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Home My WebLink About176-085pxxonftbil Production Company P. 0. sox 196601 Anchorage, Alaska 9951946601 907 5615331 Telephone August 4, 2014 R-2014 OUT -157 RECEIVED AUG 0 6 2014 AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 RE: Final Location Clearance • Point Thomson Unit (PTU) #1 (PTD 176-085) • PTU #2 (PTD 177-064) • PTU #3 (PTD 178-005) • Staines River State # 1 • West Staines State #18-9-23 (PTD 169-120) • West Staines State #2 (PTD 175-002) • Alaska State C-1 (PTD 180-046) Dear Commissioner Foerster, E*onMobil , Production OCT 0 12 014, By letter dated May 18, 2007, the Alaska Oil and Gas Conservation Commission (Commission) advised ExxonMobil that ten wells in the Point Thomson area did not meet the Commission's requirements for plugged and abandoned wells. The Commission further noted that permits to drill cannot be issued to an operator that is in violation of a Commission regulation pertaining to drilling, plugging or abandonment of a well. In addition to the seven wells listed above, the Commission's May 2007 letter addressed Challenge Island #1 (PTD 180-090), Alaska State J-1 (PTD 183-045), and PTU #4 (PTD 179- 080). Challenge Island was operated by another party, and we understand remedial work there has been completed. ExxonMobil has pursued remedial and final abandonment work on the ExxonMobil operated wells identified in the May 2007 letter. Visual inspections of all sites were conducted in 2007 and comprehensive inspections of the nine ExxonMobiI-operated wells were conducted in winter 2008/09. Remedial work was completed on the J-1 and PTU #4 wells in 2009 and 2012, respectively, and final reports were submitted to the Commission. During the winter 2013/14, final remedial or plugging and abandonment work on the seven subject wells was completed. A final report of Well Completion for the Plugging and Abandonment of each well was submitted to your office on May 14, 2014, followed by the summer well site debris clean- up reports submitted July 18, 2014. Cathy Foerster 2 August 4, 2014 All well remedial and abandonment work on the nine ExxonMobil operated wells was conducted in accordance with approved Applications for Sundry Approvals, some of which received modifications as the work progressed. Timely notices were provided to the Commission so inspection of the work could be performed at the Commission's discretion. The PTU #4 well file on the AOGCC website contains a final location clearance. With respect to work to close the reserve pit and conduct contaminated site cleanup work at WSS #18-9-23 and WSS #2 and incorporation of the PTU #3 and C-1 locations into the Point Thomson Project gravel infrastructure, our understanding is that receipt of final location clearance is not required at this time in order to be in compliance with plugging and abandonment requirements. Given the unique history of these nine sites in view of the Commission's May 2007 letter, ExxonMobil respectfully requests the Commission to either approve final location clearance or otherwise confirm to ExxonMobil that it has met AOGCC requirements with respect to the plugging and abandonment of these wells and do not represent an impediment to approval of permits to drill for ExxonMobil. If you have any questions or require additional information, please contact me at (907) 564-3773. Sincerely, Irene T. Garcia SSHE Manager ExxonMobil Production Company P. 0. Box 196601 Anchorage, Alaska 99519-6601 907 5615331 Telephone July 18, 2014 R-2014 OUT -156 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Ft CEIV�� UL 2 l 2014 AOGCC E*(onMobil Production S LVO OCT 01 Z�% RE: Abandoned Well Site Cleanup Reports • Point Thomson Unit (PTU) #1 (PTD 176-085) • PTU #2 (PTD 177-064) • PTU #3 (PTD 178-005) • West Staines State (WSS) #18-9-23 (PTD 169-120) • West Staines State #2 (PTD 175-002) • Alaska State C-1 (PTD 180-046) Dear Commissioner Foerster, 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, 'XV Irene T. Garcia SSHE Manager Attachments Summary of Point Thomson Unit (PTU) #1 Activities PTU #1 (PTD No. 176-085); Sundry No. 313-600 and Sundry No. 314-206 (modification) A Report of Well completion for the plugging and abandonment of PTU#1 was submitted 5/14/2014 to AOGCC. The well is plugged and abandoned in compliance with the Sundry approvals. Following the winter well remediation, summer debris cleanup activities were conducted the last week of June. Debris was collected and transported to Deadhorse for appropriate disposal. Photos are provided below. PTU #1 prior to debris removal PTU #1 post debris removal. Debris was collected in supersacks (shown in center of picture) and transported back to Deadhorse for appropriate disposal. Page 2 Abandoned Well Site Cleanup Report July 18, 2014 i PTU #1 removing pipe PTU #1 post pipe removal Page 3 Abandoned Well Site Cleanup Report July 18, 2014 HIKRAF PTU #1 post pipe removal Page 3 Abandoned Well Site Cleanup Report July 18, 2014 PTU #1 looking south post cleanup. Debris collected in supersacks (seen at left of picture) was transported back to Deadhorse for appropriate disposal PTU #1 aerial view looking north east post debris cleanup. Page 4 Abandoned Well Site Cleanup Report July 18, 2014 Summary of Point Thomson Unit (PTU) #2 Activities PTU #2 (PTD No. 177-064); Sundry No. 313-601 and Sundry No. 314-158 (modification) A Report of Well completion for the plugging and abandonment of PTU#2 was submitted 5/14/2014 to AOGCC. The well is plugged and abandoned in compliance with the Sundry approvals. Following the winter well remediation, summer debris cleanup activities were conducted the last week of June. Debris was collected and transported to Deadhorse for appropriate disposal. Photos are provided below. PTU #2 Well location conducting debris cleanup. El PTU #2 Well location post debris cleanup. Page 5 Abandoned Well Site Cleanup Report July 18, 2014 PTU #2 looking west post debris cleanup. PTU #2 looking southwest post debris cleanup. Page 6 Abandoned Well Site Cleanup Report July 18, 2014 Summary of West Staines State (WSS) #18-9-23 Activities WSS #18-9-23 (PTD No. 169-120); Sundry No. 313-604 A Report of Well completion for the remedial abandonment of WSS #18-9-23 was submitted 5/14/2014 to AOGCC. The well is plugged and abandoned in compliance with the Sundry approvals. Following the winter well remediation, summer debris cleanup activities were conducted the last week of June. Debris was collected and transported to Deadhorse for appropriate disposal. Photos are provided below. WSS #18-9-23 well location prior to debris cleanup. V V VV 7t I V -A -LJ VVGII IVVQIIVI I t.JVJI UGVI IJ %,Ir.Q1 IUF.J. 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 Summary of West Staines State (WSS) #2 Activities WSS #2 (PTD No. 175-002); Sundry No. 313-606 A Report of Well completion for the remedial abandonment of WSS#2 was submitted 5/14/2014 to AOGCC. The well is plugged and abandoned in compliance with the Sundry approvals. Following the winter well remediation, summer debris cleanup activities were conducted the last week of June. Debris was collected and transported to Deadhorse for appropriate disposal. Photos are provided below. EA 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. } YZ s} °►W ., w � 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 welly Plans are to cin the crick pjckjpg work and obtain AOGCC site clearance inspections in June. We would be happy to review the past season's work with you if desired. Our suggested timing for this would be after the stick picking effort. Are you interested in such a review and, if so, would you be available sometime during July 8-10 timeframe? Regards, Rob Dragnich Consultant to ExxonMobil Production Company R.G. Dragnich, LLC rob@rgdragnichllc.com 907-830-4796 SCANO NOV 18 2014 "x,. � .tV!.Ir, � a I x f Vii, a. .,t� "'.tri `�_-.. •`"✓s s�. ' ' ' v w I 'b . L0. _.� !.F _ r _ s d"'(t'` ®f "' •' PT 17 ` Pt � I I - `- Y-.„ ° ``.. Z l /�j!•� 9 -f �'. 14 E 13 A J:+^rA9� ,W Stalr es t to 1 56927.3 _ a , ■1Y4 `^4 nos, f6 i 3s 32 • � e a 12 u 4 R r f. ,P 13 to a n�14 O 17 I4 20 y7 32 s! 3+ �. .__ ..__.Y.-. .-_.... ._�..�,._. _ - "' '•'�''... tet; ° _._ t ,r^ ^11�.._ -�` _ rall 21 ' yS 26 , 25 30 ' '• I �... "` Is 33 t M u U 34 4 ''+ ....E s e •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 0 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: Exxon Mobil Corporation 5. Date Comp., Susp., or Aband.: 4114/2014 12. Permit to Drill Number: 176-085 3. Address: P.O. Box 196601, Anchorage, AK 99519-6601 6. Date Spudded: NIA 13. API Number: 50-089-20005-0000 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 #1 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- 458086 y- 5913342 ' Zone- TPI: x- y- Zone- Total Depth: x- y- Zone- 10. Total Depth (MD +TVD): 13298 ft 16. Property Designation: ADL 47560 11. SSSV Depth (MD + TVD): NIA 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): NIA I 22.Re-drill/Lateral Top Window MD/TVD: I N/A 23. See Attached Work Summary CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 24. Open to production or injection? Yes ❑ No 0 If Yes, list each interval open (MD+TVD of Top and Bottom; Perforation Size and Number): EC f..'VEr MAY 2 7 2014 AQGCC 25. NIA TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 26. CEMENT Was ydraulic fracturing used during completion?RUE�Yes ❑ No ❑ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. N/A PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate _-Jo� Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): 28. CORE DATA N/A Conventional Core(s) Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No ❑ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. PECMS MAY 2 7 201 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE„_�% �•�(• j� Submit original only 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? _ Yes [ No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, Permafrost - Top N/A N/A and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: 31. List of Attachments: Work Summary, Post P&A Well Schematic, Photographic documentation of the well before and after the work. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tom Juranek (832)624-5940 Email: tom.a.juranek(EDexxonmobil.com Printed Name: Irene T. Garcia Title: SSHE Manager Signature: 'V_t)_ 1( G✓ 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 f WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. 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 Service ❑ Stratigraphic Test ❑ 2. Operator Name: Exxon Mobil Corporation 5. D omp., Susp., or Aba 4/14/2014 12. Permit to Drill Number: 176-085 3. Address: P.O. Box 196601, Anchorage, AK 99519-6601 6. Date Spudded: 13. API Number: 50-089-20005 -oo - 0 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 #1 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- -146.337395 y- 70.174149 Zone- TPI: x- y- Zone- Total Depth: x- y- Zone- 10. Total Depth (MD + TVD): 13298 ft • 16. Property Designation: ADL 47560 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): 22.Re-drill/Lateral Top Window MD/TVD: 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): RECIV "' MAY 15 2014 AOGGG 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 26. N/A ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. 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 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. RBCMS MAY 15 2 61 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only /�R 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.6uranek exxonmobil.com Printed Name: Irene T. Garcia Title: SSHE Manager Signature:J&-tc�-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 1b: 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 E*onMobil Production May 14, 2014 R -2014 -OUT -126 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 R E C I MAY 15 2014 Re: Well Completion Report Well Abandonment: Point Thomson Unit #1 (PTD No. 176-085) Sundry No. 313-600 and Sundry No. 314-206 (modification) Dear Commissioner Foerster, OG 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 'POINTPRODUCTION THOMSON Exxon Mobil Corporation Pt. Thomson Unit #1 AN #: 50-089-20005 PTD#: 176-085 Final Well Schematic Marker Plate >_3' below tundra 13-3/8" x 9-5/8" Annulus: • Cement from marker plate to ±3,276' 3,500' mud/CaC12 interface Perforations 11,392'– 11,421', squeezed with 50 sx class G Retainer at 12,302' Perforations 12,834'– 12,874', squeezed with 76 sx class G Perforations 12,963'– 13,050', squeezed with 145 sx class G through retainer 10.6 ppg CaC12 TD – 13,298' in 9-5/8" from marker plate to ±130' 18-5/8" at 801' 13-3/8", 72#, N-80 at 3,276' Top 7" casing 4,000'± —15.3 ppg mud — 15.6 ppg mud TOC behind 9-5/8" casing at 6,900' 7", 35#, tieback cmtd w/ 120 sx Class G Top 7" liner at 9,032' M 9-5/8", 40#, S-95 at 9,532' TOC at 10,740'± in 7" casing TOL 4-1/2" liner at 10,873' Packer at 11,300'± 7", 35#, S-95 at 11,390' TOC in 4-1/2" liner at 12,100', 3bbls cement on top of retainer Packer at 12,700'± Retainer at 12,895' 15.6 ppg mud Packer at 12,900'±— PBTD at 13,248', 4-1/2" 15.1#, S-95 casing at 13,295', cemented with 317 sx class G '. �hemson Unit #1 ' � Point Thomson Unit #1 Summary of Work Activities 26 -Mar Preparing location at PTU #1. 27 -Mar Preparing location at PTU #1. Excavate around WH to access 9-5/8" x 13-3/8" annulus valves. Placed heater on WH. 28 -Mar Continued heating wellhead. Preparing location at PTU #1. MIRU Little Red on 13-3/8" annulus valve. Pressure tested high pressure hose to 2,500 psig. Open up annulus valve and bullheaded hot diesel down the 13 3/8" annulus at rate of 5 bbl/min with 20 bbls diesel at 600 psig. RD Little Red and SDFN. 29 -Mar Submitted AOGCC Notification form for Bull Heading cement down the 13 3/8" casing for March 31, 2014. 30 -Mar Continued heating wellhead. 31 -Mar _ MIRU Schlumberger cement unit and Peak trucks. Filled Schlumberger silos with cement. Completed bull heading cement into 13 3/8" annulus (215 bbl pumped at 3.5 bbis/min at pressure-o122.5-psig). SDFN and RD Schlumberger. 1 -Apr No Activity 4/1/2014-4/7/2014. 8 -Apr HSM, Completed cutting off 36", 32" & 28" annulus. MIRU Wachs Saw. 9 -Apr HSM, use Wachs cutting off 13-3/8" and 9-5/8" casings, remove WH. Install 1" down 9-5/8" and 13-3/8" casing for planned cement top job on 4-12-2014. SDFN. 10 -Apr No activity well ready for top cement job planned for 4/12/2014. 11 -Apr No activity well ready for top cement job planned for 4/12/2014. 12 -Apr HSM, pumped cement top job in 9-5/8" and 13-3/8" casings. SDFN. 13 -Apr HSM, Completed cutting off 9-5/8", 13-3/8" & 18" casing to dress out for installation of marker plate. 14 -Apr Completed dressing up final cut took photos, completed welding marker plate, took photos. Final Report on Well. PTU #1 As Found -. y �.�� , -,- � � �" '�;`,, __ � �, � ... � Tom: PTU #1 Depth below Tundra • OF Titi 0)1',\ I%%% �� 1 E STATE t �r�� .1011 � c 333 West Seventh Avenue Gov 1-1‘.'NOR SEAN PARNELL Anchorage Aioska 99501 35/2 • ee Main: 907 279 1433 u44':411:16,(31'1'' Fox. 90/'276.7542 �NED JUL2220111 S�,p► Irene T. Garcia SSHE Manager Exxon Mobil Corporation 6 �� P.O. Box 196601 Anchorage, AK 99519-6601 Re: Point Thomson Field, Exploratory Pool, Point Thomson Unit#1 Sundry Number: 314-206 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, Cathy P. Foerster Chair DATED this/U day of April, 2014. Encl. ;• RECEIVED 0 1 STATE OF ALASKA �� d1 4 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALSAOGCC 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 2 Development ❑ 176-085 • 3.Address: Stratigraphic ❑ Service El6.API Number: PO Box 196601,Anchorage,AK 99519-6601 50-089-20005-0000 • 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#1 r 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 47560 Point Thomson Unit - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13,298 • 13,298 • 0. 0 Many plugs,see schematic None • Casing Length Size MD TVD Burst Collapse Structural 61' 28"x 36" 83' 83' N/A N/A Conductor 779' 18-5/8" 801' 801' 2,420 780 Surface 3,254' 13-3/8" 3,276' 3,276' 3,450/5,380 1,950/2,670 Intermediate 9,510' 9-5/8" 9,532' 9,532' 6,820 4,230 Production 7,390' 7" 11,390' 11,390' 11,830 11,650 Liner 2,422' 4-1/2" 13,295' 13,295' 12,450 12,300 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory E . Stratigraphic❑ Developmen❑ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing1-Apr-14 Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: q-7—/Y WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑., Commission Representative: G'Th ...–I- GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is trud 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 Si Phone Date V../...r....<_ _6.4.......;.4........;.4. 907-564-3773 �/ if ++ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `1" ._ 2c)(0 Plug Integrity 1Y7 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: // Pi') GfD G`OCUrng-h'7' C43i1"), Cut- off vvC. ldr-4 p14 tC . Aller'- pig p/t,c - ,�� ,-a��. = /ie_6) Spacing Exception Required? Yes ❑ No li Subsequent Form Required: /D — 4° 7RBDM MAY 10 2014 G APPROVED BY 4—to / Approved by: 1* COMMISSIONER THE COMMISSION Date: -/y Rx14110 r^- i-e Y.7.11-( �,, 4' (1'4 of a.:!^- aRL , NA Submit Form and Form 10-403(Revised 10/2012) A vvv��ddd�� Inti n f3 �tQ� months from the date of approval. Attachments in Duplicate RECEIVED ExxonMobil Production Company P.0.Box 196601 ,APR 0 12014 Anchorage,Alaska 99519-6601 907 561 5331 Telephone AOGCC EkonMobil Production April 1, 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 #1 (PTD No. 176-085) 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 the placement of a cement isolation plug in the 9-5/8" x 13-3/8" casing annulus from surface to the 13-3/8" shoe. The procedure in our original Application for Sundry Approval as authorized by your Sundry Number 313-600 includes: 1. Drill through the surface cement plug (15'— 130'). 2. Place cement isolation in the 9-5/8" casing and 9-5/8" x 13-3/8" casing annulus near the 13- 3/8"shoe. Methods to accomplish this include: a. Bullheading cement down the 9-5/8"annulus to ±3,276', setting a CIBP in the 9-5/8" casing at ±3,400', and laying cement in the 9-5/8"casing from ±3,400'to ±2,800'. b. Circulating cement into the 9-5/8"casing and annulus through perforations in the 9-5/8" at ±3,200'. The 9-5/8"casing and annulus would be cemented from ±3,200'to surface. c. Squeezing the 9-5/8"annulus through perforations at ±3,200'. The annulus would be cemented from ±3,276'to ±3,200'and the 9-5/8"casing would be cemented from ±3,200'to ±2,800'. d. 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 ±2,800'. 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 the 13-3/8"casing shoe at 3,276'. This annular cement satisfies the goal of isolating the 9-5/8" x 13-3/8" casing annulus. The goal of placing bridge plugs and cement plugs inside the 9 5/8" casing 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. Note: An exception is requested for the existing 130' surface cement plug inside the 9-5/8" 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 was verified as being competent during well p suspension operations in December of 1977 and remains undisturbed. p 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 ‘11A POINT THOMSON 1611 PRODUCTION Exxon Mobil Corporation Pt. Thomson Unit#1 API#: 50-089-20005 PTD#: 176-085 Proposed Post-P&A Well Schematic IV late—3' below_ I 4w .` '-_ Cement in 9-5/8"from ±130'to surface 4 18-5/8"at 801' 13-3/8"x 9-5/8"Annulus: ' o o •Cement from surface to±3,276' ' ' 10.6 ppg +- CaCl215 itis L' . 13-3/8", 72#, N-80 at 3,276' 3,500' mud/CaCl2 interface ►��'-------s I Top 7"casing 4,000'± 15.3 ppg mud 4 15.6 ppg mud 4 TOC behind 9-5/8" casing at 6,900' -,, `f,.. . ,.' J..: 7", 35#,tieback cmtd w/ 120 sx Class G ,.• ,.. :. X Top 7"liner at 9,032' .* 9-5/8",40#,S-95 at 9,532' TOC at 10,740'±in 7"casing TOL 4-1/2" liner at 10,873' Packer at 11,300'± Perforations 11,392'— 11,421', * . . • 7", 35#, S-95 at 11,390' squeezed with 50 sx class G • s TOC in 4-1/2" liner at 12,100',3bbls cement on top Retainer at 12,302' >.-1 ' s of retainer > 1> 1..[4. <•s Packer at 12,700'± Perforations 12,834'—12,874', squeezed with 76 sx class G •>'" ' Retainer at 12,895' PP9 ••�_1••� Packer at 12,900'± 15. mud Perforations 12,963'—13,050', squeezed with 145 sx class G • 44----". through retainer 41 ._7\s, PBTD at 13,248', 4-1/2" 15.1#,S-95 casing at 13,295', cemented with 317 sx class G TD— 13,298' Point Thomson Unit#1 Proposed Most-Likely Sketch Nalliti Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday,April 07, 2014 4:27 PM To: 'Winter, Cassondra E';Juranek,Tom A Subject: RE: PTU 1 (PTD 176-085) You have verbal approval to modify the P&A as proposed in the new sundry submitted. The existing 130 ft surface plug is acceptable in the 9 5/8"casing. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office Original Message From:Winter,Cassondra E [mailto:cassondra.e.winter@exxonmobil.com] Sent: Monday,April 07,2014 3:04 PM To:Juranek,Tom A;Schwartz,Guy L(DOA) Subject: RE: PTU 1 Guy, Please find attached a copy of the Sundry Change Approve Application for PTU#1 that was dropped off on April 1st. The package was dropped off at the admin desk with attention to Victoria Furgerson. Thanks, Cassondra Winter Remediation Project Manager ExxonMobil Alaska 3301 C Street,Anchorage,AK 99503 Phone: 907-564-3729 Cell: 907-231-0312 Email: Cassondra.e.winter@exxonmobil.com Original Message From:Juranek,Tom A Sent: Monday,April 07, 2014 2:34 PM To:guy.schwartz@alaska.gov Cc:Winter,Cassondra E Subject: PTU 1 III Guy, Cassie Winter is going to send you an email copy of the revised 10-403 for the PTU 1. If acceptable you could just reply to her with a verbal approval. 1 Thanks, Tom Juranek 832-596-5406 2 Schwartz, Guy L (DOA) From: Sent: To: Subject: ExxonMobil Point Thomson Unit #1 Daily Report: Peterson, James M /C <james.m.peterson@exxonmobil.com> Wednesday, April 16, 2014 4:12 PM Dennis Collins; Schwartz, Guy L (DOA); Bill Penrose; Winter, Cassondra E; DOA AOGCC Prudhoe Bay; Greene, Timothy L; Cox, Mirick T; Juranek, Tom A; Hawthorne, Brian K; Emmett, Cody; Farrar, Kendall N; Denman, Erika /C; Dragnich, Rob /EXT; SXP Hagberg; SXP McGeehan; SXP Steve Lewis RE: Point Thomson Unit #1 Daily Report 4/14/2014 Completed dressing up final cut took photos, completed welding marker plate, took photos. Final Report on Well. 4/13/2014 HSM, Completed cutting off 9-5/8", 13-3/8" & 18" casing to dress out for installation of marker plate. 4/12/2014 HSM, pumped cement top job in 9-5/8" and 13-3/8" casings. SDFN 4/11/2014 No Activity, casing top job scheduled 4/12/2014. 4/10/2014 No activity well ready for top cement job planned for 4/12/2014. 4/9/2014 HSM, use Wachs cutting off 13-3/8" and 9-5/8" casings, remove WH. Install 1" down 9-5/8" and 13-3/8" casing for planned cement top job on 4-12-2014. SDFN 4/8/2014 HSM, Completed cutting off 36", 32" & 28" annulus. MIRU Wachs Saw 4/07/2014 No Activity 4/06/2014 No Activity 4/05/2014 No Activity 4/4/2014 No Activity 4/3/2014 1 No Activity 4/2/2014 No Activity 4/01/2014 Turn into AOGCC new sundry for review and acceptance. 3/31/2014 MIRU Schlumberger & Peak Vac Trucks. Bull Headed cement down 13 3/8" annulus (injection rate 3.5 bbl/min at 225 psig & 215 bbls of cement pumped). Shut in annulus, RD & SDFN. 3/30/2014 No Activity 3/29/2014 Re -located cement silo onto location. 3/28/2014 MIRU Little Red Hot Oiler onto 13 3/8" annulus valve. Pressure tested high pressure hose to 2,500 psig. Open up annulus valve and Bull Headed hot diesel down the 13 3/8" annulus at rate of 5 bbl/min with pumping away 20 bbls at 600 psig. RD Little Red and SDFN. 3/27/2014 Completed snow removal from location & continue with heat on well head. 3/26/2014 Continue snow removal on location. Excavation around well head to expose 13 3/8" annulus valve. Placed heater near excavation, placed heat onto well head & wrapped. 3/25/2014 Re -located dozer to location and commence snow removal on location. Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, March 14, 2014 4:07 PM To: 'Juranek, Tom A' Cc: Collins, Dennis /C; Greene, Timothy L; Peterson, James M /C; Farrar, Kendall N; Winter, Cassondra E; Cox, Mirick T; Dragnich, Rob /EXT; Denman, Erika /C; Bill Penrose (bill@solstenxp.com) Subject: RE: Addendum to Procedures for West Staines State #18-9-23 (PTD 069-120, Sundry 313-604), West Staines State #2 (PTD 175-002, Sundry 313-606), Staines River State #1 (PTD 179-001, Sundry 313-605), and Point Thomson Unit #1 (PTD 176-085, Sundry 313-600) Tom, Thanks for the amended PT procedures. This new lower "master valve " will take care of the concerns that were identified. ` - "-,% approval to pressure test (2500 psi) against the 9 5/8" casing for W Staines State #18-x-23 for verification of flange breaks during routine BHA change -outs. All the other following P &A wells must have tl�e new 11" test valve installed. I will print out the attached addendums and add them to our well file. x:.,.17..- . . . Senior Petroleum Engineer 907-301-4533 cell 907-793-1226 office SCpNpED 0 GT 0 0 20 From: Juranek, Tom A [ inek(d)exxonmobil.cc ] Sent: Friday, March 14, 2014 1:14 PM To: Schwartz, Guy L (DOA) Cc: Collins, Dennis /C; Greene, Timothy L; Peterson, James M /C; Farrar, Kendall N; Winter, Cassondra E; Cox, Mirick T; Dragnich, Rob /EXT; Denman, Erika /C; Bill Penrose ( ) Subject: Addendum to Procedures for West Staines State #18-9-23 (PTD 069-120, Sundry 313-604), West Staines State #2 (PTD 175-002, Sundry 313-606), Staines River State #1 (PTD 179-001, Sundry 313-605), and Point Thomson Unit #1 (PTD 176-085, Sundry 313-600) Guy, Following up on our discussion in your office on Tuesday, March 11, 1 am sending you addendums to our procedures concerning our BOP pressure testing. Attached are addendums for each of the remaining wells that we are planning to work on this winter season. Please let me know if these addendums are approved or if you need further information or clarification. In addition, we are also seeking permission to deviate with our BOP testing on the WSS #18-9-23 as we did on the PTU #2 (BOP test against our test plug with break tests of only 2,500 psi against the 9-5/8" casing) until the "Testing Valve" arrives and can be installed and tested. We have located and are mobilizing the extra 11" 10k rare that we will use as our "Testing Valve". However, we will most probably have moved our Coiled Tubing Unit to the WSS #18-9-23 and be ready for operations 2-3 days prior to the valve arriving. Once we have the Testing Valve, we will follow the addendums. Please respond on approval of the addendums and for the deviation until the testing valve arrives. I appreciate your time on Tuesday and your assistance to make our remediation campaign a success. Please let me know if you have any questions or need anything further. Thanks, Tom Juranek Subsurface Engineering Advisor EMPC Global Engineering -Houston Subsurface Engineering & Operations Support CORP -EMB -3021) Lync Phone: 832-624-6940; Fax: 713-656-7353; iPhone: 832-596-5406 email: tom.a.iuranek@exxonmobii.com POINT THOMSON UNIT #1 Sundry # 313-600 API # 50-089-20005 APTD#: 176-085 Addendum - Pressure Testine Procedures (Refer to wellhead and BOP diagram below) Initial BOP test and subsequent 7 -day BOP tests: 1. Close the 11" 10k "Testing Valve" and pressure test from the testing valve to the choke manifold to 8,000 psi. 2. Close Drilling Spool Gate Valves and "Testing Valve" and Pressure Test the CT BOP rams to 8,000 psi as per SLB Procedure (Note: 11" equipment are tree valves and not BOPS) a. SLB Combi BOPS b. SLB Quad BOPS Break Tests: 3. Close the 11" 10k "Test Valve" and pressure test across the broken connection. a. Prior to Drilling of surface plug (cement and/or CIBP), test to 8,000 psi. b. After verifying no pressure below plugs, test to 3,000 psi. 11", 10k Rams Used as Tree Valves 4-1/16", 10K Coil BOR System iii iii iii iii iii iii DSA -11" 10k X 4' 10k 11" 10k SPACER SPOOL 11" 10k DRILUING SPOOL WITH 2" 10k MANUAL GATE VALVES 11" 10k SWAB VALVE W/ BUND/SHEAR RAMS 11" 10k MASTER VALVE W/ STRAIGHT BLIND RAMS 111'10K TESTING VALVE W/ STRAIGHT BUND RAMS (RAM BODY AND RAMS INSTALLED UPSIDE DOWN) D SLB r Combi BOP's • 0 �y\177;4 THE STATE A': a 1 a P----- --5----- ,\,.r I getnz tt ,_�__ — 333 West Sevensh Avenue ,, �� GOVERNOR SEA cr PARA,1-1 i n"c1,5\ ' Anchorage, Alaska 99501 3572 �, Ti Mein 907.279 1/33 e- Irene T. Garcia SC#4.9° SSHE Manager r 0 c65-�, ExxonMobil Oil Corporation 17"f PO Box 196601 Anchorage, AK 99519 Re: Point Thomson Unit, Point Thomson Unit#1 Sundry Number: 313-600 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, 7212 -)74, -- 'U Cathy P. r oerster Chair DATED this day of December, 2013. Encl. - \)‘&' RECEIVED STATE OF ALASKA ‘10 NOV19 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION i 2 20( 1 a APPLICATION FOR SUNDRY APPROVALS AOGC 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: FK-t Scut,/, PSA [Y 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Exxon Mobil Corporation Exploratory 0 ' Development ❑ 176-085 3.Address: Stratigraphic El CI6.API Number: /2.4.1,3 PO Box 196601,Anchorage,AK 99519-6601 50-089-20005-0000 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 O Point Thomson Unit#1 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 47560 ' Point Thomson Unit 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13,298 . 13,298 • 0 0 Many plugs,see schematic None Casing Length Size MD TVD Burst Collapse Structural 61' 28"x 36" 83' 83' N/A N/A Conductor 779' 18-5/8" 801' 801' 2,420 780 Surface 3,254' 13-3/8" 3,276' 3,276' 3,450/5,380 1,950/2,670 Intermediate 9,510' 9-5/8" 9,532' 9,532' 6,820 4,230 Production 7,390' 7" e. yot ' Q 11,390' 11,390' 11,830 11,650 Liner 2,422' 4-1/2" P''' . 13,295' 13,295' 12,450 12,300 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory Q Stratigraphic❑ Developmen❑ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: February 1,2014 ' Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned 2 • 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 SignaturePhone Date �� 907-564-3773 /eft..r/ 13_ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: c-r 3V3 —Loo Plug Integrity [J' BOP Test Tr Mechanical IntegrityTest ❑ [ 'Location Clearance Vl y Other: p S. g OC )�5i. / D 7 , f ! 5� ! � do u- ca5i j cwnt?j £ lAielit� P/ . (� RBDM-4•-= MAY 0 9 2014 Spacing Exception Required? Yes Ci No D Subsequent Form Required: /o — l 0 7 APPROVED BY �� Approved by:(I/ i;.,e,,,,,,(4.___ _ COMMISSIONER THE COMMISSION Date: /Z Z-nn — /3 /2 13 /# iSWI> `� App 0 RIGINA pp Subs in Form and V )\ Form 10-403(Revised 10/2012) ro a onths from the date of approval. Attachments in Duplicate 111 ExxonMobil Production Company P.O.Box 196601 RECEIVED E Anchorage,Alaska 99519-6601 907 561 5331 Telephone N O V 19 2013 EonMobil �®GGC Production November 15, 2013 R-2013-OUT-025 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#1 (PTD No. 176-085) Dear Commissioner Foerster, ExxonMobil hereby applies for Sundry Approval to perform plugging and abandonment work on the subject well. The work is described in more detail on the attached Summary Procedure. The general procedure objectives will be: 1. Drill through the surface cement plug(15'—130'). 2. Place cement isolation in the 9-5/8" casing and 9-5/8" x 13-3/8" casing annulus near the 13-3/8" shoe. Methods to accomplish this include: a.Bullheading cement down the 9-5/8"annulus to±3,276', setting a CIBP in the 9-5/8"casing at ±3,400', and laying cement in the 9-5/8"casing from ±3,400'to±2,800'. b.Circulating cement into the 9-5/8"casing and annulus through perforations in the 9-5/8"at±3,200'. The 9-5/8"casing and annulus would be cemented from ±3,200' to surface. c. Squeezing the 9-5/8" annulus through perforations at±3,200'. The annulus would be cemented from ±3,276'to±3,200' and the 9-5/8"casing would be cemented from ±3,200'to±2,800'. d.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±2,800'. 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 lication Form 10-403 • Proposed Work Procedure including before and after wellbore diagrams If you have anyquestions or require additional information, please contact me at (907) 564-3773 or Tom q Juranek at 713-656-4225. Sincerely, JI‘'vt.1 16544 -40: Irene T. Garcia SSHE Manager Attachments: • Sundry Application Form 10-403 • Proposed Work Procedure including before and after wellbore diagrams POINT THOMSON • 14 PRODUCTION POINT THOMSON UNIT#1 WELL HISTORY AND ABANDONMENT PROCEDURE Affected Wells and API/APTD Numbers: Point Thomson Unit#1 API # 50-089-20005 APTD#: 176-085 Background: Point Thomson Unit #1 was drilled in 1977. The well was suspended on December 8, 1977. 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 13-3/8"shoe at 3,276'. 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±15'-±130'. • Place cement isolation plugs in the 9-5/8" casing and annulus near the 13-3/8" shoe. Methods to accomplish this include: 1 c o Bullheading cement down the 9-5/8" annulus to ±3,276', setting a CIBP in the 9-5/8" • a 58Bi/� casing at±3,400', and laying cement in the 9-5/8"casing from ±3,400' to ±2,800'. e 3776 o Circulating cement into the 9-5/8" casing and annulus through perforations in the 9-5/8"at ✓� ±3,200'. The 9-5/8"casing and annulus would be cemented from ±3,200' to surface. ggv o Squeezing the 9-5/8" annulus through perforations at±3,200'. The annulus would be cemented from ±3,276'to ±3,200' and the 9-5/8" casing would be cemented from ±3,200' to±2,800'. 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 ±2,800'. • 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#1 Abandonment Procedure .� POINT THOMSON 6 PRODUCTION The proposed abandonment will be supported by on-site equipment and materials such as excavator, camp, fuel, and other essential elements of remote operations. The following well abandonment program is planned: 1. Insure all necessary permits and applications are in place. Notify AOGCC at least 10 days before operations begin. 2. MI and prepare location. Record pressures on the 9-5/8" casing and annuli. Bleed off any found pressure. 3. If possible, keeping pressure no higher than 2,500 psi, bullhead cement down the 9-5/8" x 13-3/8" casing from surface to the 13-3/8" shoe at±3,276'. 138L,S 151?1--/fr.) 4. Remove the 13-5/8" 5K psi B section spool, 13-5/8" 5K psi cap, and marker post. Measure the depth to the cement in the 9-5/8" casing (expect±15'). 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 Si. 1' �s� 14 �-�- ,fir. p c--(c-1(- 5. (c-- - -� 5. Notify AOGCC of planned BOP testing and confirm steps to be witnessed throughout zsp�� )-- 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 ±15' -±130'. 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" shoe at ±3,276'. If successful, set a 9-5/8" CIBP at±3,400' and lay cement in the 9-5/8" casing from ±3,400' to ±2,800'. 11. If bullhead attempts were unsuccessful, perforate the 9-5/8" casing at±3,200' 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±3,250' in the 9-5/8 casing and circulate cement from ±3,200' 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±3,200' to the 13-3/8" shoe at±3,276'. If able to squeeze, set a CIBP at±3,250' in the 9-5/8" casing and squeeze cement from ±3,276' to ±3,200' in the 9-5/8" annulus and from ±3,200' to ±2,800' in the 9-5/8" casing. 13. If unable to circulate or squeeze with perforations in the 9-5/8" casing at±3,200', repeat steps 11 and 12 with additional 9-5/8" perforations at±3,000'. Point Thomson Unit#1 Abandonment Procedure9Z POINT THOMSON • 6 PRODUCTION 14. If unable to squeeze into perforations at±3,000', 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±2,800' 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 ±2,800'. 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#1 Abandonment Procedure . , ,. page a Of 4 • POINT THOMSON 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#1 Exxon Mobil Corporation PTD# 176-085 API # 50-089-20005 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#1 Abandonment Procedure Page 4 of 4 POINT THOMSON 14 PRODUCTION Exxon Mobil Corporation Pt. Thomson Unit#1 API#: 50-089-20005 PTD#: 176-085 Current Well Schematic Wellhead A and B sections with blindflange and marker post on top .. , Diesel TOC at 15'below ground level 44 1 ': Bottom cement plug in 9-50 casing at 130' ' -> • 18-5/8"at 801' s 10 5 ; 13-3/8" x 9-5/8'Annulus >p' x i CaCC- Arctic Pack from 0' - 1,807' m. " Arctic Pack Premix from 1.807'-2,668' , , Diesel from 2668'-3.529' P. a ,s 13-3/8", 72#, N-80 at 3,276' 2 ,s.,.„...-...,.,—.—...,,,,.,..,.,..,.„1 ,_ 3,500' mud/CaC12 interface z Top 7" casing 4,000'± s 4 15.3 ppg mud 4 15.6 ppg mud _Z TOC behind 9-518 casing at 6,900' z zL7". 35#,Tieback cemented with 120 z., Sx Class G z ,i , .. ; 19-75%7,1' at 9, ' G Qe v ,, 40 liner#, S-95 032at 9,532'-i ►�""�� TOC at 10,740"± in 7" casing Retainer at 11,250'with 50 Sx cement on top --- -- --- TOP 4-112`° liner at '10,873' Packer at 11.300'± 4 7Y. 35#, S-95 at 11,390' Perforations 11,392'- 11,421'. - squeezed with 50 Sx class G TOC in 4-112" liner at 12.100', 3bbls cement on top Retainer at 12,302' k k of retainer < Packer at 12,700'± Perforations 12.834'- 12,874', ? - 1 squeezed with 76 Sx class G 4-- C".rRetainer at 12,895' " 15.6 ppg mud Packer at 12,900'± Perforations 12,963'- 13,050', ,- ..._. squeezed with 145 Sx class G , __-- through retainer 4 ,e a PBTD at 13,248',4-1/2" 15.1#, S-95 at ` Total Depth 13,298 13,295', cemented with 317 Sx class G Point Thomson Unit#1 Current Sketch : ,yy. Y POINT THOMSON 4te, PRODUCTION Exxon Mobil Corporation Pt. Thomson Unit#1 API#: 50-089-20005 PTD#: 176-085 Proposed "Most-Likely" Post-P&A Well Schematic Marker Plate--3' below tundra ' -' Cement in 9-5/8"from ±200'to surface Perfs in the 9-5/8"csg at±200' 5� �• �"" '~ I •, 1 9-5/8"Bridge plug at±200' ' 18-5/8"at 801' • , 13-3/8"x 9-5/8"Annulus: •- 10.6 •Cement from surface to±200' fir;``• CaCl2ppg ••Arctic Pack from±200'–±1,807' 4 •Arctic Pack Premix from±1,807'–±2,668' Perfs in 9-5/8"at±3,200' g • Diesel from±2668'–±3,200' t R'''.9:4' '4 •Cement from±3,200'to±3,276' Cement in 9-5/8"from ±3,200'–±2,800' ' 1 �3 13-3/8", 72#, N-80 at 3,276' 9-5/8"Bridge plug at±3,250' Top 7"casing 4,000'± 4 ' 15.3 ppg s TOC behind 9-5/8"casing at 6,900' s, mud ' `7 ",35#,tieback cmtd w/120 sx Class G =' ", Top 7"liner at 9,032' �' " 9-5/8",40#,S-95 at 9,532' ' • • TOC at 10,740'±in 7"casing 0 ' TOL 4-1/2" liner at 10,873' Packer at 11,300'± Perforations 11,392'–11,421', 7", 35#, S-95 at 11,390' squeezed with 50 sx class G ", " s TOC in 4-1/2" liner at 12,100',3bbls cement on top Retainer at 12,302' �,• y ,.y of retainer '' _�" Packer at 12,700'± Perforations 12,834'–12,874', , squeezed with 76 sx class G s Retainer at 12,895' 15.6ppgmud ••A, :i_t".k.•y Packer at 12,900'± Perforations 12,963'–13,050', — y squeezed with 145 sx class G : through retainer 4 ' ' V PBTD at 13,248',4-1/2" 15.1#,S-95 casing at 13,295',cemented with 317 sx class G ' TD–13,298' Point Thomson Unit#1 Proposed Most-Likely Sketch "`x '-' POINT THOMSON (k PRODUCTION BOP Configuration • 4( ...*r { 1 )i, _ Il J injector Head for 2"` coiled tubing M .ft 11 11' Dual pack-off ii --- 4.05u ID, 10k Lubricator as needed 16' &8' sections} �• BCind et :11 lL: iill shear SLB Quad BOP, 10k if 1itSlips I:: pipe 7 f _ 11 SLB Com bi BOP, 10k it �. +4a _* - 11", 10kx 4 1/16",10k x-o — (flange to be used for BHA changed if, 10k Spacer Spool,3 ft if, 10k Flow/cross vow ....-JI II 1 10 f • -- 11-.101/4 Blind Ram r l • } -- 11",10k Blind/Shear Ram -- Vi,'ellheads to be upgraded to 10 k service Point Thomson Unit#1 Planned BOP Assembly 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 pro 1 742-O$ S Attachments: WSST8-9-23 Isolation Sleeve.pdf 7 V P7`�it - 1 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 w6.177---( 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) [maIto:quy.schwartz alaska.gov] Sent: Wednesday, December 04, 2013 2:04 PM To: Juranek,Tom A Subject: PT-1 PT-2 and Staines River State #1 Tom, From what I read these wells(PT-1, PT-2 and Staines River St.#1) are also using the same type of extended packoff in order to upgrade to 10K? Is the same packoff being used? What about West STaines ST.#18-9-23? That appears to have a different isolation sleeve into the existing tubing head. If so please forward the diagrams for that for our files. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 1 O I CO b� 0 I) I I �/ 0 as rr) • 0 4__- — U) I� Q N U 00 InN M,-0 O D L noinowa ;_� J r Y LI) Q_ _ N as Q --00 OI 2 00 N C L) v.' -0+-2 Oc CO OO LO H r 0 � It V - - Y NOD ti � ----- I— N - ? ! II I0_ u) a) (Ti p N Z Q L I ✓✓ -it II�� >~ i - `j - ami z il Q 1d 2 U a) 00 co)I Z Win n ' _ rn I _ r "_J :i7 � a 0 J O Q LU Icd cn ________ z j_t_z r I - h I II i W ( i i _ i, , i 7 li t y _J Q I I- 1 � w I > 0 �- 0 s RECEIVED STATE OF ALA OIL AND GAS CONSERVAT ON COMMON 2013 � REPORT OF SUNDRY WELL AOGCC 1.Operations Abandon LI Repair Well U Plug Perforations U Perforate [i Other U Inspection Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Exxon Mobil Corporation Development ❑ Exploratory IS 176.085 • 3.Address: PO Box 196601 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6601 50-089-20005-0000 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 47560 Point Thomson Unit#1 . 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Point Thomson • 11.Present Well Condition Summary: Total Depth measured 13,298 feet Plugs measured See Attached feet true vertical 13,298 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 ND Burst Collapse Structural 61' 36"x 28" 83' 83' N/A N/A Conductor 779' 18-5/8" 801' 801' 2,420 psi 780 psi Surface 3,254' 13-3/8" 3,276' 3,276' 3,450/5,380 psi 1,950/2,670 psi Intermediate 9,510' 9-5/8" 9,532' 9,532' 6,820 psi 4,230 psi Production 7,390' 7" 11,390' 11,390' 11,830 psi 11,650 psi Liner 2,422' 4-1/2" 13,295' 13,295' 12,450 psi 12,330 psi Perforation depth Measured depth N/A feet True Vertical depth N/A feet i.La , A 1 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 El • Development❑ Service ❑ Stratigraphic ❑ Daily Report of Well Operations See Attachment 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP p• 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 4 Contact Tom Juranek(713-656-4225) Email tom.a.iuranekRexxonmobil.com Printed Name Irene T.Garcia Title Alaska SSH&E Manager Signature 4,"..,e / `L/ Phone 907-564-3773 Date 9/19/2013 L HSl MS OCT 11 10 Form 10-404 Revised 10/2012 ��/ �<'.0, Submit Original Only ExxonMobil Production Com. Ire arcia „wn D P.O.Box 196601 SSH& anager Anchorage,Alaska 99519-6601 :r- qi 4 n ,r 907 564 3773 Telephone 907 564 3719 Facsimile i 1 , EonMobil Production September 19, 2013 R-2013-OUT-008 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#1 (PTD No. 176-085) 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, '4°4.4 14(24-Cti; IG:ed:gg Attachment A Division of Exxon Mobil Corporation • • Exxon Mobil Corporation Pt. Thomson Unit#1 Well Schematic API #: 50-089-20005 PTD#: 176-085 Wellhead A and B sections with blind flange and marker post on top 28" x 36" insulated Ar Diesel .r TOC at 15' below ground level conductor set at 83' cti :. t. 4 P P Bottom cement plug in 9-5/8" casing at 130' k k 's (105' BGL estimated) 13-3/8" x 9-5/8"Annulus z, Pr P s Arctic Pack from 0' - 1,807' ; e 10.6 ppg e ,s 18-5/8" at 801' Arctic Pack Premix from 1.807' - ?