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177-064
FxxonirftbH Production Company R 0. Flo- ; r? sift I hnchoeage, Alask�� 99519-E.60`.,, 901 561 5331 Telephone August 4, 2014 R-2014 OUT -157 RECEIVED AUG 0 6 2014 AOGCC SWKE-0 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 %&mMobil Production By letter dated May 18, 2007, the Alaska Oil and Gas Conservation Commission (Commission) advised ExxonMobil that ten wells in the Point Thomson area did not meet the Commission's requirements for plugged and abandoned wells. The Commission further noted that permits to drill cannot be issued to an operator that is in violation of a Commission regulation pertaining to drilling, plugging or abandonment of a well. In addition to the seven wells listed above, the Commission's May 2007 letter addressed Challenge Island #1 (PTD 180-090), Alaska State J-1 (PTD 183-045), and PTU #4 (PTD 179- 080). Challenge Island was operated by another party, and we understand remedial work there has been completed. ExxonMobil has pursued remedial and final abandonment work on the ExxonMobil operated wells identified in the May 2007 letter. Visual inspections of all sites were conducted in 2007 and comprehensive inspections of the nine Exxon MobiI-operated wells were conducted in winter 2008/09. Remedial work was completed on the J-1 and PTU #4 wells in 2009 and 2012, respectively, and final reports were submitted to the Commission. During the winter 2013/14, final remedial or plugging and abandonment work on the seven subject wells was completed. A final report of Well Completion for the Plugging and Abandonment of each well was submitted to your office on May 14, 2014, followed by the summer well site debris clean- up reports submitted July 18, 2014. Cathy Foerster 2 August 4, 2014 All well remedial and abandonment work on the nine ExxonMobil operated wells was conducted in accordance with approved Applications for Sundry Approvals, some of which received modifications as the work progressed. Timely notices were provided to the Commission so inspection of the work could be performed at the Commission's discretion. The PTU #4 well file on the AOGCC website contains a final location clearance. With respect to work to close the reserve pit and conduct contaminated site cleanup work at WSS #18-9-23 and WSS #2 and incorporation of the PTU #3 and C-1 locations into the Point Thomson Project gravel infrastructure, our understanding is that receipt of final location clearance is not required at this time in order to be in compliance with plugging and abandonment requirements. Given the unique history of these nine sites in view of the Commission's May 2007 letter, ExxonMobil respectfully requests the Commission to either approve final location clearance or otherwise confirm to ExxonMobil that it has met AOGCC requirements with respect to the plugging and abandonment of these wells and do not represent an impediment to approval of permits to drill for ExxonMobil. If you have any questions or require additional information, please contact me at (907) 564-3773, Sincerely, n ri 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) JUL 21 2014 A0GCG Evzo%nMobil Production • 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, Well remediation was conducted at the six wells referenced above this past winter in compliance with AOGCC Sundry approvals. As required by the Sundry approvals, a Report of Well Completion for the Plugging and Abandonment of each well (10-407 form) was submitted to your office May 14, 2014. Following breakup, summer debris cleanup activities were conducted at four of the well sites the last week of June. AOGCC field inspectors concluded that it was not necessary to visit these sites following the cleanup work and instead asked that we provide the attached cleanup reports and site photos for PTU #1, PTU#2, WSS #18-9-23 and WSS #2. PTU #3 and Alaska State C-1 are on active pads associated with the Point Thomson Project so debris cleanup at those locations is not warranted. Please note ExxonMobil is currently working with the Alaska Departments of Environmental Conservation and Natural Resources to close the reserve pit on the WSS #2 and to address contaminated gravel on the WSS #18-9-23 and #2 locations. If you have any questions or require additional information, please contact me at (907) 564-3773. Sincerely, Irene T. Garcia SSHE Manager Attachments Summa. M Point Thomson Unit (PTU) #1 tivities PTU #1 (PTD No. 176-085); Sundry No. 313-600 and Sundry No. 314-206 (modification) A Report of Well completion for the plugging and abandonment of PTU#1 was submitted 5/14/2014 to AOGCC. The well is plugged and abandoned in compliance with the Sundry approvals. Following the winter well remediation, summer debris cleanup activities were conducted the last week of June. Debris was collected and transported to Deadhorse for appropriate disposal. Photos are provided below. PTU #1 prior to debris removal PTU #1 post debris removal. Debris was collected in supersacks (shown in center of picture) and transported back to Deadhorse for appropriate disposal. Page 2 Abandoned Well Site Cleanup Report July 18, 2014 t d 1��� , � a ire ' �, t y , a � . . � •FG : �.+►.'-.i�.R PTU #1 removing pipe PTU #1 post pipe removal Page 3 Abandoned Well Site Cleanup Report July 18, 2014 .;.,. 17m 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 Sumrr. of Point Thomson Unit (PTU) # ;tivities 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. dNW iorf +� �°� 'jam >� � .. �i ~ . � • i MIMI w t 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 Summarti West Staines State (WSS) #18-E Activities WSS #18-9-23 (PTD No. 169-120); Sundry No. 313-604 A Report of Well completion for the remedial abandonment of WSS #18-9-23 was submitted 5/14/2014 to AOGCC. The well is plugged and abandoned in compliance with the Sundry approvals. Following the winter well remediation, summer debris cleanup activities were conducted the last week of June. Debris was collected and transported to Deadhorse for appropriate disposal. Photos are provided below. WSS #18-9-23 well location prior to debris cleanup. WSS #18-9-23 well location post debris cleanup. Page 7 Abandoned Well Site Cleanup Report July 18, 2014 WSS #18-9-23 Looking south east post cleanup. Debris was collected in supersacks (shown in center of picture) and transported back to Deadhorse for appropriate disposal. WSS #18-9-23 looking south west post cleanup. Page 8 Abandoned Well Site Cleanup Report July 18, 2014 Summ of West Staines State (WSS) M. tivities 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 well Plans are tg do rhe stick 12ickong 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@rgdragnichIIc.com 907-830-4796 SCMW Nov 18 2014 t r7�Cj�4 a r w �1`qy `" q.', I -t+• � i' i �_ 1.ep �''�� M1®.f�p. "%�l Ys `,�1 .R1�r�'rV�� e,. �.... Pru. i, , ' );-_ a 9. yj�®.•...� ` e , • b ♦ ( '13 ..1^ ,.t6" r7 _ " I 1�& . -•�.. IS, � It �! ' 11 � �_.� ��f6 .� �,•�lam�t8.,�fi�F��M� W Stei es #' 1gl2324 _ 1 i 19as as •b no a, No,/ 35 31 92 a3 k i - -1 .71 f1 •' �... 3z M 9'1 b�l I }i; n. as P ; ti� 6 8 r ( I 31 1 ... ,? r• .. _.{ �.... _. ` :. 6 s I t n `a ,,Qls �v i6' 1n 19 v 14 c i:. �6 t6 is ly to 9122 P!. ' 94 at x 1 1 24u�~ 4_ as !a.•„ qq� 4F 1 <. { is 90 !! /�er' i'ie as ..�— , qz -•''�� a6 1 - 30 ' » 9b 96 iA 1 .. 33 .N. •�36 „lye iv it to it 7 ,M • � St e� STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: 1 b. Well Class: Development ❑ Exploratory ❑� Service ❑ Stratigraphic Test ❑ 2. Operator Name: ExxonMobil Corporation 5. Date Comp., Susp., or Aband.: 3/26/2014 12. Permit to Drill Number- umberExxon 177-064 - 3/3-601 J/y -I,S. 3. Address: P.O. Box 196601, Anchorage, AK 99519-6601 6. Date Spudded: N/A 13. API Number: 50-089-20006-0000 - 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 #2 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- 435937 - y- 5909513 ' Zone- L{ TPI: x- y- Zone- Total Depth: x- y- Zone- 10. Total Depth (MD + TVD): 14,117 - 16. Property Designation: ADL 47567 11. SSSV Depth (MD + TVD): N/A 17. Land Use Permit: LOINS 09-007 18. Directional Survey: Yes ❑ No 0 (Submit electronic and printed information per 20 AAC 25.050) 1 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): NIA I 22.Re-drill/Lateral Top Window MD/TVD: N/A 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 ❑✓ If Yes, list each interval open (MD+TVD of Top and Bottom; Perforation Size and Number): RECEIVED MAY 2 7 2014 A0G-0O3 25. N/A TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 26. OUEEZE, ETC. Was ydraulic 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 —.0o. 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. SCANNED NOY 18 2014 RBEMS MAY 2 7 2 Form 10-407 Revised 10/2012)0&-q. CONTINUED O/N�REV�RSE Submit original only �T 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes I 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.aJuranek exxonmobil.com Printed Name: Irene T. Garcia( Title: SSHE Manager Signature:Acz rj' tll Phone: (907)564-3773 Date: 5/14/2014 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain) Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned Q Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: 1b. Well Class: Development ❑ Exploratory Q Service ❑ Stratigraphic Test ❑ 2. Operator Name: Exxon Mobil Corporation 5. Date Comp., Susp., or Aband.: 3/26/2014 12. Permit to Drill Number: 177-064 3. Address: P.O. Box 196601, Anchorage, AK 99519-6601 6. Da pudded: N/A 13. API Number: 50-089-20006- On ' (w 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 #2 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- 146.515411 y- 70.163259 Zone- TPI: x- y- Zone- Total Depth: x- y- Zone- 10. Total Depth (MD + TVD): c _14W44-- 141('J' `� 16. Property Designation: ADL 47567 11. SSSV Depth (MD + TVD): N/A 17. Land Use Permit: LO/NS 09-007 18. Directional Survey: Yes ❑ No Q (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost MD/TVD: 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): N/A I 22.Re-drill/Lateral Top Window MD/TVD: I N/A 23. See Attached Work Summary CASING, LINER AND CEMENTING RECORD WT. PER 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 Q If Yes, list each interval open (MD+TVD of Top and Bottom; Perforation Size and Number): RECEIVELWas MAY 15 2014 ACC- C 25. N/A TUBING RECORD SIZE DEPTH SET (MD) IPACKER SET (MDlrVD) 26. N/A ACID, FRACTURE, CEMENT SQUEEZE, ETC. hydraulic fracturing used during completion? Yes L 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 -Jim. 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. Aums MAY 15 201 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 ❑� No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: 31. List of Attachments: Work Summary, Post P&A Well Schematic, Photographic documentation of the well before and after the work. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tom Juranek (832)624-5940 Email: tom.a.iuranek exxonmobil.com Printed Name: Irenq T. Garcia Title: SSHE Manager Signature: Phone: (907)564-3773 Date: 5/14/2014 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 ExxonMobil Production Company P. 0. Box 196601 Anchorage, Alaska 99519-6601 907 5615331 Telephone May 14, 2014 R -2014 -OUT -129 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Fes! MAY 15 2014 ElonMobil .CC Production Re: Well Completion Report Well Abandonment: Point Thomson Unit #2 (PTD No. 177-064) Sundry No. 313-601 and Sundry No. 314-158 (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 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, 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 TH0" (� PRODUCTION Exxon Mobil Corporation Pt. Thomson Unit #2 AN #: 50-089-20006 PTD #: 177-064 Final Well Schematic PF cmt in 9-5/8" x 13-3/8" annulus from ±2,874' to surface. 9-5/8" Baker model D packer at 5,820' with 20 bbl cement on top 9-5/8" retainer at 5,915' TOC @ 6,860' per temp survey 75 sx class G cmt plug in 9- 5/8" csg 6,240'– 6,450' 7" retainer at 11,480' with 4 bbls cmt on top — Baker F-1 packer at 11,528' 7" retainer at 12,696' with 4 bbl cmtt on top Total Depth 14,117' Cmt plug in 9-5/8" csg surface to ±120' (±3'- ±95' BGL) 28" x 36" insulated conductor at 88', cemented to surface with permafrost cement CaC12/Mud interface at 2,300' 18-5/8" casing at 842', cemented w/ 4,700 sx permafrost cmt 3-3/8" perforated at 3,060'– 2,874' 13-3/8", 72#, N/L 80 casing at 3,296', cmtd w/ 6,800 sx permafrost cmt Perforations 5,860'– 5,861.5', block squeezed w/ 125 sx class G Perforations 5,864'– 5,886', squeezed w/ 6 bbl cmt Perforations 5,930'– 5,931.5', block squeezed w/ 110 sx class G cmtt 7" casing stub at 6,510' 9-5/8", Soo -95, 43.5#, csg at 10,099', cmtd w/ 1,430 sx class G TOC behind 7" casing at 10,660' Perforations at 11,580'– 11,678', squeezed w/ 125 sx class G cmt Perforations at 13,020'– 13,080', squeezed w/ 125 Sx class G cmt 7" csg at 14,103' cmtd w/ 1,750 sx class G Point Thomson Unit #2 Summary of Work Activities 9 -Feb Carried out inspectin of location for: PTU #2, WSS 18-9-23 & WSS #2 13 -Feb Carried out inspection of PTU #2 location, took pre -pictures of location. 14 -Feb Preparing location at PTU #2 15 -Feb Preparing location at PTU #2 16 -Feb Preparing location at PTU #2 17 -Feb Preparing location at PTU #2 21 -Feb Preparing location at PTU #2 22 -Feb PTU #2 - continue preparing location. MIRU Little Red. MIRU piping. Pressure tested lines to 3,000 psig. Opened up well and found 0 psi on 9-5/8" & 13-3/8" casings. Attempted bullhead diesel and successfully sustained 5 BPM at 1920 psi for 10 bbls. Preparing for bullhead cement job. 23 -Feb PTU #2 - MIRU Schlumberger cement unit and Little Red. Pressured tested Schlumberger cement lines. Bullheaded water spacer and 200 bbis cement down the 9-5/8" by 13-3/8" annulus. (Details attached) 24 -Feb PTU #2 - Continue preparing location. Removed top flange and remove seal unit and prepare wellhead for new seal unit. 25 -Feb PTU #2 - Continue preparing location. Installed new Cameron seal unit and crossover spool to 11" 10K. Installed 11" 10k ram assembly (master valves). 26 -Feb Finish installing master valves. Install 2" side valves. Installed scaffolding around WH. Continue MIRU of equipment. 27 -Feb Shut down due to weather. 28 -Feb Preparing location at PTU #2 1 -Mar Preparing location at PTU #2 2 -Mar Completing Insulation/wrap (Hootch) of scaffolding and install heaters for same. Majority of piping has been laid. Replace Generator for FPMS. Install Schlumberger 10k CT BOPs. 3 -Mar Complete rig up of piping. Lay hydraulic lines to BOP. Install heaters for Hootch. 4 -Mar PU CTU Injector Head. Test Workover BOPS, CTU BOPS, lines, valves, block valves, PFMS valves, Accumulators, PFMS alarms (visual and audio), repositioned and tested master valves. 5 -Mar Completed testing additional three block valves as per AOGCC request, completed welding on coil connector onto the coil tubing, tried to remove BOP test plug unsuccessfully (suspect ice build up). 6 -Mar Retrieved BOP test plug. Warm up drill fluids, circulate out piping and coil. Commence going into hole. Coil tbg pump went down, switch over to Little Red for purring. Fluids froze in CT. 7 -Mar Continue rig up, completed test of top flange to 2,500 psi, rigged up bottom hole tools, made modification to scaffolding, rigged down lubricator, shut down for day. 9 -Mar Site Safety Mtg: Review process with all parties, checked out CT unit, commence warming up diesel fluid to 90 degrees. Circulate out diesel using drill fluid. Began drilling on shallow cement plug in 9-5/8" casing. Only drilled a couple of feet before progress stopped. Extensive diagnostics determined dual back pressure valve rupture disc had burst. Shut down. 10 -Mar Due to late night on 3/9/14, allow work crews to sleep in. Meeting with Team (Anchorage, Houston & SXP) with direction forward. Contacted AOGCC and received verbal exception to leave existing cement plug in 9-5/8" (slightly shy of 150' depth require_ment). Will rig down and move CTU to WSS #18-9-23. Begirpreparrig to excavate and cut off wellhead 3' below tundra. 11 -Mar Commence rigging down and loading out equipment to be re -located from PTU #2 over to WSS 18-9-23. Completed blow or drain of all piping, rigging down. 12 -Mar Completed preparation of equipment to be re -located from PTU #2 over to WSS 18-9-23. Completed blow or drain of all piping, rigging down 13 -Mar Continue relocation of small equipment, BOP stack, connex, enviro-vac, containment material and general clean up 14 -Mar Continue relocation of small equipment, connex, containment material and general clean up 15 -Mar Continue relocation of small equipment, containment material and general clean up. Commence excavation around well head 90% complete. Re -located wachs saw from camp site to location. NOTE: Point Thomson Unit #2 Summary of Work Activities PTU #2 Cement Pump Data 1 2/23/2014 Time Received call from AOGCC and was informed that there will NOT be a witness of the BOP Test on 18-9-23 Bbls Pump Away & for Cmt. On PTU #2. 16 -Mar Complete excavation of WH 17 -Mar Completed removal of cement from around WH. Completed removal of 36" conductor pipe & 1" Glycol pipes w/36" conductor pipe. 18 -Mar Completed removal of 32" & 28" casings and chipped off cement from 18 5/8" casing. RU Wachs saw and completed cut of 18 5/8", 13 3/8" & 9 5/8" casings. RD Wachs saw. Pick up and removed well head. 19 -Mar Conducted Tool Box Talk, RU & run 1" pipes into casings. MI -RU Schlumberger Cmt. Unit, Peak Vac - Trucks, circulate out 9 5/8", 13 3/8" & 36' conductor casings. Completed cementing of all casings. Shut down & RD all equipment. 20 -Mar Tool Box Talk on JSA: RU cutting equipment and trim back 18", 13 3/8" & 9 5/8" casings to line out with 36" conductor pipe. Took photos of cmt Job. Welded on marker plate, took photos of marker plate and Start Pumping Wtr. Pill depth of cut off. Clean up around location. 21 -Mar Tool Box Talk on JSA: Completed back filling excavation and took photos. Completed removal of all 1,500 equipment & material from location. 22 -Mar Tool Box Talk on JSA: No Activity 23 -Mar No Activity 24 -Mar Re -located dozer to complete snow leveling. 25 -Mar Completed snow level on location 26 -Mar Complete PTU #2 Cement Pump Data 1 2/23/2014 Time Pump Rate Bbls Pump Away 135/811 Casing Pressure Comments 16:30 JSA & Safety Review 17:00 3,000 Pressure Test Lines 17:30 Prime Up Pump 17:50 2.0 1,000 Start Pumping Wtr. Pill 4.0 1,500 18:00 3.0 10 2,500 Start Cementing - signs of fluid frozen near surface - broke free 3.0 20 1,950 3.0 40 11800 3.3 50 2,500 3.3 65 350 13 5/8" casing commence taking fluid down hole 4.0 80 800 3.5 120 73 3.0 150 40 5.0 170 300 3.3 200 60 18:50 0 Cement shut down -13 5/8" & casing pressure left on 0 psig 19:00 Commence RD Schlumberger 21:00 Schlumberger RD & Departing for Deadhorse PTU #2 As Found PTU #2 Excavation 4,00t 9 Op pv f -ow. AMMON, If sw n » + _ ��. ' I fE• a ...,/� lx.�' .` �' t�, o'er»� r AOW 51 t w ; w, y , w a. '^' ri 9 W V PTU #2 Depth Below Tundra PTU #2 As Left • 1 Schwartz, Guy L (DOA) From: Peterson, James M /C <james.m.peterson@exxonmobil.com> Sent: Wednesday, March 19, 2014 1:17 PM To: Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Cc: Dennis Collins (drecollins1953@yahoo.com); Winter, Cassondra E; Farrar, Kendall N; Greene, Timothy L; Juranek, Tom A; Hawthorne, Brian K; Emmett, Cody; Cox, Mirick T; Denman, Erika /C; Bill Penrose; Dragnich, Rob /EXT; bob.hagberg@solstenxp.com; shane.mcgeehan@solstenxp.com Subject: RE: PTU #2 Daily Operations Report PT -0 / -� ?-- d cO'l ExxonMobil Point Thompson Unit #2 Daily WeIlWork Report: 3-18-2014 HSM, Remove 32" and 28" casings and cement, RU wach saw and cut 20', 13-3/8" and 9-5/8" casings. SDFN 3-17-2014 HSM, Remove 36" conductor and cement, cut 1" circulation lines readying casing for cut off. SDFN 3-16-2016 HSM, cleaning location and excavate around WH, preparing for WH cut. SDFN 3-15-2014 HSM, continue cleaning location, start excavating around location for WH cut off. SDFN 3-14-2014 HSM, continue removing equipment, liners, and containment from location. SDFN 3-13-2014 HSM, RD BOPE, removing containments, and buildings, moving to next sites. SDFN. 3-12-2014 HSM, Continue rigging down equipment. ExxonMobil Point Thompson Unit #2 Daily WeIlWork Report 3-11-2014 HSM, Start rigging down well work equipment. Regards, 1 SCANNED LI James (Jim) Peterson ExxonMobil Workover Supervisor Cell: 281-610-6630 Email: iames.m.peterson@exxonmobil.com Email: leyvapeterson@aol.com ® T �w��\\I'/ THE STATE A.�a c� G, � T C' G ,e Mite-- 333 West Seventh Avenue GOVERNOR SEAN PARNI_;I_I. Anchorage, Alaska 99501-3572 xr *:3 Main: 907.279.1 433 �-Ag„n,g. Fc;x: 907.976.7542 Irene T. Garcia SCANNED JUL 2 9 2094 SSHE Manager Exxon Mobil Corporation 177- 0 9" P.O. Box 196601 Anchorage, AK 99519-6601 Re: Point Thomson Field, Point Thomson Pool, Point Thomson Unit#2 Sundry Number: 314-158 Dear Mr. 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, -)59e--)4"— Cathy P. oerster Chair DATED this l/a day of March, 2014. Encl. ' R i Y • • STATE OF ALASKA MAR 1 2 /2014 / ALASKA OIL AND GAS CONSERVATION COMMISSION 1D Ts 31 1 7{ 1 APPLICATION FOR SUNDRY APPROVALS AOGCG 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑✓ • Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Exxon Mobil Corporation Exploratory D • Development ❑ 177-064 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. PO Box 196601,Anchorage,AK 99519-6601 50-089-20006 • 7.If perforating: 8.WeN 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 Q Point Thomson Unit#2 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 47567 Point Thomson Unit 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): :Total Depth D(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): ///i/ f i TV1x0 :� 1i 0 0 Many plugs,see schematic None Caassingg Length d Size MD ND Burst Collapse Structural 88' 28"x 36" 88' 88' N/A N/A Conductor 842' 18-5/8" 842' 842' 2,420 630 • Surface 3,296' 13-3/8" 3,296' 3,296' 5,380 2,670 Intermediate 10,099' 9-5/8" 10,099' 10,099' 7,510 5,600 Production 7,593' 7" 14,103' 14,103' 12,460/13,700 10,760/13,010 Liner N/A N/A N/A N/A N/A N/A 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❑ Development Service ❑ 14.Estimated Date for 15.Well Status after proposed work: CommencingOperations: 11-Mar-14 Oil p ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: 12.E optot_pi WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑✓ • Commission Representative: l.Z 1 S` ..w,t-z GSTOR III SPLUG ❑ 17.I hereby certify that the foregoing is true nd 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 ti Signature Phone Date 4, / 44' `, 907-564-3773 --JI--Il COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity V BOP Test ❑ Meclenical Integrity Test ❑ Location Clearance [ Other: 74 A66-101A-4)g- V ler-V. .. eye(1 o-t �' ,os . 26 A ftc� 1/2 C i V RBDA1RBDMS MAY 1 0 2014 4Spacing Exception Required? Yes ❑ NoIl Subsequent Form Required: /b — 4/6,7 APPROVED BY Approved by:. / / ./v COMMISSIONER THE COMMISSION Date: 3,/2 -/ile- \\ 43'1 ./ - > 'Li (Revisedp alliG4NALpp t —�Submit Form and 3 /'Form 10-403 10/20 A NAL months from the date of approval. Attachments in Duplicate RECEIVED ExxonMobil Production Company MAR 12 2134 P.0. Box 196601 Anchorage,Alaska 99519-6601 AOGCC OG('�C 907 561 5331 Telephone '�'t EkonMobil Production March 11, 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 #2 (PTD No. 177-064) 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) Place a bridge plug / cement plug at +2,900', 2) Perforate the 9-5/8" casing at ±2,800' to squeeze the 9-5/8" x 13-3/8" annulus across existing perforations in the 13-3/8"casing, and 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 subsequently filled that annulus with cement from the surface to perforations in the 13-3/8" casing at 2,874' — 3,060'. This annular cement satisfies goals 2) and 3) above. Goal 1) 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 leaving intact 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. 2e),¢Ac,Zs; 11 z 3,3. /4c • Note: An exception is requested for the existing 95' surface cement plug inside the 9-5/8" G---" casing. 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 has been verified as being competent during current CTU operations. 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 713-656-4225. Sincerely, Irene T. Garcia SSHE Manager Attachment 41•POINT THOMSON PRODUCTION Exxon Mobil Corporation Pt. Thomson Unit#2 API#: 50-089-20006 PTD#: 177-064 Proposed Post-P&A Well Schematic Marker 'late at-3' BGL PF cmt in 9-5/8" x 13-3/8" .i, . , �4. 5 . ; 1,s, ,I,: Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, March 12,2014 10:42 AM To: 'Bill Penrose' Subject: RE: PTU#2 Sundry Application Bill, Officially you have approval to proceed with the P & A as outlined in the amended sundry. The signed copy will be forwarded to you later this week. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Bill Penrose [mailto:bilk.cisolstenxp.com] Sent: Wednesday, March 12, 2014 10:25 AM To: Schwartz, Guy L(DOA) Subject: RE: PTU #2 Sundry Application Guy, Is that an approval of the proposed procedure modification? Thanks and regards, E€ Pee Drilling Manager SOLST :. N, "P 406 W. Fireweed Lane, Suite 101 Anchorage,Alaska 99503 Main 907-279-6900 Direct 907-264-6114 Cell 907-250-3113 From: Schwartz, Guy L(DOA) [mailto:quy.schwartz_ aiaska.gov] Sent: Wednesday, March 12, 2014 9:59 AM To: Bill Penrose Subject: RE: PTU #2 Sundry Application Bill, Sundry looks good. thanks. Guy Schwartz 1 Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Bill Penrose [mailto:billLbsolstenxp.com] Sent: Wednesday, March 12, 2014 7:41 AM To: Schwartz, Guy L(DOA) Subject: PTU #2 Sundry Application Guy, This Sundry app for the PTU#2 procedure modification we discussed yesterday will be hand delivered to you today. We'll hold off on further work on PTU#2 until we get your approval. Thanks and regards, &c t Poriume Drilling Manager SOLS TEN; 'P 406 W. Fireweed Lane, Suite 101 Anchorage,Alaska 99503 Main 907-279-6900 Direct 907-264-6114 Cell 907-250-3113 2 Schwartz, Guy L (DOA) From: Peterson, James M /C <james.m.peterson@exxonmobil.com> Sent: Monday, March 10, 2014 2:01 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA) Cc: Denman, Erika /C; Juranek, Tom A; Cox, Mirick T; Hawthorne, Brian K; Greene, Timothy L; Dennis Collins (drecollins19S3@yahoo.com); Winter, Cassondra E; Farrar, Kendall N; Emmett, Cody Subject: RE: AOGCC Test Witness Notification Request: BOPE, Point Thompson Unit #2 /77- o&LI Update of completed work on site: 3-9-2014 HSM, PU coil, tools, test BHA, set on wellhead, NUWH, Pump 5.5 bbls diesel, down 9-5/8" annulus, 3.5 bbls calcium ? chloride, caught and pressured to 1800# held okay 9 bbls total pump. Tested motor. Open wellbore tested connections and wellbore to 2500#, Start pumping down coil locked up, NDWH POOH with tools had ice in tools. Freeze protect surface lines, Tarp up coil unit put heat on unit overnight. SDFN. 0 5511--40`4-f 3-8-2014 �� x I if NC HSM, PU coil, tools, test BHA, set on wellhead, NUWH, Pump 5.5 bbls diesel, down 9-5/8" annulus, 3.5 bbls calcium chloride, caught and pressured to 1800# held okay 9 bbls total pumped. Tested motor. Open wellbore tested connections and wellbore to 2500#, Start pumping down coil locked up, NDWH POOH with tools had ice in tools. Freeze protect surface lines, Tarp up coil unit put heat on unit overnight. SDFN. 3-7-2014 HSM, PU stripper, test coil connector 25,000 Ib. PU BHA consisting of Dual BPV, Jars, Disconnect, Dual circ valve, stabilizer, motor, and 8.50" PDC mill. stand back tools in Hootch. SDFN. 3-6-2014 HSM, Hard time starting crane, PU latch onto test plug, POOH. Test block valves requested by AO GCC 250 low high 8000#, Tested Annulus Popoff and set at 2500#. Weld on coil connector. SDFN 3-5-2014 HSM, Receive 300 bbls calcium chloride, remove coil bop and stack at 11" x over, PU retrieving tool, made several attempts to remove test plug, unable to remove, weld on coil connector. Modify scaffolding for ability to receive mud motors inside Hootch. 3-4-2014 HSM, Pressure test ROPE, Coil BOP and stack, lines, block valves, PFMS choke and valves. All equipment tested at a low of 250 and a high of 8000 psi. Test alarms both audio and visual on PFMS, and remote BOPE panels All tests witnessed by AOGCC representative. Notified AOGCC of planned P&A, laying cement in 9-5/8" with coil. 2-24 to 3-3-2014 Daily operations consisted of cleaning location and MIRU equipment for upcoming wellwork. 2-23-2014 HSM, Receive 300 bbls calcium chloride, remove coil bop and stack at 11" x over, PU retrieving tool, made several attempts to remove test plug, unable to remove, weld on coil connector. Modify scaffolding for ability to receive mud motors inside Hootch. -=---Original Message ----- From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, March 06, 2014 5:02 PM To: Peterson, James M /C; Crisp, John H (DOA); DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA) Cc: Denman, Erika /C; Juranek, Tom A; Cox, Mirick T; Hawthorne, Brian K; Greene, Timothy L; Dennis Collins (drecollins1953@yahoo.com); Winter, Cassondra E; Farrar, Kendall N Subject: RE: AOGCC Test Witness Notification Request: BOPE, Point Thompson Unit #2 Per our conversation this afternoon: 1) OK to test as described below (against casing/plug to 2500 psi)- this well (PTU #2) only; need to come up with different approach for wells that involve perforating 2) please send morning report when working on well to Guy Schwartz (email address above) and DOA AOGCC Inspector address (that captures all Inspectors and myself) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 -----Original Message ----- From: Peterson, James M /C[mailto:james.m.peterson@exxonmobil.com] Sent: Thursday, March 06, 2014 4:13 PM To: Crisp, John H (DOA); DOA AOGCC Prudhoe Bay Cc: Noble, Robert C (DOA); Grimaldi, Louis R (DOA); Denman, Erika /C; Juranek, Tom A; Cox, Mirick T; Hawthorne, Brian K; Greene, Timothy L; Dennis Collins (drecollins1953@yahoo.com); Regg, lames B (DOA); Winter, Cassondra E; Farrar, Kendall N Subject: RE: AOGCC Test Witness Notification Request: ROPE, Point Thompson Unit #2 While testing BOPE and Coil BOP stack equipment a concern was raised about testing above 11" blind rams by AOGCC personal witnessing this test. All equipment has been tested and passed and other block valves tested per request. Results will be emailed to AOGCC later today. Knight Oil contacted there technical personal, the result was that damage could occur and wasn't recommended to test from above. Have contacted ExxonMobil Engineering they have recommended following testing produce while breaking out and installing BHA through DSA 11" x 4-1/16". Planning on starting milling operations tomorrow AM. I concur with the following: Tom Tom, Would like a variance of maximum test pressure per procedure after initial AOGCC BOP and stack equipment. Testing DSA break when installing coil BHA. 1. Test against cement plug, ins«dd of top of BOP rams (causing damage pe, —night Oil Tools). 2'. Instead of procedure request of 8000# test to 2500# limiting pressure exposure to 9-5/8" casing. Need your endorsement of above procedure. Thanks, WellWork Team -----Original Message ----- From: Crisp, John H (DOA) [mailto:john.crisp@alaska.gov] Sent: Sunday, March 02, 2014 5:45 PM To: Peterson, James M /C Cc: Noble, Robert C (DOA); Grimaldi, Louis R (DOA); Denman, Erika /C; Juranek, Tom A; Cox, Mirick T; Hawthorne, Brian K; Greene, Timothy L; Dennis Collins (drecollins1953@yahoo.com); Regg, James B (DOA); Winter, Cassondra E; Farrar, Kendall N Subject: Re: AOGCC Test Witness Notification Request: ROPE, Point Thompson Unit #2 Thank you all for working with us. It will be a pleasure to witness this PT. My cell is 240-1259. When I arrive on the Slope I will also have 448-1227. Again, thanks for the help. Sent from my iPhone On Mar 2, 2014, at 5:39 PM, "Peterson, James M /C" <james.m.peterson@exxonmobil.com> wrote: > Bob, > Will push back BOP test back until Tuesday, would like to start testing at 10:OOAM. Will give you a call on Monday night to confirm and exchange numbers of person we will have meeting and leading you to our location from 0 mile marker. > Regards, Jim > From: Noble, Robert C (DOA) [mailto:bob.noble@alaska.gov] > Sent: Sunday, March 02, 2014 3:01 PM > To: Peterson, James M /C; Grimaldi, Louis R (DOA) > Cc: Denman, Erika /C; Crisp, John H (DOA); Juranek, Tom A; Cox, Mirick > T; Hawthorne, Brian K; Greene, Timothy L; Dennis Collins > (drecollins1953@yahoo.com); Regg, lames B (DOA); Winter, Cassondra E; > Farrar, Kendall N > Subject: RE: AOGCC Test Witness Notification Request: BOPE, Point > Thompson Unit #2 > James > Tomorrow is change out day and I will be the only one on the slope. I am committed to Repsol tonight and tomorrow. > So We need to push your BOP test back a day. If you have problems with this please feel free to give Jim Regg a call @ 793-1236. > We will need to touch base tomorrow evening to get an inspector and timing lined up. So please call around 5:30 pm tomorrow @ 659 2714. > Bob > Bob Noble > AOGCC > 333 W. 7th Ave. Ste. 100 > Anch AK. 99501 > Cell 907-299-1362 > From: Peterson, James M /C [mailto:james.m.peterson@exxonmobil.com] > Sent: Sunday, March 02, 2014 10:50 AM > To: Grimaldi, Louis R (DOA) > Cc: Noble, Robert C (DOA); Denman, Erika /C; Juranek, Tom A; Cox, > Mirick T; Hawthorne, Brian K; Greene, Timothy L; Dennis Collins > (drecollins1953@yahoo.com<mailto:drecollins1953@yahoo.com>); Regg, > James B (DOA); Winter, Cassondra E; Farrar, Kendall N > Subject: RE: AOGCC Test Witness Notification Request: BOPE, Point > Thompson Unit #2 > Louis, > Plan on being ready to test BOPE and Coil stack tomorrow at 11:00 AM. Will have one of our personnel associated with the project meet you at the start of the ice road (zero mile marker) at 9:30 AM so they can show you to our location. > Call with any questions or concerns. > Regards, > James (Jim) Peterson > ExxonMobil > Workover Supervisor > Cell: 281-610-6630 > Email: > james.m.peterson@exxonmobil.com<mailto:james.m.peterson@exxonmobil.com > Email: leyvapeterson@aol.com<mailto:leyvapeterson@aol.com> > From: Peterson, James M /C > Sent: Thursday, February 27, 2014 9:32 AM > To: 'Grimaldi, Louis R (DOA)' > Cc: Noble, Robert C (DOA); Denman, Erika /C; Juranek, Tom A; Cox, > Mirick T; Hawthorne, Brian K; Greene, Timothy L; Dennis Collins > (drecollins1953@yahoo.com<mailto:drecollins1953@yahoo.com>); Regg, > James B (DOA) > Subject: RE: AOGCC Test Witness Notification Request: BOPE, Point > Thompson Unit #2 > Louis, > Details of 10k BOPE equipment and coil quad stack equipment below. We will be testing 11" BOPE equipment separate from the 4-1/16" Coil equipment. As requested on the phone I will send you an update the evening before as to when we will plan on testing equipment. If we get to work later today or tomorrow 11" BOPE would be on Saturday. As stated I will update up the evening before. > Thank You, Jim > Cell: 907-891-5838 > Phone 907-865-9912 > [cid:image001.png@01CF363C.D8D8FAB0] > From: Grimaldi, Louis R (DOA) [mailto:lou.grimaldi@alaska.gov] > Sent: Thursday, February 27, 2014 7:56 AM > To: Peterson, James M /C > Cc: Noble, Robert C (DOA); Denman, Erika /C; Juranek, Tom A; Cox, > Mirick T; Hawthorne, Brian K; Greene, Timothy L; Dennis Collins >(drecollins1953@yahoo.com<mailto:drecollins1953@yahoo.com>); Regg, > James B (DOA) > Subject: RE: AOGCC Test Witness Notification Request: BOPE, Point > Thompson Unit #2 > Mr. Peterson, > Thank you for the update. This event is a high priority test and will be witnessed. I would appreciate your continued timely notification. If possible a morning update as to your progress would be appreciated such as , stack assembled or nearing completion, etc. > Again thank you for your update. > Lou > Louis R. Grimaldi > Petroleum Inspector > Alaska Oil and Gas Conservation Commission > 907-776-5402 (Home) > 907-252-3409 (Cell) > Lou.Grimaldi@Alaska.gov<mailto:Lou.Grimaldi@Alaska.gov> > From: Peterson, James M /C [mailto:james.m.peterson@exxonmobil.com] > Sent: Thursday, February 27, 2014 7:47 AM > To: Grimaldi, Louis R (DOA) > Cc: Noble, Robert C (DOA); Denman, Erika /C; Juranek, Tom A; Cox, > Mirick T; Hawthorne, Brian K; Greene, Timothy L; Dennis Collins >(drecollins1953@yahoo.com<mailto:drecollins1953@yahoo.com>) > Subject: RE: AOGCC Test Witness Notification Request: BOPE, Point > Thompson Unit #2 > Gentlemen, > With the weather shut down today this test will be a day or two later, also we had a notification in to test BOPE today that will not occur also due to high winds today. > Thank You > James (Jim) Peterson > ExxonMobil > Workover Supervisor > Cell: 281-610-6630 > Email: > james.m.peterson@exxonmobil.com<mailto:james.m.peterson@exxonmobil.com > Email: leyvapeterson@aol.com<mailto:leyvapeterson@aol.com> > From: Grimaldi, Louis R (DOA) [mailto:lou.grimaldi@alaska.gov) > Sent: Wednesday, February 26, 2014 7:17 PM > To: Peterson, James M /C > Cc: Noble, Robert C (DOA) > Subject: RE: AOGCC Test Witness Notification Request: BOPE, Point > Thompson Unit #2 > Update both myself and Bob Noble tomorrow mid-afternoon please. > Lou > Louis R. Grimaldi > Petroleum Inspector > Alaska Oil and Gas Conservation Commission > 907-776-5402 (Home) > 907-252-3409 (Cell) > Lou.Grimaldi@Alaska.gov<mailto:Lou.Grimaldi@Alaska.gov> > From: James Peterson [mailto:noreply@jotform.com] > Sent: Wednesday, February 26, 2014 12:07 PM > To: DOA AOGCC Prudhoe Bay > Subject: AOGCC Test Witness Notification Request: BOPE, Point Thompson > Unit #2 > [jotform.com] > Question > Answer > Type of Test Requested: > BOPE > Requested Time for Inspection > 2-28-2014 9:00 AM > Location > Point Thompson Unit #2 > Name 6 > James Peterson > E-mail > james.m.peterson@exxonmobil.com<mailto:james.m.peterson@exxonmobil.com > Phone Number > (907) 891-5838 > Company > ExxonMobil > Other Information: > Testing Schlumberger Coil BOPE Estimated test date 2.28.2014. > Submission ID: >259257991922434905 > <image001.png> 7 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, March 07, 2014 1:00 PM To: 'Juranek, Tom A' Cc: Greene, Timothy L; Peterson, James M /C; Collins, Dennis /C; Dennis Collins (Personal); Farrar, Kendall N; Cox, Mirick T; Dragnich, Rob /EXT; Bill Penrose (bill@ solstenxp.com); Denman, Erika /C; Winter, Cassondra E Subject: RE: Point Thomson #2 P&A (PTD 177-064) Tom, You have approval to place diesel temporary in the OA . this will be recovered once the final cement is placed at surface. Guy Schwartz Senior Petroleum Engineer %014ED AOGCC 907-301-4533 cell 907-793-1226 office From: Juranek, Tom A [ ranek@exxonmobil.com] Sent: Friday, March 07, 2014 12:40 PM To: Schwartz, Guy L (DOA) Cc: Greene, Timothy L; Peterson, James M /C; Collins, Dennis /C; Dennis Collins (Personal); Farrar, Kendall N; Cox, Mirick T; Dragnich, Rob /EXT; Bill Penrose (, iwi� , . ); Denman, Erika /C; Winter, Cassondra E Subject: Point Thomson #2 P&A (PTD 177-064) Guy, As we just discussed on the phone, we have successfully pumped a bullhead cement job on the 9-5/8" by 13-3/8" annulus. However, after the job, the annulus went on a vacuum. We plan to pump fluid into that annulus so that we can pressure up and hold back-up pressure on the 9-5/8" casing. Because of freeze concerns when we cut the wellhead off but before we run the 1" pipe in the annulus to top off the cement job (or place cement from at least 150' to surface), we plan to pump a small amount of diesel. We will pump no more than 5.8 barrels of diesel (100' in the annulus). If additional volume beyond 5.8 barrels is needed, we will then pump CaCI brine. The diesel will swap with the CaCI brine and leave us 100' (max) of diesel in the annulus. We will recover this diesel after we cut off the wellhead by running 1" tubing. The diesel will be recovered just prior to pumping cement to top off that annulus. Please let me know if you have further questions or need anything further. Thanks, Tom Juranek Subsurface Engineering Advisor EMPC Global Engineering -Houston Subsurface Engineering & Operations Support CORP -EMB -3021J Lync Phone: 832-624-6940; Fax: 713-656-7353; iPhone: 832-596-5406 email: tom.a.iuranek@exxonmobil.co P " A-z— Pry Regg, James B (DOA) 1-71064-C) From: Regg, James B (DOA) Sent: Thursday, March 06, 2014 5:02 PM To: Peterson, James M /C; Crisp, John H (DOA); DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA) Cc: Denman, Erika /C; Juranek, Tom A; Cox, Mirick T; Hawthorne, Brian K; Greene, Timothy L; Dennis Collins (drecollins1953@yahoo.com); Winter, Cassondra E; Farrar, Kendall N Subject: RE: AOGCC Test Witness Notification Request: BOPE, Point Thompson Unit #2 Per our conversation this afternoon: 1) OK to test as described below (against casing/plug to 2500 psi)- this well (PTU #2) only; need to come up with different approach for wells that involve perforating 2) please send morning report when working on well to Guy Schwartz (email address above) and DOA AOGCC Inspector address (that captures all Inspectors and myself) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501�� 907-793-1236 -----Original Message ----- From: Peterson, James M /C[mailto:james.m.peterson@exxonmobil.com] Sent: Thursday, March 06, 2014 4:13 PM To: Crisp, John H (DOA); DOA AOGCC Prudhoe Bay Cc: Noble, Robert C (DOA); Grimaldi, Louis R (DOA); Denman, Erika /C; Juranek, Tom A; Cox, Mirick T; Hawthorne, Brian K; Greene, Timothy L; Dennis Collins (drecollinsl953@yahoo.com); Regg, James B (DOA); Winter, Cassondra E; Farrar, Kendall N Subject: RE: AOGCC Test Witness Notification Request: BOPE, Point Thompson Unit #2 While testing BOPE and Coil BOP stack equipment a concern was raised about testing above 11" blind rams by AOGCC personal witnessing this test. All equipment has been tested and passed and other block valves tested per request. Results will be emailed to AOGCC later today. Knight Oil contacted there technical personal, the result was that damage could occur and wasn't recommended to test from above. Have contacted ExxonMobil Engineering they have recommended following testing produce while breaking out and installing BHA through DSA 11" x 4-1/16". Planning on starting milling operations tomorrow AM. I concur with the following: Tom Tom, Would like a variance of maximum test pressure per procedure after initial AOGCC BOP and S equipment. Testing DSA break when installing coil BHA. 1. Test against cement plug, instead of top of BOP rams (causing damage per Knight Oil Tools). V1 L5/2. Instead of procedure request of 8000# test to 2500# limiting pressure exposure to 9- 8" casing. Need your endorsement of above procedure. Thanks, WellWork Team -----Original Message ----- From: Crisp, John H (DOA) [mailto:john.crisp@alaska.gov] Sent: Sunday, March 02, 2014 5:45 PM To: Peterson, James M /C Cc: Noble, Robert C (DOA); Grimaldi, Louis R (DOA); Denman, Erika /C; Juranek, To A; Cox, Mirick T; Hawthorne, Brian K; Greene, Timothy L; Dennis Collins (drecollins1953 ahoo.com); Regg, James B (DOA); Winter, Cassondra E; Farrar, Kendall N Subject: Re: AOGCC Test Witness Notification Request: BOPS, Point Thompson U t #2 Thank you all for working with us. It will be a pleasure to witness this ➢'T. My cell is 240- 1259. When I arrive on the Slope I will also have 448-1227. Again, than for the help. Sent from my iPhone On Mar 2, 2014, at 5:39 PM, "Peterson, James M /C" <james.m.peteron@exxonmobil.com> wrote: > Bob, > Will push back BOP test back until Tuesday, would like to tart testing at 10:00AM. Will give you a call on Monday night to confirm and exchange nu bers of person we will have meeting and leading you to our location from 0 mile mark > Regards, Jim > From: Noble, Robert C (DOA) [mailto:bob.noble@al ka.gov] > Sent: Sunday, March 02, 2014 3:01 PM > To: Peterson, James M /C; Grimaldi, Louis R ( A) > Cc: Denman, Erika /C; Crisp, John H (DOA); J ranek, Tom A; Cox, Mirick T; Hawthorne, Brian K; Greene, Timothy L; Dennis Collins (drecol ns1953@yahoo.com); Regg, James B (DOA); Winter, Cassondra E; Farrar, Kendall N > Subject: RE: AOGCC Test Witness Notific ion Request: BOPE, Point Thompson Unit #2 > James > Tomorrow is change out day and I wi be the only one on the slope. I am committed to Repsol tonight and tomorrow. > So We need to push your BOP test ack a day. If you have problems with this please feel free to give Jim Regg a call @ 79 -1236. > We will need to touch base to rrow evening to get an inspector and timing lined up. So please call around 5:30 pm to rrow @ 659 2714. > Bob > Bob Noble > AOGCC > 333 W. 7th Ave. Ste. 00 > Anch AK. 99501 > Cell 907-299-136 > From: Peterso , James M /C[mailto:james.m.peterson@exxonmobil.com] > Sent: Sunda , March 02, 2014 10:50 AM > To: Grima i, Louis R (DOA) PJ Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, March 06, 2014 11:34 AM To: Bill Penrose Cc: Tom Juranek (tom.ajuranek@exxonmobil.com); 'Regg, James B (DOA) Oim.regg@alaska.gov)' Subject: PT #2 P &A (PTD 177-064) Bill, As we discussed it looks like a Master valve would be a good idea in order to PT the wellhead after BHA swapouts (instead of using the Blind rams). I didn't think of that during review of the sundry. I know were are planning on setting 9 5/8" CIBPs so you need a large ID 10K valve gate valve. Hard to find I expect. If you don't need the full 11" ID a smaller MV may be easier to find. Alternatively , the riser flange break could be tested to against the 9 5/8" casing but that is not a good idea since there are going be perfing the casing multiple times for cement circulations. Also, Were you going to drill a pilot hole and then under ream the surface cement? It is not detailed in the procedure so was unsure of your planned bit sizes. One more note... I may have missed adding some additional pressure testing on your proposed procedure. Two additional pressure tests of the casing are added. 