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Home My WebLink About178-005IExxonMobil production Coinpany : , 0. Box 196901 Anchorage, Alaska 9951943601 907 5615331 Telephone August 4, 2014 R-2014 OUT -157 RECEIVED AUG 0 6 2014 AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 RE: Final Location Clearance • Point Thomson Unit (PTU) #1 (PTD 176-085) • PTU #2 (PTD 177-064) • PTU #3 (PTD 178-005) • Staines River State #1 • West Staines State #18-9-23 (PTD 169-120) • West Staines State #2 (PTD 175-002) • Alaska State C-1 (PTD 180-046) Dear Commissioner Foerster, 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 ExxonMobiI-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, cmV ID JUL 21 201 A®GGG E�onMobil Production Well remediation was conducted at the six wells referenced above this past winter in compliance with AOGCC Sundry approvals. As required by the Sundry approvals, a Report of Well Completion for the Plugging and Abandonment of each well (10-407 form) was submitted to your office May 14, 2014. Following breakup, summer debris cleanup activities were conducted at four of the well sites the last week of June. AOGCC field inspectors concluded that it was not necessary to visit these sites following the cleanup work and instead asked that we provide the attached cleanup reports and site photos for PTU #1, PTU#2, WSS #18-9-23 and WSS #2. PTU #3 and Alaska State C-1 are on active pads associated with the Point Thomson Project so debris cleanup at those locations is not warranted. Please note ExxonMobil is currently working with the Alaska Departments of Environmental Conservation and Natural Resources to close the reserve pit on the WSS #2 and to address contaminated gravel on the WSS #18-9-23 and #2 locations. If you have any questions or require additional information, please contact me at (907) 564-3773. Sincerely, 4J - 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. 0- -*+ `- . AA �' M Aft y s • ILI A. r� 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 ',A PTU #1 removing pipe A 41� its A PTU #1 post pipe removal Page 3 Abandoned Well Site Cleanup Report July 18, 2014 Ad PTU #1 looking south post cleanup. Debris collected in supersacks (seen at left of picture) was transported back to Deadhorse for appropriate disposal PTU #1 aerial view looking north east post debris cleanup. Page 4 Abandoned Well Site Cleanup Report July 18, 2014 Summary of Point Thomson Unit (PTU) #2 Activities PTU #2 (PTD No. 177-064); Sundry No. 313-601 and Sundry No. 314-158 (modification) A Report of Well completion for the plugging and abandonment of PTU#2 was submitted 5/14/2014 to AOGCC. The well is plugged and abandoned in compliance with the Sundry approvals. Following the winter well remediation, summer debris cleanup activities were conducted the last week of June. Debris was collected and transported to Deadhorse for appropriate disposal. Photos are provided below. PTU #2 Well location conducting debris cleanup. PTU #2 Well location post debris cleanup. Page 5 Abandoned Well Site Cleanup Report July 18, 2014 PTU #2 looking west post debris cleanup. PTU #2 looking southwest post debris cleanup. Page 6 Abandoned Well Site Cleanup Report July 18, 2014 Summary of West Staines State (WSS) #18-9-23 Activities WSS #18-9-23 (PTD No. 169-120); Sundry No. 313-604 A Report of Well completion for the remedial abandonment of WSS #18-9-23 was submitted 5/14/2014 to AOGCC. The well is plugged and abandoned in compliance with the Sundry approvals. Following the winter well remediation, summer debris cleanup activities were conducted the last week of June. Debris was collected and transported to Deadhorse for appropriate disposal. Photos are provided below. WSS #18-9-23 well location prior to debris cleanup. WSS #18-9-23 well location post debris cleanup. Page 7 Abandoned Well Site Cleanup Report July 18, 2014 WSS #18-9-23 Looking south east post cleanup (shown in center of picture) and transported disposal. . Debris was collected in supersacks back to Deadhorse for appropriate WSS #18=9-23 looking south west post cleanup. Page 8 Abandoned Well Site Cleanup Report July 18, 2014 Summary of West Staines State (WSS) #2 Activities WSS #2 (PTD No. 175-002); Sundry No. 313-606 A Report of Well completion for the remedial abandonment of WSS#2 was submitted 5/14/2014 to AOGCC. The well is plugged and abandoned in compliance with the Sundry approvals. Following the winter well remediation, summer debris cleanup activities were conducted the last week of June. Debris was collected and transported to Deadhorse for appropriate disposal. Photos are provided below. WSS #2 well location prior to debris cleanup. WSS #2 well location post debris cleanup. Page 9 Abandoned Well Site Cleanup Report July 18, 2014 WSS #2 Looking west to east post cleanup. Debris was collected in supersacks (seen in center of picture) and transported back to Deadhorse for appropriate disposal. WSS #2 Debris collection awaiting transport to Deadhorse. Page 10 Abandoned Well Site Cleanup Report July 18, 2014 Schwartz, Guy L (DOA) From: 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 webs pians are tg do the stick nicking work and obtain AOGCC site clearance inspections in June. We would be happy to review the past season's work with you if desired. Our suggested timing for this would be after the stick picking effort. Are you interested in such a review and, if so, would you be available sometime during July 8-10 timeframe? Regards, Rob Dragnich Consultant to ExxonMobil Production Company R.G. Dragnich, LLC rob@rgdragnichllc.com 907-830-4796 SEAW NOV 18 2014 - -r\.•-+mac, 178, Dolem fir•,..-. •: /}.� "'' _: .. - — '.� �, � v 35 J.'. • 4....` :. , . r $ •._.. i!`33 R-R•!,�>1+ , '♦2 0� o r PTU c I , q _ll t I ! Ir . w_.•,. 8 •\. '"'e1f p ... T_' I tic I� I� 22 + 25 i x I 28 - W@s5t'e to not, No171 t' 34 31 —�_. _.. __ r. _�,, � r�i ..... '' i `•\S ®�_-`; 7 35 , k-. r 31 ii 9z , f?I�B♦ ' �,n. 35 P I • � s a . to _ i!1ij (� �•�/ 'I i � 11 t ... �f Y•_.._.�r_.. _. ` r. + e � ��: i it '� f , `� 19 A , ' s' 14 13 17 1 ,:. t It 17 If 16 , ilV i4 m Y1 iz 1A'•' I 19 R z1 4l H, » I 90 !8 •.. X10 . 1if` =ed •, ,,•,,.� .. i� Q ; ,; , I » fa f \ifs � u }'�/ •t" M ♦ 'y' r j � � � •: f �� ...,,.,/ i + l! . _.. • ,� 11 ,� wv T + 9 9 /o a 't, , /"f^ +u ` '•<s r Al Ur �u-t. 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 0 . Suspended ❑ 20AAC25.105 20AAC25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: 1 b. Well Class: Development ❑ Exploratory Service ❑ Stratigraphic Test ❑ 2. Operator Name: Exxon Mobil Corporation 5. Date Comp., Susp., or Aband.: 4/14/2014 12. Permit to Drill Number: 178-005 • 1-9 -6- &Z— 3. Address: P.O. Box 196601, Anchorage, AK 99519-6601 6. Date Spudded: NIA 13. API Number: 50-089-20007-0000 4a. Location of Well (Governmental Section): Surface: Top of Productive Horizon: Total Depth: 7. Date TD Reached: NIA 14. Well Name and Number: Point Thomson Unit #3 8. KB (ft above MSL): GL (ft above MSL): 15. Field/Pool(s): Point Thomson Unit 9. Plug Back Depth(MD+TVD): >3' below tundra level 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 468641 - y- 5912634 r Zone- t{ TPI: x- y- Zone- Total Depth: x- y- Zone- 10. Total Depth (MD + TVD): 14125 ft' 16. Property Designation: ADL 47559 surface 147558 BHL 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 NIA 23. See Attached Work Summary CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 24. Open to production or injection? Yes ❑ No 7 If Yes, list each interval open (MD+TVD of Top and Bottom; Perforation Size and Number): RE C E 1 V E r MAY 2 7 2014 A0GCC 25. NIA TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 26• NIA ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. N/A PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate _-Jo. Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): 28. CORE DATA NIA Conventional Core(s) Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No ❑ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NE® NOV 18 2014 RECMS MAY 2'7 20 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE �ubmit original only • z - 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ''_� Yes 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.juranek exxonmobil.com Printed Name: Irene T. Garcia Title: SSHE Manager Signature: V 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 ❑✓ Suspended[E] 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: Exxon Mobil Corporation 5. Date Comp., Susp., or band. 4/14/2014 12. Permit to Drill Number: 178-005 3. Address: P.O. Box 196601, Anchorage, AK 99519-6601 6. Date Spudded: N/A 13. API Number: 50-089-20007-00-00 4a. Location of Well (Governmental Section): Surface: Top of Productive Horizon: Total Depth: 7. Date TD Reached: N/A 14. Well Name and Number: Point Thomson Unit #3 8. KB (ft above MSL): GL (ft above MSL): 15. Field/Pool(s): Point Thomson Unit 9. Plug Back Depth(MD+TVD): >3' below tundra level 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- -146.252803 y- 70.172347 Zone- TPI: x- y- Zone- Total Depth: x- y- Zone- 10. Total Depth (MD + TVD): 14125 ft • 16. Property Designation: ADL 47559 surface / 47558 BHL 11. SSSV Depth (MD + TVD): N/A 17. Land Use Permit: LO/NS 09-007 18. Directional Survey: Yes ❑ No ❑✓ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost MD/TVD: 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): N/A I 22.Re-drill/Lateral Top Window MD/TVD: N/A 23. See Attached Work Summary CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 24. Open to production or injection? Yes ❑ No r❑ If Yes, list each interval open (MD+TVD of Top and Bottom; Perforation Size and Number): RECEIVED MAY 15 2014 AOCCC 25. N/A TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 26. N/A ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes No ❑ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. N/A PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate _-Jo- 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. RSOMS MAY 15 20& Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only /G 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: 31. List of Attachments: Work Summary, Post P&A Well Schematic, Photographic documentation of the well before and after the work. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tom Juranek (832)624-5940 Email: tom.aJuranek exxonmobil.com Printed Name: Irene T. Garcia Title: SSHE Manager Signature: a �' Phone: (907)564-3773 Date: 5114/201�' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 ExxonMobil Production Company P. 0. Box 196601 Anchorage, Alaska 99519-6601 907 5615331 Telephone May 14, 2014 R -2014 -OUT -130 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 MAY 15 2014 ElonMobil AOGCC Production Re: Well Completion Report Well Abandonment: Point Thomson Unit #3 (PTD No. 178-005) Sundry No. 313-602 and Sundry No. 314-228 (modification) Dear Commissioner Foerster, ExxonMobil hereby submits the Report of Well Completion for the plugging and abandonment work on the subject well. The well is plugged and abandoned as described in the Sundry f approvals 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, 44,q 'q - Irene T. Garcia SSHE Manager ITG:ed:bt Attachments: AOGCC Form 10-407: Well Completion or Recompletion Report and Log Work Summary Post P&A Well Schematic Photographic Documentation of the Well Before and After the Work POINT THOMSON PRODUCTION Exxon Mobil Corporation Point Thomson Unit #3 AN #: 50-089-20007 PTD #: 178-005 Final Well Schematic Marker Plate 2!3' below tundra level e® 10.2 ppg CaC12 Brine 15.8 ppg Fresh Water Mud 15.8 PPg Fresh Water Mud oint Thomson Unit #3 plug from marker plate — ±75' BGL in 9-5/8" casing a 18-5/8", 96.4 ppf, K55, BTC cond csg at 811' MD (811' TVD), cmtd w/ 4,300 sx permafrost Cement in 9-5/8" x 13-3/8" annulus from marker plate to ±3,338'. Cast iron bridge plug at 2,000' MD 13-3/8" 72 ppf, L80, BTC surf csg at 3,338' MD (3,298' TVD), cmtd to surf w/ 3,750 sx permafrost TOC behind 9-5/8" casing estimated at 5,000' Top of cement in 9-5/8" casing at 8,869' MD Baker cement retainer at 9,019' MD 7", 35 ppf, P110, BTC production casing stub at 9,502' MD 9-5/8" 47# Soo -95 at 10,347' MD (9681' TVD), cmtd w/ 2,450 sx class G Top of cement inside 7" casing at 13,612' MD Top of cmt outside 7" csg at 13,664' MD per cmt bond log Halliburton cement retainer at 13,847' MD Baker model F-1 production packer at 13,852' MD Perforations 13,872'— 13,885' MD, 2 spf, 180° Cast iron bridge plug at 13,890' MD Baker model F-1 production packer at 13,892' Perforations 13,908'— 13,925' MD, 2 spf, 1801 Top of cement inside 7" casing at 14,024' MD (float collar) 7", 35 ppf, P110, BTC, prod csg at 14,114' MD (13,140' TVD), cmtd w/ 1,035 sx class G 8-1/2" open hole TD at 14,125' MD (13,151' TVD) Point Thomson Unit #3 Summary of Work Activities 5 -Apr HSM, MI excavator and dig out around wellhead. 6 -Apr HSM, Continue excavating around WH. 7 -Apr HSM, Finish excavation around WH exposing 9-5/8" x 13-3/8" annulus. MIRU Little Red, pressure test lines 3000#, pump 60bbls diesel, initial rate 0.4 bpm @ 1200# slowly increasing rate to 5 bpm max pressure 1960# ending pressure 1640#. SD RDMO. 8 -Apr HSM, MI cement silos and fill. 9 -Apr HSM, MIRU SLB, pump down 9-5/8" annulus 212 bbls Arctic Set 1 cmt 15.7 ppg at 4 bbls per minute starting pressure 1000 psig and ending pressure of 100 psig. RDMO SLB. MIRU Little Red. Pump diesel down 9-5/8" casing and pressured up to 2000 psig. Found pin hole leak on bull plug (wellhead cap) so bleed off the 2000 psig to avoid diesel release prior to obtaining a sustained pressure test. RDMO. 10 -Apr HSM, Continue excavating around WH for cutting wellhead off. SDFN. 11 -Apr HSM, Completed excavation around well head, ready for WH removal. SDFN. 12 -Apr HSM, cut and remove conductor and chipped away cement. Ready for planned cement top job 4/13/2014. 13 -Apr HSM, Cut 20", 13-3/8" and 9-5/8" casings with Wachs saw, Run in 1" pipe and pump cement top job in V casings. SDFN. 14 -Apr Completed dressing up casings, took photos of cmt., completed welding on marker plate — took final photos. AFC to back fill excavation. Final Report on Well. V/ PTU #3 As Found•• ,a PTU #3 As Found MP t P" Y _: rim PTU #3 All Strings Topped Off 11 PTU #3 Depth Below s ♦ , .x�:c - . to ��<w ' • :s -y �,*�'� .s ? < } s a2 k P N4 Tundra PTU #3 As Left Schwartz, Guy L (DOA) From: Juranek, Tom A <tom.a Juranek@exxonmobil.com> Sent: Thursday, December 05, 2013 6:10 AM To: Schwartz, Guy L (DOA) Cc: Dragnich, Rob /EXT; Denman, Erika /C Subject: RE: PTU#3 P & A ( PTD 178-005) Guy, Thanks, we will include the pressure test. Also, as we discussed yesterday, we are continuing to fine tune our procedures. Now, in our most likely cases for most wells, we will be placing cement between deeper plugs and shallower plugs rather than placing brine and a CIBP. A diagram describing this change is attached below. Please let me know if you have any questions or need anything further. Thanks, Tom Juranek Subsurface Engineering Advisor ExxonMobil 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.iuranek@exxonmobil.com CIJ3P 41 ±200' M us m Submitted "Most -Likely" Current "Most -Likely" From: Schwartz, Guy L (DOA) [ -rtz@alaska.gov] Sent: Wednesday, December 04, 2013 5:06 PM To: Juranek, Tom A Cc: Dragnich, Rob /EXT; Denman, Erika /C Subject: RE: PTU#3 P & A ( PTD 178-005) Torn, As we discussed plan on testing the lower tubing head flange to 2500 psi on every well in conjunction with the planned BOP test once the CT unit is rigged up. That is well below the 9 5/8" casing min burst for any of the wells. There looks 1 tQ be S-95 9 5/8" casing with weights from 40 ppf to 47 ppf in the upcoming wells. You should be able to test against the upper cement plug in the wells to 2500 psi with no issue. Lowest burst is 6820 psi for 40 ppf casing . Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Juranek, Tom A [ iailto:tom.a.iuranek@exxonmobil.com] Sent: Wednesday, December 04, 2013 12:38 PM To: Schwartz, Guy L (DOA) Cc: Dragnich, Rob /EXT; Denman, Erika /C Subject: RE: PTU#3 P & A ( PTD 178-005) Guy, Currently, we are planning to test the upgraded wellhead equipment as follows: - Install a 13-5/8" 5K psi x 13-5/8" 10K psi custom built Pack -Off Adapter and run in lock screws. Install a 13-5/8" 10k psi x 11" 10k psi spool. Energize secondary seals as required. Test void (between primary and bottom secondary seal) to 5,000 psi. Test between the two secondary seals to 4,000 psi. Please advise if this is acceptable or if you need further information. Thanks, Tom Juranek 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 emaii From: Schwartz, Guy L (DOA)[mailto:quX.schwartz@alaska.gov] Sent: Wednesday, December 04, 2013 1:02 PM To: Juranek, Tom A Cc: Dragnich, Rob /EXT Subject: RE: PTU#3 P & A ( PTD 178-005) Thanks Tom...that makes sense. One final question is how you will test the new tubing head flange and packoffs? It was not mentioned in the work sundry procedure. Will you test flange break against the existing cement plug or set a mechanical plug ? Once the new tubing head is installed and tested then you are back to normal BOP testing as indicated in step #6. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Juranek, Tom A[rnailtoaom.aTiuranek@exxonmobil.com] Sent: Wednesday, December 04, 2013 9:46 AM 2 To: Schwartz, Guy L (DOA) Cc: Dragnich, Rob /EXT Subject: RE: PTU#3 P & A ( PTD 178-005) Guy, Here is a diagram which shows how the new packoff is different and will isolate from the 5k psi equipment. There are two pages. The first page shows the existing packoff. The second page shows the new packoff which has an extended neck into the new 10k psi tubing head. Please let me know if this sufficiently answers your questions or if you require something additional. Thanks, Tom Juranek Subsurface Engineering Advisor ExxonMobil Production Company 800 Bell Street, CORP -EMB -30395, Houston, TX 77002 Phone: 713-656-4225; Fax: 713-656-7353; BB: 832-596-5406 email: t m a,i �np4( axx�rmnEjil,rOm From: Schwartz, Guy L (DOA) [;nailtoguy.schwartznalaska. ov] Sent: Tuesday, December 03, 2013 7:38 PM To: Juranek, Tom A Subject: PTU#3 P & A ( PTD 178-005) Tom, For PTU #3 can you supply a wellhead diagram showing the custom 13 5/8" packoff (10K x 51(psi) adaptor installed as well as the new tubing head. The IA valves are 5K so I was curious how the system would isolate that part of the wellhead. Any issues with SimOps since this is on the active construction pad? Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office Schwartz, Guy L (DOA) From: Peterson, James M /C <james.m.peterson@exxonmobil.com> Sent: Wednesday, April 16, 2014 3:09 PM To: Schwartz, Guy L (DOA); Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Dennis Collins; Winter, Cassondra E; Juranek, Tom A; Hawthorne, Brian K; Bill Penrose; Dragnich, Rob /EXT; Denman, Erika /C; Greene, Timothy L; Farrar, Kendall N; shane.mcgeehan@solstenxp.com; bob.hagberg@solstenxp.com; Steve Lewis Subject: RE: PTU #3 Daily Report tz;17 1) l7S -bos ExxonMobil Daily Report Point Thompson Unit #3 4/14/2014 Completed dressing up casings, took photos of cmt., completed welding out marker — took final photos. AFC to back fill excavation. Final Report on Well. 4/13/2014 HSM, Cut 20", 13-3/8" and 9-5/8" casings with Washs, Run in 1" pipe and pump cement top job in casings. SDFN 4/12/2014 HSM, cut and remove 30" conductor pipe chip away cement. Ready for planned cement top job 4/13/2014. SDFN 4/11/2014 HSM, Completed excavation around well head, ready for WH removal. SDFN 4/10/2014 HSM, Continue excavating around WH for cutting wellhead off. SDFN 4/9/2014 HSM, MIRU SLB, pump down 9-5/8" annulus 212 bbls Arctic Set 1 cmt 15.7 ppg at 4 bbls per minute starting pressure 1000# ending 100#. RDMO SLB. MIRU little red pump diesel down 9-5/8" casing pressured up to 2000#. RDMO 4/8/2014 MI cement silos and fill. 4/7/2014 HSM, Finish excavation around WH exposing 9-5/8" x 13-3/8" annulus. MIRU Little Red, pressure test lines 3000#, pump total of 60bbls diesel, initial rate 0.4 bpm @ 1200# slowly increasing rate to 5 bpm max pressure 1960# ending pressure 1640#. SD RDMO. Had planned cement job for 4/8/2014 postponed unable to get cement trucks. James (Jim) Peterson ExxonMobil Workover Supervisor Cell: 281-610-6630 • 7�7" --‘,--CiF �\V/7;,�� HE STATE cKe. yy 7 a _ � S _ � 333 West Seve',1h Avenue G I'RNOR SEAN Y'ARNELI. Anchorage Alaska 99501 3572 Main 907.279 1433 PA Fr,).. ;07.26.7.`,e`. Irene T. Garcia SCO SSHE Manager 1 8 Exxon Mobil Corporation P.O. Box 196601 Anchorage, AK 99519-6601 Re: Point Thomson Field, Exploratory Pool, Point Thomson Unit#3 Sundry Number: 314-228 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 this 11' day of April, 2014. Encl. • STATE OF ALASKA ,t, :k 0 9 '.: ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon 0 Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program0 4 Suspend❑ Plug Perforations❑ Perforate 9 Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Aker Casing❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Exxon Mobil Corporation Exploratory 0 • Development ❑ 178-005 ' 3.Address: Stratigraphic ❑ Service Ill 6.API Number: PO Box 196601,Anchorage,AK 99519-6601 50-089-20007 ' 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 0 Point Thomson Unit#3 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 47559 surface/ADL 47558 BHL Point Thomson Unit 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): 14,125 13,151 0 0 Many plugs,see schematic None Casing Length Size MD TVD Burst Collapse Structural Conductor 784' 18-5/8" 811' 811' 2,420 1,700 Surface 3,311' 13-3/8" 3,338' 3,298' 5,380 2,670 Intermediate 10,320' 9-5/8" 10,347' 9,681' 8,150 7,100 Production 4,612' 7" 14,114' 13,140' 13,700 13,010 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 TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program 9 BOP Sketch 9 Exploratory ❑✓ • Stratigraphic❑ Developmen❑ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: April 9,2014 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: 4(•If./K WINJ ❑ GINJ ❑ WAG ❑ Abandoned 9. Commission Representative: (? SC-44,./ GSTOR 1=1] SPLUG CI17.I hereby certify that the foregoing is true ar d correct to the bes of my knowledge. Contact Tom Juranek 713-656-4225 Email tom.a.juranek@exxonmobil.com Printed Name Irene T.Garcia Title SSHE Manager SignaturePhone Date 4L(4, 1,4yeizi e, 1� � 907-564-3773 , [/q// LI COMMISSION USE ONLY �7 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 y ..„47.ali. Plug Integrity BOP Test ❑ c�Qschanical Integrity Test ❑ Location Clearance [} Other: r A A� ✓rt•. 5 poi r( e.....,,.- are /u ZG ,4.4 c-Z : //2_, ;) RBDM MAY U 9 Z014 Spacing Exception Required? Yes ❑ No Lid Subsequent Form Required: /O— yQ 7 01,/.47 APPROVED BY > /Approved by: P� 1/4,4„......._...-- COMMISSIONER THE COMMISSION Date: 4 1/-/ C/` ) c,c"6t) - `t'•it. /K ,i, y NitAt ( QTRI,,G+4,AL12 ppSubmit Form and Form 10-403 Revised 10/2012 months from the date of approval. Attach s i D to RECE VED ExxonMobil Production Company I P.0.Box 196601 APR 7 Anchorage,Alaska 99519-6601 t� 0 9 _J1,1, 907 561 5331 Telephone AOGCC EkonMobil Production April 9, 2014 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 RE: Request for Procedure Modification Well Abandonment: Point Thomson Unit #3 (PTD No. 178-005) Dear Commissioner Foerster, ExxonMobil hereby requests approval of a modification to its previously-approved procedure to perform plugging and abandonment work on the subject well. Our original procedure called for drilling through the surface cement plug in the 9-5/8" casing in order to: 1) Perforate the 9-5/8" casing at ±2,000' to squeeze the 9-5/8" x 13-3/8" annulus from ±2,000'to the 13-3/8"shoe at 3,338', 2) Fill the 9-5/8"casing with cement from ±2,000'to ±1,500', 3) Perforate the 9-5/8"casing at 200'to circulate cement into the 9-5/8"x 13-3/8"annulus from 200'to surface. However, before rigging up on the well with coil tubing equipment, a planned attempt to bullhead into the 9-5/8"x 13-3/8" arctic packed annulus was successful and we plan to fill that annulus with cement from the surface to the 13-3/8"casing shoe at 3,338'. This annular cement satisfies goals 1) and 3) above. Goal 2) was planned as a plug-of- opportunity and is not required for the plugging and abandonment of this well per AOGCC regulations. ExxonMobil therefore proposes to finish the plugging and abandonment of this well by pumping the bullhead cement job down the 9-5/8"x 13-3/8"annulus, leaving intact and pressure testing to 2,000 psi the existing surface cement plug in the 9-5/8" casing, cutting off the wellhead and all casings at 3' below tundra level, topping off the casing and all annuli with cement to surface and installing a marker plate. r.<((1-(:4 row`/`AA Z0 efIL Note: An exception is requested for an approximate 70-75' surface cement plug inside the 9- 5/8" casing. The top of the existing 60' plug is 15' below ground level and will be filled with cement to the cutoff point with cement. The downhole plugs in this well were pressure tested and/or tagged during the original suspension procedure and no other downhole work is required. This is consistent with previous guidance provided by the AOGCC. The existing plug was verified as being competent during well suspension operations in July of 1979 and remains undisturbed. We will pressure test the plug to 2,000 psi to verify that it is competent. Attached please find the following to support this request: • Revised Form 403 Application for Sundry Approval • Proposed post-P&A well schematic If you have any questions or require additional information, please contact me at (907) 564- 3773 or Tom Juranek at 832-624-6940. Sincerely, of_ grx/t Irene T. Garcia SSHE Manager Attachment POINT THOMSON It PRODUCTION Exxon Mobil Corporation Point Thomson Unit#3 API#: 50-089-20007 PTD#: 178-005 Proposed Post-P&A Well Schematic Marker Plate >_3' below tundra level 1111111M111" Cement plug from surface — 100' (>_3'-75' BGL) in 9-5/8" casing 10.2 ppg ',' CaCl2 s 18-5/8", 96.4 ppf, K55, BTC cond csg at 811' MD (811' TVD), ': Brine cmtd w/ 4,300 sx permafrost { Cement in 9-5/8" x 13-3/8" annulus from surface to shoe at 3,338'. 1. �� 4 Cast iron bridge plug at 2,000' MD I 15.8 ppg I s Fresh ,; ' 13-3/8" 72 ppf, L80, BTC surf csg at 3,338' MD s Water t (3,298' TVD), cmtd to surf w/ 3,750 sx permafrost r s Mudk TOC behind 9-5/8" casing estimated at 5,000' s • s Top of cement in 9-5/8" casing at 8,869' MD F �� 111 Baker cement retainer at 9,019' MD s . 15.8 s ppg -. s • Fresh 7", 35 ppf, P110, BTC production casing stub at 9,502' MD s s_•• Water •• s Mud '' 9-5/8" 47# Soo-95 at 10,347' MD (9681' TVD), cmtd w/ 2,450 s sx class G s Top of cement inside 7" casing at 13,612' MD ' 5 Top of cmt outside 7" csg at 13,664' MD per cmt bond log s -'1111's Halliburton cement retainer at 13,847' MD '. �4 ►�� s Baker model F-1 production packer at 13,852' MD s — Perforations 13,872' — 13,885' MD, 2 spf, 180° ,I•�� , Cast iron bridge plug at 13,890' MD \,,,; ►�� .$ Baker model F-1 production packer at 13,892' -s Perforations 13,908' — 13,925' MD, 2 spf, 180° ;,. :' Top of cement inside 7" casing at 14,024' MD (float collar) ''r :.f 7", 35 ppf, P110, BTC, prod csg at 14,114' MD (13,140' • 5 ' ''. - TVD), cmtd w/ 1,035 sx class G '5 8-1/2" open hole TD at 14,125' MD (13,151' TVD) Point Thomson Unit#3 Current Sketch PlitgiMeell Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent: Friday,April 11, 2014 9:56 AM To: 'Juranek,Tom A' Cc: Winter,Cassondra E;Collins, Dennis/C Subject: RE: Point Thomson Unit#3(PTD No. 178-005) - Request for Procedure Modification Tom, You have verbal approval to change the P&A as proposed. The existing surface plug of 75' length has been tested previously and will provide adequate barrier. Additionally,there are no diesel or hydrocarbon fluids in the 9 5/8" casing that need to be removed. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Juranek,Tom A[mailto:tom.a juranek@exxonmobil.comj Sent: Friday, April 11, 2014 9:43 AM To: Schwartz, Guy L(DOA) Cc: Winter, Cassondra E; Collins, Dennis/C Subject: FW: Point Thomson Unit #3 (PTD No. 178-005) - Request for Procedure Modification Guy, We are seeking verbal approval of the attached sundry procedure modification. We have successfully bullheaded cement in the 9-5/8" by 13-3/8" annulus from surface to the shoe at 3,338'. We would like to top off and leave the existing surface plug in the 9-5/8" casing which requires an exception as it will be±70'-75'thick rather than the required 150'. With approval,we will expose and cut off the wellhead>_3' below tundra,top off all strings with cement, and weld on a marker plate. Thanks, Tom Juranek Subsurface Engineering Advisor ExxonMobil Production Company Global Engineering-Subsurface Engineering&Operations Support 800 Bell Street,CORP-EMB-30211,Houston,TX 77002 Lync Phone:832-624-6940;Fax:713-656-7353; iPhone:832-596-5406 email:tom.a.iuranek@exxonmobil.com From: Winter, Cassondra E Sent: Wednesday, April 09, 2014 1:42 PM To: quv.schwartz@alaska.gov Cc: Juranek,Tom A Subject: PTU 3 Sundry Application Guy, FYI-Two original versions of the attached document will be dropped off at AOGCC receptionists desk at"'11AM today (attn.: Guy Schwartz). 1 Thanks, ' Cassondra Winter 2 III ► Schwartz, Guy L (DOA) From: Peterson,James M/C <james.m.peterson@exxonmobil.com> Sent: Thursday,April 10, 2014 8:25 AM To: Schwartz,Guy L(DOA); Regg,James B (DOA); DOA AOGCC Prudhoe Bay; Dennis Collins; Winter, Cassondra E;Juranek,Tom A; Hawthorne, Brian K; Bill Penrose; Dragnich, Rob /EXT; Denman, Erika IC;Greene,Timothy L; Farrar, Kendall N; shane.mcgeehan@solstenxp.com; bob.hagberg@solstenxp.com; Steve Lewis Subject: RE: PTU #3 Daily Report III (78— Q0 ExxonMobil Daily Report Point Thompson Unit#3 4/9/2014 HSM, MIRU SLB, pump down 9-5/8"annulus 212 bbls Arctic Set 1 cmt 15.7 ppg at 4 bbls per minute starting pressure 1000#ending 100#. RDMO SLB. MIRU little red pump diesel down 9-5/8"casing pressured up to 2000#. RDMO 4/8/2014 MI cement silos and fill. 4/7/2014 I'I HSM, Finish excavation around WH exposing 9-5/8"x 13-3/8"annulus. MIRU Little Red, pressure test lines 3000#, pump total of 60bbls diesel, initial rate 0.4 bpm @ 1200#slowly increasing rate to 5 bpm max pressure 1960#ending pressure 1640#.SD RDMO. Had planned cement job for 4/8/2014 postponed unable to get cement trucks. James(Jim) Peterson ExxonMobil Workover Supervisor Cell: 281-610-6630 Email: james.m.peterson@exxonmobil.com Email: leyvapeterson@aol.com 1 or��_6. THE STATE Alaska Oil and Gas ofALAsKA GOVERNOR SEAN PARNELL 333 West Seventh Avenue 0/4; ;a- Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Irene T. Garcia �`� 0� SSHE Manager SC1° ExxonMobil Oil Corporation Q 0o PO Box 196601 en Anchorag e, AK 99519 Re: Point Thomson Unit, Point Thomson Unit #3 Sundry Number: 313-602 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. oerster Chair DATED this Ay of December, 2013. Encl. ii,L, RECEIVED STATE OF ALASKA xlANO NOV 19 20133 ALASKA OIL AND GAS CONSERVATION COMMISSION 2 120 3 APPLICATION FOR SUNDRY APPROVALS ACC 20 AAC 25.280 1.Type of Request: Abandon 0 • Plug for Redrill 0 Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time/� Extension ID Shutdown❑ Re-enter Susp.Well Stimulate❑ Alter Casing❑ Other. rikigp 5.,, .` PA* 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. 24 Exxon Mobil Corporation Exploratory Q • Development ❑ 178-005 • it•3•/3 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: PO Box 196601,Anchorage,AK 99519-6601 50-089-20007 • 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 0 Point Thomson Unit#3 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 47559 surface/ADL 47558 BHL Point Thomson Unit 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): 14,125 • 13,151 • 0 0 Many plugs,see schematic None Casing Length Size MD TVD Burst Collapse Structural Conductor 784' 18-5/8" 811' 811' 2,420 1,700 Surface 3,311' 13-3/8" 3,338' 3,298' 5,380 2,670 Intermediate 10,320' 9-5/8" 10,347' 9,681' 8,150 7,100 Production 4,612' 7" 14,114' 13,140' 13,700 13,010 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 TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory Q ' Stratigraphic❑ Developmen[ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: August 1,2014 CommencingOperations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned E• Commission Representative: GSTOR El 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 j, Phone 907-564-3773 Date fill•s// COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: fir' 3V3�6e.0Q. Plug Integrity Wir BOP Test III Mechanical Integrity Test LI -( Location Clearance Q"ZDi' Other: ,( MOO( O j,OSi: I nt 1a !GS 1— Pl-f,4 We C--4.--•)..e-A..--1— C.4...s i„i 4----5,1 Ewe./JJ ,olf, Or Spacing Exception Required? Yes ❑ No Subsequent Form Required: /6- 'its ,`Z RBDM mb` MAY © 9 2014 Approved by: I� APPROVED BY - C COMMISSIONER THE COMMISSION Date: /Z -2,0 -/ �ubmit Form and ,•,� Form 10-403(Revised 10/2012) Ap p IiG1 N ILj months from the date of approval. Attachments in Duplicate `.VV \\ • ExxonMobil Production Compa, P.0. Box 196601 RECEIVED Anchorage,Alaska 99519-6601 907561 5331 Telephone NOV 19 2013 E onMobil AOGCC Production November 15, 2013 R-2013-OUT-023 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Re: Application for Sundry Approval Well Abandonment: Point Thomson Unit#3(PTD No. 178-005) Dear Commissioner Foerster, • ExxonMobil hereby applies for Sundry Approval to perform 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(40'— 100'). ' 2. Place cement isolation plugs in the 9-5/8" casing and annulus "near" the 13-3/8" shoe. Methods to accomplish this include: - Buliheading cement down the 9-5/8" annulus to ±3,338' and laying cement from ±2,000' to ±1,500' in the 9-5/8"casing. - Circulating cement into the 9-5/8" casing and annulus through perforations in the 9-5/8" at ±2,000'. The 9-5/8"casing and annulus would be cemented from ±2,000' to surface. - Squeezing the 9-5/8" annulus through perforations at ±2,000'. The annulus would be cemented from ±3,338'to±2,000' and the 9-5/8"casing would be cemented from ±2,000'to±1,500'. - Squeezing the 9-5/8" annulus through perforations at ±3,375'. The annulus would be cemented at ±3,375' and the 9-5/8"casing would be cemented from ±3,375'to±1,500'. 3. Set the necessary surface plugs in the 9-5/8"casing and annulus (±200'to surface). 4. Cut off the wellhead and all casing strings at least 3' below the natural tundra level. 5. Top off the 9-5/8"casing and all annuli with cement. 6. 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 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 4i'l, PRODUCTION POINT THOMSON UNIT#3 WELL HISTORY AND ABANDONMENT PROCEDURE Affected Wells and API/APTD Numbers: Point Thomson Unit#3 API # 50-089-20007 APTD#: 178-005 Background: Point Thomson Unit #3 was drilled in 1979. The well was suspended on July 4, 1979. It is now planned to plug and abandon the well, which requires the 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 ' 0 - below ground level consistent with current AOGCC regulations. In addition, for improved the -K % 0.., long term integrity of the abandonment, a cement plug is planned for inside and outside the 443 9-5/8" casing near the 13-3/8" shoe at 3,338'. The current well schematic is attached to this el ✓ procedure. .‘.4021 is ee 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. tit 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 „Ai? However, pressure (±7,900 psi) encountered below the surface plug based upon Thomson 1ti Sand reservoir pressures. Therefore, the wellhead will be upgraded to 10k psi rating and €)kiBOPs and the Coil Tubing Unit will be rated to 10,000 psi. OBJECTIVE: ■ Drfe40 '. \i. , • Placerill cement throughthe isolationsuace plugs ceminnt theplug 9-5/8at "0'casing-10and annulus near the 13-3/8" shoe. Methods 6e)y to accomplish this include: V o Bullheading cement down the 9-5/8" annulus to±3,338' and laying cement from ±2,000' �� to±1,500' in the 9-5/8" casing. fli 0,.$ o Circulating cement into the 9-5/8" casing and annulus through perforations in the 9-5/8" at 1 ±2,000'. The 9-5/8" casing and annulus would be cemented from ±2,000' to surface. o Squeezing the 9-5/8" annulus through perforations at±2,000'. The annulus would be cemented from ±3,338'to ±2,000' and the 9-5/8" casing would be cemented from ±2,000' to±1,500'. o Squeezing the 9-5/8" annulus through perforations at±3,375'. The annulus would be cemented at±3,375' and the 9-5/8"casing would be cemented from ±3,375' to ±1,500'. • 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. NOTE:For purposes of AOGCC approval, ExxonMobil commits to removing hydrocarbons within 150'of the surface and installing a 150'surface cement plug in all casing and annuli. However, because we plan to work through a few scenarios to accomplish this, the final P&A sketch could vary depending on what we find during this procedure. We have chosen to display what we feel is the most likely case as the Post P&A sketch. We can supply and discuss other potential versions at your request. Point Thomson Unit#3 Abandonment Procedure POINT THOMSON 4ra PRODUCTION 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. If possible, keeping pressure no higher than 2,500 psi, bullhead cement down the 9-5/8" x 13-3/8" casing from surface to the 13-3/8"shoe at±3,338'. , .• 3 i3 Q 4. Remove the 13-5/8" 5K psi cap and marker post. Measure the depth to the cement in the 9-5/8"casing (expect±40'). Install a 13-5/8" 5K psi x 13-5/8" 10Kpsi custom built Pack- . .._ Off Adapter. Install a 13-5/8" 5K psi x 11" 10k psi tubing head. This will increase the pressure rating of the wellhead to 10K psi. /es .f/‹..3„,_ 4 Z s07> ,p v fr 5. Notify AOGCC of planned BOP testing and confirm steps to be witnessed throughout operation. 6. 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. 7. Rig Up the Coiled Tubing unit and test the CT BOPs to 8,000 psi. 8. Drill out the surface cement plug from ±40' -±100'. 9. Clean out the 9-5/8"casing to the 9-5/8" CIBP at±2,000'. 10. If successful in bullheading cement(step 3 above), lay cement in the 9-5/8"casing from the±2,000' to ±1,500' and skip to step#15. 11. If bullhead attempt(step 3 above)was unsuccessful, perforate the 9-5/8"casing just above the CIBP at±2,000' and attempt to establish circulation down the 9-5/8" and up the 9-5/8"x 13-3/8"annulus. If successful, circulate cement from perfs at±2,000' to surface in the 9-5/8" casing and annulus. 12. If circulating was unsuccessful, attempt to squeeze through the 9-5/8" perfs at±2,000' to the 13-3/8" shoe at 3,338'. If able to inject, squeeze cement from ±3,338'to±2,000' in the 9-5/8" annulus and from ±2,000' to±1,500' in the 9-5/8"casing. 13. If unable to circulate or squeeze with perfs in the 9-5/8" casing at±2,000', drill a hole in the CIBP at±2,000' &clean out the 9-5/8"to±3,375'. Perf the 9-5/8"casing at±3,375' (below the 13-3/8"shoe). If injectivity is established, squeeze cement through the perfs in the 9-5/8"at±3,375', leaving cement from ±3,375'to±1,500' in the 9-5/8" casing. 14. If injectivity is still unsuccessful, lay cement in the 9-5/8"from ±3,375'to±1,500'. Point Thomson Unit#3 Abandonment Procedure ( POINT THOMSON PRODUCTION 15. Set a CIBP in the 9-5/8" casing at±200'. 16. If prior attempts to bullhead or circulate into 9-5/8" x 13-3/8" annulus were unsuccessful, perforate 9-5/8" casing just above the CIBP at±200'. If possible, circulate cement into the 9-5/8" x 13-3/8" annulus from ±200' to surface. 17. Fill the 9-5/8" casing with cement from ±200' to surface. 18. Rig down the Coiled Tubing Unit. 19. Excavate deep enough to allow removal of the wellhead at least 3' below original tundra level. 20. Remove glycol mixture refrigerant from both annuli of the refrigerated/insulated conductor via compressed air or by vacuum. Pump returns from catch pan to waste tank. 21. Cut and remove the wellhead using a Wachs saw. 22. If the 9-5/8" x 13-3/8" annulus is not already cemented to surface, 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. 23. Run 1"jointed pipe inside the 32"x 36" conductor casing as deep as possible. Leave jointed pipe in hole for cementing to follow 24. Run 1"jointed pipe into 28" x 32" conductor annulus as deep as possible. Leave pipe in annulus for cementing to follow. Notes: • If unable to run 1" pipe to 150' or deeper in Step 22, run pipe as deep as possible and contact AOGCC to obtain approval for alternative depth. • The configuration of refrigeration tubes and insulation in the conductor is uncertain. The intent is to remove as much of the refrigerant fluid and to run tubing as deep in the conductor annuli as possible in order to fill the annuli with as much cement as possible. 25. Pump cement to surface in both conductor annuli. Top off 28" x 32"x 36" refrigerated/insulated conductor casing with cement as required. 26. Pump cement to surface in the 9-5/8"x 13-3/8" annulus. Ensure good cement returns. Cut-off jointed pipes and leave in hole. Diesel returns from cementing to be pumped from catch pan to appropriate waste tank. 27. Cut all strings flush and top off the 9-5/8" casing and annuli with cement as required. Point Thomson Unit#3 Abandonment Procedure1111111111111111111111111111111111111111111 ••••. POINT THOMSON • r PRODUCTION 28. Level casing stub using a grinder. Weld marker plate(±36" OD)with well information across all casing strings. Marker plate to contain the following information bead welded onto it: Point Thomson Unit#3 Exxon Mobil Corporation PTD# 178-005 API # 50-089-20007 29. Backfill cellar with gravel and compact to Point Thomson Project specifications. 30. 