„vni CaCl2 s 2.668 x x .;s Diesel from 2668' -3,529' ., i s "' zy. . ..s s 13-3/8", 72#, N-80 at 3,276' s z s w -U--�ti��w—�� -4 . — 3,500' mud/CaCl2 interface t sz Top 7" casing 4.000'_ s ; 15.3 ppg mud TOC behind 9-5/8" casing at 6,900' • z 15.6 ppg mud s 7", 35#.Tieback cemented with ;, 120 Sx Class G Ap I z Top 7" liner at 9.032' 9-5/8", 40#, S-95 at 9.532' Retainer at 11,250' with 50 Sx cement on top . , TOC at 10,740't in 7" casing ' -Pl TOP 4-1/2" liner at 10,873' ..► 41 ►�� " Packer at 11.300'._ '' 7", 35#, S-95 at 11.390' Perforations 11,392' - 11,421', ____ . .s squeezed with 50 Sx class G i' S i" , s / s TOC in 4-1/2" liner at 12,100', 3bbls cement on top of Retainer at 12,302' �..r s s retainer 11'■4 ►�� s Packer at 12,700'+ s Perforations 12,834' - 12,874', •,s PBTD at 13,248'.4-1/2" 15.1#. S-95 at squeezed with 76 Sx class G s 13,295', cemented with 317 Sx class G s •"s Retainer at 12,895' Total Depth 13,294. � ►Z1 .,s Packer at 12 900'1 15.6 ppg mud 5E174 Perforations 12,963'- 13,050', s squeezed with 145 Sx class G z through retainer ,._ Well schematic is prepared by Fairweather E 8 P Services, Inc. Last update May 13,2009. • • Point Thomson Unit #1 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. 08-11-13: Arrived on location @10:12. Excavated around casing valve and installed pressure gauge to bleeder valve. Found "0" pressure on 9 5/8" and 9 5/8"X13 3/8". Removed bent LDS and gland nut from tubing spool. Ran camera through gland nut port in TS, could not see top of casing due to fluid presence. Replaced LDS with blanking plug. Removed LDS/gland nut from casing head. Pack off present. Replaced LDS. Pressure tested 9 5/8" packoff seals to 1500psi. Leaked off 300psi in 10 minutes. RU plastic packing gun, pumped plastic. Re-tested to 1500psi, 100psi drop after 30mins. Good test. Estimated 4-6 inch casing stub present above CH, CH assbly# B562090. RD, secured valves, filled excavation. Removed small piece of visible liner for edge of pad, conducted stick pick. 2013 Site Inspection Point Thomson Unit#1 • • i • •. 4.., S ,.‘1.:,'4:--`,4,,,,',-7.:4.,.., *S r • y r y � »it` t �� ` W ,,,,**-;!.?:.'c f r 9J �._ 4 4 -. ., .: . ,. � t, pr p 1 ,•nH , Q4', eon' °� ../ 'iA. -` x ! # � c % , i� a - Y'w � ','t x � : n,,.. P T1 -.44 . 4 y ;%34 . Y I �i F • „ 'y ' Y �ti. �. ^• .� y - •/.s '? ck.S .' Q; 1,ir '$ .', ,,..a lx PTU #1 as found. r t v I a r 1 S`� i ( ? £ 4 ate # 1. 1. Y-{- t. r r 1 / wr • 1< 1 ,pp L t .'-4e PTU #1 Pressure Test - 0 psi 2013 Site Inspection Point Thomson Unit#1 . • • ' . itAllibe-7iiielt''--:, +�' t 7 it ;• .\ : 1.r<' . fir�.p- .. Removal of LDS in Tubing head f;442-: ,.., 4 ‘ - -, W , ?"4R' ,e _ Camera Run 2013 Site Inspection Point Thomson Unit#1 • • - V+f ..'4 .,•. �.S I �l i M 7 • 0-- .gym: 9 5/8" Pack Off Test (Good) • 1s, i $:r�w �y� 6 a 0/ . - -,..--"0. .011 , ..1'.,:' ',., , —*, ..'"*....= _ A c.r... :. . . . ,_ • „.. _.... ,...:,..: . it, i ,..:___ _ _.... . , _.. „..:1„,,,,...... • .4,_:,..„..,....„... .,. . ...„,____....,...„...._,„4 .,. Ir.:, . ,...„...,. ...i.?„,....,,,,..: ,._.-„,,,-_,. .1,-4;..,,,,r-:-,,,,-%::-. ..,-.„-- rr ,` ? .NY C `1 04��, 7'- - x - a aN Well as Left 2013 Site Inspection Point Thomson Unit#1 • • McMains, Stephen E (DOA) From: Schwartz, Guy L (DOA) PT D 1 -1 1^ ~ g 8,5 Sent: Monday, April 01, 2013 9:27 AM `E+' 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 Unit #2 (PTD 177 -064) Staines River State #1 (PTD 179 -001) SCANNED APR 1 7 2013 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 (I ` C /�rl Senior Petroleum Engineer AOGCC FINNS APR 012013 907- 444 -3433 cell 907 - 793 -1226 office From: Wong, Gilbert [ mailto :gilbert.wongexxonmobil.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: 1 • • 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.wong@exxonmobil.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 P. O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimile September 23, 2009 Commissioner Cathy P. Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Alaska Production (diansger I Joint Interest U.S. 1 Production I RE: Request for Verification of Suspended and Shut-in Well Information Dear Commissioner Foerster: SEP 2, 4 2009 f'� SPE» Nm—" " p By letter dated January 29, 2009, the AOGCC requested verification of information regarding suspended long-term shut-in wells listed as operated by ExxonMobil or predecessor companies. The lists of Suspended and Shut In Wells attached contained a total of eleven wells. We have no revisions to the information for the Kuparuk 28243 1 well which is located within the Kuparuk River Unit operated by ConocoPhillips. As with your records, we understand that the Starichkof St 1 well was operated by Pennzoil, not by ExxonMobil or a predecessor company, and the lease and well currently is within the Cosmopolitan Unit operated by Pioneer. With respect to the 9 Point Thomson area wells, a sundry notice report was filed with the AOGCC on June 1, 2009, describing the location and well inspection and remediation work performed in March and April of this year. A copy of these reports, along with a summary of the well status is attached for your reference. Please advise if there is any further information we can provide in conjunction with this response. Sincerely, DDP:jpc Enclosures xc: Mr. Tom Maunder — AOGCC SCANNED OCT 0 9 Zaj4 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 J Location and Well inspected 3/2009. /7(� '�XY�5 Location and Well inspected 4/2009. 1 % 7• a & 7 Id Location and Well inspected 4/2009. /I ()0� Location and Well inspected 4/2009. -%9• &'/&-� Further remediation work planned for the 2009-10 winter season Location and Well inspected 4/2009.,�� • a�lj Well inspected and remediated and site cleared in 4/2009. �• Q� e Location and Well inspected 4/2009. % 7 9• / Location and Well inspected 4/2009. �� -,;z Further remediation work planned for the 2009-10 winter season Well is located on former ADL 0028377 Location and Well inspected 4/2009. Further remediation work planned for the 2009-10 winter season ~~~~es~'rm~at ~a~e6ucti~rs Caesr~ar~~+ Joint interest U.S. - Alaska P.O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3789 Facsimile June 17, 2009 y ~ ~+' V `~+~. ,~., ~'~ ~,~~~ ~ ,.'i_1N ~; ~ ii~(J.9 '~08.S~f~ ~~i ~T~ r« a~* •5`~~' i.l91tY:. (~'.Gi'17RlIS$%Q4~ E o n M a b i~~~~r~~~ ~ ~~o~~~~~~n ~ C~C-~ c~ccn.~-- ~ sr~ Mr. Johnny L. Aiken, Director ~ i ~~ ~~ ~~~ North Slope Borough Planning and Community Services Department 1~a- P.O. Box 69 ~~~~~ Barrow, Alaska 99723 Re: Tundra Travel Completion Report I~~r ~~~ O~ ~yri~~,,~'~ --~'~pm5 Dear Mr. Aiken: ~0t~~ ~ Please find attached our 2009 Winter Tundra Travel Completion Report as required by North Slope Borough Conditional Use Permits. This Tundra Travel Completion Report pertains to the following activities authorized by the above permits: - Ice Road Construction from the Endicott causeway to the Point Thomson Unit Central Pad - Ice Road Construction to the Alaska State C-1 water source and other lakes from which water was withdrawn. - Tundra Travel /Ice Road Access - Point Thomson Unit Central Pad Mobilization & Construction - Well Inspections and Remediation The attached report reflects Tundra Travel activities through closure of the Alaska State C-1 ice road on May 19th, 2009, and includes the following elements: 1. Actual routes of travel and the location of all camps depicted on USGS topo maps 2. List of vehicles for off-road travel that has taken place 3. Statement of cleanup activities 4. Method of disposal of garbage and other camp debris 5. Report of known incidents of tundra damage and follow-up corrective actions A Division of ~xxo~ tN~be6 ~opp~~°atioro 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, ~~ . ~~~.~ ~ Mike Barker Environmental & Regulatory Manager KDC:eaa Attachments cc: Lori Aldrich, ADEC Gordon Brower, NSB Nina Brudie, DNR Larry Byrne, DNR DMLW Steve Davies, AOGCC Josephina Delgado-Plikat, DNR John Easton, DNR DOG Gary Evans, ADEC Susan Harvey, Harvey Consulting Lee Kayotuk, Kaktovik Tom Maunder, AOGCC William Morris, ADFG Craig Perham, USFWS Matt Rader, DNR DOG Barrett Ristroph, NSB Gary Schultz, DNR DMLW Roy Varner, NSB Waska Williams, NSB Ryan H. Winn, USACE Jack Winters, ADFG ExxonMobil Production Company Alaska Interest - Joint Interest U.S, P.O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone June 1, 2009 Mr. Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Report of Sundry Well Operations Exxon Mobil Corporation Point Thomson Unit #1 PTD No. 176-085 Sundry No. 309-083 Dear Commissioner Seamount: E~~nMobil Production r~~~~~~~~~~. ~ ~r,,,f., ~;~~ s ~ ~°_t~~s~t ~'~d~9Yi~Q ~iN Mi L~2o~ ~+6:€~:~~y i. i`.:;'!:! ~3:, ~~t~~~;~~~ Exxon Mobil Corporation hereby submits its Report of Sundry Well Operations for the wellhead inspection of the Point Thomson Unit #1 well on the North Slope. The well is currently suspended and the inspection was per~ormed at the request of the AOGCC in accordance with suspended well regulations. ~~~ ~~~€~_ ~~ ~~~~~~ During the wellhead inspection operation, the wellhead was exposed by excavating the gravel cover. The wellhead was visually inspected, and the well integrity was verified by checking for and recording pressures in the 9-5/8" casing and the 9-5/8" x 13-3/8" annulus; zero pressure was • recorded in the casing and fhe annulus. Two new gate valves were installed on the wellhead side outlets. At the end of the well inspection the top wellhead section was left above grade level to allow easier access for future wellhead inspections. Both new valves handles were left chained and ~ locked to prevent tampering. Attached please find: Form 10-404: Report of Sundry Well Operations Daily Report of Well Operations Wellhead drawing Wellbore diagram Well pfat Photographic documentation of the well If you have any questions or require additional information, please contact me at 907-564-3617. Sincerely, ~ , ~.~......_ D. Michael Barker Environmental and Regulatory Manager JAR:eaa Attachments A Division of Exxon Mobil Corporation ~~~~~~~~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ ~ ,~. ~~~~ REPORT OF SUNDRY WELL OPERATION~S~~ ~i~ ~~~~ ~~~~µ ~~y~rn'~s~nx4 1. Operations Abandon Suspend Operation Shutdown Perforate Waiver Other ~ Performed: Alter Casing ~ Repair Well ~ Plug PerForations ^ Stimulate ^ Time Extension ~ Well Inspection , Change Approved Program ^ Pull Tubing ^ Perforate New Pool ~ Re-enter Suspended Well ^ 2. Operator Exxon Mobil Corporation Name: 4. Current Well Class: + 5. Permit to Drill Number: ' ' ~ ~~_~~s -~ Development ^ Exploratory ^~ --a-t - ~ ~.~.c~ 3. Address: P.O. Box 196601 Stratigraphic ~ Service ^ 6. APl Number: Anchorage, AK 99519-6601 50-089-20005 " 7. KB Elevation (ft): 9. Well Name and Number: 33 ' Point Thomson Unit No 1 ~ 8. Property Designation: 10. Field/Pool(s): ADL 47560 . Point Thomson > 11. Present Well Condition Summary: Total Depth measured 13, 298 feet Plugs (measured) Plugged at surface true vertical 13,298 feet Junk (measured) N/A Effective Depth measured 0 feet true vertical 0 feet Casing Length Size MD ND Burst Collapse Structural 61' 36" x 28" 83' 83' N/A N/A Conductor 779' 18 5/8" 801' 801' 2420 780 Surtace 3254 13 3/8" 3276' 3276' S380/3450 2670/1950 Intermediate 9510 9 5/8" 9532' 9532' 6820 4400 Production 7390 7" 11390' 11390' 10580 11600 Liner 2422 41/2" 13295' 13295' 12450 12760 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): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Well Photographs Exploratory ^~ ry Development ^ Service ^~ Daily Report of Well Operations See attachments 16. Well Status after proposed work: nd . ~k ~~ 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: 309-083 Contact Mike Barker Printed Name Mike Barker Title Environmenta! and Regulatory Manager Signature ~~~,`~"' Phone 564-3617 Date '3 i ~`~ou ~ tC~ ~'1 Form 10-404 Revised 12/2003 ,, ; \. .~ 'r :.. _ ..p~ ~ C ~~~r~` . . _ .. . ~. ~ ~~~ ~~,~ ~$ ~a ~oo~ ~''L`~° ~~8'l~ Daily Operations Log Point Thomson Unit #1 Well Inspection Wednesday, March 18, 2009 • Arrived at location. • Positioned wellwork equipment next to the wellhead. Thursday, March 19, 2009 • Performed an assessment of the well site. • Started heating up the wellhead. Friday, March 20, 2009 • Started excavation on the outside of gravel mound down to 4 feet. • Took wellhead pictures and measurements. Saturday, March 21, 2009 • Commence excavation around the well and removed top 18" of well cellar. • Well cellar is 1/4" plate steel construction. • Jackhammered remaining concrete from existing "A" section gate valve (west side). • Functioned side outlet valve several times to count rotations and determine proper functioning. • Applied heat to ensure there is no ice plug. • Installed choke manifold and pressure gauge, opened valve to check for pressure. Pressure is zero. • Shut in valve and replaced plug. • Wrapped wellhead in canvas and visqueen. Applied heat to the well and cleared work area. Sunday, March 22, 2009 • Unwrapped wellhead and re-checked for pressure, zero pressure observed. • Rigged up and pressure tested against existing valve (250-5000 f/5 min. ea), no leaks, bled off, shut in. • Verified there was no VR plug, inspected ring groove and installed new 3"-5K gate valve. • Pressure tested new valve against existing (250-5000 f/5 min.) no leaks, bled off, shut in. Monday, March 23, 2009 ~ Prepared site for hot tap procedure. • Rigged up hot tap equipment on 13-3/8"x9-5/8" annulus bull plug. • Pressure tested hot tap to 250/5000 f/5 min. - good test. • Hot tapped plug with no problem and verified zero pressure in the annulus. • Rigged down hot tap and removed plug and flange. No VR plug found in spool. • Prepared and installed new 3"-5K gate valve. Tuesday, March 24, 2009 • Prepared camp for move to PTU#2, loaded out sleighs at well site. • Spotted camp and fuel sleighs at PTU#2. • Returned to PTU#1 well site. • Placed chains and locks on valve handles, backfilled excavation as directed. • Inspected well and camp site, photographed same, and proceeded to PTU #2. • Arrived at PTU#2 well site. PTU #1 Notes Csg head Approx 24" M c Evoy S p I it Tubi ng he ad Aoorox. 24" Speedhead System 4" LP 4-1 /16" 5 k. 13 5/8" 5k. McEvoy o Needle valve ~ O MPN~t P1MAA1d7R1 13 5/8" 5k.-- ~rial ~lf1fL~ (1_9rJ'iA McEvoy ` Needle valve ~ ~N~f mnrlol "(;' IA 8~ OA valves are 3-1/8 5k Serial # BJ -772 MPN# P10.0~~147fi1 O Sprial #Of~10-22R3 Exxon Mobil Corporation Pt. Thomson Unit #1 Well Schematic API #: 50-089-20005 PTD #: 176-085 Wellhead A and B sections with blind flange and marker post on top 28" x 36" insulated conductor set at 83' TOC at 15' below ground level Bottom cement plug in 9-5/8" casing at 130' (105' BGL estimated) 13-3/8" x 9-5/8" Annulus Arctic Pack from 0' -1,807' Arctic Pack Premix from 1,807' - 2,668' Diesel from 2668' - 3,529' TOC behind 9-5/8" casing at 6,900' 7", 35#,Tieback cemented with 120 Sx Class G e 10.6 ppg e~ 18-5/8" at 801' ni CaCl2 mi ,~ ~ x x : 13-3/8", 72#, N-80 at 3,276' ~- 3,500' mud/CaCl2 interface Top 7" casing 4,000'~ .15.3 ppg mud ~15.6 ppg mud Top 7" liner at 9,032' 9-5/8", 40#, S-95 at 9,532' Retainer at 11,250' with 50 Sx cement on top Perforations 11,392' - 11,421', squeezed with 50 Sx class G Retainer at 12,302' Perforations 12,834' - 12,874', squeezed with 76 Sx class G TOC at 10,740'f in 7" casing TOP 4-1/2" liner at 10,873' Packer at 11,300'f 7", 35#, S-95 at 11,390' TOC in 4-1/2" liner at 12,100', 3bbls cement on top of retainer Packer at 12,700'f PBTD at 13,248', 4-1/2" 15.1#, S-95 at _ 13,295', cemented with 317 Sx class G ~ ~ $ Retainer at 12,895' ~ Total De th 13,29 ^.~.~ 15.6 ppg mud p ~,; . . ..~ Packer at 12,900'f Perforations 12,963' -13,050', '' ~'" '' r squeezed with 145 Sx class G 2_~ `~''~~'}~ ~.~ through retainer ~+' ~ ~;~ ,'~ Well schematic is prepared by Fairweather E& P Services, Inc. Last update May 13, 2009. ww - N m N N ~ ~ ~------ --^-_~-....____..r.__-----i-------_.7.___------, I I ~ i ~ I ~ ~ I i ~ I ~ 24 19 ; 20 i 21 I 22 ~ 23 ~ I I ~ i I I I I ~ i ~ i ~------ ------ ~ 1--------L--_____---! ~ }------ --~-------- ~ ~ I I ~ ~ I ~ I I ~ ~ ~ ~ I ~ 25 30 ( 29 i 28 I 2'r ~ 26 ~ ( ( ~ I ! I I ~ i ~ I SWEENEY I PT. TNOMSON ' ~ I i -,~ .G~ -------~------~'4-- ------{ ------ --~--- ----- -----I ~ ti-l~ l"`;~. I ~ i ~ ~ ~ J.i ~~ ~ / I ,~~~~ ~ ~ I ~ ~ '~ I ! \( ` ~ _/ ~~.~~__r 33 -=:t ', 34 I is I~,,\ 36 Y..~` 3~ ~~ 32 ~ `^~/h..~-..~' 3 ~> ~ I ~ ~ ,~ ~ sso' I I~~. ~s-srnKrn ~~,.~~, I ,_~ ~~T - ~ ~ EXXON No.l POINT THOMS~ON UNTIT ~~r.ioN. ~ ~ = ~ `i ! ~ ~~. ~ ~AT = 70° 10~26.95~~ ~`- '~ ~;.' ( T. 9 N. `-{ LONG.=146°20~ 14.62~~ i? i ti~ ~. ( ~ ~'~.'~' ~ I ~ ~, X = 458,086 ` ~_~ 1 ~'~; ' f I ~ ~~ ej'`~._~ ~ ,, i~ Y=5,913,342 3 '' i I I S` ~ 1 ~/ ~ ~[~~ 4 J'•,' I ~ ~ ( /~~~~Y- ~ i ~- -- - -~--- - - - - - - - --t - -- - -- -r= f- - - - - - --~ - - -- --- - -- }- --- - - -- -- -- - ~-I ~ ;; ~ ~ ~ ; ~ i ! ~ ~ ~ ;~ ~ ~ ~ y, ~~i2 ~ ~ e ~ 3 1~~~ I I ~ io I ~i ~ ~ ~ ~,, i I ~,, i j ~ 1 } ` i I ~'~ ~ i I L `-._% ___1-------L------1----___.`._1_.~--....__ 1-------__.~ I SCA~E~ 1~~= I MILE CERTIFICATE OF SURVEYOR I hereby certify that I am properiy registered and I icensed to practice Vand surveying in the State of Alaska and that this plat represents a location survey made by me or under my supervision, and that ali dimensions and other details are correct. ~~~~~~ ~~~~ .o [)~' ~i t' "~?5. /~~~~~~„~~r,. :ti r, p~, ~ ~~ .s ~ ~;-• ~ • !~ ~` ~R ='hY-~ ~,~ ~t`~Y y'~ r~ ~o«aa~~.~~.,:,.,~ . , . ,? ~ \ - ~ ~a °.'~~ ~"~"""' ° ; ~ ~ ~ ~~• +aDp , ... ,. ~. v/~ ~<'/1tr "P ~p~ r.j ~ ~ `~U ~~~ •iM~YO°o~N~1 ~i~ f + ~' ~'~SStON p'_ ~ ,~;'`~. _'~'4tt~.~.~~. c..~. k. 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''~~ ~+ r.~ 1 ~ \~. \ ~~ `--~; ~ ~" ' r. ~'a ',i -. , t .?r's. '~ ~',~ ~i ~i'<. ~'~.~- ~ ~. x~~ t ~~ ~ . . - . , ~~ ~ S , ~: g e . T~~ 'c l~ ~~ k r ~• ~ . ~• . ~ . ' ` ~'~ ,.itiP~`!) ~ I ~~, ~,~ I~ ~ ~ s l ! ~ ~ ~~~'"a ~~ F ~'ti'f' .-~.,~ ~y~k#~ !~` <• I ~ .e N~ °~` . '~ f' , r fyi*~ ~-+,i~±~ Js~i~ ~.~ ~~ ~g ~ t~~~~~~~ Kv~ \ 4 ~., #a~ , "i ~ _ ~ . r _; ~~ ,,~ ~,~ ~SY~~''y~.l~~~~~'u ~ ~ J ~u'J~.s ~:a . U ~~~Ur!= !.~.Cii.~.Y'.ur~i`31~3'~C~.;ve~i"::iiE3r3i1. ~~~i; ~~o~~~ i~3or?~a~, :~°~r~L v~~, ?~J9 ~J:'?2 ~?r~ ~~a lila+.~~der; ~ ~a~as ~ ~~~:a~ ~a~~~~~~e ~~: ~~,~~C~ ~€a~d~ ~9~~ic~ ~~~+~~~s :~; ~~~a~~;~€~~~~~ ~~~BG ;`~~r~ie~~~9a~s Tom, the reports fo-r the 9 well inspection/remediation worlc at Poini. Thomson leit my office this afternoon, Thanks for your patiencee I'm now loolcing ior contractors to bid the work to for the next winter~s work for the 3 well remediation effort. Ii you have any questions regarding the recent work or next winter's an~icipate~ ~~+ork, please call, Regards, Jack , Maunder, °Phomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, May 28, 2009 7:18 AM To: jack.a.rickner~exxonmobil.com Subjec4: RE: AOGCC Sundry Notice Reports for Compieted Fietd 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 witn any details. Tom Maunder, PE AOGCC -----Original Message----- From: jack.a.rickner@exxonmobil.com Sent: Thursday, May 28, 2009 7:14 AM To: Maunder, Thomas E (DOA) Subject: AOGCC Sundry Notice Reports [mailto:jack.a.rickner@exxonmobil.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 July. Moving ahead on planning the winter remediation work for the PTU-4, West Staines #2, and the West Staines 18-9-23. Our current plans are to start the permitting, contractinq, and procedure development (including which type of equipment to drill through the bridge plugs) this summer in hopes of avoidinq 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 Well Inspection & Remedia*ion Project 907-564-3783 281-217-4350 ~~i~~ ;~N / IVl~und~r, `Thorv~as E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, May 11, 2009 8:18 AM To: Natasha Sachivichik Cc: jack.a.rickner@exxonmobil.com; Bill Penrose Subject: RE: PTU well inspection project AOGCC report status Thanks Natasha. That schedule should work. "~om Maunder, PE AOGCC From: Natasha Sachivichik [mailto:natasha.sachivichik@fairweather.com] Sent: Monday, May 11, 2009 8:16 AM To: Maunder, Thomas E (DOA) Cc: jack.a.rickner@e~oconmobil.com; Bill Penrose Subject: RE: PTU well inspection project AOGCC report status To m, Sorry for delayed reply. We should have the reports ready by the end of this week or beginning of the next week the latest. Thanks and regards, Nataslna Sachi,vich%12 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@afaska.gov] Sent: Thursday, May 07, 2009 12:29 PM To: Natasha Sachivichik Cc: jack.a.rickner@e~oconmobil.com; Bill Penrose Subject: RE: PTU well inspection project AOGCC report status Natasha, et al, What sort of time frame are you looking at to submit all reports? I understand that submitting everything can help operational efficiency. Tom From: Natasha Sachivichik [mailto:natasha.sachivichik@fairweather.com] ~:~t: Th~rs~+ay, "!~~~ ~7, 20L~Q ? 3: ~4 AM To: Maunder, Thomas E (DOA) Cc: jack.a.rickner@e~oconmobil.com; Bill Penrose Subject: PTU well inspection project AOGCC report status 6/24I2009 _';.~~,'Y.+'~"le / '~S~'~~~ ~, ~~~~ I am writing in regards to the yesterday's phone conversation betvveen you and Bill P~nrose about the status of the Sundry reports for 9 wells inspection and remediation projec~ performed by Exxonl~obil. The field operations completed on April-29-2009. I would like to confirm that we are aware of the 30 days requirernent to subrnit the reports and are currently working on generating these reports. Could you please let me know if you would like all 9 Sundry reports submitted at the same time. Thanks and regards, Natasha sachi,v~ch~l2 Senior Drilling Engineer Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 Direct:907-343-0405 Cell: 907-575-7156 6/24/2009 I~auncle~, Thorr~as E (DOA-~ From: Maunder, Thomas E (DOA) Sent: Monday, March 23, 2009 10:14 AM To: jack.a.rickner@exxonmobil.com Cc: michael.d.murrey@exxonmobil.com; rob.g.dragnich@exxonmobil.com; m ike. 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 position), flange with lj2" needle valve (left in open position), install 3/8" stainless tubing to the surface and have a second needle valve present so that pressures could be read (needle valve left closed, gauge removed and plug inserted in needle valve opening). The tubing could be banded to the wellhead and to the above ground marker. 1 we could ?nscall che new gat~ valve (le"rc in clos°d ~osi~ion), flange; wi~h 1/2" needle val-ve and a plug. After obtaining pressure reading, bury the gate valve(s) un~il the n~xt 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 reaiize there is also a risk about surface as well. What are your thoughts? Tom -----Original Message----- From: jack.a.rickner@exxonmobil.com [mailto:jack.a.rickner@exxonmobil.com] "Maunder, 2 Sent: Sa_curday; March 21, 2009 3:41 Pi~1 To: ~'taunder, Thomas E (DOA) Subject: ~~Tellhead Inspection Program Tom, would you be available Monday morning to discuss a question regarding ExxonMobil's Pt. Thomson nine well inspection and remediation program. If available, please phone me at either of the numbers below. I am only a few minutes from you office and would not take more than 30 minutes of your time. I would like to discuss the question of how to leave the wellheads, especially the question regarding valving arrangements (valves above grade to facilitate periodic checking of well pressures versus valves below grade and buried in gravel) If you are not available due to time constraints, please call and let me know. I'm scheduled to fly to Deadhorse Monday after lunch for Emergency Response Training and will not be available until Thursday. Your insight to this question would be appreciated. Regards, Jack Jack A. Rickner Pt. Thomson well Inspection & Remediation Project 907-564-3783 281-217-4350 3 ~,~~,~ ~ ...~ ~~ ~ ~ ~~ tL~ _ ,~ ~ ,~ ~t Q ~.. £:~. ~ ~ ALASSA OIL 1~1~D G~S CO1~T5ER'QA7'IO1~T C4DII-iIS51ON Craig Haymes Alaska Production Manager E~onMobil Production Company PO Box 196601 Anchorage AK 99519-6601 Re: Point Thomson Unit, Pt. Thomson Oil Pool, PTU # 1 Sundry Number: 309-083 Dear Mr. Haymes: SARAH PALIN, GOVERNOR 333 W. 7thAVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval ~et out in the enclosed form. e Inspection Procedure document submitted with tl~e application refers to the well as "currently suspended." However, the status af this well accordin~ to the official AOGCC records is still P&A, although as the ~ommission pointed out in previous correspondence this is one of several wells so classified that appear nat to meet alI of the applicable regulatory requirements for ph~~ged and abandaned wells. We appreciate your inspection efforts as described in the application. E~onMobil has submitted a request to chan~e the classification of this well to suspended status. but the Commission has not yet acted _ on _that request. Approval of this inspection work proposal does not constitute or imply a decision on the request to chan~e the well classification. When providing notice for a representative of the Commission to witriess any required test, contact the Comznissian's petroleum field inspectar 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 Comnussion grants for good cause shown, a persan 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 ne~ working c~~:~ if the 23rd day falls an a holiday or weekend. A person may not appeal a Cor~~rnission decisian to Superior Court unless rehearing has been requested. Sincerely, ~,~ Daniel T. Seamount, Jr. i Chair DATED this `?day of March, 2009 Encl. : . k~ ~~ ~ ~.~b~ ~ STATE OF ALASKA ~~~~~~~ ~ ~ ~ 3 ~9 ~~ ~ ALAS~ OIL AND GAS CONSERVATION COMMISSIOIti~~ ~~~QQg .~ y b`6 ~~ APPLICATION FOR SUNDRY APPROVALS ~~` ~, ~ ~ 2o a,ac 2s.zso AI~~[ca ~il ~ ~~s ~~r~. ~~~nassi~n 1. Type of Re est: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ ~~ ~~~rer ^ Other Q Alter casing ~ Repair well ~ Plug Perforations ^ Stimulate ^ Time Extension ~ Site Inspection Change approved program ~ Pull Tubing ~ Perforate New Pool ~ Re-enter Suspended Well ~ ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exxon Mobil Corporation Development ~ Exploratory ~ 176-085 ~ 3. Address: Stratigraphic ~ Service ~ 6. API Number: PO Box 196601 Anchorage, AK 99519-6601 50-089-20005 ~ 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 1 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 47560 - 33 . 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): 13,298 - 13,298 , Surface Surface See Attached None Casing Length Size MD ND Burst Collapse Structural 61' 36" x 28" 83' 83' N/A N/A Conductor 779' 18 5/8" 801' 801' 2420 780 Surface 3254' 13 3/8" 3276' 3276' S380 / 3450 2670 / 1950 Intermediate 9510' 9 5/8" 9532' 9532' 6820 4400 Production 7390' 7" 11390' 11390' 10580 11600 Liner 2422' 4 1!2" 13295' 13295' 12450 12760 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): N/A N/A 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ~ Exploratory ^~ Development ^ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations March 1, 2009 Oil ~ Gas ~ Plugged ^~ ~ Abandoned ~ 17. Verbal Approval: Date: WAG ^ GINJ ~ WINJ ^ WDSPL ~ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Barker / Jack Rickner Printed Name Craig A. aymes Title Alaska Production Manager Signature Phone (907) 5643617/(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: 1..:~~ 1..~~ ~~ ~fCl~~i~~` ~i9 t"~Q~.~\ '~'~~ tl.h1~ \~~C',.~ G~~~'~'CC~UCi,~\ GV~ Subsequent Form Required: ~ ~3~ ~ P ~,~~.~~ ~ ~ ~~i S ~ ~%'~ `~"- t"\ ~ APPROVED BY S A p ~ ~~ Approved by: COMMISSIONER THE COMMISSION Date: ~ ~ % Form 10-403 Revised 06/2006 ' r` ~ F,~.~.,," ~~~~ ~~ '~ ~".y ~~ ~~t~t ~ ~ t~~~ Submit in Duplicate ~, , ~ ~ i 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. ~~~~~~ ~~~ ~ ~ 200~ F~bruary 25, ~009 Mr. Dan Seamount Chairman Alaska Oif and Gas Conservation Commission 333 West 7t'' Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Application to Inspect Exxon Mobil Corporation Foint Thomson Unit #1 PTD No. 176-085 Dear Commissioner Seamount: ~., ~~~ ka o~~ ~ ~~~ ~,~as~~, car~m~~~s~r E~on o il ~~y;~~~~~~ Production Exxon Mobil Corporation hereby submits an Application for Sundry Approval to perform a surface inspection of the subject well. This inspection will assist in long-term well monitoring. No well work is anticipated at this time. The top of the well will be exposed by excavating gravel covering it to allow verification of the well integrity by checking for and recording pressures in the 9-5/8" casing and the 9-5/8 x 13-3/8" annulus. The wellhead configuration may be rYiodified 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) V1%ellbore Schematic 3) Inspection Proc~dure 4) Photo of the Wellhead/Abandonment Marker at Present Ifi you have any questions or require additional information, please contact Mike Barker at 564-3617 or Jack Rickner at 564-3783. Sincerely, ~'` i J -~ ~~ ~ CAH:eaa Attachments A Division of Exxon Mobil Corporation ExxonMobil Corporation Pt. Thomson Unit #1 Well Schematic API #: 50-089-20005 PTD #: 176-085 Wellhead A section with blind flange and marker post on top (assumed) 28" x 36" insulated ' Diesel ,. TOC at 15' below ground level conductor set at 83' ~• _ m 84 m___ Bottom cement plug in 9-5/8" casing at 130' (105' BGL estimated) 13-3/8" x 9-5/8" Annulus ~; • ~ Arctic Pack from 0' -1,807' ~+ x 10.6 ppg x~~ 18-5/8" at 801' Arctic Pack Premix from 1,807' -~~ ~ CaCl2 ~;~ 2,668' ~~ a a'~ Diesel from 2668' - 3,529' ~ ~ 13-3/8", 72#, N-80 at 3,276' ~ ~ ~ ~ ~~,~,~,~,~,~,~,~.~,~.~ ~ ~ 3,500' mud/CaCl2 interface ~ ~ Top 7" casing 4,000'± ~ 15.3 ppg mud TOC behind 9-5/8" casing at 6,900' s ~ 15.6 ppg mud 7", 35#,Tieback cemented with 120 Sx Class G ~d ~ Top 7" liner at 9,032' s , • :~; ~` ~, '~ 9-5/8", 40#, S-95 at 9,532' ~'! . ~ ~,` r .# 4 TOC at 10,740'± in 7" casing Retainer at 11,250' with ~., ~~,y~ ~~ ti~ g 50 Sx cement on top ~~ TOP 4-1/2" liner at 10,873' z f. ...4 ~;~. ~~ ' ; `~ ,-~ Packer at 11,300'± ~r f ~; ~~ ~: ~ ~; ; `;' . * ~ ~ 7„ 35#, S-95 at 11, 390' Perforations 11,392' - 11,421', x' ~~' ` ':4 ^~~,;~ squeezed with 50 Sx class G ~~„' ~~' "?' '.;~ ~~` ' Y "~ ~~~i TOC in 4-1/2" liner at 12,100', 3bbls cement on top Retainer at 12,302' ~ r`~ J~,. ,.. ~A ., ~ of retainer sa; ~~. __ a;~ Packer at 12,700'± Perforations 12,834' - 12,874', squeezed with 76 Sx class G s`' Retainer at 12,895' ~ 5 ; . +,~, . ~.:,, .; 15.6 pp9 mud ~~~ , -`• ;~ Packer at 12,900'± Perforations 12,963' - 13,050', ~" ''=; r' f~~ squeezed with 145 Sx class G ~• a~'~~'~'"~ ~~ through retainer s" .. PBTD at 13,248', 4-1/2" 15.1#, S-95 at Total Depth 13,298 13,295', cemented with 317 Sx class G Well schemaGc drawn June 29"', 2007 by Jesse Mohrbacher, Fairweather E& P Services, Inc. Updated Feb-13, 2009 by Natasha Sachivichik, Fairweather E& P Services, Inc • Exxon Mobil Corporation Pt. Thomson Unit #1 API #: 50-089-20005 PTD #: 176-085 Inspection Procedure Background Well Information • The Point Thomson Unit #1 well was drilled in 1977. 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 15'-105' BGL, with diesel above the cement and 10.6 ppg CaCl2 brine below the cement plug to 3500' then 15.6 ppg mud down to top of cement plug at 10,740'. The 9-5/8" x 13-3/8" annulus contains arctic pack, arctic pack premix, and diesel. The well schematic is attached to this procedure. The well files do not include any information on the wellhead configuration. The reservoir section of the well is effectively isolated; therefore it is unlikely that high pressure will be encountered during the inspection. However, contingency plans and procedures will be included in the detailed inspection procedure to safely manage any well pressure encountered. The inspection will include the following steps: • General inspection of the well location to the extent possible (winter operations) • Excavation of gravel covering the wellhead and cellar • Visual inspection as to the condition of the wellhead • Verification of the well integrity by checking for and recording pressures in the 9-5/8" casing and the 9-5/8 x 13-3/8" annulus o Perform diagnostic test if pressure is found (i.e., trapped vs sustained pressure) o Identify contents of the casing and annulus by attempting to get a sample • Clean up of location and leave well in a safe and secure condition The proposed inspection will be supported by on-site equipment and materials such as excavator, camp, transportation, fuel and other essential elements of remote operations. The following well inspection program is planned: ~ ~ 1. Insure all necessary permits and applications are in place. Notify AOGCC at least 10 days before operations begin. 2. Mobilize all personnel and equipment to the Point Thomson Unit #1 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. 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' µ~`i'.~ , ^ ~i:. ~ ' ~ ~r i _ ~ ti t; ; ,4.• ~r~>~ ~. .t~. ~ ~ . {~ ~ ?t. a ~ L ~ `,` ~~~ i -. .. .~` . „ ~ - STATE OF ALASKA -67 MAR GEI1 8 Vt 2008L AL OIL AND GAS CONSERVATION COM SI N I APPLICATION FOR SUNDRY APPROVAL,skaOil8 Gas Cons,Comrnls310A 20 AAC 25.280 Anchorage 1.Type of Request: Abandon❑ Suspend ❑✓ Operational shutdown ❑ Perforate ❑ Waiver❑ Other❑ Alter casing❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ Change approved program❑ Pull Tubing❑ Perforate New Pool ❑ Re-enter Suspended Well ❑ 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number:t Exxon Mobil Corporation Development E] Exploratory ❑ 76-85 I S�' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: PO Box 196601 Anchorage,AK 99519-6601 50-089-20005 • 7. If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: N/A Spacing Exception Required? Yes ❑ No ❑ Point Thoron Unit No 1 ' 9.Property Designation: 10. KB Elevation(ft): 11. Field/Pool(s): ADL 47560 - 33 . Wildcat 12. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): /. gs(measured): Junk(measured): 13,298 . 13,298 • Surface Surface ., , See Attached None Casing Length Size MD , r D Burst Collapse Structural 61' 36"x 28" 83' \i j83' N/A N/A v� Conductor 779' 18 5/8" 801' 801' 2420 780 Surface 3254' 13 3/8" 3276' ,- 3 5380/3450 2670/1950 Intermediate 9510' 9 5/8" 9532' 532' 6820 4400 Production 7390' 7" 11390' 11390' 10580 11600 Liner 2422' 4 1/2" 13295' 12450 12760 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Siz- Tubing Grade: Tubing (ft): MD 12963-13050,12834-12874, 12963-13050,12834-12874, N/A N/A 11392-11421 11392-11421 / Packers and SSSV Type: lo ers a d SSSV MD(ft): Pakers @ 12900', 12700'&11300' Retainers @ 12895',12302'&11250 13.Attachments: 14.Well Class after proposed work: Description Summary of Proposal e p p �r Detailed Operations Program ❑ BOP Sketch y Exploratory E • Development ❑ Service ❑ 15. Estimated Date for N/A �r- 16.Well Status after proposed work: Commencing Operations: / Oil ❑ Gas ❑ Plugged ❑✓ . Abandoned ❑ 17.Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact William C.Pecor Printed Name William C. Pecor Title Point Thomson Coordinator Signature 4ii)zet.0y1 C O Phone (907)564-3766 Date 3//¢/08 COMMISSION USE ONLY Conditions of approval: Notify Commis '.n so that a representative may witness Sundry Number:30b—61F341.-- A Plug Integrity ❑ BOP, est ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: This request is to change the classification from Abandoned to Suspended,no well work is proposed. Subsequent Form Required: Li(j1 T � - c a\\•,‘,1\ APPROVED BY Approved by: MISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 ORIGIN L RBDMS LL FEi3 1 1 1016 Submit in Duplicate • • March 17, 2008 f(© _ Commissioner Dan Seamount RECEIVED Alaska Oil and Gas Conservation Commission 333 \Nest 7th Avenue, Suite 100 M�- k ?OHAnchorage, Alaska 99501-3539 Re: Pt. Thomson Wells — Plugging and Abandonment & `�Alaska Oil Cone. Corn ' 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 pian. 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 ExxoniViobil to conduct a thorough and thoughtful review. Please feel free to contact me, Bill Pecor, or Rob Dragnich if you have any questions. Sincerely. -. .Aitach encs I cc Mark Ireland, ConocoPhillips Vince s 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 "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 RECEIVE~ STATE OF ALASKA MAR 1 8 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIO~ p~ &~~, ~;~ 1. Operations Performed: Abandon Repair Well Plug Perforations Stimulate Other ~ Site Inspection • Alter Casin 9^ Pull Tubing [] Perforate New Pool ^ Waiver^ Time Extension ~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ 2. Operator Name: 6ocon Mobil Corporation 4. Well Class Before Work: 5. Permit to Drill Number: Development ^ Exploratory^~ 76-85 - 3. Address: PO Box 196601 Stratigraphic~ Service^ 6. API Number: Anchorage, AK 99519-6601 50-089-20005 • 7. KB Elevation (ft): 9. Wefl Name and Number: 33 ` Point Thomson Unit No 1' 8. Property Designation: 10. Field/Pool(s): ADL 47560 ~ Wildcat 11. Present Well Con dition Summary: Total Depth measured 13298 • feet Plugs (measured) See Attached true vertical 13298 ~ feet Junk (measured) None Effective Depth measured Surface feet true vertical Surface feet Casing Length Size MD ND Burst Collapse Structural 61' 36" x 28" 83' 83' N/A N/A Conductor 779' 18 5/8" 801' 801' yqyp ~g~ Surface 3254' 13 3/8" 3276' 3276' 5380 / 3450 2670 / 1950 Intermediate 9510' 9 5/8" 9532' 9532' 6820 4400 ProducGon 7390' 7" 11390' 11390' 10580 11600 Liner 2422' 41/2" 13295' 13295' 12450 12760 Perforation depth: Measured depth: 12963-13050, 12834-12874, 11392-11421 True Vertical depth: 12963-13050, 12834-12874, 11392-11421 (size, grade, and measured depth) N/A and SSSV (type and measured depth) Packers @ 12900', 12700' 811300' Retainers @ 12895', 12302' 8~ 11250' 12. Stimulation or cement squeeze summary: Intervals treated (measured): descriptions inGuding volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequentto operation: 14. Attachments: 15. Well Class after work: Pictures from Aug 07 site inspection X Exploratory0 " Development ^ Service ^ Well Schematic X 16. Well Status after work: Abandoned Informa6on 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. Sundrv Number or N/A if C.O. Exemot ContaCt William C_ Pernr Printed Name William C. Pecor Signature ~-GC~p~G C• Form 10-404 Revised 04/2006 Title Point Thomson Coordinator Phone (907) 564-3766 . ~ _~ ~~~ ,:!~ . :p ~~ 2 i0~; Date 3 ~ d8 Sr •'---it ~-rininai [)nly ~ Exxon Mobil Corporation Pt. Thomson Unit #1 Well Schematic API #: 50089200050000 APTD #: 176-085 Wellhead A section with blindflange and marker post on top (assumed) TOC at 15' below ground level I Bottom cement plug in 9-5/8" casing at 130' (105' BGL estimated) 18-5/8" at 801' 10.6 x'~ 13-3/8" x 9-5/8" Annulus CaCl2pg ~'~~ Arctic Pack from 0' - 1,80T a y~~ Arctic Pack Premix from 1,807' - 2,668' :.,~ Diesel from 2668' - 3,529' 13-3/8", 72#, N-80 at 3,276' ~ 3,500' mud/CaCl2 interface Top 7" casing 4,000'± 15.3 ppg mud 15.6 ppg mud TOC behind 9-5/8" casing at 6,900' 7", 35#,Tieback cemented with 120 Sx Class G Top 7" liner at 9,032' Retainer at 11,250' with 50 Sx cement on top Perforations 11,392' - 11,421', squeezed with 50 Sx class G Retainer at 12,302' Perforations 12,834' - 12,874', squeezed with 76 Sx class G Perforations 12,963' - 13,050', squeezed with 145 Sx class G through retainer ; 9-5/8", 40#, S-95 at 9,532' TOC at 10,740't in 7" casing TOP 4-1/2" liner at 10,873' Packerat 11,300'± 7", 35#, S-95 at 11,390' TOC in 4-1/2" liner at 12,100', 3bbls cement on top of retainer Packer at 12,700't Retainer at 12 15.6 ppg mud Packer at 12,900't ~ "' ~Z PBTD at 13,248', 4-1/2" 15.1#, S-95 at Total Depth 13,298 13,295', cemented with 317 Sx class G Well schematic drawn June 29'", 2007 by Jesse Mohrbacher, Fairweather E& P Services, Inc. Point Thomson Unit No. 1 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 exhibited generally thick (three to five feet thickness) gravel with little/no vegetative growth or thermokarsting. Gravel mounded around the wellbore covered the wellheads and only the wellbore marker was visible. There was little debris present. The reserve pit had been partially backfilled and there was good vegetative growth over that. Two small pieces of pit liner or other similar material were visible in an adjacent impoundment. There were 3 offsite wooden piling protruding above the surface. Although significant surface waters surrounded the site, no hydrocarbon sheens were seen. . Point Thomson Unit No. 1 -1- -2- Point Thomson Unit No. 1 Point Thomson Unit No. 1 , ..r-~~/ •,~ ~~}~~ -- ~a,~.,~~~ .a.~:~:~ar > ..., wr . . ~~ i~ fif.~~~wY~~1 y t~~f~iTY~i:{~w"~~ ~If1~Zt11Ls ~6+ '~~~s~wYY~s'~'i' . . _ . -'.- i~e . ~ :.. ... . '~'~T' ~ .~..~ ,.~0 ~ . . ~.- " .. --.«s.,..a.1~s~+.~f~~ .~+K#ry.`~~~~ .1 . . ~. .. ~1 ,,, _ ~r ~ j ': "'y~ ~ - ~!~'y~' n ~ ~ . . f u ~ ' 1. ~ ~.1. ~ dFh ~ -a ~ '~_„ • ~. +'.qn-? .H. .": y~ "~ ~ ~.~t '9./ ~ ,y~ .~ ~ a ~~ ~. F;n,~, _.; u ,epp~`w# s . .n +~~ ~'i~ ~ , e) '~yT~^, ~t ~ . .w ~ ~" ' ~ «. ,~ ~ ~~ ,4 ~ ~ ye.: +lsw. „ i r . sT \°+ ~ ~' + R '", •p~~f ` '" ~l~ ~ t:: ~a r~s~~' ~. ~,ffi ~ tY ~~ y `~~-~ ~~" r ~4~j~~jt ~rY~ ~ ; < n , . . . ~. . . a~u .