1) pressure test the 9 5/8" casing to 2500 psi after step 9 to ensure you still have casing integrity after milling thru the surface cement and before you start perforating. 2) If you stick to the original program (left diagram) then test the new bottom plug to 2500 psi before setting the top 9 5/8" CIBP at 200ft. We will need to discuss your new proposal in detail before I sign off on it. (Arctic pack removal is big unknown). CIDP @ ±200' C'1 4^f r Submitted "Most -Likely" Guy Schwartz Senior Petroleum Engineer AOGCC Current "Most -Likely" 1 • • V OF T41.., yw //j;cV THE STATE Alaska Oil and Gas ofAL VK 1 Gc servat cFComi ssi011 GOVERNOR SEAN PARNELL '�*h 333 West Seventh Avenue 01Anchorage, Alaska 99501-3572 AL ASg� Main: 907.279.1433 ,4� � 0 1�14 � Fax: 907.276.7542 Irene T. Garcia SCN4HE'D SSHE Manager ExxonMobil Oil Corporation /� PO Box 196601 ' - 0 IU I Anchorage, AK 99519 Re: Point Thomson Unit, Point Thomson Unit#2 Sundry Number: 313-601 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 a) day of December, 2013. Encl. ' Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, December 05, 2013 8:58 AM To: Juranek, Tom A Cc: Dragnich, Rob /EXT; Denman, Erika /C Subject: RE: PTU#3 P & A ( PTD 178-005) prat 0 7 177 - oho`-( Tom, Your proposed change to the surface plug placement is acceptable for the affected wells in the upcoming P & A program. It provides an equal or better barrier than two separate cement plugs. I will file this email as record in the well history. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Juranek, Tom A [mailto: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 1 SCANNED C10 0 ±200' IPJ Submitted "Most -Likely" Current "Most -Likely" From: Schwartz, Guy L (DOA) [ ,-tn 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) 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 5-95 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 [ pnmobil.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. 2 - 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 Pn'r31i: 1C?nl.l it,r?nPl',n PYxn.nrnnhii. coo From: Schwartz, Guy L (DOA) [_ iailto:guy.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 [ k@exxonmobil.coml 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: to_m.a.luranek exxonmobil.com From: Schwartz, Guy L (DOA) [ ailto-guy sch_wartz@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" packo. (10K x 51(psi) adaptor installed as well as the new tubing head. The IA valves are 5K so 1 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 Akik, 2, `T .ti RECEIVED STATE OF ALASKA 0, ALASKA OIL AND GAS CONSERVATION COMMISSION NOV i. APPLICATION FOR SUNDRY APPROVALS ����� 20 AAC 25.280 1.Type of Request: Abandon Q • Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. J ' 5-....,c..... 44 Q' 2.Operator Name: 4.Current Well Class: 5.Permit to DriN Number: /2,Y,6 Exxon Mobil Corporation Exploratory D . Development ❑ 177-064 • 3.Address: Stratigraphic ❑ Service CI6.API Number: PO Box 196601,Anchorage,AK 99519-6601 SO-088-20006 ' 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#2 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 47567 ' Point Thomson Unit ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): 1) ,Total Depth ND(ft):`f t3 Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): /4/ I1713,i 1 it -'' 1"• `'1)11 7two--;,)1:-" 0 0 Many plugs,see schematic None Casing Length Size MD ND Burst Collapse Structural 88' 28"x 36" 88' 88' N/A N/A Conductor 842' 18-5/8" 842' 842' 2,420 630 Surface 3,296' 13-3/8" 3,296' 3,296' 5,380 2,670 Intermediate 10,099' 9-5/8" 10,099' 10,099' 7,510 5,600 Production 7,593' 7" 14,103' 14,103' 12,460/13,700 10,760/13,010 Liner N/A N/A N/A N/A N/A N/A Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory Q . Stratigraphic❑ Developmen[] Service El 14.Estimated Date for 15.Well Status after proposed work: February 1,2014 CommencingOperations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned Q Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tom Juranek 713-656-4225 Email tom.a.juranek@exxonmobil.com Printed Name Irene T.Garcia Title SSHE Manager Signature GI' � Phone 907-564-3773 Date `//,s-y, COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity Wr BOP Test Mechanical Integrity Test ❑ Zai' Location Clearance Er -t Other: '1 &OD pSe- 536 f -7;:51— casi n l ,P ecte_. c(..4.1.-"_. _ H� cw1--aed i. we„,/ .e.4 'AI" J /`�'�a c{o ,-,/ - RBDMS AY 09 20i Spacing Exception Required? Yes 11 No LYJ Subsequent Form Required: /� `-/D� � (i , /9 74).e._447_,_ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: /Z-X —13 R3 \ 76/2 11/3 /� "/A04, c „ K �\I A� Submit Form and ,�.� Form 10-403(Revised 10/2012) Appr p 11 a II�I♦M months from the date of approval. Attachments in Duplicate ��i r RECEIVED • ExxonMobil Production Company P.0.Box 196601 NOV 201 Anchorage,Alaska 99519-6601 907 561 5331 Telephone AOGCC E)xonMobil Production November 15, 2013 R-2013-OUT-020 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#2 (PTD No. 177-064) Dear Commissioner Foerster, VI 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. Attempt to place cement isolation in the 9-5/8" casing and annulus near the 13-3/8" perforations at 2,874'—3,060'. Methods to accomplish this include: - Bullheading cement down the 9-5/8" annulus to ±2,874', setting a CIBP in the 9-5/8" casing at±2,900', and laying cement from ±2,900' to ±2,400'. - Circulating cement into the 9-5/8" casing and annulus through perforations in the 9-5/8" at±2,800'. The 9-5/8" casing and annulus would be cemented from ±2,800' to surface. - Squeezing the 9-5/8" annulus through perforations at ±2,800'. The annulus would be cemented from ±2,874' to ±2,800' and the 9-5/8" casing would be cemented from ±2,800' to ±2,400'. - Squeezing the 9-5/8" annulus through perforations at ±3,350'. The annulus would be cemented at±3,350' and the 9-5/8" casing would be cemented from ±3,400' to ±2,400'. 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 • • Ms. Cathy Foerster 2 November 15,2013 If you have any questions or require additional information, please contact me at (907) 564- 3773 or Tom Juranek at 713-656-4225. Sincerely, 0/—)144 a-ilk- Irene T. Garcia SSHE Manager Attachments: • Sundry Application Form 10-403 • Proposed Work Procedure including before and after wellbore diagrams POINT THOMSON ('� PRODUCTION POINT THOMSON UNIT#2 WELL HISTORY AND ABANDONMENT PROCEDURE Affected Wells and API/APTD Numbers: Point Thomson Unit#2 API# 50-089-20006 APTD#: 177-064 Background: Point Thomson Unit #2 was drilled in 1978. The well was suspended in September, 1978. 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 below ground level consistent with current AOGCC regulations. In addition, for improved long term integrity of the abandonment, a cement plug is planned for inside and outside the 9-5/8" casing near the perforations in the 13-3/8" casing at 2,874'. The current well schematic is attached to this procedure. The Maximum Anticipated Surface Pressure (MASP) is 0 psi as the reservoir section of the well is effectively isolated and no pressure was found during a wellhead inspection in 2009. However, in an abundance of caution and because the top cement plug will be penetrated, the work will be performed assuming a"worst case" scenario of the highest anticipated surface pressure (±7,900 psi)encountered below the surface plug based upon Thomson Sand reservoir pressures. Therefore, the wellhead will be upgraded to 10k psi rating and BOPs and the Coil Tubing Unit will be rated to 10,000 psi. OBJECTIVE: • Drill through the surface cement plug at 40'-100'. • Place cement isolation plugs in the 9-5/8" casing and annulus near the 13-3/8" perforations at 2,874'—3,060'. Methods to accomplish this include: o Bullheading cement down the 9-5/8" annulus to ±2,874', setting a CIBP in the 9-5/8" casing at±2,900', and laying cement from ±2,900' to±2,400'. o Circulating cement into the 9-5/8" casing and annulus through perforations in the 9-5/8" at ±2,800'. The 9-5/8" casing and annulus would be cemented from ±2,800' to surface. o Squeezing the 9-5/8"annulus through perforations at±2,800'. The annulus would be cemented from ±2,874' to ±2,800' and the 9-5/8"casing would be cemented from ±2,800' to ±2,400'. o Squeezing the 9-5/8"annulus through perforations at±3,350'. The annulus would be cemented at±3,350' and the 9-5/8" casing would be cemented from ±3,350' to ±2,400'. • 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#2 Abandonment Procedure ; "` � POINT THOMSON (' 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" perforations at±2,874'. 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±42'). Install a 13-5/8" 5K psi x 13-5/8" 10K psi 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. 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 ±42' -±120'. 9. Clean out the 9-5/8" casing to±3,450'. 10. If unable to bullhead cement(step 3 above), circulate warm fluid to heat the arctic pack. 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" perfs at±2,874'. If successful, set a 9-5/8" CIBP at±2,900' and lay cement in the 9-5/8"from ±2,900' to ±2,400'. 11. If bullhead attempts were unsuccessful, perforate the 9-5/8" casing at±2,800' and attempt to establish circulation down the 9-5/8" and up the 9-5/8"x 13-3/8" annulus. If successful, set a CIBP at±2,850' in the 9-5/8 casing and circulate cement from ±2,800' 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 2,800' to the 13-3/8" perfs at 2,874'. If able to squeeze, set a CIBP at±2,850' in the 9-5/8" casing and squeeze cement from ±2,874' to ±2,800' in the 9-5/8" annulus and from ±2,800' to ±2,400' in the 9-5/8" casing. 13. If unable to circulate or squeeze with perforations in the 9-5/8" casing at±2,800', repeat steps 11 and 12 with additional 9-5/8" perforations at±2,600'. Point Thomson Unit#2 Abandonment Procedure fttioro 4 POINT THOMSON k PRODUCTION (' N 14. If unable to squeeze into perforations at±2,600', perforate the 9-5/8" casing at±3,350' (below the 13-3/8" shoe)and attempt to inject. If injectivity is established, set a CIBP at ±3,400' in the 9-5/8 casing and squeeze cement through the perfs in the 9-5/8" at ±3,350', leaving cement from ±3,350' to ±2,400' in the 9-5/8" casing. 15. If injectivity is still unsuccessful, set a CIBP at±3,400' in the 9-5/8" casing and lay cement in the 9-5/8"from ±3,400' to ±2,400'. 16. Set a CIBP in the 9-5/8" casing at±200'. 17. 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. 18. Fill the 9-5/8" casing with cement from ±200' to surface. 19. Rig down the Coiled Tubing Unit. 20. Excavate deep enough to allow removal of the wellhead at least 3' below original tundra level. 21. 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. 22. Cut and remove the wellhead using a Wachs saw. 23. 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. 24. Run 1"jointed pipe inside the 32"x 36" conductor casing as deep as possible. Leave jointed pipe in hole for cementing to follow 25. 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 23, 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. 26. Pump cement to surface in both conductor annuli. Top off 28" x 32" x 36" refrigerated/insulated conductor casing with cement as required. 27. 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. Point Thomson Unit#2 Abandonment Procedure fl, R W„.,' POINT THOMSON • ' EII ; PRODUCTION 28. Cut all strings flush and top off the 9-5/8" casing and annuli with cement as required. 29. 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#2 Exxon Mobil Corporation PTD# 177-064 API# 50-089-20006 30. Backfill cellar with gravel. Mound the gravel (5-10')to compensate for summer thawing and settling as per AOGCC guidance. 31. 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#2 Abandonment Procedure 1111111111111111111 POINT THOMSO N - 16PRODUCTION r). Exxon Mobil Corporation Pt. Thomson Unit#2 API#: 50-089-20006 PTD#: 177-064 Current Well Schematic 10.6 ppg CaCl2 or diesel? I r i'''' V Ye. ; , Cement plug in 9-5/8"casing at 42'-120' a 4.0'4 , '4. V l. (17'-95BGL) Sr, �t- . $-Ii '� ", �'�; '" ' / ,� �� 28"x 36" insulated conductor at 88', Arctic Pack in 9-5/8"x 13- s .,, . . cemented to surface with permafrost cement 3/8"Annulus s ; s . ',..../ 10.6 ppg 9 ¶ '` ` CaCl2 CaCl2/Mud interface at 2,300' s ° / /rte ..!* I.,-a ",,, , 18-5/8"casing at 842', cemented w/4,700 x * '' 12.2 ppg ", permafrost cmt " Mud *' . _13-3/8" perforated at 3,060'-2,874' 4 ` 13-3/8", 72#, N/L 80 casing at 3,296', cmtd w/ 4 6,800 sx permafrost cmt � s 9-5/8" Baker model D packer at �� .. t�� Perforations 5,860'-5,861.5', block squeezed 5,820'with 20 bbl cement on top r '� . w/125 sx class G b, ` � + 1 Perforations 5,864'-5,886', squeezed w/6 bbl f e cmt . `. gt 9-5/8" retainer at 5,915' _-....a 4 ►� ,,,. ,'a. `;` } ` ' Perforations 5,930'-5,931.5', block squeezed -,7-`.. -,'`" 7 ' w/110 sx class G cmt TOC @ 6,860'per temp survey w 4' 4 75 sx class G cmt plug in 9-5/8° '.�� .a r \,,..-v-', e csg 6,240'-6,450' 4„S" .-. .f,'. 'e+ 07 0". 15.3 ppg mud 7"casing stub at 6,510' 4 4 9-5/8", Soo-95, 43.5#, csg at 10,099', cmtd w/ 7"retainer at 11,480'w/4 bbls ,.,, 1,430 sx class G L> (3w,44-- 7 S"!� p S� cmt on top .,0 0,-.1 ti'. ►tet TOC behind 7"casing at 10,660' Baker F-1 packer at 11,528' �`... ' " 'i t. s .. Perforations at 11,580'-11,678', squeezed ",' j w/ 125 sx class G cmt ,t?";`,rfdrx.04034x, isi 7"retainer at 12,696'with 4 bbl cmt ti - Y. Perforations at 13,020'-13,080', on top - a* squeezed w/ 125 sx class G cmt , r Total Depth 14,117' C ; ;: _„ , • ;s 7"csg at 14,103' cmtd w/1,750 sx class G Point ttiaftiroifdi*T I i i nt° k tt ; � • POINT THOMSON • 14F PRODUCTION�� Exxon Mobil Corporation Pt. Thomson Unit#2 API#: 50-089-20006 PTD#: 177-064 Proposed "Most-Likely" Post-P&A Well Schematic Marker •late at-3' BGL PF cmt in 9-5/8" x 13-3/8" 4,' ` r Z �„4*+�w"^'' �V ,� annulus from ±200' to surface „,,L. ' }' « Cmt plug in 9-5/8" csg ±200' to surface Perfs in 9-5/8"csg just above CIBP @ ±200' %���� 28" x 36" insulated conductor at 88', cemented to surface with permafrost Bridge plug at±200' 1! $. cement Arctic pack in 9-5/8"x 10.6 ppg 13-3/8" annulus from $,, CaCl2 , CaCl2/Mud interface at 2,300' ±200' - ±2,800' r :'v 18-5/8"casing at 842', cemented w/ $ % 4. 4,700 sx permafrost cmt Perfs in 9-5/8" at 2,800' and annulus squeezed w/cmt '17.4t11-:•"• 'V ;/ , Cement in 9-5/8" casing 2,800'-2,400' Cmt in 9-5/8" x 13-3/8" ' Mon---- 4 .� Bridge plug at 2,850' annulus from ±2,800'-2,874' ;C",5.-, 13-3/8" perforated at 3,060'-2,874' "� 13-3/8", 72#, N/L 80 casing at 3,296', cmtd w/6,800 sx permafrost cmt o t ,� Perforations 5 860 -5,861.5', block 9-5/8" Baker model D packer � y—_ yr , t • tl l} P �C fie: 1 at 5,820 with 20 bbl cement -" r , {•�* squeezed w/ 125 sx class G on top ,ir�lk� ' Perforations 5,864' -5,886', squeezed _ r-51,421; , w/6 bbl cmt •M.y 9-5/8" retainer at 5,915' t ' $ 7,-, Perforations 5,930' -5,931.5', block $ squeezed w/ 110 sx class G cmtt TOC @ 6,860' per temp survey ,., 75 sx class G cmt plug in 9- *,:; fik` `• „ } 5/8" csg 6,240' -6,450' : *'V . .`,% .31 gip•' ;.$ 15.3 ppg r',$ 7" casing stub at 6,510' 7" retainer at 11,480' with 4 n I 9-5/8", Soo-95, 43.5#, csg at 10,099', ,A cmtd w/ 1,430 sx class G bbls cmt on top ���'t, Baker F-1 packer at 11,528' ' ��� ��� TOC behind 7"casing at 10,660' Perforations at 11,580' - 11,678', squeezed w/ 125 sx class G cmt ,,,k1* 11111111111111•1111 ,' 7" retainer at 12,696' with 4 bbl '��� ' Perforations at 13,020' - 13,080', cmtt on top ' squeezed w/ 125 Sx class G cmt Total Depth 14,117' " l 7" csg at 14,103' cmtd w/ 1,750 sx class G Point Thomson Unit#2 Proposed Most-Likely Sketch °, POINT THOMSON 16 PRODUCTION ___, BOP Configuration (7,- ''' ''''. -?r:-------,.,--:-li 7 , ; , ‘ 1.1111,1itt 1 Injector Head for 26" coiled tubing iv,..„,., „,, ----- Dual pack-off <----- 4Zi5" ID 10k Lubricator as needed (6' &8' sections) 1, i Blind ' .: SIIps SLB C ad BOP, ft 10k rII.1 I-, _l Pipe a. - i ..w 04/44 110, 11" 10k x d 1/16n,10k x-o< - ° (flange to be used for BHA changes) il ' i..r. ink Spacer Spool,3 ft Ems'. r 11". Zak Flow Cr u 10 ft #� ' a(..,-.—.:11 I I rill ®fl 11",10k Wind Ram I.; i 1',I0k Blind/Shear Rafn ' '€---- Wellheads to be upgraded to 1.0 k service Point Thomson Unit#2 Planned BOP Assembly x „ ; . ,;- „; . E F," ° Schwartz, Guy L (DOA) From: Juranek,Tom A <tom.a juranek@exxonmobil.com> Sent: Wednesday, December 04, 2013 12:47 PM To: Schwartz, Guy L(DOA) Cc: Dragnich, Rob/EXT; Denman, Erika/C Subject: RE: PT-1 PT-2 and Staines River State#1 Pr3 /77 O . Y Attachments: WSS#18-9-23 Isolation Sleeve.pdf pra- Guy, The PTU #1, #2. #3 were all heritage Exxon wells with McEvoy (now Cameron) wellheads. They are all configured similarly and be using the same extended packoff to upgrade. The WSS#2 and SRS#1 are heritage Mobil wells with FMC wellheads. Conceptually, they will be upgraded similarly to the Cameron wellheads (replace 5k psi Tubing Head with 10k psi Tubing Head and use upgraded seals to isolate the 5k portion of the wellhead). I don't have a good diagram of the FMC seals/wellhead. Please let me know if I need to get one from FMC to forward to you. The WSS#18-9-23 is an older version heritage Mobil well with a Vetco (now GE) wellhead. This was a multibowl design which didn't lend itself to a similar upgrade as Cameron or FMC. Instead an isolation sleeve had to be designed and built specifically for this wellhead. A diagram of their isolation sleeve is attached. Please let me know if you have further questions or need anything further. Tom Juranek From: Schwartz, Guy L(DOA) [maolto guy.schwartz;uaiaska.gov] Sent: Wednesday, December 04, 2013 2:04 PM To: Juranek,Tom A Subject: PT-1 PT-2 and Staines River State #1 Tom, From what I read these wells(PT-1, PT-2 and Staines River St.#1) are also using the same type of extended packoff in order to upgrade to 10K? Is the same packoff being used? What about West STaines ST.#18-9-23? That appears to have a different isolation sleeve into the existing tubing head. If so please forward the diagrams for that for our files. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 1 Y N in r A,, (N Q4 N gof a) ao _7,-.: N 0) \ iiiQ E in M` O in ~ rte) N U Y N o t q Li Oil N Z t• N tIA 2 ..,.. ....7- Q. �__4-__4-- -_J 4x3zIfi:b- JJ :--- Y i I c o U► t j Zw \ �''� Oin .j.., f s __Ji L___-� Q I 0J O Q w Cd Cf) I J I— A 1 CLi ....1 Mir l - Ulli 1111111111111H1 0 I __,+__ . , , i i JI Q I 11 1 ,_ W - . i i i i , . . J Q I- W 0 0 M Y Ln Lf-) di o Q I o co o Io Ln of I O co rD ,--- a --- - CD CO _, M - z MD 1 II o U) d N U 00 I \ LO ■ II 1111111111111All ININNOW1 c O cola 0 O a. cz czL U Y , MMM•• I _ — , r Ii 1 1 L I , , , .._,r STATE OF ALASKA • ALA.OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations [] Perforate LJ Other U Inspection Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension El Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Na me: Exxon Mobil Corporation Development ❑ Exploratory 0 177-064 , 3.Address: PO Box 196601 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6601 50-089-20006-0000 • 7.Property Designation(Lease Number): 8.Well Name and Number: RECEIVED ADL 47567 • Point Thomson Unit#2 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): ,G n 2 4 20- N/A Point Thomson • r� 11.Present Well Condition Summary: Total Depth measured 14,103 feet Plugs measured See Attached feet true vertical 14,103 feet Junk measured N/A feet Effective Depth measured surface feet Packer measured N/A feet true vertical surface feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural 88' 36"x 28" 88' 88' N/A N/A Conductor 842' 18-5/8" 842' 842' 2,420 psi 630 psi Surface 3,296' 13-3/8" 3,296' 3,296' 5,380 psi 2,670 psi Intermediate 10,09W 9-5/8" 10,099' 10,099' 7,510 psi 5,600 psi Production 7,593' 7" 14,103' 14,103' 12,460/13,700 psi 10,760/13,010 psi Liner N/A N/A N/A N/A y N/A N/A Perforation depth Measured depth N/A feet q+CAS Gi✓ In I True Vertical depth N/A feet Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): None Treatment descriptions including volumes used and final pressure: No Treatment 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A 0 psi N/A Subsequent to operation: N/A N/A N/A 0 psi N/A 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Well Photographs Exploratory Q , Development❑ Service El Stratigraphic ❑ Daily Report of Well Operations See Attachment 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP El • SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Tom Juranek(713-656-4225) Email tom.a.iuranekftexxonmobil.com Printed Name Irene T.Garcia Title Alaska SSH&E Manager Signature 1 �' Phone 907-564-3773 Date 9/19/2013 \1,�, �V"' ` 'J HI 3DMS al 1 r O 3J Form 10-404 Revised 10/2012 V �� /3 Submit Original Only ExxonMobil Production Come hen arcia P.O.Box 196601 SSH&E�lanager Anchorage,Alaska 99519-6601 907 564 3773 Telephone 907 564 3719 Facsimile EonMob.il Production September 19, 2013 R-2013-OUT-009 Mr. Guy Schwartz Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: 2013 Report of Sundry Well Operations Point Thomson Unit#2 (PTD No. 177-064) Dear Mr. Schwartz: ExxonMobil hereby submits a Report of Sundry Well Operations for the wellhead inspection of the Alaska State C-1 well on the North Slope. The well is currently suspended, and the inspection was performed for purposes of planning the future abandonment of the well. Attached please find: • Form 10-404: Report of Sundry Well Operations • Well Schematic • Well Inspection Summary • Photographic documentation If you have any questions or require additional information, please contact Tom Juranek at (713)-656-4225. Sincerely, 44A't-t N d' IG:ed:gg Attachment A Division of Exxon Mobil Corporation . • • Exxon Mobil Corporation Pt. Thomson Unit#2 Well Schematic API#: 50-089-20006 PTD#: 177-064 Wellhead 13-5/8"A section with 13-5/8", 5K flange on top 10.6 ppg CaCl2 or diesel? s -. , . Cement plug in 9-5/8" casing at 42' - 120' '. /■' (17'-95' BGL) ''''4. P." . :' ' ' ' 4" . :�„ ,< 28° x 36" insulated conductor at 88', Arctic Pack in 9-5/8"x `.' 0.' -` cemented to surface with permafrost 13-3/8"Annulus j 10.6 • ' cement y/ PP9 CaCl2 ;,1 s 18-5/8" casing at 842', % s cemented with 4,700 Sx NNNNNNYNNNYNVf CaCI /Mud interface at 2,300' permafrost ' .0 .2 <. 12.2ppg i s Mud +i 13-3/8" perforated at 3,060' A-' —2,874' s • i ? 13-3/8". 72#, NIL 80 casing at 3,296', cemented with 6,800 Sx permafrost cement• 9-5/8"Baker model D packer at ���.. �'�� 5.820' with 20 bbl cement(TOC Perforations 5,860'-5,861.5'. block at 5.553') ' squeezed with 125 Sx class G Perforations 5,864' -5,886'. squeezed with 6 bbl cement - 9-5/8" retainer at 5,915' - Perforations 5,930'-5,931.5', block TOG @ 6.860' per temp squeezed with 110 Sx class G cement survey 75 Sx class G cement plug in 9- . . • 3 5/8"casing from 6,240' -6,450' " ` 15.3 ', 7"casing stub at 6,510' j PP9 mud j 9-5/8", Soo-95, 43.5#, casing at 10.099'. 7" retainer at 11.480'with ` T cemented with 1,430 Sx class G imunim 4 bbls cement on top --.---_,041,_5 BOkwr F-1 narkar at 11,528' ►�� 11;1'741 TOC behind 7"casing at 10.660' Total Depth 14,117' •4> Perforations at 11,580'- 11.678', squeezed with 125 Sx class G Cement 7" casing at 14,103', cemented with 1.750 Sx 7" retainer at 12.696'with 4 bbl 'ump.-- --"!..'a class G cement on top Perforations at 13,020' - 13,080'. squeezed with 125 Sx class G cement Well schematic prepared by Fairweather E&P Services, Inc Last updated May-2009. • Point Thomson Unit #2 Operations Summary A site and well head inspection was conducted in order to facilitate future P&A activity scheduled for winter of 2013. The wellhead inspection was warranted to ascertain well head part numbers and determine presence and height of 9 5/8" casing extending above A-section. Attached is summary of operation and photos. 08-13-13: Arrived on location @14:45. Excavated around wellhead, installed pressure gauges, verified 0 psi on 9 5/8" and annulus. Removed bleeder valve from top of blind but unable to run camera due to only 1/4" hole at bottom of nipple. Removed LDS from CH, ran screwdriver through LDS, felt presence of stump. Unable to verify height with camera due to encroaching fog. Replaced LDS. Secured well, filled in excavation. Departed for Deadhorse 15:50. CH assbly# B562090. 13 5/8"-5k. Adapter 13 5/8" x 4 1/16 2013 Site Inspection Point Thomson Unit#2 • 0 . -.... . ,.. t.- • - -' - -, -- • - ii.i. .4. ,4 .• , fe4.711pieltt„ ., i'a,..„ir,_, . .... ,.• • , ...I... ...F.!,1. __a -'",4.7. . 1 ''- ,.../e," ;•t. ,, .0, , ..,.9..„ „,..,,,...-„•,..-, +low 'if 11 i - .... t ,4,.. 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' " i"... .'..".04-, .!!''• '41., '", ti.-,• ' , 4-.., - --=').- Excavation 2013 Site Inspection Point Thomson Unit#2 r 0 •7,% vr e e i .. < f e � A t f ° „ View of tapped hole in bottom of blind nipple. �.x t ""..0 °„},mac'% ✓ ` . , 4,,,, ..-.>14,.."-, sa r 44:' Well as left. 2013 Site Inspection Point Thomson Unit#2 McMains, Stephen E (DOA) From: Schwartz, Guy L (DOA) p 311- 6 Sent: Monday, April 01, 2013 9:27 AM To: McMains, Stephen E (DOA) Subject: FW: Vault installation on PTU #3 and Alaska State C -1 Steve, I talked with Cathy and she is agreeable to change the status from P & A to Suspended on the wells listed below. Can you update RBDMS please to reflect that . '~- " �-^�•^ Point Thomson Unit #1 (PTD 176 -085) Point Thomson g ni PTD 177 -064 Staines River State #1 (PTD 179 -001) SCANNED .PR 17 201. Guy Schwartz Senior Petroleum Engineer AOGCC 907 -444 -3433 cell 907 - 793 -1226 office From: Schwartz, Guy L (DOA) Sent: Monday, April 01, 2013 9:22 AM To: 'Wong, Gilbert' Subject: RE: Vault installation on PTU #3 and Alaska State C -1 Gilbert, April 29 th (Monday) would be agreeable for a meeting... let me know what time of day works. Usually early afternoon is good for me. Guy Schwartz Senior Petroleum Engineer S�v0 AOGCC RBDMS APR 01 ZO13 )) 907- 444 -3433 cell 907 - 793 -1226 office From: Wong, Gilbert [mailto: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 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: gilbert.wongPexxonmobil.com From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.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 . 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 AOGCC 907- 444 -3433 cell 907 - 793 -1226 office 2 ;=rzasa nkf, GLH Vieoductoanwn Catmip P. O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimile September 23, 2009 Commissioner Cathy P. Foerster Alaska Oil and Gas Conservation Commission 333 West 7 1 Avenue, Suite 100 Anchorage, Alaska 99501-3539 Alaska Production Manager Joint Interest U.S. RE: Request for Verification of Suspended and Shut-in Well Information Dear Commissioner Foerster: Production �t1J; SEP 2 4 2009 f Awtn" Olt & U'Fis Cow". C! -fm t xmilw " 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, e_ DDP:jpc SWRED 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 JJ Location and Well inspected 3/2009. /7(-" '��� Location and Well inspected 4/2009. /77- O & V '70 Location and Well inspected 4/2009. 1 I — Q� Location and Well inspected 4/2009. -%9 • Further remediation work planned for the 2009-10 winter season Location and Well inspected 4/2009. ,��� • �`7`U Well inspected and remediated and site cleared in 4/2009. 123. Location and Well inspected 4/2009. 7 %• Q6)'1 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~ss~c~;~o~a~ ~n~eiae~tioe~ Com~an9+ Joinf Interest U.S. - Alaska P.O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3789 Facsimile June 17, 2009 ~~ ~ V ~~~~~~~~~~~ ~ ~(.~~ .`sIF, ~ ~j~~)~ t~~9S~~ ~f~ s,~t t" ;, .7~.~ ~t~il~. ~'tlp7'j~ISSlqg~ E on Mobi~h~'~~~° ~ ~~o~~~~aoa~ ~ ~~~~~~~ Mr. Johnny L. Aiken, Director ~ i ~, ~~ ~,, ~ North Slope Borough Planning and Community Services Department ti~- ~ P.O. Box 69 GA~~ I"' Barrow, Alaska 99723 Q ~ ~ R e: T u n d r a T r a v e l C o m p l e t i o n Repo rt h~ ~~. ~ ~ . orhSDh ~ ~ Po,h~ ~M Dear Mr. Aiken: ,y~ l" Please find attached our 2009 Winter Tundra Travel Completion Report as required by North Slope Borough Conditional Use Permits. This Tundra Travel Completion Report pertains to the following activities authorized by the above permits: - Ice Road Construction from the Endicott causeway to the Point Thomson Unit Central Pad - Ice Road Construction to the Alaska State C-1 water source and other lakes from which water was withdrawn. - Tundra Travel /Ice Road Access - Point Thomson Unit Central Pad Mobilization & Construction - Well Inspections and Remediation The attached report reflects Tundra Travel activities through closure of the Alaska State C-1 ice road on May 19th, 2009, and includes the following elements: 1. Actual routes of travef 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 ~xxoe~ 6t~~bi6 ~~~p~rat6~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 DM~W 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 #2 PTD No. 177-064 Sundry No. 309-084 Dear Commissioner Seamount: 1~~~~~~¢'~~ ~~ UE ~'~,~ U~ ~ Y.t ~ ~~ ~~~~t4a~ ~r~9 c~ ~r~~ ~E~~.d. ~~'~aitpl#SS~u;, E~~nMobil ~~~~°°~~~~ Production Exxon Mobil Corporation hereby submits its Report of Sundry Well Operations for the wellhead inspection of the Point Thomson Unit #2 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. S~c.~- ~ ~~,1,~~ ~~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 instaHed on the wellhead side outlets, and a new finro inch ba!! valve and needle valve were installed to top flange. At the completion of the well inspection, the excavation was backfilled and the top : wellhead section was left above grade level to allow easier access for future wellhead inspections. ~ 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, ~ ` t'~ D. Michael Barker Environmental and Regulatory Manager JAR:eaa Attach m ents A Division of Exxon Mobil Corporation STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~~ ~° ~ ~ ~~~ ~.y: ~~~?~<~ ~g ~ ~O~J~+ 1. Operations Abandon Repair Well Plug Perforations Stimulate ~^ ~~ p~ fSS~~~:: Performed: Alter Casing ~ Pull Tubing ^ Perforate New Pool ~ Waiver^ Time Extension ~~h~r~~ ~ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ~ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Exxon Mobil Corporation , Development ^ Exploratory0 777-064 . 3. Address: PO Box 196601 Stratigraphic^ Service^ 6. API Number: Anchorage, AK 99519-6601 50-089-20006 • 7. KB Elevation (ft): 9. Well Name and Number: 49 Point Thomson Unit No 2~ 8. Property Designation: 10. Field/Pool(s): ADL 47567 Point Thomson 11. Present Well Condition Summary: t, r?`j i y, ~i7 ~ ~. ~.. ~ Total Depth measured 14 ~ feet ~~ ~,? Plugs (measured) Plugged to Surface true vertical 1 s,~ . feet ~~~ Junk (measured) None / ~ ~ ~~~ Effective Depth measured Surface feet ~~ ~ true vertical Surface feet Casing Length Size MD TVD Burst Collapse Structural 88' 28" & 36" 88' 88' N/A N/A Conductor 842' 18 5/8" 842' 842' 2420 630 Surface 3296' 13 3/8" 3296' 3296' 5380 2670 Intermediate 10099' 9 5/8" 10099' 10099' 6720 5600 Production 7593' 7" 14103' 14103' 12460 / 13700 10760 / 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: ~3. Representative DailyAverage Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Weil Photographs Exploratory^~ ~ Development ^ Service ^ Daily Report of Well Operations See attachments 16. Well St,~tus ~ter w : !8a en ~j~Q '~i ~1--~C~ ~~~ ~ ~ ~ Oil ~ p y'~~Gas WAG ^ GINJ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowiedge. ~> ,~ ~.f~ Sundry Number or N/A if C.O. Exempt: ~ ~ ` 309-084 Contact Mike Barker Printed Name Mike Barker Title Environmental and Regulatory Manager Signature ~~ Phone (907) 564-3617 Date Z~s+i ~' Form 10-404 Revised 04/2006 ~~~~~~ ~;~'~ ~~~~ ~ z, ~~~~~ ~ ,~'~~~,"~~Submit Origi n y~ ~ ~-- ~ ~ - ~ Daily Operations Log Point Thomson Unit #2 Well Inspection Wednesday, March 25, 2009 • Set up work site, and excavated to 6" below the top flange. • Cleaned area of inetal and concrete rubble into dumpster. • Cleared concrete off of wellhead using a jack-hammer. • Wrapped well, applied heater trunk and fueled all equipment. Thursday, March 26, 2009 • Actuated valve, removed plug and installed test manifold. Pressure tested valve to 250/5000 psi for 5 min. Obtained good test, R/D. • Opened valve and verified that there is no VR plug. • Prepared, installed and functioned new valve. Rigged up to test same for 5 min at 250/5000 psi. Good test. • Clear work area of tools, trash and changed out teeth on Excavator. • Inspected 13 5/8" flange connection for any way to check for pressure, zero . pressure. • Found 4" line pipe (marker post) is threaded into the 4"-5K flange. Investigated alternatives to welding 2" collar onto pipe for hot tapping. UT gauge showed the pipe wall to be 0.237" thick. • Tried to find VSP pipe, using photos and metal detector. • No VSP pipe found at described location. Friday, March 27, 2009 • Installed chains and padlock on wellhead valve. • Sorted debris from gravel while backfilling excavation. • Prepared camp for move in the morning to PTU#3. • The Operation moved on to perform well inspections on other wells and came back to finish PTU#2 on Saturday, 04-18-09. Saturday, April 18, 2009 (Returned to PTU #2 to complete inspection) • Mobilized tools and equipment sleighs to PTU#2. Applied heat to marker post and installed mechanical tee. • Rigged up hot-tap machine on 4" marker post (4" sch. 40 line pipe) and pressure tested mechanical tee to 500 psi. F/5min. Obtained good test. • Hot tapped into pipe and found no pressure. Rigged down and cut 4" line pipe above capped sch. 80 nipple. • Checked metal thickness with UTG and determined the cap welded to nipple was .223(1 /4"). • Welded a 2" XX 160 nipple on top and rigged down hot-tap machine. Pressure tested to 500 psi for 5min., obtained good test. Hot tapped through it and found no pressure. R/D hot-tap and cleaned up job-site. Fit 2"ported bull plug with a 1/2"needle valve and plug on top of 2"(6K) valve attached to welded nipple. PTU 2 Casing spool is 24" tall M~E~oy spi~t Speedhead System 4" LP 2" ball valve, bull plug and needle valve 3-1/8" 5k. MPN# McEvoy Model "C" 13 5/8" 5k. -~ 3-1/8 5K psi 0 0 McEvoy O needle valve IA & OA v alve s a re 3-1 /8 5k Serial #08-11-2562 model 120+ 3-1/8 5K psi O E~cxon Mobil Corporation Pt. Thomson Unit #2 Well Schematic API #: 50-089-20006 PTD #: 177-064 Wellhead 13-5/8" A section with 13-5/8", 5K flange on top 10.6 ppg CaCl2 or diesel? ¢ 1 `~, ~ 4~~`;.. ,,r~ Cement plug in 9-5/8" casing at 42' -120' ~- ' ;" ~n ~ ; ~; (17'-95' BGL) . • ~j.+,~ ~ \ ;~ :!R' r°. 5~~~: ;;~ 28" x 36" insulated conductor at 88', ,..,., Arctic Pack in 9-5/8° x a`' '~~'~ '.'~ cemented to surface with permafrost 13-3/8" Annulus 10.6 ppg '~ cement CaCl2 ~ r° ~ 18-5/8" casing at 842', T. ..~ cemented with 4,700 Sx n. ` ~~~~~~~~~titi ~ CaCl2/Mud interface at 2,300' permafrost ~ ~~ ~ ~ .2 122 ~-~ ~•:•• PPJ Mud ;~ s~~ 13-3/8" perforated at 3,060' ~' "~ - 2,874' ~ ~ ~ 13-3/8", 72#, N/L 80 casing at 3,296', cemented with 6,800 Sx permafrost cement 9-5/8" Baker model D packer at ''- ~ 5,820' with 20 bbl cement (TOC ~ ~~" ~ ~' Perforations 5,860' - 5,861.5', block ~ at 5,553') s •- ,: ` r' sQUeezed with 125 Sx class G - -r ' . ,; Perforations 5,864' - 5,886', squeezed with 6 '' ~. ~r j',~'. . ~~ ~, :~~ ~ ` bbl cement R ~ ~. . r , ` .u , , . , ,,,, : •~^a " s 5 , 9-5/8" retainer at 5,915' ,. _ ~ , • "~ ~~e ~ ~~ -"~ s Perforations 5,930' - 5,931.5', block TOC @ 6,860' per temp ~ ~ squeezed with 110 Sx class G cement survey W ~•` ~~ ~ ~~s 75 Sx class G cement plug in 9- ~° .::,~ ~,~ ~ ~ :' ~ . = ;~.~ 4 ~ .'s 5/8" casing from 6,240' - 6,450' y:, '' .s M~ ~' ppg y>> 15.3 k:«:. ftS .