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Home My WebLink About180-101 Image ll'oject Well History File Cover e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. / ~) O- ,/ 0 / Well History File Identifier [] Grayscale items: [] Other, No/Type OVERSIZED (Scannable) [] Maps: Other items scannable by ,~ Poor Quality Originals: y Other: NOTES: BY: BEVERLY ROBIN VINCENT ~HER~) MARIA Project Proofing .. WINDY large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds .X/ Other BY: ~ ROBIN Scanning Preparation BY: [~Y VINCENT SHERYL MARIA WINDY C~ x 30 = 'c~-~(~ + ,~'" = TOTALPAGES°~'-~'- ROBIN VINCENT SHERYL MARIA WINDY Production Scanning Stage ' PAGE COUNT FROM SCANNED F,LE: ~ ~/"~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~"~ES NO BY: BEVERLY ROBIN VIN~ MARIA WINDY DAT / Stage 2 YES NO BY: (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PACE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) IF NO IN ST_~.~E 1, PAGE(S) DISCREPANCIES WERE FOUND: ReScanned (~,dlvid,,al page [special atte~ti~t~] .~canning completed) RESCANNErl BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE; IsI General Notes or Comments about this file: Quality Checked (do.e) Iii i1 1)11)1)1)1 12110102Rev3NOTScanned.wpcl UNSCANNED, 4VERSI7FD MATERI.ALS AVAILABLE: ~ ~ Q / FILE # S(r ~ ~-~~. 1~~'I.A ~' ~~~ ,'~ ,'~ ~~ . To request ~ny/all of the above information, please contact: A~laslca Oil & Gas Conservation Commission ~333 W. 7th Ave., Ste. 100 ~ Anchoi•agc, Atasl{a 99501 Voice (907) 279-1433 -Tax (907) 276-7542 ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$. GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (90B 279-1433 FAX: (9071 276-7542 December 2, 1999 R.C. Gardner Fairweather E & P Services, Inc. 715 L Street Anchorage, Alaska 99501 Re; Location Clearance Work on Exxon's Alaska State Wells Dear Mr. Gardner: Reference your letter of November 17, 1999 on this subject. Our Petroleum Inspector Lou Grimaldi reported on the September 9, 1999 inspection trip to various Exxon State wells - copy attached. His report of the inspection trip states: "SUMMARY: C 1,,--,¢,..and G2 locations still need some work. Based on my observations, I recommend the A I{DI~ and F1 location clearances remain approved." Your assessment of the work that needs to be done on Exxon's Alaska State Wells C-1 and G-2 closely parallels what Mr. Grimaldi reported..-ks such, we anticipate that this additional work will be completed in the next few years. If you have comments, please contact me at (907) 793-1226. Sincerely, Blair E. Wondzell,'~.E. Sr. Petroleum Engineer Enclosure CC' D. Michael Baker Exxon Company U.S.A. I-ak-st-wells.doc D:"Pics'.FlaxmamFLAXMAN G-2 CELLAR.jpg {locai}- Microsoft Intemet Explorer Page 1 of 1 I 1/17/'99 12:21'40 PM D:',,Pics,,Flaxman'NORTHSTAR F-1 PAD.jpg tlocal/- .Microsoft Intemet Explorer Page 1 of 1 11/17/99 12:21:21 PM D:'Pics",Flaxman,,FLAXMAN C-1 VSP.jpg (local)- Microsoft Intemet Explorer Page t of l 11 17.;'99 12:21:49 PM D: Pics',Flaxman',~FLAXMAN C-I PIPES.jpg (,local)- .Xlicrosoft Intemet Explorer Page 1 of l l l. 17799 12:21'57 PM D:\Pics',Flaxman'xFLAXMAN C-1 Plastic.jpg (local} - Microsoft Intemet Explorer Page 1 of 1 11/17/99 12:23:36 PM MEMORANDUM TO: Robert Christensor~'i~~ Chairman State of Alaska Alaska Oil and Gas Conservation Commission DATE: September 10, 1999 THRU' Blair Wondzell~a.~ P. I. Supervisor ti FROM- Lou Grimald ,~'~.~ SUBJECT: Petroleum Inspector Location Clearance Insp. Exxon Point Thompson Unit A1 PTD# 74-0014 D1 PTD# 80-0101 G2 PTD# 82-0208 F 1 PTD# 81-0140 C1 PTD# 80-0046 Thursday, September 9, 1999: I traveled with Mike Barker (Exxon), Gar Caruthers (CH2M Hill), and Bob Gardner (Fairvveather) to inspect Exxon's C1, G2, Al, D1, and F1 and locations in the Point Thompson Unit. I make reference throughout this report to Chuck Scheve's report dated August 3rd (see 199KHCFE.DOC) Alaska State C1: The C1 location still has at least 3 of the 6 pipes originally reported by Chuck, these are most probably deadmen used to stabilize the now removed communication tower. The rest of the location was clean and free of debris. Although there is still some remnants of the plastic underliner used during construction of the pad. This plastic is coming out in small pieces and should not pose a serious ecological problem. There is also a large casing stub at ground level that appears to be a Velocity Survey Pipe. I mentioned to Bob Gardener that this should also be removed. Alaska State G2: The G2 location on Flaxman Island was clean and free of debris. Exxon deepened the casing cut last winter and there was a slight depression where this was filled in. Due to the severe erosion on the North side of the island, there are three small diameter pipes and two heavy cables protruding from the eroded