~..., _ . . . i Point Thomson Unit No. 1 -3- Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, March 14, 2014 4:07 PM To: 'Juranek, Tom A' Cc: Collins, Dennis /C; Greene, Timothy L; Peterson, James M /C; Farrar, Kendall N; Winter, Cassondra E; Cox, Mirick T; Dragnich, Rob /EXT; Denman, Erika /C; Bill Penrose (bill@solstenxp.com) Subject: RE: Addendum to Procedures for West Staines State #18-9-23 (PTD 069-120, Sundry 313-604), West Staines State #2 (PTD 175-002, Sundry 313-606), Staines River State #1 (PTD 179-001, Sundry 313-605), and Point Thomson Unit #1 (PTD 176-085, Sundry 313-600) Tom, Thanks for the amended PT procedures. This new lower "master valve " will take care of the corjcerns that were identified. � oval to pressure test (2500 psi) against the 9 5/8" casing for W Staines State #18423 for verification of flange breaks during routine BHA change -outs . All the other following P &A wells must have the new 11" test valve installed. I will print out the attached addendums and add them to our well file. Senior Petroleum Engineer 907-301-4533 cell 907-793-1226 office i From: Juranek, Tom A [ -anek(a)exxonmobil.c ] Sent: Friday, March 14, 2014 1:14 PM To: Schwartz, Guy L (DOA) Cc: Collins, Dennis /C; Greene, Timothy L; Peterson, James M /C; Farrar, Kendall N; Winter, Cassondra E; Cox, Mirick T; Dragnich, Rob /EXT; Denman, Erika /C; Bill Penrose ( ) Subject: Addendum to Procedures for West Staines State #18-9-23 (PTD 069-120, Sundry 313-604), West Staines State #2 (PTD 175-002, Sundry 313-606), Staines River State #1 (PTD 179-001, Sundry 313-605), and Point Thomson Unit #1 (PTD 176-085, Sundry 313-600) Guy, Following up on our discussion in your office on Tuesday, March 11, 1 am sending you addendums to our procedures concerning our BOP pressure testing. Attached are addendums for each of the remaining wells that we are planning to work on this winter season. Please let me know if these addendums are approved or if you need further information or clarification. In addition, we are also seeking permission to deviate with our BOP testing on the WSS #18-9-23 as we did on the PTU #2 (BOP test against our test plug with break tests of only 2,500 psi against the 9-5/8" casing) until the "Testing Valve" arrives and can be installed and tested. We have located and are mobilizing the extra 11" 10k ram that we will use as our "Testing Valve". However, we will most probably have moved our Coiled Tubing Unit to the WSS #18-9-23 and be ready for operations 2-3 days prior to the valve arriving. Once we have the Testing Valve, we will follow the addendums. Please respond on approval of the addendums and for the deviation until the testing valve arrives. I appreciate your time on Tuesday and your assistance to make our remediation campaign a success. Please let me know if you have any questions or need anything further. Thanks, Tom Juranek Subsurface Engineering Advisor EMPC Global Engineering -Houston Subsurface Engineering & Operations Support CORP -EMB -3021J Lync Phone: 832-624-6940; Fax: 713-656-7353; Whone: 832-596-5406 email: tom.a.iuranek@exxonmooil.; POINT THOMSON UNIT #1 Sundry # 313-600 API # 50-089-20005 APTD#: 176-085 Addendum - Pressure Testing Procedures (Refer to wellhead and BOP diagram below) Initial BOP test and subsequent 7 -day BOP tests: 1. Close the 11" 10k "Testing Valve" and pressure test from the testing valve to the choke manifold to 8,000 psi. 2. Close Drilling Spool Gate Valves and "Testing Valve" and Pressure Test the CT BOP rams to 8,000 psi as per SLB Procedure (Note: 11" equipment are tree valves and not BOPS) a. SLB Combi BOPS b. SLB Quad BOPS 3. Close the 11" 10k "Test Valve" and pressure test across the broken connection. a. Prior to Drilling of surface plug (cement and/or CIBP), test to 8,000 psi. b. After verifying no pressure below plugs, test to 3,000 psi. 11", 10k Rams Used as Tree Valves Inmwmww lil lil Iii Iii iii lil 120 DSA- 11' 10k X 4 10k 11" 10k SPACER SPOOL 11" 10k DRILLIING SPOOL WITH 2" 10k MANUAL GATE VALVES 11" 10k SWAB VALVE W/ BLIND/SHEAR RAMS 11" 10k MASTER VALVE W! STRAIGHT BLIND RAMS 4-1/16", 10K Coil BOP System a.11,1631 B Spucar s11001 to + cohe Vdling t111A 11" 10k TESTING VALVE W/ STRAIGHT BLIND RAMS u (RAM BODY AND RAMS INSTALLED UPSIDE DOWN) " 4-106 1U SLH ;)yw Dop's -n 4-1116 10 SLB t• aCombi BOP's r e1 17=11®r? CCLfv=100ECEIT January 29, 2009 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 5975 William Pecor ExxonMobil Production Company PO Box 199610 Anchorage AK 99519-6601 Re: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut -In Well Information Dear Mr. Pecor: SARAH PALIN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 SCMWOCT 0 19 ZB14 Enclosed are the Alaska Oil and Gas Conservation Commission's revised regulations regarding suspended wells (i.e., 20 AAC 25.110). Also enclosed are lists of suspended long-term shut-in and Point Thomson heritage wells operated by ExxonMobil Production Company or your predecessor companies. For each list, please verify the information for each well and provide any corrections by April 1, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with Jim Regg at 907-793-1236 orjim.regg@alaska.gov. If you have any questions regarding this notice, please contact Tom Maunder at 907-793- 1250 or tom.maunder@alaska.gov. Enclosures Sincerely, Cathy P. Foerster Commissioner Postal CERTIFIED• (Domestic MAIL RECEIPT Er Lr7 • • . • . ru +CIAL USE Poefte $ ".59 0535 62.70 09 O %kwn Remo Fee %*no* O Xndoroan"11 PaWIr" $2.20 ROM ReMkftd rU Y Fee CO (E"d°""""" Requlrod) f0.00 r -i ToNPoi W , f5,,,49 01!30/2009 L^ William recor o aw To C3 ExxonMobil Production Co. r` aAp„I, PO Box 199610 Anchorage AK 99519-6601 E Complete items 1, 2, and 3. Also complete /A. sign item 4 if Restricted Delivery is desired. Agent �x ■ Print your name and address on the reverse - i ❑ Addre B. eived fed Name) C. D e of el so that we can return the card to you. ■ Attach this card to the back of the mailpiece, � or on the front if space permits. D. Is delivery ad ss different from item t ❑ es 7. Article Addressed to: If YES, enter delivery address below: ❑ No William Pecor ExxonMobil Production Co. PO Box 199610 Anchorage AK 99519-6601 3.S rvice Type l Certified Mail ❑ Express Mall ❑ Registered )?IrAeturn Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 2. Article Number (Transfer from service label) 7x05 182D ODD1 2499 5975 PS Form 3811, February 2004 Domestic Return Receipt 102595-02-M-1540 Operator Suspended and Shut In Wells PENNZOIL CO Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... *EXPLORATORY 166-064-0 50-831-10002-00-00 STARICHKOF ST 1 SUSP 4/1/1967 843 FNL 1841 FEL Sec 33 T 3 S R 15 W SM ADL0018790 Wednesday, Jrrnanry 14, 2009 Operator Suspended and Shut ffn ` rm MOBIL OIL CORP Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... KUPARUK RIVER 181-035-0 50-029-20573-00-00 KUPARUK 28243 1 SUSP 5/29/1981 470 FSL 605 FWL Sec 17 T 11 N R 11 E UM ADL0028243 Wednesday, January 14, 2009 ExxonMobil Pt. Thomson Heritage Wells Identified May 18, 2007 in Commission Letter to Craig Haymes API WELL PTD # 'Oper Nam, a Well Name Field Sec Twp N/S Rng W/E PM Lease(s) 50-089-20001- MOBIL OIL W STAINES PT ( I 1 I f , ; I f 00-00 1691200 CORP ST 18-09-23 THOMSON 18 9 N 23 E U ADL 0028380 ........... 50-089-20004- 00-00 1750020 MOBIL OIL CORP W STAINES ST 2 'EXPLORAT ORY 25 9 { N I 22 ' E U ADL 002837 PT 50-089-20005- EXXON THOMSON PT ! I E 00-00 1760850 CORP UNIT 1 THOMSON 32 10 I N 23 E U ADL 0047560 PT 50-089-20006- EXXON THOMSON PT 00-00 1770640 CORP UNIT 2 THOMSON 3 I 9 N 22 E! U I ADL 0047567 PT 50-089-20007- 00-00 1780050 EXXON CORP THOMSON UNIT 3 PT THOMSON 34 ( 10 j N 23 ! E f U I ADL 0047558, ADL 0047559 50-089-20008- MOBIL OIL STAINES PT 00-00 1790010 CORP RIV ST 1 THOMSON 171 9 1 N 24 i E i U j ADL 0047573 PT 50-089-20009- EXXON THOMSON PT ` 00-00 1790800 CORP UNIT 4 THOMSON 32 10 j N 22 I E U I ADL 0047563 ---- — 50-089-20011- EXXON ALASKA ST 00-00 1800460 CORP C1 THOMSON 14 9 I N 23 E U j ADL 0028382 50-179-20007- EXXON ALASKA ST PT 00-00 1830450 CORP ii THOMSON 1 23 I 6 VN 22 L E YU� ADL 0344033 _ -1 20 AAC 25.110. Suso-ended vveNs (a) If allowed tinder 20 AAC 25.1�u_5, the commission will, upon application b; the- operator heoperator under (b) of this section, approve the suspension of a well if (1) the well (A) encounters hydrocarbons of sufficient quality and quantity to indicate that the well is capable of producing in paying quantities, as reasonably demonstrated by well tests or interpretive formation evaluation data; for purposes of this paragraph, "paying quantities" means quantities sufficient to yield a return in excess of operating costs; (B) is a candidate for redrilling; (C) has potential value as a service well; or (D) is located on a pad or platform with active producing or service wells; and (2) the operator justifies to the commission's satisfaction why the well should not be abandoned, and, if the well is not completed, why the well should not be completed; sufficient reasons include the (A) unavailability of surface production or transportation facilities; (B) imprudence of security maintenance of a completed well in a shut-in status; (C) need for pool delineation and evaluation to determine the prudence of pool development. (b) An Application for Sundry Approvals (Form 10-403) must be submitted to and approved by the commission before plugging operations are begun in a well for which suspension is proposed, except that oral approval may be obtained from the commission if it is followed within three days by the submission of an Application for Sundry Approvals for final approval by the commission. Approval will be conditioned as necessary to protect freshwater and hydrocarbon resources. An Application for Sundry Approvals must include (1) the reason for suspending the well and information showing that the applicable criteria for suspension under (a) of this section have been met; and (2) a statement of proposed work, including (A) information on abnormally geo-pressured strata; (B) the manner of placement, kind, size, and location, by measured depth, of existing and proposed plugs; (C) plans for cementing, shooting, testing, and removing casing; (D) if the Application for Sundry Approvals is submitted after beginning ��orl: the name of the representative of the commission who provided oral approval, and the date of the approval; and (E) other information pertinent to suspension of the well. (c) At the operator's request accompanying the submission, information submitted to show that the applicable criteria for well suspension under (a) of this section have been met will be kept confidential (1) for the period specified under AS 31.05.035 (c), if the information is described in 20 AAC 25.071(b) ; or (2) for the time that the information has value as a trade secret, if the information is not described in 20 AAC 25.071(b) but is determined by the commission to constitute a trade secret under AS 45.50.940 . (d) A well approved for suspension must be plugged in accordance with the requirements of 20 AAC 25.112, except that the requirements of 20 AAC 25.112(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 ExxonMobil pre4ltiotion Can; P. 0. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimile March 17, 2008 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Pt. Thomson Wells — Plugging and Abandonment Dear Commissioner Seamount: Crai, aymes � �� o76 Alaska Production I'v1anager Joint Interest U.S. 1-7& U Y5 X77. ab`� EonMobil Production /Z9 /a 0 /7g- oa0 REQ' IV ED MAR 1 ?008 Alaska Oil & Gas Cons. Commissial Anchorage In response to the Commission's December 7, 2007, letter to ExxonMobil, attached are sundry notices requesting the Staines River State No. 1, Alaska State C-1, and Point Thomson Unit No.'s 1, 2, and 3 wells be reclassified from abandoned to suspended status. Site inspection sundry notices, Form 10-404 reports and photos, are also attached for these five wells and the Point Thomson No. 4, Alaska State J-1, West Staines No 18-9-23, and West Staines No. 2 wells. We are making plans to conduct the inspection and remediation work described in ExxonMobil's letter of November 14, 2007, and the Commission's December 7 letter during the winter of 2008-`09. As you know, we submitted a Plan of Development for PTU to the Department of Natural Resources that calls for drilling operations to be conducted during the winter of 2008-'09. Approval of this plan by DNR will afford the opportunity to conduct the well remediation work described in our November 14 letter in conjunction with that drilling plan. We share the Commission's desire to conduct the remediation work in a timely and date certain manner, but we would like the opportunity to revisit the timing of the remedial work if the drilling program does not proceed as currently planned. We believe there are operational safety and efficiency factors that should be considered. Please note the Staines River State #1 well is under extended confidentiality as provided under AS 31.05.035(d) and 20 AAC 25.537(b). We have included its report as a separate, confidential attachment. We again thank the Commission for providing clarity around the issues and for providing adequate time for ExxonMobil to conduct a thorough and thoughtful review. Please feel free to contact me, Bill Pecor, or Rob Dragnich if you have any questions. Sincerely, Attach ents 7 cc: Mark Ireland, ConocoPhillips Vince LeMieux, Chevron ,"NM OCT © J 2-Q?14, A Division of Exxon Mobil Corporation ALASKA OIL AND GAS CONSERVATION COMUSSION December 7, 2007 Craig Haymes Alaska Production Manager ExxonMobil Production Company PO Box 196601 Anchorage, AK 99519 Re: Pt. Thomson Wells — Plugging and Abandonment Dear Mr. Haymes, SARAH PALIN. GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 This is in response to your letter of November 14, 2007 responding to the Alaska Oil and Gas Conservation Commission's ("Commission") letter of May 18, 2007 regarding the condition of certain Pt. Thomson Unit wells. The schedule and plan for remedial work provided with your letter are acceptable subject to the following conditions: 1. ExxonMobil will perform the proposed field work for the 2008 — 2009 winter operating season regardless of whether there are any concurrent drilling operations in the Pt. Thomson Unit. 2. All of the diesel will be removed from the W. Staines State #18-9-23 (169-120) and W. Staines State #2 (175-002) wells. If any of the diesel cannot be removed, a Commission petroleum engineer or inspector shall determine whether the shallow wellbore plugs are competent, and ExxonMobil must take any reasonable actions the Commission determines are necessary. 3. All current and future statutory and regulatory requirements and all applicable rules, orders, and permits of the Commission will be complied with unless a waiver to a specific requirement is timely and otherwise properly requested and granted by the Commission. To assist the Commission in ensuring that its files are complete and accurate, by March 31, 2008, please submit for each well a Form 10-404, a summary of the observations from the work performed last summer, and location photos. Finally, nothing above expressly or implicitly evidences the Commission's position with respect to the status of ExxonMobil or 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 ExxonMobii Production Comp;, P. O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimile November 14, 2007 Chairman John Norman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Pt. Thomson Wells — Plugging and Abandonment Dear Chairman Norman: Cram 'rues Alaska Production Manager Joint Interest U.S. E�onMobil Production RECEIVED NOV 14 2007 Alaska Oil & Gas Cons. Commission Anchorlago 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 lette�. While we believe the wells met AOGCC requirements when the prior P&A actions were takeirl 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, 1z, 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 ,w, i. Point Thomson Unit No. 1 Point Thomson Unit No. 1 Point Thomson Unit No. 2 Point Thomson Unit No. 2 4 IVP , f 44 40 Point Thomson Unit No. 2 ::;:�.��.:. �, t&»#,• � ,.;mak � ��"�1itx.: tt IT Al , 7;?141 I fs, W .1a Ny if 77 kAli A. Point Thomson Unit No. 4 Point Thomson Unit No. 4 Aml 14 C A*1 T W11-611 z-` jAl' 'A"r 'Ir �lk ..Po l r y `. .rte• .. t-_ r tc.: _ I. ...iF- �.�:J- ...t.w--�= ��r'ci.� ?..pw`•i! ,r"�"��;: ?{.i'. :.•i ':r C P'+Mv F Y ', � � .f .. �`:�,+ �.. ro , —.Y '3%-��.� ' . �r •yc_ ..tom "� �;� �� <�` '3Mr.,J�p �;r.}��¢aa - !• ^" r('lr� � ,� `.:+; .-- j - ^ `+., �.,,� `,�' � .ice .. ' m .x 'a., �XS�'► Arte00. it ,yam .i. A. �r'�.�. ►' , � �,. • '• �, � � ~ •`�.P ► F+ � ^rte 5�...H� '� �. , t , � ■ ' - �� <.r. -.die ♦ h. i - x e�, �'.t. r .. '.r . ' _ .. _ i t `i��eA . •° ..iiti'--`.ems _ � �- . _ ... _� ;� a ., ,�„ ,,,; �fit,�� t �� .,� �� .,. �"` .,. �;: _v . ��-` �,t,�.,. �� i .�, m .�, In West Staines State #2 West Staines State #2 —,I. V, J .l�'• 7Y+•1 .b iLLM1 t•i .1Y�lV �I�� µ.Fl .k �•�r� .. Via; .. , . � •�. !+ J ",.� i � �Slf�:sL.,'�.31f' ':�:. �"iS"�7f :� • ��:a. n.' tiA n!`i A r'_ �. ` � ; is tp � i • .. S. f _. Alaska State J-1 Alaska State J-1 F�+� fit A y, • t�� ,1�s- v � *...,�;_ by Al' 4 - ?� _ X . , ° • � • • h •R,, .fix .� ` ;� � yt��9�ii4^'� w ,� t w� ' ' � + ' .• + ' It j �h � s ♦ 1 _ � � � �,�'s';}�y,•!`'.y} � ; _ fib-.. _... ~f ' . . _ . '~.~ . 1 , _.., , t~v <~~~~~ ~ >.~t,: ~:~`~~ ~~ . ' ~;: r';;1/~~~~?J~I~S'~/~,"~f~;%1~^,~~~'~i' 1_:~~~.~'~;L.l;~'~~~~~~S~~S ~$~a iiar~ ~°: - '':; .~'i~~ ~ay _.~5 a.'3S~<3 ~?'Od~i:it^i' ~%[3t"!2$°:. r- ~.?e:KQC~~+~C~3[i P"O UrZiOP~ ~.Oi"Y)~"3~C1y s~~ I'~OX ! y~j~j~i i ~ ~chorage: ~i~ 99~ I. ~ ~.z. t t. Thomson `ie(Is - Plugging and Abandonment Dea;- ~~li~. Haymes. s~s .~~; ..~ A~~ ~~~~ s~ = ~ . '-.~~C ~Q€1~!~a= R~l-1S,'v~ 85 ~~~_ ''~OP~E . , _'?-" a's~ ~ q~ ~~G~ _ _ ~-- This is in response to your letter of _~lovemberr 14, 2007 responding to the Adaska Oil and Gas Conservation Commission's ("Commission") (etter of Vlay I 8, 2007 regarding the condition of certain Pt. Thomson Unit we(Is. The schedule and plan for remedial work provided with your letter are acceptabfe subject to The follo~~ing conditions: I E~conivlobil will perform the proposed fie(d work for the 2008 - 2009 r~vinter aperating season regardless of ~vhether there are any concurrent drilling operations in the Pt. Thomson L`nit. 2. All of the diese( wil[ be removed from the VV. Staines Stat~ #18-9-23 (169-120) and ~V'. Staines State #2 (175-002) we11s. If any of the dieset cannot be removed, a Commission petroleum engineer or inspector shall determine whether the shallow wellbore plugs are co-npetent, and ExxonMobi~ must take any reasonable actions the Commission deterrraines are necessary. 3. All current and future statutory and regulatory requirements and all applicable rules, orders, and permits of the Commission will be complied with unless a waiver to a specific requi;ement is timely and othea-wise properl}~ requested and granted by the ~ommission. To assist the Commission in ensuring that its fi(es are complete and accuraee, by March 3 l, 2008, please submit for each we(1 a Form IO-404, a summary of the observations from the work performed last summer. and location photos. F~nallv, nothing abuve expressly or implicitlv evidences ihe Commission's position with respect to the status of ~~conMobil or am other person as a current Pt, Thomson Unit operator, working interest o~vner, or lessee. ~i ~;ou have an, questions. please ca[1 me ac i~}3 !Z? I or ?~om IV[aunder, PE at 793-1Z~c~. Sincereld, / ~~ L%~ .~~'~~ ~ o ~ ~~~ ~ !~~~~~~ .~' ~,athv ~', ~=oerster ~or~?misssone~ ~xx~aa~oba@ I~eoaluctaon ~oa~eparay P. O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimile ~aaag c~o ~ayeraes Alaska Production Manager Joint Interest U.S. ~~ ~~~ ~~ ~roductio~ November 14, 2007 Chairman John Norman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Pt. Thomson Weiis - 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 will respond directly to the Commission on it.) This work included reviewing ExxonMobil's and the Commission's welt files, including confidential Commission files for one wefi, 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 eonditions from the wells. Attached are photos taken during the on-site inspections. The extensive reviews provide the basis for this response to the Commission's letter. While we believe the wells met AOGCC requirements when the prior P&A actions were taken and are safe in their current condition, we recognize that performing certain remedial work can further reduce any risk of an incident that may occur in the future. With that in mind, we have developed the attached schedule and plan to conduct remedial work on the wells. If the Commission concurs with this work program, ExxonMobil will prepare the appropriate sundry notices and begin to carry out the actions. As described in this letter and accompanying attachment, the plan contemplates conducting remedial work on certain wells in the near future and reclassifying the remaining wells to a suspended status. The wells with planned near term remedial work do not appear to have future utility while the wells identified for reclassification are capable of producing in paying quantities. We believe it would be premature to conduct work on these latter wells that may make it more difficult to utilize them in future development operations. There are other existing suspended wells in the Point Thomson Unit, and we view this action as consistent with current circumstances. VVe unders~~~u that ~ e~lass~f~~ation 1^ri!! ~ar ;~ ~n n~,ligation to abandon the wells in the future in compliance with regulatory requirements. A Division of Exxon IVlobil Corpoaation ~~~ ~ ~~~~ Commissioner John Norman - 2- November 14, 2007 Please note the plan calis for conducting the most intensive phase of fie(d 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 E~cxonNlobil 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 reqtaests 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, particu(arly 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 ~ted 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 ~ ~~;- E ~ ~s~fi~, 9~~ 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 wel~heads 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 ,~o ~t~~` 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 ~IO~ } 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 p o ss~~p~.~ t5 ~~ 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. 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 ~-~~5~`~~ + Repair or replace as necessary - Remove near-surface arctic pack from annulus and C~S-.`~ ' set cement plug in annulus using top job techniques ' ~ ~ long) (plug to be at least 50 , a~~' - Install marker plate ~ - Remove cellar - Conduct general location cleanup, and request final site clearance Alaska State J-1 - Remove marker post - Conduct work in conjunction with first - Remove wellhead and casing to lower than 3' below year of Point Thomson delineation ho ~~~~` ground level drilling planned for winter of 2008-09 - Verify integrity of surface plug ~p 1~~ + Repair or replace as necessary ~~'~ - Install marker plate ~?~ ~ - Remove cellar Conduct general location 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 River State #1 - File sundry notice to change well classification from - Subm~t sundry notice within 90 days of abandoned to suspended AOGC.;C concurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winteR 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 AOGC:;C concurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winter 2008-09 inspections -3- ALASKA OIL AND GAS CONSERVATION COPIMSSION August 14, 2007 SARAH PAEAN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Craig Haymes Alaska Production Manager ExxonMobil Production Company PO Box 196601 Anchorage, AK 99519 Re: Pt. Thomson Wells — Plugging and Abandonment Dear Mr. Haymes, This is in response to your letter of August 3, 2007 wherein you requested a ninety -day extension to the response time with regard to the condition of Pt. Thomson Unit wells as specified in the Commission's letter of May 18, 2007. It is stated that the additional time will allow further investigative work including site visits to the various wells. Your request is granted making your response due not later than 5:00 p.m. November 14, 2007 If you have any questions, please call me at 793-1221 or T^ Maunder, PE at 793-1250. SCANNED OCT 091 ).014 l ~ >>'~:~.~~'a i'~ ~~ ~ ~~~ ~ ~~51day 2~, 2fl07 ~om~nrssioner ~athy Foerster Aiaska Oil and Gas Conservation ~ommission 333 West 7th ,~venue, Suite 100 Anchorage, Alaska 99501-3539 Re: Point Thomson Wells - Plugging and Abandonment Dear Commissioner Foerster: _~ ~=~ ~ ~ ~' ~~~ ~ ',~ ~ ~ ' ,- ~~~~~~ ~~s ~`~ ~ ~ ''~ u ~ `,. ~ ~ ~~^~~~j~ ~ij~~~;~~ ~ ~ ~ ~:~~ ti~~~~-~ ~.,, ' ~ „~~ :~~y'~~,, ~~~ We have received the Commission's letter dated May 18, 2007 regarding potential issues related to certain Point Thomson wells that were drilled and subsequently plugged and abandoned. Regulatory compliance is a core value for ExxonMobil, and we take all matters seriously. Our prior track record of voluntarily re-abandoning some wells and undertaking other remediation work in the Point Thomson Unit should speak to this. The May 18 letter requests that ExxonMobil respond within 90 days and either provide sufficient information and documentation to demonstrate the wells meet all requirements for plugging and abandonment, or to provide a schedule and plan for bringing the wells into compliance. We have begun an immediate review of the wells in question and have two requests of the Commission to help expedite that review: 1. The well files for the Staines River St #1 well, which was drilled by Mobil in the 1979 timeframe and is under extended confidentiality, are not in our Anchorage office. It would facilitate our work to obtain a copy of the file from the Cornmission. 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 assessment 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 (forrnerly Sohio). To the extent another operator may be responsible for any of the identified we(Is we will work "vith the other owners to deterrnine appropriate handfing and response to the Commission. 9 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. ~inc~rely yours, ~" ,~,~., --.-~. ~! ~ ~" ~:ioc ;~~: Angu~ ~i~l~ik~~, ~~ ~~A6~~,~ ~~~JJ14, s~~~9~~419~1R ~~~~~~~~ ~~ '35.~ [~n'~~~~ ~~ta~ 1 ~. ?t)07 ~rai~ Hayines .~laska Production ~~Ianager ExxonR~Iobil Production ~ompany PO Box 196601 ~nchorage, AIC 99~ 19 l~e: Pt. Thomson Wells - Plugging and Abandonment Dear (~1r. Haymes, 333 W. 7ihAVEP1UE, SU~TE (00 ANCHORAGE, ALASKA 995Q1-3539 PHO(~E (907) 279-1433 FAX {9p7j 276-7542 During our review~ of the Pt. Thomson Field in response to your recent applications for permits to drill, the Alaska Oil and Gas Conservation Commission ("Cocnmission"j identified the following wells that, according to our records, are classified as plugged and abandoned but do not meet the requirements for plugged and abandoned wells under 20 AAC 2~.10~ - 20 AAC 2~.172: W. Staines St. 18-9-23 W. Staines St #2 Pt. Thomson # 1 Pt. Thomson #2 Pt. `I'homson #3 Pt. Thomson #4 Staines River St # 1 Alaska State C-1 Alaska Sta.te J-1 Challenge Island # 1 ~i'ithin 90 days of receipt of this letter, either provide sufficient information and documentation to aemonstrate that these wells meet all the requirements for plugging and abandonment, or provide a schedule and plan for bringing these weils into compliance. Also, please note that, under AS 31.0~.090, the Commission cannot issue permits to drill to an operator that is in violation of a Commission regulation pertaining to drilling, plugging or abandonment of a well. The C~mmission reserves the right to pursue an Entorcement ~ction according to 20 AAC 25- ~35. ~=~.a'j ~_)i~~ ~~4'S ~i~:o-,,- l U_ ?~~~ ~d`~~ ~ Ot ~ ~=ina(1~~, i~ot~ing abo~~ sh~~tild b~ c~~n~true:d i~ ~~~id~nc;~~ ~~pr~s~lc ~~~~- im~(i~itl~ iile C~c>me~iission~s po~itiar ~~~inc ~~spe~;i r_~ ~h~ ~~.~rrPr~t stat~.~s ~f r.~~~r~?~~D~il ~c any flti~er person as a~t. ~~h~m~~n unit op~rat~r or l~ss~e. Ii d;~u ha~~e any quc:sti~ns, please c~ll m~: at 793-1221. To: Cathy Foerster, Commissioner May 9, 2007 Fr: Tom Maunder, PE Re: Sta.tus of Pt. Thomson Area Wells Introduction: As instructed, an assessment of the wells in the P~ Thomson area was performed. The purposes of the assessment were to determine if the condition of the wells met the regulatory requirements in effect when operations were completed some years ago as well as if the wells would meet the now current regulatory requirements. There are a total of 21 wells in the general area (14 ExYOnMobil + 1 ConocoPhillips + 6 BP). This document wiil only address the E~onMobil welis. Recommendation: Based on exarnination of the well files, it is my assessment that 5 of the 14 ExxonMobil wells are Plugged and Abandoned in accordance with the now current regulations. The remaining 9 wells should be considered Suspended and AOGCC's databases should be changed to reflect this more accurate well status. Ea~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 attached. Requirements have become more proscriptive through time. There were major amendments to the AOGCC regulations effective 4/2/1986. These included significantly more proscriptive requirements for plug locations and lengths, a suspended well classification and included requirements for removal of the wellhead and casing "... at least 3' below rig grade." In the 11/7/99 amendments, the cutoff requirement was changed to "... at least 3' below original grade." Prior to 1980, 50' cement plugs were required above hydrocarbon zones atid at surface with heavy mud-laden fluid between plugs. After 1980 100' of cement was required above hydrocarbon zones and casing stubs were required to be covered. Neither regulation explicitly required cutting off the wellhead. and casings, although removal of all "... structures and installatians ..." was required as part of location cleanup in the 198Q 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 AOG~C, 20 AAC 25 The physical downhole work on 7 of the 14 Ea~onMobil operated wells was completed prior to April 13, 1980 and physical downhole work on 6 of the remaining wells was compieted prior io t~pril ~, i y8~. i ne iast weii, tii.asica ~iate ti 2, was piugged ana abandoned in 1Q 2002 according to the 11/7/99 regulations. Regardless of when physical operatians were completed in the legacy wells, letters were submitted (most in November E~onMobil Operated Welis Pt. Thomson Unit Area ~-~j Well PTD Date Date Work to Effective Re ulation? Comment Assessed Actual Required Work Suspended P&A 9/30/67 4/13/80 412186 ll/7/99 Status W. Staines St 169- 8/13I70 5/1/73 by YES YES NO NO Diesel in annulus and Suspended Remove fluids, place 18-9-23 120 sun casin . Not cutoff. lu s, cutoff wellhead Alaska State A-1 174- 9/6/75 ~ by letter YES YES NO YES Re-abandoned 1998 -1999. Plugged and None 0~4 11/86 Abandoned W. Staines St. #2 175- 5/26/75 ~ by letter YES YES NO NO Diesel in casing 150' - Suspended Remove fluids, place 002 9/8b 2279'. AP in annulus. Not plugs, cutoff wellhead cutoff: Pt. Thomson #1 176- 12/8/77 * by letter YES NO NO NO No plug above cut 7" at Suspended Remove fluids, place 085 11l86 4000'. Diesel in casing. plugs, cutoffwellhead AP in annulus. Not cutoff. Pt. Thomson #2 177- 8/12/78 ~ by letter YES YES NO NO AP in annulus. Diesel in Suspended Remove diesel. Cutoff 064 11/86 casing at 40'. Not cutoff. wellhead. Reroove some AP. Pt. Thomson #3 178- 7/4/79 ~ by letter YES YES NQ NO AP in annulus. Diesel 'm Suspended Remove diesel. Cutoff 005 11/86 casing at 40'. Not cutoff. wellhead. Remove some AP. Staines River St 179- 7/21/79 11/5/86 by letter YES YES NO NO Diesel in casing at 100'. Suspended Remove diesel, place #1 confidential 001 11/86 Not cutoff. lu s, cutoffwellhead Pt. Thomson #4 179- 12/20l80 ~ by letter NA YES N0~ N0~ AP in 2 annuli. No diesel. Suspended Cutoffwellhead. 080 11/86 Not cutoff. Remove some AP. Alaska State C-1 180- 7/14/81 ~ by letter NA YES N0~ N0~ AP in 2 annuli. No diesel. Suspended Cutoffwellhead. 046 11/86 Not cutoff. Remove some AP. Alaska State D-1 180- 2/16/82 ~ by letter NA YES NO YES Re-abandoned 1998 -1999. Plugged and None 101 11/86 Abandoned Alaska State F-1 181- 5/30/82 ~ by letter NA YES NO YES Re-abandoned 1998 -1999. Plugged and None 140 11/86 Abandoned Alaska State G-2 182- 8119/83 ~ by letter NA YES NO YES Re-abandoned 1998 -1999. Plugged and None (confidential 208 11/86 Abandoned Alaska State J-1 183- 6/14/84 ~ by letter NA YES N0~ N0~ No open hole plugs. No AP Suspended 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. ExxonMobil Production Com~ P. 0. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimile December 19, 2008 Crai~ Hay/mes Alaska Production Manager Joint Interest U.S. EonMobil I'roducti®n ~~:~ Mr. Johnny Aiken pp cc c North Slope Borough f~E~G~~G~ Planning Department p~~ 2 ~ 2008 P.O. Box 69 Barrow, Alaska 99723 Alaska Oil & Gas Cons. Commission Re: Point Thomson Unit #1 Conditional Development Permit Application AnchtNage 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 #1 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 NORTH SLOPE BOROUGH ,~ DEPARTMENT OF PLANNING AN DCOMMUNITY SERVICES Regulations Permit Application PERMITTING AND ZONING DIVISION d'I-rwi'" Permit Number ~ Permit Type Conditional Development Applicant Exxon Mobil Corporation Date December 19, 2008 Address P.O. Box 196601 State ID Anchorage, AK 99519-6601 Phone 907-564-3617 Contact Person Mike Barker Project Name Point Thomson Unit #1 Well Inspection Location (TRS) 1,320' NSL 660' WEL Sec. 32 T10N 823E UM Unitized Field Name Zoning District and Pad Location Point Thomson Unit #1 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 Acres ® Oil and Gas Wells Number of New Surface Holes: 0 ® Temp. Water Use Source Alaska State C-1 Pit and Lake 17 Equipment All terrain vehicles, trucks. Purpose Water for camp, ice road construction Maximum Amount 1,000,000 gpd All terrain ve 'cles, rolligon, ® Off Road Travel: Period of Travel Feb 1, 2009 -Aug 31, 2011 Equipment Steiger. aircraft Access to Site All terrain vehicles, aircraft ®Fuel Storage Type Diesel fuel stored in steel tanks Amount X10,000 gal on-mo I e 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 ~. ATTACH TO THIS APPLICATION THE FOLLOWING: -GENERAL VICINITY MAP -SPECIFIC LOCATION MAP, INCLUDING NEARBY EXISTTING DEVELOPMENT AND NATURAL FEATURES -SITE SPECIFIC FOOTPRINT (IN ESRI SHAPE FILE FORMAT) ON A CD-ROM -A DIGITAL GIS SHAPE FILE OR GEODATABASE OF THE PERMIT AREA WITH NO ATTRIBUTES. THE PROJECT SHOULD BE NAD 1927 ALASKA ALBERS OF GEOGRAPHIC -DESIGN PLANS (PLOT PLAN), ELEVATIONS, CROSS SECTIONS, PROFILES. AS APPROPRIATE -SUPPLEMENTAL INFORMATION, AERIAL PHOTOGRAPHS, STUDIES, ETC. (AS NEEDED) SEND TO:NORTH SLOPE BOORUGH, LAND MANAGEMENT ADMINISTRATOR PO BOX 69 BARROW, ALASKA 99723 PHONE: (907) 852-0320 I HEREBY CERTIFY THAT THE FOREGOING IS TRUE AND CORRECT TO THE BEST OF MY KNOWLEDGE Signature Craig A. Haymes Name ~. ~---11~€ ~A`~ Date Alaska Production Manger Title FEE PAID ^ SPECIAL PLANNING COMMISSION MEETING ....$12,000.00 ^ DEVELOPMENT PERMIT...$2,000 + $500 PER WELL ^ ADMINISTRATIVE APPROVALS ...$1500.00 ® CONDITIONAL DEVELOPMENT PERMITS...$3,000.0 AMOUNT PAID $3,000 DECISION ^ ADMINISTRATIVELY APPROVED This is a minor amendment to a development permit or is a use of land listed under administrative approvals for this zoning district. ^ REZONING APPROVED This proposed development substantially complies with the Master Plan, and a use permit is issued, conditioned on compliance with all relevant Master Plan conditions, lease stipulations and provisions of state and federal law and permits served there under. ^ DEVELOPMENT PERMIT APPROVED The proposed development meets all applicable mandatory Policies, represents the Developer's best efforts to implement all relevant best efforts and minimization policies, and as long as any conditions set forth in the accompanying letter are complied with, will represent a net public benefit. (See accompanying letter) ^ CONDITIONAL DEVELOPMENT PERMIT APPROVED This is a use of land that is listed as a conditional development for this zoning district or has been elevated by the Land Management Administrator to the Plamvng 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 fiuher remedial work on plugged and abandoned wells, and 3) closure of the open reserve pit at the West Staines State #2 well location. Assuming receipt of all required permits and authorizations by January 30, 2009, the work will commence about February 1, 2009, and be completed by April 15, 2009. During the summer of 2009, the locations will be visited by helicopter to allow for further clean-up and inspections. If the sea ice road for the drilling program is not conducted during the 2008-09 winter season, the inspection and remediation work that is conducted during the 2008-09 winter season will be supported by agency-approved off-road vehicles such as steigers, cat trains or rolligons or a combination of all off-road vehicles and conventional vehicles on local ice roads. 2. Permit Requirements This project description provides information necessary to support the applications for permits, authorizations, and coverage under general permits summarized on Table 1 which are required to conduct the desired remediation work. Page 1 of 6 Table 1-Permit Requirements C~ 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 tce Roads (onshore) • Temporary Water Use Permits** Department of Fish and Title 16/41 Fish Habitat Permit"" Game Department of • Reserve Pit Closure Plan Environmental Conservation Sec. 401 NPDES Water Quality Certification** (ADEC) Alaska Oil and Gas Sundry Notice Approvals for well work Conservation Commission AOGCC Borou h/Local • North Slope Borough (NSB) Conditional Development Permits for activity in a Resource Development District without a Master Plan (within PTU) • Develo ment Permits for activities outside PTU United States of America • Environmental Protection • Notice of Intent for coverage under NPDES General Permit AKG- Agency 33=0000 for Gravel Pit Dewatering'* • Sill Prevention Control and Countermeasure SPCC Plan • US Fish & Wildlife Service • Letter of Authorization (LOA) for Incidental Taking of Polar Bears USFWS and Pacific Walrus" * Approval of the lease Plan of Operations is the primary authorization from DNR for conducting well and related operations on a lease. All of the former exploration well operations were conducted under an approved lease Plan of Operations. The status of these Plans of Operations is uncertain and ExxonMobil will work with the DNR/ DOG to determine appropriate authorizations for this work. ** Applications for similar activities were requested for the Point Thomson Drilling Program. Coverage under the existing requests to cover the remediation program will be requested rather than submittal of new applications. 3. Site Access Site access primarily will be accomplished through the use of vehicles traveling on ice roads or off-road vehicles. Helicopter or fixed wing aircraft will also be used depending upon activity for the Point Thomson Drilling Program and the logistical capabilities that are available. Figure 1 Page 2 of 6 • shows the tundra and offshore ice road routes between the Prudhoe Bay area and the Point Thomson area. Figure 2 shows the specific drill site locations and tundra travel or ice road routes within the Point Thomson area. 4. Well Remediation Work There are nine former exploratory wells in the Point Thomson area at which ExxonMobil is planning to perform remedial work. The names of the wells and work being considered are shown on Table 2. Four of these wells have been plugged and abandoned (P&A'd) and five are suspended. All nine wells have wellheads that are partially or completely covered with gravel. ExxonMobil plans to excavate the gravel from around the wellheads, perform visual inspections of the wells, and install pressure gauges to verify there is no internal pressure. This work will be accomplished in the winter of 2008-09 and is not dependent upon the ice road or drilling program activities. Removal of debris and location clean-up will be performed at all sites as necessary. The excavated gravel will be retained on location. For the four P&A'd wells, ExxonMobil plans to remove marker posts, cut and remove casings to at least three feet below natural ground level, and weld marker plates upon the casing stubs to conform to current AOGCC regulations and practices. This will also include removal of some hydrocarbon based fluids from within the wellbores and verifying the integrity of existing cement plugs or placing of new cement plugs. The specific actions to be performed on these wells will be addressed in Sundry Notice requests submitted to the AOGCC. For some wells, it maybe necessary to mobilize a coiled tubing rig or other light duty drilling equipment to the area to conduct well remedial work. Table 2 -Point Thomson Area Wells Well Name Surface Location Well Status Planned Work PTU #1 1,320' NSL 660' WEL Suspended Inspection Sec. 32 T10N R23E UM PTU #2 2,615 NSL 1,801' WEL Suspended Inspection Sec. 3, T9N, R22E, UM PTU #3 660' NSL 711' WEL Suspended Inspection Sec. 34, T10N, R23E, UM Alaska State C-1 660' EWL 660' SNL Suspended Inspection Sec. 14, T9N R23E UM Staines River St. #1 321' NSL 1,658' EWL Suspended Inspection Sec. 17 T9N R24E UM PTU #4 2,700' NSL 2,900' WEL P&A'd Inspection, well remedial work Sec. 32 T10N R22E UM Alaska State J-1 1,886' NSL 2,404' WEL P&A'd Inspection, well remedial work Sec. 23 T6N R22E UM West Staines St. #2 848' SNL 50' WEL P&A'd Inspection, well remedial work, Sec. 25 T9N R22 UM reserve it closure West Staines St. 1,514' SNL 1,730' WEL P&A'd Inspection, well remedial work 18-9-23 Sec. 18 T9N R23E UM Page 3 of 6 • 5. West Staines State #2 Reserve Pit Closure The West Staines State #2 exploratory well site has an open but inactive reserve pit. The closure plan will include filling the pit and installing a gravel cap designed to eliminate ponding of surface water within the reserve pit footprint. An estimated 17,000 cy of fill material is required to fill the pit and construct the cap. It may be possible to obtain these amounts from existing gravel at the West Staines St. #2 pad and West Staines St. 18-9-23 pad approximately 2 miles to the north. Other sources of fill material are being evaluated and may be proposed to the ADEC as part of the closure process. Further details will be provided in the reserve pit closure plan that will be submitted to the ADEC for review and approval. 6. Water Requirements and Sources A temporary Water Use Permit (TWUP) was previously requested to obtain water from the Alaska State C-1 gravel pit. That permit application will be modified to also include additional shallow (non-fish bearing) lakes in the Point Thomson area and the scope will be broadened to address this remediation project. If ice roads are used, water will be hauled using water trucks or tanks on conventional trucks. If off-road vehicles are used, the water will be hauled in tanks placed on the off-road vehicles. 7. Logistical Support The remediation work will be supported by an existing camp at the PTU 3 pad, which was staged to support the Point Thomson Drilling Program and by one or more portable camps that may be transported to each location. These camps will be equipped with potable water storage tanks, gray water treatment plants, electrical generators, fuel storage tanks, and small incinerators. All camps will operate under valid public drinking water supply and environmental health/food services permits issued by the ADEC to the camp operators. Up to 10,000 gallons of fuel will be stored on location and will be re-supplied as needed. Pump houses will be located on the water source lakes and be fitted with ADF&G approved water intake structures. 