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. Point Thomson Unit#3 Abandonment Procedure1111111111111.1111111111111 POINT THOMSON • (o, PRODUCTION Exxon Mobil Corporation Point Thomson Unit#3 API#: 50-089-20007 PTD#: 178-005 Current Well Schematic Wellhead A-section in place with 13-5/8" x 3" capped flange and marker post on top Diesel Diesel to surface from 40' (15' BGL) in 9-5/8" casing 10.2 ppg Cement plug from 40' — 100' (15'-75' BGL) in 9-5/8" casing :.F CaCl2 5 18-5/8", 96.4 ppf, K55, BTC cond csg at 811' MD (811' TVD), fi ` Brine cmtd w/ 4,300 sx permafrost fi Arctic Pack in 9-5/8" x 13-3/8" annulus .1 Cast iron bridge plug at 2,000' MD 15.8 ppg Fresh 13-3/8" 72 ppf, L80, BTC surf csg at 3,338' MD Water (3,298' TVD), cmtd to surf w/ 3,750 sx permafrost 5 Mud TOC behind 9-5/8" casing estimated at 5,000' • Top of cement in 9-5/8" casing at 8,869' MD —�—�' Baker cement retainer at 9,019' MD 15.8 ppg Fresh 7", 35 ppf, P110, BTC production casing stub at 9,502' MD s:-• Water •• Mud ;, 9-5/8" 47# Soo-95 at 10,347' MD (9681' TVD), cmtd w/ 2,450 sx class G 415?) P s` Top of cement inside 7" casing at 13,612' MD Top of cmt outside 7" csg at 13,664' MD per cmt bond log Halliburton cement retainer at 13,847' MD 5 5 Baker model F-1 production packer at 13,852' MD — Perforations 13,872' — 13,885' MD, 2 spf, 180° Cast iron bridge plug at 13,890' MD ,STA Baker model F-1 production packer at 13,892' Perforations 13,908' — 13,925' MD, 2 spf, 180° Top of cement inside 7" casing at 14,024' MD (float collar) ;. .. j 7", 35 ppf, P110, BTC, prod csg at 14,114' MD (13,140' TVD), cmtd w/ 1,035 sx class G -"' 8-1/2" open hole TD at 14,125' MD (13,151' TVD) • Point Thomson Unit#3 Current Sketch 141POINT THOMSON 6 PRODUCTION Exxon Mobil Corporation Point Thomson Unit#3 API#: 50-089-20007 PTD#: 178-005 Proposed "Most-Likely" Post-P&A Well Schematic Marker plate-3'below tundra level Cement plug from 200'to surface in 9-5/8"casing • :. ... ;41 • Cement plug in 9-5/8"x 13-3/8"annulus 200'to surface i-.. i • / Perfs in 9-5/8"csg just above CIBP at±200'. z / CaCl2 �. Brine ' CIBP in 9-5/8" set at±200'. o , 18-5/8", 96.4 ppf, K55, BTC cond csg • 0. • , s Arctic Pack in 9-5/8"x 13-3/8"annulus±1,995'to 200' o •`' ' ' s rperfs in 9-5/8"csg just above CIBP at±2,000'. •o s Cement plug in 9-5/8"x 13-3/8"annulus±2,000' to±3,338'. ' 15.8 ppg 9-5/8" CIBP at±2,000'with cmt from ±2,000' to±1,500' ..- Fresh Water 13-3/8" 72 ppf, L80, BTC surf csg at 3,338' MD(3,298'TVD), cmtd to Mud fi surf w/3,750 sx permafrost ••••- -- TOC behind 9-5/8"casing estimated at 5,000' y k X 4 Top of cement in 9-5/8" casing at 8,869' MD •'• „ABaker I Baker cement retainer at 9,019' MD e' fi 15.8 u `? Fresh ' fi 7", 35 ppf, P110, BTC production casing stub at 9,502' MD fi ': Water • fi 4 Mud w 9-5/8"47#Soo-95 at 10,347' MD(9681'TVD), cmtd with 2,450 sx class G Top of cement inside 7" casing at 13,612' MD Top of cmt outside 7"csg at 13,664' MD per cmt bond log :"1110,----- 1Halliburton cement retainer at 13,847' MD ;. ►=� Baker model F-1 production packer at 13,852' MD ' - Perforations 13,872'- 13,885' MD, 2 spf, 180° ',0110------ •_-_ _ Cast iron bridge plug at 13,890' MD .'►11� ►.M. .• Baker model F-1 production packer at 13,892' .. - Perforations 13,908'- 13,925' MD, 2 spf, 180° : , Top of cement inside 7" casing at 14,024' MD(float collar) 7", 35 ppf, P110, BTC, prod csg at 14,114' MD(13,140' TVD), cmtd w/ •'�;� ". 1,035 sx class G . • , •'`. 8-1/2"open hole TD at 14,125' MD(13,151'TVD) Point Thomson Unit#3 Proposed Most-Likely Sketch 111 POINT THOMSON .. ti. :: PRODUCTION BOP Configuration ("6.4"Ift41( g irielil 1 �r a I ITIT Injector Head for 2' coiled tubing 4 :.,.. It .'I;' — Dual peck-off < — 4.06" ID. 10k Lubricator as needed If' &8' sections} wit. ' ®1 • Irl: 8114 1 i t * I' I.I 5h"r 1. 5L9 Quad @OP, 10k 14 I a n r, I 7 Slips I . ti I Pipe 7 ft--- ., .. SIB Combi BOP, 10k _. — ---- 11", 10k x 4 1./1.6"„10k x-off-- (flange to be used for BHA changes) 11". 10k Spacer Serol,3 ft ',' "..� ,,�y - 11", 10k Flow Crl II I/,TIT^I I 10 ft =mow l I.+• CM y• -' 11'',10k Blind Ram t4'. ' 1111 :1_ . ��11 I I KiY1.1 ,.rte 11'',10k Blind/Shear Ram - Wellheads to be upgraded to 10 k service Point Thomson Unit#3 Planned BOP Assembly ,c, . • � ..._. 1 I t a.�,-� - R 113*,s ea 38 "'�'+- -. I. - a 36 — � h . •• .r�.'''''‘9."339.I.i : _ MM. i. 35 .-T .4__j ( „ n• , •' P ) .. r eta -'_Q --•tdc �i /-. , - a . �: �T .1 t_: ri u \ ! PTU. „,. , , . • 9�„0 • • 600 1 ° r.„ ...., ...,..„:: • •w :.q —_ , ,p$� 6 _� !,^ ei I, ie 7 I 9 9 3 Ir. -•N I, JJ(f p K_• 7 �.. r • ` 62 i I♦ l! LB 17 IS I. a 1, A•1-------.!_.,-• 16 1•„"•!:::,I Alaska lite A--4 °' ..,iW Stas es -tide 18=O9-23,__. 6, , y 1' _ /10 0` 23 . 19 22 >J• 2= r 19 19 36 21 •N. 9! !! (Q� b °� ' -1-- -� 5-ti x: 1%y� 25 i • 76- as .:: --41! West-2 tains*,No12 �9 e 0 26 xd 5f- I • 0 Q 3' `-$ 31 ___M ...- d7 ....{--_.._ H !! -_•_:1—.—.1 y 31 31 ••'/ 32 „ 11. / 3. 4.1466. 35 a, -_ ._ I _I \/ 1 , \ slap / .4e...\” '76 d + 6 ` 3 2 - - .'t' a 0 ._ 'L1 . I , •v x Ci 1 /�� II A I , K —. - 1 _ j1r ._-. • _. pp 7 I l li ! 10 Il 72 - + 1 ,.,CU I •\ 1 II I - --_.. -...-_-.-- _ter .:. ...._ I6 -V 17 1 1{' Id 1. 73 I6 17 I IC I 1a 1, ....11------",,_,11. 17 ___ ... • ... ., { 9N a xl 32 !a 74 19 7C `31 71 2:P. !! 24 1!• e xD 4. I -1 (i- 444 % 4.:\_ ' 1 - V. i' ! 2 /c i 76 2, 26 / - 25 ., 36 29 /40t••/'7622 _ 27 �'-''-\x6 26 it 36 ,.@p(� i ....r - _� I Y -,.-",.,• 777 `•Y \y-f'. - 4s,{ •....a'-- 3] I' 3. '1 2?-_.' a a 63 33 \�.\! 36 c� ./I �� \ 1 1 J l` 1 33 - -i6 C.: �32 ` _ 16 .p I- .• 2 i 3!-33 ,6 1 M ....3 ( 31 1! , .. Iv r 1;' X?.\ f / git I7 7 6 9 9 16 Il i ./ f . ,..,17;,d..471 S• cit .L.1 pot - 1:40,"•----- • `^ 17 ql - 16 � 6 ' 15 ' i aY"y4 �1 y• a Alit1� 1' 16,� 17 16 16 „..15 rs � 3.•c >,,fid` Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, December 04, 2013 2:06 PM To: 'Juranek,Tom A' Cc: Dragnich, Rob/EXT; Denman, Erika/C Subject: RE: PTU#3 P&A(PTD 178-005) Tom, As we discussed plan on testing the lower tubing head flange to 2500 psi on every well in conjunction with the planned BOP test once the CT unit is rigged up. That is well below the 9 5/8" casing min burst for any of the wells. There looks to be S-95 9 5/8" casing with weights from 40 ppf to 47 ppf in the upcoming wells. You should be able to test against the upper cement plug in the wells to 2500 psi with no issue. Lowest burst is 6820 psi for 40 ppf casing . Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Juranek, Tom A[mailto tom.a.juranek a,exxonmobil_com] Sent: Wednesday, December 04, 2013 12:38 PM To: Schwartz, Guy L(DOA) Cc: Dragnich, Rob/EXT; Denman, Erika/C Subject: RE: PTU#3 P&A( PTD 178-005) Guy, Currently, we are planning to test the upgraded wellhead equipment as follows: - Install a 13-5/8" 5K psi x 13-5/8" 10K psi custom built Pack-Off Adapter and run in lock screws. Install a 13-5/8" 10k psi x 11" 10k psi spool. Energize secondary seals as required. Test void (between primary and bottom secondary seal) to 5,000 psi. Test between the two secondary seals to 4,000 psi. Please advise if this is acceptable or if you need further information. Thanks, Tom Juranek 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:tern.a,iuranek_2exxonmobil.cam From: Schwartz, Guy L(DOA) [rna_ilto:guy,schwartz(aalaska.cpo_y] Sent: Wednesday, December 04, 2013 1:02 PM To: Juranek,Tom A Cc: Dragnich, Rob/EXT Subject: RE: PTU#3 P&A( PTD 178-005) • Thanks Tom...that makes sense. One final question is how you will test the new tuning head flange and packoffs? It was not mentioned in the work sundry procedure. Will you test flange break against the existing cement plug or set a mechanical plug ? Once the new tubing head is installed and tested then you are back to normal BOP testing as indicated in step#6. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Juranek,Tom A [mailto:torpa,juranek(c6exxonmobil.com] Sent: Wednesday, December 04, 2013 9:46 AM To: Schwartz, Guy L(DOA) Cc: Dragnich, Rob/EXT Subject: RE: PTU#3 P&A ( PTD 178-005) Guy, Here is a diagram which shows how the new packoff is different and will isolate from the 5k psi equipment. There are two pages. The first page shows the existing packoff. The second page shows the new packoff which has an extended neck into the new 10k psi tubing head. Please let me know if this sufficiently answers your questions or if you require something additional. Thanks, Tom Juranek Subsurface Engineering Advisor ExxonMobil Production Company 800 Bell Street,CORP-EMB-30395,Houston,TX 77002 Phone: 713-656-4225;Fax: 713-656-7353;BB:832-596-5406 email:r m a.iu:anek 9exxonmobil corn From: Schwartz, Guy L(DOA) [mailto:guy.schwartzin��alaska.gov] Sent: Tuesday, December 03, 2013 7:38 PM To: Juranek,Tom A Subject: PTU#3 P&A( PTD 178-005) Tom, For PTU#3 can you supply a wellhead diagram showing the custom 13 5/8" packoff(10K x SKpsi)adaptor installed as well as the new tubing head. The IA valves are 5K so I was curious how the system would isolate that part of the wellhead. Any issues with SimOps since this is on the active construction pad? Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 2 PTU #3 Notes Csg head Approx 24" McEvoy Split Tubing head Approx. 24" Speedhead System 1. ,1 7" LP – needle valve azam p. irrsi Ip] 135,8"5k. -' 135,8"5k.— 0. I-'�1PNti P100001A161 PI .�,®..tffimf cP I�A In810.2560 ., dij, McEvoy 11.;.,--:.().: .. ;0 ,�. ..l: } t ,1. . . 1 1, II 1. 1 e MP1iii model "C' IA &OA v gives are 3-1,8 5k Serials BJ 172 MPd# P1000014761 2 L e Serial NNCIf1.7?fi3 f Y^ 0 N a) Q O O II 00 +• N L) f3 O c C I : CO O in 1 rr) CNCD D -a MD H N - 3 �' I O N z CL N. a_ /p q p q . , 1 �= .7- d -�-i 1 1- — o Z z 4- ,1 d - U I 1 rr C CD 00 co w I O Ln / A h I / J ,i Ali i, _.- O (I) 0 J 0 Q W DO I I— j \ \ cF—P /-3----irj r-- I I 1 1 0I I I -- - - ii � 1 1 I'II Q 1II LU ---T _ Hic (I) . L _ 1 IY, v / J ' C- 1 1 F— I 1 w 1 1 > 0 1 0 L Y Ln in E o Q O co ;1 O .-. \ I 0 in ote I O co rr) /--. 1 Cl- 1 r i 1 0 CD 1 11 z Q N U DO I Ln I I -- • : T , Schwartz, Guy L (DOA) From: Wong, Gilbert <gilbert.wong@exxonmobil.com> Sent: Friday, March 29, 2013 8:08 AM To: Schwartz, Guy L(DOA) Subject: RE:Vault installation on PTU#3 and Alaska State C-1 D -oo Guy, Thank you for the recap of the recent meeting between the Commission and ExxonMobil. To help us respond to your request most effectively,we would like to propose a technical meeting with you to ensure we have an aligned understanding of the specific work required to meet the AOGCC expectations. In addition to the PTU 3 and Alaska State C-1 wells, EM would also like to include in the discussion the three other wells that we requested to be reclassified from abandoned to suspended status per our letter dated March 17,2008. The three wells are: Point Thomson Unit#1 (PTD 176-085) Point Thomson Unit#2 (PTD 177-064) Staines River State#1(PTD 179-001) Our well remediation technical team will be in Anchorage during the week of April 28. We propose to meet with you on April 29 to discuss these. If that is an acceptable date, please advise as to your preferred time. If a different date that week would be better for you, please feel free to suggest an alternative. We look forward to meeting with you to discuss these wells. Regards, Gilbert Wong BTPO Operations Superintendent- Point Thomson Global Operations—ExxonMobil Production Office: 907-564-3607 Cell: 907-301-3318 Fax: 907-564-3705 e-mail: glibertworig@exxonmobil.com From: Schwartz, Guy L(DOA) [mailto_guy.schwartzalaska,gov] Sent: Wednesday, March 20, 2013 10:44 AM To: Wong, Gilbert Cc: Foerster, Catherine P (DOA) Subject: Vault installation on PTU #3 and Alaska State C-1 Gilbert, Cathy and I had a meeting this morning with Karen Hagedorn (Exxon Prod manager) to discuss the proposed installation of"vaults"over the wellheads on PTU#3 and Ak State C-1( PTD 178-005 and PTD 180-046). These two wells are currently secured downhole properly and are awaiting final surface P&A. 1 • • In order for the AOGCC to approve these enclosures we are requesting a written umeline for final P&A(cut off of surface wellhead and cement to surface) of the wells or operational justification to keep them as is. We understand the overriding driver is to proceed with the facility and production installation of the Point Thomson startup. The Commission is willing to work with Exxon to ensure the production facility construction timeline and Sim Ops concerns are addressed. It is our understanding that the vaults will still enable the required 5 year inspection cycle to continue but the Commission's position is that the wells must be properly abandoned at the soonest possible period. Additionally,the Commission will change the official well status from "P&A"to"Suspended" as requested back in 2009. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office 2 • From: Schwartz, Guy L (DOA) Sent: Wednesday, March 20, 2013 10:44 AM To: Gilbert Wong (gilbert.wong(aexxonmobil.com) Cc: Foerster, Catherine P (DOA) Subject: Vault installation on PTU #3 and Alaska State C -1 Gilbert, Cathy and I had a meeting this morning with Karen Hagedorn (Exxon Prod manager) to discuss the proposed installation of "vaults " over the wellheads on PTU #3 and Ak State C-1 ( PTD 178 -005 and PTD 180 -046). These two wells are currently secured downhole properly and are awaiting final surface P & A. In order for the AOGCC to approve these enclosures we are requesting a written timeline for final P & A (cut off of surface wellhead and cement to surface) of the wells or operational justification to keep them as is. We understand the overriding driver is to proceed with the facility and production installation of the Point Thomson startup. The Commission is willing to work with Exxon to ensure the production facility construction timeline and Sim Ops concerns are addressed. It is our understanding that the vaults will still enable the required 5 year inspection cycle to continue but the Commission's position is that the wells must be properly abandoned at the soonest possible period. Additionally, the Commission will change the official well status from "P &A" to "Suspended" as requested back in 2009. Regards, Guy Schwartz Senior Petroleum Engineer SCANNED BAR 2 0 201 3 AOGCC 907 - 444 -3433 cell 907 - 793 -1226 office Page 1 of 3 . • Schwartz, Guy L (DOA) From: Rob Dragnich [rob @rgdragnichlIc.com] Sent: Friday, January 04, 2013 12:00 PM To: Schwartz, Guy L (DOA) Cc: Fowler, Bill Permits /C; Gilbert Wong Subject: Re: PTU 3 (PTD 178 -005) and Alaska State C -1 (PTD 180 -046) Wellhead "Vaults" Hello Guy, 44 ? Thank you for your response and questions about the wellhead vaults. As a practical matter, there will not be any weight limitations. The vaults will be designed to support the largest loads envisioned to travel across the pad including drilling rigs and 4000 ton modules on Singe Point Module Transporters (SPMTs). A surface marker will not be installed because it would create traffic obstructions . The location of the wellheads and vaults will be shown on as -built drawings to ensure no incompatible future activities occur in the area. The wells and vaults can easily be located in the future using measurements from the drawings. Other means could include GPS coordinates and metal detectors. Given the massive steel plates and relatively shallow gravel cover, metal detectors should provide simple and positive locations. With respect to future plans, although these wells are not planned to be used as part of the IPS, they are "capable of producing in paying quantities" and may have future utility for ExxonMobil and the other Working Interest Owners. Any determination regarding use (or P &A) of these wells likely would not be made until some time after startup of the Point Thomson Initial Production System (IPS), which is planned for the winter /spring of 2015 -16. There are additional considerations why we do not want to conduct any activities on these wells until after IPS startup. There will be a lot of construction, commissioning, and start-up activities on the Central Pad (PTU 3 pad) and C -1 Pad and avoiding any unnecessary simultaneous operations (SIMOPs) will help ensure a timely completion of construction and startup and reduced the potential for any incidents. Please advise if you have any further questions on these. Am I correct in interpreting your note below to say that a form 10 -403 approval will not be required but ExxonMobil should a form 10 -404 after the work is completed? The form 10 -404 would include pictures to clearly illustrate the condition of the wellhead, the wellhead and vaults during construction, and a final picture showing the pad after installation of the vault and covers. Regards, Rob Dragnich R.G. Dragnich, LLC rob @rgdragnichllc.com 907 - 830 -4796 From: Guy Schwartz <guy.schwartz @alaska.gov> Date: Thu, 20 Dec 2012 20:25:37 +0000 To: Rob Dragnich <rob @rgdragnichlIc.com> Cc: "Fowler, Bill Permits /C" <bill.permits.fowler @exxonmobil.com >, Gilbert Wong <gilbert.wong @exxonmobil.com> Subject: RE: PTU 3 (PTD 178 -005) and Alaska State C -1 (PTD 180 -046) Wellhead "Vaults" 1/4/2013 • • Page 2 of 3 Rob, Thank you for the engineering drawings for the planned work. Some wellhead pictures will be required before and after the vault is installed. A 404 report of work can have some of the construction pictures included. Also, will there be any surface marker at all to identify the well? I assume there will be some weight limitations on what can be driven or these covers. Can you elaborate... . Can you restate your intended plans for the wells ( Alaska State C1 and PTU #3 ) in regards to future utility or a planned date for final P & A ? Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From:Rob Dragnich [mailto :rob @rgdragnichllccom] Sent: Thursday, December 20, 2012 10:24 AM To: Schwartz, Guy L (DOA) Cc: Fowler, Bill Permits /C; Gilbert Wong Subject: FIN: PTU 3 (PTD 178 -005) and Alaska State C -1 (PTD 180 -046) Wellhead "Vaults" Guy, Thanks again for your time to meet with our remediation well work supervisors last week. As discussed and as a follow -up to the attached note about the installation of wellhead "vaults" around the PTU #3 and Alaska State C -1 wells, attached are engineering drawings showing side and end sectional views of the vaults. My apologies for the detailed nature of the drawings. You can think of the vaults as large reinforced concrete boxes supported by piling. The boxes will have steel covers and a nominal 12 inches of gravel will be placed over the covers to allow for traffic. The covers can be removed when necessary to conduct the well inspections (every 5 years as required by AOGCC regulations for suspended wells). There is no physical work being done to the wells themselves. Rather the vaults are being installed to protect the wellheads from potential damage during construction and operations thereby maintaining the integrity and safety of the well and surrounding area. Also please note current timing for installation is now 2014 (vs. 2013 as shown below). Please advise if either a form 10 -403 (Application for Sundry Approval) or a form 10 -404 (Report of Sundry Well Operations) need to be submitted for these vaults. Regards, Rob Dragnich R.G. Dragnich, LLC rob @rgdragnichllc.com 907 - 830 -4796 From: Rob Dragnich <rob @rgdragnichlIc.com> Date: Wed, 14 Nov 2012 16:56:15 -0900 1/4/2013 Page 3 of 3 • • To: Guy Schwartz <goy.schvwartz @alaska.gov> Cc: Gilbert Wong <giibert.wong @exxonmobil.com>, Bill Fowler <fowler.bil @exxonmobii.com> Subject: PTU 3 (PTD 178 -005) and Alaska State C -1 (PTD 180 -046) Wellhead "Vaults" Guy, you ou for your time to discuss ExxonMobil's plans for protecting the PTU 3 (PTD 178 -005) and Alaska State C -1 (PTD 180 -046) wells. The Point Thomson Project will use the gravel pads from which these wells were drilled for Initial Production System (IPS) facility purposes. As discussed, this note describes our plans for your consideration on whether an Application for Sundry Approval (Form 10- 403) or a Report of Sundry Operations (Form 10 -404) should be filed for the wellhead vaults we plan to install around these wells. The wellheads are lower than the planned finish grade of the pads and no work to them will be required. To ensure the wells will not be damaged during construction or operations, it is planned to install steel "vaults" that cover and protect the wellheads. These vaults will allow traffic over the wellheads while also allowing access to conduct future inspections pursuant to AOGCC regulations. The wellbore marker has been removed from the PTU 3 well and the C -1 wellbore marker will be removed before installing the vault. The locations of the wells will be carefully identified to ensure no construction work interferes with access and to aid in future inspections. Current plans call for installation of the vaults in March 2013. If you advise an application for a Sundry Approval should be filed, we will submit it at least 30 days prior to the time when installation of the vaults is scheduled to occur. Please feel free to contact me at 907 - 830 -4796 or email "rob @rgdragnichllc.com "if you would like further information or details on this. Thanks again for your time and help. Regards, Rob Dragnich R.G. Dragnich, LLC rob @rgdragnichlIc.com 907 - 830 -4796 1/4/2013 I WELLHEAD 1 I EXISTING GRAVEL LID TOP PLATE EXISTING INSULATION :f' r • . ri•a Iut ti•t1 :. i�� •.� . 4111 ;.. PILE SCHEDULE - ! NI ♦ 1 11 y,111 �� 1 �� ! ��ui1 y i • 1 ��i.�1 r jj •1 �� . �1. ��1 SUPPLYLE E TH ••• 4 1 ; ; ; , - III � � : t r I ms's - 1 •. •• • A • • PILE LOCATpN PILE 512E GUAN71fY t PPLY LE GT /\ /\ / \/ -4.4•404:‘,4 ... ILL I I I ♦II ALASKA STATE 24'0x0 75 "t 4 45 - / \ / \\ \ .-- I I+rI • T l g.f. • j \ � C -i VAULT NATIVE SOIL \ � \ \ //\ / •• ital. (; � 0 1 I ! =� // // // // � / EITHER VAULT. PROVIDE (1) 40' CONTINGENCY PIPE PER USE IN EXCAVATION SLOPE, TYP II I Ici INSULATION, TYP • NOT I NO GROUND THAWING SHALL BE PERFORMED DURING CONSTRUCTION 2. ALL FlLL SHALL BE UNFROZEN DURING PLACEMENT AND L OC L 3 INSTALLATION SHALL DURING SUMMER FIELD 4 DIE VERIFY NLL L LL EXISTING ISTING EXISTING WEE LLHEHE AD DIMENSIONS VERI NSITNS AND ELEVATION PRIOR TO FABRICATION. ALASKA STATE Cl VAULT END SECTION NOTE: VAULT HEIGHT MAYBE STS ADJUSTED BY ENGINEER BASED UPON FIELD DATA. WELLHEAD & VAULT 9'-Cr VERIFY WITH FINAL F L - VAULT DIMENSION SEE ALASKA STATE C1 WELLHEAD. VERIFY USPT -WP- CDFND- 095003 -001 EXTENTS PRIOR TO FABRICATION 8" CLR, HIGHEST POINT OF TOP OF NEW PAD, REFER TO ALASKA AND NOTE 4 (SEE NOTE 4) WELLHEAD TO BOTTOM OF _ EXISTING GRAVEL I UD TOP PLATE USPT- WP- 173043 - FOR 12" FILL COVER LID TOP PLATE EXISTING INSULATION ELEVATION, PLACEMENT & COMPACTION il 11r i; 1 Big 1k� , ISi �_r1'TS 1 VA0.••�. Ngirga .Tr rger is ri •11 • x:1 • X 11 �.� V}p �, X0411 ��011104,111:;•41.1 — 1 [1 11 frgi iVnit 'iJ1 �e . rtr • �� .r�4 ri �a 'ii�: 1 :1141:1,- 4IIi.�•.. � \ % /\ \ \/ H H 11 MOUNT TYP F e II � \ BOTTOM OF a ., —.15.r1 O GO • SLOPE. EXCAVATION „ ^•I' "" __' ` EXCAVATION I 1 INSULATION 4 "t. TYP NATIVE SOIL NP 4' -0" MIN I i THOKDNSULATIONSBOARD `` �ww ` _ SEE DRAWING SHALL BE GRADED FLAT FOR INSULATION : ! ! ! iiiii Iii1 ii Ii_______ DRILL &SLURRY PILE. p3 \p ALASKA STATE Cl VAULT SIDE SECTION NIL _ REFERENCE REEWMGS DFSCRIVPGN w.y� �' ERIE ORSCRm.VR RI CNN "°°^ "" CML DRAWINGS FOUNDATION I%N uSPT- wP- C- 095000 -ar WANG INDEX P•T°F.A 10 11.1/12 MUNI FoR CONS FB NB xwB sP E*pnMobil WELLHEAD VAULTS - P1U #3 & ALASKA STATE Cl usPF- wP- msYw- OF50os -001 GENERAL NOTES '-4 t ^ Development ALASKA STATE Cl 7 49 tN ' .1 - -- VAULT ELEVATIONS "✓,, ^ - POINT THOMSON ALASKA p:•. tea u MUwx [ JGN£ 'l ®WM!YPrnanr FLUOR. ®I ®I m r SM 1E48 -12� NTS an 'w D t•p,Tis..P u EU � m I � mN USPT -WP- CDFND - 095002 -001 I. 2 C WELLHEAD LID TOP PLATE PILE SCHEDULE P EXISTING INSULATION I..1 j • • / i 1 •' • • ' � ' •'• ' • •!`• 1 j tt ♦ � [,10 ♦ •:: � - -' ...: t � a I PILE LOCATION ' Pp.E TS OVANTIfY SUPPLYLENOTN - Wita �. •i'1•.:11 ♦�1 . t:I i �� " t S1 VOW *x • .... GRAVEL _11• . . ° I WSVAI .II11k I I II. 1 I PTU N3 24 "0x0 .75 ° t 4 45' 44 \ \ — i�N ♦ STRUT TYP e I t \ \ \ \ \ NATIVE SOIL l / �� \ / /\ / / \� / •.• .�. � 1.''' • / / \ /\ EXCAVATION SLOPE. NP I I \ \/ \ / \ \ / \ \ / \\ / \\ / ' • INSULATION. TYP ,._j I±OTES I. NO GROUND THAWING SHALL BE PERFORMED DURING CONSTRUCTION FILL SHALL BE PTU #3 VAULT END SECTION 2 P AND COMPAC ONN DURING NTS 3. INSTALLATION SHALL OCCUR DURING SUMMER. 4 FIELD VERIFY ALL EXISTING WELLHEAD DIMENSIONS AND ELEVATION PRIOR TO FABRICATION. NOTE: VAULT HEIGHT MAY BE ADJUSTED BY ENGINEER BASED UPON FIELD DATA. WELLHEAD PTUN3 WELLHEAD, VERIFY & VAULT EXTENTS PRIOR TO FABRICATION 2 -8 CUR, HIGHEST POINT 11' -0" VERIFY WITH FINAL TOP OF NEW PAD, REFER TO CENTRAL VAULT DIMENSION SEE (SEE NOTE 4) OF WELLHEAD TO BOTTOM PAD PLAN DRAWINGS OF LID TOP PLATE USPT -WP -CORAL - 173039 -001 FOR USPT -WP- CDFND- 095003 -001 AND NOTE 4 72 FILL COVER LID TOP PLATE ELEVATION, PLACEMENT & COMPACTION i�� i � i� iii ��iii iii ��i �♦. -.� r � • .W1'WA!i i orto, • iii ►. EXISTING INSULATION t/ 1 ♦ -' t1 .iI It: u i • �1 1 ♦% II [I ..I ,II �I e.1k • I • 4 I • • ..1 ♦ �I 1 • • 111 ♦ I • EXISTING GRAVEL 1 1 ♦i \ MILL .I �.�1 X1 1 i 11 ♦I•.1I .♦ •11 ��uI P �11 ♦ �� - \/ / \ \ / / •••••'•.. LI H ' MOUNT TYP �• = / NATIVE SOIL / \ // \/ ••'•..•• [I _ - -: ..._.. _ _ [ I__ - /T- / \ / / \ / \ / \ / \ / \ /\ `C �O \_�` • BOTTOM Of .......� .� — - '::�/ \ \ \ \ \ \ O ♦ I � // PILE CONNECTION DETAIL, TYP SHALL BE GRADED FLAT FOR INSULATION DRILL & SLURRY PILE. TYP O 0 PTU #3 VAULT SIDE SECTION CO NTS REFERENCE DRAWINGS DESCMPNON OA�, REV DATE DESCRPTUN 9. 0. APP D PROJ J CML DRAWINGS — FOUNDATION OFA:4' E7�onMobil WELLHEAD VAULTS — PTU /3 & ALASKA STATE Cl USPT - WP - CHIN - 095000 - 001 OWING IM U SE ..'.N 1 10 03/12 ISSUED FOR CONSTRUCTION FB SB We SP � 'f P PTU #3 VAULT ELEVATIONS USPT- WP- CDSYN- 095005 -001 GENERAL N016 f49 TX �'�. Development 9'��''✓ ` POINT THOMSON ALASKA / O11 ..9 W AIOB :"°> ® ® 1 .W WLE DA I X.NF ^W n ;:. w a � worEnPF.r FLUOR CAE ...w m ® ® OPAVn xo sM 03 -06 -12 I Nis " ET ��'� USPT—WP— CDFND - 095002 -002 2a 2I 10" CENTRAL PAD 3 ` \\ i / ' 0 3 `` / / / ..... - © 8ttP• 4. WELLHEAD VAULT (PERIMETER`\ / 8 -0 WELLHEAD VAULT (P O RIMETER`\ / / FOR \ / TYp /SHOWN FOR \ k* PILE. TYP - L REFERENCE) `� ._ PILE TYP R EFERENCE) `\ • l v, `` 1 1 �. `P"-,- _ \ `I –"(i 1 WEST PAD 4�� I I ,'' Y'-6 N EXISTING 1 w I In 3' o w EXISTING I I -i > w WELLHEAD 1 1 1 v' 3 /EXISTING 1 BASIS OF BEARING EXISTING _ _ _ 1 a� > BASIS OF BEARING EXISTING _ _ 1 i 1 TWELLHEAD ALIGNMENT I No' 1 1 WELLHEAD ALIGNMENT L. i 1 1 (FIELD VERIFY) I 1 (FIELD VERIFY) I j GRAVEL MINE ■ - 1 ` O _- __9 / / I 1 ` ` O _ -- __p___ _ _ __ _, '= I / ` / / 1 \ J /I - ALASKA STATE \ \` VAULT LAYOUT PLAN i ` ` - VAULT LAYOUT PLAN i - CT PAD NTS / NTS / / AIRSTRIP .= L ` ` ` I i 'a lb 1 KEY PLAN - I NTS 1 '' 1 O �O O� 1 E EXISTING PTU N3 \ \ \\ —�— \ \ \ \\ j \�.�. WELLHEAD \\ \\ I enS ` 601\ - \ 1 N. 5912413.63 r v ` \ \ ; E 1608646 29 \, I ‘ Sl ,,�2 ` ✓ _J NOTE: - 1 I REFER TO \ I \ \ II VAULT - I G 0 031 ` CON ��, / i CENTRAL PAD I VAULT I EXISTING ALASKA STATE J C 1 WELLHEAD N. 5900530 63 %Rams L i L _. 1609987.83 1 1 - I ....,,,. I ALASKA STATE CI PAD - Na..----. c, I I III 1 11 oo– PTU #3 WELLHEAD VAULT SITE PLAN ALASKA STATE Cl WELLHEAD VAULT SITE PLAN NTS NTS REFERENCE DRAWN. S oescx�PNDx - ��"\S uv Dare DEORATORS SO 00 5500 P. CML DRAWINGS FOUNDATION US Pf MP CDIIN 095000 - 001 DRANNO NW 3.AP " ">'a. D VAULTS - PTU #3 & ALASKA STATE Cl p � 10 03/12 ISSUED FOR CONSTRUCTION FS SB MB SP E*.onMobil WELLHEAD USPT- NP- CDSYN- 095005 -001 GENERAL NOTES •~ TM SITE PLANS 9 � "-/--••••›— �'.. �i Development P OINT THOMSOO ALASKA V;.. F MPD - -. o oe°B� ®W FLUOR. ® ® ® owxixc xo S M 0 -OB -12 Nf5 a xc `6 :- " USPT- WP- CDFND- 095001 -001 t 1 --------- - - - - -- ------ - - - - -- ------------------------- - - - - -- -� CENTRAL PAD - iii j / ' 0 6 ' _0 ' ELLHEAD s VAUL ( PERIMET ER`\ / ' I © 8' -0" C WE Q VAULT (PERIMETEFA\ / FOR \ \ / / FOR \ /. / / PILE TFP L REF \ / //' r PILE, TYP L REFERENCE) \ \\ I - __ - __ __ \ \ \ \ / % / � / - - - = \ \ WE PAD 74.71..* / 1 T 1 i Q 4 -' EXISTING I I I in a E I - i > 0 3 WELLHEAD I 1 I VOW WELLH 1 1 I BA OF BEARING E %ISTING ' I 1 - _ BASIS OF BEARING E %I$TING _ - 1 � >'^ "� (WELLHEAD ALIGNMENT -\ V (WELLHEAD ALIGNMENT — � 1 1 (FIELD VERIFY) ; a i (FIELD VERIFY) GRAVEL MINE / \ O \ \ 1 \\ j / i- ALASKA STATE \\ VAULT LAYOUT PLAN / I VAU LAYOUT PLAN / I r Cl PAD NTS ■ \ `` - -T- - '' i - -- AIRSTRIP j I 1 1 I KEY PLAN ` 1 • ', I NTS \ I • '�, \\ 1 /� 1 O `O_` •,, I E EXISTING PTU #3 ♦ r....--.7.-........-...1 ^ _ I ♦�� ♦ I ``] - ( . _ ♦ ♦\ I 4 g WELLHEAD N. 5912413.63 ♦\ Il /►��/ ��V \ \ \\ ; ; E 1608646 29 \\ I ` \'//� ` K_ 1 • / -� I NOTE, \ 1 . 1 USPTRWP- WP - 000001 -001 • \ \ - ' `- rVAULT CONTROOJECT SURVEY i ,_- i GO 031� CENTRAL PAD I VAULT EXISTING ALASKA STATE 1 I J I Cl WELLHEAD ` __. ,` E. 5900530.63 E. 1609987.83 I L ' , I 1 ...rr/► ._ I I ALASKA STATE Cl PAD I l \; L- I PTU #3 WELLHEAD VAULT SITE PLAN ALASKA STATE Cl WELLHEAD VAULT SITE PLAN NTS NTS RE!EREICN DRAWINGS WESCNIPTON my \�� REY DATE ANSCRlvnar SY CRK NON 001 CIVIL DRAWINGS FOUNDATION OSPT- WP -COINF 095000 -001 DR411NG INDEX 3fUF. T 43 1 10 03/13 ISSUED FOR CONSTRUCTION CO SN KM SP E *onMobil WELLHEAD VAULTS - PTU #3 & ALASKA STATE Cl J USPf- xP- CDSYN- 095005 -001 GENERAL NOTE f •~ 49 TM , Development SITE PLANS f ,r-v^' -- POINT THOMSON ALASKA : I®�® 11 1 ; .>, ° 0ee '�• :Ti � " C I ®NbrMyPonono FLUOR. TM 0 -OB -12 N TS nrro �F 1 DRAWING ND. w EI USPT- WP- CDFND- 095001 -001 1. 1 0 a> ou9G�mQs;6. Ger wr��ttfie� C4c�rsn ar ,^ [ria56 P K'n—,an V I P. O. Box 196601 Alaska Production f\Aanager I Anchorage, Alaska 99519-6601 Joint Interest U.S. / J %��//� 907561 5331 Telephone /! /I VAC 907 564 3677 Facsimile r r Productil"Or, September 23, 2009 CC,E- � �J Commissioner Cathy P. Foerster SEP 4 2009 Alaska Oil and Gas Conservation Commission f�13� �� v�; "i@G€' hF��pn 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501-3539�a�� RE: Request for Verification of Suspended and Shut-in Well Information Dear Commissioner Foerster: 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, eL--- 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 Comment Location and Well inspected 3/2009. 17C� '�Y�5 Location and Well inspected 4/2009. /77. a b V Location and Well inspected 4/2009. 1 I — 00 Location and Well inspected 4/2009. -79• Further remediation work planned for the 2009-10 winter season Location and Well inspected 4/2009. ,I'd Well inspected and remediated and site cleared in 4/2009. 1,P"3 • OV5 Location and Well inspected 4/2009. �• Q�� Location and Well inspected 4/2009. 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 ~a~a:a~n~mt~s! ~~~~a~~taoe~ ~orn~ae~~r Joint Interest U.S. - Alaska P.O. Box 195601 Anchorage,Alaska 99519-6601 907 561 5331 Telephone 907 564 3789 Facsimile June 17, 2009 i~ ~~' ' ~ ~ ~.~,~~~~~~ ~ -'',lfV ~ ~ ii1C1.~ :"~',~5~~ ~OK U~ r~ '`~'' ~1~1t:`s, '~,'g~y,i7l17tSSlQ~~ E o n!Uf o b i~~~r~~~° ~ ~~~c~~c~~~o~ ~ ~C-~ r°~s'c e~.~- ~ v~ Mr. Johnny ~. Aiken, Director ~~ ~, f~~`( North Slope Borough Planning and Community Services Department ~~-` ~~ P. O. Box 6 9 G~~ I"! Barrow, Alaska 99723 Re: Tundra Travel Completion Repo +~$' O~~ n t~~1~ ~~ ~~ . ~,~~o~,s° Dear Mr. Aiken: .~ ~011n Please find attached our 2009 Winter Tundra Travel Completion Report as required by North Slope Borough Conditional Use Permits. This Tundra Travel Completion Report pertains to the following activities authorized by the above permits: - Ice Road Construction from the Endicott causeway fo tF~e Point Thomson Unit Central Pad - Ice Road Construction to the Alaska State C-1 water source and other lakes from which water was withdrawn. - Tundra Travel /Ice Road Access - Point Thomson Unit Central Pad Mobilization & Construction - Well Inspections and Remediation The attached report reflects Tundra Trave( activities through closure of the Alaska State C-1 ice road on May 19th, 2009, and includes the following elements: 1. Actual routes of travel and the location of all camps depicted on USGS topo maps 2. List of vehicles for off-road travel that has taken place 3. Statement of cleanup activities 4. Method of disposal of garbage and other camp debris 5. Report of known incidents of tundra damage and follow-up corrective actions A Division of ~xx~r~ ~~isb! ~app~~^at's~r~ Mr. Johnny L. Aiken -2- June 17, 2009 If you have any questions, please contact me at 907-564-3617 or by email at mike.barker@exxonmobil.com. Thank you Sincerely, t,, ~~ ~ ~ ._ ~~~~, ~ ~ Mike Barker Environmental & Regulatory Manager KDC:eaa Attachments cc: Lori Aldrich, ADEC Gordon Brower, NSB Nina Brudie, DNR Larry Byrne, DNR DMLW Steve Davies, AOGCC Josephina Delgado-Plikat, DNR John Easton, DNR DOG Gary Evans, ADEC Susan Harvey, Harvey Consulting Lee Kayotuk, Kaktovik Tom Maunder, AOGCC William Morris, ADFG Craig Perham, USFWS Matt Rader, DNR DOG Barrett Ristroph, NSB Gary Schultz, DNR DMLW Roy Varner, NSB Waska Williams, NSB Ryan H. Winn, USACE Jack Winters, ADFG ExxonMobil Production Company Alaska Interest - Joint Interest U.S. P.O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone June 1, 2009 Mr. Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Report of Sundry Well Operations Exxon Mobil Corporation Point Thomson Unit #3 PTD No. 178-005 Sundry No. 309-085 Dear Commissioner Seamount: ~ :;~ ~~ ~~ ~. r,~~ ~ ~~~~ E ,"l,ri~ F~ ~ ~~~~ +F .~~~~~ ~~" ~: ~h~~ ~ ~4"~fi ~~S?~f[t~S~'~ < E~onMobil ~~~~~~~~ Production Exxon Mobil Corporation hereby submits its Report of Sundry Well Operations for the wellhead inspection of the Point Thomson Unit #3 well on the North Slope. The well is currently suspended, and the inspection was performed at the request of the AOGCC in accordance with AOGCC~ requirements for suspended wells. ~~3'~~,~~` ~~~ ~c. ~ 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 pressure in the 9-5/8" casing and the 9-5/8" x 13-3/8" annulus; zero pressure was . recorded in the casing and the annulus. One new gate valve and one new needle valve were installed on the wellhead. At the end of the well inspection, the top wellhead section was covered with gravel, insulation mating, and rig mating to protect the wellhead from current drilling operations. • Attached please find: Form 10-404: Report of Sundry Well Operations Daily Report of Well Operations Wellhead drawing Wellbore diagram Well plat Photographic documentation of the well If you have any questions or require additional information, please contact me at 907-564-3617. Sincerely, ~ ... D. Michael Barker Environmental and Regulatory Manager JAR:eaa Attachments A Division of Exxon Mobil Corporation ~~ ~h~~ 1 ~ ~`~ ~ ~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~' ,'' ~~l ~ ~ ~0~~ REPORT OF SUNDRY WELL OPERATIONS y, i ~.~~~ ~~~~~ ~~~mi~si~~~ :r~~ 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ pection 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: Euuon Mobil Corporation Development ^ Exploratory^~ 178-005 • 3. Address: PO Box 196601 Stratigraphic^ Service^ 6. API Number: Anchorage, AK 99519-6601 50-089-20007 s 7. KB Elevation (ft): 9. Well Name and Number: 36 ~ Point Thomson Unit No 3' 8. Property Designation: , P 10. Field/Pool(s): ADL 47559 surface / ADL 47558 BHL Point Thomson 11. Present Well Condition Summary: Total Depth measured 14,125 ' feet Plugs (measured) Plugged to surface ^ true vertical 13,151 ° feet Junk (measured) None Effective Depth measured Surface feet true vertical Surface feet Casing Length Size MD ND Burst Collapse Structural Conductor 784' 18 5/8" 811' 811' 2420 1700 Surface 3311' 13 3/8" 3338' 3298' 5380 2670 Intermediate 10320' 9 5/8" 10347' 9681' 7290 7100 Production 4612' 7" 14114' 13140' 13700 13010 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: `~ , ~~A., ~~J~ ~~~Q09 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 Photographs Exploratory^~ Development ^ Service ^ Daily Report of Well Operations See attachements 16. Well S tus fter work: end ~ ri~-pS ~ ~ Oil [~,,~'~~as WAG ^ GINJ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ .t Sundry Number or N/A if C.O. Exempt: ~ ~ 309-085 Contact Mike Barker Printed Name Mike Barker Title Environmental and Regulatory Manager Signature~ , l~ Phone (907)564-3617 Date '~f ~~ ~-e~ 1 Form 10-404 Revised 04/2006 ~~ y;- a r r~~ ~~ ~~~ ~ ~~~ Submit Original ~Only ~., 0='" ~ «~~ ~6~~~1 ~ Daily Operations Log Point Thomson Unit #3 Weil Inspection Tuesday, March 31, 2009 ~ Transported and staged out equipment at PTU#3. • Removed well guard box and began excavating around well. Wednesday, April 1, 2009 • Continued excavating around well. Soil is very hard. • Cleaned out soil immediately around wellhead, exposed gate valve. • Attempted to cycle valve. Valve would not cycle, applied heat and left overnight. Thursday, April 2, 2009 • Tested and functioned existing valve. 250/5000 psi test on valve. Obtained good test. • Installed new 5K valve and pressure tested same to 250/5000 psi. Obtained a good test. • Opened valves and verified there is no VR plug. Zero pressure. • Rigged up and installed mechanical. hot-tap tee. Install hot-tap machine and attempted to pressure test, test failed. ~ Called and ordered a certified pipe welder to weld a collar on top flange. • Rigged down mechanical tee and hot-tap machine. Friday, April 3, 2009 • Obtained hot work permit and welded 2" Sch. 160 nipple on 7" marker post. • Rigged up hot-tap unit and tested to 250/5000 psi for 5 min. Good test. • Held 400 psi. back-pressure while drilling 1/2" hole. Observed zero pressure on the 7" pipe on top of the blind flange. Filled 7" pipe with water to check for communication. • Cut 7" off of 13-5/8" flange. Discovered tapped 2" bull plug welded on top of flange with 1/2" needle valve in it. • Installed new needle valve w/gauge and checked for pressure. Zero pressure on casing. • Surveyor's shot grade and determined the height we needed to stay below Cut off rathole pipe. ~ Replaced 1/2" needle valve and installed plug. Surveyor's shot new valve assembly. • Welded cover over valve and shot it to verify it was below grade. • Painted cover orange and marked with tape. • Backfilled excavation and loaded out equipment to sleighs. • Cover excavation site with large tarp and applied heat to aid in subsidence. PT U #3 McEvoy Split Speedhead System 7" LP Csg head Approx 24" I~bi ng he ad Anarox. 24" 13 518"5k. 135~"5k.-~• IA & OA v aives are 3-1~8 needle valve ~~~~~ Exxon Mobil Corparation Pt. Thomso n Unit #3 Well Schematic API #: 50089200070000 APTD #: 178-005 VUellhead A section is13-~1'8", ~a kpsi with a blind flange and marker post on top Cut off 36" x 32" csg at 9.45' below mat level Diesel to surface from 40' (1~' BGL) in 9-~18" casing Cement plug from 40' -100' (1~5'-75' BGL) in 9-~JS" casing 18-51'8", 96.4 ppf, K55, BTC Conductor casing at 811' MD (811' ND), ~ cemented with d,300 Sx permafrast 19~ bbls of Arctic pack in 9-5I8" x 13-3I8" annulus fram surface to 3,356', 50 bbls water & waste fluids below Baker cast iran bridge plug at 2,000' MD 13-38"72 ppf, L80, BTC surface casing at 3,338' fviD (3,298' T~D), cemented to surface with 3,7~0 Sx permafrost TOC behind 9-~1'8" casing estimated at ~,000' MD ~4,828' TVD) Top af cement in 9-5J'8" casing at 8,869' MD Baker cement retainer at 9,019' MD , 35 ppf, P110, BTC Production casing stub at 9,502' MD 9-~f8"40#500-95 at 10,347' MD (9681' TVD), cemented with 2,450 Sx class G Top of cement inside 7" casing at 13,612' MD Top of cement outside 7" casing at 13,664' MD per cement bond log Halliburtan cement retainer at 13,847' MD, unable to pump thraugh with 8,000 psi Baker model F-1 productian packer at 13,852' MD Perfarations 13,872' -13,88~' MD, 2 spf, 1$0° Cast iron bridge plug at 13,$90' MD Baker model F-1 production packer at 13,895' Perforations 13,908' -13,925' MD, 2 spf, 180° Top of cement inside 7" casing at 14,024' MD (float collar} 7", 3~ ppf, P110, BTC, Production casing at 14,114' MD (13,14Q' Nd), cemented with 1,035 Sx class G 8-1t1" open hale TD at 14,12~' MD (13,151' TVD} Well sketch prepared l7y Fairw~eather E 8 P Services, Inc. Last revision deted March 19, 2009 ;~ - w~ m ~ r,~l 11 ~ ~ ~- - - -- -- -~- --~ ~ .__ ---- -- . f_ ___ -- --- --- ~- ___ __ __ __ , _ _ _._ ^ _ - ._ ~ _..-~ ~ + ' BEAUFJRT ~ SE-A ~ ~ i ; I I 20 ~ 2 I I 22 ~ 2 3 I 24 i H I ~ ~ ~ { ~.~ . " ' ~ '''`''~~--~~.-- ~ I ~ ~ Fioxman ' islond v -` ~._ .._ __ - --~. --- --- ----- - __ ~__ __. __ _.-- .-- - .__.. ._. . .__ .._.. __.. .__ ._ .._ ___ .__ _~ ~ ' I ~ --_.__. fi_ ! ~ I ~ i ~ 29 ~ 28 , 27 I 26 25 30 ~ I 1 , I ~ I { ~Pi Thomson + ~ ~ I _ -- _._ _~ -- -_ ....,,.. . _ _.. ._ -- - - ~ -~- `-3'',:,~ __ - ~ ~- ' --- _.. -- ----- _ _ ___ .. ---- -.. - i -_ ___ _._., .._~ . ~ .L,Y. ~ PFOPOSeo ~ ~~,/""~ p! _ ~ M ~ EXXON No. 3 POINT TNOMSON UN{T j i 32 ~1~_ = 34 ~` LAT. = 70° 10 ZQ_4$~~ 3~ I j I 33 I ~ LONG.=i46°~5~OH.66~~ f ~ 6g2~ M X= 468, 64 I ( i j ~ I ~'~` Y=5,912,h34 T i0 N. ; O,, ~~T9N. i i ~ ~ ~ ':. i ~^~ i , ~ ~ i ~--f~ .. j 5 ~ 4 3 2 C ~ i~~ 6 ~ ~ ~ t ' `~~''` ..~ , , ~ i --= , ' f ; i i f_~ _.._ _~ ---- - -_.. .._ .~._. _, _.__. -- --- __~ .__ __. ____.. -- -± -- _ _- _ - --_._ . --- __. .. .. . `.-~ I ~ ~. . _ ' ' / ~ i I ~ ~ 8 ~ 9 1 t0 ~ : 1 ~i2 7 ~ ~ ~ i ~ 1 l I ~ i - -_.._ --- - --- ~ - __ _ _. . __ . ' _. _ _ -- r . - - _ 1. ! _ _. .__... _ _ -- ---~ ---- -- -- . __ ~ ~ ~ SCA~E I"= i MiL,E CERTIFlCATE OF St~RVEYOR `s hereby cert~fy fhat I am prnp~rly registered anc~ licenseci iu prc~ctice land surveying in the Stote of Aiaskc~ ~ and shot this p1Q# represents a Ivcatir~n survey tnade by me ~. ~~,"''~"~~~Q.-~ or under my supervision, and that all dimensions and other detoils are cnrrect ~1 , /,~ yf~ i % ---1 z. ^~...a_~.. ~ ~. --- _..- - --~,~?~G~1aw" ~ - .L er~4 Cate Surveyor ~~___.....__ ~Xlft(~j/T C NOTE~ I.OG iS 8.6' ABOVE LAGUON H OrEqti ICF v+~ a ~ ~: ti ~ . . . .. . ~ . . _ , ~~A; , y "^. ?~ `' ; . .._. _ , _ ~ i"e ~,'~~ a:.n ~ ~.. ~,,~~,~r.~,~ ~~ , ,, ~ A q~~' y f ~y, ~' ~ + , . y j ~ '~' 1 l',~ I l+~* ~' S.~ S ~ ¢ ~~ ' ~ ~ f M ~ by ~ ~'~ ~7~ ' ^~ ~d ~ ~r ~~ ~ ' ~ ~ ~` ~7 S ~ J I . 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" ~ ,.'a 4r J#3 wellhead new gate valve -40* 41 NO 1A ~ '~ _ q ti '}~ , ~ + ~- ~ ,~. ~ ~c . ~,~ -. . ~ ~ ~ ~...~ ~ ~ ;'' , f z ,, ~ , ,~ .,.~~ ~ ~.~~ ~°~- ~r ~ ~ -_~. ~~``: `~` ~.~ ~ ~~~'~- . ~ ` .w ~ ~ ~,~ ~ K <~ w,' ~,, t~ t . ~tS' ~ . ~ ~ _ -•~ ~ . , ,~ ~,~ f .w . '' A +~` -~ a' M` 1 , . ~:~'~'.,~ ~ ~` y ~• ~, ~ ~ . ~~~ " ~ _ ~ `" ~ ~. ~W ~ +~ , . .~ "~'~ ~ , jl ~ ~~ ~' ~ ^ . r ~ X ~ ~''• PTU#3 wellhead top flange as left . ~. F ~ ~''r~'0~. ` _~ _ a - .~+r. -4 ~.a~i~'~I~~~~~ .:~~~ _ ^~ ~ . ' : ~; ~"~';~ ~.~ ~. ,~'~'~ ~ . .~ ,. d _ N~c„~ .~~~ , . 'u'-~.. _ .. ~ ~. .. . . < ~~ ~ -' ~ ~ ~. <~_~? ,`_ ~r ~ ..: :, r ~ ~~ ,. ~ 5~,:~`^.: - ~ ~ ~_~' ~~ _ ~ . ~ ~ A-..~~~ " ~ ~zz ~ ~~ ~~YE ~t -.. ~ ~. ; ,~w ~~~ ` `~-" ~ ~ `-,;'" r ` ro ~ . -„ ~ y ~..M~ _ _~., *,'~ i~.. ~ . . ~ _ ~~'S~r . .'