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175-002
Exxonftbil Production Conitreny P. 0. Box 196.5101 /anchorage, Alaska 995194360/ 907 5615331 Telephone August 4, 2014 R-2014 OUT -157 RECEIVED AUG 0 6 2014 AOGCC SCANNED 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 #I • 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, E�onMobil 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, ,IfC IV a JUL 21 201 AoGCG E*(onMobil Production I OR, 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. 40 a. .r a • 16 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 i h PTU #1 looking south post cleanup. Debris collected in supersacks (seen at left of picture) was transported back to Deadhorse for appropriate disposal .asaia 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. w+ .a.9�'sii�i.'�M�.'r-.:rt.�.�: • ;.-. ,.. +�.sJ.:.'�.-.�.� �re.Atic S-�!'Ei� ..-':'��' 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 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 disposal. 2! 'AOL A 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 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. ti r �itF' v� y WSS #2 Debris collection awaiting transport to Deadhorse. Page 10 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 wells Pians are rn do the stork picking 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@rgdragnichlic.com 907-830-4796 SCAMM NOV 18 2014 ,s, A' � i _ � I 3t i� 35 . �4 'Po"�"' 31 3.. '�•.:,iyp ftp\. ,y-..++a+yp �•° �. i, {/ p%1.. it psr -� � I _ — f -�-, - " • ti'" � K-'�..91_ _ � 4 `�� ���o � q � eCof � ��ye � p ._....._.. .� °�......_.. _ _ _.,,_ __..� __. � .�3` � �'�• tea, 1 � � .�� ss ; u a � � ___ ter„ e Alai . ,,.. a9 r ^�� ra. •� Ala I s I _ i i � i ' i � 1-•+' _ i e 4� s { a �• I 24 ..0 i ; ZR i ':'1- —•ib il ►wx taiS> 23 Y g zi, 4 9i • —•_�%. -".� -- -- ns — .1 � 31 37 ` � 3w�e� { : a.. 35 -• i 5 4 � ; x � ', � �../'' '`� `j/ it 40 i ix �.,._.. _. {.� ` , C)b ! e :e 14 13 14 t' 27 zH 21 32 91- ' ��• xa 19 R 2] rt 3Y�ux r IJ I x� 3H •,„ xa�. 1 I � i r' .•��� It r, i 2e ' yf ' ( 76 xs7e as 36 13 33 22 >s 33 N ee ••� -•. e VIA -. r 1 �' �• 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 Q - 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.: 4/14/2014 12. Permit to Drill Number. 175-002 -3(3— 3. Address: P.O. Box 196601, Anchorage, AK 99519-6601 6. Date Spudded: NIA 13. API Number: 50-089-20004-0000 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 #2 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- 448175 y- 5890164 Zone- TPI: x- y- Zone- Total Depth: x- y- Zone- 10. Total Depth (MD + TVD): 13171 ft 16. Property Designation: ADL 28377 (expired) 11. SSSV Depth (MD + TVD): NIA 17. Land Use Permit: LOINS 09-007 18. Directional Survey: Yes ❑ No ❑ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: NIA (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 MD/TVD: I N/A 23. See Attached Work Summary CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD 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): RECEIVEDWas MAY 2 7 2014 A0Git. G 25. N/A TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 26. N/A ACID, FRACTURE, CEMENT SQUEEZE, ETC. 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 —..1111. Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate --po. Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): 28. CORE DATA N/A 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. SCOW NOV 18 20�� RBCMq MAY 2 7204 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE _/�� Submit original only f4 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? [7-1 Yes l , 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.a.iuranek exxonmobil.com Printed Name: Irene T. Garcia Title: SSHE Manager Signature: I rX/✓ 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 Q 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 ' S 1atU5 3. Address: J P.O. Box 196601, Anchorage, AK 4a. Location of Well (Governmental G� Surface: Top of Productive Horizon: I I Total Depth: 5. Date Comp., Susp., or Aband.: 4/14/2014 12. Permit to Drill Number: 175-002 6. Date Spudded: 13. API Number: 50-089-20004 -oO -OD 7. Date TD Reached: 14. Well Name and Number: West Staines State #2 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- `,46.41637 y- 70.110529 Zone- TPI: x- y- Zone- Total Depth: x- y- Zone- 10. Total Depth (MD + TVD): 13171 ft• 16. Property Designation: ADL 28377 (expired) 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: 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): ]72.Re-drill/Lateral N/A Top Window MD/TVD: 23. See Attached Work Summary CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD 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): �'VEL REC'Was MAY 15 2014 AQGCC 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 26. N/A ACID, FRACTURE, CEMENT SQUEEZE, ETC. hydraulic fracturing used during completion? Yes ❑ No ❑ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. 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 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. F�CAA� MAY 15 204A Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only /6 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 PBA 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.auranek exxonmobil.com Printed Name: Irene T. Garcia Title: SSHE Manager Signature: ��" 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 ElonMobil Production May 14, 2014 R -2014 -OUT -132 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Re: Well Completion Report Well Abandonment: West Staines State #2 (PTD No. 175-002) Sundry No. 313-606 Dear Commissioner Foerster, RECEIVED MAY 15 2014 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 4r-)_g01NT THOMSON PRODUCTION Cement in 9-5/8" x 13-3/8" annulus from marker plate to ±2,275' Cement in 9-5/8" Casing marker plate to ±2,397' ExxonMobil Oil Corporation West Staines St. #2 Final Well Schematic API #: 50-089-20004 APTD #: 175-002 Marker plate at >_3' below tundra 50 sx plug inside 9-5/8" csg ±2,397'- ±2,297' 40 sx plug outside 9-5/8" csg ±2,397' to ±2,250' HOWCO EZ drill BP at 3000' w/ 40 sx (+/-100'?) cmt plug on top 30", 154 Ib/ft, B Grade at 74' Cmt'd w/ 255 sx of Arctic Set _ 9-5/8" CIBP at ±150' with ±2.45" hole milled thru it. 20", 94 Ib/ft, H-40 at 787' Cmt'd w/ 4380 sx of Arctic Set Base Permafrost at 2050' FO Collar at 2223' in 9-5/8" csg 13-3/8", 72 Ib/ft, N-80 at 2275'. Cmt'd w/ 3870 s� FO Collar at 2397' in 9-5/8" casing No mud wt data TOC at +/-10,270' 9-5/8", 47 & 43.5 Ib/ft, S-95 at 11,270' Cmt'd w/ 650 sx class G w/ 18% salt 100 sx cmt plug from 11,170' — 11,370' across 9-5/8" casing shoe and 8-1/2" open hole Total Depth 13,171' Well schematic drawn June 29`", 2007 by Jesse Mohrbacher, Fairweather E & P Services, In, West Staines State #2 Summary of Work Activities 5 -Mar HSM. Preparing location. 6 -Mar HSM. Preparing location. 7 -Mar HSM. Preparing location. 8 -Mar HSM. Preparing location. 9 -Mar HSM. Preparing location. 10 -Mar HSM. Preparing location. 11 -Mar HSM. Preparing location. 12 -Mar HSM. Preparing location. 13 -Mar HSM. Preparing location. 14 -Mar HSM. Preparing location. 15 -Mar HSM. Preparing location. 16 -Mar HSM. Preparing location. 17 -Mar HSM. Preparing location. 18 -Mar HSM. Preparing location. 19 -Mar HSM. Preparing location. 20 -Mar HSM. Preparing location. 22 -Mar HSM. Preparing location. 23 -Mar HSM. Preparing location. 24 -Mar HSM. Preparing location. 25 -Mar HSM. Preparing location. 26 -Mar HSM. Preparing location. 27 -Mar HSM. Preparing location. 28 -Mar HSM. Preparing location. Receiving and rigging up equipment from WSS #18-9-23. 30 -Mar HSM. Continue rigging up equipment. Turned in AOGCC notification for BOP Test. 31 -Mar HSM. Continue rigging up equipment. Received Witness Waiver for BOP Test schedule for April 1, 2014. 1 -Apr HSM. Commence and completed BOP test. Loaded 225 bbls of Powervis mud into MI FMPS Unit. Vaccum out 400 bbl Tiger Tank. Cut off crimp connector on coil tbg, prep and started welding on weld on connector. Set the cement silos, finished installation of well head and reverse skid hooch. 2 -Apr HSM. Picked up and made up tools, pressure test & pull test tools. Flanged up BOP's & tested to 8,000 psig. Tested against cement to 2,500 psig. Circulated piping & Coil with hot diesel & then hot powerflo, RIH & tag cmt. at 39 ft., commence drilling of cmt at 1400 hours. (39' to 64' drilled in 2.75 hours) unable to mill deeper. POOH. Break out tools found no visual problems, Pressure tested BHA and hung in wellbore. 3 -Apr HSM, Change out motor and mill (PDC 8.5" OD) NU and test to 8000#, pump warm fluids. Pump power vis RIH tag at 64' milled to 95'. SLB pump went down, switched to Little Red and continued milling to 104' (total milling time 6.5 hrs). POOH winterize lines. SDFN @1900 hrs. 4 -Apr HSM, Pump and warm coil. RIH tag at 104.1' pump @ 4.2bpm @ 4125#. Mill down to 146.4' returns had metal shavings (10 hrs milling 42'). SD milling operations. POOH winterize coil. RU and pump calcium chloride down 9-5/8" annulus, max pressure 1100# at 5 bpm, broke ending pressure 542# @ 5 BPM, pumped 173 bbls. SDFN. 5 -Apr HSM, ND lubricator, break out BHA, lay down 3.5 motor and mill. Make up BHA with guide funnel. NU lub and test. RIH tag at 146.6' sat down, pumped 2.9 bbls @ 3400#. PU release funnel. POOH lay down setting tools. PU 2-1/8" motor and CIBP entry mill. NU and test to 8000#. RIH start milling at 146.6' milled 5 hours broke thru at 149.8' reamed up and down to clean up. POOH freeze protect coil. SDFN. West Staines State #2 Summary of Work Activities 6 -Apr HSM, ND lub, lay down BHA. Cut off coil connector, make up new connector w/jetting nozzle, & pull test connector. NU lub and test. MIRU SLB cementers, test lines. Bullhead 135 bbls Artic Set 1(15.7 ppge) in 9-5/8" annulus at 3.3 bpm. Max pressure 443# dropped to 219# and built back up to ending pressure of 425#. Flush and clean lines. RIH with coil in 9-5/8" casing tag up at 2261'. Pump 20 bbl calcium chloride and 20 bbls water spacer. Pump and lay in wellbore 172 bbls Artic Set 1(15.7 ppge). Circulate out Diesel in wellbore clean up and winterize lines. Good cement returns to surface. Clean out flow back tanks. Getting ready for move to SRS #1. SDFN. 7 -Apr HSM. ND lub strip coil equipment off well head rack back, break out lines & containments of all P&A equipment. Moving to Staines River State #1. 70% of equipment moved. 8 -Apr HSM. RDMO P&A equipment to SRS #1. SDFN. 9 -Apr HSM. Moving equipment to SRS #1. Excavating around WH. SDFN. 10 -Apr HSM. Complete excavation of well head. Continue removal of material to demob, Commence snow leveling. 11 -Apr HSM. Cut 30" conductor. RU Wachs saw. Commence cut of 20", 13-3/8" and 9-5/8" casings, completed''/: of casing cut. SDFN. 12 -Apr HSM. Finish cutting off WH with Wachs saw. Ready for planned cement pump top job 4/13/2014. SDFN. 13 -Apr HSM. Pump cement top job in casings. SDFN. 14 -Apr Completed dressing up final cut, took photos, completed welding marker plate, took photos, completed back fill of excavation & snow level on location. FinalWell Report. v r' 8 WSS #2 Coiled Tubing Operations M n , A, AW, INS _t v } r 'X- � r f e�-� spm-.,,•-'� _ r �•�acv- ..�-.....�,,,.�,,.�: _ .<.. ...•-._ _'° ...,sem-" W .w Schwartz. Guy L (DOA) From: Sent: To: Cc: Subject: ExxonMobil West Staines State #2 Daily Report Peterson, James M /C <james.m.peterson@exxonmobil.com> Wednesday, April 16, 2014 2:40 PM Schwartz, Guy L (DOA); Bill Penrose; Winter, Cassondra E; DOA AOGCC Prudhoe Bay; Dennis Collins; Greene, Timothy L; Cox, Mirick T; Juranek, Tom A Hawthorne, Brian K; Emmett, Cody; Farrar, Kendall N; Denman, Erika /C; Dragnich, Rob /EXT; SXP Hagberg; SXP McGeehan; SXP Steve Lewis RE: West Staines State #2 Daily Report r T -D 17S-6 6 2-- 4/14/2014 HSM, Completed dressing up final cut, took photos, completed welding marker plate, took photos, completed back fill of excavation and snow level on location. Final well Report. 4/13/2014 HSM, pump cement top job in casings, SDFN 4/12/2014 HSM, Finish cutting off WH with Wachs saw. Ready for planned cement pump top job 4/13/2014. SDFN 4/11/2014 HSM, Cut 30" conductor, RU Wachs saw, commence cut of 20", 13-3/8" and 9-5/8" casings, completed % of casing cut. SDFN 4/10/2014 HSM, complete excavation of well head, continue removal of material to be de -mob, commence snow leveling. 4/09/2014 HSM, Moving equipment to SRS #1, excavating around WH. SDFN 4/08/2014 HSM, RDMO P&A equipment to SRS #1. SDFN 4/07/2014 HSM, ND lub strip coil equipment off well head rack back, break out lines & containments of all P&A equipment moving to Staines River State #1. 70 % equipment moved. 4/06/2014 HSM, ND lub, lay down BHA, Cut off coil connector, make up new connector w/jetting nozzle, pull test connector. NU lub and test. MIRU SLB cementers, test lines, bullhead 135 bbls Artic Set 1 15.7# per gal in 9- 5/8" annulus at 3.3 bpm max pressure 443# dropped to 219# and built back up to ending pressure of 425#. Flush and clean lines. RIH with coil in 9-5/8" casing tag up at 2261' pump 20 bbl calcium chloride and 20 bbls water spacer, pump and lay in wellbore 172 bbls artic set 1 15.7# per gal. Circulate out Diesel in wellbore clean up and winterize lines Good cement Pet oto §urFace. Clean out flow back tanks getting ready for move to SRS #1. SDFN Ci' - l 1 R'Qz. 4/05/2014 HSM, ND lubricator, break out BHA, lay down 3.5 motor and mill, make up BHA with guide funnel, NU lub and test. RIH tag at 146.6' sat down, pumped 2.9 bbls @ 3400#, PU release funnel. POOH lay down setting tools. PU 2-1/8" motor and CIBP entry mill. NU and test to 8000#. RIH start milling at 146.6' milled 5 hours broke thru at 149.8' reamed up and down to clean up. POOH freeze protect coil. SDFN 4/04/2014 HSM, Pump and warm coil, RIH tag at 104.1' pump @ 4.2bpm @ 4125# mill down to 146.4' returns had metal shavings (10 hrs milling 42'), SD milling operations, POOH winterize coil, RU and pump calcium chloride down 9-5/8" annulus, max pressure 1100# at 2 bpm, ending pressure 542# @ 5 BPM, pumped 173 bbls. SDFN 4/3/2014 HSM, Change out motor and mill (PDC 8.5" OD) NU and test to 8000#, pump warm fluids. Pump power vis RIH tag at 64' milled to 95. SLB pump went down, switched to Little Red and continued milling to 104' (total milling time 6.5 hrs) POOH winterize lines. SDFN @1900 hrs. James (Jim) Peterson ExxonMobil Workover Supervisor North Slope Cell: 907-891-5838 Cell: 281-610-6630 Email: james.m.peterson@exxonmobil.com Email: leVvapeterson@aol.com 4/02/2014 Picked up and made up tools, pressure test & pull test tools. Flanged up BOP's & tested to 8,000 psig. Tested against cement to 2,500 psig./Circulated piping & Coil with hot diesel & then hot powerflo, RIH & tag cmt. at 39 ft., commence drilling of cmt at 1400 hours. (39' to 64' drilled in 2.75 hours). Received 150 bbls Cacl and 104 bbls of diesel. - - - 4/01/2014 Commence and completed BOP test. Loaded 225 bbls of Powervis mud into MI FMPS Unit. Vac out 400 bbl Tiger Tank. Cut off crimp connector on coil tbg., prep and started welding on weldon connector. Set the cement silos, finished installation of well head and reverse skid hooch. 3/31/2014 Completed equipment check out, transfer fluids around as required, Completed scaffolding for BOP stack. Worked through crane issues and completed repairs. Starting circulation of fluids to warm up as required. Received Witness Waiver for BOP Test schedule for April 1, 2014. 3/30/2014 Completed equipment set up and laying of iron into position. Commence checking out equipment for operational. Commence erection of scaffolding around BOP stack and commence putting up hooch around scaffolding. Turned in AOGCC notification for BOP Test. 3/29/2014 Continue receiving equipment and material. Placing iron and hook-up of systems. Received BOP stack and set onto well head. Torque up BOP stack. 3/28/2014 Commence receiving equipment and material from West Staines 18-9-23 and setting up within containment's. Commence hook-up of equipment. r 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 (bil I@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. c n sing for W Staines State #18-9-23 for verification of Ult:dru) uuristg rc;u.Line Brit; Uiaizge-vui�, I16idiicu. JVl-JV1-YJJJ lCll JV/'/JJ-1LLV VIIII.0 All the other following P & A wells must have the new 11" test valve SCANNED From: Juranek, Tom A [ 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 ( ) 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. 4 _ 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 Juranek Subsurface Engineering Advisor EMPC Global Engineering -Houston Subsurface Engineering & Operations Support CORP -EMB -30211 Lync Phone: 832-624-6940; Fax: 713-656-7353; iPhone: 832-596-5406 email: tom.a.iuranek@exxonrruo,i., ; i 24' i5-7/8" Sundry # 313-606 WEST STAINES STATE #2 API # 50-089-20004 APTD#: 175-002 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 Break Tests: 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 mmwmicui FIL DSA -11" 10k X 4" 10k 11" 10k SPACER SPOOL 11" 10k DRILLIING 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 BUND RAMS (RAM BODY AND RAMS INSTALLED UPSIDE DOWN) 4-1/16", 10K Coil BOP System 0 SLB r Combi BOP's • (r 0.* ////,. .sA THE STATE Alaska Oil and Gas ti~�����1 � re )mission ALASKA ��cill serPvat.io CoC �^ ft GOVERNOR SEAN PARNELL 333 West Seventh Avenue "�nnf. .. F� Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 SCANNED MAY 2 0 2014 Fax: 907.276.7542 Irene T. Garcia SSHE Manager ExxonMobil Oil Corporation PO Box 196601 17 3-- 009. Anchorage, AK 99519 Re: Wildcat Field, Wildcat Pool, West Staines State #2 Sundry Number: 313-606 Dear Ms. Garcia: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this2Alay of December, 2013. Encl. cpkitk RECEIVED STATE OF ALASKA NOV 19 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION \ /2./106/3 APPLICATION FOR SUNDRY APPROVALS AOG /to,•IS 20 MC 25.280 1.Type of Request: Abandon[f Plug for Redrill ❑ Perforate New Pool❑ Repair Well❑ Change Approved Progran❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extensiot❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate 0 Alter Casing❑ Other: WellRemediation n • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ExxonMobil Oil Corporation Exploratory 0 , Development ❑ 175-002 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: PO Box 196601,Anchorage,AK 99519-6601 50-089-20004 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 ❑ No ❑✓ West Staines State#2 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 28377(Expired) • 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): 13,171 • 13,170 • 0 0 Many plugs,see schematic None Casing Length Size MD TVD Burst Collapse Structural 74' 30" 74' 74' Conductor 707' 20" 787' 787' 1,530 520 Surface 2,255' 13-3/8" 2,275' 2,275' 5,380 2,670 Intermediate Production 11250' 9-5/8" 11,270' 11,269' 8,150/7,510 5,090/4,130 Liner 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 ND(ft): N/A N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑✓ • 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 ❑., • Commission Representative: GSTOR ❑ SPLUG ❑ 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 - �.� O ,(p Phone Date g '�{" `" 907-564-3773 iv/5—N_ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: G-r 3\3— C.o.otAL Plug Integrity V BOP Test V Mechanical Integrity Test ❑ Location Clearance 111/zds/'-( Other: A 7 Do a"06.'.. !3 OP —"le—S----- • i- (4.043 GIG a 4t Si cJ £ 4)4/le r Spacing Exception Required? Yes ❑ No 1 Subsequent Form Required: /O —Lj O7. RBDM MAY U 9 2014 ,>/e/ APPROVED BY Approved by: COMMISSIONER THE COMMISSIONDate: 2 2Z - L3 3 Submit Form and 0.(1 Form 10-403 Cievised 10/2012) ApproljaRIG i4 41ALonth om the dee of approval. Attachments in Duplicate 1)--,> /if ExxonMobil Production Company AECEIVED P.0. Box 196601 Anchorage,Alaska 99519-6601 NOV 19 2013 907 561 5331 Telephone EkonMobil AOGCC Production November 15, 2013 R-2013-OUT-024 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#2 (PTD No. 175-002) 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 objectives will be: 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±2,297'. 3. Remove±200'of arctic pack from the 9-5/8"x 13-3/8"annulus. 4. Set the necessary surface plugs in the 9-5/8"casing and annulus(±200'to surface). 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, Irene T. Garcia SSHE Manager Attachments: • Sundry Application Form 10-403 • Proposed Work Procedure including before and after wellbore diagrams POINT THOMSON ' 411 rPRODUCTION WEST STAINES STATE#2 WELL HISTORY AND ABANDONMENT PROCEDURE Affected Wells and API/APTD Numbers: West Staines State#2 API# 50-089-20004 APTD#: 175-002 Background: The West Staines State#2 well was drilled in 1975. The well was plugged and abandoned on May 26, 1975, but requires the removal of+2,150' of diesel in the 9-5/8" casing, removal of near surface arctic pack 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 the surface 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 ±2,297'. • Remove ±200' of arctic pack from the 9-5/8" x 13-3/8" annulus. • Set the necessary surface plugs in the 9-5/8" casing and annulus (±200' to surface). • 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 upper tubing head and marker post. Measure the depth to the cement in the 9-5/8" casing (expect +10'). Install new 13-5/8" 5K psi x 11" 10 ksi tubing head with extended neck pack-off. This will increase the pressure rating of the wellhead to 10K psi. _ P (• Z SC S e J � WEST STAINES STATE#2 Abandonment Procedure' POINT THOMSON ft, PRODUCTION 4. Notify AOGCC of planned BOP testing and confirm steps to be witnessed throughout operation. 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 through the CIBP to the cement plug at±2,297'. Circulate out diesel from the 9-5/8" casing. , / 10. Perforate the 9-5/8" casing at±200' attempt to establish circulation down the 9-5/8" casing and up the 9-5/8" x 13-3/8" annulus. If unable to circulate, plan to circulate out arctic pack and fill annulus with cement using 1"tubing after the wellhead is removed (skipping steps#11-12). 11. Circulate out arctic pack 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 ±2,297' 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. If the 9-5/8" x 13-3/8" annulus is not already cemented to surface (steps#11-12 above), Coot. I " run 1" tubing into this annulus to about ±200' and wash out Arctic Pack with warm diesel. ��.. Take Arctic Pack/diesel returns to dedicated waste tank. Leave jointed pipe in hole for cement job to follow. Note: If unable to run 1" pipe to 150' or deeper in Step 17, run pipe as deep as possible and contact AOGCC to obtain approval for alternative depth. 18. Pump cement to surface in the 9-5/8"x 13-3/8" annulus. Ensure good cement returns. Cut-off jointed pipe and leave in hole. Diesel returns from cementing to be pumped from catch pan to appropriate waste tank. 19. Cut all strings flush and top off the 9-5/8"casing and annuli with cement as required. WEST STAINES STATE#2 Abandonment Procedure;11111111111111111.1110.111.111 •• • POINT THOMSON PRODUCTION 20. 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#2 ExxonMobil Oil Corporation PTD # 175-002 API # 50-089-20004 21. Backfill cellar with gravel. Mound the gravel (5-10')to compensate for summer thawing and settling as per AOGCC guidance. 22. 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#2 Abandonment Procedure Page 3 of 3 POINT THOMSON ' 411 1PRODUCTION ExxonMobil Oil Corporation West Staines State#2 Current Well Schematic API#: 50-089-20004 APTD#: 175-002 evWellhead A section in place with eblind flange and marker post on top frt , % F st -r� r ::: i r*vs' BP in9-5/8"casingat150' with .��; � � �; ,��;� cement on top to surface 30", 154#, B Grade at 74' g1 Arctic Pack in 9-5/8"x 13-3/8"annulus -12 "1. Diesel �, f/2,223' to surface ,,, IT ' 20" @ 787' s r /►, U,. .. °' 0`'` tP•ws Diesel in 9-5/8"casing at 2,279'- 150' . 014 Base Permafrost 2,050' &,(1,1. 3 `, , �5 O / % FO Collar at 2,223' in 9-5/8"casing `'` " 13-3/8"casing at 2,275' cmtd to surface 50 sx plug inside 9-5/8"csg 2,397'-±2,297' s 40 sx plug outside 9-5/8" csg 2,397'-±2,250' $',-I " ,.. FO Collar at 2,397' in 9-5/8"casing 5 EZ drill BP at 3,000'with 40 sx cement on top s , __ $ No $ mud $ wt $ data c Cement Top 10,270' behind 9-5/8"casing rt 4 II, s1; '� � �'� � Tri „, . >1/44 ',; r.�„ , 9-5/8" casing at 11,270', cemented with 650 sx ''.4%,-1411 class G 100 sx class G cement plug from 11,170'- 11370' '. 4.-..0'.;;* ext across 9-5/8" casing shoe and 8-1/2"open hole fi e fi fi Total Depth 13,171' WEST STAINES STATE#2 Current Sketch Page`fa-1, , POINT THOMSON 41(� PRODUCTION ExxonMobil Oil Corporation West Staines St. #2 Post-P&A Well Schematic API#: 50-089-20004 APTD#: 175-002 Marker plate at-3' hoicm ti,rdra ,Ar e4i 0.+ rt.;,► • 1;f';1t - '•. 5} ,;V4 Perfs at±200' ' • �z - " •4 Cement in 9-5/8"x 13-3/8" csg . .., • . - . • from ±200' to surface . . % 30", 154 lb/ft, B Grade at 74' ' Cmt'd w/255 sx of Arctic Set Cement from ±2,297' to surface ,i $ , *`t` 20", 94 Ib/ft, H-40 at 787 .. , '; ' Cmt'd w/4380 sx of Arctic Set Arctic Pack in 9-5/8"x 13-3/8" annulus from 200' to 2,223' ` $' *• ,X'r'' . , Base Permafrost at 2050' FO Collar at 2223' in 9-5/8"csg m$ ,;•� -t.,..-,9. 50 sx Arctic Set plug inside $ r,. . „ -....e.,-...-.'r,t: 13-3/8", 72 lb/ft, N-80 at 2275' 9-5/8"at 2397' to +/-2297' .t. Cmt'd w/3870 sx Arctic Set FO Collar at 2397' in 9-5/8” csg Cmt'd outside 9-5/8"w/40 sx Arctic Set from 2397 to +/-2250 sf HOWCO EZ drill BP at 3000' ',",v,.„. w/40 sx(+/-100'?)cmt plug on top _ — s No mud w o wt 0 data w o `k TOC at+/-10,270' '4 A 9-5/8", 47 &43.5 lb/ft, S-95 at 11,270' ' ''-,, Cmt'd w/650 sx class G w/ 18% salt 100 sx cmt plug from 11,170'- 11,370' across ", `^3 , 9-5/8"casing shoe and 8-1/2"open hole a ' z z r z � z 5 Z Total Depth 13,171' WEST STAINES STATE#2 Proposed Sketch MEM POINT THOMSON r. V'J PRODUCTION BOP Configuration 7-/ i M O. i . � Injector Head for a" coiled tubing n. 1J Pir:::11ti I - 4I, ! I, {._.._. Dual pack-off 1 -- 4.06" ID, 10k Lubricator as needed I6' &8' sec:ionsr p Blind .1; tS Shear SLB Quad BOR, 10k L. , 5ra� rftr, OK rill is I ' Pipe 4:4=1 ' t w Wil � SIB zombi BOP, 10k .+ 11", 1Okx41x1:6".14k x-o'E— (flange to be used for BHA changed w• a ilk', lakSpacer Sjx ol,3ft . t 11", iak Flow Cross i demeti ; —'n 1 1 loft--' _ • ! - 11',10k 1',10k Blind Ram III •;:w' ' 'II tl. & i 11,",10k Blind/Shear Ram l' '— ' -- Wellheads to be upgraded to 10 k service WEST STAINES STATE#2 Planned BOP Assembly IIIMII Schwartz, Guy L (DOA) From: Juranek,Tom A <tom.a juranek@exxonmobil.com> Sent: Wednesday, December 04,2013 12:47 PM .d Z____, To: Schwartz,Guy L(DOA) tts SS Cc: Dragnich, Rob/EXT; Denman, Erika/C Subject RE: PT-1 PT-2 and Staines River State#1 h /75—OO.z Attachments: WSS#18-9-23 Isolation 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. 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) [maiito: uy.schwartz'a 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 6 o SI CNi C I co I IP1 N C/1. Nm J � 1� LL � LD kA n X � � N No Y Y S O ) 0 /y' � f O J O N F u nom, �� I. v �n �;-i 7L c9-3-: c) 1 > �11111N1 (D Li-1 �Tv. \ ,K,..t..: 0111°- ' (- —.'1 EL ` NN A / . s Q N Q / F LH Z ode .5:.;')-1 _�� J�Q rn r ® ® , 4_____[——------'--- bpiw w c_,>< k/) Q Y _...