edge. These should be removed while being careful of possible contaminants held in the pipes. LOC CLEAR FLAXMAN ISLAND 9-9-99 LG.doc Page 1 of 2 Alaska State DI' The D1 location was completely underwater today. The V.S.P. mentioned in Chucks report was not visible even though we flew around the area for ten minutes. Alaska State Fl' The F1 location on North Star Island was clean and free of equipment and debris. The island is very smooth with evidence of sea ice scraping the top of the island. SUMMARY: C1 and G2 locations still need some work. Based on my observations, I recommend the Al, D1 and F1 location clearances remain approved. ! Attachments: Photos; FLAXMAN G-2 PIPES.jpg FLAXMAN G-2 CELLAR.jpg NORTHSTAR F-1 PAD.jpg FLAXMAN Col VSP.jpg FLAXMAN C-1 PIPES.jpg FLAXMAN C-1 Plastic.jpg LOC CLEAR FLAXMAN ISLAND 9-9-99 LG Page 2 of 2 D:'"Pics'FtaxmanxFLAXMAN G-2 CELLAR.jpg {local) - Microsoft Intemet Explorer Page I of 1 I 1;;17/99 12:21:40 PM D:',,PicsxFlaxman'NORTHSTAR F-1 PAD.jpg {local! - Microsoft Intemet Explorer Page I of 1 11/17/99 12:21:21 PM D:'Pics",Flaxman,,FLAXMAN C-1 VSP.jpg (local) - Microsoft Intemet Explorer Page t of l l 1 17;'99 12:21:49 PM D: PicsxFIaxman,,FLAXMAN C-1 PIPES.jpg (local) - .Xlicrosoft Intemet Explorer Page 1 of 1 11.17/99 12:21:57 PM D:x, Pics',FlaxmamFLAXMAN C-1 PIastic.jpg (local} - Microsoft Intemet Explorer Page 1 of I 11/17/99 12:23:36 PM Exxon Company, U.S.A. 1999 Remedial Work Completion Report Flaxman Island Area Well Re-Abandonment Project Beaufort Sea, Alaska Summary of Work Completed /~~-~'z~ The Exxon Flaxman Island Area Well Re-abandonment Project was conducted over two winter work seasons during 1998 and 1999. The project activities were extended into 1999 due to an unusually early winter breakup in 1998 and the addition of work tasks identified during the summer of 1998. Project operations were conducted at four locations (Alaska State A-l, C-1, D-l, F-1 ~ on Flaxman and North Star Islands and have been completed according to Exxon's work plans. Sundry well reports have been submitted for all well work on the Alaska State A-l, D-l, F-1 This report covers non-well operations conducted during the 1999 winter work season. Remedial work completed at the A-l, C-1, D-1 and F-1 well sites during the April and May 1999 work season included the following activities: . Removal of 994 cubic yards of diesel contaminated gravel from the Alaska State A-1 location on Flaxman Island. This contaminated material was discovered during a 1998 summer site visit to the A-1 location and scheduled for cleanup the following winter season. Additional details on this work are contained in the Exxon Company, U.S.A. Alaska State A-1 Former Fuel Storage Area Cleanup Report that has been provided to the AOGCC under a separate submittal. 2. Removal of three steel piling at the southeast edge of the drilling pad at the Alaska State C-1 location. . Removal of a 42 inch O.D. vertical seismic profile (VSP) casing to five (5) feet below the toe of the slope of Flaxman Island at the Alaska State D-1 location. This casing was discovered during a 1998 summer site visit to the D-1 location. , Removal of a 30 inch O.D. structural casing at the Alaska State F-1 location to 18 feet below ground level and more than five (5) feet below the toe of the slope of North Star Island. Waste Management All waste materials generated during the project were handled in accordance with North Slope Borough, State of Alaska and Federal regulations. Project waste materials were disposed of as follows: AOGCC sup report 99 1 Waste Material Quantity Handling and Disposal Recyclable steel 10,000 lb Transported to K&K Recycling, Fairbanks, AK. Wellheads, cemented 35,000 lb Transported to the NSB landfill. casings Transported daily to Deadhorse for final disposal at Camp trash 1,800 lb NSB solid waste treatment facility. Wellbore fluids, Class II 5 bbl Transported in secure tanks and injected at Pad 3 facility. Liquid Waste, Class I, 475 bbl Transported in secure tanks and injected at pad 3 non-hazardous, facility Diesel contaminated 994 yd3 Transported in secure containers to Alaska Interstate gravel Construction in Deadhorse for thermal treatment. Miscellaneous debris 5,000 lb Transported to Deadhorse for disposal at NSB solid waste treatment facility. Note: Above quantities are for 1999 operations only. Cleanup activities consisted of grading of all excavations and a thorough stick picking effort during demobilization operations at the end of each winter work season. Summer debris pickup work was also conducted following each winter work season. AOGCC sup report 99 2 E ON COMPANY, U.S.A. POST OFFICE BOX 196601 · ANCHORAGE, ALASKA 99519-6601 · TELEPHONE (907) 561-5331 PRODUCTION DEPARTMENT ALASKA INTEREST JAMES F. BRANCH PRODUCTION MANAGER - ALASKA June 