.' ~ ` . ~ r~ .-:S ~ r 5~ ~ -~c' ~ " ' ~, - - ~ `-, ':°' ~~~"' s,~ . - - , ~. y ~l ,,~ ir`":~j~~~`~~'ti..~ *'-: ~ 4, ' ~ ~ ~' ',: Y ' . r/'F.~,. Y 9 J ~ - ~ 5 :' ~ ~ ~ ~ . - 8 a~ ~~r - ...J .. ' wd ~o- '~`' : ' ~~ ~ ! ~~` t ~ l . Y ' . i °'~Y.~ i ' . #i; ~ .- : 'A- ' . . . ~ . j.- ~t'{ ~' l~ ""~ ~ ^t ~ ~d - 'P~~ ~P:. ~ .. - . .. i-. . . ~ t~iti27E./ e , ~• • "~° ~e ::a I • . { '' f^- + '. / . ' -~ k ' ' r~ I ....' . ~ ~ ti Y ~g~ ~, ~. ' ~ . ~ ~ .. .:. ' ~' p,~ . .r~ ~ ~~k . {+~ ~ . ' i^ ~' , s .:» ~ ~ 3 ' .~" S ~ ~ . ~` ~ ~ ~ ~ ~ F ~ ~ D '~^~: "t''~. ~ ~t .,w ~ ..,~ t~ R • ~ ~.,' ~~3.:..: -~e~"":~ ~. M.. . _.. d .W . . ~~~~4 ~~ ~ .~y _ . ~V~GISiI~~~l~~ J~JJ~~~Jlr'fi~ ~~ ~~l~~f ~J ~LYtlu i:~ j~~/?'l.va. riLS\~~'~rtl vOiiOA~lJ1 :i i[~AJ~3. J~1 ~~i ~~~~~~ 1i~or±~a~, :~~rv ~'?, ?~~9 9:'?? ?~~~ ~~a li~~!~¢~de~, ~%~o~~s ~ (~fl.~) ~~a9~J~c~e ~~: A~3GC~ ~€~r~d~,r ~9cs~ic~ ~~~r~r:s ~v~ ~~y~^t~6~~~~~ r~~~~ :~~:~s~Q~?~s Tom, the reports fo-r the 9 well inspection/remediation worli at Point T?zomson left my office this afternoon. Thanks for your patience, I'm now 1_oolcing ior contrac~ors to ~id the work to for the next winter°s work for the 3 well remediation efiort. Ii you have any questions regarding the recent work or next winter's anticipated taork, please call. Regards, Jack Maunder, Thomas E (DOA) Frorre: Aflaunder, Thomas E (DOA) Sent: Thursday, May 28, 2009 7:18 AM To: jack.a.rickner(a3e~oconmobii.com Subject: RE: AOGCC Sundry Notice 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:dll or messaqe with any aetails. Tom Maunder, PE AOGCC --Original Message----- From: jack.a.rickner@exxonmobil.com [mailto:jack.a.rickner@exxonmobil.com] Sent: Thursday, May 28, 2009 7:14 AM To: Maunder, Thomas E (DOA) Subject: AOGCC Sundry IVotice Reports for Completed Field Acitivities Tom, just a note to let you know I haven't been idle. Finally completed all the wellhead drawinqs, have all the attachments and photos together for all 9 wells. The package has been provided to our inhouse legal folks for there blessing. Hope to have their check off within a day or two. Wi11 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 & Remediation Project 907-564-3783 291-217-4350 _ ~I~(~ _ ~;i~~ ~ IVlaurocl~r, T'hornas E ~DOAD Frome Niaunder, Thomas E (DOA) Sent: Monday, May 11, 2009 8:18 AM To: Natasha Sachivichik Cc: jack.a.rickner@exxonmobil.com; Bill Penrose Subject: RE: PTU well inspection project AOGCC report status Thanks Natasha. That schedule should work. Tom Maunder, PE AOGCC From: Natasha Sachivichik [mailto:natasha.sachivichik@fairweather.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 well inspection project AOGCC report status To m, Sorry for delayed reply. We should have the reports ready by the end of this week or beginning of the next week the latest. Thanks and regards, Nataslna sacl~~v~ch~~2 Senior Drilling Engineer Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Afaska 99507 Direct:907-343-0405 Cell: 907-575-7156 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thur~day, May 07, 2009 12:29 PM To: Natasha Sachivichik Cc: jack.a.rickner@e~oconmobil.wm; Bill Penrose Subject: RE: PTU well inspection project AOGCC ~eport 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] ~r#: Th;::-sd3y, Mw~ ~7, 2^~9 ? ~:~4 P.M To: Maunder, Thomas E (DOA) Cc: jack.a.rickner@e~oconmobil.com; Bill Penrose Subject: PTU well inspection project_AOGCC report status 6/24/2Q09 _":~,~iv / a3:4 / ~~ 11'1' I am writing in regards to the yesterday's phone conversation between you and Bill Penrose about the status o~f the Sundry reports for 9 wells inspection and remediation project performed by ExxonMobil. The field operations completed on April-29-2009. I would like to confirm that we are aware of the 30 days requirement ~o 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, Natasha SacH~v~ch~~ Senior Drrlling 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 I!l~launcler, Tho~raas E (DOA) From: Maunder, Thomas E (DOA} Sent: Monday, March 23, 2009 10:14 AM To: jack.a.rickner@exxonmobil.com Cc: michael.d.murrey@exxonmobil.com; rob.g.dragnich@exxonmobil.com; mike.barker@exxonmobil.com Subject: RE: Wellhead Inspection Program Jack, et al, Following up on our conversation, it appears that options 1 and 2 should not present major issues. I concur that it is not desirable to have an open excavation. It is certainly possible that an excavation would collect melt water and what rain might fall. For this case, if you equip the well so that it can be monitored and then rebury some portion, this does not seem dissimilar to how the well structures have been for 20 - 30 years. I think that your finding the A section valve still functional after all these years should give some confidence that the damage risk from reburial is likely low. The final determination will be Exxon's based on the conditions determined for each well. Call or message with any questions. Tom Maunder, PE AOGCC -----Original Message----- From: jack.a.rickner@exxonmobil.com [mailto:jack.a.rickner~exxonmobil.com] Sent: Sunday, March 22, 2009 4:33 PM To: Maunder, Thomas E (DOA) Cc: michael.d.murreyCexxonmobil.com; rob.g.dragnichCexxonmobil.com; mike.barkerCexxonmobil.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. 1 We couid install ~he new gate valve (leic in closed posi~ion), ilange, wi~h 1/2" needle valve and a plug. Afcer obtaining pressure reading, bury the gate valve(s) until the next time pressure readings are required. Again, an excavator would be required to gain access to the valves. Could leave the wellhead exposed with the walls of the excavated cellar sloped back at a shallow angle that would form more of a ramped walk way down to the wellhead. The valves could then be exposed for easy access. Valve handles could be chained or removed for security. The hole might resemble a depression that could be walked into and out of rather than a hole. The excavated area could be left open and return to at a later date to install a more conventional cellar if necessary. Valves installed and chained as above. If we found a well that did happen to have significant pressure that did not bleed off quickly, we would shut in well and contact our engineering group to decide on appropriate action including how to leave the well and confer with AOGCC. But on wellhead with no pressure or pressure that is quickly bled off, there are some concerns with leaving an open excavation as there are to leaving exposed wellhead sections, needle valves (with possible pressure that may build back with time), and marker posts. would appreciate your views and input. Mike has discussed these options with our subject mater expert and with wellhead suppliers in Anchorage including Dave Craft with Cameron and Kevin Hite/Alan Mc Arthur with FMC. Mike, have I left out other options or would you like to add anything? Tom, as you know, we plan to remove the wellhead on the J-1 this winter and return to the area next winter to address the issues at PTU-4, West Staines #2, and the West Staines 18-9-23. The closure options for these three may not be as important as the others since we are scheduled to return and work on these. Would appreciate any insight you may wish to share. Regards, Jack Jack A. Rickner Pt. Thomson Well Inspection & Remediation Project 907-564-3783 281-217-4350 Thomas E jack.a.rickner@exxonmobil.com Subject RE: Wellhead Inspection Program Hi Jack, I am in for a bit today. My preference would not to have valves buried nowever l do realize tnere is also a risk about surface as well. What are your thoughts? Tom -----Original Message----- From: jack.a.rickner@exxonmobil.com [mailto:jack.a.rickner@exxonmobil.com] "Maunder, 2 Sent, Sacurday; March 21, 2009 3:41 Pv To: Maunder, Thomas E (DOA) Subjzct: wellhead Inspec~ion Program Tom, would you be available Monday morning to discuss a question regarding Ex~conMobil'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~ ~ ~-' ~ ~ ~~ ~ ~~ 7 ~ '~.~,a ~ L1 ~~~f ~ ._A c~ ~-- ~ AI.ASS~ ~u A1~D G~5 CO1~T5ERQATIOrT COMI~IIS5I01~ Craig Haymes Alaska Production Manager E~onMobil Production Company PO Box 196601 Anchorage AK 99519-6601 Re: Point Thomson Unit, Pt. Thomson Oil Pool, PTU #`3 Sundry Number: 309-085 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. The Inspection Procedure document submitted with the application refers to the wPll as "~urrent y~,~s~g~ded " Hawever the status cf this well accorclin~to the of~'icial AOGCC records is still P&A, although as the Cammission pointed out in previous correspondence this is one of several wells so classified that appear not to meet all of the applicable regulatory requirements for p~u~ed and abandoned wells. We appreciate your inspection efforts as described in tYie application. E~conMobil has submitted a request to change the classificatior_ of this well to su~ended status, but the Commission has not yet acted on that request. Approval of this inspection work proposal does not constitute or imply a decision on the request to change the well classification. When providing notice for a representative of the Comxriission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Corrunission grants for gaod 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 followLng the date of this letter, or the next working c]ay if the 23rd day falls on a holiday or weekend. A person may not appeal a Corrunission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount. Jr. `~ Chair DATED tYzis +? day of March, 2009 ~~ ~ ~~~ STATE OF ALASKA 4 ~~~~~~E~ ~-~G ~9 ~ ~' , ( "'~~~ ~ 3ALASKA OIL AND GAS CONSERVATION COMMISSIOIYI' ~~~ ~ S ZOO l~, 9 ~~ ~ ~b APPLICATION FOR SUNDRY APP 'S ~gFi~ ~ b ~ty ~~!1~Gas ~ons. Commission ~,~ 2o aac 25.2so 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ ~C Or~@iver ^ Other Q Alter casing ~ Repair well ~ Plug Perforations ^ Stimulate ^ Time Extension ~ ~ Site Inspectio Change approved program ^ Pull Tubing ~ Perforate New Pool ~ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exxon Mobil Corporation Development ~ Exploratory ~ 178-005 ~ 3. Address: Stratigraphic ~ Service ~ 6. API Number: PO Box 196601 Anchorage, AK 99519-6601 50-089-20007-0600 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 ^ Point Thomson Unit No. 3- 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 47559 surFace / ADL 47558 BHL 36 ~ Point Thomson 12~ PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14,125 . 13,151 _ Surface Surtace See Attached None Casing Length Size MD ND Burst Collapse Structural Conductor 784' 18 5/8" 811' 811' 2420 1700 Surface 3311' 13 3/8" 3338' 3298' S380 2670 Intermediate 10320' 9 5/8" 10347' 9681' 7290 7100 Production 4612' 7" 14114' 13140' 13700 13010 Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A NIA N/A N/A Packers and SSSV Type: N/A Packers and SSSV MD (ft): 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: March 1, 2009 Commencing Operations: Oil ~ Gas ^ Plugged ^~ Abandoned ~ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ~ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Barker / Jack Rickner Printed Name Craig A. Haymes Title Alaska Production Manager Signature Phone (907) 564-3617/(907) 564-3783 Date Ff COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: O~ ~~5 Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~ Other: ~~~ S~~~M~,~~i ~ ~~~`~ ~~~ ~.~~Er--~~C~v~~`i~°c~ Subsequent Form Required: 'l„~oti~ ~1 ~ ~ ' ~ ~,~~'~G~ ~~ ~-~v S. '~.~s~--~~ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 3/` 7 Form 10-403 Revised 06/2006 ~'~ '~~~Y ~~~ '~4 ~~~~ Submit in Duplicate ExxonMobil Production Company P. O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimile Craig A. Haymes ~ ~ ~ ~'` ~~ ~ Alaska Production Manager V Jt. Interest U.S. ~-z:: 1 `~ ~ 2Q09 t~a~~5ke~ ~11 ~. t`?<;~~ ~Q~'11TlISSI+Qs'R 6~~a;~.. '~~ February 25, 2009 Mr. Dan Seamount Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Application to Inspect Exxon Mobil Corporation Point Thomson Unit #3 PTD No. 178-005 Dear Commissioner Seamount: E~onMobil Production Exxon Mobil Corporation hereby submits an Application for Sundry Approval to perform a surface inspection of the subject well. This inspection will assist in long-term well monitoring. No well work is anticipated at this time. The top of the well will be exposed by excavating gravel covering it to allow 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. The wellhead configuration may be modified to allow easier access for regular wellhead inspections in the future. Please find enclosed the following information: 1) Form 10-403 Application for Sundry Approval 2) Wellbore ScMematic 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 564-3617 or Jack Rickner at 564-3783. Sincerely, ,~'f ~~ ~ ~~ ~ CAH:e~a Attachments A Division of Exxon Mobil Corporation Exxon Mobil Corporation Pt. Thomson Unit #3 Well Schematic API #: 50089200070000 APTD #: 178-005 Wellhead A section in place with 13-5/8" x 3" capped flange and marker post on top Diesel to surface from 40' (15' BGL) in 9-5/8" casing Cement plug from 40' - 100' (15'-75' BGL) in 9-5/8" casing 18-5/8", 96.4 ppf, K55, BTC Conductor casing at 811' MD (811' TVD), cemented with 4,300 Sx permafrost Arctic casing pack in 9-5/8" x 13-3/8" annulus Cast iron bridge plug at 2,000' MD 13-3/8" 72 ppf, L80, BTC surface casing at 3,338' MD (3,298' TVD), cemented to surface with 3,750 Sx permafrost TOC behind 9-5/8" casing estimated at 5,000' Top of cement in 9-5/8" casing at 8,869' MD Baker cement retainer at 9,019' MD 7", 35 ppf, P110, BTC Production casing stub at 9,502' MD 9-5/8" 40# Soo-95 at 10,347' MD (9681' TVD), cemented with 2,450 Sx class G Top of cement inside 7" casing at 13,612' MD Top of cement outside 7" casing at 13,664' MD per cement bond log Halliburton cement retainer at 13,847' MD, unable to pump through with 8,000 psi Baker model F-1 production packer at 13,852' MD Perforations 13,872' - 13,885' MD, 2 spf, 180° Cast iron bridge plug at 13,890' MD Baker model F-1 production packer at 13,892' Perforations 13,908' - 13,925' MD, 2 spf, 180° Top of cement inside 7" casing at 14,024' MD (float collar) 7", 35 ppf, P110, BTC, Production casing at 14,114' MD (13,140' TVD), cemented with 1,035 Sx class G 8-1/2" open hole TD at 14,125' MD (13,151' TVD) Well schematic drawn June 29"', 2007 by Jesse Mohrbacher, Fairweather E& P Services, Inc. Exxon Mobil Corporation Pt. Thomson Unit #3 API #: 50-089-20007 PTD #: 178-005 Inspection Procedure Backqround Well Information The Point Thomson Unit #3 well was drilled in 1979. The well is currently suspended, but requires an inspection to verify its condition and continuing compliance with conditions of maintaining its suspended well status. The 9-5/8" casing has a diesel from 0' to 40' and a cement plug set at 40'- 100'. Below the surface cement plug there is 10.2 ppg CaCl2 brine and a cast iron bridge plug at 2,000'. The 9-5/8" x 13-3/8" annulus contains arctic pack from surface to approximately 3,338' and a mud below to 5,000' (top of cement behind 9-5/8" casing). The well schematic is attached to this procedure. The reservoir section of the well is effectively isolated; therefore it is unlikely that high pressure will be encountered during the inspection. However, contingency plans and procedures will be included in the detailed inspection procedure to safely manage any well pressure encountered. The inspection will include the following steps: • General inspection of the well location to the extent possible (winter operations) • Excavation of gravel covering the wellhead and cellar • Visual inspection as to the condition of the wellhead • Verification of the well integrity by checking for and recording pressures in the 9-5/8" casing and the 9-5/8 x 13-3/8" annulus o Perform diagnostic test if pressure is found (i.e., trapped vs sustained pressure) o Identify contents of the casing and annulus by attempting to get a sample • Clean up of location and leave well in a safe and secure condition The proposed inspection will be supported by on-site equipment and materials such as excavator, camp, transportation, fuel and other essential elements of remote operations. The following well inspection program is planned: 1. Insure all necessary permits and applications are in place. Notify AOGCC at least 10 days before operations begin. 2. Mobilize all personnel and equipment to the Point Thomson Unit #3 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 instalfation 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. Backfill the cellar with gravel with allowance for gravel settling with time. 11. Ensure well is safe and secure. Chain 8~ lock close any valves above ground level. 12. Clean up location. Remove any fluid from the well for proper disposal. Take photographs clearly showing the condition of the location as left. 13. 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J _~~~ `~'~F '~i+~ w~ A .1_.~ 'w!i `= "~.. °;Y; ~ ,'P'~l'.'cs' .. ~ . j: ~, -.,~ : ~'.~~'e..;7 ~ ~ ~;~jy X . ~.~ ~r r~~.'~'~ •t-.J~ i~`.~ ~ ~~.~ Y.. ~! v ~ a 7~ y,,. ~' ~ x _ ~'i ~ , .: r ~. ~r - . ~ ~ .~,5 ,: ~ i~ -+~ •.X~ wS-.~..~%ts^.<..v:.i.. . ..r~..v~.. _.kai~* ~;•'"~ .~.vi .._ :~~,.'.`~wXi`.:..~~~:.,~,~_. ~Y.y.._ E,; ~~a`~a_,~~~:k~S:f« - . r..~r:~....:-t ~~ _.;_fr;. ~i _ ..~ ._ s..1,.. ._> ,:`.•i~ti <<, ~°+r~. ~ ~ .tb ~. ~ ~. ~Y' w,:~) ,.. ~ fi.~,r. .a~~~~"s~~'PSSf~YPG~f' ~'c~d~ ~G~713^~~"t%'i~?;: ~~~S~C~a t;~~~ ~~RC~'~~~ ~C3f'~S~~Y~J~,~€~S.'" ~CD{'±'?d'IuiSa('C~Y' 333 ~/~~s~ ~`h A~/~~~e, S~ite ~s~~ ~,€~~horage; ~fias~Ca 99~~~-3539 ~~: ~€. -~r~omsor~ ~i~Y~las - ~'l~aggir~g a~~d ~,bae~do~r~oer~t M~ea~ Co~rz~issioner Seat~our~'c: ~~~~,~c~~~v~~~~o~ ~~~>~"~°~~ ~:~~~~~~ 1,. ~~v ~.~.~ M%,i~ ~ ~ 100~ AI~~.~~ ~~ i~ Gas ~~~'~~. ~;e,mr~t't~~~ .. ~har,ac~~ fra response #o ~he Commission's December 7; 2007, letter to ExxonMobil, attached are s~andry notices requesting the Staines River State IVo. 1, Alaska State C~-~, and Point T~omson Unit ~lo.'s 1, 2, and 3 welis be reciassified from abandoned to suspended status. Site inspectior~ st~ndry notices, Forrr~ 7 0-404 reparts and photos, are also attached for these five wel~s and the Point Thomson iVa 4, Alaska State J-~ , VVest Staines No 18-9-23, and W~st Staines No. 2 weils. We are making pians to conduct the iv~spection and remediation work described in ExxonMobii'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 Qlan of Development for PTU to the Department of Natural Resources that calis for driiling operations to be conducted during fihe 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 cor,junction with that driliing plan. We share the Commission's desire to conduct the remediation work in a timely and date eertain manner, but vve would like the oppo~unity to revisit the timing of the remediai work if tMe drilling program does not proceed as currently planned. 1Ne believn there are operational safety and efficiency factors that should be considered. ~iease ~ote the Staines 4~iver ~tate #1 well is under extended confidentiality as provided rander AS 31.J5.035(d) and 2~ AP~C 25_53Z{b). W~ have included iis report as a separate, confidential attachmen±. i/~7e agair thank the ~ommission for providing clarity around the issues and for providing adequaze ~ir~e fior txxon~/lobil to conduct a thorough a~d thoughitul review. Piease ~eel #ree k~ co~tacf m~, Bill i~ecor, or ~at~ ~Jragnich if you have any questior~s, Sincerel j -, ~~~• , ~ ~.;:i~%~':ry:e~~s ~ ar ~ ~~~;-~~ :'~-~~l~~c~; ~uor~occ~fi~i~;i~~ ?;a.~cL '~~~1/~i~L;X. ~~~:~~~~'~r STATE OF ALASKA III RECEIVED AlikA OIL AND GAS CONSERVATION COMMISSION MAR 1 8 2008 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Alaska Oil&Gas Cons.Commissbil 1.Type of Request: AbandonD Suspend 0 Operational shutdown❑ PerforateD WaiveAatorage Other El Alter casing Repair well❑ Plug PerforationsO Stimulate❑ Time Extension 0 Change approved program❑ Pull Tubing Perforate New PoolD Re-enter Suspended Well❑ 2.Operator Name: 4. Current Well Class: 5. Permit to Drill Number: "7 0o5 4 Exxon Mobil Corporation Development ❑ Exploratory ❑ 78-5—' 3.Address: Stratigraphic ❑ Service 0 6.API Number: PO Box 196601 Anchorage,AK 99519-6601 50-089-20007 ' 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 ❑ Point Thomson Unit No. 3 ' 9. Property Designation: 10.KB Elevation(ft): j1.,Fietwl/Pool(s): ADL 47559 surface /ADL 47558 BHL 36 ,. Wildcat 12. PRESENT WELL CONDITION 8*MMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effecti'J'pth TVD(ft): Plugs(measured): Junk(measured): 14,125 ' 13,151 ' Surface , Su ace See Attached None Casing Length Size TVD Burst Collapse Structural Conductor 784' 18 5/8" : 1' 811' 2420 1700 Surface 3311' 13 3/8" fj 333 3298' 5380 2670 Intermediate 10320' 9 5/8" 103 9681' 7290 7100 Production 4612' 7" 14114 13140' 13700 13010 Liner I t Perforation Depth MD(ft): Perforation Depth TVD(ft): 4ins ' - Tubing Grade: Tubing MD(ft): 13872-13885,13908-13925 12908-12921,12943-12% N/A N/A N/A Packers and SSSV Type: Baker Moder 2 ea Packers and SSSV MD(ft): Baker F-1 @ 13892'&13852' it Retainers @ 13890',13847'&CIBP @ 2000' 13.Attachments: Description Summary of#ifi kal 0 14.Well Class after proposed work: Detailed Operations Program ❑ BOP ❑ Exploratory Q Development ❑ Service 0 15.Estimated Date for 16.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ Plugged Q Abandoned 0 17.Verbal Approval: Date: WAG 0 GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 18. I hereby certify that the foregoing is true anti correct to the best of my knowledge. Contact William C.Pecor Printed Name William C.Pecor , Title Point Thomson Coordinator Signature `/ Phone (907)564-3766 Date A2126044 • 0474,8 COMMISSION USE ONLY , Conditions of approval: Notify Com Mission so that a representative may witness Sundry Number:,5vb- 055 r l s' Plug Integrity 0 VOP Test 0 Mechanical Integrity Test ❑ Location Clearance 0 f Other: This request is to change tive well classification from Abandoned to Suspended, no well work is proposed. Subsequent Form Required: LACY `:)-v �.. cl.A._T kNV.-- ))) APPROVED BY Approved by: 0RIGtirAirNER THE COMMISSION Date: Form 10-403 Revised 06/2006 vRBDMS LL Submit in Duplicate F 7 1 '1016 • March c 7 2008 7ag0O jE Commissioner Dan: Seamounf. RFI��° t� Alaska Oil and Gas Conservation Commission '�=r',�. "-a.. 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 MAR 18 ?OH Re: Pt. Thomson Wells—Plugging and Abandonment AlGasons.Ca i1 Anchorage Dear Commissioner Seamount: 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 ExxonMobii'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. \Ne 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 ExxonMobii to conduct a thorough and thoughtful review. Please feel free to contact me, Bill Pecor, or Rob Dragnich if you have any questions. Sincerell. -. :ki:tachcr.ents cc: Mark 'reiand; ConocoPhiilips Vince ?eMieux- Chevron • • Davies, Stephen F (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, December 15, 2008 8:10 AM To: Seamount, Dan T(DOA); Foerster, Catherine P (DOA); Norman, John K(DOA); 'Mintz, Robert E.' Cc: Davies, Stephen F (DOA); Roby, David S (DOA) Subject: FW: Permit to Drill and Sundry Applications All, Here is the reply to my message of last week to Rob Dragnich. Tom Original Message From: rob.g.dragnich@exxonmobil.com (mailto:rob.g.dragnich@exxonmobil.com] Sent: Friday, December 12, 2008 5 :23 PM To: Maunder, Thomas E (DOA) Subject: Re: Permit to Drill and Sundry Applications Tom, thank you for your note and for your time yesterday. In response to your questions: 1. We request the AOGCC initially process the APDs for the PTU 15 and PTU 16 wells. As you probably know, state and North Slope Borough seasonal drilling restrictions will only allow drilling deeper sections of the wells during the time period from November 1 to April 15 of each year. To maximize utilization of the drilling rig, an option we are evaluating is drilling the surface hole sections of both PTU 15 and PTU 16, before proceeding to the protective and production sections of the wells. Those portions of the wells could be drilled outside the seasonal window. We request the AOGCC keep the remaining permit applications in the active file, but not process them at this time considering the 24 month effective period from the date of approval for the permits. We will contact you in the future, when we need the additional permit applications processed, once we have further details on the order of the drilling program after the first two wells. We also would like to discuss with the AOGCC whether a spacing exception would be required for the PTU 15 well. PTU 15 is planned to be a gas injection well, but we might do some production testing as described in the drilling program for the well. The wellbore will be about 1150 feet from the lease line at the top of the Thomson Sand Formation, roughly 1000 feet at the bottomhole location. Would a spacing exception be necessary for this well? 2 . Some of the March 2007 permit applications have the same bottomhole location as those filed in July 2008. While we would not drill two wells to the same bottomhole location, we request the AOGCC keep all applications in the active file until a determination is made as to which wells will be drilled from which surface locations. We would provide a reasonable amount of notice to the AOGCC before we needed approval of a particular permit application as noted above. 3 . We're working on the permit applications for the well inspection and remediation work. We expect to submit the North Slope Borough permit application this month (will send the AOGCC a copy of it) . The sundry notice applications should be submitted in January 2009. Thanks again. Please call if I can further clarify any of the above. And have a great Christmas & Happy New Year if I don't talk to you before the new year. Regards, Rob Dragnich 907-564-3711 (office) 907-564-3789 (fax) 907-830-4796 (cell) rob.g.dragnich@exxonmobil.com 1 1/27/2009 3:35 PM 411 "Maunder, Thomas E (DOA) " To <tom.maunder@a rob.g.dragnich@exxonmobil.com laska.gov> cc Subject 12/11/2008 Permit to Drill and Sundry 03 :38 PM Applications Rob, ExxonMobil has on two occasions in the past year or so submitted a total of 16 Form 10-401 Permit to Drill (PTD) applications for new wells in the Pt. Thomson area. 7 permits (PTU #7 - PTU #13) were submitted March 30, 2007 and 9 additional permits (PTU #14 - PTU #22) were submitted July 10, 2008. We have the following questions: 1. If the Commission processes these applications, which permits need to be processed for the 2008 - 2009 drilling season? Which permits need to be processed for the 2009 - 2010 drilling season? 2 . Do any of the applications submitted July 10, 2008 replace any of the applications submitted March 30, 2007. 3 . When can we expect to receive the Form 10-403 Sundry Applications for the 4 legacy wells to be abandoned? Please respond to me with your reply. Tom Maunder, PE AOGCC 2 1/27/2009 3:35 PM ~ ~i~V Wr! r ir W STATE OF ALASKA MAR 1$ 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT O F SU N D RY WE LL OPERATI~a 0~ 8 Gas Cons. Comrnissi~tt 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Site Inspectiori ~ '- 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: `11~,.,~ ~ Name: Exxon Mobil Corporation Development ^ Exploratory^~ ~ 78-5 • ~ 3. Address: PO Box 196601 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6601 50-089-20007 ~ 7. KB Elevation (ft): 9. Well Name and Number: 36 ' Point Thomson Unit No 3 8. Property Designation: , ~ 10. Field/Pool(s): ADL 47559 surface / ADL 47558 BHL Wildcat 11. Present Well Condition Summary: Total Depth measured 14125 ' feet Plugs (measured) See Attached true verticai 13151 • feet Junk (measured) None Effective Depth measured Surface feet true vertical Surface feet Casing Length Size MD ND Burst Collapse Structural Conductor 784' 18 5/8" 811' 811' 2420 1700 Surface 3311' 13 3l8" 3338' 3298' S380 2670 Intermediate 10320' 9 5/8" 10347' 9681' 7290 7100 Production 4612' 7" 14114' 13140' 13700 13010 Liner Perforation depth: Measured depth: 13872-13885, 73908-13925 True Vertical depth: 12908-12921, 12943-12959 Tubing: (size, grade, and measured depth) NIA Packers and SSSV (type and measured depth) Baker Model F1, 2ea Baker F-1 @ 13892' 8~ 73852' Retainers @ 13890', 13847' & CIBP @ 2000' 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-Bbf Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after work: Pictures from Aug 07 site inspection X Exploratory0 Development ^ Service ~ Well Schematic X 16. Well Status after work: Abandoned Information from Aug 07 inspection X Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact William C. Pecor Printed Name Willliam C. Pecor Title Point Thomson Coordinator N'' C G~ ~ . •G~[G Signature Phone (907) 56 4-3766 Date 3~ Qg Form 10-404 Revised 04/2006 Submit Original Only ~ ~, ~ ~ ~F~-. ~U~ ~3 ~ 200~ ~A Y. i ~~~ Euuon Mobil Corporation Pt. Thomson Unit #3 Well Schematic API #: 50089200070000 APTD #: 178-005 Wellhead A section in place with 13-5/8" x 3/ capped flange and marker post on top / ` Diesel ,~ Diesel to surface from 40' (15' BGL) in 9-5/8" casing ~`* - ~ r* `~ Cement plug from 40' - 100' (15'-75' BGL) in 9-5/8" casing 10.2 PP9 . t CaCl2 ~~i •~ 18-5/8", 96.4 ppf, K55, BTC Conductor casing at 811' MD (811' TVD), ~, x Water cemented with 4,300 Sx permafrost ~~ +~ Arctic casing pack in 9-5/8" x 13-3/8" annulus 15.8 ppg Fresh Water Mud 15.8 < . < . Cast iron bridge plug at 2,000' MD 13-3/8" 72 ppf, L80, BTC surface casing at 3,338' MD (3,298' TVD), cemented to surface with 3,750 Sx permafrost TOC behind 9-5/8" casing estimated at 5,000' Top of cement in 9-5/8" casing at 8,869' MD Baker cement retainer at 9,019' MD 7", 35 ppf, P110, BTC Production casing stub at 9,502' MD 9-5/8" 40# Soo-95 at 10,347' MD (9681' TVD), cemented with 2,450 Sx class G c Top of cement inside 7" casing at 13,612' MD Top of cement outside 7" casing at 13,664' MD per cement bond log Halliburton cement retainer at 13,847' MD, unable to pump through with 8,000 psi Baker model F-1 production packer at 13,852' MD ~ Perforations 13,872' - 13,885' MD, 2 spf, 180° Cast iron bridge plug at 13,890' MD Baker model F-1 production packer at 13,892' ~ Perforations 13,908' - 13,925' MD, 2 spf, 180° Top of cement inside 7" casing at 14,024' MD (float collar) 7", 35 ppf, P110, BTC, Production casing at 14,114' MD (13,140' TVD), cemented with 1,035 Sx class G 8-1/2" open hole TD at 14,125' MD (13,151' TVD) Well schematic drawn June 29`h, 2007 by Jesse Mohrbacher, Fairweather E& P Services, Inc. ~ PPg ~~ Point Thomson Unit No. 3 Drillsite Inspection 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 leakage into the pads and surrounding surface waters. The pad is a large and generally level pad free of significant thermokarsting or other signs of degradation. Gravel was mounded around the wellbore and only the wellbore marker was . visible. There are no significant surface waters nearby. Some depressions on the pad contained water • and these were free of hydrocarbon stains. No offsite debris or other signs of the former drilling and drilling waste disposal operations were observed. The pad area is currently being used by BP Exploration to store fuel tanks, casing, a connex, soil in a containment area, foam insulation, and miscellaneous lumber and scrap materials. Steel and gravel loading ramps existed. Two small hydrocarbon stains (e.g., 1-2 feet diameter) • on the gravel pad were noted. Point Thomson Unit No. 3 -1- ~"~'r' °' ~ ~` ~ «~'`~~. ,~ `y ~~~~ ~ . ~~ a~ - k.. ' b ' ' r7. ~ ~ R . -~ .~f • t . `'~ _ . -. .. . . • . . - ~ . .I ~ _ ' ~ ~ - - ~ . _ " ' . . . . . ~ ~ - . -. . ~rt ~ -2- Point Thomson Unit No. 3 ~._ ~; ~ ~~~ _ ' ~C, . ~.:~is~.~~ ~~i.t~~ t.;;~ ~I 1 . ~~~~~ =~.~8~~ r " i~ \Y ~ r^S 7!~ '~-~y ^~7~? ~ ~ ~ y~ .r-m ~ t^ . .:--a ~_ -~~. ,~:`lu S~~l:a5~'1:,~~~1";~~, _.`:ili~`L~'~~~i~.1~"~S. o~~ ,~~n~ , ~~-~ ~~~ -<t;J ='a,,;_.?s ~.;asl~.a P~~~d~~.i:^3~ ~'(~nag~,. ~ x:~~r:~l~ouii Pr~d~rci?on ':ompanJ ~'~ ~ox 136~v ~ ~nchc~rage.~I~ 99~t9 Re: Pt Thomson F~iel.Es -~'lugging and AbandonmPnt ~ear ~'~1; . 1-iay mes, 3~3 ~~; r A~~ ~Nu~ ~i =:. ~ i~l~, On.".'o /` ,aSnf> ~~C" .,...._ :!~i7~_ ='?' ,~ =A): ~>G' _ ., G2 This is in respons~ to your letter of November 14, 2007 responding to the alaska Oil and Gas Conservation Commission's ("Cammission"} (etter of May 18, 200? regarding the condition of certain Pt. Thomson linit wells. The schedule and plan for remedial work provided with ~~our letter are acceptable subject to the follo~~~ing conditions: 1. ~~conil~Iobil will perform the proposed fie(d 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 diese! wil[ be removed from the W'. Staines State #18-9-23 (169-120) and V/. Staines State #2 (175-002) ~~ells. 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 reasonabie actions tlae 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 timel; and otherwise properly requested a~d granted by the Commission. To assist the Commission in ensuring that its files are comp(ete and accurate, by March 31, ?008; please submit for each well a Form IO-404, a summary of the observations from the work performed last summer, and location photos. ~'inally, nothing above expressly or implicitlv evidences the Commission's position with respect to the status of ~xYOnl~tobi[ or an} other person as a current Pt, Thomsor~ Un?t operator, working interest otvner; or lessee. !i yeu have an,~~ qu~stions. please ca(1 ;ne ai %~3~ i2~ f or Tom ~aunder, PE at ?93-1Z~0. ~incereid; / ~~ ~~ ~~ ~ o ~ (~'~?t~ ~ ~~,~f~ .~' ' ~.,ath~ r'. t=oerster ~~o~ nm ission~~ ~tt~~e~~i~~el ~~m¢Iuc~Boaa ~~mpaaa~/ P. O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimile ~paag ~. a~a9/~a~s Alaska Production fvlanager Joint interest U.S. ~-, ~~,~ d/ ~?' , 3~ , 0~ Proda~ctio~a fVovember 14, 2007 Chairman John Norman Alaska Oii 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: We are providing this letter in response to the Commission's May 18, 2007, letter to ExxonMobif 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 welf 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 cur~ent condition, we recognize that performing certain remedial work can further reduce any risk of an incident that may occur in the future. With that in mind, we have developed the attached schedule and plan to conduct remedial work on the wells. If the Commission concurs with this work program, ExxonMobil will prepare the appropriate sundry notices and begin to carry out the actions. As described in this letter and accompanying attachment, the plan contemplates conducting remedial work on certain wells in the near future and reclassifying the remaining wells to a suspended status. The wells with planned near term remedial work do not appear to have future utility while the wells identified for reclassification are capable of producing in paying quantities. We believe it would be premature to conduct work on these latter wells that may make it more difficult to utilize them in future development operations. There are other existing suspended wells in the Point Thomson Unit, and we view this action as consistent with current circumstances. vVe unders~a~ic~ ihat ~ e~lass~ficat;3r wi!! ~arn~ ar, nhligati9n to abandon the wells in the future in compliance with regulatory requirements. A Division of Exxon ilAobil Corporatioae ~~~ ~~~~~ Commissioner John Norman - 2- November 14, 2007 Piease note the plan cails for conducting the most intensive phase of field work in conjunction with the first winter drilling season of 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 saf~ty 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 ExxonNlobil 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 toceed w t therout~l ned work plans! ( Please eellf ee to cont ct your concurrence so we can pro me, Bill Pecor at 564-3766, or Rob Dragnich at 564-3711 if you have any questions. Sincerely, ;~ ~ ,:-i ~ `=~ li~'~`''' ~ l/ / CA :rgd/jpc Attachments xc: Cmmissioner Cathy Foerster - AOGCC Commissioner Daniel T. Seamount - AOGCC Kevin Brown, BP Mark Ireland, ConocoPhillips Vince LeMieux, Chevron ~,~ ~~e ° ~ ~~,~~ ~~! ~~~~~,~ ~ Remedial Action Program Point Thomson Welis - Plugging and Abandonment 1Nells Affected Actions Timin PTU #1, PTU #2, PTU #3, - Conduct additional integrity investigations to include: - Conduct work during winter of 2008-09 PTU #4, Alaska State C-1, + Removal of gravel from around wellheads Staines ~2iver 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 ho c~l~S~` set cement plugs in annuli using top job techniques ~~~ (plugs to be at least 50' long) ~~/~~ - Install marker plate - Remove cellar - Conduct general location cleanup, and request final site clearance Staines State #18-9-23 W - Remove marker post - Conduct work in conjunction with first . i - Remove diesel above surface plug (IC7 } 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 i5 lace as necessary Q o ss~b~. air or re + Re ~~ ~~~ ~ ~ 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 ceflar - 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 ~-~~~c`.~~ + Repair or replace as necessary - Remove near-surface arctic pack from annulus and C~S~~ ' set cement plug in annulus using top job techniques ' ~ ~ (plug to be at least 50 long) , a~rt' - Install marker plate ~ ~ - Remove cellar - Conduct general location cleanup, and request final site clearance Alaska State J-1 - Remove marker post - Conduct work in conjunction with first - Remove wellhead and casing to lower than 3' below year of Point Thomson delineation ho c~~tS~\ ground level drilling planned for winter of 2008-09 - Verify integrity of surface plug ~p ~~ + 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 #~ - Fite 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 I AOGCC regulations winter 2008-09 inspections -2- Staines Hiver State #1 - File sundry notice to change well classification from - Subm~t sundry notice within 90 days of abandoned to suspended AOGC;C concurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winte~ 2008-09 inspections Alaska State C-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 20Q8-09 inspections -3- ~. f J:~ ~~~ ''J ~ ~~ =~ ' ~ ~ !~ ~~ _, ~ ~~1ay ~3, ~0~~ ~ommissioner ~afhy Foerster Alaska Oii and Gas Conservation Cornmission 333 West 7th A.venue, Suite 100 Anchorage, Alaska 99501-3539 Re: Point Thomson Wells - Plugging and Abandonment Dear Commissioner Foerster: ,. _~ ~'~ ` ~ ~;'~ ~ ~ ~i ~:~ .:~~ ~ ~ ~ ~j~ :`,~`:; ~ '~' ~t;%; ~ ~~ :~~:~~ ~' ~ ;~~,~ j~~~ ~~~~.~.~~'~~~ ~~~~~~d°~~~ 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 file from the Commission. 2. It would be helpful to obtain a copy of the concerns or issues identified in the Commission's review. We intend to conduct a thorough review of all of the wells in auestion and having any initial assessr~ent by the Commission to check against as our work progresses may facilitate an earlier completion. tt appears the wells on the list were operated by Exxon, Mobil or BP (formerly Sohio). To the extent another operator may be responsible for any of the identified wells we will work vvith the other owners to determine appropriate handfing and response to the Commission. b 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 bringing these matters to our attention. ~incerziy yours, ~' ~ ~ t-~. f- ~ ~° ~:jnc xv: A,rg~;~ >i~i'~Iker, ~~ ~~~:~~i ~~9± Jfl1, a~~9~~d6~l~r~ ~ ~~~~~ ~~ ~~ ~~ ~~ ~Ia~ 1 ~. ?t)()7 ~raig ~-Iaymes <alaska Production ~~(anager Exxon!Vtobil Prc~ducti~n Company PO Box 196601 ~nchorage, AK 99~ 19 Re: Pt. Thomson Wells - Plugging and Abandonment Dear t~tr. Haymes, 333 W. 7thAVENUE, SUITE I00 ANCHORAGE, ALASKA 99501-3539 PHOfJE (907) 279-1433 FA~ (907j 276-7542 During our review~ of the Pt. Thomson Field in response to your recent applications for permits to drill, the Alaska Oil and Gas Conservation Commission ("Cornmission"j identified the following wells that, according to our records, are classified as plugged and abandoned but do not meet the requirements for plugged and abandoned w~ells under 20 AAC 2j.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 # I VJithin 90 days of receipt of this letter, either provide sufficient information and documentation to demonstrate that these wells meet all the requirements for plugging and abandonment, or provide a schedule and plan for bringing these weils into compliance. Also, please note that, under AS 31.0~.090, the Commission cannot issue permits to drill to an operator that is 2n violation of a Commission regulation pertaining to drilling, plugging or abandonment of a well. The Cammission reserves the right to pursue an Enforcement Action according to 20 AAC 2~- ~35. C_~~.; ~-+:"ayn~~s ?,1,, I 3. ~ 00' Pa~~e ' ot ? [=ina(ls, i~ot~?in~ ab~~~ sh~~Lilci b~ cunstru~~d tu ti~id~«L~~ ~~~rc:ssl~ or im~licit(ti ine C'~~mmission°s positi~or~ tii~ir~ s~~p~~;i r~ che v~~rrer~s_ statt~~ ~f r;~x:~r~:'~~o~i~ ~r any other p~rson as a~t. T~homson u~~t o~~rat~r or 1~sse~. It~~ou ha~~e any quc:sti~ns, please ~;all ms; 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 Pt. Thomson area was performed. T'he purposes of the assessment were to determine if the condition of the wells met the regulatory requirements in effect when operations were completed some years ago as well as if the wells would meet the now current regulatory requirements. There are a total of 21 wells in the general area (14 E~onMobil + 1 ConocoPhillips + 6 BP). This document will only address the Ez~xonMobil welis. Recommendation: Based on exarnination of the well files, it is my assessment that 5 of the 14 ExxonMobil wells are Plugged and Abandoned in accordance 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: There are 4 versions of the plugging requirements in effect depending on when the work was actually accomplished. A summary of the effective dates of the various regulations is listed below and copies of the regulations are atta.ched. Requirements have become more proscriptive through time. There were major amendments to the AOGCC regulations efFective 4/2/1986. These included significantly more proscriptive requirements for plug locations and lengths, a suspended well classification and included requirements for removal of the wellhead and casing "... at least 3' below rig grade." In the 11/7/99 amendments, the cutoff requirement was changed to "... at least 3' below original grade." Prior to 1980, 50' cement plugs were required above hydrocarbon zones and at surface with heavy mud-laden fluid between plugs. After 1980 100' of cement was required above hydrocazbon 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 ZS The physical downhole work on 7 of the 14 ExxonMobil operated wells was completed prior to April 13, 1980 and physical downhole work on 6 of the remaining wells was compieied prior io t~pril 2, i yuo. 