, AK 99519 - 6601 50 20001 - 0000 • 7. If perforating: 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? N/A West Staines State 818 - - Will planned perforations require a spacing exception? Yes ❑ No i 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 28380 • Exploratory 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13,329 ' 13,329 ` 0 0 Many plugs, see schematic None Casing Length Size MD TVD Burst Collapse Structural 32' 30" 32' 32' N/A NIA Conductor 268' 20" 303' 303' 1,530 psi 520 psi Surface 2,070' 13 -3/8" 2,105' 2,105' 3,090 psi 1,540 psi Intermediate #1 N/A N/A N/A N/A N/A NIA Production 10,052' 9 -5/8" 10,087' 10,087' 7,510 psi 5,600 psi Liner 3,156' 7" 13,004' 13,004' 8,600 psi 5,890 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N/A N/A NIA Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A 14/A e •(3 L' 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ( 1 Exploratory n Stratigraphic n Development [ 1 Service 0 14. Estimated Date for 15. Well Status after proposed work: ]Jabs 5u,--4-..... O''. Commencing Operations: March 7 , 2013 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned Commission Representative: GSTOR ❑ SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tom Juranek 713 - 656 - 4225 Email tom.a.juranekOexxonmobil.com Printed Name William J. Hone erg Title SSHE Manager — R 3 Signature W Phone Date 907 -564-3773 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 1 7-1 04 wect.,,,,,...if � :� RBDMS FEB 25 AI R Spacing Exception Required? Yes ❑ No ® Subsequent Form Required: / - y0 L i APPROVED BY ) Approved by: COMMISSIONER THE COMMISSION 2._-20-/.3 2._-20-/.3 Date: Z — 22-- [ 3 All 0 R1Gp 1 !1AL I � _-i/ / Submit Form and Form 10-403 (Revised 70/2 r i on is valid for 12 mo the from the date of approval. Attachments in Duplicate � � t, ii r Z- • ExxonMobil Production Cony • Joint Interest U.S. A. O. Anchorage, Anch Alaska 99519 -6601 RECEIVED orae, Alas 907 561 5331 Telephone 907 564 3789 Facsimile FEB 1 4 2013 E3KonMobil AOGCC Production February 4, 2013 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7 Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval Well Remediation: West Staines State #18 -9 -23 (PTD No. 169 -120) Dear Ms. Foerster, ExxonMobil hereby applies for Sundry Approval to perform an inspection of the subject well. This work is intended to confirm there is no internal pressure in the well and to prepare the well for remedial plug and abandonment work next winter which will involve downhole work utilizing • coil tubing. The work is described in more detail on the attached procedure. The general procedure will be: 1. Excavate the well cellar to expose all wellhead valves and ports. 2. Hot tap bull plugs on valve runs from annulus access points and verify no pressure exists at the surface. 3. Remove old valves and fittings and install new valves. 4. Remove the top wellhead flange and take measurements to allow manufacturing an internal isolation sleeve to be installed and utilized next year during CTU operations. 5. Re- install top flange, lock valves closed, and cover wellhead with liner material. Attached please find the following documents supporting this Application: • Sundry Application Form 10 -403 • Planned Work Procedure including Current Wellbore Diagram A Division of Exxon Mobil Corporation • Ms. Cathy Foerster Alaska Oil & Gas Conservation Commission February 4, 2013 Page Two If you have any questions or require additional information, please contact me at (907) 564- 3773 or Tom Juranek at 713 - 656 -4225. Sincerely, V VA0.4..& William J. Hanenberg SSH &E Manager WJH:nlr Attachments • • West Staines State 18 -9 -23 Alm All .0 * mans are amen ended Gray Wtlh•ad Potent Thomson Wall • West Shins Stab 018.09 -23 s4nrsk --- -i t «.�.«w. 136N"ac. _ — 0 • .l.1.I • _ T. . �I 1.1111111.11 Onq ar. i. r o i _ . 1, • „ 20 a v o' WWM art • "rtif . .... _ , ,� k1,t t "4'' :: u. $ aID :, a cR ,.�. "+r a C „.et x, gar „'�. - • • ExxonMObil West Staines State 18 -9 -23 API*: 50-089-20001 PTD #: 169 -120 Gray 20 ", 2 kpsi A- section & RKB = 63' MSL = 15.5' above bradenhead I Gray 13 -5/8 ", 5 kpsi B- section Diesel in 9 -5/8" from surface to 10' - - I 30" structural at 32' BGL cmt'd with 176 sx Diesel in 9 -5/8" x 13 -3/8" from surface to 1,472' 10 BP in 9-5/8" at 150' w/50 sx fondu to 10' '� °' — ' 20" © 303', cmt'd to surface w/ 840 sx Diesel 13 - 3/8' DV Tool at 1,385' I Diesel In 9-5/8" csg from 150' - 1.950' t 1 950 Pumped 400 sx fondu cmt plug in P ► BP in 9 -5/8" at 2,000' w/ 25 sx plug on top tot 1.950' 13 -3/8" x 9-5/6" from 1.472' - 2.105' Al= a 13 -3/8 ". 614. H-40 at 2.105' 13 -3/8" cmt'd stage 1 w/ 700 sx class G: stage 2 w/ 9.7 1200 sx fondu ftyash with 30% salt through DV Tool ppg Good returns at surface mud TOC in 9-5/8" csg at 9,838' • _i Top of 7" liner at 9,848' Retainer at 9,898' ►.�.- Sqi d w/ 100 sx class G 9 -5/8" set at 10.087' J 2.409' of 47 #, S -95 & 7.700' of 43#, 8-95 Cmt'd with 420 sx class G Pelf 'd 9,998' — 10,020' TOC at 10.422' Retainer at 10,472' Sgz'd w/ 110 sk? cmt & 11 30 sx cmt plug on top ' Perf'd 10,570' — 10.590' H . ' TOC at 11450' BP at 11,497' x +l► "+eil 30 sx cmt plug on top Perf'd 11.650' — 11,675' Perf'd 11,675' — 11,715' BP at 11.743' -- —. _ Perf'd 11.763' — 11,782' 30 sx cmt plug from 12.350' — 12409' Retainer at 12.409' Bo- - - Perf'd 12,512' — 12,525' Perf'd 12,525' — 12.537' Sqi d perfs 12.512' — 12.795' w/ 120 sx : Perf'd 12,630' — 12,650' Perf'd 12,680' — 12.700' is Perf'd 12.780' — 12.795' ii EZ drill BP at 12,869' w/ - 2 sx cmt plug on top 50 sx cmt plug in 7 "from 12.900' — 13,078' 7" liner at 13,004' 2032.8'. 29#, S -95. 1100.6'. 264. S -95 3156' total liner length with hanger, shoe and collar 6" & 5- 15/16" hole to 13,329' Cmt'd w/ 400 sx class G, sgYd 4 times w/ 542 sx G total '. well scnemaec dawn June 29'", 2007 by Faaweamer E 8 P Services. Inc. updated March 31, 2009, July 26, 2009. and Septemter 8, 2009 by EM W. Staines State 18 -9 -23 Insp. Procedure . . • • It 1.1■4 1 ""' + ` " s .� yew. , ,� ; ' w.. R ° • fir' . . , � �. . . "iY I , a F A� � �'w 11 7 �� , , A.-;-. � ,. y; i f_ e. . t 1 " i h 0. T iF West Staines State #18 -9 -23 As left after April 2010 inspection Page 5 of 5 W. Staines State 18 -9 -23 Insp. Procedure • • WEST STAINES STATE #18 -9 -23 WELL HISTORY AND INSPECTION PROCEDURE Affected Wells and API /AFE Numbers: West Staines State #18 -9 -23 API # 50- 089 -20001 APTD #: 169 -120 Background: The West Staines # 18 -9 -23 well was drilled in 1970. The well is abandoned, but requires removal of diesel and the wellhead to at least three feet below ground level consistent with current AOGCC regulations. Prior to removing the diesel and wellheads, an inspection to verify the well's condition is desired. The 9 -5/8" casing has a diesel cap at 0 -10', a cement plug set at 10' -150' on top of a bridge plug. Below the bridge plug there is diesel from 150' to 1,950' on top of another cement plug from 1,950'to 2,000' and another bridge plug. The 9 -5/8" x 13 -3/8 "annulus contains diesel from surface to approximately 1,472'. The well schematic is attached to this procedure. On a well inspection trip during 2009, it was discovered that the Vetco -Gray wellhead had GrayLoc connections. The inspection team had not anticipated this unusual configuration and did not have the necessary cross -overs to allow the inspection to be completed. The reservoir section of the well is effectively isolated; therefore it is unlikely that high pressure will be encountered during the inspection. However, contingency plans and procedures will be included in the detailed inspection procedure to safely manage any well pressure encountered. OBJECTIVE: • Pre • are the well for coil tubin• drill -out and •ermanent abandonment next winter 2013 -14 . The present procedure will accomplish this by: 1) Verifying absence of pressure within production and intermediate strings via hot - tapping. 2) Obtain internal measurements within the wellhead to allow the fabrication of an internal pressure isolation sleeve to be installed during next year's work. The inspection will include the following steps: • General inspection of the well location - • Excavation of gravel covering the wellhead • Visual inspection as to the condition of the wellhead • Verification of the well integrity by checking for and recording pressures in the - 9-5/8"casing and the 9 -5/8 x 13 -3/8" annulus • Perform diagnostic test if pressure is found (i.e., trapped vs sustained pressure) • Obtain internal dimensions of wellhead for pressure isolation sleeve • Identify contents of the casing and annulus by attempting to get a sample • Cleanup of location and leave well in a safe and secure condition The proposed inspection will be supported by on -site equipment and materials such as excavator, camp, fuel and other essential elements of remote operations. The following well inspection program is planned: 1. Insure all necessary permits and applications are in place. Notify AOGCC at least 10 days before operations begin. 2. Mobilize all personnel and equipment to the West Staines # 18 -9 -23 location. W. Marne* Sitativi 3101#11 d •. ;.x • • 3. Observe and record any signs of leaks in the area surrounding the well. Take photographs clearly showing the condition of the surrounding location. A detailed report documenting any contamination found will be prepared. 4. Heat the gravel around the wellhead. 5. Remove gravel covering /surrounding the wellhead. Cellar previously removed. Confirm access to all side outlets on wellhead sections. Monitor excavation with a four -gas monitor. 6. Install wellhead shelter, and rig up indirect fired hot air heater. Apply heat to wellhead shelter. Pump or vacuum to remove free liquids, if any. 7. Visually inspect the condition of wellhead side outlets valves, bull plugs, needle valves, test/grease ports, lock down screws, etc. Take photographs clearly showing the condition . of the wellhead as found. Document any areas of concern. 8. Check for pressure on the 9 -5/8" casing and the 9 -5/8" x 13 -3/8" annulus. This will require hot tapping of the 2 "bull plugs located on wellhead side outlets and possible removal of VR plugs if present, and the installation of needle valves and new wellhead side out valves to facilitate recording, capturing, and bleeding off any pressure found. 9. If pressure is observed, then perform diagnostic testing to determine if the pressure is sustained casing pressure or trapped pressure. Record pressure bleed down and , buildup. In addition, record the fluid type and volume. Take fluid samples for possible analysis. If any pressure is found and pressure appears to be sustained, e.g., will not bleed to zero with available bleed tankage, do not take further diagnostic actions, shut valves and secure well. 10. Once no pressure is verified, remove top flange of wellhead and perform internal inspection and measurements to be able to design and build an isolation sleeve rated to 10,000 psi to be used next winter during the coiled tubing operations to drill out the shallow plug and remove the diesel below the plug. When finished, replace top flange with new bolts. 11. Ensure well is safe and secure. Chain & lock closed any valves above ground level. 12. Do not mound gravel over wellhead.,Wrap wellhead with herculite tied tightly to prevent the wind from loosening it. 13. Clean up location before departure leaving previously excavated gravel in a level condition . no depressions). ( P ) 14. Transport all wastes to approved disposal sites. 15. Take photographs clearl ry showing the condition of the wellhead as left. 16. Fill out inspection report and file a Report of Sundry Well Operations (Form 10 -404). 1llf tita in tate 4t 2aineprprotecitl ' !'' ::;Y` / 9. /�/ ExxonMobil Development Cony Brie eep P.O.Box 241449 Enviror�R�ntal and Regulatory Manager Anchorage,Alaska 99524-1449 Point Thomson Project 907 564 3617 Telephone 907 743 9809 Facsimile October 19, 2010 E r(onMobil Development LT-EDAN-AOGC CAN-ER-0163 RECEIVED Mr. Tom Maunder OCT 2 2 2010 Alaska Oil& Gas Conservation Commission 333 West 7th Avenue, Suite 100 8t933COOS.CQ pp Anchorage,Alaska 99501 Anchorage Re: Plug and Abandonment of PTU Wells Dear Mr. Maunder: We appreciate the opportunity for ExxonMobil to discuss with you ExxonMobil's inspection and remediation activity outlined in our September 15, 2010 letter. Based on these discussions,we now plan to conduct the West Staines State#18-9-23 inspection in association with the well remediation activity during the 2012/13 winter season. We believe this inspection timing will enhance operational safety and provide efficiency benefits. As we communicated previously, our 2009 wellhead inspection showed no evidence of leaks or impacted gravel. The well is secure, covered with gravel, and the well identification marker is in place. Should you have any questions or would like to discuss these plans further, please contact me at 907-564-3617 or via email (brien.e.reep@exxonmobil.com)or Gilbert Wong at 907-564-3607 or via email (gilbert.wong@exxonmobil.com). Sincerely, For and On Behalf of Exxon Mobil Corporation HEp FEB Q 12017 BER:sw:hmk An ExxonMobil Subsidiary • • -----Original Message ----- From: gilbert.wong@exxonmobil.com[mailto:gilbert.wong@exxonmobil.com] Sent: Friday, October 15, 2010 11:01 AM To: Maunder, Thomas E (DOA) Subject: RE: West Staines State 18-9-23 Inspection Tom, Thanks for your response. Well 18-9-23 is set-up to remain secure until the planned work in 2012-13. We will follow-up with a letter to you with our updated plans. Regards, Gilbert Wong US Joint Interest - Alaska ExxonMobil Production Company Office: 907-564-3607 Cell: 907-301-3318 Fax: 907-564-3705 e-mail: gilbert.wong@exxonmobil.com "Maunder, Thomas E (DOA)" <tom.maunder@a laska.gov> 10/15/2010 10:35 AM ocl I � 'Zulu gilbert.wong@exxonmobil.com To cc Subject RE: West Staines State 18-9-23 Inspection Sorry Gilbert, I guess I misunderstood. So there is a change planned to installing the new valves and conducting the inspection? Thus far, you have confirmed that the 18-9-23 "structure" is intact and that there has been no release from the well to the immediate area. So long as 18-9-23 is "set up" to remain secure until planned work in 2012-2013, then the delay would be acceptable. By "set up", I presume that the wellhead has again been covered with gravel so as not to be exposed to the elements. Tom Maunder, PE AOGCC • 0 -----Original Message ----- From: gilbert.wong@exxonmobil.com[mailto:gilbert.wong@exxonmobil.com] Sent: Friday, October 15, 2010 8:33 AM To: Maunder, Thomas E (DOA) Subject: RE: West Staines State 18-9-23 Inspection Tom, Thanks, Jack had not had a chance to forward this message to me. Sorry, but I meant for my prior e-mail question to be regarding WSS 18-9-23, and not WSS 2 or 19-9-23. Just to clarify, is it acceptable for us to include the originally planned 2011 inspection work (internal pressure readings) with the 2012- 2013 remediation work? If yes, we will follow-up with a letter indicating our updated plans. Thanks. Regards, Gilbert Wong US Joint Interest - Alaska ExxonMobil Production Company Office: 907-564-3607 Cell: 907-301-3318 Fax: 907-564-3705 e-mail: gilbert.wong@exxonmobil.com To cc Subject Inspection "Maunder, Thomas E (DOA)" <tom.maunder@a gilbert.wong@exxonmobil.com laska.gov> 10/15/2010 RE: West Staines State #2 07:32 AM Morning Gilbert, Did you get the message I sent to Jack? I've copied it below. Does this answer your question? Tom • From: Maunder, Thomas E (DOA) Sent: Thursday, October 14, 2010 10:47 AM To: 'jack.a.rickner@exxonmobil.com' Subject: Future Legacy Well Remediation Plans • Jack, Following up on our call the other day, Gilbert called and we discussed the forward plans as given in Mr. Reep's letter of September 15. It is unfortunate that the work effort of the past winter season was not successful. It would seem that with the additional planning and optimization time ahead that the next well entry effort should enjoy more success. Please keep the Commission/me informed on progress toward the planned well work in 2012-2013. Please forward to Gilbert as I don't have his email. Call or message with any questions. Tom Maunder, PE AOGCC -----Original Message ----- From: gilbert.wong@exxonmobil.com[mailto:gilbert.wong@exxonmobil.com] Sent: Friday, October 15, 2010 6:55 AM To: Maunder, Thomas E (DOA) Subject: West Staines State #2 Inspection Tom, I was following up to see if you and Commissioner Foerster had a chance to visit and discuss ExxonMobil's preference to conduct the WSS 19-9-23 inspection (i.e., internal pressure readings) in conjunction with the planned well remediation effort in 2013? Clarification on this item will help us to progress the necessary steps for our 2011 activities both internally and with other Working Interest Owners. Thanks. Regards, Gilbert Wong US Joint Interest - Alaska ExxonMobil Production Company Office: 907-564-3607 Cell: 907-301-3318 Fax: 907-564-3705 e-mail: gilbert.wong@exxonmobil.com P.O. Box 241449 Anchorage, Alaska 99524-1449 907 564 3617 Telephone 907 743 9809 Facsimile October 19, 2010 LT-EDAN-AOGCCAN-ER-0163 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Plug and Abandonment of PTU Wells Dear Mr. Maunder: /�9.IRO 13,rfieut. 2. rReep" Environmental and Regulatory Manager Point Thomson Project Development 00 � 2 2010 We appreciate the opportunity for ExxonMobil to discuss with you ExxonMobil's inspection and remediation activity outlined in our September 15, 2010 letter. Based on these discussions, we now plan to conduct the West Staines State #18-9-23 inspection in association with the well remediation activity during the 2012/13 winter season. We believe this inspection timing will enhance operational safety and provide efficiency benefits. As we communicated previously, our 2009 wellhead inspection showed no evidence of leaks or impacted gravel. The well is secure, covered with gravel, and the well identification marker is in place. Should you have any questions or would like to discuss these plans further, please contact me at 907-564-3617 or via email (brien.e.reep@exxonmobil.com) or Gilbert Wong at 907-564-3607 or via email (gilbert.wong@exxomnobil.com). Sincerely, For and On Behalf of Exxon Mobil Corporation BER:sw:hmk SCAN An ExxonMobil Subsidiary ExxonMobil Development Company• P.O. Box 241449 Anchorage, Alaska 99524-1449 907 564 3617 Telephone 907 743 9809 Facsimile SEP 2 0 2010 Brien E. Re Environmental Regulatory Manager Point Thomson Project ooll Development September 15, 2010 - ER -2010 -OUT -0148 Mr. Tosunder a Oil 8, Gas Conservation Commission U ) DUCT 14 1010 333 West 7th Avenue, Suite100 Anchorage, Alaska 99501 Re: Plug and Abandonment of PTU Wells Dear Mr. Maunder: '1 10 1 - �a As you are aware, efforts to re-enter the West Staines State (WSS) #2 and WSS #18-9-23 wells this past winter season encountered equipment difficulties. After considering the learning gained from this effort, ExxonMobil has developed a plan for moving forward. First we plan to complete the inspection of WSS #18-9-23 well by measuring the well's internal pressures, if any, by May 2011. Thereafter, we plan to remove diesel and/or Arctic Pack from PTU -4, WSS #2, and WSS #18-9-23 wells during the 2012/13 winter season pending the availability of an ice road to move the necessary workover equipment. Regarding the WSS #18-9-23 inspection, we have obtained the Vetco Gray crossovers for this work and hope to commence site operations by March 2011. Installation of new side outlet valve(s), obtaining the pressure measurement and backfilling the excavation around this wellhead will complete the well inspection portion of the remediation program. The next stepVofUthe remediation work involves removal of Arctic Pack from the upper portion of two annuli of -4, installation of cement plugs in these annuli, welding an identification marker plate on the well, and backfilling and mounding the excavation to complete the plugging operations. Additional operations will involve the removal of diesel from WSS #18-9-23 well and diesel and Arctic Pack from WSS #2 well. We will be evaluating the use of coil tubing units, snubbing units, and workover rigs for the well re-entries. Our outlook is to conduct the work on these three wells during the 2012/13 winter season, pending the availability of an ice road. We will update the execution plans and schedule upon completion of our evaluation. Our Alaska Production Manager, Mr. Dale Pittman, met with Commissioner Cathy Foerster on August 25, 2010 and the presentation materials he provided included additional detail on ExxonMobil's inspection / remediation efforts and plans. An ExxonMobil Subsidiary Mr. Tom Maunder • -2- Sep(Rber 14, 2010 If you would like to discuss ExxonMobil's plan further, please contact me at 907-564-3617 or via email (brien.e.reep@exxonmobil.com) or Jack Rickner at 281-217-4350 or via email Qack.a.rickner@exxonmobil.com). We are available to talk about the various aspects and progress towards completing this work program. Sincerely, For and On Behalf of Exxon Mobil Corporation BER:sw:mk Point Thomson Well Inspection and Remediation Work Plans AOGCC - Cathy Foerster Review August 2010 Meeting Objective Provide update of ExxonMobil's inspection and remediation efforts and latest plans 0 1 Snubbing Unit at West Staines State #2 (March 2010) E*(onMobil Production Status Update February 2009 Plans • Perform well integrity inspection program on 9 ExxonMobil wells during Winter 2008/2009 (Phase 1) + Evaluate condition of gravel, flanges, valves, bull plugs, etc. and inspect wells for seepage or leakage + Check casing and annulus for pressure • + Install side outlet gate valves + File Form 10-404 with AOGCC documenting inspections and conditions found • Remediate Alaska State J-1 during Winter 2008/2009 • Remediate PTU 4, WSS 18-9-23 and 2 during Winter 2009/2010 (Phase 2) Activities completed • All well integrity inspection activities completed with the exception of checking the casing and annulus pressure on WSS 18-9-23 (at time of inspection, unable to add a new gate valve since existing valve did not have flanged ends) • • Alaska State J-1 remediated as planned • In Winter of 2009/ 2010, completed gravel pad remediation at Bullen Point • Attempted to complete the Phase 2 remediation scope of work in Winter 2009/2010 (i.e. PTU 4, WSS 18-9-23 and 2) but was unsuccessful 2 E*onMobil Production Status Update (continued) Winter 2009/2010 Remediation Activities • Built ice ramp to PTU -4 and ice road spurs off of main ice road to the Point Thomson Unit Central Pad • Surveyed WSS 18-9-23 for gravel contamination • Executed a lump sum contract with contractor to complete all remediation activities for PTU 4, WSS 18-9-23 and 2 • • Mobilized camp, snubbing unit, crane and additional equipment and began remediation efforts on WSS 2 • Installed anchors, anchor lines to BOP stack, rigged up hydraulics and tested BOP stack • Effort shutdown due to safety concerns and indications that contractor would be unable to complete work as planned and scheduled • Key Lessons Learned - snubbing unit not previously used in Arctic service created challenges + Inadequate winterization + Inadequate advanced planning complicated mobilization and rig -up + Extensive required use of crane complicated by North Slope wind conditions + Non -North Slope equipment resulted in delays Current Plans • Winter 2010/2011 - Install gate valves on WSS 18-9-23 to enable annulus and casing pressure testing • Conduct risk assessment and pursue other work -over rig options to ensure a safe and more efficient execution of the remediation scope of work (note: access to pads limited to winter periods) • If snubbing unit still required, may need "winterization" retrofit to ensure work can be performed safely in the winter months • Will update execution plans and schedule as additional data is gathered, but tentatively targeting Winter 2012/2013 to reschedule remediation activities (scope of work will also includes pad remediation at WSS 18-9-23 and 2) 3 E�onMo bil Production Scope of Well Remediation (WSS 18-9-23 and 2, PTU 4) Remediation Procedure • Remediate WSS 18-9-23 as follows: — Drill out bridge plug at 150' — Verify presence of bridge plug and cement at 2000' • — Replace diesel in 9 5/8" down to 200' with CaCl2 — Perforate casing @ 1000', circulate out annulus fluids and cement — Spot cement to surface — Remove wellhead to 3' below ground level — Weld marker cap — Fill excavation with gravel — File Well Completion or Recompletion Report and Log Form with AOGCC documenting P&A • Remediate WSS 2 in similar manner • Remediate PTU 4 — Remove Arctic pack (rather than diesel) in annuli — PTU #4 contains CaCl2 below surface plug Risk Assessment • Removal of diesel below shallow bridge plugs on WSS 18-9-23 & 2 — Potential pressure below bridge plug at 2000' is a risk — Use of a coiled tubing unit has not proven to be a viable option — Going through a risk assessment but snubbing unit may be only option 4 E.,XonMobiI Production C)1 11 'heteadA sectcn =n place mr tI-CTwwantcp 3C' smabra W. 32' MmIrted utt ' 7 " 74ei r 1= i$' 9 S'{' anrut.5 "rccr 1,47.* x s xtuL, 1349' : ry 73d at 1 HE ,:cmerl'n 13-36' x B -S. 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Caret 37 no W p4med or laa C1s3RRetainer Pe lcraltons10C' - ' 1 E75.4 SY Per'9ratlefis 11,EA' - '1 7'4, 4sY Pef+cralkers ' 1,'• 63' - " 1 U2. ASY Per tratkmi 12,91I' - . 3 S34, 45Y Perdaaltem 1242T- '2 ST7, 45Y Pertrotions !ZE3C' - '2 E57, 45Y Pe+ nations -ZED:' i 7C7, 4SY PertMicns 1:,7112=•'-'2755,4,zY sr Cefr+:rt ar ba Cr EZ :111 U -re lFkpr7-t]r*1:49X'-13.V-e T': Z C3: e, 29#t 5m95 1 ' 77 E' 2230, SCC45 3 -!5F 1C+at or hsr0er, s'roe srd .7lar errs ted salt LX sr G 54uemed 4 ttr-es s< C, 554: SVG lyal 0 0 zo • Page 1 of 1 Maunder, Thomas E (DOA) From: Crisp, John H (DOA) Sent: Thursday, April 08, 2010 8:20 AM 5 To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA) 6 S- \ � Subject: CUDD West Staines o 55-0 Just a note about the P &A on West Staines. We were attempting to test the Annular preventer, the CH2MHilI Rep. had a conference call with Exxon. They pulled the plug on the job & decided to De- Mobe equipment before Ice Road problems. This decision saved a lot of controversy. I'll make a detailed report with photos. Looked like Mardi Gras North Slope style because the CUDD hands were so happy. FEB J . 4/9/2010 411 Original Message From: Maunder, Thomas E (DOA) Sent: Thursday, April 08, 2010 9:28 AM To: Ijack.a.rickner @exxonmobil.com' Cc: brien.e.reep @exxonmobil.com; michael .d.murrey @exxonmobil.com; rob.g.dragnich @exxonmobil.com; silas.wong @exxonmobil.com Subject: RE: Rig Down of WSS #2 Efforts Jack, et al, The decision to accomplish any activity during the remainder of the season on these wells is Exxon's to make. I only asked the question for information purposes since I was aware that the sundry was issued for PTU #4. Best regards, Tom Maunder, PE AOGCC Original Message From: jack.a.rickner @exxonmobil.com [mailto:jack.a.rickner @exxonmobil.com] Sent: Thursday, April 08, 2010 9:23 AM To: Maunder, Thomas E (DOA) Cc: brien.e.reep @exxonmobil.com; michael.d.murrey @exxonmobil.com; rob.g.dragnich @exxonmobil.com; silas.wong @exxonmobil.com Subject: RE: Rig Down of WSS #2 Efforts Tom, thanks for your quick response. During our conference call yesterday with the field personnel to discuss this decision, I asked if it would be possible to complete the work on PTU -4. At this point, all our efforts are focused on conducting a safe and orderly demob operations. I have asked our field personnel and contractor to keep completion of PTU -4 well work as an option. I will revisit this question with our field personnel and CH2MHi11 early next week. We will be evaluating how well our demob is progressing, the current weather conditions and projected forecast, and available personnel. I would like to delay a decision on PTU -4 for perhaps a week and provide an answer at that time. Regards, Jack Jack A. Rickner Environmental & Regulatory Group Point Thomson Project 907 - 564 -3638 281 - 217 -4350 "Maunder, Thomas E (DOA)" To <tom.maunder @a jack.a.rickner @exxonmobil.com laska.gov> cc michael .d.murrey @exxonmobil.com, silas.wong @exxonmobil.com, 04/08/2010 brien.e.reep @exxonmobil.com, 08:59 AM rob.g.dragnich @exxonmobil.com a • Subject RE: Rig Down of WSS #2 Efforts Jack, et al, Sounds like the good, tough call. I am not sure of any other requirements right now. On the other effort up there, was any work able to be accomplished on PTU #4? Regards, Tom Maunder, PE AOGCC Original Message From: jack.a.rickner @exxonmobil.com [ mailto :jack.a.rickner @exxonmobil.com] Sent: Thursday, April 08, 2010 8:56 AM To: Maunder, Thomas E (DOA) Cc: michael.d.murrey @exxonmobil.com; silas.wong @exxonmobil.com; brien.e.reep @exxonmobil.com; rob.g.dragnich @exxonmobil.com Subject: Rig Down of WSS #2 Efforts Tom, perhaps by now you have heard from your field inspectors that we have made a decision to stop further work efforts to complete the defined remediation work on West Staines State #2 well. There are a number of reasons for this decision but probably the foremost reason is the late date in this winter's season. As of yesterday, we had not competed the initial BOP testing, would have had another day or two to complete the RU after completion of a good test, then perhaps 6+ days to complete the necessary well work, and another 14 days to RD and demob approximately 100 loads of snubbing unit and camp equipment /materials. As you might expect, that would almost certainly carry us into the very end of this month or May without weather delays or any mechanical problem with the defined well work. Given the current and forecasted warming conditions which almost certainly will lead to degrading ice road conditions, we decided to not tempt fate any longer and retreat while we can. Since we have not drilled the surface plug and were able to verify that the surface plug is intact and solid, we feel that we can safely RD and button -up the well leaving it in a safe condition. We will meet with CH2MHill and Cudd after the demob has been completed to evaluate this season in preparation for future efforts. We would like to visit with you after that evaluation to share our learnings. Again, I regret having to send you this note. I'll call later today to discuss this decision with you and determine if additional action may be required on our part. Regards, Jack Jack A. Rickner Environmental & Regulatory Group Point Thomson Project 907 - 564 -3638 281 -217 -4350 • • Original Message From: Maunder, Thomas E (DOA) Sent: Thursday, April 08, 2010 9:28 AM To: 'jack. a. rickner @exxonmobil.com' Cc: brien.e.reep @exxonmobil.com; michael .d.murrey @exxonmobil.com; rob.g.dragnich @exxonmobil.com; silas.wong @exxonmobil.com Subject: RE: Rig Down of WSS #2 Efforts Jack, et al, The decision to accomplish any activity during the remainder of the season on these wells is Exxon's to make. I only asked the question for information purposes since I was aware that the sundry was issued for PTU #4. Best regards, Tom Maunder, PE AOGCC Original Message From: jack.a.rickner @exxonmobil.com [ mailto :jack.a.rickner @exxonmobil.com] Sent: Thursday, April 08, 2010 9:23 AM To: Maunder, Thomas E (DOA) Cc: brien.e.reep @exxonmobil.com; michael .d.murrey @exxonmobil.com; rob.g.dragnich @exxonmobil.com; silas.wong @exxonmobil.com Subject: RE: Rig Down of WSS #2 Efforts Tom, thanks for your quick response. During our conference call yesterday with the field personnel to discuss this decision, I asked if it would be possible to complete the work on PTU -4. At this point, all our efforts are focused on conducting a safe and orderly demob operations. I have asked our field personnel and contractor to keep completion of PTU -4 well work as an option. I will revisit this question with our field personnel and CH2MHi11 early next week. We will be evaluating how well our demob is progressing, the current weather conditions and projected forecast, and available personnel. I would like to delay a decision on PTU -4 for perhaps a week and provide an answer at that time. Regards, Jack Jack A. Rickner Environmental & Regulatory Group Point Thomson Project 907 - 564 -3638 281 -217 -4350 "Maunder, Thomas E (DOA)" To <tom.maunder @a jack.a.rickner @exxonmobil.com laska.gov> cc michael .d.murrey @exxonmobil.com, silas.wong @exxonmobil.com, 04/08/2010 brien.e.reep @exxonmobil.com, 08:59 AM rob.g.dragnich @exxonmobil.com • • Maunder, Thomas E ~DOAj From: jack.a.rickner@exxonmobil.com Sent: Tuesday, April 06, 2010 7:23 AM To: Maunder, Thomas E (DOA) Cc: rob.g.dragnich@exxonmobil.com; michael.d.murrey@exxonmobil.com; brien.e.reep@exxonmobil.com; silas.wong@exxonmobil.com Subject: Withdrawal of Sundry Application for WSS #18-9-23 ' ~. Tom, as we discussed last week, it is with regret that I request for the withdrawal of our Sundry Application for West Staines State #18-9-23 dated February 22, 2010. The snubbing unit was originally moved to West Staines State #2 and as of this date has not drilled out. Therefore as this winter's season quickly draws to an end, we will not be able to complete WSS # 2 with sufficient time remaining to move onto WSS #18-9-23 this season. We will resubmit our Sundry Application for WSS #18-9-23 and any necessary modifications to our work plan at a later date after we have had an opportunity to re-evaluate the challenges that this season have presented. Currently, we are evaluating our ability to complete the work on Point Thomson Unit-4. Regarding this issue, after visiting with our contractor, I would like to visit with you later this week to provide an update on our progress on both WSS #2 and PTU-4. If you have any questions regarding this current operation or this request, please contact me at the phone numbers below. I appreciate your consideration of this request. I do regret your inability to complete all the well work that we had planned for this season and any additional work that this request may have added to your work load. Regards, Jack Jack A. Rickner Environmental & Regulatory Group Point Thomson Project 907-564-3638 281-217-4350 ~~~~ ~P ~.