- �Ln , z N r Q d I N ME, ® o N P110 � � ILJ�I�11JI _ ! � �I C �' N m ‘--.0. > v o — N I I ;_;� • 0 f ) Q N J 4co z �' WX� o Q CO CO N 0 _ x a w I v w a : >cL , F — z a- z 0 .m:i-.1',::',i Io , . ° 0 z H 0 z w a 4 m H CaH H H H f R N o 1 gio 0 (.: 1`) aC r" II, ,....v.C\ _:.,‘" ' a- 1110 ,, , _ ,) (G) L; o Q O o Q O Ci ■ � 7, r: // r c„ d 0 fid .- O � > I. aL _ ✓1 C`Y QLfl Q Y S CO W Lo J LL L Lr) O In I F C- — U i )o / ] N N V I w O L119 11 l�JJ ITa1•11u1.1cvl mmW ifi a o Amo o -- F,m 0 ago - 4 = n ,.1 a a w _ I- > H cL wW .imwai io_LL. 8 0 Z H 0 Z w a a caH H N H H H t 4 / L ; ', J 1 ,ivy M-) CO) > V IF >,•-,,{Y (() l ��I _ J_� \11\�-,�\,_i I� '—, I 1 C.5 1 m ' o Q 3. It x ti.Llui (,) L n 1 k „ ci M I_J_-_-. ,h (/)--,)0' \ '.,,,-4 _ -' (-)1 ] C) __ __ 1 i _,,,,,,, ----1 tn w < U X Q L_ CL Lr Q z V o \ II ) iii1 AIM Eii. .gg w ji® ® MI \ n ) rill z Di--.,L1-° I ---E ; • _ ( itit=a1 cc Q �I N 1,1z1 r 4 O \ I 1 Lc) -21 ji; : \ =Ln— H a Ci _VI a W Q k > d _ H Z ,LAmw<i' Lo-LL; 8 0 Z H Q Z w a a N H co H Z H i Y Page 1 of 3 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, July 16, 2012 2:08 PM To: 'Juranek, Tom A' Cc: Rob Dragnich (rob@rgdragnichllc.com); Wong, Gilbert; Hanenberg, William J; Cox, Mirick T; Collins, Dennis /C; Mohr, Jack W; Regg, James B (DOA) Subject: RE: West Staines State #2 - wellhead inspection (PTD 175-002) Tom, I misunderstood your first email ... my apologies. Here are the updated requirements: 1) A 10-403 is not required to perform the work you are proposing 2) Backfilling the mound again is not required. The wellhead should be left without handles or the valves secured with chain and locks. Some kind metal barrier should be placed around the perimeter of the wellhead also. Additionally, the wellhead can be wrapped with some kind of heavy plastic to discourage tampering. 3) We will waive witness to the inspection you are proposing. 4) Submit a 10-404 with pictures and a report of work completed That should do it. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Juranek, Tom A[mai Ito: tom.a.juranek@exxonmobil.com] Sent: Monday, July 16, 2012 1:33 PM To: Schwartz, Guy L (DOA) Cc: Rob Dragnich (rob@rgdragnichllc.com); Wong, Gilbert; Hanenberg, William J; Cox, Mirick T; Collins, Dennis /C; Mohr, Jack W; Regg, James B (DOA) Subject: RE: West Staines State #2 - wellhead inspection (PTD 175-002) Guy, Sorry for not putting the PTD number. I'm still learning the protocols for working in Alaska. I'll remember to do this in the future. The inspection we are planning is to open the side outlet valve and visually inspect inside the wellhead either with a flashlight or a scope. We are looking to verify if a support bushing is installed internally in the wellhead. FMC needs this information so that we will be able to bring out the correct equipment to change out the 5k psi tubing head with a 10k tubing head for the final P&A activities. I am attaching a wellhead diagram for the West Staines State #2 for reference. Therefore, we will need to remove the gravel to get access to the top side outlet valve. With that in mind, the question is whether we need to re -mound the wellhead with gravel or will it be sufficient to leave the wellhead exposed with reflective tape on it for the roughly eighteen months between the inspection and the final P&A activities? Likewise, would a Form 10-403 be required for this inspection 7/16/2012 Page 2 of 3 and would the AOGCC like to witness? Sorry for any confusion. Thanks for all your assistance, Tom Juranek Subsurface Engineering Advisor Exxon Mobil Production Company 800 Bell Street, CORP -EMB -30395, Houston, TX 77002 Phone: 713-656-4225; Fax: 713-656-7353; BB: 832-596-5406 email: tom.a.juranek@exxonmobil.com From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, July 16, 2012 3:51 PM To: Juranek, Tom A Cc: Rob Dragnich (rob@rgdragnichllc.com); Wong, Gilbert; Hanenberg, William J; Cox, Mirick T; Collins, Dennis /C; Mohr, Jack W; Regg, James B (DOA) Subject: RE: West Staines State #2 - wellhead inspection (PTD 175-002) Tom, I looked over the well file again and I don't see any reason to remove the gravel before the final P & A activities that are scheduled for the upcoming ice road season. An inspection of the site this summer would be prudent but I don't see any reason to notify the AOGCC or even submit a 10-404 inspection report unless there is something amiss or very different than expected. (The last time you were there to look at it was in 2010 when the rig moved off due to ice road time limitations. A thorough inspection of all wellhead pressures was done at that time and reported properly in the 10-404 report that was submitted.. ) PS Please put the PTD number in the subject line of any email correspondence. Much easier for me to make sure we are talking about the right well!! Thanks ! Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Juranek, Tom A(maiIto: tom. a.juranek@exxonmobil.com1 Sent: Monday, July 16, 2012 12:05 PM To: Schwartz, Guy L (DOA) Cc: Rob Dragnich (robC@rgdragnichllc.com); Wong, Gilbert; Hanenberg, William J; Cox, Mirick T; Collins, Dennis /C; Mohr, Jack W Subject: West Staines State #2 - wellhead inspection Guy, as we discussed earlier, we're planning to inspect the West Staines State #2 wellhead (AOGCC file 175-002) this summer in preparation for conducting further P&A work on the well during the winter of 2013-14. 1 believe you indicated we did not need to submit a Form 10-403 Application for Sundry Approval to do the inspection but that we should file a Form 10-404 Report of Sundry Well Operations reporting on the results. The wellhead is currently covered with gravel (see attached photo). We propose to leave it uncovered after conducting the inspection. Recovering would simply require additional manual labor and we would need to uncover it to conduct the well remediation work. One of the potential reasons for covering it is to prevent or reduce the possibility of a snow -machine traveling across the tundra colliding with the wellhead. In its current configuration, the 7/16/2012 Page 3 of 3 mound around the wellhead provides limited protection against this. To further provide protection, we will place reflective tape on the wellhead. There is no internal pressure in the well and the valves will be chain -locked in the closed position. We are tentatively scheduling to do the inspection beginning on August 24. Would the AOGCC wish to witness the inspection? Would you please confirm our understanding re: Form 10-403, acceptability of leaving the wellhead uncovered, and whether we should further notify the AOGCC a few days before we conduct the work? Thanks, Tom luranek Subsurface Engineering Advisor ExxonMobil Production Company 800 Bell Street, CORP -EMB -3039S, Houston, TX 77002 Phone: 713-656-4225; Fax: 713-656-7353; BB: 832-596-5406 email: tom.a.iuranek@exxonmobil.com 7/16/2012 • -----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 V 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 SLOAM 0 C i 1� 2 [its} 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 E • -----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 n 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 r7 `-A 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 42 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: 907-301-3316 Fax: 907-564-3705 e-mail: gilbert.wong@exxonmobil.com ExxonRAobll Development Company P.O. Box 241449 Anchorage, Alaska 99524-1449 907 564 3617 Telephone 907 743 9809 Facsimile September 15, 2010 ER -2010 -OUT -0148 Aftbwoe Mr. Tosunder a Oil 8, Gas Conservation Commission 333 West 7th Avenue, Suite100 Anchorage, Alaska 99501 Brien E. Reep Environmental and Regulatory Manager Point Thomson Project Development &6&#&U OCT 14 2010 Re: Plug and Abandonment of PTU Wells t�5� Dear Mr. Maunder: l�oct' tam 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 step of the remediation work involves removal of Arctic Pack from the upper portion of two annuli of TU -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- September 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 aack.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 Snubbing Unit at West Staines State #2 (March 2010) 1 E)f(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 Ef(onMobil Production Scope of Well Remediation (WSS 18-9-23 and Z 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.!PFonMo b i I Production H Ll 'to dread A sKlcn In pLwe M& tft iww an tall Scl sbudwa, a, 12' m4rerted w1r -6 sm Ctm-xg v I S-Bff x 9-W" awuk-, lkv, i,4 T 5D Tatum is-SkAll, MTod at I'mS Cempt in 13-317 x �&r zr.rulus hm,- 1,472- - 2, 1 CS . 3, 1T, 61z, C zr 2, 1, YP T-00Cm 9-SoYmift W. 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Coad rtkars zV, a-ewL, 7,7,-CVCf439!Earl. r-e-enled -jv th 423 -aG PerVallons 9 Siff - iC,OCC, 4W.- %7-etaecc aIh - X sc :1amm GIrrmp reta:m 313 u v Lg on re-ir er PWomllcins IAS77 - '3 zS7,4 we, WLP-42ed WVn 113 CLA Cerel 33 51 pug P15cedx la? cr SPRal-3fRff P&Mfoums I i'sw - I t'sn. 4 W, FtfliNatiorm 11,67V- 11,719, 4W Pefftfallom 11.753' -11,787, PerValims IZSIZ -" ZS29,44Y PerVallms IZSZ'e - `3 E37, 4sY Per%mikas I7,E3C - .ES7, AW perval kms I Z 6 9V - 7C7, 44-Y PerVallcm iZ790! - '27SIR, 4s1 2 sy cen--rt:r W Cf EZ:J*U C-e-x-rn j:Lgv 7t,,xr, 12,9XI -15:073' C3:S',28 5c�95 I ME, 2W SCC -95 a EF laW w& 13ratr , % we and :2 Jar Deffmrted Or �X, sm G squeemed 4 tires jk IP -:642 svG'm0z1 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSI~ REPORT OF SUNDRY WELL OPERATIONS 12EC~~VED MAY-1 ~ 2010 1. Operations Abandon Repair Well Plug Perforations Stimulate erformed Performed: Alter Casing ^ Pull Tubing ^ ~ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator 4. Well Class Before Work: .Permit to Drill Number: Name: ExxonMobil Oil Corporation Development ^ Exploratory Q 175-002 3. Address: PO Box 196601 Strafigraphic^ Service ^ .API Number: eSFr.~.s Anchorage, AK 99519-6601 50-089-204 • ~ 7. Property Designation {Lease Number): ~ 8. Well Name and Number ADL 28377 (Expired) West Staines State # 2 9. Field/Pool(s): \ Wildcat Field 10. Present Well Condition Summary: Total Depth measured 13,171 feet Plugs (measured) 35 - 150 feet true vertical 13,170 feet Junk (measured) N/A feet Effective Depth measured Surface feet Packer (measured) N/A feet true vertical Surface feet {true verfical) N/A feet Casing Length Size MD TVD Burst Collapse Structural 74' 30" 74' 74' N!A N/A Conductor 707' 20" 787' 787' 1530 520 Surface 2255' 13 3/8" 2275' 2275' 5380 2670 Intermediate N/A N/A N/A N!A N/A N/A Production 11250 9 5/8" 11270' 11269' 8150/7510 5090/4130 Liner N/A N/A N/A N/A N/A N/A Perforation depth: Measured depth: NIA True Vertical depth: N1A ~~ '` ` 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 11. Stimulation or cement squeeze summary: No treatment performed Intervals treated (measured): None Treatment descriptions inGuding volumes used and final pressure : No treatment with 0 psi pressure left on 9-518" and 13-3/8" casing 12. Representative Daily Average Production or Injection Data Oit-Bbl Gas-Mct Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A WA N/A 175 0 Subsequent to operation: N/A N/A N/A 0 0 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory Q Development ^ Service ^ Daily Report of Well Operations See Attachment 15. Well Status after work: Oil Gas ~ WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 16. 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: 310-060 Contact Jack Ridcner (281-217-4350) Printed Name Brien Reep Title Environmental 8 Regulatory Manager Signatur Phone 907-564-3617 Date a is a~1~ t0 DNIS MAY 12 Form 10-404 Revised 7/2009 ~ `' "' t~,ZS Submit Original Only • Current Well~ore Sketch ExxonMobil West Staines State #2 API #: 50-089-20004 PTD #: 175-002 FMC 13-5/8", 5 10.7 ppg CaCl2 brine on top of cmt plug / Arctic Set cmt from 35' to 150' ~ HOWCO EZ Drill (BP or retainer) 4 "` in 9-518" csg at 150' ~ W= ~~ -~ Arctic Pack in 9-5/8" x 13-3/8" annulus at 2,223' to surface ~~ B & C-sections, A-section unknown 30", 154 Ib/ft, B Grade at 74' Cmt'd w/ 255 sx of Arctic Set ' 20", 94 Ib/ft, H-40 at 78T Diesel ' , s Cmt'd w/ 4380 sx of Arctic Set Diesel in 9-5/8" csg at 150' to ± 2,297' FO Collar at 2,223' in 9-5/8" csg 50 sx Arctic Set plug inside 9-5/8" at 2,397' to ± 2,297' FO Collar at 2,397' in 9-5/8" csg Cmt'd outside 9-5/8" w/ 40 sx Arctic Set from 2,397 to ± 2,250 HOWCO EZ Drill (BP or retainer) at 3000' w/ 40 sx (+/-100'?) cmt plug on top '~~ >; ~ Base Permafrost 2,050' w -" s,x ;.4 . -,~'' C fi No mud wt ~ data s ~. ~ 13-3/8", 72 Ib/ft, N-80 at 2,275' t 2,297' Cmt'd w/ 3870 sx Arctic Set TOC at +/-10,270' 100 sx cmt plug from 11,170' - 11,370' across 9-5/8" casing shoe and 8-1/2" open hole Total Depth 13,171' 9-5/8", S-95, 47 Ib/ft at _ 2034' & 43.5 Ib/ft, at 11,270' (50 jts of 47 Ib/ft & 227 jts of 43.5 Ib/ft Cmt'd w/ 650 sx class G w/ 18% salt Well schematic drawn June 29`", 2007 by Fairvveather E & P Services, Inc. Last updated on May 4, 2010 by EM ~ ~ West Staines State #2 FMC OBS 13-5/8 5K 5" LP Marker Post - 13 5/8" 5M 13 3/8" to 2275' Notes: Tbg head P#19-030-636 (25" TALL) Casing head P# 19-030-626 (24" TALL) ~~~a OCT Tubing Spool i- - ~ 9 5/8„ I i I I i ~OC~ i ~ i ~ ~_._ I~ ~i ~~ it i i i OCTi ii ii iioii~ ii ii i~ i ii I'i -r~~ i i~- ~_~I~? _~ -i~_~~' FMC Model 120+ 31 /8" 5M Valve FMC Model 120+ 3 1 /8" 5M ~~ ~~ ^ Spool and Valve may or may not be present. 20" to 787• 30" to 74' • • ;~, .:' ~:;.< ~4 ~. ,~. i •., '~; - ;_~, ,'.` • • April, West nes State #2 as at end of work ~- -- - . ..,, .. ~,P ~¢~y ~=' ~~ ","` ~ ' , :~ , ~,-- • ExxonMobil Development Compan~ 3301 C Street, Suite 400 Anchorage, Alaska 99503 907 564 3617 Telephone ~ sg 907 564 3772 Facsimile ~~ ~,1- F MAY1~~201~ w ~~ ~~ ~. mmi~~lc~r; ~nchar May 12, 2010 ER-2010-OUT-0092 Mr. Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Report of Well Operations ExxonMobil Oil Corporation West Staines State #2 PTD No. 175-002 Sundry No. 310-060 Brien E. R~ Environmental and Regulatory Manager Point Thomson Project E~onMobil Development Dear Commissioner Seamount: wrc;\~-:s ~ ~c}~wn~~~ ~~~ v~xcl~,~~~~~~~ ~~vE~ 5~~~-1~ ExxonMobil hereby submits a Report of Sundry Well Operations for remedial work on the West Staines State #2 (WSS #2) well. The well is plugged and abandoned. An attempt was made to re-enter the well this winter season for the purpose of removal of the diesel from the 9-5/8" casing and the Arctic Pack from the 9-5/8" by 13-3/8" annulus at the request of the AOGCC. The operation was not completed, and the work will be scheduled for next winter season. Mobilization began to the WSS #2 well pad site on March 8, 2010. During the mobilization and rigging up process, an external visual examination of the wellhead indicated that the well head valves were in the chained and locked condition and no visible leakage of fluids had occurred. The wellhead was wrapped and heated prior to installation of pressure gauges. After wellhead thawing, the pressure reading on the 9-5/8" casing pressure was zero and no fluid recovery. A reading of 175 psi was found on the 13-3/8" casing but quickly bled to zero psi. Approximately two quarts of clean diesel was bled down with no gas. It is believed that the observed pressure was due to thermal expansion from the heat applied during the wellhead thawing operation. Several times prior to removal of the tree cap, the well was sniff tested for hydrocarbons and none were detected. Upon removal of the tree cap, the fluid level was at 30 feet below the wellhead and hard bottom, likely the top of the cement surface plug, was tagged at 35 feet. Prior to completion of the BOP rigging process, the 9-5/8" casing was filled with 10.7 ppg calcium chloride brine. An ExxonMobil Subsidiary Mr. Dan Seamount -2- ~ May 12, 2010 On April 7, an unsuccessful BOP test was conducted. Given the anticipated time necessary to complete the well work including likely weather and mechanical delays, it was projected that the necessary well work might not be completed until the end of April, which was at or potentially after the date for ice road and tundra closures. Given the intact condition of the surface plug and integrity of the wellhead, it was determined that the rig could be demobilized and the well left in a safe condition. .Therefore rigging down operations were initiated, with demobilization from the site completed by April 17. During the demobilization operations, the BOP stack was removed and the fluid level inside the 9-5/8" casing was determined to be at the 13-3/8" casing valve. The pressure on the 13-318" casing was 50 psi which was bled to zero. Final casing pressures were taken and zero psi recorded for both the 9-5/8" and 13-3/8" casings. Valves were closed, chained, and locked and the wellhead marker post re-installed. Herculite liner material was used to wrap the wellhead and gravel was mounded around the wellhead for additional protection. The remaining equipment was removed from the site and demobilization was completed on April 17. Attached please find: Form 10-404: Report of Sundry Well Operations Wellhead drawing Wellbore diagram Well Plat Photographic documentation of the well before, during and after the work If you have any questions or require additional information, please contact me at 907-564-3617. Si For and On Behalf of Exxon Mobil Corporation BER:jar:eaa Attachments • • Page 1 of 1 Maunder, Thomas E (DOA) From: Crisp, John H (DOA) t t� Sent: Thursday, April 08, 2010 8:20 AM -` ' ! 5 To: Regg, James B (DOA) (° Cc: Maunder, Thomas E (DOA) 'S Subject: CUDD West Staines Vt-lS C� Just a note about the P &A on West Staines. We were attempting to test the Annular preventer, the CH2MHill 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. 4/9/2010 • 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 CH2MHi11 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 411 411 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 CH2MHill 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 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 CH2MHi11 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 ~~ S~~G~~C~ 0~ a~a~~(Q /,~,~..E..oo~.~. Dale Pittman Alaska Production Manager Exxon Mobil Corporation P.O. Box 196601 Anchorage, AK 99519-6601 Re: Wildcat Field, West Staines State #2 Sundry Number: 310-060 Dear Mr. Pittman: n ©`~'' ~~ '~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the unclosed 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 rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 1 ~ day of March, 2010. Encl. ExxonMobil Development Compan~ 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 #2 PTD No. 175-002 Dear Commissioner Seamount: ~E~ElVEC~ EEB ~ 5 2010 All~sko Oil ~ 6as Gem. Comrnia~i~n An~hptag~t 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. Check wellhead pressures to verify integrity. 2. Use 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 CaC12 brine. 4. Set a bridge plug at approximately 250'. 5. Perforate the casing at approximately 200' and attempt to circulate out the arctic pack in the 9-5/8" x 13-3/8" annulus. 6. Cement casing and annulus with permafrost cement from approximately 200' to surface. 7. Rig down the snubbing unit and excavate the well cellar. 8. Cut off the wellhead and casing strings at least 3' below the tundra and remove. 9. 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 ely, DDP:eaa Attachments Brien E. Reap Environmental and Regulatory Manager Point Thomson Project E~onMobil Development An ExxonMobil Subsidiary • • NOTE TO FILE ~r 175-002 ExxonMobil West Staines State #2 310-060 Exxon has 'made application to perform remedial plugging and abandonment work on the subject well. This and other work proposals are in fulfillment of Exxon's commitment to perform remedial plugging and abandonment work on legacy wells in the Pt. Thomson Unit following a series of Commission letters beginning in May 2007. I recommend approval of Exxon's proposal. This proposal as well as one for West Staines State #18-9-23 (169-120) is the first new work proposed where Exxon plans to re-enter legacy wellbores. The need to re-enter the wellbores is to remove and replace the diesel in the wellbores through the permafrost interval and prepare the wells for final plug and abandonment including wellhead removal. Similar work was successfully accomplished about 1998 in several other Exxon legacy wellbores at Pt. Thomson. Similar work has also been successfully accomplished by CPAI and BP in their legacy wellbores. The novel proposal for this latest work is employing a hydraulic workover or snubbing unit to allow pipe movement in the well. In order to remove the diesel, it will be necessary to drill out the surface plugs placed in the well long ago. The snubbing unit is one of 3 possible ways to be able to move pipe in the well. The others are a conventional rig or coiled tubing. Coiled tubing was employed in the 1998 Exxon work. The Inspectors have expressed reservations about using this equipment due to it being "stick built" and potentially not adequately shielded from the elements. Both the Inspectors and myself have expressed concerns regarding the nearly exclusive use of hammer union connections. After contacting Exxon, high pressure hoses have been included in the choke and kill lines and an equipment placement drawing and winterization plan provided. It is my assessment that Exxon and their contractor (CH2MHili) have considered the need to keep equipment, fluids, etc from freezing and have made plans to have the necessary equipment available. Regarding fluid lines, the choke and kill lines are easily the most critical. These now will be flanged hoses. All hammer union connections have not been eliminated, but given short time duration (likely less than 1 month) that this equipment will be employed it is my opinion that eliminating all such connections is not practical. The lines will be tested according to the regulations and Exxon will need to make repairs, if necessary, to allow pressure competence to be demonstrated to that satisfaction of the attending Inspector. Employing multiple no-flanged connections should not compromise the ability to control any pressures. To date no pressures associated with hydrocarbon reservoirs have been encountered in the many prior similar re-entries that have been accomplished. The planned work will result in the removal of the surface cement plug, but there is no intent to disturb any deeper plug in the well although the plug at near the base of the permafrost may be tagged. It is uncertain if tagging the plug as proposed will. be possible. Shallow collapsed casing has been encountered in several of the past re-entries and in particular in wells where prior work had been accomplished more that 15 years ago. Collapsed casing was encountered in the Alaska State A-1 {179-080) during the 1998 work. The collapsed casing has not precluded removing the diesel in those wells. I recommend approval of Exxon's proposal. ~~ Tom Maunder, PE Sr. Petroleum Engineer • Maunder, Thomas E (DOA) From: michael.d.murrey@exxonmobil.com Sent: Thursday, March 11, 2010 12:46 PM 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 (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 BO Ps. 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 E-mail: michael.d.murreyCexxonmobil.com STATE OF ALASKA ~3j ALASKA OIL AND GAS CONSERVATION COMMISSION / l ~ APPLICATION FOR SUNDRY APPROVALS Alaska Oil 8t bas Cerrs. Commission 20 AAC 25.280 ®nnM~rhne R~G'~IV~L~ FEB 2 A 2010 1. Type of Request: Abandon ^ Plug for Redrill ^ Pertorate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Pertorations ^ Pertorate ^ Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-enter Susp. Well ^ Stimulate ^ Alter Casing ^ Other: Well Remediation~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exxon Mobil Corporation Development ^ Exploratory Q 175-002 ' 3. Address: ^ Stratigraphic ^ Service 6. API Number: PO Box 196601, Anchorage, AK 99519-6601 50-089-20004 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: N/A Spacing Exception Required? Yes ^ No ^ West StalneS State # 2 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 28377 •Ex fired 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): 13,171 13,170 + Surface Surface See Attached None Casing Length Size MD TVD Burst Collapse Structural 74' 30" 74' 74' N/A N/A Conductor 767' 20" 787' 787' 1530 1500 Surface 2255' 13 3/8" 2275' 2275' 5380 2670 Intermediate N/A N/A WA N/A N/A 7100 Production 11250' 9 5/8" 11270' 11269' 8150/7510 7100/5600 Liner N/A N/A WA N/A N/A N/A Pertoration Depth MD (ft): Pertoration 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 Q Development ^ Service ^ 14. Estimated Date for 2-Mar-10 15. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ 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. Contact Jack Rickner 907-564-3638 Printed Name Dale Pitt an Title Alaska Production Manager Signature Date ,i K olD COMMISSION USE ONLY Conditions of ap witness Sundry Number: ~/~ ~ (~~j~ roval: Notif Commission so that a re resentative ma p y p y Plug Integrity '~ BOP Test '~ Mechanical Integrity Test ^ Location Clearance '~ Other: e3 5O C7 P5~ 3~~ ~CS~ ~ ~~'~~ ~t`S,Q~-~ `~~~ ~®~-~5~-. ~ e-s-~~t~~~ Subsequent Form Required: ~ ,0 ~-t~~ fct~-~~~ ~ hC`V~ i~~ ~~ t~ ~~ ~'~ i ~ ~~ ~ y vJ ( ~ ~ p d A~~ROVED l3Y Approved by: COMMISSIONER THE COMMISSION Date: ~ ~ ~ l V / Form 10-403 Revised 12/2009 ~~ R I G I N A L CMS NAR 121010~M., s ~~ x _ZG., re Submit in Duplicate ,/~` ~~O Current Wellbore Sketch ExxonMobil West Staines State #2 API #: 50-089-20004 APTD #: 175-002 FMC 13-5/8", 5 kpsi A & B sections Arctic Set cmt from surface to 150' BP in 9-5/8" csg at 150' ~ Arctic Pack in 9-5/8" x 13-3/8" annulus at 2,223' to surface FO Collar at 2,223' in 9-5/8" csg 50 sx Arctic Set plug inside 9-5/8" at 2,397' to ± 2,297' - FO Collar at 2,397' in 9-5/8" csg Cmt'd outside 9-5/8" w/ 40 sx Arctic Set from 2,397 to ± 2,250 HOWCO EZ drill BP at 3000' w/ 40 sx (+/-100'?) cmt plug on top 30", 154 Ib/ft, B Grade at 74' Cmt'd w/ 255 sx of Arctic Set ~."his 20", 94 Ib/ft, H-40 at 78T Diesel "`,• ~ Cmt'd w/ 4380 sx of Arctic Set ~, : s ~~ ~~s Diesel in 9-5/8" csg at 150' to ± 2,279' ~s •; s f' ~ •~~ Base Permafrost 2,050' ~~~ t 2 297, ~ 13-3/8", 72 Ib/ft, N-80 at 2,275' . Cmt'd w/ 3870 sx Arctic Set No mud wt data TOC at +/-10,270' 9-5/8", 47 & 43.5 Ib/ft, S-95 at 11,270' Cmt'd w/ 650 sx class G w/ 18% salt 100 sx cmt plug from 11,170' -11,370' across 9-5/8" casing shoe and 8-1/2" open hole Total Depth 13,171' Well schematic drawn June 29"', 2007 by Fairweather E & P Services, Inc. Updated on April 7, 2009, July 28, 2009, and September 8, 2009 bV EM i ~ Proposed After PEA Wellbore Sketch ExxonMobil West Staines State #2 API #: 50-089-20004 APTD #: 175-002 Well marker at - 3' below tundra PF cmt in 9-5/8" csg & 9-5/8" x 13-3/8" from - 3' to 205' Perf'd csg at 200-205' CIBP in 9-5/8" csg at 250' Arctic Pack in 9-5/8" x 13-3/8" annulus from 205' to 2,223' FO Collar at 2,223' in 9-5/8" csg 50 sx Arctic Set plug inside 9-5/8" at 2,397' to ± 2,297' - FO Collar at 2,397' in 9-5/8" csg Cmt'd outside 9-5/8" w/ 40 sx Arctic Set from 2,397 to ± 2,250 HOWCO EZ drill BP at 3000' w/ 40 sx (± 100'?) cmt plug on top 100 sx cmt plug from 11,170' -11,370' across 9-5/8" casing shoe and 8-1 /2" open hole 30", 154 Ib/ft, B Grade at 74' Cmt'd w/ 255 sx of Arctic Set ~ 20", 94 Ib/ft, H-40 at 787' Cmt'd w/ 4380 sx of Arctic Set 10.7 ppg CaCl2 brine in 9-5/8" csg at 250' to ± 2,297' Base permafrost at 2,050' 13-3/8", 72 Ib/ft, N-80 at 2,275' Cmt'd w/ 3870 sx Arctic Set TOC at +/-10,270' 9-5/8", 47 & 43.5 Ib/ft, S-95 at 11,270' Cmt'd w/ 650 sx class G w/ 18% salt Well schematic drawn June 29`", 2007 by Fairweather E & P Services, Inc. Updated on April 7, 2009, Auq. 13, 2009, Sept. 8, 2009, and Feb. 11, 2010 by EM Total Depth 13,171' 'M ~ C~ • West Staines State #2 FMC OBS 13-5/8 5K 5" LP Marker Post ~ 13 5/8" 5M 13 318" to 2275' Notes• Tbg head P#19-030-636 (25" TALL) Casing head P# 19-030-626 (24" TALL) ~..ai.,,r,,. OCT Tubing Spool ~ 19 5/8" I I I I I IOCT I I 1 I 1 I I + -- -I, II II ~I II II II ~ I(,1Ctl II II II Q II I 11 II II III ~~ ~ i~i~ T~"~ ~J Valve FMC Model 120+ 31/8" 5M Valve FMC Model 120+ 31/8" 5M D° ^ Spool and Valve may or may not be present. 