'I"ne iasi weii, tiiasica ~iaie ti 2, was piugged ana abandoned in 1Q 2002 according to the 11/7/99 regulations. Regazdless of when physical operations were completed in the legacy wells, letters were submitted (most in November 1986) requesting the status of the wells be ehanged from suspended to abandoned. These requests followed physical inspection of the locations for site clearance subsequent to removal of upper casing heads and installation of abandonment markers. No downhole work was performed subsequent to removal of the drilling rig. It is interesting that following the completion of downhole work that nearly every well was labeled suspended, and that term is not defined in AOGCC regulations until the 1986 amendments. Temporary abandonment is first addressed in the DNR regulations effective 9/30/67. Examinaxion of the files for the ExxonMobil wells reveals that, so far as I can determine, the wells have been effectively abandoned downhole. All wells had cement placed over productive intervals and usually employed retainers or bridge plugs. One well, Alaska State J-1 does not have any open hole plugs, but the well apparently did not encounter hydrocarbons. The intermediate casing shoe was squeezed below a retainer. Moving up hole, most wells ha.d a portion of the production casing (~") cut and pulled. In all cases except Pt. Thomson #1, a retainer and/or a cement plug were placed on top of the stub. T'here was no specific requirement to cover the stub prior to April 13, 1980, although in 3 subsequent welis the cut top of the 7" was isolated. Wells generally had a retainer and/or cement placed at about 2500' with non-freezing fluids placed above it. Non-freezing fluids included CaCl2 brine and diesel. Where annuli were not cemented, non-freezing fluids such as arctic pack and diesel were placed. No well had all casing head heads removed. It appears that the casing heads 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 atta.ched was then bolted to the flange. It is important to note that E~on performed "re-abandonment" work on 4 of these wells that were located on the barrier islands offshore in 1998 - 1999. The offshore islands were being eroded, and it was likely that the well casings would be exposed possibly resulting in spills. E~on specifically sta.ted that the work would "... plug and abandon the wells according to current regulations." The 4 wells were re-entered, liquid hydrocarbons (diesel) removed, cement plugs placed and casings cut off we11 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 April 2, 1986. Based on examination of the well files, it is my assessment that 5 of the 14 ExxonMobil 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. Ea~onMobil should be required to perform the work necessary to praperly plug and abandon the wells. Tom Maunder, PE Sr. Petroleum Engineer E~conMobil 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 4/2/86 11/7/99 Status W. Staines St 169- 8/13/70 5/1173 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 Sta.te A-1 174- 9/6/75 ~ by letter YES YES NO YES Re-abandoned 1998 -1999. Plugged and None 014 11/86 Abandoned W. Staines St. #2 175- 5/26/75 ~ by letter YES YES NO NO Diesel in casing 150' - Suspende~l Remove fluids, place 002 9/86 2279'. AP in annulus. Not plugs, cutoff wellhead cutoff Pt. Thomson #1 176- 12/8/77 ~ by letter YES NO NO NO No plug above cut 7" at Suspended Remove fluids, place 085 11/86 4000'. Diesel in casing. plugs, cutoff wellhead AP in annulus. Not cutoff. Pt. Thomson #2 177- 8/12/78 ~ by letter YES YES NO NO AP in annulus. Diesel in Suspended Remove diesel. Cutoff 064 11/86 casing at 40'. Not cutoff. wellhead. Remove some AP. Pt. Thomson #3 178- 7/4/79 ~ by letter YES YES NO NO AP in annulus. Diesel in Suspended Remove diesel. Cutoff 005 11/86 casing at 40'. Not cutoff. wellhead. Remove some AP. Staines River St 179- 7/21/79 11/5/86 by letter YES YES NO NO Diesel in casing at 100'. Suspended Remove diesel, place #1(confidential) 001 11186 Not cutoff. lu s, cutoffwellhead Pt. Thomson #4 179- 12/20/80 ~ by letter 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~ NO* AP in 2 annuli. No diesel. Suspended Cutoff wellhead. 046 11l86 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 11J86 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-abandoned 1998 -1999. Plugged and None (confidential 208 I l/86 Abandoned Alaska State J-1 183- 6114184 ~ by letter NA YES N0~ NO* No open hole plugs. No AP Suspended Cutoff wellhead. 045 11l86 or diesel. Not cutoff. Remove some AF. Alaska State A-2 200- 3/8/02 by NA NA NA YES Plugged and None 141 sundry Abandoned N0~-no liquids present. • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, April 29, 2009 10:04 AM To: 'steve.shultz@exxonmobil.com' Cc: DOA AOGCC Prudhoe Bay Subject: RE: PTU #3 (178-005) Well Sign During New Drilling Operations Steve, I agree with the safety issue regarding having a signpost in the middle of the pad. As discussed, it is appropriate to know where the well is but not necessary to have the post at all times. It is probable that we will need to discuss the signage issues in the future. Call or message Tom Maunder, PE AOGCC with any questions. -----Original Message----- From: steve.shultzC~exxonmobil.com (mailto:steve.shultz~exxonmobil.com] Sent: Wednesday, April 29, 2009 9:56 AM To: Maunder, Thomas E (DOA) Subject: PTU #3 Tom, I noticed that our temporary P&A'd well on the location PTU #3 is located under the matting boards. With all of the activity that will be going on concerning drilling operations, I am a little concerned about having a sign post in the middle of the pad which could prove to be a safety concern. Is it imperative that we have signage for this well? Thanks, Steve a."C~ 5. ~c.F.r~ 1 1&�, i�TKi (2)M krUD GILO 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: k -1 O -e - c-) 5 C) SARAN 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 1 U.S. Postal Service CERTIFIED MAIL,,. RECEIPT ' (Domestic hfail Only, No Insurance Coverage Provided) For delivery information visit our website at www.usps.com t rti --------------- E3 CO211110d Fee k M 1 09 C3 MR_ klftv C3 ru PAM Dskwy Fin CO (End{ t t 01/30/2009 Ln William • • • • Production• agr'PWOB�Box 199610 Anchorage AK 99519-6601 • fi(•v�•r sc• ur usiruciioiis Z Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. �A. sign K Print your name and address on the reverse so that we can return the card to you. ■ Attach this card to the back of the mailpiece, or on the front if space permits. 1:1Express Mail B. eived ted Name) C. D. Is delivery ad ss different from item 1 If YES, enter delivery address below: 1. Article Addressed to: William Pecor ExxonMobil Production Co. PO Box 199610 Anchorage AK 99519-6601 ❑ Agent ❑ Addressee de of pelivery ❑ No 3.S ice Type Certified Mail 1:1Express Mail ❑ Registered )Oeturn Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 2. Article Number 7005 1820 0001 2499 5975 (transfer from service label) � _ PS Form 3811, February 2004 Domestic Return Receipt 102595-02-M-1540 Operator Suspended and Shut An WeTi o PENNZOIL CO Field Current Date of Permit API 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 VV SM ADL0018790 Wednesday, Jananry 14, 2009 Operator Suspended and Shut IIS. 'WeRs 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 14, 2009 ExxonMobil Pt. Thomson Heritage Wells Identified May 18, 2007 in Commission Letter to Craig Haymes APC WKL # PTD # Oper Name Well Name Field See Twp NIS Rng W/E PM Lease(s) 50-089-20001- MOBIL OIL W STAINES PT ( ( I 00-00 1691200 CORP ST 18-09-23 THOMSON 18 9 N 23 E j U E ADL 0028380 50-089-20004- MOBIL OIL W STAINES *EXPLORAT 00-00 1750020 CORP ST 2 ORY 25 9 i N ' 22 ! E U ADL 002837 50-089-20005- EXXON THOMSON PT 00-00 1760850 CORP UNIT 1 THOMSON 32 10 ' N i 23 E i U ADL 0047560 PT 50-089-20006- EXXON THOMSON PT 1 00-00 1770640 CORP UNIT 2 THOMSON 3 i 9 N 22 E ` U ! ADL 0047567 PT TvM 50-089-20007- EXXON 'THOMSON PT 00-00 1780050 CORP UNIT 3 THOMSON 34 10 j N 23 E U ADL_ 0047558, ADL 0047559 50-089-20008- MOBIL OIL STAINES PT 00-00 1790010 CORP RIV ST 1 THOMSON 17 9 i N 24 E U ADL 0047573 j PT 50-089-20009- 00-00 1790800 EXXON CORP_ THOMSON UNIT 4 PT THOMSON 32 ( 10 I N ' 22 I E U ADL 0047563 j 50-089-20011- EXXON ALASKA ST PT �� ' _- i i 00-00 1800460 CORP C1 THOMSON 14 9 E N 23 E U i ADL 0028382 -2 50-179 _ 0007- __ EXXON_ __.__, ALASKA ST PT 100 00 1830450 CORP J 1 THOMSON 2_ 3� _6 1 �N A 221v E ; U j ADL 0344033 20 aha' AC 25.110. "Suspended Niels (a) If allowed tinder 20 AAC 2J_..1_(;_J, the connn1ission «i11, upon application by the operator under (b) of this section, approve the suspension of a well if (1) the well (A) encounters hydrocarbons of sufficient quality and quantity to indicate that the well is capable of producing in paying quantities, as reasonably demonstrated by well tests or interpretive formation evaluation data; for purposes of this paragraph, "paying quantities" means quantities sufficient to yield a return in excess of operating costs; (B) is a candidate for redrilling; (C) has potential value as a service well; or (D) is located on a pad or platform with active producing or service wells; and (2) the operator justifies to the commission's satisfaction why the well should not be abandoned, and, if the well is not completed, why the well should not be completed; sufficient reasons include the (A) unavailability of surface production or transportation facilities; (B) imprudence of security maintenance of a completed well in a shut-in status; (C) need for pool delineation and evaluation to determine the prudence of pool development. (b) An Application for Sundry Approvals (Form 10-403) must be submitted to and approved by the commission before plugging operations are begun in a well for which suspension is proposed, except that oral approval may be obtained from the commission if it is followed within three days by the submission of an Application for Sundry Approvals for final approval by the commission. Approval will be conditioned as necessary to protect freshwater and hydrocarbon resources. An Application for Sundry Approvals must include (1) the reason for suspending the well and information showing that the applicable criteria for suspension under (a) of this section have been met; and (2) a statement of proposed work, including (A) information on abnormally geo-pressured strata; (B) the manner of placement, kind, size, and location, by measured depth, of existing and proposed plugs; (C) plans for cementing, shooting, testing, and removing casing; (D) if the Application for Sundry Approvals is submitted after begirnrning worl:, the name of the representative of the commission who provided oral approval, and the date of the approval; and (E) other information pertinent to suspension of the well. (c) At the operator's request accompanying the submission, information submitted to show that the applicable criteria for well suspension under (a) of this section have been met will be kept confidential (1) for the period specified under AS 31.05.035 (c), if the information is described in 20 AAC 25.071(b) ; or (2) for the time that the information has value as a trade secret, if the information is not described in 20 AAC 25.071(b) but is determined by the commission to constitute a trade secret under AS 45.50.940 . (d) A well approved for suspension must be plugged in accordance with the requirements of 20 AAC 25.112, except that the requirements of 20 AAC 25.1.12(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 Production Comp R O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimile December 19, 2008 Mr. Johnny Aiken North Slope Borough Planning Department P.O. Box 69 Craig~aymes Alaska Production Manager Joint Interest U.S. ~onMobil Production Barrow, Alaska 99723 (`~ /~ c~~ Re: Point Thomson Unit #3 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 Point Thomson Unit #3 well: • 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, ~~, ~~~ ~J• ~ ~-~ CAH/eaa Attachments cc: 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 iNobil Corporation - --~- Land Management ~ Regulations Permit Application °^+.~rw>j0D Permit Number Applicant Exxon Mobil Corporation Address P.O. Box 196601 U NORTH SLOPE BOROUGH DEPARTMENT OF PLANNING AN DCOMMUNITY SERVICES PERMITTING AND ZONING DIVISION Permit Type Conditional Development Date December 19, 2008 State ID _ Anchorage, AK 99519-6601 Phone 907-564-3617 Contact Person Mike Barker Project Name Point Thomson Unit #3 Well Inspection Location (TRS) 660' NSL 711' WEL Sec. 34 T10N, R23E, UM Unitized Field Name Zoning District Proposed Start Date February 1, 2009 and Pad Location Point Thomson Unit #3 Completion Date: August 31, 2011 Proposed Development Inspect well, check casing pressures. Purpose of Development See attached Project Description. ^ FilUDredge Material Acres ® Oil and Gas Wells Number of New Surface Holes: 0 ® Temp. Water Use 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 icles, rolligon, ® Off Road Travel: Period of Travel Feb 1, 2009 -Aug 31, 2011 Equipment steiger. 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 Amount < 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 y • • s ATTACH TO THIS APPLICATION THE FOLLOWING: -GENERAL VICINITY MAP -SPECIFIC LOCATION MAP, INCLUDING NEARBY EXISITING 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 ~~0~~~ Date Craig A. Hayrnes 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 minimization 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. • ~J 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 i of 6 i ~ Table 1-Permit Re uirements A enc Re uired 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 Pian (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 Inspecction 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 i • 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 Su ervisors Mike Barker Regulatory 907-564-3617 907-223-9904 Marra er mike.barker e~oconmobil.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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Point Thomson Area '~ \ ~ -~~' !'~ 0 0.75 1.5 2.25 3 ~~ ~, ".; ~.., ~`- ~~ wlr 12/15/2008 ~~ PSA Tralla ReVl.mzd ~ ~ ~: .,., 1 , ~ ~~ Miles ExxonMobil Production Cann 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: '1y. o161 Crai, .aymes / < Q . Qyb Alaska Production Manager �7 Joint Interest U.S. / 7& V �� X77. ab`a If 0 5U /79. E�onMobil Production / ,9 /� D /7g oao RECEIVED MAR 1 8 X008 Alaska ON & Gas Cores, ComrniRft 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 SCANNEV A Division of Exxon Mobil Corporation ALASKA OIL AND GAS CONSERVATION COP"USSION 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, 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 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 an), other person as a current Pt. Thomson Unit operator, working interest owner, or lessee. If you have any questions, please call me at 793-1221 or Tom Maunder, PE at 793-1250. Sincerely, Cathy . Foerster Commissioner ExxonMobil Production Cornpn P. 0. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimile November 14, 2007 Chairman John Norman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Pt. Thomson Wells — Plugging and Abandonment Dear Chairman Norman: Craig w, fines Alaska Production Manager Joint Interest U.S. E�onMobil Production RECEIVED NOV 14 2007 Alaska Oil & Gas Cons. Commission Anchorage We are providing this letter in response to the Commission's May 18, 2007, letter to ExxonMobil regarding Point Thomson area wells that are classified as plugged and abandoned. ExxonMobil, as Operator and on behalf of the working interest owners of nine of the listed Point Thomson area exploratory wells identified in the Commission's letter, has undertaken an extensive review of the current physical status of each of these wells. (As Operator of the remaining well, BP will respond directly to the Commission on it.) This work included reviewing ExxonMobil's and the Commission's well files, including confidential Commission files for one well, conducting on-site inspections to assess the physical integrity of each well site, and conducting a joint owner review of each well by technical experts. We are pleased to report that none of these activities have identified any imminent safety or environmental threat conditions from the wells. Attached are photos taken during the on-site inspections. The extensive reviews provide the basis for this response to the Commission's letter. While we believe the wells met AOGCC requirements when the prior P&A actions were taken and are safe in their current condition, we recognize that performing certain remedial work can further reduce any risk of an incident that may occur in the future. With that in mind, we have developed the attached schedule and plan to conduct remedial work on the wells. If the Commission concurs with this work program, ExxonMobil will prepare the appropriate sundry notices and begin to carry out the actions. As described in this letter and accompanying attachment, the plan contemplates conducting remedial work on certain wells in the near future and reclassifying the remaining wells to a suspended status. The wells with planned near term remedial work do not appear to have future utility while the wells identified for reclassification are capable of producing in paying quantities. We believe it would be premature to conduct work on these latter wells that may make it more difficult to utilize them in future development operations. There are other existing suspended wells in the Point Thomson Unit, and we view this action as consistent with current circumstances. We understand that reclassification will carry an obligation to abandon the wells in the future in compliance with regulatory requirements. A Division of Exxon Mobil Corporation ORIGINAL 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, 11Z1 r .. 7? 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 k" All, i. r['q` kV!a: �0.�...y.VYMK 4��F }'�Y� � �wx � `�,� ��,�l�,?,y�Y�`+ at-�- ,. u _ �.;+.F . s'� ziu s_!'. �:, ��i. 1.n: �. r _ .. d�.Az�$.a�. A +Rn�M�ln:n Point Thomson Unit No. 2 Point Thomson Unit No. 2 33 t1. �fy-w i`rs !'1'ft •• Y{3 � ;'"�, i �»� _t �,ts .+1,C,. �p.1 •#'•� �.. ^.r`- f '^A s�.*! `�y "`''''.; r c'�.�j 1 . i..` _i. _ � ry„ .� = wee . i t: :Z1'• \ • r' .. l �.,s2; + j41 • +I►� h Point Thomson Unit No. 2 Point Thomson Unit No. 3 Point Thomson Unit No. 3 �. ♦ t ! '�•t�C ��.��%�' Iyy�t� • � �; w� ♦w�a�p'I- j f ,. � +p(�'r'�x. t�-�,.� y7`rf�,',�y��%,-. f L. ♦ 7.uy r f q fir' ♦ 4 4 � �r� w'�'�1 �...iik. tom# ��,�r �c't -_,Cs. + �.t"'• a s �}_ � ,� y''r4! � p a, �/y{ + +'�'•� !�'+'/�'+i t ji�.- ':'�", � „may +�s� .f, i'�■ Lill, '�• F 1• i 4 N� ��' � �+i I '-.., 1 may` •��ti ` � �, �i�.�y, ..•'t♦/ �}{ �� 1. 'VS `.�� '. � •� i Point Thomson Unit No. 4 Point Thomson Unit No. 4 fp. .14 1 O o �1 �. lis, a � �A}t��: �.� '+� -, fir! ,,,.�, !k?� `� iR. •^'T"'Y'' s�-.� ._._ � . �� .ylislN.'�N"�.. _ i r"' _ ..-a'' �' . i k+ '� i^ .— ci Staines River State #1 Staines River State #1 r W- MET i - �+N. t+ �tYl �!r^ .,s "✓�P t . �^,aT � • .,yds . .. r ��4 st ��. ��.,�.t�Yr^. .�7 � �-`��„{ ��r�y�, Y-...T�{.i� :.�:,y�i Avo- —z l — -.�.( ` 1 ttdo V., —z l — + t '�" •.t{d ,.r .3. 1 ,y T� r#r-'N'T"`' ��"';°; maw .a � ,��, � .�. .err r I P- West Staines State #2 West Staines State #2 `�-• i '._ �� d i"''� ' roc �; �' --, �, - t �: ` � ^,` � ,�' c,;:�. r ueip��ARJ .v '• ; �' 1 { � fir,,, � .. �+kYY '� �*� ��"' �af :,, < S 3 <r r�' . �, • .M _may"f'y�� s.t S . � L `�. �.., e:4��Va _. a r 4f 1: I 93LP( ,t z r 4f 1: I 93LP( Alaska State J-1 Alaska State J-1 -07 "WRIMPOPM� wF "�"`� •"�° "R t „w . s;_ i < r l+ a 41 ¢q�,� �1lW 4.•- 10 y ! 1/ � yf� ��f i � ♦• 4 � `f♦ �,' � J ',� ' \tM17 .l�.A. 4fa `� { to y�,l Sri .1-+- '. ••'# <:. - - .fir, r. �} q 9• •iq,+ 4> .. - •qr _ din er�ft,. � p.k, dee y r $f i + y h � H { �.,•1"�. -.k+X � t. ' - - `?}. ..- a. W � ✓`moi; t' - i-` _.'hr y,� ' /,. T � � •M _ -i e.. +y Lt... , .mss: 111 a 44•; ,"•-t .. * T �l� � i. '` tib. nQ"V'gap+ ` f ALASSA OIL AND GAS CONSERVATION COMMSSION August 14, 2007 SARAH PALIN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Craig Haymes Alaska Production Manager ExxonMobil Production Company PO Box 196601 Anchorage, AK 99519 Re: Pt. Thomson Wells — Plugging and Abandonment Dear Mr. Haymes, This is in response to your letter of August 3, 2007 wherein you requested a ninety -day extension to the response time with regard to the condition of Pt. Thomson Unit wells as specified in the Commission's letter of May 18, 2007. It is stated that the additional time will allow further investigative work including site visits to the various wells. Your request is granted making your response due not later than 5: 00 p. m. November 14, 2007 If you have any questions, please call me at 793-1221 or T^ Maunder, PE at 793-1250. SWREU t E) ON COMPANY, U.S.A. POST OFFICE BOX 196601 · ANCHORAGE, ALASKA 99.519-6601 March 30, 1987 Mr. W. W. Barnwell Commissioner Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Barnwell: As requested by your letter of February 18, 1987, and further discussed with Gene Sands of our office, please find enclosed a reproducible mylar of DIL 2" runs 1, 2, and 3 for Exxon's Pt. Thomson #3 well. If you have questions, please call Gene at 907/564-3760. Sincerely, R. G. Dragnich EES/cj s/170 Enclosure A DIVISION OF EXXON CORPORATION February 18, 2987 Telecopy No. (907) 276-7542 Exxon Company, U.S.A. P. O. Box 196601 Anchorage, AK 995i9-6601 Re: Pt. Thomson #3 Gentlemen: In compliance with the regulations set forth in Chapter 25 of the Alaska Administrative Code, your company has dutifully submitted to the Commission sepias of the various logs run in the subject well. Primarily due to age and to frequency of use, the sepias of the logs indicated below have deteriorated to the point that satisfactory prints can no longer be made from them. Accordingly, in the interest of upgrading the quality of the material maintained for permanent reference in the Alaska well log library, the Commission would greatly appreciate receiving from you fresh sepias of the following logs: DIL 2" Runs 1, 2 & 3 BHC Sonic 5" Runs 1, 2 & 3 CNFD 5" Runs 2 & 3 CFD 5" Runs 2 & 3 Please direct any questions you may have in fulfilling this special request to Bill Van A!en at 279-1433. Thank you for your contribution toward maintaining a good State well log library. Sincerely, ~ j W. W. Barnwell Commissioner jo/L.FJ.01-02 November 21, 1986 Telecopy No. (907) 276-7542 · Mr. John P. Clement, III Drilling Manager Exxon Corporation P. O. Box 60626 New Orleans, LA 70160-0626 Re: Final Location Clgarance Pt. Thomson Unit Well No. 1 Pt. Thomson Unit Well No. 2 Pt. Thomson Unit Well No. 3 Alaska State A-1 Alaska State C-1 Dear Mr. Clement: Our representatives inspected the above referenced locations on August 27 and September 12, 1986, and found that cleanup was acceptable. Marker posts with the required information bead welded on them were in place, " Your letters dated November 10, 1986 requested that we change the status of each of.these wells from suspended to abandoned. Since there were no changes made to the well bores of these wells, we did change the status to abandoned on the "Well Completion or Recompletion Report and Log" which had previously been submitted for each well. Based on the above, we hereby approve the final location clearance for the Pt. Thomson Unit wells Nos. 1, 2 and 3, and the Alaska State A-1 and C-1 wells. Sincerely, ~ Lonnie C. Smith C ommis s loner jo/A.HJHo47 COMPANY, U.S.A. POST OFFICE BOX 60626 · NEW ORLEANS, LOUISIANA 70160-O626 PRODUCTION DEPARTMENT OFFSHORE DIVISION JOHN P. CLEMENT, Ill DRILLING MANAGER November 10, 1986 Mr. Chad Chatterton Mr. Lonnie Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sirs: This letter is to request a change in status from suspended to abandoned for the following well: ADL 47558 BHL & ADL 47559 Surface, Point Thomson Unit, Exxon No 3. Please refer to the attached form (P-7) for plug and suspension details dated 7/4/79. TVB: j cv Attachment Sincerely, A DIVISION OF EXXON CORPORATION OIL .AND GAS CONSERVATION COMMITTEE revers,, · .. · ii ii i i i iii i i i i! ii WELL COMPLETION OR RE'COMPLETION REPORT ,AND LOG* I lflL ,ATE OF ALASKA :' S. Aei ~w. tucAL coo~ ........ :'- · B.~CK [~. 'YYri~ or b. TYPE: Or COMPLETION: WKI.I. "a'[] Other Wildcat Exxon Corporation P. O. Box 2180, Houston, Texas 77001 UPM, 4. I.Of')t'lnN Or w£Ll. IReport location clearlv end in accordance with 0.¥ ~tatr requiremdflts)· · t,..., 660' NSL & 711' WEL, Sec 34, T10N-R23E, North Slope, Alaska At top prod. Interval reported below At total depth 1869' NSL & 15.94' WEL, Sec 35, T10N-R23E, UPM, North Slope, Alaska 1/3/79 ~ 5/15/79 ~ 7/4/79 I 36' KB ~ ,s. 'z'9~,- 9Fd,'~a.'i,~p,& 'rvop~. et. ua. ~c~c sm a ~n~. ~ ~u~w~ co~w~.. I ~. ' 13- 15! Tva [ , [ ,,- ..... i All ~. PRODOCINO !NIEIiVA~(S~, OF ~!i5 CO~IP~iON--TOP, BO~OM. NAM~ (M~ AND ~}' ~ ~: See item 28 for' perforation intervals. Yes ~4 T%'~'~ E~ECTL:~C aJq OT~ ~GS RUN ~ '"" ': Dual lnauct~on, BHC Sonic, Formation Density-Compensated NeUtron, Dipmeter, 50-089-20007 ADL ¢/D::)~ ~ur:ace ' APT. 47558 BHL Point Thomson Unit W~ NO. , * t, ~ 3 Wildcat O~V~l Sec 35~ ~O~-R23E~ UP~ · . · ~. 1. V~ 1 o~ i tv - SIZE ]8-5/8 13-3/8 9-5/8 _ 7 2G S:Zlg " CAS[NO I~ECOP, J:I' (Rcr~Jrt 31i ~trings Set In w~ll) I DE~H S~T (~) 96.4 K55 ! '8~i 22 ' 14300 sx permafrost JNoDe 72 1580 ~ 3,3~8 [ 17~ 13750 sx Permafrost [None ... 47 1Soo951 10,3~7 1~%' ~24'50 sx Class G ' ~.None '.... 35 . .. IPll0 ~ .~~4 .1 8% [1035 sx ~lass G ~9502' TOP (?,ID~ ~OTI'OM (MD) SACKS C~M~T' scnE~ qMO) ~ SiZ~ DZP~ S~ (~O~ ~ PA~ICER SZT (MD) -r ...... 28 PE/IFORA'I lO,NS OP?2Nr TO /'RODUL.--UIOH t/ntcrval, size and number! 13,872'-13,885' (2 spf) 13,908'-13,~ ~5' (2 spf) ACID, $I!OT. FaACI'URE, C~,tENT SQUEEZ2, ~C. D~IT; INI~V.a~L, (MD) AMOUNt ~'~D I'[IND OF MA7E~AL USE/) 870'-13,885' z Sx cement 908 -13 sx cement z0. PRODUCTION , ,., .,. "~ ~i;; ~ ~: ~:~ ' t '?o, S~ A~A~ --- .. , , I ~ t~ ~ "-'/~! ,, . -. r'~s. ~ [~'~"tOU~nATZ / . r,~%~ ' ' / -' '"~/00 /EST WITNESSED fl~ John C. Miller ~or~ Data, Test Data ,.'. i h.r-h~ certify that thP gureg.tl,~ and attached Ilzf,,r~i.n Il cOmplete and Correct ai determJ.t.~ from ali-available rec.rd~ sm~,,, ,- -.. - ,~.~--~'c~~~~e i M er O,T~_A~gust ..... i i i ii i iii Illl I I I I *(See Instruction, and Space, for Additional Data on Reverse Side) 3 ,._1979 I _ .... STATE OF ALASKA * AL/, .A OIL AND GAS CONSERVATION CO, }SION REPORTOF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [~ Other [] Final Location Abandonment 2. NameofOperator 5. Datum elevation(DForKB) Exxon Co., U.S.A. 8.6' GND 3. Address 6. UnitorPropertyname Pt. Thomson Unit 4. Locationofwellatsurface 660' N.S.L. & 711' W.E.L. Sec. 34, T10N-R23E UPM North Slope, Alaska At top of productive interval At effective depth At total depth 7. Well number No. 3 8. Approval number332 9. APl number 50-- 089-20007 10. Pool Wildcat Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Permanently plugged to surface feet Plugs (measured) feet feet Junk (measured) feet Size Cemented Measured depth True Vertical depth true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) · 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 0il & Gas Cons. 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I herw that/~ ~~~/~/'-the foregoing is true and correct to the best of my knowledge ~_ .,~~ _ ~_ /~,~'_, ~' Signec(_/J. P. Clement, III TitleNew Orleans Drilling Mqr. Date 9/25/8 Form 10-404 Rev. 12-1-85 Submit in Duplicate MEMORAIV- UM TH RU: FROM: Stat -of Alaska ALASKA Oil. AND GAS CONSERVATION COM~I,. %ON Chairma~~- Lonnie C. Smith~ Commissioner Doug Amos Petroleum Inspector DATE: FI LE NO.: October 1, 1986 D.ADA.54 TELEPHONE NO.: SUBJECT: Location Clearance Exxon Pt. Thomson #3 Permit No. 78-05 Exploratory ~tember ~ 1986: I traveled from ARCO PBU PBOC to ERA ~' a--~6~pAny ~Tom Burford, Exxon representative, to the Pt. Thomson #3 location and conduct the final location clearance inspection. As the attached photographs indicate, the location is in compliance with AOGCC regulations 20.AAC 25.120 & .170. Therefore, I recommend that the Commission accept this location for final abandonment. I filled out an AOGCC Surface Abandomoment Report for this location. The report and photographs are attached. In summary, I conducted the location inspection at Exxon's Pt. Thomson ~3 well, and recommend that this location be accepted for final location clearance. Attachments 'ALASKA O].l, AND GAS CON.~ERVA'fi~.~,, ,.,,:'I?i£8a£oN SURFACE ABANDONMENT REPORT 20 AAC 25, ARTICLE 2 FILE INFORMATION: Operator ~xXo~7 U,~, ~, , , Address Surface Location of Well ~ Ft. F~/5 L, ~77/ Ft. Sec...~ , T /D /q/, R ~ ~,.~. M. Date Downhole P & A 20 AAC 2~.120: WELL ABANDONMENT MARKER: Dia. Steel Post (4"Min.) Ia ~( Height Above Final Grade Lev~-i (4' Min.i Top of Marker PiPe Closed with: Cement Plug Screw Cap Set: On Well Head .~5 , On Cutoff Casing , In Concrete Plug Distance Below Final Grade Level A{ [ ~ Ft. in. Side Outlets: All Valves and Nipples Removed 5'~5 All Openings Closed M'~ With Blinds ~/,' With Cement 7-,4- Permit No. AP I No. 5 O- Unit or Lease Name Well No....~/~, Field & Pool ,~i Length (10' Min.) ..... /0 ! Welds , Other INFORMATION BEADWELDEI) DIRECT~LY TO Na\RKER POST: (List Where Different from File Information) Operator ~x7~,~i4, .... ~/,,~, ~ Unit or Lease Name ~. Well .Number A/~ ~ , Surface Location of Well: _~% 0 Ft. F~L, . W// Ft., FjJ~L, Sec ~ , T /~ ~ , R ~ 20 AAC 25.170: LOCATION CLEAN-UP ,, PITS: Filled In /, Liners Removed or Buried , Debris Removed SURFACE OF PAD AND/OR LOCATION: Rough , Smooth , Contoured ~--~, Flat Other Compacted CLEAN UP OF PAD AND/OR LOCATION: Clean ~-/, Pipe Scrap , Iron Scrap .. Paper , Other , ,, Wood , Mud , Cement SURROUNDING AREA: Wooded , Brush__, Tundra /, Grass__ Sand , Other , Dirt , Gravel CONDITION SURROUNDING A~EA: Clean ./,Trash from Site Other , Trees and/or Brush frotn Clearing Site ACCESS ROA'D: Dirt , Gravel , Ice Other CONDITION ACCESS ROAD AND SURROUNDING: Clean , Rough , Smooth , Trash from Operations , Trees and/or Brush from Clearing Road , Spoil from Clearing Road Other REMAINING TO BE DONE': RECOMMEND- APPROV. AL OF ABANDONSiENT: INSPECTED 05/26/81 Yes /, No Final Inspection DATE ~'- / ~.. t=.xXa- - PT t ~~i~1~0~ NO. 3 ~t.,L~ i---- ~n- U . 5. A . p'i'. TF~oN1So N ~ ~. 3 WE ~.c~ i- fy}aRi~:2 QoS~' : /" STATE OF ALASKA - ALAS~,..--qlL AND GAS CONSERVATION COMk..,SION APPLICATI FOR SUNDRY APPROVALS 1. Type of Request: Abandon~XC'~,~,uspend~Operation ShutdOwn [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator Exxon Company U. S. A. 3. Address P.O. Box 196601 Anchorage, Alaska 99519-6601 4. Location of well at surface 660' NSL and 711' WEL of Sec. 34, TIO~ R23E UPM, North Slope, Alaska At top of productive interval At effective depth At total depth 11. Present well condition summary Total depth: measured true vertical 5. Datum elevation (DF or KB) Approx 8.6 ' G~D 6. Unit or Property name Pt. Thomson Unit 7. Well number --~,~.tr No. 3 8. Permit number 78-5 9. APl number 50--089-20007 10. Pool Wildcat Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Pe~m~m'zently plugged to sunface. -feet Plugs (measured) feet feet Junk (measured) feet Size Cemented Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) Measured depth RECEIVED True Vertical depth AUG 1 !98,S 0il & Gas Cons, Comm!ssi0~ Anchorage 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation 14. If proposal was verbally approved Form 10-403 Rev 12-1-85 August 13:1986 Name of appr9Y~r ~b:. Lonnie Smi~2r~ Date approved July 8, 1986 Sig ne~~/¢~.15. I hereby cer~hat ~e foregoing is true and correCtcommissionTitle ~~ t~e/eStuse,~nlyOfm~~ know~edge,~t~/ Date ~//~~ I Conditions of approval Notify commission so representative may witness ~ Approval No. ~ Plug integrity ~ BOP Test ~ Location clearanceI ~ ~ F,~ [~ ~, 5~,,~'~'~"~ ,. ............ by order of ~ , Approved by ~ Commissioner the commission Date ~ Submit in triplicate Plan to convert Pt. Thomson ~3 from suspended to permanently abandoned status: After abandoning Pt. Thomson #3, cuttings disposal pit, regrade surface location so that wellhead is covered and gravel slopes gently away from wellhead. Insure all debris is removed from location. MEMORAb UUM Stat of Alaska ALASKA_ OIL .iND GAS CONSERVATION COMMI~ iON TO: C. V ton DATE: August 12, 1986 Chai~~ F~tE NO.' D.ADA.42 THRU: FROM: Lonnie C. Smith~%~{ Commissioner Doug Amos Petroleum Inspector TELEPHONE NO.' SUBJECT: Clean-up Inspection Exxon Pt. Thomson #3 Permit No. 78-05 For Final Abandonment Wednesday, June 18, 1986: I traveled this date from Kuparuk to P~dh°e Bay andme~ witlh Tom Burfford, Exxon representative. The location listed above requires work as stated on the attached list and shown in attached pictures. i filled out an AOGCC Surface Abandonment Report for this location. It is also attached. I 'ALASKA Oli, AND GAS Ct.t~,~ERVAYi~.;,, ~ hli$SLoN -~ SURFACE ABANDO:LMENT REPORT .... 20 AAC 25, ARTICLE 2 FILE INFORMATION: Operator ~ Address ~ &~D~l ~rv~ eCx~)-r ~.c~ ,~ '~'~ Surface Location of Well ~~ Ft. F ~I~L, . ~ t..I Ft. F~4~L, Sec. , , 2i, '. 20 AAC 2~.120: WELL ABANDONMENT MARKER: Date Downhole P & A -"1'" 4-q~ Permit No. AP I No. Unit or Lease Name No. Field & Pool [~'1 Dia. Steel Post (4"Min.) ~t~ Lengt, h (10' Min.) Height Above Final Grade"Level (4' Min.i _ ~'~~ ' Top of Marker Pipe Closed with: Cement Plug Screw Cap Welds Set: On Well Head W''~, 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 INFORMATION BEADWELDED DIRECT/LY TO MARKER POST: (List Where Different from File Information) Operator ~,~ ~~ Unit or Lease Name Well .Number .~ , Surface Location of Well: , Other 20 AAC 25. 170: LOCATION CLEAN-UP PITS: Filled In ~/~ , Liners Removed or Buried , Debris Removed SURFACE OF PAD AND/OR LOCATION: Rough__, Smooth , Contoured ~/ , Flat Other , Compacted CLEAN UP OF PAD AND/OR LOCATION: Clean '~', Pipe Scrap , Iron Scrap , Wood Paper __, Other ~i~ ~_.,M'~'~ ~.~Co.~O~\ ~i~ , Mud , Cement SURROUNDING AREA: Wooded , Brush , Tundra Sand , -Other ~~rass , Dirt , Gravel CONDITION SURROUNDING AR'LA: Clean ~,/,'Trash from Site Other , Trees and/or Brush from Clearing Site ACCESS ROKD: Dirt__, Gravel , Ice , Other CONDITION ACCESS ROAD AND SURROUNDING: Clean , Rough , Smooth , Trash frown Operations , Trees and/or Brush from Clearing R~ad , Spoil from Clearing Road Other REMAINING TO BE DONE: ~ &t~o~ ~O~,~g ~'~\! _~,q,~ ,~ ~ RECOMblEND-APPROVAL OF AB~NDO~iENT: Yes , ~No / Final Inspection INSPECTED BY ~o~<. ~~ , DATE 05/26/81 } SUMMARY OF 1986 LOCATION CLEAN-UP WORK Location Pt. Thomson #1 Required for Suspension Required for Abandonment No work required -Remove valve & blind flange & needle valve -Level mound near well- head -Remove rat-hole below grade and cellar Pt. Thomson #2 No work required -Smooth down gravel mound near wellhead -Remove debris Pt. Thomson #3 No work required -No work required pro- vided wellhead is not too high after abandoning pit Alaska State A-1 No work required -Remove debris · -Lower wellhead Alaska State C-1 No work required -Cut off refrig pipes below grade -Remove valve & blind flange & needle valve Alaska State J-1 Remove trash -Remove sewage lift station -Remove debris-Regrade & smooth pad-Verify cellar filled with gravel - under water when inspected -Remove cellar boards 7/8/86 GX X DiU` ~T. ?r.10I'/JSf ,~,~ /~v,'J . ~ ',c,~t= , ~ ~-- _t _. !~ `k~ ~l ~~ ~~~~~: ~~~~~" n ,\ ~' iC j'Z'+ Ut ~- c-ti~-~ \~ E~ON COMPANY. U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99,502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION D.H. JONES EXPLORATION COORDINATOR -- ALASKA September 6, 1985 Exxon's Drillsites Inspection and Status Mr. Lonnie Smith State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Enclosed for your review and approval are Sundry Notice forms 10-403 for ten Exxon drills±tes located on the North Slope. We request that the status of the Duck Island pad drills£tes be approved as permanently abandoned, all the other drills±tes to be maintained 'as suspended. Very truly yours, NB3/13:ng Enclosures RECEIVED SEP 1 1 1~I1~ Alaska Oil & Gas Cons. Commission Anchorag~ A DIVISION OF EXXON CORPORATION . .... STATE OF ALASKA '-' ALASKA ..,IL AND GAS CONSERVATION C,..,¢IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL[] COMPLETED WELL [] OTHER 2. Name of Operator Exxon Corporation 3. Address P. 0. Box 6601, Anchorage, AK 99502-0601 4. Location of Well 660' NSL and 711' WEL, Sec. 34, T10N, R23E, UPM, North Slope, Alaska 5. Elevation in feet (indicate KB, DF, etc.) Approx. 8.6' GL 6. Lease Designation and Serial No. ADL 47559 (surface) ADL 4755 7. Permit No. 78-5 8. APl Number 50- 089-20007 9. Unit or Lease Name Pt. Thnm_~nn tlnit 10. Well Number Exxon No. 3 11. Field and Pool Wildcat (BHL) 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We request a one year extension to August 1986 of the suspended status of this well. We will arrange to have the location inspected by your representative on a yearly basis or until final abandonment. 14. I hereby certify t~g~fh"~-E~rue and correct to the best of my knowledge. ..._~~/~/,'/'~ J./'/"~. ~y~~~ Exploration Coordinator- Signed Title A1 as ka The space below for Commission use Date 9/10/85 Conditions of Approval, if any: Approved by. COMMISSIONER ~pproved CoDy Returned By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MEMORANDUM TO: . THRU .' FROM: Stat of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION e DATE: 11 1984 C.V. r~ton September , · Chairm~ Lonnie C. Smith,~MPx/.i~ Co mm issio ner~ .k_/ Bobby Fo s t_er~. Petroleum Inspector FILE NO: D. 3I. 62 TELEPHONE NO: SUBJECT: Inspect Suspended EXXON Locations Listed Below For Suspended ~ Status. Wednesday, September 5, 1984: I traveled this date to Prudhoe Bay and met with Junior Westbrook and Noreen Borys, Exxon representa- tives. As the attached pictures show the locations listed below are in compliance with AOGCC regulation 20 AAC 25.170. Therefore I recommend to the Commission that these wells be accepted as sus- pended from September 5, 1984 thru September 5, 1985. Duck Is land #2 Duck Is land #3 Alaska State A-1 Alaska State C-1 Alaska State F-1 Point Thompson #1 Point Thompson #2 Point Thompson #3 Atta.chment/pictures in file 02.001A(Rev. 10119) Suspended Well and Location 20 AAC 25, ARTICLE 2 Report Surface Location of Well . ~'~ Ft. F.~./j~ L, ~// Ft. se c.?/; ; Date Suspended Con~[tion ?f ~ad . Permit No. F~L/~ L API No. Uni~--or Lease Name Well No. Field & Pool ~/.~~.~/~ Condition of Pits Well head - Ail outlets plugged No Wel 1 sign - Attached to well head Attached to we~!, guard ., Attached to_ Ye s Ye s No Information correct No Cellar - Opened Fil led Covered WaterWell - Plugged off Ye s No Capped Ope n Rat Hole Explanation O[mn Fil led Covered · Ye s No '~-e"s> No Ye s No Photographs taken to verify above Work to be done to be acceptable conditions /Yeti No Explanaton This well and location is (~ept-~i~:~ (unacceptable suspended for the_p~e~iod of~~ ?: 1B~:-thru ~ ? Ins~cted by: ,~~,~, ..... · / , :/ to be classified as Revised 8124/82 ~~o~ - ~~, Th~pso,J ~3 Sec. ~9 ~ i ~~in; ,'~a~, urn - ~ ~~ `~ IiNe~ ~, ~ used ~o~G d;s~pO3f~/ o f' C~}/,-uys y~•~ q~~i.L tve~s S' ~` -~. MADE IN U.S.A. NQ. T~~ ~/~ ~~~ ~~~ well /Li.~~,4c ~ ESSELYIt STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUHDRY NOTICES AND REPORTS ON WELLS OTHER 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Exxon Corporation 78-5 3. Address 8. APl Number P. 0. Box 6601, Anchorage, AK 99502-0601 5o-089-20007 4. Location of Well 660' NSL and 711' WEL, Sec. 34, T10N, R23E, UPM, North S19Pe, Alaska 5. Elevation in feet (indicate KB, DF, etc.) Approx. 8.6' GL 12. 9. Unit or Lease Name P0int Thomson Unit 10. Well Number Exxon No. 3 11. Field and Pool I6. Lease Designation and Serial No. ADL 47559 (surfar. e/ An! 47RSR ( Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data Wildcat ~HL) 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). We request a one year extension to August 1985 of the suspended status of this well. A general cleanup will be conducted this summer, which will include levelling and grading the pad area except for the mud and cuttings disposal pit which shall'be maintained as necessary. We will arrange to have the location inspected by your representative on a yearly basis or until final abandonment. R E C E i V E D q r'~r~ Alaska Oil & Gas 60,% Commission Anchoraoe 14. I hereby certify that t.~e~ foregj;~igg is. true and correct to the best of my knowledge. · ..~ "' ~ Exploration Coordinator - Signed /~(/~- ~~~~ Tit,e Alaska , Dateg/ I o/SZ~ The space below for Commission use ' / - ~ 3, I, : :' Conditions of Approval, if any: Approved · , By Order of APproved by COMMISSIONER the Commms~on Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate EXPLORATION DEPARTMENT ALASKA/PAC I F lC D IV I SI ON EXXON COMPANY, U.S.A. POUCH 6601 Anchorage, Alaska 99502 TRANSMITTAL OF DATA FROM: Roy Lonqstreet TO: Alaska Oil & Gas Conservation Commission Attn: Fran Jones 3001 Porcupine Drive Anchorage, Alaska 99501 Material transmitted Exxon Point Thomson Unit The material listed below is being transmitted via hand del ivery 1 sepia Composited FDC/GR Please acknowledge receipt of the above material by signing and returning the duplicate copy of this letter. Roy Longstreet November 14, 1983 Date Sept~'~b~r 29, 1983 Exxon Compan}~, U.S.A. P. C. Box 6601 Anchorage, Alaska 99502 Re: Cleanup Inspection for the Following Wells~ · Duck Island Unit I~o. 2, Sec. 8, TllN, R17E, U.M. Duck Island Unit ~o. 3, Sec. 10, TIlN, R17E, U.~]. Point Thomson Unit No. 1, Sec. 32, T10~, R23E, Point ~homson Unit }~o. 2, Sec. 3, T9t~, ~22E, U.