15, 1999 Permit D-980186 Nationwide Permit 6 and Permit 4-820502, Beaufort Sea 333 Mr. Tim Jennings Unit Coordinator United States Army Corps of Engineers P. O. Box 898 Anchorage, Alaska 99506-0898 Dear Mr. Jennings: RECEIVED JUN 2 2 1999 Alaska 011 & Gas Cor~. Commlssior, Anchorao¢ During March and April of 1998, and April of 1999, Exxon Company, U. S. A. conducted and completed well abandonment and casing removal operations in the vicinity of Flaxman Island in the Beaufort Sea. These activities were authorized in the Department's March 6, 1998, letters to Exxon. Attached is Exxon's certification of our recent work activities at the AlaSka State D-1 well location on Flaxman Island under Permit Number D-980186. The work at the Alaska State D-1 location was in accordance with Nationwide Permit D-980186. Additionally, operations at the Alaska State G-2 location were in accordance with Exxon's individual USACE Permit 4-820502 and no certification is required. If you have questions or require additional information, please contact Mike Barker at 907- 564-3691. DMB:ddm Attachment c:~lata\winword~dmb~enviro~pttom~admin~tim jennings 6-7-99.doc c: Jim Haynes, DNR-DOG Gene Pavia, DGC Blair Wondzell, AOGCC Sincerely, / A DIVISION OF ExxoN CoRpORATION RECYCLE[ Enclosure 2 US Army Corps of Engineers Alaska District Permit Number: D-980186, Beaufort Sea Name of Permittee' Exxon Company, U.S.A. Date of Issuance: MARCH o 6 1996 Upon completion of the activity'authorized by this permit and any mitigation required by the permit, sign this certification and return it to the following address: U.S. Army Corps of Engineers Alaska District Regulatory Branch Post Office Box 898 Anchorage, Alaska 99506-0898 PleaSe note that your permitted activity is subject to a compliance inspection by an U.S. Army Corps of Engineers representative. If you fail to comply with this permit you are subject to permit suspension, modification, or revocation. I hereby certify that the work authorized by the above referenced permit has been completed in accordance with the terms and conditions of the said permit, and required mitigation was completed in accordance with the permit conditions. Cgnature o~ermltte~ Da~~//~ RECEIVED COMPANY, U.S.A. POST OFFICE BOX 196601 · ANCHORAGE. ALASKA 99519-6601 · TELEPHONE (907) 561-5331 PRODUCTION DEPARTMENT ALASKA INTEREST JAMES F. BRANCH PRODUCTIOi',,I MANAGER - ALASKA April 13, 1999 Flaxman Island Area Well Site Re-abandonment Alaska State A-l, C-1, D-l, F-l, and G-2, Beauf, Sea, Alaska Mr. Robert N. Christenson, Chairman Alaska Oil and Gas Consen.,ation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Christenson: This letter is intended to give you a status update of Exxon's work activities on Flaxman Island. No action on your part is required. During March and April of 1998, Exxon Company, U. S. A. conducted well abandonment and casing removal operations in the vicinity of Flaxman Island in the Beaufort Sea. These activities were authorized by the AOGCC. Due to an unusually warm spring and early break-up, the work season for 1998 was cut short and not all of the work was completed. We inspected the work sites with the AOGCC in August 1998, and the remaining work was outlined in the AOGCC's letter to Exxon, dated September 4, 1998. In accordance with our letter responding to the AOGCC dated December 1, 1998, Exxon is now returning to the area to complete the work, including the abandonment of the Alaska State G-2 well. We are also removing large diameter casings that were exposed at the Alaska State D-1 and F-1 locations during 1998 and the smaller pipes noted at the Alaska State C-1 location. Lastly, we plan to remove the contaminated gravels from the Alaska State A-1 fuel storage area. If you have questions or require additional information, please contact Mike Barker at 907-564- 3691. Sincer/et?, .---'--'-~., ?? DMB:ddm / c:~data\winword~mb~enviro~ot.tom~federal-stete egencies~Robe~t Ohdstenson 4-9-99.doc / c: Mike Barker, Exxon / Jim Haynes, DNR-DOG / Jesse Mohrbacher, Fairweather / A DIVISION OF EXXON CORPORATION RECYCI. E) ON COMPANY, U.S.A. POST OFFICE BOX 196601 · ANCHORAGE, ALASKA 995196601 · TELEPHONE (907) 561-5331 PRODUCTION DEPARTMENT ALASKA INTEREST JAMES F. BRANCH PRODUCTION MANAGER - ALASKA March 10, 1999 Permit 4-820502, Beaufort Sea 333 and Nationwide Permit 6, Survey Activities Exxon Company, U. S. A. Pt. Thomson Well Re-abandonment Project Mr. Tim Jennings Unit Coordinator United States Army Corps of Engineers P. O. Box 898 Anchorage, Alaska 99506-0898 Dear Mr. Jennings: This letter is intended to give you a status update of Exxon's work activities on Flaxman Island. No action on your part is required. During March and April of 1998, Exxon.Company, U. S. A. conducted well abandonment and casing removal operations