~ ~~1G 1 • u Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, April 02, 2010 2:40 PM To: 'jack.a.rickner@e~oconmobil.com' Cc: michael.d.murreyQe~oconmobil.com; silas.wong@exxonmobi[.com Subject: RE: West Staines Well Work Jack, Thanks for the note and call. So, since it appears that work on 18-9-23 is off the table for this season and the work plan will also be modified, do you want to withdraw the sundry and then resubmit for next season? Thanks in advance. Tom Maunder, PE AOGCC _____Original Message----- From: jack.a.rickner@exxonmobil.com [mailto:jack.a.rickner@exxonmobil.com] Sent: Friday, April 02, 2010 2:08 PM To: Maunder, Thomas E (DOA) Cc: DOA AOGCC Prudhoe Bay; michael.d.murrey@exxonmobil.com; silas.wong@exxonmobil.com Subject: RE: West Staines Well Work Tom, you were not the hold up on WSS 18-9-23. I am. I was waiting to see if we needed to make any last minute modifications to the BOP stack design, final layout drawings, and any changes to our winterization efforts based on the work we were doing on WSS #2. The good news is that we have just about finalized everything and learned a lot, but now it is probably too late to attack 18-9-23. So it looks like WSS 18-9-23 will need to be deferred. As I indicated, I still am holding out hopes for completing the work on PTU-4 as we beat the melting ice roads. As to WSS #2, looks like we are still rigging up the snubbing unit and associated equipment, but getting close, close but not completely rigged up as yet. We do hope to have a successful test this weekend. And you are correct, the weather has not been kind to the guys on site. As you know, the snow and cold always presents challenges, but the wind has proven to be a limitation to our use of the large crane for spotting equipment. This has slowed the work progress more than anticipated. I think the debriefing session with CH2MHill will provide a number of very interesting learnings for all of us. Given this season, I'm not banking on the ice roads holding out until 1 May. So we may be able to visit about the ups and downs of the effort before the end of the month or shortly thereafter. Will let you know when I have more information. Regards, Jack Jack A. Bickner Environmental & Regulatory Group Point Thomson Project 907-564-3638 281-217-4350 -----Original Message----- From: Maunder, Thomas E (DOA) Sent: Friday, April 02, 2010 1:47 PM To: 'jack.a.rickner@exxonmobil.com'; 'michael.d.murrey@exxonmobil.com' Subject: RE: West Staines Well Work Jack and Mike, 1 In looking at the 18-9-23 paperwork, I see why I still had it. The~etter containing the revised line drawing for the snubbing unit was specific to West Staines #2. Was there a separate similar letter sent for 18-9-23? I've not seen any "other" letter. Thanks in advance, Tom Maunder, PE AOGCC "Maunder, Thomas E (DOA)" To <tom.maunder@a jack.a.rickner@exxonmobil.com laska.gov> cc michael.d.murrey@exxonmobil.com, silas.wong@exxonmobil.com, DOA AOGCC 04/02/2010 Prudhoe Bay 01:32 PM <doa.aogcc.prudhoe.bay@alaska.gov> Subject RE: West Staines Well Work Jack, I was just scanning some of the documents to forward to Lou and I'm looking at the 18-9-23 documents right now. I apologize; I thought I'd gotten that package off to you. I understood there could be a BOP test this weekend. Are "things" rigged up? From what I have seen on tv, the weather does not appear to have cooperated. After the "dust" settles, I'd welcome an opportunity to talk/review. Tom Maunder, PE AOGCC -----Original Message----- From: jack.a.rickner@exxonmobil.com [mailto:jack.a.rickner@exxonmobil.com~ Sent: Friday, April 02, 2010 1:28 PM To: Maunder, Thomas E (DOA) Cc: michael.d.murrey@exxonmobil.com; silas.wong@exxonmobil.com Subject: West Staines Well Work Tom, sorry for taking so long to get back with you. By now you have probably figured out that we have lost all hopes of being able to move the snubbing unit onto West Staines State 18-9-23 and completing the scheduled well work during this winter season. We still are holding out hope to be able to complete both WSS #2 and PTU-4. Only time will tell. I've asked CH2MHill to put together a plan on how to complete PTU-4 work while a different crew is rigging down the snubbing unit after completion of W5S #2. Hope to see something of a plan from them by mid next week. We hope to test WSS #2 BOPS over the weekend. Apparently, Lou is at PTU-3 for some inspections today and may stop by WSS #2 this evening for a visit. Hope the BOP test goes well and we can complete RU and start to drill out early next week. If you have any questions, please give me a call. Wish I had more positive news for you, but this is about where we are as of this a.m. Regards, Jack 2 • Maunder, Thomas E (DOA) From: michael.d.murrey@exxonmobil.com Sent: Friday, March 12, 2010 6:17 AM To: Maunder, Thomas E (DOA) Cc: jack.a.rickner@exxonmobil.com;randall.I.richardson@exxonmobil.com; rob.g.dragnich@exxonmobil.com Subject: Upgrades to the Sundry Notices for WSS #2 &WSS #18-9-23 (Test Plug) Tom, Yes. We plan to remove the top 13-5/8" 5k flange and NU the 13-5/8" 5k by 11" 5k temporary tubing spool. Please let me know if you have any additional questions. Thanks, Mike Michael D. Murrey ExxonMobil Production Company Production Engineering - Subsurface Phone: (713) 656-9624; Fax: (713) 656-7353 E-mail: michael.d.murrey@exxonmobil.com "Maunder, Thomas E (DOA)" To <tom.maunder~a michael.d.murrey~exxonmobil.com laska.gov> cc jack.a.rickner@exxonmobil.com, randall.l.richardson@exxonmobil.com, 03/11/2010 rob.g.dragnichCexxonmobil.com 05:12 PM Subject RE: Upgrades to the Sundry Notices for WSS #2 (Test Plug) Mike, I presume this will be the practice for the WSS #18-9-23 as well? Tom Maunder, PE AOGCC -----Original Message----- From: michael.d.murreyCexxonmobil.com [mailto:michael.d.murrey@exxonmobil.com] Sent: Thursday, March 11, 2010 12:46 PM To: Maunder, Thomas E (DOA) Cc: jack.a.ricknerCexxonmobil.com; randall.l.richardson@exxonmobil.com; rob.g.dragnich@exxonmobil.com Subject: Upgrades to the Sundry Notices for WSS #2 (Test Plug) Tom, 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, March 11, 2010 2:13 PM To: 'michael.d.murrey@exxonmobil.com' Cc: jack.a.rickner@exxonmobil.com;randall.I.richardson@exxonmobil.com; rob.g.dragnich@exxonmobil.com Subject: RE: Upgrades to the Sundry Notices for WSS #2 (Test Plug) Mike, I presume this will be the practice for the WSS #18-9-23 as well? Tom Maunder, PE AOGCC -----Original Message----- From: michael.d.murreyC~exxonmobil.com [mailto:michael.d.murreyCexxonmobil.com] Sent: Thursday, March 11, 2010 12:46 PM To: Maunder, Thomas E (DOA) Cc: jack.a.ricknerCexxonmobil.com; randall.l.richardson@exxonmobil.com; rob.g.dragnichCexxonmobil.com Subject: Upgrades to the Sundry Notices for WSS #2 (Test Plug) Tom, As requested, I have summarized below our plan to use a Test Plug to pressure test the Snubbing Unit BOP stack on the west Staines State #2. Plan The upper tubing spool, 13-5/8" 5k by 13-5/8" 5k, will be removed and a 13-5/8" 5k by 11" 5k tubing spool will be installed in its place prior to rigging up the Snubbing Unit. The tubing spool is to allow a profile to be used for the Test Plug if we have to do a second BOP test after 7 days (as per AOGCC regulations). Procedure: Unbolt and remove top 4-1/6" by 13-5/8" 5k flange. Tag top of cement inside the 9-5/8" casing and report findings on daily report. Unbolt and remove the 13-5/8" 5k by 13-5/8" 5k tubing spool. Have wellhead technician dress the top of the 9-5/8" casing stub and clean the ring grooves to ensure they are free of dirt and/or other foreign materials that would prevent flanges from obtaining a pressure seal. NU the temporary 13-5/8" 5k by 11" 5k tubing spool. Ensure that the BOP Test Plug has been checked and pre-fitted in the tubing spool. Install new pack-off seals around the 9-5/8" stub, new RX ring gaskets, and a blind flange on top of the temporary tubing spool. Ensure there are extra nuts, bolts, RX ring gaskets, grease fittings, etc. on location. NU on side outlet valve of the new temporary tubing spool and shell pressure test the spool and flange connection to the casing spool to 250 psi and 2500 psi against the cement plug inside the 9-5/8" casing. Record pressure test on chart recorder. This flange will not be able to be retested once the BOPS are NU as this is the spool that will seat the test plug. Have wellhead technician test secondary seal pack-off around the 9-5/8" casing to 250 psi and 2500 psi prior to NU BOPS. Please let me know if you have any additional comments or questions. Thanks, Mike Michael D. Murrey ExxonMobil Production Company Production Engineering - Subsurface Phone: (713) 656-9624; Fax: (713) 656-7353 1 ~ F~EC~IVED STATE OF ALASKA ~~~ ~ ~ ~Q~~I ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Alaska pii $ 6»s Cuts. Cutr>rriission 20 AAC 25.280 A.~wharflfl~ 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change pprove Program ^ Suspend ^ Plu Perfor ns ^ Perforate ^ Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-ente S . Well Stimulate ^ Alter Casing ^ Other: Well Remediation0 2. Operator Name: .Current Well Class: 5. Permit to Drill Number: Exxon Mobil Corporation Development ^ Exploratory Q 169-120 . 3. Address: ~Stratigraphic ^ Service. ^ 6. API Number: PO Box 196601, Anchorage, AK 99519-6601 50-089-20001 • 7. If pertorating, closest approach in pool(s) opened by this o o nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Ye ^ West Staines State 18-9-23 9. Property Designation (Lease Number): 0. Field/Pool(s): ADL 28380 WILDCAT 11. EL ONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): pth (): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13,329 13, Su Surface See Attached None Casing Length Siz TVD Burst Collapse Structural 32' 0" 2' 32' N/A N/A Conductor 268' 20" 3' 303' 1530 520 Surface 2070' 13 3/8" 2105' 3090 1540 Intermediate WA WA N/A N/A N/A Production 10052' 9 5/8" 10087' 7510/8150 5600/7100 Liner 3156' 7" 130 13004' 8600 5890 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N!A N/A WA Packers and SSSV Type: Packe and SSSV MD (ft) and TVD (ft): N/A N/A 12. Attachments: Description Summary of Proposal Q 13. Well la fter proposed work: Detailed Operations Program ^ BOP Sketch ^~ Explorato ~ Development ^ Service ^ 14. Estimated Date for 2-Mar-10 15. Well St u roposed work: Commencing Operations: Oil ^ as ^ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: WINJ ^ GINJ ^ WAG ^ Abandoned Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. C ct Jack Rickner 907-564-3638 Printed Name Dale Pittman Title Alaska Productio ger Signature ate ~ ~ ZD/o COMMISSION USE ONLY C diti f l N tif i i th C t d N mb t ti it S / ~ (/L~~^ ~j er , : un ry u on ons o approva : y omm on so a represen a ve may w ness o ss a Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Cle rance ^ Other: Subsequent Form Required: APPROVED Y Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 12/2009 Submit in Duplicate ~~~fi® ExxonMobil Development Compa~ 3301 C Street, Suite 400 Anchorage, Alaska 99503 907 564 3617 Telephone 907 564 3772 Facsimile February 22, 2010 Mr. Daniel T. Seamount, Jr. Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Application for Remediation ExxonMobil West Staines State #18-9-23 PTD No. 169-120 Dear Commissioner Seamount: ~E~EIVE® FEB ~ ~~11~ Atl~sk~ Oil & Oa: Cuts. Cornmissian Arr~h~lt~~e Exxon Mobil Corporation hereby submits an Application for Sundry Approval to perform remedial , plugging and abandonment work on the subject well. This work was described in ExxonMobil's letter of November 14, 2007 to the AOGCC and has been discussed in correspondence and. meetings between AOGCC and ExxonMobil staff. The work is described in more detail in the attached. The general procedure will be: 1. Excavate the well cellar and check wellhead pressures to verify integrity. 2. Rig up Snubbing Unit to drill out surface cement plug and bridge plug from 9-5/8" casing. 3. Displace the diesel in the casing with 10.7 ppg CaCl2 brine. 4. Perforate the casing at approximately 1200' and attempt to circulate out the diesel in the 9- 5/8" x 13-3/8" annulus. 5. Cement casing and annulus with permafrost cement from approximately 1200' to surface. 6. Cut off the wellhead and casing strings at least 3' below the tundra and remove. 7. Install well identification marker cap, backfill excavation with gravel and mound gravel to allow for settling. Please find enclosed the following information: • Form 10-403 Application for Sundry Approval (Original and 1 copy) • Revised Current Wellbore Schematic • Proposed Wellbore After Remediation Schematic • Revised Wellhead Schematic • Overview of Remediation Procedure • Proposed BOP Schematic If you have any questions or require additional information, please contact Jack Rickner at 564- 3638. Sinc aly, ~---~ DDP:eaa Attachments Brien E. Environmental and Regulatory Manager Point Thomson Project E~onMobil Development An ExxonMobil Subsidiary Current VVeIIYaore Sketch Exxonhbbll West Shalnes State 18.9.29 API #: 50-089-20001 PTD #:169.120 Gray 20", 2 kpsi A-sectlon & Gray 135!8", 5 kpsi B-sectlon Dlesei in 9-5l8" from surface to 10' Diesel In 9-518" x 13-3lB" from surface to 1,472' 13-318" DV Tool at 1,385' Pumped 400 sx fondu cmt plug in 13-3/B" x 9-518" from 1,472' - 2,105' Retainer at 9,898' Sgz'd w/ 100 sx class G Retainer at 10,472' SgYd w/ 110 sk? cmt & 30 sx cmt plug on top BP at 11,497' 30 sx cmt pk~g on top BP at 11,743' 30 sx cmt plug from 12,350' -12,409' Retainer at 12,409' SgYd parts 12,512'- 12,795' w1120 sx EZ drill BP at 12,869' w/ 2 sx cml plug on top ~J RKB = 63' MSL = 15.5' above bradenhead 30° structural at 32' BGL cmt'd with 176 sx BP in 9-5/8" at 150' w150 sx fondu to 10' ' 20" (~ 303', cmt'd to surface w1840 sx Diesel in 9-518" csg hom 150' -1,950' BP n 9-518" at 2,000' w! 25 sx plug on top tot 1,950' 13-318", 61#, HwtO at 2,105' 13-318" cmt'd stage 1 w/ 700 sx class G; stage 2 w! 1200 sx fondu flyash with 30% salt through DV Tool Gaod returns at surface TOC in 9-518" csg at 9,838' Top of 7" liner at 9,848' 9-5~" set at 10,087' 2,409' of47#, S-95 & 7,700' of43#, S-95 Cmt'd with 420 sx class G PerF'd 9,998' - 10,020' TOC ai 10,422' Perf'd 10,570' - 10,590' TOC at 11 A50' PerPd 11,650' - 11,675' PerPd 11,675' - 11,715' Pert'd 11,763' - 11,782' Pert d 12,512' - 12,525' PerPd 12,525' -12,537' PetTd 12,630' -12,650' PerPd 12,680' -12,700' Perfd 12,780' -12,795' ~/ 50 sx cmt plug in 7"from 12.900'- 13,078' 7" liner at 13,004' ~ 2032.8', 29#, 5-95, 1100.6', 26#, S-95 3156'total liner lengihw8h hanger, shoe and collar 6" & 5-15/16" hole to 13,329' ~ z Cmt'd wd 400 sx class G, sgYd 4 times w/ 542 sx G tdal WHI schematic dawn June 29'", 2007 ty Fairweather E R P Services, inc. Up tlatetl March 31, 2009, July 20, 2009, antl September 8, 2009 by EM • Pur posed After :P ~A LVellho re Sketch ExxonMobll bleat Staines State 18-9-23 API ~ 50-089-2 0 0 01 PTl] #:169.120 RKB = 63' MSL = 15.5' above bradenhead 15.7 ppg permafrost cmt in 9-5/8" csg & - 30" structural at 32' BGL cmt'd with 176 sx 9-5l8'° x 13-3J8" anrnalus from ~3' io 1.200' 20" ~ 303', cmt'd to surtace w1840 sx - Casing perPd at 1,145'-1,200' 13-318" DV Tool at 1,385' 9tia.7 ppg GaClz brine in 8-51r3" csg from 1,200' -1,850' Pumped 400 sxfondu cmt plug In :7,9so 13-3/8" x 9-518" from 1,472' - 2,105' ~ BP tt 9-5/8" at 2,000' with 25 sx plug on top to t 1,950' 13-3/8", 61#, Ft-40 at 2,105' 13-38" cmt'd stage 1 w/ 700 sx class G; stage 2 w! 9.7 1200 sx fandu tlyash with 30% salt through DV Tool ppg Good returns at ~rtace mud Retainer at 9,898' Sgz'd w/ 100 sx class G Retainer at 10,472' SgYd w/ 110 skT cmt & 30 sx cmt plug on tap TOC In 9-5/8" csg at 9,838' Top of 7" Ilner at 9,848' 9-5A1" set at 10,087' 2,409' of 47#, S-95 & 7,700' of 43#, S-95 Cmt'd with 420 sx class G Pert°d 9,998' -10,020' TOC at 10,422' Pert'd 10,570' -10,590' TOC at 11,450' BP at 11,497' 30 sx cmt plug on top BP at 11,743' 30 sxcmt plug from 12,350' - 12 A09' Retainer at 12,409' Sgz'd perfs 12,512' -12,795' w/ 120 sx Pe rfd 11,650' -11,675' Pe rt'd 11,675' -11,715' Pert'd 11,763' -11,782' Perfd 12,512' -12,525' Perfd 12,525' -12,537' PerFd 12,630' -12,650' Perfd 12,680' - 12,700' Perf'd 12,780' - 12,795' F~ drill BP at 12,869' w/ '_ 2 sx cmt plug on top r ~ ~•° ~ 50 sx cmt plug h 7"from 12,900'-13,078' , - ~: ,•~, ~`~ 7" Ilner at 13,004' >"a +` 2032.8', 29#, 5-95, 1100.6', 26#, 5-95 z ; 3156'total Ilner length with hanger, shoe and collar 6" & 5-15116" hole to 13,329' ~ i Cmt'd vv! 400 sx class G, sgYd 4 times w! 542 sx G tdal WeJI schematic tlrawn June 29'", 2007 by Fairweather E & P Services, Inc. Uptlated March 37, 2009, Juy 28, 2009, Septemher 8, 2009, antl February 10, 2010 fry EM • • West Staines State 18-9-23 Notes: Gray Well Head PT. Thomson Well Some outlet valves are West Staines State 18-9-23 4" LP needle valve 13 5/8" 5k. ~"" 20"2Mx135/8"5M _ Multi Bowl Head 20"2M 21 1/4" 2M connection 20" CSG Spool • West Staines State #18-9-23 Point Thomson Field Well Remediation Procedure Overview of Remediation Procedure: 1. Ensure all necessary permits and applications are in place. Notify AOGCC: • at least 10 days before operations begin and review procedure • at least 48 hrs prior to testing BOPs, due to remote well location • at least 48 hrs prior to cementing and capping the well, due to remote well location • of any procedural changes during operations 2. Mobilize all personnel and equipment to the West Staines State #18-9-23 location via ice road. Record travel routes and well location using GPS. 3. Observe and record any signs of hydrocarbon leaks in the area surrounding the well. Take photographs showing the condition of the surrounding location. A detailed report documenting any contamination will be prepared. 4. Hold safety meeting. Excavate gravel around wellhead as needed. Take photographs showing the condition of the wellhead as found. Document any areas of concern. 5. Check for HC by using a gas analyzer. Install temporary cellar if necessary. Warm up the wellhead using heaters to remove any ice plugs to the extent possible. 6. RU Hot Tap Unit. Hot tap the bull plug on the upper B-section side outlet valve. This should allow pressure access to the 9-5/8" casing. Bleed off any pressure. RD Hot Tap. 7. Remove bull plug. Install and test new wellhead valves on the upper and lower B-section side outlets. EM to provide two (2) crossovers from 2" Grayloc to 3-1/8", 5 kpsi API flange, two (2) 3-1/8", 5 kpsi FMC gate valves. The 13-3/8" x 20" annulus appears to be full of cement based on observation of the side outlet where outlet valve was broken off. 8. Grease and open the WKM gate valves. The hot tap machine should have the capability to drill out the gate valve, although hole size may be limited (~1 "). Inspect side outlets for any VR plugs and remove using a pulling tool and lubricator. Check for any wellhead pressures. If pressure is observed, perform diagnostic testing to determine if the pressure is sustained casing pressure or trapped pressure. Record pressure bleed down and build up using a chart recorder. Record the fluid type and volume. Take fluid samples for possible analysis. 9. Move in and offload Snubbing Unit. ND wellhead flange cap and install 13-5/8" 5 kpsi by 11 ", 5 kpsi casing spool. NU BOPs. Install Snubbing Unit. Pressure test BOPs to 250 psi and 2500 psi. Test pressure based on maximum expected surface pressure of about 925 psi assuming freshwater pressure gradient above the 13-3/8" shoe and the age of the wellhead (40 years). 10. PU bit, mud motor and drill pipe. Tag TOC at about 10'. Note: diesel is above the surface cement plug. Drill out surface cement plug and bridge plug down to 150' with 10.7 ppg CaCl2 brine (kill weight fluid). Use gas sniffer to check brine returns for HC and to monitor changes in HC levels (i.e., diesel) while circulating if possible. POH. Page 1 • 11. RIH with mule shoe and drill pipe to PBTD at about ±1950'. If cement plug is not at the expected depth or the plug is soft, then may be necessary to spot an additional cement plug. Notify AOGCC of any procedure changes. 12. Circulate diesel out with warm 10.7 ppg CaCl2 brine. Pressure test casing to 1000 psi. Ensure contingency 9-5/8" RBP and packer are available to locate any casing leaks. Run casing scraper before running any full size tools in the hole. Pull up the hole to about 1100'. 13. RU Electric Line Unit. NU lubricator joint and pack-off. Pressure test to 250 psi and 2500 psi. RIH with 1-11/16", 4 spf, zero degrees phasing, magnetically decentralized perforating gun and perf 9-5/8" casing at 1195 - 1200' (5') . POH. RD Electric Line Unit. 14. Circulate the diesel out of the 9-5/8" x 13-3/8" annulus by pumping warm 10.7 ppg CaCl2 brine down the 9-5/8" casing and taking returns on the annulus. POH with drill pipe. 15. RU Cementing Unit and pressure test lines. Mix and circulate 15.7 ppg, 0.93 ft3/sk, permafrost cement plug down the 9-5/8" casing and up the 9-5/8" x 13-3/8" annulus. RD. 16. RD Snubbing Unit. 17. Finish excavation of gravel from around wellhead as needed. 18. RU Wachs Guillotine saw (maximum cut OD is 30"). Cut-off wellhead and casing strings to at least 3' below tundra level. RD saw. 19. Level casing stub as needed. Top off casing/annuli with 15.7 ppg, 0.93 ft3/sk, permafrost cement as required. 20. Weld marker plate with the required AOGCC information on it across all casing strings. Take photographs showing the condition of the casing stub and marker plate. 21. Backfill cellar with gravel. Mound the gravel (-5-10') to compensate for summer thawing and settling, per AOGCC guidance. 22. Conduct general location clean-up. Final well site restoration will be performed at a later date. Site gravel may be used for fill in the West Staines #2 reserve pit. Take photographs showing the condition of the location. 23. Transport all wastes and site clean-up debris to Deadhorse for disposal at approved waste disposal sites in accordance with EM Waste Management Plan. 24. Prepare final well report and Sundry Report. 25. After the summer thaw, notify AOGCC for visual inspection and site clearance. Page 2 ExxonMobil West Staines State API # 50-089-2000 PTD # 169-120 w a a a c d ++ H Hleedof = Llne To Returns: Tank ~~ 3~d 6 STATIC IiLCtM1~A1 r ~/21-1'X23'SS was PuMp Manifold \ ~~ B All PuMp & Flow Lines 2' 1502 Chlcksnn - -- ~ - CUDD ENERGY SERVICES BOP STACK ExxonlViolsii Development ~oanpa~y 3301 C Street, Suite 400 Anchorage, Alaska 99503 907 564 3617 Telephone 907 564 3772 Facsimile February 8, 2010 Mr. John Easton Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 800 Anchorage, Alaska 99501 Brien ~. F~eep environmental and Regulatory Manager Point Thomson Project s iss6o~ pChltt~ C ~T'~es~SG~~ ~~~\c~ ~.~~ Re: Lease/Unit Plan of Operations Applications `~` ~ ~ ®~~ Point Thomson Area Site Remediation Project ~~ , ~ .a Dear Mr. Easton: `~ ~ _ ~ Exxon Mobil Corporation requests approval to conduct site remediation at the West Staines State #2 (WSS #2) and at the West Staines State #18-09-23 (WSS #18-09-23) exploratory well locations as set forth in the attached Lease/Unit Plan of Operations Applications. We also request approval to perform remediation on these and the Point Thomson Unit #4 (PTU 4) well. This work is being conducted in conjunction with other remediation projects in the Point Thomson area. The overall effort is described in the attached Project Description entitled "2010 Inspection and Remediation Program, Point Thomson Area" and corresponding Coastal Project Questionnaire. These documents were amended on February 5, 2010, to reflect the discussion and agreements reached in January 29, 2010 meeting with ADEC and ADNR. The specific approvals requested from the DOG are: West Staines State #2 Gravel/Reserve Pit Remediation - LO/NS Application Attached Exploration activities at the WSS #2 site were previously authorized by LO/NS 74-24. The WSS #2 site has an open reserve pit that will be closed in accordance with a Corrective Action Plan (CAP) submitted to the Alaska Department of Environmental Conservation for approval on January 13, 2010. The reserve pit contains ice and water that will be removed and transported to the Prudhoe Bay area for disposal. Following sampling and characterization under a Phase II Site Assessment Work Plan, also to be approved by ADEC, gravel from the WSS #2 pad will be placed into the reserve pit as part of the closure process. Gravel will not be removed below the level of the surrounding tundra unless that is necessary to meet clean-up levels. If additional gravel is required to fill and level the reserve pit, gravel will be taken from the nearby WSS #18-09-23 exploratory well gravel pad. Field surveys have indicated sufficient gravel is available at these two sites to fill the reserve pit. Site rehabilitation following gravel removal will be conducted as described in the ADEC approved CAP. An ~x~anf~4obii Subsidiary Mr. John Easton -2- February 8, 2010 West Staines State #18-09-23 Gravel Remediation - LO/NS Application Attached Exploration activities at the WSS #18-09-23 site were previously authorized by LOINS 69-017. Following sampling and characterization under a Phase II Site Assessment Plan and CAP, both to be approved by ADEC, it is proposed to remove as much gravel from the WSS #18-09-23 pad as necessary to fill and mound the open reserve pit at the WSS #2 location. Gravel will not be removed below the level of the surrounding tundra unless that is necessary to meet clean-up levels. Site rehabilitation following gravel removal will be conducted as described in the ADEC approved CAP. WSS #2, WSS #18-09-23, PTU #4 Well Remediation - LO/NS 09-007 Concurrence Section 4.2 of the attached Project Description describes the remedial work that will be performed on three exploratory wells (WSS #2, WSS #18-09-23, and Point Thomson Unit #4 (PTU #4)) in the Point Thomson area. The remedial well work is to bring their abandonment condition into conformance with current AOGCC regulations. No other well re-entry or drilling operations will be undertaken at these locations. Approval for investigative work on these wells was provided administratively under LO/NS 09-007 on March 16, 2009. The investigative work was performed during the winter of 2008-09 and there are no changes to the well remedial work as described in the December 2008 Project Description and amended on March 5, 2009. We would appreciate confirmation that LO/NS 09-007 authorizes ExxonMobil to conduct the well remedial work described. The reserve pit closure, site rehabilitation, and well remediation activities will be performed concurrently as a single, overall project and will rely upon some of the same support services and personnel. Accordingly, they are described in a single Project Description and Coastal Project Questionnaire. The Inspection and Remediation Program is a separate project from the Point Thomson drilling activities described in the February 10, 2009, Plan of Operations for Point Thomson Drilling. However, it will be supported by and will use the ice roads, other infrastructure, and permits established for drilling activities. The ice road between Endicott and the Central Pad location will serve as a supply road and the origination point for inspection and remediation activities. Access from the ice road to the individual well sites will be supported by agency-approved off- road vehicle travel or by conventional vehicles travelling on additional spur ice road routes that may be constructed. Previously this type of activity has been found consistent with GCD-49 and A-List #3, #4, and #7. ExxonMobil has reviewed General Concurrence 49, Removal of Uncontaminated Gravel Structures, and has adopted the alternative measures (termed "standard conditions") into our proposed project plans. Attached are the following: • Lease/Unit Plan of Operations Applications for the WSS #2 and WSS #18-09-23, • Project Description (Amended as of February 5, 2010), • Corrective Action Plan for WSS #18-09-23, • Coastal Project Questionnaire and Certification Statement, and • Permit fees of $500 ($250 for each application). Mr. John Easton -2- February 8, 2010 The WSS#2 CAP was submitted to you on January 13, 2010. The WSS#2 and WSS#18-09-23 Phase II Site Assessment Work Plans were submitted to you on January 25, 2010. If you have any questions or need additional information, please contact Rob Dragnich at (907) 564-3711 or via email (rob.g.dragnich@exxonmobil.com) or Janet Sheldon at (907) 564-3650 or via email (janet.sheldon@exxonmobil.com). Sincerely, BER:eaa Attachments cc: w/ Attachment Nina Brudie ADNR/DCOM Gary Schultz, ADNR/DMLW w/o Attachments Tom Maunder, AOGCC Don Perrin, ADNR/OPM Jack Winters, ADFG P. O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimile September 23, 2009 Commissioner Cathy P. Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 LaeC- P"f,�Zm'an Alaska Production Idlanager Joint Interest U.S. RE: Request for Verification of Suspended and Shut-in Well Information Dear Commissioner Foerster: Product -on 19 6 TP 700' By letter dated January 29, 2009, the AOGCC requested verification of information regarding suspended long-term shut-in wells listed as operated by ExxonMobil or predecessor companies. The lists of Suspended and Shut In Wells attached contained a total of eleven wells. We have no revisions to the information for the Kuparuk 28243 1 well which is located within the Kuparuk River Unit operated by ConocoPhillips. As with your records, we understand that the Starichkof St 1 well was operated by Pennzoil, not by ExxonMobil or a predecessor company, and the lease and well currently is within the Cosmopolitan Unit operated by Pioneer. With respect to the 9 Point Thomson area wells, a sundry notice report was filed with the AOGCC on June 1, 2009, describing the location and well inspection and remediation work performed in March and April of this year. A copy of these reports, along with a summary of the well status is attached for your reference. Please advise if there is any further information we can provide in conjunction with this response. Sincerely, ot_ _____ DDP:jpc Enclosures xc: Mr. Tom Maunder — AOGCC SCANNED A Division of Exxon Mobil Corporation ExxonMobil Submittal Suspended and Shut in Well Status Well Name Current Filing Report Comment Status Date Point Thomson Unit #1 Suspended June 1, 2009 Location and Well inspected 3/2009. r� /77- a b V Point Thomson Unit #2 Suspended June 1, 2009 Location and Well inspected 4/2009. Point Thomson Unit #3 Suspended June 1, 2009 Location and Well inspected 4/2009.1 Id a 005 Location and Well inspected 4/2009. / -% 9. 61451 Point Thomson Unit #4 Abandoned June 1, 2009 Further remediation work planned for the 2009�-T10 winter Alaska State C-1 Suspended June 1, 2009 Location and Well inspected 4/2009. /season ,/�(/ (�)G Alaska State J-1 Abandoned June 1, 2009 Well inspected and remediated and site cleared in 4/2009. ��� • Q�� Staines River State #1 Suspended June 1, 2009 Location and Well inspected 4/2009. % 7 %• C/ �� Location and Well inspected 4/2009. West Staines State #2 Abandoned June 1, 2009 Further remediation work planned for the 2009-10 winter season Well is located on former ADL 0028377 West Staines State #18-9-23 Abandoned June 1, 2009 Location and Well inspected 4/2009. Further remediation work planned for the 2009-10 winter season 9/23/09 ~~~~nt~foEs"sl 9~~~cfucti~e~ ~om~ar~gr Jointlnterest U.S.- Alaska P.O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3789 Facsimile June 17, 2009 ~ ~ ,~~~~~~~~~~~ ~ .l(1N `, ~ /~l~).~ :~jAS~f~ ~I~ ~rr ~; H ,~~,~ ~.'~tl.'}, 6"UqhmfSS-q~$ E o n M o b i~~°`~~~ ~ ~~oc~u~~~on Mr. Johnny L. Aiken, Director North Slope Borough Planning and Community Services Department P.O. Box 69 Barrow, Alaska 99723 Re: Tundra Travel Completion Report Dear Mr. Aiken: +r~ ~~~ ~~~b-9 N~'I ;~5 c, a ~ ~°``n Please find attached our 2009 Winter Tundra Travel Completion Report as required by North Slope Borough Conditional Use Permits. This Tundra Travel Completion Report pertains to the following activities authorized by the above permits: - Ice Road Construction from the Endicott causeway to the Point Thomson Unit Central Pad - Ice Road Construction to the Alaska State C-1 water source and other lakes from which water was withdrawn. - Tundra Travel /Ice Road Access - Point Thomson Unit Central Pad Mobilization & Construction - Well Inspections and Remediation The attached report reflects Tundra Travel activities through closure of the Alaska State C-1 ice road on May 19th, 2009, and includes the following elements: 1. Actual routes of travel and the location of all camps depicted on USGS topo maps 2. List of vehicles for off-road travel that has taken place 3. Statement of cleanup activities 4. Method of disposal of garbage and other camp debris 5. Report of known incidents of tundra damage and follow-up corrective actions ~ C~C~ ~~cc+~~- ~ v~ ~' ` ~i~.~~ -~t~ _ ~- / " i A Division of Exxo~a N{~bi! ~~rp~ratior~ Mr. Johnny L. Aiken -2- June 17, 2009 If you have any questions, please contact me at 907-564-3617 or by email at mike.barker@exxonmobil.com. Thank you Sincerely, • `: t~ `~ ~~~~. .. , ~ ~, Mike Barker Environmental & Regulatory Manager KDC:eaa Attachments cc: Lori Aldrich, ADEC Gordon Brower, NSB Nina Brudie, DNR Larry Byrne, DNR DMLW Steve Davies, AOGCC Josephina Delgado-Plikat, DNR John Easton, DNR DOG Gary Evans, ADEC Susan Harvey, Harvey Consulting Lee Kayotuk, Kaktovik Tom Maunder, AOGCC William Morris, ADFG Craig Perham, USFWS Matt Rader, DNR DOG Barrett Ristroph, NSB Gary Schultz, DNR DMLW Roy Varner, NSB Waska Williams, NSB Ryan H. Winn, USACE Jack Winters, ADFG ExxonMobil Production Company Alaska Interest - Joint Interest U.S. P.O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone June 1, 2009 Mr. Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Report of Sundry Well Operations Exxon Mobil Corporation West Staines State 18-9-23 PTD No. 169-120 Sundry No. 309-081 Dear Commissioner Seamount: ~~~~~~~~~~~~'~ ~I~f ~u ~ ~ ? ~ ~ ~1.~ ~~~5~~1 ~~s~ t~ ~a'~~ a`~a's, +~~~;'Aft~~S~EQ1~ ~t~s~~~r,~~~ E~onMobil Production Exxon Mobil Corporation hereby submits its Report of Sundry Well Operations for the wellhead inspection of the West Staines State #18-9-23 well on the North Slope. The well is plugged and abandoned, and the inspection was performed upon request of the AOGCC. The inspection results will assist in planning for the well remediation during the winter 2009-2010 season. During the wellhead inspection operation, the wellhead was exposed by excavating the gravel cover. The wellhead was visually inspected, but no well pressures were measured due to incompatible tools and materials. No evidence of leaks or impacted gravel/tundra was noted. No new gate valves were installed on the wellhead. With concurrence from Mr. Tom Maunder, this well will be inspected for pressure prior to the additional remediation work planned for next winter. At the end of the well inspection, the wellhead was covered with gravel. Attached please find: Form 10-404: Report of Sundry Well Operations Daily Report of Well Operations Wellhead drawing. Wellbore diagram Well plat Photographic documentation of the well If you have any questions or require additional information, please contact me at 907-564-3617. Sincerely, ~~ , D. Michael Barker Environmental and Regulatory Manager JAR:eaa Attachments A Division of Exxon Mobil Corporation STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CCIMMISSION REPORT OF SUNDRY WELL OPERATIONS +~+~,~°~ ~~ ~ ~',~~"" ~.~' Ei Phd d~t - "]rnn 1. Operations Abandon Repair Well Plug PerForations Stimulate Other ~ e I Inspecfion Performed: Alter Casing ^ Pull Tubing ~ Perforate New Pool ~ , Waiver Time E ~ ~ ~~ ~ ~ ~~ Chan eA roved Pro ram g pp g ^ Operat. Shutdown ~ Perforate ^ ~ ~ ~ ~'~~~` ~'~~~~s Re-enter Suspended Well 2. Operator 4. Well Class Before Work: , 5. Permit to Drill Number: Name: ExxonMobil Oil Corporation Development ^ Exploratory^~ 169-120 ' 3. Address: PO Box 196601 Stratigraphic^ Service^ 6. API Number. Anchorage, AK 99519-6601 50-089-20001 ' 7. KB Elevation (ft): 9. Well Name and Number: 63 ~ West Staines State 18-9-23 8. Property Designation: 10. Field/Pool(s): ADL 28380 Wildcat 11. Present Well Condition Summary: ~'~ ~t ~yy ~ ., ~ ~;~~ ~ Total Depth measured 1~1'r'f ~ feet ~ i.~ ~~ f:= e Plugs (measured) Plugged to surface ~~c~ truevertical 13,170~3;3~2et . , rf~r~'~ ~~, ~~{ Junk(measured) None ~ l~~~ Effective Depth measured Surface feet true vertical Surface feet Casing Length Size MD TVD Burst Collapse Structural 32' 30" 67' 67' N/A N/A Conductor 268' 20" 303' 303' 1530 520 SurFace 2,070' 13 3/8" 2,105' 2,105' 3090 1540 Intermediate Production 10,052' 9 5/8" 10,087' 10,087' 7510 / 8150 5600 / 7100 Liner 3,156' 7" 13,004' 13,004' 8600 5890 PerForation depth: Measured depth: N/A True Vertical depth: N/A Tubing: (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative DailyAverage Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Well Photographs Exploratory^~ ° Development ^ Service ^ Daily Report of Well Operations See Attachments 16. Well tus ~fter work: . ~ ~ Oil [ ,';; Gas ~ t~' WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~,c:~ Sundry Number or N/A if C.O. Exempt: ~ 309-081 Contact Mike Barker Printed Name Mike Barker Title Environmental and Regulatory Manager Signature~ . Phone (907) 564-3617 Date p~ ~6&~~; Form 10-404 Revised 04/2006 "~ M' ~~~ H L ~~ Submit Original Only ~,~,~ ~~~~e~,'.'? ~~ ,1~vL ;~ `-= LOO,~i . . ,. ra~~,~~~ / G?"I 1 !.~ Daily Operations Log West Staines State #18-9-23 Well Inspection Thursday, April 16, 2009 • Mobilized equipment and tools to West Staines State 18-09-23. • Set up the camp. • Returned to WSS #2 to excavate and verify no additional flanges below previous excavation • Returned to WSS 18-9-23 and began excavation around well. Friday, April 17, 2009 • Cut cellar walls with air arc. • Removed cellar walls and continued excavating around well. • Used jack-hammer to clean immediate area around well and expose valves for inspection. • Cleared area around wellhead. • Inspected, photographed and recorded pertinent info of wellhead. Saturday, April 18, 2009 • Headed to well-site WSS 18-9-23. Evaluated options to check for pressure in the casing and the annulus. The annulus valve had been broken off exposing the annulus. Made the decision to leave the wellhead as is. No new valves installed on the wellhead. Pressure was not checked on the casing.. • Wrapped well in reinforced visqueen. Backfilled excavation and loaded out sleighs. ~ Mobilized tools and equipment sleighs to PTU#2. West Sta i n es State 18-9-23 Gray Wellhead Point Thomson Well West Staines State #18-09-23 4" LP All outiet valves are open ended 4-1/16" 5k. ~ needlevalve 13 5/8" 0 Q ~ Gray ~ 20" 200 24" TUBING HEAD 0 O ~~ ° Gray o O O " Broken valve 20°° cs~ sPOO~ 0 Ex~conMobil Oil Corporation West Staines St. 18-9-23 Well Schematic API #: 50-089-20001 PTD #: 169-120 Gray wellhead A and B section in place with blind flange on top 30" structural set at 32', 140 sx of cement used Diesel in 13-3/8" x 9-5/8" annulus from 1,472' to surface 13-3/8" DV Tool at 1,385' Cement in 13-3/8" x 9-5/8" annulus from 1,472' - 2,105' 13-3/8", 61 #, H-40 at 2,105' TOC in 9-5/8" casing at 9,838' Top of 7" liner at 9,848' Retainer at 9,898' 9-5/8" at 10,087' TOC at 10,422' Retainer at 10,472' TOC at 11,450' BP at 11,497' BP at 11,743' 30 Sx cement plug from 12,350' -12,409' Retainer at 12,409' Perforations 12,512' - 12,795' squeezed with 120 sx EZ drill BP at 12,869' 7" liner at 13,004' 6" and 5-15/16" hole to 13,329' -RKB = 63' MSL = 15.5' above bradenhead Diesel in 9-5/8" casing from 0'-10' BP in 9-5/8" at 150' with 50 Sx fondu to 10', Diesel I~;`~ 20" @ 303', cemented to surface Diesel in 9-5/8" casing from 150' - 1,950'f ' BP in 9-5/8" at 2,000' with 25 sx on top ~~ 4~ ~'~ .., ' ~ 9-5/8": 2,409' of 47#, Soo-95, 7,700' of 43#, Soo- ~, 95, Cemented with 420 sx G 13-3/8" cemented with 700 sx G in stage 1, 9•7 PP9 1,200 sx fondu flyash with 30% salt through DV mud Tool for stage 2. Good returns at surface Perforations 9,998' -10,020', 4spf, squeezed with 100 sx class G through retainer 30 sx plug on retainer Perforations 10,570' - 10,590', 4 spf, squeezed with 110 cu.ft. cement 30 sx plug placed on top of BP/Retainer Perforations 11,650' - 11,675', 4 Perforations 11,675' - 11,715', 4spf Perforations 11,763' - 11,782', 4spf Perforations 12,512' - 12,525', 4spf Perforations 12,525' -12,537', 4spf Perforations 12,630' - 12,650', 4spf Perforations 12,680' -12,700', 4spf Perforations 12,780' - 12,795', 4spf 2 sx cement on top of EZ drill Cement plug in 7" from 12,900' - 13,078' 7": 2,032.8', 29#, Soo-95, 1,100.6', 29#, Soo-95 7": 3,156' total with hanger, shoe and collar 7": Cemented with 400 sx G 7": Squeezed 4 times with 5542 sx G total Well schematic was prepared by Fairweather E& P Services, Inc. Last updated May-2009. ` ~ i R22E I R23E I I ( I ~i...~.~~~~_ ~~ _r_ ~ ___-. T_ -T ~ ~ j I I f ~ 2 ~ ~ ~ e j s I 4 ~ 3 I I ~ ~ I I ~ I I I ~-------~---... _ __.--- --~-------l--------~ ~ ~ ------ --~---~_-- i i ~ ~ I I ~ ~ ~ ~ I I ~ ii ~ i2 ~ ~ a ~ a ~ a ~ I ~ j ~ ~ ~ L___~ ~ ..___ _ _. _J_ ~ ~ I ~ -y-- - - _ .. ~. ~ -- ------~---------i-------' I i ~ §~i WEST STAINES ~ I I LAT. 70° 08~ I~S.19~~ ~ I I ,~ ~ 13 is ~ LONG 146° 23~ 17.3~' ~ 15 ~ ~ ~ i Y= ~,ess,seg i ` T9N ~ i I i X= 45t,694 ~ I F-------.-r--_.--- --- ~------._ 1_ ___-._ ~-------I i f r ~ - r------' i i I ~ ~ ~ i ~ _ 2a ~ za ~ ig I zo ~ zi I z2 ~ I ~ ~ ~ I I j I ~ --t --- --- - ~- -- ~ I I ~ r_____ ~ _____---fi----~---1------}------- ~ ~ ~ I ~ ~ I I i I ~ 2 B I 25 30 ~ 29 ~ 28 ~ 27 I I I I ~ ~ ~ ~ ~ ~ I t I I L--_..___.1_._~._._._ __-_.____1..------~J`~.____.1.__._~_~J SCALE~ 1° = 1 MILE CERTIFtCAT~ OF SURVEYOR I hereby certify that I am properly registere~ and I ic~sed to practice land surveying in the State of Alaska and thot this plat represents a location survey mada by me or under my supervision, and thof ai1. dimensions and other details are co~rect. ~t w . 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'~ ~b ~ r .~~,q ~~ s "~? l.'~ '~Q, *~y ~ 1. ~:~ r 1~ ~A~ w ~ x~~ w •~ ~~~4~~ F ' ~'~ ~ i,~ ~~ }~ Y• _ ~ y t ~ •+~'!c '~ 4 T r ~ i i~ y~, s R'i~ ~R~+~~ ~+~ t~:;'~~~~ ~~: ~ ~~•. ,~ ;+: „ ~~- ~~ ~~ ~ ~k, . . . : , ~,rt 'e ',1 a,~_ .~ ~ . . . ~ . y. , , . ..,+.r ; ~. : `: ~ _. _.u; ... ~ ~<,,-. ~ `; .~_ ; ' ; .,;~ . ll'9~~a~.3.(1~~:~y, .~i~;i~~11°~~`-~ "~ .~~~F~~ ~~~~. ~. .. . ~C3Ciii..~.1~.~4Yli~.~.~~~iv~'La~:~?'c'dFl~~.~.ri~~i ~ . ~~~i~~ ~i3on~a~, :~~r~e ~`!, 2~t~9 9:'?~ ?~~? ~~v lrlaue~der, Tr~or~as ~ {~~~?) ~~~J~~o ~~: A~OGC~ ~ur~dry ~9ofice ~Ze~Qr€s ~c~~ ~~g,~~i~c~a ~=9eic; ;~e~$9V9~3ES Tom, the reports for the 9 well inspection/remediation wor;;. at Point Tizomson left my office this afternoon. Thanks for your patience. I'm now loolcinq ior contractors to bid the work to for the next winter°s work for the 3 well remediation effort. Ii you have any questions regarding the recent work or next winter's anticipated ~~vorlc, please call. Regards, Jack Maunder, Thomas E From: Sent: To: Subject: ``~-~ Maunder, Thomas E (DOA) Thursday, May 28, 2009 7:18 AM jack.a. rickner(a~e~oconmobil. com RE: AOGCC Sundry Notice Reports for Completed Fieid Acitivities Hi Jack, Thanks for the update. I will look forward to receiving the reports. I agree with your ~ntent to work to avoid the last minute crunch. c;atl or message witn any details. Tom Maunder, PE AOGCC -----Original Message----- From: jack.a.rickner@exxonmobil.com Sent: Thursday, May 28, 2009 7:14 AM To: Maunder, Thomas E (DOA) Subject: AOGCC Sundry Notice Reports [mailto:jack.a.rickner@exxonmobil.comJ for Completed Field Acitivities Tom, just a note to let you know I haven't been idle. Finally completed all the wellhead drawings, have all the attachments and photos together for all 9 wells. The package has been provided to our inhouse legal folks for there blessing. Hope to have their check off within a day or two. Will deliver to your office as soon as they catch my grammatical and spelling errors. Currently we are tentatively scheduling the summer stick picking work for July. Moving ahead on planning the winter remediation work for the PTU-4, West Staines #2, and the West Staines 18-9-23. Our current plans are to start the permittinq, contracting, and procedure development (including which type of equipment to drill through the bridge pluqs) this summer in hopes of avoiding a last minute crunch to obtain permits and equipment. That is our hope anyway. If you have any questions, please call. Regards, Jack Jack A. Rickner Pt. Thomson We11 Inspection & Remediation Project ~07-564-3783 281-217-4350 ~~o~;; _ '.~! / Maunder, Thornas E (DOAj From: Maunder, Thomas E (DOA) Sent: Monday, AAay 11, 2009 8:18 AM To: Natasha Sachivichik Cc: jack.a.rickner@exxonmobil.com; Bill Penrose Subject: RE: PTU well inspection project AOGCC report status Thanks Natasha. Thafi schedule should work. Tam Maunder, PE AOGCC From: Natasha Sachivichik [mailto:natasha.sachivichik@fairvveather.com] Sent: Monday, May 11, 2009 8:16 AM To: Maunder, Thomas E (DOA) Cc: jack.a.rickner@e~oconmobil.com; Bill Penrose ~ co~ "~~~ Subject: RE: PTU well inspection project AOGCC report status To m, Sorry for delayed reply. We should have the reports ready by the end of this week or beginning of the next week the latest. Thanks and regards, Natasha sachi.vtch~~2 Senior Drilling Engineer Fairweather E8~P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 Direct:907-343-0405 Cell: 907-575-7156 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, May 07, 2009 12:29 PM To: Natasha Sachivichik Cc: jack.a.rickner@e~oconmobil.com; Bill Penrose Subject: RE: PTU well inspection project AOGCC report status Natasha, et al, What sort of time frame are you looking at to submit all reports? I understand that submitting everything can help operational efficiency. Tom From: Natasha Sachivichik [mailto:natasha.sachivichik@fairweather.com] Sesa#: Thursday, M~y ~7, 2009 ~ 1:14 AM To: Maunder, Thomas E (DOA) Cc: jack.a.rickner@e~oconmobil.com; Bill Penrose Subject: PTU well inspection project AOGCC report status 6/24/2009 ~ :?.~~ ~ i~ 9 i ~~~~ I am writing in regards to the yesterday°s phone conversation between you and Bill Penrose about the status o~ the Sundry reports for 9 wells inspection and remediation project performed by ExxonMobil. The field operations completed on April-29-2009. I would like to confirm that we are aware of the 30 days requirement to submit the re~orts and are currently working on generating these reports. Could you please let me know if you would like all 9 Sundry reports submitted at the same time. Thanks and regards, Natasha sach%v~cl~~f2 Senior Drilling Engineer Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 Direct:907-343-0405 Cell: 907-575-7156 6/24/2009 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, April 17, 2009 4:04 PM To: 'jack.a.rickner@exxonmobil.com' Cc: bill@fairweather.com; mike.barker@exxonmobii.com; michael.d.murrey@exxonmobil.com; DOA AOGCC Prudhoe Bay Subject: FW: West Staines 18-9-23 (169-120) Attachments: 18-09-232.JPG; 18-09-233.JPG ~ ~ 18-09-232.JPG 18-09-233.JPG Jack, et al, Thanks for the update. I agree with your plan forward. One of the goals of this investigative program was to determine what was actually buried at the various drilling sites. Determining that you cannot safely go forward at this time is a valid determination. It is also appropriate to insure that the well is protected until work can resume next year. Backfilling the excavation should provide the necessary protection to the well structure. Good luck with the remaining work. Tom Maunder, PE AOGCC -----Original Message----- From: jack.a.rickner@exxonmobil.com [mailto:jack.a.rickner@exxonmobil.com] Sent: Friday, April 17, 2009 3:52 PM To: Maunder, Thomas E (DOA) Cc: bill~fairweather.com; mike.barker@exxonmobil.com; michael.d.murreyCexxonmobil.com Subject: West Staines 18-9-23 Tom, wanted to provide you with some information on the West Staines 18-9-23 wellhead (see attached photos). Appears that we have a Grey wellhead with a number of Greylock clamps. We are continuing to excavate to reach the bottom of the wellhead. At this time, we are not prepared to tackle this wellhead with these types of clamps in order to determine if the wellhead is under pressure. The crew will continue to excavate until they get to the bottom of the wellhead. The crew will then obtain all the necessary measurements, sizes, ID plate information, and photographs so that over the summer we can obtain the necessary equipment to safely address this wellhead next winter. Once we obtain the necessary information and determine what we have, we will be able to develop a procedure that will enable us to conduct the anticipated well remediation work safely. I propose that once we have the information, we will backfill the site and move on to the PTU-4 completing the remaining PTU-2 work on the way. The crew has not found any indication that the well has leaked fluids, and it is not leaking any gas. If that changes as they excavate, I will let you know. We will complete form 10-404 for this well and include photos and an explanation of our findings. If you wish to discuss this approach or have alternative options, please let me know, otherwise we will proceed as outlined above. It is my understanding that the inspection team has notified the field inspectors of our intent to move to the PTU-4 on Saturday or Sunday. We are making good progress and hope to complete the remaining wells as scheduled for this winter. Regards, Jack 1 � 'µr , , . ~~ .. ,~ ,~ ~~ ~°~~,,., a~ t~;~ , ~ s .~ ~ ~ ~ ~. ~~ ,~ . ~ ~ ~~ ~ y .. " .. d.r,T ~ ,~ ~.:,..' _ ~; `~~h'~+~ ~~ ~ , ' . .~. ~F ~ ~ i~ " ,., ~. . ~ _ ~.~ ~ . ..,: 1J- ~r?!~ ` ° ~ ~ `ti s.~4 i ., - ~ ' _ ~ '. r . ;~°~.. : . .~» 5 ..~ _ ~~ ~ .~;' ~°~ ~ M~ T~_ a~, ~.. ~ ~ ~- , ~ ~ " r . . . - x~ ~ ~^.~~ . . " ~~ ..~. ~ ~ ` SS~~~~y ^ ~`°i 3~ ~ ,~ C : ~ }.F Y r - x ~ ~,,~, ,, . ~,? k~j . ~ , , , _ '';~ .. ~ .~ ~ ~~ ~ ,, „ ?, - ,~; , ~: ~ ~~. 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""~ ~ , " a. ,. • ~ i, ~ ~ ` v~~+i's Maunder, Thorraas E (DOA) From: Maunder, Thomas E(DOA) ~~ q,-- ~~-(~ Sent: Monday, March 23, 2009 10:14 AM To: jack.a.rickner@exxonmobil.com Cc: michael.d.murrey@exxonmobil.com; rob.g.dragnich@exxonmobil.com; mike.barker@exxonmobil.com Subject: RE: Wellhead Inspection Program Jack, et al, Following up on our conversation, it appears that options 1 and 2 should not present major issues. I concur that it is not desirable to have an open excavation. It is certainly possible that an excavation would collect melt water and what rain might fall. For this case, if you equip the well so that it can be monitored and then rebury some portion, this does not seem dissimilar to how the well structures have been for 20 - 30 years. I think that your finding the A section valve still functional after all these years should give some confidence that the damage risk from reburial is likely low. The final determination will be Exxon's based on the conditions determined for each well. Call or message with any questions. Tom Maunder, PE AOGCC -----Original Message----- From: jack.a.ricknerCexxonmobil.com [mailto:jack.a.ricknerC~e~onmobil.com] Sent: Sunday, March 22, 2009 4:33 PM To: Maunder, Thomas E (DOA) Cc: michael.d.murreyCexxonmobil.com; rob.g.dragnich@exxonmobil.com; mike.barker@exxonmobil.com Subject: RE: Wellhead Inspection Program Tom, we have a couple of concerns. From a safety standpoint, we would prefer not to leave an open excavation. And we are not sure if an open excavation would collect and retain water during the summer and then freeze as the temperatures cool. Not sure how this might impact tubing and needle valves through time. At this point, we think that we have three scenarios. (1} The wellhead basically at or above ground/pad level. (2) the wellhead just at or slightly below pad level. (3) the wellhead below at perhaps 3-4 feet below pad/ground level. If the well head is above the normal grade of the well pad, we would install the new gate valve(s), flange with 1/2" NPT threads, needle valve(s), and plug(s) in the end of the needle valve(s). That would allow us to read pressures in the summer time with relative ease. If the wellhead sections are just slightly below the pad level, we would like to leave the wellhead exposed and the valve(s) in place, flanged with needle valve(s) and plug(s) as above. There might be a slight dip in the surface of the pad but not significant. If the wellhead is some depth below grade (perhaps 3-4 feet), we have a number of options. It is this situation that I would like to discuss. We could: As proposed in our curren procesures, install new 3" gate valves (left in open positionj, flange with lj2" needle valve (left in open position), install 3/8" stainless tubing to the surface and have a second needle valve present so that pressures could be read (needle valve left closed, gauge removed and plug inserted in needle valve opening). The tubing could be banded to the wellhead and to the above ground marker. 1 we could install ~he new ga~e valve (lefc in closed position), flange, wich 1/2" needle valve and a plug. After obtaining pressure reading, bury the gate valve(s) until the next time pressure readings are required. Again, an excavator would be required to gain access to the valves. Could leave the wellhead exposed with the walls of the excavated cellar sloped back at a shallow angle that would form more of a ramped walk way down to the wellhead. The valves could then be exposed for easy access. Valve handles could be chained or removed for security. The hole might resemble a depression that could be walked into and out of rather than a hole. The excavated area could be left open and return to at a later date to install a more conventional cellar if necessary. Valves installed and chained as above. If we found a well that did happen to have significant pressure that did not bleed off quickly, we would shut in well and contact our engineering group to decide on appropriate action including how to leave the well and confer with AOGCC. But on wellhead with no pressure or pressure that is quickly bled off, there are some concerns with leaving an open excavation as there are to leaving exposed wellhead sections, needle valves (with possible pressure that may build back with time), and marker posts. Would appreciate your views and input. Mike has discussed these options with our subject mater expert and with wellhead suppliers in Anchorage including Dave Craft with Cameron and Kevin Hite/Alan Mc Arthur with FMC. Mike, have I left out other options or would you like to add anything? Tom, as you know, we plan to remove the wellhead on the J-1 this winter and return to the area next winter to address the issues at PTU-4, west Staines #2, and the West Staines 18-9-23. The closure options for these three may not be as important as the others since we are scheduled to return and work on these. Would appreciate any insight you may wish to share. Regards, Jack Jack A. Rickner Pt. Thomson well Inspection & Remediation Project 907-564-3783 281-217-4350 Thomas E jack.a.ricknerQexxonmobil.com Subject RE: Wellhead Inspection Program Hi Jack, I am in for a bit today. My preference would not to have valves buried nowever l do realize tnere is also a risk about surface as well. What are your thoughts? Tom -----Original Message----- From: jack.a.ricknerCexxonmobil.com [mailto:jack.a.ricknerC~exxonmobil.com] "Maunder, 2 Sent: Sacurday; ~arch 21; 2009 3:~1 Pi~[ To: Maunder, Thomas E (DOA) Subject: Wellhead Inspec~ion Program Tom, would you be available Monday morning to discuss a question regarding ExxonMobil's Pt. Thomson nine well inspection and remediation program. If available, please phone me at either of the numbers below. I am only a few minutes from you office and would not take more than 30 minutes of your time. I would like to discuss the question of how to leave the wellheads, especially the question regarding valving arrangements (valves above grade to facilitate periodic checking of well pressures versus valves below grade and buried in gravel) If you are not available due to time constraints, please call and let me know. I'm scheduled to fly to Deadhorse Monday after lunch for Emergency Response Training and will not be available until Thursday. Your insight to this question would be appreciated. Regards, Jack Jack A. Rickner Pt. Thomson Well Inspection & Remediation Project 907-564-3783 281-217-4350 3 ~'~~'~ ~ ~ ~ ~ ~~ ~ ,..~~~ ~l ~ ~ ..,..,..., . ~ ~ ALASS.~ ~IL A~TD G~S CO1~S~RQATIOI~T CO1~II~IISSIOI~T Craig Haymes Alaska Production Manager E~onMobil Production Company PO Box 196601 Anchorage AK 99519-6601 Re: Exploration Well, West Staines St. 18-9-23 Sundry Number: 309-081 Dear Mr. Haymes: SARAH PALIN, GOVERNOR 333 W. 7thAVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As noted in the Inspection Procedure document subrrutte~ with the application the status of this well according to the official AOGCG records is P&A, although as the Commission pointed out in previous conespondence this is one of several wells so classified that appear not to meet all of the applicable regulatory requirements for plugged and abandoned wells. We appreciate your inspectian efforts as desc~bed in the application. When providing notice for a representative of the Commission ta witness any required test, contact the Cotnmission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.Q5.080, within 20 days after written notice of this decision, or such further time as the Cammission grants for good cause shown, a person affected by it may file with the Comrnission 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 ne~ct working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Comnussion decision to Superior Court unless rehearing has been requested. Sincerely, %~ Daniel T. Seartiount, Jr. 7 Chair DATED this /" day of March, 2009 Encl. ~~' h ~~~~~ J~~ ~a ~~ "' ~ltp'~ STATE OF ALASKA ~ 3-3-p9 `b~ ~ ALA~KA OIL AND GAS CONSERVATION COMMISSI~~.S `~ ~~ p~~~,t~~. ,~,b `~' APPLICATION FOR SUNDRY APP R~V~-I~S~ ~n aac: ~~ ~Rn Al~s '~ ~ ~s ~ot~~. Commission 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ^ Perforate ^ aiver^ OtherO Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ~ Site Inspection Change approved program^ Pull Tubing ^ Pertorate New Pool ~ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Weli Class: 5. Permit to Drill Number: EuuonMobil Oii Corporation Development ~ Exploratory ~ 169-120 ~ 3. Address: Stratigraphic ~ Service ~ 6. API Number: PO Box 196601 Anchorage, AK 99519-6601 50-089-20001 ~ 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: NIA Spacing Exception Required? Yes ^ No ^ West Staines State 18-9-23 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 28380 - 63 ~ Wildcat ~~• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13,171 • 13,170 SurFace Surface See Attached None Casing Length Size MD TVD Burst Collapse Structural 32 30" 67 67 N/A NIA Conductor 268 20" 303 303 1530 520 Surface 2070 13 3/8" 2105 2105 3090 1540 Intermediate N/A NIA NIA N/A N/A N/A Production 10052 9 5I8" 10087 10087 7510/8150 5600/7100 Liner 3156 7" 13004 13004 8600 5890 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NIA N/A NIA N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft): NIA NIA 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ~ Exploratory ~ Development ^ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: March 1, 2009 Oil ~ Gas ^ Plugged ^ Abandoned Q 17.VerbalApproval: 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 Mike Barker I Jack Rickner Printed Name Craig ~ Haymes Title Alaska Production Manager Signature Phone (907) 564-3617/(907) 564-3783 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~~ ''U ~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~ Other: ~ '~~ ~ ~`~ ~ -~ ~ Tx''~ ~'° FtY,~n: . c^ 1~~~,i Subsequent Form Required: ~~ l~I p`~~ ~~ C'~M~'~~ ~~~ ~~~` ~~G~ V`~~~~CU~~~O~ ~ ti..~C ~~M~~~~t-~~i~ C5c ~-~~S ~Q~'~~ APPROVED BY / / / Approved by: COMMISSIONER ,~ I I~ r; C Date: ~, ~/ ~ ~n} < ~~ ~ :E ~ ; , ...... , _ ..,., . ..,.,.,,,.. ,,.,, ~ ~,., t , < ExxonMobil Production Company P. O. Box 196601 P,nchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimile February 25, 2009 Mr. Dan Sear~ount Chairman Alaska Oil and Gas Conservation Commission 333 West 7t'' Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry application t~ Inspect ExxonMobil Oil Corporation West Staines State 18-9-23 PTD No. 169-120 Dear Commissioner Seamount: Craig A. Haymes Alaska Production Man ~~~~~~~ Jt. interest U.S. `~~~ ~ ~ ~~~~ ?~,~C'~ sciC'~ (~P~ ~f 47~ ~/lJ~iaSt C~(i'1(71i~Sf~`iP ~ E~o n M o b i I A~~~°«~~ Production ExxonMvbil Oil Corporation hereby submits an Application for Sundry Approval to perform a surface inspection for additional remediation work ihcluding removing well fluids and the wellhead on the subject welL This inspection will be performed to verify the well integrity by checking for and recording pressures in the 9-5/8" casing and th~ 9-5/8 x 13-3/8" annulus. The inspection work will be performed during the winter of 2008-09 to provide information that will be used in detailed planning for removing of well fluids and the wellhead during the winter of 2009-10. Please find enclosed the following information: 1) Form 10-403 Application for Sundry Approval 2) Wellbore Schematic 3) Inspection Procedure 4) Phota of the Wellhead/Abandonment Marker at Present If you have any questions or require additional information, please contact Mike Barker at 564-3617 or Jack Rickner at 564-3783. Sincerely, , f~ ~ ~ CpH:~aa Attachments A Division of Exxon Mobil Corporation Well schematic drawn June 29~h, 2007 by ExxonMobil Oil Corporotion Jesse Mohrbacher, Fairweather E& P lnlest SGaine.x 5~..1.8-9.,23 Services Inc Well Schematic , . API #: 50-089-20001 PTD ;~: 169-120 'J~;ellhead A section in place :rith blind flanqe on top 30 structural set at 32' ~r,_~~ ;- . RK6 = 63' hASL = 15.5' above bradenhead ,~ . 140 sx of cement used c _ _-,. Diesel in 9-5,8' casing from 0'-10' ... . ~* 6P in 9-5,8' at 150 ovith 50 Sx fondu to 10'. diesel Diesel in 13-3;8 x 9-5,'8`"annulus from 1.~72'to -` o o P surface ~ °(; ~ ~ :F on to Diesel 20 ~ 3~3'. cemented to surface k ) ;; G~iesei in 9-5%8` casing from 150 - 1.350't 13-3~~~ D'~~' Tool at 1 3$~~ Cement in 13-3 8 r, 9-~ 8 annulus frnrn ~ 4'2 - 2 ~0~ , EP in 9-518" at 2.000' riith 25 sx on top 13-318~ 61#. H-4D at 2 10~ 13-3?B° cemented ~vith 700 sx G in stage 1 1200 sx tondu flyash ~vith 30°o salt through DV Tool for stage 2. g- uood retums at surface PPg mud TOC in 9-51$' casing at 9.838' Top of 7 liner at 9.&38 Retainer at 9.898 ~ 9-5~8` at 1~J D8" ~ . ,~~ . ~: :~ _, ` ; 9-~!8-: 2.409` of 47~. Soo-95 " ~ ~,'~ : 7.70D' of ~3# Soo-95 '~ ~~ = , Cemented dvith A20 sx G i h 9 10 020' 4 f d ' ~ av . . sp . squeeze t Perforations 9.9 8 - ;~ ;~ 100 sx class G through retainer TOC at 10 422 -: . : ~" f: -' , . ~ ~ 30 sx plug on retainer Retain,r a? 10 ~'2~ ~ '` ~r ~'~ ~~ '' Perforations 10.570' - 1~.590'. A spf. squeezed with 110 , , cu ft. cement T~C at 11 450 ,%~ ~`~ : A~ :' *" 34 sx plug placed on top of BPJRetainer '~ BP at 11.49T ~ ~'~ ~ Perforations 11.650' - 11.675'. A spf .. ~ . Perforations 11 675 - 11 715' 4spf BP at 11.743' y s s s s 30 Sx cement plug from s 12.350' - 12409' s s Retainer at 12.409 3 s s Perforations 12 512' - 12.795' squeezed with 120 sx s s s EZ drill BP at 12.869' i i T liner at 13.004 i 6 and 5-15.+16 hole to 13.329' Perforations 11 763 - 11 782' 4spf ~ ~,.`.; t ~ .`~- ,,,~, f~~ Ferforations 12.512' - 12.525. 4spf Perforations 12.525' - 12 53T. 4spf '~~: °~ Perforations 12.630 - 12.650' ~1spf '='" . Perforations 1268U' - 12 70D' 4spt ~'~ ~~ ~" Perforations 12780' - 12 795' 4spf r 2 sx cement on top of EZ drill ,{: , s: : Cement plug in T from 12.900' - 13.078` •. ~ i ^'~ . -~~,~ ~`• ~` 2 032.8'. 29#. Soo-9~ r,~. ~~ 1.100.6'. 29#. 500-9~ s ~ 3.156` total evith hanger. shoe and collar s ~ Cemented ~mvith 400 sx G Squeezed 4 times ti+:ith 5~12 sx G total Ex~conMobil Oil Corporation West Staines St. 18-9-23 API #: 50-089-20001 APTD #: 169-120 inspection Procedure Backqround Well Information The West Staines # 18-9-23 well was drilled in 1970. The well is abandoned, but requires removal of some well fluids and the wellhead to at least three feet below ground level consistent with current AOGCC regulations. Prior to removing the well fluids and wellheads, an inspection to verify the well's condition is desired. The 9-5/8", casing has a diesel cap at 0'-10', a cement plug set at 10'-150' on top of a bridge plug, Below the bridge plug there is diesel from 150' to 1,950' on top of another cement plug from 1,950'to 2,000' and another bridge plug. The 9-5/8" x 13-3/8" annulus contains diesel from surface to approximately 1,472'. The well schematic is attached to this procedure. The well files do not include any information on the wellhead type and configuration. The reservoir section of the well is effectively isolated; therefore it is unlikely that high pressure will be encountered during the inspection, However, contingency plans and procedures will be included in the detailed inspection procedure to safely manage any well pressure encountered. The inspection will include the following steps: • General inspection of the well location to the extent possible (winter operations) • Excavation of gravel covering the wellhead and cellar • Visual inspection as to the condition of the wellhead • Verification of the well integrity by checking for and recording pressures in the 9-5/8" casing and the 9-5/8 x 13-3/8" annulus o PerForm diagnostic test if pressure is found (i.e., trapped vs sustained pressure) o Identify contents of the casing and annulus by attempting to get a sample • Clean up of location and leave well in a safe and secure condition The proposed inspection will be supported by on-site equipment and materials such as excavator, camp, transportation, fuel and other essential elements of remote operations. The following well inspection program is planned: ~ 1. Insure all necessary permits and applications are in place. Notify AOGCC at least 10 days before operations begin. 2. Mobilize all personnel and equipment to the West Staines # 18-9-23 location. 3. Observe and record any signs of leaks in the area surrounding the well. Take photographs clearly showing the condition of the surrounding location. A detailed report documenting any found contamination will be prepared. 4. Heat the gravel around the wellhead. 5. Excavate gravel covering the well and cellar. Ensure access to all side outlets on wellhead sections. Monitor excavation with a four-gas monitor. 6. Install wellhead shelter, and rig up indirect fired hot air heater. Apply heat to wellhead shelter. Pump or vacuum the cellar dry when thawed. 7. Visually inspect the condition of wellhead side outlets valves, bull plugs, needle valves, test/grease ports, lock down screws, etc. Take photographs clearly showing the condition of the wellhead as found. Document any areas of concern. 8. Check pressures on the 9-5/8" casing and the 9-5/8" x 13-3/8" annulus. This may require the installation of needle valves and wellhead side out valves to facilitate recording and bleeding off pressures. In addition, operations such as removing VR plugs, hot tapping, and gate valve milling may be required to verify any well pressure. 