~. ~Point Thomson Unit ~:o. 3, Sec. 34, T10N, R23E, Alask~ State A-I, Sec. 27, TI01%', R24E, U.M. Alaska State C-i, Sec. 14, TPI~, R23E, U.M. Alaska State D-l, Sec. 23, T10N, E23E, U.M. Alaska State F-i, Sec. 17, T10N, R23E, U.M. Alaska State C-2, Sec. 35, T10N~ R24E, Centle~.~n: Our representative inspected the above ten suspended and abandoned well sites for extension of cleanup on August 31, 1983. With exception of Alaska State C--2, the cleanup of these well sites are satisfactory. Because ~e drilling rig was still on location at Alaska State G-2, a cleanup inspection could not be comE~leted. Returned are eight approved 10-403's, Sundry t{otices and M~eports on Wells, for all the listed wells e;:cept for two which need no further approval. Alaska State G-2 has a year to go under 20 AAC 25.170(a) and Alask~ State E-I which (classified as aban- doned) has previously been ~ranted an extension to August, 1984 for removal of the sheet piling. The 10-403's %;hich you submitted for Euck Island ~nit k:o. 1 and Alaska State D-1 are not necessar~~ and are returned unsipncd. Duck Island Unit ~o. 1 was abandoned dcwr2~ole and Duck Island Unit [-?o. 2 was sidetracked fro~ the well kote of ~;o. 1. Conse- quently a 10-403 is net required for ~-~o. I. A subsequent inspection of each well -will be necessary- by August, 1984. Sincerely, ; · Lonnie C'i- St~'&tk LCS/J~]T :lc: !03~ i~ MEMOR ANOUM Stat6 of Alaska ALASK,~ OIL AND GAS CONSERVATION COMMISSION TO: C. ~_.~tt.erton/~- DATE: September CharOn~--' FILE NO: 108B: Z 1 Thru: Lonnie C. Smith Commis s ioner TELEPHONE NO: FROM: Bobby Foster~;~. SUBJECT: Petroleum Inspector 6, 1983 Inspect Suspended Exxon Location's Listed Below. Wednesday,..August 31, 1983: I met with Tom Bruford, Exxon repre- sentative, this date and inspected the following suspended loca- tion's. Pictures were taken and attached to each report. Duck Island #3 Duck Island #1 and ¢2 Point Thomson #1 Point Thomson ¢2 Point Thomson #3 Alaska State A-1 Alaska State C-1 Alaska State D-1 Alaska State F-1 Alaska State G-2 I recommend to the Commission that all these location's with the exception of Alaska State G-2 be accepted as suspended locations in regard to pads, pits, and well signs. Alaska State G-2 is not acceptable due to the rig still being on .location. In summary, I inspected the above suspended locations. Attachments ! t Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: -- ~ /7 _ x ' 6~at-~.~,~>~O~_. C.~f,~-, ~ .... Date Suspended ~-~- 7~ Address _.~.,_(?.i _ _~_,~/- ~/~O[ ~.-~~/ [~ ~~~_ Surface Location of Wel~ ' ' permi~ N~2 :~-~ .... ~ '~~ Ft. F~L, ~// Ft. F~L API NO. 5~'~'Z O~~o~ . ~ev~ ·/~_ ~_, n~,s~,' ~M. Uni't o~ L~ N~m~;~-~~~g ~,'~ Well N9.~ ._~ Condition of Pad ~O ~__ Well head - Ail outlets plugged ~ Well sign - Attached to well head Yes Attached to well guard Yes Attached to _ _(f?-.~.Jf~_/'~LD'.)~,t'"'. _ Information correct ~ No No No Cellar -' Opened Filled Covered WaterWell - Plugged off Ye s No No capped Ope n Rat Hole Open Yes No Fi 1 led ~ No Covered Yes No exp la na ti on ~/~~ .............. Photographs taken to verify above conditiOns~ No Explanaton Work to be done to be acceptable This 'well and location is ~=~c_~ff-~blDJ2 (unacceptab~%) to,be classified as suspended for the period of ~//~-~z~SL .~-/?lg~thru ~~,/~ 19~. Ins~cted by -.- . ....... Revised 8~24/82 STATE OF ALASKA ALASKA ~JIL AND GAS CONSERVATION CO,¢IMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator Exxon Corporation 3. Address Pouch 6601, Anchorage, AK 99502 4. Location of Well 663' NSL and 662' WEt, Sec. 34, T10N, R23E, UPM, North Slope, Alaska 5. Elevation in feet (indicate KB, DF, etc.) Approx. 8.6' GL I6. Lease Designation and Serial No. ADL 47559 (surface) ADL 47558 12. 7. Permit No. 78-5 8. APl Number 50- 089-20007 9, Unit or Lease Name Point Thomson Unit 10. Well Number E××on No. 3 11. Field and Pool Wildcat 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). We request a one year extension to August 1984 of the suspended status of this well and to complete the final cleanup. A general cleanup will be conducted this summer, however this pad is currently being used as a stockpile for contingency gravel and tubulars for exploratory drilling. We will arrange to have the location inspected by your representative on a yearlY basis or until final abandonment. 14. I hereby certify tha,~l~e fore, going is true and correct to the best of my knowledge. /~~~~~~ Exploration Coordinator - Signed _ __ Title Alaska The space below for Commission/---rise' Date 7/25/83 Conditions of Approval, if any: Our representative inspected this w~ll site on August 31, 1983 and cleanup was acceptable for a suspended location. A subsequent inspection will be necessary by August, 1984. ApproYed Returned Approved by BY LON,qlE C. S [Tll COMMISSIONER the Commission Date g..,.,/ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate E)C ON COMPANY, US.A. POUCH 6601 ° ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION D.H JONES EXPLORATION COORDINATOR -- ALASKA July 26, 1983 Mr. C. V o Chatterton, Chairman State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached for your approval are Sundry Notices for one year extensions of the suspended status of the following Exxon wells° tPoint Thomson 1, 2, &!~3. Duck Island 1, 2, & 3 Alaska State C-l, D-l, F-1 We would be pleased to arrange an inspection tour of each of these locations for your representative sometime in late August. Please contact Mr. R. L. Westbrook at (907) 263-3742 to arrange a convenient date. Very truly yours, NB: rms 40/42 A DIVISION OF EXXON CORPORATION AMOCO PRODUCTION COMPANY Tulsa, Oklahoma June 13, 1983 83164ART0077 FILE: Technical Service 839146SX TO: W.S. Davis, Denver ATTN: Kirk W. Sherwood SUBJECT: Mineralogy of Chips from Exxon Pt. Thomson Wells No. 1 and 3 The attached table, summarizes the semi-quantitative x-ray mineralogy of six samples from Exxon Pt. Thomson Wells No. 1 and 3. As instructed, I am returning what remains of each sample (both unused and prepared) to Kirk Sherwood in Anchorage. If there are any questions about these results, please call me at the Research Center at Ext. 3477. J. C. Hoffman JCH:ceh Attachment cc: C. F. Upshaw/E. R. Michaelis H. D. Winland R E C E E D Alasl~a ()ii N .~., ~ .... ,,,,,~ .... , Prt~ - To Be Mab~ca~ed In ~e %~AUT~bN: THESE ESTI[~ATE5 ARE ONLY SEMI-QUANTITATIVE. X-RAY DIFFRACTION MINERAL PERCENTAGES LOCALITY: PT. THOMSON WELL NO. I AND'"3. FORMATION: unnamed AGE: CRETACEOUS PAGE 1 OF I T.S. NO.: 9146sx CHARGE: 9146 SAMPLE' : Q : K : C : D : S : A : G. : P : B : K : M : C : M : H : H : C : ID. : R : S : A : O : I : N : Y : Y : A : A : I : H : O : X : A : E : NUMBER : T : P : L : L : D: H : P : .R : R : 0 : C : L : N : L : L : L : : Z : R : C : O : R : Y : S : T : I : L : A : R : T : R : I : E : .... : : : : : ...... : : EXXON PT. THOMSON 12922 : 31:TRC: 9: 49: :TRC: :TRC: 2:TRC: 9: : · ' : : ...... . : ..... : : : ...... ~'TRC: TRC TRC 4 · · : : 13090 : 22: : 40: 34: : : : : : : ........ . ........... :---: . . · ........ :---: ........ :---:---: ............... . . . : 13138 : 36:TRC: 33: 16: :TRC: : 2: : 3: 10: : : : : : · : : : : ...... : · · · · · EXXON PT. THOMSON ~3 137~ 13682 : 28: 2:TRC: 67: :TRC: :TRC:TRC: : 3: : ' : : : ............ :---:---: ....... : : : : : :---: : 40: 2:TRC: 54: 13850 · · · · · : 35: 2: 33: 25: : TRC: : TRC: · : : : : TRC: : TRC: : : : · February 4, 1983 Mr. D. H. Jones Exploration' Coordinator-Alaska Exxon Company U. S. A. P. O. Box 6601 Anchorage, Alaska 99502 Dear Mr. Jones: The Alaska Oil an~ Gas Conservation Commission has recently checked the records of wells completed since January 1, 1979. This review has revealed that' the digitized data for certain logs run in a well is not on file with the Commission. . The Oil' and Gas Regulations require the operator to file, within 30 days after completion, suspension, or abandonment of a drilling well, the digitized data, if available, for copying, for all logs run in the well except velocity surveys, experimental logs and dip- meter surveys. We would request that you check your records to see if the data has been submitted to the Commission and, if not, that you comply with the regulation with regard to the following wel Is: Pt. Thomson Unit No. 3 Alaska State D No. 1. Thank you for your cooperation in this matter. Yours very truly, Harry W. Kugler Commissioner BY ORDER OF THE COMMISSION be ~ - 1982 ~.eptemD~ ~ ! 3, Exxon Compa ny USA P.O. Box 6601 Anchorage, Alaska 99502 Clean-up Ins~¢tion Point Thomson Unit 1.~o. 3, Sec. T10~, R23E, ~. Centle~n: Cur representative insFected this susi~nde~l location for clean-up on August 12, 1982. This location is bein~ ~ ~ ~ us~Q as a staging area and tl~er¢ are several mounds of gravel, the mud pit is o~n, the cellar is open an~ there~ are stockpiled materials and equipment. It will k~ necessary to sub~it a form 10-403, Sundry ~{otices and. Reports on Wells for a one year extension. A subsequent inspection $~ilI ~ necessaz~' by August 19S3. Also it %~as noted that the area immediately surroundin9 the i>ad v~s in %~ry ~or con~tion %~th clebris scattered about in large quantities. It would k~ expected that you would attempt an immediate correction of this deficienc~, and photographs suDmitte¢~ vitk your letter of September 1, 1982 to ~'. C. V. Chatterton would ~]9gest that this has b~en substantially accomplished. Si ncc tel y ~ Lonnie C. Smith Co-mi s sione r 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~t~-~ 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 to 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 DfVISION OF EXXON CORPORATION . . . Mr. C. V. Chatterton September 1, 1982 Page Two We also request clarification of the status of Mobil's West Staines #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: sim 60/2 At t achment s MEMORANDUM State of Alaska TO: Thru: A.LA;~ ~: AI'~D ~S CONSERVATIOI,~ COMMISSION C. ~./~t. terton DATE: August 27, C~ ssioner 19 8 2 FROM: ~arold ~. Hawkins Petroleum Inspector SUBJECT: Ins~:,ection of Exxon's SusL~nded Point Thomson I~fo. 3 Location fox' Clean-u~ Sec. 34, T10t~, R23E, b.P.M. Permit No. 78-05 Thursday, August 12, 1982 I left the D-1 location that inspected, subject of another re~rt, to ~xon's t~'oint Thomson. location ~3. The Point Thomson No. 3 location ins[~ction is a follow-up of the ins~ction for clean-up August 11, 1981. Exxon is still using the location for a staging area and stod~piling of material and equipment. The location is far from kming level as there are mounds of gravel over location, the mud pits are bermed and lined ~th plastic and o~.~n, the cellar is also open. There is also debris scattered off the location in. the surrounding tundra that should be cleaned up. The surface location on the well sign is not correct (see field report). I took pictures Which are attached to this report, I also filled out an A.O.G.C.C. re~ort which is also attached. In sumR~ry, I inspected Point Thomson ~'o. 3 location for ~xon. The location and surrounding area is far from being in condition for approval for a clean-up of location. Another follow-up inspection will ~ needed. Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: Opera tor ~.~_~.~j~. _. _~A--./3 /) ~<c ~. Addre s s · Surface Location of Well ~ ~O Ft. F~L, V// Ft. Sec.~.~, T_/~ ~, $~.~ ~, U~. M. Date Suspended F Permit No. ~/&c L API No. Unit or Lease Name Well No. Field & Pool Well head - Ail outlets plugged Yes No Well sign - Attached to well head Yes~ No Attached to well guard Yes No . Attached to .... ....~1~4/~//~:ff ~ ~ ~2~ ~ Infor~tion correct Yes ~_~. ~ Cellar - ~QO~~~ Yes No Rat Hole Open Yes ~ F~I'~ d Ye s No Fi 1 led Ye s No Covered Ye s No Cove red Ye s No WaterWell - Plugged off Capped Open Explanation Photographs ~taken to verify above conditions ~Y~es/ ,' '~ . ._. -:~7 :.: _ -_~ : -- No Explanaton 7' . ' Work to be done to be acceptable This well and location is (acceptable) (unacceptable) suspended .for the period of 19.. thru ~ ,:- . , ..,~ ,~ , :,'. : .~ .... .- ' .:: ' .:~i~''. : :.' . ~..:;'~, ' .,,, Inspected by: .. :</::. ::,::: ::: ::,::::::_ _z:::~::: ::.,~-:-~'~:.-.:,: to be classified as 19 . Da te: - Revised 8/24/82 w. :.:.,e + ~ ~. ~, .}, ~ thvA ~`r T w~flr' _ f ._ - ; r P~hs ~ ~' IkRO+~'P Pi 1 ~ :, (~ _ 1 _ "yn..r. .> ~'~ ~--^:.-...sue. ^.a ,.r !,. yes_^=~ ~7r. ~_«:..x~....•_ 'r. ~ „~: ~ . ~,~: ;i .~ R ~ G. ~ ` ~,~ Y'~ ~ -Xa .,.. .r~~` . .,,~. ~,.~,~~ o f ~~F ~ ~ ~ ,~.,.: f ~ ; ,~,/ T T i~ ~ ~~ s ~ ~.> ~ ~. ~ ; _. fig ~- ,_~~ -r_- -_ ei~ i ~ 0 - /'i T; ~~ ,v~ ,9 }, , ~~ ~~ r +" ri ~ r,~,- ~ ~~ . ~u ---an_~i~-~-c~_Gl~_ /Y, ~r. r ~ i) ~~d;~.;: _ Pic- : ~Rss c: , ~, N pKOnr _~~ v ~ .~ ~__: ~:' .. ~ --=- .~.~,: .~-: ~. ~ T~ ,~ 1 ~~~, ' ; ~.. --~ _: ~ _ .. a., ~`rrva ~- j - !'u 1 / =. .~:=:: ~' " ' ;%~` .~ ~_ f..~ ~,l-XaW Lo,~ ~e e . 3 Sl , T'/o .c/ , ,~.? 3 E~ tJ/~ ~ ~ ~ o~/ ~-~~ ~~ ~~~~~~s ~9~~ r. - _ ~~ t ap,. _ P.~F~-~~4' ",~. ~.~~?Cr~.~, ~ mot" ~y„ w.ti Pte" . ~f - ~._ _w..~ /~.C~e~ orv ~oC,tz ~'o ~ x r ~ ~-~~-8 3 ;,; ,.tr ~, ~, ~' ~ ' ~~~, _. .~ ~: g .3i. S 3 ~,/ ~i~~s•zr ~9 COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION August 10, 1982 Mr. C. V. Chatterton, Chairman State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached for your use are Forms 10-403 requesting one year extensions of the requirement to clean up our Alaska State "C" and Point Thomson No. 3 dritlsites. We plan to conduct general cleanup operations at both of these sites this summer, however we will be unable to fill in the pits at the Alaska State "C" loca- tion until the winter when we can haul gravel from the stockpile at the Point Thomson No. 3 location. We are currently utilizing the Point Thomson No. 3 pad as a storage area for tubulars and as a contingency gravel stockpile for future eiploratory drilling activities and plan to coninue doing so. We have also constructed a pit for mud and cuttings disposal adjacent to the pad. In addition, the following locations are ready for your inspection: Duck Island #1 and #2 (single wellhead) Point Thomson No. 1 Mobil's West Staines #2 A DIVISION OF EXXON CORPORATION ~M~. C. V. Chatterton, Chairman August 10, 1982 Page Two We plan to conduct clean up operations this month at other drilling locations utilized during the winter of 1981-2 and we will submit appropriate sundry notices in the near future. R. L. Wgstbrook of this office will be contacting a member of your staff this week to coordinate inspection of Exxon's North Slope locations. Very truly yours, D. H. Jones NB: b sw 40/2 Attachments STATE OF ALASKA '-- ALASKA ~.,L AND GAS CONSERVATION CCMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER DX Wi 1 dcat 2. Name of Operator 7. Permit No. Exxon Corp0rati on 78-5 3. Address 8. APl Number Pouch 6601, Anchorage, Alaska 99502 5o-089-20007 4. Location of Well 663' NSL & 662' WEL, Sec. 34, TION, R23E, UPM 5. Elevation in feet (indicate KB, DF, etc.) Approx. 8.6' GL 12. I 6 . Lease Designation and Serial No. ADL 47559 (Surface) ADL 47558 i 9. Unit or Lease Name Point Thomson Unit 10. Well Number Exxon No. 3 11. Field and Pool Wi 1 dcat BHL) 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). Request one year extension of requirement to clean up location upon completion of the well. A general clean up of the location will be conducted 'this summer, however, this pad is currently being used as a stockpile for contingency gravel and tubulars for exploratory drilling. Approved ~:opY ....... ~'~: :: 14. I hereby certify lng is true and correct to the best of my knowledge. ~2', / ~ _(~ ~--- Signed ~,¢-~--~--''' ~ Title Drilling Hanage~ ~,' Dat~ August 9, ~982 The space below ~Commission use Conditions of Approval, if any: ~ represen:a:ive inspected Chis suspended location on a~s: 12, ORIG~NA[ SIGNED By Order of Approved by. ~Y [0~IE ~. S~ITH COMMISSIONER the Commission Date ~ Form 10~,03 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate E .ON COMPANY. U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 PRODUCTION DEPARTMENT ALASKA OPERATIONS September 17, 1981 Exxon No. 3 Pt. Thomson Unit Sec. 35, T10N, R23E, UPM ADL 47558 (BHL) North Slope, Alaska Permit No. 78-5 Mr. Hoyle H. Hamilton, Chairman State of Alaska Oil & Gas Conserv.ation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton: In accordance with the Plan of Operations and Permit to Drill for the subject well, upon completion, we planned to clear all waste materials from the location, backfill pits, level the location, and spread stockpiled topsoil or tundra. As we are currently stockpiling contingency gravel for exploratory drilling at Point Thomson ~3, by this letter we are requesting a five year extension for cleanup of the location. In addition to the triplicate copies of the Sundry Notice required, enclosed is a fourth which we request you return for our file if you approve of the Notice. JRH:bsw 218B/D/7 Enclosures 395-653-100 cc: B. Elkin R. K. Riddle Very truly yours, SEP 2 2 1.981 R. K. Riddle Alaska Oil & 6as Cons. Commission /mchorage A DIVISION OF EXXON CORPORATION STATE OF ALASKA ALASKA ~IL AND GAS CONSERVATION C~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 1~ Wildcat 2. Name of Operator Exxon Corporation 3. Address Pouch 6601, Anchorage, Alaska 99502 4. Location of Well 663' NSL & 662' WEL, Sec. 34, T10N, R23E, UPM 5. Elevation in feet (indicate KB, DF, etc.) · 8.6' GL 12. 7. Permit No. 78-5 8. APl Number so- 089-20007 9. Unit or Lease Name Point Thomson Unit 10. Well Number Exxon No. 3 11. Field and Pool I6. Lease Designation and Serial No. Wildcat ADL 47559 (Surface) ADL 47558 (BHL) 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). Request five-year extension of requirement to clean up location upon completion of the well. Contingency gravel for exploratory drilling is currently being stored on the drill pad. RECEiV'E SEP 2 2 198~ A~aska 0il & Gas Cons, C0mm/ssi0~, Anchorage 14. I hereby certify that/~e f~goi~is true and correct to the best of my knowledge. Signed .......////\/=~ ,~- )~~~2=/ Title Drilling Manager T e space below ford~omm~ssloj~ use ~s of Approval~t~ny: Extension of time for clean-up granted until August 15, 1982. subsequent entension de.~,ndent on field inspection, ,, By Order of Approvedby. ,~ ].~,~;,.;~1~ ~. S~[t COMMISSIONER the Commission Any summar of 1982. Date Form 10-403 Rev. 7-1 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate September 11, 198i Exxon Company, U.S.A. 3301 "C" Street P.O. Box 6601 Anchorage, Alaska 99502 Location Inspection of Clean-up for Point Thomson Unit No. 3, Sec. 35, TiON, ~23E, U.~. Gent ©ur representative inspected this site on August 11, 1~[,:1. L,ue to the soft condition of stockpiled gravel it was not ----- possible to verify the condition or the well marker or the well location infor~.~tion ~ad weld~ on it. Since this site is bein~ used for stockpil ~: ~ e(~ gravel and supply storage it will be necessa~ for you to request on form 10-403, Sund~ Notices an~ Reports on Wells, for an extension of the final clean-up date. A s~seq~ent inspection will be necessary for this site. Sincerely, ~L-onnie C. ~mith Commissioner ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle Ho Hamilto~/~.~ Chairman THRU: Lonnie C. Smith ?~:.::~ · , ~/ ~" ~ : Comml s s loner ~ Doug Amos ,~ ...... :3 Petroleum Inspector August 31, 1981 Conduct clean-up Inspection on EXxon's Suspended Point Thomson No. 3 Well, Sec. 35 T10N, R23E, UPM., Permit No. 78-05. Tuesda_~_August 11, 1981: I accompanied Mr. Dave Galloway Exxon representat~-~to the well site. As the attached pictures show, this locatiOn is now being used for stock piling gravel and as a supply staging area. There are approximately 150,000 cubic yards of gravel stockpiled around the wellhead and on the mud pit. Due to the water content and soft condition of the stockpiled aggregate, I was unable to get close enough to the well marker post to verify the bead welded information. There- fore, I recommend to the Commission that this location not be granted approval for clean-up until the stockpiled gravel and drilling mud has been removed. Another suspen- sion inspection should be conducted at this location next summer, to verify the well marker post information and con- dition of the pad. In summary, I conducted the clean-up inspection of Exxon's suspended Pt. Thomson No. 3 well. Because the well marker post information could not be verified, and the stockpile of gravel and drilling mud on the location. I recommend that this location not be approved for clean-up and that an inspection be conducted by a petroleum inspector next summer. DA :vdl '- ..... ... ' ' SUI(FACE ABAN,X)' qI':NT REI'I)ICr ·3- . ~ :'::20 .... AACi25'..\RTICLI~ 2, ~ OI,erat,~r ~~ ~v'~. Date l)ownhole P a A ~~.~?' Surface 1.ocation of Well '!%5' 9 Ft. FklSL, 1 94 Ft. Fl/JgL, sec. 3B , T IO l Pa ' 20 AAC 25 120 WEI.i. AB,\NI)O .... I.,,i ,.,,xI-IKi,]R: Dia. Steel Post (4"Min.) ~/ ,. Length (10' Hin.) ~/' tle/ght Above Final Grade Level (4' Hin') i ~O~,, Top of Harker Pipe Closed with: Ce,hunt.Plug Screw Gnp ~" Welds Set: On Well fiend , On Cutoff casing ~, In Concrete Plt~g Distance Below Final. (;rede Level ~- Ft. in. Side 'Outlets: All Valves and Nipples Removed. All Openings Closed , With Blinds ,/- , With Cement , Other ' ~ ' . INFORHATION BEAlJWEI~I)EI) I)[R'' '" · I'.L~,'.I.5 '['O HARKE[I POST: (List kq~ere Different frmn File Information)" Operator Un.it or Lease Name Well Number , 'Surface Location of Well: Ft. F L, Ft., I: ' L, Sec , T , R , AAC 2~.170: LOCATION CL~bXN-UP To U~Zl ~ t~--~:~-'-'o'~ PiTS: Filled In ~, Liners Removed or Burjied ~, Debris Removed SURFACE OF PAl)AND/OR l.'.ough ~ Smooth , Contoured Flat Other ~,~ ~q ~. , Compacted CLEAN UP OF PAD AHI)/OR I.OCATION- Clean ~ Pipe Scrap Paper , Other ., , SURROUNI)IN(; ARE:\: Wooded , Brush Sand ,//, Other , Iron &crap · , Wood H u ¢1 , Cement , Tundra · / ., Grass , Dirt ~/~, Gravel CONDITION SURi~OUNI)[N(i AF',I'iA' Clean f , T-rasl~ from Site Other , Trues ,and/or Brush from Cie;icing Site ACCF. SS ROAD: Dirt , Gravel , Ice , Otlmr i:. ~i~',' I' COHD£TION ACCESS ROAI) AND Clean , Rough , Smoott~ ,. Trasl~ from Ol~er;~tions _ Trees and/or Brush from Clearing Road I , .SpoLl from Clearing Road Other REM,\[NING TO BE DONE:'*~-~,...~c:.,*~,rl. ..,..:, ~'"i~ ..... t .....,. -.' , .., l ~. , .,...~ .,. , . , RECOHI.IENIY ,AI)PIIOV,%I, OF A!~ANI)(I?QHEN'I' Yes , ,,o Final inspect ion INSPECTED BY _ 05/26/81 ~, PoiNT THoMso~1 UNIT (~o. 3 8-i~~gl ,rk°'~ ~ctl ~° :~ a `. s ~?= MNd s1},~IcP~IG ~~~, ~arYVbl 5}•ala *~ IG ki ~~1 ~~~ k ~,. `~ ~~! w g- U - BI 1 11111, --v ' . "` r'-Y ~P' 'gad ~ .=.w•+t.'rr". .. p ;, , ~{F Y h N III , ~'~~1'+D~ ~t) J;Y a,{ ~S .J ~+ ~ S! d ~'k ~- , c ~. ~,~ tr..v t 'ylrf!'~'s~~ ~.'~~ ~`e`' "~:• ` ~ r..,; ir~~" fir. . wy:~a e. r: t._ a. n r. ~ 4 8" t~-$1 app ~~•Il •~~ ,, ,u•a- Mw,l P. ~ Grua( 5~~~+(C ., ~_ 4`'~, ~ ~~%~ ~~~n9 MN7 G~~c~te~ 1~ `" ~l .: ~~~ ~~1~Cf;, ~ti ~'°cs ~ l~+ aN~l~~ Ar h (.„~.)y r a:;agv~ ~„lk~~`rl N 1 ~ ~~ s -. ~! f r ~:j~ t r. ®~' gaol .:. ~,. 3 'J ix K qyL,'; t ~0p6 Y r„, i ~ ki.,: t ~ ~S it o~ ~_;~ ; ~~ ~ {J,~~ ~t~~`r. ~3' hil ~r. ~y14~ ~'1 K ~1alf d/ rlArkGr E (,ON COMPANY. U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 PRODUCTION OEPARTMENT ALASKA OPERATIONS JulY 7, 1981 Mr. Lonnie C. Smith, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: In accordance with Alaska Oil and Gas Conservation Commission regulations, Article 2, Abandonment and Plugging, 20 AAC 25.120, Well Abandonment Marker and 20 AAC 25.170, Location Cleanup, it is respectfully requested that a program be initiated to inspect wellsites at Prudhoe Bay during the first part of the week of August 10, 1981 or during the week beginning August 17, 1981. Please notify us if these dates are convenient and if so, which is preferable. The sites to be visited and inspected are as follows: Duck Island Wells #1 and 2 on Duck Island Pad #1 Pt. Thomson #1 Pt. Thomson #2 Pt. Thomson #3 Canning River B-1 It is requested that the inspection of Duck Island Pad #2 (site of Duck Island #3 well) be deferred until the summer of 1982 since drilling on this location will resume during the 1981-82 winter season. Mr. D. E. (Dave) Galloway (263-3756) is our contact for finalizing the aforementioned inspections. ALH:,,dag A DIVISION OF EXXON CORPORATION Very truly yours, Drilling Manager 3une 24, 198l I 20EOL .... I 3 O:OL J ,STAT TEC _ I StaT TEC CONFER: FILF: Nr. Robert Ko Riddle Exxon Company, U.S.Ao Exploration Department Alaska/Pacific Division Pouch 660] Anchorge, AK 99502 Dear Mro Riddle: I am granting your request of May 26~ 1981 for an extention of the confidentiality period pursuant to AS 31,05.035 (c) on date from Rt. Thomson Unit Well No. 3. The data will be held confidential for a reasonable time after the State Supreme Court issues it s final ruling on the Beaufort Sea sale litigation. Y, Commissioner co: Holye Hamilton Alaska 0il and Gas Conservation Commission 3001Roroupine Drive Anchorage, AK 99501 Glenn Harrison Director, DMEM RECEIVED JUN 0 1981 Ntdm Oil & Gn CoM. ~ Anchorage June 4, 1981 Exxon Company U.S.A. P. O. Box 6601 Anchorage, Alaska 99502 Re: Alaska Oil and Gas Conservation Commission Regulations Article 2, ABAMDONHENT AHD PLUGGING, 20 AAC 25.120 WELL ABAND©NMENT MARKER 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 ;,yells which, according to our records,, have not received a final location ins~.',~ection and approval of clean up. In compliance with 20 AAC 25. 170 Section (a), "Within ode year of suspension or abandonment of an on- shore well", all clean up work is to be finished. Section (b) provides the means for an extension cf time if a valid reason exists. Section (c) provides for on site inspection. Consequently, we are presenting the following list of your abandoned and/or suspended wells. Many of these are now more. than one year old and are not in compliance with regulations. Others should have the. final inspection completed this summer while weather permits. This list covers the years 1975 to date. There may be some earlier wells that also need inspec- tion. If you have any earlier wells to be inspected 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. ru 1 y, .~ ,./~Y'~°~rs t ~~~i ~Lonnie C.~S~ith Commi ssi one r LCS/JET: be EXXON COMPANY U. S . A. SUSPENDED Duck Is. Unit %1 Pt. Thomson Unit #1 Pt. Thomson Unit #2 Pt. Thomson Unit #3 PLUGGED & ABANDONED Canning River Unit B-1 Pt. Thomson Unit #4 COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION Mr. Frederick Smith, Chief Water and Materials Section Division of Forest, Land and Water Management 4420 Airport Way Fairbanks, Alaska 99701 November 6, 1980 Re: Borrow Pit 'Construction ADL 28381, ADL 28382 Pt. Thomson unit No. 3 LO/NS 79-84 (78-6) COMM 'J I ~N~ .. .. ~ STAT TFC I FII F: Dear Mr. Smith: Please refer to our letters of July 28 and July 30, 1980 requesting approval of our plans to open the subject borrow pit, the initial production from which will provide material for construction of the drilling pads for the three drilling operations presently awaiting state approval (LO/NS 80-225, 80-226 and 80-228). To facilitate operations we plan to stockpile during the current (1980-81) winter season, 150,000 cubic yards of pit run gravel at the site of the Pt. Thomson Unit Well No. 3, all of which gravel will be confined to the present pad configuration without expanding or otherwise altering the drilling pad of this suspended well the suspension was approved by the AOGCC July 11, 1979. The U.S. Army Corps of Engineers has advised that inasmuch as none of the stockpiled gravel will extend beyond the limits of the pad constructed pursuant to the subject lease operations approval no federal permit of any kind will be required. Yours very truly, d.12 .,, .. Robert K. Riddle RKR: et cc: EPA, Region X; Alaska Oil & Gas Conservation Commission; U.S. Army Corps of Engineers; Douglas Lowery; Glenn Harrison; J. Scott Grundy; Shehla Anjum RECEIVED NOV ! 1980 A DIVISION Of EXXON CORPORATION Alaska 0il & Gas Cons. Commission Anchorage E) ON COMPANY, U.S.A. POST OFFICE BOX 2180. HOUSTON, TEXAS 77001 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION W.R. FUGE, JR. MANAGER ACREAGE/WELL EVALUATION CONFI August 3, 1979 Re: Exxon Point Thomson Unit No. 3 ADL 47559 (Surface) ADL 47558 (BHL) North Slope, Alaska Mr. Hoyle H. Hamilton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton: On July 4, 1979 the captioned well was plugged and suspended in accordance with the Sundry Notice dated July 11, 1979. We are submitting two copies of Form P-7, Well Completion or Recompletion Report and Log, with the following additional data: (1) One set of washed and dried samples (in 9 brown boxes) from 851' to 14,125'. (2) One blueline and one sepia print of the complete mud log from 851' to 14,125'. (3) One composite sepia and one composite blueline print of the following open hole logs: Dual Induction - Laterolog BHC Sonic Compensated Neutron - Formation Density Compensated Formation Density (4) Core chips taken at 1' intervals (in 8 white core boxes) from the following cores: Core No. a DIVISION OF EXXON CORPORATION Interval 13,665'-13,695' 13,695'-13,725' 13,725'-13,756' 13,756'-13,811' 13,811'-13,871' 13,871'-13,886' 13,886'-13,894' 13,894'-13,955' 13,955'-14,014' Mr. Hoyle H. Hamilton Page two August 3, 1979 CONRDENTIAL (5) Summary of formation test data. (6) One copy of Eastman gyroscopic survey. Please note that the above material is marked confidential and should be kept confidential in accordance with the provisions of 11 AAC 22.535(f). WRF: et enclosures Very truly yours, W. R. Fuge, Jr. -. " SUBMIT -' '-~_.~,<ATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* 18. TYPE OF WELL: OII,w~.LL ~ OASWELt. ~ DRY [] Other Wildcat b. TYPE OF COMPLETION: .~Ew [] wo~x ~ D~e-~ ~, ~ D~. ~ Suspended V~' EL I. OVER ~ EN BACK P~ESV R. Other 2.' NIME OF OPERATOR Exxon Corporation 3. ADDRESS OF OPERATOR P. O. Box 2180, Houston, Texas 77001 4. LOC,~.TION Ob' WELL (Report location clearly and in accordance with a~y State requirements)* ~t~u~ 660' NSL & 71i' WEL, Sec 34, T10N-R23E, UPM, North Slope, Alaska At top prod. interval reported below At totaldepth 18L~9!.' NSL & 15.94' WEL, Sec 35, T10N-R23E, UPM, North Slope, Alaska CONFID 5. API NU1VIF_~q/CAL CODE 50-089-20007 6. LEA~SE D~iGNA~ON ~DSERLA/~ ADL 47559 Surface _ ADT. ~7558 BHL 8. UNIT,FA/TM OR LEASE NAME Point Thomson Unit 9. WELL NO. 3 10. FIELD A/hID POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECWIVE) Sec 35, T10N-R23E, UPM 12. P~%iVIIT I~TO, 78-5 1/3/79 t 5/15/79 ! 7/4/79 I 36' KB . , -- 18. TQT~L ~}F~PI, a%~Q. & TVD~19. PLUG, BA~CK MD & ~D~, ~ ~ULT~LE CO~L., I 21. INTERVALS DRILLED BY lqt IgD iVlD [ -- I / ~OW~Y* ] ROTARY TOOLS [ CABLE TOOLS . 4u ./ --. I -- ~, P~UCING [N~VAL(S), OF ~IS CO~P~TIO~TO~, BO~OM~ NAME (M~ AN~ ~)* ,23, WAS DIRE~O~~ , SURVEY MADE See item 28 for perforation intervals. ~ Yes 24. T5~PE ELECTEIC AND OTHEI% LOGS RUN Dual Induction, BHC Sonic, Vm l oa ~ t.Y , 25. CA, SI~4G SiZE \VEIGHT, LB/FT. [ GI%ADE .. 96.4 ~K55 Formation Density-Compensated Neutron, Dipmeter, CASING RECORD (Report all strings set in we{l)' 811 22 .4300 CE3XLNTING RECOtqD sx Permafrost · None 13-3/8 72 IL80 3,3,38 9-____~5/8 . 47 Soo 95 10,3,47 7 35 Pll0 14,1.14 26. LINER EEC OI~D 28. 15ERFORAT1ONS OPFLN TO PRODUCTIOlhT (interval size and number) 12~ 50 sx Class G 8½ ,[1035 sx Class G I 27. [I'UBING 1REC~OFJ~ SC}%EEN ~5~D) SIZE DEP~rt SET (MD~ 13,872'-13,885' 13,908'-13,925' (2 spf) (2 spf) PRODUCT/ON None None 9502' PACKER SET (MD) ACID, SHOT, FRANC] (IRE, CE&lENT SQUEEZE, ETC. D"""""""""""""""""""~I~Ii lrCI']gRVAi, (MD) ! AMOUNI' A_ND I-;~IND OF MATEP, XAL USE, D 13,870 '-13,885' IB!k' sqz w/100 sx cem~n-~ ' 1.3,908 '-13,927 ' [ Blk sqz w/100 sx c~m~ent ~ . r~,-~ ,, , .... ,,,, DATE FIHST PlZODUCTION T P~ODUCT1ON MEL[{OD ,Fl .... ii~E..t::as lifL, pamp[ng -size and type of pump) ~ZAX~S (~r~d~Clng or 31. DISPOSITION OF OaS (Sold used Jor yuel vented etc ) ~ ..... ~ · [TEST X~S[D nY ' ' ' ' ~.~:~;'~: _/~ .' ' . : .' ~ ~ 1 ::0 ~t~i~--~ Acu,~:~.~'¢ .... ~E . Miller 32.LIST OF ATTACHMENT8 re Data. ~ I hereby eertif~fhat the foregoing and attached lnfo~tlnn Is complete and correct as determined from all-available records '(~ /~ ,~ ~~, (~;4t Acreage and Well · (S~e Instruction~ and Spaces [or Additional Data on Reverse Side) ~~';da~B6~ ~d i r tart and to on well com let on e I~~Ittln a com lete and correct p f`' ~~ ned for sub r ~ form is des p ne al. Thls 9 Ge ~ ska. nr! nd leases in A a all t es of la ~s a YP E wn for de th measure- h r not otherwise s ~o eference wee p Lion IS used as which eleva Item. 14. Indicate ~ in an attachl~~ents. on thls form anc is Iven In ether s does men Y g p n interval zone r m mo-e than o e .. . cductlon fro m leted for se aratc tl~IS well Is co 20 and ~2.. If p Items p p • ~ ~ il~tervals ~ in_ interval or , h Ic.luc ~ Ite~~ 2~ show t (. , n item 10 and ~I U ~ com Ietlor~ so state I p mu t le , P p 't rn U. Submit a se ante re ort rtdln~e 3 P n! the Interval re ~o e p m s If an for o to s bottoms and na e I Y Y p ' I OdUCf'`'~ S~IOW- I int ~ val to be se erate r , addlt~ona e Y p d or each P t I Identlfle f n this form ade ua e page o q y , to ertinent to such interval. n th acFdltlonal da I g e p ~, n mu!- tads of a h w the de • II shoulJ s o . for this ~ e Y tal records tt h su lemon nt A ac ed It®n~26. Sacks Ceme . pP i too I . Iocatlon of the cement n t ancf the tI le sta e cemen In g p g 9 ;, r duced. se aratel o Int rval to be fo each e th s f orm r p Y p ar to om Ietlon re rt on I Item ~~, Submit a se a c p p Po r ' m 20 and 22 above . Instruction fo Ito s e 39. SUMMARY OF E'ORMATION TI'S'I'~ 1NC'I,UI)IN(~ INTERVAL TE.S'I'El), YRE.SSURE DATA AND RECOVERIES OF OTL, GAS, 35. GDOla0G1C' MARKF~i.S WA'T'ER A N ll M U D NAME A1EAS DFF'TH ti VfiRT. D1±~''I'1{ . r ertlar Lowe T wer Eocene Lo Pa eocene , r MENT ATTACH SEE ' San Tnomson , , re-Miss. P , __ r~ _ .. ~ ~ ~ ~ r,S APPARENT UII'S 3(3. CnIIF. DA 1 A, A`l"I~AC'!{ tlitiF.F DESCit[I7I I Ic)NS OF LITItULUC,~ , POR~,SITY, FI{AC TUIt ~ , ANU UE'I'F:C'1'1~:I) tillOWS Of<' OlL, GAS OIL 1VA'1'EI{. •~+~.~s:..:ne~mma.~scr%zas~ce~e.~axs~n~av -na---rw-~.ss~=.s~:~r-s ~zxxcxrssorar e: ' . ~es6tr+eaes _ . Tcs~m•x~: z•: ~-rxmr~e~~7x:.,:c^-~'~-.~ytc.-~'a_-~¢~,.°~:aka`~cc~,~w~_1u:=:,_~'~z~a -~ b ~ ... ~ . ' •. :7 1elC • . ENT TTACH E A 5E . , ~~~ ~,.,~ ,- .t;,~- . ..e. _.. ...._._.._._ ..~.. _ .__ ~~ __._._... _.___~ - - - .~....-~-___ .~ .~. _.~_ ~ ~ .~__._..___ .._.._~___._ ~... _ ~:: r .. i~ ; ~; ,} ~,: ; t +. ~; , . 4. IY ~ :._ 1.':. : ~: . ~ .. ::. w TEST DATA Exxon Point Thomson Unit No. 3 TEST NUMBER DATE TYPE TEST INTERVAL CUSHION HOURS TESTED PROD'N FOR TEST PERIOD CHOKE SIZE FLOW RATE FLOWING TBG PRESS TBG SIZE IFP ISIP FFP FSIP 1 6/8/79 DST through perfs 13,908'-13,925' (2 spf) 13,700' diesel 3 hrs. 22 min. 2 6/21/79 Prod'n through perfs 13,872'-13,885' (2 spf) 13,852' diesel 9 hrs. 4 min. <1 bbl 16/64" 2-7/8" 4866 psi 9878 psi 4877 psi 2,316 MCFG + 181 BC 11/64" + 20/64" in series (2)6,348 MCFG/D & 476 bbls 38° API gravity condensate (.1)Press Falloff 6,125 psi 2-7/8" 8716 psi 10,358 psi 9900 psi 10,236 psi (-2)Based on 4 hour stabilized test Core ~ 1 Core #2 Core #3 Core #4 Core #5 Core #6 Core # 7 Core #8 Core #9 Exxon - Point Thomson Unit No 3 i~! ;[ ~' 13,665'-13,695'. Rec. 28' sandStone, lt. gry, f-cg, fair porosity with no oil staining. 13,695'-13,725'. Rec. 28' sandstone, It. gry, vf-fg, poor to good porosity with no to spotty oil staining. 13,725'-13,756'. Rec. 31' sandstone, it. gry- brn, vf-fg, poor to good porosity with no oil staining. 13,756'-13,811'. Rec. 56' sandstone, it. gry to it. brn, fg, poor to fair porosity with no oil staining. 13,811'-13,871'. Rec. 60' of sandstone and conglomerate, it. gry to it. brn, f-vcg, poor to fair porosity with no to some oil staining. 13,871'-13,886'. Rec. 11' sandstone, med to dk gry, f-cg, poor porosity with oil stain; 4' breccia, wh to dk gry, very poor porosity with oil stain. 13,886'-13,894'. Rec. 8' breccia, it. gry, very poor porosity with oil stain. 13,894'-13,955'. Rec. 25' sandstone and conglomerate, gry to dk gry, vf-vcg, poor~ porosity with oil stain; 9' breccia, med to dk gry, very poor porosity with oil stain; 27' phyllite, gry to dk gry, no show. 13,955'-14,014'. Rec. 59' phyllite, it. gry to dk gry, no show. RGD 7-5-79 Diesel 10.2 ppg CaC12 Water 15.8 ppg Fresh Water Mud FINAL WELLBORE SCHEMATIC AFTER SUSPENSION POINT THOMSON UNIT NO. 3 Diesel cushion to surface Cement plug from 40' to 100' 18-5/8", 96.4 ppf, K55, BTC Conductor Csg. @ 811' MD (811' TVD) Cast Iron Bridge Plug @ 2000' MD Arctic Casing Pack in 9-5/8" x 13-3/8" Annulus 13-3/8", 72 ppf, L80, BTC Surface Csg. @ 3338' MD (3298' TVD) · .. Top of Cement @ 8869' MD Baker Cement Retainer @ 9019' MD 7", 35 ppf, Pll0, BTC Production Csg. Stub @ 9502' MD 9-5/8", 47 ppf, Soo95, BTC Protective Csg. @ 10~47' MD (9680' TVD) Top of Cement inside 7" Csg. @ 13,612' MD Top of Cement outside 7" Csg. @ 13,664' MD Halliburton Cement Retainer @ 13,847' MD Baker Model F-1 Production Packer @ 13,852' MD 13872' - 13885' MD: 2 spf, 180° Cast Iron Bridge Plug @ 13,890' MD Baker Model F-1 Production Packer @ 13,892' MD 13,908' - 13,925' MD: 2 spf, 180' Top of Cement inside 7" csg." @ 14,024' MD (Float Collar) · 7", 35 ppf, Pll0, BTC, Production Csg. @ 14,114' MD (13140' TVD) 8-1/2" open hole TD @ 14,125' MD (13,151' TVD) EXXOI USA PROPRi , . i"t CONRDEH~L DIRECTIONAL SURVEY REPORT Precision Instruments / Proficient Service SPERRY-SUN, INC. EXXON CO U S A ANCHORAGE, ALASKA PT. THOMPSON ~3 ........ ' ............. : ...................................... COMPULATION DATE FIELD: WILDCAT MAY 29, 1979 NORTH SLOPE, ALASKA RECORD OF SURVEY CONFID TRUE COURSE MEASURED VERTICAL INCLINATION DEPTH DEPTH DEGREE COURSE DOG-LEG DIRECTION SEVERITY AZMIUTH DEG/100 ~" 100 ....................... 100 ~"00 .................... . 22 200 200.00 .16 300 300.00 .,i8 400 400.00 .16 500 500.00 .09 600 600.00 .11 700 700'.00 .07 800 800.00 .06 900 900.00 .18 1000 1000 00 .: ~ 17 1200 1200.00 ~:~ '< ..... ~' '~*' .28 1300 1300 O0 ':~.' ..... ':"' ..................... .22 1400 1400 00 ~'~':::' ~ .... .:':~ 30 1500 1500·00 ~:~ ~ . :_.,.~ . 1600 ............. 1600'i 00 :%':' '" : ..... "':::~ ............... . 1700 1700.00 ~:":' ' '":: ! 1800 1800.00 .... :: . ..... 1900 ......... 1900 ' O0 ~: ' ~ :.:-':~-::'! .......... . _ , 2000 1999 99 ~: .... 1 2100 2099 95 ...... , ,:=,~ . 2200 .... 2199.86 2300 2299.66 2400 2399.28 2500 ......... 2498.64 2600 2597.61 2700 2696.0! 2800 .............. 2793.57 2900 2889.97 3000 2985.15 3100 3079.23 3200 3172.12 3300 3263.63 . 4. 5. 7, 9. 11. 14. 16. 18. . · 20. 22. 24. 44 31 38 32' 65 14 96 98 25 71 24' 19 32 O3 79 95 69 77 80 49.9 14.8 19.2 32.5 46.]. 60.4 69.0 50.7 43.4 27.2 28.3 22.6 61.8 57.3 68.9 80.2 07~1 11.9 98.8 91.0 94.6 98.7 99.2 99.7 97.8 98.3 96.6 96.7 96.3 96.8 96.0 95.7 95.8 .21 .12 .01 .04 .16 .02 .13 .02 .11 .04 .16 .07 .24 .08 .15 .15 .16 .05 .34 .49 .82 1.03 1.28 1.45 1.54 1.95 2.15 2.70 2.76 2.17 ! .75 2.08 2.03 PAGE 1 DATE OF SURVEY: MAY 29, 1979 BOSS GYROSCOPIC SURVEY' JOB NO, BOSS-16347;16366;16400 MINIMUM CURVATURE CALCULATION TOTAL RECTANGULAR NORTH/SOUTH COORDINATES EAST/WEST .05 S .19 .27 S .44 .40 S .70 .57 S .94 .58 S 1.16 .48 S 1.30 55 S 1.44 ,66 S 1.48 .84 S 1.59 1.06 S 1.80 1.33 S 2.15 1.64 S 2.59 1 6'6 S ....... 3.03 1.43 S 3.42 1.14 S 4.00 97 S " ' 4.63 1.01 S 5.23 1.21 S 5.81 1.43 S 6.63 1.56 S 8.19 1.69 S 10.89 2.19 S ~ 15.17 3.17 S 21.40 4.60 S 29.96 6,32 'S 41.11 8.32 S 55.26 10.63 S 72.91 13.17 S 94.70 16.18 S 121.10 19.68 S 151.59 23.46 S 185.29 27.23 S 222.1.2 31.27 S 262.25 SPERRY-SUN, INC. EXXON CO. U.S.A. .. ANCHORAGE, ALASKA PT. THOMPSON'~3 ............ 7L:'i'~"f'"~ ....... : ................................ COMPULATION DATE FIELD: WILDCAT MAY 29, 1979 NORTH SLOPE, ALASKA ................... RECORD OF SURVEY -CONFID. I PAGE 2. DATE OF SURVEY: MAY 29, 1979 BOSS GYROSCOPIC SURVEY JOB NO. BOSS-16347;16366;16400 ' MINIMUM CURVATURE CALCULATION TRUE COURSE COURSE MEASURED ........... VERTICAL INCLINATION DIRECTION DEPTH DEPTH DEGREE AZMIUTH DOG-LEG SEVERITY DEG/100 RECTANGULAR NORTH/SOUTH TOTAL COORDINATES EAST/WEST 3400 ......................... 3355 03 35OO 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 3446.9]. 3539.40 3632.68 3726.63 3820,94 3915.26 4009.02 4].01.89 4].93.85 , 4285.17 4376.14 00 4467 00 00 00 00 00 00 00 00 00 00 00 4557 4648 4738 4828 4918 5008 5099 5190 5281 5371 5462 5800 5900 6000 6100 6200 6300 6400 6500 6600 5552 5643 5733 5824 5915 6006 6097 6188 6279 .04 .92 .44 .55 .47 .51 .82 .43 .34 .12 .65 .17 .77 .31 .83 .46 .31 .44 .66 .74 .73 .......... 24]'06 . 22.55 22.24 20.20 19.98 19.17 19.81 -21.15 22~69 23.75 24.47 24.70 24.68 24.78 25.66 25.94 26.14 25.59 25.40 24.90 24.61 25.15 25.25 25.15 25.04 24.52 25.12 24.99 24.52 24.25 24.28 24.60 24.57 95 . 8 .............. '?' .......... 0-' 70 98.4 1.80 102.0 ..................... 1.40 103.6 2.00 108.4 1.60 99.0 ............... 3.20 92.5 2.20 84.5 3.10 76.0 ....... 3,50 94.5 ., 1.10 74.9 0.70 75.9 0.20 75.4 0.00 76.0 0.10 76.1 0.90 76.8 0.30 77.6 0.20 78.6 0.60 78.0 0.2O 70.9 3.00 63.5 3.10 61.3 0.90 62.0 0.10 61.5 0.10 62.5 0.10 61.6 0.30 63.6 0.80 64.7 0.10 65.1 0.50 64.9 0.30 64.5 0.00 65.5 0.30 64.7 0.00 34.48 S 39.30 S 46.01 S 53.98 S 63.40 S 71.35 S 74.63 S 73.62 S 67.21 S 57.16 S 46.3.7 S 35.90-S 25.56 S 15.22 S 4.93 S 5.26 N 14.97 N 23.97 N 32.71 N 44.08 N 60.28 N 79.79 N 100. O2 N 120.16 N 140.06 N 160.01 N 179.60 N 198.03 N 215.79 N 233.23 N 250.77 N 268.22 N 285.73 N 302.77 342. O0 379.46 414.76 447.73 480.15 513.26 '6:227:~,87 :663'. 24 :~7 (},..~. 48 ~7z~2 92 783.44 824.76 867.04 909.81 952.46 994.58 1.035.44 ].073.95 1111.18 E 1148.61 E 1186.09 E 1223.52 E 1261.06 E 1298.85 E ]336.95 E [ '~74.84 1412.22 E 1449.34 F, 1486.82 ].534. EXXON CO. U.S.A. · PT. THOMPSON ?IELD' WILDCAT NORTH SLOPE, ALASNA SPERRY-SUN, INC. ANCHORAGE, ALASKA COMPULATION DATE MAY 29, 1979 RECORD OF SURVEY CONFIDENTIAL TRUE COURSE MEASURED VERTICAL INCLINATION DEPTH DEPTH DEGREE COURSE DIRECTION AZMIUTH DOG-LEG SEVERITY DEG/100 6700' .......... 6370'.33 .............. 25.63 6800 6460.36 26.06 6900 6550.42 25.55 7000 6640.95 24.83 7100 6731.74 24.85 7200 6822.40 25.20 7300 6912.93 25.23 7400 7003.46 25.20 7500 7094.08 24.98 7600 7184.74 25.04 7700 7275.37 25.04 7800 7365.81 25.60 7900 7455.84 25.].4 8000 7545.59 26.32 8100 7635.13 26.67 8200 7725.03 25.23 8300 7815.97 24.27 8400 7907.51 23.46 8500 7999 21 23.71 8600 8090.70 24.03 8700 8182.04 24.15 8800 8273.06 24..90 8900 8363.89 24.64 9000 8454.67 25.04 9100 8545.62 24.19 9200 8636.71 24.67 9300 8727.32 25.48 9400 8817.62 25.51 9500 8907.84 25.71 9600 8997.94 25.85 · . 