in the vicinity of Flaxman Island in the Beaufort Sea. These activities were authorized in the Department's March 6, 1998 letters to Exxon (attaChed for your reference). Operations at the Alaska State G-2 location were covered under existing Permit 4-820502 and the work at the Alaska State D-1 location was covered under Nationwide Permit 6, Survey Activities. Due to an unusually warm spring and early break-up, the work season for 1998 was cut short. As a result, work at the Alaska State G-2 location was only partially completed. Exxon intends to return in April 1999, to complete the abandonment of the Alaska State G-2 well in accordance with Permit 4- 820502. A third large diameter casing was discovered at the Alaska State D-1 location during the 1998 work oPerations. Exxon also intends to abandon this casing at Alaska State D-1 during the work program for April 1999. This activity is covered under Nationwide Permit 6. If you have questions or require additional information, please contact Mike Barker at 907-564-3691 or Jesse Mohrbacher at 907-258-3446. /JM Attachment c: Mike Barker, Exxon Jim Haynes, DNR-DOG Jesse Mohrbacher, Fairweather Gene Pavia, DGC Blair Wondzell, AOGCC Sincerely, RECEIVED Alatla011&GasCons. An 0ra A DIVISION OF EXXON CORPORATION U.S. ARMY ENGINEER DISTRICT, ALASKA . . P.O. BOX 898 ANCHORAGE, ALASKA 99506-0898 ATTENTION OF: Regulatory BranCh North Section D-980186 Mr. James F. Branch Production Manager Exxon Company, U.S.A. Post Office Box 196601 Anchorage, Alaska 99519-6601 FIEC V. ED ! k AR 10 1998 J,F, BRANOH Production '- Alaska Dear Mr. Branch: This is in response to your Pre-Construction Notification letter dated February 23; 1998, concerning your proposal to excavate and backfill approximately 600 cubic yards of material thereby impacting approximately 0.02 acre of waters of the U.S. (Beaufort Sea bed), to facilitate the abandonment of the Alaska State D-1 exploratory well and an associated structural casing. The proposed work would be located in the Beaufort Sea at the western end of Flaxman Island, within section 23, T. 10 N., R. 23 E.', Umiat Meridian, on the North Slope of Alaska. A Department of the Army nationwide permit (NWP) has been issued pursuant to December 13, 1996, Federal Register, Final Notice of Issuance, Reissuance, and Modification of Nationwide Permits (61FR 65874), which authorizes: survey activities including core sampling, seismic exploratory operations, plugging of seismic shot holes and other exploratory-type bore holes, soil survey and sampling, and historic resources surveys. Discharges and structures associated with the recovery of historic resourCes are not authorized by this NWP. Drilling and the discharge of excavated material from test wells for oil and gas exploration is not authorized'by this NWP; the plugging of such wells is authorized. Fill placed for roads, pads and other similar activities is not authorized by this NWP. The. NWP does not authorize any permanent structures. The discharge of drilling muds and cuttings may require a permit under Section 402 of the Clean Water Act. (Sections. 10 and 404) RECEIVED 1999 Almk & COns. )mmielm -2- The proposed Work may be conducted under the authority of the above NWP provided it conforms to the general conditions shown on Enclosure 1. Attached with the general conditions on Enclosure 1 is a list of other required State, Federal and local authorizations the State of Alaska would like to emphasize. Please note General Condition 14 in Enclosure 1, which reads: ~Every permittee who has received a nationwide permit verification from· the Corps will submit a signed certification.regarding the completed work and any required mitigation." Enclosure 2 is the form you need to send us once your project is complete. This NWP verification will be valid for two years from the date of this letter, unless the NWP authorization is modified, reissued, or revoked. In .an effort to determine the level of customer satisfaction with the services provided to you, the Regulatory Branch asks that you take a few moments to provide us with any constructive comments you feel are appropriate by filling out the enclosed questionnaire. Our interest is to see how.we can continue to improve our service to you, our customer, and how best to achieve these improvements. Additional comments may be provided through the use of an oral exit interview, which is available to you upon request.~ Your efforts and interest in evaluating the regulatory program are much appreciated. Nothing in this letter shall be construed as excusing you from.