8. Waste Management Solid, non-burnable wastes will be deposited into containers on site for back-haul to the Prudhoe Bay area for disposal. Any food wastes that could attract wildlife will be incinerated onsite, stored in enclosed containers awaiting periodic hauling, or hauled each day to the PTU 3 staging area. Camp waste waters will be treated and discharged to the tundra by the camp operators in accordance with EPA's NPDES General Permit AKG-33-0000. Page 4 of 6 • 9. Wildlife Issues Wildlife that could be in the area during the winter includes owls, ravens, arctic foxes, polar bears and brown bears. Polar bears are expected to be present in the area and are known to den in the surrounding coastal environment, Brown bears inhabit the general area. It is unlikely they will still be active during the winter season but they may be present beginning in April when they emerge from their dens. LOAs from the USFWS for the incidental take of polar bears and Pacific walrus will be requested, and operations will be conducted in accordance with those authorizations. A Bear- Personnel Encounter Plan which describes procedures to protect bears and personnel and avoid encounters has been prepared. The USFWS will be consulted as appropriate during planning and construction of ice roads and in conducting surveys to identify dens. If a polar bear den is identified, the USFWS will be notified and the transportation route will be altered to maintain at least one mile from bear dens unless otherwise approved by the USFWS. Approval for such changes will be addressed via the Land Use Permits. Project personnel will be instructed not to feed wildlife of any type or in any other way attempt to attract animals and birds either at the drill site or on ice roads. Food will be kept inside buildings or containers that minimize odors. Hazardous materials will be kept in drums or other secure containers. Any bear sightings will be immediately reported to the site superintendent and the personnel in the area warned of the location of the animal. Dedicated bear monitors will be maintained on location to look for and identify evidence of bear presence in the project vicinity. Upon identification of bear signs or a sighting, the bear monitor will notify the site superintendent of the presence of bears in the area. Bear monitors will also be assigned to continually watch bears when present in the project vicinity. Qualified bear monitors from the village of Kaktovik or Nuiqsut will be employed, if available, particularly during periods of potential subsistence use of the Point Thomson area to monitor project activities and coordinate with onsite staff to ensure subsistence activities are not impeded. 10. Oil Spill Contingency Plans ADEC does not require oil discharge prevention and contingency plans be prepared or approved for rernediation projects including well entries such as are being considered here. Spill Prevention Control and Countermeasure Plans (SPCC) as required by EPA regulations will be prepared and in effect. Page 5 of 6 11.0 Communications and Supervision An ExxonMobil designated representative will be on site at all times during operations. Twenty- four hour phone service will be available at the drilling or construction camp. The following persons or positions are designated contacts for the project. Name Title Phone/Email Mobile Phone TBD On-site TBD NA Su ervisors Mike Barker Regulatory 907-564-3617 907-223-9904 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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I^^ ~ fit! i F --~~ 1 l '~ °7 '~- ~:~bl s~' % ^+v,~~4~ t ~ of` I, ~--4_ '~ .2 ..+=. 7 ::..(.- ,.s. .+~'fhZ'';'~Y '`~~~ { ~ l~ ~ ~ d ,'-C ~r ~.? pr,l.~Y{`'•~+ ry,T,r., ~ir ~ i7l a~ 1r~~fi ~ ~s ~.~i h~v `.i?.~ } . .,1,•-~4'.`.1. ~. ~~'~ ll -ti•T" ,['i r ~.l .. l,~`i$,~ ~~'Ca~°~"'~~^ ~ y ~'3, .'~~u '` .x _ _. .. .. i ~ . ~ _7 7~ +d.. `..t.I ._ -7- /* "+------- ----36 31 ql- PTU-_4 --mFL4 ;U;1 PTU�3— PTU LN t i2 14 isA% UMb 18LO'9;23,-- Alas -a -.3 to Staines Is 24 19 2122 23 O:N6 I St nos iR verS.t%a 21 22 23 19 24 j — --------------- 25 30 28 0 West,Staines,Noi2 0 24 2B, 31A, 3\ 3- 1/"- as 31 32 33 ICA fin 4 3 , %. `i •�-. 2 D 4 __/2 12 .00 9 12 15 14 13 17 0 16 14 1 17 �f4 -77' 14 20 21 2223,., 2,l 20 21 2L 2' 2 D1 i 28 2625 30 22 1 26 28 21 30 j X �1; zi 33 36 33 33 L ? 33 3 34 4� V36 4 6 5 4 . ........ — ------------- 1— el- to J is 13 rw 17 16 16 20 21 23 202 21 21 dk N; 26 29 28 28 . .... . ..... 34 N� 32. 36 31 33 34 + A C, 46. 2 < V2� 7L 9 d .Z7 31 APA L t4 't11 '. 14' at 7 r 4 3 CT-J." d Figure 2: w Proposed Tundra Travel or Ice Road Routes, E*(onMobil Point Thomson Area ft• kW By. 0 0.75 1.5 2.25 3 12115/2008 P&A Trails Rov2.mxd Miles -i- CT-J." d _COASTAL FRONTIERS PERMANENT RECLAMATION AND ABANDONMENT OF ALASKA ISLAND DRILLING PAD Coastal Frontiers Corporation 2193 North Roosevelt Avenue Altadena, California 91001 (818) 398-0081 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. 2 Pt. Thomson Unit Well No. 3 Alaska State A-1 Alaska State C-] Dear Mr. Clement: Our representatives inspected the above referenced locations on August 27 and September ]2, 1986, and found that cleanup was acceptable. Marker posts with the required information bead welded on them were in place. Your letters dated November 10, 1986 requested that we change the status of each of these wells from suspended to abandoned. Since there were no changes made to the well bores of these wells, we did change the status to abandoned on the "Well Completion or Recompletion Report and Log" which had previously been submitted for each well. Based on the above, we hereby approve the final location clearance for the Pt. Thomson Unit wells Nos. 1, 2 and 3, and the Alaska State A-1 and C-1 wells. Sincerely, . t~ Lonnie C. Smith Commissioner jo/A.HJH.47 EE) ON COMPANY, U.S.A. POST OFFICE BOX 60620 · NEW ORLEANS, LOUISIANA 70100-0626 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 47560, Point Thomson Unit, Exxon No. 1. Please refer to the attached form (P-7) for plug and suspension details dated 12/8/77. TVB: j cv Attachment Sincerely, A DIVISION OF EXXON CORPORATION -' "~TATE OF ALASKA i ". ' :~,r~- IT .'~¢tJOl'il · OIL AND GAS CONSERVATION COMMITTEE .*,.r..id., i , i I I II I i iii WELL COMPLETION O- RECOMPLETION REPORT AND LOG* i I iii ! I 11. TYP!~' OF W~L/~.' OiL I - ..w 0 '°'0 '"0 "~"0 "'" ~ o~c~ nc~R. U Otb~ ~ I. U~IT~F~ OR =. ,,,, o, o,,,,,o, -~ " ~ ~~ ~TR ~//-/~-~"' Point Thomson Untt Exxon Co~poration W~W ~. ~--.= o~'o...o~ .... Exxon No. 1 P.O. Box 2180, Houston, Texas 77001 ~,.r~~oaw=~ 4. ,.oc..,o, o..=~ (~e.- ,...o. ~,,..,...~ ,- .--,.,.--- ~"~'*-" ~,.',--e.,-----,,~' .~,.... 1320' NSL & 660' ~EL of Sec. 32, T~ON, R23E, UP~ o. s ' luggea s ~us~naea / 33.45' KB'X 3-6-77 9-12-77 , 12-R-77 . Il. T~A~ D~H, ~ & TVD~J. ~bUo, ~ MD & ~. a ~~ ~, ! ~. I I '. ~ I ~W ~yo I IOTAR~TOOL8 ..... ~ I CAILI ~OOLI .. ]s,~9a l ~ ~u~ace I, --- i . ~11 n. P~oDucINO I~A~(Si. OF ~S C~I~,'~M, ~i ~ AND ~) ..... In.'w~ Perforations cemented for purposes of safety. See item Z8 and · ' for perforation intePvals and cementing. See Attachments for test data.J N0 50-089-20005 ADL 47560 1. 11~ INDIAN. A. LI~ OR TRIBE NAM.~ OBJIOTIVI) Sec 32,T10N, R23E UPM (Pre-Mi ss) 76-05 ~T. a& ~m).l,. =.~.v. cAsmoHEAD ' ' I 24. TYPE FJ.~CTRIC AND OTHer l~)GS RUN Dual Induction, Sonic, Density, Compensated Neutron, Oiometer. Vi~Ioc~tv' Rorehole Geom._try. Thermal flecav . CASI~IG R]~O~ (Repofl ~11 ilrlllfI let bi w~,ll) · . 28" x 36" insulated dondlfct~r R3' 4?'' l'tn ~urfac. wif_h n.rmmfrndt cml__~ Nnnp 1 ~~ / ~ 'l ~ ~ I ~ m I K-- ~ ~ ! ~1 I I 24. i 6.':Ifil1 ~x P~rmafr~t cmt I Nnn~' 9 5/8" 40 . I s0h~sl ~ss~' 1]~ 1~4,,I lS~0 sx cia~S..G .... - . ! 7" * q032 ~ ' 113qfl I 6rio nnn~ _ 4¥, [ 10873" 1'13295 I 317 [ none , zm. PE)~U~AI'IONS OP~ TO P~ODU~O~ - ~in~, mlze mod number) ~ ~. ACZD, SlZO~, F~'U~, C~X~N~ SQU~Z, ~C.' .... ]2,834' to ]2,874' (4 spt) ~'~,~~J ]2,963~-].3,050'1. s~z cmt w/]45 sx class G 11,392' to 11,42]' (4 spt) 12,834'-12,874'/ sqz cmt w~76 sx Class ~}~'.~ i819~ i',392' 11,421'~ sqz cmt w/50 sx Class G ~ =~'.. .~ ..... i iiii ii i i m iiii i m I DArE FinST PRODUC~ON ~ODUCTION ~~low~g, :Gas liI[~ mmpml--mize and type of prop) W~LL STATUS (Produc~ or SEE ATTACHMENT ~ ...... i · JA~! i 01978 Bl~ir Core Data, Test .Data' Evision ot Oil nnd G~s Di~t. Mgr. Ilff~hnre/Ala.~ka. DATI:I *(See Instructions and Spaces for Additional Data on Reverse Side) * 7" liner tied back to surface; was backed off at 4003' and pulled. STATE OF ALASKA ~-¢ AL" A OIL AND GAS CONSERVATION CO, !SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate L~ Pull tubing Alter Casing [] Other I~: Final Location Abandonment 2. Name of Operator 3. Address Exxon Co., U.S.A. P. O. Box 60626 New Orleans, LA 70160-0626 4. Location of well at surface 1320' Sec 32, T10N-R22E, UPM, At top of productive interval At effective depth At total depth N.S.L. & 660' W.E.L. North Slope Alaska of 5. Datum elevation (DF or KB) 11 ' GND 6. Unit or Property name Pt. Thomson Unit 7. Well number No. 1 8. Approval number 333 9. APl number 50-- 089-20005 10. Pool Wildcat 11. Present well condition summary Permanently pluaqed to surface lotal depth: measured 7ee[ ~Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) Measured depth True Vertical depth Gas Cons. 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby'/ certify that the_ fo,,~oing Ls truel~ // and correct to the best of my knowledge ~ ~r. ~ Signed ~. P. Clment, III Title New Orleans Drilling Mqr Date 9/25/8( Form 10-404 Rev. 12-1-85 Submit in Duplicate Feet MEMORA 'DUM Staf of Alaska ALASKA Oil AND GAS' CONSERVATION CO~MI` 'ION TO' ~/f¢%hatterton DATE:Sept ember 5, 1986 '""~'"~c~~,'~' ~, ,~ ~o.. ~. ~. 2 o TH RU: FROM' Lonnie C. Smith ///?~'~'~ TELEPHONE NO.: C ommi s s ioner SOSJECT: Location Clearance Exxon Point ThomPson John F. Boyle .~.n~!. Unit #1 Petroleum Engineer Asst Permit No. 76-85 Wednesday, August 27, 1986: I traveled this date from Anchorage to p~-~dho'e~' Ba~' and metwi~ ~om Burford, Exxon representative. I visited the above listed location and observed a small 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 02-'001 A(Rev 10-84) 'ALASKA OIL AND GAS C(IKSERVATION COMMISSION ~" SURFACE ABANDO;~MENT REPORT 20 AAC 25, ARTICLE 2 FILE INFORMATION: Operator ...~. .~ ~./ Address ~i~ . ~:~:~ ~(oO Surface Location of Well Sec. ~, T /~ ~, R ~ Date Downhole P & A Permit No --2~ - AP1 No. 50- f>~-~/ ...... '- Unit or Lease Name~_v~vV- Well No. /: Field & Pool Welds 20 AAC 2~.120: WELL ABANDONMENT MARKER: Dia. Steel Post (4"Min.) ~'~ Length (10' Min.) f~ '~ Height Above Final Grade Level (4' Min.i . / ~ ~. 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. in. Side Outlets: All Valves and Nipples Removed ~ 3 All Openings Closed ~', With Blin~s ~, With Cement , Other INFORMATION BEADWELDED DIRECT~LY TO MARKER POST: (List k~ere Different fro..__~m File Information) Operator '~.:-i~! '..'. ~:, ~p,~'?, Unit or Lease Name ~.-~ ~ "~ ~. ~ , .~ Well Number ~ ~ ~ , Surface Location of Well: 20 AAC 25.170: LOCATION CLEAN-UP PITS: Filled In~,~g, Liners Removed or Buried 'i~ ~ , Debris Removed SURFACE OF PAD AND/OR LOCATION: Rough , 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~4 , Grass , Dirt , Gravel ..CONDITION.___SURROUNDING AREA: Clean.~.' , Trash from Site Other , Trees and/or Brush from Clearing Site ., ~ ACCESS ROKD: _ , Gravel__, Ice__, Other ~//~ Dirt.. CONDITION ACCESS ROAD AND SURROUNDING: gao , om Clean , Rough , oth Trash fr Operation, s , Trees and/or Brush from Clearing Road , Spoil from Clearing Road Other ,. REMAINING TO BE DONE: RECOMblEND-APPROV. AL OF ABANDONMENT: Yes ~, c;! ' "' -(3 No Final Inspection ~' DATE '~'1'::'i': C"'"~ __ x 't ., - - :{ ~` -rz "~ra~viiA~ ~yC,~oN s 4 r~-e~ ~s ~~ i N ~ ~+~r~soa ~~+~*~ 1. ~\~. 5~.~. A, ro~i ~~ ,_~ ,~ ;~ ; ~~~ ~ ~-, ~ ~~~~ 4 Av ~_. e a CLE,aN A ~U ~~„~ ~~"? ~~~~~~ ~` y~~S~ 7`F' STATE OF ALASKA ALAS,..;..., OIL AND GAS CONSERVATION COM;. ~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing I'll Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [;~1 Perforate [ ! Other 2. Name of Operator Rxxon Coz'r~oany U.S.A. 3. Address P.O. Box 196601 Anchorage, Alaska 99519-6601 4. Location of well at surface 1320' N.S.L. and 660' W.E.L. of Sec. 32, TION, R22E, UPM, North Slope, Alaska At top of productive interval At effective depth At total depth 5. Datum elevation (DF or KB) Approx 11' G~D 6. Unit or Property name Pt. Thomson Unit 7. Well number 8. Permit number 76-85 9. APl number 50-- 089-20005 10. Pool Wildcat 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 true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) Measured depth True Vertical depth RECEIVED AUG 1 ¢, !98~ 0il & Gas Cons. C0mrn,ssi,,~? Anchcr,'~ge 12.Attachments Description summary of proposal ~ Detailed operations program E-J BOP sketch 13. Estimated date for commencing operation August 15, 1986 14. If proposal was verbally approved Name of approve% tv~'o Lo:D~'ie S:tTL~t~ Date approved 15. I here~t is true and correct to~e~:st of~ knowledge Signed / ~/;~ . ~ Title July 8, 1986 Date ~ Commission Us'~ Onl-/ Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location cleara~nce '~ ,~,~, , ~,,~,' '~ ~ ~:~:,~ '-~.-~ ............ ' Approved by ~ ;¢;;~ ¢,t,,,,,, Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Plan to convert Pt. Thomson #1 well from suspended to permanently abandoned status: 1. Remove valve and blind flange. 2. Level mound near wellhead. 3. Remove ratholebelow grade. 4. Remove cellar material below grade. MEMORAI,! UM TO: THRU: FROM' Stat of Alaska ALASKA OIL .~{D GAS CONSERVATION COMMIS~_ON C. V.~~rton Chair~~~ L°nnie C. Smith C ommi~ s iomer Doug Amos Petroleum Inspector DATE: August 12, 1986 FILE NO.: D.ADA. 40 TELEPHONE NO.: SUBJECT: Clean-up Inspection Exxon Pt. Thomson ~1 Permit No. 76-85 For Final Abandonment W~dnesdaY,....June .1~, 1986: I traveled this date from Kuparuk to prUdhoe Bay and 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. SUMMARY OF 1986 LOCATION CLEAN-UP WORK Location Pt. Thomson #1 Required for Suspension Required for Abandonment No work required -Remove valve & blind flange & needle valve -Level mound near well- head -Remove rat-hole below grade and cellar Pt. Thomson #2 No work required -Smooth down gravel mound near wellhead -Remove debris Pt. Thomson #3 No work required -No work required pro- vided wellhead is not too high after abandoning pit Alaska State A-1 No work required -Remove debris -Lower wellhead Alaska State C-1 No work required -Cut off refrig pipes below grade -Remove valve & blind flange & needle valve Alaska State J-1 Remove trash -Remove sewage lift station -Remove debris-Regrade & smooth pad-Verify cellar filled with gravel - under water when inspected -Remove cellar boards 7/8/86 'ALASKA Oii, AND GAS SURFACE ABANDCNMENT REPORT 20 AAC 25, ARTICLE 2 FILE INFORMATION: Operator ~40~ ~.20~, Address ~>, O, Oox ~ ~O~ ~ ~~-~ Surface Location of Well ' _]5~ Ft. FNSL, ~0 Ft. FP~gL, , 20 AAC 2~.120: WELL ABANDONMENT MARKER: Date Downhole P & A 1~--~' ~ Permit No AP1 No. Unit or Lease Name Well No~ Field & Pool ~'~ Dia. Steel Post (4"Min.) Otl Length (10' Min.) 1~ Height Above Final Grade Level (4' Min. . .... i. ~ -- 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 ~,(D All Openings Closed~.~ , With Blinds ~ , With Cement , Other INFORMATION BEADWELDED DIRECTF~LY TO ~9\RKER POST: (List Where Different from File Information) Operator ~.O,~ ~x~_~.~ Unit or Lease Name ~D~ Well .Number .~ ! , Surface Location of Well: 20 AAC 25.170: LOCATION CLEAN-UP PITS: Filled In ~, Liners Removed or Buried "l~.~, Debris Removed SURFACE OF PAD AND/OR LOCATION: Rough , Smooth , Contoured ~ Flat Other , Compacted CLEAN UP OF PAD AND/OR LOCATION: Clean__, Pipe Scrap __, Iron Scrap Wood Paper__, Other , Mud , Careen t SURROUNDING AREA: Wooded , Brush Sand , Other Tundra ~ Grass__, Dirt__ , Gravel CONDITION SURROUNDING A~EA: Clean ~/, Trash from Site Other , Trees and/or Brush frown Clearing Site ACCESS RORD: 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 k! //~, RECOMMEND-A-PPRO~AL OF AB~DO~iENT: Yes , No ~ Final Inspection 05/zs/si - p~S TC~Y-~ n 1~J~`~S~I~~S° ~O~ E2~ ~~ vN rfi. ~rroNi.x~N ~,...~ 1,v~u~ ~ ~~~ ~,`c.s~. n c~J K~~~ ~~ ~ '~ ~ 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 ~1~ Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA ,~IL AND GAS CONSERVATION C,~-MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. ' 76-85 3. Address 4. Location of Well 1320' NSL and 660' WEL of Sec. 32, TION R23E, UPM, North Slope, Alaska 5. Elevation in feet (indicate KB, DF, etc.) . 11' GL 6. Lease Designation and Serial No. ADL 47560 8. APl Number s0- 089-20005 9. Unit or Lease Name . Pt. Thomson Unit 10. Well Number Exxon No. 1 11. Field and Pool Wildcat 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing' [] Perforations [] Altering Casing Stim u late [] Abandon [] St im u lation [] Aba ndo nment 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 ,o5.105-170). 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. RECE Vr AlasKa 0il & Gas Cons, Anchorage 14. I hereby certify t~¢{'~ for. eg~n~ismcr~e and correct to the best of my knowledge. Exploration Coordinator - Signed (V Y_ N~/~~,~-, Title Alaska The space below for Commission use~ Date 9/10/85 Conditions of Approval, if any: " ' ,,"/i? By Order of Approved by. COMMISSIONER the Commission Approved Cop'y m_ .... Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA ~L AND GAS CONSERVATION C~,MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. 'DRILLING WELL [] COMPLETED WELL [] OTHER rX1 2. Name of Operator 7. Permit No. Exxon Corporati on 76-85 3. Address 8. APl Number P. 0. Box 6601, Anchorage, AK 99502-0601 so-089-20005 9. Unit or Lease Name Pt. Thomson Unit 4. Location of Wel! 1320' NSL and 660" NEL of Sec. 32, T10N R23E, UPH, North Slope, Alaska 5. Elevation in fmmt (indicate KB, DF, etc.) Approx. 11' GL 6. Lease Designation and Serial No. ADL 47560 10. Well Number Exxon No. 1 11. Field and Pool Wildcat 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] . Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other [] Other [] Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We request a one year extension to August 1985 of the suspended status of this well. We will arrange to have the location inspected by your representative on a yearly basis or until final abandonment. /U~sk~ 0il & (-;~s Cons. Commission Anch0ra~]e 14. I hereby certify that the~f~ regoi)qg .i,s~jrue and correct to the best of my knowledge. Signed Title A1 aska The space below for Corn 'ss'o s~ Date -. · .= ? Conditions of Approval, if any: 8T LON~I[ C. SNITit Approved by_ COMMISSIONER Approve(~ Copy Roturnecl __ By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MEMORANoUM State of Alaska TO: THRU: FROM: ALASKA OIL AND GAS CONSERVATION COMMISSION C. V ~t, erton DATE: Chai~~-~ FILE NO: Lonnie C. Smith ~ TELEPHONE NO: C ommission~,~ Bobby Fos~e_rr~b; SUBJECT: Petroleum Inspector September 11, 1984. D.31.62 Inspect Suspended EXXON Locations Listed Below For Suspended Status. Wednesday, September 5, 1984: I traveled this date to Prudhoe Bay and met with Junior Westbrook and Noreen Borys, Exxon representa- tives. As the attached pictures show the locations listed below are in compliance with AOGCC regulation 20 AAC 25.170. Therefore I recommend to the Commission that these wells be accepted as sus- pended from September 5, 1984 thru September 5, 1985. Duck Is land #2 Duck Is land #3 Alaska State A-1 Alaska State C-1 Alaska State F-1 Point Thompson #1 Point Thompson #2 Point Thompson #3 Attachment/pictures in file 02.00IA(Rev, 10/79) Suspended Well and Location Report 20 AAC 25, ARTICLE 2 ? FILE INFORMATION: -- ~ , ' ~perat6r ~~4~_~ ~_ _~ '_ ~ Date Suspended ~/~-~ .~-~ Address '_~6~-~ ~/ ~3~~~~ ~~._. ' Surface L66a~io~ ~f Weil ........ / .... Permit No. ~-~' ~ ~- Sec.~ ~m ~, ~~, ~M. unit or Lease Nam~~=~~~J~~'~- Wel 1 Condition of' Pad Condition of Pits _~~ ~,. Well head - Ail outlets plugged Well sign - Attached to well head Attached to well guard Attached to No Information correct No Cellar - Ope n ed Ye s No Fi 1 led /~S% No Covered ~ No WaterWell - Plugged off Capped Open Rat Hole Open Fil led Covered Exp la ns ti on ~//~ Ye s No Ye s No Ye s No Photographs taken to verify above conditions~ No .. Expla naton Work to be done to be acceptable This well and location is~_~lg_c_~ab~~~e (unacceptable)~to be classified as suspended f.or the period of- ~7,, _~~ ,l~~thru ~-~ ~ ~ 19.-~Q--. Inspected y:_ :_._~ ~ Revised 8/24/82 1; t. ~xu~ cow ~o.~~ i h~,~~~ti Sac . 3 z,~~, ,v, ~.z3E ~lryi _~ ~..,~ ~.~`__ - ~ a _~* _ - y ~j .~ : ~ .~. ,~. .. ~:,,: M .. ... r t_ t t.. ~+ ~: .- .. , ',y' ~ ~r. v ~- ~'~` . a ~ ~~~N ~I ~~Cs.'~ Q~~ ~ 5 `~`~ ~ ,~ Q ,o~ ~.~ ~ `` ~ J/ °W 'f~ ~. ~or~1,p,5o~ '~ ~ec . 32 , ! /onJ, ~.?36, UM - ~us~e~v~ ~~ ~~ ~c6v1 ~~ s ~'~ .~`~ ~~~,~ ~~~~ _.~~jl. - 0~ ~; i ~,~ J g~ Se~te~.~ber 29, 1983 Exxon Compan5~, U.S.A. P. C. Box 6601 Anchorage, Alaska 99502 Re: Cleanup Inspection for tAe Following Wells: Duck Island Unit t~o. 2, Sec. 8, Tll~.~ i,'17E, U.~]. Duck Island Unit l~o. 3, Sec. lO, TI/N, R17E, U.~]. Point Thomson Unit No. 1, Sec° 32, T10~, R23~-, Point %'homson Unit ~o. 2, Sec. 3, T9N, 1122E, U.~. Point Thomson Unit ~o. 3, Sec. 34, %~10N, R23E, Alas~ State A-l, Sec. 27, TION, R24E, U.M. Alaska State C-I, Sec. 14, T9I~, R23E, U.M. Alaska State D-i, Sec. 23, TiON, R23E, U.M. Alaska State F-l, Sec. 17, T10N, R23E, U.~]. Alaska State C-2, Sec. 35, T10N, R24E, U.I~. Cent lea. mn: Our representative inspected the above ten suspended and abandoned well sites for extension of cleanup on August 31, 1983. With the exception of Alaska State C-2, the cleanup of these well sites are satisfactory. Decause the drilling rig was still on location at Alaska State (~-2, a cleanup inspection could not be com~leted. Returned are eight approved 10-403's, Sundry l.~otices and Reports on Wells, for all the listed ~lls e~:cept for two which need no further approval. Alaska State G-2 has a year to go under 20 AAC 25.170(a) and AlasP~ State D-I which (classified as aban- doned) has previously been granted an extension to August, 1984 for removal of the s]~eet piling. The 10-403's which you submitted for Duck Island ~nit ~'.o. 1 ant Alaska State D-1 are not necessary- and are z'eturned unsigned. Duck Island Unit ~o. 1 was abandoned, dcwrd]ole and Duck Island Unit ~-}o. 2 was sidetracked fro~ the ~-ell Dore of I;o. 1. conse- quently a 10-403 is net req~uired for ~..!o. I. A subsequent insD~ection of each well will be necessary by August, 1984. Sincerely, .. · Lonnie C"- Ccr~:n~i s s loner LCS/J~5~ :lc: 103:i] M EMORAN_ UM State of Alaska ALASKA OIL AND -GAS CONSERVATION COMMISSION C. ~t~ rton Cha~u~ Thru: Lonnie C. Smith Commi s s ione r FROM: Bobby Fos ter~~ Petroleum Inspector DATE: 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 C-2 is not acceptable due to the rig still being on location. In summary, I inspected the above suspended locations. Attachments Suspenaed Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: ~ 0~r~t6~ ..~ ~-'~.(~)~. ~D~ ~i , ' Date Suspended Address ~-~ ~ ~~O .~~~3 .~~ ' Surface L~at~o~'o~ 'W~li '-- -~ '~- ~ P~rmi~ ~Ft. F~L, ~~t. F~L API No. Sec.~, T~ ~, R~~, ~ M. Unit or Lease Well No~ ~._ ~ .... Field & Pool Condition of Pad Condition of Pits _. Well head - Ail .outlets plugged Well sign - Attached to well head Attached to well guard Attached to Info rm~tion correct No No Cellar -' Opened 'Filled Covered WaterWell - Plugged off Ye s No ~ ~o Yes No capped Ope n Rat Hole Open Fi 1 led Covered Exp la na ti on ~/~~ Ye s No Ye s No Photographs taken to verify above conditions ~ No Explanaton Work to be done to be acceptable ~O~/~_~ .._ This 'well and location is ~ (unacceptab~) to/be suspended for the~pe~_~od Inspected by:'-!~ .. c la ssi. lied as Revised 8/24/82 fVIADE IN U.S.A. ~ ~Q'. ~~~ ~~~ Ped ~,~~ lUel~/19I~ o.J wcll ~2x~ ~~r . ~~ ~ ~~' ~~,~ Q ~~ ~ -, ~~~~~~~ E)( ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99.502 EXPLORATION DEPARTMENT ALASKA PACIFIC D!VISION D H JON~' ~ E~(PLOR:-- ON CO,'~RDINATOR --- AL,~ S~:,'~ July 26, 1983 Mr. C. V. 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 ,_ .L AND GAS CONSERVATION CO,.,';MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator Exxon Corporation 3. Address Pouch 6601, Anchorage, AK 99502 4. Location of Well 1320' NSL and 660' WEL of Sec. 32, T10N R23E, UPM, North Slope, Alaska 5. Elevation in feet (indicate KB, DF, etc.) Approx 11' GL 6. Lease Designation and Serial No. ADL 47560 7. Permit No. 76-85 8. APl Number 50-089_20005 9. Unit or Lease Name Pt. Thomson Unit 10. Well Number Exxon No. 1 11. Field and Pool Wildcat 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stim u late [] Abandon [] St im u lation 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 clates, 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. Approved Copy Returned &nch0rage 14. I hereby certifyJ, l~rt~the f,~regoing is true and correct to the best of my knowledge. M~~~~ ~'"~ AlaskaEXpl°rati°n Coordinator - Signed ¢¢._ . ~ .... ~ Title The space below for Commission use Date 7/25/83 Conditions of Approval, if any:Otlr representative inspected this well site on August 31, 1983 and cleanup was acceptable for a suspended location. A subsequent inspection will be necessary by August, 1984. ORIG!N~[ $111NED By Order of Approved bv 8Y [[l[~lE C. SM.!T!! COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate AMOCO PRODUCTION COMPANY Tulsa, Oklahoma June 13, 1983 83164ART0077 FILE: Technical Service 839146SX TO: W.S. Davis, Denver ATTN: Kirk W. Sherwood SUBJECT: Mineralogy of Chips from Exxon Pt. Thomson Wells No. 1 and 3 The attached table summarizes the semi-quantitative x-ray mineralogy of six samples from Exxon Pt. Thomson Wells No. 1 and 3. As instructed, I am returning what remains of each sample (both unused and prepared) to Kirk Sherwood in Anchorage. If there are any questions about 'these results, please call me at the Research Center at Ext. 3477. J. C. Hoffman JCH:ceh Attachment Cc' C. F. UPshaw/E. R. Michaelis H. D. Winland Preprk~ - To Be Mab~thed In Coufide~e A ..... P.~.l..t~r,~ ~nmn~nv .~AUTION: THESE ESTI[~ATEb aRE ONLY SE~I-QUANTITATIYE~ . X-RAY DIFFRACTION MINERAL PERCENTAGES LOCALITY: PT. THOMSON WELL NO. 1 FORMATION: unnamed AGE: CRETACEOUS PAGE 1 OF I T.S. NO.: 9146sx CHARGE: 9146 SA HPLE ID. NUMBER ::::::::::::::::::::::::::::::::: : T : P : L : L : D : H : P : R : R : 0 : C : L : N ' L : L : L : : Z : R : C : O : R : Y : S : T : I : L : A : R : T : R : I ' E : ........... : : : : : : 12922 13090 13138 EXXON ?T. THOMSON : 31:TRC: 9: 49: :TRC: :TRC: 2:TRC: 9: : : · : : 'TRC: :TRC: :TRC: 4: : : : : : :TBC: : 2: : 3: 10: : · : ' : ...... : : · . : : · · · · · : 22: : 40: 34: : 36:TRC: 33: 16: 13682 EXXON PT.THOHSON #3 · · · · · · : 28: 2:TRC: 67: · · : TRC: : TRC: TRC: : 3: : ' ' : · 1374~. : 40: 2:TRC: 54: 13850 : 35: 2: 33: 25: :TRC: · : TRC: : · 5: : : ' : : .... : : · : - : February 15, 1983 ~r. P~o~rt A. Bailog Union Oil Compar~- of California P.O. Box 6176 Venture, California 93303 Preparation of Palynologic, Eerogen add Foram Slides Ditch Cuttings and Core Chips in State ~gell Daml-,le Libra~ Dear Ro~.:ert: Pursuant ldo ~y recent discussions with you, John Packard, Clark Weaver and ~..on ~ies, permission is hereby granted to Union Oil Company of California to extract a maximum of 1 cc. oi sample (c~tin~s) material per sample envelope and 1 cc. of core n'o.terial per foot of core from the state's set of samples an~ core chips for %ho sole purpose of preparing palynologic, kerogen and fora~:~ slides at nc greater than 90 foot composite depths within the designated intervals in. the following wells, sukject to the conditions set forth below: Ue 1 1 Int erva 1 Set ~o. .... =.=_~ 39~ F~x~n ~. ~omson Unit ~1 &26'-13,27~]' 426 Sohio ~i~uk ~3 90'-12,43C' '1. Cuts of the sample and/or core [~ateria] from the State co]!e~ion are to be e~racted only fron those individual envelopes or bags in which total content of cuttings or core ~-~terial is greater than i0 cc. (~o 'c~s are to be extracted if the volumes of ,~ate~lal in the individual envelope is less than 10 cc.) 2. Union will provide the State with a list of the si~ecific sample and core footages fron %~9'~ich ~terial was extracte6~. =c~eerie~, set of l~alynologic ,Jliqes, One composite set and one one set of kerogen/TAI slides anal. one set cf fora~'~ slid. es are to be t~.rel?are.~ coverinq the entire respective intervals In thc above wells, ~ Robe~ A. Baltog ruary 15, 19 83 . All slides prepared are to be received by the Commission no later than June 1, 1983, and are to be transmitted direct to the Commission and not examined by outside parties. 5~ Ali residue and excess material is to be returned to the Commission; no slides or sample materials are to be retained by Union. . No petrographic, vitrinite refle~ance or other slides are to be prepared nor analyses made without specific prior consent from the Commission. 7. Union shall bear all costs entailed. 9~e are pleased to work with you in this beneficial project and look for~rd to your company's continued exercise of care and good. judgement in the handling of this limited quantity of well ~terial. i know we both understand that the State's well sample libra~ is public property and that granting Union permission to e~ract ~rtions of material from this library for the purpose of preparing the indicated slides enhances the value of the library and is in the p~iic interest. Sincerely, William Van Alen Senior Petroleum Geologist John A. Pack~rd Union Oil Company of California P.O. Box 6247 Anchorage, Alaska 99502 E ON COMPANY, U.S.A. POUCH 6601., ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION September 1, 1982 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: On August 12; 1982 a representative of the AOGCC (Harold Hawkins) along with R. L. Westbrook and R. G. Dragnich, conducted an inspection of several of our drilling locations in the Pt. Thomson and Duck Island areas. During these inspections, the representative indicated that one-year extensions on suspended wells would be approved after the cleanup work was completed at these locations. We therefore submit, the enclosed photographs of our Pt. Thomson #3 and Alaska State C-1 drilling locations which indicate that the cleanup has been completed. We submitted Sundry Notices requesting extensions for these locations on August 10, 1982. Also attached are Sundry Notices requesting one-year extensions on our Pt. Thomson #1, Duck Island #2, Alaska State D-l, and Pt. Thomson #2 locations. These are wells which we wish to carry as suspended rather than abandonments. The Pt. Thomson #1 and Duck Island #2 locations were inspected by your representative who indicated that extensions would be approved. As you recall, Duck Island #1 and 2 is a single wellhead and the AOGCC has previously approved the abandonment of Duck Island #1. The Alaska State D-1 location was previously submitted for abandonment approval on February 18, 1982 and was al. so inspected by your representative. We understand that to obtain a final abandonment status for this location, the sheetpiling will have to be cut off below grade. The attached Sundry Notice requests a one-year extension to enable us to conduct this work at a future date. The Pt. Thomson #2 location has been suspended since September 1978 and was not included in the inspections. The attached Sundry Notice requests a one-year extension of this status. ! A DIVISION OF EXXON CORPORA[ION 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: Sjm 60~2 Attachment s STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON .WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator Exxon Company, U.S.A. 3. Address Pouch 6601, Anchorage, AK 99502 4. Location of Well 1320' NSL & 660' WEL of Sec. 32, TION, R23E, UPM North Slope, Alaska 5. Elevation in feet (indicate KB,.DF, etc.) Approximately 11' GL 12. I 6 . Lease Designation and Serial No. ADL 47560 7. Permit No. 76 -85 8. APl Number 50- 089-20005 9. Unit or Lease Name Pt. Thomson Unit 10. Well Number Exxon No. 1 11. Field and Pool Wi 1 dcat Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We request a one-year extension 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. Approved Co~¥ ; Returne~ ....... ~ . 14. I hereby certi~ the ~ng is true and correct to the best of my knowledge. Signed ' Title Alaska/Pacific Div. Rep. The space be~w~r Co'mmissic~ u;e Date 9/1/82 Conditions of Approval, if any: This suspended location was inspected by our representative on August 12, 1982. The well marker is ccmplete. Approval is given to leave the rrud pit open, the gravel nDund and the well head above grade levetl~ ¢ Approvedby ORIGINAl. $ N:E reinspection will be ne~¢sa~r~ by August 1983. COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 BY [O]~NIE C. SMITH Rev. 7-1 ~0 STATE OF ALASKA ALASKA 0IL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON .WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator Exxon Company, U.S.A. 3. Address Peuch 6601, Anchorage, AK 99502 4. Location of Well 1320' NSL & 660' WEL of Sec. 32, TION, R23E, UPM North Slope, Alaska 5. Elevation in feet (indicate KB, DF, etc.) 12. Approximately 11' GL I 6 . Lease Designation and Serial No. · ADL 47560 7. Permit No. 76-85 8. APl Number 5o-089-20005 9. Unit or Lease Name Pt. Thomson Unit 10. Well Number Exxon No. ] 11. Field and Pool Wildcat Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We request a one-N_e~.~.e, xtensj;~., 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. Approved Copy Returned 14. I hereby certify tat the for, egoing is true and correct to the best of my knowledge. Signed . _ Title Alaska/PacificDiv. Rep. '"h~ e space De[ow or Commissio~n use Date 9/1/82 Conditions of Approval, if any: This suspended location was inspected by our representative on August 12, 1982. The wel'l rmrker is complete. Approval is given to leave the rind pit open, the gravel rround and the well head above grade level. A 'reinspection wil 1 be necessary by August 1983. By Order of Approved by I)l~ll;;lllA[ SlI~ItED COMMISSIONER the Commission Date ~orm ~0~0~ BY [0~NIE IL Si~ITI! Submit "Intentions" in Triplicate Rev. 7-1-80 .~na "~ilhC~nll~,nt R~nnrt¢" in MEMORANDUM State of Alaska TO: Thru: ALASK~OIL A~D C~S CON.~.ERVA~IO~. CO~ISSION C. V ~t~n o~s:gu~ust 27, 1982 Chai~~~ Lonnie C. Smith FILE NO: 108/A C~ ssioRe r / TELEPHONE NO: FROM: ~a rold R. Hawki ns ~?-.~. ~ Petroleum Inspector '~';' ¢ '~' SUBJECT: Inspection for Extension of C lean-uI> ~xon Company 0.S.A. Suspended Point Thomson Unit l~o. 1 Sec. 32, T10N, R23A, UPI.~ Per~it No. 76-85 ~hursday, August 12, 1982 - I left Exxon's Point Thon~son ~U~.i~'"'-~o" 3~' s~jec% of a~other rerx~rt, to ~[xon's Point Thomson Unit No. 1, for clean-up inspection. I insFected~ the location of Exxon's susl~nded well Foint Thomson No. !. The well marker has all the well data bead welded okay. The mud~ pit is ot~n and a ~und of 9ravel still exists, the well head. is above ground about two feet. The location is clean and free of debris. I took 12 pictures of the location to ~ attached to this ret~ort. I also filled out an A.O.C.C.C. which is attached. In sums~ry, I inspected Exxon's suspended well, Point Thomson No. 1. All well ¢~ta has been corrected on n~arker since Doug Amos insFected it August 11, 19gi. I aiiF~rove Point Thomson No. 3 for susF~nsion only. ~xon should. submit Form 10-403 for an extension of location clean-up. Suspended Well and Location Report 20 LAC 25, ARTICLE 2 FILE INFORMATION: Operator ~-~.:<~ .f~-~ ,:~ :~.:'~ Date Suspended Surface Location of Well ~- Permit 73 20 Ft. F ~3 L, ~ ~ .... Ft. F ~3~ L API No. 50 Sec.~, T3Q ~, R~.~~, uF M. Unit or Lease Name Well No. Field & Pool ~ Condition of Pad _ _~3 ~ Condition of Pits _ ~ ~::z~ ~ fizz Well head - Ail outlets plugged Well sign - Attached to well head Attached to well guard .Attached to Information correct No No Cellar - Wa te rWe 11 Opened Yes, No Rat Hole Open Yes No ~ ~ No Fil led Yes No Covered e~ No Covered Yes No - Plugged off Capped Open Explanation Photographs~ taken to verify above conditions ~e: No Explanaton ~/2 _; '.~_~__. 4' .,: ~ , ~ ~ ~:-~ 4.. ~' ~ ! ~_ ~ ,~_~ ,~ ~ Work to ~ done to ~ acceptable ~~x~ z~f)ff :~, <p.~,<..~ This well and location is a~~~~~ (unacceptable)to be suspended for the period o~ 19 thru Inspected by:_ classified as 19 . Revised 8~24/82 r-- ~ ~: ~ 3 z, i /o ~J l~ z 3~ J v r~~ ~~ /~~ ~. ~~S >.~__-,~~ ~ ~ /. ~~~. ,~ ~` ~ l i t~J ,~ ~- API:: "_._. S.. - - �- •�"� a .• - � tC l+i�:^3 r+.'�r..�,!'.,; i ala ,• _ *..' 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Y - - - - -; y - ,<rfr:ty.# -rc�. ihy;,:•1 Z. ;hc.-. i L.. -+:_its ,...s' �'� '�7 t _ _ _ _ _ x• f" _i•` • t� .,}t•�i ie :�a f..r {r: � S r.5 ..7 '` '� h - :h-, ate, ' >.- �.+'g �:fi�:.��•:- `4.R-:tCi.- .t?., �: 'A' .J�� •iii '�-. � .r .r. :s... c`. - - _ f .. Y v. ir. 'fir' a: �a, #'..•i :._. E. ti-� ��} �-, M -l'" -^i • _ ��. ems,., al- � s-1�' . ' -�` � _ 1 "t'f•. "Y � ♦� 1. .i i?}^:. - i}.' v�` •i Y' _ _ - _ t; '.{` -'fir . K v1- • ,1 . `t 5 " .Y: GY.• •,.. � - ;+w h. s - y �1 L J ♦]2. ;Y.. ] tip' y: ♦. � .- - - ]a> i� C• f tf r •t' a � - �. fir.• t �•; '* r - r - 'ar' t :L �-• ,.rye.. - . . , 1 A C .1rf.t -k S E]I( ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 PF~O[}UCTION DEPAIRTMEN~ OPERATIONS Harch 23, 1982 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attention: Mr. Lonnie Smith Dear Mr. Smith: Attached are Polaroid photographs showing the wel!bore markers for the Exxon Point Thomson No. 1~ and Duck Island Ne.'s 1 and 2 wells as requested in your letter of Septe!.~ber II, i981. Very truly yours, RGD:rms 25A/Y Attachments 295-651-100 295-64~-~00 295-642-~00 · / {}PT!S!ON OF EX X(')N ('}O~,P()RAI ION l~T Tho M s c~~v 1~ i.. ~ ~7"l~ a ~~± 5~ ~~ ~~ ~ l ~~T ~l"h d l'~+ s aN ~ j .,~ -,~w~* ~: ~I \1 . .. ,. _~ :.,,, STATE OF ALASKA ALASKA t.,,L AND GAS CONSERVATION CO.,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] Wildcat 2. Name of Operator 7. Permit No. Exxon Corporation 76-85 3. Address 8. APl Number Pouch 6601, Anchorage, Alaska 50-089-20005 4. Location of Well 1320' NSL & 660' WEL of Sec. 32, T10N, R23E, OPM North Slope, Alaska 5. Elevation in feet (indicate KB, DF, etc.) __ Approximately 11' GL 6. Lease Designation and Serial No. ADL 47560 9. Unit or Lease Name Pt. Thomson Unit 10. Well Number Exxon No. 1 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). Request extension to June 1, 1982 to clean up location. 14. I hereby certify tl~ Signed ~---/~ The space below(~'~x~f-~:ommission use i Cie fore~oing is t~ue ang~o~r~ect to the best Of my knowledge. Title Senior Landman Date 3-18-82 Conditions of Approval, if any: Approved by COMMISSIONER Approved Copy Eetur:~d By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate March I1, 1982 ~xxon C~pany U. S .A. p.©. Box 6601 Anchorage, Alaska 99502 De: Request for Extension of Time for Clean-up Cent lean: This office informer] you [~y letters on September I1, 19~1 that a..submittal of form 10T~.Q..~.~,~n~..,~igti~c..es..~~.e~x)rts cn ~.~elts, wa~ necessary f~ Pt. Thomson Unit No. l~nd Duck Island Unit ~o. 1 and No. 2, to request an eztensi6n'-'~6~-"~ti[~ for clean-up. These r~uests have not been received. Please subn~it these 1O-~03's promptly. ~ lncerely, Lonnie C, ~'Smith Commissioner cc: Letters cf September 11, 1981 S~pt ~ember 11, 1981 ~xon Company, U.S.A. 3301 "C" Street P.O. Box 6601 Anchorage, Alaska 995~2 Re: Location InspectioD of Clean-up, ? Thomson Unit. %1, S Cent ] er?~n: This site was inspected by our representative on August il, 1981 and the follo%~in~ deficiency was noted: lO The distance from the section line was not bead ~elde~ to the wel I marker. Please notify us uhen this correction is ~'~a~;e. Vcriiication can be made by close-up photographs or by a site inspection. This correction should be made in the near future. If there is s,~fficient reason for not accomplishing this in the near ~uture it will be necessary to request on form 10-403, Sundry Notices and P~eports on ~ells, for an extension of the final clean-u~ date. A subsequent inspection will be necessary for this site. Sincerely, Lonnie C Commissioner tCS/g].h ALASF~ OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton/~ Chairman THRU: Lonnie C. Smith Commi s s ioner Doug Amos ~'i~'~'~ .......... Petroleum Inspection August 31, 1981 Conduct Abandonment Inspection on Exxon's Pt. Thomson Unit No. 1 We~, Sec. 32, T10N, R23E, UPM, Permit No. 76-85. Tug~daI August 11, 1981: I accompanied Mr. Dave Galloway, Exxon representative, to the well site. As the attached pictures show, the pad and mud pit areas are in good con- dition and returning to their natural state. There is a proper well marker post on the wellhead, however, the dis- tance information from the section lines to the well was omitted. Therefore, I recommend to the Commission, that final aban- donment approval not be granted until the omitted well post marker information has been corrected and varified. In summary, I conducted the inspection for final abandonment on Exxon's Pt. Thomson Unit No. 1 Well. I recommend that final approval not be granted until the information ommitted on the well marker post has been corrected and varified. DA:vdl FILE [NI:()RHA'FiON: ' ':" ' ~ ,. Ol,erat )r [.,.-, ~ .! .~ . Date })ownl~ole I' & A Address ~,,~' ~.'.,~{ " .,~ .... Surface I,ocation of Well Sen. 3~ , T~ ~, R 5~ 20 AAC 2.5.1'20: ',,'El,I. AI;A?,'I)O,';>I[C,';T Dia. Steel Post (4"Hin.) ,~- Length (10' Hin.) }{e/ght Above Final Grade Level (4' Hin ) ~-, Top of Marker Pipe Closed with: Cement PLug Screw Cal~ Set: On Well tiead /' , On Cutoff Casing , In Concrete Distance Below Final Grade Level Ft. Side Outlets: All Valves and Nil)l')les Removed Ail Openings Closed "~/ ' , With Blinds ~-' , With Cement AP1 N~). 5{)-,."'!;',_Q ,"",'-.'~-.. Unit or Len~;e N,'lme Wet 1 No. Field & Pool.. ~Z'~l ~/'~"~' .... Welds , ()tl~er INFORHATION BE,\I)WEI, I)F.I) I) IRI:,CTF, I,Y 'l'(') H.',RKER }>OS'F: (List kq]ere Different from File Information) Operator ~O,~ ~o, 2:, ,, A, ..' ..... - ' O- unit WeZl Number ~ [ , Surface Location of Weii: Ft. 'F L, Ft., F L, Sec 20 AAC 25.170: .LOCATION cLEAN-uP PITS: Filled In __, Liners Removed or Buried /, Debris Removed SURFACE OF PAD AND/DP, I.OCAT[OI:' Rough , Smooth , Contoured Flat b~, (]omi}acted , ~ , Other 'JA ~ ~0,~,~4% ,~ -~'/~.a~ ~.,],,..~po~,.~ ~z,~ :4 .... CLEAN LIP OF PAD AHI)/OR I.OgAI'I()N' Clean ~/ Pipe Scrap ._ , Iron Scrap __, Wood__, ~.lud , Paper. , Other C (2Ill e 11 L SUR RC)IJNI) lNG ARE,,\: ' "'" Grass Dirt Gravel Wooded , Brush , Tundra .- , , , Sand ..