20" to 78r 30" to 74' U West Staines State #2 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 #2 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. Warm up the wellhead using heaters to remove any ice plugs to the extent possible. 6. Check 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. 7. Move in and offload Snubbing Unit. ND wellhead flange cap and install 13-5/8" 5 kpsi by 11" 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 1000 psi assuming freshwater pressure gradient above the 13-3/8" shoe and the age of the wellhead (35 years). 8. PU bit, mud motor and drill pipe. Drill out surface cement plug and bridge plug down to 150' with 10.7 ppg CaClz brine (kill weight fluid). Use gas sniffer to check brine returns for HC and monitor changes in HC levels (i.e., diesel) while circulating if possible. RIH to 300'. POH. 9. RIH with mule shoe and drill pipe to PBTD at about 2297'. If tagged 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. 10. Circulate diesel and any debris out with 10.7 ppg CaCl2 brine. PU up to 300'. Circulate warm 10.7 ppg CaCl2 brine prior to perforating. POH. PU bit and casing scraper and RIH with drill pipe to 300'. POH with B&S. 11. RU Electric Line Unit. RU lubricator joint of drill pipe and pack-off. Pressure test to 250 psi and 2500 psi. • RIH with 9-5/8" gauge ring and junk basket to 300'. POH. Page 1 • RIH with 9-5/8" CIBP. Set BP at 250'. POH with setting tool. Pressure test BP to 2500 psi. • RIH with 1-11/16", 4 spf, zero degrees phasing, magnetically decentralized perforating gun and pert 9-5/8" casing from 200'-205' (5'). POH. RD. 12. Run in hole to 200 feet with drill pipe. Spot diesel at end of drill pipe and close annular preventer and circulate out arctic pack with warm diesel. Let diesel soak to assist in removing the arctic pack. Displace diesel with warm 10.7 ppg CaCl2 brine. POH with drill pipe. 13. RU Cementing Unit and pressure test lines. Bullhead 15.7 ppg, 0.93 ft3/sk, permafrost cement down the 9-5/8" casing while taking returns on the 9-5/8" x 13-3/8" annulus. Shut down when cement returns to surface. RD. 14. RD Snubbing Unit. 15. Excavate gravel from around wellhead as needed to allow Wachs external saw access and still be at least 3' below tundra level. May need to use jackhammer to remove any cement in the cellar to get below the 20" wellhead. Verify there is no pressure on the 13- 3/8" x 20" casing (it should be full of cement). 16. RU Wachs Guillotine external saw (maximum cut OD is 30"). Cut off the casing strings and wellheads to at least 3' below tundra level. RD saw. 17. Level casing stubs as needed. Top off 9-5/8" casing and all annuli with 15.7 ppg, 0.93 ft3/sk, permafrost cement as required. 18. Weld marker plate with the required AOGCC information on it across all casing strings. Take photographs showing the condition of the casing stubs and marker plate. 19. Backfill cellar with gravel. Mound the gravel (~5-8') to compensate for summer thawing and settling, per AOGCC guidance. 20. Conduct general location clean-up. Final well site restoration will be performed at a later date. Site gravel may be used for fill for the reserve pit. Take photographs showing the condition of the location. 21. Transport all wastes and site clean-up debris to Deadhorse for disposal at approved waste disposal sites in accordance with EM Waste Management Plan. 22. Prepare final well report and Sundry Report. 23. After the summer thaw, notify AOGCC for visual inspection and site clearance. Page 2 -- . - - _ _ - ExxonMobil CUDD ENERGY SERVICES West Staines State No. 2 ~ PROPOSED BOP STACK API # 50-089-20004 ~PTD # 175-002 ~ v~ a a a c d f~/1 ? t ~j }]~'^ to ip' j Cudd Snubbing ~ .. Alaska Stack r~ ~ l~ ; ~, .+• Bleedoff Line II ^~~~-Y ----- To Returns Tank n ~ ~,--w / pp,,yy~~ si~h~ > ~ ~ ~ r Y ~\•aMl ':I ~ 'o° ~ s 6 STATIDI M&e Freeman ALCUMAATpt 773.15E-19N ~~ :..a1= a/21-1'X23'4$ MOSES Housmn, Tx ((~~ ip Manlfold ~~ ~ ~ "`~' , - - ~ All Purop & Flow Lines a 2' 1502 Chlcksan ~] :~ Q w Choke Manlfold ExxonMobil Development Compa~ F O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3772 Facsimile ~tECEIVEQ MAR 0 8 2010 ~glvww~ ~c ~ ~1$, P,~T1I~ISS16iR ~~ March 8, 2010 ER-2010-OUT-059 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Application for Remediation ExxonMobil West Staines State #2 PTD No. 175-002 Dear Mr. Maunder: E~onMobil Development Attached for your review is the requested information regarding proposed well work on the West Staines State #2. The Sundry Notice application was provided by letter dated February 22, 2010. These enclosed attachments provide the following for your consideration: • Revised BOP Stack with the addition of hoses • Additional drawing of proposed equipment layout on the pad • Proposed winterization approach for the snubbing unit An original and one copy are provided. If you have any questions or require additional information, please contact me at 907-564-3638. Sincerely, rte` ~~~ ,~/. ~c'`'r~r~,2-," Jack A. Rickner Environmental and Regulatory Advisor Point Thomson Project JAR:eaa Attachments ~"~ L __. An ExxonMobil Subsidiary .. ~..~ a, a n. c 6 N Cudd Snubbing Alaska 11"5M 6-Ram Stack ~~_orW-C~`~ 'K 11' SM SNUBBING STS Bleedoff Llne ASSEMBLY To Returns Tank ~ ~~ ~ ~ B~ ~~ ~ o ~ RENl'~ 1 i o° ~ \, o`d s 6 STATION Mlke Freeman ACCUMULATOR Tt&252-19x4 ,. r ~ ---...!l. ~/24-1'X25'SS HGSES Houatan, Tx Pump Manifold ar r 2 Q n,-r To Tan > per Bobby Bray's conversation with Im Maunder regarding the AOGCC's Incerns with the number of connections the lines, all lines from valves below ind/Shear wlll be hose with flanged ~draulic connections to both pump. a ~> ~~ Choke Manifold • EDGE OF OLD RESERVE PIT IS 60 fEET FROM THE WEII • E ,E % E ~ ' r , ~ i~ ' ~ ~Y§ ~ MUD PUMP AAercv I I ~ h ~,~~ y''~ choke ~ I ~ COMPONENT LIST ~ PDmp Man nin ITEM NUMBER ITEM DESCRIl'TION QUANTITY W L ~ ~ ' MUD PUMP ~~,,,~ „"~: 1 Powerpack 1 8 14 ~Q~T i -. RACK LACK Sills for 2 POWCrpaCk 1 8 14 [ HosE wiNOwnus pipe Racks ' 3 RACK JACK Beam 1 1.5 40 ~ SlpBar ~ ' ~ AIA ~~' Hrarra 4 RACK JACK Beam 1 1.5 40 HOSE 'llvork ~' ;~. _ K'' ~' 5 Fuel Tank 1 8 6.66 ~ ~ 0 i P P GYM ~~R''~e'~~ ' ~ ?, Channel Iron or Beamfor lay down skid •" 6 HOSe Basket 1 7 7 ~ HOSE ~' , ~~ ~ ~~" ~~A 7 Hose Basket 1 7 7 ,: A~P ~e.~o ~ I eR ~ 8 Guide Wire Box 1 9 4 ~ n(~' ~ -i D.i TAE RACK,ncK 9 OIL TOTE 1 4 4 /,,,..%•"' , sHEO ~ wiNOwALLs ~, ~.:,, ~ _ „, 10 Slip Die Box 1 8 4 ' a~R PO 11 Pump Parts Box 1 5 4 ~~~~ Pa a~A RT 12 TOOL SHED 1 8 8 ~ `°`' Bottl - AB 13 Work Basket 1 21.66 8 Pa ~ ~ Accum ator LE 14 TONG UNIT 1 8 6 G HOUSE ; ;a er •~~ y a ~~, raNC ~„„ n ` r , o~~ ~~: skid OF 15 AccumulatorSkid/Conne 1 8 20 };, 16 Air Compressor 1 9 4 ' _ E E S 17 Mud Pump 1 8 20 4J aDLLRA,r ~ 18 Mud Pump 1 8 20 19 100 Bbl Return Tank 1 10 25 20 Choke Manifold 1 6 6 21 Pump Manifold 1 6 6 22 Dog House 1 8 16 23 Rack Jack Wind Walls 1 8 16 24 Rack Jack Wind Walls 1 8 16 25 SCAFFOLDING SKIDS 3 8 10 26 Hose Basket 1 7 7 27 Bottle Rack 1 5 3 28 LAY DOWN SKID BEA 1 2 40 29 Sill for Pipe Rack 1 1 30 30 Sill for Pipe Rack 1 1 30 31 Sills for Berming 20 1 20 32 Herculite 1 100 100 33 Two by Fours for Bermir 50 2" 12 foot 34 Nails for Berm Caps 300 10 Penny or better 35 ANCHORS ]5 1.5 I.5 35 Matting boards 35 8 30 36 LIGHT PLANTS 7 5 6 37 BOILER 1 10 50 38 AIR HEATERS 7 8 10 39 PORTABLE OFFICE 1 10 50 STEAM GENERATOR/BOILER 1 , BBL RETURN TANK H 8.6 8.6 3 3 6.83 2.5 2.5 3 4 3 3.3 7 4 8 8 3 8.6 8.6 6 3 3 8 16 16 8 2.5 6 1.5 I 1 1 0.05 4" 10 0.5 WT 18500 18500 4500 4500 6000 8000 8000 12500 13500 8000 20000 6000 14000 14000 4500 6000 2000 2000 40000 400 200 15000 4000 Winterizing of BOP, Piping, and Snubbing Unit Hydraulics BOP Stack & Piping • The stack will be drained and lines evacuated via blow down with air and/or vacuumed out with a vacuum truck each time pumping ceases. • As much of the piping and hoses as possible and practical will be run inside the heated rig structure or inside 12" heater trunks with hot air circulating through them and around the outside of the piping/hoses. • The fluid tank will have mobile steam generator/boiler circulating steam through the tank coil to keep fluids warm. • Fluids will arrive on location warm (approximately 120°F) and will be 10.7 ppg calcium chloride or diesel. • Cementing will be done with preheated fresh water. • Little Red Services has been contracted to provide a hot oil truck and heating services on a callout basis as needed. Snubbing Unit Hydraulics • Hydraulic fluid has been changed to synthetic OW-30 oil that has a lower pour point of -60°F. • Hydraulic hoses are low temp (-50°F) rated hoses. • Where possible, hoses will be run either inside the heated rig structure or inside 12 inch heated trunks with hot air circulating through the trunks and around the outside of the piping/hoses. • The entire rig operation will be set on a 90ft. by 90ft. lined secondary containment area. ExxonMobil Developmen# ~ompa~ 3301 C Street, Suite 400 Anchorage, Alaska 99503 907 564 3617 Telephone 907 564 3772 Facsimile February 8, 2010 Brien E. R• Environmental and Regulatory Manager Point Thomson Project _E~onMob~l I)e~a~~6~~a~ent ~~`~J Mr. John Easton Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 800 Anchorage, Alaska 99501 -'~~-- FED ~ ~ 2Q1~, FED ~. 0 2010 S C o issian nChf0 Re: Lease/Unit Plan of Operations Applications Point Thomson Area Site Remediation Project Dear Mr. Easton: ~~-~~o~~~~ ~Zc~A~ ~.~~ r~~-~aC~ 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 ExxonNiobi{ 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 LO/NS 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 , rriic 9MIGbK rmcdhncUan Curnprny 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 Alaska Production Manager Joint Interest U.S. RE: Request for Verification of Suspended and Shut-in Well Information Dear Commissioner Foerster: j:l' SEP 2 4 2009 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, DDP:jpc Enclosures xc: Mr. Tom Maunder — AOGCC A Division of Exxon Mobil Corporation Well Name Point Thomson Unit #1 Point Thomson Unit #2 Point Thomson Unit #3 Point Thomson Unit #4 Alaska State C-1 Alaska State J-1 Staines River State #1 ExxonMobil Submittal Suspended and Shut in Well Status Current Filing Report Status Date Suspended June 1, 2009 Suspended June 1, 2009 Suspended June 1, 2009 Abandoned June 1, 2009 Suspended June 1, 2009 Abandoned Suspended June 1, 2009 June 1, 2009 West Staines State #2 Abandoned June 1, 2009 West Staines State #18-9-23 Abandoned June 1, 2009 9/23/09 Commen�t7l Location and Well inspected 3/2009. 1702 �5 Location and Well inspected 4/2009. /77- a & V Location and Well inspected 4/2009. 1/O — ()0 Location and Well inspected 4/2009. -79 • Further remediation work planned for the 2009-10 winter season Location and Well inspected 4/2009. /X:�r • Well inspected and remediated and site cleared in 4/2009. lf,3• O.V5 Location and Well inspected 4/2009. 7 %• Location and Well inspected 4/2009. �� �Q4;z Further remediation work planned for the 2009-10 winter season Well is located on former ADL 0028377 Location and Well inspected 4/2009. Further remediation work planned for the 2009-10 winter season ExxonMobil Production Compa~ 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 7t" Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Report of Sundry Well Operations Exxon Mobil Corporation West Staines State #2 PTD No. 175-002 Sundry No. 309-080 ~ ~~~;~,~~~~$~~'~~~ .~~P~r± ~ ~ ~00~ 4~5~; ~~ yviA~ ~ ;;~~ ~;f~9T~: ~l~~'ft71~S~~~~4 ~~c~~r~~~ E~~nMobil Production 1~~s- 002- . ~,J-est ~ nes S~a~- ~k ~ ~ -- - Dear Commissioner Seamount: Exxon Mobil Corporation hereby submits its Report of Sundry Well Operations for the wellhead inspection of the West Staines State #2 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 the 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, and the well integrity was verified by checking for and recording pressures in the 9-5/8" casing and the 9-5/8" x 13-3/8" annulus. A pressure of 200 psi was noted on the casing, but this pressure quickly bled to zero and did not build back during the inspection. Two new gate valves were installed on the wellhead. At the end of the well inspection, the "B" section of the wellhead was left above grade, and the "A" section was partially covered with graveL Attached please find: Form 10-404: Report of Sundry Well Operations Daily Report of Well Operations WeUhead drawing Wellbore diagram Well plat Photographic documentation of the well before, during and after the work If you have any questions or require additional information, please contact me at 907-564-3617. Sincerely, _.~ ~ ' D. Michae! Barker Environmental and Regulatory Manager JAR:eaa Attachments A Division of Exxon Mobil Corporation i~ STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMI~N ~ ~ ,~~ .~~ ~ ~~~~a ~? J~~ ~~ .~ ~ .i'i0~ REPORT OF SUNDRY WELL OPERATIONS ~~~~~~~ ~~~~ ~~~~ ~;~~~ti ~~~~~~~~~~,; ~~rv~H 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Well Ins ction Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ^ Waiver^ 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~c~conMobil Oil Corporation Development ^ Exploratory^~ 175-002 • 3. Address: PO Box 196607 Stratigraphic^ Service^ 6. API Number: Anchorage, AK 99519-6601 50-089-20004 7. KB Elevation (ft): 9. Well Name and Number: 95 ° West Staines State # 2 ° 8. Property Designation: 10. Field/Pool(s): ADL 28377 ~ Wildcat , 11. Present Well Condition Summary: Total Depth measured 13,171 ~ feet Plugs (measured) Plugged to surface true vertical 13,170 ~ feet Junk (measured) None Effective Depth measured Surface feet true vertical Surface feet Casing Length Size MD TVD Burst Collapse Structural 74' 30" 74' 74' N/A N/A Conductor 767' 20" 787' 787" 1530 520 Surface 2,255 13 3/8" 2,275' 2,275' 5380 2670 Intermediate Production 11,250' 9 5/8" 11,270' 11,269' 8150 / 7510 7100 / 5600 Liner 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) N/A 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 Well Phographs Exploratory^~ ° Development ^ Service ~ Daily Report of Well Operations See Attachments 16. Well S tus ~ter work: Oil [~~y~;`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: ~ 309-080 Contact Mike Barker Printed Name Mike Barker Title Environmental and Regulatory Manager Signature~ ~ e, Phone (907)564-3617 Date ~ J ~~ ~ Form 10-404 Revised 04/2006 ~~ F-`~~ f ~~ Submit Ori inal Only ~ . ~ 61~~f • • Daity Operations Log West Staines State #2 Well Inspection Tuesday, April 14, 2009 • Started camp move to West Staines State #2. Verified camp-site is clean. • Arrived at West Staines State #2 and set up camp. • Applied heat to wellhead, built a snow ramp to off-load excavator. Wednesday, April 15, 2009 • Off-loaded excavator and began excavating around well. Put heat on new valves and prepped for installation. • Installed new 1/2" needle valve on existing needle valve of "A" section (outer annulus- 13 3/8" X 9 5/8" ). Tested valve to 250/5000 F/5 min., Obtained good test. Opened valves and bled off 2 gallons of diesel from thermal expansion. Shut in, waited and re-opened, no pressure observed. • Installed VR plug and removed flange and studs, installed new studs and valve. • Set up to test valve break. Pressure test to 250/5000 psi. Obtained good test. • Repeated above steps on "B" section (9 5/8). There was no pressure or any diesel in the "B" section. Installed bull plugs and chained valve handles shut. • Installed new needle valve on top flange (9 5/8") and pressure tested to 250/5000 psi for 5 min., obtained good test. • Opened valves, observed zero pressure, • Installed bull plug. Cleaned work area and welded marker post back on. • Located both VSP's and cut them off. • Coordinates for cut off's are: N 70deg. 06' 39.2" N 70deg. 06' 37.6" W 146deg. 25' 06.8" W 146deg. 25' 01.3" Thursday, April 16, 2009 • Mobilized equipment and tools to West Staines State 18-09-23. • Moved the camp. • Returned to West Staines #2 well-site with excavator and excavated a few feet down to verify there were no more flanges. • Headed to West Staines State 18-09-23 to start excavating around well. ~ ~ West Sta i n es State # 2 Tbg head P#19-030-636 (25" TALL) Casi ns~ he ad P# 19-030-626 (24" TALL) FM C OBS 13-5/8 5K 5" L P Marker post 13 5/8" 5k. OCT 13-5/8 5 000 k. ~ ncedle valve Ineirlo valvo FMf_ Mit7~ Z_1/R 5K 120+ OCT O IA ~ OA v alv es are 3-1 /8 5k Inside valve FMC M~753-1/8 5K Outboard valve 3-1/8 5K IW~ 120+ ^~ ExxonMobil Oil Corporation West Staines St. #2 Well Schematic API #: 50089200040000 APTD #: 175-002 Wellhead A and B sections in place with blind flange and mark post on top BP in 9-5/8" casing at 150' with cement on top to surface Arctic Pack in 9-5/8" x 13-3/8" ~;' Diesel ~' 4 annulus at 2,223' to surface ,1: °' ~' ~ 20" @ 78T Diesel in 9-5/8" Diesel in 9-5/8" casing at 2,250' - 150' Base Permafrost ~'~ "` r ~~~ '~ ~~ 2,050, : : ~ ~ .~.. ; hr~ ~: ~ ' ''~~ FO Collar at 2,223' in 9-5/8" casing ~ ~`~ '~' 13-3/8" casing at 2,275' cement to 50 sx plug inside 9-5/8" casing at ~;,. . '~• ~~~ surface 2,250'- 2,397' ~ ' ~ ~ '~ ~ ~ ~' ~ . ~ FO Collar at 2,397' ~ ~ ~ 9-5/8" -13-3/8" annulus cemented w/ 40 sx ; .~;~ ~ ;~ = ~ ( 2,250' - 2,397') EZ drill BP at 3,000' with 300' cement on top No mud wt data Cement Top 10,270' behind 9-5/8" casing 9-5/8" casing at 11,270', cemented with 650 sx class G 100 sx class G cement plug from 11,170' - 11370' across 9-5/8" casing shoe and 8-1/2" open hole Total Depth 13,171' Well schematic was prepared by Fairweather E& P Services, Inc. Last updated May-2009 ~ ~ ' . . ~. ~ - ' . - .~ ' ~ ' :4A1..~ • :~s I,N.f1~f- ~ ~ ~ ' ~ ~ . . 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'v Y r u ~~ ~1~+ ~ A: Y 'S, + . ~i, ~i . ~~. ~ ~~ _ _ ~`~,„ ~ ~~,^ ~, ~, ~ ~ :.~ ~;~;~~ 3. .i `;;~`(~`rrt ~ ~ ~" ~ !~` r h `~j,~ `~';~ r~ ~~1 A +,d'' * ~~~i R .y~ ~ ~ ~i~y, ,y ~ '~ ~ : ~+ ~ ~j" , w ,~ ~ +~i 'f t ~3 ~~ ~+ ~ ~ y~~1'- ~ ~ ~` ` . ~ ;!~ a ~' ~`.x ~~,~,~,C' „~ ~ ~~ ~ •~ ~~ f ' S _ ~ ~ - ~ .~... . ~~ Yh ~ +d~' 'W4 ~ ~ IYr~`~_~Vt''~~~_~' . ~VYfsd'.~~sJ ~S~~~J~~ J~~~~l 1~'3tr_! ~.~m ~ ~ {~~~d ~T~~'?!, 1~C?1.~. f ~~~:~"~G3P•~~;;'s:~~:: , sJi~ll. ~fl~ ~~a~s, ~li3or~:~a~, :~?ar~~ ~`!, ?~fl9 ~: t? ?~~; ~'~e U~~ar~der, ~~or~a~ ~ (~~~; ~a~bj~c~e ~~: A~~G~ ~~~d~-y ~4cs~ic~ ~2~~,~~.s ~~y ~~~~:^~~i~~c~~ r9~lc; ~~n~~svg~.4~s Tom, the -reports for the 9 well inspection/remediation wor;~ at Point Thomson left my office this afternoon. Thanks for your patience, I''m now 1oo:cing ior contractors to ~id 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 ~aork> please call. Regards, Jack Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, May 28, 2009 7:18 AM To: jack.a.rickner~e~oconmobil.com Subject: RE: AOGCC Sundry No~ce Reports for Completed Field 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 mint~te crunch. c;all or message with any ctetails. 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.com] 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 blessinq. 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 permitting, contractinq, and procedure development (including which type of equipment to drill through the bridge plugs) 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 ca11. Regards, Jack Jack A. Rickner Pt. Thomson We11 Inspection & Remediatior Project 907-564-3783 281-217-4350 _ w.i ~i ; _ ~i`j n / IlAaunclec, Thorv~as E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, May 11, 2009 8:18 AM To: fVatasha Sachivichik Cc: jack.a.rickner@exxonmobil.com; Bill Penrose Subject: RE: PTU well inspection project AOGCC report status Thanks Natasha. That schedule should work. Tom 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 Subject: RE: PTU we!! inspection project AOGCC report status Tom, Sorry for delayed reply. We should have the reports ready by the end of this week or beginning of the next w~eek the latest. Thanks and regards, Natas~na Sach%v%cl~i,{2 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 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] 5~::#: T!~urs~+a`~,'"'~`~ ^7, 2009 11:±4 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 ~ :~~~; . .~~~ ~ Tarra, I am writing in regards to the yesterday's phone conversation between you and Bill Penrose about the status of the Sundry reports for 9 wells inspection and remediation project performed by ExxonMobil. The fleld operations completed on April-29-2009. I would like to confirm that we are aware of the 30 days requirement to submit the reports 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, Natasl~a sach%v~ch~l~ 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 Il~auncie~, T'huoaa~as E (DOA) Frorra: Maunder, Thomas E (DOA) Sent: Monday, March 23, 2009 10:14 AM To: jack.a.rickner@exxonmobil.com Cc: michael.d.murrey@exxonmobii.com; rob.g.dragnich@exxonmobil.com; mike.barker@exxonmobil.com Subjec#: 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.rickner@exxonmobil.com~ Sent: Sunday, March 22, 2009 4:33 PM To: Maunder, Thomas E (DOA) Cc: michael.d.murrey~exxonmobil.com; rob.g.dragnichCexxonmobil.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 position), 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. We could instali ~he new gate valve (leic in closed posi~ion>, flange, with 1/2'~ needle valve and a plug. After ob~aining 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.rickner~exxonmobil.com Subject RE: Wellhead Inspection Program Hi Jack, 2 am in for a bit today. My preference would not to have valves buried however l do realize there is also a risJc about surface as well. What are your thoughts? Tom -----Original Message----- From: jack.a.ricknerCexxonmobil.com [mailto:jack.a.ricknerCexxonmobil.com) "Maunder, 2 Sent: Sa~urda_y; ~arch 21, 2009 3:41 Pi~ To: Maunder, Thomas E (DOA) Subject: T~ellhead Inspection 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 i~.[,.~ ~..~,_~ _ ...z-.. ~°~°° ~ ~ " ~ ~ ~ ~ ~ ~ ~.~; ~ ~~ ~- ~ AL~SSA ~u A1~TD G~5 CO1~T-SER`rATIOAT COMl-IISSIOI~T Craig Haymes Alaska Production Manager E~onMobil Production Company PO Box 196601 Anchorage AK 99519-6601 Re: E~cploration Well, West Staines St. #2 Sundry Number: 309-080 Dear Mr. Haymes: SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, 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 submitted with the application the status of this well accord3ng to the official AOGCC records is P&A., although as the Commission pointed out in previous correspondence this is one of several wells so classified that appear nat to meet all of the applicable regulatory requirements for plugged and abandoned wells. We appreciate your inspection efforts as described in the application. When providing notice for a representative of the Com.mission to witness any required test, contact the Cominission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Comrnission grants for good cause shown, a person affected by it may file with the Comrnission an applicatian for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Gom.mission decision to Superior Court unle~s rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair DATED thisl? day of March, 2009 Encl. ~ , ~l~ ~p~ ~,,~b ~' ~l~j ~ STATE OF ALASKA ~~~~~~~~ ~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSIO~I c~ 6 2Oflg APPLICATION FOR SUNDRY APPROVAL~ ~~~s 2o aac 2s.2so NIi.nIi7 n~- R Gas ~on~. Commission 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Pertorate ^ ~n~h~;~&ver ^ ~ Other Q Alter casing ~ Repair well ~ Plug Perforations ^ Stimulate ^ Time Extension ~ Site Inspection Change approved program ~ Pull Tubing ~ PerForate New Pool ~ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ExuonMobil Oil Corporation Development ~ Exploratory ~ 175-002 ~ 3. Address: Stratigraphic ~ Service ~ 6. API Number: PO Box 196601 Anchorage, AK 99519-6601 50-089-20004~ 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: N/A Spacing Exception Required? Yes ^ No ^ West Staines State #2 ~ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 28377 - 95 ~ Wildcat 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effectiye Depth TVD (ft): Plugs (measured): Junk (measured): 13,171 , 13,170 . Surface Surface See Attached None Casing Length Size MD ND Burst Collapse Structural 74' 30" 74' 74' N/A N/A Conductor 767' 20" 787 787 1530 520 Surface 2,255' 13 3/8" 2,275' 2275 5380 2670 Production 11,250' 9 5/8" 11,270' 11269 8150/7510 7100/5600 Perforation Depth MD (ft): PerForation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NIA N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft): NIA N/A 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. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Barker / Jack Rickner Printed Name Craig A. H es Title Alaska Production Manager Signature Phone (907) 5643617/(907) 564-3783 Date c .,P^." COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `'~~ -O~~ Plug Integrity ~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: 2'~~11~ 'V`~~C~~~~~9.V 8-~~~~-'~C~~~yl.,~v~ ~~1~~Ip ~C~Q' d ~ C~To ~ C C Subsequent Form Required: ` ~ ~ ~~ ~~•Q`~~o ~ ~ -~~~5 .~.~~~~ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ~/( 7 v ~ . , ~~ ~_ _ ~~. €~~;~ ~ ~_ `r.~~Je Form 10-403 Revised 06/2006 Submit in Duplicate ExxonMobil Production Company P. O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimile February 25, 2009 Mr. Dan Seamount Chairman Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Application to Inspect ExxonMobil Oil Corparation West Staines State #2 PTD No. 175-002 Dear Commissioner Seamount: Craig A. Haymes Alaska Production Manag ~~ ~ ~~~ ~ Jt.lnterest U.S. ~~~ ~ ~ 2~~~ Alaska (Jil & Gas Cans. Commi~ior~ E~~o n M o b i I a~~~~rage Production ExxonMobii Oil Corporation hereby submits an Application for Sundry Approval to perform a surface inspection fior additional remediation work including 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 the 9-5/8 x 13-3/8" annulus. The inspection w+~rk will be performed during the winter of 2008-09 to provide information that will be used in detailed planning for remo~ing of well fluids and the wellhead during the vwinter of 2009-10. Please find enclosed the following information: 1) Form 10-403 Application for Sundry Approval 2) WeHbore Schematic 3) Inspection Procedure 4) Photo of the Wellhead/Abandonment Marker at Present If you have any questions or require additional information, please contact Mike Barker at 564-36~7 or Jack Rickner at 564-3783. Sincerely, ~GL ~ CAH:eaa Attaehments A Division of Exxon Mobil Corporation ExxonMobil Oil Corporation West Staines St. #2 Well Schematic API #: 50089200040000 APTD #: 175-002 Wellhead A& B sections in place with blind flange on top with marker post 9-5/8" EZ Drill BP at 150' with Arctic cement on top to surface Arctic Pack in 9-5/8" x 13-3/8" annulus at 2,223' to surface Diesel ~~ . °.