9700 9088.25 25.08 9800 9179.18 24.].9 9900 9270.69 ' 23.45 .66,[3 67.7 67.8 ,, 69.7 70.8 71.1 70.9 70.9 73.8 74.3 ' 74.9 76.4 77.6 79.5 80.2 80.1 73.6 66.2 62.8 63.1 65.2 65.2 67.9 67.2 65.6 65.5 67.6 70.4 70.5 7].]_ 71.'~ 71..9 '72.9 1.1 0.4 0.5 1.0 0.0 0.4 0.0 0.0 1.1 0.1 0.0 0.6 0.5 0.8 0.4 1.5 2.9 3.]. 1.3 0.3 0.7 0.8 1.1 0.4 0.8 0.5 1.1 1.! 0.2 0.8 0 a 0,8 PAGE 3 DATE OF SURVEY: MAY 29, 1979 BOSS GYROSCOPIC SURVt[Y - JOB NO. BOSS-16347;16366;16400- MINIMUM' CURVATURE CAL, CULA'.I'ION · TOTAL RECTANGULAR . NORTH/SOUTH 303.32 N 320.35 N 336.84 N 352.24 N 366.41_ N 380.22 N 394.09 N 408.01 N 420.83 N 432.43 ...... N.,.:, · 443.65 ..... N" ' · 454.22~ N · 464.. 472.76 ~N 4.80.60 . N 483.08 N 497 . 54 ,iN 511.37 528 . 58 :N_ 546.97 564.73 582.10 N 598.73 N 614.77 N 631.46 N 648.51 N 665.30 N 680.79 N 695.26 7O9..%9 736. % 7 N 74 ~,~. '/~ ~:' COO R I} I NATES ]:,A,__ l/W! ,S':I.' 1563.10 1603.20 1643.47 1683. 1.722.6] 1.762.56 1.802 . 1843.05 188~.43 ]_925.06 1964.85 2006.28 2048.77 2092.05 2~35.95 2179.04 2219.75 2257.68 2298 73~9 76 2366.47 2404. 1_ 4 '-~ 4 4 '> 5 6 '~ 4 S 1. 36 o 5 1 9 2557. 2595.96 2670. ~ 0 2758.49 279 U. (~ 1 28 .~ 0. 4 {) SPERRY-SUN~ INC. EXXON, CO .... U.S.A ' . .......... ANCHORAGE,. ALASKA PT. THOMPSON ~3 COMPULATION DATE PIELD: WILDCAT MAY 29, ].979 NCR2H SLOPE ALASKA ' RECORD OF SURVEY .... TRUE COURSE COURSE MEASURED VERTICAL INCLINATION DIRECTION DEPTH DEPTH DEGREE AZMIUTH 1 10100 9454.41 10200 9545.68 10300 9637.29 10400 9729.91 10500 9822.84 11_0600 9.915.46 10700 10008.01 ].0800 ].0099.87 0000 ...............9362-71 10900 10190.72 11000 10280.88 11100 10370.41 ._ 11200 10459.52 11300 10548.39 11400 10637.19 11500 10725.61 11600 10813.84 11700 10901.57 11800 10988.67 11900 11075.84 12000 11163.06 12100 11250.45 12200 11338.11 12300 11426.66 12400 11516.69 12500 11608.00 12600 11700.71 12700 11794.63 12800 11889.17 12900 1]_984.00 13000 12079.11 ].3100 12].74.31 ].3200 12269.26 22.75 72.2 24.46 66.5 23.96 60.5 23.18 60.4 21.32 63.0 22.17. 64.1. 22.27 64.9 22.34 65.7 24.36 66.2 25.13 67.8 26.23 70.3 26.79 71.7 27.32 72.9 27.36 73.4 27.51 74.8 . 28.31 74.4 27.98 69.5 29.51 70.7 29.48 72.7 29.34 75.5 29.34 78.8 28.90 80.0 28.69 79.6 26.90 70.9 24.92 63.5 23.28 63.9 20.85 66.0 19.48 69.6 18.69 72.7 18.46 74.7 ].7.63 78.8 1_8.10 80.7 18.62 83. ]. .CONFIDENTIAL DOG-LEG SEVERITY DEG/100 · 0.7¸ 2,8 2.4 ]..0 2.1 0.8 0,! 0.1 2.0 0.8 1.4 0.6 0.5 0.0 0.2 0.8 2.3 1.5 0.9 1.3 1.5 0.4 0.2 4.4 3.8 1.7 2.5 1.8 L.3 0.6 1..5 0.7 0.8 PAG15 4 ' DATE OF SURVEY: MAY 29, 1979 BOSS GYROSCOPIC SURVEY JOB NO. BOSS-16347;16366;.l. 640h MINIMUM CURVATURE (.,Al .... UIA I;()N TOTAL RECTANGULAR' NOR[Pt-I/SOUTH 760.54 7'74.71 792.94 812.73 8130.07 847.19 863.48 8'79,34 895.49 911.81 927.28 941.80 955.61 968.91 981.51 993.92 1008.50 lO24.85 1040.29 1.053.74 1064.62 1073 . 57 1082.10 1093 . 84 1110.65 1128.76 1144.69 11.57.70 1168.25 1177.17 1184.29 1 ]. 8 9 . 7 } 1194 . 16 2873.86 29111.26 2947.94 29 8 2.84 30]_6.1_4 3049.29 3083.40 3117.86 3].54 . 06 3 ].. 92 . 58 32 } 3 . 02 3275 . ]. 8 3318 . 50 3 362 . 44 34 06. '7"t 345 I . 84 3496.63 3541.82 358 a . 53 363 %. ? .L 3683.43 3731.23 3 ? 78.62 3823.64 3863.89 3900.46 ¢ 934,. 45 3 a 66. % 2 3997 . 22 4027.76 ,1057.8 % EXXON CO. U.S.Ao PT. THOMPSON fib FIELD: WILDCAT NORTH SLOPE, ALASKA SPERRY-SUN, INC. ANCHORAGE, ALASMA COMPULATION DATE MAY 29, 1979 RECORD OF SURVEY CONFIDENTIAL TRUE COURSE COURSE MEASURED VERTICAL INCLINATION DIRECTION bidP'fH DEPTH DEGREE AZMIUTH DOG-LEG SEVERITY DEG/100 13300 12363~85 ..... 19.44 13400 12458.08 ]_9.86 13500 12552.53 18.64 13600 12647.72 17.22 13700 12743.47 16.45 13800 12839.46 16.28 13900 12935.46 16.40 14000 13031.40 16.52 14125 13151.24 16.52 84.2 .. 0.8 84.9 0.4 87.3 ,, 1.4 90.0 1.6 91.4 0.8 91.7 0.2 91.8 0.1 92.9 0.1 92.9 0.0 ., PAGE'5 DATE OF SURVEY: MAY 29, 1979 BOSS GYROSCOPIC SURVEZ JOB NO. BOSS-16347;].6366;16400 MINIMUM CURVATURE CALCUI.,ATION RECTANGULAR NOlTe-I/SOUTH 1197.75 1200.93 1203.19 1203.95 1203.61 1202.85 1201.99 1200.84 ]_199.04 TOTAL C O O 1'{ D I N A T E S "~ lEAS I/WE,~ [ 4].51.53 41.84.98 4217.84 4248.58 4277.52 4305.66 4333.75 4362. O3 4397.52 HORIZONTAL DISPLACEMENT = 4558.06 FEET AT NORTH, 74 'DEG'.' 4'5MIN. EAST AT MD = 14125 ^' IN'PERPOLATED BELOW ACTUAL SURVEY DEPTH E (.ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION July 11, 1979 Mr. Hoyle H Hamilton ~: " ~ Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Exxon Pt. Thomson Uni~ Permit No. 78-5 North Slope, Alaska Dear Mr. Hamilton: Enclosed in triplicate is the Sundry Notice Form 10-403 with attachments covering the suspension procedure compl 7-4-79 with respect to the subject well. 12 ENO ,,;' I 3 ENG I 4 ENG "~ ,- I 2 GEOT ~' 3 GEOl. SS'rAT TE'(~'~ TAT TEd'" '"1 : FILF: Also attached is a fourth copy of the completed Form 10-403 without attachments which we ask that you return to us for our file upon your approval of the submitted notice. Yours very truly, RoBert K. Riddle RKR: et attachments A DIVISION OF EXXON CORPORATION RECEIVED Form ! 0-403 REV. 1-10~73 Submit '1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) 5. APl NUMERICAL CODE 50-089-20007 6. LEASE DESIGNATION AND SERIAL NO. ADL 47559 Surface ADL 47558 BHL Ow~LLLD GAS O OTHER WELL Wildcat 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Exxon Corporation Point Thomson Unit 3. ADDRESS OF OPERATOR Pouch 6601, Anchorage, Alaska 99502 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 9. WELL NO. Exxon No. 3 4. LOCATION OF WELL 10. At surface 663' NSL & 662' WEL, Sec. 34, T10N-R23E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, et~) Approx. 8.6' GL 14. FIELD AND POOL, OR WILDCAT Wildcat ll. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 35, R10N-R23E, North Slope, Alaska 12. PERMIT NO. 78-5 Check Appropriate Box To Indicate Nature of Notice, Re )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L----J PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Suspend SUBSEQUENT REPORT OF: · ~ rREPAI RI NG WELL WATER SHUT-OFF : ALTERING CAS ING~ FRACTURE TREATMENT (Other) '~ ..... ~" c (NOTE= Re~o~ results of multiple completiomon Well C~l~lon or Recompletion Repo~ and Log form,) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of_ 979 starting any proposed work. ~J [!L ! ~; J · Attached hereto are the following: 1. Final wellbore schematic ~,i~a ,.. ~ ,,, ~,.,i,,~l~i~!l 2. Suspension procedure ~,~]~la~, 3. Squeeze procedure for final squeeze after testing. Mr. R. P. Bright, Exxon Drilling Manager, and Mr. R. L. Longstreet, Production Geologist, discussed the procedure described in attachments 1, 2 and 3 with Mr. Russell Douglas, Alaska Oil and Gas Conservation Commission on 6-22-79 at which time Mr. Douglas gave verbal approval of the procedure. The suspension squeeze began at 0200 hours, 6-24-79; on 6-25-79 Mr. Douglas gave verbal permission to Mr. R. L. Longstreet to not squeeze the upper set of perforations as long as a minimum of 50 feet of cement was placed in the casing above them and the cement plug.was tagged. This change was made when we were unable to pump through the cement retainer at 13,847 feet. The final step of the suspension procedure was completed at 1000 hours, 7-4-79. TITLE Drilling Manager DATE July 11, 1979 (This space for State office use) CONDITIONS OF APPROVAL, ~/F ANY: TITLE See Instructions On Reverse Side STATE OF ALASKA SUBMIT ~N DL?LICAT~ OIL AND GAS CONSERVATION CO~I~EE . 5~9-20007 '- ~ L~SE DESiG~A~ON AN'D S~IAL NO. ~ONT'HLY REPORT O'F DRILLING ~L 47559 S~face AND WORKOVER OPERATIONS ~ ~755~ .... ' ' ['~ '' ~ .... ' :' .... ,~IT PA~ Off LEASE '~E ~ I~OMM ~ ,.. : Co o tton ,- .:. po[2t Unit Po~ch 6601~ ~chor~e, Alas~ 99502 ~' '~ -:; ',~ f L..,, ~)~ ;~ ~:i "~ ~ i~ ~ ~ ~on No. 3 S~ace: 663' NSL & 662' ~, Sec. 34, T10N-~3E, ~M __Wildcat 14ENG North Slope, Alaska n s~C,o~~T.. ~. ~ (~O~OM ~o~ ,,f~l-~- GEO'L ~ (~oposed)' 2160' NSL & 1400' ~, Sec. 35, j ~GE~ T10N-~3E, ~M, North Slope, Alaska Sec. 35, T10N, ~M ~ ~ZT ~O ~ STAT TEC ~8-5, 1~. ~O~T TOTAL D~ AT ~D O~ ~O~. C~NG~ IN ~ODE ~IZ~. CA,lNG A~ C~T[NG ~OBS INCLt:D~NG DEPT~ SET A~ VO~ USED. ~O~TIO~S, ~ST~ ~ ~S~LTS ~I~HI~ ~O~ ~b~ ~N HO~E AN~ ~IDE-~.AC~ED HOL[ CON .~ ~ o~ Sm~F~C~T ~~ ~ ,~o~ eo~m~Tm~s FER: FILF: Squeezed perfs 13,908'-13,927' w/100 sx class G cement. Perforated 13,870 - 13,885' w/2 spt, set a c~ment retainer at 13,850' and squeezed w/100 sx class G cement. Tested 2-7/8" tubing to 10,000 psi. Milled cement and retainers at 13,850' and 13,900'. Cleaned out 7" casing to a PBD of 14,024 '. Perforated 13,908'-13,925' w/2 spt and set a Bake~.__..M0~...?,l.~packer at 13,895'. Ran conventional DST using a diesel cushion. Opened tool for 14 minute IF. Closed for 60 minute ISI. Reopened for a 6 hour, 50 minute final flow. Total entry during both flow periods was less than one barrel of fluid. Reversed out diesel cushion and was unable to work stinger out of packer. After cutting the tubing at 12,124' and jarring, ~the fish came free and was recovered from the hole. Set a Baker CIBP at 13,890'. Perforated w/2 spt 13,872' -13,885' and set a Baker Model F-1 packer at 13,852' and ran a conventional production test using a 70 barrel diesel cushion. Opened tool for 1 minute IF. Closed for 60 minute ISI. Reopened for a 9 hour, 3 minute final flow. On a 4 hour stabilized test the well flowed gas at the rate 6,348 MCF/day plus 476 BC/day. Shut in 13 hours, 30 minutes for BHP buildup. Killed the well and set a c~em~nt retainer at 13,847'. Attempted but could not pump through retainer with 6000 psi. Spotted an 8 barrel cement plug on top of the retainer at 13,847'. After WOC tagged top of cement at 13,612'. Cut 7" casing at 9502'. Pulled and layed down 225 joints of casing. CONFIDENTIAL RECEIVED jUL 1 2 1979 Ata~a 0il /~. fl~ 6ons, .~omlTIl$3;0il Anctl0r~g~ smmm //(/'~.v/#. nT~ ~m!u?_tion__U3m?_ger ...... r:,~,~. ,_July 9:1979 NOTE--Re,oft ~thi, f~i, r~red .r eQCh Collndar ~nth, regordless of the ,tflt.s ,f o,,ratio,,, o.d must. filed 1. duplicate with the oil an~os conlervaf{on commiflee byfbe I~ of the su~c~diflg mofl~, u~la~ otherwise ~r~cfed, /- Oil ar~ C~as Corservation Ccmmission Files July 2, 1979 On June 29 th~xon r _~?ort 1 1/2 gallons of new motor oil had leaked frc~ a drum at the Pt. Th~n b~it ~1%-~e!l site. The contamin~mted gravel was pick~] ilo and placed in a metal container and the drum was emptied~. Liquid, residue is to be punped down the a~ulus. FILE June 27, 1979 Russell A. Douglass Petroleum Engineer Suspension of Exxon Pt. Thomson Unit #3 : Received a call from Roy Longstreet, Exxon 06/25/79. He infommed-me. .... ] ";~-~ they had set a cement retainer at 13,857' in their Pt. Thomson Unit #3 well, but were unable to pump through it. He requested approval to dump 50 feet of cement on top of the retainer, WOC then tag plug before continuing suspension operations. I gave verbal approval for the opera- tion as he described it and requested a P-3 outlining the procedure. PJ~D:emi Revision 2 POINT THOMSON UNIT #3 SUSPENSION PROCEDURE This procedure begins after cement squeezing of the last test i~.terval. . Pull out of the hole with cementing workstring. Trip in hole with 2-7/8" tubing and pull out of hole laying down tubing. o Nipple down the BOP stack and remove the "C" section. Install an 11" 10M# x 13-5/8" 10M~ spacer spool and nipple up BOP stack. Install 3-1/2" drill pipe rams in the bottom preventer, blind rams in the middle preventer, and 7" casing rams in the top preventer. e e Rig" up the test pump and test the bonnets in the stack to 3,500 psi. .. Make up a Tri-State 5-3/16" OD Mechanical Cutter on 3-1/2" drill pipe with 1 joint 3-1/2" drill pipe below cutter and trip in hole. Tag cement top at approximately 13620 ft. Be Pull out of hole back to 9500 ft. Check for pressure in annulus before making casing cut. Cut 7", 32 ppf, Pll0 BTC casing at 9500 ft. MD. 6. Make up Tri-state or Bowen casing spear and .latch into casing. Pick up casing and remove McEvoy casing hanger. Rig up casing crew and tongs. Retrieve 9500' of 7", 32 ppf, Pll0, BTC casing. Limit tong speed breakout speed to 15 rpm initially and increase speed to a maximum of 25 rpm if no galling is observed. Install thread_protectors _on~_casin~ joints.. before !avi[~c. down cas~r_%g-- 8. Rig down casing crew and tongs. Trip in hole with 9-5/8" casing scraper on drill pipe to 9,500 ft. Circulate bottoms up and pull out of hole. Run in hole with Baker cement retainer for 9-5/8", 47 ppf casing with latch-in collar one stand above retainer on 3-1/'2", 13.3 ppf drill pipe. Set retainer at 9~00~ ft. (MD) and establish injection rate..'~, ~PiCk~up Out of' retainer 5 ft. ' ~ Point Thomson Unit #3 Suspension Procedure Page Two Revision 2 10. Mix the following cement slurry in recirculating blender as follows: 78 sacks Class "G" cement w/1.0% CFR-2, 0.5% Haiad 22A, 0.2% HR-7 · 15.8 'ppg slurry with 5.0 gals. mix· water.~perf.~ack ~ 16.0 bbls, cement slUrry ' ·~ ·~ ' ,i/~', ~ ~· 1.15 ft3/sk cement yield · ~ 9.3 bbls. water for mixing Thickening Time = 3 hours 50 minutes 11. Pump the following into the workstring at 2 bbls./min. 5 bbls Fresh water 16 bbls. cement slurry Insert latch-in wiper plug 45.1 bbls. 15.8 ppg mUd 12. Sting into cement retainer with workstring and~umP 10.7 bbls. 15.8 ppg mud. This will place 5 bbls. cement beneath the retainer. Pick up out of retainer 5 ft. and pump another 11 bbls. of 15.8 ppg mud or until the plug latches in. · ~ -. 13. Pull up slowly 165 ft. and pressure,·uP-'drii! pipe to approximately 2000 psi 13.30 ppf until PlUg ~atcher pins shear. Reverse out. Pull out of ho~e. with drill pipe and lay down 7500' drill pipe and 4-1/8" drill collars. Stand back 2000' of drill Pipe in~.derrick. Note: Begin injecting all waste fluids on location down 9-5/8" x 13-3/8" casing annUlus. Double check all mud tanks, pits, test tanks, waste oil tanks, effluent {anks, and miscellaneous barrels to insure that no potential pollutants are left on location. ' ~ ~ a %" "~ q~ ~'~ ~ % ~ ~a r . .~ ,~% · 14. Run in hole with 3-1/2" 13.30 ppf dril1 p~pe and cast iron bridge plug for 47 ppf, 9-5/8" casing. Set CIBP at 2000 ft. Clean out mud pits. 15. Rig up to pump 139 bb!s. of 10.2 ppg CaC12 solution into 9-5/8" casing by adding 14900 lbs. of High'~TeSt'Fl~ke Calcium Chloride (95% CaC12) to 128 bbls. fresh wa~er. Mix'at approximately 60°F. The freezing point of 10.2 ppg CaCl2 solution is -20°F. If excess CaC12 solution is required to maintain pump suction out of the rig suction pit, mix 116.3 lbs. CaCI2 flake to 1 bbl. fresh water to make 1.09 bbl. of CaCl2 solution. EX ON USA Revision 2 Point Thomson Unit #3 Suspension Procedure Page Three 16. Rig up to displace the Calcium Chloride solution. Pick up out of the CIBP and displace the 15.8 ppg mud into trip tank with 10.2 ppg CaC12.0solution. Inject displaced.mud down annulus. Pull out of hole with 3-1/2" drill pipe keeping the hole full with Calcium Chloride solution. 17. Rig up a suction line from the rig suction tank to the Halliburton annulus injection pump. ThroUghly clean out the rig suction tank and mix according to the attached detailed procedure, the following Arctic Pack solution (premix) at 70°F for bullheading down the 13-3/8" x 9-5/8" annulus. 174 bbls. diesel 11 bbls. water 330 gals, EZ Mu! 10700 lbs. Ge!tone 600 lbs. salt Yields 200 bbls. Arctic Pack (final Volume..) . ' . Cool mixture to 40°F before pumping down annUlus. Test all lines to 5,000 psi and begin pumping ArCtic Pack down annulus at 2 bpm. After the first 10 bbls has been pumped away, begin adding an additional 25 ppb' Geltone to the premix on the fly (4750 lbs. additional total). Pump a total of 200 bbls. Arctic Pack down annulus. Close in the 9-5/8" x 13-3/8" casing annulus and carefully catch all remaining Arctic Pack premix from the Halliburton lines in 55 gallon drums. 18. Trip in hole with drill pipe to 2000 ft. and circulate 10.2 ppg CaC12 heated to 70° to 80°F for two hours and pull out of hole to 100 ft. keeping hole full of 10.2 ppg CaC12. 19. With the open ended drill pipe at 100 ft.'; mix and pump the following cement slurry at 2 bpm. 26 sacks Halliburton Permafrost cement 15.0 ppg slurry with 3.5 gals. mix water per sack 4.4 bbls. cement slurry 0.95 ft3/sk cement yield 2.2 bbls. water for mixing 20. Pull out of hole with drill pipe. EXXO LISA PROPR]ET^RY ' I,,,/%/~,~./11 I./I~tll g tlVi I~11.. Il ilig- Point Thomson Unit #3 Suspension Procedure Page Four 21. Drain the BOP stack and 13'5/8" "B" section and nipple down'the same. Cut off 9-5/8" casing stub with power saw. Run air hose to 40..ft. and blow out CaC12 water. Fill casing with diesel. 22. Install a 13-5/8" flange with 3" bullplugged companion flange assembly as shoWn in the attached sketch. Weld a 'piece of pipe to the top of the flange and weld the following information to the pipe extension. Exxon Company, U.S.A. Exxon No. 3 Point Thomson Unit Sec. 34, T10N, R23E, UM 663' NSL, 662' ~CEL Lat. = 70010'20.456'' Long. = 146°15'10.088'' Approved: Superintendent Approved: ~-~/.~ E~heerin~ Supervisor Approved:-_~ ~illing Engineer JFG: j rh 6-27-79 Attachments UNWEIGHTED BAROID ARCTIC CASING PACK Baroid's Arctic Casing pack is a stable, highly viscous, nonfreezing fluid which is placed between casing strings to prevent casing failures and provide insulation of casing used in wells drilled in permafrost ground. The unique gelling characteristics eXhibit excellent thermal properties. The Baroid Arctic Casing Pack has a low heat transfer co- efficient of approximately 0.1 BTU/hr. per sq. ft. per ft. per degree F at 32°F and remains at about the same value even when heated to 150°F. · Materials needed for 100 barrels of-UnWeighted Baroid Arctic Casing Pack: 107 ~50 lb. bags GELTONE 3 55 gal. drums E Z MUL 300 lbs. Salt 87 bbls. Diesel 5-1/2 bbls. Water Weight of unweighted pack 8.3 lbs./gal. Mixing procedure for Unweighted Baroid Arctic Casing Pack: A.· Formula for 100 barrels of Baroid Arctic Casing Pack (premix): Diesel Water E Z MUL GELTONE Salt 87 barrels 5-1/2 barrels 12.5 ppb. 28.5 ppb. 60 ppb. per barrel of water Weight of unweighted premix 8.2 lbs./gal. Recommended procedure when using rig equipment: lo 2. 3. 4. 5. Clean rig tanks and check for leaks Add water through salt barrel Add diesel Add E Z MUL- agitate pit Add GELTONE ,~.~ EXXON PROPRI AF Y Baroid Arctic Casing Pack Page Two Recommended procedure when using Dowell/Halliburton equipment: le e 3. Clean and check tank for leaks and proper hookup so casing pack can be rolled Mix water and salt through hopper and circu- late in displacement tanks until ready to mix in with diesel Add diesel ~r~- ~ · Add E Z MUL - agitate tank Add GELTONE .~ Note: When using Halliburton equipment, have their operator open jet in mixing hopper bowl~ide~open. When using Dowell equipment, have their operator install the largest jet possible in the hopper mixing bowl, Or arrange to have their three jet bowl on hand. The hopper must have a jet installed or the discharge line will plug up. B. Displacement Procedure At Halliburton/Dowell unit have sufficient GELTONE on hand to add the final 25 ppb to the casing pack. When ready to place the' pack, add on the fly 25 ppb GELT©NE through the hopper located just upstream from pump suction. e Establish pump rate so that the GELTONE can be added evenly. ~o barrels per minute is the recommended pump rate. If a cubic foot per minute counter is not available on the pumping unit, keep a p~p rate/time log so that the proper amount of GELTONE can be added and volumes determined. C. Final formula of Baroid Arctic Casing Pack left in annulus: Diesel Water Salt - EZ MUL GELTONE 87 barrels 5.5 barrels 60 ppb per barrel of water 12.5 ppb 53.5 ppb For the GELTONE to yield sufficiently to suspend the Baroid, it is recommended that the~premix be heated to 70°F while mixing. After the casing pack is premixed, it should be left to cool as much as'possible before being used. (40°F is the optimum temperature). · EXXON. USA PROPR!ETARV Baroid Arctic Casing Pack Page Three An alternate to the above mixing procedure if it is not practical to heat the mixture to 70°F; is to add additional GELTONE to the premix, thus insuring the Baroid is held in suspension. W~atever amount of GELT©~E that is needed shOuld be subtracted from the final,25 pounds of GELTONE. Care · should be used not to overtreat With GELTONE if this procedure is chosen. The GELTONE content can be easily determined by running a modified Methylene Blue test thus making the reconditioning of the casing pack a simple procedure. EXXOIx USA PROPRI POINT THOMSON UNIT NO. 3 SURFACE ABANDONMENT SKETCH 3", 5000 psi Gate Valve 4" to 6" OD line pipe x 10' long Bead Weld Lettering As Follows: EXXON CO. U.S.A. EXXON NO. 3 PT. THO~qSON UNIT SEC. 34, T1ON, R23E, UM 663' NSL, 662' I~J'EL Lat. = 70o10'20.456'' Long. : 146°15'10.088'' n3" companion Flange 13-5/8" 5000 psi Ported Flange 13-5/8" 5000 psi Flange on Existing "A" Section 9-5/8", 47 ppf csg. F3D('ON USA PROPRiETAE ~INT THOMSON UNIT NO. 3.. · J L 18 5/8,, 96.5 ppf, K-55 BTC Conductor 8 81'1' liD - 13 3/8", 72 ppf, L-80, BTc Surface Casing @ 3338' MD ~$ 1/2", 23 ppf, 'RS-90, }I-SFJP Circulating Casing @ +/- 4600' MD 32Ppf Soo-95 BTC to 8180' MD ~ · · . ..' , . -.o .~ . · · .' · . . 5/8", 47 ppf, P-110, BTC Protective ~ 10347' 2 7/8"· 8.7.ppf, ~]-80, PH6 CB Test Tubing ' : .. · · 8 ppg l. lud ~ ......... : ....... ' ................... Otis "K" Landing Nipple @ +/- 12000' MD · . Baker Nodel F-'i Packer @ 13S57' DIL 13872'-13885' DIL: 2 Spf, 180o Phasing Brid~e Plug @ 13,8~S' DIL Baker ~-lodel 'F-1 Packer @ 13891' DIL 1399S'-13925' DIL: 2 spf, 180° Phasing TOC after squeeze ~ 14,024' 7", 35 ppf, P-110, B?C Float Collar @ 14,024' I.'.D 7", 35 ppf, P-110, BTC Production Casin.q @14,114' MD 8 1/2" open hol[? 0 14125' ~ID USA PROPRIETARY X×Ot'.l !JSA ?RO??,I PROPOSED I~ELLBORE SCIIE:.L¥1'IC AFTER SUSPF '<SION POINT THOMSON UNIT NO. 3 Water :~.-.< Diesel cushion to surface k .~1'.~1 ' l~'-i:':i~:j Cement plug from 40' to 100' 18-5/8", 96.4 ppf, K55, BTC Conductor Csg. @ 811' HD (8].1: 15.8 ppg Fresh Water Mud Cast Iron Bridge PlUg @ 2000' Arctic Pack in 9-5/8" x 13-]3/8'' Annulus 13-3/8", 72 ppf, LB0, BTC Surface Csg. @'3338' MD (3293' ?VD) TOC @ 8850 }~ Cement retainer @ 9000' }~ .. 7", 35 ppf, Fi10, BTC Production Csg. Stub @ 9500 l}~ (~ I 5 0 0 : ~ ' ~[ ; 9-5/8", 47 ppf, Soo95, BTC Protective Csg. @ 10347' MD (9680' 'iVD) TOC @ 13664' }~ Perfs from 13272' - 13885' Bridge Plug @ 13858' DIL .. Baker Model F-1 Packer Perfs from ].390S' 13u2_) DIL TOC after squeeze ~ , 35 ppf, PI. lO, BTC, Product]ion C>:g. ~ 14114' }iD (13140' TVD) ' 8-1/2".Open llole TD ~ 14125' MD (1315].' TVI)) SUSPENSION SQUEEZE PROCEDURE POINT THOMSON UNIT NO. 3 This procedure begins after pulling out of the hole test string following Production Test' No. 2. Change top pipe rams to 3-1/2" drill pipe rams. Test doors to 3500 psi. 2. GIH with Halliburton EZ Dril SV cement retainer on 3--]./2" DP and set retainer at 13,850' D!L. Retainer wJ. ll be set in 7", 35 ppf casing. Run Halliburton Latch-in collar four stands above stinger. e After setting retainer at 13,850', establish injectivity into perfs 13,872' - 13,885' DIL using 15.8 ppg mud. Do not exceed 5000 psi. 4. Pull out of. retainer. 5~ Mix 8.1 bbl. of Class "G" cement (15.8 ppg) in recJ..rcu].atin9 blender as follows: 42 sx Class "G" cement (yield 1.08 ft3/sx) 4.5 bbl. (189 gal) fresh water 39.5 lbs. (1.0%) CFR-2 19.7 lbs. (0.5%) Haled 22A 11.8 lbs. (0.3%) HR-7 4 hours 20 minutes thickening, time 6. Pump the above slurry into the workstring as follows: 5 bbl. fresh water 8.1 bbl. cement Insert latch-in wiper plug (top plug) 3 bbl. fresh water 86 bbl. 15.8 ppg mud Stab into retainer 10 bbl. 15.8 ppg mud 7. Squeeze the perforations using the above cement. Do not exceed 5000 psi squeeze pressure. When either a) the plug lands in the plug catcher, or b) the squeeze pressure of 5000 psi is reached, pull out of the retainer and pick up two feet. abov'e J.t. DO NOT SHEAR PLUG CATCHER WI!ILE IN RETAINER. USA PROP - LTJ, UR UbR Suspension Squeeze Procedure Point Thomson Unit No. 3 Page Two After picking up the two feet, pump until the plug ].ands (if necessary) and then pressure up to 2000 psi in the drill pipe to shear the plug catcher. Stop pumping. ~Slowly pull four stands to leave the cement on top of the retainer and to pull the drill pipe clear of the cement. 8, Circulate out and pull out of the hole. Proceed to the Suspension Procedure. RGD: JBW: jrh ' 6-27-79 · USA PROPRiE1rAR¥ 6-22-79 Revision 1 POINT THOMSON UNIT #3 SUSPENSION PROCEDURE This procedure begins after cement squeezing interval. 1. Pull out of the hole with cementing workstring. 2. Nipple down the BOP stack and remove the "C" section. Install an 11" 10M# x 13-5/8" 10M# spacer spool and nipple up BOP stack. Install 3-1/2" drill pipe rams in the bottom preventer, blind rams in the middle preventer, and 7" casing rams in the top preventer. 0 Rig up the test pump and test the bonnets in the stack to 3,500 psi. 4~ Make up a Tri-State 5-3/16" OD Mechanical Cutter on 3-1/2" drill pipe and trip in h01e. Check for pressure in annulus before making casing cut. 5 Cut 7" 32 ppf, Pll0 BTC casing at 9500 ft MD e Slug drill pipe and pull out of hole laying down drill collars and drill pipe. 0 Make up Tri-state or Bowen casing spear and latch into casing. Pick up casing and remove McEvoy casing hanger. Rig up casing crew and tongs. 8~ Retrieve 9500' of 7", 32 ppf, Pll0, BTC casing. Limit tong speed breakout speed to 15 rpm initially and increase speed to a maximum of 25 rpm if no galling is observed. Install thread protectors on casing joints before laying down casing. Rig down casing crew and tongs. Trip in hole with 9-5/8" casing scraper in drill pipe to 9,500 ft. Circulate bottoms up and pull out of hole. 10. Run in hole With Halliburton EZ Dril SV cement retainer for 9-5/8", 47 ppf casing with HOWCO latch-in collar one stand above retainer on 3-1/2", 13.3 ppf drill pipe. Set retainer at 9000 ft. (MD). Pick up out of retainer 5 ft. Oil & Gas I,ons. [,ommissiori .EXXON USA ?NU?NIEIAN¥ 6-22-79 Revision 1 Point Thomson Unit #3 Suspension Procedure ~',~,:.~' :- '~- '~"~ ~: .!i!, i Page Two 11. Mix the followin9 cement slurry in rec~rculat~n~~'~~ ~ ~ ~ ~ as follows: 78 sacks Class "G" cement w/1.0% CFR-2, 0.5% Halad 22A, 0.2% HR-7 15.8 ppg slurry with 5.0 gals. mix water per sack 16.0 bb~s. cement slurry 1.15 ft /sk cement yield 9.3 bbls. water for mixing Thickening Time = 3 hours 50 minutes 12. Pump the following into the workstring at 2 bbls./min. ,16 bbls. cement slurry Insert latch-in wiper plug 50.1 bbls. 15.8 ppg mud 13. Sting into cement retainer with w°rkstring and pump 5.7 bbls. 15.8 ppg mud. This will place 5 bbls. cement beneath the retainer. Pick up out of retainer 5 ft. and pump another 11 bbls. of 15.8 ppg mud or until the plug latches in. 14o Pull up slowly 165 ft. and pressure up drill pipe to approximately 2000 psi until plug catcher pins shear. Reverse out. Note: Begin injecting all waste fluids on location down 9-5/8" x 13-3/8" casing annulus. Double check all mud tanks, pits, test tanks, waste oil tanks, effluent tanks, and miscellaneous barrels to insure that no potential pollutants are left on location. 15. Rig up a suction line from the rig suction tank to the Halliburton annulus injection pump. Throughly clean out the rig suction tank and mix according to the attached detailed procedure, the following Arctic Pack solution (premix) at 70°F for bullheading down the 13-3/8" x 9-5/8" .annulus. 174 bbls. diesel 11 bbls. water 330 gals, EZ Mul 10700 lbs. Geltone 600 lbs. salt 200 bbls. Arctic Pack (final volume) EXXON USA PROPRIEIAI Y 6-22-79 Revision 1 Point Thomson Unit #3 Suspension Procedure ~:~~,~ ~ ......... i~i~!!?!~...~.~ Page Three Cool mixture to 40°F before pumping down all lines to 5,000 psi and begin pump±ng Arct±c Pack down annulus at 2 bpm. After the first 10 bbls. has boon .pumped away, begin adding an add±t±onal 25 ppb Geltone to the premix on the fly (4750 lbs. additional total). Pump total of 200 bbls. Arctic Pack down annulus. Close in the 9-5/8" x 13-3/8" casing annulus and carefully catch all remaining Arct±c Pack prem±x from the Halliburton lines in 55 gallon drums. 16. Circulate 15.8 ppg mud heated to 70° to 80°F for two hours and pull out of hole keeping hole full of 15.8 ppg mud. 17. Run in hole with 3-1/2" 13.30 ppf drill pipe and cast iron bridge plug for 47 ppf, 9-5/8" casing. Set CIBP at 2000 ft. 18. Rig up to pump 139 bbls. of 10.2 ppg CaCl2 solution into 9-5/8" casing by adding 14900 lbs. of High Test Flake Calcium Chloride (95% CaC12) to 128 bbls. fresh water. Mix at approximately 60°F. The freezing point of 10.2 ppg CaC12 Solution is -20°F. If excess CaC12 solution is required to maintain pump suction out of the rig suction pit, mix 116.3 lbs. CaC12 flake to 1 bbl. fresh water to make 1.09 bbl. of CaC12 solution. '19.' Rig up to displace the Calcium Chloride solution. Pick up out of the CIBP and displace the 15.8 ppg mud out of hole with 10.2 ppg CaC12.solution. Pull out of hole to 100 ft. with 3-1/2" drill pipe keeping the hole full with Calcium Chloride solution. 20. With the open ended drill pipe at 100 ft., mix and pump the following cement slurry at 2 bpm. 26 sacks Halliburton Permafrost cement 15.0 ppg slurry with 3.5 gals. mix water per sack 4.4 bbls. cement slurry 0.95 ft3/sk cement yield 2.2 bbls. water for mixing 21. Displace with 11 gallons Calcium Chloride solution at slow rate, the previous cement slurry as a balanced plug. 22. Pull out of hole with drill pipe to 40 ft. and displace Calcium Chloride.solution with approximately 115 gallons diesel. Pull out of hole keeping hole full of diesel. EXXO,N USA PRUPRIk I AK]f' 6-22-79 Revis ion 1 Point Thomson Unit #3 Suspension Procedure ,-,' ,~-.':' ~, ~;' ~ Page Four ~. :' : 23. Drain the :BOP stack and 13-5/8" ":B" section an~ ~~ ~o~ ~e same. ~c~ l~to 9-5/8" casl~g ~it~ 9-5/8" spea~. ~ic~ up to ~elease c~sl~g ~a~ge~ slips ~ lo~e~ 9-5/8" casing ~n~11 c~si~g s~ub ls ~lus~ ~1~ ~l~ge. slips. 24. Install a 18-5/8" flange with 3" bullplugged companion flange assembly as shown in the attached sketch. Weld a piece of pipe to the top of the flange and weld the following information to the pipe extension. Exxon Company, U.S.A. Exxon No. 3 Point Thomson Unit Sec. 34, T10N, R23E, UM 663' NSL, 662' WEL Lat. = 70010'20.456'' Long. = 146°15'10.088'' Approved: Operations Superintehdent JFG:jrh 6-22-79 Attachments Approved: Engineering Supervisor 'Approved: Drilling Engineer UNWEIGHTED BAROID ARCTIC CASING PACK Baroid's Arctic Casing Pack is 'a stable, highly viscous, nonfreezing fluid which is placed between casing strings to prevent casing failures and provide insulation of casing used in wells drilled in permafrost ground. The unique gelling characteristics exhibit excellent thermal properties. The Baroid Arctic Casing Pack has a low heat transfer co- efficient of approximately 0.1 BTU/hr. per sq. ft. per ft. per degree F at 32°F and remains at about the same value even when heated to 150°¥. Materials needed for 100 barrels of Unweighted Baroid Arctic Casing Pack: 107 50 lb. bags GELTONE 3 55 gal. drums E Z MUL 300 lbs. Salt 87 bbls. Diesel 5-1/2 bbls. Water Weight of unweighted pack 8.3 lbs./gal. Mixing procedure for Unweighted Baroid Arctic Casing Pack: · A. Formula for 100 barrels of Baroid Arctic Casing Pack (premix): Diesel Water E Z MUL GELTONE Salt 87 barrels 5-1/2 barrels 12.5 ppb. 28.5 ppb. 60 ppb. per barrel of water Weight of unweighted premix 8.2 lbs./gal. Recommended procedure when using rig equipment: lo Clean rig tanks and check for leaks Add water through salt barrel Add diesel Add E Z MUL - agitate pit Add GELTONE EXXON USA PROPRIETARY Alaska Department of ~nvironmental Conservation Page 2 Cleaning actions undertaken Spill was 100 percent cleaned up with absorbent materials and all contaminated ice and snow was disposed of into plastic bags and placed into steel drums for further disposal via incineration pending approval by the ADEC. Location and method of ultimate disposal of the hazardous substance and contaminated clean-up materials including date of disposal: The contaminated snow, ice, and absorbent materials have been contained with steel barrels and will be ultimately disposed of by incineration pending approval by the DEC. 9~ Actions taken to prevent recurrence of the discharge: The defective by-pass valve will be replaced with a new valve. If you require any additional information, please contact Mr. R. P. Bright of the Exxon Anchorage office at 907/276-4552. Very truly yours, JFG:jrh 240~ B0 cc: Mr. Hoyle Hamilton Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99504 R. K. Riddle 7'i0 1 LISA PROPRIETAR' FINAL WELLBORE SCHEMATIC AFTER SUSPENSION POINT THOMSON UNIT NO. 3 Diesel 10.2 ppg CaC12 Water 15.8 ppg Fresh Water ~d Diesel cushion to surface Cement plug from 40' to 100' 18-5/8", 96.4 ppf, K55, BTC Conductor Csg. @ 811' MD (811' TVD) · · Cast iron Bridge Plug @ 2000' MD --Arctic Casing Pack in 9-5/8" x 13-3/8" Annulus 13-3/8", 72 ppf, LB0, BTC Surface Csg. @ 3338' MD (3298' TVD) · .. Top of Cement @ 8869' MD Baker Cement Retainer @ 9019' MD RGD 7-5-79 7", 35 ppf, Pll0, BTC Production Csg. Stub @ 9502' MD 9-5/8", 47 ppf, Soo95, BTC Protective CSg. @ 10~47' MD (9680' TVD) Top of Cement inside 7" Csg. @ 13,612' MD Top of Cement outside 7" Csg. @ 13,664' MD .. Halliburton Cement Retainer @ 13,847' MD Baker Model F-1 Production Packer @ 13,852' MD .. 13872' - 13885' MD: 2 spf, 180° Cast Iron Bridge Plug @ 13,890' MD Baker Model F-1 Production Packer @ 13,892' MD 13,908' - 13,925' MD: 2 spf, 180° Top of Cement inside 7" csg. @ 14,024' MD (Float Collar) 7", 35 ppf, Pll0, BTC, Production Csg. @ 14,114' MD (13140' TVD) 8-1/2" open hole TD @ 14,125' MD (13,151' TVD) EXXON USA PRO,' STATE OF ALKSKA svB~rr u~ mm~.zcar~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT OF DRILLING AND WORKOVER OPERATIONS APl NU~IERICAL CODE 50-089-20007 1. o,L [],,,LL°'" ?-] o,.,, Wildcat WELL 2. NAME OF OP~TOR 8. UNIT FA~ OR LEASE ~on ~rporation Point Th~on 3. ADdREss OF OPhiR 9 Wg~ NO Pouch ¢~01, ~chorage, Alaska 99502 ~on No. 3 4 LOCA~ON OF WELL Surface: 663' NSL & 662' WEL, Sec. 34, T10N-R23E, UPM, North Slope, Alaska BHL (Proposed): 2160' NSL &1400' WEL, Sec. 35, T10N-R23E, UPM, North Slope, Alaska LEASE DESIGI~IATION AND SEE1 ADL 47559 Surface ADL 47558 BHL IF INDIAk~ ALO'i'~E O~ TI~B~ 10 FLFJ~D ~%ND POOL, OR Wildcat I I SEC, T.. R. M Sec. 35, T10N, 1~ PERMIT NO 78-5 ? G~OL j 13. REPORT TOTAL DEP~rI AT END OF MON~tl. CIiA.NGES IN HOLE SIZE, CASING A~ C~F~TING JOBS INCLCDING DEPTH SET A~ VOL~ USED, P~O~TIONS. ~$TS ~ ~SULTS FISHIN~G JO~ J~K L~ HO~ AND SIDE-~ACKED HOLE AND ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS Cores were cut from 13,655' to 14,014' as follows' Core #1 13,665' - 13,695' Core ~2 13,695' - 13,725' Core #3 13,725' - 13,756' Core #4 13,756' - 13,811' Core #5 13,811' - 13,871' Core #6 13,871' - 13,886' Core ~7 13,886' - 13,894' Core #8 13,894' - 13,955' Core //9 13,955' - 14,014' OnMay 15, 1979 a final total depth of 14,125' MD (13,151' TVD) was reached and the following open hole logs were run: Dual Induction BHC Sonic Formation Density - Compensated Neutron Dipmeter Also 42 sidewall cores were recovered from 90 attempts. Set 7" casing at 14,114' and cemented with 1035 sacks class G cement (16.3 ppg). Had 30%returns while cementing. Drilled out cement inside 7" casing to the float collar at 14,024'. Ran a cement bond log, thermal neutron decay time log and a velocity survey. Perforated 13,908' - 13,927' w/2 spf and set a cement retainer at 13,900'. Prep to block squeeze ttrcoughperforations. · ~i~y ~ o~g ~' ~ ~ - " ~ .... J ............... ~' ' ~'~ Acre~e and Well sm~ ' =T~ ~aluatio~i_~e~ ......... ~a~ J~e 11, 1979 Form No. P--4 l%,~V. 3-1-70 STATE Ot ALASKA OIL AND GAS CONSERVATION COMMll-rEE SUBMIT 1~ 13L~. LICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~'~ N~ER~c*~ CODE 50--089--20007 LEASE DESIGNATION AND ADL 47559 Suriace ADL 47558 BI-IL WILL 2, NAME OF OP~TOR 8. L~'IT FA~ OR LEASE N~E ~on Corporation Point Thorn Unit 3. ADDRESS OF OP~ g WE~ NO Pouch 6601, ~chor~e, Alaska 99502 ~on No. 3 4 LOCA~ON OF 'WFJ~L Surface: 663' NSL & 662' WEL, Sec. 34, T10N-R23E, UPM, North Slope, Alaska BHL (Proposed): 2160' NSL & 1400' WEL, Sec. 35, T10N-R23E, UPM,'North Slope, Alaska 10 FIE~,LD ~_ND PfkqL. OR %VII,DC Wildcat ~l-I SEC. T.. R. M (BO'I'TOM HO Sec. 35, T10N, UPM 12 PERMIT NO 78-5 13. REPORT TOTAL DEPTH A'r END OF MONTH, CHA_NGK$ IN HOLE SIZE, CA~ING AND C~VIF2~TING JOBS INCLUDING DEPTH SET ~ VOL~ USED. P~O~TIONS. ~STS ~ ~SULTS FISHING JO~ JD~K ~ HOLE AND SIDE-~.ACKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ ~0~ CONDITIONS During the month an 8TMa hole was directionally drilled to 13,665' and the mud weight was increased from 14.5 to 15.8 ppg. At the end of the month we are at a measured depth of 13,665' preparing to cut core No. 1. ... . ..... . ~..~ .. CONFIDENI' k oiFan~ 9es ~onserv~tlon ~ommiMee b~the I~ of the suoo~din9 month, u~le~ ~therwis~ 4ir~ted. ~. ~-,-?o STATE ~.. ALASKA SUB~rr n~ mmLICA~'~ OIL AND GAS CONSERVATION CO~I~EE 50-089-20007 j COMM_~ .... - ' I cc,.~x~ ' ~ L~SE DESiG~A~'ON AND S~IAI ~ .... ~ ,- _ MONTHLY REPORT OF DRILLING ~L 47559 S~face AND WORKOVER OPERATIONS ~L 47558 B~ o,~ ~ ~' ~ o,,,, Wildcat WELL W~LL , ,' ~on Corporation ,,, ...... ~ Point ~o~on Unit~' 3. ADDRESS ~OP~R 9 W~ NO I 3 GEOL Pouch 6601~ ~qho~e~ Al~s~ 99502 I ~on ~o. 3 '4' ~CA~O~ O~ W~ ............ ' ~0 r~ ~D P~. OR [ ~Ace' 663' N~ & 66~' ~, ~eo. ~, ~10~-~3~, ~M, . WlldcA¢ ' ~o~¢h ~lope, A~A8~ n s~c. ~.. ~. M (~O~OM ~O~ O~~ CONFER: ~ (~o~se~)' ~0' ~ & lA00' ~ ~eo. 35, -FILF: · 10N-~3~, ~, ~o~¢h ~lope, A1As~ ~eo. 35, ~0~, 78-5 13. REI~ORT TOTAL DIEPTH ATEND OF MONTH, CHA~N'GF~S IN HOLE SIZE, CASING AND C~VIF~NTING JOBSINCLCDING DEPTH SET ~ VOL~ USED. P~O~TIONS, ~TS ~ ~SULTS FISHI~TG JO~ JUnK LN HO~ AND SIDE-~.ACKED HOLE ~D ~NY O~R SIGNIFIC~T ~G~ ~ HO~ CO~ITIONS The open hole logging program was completed with the Dipmeter survey. Then 9-5/8" casing was set at 10,347' and cemented with 2450 sacks cement. Injectivity down the 9-5/8" x 13-3/8" annulus was established by injecting 100 barrels mud at a maximin pressure of 850 psi. A gyro survey was run from 3300' to 10,250'. Drilled new hole to 10,370' and performed a pressure integrity test. Leak off occurred at 12.0 ppg. Squeeze cemented the 9-5/8" casing shoe w/42 barrels cement. On a second pressure integrity test leak off occurred at 17.6 ppg equivalent mud weight. During the month mud weights were increased from 11.1 to 14.5 ppg. At the end of the month we are directionally drilling at 12,236' with an 8~''~. bit a~'~d 14.5 ppg mud. CONFIDENTIAL ,4., he.by ~i~~o.~_ ,- ,~/~ ~ Acreage and Well S~N~ _CX~/.~~~~, ~ ~a]uatio~~er ....... ~ A~ril 12. 1979 ...... ' / /// .... :-- :-::_.._- ...... z ' o,.,........., ,,. ot~d gas [ofllorvotion commiflee by tho 15~ of the succ~iflg mon~, ufll,~ otherwisa directed. l~rm No. P--4 STATE C~ ALASKA OIL AND GAS CONSERVATION COMMII'rEE WJONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Wildcat NAME OF OPEI%ATOR Exxon Corporat ion ADDRESS OF OPEI{ATOR SUBMIT IN DUPLICATE Pouch 6601, Anchorage, Alaska 99502 4. LOCA~ON OF WF.~ Surface: 663' NSL & 662' WEL, Sec. 34, T10N-R23E, UPM, North Slope, Alaska BHL (Proposed)' 2160' NSL & 1400' WEL, Sec. 35, T10N-R23E, UPM, North Slope, Alaska 9 WELL NO E0c~:on No. 3 10. FIELD AND POOL. OR WILDCAT Wildcat n SEC., T., R., M.. (~TTOM HOLE oaJ~rr~ Sec. 35, T10N, UPM ,, 12. PEI{/V~IT l~IO. COlx!I:ER: 78-5 13. REPORT TOTAL DEPTI-I AT END OF MONTH, CHA~NGF, S IN HOLE SIZE. CASING AI~rDCE~iENTING JOBS INCLUDING DEPTH SET ~ VOLLrMES USED. PEI~FOlq. ATIONS.TESTS A/ariD RESULTS FISHING JOB~. JLENK IN HOLE AND SIDE-TRACKED HOLE AND ~NY OT%IER SIGNIFIC2~NT C~GF~ IN HOI~ (NDbrDITIONS. A 12¼" hole was directionally drilled to 10,348' and the following open hole surveys were run: Dual Induction BHC Sonic Formation Density - Compensated Neutron A Formation Density - Compensated Neutron tool was stuck at 10,040', and was successfully recovered from the hole by cutting and stripping over the wireline with the drill pipe. Preparations are now being made to run a dipmeter survey. During the month mud weights were increased from 9.6 to 11.1 ppg. 14. I hereby certi£y~b~ th~//~t~ng is true,~ correct Acre e "' '"' J'' .... 7//~/M~ . _ / /_/ a~ ~ well ~valua~lon ,, , I' ' / [,F /// ~ ' oil ~lfd gas conjervation committee by th, 15Ih of the Jucceeding monm, unle, OtherwiJe directed. Alaska Oil and Gas~Conservation Commission Hoyle H. Hamilton Chairman of CommissionfV~ - Commissioner Harold R. ~wkinS Petroleum Inspector March 12, 1979 Wintess: BOP Test Exxon Co USA Point Thompson Unit No. 3 Sec 35/T10N/R23E/UPM Permit No. 78-5 Mmrc!i_ 7, ~i97~~ -I left Anchorage by Wien Air to Prudhoe at 11:30 AM, arriving at Prudhoe by 1 PM. I went to Point Thompson No. 3 at 2 PM by Seaair motive in a twin otter chartered by Exxon~ Purpose of trip to witness a BOP test to t0~000 PSI~ When I arrived at Point Thompson No. 3 at 2:30 PM, I met J. C~ Walker, Supervisor for Exxon. Nippling up of BOP stack was in progress. Testing of the stack started at 7 PH. The annular preventer was tested first to 3500 PSI, The upper pipe rams, the check valve on kill line, and HCR on choke line was tested to I0,000 PSI. The outside kill valve and outside choke valve was tested next to 10,000 PSI. The inside kill valve with upper pipe rams still closed was tested to 10,000 PSI. The lower pipe rams was tested to 10,000 PSI. The lower Kelly failed to test. Testing was stopped 11:10 PM. The building of the choke manifold was in progress. ~_ar_ch~. 8,~ !9~9 - Weldir~g off. lO,000 PSI Choke manifold in progress. 1i:30 PM- John jackson, Superintendent for Exxon, asked J. C. Walker, Foreman for Exxon to ask me ~if it would be alright to go ahead and drill out the shoe, so that they could test. I told J. C. Walker that I could not allow them to drill out the shoe until the choke mmnifold was completed and tested, J, C~ Walker informed John Jackson of the decision.