~../;- Other CONI)[TION SUR~()U~:I)[>:G ARF. A' Clean v~, Trash frum.Site Other , Trees and/or Brush from Clearing SiLe , ACCESS ROAD: Dirt , Gravel , Ice , Ot}~er CONI)[TION ACCESS ROAI) AND SURROUNI)]~NC: Clean , Rough , Smooti~ , , 'i'IFasl~ from Ol~Cration~ , Trees and/or Brusl] from Clearing Road , St)oLl from Clearing Road Otl~er RECOHHENIY'APPROVAL OF ABANI)(3"v' .... P. / . ,,,~,'~ ~. Yes , No Finai ].nspec t ton 05/26/81 , , , ~, v'n ...... ALASKA Ol.i, AND GAS C,.~,x .I.!RVATiON C(IM~I£SSIoN ~]"!SURI:ACE ABANDO' >lENT I~EPflRT 20 AAC 25, 'XRTICLI~ 2 ~:.../ . FILE iNFORMATION: Operator '~~k~ ~0~ Date Do.hole P & A '~~'~ Address '~ ~0~ ~0[ [ ~~P~. ~P ~.6~ ~ Surface Location of Well , ~Y '~ ' -' pe-n~{i't No. [giO Ft. F B~U, OUO~ ~t. F~L, ~ ~o. S()- Sen. ~ , T !O ~, R D~ ~, M,~M. Unit or Lease Name ' '~,~' ~ ~,Field & Pool ~'~ 20 AAC 25.120' WELI~ ABANDONMENT ~bXRKER: Dia. Steel Post (4"Min.) / Leng.th (t0' Min.) Height Above Final Grade Level (4' Min.~ ~ l Top of Marker Pipe Closed with: Cement.Plug Screw Cap Welds Set: On Well fiend ~, On Cutoff Casing , In Concr. ete Pl~g Distance Below Final Grade Level Ft.' in. Side Outlets: All Valves and Nipples Removed All Openings Closed ~ , With Blinds ~ , With Cement , Other INFORMATION 1½EADWELI)F,I) DIRECTELY TO M,\RKER POST: (List ~d~ere Different from File Infonnation) 'Operator ~Xo~ ~o, ~.S, A- Unit or Lease Ma,ne ~$, Well Number ~ [ , Surface Location of Well: Ft. 'F L, Ft., F L, Sec ~2 , T ~OM , R Z~ 20 AAC 25.170: LOCATION CLEAN-UP PITS: Filled In __, Liners Removed or Buried ~/, Debris Removed SURFACE OF PAl) AND/OR LOCATI©N: Rough , Smooth , Contoured , Flat b~, Compacted Other W'~ CLEAN UP OF PAD AND/OR LOCATION' Clean__~ Pipe Scrap Paper. , Other , Iron Scral) , Wood , Mud , Cement Sb~ROUNI) ING AREA: Wooded , Brush , Tundra b~, Grass , Dirt Sand ~ Other Gravel CONDITION SURR~OUNU[.:N~G AREA' Clean ~ Trash from .Site Other , Trees and/or Brush from Clearing Site ACCESS ROAD: Dirt __, Gravel__, Ice __, Other CONI)£TION ACCESS ROAD AND SURROUNI)IMC" Clean , Rough , Smooth , Trash from Operations , Trees and/or Brush from Clearing Road , Spoil from Clearing Road Other RECOI'IHENI)'j. APPROVAL OF ABANI)ONblENT: Yes INSPECTED BY 05/26/81 No b// Final Inspection ~~ Exxon Co. 0 Po~~T T~M~N /1 u.s a. uu,T No. 1 ~i ~~ ~~ ~° `"~" ._ ~ "~ ` 11 Jb~ r .....K~~ G a- ~ ~ 1 ~~. '('kew~~eh ~ ~ ~ 18 8p11-d1 P~. w~ ~ ke x~H I z -;~} ~,, . :} Y \..x . 9~T St., {.,~'„, ,~ :~~~<`. - ~. ~,'°!~ . .~ rn ~~ 4__ i , . , i z ~'~, ~; . ~- r _ -.._.~ ~_~ 5. S~~t- b I T~ , ~ ~ hb ~ns~h Mid P~F 3~~ 8^11.81 P~: j'kew1e-~ ~' 1 -mss r~'h ~' ~~ Ws l) I~ ~r_~ vr~ ~r~~~~l Wad ~ ~6~~ Mo~rio~ _ ~~~ ~ P; ~• , -- - - ~ ~ .~ ,. 3.,._ ~_ _ Fir r w~ ~~ r - :-- --~ _ ~ ~ o o k ~ n9 l __ ~ rt __ _ - . r: 4~ - ` r7„y,~~ '~r~~ air L.oo ki h~ $ ~va J~ ~~ L, 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 2 ~l i" ' 4 ~: ,.'J '.. I ?rAT T~ STAT TFC '- CONFER..' 'L_F i L F : 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 P~t~homson #1 Pt. Thomson #3 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 June 4, 1.981 Exxon Company U.S.A. P. O. Box 6601 Anchorage, Alaska 99502 Re: Alaska Oil and Gas Conservation Commission Regulations Article 2, ABAI'IDO~-.:ENT AI-~D PLUCGING, 20 AAC 25. 120 WELL ABANDO~MENT ~ARKER and 20 AAC 25.170 LOCATION CLEAN UP. Centlemen: In regard %o 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 %~ith 20 AAC 25. 170 Section (a), "~ithin one year of suspension or abandonment of an on- shore well", all clean uF %~ork is to be finished. Section. (b) provides the means for an extension cf time if a valid reason exists. Section (c) provides for on site inspection. Consequently, we are presenting the following list of your abandoned and/or suspended %~ells. .~any of these are now more than one year old and~ are not in compliance with regulations. Others should have the final inspection conpleted 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 inspected this summer please inform us. Therefore, %~e are requesting a schedule ~rom you for this summer when our field inspectors can accompany your representa- tives to these sites for the final clean uD insl~cction. You.rs truly, ~Lonnie C. ~$.ith Commissioner LCS IJKT: be / EXXON COMPANY U. S. A. SUSPENDED Duck Is. Unit 91 Pt. Thomson Unit #1 Pt. Thomson Unit #2 Pt. Thomson Unit 93 PLUGGED &' ABANDONED Canning River Unit B-1 Pt. Thomson Unit #4 E ON COMPANY, U.S.A. POUCH 6601'ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION Re: May 23, 1980 Exxon Pt. Thomson Unit #1 ADL 47560 North Slope, Alaska Mr. Hoyle Hamilton, Chairman Alaska Oil& Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton: Enclosed is your copy of a sepia print of the mud log on the captioned well. Please note that it is marked Confidential and should be kept so in accordance with the provisions of 11 AAC 22.535(f). We are sorry for the delay in furnishing you with this log and hope that it has not inconvenienced you in any way. Very truly yours, RLL:et enclosure A DIVISION OF EXXON CORPORATION STATE of ALASKA r- OIL & GAS.CONSERVATION COMMISSION DATE: SUBJECT: OIL SPILI, RI'ii~()RT at (location) NOTIFICATION TO O&GCC Date & Time of Notification: Person Notified: Information required by 18 AAC 75,110 1. Date and time of disCharge: /o ~oO ~-4~c ~ ! o, e · e Location of Discharge: ~ ~e= ~+ 7_~,~.~,~..l ~x- ~ Per,'on or Persons causing or re.~ponsible for t~e discharfJe: ?ype (s) and amount (s) o~ hazardous substance (s) discharged; e i Cause of Discharge: Environmental damage cause by the discharge to the extent asce~:- tainable: )kd~ O , Cleaning actions undertaken: · Location and method of ultimate disposal of the hazardous substance and contaminated clean-up materials including data of disposal' · Actions taken to prevent requrrence of the discharge: . I POD'CIt H .... JU,~'£q LI 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 Company, U.S.A., Point Thomson Unit Wells No. 1 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. ~int Thomson Unit We,l~?~. 1/7/80 L Poin~--~o~--~u.n_¥C-w_e,,l,ri-=_~,,~ 9/11/80 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. Hamilton ,~ Thomas Cook DEPARTMENT OF NATURAL RESOURC~S OFFICE OF THE COMMISSIONER ,',~pieS to: ( [ ] Administration [ ] Agriculture [ ] Geological Survey =[ ] Forest, Lamd..and ~'1ater Management I ~ .M]neral s.a.!d.E~ergy Mana~'i~nt', ":[' ] '~FWs~ ~ ~'::=--~:~"~"'-:'%-":~ "'. ....... [ ] Pipeline Coordinator [ ] Planning ' '.[.-] RoYalty Board ' ::'",:.' ~'."- ' -' (~¢!~Lructions and Form oF.response:-. Dos ton Conheady Dennerlein S Loops Suspense 1,~ be Coordinated by' Priori F~B ~_ 1979 Div.. of Minerals & Energy Mgt. Anchorage, Ak. DW- oi ~A'mera/s 8, Energy ~Agt. ~kochorage' A~' ' 1!, COMPANY, U.S.A. '~ · POST OFFICE BOX 2180. HOUS1-ON. TEXAS 77001 EXPLORATION D EIJA RTI'~I E N'I' ALA%KAIPACIFIC CRANDAI. L D. JO~ES January 16, 1979 Confidentiality of Well Data Wells #1 and #2 - Pt. Thomson _. Unit . . .-'.-'.'." Mr. Robert E. LeResche Commissioner of Natural Resources Pouch M Juneau, Alaska 99801 Dear Mr. LeResche' F'r_.} 8 1 1U Div. of lvlinera!s & Energy Mgt. Anchorage, Ak. As operator of the Pt. Thomson Unit, Exxon hereby requests tl~at 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 confidential indefinitely pursuant to Alaska Statutes 31.05.035(C), as amended by H.B. 518. 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-SN/R-22.and 24E, T-gN/R-24E, and T-lON/R-21-24E, inclusive. Please advise if you have any questions regarding this matter. Very truly yours, C.DJ- nh cc - To Particip_ants. Al-Aquitaine Exploration, Ltd. Mr. Kingdon R. lluflhes 540 - 5th Avenue, S.W. P.O. Box 2424 2000 Aquitaine. Tower Midland, Texas 79701 Calgary, Alberta, Canada T2P OM4 -- Attention' Mr. Don ttill Mr. Edward ii. l.eede -. ' : -- 516 Building of the.SouLlnves~ . Atlantic Richfield Company-,. . ..._ -. ~- Midland, Texas 79701 -.-. '. P. O. Box 360- ' '"~" :~ ':'-'-~-'-'--:':---' ....... "'"=' ' "- '"' - "' ':" ' - ' ';'- ":~:'' Anchorage, 'Alaska'; 9'95iq' ~"-'-g-~;'t: ?:" '~' ":' ~Leed6.'afld'?fne" ~..-~-:"- - ..' --: --- ~-.-:--: ..... Attention.:- I,lr~ ~J6hh aFr:: A' Edward l.t.' l_eede "':'' "':' '_-']7 ' - ' .... ' "'"-:-~'-";-~'.il-.~-II''- ~'-'--z:~?~''-'-:- ::' "516 Bu~ld'ing of' t'ii'e Sout. in,)es'~ .... ' -~-:-- .. Star Oil & Gas Corporation Midland, Texas 79701 2402 Norcen Tower 715- 5th Avenue, S.W. ~.lobil Oil Corporation Calgary, A1 berta, Canada T2P 2X6 P. 0'. Box 5444 Attention: Mr. Ralph Estelle Denver, Colorado 80217 Attention' Iqr. W. S. Bl anton . Coastal States Gas Producing Company P~ O. Box 749 Ne;,.~ont Oil Company Denver, Colorado 80201 600 jeFFerson - Ninth Floor Attention: blr. H. E. Dickard tlouston, Texas 77002 Attention' Mr. Roland E. Squyres Gas Producing Enterprises, Inc. P. O. Box 749 Mrs. Bernice C. Peery Denver, Co-lorado 80201 P.O. Box 4023 Attentio~fi' Mr. H. E. Dickard Odessa, Texas 79760 Cities Service Company 900 Colorado State Bank Building 1600 Broadway Denver, Colorado '80202 Attention: Mr. John Freeburg Grace Petroleum Cor?o.ra ti on 3 Park Central, Suite 200 1515 Arapahoe Denver, Colorado 80202 Attention: Mr. E. G. llickel Continental Oil 'Company P. O. Box 2197 Houston, Texas 77001 Attention: Mr. Duane Barrels Pennzoil Company P. O. Box 2967 Houston, Texas 7]001 Attention: Mr. IIerbert G. OFFicer 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 Cal gary, Alberta, Canada J2P 2Y3 Attention' Mr. H. V. Pederson Phillips Petroleum Co~npany 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 CheVron U.S.A. linc. P. O. Box 7643 San Francisco, California 94120 AtCen[ion- l,]r. ~..~. Anders Sunlite International Inc. 2500 One Allen Center Uouston, Texas 77002 Attention: Iqr. Edwin James Tipperary Corporation ~ 500 West Illinois .... '.. .... l.lidland, Texas 7970] .... -. .... Attention- ~,~r. Phil t4. ~,~!hitsitt Trans World Oil & Gas Ltd. 625 - 4th Avenue, S.W. Calgary, Alberta, Canada 12P 0K2 Attention' t, lr. J. A. Phillips Pacific Lighting Gas Development Company 7~0 ~,Iest Eighth Street Los Angeles, California 90017 Attention: Mr. W~ E. Ryan DEPARTMENT OF NATURAL RESOURCES OFFICE OF THE COMMISSIONER Copies to' [ ] Administration [ ] Boston [ ] Agriculture [ ] C(~;'~heady [ ] Geological Survey [ ] Dennerlein .] Forest, Land and Water Managemept [ ] Stoops Minerals and Energy Management [~,C_ [ ] Suspense [ ] Parks [ ] Pipeline Coordinator [ ] Planning ',[ ] Royalty Board ' · . ' Instructfbns and form of response: / To be Coordinated by: Date Due' Priority- From: COMPANY, u.S.A. POST OFFIGE BOX 2180 · HOUSTON TEXAS 77001 CRANDALL I~. JONES MANAGER January 16, 1979 Confidxe-p4~iality of l~ell Data Wells(.#1_jand #2 - 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 l~ell No. l, Section 32, T-lON/R-23E, U.B.M. and Well No. 2, Section 3, T-9N/R-22E, U.B.M., in said unit, be held confidential)ndeiTinitely pursuant to Alaska Statutes 31.05.035(C), as amended by~H.B. 518.~. 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-gN/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, Cahada 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 AttentiOh-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 }',,~gh.~': P. O. Box 2424 Midland, Texas 79701 Mr. Edward H. teede 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 /~023 Odessa, Texas 79760 'Chevron U.S.A. Inc. P. O. Box 7643 · San Francisco, California 96120 Attention' Mr. J. J. Anders · Sun'lite 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 Li'ghting Gas Development Company 720 l~Iest Eighth Street Los Angeles,.California 90017 Attention: Mr. W. E. Ryan Conservation September 14, 1978 ~. R. L. Boane District ~anager Exxon Company USA Pouch 6601 Anchorage, Alaska 99502 Dear ~r. ~ane: The Oil and Gas Conservation Committee has reviewed the incident at your Pt. Thomson Unit #1 well where oil was found in the burn pit. Fo~UnateI~ your Ci~p efforts have prevented any signi- ficant damage to the surrounding tundra from seepage from the gravel pit. After discussions with your personnel, the state engineer who was present during this testing of the well and the inspection of the daily well records, the Committee feels that the explanation of ~his occurrence as stated in your letter of September 7, 1978 is probably the most reasonable. That is the oil from the test tank bottoms was put into the burn pit and not burned. It is imperative that. this type. of incident should not be repeated, o~e~ise the Committee will consider imposing a fine. The Co~ittee recommends that you educate everyone associated with any of your well operations ~hat all waste must be disposed of in an acceptable manner as approved by the State. The Committee will have a representative inspect this location next summer to insure that conditions are stablized. However, if they have not you ~ill be r~uired to resume clean-up operations. Yours truly, Chairman Alaska Oil & Gas Conservation C om~.J t tee DEPA~NT OF ~UtTURAL I~ESOUi~CES Division of Oil and C~s Cc~servatic~ Sept~be= 12, 1978 The Oil and Gas Conservation Cc~m~ttee requested the cz~plete set of tour sheets to review the activities related to testing and disposin~ of oil frc~ the first px~duutic~ test of subject w~ll. Kugler c~ Septembe~ 1, 1978 as requested. He also included a packet of more cu~p~ehensi%~ daily w~ll operation sheets m~ntained by Exx~n's office. These sheets w~re ~y scrutiD/zed by 1978. The follow/rig is a brief sam~sxy of the points of interest hav/ng~. to do with the first productic~ test. October 22, 1977. Subject well was perfGrated in an interval of 12,962 to 13,049 feet. Blair Wonzell, EMEM en~/neer, arrived at location to witness producticn tests. October 26, 1977. First oil samples and production to tanks. 69.3 barrels of oil r~overed in tank. From October 26 throu~ the 29th the well was apparently plug~ due to high gas/oil ratio freeze-off, possibly gas hydrates, October 30, 1977. Well ~ frcm 0005 hours when it was opened to 1930 hours when it was shut-in. Blair l,k~zell departed the locatgm. November 1, 1977. ~ecording pressure data. "Oil ~ture in tank 100O." "oil t~~ature in ~ank 110v. Will inject into ~nulus". -2- Se~ 12, 1978 ~ 6, 1977. i~c~-~d~ed with 10 ~ of nazl flush, 10 barrels of 15% ttCL and 10 barzels of 12% ~ with ~ additi~s incl~ sumfactant. Acid flush f~ by 62 barrels of n~d ]~r~aber 9, 10, 1977. Pul]/r~ out of the hole and fishing for t~bing. ~ 11, 1977. A ~nt retaitler was run, the perfora~ w~re ~ ~~ am~ a te~?_rature m=~y nm. E ON COMPANY, U.S.A. POUCH 6601·ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION R.L. BOANE DISTRICT MANAGER Mr. Hoyle H. Hamilton ~ Chairman Alaska Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99501 September 7, 1978 Re' Exxon Pt. Thomson Unit Permit No. 76-85 LO/NS No. 76-109 North Slope, Alaska Dear Mr. Hamilton' Pursuant to your request of August 28, 1978, on August 31 we delivered to Messrs. Lonnie Smith and Harry Kugler the daily records prepared at the well site (tour sheets) during the course of the drilling of the Point Thomson Unit No. 1 well and in addition the confidential written record, likewise a daily report, but prepared by this office. The two sets of written records covering the entire period of the drilling operation were entrusted to your staff with the understanding that the materials would be kept confidential during the period required for your examination, at the completion of which period they would be returned to this office. At the time of delivery we stated that work was continuing in our office to ascertain the cause or source of the oil seep in the area of the burn pit at the subject location which work would be shared with you when completed. Ac- cordingly, as we believe we have reached a conclusion reasonably supported by the available information such conclusion is summarized below for your file. Data from three production tests on Pt. Thomson No. 1 shows that approximately 953 barrels of oil, 61 barrels of water cushion and three barrels mud were produced into test tanks located in the contingency pit. Although our records show that 875 barrels of oil from the test tanks were pumped down the 9-5/8 x 13-3/8 inch annulus, we now believe from a re- examination of the data that 64 barrels of this was water cushion and rat hole mud recovered from Zone 1. This means that 142 barrels of oil remained in the tanks after the testing program was completed on December 1, 1977. The morning reports show that the two fuel tanks used as production test tanks were steamed and cleaned out on December 30 and 31, 1977 (2 days). The oil was probably drained into the burn pit at this time and was never burned. ~ i,,~( .... ~'- \ f A DIVISION OF EXXON CORPORATION Mr. Hoyle H. Hamilton Page two September 7, 1978 We do not have shake out data on the 167 drums of fluid recovered from the burn pit but if it approximates 15% water then this would support the possibility that the source was the 142 barrels of oil which remained in the test tanks at the conclusion of the testing program. We could find no other possible source for the oil. Although we deeply regret the incident and have spared no expense to correct it, we wish to assure the Oil and Gas Conservation Committee that every effort will be made in future operations to prevent its recurrence. Yours very truly, Rod L. Boane RLB'RKR'et DEP~ (IF ~TURAL RESOL~ Divisic~ of Oil and Gas Cc~servaticn Files Se_r~m~0er 1, 1978 Petroleum Geologist Pt. ~ Unit #1 Oil cleanup Bob Riddle cawe to our office about 9:15 1~ this date to bring in tour reports and daily drilling reports for the subject w~ll (3 larg~ files). He reported that a ~matsrial balance" of the c~_~ oil indicated that the oil in the burn pit had to be the bottc~s from the tanks. He sa/d that this was based on ~ore J=nfox~ation that had been gathered and after talkLng to other peril s/rice our mseting on Monday, August 28, 1978. I told him to put all this information in a letter and send it to us. DEPARTM~ C~ Iq~JRAL RESOUNEES Divisic~ of Oil and Gas Cc~servatic~ Sep~ 1, 1978 Lonnie C. Smith Chief Petroleum Engineer Petroleum Inspector Oil Spill - Exxon' s Pt. Thompson ~1 ~.~~~ 24, 1978 - I departed my hume at 9:30 AM for a 10:00 A%~ ~ and li~A~~ ~a Wien flight ~9, arriving at Prudhoe Bay at 12:45 PM. I was met at Prudhoe Bay by Fmxcn's C~orge Nash and w~ proceeded to their office whe~-e we picked up Paul Batsman, F~_~rbanks based representative of _Alaska D.E.C., and Byrc~ Teer, Exxon senior drilling technician. We departed Deadbmrse at 1:40 PM via ExXon leased S-61 Sikorsky helicopter arrive_rig at Pt. Thcmpsc~ #1 at 2:05 PM. There we met Adolph To, mas, Exxon drilling superinbendent. Mr. ~s explained, the problem first becan~ evident approximately four weeks earlier when oil began leaching frcm the burn pit onto the tundra. Subsecfuent investigation revealed an unkn(~ quantity of oil ~~ ~ ice layers in the pit. Actual cleanup operati~ were begun approximately August 10th with a hot %rater rope mop ~ installed and settling pits, filter pit, and sludge pit dug. Operation of equipment was contracted to Crowl~ Marine persconel. ~fhe s~oe of operation began with steam/rig of the ice in the burn pit (Pic~are No. 1) and pumping of the liquid into a hot water tank in whJ_~ a~rope mop continually operated (Picture ~b. 2). Contaminated water was then gravitied into t%~ lined set'~g-Pits_ (Picture ~. 3) ~ _~d_~itional oil was absorbed by pads. ~mairn~' g liquid was then p~ into a filter (skin9 pit (Picture No. 4) where Crc~ley l~_rsc~nel mc~ the surface with absorbent pads. According to Mr. Tcmas, all oil soaked pads were being helicoptered to Loffland rig #162 at Pt. Thc~Emon 92 for incineration. Oil soaked dirt and miscellaneous debris was being placed in a lined pit fPicture No. 5) which would then be covered and back filled. At the time of my inspection 144 barrels of oil had been recovered and. barreled awaiting freezeup of the ice road for back hauling to Prudhoe Bay. Mr. 5kxa3s advised recovery of oil was approximating 17 barrels per day at that t/a~. Total cost of the operation at that time was one-half million dollars with cost of absorbent material reaching one thousand dollars per day. Pt. ~ 91 2- Se~cer~ber 1, 1978 testing prooe~ares ~ ~ fozmulated to p~t recurrence of this ~ problem. We departed Pt. T~ %1 via helicopter at 2:55 PM and arrived at Deadhorse at 3:35 PM. I departed Prudb&~ Bay via Wien flight %10 at 6:20 PM, arrivip~ in Anchorage at 7:45 PM and at my hcme at 8:15 PM. ~: I inspected clean%~> ~~ of crude oil frc~ the burn ~'s Pt. ~ #1 appzox/ma~ely 70 miles east of Prudhoe At--ts UZ-UU I D ~Kev. STATE of ALASKA DEPARTMENT OF NATURAL RESOURCES Division of Oil and Gas Conservation ¥O: FFiles and Pt. Thomson Unit #1 II. W. Kugler ~%~{~' FROM: EXecutive Secretary Oil & Gas Conservation Committee DATE: FILE NO: TELEPHONE NO: SUBJECT: August 28, 1978 Oil Clean-up at Exxon's Pt. Thomson Unit #1 Well Site. On Thursday August 24, 1978 Mr. Ben LeNorman visited the referenced well site, at the invitation of Exxon, and it became apparent that major quantities of oil existed in and/or near the "burn" pit and some leakage onto the tundra has occurred. On Monday, August 28, 1978 Monte Taylor, John Jackson and Bob Riddle from Exxon visited with Hoyle Hamilton, Lonnie Smith, Ben LeNorman and Harry Kugler from this office. The information from Exxon, SOmetimes prompted by questions, is summarized as follows: 1) Oil could not have escaped from the annulus, although oil had been injected. 2) Exxon did not know how the oil got into the burn pit but offered the possibilities that: a) Ail the oil from a DST did not burn. b) The oil from 2 tanks that could not be injected was dumped in the pit and not burned. 3) Exxon would take more precautions in the future. 4) A total of 167 barrels of fluids, mostly oil, was re- covered and the clean-up operation was essentially complete. 5) No other tests were performed on the well except those already reported. - s - ~ a ~ ®i~c. ,La'~4 Cat/ LNG ra ~v rea ~'u ~tJ~~t~4. 0 ~c~ _ ,. -~ :, _, ,~.; ~. - ,~, .~ .. - .., a"~-.».= 1 , ~. _. i.` . ~+.. _.___e, Q 77 ,`-~. Y ~ f ml J i ~ a ., _ _ ~ -- ~ /1~ aS'c~7' a'~G/~G ~s 7~f ~C O ~~ (,.~~, . , ~ N ~.~' /"`~':' ~' ~iV:~.a° `fit ~ ~ $ ' ' ~ ,z.~.~ ~ia~~~~ r~f'_ ~\ ~~ ~ ' y a ,v., - ...+~. ~s~ _ ___ , -~.., ~ ~ 6 - _ _ _ ~ ..~ ~.. 'gab ., >~ ' ' ,~, ~ ~ ~ ~ ~ ...~~ _ 03~'?`, ~Y"45 ~.~ . Ayrr~ ~.._ ''mss ~ '~ -.w.~, w -~ ~ --,;-'. ~ ~ ~ A _ w ' ~~--"~'~" ~ ~' ~ `~ ~ ~' ° - -.r w ~.-V ti's"' ~ }..~~-,- . - .. r. 4 `n i`.~i. i 7~a ~ ~J F.6t ,i•~l.~auyc. - /~~; ~+o~rr~s®.J ~'`0 N 0 ~, W _ -- - ~ r:~.. Q _. _ - ` -:r _. .. 4 ~a~i'..d~ '.`.S. 1d a _~ _ - Y 1 ~. ti ~ ~ ~i=~ ~y ~ ~° j ~.~ ~ irk ~i=s*~~~. ~ ~o ~ ~' -- - ~.~ , w~ .~ Q .. .. ~~ m, .:;ti.. Y~ ~'y _ Q. - ~ .:~. a ..y _ - ~ ~ ..-.1C c ~'"'~Kv Q _ ~,.. - _ ,~,y .:iO ` ~~~ S _ ~' t Jr may. h'.. •_ '~rSN -l ..~ ~~ Form No, P---4 REV. $- I-?0 STATE O1" ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS o,L FI cA. []] oT.~. Wildcat APl NU,~ERICAL CODE 50-089-20005 LEASE DESIGNATION AND SERIAL ADL 47560 7 IF I~DIA]~, ALOI 1~1:. OR TRIB~ t'~ NA/~E OF OP~TOR Exxon Corporation 3. A~DRESS OF OPERATOR Pouch 6601, Anchorage, Alaska 99502 4. LOCATION OF WF, LL 1,320' NSL & 660' WEL of Sec. 32, T1ON, R23E, UPM, North Slope, Alaska 8. L.~IT FARA{ OR LEASE Point Thomson Un' 9 WELL NO Exxon No. I 10. FIELD AND POOL. OR WILD( Wildcat AT I1 SEC., T.. R., M. (BO'FrOM HOLE OBJF, CT~ Sec. 32, T1ON, R23E 11. PEItNIIT NO REPORT TOTAL DKPTH AT END OF MONTH, CHA2fGES I* HOLE SIZE, CASING AND C~V[ENTING JOBS INCLUDING DEPTH SET A/~q~ VOLLrNIES USED. PERFOI:LATIONS. TE~TS ANT) RESULTS FISHING JOB,S JL2qK L~/ HOLE A_ND SIDE-TRACKED HOLE A.~D ANY OTHER SIGNIFICANT CHANG-~ IN HOLI~ CONT)ITIONS. SUBSEQUENT REPORT OF WELL sUSPENSION' Upon completion of a flow test through perforations from 11,392' to 11,421', a retainer was set at 11,250'. The perfs were squeezed with 50 sacks class G cement below the retainer and 50 sacks were placed on top of the retainer. After testing to 1000 psi, the csg was displaced with 15.7 ppg mud. Then the 7" csg was backed off at 4003' and pulled from the hole. Injected 473 barrels mud down 13 3/8" x 9 5/8" annulus, followed by 105 bbls of 9.6 ppg salt water, followed by 50 barrels of diesel oil, 50 bbls of Arctic Pack premix and 101 bbls of Arctic Pack. With open ended drill pipe at 3500', 265 bbls of 10.6 ppg CaC12 water was circulated into the 9 5/8" csg. Pulled out of hole to 130' and placed a 53 sack permafrost cement plug in the 9 5/8" csg. Removed BOP stack and blew out 9 5/8" csg with air down to 25' below GL. Poured in 4 gal glycol and filled rest of 9 5/8" csg with die~el oil. Installed 13 3/8" blind flange totopof wellhead and tested to 500 psi. Well marker placed on top of well at 0600 hours 12-8-77. This will be the final report on the well. ~.~.~h,,~b,,~ ' ' ,,..~,'o,',',~ .,d"'g~ Dist. Mgr. Offshore/Ak. Div. StoWeD Rod L. Boane ~=~ Exploration Department DAT~ 3-17-78 NOTE--Report on this form is required for each calendar months regardless of the etatus of operations, and must bo flied In duplicate with the oil and gas coneervat/on committee bythe ISth of the succNding montlt, unleM otherwiee directed. CONFIDENTIAL STATE OF ALASKA SUBMIT IN DUPLICA'I'~ OIL AND GAS CONSERVATION COMMII-I'EE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS AP1 NU~[ERICAL CODE 50-089-20005 LEASE DESIGNATION AND SERIAL NO. ADL 47560 ? IF INDIA)4', ALOTTEE O]~ TRIBE NAME 1, o,L J-] ("" [-] oT.E~ Wildcat WELL WELL 2. NAME OF OPE~tATOR 8. L.~IT Fbd~ OR LEASE NAME Exxon Corp. oration Point Thomson Unit i. ADDRESS OF OPERATOR Pouch 6601, Anchorage, Alaska 4. LOCATION OF WELL 1,320' NSL & 660' WEL of Sec. North Slope, Alaska 99502 32, T1ON, R23E, UPM, 9 WELJ~ NO Exxon No. 1 10 FIELD A_ND POOL. OR WILDCAT , Wildcat , 1I SEC., T., R., M.. (BOTTOM HOI~E OB~-ECT~ Sec. 32, TION, R23E 12. PERNIIT N'O. 76-85 ,, 13. REPORT TOTAL DEPTtt AT END OF MONTH, CHA2~'GES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AI~D VOLLrlVIES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOB~. JUNK LN HOLE A_ND SIDE-TR~.CKED HOLE A. NDANY OTHER SIGNIFICANT CI-tANGES IN HOLE CONDITIONS. Point Thomson Unit No. 1 was plugged and suspended, per last months report and Loffland's rig 162 was moved off location. Therefore this will be the final report for this well. he.by ~erti,y %l~(,he f~e~F~/J~%~ue ~ ~' Di st. Mgr. Offshore/Ak. Div. .... : x ora on e ar men SIG~ NOTE--Report on this form ii required for each calendar ~ntht regardless of lhe status of operations, and must ~ filed in duplicate with the oil and gas coniervatlon commi~ee bythl 15~ of the luoc~ding mon~, unle~ otherwiie directed. CONFIDENTIAL OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT OF DRILLING AND WORKOVER OPERATIONS 1. O,L [] o*, F~ 0THZR Wildcat ~LL W'ELL 2, NAME OF OPERATOR Exxon Corporation ~. ADDRESS OF Pouch 6601, Anchorage, Alaska 4. LOCATION OF WELL 1,320' NSL & 660' WEL of Sec. North Slope, Alaska 99502 32, T10N, R23E, UPM, APl 'NUA{ER/CAL CODE Point Thomson Uni~ 9 WELL NO Exxon No. 1 [ 10 FI~I.D ~NDPOOL. ORWILDCAT Wildcat 11 SEC., T., R., Sec. 32, T10N, R23E~ 76-85 ~ ~;: JOBS INCLUDING DEPTH 13.REPORT TOTAL DEI>/~q AT EJqD OF MON~~zI, CHA~GF~ IN HOLE SIZE. CASING ABED C~mVIE/~TING SET ~ VOL~ USED. P~O~TIONS. ~TS ~ ~SULTS FISHING JO~ JI.~K L~ HO~ ~D SIDE-~CKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS. A 5% hour stabilized test through perforations~ from 11,392' to 11,421' flowed gas at the rate of 2,250 MCF per day and 132 barrels of 44.4©API gravity condensate. The perforations were squeezed, below a retainer set at 11,250', with 50 sacks of class G cement. Fifty sacks of cement was placed on top of the retainer. The well was plugged and suspended, per Sundry Notice dated 12/2/77, at 0600' hours Dece~er 8, 1977. RECEIVED D'.'.'isiaa et 0il al!d Gas Consca,?,ti0n Afl~hora~0 1,~. ! hereby cer~m~t th~ fo~go~;~ true ~ eorrc~[ Dist.Mgr. Offshore/Ak. Div, sm~~~/~~~~/~, 'mT~ Exploration Department DA~ 1/18/78 NOTE--RI~ort on this form is requirld for each calendar ~nth% regardless of the ~tatus of operations, and must ~ filed In duplicate with the oil and gas con. ervation commiffee by the 15ffi of the suoc~ding monffi, unle. otherwile directed. /*,! -; E ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION R. L BOANE DISTRICT MANAGER CO N FI D'ENTI AL Mr. O. K. Gilbreth, Jr. Director, Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 January 9, 1978 Re' Exxon Pt,. Thomson Unit No. 1 ADL 47560 LO/NS 76-109 North Slope, A1 aska Dear Mr. Gilbreth' On December 8, 1977 the subject well, Exxon Point Thomson Unit No. 1 was plugged and suspended in accordance with the Sundry Notice, Form 10-403, filed and approved December 2, 1977. Pursuant to the provisions of ll AAC 22.535 we submit the Well Completion Report, P-7 with the following additional data' (1) One set of washed and dried samples from 826' to 13,278' - (in 14 brown boxes) (2) Core chips taken at 1' intervals (in white core boxes) from the following cores' Core No. Interval 1 10,720 ~',.~ 2 11,420 ~.'~',-.,, 3 11,455 :- ~,~-* 4 12,052 .,. i 5 12,158 6 12,830 7 12,890 8 12,950 : 9 1 3,009 10 13,069 11 13,128 12 - 1 0,780 - 11,455 - 11,492 - ll ,086 - 12,178 - 12,890 - 12,950 - 13,009 - 1 3,069 - 13,128 - 13,158 13,158 - 13,163 (3) One blueline print of the complete mud log from 826' to 13,278'. At the present time a sepia print cannot be obtained from the mud logging company, but will be furnished as soon as it becomes,~. available. A DIVISION OF EXXON CORPORATION Mr. O. K. Gilbreth, Jr. -2- 1-9-78 (4) 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, Borehol e Geometry Cased Hole Logs: Dual Spacing Thermal, Neutron Decay Time BHC Sonic, Cement Bond Log, Compensated Neutron - Formation Density, Compensated Formation Density. (5) Test Data, Point Thomson Unit No. 1. As noted above the sepia print (3) above will be furnished as soon as it becomes available from the logging company. We ask that all of the above be kept confidential in accordance with the provision of 11 AAC 22.535. Rod L. Boane District Manager RLB'RKR'jh cc' Mr. Joseph Green, DMEM CONFIDENTIAL Form P--7 ~ ]LASKA i .. Stm~ZT z ']/ STATE OF in- - structions on ' · $. A~I ~UM.F-,R/CAL CODE OIL AND GAS'CoNsERVA~ON COM'MITTEE reverae side, ~0-039-~0~0~ WELL CO~PLETIO~ ~R RECO~PLETIO~ REPORT ~D L~* I,. TYPE OF WELL: OILWgLL ~ ~*SWgLL ~ DR~ ~ Oth'er Wildcat b. TYPg OF COMPLE~ON: W~L~ OVeR ~ ~*C~ n~SVB. Other ~l.lgppndpd ~. UN~T,F~ OR mSg ~. ,,~ o, o~,~,~o~ Point Thomson Unit Exxon Corporation ~. w~L ~o. 3. ~,~,~ o, o~o, Exxon No. 1 P.0. Box 2180, Houston, Texas 77001 ~0. ~ ~D ~L. OR W~t ~. L0Ca~,0S O~ w~nn (Re~ort ~ocation cl,ar~y and in accordance with an~ State requiremeat,)' Wi 1 dcat UPM -. (~~ ~o~ at,~¢, 1320' NSL & 660' WEL of Sec. .32,JtON, R23E,~,~ ~ ~..~..a..~.. North Slope Alaska · t top prod.interval repor~belbw at tot~ a~' .. ~'".~ ~_._..'",.~ H' s::= ~. ~q~ ~:: '~(]~;>2-~"~ ~ uPMSeC 32,( Pre-MiT10N,ss R23 E<') 3-6-77 9-]2-~7 : [Pi~gge~-~ Suspended 33.45' KB --- . . I ] P-~-77 ' , f ~ ~OW ~Y* ROTAR OLS ' CABLE TOOL8 /~98' : Surface --- m. P~ODUC~ ~VaL(S), O~ ~ ~M~X~~. ~M. ~ (~ A~D ~)' ' l~. W~ DX~O~ ' Perfor~ons cemented for purposes of safety. See item 28 and for perf~tion intekvals and cementins. See Attachments for test data..] No ~..~E~IC ~D T~ ~S~ ' ' ' 'U ~ ~ ~ Dual Induction, Sonqc, Density, Compensated Ne~.tron, ~ Diometer, VeloCity. Boreh0le Geometrv. Thermal Decav , ,, OAS~ ~ (Re~ all arras set in weld 28. PERYORATIONS OPW-LN TO PRODUCTION 28" x 36" insulated-dond,Jctbr 23' 18 5/8" 96,5 -' I K-55 [ Rill' 13 2/2" 72/62 . INan/,~;~ 2776' 9 5/8" ao ' I °bg l 9532, LINER ~CO~ : 7" * 9fl32~ ~ ll3qfl ! 560 4%" 10873 ' '13295 [ 317 (In~, size ~d number) 12,963' to 13,050' (4 spf) 12,834' to 12,874" (4 spf) 11,392' to 11,42]' (4 spf) HOI~E SIZE I CFa%~tLNTING RECORD 4?" !to siJrface with normafro~ 6. LEASE DESIGNATION AND SERIAL NO. ADL 47560 7. IF INDI;dNI, ~J_fl. XZ>I'I'EE OR ~ELIBE NAM~ AMOUNT PULLED 30. PI{ODUCTION t cmt_/ None Nnne . Nnno None 24" I 6350 sx Pormafro~t cml 17 ]/?"1 7~00 sY Pmwmmf~'nSf rmt l?_ i?4"l 1300 sx Class G 27. TUB~G ~ (MD) SIZE DE~ S~ (MD) ~PACKER S~ (~) nonP no~fl , ACID. SHOT, F~'U~, C~:~ SQU~ZZ, D]~PTI{ INT]~RVA_L (MD) [ AMOUNF ;~D KIND OF M/kTEi~IAL USeD 12,963'-13,050'1..sqz cmt w/145 sx Class G 12~834'-12,874'I sqz cmt w/76 sx Class G li',392'-11,421'1 sqz cmt w/50 sx Class G i DATE FIRST PR. ODUCTION I FI{ODUCTION METHOD (Flowh~g, gas lift, pumping--size and type of pump) SEE ATTACHI/1ENT DATE OF TEST. [HOURS TESTED '[CHOI<E SIZE ~PROD'N FOR FLOW, TUBING [CASING PRESS~ [CALCULATED OIL--BBL. 31. DISPOSITION Or GAS (Sold, u,ed $~r ]uel, vented, etc.) I WELL STATUS (Producin~ or '- [;nut-in). OIL--BBL. GAS--IV~CF. WATEr--BBL. ~ GAS-OIL I GAS--M .QF.I . WATEIH,---BBL. [ OIL GRAVITY-APl (COi?~I~,.) 1 TEST WITNESSED BY ,..i... !'J L,~ :~'~t'" Blair Wondzell,OMiM 32. LIST OF ATTACHMENTS Core Data, Test .Data Dhisi(,r~ cf (,. ~,., ~.: ...... , ' ,, ,. 33. I hereby certify that the foregoln r tlon is complete and correct ['~i. determined from all-available rec6rds SIGNED Rod k. Beane ,~ ~~TLEDist. Mor. Offshore/alaska. DATE j/9/78 ~ F~pl.n~a..t~nn QPD~, ' - - '(~e I,~tr~:tiQ,~ a,d S~:e~ tQr AdditiQ,al'Data on Reverse Side) * 7" liner tied back to surface; was backed off at 4003' and pulled. CONFIDENTIAL INSTRUCTIONS General: This form is designed for submitting a complete and correc~ well completion report and 10g on. all types of lands and leases in Alaska° Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate prcduction from more than one ~nterval zone (multiple completion), so state in item 20, and in item 22 show the prcJucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the ackiitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should 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 produced. (See instruction for items 20 and 22 above). 34. SUMMARY 'OF' 'PORMAT'ION TE,S'I'S IN('£,UDIN(; INTERVAL TE,S'FED, t't~E~SURE DA~ ~ ~COVERI~ OF OIL. GAS. 35. G~GIC MAR~ WAT~ AND MUD . ~mAS~ .~ ~u~ v~r. ~ ..... ~~ lert~ary Surface =. .=~ Paleocene 8280' See Attachments F ~.~ Thomson Sd 12,815' ~ ~[.=~ Pre-Mi ss 13,1 61 ' . -. ~ ~- · See ~ttachments .... .................. m.. ~ ,.~ .,~, ....... ~ ............... (2) CONFIDENTIAL CORE DATA Exxon - Point Thomson Unit No. 1 1VIIN3EIIJNOD Core #1 10,720 -10,780 . Rec. 60' siltstone with thin shale partings and thin laminae of sandstone, med gry-brn, vfg, dense,-pin point porosity with oil staining. Horizontal dip. Core #2 11,420 -11,455 . Rec. 29' siltstone with partings of shale and thin laminae of sandstone, It brn, vfg, poor porosity. Oil staining in upper 8' of core. Dip 5 - 10°. Core #3 11,455 -11,492 . Rec. 37' siltstone with thin shale partings and thin laminae of sandstone, It brn, vfg, poor porosity. Oil stain in bottom 23' of core. Dip 0 - 50. Core #4 12,052-12,086. Rec. 10' sandstone, It gry, vf-fg, poor porosity with oil stain; 24' shale with thin beds of siltstone, It tan, no show. DiD 10°. Core #5 12,158 -12,178. Rec. 8' sandstone, It brn, vfg, fair porosity with oil stain; 2' siltstone, It gry, no show; 10' shale with thin laminae of siltstone, no show. Core #6 Core #7 12,830-12,890 . Rec. 60' sandstone, gry-brn, vf-f~, calc, poor to fair porosity with oil staining. Dip 0 -5u. 12,890'-12,950'. Rec. 59.5' sandstone, gry-brn, vfg, silty, calc, poor porosity with oil staining. Horizontal dip. Core #8 12,950'-13,009'. Rec 48' sandstone, gry-brn, vf-fg, poor to fair porosity with oil stain, sctd thin beds at pebble congl, brn-gry, fair to good porosity with oil stain; 11' pebble congl, brn-gry, good porosity with oil stain. Dip 0 - 20. Core #9 13,009'-13,069'. Rec. 41' pebble congl, med-dk brn, cg, good porosity with oil stain; 17.5' breccia, med-brn, pebbley, calc, poor porosity with oil stain. Dip 0 - 50· Core #10 13,069'-13,128'. Rec. 4' breccia, med brn-gry, cg, poor porosity with oil stain; 30' pebble congl, brn-gry, vcg, poor porosity with oil stain; 25' sandstone, dk to med brn, vf-cg, poor porosity with oil stain, sctd pebbles. Dip 0 - 10°. Core #11 13,128'-13,158'. Rec. 30' sandstone, med brn to gry, vf-vcg, sctd thin beds of pebble congl, poor porosity with oil stain. Dip 0 - 10°. Core #12 13,158'-13,163'. Rec. 2' breccia congl, med brn to gr,y, hard, poor porositY }Nith oil stain; 3' phyllite, It gry, pyrite, no shows. Dip 40v. CONFIDENTIAL 13-3/8" x 9-5/8" annulus - Annular fluid will be flushed using 105 bbls. of 9.4 ppg saltwater, followed by 50 bbls of diesel oil, 50 bbls. of Arctic Pack premix and 105 bbls. of Arctic Pack. Approximate depths: 0 to +/- 1800' Arctic Pack +/- 1800' to +/- 2600' Arctic Pack premix +/- 2600' to +/- 13-3/8" shoe diesel oil Cement Plug No. 4 - (35-130) A balanced cement plug will be placed from 130' to 15' below ground line. Test to 500 psi. Note: Diesel oil will be placed in the 9-5/8" from 15' below ground line into the remaining wellhead. A 13-3/8" 5000 psi blind flange will be bolted to the top of the wellhead. Marker placed on top of well. q-0c (~ IS~ .Poebou~ 6~utoo ~[U~L (,'-- SS' ~r~~ ':~roM cE~6~? ~u&(~ i~! !t :3q'L- IlqZl ..... :' tTK(~ ~ tl$ob~ -~' q" ~S~ $~S ~%(D IL~qo~ (5) TEST DATA Point Thomson Unit No. 1 CONFIDENTIAL Test Number Date Type Test Interval Cushion Test period S. I. Period )w Rate Flowing Tbg Pres Surface Choke Tubing Size Depth BHP Guage IFP ISIP FFP FSIP #1 10-30-77 Potential thru Perfs 12,963' - 13,050' (4 spf) 12,900' water 18 hrs 30 min : #2 11-20-77 Production thru Perfs 12,834' - 12,874' (4spf) 12,700' diesel 7 hrs #3 11-30-77 Production thru perfs 11,392' - 11,421' (4 spf) 11,300' diesel 11 hrs 45 min 82 hrs 15 min 18 hrs 30 min 31 hrs 30 min (1) 2,283 BOPD(18.4°API grav)&(2)3,860 MCFG/D & 170 bbls~ 45.4© (3)2,250 MCFG/D & 132 bbls 44.4© 13,307 MCFG/D (GOR 5830:1) 3,500 psi Variable 5/64" - 12/64" 2 3/8" by 2 7/8" tapered string 12,937' Guages Not Recovered 10,160 psi (est) API gravity condensate 4,380 psi 12/64" 2 3/8" by 2 7/8" tapered string 12,007' 8,875 psi 10,118 psi 6,363 psi 10,007 psi API gravity condensate 2470 psi Variable 21/64" - 39/64" 2 3/8" by 2 7/8" tapered string 11,338' Recording stylus off chart Recording stylus off chart 5,498 psi 9,203 psi (1) Based on 8 hr stabilized test (2) Based on 4 hr stabilized test (3) Based on 5 1/4 hr stabilized test Form 1~o. I'LlgV. $-1-70 STATE O~ ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WOR'KOVER OPERATIONS SUBMIT IN DUPLICA~ AP~ NU~IERICAL CODE 50-089-20005 1, o,L,,L~ []] °*',,.,.~ []] o,,,~, Wildcat 2.NAME OF OP~a~TOR Exxon Corporati on ADDRESS OF OPEI:I.~TOR Pouch 6601~ Anchora§e, Alaska 99502 4.LOCATION OF W 1,320' NSL & 660' WEL of Sec. 32, TION, R23E, OPM, North Slope, Alaska 6 LEASE DES:GINIA'?ION AND SElqlAI~-I~. ADL-47560 7 IF INDIAM'. ALOTTEE OR TRIBE~NAJ~E 8. L,~IT FAF~{ OR LEASE lqAME ,~ Point, yELL .~-oTh°ms°n Uniti Exxon No. 1 10. FIELD END POOL. OR IVI1.DChT ; Sec. 32, T1ON, R23Ei . ~3. R~ORT TOTAL D~ AT ~D OF MON~, C~NG~ IN .OL~ SIZS, CASING A~ C~TING JOBS INCLUDING DEPT~ SST A~ VOL~ ~SED, ~O~T~O~S. ~ZS ~ ~S~S ~SmSO JO~ J~X IN HO~ ~D S~D~-~.*C~SD ~On~ ~D ~Y O~ S~F~C~T ~m m ~O~ ~T~O~S. ~q~.~:.~?~fter the potential test from perforations 12,963' to 13,050', 70 barrels of diesel was pumped down the tubing and the well shut in. Final stabilized shut in surface tubing pressure was 5544 psi. Attempts to free the wireline from the pressure guages were unsuccessful so the line was cut and removed from the tubing. The well was then killed with 15.8 ppg mud and the tubin9 pulled out of the hole. The pressure guages were not in the tubin9 so were therefore not recovered. A cement retainer was set at 12,895' and the perforations squeezed with 145 sacks of neat cement with 1% Halad 22-A and .5% HR-7. ,~~~nterva] from ]2,834' to 12,874' was perforated w~th 4 shots per foot using a (~ 2 7/8" casing gun. A Baker ~ode] F-] packer was set on a w~re]~ne at 12,700'. A 2 3/8" by 2 7/8" tapered string of tubing was set ~n the packer. The tubing was d~sp]aced w~th 60 barrels of d~ese] and the we]] was opened for flow. After the we]] cleaned up, a 4 hour stabilized test flowed gas on a 12/64" choke at the rate of 3,860 NCF/day and 45.40 API 9rarity condensate at the rate of ]70 barrels per day. The perforations were squeezed, below a retainer set at ]2,302', with 76 sacks of class G cement. Three barrels of cement was dumped on top of the retainer. ~,~n interval from 11,392' to 11,421' was then perforated with 4 shots per foot ~ using a 2 7/8" casing gun. A Baker model F-1 packer was set at 11,300'. Then a 2 3/8" by 2 7/8" tapered string of tubing was set in the packer. The tubing has been displaced with diesel and at the end of the month preparations are being made to open the well for flow. R~CEIVED CONFIDENTIAL ,.~ 14. I he~b~ th~e~~o~ ,~ ~ ~ Di st. Mgr. Offshore/Ak. Div. SIG~ ,~~ NOT[ ~R~port on this form is required for eoch colend~r ~nth~ re9mrdless of ~he stot~$ of operotions~ ~md mus~ ~ flied in duplic=t$ with th oil end gms conservation commIHee bythe 15~ of the s~cc~din9 mon~, unle~ 0ther~i$e directed, 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,~) GAS 0 OTHER Wi 1 dcat WELL 2. NAME OF OPERATOR Exxon Corporati on i5. APl NUMERICAL CODE 50-089-20005 6. LEASE DESIGNATION AND SERIAL NO. ADL 47560 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Point Thomson Unit 3. ADDRESS OF OPERATOR · -!. ..~ · -. 9. WELL NO. P.O. Box 2180, 'Houston, Texas 77001 ' Exxon No. 1 10, FIELD AND POOL, OR WILDCAT Wi 1 dcat 4. LOCATION OF WELL At surface 1320' NSL & 660' WEL of Sec, 32, T1 ON, R23E, UPM, North Slope Alaska 13. ELEVATIONS (Show whether DF, RT, GR, etc.) Approximately 11' GL 14. Check Appropriate Box To Indicate Nature of Notice, Re 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 32, TI0N, R23E 12. PERMIT NO. 76 -85 3orr, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Suspend SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENTW ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Reason For Suspension - Well suspended for possible later re-entry. Cement Plug No. 1 - (12895-13050) Cement retainer set at 12,895'. Cement squeeze performed. Test to 1000 psi. Cement Plug No. 2B-l (12100-12874 )a Cement retainer set at 12,300'. Cement squeeze performed, anced plug set atop the retainer from 12,100' to 12,300'. Test to 1000 psi. Cement Plug No. 3 - (10,770 +/- - 11,421) Cement squeeze performed through retainer 11,250' +/-. Balanced plug set atop packer from 10740 +/- to 11,250'. Test to 1000 psi. Note' Drilling mud weighted to 15.6 ppg will be in place between the first three cement plugs and to a depth of +/- 3500' and below. The 7" casing will be cut and retrieved from 4000'. A 10.6 CaC12 - H20 solution will be circulated into 9-5/8" casing from 3500' to 130'. 