~ 20" @ 78T Diesel in 9-5/8" casing at 2,279' - 150' Base Permafrost 2,050' 50 sx Arctic cement plug inside 9-5/8" casing at 2,279' - 2,397' EZ drill BP at 3,000' with 40 sx cement plug on top to -2,888' 100 sx class G cement plug from 11,170' - 11370' across 9-5/8" casing shoe and 8-1/2" open hole Total Depth 13,171' No mud wt data FO Collar at 2,223' in 9-5/8" casing 13-3/8" casing at 2,275' cement to surface 40 sx Arctic cement plug outside 9-5/8" casing at 2,250' - 2,397' FO Collar at 2,397' in 9-5/9" casing Cement Top 10,270' behind 9-5/8" casing 9-5/8" casing at 11,270', cemented with 650 sx class G Well schematic drawn June 29th, 2007 by Jesse Mohrbacher, Fairweather E& P Services, Inc. Updated by N.Sachivichik & M.Murrey Feb-24, 2009 ExxonMobil Oil Corporation West Staines St. #2 API #: 50-089-20004 APTD #: 175-002 Inspection Procedure Backqround Well Information The West Staines St. #2 well was drilled in 1975. 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 cement plug set at 0'-150' on top of a bridge plug. Below the bridge plug there is diesel from 150' to 1,573'; another cement plug is located below from 1,573'to 2,397' across a ported collar (at 2,223'). The 9-5/8" x 13-3/8" annulus contains arctic pack from surface to approximately 1,506' and a cement plug at 1,506' - 2,223'. The well schematic is attached to this procedure. The reservoir section of the well is effectively plugged; 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 St # 2 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 & 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. 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R ~C ~a ~'. 7i '~'7 c. n, ~',~ wc .f ~ .! y ~j4~ ~~, '[~'~ ,1. •~v'~~I'.~ K' .~k .1'.ti> .'( 1' ~'! ?; ~ .,s. ~.:~ a r ~ ~>, . ~!• ,~ , k ,.l~r. 'h , ,t';, . :~ • 3F y °~`•~. : ~iy~ .~.at~, . . . , .. ~i _s. • i},J~~. : ~i4 r. , ~ . 5! n" , w•' . . ' c ~ 7 . . • w~ .. , e , .. . ~: . . ; ; ~. 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 Re: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut -In Well Information Dear Mr. Pecor: 1"1-51C)Z_G SARAH PALIN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 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 orjim.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 3 U.S. Postal Service,. CERTIFIED MAIL. RECEIPT ' (Domestic Mail Only; No Insurance Coverage Provided) For delivery information visit our website at v;ww.usps.com • rLi Poetmp Qwdllled Fee E3 1 i /' 1HM D. CO t 1 i 01/30/2009 C3 �Mars— William - • C3 ExxonMob'l Production Co. xm orpoawNa PO Box199610 Anchorage + • • 519-6601 C, •ij°" ns iuctionti i K Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. /A• Signa e \X—� K Print your name and address on the reverse � so that we can return the card to you. a Attach this card to the back of the mailpiece, or on the front if space permits.- M,.eyZedV-,j,,n,10d Name) C D. Is delivery ad ss different from item 1 If YES, enter delivery address below: 1. Article Addressed to: William Pecor ExxoiiMobil Production Co. PO Box 199610 Anchorage AK 99519-6601 ❑ Agent ❑ Addressee de of pelivery ❑ Net ❑ No 3. Service Type Certified Mail ❑ Express Mail ❑ Registered )Oeturn Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 2. Article Number (Transfer from service label) 7005 1520 0001 2499 5975 PS Form 3811, February 2004 Domestic Return Receipt 102595-02-M-1540 Operator Suspended and Shut In WeHis PENNZOIL CO Field Current Date of PermitAPI Number Well Name Status Status Surface Location .................................................... Lease(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 Wednesriny, Jim6nq)14, 2009 Operator Suspended and Shut IIn X11! MOBIL OIL CORP Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... KUPARUK RIVER 181-035-0 50-029-20573-00-00 KUPARUK 28243 1 SUSP 5/29/1981 470 FSL 605 FWL Sec 17 T 11 N R 11 E UM ADL0028243 Wednesday, January l4, 2009 ExxonMobil Pt. Thomson Heritage Wells Identified May 18, 2007 in Commission Letter to Craig Haymes API WELL PTD # Uper Marne Well Name Field Sec Twp N/S Rng W/E PM Lease(s) 50-089-20001- MOBIL OIL W STAINES PT I I � i j 00-00 1691200 CORP ST 18-09-23 THOMSON 18 9 N 23 ' E U ADL 0028380 50-089-20004- 11750020 MOBIL OIL W STAINES `EXPLORAT j ! i i 00-00 CORP ST 2 CRY 25 9 j N ! 22 � E i U ADL 002837 PT 50-089-20005- EXXON THOMSON PT 00-00 1760850 CORP UNIT 1 THOMSON 32 10 N { 23 E ; U i ADL 0047560 PT _._.._ . - 50-089-20006- 00-00 1770640 EXXON CORP THOMSON UNIT 2 PT THOMSON 3 + I 9 N 22 ! E ! U ! ADL 0047567 3 PT 50-089-20007- 00-00 50-089-20008- 1780050 EXXON CORP MOBIL OIL THOMSON UNIT 3 STAINES PT THOMSON PT 34 10 j N 23 i E U j ADL 0047558, ADL 0047559 4 ( 00-00 1790010 CORP RIV ST 1 THOMSON 171 9 N i 24 E U ADL 0047573 PT __.._........ _............... i _.. _ _... 50-089-20009- EXXON THOMSON PT ( 3 00-00 1790800 CORP UNIT 4 THOMSON^ j 32 10 j N 22 I E j U ADL 0047563 50-089-20011- EXXON ALASKA ST PT 00-00 1800460 CORP C1 THOMSON' 14 9 N 23 E U i ADL 0028382 _ 50 179-20007- EXXON ALASKA ST PT i i 00-00 1830450 CORP 11 THOMSON 2 6 i N 22 E U I ADL 0344033 1__._...__ ____ -1 20 AAC 25.110. ;_usuended vvetls (a) If allowed under 20 AAC 21�.1(!�, the commission will, 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 Appro%,als is submitted after be;innin" ��orl: 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(4) 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 ExxonMobil Prorltuction Cam 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: /791f ala Crai .ayrnes / O Q . oyb Alaska Production Manager Joint Interest U.S. 1'7& o Y5 i-7-7, obLl If 0 561) /79• E�onMobil yti Production /�ycJ /aGO /75. oar RECEIVED MAR I � an Alaska Oil & Gas Cions, Comrnbft 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 Aw, o A Division of Exxon Mobil Corporation SARAH PALIN, GOVERNOR ALASKA OIL AND GAS 1 333 W 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, 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: 1. 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. 2. 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. 3. 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, orlessee. If you have any questions, please call me at 793-1221 or Tom Maunder, PE at 793-1250. Sincerely, �� Cathy . 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 7`h Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Pt. Thomson Wells — Plugging and Abandonment Dear Chairman Norman: Craig Alaska Production Manager Joint Interest U.S. EWonMobil Production RECEIVED NOV 1412007 Alaska Oil & Gas Cohs. 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 0 .40* Point Thomson Unit No. 2 Point Thomson Unit No. 2 t C '•fit 1. .. - • ••• � �' J�l��,�-i ,t, ' ,fes ylf±� �, Aa :> '♦ '� • , ,,� t«'. 1` ^ t , n :If •y A -A } . x ��! .f ;' + ♦� °.-� rp,�, itis n 'y A�--�{�` (jai• ?? Point Thomson Unit No. 2 Point Thomson Unit No. 3 Point Thomson Unit No. 3 4r t t, •K a ,.�`�ir�����-'�1��r['� 3`nr� s,�► .t r -' psi /.s,, Ni r w ti � lr;.� � ��� fry,./ -/ �tj*•',_ ,i� Ir 1 �s ,r".4,y4ru 1 � 1 vx is V \ w 1 Via. l: • ��{�y'��.. :bT try �.� �r ' �� } � �` }i 'f i r r + - . a • � S r y v'' iyj- �o}..,�„'��. fi r1 � " ,,,, � }' �� v''� ��r x: Y ; f', f r' tY Qi �rf Point Thomson Unit No. 4 Point Thomson Unit No. 4 .�t��,.,.�� }lk������ ,tar�f•�p.�c�s ^n bt�t'{ t».•�"' �G�� -moi t #� ? - ..n ' .:.rf� r ' •-p t' r$ iY-r/ ' .Ya tf„y% V.d« , ✓ 3 Y":,�'.' 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It �,vr ,j6.•ify s f ti L �7 :y, ''4'Csr"r �^'4 !!J �.y �y o. ��+Or, �, � �la,�..- .r g �,i.... s .�'`a��.,♦ly.•�. ,,,4�C Staines River State #1 Staines River State #1 r„ "� y �^ � •�r r • O^ x ♦ = tt�� H:� - :�5. "l� lam, � ��tyg^;,�' �" "� � i `jl �T ` 'Werk w�'F1 '� � ,/� r'•'t". r � a 'r- �. _Y - •l i�r,•r. 1 � .. - �,,,, , x, r ' - 1 w.� r.. : _ �- e ; . � .. �� ^ :.yam. .r. lic T ; i a � .. 1 1 � N`.'� ,� y; v _ � ', M _ � .. - �1 "� �.0 rem r'�. _- \ � _" N � �� -�• ea . .. � _ ._ 1 ._j e .�. z ,. t t '� .-�� ,�` .��, C �' C 1; �� m e lsr.� iyt.� tF w� t T ja x t i� > � ,t. � � n{? � . t � � >,� '+.� t t h �s l i %y �� �: ,.h . ,� '�� . � � r b �., s .�� ,, � "Ra .Y .Ki y, t. �. .� ,0 _ -. `_ . _ ^ *•a Y 14 ear/ J° ' � `, J ., tJ. of o. . ♦ , West Staines State #2 West Staines State #2 r ` •Isyr4" � �W . �; � • t ..t \ . t "_ _sy '+.� ..ayE. • . �i.: .' . �NS4 .. "S � tiat71� 'r. ice► � � �' i'nt' is - �`� ...+•+p��� ^:k y._Y�J'. � wi�t� .. .!ti•. P�AdL '�i:At �5 _, J F`_a' .ML ;r v;. 'fit•' . Alaska State J-1 Alaska State J-1 7771" ;.moi '."ht';�.^ '`� �'.�;�"yM".{�-'+• �-' ����aV4a.-M A .is f .r fi. ';moi w�'��'pY' pYF'a °� ��`'' �• ,�,%, i•�' �� . �` } Y. 1 . �*��'� hk � �t � ,•. r�.`'}'4,� p°` .moi' �� r,,�',y `�" �.;: ^� �x' 3�•� ��r 7 AW ` ;; �SOL ;.moi '."ht';�.^ '`� �'.�;�"yM".{�-'+• �-' ����aV4a.-M A .is f .r fi. ';moi w�'��'pY' pYF'a °� ��`'' �• ,�,%, i•�' �� . �` } Y. 1 . �*��'� hk � �t � ,•. r�.`'}'4,� p°` .moi' �� r,,�',y `�" �.;: ^� �x' 3�•� ��r 7 AW ` ;; ~ " .~ ~ 3 ,~ :~,~!i~ ^'CP;SSE~~G4' ~'~i.?! ~Ce°~i~C3t~i'r:< ~~asK~ ~~~ ~~~ ~a~ ~~r~~~rv~~~~~ ~~~~;ss~~r ~33 ~liLs~ ~~n ~~,~~~^~e, S~s~e 7 0~ ~~s~~orage, l~~as~c~ 995~3~ ~353~ R~: ~fi.. ~f?os~s~r~ `if~'~IAs - ~I~ggir~g a~~ad ~~a~do~a~aer~f ~ear Comr~issioner Sea~nounf: . ~~~i~~~~~~~~~~~~0 ~~~C~ r :~4~.,,~i'":~~~~~} ~%.~ ~ ~; '1.0~1~ ~~.~;~~ ~I i~ C,~~~ ~~r~~, ~~,r~r~' ~ t; . ~~hor~~~ ir~ respor~se #o ~he ~ommission's December 7; 2007, letter to ExxonMobil, attached are sundry notices requesting the Staines 1~iver State i~o. 1; Alaska State C~~ , and Point Thomson lJnit iVo.'s 1, 2, and 3 wells be reclassified from abandor~ed to suspended status. Site inspection sundry ~otices, Form 10-404 reports and photos, are also attached for tMese five wells and the Ps~int Thomson No. 4, Alaska State J-1,1/Vest Staines d~o 18-9-2~, and West Staines IVo. 2 wellsa We a~-e making plans to conduct the inspectior~ and remediation work described in ExxonMobil's letter of fVovember 14, 2007, and the Commission's December 7 letter dur~ng the winter of 2008-`09. As you know, we submitted a~Plan of Development for P3U 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 iVovember 14 letter in corjunction with that drilling pian. We share the Commissiora's desire to conduct the remediation work in a timely and dat~ certain manr~er, but vve would like the oppo~iunity fio revisifi the timing ofi the remediai work if the drilling program does not proceed as currently planned. 1Ne believe there are operational safety and efficiency facfors that should be considered. ~iease ~ote #he Staimes Ftiver State #1 well is under extended confidentiality as provided ~ander AS 31 a05_035(d) and 2~ AAC 25~537(~i). We have incf~ded its re~ort as ~ separate, ~onfidential attachmenf. V`,le agai~ thank the Commissiora fior ~roviding clarity around the iss~es and for providing adequaze tir~e for ~xxon~Vdo~ii to coraauct a thorough as~d #houghtfiul review~ ~'fease fieel ~ree fi~ contacr me, ~ill Pecor, or ~o~ "~ragnich if you i~av~ ar~~ ~uestia~?s. ~incer~iy,_~~ .;~= ` .~~. ~ _-~~:. ~ ~~Aa ;~-ar~3e~~s ~ ~~. ~~~,q~c'rva~~?~, ~u~~o~c~~i~~i;~~ ,,;;~/'+v v~~ 1/~ 9a ~~ ~ ~~, ~ ,,.V.I .~ ~11~A.~i3~._ ~O6~v~1r V1... ~~C'~v tv i • STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMN~ION MAR 1 8 2008 REPORT OF SUNDRY WELL OPERATIONS q~~a Qii & Gas Cons. Commisswn 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ection ~ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time Extension ~ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well [] 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: ~~ ~_ uQ Name: E~cxonMobil Production Company Development ^ Exploratory^~ 75-0002 - 3. Address: PO Box 196601 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6601 50-089-20004 ' 7. KB Elevation (ft): 9. Well Name and Number: 95 " West Staines State No. 2' 8. Property Designation: 10. Field/Pool(s): ADL 28377 ° Wildcat 11. Present Well Condition Summary: Total Depth measured 13171 ' feet Plugs (measured) See Attached true vertical 13170 . feet Junk (measured) None Effective Depth measured Surface feet true vertical Surface feet Casing Length Size MD TVD Burst Collapse Structural Unknown 30" Unknown Unknown N/A N/A Conductor 767' 20" 787' 787" 1530 520 Surface 2255 13 3/8" 2275' 2275' S380 2670 Intermediate Production 11250' 9 5/8" 11270' 11269' 8150 / 7510 7100 / 5600 Liner 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 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 Q~ 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: ~o SV~ ~ Contact William C. Pecor, 907-564-3766 Printed Name William C. Pecor Title Point Thomson Coordinator Signature ~.t.*~,s C:.. ~~~ Phone (907) 564-3766 Date 3 ,D8 ~ r.,! ~ Form 10-404 Revised 04/2006 Submit Original Only t.L `^: . ~. ; ~ ~'~._ ,~.:~z ~ ~~ 2~09 ~3~~, ;.~~ ~ ~ ExuonMobil Oil Corporation West Staines St. #2 Well Schematic API #: 50089200040000 APTD #: 175-002 Wellhead A section in piace with blind flange and mark post on toK BP in 9-5/8" casing at 150' with cement on top to surface Arctic Pack in 9-5/8" x 13-3/8" annulus at 2,223' to surface Diesel ~'//~ ~ _~ 20" (a~ 78T Diesel in 9-5/8" casing at 2,250' - 150' Base Permafrost 2,050' 50 sx plug in 9-5/8" casing at 2,397' EZ drill BP at 3,000' with 300' cement on top 100 sx class G cement plug from 11,170' -11370' across 9-5/8" casing shoe and 8-1/2" open hole Total Depth 13,171' No mud ~ data FO Collar at 2,223' in 9-5/8" casing 13-3/8" casing at 2,275' cement to surface FO Collar at 2,397' in 9-5/8" casing Cement Top 10,270' behind 9-5/8" casing 9-5/8" casing at 11,270', cemented with 650 sx class G Well schematic drawn June 29`", 2007 by Jesse Mohrbacher, Fairweather E& P Services, Inc. West Staines State #2 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 appreciable amount of vegetation growing on it. The pad around the wellhead had been mounded up five feet above the surrounding area and the wellheads protruded about three feet above that. The mound around the wellhead had a significant amount of vegetation growing on it. There were bull plugs with needle valves on the side outlets and top flange of the wellhead; there were no plugs in the needle valves. There was some wooden piling protruding above pad level but little other debris. There were also two steel piling off the pad. There is a large "pond" adjacent to the pad. There were no signs of drilling mud in the pond and the water appeared clear. West Staines State #2 -1- ~x~A ' ' R • ~r ~ ~'f ~ -~ +: Y: _ „~~ _ ~~~-4:.F. ,~;~r ~ ~~..~. ~ ~,, .~~~, ~. [Y::~~•' 'i.. > ;~ ,... Yi ~ ~i. ~ ;~ _ y :~E.~^~'~~: ~.~~:^~i~~ ~ ~ •~F.. ' `i~E-. . h ~ ~ . s r,~ ~;•. ~ ~-.~~~! ~ ~ -~h ~ ~ ~'s~ i „ d.~n ,~, ~e'~ w ~.. tr•. ti y ~ ri{S„` `.,,,;~:"~ ., ;, ;, ~. iy,,Fri,~•.:,~;: . T .~r -~~. ~, °~ ~ 4. .. ., ., n .n ~1~ . ~ (1: . ~ _ ~` `v .S. .. .3~ ~ 1 4 ~ ~ ~~~~ ~~ !it ~~ ~' :-; ''.p{,-~.~ ~' ~ ~ ~ ~+ ~~ . y . ~ ~ ~ ~+~~ . - , .., , •:h' . ~ . ~ _ . .'~ • ~~.t~, >• ~ .. ~.. . .~. .. ~y. ~ . . ~ -2- ~ y' ,~~ya: ~_ .?~~ West Staines State #2 West Staines State #2 , _.~. ~- :f.,,,,,,,,nn....~..+, . - ~'~`~„ a.,..r". x~..,~ _ ;rt"-"~'~' .-..~'~"•"`'~.:;re.. .~,~ _ _ '~ . .. . :_;.,,,,~~.. - + - -. ,., " ., h - _ . 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Yy~, ,~ ',~ A.~~' '.h't ~~1' T•.~`. (~ t ~' 1 i ~1' ~ ~ 4 ~. .v _. ' ~ t ~ 1~ ~M /~. `. t .,4~7M~ r~!'~..ft Al/..` -3- West Staines State #2 West Staines State #2 _. ~ ! . . c-~ --.s tt,~~, ~.~::t~~~ ~_ ~i.,'`r,`_t iJ.iv.~i ~.; t'=~~~ Y(~ ~ ~;°~ ~ ~~ ~~~ ~ _; ~ ~' ~s ~~~ '~'~I'~ r~''~7 T' ~'j `, ` i ; a( '"` ~ ~ ~"~ <: j. ~ . •~,.~~s...~a ~~.~.~_.s i~~.l~ ~ L ~_.~~~ ,,~s~ .~'.! ~.°. 7'~ ~~, _,:._ ~ ` !3°, ;.~p~ ~.`3S~i~ i~~'~~LlC_ii 1, ~(1Pa~Pr ~ =~n:~~J~l'~.'~Ovi~ `.'~rJdL1CCtOt? ~Oi7i~aP1'~% ~v ~{Jx I y+~JEJ~ i ~nct?orage, :~1~ 99~ 19 Re: i t. Thomson `th,%~?[s - Pl~gging and Abandonment I~ear ~~/I_r. Hay~mes. 3~3 J,; ' r A` ~y,JE Si , ?IY~. (J~ „ _ F;,AS,:a 79:~ ~~~- ~-Oi~E ~ . 2'?-' _~ ~-~a~ ~ _ ~ , _ This is in iesponse to your letter of :ilovember l4, 2007 responding to the Alaska Oil anci Gas Cons~rvation Commission's ("Commission") (etter of May I 8, 2407 regarding the condition of certain Pt. Thomson Unit well~. The schedule and plan for remedia! work provided with your letter are acceptab(e subjecz to the fo(lo~~~ing conditions: 1, £xxonlVlobil will perform che proposed Feld u~ork for the 2008 - 2009 winter operating season regardless of whether there are any concurrent drilling operations in the Pt. Thomson Unit. 2. AI! of the diesel will be removed from the Vv'. Staines State #18-9-23 (169-120) and ~V'. Staines State #2 (175-002) u~ells. If any of the dieset 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. 3. 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 requi;ement is timely and ot~en~~ise properly requested a~d 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 (ast summer. and location photos. F:na(lv, nothing above e~cpressly or imp(icitly evidences the Commission's position with respect to the status of ~:~on~tobil or an~ other persor~ as a current Pt. Thomson Unit operator, working interest o~vner, or lessee. ~r you have an,, qu~stions. please call me at 7~3- ? Z21 or Tom ~~aunder, P~ at 793-1 z~~. ~incereld, ~~~~ ~~~ ~ o / c~-?~~ ~ ; /~'~~.~_ iathv ~~ ~=oerster ~ornrnission~~ ~~acoeaPAaba~ tPv~duc~uon Coenpa~n~ F 0. Box 196601 Anchorage Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimile ~P~A~ ~a G~~~647~5 Alaska Production Nlanager Joint interest U.S. ~ ~;~x ~"~~'~ ~ ~~ ~~oc~~~c~-~oa~ November 14, 2007 Chairman John (Vorman Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Pt. Thomson Wells - Piugging and Abandonment Dear Chairman Norman: We are providing this letter in response to the Commission's May 18, 2007, letter to ExxonMobil regarding Point Thomson area wefls 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 wil! 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 unders~a~iu ii-~at re~~ass~f~ca;;~r ~vi!! c~r~~ ?n ~~!ig~tion to abandon the wells in the future in compliance with regulatory requirements. A Division of Exxoae PAobil Corporatioae ~9v~ ~ _~~ li ~ Commissioner John Norman - 2- November 14, 2007 Please note the plan calis for conducting the most intensive phase of field work in conjunction ~nrith 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 ExxonMobilp 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 regarrat~ill addre s'these matte sson the wells'ptan ed forrneare-term em). The planned work prog remedia! 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 deepa r es oh devi t ons~from cureenteegulations Sn our sundry not ces fi ed with the address any var Commission. We appreciate the Commission's help in providing clarity around the issues and allowing adequate time for ExxonMobil ~oceed w h therout~l ned woh k plansl r Please eellf ee to co t ct y o u r c o n c u r r e n c e s o w e c a n p me, Bill Pecor at 564-3766, or Rob Dragnich at 564-3711 if you have any ques tion s. Sincerely, ;~ ~ ,; ~ , `' ~li ~ % CA :rgd/jpc Attachments xc: Cmmissioner Cathy Foerster - AOGCC Commissioner Daniel T. Seamount - AOGCC Kevin Brown, BP Mark Ireland, ConocoPhillips Vince LeMieux, Chevron ~~~~~ ~ ~~~4y,~~ Remediai Action Program Point Thomson Welis - Plugging and Abandonment Wells Affectecl Actions _ . Timin #2, PTU #3,_ - PTU #1, PTU 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 tl~iver 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 ~---p- - Remove near-surface arctic pack from 2 annuli and ,~o ~~~~` 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 dritling planned for winter of 2008-09 ground level - Verify integrity of surface plug 15 lace as necessary po55~b~ + Re air or re ~~ c~~esE~ ~ p p - 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. Stair~es 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 ~-~r~~`~~ + Repair or replace as necessary - Remove near-surface arctic pack from annulus and ~~5~~ set cement plug in annulus using top job techniques ' ~~ (plug to be at least 50 long) . a~~' - Install marker plate ~ ~ - Remove cellar - Conduct general location cleanup, and request finat 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~~~S~ \ ground level drilling planned for winter of 2008-09 - Verify integrity of surface plug ~p ~~ + Repair or replace as necessary b~~'-'~ - Install marker plate U~ ~' - 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 (~iver State #1 - File sundry notice to change well classification from - Submit 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 winter 2008-09 inspections Alaska State C-1 - File sundry notice to change well classification from - SubrrEit 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 winter 2008-09 inspections -3- ALASKA OIL AND GAS CONSERQAIMON COMMSSION August 14, 2007 Craig Haymes Alaska Production Manager ExxonMobil Production Company PO Box 196601 Anchorage, AK 99519 5NEU Re: Pt. Thomson Wells — Plugging and Abandonment Dear Mr. Haymes, SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279.1433 FAX (907) 276-7542 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 Twil Maunder, PE at 793-1250. ~ ~ .~~ ^J J^~ .~, %~ ~~'_~J ~ ~ ~1~~~/ i~, ~~~~ ~omrriissioner ~afihy Foe~ster Alaska Oil and ~as Conservatior~ ~ommission 333 West 7`h Avenue, Suite 100 Anchorage, ,4laska 99501-3539 Re: Point Thomson Wells - Plugging and Abandonment Dear Commissioner Foerster: ~, ~~ ~ ~~ ~ ~~~~ ~~ ~ { .i i-~~1~~1 '~ _~> 1, ~'; ~ -, '~ , ~ ~ ,~ ~.,. ,:~ -~ . -~.~.'. ~ ~ ~~,~, ,~ , ~, ~.~~ ~ ,,,, ~ ~,_ ..~, ~~ J~;~~ :`~~ ~~ab ~~~ We have received the Commission's letter dated May 18, 2007 regarding potential issues related to certain Point Thomson wells that were drilled 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 well 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 fiie frorn 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 question and having any initial assessrnent by the Commission to check against as our work progresses may facilitate an earlier completion. It 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 deter~nine appropriate handiing and response to the Commission. ~ will be out of town until May 31. Please contact Rob Dragnich at 907-574-3711 or Bill Pecor at 713-656-7064 to coordinate any information you are able to provide. Thank you for brir~ging these matters to our attention. ~incerziy yours, r' ~~ ~ .~- ~ ~" ~;jpc ~<;~ A~;gus ~i~i~ik~~', ~~ ~a1~~~1 ,~~4~Jdb, :s~~d~~~f~~8 tll~~~~~t~~~ ~~ ~~ ~~~~~ ~Ia~; 1 ~. Z{)07 ~'rai~ Haymes Alaska Production ~Ianagee- ~xxon!~Iobil Production Company PO Box 196601 ~nchorage, AIC 99~ 19 l~e: Pt. Thomson WeIIs - Plugcing and Abandonment Dear (~1r. Haymes, 333 W. 7thAVEfVUE, SUITE i00 AtVCHORAGE,ALASKA 99501-3539 PPiONE (907) 279-1433 FAX (907) 276-75A2 During our review of the Pt. Thomson Fietd in response to your recent applications for permits to drill, the Alaska Oil and Gas Conservation Commission ("Commission"j identitied the following wells that, according to our records, are classified as plugged and abandoned but do not meet the requirements for plugged and abandoned welIs under 20 AAC 2~.10~ - 20 AAC 2~.172: W. Staines St. 18-9-23 W. Staines St #2 Pt. Thomson # 1 Pt. Thomson #2 Pt. T'homson #3 Pt. Thomson #4 Staines River St # 1 Alaska State C-1 Alaska State J-1 Challenge Island # 1 V/ithin 90 days of receipt of this letter, either provide sufficient information and documentation to demonstrate that these wells meet ail the requirements for plugging and abandonment, or provide a schedule and plan for bringing these wells into compliance. Also, please note that, under AS 31.0~.090, the Commission cannot issue permits to drill to an operator that is in violation of a Commission regulation pertaining to drilling, plugging or abandonment of a we11. The Cammission reserves the right to pursue an Enforcement flct~on according to 20 AAC 25- ~3~. ~ _ ~:.~ '-ia;, n~zs ,~.~1;a~_. I ~_ ~00~ Pa~,e 3 o t ? ~=ina(1~, i~ut~ing abo~~ sh~~tild b~ ~:<~nstruc~d iu e~id~n+:~~ ~~~r~s~lti or impli~itlti the t'ommission"s co~i~i~~ ~~~irh respes;i t~ ~n~ ~~.irrP~t stat~as ~t F;tx:~r~?~to~~l ~c axiy flth~r person as a~t. ~I'h~qns~n un3t c~~~rat~r or l~sse~. $f ~~u ha~~e any quc:sti~~ns, pleas~ f„ali rne at 793-1221. To: Cathy Foerster, Commissioner May 9, 2007 Fr: Tom Maunder, PE Re: Sta.tus of Pt. Thomson Area Wells Introduction: As instructed, an assessment of the wells in the P~ Thomson area was performed. The 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 will only address the ExxonMobil wells. Recommendation: Based on exarnination of the well files, it is my assessment that 5 of the 14 E~onMobil wells are Plugged and Abandoned in ac~ordance with the now current regulations. The remaining 9 wells should be considered Suspended and AOGCC's databases should be changed to reflect this more accurate well status. E~onMobil should be required to perform the work necessary to properly plug and abandon the wells. Discussion,: T'here 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 weli classification and includ~d requirements for removal of the wellhead and casing "... at least 3' below rig grade." In the 11/7/99 amendments, ~lie 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 14 E~onMobil operated wells was completed prior to April 13, 1980 and physical downhole work on 6 of the remaining wells was compieied prior io ~prii ~, 19$n. i ne iasi weli, i~iasica Siaie ~1-2, was pluggea and abandoned in 1Q 2002 according to the 11/7/99 regulations. Regardless of when physical operatians were completed in the legacy wells, 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 insta.llation of abandonment markers. No downhole work was perfarmed 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. Examina.tion of the files for the ExxonMobil wells reveals that, so far as I can detertnine, the wells have been effectively abandoned dovcmhole. 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 ('I") cut and pulled. In a11 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 wells the cut top of the 7" was isolated. Wells generally had a retainer andlor 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 ha.d 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~con 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 stated 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 the 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~onMobil 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 database. 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 lation? Comment Assessed Actual Required Work Suspended P&A 9/30/67 4/13/80 4/2/8b 11/7199 Status W. Staines St 169- 8/13170 5/1/73 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- 9/6/75 ~ 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- 12/8/7? ~ by letter YES NO NO NO No plug above cut 7" at Suspended Remove 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 annutus. 