9. If pressure is observed, then perForm diagnostic testing to determine if the pressure is sustained casing pressure or trapped pressure. Record pressure bleed down and build up. In addition, record the fluid type and volume. Take fluid samples for possible analysis. 10. Take photographs clearly showing the condition of the wellhead as left. 11. Ensure well is safe and secure. Chain 8~ lock close any valves above ground level. 12. Clean up location. Remove any fluid from the well for proper disposal. Take photographs clearly showing the condition of the location as left. 13. Fill out inspection report and file a Report of Sundry Well Operations (Form 10-404). 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C,S,~. y3. r ~E,i ~ ,i.: ~..F . ,.r., ' g,l S-~ i r~' '•.2.~ r~. . ~~r~ }~ ~1..tt ~ ';» ,r~y~ .ar ~'~ .:~:xt t .~-. r- .y.~M. ~ ~i~ i`"^` . r -r+ t: ir s. . .; ~. " ;a ~, ~ ~:,Y :l.;.. , ~ ~ ' T z. ~:x ~,hJ '.` ~afr-f a~ ~ ~v. - .,b:,,, ~~ r ~ ~~,•~ ' :i r~x~•~ N. , `~,r~ ~ :l~ ~~ .. .-'x • . Yi ~ - . . ~. A _ ~ }~ i' M+'u '"~'~,t'A~ . ..~ ~r M~ .,-c~ ~.~ -.=Y . ~>+''ar ~s~ ' ~,. ~`.: y.~C~..~ ~.a;~~'.M ~ ~f? + t ..'. r M1r w. t y, sn r.. ~' . , _ 'T ;~ :;X` ..),"{', • , ~ ``•c r ~'~n, ~ ...., . . .~*.. _ ~.r~.,. ... 'J'`+ - . _ !~}:1.: ~ . ~f ~ ~ . ... . ~. . ,.. .. . .... ' c`.. ~ _ ~'....~ .. ~ . .wi`. - t~ y :y~ ta'v' ~..." ~ ._ c~ ~_ .:r~. . ~,.- - - ~ ~r~~ ;'. _ .., ,. . _ . . . , . , . , f ,, ~. _.. :.Y _ .. 1'11 a d� L UIT�-0, ®r 031 M,7kl-rLT-®% CCDi S0A0% January 29, 2009 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 5975 William Pecor ExxonMobil Production Company PO Box 199610 Anchorage AK 99519-6601 �,, c.` \ 2 C, C-) SARAH PAL1N, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut -In Well Information SCAIANK Dear Mr. Pecor: Enclosed are the Alaska Oil and Gas Conservation Commission's revised regulations regarding suspended wells (i.e., 20 AAC 25.110). Also enclosed are lists of suspended long-term shut-in and Point Thomson heritage wells operated by ExxonMobil Production Company or your predecessor companies. For each list, please verify the information for each well and provide any corrections by April 1, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with Jim Regg at 907-793-1236 or jim.regg@alaska.gov. If you have any questions regarding this notice, please contact Tom Maunder at 907-793- 1250 or tom.maunder@alaska.gov. Sincerely, Cathy P. Foerster Commissioner Enclosures s U.S. Postal Service, CERTIFIED MAIL, RECEIPT ' (Domestic Alai/ Only; No Insurance Coverage Provided) For delivery information visit our website at www.usps.com 3 ON2111110d Fee■� 0. r WAftunwill Ra**" Here 1 ■ (EmbTOW Powp,' t t1 01/30/2009 CWilliam �- • ExxonMobil Production• o#rft-PW08'W=Z67* PO Box 199610 Anchorage AK 99519-6601 • rtrvcr,o u� ,T-,,, ciions E Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. ■ Print your name and address on the reverse so that we can return the card to you. ■ Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to: William Pecor ExxonMobil Production Co PO Box 199610 Anchorage AK 99519-6601 ❑ Agent r ❑ Addressee B. eived7TPted Name) C. D e of elivery D. Is delivery ad ftss different from item 11 LJ'Ye' If YES, enter delivery address below: ❑ No 3. Sice Type lirertified Mail ❑ Registered ❑ Express Mail I*eturn Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 2. Article Number (transfer from service label) 7005 _18_2 0 0001 2499 5975 PS Form 3811, February 2004 Domestic Return Receipt 102595-02-M-1540 Operator Suspended and Shut In Wens PENNZOIL CO Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Leasc(s).................. . ................ 'EXPLORATORY 166-064-0 50-831-10002-00-00 STARICHKOF ST 1 SUSP 4/1/1967 843 FNL 1841 FEL Sec 33 T 3 S R 15 W SM ADL0018790 lf'ednesdny, Jnnnnry 14,20 0 9 Operator MOBIL OIL CORP Field Permit API Number Well Name KUPARUK RIVER 181-035-0 50-029-20573-00-00 KUPARUK 28243 1 Wednesdgv, Jnnstary 14, 2009 Suspended and Shut In WmHc., Current Date of Status Status SurfaceLocation .................................................... Lease(s)................................... SUSP 5/29/1981 470 FSL 605 FWL Sec 17 T 11 N R 11 E UM ADL0028243 ExxonMobil Pt. Thomson Heritage Wells Identified May 18, 2007 in Commission Letter to Craig Haymes API WELL # PTD # FPWRamw Wei Name Field See Twp NIS Rng W/E PM Lease(s) 50-089-20001- MOBIL OIL W STAINES PT I � f i 00-00 1691200 CORP ST 18-09-23 THOMSON 18 j 9 j N 23 E U j ADL 0028380 ` 50-089-20004- MOBIL OIL W STAINES 'EXPLORAT 00-00 _ 1750020 CORP ST 2 PT ORY 25 9 j N i 22 j r__ E i U ADL 002837 50-089-20005- EXXON THOMSON PT 00-00 1760850 CORP UNIT 1 THOMSON 321 10 1 N { 23 E i U i ADL 0047560 — — PT 50-089-20006 00-00 7064 170 7064 EXXON CORP THOMSON UNIT 2 PT THOMSON 3 9 + N 22 ! I E I U ! ADL 0047567 ._...___.. .. PT 50-089-20007- EXXON CORP THOMSON UNIT PT THOMSON I 34 10 N 23 E U ADL 0047558, ADL 0047559 00-00 1780050 3 — 50-089-20008- MOBIL OIL STAINES PT 00-00 1790010 CORP RIV ST 1 THOMSON 17 9 N 24 E j U ADL 0047573 PT 50-089-20009- 00-00 1790800 EXXON CORP THOMSON UNIT 4 PT THOMSON 32 10 N 22 E j�U 14 ADL 0047563 50-089-20011- EXXON ALASKA ST PT 00-00 1800460 CORP C1 THOMSON 14 9 N 23 E U I ADL 0028382 I 50-179-20007- 00-00 1830450 EXXON CORP ALASKA ST J 1 PT THOMSON 23N i i 22 22 � E i U a -` ADL 0344033 a 20 AAC 25.110. 'i uso:nded "eNhs (a) If allowed under 20 AAC 21�.1_O>, the commission «-ill, upon application by the operator under (b) of this section, approve the suspension of a well if (1) the well (A) encounters hydrocarbons of sufficient quality and quantity to indicate that the well is capable of producing in paying quantities, as reasonably demonstrated by well tests or interpretive formation evaluation data; for purposes of this paragraph, "paying quantities" means quantities sufficient to yield a return in excess of operating costs; (B) is a candidate for redrilling; (C) has potential value as a service well; or (D) is located on a pad or platform with active producing or service wells; and (2) the operator justifies to the commission's satisfaction why the well should not be abandoned, and, if the well is not completed, why the well should not be completed; sufficient reasons include the (A) unavailability of surface production or transportation facilities; (B) imprudence of security maintenance of a completed well in a shut-in status; (C) need for pool delineation and evaluation to determine the prudence of pool development. (b) An Application for Sundry Approvals (Form 10-403) must be submitted to and approved by the commission before plugging operations are begun in a well for which suspension is proposed, except that oral approval may be obtained from the commission if it is followed within three days by the submission of an Application for Sundry Approvals for final approval by the commission. Approval will be conditioned as necessary to protect freshwater and hydrocarbon resources. An Application for Sundry Approvals must include (1) the reason for suspending the well and information showing that the applicable criteria for suspension under (a) of this section have been met; and (2) a statement of proposed work, including (A) information on abnormally geo-pressured strata; (B) the manner of placement, kind, size, and location, by measured depth, of existing and proposed plugs; (C) plans for cementing, shooting, testing, and removing casing, (D) if the Application for Sundry Approvals is submitted after beginning worl:, the name of the representative of the commission who provided oral approval, and the date of the approval; and (E) other information pertinent to suspension of the well. (c) At the operator's request accompanying the submission, information submitted to show that the applicable criteria for well suspension under (a) of this section have been met will be kept confidential (1) for the period specified under AS 31.05.035 (c), if the information is described in 20 AAC 25.071(b) ; or (2) for the time that the information has value as a trade secret, if the information is not described in 20 AAC 25.071(b) but is determined by the commission to constitute a trade secret under AS 45.50.940 . (d) A well approved for suspension must be plugged in accordance with the requirements of 20 AAC 25.112, except that the requirements of 20 AAC 25.112(d) do not apply if (1) a wellhead is installed or the well is capped with a mechanical device to seal the opening; and (2) a bridge plug capped with 50 feet of cement or a continuous cement plug extending 200 feet within the interior casing string is placed at or above 300 feet below the surface; the commission will waive the requirement of this paragraph for a development well drilled from a pad or platform, if the commission determines that the level of activity on the pad or platform assures adequate surveillance of that development well. (e) Until a suspended well has been abandoned or re-entered, the operator shall maintain the integrity of the location, provide the commission with a well status report every five years, and clear the location in accordance with 20 AAC 25.170(a) (2) or (b) or with 20 AAC 25.172(c) (2) or (d), as applicable. History: Eff. 4/2/86, Register 97; am 11/7/99, Register 152 Authority: AS 31.05.030 ~~~~~~ ~t ~ _- , y~~~~~ ~~~~~.~~s~ie~~~r ~a~ ~~~~~r~r~i ~I~~kC~'~"~ ~~C~ ~~~ ~~{'~SG'i"V~iEOC' <oQ6't"Ffi'Y~~~S4l.7~ 33~3 t/li~st ?th ~v~~~ae, S~ite 1 ~0 ~c~~i~orage. l~BasEca 995f~~-3539 ~~~~~cl-~~~~~~~~~ ~ /7 e ~.., ;t t ~- ~ ~ Nf ~ " `i ~ `~, x~l ~~ ~. .~ M%~~ ~ ~ lo~~ ~~: ~t, ~°hor~sc~n ~i"~I~s - Plugging ar~d P~bandor~nlent '~~~ ~ ~ C~~~ G~t't~. ~~r~1~D "' . , r~fiCh4i~~~ ~ea~ Comr~aissioner Searnour~f: ~C~6~_ t~:~ Ir~ response to the Commission'~ December 7, 2007, lett~r to ~xxonMobil, attached are su o. ; m , ~ ~ • 5 9 • Site inspection sundry notices, Forrra 10-404 reporks and photos, are also attached for these , , West Staines No 18-9-23, and We are rnaking plans to conduct the inspectiora and remediation work described in ExxonMobil's letter of November 14, 2007, and the Commission's December 7 letter during the winter of 2008-`09. As you know, we submitted a Plan of Development for P~fJ to the Department of IVatural 64esources that ca~ls for drilling operations to be conducted during the winter of 2008-'09a Approval of this plan by DNR will afford the opportunity to conduct the well remediation work described in our November 14 letter in corjunction with that drilling pian. We share the Commission's desire to conduct the remediation work in a timely and date certain manr~er, but we vvould lik~ the oppor~unity to revisifi the timing of the remediai work if the drilling program does not proceed as currently planned. 1Ne believs there are operational safety and e~ciency factors that should be considered. P~ease r~ote the Staines River State #1 well is under sxtended confidentiaiity as provided ~nder ~S 31.:?5.035(d) ar~d 2C~ AAC 25.537(b). We have included its report as a separate, ~onfidential attachment. t!!Je again thank the Com~missiora for ~roviding clar~ty around the issues and for praviding adequate ~irr~e for ~xxon~/do~il to conaucfi a thorough and thoughtfiul r~view, ~iease feel ~ree ~c contaci me, Bill Pecor, or Rob ~ragnich i~ you have any ~ues#io~ns. ~incer~iy, ~.-, ~ `'~~• , ~~s.acs~r~:es~is ~ _~ ~. ~~y ~ ~i ~?I~~'?G~; 'i {3B?OCG~C~'d?i~~B!3S as'~~~~ ? ~~I~i;:<<. ~V^~~1~~~? ExxonMobil Production Cora P. O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimile March 17, 2008 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Pt. Thomson Wells — Plugging and Abandonment Dear Commissioner Seamount: Crai, aymes yo . Qyb Alaska Production Manager �7 Joint Interest U.S. 7&i V Y6 � 7-7, ab`a -7f' 5� /-79. ago EonMobil Production 1,WL0 /75. oat RECEIVED MM 19 x008 Alaska Oil & Gas Cons, Commissim Anchorage In response to the Commission's December 7, 2007, letter to ExxonMobil, attached are sundry notices requesting the Staines River State No. 1, Alaska State C-1, and Point Thomson Unit No.'s 1, 2, and 3 wells be reclassified from abandoned to suspended status. Site inspection sundry notices, Form 10-404 reports and photos, are also attached for these five wells and the Point Thomson No. 4, Alaska State J-1, West Staines No 18-9-23, and West Staines No. 2 wells. We are making plans to conduct the inspection and remediation work described in ExxonMobil's letter of November 14, 2007, and the Commission's December 7 letter during the winter of 2008-`09. As you know, we submitted a Plan of Development for PTU to the Department of Natural Resources that calls for drilling operations to be conducted during the winter of 2008-'09. Approval of this plan by DNR will afford the opportunity to conduct the well remediation work described in our November 14 letter in conjunction with that drilling plan. We share the Commission's desire to conduct the remediation work in a timely and date certain manner, but we would like the opportunity to revisit the timing of the remedial work if the drilling program does not proceed as currently planned. We believe there are operational safety and efficiency factors that should be considered. Please note the Staines River State #1 well is under extended confidentiality as provided under AS 31.05.035(d) and 20 AAC 25.537(b). We have included its report as a separate, confidential attachment. We again thank the Commission for providing clarity around the issues and for providing adequate time for ExxonMobil to conduct a thorough and thoughtful review. Please feel free to contact me, Bill Pecor, or Rob Dragnich if you have any questions. Sincerely, Attach ents cc: Mark Ireland, ConocoPhillips Vince LeMieux, Chevron ` CATANED A Division of Exxon Mobil Corporation SARAH PALIN, GOVERNOR 77���� AL1ASKA OIL AND GAS 333 W 7th AVENUE, SUITE 100 CONSERVATION COMMISSION fANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 December 7, 2007 Craig Haymes Alaska Production Manager ExxonMobil Production Company PO Box 196601 Anchorage, AK 99519 Re: Pt. Thomson Wells — Plugging and .Abandonment Dear Mr. Haymes, This is in response to your letter of November 14, 2007 responding to the Alaska Oil and Gas Conservation Commission's ("Commission") letter of May 18, 2007 regarding the condition of certain Pt. Thomson Unit wells. The schedule and plan for remedial work provided with your letter are acceptable subject to the following conditions: ExxonMobil will perform the proposed field work for the 2008 — 2009 winter operating season regardless of whether there are any concurrent drilling operations in the Pt. Thomson Unit. All of the diesel will be removed from the W. Staines State #18-9-23 (169-120) and W. Staines State #2 (175-002) wells. If any of the diesel cannot be removed, a Commission petroleum engineer or inspector shall determine whether the shallow wellbore plugs are competent, and ExxonMobil must take any reasonable actions the Commission determines are necessary. All current and future statutory and regulatory requirements and all applicable rules, orders, and permits of the Commission will be complied with unless a waiver to a specific requirement is timely and otherwise properly requested and granted by the Commission. To assist the Commission in ensuring that its files are complete and accurate, by March 31, 2008, please submit for each well a Form 10-404, a summary of the observations from the work performed last summer, and location photos. Finally, nothing above expressly or implicitly evidences the Commission's position with respect to the status of ExxonMobil or any other person as a current Pt. Thomson Unit operator, working interest owner, or lessee. If you have any questions, please call me at 793-1221 or Tom Maunder, PE at 793-1250. Sincerely, Cathy P. Foerster Commissioner ExxonMobil Production Comp P. O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimile November 14, 2007 Chairman John Norman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Pt. Thomson Wells — Plugging and Abandonment Dear Chairman Norman: Crain a. rhes Alaska Production Manager Joint Interest U.S. E�onMobil Production RECEIVED NOV 14 2007 Alaska Oil & Gas Cons. Commission Anchorage We are providing this letter in response to the Commission's May 18, 2007, letter to ExxonMobil regarding Point Thomson area wells that are classified as plugged and abandoned. ExxonMobil, as Operator and on behalf of the working interest owners of nine of the listed Point Thomson area exploratory wells identified in the Commission's letter, has undertaken an extensive review of the current physical status of each of these wells. (As Operator of the remaining well, BP will respond directly to the Commission on it.) This work included reviewing ExxonMobil's and the Commission's well files, including confidential Commission files for one well, conducting on-site inspections to assess the physical integrity of each well site, and conducting a joint owner review of each well by technical experts. We are pleased to report that none of these activities have identified any imminent safety or environmental threat conditions from the wells. Attached are photos taken during the on-site inspections. The extensive reviews provide the basis for this response to the Commission's letter. While we believe the wells met AOGCC requirements when the prior P&A actions were taken and are safe in their current condition, we recognize that performing certain remedial work can further reduce any risk of an incident that may occur in the future. With that in mind, we have developed the attached schedule and plan to conduct remedial work on the wells. If the Commission concurs with this work program, ExxonMobil will prepare the appropriate sundry notices and begin to carry out the actions. As described in this letter and accompanying attachment, the plan contemplates conducting remedial work on certain wells in the near future and reclassifying the remaining wells to a suspended status. The wells with planned near term remedial work do not appear to have future utility while the wells identified for reclassification are capable of producing in paying quantities. We believe it would be premature to conduct work on these latter wells that may make it more difficult to utilize them in future development operations. There are other existing suspended wells in the Point Thomson Unit, and we view this action as consistent with current circumstances. We understand that reclassification will carry an obligation to abandon the wells in the future in compliance with regulatory requirements. ORIGINAL. A Division of Exxon Mobil Corporation Commissioner John Norman - 2 - November 14, 2007 Please note the plan calls for conducting the most intensive phase of field work in conjunction with the first winter drilling season of currently -planned Point Thomson Operations drilling, which is proposed to occur during the winter of 2008-09. We believe conducting this work in conjunction with this drilling program will offer significant operational safety and efficiency benefits. In the event the drilling program does not progress as proposed, we will work with the Commission to determine appropriate timing for the remedial work. We believe this plan responds to the Commission's request that ExxonMobil provide information and documentation to demonstrate that the wells meet the requirements for plugging and abandonment or provide a schedule and plan for bringing these wells into compliance and should address any concerns that may exist regarding compliance with AOGCC requirements for plugging and abandonment. As the Commission is aware, a number of changes have occurred in the requirements for plugging and abandonment of wells over the past 40 or so years. We believe these changes were generally sound and resulted in safer operations. In some cases, however, the changes created specific conflicts for operators, e.g., the 1986 regulations required installing marker posts while the 1999 regulations prohibited such posts (unless the land owner requests them). The planned work program will address these matters on the wells planned for near-term remedial work and through future actions on the remaining wells. Other regulatory changes involving placement of cement plugs and retainers, cementing of casing stubs, or requirements of fluids left in the well are more subtle. In general, it would be unnecessary and impractical to later attempt to modify many of these items, particularly those that exist at deeper depths in the wells. In the interest of transparency and clarity, we will address any variances or deviations from current regulations in our sundry notices filed with the Commission. We appreciate the Commission's help in providing clarity around the issues and allowing adequate time for ExxonMobil to conduct a through and thoughtful review. We look forward to your concurrence so we can proceed with the outlined work plans. Please feel free to contact me, Bill Pecor at 564-3766, or Rob Dragnich at 564-3711 if you have any questions. Sincerely, j CA :rgd/jpc Attachments xc: Cmmissioner Cathy Foerster - AOGCC Commissioner Daniel T. Seamount - AOGCC Kevin Brown, BP Mark Ireland, ConocoPhillips Vince LeMieux, Chevron ORIGINAL Remedial Action Program Point Thomson Wells — Plugging and Abandonment Wells Affected Actions Timing PTU #1, PTU #2, PTU #3, - Conduct additional integrity investigations to include: - Conduct work during winter of 2008-09 PTU #4, Alaska State C-1, + Removal of gravel from around wellheads Staines River State #1, W. + Conduct visual inspection Staines State #18-9-23, W. + Install valves and pressure gauges Staines State #2, Alaska + Check for pressure in casing and all annuli State J-1 + Conduct further diagnostics as appropriate PTU #4 - Remove marker post - Conduct work in conjunction with first - Remove wellhead and casing to lower than 3' below year of Point Thomson delineation ground level drilling planned for winter of 2008-09 - Verify integrity of surface plug + Repair or replace as necessary - Remove near -surface arctic pack from 2 annuli and set cement plugs in annuli using top job techniques (plugs to be at least 50' long) - Install marker plate - Remove cellar - Conduct general location cleanup, and request final site clearance W. Staines State #18-9-23 - Remove marker post - Conduct work in conjunction with first - Remove diesel above surface plug year of Point Thomson delineation - Remove wellhead and casing to lower than 3' below drilling planned for winter of 2008-09 ground level - Verify integrity of surface plug + Repair or replace as necessary - Remove near -surface diesel from annulus and set cement plug in annulus using top job techniques (plug to be at least 50' long) - Install marker plate - Remove cellar - Conduct general location cleanup, and request final site clearance - 1 - W. Staines State #2 - Remove marker post - Conduct work in conjunction with first - Remove wellhead and casing to lower than 3' below year of Point Thomson delineation ground level drilling planned for winter of 2008-09 - Verify integrity of surface plug + Repair or replace as necessary - Remove near -surface arctic pack from annulus and set cement plug in annulus using top job techniques (plug to be at least 50' long) - Install marker plate - Remove cellar - Conduct general location cleanup, and request final site clearance Alaska State J-1 - Remove marker post - Conduct work in conjunction with first - Remove wellhead and casing to lower than 3' below year of Point Thomson delineation ground level drilling planned for winter of 2008-09 - Verify integrity of surface plug + Repair or replace as necessary - Install marker plate - Remove cellar Conduct general location cleanup, and request final site clearance PTU #1 - File sundry notice to change well classification from - Submit sundry notice within 90 days of abandoned to suspended AOGCC concurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winter 2008-09 inspections PTU #2 - File sundry notice to change well classification from - Submit sundry notice within 90 days of abandoned to suspended AOGCC concurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winter 2008-09 inspections PTU #3 - File sundry notice to change well classification from - Submit sundry notice within 90 days of abandoned to suspended AOGCC concurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winter 2008-09 inspections -2- Staines River State #1 - File sundry notice to change well classification from - Submit sundry notice within 90 days of abandoned to suspended AOGCC concurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winter 2008-09 inspections Alaska State C-1 - File sundry notice to change well classification from - Submit sundry notice within 90 days of abandoned to suspended AOGCC concurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winter 2008-09 inspections -3- Point Thomson Area Drillsite Photos July 23, 2007 and August 22, 2007 Point Thomson Unit No. 1 Point Thomson Unit No. 1 Point Thomson Unit No. 1 Point Thomson Unit No. 1 Point Thomson Unit No. 2 Point Thomson Unit No. 2 s _,, - ��'�,*p •"'. bra -<(� r►[`�. '. �j� +` .- ''c �.`f.', ��i +.� /. �►.� '.,s "�'. j -' �3 � ��'(»� is irC� � t "~'' � ?r a •! 'r�, r :' - " `' t> �� �'" ' �` L �. �� .�` . 1ti�.► .'i, .A � _• � �'' �i` ` ` of �' - /'a'..1�. �. . '•i �f ` °r 'tr ✓�.-�.._ ' sii' < . f • i!3<� "\ .rr .,S : J2`<` - •'-`.r . 11►`� h Point Thomson Unit No. 2 Point Thomson Unit No. 3 t Point Thomson Unit No. 3 � � � *is �"'t d1r`t D� f�� �" :R. 1'� ' ci�' '4``•y' ��:,�y.f/�r"- • �: �'•f.`'� .�"�,.. '�yF"' f � 3V r ,'� � f. a �• �. 2 i'',���►I j� � �`�•� � T ! (. t _ � - ��^•' J � of r'A. "jig. < ',� 4� � ✓:y �` .. �: _•` � (" it �t� � ` j'.1{ '� .c. *� A � � ;tl ' k . � r o t V. �' 3., b er " � ;�.. �'L ,� � sysy pp �.• �.� ,, tyle ,y�� '.. .,. )Tar �' '•. � Point Thomson Unit No. 4 Point Thomson Unit No. 4 m • vv 461 . 4ir 1:0 u*, ow, VO 1p, 71 Ar, ol Jp 7!o to v. p p - f '<• " .. •_Y•� 4 •�i •. t,- ,. }w ♦ mow. Staines River State #1 Staines River State #1 '�!' ;fit l..A. ... � � a",�•_ , b .�'� ic."��,� :�'. 'f�.I•��s, " � rater + 44 .-.*I . - .. .a -a... '.i.E.,�. X t s •4 '.►.1 [7 .ss• r ` t • ` _ „� • rte} Y i ` .. 1.F sA u o • - 1 -i14 I r ' �. • y6 a �` t f O�4'�t + T Al i 'i At • �, `rr s �t 'S., '. �-mit w - s .. +{f� .7 •. i,' � r . .'._ ,t }mss s�+ � ' - , � �y to .»�,;, .., ,, 's.� ,rw, . ... �a� --...._ pay �'� R .- West Staines State #2 West Staines State #2 :.T .t t If J ''�'t` ��sy�j,,�� n :;1R`�• 4t`r�x.,� h {•'r�is,�ay. •ti. _ moi,. ,' � ,� y�.�i+{. \ .tom .� � .,,L�ti.•y�.i•:�-� �.� t �.�... a.� h'>!!%�!!lr 1 A ' ' i' A,, L ., Y Alaska State J-1 Alaska State J-1 •,�y �-0 � �;£..�is�'; i . ,. _ ., _ _. � ... T � �_ s �. !� � ' .. � � . ' ��' ,� � ' it `u .. ;,sir -� s � .ice-� � _/�•y� �' ...,. w ,,,�. w, r _ � ' t. � �•.. �P�c.'',s�\ !. k•_ � ',=aV �^ aY�C..,�ir'��4iR'��"`�_ t J•y e` �_•! 'ft t -.-. '. � �: y�'', i x �. t � t'ro' ,t) u.. :-�R. j�1�`' a f•'ii'i,Kiv,•„t,,,� 3 r� ��t 1 ,� �,< .. � �'°•-'�s` :_ 'f gr .0 i,tF t'. t 'yCd y �` ,,•. 1 j"� �c ! �k ori• r, �' ^;�� `H�'r�r� } H� t�� vr��Y� t� t �,�,t� r• , i. ��..� `>�, t ,�{r/}� 1 trr' .�- , ✓� _ � � y� 7 ��,. Y ,±�.'k�k 'S'� �Cry(.. �..n � r�'r���i s' •- j" . f "fit �4 - +�,.�, t + �� � .J :'T^ L �� Wf►. Y!. 4 ..�['� Y '\ � 1 Y' � � !P ,t � •� < � .c. iF r1 ^-V ,t` y \ � ,... i � A�, it n i�� � .:�:, f ��. � .'f �fr�'•- .!.ii -..1. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI ION 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ '~tion • Performed: Alter Casing ^ Pull Tubing ~ Perforate New Pool ^ Waiver ^ "" "y° Time Extension ~ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ~ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: E~cxonMobil Production Company , Development ^ Exploratory ^~ ~ 69-120 ' 3. Address: PO Box 196601 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6601 50-089-20001 ` 7. KB Elevation (ft): 9. Well Name and Number: 63 ' West Staines State No. 18-9-23 • 8. Property Designation: 10. Field/Pool(s): ADL 28380 • Wildcat 11. Present Well Condition Summary: Total Depth measured 13329 - feet Plugs (measured) See Attached true vertical 13329 ' feet Junk (measured) None Effective Depth measured Surface feet true vertical Surface feet Casing Length Size MD TVD Burst Collapse Structural 32' 30" 67' 67' N/A N/A Conductor 268' 20" 303' 303' 1530 520 Surface 2070' 73 3/8" 2105' 2105' 3090 1540 Intermediate Production 10052' 9 5l8" 10087' 10087' 7510 / 8150 5600 / 7100 Liner 3156' 7" 13004' 13004' 8600 5890 Perforation depth: Measured depth: 9998-10020, 10570-10590, 11650-11675, 11675-11715, 11763-11782, 12512-12525, 12525-12537, 12630-12700, 12780-12795 True Vertical depth: 9998-10020, 10570-10590, 11650-11675, 11675-11715, 11763-11782, 12512-12525, 12525-12537, 12630-12700, 12780-12795 Tubing: (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^~ ~ Development ^ Service ^ Daily Report of Well Operations 16. Well Status after work: Oil ~• Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 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: ro Sv~~ ~~ Contact William C. Pecor Printed Name Willliam C. Pecor Title Point Thomson Coordinator Signature (,!>,/G~y~.~ C:• ~/7~ Phone (907) 564-3766 Date ;$' /~ Og S,~ ~ Form 10-404 Revised 04/2006 RE~~IVEI~ MA,R ~ ~ ~0~~ REPORT OF SUNDRY WELL OPERATIONS A{aska 0~ & Gas C~na. 3 <~~ . S/ _ " _ '' '/~ ly . s„~,*: 1 ~ ExxonMobil Oil Corporation West Staines St. 18-9-23 Well Schematic API #: 50089200070000 APTD #: 169-720 Wellhead A section in place with blind flange on top 30" sWctural at 32' cemented with 176 sx Diesel in 133/8" x 9-5/8" annulus from 1,472' to surface 13-3/8" DV Tool at 1,385' Cement in 13-3/8" x 9-5/8" annulus from ~ 1,472' - 2,105' 13-3l8", 61#, H-40 at 2,105' TOC in 9-5/8" casing at 9,838' Top of 7" liner at 9,848' Retainer at 9,898' 9-5/8" at 10,087' TOC at 10,422' Retainer at 10,472' TOC at 11,450' BP at 11,497' • ~. ~ RKB = 63' MSL = 15.5' above bradenhead , ~~;~. Diesel in 9-5/8" casing from 0'-10' / 30" cemented with 176 sx cement .'::;; ' BP in 9-5/8" at 150' with 50 Sx fondu to 10', diesel ° on top DiCSeI ZO" @ 303', cemented to surface ~ Diesel in 9-5/S" casing from 150' - 1,950'± BP in 9-5/8" al 2,000' with 25 sx on rop . 13-3/8" cemented with 700 sx G in stage 1, 1,200 sx fondu flyash with 30 % salt through DV Tool for stage 2. 9 ~ Good returns at surface PPS mud 9-518": 2,409' of 47#, Soo-95 7,700' of 43#, Soo-95 Cemented with 420 sx G Perforations 9,998' -10,020', 4spf, squeezed with 100 sx class G through retainer 30 sx plug on retainer Pertorations 10,570' - 10,590', 4 spf, squeezed with 110 cu.ft. cement 30 sx plug placed on top of BP/Retainer Perforations 11,650' - 11,675', 4 spf Perforations 11,675' - 11,715', 4spf BP at 11,743' 30 Sx cement plug from 12,350' -12,409' Retainer at 12,409' Perforations 12,512' - 12,795' squeezed with 120 sx EZ drill BP at 12,869' 7" liner at 13,004' 6" and 5-15/16" hole to 13,329' PerForations 11,763' - 11,782', 4spf : Perforations 12,512' - 12,525', 4spf ~ Perforations 12,525' - 12,537', 4spf ' Perforations 12,630' - 12,650', 4spf ; PerForations 12,680' -12,700', 4spf Perforations 12,780' - 12,795', 4spf 2 sx cement on top of EZ drill Cement plug in 7" from 12,900' - 13,078' 7": 2,032.8', 29#, Soo-95 1,100.6', 29#, Soo-95 3,156' total with hanger, shoe and collar Cemented with 400 sx G Squeezed 4 times with 5542 sx G total Weil schematic drawn June 29'", 2007 by Jesse Mohrbacher, Fairweather E& P Services, Inc. ~ • West Staines State 18-9-23 Drillsite Inspection August 22, 2007 This drillsite inspection occurred on August 22, 2007. As can be seen from the attached photographs, weather conditions were moderate (around 60 degrees F) and clear, allowing for good viewing conditions. There were no visible indications of well integrity problems nor were - there indications of oil spills or stains on the pads and surrounding surface waters. The pad had some vegetation growing on it. Gravel was mounded around the wellheads and the top of the uppermost welthead and side outlet valve were visible. Wooden piling in the vicinity of the rig location and camp area extended several inches above pad level. There was no other appreciable debris or pipe piling visible. West Staines State 18-9-23 -1- . . ~ ~ ~ ~,,": , .. ... ~~~~" ~~, ._.~ .:_:.;,~.- . ji~~. - ~ _ ~ ..~..~:~. ~ ;~- .. _ ~~~.!' _ , :~..^' ,~, ... ~` . 7 ~ ; - d ~` t ~sz . ' , ~ L~ ~. r r .. . +~~ a. __, I x ~r ~ y~y, .: L~~~~ •4 ~ y ' (y ' '; ~~ K.. .. t ~~ t .# C.. Jt r ~~; y - Y~i~y w ~ ,~ ~4~t~,~ii ~' r ~% n ; ~y1 ,'"~ +.,a . y,y ' Y •^ r t '' , ;_-r~ . - n~.-""" •. -- _ :~- _-~ ~« E~~~~~ ~ ~, ~~~~ry~~.. ' ~ ~i w1~~~ ~ ~ ..'f ~ '" 1 {. /~} ... ..I ~ , .:.~ . • • ~ # ~~ «'~ 1 ~„ 4 K ~~J'~~~~t~~ * ~ „ , ~:,~'~„~„'~~-~'`~~ i ` ~= a _ :~x s :~_~~^ .r''~r ~~r~ '~? ~r.. ~r~..."„~! -2- West Staines State 18-9-23 West Staines State 18-9-23 ,. - , ~.~.~~ ~.~::~i.,k.'~',,~~~~~'u~, ~ ~3' 7 ~~~ ~ rr . ~ ~ `~.t`, `~.~~~ ~, '~,~`~~ :~ ~V ~' `~J i~l`i(`'~~~i~ j._,),,:~ 'r ~~ . . .. /'a' ~ '~':W iL~~. ~~~(',.~1 !-4.i:~j1AC~ ~~.-~iili~ii_3li'1~ ~~.~~C3.~'a.~ i ~ ~,~:~orl'~'~<»ii P~ociuc:i?on c~~~r~} ~+ ~ ~~~ ~ y~6~^v i ~;~ch~rag~; ~~i~ 995 i ~ 33s /~, ~~;~rA~. '~l:i= SJ'~Tc „ ~iC 0~:~,G= F ,aS,:A ,e; ~-Oi~E 'a.` ., C:~,'! -f' _ : .. _ R~: t~2 Thomson ~~%b~ls -~'l;~ggia~g an~ Abandon:mPnt ~~pC1- ~`~~ ~ear i`~Ir ~a} mes, ?his is in re~ponsz to your lerter of '~tUVember 14; 2007 responding to the Alaska ~il and Gas Conservation Commission's ("Commission") letter of t/Iay 1~, 2~0? regarding the condition of certain Pt. Thomson Unit weils. The schedule and plan for remedial work provided with your letter are acceptable s~abjecz to the follo~~~ing conditions: 1. E~con?vlobil ~vill perform the proposed field work for the 200~ - 2009 winter operating season ~~gardless of whether there ar~ any concurrent drilling operations in the Pt. Thomson ~.