16. I hereby certify that the foregoing is true and correct (This space for State office use) CONDITIONS OF APPR~AL, IF ANY: ITLE See Instructions On Reverse Side , 13-3/8" x 9-5/8" annulus - Annular fluid will be flushed using 105 bbls. of 9.4 ppg saltwater, followed by 50 bbls of diesel oil, 50 bbls. of Arctic Pack premix and 105 bbls. of Arctic Pack. Approximate depths: 0 to +/- 1800' Arctic Pack +/- 1800' to +/- 2600' Arctic Pack premix +/- 2600' to +/- 13-3/8" shoe diesel oil Cement Plug No. 4 - (35-130) A balanced cement plug will be placed from 130' to 15' below ground line. Test to 500 psi. Note: Diesel oil will be placed in the 9-5/8" from 15' below ground line into the remaining wellhead. A 13-3/8" 5000 psi blind flange will be bolted to the top of the wellhead. Marker placed on top of well. r)~E~EL PeG- -/" S$~ T~EP-.,AC..IX 'Th? q~'z..." Lt,,R('~ -.Z:o~6.~.i ,[,.:., :. "F6 C. I?-, 5-qS (~D Form ~o. P,.,~"V, ~- I-?0 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATi. ~=C 1. o,L [] °'" [] oT,, Wildcat 2, N~E OF OP~TOR Exxon Corporation Pouch 6601, Anchorage, Alaska 99502 4 LOCATION OF WELL 1,320' NSL & 660' WEL of Sec. 32, TION, R23E, UPM North Slope, Alaska 50-089-20005 LEASE DESiG~A~ON AXD S~IA', N ADL 47560 Exxon No. 1 ~ cat o~~ Sec. 32, TION, R23E 1~ PlglqlVllT N'O 76-85 13. REPORT TOTAL D1KPTH AT END OF MONTH. CI-IJ%.NGIgS IN HOLE SIZE. CA,lNG A~ C~TING JO~S INCLUDING DEPTH SET ~ VOL~ USED~ P~O~TIONS. ~TS ~ R~SULTS FISHI~G JO~ JI~K ~ HOL~ AND SIDE-~.ACKED HOLE ~ND ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS On October l, 1977, the top of the 4½" liner was pressure tested to 1,000 psi and leaked off to 850 psi in 10 minutes. After squeeze cementing the liner top with a 16 barrel slurry of cement, it was pressure tested successfully to 1,500 psi. Then 7" casing was set from the surface to the tie back sleeve at 9,032' and cemented with 120 sacks of Cl G cmt with 1% CFR-2 and .1% HR-7, 16.1 ppg. Cement inside the 7" casing was tagged at 8,652' and drilled to 9,038'. The 4½" liner was cleaned out with a mill to a plug back total depth of 13,248'. With a RTTS tool set in the 7" casing at 10,210', the annulus above the tool was successfully pressure tested to 5,000 psi. A pressure test below the packer to 3,000 psi was OK. The RTTS was then set at 10,515'. A pressure test below the tool to 4,000 psi broke down the 4½" liner top. Attempts to squeeze with a 20 barrel and a 23 barrel Diaseal D slurry were unsuccessful. The 4½" tie back receptacle was cleaned out and the top of the liner dressed off with a 5¼" mill. A tie back pack off assembly was set in the receptacle and pressure tested OK to 3,000 psi. The following cased hole surveys were run' Thermal Neutron Decay Time, Sonic, Formation Density-Com- pensated Neutron, and Cement Bond. The 4½" liner was perforated from 12,963' to 13,050' with 4 shots per foot using a 2 7/8" casing gun. A Baker Model F-1 packer was set on a wireline at 12,900' Then a 2 3/8" by 2 7/8" tapered string of tubing was set in the packer. After dispiacing the tubing with water, pressure guages were set on a wireline at 12,937'. We could not get off the guages with the wireline so the well was opened for flow. After recovering the 64 barrel water cushion plus 5 barrels of new fluid, the well was shut in. While attempting to free the wireline from the pressure guages, the wireline broke and was tied off at the lubricator. When the well was again opened for flow, the tubing pressure dropPed from 5,500 psi to 950 psi with no fluid recovery. A hydrate plug formed in the 2 7/8" tubing and was melted by pumping batches of hot water down the 9 5/8" by 13 3/8" annulus. On October 29, 1977 at 2400 hours the well was opened to flow. The well reached a stabilized flow rate and an eight hour potential test was conducted on October 30, 1977, from 0800 hours until 1600 hours. During this period, ~\./l~he well flowed at an average rate of 2,283 BOPD with an average GOR of 5,829 CF/BBL. At the end _of_.tb_e_.nlo, nth the well is shut in for the final bottom hole pressure buildup. ONFI UENIIAL s~ ,~~ ,.z.~:~ ~p~orat~on Department .~ November 16, 1977 NOTE ~Reoort on this form i~ required for eac~ cal,ndar ~nth~ reg°rdle~s of t~-it~tus .f o~,ratleas, and mu~t ~ fi~ed In duplicate wlt~ the oil and gas conlervaf/on commtflee by fhe 15~ of the su~c~ding mon~. ~1~ ~therwita d~rected.~ ?~ ~,:~L ~'~ ~ :~ ~ '~ ~h ~'~ ~ ~': ~ ~ ~: ::~=: q: ~ ~ ~ COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION November 11, 1977 Alaska Dept. 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 our Point Thomson Unit, Exxon No. 1 well. Very truly yours, Rod L. Boane District Manager JLG: j rh Attachments 295-600-110 A DIVISION OF EXXON CORPORATION 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 WELL~ (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELLL_.J WELLI...J OTHER Wildcat ....... ' 2. NAME OF OPERATOR Coroora~ion Exxon 5. APl NUMERICAL CODE 50-089-20005 6. LEASE DESIGNATION AND SERIAL NO. i~DL 47560 7. IF INDIAN, ALLOTTEE OR TRIBE NAME NA 8. UNIT, FARM OR LEASE NAME pOint Thomson Unit 3. ADDRESS OF OPERATOR 9. P.O. Box 2180, Houston, Texas 77001 T10N, 4. LOCATION OF WELL At surface 1320' NSL and 660' WEL of Section 32, R23E, UPM North Slope, Alaska WELL NO. Exxon No. 1 10. FIELD AND POOL, OR WILDCAT Wildcat 13. ELEVATIONS (Show whether DF, RT, GR, etc.) Approximately ll' GL Check Appropriate Box To Indicate Nature of Notice, Re 14. 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 32 T10N, R23E 12. PERMIT NO. 76-S5 )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Squeeze Perforations , (NOTE: Report results of multiple completion on Well COmlHetlon or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. This well has been perforated in the interval (12962' - 13,049') and has been production tested through tubing with a permanent packer set at 12,900'. 4-1/2" 15.1~/ft S-95 liner is set at 13,295' and plugged back to 13248'. A retainer was set at 12895', and perforations were squeezed with 145 sx of Neat Class G + 1% HA-22A + .5% HR-7 (30 Bbl. slurry volume). The first 15 Bbls. contained approximately 8 millicuries radioactive tracer to allow tracing the lead slurry with a gamma ray log. Verbal approval to inject radioactive tracer was received from Mr. Lonnie Smith of Division of Oil and Gas at 2:15 kH November 11, 1977. All 30 Bbl. were pumped through the retainer leaving the top of the cement at the retainer and placing 28 to 29 Bbls. cement into the formation. Please note this will be retaine~ as a production well. A proposal to suspend the well will be furnished at a later date. SIGNED _ · District Manager Offshore/AK Division TITLE DATE November 11, 1977 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE See Instructions On Reverse Side E , ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION November 9, 1977 Alaska Department of Natural Resources Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Attn: Mr. Lonnie Smith Dear Mr. Smith: During production testing operations on October 30, 1977, two separate but related discharges of produced crude oil occurred at Exxon's Point Thomso~ drill site location. Mr. J. F. Homer called the Di~i§ion of Oil and Gas at 0656 AST on October 30, to report the first ~zi~l and an answering service said the call would be returned. The Division was again contacted at 1225 AST the same day after the second sram! was discovered and the answering service took the call. Below are pertinent facts regarding this incident. 1. Date and time of discharge - October 30, 1977 at 0000 ADST hours. 2. Location of the discharge - Latitude 70o10'26.95'' N, Longitude 146°20'14.62'' W or on the Exxon No. 1 Point Thomson Unit well drill site location. 3. Person or persons causing or responsible for the discharge - Exxon personnel were conducting production testing operations when the discharge occurred. 4. Type(s) and amount(s) of hazardous substance(s) discharged - Produced crude oil, approximately 5. Cause of the discharge - Bypass hose connection between a pump discharge line and a stock tank line came loose. When the hose connection came loose, the flow was immediately directed to the flare line and further discharge was prevented. A DIVISION OF EXXON CORPORATION Alaska Department of Natural Resources November 9, 1977 Page 2 · Environmental damage caused by the discharge, to the extent ascertainable - No environmental damage is apparent or has been detected. All spilled fluid was contained within the contingency pit and solidified upon being deposited on six inches of snow within the pit. · Cleanup actions undertaken - The solidified crude oil and snow were scooped up in shovels and transferred to the burn pit for ultimate disposal. · Location and method of ultimate disposal of the hazardous substance and contaminated cleanup materials, including date of disposal - All the solidified oil and snow were placed in the burn pit and incinerated on October 31, 1977 upon verbal approval by Bob Tsigonis of the Alaska Department of Environmental Conservation. · Actions taken to prevent recurrence of the discharge - Ail equipment and piping will be carefully inspected prior to commencement of production testing operations. Below is the information on the second spill. 1. Date and time of discharge - October 30, 1977 at approximately 0000 ADST hours. · Location of the discharge - Latitude 70o10'26.95'' N, Longitude 146°20'14.62'' W or on the Exxon No. 1 Point Thomson Unit well drill site location. · Person or persons causing or responsible for the discharge - Exxon personnel were conducting production testing operations when the discharge occurred. 4. Type(s) and amount(s) of hazardous substance(s) discharged - Produced crude oil, approximately 1 to 2 barrels. 0 Cause of the discharge - With the well flowing during produc- tion teSting, a hose connection came loose near the stock tanks resulting in the spill detailed above· This problem was immedi- ately nOticed by the crew and the flow was diverted to the flare line and ignited· Unknown to _the crew at the time, an estimated 1 to 2 barrels of oil mist from the flare line blew out of the burn pit upon the surrounding snow prior to ignition· This second spill was not discovered until after daylight· If the flare line had been intended to be used, it would have been preignited. ~ i-~i~!~.~'~ ~'~ ~ .... , Alaska Department of Natural Resources November 9, 1977 Page 3 · Environmental damage caused by the discharge, to the extent ascertainable - No environmental damage is apparent or has been detected. All spilled fluid solidified upon being deposited on six inches of snow. · Cleanup actions undertaken - The solidified oil and snow were scooped up with a front end loader and shovels after permission was received to use the equipment from DMEM at 1300 AST 10/30/77 and transferred to the burn pit for ultimate disposal. · Location and method of ultimate disposal of the hazardous sub- stance and contaminated cleanup materials, including date of disposal - The solidified oil and snow were placed in the burn pit and was incinerated on verbal approval by Doug Lowrey of the Alaska Department of Environmental Conservation on November 1, 1977. 9. Actions taken to prevent recurrence of the discharge - The flare line will be ignited prior to production testing. 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 HED:cl Form ~o. STATE Oi' ALASKA OIL AND GAS CONSERVATION COMMII-I'EE AND WORKOVfR OPEP. AT~OHS SUB,WIlY ADL 47560 ~ 6~s Exxon Corporation Point Thomson Un~it 3 ADD.SS OF OPhiR g WE~ %'0 Pouch 6601, Anchorage, Alaska 99502 4 LOCATION (>F WF_J_J. 1,320' NSL & 660' WEL of Sec. 32, TION, R23E, UPM North Slope, Alaska FiF. Z~) A~;D POOL. Ol{ Wildcat ~ ' o~~) ~ ." Sec. 32, TION, ~23E' 76-85 13. R]F~O~T TOTAL DE2:>'i~-~I AT L*qD OF ~{[ON~'i/{_, CHP~"~G~3 IN HOLE SIZE. CASING AND C~[?~T!NC; JOBS INCLUDING DEPTH SET ~N~ VOLU~ US~. P~OP~TIONS, ~STS g~TD ~SUL~ FISHING JO~ JLWK IN HOLE AND SIDE-~.AC~ED HOLE ~N-D ~%'Y O~ SIGNIFIC~T ~$G~ ~ HO~ CO~ITIONS The-month started by attempting to complete the open hole logging program~. We cou.ld not get the Formation Density-Compensated Neutron below 12,318'. The Dipmeter would only go to 13,069' and it was logged to the 7" casing shoe. Cores were then cut from 13,069' to 13,163' and hole was drilled from 13,163' to 13,298', which is the final total depth for the well. Cored intervals are as follows' Core #10' 13,069' - 13,128'; Core #11- 13,128' - 13,158'; and Core #12- 13,158' - 13,163'. While circulating for open hole logs at 13,298', the jars in the drill string parted leaving a fish in the hole which was recovered on the first fishing attempt. After recovering the fish, hole conditions developed that caused us to wash and ream the open hole section for 12 days from 11,396' to 13,160'. At 13,160' the bit fell free and the hole was washed to 13,298'. Attempted to run a sonic log and could not get the tool below 12,510'. Because of hole conditions additional attempts to obtain open hole logs were not tried. A 4½" liner set from 10,873' to 13,295', was cemented with 317 sacks of class G cement with 1% CFR2 plus .75% HA9 and displaced with 189.5 barrels of 15.4 ppg mud. Bumped plug with 2,900 psi at 2018 hours, September 28, 1977. At the end of the month we are nippling up and WOC. L;ONFIDENTIAL .. /:,; t, 'i ;: l.' ,' ', .~~y~~/~__=~~~ _~xPloration Bept. n~ _ October 14., ~,7 SIG~ DEPAR~NT CF ~ ~ Division of Oil and C~s Conservation The Files 12, 1977 Acting Chief Pet~e~m Eng/neer Exx~' s Point Tbxx~oson ~. 1 Oil Spill Bec~ conversation ~ Imnnie C. Smith (LCS) and Jerry Argile, Exxon engineer, who was reporting an oil spill which occurred c~ 10/11/77 at the Point T~pscn No. 1 w~ll: parked it right beside the fuel pit, and were pumping frcm the Catco tank into our tanks in the fuel pit. And th~ ~i~ c~ the disdmarge line or the transfer line parted on us and w~ pumped approx/mately 2,000 g~ of fuel into the impea~zeable Lined pit. We discovered the leak and shut down. So it parted while you w~re PimPing and you didn't know it? diesel that was con~ inside the pit back into the rollogcn tank and we ~ about 2,000 gallons, that's what we're saying our spill volume was, about 2,000 gallc~s. And then we mopped it all up with 3-M absorbent material. this is still insid~ the berm? Yes, ~ is ~ll insid~ the belm. pit ~a. Mc~ it up with ab~t material manufactured by 3-M manufacturing ~y and ~ we got it all cleaned up, we've got these in barrels and as soon as ~ ~ ~ ~ssic~, ,~' 11 incinerate the absoxSent material. But as soon as we got ~he spill all cleaned up, then we transferred back cut of ~ rollogc~ tank that w~ had put the spilled Then ~ put all this rec~ fuel in no. 9 tank so it w~uld be separate. If ~ w~s any water in it we could let it settle cut. Th/~ ~'11 be able to use it or will you have to dispose of it? Oh, I ~'t ~ we're going to have any trouble. We'll just use it. Since it was all inside, all of ~_he spillage occurred inside the ~ pit, none of it got off the pad. -2- October 12, 1977 You ~'t ~ ~ indication of leakage? ~ that we~ ~. ~se ~ was a little bit of ice in ~ too, ~ so w~ ~uld have that acting, as an ' _m~le area as well, it ~ ~ide ~he ~ pit and we cleaned it all up. It took us ~ 3 to 3 1~ ~ to get it all cleaned up before we could finish with tb~ transfer opera~ ~ to the no. 9 pit. It'll cost you a lot, it's a lot of probl~, but your redundant system worked, I mean, your safet~ impexE~m~ble lined pit functic~ed just exactly the way its ~pposed to, so it's a good deal. How long do .y~a ~ it ~ ~ pump out that 2,000 g~ before 1:307 Hc~ long. did it go under? That's ~ thing that bothers ~.~. That's ~ th/r~ I'll j~ ~ to conf~ here, is what transfer rate ~ wex~ shipping that to, ~ can .get the vol~, if we can get the rate, ~ w~ ~ g~t... It might not ha~ been very long.. I ~'t feel tb~t it was too long. We've inf~ the DEC and nc~ we're infozming ~. ~ ~ no ~t of the spill, . . (repeat) It ~ the llth ~ 13:30 hours. E ON COMPANY. U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION October 18, 1977 Alaska Department of Natural Resources Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Attn: Mr. Lonnie Smith Dear Mr. Smith: This letter is written confirmation of Exxon's notification to your agency by Mr. G. L. Argall oil spill that occurred on th~.~6~'""~¥'~"'~"'~i~'~'~¥~% Thomson Unit.i drill site location at approxi~"%-e'l~3~'~30"']~'~'~'~"~-'~..... ~'6'~ober 11,-' 1977. Below are pertinent facts regarding this incident 1. Date and time of discharge - October 11, 1977 at 1330 hours. · Location of the discharge - Latitude 70010'26.95'' N, Longitude 146°20'14.62'' W or on the Exxon No. 1 Point Thomson Unit well drill site location. · Person or persons causing or responsible for the discharge - CATCO personnel were operating the fuel transfer equipment. At the time of the spill the fuel transfer operation was not being attended because the CATCO personnel had gone to lunch for 20 minutes in the drill site living quarters. · · Type(s) and amount(s) of hazardous substance(s) discharged - Arctic grade diesel fuel, approximately 2000 gallons. Cause of the discharge - CATCO discharge hose from CATCO tank extending to steel fuel tank No. 4 came out of the top of the No. 4 tank while transferring fuel. · Environmental damage caused by the discharge, to the extent ascertainable - No environmental damage is apparent or has been detected. All spilled fluid was contained in the plastic membrane lined fuel pit. RECEIVED Alaska Department of Natural Resources Division of Oil & Gas October 18, 1977 Page 2 e Cleanup actions undertaken - Spilled fluid was pumped into the CATCO tank and then transferred to the No. 9 steel fuel tank using the CATCO fuel transfer equipment. Residual fluid was mopped up with 3M type 100 absorbent material; no other equipment or materials necessary. · Location and method of ultimate disposal of the hazardous substance and contaminated cleanup materials, including date of disposal - All useable recovered fluid will be retained for use on location. All used absorbent material was placed in barrels, transferred to the incinerator site and incinerated on October 13, 1977 upon verbal approval by Mr. Brossia of the Alaska Department of Environmental Conservation. · Actions taken to prevent recurrence of the discharge - All equipment and piping will be carefully inspected prior to commencement of transfer operations and all future fuel transfer operations will be attended by Exxon personnel while in progress. 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 GLA:jrh Form No. P--4 STATE C ',LASKA OIL AND GAS CONSERVATION COMMII-fEE ,, SUBMFT LN DU?LICATE j~.AONTHLY R~PORT OF DRILLING AND ~¥ORI,(OV/;R OPF. RATJOH5 o,~ ~ ,;,,, [] o,,~., Wildcat 2. NAoMi- OF OP~TOR Exxon Corporation Pouch 660], Anchorage, Alaska 4 LOCATION OF WELL 1,320' NSL & 660' WEL of Sec. North Slope, Alaska 99502 32, TION, R23E, UPM AP[ I,;U.~.iEI~.IC.-EL (':ODE 50-089-20005 I.EA$~ :~E$ZG~ZA?ION AXD SERIAL NO ADL 47560 T Il:' INDi;'.I'T ALOTiZE OR ':RIBE t'JAJ4E Point Thomson Unit 9 WELJ~ NO Exxon No. 1 10 F£F. LD AND PC~)lo. OR XViLDCA. T Wildcat 1~ S~C . T.. iR.. 5I (LUDTTGM ]-t. OL.~~ - Eec. 32, liOn, R23E 12 PILLR~MIT I~'0 76-85 13.i~ORT TOTAL DEI:~'H AT F~ND OF MON*~'H. C~3~NG]~.~ IN HOLE SIZE. CAGING AN~ C~,I~N r~NG JO~S INCLUDING DE~H SET ~N~ VOL~ US~. p~OP~TIONS. ~S~S ~%~ ~SUL~ F~HIN'G JO~ JL~K L~ HC)~ AND SIDE-~C~ HO~ ~D ~Y O~R SIGNIFIC~T ~iG~ ~ HO~ ~iTIONS On August 1, 1977~ a pressure i'ntegrity test was run t© 18.5 Ppg EMW. 'Hole was .then drilled and cored to 13,069' Cored intervals are as follows: core #2 11,420' to 11,455'; core #3 11,45~' to 11,492'; core #4 12,052' to 12,086'; core #5 12,158' to 12,166'; core #6 12,830' to 12,890'; core #712,890' .to 12,950'; core #8 12,950' to 13,009'; and core #9 13,009' to 13,069'. Schlumberger Dual Induction and Sonic logs were run at the current total depth of 13,069'. On August 31, 1977, mud is being circulated and conditioned prior to running the CNL-FDC log and Dipmeter. CONFIDENTIAL , he,-m-by ~ify %t%a1 the ,oregOing iat~e&nd co~.'~Assi.'Mgr. Off~hor6/A-~.Div. s~o~.:~~~ ~~~ ~ Explo.r.a~ion~Dept ...... ~ ~ep~ember 8, .1977 NOTE --Report on this form t3 required for each cal~ndar ~nth% regordles9 at the ~totu~ nf omarations, and must ~ filed In duplicqt.e wilh the oil end gas conatrvot;on commlH,e by th~ 15~ of Ihs ~uc~ding mn,~. unle~ etharwi~s d~rac~ed. STATE of AI.A~KA DEPARTMENT OF NATURAL RESOURCES Division of Oil and Gas Conservation TO.. TO FI LES FROM: Russell A. Douglass Petroleum Engineer DATE : Au§ust 23, 1977 SUBJECT.. Diesel Spill Pt. Thompson North S lope On Saturday, August 20, 1977, I received a phone call from Mrs. Homer. Mr. Homer works for Exxon and reported to me a diesel fuel spill that occurred at their Pt. Thompson facilities late Friday night. ^ Crc~,iley barge was unloading diesel fuel into the Exxon pi~line located at Pt, Thompson. A leak developed in the floating hose and approximately ten gallons of diesel fuel was spilled into the water. The spill was contained and cleaned up with sorbent pads within 30 minutes and the floating hose w~ repaired. Beach inspections on Saturday shc~ed no trace of diesel fuel for 3 mi les up or down tile coast from the point of the spill. Mr. Homer indicated he had cc,~tacted the Coast Guard and the EPA. I told him we ap- preciated the information and felt the actions taken by the personnel involved had been adequate to prevent any possible environmental damage. :.'qAD:hgh l~o,--m N'o. P--4 1R.L'*V. ~,~ I- ?0 STATE O. ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DL'PLICAT~ /V~ONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1, ! ~ Wildcat 0IL ~ GA{{ ' · ;'~;LL ~ ~" ~;LL ~ OTI~ Eli 2. NAME OF OPKP,.ATOR Exxon Corporation 3. ADDRESS OF OPKRATOR Pouch 6601, Anchorage, Ak 99502 4 LOCATION OF WELL 1320' NSL & 660' WEL of Sec 32, T]0N, R23E, OPM North Slope, Alaska -:uUNklUkNII L 5 APl .NUMERICAL CODE 50-089-20005 I.F.A$1/; DES:GNATION AND SENIAL NO ADL 47560 I1:' I:JDiA}I' AkA)/'FEE. OR TRIBE NAME 8 UNIT F.a,.R~I OR i.E..\tcE NAME Point Thomson Unit 9 WELL NO Exxon No. 1 Io FI};LD ,X_ND PCkqI, OR Wii.DC.~.T Wi 1 dcat l-, S~C T. R .M (BOT~,OM HC)LE Sec 32, T10N, R23E 12 PIq~.MIT NO 76-85 13.REPORT TOTAL DE:Pi'i~I AT F_2qD OF MC)N,'i'H. CH.a~.NGF. S IN HOLESIZE. CASING AND C~'IENT!NG JOBS I?<CLUDING DEPTH SET AN~ VOLU3~ USED P~OP, ATIONS. ~STS .~N~ ~SUL~ FISHING JO~ JLZqK LN HOLE AND SIDE-~.ACKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~N~ITIONS Operations for July consisted of washing over 3 1/2" drill pipe and an RTTS tool which was cemented in place while attempting to squeeze cement around the 7" casing shoe. On July 28, 1977 top of packer was found at 10,670' and was milled over to 10,678'. All of the packer was recovered on July 30, 1977. At the end of the month we are at 10,517' going in the hole with a bit. All the fish has been recovered and plans are to drill ahead after cleaning out to the current total depth of 11,416'. i, ,i -;4 · / ~ ~=~,= ~, ,,. ,o=~o,=, ,, ,~-~ ~ ~ Assr .Jqgr' 0ftsn'6re/Ak .u~ v. smm~~~n~ [xploration Dept. ,yin ~u~ust 16, 1977 NOTE ~Report on this form ii required for each calendar ~nth& regardless of the status of adorations, and musf ~ filed In duplicate with the oil and gas conservation commiHee byfhe 15~ of Ih~ succ~ding ~nth, ~le~ otherwise directed. CONFI , N/IAi r~nn ~o P---4 ]L,~'v'. 3-1-70 STATE, .,A,SKA OIL AND GAS CONSERVATION COMMITFEE SUBMFr 12q' DL.'PLICAT~ MONTHLY REPORT OF DRILLING AND waR,cOVER OPERATIONS o,, ~ o,. [--] o,,- Wildcat WKLL WZLL ,. NA_MF-OF OPF/~ATOR Exxon Corporation ADD.tESS OF OPKP..ATOR Pouch 6601, Anchorage, AK .99502 4 LOCATION OF'WF2.~ 1320' NSL & 660' WEL of Sec. 32, TION, R23E, UPM North Slope, Alaska o .'~~'I I']U:',IERtCAL C'OI)E 50-089-20005 ": I,EASE DES:G;"I.%TION AND SERIAL NO · . ADL 47560 L-NIT I:'AP~,! O.q LEASE NAME Point Thomson Unit WEL2. N.D Exxon No. 1 FI/LO AND PCK)L. O'q WiI,T)CAT Wildcat 1: S-2C T.. 1l .M {BOTT, O.~I HOI-~ Sec. 32, T10N, R23E P ------------------~\ "11T NO 76-85 13.REPORT TOTAL DEl:vi'lq AT F_,ND OF ,~.:oN'r'H. CHA_XGF, S IN HOLESIZE. CA~ING AND CF_%I~N~NG ,IOB~ INCLUDING DEPTH SET ~%~ VOLb%'~ US~. P~ORATIO~S. ~STS ~_N~ ~SULTS FISHING jO~ JL~K LN HOLE AND SIDE-iRACK~ llOLE ~ND ~Y 0~ SIGNIFIC~T ~'G~ IN HO~ CONDITIONS On June 1, 1977 ran the following surveys: Density - Compensated Neutron, Velocity Survey, Dipmeter, Long Spaced Sonic, and Sidewall.cores, shot 60 and recovered 50. Mudweight was 15.6 ppg. 7" csg was set at 11,390' with top at 9,032. The liner was cemented with 560 sx C1 G, with 1% CFR-2 and.4% HR-7. Cement was Tagged at 8,510' and drilled to top of liner at 9,032'. Tested liner top with 2500 psi for 15 min. OK. Tripped in hole to 11,307' and tested liner to 2500 psi. OK. Drld to 11,407' and ran leak off test to 18.3 ppg. Set RTTS tool at 10,667' and squeezed'shoe with 120 sx then 240 sx C1G cmt with 1% CFR-2 and .4% HR-7. Attempted to unseat RTTS tool but would not release. Ran string shot and backed off drill pipe at 10,101'. Washed over 3½" drill pipe to 10,338'. POH Recovered 8 jts of drill pipe. On June 30, 1977 top of fish is at 10,338'. Washed over fish to 10,377'. Fish appears to be cemented in place from 10,336'. Mud weight .was increased to 17.0 ppg during the month. . CONFIOENT!AL ,4 , h,~, ~,,,.,.~u~,. ~o,.,,,,o,,,~.~,~,,~,a~,'~ Asst. Mgr. Offshore/AK Div. s,,~_~,~4~.~. ~ _Exploration Department ,,,~ dul.v 5, 1977 _ NOTE--ReDoFI on lhJ~ fo~ il required for tach calendar ~nth$ regardless of tho atotu3 nf op,rafie.~s, and must ~ filed In duplkate ~Jfh the oil and g.o~ conaervotlon commlHee byfhe 15~ of Ihe ~ucc~ding mon~.unta~ Otherwila directed. oIL AND GAS CONSERVATION COMMII%EE 5~0-089-20005 ~ONTHLY R~PORT' OF DRILLING ADL 47560 o,: ~ ~,, ~ o,,,, Wildcat . ~s~:"6r 6~TOa .......... ' ' --- S. :'~:T F.~ Oh ::AS': ~.~M~ -- I : 'S:;:':L J' "[ Exxon Corporation Point Thomson Uni~-~'~ ,, ~,, Pouch 6601, Anchorage, AK 99502 Exxon No. 1 '~i: s~c. T.. R/. k:. (~O~< ~o~NF:;~:' ........ I320' NSL & 660' NEL of Sec. 32, T10N, R23E, UPH o~~ North Slope, Alaska Sec. 32, T10N, R2~3~::: 76-85 ,,,, , ,, , , ,,, , , ~ , 13. RF~ORT TOTAL DKPTlq AT ]SND OF MON,'i"~L C}{A_\'GF.S IN HOLE SIZE. ~ SET A3,,q:) VOLI/I%TE~ USED. pF_ff~F'OP. ATIONS. ~'I-~"~S75 .A.I~'-D RESULTS F~$HING JOB.~3 JL~"'~K L~ HOLE AND SIDE-T'RACKE'D HOLE 'A~%'D ~.~Y OTTH]SF~ SIONIFICAA~;T CH.A/WGF_.S IN HOL~ CObl-DITIONS On 5-1-77, drilled out of 9-5/8" casing with an 8½" bit. At a drill depth of~, a pressure integrity test was performed. Leak off occurred at 18.7 ppg EMW (equivalent mud weight). After drilling to 9871' another pressure integrity test was performed to 21.0 ppg EMW and no leak off occurred. Core #1 from 10,720' to 10,780' recovered 60'. At 11,400' returns were lost while circulating bottoms up prior to a trip out of the hole. A temperature survey indicated fluid going out between 10,000' and 10,250'. After regaining circulation open hole logging was started and the following surveys have been completed' Dual Induction Borehole Compensated Sonic Formation Density - Compensated Neutron At the end of the month preparations are being made to run the velocity survey and the drill depth of the well is 11,400'. During the month mud weights were increased from 10.5 ppg to 16.5 ppg. ~ .~.~ :~m~ ~ ~h~ :o~o~-~ = ~ ~ ~ Asst. Mgr. Offshore/AK Di v ~ ~~ ~~~~ ~,._~ _,~ ~_ ~ ......... ~ ~ June 15, 1977 BIG ill I Jl,, I I NOTE --Report on this form is requ,red for each calendar ~nth% regordlels of th~ status of o~erotie.s, and must ~ flied in duplicate with the oil Grid COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION Mr. John Miller State of Alaska Department of Natural Resources Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, A1 aska 99501 Dear John' Instead of using this letter which was directed to your office as discussed with you and filing it with DMEM, we wrote a further letter, a copy of which is attached, which letter states what we propose to do and why we require permission to do it. The original letter of May 13 is returned to you for your file or for destruction as you see fit. Robert K. Riddle RKR: j h A DIVISION Of EXXON CORPORATION 02-001B STATE of ALASKA Division of Oil and C~ns Conservation TO: [-- Pete ~lsc~ Lar~ ~-~qna~t Officer III FROMm: Lclo~e C. Smith ~'~/~/' ~' Chief Petroleum Eng~ DATE : [~y 18, 1°~77 SUBJECT: LO~S 76-109, ADL 47560 Exxon-Point ~ ~. 1, ~.brth Slope And_nd Plan of Operations By f_he attached letter ~'has applied for an arenclTent to the Plan of O~_ratic~s for the captioned well. ~ a~lclTent %~uld pemmit the .operator to inject oil into pcrc~ salt wa~_r sands between 3276' and 6900' in ~cy situations ar~ to prevent possible pit .~pillag. e cnto the tundra. In this partied]hr case we attarove of the ~-ent as a practical alternate to burning oil in a pit. Attac~ 1~ Ilo, P..-4 R~'V. 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT 12~ 13UPLICATE o,,. ~ ~" []] o~,,, Wildcat w~:LL · i~. o~ 6~ro~ ' ' Exxon Corporation XD~hZss oF oP~O~ Pouch 660], Anchorage, Ak 99502 lOCATION 1320' North OF W~Lt- NSL & 660' WEL of Sec. 32, TlON,R23E, UPM, Slope, Alaska ' AP1 NU~,{EI:~ICAL CODE 50-089-200O5 6 L~$E DE$iG~A~ON AND SEHIAL NO ADL 47560 IF INDIA~. ALOTTEE O~ TRIBE 8. L.~IT Fb~,,~M OR LEASE N.~ME Point Thomson Unit g wEt.r. NO Exxon No. 1 10. FI~T~? ~ND POOL. OH WILDCAT Wildcat I1 SEC.. T., R., .M.. (BOTTOM HOLE o B,r~ r~F_~ Sec. 32, TlON,R23E 12 PKRMIT NO. 76-85 13, REPOR~ TO~AL D~iPTH' AT END OF MONTH, CI-IA. NGES IN HOLE SIZE, CASING AND CE.~IENTING JOBS INCLUDING DEPTH SET A..N'D VOLU'M'ES USED. PERFOHATIONS. TESTS A,N'D t:~ESULTS FISHING JOl~. JU-NK L~I HOI.,E A. ND SIDE-T~ACKED HOLE A.I~D ANY OTI-IEi~ SIGNIFICANT CH_ANGE~ IN HOLI/: CONDITIONS. Drilled cement inside 13 3/8" csg from 3172' to 3180'. After failing to hold pressure at the 13 3/8" csg shoe, it was squeeze cemented with 200 sacks of class G neat cement. New hole was drilled from 3295' to 3328' using a 12 1/4" bit. At 3328' a pressure integrity test was performed and leak off occurred at i4.9 ppg equivalent mud weight. A 12 1/4" hole was drilled to a total depth of 9533' and the following open hole surveys were run: Dual Induction F.ormation Density - Compensated Neutron BHC Sonic Long Spaced Sonic Di pmeter In addition, lO1 sidewall cores were attempted with 90 being recovered. Set 9 5/8" csg at 9532' and cemented with 1300 sx class G cement (15.8 ppg). A temperature survey indicated the top of cement at 6900'. Injectivity into the interval from 3276' (base 13 3/8" csg) to 6900' was established by pumping water down the 13 3/8" x 9 5/8" casing annulus. Maximum injection rate was 8 BPM at 1520 psi. At the end of the month the drill depth of the well was 9533' and an 8 1/2" bit was being run in the hole to drill cement inside the 9 5/8" csg. RECEIVED 1 L; !977 ~,. ,'h,~4~ ~,, ~' t~; i;,,,'~m~ ~,',~; ~'-~ Asst. Mgr.'OffShor6/A'k. Div. s~a~_~~/Z ~~.-~ :~ Expl.oration Department_ ~ May 17~ !977 ........ . I ' i . I __ ii i jljl_] . i. .i ii . i'rl i -. · i ' . _, , .. ...... _ . , ,, .. i lit "- NOTE--Report on this fo~ is requited for each calendar ~tht regardless of the status of operations, end must ~ filed In duplicate with oil and gas conservation commlflee by the 15~ of the succ~ding ~n~. unless otherwime directed. ,. E)F ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION C. A. TUCKER ASSISTANT MANAGER-ALASKA-ANCHORAGE May 17, 1977 State of Alaska Department of Natural Resources Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. Thomas R. Marshall, Jr. Dear Mr. Marshall- Enclosed are three copies of Form 10-403, "Sundry Notices and Reports on Wells" being submitted for our Point Thomson Unit, Exxon No. 1 location. Very truly yours, Carl A. Tucker JLG:jrh Encl os ure CONFIDENTIAL -:~ :, "fT]:_7:,TjT'.E.L.:;7'..,..-'.~ ............ A DIVISION OF EXXON CORPORATION E (,ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION C A TUCKER ASSISTANT MANAGER-ALASKA-ANCHORAGE State of Alaska Department of Natural Resources Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. Thomas R. Marshall, Jr. '"3 i .......... ..., _ ~;?:.' 4:' Dear Mr. Marshall: · 4~1; I,..,! ": ~i'.'! Enclosed are three copies of Form 10-403, "Sundry Notices and Reports ,on Wells" being submitted for our Pt. Thomson Unit, Exxon No. 1 location. At this time, we wish to amend the Plan of Operations submitted with our Permit to Drill or Deepen on November 1, 1976. The original Plan of Operations was submitted with the intent of subsurface injection and disposal of waste water into the salt water sands projected to occur below the shoe of the surface casing set at 3,300' and the top of the 9-5/8" casing cement at approximately 6,000'. The 13-3/8" surface casing was cemented at 3,276' and the top of the 9-5/8" casing cement was located at 6,900'. We wish to amend the Plan of Operations to include the subsurface disposal of oil in addition to waste water under certain conditions. The injection of oil would occur only under an emergency situation, such as, for example, when a well is out of control or a kick is circulated to the surface. Another possible situation would be the accumulation of a sufficient volume of oil and water at the surface such that runoff into the tundra from the drilling location was anticipated. Your approval of our amended plan is requested. It is our opinion that this plan is necessary 'to prevent possib].o po].].ut~on of the surface environment under certain remote, but nevertheless possible, conditions. Very truly yours, Car]. A. Tucker JLG:djb File 295-600-110 (A-20) A DIVISION OF EXXON CORPORATION Attachments E .ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION C. A. TUCKER ASSISTANT MANAGER-ALASKA-ANCHORAGE State of Alaska Department of Natural Resources Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. Thomas R. Marshall, Jr. May 13, 1977 Dear Mr. Marshall: Enclosed are three copies of Form 10-403, "Sundry Notices and Reports on Wells" being submitted for our Pt. Thomson Unit, Exxon No. 1 location. At this time, we wish to amend the Plan of Operations submitted with our Permit to Drill or Deepen on November 1, 1976. The original Plan of Operations was submitted with the intent of subsurface injection and disposal of waste water into the salt water sands projected to occur below the shoe of the surface casing set at 3,300' and the top of the 9-5/8" casing cement at approximately 6,000'. The 13-3/8" surface casing was cemented at 3,276' and the top of the 9-5/8" casing cement was located at 6,900'. We wish to amend the Plan of Operations to include the subsurface disposal of oil in addition to waste water under certain conditions. The injection of oil would occur only under an emergency situation, such as, for example, when a well is out of control or a kick is circulated to the surface. Another possible situation would be the accumulation of a sufficient volume of oil and water at the surface such that runoff into the tundra from the drilling location was anticipated. Your approval of our amended plan is requested. It is our opinion that this plan is necessary to prevent possible pollution of the surface environment under certain remote, but nevertheless possible, conditions. Very truly yours, Carl A. Tucker JLG:djb File 295-600-110 (A-20) A DIVISION OF EXXON CORPORATION Attachments Form 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) " v~LE]WELcGAS E] OTHER Wildcat 2. NAME OF OPERATOR Exxon Corporation 3. ADDRESS OF OPERATOR P. O. Box 2180~ Houston~ 4. LOCATION OF WELL ~ At SUrface Texas 77001 1,320' NSL and 660' WEL of Section 32, TION, R23E, UPM, North Slope, Alaska 13. ELEVATIONS (Show whether DF, RT, GR, etc.) Approximately 11' GL Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-089-20005 6. LEASE DESIGNATION AND SERIAL NO. ADL 47560 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME P0int Thomson Unit 9. WELL NO. Exxon No. 1 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 32, T10N, R23E 12. PERMIT NO. 76-85 3orr, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF= TEST WATER 5HUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS 15. DESCRIBE WATER SHUT-OFF ~ REPAI RING 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.) PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated dat~ of starting any proposed work. Sub surface Injection: The Permit to Drill or Deepen was approved with the plan for subsurface injection and disposal of waste water into salt waker sands projected to occur between the surface casing shoe at 3,300' and top of 9-5/8" cement at approximately 6,000'. The 13-3/8" surface casing was cemented at 3,276' on 3/26/77. The 9-5/8" casing string was cemented at 9,532' and injection established on 4/26/77. A temperature log was run on 4/27/77 and showed the cement top at 6,900'. It is proposed to amend the plan of operation to include injection of oil in addition to waste water into the sands below the surface casing shoe. Injection of oil would be carried out only under emergency conditions, such as a well control problem or a situation where run-off of oil into the tundra at surface w~ls~j~rktj,c~i~a~.ted. 16. I hereby certify that the foregoing is true and correct h ~,~h~,,,- Asst. Mgr., Arch., AK Exp. Dept., Offshore/AK (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY.' TITLE DATE See Instructions On Reverse Side 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.) 1. ~/~LLLDWELLGAS D OTHER Wildcat 2. NAME OF OPERATOR Exxon Corporation APl NUMERICAL CODE 50-089-20005 LEASE DESIGNATION ANO SERIAL NO. ADL 47560 7. IF INDIAN, ALLOTTEE OR TRIBE NAME NA 8. UNIT, FARM OR LEASE NAME Point Thomson Unit 3. ADDRESS OF OPERATOR P.O. Box 2180, Houston, Texas 77001 4. LOCATION OF WELL At surface 1320' NSL and 660' WEL of Sec. 32, T1ON, R23E, UPM North Slope, Alaska 13. ELEVATIONS (Show whether DF, RT, GR, etc.) Approximately ll ' GL 14. Check Appropriate Box To Indicate Nature of Notice, Re 9. WELL NO. Exxon No. 1 ;10. FIELD AND POOL, OR WILDCAT Wi 1 dcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 32 T10N, R23E 12. PERMIT NO. 76-85 3orr, 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 state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. The original Permit to Drill or Deepen (Form lO-401) was submitted with the following planned casing setting depths: 9-5/8" casing at 9,000' +, 7" liner at 11,000' +, and 4-1/2" liner at 14,0'00'. A Form 10-403 was submitted on April 21, 1977 notifying intention to set 9-5/8" casing at approximately 9533'. On April 27, 1977, the 9-5/8" casing was cemented in place at 9532'. Leakoff tests were conducted at 9553' and 9871'. Leak°ff occurred at 18.7 ppg and 21.6+ ppg equivalent mud weight at the two respective depths. Request is made with this notice to extend the setting depth of the next string of 7" casing down to approximately 14,000' or shallower. A full string of 7" casing to surface may be set, or a 7" liner set and tied back to surface. CONFIDENTIAL · 16. I hereby certify that the foregoing is true and correct Asst. Mgr. Anch., AK Fxpl. DePt. Offshore/AK Di~YmTE ADril 21, 1977 (This space for State office use) ~ CONDITIONS OF R~'I~ROMAL, IF ANY: .. r DATE See Instructions On Reverse Side Approved Copy Retumed COMPANY. U.&A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION C A TUCKER ASSIS,"ANT MANAGER-ALASKA-ANCHORAGE May 13, 1977 Re: LO/NS 76-109 A 77-58 EXXON No. I - Point Thomson Unit Mrs. Ethel H. Nelson Land Management Officer Division of Minerals and Energy Management 323 East 4th Avenue Anchorage, Alaska 99501 Dear Mrs. Nelson: Filed concurrently with the subject plan of operations submitted to Mr. O.K. Gilbreth on November 2, 1976, was a copy of Exxon's application of even date for a Permit To Drill, Form 10-401 which contained a provision for subsurface ' injection and disposal of waste water into the salt watgr sands below the shoe of the surface casing and the top of the 9-5/8" casing~'%'~'~h surface casing has subsequently been cemented at 3276'-and the top of the 9-5/8" casing cement located at 6,900', each with proper notification to and approval from the state. Concurrently with the filing of each of said applications, we also filed with the Department of Environmental Conservation an application for an Air Quality Control Permit To Open Burn flammable materials produced during drill stem tests conducted in the course of the subject drilling operation. On January 18, 1977, the requested permit was issued to Exxon by said department. It continues to be Exxon's intent and plan to dispose of any hydrocarbons recovered during drill stem tests precisely in the manner provided for in the said air quality control permit. We recognize, however, that in an emergency situation, such as when the well may be out of control or a kick is circulated to the surface, a further means of disposal in addition to that presently provided may be required in order to prevent a possible runoff of hydrocarbons and resultant pollution of the surface environment. Accordingly, we are with this letter requesting an amendment of said plan of opera- tions to include in addition to was'~water disposal as presently permitted, the subsurface disposal of test hydrocarbons in the event of the occurrence of such an emergency as above noted. As this request modifies the provisions contained in said Permit To Drill, Form 10-401, a Sundry Notice, Form 10-403 has been filed with the Division of Oil and Gas Conservation concurrently with this application which notice contains all necessary particulars with respect to this request. A DIVISION OF' EXXON CORPORATION r Mrs. Ethel H. Nelson L2- May 13, 1977 Additional copies of this request are submitted herewith to facilitate circulation as you may determine to be necessary, however, no further transmission has been made of this request by this office except to the Division of Oil and Gas Conservation as noted. If further material of any nature is required to facili- tate your consideration of this request, please advise and every effort will be made to provide it. Very truly yours, Carl A. Tucker Assistant Manager RKR- CAT: el c Enclosures E ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION C. A. TUCKER ASSISTANT MANAGER-ALASKA-ANCHORAGE CONFIDEN April 21, 1977 State of Alaska Department of Natural Resources Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. Thomas R. Marshall, Jr. Dear Mr. Marshall: "Sundry Notices and Enclosed are three copies of Form 10-403, Reports on Wells" being submitted for our Point Thomson Unit, Exxon No. 1 location. Very truly yours, Carl A. Tucker JLG:jrh Enclosures File 295-600-110 (A20) A DIVISION OF EXXON CORPORATION Form 10-403 REV. 1;10-73 Submit "Intentions" in Trlpllcate & "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,) WELLL-J OTHER Wi ldcat 2. NAME OF OPERATOR Exxon Corporation 3. ADDRESS OF OPERATOR P.O. Box 2180, Houston, Texas 77001 APl NUMERICAL CODE 50-089-20005 6. LEASE DESIGNATION ANDSERIAL NO. ADL 47560 7. IF INDIAN, ALLOTTEE OR TRIBE NAME NA 8. UNIT, FARM OR LEASE NAME Point Thomson Unit WELL NO. Exxon No. 1 4. LOCATION OF WELL At surface 1320' NSL & 660' WEL of Sec. 32, T10N, R23E, UPM North Slope, Alaska 13. ELEVATIONS (Show whether DF, RT, GR0 etc,) Approximately Il' GL Check Appropriate Box To Indicate m~ture of Notice, Re 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 32, T10N, R23E 12. PERMIT NO. 76-85 3oft, or Other Data NOTICE OF INTENTION TO; TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF [~ REPAIRING WELL FRACTURE TREATMENTM ALTERING CASING SNOOTING OR ACIDIZING ABANDONMENT* (Other) .... (NOTE,' Report results of multiple completion on Well Completion or Recompletion Report and Rog form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. · 2 A proposal to set 9-5/8" 40#/Ft S00-95 casing at 9800' _+ was approved verbally by Mr. John Miller on 4-15-77 and 4-19-77. A 12-14" hole was drilled to 9533' reaching TD at 12'30 PM on 4-20-77. It is planned to set 9-5/8" casing at approximately 9533'. Request was made to delete HOWC0 F.O. cementers in 9-5/8 casing string at 2000' and 2500'. Purpose was to eliminate potential source of leakage into 9-5/8" casing while injecting waste water down 9-5/8" x 13-3/8" annulus. This matter was discussed in telephone conversation with Mr. Miller on 4-15-77, and in meeting'with Messrs. Miller and Smith, and Mr. Glaeser of Exxon on 4-18-77. Plan was presented to displace salt water in 9-5/8" x 13-3/8" annulus on aban- donment with lightweight Arctic Casing Pack. Verbal approval was received from Mr. Miller on 4-19-77. 