~ ~[ ~ 7" casing stub at 6,510' ~ mud ' .] 's g_5/8", Soo-95, 43.5#, casing at 10,099', 7" retainer at 11,480' with ~_ .~,rw ~_ , ~ ,: ~. ~ cemented with 1,430 Sx class G , 4 bbls cement on top ' ` ~ Bakar F-1 nar.kar at 'I 1,528' ~~ ~.+' ~` ` 1 . ~ TOC behind 7" casing at 10,660' ~ `~ ` ` - ~ Total Depth 14,11T ~ , . ~,~ ~ Perforations at 11,580' - 11,678', squeezed ~~; ~ with 125 Sx class G Cement 7" retainer at 12,696' with 4 bbl cement on top Well schematic prepared by Fairweather E& P Services, Inc. ~ast updated May-2009. ~ ~., y:~ 7" casing at 14,103', cemented with 1,750 Sx ~ ~ Y . .~ ~ ~ class G • ~ ~ Perforations at 13,020' -13,080', fi. .~~_~• i• _ .,- ~ fi., '~a squeezed with 125 Sx class G cement ,~, ; ,, ~ W W N M N N ~ ~ r_-_ _ - .T--_. -_,~__ ----'~'---.~ ~__ ~_.._.- _~.... ,_-~~._.., i ~ ~ BEAUFOR T ~ SEA j I I ~ ~ , ~ i I 29 ,I 28 ~ 27 ( 26 ~ 75 30 , ~ ~ ~ i ! ~ ~ Point Gordon 4 ~ I Poinf Sweeney ~ G--------_~-__-. -- ---t ---~-----~-~ ---- -•--I ~ ~ I ~ ~f~ ~ _i - < /~/~~~ ~ ~ ~~---~ , ~ ~ ~ ~ . i" ~ I ~ 32 ~~3 ~ 34 - i'~, 35 36 `( 3~ ~ ~ ( ~ ~ ~ ~~ ' n i i ~ ~ , ''~______~. ~_.. _._,.T 10 N ~ --j-~ EXXON No.2 POINT THOMPSON UNIT ~ T g N LAT. = 70°09~47.76~~ ~"'~ ~ ~ 4 ~ 3 ieoi.~ X N 435693055.48~~ i ~ 6 ~ I I ;~ ~ , ~ ~~ Y= 5~909, 5 I 3, ~ ~.__~_.... ~ -- ~-~-~~--,~ _..i_ ~_ ~.,- --- --------i ~ I ~ I I ; ~ ~ ~ I ~ e ~ s ~. ~o I i i ~ iz ~ I t I ~ ~ i ~ i ------ - ---t--- ---~------ _1 _~._.._ ---_-----I ~ ! i I ~~ ~ ~ ~ , I I I ~, ~~ i Ifi/ ': ~~~ 15 i 14 ~ /' 13 IH I 3 ~ i ~ i ;,~ ` ~ ~ 1 f j ' I ~--- , --l------1__-----j------- -.~-__- -----~~ SCALE~ 1~~ = 1 MILE ~ CERTIFICATE OF SURVEYOR I hereby certify that I am properly registered and ! icensed to practice land surveying in the State of Alaska ond that this pla.t represents a location survey made by me or under my super~ision, and that ail dimensions and other detaiis are correct. ; ~ ~ / ~° ~' ~ ~ ~ ~, l 1 ! l !~~ ~+~ D~te ,~ SURVE R AS STAKED JULY 19,1977 -~ 'IMF FA Iry Ilt left— » 1 w; :~ ~ .M .y ~ ~ ~ ~ ~ ~ ~' ~' , ~ ~~ , r . 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Aric~' 4 , ~~' , ~ ',t~~_~•~ ~~.~. .:.Nil~-~ ~ ~ •~_ . . ~ - .~ ~+L~~ ~i=s~ ~~S'" i_°~ `' ~ . ~~1J.~'~~ ~ ~. , t aa` •'~ta+~~ ~., ^ ., ~ `~ , ~° ~ ~~ ~_ ~ ~ ~{. ~ ~~. `- +~ i. ~~-:,i~ . , ~f • ,.1 ~ ^~ ~~' ` y~ r .i j~ ~ r~ i - ~ .~`t ~ . !~ ` ~ ~~ ~, ~-~`+7-~ .~ .:~ _y.~ °~ .~•_• 1r . .p`~__4 . .~ .~``;~~. ~' ~~g .. ~~p ~ - , ~:.i~; ~~'~ : ~ 4 ~ { ~1"~~ .i' ',~ „'~' „~,~.~~ . fk "'!t ~~ ^ _ _ `_ _ ~ ~ y~ ~.._ '- ~r 1. ..~~. .-~ , ,;,, •. ~ ~ ~ '• ;; ~ _~ ,; ` v. . l .y ,~u/ / ~ . . :' . ~~' ~ PTU#2 new ~alves r~ ~ , ~- .4 - t _._... . • . `• - . ~ -~ ~~~- r - . ~ _ .,~ ~ .~,: ~ ~~~, ° ,.~.,.. ~ _ ~„'~' _ ,~ _. r .s ~ : 't , ~_{" ~ 1~~~~~~J~~~~'J~ .IJI~JJ~~A`I :m ~~' ~~f ' ~~'~~1 ~ j~Ci <.~. i~~kii~V3 ~W~i'.~s.~ai~~ii i s'~C~i~. v~Y~3 1 ~~~~~~ 1r3or~~a~, :~~rr ~'~, ?~~~ ~J:'? ~~~~ ~°.~,e iii~~+~rtder, 1 ~3fli~tas ~ (~~~, ~~ab~~c~~o ~~: ~~GG~ ~€~e~d~,~ ~~~ic~ ~~~r~r.s ~a~ vr~:~~i~~~~ ~=~~4c~ ~p~~:~~rii?~s Tom, the -reports for the 9 well inspection/remediation wor;~ at Point T~omson left my office this afternoon. Thanks ior your patience, I'm now loo:cing for contractors to ~id the work to for the next winter~s work for the 3 well remediation efiort. Ii you have any questions regardinq the recent work or next winter's anticipated work. please ca11, Reqards, Jack Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, May 28, 2009 7:18 AM To: jack.a. rickner@exxonmobil.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 min~~te crunch. ~ c;all or message with any aetails. Tom Maunder, PE AOGCC -----Original Message----- From: jack.a.rickner@exxonmobil.com Sent: Thursday, May 28, 2009 7:14 AM To: Maunder, Thomas E (DOA) Subject: AOGCC Sundry Notice Reports [mailto:jack.a.rickner@exxonmobil.com] for Completed Field Acitivities Tom, just a note to let you know I haven't been idle. Finally completed all the wellhead drawings, have all the attachments and photos together for all 9 wells. The package has been provided to our inhouse legal folks for there blessing. Hope to have their check off within a day or two. Will deliver to your office as soon as they catch my grammatical and spelling errors. Currently we are tentatively scheduling the summer stick picking work for Juiy. Moving ahead on planning the winter remediation work for the PTU-4, West Staines #2, and the West Staines 18-9-23. Our current plans are to start the permittinq, contracting, and procedure development (includinq which type of equipment to drill through the bridge pluqs) this summer in hopes of avoiding a last minute crunch to obtain permits and equipment. That is our hope anyway. If you have any questions, please call. Regards, Jack Jack A. Rickner Pt. Thomson We11 Inspection & Remediation Project 907-564-3783 281-217-4350 = °^~..,~':~ _ ~.d ^ / M111~1C~~9', ~h019'D13 ~ ~~~~1~ From: Maunder, Thomas E (DOA) Sent: Monday, May 11, 2009 8:18 AM To: fVatasha Sachivichik Cc: jack.a.rickner@exxonmobil.com; Bill Penrose Subject: RE: PTU well inspection project AOGCC report status Thanks Natasha. That schedule should work. Tom IMaunder, PE AOGCC From: Natasha Sachivichik [mailto:natasha.sachivichik@fairvveather.com] Sent: Monday, May 11, 2009 8:16 AM To: Maunder, Thomas E (DOA) Cc: jack.a.rickner@e~oconmobil.com; Bill Penrose Subject: RE: PTU well inspection project AOGCC report status To m, Sorry far delayed reply. We should have the reports ready by the end of this week or beginning of the n~xt week the latest. Thanks and regards, NatASha Sachi.vicH%!2 Senior Drilling Engineer Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 Direct:907-343-0405 Cell; 907-575-7156 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: rnu-~aay, May 07, 2009 12:29 PM To: Natasha Sachivichik Cc: jack.a.rickner@e~oconmobil.com; Bill Penrose Subject: RE: PTU well inspection project AOGCC report status Natasha, et al, What sort of time frame are you looking at to submit all reports? I understand that submitting everything can help operationaf efficiency. Tom From: Natasha Sachivichik [mailto:natasha.sachivichik@fairweather.com] 5r~#: Th~rs~w`f, M3y 0?, 20Q9 ? 1:14 en,- To: Maunder, Thomas E (DOA) Cc: jack.a.rickner@e~oconmobil.com; Bill Penrose Subject: PTU well inspection project AOGCC report status 6/24/2009 _'°w?.~~+i< G p~:~ i ~~ Pll, 1 am writing in regards to the yesterday°s phone conversation between you and Bill Penrose about the status of the Sundry reports for 9 wells inspection and remediation project performed by ExxonMobil. The field operations compieted on April-24-2009. I would like to con~rm that we are aware of the 30 days requirement to submit the reports and are currently working on generating these reports. Could you please let me know if you would like all 9 Sundry reports submitted at the same time. Thanks and regards, Natasl~a sach~vCcH~f~ Senior Drilling Engineer Fain+veather E8~P Seroices, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 Direct:907-343-0405 Cell: 907-575-7156 6/24/2009 9Viaunder9 ~hornas E (DOA~ From: Maunder, Thomas E (DOA) Sent: Monday, March 23, 2009 10:14 A(~ 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.dragnich@exxonmobil.com; mike.barker@exxonmobil.com Subject: RE: Wellhead Inspection Program Tom, we have a couple of concerns. From a safety standpoint, we would prefer not to leave an open excavation. And we are not sure if an open excavation would collect and retain water during the summer and then freeze as the temperatures cool. Not sure how this might impact tubing and needle valves through time. At this point, we think that we have three scenarios. (1) The wellhead basically at or above ground/pad level. (2) the wellhead just at or slightly below pad level. (3) the wellhead below at perhaps 3-4 feet below pad/ground level. If the well head is above the normal grade of the well pad, we would install the new gate valve(s), flange with 1/2" NPT threads, needle valve(s), and plug(s) in the end of the needle valve(s). That would allow us to read pressures in the summer time with relative ease. If the wellhead sections are just slightly below the pad level, we would like to leave the wellhead exposed and the valve(s) in place, flanged with needle valve(s) and plug(s) as above. There might be a slight dip in the surface of the pad but not significant. If the wellhead is some depth below grade (perhaps 3-4 feet), we have a number of options. It is this situation that I would like to discuss. We could: As proposed in our curren procesures, install new 3" gate valves (left in open positionj, flange with lj2" needle valve (left in open position), install 3/8" stainless tubing to the surface and have a second needle valve present so that pressures could be read (needle valve left closed, gauge removed and plug inserted in needle valve opening). The tubing could be banded to the wellhead and to the above ground marker. 1 we could install che new gate valve (le"rt in closed posicion), flange; wi~h 1/2'~ needle vaive 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 however l do realize tnere is aiso a risk about surtace 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; ~arch 21, 2009 3:a1 PN_r To: Maunder, Thomas E (DOA) Subject: Wellhead Inspection Program Tom, would you be available Monday morning to discuss a question regarding E~onMobil'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 ~~~~~ ~~~~ ~ ~~ ~ ~ d ~ ' 4 ~ ~~~ ~ ~. ~ ~ ALASSA OIL A1~TD G~S C01~5ERQATIOI~T COMl-IISSIOI~T Craig Haymes Alaska Production Manager E~onMobil Production Company PO Box 196601 Anchorage AK 99519-6601 Re: Point Thomson Unit, Pt. Thomson Oil Pool, PTLJ #2 Sundry Number: 309-084 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 well as "currently suspended " However the status of this well accordin~ to the_ offi~iai A(~(`~(" rec~rds is s'tLll P&A, although as the Comrrussion pouzted out in previous correspondence this is one of several wells so classified that appear not to meet all of the applicable regulatory requirements for plugged and abandoned wells. We appreciate your inspection efforts as described in the application. ExxonMobil has submitted a request to chan~e the classification of tYus well to suspended status, but the Commission has not yet acted on that request. Approval of tYus inspection work proposal does not constitute ar implv a decision on the request to change the well classification. When providing notice for a representative of the Commission to witness any required test, contact the Commissiori s petroleum field inspector at (907) 659-3607 (pager) . As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for 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 following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ~ 17~ DATED ttus _ day of March, 2009 Sincerely, Daniel T. Searz~ount, Jr. Chair Encl. ~f~' ~~~~1~~~ ~~,~ ~ U ~~ STATE OF A~ASKA ~-'~1~ OQ9 3--^' ~y ~~ ~O ~lb ALASKA OIL AND GAS CONSERVATION COMMISSION ~FEB 2 6 2 ,~./ ~~~° 3 APPLICATION FOR SUNDRY APPROVA L fi~,~~ ~~~~ ~~n~, C,mnmission ` 7 ~ 2n aac 2s2ao ~~5~ 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ^ PerForate ^ "G~/ai'ver Other^~ Alter casing^ Repair well ~ Plug Perforations ~ Stimulate ^ Time Extension ~ Site Inspection Change approved program^ Pull Tubing~ Perforate New Pool ~ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exuon Mobil Corporation Development ~ Exploratory ~ 177-064 - 3. Address: Stratigraphic ~ Service ~ 6. API Number: PO Box 196601 Anchorage, AK 99519-6601 50-089-20006 " 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~q Spacing Exception Required? Yes ^ No ^ Point Thomson Unit No 2- 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 47567 ~ 49 - 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): 14,103 14,103 Surface Surface See Attached None Casing Length Size MD TVD Burst Collapse Structural 88 36" x 28" 88 88 N/A NIA Conductor 842 18 5/8" 842 842 2420 630 Surface 3296 13 3/8" 3296 3296 5380 2670 Intermediate 10099 9 5l8" 10099 10099 6720 5600 Production 7593 7" 14103 14103 12460/13700 10760/13010 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NIA N/A N/A NIA N/A Packers and SSSV Type: Packers and SSSV MD (ft): NIA NIA 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ^ Exploratory Q Development ^ Service ^ 15. Estimated Date for 16. Well Status after proposed work: March 1, 2009 Commencing Operations: Oil ^ Gas ^ Plugged ^~ Abandoned ^ 17. VerbalApproval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Barker I Jack Rickner Printed Name Craig A. H~ mes Title Alaska Production Manager Signature Phone (907) 564-3617/(907) 564-3783 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ Plug Integrity ^ BOP Test [] Mechanical Integrity Test ^ Location Clearance ~ Other: `"' I wE~\~~ ~ o.`~~~~ec~.uc~~n ~~~~ v~ c ,r- ~ ` ~ ~ ~= ~ ~ ~~n ~ ~ ~ p s 1 , Subsequent Form Required: ` ` (~ ~ ~ ~ G~ C-~ ~ ~2T`CC~ t~ O"'~ ~'~h\ ~. v~1 ~ ~,~ ~. APPROVED BY / I ~ I ~ ~ Date: ( Approved by: COMMISSIONER THF~ O MISSION , } • -•••• •- •~••••~••••••~• ~~•Y~~ . . t S Y1T°~3TE8@'L~P •.: 4vv~t 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 Jt. Interest U.S. ~~~~~~ ~ ~E~ 2 6 ZQQ9 February 25, 2009 Mr. Dan Seamount Chairman Alaska Oil and Gas Conservation Commission 333 West 7~h Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Application to Inspect Exxon Mobil Corporation Point Thomson Unit #2 PTD No. 177-064 Dear Commissioner Seamount: ~laska t?ir & Ga~ ~,~~s. ~o~~~~si~ . E~o n M o i ~~~~~,~~~~ 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 welf 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 Schematic 3) Inspection Procedure 4) Photo of the Wellhead/Abandonment Marker at Present If you have any questions or require additional informafion, please contact Mike Baricer at 564-3617 or Jack Rickner at 564-3783. Sincerely, r~'T-z=- - e - / ~ CAH:eaa Attachments A Division of Exxon Mobil Corporation ExxonMobil Corporation Pt. Thomson Unit #2 Well Schematic API #: 50-089-20006 PTD #: 177-064 Wellhead 13-5/8" A section with 13-5/8" x 3" flange on top 10.6 ppg CaCl2 or diesel? Arctic Pack in 9-5/8" x 13-3/8" Annulus 18-5/8" casing at 842', cemented with 4,700 Sx permafrost 13-3/8" perforated at 3,060' - 2,874' 9-5/8" Baker model D packer at 5,820' with 20 bbl cement (TOC at 5,553') TOC @ 6,860' per temp survey 75 Sx class G cement plug in 9- 5/8" casing from 6,240' - 6,450' 7" retainer at 11,480' with 4 bbls cement on top Baker F-1 packer at 11,528' 7" retainer at 12,696' with 4 bbl cement on top Total Depth 14,117' Cement plug in 9-5/8" casing at 42' - 120' (17'-95' BGL) 28" x 36" insulated conductor at 88', cemented to surface with permafrost cement CaCl2/Mud interface at 2,300' 13-3/8", 72#, N/L 80 casing at 3,296', cemented with 6,800 Sx permafrost cement PerForations 5,860' - 5,861.5', block squeezed with 125 Sx class G Perforations 5,864' - 5,886', squeezed with 6 bbl cement 9-5/8" retainer at 5,915' Perforations 5,930' - 5,931.5', block squeezed with 110 Sx class G cement 7" casing stub at 6,510' 9-5/8", Soo-95, 43.5#, casing at 10,099', cemented with 1,430 Sx class G TOC behind 7" casing at 10,660' Perforations at 11,580' - 11,678', squeezed with 125 Sx class G Cement Perforations at 13,020' - 13,080', squeezed with 125 Sx class G cement 7" casing at 14,103', cemented with 1,750 Sx class G Well schematic drawn June 29"', 2007 by Jesse Mohrbacher, Fairweather E 8~ P Services, Inc. Updated Feb 13, 2009 by Natasha Sachivichik, Fairweather E& P Services, Inc E~cxon Mobil Corporation Pt. Thomson Unit #2 API #: 50-089-20006 PTD #: 177-064 Inspection Procedure Backqround Well Information The Point Thomson Unit #2 well was drilled in 1978. 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 cement plug set at 42'-120' RKB (17'-95' BGL). Below the surFace cement plug there is 10.6 ppg CaCl2 brine (120' - 2,300') and 12.2 ppg mud (2,300' - 5,553'), a cement plug is set at 5,553' - 5,820' on top of a production packer at 5,820'. The 9-5/8" x 13-3/8" annulus contains arctic pack from surface to approximately 2,874'. 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 inctude 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 #2 location. 3. Observe and record any signs of leaks in the area surrounding the well. Take photographs clearly showing the condition of the surrounding location. A detailed report documenting any found contamination will be prepared. 4. Heat the gravel around the wellhead. 5. Excavate gravel covering the well and cellar. Ensure access to all side outlets on wellhead sections. Monitor excavation with a four-gas monitor. 6. Install wellhead shelter, and rig up indirect fired hot air heater. Apply heat to wellhead shelter. Pump or vacuum the cellar dry when thawed. 7. Visually inspect the condition of wellhead side outlets valves, bull plugs, needle valves, test/grease ports, lock down screws, etc. Take photographs clearly showing the condition of the wellhead as found. Document any areas of concern. 8. Check pressures on the 9-5/8" casing and the 9-5/8" x 13-3/8" annulus. This may require the installation of needle valves and wellhead side out valves to facilitate recording and bleeding off pressures. In addition, operations such as removing VR plugs, hot tapping, and gate valve milling may be required to verify any well pressure. 9. If pressure is observed, then perform diagnostic testing to determine if the pressure is sustained casing pressure or trapped pressure. Record pressure bleed down and build up. In addition, record the fluid type and volume. Take fluid samples for possible analysis. 10. Take photographs clearly showing the condition of the wellhead as left. Backfill the cellar with gravel with allowance for gravel settling with time. 11. Ensure well is safe and secure. Chain & lock close any valves above ground level. 12. Clean up location. Remove any fluid from the well for proper disposal. Take photographs clearly showing the condition of the location as left. 13. Fill out inspection report and file a Report of Sundry Well Operations (Form 10-404). API #: 50-089-20006 PTD #: 177-064 ~~~ }~ . ~ ~ ~ . . . . . ~ ~b!~.... . . 9 .l4 . ~ ~ .. ~ fiR~ ~~'~``~9'`,, ,'r`~ ~~ ..n-' . . _ . . . ... . . ... _ . .: . ~~~=~L: ~_ . . . , y - . . . ~ . . , - .. . ,'~OtR+ - , , ~ '~~ ~ ~ ~ t~. :+~,_ ~_..~ ~,p ~ '°~^ , '.. . -~ r January 29, 2009 CERTIFIED MAIIL. RETURN RECEIPT REQUESTED 7005 1820 0001 2499 5975 William Pecor ExxonMobil Production Company PO Box 199610 SWOED Anchorage AK 99519-6601 Re: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut -In Well Information Dear Mr. Pecor: � -1 -1 - (_g_4k c_) SARAH PALIN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed are the Alaska Oil and Gas Conservation Commission's revised regulations regarding suspended wells (i.e., 20 AAC 25.110). Also enclosed are lists of suspended long-term shut-in and Point Thomson heritage wells operated by ExxonMobil Production Company or your predecessor companies. For each list, please verify the information for each well and provide any corrections by April 1, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with Jim Regg at 907-793-1236 or jim.regg@alaska.gov. If you have any questions regarding this notice, please contact Tom Maunder at 907-793- 1250 or tom.maunder@alaska.gov. Enclosures Sincerely, Cathy P. Foerster Commissioner U.S. Postal Service, CERTIFIED MAIL RECEIPT ' (Domestic Mail Only; No Insurance Coverage Provided) For delivery information visit our website at www.usps.com t 0535 Cerfflod Fee ■ /. E3 Patten PWoW PostmarkP4 W=M— ruHWO LD: • 1 t1 Tatid Postage V S5,.,49 01/30/2009 Ln C3 107ra— William �- • ExxonMobil ProductionCo. .:=-7N-'0&F PO Box 199610 Anchorage 99519-6601 • •• fc r: J�.... .. rt•vw sc u nsF,—ht v E Complete items 1, 2, and 3. Also complete Signa item 4 if Restricted Delivery is desired. s Print your name and address on the reverse r so that we can return the card to you. B. eived ted Name) C. ■ Attach this card to the back of the mailpiece, or on the front if space permits. D. Is delivery ad ss different from Item 1' 1. ARicle Addressed to: If YES, enter delivery address below: William Pecor ExxoIiMObll Production Co. PO Box 199610 Anchorage AK 99519-6601 ❑ Agent ❑ Addre afe of Wel ❑ No 3. S ice Type *7 Cvertified Mail ❑ Express Mail ❑ Registered IVIeturn Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 2. Article Number 700_5 1820 0001 2499 5975 (Transfer from service label) PS Form 3811, February 2004 Domestic Return Receipt 102595-02-M-1540 i 2. Article Number 700_5 1820 0001 2499 5975 (Transfer from service label) PS Form 3811, February 2004 Domestic Return Receipt 102595-02-M-1540 Operator Suspended and Shut ffn WeRs 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 151M SM ADL0018790 Wednesday, January 14, 2009 Operator MOBIL OIL CORP Field Permit API Number Well Name KUPARUK RIVER 181-035-0 50-029-20573-00-00 KUPARUK 28243 1 'wednesd* january 14, 2009 Suspended and Shut IIn WeRtiq Current Date of StatusStatus Surface Location .................................................... Lease(s)................................... SUSP 5/29/1981 470 FSL 605 FWL Sec 17 T 11 N R 11 E UM ADL0028243 ExxonMobil Pt. Thomson Heritage Wells Identified May 18, 2007 in Commission Letter to Craig Haymes AN VVLLL # PTD aperN2me Well Name Field See Twp NIS Rng W/E PM Leases) 50-089-20001- 00-00 1691200 MOBIL OIL CORP W STAINES ST 18-09-23 PT THOMSON 181 9 N 3 2j3--E--J U ADL 0028380 50-089-20004- 00-00 11750020 MOBIL OIL CORP W STAINES ST 2 'EXPLORAT ORY 25 9 N E ! U ADL 002837 l PT k22 __........ ......z 50-089-20005- EXXON THOMSON PT ! l l 00-00 1760850 CORP UNIT 1 THOMSON 32 j 104 N 23 E } U j ADL 0047560 j 50-089-20006- 00-00 1770640 EXXON CORP THOMSON UNIT 2 PT PT THOMSON 3 9 N 22 I E ! U ADL 0047567 50-089-20007- 00-00 1780050 EXXON CORP THOMSON UNIT 3 PT THOMSON 34 10 ' N 23� E U ADL 0047558, ADL 0047559 50-089-20008- MOBIL OIL STAINES PT 00-00 1790010 CORP ST 1 THOMSON 17 i 9 N 24 E I U I ADL 0047573 _RIV 50-089-20009- EXXON THOMSON PT 00-00 50-089-20011- 1790800 M CORP EXXON — UNIT 4 ALASKA ST THOMSON PT 32 10 22 _ E j U ____.._ ADL 0047563 µ 00-00 1800460 CORP C1 THOMSON ' 14 9 j N i 23 I E U j ADL 0028382 50-179-20007- 00-00 1830450 ON CORP ALASKA ST ii PT ITHOMSON 23 ' 6+ N 22 I l E l U i ADL 0344033 20 AAC 25.1 1 . S'uspen ded vvells (a) If allowed under 20 AAC ?.1(S, the con:n]lsslon «-i11, upon applicatlon 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 Suridry Approvals is submitted after be;irnnin� \�orl:, the name of the representative of the commission who provided oral approval, and the date of the approval; and (E) other information pertinent to suspension of the well. (c) At the operator's request accompanying the submission, information submitted to show that the applicable criteria for well suspension under (a) of this section have been met will be kept confidential (1) for the period specified under AS 31.05.035 (c), if the information is described in 20 AAC 25.071(b) ; or (2) for the time that the information has value as a trade secret, if the information is not described in 20 AAC 25.071(b) but is determined by the commission to constitute a trade secret under AS 45.50940 . (d) A well approved for suspension must be plugged in accordance with the requirements of 20 AAC 25.112, except that the requirements of 20 AAC 25.112(d) do not apply if (1) a wellhead is installed or the well is capped with a mechanical device to seal the opening; and (2) a bridge plug capped with 50 feet of cement or a continuous cement plug extending 200 feet within the interior casing string is placed at or above 300 feet below the surface; the commission will waive the requirement of this paragraph for a development well drilled from a pad or platform, if the commission determines that the level of activity on the pad or platform assures adequate surveillance of that development well. (e) Until a suspended well has been abandoned or re-entered, the operator shall maintain the integrity of the location, provide the commission with a well status report every five years, and clear the location in accordance with 20 AAC 25.170(a) (2) or (b) or with 20 AAC 25.172(c) (2) or (d), as applicable. History: Eff. 4/2/86, Register 97; am 11/7/99, Register 152 Authority: AS 31.05.030 KCt,.c1VGL, STATE OF ALASKA �3� MAR 1 8 2008 AL OIL AND GAS CONSERVATION COM 10 APPLICATION FOR SUNDRY APPROVALkaska oil&Gas Cons.Ccammiss# 20 AAC 25.280 1.Type of Request: Abandon': Suspend 2Operational shutdown 0 Perforate ❑ Waiver L_IrIckx�t. Other❑ Alter casing❑ Repair well 0 Plug Perforations❑ Stimulate ❑ Time Extension ❑ Change approved prograrr❑ Pull Tubing❑ Perforate New Pool 0 Re-enter Suspended Well ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: , 71/0 Exxon Mobil Corporation Development ❑ Exploratory ❑ 77-64^• 3.Address: Stratigraphic ❑ Service ❑ 6.API Number:�b PO Box 196601 Anchorage,AK 99519-6601 ,O 50-089-20006 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 0 No 0 Poin homson Unit No 2 . 9.Property Designation: 10.KB Elevation(ft): 11. Field/Pool(s) ADL 47567 49 Wildcat 12. PRESENT WELL CONDITION SUMMARY, Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD\- : Plugs(meas red): Junk(measured): 14,117 14,117 • Surface Surfac- \;. e Attached None Casing Length Size MD VD Burst Collapse Structural 28"&36" 88' `�� (..)88' N/A N/A Conductor 817' 18 5/8" 842' } 8.4 2420 630 Surface 3271' 13 3/8" 3296' 6/ 9 6' 5380 2670 Intermediate 10074' 9 5/8" 1009 ' / 10099' 6720 5600 Production 7593' 7" 14 0 ` 14103' 12460/13700 10760/13010 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: bing Grade: Tubing MD(ft): 2874-3060,5860-5861.5 2874-3060,5860-5861.5 ; /A N/A N/A 5864-5886,5930-5931.5 5864-5886,5930-5931.5 11580-11678,13020-13080 11580-11678,13020-13080 9 • Packers and SSSV Type: Baker F-1,Baker D Packers and SSSV MD (ft): Baker F-1 @ 11528',D @ 5820', Retainers @ 12696',11480'&5915'. 13.Attachments: Description Summary of Proposal Ela' - 14.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory Q Development 0 Service ❑ 15.Estimated Date for 16.Well Status after proposed work: Commencing Operations: Oil 0 Gas ❑ Plugged Q Abandoned 0 17.Verbal Approval: Date: WAG ❑ GINJ 0 WINJ 0 WDSPL ❑ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact William C.Pecor Printed Name William C.Pecor f Title Point Thomson Coordinator Signature /Phone (907)564-3766 Date GJ.t.CP.�r,• Qtc3//4/a 8 COMMISSION USE ONLY j � Conditions of approval: Notify Commission that a representative may witness Sundry Number:3D8 yob Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: This request is to change the classfication from Abandoned to Suspended,no well work is proposed. Subsequent Form Required: k---\ ..)Th ( k) c .\--.\\ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ORIGI V A i RBDMS Lt- FEB 1 1 2016 Form 10-403 Revised 06/2006 Submit in Duplicate • • March 17, 2008 :gzr<Oo n © proauctioll Commissioner Dan Seamoun. >,' a°F, {�(����(�J7 Alaska Cil and Gas Conservation Commission' = � :MY FLS 333 West 7th Avenue, Suite 100 Anchorage; Alaska 99501-3539 MIA 1 8 LOU8 Alaska OilisSiCia Re: Pt, Thomson Wells —Plugging and Abandonment &�� on , om 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 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, Atachv:ents cc Mark Sreiand, ConocoPhillips Once r 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@exxonmobi1.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 ~~l.i ~1 Y 1.~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR Y 8 2008 REPORT OF SUNDRY WELL OPERATION aska Oii & Gas Cons. Camm+ssior~ 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ction . Performed: Alter Casing ^ Puli 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. t~~ ~~'L Name: 6cxon Mobil Corporation Development ^ Exploratory~ 77-64 ° 3. Address: PO Box 196601 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6601 50-089-20006 ' 7. KB Elevation (ft): 9. Well Name and Number: ~ 49 Point Thomson Unit No 2 ' 8. Property Designation: 10. Field/Pool(s): ADL 47567 ' Wildcat 11. Present Well Condition Summary: Total Depth measured 14117 ' feet Plugs (measured) See Attached true vertical 14117 • feet Junk (measured) None Effective Depth measured Surface feet true vertical Surface feet Casing Length Size MD TVD Burst Collapse Structural 28" & 36" 88' 88' N/A N/A Conductor 817' 18 5/8" 842' 842' 2420 630 Surface 3271' 13 3/8" 3296' 3296' S380 2670 Intermediate 10074' 9 5/8" 10099' 10099' 6720 5600 Production 2593' 7" 14103' 14103' 12460 / 13700 10760 / 13010 Liner Perforation depth: Measured depth: 2874-3060, 5860-5861.5, 5864-5886, 5930-5937.5, 11580-11678, 13020-13080 True Vertical depth: 2874-3060, 5860-5861.5, 5864-5886, 5930-5931.5, 11580-11678, 13020-13080 Tubing: (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) Baker F-1, Baker D Baker F-1 @ 11528', D@ 5820' Retainers @ 12696', 11480' & 5915' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daify 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: Pictures from Aug 07 site inspection X Exploratory^~ 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 William C. Pecor Title Point Thomson Coordinator Signature W-G~+C+M~ G:. ~ Phone (907) 564-3766 Date 3 d Form 10-404 Revised 04/2006 ~ ~ Submit Original Only ~ ~~~> .;;1~ ~ ~~ 2D0° ~ </./. oS l~.~~ E~cxon Mobil Corporation Pt. Thomson Unit #2 Well Schematic API #: 50089200060000 APTD #: 177-064 , / ~° Wellhead 13-5/8" A section with 13-5/8" x 3" flange on top Arctic Pack in 9-5/8" x 13-3/8" Annulus 9-5/8" Baker model D packer at 5,820' with 20 bbl cement on top TOC @ 6,860' per temp survey 75 Sx class G cement plug in 9- 5/8" casing from 6,240' - 6,450' 7" retainer at 11,480' with 4 bbls cement on top Baker F-1 packer at 11,528' 7" retainer at 12,696' with 4 bbl cement on top Total Depth 14,117', 10.6 ppg CaC12 or diesel? / Cement plug in 9-5/8" casing at 42' - 120' (17'-95' BGL) ~ V{`~" ~~s~ ~ `/' ~ O6 O 28" x 36" insulated conductor at 88', cemented to surface with permafrost cement CaCl2/Mud intertace at 2,300' 18-5/8" casing at 842', cemented with 4,700 Sx permafrost 13-3/8" perforated at 3,060' - 2,874' 13-3/8", 72#, N/L 80 casing at 3,296', cemented with 6,800 Sx permafrost cement Perforations 5,860' - 5,861.5', block squeezed with 125 Sx class G Perforations 5,864' - 5,886', squeezed with 6 bbl cement 9-5/8" retainer at 5,915' Perforations 5,930' - 5,931.5', block squeezed with 110 Sx class G cement 7" casing stub at 6,510' 9-5/8", Soo-95, 43.5#, casing at 10,099', cemented with 1,430 Sx class G TOC behind 7" casing at 10,660' Perforations at 11,580' - 11,678', squeezed with 125 Sx class G Cement Perforations at 13,020' - 13,080', squeezed with 125 Sx class G cement 7" casing at 14,103', cemented with 1,750 Sx class G Well schematic drawn June 29`h, 2007 by Jesse Mohrbacher, Fairweather E& P Services, Inc. Point Thomson Unit No. 2 Drillsite Inspection August 22, 2007 This drillsite inspection occurred on August 22, 2007. As can be seen from the attached photographs, weather conditions were moderate (around 60 degrees F) and clear, allowing for good viewing conditions. There were no visible indications of well integrity problems nor were . there indications of oil spills or stains on the pads and surrounding surface waters. The pad had varying thicknesses of gravel and exhibited moderate to heavy thermokarsting. Much of the pad was also re-vegetated. Gravel was mounded around the wellbore and only the wellbore marker was visible. A buried vertical culvert extending about six inches above tundra pond level was just off the pad • edge. There were several ponds in or around the pad areas and none exhibited hydrocarbon sheens. Offsite from the pad, there were 3 wooden piling protruding above ground level and two pieces of plastic pipe. ~ .. ~ ~ ~ ~~6 $ ~ -,~ -~ . ~ ~.^ a . ehj at ; ~„ . ..,, . . -.:"5'-: . , ~ ,m: _ ,.._,, .,~ .., ~... . ~ ~ • ~w ~ ~,'~-: ,~.,~~ `}~~,~ ... _~•~.. ~.M ~~,~wi~.,. :+IR*Z'~ r a•~ ~i~~~~~' ."~~'.1~7~ ; - . - ~. . . ,„ ~~ ~~~ . ~. . ~~.f •'' ~ ~ ~ ~+...: `. ^'c.o,. ~!"` "" ~r~~ ~~b ._T"'.,. . '°{' ~ 'S'r . .+~~'- _ ~ . ' ~~~,_ , . . ' j . ~ ' . , "1'R °~"` ~ - ~ ~lFs,~ . . ~ ~'` ~'~"ii~ . , ' -ti. ~ i ~ ~ ... _. .q?~ . ~ ~ , „; "i :4 . `Y. ` J ' ,. ~ ~ ~. ~ . ~:•`~.. . ~,','l. _ _ ~ ,. . ,. i ; Point Thomson Unit No. 2 -1- , ~..~~:~*`s:: . R ~ ~.'"'a.v~'Y+~~,~' ft 1 t1~%iSa ~ ~..~.~~R.y~, tl[F[y c'¢T'C~~tY:~ ~ ~T C ft'~`~ -- ''. ~ .,. ~ ::~~ ' ", F<1 Y Yv C~ MFei~~~ ~~~~~~f V~ ~4'.~~Je~t ~ ;. . f .E _'S°w~ ~ . L ,+i ~l~b yv4 'oY. . dl ..+Y~ r .: . 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' ~~ ~ + ~i~'~fi~~~~~~ ~ _ ... _.. ~r.~ . . ~, . ~ . Point Thomson Unit No. 2 .~ ;a. _, . -.. ~, _ , '~+* ~~.~#dqyF~+°'Yr*".,.w1"-~'~~~~"'t Y Ya``~'`~j_~_~~;Y ~~..,~, ~. , aw ~r,@~ ..~. ~~ ~ ~ ~ ... ,x~ ~ 4~a sr ~ .w. ... Ay~.}. ~,~~.~,fl t. y~^j`'~~7~ ~ `~ y .. ~4 . ~ t~ } ~ .FA ~ ' , ~ ,{ „ ~y,.y, ~-..', . ~. ~~.~` ~ . Yil ~ ~ r ~dfR~,~"~~ t .V ~-.uM~ .~ d~ ~~ .. ~ ~,~~r k. ~~tM G" ~ ¢ ~Ca ~.~~',. A. CJ.1 t i~. ., ~ t ~ ~ r~ ~ ~; ~' ~.. ~ ~ •u~ ~.. e Point Thomson Unit No. 2 -2- ..+~. . ,i ai~:t31+s. -s ~•,' ~ .~~~'x...I~':i;^'T."" -' -...-~ ~ .~~ .-~,« ,~..~„~.~~~ ~. ., ... _ g . a~'' yf.:: ir ~ ~~Y`~ 'e^~,~1`.,e ., ~ ~' ,y; w~ ~ ~ i,.-w R"i., ~, y -.~~t ,~''~'`~` ~` ~ . 4~~ ~,'~ ~ ' . ~ i. ~ ~i ~~,v, ~ -y .. N y ~~ ' %, -~ 1 7 ~ ~ ,,~y~} ~y .- -• .. t ~( ~ ~ ~ '~~~.lr 7 ~ ~~`;' ~ ~ ~ 'n t C ~'!Vi~' T'' ~e,t • • ~ . ". ~ y ~`n~ A „' ~~ ~ ~ ~ ~ ~ ~ V~ ` ~ " . ~ -!%~ .~., r• rYla .~ f ~.~jt7' ~TS' ~~!i ;Sr ~kr 5r J• 4$~ P~~":xs.`4 ~^:°" ~y' ~ 4 i~i`~ ifR '~ t..H ' C~ U,+4i nY f~/~ y tatpk . Y t ' y,_„ • . ~'f~''~1~~.° Y~j~~ ~i.~ ' ~'/~Y~~~'"~ '-+"~ . + , ~ti, `r. ~ ,. ~niv ~~ ' g~ . ~+ ~~~~~~ ~ t '~~(~~~~. ~I« 19 ! ~f r 4 P 11~, ~ ~ ~ ' t~ _ ~~ t ~ . i jlE ~.{ 4 ~'V~ ~ `~ ~.~' h ~~ }~~. ~-~.rJy ~J~y~~E~~~~ ~~' `O - , `r'd' f j . . '~ , , : ~~, a~ , +..• r . ,,.~ ~p,~A x . . ~ ~ ~1'. Y~. t . ~ ~ ,.~ ~ ~ ~ . %~ 4 ,~.~ `~i ~` ~ : i~{tt t . ~b ,~ ` y ~ i'~ ~ ~,~„}s b~'.,~ ~~:,°44~ .... ts~. ir~•i Y , _ ~dt ~~~ .~~?'!. ~nl~.i~~t.,; d~, .. . . . .aW~ ~7 ~`~;%y~~ i _~; ", ~S. . . t.'# w~, ~y~ Point Thomson Unit No. 2 "..._,,,r.~~ ~ ,;.;t , ;: . . - . ~(~ . _ - ~k~'s~ _. _._ . _~,... ~ .w.- - ~, _ _ . ,,.:.~.,,,:~.~ - _„s - " :.,.rS '` t="~"a.*M{,~"+e ar~'~ ~"a~~'`'~~ ".~,`a~~. ,< ~~t,. , , r~ ~rD~i~kl~" ' t:, ~ ~~ ' ` ! i ` ~..,,. .~~~7l~ ..s~sh*a~e~ .~ _.~ ., (t •.~.i4~~ ~ ~ ... +~`a+w}'+i„r:~ .,t~~~~~ ~ '~ Y: ... ~ ... . , . f~ ! u.: r~ ~~~:... +~ '`,~ ,°` ,~.,n .. . . . . ^ . ~ .. . , , . ...'-~`~ , . ~ F!~ ~'~ ~~ 1~£ ~ ~'~ s . y ' .._ ~ ~,j,+ ~y,... ~ : . ~. ~~ ~ ~ ~~b •~~ir~, 'i , . ~~'~ . . :' .., . ..~. ,~ ~ "~ ~ ~ - e , s9 ~~,~'"~-k~`"~,;~. t't ~r ~~7!~~~'!-'~~y.~{pq'}x,~ .,,a.:. r ;;.'~y'`~'~`~K'~•T i .'~.~a t.~ b ~ F ~y ;~'r," i w ~; • ~ ~ 1 ~ '~ ~'~ . s ,, ~ -5 ~ a. p ~ t S ~ ~;,ti' y -.~~ t ~,~a~~ ~~y;r'.v.a ~ ~`~+i~e' " 1t~ a'~'';'~w'~'~' ~'~P yy, '.. ~! ~ ti ..~~ ~ ~ ~~ ~ 1Jy'-,~a~~+~~'riQ~t&"~ ~ y ,, a y .'3 ~ 4~`!~~ ~ ~ ~ ~ ~,' e ~ r ~ y ~n .'^.. ' _ ~ ! s ~ ~ `W s ,~y" t i ~« ~ Y ~. ~:,$74~ ~'ri~ 7S ~ ~ ~ y~i~£'h~; ( .•~ ,e s ..y • ,~ ~ ~ 'h % Py+~.~ai ~ R . rr ~ ~^i '~xlyY \ b;i , t ~k9}~}.~i ~ 1 . ~ r f ~ ~ ~r ~, 1? . , t . ,.'.`~ PS ~k AVEa ~~' ~ !'l''~,~nr~ ~,1, ~,i.#~M.: "' ~ :'~r1tis ~ s.i`ir~t ~~'k(Sir`*~ 7W 4~:f ~ - a ~c . . ,~ 1 ,> w.,, ~; ' ' ~. ~, ~ .: + T + ?~ ~ x ~ . k ~:. ' ~, 1 ~ t ~x ~*~r ~~ ~ ~ ~ _ f ~ ,~ +~x, ~` A a . ' ,-rc. ' ` ~ a` ~, ' ` ~ r~~~^~~ ~x?a~, ~ f' zE' ~ r~ 4,~~3!r e`~r~! .w1 i~ ~,)1~'k"7„~ .`1~~~* ~LM1'F.iF ~ } ~{ ~ \9~ ~ ~ ,~6C'~4F~~ a ~ +,~ j, • .:= r . ..~; h ` . . k.+^ ` ~ ~ `~'~'~{~ st, ~ } ~S.~t~..~ t . *^lf2'~ ~"~~,~'t~ ~, ~• •R! d,'~`'. •.@~~k14fC `~' ~'!z . ~ ~ \ ~ ~ 1 < ~' ' r ~ . •~1 . ~ g. i ~tii"y~~ ~ ~1 ~~~~.. ~~, ~ ~ „~y'~ ~ ~~ ~ -~~.~ rK k . ~ .~' ~ i~s , +~. .r , i.y 2 ~,~a • ~~~~ 1~~ ~ ''y w y • ',~ `f` fir 4~~Sx~' ~~ ~~ ;.y~~ ~rv' ti ~ , l~ ~,"~~~ N:~r.-~ ~ . ,~~ '~~»4 t ~.titl~~ ~.t!' ~ .~`+ ~ ~P' i . ~ ~ ..; a; '~ ~' r~` t~ 1: t~~~ ~li ~`i ;~ `3Al~ ~ 5~~~?~''. ~~,~ ~p •.a~. +.'~ .._ ~ ~.3c~:~~~a- .~,:~ -~= . . tf ~~ ,~ . f S (~, f ,~~~•~ ~M~ t` ~~ ~y 4 ~Yl ~ \ . . y ~. ~~~~ '3 ~4,~~,f 1~ ~~~. ~,~ ; ~;9i~ ~ ,,{"S f,~,.:t ~r~i Point Thomson Unit No. 2 ~tk+ t .~ - -3- ,.. . ~ ` . , t° _' 1 _„ . [^cn, ~..~i .:~a~i~ ;f-r. ~1 ~i1~ de~"~sSi~L1`~ 3~ ,-` ~~ ~~~'~'+ s ~~~" '~'~~ ~ r~ i ' ~` ~^,{~r-> ^-a ,- ~ ~ ~_.'1r/ .~o-?J_11s.. \';5~.~;i 7~ %~~L ~ ~ _:'~%V,`il.~'~~~~/.S`~SF~ ., . ,_. "~~~ ~'Jv. G v'~ ~' ~ _.=:i;? ~ l8.i i;~,? ~ A.:3Sei2 ~I~~'l1L1:?;:;7' ~~~~IIS~~~.. ~~x:~~t;;4~c;~t? ~r~duCt?On ':ompan~; ?~ 3~x ! >6~C i =~nchorage, ~I< 99~ ~ ~ Re: Pt Thomson ~Tr`e~Es - Piugging and Abandonment Dear :v~r. §-~ay mes, 333 i, 'rrA'/~i11~'~ ~~ ,. ;~CI-VGR.4G= A~ASK? , .~,_ ~iCP4E ~?~~ Z'?-~~ _` c,~; This is in ;esponse to your ietter of November 14; 2007 responding to the Alaska Oil and Gas Conservation Commission's ("Cammission") letter of May 1$, 2007 regarding the condition of certain Pt. T'homson Unit wells. The schedule and plan foi- remedial work provided with }our letter are acceptab(e subject to the fo(lowing conditions: 1. E~conl~obil 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 L`nit. 2. All of the diese! wil( be removed from the Vv`. Staines State #18-9-23 (169-120) and W. Staines State #2 (175-002 j w~ells. If any of the diesel cannot be removed, a Commission petro(eum 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. Al( current and future statutory and regulatory requirements and all applicab(e rules, orders, and permits of the Commission will be complied with unless a waiver to a specific ~equirement is timely and ot~'~erw~ise properl}~ requested and granted by [he Commission. To assist the Commission in ensuring that its ~i(es are complete and accurate, by March 31, 2008, please submie for each well a Form 10-404, a summary of the observations from the work performed last summer. and location photos. Fanally, nothin~ above ~xpressly or implicitlv e~~idences the Commission's position with respect to the status of Exxonl~~obil or am other person as a current Pt. Thomson Unit operator, working interest o~vner, or lessee. ~z you ha~,e an~ qu~stions. please ca(I me at %~3 ~ 2~? f or Torn fVlaunder, PE at 793-12~~. ~incere(b, ~r~~ ~~ o ~ c~?~ a ;/~~~-~ ~~th~ ~ ~=oerster ~~o~~? m issione~ ~~ttoaeEi~o9sa9 ~a~duc~eoea ~oee~paea~ P. O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimiie cG~aag ~ae c~ayevaes Alaska Production Manager Joint Interest U.S. ~ ~, ~~~~E"~ d ?~%' ~ ;f ~~ ~~odttcti~~a November 14, 2007 Chairman John Norman Alaska Oil and Gas Conservation Commission 333 West 7t'' 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 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 wilt 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 wor-k 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 svspended wells in the Point Thomson Unit, and we view this action as consistent with current circumstances. 'vVe under~tanc~ ~~at ~ e~~ass~f~ca:;o^ ::~i!! e~!'~;' a" ~~i~igatipn to abandon the wells in the future in compliance with regulatory requirements. A Division of Exxon 11Aobil ~orporatioee ~~~, fi ~v`~~u~~ Commissioner John Norman - 2- November 14, 2007 Piease 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 dritling 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 ExxoniViobilp rg9d g information and documentafiion to demonstrate that the wells meet the requirements for lu in and abandonment or provide a schedule and plan for bringing these wells into compliance and should address any concerns that may exist regarding compliance with AOGCC requirements for plugging and abandonment. As the Commission is aware, a number of changes have occurred in the requirements for plugging and abandonment of wells over the past 40 or so years. We believe these changes were generally sound and resulted in safer ope~ations. 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, ~ ~/,~ ,.-i ~ ~li ~ % CA :rgd/jpc Attachments xc: Cmmissioner Cathy Foerster - AOGCC Commissioner Daniel T. Seamount - AOGCC Kevin Brown, BP Mark Ireland, ConocoPhillips Vince LeMieux, Chevron ~ ~ ~ ~ ~ ~ ~ ~~1`t,~ ~ Remedial Action Program Point Thomson Wells - Plugging and Abandonment Wells 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 tl~iver State #1, W. + Conduct visual inspection Staines State #18-9-23, W. + Install valves and pressure gauges Staines State #2, Alaska + Check for pressure in casing and all annuli State J-'1 + Conduct further diagnostics as appropriate PTU #4 - Remove marker post - Conduct work in conjunction with first - Remove wellhead and casing to lower than 3' below year of Point Thomson delineation ground level drilling planned for winter of 2008-09 - Verify integrity of surface plug + Repair or replace as necessary ~-P - Remove near-surface arctic pack from 2 annuli and +c~o c~l~,s~.