~ ~rch 9~_:~:9]p - I AM John Jackson ask if I would ok drilling out the float, as this would help them out considerably so they could run a deviation survey while they were working on the manifold. I told them that I would approve drilling out the float only, ~is they did, and run their survey's until 11 At 5 PM the blind rams were tested to 3500 PSI~ this was.done with pressure against 9 5/8 casing. The choke manifold was completed and testing started at 9 PM, ~nere were two supercho~s on manifold that operated freely 180". There was I3~valves and 14 double flanges that tested tol0,000 PSI. There was also one manual choke that operated freely. The last test done was a performance test on accpmulator. The master gauge read 3000 PSI, the manifold pressure was 1500 PSi, the annular preventer was set at 1500 PSI. with the power shut off on accumulator - the two set's of Exxon, Point Thompson unit #3 Permit no. 78-5 2 March 12, 1979 pipe rams and the annular preventer were closed and the HCR valve was opened at one time. The remaining pressure on acc~lator was 1200 PSI and did not drop, The pump~ were turned back on and the pressure rose back to 1400 PSI in 45 seconds. ~is test indicated accumulator and precharge and the pumps were ok, and that there were no leaks in the control system. The well sign was up with all well data ok. The reserve pits were in very good shape. The location in general was clean and free of debris. Also the remote and master controls operated ok. In summary: I witnessed the testing of BOP's and control unit, and. inspection of location, The test's were satisfactory with two exceptions. The lower Kelly failed, and no ball type floor valve on location. These were ordered and ~xon to call our office ~en these valves received and tested. ~'La~¢h~12, 19~.9.- Attachment: Charles Kelly, Assistant Supervisor with Exxon called and lower Kelly and floor valve received and tested ok to 10,000 PSI. Drlg. Permit No. Operator ~__~. ~0~ Satisfactory Type Inspection Yes No Item (,~)~ Location,General () (~) () (~) () () () () () Ai,,~'ka Oil and Gas Conservation Commi%%ee Field Inspection Report Wel 1/Platfm Sec ~_~R RepreSented by Satis'factory Type Inspection Yes No Item ~ BOPE Tests 1. Well Sign (~) ( ) 2. General Housekeeping ~') ( ) 16. ~t f'luid-~)wt~ )mud ( ) oil 3. Reserve Pit-(A)open( )filled (A') ( ) 17. Master Hyd. Control Sys.- psi9 4. Rig ~') ( 18. N~ btls27~O ,~}~,~,~Fzpsig ( ) Safety Valve Tests (A) ( 19 R~mote Contr~l~ 5. Surface-No. Wel~lls (N~ ( 20. ~il.~g ~ol-~"outlets 6. Subsurface-No. ~ (~ (. ,~2.~,~q~~.~}-Check Valve ( ) Well Test Data (~~.~ :~?~$'.:~'~.~:~k~=~',~'~;ne (~ HCR valve ,. 7. W~~~' , (~) ~,~ '~ ?2.3. ChOk~' H. an~,f~.~d No. valvs}~ flQs]K "~(-~ ~ ~'24-Chbkes~ '~R~mote( )~os (~dl 8. Hrs, obse~ 9. BS&W ,~,~', --, (~ V,.)~'~'2~,~ Tes~ ~l~uN.=(~)~'~ellhd( )cs9( )here 10. Gr. Bbls.' ~~' , (~') ~<'~])~ ~2'6~ '~~'~~enter~d~s~g 11. P~--~-~ ~)~"~( )" 28. Pipe Rams~e~ psig 12. Water well-( )capped'( )plugQed (X) ( ) 29. Kelly & Ke~l~ock1~p~ig 13. Clean-up ( ) (X) 30. Lower Kelly valve pslg () () () () () () () () () () () () () () ( ) ( ) 14. Pad' leveled (') (~) 31. Safety Floor valves--~BV (~()Dart Total inspection observation time ~' ~'~/days Total number leaks and/or equip, failures ~7~ Remarks ~ o~/~~ /r~z~ v ~ v~'~ ~ ~ F T~7~ ~}~b ~ ~ ~: ~ v ,'~ Y~K~ - F~z~: ~u~ cc' ~d/?~' ~j.£~/$~ Notify in __~days or when ready Inspected by /~'~A~/x/9 Da te3/,)7/77 E ,(ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION February 15, 1979 Re' Exxon Pt. Thomson Unit Permit No. 78-5 North Slope, Alaska Mr. Blair Wondzell Petroleum Engineer Department o£ Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Wondzell' The revised course which we have pursued following the unanticipated wellbore inclination which developed prior to our having reached our planned directional kick-off point which we discussed with you today is described in the attached Sundry Notice. As stated in our conversation and in the notice the target bottomhole location and horizontal departure for this well wii1 remain unchanged from the previous plans we have filed with you. In addition to the triplicate copies of the notice required to be filed we enclose a fourth and ask that it be returned for our file if you approve the notice. Yours very truly, Robert K. Riddle RKR'et att achment s cc' Mr. R. P. Bright w/attachment Mr. W. M. Selvidge w/attachment A DIVISION OF EXXON CORPORATION Form 10-403 '~ Submit "Intentions" in Triplicate REV. 1-10~73 & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) " ~LF]WELl'AS 0 OTHER Wildcat 2. NAME OF OPERATOR Exxon Corporat ion Alaska 99502 3. ADDRESS OF OPERATOR Pouch 6601, Anchorage, 4. LOCATION OF WELL At surface 663' NSL & 662' WEL, Sec. 34, T10N-R23E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, et~) Approx. 8.6' GL 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-089-2000? 6. LEASE DESIGNATION AND SERIAL NO. ADL 47559 Surface ADL 47558 BHL 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Point Thomson Unit 9. WELL NO. Exxon No. 3 10. FIELD AND ~OL, Od WILDCAT Wildcat ll. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 35, T10N-R23E North Slope, Alaska 12. PERMIT NO. 78-5 )ort, or othe~ii'~a~a~' '' NOTICE OF INTENTION TO=~ TEST WATER SHUT-OFF l------J FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) SUBSEQUENT REPORT OF: PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS FRACTURE TREATMENT iALT'ERING CASING SHOOTING OR ACIDIZI'NG ABANDONMENT* (Other) (NOTE; Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent ~letall$, and give pertinent dates, Including estimated date of starting any proposed work. In the process of drilling the **~z" ~,~ surface hole at Pt. Thomson #3 an unplanned departure from our original plan to drill a "straight" hole to our directional kick-off point developed. A gyroscopic directional survey routinely performed after setting 13-3/8" surface casing verified that a wellbore inclination had developed with the wellbore angle at the casing seat (3338' MD) being 24.8 degrees. A plot of the gyro survey reveals that the actual directional kick-off point on this well was 1800' MD. At the casing seat we calculate that the vertical depth of this well is 3264'. Due directionally beneath the surface casing following course. We calculate that the revised final depth approximately 14,904' MD (13800' TVD). The target and horizontal departure for this well will remain previous plans. to the high wellbore angle, a decision was made to continue to drill a revised wellbore for this well will be bottomhole location un c hang e d~ f. r or~:~, our 16. I hereby certify that the foregoing is t[ue and correct (This space for State offi use) t APPROVED BY CONDITIONS OF ~-PPROVAL, IF ~NY: TITLE Drilling Manager DATE. 2/13/79 TITLE See InStructions On Reverse Side ~ ~°' P-'~ STATE O, AIA3KA OIL AND GAS CONSERVATION COMMITYEE . . ..... AND WO~LKOVER OP~P. AT~O~$ SUBMIT 1~ DIYPLICATE on. [--] G,, ~] ...o.,.~,, Wildcat ~.N~E OF OP~TO~ ~on ~r~rat ion Pouch 6~Q1~, ~cbor~e, Ala~ g~0~ B~ (~o~)' ~160' ~ ~ 1~00' ~, Sec. APl NLrMEPdC~L CODE 50-089-20007 6 LEASE DES:GNATION AND SERIAL NO. ADL 47559 Surface ADL ~7558 BHL 7 IF INDIA~,I', AI.~OTTEZ OR TRIBE NAME 8. L.~IT F.~M OR LEASE N,~ME .~.P~int _Thomson ~Un__it 9 \VELL 10 FI~ &~D POOL, O~ WI~DC~W ii. SEC, T., g., ~'I.. {BO~'OM o~ See. 35, T10N, ~M 1~-. PIgP,.MIT NO 78-5 13.-~EPOR~ 'T~AL DE2~r~I AT END OF MON~I. CHA--%'GES IN HOLE SIZE. CASING A~ C~TINO JOBS INCLUDING DEPTI] SET ~N~ VOL~ US~. P~O~TIONS. ~TS ~ ~SUL~ FISHING OO~, JL~K LN HOLE ~D S1DE-~%C~ HOLE ~n ~Y o~ s~o~c~ ~~ ~ ~o~ co~m~s. Spudded well at 1330 hoars 1-3-79 w/17½" bit. Drilled to 851' and opened hole from 17½" to 22". Set 18-5/8" csg, at 811' and cemented with 1200 s~pe~frost (14.6 ppg) plus 3100 sx permafrost (15,0. ppg). Cement circulated to the surface. Drilled a 17½" hole to 3_~3QQ' and ran the following open hole surveys: Dual Induction BHC Sonic After drilling to 3350', 13-3/8" csg was set at 3338' and cemented with 3000 sx per~frost (14.6 ppg) plus 750 sx permafrost (15.0 ppg). Cement circ~Aated to the surface. A pressure integrity test was performed below the 13-3/8" casing shoe at a drill depth of 3360'. Leak off occurred at 13.6 ppg equivalent mud weight. A gyro survey was run in the 13-3/8" csg and showed the actual directional kick-off point on this well was at 1800'. The bottom hole closure is 264' S84°E at 3300'. At the end of the month we are directionally drilling at a ~asured depth of ~___7~' with a 12~"' bit and 9.6 ppg mud. CONFIL Et, IT!A£ 14 I hereby certify J,k~Ahe ~~t~ true ancL, t~k~rcs~-ct oil ~ gas COnilrvQtion commi~ee byt~e JS~ of Jhe succgdi~g ~n~ u~ltg otherwJsa dirocted, Alas~m Oil & Gas Conservation Commission Hoyle II. Hamilton ~~ Commissioner Chairman~ ~~' ~' Lonnie C. Smith ~ ~ Commissioner Ben LeNorman ~ Petroleum Inspector Janaury 25, 1979'. BOPE Test - Exxon's Pt. Thompson #3 FrJ~..ay.,....Janaury 1.9 - I departed my home at 6:30 AM for a 7:00 AM showup and 8:00 AM departure via Wien fiightt #I for Deadhorse arriving via Fairbanks at I0:30 AM. I was met by an Exxon representative and pro- ceeded to Sea-Airmotive where we departed by twin otter at 11:15 A3~ and arrived at Pt. Thompson #3 at 11:45 AM. Weather: -6°F, light wind, clear skies. After being assigned a room I ~et with Exxon drilling foremen J. C. Walker and B. C. Teer, and Loffland Rig #162 toolpushers Junior Henson and Bennet Smith. Nippling up was in progress. Sa~urday,~ Ja~- An attempt to start testing at 3:30 PM failed when the test pump malfunctioned, l~ile repairs were made I toured the location which was well organized, reserve pit well built, rig in good repair, and the well sign was in place. Shoe on the 13 3/8" was set at 3338', Tests resumed at 7:00 PM with the annular preventer testing to 3500 PSIG. Eight valves and eighteen flanges in the ~oke manifold tested to 5000 PSIG. However, one valve did not test and repairs were initiated. The Swaco superchoke was actuated both fully opened and fully closed and the manual adjustable choke was free moving. Upper pipe rams, outside valve on the choke line and outside wing valve on the kill line then tested to 5000 PSIG. HCR valve in the choke ]ine and inside valve and check valve in the kill line tested to 5000 PSIG. Lower pipe rams then tested to 5000 PSIG. We then tested the accumulator by turning both pumps off and closing the annular preventer ~d both pipe rams and opening the HCR valve simul- taneously. Accumul%or pressure dropped to 1250 PSIG and remained steady. ~I2 backup bottles tested 2400, 2400, 2500, and 2400 PSIG. Due to the stack configuration we tested the blind rams to 3500 PSIG. The pressuring input point was through the side outlet on the 13 3/8' casing head and therefore below the test plug. Sunday,~&qu~2~I- Kelly cock tested to 5000 PSIG. However, the lower kelly valve failed and repairs were initiated. Finally, the repaired lower kelly valve and repaired choke manifold valve tested to 5000 PSIG. Both dart and ball type floor valve were in place. BOPE TEST - F~tXO~' S PT. THOMPSON #3 January 25, 1979 Tests were concluded at 1:30 AM and a field inspection report prepared with a copy given to J.Co Walker, a copy mailed to John Jackson, and the original attached to this report. A full scale blow developed during early morning and the otter was grounded. Deadhorse airport reported below minimums for commercial flights. The weather improved by early evening and I departed Pt. Thompson via twin otter at 8:10 PM arriving in Deadhorse at 8:40 PM. I departed Deadhorse via Wien flight #20 at 9:45 PM arriving in Anchorage via Fairbanks at midnight and at my home at 12:30 AM. In summary: i witnessed successful B.O.P.E. tests on Exxon's Point Thompson #3. BL/LCS: emi Drl g ~.~ Permit Operator Satisfactory Yes (~() (~r() (~- ( ) () () (-) () AI~' .a Oil and Gas Conservation Commit a ' ]"'] Field Inspection Report ~ co-r~.-~ Well/P~m Sec~./.o~.R~, _.~_.M Represented by~.~, ~/~£~ Name & Number/~?. Type Inspection Satisfactory- Type Inspection () () () () () () () () No Item (~f"[ocation,General 1. Well Sign 2. General Housekeeping t. Reserve Pit-( )open( )filled 4. Rig ( ) Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos. , , , 8. Hrs. obser , , 9. BS&W , , 10. Gr. Bbls. ( ) Final Abandonment Yes (~() (-~r' ( ) (~- ( ) () (.~- ( ) (~() (~' ( ) (~' ( ) (~Y() (~)- ( ) No Item (~-)"BOPE Tests 15./~_~Casing set @~:q[~_~:~ ~ 16 T6§L fluid-( )wt~( )mud (~,)~oil 17. Master Hyd. Control Sys.-~JF~psig 18. N2 btls~~~.~,,2~sig 19 Remote Controls 20. Drilling spool-~ "outlets 21. Kill Line-(~C~eck valve 22. Choke Flowline (~,)~'HCR valve 23. Choke Manifold No. valvs~ fl~s/~<~ 24 Chokes-(~fi~emote( )P~s.(~dj' - 25. Test Plue-(~/ilellhd( )csg( )none 26. Annular Preventer.~_~psi~ 27. B1 ind Rams~lI~psie~._$-o~ ( ) ( ) ll. P&A Marker (~)-- ( ) 28. Pipe Rams..~opsiq ~:z) ( ) ( ) 12. Water well-( )capped( )plugged (~)~ ( ) 29. Kelly & Kelly-cock=;~~sig ( ) ( ) 13. Clean-up (~.)~' ( ) 30. Lower Ke_.ll.y,v~tlve.,~]~_Z_psi~ ( ) ( ) 14. Pad leveled (~~ ~, 2~.~f~/a~p~alveT-l~V (~art Total inspection observation time ~ hrs/~ Tota~'~5~e~'t~ak~ and'/6r~6a~.ip, failures ~ Rema r ks ~.~. ~. :- ' ' ' ' "~ cc:~o~ ~~~'Notify. in days or when ready ~i ~~ted b~; 71~.. ...... ~ ~teW~/-~ P,J~. 3-1-70 STATE C ALASKA OIL AND GAS CONSERVATION CON~ITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIOHS , SUBMrI' IN UUPLICATE 2. NA/~le. OF OP~.ATOR EXX~. on Corporation 3. ADDRESS OF OP~TOB Pouch 6601., ..Anchorage Ak. 99502 4. LOCATION OF W Surface: 663' NSL & 662' WEL, Sec. 34, T10N-R23E, UPM, North Slope, Alaska BHL (Proposed): 2160' NSL & 1400' WEL, Sec. 35, TiON-R23E, UPM, North Slope, Alaska ~L 47559 ~face ~_ ~on. No. 3 o~ Sec. 35, T10N, R23E, UPM 12. PER.MIT N'O. _ 78_-5 13.REPORT TOTAL DEiPTH AT END OF MONTI-I. CI-I.~NG~ IN HOLE SIZE. CASING AND C~-"V[F_.,NTING JOBS INCLUDING DEPTH SET A_N'D VOLIJ1VII~ USED. PF_,I:~O~TIONS, TESTS AND RESULTS. FISHING JOBIB. JUNK LN HOLE A, ND SIDE-TFf, ACKED HOLE A.ND ..,~N'y OTHEt~ SIGNIFICAi~I'T C'H~NG~ ~ HOL~ ~3,N'DITIONS. During the month, Loffland Rig 162 was moved from Point Thomson 2 to Point Thcanson 3. At the end of the month rig up is 9~o complete. · .. - , ONFIDENTt I. ,:,.: ! ti!,,,.: 14. I hereby certify_ lJj~atj~e foregoh~ is ~-~e ~ ~ Acreage Well B~aluation _ . - - ~ / ~ .... Mm~~ ....... n.~. 1/23/79 .. NOTE--Report ~this f~rm /' ~' ~' it required for each calendar ~th$ regardless of the *totus of operations, and must ~ ~ied in duplicate wit, the oil an4 gas contervetlon commiffee bl the 15~ of the tucc~ding mon~. unle~ othsrwise directed. l~orm. No. P--4 irt-L~'V. 3-1-70 STATE ALASKA OIL AND GAS CONSERVATION COMMIT-tEE ~O~iT'H£Y ~.PORT OF DI~LLING AND WOP. KOVEP. OPERAT~ON.S I. o.. ~ °"~ '--i Wildcat ~'~;LL ~J wELL ~ 0Tl=l ER 2. NA~E OF OP~:L4~TOR SUBMIT IN DtJ-?LICATI~. API NL~,IERICAL CODE 50-089-20007 ADL 47559 Surface ADL 47558 BHL '~ IF INDIA~ A~'?'~E OR ~IBE NA~E Exxon Corporat ion ADDRESS 0 F' '~'~b~ Pouch 6601, Anchorage, Ak. 99502 ~CA~ON OF WF_J~L Surface: 663' NSL & 662' WEL, Sec. 34, T10N-R23E, UPM, North Slope, Alaska BHL (Proposed): 2160' NSL & 1400' WEL, Sec. 35, T10N-R23E, UPM, North Slope, Alaska Pnint Thomaan Unit 9 WELL .NO /. Exxon No. 3 10 F[FJ~D ZkND P~L. OR WILDCAT · Wildcat , l'i SEC T. R. 5I (BOTTOM IiOLE O~~ Sec. 35, T10N, R23E, UPM 78-5 13.R~--~OR~' TOTAL D]EPi'FH AT E~rD OF MON~"-I-I. CHA~G]E~ IN HOLE SIZE CAS1N~ AD C~,IF~'T!NG JOBSINCLUDING DEPOt S~ ~ VOL~ US~ p~O~TIONS. ~7S -~ ~SUL~ FISHIN'G JO~ JL~K LN HO~ AND SIDE-TRACKED HOLE ~N'D ~N"g O~R SIGNIFIC~T ~G~ ~ ~O~ CONDITIONS During the month, construction of the camp and an ice airstrip were completed at the wellsite. Also in preparation for the rig move an ice road was finished from Point Thomson 2 to Point Thomson 3. CONFIOENTIAL RECEIVED the foregoing xs ~rueand correc~ Acreage & Well Eval- ' ~~~~~~~y~~ ~~--~ uat ion. ___ Manager_ n~ _ 12/13/78 ................ :-~- J m. Files November 30, 1978 John Levorsen~ / At 7:45 ~ ~n 11-28-78, the telephone ans%~g service relayed a n~ssage to me frcm John Jackson, Exxon. At Pt. ~ Unit 93, at 1820 hours 11-28-78, 1 gmllc~ of Arctic diesel fuel spilled at the Southwest corner of the pad in Sec. 34 ~ TION, R23E, ~M. A writbsn report will follow. JoDn Levorsen Petroleum. Geologist Files November 30, 1978 Lonnie C. Smith Chief Petroleum Engineer Day: - Thursday Date: 11/23/78 Ti~e: 09:10 AM ~: Arctic Diesel Fu~l ~: 1/2 ga/l~ ~.~ather: + 5% ~ ~. 22 MP}! En~t: Lt. blc~ing sn~ Visibility: 15 miles Clean-up ~~: ~ie C. Smith Chief Petroleum Eng~ Con--ted snow pid~ed up and placed in plastic bags Bags placed in 55 gallon drum l~rm No. 1'--4 REV, &- I-?0 STATE Or ALASKA OIL AND GAS CONSERVATION COMMI'~EE MONTHLY RE!PORT OF DRILLING AND WORKOVER OPERATIONS NAME OF OpE~ATOR Exxon Corporat io~- Pouch 6601, Anchorage~ Ak. 99502 Surface' 663' NSL & 662' WEL, Sec. 34, T10N-R23E, UPM, North Slope, BHL (Proposed)' Alaska 2160' NSL & 1400' WEL, Sec. T10N-R23E, UPM, North Slope, Alaska 35, Exxon No. 3 i0, FI~-~D POOL. Oil WILDCA Wildcat OBJF~r~ Sec. 35, T10N, ~ 12. pI~IT NO. 78-5 , : CASING AiN-D C~-WIF. NTING JOBS INCLUDING DEPTH '-------- HOLE REPORT TOTAL DEPTI4 AT ~D OF MON~, CRNGES IN HOLE SIZE, SET ~ VOL~ USED, p~O~TIONS. ~TS ~ ~SULTS FISHING JO~ J~K ~ HO~ ~D SIDE-~C~ED ~D ~Y O~ SIGNIFIC~T ~G~ ~ HO~ ~ITIONS. Finished grading and leveling pad and suspended operations October 2, 1978. On October 20, 1978 we started moving the camp and equipment on rolligons /rom Point Thomson No. 2 to Poin~ Thomson No. 3. At months end all of the camp is on location and being assembled together. t. .-- ii that the £oregoin. gistrueamte°rre~ Acreage & Well Eval- _ ~/16/78 02-001B (Rev. 10/76} STATE of ALASKA DEP~ OF NA~3RAL RESOURCES Division of Oil and Gas Conservation To: ~The Files FROM: Petroleum GeologistC~v / / ? DAT~ctober 30, 1978 FILE NO: TELEPHONE NO: SUBJECT]~cxon Pt. Thampson ~3 Surf (34-10-23, UPM) At 2: 30 PM, Saturday, October 28, 1978, Doug Amonson of Exxon reported to the State Division of Oil and Gas Conservation via phone call to William Van Alen that there had been a spill of approximately 1 pint of engine motor oil at the subject well site, Mr. Amonson reported that the spill occurred during the night of October 27-28, 1978 on the frozen surface of the gravel drilling pad. The spill occurred frcm a crankcase oil pan drip in a gin pole truck parked overnight at the drill site. All the spilled oil was in the snow and all the oiled snow was picked up. There was no trace of spilled oil in the underlying gravel; there was 100% recovery of the spill. I thanked Mr. Amonson for reflecting his campany's concern to remedy well site oil spill problems. REV. 8'1-70 STATE Or ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 0IL ~-~ GAS [] OTHER W~iLL WELL Wildcat '~. NAM.~. OF OP~TOR Exxon Co....rporat ion 3. ADDRESS OF OPEI~ATOR Pouch 6601, Anchorage, Alaska 99502 4. ~CA~ON OF W~TJL Surface' 663' NSL & 662' WEL, Sec.. 34, T10N-R23E, UPM, North Slope, Alaska BHL (Proposed)' 2160' NSL & 1400' WEL, Sec.35, T10N-R23E, UPM, North Slope, Alaska Not Available 6 LEASE DESIGAIA*I'ION AND ADL 47559 Surfac,~-~.--~ . ~ L~IT FA~{ OR LEASE N~E Exxon No. 3 . Not Available 13. REPORT TOTAL DI~Pi"I-I AT F2~D OF MON~"~%I. C}IA.\'GI~S IN HOLE SIZE, CASING A~ C~iENTiNG JOBS INCLUDING DE~TH SET A~ VOL~S USED. P~O~TIONS, ~TS ~ ~SULT5 FISHING JO~ JL~qK ~ HO~ AND SIDE-~.ACKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ ~O~ ~ITIONS No operations were performed during August EONFI ENTIAL ,'~,~ ~.~ f .~>. ~-:.i.,~ ii.,h,~ ~n~~~. D i:t. Mgr. A~/Pa6~fic-DiV. sm~ = Ex~loration__P_~t_, ~,~ Sept, 7, 1978 NOTE ~ReDort on this form is required for each COllndar ~nth~ regordle~s of oil and gas conservafion commiHee by fbe 15~ of the su=c~ding month, u~le~ Gtherwi~a ~ir~cted, 1~orm No STATE C'~-<~kLASKA OIL AND GAS CONSE~,: ATION COMMITTEE SUBMIT II~ I~L~LICAT~ · ~ONTH~.Y R~PQRT ;DF DRILLING AND WO~KOVER OP~;RATtON$ o,L ~] o^, [] o~..-R Wildcat WKLL ~W~ZLL NA-~E OF OP~IR3kTOR Exxon Corporat ion Pouch 660~, Anchorage, Alaska 99502 LOCATION OF WELL Surface' 663' NSL & 662' WEL, Sec. 34, T10N-R23E, UPM, North Slope, Alaska BILL (Proposed)' 2160' NSL & 1400' WEL, Sec 35 T10N-R23E, UPM, North Slope, Alaska ADL 47559 Surflac'¢. ADL 47558 BHL [ m mm^~r ,,.~.~zzZ~: point Thomson .... E~xon .~o. 3 Wildcat Sec. 35, 12 PIKI~/[ IT Not Available 13. REPORT TOTAL D]5'~T~{ AT F~ND OF I%ION~t. CHAZ~GES IN HOLE SIZE. CASING A.~D C~ENT!NG JO~S INCLUDING DEPTH SET ~ VOL~ USED P~O~TION'S. ~STS ~ ~SULTS FISHI~G JO~5 JL~K [N HOLE AND $1DE-~%ACKED HOLE ~D ~Y O~R SIGNXFIC~T ~G~ ~ HO~ CONdiTiONS No operations were performed during July 1978. CONFIOENTI/ [ RECEIVED ! 6 Division cf 0il & Gas 14. I herebycer%ify/~hatth%.for~.~gm~/~e ~d ~o~ D i st. Mgr. Ak / Pa c i.f i c sm~ .,_ ~ ~? Z-¢ .~~.~:~ ,~ E~p] nrs_~~~_ .~ ~us~ 16, . NOTE: --Report on this form is required for ~ch calendar ~nth~ regordle~s of the =t~tu~ ~f operatie~, and mu~t b~ flied in duplicate with the 0il a~d go~ conservation commJH~e bythe 15th of l~e suec~ding month, unl~ et~erwit~ ~r~cted. July 13., 1978 Exmm% Cumpany, U.S.A. P. O. Bo~ 2180 ~, Texas 77001 Enclosed is the ~ppro%~d application for ~ ~penni. t to drill the referenosd well at a locatic~ in Section 35, Township 1ON, Range 23E, Many ri~s in Alaska and ~r drainac3e systems have been classified as important for the spm~dng or migration of ~mdrommm fish. Operations in ~hese areas are subj~ to AS 16.50.870 amd the regulaticms prc~ated ~under (Title 5, Ala-aska Administra~ ~). Prior to ~ing operati(x~ you ~ay be ccn~~ by the Mabi~t Coordinator's office, Department of Fish and Game. Pollution of any wa~ of the State is prohibited by AS 46, Chapter 03, Article 7 and ~he regulaticm~ promulgated thereunder (Title 18, Alaska ~istrativ~ Code, ~. 70) and by the Federal ~ter Pollution Oontrol Act, as ~. Prior to ~ing operations you may be con~ by a repz~sentative of the Departrmant of En~tal Cnnservation. ~arsuant to ~ 38.40, Iz~ml Fire Under State Leases, the Alaska Department of Labor is ~~ notified of ~ is~ of this ..permit to drill. To mid us ~ sd%e~kGing field ',,,~:)rk, ~ would appreciate your notifyLng this office wi~_h~ 48 hours afY~er ~ w~l! is ~. I,~e would also like to be ~fied so ~hat a reparative of the Division may be present to witness ~ of bl~ preventer ~pment befc~e surface casing shoe is drilled. C. D. Jones -2- July 13, 1978 Ln ~ event of suspensic~ or aban~t please give this office adequate ~ ~fica~c~ ~ that we may h~e a witness present. Very truly ~, Alaska Oil and C~s Co~u.~_rwtic~ C~ttee Enclosure Departm~r~ of Fish and ~, ~a_bitat Section w/o encl. De~t of En'~ir~tal ~atics% w/o encl. Department of ~, Supervisor, ~ Law Compliance Division w/o er~l. Form SA-06 .",-' ' -to Div. of' oil& Gas 'DATE 7/6...~8 ~ Attn: t~'o Kuqler .................................................................................................................................................................................. J'-UL'""-"" 1978 ................................................................................................................................................................................................................................ 1. KEEP YELLOW COPY° 2. SEND WHITE AND PINK COPIES WITH CARBON INTACT. 1. WRITE REPLY. 2. DETACH STUB, KEEP PINK COPY. RETURN WHITE COPY TO SENDER. March 9, 1978 Exxon Company, U.S.A. Pouch 6601 Anchorage, Ak. 99502 Re: LO/NS 78-6 Pt. Thompson #3 ATTN: Robert K. Riddle Dear Mr. Riddle: The above referenced lease operation Is hereby approved, subject to the following stipulations: · 3~ me Utilize material from the same source as Exxon's Unit No. 2 following the same stipulations regarding the taking of material only from unvegetated gravel bars without creating berms or potholes which could entrap fish, etc. Evaluate ~he material in the lagoon system, in Section 3, near the proposed well site and solicit input from NOAA regarding the advisability of such a source since the use of gravel from coastal spits and beaches is discouraged. The fuel storage pit area must have a minimum volume of 115% of the fuel tankage volume and the plastic lining in the fuel storage area must be maintained throughout its use to prevent any fuel spilled in the fuel storage area re:st b: ma!nt:Ir,~ %~ ..... '~ .... use to pre. v~t ~ y fu:! cp~ll~ ~- ~h~ .~,.~ s~ragc ar~ from leaking out. Applications for s~wa~, solid waste, and air permits must be submitted to A.D.E.C. c .~ 5. A.D.E.C. would like the opportunity to review and comment on ' ~ a Spill Control and Counter measures (SPCC) plan prior to the issuance of_ a_~perm! t to_dri 11. .................................. -- proposed gravel~.:~'~O e .feel that,the. aha reco~ena using an ice Page 2 Marth 9, 1978 7~ A completion report shall be submitted within 15 days upon termination of permit activities. This report shall contain the following information: A. Actual routes of travel and actual locations of all camps depicted on a USGS topo map. B. All additions to original application. C. Statement of cleanup activities. D. Time spent in each campsite. E. ~ethods of disposal of garbage and other camp debris. This recommendation does not include authorization for water use for domestic or ice road construction purpose~. A request for such authorization should be sent to the Northcentral District Office, Division of Land and Water ~nagement, 4420 Airport Way, Fairbanks, Alaska 99701, Attention: Mr. William Cop,land. Such a request should include a map showing proposed water take points and access and a statement of the quantity of water needed for each purpose. If water will be required for more than 120 days, it will be necessary to submit a water use permit application. Sincerely, Ethel H. Nelson Land Management Officer EHN'p1 lmon-~ No, STATE OF ALASKA SUBMIT EN DU?LICATE APl NIiA.~[ERICA/. CODE Not Available LEASE DESIGNATION AND SERIAL NO OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS o,L [] oA. [] oT... Wildcat ~J:LL NAME OF OPERATOR Exxon Corporation 3. AD~ESS OF O~ERATOR Pouch 6601, Anchorage, Alaska 99502 4 LOCATION OF WELL Surface: 663' NSL & 622' WEL, Sec. 34, TlON-R23E, UPM, North Slope, Alaska BHL (Proposed)- 2160' NSL & 1400' WEL, Sec. 35, ADL 47559 SurfactqEC~lVED ADL 47558 BHI~NsHO~E OlST. OmCE 7 IF INDiA~ ALOTT'EE OR TRIBE NAME JUL ~ ]qTr-,, 8. L~IT FARJ¢I OR LEASE NAME ,t~ -- Point Thomsomo~d~i~ATION DIVISION ~ w~ ~'o U.S. GEOLOGICAL SURVEY Exxon No. 3 ANCHORAGE, A~SKA 10 F~D ~D P~L, O~ WILDCAW Wildcat SEC . T.. R.. M. (Ilo'FrOM HOLE OB,mCT~ Sec. 35, TION, R23E, UPM TlON-R23E, UPM, North Slope, Alaska Not Avail.able REPORT TOTAL DEPTH AT ~D OF MON~. CH&NG~ IN HOLE SIZE, CASING A~ C~F~TING JOBS INCLUDING DEPTH SET A~ VOL~ USED, P~ORATIONS. ~TS ~ F~SULTS FISHING JO~S JL~K ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS No operations were performed during June 1978. "i gONFIBENT!AL RECEIVED ..: 5t9/8 Division c,f Oil & Gas C~h~'vatlon . 14. I hereby =rtii¥ that the foregoing is ta-ue and eon-ec% JJl st. Mgr. Ottshore/Ak S~G~~~¢ _ Rod. L. Boane TIT~ E~xploration Depar~_me.n_~t_ ~D~, ~ July 5. ]978 NOTE --Report on~l~l~ss'f~'mli~required for each calender month% regordle,s ef the stagu$ of operations, and must I~ filed 'in duplicate with tho oil and gas conservation committee bythe 15th of the suoceedifl9 month, u~lel~ ~fherwise d~r4cted. RE~. ~- I-?0 STATE OF ALASKA SUBMIT IN I)UPLICATlg OIL AND GAS CONSERVATION COMMII-rEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. o~L,,~,~ ~ °"~,~.. [] o..~, Wildcat 2. NAME OF OPEI:L~TOR Exxon Corporati on 3. ADD~_~S$ OF O~'F_~TOa ................ Pouch 6601, Anchorage, Alaska 99502 -~i LOCA~O~ OF Surface- 663' NSL & 622' WEL, Sec. 34, T10N-R23E, UPM, North Slope, Alaska BHL (Proposed)- 2160' NSL & 1400' WEL, Sec. 35, T10N-R23E, UPM, North Slope, Alaska r5 API N~iERICA3~ CODE Not Available ADL 47559 Surface ADL 47558 BHL 8. 'L~IT FA~ OR LEASE I ~E Point Thomson knit 9 WE~ ~O lO F~ ~ND P~L OH ;Ii'~DCAT, o~~ Sec. 35, T10N, R23E, Not Available REPOI~ 'TOTAL DEI~'IW~I AT END OF MONTH. CPIA]'qGES IN HOLE SIZE, CASING A~ C~TING JOBS INCLL'DING DEPTH SET ~ VOL~ USED. P~O~TIO~S. ~2TS ~ ~SULTS FISHING JO~q JI'JK ~ HOLE AND SIDE-~.ACKED HOLE ~D ~Y OMa SIGNIFIC~T ~G~ m HO~ CO~!TIONS No operations were performed during May 1978. CONFIDENTIAL RECEIVED JUN 2 2 t9t8 ~ivision o! Oil & Gas Conservation l,.Ihe~eb, ce~ti£yt~att'heforegoingts,ruee_,%dc~rz%~-~ Dist. Mgr. 0ffshor~/~.' sm~'Rc4/i~:~-b,, ,q9d ~ ,~ogge =~ Explora}iga.~Q~r]ment .~ _,June 22, 1978 .... ~c-.. '1 ' ~_ i i ....... , NOTE--Report off this fGr~ is~equired (~ eoch Calendar ~nth~ regardless of the tt~tus of operations, and mu~t ~ filed in duplicate with tho oil and gas conservation commiffee by the 15~ of the suec~Oing mon~, uflle~ otherwise COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DiViSiON R, L 8OANE DISTRICT MANAGER May 31, 1978 Re' Exxon No. 3 Point Thomson Unit LO/NS 78-6 Mr. O. K. Gilbreth Director, Division of Conservation Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Gilbreth' Form 10-403, Sundry Notice, advising of the change in surface location of the subject well and a copy of the plat of survey of such revised location are enclosed in triplicate. RLB'RKR'et Yours very truly, Rod L. Boane attachments xc' W. Copeland w/plat of survey only J. S. Grundy w/plat of survey only D. Lowery w/plat of survey only A DIVISION OF EXXON CORPORATION Form 10-403 REV,, 1o10-73 ...... Submit "Intentions" In Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not us~ this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for $ucll proposals.) WELL L.-J OTHER 2. NAME OF OPERA*TOR E~con Corporation 3. ADDRESS OF OPERATOR Pouch 6601, Anchorage, Alaska 99502 ¢. LOCATION OF WELL At~,ce 660' NSL & 711' WEL Sec 34, T1ON - R23E UPM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) ~oprox. 8.6' ]4. Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING L.~ FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) AP! NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. ADL 47559 Surface ADL 47558 B~L 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Point Thomson Unit 9. WELL NO. Exxon No. 3 10. FIELD AND POOL, OR WILDCAT Wildcat ll. SEC., T., R., M., (BOTTOM HOLE OBJECT!VE) Sec. 35, T1ON - R23E, UPM North Slope, Alaska 12. PERMIT NO. ~ort, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF [~ REPAIRING WELL FRACTURE TREATMENTH ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all 13erttnent details, and give pertinent dates, Including estimated date of starting any proposed worK. Per attached plat of survey the surface location was revised 2-13-1978 to the coordinates stated in 4. above. The bottom hole location remains the sa~e as stated in 10-401 filed January 12, 1978. hereby certify that~the fore$olng is truce an? correct ~IGNED' /~ /", ~' ~']~ . __ TITLE District ~]oration M~. OAT~ .Mny R1 197R (This space/or State o~'flce u~a) ~ON~I~ION~ O~ APP~QVAk, I~ ANY: See Instructions On Reverse Side DATE ~ /~- / 7.~i .... Approved Copy Returnod 2~ ~2 2~ 2O 24 29 2g 27 ~:~1. Thomson 19 Isla 25 30 AS STAKED -,~EXXON No 3 POINT THOMSON UNIT LONG.=I46©t5 t0.088" X= 468,591.51 '"" " SCALE I":: ! MiLE ::,,-:.,!,- .. CERTIFICATE OF SURVEYOR ~-~!~-: hereby certify that iam properly recj]stered end licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me or under my supervision, and that alt dimensions and other details are correct. Date Surveyor REVISED SURFACE LOCATION i i i II I I I I I fl I ! l lj III I I 2 ~ I~-- 1978 R.H,M. NOTE_: LOC. IS 8.6' ABOVE LAGOON & OCEAN ICE AS STAKED EXXON No,:3 POINT THOMSON UNIT Located in SE /4 PROTRACTED SEC. 34LT: ION,.~R 2:5 ~E_~L~_UM__tAT MERIDIAN A_~K. Surveyed for ';EXXON COMPANY U.S.A. Surveyed by F.M. LINDSEY 8~ ASSOC. LAN[) ~ HYDR©GRAPHIC SURVEYORS 250~ West Northern Lights BoulevQrd Box 4-081 Anchorage Alask~ I I I I I II I II I fl I i I lt.~"V. STATE OF ALASKA OIL AND OAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS r~:A~x'~m~{~:mcAL CODE Not Available LF-~ASE DESIG~A~O~ AND S~IAL NO AD[ 47559 Surface ADk 47558 BHk 1. ? IF INDIAIq[ ALOT-I--F,E OR TRIBE o,~,~ ~ o~,,,~ ~ o,.,, Wildcat ~. N~E OF OP~TOR 8. L~IT FA~ OR LEASE N~E Exxon Corporation Point Thomson Unit Pouch 6601, Anchorage.., Al_aska 99502 4 LOCATION (>F WELL . Surface. 663' NSk & 622' WEk, Sec. 34, T]0N-R23E, UPM, North Slope, Alaska BHL (Proposed)- 2160' NSL & 1400' WEL, Sec. 35, TlON-R23E, UPM, North Slope, Alaska Exxon No. 3 lO F~LD Y~ND PCK'-)L. OR WILDCAT! '2 (~) (.' Wildcat 11 sEC, T., R., M. (BOTTOM HOLE OBJEC~rvE) Sec. 35, T1ON, R23E, .UPM ::~'' 12. PI:IPdVIIT NO Not Available 13. RE, I~ORT TOTAL DE~T"x-I AT E/X:D OF MON'I/-I. CHA2'qG~ IN HOLE SIZE, CASING A~ C~TVIEN'TING JOBS INCLUDING DEPTH SET ~ VOLI3/VIES USED. PFa~I~"ORATIONS, 'Tm"~TS ~ IRESULTS FISHING JO}3,$ JLrN'K ~ HaLlE AND $IDE-~.ACKED HOLE A/¥D A_NY OTH]~R SIGNIFICAJ%IT C'f-I.A/~F~S IAI HOI_~ CONDITIONS Moved out equipment, temporary camp and cleaned up location during April 1978. CONFIBENTIAL ,'~, ~,$~h, rXo="*om*~"~~ ...... ul§t.rqg~:: Off-shore~Ak': .................... ~m~~:/~'~'///~~.d L~. Boan~: Exploration Department ,~ May 5~ 1978 iii, q ,l,i ' i',l,, Il ...... I ~. -' - illii ill NOTE--Report on this form is required for each colendQr ~ntht regardless of the Ita?us of o.erotiofls, and must ~ tiled in duplicate with t~e oil and gas conlervatlon commiffee by the 15~ of the IuccNding mon~, u~le~ otherwise directad. Form l~b. P--4 l~,g'd'. ~- 1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS o,L ~ o,e ~ cT,,-, Wildcat W~;LL WELL 34, TlON-R23E, 2. NAME OF OPIgRATOR Exxon Corporation 3. ADDRESS OF OPE~,~TOR Pouch 6601, Anchorage, Alaska 99502 4 ~OCAT~ON OF w~ Surface' 663' NSL & 622' WEt, Sec. UPM, North Slope, Alaska SUBMTT IN DLLPLICAT~ Am N~{smcAn ~oPf Not Available LF_,ASE DESIGI~ATTON AND SEIRIAL '.;NO. ADL 47559 Surface ADL 47558 BHL BHL (Proposed)' 21 60' NSL & 1400' WEL, Sec. 35, TlON-R23E, UPM, North Slope, Alaska ? IF II~DIA]~ ALe7 tEE Olq TRIBE NAME . , ,~,~,_~, _ 8 L,~IT FARMI OR LEASE NA.ME . Point Thomson Unit 9 W~LL NO Exxon No. 3 10 FL]g, LD ;~--YD PCkOL OR XVI].DCAT .__ Wildcat 11 SEC T.R. M ~OSUTOMHOLE ": Sec. 35, T10N, R23E, UPM 12 PI~-M IT Not Available 13. REPORT TOTAL DEPTH AT END OF MONTH. CHA~NGIgS IN HOLE SIZE, CASING AND C]~ViF~'qTING JOBS INCLL'DING DEPTH SET ~ VOL~ USED PERFORATIONS, TESTS Aa'NrD R]gSULTS FISHING JO}~4~ JL~fqK LN HC)~ AND SIDE-~ACKED HOLE AND ~Y O~R SIGNIFIC~T ~G~ ~ HO~ CO~ITIONS No operations were performed during March 1978. CONFIDENTIAL RECEIVED ,,.i~,~ . .~,~,~,~o=~-~ Dist: Mgr. Offshore/Ak. Div. sm~mu [,.~ ~oane ~TUS ExD1 orati_o~. Department D~ _ 4/17/7g NOTE--Report on this form is required for each calendar ~nth~ regardless of the status of operations, amd must ~ filed in duplicate with the oil and gas conservation commiffee by the 15~ of the $ucc~diflg mon~, unle~ otherwise directed. 2ECEIVED £[vi.~n c.~ Oil & Gas ! POUC~ 0 -. JZb¥~_A~/99~11 April 3, 1978 CERTIFIED ~tAIL RETURN RECEIPT REQUESTED Mr. Crandall D. Jones, Manager Exxon Company, U.S.A. Pouch 6001 Bmchorage, Alaska 99502 Dear Mr. Jones: of Environmental Conservation has completed its e~at.uatio~' (~l The Department of your Waste Disposal Pern~t application for the discharge of treated 'r~ the lands or waters of the State from wastewater treat-~ ~/[C~'~"__ liquid waste to sent facilities serving an exploratory drilling operation and is issuing\. the enclosed permit in accordance with AS 46.03.100-110 and 18 AAC 70. Please review the conditions and stipulations in the permit and insure they are all understood. If you disagree with any portion of the permit, you may request an adjudicatory hearing by filing a statement of issues under AS 44.62.370 within thirty (30) days of receipt of this letter. The statement of issues should be mailed to the Alaska Department of Environmental Conservation, Pouch O, Juneau, Alaska 99811, or delivered to our office at 3220 Hospital Drive, Juneau. The filing of a statement of issues entitles you to an adjudicatory hearing to contest the permit. Failure to file a statement of issues within thirty (30) days of receipt of this letter shall constitute a waiver of your right to judicial review of these permits. Enclosure ., cc: EPA, Alaska Operations Office (w/enCls) '1 Div. of Oil and Gas. ~O. K. Gilbreth NRO, Doug Lo;~y (w/encls) STATE OF AnAS~A DEPARTMENT OF ENVIRONMENTAL CONSERVATION. POUCH O JUNEAU, ALASKA 99811 WASTE DISPOSAL PERMIT No. WPC 78- 3 Date April 3, 1978 This waste disposal permit is issued to Exxon Company, U.S.A., Pouch 6001, Anchorage, Alaska 99502 for the discharge of treated liquid waste to the land or waters of the state from a wastewater treatment facility serving an exploratory drilling operation. The operation, identified as~ P.~_9_oint Thompson Unit, is located at Section 35, Township iON, Range 23E, Umiat Meridian, A.D.L. 47558, North Slope; Alaska. This permit is issued under provisions of Alaska Statutes AS 46.02.100-].10, Water, Air and Environmental Conservation, the Alaska Administrative Code as amended or revised, and other applicable State laws and regulations. This permit is effective upon issuance and expires March 1, 1983. It may be -terminated or modified in accordance with AS 46.03.120. During tl~e period beg.inni,:',.g o=~ t,t~e effective dale of this perp..it and lastir:g tl~rough the e:<~irv_tion d?_te or ter~d.n'atio~ date, the pe~mittee is authorized to discha~'~o= treated wastewo, tcr effluent as specified in this section- - ' . The treated liquid waste discharge shall nc>'~_ e>:ceed the fo!!o,:eing lim'ltations ' E f f ].u en t Th ir fy-d ny N'a >:i mum · Ch a t' ac ~e r is tic Ava :ag_e~ _ V_~2_!33~2 ..... Total Flow Biod~en:ical Oxygen Pe~,~.a:_~d (SODS) Suspended So-Lids (SS) . e~ .... Coliform Bacteria' 7000 gpd 30 nS/! 60 30 ~.',.g / 1 60 200/!00 400/_1 O0 ~.:l . The total chlorine residual ~n the effJue:~.t alto:: at least 30 minutes contact time shall ~.at be m.o~a ti~n 2 n:S/1 at at~y time. The dissolved oxygen in the effluep, t shall not b.-". less ti:an 2 ma/t- . . o . The pH of the effluent shall be batwen 6.0 and 9.0 pN t~ui. ts or within 0 5 unit of the oH of the ~-ow weber slopply. . There sh~ll be no disch~_rge o~ floating solids or ~.oa in -other than trace~mo,.t:_=s~ , ~ or o~'ly'washas wh:ict~ produce a sheen on the surface of the recelvit~g wa~ers- Sludge from the wastews_te: treatment facility shall not discharged to the waters of the state. The method o~ dispo~a! of sludge shall be by incineratiou~ unless an alternative disposal method is approvei in writing by tl~e. depacti~,ent. . No untreated domestic waste::ateu s!~a]_t be discharged to the lands or waters of the state unless o~her,-.-:'i.':e ~tpproved_ B. 1 }[n~·i,~ori~,c' of Effluent - __ _'_~ - ~ _ __-- ....... tC~ ....................... Tt~e perm'.ittee shall mo~,itor ,~},e v'~s~o:.:a~c-'r stt-c'am i',,. the followino manner a~,d frequency: ~'~;~:'~:~"'<~' -, is occucri, nS ' -~..~ ~...-:tter Ci~arac [e r i~:t Lc Flin;[ mum Sa'.'..,,] Et Biochemical De.and (5-Dh)') least dr:ring 1.2 hoL per Total Flow daily Suspended Solids mort t:h ly composite of least 4 grab~ during ]_2 hot pc r.;.od pH ' d a-L ly [4 cub Toca! Ch!ocine da[_Iy Residual Dissolved0_.;.'-' .... &._p,-~. Fecal Co!'lfo:-m moa t'.h ty g'r . . . _ Samo!es and measurements taken as required ]-.,ere-l.p. sb.a!], be representative of the volu~e, and nature of_' the monitored discharge. The permittae .%l~all submit a brief de;4cription of compositing methods including> but not !4mited to, of samplLng and measuL:e;..nent points. If the perm-ltee monitors any inf!uent or eff-.l_ue;nt characte~.lstic identified ip. this pe~-eit more frequently than requiced~ the results of such monitoring shall be reported to tl~e Depa~-tme.'~t in the monthly monitoring report required under paragraph of t]~is permit. r[onAtoring results obtai,nee dur'in~ the prc"viou~; ~:'.onth shall bc summarized and rep'o~-ted to t~e ~,~p~t~an~ and .postmarked no later than the 14ti~ day of the ~o2_t!t fo]towit~g tt,e co:ppleted repo.~tin~,o period i'[onitorin~C~ snail b__o.~n na tt~c: con-.mc~nceme~t c~ d4scl~ar~;c. Sigued copies of [i've .... , and a_c . ot.l~?r reports required here:i.n, si~al_l be s~bmitted to the DeparCrtc~;-~t al tt~e followino ¢~d,,ress Alaska Dapaz-tmoat of Env:ivoiti::enLal ~ P O. I-;o:< 16Ol ~ Fairbanks, Alaska 99707 phone- (90?) . such report may rest~lc in the inposhhl, oa of' c[imhnal penal_~lles as provided for under AS 46.03_790. Test Procedures Test procedures for the analysis to meti~ods cited ........ '~,t !8 AAC 70 020{c), o~ an. ~uc~ r~.~l.~.~tionso may be amended_ ' The perm[tree may s~bstitute alcerna~i~:e n:ethcls of monitoring or aua!ysis upon race.[pt of prior w~:l~tt:ea approval fro,n t~e Records Retention All recoL-cls and infoc.>:taLion z-asu!~[~ activities required'D}' tltis pc C~n'U' C of analyses parlor~-' instuumau~ation~ shall be r~.~taLuad i~ Alas~-:a fr~c by the Department for three }'ears_ such records. C. AI)iilNI ST[O\TiVE P-. EQU ! U. E}{E,}~T S Al! discka-ugas authorized haraip, shall be co:{s:lstant the terms and conditions-of this p=C,,,L~ Th~: (lischc,~ge of amy pollutant identified in this palm/t, o~: toxic material~ includina oit~_ gr~as~__ ~, oF sc=va .... , [nora freque~tiy., tlta~, ou at a concentration or limit not authosized shall constLtute noncompliance with the peak. it_ Any anticipated facility expansion~ production incrasse~ or p~ocess modification which will result in new~ 'die=~erenu,~ or iac'reasr~,q._ _ discharge of pollutants must be re)ouaed by subtn[_ssie:~ of -a new disposal permit appl. ication~ or if such c~an[les will ~o~ a~fcch the ability o~ the permA,tee to ce~nply w.{.u[t the effluent limitations specified in this perni,t, by wuith(,n noir[ce to the Department at the address sv~ecl{ied in p:~NztSrapl~ ].%-4. at least 30 days prior to the i;~p!c{,-ta~ttm.~lor: o.[ st~.cl~ char~ges. To×ic Pollutants .. If a to::ic po!lutant, i_qc]_ucl~n~ ~ ;~iC 70 for a pollutant such standard is more stL-inscnt ~ ,-:..:: Fer:::i t No. I.;I'C 78--3 The permittee slip_I_]_ provide protection from acc~d~:ntal discharges not in compliance w'~th t.l~e provisions of this per~Lt- Facilities to prevent, such.discl~ar:gas shall be maintained in good working cono~ions aP alt_ times by the a. If for any reason the perm!tcee do.