16. I hereby certify that the foregoing Is true and correct Asst. Hgr. Anch., AK TITLE Exp. D.ept, Offshore/AK.DiV~ATE April 21.. lq77 (This space for State~:~.ffice,//use) DITION50F[~PROVAL, IF A~Y: ,- : . TITLE ..... , ....... DATE ..... R IRFNTIA/ . , ~e Instructions On Reveme Side Form No. P--4 ~, 5- I-?0 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS o,L [] o,. [], oT.,, Wildcat 2. NAME OF OP]~:~ATOR Exxon Corporation 3. ADS'ESS OF O~ATOR Pouch 6601, Anchorage, Ak 99502 4. LOCATION OF WELL ]320' NSL & 660' WEL of Sec. 32, T]0N, R23E, UPM North Slope, Alaska SUBMrr ~ DUPLICATE A!~! HUA~[ERICAL CODE 50-089-20005 LEASE DESIGNATION A.'\'D SEIqI, ADL 47560 IF I'NDIA~ ALX3'I lEE O~ TRIBE UNIT FA~{ OR LEASE NAME PoSnt lhomson ~n5 WE~ NO Exxon No. ] 10 F1FJ. D AND P~h, OR WIi. Wildcat. -- sec T.. ~.. ~ mo~o~ -~': ~ O~~ Sec. 32, TION, R23E 12 PERMIT NO 76-85 13. REPORT TOTAL DKPTH AT F_~ID OF MONTH. CHA~NGF_~S IN HOLE SIZE, CASING A~ CHF~TING JOBS INCLUDING DEPTH SET ~ VOL~ USD. P~O~TIONS. ~TS A~ R~SULTS FISHING JO~S JL~¢K LN HO~ AND SIDE-T~ACKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS Spudded 7:30 p.m. 3-6-77 w/17 ½" bit. Drilled to 828' and ran dual induction log. Opened hole from 17 ½ to 24" to 828.'___, Set 18 5/8" csg at 801' and cemented with 250 sx permafrost (14.3 ppg) and'4500Sx permafrost (15 ppg). Lost returns while pumping 15 ppg cement. Ran 316"of 1" pipe in 18 5/8" x 24" annulus and cemented to the surface with 1600 sx permafrost. At 828' pressured up to 15 ppg equivalent mud weight and died not get leak off into formation. Drilled a 17 ½" hole to a total depth of 3290' and ran the following open hole surveys: Dual Induction Borehole Geometry Long Spaced Sonic Set 13 3/8" csg at 3276' and cemented with 250 sx high yield permafrost and 7000 sx permafrost. HOWC0 discharge line froze up and cement set up inside casing (Top of cement inside casing was at 129'). Ran 1" tubing in 13 3/8" x 18 5/8" annulus and cemented from 315' to 40' using 250 sx permafrost cement. Drilled cement inside 13 3/8" casing from 129' to 3172'. At the end of the month BOP's are being tested and the drill depth of the well is 3295'. RECEIVED APR 1 519t? Dh/is!on ef Oil & Gas Conservation Anchorage -14. I hereby certify that the foregoing is true ~ oo~ec~ s~o~ ~:~~//~ ,~~'~~~ Asst. Mgr.0ffshore/Ak. Div~ April 15, 1977 NOTE --Report on this form is required for each calendar ~nthl regardless of the status flf operations, and ~t ~ filed In duplicate wtt~ th e oil and gas conservotlon commiHee bythe 15~ of the suoc~ding mofl~, u~le~ otherwise d~r4cted. (X~I B STATE Of ALASKA DEPART~IENT OF NATURAL RESOURCES Division of Oil and Gas Conservation TO: ~-- Hoyl e H. Hal¥1il ton~ Director Thru:Lonnie C. Smith Chief Petroleum Engineer FROM: Harold R. Hawkins Petroleum Inspector DATE : April 5, 1977 SUBJECT: Nitness BOP Test, Sec. 32, TION, R23E, . 76-~ UPM. Exxon ~o 1, Permit ~Io. o~ Point Thompson Unit i " ' ~:4~ AM for 6 O0 A~i check in Wednesday, ~arch 30., 1977 - t left my house at" ~. · ~-~'~r''a {l~rudhoe at 7:00 AM to witness a BOP test at Point Thompson Unit, Exxon No. 1. Gordon Ashwood is the operator. When i arrived at Point Thompson, the crew for Loff!and Brothers was nipplin!] up the BOP's. Pusher for Loffland #162 ~as Junior )~nson. Thursday, March 31, 1~77 At 12:10 A?~ tests, were started. The master closing '~-6it ~ould no~t oper--F~-. ~ control valve for the hydril tvould not work. They replaced several valves and filters on the accumulator which is a Payne type. Spool has 6" outlets. ¥~hile waiting for accumulator to he repaired, I witnessed the testing of the choke manifold. There were 10~ valves and 1~,~ flank!es. There were two manually operated chokes also and a Swaco superchoke that was tested to 5000 psi with no leaks. The accumulator was repaired and tests started again at 12:10 PM on the BOP's. The accumulator still wouldn't completely close the hydril and was worked on again 2:10 Piq. Also the control panel on the rig floor wasn't operating right. The dart valve on the floor had to be repaired. The lockin(~, handle ~.,~as missing and the spring to help close the valve was broken. The locking handle ~as fixed, but they had no springs to replace the broken one. The dart valve was tested though a)':d held riO00 psi. Also the ball valve was tested and held fi()O0 psi. At 5:00 PM the accumulator' was finally repaired. The annular preventer was tested to 5000 psi and held OK. Exxon's work order called for 5000 psi test on the hydril on initial testing, then 70% thereafter. The louver pipe rams anLl upper F~ipe rams tested to ~JO00 psi and held OK. The test st~me~ and test plu~. was pulled which ~as a ~,ellhead tvpe.~ ~luo,. The outside choke which was a HcEvoy and the inside choke which was a )ICR valve ~.~ere tested to ~aO0~o psi and held l~ressure. ~ O.~k.'~ The inside kill and_ outside kill valve did not hold on initial test, but ~vas repaired and held OK. At ~-~:00 PM the lower kelly tested..., to .,~_,~,u~:n~n psi OK. The upper kelly did not test. Also after beinn.... replaced, ~he second upper kelly did not hold pressure. The operator~ ~nrdon Ashwood, told Junior Uenson, pusher for Loffland, to ~!et one or~,:lered, ~?hich he did. I toured the location and there ~as quite a lot of debris, paner, ~.~etal, etc. scattered al! over the location. I informed Gordon Ash,~,~ood, eperat~>r for Exxo)~ ~ha~ ~ found and he i~ediately started the roustabouts cleanin(! 'Pt. Thompson Unit 2- April 5, 1977 the location up. The accumulators master gauge showed 2850 psi, but there was no nitrogen backup bottles manifolded up to the closing system. Gordon Ashwood said he didn't kno~ they ~ere mandatory. He ordered four N2 bottles to hook up. There was also no well sign on location. They had a steel fuel tank and it is well bermed. FridaY_,.April_ ]_, 1977 - The new upper kelly which is a hydril type arrived on l~ation and iS being installed. Meanwhile Gordon Ashwood called a Haliburton cre~ to pressure up with mud between the blind rams and casing. The pressure would not hold. Meanwhile the cellar was pumped out and I found a flange on the double gate where they could pressure up under the blind rams. They connected the Sprague pump up and ran the test plug back in the hole and then closed the blind rams which held 5000 psi OK. The new hydril upper kelly was installed and was pressured up to 5000 psi OK. Tests ~ere concluded at 9:30 PM. I gave one copy of the field report to Gordon Ashwood, superintendent for Exxon. One report is to be sent to Johnny Jackson, nmna.qer. Test fluid was water and diesel. ,)in s~ry: I found the master BOP closing unit in very bad shape, plus 7 ~ther failures which were repaired. BOP's are now satisfactory condition except for nitrogen backup and dart valve and well sign not being up. Gordon Ashwood is to call our office within five days on their three discrepancies. Attachment · ...- (, c '$atisfactor~ ' Type InSpec'tion :~.' _.. Yes No Item 0~) Location',General (')-(~) /.~') () (~) () ~) () () () (-') () () () () () () () () () () () () () 1. Well Sign 2. General Housekeeping 3. Reserve Pit-(~)open( )filled 4. Rig ( ) Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data '7. Well NoS. , , , 8. Hrs. obser~,.. , , , 9. BS&W , , , 10. Gr. Bbls. ('.) Final Abandonment II. P&A Marker Y:~ ~z,~.'~'. Name. & Number~ . - : , ~ . .,~..:~-, - . .. . .. Satis'~actory-.' Type InspeCtion ~.. · Yes ' No ':~'Item ~) BOPE Tests -' (;,:) () .(~') () ~<) () () (x) x~~) ( ) () () (x) () (~) () 0<) () (~) () (×) () ~') () (~) () 15./-.~.~Casing set Ca,-~_:~ ' 16. Te~t f'luid-~ItX)wtr.---~--( )mud ~') oil 17. Master Hyd. COntrol Sys.-~si.Q. 18. N? btls. , , , ps~g 19. R~mote C~trol~ 12. Water well-( )capped( )plugged l~) ( ) 20. Drilling spool-~/~ "outlets 21. Kill Line-()(') Check valve 22. Choke Flowline (/~) HCR valve 23. Choke Manifold No. valvs. LO__flgs/~ 24 Chokes-()~)Remote( )Po~.~'~)Adj. 25. Test Plug-(;\/)l'lellhd( )csg( )none 26. Annular Preventer,~r~,~usig 27. Blind Rams~oo psig 28. Pipe Rams~psig 29. Kelly & Kelly-cock~psig ( ) ( ) 13. Clean-up (;x.')( ) 30. Lower Kelly valve,,',:.~sig ( ) ( ) 14. Padi-leve]ed ) [~,,~__ 31 Safety Floor valve~BV (q')Da~t~,!'., (hr~/'-"days ~ ~ ' ' Total~,nspectl on ..... observation tlme~..~.~' Total number leaks and/or e~ulp, failures Remar~/./-~'.,~'.,~,,.;-,?.~: ...~,..~?;,.,../~' .~~.~ ~ Z~ ~'~.~-'~ZzE~ Z'" .~. '7.:; .."~-".C ~ ~ ,f .,'~-~':' ..'~,~ ~.?77 lz~z~z= ,~ ,~T l~'~.x~/~ . ~ . ..i, . , . .. cc'?D~/'~,' ,..~'-'. ,~..~ A?' Notify in ~days o~~~ Inspected by'/~'_,~ ~.~..'/-r.-,~,-,' ~ Date~ --i Pete Nelson Cn~e Minerals Section ActinS '~ ~: f -- Alas4a Division of Lands Ancho rage D ATE : March '1.1~ 1977 James W. Brooks~ Commissioner Department of Fish and Game StX!JECT: LO/NS 76-J. 09 -/;' 'l Exxon --Point Thomson AD!, - 47560 Spill Preventioa Control · ~- ~ and Count:ermeasure t l,:.,n The z~__a, ska Department of Fish and Game has reviewed tNe subject plan and has no objections~ providing the proposal meets Departmer, t of Environme'r:i:al Conservation guidelines. We advise t'he following: t) · n~_ day tank should be 'placed in a separate contain-- merit area, ~) The procurement and transport of a drill rig for boring emergency relief well should be discussed in such a plan. Would a spare rig even be available i.n case of a b].owout at this si~:e? If such a rig were available, .how would it be transported to Thomson Point and how soon cou].d it be avail..- able onsite? 3) Paae 4 of attachment 2~ in the Contingency Plan lists equipment and absorbent materials normally maintained at drill sites. The applicant should state what will be avail- Thank you for the opportunity to comment. cc: W, Copeland - ADL Fairbanks D, Lowery - DEC .Fairbanks A. Brower - NSPP Barrow H, Hamilton-- O&G Anchorage of ALASKA Division of 1.!i_nerals and Er~! ~",~nage~.~nt Carls G~nn - Scott Gr~_- DF&G Doug Lc~m~_; - DEC Hoyle H~nilton - O&G FRON~: Pete N~--lson Lm~ CONFER: Attached for your review and cc~a~nt is a copy of ~ referenced for t~he oonstruction of ~u airstrip. Your ~y re~ is appreciated. DAn : ~,~r~ 3_l, 1977 susJ~: LO/NS 76-109 (~nd. 77-29 ADL 47560 i!J 'C'ONFr: appli~a~ COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFS HORE, ALASKA DIVISION FEB 8 1977 Div. of Minerals & Energy Mgt Anchorage, Ak. February 25, 1977 Re: Exxon No. l, Point Thomson Unit S.E./4 Sec.. 32, TION, R23E, UM A.D.L. 47560 North Slope, Alaska Mr. O. K. Gilbreth Director, Division of Minerals and Energy Management Department of Natural Resources State of Alaska 323 East 4th Avenue Anchorage, Alaska 99501 Dear Mr. Gilbreth' Exxon's plan of operation filed with our letter to you of Nov. 2, 1976 provided for the construction of a gravel airstrip to serve the subject drilling operation at a location adjacent to the camp facilities more particularly depicted on the attached 1" = 2000' vicinity plat. Your letter of Dec. l, 1976 generally approving such plan of operation denied the specific provision thereof dealing with the construction of the requested airstrip at that time; however, such denial was made subject to revaluation "...next spring when the applicant can better document a need for it". As we have verbally explained today to representatives of the Departments of Environmental Conservation, Fish and Game and Natural Resources, assembled in the Fairbanks office of the last named department, we believe that we can document the need for a gravel airstrip at the Pt. Thomson location at this time even more emphatically than was possible at our Nov. 25, 1976 meeting with representatives of the said departments. Primarily our need for such an airstrip rests upon the imPossibility of completing the operation prior to commencement of summer thaw, as the late commencement of drilling operations which was forecast at such meeting has now become a reality. Instead of an early February commencement of such operations, a point in time which would itself have made completion prior to thaw conditions an unlikely possibility, we now must concede, as a result of environmental conditions peculiar to this current winter season together with certain problems in securing necessary agreement ih~' i:iVED A DIVISION OF EXXON CORPORAT!ON Mr. O. K. Gilbreth -2- 2-25-77 all parties to the unit and unit operating agreement, that a spud of the well prior to March 1 is an impossibility. We have previously submitted with our Form 10-401 Application a copy of a wellbore schematic drawing describing our casing program from surface to total depth. Any reasonable drilling curve drawn to accomplish such program with a March 1 spud date will demonstrate the physical impossibility of a completion prior to a summer thaw, thus projecting operations into the summer season. We have, we believe, made adequate provision 'for a continuation of the drilling operation through the transition from winter into the summer season by stockpiling supplies of all .major co~odities and materials necessary to the drilling operation. Accordingly, our transportation requirements should be only those which are incidental to the movement of camp supplies and the movement of personnel to and from the location. After the summer thaw the only two ways this transportation may reasonably be accomplished appear to be by fixed wing or by helicopter aircraft. Although helicopter transport may well be adequate under most circumstances to transport materials from our base at Prudhoe to Pt. Thomson, we believe that the record of air serviCe provided in the arctic by each of these alternatives unquestionably d~_monstrates that a fixed wing aircraft is a safer and more reliable means of transporting personnel than is a helicopter. We do therefore respectfully request your reconsideration of stipulation No. 2 of your letter of Dec. 1, 1976 and your permission to construct a gravel airstrip at the subject location in accordance with the construction plan submitted herewith. Yours very truly, Robert K. Riddle RKR:jh Attachment REC_F. IVED Plan of Operation Pt'. Thomson Otter Airstrip Equ i pmen t' Three(3) D - 9 Caterpillar Tractors with bulldozer blades and ripper points' Five (5)'Euclid 25 cu. yd. belly dump trucks One (1) D-14 Caterpillar road grader Three (3) 966 Caterpillar front end loaders. Route: Over existing Prudhoe road to Beaufort Sea ice thence to location and return, per attached plat. Gravel source and required amount' The 20,000 cu. yds of gravel required will be removed from the Pt, Thomson spit (see plat) and transported to location over existing ice roads. No gravel will be removed below a level of one foot. Date of commencement and completion' If permission is granted mobilization will commence March 20. As the construction will require but six days, total time required, weather permitting should not exceed two weeks; thus completion by April 2, 1977. '. ,.,D:nkum X · . 6'. Lion Pt · $* ,.., ,% ...... "' ~Ole"'l-" ' POI~ StOckt.~h Is!ands ~e ! ,' laland -. , ';,; b %,% \ , Lookout ~ ~,/.,~...': ,.TiDza~iak Island ~bin '. . · LEGEND.· · , POSSibLE 6RAVEL t., ~ '.. ..... A nska I Duchess I Challen:o I "' ............... North '" '"': .,. Star t Ma~uir.e :' .Islancys Bul!en Pt.'... ~tllien Pt Gordon .. .~,~,, ..', .~: .. ...,, .... .:.,:,.. ~ :t"' '~.~ E~, MIKKELSEN BAY ;'" '~: '*~;'~' "' .... "_..' -~ ' ':-'¢ .... . PT. THOM. ... .'...".~ . ,, ,,,,< ?' .:....~. ,...,.,....:.. x .....~ ,.. , i"..:. '" ~*~*~* /',".'7 ,'... /~. ~ :'~': '~ ,'~. ~' "~' " ' ~'; ~ '~ APPROX. 'R( L~IG'ON" :.' WEST '' '~ HAUL..' RCA '. ICE ROAD EXHI. BtT "B" -- PROPOSED ROLL1GON HAUL ROL SOURCE EXXON COMPANY U.S.A. VICINITY' SCALE. l"r. ~'-'PROPOS¢D LAND DEP_~q~%~f OF NAT0/RAi ~gDO~ Division of ~nera!s and ~%er~i l+~nagem~nt DATE : ~trch 4, 1977 ~OM~ Land ~ga~_~t Officer SUBJECT: LO/NS 76.109 ADL 47560 Spill Prevention Control measure Plan Attac. hed for your review ar~ ~t is a copy of the referenced spill prevent/on control ar~ coun~ plan sukmitted by Exxon. Your ~y respom~e is E - ON COMPANY. U.S.A. POUCH ~,~_,1 · ANCHORAGE, ALASKA 99502 DEPARTMENT ~'.i_ASKA DIVISION February 23, 1977 Re: LO/NS 76-109 Exxon #1 Point Thomson ADL 47560 Mr. Pedro Denton Chief, Minerals Section Division of Minerals and Energy Management 323 E. 4th Avenue Anchorage, Alaska 99501 Dear Mr. Denton' In accordance with Stipulation No. 12 'of your letter of December l, approving our plan of operation submitted November 2, 1976, we enclose two copies of the Spill Prevention Control & Countermeasure Plan prepared for Loffland Bros. COo Rig No. 162 by Kenneth L. Willits, and Associates, 3740 Mt. Blanc Circle, Anchorage, Ak. 99504. In addition we enclose likewise in duplicate copies, an Exxon prepared Pollution Control Plan, Oil Spill Containment and Cleanup Plan, and Relief Well Location and Pad Construction Plan for the subject operation. Robert K. Ri ddl e RKR-jh xc- Mr. W. M. Selvidge w/o encl. Mr. Otto Rath A DP~SiON OF EXXON CORPORATION ADDENDUM TO SPCC PLAN L O F F LAN D B R O T H E R S C O M P AN Y RIG NO. 162 E X X O N.~ N O. _t p 0 T N T_, T H O M S O N U N I T.. ~.r~ 0 N T E N T S: (1) POLLUTION CONTROL PLAN (2) OIL SPiL CONTAINMENT & CLEANUP PLAN (3) RELIEF WELL & PAD CONSTRUCTION i!i. !. Objectives -~ ~lE: wi ldca% ,,,7~ .~ t The objectives of tile Pollution Conhrot Plan for '~-' ' are as for!ows- A~ B~ To define ~_e operating conditions at the wetlsit_e and %he actions that will t~e place. To outline the h~ndting of necess~ revelatory ag:~cy notification in the event of ~n ell spill en {i~e lose- tion or discharge of andy location effluent in-~o ~ -- 9 5/8" X 13 3/8" casing annulus. Sco~ of Pl~n This plan applies to all operations en ~n~s wildcat. ~'~' ........ shall be rigidly followed by all persePzeei (including contract personnel and visitors). During drilling ob~mrations ~ it is tl~e ~o{on Drilling Superintendent' s respnsibili%y to see--tb_at 'these r .,= ~ p_oc~a,Jres are observed. These rules shall be considered as mL~.~gum r~rem~hs. ?hey are not in%ended ~o supplant ~e exercise of ~n~n sense and judgement by super- visors ~nd o~rating ~rso~ei when under e~.erg~cf conditions, t-Pm~ever, tt~ey ~e to be follc~,,Ted ~ ~hn~ re~re~en'hs unless aRd .... '' ture is au~orized by suNervisoFs au~.ority. Division Catas~ophe Orgeaization The Catastrophe Organization is a staff of pePsonnel specifically desig- nated to cope with e~arge~ncies such as a~n out-of-control d~.illi, ng well er a~n uncentained location effluent discharge. The Po!!utien Centre]_ P!a~n CatastroPhe Organization will be. identical to the Well Control Catastrophe Organizatien. Drillimg Operations - Location S'~ei!l~nce and Control ' ~. A. Tine dril!im~g rig is to be situated on locac~o_~ various pits aced ~i~nt s~tted as sh~,~ on Exh~i-h A. B. A list of ~rent ~uerg~ telephone n~,bers and a map of ~ee moca! ~ea w.~it be maLtreAted by ~e Drilling Su~intendent. C. ~ae site will ~ eq~p~d wi'~ ~ ~en e~ra'ted radio syst~ D, The Drill_~g Su~rintend~t wilt desi~ate "Briefing Areas" where all p~somnel m~ in c~e ef an e~rg~mEo7 and ~.~ro~, ~~t is kept V ..... Defini+-~ or'~ of Oueration.. ~r~'o~d ........ ~ ~ ~ A~ Pit Level Maintenance Ail pits will be con-a~_nuousl, y monitored to ascertain that the fluid level, is at leash 3'' below ground level. Utilize -the supplied fo~s 'to record fluid levels in each pit' daily. 3. In the event any pit fluid level is less -hhau 3" below ground level notify the Operations Superintendent of intent' to move fluid from one pit ho another. 4. Only upon approval of the Operations Superintendent will ~ '' ~tuma be moved from one pit-to another Use the provided recording forms. After 9 5/8" casing is set an injectivi, ty -test will be conduc~e~ down the 9 5/8" x 13 3,,/8" annulus using drilling mud make-up_ water limiting injection te below the collapse rating of -the 9 5/8" casing. A [tewco skid mounted p%Lmp with recorc!ing flewmeter will be 'use0. to injec-h or move all fluid. 6~ Prior to injecting any fluid down ~he 9 5/8" x 13 3/8=' annul-us, .~_ehify the Operations Superin-~'~ Any_ removals ....... ~rom tN~ pits :must be injec'~d down the 9 5/8" x !3 3/8'~ annulus, or reta in the mud er make.-up -' = r . . ~,~a-ce_ systems Fluid ='~ ' ' l.. Every other week: water samples from the sewag..?. treatment plants, the contingeN, cy pit, arid the, water so-urce lakes will be transmitted for testing by Dubois Chemical. Snow Removal !. When necessary for good housekeeping~ snow should be removed from the location pad to !ecations necessary to dike elf the well site by windro~ging snow in accordance with the well oil spill plan. · o. bet ground PiT LEVEL CHECK FOP,;4 'i eve 1 ~'"= 3'~.-~.2'' balov,, ground \/ A = Les s !'lAS' i';: '? iT SAiqTTt~Y ,rOLDIi'i~ ?iT FUEL ? I T C UTT i hlr~ & REFUSE ? IT PIT PIT \ f,, ['~ r~.., ? r-' [:: 5 S ~ i ? E,, ,., .., .[ F 't '~ 3/8" !'I ., A i'iUL. US Plans aha scned,~.!e of opera'hzo.s_s ~or CO}iin{ffi~_RJ_R~:]' }pOSS.i.}D]_C'. oil spills ae ~ne above location a ..... ~,resenked In the evene of an oil .... spill, ,. ...... ~pc ......... ,_ ~ ,_..:ndeet wJ..]_.l it~xnedia'he]v nekify the Operations Sueer'~-r~i-,~.~,,']r-,r,t a~d advi_ him ef the severiey eA %he sDil! and prevail; ~ .... ~n?, '?:e 11 s i he co). ~o ition s. The dies~g~..a.~ed Exxon., U S.A re-o*-~,-'en~.~.. ..... ve agency or agenc~-s ...... as shOvaq -~!t n.i.'~ .z ~q.p~.:~,_~'~ No[-.i..Eicat:ion Requirements ~ ?he following equipment should 'be employed ho build d.~kes and control_ the f'~zow. Available at Location 2 Water Trucks i Front End Loader 1 Butldezer t Grader Polyethylene Sheeting Available at Pr,adhoe P~ay Area Fron-t End Loaders Gravel ~[' ~, k * ._ ruc (S ' Laber Crews *Gravel -~- ~'~ ' ~ru~,-.~ or equivalent for haull~ci' sn.c}'~,,? if ne. cessa'~'y q'he ..... eauipmen%~ ~grom_ Prudho~ Bay area., wi'~'~.~ _uequir,:~_ . ........ ]P,--l~; in '~ur~nslt~~ ' depending on exis'h~r~}' .......... weather conS~-~ier~s~_, .... .. Containment Plan: . 'i ~ The genera'~ conta~~''-- ..... -~':,~ w~ ~i be %0 qirech :[['[c}:$ 'hO ~,~.~n .~,p and n~id .!zqu.~_ds +'~,=r~ for as long as possib'~-' ~.~.~lce,~ overflow to ~: .................. area ~:nrougzz drainage pattern as onown on attachedc~_~ ..... aw~'"ng... 2 The ~-~a-~v oon~ainment a-roa is a }naru~-a, gully approximatellz 500~ W.S.~{~ of the location which is in 'b. he direction of natural drainage. An oC1 spill boom will be placed in the water ak the e~d of the gully to ~-'-~ ~o.n~ain any escaping oil. Hateria!s for D~ke Construction Snow and water will be used for dike cons'truc-hion~ The shew ~'' ~ ~ o be held ,.i'chtn the centainment area sn_uld sufficien'h for construction~ Construc-hion Schedule: .................. w I ..... on co~ld_i~ 'hi o~ts heneative .... ~ S~lines Conseruct ice -~---n "-~-' e;.um across e~Eld of guTM ~_iy ctuE ~ng drilling operatiens as equipment .availabilit}{ permits~ Cons-truer ..~.-~'lo~,~ ............. ~-hsnn::~] ~o containment area Drainage Par'bern The na-hural drainaoe w~it be -~o ~..~ ~-~ ~.,.e, ~.', ..... on the .... ~ ~R~, -~ i~.o ~e~au ..... d oontxDux map .. !n orde~ '~)romo f~ " b" ~ ' d doze channel .:, _ zades wioe ~ ccnsetruc'Li.;{tg ikei-~ '...:e .~.,r,~,~R-:~e]{-o along the draiNan~ are.~ Cc. nskrnr:~ herrj, ngbor~e [ype snewbank pahterns depending on %attain and topography ~'~ direct oi"x flow "~-o Srain._~::~g .... ......... hann'~i.., a~,:~ ho ,.,,~-,~-', dozed to the downhi-'i. ~ side ho h~_p' di~qech'~ -~he_ ~-":]r~,:n.. ..... ~"'~.y eo ensure %hat alt ;aa. chinerl~' is kep~ o~h of SDi_i[]. ~.'rea whenever possible to avoid unnecessary ~ra~' . on virgin tersain. Dike COns'eructien An impermeable dine will be constructed ut%lizing cats, loader~ and grader by windrowing the snow, spraying on the windrew~ mixing the shew and wa her, and -hhen placing Chis ~a't:.erial on the dike area Ensure ~_ho.{_ {:he Cl.i~-~ material is well cempack, ed., This precedure is to be cat,lied on unhii a minimum height of 5' has been ob-ia{ned. 'Fha level o[ the d~ke ;s %0 be cons~st;enh ~hrougbo-,at dike sho~lLd have a 3 to 1 s]..ope .......... :,---,,-~ ':",-,-,' '" ...... s'~ n'o,~ s'il,oul, c~ se ~ ~ ~. .~'. % '- t:he [ell.ow.- lng. . ~Ne ~ina_l ~in. isi~i:eg of e}-,,_, ...... dike w!!A be (.~o~..:~ ~-~:.. by_ grade:~ ~ ' ~ ,. ... This wi]_l using a ~now w~ng ,_~ achieve flat, provide a more sui%ab!e s'{irface ~{or the ItnJ. ng. Airier insha!!a-hi, on Cut V ~-no~ slot '12:' .~l~-o and 6" wide in -~-," '~-, ~.. ...... ~ ........ ~.,Ol_ _. tiS_. .... ~.~ aa.t on ,..~ ..... n,~_~ s~de o:t' the --:~-- shown in ~'~-~ ?ma~.~..~g' ' .... our~ .... +e~.~--.~.~ the lining will fie lining at a time (each sheet should overlap a minimum of I0' wiqh nexL shoe%).' Backfi].! the V s'iot wilt wsIer and loose snow and..~¥ .... ~ze the _.liner .~nuo posed-ion. Cover the iinefwi%h !eose snow aL a 3 'Lo '~ sl.,'~~.,~ Lo hr,--vent . · wind damage This is fro be d,..n~ very ~ .... ~..,-:.fn]_.l.f and -Lb ~ ............ s ground te vent ' -' ' ~ ~ .... aa?aqzng._ ~he liner. Aster the iine'z is s~.'f:}{}ic'''.~,~, ..... ~,;.~. covered~ the slope is [o be sprayed ~ighLily wi[h waher consolidate the snow a, nd ['r~'n' w~'~S " G~o'?~:~ Cleanup elan Major Sp~ll: Cleanup wit1 be conven~-~,~ , ,,r,.al. s'ttj mr~ ~ qr'r ox pum[::~ing equipment Damaged snow wil'~ ..... u,~ s coop:~,i up and . ~ · .~ .~ ~- ~ .... placed in a holding area un~.~l hh,itw, and eno products wiA! be ...... i~;~-,,~-,.-o-op ti.tn be placed in a holding area, then ~z-~por Spil2: She ei!, snow and ice mixture will be scoopeS and moved tea holding area un'hil thaw and 'then b~rned. ?he damaged spill areo. will h.e res-bored as _~t ......... by apprepria%e governmental agencies. TYPE OF SPZZ,L OR DZSCHT~.RGE Any sized spill or discharge on land. ::L~,y' si .... d spil ~ t¼ '~ ente ............ .~.,.a ~ r s navigable waters so as to cause a film or sheen, upon er discoloration ef the surface of t. he water er adjoining shore- lines or cause a sludge or emulsion ~-~ _ _~h ~he surface to ~ deposited bene~~ of the wa~er or upon adjoining shore--' lines. Navigable waLers include but are not limited ~e seas, oceans, bays, lakes~ inle'hs~ seunds~, canals~ s-breams rivers, creeks~ drainage dihches in which waeer is flowin~9~ we-hlands periedicatl, y inund[ated with wafter and . ~rmme-hen'h '~i~rs~ se~eams and even %brough dry at Lime of spi!t~ i:f the t.~'r'~ _c ~.~.~,~ year is such that 'hhe use of ground contact vehicles on the hundra has been termina-hed by-hhe DNR and i% is · necessary to mebitize eqmipmenh on~e ~he tundra to clean up the spill, the DNR must be nefified. U. S. Cc)asi:t Guard Cap ta i..n., of Porh ',}i: Anc~o~?aue (o0l) 065 o Coa'~ant~der !'7'hh Dis (90'/) 586- rte u' i_o n 'i 0 U ~. S ~ E p v J. r o n-,;,n e n t ,.~. ]. Prohec~:i,:')~ Agency (const_~!h l.,aw D:~par'izmen[: before ca!-L:tng-this (206) 4:12-1213 FZGUP. E i i PAD' LAYOUT" *. · PO T .... ~ ,','riLL _~r','~ THOMSON RELIEF ~' :_~:o,_.,t&_z~_OL'~ AND '~AD CONSTRUCTION 'r'a i-_:he e}~tre-mely .................... u~.,'l '-} !.-= i ,,. .... .~ event 'h.ha.t a relief well is required,, we will lo- c~:~.~e.~-~n'-'~ cons%?_:uct a relief well p~d as ~:,~"~"n.~.,,~,;.,,~. below. i_~, 0 C a t i. O iq - The relief well will be located approximately 6,000 feet east- northeast ef the Pt. Thom. sen well regardless ef the time that it is required' This location is approximately 120 feet west: .~ . ~.eet nerkh ef the south line of -' T la~,, ':~ z3E, U ~'~ (see attecn~.d locnt4on map) '~r-'-f-'{ oi% s3, dP~ ~ = ......... This /.ecation was selected because of the ready source of gravel on the Pt. Thomson spit and the moderate 6,000 foot direc'tienal kick that would be required. Approxi:mate~y 26,000 cubic yards of grovel 'will be required to c.:ORSe~-~3ch~ .... a 700, ~_'~eo-h x 250_ foe% x 4 foot locetion pad. for a ty-oica7_, ..~ ~ }~,l~ ........... '~ copter 'traRs Dot ~a. bl,--_ .. rig . The ~ o,--a,~. 'Lien n'a ..... F 3 s tows ~ ~ub.~c yards is ava{labiLe at. the that epprox~rn,~t~,!y PO~O00 ~" ~ 'i?ho~sen spit and there is additional gravel in the area of the ~_"~-:~ ~.. _~. ie~.u ~,:re l 3_~ ~'~ oc'~ e ion.._. ~ Prior %0 breakup: ONe dozer,. one grader, .':)ne loader and one ?;at. er e~-~-'~..~ ...~..~. will be maint3.~ned at the pr'~ma'~'"y_, well !oca'h'ion - ~ .- ~ ~,.~ 4 ~iona'i ater c~..}ck, t~,:o adSi'hiona! dozers with rippers and tNree belly d~mps ~:,:i2.1 be -k. renspor'hed uro,u Dea0t.norse %0 the si-he for pad construc-hio:n. TNt necessz, ry cons%ruch:kon ec~uipment will be transported ovax ~he ice rend ~-o near the primary location where a new ice read will be con ~kruct:ad to 'the relief well loca%ion~ The gravel from the Pt~ Thomson spiL will be moved over_' the spit it. self.. The additional gravel in the area of -Lhe relief well iocatier.,,_ will be utiiize{l to fulfill the rem.ninir.~g gravel needs. Ali. soils removed for -the construc~c, ien of pits will be stockpiled for reuse in restora{~ion work after completion of drill- lng operations. If time permits, the neares'k available ha!icop'her rig arid necessary equipment and supplies will be transported to the relief well !ecatien by the ice road. If t. his would prove dangereus~ ail components will he f!ewn in hy helicopter. During breakup~ g2he dozer~, gL-ader, and loader mai. n-hained on the primar? welt loca~ion will be utilized in pad cons'hruckion during Lhis phase also, and moved {~o the re!ie~{ well !oca-hion u'hi!izing a Roil. igon. The additional equipment, two dozers '~?zi'hh rippers and three belly dumps will be transperted hy Ro!ligon ever 'the ~oundra making river cross;Lngs where permitted. ~;'~',nTM spit will be moved over '~he The gravel from the Pt. spit itse!i{~ The additiena! gravel in 'the area. ef 'the relief well location will be u%i!ized to fulfill 'the remaining grave]_ fill 'needs~~'t~_1 soils _~-~o~,,~v~r~. for the cons-b, ru. ction of pits ....~ ~.oc~,p~_ed fer in restoratien work after cempletion ef drilling eperatiens. The nearest available helicopter rig ~_ -,~ ~ ' ,-' and ~'~iats wilt. be 'hransporeed and a!~l necessary su?p~_zeb 'to ~'~.n~. re!~=~ ....... well site by Ine!icopter. ~ Barges will be utilized "~,-~.~:.n pessib!e te e~-ansoort~, maheria!s and equipment to the relie~' well Aocation fromD=a,~_~_~e.~_,~'-~ ...... o .... .arte-~ bz~e~kuo:.,,_ ~.~ ~n±s plan i ~ identical 'ho ~n~ plan / { 323 £. ,fly ~?£,Y0£--l,;qcflOIt,~£ 96501 J~0.ua~y 31, 1977 Ex, on Comv~any, USA Pouch 6601 Anchorage, A!as~ 99502 At~: Robert K. ~d~e Re: LO/NS 76-109 (!~,terc!. 77-7) Velocity ~Survey -~DL 47560 The operations outi~aed in your letters of january 10 a 14, 1977, are ............ approved, ~0bject-to the s, pplicabte t,~rms'amd condihions of our approval letters dated t~c~nber !, 2, 1976 and. January 6, 1977. P~o Dem. fion C~def, P.~erals Section RECEIVED FEB - 3 977 DivMon ~f Oil ,qrld "~ IDF~IP~%I~'IT~I~NT OF N.~TUR.~L III~:~OI~'RCIES 323 [. 4TH iIVEItUE-ANCHORAGE 99501 Janua~.[ 6, 1977 Exxon Corporation Pouch 6601 Anchorage, Alaska 99502 Attn: Pober t P~iddle Re: LO/NS 76-109 (Amend. 76-116) Gekntlemen: --lc. } Dk:',i:T CONFER: FIL~: The route change proposed in your letter of December 9, 1976 is hereby approved subject %o our approval letters of December 1 and 2, ].976, and the follc~ing additional stipulations: : 1. ~nere shall be no blading or re,oval of snow from the Sag River. 2. The Northcentral District Office, Division of Lands, 4420 Airport Way, Fairbanks, Alaska, phone 479-2244, s~hall be notified of the date. of the rig move and shall be allc~ed to observe a portion of t/qe move and inspect the route. Pedro Denton Chief, ~.tinerals Section RECEIVED JAN 1 11977 Division of Oil an(t Gas Conservation Artohorage Conservatlon ~cember 6, 1976 Re: Point Thom~ Unit, Exx°n ~(o. 1 Exxon Corporation State Permit No. 76-85 C. [). Jones Manager, Offshore Alaska. Division Exxon Corporation P. O. Box 2180 Houston, Texas 77001 Dear Sir: Enclosed is the approved application for permit to drill the above referenced well at a location in Section 32, Township 10~4, Range g3E, U.P.M. ~lell samples, core chips and a mud log are required. A directional survey is not required. )~lany rivers in Alaska and their drainage systems have been classified as t~portant for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations nromulgated thereunder {Title 5, Alaska Administrative Code). Prior to co,~nenctng operations you may be contacted by the Habitat Coordinator's office, Depart- ment of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 03, Article 7 and the regulations p~lgated thereunder {Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Lair is being notifi~ of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We ~ould also like to be notified so that a representative of the Division may be present to witness testing of bl~t preventer equi~nt before surface casing shoe is drilled. C. O. Jones 2- December 6, 1976 In the event .of sus~ston or abandonment please give this offtce adequate advance nottflcatlon so that we may have a w~ness present. ,..%. . Thos. R. ~rsha11, ~r. Ex~utt~ ~c~~ Alaska 0tl and Gas Conse~atton ~tt~e £nclosure CC: Oepar~t of F~sh and Game, I~ab. Jtat Section w/o encl. ~partment of Envl~men~l Conservation w/o encl. ~par~nt of Labor, Supervisor, Labor Law Compliance O~v~ston w/o encl. Exxon Company, USA P. O. Box 2180 ~lDuston, Texas 77001 Attn: Crandall D. Jones Manager LO/NS 76-109 Exxon .~1, Point ~n ~DL 47560 f~ar approval letter on the referenced lease operations dated Dec~ 1, 1976, is herelm~ amended to delete stipulation ~9 and add the following stipulations: 15. Any waste water discharges shall meet EPA's secondary.. treatment standards, 30mg/1 BOO, 30mg/1 suspended solids and 200 fecal coliforms/100mls. 16. All putrescible ~,~stes and sewage sludge sh~l be inc2- erated in an approved unit. Other products such as paper, ~od .and cardboard may be open burned. (No it~n shall be burned in a manner that will cause a black s~oke emission.) Tin cans shall be burned in the ir~J~erator prior to .disposal. The residue from the above refuse sbz~ll be buried in a "false start well b~le", however, if this is not feasible it shall be buried in a pad or reserve pit. A minimum of five (5) feet of fill material s~h~ ]! be placed over this residue upon completion of operations. 17. and brought to Prudhoe Bay for disposal. Sincerely, ~'. Pedro Denton Ckief, Minerals Section All waste, test and cleanup oils are to be containerized Exxon Company Pouch 6601 Anchorage, Alaska. 99502 ,}-7560 B/k'/S/8,¥ O? f_ L71~$ 323 £ 4'[!I ,4 KC,YJ/ ,%~i I DIR ' I C.D,G ._i'-! ..... ..... I. 2 ENG - ..I 3 tiNG ! x ('_~:.OLI-- ----- .~_ .... L.~ I R~v I .... ...................... FILE: Use of %he a.].'i::e)z':nate sea sho'u, ld he usel %o i:!).e c<s-:'?:c~,:!'h. [mow ro;>~d is {:o t:~sed 'hbo ap:Tg, icant s}.ua]_! Dep. anz[::r:<:~n~ o~: F:[.s}.': and G{:~;ue cae ins.?::c-::: '[.:.] :u{}: co.~(.{:-Lk.[.e}.~ oP [:.~.:.:":: :t"oa,:'l p;fior '[0 ac'[:t~(.t~ use. ..... ,::~ ...... w. ~,'t:Z~.:.~:.!.L:o tx.~. ......,-. ......... ,,! .'itl C.O'.,i'"', ......... the ...... TM~: ,itJ,;. ....................... u.~ ::.., ;::: ~ ~' ,":.,'i~.,:. ~ ~ ........ D'i. st::.:i c:h ~.~ ........ :~: :u"3 .c ;:-:' :.~:.:~ '~ 'i, ........... ~. :..-~ i :,;:; ,...>" .': i ,..- ~. ~.. ,..... ~ (P '[ ?'~-':,. ....... 'UNWEIGHTED' BAROIU ARCTIC C~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 'fo'ri.~'li0'O barrels', of Unweighted Baroid Arctic ~asing. pac. k~: 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' Unwei~hted' Baroid ~rctic''Casing 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 premix 8.2 lbs./gal. Recommended procedure when using rig equipment: 1. Clean rig tanks and check for leaks. 2. Add wa%er through salt barrel. 3. Add diesel. 4. Add E Z MUL -agitate pit. 5. Add GELTONE. BAROID 'ARCTIC CASING PACK -2- 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. 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 GELTONE on hand to add the final 25 ppb to the casing pack. When ready to place the pack, add on the fly 25 ppb 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 C~SiNG P~CK -3- 6. 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. 7. When the RTTS tool is released, the D.V./F.O. collar should be immediately closed to prevent any U-tube effect from occurring. C~ The F. O. collar is recommended as it can be reopened as needed. It is also suggested that the RTTS 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 while displacing with casing pack. Final formula of BAROID Arctic Casing Pack left in annulus: Diesel Water. Salt EZ MUL GELTONE '87 barrels 5.5 barrels 60 ppb per barrel of water 12.5 ppb 53.5 ppb For the GELTONE to yield sufficiently to suspend the BAROID it is recommended that the premix be heated to 70°F while mixing. After the casing pack is premixed it should be left to cool as much as possible before being used. (40°F is the optimum temperature). An alternate to the above mixing procedure if it is not practical to heat the mixture to 70°Fi 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 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; 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 the reconditioning of the casing pack a simpl~ procedure. B'AROID~ ARCITC C~SING PACK -4- Reference: STB-185 Field Trial of BAROID'S Thermo-Pack on the' North Slope of Alaska. L. J. Remont STB-639 Oil Mud Casing Pack for Permafrost Formations. R. L. S~erman ,~oOuc'T~ 0 ~. j -'Foiz Z ~ouf~s 'T"O -~ ~T'- AtZCT;c t~ACI~. E ON Pouch 6601, Anchorage, Alaska 99502 PRODUCTION DEPARTMENT Mr. Hoyle Hamil ton Director, Division of Conservation Department of Natural Resources State of Alaska 3301 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton' In accordance with the Oil and Gas Conservation regulations for the Sta' Alaska we wish to amend our Permit to Drill application for the EXXON Nt Point Thomson Unit S.E./4 Sec. 32, TION, R23E, UM, A.D.L. 47560, North Slo , Alaska dated November 2, 1976. November 15, 1976 · Exxon No. 1 Point Thomson Re ' 32, T1ON, ~< S. E./4 Sec. -23 A.D.L. 47560 North Slope, The 9 5/8" casing included in the permit application will be utilized solely as protective casing. In the event the well is production tested a 7" tie- back string will be run as shown in the attached wellbore sketCh· This 7" tie-back string will prevent casing collapse if production is established. , .. ,i'.~ z;~ /._..,.,./ ..,,. .....,_. ..... ,/'3 H ~3ackson JWJ/sw xc; EPA Region X (Danford G. Bodien) W/enc. A DIVISION OF EXXON CORPOFiA'FIC,'N XXON BORE I Hr.~MUL)i% UI"~I I SCHEMA'Fi. PERMAFROST CEMENT TO SURFACE 56"x28" INSULATED CONDUCTOR (-~ PERMAFROST CEMENT TO SURFACE 18 5/8" CONDUCTOR (-~ 800' PERMAFROST CEMENT TO SURFACE 85 9 5/8" HOWCO FO ~ 2000' (to circulefe non-freezing mud) 95/8" HOWCO FO ~C~ 2500' (to cement 9 5/8"x 13 5/8"o! (]bndt.) !;5:5/8" SURFACE L~ 3:500' INJECTION INTERVAL TOC ('~ APPROX. 6000' 95/8" PROTECTIVE ¢ APPROX. 9000' CEMENT INTO 9 5/8" 7" PRODUCTION ~ APPROX. I1,000' CEMENT INTO 7" !/2" LINER (-~ 14,000' STATE of ALASKA nE",r~ :~:,, OF '" r, ,,,ESOURCES Division of Oil ansi Gas Conservation TO: F-- Pedro Denton Chief, Minerals Section FROMz Lonnie C.-Sr, d th Chief ,Petrol cum Engi neet ., /(\f "' / DATE ' Hovemher 1~, 1976 SUDJECT~ l.!xxon- Point Thnm.:.~nof l)nit [.1o. 1 Sec. 32, llOtI, [.).23[, U.M. ADL 47.~0. North Slope ~,~e have reviewed the "Plan of Operations" and "Contingency Plan" for the captioned well and recol~mlend their approval. LC~,/.Cr'i :bjm COMPANY, U.S.A. POST OFFICE BOX 2180 - HOUSTON. TEXAS 77001 November 2, 1976 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION CRANDALL D. JONES ,¥ANAGER Re: Exxon No. 1, Point Thomson Unit S.E./4 Sec. 32, T10N, R23E, UM A.D.L. 47560 North Slope, Alaska Mr. O. K. Gilbreth . Director, Division of Minerals and Energy Management Department of Natural Resources State of Alaska 323 East 4th Avenue Anchorage, Alaska 99501 Dear Mr. Gilbreth: In accordance with the Oil and Gas Conservation Regulations of the State of Alaska, Exxon has today filed with the State Division of Conservation an application for a permit to drill the subject well together with our check in the amount of $100 in payment of the required permit fee. In addition 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 disposal, pollution prevention, and measures which will be taken to prevent erosion. (2) Four Exhibits (plats) showing the routes to mobilize the construction equipment using rolligons and move the rig over Beaufort Sea shore ice as well as possible gravel and water sources: Exhibit A - Pad Layout and Vicinity Map, Exxon No. 1 Point Thomson Unit Exhibit B - Proposed Ice Road and Rolligon Haul Route Exhibit C - Point Thomson Gravel Removal Area Exhibit D - Proposed Arctic Drillsite As stated herein it is our plan, State approval permitting, to commence location work in late November, 1976 and actual drilling operations are to be commenced ...... : ¢V~ /7\ ~ ' "~ ¢~ OCR: r 11 /, ...~.r:':-~.,.~ . - xc: EPA Region X (Danford G. Bodien) w/enc. DIVISION OF EXXOt',~ CORPORATION PLAN OF OPERATIONS EXXON #1, POINT THOMSON UNIT LOCATION: 1320' NSL and 660' WEL Section 32, TION, R23E Umiat Meridian North Slope, Alaska The enclosed plats show all available information regarding' I. Planned winter access roads which are to be constructed. 