` set cement plugs in annuli using top job techniques ~~~ (plugs to be at least 50' long) ~,/~~ - Install marker plate - Remove cellar - Conduct general location cleanup, and request final site clearance Staines State #18-9-23 W - Remove marker post - Conduct work in conjunction with first . + - Remove diesel above surface plug (1~ } 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 Qosa~b~~ ~S l~~ c~\esE~ - 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. Stairies State #2 - Remove marker post - Conduct work in conjunction with first - Remove wellhead and casing to lower than 3' below year of Point Thomson delineation ground level drilling planned for winter of 2008-09 - Verify integrity of surface plug 8-~~~`~~ + Repair or replace as necessary - Remove near-surface arctic pack from annulus and ~~5~~ ' set cement plug in annulus using top job techniques ' ~ ~ long) (plug to be at least 50 a~~~ - Install marker plate ~ - Remove cellar ~ - Conduct general location cleanup, and request final site clearance Ataska 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 ~~ f,S~~ ground level drilling planned for winter of 2008-09 - Verify integrity of surface plug ~p ~e~ + Repair or replace as necessary ~~'-'~'1 - Install marker plate U ~ S - Remove cellar Conduct general ~ocation cleanup, and request final site clearance PTU #'I - 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 I~iver State #1 - File sundry notice to change well classification from - Submit sundry notice within 90 days of abandoned to suspended AOGC;C concurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winteE 2008-09 inspections Alaska :>tate C-1 - File sundry notice to change well classification from - Submit sundry notice within 90 days of abandoned to suspended AOG(:;C concurrence with action plan - Establish status reporting program in compliance with - Subm~t status report within 90 days of AOGCC regulations winter 2008-09 inspections -3- ;'~~~ ;~~ ~~t~ ~~,~~~~~ _~ 1 ~Iiay ~3, ~fl07 ~ommissioner Cathy Foerster Alaska Oil and ~Gas Conservation Com~nission 333 West 7t" Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Point Thomson Wells - Plugging and Abandonment Dear Commissioner Foerster: _ ,,~, at :_-~ ~; ~_~,) 1 \~~ ~~-'? ~iY~ ~ . ~ . ;~! • ,`i~i~j~ ~ '~ ~`t'~~ ~ ~ ~ ~ ~, ~~~~ :~ ~~:~~ ~i' ~ ~)~`~ ' .~~i_~ ,~,,,...o.u.;,.,~~ :~~ ~~~~ ~~~ 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: 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 frorn the Commission. 2. It would be helpful to obtain a copy of the concerns or issues identified in the Commission's review. We intend to conduct a thorough review of all of the wells in question and having any initial assessr~ent by the Commission to check against as our work progresses may facilitate an earlier completion. It appears the wells on the list were operated by Exxon, Mobil or BP (formerly Sohio). To the extent another operator may be responsible for any of the identified wells we will work with the other owners to determine appropriate handiing 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. ~incer~iy yours, i" rI ~ . ~~ ~` ~' ~;jn~ x~: .~~;g~;s 111i~ik~r, ~~ :~,~r~d3~l ~~WIlN, ~S~iP~d1193~~ 31~~e1'~~~~1~~ ~A~ Slo~ ~~'~l~A~ ~1a~ 1 ~. ZU07 Crai~ F-Iaymes Alaska Production ~tanagec- ExxonMobil Production ~ompany I'O Box 196601 ~nchorage, AIC 99~ 19 Re: Pt. Thomson Wells - Plugging and Abandonment Dear 1~1r. Haymes, 333 W. 7ih AVEfVUE, SU~TE I00 ANCHORAGE, ALASKA 995Q?-3539 PHONE (907) 279-1433 FAX (907;276-7542 During our review~ of the Pt. 1'homson Field in response to your recent applications for permits to drill, the Alaska Oil and Gas Conserv~ation Commission ("Coinmission"j identitied the following wells that, according to our records, are c(assified as plugged and abandoned but do not meet the requirements for plugged and abandoned welis under 20 AAC 2~.10~ - 20 AAC 2~.172: W. Staines St. I 8-9-23 W. Staines St #2 Pt. Thomson # 1 Pt. Thomson #2 Pt. Thomson #3 Pt. Thomson #4 Staines River St # 1 Alaska State C-1 Alaska State J-1 Challenge Island # 1 V/ithin 90 days of receipt of this letter, either provide sufficient information and documentation to demonstrate that these w~ells meet all the requirements for plugging and abandonment, or provide a schedule and plan for bringing these wells into compliance. Also, please note that, under AS 31.0~.090, the Commission cannot issue permits to drill to an ~perator that is in violation of a Commission regulation pertaining to drilling, plugging or abandonment of a well. The ~atnmission reserves the right to pursue an Enforcement r-lction according to 20 AAC 25- ~3~. ~, ~ a i v'-# i~;, ii? 4' S _. ~:~ ?~1~`<~ 1 ~_ ?00' D'd ~~ ~ ~ 0 ( ~ [~inall~. i,oti?ing abo~~ sh~~t~Id b~ cunstru~d tu ti~ id~ns:~~ ~~pr~ssl~ or implicitlti the ~~c~minission's ~ositi~~ v~~it~~ ~es~est ~u rh~ vu~rent stat~.zs ~t~ r;c~~r~~~flnil ~r any flti~er perSOi1 1S a~t. ~I10P11~OI? U~l~ J~J~"t1~~~' OT' l~SS~~. I~'~o~ ha~~e any~ quc:sti~ns, please ~;all me at 793-1221. To: Cathy Foerster, Commissioner May 9, 2007 Fr: Tom Maunder, PE Re: Status of Pt. Thomson Area Wells Introduction: As instructed, an assessment of the wells in the Pt. Thomson area was performed. The purposes of the assessment were to determine if the condition of the wells met the regulatory requirements in effect when operations were completed some years ago as well as if the wells would meet the now current regulatory requirements. There are a total of 21 wells in the general area (14 E~onMobil + 1 ConocoPhillips + 6 BP). This document wiil only address the E~onMobil wells. 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. T'here were major amendments to the AOGCC regulations effective 4/2/1486. 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-lad.en fluid between plugs. After 1980 100' of cement was required above hydrocarbon zones and casing stubs were required to be covered. Neither regulation explicitly required cutting off the wellhead and casings, although removal of a11 "... stntctures and installations ..." was required as part of location cleanup in the 198U regulations. Effective Date 9/30/1967 DNR, 11 AAC 22 4/13/1980 AOGCC, 20 AAC 25 4/2/1986 AOGCC, 20 AAC 25 11/7/1999 AOGCC, 20 AAC 25 The physical downhole work on 7 of the 14 E~onMobil operated wells was completed prior to April 13, 1980 and physical downhole work on 6 of the remaining wells was compieied prior io I~prii 2, i 9u6. i ne iasi weii, tiiasica Siaie ti-2, was piugged ana abandoned in 1Q 2002 according to the 11/7/99 regulations. Regardless of when physical operations were completed in the legacy wells, letters were submitted (most in November 1986) requesting the status of the wells be changed from suspended to abandoned. These requests followed physical inspection of the locations for site cleaxance subsequent to removal of upper casing heads and installation of abandonment markers. No downhole work was perfarmed subsequent to removal of the drilling rig. It is interesting that following the completion of downhole work that nearly every well was labeled suspended, and that term is not defined in AOGCC regulations until the 1986 amendxnents. Temporary abandonment is first addressed in the DNR regulations effective 9/30/67. Examination of the files for the ExxonMobil wells reveals that, so far as I can determine, the wells have been effectively abandoned downhole. All wells had cement placed over productive intervals and usually employed retainers or bridge plugs. One well, Alaska State J-1 does not have any open hole plugs, but the well apparently did not encounter hydrocazbons. The intermediate casing shoe was squeezed below a retainer. Moving up hole, most wells had a portion of the production casing (~") cut and pulled. In all cases except Pt. Thomson #l, a retainer and/or a cement plug were placed on top of the stub. There was no specific requirement to cover the stub prior to April 13, 1980, although in 3 subsequent wells the cut top of the 7" was isolated. Wells generally had a reta.iner and/or cement placed at about 2500' with non-freezing fluids placed above it. Non-freezing fluids included CaC12 brine and diesel. Where annuli were not cemented, non-freezing fluids such as azctic 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 Iocated 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 cunent regulations." The 4 wells were re-entered, liquid hydrocarbons (diesel) removed, cement plugs placed and casings cut off well below sea level. These 4 wells and the Alaska State A-2 are the only wells that meet the piug and abandon requirements effective since Apri12, 1986. Based on examination of the well files, it is my assessment that 5 of the 14 Ex~onMobil welis are Plugged and Abandoned in accordance with current regulations. The remaining 9 wells should be considered Suspended and carried as such in the AOGCC database. E~onMobil should be required to perform the work necessary to properly plug and abandon the wells. Tom Maunder, PE Sr. Petroleum Engineer ExxonMobil Operated Wells Pt, Thomson Unit Area _.~ ~...~ Well PTD Date Date Work to Effective Re ulation? Comment Assessed Actual Required Work Suspended P&A 9/30167 4113/80 4/2/86 1117/99 Status W. Staines St 169- 8/13/70 511/73 by YES YES NO NO Diesel in annulus and Suspended Remove fluids, place 18-4-23 120 sun casin , Not cutoff. lu s, cutoff wellhead Alaska State A-1 174- 9/6/75 ~ by letter YES YES NO YES Re-abandoned 1998 -1999. Plugged and None 014 11/86 Abandoned W. Staines St. #2 175- 5/26/75 ~ by letter YES YES NO NO Diesel in casing 150' - Suspended Remove fluids, place 002 9/86 2279'. AP in annulus. Not plugs, cutoff wellhead cutoff. Pt. Thomsan #1 176- 12/8/77 ~ by letter YES NO NO NO No plug above cut 7" at Suspended Remove fluids, place 085 11l86 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- 7/4179 ~ 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- 7121179 11JS186 by letter YES YES NO NO Diesel in casing at 100'. Suspended Remove diesel, place #1(confidential 001 11/86 Not cutoff. lu s, cutoffwellhead Pt. Thomson #4 179- 12/20/80 ~ by letter NA YES N0~ N0~ AP in 2 annuli. No diesel. Suspended Cutoff wellhead. 080 11186 Not cutoff. Remove some AP. Alaska State C-1 180- 7/14/Sl ~ by letter NA YES N0~ N0~ AP in 2 annuli. No diesel. Suspended Cutoffwellhead. 046 11/86 Not cutoff. Remove some AP. Alaska State D-1 180- 2/l6/82 ~ by letter NA YES NO YES Re-abandoned 1998 -1999. Plugged and None 101 11/86 Abandoned Alaska State F-1 181- 5/30/82 ~ by letter NA YES NO YES Re-abandoned 1998 -1999. Plugged and None 140 11/8b Abandoned Alaska State G-2 182- 8I19/83 * by letter NA YES NO YES Re-abandoned 1998 -1999. Plugged and None (confidential 208 11/86 Abandoned Alaska State J-1 183• 6/14/84 * by letter NA YES N0~ NO* No open hole plugs. No AP Suspended Cutoffwellhead. 045 11/86 or diesel. Not cutoff. Remove some AP. Alaska State A-2 200- 3/8/02 by NA NA NA YES Plugged and None 141 sundry Abandoned N0~-no liquids present. ExxonNlobil Production Cam~r P. O. Box 196601 Anchorage, Alaska 99519-6601 ~ 907 561 5331 Telephone 907 564 3677 Facsimile December 19, 2008 Crai~iiaymes Alaska Production Manager Jointlnterest U.S. E~onlVlobil production Mr. Johnny Aiken North Slope Borough Planning Department ~~ .fit°;; .1~,j~ ~ ~~~~ P.O. Box 69 Barrow, Alaska 99723 ~ ~ Z --y ~; Re: Point Thomson Unit #2 Conditional Development Permit Application Point Thomson Area Remediation Program North Slope, Alaska Dear Mr. Aiken: Exxon Mobil Corporation proposes to perform inspections and remedial work at nine former exploratory wells and drill sites in the Point Thomson area. The Conditional Development Permit application and following project documentation are attached for the Point Thomson Unit #2 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, 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 Mobil Corporation • -` ---- - Land Management ~ Regulations Permit Application ~ww:~ Permit Number Applicant Exxon Mobil Corporation Address P.O. Box 196601 Anchorage, AK 99519-6601 907-564-3617 Contact Person Mike Baker Project Name Point Thomson Unit #2 Well Inspection Location (TRS) z,6is NSL 1,801' wEL sue. s, T9N, R22E, uM Unitized Field Name Zoning District Conditional Development December 19, 2008 Proposed Start Date February 1, 2009 Completion Date: August 31, 2011 Proposed Development _ Inspect well, check casing pressures. Purpose of Development See attached Project Description. ^ FilUDredge Material ® Oil and Gas Wells ® Temp. Water Use ® Off Road Travel: ®Fuel Storage Number of New Surface Holes: 0 Acres 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 vehicles, rolligon, Period of Travel Feb 1, 2009 -Aug 31, 2011 Equipment Steiger, aircraft Access to Site All terrain vehicles, aircraft Type Diesel fuel stored in steel tanks Amount X10,000 gal on-mo I e 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 • NORTH SLOPE BOROUGH DEPARTMENT OF PLANNING AN DCOMMUNITY SERVICES PERMITTING AND ZONING DIVISION Permit Type Date State ID Phone and Pad Location Point Thomson Unit #2 ., , , n • 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 Date Craig A. Haymes Name Alaska Production Manger Title FEE PAID ^ SPECIAL PLANNING COMMISSION MEETING ....$12,000.00 ^ DEVELOPMENT PERMIT...$2,000 + $500 PER WELL ^ ADMINISTRATIVE APPROVALS ...$1500.00 ® CONDITIONAL DEVELOPMENT PERMITS...$3,000.0 AMOUNT PAID $3,000 DECISION ^ ADMINISTRATIVELY APPROVED This is a minor amendment to a development permit or is a use of land listed under administrative approvals for this zoning district. ^ REZONING APPROVED This proposed development substantially complies with the Master Plan, and a use pernut is issued, conditioned on compliance with all relevant Master Plan conditions, lease stipulations and provisions of state and federal law and pemuts 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. Project Description Point Thomson Area Remediation Program Exxon Mobil Corporation 1. Project Overview and Schedule Exxon Mobil Corporation (ExxonMobil), on behalf of itself and other Point Thomson area lease owners, intends to conduct various inspection and remedial actions at nine different former exploratory well sites in the Point Thomson area beginning during the winter of 2008-09. This project description covers the full range of remedial activities that are being planned although only a portion of the work may be conducted during the winter of 2008-09. The entire program is expected to be completed by August 31, 2011. The timing of specific components will depend upon the status and plans for other activities in the Point Thomson area. A key consideration is the extent to which the Point Thomson Drilling Program, which includes construction of a sea ice road from Prudhoe Bay to the Point Thomson area, proceeds during the winter of 2008-09. For instance, if the drilling program does not proceed as planned during the winter of 2008-09, certain remedial activities that can be conducted more efficiently and safely in conjunction with certain aspects of the drilling program may be deferred to when those activities are conducted. Any work that may be deferred is not time sensitive and deferral would not pose an environmental threat; the locations and wells are stable. A decision on remediation work to conduct this winter will be made following a determination of the drilling program activities that will proceed, development of detailed work plans, and receipt of the necessary permits. The work scope includes 1) conducting inspections of nine former exploration wells as required by Alaska Oil and Gas Conservation Commission regulations for suspended wells, 2) conducting further remedial work on plugged and abandoned wells, and 3) closure of the open reserve pit at the West Staines State #2 well location. Assuming receipt of all required permits and authorizations by January 30, 2009, the work will commence about February 1, 2009, and be completed by April 15, 2009. During the summer of 2009, the locations will be visited by helicopter to allow for further clean-up and inspections. If the sea ice road for the drilling program is not conducted during the 2008-09 winter season, the inspection and remediation work that is conducted during the 2008-09 winter season will be supported by agency-approved off-road vehicles such as steigers, cat trains or rolligons or a combination of all off-road vehicles and conventional vehicles on local ice roads. 2. Permit Requirements This project description provides information necessary to support the applications for permits, authorizations, and coverage under general permits summarized on Table 1 which are required to conduct the desired remediation work. Page 1 of 6 • 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 Plan (within PTU) • Develo ment Permits for activities outside PTU United States of America • Environmental Protection Notice of Intent for coverage under NPDES General Permit AKG- Agency 33=0000 for Gravel Pit Dewatering** • Sill Prevention Control and Countermeasure SPCC Plan • US Fish & Wildlife Service Letter of Authorization (LOA) for Incidental Taking of Polar Bears USFWS and Pacific Walrus** * Approval of the lease Plan of Operations is the primary authorization from DNR for conducting well and related operations on a lease. All of the former exploration welt operations were conducted under an approved lease Plan of Operations. The status of these Plans of Operations is uncertain and ExxonMobil will work with the DNR/ DOG to determine appropriate authorizations for this work. ** Applications for similar activities were requested for the Point Thomson Drilling Program. Coverage under the existing requests to cover the remediation program will be requested rather than submittal of new applications. 3. Site Access Site access primarily will be accomplished through the use of vehicles traveling on ice roads or off-road vehicles. Helicopter or fixed wing aircraft will also be used depending upon activity for the Point Thomson Drilling Program and the logistical capabilities that are available. Figure 1 Page 2 of 6 • shows the tundra and offshore ice road routes between the Prudhoe Bay area and the Point Thomson area. Figure 2 shows the specific drill site locations and tundra travel or ice road routes within the Point Thomson area. 4. Well Remediation Work There are nine former exploratory wells in the Point Thomson area at which ExxonMobil is planning to perform remedial work. The names of the wells and work being considered are shown on Table 2. Four of these wells have been plugged and abandoned (P&A'd) and five are suspended. All nine wells have wellheads that are partially or completely covered with gravel. ExxonMobil plans to excavate the gravel from around the wellheads, perform visual inspections of the wells, and install pressure gauges to verify there is no internal pressure. This work will be accomplished in the winter of 2008-09 and is not dependent upon the ice road or drilling program activities. Removal of debris and location clean-up will be performed at all sites as necessary. The excavated gravel will be retained on location. For the four P&A'd wells, ExxonMobil plans to remove marker posts, cut and remove casings to at least three feet below natural ground level, and weld marker plates upon the casing stubs to conform to current AOGCC regulations and practices. This will also include removal of some hydrocarbon based fluids from within the wellbores and verifying the integrity of existing cement plugs or placing of new cement plugs. The specific actions to be performed on these wells will be addressed in Sundry Notice requests submitted to the AOGCC. For some wells, it maybe necessary to mobilize a coiled tubing rig or other light duty drilling equipment to the area to conduct well remedial work. Table 2 -Point Thomson Area Wells Well Name Surface Location Well Status Planned Work PTU #1 1,320' NSL 660' WEL Suspended Inspection Sec. 32 T10N R23E UM PTU #2 2,615 NSL 1,801' WEL Suspended Inspection Sec. 3, T9N, R22E, UM PTU #3 660' NSL 711' WEL Suspended Inspection Sec. 34, T10N, R23E, UM Alaska State C-1 660' EWL 660' SNL Suspended Inspection Sec. 14, T9N R23E UM Staines River St. #1 321' NSL 1,658' EWL Suspended Inspection Sec. 17 T9N R24E UM PTU #4 2,700' NSL 2,900' WEL P&A'd Inspection, well remedial work Sec. 32 T10N R22E UM Alaska State J-1 1,886' NSL 2,404' WEL P&A'd Inspection, well remedial work Sec. 23 T6N R22E UM West Staines St. #2 848' SNL 50' WEL P&A'd Inspection, well remedial work, Sec. 25 T9N R22 UM reserve it closure West Staines St. 1,514' SNL 1,730' WEL P&A'd Inspection, well remedial work 18-9-23 Sec. 18 T9N R23E UM Page 3 of 6 • • 5. West Staines State #2 Reserve Pit Closure The West Staines State #2 exploratory well site has an open but inactive reserve pit. The closure plan will include filling the pit and installing a gravel cap designed to eliminate ponding of surface water within the reserve pit footprint. An estimated 17,000 cy of fill material is required to fill the pit and construct the cap. It may be possible to obtain these amounts from existing gravel at the West Staines St. #2 pad and West Staines St. 18-9-23 pad approximately 2 miles to the north. Other sources of fill material are being evaluated and may be proposed to the ADEC as part of the closure process. Further details will be provided in the reserve pit closure plan that will be submitted to the ADEC for review and approval. 6. Water Requirements and Sources A temporary Water Use Permit (TWUP) was previously requested to obtain water from the Alaska State C-1 gravel pit. That permit application will be modified to also include additional shallow (non-fish bearing) lakes in the Point Thomson area and the scope will be broadened to address this remediation project. If ice roads are used, water will be hauled using water trucks or tanks on conventional trucks. If off-road vehicles are used, the water will be hauled in tanks placed on the off-road vehicles. 7. Logistical Support The remediation work will be supported by an existing camp at the PTU 3 pad, which was staged to support the Point Thomson Drilling Program and by one or more portable camps that may be transported to each location. These camps will be equipped with potable water storage tanks, gray water treatment plants, electrical generators, fuel storage tanks, and small incinerators. All camps will operate under valid public drinking water supply and environmental health/food services permits issued by the ADEC to the camp operators. Up to 10,000 gallons of fuel will be stored on location and will be re-supplied as needed. Pump houses will be located on the water source lakes and be fitted with ADF&G approved water intake structures. 8. Waste Management Solid, non-burnable wastes will be deposited into containers on site for back-haul to the Prudhoe Bay area for disposal. Any food wastes that could attract wildlife will be incinerated onsite, stored in enclosed containers awaiting periodic hauling, or hauled each day to the PTU 3 staging area. Camp waste waters will be treated and discharged to the tundra by the camp operators in accordance with EPA's NPDES General Permit AKG-33-0000. Page 4 of 6 • 9. Wildlife Issues Wildlife that could be in the area during the winter includes owls, ravens, arctic foxes, polaz bears and brown beazs. Polaz bears are expected to be present in the area and aze known to den in the surrounding coastal environment. Brown beazs 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 beazs and Pacific walrus will be requested, and operations will be conducted in accordance with those authorizations. A Beaz- Personnel Encounter Plan which describes procedures to protect beazs 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 beaz 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 beaz sightings will be immediately reported to the site superintendent and the personnel in the area warned of the location of the animal. Dedicated beaz monitors will be maintained on location to look for and identify evidence of beaz presence in the project vicinity. Upon identification of beaz signs or a sighting, the beaz monitor will notify the site superintendent of the presence of beazs in the azea. Beaz monitors will also be assigned to continually watch beazs when present in the project vicinity. Qualified bear monitors from the village of Kaktovik or Nuigsut will be employed, if available, particulazly during periods of potential subsistence use of the Point Thomson azea to monitor project activities and coordinate with onsite staff to ensure subsistence activities aze not impeded. 10. Oil Spill Contingency Plans ADEC does not require oil discharge prevention and contingency plans be prepazed or approved for remediation projects including well entries such as aze being considered here. Spill Prevention Control and Countermeasure Plans (SPCC) as required by EPA regulations will be prepazed 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 Nq Su ervisors Mike Barker Regulatory 907-564-3617 907-223-9904 Mana er mike.barker exxonmobil.com Prior to the start of field operations this contact list will be updated and provided to the applicable agencies. 12.0 Environmental and Safety Training All North Slope based company and contractor personnel will complete an 8-hour unescorted training program provided by the North Slope Training Cooperative (NSTC), which will include receiving a Field Environmental Handbook, an Alaska Safety Handbook, and a North Slope Visitor's Guide. This training will provide the basis for compliance with lease terms and permit conditions/stipulations for most employees, including wildlife and environmental awareness training. Additional specialized training will be provided to employees as needed, including such topics as detailed waste analysis planning, manifesting, and permit compliance requirements. 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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: 1179"f o/U Crai; aymes / Lea - Q76 Alaska i reduction Manager �) Joint Interest U.S. 7& v �� i7-7, ob`a M. a �U E&onMobil Production /90 /7g. oao RECEIVED MAR 1 8 X008 Alaska 00 & Gas Cans, Commisf l 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, SCANNED Attach ents cc: Mark Ireland, ConocoPhillips Vince LeMieux, Chevron A Division of Exxon Mobil Corporation SARAH PALIN, GOVERNOR �t ALASKA ®IL AND GAS 333 W 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 December 7, 2007 Craig Haymes Alaska Production Manager ExxonMobil Production Company PO Box 196601 Anchorage, AK 99519 Re: Pt. Thomson Wells — Plugging and Abandonment Dear Mr. Haymes, This is in response to your letter of November 14, 2007 responding to the Alaska Oil and Gas Conservation Commission's ("Commission") letter of May 18, 2007 regarding the condition of certain Pt. Thomson Unit wells. The schedule and plan for remedial work provided with your letter are acceptable subject to the following conditions: ExxonMobil will perform the proposed field work for the 2008 — 2009 winter operating season regardless of whether there are any concurrent drilling operations in the Pt. Thomson Unit. All of the diesel will be removed from the W. Staines State #18-9-23 (169-120) and W. Staines State #2 (175-002) wells. If any of the diesel cannot be removed, a Commission petroleum engineer or inspector shall determine whether the shallow wellbore plugs are competent, and ExxonMobil must take any reasonable actions the Commission determines are necessary. All current and future statutory and regulatory requirements and all applicable rules, orders, and permits of the Commission will be complied with unless a waiver to a specific requirement is timely and otherwise properly requested and granted by the Commission. To assist the Commission in ensuring that its files are complete and accurate, by March 31, 2008, please submit for each well a Form 10-404, a summary of the observations from the work performed last summer, and location photos. Finally, nothing above expressly or implicitly evidences the Commission's position with respect to the status of ExxonMobil or any other person as a current Pt. Thomson Unit operator, working interest owner, or lessee. If you have any questions, please call me at 793-1221 or Tom Maunder, PE at 793-1250. Sincerely, Cathy . Foerster Commissioner ExxonMobil Production Corm P. O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimile November 14, 2007 Chairman John Norman Alaska Oil and Gas Conservation Commission 333 West 7 1 Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Pt. Thomson Wells — Plugging and Abandonment Dear Chairman Norman: Craig mes Alaska Production Manager Joint Interest U.S. E�onMobil Production RECEIVED NOV 14 2007 Alaska Oil & Gas Cons. Commission Anchorago 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. ORIGINALA Division of Exxon Mobil Corporation Commissioner John Norman - 2 - November 14, 2007 Please note the plan calls for conducting the most intensive phase of field work in conjunction with the first winter drilling season of currently -planned Point Thomson Operations drilling, which is proposed to occur during the winter of 2008-09. We believe conducting this work in conjunction with this drilling program will offer significant operational safety and efficiency benefits. In the event the drilling program does not progress as proposed, we will work with the Commission to determine appropriate timing for the remedial work. We believe this plan responds to the Commission's request that ExxonMobil provide information and documentation to demonstrate that the wells meet the requirements for plugging and abandonment or provide a schedule and plan for bringing these wells into compliance and should address any concerns that may exist regarding compliance with AOGCC requirements for plugging and abandonment. As the Commission is aware, a number of changes have occurred in the requirements for plugging and abandonment of wells over the past 40 or so years. We believe these changes were generally sound and resulted in safer operations. In some cases, however, the changes created specific conflicts for operators, e.g., the 1986 regulations required installing marker posts while the 1999 regulations prohibited such posts (unless the land owner requests them). The planned work program will address these matters on the wells planned for near-term remedial work and through future actions on the remaining wells. Other regulatory changes involving placement of cement plugs and retainers, cementing of casing stubs, or requirements of fluids left in the well are more subtle. In general, it would be unnecessary and impractical to later attempt to modify many of these items, particularly those that exist at deeper depths in the wells. In the interest of transparency and clarity, we will address any variances or deviations from current regulations in our sundry notices filed with the Commission. We appreciate the Commission's help in providing clarity around the issues and allowing adequate time for ExxonMobil to conduct a through and thoughtful review. We look forward to your concurrence so we can proceed with the outlined work plans. Please feel free to contact me, Bill Pecor at 564-3766, or Rob Dragnich at 564-3711 if you have any questions. Sincerely, r CA :rgd/jpc Attachments xc: Cmmissioner Cathy Foerster - AOGCC Commissioner Daniel T. Seamount - AOGCC Kevin Brown, BP Mark Ireland, ConocoPhillips Vince LeMieux, Chevron ORIGINAL Remedial Action Program Point Thomson Wells — Plugging and Abandonment Wells Affected Actions Timing PTU #1, PTU #2, PTU #3, - Conduct additional integrity investigations to include: - Conduct work during winter of 2008-09 PTU #4, Alaska State C-1, + Removal of gravel from around wellheads Staines River State #1, W. + Conduct visual inspection Staines State #18-9-23, W. + Install valves and pressure gauges Staines State #2, Alaska + Check for pressure in casing and all annuli State J-1 + Conduct further diagnostics as appropriate PTU #4 - Remove marker post - Conduct work in conjunction with first - Remove wellhead and casing to lower than 3' below year of Point Thomson delineation ground level drilling planned for winter of 2008-09 - Verify integrity of surface plug + Repair or replace as necessary - Remove near -surface arctic pack from 2 annuli and set cement plugs in annuli using top job techniques (plugs to be at least 50' long) - Install marker plate - Remove cellar - Conduct general location cleanup, and request final site clearance W. Staines State #18-9-23 - Remove marker post - Conduct work in conjunction with first - Remove diesel above surface plug year of Point Thomson delineation - Remove wellhead and casing to lower than 3' below drilling planned for winter of 2008-09 ground level - Verify integrity of surface plug + Repair or replace as necessary - Remove near -surface diesel from annulus and set cement plug in annulus using top job techniques (plug to be at least 50' long) - Install marker plate - Remove cellar - Conduct general location cleanup, and request final site clearance - 1 - W. Staines State #2 - Remove marker post - Conduct work in conjunction with first - Remove wellhead and casing to lower than 3' below year of Point Thomson delineation ground level drilling planned for winter of 2008-09 - Verify integrity of surface plug + Repair or replace as necessary - Remove near -surface arctic pack from annulus and set cement plug in annulus using top job techniques (plug to be at least 50' long) - Install marker plate - Remove cellar - Conduct general location cleanup, and request final site clearance Alaska State J-1 - Remove marker post - Conduct work in conjunction with first - Remove wellhead and casing to lower than 3' below year of Point Thomson delineation ground level drilling planned for winter of 2008-09 - Verify integrity of surface plug + Repair or replace as necessary - Install marker plate - Remove cellar Conduct general location cleanup, and request final site clearance PTU #1 - File sundry notice to change well classification from - Submit sundry notice within 90 days of abandoned to suspended AOGCC concurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winter 2008-09 inspections PTU #2 - File sundry notice to change well classification from - Submit sundry notice within 90 days of abandoned to suspended AOGCC concurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winter 2008-09 inspections PTU #3 - File sundry notice to change well classification from - Submit sundry notice within 90 days of abandoned to suspended AOGCC concurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winter 2008-09 inspections -2- Staines River State #1 - File sundry notice to change well classification from - Submit sundry notice within 90 days of abandoned to suspended AOGCC concurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winter 2008-09 inspections Alaska State C-1 - File sundry notice to change well classification from - Submit sundry notice within 90 days of abandoned to suspended AOGCC concurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winter 2008-09 inspections -3- Point Thomson Area Drillsite Photos July 23, 2007 and August 22, 2007 Point Thomson Unit No. 1 Point Thomson Unit No. 1 Point Thomson Unit No. 1 Point Thomson Unit No. 1 Point Thomson Unit No. 2 Point Thomson Unit No. 2 y.wcJj •. 'i4.a*%^....r. Y; ,y,.. �•" *• .. .. c, r ..�s6,� >?"�•.,'� 1s!t,.*..i `��� i ,j '� .,�''-rr'w n_C - re � t ' _ -. kt 1�'* a .•. %�y, � �a-R `,r� J.t - - .1�' a. .'�.•'1 �r:�i. .{�r�'" r..•,,_ F sa. r i :~ •�.:' � __'_�' �. .•S�i`s2..'_ r'..'.�, w Point Thomson Unit No. 2 Point Thomson Unit No. 3 Point Thomson Unit No. 3 t s )wAT r f., liY J�• � :. � w .�'� <�y,�1� !ter s1 /� /``4� •'� �`. � L,�i-, / '. J / A /ZZ 44 i�. Y.. l'h v.o. ��¢if• ,, . ► m Point Thomson Unit No. 4 Point Thomson Unit No. 4 i Ash`' t .. . �� .,c,s'rr . `,� a4 Y.'• �1 t 5��'*Jx !� s' r'�C�' �y �����'�?� �� '. r �:;�•" c° - f �' . - ,qI �+�� r�"` f s:: ; t n< "r�¢ `'�'.iYr� +'r / .. < Ir yif> ^: ' ;{1•�—~'pC - � "�-'"f'c3r w�i[" �:;. "' }��,:. ,�' x..' --'i;re' .. � t ! �a 97'zCA r 'i.Rr . T rt -L„ -. . i j' � � �k. - �•�` .. � '+ s. 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Ps' ,-•tee 4 ;� �' .iii. i SARAH PALIN, GOVERNOR 7� ALASKA 011L A��S333 W. 7th AVENUE, SUITE 100 CONi SERVA170 COMMSSIOT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279.1433 FAX (907) 276-7542 August 14, 2007 Craig Haymes Alaska Production Manager ExxonMobil Production Company PO Box 196601 Anchorage, AK 99519 Re: Pt. Thomson Wells — Plugging and Abandonment Dear Mr. Haymes, This is in response to your letter of 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 793-1221or T Maunder, PE at 793-1250. &9.iad � 77 • o&y 1-2g_ 005 X 79• aj0 ' -79 . ON o yG iP3 , o 46 0 9U SENNE ' 9 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 Clearance 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-I 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, Alaska State A-1 and C-1 wells. and the Sin~cere ~. Lonnie C. Smith Commis s loner jo/A.HJH.47 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 47567, Point Thomson Unit, Exxon No. 2. Please refer to the attached form (P-7) for plug and suspension details dated 8/12/78. TVB: j cv Attachment Sincerely, A DIVISION OF EXXON CORPORATION Form ; SUBMIT IN DU JA~E' STATE OF ALASKA ' t,,*~-'-her lu- st ruct,ons on OIL AND GAS CONSERVA~ON COMMITTEE ' ~e~,~,e ,ide; i II ! II WELL COMPLETION OR RECOMPLETION REPORT AND LOG* I II I 18. TYPE OF Wi~LL: OIL E] ~AS -- Wi ] d~.t WELL WELL L.J DSt ~ Other ~on ~~rat ion _~ 3. A~'ORES8 o~ OPERATOI ' P.O. ~ox 2180~ Hg..uston, Texas 77001 ~. LOCA~0N or WELL -(Report iocatto~ clearlil a~4 t~ accordance wttA any l~tate AP1 ~~,~1~ CODE 50-089-20006 ~L 47~7 ~t ~~ Uuit [~ ~on No. 2 I · A,N'D POOr-, OR WI~AT l Wildcat *''""'"' 2615' NSL & 1801' WEL of Sec. SA TgN, R2~E, Ut~.{/ 13. DA~ SPUDD~ 14. DA~ ~.~. ~ IL D ~ CO VSP 'z+ u: ! ~ -' ! ~-78 I 49 ~ . iS. ~ D~, '~ a TVb~g. P~UG, ~dK ~D & ~. ~ ~L~ ~L.. [ ~. INTERVALS .14,117' l, ~fzce , , . {_~w_ .~v. ~. ~RODUCING I~VA~(S), O~ ~' C~[~~, ~~. Per~or~t~ons c~nt~ ~or ~~s o~ ~et~. ~rforation ~te~s~d c~nt~.. ~1 Induction, ~ ~nic, Fomtion ~nsity~n~t~ · 24. TYPE lr.[J~_-Cl~:~lC A.ND OTI-LI~R. Ld:)~rS RUI~ Dieter, ~re~ ~try, Vel~ity ~. CAS~G ~ (Re~ all strips set ~ w~ll) CASLNG SIZE WEIGHT, LBIFT, DEPTH S~T (M:D) HOI~ SIZE LINER TLECOI~D 28. PERFORATIONS OPE/~ TO PRODU ON (Interval. size and number) 13,020' to 13,110'· (2 spf) 11,580' to 11,678' (2 spf) 5,864' to 5,886" (2 spf) ~r, NTING R~COI:tD AJVIO~ PULJ.,ED TUBING P,~CO PA~ ii SCREEN (MD) SIZ~ ,,, 29. ACID, SI!OT, F?~CI O'RE, CF~%IENT SQUEEZF~. . DI~P'rII IN'rERVA.L (MD) /~MOUNr ;~D ~ND OF MAI'E?~ US~ ~EE ATTACHMEN~ D~TH S~[' (M~D) I PACKER SET (IV[D) SEE ATTACHMEN~ 'o,?, or ,,sT. IHOURS T~T~:) : I~oxr s~s IP~O~'N fOR / I 33. ~ bereb~ ce~t~t t~e to~lol~ ~nd ~tt~cbed tntorm~tlou l~ cOmPlete ~d ear,eat ~ data,raiDed ~rom ~H-~v,ihbJ'~ reco~d~ ~_J~ /f District ~~er SIGNED STATE OF ALASKA ..... AL/, ,A OIL AND GAS CONSERVATION CO, tSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Iii Alter Casing [] Other E~ Final Location Abandonment 2. Name of Operator Exxon Co., U.S.A. 3. Address P. O. Box 60626 New Orleans, LA 70160-0626 4. Location of well at surface Sec. 3, T9N-R22E At top of productive interval At effective depth At total depth 2615' N.S;,L. & 1801' W.E.L. UPM North Slope, Alaska 5. Datum elevation(DForKB) 24' GL 6. UnitorPropertyname Pt. Thomson Unit 7. Well number No. 2 8. Approval number 334 9. APl number 50-- 089-20006 10. Pool Wi ldcat Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length 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 I 1 15. I hereby ce, I;tify t.~at the foregoing is_true and correct to the best of my knowledge _~/. _.,~ c/'- iQ,.._-. ~2'/' Sige~ J. P. Clement, III TitleNew Orleans Drilling Mgr Form 10-404 Rev. 12-1-85 Date 9/25/86 Submit in Duplicate MEMO'RAI'-'DUM TO: TH RU' FROM: Stat--of Alaska ALASKA Oil ~ND GAS CONSERVATION CO~I~ C. V,~- 'g tier ton · Lonnie C. Smith~ ~:'i:~//; Commissioner yle ~ -,lC John F. Bo ~ ..... Petroleum Engineer Asst DATE: September 5, 1986 FI LE NO.' D. JFB. 19 TELEPHONE NO.' SUBJECT: Location Clearance Exxon Point ThomPson Unit ~2 Permit No. 77-64 Wednesday, August 27, 1986: I traveled this date from Anchorage to P~dh°e Bay' and' me't With Tom Burford, Exxon representative. I visited the above listed location and observed a mound of gravel around the abandoned well. After conferring with Lonnie Smith, I recommend this location for final abandonment. I filled out an AOGCC Surface Abandonment Report which is attached. Attachment FILE INFORMATION: Operator Address 'ALASKA OIL AND GAS C(INSERVATION COMMISS£ON .