~ "not con, ply with or will be unable to como;v w/th a~ ~":~a!u-eat 1. imit.ations specigied in this permit, the pe~ittee s]~alt report noncompliance to the Dzpartc. ant wi. th:~ 24 houcs of beco;uing awace of such coudi~ioa by t'elepi~one, Le].eg'uapb, or in tt~e absence of both, by mai!_ b , A written follow-up report shT!l be se~:t to the Depa?:tment report sha]_] contain bL~t not be ].imitc, d to' (i) times and dates on wh£ch not coquetted, t~a a:i[-ic::[pated r.:[_~ ti~a nonco:aptL~.ace is expected to contim~e; (2) a detailed descc lptio?, of the erect:, :l~tcludi. ng~ qi~antities and types of materials :involved; -.- (3) details of an}' damage to the rec'.eiv.i~.~Z en'ziro:'~,?.eat; · (4) details of actions takan oc to t')a taken to cor~-ect the causes of thc event, j and (5) details of actions ~a..-~ca o~ to be taken to correct any damage resulting froa~ the ave~It. It is recognized that inf!ueat qna]..l~y changes~ equipment malfunctions, or uncontrollable circ~,ms;tances may ~'m~ result in effluent conceut-~ations exceed': c~ the permit limi. tations, des2Lte the exercise of all possible care and mainte~aace measmces gad correc~'[ve massacres by the permittce. The permltcca may demonstrate to ~he Papartmeat ~hat such circu:2stances exist in any case where effluent concentrations exceed those set fo,rah in tl~is permit. The Co;aTissioner shall cons[dec such showinS in datern'ln[nS ccrnlt violations a~d .fo;: enforcement purpones. The Dapa~tma~ do-as not w;ti_ve any of its less]. rig]~ts during Such cens[derat~on- !']' ;('i':' '"'~''~ '?"~5] Adverse Impact '~'~ ~:-~O'Tf;, The pex'mitree shall t .... e all noccssa'uy t_~ any adverse impact to thc receiv[:iS water's o~ ].ailds res~].~.irig ~.'~':,?'%~"[fu'}~. rf O? ?: .... from noncomnJ_iance, with any li~r, itatio:~s spec-[_lied in tJl'[~;. ..... ta~ (k,~!4o~v:~;?pern~it, including such adct/t.i, onal monftorinZ as ;~cass:ciry to decermip, e the nature.an~.__ in;)act. . of t.i~e r:o~cotxp]ying dischau~,~,;'._ The per~ittee is reqt~iued tt~e event of any advec~-e . Chan.qa of location ]). Prior to co~a;:ancit:g a discharge to the waLers ou ].anJs of the S~ata, eithe~ in the first location afc.r~- th.is p~.~rm'it is issued, er in any subseqttent re].ocati, ons of ti~e drill rig, the permittee s!ta!! sub]ni.[ a plan. for app,:oval to the Sttperviso~- of the Department's R~40,-,.,1 0ffqce in wl~:lch tt~a o~eratioa is located. The pa~-mitte~ shall obtain puioz- approval fuo~a the Region~.l Oft;ice ..... be~o:e dfoz~a~-g ,~,-~=, anv~ s;te. If the ~, _ ~eoional Office (loa~; not app?ova the site operation under this permit, the pezrni, tcee~ ntt~nt obtain appropriate amead~ent to this oar,ntt pur:st~:z~t to 1S AAC t5.'l_00(d). G EN E RAI, 1. _~_? ....... -- ....... ~ ~, · ;, . : The De,mitten shall allow the CoT~2lssio~zar or t~[~-: a,~tl~o~:ized representative, upon presentation of credent-ia]s, to ente~ upon the -~m-r ~ ' ' collection or Cceatnent works az'e ].oc:zttec! at stroh times and upo~ such te~ms gts the Depa~-~t'0. anc m~_y rea,3on:~1)!y require, and at reasonable times, to have c_.- ....to and to be allowed to copy ~_ny records required to be kept: under kite and conditions of this per~i*-~ to in:<,i-,acm a~v, mo~lt-oL-ing equipment or mon/tor:~.~.o met~od requested_, in ti~is and to take any sa~.p]~s neca-¢'',~- __ s. ....y [o the c:n[orcecn-~.~tt of ti{is permit. . In the event of any change in co.nt[o! or o--...?.n.c'r~;hip o[ facil, itie3 from which the authorized discharges e._:~a:~atc~-, the p¢:[mithea shall notify the succeeding o.-..~nar or c.ont,:ol.]_e~ of the ex-lr<tence of this pa[mit by ].ette~, a cop}; of wlt.lc~, ~-;ha].l be zf.>~.wa~ded to the Co~.mtissioner. . A~ai]abilit¥ of Recor-'ds Except for inforrn*,t~on re~in,g of manufacture, all records: and reports p'ce~;,red_ _, ...... in accords:ncc with the terms of th~s__ per:,~c shall be available, for pctb].ic inspection at the o[fices of the 'DeparLn~et~t;.. ri~t~- in either real or pe:~p~l pro~cy, or any o~heu privi!e$as; nor does it auc}~o-ize any injury ~o privata prop~rtv, ~ or anv~ invas~o;~ ..... of .pa,~aonal. _ riKhts~ , nor any fringements of federal, S~ate or local la~s and regulations, . The p~_ovisions of this permit a:e sever,:ble a:~.d, if any .provision of this p'emnit os the app!ication of any provision of this permit to any circum~ta2ccs 'is held invalid, tl~~ application of s:~ch provision to o~h~r cicct~nstances a~d the re~,ainder of tttis parait sba!~ no La aff~,c'rL~~ t!~ ' Notwithstand~nS_ the anova', in the evc~nt the~ suc,~ in,.'~t!idaLLon. Department shall have the right, aa ils sole Of,Cio:t, to ter~::i, nat~ the pa~mi.t fi- ' .. State ~aws ..... ,. . (.~ any legal action or tel'icy5 :.,crc:'t.t:tee fro,:~ any rcsponslb-[li, ties, liabilities, or [~en~lt'i. es e:stabl, i. sl:e4 pursuant to any applicable Scare law or regulI, ahio[~. . , Posainm of Permit The permitt-ee shall' po~t this par-mit consp'l¢:uo~:sly at thc treatment works location and maintain a copy o: it in thole central office. Definitions }'or the purpose of this pernit the fol!owAng deflnitio'ns shall apply- . Average The aritl~,:netic mean of vah~es obtained ove~' a specified periot time. For coliform da te~ained by the n:ult:,-~p_ ~ :,nba proced,'re., t.h~ average, shall be computed as theo<-°-'t~t~:Lc m,-'~n-_, , for co].i[or~ determined by the ::e:::i>~ane filter proceduce the average .shall be co:nputed as ti,e a'r/tl',:nehic mean. Comaiss:[c, ne:- Co::::nis.<;ior:er c- :P, vLrop, z:att'-L<._ ~a. ~ Consorvs. k.-ion... Compos ite A combination of indtv:[c}tial samples of wa,.tcr or wgste:.:ater take:: at selected i.ntc:rvals> generally ho:~rly for so;ne specified period, to minimize the effect of' thc va~-.[ab-l],ity of individual samg].es. Ind'Lvidua]. samples are combined into the co::pc, s:lte in proportion to . is within or immediately fol]ow:.L~.S a surge or equaI, iza.tion tank, pro-,:JdinS that only raw wastewater or raw w~:st,_;wator imv..;.ed-Lately after p~etrcatment enters tl,.~ tanks, or 3. enters the first step of thc; treatment process if no pretreat,.-;~ent or eq~a]_i;:atio~ facilities exi s t. NaX.Lmum Value The value o':. any ,¢4iven- pat-amete-,-, tl~at is ~evcr to be e>:ceeded bt, an}' sa,::.p!e. · PI;etreatmenE Raw Nater Nater as J.t e_'<-Jsts :in its r.,att.:ca] ,~;[at'e at the point of t "' - a:,!nS for dor. astic ttsc o'~ o~t-ic~r pt~rposes. Receiving Erlviro~l~,f_t~ The location at which waste :i_s d:i_sc.b.z,.rged to the environx:ant, be it 1~ Thirty Day Average The average of all samples taken. . c~u~ r:inS'a th:i r-fy consecutive day period. ~', as t ewat er Stream The flow of wastewater from its sourcc:(s) tl~rouf.,,h the collection a~d treatment- fac-iNit:les to the point of final disd~arge t.o the receJvAng envt~:on{nent. I,,~a s t ewe te r S t: ream A portion of the wastewater stream. ~.,7 a t e r s Includes 1 : bays, ._, ._ a.<es, sounds, D o~_ ~_cI ~; 5.~n reser,,oirs., sprin~;s. ~ , creel.:, c~; ['ti.Ri ii ~!E; ~ inlets, srt:aits, pa ...... o -- , , Ocean, Gulf of Aiasl.:a~ t;er'lnl% Sea, and Ocean~ in the tea-Fit-erie! ]'[.i:!iLs of t:he State, and al]. et. her bodies of surface or t.t,.dc'.;-grc>und wet:er, natural or art:lf_icia], puhIi(: o~ prix'at.c-, :inland or coast:al, f'- ~' _.~:con oK salE, wi~ic:lt nrc wl,olly or partially in or bordering [-h<t St. at:e or under jurisdiction of the State. Form ~o. P---4 REV. ~,- I- 70 STATE OF ALASKA suBMrr OIL AND OAS CONSERVATION COMMITTEE MONTHLY REPORT O'F DRILLING AND WOR'KOVER OPERATIONS 1. o,L []] oA. []] OT.E, Wildcat WELL WELL 2, NAME OF OPEP,~TOR Exxon Corporation 3. ADDRESS OF OPEP~R Pouch 6601, Anchorage~ Alaska 99502 4. LOCATION OF WELL Surface' 663' NSk & 622' WE[, Sec 34, T10N-R23E, UPM, North Slope, Alaska BHL (Proposed)' 2160' NSL & 1400' WEL, Sec. 35, TlON-R23E, UPM, North Slope, Alaska ~. API NUA~IERICAL CODE Not Available 6 LEASE DESIGAIATION A.X-D SEMI, ADL 47559 Surface ADL 47558 Bltl 8. L,~IT F.~A{ OR LEASE NA34[E pOint Thomson Uni g WELL KO Exxon No. 3 10. FLELD AND POOL. OR WILDCA~ Wildcat I1. SEc., T., R., M..' (BO/~FOM HOI~ Sec. 35, TION, R23F/'U'PM 19.. PEP~IT NO. Not Available 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA. NGF, S IN HOLE SIZE, CASING AND C~L%~ENTING JOBS INCLUDING DEPTH SET AND VOLLqVIES USED, PERFORATIONS, TESTS ANT) RESULTS FISHING JOBS. JUNK LN HOLE AND SIDE-TRACKED HOLE AND ANY OT]~IER SIGNIFICANT ~G~S IN HOL~ CONDITIONS. Started hauling gravel to location on 1-28-78. Point Thomson Unit No. 3 was completed 2-16-78. until a rig is available to drill the well. Construction of location for Operations will be suspended / l~.Ihereby~erti,~tl~t,he'ore~otn~i~ a_,~i~O~%"~ ~ Dist. Mgr. Offshore/Ak. Div. s~ Rod L. Boane ~ Fxploratinn ~opartm~nt DA~ 3/17/78 NOTE IRe~ort on this form ii required for ·each calendar ~nth~ regardless of the status of operations, and must ~ flied in duplicate with the oil and gas conlervation commiffee by the 15~ of the luec~ding month, unle~ otherwile directed. CONFIDENTIAL E ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE. ALASKA 99502 EXPLORATION DEPARTMENT OFFSHOREiALASKA DIVISION Mro Joseph Green Director, Division of Minerals and Energy Management Department of Natural Resources State of Alaska 323 East 4th Avenue Anchorage, Alaska 99501 January 20, 1978 Re: Exxon No. 3 Pt. Thomson Unit Sec. 35, T10N uR~2~3Ei UPM A.D.L. 47588 ~B North Slope, Alaska. Dear Mr. Green: The Plan of Operations. attached to Exxon's letter to you of January 12, 1978, re the subject well was in error in its reference to the surface location; the correct location of which is: 663' NSL and 662' WEL Section 34, T10N, R23E UPM, North Slope, Alaska Accordingly, we ask that you substitute the attached revised p~ge one of such plan of operations, which page correctly describes such surface location, in place of the previously submitted page which page should be destroyed. We deeply regret this Exxon error land the inconvenience it has caused your office and those listed below. rs very truly, Robert K. Riddle x.c.O.K. Gilbreth Wm. Copeland J. Scott Grundy Douglas Lowery w/attachment A DIVISION OF EXXON CORPORATION STATE of ,ALASKA TO: Chris Guinn, NCDO Scott Grundy, F & G Doug ~, D~C O. K. Gilhreth, O & G FROM:pete Nelson FILE NO: IJO/SS 78/6 TELEPHONE NO: SUBJECT: ~XO]% NO. 3 Pt. Thcmpson Unit Attached is a aopy of a correction of the location on ~ above referenCed lease operation sent to us by Exxon. ALASKA DATE: ]../'].7/78 .. . TO: r Chris Guinn NCDO Scott Grur~y, F & G FILE NO: LO/NS 78-6 O.K. Gilbreth, O & G TELEPHONE NO: FROM: Pete Nelson Land Manage' officer. Copies of the referenced Lease 09eration application were sent direc~Y to you by Exxon. Please review and send me your conne/%ts as soon as pos,~ible. O. K. Gilbreth, Jr Director Janua~t 18, 1978 Exxon-I~int Thcmpson Unit No. 3 Sec. 35, T10N, R23E, UPM ADL 47558, LO/NS 78-6 We have reviewed ~ "Con~~ Plan" and "Plan of Operations" for ~ ~ ~1 ~ pit ~ have a ~ volune of 115% of the fuel ~ voltm~ ~ that th~ plastic ]/nJ_ng Ln the fuel s~e area be stor~ ~ frc~ leaking ~. E] ON COMPANY, U.S.A. POST OFFICE BOX 2180' HOUSTON, TEXAS 77001 January 12, 1978 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION CRANDALL D, JONES MANAGER Exxon No. 3 Pt. Thomson Unit Sec. 35, T1ON, R23E, UPM A.D.L. 47558 (BHL) North Slope, Alaska LO/NS 78-6 Mr. O. K. Gilbreth, Jr. Director, Division of Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Gilbreth' CONFIDENTIAL Exxon Corporation submits the following ~n ~,r:egard to the captfoned well' (1) State of Alaska Oil and Gas Conservation Committee Permit to Drill, Form 10-401, in triplicate with triplicate copies of the location plat and contingency plan. (2) Exxon Check No. EC50176 dated January 12, 1978 in the amount of $100.00 in payment of the required permit fee. Concurrently with this application we have also filed with the State Division of Energy and Minerals Management the following' (1) A plan of operations describing the location, construction, rig move and resupply, waste and sewage disposal, pollution preven- tion and measures which will be taken to prevent erosion (The waste water treatment system that is to be used is owned by Exxon and will be operating under a WPC permit (yet to be issued) at the Point Thomson Unit #2 Site~until required. (2) Plats showing the routes to mobilize the construction equipment using rolligons and to move the rig as well as possible gravel and water sources and the pad layout. It is our plan to commence location work in February 1978 immediately following the preparation of the No. 2 drillsite to utilize equipment already mobilized; drilling operations are to be commenced after freeze up in November or December 1 978. ~ ' .... ' ~ Sincerely, OCR: 1 j 7/ cc EPA Region X w/enclosures A DIVISION OF EXXON CORPORATION Joseph Green w/att COMPANY. U.S.A. POST OFFICE BOX 2180- HOUSTON, TEXAS 77001 EXPLORATION DEPARTMENT OFFSHORE/ALASKADIVISION CRANDALLD JONES MANAGER ~df~'r. Joseph Green Director, Division of Minerals and Energy Management Department of Natural Resources State of Alaska 323 East 4th Avenue Anchorage, Alaska 99501 Dear Mr. Green' January 12, 1978 Exxon No. 3 Pt. Thomson Unit Sec. 35, T1ON, R23E, UPM A.D.L. 47588 (BHL) North Slope, Alaska LO/NS 78-6 Exxon Corporation filed an application with the State Division of Conservation for a permit to drill the subject well together with our check in the amount of $100.00 in payment of the required permit fee. Additionally, and in accordance with the requirements of the subject oil and gas lease, we submit the following- (1) A Plan of Operations describing the natural environment, the location construction, rig.move and resupply, camp facilities, potable water supply, waste and sewage disposal, pollution prevention and measures which will be taken-to prevent erosion (The waste water treatment system that is to be used is owned by Exxon and will be operating under a WPC Permit (yet to be issued) at the Point Thomson Unit #2 site this winter). (2) Exhibit A (plat) showing the ice roads to mobilize the construc- tion equipment and to move the rig as well as possible water sources and pad layout. (3) Exhibit B (plat) showing ice road and rolligon haul route with possible gravel sources. As stated herein, it is our plan, State approval permitting, to commence location work immediately after completing the No. 2 site in February 1978 and actual drilling operations are to be commenced after freeze up during November or December and conclude after breakup four to five months later. The rig will be left on location until the following winter. OCR'lj xc.'~.K. Gilbreth w/att Enclosures i~m. Copeland w/att J. Scett Grundy w/att A DIVISION OF EXXON CORPORATION Douglas Lowery w/att Sincerely, · -ll,,tm 10--40! -nxv.- ~-~-?~ -lJylII M n' IN STI OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN DRILL J~] DEEPEN [:] []] °'" ['] ~.,, Wi 1 dcat ""~" [] """"'~ [:] Exxon Corporation P. O. Box 2180, Houston, Texas 77001 iX)CATION OF 663' NSL & 662' WEL, Sec. 34, TlON - R23E, UPM . 2160' NSL & 1400' WEL, Sec. 35, TION- R23E, uPM API No. 50-089-20007 I.L.[JL.gI:~%G,NA~'ION.j%N'D ~agJ~L NO. /AUk 4/bb~ 5urtace ADL 47558 BHL ;. IF i.%'DLK.N. ~,L.J.~D~ ON, ~11- Point Thomson Unit w~l. ~o. .... Exxon No. 3 10. rl£L..D AND POOL.. OH, WILDCAT Wildcat II. SEC.. '1'.. R., M., f BOTTOM ~OLE OBJECTIVE, Sec. 35, TION- R23E · North Slop,e: Alaska= ~. D~TA-~CE 1-~ ~IZ~. AS3 DIRE~N ~OM ~EAREST TOWN O~ ~ST OFFICe' 52 miles east of Deadhorse ~ ~ND Oil & Gas Conservation~134049 State Board File B-l-4 ~oc~,o~ To ~'~S: lease & 31 SNL t ~.._ ~ D~STANCg FKOX~ PROPOSED ~R AP~LI~ FOR. Appx. 10,600' E of Exxon ~1 Pt. Thomson , .,...,,., $!'00,000 ,';..,,~o,,os~ 15050' MD (13800' TVD F. LEVATION$ d$t~ow whethcr DF. RT. C~. etc. J Approx. 8.6' GL PROPOSED CASING AND CE.%IE.'~T2~,'G PROGP,~LA4 NO. ~cRr~s ^SS,JG~£D 20. ROTARY' OR CABLE TOOLS RD ta ry ~- APPROX. DATE WORK WILL STAHT* Location' Feb: '7..8,....Spud,: Dec.'78 .................... [ s~.~ D~ ..... q,,o,,,i?, · zz£ Or.OL£ S~:£ or c.~ wmG~ P~R r°~ GRAD~ ..... 40" .... 36"x32""x28 f' Insul ated/R~fri.~era~ed 85' To' surface " ' __ 26" 18-5/8" 96.4 K-55 800' ...... To Surface .... _ ]_7-_l/2" .1 3-3/8" ........... ~2 N-~O '" 3300~ ....... 'To surface ..... = 12-1/4" .. 9-~/8" ............. 47 ~S0p:95 '~iOg'O'o' " ADDmOX..$OP"~f S'~eg'$.~ 600'0' ' _ ~-1/2" .... 7". 32/35 ~110 ~lfi~Od' .. ~Ob' above...pgtgg~al hyd~.ocarDO~"z', Subsurface Injection- It is planned to set the 9-5/8" casing into the pressure transition zone to provide for disposal of waste water into salt water sands projected to occur between the surface casing shoe at 3300' and top of the 9-5/8" cement at approximately 6000'. -A wellbore sketch is attached which illustrates the well design with provisions for preventing casing collapse if commercial production is established. ..., Blowout Preventers- (See attached sheet) :~ vz.s 0 .o A-P.L N"U'M.X~%ICA.I.. L"OD~ Manaaer, Offshore/Alaska Division 50-089-20007 July, 13, 1978 , vA~ July 13, 1978 Blowout Preventers: A 20" annular blowout preventer with a diverter line will be installed on the insulated conductor and the 18-5/8" conductor; the diverter will. be -removed while opening the 17-1/2" hole to 26" to 800'. A 13-5/8", 5000 psi WP BOP stack consisting of an annular BOP and three ram type preventers will be installed on the 13-3/8" and 9-5/8" casing. A 7-1/16", lO,O00 psi BOP stack will be used if required during well testing.. BOP installation and testing will be in accordance with £xxon standards which require pressure testing on initial installation, when any com- ponent is changed and at least once weekly thereafte.r; all BOP's will be function tested each trip. Drilling crew proficiency tests of well shut-in procedures will be conducted at least once each week with each crew. WELLBORE SCHEMATIC Point Thomson No. 3 PERMAFROST CEMENT TO SURFACE 36" x 28" INSULATED CONDUCTOR @ 85' PERMAFROST CEMENT TO SURFACE 18-5/8" CONDUCTOR @ 800' PERMAFROST CEMENT TO SURFACE 13-3/8" SURFACE @ 3300' INJECTION INTERVAL TOC @ APPROX. 6000' 9-5/8" PROTECTIVE @ APPROX. 10000' CEMENT 500' ABOVE HYDROCARBgri'<:~_ONE 7" PRODUCTION CASING @ 15000' CONTINGENCY PLAN POINT THOMSON UNIT EXXON NO. 3 The objective of this plan is to list major operating and contingency requirements to ensure a safe and efficient operation throughout the drilling activity. The location has been designed to provide containment of any drilling operation effluents that could be considered as pollutants. The 190' x 190' x 10' deep reserve pit will receive and contain all drill cuttings, excess mud material, wash and drain water from around the rig, and have the capacity for use in the event of a severe well control problem. Sewage and kitchen waste water will be processed through a Steel Fabricators, Inc. biological treating system with excess sludge being incinerated and the disinfected liquid contained in a sanitary waste pit; a separate sanitary holding pit is provided to divert the treating plant effluent in the event of a system malfunction. A burning pit is located clear of the rig to permit burning any waste oil recovered from the drainage system and any produced hydrocarbons resulting from well testing or an upset. Fuel will be stored in steel tanks in the plastic membrane lined fuel storage area. A primary feature of the drilling plan is to provide 9-5/8" x 13-3/8" annular injection capability. The well casing program is designed to set 13-3/8" surface casing through the major gravel sections and below any possible fresh water zones. The 9-5/8" protective casing will be set into the anticipated pressure transition zone and cemented to iso- late the salt water sand sections from below the surface casing shoe to approximately 6000 feet for injection of excess mud, melt, and waste waters and welltest liquids collected. Liquid levels in the sanitary waste pit, sanitary holding pit, and burning pit will be maintained below ground level after breakup to prevent migration of any liquid out of the pit while the reserve pit will be maintained at a minimum level at all times to provide for containment of well fluids in the event of an upset. All pits will be pumped out to a minimum level and waste water injected into the injection zone before abandoning the location. The entire operation is planned so that no fluids associated with the operation will be discharged on the surface outside the location. The drilling contractor will be required to develop a comprehensive SPCC Plan to prevent pollution as a result of any drilling rig opera- tions. In addition to drip pans under the engines and rig machinery, the rig area will be located within a drainage system to direct any. rig waste into the reserve pit. All oils, greases, and chemicals are to be stored within the rig drainage area. Good housekeeping will be stressed on all parts of the location with emphasis on minimizing contamination of the peripheral drainage from the pad. Any minor spill 'of oil will be collected using sorbent material for disposal in the burning pit. ' _ Personnel safety and well control are the uppermost factor's in well design and operational planning. Sufficient data are available to plan the well for evaluation of the geologic objectives, provide for subsurface disposal of waste water, and conduct a safe drilling operation. Advanced abnormal pressure technology will be used to predict and detect changes in formation pressure to permit adjusting the casing and drilling fluid program to control the well. Emphasis will be placed on well control equipment and procedures to permit circulating out a formation "kick" in an orderly manner if it should be necessary; any hydrocarbons in the influx will be diverted to the burning pit and burned. In the event of an unplanned upset result'ing in uncontrolled well flow, the following basic procedures will be followed: , 1. Divert flow to burning pit as the first defense against a spill. Switch the flow to the reserve pit when the safe working level is approached in the burning pit. The design capacity of the reserve pit is 64,000 barrels which will be maintained at a maximum, practical working capacity at all times by keeping mud and fluids use at a minimum and pumping fluids' into the annular injection well when possible. 2. Prepare plans for drilling a relief well from an alternate location. 3. The well will be ignited, if the situation warrants, only after discussion with proper governmental agencies and Exxon management. Major supplies of mud, cement, casing, fuel, and'miscellaneous supplies will be transported over winter roads or flown directly to location. After breakup light consumables will be transported by fixed wing air- craft. A Rolligon will be on location for any local movement of water or fuel as permitted by land conditions. A Catastrophe Organization consisting of specifically designated per- sonnel will be activated to cope with an emergency such as an out-of- control drilling well. The Drilling Section of the Catastrophe Organi- zation is responsible for performing the well control function which includes all surface well control procedures as well as plans for a relief well. Immediate action will be taken to minimize environmental damage and institute cleanup operations. The basic relief well plan involves construction of another surface location approximately 5,000 feet southeast of the original well's surface location. The most likely time for a severe well control problem to develop would be late February, which would allow sufficient time to construct the location and spud the relief well before breakup. The planned relief well location would permit the relief wellbore to penetrate the flowing zone near the out-of-control well with a 5,000 -2- foot horizontal displacement. In the event insufficient time is avail- able to initiate the relief well, a barge rig operation could be mobilized after breakup to drill a relief well. Both relief well plans are predicated on emergency approval of all phases of the operation by all state and federal regulatory agencies. TLP' kc 1/9/78 -3- PLAN OF OPERATIONS POINT THOMSON UNIT, EXXON NO. 3 Surface Location: 663' NSL and 662' WEL Section 34 T10N, R23E UPM, North Slope, Alaska Bottom Hole Location: 2160' NSL and 1400' WEL Section 35, T10N, R23E UPM, North Slope, Alaska Attached Exhibits show the following: !i.' Proposed location layout including well position, reserve pit, sanitary waste pits, burning pit, fuel storage area and water supply (Exhibit A). Planned winter access roads which are to be constructed and proposed gravel sources (Exhibits B, B-1 and B-2). Plat of Survey, Exxon No. 3 Point Thomson Unit (Exhibit C). Natural Environment The proposed drilling location shown on the attached Exhibit A lies approximately 10,500 feet east of Point Thomson Unit Exxon No. 1 and is situated 1,000 feet inland from the B~aufort Sea coastline. The surrounding terrain is low lying coastal plain with mud flats and scattered small lakes. Surface vegetation is typical tundra type with mosses, lichens, grasses, and sedges being most dominant. Elevation of the proposed drill site is approximately 8.6 feet above sea level. The proposed well is in the continuous permafrost zone of Northern Alaska where the depth of permafrost is approximately 1,600 feet and the active surface layer or thaw zone is from one to three feet. Since the ground cover acts as insulation limiting the depth of the active layer, removal or damage to the. ground cover especially in areas of any appreciable slope is a major factor in causing erosion. Consequently, every possible effort will be made to protect the surface from unnecessary damage. There are no established roads, airstrips, housing, or other facilities in the area and, because of the fragile nature of the terrain, heavy vehicular traffic can operate only during the winter season while the ground, streams, and lakes are frozen. Prudhoe-Deadhorse, located approximately 52 miles west of the location, is the nearest staging area and airstrip with facilities for handling cargo and housing personnel. PLAN OF OPERATIONS POINT THOMSON UNIT, EXXON NO. 3 Surface Location: 663' NSL and 662' WEL Section ~, T1ON, R23E ~ UPM, North Slope, Alaska Bottom Hole Location: 2160' NSL and 1400' WEL Section 35, T1ON, R23E UPM, North Slope, Alaska Attached Exhibits show the following: Proposed location layout including well position, reserve pit, sanitary waste pits, burning pit, fuel storage area and water supply (Exhibit A). Planned winter access roads which are to be constructed and proposed gravel sources (Exhibits B, B-1 and B-2). plat of Survey, Exxon No. 3 Point Thomson Unit (Exhibit C). Natural Environment The proposed drilling location shown on the attached Exhibit A lies approximately 10,500 feet east of Point Thomson Unit Exxon No. 1 and is situated 1,000 feet inland from the Beaufort Sea coastline. The surrounding terrain is low lying coastal plain with mud flats and scattered small lakes. Surface vegetation is typical tundra type with mosses, lichens, grasses, and sedges being most dominant. Elevation of the proposed drill site is approximately 8.6 feet above sea level. The proposed well is in the c ntinuo~__p~a~t~.~._~_.?f Northern Alaska where the depth of permafrost is a~ll~_~l~feet and the active surface layer or thaw zone is from one to three feet. Since the ground cover acts as insulation limiting the depth of the active layer, removal or damage 'to the ground cover especially in areas of any appreciable slope is a major factor in causing erosion. Conse- quently, every possible effort will be made to protect the surface from unnecessary damage. There are no established roads, airstrips, housing, or other facilities in the area and, because .Df the fragile nature of the terrain, heavy vehicular traffic can operate only during the winter season while the ground, streams, and lakes are frozen. Prudhoe-Deadhorse, located approximately 52 miles west of the location, is the nearest staging area and airstrip with facilities for handling cargo and housing personnel. Construction and Opel~ting Plan A 78 man camp, recently purchased by Exxon from Frontier Companies, Inc., will be used with Loffland Bros. Rig No. 162 in the drilling of Point Thomson No. 3. The existing Loffland Bros. Camp at Point Thom- -son No. 1 will continue to be used to house personnel during the construction of the site; thereafter it will be removed by Loffland to another location and the new camp will house all personnel. Construction equipment will be moved along the Rolligon route shown on Exhibits A and B and construction will be started in February 1978, consistent with state approval, following the preparation of the drill site at Point Thomson Unit Exxon No. 2, which is in progress. It is planned to construct the location at this time using equipment already in the area and 'in November or December 1978, after freeze-up is suffi- cient to reconstruct the routes shown on Exhibit B, move in the drilling rig from the No. 2 well. This procedure will result in the least environmental disturbance and will permit the earliest start for Well No. 3. The sequence of location-preparation should be as follows' Lay out road route with an empty Rolligon as soon as equip- ment is available from the construction of Point Thomson Unit Well No. 2 location. Continue camp site at Exxon No. i Point Thomson, per.above. Start construction of ice roads for water and gravel haul using equipment currently located at No. 2 Point Thomson Unit. Move in dozers and other equipment with Rolligons.i.~, ., ~ove Belly-dumps, loaders, and graders over road. Water trucks will. be used during construction to mainiain haul roads. Construct location and Otter strip. After location construction is complete, the campsite will be removed from the No. 1 Point Thomson site. The No. 3 Point Thomson Unit location shown in Exhibit A will be approximately 730' x 710' overall and with a five foot gravel pad will require approximately 55,000 cubic yards of gravel. In addition, be- cause of the time required to drill and evaluate a well of this nature, it is planned to construct a 2,000 foot long Otter landing strip to permit operation after breakup. This strip will require about 15,000 yards of gravel. The proposed gravel source is from graVel bars in the vicinity of Sections ll, 14, 23, 25, 26, and 36, T9~, .R20E, and~ Section 31, T9N, R21E. In addition, approximately 20,0Q0i.cubic~,~ar~s of gravel will be obtained along the shoreline in Sections 32, 33, and 34, T10N, R23E. Locations are shown in .Exhibit B. ~.~ ~ ~ i: ~'~ -2- Gravel removal and hauling will be ac-:~emplished using rubber-tired loaders and belly-dumps for ~irect movement; however, when necessary, the gravel will be placed in piles fo~ convenient loading. Movement Will be over sea ice roads along the coast and ice roads constructed of snow and water to protect the existing land surface. Only the exposed gravel deposits above the water line will be removed to ensure that no holes remain at the borrow area which could cause fish. or animal entrapment after spring flooding, The planned drilling location will accommodate the rig and equipment, camp, and support facilities. The site is to be overlain with suffi- cient gravel to act as an insulation barrier to prevent thawing of the permafrost' during summer operations. Wooden matting will be used under drilling rig amd mud pumps for stability and as a further aid in preventing permafrost degradation. All pits are to be diked with gravel. A 190' x 190' x 10' deep reserve pit will be used to retain cuttings, excess drilling fluid, and drainage around the rig. The well will be designed for annular injection which will permit subsur- face disposal of wash and melt water, excess drilling fluid, and well test liquids. The level in this pit will be kept as low as possible to prevent migration of fluids and provide capacity in case of an emergency such as a severe well control problem. A 60' x 60' x 6' deep burning pit will be located a safe distance from the rig to permit burning of all hydrocarbon test liquids. Fuel storage will be approximately 300,000 gallons in welded steel tanks located ~ithin a 60' x 130' x 6' deep, plastic lined area. All excavated /~Z. topsoi! or tundra from the pits will be stockpiled at an accessible site adjacent to the location in order that the pits may be restored as nearly as possible to the original condition at the time of back- ~iI1 and clean-up operations as required by applicable regulations. The Loffland R'ig 162 will be moved in late November 1978 from Exxon's No. 2 Point Thomson Unit over an ice road along the coast. Actual drilling and evaluation operations will require six to seven months and. plans are to stockpile materials and supplies to permit operation after breakup. After completion of the well, the rig will be left on location until the following winter. Major supplies of mud, cement, casing, fuel, and miscellaneous drilling supplies will be transported to the location and stockpiled before spring breakup. ~hen bulky equipment is to be delivered on short notice or large shipments can be accumulated, it is planned to construct an ocean ice landing strip off the coast for Hercules aircraft. After breakup, personnel and light consumables will be resupplied by fixed wing aircraft using the gravel airstrip described above. All support equip~ent not required for summer operations will be moved out before breakup. Camp Facilities An Exxon owned 78 man camp for rig personnel will be moved in from ~oint Thomson Unit Exxon No. 2. Sewage and gray water from the kitchen and shower area~ will be discharged in separate lines and will be introduced into an approved waste disposal unit installed at the site. Sewage, water, and garbage use and disposition will be as follows' 1. .Sewage,. Di.sposal A Steel Fabricators, Inc. biological sewage disposal unit which complies with the requirements of the state of Alaska and the EPA for water quality in the area of operation will. be installed. A 75' x 60' x 10' deep sanitary waste pit is provided for the treated liquids discharge. Also, a 25' x 60' x 10' holding pit is planned to allow diverting the unit dis- charge in the event of a treating plant upset. 2. Water Supply Potable water for the camp facilities will be hauled from small lakes near the rig and a large, eight-foot deep lake approximately four miles south of the location in Section 22, TgN, R23E.. A snow melter will be used to supplement the rig requirements until shallow lakes closer to the rig thaw in the summer. The water will be processed through a Steel Fabricators, Inc. water treating unit before use in the camp. Additionally, gray water from the camp will be used for mud and rig wash water. 3. Garbage and Waste Disposal Burnable garbage and wastes will be disposed of in a ~{cNaulin-Goder Model-1510 trash incinerator unit. Some of the more readily combustible products~ such as paper, wood, and cardboard, may also be open burned. Noncombust- ible wastes, such as scrap metal, tires, batteries, and drums, will be hauled to Deadhorse and final disposal will be in accordance with State Waste Management requirements. Development Plans If oil is discovered in sufficient quantities to warrant future de- velopment, the Prudhoe Bay to Valdez oil pipeline will be the probable marketing outlet from the area. Oil and casinghead gas would be processed through central oil gathering facilities with oil being pipelined to the Trans-Alaska line passing approximately 52 miles to the west. If conm]ercial quantities of gas are discovered, development of a gas market outlet will be related to studies to market gas from the Prudhoe area. . ~.~?~ ~:. Surface Protection and Restoration Plan As previously mentioned, precautions will be taken to protect the surface by not beginning operations until after freeze-up and by using existing roads and winter trails where possible. At the completion of the well, the location and adjoining area will be cleared of all waste materials. Ail pits will be backfilled and leveled in accordance with governmental regulations. After leveling the location, stockpiled topsoil or tundra will be spread over the site as it is available. ', Special procedures fOr drilling and subsurface equipment are required by the unique characteristics of the permafro, st area. Casing cement used through the permafrost zones is of special composition to reduce possibility of freezing and other casing problems. Casing is run and cemented through the permafrost, and in the event of production or interruption of operation, the casing must be protected by non-freezing fluid. TLP' kc 1/:lo/v8 2 MtKKEL.~EN / 2O ! / ? i MATERIAL SOURCE 24 28 34 26 SCALE 50 56 29 52 T. gN. · f MILE NOT E TOPO TAKEN FROM US.G:S. BEECHEY PT. (A-t) 8~ FLAXMAN iSLAND (A-5), ALASKA. ON SITE INVESTIGATION ASCERTAINED THAT MATERIAL HAS BEEN TAKEN FROM THE MATERIAL SOURCE IN SECTION 23 AND THAT UNKNOWN QUANTITIES OF GRAVEL ARE RECOVER- ABLE FROM THE SITES SHOWN iN SECTi~S-,2;~,.25& 26. EXHIBIT MATERIAL SOURCE Locc~ted in for EXXONCOMCANY U.S.A. Prepored by E M. LINDSEY 8~ ASSOC. L_AND & HYDROGRAPHIC SURVEYORS ~02 West Nor'lhern Lights [5oulevdrd Bo~ 4~-081 Anchorage Alaska I 28 27 26 PROPOSED /----MATERIAL SOLJRC E l( ~ _ T. I0 N , 3 - 2 SCALE ! :: t M![.E NOTE: TOPO TAKEN FROM U,S.G S. FLAXMAN iSLAND (A-- 5), ALASKA. EXHIBIT B-2 PROPOSE D MATERIAL SOURCE Located in Surveyed for EXXON COMPANY U. Surveyed by E M. LINDSEY 8~ ASSOC. LAND & HYDROGRAPHIC SURVEYORS 2502 West Northern Lights Boulevard Box Anchorage Alaska ('d I ~J 2 5 24 ] ~ ' ~ FlQxman Ilsimnd ~ PROPOSED ~EXXON No. 3 POINT THOMSON UNIT LONG =i46 i5 08 66 I , ~ t 2 S(;ALE ": i Mi[.E -[ ~0 N. TgN CERTIFICATE OF SURVEYOR ! hereby certify that lam properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me or under rny supervision, and thai at! dimensions and other details (]re correct Date ~. /I ) " /./* ~ ~ / /' / .' / I/ ..~ , Surveyor _¢× U.L 1~/-r e_ NOTE: LOC, IS 86' ABOVE LAGOON 8~ OCEAN iCE. _ [ iii ii i i J i i ,j i PROPOSED EXXON No. 3 POINT THOMSON UNIT Located in SE i/4 PROTRACTE{) SEC 34, T. !0 N,~ R 23 E.~_UMtAT MERIDIAN Az~_K Surveyed for £XXO COMPANY U.S.A. I II III IIIlll Illll II I I I I Surveyed by EM. LINDSEY 8~ ASSOC. [_AND & HYDROGRAPHIC SURVEYORS 2502' West Northern Lights Boulevard Box 4-081 Anchorage Alask~ ii r iiii rllUllll I I II I I J I Ill Ill II I Prud~o. · HMId 6 , APPROx. ICE ROAD · Stockton IslafldB ~Tlgvarlak Island ! isbnd ~ ,..... AImm~ ~ MaSulre r, Duchm 1 "", North .,,1~' :...-,,,,...Sar I ,, ".. PT. THOMSON UNIT · .., ,: ~'f · . ::.. ,,. ¢' ..,. (ii, , · ,. . .~:. 'f ,'t:~' I ,,t ' ' q'' "~ ' . · ,~, ''~ (~ ' .d' " ',, '.' '* ~., "~, ~ " · , ' APPROX.. IOLLIGON ,, ~ ~. .'":'.. "" HAUL D ..t -' ' ; .... ~-- ~EVI9EO LEGEND -- POSSIBLE GRAVEL. SOURCE EXHIBIT B PROPOSED ICE. ROAD 8~ ROLLIGON EXXON COMPANY BY F.M. LINDSEY HAUL ROUTE U.S.A. ASSOC. -. 1,~. ?I's the permit fee attached .... ? ................ ~~: ~2. Is well to be located in a defined pool ' ~~ 3. Is a registered survey plat attached ................ /6~d_ ~ 4. Is well located proper distance from property line ......... x/~az[ 5. Is well located proper distance from other wells .......... /~j~. 6. Is sufficient undedicated acreage avai~e, in this pool ...... ~AC 7' Is well to be deviated . ,, ' /~ ...... ~.~,~: .,~,-~ 8. Is operator the only affected part~?;--- .............. ~4 e 10. 11. i2. Can permit be approved before t~'~'~]!wait.~ ~. .... "~.'% ~?-' ..~ . uoes operator have a bond in ~~=q ..~~ Is a conservation order nee~:~~S~ ~,~]~]~=~ ............. Is administrative approval needed .~ ............... 13. Is conductor string provided ..................... 14. Is enough cement used to circulate on conductor and surface .... 15. Will cement tie in surface and intermediate or production strings 16. Will cement cover all known productive horizons ........... 17 Will surface casing protect fresh water zones .......... 18. Will all casing give adequate safety in collapse, tension & burst 19. Does BOPE have sufficient pressure rating - Test to ~~,mpsig 20. Has DMEM approved Plan of Operation ................ Additional Requirements' ,. ~~ '~ '~ ° Approval" Recommended' Geology' Engineer i ng' TRM JAL HHH JCM HHK ~~ LCS ,~_ RAD Revised 11/17/76" Is the pezTui% fee at~ached'. ........... .. 2. Is well to be- located in a defined pool .............. 3. Is a registered survey plat attached ................ 4. Is well located pr .oper distance frcm property ] ~ne ......... 5. Is well located proper distance from., other wells .......... 6. Is sufficient undedicated acreage available in 'this pool ...... 7. Is well to be deviated ....................... :9. Is operator the only affected party . . . : ............ 9. Can permit be approved before ten-day ~ait ...... . ....... .0. Does operator have a bond in force . . · ............... _1. Is a conservation order needed ................... _2. Is administrative approval needed ................ .. Yes No Remarks Item. .Approve Date ' -(1) Fee '/~ / /~.~. ? · ".i" '; [2) Loc. (3) Admin. /~ _3. Is conductor string provided .................... L4. Is enough cement used to circulate on conductor and surface .... L5. Will cement tie in surface and intermediate or production strings . L6. Will cewent cover all known productive horizons .......... L7. Will surface casing protect fresh water zones ........... LB, Will all casing give adequate safety in collapse, tension & burst . 19. Does BOPE have sufficient pressure rating - Test to psig . 20. Has DMEM approved Plan of Operation ................ ~dditional Requirements: -(5) BOPE '/'-"~ Apprdval ~eccnmended: ~J-- Geology: I/? 8 Engineering: HHH JCM ~ LCS P, gD Revised 4/14/78 :)mson Shoal Shoal i Shoal ,-., ,'.:__.-7:' · '~:--:~.~_.~[ '.~. ':,'~..:~>'~ F EE'~ ~- _. - . ~ - ' - ~~ ~,~ >~x . , Shoal area --' 0 ' - ',L ..... '- :.' : ..,7--~'~ ~".._, : u~- ~ [ " .... : -~ ~ ~_ ~. Shoal .... ; "-:"~ -&, - -' ~: '~ - [":T, :-',. "' ;': "'~ -"- '"' -- ,, ' · ' - ~ : ' :~,~ t --' , U-, ~--~- x '-', ~' ' -- ~ ; ....... x~ .: " ~." _~ ...... -<: ,:, ~ - .; , "~¢~ ....: '-t-,~, ,"~ ' ---:- .... ( - ...: '~ -: . -' ._._ ._ ,4-. 10' ?V 6- 6 reakers .: )mson i4(~., Shoal ~....~.. ~, = :_: bL, Shoal Sh!al 1 Shoal :~;~::i ............... >" 70° 15' 5 930 000 __ FEE~ /