`nit. 2. All of the diesef will be removed from the ~`. Staines State #1~-9-23 (I69-120) and Vv. Staines State #2 (17~-002) ~~ells. If any of the diesel cannot be removed, a Commission petroleum engineer or inspector shall determine whether the shallow wellbore plugs are competene, and ExxonMobil must take any reasonable actions the Commission determines are necessary. 3. All current and future statutory and regulatory requirements and all applicab(e rules, orders, and permits of the Comrnission wit( be comptied ~ith unless a waiver to a specific requi;ement i~ Tirr-el; and othe~~ise properl}~ requested and branted by the Commission. To assist the Commission in ensuring ihat its ~iles are complete and accurate, by March 3(, 2008, please sub~nii far each we~l a Form l0-404, a summary of the observations from the work performed last summer. and location photos. ~~nall~~, nothing abo~~ expressly or irr-plicitlv ~ti~idences ihe Commission's position with respect to the status ~t ~~oni~~obil or an;e other person as a cur~ent Pt. Thomso~ ~`n~t operator, working interest o«ner, or lesse`. ~f ~~eu have an,, questions. please ca[1 ,-rae at 7~~3~~?Z21 or Tom !~Iaunder, PE at 793-12~0. ~ince~~i~, r~~~ .~~~ o ,~ c~-?~~ ~ ; ~ o ~.~th4 ~~ ~=oers2et~ ~ommi~~ian~~ IE~ttoaa~fto9ael 6~POduc~amsa Coenpare~ P. O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimiie ~~ae~ ~o ~ayrvees Alaska Production Manager Joint Interest U.S. .~ ~ ~'"; € ~'~~ ~ d ~~ f 0~ ~~odttc~i~~s November 14, 2007 Chairman John Norman Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Pt. Thomson Weils - Plugging and Abandonment `c~~,_ ~;~ Dear Chairman Norman: We are providing this letter in response to the Commission's May 18, 2007, letter to ExxonMobil regarding Point Thomson area wells that are classified as plugged and abandoned. ExxonMobil, as Operator and on behalf of the working interest owners of nine of the listed Point Thomson area exploratory wells identified in the Commission's letter, has undertaken an extensive review of the current physical status of each of these wells. (As Operator of the remaining well, BP will respond directly to the Commission on it.) This work included reviewing ExxonMobil's and the Commission's well files, including confidential Commission fites for one well, conducting on-site inspections to assess the physical integrity of each well site, and conducting a joint owner review of each well by technical experts. We are pleased to report that none of these activities have identified any imminent safety or environmental threat conditions from the wells. Attached are photos taken during the on-site inspections. The extensive reviews provide the basis for this response to the Commission's letter. While we believe the wells met AOGCC requirements when the prior P&A actions were taken and are safe in their current condition, we recognize that performing certain remedial work can further reduce any risk of an incident that may occur in the future. With that in mind, we have developed the attached schedule and plan to conduct remedial work on the wells. If the Commission concurs with this work program, ExxonMobil will prepare the appropriate sundry notices and begin to carry out the actions. As described in this letter and accompanying attachment, the plan contemplates conducting remedial work on certain wells in the near future and reclassifying the remaining wells to a suspended status. The wells with planned near term remedial work do not appear to have future utility while the wells identified for reclassification are capable of producing in paying quantities. We believe it would be premature to conduct work on these latter wells that may make it more difficult to utilize them in future development operations. There are other existing suspended wells in the Point Thomson Unit, and we view this action as consistent with current circumstances. vVe under~ta~id i ~at ra~~as~~t~~at:or~ Lv:!! ~ar ;~ ?•"• nbl~aation to abandon the wells in the future in compliance with regulatory requirements. A Division of Exxon i1~Nobi1 Corporateoee ~~~~ ~~~~~ Commissioner John Norman - 2- November 14, 2007 Piease note the plan cails for conducting the most intensive phase of field work in conjunction with the first winter drilling season of currentfy-planned Point Thomson Operations drilling, which is proposed to occur during the winter of 2008-09. We believe conducting this work in conjunction with this drilling program will offer significant operational safety and efficiency benefits. In the event the drilling program does not progress as proposed, we will work with the Commission to determine appropriate timing for the remedial work. We believe this plan responds to the Commission's request that ExxonNlobilp rggd ginformation and documentation to demonstrate that the wells meet the requirements for lu in and abandonment or provide a schedule and plan for bringing these wells into compliance and should address any concerns that may exist regarding compliance with AOGCC requirements for plugging and abandonment. As the Commission is aware, a number of changes have occurred in the requirements for plugging and abandonment of wells over the past 40 or so years. We believe these changes were generally sound and resulted in safer operations. In some cases, however, the changes created specific conflicts for operators, e.g., the 1986 regulations required installing marker posts while the 1999 re aurrat~ill address these matters on the wells~plan d forrneare-term em). The planned work prog remedial work and through future actions on the remaining wells. Other regulatory changes involving placement of cement plugs and retainers, cementing of casing stubs, or requirements of fluids left in the well are more subtle. In general, it would be unnecessary and impractical to later attempt to modify many of these items, particularly those that exist at deeper depths in the wells. In the interest of transparency and clarity, we will address any variances or deviations from current regu{ations in our sundry notices filed with the Commission. We appreciate the Commission's help in providing clarity around the issues and allowing adequate time for ExxonMobil to eed w th therout~l ned work plans! r Ple se eellf ee to contact your concurrence so we can proc me, Bill Pecor at 564-3766, or Rob Dragnich at 564-3711 if you have any questions. Sincerely, ;~ / ~/~ ,',i ~ • `=~(i ~ % CA :rgd/jpc Attachments xc: Cmmissioner Cathy Foerster - AOGCC Commissioner Daniel T. Seamount - AOGCC Kevin Brown, BP Mark Ireland, ConocoPhillips Vince LeMieux, Chevron ~} ~ ~ ~~ ~ `~ d~~ 1`~,~ ~ Remedial Action Program Point Thomson Wells - Plugging and Abandonment VNells Affected Actions Timin PTU #1, PTU #2, PTU #3,_ - Conduct additional integrity investigations to include: - Conduct work during winter of 2008-09 PTU #4, Alaska State C-1, + Removal of gravel from around wellheads Staines Etiver State #1, W. + Conduct visual inspection Staines State #18-9-23, W. + Install valves and pressure gauges Staines State #2, Alaska + Check for pressure in casing and all annuli State J-1 + Conduct further diagnostics as appropriate PTU #4 - Remove marker post - Conduct work in conjunction with first - Remove wellhead and casing to lower than 3' below year of Point Thomson de~ineation ground level drilling planned for winter of 2008-09 - Verify integrity of surface plug + Repair or replace as necessary ~---p - Remove near-surface arctic pack from 2 annuli and ho c~l~s~` set cement plugs in annuli using top job techniques ~~~ (plugs to be at least 50' long) ~~/~~' - Install marker plate - Remove cellar - Conduct general location cleanup, and request final site clearance Staines State #18-9-23 W - Remove marker post - Conduct work in conjunction with first . - Remove diesel above surface plug ~IC~~ ~ year of Point Thomson delineation - Remove wellhead and casing to lower than 3' below drilling planned for winter of 2008-09 ground levef - Verify integrity of surface plug + Repair or replace as necessary p o ss~b~~ 15 ~~ c~\esE ~ - Remove near-surface diesel from annulus and set cement piug in annulus using top job techniques " (plug to be at least 50' long) - Install marker plate - Remove cellar - Conduct general location cleanup, and request final site clearance -1- W. Stairtes State #2 - Remove marker post - Conduct work in conjunction with first - Remove wellhead and casing to lower than 3' below year of Point Thomson delineation ground level drilling planned for winter of 2008-09 - Verify integrity of surface plug 8-~~~`~'n + Repair or replace as necessary - Remove near-surface arctic pack from annulus and ~~5~~ set cement plug in annulus using top job techniques ' ~~ long) (plug to be at least 50 a~~~ - Install marker plate ~ - Remove cellar - Conduct general location cleanup, and request final site clearance Alaska State J-1 - Remove marker post - Conduct work in conjunction with first - Remove wellhead and casing to lower than 3' below year of Point Thomson delineation ho c~'~tS~\ ground level drilling planned for winter of 2008-09 - Verify integrity of surface ptug ~p ~~ + Repair or replace as necessary ~~~ - Install marker plate ~~~ S - Remove cellar Conduct genera~ location cleanup, and request final site clearance PTU #'1 - File sundry notice to change well classification from - Submit sundry notice within 90 days of abandoned to suspended AOGCC concurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winter 2008-09 inspections PTU #2 - File sundry notice to change well ctassification from - Submit sundry notice within 90 days of abandoned to suspended AOGCC concurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winter 2008-09 inspections PTU #3 - File sundry notice to change well classification from - Submit sundry notice within 90 days of abandoned to suspended AOGCC concurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winter 2008-09 inspections -2- Staines f~iver State #1 - File sundry notice to change well classification from - Submrt sundry notice within 90 days of abandoned to suspended AOGC;C concurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winte~~ 2008-09 inspections Alaska :~tate C-1 - File sundry notice to change well classification from - Subrr~it sundry notice within 90 days of abandoned to suspended AOG(.;C concurrence with action plan - Establish status reporting program in compliance with - Subm~t status report within 90 days of AOGCC regulations winter 2008-09 inspections -3- ATA KA OIL AND GAS CONSERVATION COMUSSION August 14, 2007 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Craig Haymes Alaska Production Manager ExxonMobil Production Company PO Box 196601 Anchorage, AK 99519 Re: Pt. Thomson Wells — Plugging and Abandonment Dear Mr. Haymes, This is in response to your letter of August 3, 2007 wherein you requested a ninety -day extension to the response time with regard to the condition of Pt. Thomson Unit wells as specified in the Commission's letter of May 18, 2007. It is stated that the additional time will allow further investigative work including site visits to the various wells. Your request is granted making your response due not later than 5:00 p.m. November 14, 2007 If you have any questions, please call me at 793-1221 or T,PM Maunder, PE at 793-1250. N sa 4" ? ~_., i~ ~7~ ~J~~ ~'f~ ~-~~':~~ ~/aay ~3, ~~~? ~ommissioner ~athy ~oerster l~laska Oii and ~Gas Conservation ~ommissior~ 333 West 7`" Avenue, Suite 100 Anchorage, ,4laska 99501-3539 Fte: Point Thomson Welis - Plugging and Abandonment Dear Commissioner Foerster: _ _ - > ,-,. , _ : :~ ~ ~~~ E `~;{ ~!~ ;- ~ 3 ~ ~' `~ ~ ~_~. ':'~ ~ , =~{."~: ~ P, ~~~ ~ ~~ ' ~ ~ ~.~:-~~ i 1.~_i w i ;~~~.~i~~,l t 1 ~.3~a~ > . :~~~ ~~~~ ~:~~ We have received the Commission's letter dated May 18, 2007 regarding potential issues related to certain Point Thomson wells that were dril(ed and subsequently plugged and abandoned. Regulatory compliance is a core value for ExxonMobil, and we take all matters seriously. Our prior track record of voluntarily re-abandoning some wells and undertaking other remediation work in the Point Thomson Unit should speak to this. The May 18 letter requests that ExxonMobil respond within 90 days and either provide sufficient information and documentation to demonstrate the wells meet all requirements for plugging and abandonment, or to provide a schedule and plan for bringing the wells into compliance. We have begun an immediate review of the wells in question and have two requests of the Commission to help expedite that review: 1. The wefl files for the Staines River St #1 well, which was drilled by Mobil in the 1979 timeframe and is under extended confidentiality, are not in our Anchorage office. It would facilitate our work to obtain a copy of the file from the Commission. 2. it would be helpful to obtain a copy of the concerns or issues identified in the Commission's review. We intend to conduct a thorough review of all of the wells in auestion and having any initial assessment by the Commission to check against as our work progresses may facilitate an earlier completion. !t appears the wells on the list were operated by Exxon, Mobil or BP (formerly Sohio). To the extent another operator may be responsible for any of the identified wells we will work vvith the other owners to determine appropriate handiing and response to the Commission. 6 will be out of town until May 31. Please contact Rob Dragnich at 907-574-3711 or Bill 9'ecor at 713-656-7064 to coordinate any information you are able to provide. Thank you fior bringing these matters to our attention, jincereiy yours, /~~ ~ ~ ~-_. ~ ~ ~ .~;jnc ;<~; `,~~g~;~ ~i~i~ikvi°, ~~ :~,~ ~.~ ~1 ~;4± IR7, ~a~ /~~fli ~~ ~ ~~~~~ ~~ ~~ ~~ ~ ~ ~ ~~la~~ I ~, Z007 ~raig I-Iaymes Alaska Production ~~Ianagee• ~xxon!VIobil Producti~n Company I'O Box 196601 ~nchorage, AK 99~ 19 Re: Pt. Thomson Wells - Plug~ing and Abandonment Dear I~Ir. Haymes, 333 ~N. 7thAVENUE. SUITE 100 AftIC'r90RAGE,.4LASKA 99501-3539 PFiONE (907) 279-1433 FAX (907j 276-7542 During our review~ of the Pt. Thomson Field in response to your recent apptications for permits to drill, the Alaska Oil and Gas Conservation Commission ("Commission"j identified the following wells that, according to our records, are classified as plugged and abandoned but do not meet the requirements for plugaed and abandoned w~ells under 20 AAC 2~.10~ - 20 AAC 25.172: W. Staines St. 18-9-23 ~--- ~(oC~ _ r~ W. Staines St #2 Pt. Thomson # 1 Pt. Thomson #2 Pt. Thomson #3 Pt. Thomson #4 Staines River St # 1 Alaska State C-1 Alaska State J-1 Challenge Island # 1 VJithin 90 days of receipt of this letter, either provide sufficient information and documentation to demonstrate that these welis meet ail the requirements for plugging and abandonment, or provide a schedule and plan for bringing these weils into compliance. Also, please note that, under AS 31.0~.090, the Commission cannot issue permits to drill to an ~perator that is in violation of a Commission regulation pertaining to drilling, plugging or abandonment of a well. The Cammission reserves the right to pursue an Enforcement ~lction according to 20 AAC 25- ~3~. `. :i~ ;-~d,i3i4'S ~ ~' ~ . , ~~~>' 13. ?n~„ °a~,e ~ or 3 t=inall~, i~othing ab~~~ sh`~ttld b~ ct~n~tru~.:d iu ~~ id~n~:~~ ~~:pr~ssl~ or imp(icitlti the ~'ommission's positi~~: v~~irh resp~si t~ ~h~ ~,irren~ stat~,~s ~t~ ~;~x:~r~~~fl~il ~r any oti~er person as a~t. T~h~ms~n unit c~p~ratc~r or I~ss€~. I'r j,~u ha~~e any~ quc;sti~ns, pleas~ ~;~.I1 m<; at 7~3-12? 1. Ta: Cathy Foerster, Commissioner May 9, 2007 Fr: Tom Maunder, PE Re: Sta.tus of Pt. Thomson Area Wells t(oC, - ~ a-~ Introduction: As instructed, an assessment of the wells in the Pt. Thomson area was performed. T'he purposes of the assessment were to determine if the condition of the wells met the regulatory requirements in effect when operations were completed some years ago as well as if the wells would meet the now current regulatory requirements. There are a total of 21 wells in the general area (14 E~onMobil + 1 ConocoPhillips + 6 BP). This document wiil only address the E~onMobil wells. Recommendation: Based on examination of the well files, it is my assessment tha.t 5 of the 14 E~conMobil wells are Plugged and Abandoned in ac~ordance with the now current regulations. The remaining 9 wells should be considered Suspended and AOGCC's data.bases should be changed to reflect this more accurate well status. E~cxonMobil should be required to perform the work necessary to properly plug and abandon the wells. Discussion: There are 4 versions of the plugging requirements in effect depending on when the work was actually accomplished. A summary of the effective dates of the various regulations is listed below and copies of the regulations are attached. Requirements have become more proscriptive through time. There were major amendments to the AOGCC regulations effective 4/2/1986. These included significantly more proscriptive requirements for plug locations and lengths, a suspended well classification and included requirements for removal of the wellhead and casing "... at least 3' below rig grade." In the 11/7/99 amendxnents, the cutoff requirement was changed to "... at least 3' below original grade." Prior to 1980, 50' cement plugs were required above hydrocarbon zones and at surface with heavy mud-laden fluid between plugs. After 1980 100' of cement was required above hydrocarbon zones and casing stubs were required to be covered. Neither regulation explicitly required cutting off the wellhead and casings, although removal of all "... structures and installations ..." was required as part of location cleanup in the 1980 regulations. Effective Date 9/30/1967 DNR, 11 AAC 22 4/13/1980 AOGCC, 20 AAC 25 4/2/1986 AOGCC, 20 AAC 25 11/7/1999 AOGCC, 20 AAC 25 The physical downhole work on 7 of the l4 ExxonMobil operated wells was completed prior to April 13, 1980 and physical downhole work on 6 of the remaining wells was compieied priar io Aprii 2, i 980. T'ne Iasi well, tiiasica Siaie r'~-2, was piugged ana abandoned in 1Q 2002 according to the 11/7/99 regulations. Regardless of when physical operatians were completed in the legacy welis, letters were submitted (most in November 1986) requesting the status of the wells be changed from suspended to abandoned. These requests followed physical inspection of the locations for site cleaxance subsequent to removal of upper casing heads and installation of abandonment markers. No downhole work was performed subsequent to removal of the drilling rig. It is interesting that following the completion of downhole work that nearly every well was labeled suspended, and that term is not defined in AOGCC regulations until the 1986 amendments. Temporary abandonment is first addressed in the DNR regulations effective 9/30/67. Examination of the files for the ExxonMobil wells reveals that, so far as I can determine, the wells have been effectively abandoned downhole. All wells had cement placed over productive intervals and usually employed retainers or bridge plugs. One well, Alaska State J-1 does not have any open hole plugs, but the well apparently did not encounter hydrocarbons. The intermediate casing shoe was squeezed below a retainer. Moving up hole, most wells ha.d a portion of the production casing (7") cut and pulled. In all cases except Pt. Thomson #1, a retainer and/or a cement plug were placed on top of the stub. There was no specific requirement to cover the stub prior to April 13, 1980, although in 3 subsequent welis the cut top of the 7" was isolated. Wells generally had a retainer and/or cement placed at about 2500' with non-freezing fluids placed above it. Non-freezing fluids included CaC12 brine and diesel. Where annuli were not cemented, non-freezing fluids such as arctic pack and diesel were placed. No well had a11 casing head heads removed. It appears that the casing head.s from any casings smaller 13-3/8" were removed and the casings cut below the lowest flange depth. A blind flange with the abandonment post attached was then bolted to the flange. It is important to note that E~on performed "re-abandonment" work on 4 of these wells that were located on the barrier islands offshore in 1998 - 1999. The offshore islands were being eroded, and it was likely that the well casings would be exposed possibly resulting in spills. Exxon specifically sta.ted that the work would "... plug and abandon the wells according to current regulations." The 4 wells were re-entered, liquid hydrocarbons (diesel) removed, cement plugs placed and casings cut off well below sea level. These 4 wells and ~lie Alaska State A-2 are the only wells that meet the plug and abandon requirements effective since Apri12, 1986. Based on examination of the well files, it is my assessment that 5 of the 14 E~conMobil wells are Plugged and Abandoned in accordance with current regulations. The remaining 9 wells should be considered Suspended and carried as such in the AOGCC da.tabase. E~onMobil should be required to perform the work necessary to properly plug and abandon the wells. Tom Maunder, PE Sr. Petroleum Engineer ExxonMobil Operated Wells Pt. Thomson Unit Area ~ Well PTD Date Date Work to Effective Re ulation? Comment Assessed Actual Required Work Suspended P&A 9/30/67 4/13/80 412/86 11/7199 Status W. Staines St 169- 8/13/70 511/73 by YES YES NO NO Diesel in annulus and Suspended Remove fluids, place 18-9-23 120 sun casin . Not cutoff. ~ lu s, cutoff wellhead Alaska State A-1 174- 9/6175 ~ by letter YES YES NO YES Re-abandoned 1998 -1999, Plugged and None 0~4 11/86 Abandoned W. Staines St. #2 175- 5/26/75 ~ by letter YES YES NO NO Diesel in casing 150' - Suspended Remove fluids, place 002 9/86 2279'. AP in annulus. Not plugs, cutoff wellhead cutoff. Pt. Thomson #1 176- 12/8/77 ' by letter YES NO NO NO No plug above cut 7" at Suspended Remave fluids, place 085 11/86 4000'. Diesel in casing. plugs, cutoffwellhead AP in annulus. Not cutoff. Pt. Thomson #2 177- 8/12/78 ~ by letter YES YES NO NO AP in annulus. Diesel in Suspended Remove diesel. Cutoff 064 11/86 casing at 40'. Not cutoff. wellhead. Remove some AP. Pt. Thomson #3 178- 7/4/79 ~ by letter YES YES NO NO AP in annulus. Diesel in Suspended Remove diesel. Cutoff 005 11/86 casing at 40'. Not cutoff: wellhead. Remove some AP. Staines River St 179- 7/21/79 11/5/86 by letter YES YES NO NO Diesel in casing at 100'. Suspended Remove diesel, place #1(confidential 001 11/86 Not cutoff. lu s, cutoffwellhead Pt. Thomson #4 179• 12/20/80 ~ by letter NA YES N0~ NO* AP in 2 annuli. No diesel. Suspended Cutoff wellhead. 080 11/86 Not cutoff. Remove some AP. Alaska State C-1 180- 7/14/81 * by letter NA YES N0~ N0~ AP in 2 annuli. No diesel. Suspended Cutoffwellhead. 046 11/86 Not cutoff. Remove some AP. Alaska State D-1 180- 2/16/82 ~ by letter NA YES NO YES Re-abandoned 1998 -1999. Plugged and None 101 11/86 Abandoned Alaska State F-1 181- S/30/82 ~ by letter NA YES NO YES Re-abandoned 1998 -1999. Plugged and None 140 11/86 Abandoned Alaska State G-2 182- 8/19/83 ~ by letter NA YES NO YES Re-abandoned 1998 -1999. Plugged and None (confidential 208 11/86 Abandoned Alaska State J-1 183- 6/14/84 ~ by letter NA YES N0~ N0~ No open hole plugs. No AP Suspended Cutoff wellhead. 045 11/86 or diesel. Not cutoff. Remove some AP, Alaska State A-2 200- 3/8I02 by NA NA NA YES Plugged and None 141 sundry Abandoned N0~-no liquids present. February 18, 1987 Telecopy No. (907) 276-7542 Mobil Oil - Alaska c/o Phil Braithwaite P. O. Box 900 Dallas, TX 75221 Re: W. Staines St. 18-.9-23 Gent 1 emen: In compliance with the regulations set .forth in Chapter 25 of the Alaska Administrative Code, your company has dutifully submitted to the Commission sePias of the various logs run in the subject well. Primar. ily due to to frequency of use, the sepias of the logs indicated b deteriorated to the point that satisfactory prints can - no longer be made from them. Accordingly, in the interest of upgrading the quality of the material maintained for permanent reference in the Alaska well log library, the Commission would greatly appreciate receiving from you fresh sepias of the following logs: D IL 2" Runs 1, 2, 3 & 4 CFD 2" Runs 1, 2 & 3 Mud log Please direct any .'"questions you may have in fulfilling this special request to-Bill Van Alen at 279-1433. Thank you for your contribution' toward maintaining a good State well log library. Sincerely, W. W. Barnwe C omm~s s loner jo/L.FJ. 01-02 Telecopy No. (907) 276-7542 September 12, 1986 Mr. Greg' Aggerman Mobil Oil Corporation P. O. Box 5444 T.A. Denver, CO 80217 Re: Final Location Clearance west Staines State 18-9-23 Permit No. 69-120 Sec. 18, TgN, R23E, UM Dear Mr. Aggerman: WRen the above referenced location was inspected in August, 1983, it was satisfactory for final location clearance except for incorrect data on themarker post. On August 21, 1986, our representative accompanied Mr. C. L. Stimmel to the location and witnessed the punch marking of the correct data on the marker post. Based on the above, final location clearance of the West Staines State 18-9-23 well is approved. cerelv,.... ~ '~ ~/l~'''' ~. Lonnie C. Smith Commissioner jo/A.HJH.33 4EMORA, " UM Stat[,?f Alaska FILE NO.- D.HRH.51 THRU: Lozmie C. Smith TELEPHONE NO.' Coamis sioner FROM- Harold R. Ha~kins Petroleum Inspector SUBJECT: Location Clearance Mobil West Stains No. 18-9-23 Permit No. 69-120 Sec. 18, T9N, R23E, UPM Exploratory Thursday, August 21, 1986: I finished the location clearance inspe'ction on ~west staines state No. 1, and went to West Staines No. 18-9-23 for a final location clearance inspection. I was told by the Commission to witness the changing of the range data on the marker post from R-22 to R-23. Using a punch, C. L. Stimmel, Mobil representative, and Bill Kuper, Operations Manager, punched., out the' corre-ct~--~range~-data (23-E) on the marker post. Attached are pictures verifying this. I filled out an AOGCC report whEch is also attached. In summary, I'~'Witnessed t~he punch marking of the correct data on the marker post as agreed by Lonnie Smith. Final location clearance can be approved by the Commission. Attachments -O01 A(Rev 10-84) AL~..~' OIL AND GAS CONSERVATION C0,~MI~$ION SURFACE ABANDONMENT REPORT 20 AAC 25, ARTICLE 2 FILE INFORMATION: Operator ffl~ ~_~ Address Surface Location of Well If/~II Ft. F/~/L, tTYO ! Ft. F ~L, . - Date Downhole P & A .f~/~',~'/-'~:~.~'~ ~//~.J'/F~9 ' Pemit No. ~ Y --/~O ~I No. 50- Unit or Lease N~e ~~ ~/~ ~~ - f f Field & Pool ~ ~ ~~'~ 20 AAC 2~.120: WELL ABANDONMENT MARKER: . Dia. Steel Post (4"Min.) ~ Height Above Final Grade Level'(4' Min.i Length./~/ (10' Min.) Top of Marker Pipe Closed with: Cement Plug__ Screw Cap Welds Set: On Well Head P On Cutoff Casing ~ · · · Distance Below Final Grade Level Side Outlets: Ail Valves and Nipples Removed AIl Openings Closed , With Blinds__ , In Concrete Plug -~ ' e Ft. ~ in. · With Cement_. ~Other ~ L~st ~ere Dmfferent fr~ File Infomation) 50~~ ~ffC~F~...~~~L Operator Unit or Lease N~e Well N~ber , Surface Location of Well: Ft. F L, Ft,, F L, Sec , T__, R " 20 AAC 25.170: LOCATION CLEAN-UP PITS: Filled In ~, , Liners Removed or Buried ~ , Debris Removed · . ' SURFACE OF PAD AND/OR LOCATION: Rough , Smooth kf , Contoured Other . - z% ~,~ ' CLEMN UP OF PAD AND/OR LOCATION: Clean ~,., Pipe Scrap Paper , Other SURROUNDING AREA: ........ Wooded , .Brush Sand , Other · Iron Scrap , Wood ., Mud ., Cement ,, Tundra ,~., Grass · Dirt , Gravel'q': ", Trees and/or Brush rrm Clear~ng S~te -,.~ CONDITION SURROUNDING AREA: Clean ~ , Trash from Site__ Other ACCESS ROAD: . -::.~..... Dirt , Gravel , Ice __~__, Other CONDITION ACCESS ROAD AND SURROUNDING: Clean _~., Rough Smooth , Trash from Operations , Trees and/or Brush fr01 Clearing Road ., Spoil from Clearing Road" _, Other RE,~LAINING TO BE DONE: RECOMMEND APPROVAL OF ABANDONMENT: Yes ~ , o5/26/8~ '-'" No tS • _ . -44-1-44u2L_1)A8/1iW y_pvyz Ate elk k / //e Z 1 04 l icig,2: 7 d1-7_c_&) I -_, 5i-t u7.9141 f4l'Alv? 4 :t 1 Telecopy No. (907) 276-7542 July 10, 1986 Mobil Oil Corporation P. O. Box 5444, T.A. Denver, CO 80217 Re: Final Location Clearance West Staines State 18-9-23 Gentlemen: A review of our records shows that final location clearance for the above referenced well has not been approved. When our representative inspected this location on August 12, 1982, the well marker did not have the well number or distance from the section lines bead welded on it. When our representative again inspected this location on August 7, 1983, the well marker read "1513' FNL, 1730' FEL' Sec 18, TSN, R22E." The well marker should read 1514' FNL, 1730' FEL, Sec 18, T9N, R23--E, ~. -- When the underlined items are corrected, final location clearance can be approved. If you provide this office with photographic evidence of these corrections, another field inspection will not be required. If you have any questions, please contact Harold J. Hedlund at (907) 279-1433. Sinc~erely, ~ Commis s ioner Attachment jo/A.HJH. 8 TABLE 10 Clay Mineralogy of Conventional Core Samples From Mobil , ~ -~_ ~-- -~ i~,/~ _,, North Slope, Alaska DEPTH FT SMECTITE ILLITE/SMECTITE ILLITE CHLORITE KAOLIN OTHER MINERALS 10614 - MOD MAJ MOD MAJ Q1,P1,BNSH. 11170 - MIN MAJ MOD MOD Q1,P,PY,BNSH. 11223 - MIN MAJ MOD MOD 01,P1,BNSH. 11733 - MIN ..~ MAJ -~ MAJ MOD Q2,P,CA,BNSH. 12543 - T~RACE MOD TRACE - Q2,P,PY1,BKSH. 12559 - MOD - - - Q,F,HC,TUFF 125161 - MAJ - - - TUFF 12658 - MAJ - - - O,~N,TUFF 12659 - MAJ - - - Q2,AN2,TUFF 12671 - - MAJ - - Q2,P,PY2,BKSH. 12678 ..... Q3,AN2,TUFF Definitions: TRACE = <3%, MIN = 3 - 12%, Mod'= 13 - 35%, Major = >35%. Other E mineral abbreviations: Q = Quartz, P = Plagioclase, AN = Analcime, HC Heulandite/Clinoptilolite, CA = Calcite, F = Feldspar, PY = Pyrite, BNSH = Brownfsh gray shale, BKSH .= Black carbonaceous Shale. Analyses based on <2-um ~-saturated clays using air dry and glycol treatments. MEMORANDUM State of Alaska. ._~.'A.I~%SKA OIL AND -GAS CONSERVATION COMMISSION TO: C. V. Chatterton DATE: Chairman FILE NO: THRU: Lonnie C. Smith C~missioner TELEPHONE NO: FROM: Edgar W. Sipple, Jr Petroleum Inspector SU BJ ECT: August 25, 1983 108A:F8 Inspection of Mobil's Surface Abandonment for Final P&A on West Stains State and West Stains State #2. .. .~nda¥, August .7, 1983: I traveled this date to Prudhoe Bay, .~here I met Duane Schlosser of CATCO, a representative for ~k)bil Oil, to look at West Stains Stae and West Stains State #2 for a final approval of abandonment. The P&A marker on West Stains State, the-legal description should read R23E not R22E. The P&A marker on noted a gauge at the Stains State #2 is correct. There was of the P&A marker. It is my State~ #2 and approve We on the range is changed the Commission to approve West Stains State when the legal description 22E to 23E. In summary, I ins the above wells for a final P&A and surface abandonment, for Mobil's West Stains State and West Stains State #2. Attachments 02-00IA(Rev. 10/79) 'Ar ASKA OIL AND GAS CONSERVATION C ''MISSIO.N SURFACE ABANDONMENT REPOL. 20 AAC 25, ARTICLE 2 FILE INFORMATION: Operator klo 0t1 CO,e9 Date Downhole P & A Address A O. AkeFf 1 -003 ,4416k ,,AK 995 / Surface Location of Well Permit No. (,q- /20 /5/y Ft. FA/ L, /730 Ft. F6 L, API No. 50- 4 a9 2 oo I Sec. j$' , T 9' AL, R3 E , LIP M. Unit or Lease Name 1.60...s7 57 5r"ATL Wel l No. / k -' 9- 23 Field & Pool A ,!) c 47 20 AAC 2 WELL ABANDONMENT MARKER: Dia. Steel Post (4"Min.) 4 0 , Length (10' Min.) / _1' Height Above Final Grade Level (4' Min.) Pr / Top of Marker Pipe Closed with: Cement Plug Screw Cap Welds ;/ Set: On Well Head .= , On Cutoff Casing , In Concrete Plug Distance Below Final Grade Level u Ft. in. Side Outlets: All Valves and Nipples Removed -r All Openings Closed L- , With Blinds • -- , With Cement , Other INFORMATION BEADWELDED D IRECT)LY TO MARKER POST: (List Where Different from File Operator f>; ^ D I r , Information) ,, r' Unit or Lease Name 9 J' We Number ' ( (> 1--1 , Surface Location of Well: Ft. F L, I"7 0 Ft., F & L, Sec I , T Q ,1.J R cv/a�+, 20 AAC 25.170: LOCATION CLEAN -UP PITS: _ Filled In , Liners Removed or Buried t'' , Debris Removed SURFACE OF PAD AND /OR LOCATION: Rough L/1 Smooth , Contoured , Flat ' Compacted , Other 5'u ! zto (41 .L . /3/, 1 I 6. 6 ti, )J L- <1 u2 Cori' ,�urelccf/Drr ftArid.-t, 4t AI L44*e/ray. �l CLEAN UP OF PAD AND /OR LOCATION: Clean , Pipe Scrap , Iron Scrap , Wood , Mud , Cement , Paper ----" , Other Po " ti � di \ .,� cf.' .A1 Y . SURROUNDING AREA: Wooded , Brush L-_ , Tundra , Grass Dirt , Gravel , Sand , Other CONDITION SURROUNDING AREA: Clean L, Trash from Site Other REMAINING TO BE DONE: / i 7 /...9 RECOMMEND - APPROVAL OF ABANDONMENT: Yes , No INSPECTED BY 05/26/81 , Trees and /or Brush from Clearing Site ACCESS ROAD: Dirt , Gravel , Ice , Other V L') 1,,..) - rr,.A1. S'r,i /0,1 ,f, p. t,./ CONDITION ACCESS ROAD AND SURROUNDING: Clean , Rough , Smooth , Trash from Operations , Trees and /or Brush from Clearing Road , Spoil from Clearing Road , Other 0 i Final Inspection DATE 2- .- Rokeil 4 M6ud4 A S4dV ( 1 P A FAA kA, pov, 140.4 "AA. k.,/* West StAird SIVE 0) ,,, SEA I S T qN R 23 CU MI 9.743 ALASKA ~', ~_ AN STATE OF ALASKA COl, D GAS CONSERVATION MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator Mobil Oil Corporation; Attn: L. C. Case 3. Address P.O. Box 5444; Denver, CO 80217 4. Location of Well 1514' FNL, 1730' FEL, Section 18-T9N-R23E 5. Elevation in feet (indicate KB, DF, etc.) 28' GR ' 12'. 6. Lease Designation and Serial No. AD~. 28380 OTHER [] 7. Permit No. 69-120 8. APl Number 50- 089-20001 9. Unit or Lease Name West Staines State 10. Well Number 18-9-23 11. Field and Pool Wildcat Sec 18-T9N-R23E, UFM Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [-I Repairs Made [] Other Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Mobil proposes to alter the well marker such that it has: (1) the well number (18-9-23) and (2) the exact distance of the well from the section lines. ECEIVED ~AR .... ? ~983 Anchorage 14. I hereby certify that the~f~regoing is [rue and correct to the best of my knowledge. . Signed .. , Title Acting D~v'~.