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. St~ines River St 179- 7/21/79 11/5/86 by letter YES YES NO NO Diesel in casing at 140'. Suspended Remove diesel, place #1 confidential) 001 11/86 Not cutoff. lu s, cutoffwellhead Pt. Thomson #4 179• 12/20/80 ~ by l~tter NA YES N0~ N0~ 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 Cutoff wellhead. 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- 5/30/82 ~ 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-a6andoned 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 Cutoffwellhead. 045 11/86 or diesel. Not cutoff. Remove some AP. Alaska State A-2 200- 3/8/02 by NA NA NA YES Plugged and None 141 sun Abandoned N0~-no liquids present. ExxonMobil Production Comp P. O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimile December 19, 2008 Crai~ Haymes Alaska Production Manager Joint Interest U.S. E~onMobil Production Mr. Johnny Aiken North Slope Borough ~~~~~_ J; ~~~~ ~ ~ ~~~ Planning Department P.O. Box 69 Barrow, Alaska 99723 ~ '~~ ._.,, ~ /~~ Re: W. Staines State #2 Conditional Development Permit Application Point Thomson Area Remediation Program North Slope, Alaska Dear Mr. Aiken: Exxon Mobil Corporation proposes to perform inspections and remedial work at nine former exploratory wells and drill sites in the Point Thomson area. The Conditional Development Permit application and following project documentation are attached for the W. Staines State #2 well, which also includes provisions for closure of the existing reserve pit: • Coastal Project Questionnaire including North Slope Borough Title 19 Analysis, • Project Description (including all maps), and • Application fee of $3,000. Additional permit applications or amendments to existing applications/permits will be submitted to the Alaska Department of Natural Resources, Alaska Department of Fish & Game, Alaska Department of Environmental Conservation, Alaska Oil and Gas Conservation Commission, and US Fish & Wildlife Service in January. Please call Rob Dragnich at 907-564-3711 or Mike Barker at 907-564-3716 if you have any questions. Sincerely, k `~ ~~~ CAH/eaa Attachments cc: Bob Blankenburg, ADEC Shawn Stokes, ADEC Steve Schmitz, DNR DOG Gary Schultz, DNR DMLW Nina Brudie, DNR DCOM Patricia Bettis, DNR DMLW Jack Winters, ADFG Tom Maunder, AOGCC Cindy Godsey, EPA Craig Perham, USFWS A Division of Exxon Mobil Corporation -~- Land Management ~ Regulations Permit Application Permit Number Gravel fill for reserve nit closure Applicant Exxon Mobil Corporation Date December 19, 2008 Address P.O. Box 196601 State ID Anchorage, AK 99519-6601 Phone 907-564-3617 West Staines State #2 Well Inspection and Contact Person Mike Barker Project Name Reserve Pit Closure Location (TRS) sss° SNL 50' WEL sec. 2s T9N R22 iJNi Unitized Field Name Zoning District and Pad Location West Staines State #2 Proposed Start Date February 1, 2009 Completion Date: August 31, 2011 nspect we , c ec casing pressures and perform final we reme cation. Proposed Development _ Construction of gravel can for closure of inactive reserve ~Iit. Purpose of Development See attached Project Description. ® Fill/Dredge Material ® Oil and Gas Wells ® Temp. Water Use Number of New Surface Holes: 0 NORTH SLOPE BOROUGH DEPARTMENT OF PLANNING AN DCOMMUNITY SERVICES PERMITTING AND ZONING DIVISION Permit Type Conditional Development Acres 7.98 Source Alaska State C-1 Pit and Lake 17 Equipment All terrain vehicles, trucks. Purpose Water for camp, ice road construction Maximum Amount 1,000,000 gpd All terrain ve 'cles, ro igon, ® Off Road Travel: Period of Travel Feb 1, 2009 -Aug 31, 2011 Equipment stem. aircraft Access to Site All terrain vehicles, aircraft ®Fuel Storage Type Diesel fuel stored in steel tanks Amount X10,000 gal on-mo i e t to ave o secon ary containment capacity per Handling Plan requirements for fuel transfers and handling. ^ Hazardous Type Amount Materials Storage Handling ® Solid Waste Treatment Backhaul to permitted facilities in Prudhoe Bay or incinerate on site. ^ Mining Mining Habitat ® Air Emissions Type Heavy equipment, trucks, heaters, generators pmoimt < 100 tons/yr All terrain vehicles, aircraft, trucks, heavy ® Noise/Vibrations Type equipment Amount <_ 110 dBA ^ Sensitive Habitat Floodplain Shoreline ® Transportation Type All terrain vehicles, aircraft, trucks ^ Marine Tanker Facility ^ Seismic Work ^ Utility Development ^ Recreational Development ^ Causeway Construction ^ Offshore Drilling ^ Residential Development ^ CD-ROM Included ^ Airport or Helicopter Pad ^ Oil Transport System ®Snow Removal i ~ • ATTACH TO THIS APPLICATION THE FOLLOWING: -GENERAL VICINITY MAP -SPECIFIC LOCATION MAP, INCLUDING NEARBY EXISTTING DEVELOPMENT AND NATURAL FEATURES -SITE SPECIFIC FOOTPRINT (IN ESRI SHAPE FILE FORMAT) ON A CD-ROM -A DIGITAL GIS SHAPE FILE OR GEODATABASE OF THE PERMIT AREA WITH NO ATTRIBUTES. THE PROJECT SHOULD BE NAD 1927 ALASKA ALBERS OF GEOGRAPHIC -DESIGN PLANS (PLOT PLAN), ELEVATIONS, CROSS SECTIONS, PROFILES. AS APPROPRIATE -SUPPLEMENTAL INFORMATION, AERIAL PHOTOGRAPHS, STUDIES, ETC. (AS NEEDED) SEND TO:NORTH SLOPE BOORUGH, LAND MANAGEMENT ADMINISTRATOR PO BOX 69 BARROW, ALASKA 99723 PHONE: (907) 852-0320 ---------------------------------------------------- IHEREBY CERTIFY THAT THE FOREGOING IS TRUE AND CORRECT TO THE BEST OF MY KNOWLEDGE Authorized Signature Date Craig A. Haymes Name Alaska Production Manger Title FEE PAID ^ SPECIAL PLANNING COMMISSION MEETING ....$12,000.00 ^ DEVELOPMENT PERMIT... $2,000 + $500 PER WELL ^ ADMINISTRATIVE APPROVALS ...$1500.00 ® CONDITIONAL DEVELOPMENT PERMITS...$3,000.0 AMOUNT PAID $3,000 DECISION ^ ADMINISTRATIVELY APPROVED This is a minor amendment to a development permit or is a use of land listed under administrative approvals for this zoning district. ^ REZONING APPROVED This proposed development substantially complies with the Master Plan, and a use permit is issued, conditioned on compliance with all relevant Master Plan conditions, lease stipulations and provisions of state and federal law and permits served there under. ^ DEVELOPMENT PERMIT APPROVED The proposed development meets all applicable mandatory Policies, represents the Developer's best efforts to implement all relevant best efforts and minimisation policies, and as long as any conditions set forth in the accompanying letter are complied with, will represent a net public benefit. (See accompanying letter) ^ CONDITIONAL DEVELOPMENT PERMIT APPROVED This is a use of land that is listed as a conditional development for this zoning district or has been elevated by the Land Management Administrator to the Planning Commission. ^ PERMIT DENIED (See accompanying letter) Land Management Administrator Date If you wish to appeal this decision, use must submit written notice to the secretary of the Planning Commission prior to the next regularly scheduled meeting, stating the policy or policies in questions and the reason you believe the decision is incorrect. Project Description Point Thomson Area Remediation Program Exxon Mobil Corporation 1. Project Overview and Schedule Exxon Mobil Corporation (ExxonMobil), on behalf of itself and other Point Thomson area lease owners, intends to conduct various inspection and remedial actions at nine different former exploratory well sites in the Point Thomson area beginning during the winter of 2008-09. This project description covers the full range of remedial activities that are being planned although only a portion of the work may be conducted during the winter of 2008-09. The entire program is expected to be completed by August 31, 2011. The timing of specific components will depend upon the status and plans for other activities in the Point Thomson area. A key consideration is the extent to which the Point Thomson Drilling Program, which includes construction of a sea ice road from Prudhoe Bay to the Point Thomson area, proceeds during the winter of 2008-09. For instance, if the drilling program does not proceed as planned during the winter of 2008-09, certain remedial activities that can be conducted more efficiently and safely in conjunction with certain aspects of the drilling program may be deferred to when those activities are conducted. Any work that may be deferred is not time sensitive and deferral would not pose an environmental threat; the locations and wells are stable. A decision on remediation work to conduct this winter will be made following a determination of the drilling program activities that will proceed, development of detailed work plans, and receipt of the necessary permits. The work scope includes 1) conducting inspections of nine former exploration wells as required by Alaska Oil and Gas Conservation Commission regulations for suspended wells, 2) conducting further remedial work on plugged and abandoned wells, and 3) closure of the open reserve pit at the West Staines State #2 well location. Assuming receipt of all required permits and authorizations by January 30, 2009, the work will commence about February 1, 2009, and be completed by April 15, 2009. During the summer of 2009, the locations will be visited by helicopter to allow for further clean-up and inspections. If the sea ice road for the drilling program is not conducted during the 2008-09 winter season, the inspection and remediation work that is conducted during the 2008-09 winter season will be supported by agency-approved off-road vehicles such as steigers, cat trains or rolligons or a combination of all off-road vehicles and conventional vehicles on local ice roads. 2. Permit Requirements This project description provides information necessary to support the applications for permits, authorizations, and coverage under general permits summarized on Table 1 which are required to conduct the desired remediation work. Page 1 of 6 Table 1-Permit Re uirements A enc Re wired Authorizations State of Alaska Department of Natural Alaska Coastal Management Program Consistency Resources (DNR) Determination; expected to operate under following General Concurrence Determinations - GCD-5 Equipment Crossing of Streams - GCD-19 Cross Country Movement of Equipment Winter/Summer - GCD-34 Ice Road and Ice Pat Construction in the NSB - GCD-45 Storage of Materials at Existing Pads in the NSB - GCD-49 Removal of Uncontaminated Gravel Structures • Lease Plan of Operations Amendment* • Land Use Permit for Off Road Travel"* • Land Use Permit for Ice Roads (onshore) • Temporary Water Use Permits** Department of Fish and Title 16/41 Fish Habitat Permit** Game Department of Reserve Pit Closure Plan Environmental Conservation Sec. 401 NPDES Water Quality Certification"* (ADEC) Alaska Oil and Gas Sundry Notice Approvals for well work Conservation Commission AOGCC Borou h/Local • North Slope Borough (NSB) Conditional Development Permits for activity in a Resource Development District without a Master Plan (within PTU) • Develo ment Permits for activities outside PTU United States of America • Environmental Protection Notice of Intent for coverage under NPDES General Permit AKG- Agency 33-0000 for Gravel Pit Dewatering** • Sill Prevention Control and Countermeasure SPCC Plan • US Fish & Wildlife Service Letter of Authorization (LOA) for Incidental Taking of Polar Bears USFWS and Pacific Walrus** * Approval of the lease Plan of Operations is the primary authorization from DNR for conducting well and related operations on a lease. All of the former exploration well operations were conducted under an approved lease Plan of Operations. The status of these Plans of Operations is uncertain and ExxonMobil will work with the DNR/ DOG to determine appropriate authorizations for this work. ** Applications for similar activities were requested for the Point Thomson Drilling Program. Coverage under the existing requests to cover the remediation program will be requested rather than submittal of new applications. 3. Site Access Site access primarily will be accomplished through the use of vehicles traveling on ice roads or off-road vehicles. Helicopter or fixed wing aircraft will also be used depending upon activity for the Point Thomson Drilling Program and the logistical capabilities that are available. Figure 1 Page 2 of 6 • shows the tundra and offshore ice road routes between the Prudhoe Bay area and the Point Thomson area. Figure 2 shows the specific drill site locations and tundra travel or ice road routes within the Point Thomson area. 4. Well Remediation Work There are nine former exploratory wells in the Point Thomson area at which ExxonMobil is planning to perform remedial work. The names of the wells and work being considered are shown on Table 2. Four of these wells have been plugged and abandoned (P&A'd) and five are suspended. All nine wells have wellheads that are partially or completely covered with gravel. ExxonMobil plans to excavate the gravel from around the wellheads, perform visual inspections of the wells, and install pressure gauges to verify there is no internal pressure. This work will be accomplished in the winter of 2008-09 and is not dependent upon the ice road or drilling program activities. Removal of debris and location clean-up will be performed at all sites as necessary. The excavated gravel will be retained on location. For the four P&A'd wells, ExxonMobil plans to remove marker posts, cut and remove casings to at least three feet below natural ground level, and weld marker plates upon the casing stubs to conform to current AOGCC regulations and practices. This will also include removal of some hydrocarbon based fluids from within the wellbores and verifying the integrity of existing cement plugs or placing of new cement plugs. The specific actions to be performed on these wells will be addressed in Sundry Notice requests submitted to the AOGCC. For some wells, it maybe necessary to mobilize a coiled tubing rig or other light duty drilling equipment to the area to conduct well remedial work. Table 2 -Point Thomson Area Wells Well Name Surface Location Well Status Planned Work PTU #1 1,320' NSL 660' WEL Suspended Inspection Sec. 32 T10N R23E UM PTU #2 2,615 NSL 1,801' WEL Suspended Inspection Sec. 3, T9N, R22E, UM PTU #3 660' NSL 711' WEL Suspended Inspection Sec. 34, T10N, R23E, UM Alaska State C-1 660' EWL 660' SNL Suspended Inspection Sec. 14, T9N R23E UM Staines River St. #1 321' NSL 1,658' EWL Suspended Inspection Sec. 17 T9N R24E UM PTU #4 2,700' NSL 2,900' WEL P&A'd Inspection, well remedial work Sec. 32 T10N R22E UM Alaska State J-1 1,886' NSL 2,404' WEL P&A'd Inspection, well remedial work Sec. 23 T6N R22E UM West Staines St. #2 848' SNL 50' WEL P&A'd Inspection, well remedial work, Sec. 25 T9N R22 UM reserve it closure West Staines St. 1,514' SNL 1,730' WEL P&A'd Inspection, well remedial work 18-9-23 Sec. 18 T9N R23E UM Page 3 of 6 • 5. West Staines State #2 Reserve Pit Closure The West Staines State #2 exploratory well site has an open but inactive reserve pit. The closure plan will include filling the pit and installing a gravel cap designed to eliminate ponding of surface water within the reserve pit footprint. An estimated 17,000 cy of fill material is required to fill the pit and construct the cap. It may be possible to obtain these amounts from existing gravel at the West Staines St. #2 pad and West Staines St. 18-9-23 pad approximately 2 miles to the north. Other sources of fill material are being evaluated and may be proposed to the ADEC as part of the closure process. Further details will be provided in the reserve pit closure plan that will be submitted to the ADEC for review and approval. 6. Water Requirements and Sources A temporary Water Use Permit (TWUP) was previously requested to obtain water from the Alaska State C-1 gravel pit. That permit application will be modified to also include additional shallow (non-fish bearing) lakes in the Point Thomson area and the scope will be broadened to address this remediation project. If ice roads are used, water will be hauled using water trucks or tanks on conventional trucks. If off-road vehicles are used, the water will be hauled in tanks placed on the off-road vehicles. 7. Logistical Support The remediation work will be supported by an existing camp at the PTU 3 pad, which was staged to support the Point Thomson Drilling Program and by one or more portable camps that may be transported to each location. These camps will be equipped with potable water storage tanks, gray water treatment plants, electrical generators, fuel storage tanks, and small incinerators. All camps will operate under valid public drinking water supply and environmental health/food services permits issued by the ADEC to the camp operators. Up to 10,000 gallons of fuel will be stored on location and will be re-supplied as needed. Pump houses will be located on the water source lakes and be fitted with ADF&G approved water intake structures. 8. Waste Management Solid, non-burnable wastes will be deposited into containers on site for back-haul to the Prudhoe Bay area for disposal. Any food wastes that could attract wildlife will be incinerated onsite, stored in enclosed containers awaiting periodic hauling, or hauled each day to the PTU 3 staging area. Camp waste waters will be treated and discharged to the tundra by the camp operators in accordance with EPA's NPDES General Permit AKG-33-0000. Page 4 of 6 • 9. Wildlife Issues Wildlife that could be in the area during the winter includes owls, ravens, arctic foxes, polar bears and brown bears. Polar bears are expected to be present in the area and are known to den in the surrounding coastal environment. Brown bears inhabit the general area. It is unlikely they will still be active during the winter season but they may be present beginning in April when they emerge from their dens. LOAs from the USFWS for the incidental take of polar bears and Pacific walrus will be requested, and operations will be conducted in accordance with those authorizations. A Bear- Personnel Encounter Plan which describes procedures to protect bears and personnel and avoid encounters has been prepared. The USFWS will be consulted as appropriate during planning and construction of ice roads and in conducting surveys to identify dens. If a polar bear den is identified, the USFWS will be notified and the transportation route will be altered to maintain at least one mile from bear dens unless otherwise approved by the USFWS. Approval for such changes will be addressed via the Land Use Permits. Project personnel will be instructed not to feed wildlife of any type or in any other way attempt to attract animals and birds either at the drill site or on ice roads. Food will be kept inside buildings or containers that minimize odors. Hazardous materials will be kept in drums or other secure containers. Any bear sightings will be immediately reported to the site superintendent and the personnel in the area warned of the location of the animal. Dedicated bear monitors will be maintained on location to look for and identify evidence of bear presence in the project vicinity. Upon identification of bear signs or a sighting, the bear monitor will notify the site superintendent of the presence of bears in the area. Bear monitors will also be assigned to continually watch bears when present in the project vicinity. Qualified bear monitors from the village of Kaktovik or Nuiqsut will be employed, if available, particularly during periods of potential subsistence use of the Point Thomson area to monitor project activities and coordinate with onsite staff to ensure subsistence activities are not impeded. 10. Oil Spill Contingency Plans ADEC does not require oil discharge prevention and contingency plans be prepared or approved for remediation projects including well entries such as are being considered here. Spill Prevention Control and Countermeasure Plans (SPCC) as required by EPA regulations will be prepared and in effect. Page 5 of 6 • . 11.0 Communications and Supervision An ExxonMobil designated representative will be on site at all times during operations. Twenty- four hour phone service will be available at the drilling or construction camp. The following persons or positions are designated contacts for the project. Name Title Phone/Email Mobile Phone TBD On-site TBD NA Supervisors Mike Barker Regulatory 907-564-3617 907-223-9904 Mana er mike.barker exxonmobil.com Prior to the start of field operations this contact list will be updated and provided to the applicable agencies. 12.0 Environmental and Safety Training All North Slope based company and contractor personnel will complete an 8-hour unescorted training program provided by the North Slope Training Cooperative (NSTC), which will include receiving a Field Environmental Handbook, an Alaska Safety Handbook, and a North Slope Visitor's Guide. This training will provide the basis for compliance with lease terms and permit conditions/stipulations for most employees, including wildlife and environmental awareness training. Additional specialized training will be provided to employees as needed, including such topics as detailed waste analysis planning, manifesting, and permit compliance requirements. 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Y~T.'~ S / ~ ~ ~~ 1~ ~~~. / ~~ ° ~~ 24 r ~ ~~, , 6~'~ ~ _ ~ ~ ~ ~, r ~ I ~ _ 1' ~ I ~ • ~ ~ ~ ~ ~ ~ 1 ~ ~ \, -,- 9g 1 ~ a= ~-- T7 ~ . ~ 1 ~ ,3 T ~~~, ~~~ N W E Figure 2: Pro osed Tundra Travel ^ ~, ~ , ~l `\ '` ~.~ ~' -- , ~' ~ p or Ice Road Routes E o n M o b ~ I 1 ` ~~ ~ ~ • ~ ~ S , ~ ~ "~~ ' //~ '~ y q - ~ 1 ~ Point Thomson Area I, "\` ~ ` ): ~ ~ r . `/ ~; \ ~~ ~ ~' '~:~ ~ G~oNct No. Ch•ck•d BY: 0 0.75 1.5 2.25 3 ~ ` ~~ ..4 ` ~ ' + ( _ I °•'•° 12/15/2008 "'•° P&A Trails Re~/l.mxd Miles I _ Telecopy No. (907) 276-7542 September 19, 1986 Mr. Greg Aggerman Mobil Oil Corporation P. O. Box 5444, T.A. Denver, CO 80217 Re: Final Location Clearance West Staines state No. 2 Permit No. 75-002 Sec. 25, TgN, R22E, Dear Mr. Agge~an: Our representative inspected .this location on August 7, 1983 and found that clean-up was acceptable for abandonment. The reserve pit had been backfilled, and a marker post with the required information bead Welded on it was in place. Consequently, final location clearance of the West Staines State well No. 2 is approved. We apologize for any inconvenience our delayed notification of final location clearance approval may have caused you. Sincerely, C ommis s loner j°/A.HJH,39 M EMOR, , IDuM St, z e of Alaska ~I,AS~A OIL AI~D -CAS COnSERVaTION TO: FROM: C. V. Chatterton Chairman l~nn~e C. Smith Comnissioner Edgar W. Stpple, ar Petroleum Inspector DATE: FILE NO: TELEPHONE NO: SUBJECT: August 25, 1983 10SA:F8 Inspection of ~'obil ' s Surface Abandonment for Final P&A on West Stains State and West Stains State #2. Sunday, ~..ugUSt 7, 1983~ I traveled this date to Prudhoe Ba~, Wh~re i met' Dua~=~C~osser of CaTCC, a re~resentative for Hobil Oil, to look at [~est Stains Stae and ~est Stains State ~2 for a final approval of abando~ent. The P&~. marker on ~'est Stains State, the legal description should read R23E not R22E. The P&A marker on t'rest Stains State ~2 is correct. There was noted a gauge at the bottc~, of the P&A F~rker. It fs my recommendation to the Commission to approve West Stains State ~2 and approve ~est Stains State ~en the legal description on the range is changed from 22E to 23E. In s%,~mary, I inspected the above wells for a final P&A and surface abandonment, for ~'~obil's West Stains State and West Stains State ~ftachments 02-00IA(Rev. 10179) FILE INFORMATION: Operator bb/( a/ Co Date Downhole P E, A Address i ge*, 5 TA, _pp vac (_.b Eott? SUrface Location of Well - Permit No 7.5 000 2.. “g Et. F S L, 5c) Ft. F LA) L, MEC API No. 50- 087_ zcvc Sec. 5 , T_/ „, Rza,e, .1 Unit or Lease Name May/ .,. Well No. (,06. sli-mis sy-4-1. c-- . 4 '2_ Field 6, Pool 20 AAC 25.120: WELL ABANDONMENT MARKER: / Dia. Steel Post (4"Min.) 4 ,, , Length (10' Min .) / .) t.') Height Above Final Grade Level (4 Min.) /6 ' Top of Marker Pipe Closed with; Cement Plug Screw Cap Welds --- Set: On Well Head L,..../ , On Cutoff Casing , In Concrete Plug Distance Below Final Grade Level Ft. ,‘ in. Side Outlets: All Valves and Nipples Removed i v ;',) All Openings Closed NO , With Blinds , With Cement , Other ---- / a,a,f(zt w ).--if, r Ctf :„ INFORMATION BEADWELDED DIRECTJLY TO MARKER POST: (List Where Different from File Information) Operator /IA08/ /- "Hs /h Unit or Lease Name /Aii..,/ rrArt. Well Number , Surface Location of Well; ,:1 Ft. FS_L, SO Ft., F v., L, Sec ;15 , T ‘-/ • ,, , R N to r66, 7 4)904 2 ;air ki, r ....” - ai,...4 20 AAC 25.170; LOCATION CLEAN PITS: Filled In Liners A Pporz7",, , :k/ SURFACE OF PAD AND/OR LO Rough , Smooth Other SURROUNDING AREA: Wooded , Brush , Tundr Sand Other 'ALA Sit AND GAS Cttt COMMISk / SURFACE ABANDC'NEN T REPORT 20 AAC 25, ARTICLE 2 Removed or Buried , Debris Removed / 4c CATION: Contoured ---, Flat Compacted Grass ---, Dirt , Gravel CLEAN UP OF FAD AND/OR LOCATION: Clean , Pipe Scrap , Iron Scrap • Wood Mud , Cement Paper , Other S. „„., 2 1, N 7 1,.. , . 6+,„4 CONDITION SURROUNDING AREA; Clean , Trash from Site Trees and/or liti from Clearing Site -Other ACCESS ROAD: Dirt , Gravel , Ice • Other .F t fr"J & lielAc CONDITION ACCESS ROAD AND SURROUNDING; Clean , Rough , Smooth • Trash from Operations , Trees and/or Brush from Clearing Road , Spoil from Clearing Road Other INSPECTED BY 05/26/81 4( J4/ 0, r, v--k- 1.1, 41- 7 .;. 1 5.4=4" DATE REMAINING TO BE DONE: RECOMMEND-APPROVAL OF ABANDONMENT: Yes i No Final Inspection 0 N y ./0 cki Nkt� SbtiAc rem 0 Z stt 2s ray, RUE, uM 10 EST tq StA* 4 2 g. 743 ':.~ STATE OF ALASKA · ~' ~- -ALASKAi ", AND GAS CONSERVATION C~. . ,MISSION SUNDRYi OTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ 2. Name of Operator 7. Permit No. Mobil Oil Corporation; Attn: L. C. Case 75-0002 3. Address 8. APl Number P.O. Box 5444; Denver, CO 80217 50- 089-20004 4. Location of Well OTHER [] 848' South and 50' West of the NE corner of Section 25-T9N-R22E, UFM 5. Elevation in feet (indicate KB, DF, etc.) DF 95 ' 12. I 6 . Lease Designation and Serial No. ADL 28377 9. Unit or Lease Name Mobil - Phillips 10. Well Number West Staines #2 11. Field and Pool Wildcat Sec 25-T9N-R22E, 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 ~ 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 requests an extension for the following proposed change in the well marker: (1) correction in the range to R22E. (2) the exact distance of the well from the section lines. ECEIVED MAR ; 1983 glaska 0JJ & Gas Conb. Anchorage uumrniS$ion 14. I hereby certify that t~l foregoing is true and correct to the best of my knowledge. Signed L.7~~~~ T,tleActing Division Regulatory The spac~lo~forCo~miss~use j'o 1.. Douglass Engineer Date March 3, 1983 Conditions of Approval, if an¥:.OLl~ repreSentative inspected this site on August 12, 1982 and noted the needed correction. Only the range change is needed. A subsequent inspection will be needed by August 1983 Approved Copy · Returned '-~ ..... "By Order of ~-~ .~_~_ ~' 5 · Approved by j~v ~n~- n ~,~|T~ COMMISSIONER theComm~ssion Date _ ' _! L~!~.r,2.~'' ~; ...... ... Form 10-403 Submit "Intentions" in Triplicate Rev, 7-1-80 and "Subsequent Reports" in Duplicate Septem~r 13, 1982 ~obil Oil C~nY P.O. Box 5444, T.A. ~n~r, Colorado 80217 Re= Clean-up Inspection for Final Abandonment Mobil Oil C~ny, West Staines St. No. 2, Sec. 25, T9~, R22E, ~N. C~entlemen = Our representative inspected this site on August 12, 1962. The well head is higher than ~ like, but in general the clean-up was ~11 done. The well marker has R23E bead welded on it instead of the correct range, R2_~E. When the range number is corrected this location will ~rapproved for final abandonment. A close-up photograph of the corrected well marker will be satisfacto~ evidence. Sincerely, I~S/O~/glh E ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION September 1, 1982 Mr. C. V.'Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: On August 12, 1982 a representative of the AOGCC (Harold Hawkins) · along with R. L. Westbrook and R. G. Dragnich, conducted an inspection of several of our drilling locations in the Pt. Thomson and Duck Island areas. During these inspections, the representative indicated that one-year extensions on suspended wells would be approved after the cleanup work was completed at these locations. We therefore submit, the enclosed photographs of our Pt. Thomson #3 and Alaska State C-1 drilling locations which indicate that the cleanup has been completed. We submitted Sundry Notices requesting extensions for these locations on August 10, 1982. Also attached are Sundry' Notices requesting one-year extensions on our Pt. Thomson #1, Duck Island #2, Alaska State D-l, and Pt. ThOmson #2 locations. These are wells which we wish to carry as suspended rather than abandonments. The Pt. Thomson #1 and Duck Island #2 locations were inspected by your representative who indicated that extensions would be approved. As you recall, Duck Island #1 and 2 is a single wellhead and the AOGCC has previously approved the abandonment of Duck Island ~/1. The Alaska State D-1 location was previously submitted for abandonment approval on February 18, 1982 and was also inspected by your representative. We understand that to obtain a final abandonment status for this location, the sheetpiling will have t° be cut off below grade. The attached Sundry Notice requests a one-year extension to enable us'to conduct this work at a future date. The Pt. Thomson #2 location has been suspended since September 1978 and was' not included in the inspections. The attached Sundry Notice requests a one-year extension of this status...,,., A DIVISION OF EXXON CORPORATION We aiso request clarific~'tion of the status of Mobil's West/ ~taines'~#2 ~'location. This location was inspected by your repre- sentative and discussed at a-meeting with Lonnie Smith and Jim Trimble of your office and Exxon representatives Dave Galloway and ROb Dragnich. Please advise Mobil as to the requirements for their obtaining a final abandonment for this location. Very truly yours, D. H. Jones NPB:sjm 60/2 Attachments · MEMORANDUM State of Alaska ~ ALASKA .~L AND .~$ CONSERVATION COMMISSION C. %7. ~h~er~ton ~. :--~ August 31, 1982 Chairm~ %~J ~ (? / F,LE NO' ' T~RU:Com~~nniessionerC' Smith. ~/ ~) TELEPhOnE ~O'. FROM: SUBJEGT: ~arold R. ~awkins ~ ~ tro le,mm Ins~ctor ~:~' ~ Final Abandonment Inspection Mobil Oil Company West Staines St. No. 2 Sec. 25, T9N, R22E, UM Permit No. 75-0002 _T_h~_rSda¥_,~ Au~ust 12, 1982 - I left Mobil's West Staines St. 28-9-23, s~ject'of anOther report, to go to Mobil's West Staines St. No. 2. Exxon removed gravel from the location using Frontier Sand & Ravel Core, ny, Mobil Oil gave Exxon approval to remove the gravel. ?he gravel taken was removed and placed on ~Xon's Point Thomson No. i location. Doug Amos inspected this location August 10, 1981 and one of Doug A~s's stipulations ~as that Mobil Oil remove the well head and proper marker post put on well. The proper mar~r post ~as ~at on, but the well head still protrudes above the ground about 2% feet, as shown in picture #1. The range that is bead welded on marker post is not correct. As shown in picture #2, the rest of the data is correct, as is shown in pictures 3 and 4. I informed Junior Westbrook, supervisor for Exxon, of the infraction of the well head above ground and the incorrect number for the range on the well marker post. I also visually inspected the surrounding area and pad condition. The drilling pad was clean and .free of debris, but approximately 75 foot square and by about 4 foot high, the pad w~s left higher than the ~inal ground level around marker post of the surrounding area shown in pictures 5, 6, and 7. The pad that is left high around marker, post can also be seen from the aerial pictures 8, 9 and 10. Picture #10 is an extra well sign welded to a post, but could not tell whether it was welded below or not. In summary, I inspected Mobil's West Staines No. 2. Mobil approved ~xon Oil Company U.S.A. taking gravel from location. As this location was to be put back to its original state or as close as possible and the regulations of the A.O.~.C.C. -were not complete, I s~ggest the final abandonment not be approved until stipulations on the A.O.G.C.C. field report are met by responsible party. 02-00IA(Rev.10/79) 'ALASKa!I. AND GAS CON.~I.~RVATION Cc)MMISSION SURFACE ABANDONHENT REPORT 20 AAC 25, ARTICLE 2 FILE INFORMATION: Operator /~a_,gfF]l ~/~ ~'~~/~F/~ Date Downhole P & A ~-~f-~ Address ~ ~ ~ .5-~ ~ ~ ~~7~ Surface Location of Well Pennit No. ~- ~~ Ft F ~ L, ~t. F~L.,d~/f f~~ API No. 50- %e_. ~ ~'T ~ ~,~}i~M. Unit or Lease Name ~3 ' Wel 1 No. Field. & Pool f4~ x~d 20 ~C 2~.120: ~LL AB~DONMENT ~RKER: Dia. Steel Post (4"Min.) ~ ~ Length (10' Min.) /~ / . Level ~' Min ~ /~ / Height Above Final Grade . Top of Marker Pipe Cloud .with: Cement Plug ~ Screw Cap Welds Set: On Well Head ~ , On CUtoff Casing , In Concrete Plug Distance Below Final Grade Level ~~Ft. in. Side Outlets: All Valves and Nipples Removed All Openings Closed ~ ~With Blinds , With Cement , Other INFORMATION BEADWELDEI) DIRECTF~LY TO bbiRKER POST: (List Where Different from ~Fi'ie Info'rmation) Operator ,~7~/~ O7~ ~-~~?~?/~' 'Unit or Lease Name ~ST $~/~ ~T~ Well Number ~ . , Surface Location of~%~ ~ M ~Ft. 'F5 L, ~Ft., F ~L, Sec ~ , T~ ~ , . F~lled In ~ners Removed or Bur~ed ~Debr~s Removed ~ SURFACE OF PAD AND/OR LOCATION: Rough ' , Smooth , Contoured~ , Flat , Compacted , Other 70,~ D !v/,4~' .~ ~o~,n ~;F ~TB~.~/~,( 7J~ ~~£ A,~O ~.~Tq'/~/~]~ '~/?~ ~o~ 7H~' Clean ~"', Pipe Scrap. . , Iron Scrap , Wood , Mud , Cement , Paper , Other SURROUNDING AREA: Wooded , Brush , Tundra L//, Grass , Dirt , Gravel Sand , Other CONDITION _SURROUNDING AREA: Clean ... /~_, Trash from Site Other , Trees and/or Brush from Clearing Site ACCESS ROKD: Dirt__, Gravel Ice__gi/, Other CONDITION ACCESS ROAD ANq SURROUNDING: Clean ~, Rough__, Smooth , Trash from Operations , Trees and/or Brush from Clearing Road __, Spoil from Clearing Road Other REMAINING TO BE DONE: R/~g[. t~RA~, M&~c~ REm&O~. 7~A~,~ FAb RECO~END. APPROVAL OF AB~DO~IENT: Yes .... --~--. Final Inspection INSPECTED BY ~ "? ' ~' ..... / · DATE ~// Z /~._ _ Fl Al _ABAA4WAste,✓r_,L.r& A ,CTief/ £srST 1 T,Vo- 2 SLc �` � T 9,(/ ) 8 AA i kM ori,oE 6sty Ale. 5 - Ao- >z1 June 4, 1952 ~::~:· AH/D Exploration Co., Inc. ..... -"?' ~" P.' O. Box 360- '~ Anchorage, Alaska ... 995'10 Re= Geologic Slides and Analyses Prepared from State Well ..... Samples and Core Chip. s, Dear:~Mr, Brown :. The .enclosed list'reflects various ~eolo~ic slides and analyses that have been recently added to the ~tate's library of ~pecial materials prepared from well samples and core chips filed with the Co~ts~ion, The materials listed are in addition to those tabulated in the 1980 Statistical Report and those reported in the'February, March and April ~nthly bulletins. P'lease'~-_ photo-copy and distribute copies, of this list to appropriate ps,sons within your companY.:.. You'~are ~he only person in your c~p.~ny:~to'wh~:~the:list has been sent - In:the event publication of the C~ission~s monthly bulletin not resumed, the next listing of newly received geologic materials will be distributed approximately September 1, 1~2. For current info.etlon on newly'received materials please call the C~ission office at any time, weekday~ 8:00 ~,~ to 4:30 P~, Alaskan Time. ALASKA OIL AND GAS CONSERVATION C,OMMISSION June 1, 1982 :-,.?~¥?:~'~.~.:;?,?~::~r.?~?~:?~?~.;. RECENTLY ~CEIVED GEOLOGIC MATERIAL~ +::The~fOllowing geologic materials have been recently.added t.o the Co~ission's library of special mterials prepared from well s.amples and cores of wells drilled in the State. These materials are in addition to those tabulated in the 1980 Statistical Report and those reported in the February, March and April Bulletins. ~co Cathedral Riv. U. ~1 89 50 - 14,360 ~alynol~gie Slides S~AL NaptoWne Unit ~24-8 13 14,600 - 15,226 Soldotna .Ct ~22-32 19 13,640 - 14,560 e~ .?;~ .~-;~?,.: ;~ ~:~-~¢~:~ ~,~:... ,. ~,~ ~ .~/- .~: .... ~ 'L. 5~~ .~?-- .. ',. :'.-~ ~.'-~ ' ~z~' % .-' -.~'~';~' . , . :: . .'- ,~'.. · ' ~---':~ ' ~-~::, ?; ~:i-~.~, '-~ ~'~ '~ : ',~ ,, .~- , ,~,-~ -- ~'.: ,',~ : ;, ~-;:.:: -~" ~,.. :~ . .t- Th~n-Sectlons of Core Ch~PS:~..::~.'~:.. ~:. ~,~....- M~il Kadler ~t. ~'1'5-9-6 ~ "- : ' 11 9644 - 9695 · -Thin-Sect ions of Ditch Samples.t ..,,:. .. Great Basins Ugashik~l ' 14 2400 - 4490 Gene. ral~:~Petroleum G~eat. Bastns.::~2.,.' : 37- 2210 - 8810 GUlf :'Sandy'- RiVer'-: ~ 1 , 2 .6280 - 8180 ..,.-Pan,~er~can Davld"R~ver~l~-A~:i,.,'-~"';~, : 34 : 1350 - 4760 j.;-J:Pan~:~.~eriean:,Hoodoo, t~Lake ~1'.'..~ '. ' 34 2480 - 8050 Vi trini te ~e fleetanee'-'s1 ides/Plugs :'>i(¢ Mobi.l'~'-W.,:..S[a.ines '~2 48 1020 - 13. 150 Texaco W. Kav~ ~1 ' 44 Exxon Canning River B-1 39 ARCO Kavik #1 37 Fores't.Kemik #1 37 B.P. Kemik #2 .. 4 ~ Exxon Canning River A-1 -' ..-:~ 11 Thermal Maturation Reports ~-R~port-'on totaf~o~ga~i-c Carbon· -~: ' and:',Vi..trinite Reflec.tance Values .. for. eight North Slope wells. .,- ,'"~t.:;.:," '~' -i~ ' ..".:i - - . . ...' -"_ ":. ..,', e~ght' ~orth. S10pe-w~lls .:z~ '..;?.."~'~ - . ..... " 1590 - 16,530 1040 - 10,800 560 - 9500 710 - 10,000 3750 - 5250 .530 - 6500 1359 analyses 320 analyses · . ~rch 31, 1982 Mr. Joe Curiale Union Oil Company of California 376 Sour h Va leni a Avenue Brea, California 92621 ¢~ochemical Analyses on Samples and Core Chips from State Well Sample Library Dear Mr. Curiale: Pursuant to our March 5, 1982 phone conversation and your disCus- sions with Commissioner Kegler March 17 nd 18, 1982, permission has been granted to Union Oil Company of Calfornia to extract a maximum, of I cc. of sample material per sample envelope, or I cc. of core material per foot of core, from the State's set of samples and cores for the purpose of conducting the following analyses and submitting the ind. icate~ material within the designated intervals in the following wells, subject to the below listeO conditions: AN~.L YSE S - Total Organic Carbon (TOC) - Rock-Eval ~yrolysis (RE) - Vitrinite ~eflectance (VR) (~?ot to be done on ARCO Toolik Fed. ~1) Your March 24, 1982 letter to Harry Kugler indicates the approximate numar of the analyses to be run on each well. · SAMPLE SZT No. 248 337 240 · 299 342 322 204 Texaco W. Kavik 1 ~xon Canning River #B-i ARCO Ka~ik # 1 Forest Kemik U~it #1 B.P. Kemik Unit #2 ~xon Canning River Unit #1 ARCO Tootik Federal #1 INTERVAL 2, 800'-13,170' (183 samples) 330'-16,613' (105 samples) 800'-10, 800' (190 samples) 400'- 9,559' (168 samples) 700'-10,000' (178 s~mples) 500'- 8,870' (128 samples) 1, 170'- 8,880' (160 samples) 10, 140'-10,230' ( 20 samples 2 ch 31, 1962 - TOO, ~ and ~ data on above wells in report form - VR Plugs Cuts of the samples and core chips from the State library, set are to be extracted only from those individual envelopes or bags in which total content of samples or core chips is greater than I0 cc. (No cuts are to be extracted if the volume of material in thQ individual envelope is less than l0 cc. } 2~ Union will prowtde the ~tate with a list of the depths in the well from which material was extracted. (This condition has been met by our receipt of the memo you prepared ~arch I~, 1982, copy enclose~). 4~ All reports and V~ plugs prepared are to be received the Ccmmtssio~ by approximately ~ay 14, 1982 and are to be transmttte~ ~irect to the Commission and not ~amtn~ hy outside ~ies.. ~1~ residue and ~ceas ~terial ts to ~ returned to th~ C~sSiOn. 5~ No additional slides are to be prepared nor analyses made on the s~le or core material without specific consent from the Commission. 6. ~nton shall hear all costs entailed. We are pleased to work with you in thi~: beneficial 'project and look forward to your company's continued exercise of care and good j~gement in the ~a~.dlin~ of this limited quantity of valuable 20 e~tra~ ~tons of ~tertal fr~ this libra~ for the put,se ~ preparing the tn~icat~ re~rts and VR p]u~s enhances the Very truly yours, William Van Alert P~troleum ecologist cc: Mr'. J. A. Pa. ckar~.- Union, Anchorage' ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilto~ Thru.- .Lonnie C. Smi Commissioner Doug Amos Petroleum Inspector August 21, 1981 Inspection of Mobil Oil Corporation West '-~. 25, T9N, R~: ~.~. Permit No. 75-0002 Monday August 10, 1981~ I accompanied Mr. Chris Cooper, Mobil 0~-i C0~0ratio~::repr~'~entative, to the wel 1 site. As the attached, pictures show the pad area is in a deteriorated condition. The well head still remains and there is no well abandonment marker. There is in my opinion enough material mounded in the mud pits to cover and level the pad area. Therefore I reccmmend to the commission that the well head be removed, and a proper well marker placed on the well; that the material in the mud pits be spread over the pad and leveled and that Chris Cooper's recommendation to taper a 50' square gravel pad around the well marker post be approved. In summary.. I conducted a clean-up inspection on Mobil Oil's West Staines State #2 well. MOb1L IL GORE W �sj TA! N ES STATE 14O. 2 " Pie-Auras 41%kea $- I o -8I 4-s-10-61 Frk01 Aga' l.oelcIPICI 14651 FRAM AIR Losk114 4 EAST -i H - I; 0 IVI VA _ __PvT 14 ve, 4 5,E '1 Prc41.4 v c. June 12, 1981 Mr.. Hideyo Haga Senior Biostratigrapher, Palynology Bi oStra ti g raphi c s 7202 Clairemont Mesa Boulevard San Diego, California 92111 Dear Mr. Haga: · We have received your request, dated June 11, 1981, to cut certain sets of our well cuttings samples for processing. We are happy to received your request and~ to b~ able to approve it. It is the Commissions understanding that BioStratigraphic will cut the samples from the following'wells~ ARCO ARCO Mobi 1 Richfield West Beach St. No. ?~C~'"Staines St. No. * ARCO * Phillips Gull Island St. No. 1 .Big River A No. 1 * Will be cut if available thin sections not adequate. A small portion of the existing well cuttings at each depth may be removed for your work. It is understood that all slides, foraminiferal specimens, and other material will be returned to the 'State for our library. It is further understood that the material from each well will be returned at the time the processing is completed and all .processed material will be returned by December '1, 1981. We hope the material is adequate, and supplies valuable information to you and to all industry. Yours very truly, Harry W. Kugler Commissioner HWK:be ~ : ..,,' June 4, 1981 Mobil Oil Corporation P.O.Box 54.44, T.A. Denver, Colorado 80217 Re: Alaska Oil and Gas Conservation Commissicn Regulations Article 2, ABANDONME~?T AND PLUCCING, 20 AAC 25. 120 WELL ABA~DON~'~ENT ~ARt~ER and 20 AAC 25.170 LOCATION CLEAN UP. Gentlemen: In regard to the above referenced regulations, your attention is called to an attached list of %-~ells which, according to our records, have not received a final location inspection and. approval of clean up. In compliance with 20 AAC 25.170 Section (a), "Within one year of suspension or aban¢~.oDment of an on- shore well", all clean up werk is to be_ finished. Section (b) provides the means for an extension of time. if a valid reason · exists. Section (c) provides for on site inspection. Consequently, we are presentin9 the following list of your abandoned and/or suspended %,;ells. ~,iany of these are now more than one year old. and are not in compliance ~.;ith regulations. Others should have the final inspection co~'~pleted this summer while weather permits. This list covers the years 1975 to date. There may be some earlier %~ells that also need inspec- tion. If you have any earlier wells to .be inspectec], this summer please inform us. Therefore, we are requesting a schedule from you for this summer when our field inspectors can accompany your representa- tives to these sites for the final clean up inspection. Yours truly, Lonnie C.~ Snith Commi ssi oner LCS/JKT.- t>s Staines River .St · Kut:~.ruk 30-11-13 Kuparuk 9-11-12 W. Staines St. #2 MOBILE OIL CORPORATION SUSPENDED PLUGGED. & ABANDONED Mobil Oil Corporation September 12, 19 75 P O i~(')X 54,1,$ DENVfLR. COl. ORAI)O 80217 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 July 15, 1975 'Hr. tlarry Porter Mobll 011 Corp. Pi. O. Box 5444 Terminal Annex Denver, Colorado 80217 Dear Mr. Porter: We are trying to schedule our field work thls summer and If would help us to find out when you utll be ready for the final location Inspection on the followlng wells. West Stalnes St. ~ 18-9-23 N. Kuparuk # 26-12-12 West Stalnes St. # 2 ----- Kuparuk # 9-11-12 Sincerely, Hoyle H. t lamllton Chief Potrolet~ Engineer HI IH: pb MOBIL OIL CORPORATION P. O. BOX 5444 DENVER, COLORADO 80217 ...... . . ~~-~~ DATA TRANSMITTAL RECORD DATA DESCR i PT I ON mil ~.r- j' _ .~. =_ ~ ..... .. _: .-: '.". -.=.:.._. -z_:':-_.__~==~=~__._..=-:---'...' -... ........... . _.. ~ $ · .......................... .~/~.-~/.../~ ~, -- -/~-/7/,'~_ ~..~: ................... . · - ..... . ...... ._ ii m , ) il 11 ii i ~ i i _ PLEASE CHECK SHIPMENT THEN SIGN AND RETURN ORIGINAL COPY Descriptors to inclUde when applicable: 1. Number copies or copy numbers L3~ 2. Type of print: Field or Final 3. Type of copy: Film, Sepia, Bl-uel ine, Ve.)um 4. Series, Sequence or Interval- " '-'" Numbers RECEIVED BY: c_ ~..:~ _ DIV;$1ON OF OIL AND GAS ANCHORAGE OBIL OIL CORPORATION P. O. BOX 5444 DENVER, COLORADO 80217 R, T.nmm u~ DATA ~,,R~NSFERRED ~ TO: State of Alaska, Department of Natural Resources, Division of Oil. and Gas, 3001 Porcupine Drive, Anchorage, AK 99504 TRANSFERRED BY: R. T. Donahue DATE: 6/6/75 DATA DESCRIPTION Mobil-Shell West Staines State #2, (Sec. 25-gN-22E, North Slope, Alaska) Eastman Directional Survey ~ , es) :Well Completion Report Form #P-4 ] BHC Sonic 2" & 5" (composited) I blueline print ! sepia DIL 2" & 5" (composited) ! blueline print I sepia 5" (compos!t~ed_).(! blueline print ~i ! se.p!..a_. _- ......... , .~-- 5" (composited)~~" ~_ I sepia FDC FDC-CNL PLEASE CHECK SHtPMENT THEN S Descriptors to include when applicable: GN AND RETURN ORIGINAL C(]PY t. Number copies or copy numbers Type of print: Field or Final 3. Type of copy: Film, Sepia, Biuelina, Velum Numbers jL9~ L~ U~ ~ t] ~ ~ DW'~ION O? O~J A~D GAS ANCHORAGE RECEIVED BY: _, DATE: c/~ - /~' '4-~/ Form P--? STATE OF ALASKA ',See other structions on OIL AND GAS CONSERVATION COMMITTEE reve,'se ' o " WELLcOMPLETION REPORT AND LOG* I I ii ' II i il i la. TYPE 0 W~LL: ~ OzL ~s ~WELL WELL DR~ Other ' ~ . b. TYP~ OF WELL OYER EN BACK n~SVg. ~ Other NAME OF OP'.RATOR Mobil 0il Corporation. , .,., ..., ,. ..... , , 3. ADDRESS OF OPERATOR P.O. Box 5444 TA, Denver, CO 80217 50-089-20004 g. I, OCATt0N Or WELL (Report location clearly and in accordance with any State requirements) At.urface 848' South and 50' We~t of Northeast corner At top prod. Interval reported below At total depth 935' South 'and 97' West of Northeast corner 13. DAT~ SPUDDED 3/8/?5 13,171' & 13,169r ~ Surface sow~* ' Surface"°~"~ ~oo~- ~. PRODUCING IN'r~VAL(S), OF ~ ~OM~'r~O~, BOSOM, ~E (~ ~ ~)* . . 24. ~E E~CTRIC ~D OT~ ~S ~ 6. LEA~m DES/GNXTIO~' AND SERIAL NO.. ADL 28377 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT,FA, R/VI ~OR LEASE NAME Mob i I -She I'l 9. WELL NO. West Staines State #2 10. FIELD ~ POOL, OR WILDCAT W i I dcat 11. SEC., T., R.,' 1VL, (BOTTOM HOLJ~ OBJECTIVE) Sec. 25-9N-22E UM 12. PI~VIIT N'O. 75-0002 II4'DXTET'D'RE~CPAJ~II~""]~ATlnCO/VLPSU~PO~BA]3'A3~TD'" I16'~'~'l~"VATIONS(DF'RKB'RT'GR'E'lr~)'[l?'~'CA$INGHEAD5/21/75 " 5/26/75 RKB-95' (USED) GL-75' 80' INT~RYAL~ DRILLED BY I 3, 171 ' '{ ¢,.~- Too~,~ I SURVEY 1VIAD E J Yes J Resistivity, Acoustic, ]Density, Neutron, Gamma Ray, Dipmeter, Cement Bond CASING ~RD (Report all strings set in w~ll) 30" 154 ~ ~ B 255 Sx Arctic Set 20" 94 :- " H-40 78~ ' ~26" 4380 Sx Arctic Set 13 3/8." 72 ~ iN-80 I 2275 ' 117 I/2" 3870 Sx Arctic Set , 9 5/8" "j" , ,47, ~ 43.'5ls-95 J 11270 ' ll2 1'/4" 650 Sx Class G 26. LINER ILECOI%D 27. TUBING R,ECO~ SIZE 'i TOP (MD)[ B TTOM (MD)'l SACKS Cm~m~T, D]~I~I INT]~VAL (NLD) AMOUN:£ ."&rD KIND O~ 1VInTnER/AL USED · · i i I I I i i · 30. PRODUCTION DATE FIRST PRODUCTION [. PRODUCTION METHO'D (Flowh~g, gas lift, pumping--size and type of pump) ]JW'ELLsnut'in)STATUS (Producing or ,AT-- o, TEAT. lfiour, s Tr.S~'~D j' Ic~Ioxr slzz Ir~ov's FOR: O~BP.L. '"~A~i~CF. W,~BB~. J dAs-jm"r,,~'no I 'i t I FL~"~W,' TUBI~O' ~bING V~s~l~ ICA~J'T.~T~D 'OIL~BBL. ' I "'r , : uu~ . 33.'I hereb~ ee~tffy'{h~t the'for.going .n~ attached Information ,.'complete and eorr~t fr6~ 1 r s SIGNED TiT~Area Goo J oq i st DATE II I ~1 i ~ i I iA1VIOUlVT PULLED None None None . None ACID, St~OT, FD~'~RE, C~VLENT SQUeeZE, ETC. INSTRUCTIONS General: This form is designed for submitting a complete and correct well com'pletion'report end log on all types of lanJs and leases in Alaska. Item: '16: Indicate which elevation is used as reference (vvhe,'e not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate prc, duclion from more than one interval zone (mulliple completion), so state in item 20, and in item 22 show the p~c.Juc,ng 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 each additional interval to be seperately produce.J, show- ing the additional data pertinent to such interval. 'lt~m~6: ".Sacks Cement": Attached supPtement~l 'records for this well should show the details o'f any mul- tiple stage cementing and the location of. ~he cementing tool. ~,' ~ Item 28: Submit a separate completion report-on ~his form for each inlerval to be separatel¥-.~roduc~l. '(See instruction for items 20 and 22 above). .';..,5.'" '4" .. · '.¥ ..'..~.v ~''' WATEFt AND MUD HA.M~ ..... ~t,'-"r' -' ..... II I J i Jr Jl i ....... ' ion tests attempted B/Permafrost 2050' 2050 ]~ Tertiary ~ Coaly Bluff 7155' 7155 Cretaceous / Fishbone 12405" 12405 Devon lan ................. , .................. ~ .... ~ ,,.. ............. :._ ............ :._.: ..................... ':1 Argill ite 13130' 13130 ' .~,'n,~ ~.~ml~c~,i~) -~i~vts ~o~ :om. ~O'A~ .,OR ~X~. .;' " · ~'..,~:L.,. ii 11#1 ...... '::'' ' '11, _ ' 1 .'! I '1'11' I" ...I II I Ill Il III1'11 '1 ~ ...... z ' ' , . ~g 8~emp~ed .... _ _ ~ . ..... ,,,,r, ...................... ~r' ,. · ,,,' '~ '~. , ~,, .......................................... ~m~r ............ , ..... ,~ ' r'. SUPPLEMENT WELL COMPLETION LOG MOBIL OIL CORPORATION WEST STAINES STATE #2 CONFIDEN[Mi Pl§gging detail - Set I00 sacks Class G cement from 11170'-11370'. Set 9 5/8" HOWCO EZ Drill at 3000' capped with 40 sacks Class G cement. Opened f/o collar at 2379' and cemented with 40 sacks Arctic set cement and f/o collar at 2223' and placed Baroid Arctic Pack between 9 5/8" and 13 3/8" casing. Set 50 sack Arctic set cement plug at 2397'. Set 9 5/8" HOWCO EZ Drill at 150' and capped to surface with Arctic set cement. DIV:$1ON CiJ: OIL AND GAS ANCHORAGE 1 REPORT of SUB'SURFACE DIRECTIONAL SURVEY Mobil 0il Corporation COMPANY West Staines #2 , , , WELL NAME North Slope LOCATION Radius of Curvature Method JOB NUMBER AM0575S-1 3 TYPE .OF SURVEY Magnetic Multi-Shot DATE 5-21-75 SURVEY BY OFFICE Jay Martin Alaska IFOIlld IJ-~OI Ill MOB]t~ OIL:--CORp', ....................................... WEST STAINE$ NO. 2 MAGNETIC MULTISHO~._.SUR~E_y/i_~i]i._.,i'~"~.~iii'.~". .... i"i' .RADIUS OF CURVATURE METHOD~'_"~/._"~["'~_~ '/'~_~/~ KB ELEV, 100.1 FT. DECLINATION 32 DEGREES EAST -RECORD' OF--SURVEY ............................................ - TRO'E DOG LEG D M ~E~_, ....... - .......................................................... D ...... M S T2T-O'-'2FOZ. ..... s ......... ........ Fo',oo._.w .......... o.oo s o. o .. ......... o.ooo ...... ~50____0___2_5. _ _A~9~_9.9_ .... !_~..,_8~__ 562,00E 0,76_ $ .............. O,~A. E 0.89.__5.30._59 59 E 0.410 ~0 0 20 409.99- 309.89 S68.00E ............ ~.21._S .................. !.~..~.~...._E 1'-88 $ ~9 ~6 56 E 0.060 600 0 ~5 ...... 599,98= ......~99.88 S77.00~ 2.57 S ~.32 E 2.89 S 27-1~ A5 E ~.392 770 0 ~5 769.97 669,87 S32.00W 3,83 S 0.~ W 3.86 S 6 3~ 5 W 0.~8 1~20- ~"--30-- .... i0i9,'.9-~ .... 919-;~'5 ..... S~',"o'OW~' ...... 6J02'""S ...... 2"05--W ............. 6.3~-s ~8 -si ...... 39-W ..... 1300 ..... 0--'i5 ..... 1299.94-- 1199,84 .... N58,OOW ........... 6.27'$ ........ 3.72 "W ............7.29 S 30'41 8-W .... .... 233'I-o-~-5 ...... 2330'93 223o.-8M-'-$23.00E ....... 8.47-S ......6.30'-~--' 10.56 S 36 ~7--~f - 2~25 .... 0 .... 0--' 2424,93 232~.83- S O.OOE ...... 8.67 S 6.26 ~ ...... 10.70 S 35 ~8 .... 5-~---~ ........ 0.266 -2519 0'-'30 25~8.9~ "2~8.83 S68.00W'-' 8.9~ S ..... 6.~7 W .......... 11.08 S ~5 ~5 2613 0 15 2612.93 2512.83 N78,00W 9,05 S 7.08 W 11,~9 S 38 2 30 w 0,286 ................... . 270& 0 30 2705.9~ 2605.83'-'S78;oow- 9,05 S 7.68 w 11.87 s ~0 20 ~9 w 0.~03 ..... 2800~'"'0'"30 ...... 2799,93 ...... 2699'83 N68;'OOW ............ 8,98""S ........ 8,~9-W .... 12,35 S ~ 2~ '~'~-W '0'311 ~_2_89~'-__0..35'~-.2'B93'92 .... 2793.82 S86*OoW ...... 8.8~ S ........ 9'36 W ........ J2..88-S- ~6'-,39- -9--~ ....... 0,~-2~ ..................... 298~ ...... 0_..!0 .... 2986,92 2886,82 S82"00W 8,90 S 9,98 W ~,37 S ~8 15 18 W ....... _ ......................................... _3173 0 15_ 3172,92 ...... 30~2;82 ._.3~.6.6 ..... 0__].5_ ..... 3.265,92 ..... 3].65.82_..Nlo,ooW ....... 8._82_._$ ..... 11.0:) W 3359 0 30 3358.91 3258-;-81 N18.OOE 8.22 S 10.97 W 3453 0 30 3452.9i 3352.8]. N21,OOE 7e45 S 10.70 W __36¢0_040 .... 363_9,_90_ 3539-80 N32.00E 5,58 $ 3734 0 35 3733.89 3633.79 N57.00E .... 13.65 S ~9 4 ~2 W 14.00 S 49 54 35 W 13.71 S 53 9 26 W 13.0~ S 55 9 16 W 0,~52 0..0.87 0~042 0,442 0._~.28 10.23_W _. 12.15 S 57 19_.57.~_ .... 0~.358 9.58_.~ ..... 11.09..S__59 45_.~6._W .... 0.092 8.86__W ....... 10.11 S 61 17 33__W ...... 0e270 8,17..~ ...... 9_..14._S 63 21_21._~ ...... 0.~93 7,63 W_ ...... 8e32__S..66 27_ _~_.~ ..... 0.2!5 SECT ..~-- __ D_I_STANCE 0.00 0.~5 0.38 1.63 5.58 6.27 7.29 10.45 10.61 10,99 11,33 11,62 12.58 12'78 13,03 13.01 12.46 RECORD OF SURVEY ...................... ....................................... A~L,'_~A~'~_uL_A_I'.~_o~.$p..[~.FORM ED._B.y .! B_.~.. E L E CT. RON l ¢. COMP_UT ER TRUE DOG LEG. ' M. EA~S.; ~i~D-~"~ .F ?:._~ E E T I C A.~_ .~.' '_-i~ S'o Bi- "~'_'.'i~i~ DR'I F T~'_'"i.i~'"'~'_'~j:_'i~...T o ~A L .. C OOR D INA T E S ..... ~'~i'~ ~i'C-_i-~'-"O ..._$-~-i~~ R ' 'E_._S~_.~ SE V E~.T~ ....... 5 EC~_~ ON DEPTH ANGLE DEPTH SEA ' DIRE'~ ......................................................... DISTANCE ANGLE 'DEG/iOOFT DISTANCE ~OZ~ 0_..39 __~0~3,88 ......... ........ 39l-'3';'78 ....... ..... N~8'*OOE .... 2';75 S ......... 7,06 W ......... ~,~7 .... .... S--68'"'4~'-~5 w 0,056 ~107 ........ 0_..55 ...... ~106,87 ~'00~-;77 N47,O~'E ~'~'~' ~"*'96'~- ~';20 W 6;'~ 5-72- 4200 .__9_~5._~Z99_.a6 ~099_%76.'.~._~.3.6,0.9E .......... _0~_~_5_.---.-._5...,_~0__~_~-""'~'~_5.,~.~_~_79 .... 50 ~0 w 0.238 3,36 ~385 0 20 ~3~,-85- ..... ~28'~;7"5--"'N~3;-OOE .............0,'[7 S 3,85 W 3,85 S 87 22 ~3 ........ ~'~77 ...... 0 ..... i5 ......... ~7'~,~'5- -~376,75 ....... N66'*'oOE ................ O,og'N .......... 3'~7 W ............ 3e~7'~ N"-88 2~ 12''''w ............ 0',135- 'i~57 ...... ..... 457'~' 0-20 ....4570.85'-~70,75 S~5,00E ......... 0,01 N ..... 3,-02-"W ......... 3.02--N-89 ~--i8 ....................... --46-6'4 ......0 .... 50 ....... 4663,8~"i--456'3;"7~'-$61,OOE -- 0.56-$ ..... 2',26 W ............... 2.32 S 76 .... ~758 o ~5 -~757,8~ ~57,74 s2z,ooE ....... z,52 s "' z,~2-'w ......... 2,o8"s ~3 z ~'-w .......... o,534 2,oz ~85Z ~ 5 ~850.82 4750,72- S2~.OoE 2,9~ $ 0.88 W 3,05 S ~6 55 8 W 0.366 2,98 .... -~945 ....... ~ .......... 0 ...... 494'4.81 ..... 48~4,71'" $~8.00E ..... 4,53 S 0,3~ W ............... 4,5~ 5 3 58 59'-W ......... Oel~O 4,13 5132 1 0 5131.79 5031e-69 ..... S30.OOE 7e15 S 0.79 E 7J20 S 6 21 13 E 0e319 5e91 5'2~'~ .... %--30 ......... 5'22-3';"~8 .... 5i23;68 S36-;00E .............. 8,Z6'5 ......... Z'~5--E ....... 8829 S-Z~ ' 5 3 E 0,5~5 "5317 .... i .... 0 ...... 5316,77 5216'67 SlO,OOE ............9,27 S ..... 1,92 E .............9,47 S 11 ~2 55 'E ........ 0-,8~ 7,23 -~5-~11-'~!~"-~.0~ _5_~10~76 ..... 5310,66 523,00E- 1-0,8~ S 2,38-E ....... i1.10 5-12 25 11-'E ......... 0,2~1 8.39 _5599 ......0_..~0 ...... 55.98.73 __ 5~98,63 834,00E ....... 13,09-5 ...... 3.95"~E .... 13,67"5"i6 5787 0 40 5786,73 5686,63 SSO,OOE ~3,80 S 5,25 E Z~,77--5--20 ~9-Z? E 0,?0~ 9~6.5_ 5880 0 30 5879,72 5779,62 N?~,OOE -~3,97 5 6,1'~ ~ ....... ;15,2~ S 23 ~'-'5 E 0.507 9.35 ~-597~-'-~.30.~-5_973.72 "5873.62-N69.00E .... 13,6g S ........ 6,9Z--E ....... 15,33 S 26-47 37 E 6068 0 30 6067e72 5967.52 587.00E Z3.56 $ 787Z E ZSe60 S 29 38 6~60 0 30 6159.7~ 6059,61 S39eOOE 13e9~ S 8,'4~ E ~6,~6 S 3~ 9 6 E 625~ '_9_~0 ....6252,7Z 6152e61 S35e-OOE .... 16e78 S - 9eO6'E --- ~7,34'5 31 3~ 6-"E ..... 0';~7~ 8,67 _6~6._._1 .... O .... ~3~5;.69 .... ~245-'59._._~S._7,00E..~ ..... 16;16'~S'-/~_~.."~--9;59-'~_.._-..-]~.~ ..... ~8',80--S'"30 ~1 ~3 E ......... 0,596 9,63 . . .6~0_ .... ~Zo_._ ~39.6e'-~339_,-5e S_~.OOE Z7.e~ S ....... 9,.71_'E ...... 20.~0 s 28 653~ .....!_ _5__. 6530,66_.. 6430_,~6_ .S.~oOw .... 19,73 S 9,69 E 21,98 S 26 9 3 E Oell9 12,72 _~662~_._1._15 ..... 6623,6~ ..... 652.~_,.5~_ SIXeOOW ..... 21,61 S ........ 9,~5...E_ ........... 23e59 S 23 37 51 E 0,26~ ... ........................ RECORD OF SURVEY A'CL---CALcULATI'ONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE DOG_LEG MEAS, DRIFT. VERTICAL SUB DRIFT TOTAL COORDINATES C L 0 S U R E S SEVERITY D M DEG. D M S ............ . -,.. ....................... SECTION DISTANCE '-6~-i~-~- ~ .... 67'"17,62 ...... %"~i'i";~ ........ S~4;-~OW ............ 2~;~7'-S 8.90 E 25.01 S 20 5i i8 E 6811 1 30 6810,60 6710,50 S12,00W 25,~0 S 8,2~E ............26,62 S 18 7..11 E 6998 1 30 6997,55 6897,~5 S18,00W 29,60 S 7,67 E 30,58 S 14 32 1 E 7090 1 45 708~.~1_ 6989,4~ S2.1_,OOW 32,06 S 6'80~E .............. 32,7.7_.~_...11 .... 58~.50 E ~"~85 ..... ~'"~45 ....... 7182.~7 .7082"-3~ ........ S28,00W'~ ........34,6~ S ~,62 E 35.09 S 9 13 29 E 0.~2 0,~13 20.29 0,6~7 22.36 0.292 2~.~__ 0,230- 27,76 30.37 7275 1 30 727~,43 7174.33 $31,00W 36,91 S 4,~4 E 57,16 S 6_~2__~ E_ ....~_.e~3 --7~6'6 ..... ~--~'0 ...... ~67.4o .... 7~67.~0 s~5.00~'-" ..... 38.8~ S 3.08 .................. E 38~96,~s .... 4_~2 ~6 E 0.i96 -~746f 1"=30 7~60.~7 ....... 73'60.27 .... S2B,OOW ...... 46,80 S 1,86 E 40,8~ S 2 37 8 E 0,248 ---7-55~ ...... ~--15 ...... 7553;3~- 7~'53-;'25----5~0'"00W--~ ..... ~-2-,7~'-'~ ............ 0.76 E ...........42075-S-1 ...... 1--43-E ......... 0.270 763~ ! 2-0 ?~'-~;'2'~ ..... 773~-'19- s~8;'00~ 46.~77-s ....... 3.~1 ~ .... ~6.a?-'s .... 3-"48--%6 w 0.22~ .................................... 792-7 ........ U .... ~ ....... 7926.27 7826.17 S~.OOW 48.1~ $ ~,37 W 48.39 S ....... 5-'-ii -~-~ .... 0;421 --"~02d .... i"-~-~ ..... 80~9.2~ 7919'~ $52'00w ........ 49.51 $ .... 5.62"W ............. ~9.8~"$' 6-2~-~'-~ ........... ..... 8~f~---i'--~-5 ..... 8~3.2~ ..... 80~3-.1~- ssO. oow ...... 5'0.80"$ ........ 7.21'-~ .......... 5~.~--s .... 8 ..... ~--i2-~ ........ 0.046 ............................................. 8208 ! 20 8207.2! 8!07.!1 S4~.OOW 52.25 S 8.77 W 52.98 S 9 31 ~5 ~ 0.182 ..... 830'0-' .... ! 20'--8299.18 ......... 8!99.08 ssf, oow .....53.7d=~s ......... 10,:~5-~'-~ ........ 5~;69 s'~O~'5~-~'5-w 0;i7~ ............................... 8487 1 5 8486.15 8386,05 S3~,OOW 56,~3 S 13,01 W 57,62 S 13 2 58 W 0,396 --~8'f-£'i'0--8~80.~3 ..... a,80.03 ..... s58.00w ...... -~7.~1 s ..... 14.3~"~ ............ ~9.~7-"s"i$--1":='~-w- .......... ..................................................... 8766 1 20 8765.08 8664,98 S50.00~ 59,87 S !7.71W 62.44 S 16 29 0 W 0,101 8858 0 50 8857.06 8756,96 S~7.OOW 61.03 S 19.02 W 63.93 S 17 18 53 W 0.5~5 ---895~- '~ ..... 5 895-0.05 8849.95 '-S~9,00W -' 62,18 ~' 20,09 W ..... 65.35 S 17 5~-3~--W .... 0.326 .............................................................. 9045 I 15 9044.03 8943.93 S36.00W 63,70 S 21,26 W 67.16 S 18 27 31 W 0,186 9139 ! 0 9138.9! .... 9937,9! ..... $32,00W ...... 65,2~ S .... 22,29 W .......... 68,9~ S 18_52_~0_.~ .... 0,27~ 9233 0 45 9232,00 9131.90 S~7.00W 66,41 S 23,10 W 70.32 s 19 11 ~ w 0,273 - - 9326 1-- 0 932~.99 9224,89 S25-,00W ..... 67,63 $ ..... 23,83 W 71.71 S 1~-24 59 W 0,372 32,67 ~4.97 37,20 39.01 60,69 ~2,60 ~6,20 ~8.09 50,11 55.5~ 57,30' 59.08 61,08 62,72 6~,2~ 66~.J~ 67.97 69,/-+0_ 70.81 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER . TRUE DOG LEG ~"~-X-~i~'.'~ R'-I '~-Ti.i~i"iV E R T ! C A C ......... $ I~B ........... DR"~: F T'.~S'~i-~"~i.:-'_~_i._T, o T'AL_ ~ c~ o ~D_~"'~'A .f_~'SS'~' ,,_ ~_ c'-r'L"-0.."' .S.' ,.U~ ',~.E ~"~S"~'~ ~'__~'_~"~'~ E V E ~ Z T..~_.'~ ........ S E C T Z ON DEPTH ANGLE DEPTH ............ SEA"-' ......... DIREC D I STAN_~.E_ .......... A~G~ ...... PEG.~_.i.O.~_~T .... DISTANCE ............. D M ................ ~ ....................................... :DEG. D M .... ~4-2~ .... ~-'1-5- .... 9'4"18;9'7 ...... 9~18';8f ...... s~O;oow ........ 69,~8-"'S ...... 24,82'--W ....... 7~;50 ....S-19-44-'28 W 0,~69 72 9~1~ ~--~5 ...... 951~-~5 9~.85 SD~".00W 70.56 S 26.D0 ~ 7~.~1 S 20 26 ~6 ~ 0,~28 9606 0 50 960~.9~ g50~,8D' S32.00W 71.79 S 27,~ ~ 76.87 S 20 ~ ~1 ~ 0.~22 76.20 9699 ~ 20 9697.92 9597.82 S4~,OOW 7~.20-"S ........... 2B.5~ W 78.56 s 21 17 ~4 W 0.6~6 77.9¢ 9792 1 ~0 9790.89 9690.79 S~.OOW 75.01'--S ......... 29'95 W 80.77 S 21 .... 45 5~ W 0,~ 80.21 '-~'9885 ........ 1" 5 ....... 988~8~6 ........ .978~76 s~7'OOW ....... 76.7~ $ ............ ~I'i15':'W ............ 82.8~'~'S-'22 .... 5 .... 52 W 0~4~6 82.~0 .... 997~ ~ i0'-- 9977.85 9877.75-- S~5.'OOW .... 78'1~'--"S ................ ~2.~7-W ......... 8~.57-s-22 ~0--15-W ....... 0'~i-99 8~.11 ~0072 1 20 ~0070;82_..9970';72 S38;'00w 79.65 S 3~'7i'W ........ 86'50 s 22 56 ~5 w 0.262 86.09 -'10'16'5 .......... ~ ......... 0 1016~.80 .... 10063'~:70 ...... S46.00W ........... 81';06""S ......... ~4.98'-"W ........ 88'29-S-2~"'20 ~2-"~ ......... 0';~87 87 -10257"- 0--55 .... 10255,79 10'15~.69 S22"00W ..... 82.~4 S .... ~,8'4 W ......... 89;80 'S--2~'"3i'-~5"W ........ 0'4'~ .......... 1-03~0 ...... ~ ...... 0-10348.78 ~0248,-68 .... S20.00W ..........85.80- S ~6.41 W .... 91.~7-'S' 2~-'--'29 .....0 W ........ 0'.08"~ ........ 9~.02 10~4~ .... 0"5'0 10441.77 10~1,67'-S~2.00W 85.14 S ..... ~7.06 W ........... 92.'86-S'"2~-'~1-"25"'~ ..... 0,244 -105~7 .....0-'-A5-'i0535,76 i'0~5~;-66- 'S~O.OOW 86.~g-S ..... ~7.83 W ..... ~.1~-S 2~'-~1' ~2 ~'- '~-,~'-~2 ~06~0 ....0 30 10628.75 10528.65 S6~.OOW'- 86.82 S ........~8,61 w -' - e5.02 $ 2~' 58 '~2-~ ....... 0.~19 .................... 1072~ "0 15'10721'75 10621.65 S81.00W .... 87.01' S ........... ~9'19mw .......... 95.~3-S-'2~' 14' 56-W ........ 0'275 95.17 10817 .... 0 ~0-10815.75 10715.65 $52'00W .... 8~'25 S ....... ~9.75-W ....... 95.8B- S 2~ 29 ~6-W ........ 0.~7 95.65 10911 0 5 10909.75 10809;65 N55.00W 87.26 S ~0.20 W 96.08 $ 2~ ~4 8 W 0.~'38 95.q7 11005 '-'0-35 11003;74"~0903'6~ .... $48,oow ...... S7.29-S ...... '~0',72 W ........ 96.33 s 2~ ..... 0 2'~W ....... i';557 11099 --0'-~0' 11097,74 10997.64 .... N8oeo-OW ...... 87.57' S .........41.68' W ........ 96.98-5 25 27 .... 6 W 0.693 ~'6~8~ 1i~-92 0 10 i1190~73-11090'.63 .... S22.00W ......... 87".88"S .......~2.23 ~ ..... 97,5~--s 25---40'--~-W ...... 0,5¢7 97.~8 --~285-' 0 15 11283.73 1~183.63 NSOeOOW ..... -87.95 $-' 42.51"-W ....... 97.68 S 25-¢7~5'6-W .... O~Og i1-32~--'0'-'45 11321.73 11221.6~ N32.00W .... 87.70 S ...... ~2.7~'W ........ 97.55 s 25-58--~8 W' -'~.611 '"f~-~-i'7-'--0--45--~'i~5'-72 .... ~3i5,62 'N28*oow .......... 86.63--5 - ~3.~¢'W ........ 96.87 'S-26--3¢-'~9-'-W--- 0"056 96,82 '"115i"i'--0 ..... 15--'l'1509;TZ"l'1409'e-6'E-"N~2;OOW ......... 86.0~5 ....... '~3"87 W 96;5~-S"27 .... i-E5 W 0;5:~5- 96.52 '1i605 .... 0 15 1160~.72' 11505-;62 ..... S62'.00W 85.97~ ........ ~.25-W ..... 96.70 S-27-1~' 12 W .... 0.290-- 96.6'~ --i--i699 0-15-11697,72 1159~62 N6~-"OO~ ........ 85.99---S ............ ~65 ~ 96,8~-S--27 26-26 ~ 0~229 96.88 1i~93--0-'"15--1179i~.72-1169-i~62 .... N3B;oOW --~ 85.7~ $ 44.97 W .... 96.82"S'27-40-~7-W ........ 0.1~.~ 96.81 11~87' "0~5 i1885;72-'i'1785.62-' NgO.OOW ..... 85-'57 ~ ..... 45-.~'~ W .... 96.84-5 27-54-g~"-W -~-'-2~ 96.8~ RECORD OF SURVEY ALL CALCOLATIONS PERFORNED BY I B N ELECTRONIC COMPUTER TROE ....................................................... DOG_LEG MEAS. DRIFT VERTICAL_'_:_:_'"':_':SU.B_'::: .... _DR_IF~_:--_:_:~:::.TO.TAL ~O.ORDINAT'E$ ................. ~'"L-'O $"0""~"'"~"~ ............SEVERITY SECTION DEPTH ANGLE DEPTH SEA DIREC --- ' ............ DISTANCE ............A'NGL~ DE6/looFY - DIS"YANCE ............... O ~ ......... ; ............................................ DEG', D ~ $ ............... ~o~ ..... o ..... ~'"'-~o~,;'~'~--z'~,~;~-- ~'~o, ........... ~'~'--'~- ~'.oo-, ............ -"-~" ~-"'~'~'-'-~"~ ~'"-~ o.~ .............. ~ -i~i69 ........0-'10 12167.71-12067.'61 S~2,00W.......... 85.57 S --~6,~0'--'~ ............ 97e29 S-"'28 25.... i"W ....... 0,257 97 '-,-~9 12263 0 15 12261.71 12161,61 N 5,00W 12357 0 15 12355,71 12255,61 S13,00E- '12545 0 45 '12543,'~1-12443,61 ..... S46.00W ............................. 12639 0 15 12637.70 12537.60 SIO.OOW 8~.46_..$ ........... ~6.28 W ............... 9.?.1~_$.._.2~_.26!9 W 86,07....$ .............. 46,29 W .............. 97.73 S 28 86,94 S 46,81 W 98e75 S 28 17 49 W 0.582 . . 87,66 $ 47,19 W 99.55 S 28 17_ ~0._~ ........ 0,538 97,36 97,19 98,74 99.55 12733 ..... 0 15 t2731'.70_.126D'tleo ......... $15.00E ............. 88.06 $ ........ 4'7.171. W ..... 99.90 $"~8 12827 0 30 12825,70 12725,60 S78,00E 88e47 S 46,74 ~ 100,06 S 27 51 7 W 0,82.~ ........ 100~.0_5 '-'1292~ .... 0 3'0 12919,70 12819.60 N32.00E ............ 88,17"'S 46.03'-W ........ 99.4~.S_27 34 19"w ........ q,.610 9~.~__~ _ ~_~'o_~'~i'":~:-~-~_..~o ~, e~'- ~z~ ~_..~:-- ~'e'Oo~-'~il .... 8 ?.~ S .......... ~e. ~'7__~:]-:-,.~'_.~e. ?o .s_._z.? ~. ~27__~ ............ ~.~e~ ............. ~..6L 13109 0 30 13107,68 '13007,58 N62,00W 86,64 S 47,00 W 98,57 $ 28 28 50.._~_ .......... 0,286 98,57 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, TRUE .~tEASURED VERTICAL SUB MD-TVD VERTICAL ~g_B._TH ................ _DEPTH_ SEA DIFFERENCE ...... CORRECTION TOTAL COORDINATES _3_0__0__ - 300; . 200 0 0 0,92 $ 400 400, 300 ......... :0 ................ 0 ............. 1,18 5 500 500, 400 0 0 1,75 $ 600 600, 500 0 0 2,57 S ?00 700, 600 0 0 3,15 S ...................... 800 ................ 800. 700 ...... 0 ......... 0 4.16 S 900 ................ 90o, ...... 8_0.0_ ............... 0 ............................ 0 ............................ 5, I t._$ lO.P.~ ..................... 1000. ...... 9.00 ........... 0 ................. 0 ......... 5,89 s 1100 1.100, 1000 0 0 6.41 S 1200 1200, 1100 0 0 0,77 E 1,35 E 1,78 E .._ 1.32 E ... 0,16._..E 0,64 W 1.3.!_.W 1.94 W 2,57 W ............................................................................................ 6.525 ............ 1~0 1300, 1200 0 0 6,27 S 3,72 W 1400 .................. 1400, ....... 1300 ............ 0 ........................ 0 ...................... 6,09 $ 4,1I.~... 1500 1500, 1400 0 0 6,00''$ ......... 4,54 W 1600 ................ 1600, ~_1500 ...... 0.. ........... 0 ........ 6,03 $ 1700 1700, 1600 0 0 6,16 S 1800 1800, 1700 0 0 6,38 $ ..................................................... 1900 1900, 1800 0 0 6,69 S' ........................ . 2000 2000, 1900 0 0 ?,07 S 2100 2100, 2000 0 0 7,49 $ 2200 ......... 2200. 2100 .... 0 ...... 0 7.92 $ 8,35 S ........... 2400 2400, 2300 0 0 8,66 $ ...................................... 2500 2500. 2400 0 0 8.90 S ............................................... 2600 2600. 2500 0 0 9.06 $ 2700 2700, 2600 O' 0 9,04 $ ..... 2.800 ....... 2800, __2700 ............ ~ ................... 0 .............. 8,98 $ 4.98 W 5,39 W 5,76 W 6,07 W 6,29 W 6,41 6043 W 6,34 W 6,25 W 6,37 W . ._ 7,02 W 7 8.49 W 29_00 ................ 2900, ......... 2800 0 ................... 8.84 3000 3000, 2900 0 0 8,91 3100 3100, 3000 0 0 8,95 3200 ............ 3200. ..... 3100 ........ 0 ............. 0 .... 9.02 3300 3300, 3'200 0 0 8.65 3400 3400, 3300 0 0 7,88 3500 3500. 3400 0 0 7.03 3600 ..... 3600, 3500 0 0 5,99 9,42 W 10.01 W 10,40 W 10.83 W 11,03 W 10,86 W 10.51 W 9,84 W MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, TRUE ' HEASUREI~' VERTICAL SUB MD-TVD vERTICAL .................. DEeP TH ......................... D E:_._P..~H .... $ E.~.~.D.[.F...F_.[.g E~_CE ............ CORRE C.T ! ON ........ .TOT AL ....COORD :INA TE $ 3900 ~900l ~800 ......... 0 ............................... 0 ............. ~.~7 5 7,76 ............. ~000 ........... ~000, .... 3gO0 0 0 2,8~ S .............. ~100 ~100, ~000 0 0 2.05 ~ ~200 4200. 4100 0 0 0,~ $ ....................... 4~00 ................ ~300. ...... 4200 ...... 0 .............................. 0 ................................ 0;~5,~S- ........ 4.~8 ....................... 4400 .................... 4400, 4~00 ......... 0 .................... 0 ..................... O, 1~" S ................. 4500 4500, 4400 0 0 0.12 N ~,~7 4600 4600, 4500 0 0 0,12 S ............ 2,87 .................... ~700 .............. : ..... '4VO0' ..... 4~600 ............... 0 ................. 0 ......................... 0,86 S .................. ~00 ............. 4~00-. ...... 4~00 .......... 0 ......................... 0 .................................... 2.0~'-~- ............ ................... ~00 ....................... 4900'~ ........... 4800 ............ 0 ........................ 0 .................... ~, 77"-S ............. .................. 5000 .............. 5000,'" 4900 ..... 0 .......... 0 ........................... 5.~7 S 0,02 5100 5100, 5000 0 0 6.68 S 0,54 ................. 5200 ............ 5200. ...... 5i00 .............. 0 ......................................... 0 ......................... 7,97-'S .......... ~,~ ...................... S~O0 ............... S~.O0, ....... ~200 ............... 0 .................................... 0 ................................................. ~,O0'-S ............... 5~00 5400, 5~00 0 0 10.67 S 5600 5600. 5500 0 0 1~.10 ~ 3e96 .......... 5800 5~00, 5700 0 " 0 l~,Sg S ............ ~ob ................... S~oo;'~ '- seoo o o xs-.~X'-'-s- ......... ~,~o ..................... 6000 6000, 5gO0 .0 0 1~,62 S 7,13 6100 ............ 6100, 6000 ........ 0 ....................0 ...................... 1~. 61_.~ ...........7.99_ ............ 6200- 6200. 6100 0 0 14.23 S 8.66"E ...... 6~0o ............ 6~oo. 6~o0 .... o o ~?.'~S 6500 6500. 6~00 ....... O_ ................O. ~9.~3 5 6800 ................. 6800. ..... 6700 .........0 ................... ~ ........................... 25,02 5 ........ 69'01 .............. 6900. 6800 ...... ~ ....................... 0 ................... 27,-~7 -"S .....8.0~ 7oO'i ......... 7o0o,- - '6~oo ........ o- ................ o ...................... 2~.66'-s ...... .......... ~0~ ..... 7~oo. 7ooo ...... o : ........................ o ......... ' .............. ~. ~6'-s ..... N E A-S-OR E~- .......... Vt~RT Z CAE-SUB ..... ND'~gD .................. ~ERT'X'CAL ................... DEP'TH .................... DEP-TH SE..~,-_ D~[F F.F_R E,~"~.,~ .......... CORR E ¢! ! QN...i-i,~'-_~--_?~'OTAL~i ..... CO0-R D ! N~_TE $ ........................... gO01 9101 720.~ ..................... 7200, .......... 7100 ............. 0 ........................................... 0 35, l!._.S 5.37 7301 . 7300, .......... :.7__200 0 . . ............ 0 ............................... 37,/+7 $ 3,99 7/~01 7400. 73'00 0 0 39./+9 S 2.65 ........................760~ 7800~ 7~00' .................. 0 ................. : ........................................................ 0 ~S& ........................................ S 0~25 F :--"/i_.'7 7of-- ' - -_~::L7 7 o'o ~ '~' ..- .... ....... ..................... 7eo.1_ ............... 7eoo. ............ 77oo 790~ 7900~ 7800 0 0 ~7~80 800~ 8000, 7900 0 0 ................ e ~o ................... [- ......... '~ .......... ~ ~ o o_,;:'];'h:~~ i o0-.~-~i'2 ~_~ 8~0~ 8~00~ 8200 0 0 ~7[ S ~O,D7 8~01 8~00, 8300 0 0 ~.97. J ............11_,95 8601 8600. 8500 0 0 57.63 S 1~.68 8 vo ~ 87o"o'; ......... ~-~b'O- ......... -0- ............... 0--;: ................. 58. e~ S- ~-.'52 e-soz .... .sOo; ........ 87oo o 9201 9301 9z+O1 9501' 9i00. 9000 0 9601 9701 9E31 9200. 9100 0 9300. 9200 1 ' 9400? ........ 9300 ! o 9500. 9400 1 0 __ 9600. 9500 I 0 9700. 9600 1 0 ........ O- _ ............... 6~_.., 6/+. S ......... 21;_92 0 .. 66.06 ,5 22.8/+ 1 67.25 $ 2 3.6~+ 68.86 S 24.57 70./+0 S 26.09 71.73 9800. 9700 I 0 9901 9900. 9800 I 0 10001 10000. 9900 1 0 10101 10100;' 'ioooo ......... 1 10201 10200, 10100 1 0 10301 i0300e 10'200 I ~0 ......................... .83.01 $ 36~11 W 1.640! 10~00. 1030'0 I ':-- ..... 0 10601-- -10500' .... 10~.00 -- o- = .............. 86.69-S ....... 38';~'7 w 73,23 5 28,56"W 75,20 $ 30.07 W 76.97 `5 31.34 W 78.46 S 32.68 W __ 80,15 S 3~.12 W 81,53 S 35,39 W MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. TRUE ........ MEASURED VERTICAL SUB MD-TVD VERTICAL .......... 108Q1_.;.. .......... 10800. 10700 1 0 87.18 10901 10900, 10800 ............... 'i .............................. 0 ............................. 87.2'9 11001 11000. 10900 1 0 87,28 S 40.67 ......... 1i101 ............... 11100, 11000 ....... ~ ...................... 0 .....................87.57 ................................. . ............................................................................................ 11201 11200, 11100 1 0 87.90 11301 11300, 11200 1 0 87.88 $ ~2.58 11401 11400, 11300 1 0 8~.82 $ ~3.2~ 15o1 115oo. 11601 ............ 11600, 11500 11800; ll?O0 11900, 11800 2ooO' .... 1 9oo 12100. 12000 12200; .... 1-2100 12300.' 12200 11801 11901 12001 12201 12301 12300 1 0 2500. 1'2400 1 0 2600,.. 12500 ......... 1 85,97 S 4~,24 W 85e99~$ ........ 4~;-66 W 85,72 $ 44e99 W 85.60 S 45,7~ W 85,.47 $ 46,09 W ............. 85.62 $ 46,38 W ............ 85,37 S ~6,47 W 85,70 S 46.,26 W 86.52-S 46e~9-W 87.42 $ ~7.1~ W 12~01 12~00. 12501 12601 1 1270-1 ............1 12801 1 12901 1 13001- 1 13101 1 2700~ 12600 ............ ~ ......... . 0 ................ 87;93 -$ ...... ~7"-19~ 2800. _.1279~ ........ ! ............................. 0 .......... 88,37 'S ..........~$,93 W 2900. 12800 I o 88.3o'"s ............. 3000. 12900 1 0 87,84 ~ ~5.30 W 3100. 13000 I 0 86,68 $ 46.94 W . INTERPOLATED VALUES FOR EVEN 1000 FEET OF . TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA TOTAL HEASURED DEPTH, COORDINATES 1.94, W 6,29 W 10,01 W .. _ · .. ' ..... ~ ',?:_: ' ~_'~J .-~= ....~' L:_:'.:L"~ ..... ].7- : ........ =:..~:. _._? _ '" " ~ ' -' ...................... 1000 .................. 999. 899. 5.89 ............... 2000 .......................... 1999. "1899, ..... 7.07 3000 2999, 2899. 8.91 5000 4999. ~899. 5,37 ............ :'6000 ......... 5999. 5899, 13.62 . . 7000 6999. 6899. 29,65 8000 7999. 7899. 49,23 9000 8999. - 8898. ......... 62,94 I0000 9998. 9898. 78.44 11000 10998. 10898. .......... 87'28 12000 11998, 11898-. .... 85,60 7.15 W 0.02 W 7,13 E 7.65 E 5,30_,W ........................................................ >_ 20.69 W 32.67 W 40.65 W ................................................... 45,73 W 45,32 W : '"'~?"'~MOBIL 0 IL CORPORATION P. O. BOX 5444 DENVF_R~ COLORADO 80217 D!V:SION O~: OIL AND' GAS ' ANCHORAG~ DATA TRR'AN~:H Donahue ITTAL RECORD TRANSFERRED TO: State of Alaska, Department of Natural Resources, Division of Oil and Gas, 300t Porcupine Drive, Anchorage, AK 99504 TRANSFERRED BY: R. T. Donahue DATE: 6/6/75 DATA DESCRIPTION Mobil-Shell West Staines State #2, (Sec. 25-9N-2.2E, North Slope, Alaska) Eastman Directional Survey 2 copies Well Completion Report Form #P-4 BHC Sonic 2" & 5" (composited) i blueline print I sepia DIL 2" & 5" (composited) ! blueline print I sepia FDC 5" (composited) ! blueline print I sepia FDC-CNL 5" (compos. ited) ! blueline print I sepia ~4~ .... Z~e. PLEASE CHECK SHIPMENT THEN SIGN AND RETURN ORIGINAL e~3PY DescriPtors to include when applicable: Number copies or copy numbers 2. Type of print: Field or Final 3. Type of copy: Film, Sepia, BIueline, Velum 4. Series, Sequence or Interval Numb~ r s F~rm No. l~'V. 3- 1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 0IL ~-~ GA8 --,~L .~,.L E~ o?H~, Will dcat '~.NAME OF OPERATOR Mobil Oil Corporation 3. AD~)RESS OF OPERATOR P.O. Box 5444 TAt Denvert CO LOCATION OF WELL 80217 SUBMIT IN DUPLICATE AP1 NUA{ERICAL CODE 50-089-20004 6 LEASE DESIGNATION AND SERIAL NO. ADL 28377 ? IF INDIA],~, ALOTiEJ~ OR TRIBE NAME 8. L,~IT FA.P~ OR LEASE NAME 848' South and 50' West of NE Corner Sec. 25-9N-22E UM, Alaska Mobil-Shell West Staines State #2 10, ¥1~:~.D ~ND POOL, OR WILDCAT Wildcat 11. SEC.. T., R., M.. (BOTTOM HOLE oa,mCTn~ Sec. 25-9N-22E UM 12. PIS~RMIT NO. 75-0002 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA~NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLLrNIES USED. pERFORATIONS. TESTS AND RESULTS FISHING JOB& JUNK IN HOLE A.ND SIDE-T'RACKED HOLE A.N'D ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 5/I/75 to 5/21/75 Drilled 8 I/2" hole from 12043' to 13171'. 5/21/75 to 5/24/75 Well Surveys. Ran Schlumberger. DIL, BHC Sonic, FDC-CNL, FDC, and Dipmeter. Took.Sidewall Cores and ran velocity survey and directional survey. 5/24/75 to 5/26/75 P]_ugg_e_d_.__~ell for abandonment. Set I00 sack cement plug from 11,170,-1i~;370,',-se~ 9 5/8,, HOWCO EZ Drill at 3000' capped with 40 sacks of cement. Opened f/o collar at 2,379' and cemented with 40 sacks Arctic set. .Opened f/o collar at 2,223' and placed Baroid Arctic Pack between 9 5/8" and 13 3/8" casing. Placed diesel in 9 5/8" casing from 2,279' to surface. Set 50 sack Arctic set cement plug at 2,397'. Set 9 5/8" EZ Drill at 150' and capped to surface with Arctic set cement. Surveys: 12643' 3/4° S 7~ E. . DIR - 1 ENG" 2 ENG ~ CO~FER: ,, J 14. I he.by ~ify~t th~,forego~ ~ ~e ~ ~ S~G~_ . ~ Alaska Area Geologist n~ 6/3/75 I Form P--3 $~bmlt "Intentions" in "l'riplicat, e ,,,,~. F~EV. 9-3&-69 & "$ub.~equen[ Reports" m Duplicate STATk OF ALASKA OIL AND GAS' CONSERVATION COMMITTEE (Do not use this form /or proposals to drill or to dc.' pen Use "APPLICATION FOR P'EI~iIT-2-' '' '/or such 'pi:ol~osals.) Wildcat OIL ~ GA~ %tELL ~ WELL ~ OTHER 2. NAME OF OPEtL&TOP~ Mobil Oil Corporation ADDRESS OF OPERATOR P. O. Box 5444, TA, 4. LOCATION OF W~L ^t~.-:~o~ Approx. 848' corner, Sec. Denver_x_Colo. 80217 S & 50' W from the NE 25-TgN-R22E, UM, Alaska ELEVATIONS (Show whether Die, tIT, GR, etc. 95' (DF) 14. Check Appropriate l~x To lndk~te N~ture of Notice, Re 5. API ND'MIFJHC'Ai~ C'Oi.~E AP1 ~50-089-20004 ADI.-28377 ~ Wildcat li. SEC., T., Il.. -M., (LIOTTO~I Sec. 25-T9N-R22E, 75-0002 .. ~o~, or Other Dete U.Mo NOTIC~ OF INTENTION TO: SUBSEQUW-NT R~PORT OF: ~ WATER SIIUT-OFF : REPAIRING WELL TEST WATER 8HUT-OFF [ I PULL OR ~LTER CASING ~ 'i [ ] . FRACTURE TREAT --{ [ ABANDON M gh, T· SHOOT OR ACIDIZE ABANDON* [X ~ S~OOT1NG OR ACIDIZING REPAIR WELL CHAN0~ PS&Y8 , ~ (Other) { (NOTE: Report rew~Its of multiple completion on Well , Other} .... , Comple~ton or Rec,..mpletlon Report anti Log form.) !5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clenrly state all pertlnm;t details, and gte,, pertinent dates, In¢lud!ng eatlmated date of sear'ting any proposed work. Due to absence of hydrocarbons, we propose to ab~don the well. The proposed abandonment procedure is attached herewith. P.K.Paul discussed this procedure with Mr. John Miller on 5-23-75 at 11:05 a.m. (Denver time) by long distance telephone and Mr. Miller gave verbal approval to the attached procedure. Other pertinent details are: Total depth 13,171' 9-5/8" Csg. shoe 11,270' 9-5/8" F.O. Collar (1) 2397' (2) 2223' 13-3,/8" Csg. Shoe 2275' Formation tops: hereby eertlZ.7,._..that ~b~vfore~olng i~ tr,ue~nd ?orrect (Thl~ ~pace for State o~c~ use) ~-4 , A~roved Copp Refund ~ Instructions On Rever~ Side Base Permafrost 2050 Coaty Bluff 6920 Cretaceous Fishbone 12,400 Devonian Argillite 13,130 1,:io_j _l: X)XTr 5 '" 2 3-7 5 WEST STAINES STATE ~2 ABANDONMENT Procedure 1. Run open ended drill pipe and set a 200' cement plug from 11,170' to 11,370'. 2. Run in hole wi~h a 9-~5~8" retainer or bridge plug, set at 3,000' +- and cap with./tS~~ cement plug. 3. Run drill pipe with packer and HOWCO full opening collar opener. Open HOWCO full opening collar at 2397'. 4. Cement outside 9-5/8" casing from 2397' to 2250 5. Immediately come up and open HOWCO full opening collar at 2223'. Set packer. Flush and clean 9-5/8" x 13-3/8" annulus with water until mud is displaced and cleans up. Place "Baroid ~A?cti_ ~c~Casing Pack" in the annulUs. Release packer and immediately close F.O. Collar. 6. Cement with 50 sacks of cement from 2397' to 2297". 7. Displace with Diesel from 2250'± to surface. 8. Set a bridge plug at 150' and cap with cement to the surface. 9. Seal all annuli with valves with bull plug and 9-5/8" casing housing with blind flange. P. K. Paul 5/23/75 DIYf$tON CF (~lJ. A/~D ~A~ C_ T, /O;, 2_-70 7-/P '/ ~,, f T / l~,rm No. P--4 REV, 3-1-70 SUBMIT I:N DL~PLICA'I~ -- ~. AP~ NmVmmCAL ~ODE 50-089-20004 6 LE, ASE DESIGI~ATION AND S:Et:~IAL NO. STATE OF ALASKA OIL AND GAS CONSERVATION COMMII-rEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS O;L [] G,s [] o?,=,--. Wildcat WELL WELL 2. NA~.'. oF oPm~ATOR Mobil Oil Corporation 3. ADDRESS OF OP~ATOR P.O. BoX 5444 TA, Denver, CO 80217 4. LOCATiON OF WELL 848' South and 50' West of NE Corner Sec. 25-9N-22E UM, Alaska ADL 28377 i? IF INDIA~ A~T~E OR TRIBE NAME 8. L~/IT FAR~ OR LEASE NAME Mobil-Shell 9 WELL NO West Staines State #2 10. FIKL~ ~ND POOL, OR WILDCAT Wildcat 11. SEC.. T., 1~., M.. (BO'ri'OM OB.rF, m-rv~ Sec. 25-gN-22E UM 12. PERMIT NO. 75-0002 "13. REPORT TOTAL DEPTH AT END OF MONTH, CI-L~'~GE, S IN HOLE SIZE. CASING AIN-D CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED. PERFORATIONS. TESTS A.ND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 4/30/75 Depth 12,043 - Drilling 8 1/2" hole .Drilled 12 1/4" hole to 11,300'. Ran.Schlumberger DIL, BHC Sonic, FDC, CNL-FDC, Dipmeter logs. Set 9 5/8" casing (50 its 47# 395 and 227 its 43.5# S95 LTC) at 11,270' cemented with 650 sacks class G cement with 18% salt. Surveys: 7583' 8565' 8871' 10179' 11700' 11285' 1© S22°E 1o s38Ow 1/4° S49°W 3/4© N62oE 1/4© 372Ow Eastman Multi Shot Coordinates 87.95'S and 42.51W . closure 97.7' S 25© 48'W ANCHORAGE 14. I hereby certify thai,, the ~fegoing/i~ true a_nd correct . L Alaska Area Geologist o.r~: 5/2/75 NOTE--Report on this form.is required for .each calendar month~ regardless of the status of operations, end must I)o filed in duplicate with the oil and gas conservation committee by tho ISth of the succeeding month, unlem Otherwise directed. l~rm No. P--4 REV. 