- compliance with other Federal, State, or local statutes, ordinances, or regulations which may affect this work.. Please contact me at the letterhead address, at (907) 753'-2716, .toll-free from within Alaska at (800) 478-2712, or by FAX at (907) 753-5567, if you have additional questions. Enclosures Sincerely, Project Manager · COMPANY, U.S.A. POST OFFICE BOX 196601 · ANCHORAGE. ALASKA 99519-6601 · TELEPHONE (907) 561-5331 PRODUCTION DEPARTMENT ALASKA INTEREST JAMES F. E~RANCH PRODUCTION MANAGER - ALASKA December 1, 1998 ~ Alaska State A-l, D-l, and C-1 ~O - ! O [ Mr. David W. Johnston Chairman/Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Commissioner Johnston: This communication is in response to your letter dated September 4, 1998, which summarized the results of an August 1998 AOGCC inspection and requested Exxon to undertake some remedial work at the Alaska State A-l, D-l, and C-1 well sites. Following the AOGCC inspection of these well sites in August 1998, Exxon revisited them in late August, to conduct some of the site clean-up work, and to develop plans for the remainder. Below is a brief summary of the status and our current work plans for these well sites. Alaska State A-1 The referenced pallets have been removed from this site.. In addition, Exxon has been working with ADEC representatives to determine the cause of the sheen and evaluate the extent of hydrocarbon contaminated gravel. We have collected and analyzed gravel samples for hydrocarbons and are preparing a "Clean-up Plan" for ADEC review. Alaska State D-1 Exxon has notified the U. S. Coast Guard about the submerged large diameter pipe (a velocity survey pipe) and in turn, they have issued a "Notice to Mariners." Exxon plans to remove this pipe below the mud line during the upcoming 1998/1999 winter season. A DIVISION OF EXXON CORPORATION RECYCL Commissioner David W. Johnston 2 December 1, 1998 Alaska State C-1 Exxon has revisited this site and cleaned-up debris. However, we have not removed the six-inch pipes referenced in your letter. We will cut the pipes off this winter while we are working in the area. In addition to the work outlined in this letter, Exxon plans to conduct further clean-up activities at the Alaska State F-1 well site and to complete the abandonment work started last year on the Alaska State G-2 well site. We will contact you and your staff again as our plans and schedule become more finalized. In the interim, please contact Mike Barker at 564-3691 if you or any of your staff have any questions. DMB:ddm c:~m~wlnword~lmb~ag~C, ommmmon~r Johnlor~ 11-9-9~.do~ Sincerely, ·., , / / / TONY KNOWLES, GOVERNOR ~K~ OIL ~ ~ CONSERVATION COMMISSION September 4. 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 James F. Branch Exxon Company. U.S.A. P.O. Box 196601 Anchorage, Alaska 99519-6601 Re: Alaska State A 1. D 1 and C 1 Dear Mr. Branch: One of our inspectors visited several Exxon cxploratoD' xv¢il sites in the Pt. Thompson Unit on thc North Slope during August this ,,'car. Rob Dragnich accompanied him. Several of the sites require additional work as follows. Alaska State Al (AOGCC Permit 74-014): The well is located on Flaxman Island. A portion of a plastic liner was visible on the north edge of the island, a small sheen was visible, and six wooden pallets remain at the site. Alaska State D I (AOGCC Permit 80-101): The well is located on Fla~xman Island. A large diameter pipe was visible in thc area of the drill site. which is now submerged, the pipe is obscured bx' waves and mav only be visible from thc air. Alaska State C 1 (AOGCC Permit 80-046): The location appears to have a partially opened pit and scvcrat six inch pipes standing in water on the southeast side of thc location, the casing max' need to be cut offdceper below ground level. Those sites have previously bccn approved bv thc state tbr abandonment. However. Exxon remains responsible for these sites and under 20 AAC 25.026 is not relieved of further claims bv the Commission a~cr abandonment. Accordingly, the Commission requests Exxon to undertake appropriate remedial work to correct thc above deficiencies. Please advise the Commission when Exxon will undertake remedial work. Chairman PLUGGV & LOCATION CLEA_R~_,NCE REPORT State of Alaska ALAS~ 0IL & GAS CONSERVATION COMlfISSION Nots casin_c size, wz:, depth, cmo vol, & procedure-. - Perf fi=new, als - t=ps: ~o~ wet ~ ~l e and' c~enu on plugging, well head ~d location c!ear~ca - urcvide icc. clear, code. Well head cut oil: ~/~ff .., .... Marker posU or plate: , ~ / / Code MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnston, DATE: Chairman THRU: Blair Wondzeil, ~ FILE NO: P. I. Supervisor FROM: Chuck Scheve,~ ~ SUBJECT: Petroleum Inspector August 3, 1998 i99khcfe. DOC Location Clearance Insp. Exxon Point Thompson Unit A1 PTDg 74OO14 D1 PTD# 80-O101 G2 PTD# 82-0208 F 1 PTD# 81-0140 C1 PTD# 80-0O46 Mort. d,a¥. Auc~ust., 3,1_9,98: I traveled with Rob Dragnich (Exxon), Gary Schuitz (DNR) and Bob Gardner (Fairweather) to inspect Exxon's Al, D1, G2, F1 and C1 locations in the Point Thompson Unit. A!ask. a state A!: The A1 Location is on Flaxman Island and the well was P&A in 1975. The north edge of the island has eroded away revealing a layer of plastic (possibly a pit liner) approx. 