~inn Reg. l~nry Date ,M~rch 3: 1983 The space belo~for Commissior~se J. L. Douglass Engineer Co~o.s o~ A,,~ov~. ~ anV:~r representative ~pected this site on Aunt 12, 1982 ~d noted these needed corrections A s~se~ent instep%ion ~11 be necessa~ by Aunt, 1983 ' Appro~ L . ' ORIGIHA[ SI~NED ' Approvedby ~Y LO.NHIE C, SMIT~'' .,~.~'8~ BvOrderof ' ' '-- COMM~SS'~oNER the Commission Date ~-~ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent RePorts" in Duplicate September 13, 1952 Mobi! Oi I Company P.O. Box 5444, T.Ao Denver, Colorado 80217 Re: Final Abandonment Mobil Oil Company West Staines St. 18-9-23. 1513'FILL, i?30'FEL, Sec. 18, T9N, R23E, UM. Gentle~n ~ Our representative was at this site on August 12, 1982. The existing well marker does not have the well number or the distance of the. surface location from the section lines bead welded on it.. When this is accomplished a letter of approval for final abandon- merit will be issued. Please advise this office of action taken. to cc~plete this. abandonment. LCS/JKT/glh MEMORANDUM TO: THRU: Lonnie C. Smith~'//- 6 Commi s sioner of Alaska ALASKA OIL .AND GAS CONSERVATION COMMISSION C. t~rton August 31, 1982 Chai~~w/ FILE NO: 108A/A FROM: Harold R. Hawkins Petroleum Inspector TELEPHONE NO: SUBJECT: Inspected Well Data on ~arker Mobil Oil Co. West Staines St. 18-9-2. Sec. 18, T9N, R23E Permit No. 69-120 Thursday, August 12, 1982 - I left Exxon's Point Thomson unit' NO. '3,-subject Ok-another report, to go to Mobil's West Staines St. 18-9-23. The purpose of stopping at West Stai.nes was to get our bearing of the directions of other locati OhS. I had taken two snapshots of the well marker on Mobil's West Staines St. 18-9-23, but the pictures did not turn o~t. I found that ,'the extisting w~ll marker did not have the surface .location or the well number bead welded on it. I approved the final abandonment of this location and evidently I overloaded reading the well data right or the marker post was someh°w removed and replaced with another one. Final abandonment was approved August 25, 1976. In summary, I inspected West Staines St. 18-9-23 and found that the data on the marker post was, Mobil West S~aines, Sec. 18, T9N, R23. With no surface data or distinct well num~ber o 02-001,~,(Rev.10/79) .02~01B STATE of ALASKA DEPARTMENT OF NATURAL RESOURCES - DIVISION OF LANDS TO: ~ Hoyle Hamilton Acting Director Division of Oil & Gas FROM: Howard C Guinn ~J %,%J Land Management O'~'~lcer Division of Lands Northcentral District Office DATE : September 23, 1976Fi SUBJECT: ~_~..15~n_~ ~ ~.~ We have reviewed the abandonment inspection report and accompanying photos, for M~bil's Kadler State 15-9-16, Permit #69-38 and West Staines State #1, 18-9-23, Permit #69-120 and agree with the conclusions and recommendations of the inspector We are retaining the. photos for our records; let me know if you want them back. ~ o~Ol B STATE of ALASKA DEPARTMEtIT OF NATURAL RESOURCES Division .of 0fl and Gas To: F- Hoyle fi. Hamtl .ton/~ Acting Director FROM: Harold R. Hawkins Petroleum Inspector September 8, 1976 ,SUBJECT: ABandonment inspection for )4obi1 Oil Co. West Statnes State No. 1 Sec. 18, TgN, R23E, UPM. Permit No. 69-120 ~ .A~st 27, 1976 - I finished.abandonment, inspection, of Kadle.r. State at '4:~ 'pM .a~ fl~ over West Staines' No, 2 on which a rig is setting. Bud Abrm)as said they were going to move the rig this winter. The location looked very geed from the air othene, tse. We flew over, the ice road they used for West Statnes No. 1 and it looked very good. There were no deep ruts and debris, We flew the road a11,the way,. from the beach .to the drill site. We. laaded at .West. I fou~ the drilling ~pad in very ,good sha~, marker was up and data bead welded OK. The pit was ftl,led and I walked t~ full perimeter of the location and found it, level and of debris. One section off ,of the pad ~ the south wa:s: used as a fl,are ~ch is a little ~gh,. :but any work done ~ere now.would make it worse is vegeta~ea growi~ all over and the ,ful~l I~ength of the flare area.. this report and piCjtures should .be sent. to Chris Gutnn, Alaska of Lands, ~[420 Airpo~t Road, Fa.lrbanks, Alaska 99701.. ,,~. smmm~. I inspected West ,Sta,Jnes., ilo. 1 and found the ,location tn very good sha~, !eve1 and clean of debris and all necessary data .OK, including t~ ice road. ! feel this location should be approved for ,final abandonment. S aFTown-AA ar ARK$ f A�R� Mobil Oil Corporation P O BOX 54.14 DEi',iVER. COLORADO 80Z17 September 12, 1975 Mr. Hoyle H. Hamilton Chief Petroleum Engineer Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton: In reply to your letter of July 15, 1975, concerning final location inspections on several of our North Slope wells, the inspection of two wells on August 29 and subsequent conversa- tions with F. W. Schall, this is to advise that we are pre- paring cost estimates and making plans to cover the pits and, hopefully, complete the necessary cleanup work this winter season. It is planned to have this problem taken care of by next summer. We will keep you advised. Very. truly yours, · W. G. Sole Area Engineer WGS/rk ,! Division of Oil and Gas TO~ O.K. Gilbreth, Jr~..~~ Director THRU: Hoyl e H. Hami 1 ton Chief Petroleum Engineer FROM: Russell A. Douglass Petroleum Engineer (on contract) State of Alaska DATE: September 5, 1975 FILE NO: TELEPHONE NO: SUBJECT: Abandoned Location Inspection, Mobil, North Slope, Alaska .Friday AUlgUS~t 29,]975~- Left Anchorage at 8:30 AM via Wien. Arrived .at Arco strip at 10~05 AM. Met Barry Wood, Mobil helicopter pilot, who flew me to the Mobil camp. The purpose of my trip was to inspect abandoned locations of three Mobil wells: 1. North Kuparuk No. 26-12-12 2. Kadler State No.15-9-16 3. West Staines State No'. 18-9-23 ~. ., I arrived at the Mobil camp at 10:45 AM. Here I met Bud Abrams, Mobil Drilling SuperVisor. ~)e talked briefly about abandoned location markers. He showed me one at the base camp location. Instead of welding the infor- mation directly to the marker pipe, he had made a flag out of quarter inch steel plate and had welded the well information on this and then welded it. to the marker. I told Bud that I would check with the office to see if this was satisfactory. !We then flew to the North Kuparuk location (Photos No.1- No. 6). The well cellar had not been filled and the marker had been placed to the side of the w~!l. I told Bud that the regulations require the marker to be attached direct~ to the wellhead in some manner. He made a note to correct the Well'marke~s. There were also some piles of metal and debris on and off the pad. The'reserve pit and the sewage pit had not been backfilled. When I told him they would have to be backfilled he was puzzled. Somewhere along the line he had been informed that the older locations.on the Slope did not have to backfill their' pits. I told him I hadn't heard anything, to that effect but would check with the office 'when we 'returned to the camp."' I called Anchorage about 11:30 AM and talked with Lonnie Smith. He told me the well marker infomation had to be bead welded to the pipe and the flag was not acceptable. In regard to the pits it was decided to check on past inspections and make a decision on the results sometime next week. Bud · agreed to this and the subject was referred to Fritz Schall, Mobil Drilling Superintendent. Bud and I went to the Kadler State well after lunch (Photos No.7-No.12). The pad was clean and the leVeling was rough but acceptable. The reserve pit was not filled and the abandoned location marker was not yet in place. We returned to the Mobil camp since the weather 'would not pemit us to go to the West Sta i nes 1 oca ti on. O. K. Gilbreth, Jr. R.A. Douglass - Field Trip Report Mobil, North Slope Page 2- September 5, 1975 I filled out a Field Inspection Report for Bud and will send a copy to Mobil in Anchorage (a copy is attached). I told Bud that I would call him back Tuesday (September 2, 1975) and tell him of any developments concerning the pits. I returned to Anchorage on the 5:15 Pr,; Wien flight. · In summary, I made preliminary inspections of Mobil's North Kuparuk N0.26-12-i2 and Kadler State No. 15-9-16 abandoned locations. Final inspection is pending a decision by the Division concerning backfilling of reserve pits. On Wednesday September 3, 1975 Hoyle Hamilton called Fritz Schall to inform him that the State would require all pits to be backfilled before any aban- doned location can be approved. RAD:be Attachments (REV. 08-73) MEMORANDOM BEPARTHENT OF' NATURAL P, ESOUROES// D i rec to r ' " , ~,¢ , ~,?~ FILE NO: Hoyl e H. Hami 1 ton ~¢~%/~ Chief Petroleum Engineer ~Vz' TELEPHONE NO: ltlRU' FROM: Lonr, ie C. Smi-~h Petroleum Engineer State Alaska SUBJECT: DATE: August 19, 1974 Preliminary Clean-Up Inspection for Mobil's P&A Hells, Hest Kadleroshilik No. 1, Echooka Unit No. 1, Bell Unit No. 1 ~ st~ines. S~te q~. 1~ [,h~-.:,,e~sen Bay State No, 1. l~Jednesday_, JulY 31,.. 197Zl - Mobil Oil Corporation Drilling Superintendent, Fritz Schall met me at the Anchorage airport where we boarded the Wien co~'~ercial flight for Deadhorse, arriving at 9:05 a.m. We were ~t at the Deadhorse airport by Frontier Sand and Gravel contractor, Jim Taylor who carried us to the Gay Ai~,,~ays Heliport where we boarded a waiting charter helicopter. Mobil's ~Jest Kadleroshilik Ho... 1, Sec. 1~4_, TSN.~_.R14E, U.M. (P&A .3/18/74) ~ _ ~le departed Deadhorse by helicopter at 9:20 a.m. and arrived at the ~;est Kadiero- shilik No. 1 well location at 9:40 a.m. This is the location where the peregrine falcons are nesting ,.nearby along the Franklin Bluffs. t~hen we arrived over the location we were met by one. of these falcons and had to veer a~ay f~m it sharply. As we passed over the location I took a picture from the air, Photo (all photos attached). Then-~e flew to what had been the ice airstrip landed to observe the tundra and to see how the growth was coming along where the airstrip had been used. ~le also landed at the northeast end. of the airstrip where a collection of tundra material had been scrapped over the ice and snow. There appeared to be no p~rn~ane~t damage to the tundra, .just a pile of melting snow intermixed with grass and..re~ts. ~!e flew back to the ~etl location, landed a~d made a ground inspection, ~here I took Photo ¢~2. This photo shows some of the gravel-ice boulders that were placed on top of the pit area and v~ellhead with the P&A marker attached. Mis- cellaneous trash and debris can be seen in the foreground. I then stood on top of the gravel boulders in the pit area and took Photo #3. This photo is similar to Photo #2 with the exception that you can see the Fra~kl'in Bluff area in the backgrom~d where the falcons have been nesting. ~ork cannot continue at this locatio~ until after August 15, when the falcons have completed the'ir nesting. After walking the perimeter of the well location ~e discussed the leveling of the gravel over the pit area where the frozen gravel boulders been placed. I requested that the graYel be ~orked toward the wellhead and tie in t~'ith the gravel mound around the wellhead so that it would be more or less level. After ~..~e took off I took Photo #4 which shows not only the pit and the ~ellhead but the campsite area ~,~he~'e "~here was a collection of debris and trash ~,~hiCh must be buried. Mobil' s Echooka [Init ~I, Sec... 29 TIN R15Ez U.~q'. [~_e..d. PB for USGS Obs. v.~eil 9/2.3/72_) ~le departed the Kadleroshilik .~,~ell and n=aded for the Ecnooka Unit No. 1 ~.~hich ! ~., is on a federal lease several miles furtn.r to the south.. ~e arrived there at 10:20 a.m., flew over the landing strip, road and camp pad and landed at the · }~)!~.er L. Burrell -2- August 19, 197~ ~.~ell site. A geoFhysicat crew is currently parked on the camp pad and roads and part of the landing strip, u:i!izing it as a su~.~er base camp. They are not utilizino tn~ '.~ell pad itself. This area had been fairly well cleaned up at one time. I took four photos. Photo · ,~o shows the large berm 'that ren'~ains on the side of the old reserve pit area. This berm has been reseeded and even thc. ugh it is not appare~'t'in the picture, the grass is coming along quite strong. In the background can be seen the gravel road that leads to the river, on the ri~h~, there is a filled in a,.a with a portion ~;h~ch sunk, and due t~ 'the drainage fro~ the hillside there has been a pool accumulate there. Photo ~6 is a vie~ toward the ~tell pad fr~t across the filled reserve pit area, which is in the foreground. It shows a drainage ditch coming froJ.~J the hillside into the filled area where a channel has erroded. The P&A marker can be seen 'ia the background as can the geophysical camp which is using the gravel roadways and airstrip as a subtler base camp. Photo #7 shows the filled in pit area and how part of it has sunk quite a bit. There are bits of debris showing, pieces of pipe, boards, rubber protectors, barrels, and in the background can be seen the P&A m~rker'. Pho'~o ~!~8, in this photo the P&A marker can be seen welded to the ~ellhead ~lange, the temperature survey nipple and valve connected to the center of the flange and the filled in cellar area. I recommended that more gravel be pushed into the reserve pit area both to cover the debris that has started poking up a~d to i~ake the pool collection area much smaller. ~qy recomme~,,dations for further ~.~ork at this location will be passed on to U.S.G.S. representatives and are ~ot required directly of '~'~-~ ~n~:~ operator by this division. .~J_c_Cu!_l.o~oh - Fin Creek Unig #_l_a_ Sec 25, T2N, RISE., U.~,'~. _(Fed - P&A_ 1~9-72_]__ We deaprted Echooka location at 11:00 a.m. and flew over to the McCutlogh Fin Creek Unit ~Jl location in just a 'fly over. I observed ~any barrels scattered around on the ?&A location. The ~qobil representer'ire ~ta,n. ted to observe and photograph the path taken across the tundra by rolligons that made trips from the Echooka well site to the Bell ~ell site during the last t~,~o years. Colora. do Oil and Gas - Shaviovik Unit #l, Sec 8, T2N, RIgE, U.~I. (P&A 7-4-.69~ t~e~, flew northeast to the Shaviovik P~ ~ll site '~.~here the rig was still standing over the ~,~ell and a campsite abandoned nearby. I took two photos of this location. This lease and well ~.~ill be transferred to the state from the federal government in the near future, and since the rig and camp are still in place, there will be some future clean-up work and inspections by this division.. Photo ~9 shows the rig standing coraplete v~ith its equipment over the location. It appears that very little or no gravel ,~as used for the pad. The rig has been here since 1969 when the well was abandoned d~e to litigation. It is apparent that the ,,~eather is taking its toll on the buildings and l:omer L, Burrelt A~.~,.-3ust !9., 1974 A quar'Ler of a mile to the east I took Photo stacked equipment, trucks, pipe and so forth. In theua~ cksre, und closer to the river is a large stack of 55 gallon drums. Ue continued to follow the rolligon trail northeast ~.,~ntil we arriN'ed at Arco's L~est Kavik airstrip and sup~]ly pad '" . - w~ere we landed to refuel. ~"~obil's superintep`dent wanted to observe the condition of the~"',,~"~=. ~.~. ri~ =:~, w;'~ich is stacked on this pad. The inspection revealed tna'c bears had bro~e,~ i~to most of the crew camp quarters The dm~age was m$~t~ confined to ~ne entry through the doors or by tearing the doors off. Hr. Shaw was particularly interested in the condition of this rig since ~,!obil has the rig on retainer and plans to drill two wells this winter with the one rig. Available rigs are rather tight on 'the North Slope at this time due to the increase in drilling activity. ~:o~l is organizing to a,~tl v~ ~ ~ ng cut down time to a minimum when moving onto a new location a~d the rig for drilling operations. They feel they will be very pressed to drill the two wells that are planned and make the move betv~een wells during the hemal winter ti~ span. They hope to accomplish this by moving the camp before freeze-up by using rolligons under special pemits. This would require about twenty trips from the Nest Kavik location, across the tundra to the northeast to the Bell location, and from there north te the coast area. and across to the vicinity of their Bullen's Poi~t staging area (40 miles), and from there approximately 8 miles south of the Mikkelsen Bay State ~l well to the new location. ~4obil's Beli Unit We departed the Nest Kavik location and proceeded to the aeli Unit -~l location, arriving just before 12:00 noon. I took Photo -'J~ll from the air as we passed over the airstrip; it shows the airstrip in the foreground, reserve pit area in the background, and the wellhead with the P&A marker, and the gravel campsite pad. These are all connected by a road on ~-~hich cap, be seen a rolligon and crew quarters. On the campsite pad to the right side is the cat which is being used to level this location° After we landed i walked 'the perimeter of the location and took Photo ~:12 of the P&A " -~ ' marc,er. This photo also shown how coarse 'the so calleo (~ravel is here. It is a mixture of dirt and ungraded , ' rOCKS, it ranges from~,~..~-"a~l pebbles on ~;p into the boulder size. It is very hard to do a smooth job of leveling or grading with this type of soil. Photo ~}13 is from the campsite pad back toward the wellhead and shows tim partially filled and leveled pit area and the P&A marker. Photo fil4 is from the southwest corner of the pit area, looking back toward ~llhead marker that can be seen in the background. The pit area, was still pretty wet and unleveled. Several boards, wire rope and pieces of debris had not beeF~ covered, and a great deal of moisture is being squeezed out o'F~ the mud that was in the pit when filling com~,~nced. It rained the morning of our arrival which did not help the drying up of a pit like this. U.omer L. Burrell A,arjust 19~ 1974 l~;hen walking the perimeter of the pad I also located a six inch drain pipe ...... ~e ren'~oved or buried. Off of +;~o pad on the east side of ~,~.= caFnpsite area was a piling ~-~hich h~d been used for the geronimo line the top of the rig ~mst. %'ia. d~scussed the remaining gradi.q§ and c]eaa-up ,.~ork and concluded' ~ '~ %:;0 n~ore days work %.~'~u~d be required for co~p] ~-' e~.]on I informed I--Ir. Schall that i would have to come back after ti~e %,~ork Nas complete for the final inspection. }~ol_]]~on Path Across Tundra ~-Je departed the location and again flew the route which the roll igons had previously used across the tundra so we could observe the lack of damage that they impart to the 'tundra, and with the thought in mind that }.~obil vHlt be seeking a permit for moving their rigs before freeze-up. As a result of ply observations of the rolligon pa'u~s I would reco~.end that they use different path%qays on each trip because it appears that repeated tracking on the same path does cause light da~age, especially where %~et conditions exist. Nob!].l.~S Buli_en Poi~tt~:~u_~ Staqinq. Area ~e flew to Bullea ~oint, Nobil staging area on the coast and had lunch. Following lunch I took a walk around the Mobil fuel revetment area, and Iqr. Taylor sho$ted me how they ~.~ere hooking up the pillov~ tanks and install- ing the pit liners to further protect auainst possible fuel spills. cre~s were in the process of installing several more pillow tanks to pro- vide a total of ten by the time winter times operations b~g)n. Supply barges due to arrive in late Au~uot will bring additional fuel and to be staged here for use in drilling the t~o wells this winter. Point Gordon Gravel S~. 31, %~.Ie then 'Flew down the coast to Point Gordon gravel spit and. landed. ~'.~Ir. Schatl showed ~]e ho~ the ice had built up this gravel spit to about t~ice the width from the previous year. He took more pictures of the spit and stated that he has other photos to prove this growth. He po'i~]ted out that there v,,as a great deal of gravel available here and their plans are to make a proposal to the Division of Lands to ~ine the gravel which is over one foot above the high tide line and utilize it to build their nearby well site. He said this would prevent hauling gravel over a much lon§er haul from a river area. It sounds like a reasonable proposal with a good substantiation of data on the availability of the gravel. ///Nobil's - ~est Staines State F;1., Sec. . 18,~ TgN, R23E, U.iq. (P&A 7/2/71) We next flew to the West Staines State #l, arriving at 2:40 p.m. Afro)' landing I took Photo #15 looking to the southwest and showing the P&A marker on the ~ellhead and the level pad area beyond. I-~ol~.er L. Burrel 1 -5- August 19, 197q. Photo ~16 is a view to the east and shows the level gravel pad across the original drill sl~e and over to the campsite area. A large neat stack of '~oarc...s can be seen in the b~c!(gro:,,~nd. I ~?as infori~ied that these boards ~-~;ere left here o~~, purpose because they hope to use this as a staging area ~-~.~. ~:, k~,.qloading so',~'~,· ._ of the rig that ¥~ill be moved to the .ne:.~, ~,, ~.~ell location p. ear ),ere. The P~A marker can also be seen on the right hand side of P~:oto #17 is a view to the south showing the filled and leveled pit area. Photo #18 was taken fro.~ the air after we took off. An arrow shows the location of the P&A ~arker, the filled pit areas and 'the level gravel pad. The larger ~..,~ater covered area is a portion of the secondary reserve pit area that was made for this well. ~-~alked the perimeter of the gravel pad area, and although the gravel is fairly rough, I consider it level enough for approval. However, I noted considerable scattered debris that could be hand picked up, small boards, paper and trash. !~,~obi 1 ' s-Mi kkel sen ~e depar'~ed the ~est Staines and fle~ west to the [qikketse;~ Bay State #1 arriving approxi.~ately 3:00 p.m. As ~,~e approached for the landing I took Photo #t9 ~,~hich shows the P&A marker on the wellhead, the well leveled gravel pad, and the filled and level pit area. 2,fret ,~-~e landed I took Photo .#20 which shows a view to the southwest, showing the filled and level pit area, the P&A marker on the wellhead, and the unfilled cellar. Also in the background can be seen some pipe. I also noted debr~is, s~ch as drilling bits trash and metal scraps ~fi~ich have not been cleaned ~:~ ~,~.ov,.,d or buried. Photo #21 is a filled f~,~el pit revetment that has no~,~ slu:~,ped and sun[< in and has a ~_.~ol of oil standing in it. Everyone agreed chat additional ~ravel t~ou!d have to be filled in here to cover this oil~ In the background over the edge of the pa~ can be seen some debris. As we took off and I noted that there a~e several pretty good.piles of plate steel and miscellanao,~s debris arot~nd the edge of the pad. Photo #22 is a view from the air after ~e took off and it shot4s the 'level pad, the P&A marker, and the filled and level pit area. ~e proceeded to Deadhorse arriving about 3:30 p.m. and Hr. Schalt and [~]ro Taylor took the chopper an~] 'fle,~ on to review the locations they plan to build 'For this winter. ! stayed at the Gay Airways office and 'Filled out my Field Inspection Reports for each of the five wells ~:~e had visited. (cop'~es attached). I later rode over to the Nabor's camp ~¢ith one of Mobii's personnel and there I met Nr. Schall and Nr. Taylor at dinner time. I gave ~;Ir. Schal! two copies of each one of the Field Trip Reports. t wrote remarks o~ each report noting the u~tsatisfactory items previously discussed for eaci~ one of the five wells. Homer L. Burrell August i ~.$, l'~?,.'~ lney dro~ze ~e ~:.c~, to ~I,~ Beadhorse airport at 7'30 on a ~'.iien flight, at ar~)~roximately.. 9'30 ~', ...... ~.~ and arrived On this field trip I moue. '~ a prelii~inarv~ clean-t:o, ins?ection of four ,:oo~"~ ~'! P&A locations, one Federal lease plug back l.n. cation, observed .supplies at I~:~o staging areas, obserwed the effects on the tundra of rej~eated rolligan travels a.~:a inspected a possible gra¢~, source area included on Field Trip Reports require the ...... '~ ' "' . . o~r~.cor to oo addi.~onal hand pick up of debris at each location a~d additional leveling and filling gravel at four locations. Attachmen'Bs cc: Pedro Denton Division of Lands 44©Li ET-Ark— / 6,e., To E) /.Lrvrie.4 rh..l } ; "1'e (/f Fr 2 . 57%-c; t% Gt vr4 5 <e E ✓. I �/ I 3. PO vxa 4<L,. A /2. /'I lXvL7 i /! 5.c, / R23 t; /A,,4l )/31/')4- P40d /L - W4-sT STA/A) s STATE C;tew twiflt p A tel � � A 7 /2./7 2, 11-41 /� 3 Sec /B 7!N Z 1 2/3 2 m e,L — dsVt 75 5 Yr.tr /(v1 i f° S i , I. . PTIA ( /a /)6(r k) - fo?o )S-- Yee/8, / 2 I.I.t '7/3 MoBit - r Sr /k -rr,E sr* - i / / r- p i I ;11,_4 ��u��VL oTaK� �vlrw 7r P ,..s. Sep /8, TIN, R2. 4". 1A M i/ 3lh4 rnotaxL, WEST JTaiiuES Alas4 0i1 and Gas Conservhtion Commit ee Field InspectionfReport letAtor . Mod', Oh v.3 P. Well Name ,& So. lie . ia au:e / Nuffiber Inspected by 7 Operator's Rep. 1 ;trsc t Contr. Rig No. ^' Satisfactory Yes No Rema rks» Item Well Sign Safety Valves - Floor Safety Valves -Kelly Safety Valves- Subsurface BOP Closing System Remote Controls Drilling Spool- outlets Flow Lines Kill Lines Manifold Chokes 4.. A .. .1 • e . i— . Signed L7 Satisfactory Yes No () () 11. () () 12. ( ) 13. () () 14. () () 15. (} () 16. () ()" 18. (V)' () 19. () () 20. Item J. Date Drilling Permit Manifold Pressure Test BOP Pressure Test Reserve Pit Pit Berra Location Berm Fuel Berm Operations off "Pad" "General Housekeeping" Abd. Marker in place Water Well covered .% o . ALASKA $ ' · E ~ IT E t I ~ "! IDI~E - DE~PART, 4EN, O, NATURAL P~ ~,>,C~ i /~ .~, DIVISION OFOIL AND GAS~/~ TO: [---Homer L. Burrell · D i recto r I THRU: O.K. Gilbreth. ~/~...~' Chief Petroleum Engineer FROM.. Lonn i e C. Sm i th Petroleum Engineer DATE : · SUBJECT: November 30, 1973 Inspection of Various Locations on the North Slope Tuesday, September 18, 1973- I departed Anchorage by commercial aircarrier, arriving in Fairbanks at 7:50 a.m. Due to continued bad, foggy weather on the North Slope the flight was unable to continue. Following a six hour delay, the airline returned me to Anchorage and the flight was rescheduled the next day, ' Wednesd..a.y~ Sep.~ember 19~ ...I.9,7.3 - I departed Anchorage on the rescheduled flight but the plane was unable to land at Fairbanks due to fog and rain. The flight returned to Anchorage for fuel and then proceeded back to Fairbanks and on to the North Slope arriving at Deadhorse in the early afternoon, i immediately made contact with the' Gay Airways Inc. helicopter pilot and we decided the wea- ther was sufficiently good and the daylight adequate for photos. We took off at 2:20 p.m. and proceeded to the Mobil West Staines location, approximately 50 mi les east of Deadhorse. On the way we flew directly over t~o other loca- ti ons. Mobli's Mikkelsen Bay S~tate #13_-9, t9~.. Sec.. 13~ ~9~.~ RIgE,' U.M.. This well is approximately 30 mi les east of Deadhorse. Mobil has not completed the abandonment clean-up work at this well site where the well (item !) was plugged and "Abandoned" September 30, 1970. Photo #1 (see Appendix A for all photos) shows a large stack of mud supplies (item 2) beyond the open pit (item '3). Other equipment (item 4) is stacked around the perimeter of the pad. This drill site is viewed from the west toward the east. The gravel airstrip (item 5) 'and connecting road is in the background. Exxon's East Mikkelsen Bay State.~l_, Sec. 7, T..9jN~21E,~ UBM: As we passed on the south side of the this drill site, ! took ?hot~. This photo shows the rig, still standing over the well with alt equipment and the camp still intact at this location. I was informed by the chopper pi lot that this camp had recently been broken into by bears and as we swept past the location I could see the open doorway at the east end of the campsite. (i passed this information to the rig owners who went in two weeks later and re- boarded-up the camp) This well was plugged back to 3000' and "Suspended" for observation of permafrost on June 9, 1971. Mobil's West Staines State #i8-9-23, Sec. 18, T9~, R23E~..U.M. As we approached this location directly from the west i took the first (Photo #3) of the nine attached photos (nos. 3-11) of this location. This aerial shot of the West Staines State location, shows the well pad (item I), pits (item 2), supplies (item 3) stacked on the pad and a building (item 4). We circled the PRINTED aY THE ~T~DARD ~QleTEM OOklPANY, U,$.A. ZIP:SET ~) , . . Homer L. Burrel ! -2- November 30, 1973 location, landed and I took Photo #4 looking to the south showing the wellhead marker (item I) and piles of supplies (item 3) on the south perimeter of the pad. Photo #5, taken from the west side of the wel Ihead, looking across to the east, shows the capped wei Ihead with the attached P&A marker (item I) the rat hole · (item 5) and the mouse hole (item 6) casements were still in .place along with the cellar (item 7) and the pilings (item 8) for the rig. In the background can be seen neat stacks of supplies (item 3), equipment (item 9), a building (item 4), and a fuel revetment (item 10), with a pi l iow tank roi led up on the ground. I walked to the southwest corner of the pad and took Photo #6, showing a stack of tubing and casing (item I) located on the west edge of the pad , (item 12) with its uneven gravel and, in the foreground, a stack of fuel drums (item 13), some empty and some full of fuel. Also a box containing a pillow tank (item 14) and a large stack of wood piling, (item 15) is. in view. Photo #7 was also taken from the stack of tubing and casing (item I!)' looking across to the east. It shows a stack of miscellaneous pipe and metal supplies (item 16) and across the pit area (item 2) a large stack of mud supplies (item 17) with the building (item 4) to the left side. Closer examination of the stacked mud supplies showed them to be in very poor condition with many of the sacks burst' or the container had leaked sufficiently to al Iow water and moisture to get to the mud whiCh had burst the sacks due to swelling. Photo #8, a view from the south to the northeast, shows a large stack of pi ling and boards (item 15), the wellhead and marker (item I) in the background with other stacks of supplies. (item 3) and the building (item 4) beyond that. The helicopter can also be seen near the lake on the north edge of the pad. Photo #9, a photo looking to the northeast along the north edge of the pad, shows the fuel revetment (item I0) with the gravel berm (item 18) partly covered by a plastic liner (item 19) which has been partly burned along with some boards. The remains of the boards and liner are now trash. A rolled up pi I Iow tank (item 14) can be seen in the foreground. Photo #lO.was taken from the southeast corner of the drilisite pad looking from the northeast across the pad at the area where the drilling crew camp (item 20) had been located for thls driilsite. Scattered and ungraded gravel areas are evident in this photo as well as scattered boards (item 21) and a trash pile (item 22). Photo II was also taken from the vicinity of the southeast corner of the drilisite pad, but it is looking back over the stack of deteriorated mud (item 17), across the tundra to the south. In the background can be seen pieces of pla§tic, paper and trash (item 23). The pit area can also be seen in this photo, it-appears to be just another lake, (item 2). The nine photos at this location show the pr~ogress of the work to date per- formed by Mobil's crews. This well was plugged and "Abandoned" on July 2, 1971 and awaits clean-up so that the final location inspection can be made. Major equipment and materials have been pi led in neat stacks large enough so they may be located in the winter time when the frozen tundra will al low hauling to a permanent location. There appears to be much work that hasn't been done, such as hand pick-up of trash and debris. This work wi il have to done in the summer time when the snow isn't there to cover the. debris. The wel i- head work has not been completed, no attempt at grading the pad, filling in the cellar, pulling the mouse and rat hole casements, covering or cutting up the pilings, leveling the fuel revetment or filling in the pit area, has been attempted. The paper work on this wel I, based on a P-3, approved July 15, 1971 indicates that clean-up work was to have been performed and supplies Homer L. Burrell' ~' November 30, 1973 moved out by the end of fall of t971, as the weather permitted. It appears we are at least two seasons away from the final inspection of this location where the well was plugged 2½ years ago. I recommend that we contact the operator with regards to his intentions and timing to complete the final abandonment'of this location. We arrived back in the vicinity of the ARCO's base camp at Prudhoe Bay at 3:55 p.m. To the northwest there appeared to be enough light to continue inspection and photos so ! had the pi lot head for the Point Storkersen well. As we ~flew past the Point Mclntyre landing strip ! noted the tremendous amount of clean-up .work that had been performed in that vicinity. Large stacks of oil drums had been stock pi led in neat stacks. Trash and debris had also been picked up and piled. I noted a crew of three men working along the coastline at the time we flew past and ! saw more pi les' of drums and debris stacked along the beach area. Exxon's Point Storkersen #1~. Sec. 7~. TI2N.