~-- SURFACE ABANDOqHENT REPORT ..... 20 AAC 25, ARTICLE 2 ~ %-/?~/ ~i~:~ (~~' Date Do,hole P & A Surface Location of Well ' ~'~', ~ Ft F! ~: L, ~ ~ ~ Ft. F~7~L, : ~_; . Sec. < T v R'"~ i" , // M. P e nn i t N AP1 No Unit or Lease Name Well No. Field & Pool " 20 AAC 2~.120: WELL ABANDONMENT MARKER: Dia. Steel Post (4"Min.) ~-z Length (10' Min.,) / Height Above Final Grade' Level (4' Min. /'~ Top of Marker Pipe Closed with: Cement Plug Screw Cap Set: On Well Head ~, On Cutoff Casing ' , In Concrete Plug Distance Below Final Grade Level Ft. Side Outlets: All Valves and Nipples RemovedV.~-~ All Openings Closed ~_ r.~, With Blinds~ , With Cement INFO~ATION BEADWELDED DIRECT~LY TO ~RKER POST: (List k~ere Different from File Info~ation) Operator ~' ;~ ~ ~ ~ ~ , , ,,t.,,~ Unit or Lease Name Well Number ~'- ,;.;~ , Surface Location of Well: Welds / ill. S/~'.~ i o~ ~ :: ~ , Other 20 AAC 25.170: LOCATION CLEAN-UP PITS: Filled In ~'J ~i~ , Liners Re~'noved or Buried '~i,? .! , Debris Removed ~ ' SURFACE OF PAD AND/OR LOCATION: Roug ,h~.~.~ _, Smooth__, Contoured Other , Flat , Compacted , CLEAN UP OF PAD AND/OR LOCATION: , ~ Clean~ , Pipe Scrap , Iron Scrap Paper , Other .., Wood __, Mud , Cement SURROUNDING AREA: Wooded , Brush Sand , Other , Tundra-~'-, , Grass , Dirt , Gravel CONDIT~N SURROUNDING AREA: Clean~ ; Trash from Site Other , Trees and/or Brush from Clearing Site ACCESS RO~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-APPR0~AL OF ABANDONMENT: Yes~ , No INS PECTED BY ~-,,~:i f, o5/ s/8 C? Final Inspection ¥~,' " DATE ,~ /~,i ~.~ ~OtNT VN,'t ~'~ J a r''` `~~~~ A S~ ~~~~ o~ r~ \~ ~` t R 0,\. V i ~,y1 ~~ P~~~~ ~~ ~~ ~~ ~a.~~.~~ 1 S„ r~o ~.. ~.;tea -C'rtMOf~~ STATE OF ALASKA ALAS. _, OIL AND GAS CONSERVATION COM 3SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon }Q Suspend [] Operation Shutdown [] Re-enter suspended well [11 Alter casing I ] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order E] Perforate I1 Other feet 2. Name of Operator ExxDn Company U.S.A. 3. Address P.O. Box 196601 Anchorage, Alaska 99519-6601 4. Location of well at surface 2615 NSL and 1801' W. EL. Sec. 3, T9N, R22E, UPM, North Slope, Alaska At top of productive interval At effective depth At total depth 5. Datum elevation (DF or KB) Approx 24' G.L. 6. Unit or Property name Pt. Thomson Unit 7. Well number _~w~rr No. 2 8. Permit number 77-64 9. APl number 50-- 089-20006 10. Pool Wildcat 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Permanently plugged to s, urface. feet Plugs ~measured) feet feet Junk (measured) feet Size Cemented true vertical Tubing (size, grade and measured depth) Measured depth True Vertical depth FcECEIVED Packers and SSSV (type and measured depth) 12.Attachments Description summary of proposal ~ Detailed operations program I3 BOP sketch [] 13. Estimated date for commencing operation August 15, 1986 14. If proposal was verbally approved Name of approve/~ Mr. Lonnie Smith Date approved 15.1he~atthg foregoing is true and correct to t~e bj~st of my,. knowledge Signed'----'-'~'~ / / Commission UsefOnly Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved by ...~ ~ ¢::;,:~, :_ · , Form '10-403 Rev 12:1.85 July 8, 1986 ~eturned ~ ' ' by order of Commissioner the commission Date ¢~-¢ Submit in triplicate Plan to convert Pt. Thomson #2 well from supsended to permanently abandoned status: 1. Smooth down gravel mound near wellhead. 2. Remove all debris, including any exposed liner or cellar material. 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 Alaska State C-1 No work required -Remove debris -Lower wellhead -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 MEMORAi ?)UM Stat? of Alaska ALASF~ ~OIL .__~D GAS CONSERVATION COFR4IS~ ON TO: C.V. C n DATE' August 12, 1986 Chairma~~~ mLENO.: D.ADA.41 THRU: FROM: Lonnie C.. Smith Commiss zoner Doug Amos' Petroleum Inspector TELEPHONE NO.: SUBJECT: Clean-up Inspection Exxon Pt. Thomson #2 Permit No. 77-64 For Final Abandonment Wednesday, jUne 18, 1986: I traveled this date from Kuparuk to P'~d~°e BaY an'd met~With 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. 'ALASKA o£i~ AND GAS CON.~ERVA'fi~,., ,.,,['IM£S:5£oN SURFACE ABANDO:~MENT REPORT ..... 20 AAC 25, ARTICLE 2 FILE INFO~TION: Operator ~?,~-~ ~~ Date Do,hole P & A Address Surface Location of Well ¢¢~ Ft. F~__~p_L, /~Ot Ft. F~I{L, Sec.,,~2 , T,~I ~_, R2~_~,. bZ M. 20 AAC 2~.120: WELL ABANDONMENT MARKER: Dia. Steel Post (4"Min.) ~ '~ Height Above Final Grade Level (4' Min.i Permit No. _ AP1 No. 50- Unit or Lease Name qZ>+ 7MD~. ~ovq. ..... Length (10' Min.) ID Top of Marker PiPe Closed with: Cement Plug Screw Cap Welds Set: On Well Head / , On Cutoff Casing , In Concrete Plug Distance Below Final Grade Level Ft. in. Side Outlets: All Valves and Nipples Removed All Openings Closed ~, With Blinds / , With Cement ~, Other INFORMATION BEADWELDED DIRECT~LY TO Fu\RKER POST: (List Where Different from File Information) Operator ~¢4-.¢P~_. ~+~.~"~~.~ t Unit or Lease Name ~ Well .Number ~.~,~, ~ , Surface Location of Well: ~Ft. Fk).~L, .~} Ft., F~yL, Sec ~ , T 4 . ~, R Z% 20 AAC 25.170: LOCATION CLEAN-UP PITS: F'----~lled In ~ Liners Removed or Buried x/~9, Debris Removed SURFACE OF PAD AND/OR LOCATION: Rough , Smooth , Contoured , Flat , Compacted CLEAN UP OF PAD AND/OR LOCATION: Clean Pipe Scrap ~, Iron Scrap ~, Wood , Hud , Cement Paper , Other SURROUNDING AREA: Wooded , Brush , Tundra ~, Grass , Dirt , Gravel Sand , Other CONDITION SURROUNDING A~EA: Clean /, Trash from Site Other , Trees and/or Brush from Clearing Site ACCESS ROKD: Dirt__, Gravel __.,. Ice CONDITION ACCESS ROAD AND SURROUNDING: Clean , Rough , Smooth , Trash from Operations , Trees and/or Brush--f~rom Clearing Road , Spoil from Clearing' Road Other REGOMMEND-APPROVAL OF AB~NDON~iENT: Yes , No~ F~na~ ~nspect~oa INSPECTED BY 0~/2618z C~ ~o~v ~~,~ ~\~ ~ J `'-~ ~\ ~~~ J horn ~ ~N /~/o . Z ,I,~.al crC.L, E~ON COMPANY, U.S.A. POUCH 6601 .ANCHORAGE, ALASKA 99502 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 drillsites located on the North Slope. We request that the status of the Duck Island pad drillsites be approved as permanently abandoned, all the other drillsites to be maintained 'as suspended. Very truly yours, NB3/13 :ng Enclosures A DIVISION OF EXXON CORPORATION RECEIVED SEP 1 1 191~ Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA - ALASKA JIL AND GAS CONSERVATION C,_ :vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 3. Address 4. Location of Well 2615' NSL and 1801' WEL, Sec. 3 T9N, R22E, UPM, North Slope, A1 aska 5. Elevation in feet (indicate KB, DF, etc.) _ Approx. 24' GL 6. Lease Designation and Serial No. ADL 47567 7. Permit No. 77-64 8. APl Number 5o- 029-20006 9. Unit or Lease Name Pt. Thomson Unit 10. Well Number Exxon No. 2 1 1. Field and Pool Wildcat 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. 14.1 hereby certify~Ifor.ego~rue and correct to the best of my knowledge. Signed 'S" Title Alaska The space bel~-r Commission use Date 9/10/85 Conditions of Approval, if any: ~I' [,~[ 8, S~Ift By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate August 15, 1985 Dr. MichaeI D. Wilson Alaska Research Associates 11440 W. 39th Place Wheat Ridge, Colorado 80033 Re: Preparation of Shale Compressibility Correlations through Boyless Law Porosity Analysis using Ditch Cuttings and Core Chips From State Sample Library. Dear Mike: Your June 28, 1984, letter explains why only four of the nine samples of the Exxon Alaska State A-1 well analyzed; however, nothing was mentioned of twenty-eight samples that you cut from the ~xxon Point.-Thompson Unit No. 2 well. In your April 4, 1985, letter you stated that none of the twenty-eight cuttings from this well were analyzed, but offered insufficient detail on why the analysis was not prepared covering the specified interval sampled in this well; as agreed to in our letter dated July 18, 1984. Please explain in detail why none of the twenty-eight cuts were ever analyzed. This would clear up any remaining uncertainties and conclude the Bulk Density Analysis proj:ect began June 18, 1984. Sincerely, Michael T. Minder Petroleum Engineer dlf:A.MTM. 9 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION Ct- MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 'DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. Exxon Corporation 77-64 3. Address 8. APl Number P O. Box 6601, Anchorage, AK 99502-0601 so-089-20006 4. Location of Well 2615' NSL and 180i' WEL, Sec. R22E, UPM, North Slope, Alaska 5. Elevation in feet (indicate KB, DF, etc.) . Approx. 24' GL 3 T9N, 6. Lease Designation and Serial No. ADL 47567 9. Unit or Lease Name Pt. Thomson Unit 10. Well Number Exxon No. 2 11. Field and Pool Wildcat 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 1985 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. Alaska Oil & Gas Cs:s, Cemmission Anchorage certify that~or, egj~f~ng.is,~t~ue and correct to the best of my knowledge. L/~,_ Exploration Coordinator- Signed Title A1 aska The space below for Commission use Date 9/10/84 Conditions of Approval, if any: 91 LGIIttlE C. $1111ti Approved by COMMISSIONER Approved Copy Returned _! _.~ ~ , . By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MEMORANDUM Stat of Alaska TO: THRU: FROM: ALASKA OIL AND GAS COI~SERVATION COPR~ISSION Cha~~~ Lonnie C. Smith '/ © Commissioner .~ Petroleum Ins~pector DATE: FILE NO: TELEPHONE NO: September 11, 1984 D.31.62 SUBJECT: Inspect Suspended EXXON Locations Listed Below For Suspended Status. Wednesday Se tember 5, 1984: I traveled this date to Prudhoe Bay an met with Jumidr-~7~st~k 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, i984 thru September 5, 1985. 'Duck Island #2 Duck Island ¢3 Alaska State A-1 Alaska State C-1 Alaska State F-1 Point Thompson #1 Point Thompson #2 Point Thompson #3 Attachment/pictures in file 02-O01A(Rev, 10/79) Suspended Well and Location 20 AAC 25, ARTICLE 2 Report FILE INFORMATION: ..... : / , ~pe---~ato----~-'-- ~.~>'..i_.,<::,.:../ ' ,' Date Suspended ";"::~ -~-' ~' ' : ~ ~ - '~ ~ "~ "' '~ ~ ' " ' ~-: ~ 'i ' Address __~::..::...~.~ ~:~>/ _. ' surface L6~i6n' Sf We'~ - - ' ,' "~ Ft. F /~ ~ ~ L, ~ ~ F . F~ ~ n API No. 50~' sec._7~', T~/./' ~ R.~.~~, M. Unit or Lease Nam f'?~ Well No,. : ~ Field & Pool ~ ~.,>.:-~.<:~ ..~_ Con~tion' of Pits . ::: .... :-:::_:~ Well head - Ail outlets plugged Yes ~ No Well sign - Attached to well head ~ No Attached to well guard Yes No Attached to Information correct Cellar - Opened Fil led Covered WaterWell - Plugged off Yes No Rat Hole No lr~s No Capped Open Explanation Of>an Fil led Covered 1'~/ ~ .... Ye s No No No Photographs taken to verify above conditions ~ No Explanaton Work to be done to be acceptable This well and location is (acc,.~ept.able) (unacceptable) to suspended for the period of _ ~7:: 19_~'~'thru ~':-:'~ ! ,.<::: > ~ :' ,-:' ,? . . , ~/ . . '~ . Ins~cted by: / '" ~'" '~ Date :..'%, ' ,.:. ?. ~: be classified as 19 ~._':, . Revised 8/24/82 EXXo.rJ - ~~, 7'ham~osonl ~~ .mac 3 , % ~ ~ ,(azE ~h'1 - S s~°~~1 ;~~ ~ r ;~ ~ ,. ~z.. ~'r'~ _ '" ylowd rx1~h~ cuel ! m~~.~ c~l~ ~~ ~ ~~~ ~~' ~ a it ~''1 September 29, 1~83 .Exxon Company, U.S.A. P. C. Box 6601 Anchorage, Alaska 99502 Cleanup Inspection for the Pollowing Wells~ Du/-~k Island Unit' ~o. 2, Sec. 8, TllN, R17E,' U.M. DuCk Island Unit No. 3, Sec. 10, TIlN, R17E, U.~J. Point Thomson Unit No. i, Sec. 32, T10~, R23E, ~oint-.Thomson~Unit :~0-i',~2; Sec. 3, T9N, R22E, U.~. Point Thomson Unit }Jo. 3, Sec. 34, %'10N, R23E, U.~4. Alaskm State A-l, Sec. 27, TiON, R24E, U.M. Alaska State C-i, Sec. 14, Tg~, R23E~ U.S. Alaska State D-l, Sec. 23, T10N, E23E, U.S. Alaska State F-i, Sec. 17, T10~, R23E, U.S. Alaska State C-2, Sec. 35, T10N, R24E, U.S. Cen tlen~n: Our representative inspected the a ~-bove ten suspended and abandoned well sites for extension of cleanui~ on August 31, 1983. With the exception of Alaska State C--2, the cleanup of these well sites are satisfactory. Because tl]e drilling rig was still on location at Alaska State G-2, a cleanup inspection could not be completed. Returned are eight approved ~0-403's, Sundry ~otices and ~eports on Wells, for all the listed wells ex. cept for two which need no further approval. Alaska State G-2 has a year to go under 20 AAC 25.170(a) and Alas~ State D-I which (classified as aban- doned) has previously been granted an extension to August, 1984 for removal of the sheet piling. The 10-403's which you submitted for Duck Island ~nit k:o. 1 ant Alaska State D-1 are not necessar~~ and are returned unsigned. Duck Island Unit ~o. 1 was abandoned, dcwr2~ole and Duck Island Unit ~-}o. 2 was sidetracked from the well bore of ~;o. 1. Conse- quently a 10-403 is net required for ~:o. I. A subsequent inspect/on of each well will be necessary by August, 1984. Sincerely, tonnie C"2- C or..~ ~:i s s ioner LCS/J~5~:lc: 103~D MEMORANOUM Stats of Alaska ALASKA OIL AND -GAS CONSERVATION COMMISSION TO: C. ~~tterton DATE: Thru: Lonnie C. Smith Commissioner FROM: Bobby Fos ter~%. Petroleum Inspector FILE NO: TELEPHONE NO: SUBJECT: September 6, 1983 108B:Z1 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 Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: _- Surface L6C~{lO Well N~ Condition of Pits Well head - Ail outlets plugged Well sign - Attached to well head Attached to well guard · Attached to Information correct No Ye s No No Cellar -' Opened Yes Filled ~ Covered Yes WaterWell - Plugged off No No No capped Ope n Rat Hole Fi 1 led Covered Exp la na ti on Ye s No Ye s No Ye s No Photographs taken to verify above conditions~ No Explanaton Work to be done to be acceptable This ·well and location is~-acceptable~ (unacceptable) suspended f.or the_~pe~od o~_ Inspected by: _ ~ ~ -- . -~ -- be classified as 19~. Revised 8/24/82 ~~ L ~j(~tac~ 70%~ I /~ ~~~ 3. co,~-~~ T9~J, ~° a~E , v~ ~/.~ race ~e ~: ~ /~ .~ ..~~ - y: ,~ __ y .~.._ _ - +f_~. _ ~-~:~ ~~ ~,: ~e~ ~~~ ~~~ rid ~~~ 8 -~~ ~ 3 - ---~x-- ~,.., c,,,,, ~-^-~- ~~x~~ ~~ ~~~,~.~ ~ Z D~ ,ors E) ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99§02 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION D H JONES EXPLORATION COORDINATOR -- ALASKA July 26, 1983 Mr. C. Vo 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. Point 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 STATE OF ALASKA ALASKA ..iL AND GAS CONSERVATION CL..AMISSION ,SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. Exxon Corporation 77-64 3. Address 8. APl Number Pouch 6601, Anchorage, AK 99502 50-089-20006 4. Location of Well 2615' NSL and 1801' WEL, Sec. 3 T9N, R22E, UPM, North Slope, Alaska 5. Elevation in feet (indicate KB, DF, etc.) _ Approx. 24' GL 6. Uease Designation and Serial No. ADL 47567 9. Unit or Lease Name Pt. Thomson Unit 10. Well Number g××on No. 2 11. Field and Pool Wildcat 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 1984 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, _Returned 14. I hereby certify that the fore, going is true and correct to the best of my knowledge. ~/'-7 . Exploration Coordinator - Signed ~*'*,¢~~~~ TitleAlaska Date 7/25/83 The space below for Commissio'n use _lvf Conditions of Approval, if any: Our representative ±~spected thls ~ell site on August 3i;~ 1983 cleanup was acceptable for a suspended location. A subsequent inspection will be BV Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate necessary by August, 1984. Approved by ~_ ~ Form 10-403 Rev. 7-1-80 February 23, 19 83 Mr. Hideyo Haga Mr. Michael B. Mickey Micropaleo Consultants 1217 Fal lbrook Court Bonita, California 92002 Preparation of Foraminifera, Palynologic and TAI/Kerogen Slides! and Selected Paleontologic Thin-Sections from Ditch Cuttings and Core Chips in State Well sample Library Dear Hideo and Mike.- Pursuant to my February 2, 1983 phone conversation with Hideo and your February 7, 1983 letter, permission tb hereby granted to Raga and Mickey, Micropaleo Consultants, to extract a maximum of 1 cc. of sample (cuttings) material per sample envelope and 1 cc. of core material per foot of core from the State's set of samples and core chips for the sole purpose of preparing palynologic, kerogen and foram slides at no greater than 90 foot composite depths, plus selected paleontologic thin-sections, within the designated intervals in the following wells, subject to the conditions set forth below, Sample Set No. Woll Interval 400 463 408 Sohio Sag Delta ~4 Exxon Duck Island Unit ~2 ~xxon. Pt. Thompson #2 2,570' -12,855' 2,136'-13,90f' 88'-14,117 ' II. MATERIAL TO BE PREPARED a. All welIs~ - Palynologic Slides - TAI/Kerogen Slides - Foram Samples (slides) b. In addition to the above slides, selected paleontologic (foram) thin-sections will be prepared in the 11,050' to 11,500' interval in the Sohio Sag Delta #4. - CONDITIONS ~ ~-. " ' 1.. Cuts'of the cuttings and/or core material on the above ' . ~ wells in the State sample coll~ction are to be extracted ~!i~i;~i~.i:.'i;~-- only from those in~ivi~ual ~nvelopes or bags in' whic~ total content of."cutting~ or core material is ?~... than 10 c~.< (No cuts are to b~ extracted if the ~;;~./~ !:,~-,,of~,material;',in the ~indivl~ual envelope is less than 10 ,;.~"-;~-_2.'~'~: .icropaleo Consultants will provide ~he Stato with a 3. ~'~L~e core, site aat~'~:and on~ ~creene8 set of ~alynologic , ?::~ sli~es, OhO'Set o~ korog~n/TAI slides an~ on~ s~t of -,. :'.. foram slides are to be ~re~red covering the ~ntir~ '-.. res~.~ive i~e~als in th~ '~ove ~lls~ ..:~ .,.~,~ :,. .: paleo~olog~c th~n-se~ons are to be pre~ared as '-"""~: '~:~-the C~ssion no later than. July ~, 1983, and are to . ~ be tra~mitted ~ire~ to the Com~ssion and not ~amin~d . . . . ~" 5~ ]'~. All residue--and ~c~ss ~terial is to be returned to ~ 'the C~s~ion~ no slides'or sample ~terials in .. -~ ,? 6. ,~ .No ~trogra~hic, vi~rinite refl~nc~ or other ....... ~,",~'.¥~.,~ ar~ to be pr'e~are~ nor analyses made without s~cific ..~.~.~?/~:~/~'~ ~!or.- consent,- from the C~ssion. ~. /... ; .' .. -. ., . . "'..'7.. ~icropaleo Co~ultants shall bear all costs entailed. "We are pleasea 'to ~rk with you in th~ ~n~ficial project and look fo~ar~ to.~our continue~ exercise of care an8 good in the handling of this li~te~ ~uantity of well ~terial. of us ~ow we all un~erstan~ that the S2ate~u well s~ple libra~ is public pro~rty and that granting you per~ssion to e~ra~ ~o~ions of ~terial fr~ this l~bra~ for the pu~o~u of preparing the[ in~[cated s lides,-.e~ances the value of tho libra~ and is in As you may 'know~ Chick Unde~oo~ and Lar~ ~her ~tarked cutting the samples on Februa~ 22~ 1983, Th~ ex~oc~ to finish by Willta~ 'Van Alen Senior ~etroleum G~ol°gist, CC~, ~r. Charles A. Un~e.r~o~. II :.~ ~;~ _~:.. .~¥~;~,~-~,~:~::~.¥,-..:~ 4540 Business Park Blvd. ~}!~?.~~;.~::: ~chorage, A las ka 9 95 03 E ,ON C0M PANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DIE:PA R T M E: NT AL. ASKA]PACI FIC DIVISION September 1, 1982 Mr. C. V. 'Chatterton Alaska Oil & Gas Conservation Commission .'.: 3001 Porcupine Drive ~ Anchorage, AK 99501 Dear Mr. Chatterton: On August 12, 1982 a representative of the AOGCC (Harold Hawkins) along With R. L. Westbrook and R. G. Dragnich, conducted an inspection of several of our drilling locations in the Pt. Thomson and Duck Island areas. During these inspections, the representative indicated that one-year extensions on suspended wells would be approved after the cleanup work was completed at these locations. We therefore submit, the enclosed photographs of our Pt. Thomson #3 and Alaska State C-1 drilling locations which indicate that the cleanup has been completed. We submitted Sundry Notices requesting extensions for these locations on August 10, 1982. Also attached are Sundry Notices requesting one-year extensions on our Pt. Thomson #1, Duck Island #2, Alaska State D-l, and Pt. Thomson #2 locations. These are wells which we wish to carry as suspended rather than abandonments. The Pt. Thomson //1 and Duck Island #2 locations were inspected by your representative who indicated that extensions would be approved. As you recall, Duck Island ~/1 and 2 is a single wellhead and the AOGCC has previously approved the abandonment of Duck Island ¥/1. The Alaska State D-1 location was previously submitted for abandonment approval on February 18, 1982 and was also inspected by your representative. We understand that to obtain a final abandonment status for this location, the sheetpiling will have 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 f/2 location has been suspended since September 1978 and was not included in the inspections. The attached Sundry Notice requests a one-year extension of this status.. .~.. A DIVISION OF EXXON CORPORATION ' .,.,,, : , ,I . 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: sj'm 60/2 Attachments STATE OF ALASKA ALASKA UlL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON .WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator Exxon C0mpany,. U. S. A. 3. Address Pouch 6601, Anchorage, AK 99502 4. Location of Well 2615' NSL & 1801' WEL of Sec. 3, TgN, R22E, UPM North Slope, Alaska 5. Elevation in feet (indicate KB,.DF, etc.) Approximately 24' GL 12. 7. Permit No. 77-64 8. APl Number 50- 089-20006 9. Unit or Lease Name Pt. Thomson Unit 10. Well Number Exxon No. 2 11. Field and Pool I 6. Lease Designation and Serial No. ,..ADL 47567 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 [] Alte~ Casing [] Perforations [] Altering Casing [] Stimulate [] Abandd~ [] 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 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. o 14. I hereby certify that~fore,going is true and correct to the best of my knowledge. smn~ T~t~e ^laska/Pacific Div.. Rep. lhe space below for Commission use Date 9/1/82 Conditions of Approval, if any: ORIGINAl SIGNED BY LONNIE C. SMITH Approved by . COMMISSlON ER Approved "?opy Returned · By Orde;-of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subseouent Reoort~" in Duolir. Rte ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton/~' .Chairman Thru.. Lonnie C. smith~/~'~ ~ Commissioner October 9, 1981 Doug Amos /q~-~ Petroleum Inspector Conduct Clean-up Inspection on Exxon's Suspended Point Thomson Unit No. 2 Well, Sec. 3, T9N, R22E, U.P.M. Permit No. 77-64 Tuesday AP.gust_ !_!, ~981: I accompanied Mr. Dave Cal loway, ~xon's representa~i~e~to the well site this date. As the attached photo's show the location is clean and returning to it's natural state. There is a proper well marker post cemented in the wellhead, with the required information bead welded to it. Therefore, I recommend to the commission that this location be grante~ clean-up approval. In summary, I conducted the clean-up inspection on Exxon's suspended Pt. Thomson No. 2 Well. I recommend to the commission that clean-up approval be granted for this location. FILl'; [ NFORr'IA'F ION: Address Surface I,ocacio~ of Wel~ Date I)ownhole }' ri.., , APl N,.). .5{) ..... ~- .- '..: rg.')o ,, IJni'L oC Le;~;e Name ."~ ' 20 AAC 25.120' X.,l;l~L AI~:\N1)O:.4MENT I)±a. Steel Post (4";,l~n.) -T~- , }letght Above I,'ina[ Grade Level (.5~ Hin.) Top of Marker Pipe Closed with' Cement Plug Set: On Well }lead ,~, On Cutoff Casing Distance Below Final Grade Level Side Outlets: All Valves and Nipl)les Re,proved ... All Openings Closed , Witi~ Blinds Length (10' Hin.) "~/~D, · · Screw Cap Welds , In Concrete , , Ft. in. , With Cement , Other INFOIU,iAT ION I~,E,\I)~.,'EI, I')I']I) I) [I~,I':C'I'E[,Y T'o :q.~I.:KEI{ PO,ST: (List M~ere Different from File lnfoFmaaion) Operator ~:-z-::~/O~ · ~o, (.~, ~, Unit or Lease Name Well Number 4':':¢ '[['~::,~5or~ ~h~,',4 ~-~ , Surface Location o~ We[l- '~[%.Fi' F~. L, (¢0 I Ft., I.~L, Sec 20 AAC 25.170: LOCATION CLE,,\N-UP PITS: Filled In ,'~/~, Liners Removed or Buried '-/ Debris Removed SURFACE OF PAl) AND/OR LOCAT[O"' Rough '~-~, Smooth , Contoured , Flat , Co~npacted , Other /7',,.~, ~ ~-~"~ ~o~ ' ~ ':~ CLEAN UP OF PAD AND/OR t,OCA'i'ION' Clean c~7~, Pipe Scrap Paper , Other Iron .~,~cr;ip , Wood , Mu d SUI",ROUNI) ING ARF. A' Wooded , Brush , Tundra p-"/, Grass , Dirt Sand , Other , Gravel CONDITION SUllI{OUND[>;('; Clean ~/'~ Trash from Site Other , Trees and/or Brush from Clearing Site ACCESS ROAI): Dirt __, Gravel , Ice , Otl~e.r h3 / ! CONI)[TION ACCESS ROAD ANt) Clean , Rough , Smooth , Trash Er(mi (')t>,?rations , Trees and/or Brush from Clearing Road , SI)oil from Clearing Road REMAINING TO BE DONE: RECO,~fflENI(i'~I>I>ROVRI~ OF ABANI)ONblEN'I?' ' Yes ' , -/, -¥ Final inspection t~5"__;-' , .... 05/26/81 /I p}. ?how. ~ov- yao • L ~~~ t,ooki~+q 5jE Fronn Air ~olc.n~ ~+I'vs t~ t~* frets A~~r Leo~ai~~ S,v~ ~~ E-t1-8) Q}. TN,..~.sort No. Z E (ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 PRODUCTION DEPARTMENT 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 ~_ Pt. Thomson #4 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. Very truly yours, ALH:..dag . A DIVISION OF EXXON CORPORATION Drilling Manager 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, ABA~DON~.~ENT A~D PLUCGIN(~, 20 DJAC 25.120 WELL ABAU. DONMENT IJ'~ARKER and 20 AAC 25.170 LOCATION CLEAN UP. Gentlemen: In regard to the above referenced regulations, your attention is called to an attached list of %~ells which, according to our records,, have not received a final location ins~,~ection and approval of clean up. In compliance v~ith 20 AAC 25. 170 Section (a), "~ithin one year of suspension or abandonment of an on- shore well", all clean up work is to be finished.. ~lection (b) provides the means for an extension of 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. ~,iany 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 %~hile 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 ins~.ecte¢] this summer please inform us. Therefore, %~e 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. LCS/O KT: be EXXON COMPANY U.S.A. SUSPENDED Duck Is. Unit #1 Pt. Thomson Unit #1 Pt. Thomson Unit 82 Pt. Thomson Unit #3 ~ PLUGGED & ABANDONED Canning River Unit B-1 Pt. Thomson Unit #4 DEPARTMENT OF NATUI~AL RESOURCES OFFICE OF March 29, 1979 Mr. Crandall D. Jones, Manager (~:: Exploration Department Alaska/Pacific Division Exxon Company, U.S.A. Post Office Box 2180 Houston, TX 77001 RE' Request for confidentiality of well data pursuant to AS 31.05.035(c)' Exxon Comp. any, U.S.A., Point Thomson Unit Wells No. I and No. 2. Dear Mr. Jones' By letter, dated January 16, 1979, Exxon Company, U.S.A. requested that the well data and reports submitted to the State be held confidential for a reasonable time after the disposition of unleased lands in the vicinity of the wells. The well data are due for release on the dates indicated below, unless the period for confidentiality is extended in accordance with AS 31.05.035(c) as amended by HB 815 during the last legislative session. Point Thomson Unit ~~ 1/7/80 Each of the referenced wells is located on a State lease which is ad- jacent to or near unleased State acreage. In my judgment, the well data and reports which have been filed with the State contain signi- ficant information relevant to the evaluation of adjacent and nearby unleased State lands. Therefore, all data from these wells submitted to the State pursuant to AS 31.05.035(c), as amended, shall be kept confidential until after the issuance of State of Alaska oil and gas leases in the vicinity of the wells. Sincerely, Robert E. LeResche Commissioner cc' Hoyle H !i~Hami.lton Thomas Cook COMPANY, U.S.A. POST OFFICE BOX 2180. HOUSTON, TEXAS 77001 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION CRAND~LL D. SONES MANAGER January 16, 1979 P ' Beso ces Confidentialit~-.of Well Data " Wells #l an~"~,~ ~ Pt. Thomson ............. ' ...... ":Unit - "-'~ .. Mr. Robert E. LeResche Commissioner of Natural Resources Pouch M Juneau, Alaska 99801 Dear Mr. LeResche- As operator of the Pt. Thomson Unit, Exxon hereby requests that all data submitted to the State of Alaska regarding Well No. l, Section 32, T-lON/R-23E, U.B.M. and Well No. 2, Section 3, T-gN/R-22E, U.B.M., in said unit, be held confidentl]~]--i~u~efinitel pursuant to Alaska Statutes 31.05.035(C), as amended D(H.B. 51'..~... Y We request that the Commissioner determine that the well data from the said wells will remain confidential. The information and reports from the said wells contain significant information relating to the valuation of unleased land in the vicinity. Specifically, there are unleased lands in T-8N/R-22 and 24E, T-'9N/R-24E, and T-lON/R-21-24E, inclusive. Please advise if' you have any questions regarding this matter. Very truly yours, CDJ 'nh A DIVISION OF EXXON CORPORATION cc - To Participants: Al-Aquitaine Exploration, Ltd. 540- 5th Avenue, S.W. 2000 Aquitai ne Tower Calgary, Alberta, Canada T2P OM4 Attention: Mr. Don Hill Atlantic Richfield Company P.' O. Box 360 Anchorage, Alaska 99510 Attention: Mr. John Carr Star Oil & Gas Corporation 2402 Norcen Tower 715 - 5th Avenue, S.W. Calgary, Alberta, Canada T2P 2X6 Attention: Mr. Ralph Estelle Coastal States Gas Producing Company P. O. Box 749 Denver, Colorado '80201 Attention: Mr. H. E. Dickard Gas Producing Enterprises, Inc. P. O. Box 749 Denver, Colorado 80201 Attentio~n: Mr. H. E. Dickard Cities Service Company 900 Colorado State Bank Building 1600 Broadway Denver, Colorado '80202 Attention: Mr. John Freeburg Continental Oil Company P.. O. Box 2197 Houston, Texas 77001 Attention: Mr. Duane Barrels · Mr. G. H. Doelling, Jr.' P. O. Box 3506 Odessa, Texas 79760 Mr. Richard Donnelly 704 Western United Life Building Midland, Texas 79701 Forest Oil Corporation 500 Canada Place Calgary, Alberta, Canada J2P 2Y3 Attention: Mr. H. V. Pederson Mr. Kingdon R. Hughes P. O. Box 2424 Midland, Texas 79701 Mr. Edward H. Leede 516 Building of the Southwest Midland, Texas 79701 Leede and Pine c/o Mr. Edward H. Leede 516 Building of the Southwest Midland, Texas 79701 Mobil Oil Corporation P. O. Box 5444 Denver, Colorado 80217 Attention: Mr. W. S. Blanton Newmont Oil Company 600 Jefferson - Ninth Floor Houston, Texas 77002 Attention: Mr. Roland E. Squyres Mrs. Bernice C. Peery P. O. Box 4023 Odessa, Texas 79760 Grace Petroleum Corporation 3 Park Central, Suite 200 1515 Arapahoe Denver, Colorado 80202 Attention: Mr. E. G. Hickel Pennzoil Company P. O. Box 2967 Houston, Texas 77001 Attention: Mr.. Herbert G. Officer Phillips Petroleum Company 1000 Security Life Building Denver, Colorado 80202 Attention: Mr. Vernon Stone Mr. Jack L. Russell P. O. Box 1604 Midland, Texas 79701 Mr. Robert Searls, Jr. P. O. Box 4023 Odessa, Texas 79760 . ~ ?age z Chevron U.S.A. Inc. P. O. Box 7643 San Francisco, California 94120 Attention: Mr. J. J. Anders Sunlite International Inc. 2500 One Allen Center Houston, Texas 77002 Attention: Mr. Edwin James Ti pperary Corporation 500 West Illinois Midland, Texas 79701 Attention: Mr. Phil M: Whitsitt Trans World Oil & Gas Ltd. 625 - 4th Avenue, S.W. Calgary, Alberta, Canada T2P OK2 Attention: Mr. J. A. Phillips Pacific Lighting Gas Development Company 720 West Eighth Street Los Angeles, California 90017 Attention: Mr. W. E. Ryan qEPARTMENT OF NAI'URAL RESOURCE'. OFFICE OF THE COMMISSI~,v'n Copies to: [ ] Administration [ ] Agriculture [ ] Geological Survey .[ ] Forest Land and Water Managemept '[~] Minerals and Energy Management [ ] Parks [ ] Pipeline Coordinator [ ] Planning [ ] Boston [ ] Conheady [ ] Dennerlein [ ] Stoops [ ] Suspense .[ ] Royalty Board ' . · ¥ . , IH~Yruct]bnS an fo ponse: ,.. · / To be Coordinated by: Date Due' Priority' From: 'q ~,,~,EPARTI4ENT OF NATURAL RESOURCE? OFF]CE OF THE COMMISSIONER ,',.)pi es to: ( [ ] Administration [ ] Boston [ ] Agriculture [ ] Conheady [ ] Geological' Survey . [ ] Dennerlein .[ ] Forest, La~n~d~..a..nd Water Managemep~t.~_~ ..... ,. [ ] Stoops -'-:-~-]--t;n-~TF~]-~"~a ~--~ ~]~r~ ~4~'HF~t~"-'~'~ - '? ""~ L ] ParKs .......... - ~ [ ] Pipeline Coordinator .. [ ] Planning ':- .-,-' .._ ..~ ' ..... - ' [.-] RoYalty Board (" ::"'~:--' :.]'. .... ':-'~" ..,."'..:-. '.. ."- :.~.-'~'..' '.- _- ~f~tructi~nS and for~ of.r~sponse:::..~: ": ' ' '" ' :' ._ . . tie Coordinated by' ! ,~,ie Due: ' Priori fy' . -- . · FEB ~_ 1979 Div. of Minerals & Energy Mgt.' Anchorage, Ak. ~ No. r--4 STATE Or ALASKA sus~rr ~ UU~.ICA'~ _ ' 50-089-20006 AND WORKOVER OPERATIONS ........... ~ ~'" ADL 47567 ci:~ ~ ~, ,.. ,-~. ....~ Exxon Corporation Ai'zch0r;;?:: . ~Poin~ Thomson Pouch 660~, Anchorage, Alaska 99502 IEx~on No. 2 DCA~ON OF W~ ' l0 . IFaD AND P~L OH Wildcat ' 2615 NSL & 1801 WEL of Sec . 3, T9N, R22E, o~~ ??-6~ REPORT TOTAL D~P~ ATF_~JD OF MON~'H. CH~\'G~S IN HOLE SIZE, CASING AD C~NTING JOBS INCLUDING DEPTH SET ~ VOL~ USED, P~ORATIO~S, ~STS ~ RESULTS FISHING JO~ JL~K IN HO~ AND SIDE-~.ACKED HOLE ~HD ~Y O~R SIGNIFIC~T ~qG~ ~ HO~ CO~ITIONS After pulling 6461' of 7" casing from the well, a 75 sack class G cement plug was spotted from 6240' to 6450'. The 9-5/8 inch casing was perforated with 6 shots from 5930' to 5931½'. The perforations were then block squeezed, below a retainer set at 5915', with 110 sacks of class G cement. Maximura squeeze pressure was 1000 psi. Next, the 9-5/8 inch casing was. perforated from 5860' to 5861½' with 6 shots. These perforations were block squeezed, below a retainer set at 5850', with 125 sacks of class G cement. Maxhnum squeeze pressure was 2000 psi. After waiting on cament for 6 hours, the 9-5/8 inch casing was cleaned out to~ by._., drilling out cement and the retainer at 5850'. ~~' A Baker model D packer was set at 5820'. Then 2-7/8" tubing, displaced with diesel, was set in the packer and an interval from 5864' to 5886' was perforated with two spt using a 1-11/16" tubing gun. The well was opened for flow and died after ½ barrel of fluid was recovered from the formation. The fluid level in the tubing was swabbed down to 2196' and remained at that level with no fluid entry. A wireline fluid sampler was run to 5865' and recovered 660 cc of .muddy filtrate. Monitored well for 6 hours and fluid level remained at 2196'. Pumped diesel into forn~tion at 1.5 BP,M with 2300 psi to confirm that perforations were open. The peEforations were squeezed, below the retainer at 5820', with 125 sacks of class G cement. Pumped 2 barrels of cement into the perforations, 4 barrels below the retainer and placed 20 barrels on top of the retainer. Displaced 9-5/8" casing v¢ith 12.2 ppg mud. Injected mud and surface fluids down 13-3/8" x 9-5/8" annulus, followed by 194 barrels of Arctic Pack. With open ended drill pipe at 2300', the 9-5/8" casing was displaced with 175 barrels of CaC12 water. Pulled out of hole to 120' and placed a 35 sack pernmfrost cement plug in the 9-5/8" casing from 42' to 120'. Removed BOP stack, cut off 9-5/8" casing below the top of the 13-5/8" "A" section and installed a 13-5/8" blind flange to top of wellhead. Well marker placed on top of flange and the well was plugged and suspended at 2000 hours August 12, 1978. This will be the final report on the well. Ex'pi o'rn f. inn Bant. ' 9~.~, ,qp~t- 7 1 972 '__z L. '_d___ --- NOTE--Report on this form ii required for each calendar ~nth~ regardless of the status of operations, and ~t'~ flltd~Jn dupll~le with the oil and gas conlervation commiHee by the ID~ of the ~uGcNding mon~. ~le~ ~t~erwile ~r~ct,d. ~ EYj ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION R .1.,. BOANE DISTRICT MANAGER Re' gONFIBENTIAL Mr. Hoyle H. Hamilton Director, Division of Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 September 6, 1978 Exxon Point Thomson ADL 47567 North Slope Alaska Dear Mr. Hamilton' We are attaching two copies of Form P-7, Well Completion or Recompletion Report and Log, for the captioned well which was plugged and suspended on August 12, 1978. Also attached are the following data: [,..c~ c~-- (1) One set of washed and dried samples (in 12 brown boxes) from 88' to 14,117'. (2) One blueline and one sepia print of the complete mud'log from 90' to 14,117'. (3) One composite sepia and one composite blueline print of the following open hole logs: Dual Induction-Laterolog BHC Sonic Long Spaced Sonic 8'-10' Long Spaced Sonic 10'-12' Compensated Neutron - Formation Density Compensated Formation Density Borehole Geometry Log (4) Core chips taken at 1' intervals (in eight white core boxes) from the following cores: A DIVISION OF EXXON CORPORATION Mr. Hoyle H. Hamilton Page two .September 6, 1978 Core No. Interval 1 9,855 2 10,152 3 11,595 4 11,6'78 5 11,697 6 11,757 7 13,124 9 - 9,885 - 10,212 - 11,655 - 11,697 - 11;757 - 11,847 - 13,161 14,090 - 14,117 No recovery on Core No. 8 from 14,058' to 14,086'. (5) Summary of format ion test data. Please note that the above material is marked confidential and should 'be kept confidential in accordance with the provisions of 11 AAC 22.535. Very truly yours, Rod L. Boane RLB:et attachment s CONFIDENTIAL Form P~7 '~ STATE OF ALASKA ' ' , .....er ; · ~ st rv.,t,ons on ' reverse OIL AND GAS CONSERVA~ON COMMITTEE '1 II I IL I i I I WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* I III I I la. TYPE OF WELL: :: W~LL WgLL b. TYPE OF COMPL~: .' ~~~ ~on ~~ration . · . o..w~.o. ~. f. OCaZ~O~ or wELL (Report Iocatto~ cleorl~ and ia ~ccorda~ce wtIA a~ State reqalrem~tf)· W~ldcat · ~,.~-, g615~ N~ ~ 1801~ ~ of 8~. ~~N~ ~, ~.I/ Ii~.~..*..~..~..~~o~ - '~ ~ ~, ~ , I o~VE) ~. PRODUCING I~-r~VAL(S), OF ~' C~l~~,' BM, N~B (B k~ ~)' ~. W~ DI~ON~ . Perforations c~nt~ for ~~s of ~fety. ~ it~ 28 ~d 29 for su~v~z ~rforagion ~te~s~ ~d c~nt~.. ~ Attaints for te~ ~ta AP1 NUMERICAL CODE 50-089-2OO06 ADL 47567 IF INDIA~, ALLO~ OR TR/BE NAM~ 24. r~',Z "-'-Cftc A~DOTHm ms,~u~, ~1 Induction, ~ ~nic, Fo~tion ~nsity~n~t~ Neutr~, Dieter, ~re~ ~%ry, Vel~ity ~. CAS~G ~ (Re~ all strips set ~ well) CASING SIZE WEIGHT, LB/FT. DEPTH SET (MD) HOL~ SIZE CEI~r-~TING AMOUNT PULLED 26. LANER P,~COIRZ) ~. PEP,/rORATIONS OPr._.~ TO PRODUC~ON (Interval, size and number) 13,020' to 13,110' (2 spf) ! 11,580' to 11,678' (2 spf) 5,864' to 5,886' (2 spf) 30. PRODU~'I~01~ DATE FIRST PITODUCTION ~ .PRODUCTION MEIHOD (Flowing, gas lift. pump~g--si~ and-type of ~EE ATTAC~EN~ ~OXE SIZE {PROD'N ~R -- ~ow'.' ~mo~ ~o P~S~ [c~~ o~n~ / ·TM TUBING R~C~ RD SCREEN (MD), ~ SIZe, D~I-I SET (M~), PACIC~ S~ (~) ACm. s.o~, Fr~='U~. C~=~ S~U~ZZ, ~C, D~I ~V~ (Mp) [~OUNr ~D ~ND OF ~Em~ U~ ~EE ATTACHMENt, OI 0;{ and {Gas 0;I ! ~2. ,-,aT aT~CH,ZNTS Casin~ Record; Acid & Squeeze Cement Jobs~ Core Data~ Test Data , 33. I her~'~ certff$~q~t t¥ for~gol~] and attached information la complete and correct ae determlu~d from all-available records SIGNED Pa~K~/[ ~'-~L. ~%3mne/'-'/~W~ ;--~- ~ ' , TITLE Alaskz/Paeifie. Division DATE, .q/~/7R INSTRUCTIONS General: This form is designed for submitting a complete and correct ,.,,,.ell completion report end leg on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (whe,-e not otherwise shovvnl for depth mec~sure- ments given ~n c. ther spaces on this form and in any att,~chr.'ner~ts Items 20, and 22:: If ti~is well is completed for separatc prcc~uction from more than one ~nterval zone (multiple completion), so state ~n ~tem 20. and in ite'-,~ ?2 show the ptc;]~Jc~:~{l interval, or ~nte, vals, top(s), bottom(s) and name (s) (if any) for only the intervu! rel)orted in item 30 Submit a separate report (page) on this form, adequately identified, for each add~tion~l interval to be seperately produce:i, show- lng the ackJitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produc~ct. (See instruction for items 20 and 22 above). :14. SUMM'AI~,Y ()lv F~)[{M'ATI6N TESTS IN('LUDIN(; IN'I'~It. VAL, T~s'rED. P}~E~SURE DATA ~'~d'0VERI~ OF OIL. GAS. 3S. G~GIC MARK~ WAT~ AND MUD NA~ SEE ATTACHMENTS Tertiary Surf Paleocene 7980' Thomson Sd 13,020' Pre-Miss 13,116' AN~ I)~'I'EC'I'E!) Sll1.)Ws OF OIL, GAS 0I~ XVAq~ SEE ATTACHMENTS FJ~xon TEST DATA Point Thomson Unit No. 2 DATE TYPE TEST INTERVAL CUSHION HOURS TESTED PROD' N FOR TEST PERIOD FLOW RATE FLOWING TBG PRESS TBG SIZE IFP ISIP FSIP 1-2-3 7/7/78- 7/10/78 DST through Perfs 13,020' -13,110' (2 spf) 12,975' diesel Unsuccessful Tests 4 7/13/78 DST through Perfs 13,020'-13,110'(2 spf) 12,975' diesel 13 1.5 bbls drlgmud 1/8" 0 psi 2-7/8" 4885 psi 6318 psi 5710 psi 7234 psi 5 7/19/78 Prod'n through Perfs 11,580'-11,678'(2 s/of) 11,528' diesel 25.3 10.5 bbls drlg mud and filtrate 3/~6" 0 psi 2-7/8" 4904 psi 7122 psi 5379 psi 6789 psi * Died in 5.5 hrs. 6 7/25/78 (1)Potential Test 11,580'-11,678'(2 spf) 11,528' diesel 15 178 B0 + 87.8 MCFG (0OR 493:1) 1/8" (2)248 BOPD (21° Gty @ 60°F) and 124 MCFG/D (GOR 500:1) 200 psi 2-7/8" 4965 psi 7122 psi 3202 psi 6739 psi (1) After Acid (2) Based on 6 hour stabilized test 7 8/4/78 Prod' n through Perfs 5,864 '-5,886' (2 spf) 5,820' diesel 3½ 0.5 bbls drlg mud CORE DATA Exxon - Point Thomson Unit No. 2 Core #1 Core #2 Core #3 Core #4 Core #5 Core #6 Core #7 Core #8 Core #9 9855' - 9885'. Rec. 28.5' siltstone with thin shale partings and thin laminae of sandstone, med gry-brn, firm, bleeding pin points gas and oil stain on shale partings. Horizontal dip. 10,152' - 10,212'. Rec. 60' of alternating thin bedded claystone and sandstone. Sandstone is med brn, vf to fg, v silty, poor porosity with oil staining. Claystone is med brn, silty, micaceous. Horizontal dip. 11,595' - 11,655'. Rec. 10.0' siltstone, lt-med gry, no show; 49.5' sandstone, It gry, vf to fg, hard, poor porosity with oil staining. Horizontal dip. 11,678' - 11,697'. Rec. 7' sandstone, It gry, fg to mg, fair porosity with oil stain; 6' shale, med gry, silty with thin beds of sandstone; 6' siltstone, med gry, shaley, no shows. Horizontal dip. 11,697' - 11,757'. Rec. 44' siltstone, med gry, firm, sandy (sand content increases downward), poor porosity with no shows. 