3' below current pad level. Upon closer inspection a diesel odor was observed and a small sheen was visible on the bank in one spot. The affected area appeared to be 90' long on the north east corner of location. On the East edge of location there were 6 wooden pallets mostly covered with over burden and vegetation starting to grow on top. of them. c.;a~e'n..~.~ C~4'o~ (oea~ ~"=~?- 9.8° .P~r ~oa'e, Alaska State DI: The D1 location on Flaxman Island is mostly under water and the casing stub was cut off below the base of the island this past winter. The visible portion of the location was clean and free of debris. Off shore to the north east of the~H~,~-- remaining location there is what appears to be a large diameter pipe (possibly a velocity survey pipe or an unused conductor) that was only visible from the air and in the trough of the waves. Alaska State G2: The G2 location on Flaxman Island was clean and free of debris. Exxon plans to deepen the casing cut off this next winter due to the severe erosion of the island. Alaska State Fl- The F1 location on North Star Island was clean and free of equipment and debris. (.?~'ew · cud- ~ loua ar 1~ '~ 9 7- '-) $ Alaska State C1- The C 1 location has what appears to be a partly open reserve pit and 6 each~6" pipes standing in a water covered area off the south east edge of location. It appears that the casing cut off is just below pad level, with the location mounded slightly to cover it. The marker post is weathering well and had the proper info welded to it. The rest of the location was clean and free of debris. ['/er ~ [P~ ~o -Ja.{,a. ~ /~ SUMMARY: It is my understanding that the above mentioned locations ali have approved location clearances, if this is the case ! recommend that the commission reevaluate the Al, D1 and C1 locations. Based on my observations I recommend the G2 and F1 location clearances remain approved. Att,,achments, ,: Photos Attachment to: Chuck Scheve's 8/3/98 Memo: "Location Clearance Inspections, Exxon" Location Clearance. Chuck conducted a location inspection on five Exxon wells, Alaska State A-l, C-l, D-l, and G-2. Wells A-l, D-l, and F-1 were re-abandonments. The Commission has previously acknowledged that all 5 wells were properly abandoned. * After a 9/5/84 inspection, on 9/20/84 LC Smith approved "final abandonment" of Exxon's Alaska Sate well D-1 * After a 6/18/86 inspection, on 8/25/86 LC Smith approved ~final location clearance" of Exxon's Alaska State wells F-1 & G-2 * After inspections on 8/27 and 9/12/86, on 11/21/98 LC Smith approved "final location clearance" of Exxon's Alaska State wells A-1 & C-1. The diesel and pad liner at A-1 and the reserve pit at C-1 will be corrected under DEC's jurisdiction. The pipe offshore of D-1 will be removed this winter (98-99) per Exxon's Rob Dragnich. Well Abandonments. I reviewed the 10-404 data on the three wells that were ~re-abandoned" A-l, D-l, and F-1 and can make the following comments: * Well A-i: diesel was displaced from the 9-5/8", the 9-5/8" x 13-3/8" annulus was circulated with cement at 205', and the casings were cut-off 40" below sea floor. Based on the 404 data, the re-abandonment is an improvement over the original and is acceptable: well A-1 is properly abandoned. * Well D-I: casings were cut-off 15'below MLLW, cemented 9-5/8" x 13-3/8" annulus, and re-cemented inside 9-5/8." from 47' to 16' MLLW. Based on the 404 data, the re-abandonment is an improvement over the original and is acceptable: well D-1 is properly abandoned. · Well F-l: casings were cut-of 13' below MLLW, filled with cement the 7"x9-5/8" and 9-5/8" x 13-3/8'" annUli, Blair E. Wond~l, -Septef~ber al, 1998 E~ON COMPANY, U.S.A. POST OFFICE BOX 196601 · ANCHORAGE, ALASKA 99519-6601 · TELEPHONE (907) 561-5331 PRODUCTION DEPARTMENT ALASKA INTEREST JAMES F. BRANCH PRODUCTION MANAGER - ALASKA June 19, 1998 Report for Sundry Well Operations, Exxon Company, U.S.A., Flaxman Island Area Well Re-abandonments, AK State A-l, D-l, & F-l, Beaufort Sea, Alaska Mr. David Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Blair Wondzell Dear Mr. Wondzell: Attached are Exxon Company, U.S.A.'s reports for the Flaxman Island Area Well Re-abandonments at AK State A-l, D-l, and F-2. Originally, Exxon also planned to re-abandon Alaska State G,2 during the 1997-1998 winter work season. However, an early spring on the North Slope led to a postponement of the Alaska State G-2 work. We are currently developing plans to complete the G-2 work and will keep you apprised. If you have any questions or need additional information, please contact D. Michael Barker at 907-564-3691 or Jesse Mohrbacher at 907-258-3446. DMB:ddm Attachment c:~data~inword~dmb~enviro~pttom~sund ry.doc Thank you for your attention to this matter. Sincerely, //~ , R CE VEt) ,/ ,.!