~..RI4E, U,M. When we arrived at this well and circled the location I was amazed at the .remarkable clean-up job that had been accomplished for this had been one of the unsightliest well locations on the North Slope area. As we swung around the location I took Photo ~12 which was the first of eight photos (nos. 12-19) taken at this location. This photo, taken looking toward the northeast, sho~s the wellhead (item I), the filled in pit area (item 2), a neat stack of mis- cellaneous supplies (item 3), and the old camp area (item 4). We landed and t quickly took Photo #13, looking toward the east showing the wellhead with the christmas tree still in place ( item l ) with all outlets~both on the cas- ing and the christmas tree, closed with blind flanges. Cellar boards (item 5), are still in place along with refrigeration pipes (item 6) which can be seen sticking up around the perimeter of the ceilar. Both the rat and mouse hole casements (item 7) are still in place. Photo #1.4, taken looking east along the south edge of the gravel pad, shows the location (item 4) of the old camp area. This area was originally one of the dirtiest areas of the location. It is now remarkably clean; however, there are still bits of trash (item 8) such as paper cups, cans and such that need to be picked up. Photo #15 is a view of the wellhead' (item I) looking toward the north. This picture is dark even with the camera open to the widest setting. Several things can be seen how- ever, in the foreground are some boards and also a steel band sticking out of the gravel (item 9). These items obviously were not picked up after the back dragging was complete. Item lO is gravel that was never graded level. Photo #16 was looking to the east from the edge of the gravel pad and shows the lake (item Ii) east of the location, miscellaneous debris (item 12), both in and around the lake, and one of the buildings (item 13) at the Point Mclntyre landing strip. Photo #17 was taken looking toward.the northwest and shows the large neat s~lscellaneous supplies (item' 3) that are to be re- moved from the Iocatlon and th~ northwest corner of tn~ oraveI pad (item 14). Photo #18 shows two pieces of debris (item 15) located just off the north- west corner of the pad. Photo #19 shows the wetihead (item !) looking to the south and the large neat stack of miscellaneous supplies (item 3). Homer L. Burrel I -4- November 30, 1973 This well was plugged and "Abandoned" September 3, 1970 but location clean-up for the final inspection has yet to be accomplished. It is obvious that a great deal of work has occured at this location since my previous inspection here in August of 1972; however, the work is not complete, tt is evident from several of the photos that additional hand clean-up, work is necessary both on the pad and in the vicinity around the pad. The wellhead itself is in an unsatisfactory condition with the christmas tree being .left in place. It should be removed and a proper P&A marker instal led. The cellar should be removed and or fl lied along with removal of all the refrigeration pipes and mouse and rat hole casements. The stack of miscellaneous supplies will have to be removed prior to the final inspection. It is recommended that the operator be contacted as to the timing and the amount of remaining work so that the final inspection can be performed next summer on this location. We departed the Point Storkersen location at 4:38 p.m.. It was too dark for any further work of this sort, however, it was sti I I' ! ight enough for visual inspection so i had the pi lot swing over the Kup Delta location which is very near to this location. (The possibility of this coastal area being fog bound the next morning was very imminent.) As we swung over the. location-! could see that a great deal of clean-up had been done here since my last visit. It appeared, however, that the 30 foot aluminum mast that had been left on the location last year was still there. It does not belong to the operator and he doesn't consider it his responsibility to remove it. In general the location looked good and we swung back south and headed for Dead- horse, arriving at the Gay Airways helicopter landing area on the Deadhorse airstrip at 4:55 p.m. After making plans with the helicopter pi lot for an early morning departure i drove to the Mukluk base camp and got a room for the even Ing. At dinner I met Mr. Tom Moseley, a geologist with the U.S.G.S., and found out that he had made plans to use the same he l i copter for the next morning. Mr. Moseley was recording temperature data through the permafrost interval in many of the.wel Is that had been made available to their use on the North S lope. Thursday, September 20, 1973 - We drove from the Mukluk base camp to Dead- horse airstrip and after loading Tom Moseley's equipment into the helicopter we took off .at 7:i5 a.m. and headed for Prudhoe Bay where ~e landed at the Prudhoe Bay landing area and picked up Mr. Frank Hunt, an Arco foreman, who was to help Mr. Moseley with his survey. ARCO's North Prudhoe .Bay_ State #23-12-14, Sec. 23, TI..2N, RI4E, U.M. We then flew north to the ARCO's North Prudhoe Bay State well where I took Photo #20 an aerial view of the location from the south. This photo shows 't~e well house (item I)~ the drilling rig matting (item 2) and the open pit area (item 3). After a brief landing to drop off the two men and their equip- r.~nt we continued to the northwest and soon arrived at the Kup Delta location. Homer L. Burrell -5- November 30, 1973 Continental's Kup Delta #51-1 and 5t-2, Sec~__ll,.Tl2N~ _R. 13E,. U.M. I took Photo #21 from the air as we approached the location from the south- east, the Beaufort Sea can be seen to the north and northwest. This photo shows the wellhead (item I), the filled pit area (item 2), the camp area (item 3), the 30 foot aluminum tower (item 4) and tracks made by a roi i- agon (item 5). These tracks are not as damaging as they might appear, for they only mashed down the grass which appear in the photo to be a heavy deep. track. Two wells were drilled from this location, but there is only one surface hole because the second well was kicked off at the 3,000 foot level after the first wel I had been abandoned. We landed and I took Photo #22, looking back toward the northeast showing the wellhead (item I) with blind flange, the 30 foot aluminum tower (item 4) and the cellar (item 6); the helicopter can also be seen in this photo. Photo'#23, was taken looking toward the northwest from the edge of the old pit area and shows trash (item 7) scattered over a considerab le area. Pho_t~o #24, was taken from the woutheast portion of the pad looking back toward the west and shows the wel Ihead and cellar (item I) and some trash in the foreground (item 8). Photo #25, was taken on the tundra looking north along the west end of the pad and shows some 3" X 12" boards that were left embedded in the tundra (item 9)° This well has been "Suspended" since August 26, 1970 and considerable clean- up work has been performed here since my last visit in August of 1972. We departed the Kup Delta at 8:55 a.m. and headed west for the Milne Point loca- tion. P I acid's P ! agham Beechey Poi nt ~_.upp I y Depgt; Sec .... 14, T.I_3N, RI_IE,~__U ~M._- As we flew west along the beach we soon approached Placid's Beechey Point Supply depot and I took Photo #26, which shows'the gravel stock pile (item !) six full pillow tanks of fuel (item 2) and a large supply of casing and pil- ing (item 3). This location seemed to be in the same clean condition as on my previous visit last year. Continental's Mi Ine Point_.#.l.8-1,._ Sec. I! After flyin9 slightly past the Mtlne Point location we circled back and approached it from the southeast and I took Photo #27 from the air which shows the well- head (item I), the fuel revetment with two pillow tanks (item 2) and the level- ed pit area (item 3). We landed and i took Photo #28_ : lookin9 toward the northwest, showing the wellhead with blind flanges on the christmas t-ree (item I) and the cellar and ri9 mattin9 still in place (item 3). I then took Photo #29~ Iookin9 west along the north edge of the gravel pad, showing the fuel revetment with two full pillow tanks in place (item 2) and a wellsign on the edge of the pad (item 4). Photo #30, was taken on the east edge of the gravel pad looking north, It shows trash and debris scattered off the north- east corner of the pad (item 5). This had been the location of the crew quarters. .Photo #31, is looking from the middle of the pad toward the north- west and shows scattered debris on the northwest corner of the pad (item 6). This well was "Suspended" July 18, 1970 and considerabl, b clean-up work had been done since my last visit in August 1972. We took off at 9:25 a.m. and headed west for the Colville River delta area. Homer L. Burrel I -6- November 30, 1973 Gulf's Colvi I le Delta Stat_e. //I, Sec.. 9, Ti _3~1.~. R6E, U.M. There was very little to distinguish this location since it is on the Colville Delta, which is sometimes under water at high tide or when the river runs high. We soon located the well and ! took Photo #32, from the air, looking toward the west which shows the wellhead (item !) and a stack of material (item 2). We landed and ! took Photo'//33, looking toward the west which shows the wellhead with P&A marker in place (item I), a stack of material in the background (item 2) and some pieces of trash which were plastic material (item 3). Photo #34 was a similar view, taken from .the north looking back to the south, sho'~ing __ the wel-lhead?P&A' marker (item I),'a stack of material (item 2) and several pieces of plastic trash (item 3). This well has.been plugged and "Abandoned" and this was the final inspection on this location. Although there still remained a small stack of materials, mostly boards to be removed from the location, Ifil led out a Field Trip Inspection Rep.oft (atta¢-h'e'd) statin.~ .that the final inspection would be approved when these ~tems were removed..{commu- nication with Gulf and a duplicate photo of this location resulted in the re- moval of the trash and materials and a formal release of the bond on this lo- cation was approved). .. · · We departed the .Gulf location at !0:00 a.m. and headed back so, uthe~st where we soon flew past Mr. Bud Helmrlcks house and airstrip located on the Col- vi lie River Delta. I took Photo //3.5 as we fiew past showing his house and miscellaneous buildings (item !), his airstrip (item 2) and a large stack of fuel barrels beyond his house (Item 3). Union's Kalubik's Creek Unit #_l, Sec..10,_ TI2N, .R8.E_,. U.M.. This well was plugged March .27, 1970 and is now waiting for clean-up and final location approval. Mr. Helmrick has a contract to clean up this location. As we flew past, I took Photo //36 showing the wellhead with marker (item i), the pit area (item 2), supplies and equipment still on the location (item 3) and the location of the rig stacked at-the' mouth of the Kal ubik River (item 4). As we proceeded back to Deadhorse I took Photo //37 sh~ing BP's new Prudhoe Operations Camp under constrUction. The installation construction crews were at v,,ork putting it together. It shows the main building (item i), tanks in the background (item 2), and the Spine Road (item 3). Just a little ways down the road we came to the BP Central Power Plant where I took Photo #38 showing the power plant under construction (item I), the transformers (item 2) and the gas supply well location in the far background (item 3). We arrived back at the Gay Ai'rways helicopter landing site at the east end of the Deadhorse strip at !0:37 a.m. and I quickly made arrangements to depart Deadhorse on the Wein flight at Ii:00 a.m. I noticed the drilling rig had been moved from the location of the Socal well #31-25,at Deadhorse and.a new control tower had-been constructed just to the west of the old Socal pad. Some supplies have been stacked up around the wellhead but all of the rig equipment, debris and trash have been removed. The north edge of this pad had at one time been a regular "dump ground" for camp trash. Homer L. Burrel I -7- November 30, 1973 I departed Deadhorse on the 12:15 p.m. flight and returned to Fairbanks and Anchorage by 3:00 p.m. On this field trip i took 38 photos of ten different locations On the North Slope covering an area from 50 mi les east of Deadhorse to 55 mi les west Deadhorse and as far as 20 miles north of Deadhorse. This field inspection trip has already resulted in the final approval of the "Abandoned" Coivllle Delta location (Gulf) and it has shown the degree of clean-up work that has been performed by operators on other locations, which gives a good idea the work yet remaining to be done. It is recommended that we talk to certain operators concerning work remaining undone where wel Is have been plugged, such as Exxon's Point Storkersen and East Mikkelsen wells, Mobil's West Stalnes State and Mikkeisen State wel Is and Union's Kalubik Creek well. Attachments APPEND IX A 6-8 Attachments PHOTO NO. SUBJECT PAGE NO. I8, I9 2O 21--23 24, 25 26 27-29 30-3I 32-34 35 35 37,38 Mobil's - Mikkelsen Bay St. #13-9-19 .............. i ExX°n's - E. Mikkelsen Bay St. #1 ............... 2 Mobil's - West Staines St. # 8-9-23 .............. 3 f Mobil's - West Staines St. # 8-9-23 .............. 4 Mobil's - West Staines St. # 8-9-23 . . 5 J Exxon's - Point Storkersen # Exxon's - Point Storkersen # Exxon's - Point Storkersen # · · · · · · · · · · · · · · · · · 6 Arco's - N. Prudhoe Bay St. //23-13-14 ............. 9 Continental's - Kup Delta #51-1 & #51-2 ............ !0 Continental's - Kup DelTa #51-1 & #51-2 ............ !i PI'acid's - Beechey Point Supply Depot ............. I2 Continentai's - Milne Point #18-1 ............... 13 Continental's - Milne Point #18-1 ............... 14 . Gulf's - Colville Delta St. #1 ................. I5 Gulf's - Colville Delta St. #1 ................. I6 Union's - Kalubik Creek Unit #1 ................ 17 BP's - Operations Camp and Power Plant ............. 18 AN QA[ POLARO1D'' LAND PHOTOGRAPH Photo #3 9-19-73 STE DATE NAM Staines St #18-9-23 AODSS Sec. 19, T9N, R23W, UM Well Status: P&A 7-2-71 Location clean-up not cemap-l-eto Item #1 Capped well and pad -Item #2 Pits Item #3 Misc supplies Item #4 Building AN OPA7:1‘1." POLAROla LAND PHOTOGRAPH JCT Photo #4 NA Same as #3 Item #1 Capped wellhead w/marker Item #3 Misc supplies CRIGiA.AL POLARDiD ' LAND PHr,_`,TOGRAP'H - 9-19-73 '1J9 Photo #5 DAP= 9-19-73 . Same as #3 ADDET . Item #1 Well head w/P&A marker I lem ff3 Item #4 Building Item #5 Rat hole Item #6 Mouse hole Item #7 Cellar Item #8 Rig pilings Item #9 Equipment Item 1110 Fuel reventment & pillow tank 1 3 le A 4 PZ)LAROiD LAND PHOTOGRAPH Photo #6 NAW Same as #3 Item #11 Tubing and casing Item #12 West edge of gravel pad Item #13 Fuel drums Item #I4 Pillow tank in box Item #I5 Wooden pilings 02,:C:NAL P;DL_AP,OI D" LAND PHOTOGR1-\ PH Photo #7 Same as #3 9 - I 9 Item #2 Pits Item #4 Buildings Item #I1 Tubing and casing Item #16 Misc pipe & metal supplies Item #17 Mud supplies AN O'r POLAP,O:D LAND PHOTOGRAPH • Photo #8 9-19-73 Same as #3 Item #1 Wellhead and P&A marker Item #3 Misc supplies Item #4 Building Item #I5 Wooden piling & boards -4- 8 AN "ORaNAL - ' - '0L.:AROJD''' LAND PHOTOGRAPH s Photo #9 NAmt Same as #3 ADDREZ,S Item gl 0 Fue I revetment Item #14 Pi I low tank Item #I8 Gravel berm Item #19 Plastic liner AN • Li-AD PHOTC Item #20 Crew Camp area Item #2I Boards Item #22 Trash pi le AN ORiDAV. !AND PHOTnRAPH .J3J7CT Photo #11 S(. Same as #3 Item #2 Pit Item #17 Mud supplies Item 23 Trash & debris DATE 9-19-73 Photo 111 1 f: 9-19-73 NAM Same as #3 flT 9-19-73 -5- 9 0 17 23 11 Form .~EV. 9-30-6 9 STAT(OF ALASKA S~brnit "Intentions" in Triplicate & "$ub.~equent Reports" /n Duplicate OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (I~o not use this form for proposals to drill or to deepen Use "~P~LACATIO~ 'FOil P'E~J~,ii'£'-=" tor such 'piobosali) OIL ~,. ~ o^s J'-"l Wildcat WELL __ 0THEa 2. NAME OF OP~TOR Mobil 0il Corporation 3. ADDRESS OF OPERATOR Pouch 7-003, Anchora~;e~ Alaska 4.LOCATION' OF WELL At surface 1514 FNL 99510 1730 FEL' Section 18, T9N, R23E, UPM 13. ELEVATIONS (Show whether DF, RT. GR, etc. 62 DF est. 14. Check Appropriate Box To Indicate Nature of N'oti'ce, Re %: API NUMERIC.%L CODE 50-0892001 6. LEA. SE DI/~GNATION .~;.ND sERIAL NO. ADL 28380 7. IF LN'DI.~. A.L,~O'~ OR TRIBE West Staines. State 9. WELL NO. - 18-9-23 10. FIELD A/~D POOL, OR %VILDCAT Wildcat 11. SEC., T., R., M.. (BOTTOM HOLE OBJECTIVE) Sec. 18, T9N, R23E, UPM 12. PEt~'~LIT NO. 69-120 ~ort, or Other Data rRaC~Ua~ ~arAT [__[ REPAIR WELL CHANO~ PLAN8 SUBSEQUENT R~PORT OF: PULL OR ALTg[~ CASINO [= WATmR BHUT-OFP RgPAIRING WZLL ' ~ MULTIPLm COMPI.ETE FRACTL'R~ TReATMeNT J ~ ABANDONs 8HOOTINO OR ACIDIZING [ ,-' J ABANDONMENT* (Other) ~O~her) (No~z: Report results of multiple completion on Well , Completion or Recompletion Report and Log form.) ]5. DK~CRIBE I'ROPO~ED OR COMPLETED OPERATION~ (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Well was abandoned as 'described on the "Sundry Notice and Reports on Wells" dated July 2, 1971, giving notic~ of intention. 16. I hereby certlf~ that/~s~goin~Jm/tru.e/and corfeg~/ SIGNED TITLE (Thisspace for State office use) APPROVED BY TITLE CONDITIONS OF APPROVAL, IF ASr~: Area Engineer DATE May '1, 1973 -t DATE See Instructions On Reverse Side Form PL-7 :: STATE OF ALASKA OIL AND GAS CONSERVATION · WELL COMPLEIION OR RECOMPLETION REPORT AND LOG* · . o,i. ~ ~A~ © W£LL WELL DRY Other b. TYPE OF COMPLETION: .w r L L OV r,a £ x n ac K n£sv R. Oth er NAM'E OF OFERATOg Mobil Oil Corporation SUBMIT IN DU .~E* stem Lions on COI~SMITTEE reverse side; 5. ~I N~UC~ CODE 50-0892001 3. ADDRESS OF OPERATOR P. Oo Pouch 7-003 Anchorage, Alaska 99501 ~. LOCATION OF WELL (Report location c~ear' ' and in accordance with any State requirements)* at su.aee 1514' FNL, 1730' FEL, Sec. 18, T~N,,,,-R,,23B. U~p[ At total depth Same 2/8/7O Suspended 8/13/70 / 63 KB ~OW~N¥. I ROTarY ~OOLS 13329 · 13. DA.TE SPUDD~.T~ 7/16/70 18. TOTAL DEartH, I~LD & TVD ~9. PLUG, 13329 22. PRODUCING INTERVAL(S). OF THIS CO.MPLETIO~N'--TOP, BOTTOM, N'A2vIE (MD AND TVD)* None 24. TYPE ELECTRIC AND OTHElq. LOGS RUN 6. LEASE DESiGNATiON A.ND SERLA. L NO. ADL 28380 7. IF Ihq)IA..N[, A.L,I-~TTEE OR TRIBE NA.M_E 8. UNIT,F~klRa~i OR LF~KSE NAaME West Staines State 9. WELL NO. 18-9-23 10. FIEJ~D AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., i%I., (t:lO~I'I'O~I HOLE O13JECTIVE) Sec. 18, T9N, R23E, UPM 12. PEt~%IIT NO. 69-120 ' RT, GR, ~TC)' {17. ~t[,~r. CASINGI-IEAD I INTERYALS DRILLED BY ' " CABLE T00L8 23~ was DIRECXqO.NA-L SURVEY MADE ,t 1ES, BHC, SNP, FDL, HDT, CBL · -~- : ~ ..... ~ ..... ~ ~m-~,a~ - - =, - ~ e ~.~ - ~-- - - _ ...... -_ -_ : 25. CASING RECOi:LD (Report all strings set in well) ~0" 1" 94¢~ .~40 l--~-~~j ..... 840 sx" ~~~~l ~ooaV" i ~a'~/~;"[ ....... 4ko sx ~ ' ] ~" . ~. +~=~~o~~ ........ ~'-~'~ __ See attached well h~story. . ~. '" PRODUCION DATZ OF T~ST, HO~S TEST~ ~[~OXE SIZE IPROD'N FOR O~BEL. G~MCF. WA~I~BBL. ~. v,srosmos or ~ ~ h~e~ 70;'~ez, reared, etc.)- ~2. LIST OF ATTACtt,MENTS See well h_is. t0r~ . hereby certify that the foregoing and attached information is comp~~te'~{{ned from a,! ava ;a e recor _~' *(S~e [nsfructions and Spaces [or Additioaal Dc~a on Reverse Side) J TEST WITNESSEDBY INSTRUCTIONS Generah T~is form is designed-roi submitting a complete and correct well co .repletion reporl end log on all types of lan.ds and leases in Alaska. " Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- mentsgiven in other spoces on this form and in any attachments. Items :20, and :22:: If this well is completed for separatc, production from more than one interval zone (mulliple completion), so state in item 20, end in item 22 show the prc-Jucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for eech additional intel val to be separately produced, show- ing the eor~Jitiona. I dote pertinent to such interval. ltam:2&. "Sacks Cement": Attached supplemental records for this well shoulal show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 2B: Submit ~ separate completion report on this form for each interval to be separately produced'. (See instruction for items 20 and 22 above). WAT,~. AND MUD See attached well history~ Cretaceous 8700? Paleozoic ~ 13,120 ]: ~ '.' , ,q~ _, ._ '._..._~ _ ............. ~ ............ ..~ ...... . ........................... · :. . . '... ~q . See attachment. . ,, , · , ,~ ............. ~ ..... . ............. ~ ............ , ................................... MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL (' ,20NFIDI NTIAL DATE OPEPdtTOR Mobil Oil Corporation. FIELD West Staines State 18-9-23 10/6/70 · Wildcat SEC. 18 T 9N R 23E SIGk!ED TITLE 1970 2/2-2/3 2/6-2/23 ',/23-2/28 2/28-3/2 3/2-3/10 /lO- ./22 /22-3/23 3723-4/s 4/5 The well .was drilled by the Peter Bawden Drilling Company, Ltdo, using rotary rig f~2!, on location 1514' FNL, 172.0' FEL, Sec. 18, T9N, R23E,' UPM. Ail d~.pths refer to the Kelley Bushing elevation 63', 15.5' above the casing flange, unless otherwise noted, Set 32' of 30" conductor ~. Drilled a 36" hole 32' below ground level, set 30" conductor w/20 sacks at bottom and outside w/156 sacks. Drilled 17-1/2" hole to 347' and set 20" cs~ at ~03'. Finish rig up. Spud well 7:30 A.M. - 2/8/70 Drilled 17-1/2" hole to 347' opened to 24"° Attempt to run 20" csg. Shut down by weather. Ream hole to 325' " ' , run 20 to 303 and cement w/840 sacks. Finish rig up,niPple up and drill out shale. Drilled I7-1/2" hole from 347' to 2116'. Schlumber_g_e_~ T.D_? 2116'. Cleaned out bridge at .1570. Ran IoE.S. 300-2088, BHC Sonic-Gamma ray 300'-2096'. Took 9 side wall cores.. Ran 13-3/8" cs~. to 2105' and cemented~ WoOoC. Ran 2105', 61#, H-40 csg. set at 2105'. Cement 1st stage w/700 sacks, Class "G". Open HOCOW DoVo tool at 1385 and cement Znd stage w/1200 sacks Fondu flyash w/30% salt. Good returns at surface. Plug down 9:00 A.M. - 3/4, .W.O.C. Work on rig, nipple· up, pressure test BoOoP. to 3000#, drill out shoe~ . Start drilling 12:10 3/10. Drilled 12-1/4" hole from 2116' 'to 7748'. Cut core -/~1 7748' to 7778' 8-15/32" hole ~ O Rec. 29' sandy sltsto, no show. Drilled 12-1/4" hole from 7778' to 9659'. Reamed core hole and drilled ahead. Ra__n__~a~_~a__~.~ay caliper log 2105-9310. Check for washout. . .. D A~cbORAG GE 2 WELL (~ Drill 12-1/4" hole from 9659' to 10~0~8_'. $~chlumberger loggj_n_g ruqz ToDo~'tQ,098,. Ran IES #2 2124-10,067 FDC #1 2122-10,067 SNP #1 2124-10,068 CDM #1 2126-10,069 4/5-4/7 4./7-4/10 4/10-4/1 4/15-4/17 4/17-4/19. Cut c~re #2 from 10_~_573' to !P s-15/32', hole. Recover 40', 12' sandstone w/show oil. 4/19-4/20 4/20-4/21 4/21-4/22~ 4/22-4/26 4/26-4/28 4/27-5/4 5/4-5/5. 5/5-5/9 5/9-5710 ~/lO-5/12 .CONFIDENTIAL BHC Sonic #2 2124-'10,075' Attempted 180 side wall cores~ recovered 148. Clean out bridge and conditioned hole. during logging. Lost 233 bbls mud while logging. Ran seismic check shots. 5 R__a~n 9-5/8" csg. to 1Q,087' and cemented;___W~OoOo Ran 2409' of 47# S-95, 9-.-5/8'! csg. Ran 7700' of 43# S-95, 9-5/8" csg. Set at 10,~87 and cemented w/420 sacks class "G". Nipple up. Pressure test hydril to 3000#. D~ill float shoe. · Drilled 8-1/2" hole from 10__z098' to 10~57A' nholg 10~582' to 1~613'. R~h~gi~~ a~g~b~ w/pacl~r~ a~,582'. Rec~ 3 bbts gas and oil cut mud and 3/4 gal. clean oil. B~P 1054#, 1 hour, BHSIP 5252#, 2 hours. Reamed hole to 8-1/2~'- 1~j73' to ~1~. Cut qgre {J3 from 10~13~' to 10~0' - 8-15/32" hole. Rec. 57' laminated to thin bedded ss, sltst, and shale, shows in ss. D~i~_led 8-1/2" hole from 1.0~670' to ~'_. , Cut core #4 from 11z166' to 11~' - 8-15/32" hole. ~c. 60' shale. Re'amed hole to 8-1/2".-- . Drilled 8-1/2" hole from 11~26' -~ll~i Had good show 11,552'-11,663'. Well kicked. Built mud wt.. from 10 6# to 13# to condition mud and control well -~ ~ ..... Cut core #5 from 1~655' to 1!~77' - 8-15/32" hole. ss, Wait_oq 4-3/4" core barrel due to weather. ~, ~'~ "~' '~ OF 0iL ~:'.~D GAS Cut core #6 from 1~677' to 11~07' - 5-31/32" hole. Rec~ 30.', 20' of ss w/show oil~ ~in o~en hole from ~690' to 11,707'. R~n HOWC~ ~ght "h~6i~ a~b~ ~/pac~ a~ 1~~ Rec. 3 bbls clean 27° oil' BHFP 7622#, 1 hour, BHSIP 7741#, 2 hours. MOBIL OIL CORPORATION HISTORY OF OiL OR GAS WELL PAGE 3 DATE 5/12-5/14 5/14-5/24 5/24J~5/26 5h6-5/29 5/29-5/31 5/31-6/2 6/2--'6/4 6/4-6/10 6/10-6/11 6/11-6/14 6/14-'6/26 Cut core #7 from 11~707' to_ 1!~738' - 8-15/32" hol~. Reamed rat hole 11,677' to 11,707' to 8-1/2", conditioned hole, raised mud weight to 13.4#, cored and rec. 31' sand and shale, sl. s~b. & g. · Drilled 8-1/2" hole from 11~738~ to 12 ~5.05 '_. Reamed core hole to 8-1/2" and drilled· Had approx. 3 bbls/hr, mud loss while drlg 12,181' to 12,265' added 20 sx lost cir. mat , no further loss · , · · Schlumberger Ran IED #3 10,087-12,487 BNC Sonic #3- 10,087-12,487 CBL 8962-10,0.87 SNP #2 10,087-12,487 Trip to condition mup. Ran F~D.C. #2 - 10,087-12~496. Proximity Log #1 - 10,082- 12,483· MDT #2.- 10,082-12,487. Took side wall cores· Drilled 8-1/2" hole from'12 ,505 ' to 12,540'. Mud cut to 1'1# from-i-~..4~-~,~-raiSe wt. ~-i-~-1#. Cut core .{)8 fro_~!2~540' to !2,566' - 5-15/16" hole· Rec. 26', .bentonitic shale and sltst· Reamed rat hole. Drilled 8-1'/2" hole fromm566'~ to ~. Cut core -{)9 from 12,648' to 12,_683' - 5-15/16" hole. Rec 35' bentonitic shale and sltst Reamed rat hole · , · · 8-1/2" hole from~ 12L683' to 13_~003 . At 12,800' gas increased in mud, raised wt. to 14.2~. Schlumber.. ~er lo~o~g__in run, ........ Ran IES #4 11,496-12,996 FDL #3 SNP #3 MDT #3 BHC Sonic #4 ll,497-12,896- Attempted 60 side wall cores, recoVered 38" left 16 bullets in hole. Recovered junk and drilled 8- 3/8" hole Ran 7" liner from 9848 to 13_~p04', cemented and squeezed., D.O.C· and fish for 'u~k_o Ran 2032.8 of 29# S-95, 7" csg. - Ran 1100.6 of 26# S-95, 7" csg. w/shoe, landing, collar and hanger = 3156'. " Cemented w/400 sacks class "G", w/18% salt, 4% gel and Other additives. Squeeze 1 w/160 cu. ft. class "G". Squeeze 2 w/140 sacks class "G"· Squeeze 3 w/130 sacks class "G". -~ ~ Squeeze 4 w/l12 cu. ft. class "G". Drilled out cement and float collar· Ran CBL log, fish for junk~ D~VtS~ON AMCHORA~ MOBIL OIL CORPOP~TION ~ISTORY. OF OIL OR GAS WELL PAGE 4 DATE 6/26-7/1 Drilled 6" hoie 13~QQ5' to._13,026'.o "7/1-7/2 Cut core #10 from 13~026' to_1~,035' - 5-15/16" holeo Reco 7' sltstn. 7/2 Drilled 6" hole from 13.,.035' to Reamed core hole and drilled new hole, no junk. 7/~]7/3 Cut core #11 from 13~_062' to 13,122' - 5-15/16" hole. Rec. 58' sltstn., 2' phyllite, w/show oil in fractures° 7/3-7/4 Cut core #12 from 13,~!~22' to 13 153' - 5-15/16" hole Rec. 11' argillite° 7/4-7/5 Cut core #13 from 13~15_3_J_' to _13_~178 '-5-15/16'" hole. Rec. 14' argillite. ~, . 7/~-7/6 Cut core #14 from 13,~!7_8~'~t~__13~,2q?_~_?_l_5_J/,16" hole. Rec. 11' argillite. 7/6-7/7' Ream core hole_ 13~_06~' to 13r202' to 6". 7/7-7/9 Ran DoSoTo '~3 in open_hole 13~,~qQ4~'- ~o~ !3_z202. Packer set at 12,846' in 7" csg.---with tail pipe at 13,'122'. Rgb. est. less than 10 bbls gas cut mud w/trace of oil. Tool plugging. 7/9-7/10 Ran DoSoTo #4 in open hole 13 004, to__1_3_~202__'. Packer set 12,848' in 7'~ csg. w/tail pipe at 13,150', open 1'30'~ died.. Reset packer · at: 12,818~ w/ta±l pipe at: 13,120'. Rec° small amount: gas cut: mud. TooI plugging. ~/10-7/11 Condition holeo Reamed hole 13,004' to 13,202'. ~/11-7/12 Sc__hlu__ mbgr_g~r!~igj_~_r__un_, T'°D'o 1. 3,202_ '. Ran IES #5 BHC Sonic #5 sNP #4 FDC #4 CBL 9847-13,004 '/12-7/14 Drilled 6" hole from 13z2__02'__tO~o Ran junk basket recovered bit cone. /t4-7/15 Cut core #15 from 13_,271' to 13~309' - 5-15/16" hole. Rec. 38.' argillite. /15-7/16 Cut core #16 from 13~309' to 13,329' - 5-15/16" hole, Reco 17-1/2' argillite. Ran 1ES #6 12,998-13,327 .BHC Sonic #6 12,999-13,318 FDC #5 12,997-13,327 SNP #5 12,999-13,327 HDT #5 12,999-13,$27 D~V!$!©bt OF C~,~ A'?.~,D GAS MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL PAGE 5 DATE __ 7/18-7/20 7/20-7/22 7/22-7/24 7/2327/26 7/26 7/26-7/28 7/28-7~29 7/29~7/31 7/31 7/31 7/31-S/2 8/2 8/2'8/5 8/5 BHTV tool did not work. Ran seismic check shots. Waited 9 hours for replacement HDT tool. Ran D.S.To #5 in open hole 131~4' to 13z329: · Packer set at 12,863' with tail pipe at 13,113'. Rec. 4 bbls slightly gas cut mud. BHFP 1888#, 4 hours, BHSIP 3648#, 4 hours° Reamed hole from 13,029' to'13,329'. . Se_t_bEid~_Rlu_~aq~LR%ug back ·to 12,869'_. Ran CBL lo_~. Set 50 sack plug.from 12,900-13,078'. Set EZ drill·B,P. @ 12,869' w/2 sack plug. Build mud wt. to·14.3#. Ran CBL_ gamma-ray log 9800' to 12,867'. · Per_f.,. !2z780' - 795' w/60'andran DoS. To #6. Set packer at 12,757' w/tail pipe to 12,774'.o Rec. 4.6 bbls gas cut mud w/trace of oilo Perforations~plugged. Lost 110 bbls mud.. Build volume conditioning mud. · . Ran D%--~a~_//7_Z3_perfs. 12:780' - 795'. Set packer at 12,727' w/tail pipe at 12,744'. Rec. 10 bbls gas cut mud. BHFP 1729#, 2-1/2 hours, BHSIP 5514#, 5 hours. Perf. 12~680' - 700'' 12u_~630' - 50';_ 12,525~: -37','_._12 512' - 2.5! w/4 shots per foot. · :Ran I)o S.'o T. Flow gas to surface, rec. 14 bbls mud plus 26 bbls oil and gas cut water cushion. 26 bbls gas and oil cut mud. BHFP 2216 #, 11 hours, BHSIP 8853 #, 16-1/2 hodrs. Set B~.P. at 12,409' and-squeeze perfs. 12,525'-12,795' (oa) w/120 sacks. Set 30 sack cement plug 12,350'-12,409'. Perf. 11~763' - 782' w/56 and ran Dogo~. #9. ' Set packer at 11,717' w/tail pipe at 11,744'. Gas to surface, rec. 1.5 bbls. oil and gas, 12 'bbls~gas cut mud and water. Se t t)'~ P_', at !1_ 74zZj~3t. Pe~f_t. 1_ 1._650'~11_.6~p'' w/100. '' -- Ran Do~.~ #10_uperfs.~~0.'-I ~ Packer at 11,62.0' w/tail pipe at 11,648'. Flow gas to surface. Rec. 17.5 bbls oil plus 7.5 bbls oil and mud. BHFP 2750#, 2 hours, BHSIP 7600#, 7 hours 40 mino P~rf.__ll_~675'-ll/715' w/160. Packer at 11,615' w/tail pipe at 11,648'. Flow gas and oil, reversed 16 bbls oil / plus 15 bbls gas cut mud. BHFP 2550~/, 9 hours, BHSIP 7575#, 30 hours. Set ~'".M'g at 11_,497' an_d_~ug_back to 11 45z~0'. Set 30 sack plugo OCT fl ~cj?6 , · DIVISION OF O?l A~,~D ~AS ANCHO~A~ MOBIL OIL CORPO?~TION ~ HISTORY OF OIL OR GAS WELL PAGE DATE ONFIDENTIAL 8/5-8/6 Conditioned mud° Reduced mud wt. from 13.5fi to 10.5f~o 8/6 Perf. 10,570' to 10,~590' W/_~80. 8/6-8/8 Ran P.S'.To f~12~_p_~r~.__lO,~570' to lq.,59q'_. Packer at 10,532' with tail pipe at 10,560'o Rec. 12 bbls gas cut mud w/trace - oil. Perfs. plugging. 8/8 R~perf. 10,__570'-10,590' w/80o 8/8'8/9 Ran Do Si~_~_Rers. !o,.,57o'-_~!o,~59p;. Packer at 10,528' w/tail at 10,555'o Rec. 21.5 bbls gas cut mud w/trace oilo Perfso plugging° BHFP 1600f~, 1-1/2 hours, BHSIP 3550fj, 7 hours. 8/9 S ue~~erfs. 10,570'-10,590' and Elu~ back to 10~422'o Se~ B~oPo ~-1~0~-~72~', ~s-q-6~ze--pe~-f~S~. 10,5~Zi0~9~~ w/9~' cu. ft. out and left 20 cu. ft. below MoPo Put 30 sack plug on ~oPo, plug back to 10,422'. 8/9-8/10 C__onditio_ ___ned mu~ d. Reduced mud wt. from 10.5f~ to 9°7fi. 8/10 S/lO-S/il Ran ._ {!C,_ e__rfso Packer at 9965' w/tail at 9988'. Rec. 100 cc. oil, 300 cc° water, 1800.,cc. gas cut mud in dual CIP sampler. BHFP 780~, 30 mino, BHSIP 2150fi, 2-3/4 hours. 8/11 S_q_u_ee:ze__perfso~9998'-10,020'~ ~ = ~_~ and PoBo to 9838'. · Set B~I~O at 9898' and squeeze pers with 100 sacks class "G". Put 60' plug on t~;l~o and P~B~'~ to 9838'o " 8/11-8/13 ~ded well. Laid down drill pipe° Pump 400 Sacks fondu cement in 9-5/8"-13-5/8" csg. annulus from 1472'-2105'. Filled annulus with diesel oil. Set ~oP° in 9-5/8" at 2000' w/25 sacks plug on top, ~. to 1950'. Fill 9-5/8" with diesel 150'- 1950'. Set ~oPo at 150' and put 50 sacks fondu cement plug on top. PoBo to 10'. Fill with diesel oil to surface. Cap with a blind flange and valve° Released rig° ' - Nm No. P~ STATE OF ALii ~A ~. ~- 1-70 · OIL AND GAS CONSERVATION CO/V~I'I-i'EE /~ONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS O,L [--~ 0,, [] OTa~ Wildcat W£tL WELL 2. NA_ME OF OPeRaTOR · __.~il Corporation ,3. ADDRSSS or O?E~%ATOR Pouch 7-003 Anchorage, Aiaska 4. LOCATION OF WF.2.,L 1514' FNL, 1730 FEL Sec. 18, T9N, R23E, UPM SUBMIT L~ DU?LICAT~ 50-0892001 6 LEASE DESIGNATION AND SERIAL NO. ADL 28380 7. IF IND~IA~T. ALOT/EE OR TRIBE NA~E 8. L.~IT F.~TM OLR. LEASE N.~ME ..W~.~t Rtaines State 9. WELL .~O 18-9-23 I0. FIEI.D AND POOL. OR WILDCAT Wildcat 11. SEC., T., R., 1~.. (BOTTOM HOL~ OP~ZTrV'~ Sec. 18, T9N, R23E, UPM 12. PEIR~MIT NO. 69-120 , 13. RF_~ORT TOTAL DI~P'ITrI AT END OF MONTH, C}tA.\'GES IN HOLE SIZE. CASING AND C~ENTING JOBS INCLUDING DEPTH SET AND VOLLq%~'ES USED. PERFORATIONS. TESTS A_ND RESULTS. FISHING JOB~. JL~'"NK LN HOLE AND SIDE-TRACKED HOLE AND A.N'Y OTI4~R SIGNIFICANT CHANGES IN HOL.~ CON'DITIONS- Report for August 1970: Depth at end of August was 13329. Set B.P. @ 11743. Perf. 11650-715. Flow gas and oil. Set B.P. @ 11497, cap with 50' cement plug. Perf. 10570-590. "' Rec. 12 bbls mud, no oil or gas. Sqz. perfs, with 110 sx, cement retainer at 10472 with 50' cement plug on top. Per~. 9998-10002. Rec. est. 1 bbl mud with trace oil. Sqz. perfs, with 100 sx, cement retainer at 9898, with 60' cement plug on top. Temporarily abandonded well 8-13-70. CONFIDENTIAL ., SJ*N'~D /~~ F'~*.~ vk.w-/"~x ~z~: Division Geologist ,AT~ September. _ , 1.. 197? .... NO~--Report on this form i~ required for each colend0r ~nth% regardless of the $totus of operations, and must ~ filed ~n d. upllcote with the oil and gas conservot{on comm i~ee b~ the 15th of the ~ucceeding month, unle~ otherwise directed. Form REV. Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS c TI _ONSERVA..Oi 4 COMMIYI'EE SUNDRY NOTICES AND R£PORYS ON WELLS (33o not use this form /or proposals to drill or to deepen or plug back to a dif£ierent reservoir. U~e "APPLICATION FOR PEB2VIIT--" for such proposals.) 1. '~. ~A.M~ OF O~E~I. ATO~ Mobil Oil Corporation. , ~,¢6 1 fl !fi70 {. ADD~ OF OP~ATOE rouca 7-0G3, anchorage, Alaska 995~v~°~ or o:c A~ GAs 4. LOCATION. O.F WELL *t,=f, ce 1514' FNL, 1730' FEL Sec. 18, T.9N., R23E. U.P.M. 13. ELEVATIONS (Show whether DF. RT. GR, etc. APl N~CAL CODE 50-0892001 $. LEASE DESIGNA~ON 2.ND SEFJ3~L NC). ADL 28380 '/, IF INDIA_N', AiJ. A>~ OR TI/IRE NA~/.E 8. UN1T, FA/~NI OR LE.