14' siltstone as above with thin ½' to 1' thin interbeds of sandstone, salt and pepper, fg, fair porosity with no sh~ws. 2' sandstone as above with no shows. Dip 0-45v. 11,757' - 11,847'. Rec. 28.3' sandstone, salt and pepper, mg, fair porosity with interbeds of siltstone, med gry, shaley, no shows; 58.7 siltstone, med gry v shaley sandy poor porosity, no shows. Dip 0-20©. ' ' ' 13,124' - 13,161'. Rec. 1' siltstone, med gry, poor porosity with slight oil stain; 36' phyllite dk gry-blk micaceous sheen, fissil, no shows. Dip 0-906. ' 14,058' - 14,086'. No recovery. 14,090' - 14, 117'. Rec. 26½' argillite odk gry, silty, micaceous, no shows. Dip 30° - 95 . Mr. Hoyle H. Hamilton Page two September 6, 1978 Core No. Interval 9,855' - 9,885' 10,152' - 10,212' 11,595' - 11,655' 11,678' - 11,697' 11,697' - 11,757' 11,757' - 11,847' 13,124' - 13,161' 14,090' - 14,117' No recovery on Core No. 8 from 14,058' to 14,086'. (5) Summary of formation test data. Please note that the above material is marked confidential and should be kept confidential in accordance with the provisions of 11 AAC 22.535. Very truly yours, Rod L. Boane RLB' et attachments CASING RECORD Exxon Point Thomson Unit No. 2 25 CASING RECORD (Report all strin s set in well) Cas ing 'We ight Depth Ho le Am6unt '- Size ..Lb/Ft Grade Set (MD) Size Cementing. Record Pulled 28" x 36" insulated c:onductor 88' 42" to surf w/permafrost cmt None 18-5/8" 96.5 K55 842' 24" 4700 sx permafrost cmt None 13-3/8" 72 N/L 80 3296' 17~''2 6800 sx permafrost cmt None -5/8" 43.5 SO0 95 10,099' 12¼" 1430 sx class G cmt None 7" 35/32 Pll0 14,103' 8-½" 1750 sx class G cmt 6461' * 7" csg was backed off at 6510' and pulled prior to perforating 9-5/8" csg from 5864' to 5886'. ACID AND SQUEEZE CEMENT SUPPLEMENT Exxon Point Thomson Unit No. 2 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 13,020' to 13,110' 11,580' to 11,678' 11,580' to 11,678' 11,580' to 11,678' Sqz w/125 sx class G cement 2000 gal. of 15% HCL + 3% HF acid . 1~0 HF acid 4000 gal of 6% HCL + ~ and 50 ball sealers. Sqz w/125 sx class G cement 5930' to 5931½' 5860' to 5861½' 5864' to 5886' Block sqz w/ll0 sx class G cement Block sqz w/125 sx class G cement Sqz w/125 sx class G cement "~ No, v-4 STATE ~,, ALASKA ~m,.~v', ~,- I- ?0 OIL AND GAS CONSERVATION COMMIT'I'EE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS o.L [] G,. [] oT.,, Wildcat . NAME OF OPEI~TOR Exxon Corporation ADI~RESS OF' O~RATOR Pouch 6601, Anchorage, Alaska 99502 LOCATION OF WELL SUBMIT I~I DUP. LICAT~ 2615' NSI, & 1801' WEL of Sec. 3, T9N, R22E, UPM, North Slope, Alaska ~PI NUA¢ERICAL CODE ,, 50-Q89-20006 LEASE DESIGI~IA'~ION AXD SEI{I~ ADL 47567 IF INDIA]~ AL,~TT'E,E O]~ TRIBE 8. L,~IT FARAi OR t,EASE NAME Point Thomson 9 WELl, NO Exxon No. 2 l0 FIELD AND POOL. OR ~%'I]'~DCA Wildca% ~Rt s~c, T.. R. M (BOSOM H Sec. 3, T9N, PEP,MIT NO ,77-64 13. REPORT TOTAL DEPTH AT END OF MONTH. CHA~NGIkK IN HOLE SIZE, CASING AND CEMF~NT!NG JOBS INCLI;DING DEI~TH SET AN]) VOLI3/VIES USED. PER3~ORATIONS. T~STS A_N--D RESULTS FISHING JOB~ JL~K IN HOLE AND SIDE-TRACKED HOLE A~D A_~IY O~{ER SIGNIFICA3%IT CI6LAI~GES IN HoL~ COI~-DITIONS Set 7" csg at 14,103' and c~nented with 1750 sacks Class G cement (15.5 ppg), displaced with mud and bumped plug with 3000 psi. After pressure testing to 5500 psi, the 7" csg was perforated fr~n 13,020' to 13,110' with two spf using a 4" csg gun. The first three attempts to DST this interval were unsuccessful. On DS~r No. 4 the tub~Dg ~s filled with a 65 bbl diesel cushion and the well was opened for flow. In 9.8 hours.,_ .total---f~uid recovery was 1.5 bbls. Reversed out diesel cushion and mud ~i.th n~ Sho~ of hydrocarbons. Tlae perforations were squeezed, below a retainer set at 12,696', with 125 sacks of Class G cement. Four barrels of cement ~ere dumped on top of the retainer. An interval from 11,580' to 11,678' was then perforated with four spf using a 4" csg gun and a Baker model F-1 packer was set at 11,528'. Then 2-7/8" tubing, displaced with diesel, was set in the packer and the well was opened for flow. The well died after 10.5 barrels of fluid was recovered from the formation. A wireline fluid sampler was run to 11,420' and recovered 600 cc filtrate. After displacing 47½ barrels of 15% acid into the formation at a rate of ½ BPM, the well was opened to flow and recovered 42 barrels of load water before dying. The interval from 11, 622' to 11,642' was reperforated with two spf and acidized with 95 barrels 7% acid using 50 ball sealers. A six hour stabilized test through perforations from 11,580' to 11,678' flowed 21°API gravity oil at a rate of 248 BPD with a GOR of 500 CF/bbl. The perforations were squeezed, below a retainer set at 11,480', with 125 sacks of Class G cement. Four barrels of cement were dumped on top of the retainer. The 7" casing has been cut at 6510' and is being recovered from the s~a~ ~_~ /"~~ =~ ~lora~ion uep~ ......... n~ _Au~st 16. 1978 Form 10-A03 ~ Submit "1 ntentlons" in Triplicate RE'.V, 1-10-.73 da "Subsequent Reports" In Duplicate STATE OF ALASKA 5, API NVMERICAL COUE OIL AND GAS CONSERVATION COMMITTEE r 50-089-20006 5. LEASE DESIGNATION ANOSERIAL NO. SUNbRY NOTICESAN® REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen " ~I, 47567 for wch proposals.) Use "APPLICATION FOR PERMIT- 1 7. IF INUTAN, ALLOTTEE OR TRIBE NAME . WELL WELLC~ OTHER Wildcat 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAM EXXON CORPORATION Point Thcgnson Unit _ 3. ADDRESS OF OPERAI-OR 9. WELL NO. P.O. Box 2180 #2379, Houston, Texas 77001 Exxon No. 2 4, LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT At surface T9N 3 f S ' Wildcat , , eC. NSL & 1801 WEL o 2615 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) R22E, UPM, North Slope, Alaska Sec. 3, T9N, R22E 13. ELEVATIONS (Show whether DF, RT, GR, etc.) T2. PERMIT NO. Approx 24' Q, -~ 77-64 lA, Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: TEST WA"TER SHUT-OFF PULLOR ALTER CASING WATER SHUT-OFF REPAIRING WELL FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING SHOOT OR ACIDIZE ABANDON* SHOOTING OR ACIDIZING ABANDONMENT" REPAIR WELL CHANGE PLANS (Other) r (Other) Sl~~end X (NOTE: Report results of multiple completion on Well Camplstfon or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent tlstalls, and glue pertinent dates, including estimated date of starting any proposed work, Reason for Suspension -Well suspended for possible re--entry. Suspension plugging procedure as described in attachment hereto. RECEIVED ~~~~Ft ~~~~ u;i ~ i kr f _ _ ~:~ ,F ~i'h yi Division mf QAnchorape~n~ryat'scn 16. !hereby certify fiat~he foreg~ is yry~e and correct //,~- ~' ~ District Manager SIGNED +~i -~'~, ~ ' ~°'~f /~ "'~-~ TITLE ~-aska/Pacific_ Division _ DATE August 7, 1978 (This space for State ca usv) r ~ ~ ~ >~ APPROVED BY TITLE QATE COPJDITIONS O APPROVAL, IF ANY: t`~ti`t1Pf3a~..~~;,,.f See Instructior-s On Reverse Side ~u Form 10-403 · REV. 1-10~73 Submit "intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL Wildcat 2. NAME OF OPERATOR E:x3CON CO~POPAT TON 3. ADDRESS OF OPERATOR P.O. Box 2180 #2379, Houston, Texas 77001 4. LOCATION OF WELL At surface 2615' NSL & 1801 ' WEL of Sec. 3, T9N, R22E, UI~M, North Slop~, g~aska 13. ELEVATIONS (Show whether DF, RT, GR, etc.) Approx 24' GL 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-089-20006 6. LEASE DESIGNATION AND SERIAL NO. ADL 47567 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Point Thc~son Unit 9. WELL NO. Exxon No. 2 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 3, T9N, R22E 12. PERMIT NO. 77-64 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) Suspend PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF r--I REPAIRING WELL FRACTURE TREATMENT~ 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 Dertlnent details, and give pertinent dates, including estimated date of starting any proposed work. Reason forSuspension - Well suspended for possible re-entry. Suspension plugging procedure as described in attachment hereto. RECEIVED A J6 fi..- !9t0 Division ~f 011 & Ga.~ g~n~ervation 16. I hereby certifyz~t~he foregolr~ is.~e and correct /~c'-~'_ _~/'--~/:~' District Manager SIGNED ?? _~ ~ /'~ ~"~ .... TITLE Alaska/Pacific Division August 7, 1978 (This space fo r St ate o~..f, f4/e use).~() /) ONDITIONS OF~APPROVAL, IF ~..Y: ' See Instructions On Reverse Side DATE DATE POINT THOMSON #2 SUSPENSION PROCEDURE (PROCEDURE BEGINS AFTER PLUGGING THE TEST INTERVAL AT 5862' - 5960') i · Trip in the hole with open ended drill pipe to 5750' and circulate and condition the well bottoms up. · Thoroughly clean out the rig suction tank and mix the following premix slurry for Arctic Pack placement in the 9-5/8" x 13-3/8" annulus: 173.5 bbls diesel 11.0 bbls H20 12.5 lb/bbl EZ Mul 28.0 lb/bbls Geltone 660.0 lb salt Mix the Arctic Pack premix according to the attached instructions. Mix this slurry at 60°F and after mixing is complete reduce the mix temperature to 40°F. · Rig up the Halliburton cementing unit to displace the Arctic Pack premix with additional Geltone to the 9- 5/8" x 13-3/8" annulus. Pressure test all cementing lines to 5000 PSI. · Displace 30 bbls of the Arctic Pack premix to the 9- 5/8" x 13-3/8" annulus. Displace the additional 150 bbls of Arctic Pack to the annulus while adding 25 lb/bbl of additional Geltone to the premix on the fly (3750# total additicnal Geltone). Cease displacement to the annulus after the full 150 bbls have been dis- placed. Close in the 9-5/8" x 13-3/8" casing annulus and carefully catch all remaining Arctic Pack premix in the Halliburton lines in 55 gallon drums. Excess fluid should be stored in the drill site burn pit pending future disposal. Circulate 12.2 lb/gal mud heated to 70°F+ inside the 9-5/8" casing string for 2 hrs. ~ In the rig suction pit mix 175 bbls of 10.6 PPG CaC12 water according to the following formula: · - 139 bbls H20 - 28000 lbs CaC12 (Dowflake) Mix and heat the CaC12 mixture to +70°F. Trip out of the hole to 2300' and circulate and condition the well. · · · 10. 11. 12. Rig up to displace the CaC12 water. Close the annular preventor and reverse out the existing mud with 50 bbls water followed by 140 bbls CaC12. Trip out of the hole to 120' keeping the hole full with the remaining CaC12 water. With the drill pipe at 120' mix and displace the fol- lowing cement slurry to the wellbore as a balanced plug displacing cement with clear water: Slurry 35 sx, 15.0 ppg Permafrost 5.8 bbls slurry volume 3.5 gal/sx mix water 2.9 bbls mix water TT = 4 hrs + Trip out of the hole to 40' and reverse out. of the hole. Trip out After waiting on cement 6 hrs, run in the hole and tag the cement plug top. Reverse circulate out the remaining CaC12 water with 10 bbls clear water followed by diesel. Insure that all CaC12 water and diesel is contained in the rig active pits and not jetted to the reserve pit. Drain the BOPE stack and 13-3/8" "B" section and nipple down the same. Cut the 9-5/8" casing stub looking up to rest below the top of the 18-5/8" "A" section. (Note: Requires removal of the secondary seal above). Use a power saw to cut off the 9-5/8" casing. Install a 18-5/8" flange with 3" bullplugged companion flange assembly as shown in the attached sketch. To the top of the flange weld a 6" dia by 10' long piece of line pipe with the following information bead welded on the pipe: Name of operator Well name and number Exact location The top end of the pipe must be welded closed. 'UNWEIGHTED' BAROID~ ~RCTI~C CA'SInG PECK Baroid's Arctic Casing Pack is a stable, highly viscous, non- freezing fluid which is'placed between casing strings to prevent casing failures and provide insluation 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 coefficient 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 neede'd' 'for'"l'0'0' ba'r'reTs'.of' Un~.~e~'~hted Baroid Arctic ~asing Pack: 107 50 lb. bags GELTONE 3 55 gal. drums E Z MUL 300 lbs. Salt , ° 87 bbls. Diesel 5% bbls. Water Weight of unweighted pack' 8:3 lbs./gal. ~ixing .procedure 'for' ~nwe'i'ght'ed' Baroid~ Arctic' 'CasLi.n~ Pack: A. Formula for 100 barrels of Baroid Arctic Casing Pack (premix): Diesel Wa ~er E Z MUL GELTONE Salt 87 barrels 5% 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: 1. Clean rig tanks and check for leaks. 2. Add water through salt barrel. 3. Add diesel. 4. Add E Z MUL -' agitate pit. 5. Add GELTONE. · BAROID 'ARCTIC CASING PACK Recommended procedure when using Dowell/Halliburton equip- ment: 1. clean and check tank for leaks and proper hookup so casing pack can be rolled. 2. Mix water and salt through hopper and circulate in displacement tanks until re~dy to mix in with diesel. 3. Add diesel. 4. Add EZ MUL - agitate tank. 5. Add GELTONE NOTE: When using Halliburton equipment have their operator open jet in mixing hopper bowl wide 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 hop- per must have a jet installed or the discharge line will plug up. Displacement Procedure Run in with the drill pipe and open the D.V./F.O. collar, then set the RTTS tool. Pressure up the casing/drill pipe annulus to check the RTTS packer. 5'00 psi is sufficient for this test. 2. Flush and clean the annulus with water until mud is displaced. · 3. At Halliburton/Dowell unit have sufficient GE~TO~ on hand to add the final 25 ppb to the casing pack. When ready to place the pack, add on the fly 25 ppb GELTONE through the hopper located just upstream from pump suction. 4. Establish pump rate so that the GELTONE can be added evenly. Two barrels per minute is the recommended pump rate. 5. If a cubic foot per minute counter is not available on the pumping unit, keep a pump rate/time log so that the proper amount of GELTONE can be added and volumes determined. ARCTIC CA'SI~.~G PA'CK -3- o ~ . Adequate samples should be 'caught of the casing pack returns so that a retort analysis can verify that the casing pack is not conaam.lnaued with drilling, mud or water. When the RTTS tool is released, the D.V./F.O. colla~ should be immediately closed to prevent any U-tube effect from occurring. The F. O. collar is recommended as it can be reopened as needed. It' is also suggested that the ~TTS tool be set immediately above the collar so a positive seal is raade when packer is set. This should eliminate any mud from the casing/drill pipe annulus being stripped in while displacing with casing pack. , Final formula of BAROID Arc~i~ Casing Pack left in annulus: Diesel Water. Salt · EZ MUL GELTONE '87 barrels 5.5 barrels 60 ppb per barrel of %cater 12.5 ppb 53.5 ppb For-the GELTONE to yield sufficiently to suspend the BAR0~D it zs recommended that the premix be heated to 70°F while mixing. Afte~ the casing pack is premixed it should be left to cool as much as possible before being used. (40°F is the optimum temperature). =~e mixinc procedure if it is not practical An alternate to the ~ .... ~ ~ · · ' %e to heat'the mixture to 70°F; is to add addztmonal GELTONE to ~1 premix, thus insuring the BAROID is held .in suspension. Whatever amount of GELTONE that is needed should be subtracted fron~ the final 25 pounds of GELTONE. Care should be used, not to overtreat · with GELTONE if this procedure is chosen. When calculating the volumes for the job, a certain excess of cas- ing pack will be needed. The casing pack/water interface normally will be displaced in the first 30 barrels. An additional amount; no% less than 50 barrels, should follow so that adequate samples can be caught and analyzed to insure that the casing pack is com- ing back clean. The casing pack returns can be caught and recon- ditioned for later use. The GELTONE content can be easily determined bY running a modified Methylene Blue test thus making the reconditioning of the casing pack a sim. pla procedure.. BARO'ID' ARCITC CASING PACK -4- Reference: · STB-185 Field Trial of BAROID'S Thermo-Pack on the' North Slope of Alaska. L. J. Remont STB-639 Oil Mu~ Casing Pack for Permafros% Forma%ions. R. L. Sherman PI- TI--tOHSON '¢ ¢_.. ~URF, ACE ABANDON I"'I EN T SKF_TO H G" DI,~ x '~ ' LONE~ LINE: PiPE BEAD ;~/ELD LETTERED A~ FOLLOX4~: "EXXON P+ TI-IOi"I~5ON UNIT - WELL 1'40. P615' NSL .9" C..OI"I PAN ION FLAb,,t~F_. I'~-~" 5000 PSZ ~F__.D FLANC--.-.-.-.-.-.-.-.~E L I:~ 3OOO ~ FI_~J~C_.-.-.-~ ON EXISTING '~:~' 5E. CTI~ 9;i~" CASING, ...%" ~ ~ GATE: VALVE POINT THOMSON #2 ABANDONMENT PROCEDURE WELL SKETCH r_~c~ i~.~ PP~ E'v,/ I'IUD Cement Plug @~40' - 120' 28" x 36" Conductor @ 88 Arctic Pack in 9-5/8" x 13-3/8" Annulus CaC12/Mud interface @ 2300' 18-5/8" casing @ 842' 13-3/8" perforated @ 3060' - 2874' 13-3/8" casing @ 3296' 9-5/8" packer @ 5820' 9-5/8" bridge plug @ 5915' 7" casing stub @ 6510' 9-5/8'~ casing @ 10099' TOC @ ].0660' 7" bridge plug @ 11480' Perforations @ 11580' - 11678' 7" bridge plug @ 12696' Perforations @ 13020' - 13080' 7" casing @ 14103' l'~rm No. P--,I REV. 3-1-70 STATE O~ ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. o,~,,~L [] G,sw,~,. [] o,.,, Wildcat NAME OF OP~:tATOR Exxon Corporation 3~ ADDRESS OF OPEP,~TOR Pouch 6601, Anchoraqe, Alaska 99502 4.LOCATION OF WELL 2615' NSL & 1801' WEL of Sec. 3, T9N, R22E, UPM, North Slope, Alaska 50-089-20006 ONSHORE D/ST, OFFICE LEASE DESIGNATION AND SEIqIAL NOr JUL 5 ADL 47567 ~F [NmA~ ^Lo~'T~,,E o~ ~~TION DIVISION ~S. GEOLOGICAL SURVEY t~ZT ~.~ o~ L~AS~ .~NC; ;ORAGE, A~SKA Point ThomsOn Unit 9 WELL NO Exxon No. 2 13. REPORT TOTAL DEPTH AT F2~D OF MONT%I. CHJkNGES IN HOLE SIZE. CASING AD Clk-NIENTING JOBS INCLUDING DEPTH SET ~ VOL~ USED. P~O~TIONS. ~--~TS ~ ~SULTS FISHINTG JO~ JUnK ~ HOLE AND SIDE-~.LACKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS 10 FIELD A_AID POOL. OH WILDCAT Wildcat 11 SEC, T.. R., M (BoTToM HaLl Dl~ o~~ j Sec 3 T9N R22E . , , IC~ 77-64 An 8-1/2 inch hole was drilled to a depth of 13,396 feet and the following open surveys were run- Dual Induction BHC Sonic Long Spaced Sonic Formation Density - Compensated Neutron Repeat Formation Tester Dipmeter Velocity Survey In addition 99 sidewall cores were attempted with 83 being recovered. On June 23, 1978 a final total depth of 14,117 feet was reached. The well was logged up as follows' Dual Induction BHC Sonic Long Spaced Sonic Formation Density - Compensated Neutron Repeat Formation Tester Also 25 sidewall cores were recovered from 45 attempts. month were' Intervals cored during the Core #8 - 14,058 to 14,086 feet Core #9 - 14,090 to 14,117 feet RECEIVED At the end of the month 7 inch casing is being run in the hole.,,~?L~ ,5 %978 Division of 0il & Gas (;o!l~mvatie An~hot~o st. Mgr. "OffShor6/Ak ........ 14. I hereby c~'tif2t that the foregoing is true and correct s~mm~'.J~w~. Rod L. Boane TITU~ Exploration Departm.ent ~-~ _ ,]uly 5, 1978 -" - ~/~flr~ ........... NOT[--Report o~rm~required for each calendar ~nth% regardless of the stotas of operations, and must ~ flied In duplicate with the oil and got con.ervation commiffee bythe 15ffi of the suec~ding monffi, uqle~ otherwise ~irected. l"orna Ho. 1R~V. ~- 1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COAA~ITTEE MONTH£Y REPORT O'F DRILLING AND WOR'KOVER OPERATIONS Wildcat . 2.NAME OF OPi~:kA. TOR Exxon Corporation 3.ADDRESS OF OPER. A~R Pouch 6601~ Anchoraqe, Alaska 4 LOCATIOlgi OF WELL 99.~N? 2615' NSL & 1801' WEL of Sec. 3, T9N, R22E, UPM, North Slope, Alaska SUBMFr ~ DU'PLICATE 15 Alii N{JMERICAJL CODE 50-089-20006 ~ ADL 47567 ~ ~. 8 L~IT FA~{ OR LEASE ~AM~ .. Point Thomson Unlit ~ 9 WELL NO ~ Exxon No. 2 [ ~ 10 FIELD Ak;D P~I,. OR WI'i]D~AT Wildcat ~: n sec, ~.. a. M (~O~OM HO~ O~ Sec. 3, T9N, R22E ~ 77-64 ~ 13. REPORT TOTAL DEPTH AT END OF MONTH1 Ct-~k.'~N'G~S IN HOLE SIZE, CASING A~ C~ENTING JOBS INCLUDING DEPTH SET ~ VOL~ USED, P~O~TIONS. ~STS .~ ~SULTS FISHING JO~ JD~K ~ HOLE AND SIDE-~ACKED HOLE ~ND ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~N~ITIONS During the month the 9-5/8 inch casing was backed off at 3110' and pulled up to 2832'. The 13-3/8 inch casing was then perforated with 4 shots per foot in the following intervals. 2874' - 2884' 2900' - 2910' 3010' - 3O20' 3050' - 3060' After breaking down the formation, the following injection rates were established through the perforations. 1BPM at 260 psi 2 BPM at 650 psi 4 BPM at 850 psi 7 BPM at 900 psi The 9-5/Sinch casing was reconnected and pressure tested O.K. to 3000 psi. Raised the mud weioht to 15 ppg and resumed drilling operations after drilling out the retainer and cement plug. Increased mud weight from 15.0 to 15.3 ppg at 12,930' and cut core #7 from 13,124' to 13,161'. At the end of the month the well was drilling at 13,248' with an 8-1/2 inch bit and 15.3 ppg mud. GONFIDENTIAL RECEIVED Division ~l Oil & 6a~. Omm. mvati0 .... /Ak; l;. I hereby certif, %hat the foregoing is ,~ue a~"~d eorre~ Dist, Mgr Offs-hore ~ s~G~~~:~V Rod L. Boane =~Exp]ora_tion DepartmeD~t .... n~ June 22. 1978 NOTE --Reoort on this for~i~ required for each colendar ~nth~ r~gordless of t~ .tntus of operutio~s, und must ~ filed in duplic, te wiih th e oil .nd gas conservation commiffee by the 15~ of the su~c~ding mon~, u~le~ ofherwiss ~ir~cted. E]I ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION R. k BOANE DISTRICT MANAGER June 6, 1978 Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Attn- Mr. Lonnie Smith Dear Mr. Smith- Enclosed are three copies of form 10-403, "Sundry Notices and Reports on Wells" being submitted for Exxon Point Thomson Unit No. 2. Very truly yours, Rod L. Boane RLB:mrs attachments xc: J. F. Homer B. E1 kin W. Fuge A DIVISION OF EXXON CORPORATION Form RE¥. 1-10-73 Submit "Intentions" tn Triplicate & "Subsequent Reports" tn 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 cleepen Use "APPLICATION FOR PERMIT-J' for such Proposals.) WELLL..-i OTHER Wi 1 dcat 2. NAME OF OPERATOR Exxon Corooration 3. ADDRESS OF OPERATOR P.O. Box 2180 Houston, Texas 77001 4. LOCATION OF WELL At surface 2615' NSL & 1801' WEL of Sec. 3, T9N, R22E, UPM, North Slope, Alaska 13. ELEVATIONS (Show whether DF, RT, GR, etc.) Approximately 24' GL 14. Check Appropriate Box To indicate Nature of Notice, Re 5. /~'Pl NUMERICAL CODE 50-089-20006 6. LEASE DESIGNATION AND SERIAL NO. ADL 47567 7. IF INDIAN, ALLOTTEE OR TRIBE NAME , 8. UNIT, FARM OR LEASE NAME Point Thomson Unit 9. WELL NO. Exxon No. 2 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 3, T9N, R22E 12. PERMIT NO. 77-64 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ puLL OR ALTER CASING ~ FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL P CHANGE PLANS SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Comoletlon or Recompletion Report and Log form,) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent ¢letalls, and give pertinent dates, including estimated date of startin9 any proposed work. We propose to increase the depth from that stated in the lO-401 filed September 21, 1977 from 13,500' to 14,500'. No alteration of the casing program is presently proposed. SIGNED ~ ~"u ' , TITLE District Exploration ManagerDATE (This space for State of~f~use) ..... ~; / ~'~ ~ ' See Instructions On Reverse Side DATE ~/[[ ~.i,// / i E/ Approved Cop~ Returned COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE'ALASKA DIVISION R L 8OANE DISTRICT MANAGER May 26, 1978 Alaska Department of Environmental Conservation P.O. Box 1601 Fairbanks, Alaska 99707 Attn: Mr. Doug Lowery cc' o. k. ¢i ilordh . Dear sir: A hydraulic fluid leak occurred at Exxon's Point Thomson #2 location at 3:30 pm AST on May 7, 1978 due to the malfunction of a remote control cylinder on a closing unit valve causing the BOP system reservoir to overflow. Pursuant to 18 AAC 75.100 under authority of AS 46.03.020 (10) (A) and AS 46.03.755 this letter is written confirmation of the telephone report made by Mr. J. W. Jackson to Mr. John Janssen of your office at 9:15 am AST, May 7, 1978. Below is the information required by 18 AAC 75.110. · Date and time of discharge - May 7, 1978 at 3:30 pm AST. · Location of the discharge - Latitude 70°09'47 46"N Longitude - 146030'55.48'' W, or the Exxon No. 2 Point Thomson Unit well site location. 3.' Person or persons causing or responsible for the discharge - None. Discharge due to equipment mal- function. · Type(s) and amount(s) of hazardous substance(s) discharged - ARCo Dextron ATF hydraulic fluid. Approximately 35 gallons. · Cause of discharge - Malfunction of remote control actuator cylinder on a Barksdale control valve and associated fluid bypass causing the hydraulic system reservoir to overflow. · Environmental damage caused by 'the discharge t extent ascertainable - No environmental damage detectable as a result of the spill. 100% of spilled fluids recovered· A D!VISION OF EXXON CORPORATION Alaska Department of Environmental Conservation May 26, 1978 Page 2 e Clean-up actions undertaken - Ail spilled fluid was recovered by use of absorbent materials and recovery of contaminated snow and ice. · Location and method of ultimate disposal of the hazardous substance and contaminated clean-up materials. The contaminated absorbent, snow and ice has been placed in containers in the drill site burn pit for future disposal via burning pending approval by the D.E.C. ~ Actions to be taken to prevent recurrence of the dis- charge - The ..... m~~ tank has been emptied and cleaned. The drain ports have been bull plugged to prevent further leakage. If you require any additional information, please contact Mr. J. F. Homer of the Exxon Anchorage office at 907/276-4552. Very truly yours, R. L. Boane DRA: jrh cc: O. K. Gilbreth 02 ~ 001 B I Rev. 10/761 STATE of ALASKA TO: r ~~~~~~~'~~~~~I Division of Minerals & Energy Mngmt. 0. K. Gilbreth, Director FROM: ('~p~ Pe e Nelson, LMO J~v`'~ Acting Lsg. Mngr. DATE: May 8 , 19 7 8 /; ,;~ ~ °~~ ~ ~~ FILE NO: Work File S~I~~?~ TELEPHONE NO: ~ K~ SUBJECT: Pt. Thomson Plan of Development and Operation Attached is Exxon's First Plan of Development and Operation for the Point Thomson unit which has been submitted in accordance with Section 10 of the agreement. May we have your comments? C.GErI ~~~. EPt _- ii--E*~~, _~ ,~ .I~ _ ~ _ -- -I - •r4 ~ . , ___ I v ... 1 _. ~ - R„~ ~ - ~~,,. i - -_ ~ ~ '-,- _c -F: O ~vV~ ~v, ~ V %C .d'w-we.Q~G.~rZ,. ~ ~ z- (~~.~ G--mac. o^-~ ~ L`""mac ~~~ ~ ~~~ ~/ ~~~~~~~~ D`vi~1~r~ of fir) arrd Gas ~snserv~tlon ht3~itePgr~a COMPANY, U.S.A. POST OFFICE BOX 2180 · HOUSTON, TEXAS 77001 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION CRANDALL D. JONES MANAGER November 18, 1977 Plan of Further Development and Operation Point Thomson Unit · Arctic Slope, Alaska Mr. 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' JAN - 3 1978 Div, of Minerals & Energy MgL Anchorage, Ak. By letter dated September 21, 1977, Exxon Corporation, as Unit Operator, filed an application with the Director, Division of Oil and Gas~Conservation, Department of Natural Resources, for a Permit to Drill the Point Thomson Unit No. 2 well. Concurrently, we filed with you a Plan of Operations, with various Exhibits, for such well. A copy of said Plan is enclosed. By Decision letter dated November 4, 1977, your office certified that the test conducted October 30, 1977 demonstrated that the Point Thomson Unit No. ! well is capable of producing in paying quantities as per paragraph 9, "Drilling to Discovery", of the Point Thomson Unit Agreement. Article 10 of the Point Thomson Unit Agreement provides in part that within six months after completion of a well capable of producing unitized substances in paying quantities, the Unit Operator shall submit for the approval of the Director an acceptable Plan of Development and Operation for the unitized land which, when approved by the Director, shall constitute the further drilling and operating obligations of the Unit Operator under the agreement for the period specified therein. Exxon Corporation, as Unit operator of the Point Thomson Unit, here- by requests that you consider the enclosed Plan of Operations as its proposed Plan of Further Development and Operation specified in A DIVISION OF EXXON CORPORATION Mr. Joseph Green - 2 - November 18, 1977 said Article 10. This Plan, upon approval by you, will constitute the further drilling and operating obligations of the Unit Operator under the Unit Agreement for the duration of the drilling of the Point Thomson Unit No. 2 well and for six (6) months after comple- tion thereof. W:kll Enclosure Very truly yours, K...' ) I , AS : TAK, ED , . ' ..... /~EXXON No. 2 POINT THOIvlPSON UNIT ,/' I Li T, = TO ID9 47 76 j SCALE: I": IMILE CERTIrt~ATm OF SURVEYOR I hereb) certify i'hat I am properly registered and I censed to practice land surveying in the Slate of Alaska and that this plat represents a location survey made by me or under my supervision, and that all dimensions and other details ore correct. i r.. Date T 9N AS STAKED ,.,L, Lf ~:~, :3'/ EXXON No. 2__ POINT THOMSON UNIT L. occted in SE /~4 PRO'FRACTF'~ c:[(, ~ 1 '~/.i~.k~;'[~b M~ALA.SKA Survsyed ~or EXXON COMPANY U.S.A. ~..;ur v e y u d by F. M LINDSFY ~A A°SOC LAND ~{ HYDROGRAPHIC SURVE-YORS £502West Norlhcrn Lights Boulevard Box n c~uq e A la'~ · PLAN OF OPERATIONS EXXON NO. 2, POINT THOMSON UNIT Location' 2615 NSL and 1801' WEL Section 3, T9N, R22E Umiat Meridian North Slope, Alaska The enclosed plats show all available information regarding' 1 Local and area topography around location. (Exhibit A) 2. Planned winter access roads which are to be constructed. (Exhibit B) 3. Proposed location layout including well position, reserve pit, sanitary waste pits, burning pit, and fuel storage area. (Exhibits C and D) 4. Location of gravel airstrip. (Exhibit C) 5. Location and type of water supply. (Exhibit A) 6. Location of gravel sources. (Exhibit B) There are no existing facilities (roads, camps, etc.) within a three mile radius of the proposed location. Natura. 1 ..Setti n9 The proposed drilling location shown on the attached Exhibit A is situated on a relatively flat area approximately 8000 feet inland from the Beaufort Sea Coastline. The surrounding terrain is low lying coastal plain with 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 24 feet above sea level. The proposed well is in the continuous permafrost zone of Northern Alaska. Depth of permafrost in the area under consideration is approximately 1600 feet. The active surface layer or thaw zone is from one to three feet. 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 preserve the ground cover and protect the surface from unnecessary damage. 'Arctic: climatic conditions include relatively cold temperatures year round. Strong winds, small annual precipitation, and visibility strongly influenced by the combination of winds and coastal sea ice condition are factors contributing to an extremely harsh environment. Temperatures vary from a high in the 40 to 60OF range in the summer to a low of -50 to -60OF in winter which, with the chill factor,, may reach -lO0°F or lower depending on the severity of winds. Surface winds predominate from the east at an average velocity of 12 miles per hour along the coast with a velocity range of 35 to 50 mph associated with winter storms. Total annual precipitation is in the range of 4 to 6 inches which includes 12 to 48 inches of snowfall. Various species of wildlife exist in the area. During the winter months, when the major part of activities are planned, wolves, wolverines, foxes, polar bears, and caribou may be present. Bird life is limited primarily to the raven and ptarmigan, with waterfowl and most other birds having migrated from the area for the winter. There are no roads, airstrips, housing, or other facilities in the area. Surface travel, because of the fragile nature of the surface active zone, can only take place during the winter season while the ground, streams, and lakes are frozen. Prudhoe-Deadhorse, located approximately 45 miles west of the location, is the nearest staging area and airstrip with limited facilities for handling cargo and housing personnel. The nearest supply center with limited machine shop facilities is Fairbanks. The only known use of the area by man is the occasional use by oil and gas exploration people, naturalists, government resource and management personnel, and very occasional visits for hunting, trapping, and recreation Purposes. Construction and Operating Plan A new 78 man camp, recently purchased by Exxon from Frontier Companies, Inc., will be used with Loffland Bros. Rig No. 162 (presently on location at Pt. Thomson No. 1) in the drilling of Pt. Thomson No. 2. The existing Loffland Bros. Camp will continue to be used to house all personnel during the establishment of the new camp and the construction of the site; thereafter it will be removed by ['offland to another location and the new camp will house all personnel. Location work will be started in late November 1977, consistent with State approval, provided freeze-up is sufficient to facilitate movement of heavy equipment to the location using Rolligons. It is planned to move the rubber-tired vehicles over the Rolligon road after a suitable route has been established. The Rolligon route is shown on Exhibit B. The camp at No. 1 Point Thomson Unit drill site will provide housing during the construction of the No. 2 Point Thomson Unit drill site located approximately four miles west of the present location. After completion of the location, the camp and drill rig will be moved in from No. 1 Point Thomson. In order to protect the personnel during the latter move, it may be necessary to utilize a'self-sustaining camp unit. Roll igon has such a unit that has a kitchen, electric toilet unit, and generator system that will sustain eight (8) men and provide shelter for more if necessary on an emergency basis. This can be hauled and set up by one Rolligon. Also it is anticipated that for operation during this period, emergency shelters should be provided along the overland route. The..~s~equence of moving camp and equipment to the area should be as follows: Lay out road route.~with an empty Rolligon at earliest possible time. o ~'Continue camp-site at Exxon No. I Pt. Thomson Unit, per above. o Start construction of ice roads for rig move and gravel haul using ~'..,equipment cu[rently located at Pt. Thomson Unit No. 1. -2- o Move in dozers and other equipment with Rolligons. o Move in new camp with Rolligons. o With two water trucks haul camp water and repair bad spots in,haul roads during construction operations. o With gravel from Pt. 'Thomson Unit No. I construct the pad for the new camp at Pt. Thomson No. 2. Two specific things will be kept in mind when it is desirable to move across the overland route. These are that, in order to protect the tundra, adequate snow cover must be available at the time a move is made, and freezing at the river crossings will be enhanced by removing snow cover and exposing the ice to ambient temperatures. The Pt. Thomson Unit No. 2 location in Exhibit C will be approximately 700' x 700' overall and with a 5' gravel pad will require approximately 37,000 cubic yards of gravel with the airstrip requiring an additional 15,000 cubic yards. The proposed gravel sources-~re listed below in the order of planned usage: o Approximately 20,000 cubic yards of gravel will be salvaged from the Exxon Pt. Thomson Unit No. 1 site. o Remainder from gravel bars in the vicinity of Sections 14, 23, 25 and 26, T9N, R20E above one foot above grade. The gravel removal and hauling will be accomplished using rubber-tired loaders and belly-dumps for direct movement; however, when necessary, the gravel will~' be placed in piles for convenient loading using dozers. Movement will be over ice roads constructed of snow and water to protect the existing land surface. The planned drilling location, as shown on Exhibit C, will accommodate the rig and equipment, camp, and support facilities. The site is to be overlain with sufficient gravel to act as an insulation barrier to prevent thawing of the permafrost during summer operations. Wooden matting will be used under drilling rig and mud pumps for stability and as a further aid in preventing permafrost degradation. All pits are to be diked with gravel. A 200' x 200' 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 before breakup which will permit subsurface disposal of wash and melt water, excess drilling fluid and hydrocarbons. 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 10' deep burning pit will ibe'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 within a 60' x 130' x 6' deep, impermeably lined 'area All-excavated topsoil or tundra from the pits will be stockpiled at an accessible site. adjacent to the location in order that the area may be restored as nearly as possible to the original condition at the time of back-fill and ..~'clean-up operations.. As stated, Loffland Bros Rig No. 162 has been selected for the drilling operation and will be moved from Exxon's No. 1 Point Thomson Unit. Transportation of the -3- rig will be over the ice road. Exxon will move the selected rig to the well site location depicted on Exhibit C as soon as the location is ready, to permit spudding the well on or before the first of February 1978. Actual drilling and evaluation operations will require four to five 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. In this regard, when 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 utilizing the gravel ~.airstrip described above. All support equipment not required for summer operations will be moved out before breakup. .C_amp Facilities It is planned to activate the 65-man camp system at Exxon's No. 1 Point Thomson Unit as early as possible to provide facilities during location construction. .Upon the removal of said camp as noted above Exxon will shift personnel to the new 78 man camp. Sewage and gray water from the kitchen and shower areas 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: I. A sewage disposal unit will be installed as outlined in our letter of Dec. 19, 1977, to the Department of Environmental Conservat~ion, a copy of which was placed in your file LO/NS 77-144. 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 discharge in the event of a treating plant upset. e Potable water for the camp facilities will be hauled from small lakes near the rig and a large, eight-foot deep lake approximately seven miles south- east of the location. 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 as outlined in said letter of Dec. 19, 1977, to the Department of Environmental Conservation. Burnable garbage and trash will be incinerated through a separate Incineration Unit. e Products such as paper, wood, and cardboard will be open burned. Cans, glass, and other items will be compacted and bagged by means of a standard kitchen type compactor and will be stored and buried in the bottom of the burning pit area prior to the time of backfill. . Scrap metal, ti res, drums, batteries, and other non-burnable items will be hauled to Prudhoe Bay area for further disposition. -4- Development Plans If oil is discovered in sufficient quantities to warrant future development, the Prudhoe Bay to Valdez oil pipeline will be the probable marketing outlet from the area. 0il and casinghead gas would be processed through central oil gathering facilities with oil being pipelined to the Trans-Alaska line passing approximately 46 miles to the west. If commercial 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, by use of existing roads and winter trails where possible, and.by construction of a graveled well site, storage location, pits, and dikes. At the completion of the well, the location and adjoining area will be cleared of all waste materials. All 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 construction of surface facilities, procedures for drilling, and subsurface equipment are needed to allow for the unique characteristics of the permafrost area. On the surface, the gravel pad and wooden mats are placed under the drilling equipment to reduce heat loss, melting, and settling. For future permanent construction, sufficient gravel or other insulation must be used to prevent thawing'and damage to the tundra and facilities during elevated summer temperature. 