2. Local and area topography around location. 3. Proposed location layout including campsite, rig position, refuse pit, contingency pit, sanitary waste pits, burning pit and fuel storage area. 4. Location and type of water supply 5. Location of gravel Otter strip and ice airstrip which will be constructed. 6. Location of gravel sources. There are no existing facilities (roads, camps, etc.) within a three mile radius of the proposed location. Natural Setting The proposed drilling location is situated on a relatively flat area approximately 1500 feet inland from the Beaufort Sea Coast line in Section 32. The surrounding terrain is low lying coastal plains 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 eleven 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 approxi- mately 1500 feet. The active surface layer or thaw zone is from 1 to 3 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 to take place. 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 strong- ly influenced by the combination of winds and coastal sea ice condition are factors contributing to an extremely harsh environment. Temperatures vary from an extreme high in the 40 to 60°F range in the summer to a low of -40 to -50°F in winter which, with the chill factor, may reach a low of -80°F or lower. 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 approxi- mately 50 inches of snow fall. 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 50 miles west of the location is the nearest staging area and airstrip with limited facilities £or 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, ~trappin~, and recreation purposes. Construction and Operating Plan Location work will be started in late November 1976, consistent with State approval, provided freeze-up is sufficient to facilitate movement of the camp and 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". In order to protect the personnel during the early stages of the operation, 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 perhaps provide shelter for more if necessary, on an emergency basis. This can be hauled and set up by one Rolligon. Also, it is anti- cipated that for an operation during this period, emergency shelters should be provided along the overland route. Frontier sand and gravel has small buildings (Wannigans) that provide adequate emergency shelter and it is suggested that' one of these be placed at least each ten miles along the route. This limits distances to five (5) miles or less from any point to shelter. 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. Move in small dozer or grader to move snow from river crossings, if necessary. After sufficient river ice is available, the first Ro].ligon load should be temporary camp shelters. Move in rig camp on two Rolligons with trai~ers and six Rolligon units. First loads should be blocks and timbers necessary to set camp units in temporary position. ~ . -2- 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 construction operations. Approximately 65 men will be required to staff an operation of this magnitude for 24-hour operation. Two specific things shoul'd be kept in mind if it is-desirable to move across the overland route and these are that the amount of snow cover available at the time the move is to be made is significant to protect the tundra, and freezing at the river crossings may be enhanced by re- moving the snow cover and exposing the ice to ambient temperatures. To mobilize for the operation, the first need is to set up a temporary camp- site at the location. It is proposed that the camp be obtained from the drilling rig that is to be employed for the operation. Since the pad will not be constructed at this time, it will be necessary to set up the camp in a temporary manner and move it to the proper location on the pad after the pad is completed. It would be advisable to dig one of the sewer pits at the onset and utilize this for effluent discharge during the construction period. This would necessitate setting the camp off the pad area opposite the sewer pit area. The gravel drilling site will be approximately 300' x 500' x 5' thick and will require approximately 30,000 cu. yds. of gravel. An additional 20,000 cu. yds. of gravel will be required to construct an Otter strip. The proposed gravel sources are listed below in the order of planned usage. (See Exhibit "B".): 1. 20,060 cu. yds. of gravel above the +one-foot elevation on the Point Thomson gravel bar as indicated on Exhibit "C". 2. 15,000 cu. yds. of gravel stockpiled by Mobil at Bu!len Point. 3. Reclaiming gravel at Mobil's West Staines - 2 location. 4. Reclaiming gravel on Exxon's East Mikelson Bay location. 5. Gravel from other bars along the coast line, from Bullen Point to Point Thomson with the same limits as #1 above. The gravel removal and hauling will be accomplished using rubber-tired loaders and belly-dumps. 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 pro- tect the existing land surface. -3- - The'planned drilling location, as shown on Exhibit "D", will accommodate the rig and equipment., camps, 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. ~ooden matting will be used under drilling rig and mud pumps for stability and as a further aid in preventing permafrost degradation. All soil removed from the con- struction of pits will be stockpiled for reuse in restoration work after completion of the drilling operation. All pits are to be diked with gravel. An earthern cuttings and refuse pit will be approximately 60' x 200' x 10' deep; all excess drilling fluid, drill cuttings and drainage around the rig will be contained and disposed of in this pit. The well will be designed to provide for annular injection before break-up which will permit subsurface ~ disposal of waSh and melt water from the refuse pit. A 100' x 200' x 10' deep contingency pit will be constructed with a minimum separation of 30' from the refuse pit to prevent migration of liquids; this pit will not be used except in case of emergency such as a severe well control problem. A 60' x 60' x 6' deep burning pit will be located a safe distance from the rig to permit burning of all hydrocarbon test liquids. Fuel storage will be approximately 200,000 gallons in welded steel tanks located within a 60' x 100' 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 to as near as possible to the original condition at the time of back-fill and clean up operations. 'The rig has not been selected for the drilling operation; however, the rig will probably have to be moved from the Prudhoe Bay Area. Trans- portation of the rig will be over an ice road along the coast, primarily on sea ice, using trucks and/or cats and sleds. Husky plans to move Parker Rig 96 from West Staines-2 to NPR-4, and will utilize this route to Prudhoe Bay as soon as conditions permit. Exxon will move the selected rig to the Paint Thomson Unit as soon as the location is ready to permit spudding the well in February, 1977. Actual drilling and evaluation operations will require four to five months and plans are to stockpile materials and supplies to permit operation after breakup. The rig will be left on location until the following winter. ~iajor supplies of mud, cement casing, fuel and miscellaneous~drilling supplies will be transported ~o the location and stockpiled ~W spring break-up. After break-up, personnel and light consumables will be re- supplied by rl~vin Otter. Helicopters can also be used to move equipment too bulky to be transported by Otter. All supp~rt~equipment not required for summer operations will be moved out before ~-up. Camp Facilities It is planned to activate the 60-man camp system associated with the rig 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 introduced into a Met-Pro Series 14,000 waste disposal unit. 1. Met-Pro Series 14,000 Unit This unit will separate the solids from the system by physical- chemical treatment and the solids are destroyed by incineration. Comminuted sewage is pumped from an equalizi~ng tank by a ra~ waste pump to a flash mix tank. A coagulant feeder delivers a proportioned amount of chemical solution to the flash mix tank where intimate contacting is accomplished by means of a high speed agitator. From the flash mixer, the wastewater flows by gravity into the flocculating section of the clarifier where gentle agitation promotes floc formation. As sedimentation takes place in the clarifier, the settleable solids are collected and are pumped to disposal; a disposable media filter is provided for sludge concentrating prior to ultimate disposal by incineration. The clarifier effluent flows upflow through granular carbon adsorber for removal of dissolved organic materials and into a surge tank. An adsorber aerator proportions air into the bottom of the adsorber, maintaining an aerobic fluidized carbon bed. The filter pump delivers the waste through a pressure filter for final polishing. A disinfectant feeder pumps a controlled amount of chlorine solution into the surge tank for disinfection. The unit is designed to comply with all requirements set forth for water quality in the Alaska area. 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 Met-Pro 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 lake approximately four.miles south of the location. The large lake is approximately eight feet deep and probably will supply 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. 3. Burnable garbage and trash will be incinerated through a separate Incineration Unit. 4. 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. Development Plans I'f oil is discovered in sufficient quantities to warrant future devel- opment, the Prudhoe Bay to Valdez oil pipeline will be the probabl~ marketing outlet from the area. Oil and casinghead gas would be pro- cessed through central oil gathering facilities with oil being pipelined to the. Trans-Alaska line passing approximately 50 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. -5- ~3urface 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 accommodate for the permafrost. On the surface, the gravel pad and wooden mats are placed under the drilling equipment to reduce heat loss, melting and settling. For permanent construction, sufficient gravel or other insulation must be used to prevent thawing and damage to the tundra and facilities during elevated summer temperature. Cement used through the permafrost zones is of special composition to reduce possibility of freezing and casing problems. Casing is run and cemented through the permafrost, and in the event of production or suspension, the casing must be protected by non-freezing fluid. RMH/kc 10-29-76 -6- E] , ON COMPANY, U.S.A. POST OFFICE BOX 2180 ° HOUSTON, TEXAS 77001 November 2, 1976 EXPLORATION DEPARTMENT OFFSHORE/ALASKADIVlSION CRANDALL D. JONES MANAGER Re: Exxon No. 1, Point Thomson Unit S.E./4 Sec. 32, T10N, R23E, UM A.D.L. 47560 North Slope, Alaska Mr. Hoyle Hamilton Director, Division of Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton: In accordance with the Oil and Gas Conservation Regulations for the State of Alaska, we submit herewith the following: (1) State of Alaska Oil and Gas Conservation Committee Permit to Drill, Form 10-401 in triplicate with triplicate copies of location plat and contingency plan. ,/~;~:-d/~- Exxon Check No. F13271 dated November 1, 1976 in the amount of $100 ~/~.~]~'~".~'L in payment of the required permit fee. ~H~/~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 prevention, and measures which will be taken to prevent erosion. (2) Plats prepared showing the routes to mobilize the construction equip- ment using rolligons and to move the rig over Beaufort Sea shore ice as well as possible gravel and water sources. It is our plan, State approval permitting, to commence location work in late November, 1976, ~ ~.~r~ ~~. ~.~..~r,~t~s are to be commenced during February, 1977. ' ~ -. , ~i~:. i~., ~"'~ Li'~' ..... il i~ Sincerely, OCR:rll xc: EPA Region X (Danford G. Bodien) w/eric. A DIVISION OF EXXON CORPORATION · . .sZv. ~, --..t-, ?l STA,.. OF ALASKA · .OIL AND GAS CONSERVATION COMMITTEE' PERMIT TO DRILL OR DEEPEN DRILL [] DEEPEN l--I Wildcat }dA),IE OF Exxon Corporation P. 0. Box 2180, Houston, Texas 77001 LOCATION OF WELL ..... "" ' 1320' NSL & 660' WEL of Sec. 32, TION¢ R2.3R:~'UPt~' At ~ro~d prod. zone North Slope, Alaska ,UltMIF Ill -1-tlll'lAk-Alr. Nv~rfe side {~ DISTA~NCE IN MILES AND DiRECTiON ~iO,~! NEAREST TOWN OR POST OFFICE' 50 miles east of Deadhorse No. 50-089-20005 {. L. EASE DIKqIGNAT1ON K.YD SIiIUAi, NO. ADL ~756o 1. IF INDIAN. ~~E Poin~ ~omson 9. WELL NO. Exxon No. 10. ~ELD AND POOL. OtJ WILDCAT Wildcat HOLE O~ECTIVE~ Sec. 32, TION, R23E ~4. BOND Oil & Gas-Conservation Bond S~-,,~,~d'o~ ~-o 5134049 (State Bond Fi~e No. B-1-4) ~. DISTANCE FROM PROPOSED' il6. HO. OF ACR~ IN LEASE ~OCATION TO NE~EST I PROPERTY OR LEASE LINE. ~ .... {AI~ !o nc-arc~ dr~ ~:~. !f anyl ,,. ~is~'~xc'~ r~.o~.~ ~,=~ ~oc.~0~'.' - "l:~: ~°~os~'u~ · O NEARE51' WELL DR:LLING. CO~PLET~, i o~ ~,~D rom ~. Approx. 16,000' J 14 ~ 000' ' ~ of Mob~?_West StaShes No. ~ [~L ~VAI'IONS ~Snow ~ae;ncr DF. RT. CB. crc., ~: Aoproximately 11' GL P~oPos~D CASING AND imco, $100,000 TO THiS WELL j ~. ROTARY OR CAELE TOOLS Rotary j ~. APPROX. DATE WORK WILL STAR November 15, 1976 ~£OF HOLE SIZE OF CASING [ WEIGHT PER FOOT j GRADE S ~'i~TING DEPTH quantify of Cement ~ ~0. '.'~"36,,×32,,×2~,' Z'~L~ated./:{efrige~:~{ed 85' ..... TO S~?~ce ...... 26" 18-5/8" 96.4 K-55 800' ' ' To ~urfaCe ...... -17-X/2""i3:3/8" .... 6i./7~ K-5~/N,.Sb 33~' ~'. To surfak? . 12-l/~"] 9-5/8" 20 .~00-95 ±9000' ...~ppr°x. top of cement ~ 6000' ., 8-1/~'[ 7" 35' S00-95 ±1~,000' 500' above potential 'hydro'carb~. z~ zone 6" 4.-1/2" - 15.1 :.~ 0-95 1~,.000' . SubsUrface In$ection: It is 'planned to Set' the 9'-5/8" casing before breakup' t6 ~rovide for disposal of wabte-water into salt water sands projected to occur between the Surface casing shoe at '33'00'.'--and top.-o-f tt~e 9'-5/8"~'ce~'ent k't a~p~oXimately 60'00":' A wellb°re sketch is attached which ilEGb, trates:t-he ~gel'l' design'.with-pr$vision's fbr' preve'nting-casing collapse if commercial production is established. Blowout..Preventers: A" 20"' a~ntntaD' %'lowoUt': pre~en{er 'with"a ~iverter line w.{ll-'be installed · on the insulated 'conduc2or:and the 18-5/8'" conductor;:the diverter will be remOv'ed 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 preventerJ 'will be installed on the 13-3/8"' and 9-~/8"' casi.ng. ~ ABO%'I: SPAC~- ]~.---RIBE P~OPOSI~T) PROG~.J~%t: Yf {~r~l~os~! Is to deel>en 'give data on ~resent pr~uductlve zone ~nd pro,~o~-d( Cont. on ' .~e~' pro'du~li~_~e~o:P..e. If. ~-.ro~.~.t ts to o7:11 or o<-~p~n cl~ec,..konaliy, Slve pe.rtinen? ~.al~ on sdbsur/ace l~c~t~or~s and rne&sui~d and UUeattached sheet ) · =-~'".-. '-, , , .... ,/ Jl his Spa e for ~ ' c SLt ~f::. u ~/ CO,' I~O.'. OF APP iOVAL. IF ANY: ~~ ..v.~. ~c~ co~ 50-089-20005 ~-' 76-85 · December 6, 1976 ~'lr~MIT ~0= : APPROVAL DATE '"~ / /~~ Decesber 6_ 1976 I I I t Z .5 30 'T- 21 I II I i I I i PT THOMSON :C~% ' ' ' I ~. ::: - _ ' ~~EXXON NO I POINT THOMSON UNIT LAT = 70 10'2695' t"~"~ -';: LONG.:I46°20 14.62 I SCALE: I"= IMILE CERTIFICATE OF SURVEYOR l 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. SURVEYOR Date T. I0 N. T. gN, c, J, R. AS- STAKED EXXON No.! POINT THOMSON UNIT Locoted in s E I/4 P R 0 T R A C.Z~ [.~.. S_~. T_~Z:~_¢.,.~Z~ 9,MJ&Z~fi Surveyed for EXXON COMPANY U.S.A. Surveyed by [ M. LINDSEY ~ ASSOC. LAND A HYDROGRAPHIC SURVEYORS 2502 West Northern Lights Boutevord Box .E.,XXON POI N I 1HOMSL)N..UNI I BORE SCHEMATIL PERMAFROST CEMENT TO SURFACE 36"x 28" INSULATED CONDUCTOR C~ PERMAFROST CEMENT TO SURFACE 18 5/8" CONDUCTOR C~ 800~ PERMAFROST CEMENT TO SURFACE 9 5/8" HOWCO FO C~ 2000' (to circulate non-freezing mud) 95/8" HOWCO FO C~ 2500' (to cement 9 5/8"x 133/8"at obndt.) 13 3/8" SURFACE C~ 3300' INJECTION INTERVAL TOC C~ APPROX. 6000' 95/8" PROTECTIVE C~ APPROX. 9000' CEMENT INTO 9 5/8" 7" PRODUCTION C~ APPROX. IItO00' CEMENT INTO 7" 4 I/2" LINER C~ 14tooo' MidWay Islands '.~ Ar~o I . Gull I Niakuk $ Prudflo, Ba~ Pier, Heald ..',, // 6~ Dinkum Sands Howe I Pt 6 Pt Brower APPROx. ICE ROAD Lion Pt Lookou~ 6 - Pole- i St'°cktOh Islands . ' Island ~bin Reliance Pt \~ Pole Island .~' LEGEND- POSSIBLE GRAVEL SOURCE Bullen Pt ~:.. Bullen ,,. ..... ,., Alaska I Duchess I Challenge I ................. · .......... North ~'~ ~:!' '.:..-,~..~ Star I ~aguir,e "l~lan(~s .. E~* MIKKELSEN Pt Gordon EXHIBIT "B" ~Thomson -Gra~ -~d~ Sou~ WEST STAINES No.' · ~ PROPOSED ICE ROAD 8~ ROLLIGON EXXON COMPANY U.S.A. HAUL ROUTE BY F.M. LINDSEY 8~ ASSOC, ~APPROXIMATE LOCATION OF GRAVEL ISLAND, NOT SHOWN ON GEOLOGICAL SURVEY MAPS. POINT THOMSON (GRAVEL SPIT) SCALE I000 5&O 0 It IOOO FEET SECTION 33, T I0 N, TRI. STA, "RODA"---~./~ R 23 E, U.M. TUNDRA SEA LEVEL A-A B-B C-C TYPICAL CROSS-SECTIONS ( NOT TO SCALE ) NOTE: Excavating Pt. Thomson to 1.0' above MSL would yield an estimated 20,000 Cu. Yds. of Gravel. -r- Areas of known Accretion. EXHIBIT C PT. GRAVEL 21 THOMSON REMOVAL AREA FOR EXXON COMPANY U.S.A. BY F.M. LINDSEY ~ ASSOC. CONTINGENCY PLAN EXXON NO. 1, 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 operation. 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 a pollutant. The customary reserve pit will be replaced with (1) a cuttings and refuse pit for containment of excess drilling fluid, drill cuttings and drainage around the rig, and (2) a contingency pit which will be used only in case of emergency such as a severe well control problem. The above two pits will be constructed with a minimum separation of 30' to prevent migration of liquids after breakup. 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 produced hydrocarbons resulting from well testing or in the event of an upset and any waste oil recovered from the drainage system. Fuel will be stored in steel tanks in the imper- meably 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 anticipated pressure transition zone, or before breakup, and cemented to isolate the salt water sand sections from below the surface casing shoe to approximately 6000 feet for injection of melt and waste waters collected in the pits. It is planned to maintain the' liquid level in the refuse pit, sanitary waste pit, sanitary holding pit and burning pit below ground level after breakup to prevent migration of any liquid out of the pits. The contingency pit will be maintained at a minimum level to provide for containment of well fluids in the event of an upset. Ail pits will be pumped out to a minimum level and waste water in- jected into the injection zone before abandoning the well. The selected drilling contractor will be required to develop a comprehensive SPCC plan to prevent pollution as the result of any drilling rig operations. In addition to drip pans under the engines and rig machinery, the rig area will be within a drainage system to direct any rig waste into the refuse pit. Ail 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. Well.Control is the controlling factor in well design and opera- tional planning. Sufficient data are available to plan the well for evaluation of the geologic objections, provide for subsurface disposal of waste water and conduct a safe drilling operation. Abnormal pressure technology will be used to 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 well "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 following basic procedures will be followed: 1. Divert flow to burning pit as the first defense against spill. Switch the flow to the contingency pit when the safe working level is approached in the burning pit. The design capacity of the contingency pit is 35,000 bbls · which should be maintained at a maximum, practical working capacity at all times. 2. Make preparation for drilling a relief well from a site along the coast. 3. After discussion with proper governmental agencies and Exxon management, ignite the well if the situation'warrants. Major supplies of mud, cement, casing, fuel and miscellaneous supplies will be transported over winter roads or moved directly to location, by Hercs before spring breakup. After breakup, light consumables will be'transported by Twin Otter, and helicopters will be used to move equipment too bulky for the Otter. A Rolligon will be on location for any local movement of water or fuel as permitted by land conditions. Equipment and material stockpile requirements are tabulated below: EQUIPMENT REQUIRE~ENTS - (Normal Operations) 1. Aircraft - Twin Otter will be used'to transport material and supplies up to a maximum 4,000# payload. All personnel will be moved via Twin Otter. An all-weather airstrip will be maintained at the site to facilitate summer ~vin Otter operations. 2. On-Site Support Equipment 1 - Rolligon with detachable fuel and water tanks 2 -966 Front Loaders 1 - Combination Flat Bed Truck with winch 1 - Bull Dozer MATERIAL STOCKPILES 1. Mud Supplies CONFIDENTIAL a. Barite - 10,000 sks. b. Bentonite - 3,000 sks. c. Lignosulfonate - 500 sks. d. Lignite - 500 sks. e. Lost Circulation Material - 500 sk-s. f. Casing Pack Material - Minimum Requirements for 150 bbl. mixture. 2. Cement - Minimum of 3,000 sks. of Class G. 3. Casing & Tubing - 14,000' - 7". 35#, SOO-95, SFJ-P & BT Casing 3,500' - 4 1/2", 15.1#, 0-95, 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 & Collars 14,000' - 5" 19.5#, Grade E&G 14,000' - 3-i/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 RMH/kc 10/29/76 -3- Blowout Preventers (cont.) ! ~i !!~!]-~i! ~ il~I~ ~! i~! ! A 7-1/16", lO,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 component is changed and at least once weekly thenafter; all BOP's will be function tested each trip. Drilling crew proficiency tests to perform well shut-in procedures will be performed at least once each week with each crew. 1I* /KII" ' 13R l~ ¢_.C~ING OUT LEIL INSPEC'I' ION PORT INCLINED DOOR rT:-73rTT! ...... :T)~ _-:'.._~ IF'":_%1 ['%7%1L-7_ ~'7...'J[ :1 T, 3L.O. · , -tg c.o, DOO :S lO'X lO" , , ---'TRANSVERSE SECTION OF PRIMARY- _ NOTE5: I.' BREECHING OUT BACK AT P__,OTTOM ONLY. 2. BURNERS, INSPECTION FORT & CwT. MAY BE EITHER SIDE TO SUIT JOB CONDIT$ON5. '3, ls~o-P UNIT SHIPPED COMPLETE ON _~KIDS AS 4. 1~o FIELD ERECTED UNi'T WITItOUT 5KIDS .5. GA.5 OR OIL. [~URNERS OPTIONAL AT E×q'IRA .. $ ..... _ · ,, _ .... ......... ,., i .... iii .... _-- , ,., ,.........1, ~ , · ,t4.' 2,<,83' G~t:ENL~A! AVENUE · · . OurNew l'l~3m~ Is: MI:INAULIN- 5KIO$---,-~()pr/or~AL AT EXTP~/\ tO.ST) ~312) 43~.~700 14t4l ?0~.3,3u0 o . The .MODEL 1800 Pollution Packer compacts 2'4, Cubic Yards of loose wastes into a 17.9x 19.9x17.9 inch cube or box. It bales, bags or boxes all types of waste and refuse. A poputar size for minimizing tim9 and labor costs in the medium volume area of waste generation. Super quiet operation; total safety design. One year warr.anty, against defective workmanship and manufacture on all Pollution Packer .com- 'pactors, a-l[ sizes. Model ' ' ~ ' ' .'~ ., :';::15 ' ;" "' i..,.......~ ., ... · · . ^MPERAGE .... ' ..... '; ....'..'.'L':'.'.'.: .8.8/4.4 ~] MACHIHE WEIGHT, Lbs...'~'. L ....... L ;'.'.2 :BOx SIZE ........ ~AACHh~E SIZE: ' .. '-- Width. :...-.'.... .... .FINISH: Dover White, Vinyl, Acid-Resistant, .. "-~t 400 F. Entire c~bin.t CASTER ~/H~ELS .................. ' - Locking Das~gn HSF-Approved C STEEL FABRICATORS · · . e o. · · · o. , o T'r~_A T'ED EFFLtJEI~I~ ' ~TO EN V I ~ON M E,N"r" · WASTE- WA, .R INLETx RAW\I C NJASTE FLASH. MIX TANK SLUDGE LEVEL SENSOR · , 7'-0' BELT FILTER )GE PuMP (OPTIONAL) PRESSURE FILTER --PRESSURE FILTER FEED & BACKWASH PUHR SURGE TANK i FINAL DISCHAR~ VALVf BACKWASH WATER TO WASTE ,~DrSCHARGE LINE OUTLET AN~E VALVE ~ FLOCCUL ATOR - CLARI F IER I CON,TROL PANEL· DISINFECTANT CHEMICAL' COAGULANT CHEI'IICAL ,TANK & FEEDER ;ANK & FEEDER · I I i-'' ~ ,,, liLlE; f[~ I ENGINEERING DATA CaPacity Length Width Height ShiPping Total Pipe..Connections - · :GpD ........ , ..... b ..... c ..... W.t: (!b.s:) .. Horsep.0wer, , . Inlet Outlet 7,000 8'-0" 7'-0" 8'-8" 5,700 2.75 3/4" 3/4" 25,000 20'-0" 8'-0" 8'-8" 1.5,000 3.50 1~'" 1" PO'f/ER REQUIREMENT:...~2~ V, 3 Phase, 60 -lertz (-- 'Z.'.~ O DESCRIPTIONOF OPERATION sewage is pumped from an equalizing tank (not shown) by raw waste bio. ~4007 ' ~4025 pump (1) to flash mix tank (2).Coagulant feeder (3) delivers a proportiorted cmount of chemical solution to the flash tank where intimate contacting is ¢omplished by means o,~ high speed itator. From the flash mixer, the waste- water flows by gravity into the floccul- ating section of clarifier (5)where gentle agitation promotes floc formation. As sedimentation takes place in the c!ari- tier the settleable solids are collected and are pumped (6) to disposal. A dis- posable media filter (7) is o~iered as an option for sludge concentrating prior to ultimate disposal. The clarifier effluent flows up[Iow through granular carbon adsorber (8) for removal of dissolved or~nic materials and into surge tank (10). Adsorber ator (9)proportions air into the bottom of the odsorber, maintaining an aerobic fJuidized carbon bed. Filter pump (l l) delivers the waste through pressure fil- ter (12) for final polishing. Disinfectant feeder (4) 1lumps a controlled amount of chlorine solution into the surge tank for disinfection. T-PRO SYSTE.s~S DIVISION ' :STREET & MITCHELL AVE. ~SDALE, PA. ].94-:6~-'/--'~_" ~--'~'~::== :--~' · · · o ~, UNIT OF' M[T-P.qO WATER TREAT~t£NT CO~P. ,g~l ~ ' O J972 A~ET-PRO SYSTEMS DIVlSION ~dn~ad in U.S.A. · ~XAT IS IPC? IPC (Independent Physical-Chemical) treatment provides cn exceptionally efficient means of treating wastewater to meet the increasingly stringent demands of the regul- olory agencies as they attempt to preserve our nation's waterways. The pro:ess is oroven, simple and easy to control, involving: CHEMIC,~L FEED- the..addition of ¢o<~guTant chemical with rapid mixing; FL. OCCUIATION/ CLARIFICATION - coagulating chemical precipitates i~osphates and gathers settleable and suspended solids tc~ produce rapid settling floes (:nd a clear overflow; CARBON ADSORPTION - for the removal of dissolved ~9anic materials; F!L. TRATION - for removal of ~he rea toothing suspended solids; and DISINFECTION - for the geslruction of harmful bacteria, INDEPENDENT PHYSICAL-CHEMICAL WASTEWA TER TREATMENT SYSTEM .SERIES 74000 FEA 1) 2) 3) 4) 5) 6) TURES: " Highest degree of treatment Inse~sitiYe to loa~l changes Small land re. quJrement Portable - can readily be movecJ from one location to another Immediate, high quality effluent on start up .. Extreme flexibility Simple op. eration · WHERE IS IPC USED? '[fie result is a sparkling c[ear effluent extremely low in B.O.D., suspended solids and phosphates.' · Physical-chemical treatment is not depenc[ent on 61oleg- leal action. It is insensitive to "shock" loads, temper- ~ture or strong wastewaters that unbalance biological systems and permit wastes to be discharged into our llreoms with little or no treatment. Housing Developments - Easy to install and requiring little land area, the plants can be permanently located or moved to other developing areas if necessary. No need for a developer to wait years for a regional system to be installed in order to develop valuable property. Recreational Areas - The ability to produce a high qual- ity effluent during changing load conditions makes IPC ideal for these applications where high weekend and iow weekday loads c~re expected. On-off operation 'is also possible with IPC treatment. Mobile Home Sites - Minimum space requirements and lack of odors permits the utilization of valuable property for more units rather than using this property for a larger, less efficient bioioglca[ system. Schools - Simplicity of operation is of extreme import- ance since manpower is usually at o minimum end maint- enance personnel must perform a multiplicity of duties. Fluctuating loads that may require the close aztention of a biological plant operator to prevent an "upset" will not effect IPC plant operation. Pilot Plant Application - Compact, easy to instrll and reasonably priced, the Met-Pro 14000 Series plants are excellent for engin:ers to gather valuable d~tc to use in lhe design of larger IPC sys:cms. · · 'STEEL FABRICATORS MADE THE SKID-MOUNTED HOUSING AND .' INSTALLED THE TREATMENT PLANT AND INCINERATOR. .. View showing the container roof re.. moved which reveals the clean, Compact assembiy of the Mel-Pro plant. Cornplete;y piped and wired On a skid only 7' wide by 8' long, It ~eighs only 5,800 pounds. Sene for detailed information, or phone: 215-35~-1671 MET-PRO'Systems Division Street & MitchelI Avenue, Lansdale, Pennsylvania 19446 UNIT OF MET-PRO WATER TREATMENT CORP. .. Met-Pro's Model 14007 physical-chemical treatment plant, in this instance containerized, being unloaded in Alaska for transport to a drilling 5ire on the North Slope, What's good for advanced waste treatment on Alaska's North Slope can be equally good on any site throughout the 50 states of the, U.S.A.. and beyond. The prob;em for the Alaskan .venture was to handle all the camp wastes, and produce a high quality effluent imm.3di- ately upon startup. Discharging direcdy to lhe tundra, a sparkling clear, vir[ualty contaminant-free effluent was a strict requirement. Thus. the Met-Pro Model 14007 physical- chemical treatment plant ;,;as first eva!ua:ed for reliab;.lity, then selected ~nd instal;ed. A high quality effluent was obtained immediately on st~rtup and prompted the operator to remark, "it looks like drinking water." And he wasn't far off. With an exceptionally high incoming BeD, better than 97'% removal is currentiy being at~ained~consistently. The Met-Pro Model 14007 is designed for intermittenl: opera- tioa and may be shut down and restarted at will while main- raining a high quality effluent. This makes it ideal for small communities, responsible developers, trailer camps and contractors. $o. what's good for Alaska. can be good for you. Anywhere. · [~'Y:;T,'-H.S DI'~'IStG.u. DISTRIBUTED IN ALASKA BY ;STEEL FABRICATORS '213~ Railro~J Avenue ~nchora~2e. Ala~,a 99501 I907) 272-5461 STEEL FABRICATORS COMPANY. U.S.A. POST OFFICE BOX 2180. HOUSTON, TEXAS 77001 November 1, 1976 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION CRANDALL D. JOi'-,IES MANAGER Exxon No. 1 Point Thomson Unit Exploratory Well, North Slope Alaska (Stipulation of Settlement Order A76-184 CIV) U. S. Environmental Protectiom Agency Region X 1200 Sixth Avenue Seattle, Washington 98101 Attention: Mr. Danford G. Bodien, ~P. E. Chief, Water Permits Section Dear Sir: Exxon Corporation has this date filed an application with the Department of Natural Resources to drill the captioned well. The well will be spudded in late February, 1977. Under Stipulation 2. (c)(1) of the Stipulation of Settlement Order (Civil Number A76-194 CIV), we are directed to provide contemporaneous distribution to the U. S. Environ- mental Protection Agency of copies of any drilling permit applications to the Alaska Department of Natural Resources. You will find attached hereto such application and material related to the captioned well. The operational plan. under which we will proceed contains redun- dant safety features designed to preclude the need to discharge potential pollutants into navigable waters of the United States. Further, the operations is to be implemented in such a fashion as to .meet all stipula- tions of the subject order. Although the details of our operation are covered in the attached materials a synopsis of the salient points of the operation related safe disposal of potential pollutants is as follows: 1. The subject well location was chosen as the optimum geological position for penetrating prospective sub- surface hydrocarbon reservoirs. The required drilling pad for the operation is sited at an average elevation of +11 feet, well above any recognized storm high water levels. It is approximately 1500 feet from the closest point on the Beaufort Sea coast and about 300 feet from a freshwater inlet to the Beaufort Sea. 2. Operations will be conduCted ~hrough the winter and into the summer. Equipment move in and pad construction is to A DIVISION OF EXXO,",I CORPORATION Mr. Danford G. Bodien -2- November 1, 1976 start about December 1, 1976 and the well spudded in late February 1977. Protective pipe will be set in mid-April which will provide access to a thick, porous saltwater bearing zone for subsurface injection capability, well in advance of the anticipated June 1, 1977 thaw and ice breakup period. A State permit application for subsurface disposal is included with our drilling permit application. Drilling will continue until targeted potential hydrocarbon zones are evaluated in early sunm~er. Operations will then be suspended. During the winter of 1977, the rig, support equipment and supplies will be remOved, pits backfilled and crowned and the location left clean. 3. The design for the subject operation is such that planned discharges of pollutants into the navigable waters of the U. S. will not be required. This will negate the need for a NPDES permit application for new point source discharges. The disposal of attendant wastes in this multiseason Arctic operation will be as follows: a. Drill cuttings, waste mud, boiler blowdo~ solid rig waStes and will be directed to and contained in a cuttings and refuse (reserve) pit. The fluid level of this pit will be maintained below ground level for positive hydrostatic flow of any ~ermafrost melt. This will be accomplished by subs~ace~i~o'~'~%~ T~aPa-' ~i'{~-~{~']'~"~'~ was~sWili be'°b~ained well in advance of its possible need after the sun~er thaw. If such capability'is not attained, drilling will be suspended before the thaw and not resumed until after freeze-up the following winter. The backup system is a large contingency pit isolated from, and having no connection to, the cuttings and refuse (reserve) pit. It is expected to fill with snow during the winter and thereafter, receive some permafrost melt water. During routine operations, no other materials will be allowed into this pit. Some of this collected water may be used for rig makeup water. In order for the pit to be useful in an emer- gencY, it must be periodically drained of its con~ents. It is planned to sample and conduct routine tests on waters from the contingency pit as well as nearby lakes to assure that melt water in this pit is similar Mr, Danford G. Bodien -3- November 1, 1976 to other, naturally oCcurring waters. The primary _?~q~ipto~.maintain, emergency capacity by',,disposing qf.me!t~water from th~n~,ingen~y pi.t ~y ~ub~.~r~ disposal. Our secondary or emergency plan is to inter- -m~~Iy pump uncontaminated (confirmed by laboratory analysis) melt water into the adjacent inlet. Should this contingency pit ever be used to temporarily contain emergency wastes, disposal therefrom would be through sub-surface injection or by disposal to the fresh water inlet after applying for an NPDES permit. Additional points of the contingency plan for control- ling unauthorized discharges are shown in the attachment to the letter to the Director of the Division of Conser- vation. A copy of the drilling contractor's SPCC Plan for the rig will be mailed to you before proceeding with drilling operations. b. The five foot thick gravel pad will have a drain system circUmscribing areas normally subject to contaminated wastes of wash water/percipitation f~illing in the rig area. This flow will be directed to the refuse (reserve) pit. Snow and ice will be cleared from the uncontami- nated pad area outside of this drain system and pushed off the edge of the pad. Good housekeeping practices will be followed to keep this area clean. c. A flare (burn) pit will be used to consume any oil skimmed from the reserve pit or formation fluids. The fluid level will be maintained below ground elevation. Compacted and bagged solid kitchen wastes will be placed in the pit before it is back filled. d. ~S~g~.,~~.~r will be processed through a Met- Pro Unit. Solids therefrom will be incinerated; treated liquids will be retained in a sanitary pit. The fluid level in this pit will be maintained below ground ~e~'~'~ionby-~nbs~fac~e'~isp0~sal and any liquids remain- i~g"~i~the'pit~at the time drilling o-per~tions for the ~I1 are comple~ed~W~li~b'e' injected ~t0~ t~e pu~purface. ~~'~a'a~-i$~i~-r~"~e~ liq'ui~s'~{il~ be"' added to the pit the following winter during the rig dismantling operations. The pit will then be backfilled. e. Combustible garbage and trash will be incinerated. f. The water supply for this operation will come from Mr. Danford G. Bodien -4- November 1, 1976 natural surface ponds; a sea water/fresh water con- version unit will not be required. Exxon submits this plan to you as being both resonable and responsive to the letter and spirit of the subject Stipulation and Settlement Order. As you know, an operation of this nature involves a significant amount of lead time to assure that we meet our target spud date. We welcome any suggestions to our plan or the conclusions expressed herein, otherwise we intend to proceed as outlined above. Sincerely, OCR:rll xc: EPA Anchorage bxc: Messrs. J. L. Loftis R. W. Bybee W. J. Whaley C. M. Harrison H. J. Flatt w/attach. J. O. Langley w/attach, Judd Miller, Jr. M. Taylor w/attach. C.. A. Tucker J. E. Phillips T. M. Frois J. W. Van Ert W. R. Fuge, Jr. W. M. Selvidge R. Riddle w/attach. COMPANY, U.S.A. POST OFFICE BOX 2180 ° HOUSTON, TEXAS 77001 November 1, 1976 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION CRANDALL D. JONES MANAGER Re: Exxon No. 1 Point Thomson Unit SE/4 Sec. 32, T10N, R23E, UM A.D.L. 47560 North Slope, Alaska Mr. Ernest W. Mueller Commissioner Department of Environmental Conservation State of Alaska Pouch O Juneau, Alaska 99801 Dear Mr. Mueller: We have this date filed with the State Department of Natural Resources, Division of Conservation, our application to drill the subject well and have filed with the Division of Minerals and Energy Management our plan of operation. Said plan of operations describes in addition to the site construction, rig move and supply program, the plan which we propose for potable water supply, waste and sewage disposal, pollution prevention and measures which will be taken to pre- vent erosion. In addition, however, we are repeating herewith the details of the proposed operation which we believe will be of principal concern to your department and respectfully request your approval thereof. 1. Water Supply and Sewage Disposal Permit The camp system will be that which is associated with a drilling rig which is yet to be selected. Sewage and gray. water from the kitchen and shower areas will be discharged in separate lines and will be in- troduced into a Met-Pro series 14,000 waste disposal unit. A. Met-Pro Series 14,000 Unit This unit will separate the solids from the system by physical- chemical transport of the solids to an incineration system and will destroy the solids by incineration. Comminuted sewage is pumped from an equalizing tank by a raw waste pump to a flash mix tank. A coagulant feeder delivers a proportioned amount of chemical solution to the flash mix tank where intimate contacting is accomp- lished by means of a high speed agitator. From the flash mixer, the wastewater flows by gravity into the flocculating section of clarifier where gentle agitation promotes floc formation. As sedimentation takes place in the clarifier, the settleable solids A DIVISION OF EXXON CORPORATION Mr. Ernest W. Mueller -2- November 1, 1976 are collected and are pumped to disposal; a disposable media filter is for sludge concentrating prior to ultimate disposal by incineration. The clarifier effluent flows upflow through granular carbon adsorber for removal of dissolved organic materials and into surge tank. Ad- sorber aerator proportions air into the bottom of the adsorber, main- taining an aerobic fluidized carbon bed. Filter pump delivers the waste through pressure filter for final polishing. A disinfectant feeder pumps a controlled amount of chlorine solution into the surge tank for disinfection. The unit is designed to comply with all requirements set forth for the water quality in the Alaska area. B. Burnable garbage and trash will be incinerated through the incineration system provided for this disposal in the Met-Pro Unit and an independent separate Met-Pro Incineration Unit. C. 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. D. Potable water will be obtained from a lake near the location and processed through a Met-Pro Water Treating Unit. E. It is our intention to activate the 60-man camp at the location during December, 1976. Attached are descriptive articles as well as drawings and flow diagrams of the Met-Pro Unit. 2. Air Quality Control Permit In addition we wish to apply to you for permission to construct an earthen .flare pit 60'x 60'x 6' deep in which all hydrocarbon test liquids will be disposed of by burning and specifically request an Air Quality Control Permit to Open Burn, similar to that issued by your office on February 6, 1975, in re the Canning River Unit No. B-1 well and that issued August 19, 1975, in re the Alaska State A No. 1 exploratory drilling operation on Flaxman Island. In the event any further information or materials are required in your processing of this request, please do not hesitate to contact this office. As we anticipate a commencement of the subject drilling operation, the early approval of the above features of the plan of operation which are most likely to be of primary concern to the Department of Environmental Conservation will be sincerely appreciated. Sincerely, OCR:rll Attachment xc: EPA Region X (Danford G. Bodien) w/enc. ~. ECK LIST FOR. N ¥~.,LL PERMITS '~i'r' Company . Yes No Remarks ~il..~ ~iIs t.h.e permit~'fee'~attach~ed ......... '. ' ,A~.~:-__ 2.- Is'well to be located in a defined pool .... ........ ~... / X~. 13. Is a registered survey .plat attached ............ .... /~ 4. Is Well 'ioca=t~_d 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 ' . o . .~ ...... ~ 9. Can permit be approved before ten-day wait ............. ~F~J( · lO. Does operator~have a bond in force l l. Is a, conservation order needed . ' ........... ~ ~/~4F-~ i2. Is administrative approval needed 13. Is conductor stroh§ provided .... ~14. Is enough~ cement used-to c~rculate on conductor and surface . - 15. Will cement tie ~n surface and intermediate or production strings 16. W~I~ cemeht cover all known productive horizons ........... 17. ~1 surface~cas~n~ protect fresh 18. ~1~ all cas~n~ ~ive adequate safety ~n collapse, tension 19. ~oes BOP[ have sufficient pressure Far,n9 . .~~" ........ Approval Recommended' Geol o.qy Engi neeri ng' TRM HWK /~-~4~. ~K~ Hiqiq- JAL LCS ~ JCM ~/~"! Revised 1/15/75