~L C, i 1998 ., A DIVISION OF EXXON CORPORATION Alaska Oil & Gss Cons. 6ommissio~ Anchorage RECYCLED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [ ] Operation shutdown [ ] Stimulate 2. Name of Operator 3. Address . [ ] Pull Tubing [ ] Alter Casing EXXON Company, U.S.A. P O Box 196601, Anchorage, AK 99519 [ ] Plugging [ ] Perforate [ ] Repair Well 5. Type of well: [ ] Development [ X ] Exploratory [ ] Stratigraphic [ ] Service Location of well at surface 305' WEL, 1169' NSL, Sec 23, T10N, R23E, UM At top of productive interval Straight hole At effective depth Straight hole At total depth Straight hole 13,050' feet 13,050' feet 12. Present well condition summary Total depth: measured true vertical [ X ] Other: Re-abandon 6. Datum Elevation (DF or KB) RKB 38 feet 7. Unit or Property Name Alaska State D 8. Well Number Exxon No. I 9. Permit Number/Approval Number 80-101 10. APl Number 50-089-20015 11. Field/Pool Wildcat Plugs (measured) 12,659'-12,898', 11,200'-11,600' 9,908'-10,200', 53'-150' Effective depth: measured Surface feet true vertical feet Junk (measured) None Casing Length Size Structural 110' 30" Conductor 2,056' 20" Surface 3,998' 13-318" Intermediate 10,082' 9-5~8" Production Liner Cemented Est. 600 sx pf 5,380 sx pf 600 sx pf, 250 sx G 1,680 sx G MD TVD 110' 110' 2,056' 2,056' 3,998' 3,998' 10,082' 10,082' Perforation depth: measured None true vertical Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None ORIGINAL 13. Stimulation or cement squeeze summary None REC[IVED Intervals treated (measured) None Treatment description including volumes used and final pressure None Alaska 0il & Gas Cons, 14. Representative Daily Average Production or Injection Data Oil-bbl Gas-Mcf Water-bbl Casing Pressure Tubing Pressure Prior to well operation None, well was abandoned. Form 10-40/~v. 06/15/88 Subsequent to operation 15. Attachments [ ] Copies of Logs and Surveys run [ ] Daily Report of Well Operations [ X ] Re-abandon.r,rpent report 17. I hereby certify.tl~t the foregoing is true and correct to, he best of None, well was re-abandoned. 6. Status of well clasification as: Abandoned ]Oil [ ]Gas [ ]Suspended [ ] Service my knowledge Production Manager - Alaska /tCubn~it In Duplic~ Summary of Operations Permanent Re-abandonment Exxon Company, U.S.A. Alaska State D-1 Flaxman Island Area, Beaufort Sea, Alaska Exxon Company, U.S.A. (Exxon) drilled the Alaska State D-1 well on Flaxman Island in the Beaufort Sea in 1981/82. At the completion of drilling and testing operations, the well was plugged downhole and at the surface for final abandonment. Subsequent to well abandonment, the D-1 location underwent abandonment by pulling the protective sheet pile around the drill site and removing all equipment and debris. Since the mid 1980's, Flaxman Island and neighboring islands have undergone natural erosion and migration due to wave and storm action. A site inspection at the D-1 well site and three other Flaxman Island area wells (Alaska State A-l, F-1 and G-2) on October 25, 1997 revealed that at the D-1 location, the well and an extra 30 inch structural casing had been exposed by natural erosion and are now offshore. The other three wells and related appurtenances were also at risk of being affected by natural erosion in the future. Exxon chose to re-abandon the D-1 well in compliance with current AOGCC abandonment regulations to ensure that the well does not present a navigation hazard in the future. Figure 1 shows the final status of the Alaska State D-1 well. Figures 2 and 3 present the final condition of the well in relation to sea and island level. The D-1 well was re-abandoned as part of a multi-well re-abandonment program that also included the wells Alaska State A-1 and F-1. Final details for the A-1 and F-1 well re- abandonment operations are covered under separate Reports of Sundry Well Operations. The re-abandonment of the extra 30 inch structural casing included the following operations: . Drill out of the ice and gravel in the 30 inch casing to 18 feet below sea level (MLLW) with a 6 inch O,D. auger. See Photo 1. . Ran a 50 lb nitromethane explosive charge (5.5 inch O.D.)inside the 30 inch casing to 18 feet below sea level. See Photo 2. Detonated charge. Charge did not cut casing but did evacuate remaining ice and gravel from 30 inch casing to 18 foot depth. . Ran additional 50 lb nitromethane charge (11 inch O.D.) in 30 inch casing to 15 feet below sea level. Detonated charge and cut 30 inch casing, however, casing was held by additional 42 inch O.D. outer refrigeration casing. . Worked casing