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. GLA:jh ' 12/27/77 -5- CONTINGENCY PLAN EXXON NO. 2,,POINT THOMSON UNIT The objective of this plan is to list major operating and contingency requirements to ensure a safe and efficient operation throughout the drilling activity. Equipment and material stockpile.requirements for operating after breakup are tabulated for operational planning. The location has been designed to provide containment of any drilling operation effluents that could be considered as pollutants. The 200' x 200' 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 from the camp will be processed through an activated sludge extended aeration system with the solids being inci'nerated and the disinfected liquid contained in a sanitary waste pit; a separate sanitary holding pit is provided to divert the treating plant effleunt 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 impermeably lined fuel storage area. A primary feature of the drilling plan is to provide 9-5/8" x 13-3/8" annular injection capability before breakup. 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 antitipated pressure transition zone and cemented to isolate the salt water sand sections from below the surface casing shoe to approximately 6000 feet for injection of excess mud, melt, waste waters collected in the pits and hydrocarbons. 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, Loffland Bros., will be required to develop a compre- hensive SPCC plan to prevent pollution as a result of any drilling rig operations. 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 Qf oil will be collected using absorbent material for disposal in the burning pit. ?ersonn~l safety and well control are the uppermost factors in well design and operational"~lanning. 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 resulting in uncontrolled well flow, the followi.ng 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 71,000 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 before spring breakup. After breakup light consumables will be transported by helicopter. A Rolligon will be on l ocati'on for any local movement of water or fuel as permitted by land conditions. Equipment and material stockpile requirements are tabulated below: Equipment Requirements- (Normal Operations) l.. Aircraft - A DHC 6 series 300 Twin Otter will be used to transport personnel, material, and supplies up to a maximum 4,000 pound pa. yload. 2. On-Site Support Equipment I - Rolligon with detachable fuel and water tanks 2 - 966 Front Loaders I - Combination Flat Bed Truck with winch I - Bull Dozer Material Stockpiles 1. Mud Supplies a. Barite - 20,000 sks. b. Bentonite - 3,000 sks. c. Lignosulfonate - 500 sks. d. Lignite - 500 sks. 'Lost Circulation Material - 500 sks. f. Casing Pack Material - Minimum requirements for 150 bbl. mixture. 2. Cement - minimum~of 3,000 sks. of Class G. 3. Casing and Tubing 1'4,000' 7", 32/35#, P-110, BT Casing 3'500' - 4-1/2", 15.1#, C-95, LTC Casing 14,000' - 2-7/8", 8.7#, N-80, Hydril PG-6 Tubing 3,500' - 2-3/8", 5.95#, N-80, Hydril PG-6 Tubing -2- 4. Drill Pipe and Drill Collars 14,000' - 5" 19 5# Grade E&G 14,000" - 3-1/2", 13.30#, Grade E drill pipe 900'-4-1/8" drill collar.s 5. 7-1/16", lO~O~O psi WP BOP Stack and choke manifold lO,O00 psi WP christmas tree and wellhead equipment 6. Fuel - Minimum 200,000 gals. in steel tanks GLA:jh 12/27/77 -3- FOrm No. P---4 I~'V, 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMAAITTEE MONTHLY RE!PORT OF DRILLING AND WORKOVER OPERATIONS § API NUiVIER1CAL CODE 50-089-20006 SUBMFr IN DLrPLICATE LEASE DESiGI',IATION AND SE]RIAL NO. ADL 47567 1. 7 IFINDIANT.AL,O'TT'£E O]~ TRIBE N~ME OIL ~ GA8 w,LL w,,.,. ~ o,,~ Wi 1 dcat :. 8. L~IT ~A~ OR LEASE Point Thomson Un~t~ 9 WELL NO ~ Exxon No. 2 i 10 FIF. J.,O A_'qD POOl.,Ott%VI'I.DCA4 Wildcat ~ Il S~C. T.. R. M (BOSOM HO~ Sec. 3, T9N, R22E ~. 12 P~IT ~0 77-64 2, NAME OF OPtlRATOR Exxon Cor. poration 3. ADDRESS OF OPEP,,ATOR Pouch 6601., Anchoraqe, Alaska 99502 4 LOCATION OF WELL 261 5' NSL & 1801' WEL of Sec. 3, T9N, R22E, UPM, North Slope, AlaSka 13. REPORT TOTAL DEPTH AT END OF MONTH. CHA_NGF~S IN HOLE SIZE, CASING AD C~'MF~NTING JOBS INCLUDING DEPTIt SET ~ VOL~S USED. P~OHATIONS, ~TS ~ RESULTS FISHING JO~ JI~K ~ HOLE AND SIDE-~ACKED HOLE AND ~Y OT~R SIGNIFIC~T ~G~5 ~ HO~ ~N~ITIONS On 4-3-78 drilled out of 9-5/8 inch casing with an 8-1/2 inch bit. At a drill depth of 10,112 feet a pressure integrity test was performed. Leak off occurred at 17.3 ppg EMW. After drilling to 10,522 feet another pressure integrity test was performed with leak off occurring at 16.5 ppg EMW. Intervals cored during the month are as follows: Core #2 - 10,152 to 10,212 feet Core #3 - 11,595 to 11,655 feet Core #4 - 11,678 to 11,697 feet Core #5 - 11,697 to 11,757 feet Core #6 - 11,757 to 11,847 feet Mud weights were increased from 12.1 to 15.0 ppg during the month. Injection capability down the 9-5/8 inch casing annulus was lost on 4-19-78. So after cutting core #6, a 70 sack cement plug was placed from 9849 to 10,056 feet, a cement retainer was set at 9652 feet and operations to establish subsurface in- jection capability, per Sundry Notice dated 4-28-78, was started on 4-28-78. Results from a cement bond log and a free point survey indicate the pipe is stuck at 3256 feet and 3246 feet respectively. After failing to clear the bridge by working the pipe up and down with a spear, the mud weight was cut from 15.0 to 12.0 ppg and preparations are being made to unseat the 9-5/8 inch casing slips. CONFIDENTIAL s~m:~~//~~°d L. Boanem~= Exploral;io~_Depar_t. ment_,.~ May 5, 1978 NOTE--ReOor! om Ibis form is req.ireg for eoc~ colend.r ~mt~ regordless of [~; sto?.s of ooerotioms, crag re.s! ~e fiisg ia duplicole with th e oil ~nd gos conservation ¢ommiffee by,he 15th of lhe su¢c~ding mo~, unlss~ otherwise ~irmcied, COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION R. L. BOANE Ap DISTRICT MANAGER r 1.1 28, 1978 Alaska Department of Natural Resources Division of 0il and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Attn: Mr. Lonnie Smith Dear Mr. Smith' Enclosed are three copies of form 10-403, "Sundry Notices and Reports on Wells" being submitted for Exxon Point Thomson Unit No. 2. Very.17 truly yours, If -C/,/ :/ :' / L..~/,2: ,¢:...._.,,." ..z¢.z~ ~-c_.? ....... Rod L. Boane RLB' et at t achment s A DIVISION OF EXXON CORPORATION Subml t "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate Form 10-403 REV. 1-10-73 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this forrp for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL i i OTHER 2. NAME OF OPERATOR Exxon Corporation 3. ADDRESS OF OPERATOR P.O. Box 2180 Houston, Texas 77001 4. LOCATION OF WELL At surface 2615' NSL & 1801' WEL of Sec. 3, R22E, UPM, North Slope, Alaska T9N, 13. ELEVATIONS (Show whether DF, RT, GR, etc.) Approximately 24' GL 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-089-20006 6. LEASE DESIGNATION AND SERIAL NO. ADL 47567 ' 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Point Thomson Unit 9. WELL NO. Exxon No. 2 10i FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 3, T9N, R22E 12. PERMIT NO. 77-64 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT 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 ~ate all pertinent details, and give pertinent dates, including estimated date of ~arting any proposed work. Subsurface Injection: To establish subsurface injection capability down the 9-5/8" casing annulus it is proposed to perforate the 13-3/8" casing over -for~ty feet of selected intervals between 2800' - 3200' MD. Prior to perforating, the 9-5/8" casing will be backed off at 3200' +/-. A cement plug (10056' - 9856') and retainer at 9652' has been previously set to insure well control safety is maintained during this operation. The 9-5/8" casing string will be reconnected and disposal of miscellan- eous fluids will be achieved to,the perforated intervals above 3200' subsequent to this perforation work. 16. I hereby certify,~t the foregoJ~;g Is true and correct (This space for State o e u.~) CONDITIONS OF APPROVAL IF 'ANY: TITLE TITLE See Instructions On Reverse Side The Desk Of: ]II~¢l,,,,f ¢.' T. $ .. tT" DEPARTME~T ~F NATUt~AL I Division of Oil and Gas Conservation O. K. Gilbreth, Director Point Thomson Unit ~2. We have been told ~hat again this year the ADL has refused to permit Exxon to build an airstril) near the subjectt location and has required helicopter support if the rig is to operate after break-up. As a censer-ration agency, we think this is a vow dangerou~ practice an¢t one that should nOt be condoned. I%~e ~ecommend to you very stronqly that you consider this matter in the light of %he risk and the benefits of an airstrip, as compared .~o the .small ~mount of enviror~nental damage resulting from an airstrip. You will recall that when the ARCO NGI %7 ~.gent out of control at prudhoe Bay in 1976, in the first 24 hours tJ~e operator set-up an operation center; a communiCatibn center and netv:ork; started hau!- ~ ~ , location for ing in pipe for %-ater lines and T.~ud lines; .~uar~ed a a relief well; moved in dry bucket unit and dri!le(~ conductor hole for a relief well; started marshalling trucks and bulldozers; set-up gas sniffers; hauled in explosion proof lights; set-up Power generating equipment out of the zone of danger; ordered out fire fighters and %~ell control men; started hauling mu¢l~ brought in additional pumping facilities; started building a ~¢ooden chill box; started flying in dry ice from Anchorage to freeze fluid in the drill pipe; brought in a complete new blowout preven- ter assenf~ly and had practice exercises ~¢ith their crew in replacing rams to have-specially trained cre~.;s to operate under the rig floor; and within-10-1/2 hours they %.;ere pumping in water from a remote location in an attempt to kill t_he well. Concerted efforts will be made to prevent a well blowout at the Pt. Thomson' Unit ~!2 location but it must be recalled, that nearly all blowouts 'are caused by people. ~.~here people are employed, it is impossible for the operator to keep a continuous survcil- lance eye on everyone at all times. If a %zell at this location should go out of control it would take fro.~n 4 to 7 days just to construct.-the emergency strips to start marshalling men and. cquip- ,/ment. In our opinion, the. very shortest time a ~'cll could be ~.rom one to two %.zceks If this brought under c~ntrol would be = · ,; should happen, ;ce kno%¢ and you kno~.~ that the preservationist ~Will shut t~he industry do~n% 0~n~.._t_h_e ?o__r~)..~lo_J2D. Thus we find a ',~htCh--9.-'9_m--s-~'~£Bn----~,~-~e~.~oping for outlying exploratoz~ wells. If-a blowout should occur at the Pt. Thomson Unit ~2 a lot of time-will be required to construct an airstrip and road before anything can happen on location. Of course 'there will. be no opportunity to rapidly mobilize like that mentioned above on NGI. #7. We want you to be aware of this situation. Form No. ]=--4 STATE Or- ALASKA susMrr ~ DU~,L, CA~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT O'F DRILLING AND WORKOVER OPERATIONS 1. WELL W~.LL OTHER NAME OF OPERATOR Exxon Corporation AP1 NUMERICAL CODE Wildcat Pouch 6601, Anchorage, Alaska 99502 4 LOCATION OF WELL 2615' NSL & 1801' WEL of Sec. 3, T9N, R22E, UPM, North~Slope, Alaska 8 'L.~IT FAP,~I OR LEASE Point Thomson Unit g W~LL NO Exxon No. 2 10 FIELD AND POOL. OH WI'LDC,~' Wildcat 11 SEC, T., R. M (BO'I~OM HOL] OB.mC-rivE) Sec. 3, T9N, R22E 12 PF~CLMIT NO 77-64 13. RE~ORT TOTAL DEPTH AT END OF MONTH. CHA~NGF-~ IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET ~ VOL~ USED. p~O~TIONS. ~TS ~ ~SULTS FISHING JO~ JI~{K LN HOLE AND SIDE-~.AC'KED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ CO~ITIONS A 12-1/4 inch hole was drilled to a total depth of lO,lO2 feet and the following open hole surveys were run' Dual Induction Formation Density - Compensated Neutron BHC Sonic Long Spaced Sonic Repeat Formation Tester Dipmeter In addition, 125 sidewall core were attempted with 98 being recovered. Set 9-5/8 inch csg at 10,099 feet and cemented with 1430 sx class G cement (15.9 ppg), displaced with 750 bbls 12.2 ppg mud. Dl~ notbum~p_.p~_~qg an~.di~..no~_]la.~_e_.r~£n~ while cementing. A temperature survey indicated ~h6'-~{~p of cement at '6860 fee'S. Pumped water down the 13-3/8 inch x 9-5/8 inch casing annulus to establish injectivity into the open hole interval between the 13-3/8 inch csg shoe and the top of cement behind the 9-5/8 inch csg. Maximum injection rate was~.~._~P. M at 1190 psi. During the month mud weights were increased from 9.9 to 12.1 'ppg and core #1 from 9855 feet to 9885 feet recovered 28-1/2 feet. At the end of the month preparations were being made to nipple down the BOP stack and cut off 9-5/8 inch csg. CONFIDENTIAL s~ 2'~-'/~/L'-~°*t~/","" .... _ L. Boane :T~ Exploration Department .,~, ~ 4/17/78 NOTE--Report on this form is required for each calendar month~ regardless of the etatus of operatioms, and must bo filed in duplicate with the oil and gas conservation committee bythe 15th of the succeeding month, u~le~ ofherwiea directed. DEPARTS~NT OF NATURAL RESOURCES Division of Oil and Gas Conse~-~ation Robert E. LeResche Commi s s loner April 11, 1978 Oo K. Gilbreth, Jr.~j Director Point Thomson Unit #2. We have been told that again this year the ADL has refused to permit Exxon to build an airstrip near the subjectt location and has required helicopter support if ~_he riq is to operate after break-up. As a conservation agency, we think this is a very dangerous practice and one that should not be condoned. We recommend to you very strongly that you consider this matter in the light of the risk and the benefits of an airstrip, as compared to the small amount of environmental damage resulting from an airstrip. You will recall that when the ARCO NGI #7 went out of control at Prudhoe Bay in 1976, in the first 24 hours the operator set-up an operation center; a communication center and network; started haul- ing in pipe for water lines and mud lines; started a location for a relief well; moved in dry bucket unit and drilled conductor hole for a relief well; started marshalling trucks and bulldozers; set-up gas sniffers; hauled in explosion proof lights; set-up power generating equipment out of the zone of danger; ordered out fire fighters and well control men; starte~ hauling mud; brought in additional pumping facilities; started building a wooden chill box; started flying in dry ice from Anchorage to freeze fluid in the drill pipe; brought in a complete new blowout preven- ter assembly and had practice exercises with their crew in replacing rams to have specially trained crews to operate under the rig floor; and within 10-1/2 hours they were pumping in water from a remote location in an attempt to kill ~he well. Concerted efforts will be made to prevent a well blowout at the Pt~ Thomson Unit ~2 location but it must be recalled that nearly all blowouts are caused by people. Where people are employed, it is impossible for the operator to keep a continuous surveil- lance eye on everyone at all times. If a well at this location should go out of control it would take from 4 to 7 days just to construct the emergency strips to start marshalling men and. equip- ment. In our opinion, ~he very shortest time a well could be brought under control would be from one to two weeks. If this should happen, we know and you know, that the preservationist ~ill shut the industry do~rn on the North Slope. Thus we find a "catch 22" situation developin~ for outlying exploratory wells. If a blowout should occur at the Pt. Thomson Unit #2 a lot of time will be required to construct an airstrip and road before anything can happen on location. Of course there will be no opportunity to rapidly mobilize like that mentioned above on NGI 97. We want you to be~aware of this situation. E ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION R L, BOANE DISTRICT MANAGER March 22, 1978 Alaska Department of Natural Resources Division of Oil and Gas Conservation 3001 Porcupine Drive ?:-~i~-. , Anchorage, Alaska 99504 i Attn: Mr. Hoyle H. Hamilton Gentlemen: Approximately three gallons of diesel oil were spilled at 4:00 A.M. AST on March 5, 1978 at Exxon's Pt. Thomson No. 2 location. The incident occurred while diesel fuel was being transferred from the storage tank to the generator day tank. This letter confirms Mr. J. F. Homer's telephone notification of this occurrence To Mr. O. K. Gilbreath of your office on March 7, 1978 at 2:50 P.M. AST. The pertinent facts of this incident are summarized below. 1 Date and time of discharge - March 5, 1978 at 4:00 A.M. AST. · Location of the discharge - Latitude 70o09' 47.46"N, Longitude 146030' 55 48"W · , or on the Exxon No. 2 Pt. Thomson Unit well site location. e Person or persons causing or responsible for the discharge - Loffland Drilling Company personnel were transferring fuel to the generator day tank. · Type(s) and amount(s) of hazardous substance(s) discharged - Arctic grade diesel oil, approximately three gallons. · Cause of discharge - Overflow of the camp generator diesel day tank. · Environmental damage caused by the discharge to the extent ascertainable - No environmental damage is detectable as a result of this spill since all of the spilled fluids have been recovered. · Cleaning actions undertaken - Ail spilled fluid was recovered by removal of fifteen gallons of contaminated gravel from the floor of the generator room· A DIVISION OF EXXON CORPORATION Page Two March 22, 1978 · Location and method of ultimate disposal of the hazardous substance and contaminated clean-up materials, including the date of disposal - The contaminated gravel has been placed in containers in the rig site burn pit for future disposal via burning pending approval by the DEC. · Actions taken to prevent recurrence of the discharge - A procedure has been established that requires full time surveillance at the day tank during fuel transfer operations. Installation of automated tank level controls is planned to further prevent future overfilling. If you require additional information, please contact Mr. J. F. Homer of the Exxon Anchorage office at 907/276-4552. Very truly yours, R. L. Boane JFH:sr Bcc: B. Elkin W. R. Fuge J.F. Homer H. C. Martens R. K. Riddle W. M. Taylor F~rm No. P---4 1R~'V. $- I-?0 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS O,L,,L,~ []] °"w,,,.L []] oT,,, Wildcat 2. NAME OF Exxon Corporatio~ 3, ADDRESS OF OP~TOR Pouch §60], Anchorage. Alaska 4.LOCATION OF WEL~ 2615' NSL & 1801' WEL of Sec. UPM, North Slope, Alaska gq50? 3, T9N, R22E, ~ API NUAiERICAL CODE 50-089-20006 stoicAL ~o ', 6 LEu~SEADLDESIGNA'I'ION47567 A×D ~ IF INDIA~T. Ai,OTIE£ OR TRIBE NAME 8. L~,'IT F.~q~l OR LEASE N~E~ Point Thomson Un t ~, 9 WE~ NO ~ Exxon No. 2 i 10 FI~ ~ND P~L, OR WILDCAT Wildcat ~ ~ Sec. 3, T9N, R22E PERMIT NO 77-64 13. REPORT TOTAL DEPTH AT END OF MONTH. CI-LA. NGES IN HOLE SIZE, CASING A1NrDCE!VIENTING JOBS INCLUDING DEPTH SET A3CD VOLU1VIE~ USED, PER/~OllATIONSi TESTS A/xED IR.E.c. ULTS FISHING JOB~. JUNK L~T HoLE AlxID SIDE-T1R.ACKED HOLE A.ND A~TY OTI-EER SIGNIFICANT CILM~GES IN HOL~ CONDITIONS. Spudded 8:00 P.M. 2-4-78 w/17½" bit. Drilled to 855', ran dual induction and BHC sonic logs and opened hole from 17½" to 24" to 855'. Set 18 5/8" csg at 840' and cemented wi th 2500 sx permafrost (14.6 ppg) and 2200 sx permafrost (15.6 ppg). Cement returns to surface weighed 14+ ppg. Drilled a 17½" hole to 3310' and ran the following open hole surveys: Dual Induction BHC Sonic Long Spaced Sonic Borehole Geometry In addition, 102 sidewall cores were attempted with 99 being recovered. Set 13 3/8" csg at 3296' and cemented with 1500 sx permafrost (14.6 ppg) and 5300 sx permafrost (15.0 ppg) with full returns. A pressure integrity test was performed below the 13 3/8" casing shoe at a drill depth of 3317'. Leak off occurred at 15.0 ppg equivalent mud weight. At the end of the month the well was drilling at 5360' with a 12¼" bit and lO.O ppg mud. s~s~ Rod L. Boane:t= Exploration Department ~,~ 3/17/78 . NOTE--Report on this form il required for each calendar ~nth~ regardless of the status of operations, and must ~ filed In duplicate with the oil and gas conservation commiffee by the 15~ of the succ~ding mon~. ~le~ otherwise directed. CONFIDENTIAL E ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 PRODUCTION DEPARTMENT ALASKA OPERATIONS J. F. HOMER DRILLING MANAGER March 7, 1978 Mr. Hoyle H. Hamilton State of Alaska Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Hamilton: In response to our previous conversation and to follow-up the Department of Oil and Gas field inspection report, we wish to inform you that the following action has been taken to bring the blow-out prevention and well control equipment on the Loffland 162 rig, currently drilling at our Point Thomson #2 location, up to State and industry standards. · The existing 5000 psi WP choke manifold has been modified as shown in the attached sketch. Three 5000 psi WP valves were added to the manifold, one to each wing of the main cross to give addi- tional redundancy to the manifold in the event of valve leakage occurring. This revised design meets with API RP 53 recommendations for service over 3000 psi WP. The manifold was tested on March 5, 1978 to 300 and 5000 psi with no leakage noted. · A remote control panel capable of functioning all BOPs and hydraulic gate valves (HCR valves) has been added to the existing BOPE control system and was function tested to insure correct operation · A DIVISION OF EXXON CORPORATION The required nitrogen back-up system for operation of the BOPE system in an emergency consisting of 4-300 cu. ft bottles with ancillary controls has been added to our existing system as per State requirement· With our already redundant fluid supply system, we feel this addition will insure correct BOP operation should the need arise. Anohorag~ Mr. H. Hamilton March 7, 1978 Page 2 · The kelly, kelly cock and lower kelly valves used on the Loffland 162 rig were tested to 200 and 5000 psi prior to drilling out of the 13-3/8" casing shoe with no leakage evident. It is the objective of Exxon Company, U.S.A.'s drilling efforts to take all necessary measures to insure that maximum well control is maintained on all locations. We trust that our efforts meet with your approval. J. F. Homer DRA:jrh Attachment 240-500-200 cc: G. L. Argall J. W. Jackson LOFFLAND I~02. CltOKF_ I"I,~iFOLO --HAND AELT U$'1'. CHOKE OCT LO TOi~C VALVE ON ~" TEE. 2.. LO TORC VALVF-~ 4' LlklE LO TORC VALVE~ BULL PLU~, 'rvp ~ LoG. 7" t 5~,/ACO CI-IOKE E~P~~ OF ~mAL RESOUNCES Division of Oil and Gas Cc~servati(~n Well file, #2 March 6, 1978 Hoyle H. Hamilton . Val~w~s Required in ~nifo~ I ~i~ed a ~ @ 9:30 AM, ~ 6, 1978 f/Tan John J~, Exxon, who repoxted that the 3 ~~ valves ~hat ~ required, in their manifold O: K. ~, Jr. Feb~_~ry 27, 1978 chief petroleum m~~" ~~ R. ~ ,,~'~/ Wi~ ~ ~t,~t~~. O~2 ~Y P~t ~. 7~64 Monday~._ ~2O, 1978- I left Anchorage by Wien air at 10:00 AM for PrudhOe Bay. I met Pete Jc~c~, expedi~ for Exxon. He took me to Era flight service where Exxc~ '_bx~d___ c~_~~ a twin otter. I left Prudhoe Bay by twin otter at 1:00 PM and arrived at Point T~scn No. 2 at 1:20 PM.. Purpose of trip to witness BOP test. I met Buck Erwin, operator for ~. Cementing w~s just finished. The cement stinger was out of hole at 5: 30 PM. Oellar was filled with mud and had to be cleaned out before nippl/n~, up BOP's could start. was a brand new koc~ey and had %o be hooked up with new c~ntrol lines. Also a new Swaco superchoke and hydr~lic lines had to be installed. ~_~sd~_.y, February_ ~2, 1978 - 6:00 AM. Nippling up BOP's still in progress, ~0 niPPling ~ manifold. Thursday,..F~ 23, 1978 , Nippl/ng up BOP's and repairing the accumulator cc~trol ~s tha~ broke When uressured up c~. 10:00 PM. Started BOP %ests, a~tor I/ne broke again. Friday~.F~..24, 1978 - Test p~ ~ould not work. BOP tests beld up ~12:00 ~4 to '12:00'PM, Hal/burtc~ w~s called out to job to do the pres~~g up. The sta~k was pre~ to 7500 psi, but t~ door rings gates had to be replaced before tests held. The manifold ~s tested to 5000 psi and all valves held OK. The manifold was welded over in two places that leaked before tests c~ manifold ~re ~~ed. There was a superchoke, a man~ operated choke and 7 valves and 13 flange, s that were tested cn manifold° The upper pipe rams and lower pipe rams were tested to 5000 psi. The inside and outside kill val%~s and choke valves and check valve were also tested to 5000 psi and held OK. The annular preven~ was also tested to 5000 psi and held OK. There was a ball valve and dart valve c~ floor OK. The upper and lc~_r kelly ~Duld not test. I requested that the a~t~r and all c~mponents be tested. The accumulator was brand new with 3000 psi c~ master gau~.e and 1500 psi c~ manifold. I pipe rams, and the I~R valve on choke line .~in 17 ~nds with all pumps shut off. There was 1450 psi left on master gauge. I also ob~ the annular Pt. ~%cmpson ~t No. 2 2- February 27, 1978 the ~ and ~r kelly. ~ locatic~ was in very good shape, free 's of debri o The mud pit was ~ Bat ~11 ~. The w~ll sign was up with all ~ OK. ~e 13 3/8 casing was set at 3296'. ~: I observed the test/rig of BOP's and ~ts at Point Unit No. 2. ~ t.~c/ng was fiD3_shed, BOP's ~ were satisfactoz~, except f~r th~ 4 items m~ntic~ed in my report. Attadm~nt 2/27/78 Buck Irwin, operator f~r Ex~0n, called and told ms all cc~pcmen~ ~ fi~ed and ~ested per my /nstruct/eDs. Nitrogen backup bottles were connected with 2250 psi on 4 bottles. The r~mo~ controls ,~_~e ~ and operate BOP cc~trols OK, the upper and lower kelly ~_-~e ~'~nn~ out and %~re tested to 5000 psi. Ala j Oil and Gas Conservation Commit , Field Inspection Report _..rlg. Permit No.~_~~ Well/Platfm Secj~__TJ2~/ _R~,~_ .)perator~'X ~'~' ~ Represented Dy~F~w~ Name & Number~~ Satisfactory Type Inspection . SatisFactory Type Inspection Yes No Item ~) Location,General Yes No Item (~ BOPE Tests ( ) 1 Well Sign ~) ( ) 15. ~asing set ' 16 les~f'luid-(~wt~ )mud ( ) oil ~~ ( ) 2. General Housekeeping (~ ( ) ( ) 3. Reserve Pit-~)open( )filled (~ ( ) 17. Master Hyd. Control Sys.-~opsig ~ ( ) 4. Rig ()~~ 18' N~ btls' -- ' '-- ' -- "-- psi~ ( ) Safety Valve Tests ( ) 19 R~mote Co~rols 20. Drilling spool- ~/~ "outlets ) ( ) 5. Surface-No. Wells ~ ) ( ) 6. Subsurface-No. Wells ) ( ) 21. Kill Line-(X) Check valve ( ) Well Test Data- (~) ( ) 22. Choke Flowline (~) HCR valve ( ) ( ) 7. W611 Nos. , , (X) ( ) 23. Choke Manifold No. valvs~flQsJ~ ( ) ( ) 8. Hrs. obser -,..--, ' ~ ( ) 24. Chokes-(~)Remote(X)Pos.~)A~.il ( ) ( ) 9. BS&W , ,~, ' ( ) 25. Test Plug-~)Hellhd( )cs~( )none ( ) ( ) lO. Gr. Bbls. , , ~ (~ ( ) 26. Annular Preventer~d~s~g () Final Abandonment ~ (~) ( ) 27. Blind Rams~~sig ( ) ( ) 11. P&A Marker (~ ( ) 28. Pipe Rams~¢~O psig ( ) ( ) 12. Water well-( )capped( )p~ugQed ( (~) 29. Kelly & Keliy-c~ck ' psig ( ) ( ) 13. Clean-up ~ ( ) (~') 30. Lower Kelly valve psig ( ) ( ) 14. Pad leveled ~) _( ) 31 Safety Floor valve~BV ~')Dart Total inspection observation time ~ ~/days Total number ~eaks and/or equip, fallures~ Remarks ~~F~ ~ ~(S) ~m~ ~ ~A~[ ~~~ ~C'~'~,~~~ N~ti~ ~n ~days or when r~ady ~z= Inspected by~~J~_ }~ 'Crandall D. Jones, Manager Exxon Company, U.S.A. Pouch 6001 ;~mhorage, Alaska 99502 February 15, 1978 Dear Mr. Jones: The Department of Environmental Conservation has completed its evaluation of your Waste Disposal Permit application for the discharge of treated liquid waste to the lands or waters of the State from wastewater treat- ment 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) ~/~iv. of Oil and Gas O.K. Gilbreth NRO, Doug Lowry (w/encls) STATE OF DEPARTmeNT OF E~NVIRONMENTAL CONSERVATION POUCH 0 JUNEAU, AI/tSKA 99811 WASTE DISPOSAL PERMIT No. !'~C 78- 2 Date Febm~r¥ 15, 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 treannent facility serving an exploratorY drilling operation. The operation, identified as ~Exxon No. 2, Point ~Th?~_~son Unit, is located at SE 1/4, Section 3, Towns~hip 9N, Range 22E Umiat Meridian, A.D.L. 47567, North SloPe, Alaska.' This permit is issued under provisions of Alaska Statutes AS 46.02.100-110, Water, Air and Fmvironmental Conservation, the Alaska Administrative Code as anmnded or revised, and other applicable State laws and regulations. This permit is effective upon issuance and expires Feburary !, 1983. It may be terminated or modified in accor&m7ce with AS 46.03. 120 Pa~e 2 of 8 le~.r,',~.. No WPC 78-2 A EFFLUENT lo . During the period beginning on the effective date of permit and lasting ~h.rough the expiration date or fermi.nation date', the permiutea is authorized ~o discharge treated Nastewater effluent as specified -in this section. The treated liquid waste discharge shall not exceed the following limitations' E f f In ten t Thirty- day 't~!a xim Lun Ch ar ac teri s tic Average _Va_.].:) ~ ..... Total Biochemical Oxygen Demand (BODi) Suspended Solids (SS) Fecal Coliform Bacteria' 30 mg/1 30 rog/1 200/100 mt 7000 gpd 60 rog/1 60 mB/.1 400/] O0 ml .3. The total chlorine residual in the effluent aft-er at 30 minutes contact time shall not be more th_an 2 rog/1 at any time. . 5~ The dissOlved oxygen in the effluent shall not be less than 2 rog/1. The pH 'of the effluent shall be betwen 6.0 and 9.0 pH units or-within 0.5 unit of the pH o:f the raw water supply. . There shall be no discharge of floating solids or foam in · other than trace amounts or oily wastes which produce a sheen on the surface of the receiving waters. . Sludge from the wastewater treatment facility shall not be discharged to the waters of the state. The method of dispo:;al of sludge shall be by incineration unless an alternative disposal method is approved in writing by the dapart~-'~:,,unt. . No untreated domestic wastewater shall be discharged to the lands or waters of the state unless otherwise approved. B.'NJ' -)";~-ITORIIsG' '~ AND REPORTING lo Monitoring. of Effluent The permittee shall monitor the wastewater.stream in the manner and frequency while discharge is occur'ring. $ [-.t',a,_'mt Se.g.~man[ E f £ tuen t Char ac t er i s t'[ c Biochemical Oxygen Demand (5-Day) Total Flow Suspended Solids Page 3 of 8 mon t:h ]y daily mo n t:h ].y c:c~m[)',~:_:;-i, t e o£ ].east: 4 grabs du,-'i,,~ _t. 2 hou~ p e ~: :i. od composite of le-;;.s~: 4 grabs duri_ng 11.2 hou7 pH d ct 'f_ '1_y g r' ab Total Ch lorine da'[.ty g~al) Residual Dissolved Oxygen we. ekly gr~d, Fecal Coliform mon[ttl.y grab . . Representa rive Sam21ia~ Samples and measurements taken as required herein sha].l be representative of the volume and nature of the; monitored discharge. The permittee shall submLt a brief description of compositing methods including, t~ut not lim-Lted to, loc. atio:~ of sampling and measurement points. Additional Monitorin% If the permitee monitors any inf_l, uent or effl.ue~.t charact:eristic identified in this permit more frequently tt,.an require, d, t't~e results of such monitoring shall be reported to thc ])epa'~"tment: in the month].y monitoring report required under pa~:agraph of this permit. Reporting Monitoring results obtained during the previot,.s ~:,o~t,~ shall summarized and reported to the I)apartmen'/ and postmarked no later than the 14th day of the month followi~g tl',e completed reporting period. Monitoring shall begin at the conuuancemeut of discharge. Signed copies of th~'~'~'_.,--, and all ot:l~er reports required herein, shall be submitted to the Departmc~nt at the following address' Alaska Department of Envii_rona':~nt'.al Conser va [:ion P.O. Bo>: 1601 Fairbanks, Alaska 99707 phone' (907) 4.52-t 71.4 . · . . Knowingly makin~ at false sta~cmc~nt, by t:t~e pctrmitt~c, t'hc~ operaaor o'c other employees, :inc].ud:[~ co~ttractto~'~;, on any such report may result in the iml~osit.i, on of c-rim[hal, l~analti, em as provided for under AS 46.03.790. Test Procedures Test procedures for the analysis of poI.[utants st~all conform to methods cited in 18 AAC 70 020(c), or as be amended. The permittee may substitute alterm'~t:[ve method:; monitoring or analysis upon rece. ipt of prior: wr:[tten approval from the Department. Records Retention Ail records and information resulting fro:i~ the activities required by this permit, J~?.'.~cluding all ~c. coF. ds of analyses performed and ca] :[b ca ti on and maintcaanc,.'~ instrumentation, shall be retained ia Alaska 'loc ¢,bservat_ioa. by the Department for three years. Upon reque.~t from t-i~e Department, the permittee shall s,.:'bmit cerEif:ied coi,:i.c~.; of such records. Co AD>fIN I STtLtf£ IVE REQU IRE~4ENT S . Change in Dischar.~_e_ All discharges authorized herein shall be consist:ant with the terms and conditions of this permit. The discharge of any pollutant identified in this permit,-or tox_[c mater:[al~ including oil~ grease, or solvents, more frequently il,an or at a concentration or limit not authorized shall cong;t:.itute noncompliance with the peak. it. Any anticipated fac:[ ].i [~y expansion, production increase~ or process modification which will result in new, different, or increased d_Lscharge of pollutants must be reported by submiss:ion of a new waste disposal permit application, or if such chan~;¢.~s will_ not affect the ability of the permittee to comply with the e.f'flueat limitations specified in this permit, by written nc>ti_ce to ec~.~_Lcd in pa.cag'l:aph 1',.6. the Department at the address sp _-r.. .~ at least 30 days prior to the implementation of such cl~mges. 2. Toxic Pollutants If a toxic pollutant, including o:[1, grease, ,. concentrat:ion standard is established in accorda~ma 18 ~1C 70 for a pollutaut present in tills d~[~.:chargt~, such standard is more stringent than the 15mit:ati.o~ permit, this permit may be modified 5.n accordance with the toxic pollutant concent:ration standard. 3. Accidental Discharges The permittee shall provide protection from acc:[dental discharges not in cOmpliance with the provisions of tt~is permit. Facilities to prevent such discharges st~:~].l be maintained in good working conditions at al]~ t-h~.as by the 'permittee. 4. Noncompliance Notification b. If for any-reason the permittee does not: comp].y with or will be unable to 'comply with any eff]_ue~t limitations ,_p=cified in this permit, the permittee sl~al] report the noncompliance to the Departu~a'~.t within 24 hottss of becoming aware of such condition by te]_ep~,.or~.e> telegraph, or in the absence of both, by mail. ' A written follo~,~-up report shall be sent to the Department within seven days of the event reported. Tt~e written report shall contain but not be limited to' (1) times and dates on which the e'voI][l occ~_~rred and, if 'not cOrrected, the anticipated time thc noncompliance is expected to continue; (2) a detailed description of the event, including · quantities and types of materials invo].ve~-t; (3) details of any damage to the '~'' rece~ (4) details of actions taken or to be taken to correct the causes of the event; and (5) details of actions taken or to be taken to correct any damage resulting from the event. It is recognized that influent quality changes, equipment malfunctions, or uncontrollable circumstances may sometimes result in effluent concentrations exceeding the permit limitations, despite the exercise of all possible care and maintenance measures and corrective measures by the permittee. The permittee may demonstrate to the Department that such circumstances exist in any case where effluent concentrations exceed t]~ose set forth in this permit. The Commissioner shall consider such showing in determining permit violations and fo~: enforcem~.:0, t purposes. The Department does not waive any of its legal rights during such consideration. 5. Adverse Impact ta~e all necessary means to minimize The permittee shall ~' any adverse impact to the receiving waters or .].ands result:i, ng from noncompliance with any limitations specified in this permit, including such additional' monitoring as necessary I>c. rmit No. WPC 78- 2 6~ to determine the nature and i~pact of the nonco~p],ying, discharge. The permittee is required to undertake cleanu? a¢:tivities in the event of any adverse impact resulting from noncompliance. Change of location Prior to cobb. eh'ting a discharge to the waters or ]..a~ds of the State, either in the first location after this permit is issued or in any subsequent retocatioits of uhe drill, rig, the permittee shall submit a plan for approval to the Supervisor of the Department's Regional Office in which the operation is ].ocated. The permittee shall obtain prior approval from. the Regional Office before discharging any t.~a~;[:e:t: at the new site. If the Regional Office does not approve_ the site for. operation under this permit, the permittee must obta"i.n an appropriate amendment to this permit pursua~t to ].$ AAC ].5.100 (d) . GENEPu%L 1. Right of Ent_r_x The permittee shall allow the Co~nissioner or his authorized representative, upon presentation of credentials, to enter upon the permittee's premises %¢here collection or treatment works are located at such times and upon such 'terms as the Department may reasonably require, and 2~ at reasonable times, to have 'access to and to be allowed to copy &ny records required to be kept under the terms and conditions of this permit, to inspect any monitoring equipment or monitoring ~ethod required in thi.~.; permit~ and to take any samples necessary for the enforcement of this permit. Transfer of ~nership or Control In the event of any change in control or ownership of faciliti~as from ~hich the authorized discharges emanate, the permit,.ce shall notify the succeeding o~;mer or controller of thc existence of this permit by letter, .a copy of which shall be forwarded to the Comm.~issioner. 3. Avail_ability of Records Except for information relating to secret process~.s or methods of manufacture, all records and reports prepared in accordance with the terms of this permit shall be available for public: inspection at the offices of the Department. o . 6. 7, Property Rights The issuance of this permit does not convey a~y properly rights in either real or persoaal property, or a~O, other privileges; nor does it authorize any _injury to p.~_'ivate property or any invasion of personal rights, nor a~y in- fringements of federal, State or local ].a~,~s and reg~latio~s. Severabiliqz The provisions of this permit are severable a~td, if any i provision of this permit or the application of any provision of this permit to any circc~mstance$ is held invalid, the application of such provision to oth~_r circtu:~.st-ances and the remainder of this permit sha]_l not be affectc, d Notwithstanding the above, in the event t~{at sucl~ materially al. tars the scope or conditions of this permit, tb.e Department shall[ have the right, at its sola optio..~, to terminate the permit. State Laws Nothing in this permit shall be construed to prec].ttde the institution of any legal action or relieve permittea from any responsibilities, liabilities, or penalties estab]_i~hed pursuant to any applicable State law or regt,lation. Posting of Permit The permitt~e shall post this permit conspict, tously at the -treatment works location and maintain a copy of it in their central office. Definitions For the purpose of this permit the following definit-[ons shall apply. Average The arithmetic mean of values obtained over a specified period time. For coliform de te~_~mined by the multiple, tube procedure the average shall be computed as the geometric: n~e~a; for determined by the membrane fi!'t-er procedure the average shall be computed as the arithmetic Co,~mmissioner Co~mnissioner of Environmental Conservation Composite Sample A combination of individual sa~ples o.f water or wastewater taken at selected interval.s, generally hourly for some specified period, to minimize the effect of the va~iab~.lity individual samples. Individual sz~mples are combined into the composite ~_n proportioa to flow. ]_uf luen t I'ag<: 8 of 8 Por~ai.c No. WPC 78-2 That segment of the wasters;star stream x~q'~ich . 