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMI'I-i'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT IN DUPLICATE ~ AP1 NUMERICA. L CODE 50-089-20004 LEASE DESIGNATION AND SEHIAL NO, ADL 28377 1. ? IF INDIA~ AL~TTEE OR TRIBE NAME O,L ~] o,, ~] o?-z, Wildcat WKLL WELL 8. L~IT.F~ OR LEASE N~E ~obil-5hell 2. NAME OF OP~%A. TOR Mobil Oil. Corporation 3. ADDRESSOFOPERATOR P.O. Box 5444 TA, Denver, CO 80217 4. LOCA~'6N OF WELL 848' South and 50' West of NE Corner Sec. 25-9N-22E UM, Alaska g WELL NO West Staines State #2 10. FLEI2~ AND POOL. OH WILDCAT Wildcat ' I1 SEC'., T,, P~., M.. (BOSOM HOI~ om.mc-nv~ Sec. 25-9N-22E UM 12. PERMIT NO. 75-0002 REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AN'D VOLUMES USED, PERFORATIONS. TESTS A1VD RESULTS FISHING JOI~S JUNK LN HOLE AND SIDE-TRACKED HOLE A.ND ANY OTI-EER SIGNIFICAT~[T CI-IANG]/~ IN HOLE C~)NDITIONS. 3/31/75 Depth 8060' Drilling 12 1/4" hole Spud 8:00 a.m. 3/8/75 30" casing set at 74' w/255 Sx 20" casing set at 787' w/4380 Sx 13 5/8" casing set at 2275' w/3875 Sx Drilled 17 1/2" hole to 2412' and ran Schlumberger DIL and BHC Sonic logs r,2!V~',~l:L.i~ CF OIL AFtD OAS ANCH©RA~ "i4. I 'h~eby cqrt, ify~ the ~'~egotng~s true ~ szG~ ~ ..Alaska Are~ Geologist DA~ Ill I I I i ........ ~0TE --Report on this farm is required for .ea~ calendar ~th~ regardless of the status of operations, and must ~ tiled in duplicate wit~ t~. oil and gas conservation commiflee bythe IS~ of the suee~ding ~n~, ~le~ otherwise directed. M-EM,ORANDUM State of Alaska DATE: FILE NO: _ April 2, 1975 TELEPHONE NO: SUBJECT: Fteld Trip- BOPE Test on Mobil - W. Statnes State No. 2 North Slope. March 21, 1975 ! traveled to the North Slope..~to test blowout preventer equipment and check dr!lltng~ operations at the captioned.exploratory drtlltng well. ! departed Anchorage by Wien commercial aircraft at 7:40 AN for Oeadhorse arrtvtng at 9:30/Lq. The weather was-31eF, calm and high overcast. ! found two Sweco representatives headed for Pa~ker Rtg No. 96 and Introduced ntyself. They were rigging up the desander on the rtg and had to watt for a free fork- l tft to put a 400 pound part aboard the Mobtl contract twtn Otter that serves the rlg on Mob11 - W. Statnes .State. No. 2. Ne departed Oeadherse tn the twtn Otter at 10:25 AM and landed on the ice atrstrtp adjacent to the well pad at 10:50 ~AM, ! met the Mobtl drilling foreman, Ken Sullivan, and we had lunch together whtle discussing the BOPE test, and drtlllng progress on Hobt1's two north slope wells. . Ntppling up was in progress so.. after lunch I walked around the area and through the rig and buildings.. There was an area cleared adjacent te the drill .pad which wa~ being used., to store palets and crates of drilling mud. This offpad use was satisfactory. The reserve pit was extremely large and deep. A small shall~ pit had been formed in the gravel pad. at one end to burn solid combustibles. The .ca~ utilizes a sewage treatment plant with an operator-on duty. The plant effluent runs into a diked lageen. The steel rectangular diesel fuel storage tanks are not enclosed by a dtke, hewever, I found no requirement in the we1] file from the. State Olvtsion of Lan(Is that they should be diked. The dril.ltng pad, in ge~_neral, was in need of heuse- keeping. Boards, steel packaging straps, pieces of pipe, trash, etc, needed to be picked up and contained- in. one sPOt for back' haul or burtal. The area around the sewage treatment plant was especially dirty. I visited a)l the shops, generator and botler buildings, and the rig where hydraulic 1tries were being connected to the bl.owout preventer. At 8:25 PM Mike Bates, the Parker tool pusher,, said they were ready to start testing. The BOP closing system accumulator and hydraulic otl was used to apply test pressure. Test pressure .was applied between the check valve and c~dtstde valve on the kill line and these two valves were tested. The check vtlve would not hold pressure and the gate valve lost 150 psi or 3% of the 5000 psig test pressure in ten.minutes, The inside kill l(ne gate valve lost 100 psi or 25 in ten minutes.. The test plug had been set in the drtlltng spoo!. The-blind rams and Inside choke line gate valve were closed. These were-tested at 5000 pslg without leaking, Progressively, the outside choke line valve, choke line, choke manifold, and choke manifold valves were each tested at 5000 pstg without leaking. The Swaco automatic choke fatled to close on the first try, popped open on the second try and functioned prop- erly thereafter holding 5000 psig pressure. The manual adjustable choke ~eouid not hold 'the test pres..s~ure:, ~t ~.s d~sassembled, c~cked, clea~ ~ed ~as~l~. ~ ~tl~, I~ ~o~e ~s ~e ~n ~fo~ ~e ove~ul. ] ~v~sed ~ t~t ~ ~ ~t ~ ~pat~d or ~pla~ so tt ~ld ~ld ~ ~lg for I0 ~~. T~ p~ss~e ~11ef valve tn ~e c~e ~tfold ~s ~s~ ~. ~f~ ~ ~11e~ at ~ pstg. At ~ts ~tnt, ou~ ~sttng ~s sus~~ so;~ ~~ ~le a~ rtg flor c~ld ~ ~tn- s~11~.s ~t ~s 1~:1~ ~. Resmaptton oi' 'BOP testtog ~s del.~yed untt1 8:15 AM whtle a frozen test 11ne was ~. The test plug was Installed on a dr111 ptpe Joint and the ptpe rams were closed. The ptpe .rams were tested without leaktng at 5000 pstg followed b~y the hydrt1 at ?.SO0 pslg. The 2500 pstg pressure was applled to the kili 1t~ check valve that leaked on the prevtous ntght's test.. This ttme it held wlt[~out leaktng. !hed Ken operate the I~ydrtl and bot. h sets of rams wtth the remote controls so ! could observe and ttme the closures. Closure was slo~ at ftrst and the controls were adjusted unt11 operation was satisfactory. Next ! bad the dr111er operate the two floor valves. ge were ready for the ftnal 1rte'- The cre~ latd dow~ the test plug, picked up the ke11:y and Installed the test ntpple below the lower kelly valve. The kellycock was closed and pressured to 5000 pstg. The pressure leaked off. Several trials were all unsuccessful. The lo,er kelly valve was closed and tested satlsfactorJly at $000 pstg. The kellycock was operated several ttmes, closed and retested, but st111 leaked. ! told Ken he'd have to get a good 5000 psig test before- using the kellycock so they removed tt and started to disassemble it. The test was completed at 11:30 AM. !trted to get reservations on the ofle remaining Saturday fltght but there was already a long stand-by 11st. ! got space on the 10:00 AM Sunday Wten trltght. ! prepared my "Field Trip Report" and dlscussed the deficiencies noted therein wtth Ken later In the day. The deficiencies were: (1) The manuat ad.lustable cFmke and kellycock did not hold pressure and must be repatred or replaced, then tested by holdtng 5000 pslg for 10 minutes; these tests must be recorded on the driller's log. (2) Trash around the rtg and camp must be collected and properly dis- posed of to 1reprove the a~rance, to keep trash from getttng off the pad, and to facilitate post drilling locatton clean-up. Ken agreed to get the area clea~l-up and ~ew seals were already, betng tn- stalled in the kellycock. !-gave Ken a copy :of my "Fteld Trip Report", matled a copy to Frttz Scha11, Mob11 drtlltng supertn~nt tn Anchorage, and a copy ts attached. Unfortunatel:y drtlllng couldn't be resumed rtght away. The 13-3/8" castng shoe was pressure tested and leaked at 1600 pslg. Dowel1 was scheduled to arrive about 3:00 Alq Sunday to recement. When ! leer the dr111 stte at 9:00 AM tn l~ob11's fully loaded twtn Otter, t~:y had run the Ceaent Bond L°g and were preparing to recement the 13-3/8" casing shoe. ! a~tved at Oead~rSe at 9:30 APl and departed by comaerctal 3~ aircraft at 10:15 AI~ for Aoc~rage, a~,'tvlng at i6:15 PM. On th~s ¢teld trtp a s~t~s~c-.tory BOPE check and Inspection of drt111ng oper- ations ~s mede on !eo~tI - W. S~1nes State go.. 2 explor~or~ drt111ng ~e11. The opera,or ~s ~clvJsed ef ~ following deficiencies ~nd agreed to correct them g .r~mptly: (1) Repair or replace maaual adjustable choke and test mt SO00 psig for lO minutes. I~l Repair kellycock and test at SO00 pstg for 10 minutes. Clean up the ~sh on the drilling pad to improve the appearance, to prevent littering the surrounding tundra and to facilitate post drilling location cleanup. March ?, 1975 ~tt oil ~~ P.O. Pouch 7-003 A~cr~ge, Alaska 99510 _ _~ ID/NS 74-24 Attu: Ral~ ! ,- r ,'LI · I~ILE: TA~ lease o~ra~ ~ in your 1~ of A~r&l 29, 1974 an~ July 29, 1974 as ~ by ~ of Nov~b~r 20, 1974 ~ Dec~b~ 10, 1974 ts o no v~/eta~/ve cover such as ~ river beds ~ gravel bars. After ~ !5, 1975, ~e use of 9=o=~ co~c~ vekt~.tea =aa~ be sobj~ to t~=~n_~n~-_t{_~n~_. ~i. th/~ 72 bouts of no~t. ic~ by the dire~cor. 3.97.5 . th~ ~ site(s) shall be ~ra~t ~mxY~h with all betas ami =~nt of fish. th~ f~x~u ~= ~o ~ ~=~ku~ of ~y ~5, 1975, which- ev~ .cc=rs first. · he Det~rtm~t of Fish a=i' G~e, Habitat Prot~T/on ~, 1300 Oollege ~, ~, ~ ~701 ~ 452-~31), ~~~~~14~~~~~t~ . .. ~. If ~ ~ ~ ~eof ~~~t ~ ~~~t~~~ 76.40~ ~~ 76.5~~ ~~. 16. Page3 20. very truly _ . . :-5, ':" 6';' Remot6::-Controls (.'~ SPo°l-outlets ':i: i ..:(/) . 7. Drilling ( )':::' '( ) 8. Flow..Lines (~') -,- .( )" 9 Jill Lines (~'-- ( ) 10. Manifold ~okes~' 15. Locaci°n':Be~n ' 16. Fuel Berm 17. Operations off "Pad" 18. "~eneral Housekeeping" 19. Abd. Marker in place 20. Water Well covered tt~: t~t Stal~$ State ~2 . . . ~I t O11 ~~tt~ E~I~ Is t~ ~pp~ ~tl~t~ ~ ~1~ ~ d~lll the ~~ ~e~n~d ~tl, ~ ~ ~ ~~~ t5, t9~, ~t ~ .l~lon In ~tl~ 25, T~nship ~1t s~t~, ~e ~lps, ~d,a ~ I~ n~ r~ul~d. ~ dlr~tt~nl survey ~ny tiers In AI~ and ffhetr dralnn~ syst~ have b~n clnsslfled ns t~ a~ ~e ~~ ~ AS-16.~.870 ~d the regulatl~s pr~lga~d there- ~r (Tltte 5, At~ A~lnlst~ttve ~)- Prlor ~ ~~ing ~atlons ~ ~y ~ ~~~ by ~ ~t~ ~Nl~tor~$ offl~, ~par~nt of Fish end ~. Pol lufton of any ~aters of the .State Is prohlbit~l by AS 46, Chapter 03, Article 7 and the regulations promut~d there,Jnder (Tltle 18, Alaska Adminlsfratlve Code, Chapter 70) and by ~he Federal Water Pollution Control R~t, as aaended, Prior to ~.l.ng .operations you ay be contacted by a representative of the Departaent of Envlronmen~al Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor Is bel~ notified of. ~he Issuance of this permit to drill. Enclosure Cc~ Department of Fish and Galm, H~bl.,at Section w/o encl. Department of Env! ron~~ ! ~ervatlon w/o enc I. ~pa~, of Labor, Supervisor, Labor La~ Compt lance Division w/o encl. Mobil Oil Corporation P.O. BOX 5444 DENVER COLORADO 80217 CONFIDENTIAL December 12, 197~ State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99503 Gentlemen: WEST STAINES STATE #2 NORTH SLOPE, ALASKA Mobil Oil Corporation requests your approval for the drilling of the West Staines State #2 well from a surface location approximately 848' south and 50' west from the northeast corner of Section 25, -TgN-R22E, Umiat Meridian, Alaska in the State Lease No. ADL 28377. The subject well is to be drilled to a total depth of 13,500'. Mobil Oil Corporation also request an order of exception to the well spacing restriction for drilling West Staines #2 in that the well's location deviates from the State Conservation Regu- lation, Section 2081(a), which specifies a 500' minimum stand- back at the lease line between state leases Nos. ADL 28377 and ADL 28888. The same parties are owners of both leases. This site i~ considered optimum to secure desired geological information. Application for Permit to Drill (form P-l) with a check for $100 and other necessary attachments accompany this letter. Yours very truly, H. N. ?otter Area Engineering Supervisor Alaska Producing Area PKP/vm att. / (Ot~ler lnstruct[~ reverse atd~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK 'IlL TTPB OF WORK DRILL :i~ DEEPEN [] PLUG BACK b. TYPE Or WELL 2. NA~IE OF OPF:-R.ATOR ~ ~o,,bil 0i~~ration P.O. Box. 54a4; TA; De_nye,: Cn]arad~ 80217 J~OCATION OF %VELL ~:..r~,,~e Approx. 848' S a 50' W f~ the ~ ~er Sec. 25-TgN-R22E, b~, .~as~ .Al ~d prod, zone Same as above i~fSTANCE IN NIiLF~ AND DIRECTION F.IOM NEAREST TOWN OR POSt OFFICE ,~ ....... .ox~=,_e]_y ramies east of Re_ad Horse AP.I #50-089-2~ zoooy 8. L,EA.~E DESIGNATIO.~/~-N~D S~L4uL NO. AkL 28377 1. IF IN-DIA~N, A.L/.,OTTEE OR TI:~LBE NA.M~ 8, UNIT, FARM OR LEASE N~%IE Hobil-Fnil!ips =9. WELL NO. g~st Staines State #2 I0. FIELD AND POOL, OR WILDCAT Wildcat '- 11. SEC., T.. R., M., fBO'rTON[ HOLE OBJECTIVE) Seo.25-TgN,R22E, U.M. l~. }~JO~ D INFOI~M ATiON: . . Pacmfzc In~demnity Co. 15. DISTANCE FROM PROPOSED* LOCATION TS NEAREST 50 t from east PROPERTY OR LEASE LIN~, ~. ,~'~o ~,a~e~t d~i~. ~i~. if ~ lease l~e TO NEAREST ~'ELL DRILLING. COMPLETe. o~ A~mmD Fern ~. 2 ~&les f~m k!~, ~t~5_nes State ~q 21. ELEVATIONS (Show whethcr DF, RT, CR, etc.~ DF ~5~ il6. No. OF AC~.S IN LEASE J 2560 II~. PRoPOsED D~TH I 13,500'' ,~o=t$100,O00.O0 17. NO. ACRES ASSIGNED TO THiS WELL 20. ROTARY OR CABLE TOOLS Ro,ta~ 22. APPROX~. DATE WORK WILL STAHT* January 15~ 1975 PROPOSED CASING AND CEMEN'rlNG PROGRAM - 36" '[ 30" 154 J-SS ~ 50'2 300 sx -26"[ 20" 94 H-40 750'± 2160 sx -- 17%" 13-3/8" 72 N-80 2~7~.0'z ' "~2525'sx ~ qo~,, 9r5/8" . _ F?inimum 575 sx ' =~. 43 5 & 47 S-95 ql,sq,0'~ 8~". 7" 29 S-95 13,500 - Completion program wi±± De forwa~ ~ded Follow~g ~e attached with the application: 1) Drilling program 2) Blowou't prevention program 3) Survey plat T~ ABO%"E SPACE DESCH/I~E P"ROPOSE-'D PR~R~: If ~1 is to dee~n or plug ~, give ~ on p~sent p~u~ive zone ~d pro~ ~w produ~ive ~ne. If propel ~ W drill or d~n d~e~., give ~r~ent ~ on subsu~a~ ~t~ ~d meas~d ~d ~ue venial dept. Give blo~ut preventer p~gram. ~.', h~reby ~=i~' that the Fo~o~. 1, ~ ~ Co=.~ ~a ~g~eeri~ (This space for State office use; CONDITIONS OF APPIROVAL, IF ANY: I SAMPLES AND' CORE' CHIPS iRF-~ I~Y'~ u ~o SEE TRANSMITTAL LETTER - j DIIt~_J~'rlONAL SURVEY RE~ A.P.I. I~/I;I%~C~L CODI~ ~ ~ .~ so 50-089-2004 Iq75 o. rs January 6, 1975 'e CONFIDENTIAL DRILLING PROCEDURE WEST STAINS STATE #2 NORTH SLOPE ALASF. A Location: Approximately 8~8~+_ So. and 50' + West from the NE corner, Sec. 25 TgN-k22E, Umiat NeridiAn, Alaska.- General- Deviations from the recommendations made herein may be necessary, due to conditions arising during the drilling of the subject well. However, if possible, any deviations from this program, along with the ~easons, there- fore, should be discussed with the Drilling Superintendent prior to making the changes. If specific conditions make it unfeasible to discuss vari- ations prior to their implementation, they should be reported, along with the reasons, therefore, to the Anchorage offices as soon thereafter as possible. This well will be drilled as a straight hole. The projected casing program is as follows' Casing size 'Depth 30" o.D. so.'+- 20'' O.D. 750'" 13-3/8" O.D. 2,700',, 9-5/8" O.D. 11,500'" 7" O. D. (Liner) 1-3,500'" . P.a§e 2. Deviation It is possible that deviation problems will be encountered. Pack hole assembly and/or stiff hook-ups are recommended for use from the surface. Single shot directional measurements will be made the first 30', 60' and 90' and thereafter every 90' to 750'. From 750' deviation measurements will be made every 250' to 2700' +, and every bit change thereafter. If "dog-leg" severity g'reater tha~ lO/100' is indicated, surveys will be taken at 30' intervals through the suspected interval. The following maximum limits on deviation shall apply' DeFAn Interval Maximum deviation Maximum Dog-Leg Severity 0 - 750' 750' - 2,700' 2,700' - 5,000' 5,000' - 7,000' 7,000' - 11,500' Il,500'-- 13,500' 1° 1 _o/100' 2o l°/100' 5o. 1N©] 100' 6o 2°/100' .70 2o/100' 7O-lOO 3 o/100' Mud Program A. Drilling mud to be used fcom 50'+_ To 7-50''+_ Prepare a 600 bbl. surface mud system with following composition: Fresh water Soda Ash XC Polymer Chrome Alum Caustic Soda Paraformaldehyde 1 bbl. 0.5 to 1.5 lb/bbl.(depending on water hardness) 1 lb/bbl. 0.3 lb/lb polymer to pH 9 to 9.5 0.5 lb/bbl (if needed tc prevent spoiling of polymer) The order of addition of materials shoul,d be as they are listed above. 'Caustic soda should not be added at the same time as the Chrome Alum, and it is preferred to dissolve the caustic in water first and add this solution to the mud. The following mud properties are recommended: Weight Funnel Viscosity Plastic Viscosity Yield Point Initial Gel lO min. Gel Fluid Loss So 1 i ds PH 8.7- 9.5#/gal. 50-60 sec./qt. 10-12 cp. 0-10 ///100 sq. ft. 0-10 ///100 sq. ft. 10-20 #/100 sq. ft. 10-20 .cc/30 min. 10% by Vol. 9-9.5 If loose gravel and boulders are encountered requiring a high viscosity (400+.sec/qt.) then switch to Gel and Ben, ex. The desander and desilter should be run while drilling or circulating to maintain low drilling solids. (The working time of the desander and desilter should be reported on the mud sheet each day, and should include the solid and sand content). This equipment is not de- signed to reduce, but rather to maintain low solids. Mud temperatures in the suction pit and at the shale shaker, and the ambient temperature sould be measured and recorded with each mud check. These checks~should be spread over a 24-hour period, so as to provide representative data throughout the mud system. B Drillin~ mud to be used from 750'+ to 2700'~ i,i~in~ain ~i~gh viscosi~ u, the mud to ~o.-~/~ casln§ point ~90' + or as long as required to handle the gravel and boulders. Rretreat mud with 0.3#/bbl. bicarbonate of soda before drilling cement. Maintain same drilling procedures and equipment utilized in Section A. Gas may be found below permafrost, (1900' ~) with normal pressure gradient. The following mud properties are recommended: Weight Funnel Vi scosi ty Plastic Viscosity Yield Point Initial Gel lO min. Gel Fluid Loss Sol id content Sand Content pH Annul u.s Velocity 8.7 - 9.5 ///Gal. 50-60 Sec./qt. lO-12 cp. O-10#/lO0 sq.ft. 0-10 #/100 sq. ft. 10-20 #/100 sq. ft. 10-20 cc/30 min. 5-10% by vol. 0-3% by vol. 9-9.5 o- oo !.6 """ D""~( 1'4 "? OIL Pa'ge. 4. C. 'Drilling mud to be used from 2700' +-- to ll,500'+- Pretreat mud with 0.3#/bbl. bicarbonate of soda before drilling cment. The polymer additions should be based on the water addition and upon the desired viscosity. With each addition of polymer, there must also be an addition of chrome alum. Add water dispersable asphalt if require~ and maintain a concentration of 6 lb/bbl. Asphalt concentration also should be regulated by know- ing the amount of water added to the system. 'Reduce filter loss by adding CMC in.the'mud system. The addition of water to the system should be limited to that required to make up volume while drilling and to properly operate the centrifuge. If the polymer at a concentration of l½ lb./bbl does not provide eneugh hole cleaning capacity, then use bentonite below the limit of 10 lb./bbl. Maintain "n" factor of mud within a range of 0.3 to 0.5. If it is too low, the mud probably has strong gels. If it is too high, the mud does not have enough polymer. l"he foil owing mua properties are recommended: Weight Plastic Viscosity "n" Factor pH Fluid loss Solid content Drilled Solids Sand Content Annulus velosity 9.7-10.8 #/gal. 12-14 cp 0.3-0.5 9-9.5 6-8 cc to 5000 ft. 5cc or less below 5000 ft. 8-10% by vol. less than 4% by vol. 0-1% by vol. lO0+ ft/min. D. Dr. ill.ing, mud to be used from ll,500' .to T.D. Pretreat mud with 0.3#/bbl. bicarbonate of soda before d~illing cement. The same drilling procedures and equipment to be utilized as in Section C. Try to maintain the same mud properties as are recommended in Section "C" until weighted mud is required. When it will become necessary to weight the polymer mud to 14.5 ppg. a point may be reached (probably above 12#/gal.) where the properties cannot be maintained adequately· At this point convert to a lignosulfonate system by addition of lignosulfonate and caustic soda. BOP Requirements (See BOP Policies)' A. From 20" casing point to 13-3/8" casing point, use Bag Type 20" series 600- 2000 psi W O.G., 20-3/4" bore. B. From 13-3/8" casing point to 9-5/8" casing point: 1 ' Bag Type 13-5/8" series 1500, 5000 psi W.O.G. 13-5/8" bore. 2 - Double gate, 13-5/8" series 1500, 5000 psi W.O.G. 13-5/8" bore, complete with 5" DP and blind rams. C. From 9-5/8" casing point to TD. 1 -Bag Type 13-5/8" series 1.500, 5000 psi W.O.G. 13-5/8" bore. 2 - Double gate, 13-5/8" series 1500, 5000 psi. W.O.G. 13-5/8" bore, complete with 5" DP, and blind rams. 7" and 9-5/8" casing rams to be available on location. All type BOP's should be opened and closed daily and tested weekly. The Gate Type BOP's should be tested to working pressure rating and the Hydril (Bag Type) should be tested to 50% of the working pressure. All the tests must be recorded on the daily drilling reports. SEE BOP Policies. ~Casing Requirements' A. Surface conductor 30" O.D. 50'-+oof 30" O.D., new /54 1B/ft. line pipe. B. Permafrost casing 20" O.D. 750"-of 20" O.D. 94 lb/ft., H-40 ST&C new casing. C. Surface casing 13-3/8" O.D. 0-2700'+-, 13-3/8" O.D. 72 lb/ft., N-80, ST&C. D. Intermediate string 9-5/8" O.D. 0-7000 ft., 880-0 ft. of 9-5/8" O.D., 43.5 lb/ft., S-95, LT&C. 7000-11,500'+ 2700 ft of 9-5/8" 0 D , 47 0 lb/ft., S-95, LT&C Page 6. CONF[D,.EN ', iA'L E. Production liner (if needed) 7" O.D., 29#/ft., S-95, LT&C. Drilling Procedure' 1. Drill 36" hole to 50+_ ft. This hole will be drilled with auger rig. The bottom of the 30" conductor should be plugged with cement or wooden plug. The 30" conductor should be set in place and cemented to the surface through 1¼" tubing down the outside of the conductor with "Permafrost" slurry, and cement slurry should be kept at approximately 600 F. while pumping into place. The 1¼" tubing should be run to the bottom of the conductor. 2. Drill 12¼" hole to 750 ft. +. Run electric logs (DIL, GR-Sonic- Cal and a long spaced sonic log). It is possible that deviation problems will be encountered. 3. Open 12¼" hole to 26". 4. Set 20" O.D. permafrost casing at 750' +--with a subsea hanger at 500 ft; + . Use duplex collar, guide shoe and Arcticset cement to surface. If cement falls back, use 1¼" tubing and cement down the outside of the casing. W.O.C. 12 hours (See attached 20" casing cementing procedure). 5. Nipple up wellhead and 20" bag type BOP. Pressure test BOP to 1000 psi, and choke manifold, valves, etc., to 2000 psi. (see BOP policies). 6. Drill 12¼" hole thorugh gravel beds 2700 ft. +__. Run electric logs (DIL, GR-Sonic-Cal, 30 side wall cores and a long spaced sonic log). Note that it is very important that the mud loggi,ng unit be installed and operating prior to drilling out from 20" casing. 7. Open 12¼" hole to 17½". 8. Run 13-3/8" O.D. Casing with centralizers on the first four joints, and a sub-sea type suspension system at 500'~ with two 13-3/8" x 20" centralizers, one beneath and one above; thereafter on every second joint. Set 13-3/8" O.D. casing string at 500 ft._. + on subsea suspension system. Use duplex collar, float shoe, and Arcticset. cement. Duplex collar should be run one joint above g~ide shoe. To cement the 13-3/8" O.D. casing string from 500 ft. ~ to 2700 ft.~, ~se the following procedure' a. Run 5" drill pipe inside casing and screw into duplex collar. b. Cement to surface. c. RUn Howco FO Collar @ base of 20" casing. Straddle with centralizers. Page 7. 9. Nipple up 13-3/8" series 1500 BOP' Stack· Pressure test BOP at ~5000 psi. (See BOP policies). 10. Pressure test casing at 2000 psi. ll. Drill 12¼" hole to 11,500 ft. + . Exact depth will be determined by well site geologist. Core with 8-7/16" core head and take electric log (D~.L, GR-Sonic-Caliper-SNP, HDT, 180 side wall cores, 4 arm dipmeter and a long spread sonic). Detailed information on testing will be forwarded at a later date. 12. Run and set 9-5/8" casing with a tie-back at 2000 ft + (Place · diesel oil in the 13-3/8" x 9-5/8" annulaufSt)e,r Possible use and place- ment of E.O. collars will be determined logging is completed.Cement first stage with a minimum of'575 sx class "G" cement with 18% salt. (calculated lO00' fill with 100% excess - see'attached cementing program. W.O.C. 24 to 48 hours. 13. Nipple up 13-5/8" series 1500 BOP stack. Pressure test BOP's choke manifold, valves, etc., to 5000 psi. (See BOP policies). 1~..:, Drill nut aha cle~..~n ot(t fiD,+ cnlla~ with ,n ~" h~t, P.r~.~ure test casing to 2000 psi before drilling out sh(.~e. 15. Sperry Sun non-magnetic directional survey may be run from 9-5/8" casing point to surface. 16. Drill 8½" hole to total depth. Core with 8-7/16" core head. Test information will be the same as for 12¼" hole and will be forwarded at a later date. Run electric log (same set as was run at 9-5/8" casing point). 17. Total depth is estimated at 13,500' + A 7" liner will be run if productive possibilites exist betw~eF~ 9-5/8" casing point and T.D. A ,completion program will be forwarded on completion of drilling operations. . . , ~ NOTE; Catch 30' samples or as directed by well site geologist. Samples should be washed, dried, and sacked. ' P.K.Paul July 22, 1974' (lst revision) 20 " SERIES 600 HYDRIL 2000 PS/ W, P, AL SERIES 1500 D,F, VALVES · -'T' "T-' VALVE CHECK 5" S~.qlc"S 500 D,F, SERIES 1500 D.F.. VALVES VALVE FIGURE I UUUU E] 0 E3 FI I$ 5/~__ . SE£1E$ I~00 H YDRIL I,,~ ~'78" SERIES I~00 DOUBLE GA TE D. O. R - BLIND RA MS ON BO TTOM DODO CHECK VALVE '. L /S ~" J D.F VALVE . . FIGURE CHOKE MANIFOLD NOTE ' THIS IS A SCHEMA TIC SKETCH AND NOT A DIMENSIO~IAI DRAWING. : ~ UNIT TO BE ASSEMBLED, MOUNTED ON H BEAM SKIDS AND TESTED TO 5000 PSI. !. $" X 2" FLANGED CROSS '2. $" X 2" STUDDED CROSS $. 2" FLANGED GA TE VALVE ~. 2" ADdUSTABLE CHOKE FLANGED TYPE B 9. 2" COMPANION FLANGE AND 2" HIGH PRESSURE NIPPLE I0. 2" COMPANION FLANGE - SCRE~ II. 2" HP BULL PLUG 12. SPACER ~IPPLES CONSISTING OF '~" WELD FLANGE ~ 2" LIN,~ PIPE. I ~. ' 2" STUDDED EL BO WS ' 14. ~" COMPANION FLANGE SCRE~ OUTL~ FIGURE Company //~Ym~F/~"/~[~m___ Lease & Well No. ~~r,m~Z ~L. ~__ CHECK LIST FOR NEW WELL PERMITS Yes No Remarks Is well to be located in a defined pool ................. Do statewide rules apply ........................ ~-- Is a registered survey plat attached .................. %~ well located proper distance from property line · s well located proper distance from other wells ............ Is sufficient undedicated acreage available in this pool ........ _y/~,j~. Is well to be deviated ......................... y/~: -- Is operator the only affected party ................... -- · Can permit be approved before ten-day wait ............... ~o~ ). Does operator have a bond in force ................... ~_____/~.__ !. Is conductor string provided ...................... .~. .ls enough cement used to circulate on conductor and surface ...... ~. .1 cement tie in surface and intermediate or production strings . . . ~.~ ~. Will cement cover all possible productive horizons ........... Will surface casing cover all fresh water zones ............ 6. Will surface csg. internal burst equal .5 psi/ft.'to next string . 7. Will all casing give adequate safety in collapse and tension ....... ~ ~___ 8. Does BOPE have sufficient pressure rating ............... ~dditional Requirements' /fm~.~¢~,/.~,,~'/~ ~}// ~ ~,ofo~,~/ v~ /~-¢,'~/ 4