&SE NA/~IE West Staines State 9. WELL NO. · 18- 9- 23 10. F/~_I~D AND FOOL, OR WILDCAT Wildcat SEC., T., R., IV/., (BOTTOM HOLE OBJECTIVE) Pm~var69_ 120Sec~°" 18, T. 9N,' R23E U.P.M. 62DF est. 14. Check Appropriate Box To Indicate Nature of N~oti'ce, Report, o.r Other Data NOTICE OF INTENTION TO: TEBT WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASINO MULTIPLE COMPI,ETE ABANDONs CHANGE PLANS (Other) {UBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZINO ABANDONMENT* Suspended (Temporary Abandonment) NOTE: Report results of multiple completion on Well orapletion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an}' proposed work. 7-20 & 21 Set cement plug from 13004-12900, BP @ 12869 7'-22 to 28 Perf ].2525 to 12780 (oa), test, sqz w/ 20 sx, cement retainer @ I ~-409, capped w/60' cement plug. . 7-29 & 30 Perf 1.1763-782, test, set B.P. @ 11743 7-31-tO 8-5 Perf 11650'715, test, set B,P. @ 11497, capped w/50' cement plug. 8-6 to 8-8 Peri ~0570'590, test, sqz w/Il0 sx, cement retainer @10472 capped w/50' cement plug. 8-8 to 8-11 Perf 9998-10020, test, sqz w/100 sx, cement retainer @ 9898 cappe.! w/60' cemer t plug. 8-12 & 13 Set B.P. @ 2000' capped w/50' cement plug. Df. splaced mud in 9-5/8.- 13-5/8 csg annulus w/400 sx Fondu;cal. Cement from. 1472-2105. Fi .1 annulus from 1472 to surface w/dies,.~l'. Fill g-5/8 csg w/diesel oil from 2000 to 150', set B.P.. 'and cap w' 140' cement plug. Fi]~ 9-5/8 csg from 10' to surface w/diesel oil ,~.~ with a blind flang-~, with ~,alv~ - ' Verbal .approval to suspend the well following the above procedure was received f':0m O. K. Gilbreath on 8-12-70. ~ CONFIDENTIAL 8IGNE -. '%~ LE ' Divl sion ~o]O~ist (Th!s spa~e for State o)~e%use)] ~ //')/'] ' APPROVED BT ' ._ ~_ TITLE ~/0, ~ ......... See Instructions On Rever'~:.e Side Approved COpy Returned ~,-,~ ~o. ~ STATE OF ~KA 1R~-~. 3- 1-70 OIL AND GAS CONSERVATION COMMI'FI'EE ~'&ONTHLY RI~PORT OF ORILLING AND WORKOVER OPERATIONS SUBMIT I~ DL~-LICA~ CODE q0-9~92001 LEASE DESiGi'aA~ION AND SERIAL ADL 28380 l. ~. IF INDiAIq~. ALOT~-EE OJ~ TRIBE o,L ~ o,, ~ o~.~, Wildcat ~LL WEL~ ~. ~ME OF OP~TOR I ' %~7if. F.~ OR LEASE Mobil Oil Corporation ~ West Staines State P.O. Box 979, Anchorage, Ai~k= . 99551 ~' 18-9-23 4. LOCATION OF 1514~FNL, 1730~ FEL Sec. 18, T 9. lq., R 23 E, UPM 10. Fiji.r) A.X:D POOL, OR WILDCAT Wildcat Il. SEC., T., R., M.. (BO'I'~OM HOlE O~~ Sec. 18, T.9.N., R23E, U~ 12. PKRMIT I~0. _69-120 13. REPORT TOTAL DI~-qPTH AT FY4D O1~ MO.N"Tt{, CHA. NGES IN HOLE SIZE. CASING AND C~{ENTING JOBS INCLL'DING DEPTH SET AND VOL~uqVUr2S USED. PEI:~OILATIOlffS. TF.;STS A2q'D I~$ULTS. FISHING JOB~. JUNK LN HOL,g A_ND SIDE-T]:LACKED HOLE AND A_NY OTHlgR SIGNIFICANT CH A_NGF, S IN HOL~ CO,N-DITIONS. REPORT FOR JULY 1970 Depth at end of July wa~ 13329 Drilled 6" hole from 13)04 to 1332~ D S.T. 13004 - 13202 Rec. est. 10 bbls, gas cut mud w/ trace oil D~S T. 13004 - 13329 Rec. 4 bbls, slightly g~s cut mud w/trace oil Spotted 50 sx cement @ 13078, and 50 sx @ 12900, cIBp @ 12869 Perf. 12780-95 D.S T. 12780-95 Rec. 415' salt water cu~ mud + 200' gas cut mud w/ trace oil Perf. 12525-37, 12630-5), 12680-700 D.S.T. 12525-795 (oa) Flow est 50 MCFGPD, Re~ est 5 B.O. Set retainer at 12409 ~nd squeeze perfs. 12525-795 ~oa) w/120 sx w/60' plug above Perf 11763-82 D.S.~. perfs 11763-82 Rec 1-1/2 bbls oil + 15 bbls oil and gas cut mud 7 i§7b DIVISION Of O~ AND GAS ANCHORAG~ COMF DZ'NTIAL --. I~ ,~ ~ I~ ~ ~, ~ i '~ i ' iJ s,o~~kx~'t/'~t~L~'&.- _ ,(~1 - ~,,. ~Divisi°n .Ge°l°~..ist ...... m,= August 6, 1970 ' N'~TE--Rep~rt on this form is r qulred for each calendar ~nt~, regardless of lhe slo;us of operations, and must ~ filed in dupllcAc ~:]t,~ the oil and g~s con~ervet:~.~ comml.ee by the 15~ of the succ~ding month, unle~ otherwise directed. FORM SA- I B MEMORANDUM TO: n' FROM: O. ~, ~-lbrath, Jr, State of Alaska DZFISIOh3 OY OXL AND CAS DATE : SUBJECT: July 28, 1970 Honer L. hrreXX -2- D~reetor 1970 The Mt testing of .qutpmt ben at 6 ~. with the pipe ms, bllud The toot vas esuph~ at. 8 F*H. Z signed the driller's l~g epp~~ tho test md then pron~bd to tnopeet the CS! sttsuo~ cmtsXte~ vhtth xe fully repertod in mther trot. then proeedded bn~k to ~ Bay em the helicopter, attiring nc Ii F.li. At the lttkkelo~- Ba~ ~ the operation under ray vas eortu~, uhteh was onnpb~ at app~~y X0 &.~. on July 23. the ~0' ring seal. 'The ~ test on th~ 'veXX vas ~o ~ rode ~be .erew~h~ plm ~ to Desdhme the next morning, arriving I rJwn eheeked wi~h ~he ~obX! operacXens at ~ m~ found out the r~$ on ~d~ 37 ~0 the mt oJ ~horse had ~ completed a B~ ! ~old ~um ~hat ! did net vent a s~ ~eot ~nd ~h~C ! mmXd ~ry to catch ~,theu n~xt I then pre~m~ed to cheek v~th BJP d~,'~ operat~ns and fond out that they hsd, emepb~ ~he ~t~ of ,~,~ X3~ pipe on KXS Jfo, 1 on Thursday smd ~ the BO?E had been m~8~ at 'hr tiM. ~ hole vms Just ~ eoupletod tm the other ~ mad it was due to be relmased in a few bou~ so ! did not bother with trFins to Set a test on it. I ~hem premmded to ~rudhee Bay -to ~hecJt vXth the AR~ peeple coneenatn~ I ~t the ~ chazter ~hC b~c~ to Aucher~. aFrXTlnl ac a~proximaCeXy 6:30 p.n. FORM SA- lB MEMORANDUM TO: J-' FROM: State of Alaska DIVL~OH OY OXL ~ GAS SUBJECT: aom~ L. ~m~-ell -2- J=l.~y :17, 1970 ~ mo LB ao close to the Xobll-~JLtl].tps welt t~t tt ~ ~~t ~ ~ tt ~. ~ ~se. at ~ t~ ~ ~y ~tbt~~ldbeby R. EV. 9-30-69 ~ & "Subsequent Reports" in Duplicate I C. ~E'O tc.mo STATE OF ALASKA ~. ^P, Nt.~_S~C.,~...COD~. I i ENO~ OIL AND GAS CONSERVATION. CO~I~EE 50-08~200% J ~EN~ SUNNY NOTICES AND REPORTS ~ W~ j Use -~P~ICAT~ON FO~ ~E~T~' ~o~ No~ 0~% Co~o~a~o~ ~es~ S~a~aes ~REv'" 3. *DD~SS O~ O~TO~ ~. ~ ~0. Pouch 7-003, Anchorage, Ai~E~ ~~ ~/ ~ ~ 18-9-23 4.~OCAV~ONO~W~ ~ k ~= ~ ~ ~ ~' m.~~m~n.o~wm Wildcat 1514 F~ 1730 FEL o~s~w) Sec. 18, T9N, R23E, UPM give,ioN o~ O~L ANO ~C~O~J Sec. 18, T9N, R23E, UPM '"~?~ ~L~VAT~W~ I~hmw whmther g~_ R~. GR. etc. ~2. PE~T 62 DF est. 69-120 . 14. Check Appropriate Box To indi,cate Nature of NOtice, Re ~ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ~ ABANDONs R£PAIR ',','ELL [. CHANOE PLANS ~Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERINO CASING SHOOTING OR ACIDIZINO ABANDONMENTs (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) ~5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. COMPLETED WORK 7-20 &21 Set cement plug from 13,004 - 12,900 BP @12,869 7-22 to 28 Perf 12,525 to 12,780, test, sq. w/20 sks, cmt. ret. @12,409' capped w/60' cement plug 7-29 & 30 Perf 11763 - 782; test, set BP @11743 7-31 to 8-5 Perf 116.50 - 715; test, set BP @11497, capped w/50' cement plug 8- 6 to 8-8 Perf 10570 - 590; test, sq. w/ll0 sks cmt. ret @10,472, capped w/50' cement plug 8- 8 to 8-11 Perf 9998 - 10020,t~st, sq. w/100 sks cmt. ret @9898, capped w/60' cement plug 8-12 & 13 Set BP @2000', capped w/50' cement plug, displaced mud in 9 5/8 x 13 3/8 annulus w/400 sks Fondu, Cal. cmt. from 1472-2105. Fill annulus from i472 to surface w/diesel. Fill 9 5/8 csg. w/diesel from 2000 t° 150'. Set BP and cap w/140 ft. cmt. plug. Fill 9 5/8 csg. from 10' to surface w/diesel and cap with a Verbal approval to abandon well following the above work was received from O.K. Gilbreath on 8-12-70. PROPOSED WORK Cleanup of location to start the latter part of July 71. An appropriate well head sign will be erected. SUpplies will be moved out this fall when conditions permit. 16. I hereby certif~ that the fore~oin~ ia true and correct .... /, .,_ .--~...-,, ~: :._.~.- , (This apace for State office Xl~e) ;4~j , .. CONDITIONS 0F APPROVAL, IF A~: DATm 2 July 1971 See Instructions On Reverse Side Approved Copy, Retum~;l t Form No. cONFIDENTIAL sUBMrr IN DUPLICATE OIL AND GAS CONSERVATION COMMIT[EE Wildcat OT~£R o~ OP~.xTos Mobil Oil Corporation 5. ADDRSSS OF OPm~A~O~ P. O. Box 1734, Anchorage, Alaska 99501 4. LOCA~ON O~ W~LL 1514' FNL 1730' FEL Sec.18,T.9N.,R23E. UPM 5. APl NI. LXIER1CAL CODE 50-08920001 6 LEASE DESiGiqrA~'i~ION AND SERIAL ADL 28380 7. IF INDIA],(, AI,OTTEE OK TRIBE 8. I~;~IT F.M~xAi OR LEASE West Staines State 9 WELL NO 18-9-23 10. FIELD A_\'D POOl,. OR WILDCAT Wildcat 11. SEC.. T., R., .M.. (BOTTOM HOLE OBO~CTrV~.) Sec. 18,T. 9N. ,R23E UPM 12. Pk~P~IT NO, 13.REPORT TOTAL DtEPTH AT FiND OF MON'i~it, Ct.IA_NGES IN HOLE SIZE. CASING AND CELMENTING JOBS INCLUDING DEPTIt SET ~ VOLU~gES USED, P~O~TIONS, ~STS ~ ~SULTS. FISHING JO~. JUnK LN HO~ ~D SIDE-~CKED tlOLE AND ~Y O~R SIGNIFIC~T C~G~ IN HO~ ~ITIONS. ,, Report for June 1970 Depth end of June was 13,004 . Drilled 8 1/2" hole from 12,58~1 to 13,004 set 7" liner from 9848 to 13,004 W/680 ft. S~G .~r~__ _~,-[g~'~.~'~_--.- '--~>'~--< ~ Division Geologist nA~ July 1, 1970 CONFiDENTiAL Form ~o. P--4 ~'Y. ~- I-?0 Revised June 15, 1970 ,... original dated June 1, 1970. C 0 N F..I D E N.(:: '[_ A L STATE OF ALASKA su.Mrr IN ~. APl N~i~mC~ ~ODE OIL AND GAS CONSERVATION COMMI'ri'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS O,L [] G.~. ~' Wildcat NAME OF OP~2~ATOR Mobil 0il Corporation ADDRESS OF OPERATOR P. O. Box 1734, Anchorage, Alaska 99501 4. LO~ATION OF WELL 1514' FNL, 1730' FEL, 50-08920001 LEASE DESIGNATION AND SE1RIAL NO ADL 28380 IF INDIA]~. ALOTAk~ OR TRIBE NAME 8. L.~IT.FA_R~I OR LEASE NA_ME West Staines State 9. WELL NO 18-9-23 10. FI~:i .r~ AND POOL. OR WILDCAT Wildcat , T 9 N, R 23 E, UPM. Section 18, Township 9 North, Range 23 East, 1~. PEItMIT NO. Umiat Principal Meridian 69-120 13. R'EPORT TOTAL DE~TH AT END OF MONTH, CI-L~'qGES IN HOLE SIZE, CASING AND C~ENTING JOBS INCLUDING DEPTH SET AAFD VOLLrNIES USED, PERFORATIONS. TESTS ~ RESULTS. FISHING JOBS. JUNK IN HOLE AND SIDE-TP~CKED HOLE AND ANY OTHER SIGNIFICANT ~ES IN HOLE CONDITIONS. Report for May 1970 Depth end of May was 12,581 feet. CONFIDENTIAL Drilled 8 1/2" hole from 11,640 to 12,581. D. S. T. 11,690- 11,707 Rec 4 stds, gas cut oil, no water. --Ri~ort off this ~ il required foYeQch CQIIndQT ~nthj/tgQrdlell of the IJOtUS Of operotions, Qfld must ~ filed Jn duplicate with the oil and gQS conlervation commiflee b~ the I~ of the suoc~ding mon~, unle~ otherwiee directed. ~,o~ x-o. P-..~, STATE OF ,.~LA.q. KA OiL AND GAS CONSERVATION COMMI'I"TEE SUBA~IrT i/~' Db?LICAT!~ 1. o~ [~3 G*s ['~ ot.~ Wildcat ~£LL ~V£LL __ 2. NAME OF OPA,-RATOR Mobil 0il Cor~. ~. ADDRE~JS OF OPEIR~kTOB P. 0. Box ].7 34 A~nc.h_or . . ~. ~OCA~ON or V:~LL 1514' FNL, 1730' FEL, Sect. 18~ T9N, R23E, U. P. M. ~. APl NL~,.'~ERICAL CODE ADL 28380 %'~- 7. IF INDIA]',!. ALOTTEE O]{ TRIBE NA}dE - ~ 8.L,~IT,F.A/:L~I OR LEASE NAME West Staines State 9. WELL NO 18-9- 23 10. FIEL~D A_ND POOL. OR %VIi,DC;k? 11. SEC., T., R., M.. (BOTTOM HOLJ~ OBJ~CTrVE) Sec. 18, T9N,R.23E UPM 12. PEF~¥1IT N'O. 69-120 REPORT TOTAL DEPTH AT V-ND OF MONTH, CHAfWGES IN HOLE SIZE, CASING AiNrD C~V!ENTINQ JOES INCLUDING. DEPTH SET ~ VOLU~S USED, p~O~TIONS. %~TS ~ ~SULTS, FISHING JOBS, J~K L~ ~O~ ~ND SIDE-I~CKED HOLE A~ ~Y O~ SIG~'IFIC~T ~N~ ~ HO~ ~ITIONS. Report for'May, 1970 Depth end of May was 12581 Drilled 8 1/2"hole from 11640 to 12581 ....... 77~'--~-----_-l~ _ ./-_/.b ........... ~,~,,~ ~~'~*-~'~'~~]~7~ ..... ~J ....... h ~e~ardles$ of the status of operations anci must be flied with the Division of Mines & Mi~era!s by t.he 15th of the succeeding'month, unless otherwise direc[ed. ' ( ~.~v. 9-z0-6~ STATE OF ALASKA SUBMIT IN DUPLICATE OIL AND GAS CONSSRVATION COMMITIEE. MON't'HLY EEPOR'i' OF DRILLING AND WORKOVER OPERATIONS · OKG ~ii~"~ CODE ...... HWK 50-08920001 . 4. LOCATION OF WELL 1514'FNL, 1730' FEL, Sec. 18, T9N, R23E, UPM. i. o,L [-] GAS [-] O~E, Wildcat WELL WELL 2. N~{E OF OP~TOR 8. L~IT F.~.I OR LEASE N.~E · Mobil 0il Corporation We'st Staines State 3.ADDRESS OF OP~TOR 9. %VE~ NO. P. 0. Box 173~, Anchorage, Alaska 99501 18- 9 - 23 ~ildcat 6. LF. ASE DESiG~IA'i'ION AXD SEI~IAL ADL 28380 -- - 7. IF INDIA}~, A~T~E OR 11. SEC.. T., R., M.. (BOI'I'OM HOf.E Sec. 18, T9N, R23E, U. P.M. 12. PF2RIVlIT NO. 69 - 120 13. REPORT' TOTAL DE?TH AT END OF MONTH, CI-L~N'GES IN HOLE SIZE. CASING AND C~WIENTING JOBS INCLUDING DEPTH SET A/hrD VOLUATES USED, PERFORATIONS, TESTS ANT) RESULTS. FISHING JOBS, JUNK LN HOLE AND SIDE-TR~CKED HOLE AND' A~gY OTI-I~I~ SIGNIFICA-~T ~NGES IN HOL~ CONDITIONS. Depth at end of April 1970 was 11640. Drilled-12 1/4 hole from 8940'to 10098. Set 9 5J8" casing at 10087 with 420 sx. Drilled 8 1/2" hole 10098 to 11640. ~reby--~ti~y__t ~// q /~/~- ]/]]thatlhe f~regoing isfue and eortec% Alaska Division ' sm~ ~~~~_,_~LCu_ TIT~ iP.~-vi SiO._.n _ G e Q.!.,.og i s t mxT~. ~ 1970 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. FORM SA- lB MEMORANDUM TO: I-Homer L. Burrell ~ Director ~hrough: O. K. Gilbreth, Jr. z~//~_ Chief Petroleum Engineer F"OM:L°nnie C' Smith Petroleum Engineer State of Alaska Department of Natural Resources Division of 0tl & Gas DATE : April 9, 1970 SUBJECT, Checking BOP Equipment on North , Slope On March 311 traveled to the North Slope by commercial aircraft arriving at Deadhorse at app?oximately 2:00 p.m. I made arrangements with the Mobil Oil Company's expeditor to proceed by their charter plane to the West Staines State No. 1 well. I was met there by their contract drilling foreman, Mr. Weldon Ingram, who informed me that they would be unable to test the well for a period of time because the proper plug testing equipment was not on location, but was expected on the next plane. It was to~ late to make any further arrangements so I stayed overnight at the West Staines and the next morning proceeded on the early morning flight to the Mikkelsen Bay State No. 1 well. The drilling foreman on the Mikkelsen State Bay well is Mr. Paul Hodges, who informed me that they would not be able to pressure up to working pressure of the equipment, 5,000 psi, without getting a special Halliburton crew out at approxi- mately $1,000 per day. I informed him that we preferred a full working pressure test because the drilling permit had been approved for a certain ultimate objec- tive and that was what this equipment was designed for. I did agree to accept the pressure he could put up with his rig pumps on the test. The pipe was pulled out of the hole at 11:30 p.m. on April 1, and we began our BOP testing and completed the pressure testing at 2:30 a.m. on April 2. Test pressures range from 2300 psi to 2650 psi on the equipment, however, the driller noted on the drilling log that the BOP equipment was tested to 2,000 psi, which I signed as a witness. Two leaks in the kill line were repaired before a satisfactory test was obtained. This mani- fold and BOP equipment stack is 5,000 psi equipment, however, I noted that there was only a 3,000 psi SWACO adjustable choke installed on the manifold. An internal blowout preventor type floor valve was available. I also inspected the location and informed Mr. Hodges that they needed a well sign and that the location should be cleaned up better, since there was considerable trash on all sides of the loca- tion and unburned trash piles in various locations around the pad. I also suggested that Mobil might give more attention to putting complete berms around their pillow tank fuel storage areas. .The fuel storage area is necessarily on the pad or adja- cent to it and very close to the well and crew quarters. There are seven pillow ~tanks located at this well and a rupture 'in any one could, with no berm involved, allow fuel to reach either the crew quarters or possibly the rig. The next morning Mr. Hodges informed me that well signs had been ordered for the Mobil wells and that they would give more attention to the berms and clean up around the wells. I returned to the West Staines State No. 1 well that afternoon. The new test plug had arrived and on the next trip the equipment could be tested. Unfortunately for me the bit they had run drilled for some 400 plus feet and was in the-well for over 24 hours, consequently it was 9:00 p.m. on April 3 before they were ready to pull the pipe. Even after this the geologists decided they would have to circulate the hole for some period of time and it was the next morning at 5:00 a.m. on April 4 before we were ready to test the BOP equipment. This particular well was rigged up with the main kill line on the drilling spool placed right ~n top of the casing Homer L. Burrell Page 2 April 9, 1970 head underneath the blind rams, and the test plug seated just below the blind rams above the main kill line, so it was necessary t° take a blind flange off the side of the double blow, ut preventor stack in order to pum~ in Jus~ below the blind rams for testing. This waantt the most satisfactory procedure since it was necessary to rob the kill line off of the drilling spool and place it on this new flange for the pressure test only, ~nd then to replace it on the original hookup. The preventor equipment was tested with 1400 # and 3,000 # to my satisfaction. This. well had a ball type valve installed below the kelly as well as the kelly cock. Both of these valves were actuated in my presence. They had both a ball type and an internal blowout preventor type valves available on the floor. An inspection of the location revealed that this well also did not have a well sign, that the location needed further cleanup, and that the berms around 'the storage pillow tanks were incomplete. On both Mobil wells the manifold system had been pressure tested when installed to 5,000 psi and was left filled with diesel oil to prevent freezing. Neither of the rigs had an auxiliary hydraulic pump and without the Halliburton pumps they could not pressure test the manifold system without the necessity of flushing, steaming and refilling it with oil to prevent freezing, following the test. Due to the trouble involved, the drilling foreman requested that the manifold systems..not be tested. I considered both of these tests unsatisfactory from the standpoint of being overall incomplete (manifold not teSted~, kill sYstems changed, etc.) and at mini- ~mum pressures and w~uld recommend that.the 'loCa1 MObil drillin de ar - ~11' . g p tment be in formed of our lack of satisfaction with the BOP testOn these two wells and other points Such as w~ll. signs, pillow tank bermS~and the'clean ~ _. ;..,,...., . . ..~ .... ..... · . . up needed around these From Deadhorse I contacted'BP at. the Mukluk c~ and'fOund .~ ~2'; ~ei~'~oi' posed test on Put been postponed due to problems with the casing. I contacted the~Gulf rig,by side band radio<and made arrangements to be picked up by the charter.~aircraft servicing the Gulf~,rig. I arrived at the GUlf rig on ~CoiVille~De< No. 1 at approximately 9:30 p.m. ~e pipe.was ="the~ hole arrived and we imediaCely' proceeded to prepare fOr the BOP,,test,,,?,~Ram,p~ventors were tested'with approxi- mately 3500 to'3700 psi and,,che annula~i~prevent0r was,tested with 1500 psi. I witnessed the actuation of=¥the~;~ellYc0Ck ~alVd~,and wds infomed that there was a ball valve installed on the lowe~-,end,0f,.~dhe kelly. An internal blowout preventor tpe valve was available on the,'rig floor. Ail preventors closed in approximately ~ seconds, whiCh,.,was ,the ,faStesd closer on BOP's that I had witnessed on any test. · Ail e~ipment was in excellent condition and the crew seemed to be better trained and better prepared on BOP procedures than any that I had encountered so far to date. ~e manifold was well constructed and sized, with one positive ~choke, one adjustable choke and one automatic adjustable 5,000 psi SWACO super ~{~hoke. The manifold system on this well also was not tested, since it had been ef~~ga2~ ~sa~wt~[~ ~ would require ste~ cleaning and draining to ~~[ t i ~e drilling foreman, ~. Buzz Buzzard, was willing to test the choke manifold system, however, after reviewing their rig a~d equipment status I was co~letely satisfied that the manifold was in good order and felt sure that it had been tested adequately, We-were finished with the BOP check by 11:30 p.m., only t~ hours after my arrival on ~ location. ~.,. Homer L. Burrell Page 3 April 9, 1970 their one pillow tank had a berm around it,(even though very little gravel was available ~f~zP-~e~n____ used on this pad or location). This rig is rigged up on a board matting pad with no gravel-or piling underneath it. There has been no thawing under the rig or mud tanks and no settling of the equipment. I was allowed to examine the test data tabulated from the thermo couples installed around the cellar'~nd under the mud tanks. Gulf did not have a well sign on the location and I informed them that it was a requirement and requested that they get one. I returned to Deadhorse by a Gulf charter at 11:30 a.m. and continued by commercial plane to Anchorage. I arrived in Anchorage at approximately 3:15 p.m. on April 5, LCS:jw PALYNOLOGICAL ANALYSES of Core Chips 'Mobil M~kkelsen Bay St. #13-9-19 Sec. 13-T9N-R19E (UPM). Humble East Mikkelse'n Bay St. #1 Sec. 7-T9N-R21E (UPM) Mob i 1 ~~i n~s t ;~.' ~#. ~s,~~' sec. 18-T9N-R23E (UPM) Exxon Alaska St. A-1 Sec. 27-T10N-R24E (UPM) David I. Wharton Sohio Petroleum Company 100 Pine Street San Francisco, California 94111 June ~26, 1981 PALYNOLOGICAL AN~. ZSES Sohio Petroleum Company June 26, 1981 Page 2 MOBIL WEST STAINES STATE NO.1 (18-9-23) (8 slides--13,125' to 13,326') Eight samples from cores No. 12 to No. 16 'in the Neruokpuk Group were examined. These samples (13125'-13132', 13158'-13166', 13177'-13185', 13278'-13281~, 13283'-13292', 13297'-13301', 13312'-13316' and ' 13319.'-13326') contained.nothing but highly carbonized organic debris of indeterminable origin. EXXON ALASKA STATE A-1 (40 slides--10,213' to 14,206') Thirty-five samples from cores No. 1 to No. 9 in the lower part of the Tertiary sequence and five samples from cores No. 12 to No. 14 in the Neruokpuk Group were examined. The samples from the Tertiary section spanned the intervals 10213'-10871' and 12428'-12756', those from the upper interval being substantially more fossiliferous than those from the lower (oil-producing) interval. The higher interval is characterized by consistent occurrences of the pollen general Alnipollenit.es, Quercoidites, Tiliaepollenites, Caprifoliipites and Pterocayapol- lenites with sporadic occurrences of the dinoflagellates Spini- dinium densispinatum, Sene~alinium micro~ranulatum, Phelodinium ma~nificum and Wetzeliella articulata, the fungal spores Pesavis ta~luensis and Ctenosporites eskerensis, and the pollen Betulae- pollenites and Nudopollis. These assemblages are considered to indicate an early to mid-Eocene age. The lower interval is characterized by generally numerous and diverse fungal spores, including the forms Dicellaesporites, Multicellaesporites, and sporadic Pesavis tagluensis, nondescript disaccate pollen, the pollen Paraalnipollenites, and rare organic-walled microplankton including Spinidinium densispinatum, Oligosphaerdium complex and Palaeoperi dinium sp. The scacity of triprojectate pollen which are generallY frequent in the late Campanian to Maastrichtian of Arctic North America, the absence of the pollen Wodehouseia which characterizes the late Maastrichtian to earliest Paleocene of the. region, and of the Eocene and younger pollen Tiliaepollenites which occurs consistently in the higher interval, together with the presence of the Paleocene to Eocene dinoflagellate Spinidin- ium densispinatum and the Paleocene pollen Paraalnipollenites, all support a Paleocene age for this interval. David I. Wharton Sohio Petroleum Company- 100 Pine Street San Francisco, California 94111 PALYNOLOGICAL ANALYSES The following are the results of a palynological study of core samples from the indicated four Beaufort Coast wells in the State well library. The study was conducted by David I. Wharton, Sohio Petroleum Company, and reported'to the Alaska Oil and Gas Conser- vation Commission June 26, 1981. The palynologic slides, within the respective intervals for each well, are available for refer- ence in the commission's well sample library. MOBIL MIKKELSEN BAY STATE NO.1 (13-9-19) -' ( 84 s'I'i ~[~ s--~- l~ ,-~i~~-]~, }~))]Fr~---- Five samples from cores No. 15 and No. 18 in the lower part of · the Endicott Group, and three samples from cores No. 19 and No. 20 in the Neruokpuk Group were examined. Core samples from the Endicott Group (15101'-15102' 15106'- 15109', 15115'-15120' 15123'-15129', and 15905'-15919") yielded poorly-preserved assemblages of miospores including Lycospora spp., Corbulispora spp. Lophozonotriletes rarituberculatus ~ abunda'n'{-'-D-~nso spor ~ t es, w~'i'~-h---'{~-~-~-~-~--a--~~1~T~-~-i-~'~L//'n--( 1 a t e Osagian to early Chesterian) age for this interval,. Core samples from the Neruokpuk Group (16545'-16546', 16573'-'16581, 16583'- 16'598') were devoid of any identifiable palynomorphs. HUMBLE EAST MIKKELSEN BAY STATE NO.1 ( i 0 One sample from core No. 2 in the higher part of the Endicott Group, and nine samples from cores No. 3 and No. 4 in the Neruok- puk Group were examined. The sample from the Endicott Group (12696 '-12698') contained a poor miospore assemblage including the forms Lophozonotriletes raituberculatus. Densosporites'variomarginatus, and D~ool~sporx~es ~[l'~T~tus ---T-~e-'T~'F~'{ species ~s res~r~c~eo to {'~'~'-]-~-~-T})ur- ~a~-~an and early Visean (Os.agian) of Western Europe. It has no.t been recorded previously from northern Alaska, nor, as far as I am'aware, from Arctic Canada. Its precise stratigraphic signifi- cance is :therefore not known. Nine samples from the Neruokpuk Group (13896'-13878', 13885'- 13894', 13903'-13908', 14605'-14608',' 14611'-14620', 14621'- 14629', 14631'-14639', 14641'-14645' and 14657'-14660') contained no palynomorphs considered to be in place. Five of these samples contained very small numbers of Visean miospores presumed to represent contamination, in view of the nature of the accompany- ing kerogen which was quite atypical of the Endicott Group. STATE OF ALASKA summer IN D~LZCA~ OIL AND OAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS LOCATION OF WTM 1514 feet FNL, 1730 feet FEL, Section 18, Township 9 North, Range 23 East, U. P. M. AP1 NUA{ERICAL CODE 50-08920001 6. LEASE DESiGI~AT'ION AND SERIAL NO. ADL 28380 7. IF INDIA]~, ALOT'YEE OR TRIBE NAME Wildcat ---- ~-~ OF OP~m~TOR ~. ~.~IT,F.~a~ OR LE^S~ ,~.~'~ Mobil Oil Corporation West Staines State ADDRESS OF OP]~.ATOR 9. %VELL NO. P. O. Box 1734 Anchorage, Alaska 99501 18-9-23 10. FLF_J_,D A_ND POOL. 0It WILDCAT Wildcat 11, SEC.. T., R., M.. (BO~'I'OM HOLE Se°c~ T 9 North, Kanse 23 East, U. P. M. 19`. PEP.MIT NO. 69 - 120 13, REPORT TOTAL DEPTH AT END OF MONTH, CI-[A-~GES IN HOLE SIZE, CASING ANT) CEMENTING JOBS INCLUDING DEPTH SET ~ VOLLrNIES USED, PEtlFO'RATIONS, TESTS A.N-D I:LESULTS. FISHING JOB,S, JLrNK IN HOLE A_ND SIDE*TRACKED HOLE ANT) A_NY OTHER SIGNIFICANT CH.A_N,~F~ IN HOL~ CONDITIONS. REPORT FOR MARCH 1970 Depth at end of March 1970 was 8940 feet. Drilled 12 1/4 inch hole from 2116 feet to 8940 feet. V NOTE--Report this form is for each calendar of the status of aacl be filed in on required month, regardiess operations, must duplicate with the Division of Mines & Minerals by the 1Sth of the succeeding month, unless otherwise directed. Form No. P--4 REV. 9-29-67 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT L-N DUPLICA. T]g WILDCAT WELL 2. NAME OF OPERATOR MOBIL OIL CORPORATION ~: ~'DI)'RE$$ OF OP]~R,ATOR P.O.Box 1734, Anchorage, Alaska 99501 4. LOCATION OF WELL 1514' FNL, 1730' FEL, Section 18, Township 9 North, Range 23 East, U. P. M. JNFIDENTIAL " ADL 28380 REL 7. IF INDIA~T, ALO'I 1E~ O]{ TRIBE NAME 8. L'/X-'IT,F.~:JA{ OR LEASE FILE West Staines State 9. %VELL NO 18-9-23 10. l~-i~i.~ A-'qD POOL. OR WILDC.~T Wi 1 dcat 11. SEC., T., R., M.. (BO'i~I'OM HOLE ommcTzv~) Jn i Section 18, Township 9 North Range 23 East, U. P. M. 12. PEI~MIT NO. 69-120 13. REPORT TOTAL DEI~TH AT F_,ND OF MONTI-I, CHA~NGF. S IN HOLE SIZE, CASING AINTD CE1ViENTING JOBS INCLUDING DEPTH SET A/ND VOLUA/I~S USED, PERFORATIONS, TESTS A/XTI) RESULTS, FISHING JOBS, JUATK IN HOLE A_ND SIDE-TP,-ACKED HOLE .~NT) ANY OTHER SIGNIFICANT CI-I3~TG~ IN HOI.~ CONDITIONS. REPORT FOR FEBRUARY 1970 Depth at end of February 1970 was 2116 feet. Spudded 2/6/70. Drilled 17 1/2" hole to 347'. Opened hole to 24" to 324'. Ran 20" casing 94# R-40 STC, with shoe at 303', and cemented wi th 340 sx Fondue cement. Drilled 17 1/2" hole to 2116 feet. ~4'~he"b'~:T,.~.Alaska Div. Expl. Manage..r~^~ March 13, 1970 ~,:[GN"J~), · ..N0~R~s ~ ~quired '~[ each calendar month, regardless of the status of operations, aha must ~ filed in duplicate ] with the Division of Mines & Minerals by the 15th of the succeeding month, unless othe~ise directed. [ I I I ~' I I I I 23 26 ' 24 WEST STAINES LAT. 70° 08' 15.19" LONG. 146° 25' 17. Y = 5,899,985 X = 451,694 I" = I MILE SCALE; CERTIFICATE OF SURVEYOR I hereby certify that I am properly registered (]nd licensed to practice land surveying in the Store of Alaska and that this plat represents a location survey rhode by me or under my supervision, (]nd that all. dimensions end other details are correct. Z2 27 '~2 ~ _o ........ Date SURVEYOR JAN B 1970 WEST STAINES Located in ~lE. I/4 OF PROTRACTED SEC 18 Surveyed for MOBIL OIL CORP Surveyed by F. M. LINDSEY I~ ASSOC. LAND & HYDROGRAPHIC SURVEYORS 2502 West Northern Lights Boulevard Box 4-08 Anchorage Alaska AL~KA OIL AgD GA~ CONSE2VA?I~ ~ITT~ 1969 Be= West; ~talne~ ~tate .~obll 011 Co~po~atlo~. O~att~ ~n ~se ~eas .~. ~b~t to ~ 16.05.870 a~ t~ ~u-. latl~ p=o~lga~ed the=e~e~ (Title ~, Alaska Admlnts~t~ative. C~e). o~t~.. ~~~nt of Fl~h ~ G~e, 1018 Internatlo~l ~~~e, ~1~ 99502. ~aeb elee~t-~ie 1o~, sepia ~ p~ln$ flled ~rsua~t to ~ t:he mee~I~l zero ~Slt1~ of ~1 log af~ t~ .~ ~.. ~a~ .log sh~l sho~ all 50-089-20001 SUBMIT IN 3ATE leorr~ P--I (Other instru~ on reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE' APPLICATION FOR PERMIT TO DRILL, DEEPENt OR PLUG' BACK ' ltl. TYPE Or WORK DRILL [] DEEPEN b. TTPI oF WgLL w,~ w,~ o~n,~ Wildcat zeN= 2. NAME OF OPERATOR Mobil 0il Corporation , P. O. Box 1734~ Anchorage~ .A. laska 99501 4. LOCATION OF WELL At surface A1514' .FNL~on~730' FEL Section 18, T9N, R23E UI~I ~ proposea proa. ' ~ Same 13. DISTANCE iN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 250 miles Southeast of Barrow 6.LEAS~- DI~"IGNATION A.N'D SEI~.AL NO. ADL 28380 L IF IN'DLA~, A.L,LO'i-'r~:~: OR Tl~I. BE NA.M~ !8.~ UNIT, FARM OR LEASE NAjVIE West Staines State 9. WELL NO. 18-9-23 10. ~IELD AND POOL. OR WILDCAT Wildcat I1. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 18, T9N, R23E, UPM 12. 14. BOND INFORMATION: TYPE 0il & Gas suretyand/orNo. Pacific Indemnity Co. 243305 15. DISTANCE FROM PROPOSED* ' ' '[I~.'NO, OF ACRE~ IN LEASE LOCATION TO NEAREST i (ALSO tO nearest dr(g, unt~, if any) 1514 '. 18. DISTANCE FROM PROPOSED LOCATION* ] I~. PHO~S~ D~ TO NEAR~T WELL D~ILLING, COMPL~, OH APPLI~ FOR. ~. 14,500 ' (Expires 9/18/71) A~o~nt $100 ~000 i'/. NO. ACRES ASSIGNED TO THiS WELL 20. ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF. RT, CH, etc.) 22. APPROX. DATE WORK WILL START* 28' Gr. Jan. 1, 1970 P~OPOSED CASING A.ND CEiVIE~TING /nrROGRA.M SIZE OF CASING] WEIGHT PER F°OT ~I~ S~-i-'r~NG DEPTH. qUANTIT! OF C~MEN: - SIZE OF HOLE , . 36" ~ 30"'~j~' 154 Line 40' 200" sax ~/~:.ll~ ,~ ~,~ 24" 20" ~4 H-40 300 ' 1200 sax 17~', 13 3/8"~. ~1 .J=~ '2500' 2500 Sax:' ~///~ , ,, ~ .. 12~"~ 9 5/8" 43.5 ~ 4~ S-95 1~..2.00.' 2300 sax 8~" 7" · 26' ~ S-95 ..14,~.0Q.'. . 300 sax . B.0.P. Program: 300' to 2500': 2500' to 13,200': 13,200 to TD: Hydril '~ISP'.' Series 900, 3000 psi, W.0.G. 20 3/4" Nominal Hydril "GK" 13 5/8", Series 1500, 5000 psi, W.0.G. Shaffer, Double Gate 13 5/8" Series 1500 5000 psi, W.0.G. Hydril "GK" 13 5/8", Series 1500, 5000 psi, W.0.G. Shaffer, Double Gate 13 5/8", Series 1500, 5000 psi, W.0.G. ABOVE SI~ACE D]~SCI~tBE I~ROPOSE~ PROGRAM: If ~1 ~ ~ dee~n or pl~ ~, give ~ on p~nt p~u~ive ~ ~ pro~' ~w pr~u~ive ~. If ~o~ ~ W ~ill or ~n d~~ly, give ~ent ~ on ~bs~ ~tW~ ~d m~d ~d ~ue ve~l dept. Gi~ blo~ut preven~r p~gram. , 24. I hereby J~,~U~JL~hat the'Foregoing i_~ True an~ Correct (Th~ space for S~te offl~ Y~ a ~o SEE TRANSMITTAL LETTER DI~ION~ SURVEY ~~ A.P.L ~C~ "o_ , ' t° ,,, _, _ , , , ~ ,,,,, NORA ! i I 34 28 . 27 26 · · ~35 36 ~ 31 34 ' ' 35 ~,HOPS°i~ : . - ~ ~ ~-~,40 ~,0 AG ~-~.~. ' '~45 AC ~ ~) ~,40 , ~- R( ' ~ ' I~ AC. , ~ , W5 I 295 ,AC ' ., ~~m~m mmmm~ ~~ mm mm mini m m ! mmmm mmm mmm m '" ~ i~°~',w~" ,, A ~ ', w~ ......... x ...... i ..................... ~ ....... I '' : ..... . .... , . .,. , , ~,, .7-:~ , j I..2~-":T ,. ., .. ;. ". ; .[., ~ ~... m-'" ~. ' .~. ' I .< ~ ' ', ... , ~ .., ~ h, I,o,,c , ,,,,c.. ., : ........ . ....... t .... ,--t---~ ..... ~ -. ~--~.~ ---~ ............ ~ ........... ~ ....... .' ~. , . , ~,,,.: ., ..r. '" . ~.. . [ .y,, { / [.,,o ~ ~ . . ' West Staines S e 8-9 3 : 909 SCALE I" = I MILE DM$1ON~ OIL ~ ~ CONTOURED ON TYPE: INFO. C, lo GEOL. BY DATE DRAWN BY. DAT~D__DEC. 19~J969 ...... ~ ~ .. ..... CHECK LIST FOR NEW WELL PERMITS' Company Mob i IOi I Corporation ADL 28380 Lease & Well No. West Staines State 18-9-23 Yes No Remarks 1. Is well to be located in a defined pool ................. · X/~ 2. Do statewide rules apply ........................ 3. Is a registered survey plat attached . ................. 4,~Is well located proper distance from property line ........... 5. Is well located proper distance from other wells ............ 6. Is sufficient undediCated acreage available in this pool ........ Is wel 1 to be deviated ......................... __ Xz~LX~ 8. Is operator the only affected party ................... ~-,-- 9. Can permit be approved before ten-day wait ............... ~/~y~ lC. Does operator have a bond in force ................... ll. Is conductor string provided ...................... 12. ~Is enough cement used to circulate on conductor and surface ...... _~- 1 ill cement tie in surface and intermediate or production strings · · · __ _y~/~' 14. Will cement cover all possible productive horizons ........... 15. Will surface casing cover all fres)~water zones ..... ....... 16. Will surface csg. internal burst equal .5 psi/ft, to next string .... 17. Will all casing give adequate safety in collapse and tension ...... 18. Does BOPE have sufficient pressure rating ........ . . . . . . .~z . Additional Requirements' _~/?~:]~~r~~ ApprovaTRHKLv -~1 R~e c omJ)l ~ nd e d '~ oKGREL ~