1. itwm~ediately follows pretreatment, or 2. ' is within or immediately following a surge or equalization tank, 'providing that only raw wastewater or raw wastewater immediately after pretreatment enters the tanks, or 3. enters the 'first step of the treatment process if no pretreatment or equalization facili, ties exis t. Maximum Value The value of any given par~mteter that is never to be exceeded by any sa~:2ple. Pretreatment The removal of large solids from r~.z sewag(~ by coarse filtration, or the shredding o.f large so.l:i.d:::~ by comminution. Raw Water Water as it exists in :its natural state at the point of taking for domestic use or othc~r 1)urpose~. Receiving Environment The location at which waste is discharged to the environment, be it lands or waters. Thirty'Day Average The average of' all samples taken during a thirty consecutive day period. Wastewater Stream Wastewater Stream Segment The flow of wastewater from its source(s) through 'the collection and treatment facilities to the point of final discharge to the receiving env:i, ronment. A portion of the wastewater stream. Waters Includes lakes, bays, sounds, ponds, impounding reservoSrs, springs, creek, estuaries, marshes, inlets, straits, passages, canals, the Pac:i. fic Ocean, Gulf of Alaska, Bering Sea, and Arctic Ocean, in the territorial limits of the State, and all other bodies of surface or underground water, natural or artificial., public or private, inland or coastal, fresh or salt, which are wholly or partially in or bordering th(: State or under jurisdiction of the State. F'owa No. P--.4 REV'. ~- I-?O STATE OF ALASKA OIL AND GAS, CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. o,L [-q aA, []] oTH'-, Wildcat WELL ~ELL 2. NAME OF OP]~TOR Exxon Corporation 3. ADDRESS OF OPERATOR Pouch 6601, Anchorage, Alaska 4. LOCATION O,F W~-J-~ 99502 APl NU~IERICAL CODE 50-089-20006 6 LEakSE DESiGNA~ON AND SERIAL NO ADL 47567 SUBMIT IN DUPLICATE ? IF INDIAJ~T, ALXDTTEE OR TRIBE NAME 8, L.~IT FAI~'I OR LEASE lqAME Point Thomson Unit 2615' NSL & 1801' WEL of Sec. 3, T9N, R22E, UPM, North Slope, Alaska 9 WELL NO Exxon No. 2 10 FIELD A~D POOL, OR WILDCAT Wildcat 11 SEC, T., R., 3'I.. (Bo'I~OM HO12E OB.mc-fryE) Sec. 3, T9N, R22E 12. PEPdVIIT NO 77-64 REPORT TOTAL DEPTH AT END OF MONTH, CHA_NGES IN HOLE SIZE, CASING AND C~WIENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOB~ JUNK IN HOLE AND SIDE-TRACKED HOLE AND A2qY OTHER SIGNIFICANT CI-IAJqG~ IN HOI~ CONDITIONS. The location and Otter ice airstrip are complete. Rigging up is 90% complete. 14. I hereby eerti£~t~t~_~,~the/~or~g''~4rue~ _ ~ ~ Di st Mgr. Offshore/Ak. Div. sm~ _/~~ ~'/~ .... ~ Exolnratinn n~nnrtm~nf ~A~' 2/1R/7.7 ~oa ~. nnan~ ' ' - ...... NOTE--Report on this form Jl required for tach calendar ~nth~ regardless of the Itatus of operations) and must N flied In duplicate with the oil end gas conlervofion commiffee by fbi 1Sm of the su~cNding month. ~le~ ofherwile directed. CONFiDENTiAL December ~, 1977 Exxon Company, USA ~~~Y~/~ Pouch 6601 _ ,, J Gentlemen: The operations outlined in your letter of September 21, 1977 are hereby approved subject to the following stipulations: 1. Adequate ice pads must be constructed wherever wheeled vehicles are used. e . t 6, The use of tracked vehicles on the tundra must occur only after a representative of the Division of Land & Water in Fairbanks has determined that an adequate snow cover exists. The snow cover, on the lake being used as a water source, must not be removed in order to maximize its insulating properties. The turn-around for the water trucks must be located off the lake's surface. Daily records of the amount of water extracted from the source lake shall be reported monthly to the Division of Land and Water Management, 4420 Airport Way t n Fairbanks.. ,. Stream crossings should be at known (shallow) areas. Stream ice cover routes should be avoided as much as possible to prevent accel ,rated freeze-down. The banks of watercourses' shall not be altered. If steep banks are encountered at watercourse crossings, snow ramps sh~ll be constructed to assure bank protection. -2- 10, To avoid unnecessary stress to nesting birds, the Department of Fish & Game requests that helicopters avotd flights near barrier islands and known nesting bird concentrations from June 15 to August 1. A route along the coastline but avoiding the Sag Delta and a minimum altitude of 1,000 feet whenever possible is preferred. 11. The Department of Fish and Game advises the operator of the federal regulation {50 CFR 19) which prohibits the harassment of wildlife and 5 AAC 81.120 which prohibits use of helicopter participation in any form of taking or pursuing game, Department of Fish and Game also suggests wildlife be avoided with air craft by a minimum of one-half {~) mile horizontal or 1,O00 feet vertical distances, 12. Material shall be removed only from unvegetated and exposed (de-watered) bars of the watercourse to the existing ice or water level, 13, Removal shall occur in such a manner that the water flow of the watercourse shall not be rechanneled, blocked, or diverted. 14, To the greatest extent possible removal shall occur in such a manner that berms, potholes, and/or depressions are not created, 15, Upon completion of material removal or before expiration of this authorization the mining site{s) shall be graded smooth with all berms and potholes removed, and all depressions filled to prevent entrapment of fish. 16. Equipment shall not enter or cross an active (open flowing) channel of the watercourse, 17. The 'Habitat Protection Section, 1300 College Road, Fairbanks, Alaska 99701 shall be notified in writing or by phone (452-1531) prior and subsequent to removal of material. An authorized representative of this department may wish to view the operation to insure protection of fish and wildlife values. 18. A copy of this authorization shall be available for review, at the removal and/or construction site{s), upon request by an employee of the Department. of Fish and Game in Fairbanks. 19. Fuel or motor oil storage areas shall not be located within one-quarter mile of a waterbody. All fuel must be stored in a location where spilled fuel can be easily contained and retrieved. Refueling of equipment should not occur Within 100 feet of a waterbody. Permanent fuel storage areas shall conform with the requirements of the Alaska Department of Environmental Con servatton. 20. All putresctble wastes must be incinerated daily or back-hauled on a regular basis to avoid attracting scavenging animals to the location. The applicant is advised of Department Fish & Games's regulation (5 AAC 81.218) which prohibits making food items available to bears, wolves, foxes or wolverine. 22. All ground vehicles utilized in conjunction with this operation shall be plainly marked on a horizontal, exposed, upwind facing surface with the operator's party number and the Director and the r~.orthcentral District Office shall be notified of the number assigned before operations begin. -3 23. Any time after April 15, 1978, the use of ground contact vehicles shall be sub ject to termination within 72 hours of notification by the Director. 24. Campsites and/or storage and stockpiling of material on the surface ice of lakeS, ponds, or rivers is prohibited. 25. The applicant shall be responsible for restoring and stabilizing all disturbed areas to prevent erosion. 26. All operating areas shall be maintained and upon completion of operations left in a condition satisfactory to the director. 27. Drinking water must meet State standards. The water treatment unit proposed for use. is satisfactory. 28. Any wastewater discharges must meet EPA's secondary standards of 30 mg/1 BODS, 30 rog/1 suspended solids, and 200 fecal coliforms per 100 milliliters. The proposed reinJectton of treated wastewater into the well as well as solid waste disposal is being addressed under a separate permit to be issued by the Department of Environmental Conservation. 29. Disposal methods for waste, test, and clean-up oils must be. approved by the Department of Environmental Conservation. 30. The area around and below the fuel storage facilities shall' have a dike surrounding it with impermeable membranes beneath OR the fuel storage facilities shall be of double wall construction. 31. Any hazardous material spills must be reported and cleaned Up as per section 18 ~ 75.080 of the environmental regulations. 32. A completion report shall be submitted within 15 days upon [ermtnation of permit activities including the following information: a. All routes of travel and all campsites depicted on a USGS topo map. b. All additions to original application. c. Statement of clean up activities. d. Time spent in each campsite. e. Methods of disposal of garbage and other camp debris. 33. The extraction of gravel must be completed by March l, 1978. Ethel H. I4elson Land Management Officer Cc., p c_ E ()N COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION 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' Exxon's application for Permit To Drill, Form lO-401, filed with your office September 21, 1977, erroneously referred to the location of the well as 2165' NSL and 1801' WEL of Sec. 3, T.9N, R22E, UPM, when the correct location, consistent with the plat of survey accompanying said application was 2615' NSL and 1801' WEL of said Sec. 3. The inconsis- tency between application and plat of survey was called to our attention by Mr. Harry Kugler of your office and as a result of his inquiry the error has now been corrected. Please accept our apologies for any inconvenience this may have caused you in the processing of Exxon's application. Yours very truly, Robert K. Riddle RKR:jh XC: Mrs. Ethel Nelson Mr. Scott Grundy Mr. Wm. Copeland Mr. Douglas Lowery A DIVISION OF EXXON CORPORATION ~ Corporation Permit ~. 77-64 C. D. Jones ~, Offshore/Alaska Division P. 0. ~ 2180 Houston, Texas 77001 Enclosed is ~ app~c~ed application for permit to drill the above ref~ w~ll at a locatic~ ~ ~ 3, Township 9N, ~ 22E, UP~?. A dfre~c~al ~y rivers ~ AlasP~ and their cfrainage ~ .have been classified as L~t for ~ ~~ or migration of aa~adrclmm3s fish. Operations in ~ese areas ~ sub~-t to AS 16.50.870 and the _regulations prclrulgated tt~reunder (~_tle 5, ~ ~strative Code). ~rior to ommmmcing_ operations ~ may be oc~tacted by. t_~ Habitat Goo~d/nator's office, De~t of Fish ~ ~. Pollution of any ~ of ~ State is prohibited by AS 46, Ch~er 03, Article 7 ~ the z~FulatioD~ plxxm~.gated thereunder (Title 18, Alaska ~~/stra~ve ~, C~pter 70) ~ by the Federal Water Pollution Control ~, as ~. ~ior to ~ing operations you may be. Pur~t to ~ 38.40, ~ ~Lire Unde~ State Leases, the Alaska Department of ~ is being notified of ~he issuance of this ~r~zmit to drill. ~b a~ ~ in ~ul~ field ~Drk, ~ w~a]~ appreciate your rf~utfying this ~fice with~ 48 ~ after ~ w~l! is ~. We. ~culd also like to be notified so ~ a representative of ~ Division ~ay be present to %fitness tes+_ing of blowotfc preventer e~~t before ~ace casing, shoe is drilled. Pt. ~ UDit %2 ~r 8, 1977 In the e~at of ~~ or abandom~ent please give this office ad ~equate ~ notification so that we may have a witness present. Very truly yours, cc: Deparu' ~-~_nt of Fish and Game, Habi~t Section w/o encl. Department of En~~tal Cc~servaticn w/o encl. Departnm~t of ~, Supervisor, !~_bor Law Cc~pliance Division w/o encI. - 7~ STATE OF ALASKA OIL AND GAS CONSERVATION COtAMi~EE PERMIT TO DRILL OR D[E~EN DRILL ~ DEEPEN Wildcat EXXON CORPORATION 4 · P 0 Box 2180 :T:2379 Houston, Texas 77001. % ~>C^TtON .... ~ ' ^,,,,,,:, o~ ;IsL & 180I'WEL of Sec. 3' T9N, R22E, UPM, North 2&/~//~4~/~ Slope', Alaska ^,,,o,,d ~,od.,o-~ Straight Hole DISTANCE IN .%',[L~S AND D:RECT[ON }-I~OM ,~[AR£ST TO~¥N OR POST 46 miles east of Deadhorse 14. ' ~,ON D INFO/-i M AT iC.", Oil & Gas Conservation Bond 5134049 State BOnd. File B-I-zl TYPIC. S~'v ~a'~r .~o ' ~OCATION TO NE~PEST ' . I ' tO ~EARESi' W~LL CR:LLISG. CO~4PL~. OR APPLIED FOR. ~. gpprox 22600' W of Exxon gl Pt ThomSo '!3,500' .- ,;gpprox 24' Ck 40" 26" ]7-1/2" 2-1/41" . 8-1/2" SIZE OF CA$:NG 136"x32"x28' _.18-5_/8" 13.3/8" 9-5/8" _ 7" 6" 4-1/2" ^_PI No. 50-0.89-20006 $. I. I.~NA$£ Df':%IG."IAT'ION AND S~:LU~L NO. ADL 47567 1. Jr IN'DI~N. ~ ~'-I~E git T'P,.LB£ Point Thomson UnSt I. WELL .NO. £xxon ~o. 2 IIX tIE'oD AND POOL. OH. WILDCAT W-i I dca t II. $£C.. T. R . :4 . HOLE Sec 3, T9N, R22E ~o,,-, $100,000 17. NO. ACKES ASSIGNED TO THiS WELL /. 20. R,QTAR.¥ OR CABLE TOOLS Rotary .. 22. APPROX. DATE WORK WILL STAR PP. OPOSED CASING AND CEM£NTi, NG PP, OCF..kM I , I nsul ated/R~Lfri gera~ed 85' . 96 4 K,55 ~ 72 iN-SO { 43.5 tS00-95 32/35 j P=i:,I,O j 15.1 .., ~_0-95/-? 13500' November 15,.. 1977 800' 3300' ±9000' fl 1000' · q'uontity of cement To surface TO surface To surface. Approx. _top of cement @ 6000' 500' above -pot.enti al h~vdrocarbon zone Subsurface Injecti-on: It is planned to set the 9-5/8" casing into the pressure transition zone before breakup to provide for dispos.al 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- (Se~ attached sheet) S~AC'~- D~3S~.---P. IBE P'~OY'OSFO PR~R.~M- If ~1 Is to dee~n 'give ~ pn pre~ent p~ualve tone and that t~oregcml ~ ~e an~ Corre~ ..... ,. __ . _c~ ~ September 21; 1977 77-64 ........... A~I~RO V AL DAT~ , Hanager, Offshore/ Alaska Divisiom 50-089-20006 December 8, 1977 , Member December 8, 1977 DATE __ ~ Division of Oil and ,":.'ts ~Conservation ., Pete Nelson Land Mana~t Officer III Divisic~ of M~_rals & Energy Mgmt. -- / o. Director. Octo!~r 10, 1977 F~on-Point ~mpson Unit SE/4, Sec. 3, T~, R22E, ~ ADL ~ 47567 .. We have reviewed the-"Plan of Operations" and "Contingency Plan" propo~ and sutxnitted by the operator for the cap~ ~11 ar~ recommend its approval as sub~tt~l. IE]I ON COMPANY, U.S.A. POST OFFICE BOX 2180- HOUSTON, TEXAS 77001 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION CRANDALL D, JONES MANAGER September 21, 1977 Exxon No. 2 Pt. Thomson Unit SE/4, Sec. 3, T9N, R22E, UPM A.D.L. 47567 North Slope, Alaska 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' Exxon Corporation submits the following in regard to the captioned 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. DC10581 dated September 21, 1977 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 is presently operating under Permit No. WPC 77-2 at the Point Thomson Unit #1 Site). (2) Plats showing the routes to mobilize the construction equipment using rolligons and to move the rig over Beaufort Sea shore ice as well as possible gravel and water sources. It is our plan to commence location work in late November 1977 and drilling operations are to be commenced during February 1978. Sincerely, OCR- 1 j Enclosures cc' EPA Region X w/enclosures A DIVISION OF EXXON CORPORATION PLAN OF OPERATIONS EXXON #2, POINT THOMSON UNIT Location: 2165' NSL and 1801' WEL Section 3, T9N, R22E Umiat Meridian North Slope, Alaska The enclosed plats show all available information regarding: 1. Local and area topography around location. (Exhibit A) 2. Planned winter access roads which are to be constructed. (Exhibit B) 3. Proposed location layout including well position, reserve pit, sanitary waste pits, burning pit, and fuel storage area. (Exhibits C and D) 4. Location of ice airstrip. (Exhibit A) 5. Location and type of water s~pply (Exhibit A) 6. Location of gravel sources. (Exhibit B) There are no existing facilities (roads, camps, etc.) within a three mile radius of the proposed location. Natural Setting The proposed drilling location shown on the attached Exhibit A is situated on a relatively flat area approximately 8000 feet inland from the Beaufort Sea Coastline. The surrounding terrain is low lying coastal plain with 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 24 feet above sea level. The proposed well is in the continuous perma- frost zone of Northern Alaska. Depth of permafrost in the area under consideration is approximately 1600 feet. The active surface layer or thaw zone is from one to three feet. 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 preserve the ground cover and protect the surface from unnecessary damage. Arctic climatic conditions include relatively cold temperatures year round. Strong winds, small annual precipitation, and visibility strongly influenced by the combination of winds and coastal sea ice condition are factors contributing to an extremely harsh environment. Temperatures vary from a high in the 40 to 60°F range in the summer to a iow of -50 to -60°F in winter which, with the chill factor, may reach -100°F or lower depending on the severity of winds. Surface winds predominate from the east at an average velocity of 12 miles per hour along the coast with a velocity range of 35 to 50 mph associated with.winter storms. Total annual precipitation is in the range of 4 to 6 inches which includes 12 to 48 inches of snowfall. Various species of wildlife exist in the area. During the winter months, when the major part of activities are planned, wolves, wolverines, foxes, polar bears, and caribou may be present. Bird life is limited primarily to the raven and ptarmigan, with waterfowl and most other birds having migrated from the'area for the winter. There are no roads, airstrips, housing, Or other facilities in the area. surface travel, because of the fragile nature of the surface active zone, can only take place during the winter season while the ground, streams, and lakes are frozen. Prudhoe-Deadhorse, located approximately 45 miles west of the location, is the nearest staging area and airstrip with limited facilities for handling cargo and housing personnel. The nearest supply center with limited machine shop facilities is Fairbanks. The only known use of the area by man is the occasional use by oil and gas exploration people, naturalists, government resource and management personnel, and very occasional visits for hunting, trapping, and recreation purposes. Construction and Operating Plan Location work will be started in late November 1977, consistent with State approval, provided freeze-up is sufficient t'o facilitate move- ment of heavy equipment to the location using Rolligons. It is planned to move the rubber-tired vehicles over the Rolligon road after a suitable route has been established. The tentative Rolligon route is shown on Exhibit B. It is currently planned to activate the camp at No. 1 Point Thomson Unit drill site to provide housing during the construction of the No. 2 Point Thomson Unit drill site located approximately four miles west of the present location. After com- pletion of the location, the camp and drill rig will be moved in from No. 1 Point Thomson. In order to protect the personnel during the latter move, it may be necessary to utilize a self-sustaining camp unit. Rolligon has'such a unit that has a kitchen, electric toilet unit, and generator system that will sustain eight (8) men and provide shelter for more if necessary on an emergency basis. This can be hauled and set up by one Rolligon. Also it is anticipated that for operation during this period, emergency shelters should be provided along the overland route. The sequence of moving camp and equipment to the area should be as follows: Lay out road route with an empty Rolligon at earliest possible time. -2- Activate the camp site at Exxon No. 1 Point Thomson Unit. Start construction of ice roads for water and gravel haul using equipment currently located at No. 1 Point Thomson Unit. 'Move in dozers and other equipment with Rolligons. Move Belly-dumps, loaders, and graders over road. Two water trucks will be required to haul. camp water and to repair bad spots in haul roads during c.onstruction operations. Two specific things will be kept in mind when it is desirable to move across the overland route. These are that, in order to protect the tundra., adequate snow cover must be available at the time a move is made, and freezing at the river crossings will be enhanced by removing snow cover and exposing the ice to ambient temperatures. The No. 2 Point Thomson Unit location shown in Exhibit C will be approximately 600' x 700' overall and with a 5 foot gravel pad will require approximately 35,000 cubic yards of gravel. The proposed gravel sources are listed below in the order of planned usage (see Exhibit B): · Approximately 20,000 cubic yards of gravel will be salvaged from the Exxon No. i Point Thomson. site. · Remainder from gravel bars in the vicinity of Sections 14 and 23, T9N, R20E above one foot above grade. · The gravel removal, and hauling Will be accomplished using rubber- tired loaders and belly-dumps for direct movement; however, when necessary, the gravel will be placed in piles for convenient loading using dozers. Movement will be over sea ice roads along the coast and ice roads constructed of snow and water to protect the existing land surface. The planned drilling location, as shown on Exhibit C, will accommO- date the rig and equipment, camp, and support facilities. The site is to be overlain with sufficient gravel to act as an insulation barrier to prevent thawing of the permafrost during summer operations. Wooden matting will be used under drilling rig and mud pumps for stability and as a further aid in preventing permafrost degradation. All. pits are to be diked with gravel. A 200' x 200' 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 before breakup which will permit subsurface disposal of wash and melt water and excess drilling fluid. 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 10' deep burning pit will be located -3- a safe distance from the rig to permit burning of all hydrocarbon test liquids. Fuel storage will be approximately 200,000 gallons in welded steel tanks located within a 60' x 100' x 6' deep, impermeably lined area. Ail excavated topsoil or tundra from the pits will be stockpiled at an accessible site adjacent to the location in order that the area may be restored as'nearly as possible to the original condition at the time ef back-fill and clean-up operations. The rig has not been finally selected for the drilling operation; however, there are two possibilities. Either the Loffland Rig 162 will be moved from Exxon's No. 1 Point Thomson Unit or a rig will be moved from the Prudhoe Bay area. In either case, transportation of the rig will be over an ice road along the coast, primarily on sea ice. Exxon will move the selected rig to the Point Thomson Unit as soon as the location is ready, to permit spudding the well in February 1978. Actual drilling and evaluation operations will require four to five 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. In this regard, when 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 helicopter. All suppbrt equipment not required for summer operations will be moved out before breakup. Camp Facilities It is planned to activate the 65-man camp system at Exxon's No. 1 Point Thomson Unit as early as possible to provide facilities during location construction. Sewage and gray water from the kitchen and shower areas will be discharged in separate lines and will be intro- duced into an approved waste disposal unit installed at the site. Sewage, water, and garbage use and disposition will be as follows: 1. A 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 discharge in the event of a treating plant upset. 2. Potable water for the camp facilities will be hauled from small lakes near the rig and a large, eight-foot deep lake approximately seven miles southeast of the location. 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 Met-Pro water treating unit before use in the camp. Additionally, gray water from %he camp will be used for mud and rig wash water. -4- 3. Burnable garbage and trash will be incinerated through a separate Incineration Unit. 4. Products such as paper, wood, and cardboard will be open burned. 5. Cans, glass, and other items will be compacted and bagged by means of a standard kitchen type compactor and will be stored and buried in the bottom of the burning pit area prior to the time of backfill. 6. Scrap metal, tires, drums, batteries, and other non-burnable items will be hauled to Prudhoe.Bay area for further dis- position. Development Plans If oil is discovered in sufficient quantities to warrant future development, 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 46 miles to the west. If commercial 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, by use of existing roads and winter trails where possible, and by construction of a graveled well site, storage location, pits, and dikes. 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 construction of surface facilities, procedures for drilling, and subsurface equipment are needed to allow for the unique character- istics of the permafrost area. On the surface, the gravel pad and wooden mats are placed uner the drilling equipment to reduce heat loss, melting, and settling. For future permanent construction, sufficient gravel or other insulation must be used to prevent thawing and damage to the tundra and facilities during elevated summer temperature. 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 -5- CONTINGENCY PLAN EXXON NO. 2~ POINT THOMSON UNIT The objective of.this plan is to list major operating and contingency requirements to ensure a safe and efficient operation throughout the drilling activity. Equipment and materiel stockpile requirements for operating after breakup are tabulated for operational planning. The location has been designed to provide-containment of any drilling operation effluents that could be considered as pollutants. The 200' x 200' 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 from the camp will be processed through a Met'Pro Waste Water Treating system with the solids 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 impermeably lined fuel storage area. A primary feature of the drilling plan is to provide 9-5/8" x 13-3/8" annular injection capability before breakup. 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" pro- tective casing will be set into the anticipated pressure transition zone and cemented to isolate the salt water sand sections from below the surface casing shoe to approximately 6000 feet for injection of excess mud, melt, and waste waters collected in the pits. 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 selected drilling contractor will be r~quired to develop a comprehensive SPCC plan to prevent pollution as a result of any drilling rig operations. 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 factors 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 o£ an unplanned upset resulting 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 71,000 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. ~l~--- 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 before spring breakup. After breakup light consumables will be transported by helicopter. A Rolligon will be on location for any local movement of water or fuel as permitted by land conditions. Equipment and materiel stockpile requirements are tabulated below: Equip.ment Requirements -. (Normal Operations) 1. Aircraft - A Bell 212 Helicopter will be used to transport personnel, material, and supplies up to a maximum 4,000 pound payload. 2. On-Site Support Equipment 1 - Rolligon with detachable fuel and water tanks 2 - 966 Front Loaders i - Combination Flat Bed Truck with winch 1 - Bull Dozer -2- Materiel Stockpi.les 1. Mud Supplies a. Barite - 20,000 sks. b. Bentonite - 3,000 sks. ¢. Lignosulfonate - 500 sks. d. Lignite - 500 sks. e. Lost Circulation Material - 500 sks. f. Casing Pack Material - Minimum requirements for 150 bbl. mixture. · 2. Cement - Minimum of 3,000 sks. of Class G. 3' Casing and. Tubing 14',000' - 7", 32/35#, P-110, BT Casing 3,500' - 4-1/2", 15.1#, C-95, LTC Casing 14,000' - 2-7/8", 8.7#, N-80, Hydril PH-6 Tubing 3,500' - 2-3/8", 5.95#, N-80, Hydril PH-6 Tubing 4. Drill Pipe and Drill Collars 14,000' - 5", 19.5#, Grade E&G 14,000' 3-1/2", 13.30#, Grade E drill pipe 900' - 4-1/8" drill collars 5. 7-1/16", 10,000 psi WP BOP Stack and choke manifold 10,000 psi WP christmas tree and wellhead equipment · 6. Fuel - Minimum 200,000 gals. in steel tanks TLP' kc 8/4/77 -3- Eye.ON COMPANY. U.S.A. POST OFFICE BOX 2180- HOUSTON. TEXAS 77001 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION CRANDALL D JONES MANAGER September 21, 1977 Exkon No. 2 Pt. Thomson Unit SE/4, Sec. 3, T9N, R22E, UPM A.D.L. 47567 North Slope, Alaska 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: . Exxon Corporation submits the following in regard to the captioned 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. DC10581 dated September 21, 1977 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 ~nove 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 is presently operating under Permit No. WPC ~7-2 at the Point Thomson Unit #1 Site). (2) Plats showing the routes to mobilize the construction equipment using rolligons and to move the rig over Beaufort Sea shore ice as well as pOssible gravel and water sources. It is our plan to commence location'work in late November 1977 and drilling operations are to be commenced during February 1978. Sincerely; OCR:lj Enclosures cc' EPA Region X w/enclosures 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", 10,000 psi BOP stack will be used if required during well testing. BOP installation and testing will be in accordance with Exxon standards which require pressure testing on initial installation, when any com- ponent is changed and at least once weekly thereafter; 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 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 @ 3~300' INJECTION INTERVAL TOC @ APPROX. 6000' 7" TIED BACK TO SURFACE FOR PRODUCTION 9-5/8" PROTECTIVE @ APPROX. 90(0' CEMENT INTO 9-5/8" 7" PROTECTION/PRODUCTION LINER @ APPROX. l l,O00' CEMENT INTO 7" 4-1/2" PRODUCTION LINER @ 13,500' '1'- EXXON No. 2 POINT THOMPSON UN LAT. : 70°09'47.76':) LONG,=I46°50'55.48 X= 435,937 Y = 5,909,5 I 5.. I t I I L__ , _1 L _J SCALE: I"= IMILE CERTIFICATE OF SURVEYOR I hereby certify that I am 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 my supervision, and that all dimensions and other details are correct. D13te ~ SURVECdR I I I IT ION. IT 9N. I I I I I I I I 1 I I I I I i i AS STAKED EXXON No. 2 POINT THOMSON Located in 'SE I/4 PROTRACTED SEC. :5 Surveyed for JULY 19~ 1977 UNIT ALASKA Surveyed by F. M. LINDSEY I~ ASSOC. LAND & HYDROGRAPHIC SURVEYORS 2502 West Northern Lights Boulevard Box 4-O81 Anchor(~ge Alaska EXXON COMPANY U.S.A. E Ol'tl COMPANY, U.S.A. POST OFFICE BOX 2180. HOUSTON. TEXAS 77001 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION CRANDALL D. JONES MANAGER September 21, 1977 Exxon No. 2 Pt. Thomson Unit SE/4 Sec. 3, T9N, R22E, UPM A.D.L. 47567 North Slope, Alaska Mr. 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: 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 location construction, rig move and resupply, potable water supply, waste and sewage dis- posal, 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 is presently operating under Permit No. WPC 77-2 at the Point Thomson Unit #1 site). (2) Four exhibits (plats) showing the routes to mobilize the construc- tion equipment using rolligons and move the rig over Beaufort Sea shore ice as well as Possible gravel and water sources' Exhibit A - Vicinity map, Exxon No. 2 Point Thomson Unit with proposed ice road and rolligon haul routes Exhibit B - Possible gravel sources and proposed ice and rolligon haul roads Exhibit C- Pad layout Exhibit D - Pad topography OCR:lj xc' EPA Region X A DIVISION OF EXXON CORPORATION As stated herein, it is our plan, State approval permitting, to commence location work in late November 1977 and actual drilling operations are to be commenced during February 1978 and conclude after breakup four to five months later. The rig will .be left on location until the following winter. Sincerely, POINT THOMSON #2 (PROCEDURE BEGINS AFTER PLUGGING THE TEST INTERVAL AT 5862' - 5960') e Trip in the hole with open ended drill pipe to 5750' and circulate and condition the well bottoms up. ., Thoroughly clean out the rig suction tank and mix the following premix slurry for Arctic Pack placement in the 9-5/8" x 13-3/8" annulus: 173.5 bbls diesel 11.0 bbls H20 12.5 lb/bbl EZ Mul 28.0 lb/bbls Geltone 660.0 lb salt Mix the Arctic Pack premix according to the attached instructions. Mix this slurry at 60°F and after mixing is complete reduce the mix temperature to 40°F. e Rig up the Halliburton cementing unit to displace the Arctic Pack premix with additional Geltone to the 9- 5/8" x 13-3/8" annulus. Pressure test all cementing lines to 5000 PSI. 4.- Displace 30 bbls of the Arctic Pack premix to the 9- 5/8" x 13-3/8" annulus. Displace the additional 150 bbls of Arctic Pack to the annulus while adding 25 lb/bbl of additional Geltone to the premix on the fly (3750# total additional Geltone). Cease displacement to the annulus after the full 150 bbls have been dis- placed. Close in the 9-5/8" x 13-3/8" casing annulus and carefully catch all remaining Arctic Pack premix in the Halliburton lines in 55 gallon drums. Excess fluid should be stored in the drill site burn pit pending future disposal. Circulate 12.2 lb/gal mud heated to 70°F+ inside the 9-5/8" casing string for 2 hrs. 5~ In the rig suction pit mix 175 bbls of 10.6 PPG CaC12 water according to the following formula: ~ - 139 bbls H20 - 28000 lbs CaCl2 (Dowfla~e) Mix and heat the CaC12 mixture to +70°F. Trip out of the hole to 2300' and circulate and condition the well. 10. 11. 12. Rig up to displace the CaC12 water." Close the annular preventor and reverse out the existing mud with 50 bbls water followed by 140 bbls CaC12. Trip out of the hole to 120' keeping the hole full with the remaining CaCl2 water. With the drill pipe at 120' mix and displace the fol- lowing cement slurry to the wellbore as a balanced plug displacing cement with clear water: ~lurry ~' 35 sx, 15.0 ppg Permafrost 5.8 bbls slurry volume 3.5 gal/sx mix water 2.9 bbls mix water TT = 4 hrs + Trip out of the hole to 40' and reverse out. Trip out of the hole. After waiting on cement 6 hrs, run in the hole and tag the cemen% plug top. Reverse circulate out the remaining CaC12 water with 10 bbls clear water followed by diesel. Insure that all CaC12 water and diesel is contained in the rig active pits and not jetted to the reserve pit. Drain the BOPE stack and 13-3/8" "B" section and nipple down the same. Cut the 9-5/8" casing stub looking up to rest below the top of the 18-5/8" "A" section. (Note: Requires removal of the secondary seal above). Use a power saw to cut off the 9-5/8"' casing. Install a 18-5/8" flange with 3" bullplugged companion flange assembly as shown in the attached sketch. To the top of the flange weld a 6" dia by 10' long piece of line pipe with the following information bead welded on the pipe: Name of operator Well name and number Exact location The top end of the pipe must be welded closed. POINT THOMSON #2 ABANDONMENT PROCEDURE WELL SKETCH io.e~ PP6 Cement Plug .- 28" x 36" Conductor @ 88 Arctic Pack in 9-5/8" x 13-3/8" Annulus CaC12/Mud interface @ 2300' 18-5/8" casing @ 842' MUD '. / l 13-3/8" perforated @ 3060' -~ 13-3/8" casing @ 3296' 9-5/8" bridge plug @-5800' 9-5/8" bridge plug @ 6980' 7" casing stub @ 7006' 9-5/8" casing @ 10099' TOC @ 10660' 7" bridge plug @ 11480 ' 7" bridge plug @ 12696' .... 7" casing @ 14103' ..... - PI- THOMSON ¢, E.' SU..,-ACE ABANDON MEN' SKF_TO ~,* Di~, ~ J~'LoN6 LII,,IE PIPE BE~D kd'ELD LETTERED 'EXXON CO U.S./~ - I~ TI-IOi~ISON UNIT - ~/ELL NO. ~.~15' N~ ~ I~1' WEL, S~ 3, ~N RPPE UM :~" COI"lPAN tON FI..~N~E. I~J-~'' 5000 ~ PORTED FLANGe_ ~ 3ooo ps~ FLANGE ON EXISTIh,IG '~:~," ,SECTION g~" CASING 3" 5000 F'S~ -.GATE V~.V ~' 'UASfEIGHTED BAROID' ARCTIC CA'SI~G PACK Baroid's Arctic Casing Pack is a stable, highly viscous, non- freezing fluid which is placed between casing strings to prevent casing failures and provide insluation 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 coefficient 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 neede'd' fo'r-l'0'0' barre'l's' of' Unwe~%'.qhted Baroid Arctic Casin~ Pack: 107 50 lb. bags GELTONE 3 55 gal. drums E Z MUL 300 lbs. Salt . '87 bbls. Diesel 5% bbls. Water Weight of unweighte~ pack 8:3 lbs./gal. Mixing .procedure 'for' Unwe'i~h'ted' Baroid' Arctic' 'Cas__ing Pack: . A. Formula for 100 barrels of Baroid Arctic Casing Pack (premix): Diesel Water E Z MUL GELTONE Salt 87 barrels 5% barrels 12.5 ppb. 28.5 ppb. 60 ppb. per barrel of water. Weight of Unweighted pr~ix 8.2 lbs./gal. Recommended procedure when using rig equipment: 1. Clean rig tanks and check for leaks. 2. Add water through salt barrel. 3. Add diesel. 4. Add E Z MUL - agitate pit. · 5. Add GELTONE. :BAROID 'ARCTIC CASING PACK Recommended procedure when using Dowell/Halliburton equip- ment: , . 1. clean and check tank for leaks and proper hookup so' casing pack can be rolled. 2. -Mix water and salt through hopper and circulate in displacement .tanks until ready to mix in with diesel. 3. Add diesel. 4. Add EZ MUL - agitate tank. 5o Add GELTONE NOTE: When using HallibUrton equipment have t~eir operator open jet in mixing hopper bowl wide 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 hop- per must have a jet installed or the discharge line will plug up. Displacenuent Procedure Run in with the drill pipe and open the D.V./F.O. collar, then set the RTTS tool. Pressure up the casing/drill pipe annulus to check the RTTS packer. 5'00 psi is sufficient for this test. 2. Flush and clean the annulus with water until mud is displaced. 3. At Halliburton/Dowell unit have sufficient GELTOI~E on hand to add the final 25 ppb to the casing pack. When ready to place the pack, add on the fly 25 ppb GELTONE through the hopper located just upstream from pump suction. 4. Establish pump rate so that the GELTONE can be added evenly. Two barrels per minute is the recommended pump rate. 5. If a cubic foot per minute counter is not available on the pumping unit, keep a pump rate/time log so that the proper amount of GELTONE can be added and vol~es determined. ~-BAROID' ARCTIC CASING P~CK -3- Adequate samples should be'caught of the casing pack returns so that a retort analysis can verify that the casing pack is not contaminated with drilling, mud or water. When the ~TTS tool is released, the D.V./F.O. collar should be immediately closed to prevent any U-tube effect from occurring. The F. O. collar is r~commended as it can be reopened as needed. Ir'is also suggested that the ~TTS tool be set immediately above the collar so a positive seal is made when packer is set. This should eliminate any mud from the casing/drill pipe annulus being stripped in displacing with casing pack. · Final formula .of BAROID Arctic Casing Pack left in annulus: · ! '~l Diesel Water. Salt EZ MUL GELTO~E '87 barrels 5.5 barrels 60 ppb per barrel of ~¢ater 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 %.~hile mixing. Afte~ the casing pack is premixed it should be left to cool as much as possible before being used. (40°F is the optimum temperature). 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. Whatever amount of GELTONE that is needed should be subtracted from tt~e final 25 pounds of GELTONE. Care should be used, not to overtreat . with GELTONE if this procedure is chosen. 'When calculating the volumes for the ~ob, a certain excess of casK lng pack will be needed. The casing pack/water interface normally will be displaced in the first 30 barrels. An additional amount; not less than 50 barrels, should follow so that adequate samples can be caught and analyzed to insure that the casing pack is com- ing back clean. The casing pack returns can be caught and recon- ditioned for later use. The GELTONE content can be easily determined by running a modified Methylene Blue test thus making th~ reconditioning of the casing pack a simple procedure. BAROID' ARCITC CA'SINS PACK Reference: STB-185 Field Trial of BAROID'S Thermo-Pack on th6 North Slope of Alaska. L. J. Remont STB-639 Oil Mud Casing Pack for Permafrost Formations. R. L. Sherman PrudAo~ Polel Stockton Islands Island LEGEND POSSIBLE GRAVEL SOURCE . + ~' . .......... Alaska I Challeng~ I ............. MaSuire ,. Bullen Pt .:. Bullen Pt Gordon ... E,MIKKELSEN BAY STATE NO. I ' Islan(/s Pt Pt APPROX. HAUL '--REV].S ED [OLLIGON D PROPOSED ICE ROAD (~ ROLLIGON EXXON COMPANY BY F.M. LINDSEY UNIT 8- 9 - 77 ..,~..J. I HAUL ROUTE ,m, U.S.A CHECK LIST FOR NEW WELL PERMITS Company ~:.×~.~:'~ Yes NO Remarks 1.Is the permit .fee attached ..................... Lease & Well No. 2. Is well to be located in a defined pool 3. Is a registered survey plat attached . 4. Is well located proper distance from property line ......... ,~ 5. Is well located proper distance from other wells ............ 6. Is sufficient undedicated acreage available in this pool ...... ~:,:,,', 7. Is well to be deviated ....................... 8. Is operator the only affected party ................ 9. Can permit be approved before ten-day wait ................. >,: ...... ' 10. Does operator have a bond in force ................. ll. Is a conservation order needed ................... 12. Is administrative approval needed ' · ....... 13. Is ~onductor. 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 ~-~o©© psig Additional Requirements' App. rova 1 Recommended' Geo 1 ogy.: En g i nee r i n g: HWK ::.'...' LCS :~ RAD ~ Revised 11/17/76