stubs back and forth with backhoe until outer 42 inch casing failed. Recovered 11 feet of 30 and 42 inch casing stub cemented together. See Photo 3. , Verified depth of casing removal at a minimum 10 feet below sea level by probing with a backhoe. D1-404 06/15/98 Re-abandonment of the D-1 well included the following operations: . Drill out of the cement plug in the 9-5/8 inch casing to 16 feet below sea level (MLLVV). See Photo 1. Encountered frozen cement and decided to drill off another 30 feet of cement plug after consultation with Mr. Blair Wondzell of the ^OGCC (See attached letter). . Mixed and set a 12 sack (2.25 bbl) permafrost cement plug in the 9-5/8 inch casing from 47 to 16 feet below sea level. o Checked status of 13-3/8 x 9-5/8 inch annulus (former disposal annulus). Found annulus to be on vacuum. See Photo 4. Filled annulus with 47 bbl, 9.0 ppg, CaCI2 water and verified annulus in static condition. Determined top of cement in annulus at approximately-785 feet MLLWo , Mixed and set a 14 sack permafrost cement plug in the top 50 feet of the 13-3/8 x 9-5/8 inch annulus. VVOC 10 hours. Ran a 75 lb Composite B explosive charge inside the 9-5/8 inch casing to 15 feet below sea level and detonated charge. o Recovered 13 feet of casing stubs including 9-5/8, 13-3/8, 20, 30, and 42 inch casings, See Photo 5. o A final site cleanup and location clearance visit is scheduled for the summer of 1998 after the snow cover has melted. All scrap steel recovered during the D-1 re,abandonment program was sent for recycle. The D-1 wellhead and cemented casings were transferred to the North Slope Borough landfill for disposal. D1-404 06/15/98 All Depths RKB RKB = 3.8' MLLW Grade = O' MLLW Cement in 13 :S/8" x 9 5/8" Annulus from 53' to 85' RK8 CeCI2 in I$ 3/8" x Annulus fram 85' to Permafroet Home Collar 20" x 13-3/8" fo 2,100' ~ All Casings Cut and Removed to -15' IdLLW (53' RKB) 42" Refrigeration Casing ~1 ~' 60' 30" Structural Casing O 110' of Cement O I SO' +/- (RKB) Permafrost Cement to 53' RKB 10.2 ppg CaCI2 to 2,000' 20" !;5;5 ~/ft K55 BTC Conductor Casing ~ 2.056' Cemented to Surface Cement Below 13-3/8" Shoe Permafrost TOC Approximately 5,000', Claae G 13-5/8" 72 #/ft 1.80 BTC Surfaee Ce~. ~ 3,gg~ g.6 ppg Mud ppg Mud TOC Approximately 7,500', Class G Plug fop 9.908'. 120 Sacks Class G HOWCO EZSV Retainer ~ 9,976' 9-5/8" 45.5 ~/ff Pl10 LTC Protective Casing ~10,082' 11.5 ppg Mud Plug Boflom :1: 10,200' 15.7 ppg Mud --11,200 Top of Plug 200 sx Class G LEGEND Cement Mud CaCI2 Wafer NO SCALE FAIR/£XXON/£X498D I 1:1 6/15/98 SR 11,600 Boffom of Plug 12,898' TO ~} 15,050' 8-1/2" Hole Figure 1 EXXON Company U.S.A. Alaska State D-1 Wellbore Schematic, April 1998 ,,,~.,...,.:.~. := ..... ,.... ,...~ ....... ,,_ ,,. ,., ...... I.. ............ Co~s~, Southeast -;'.. 'c,,..~,'.,-"~'~e".'";:'~'.' .... """ ;T ..... ~~'~" / ' Island Toe ~ ~ ~ Se,floor . Well Cesings Severed ef -15' MLLW 8' Below the Islend Toe NO SCALE FAIR/EXXON/EX4OBD3 1;1 6/1/98 II I Figure 3 EXXON Company, U.S.A. Alaska State D-1 Location, Elevation View, Looking Northeast Flaxman Island, Beaufort Sea II IlIII I II II I D- 1 Well Casings Severed Below Sea Level and Pulled NO SCALE FAIR/EXXON/EX4gBDZ 1:1 6/1/g8 I III I II II II I I I1! I I Figure 2 EXXON Company, U.S.A. Alaska State D-1 Location, Elevation View, Looking Northwest Flaxman Island, Beaufort Sea Sea Ice Surface Seafloor ////~ 4Z" Refrigeration and 50" Sfruolural Casing I I Photo '1; Drilling out the extra 30 inch structural casing at Photo 2; Rigging up a 50 lb, 5.5 inch O.D. nitromethane the D-1 location, charge at the D-1 location. Photo 3: R_e_~overed 30 and 42 inch casings at the D-1 location. Photo 4: Checking the status of the 13-3/8 x 9-5/8 inch annulus on the D-1 well. ~hOto 5: Recovered 42, 30, 20, 13~3/8 and 9.5/8 inch casings from the D-1 well. 9-April-98 Mr. Blair Wondzell Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Changes to Re-Abandonment Programs for Exxon Company, U.S.A. Alaska State A-1 and D- 1 Dear Mr. Wondzell: This letter confirms our telephone conversation yesterday regarding the referenced wells. Well A-l: During coiled tubing operations an obstruction was encountered at 335' while running in the hole. The 9-5/8 inch casing was then pressure tested to 1200,1400, and 1500 psi in five minute intervals, with no bleed off. We agreed that no further penetration depth was necessary in the well and that the abandonment program could continue from 335 feet to surface. Well D- 1: While drilling out the originally planned 20 feet of the existing surface cement · plug, frozen cement was encountered at.approximately 16 feet below surface. We ' agreed that an additional 30 feet could be drilled offthe existing plug, if necessary, and replaced with competent permafrost cement prior to cutoff at the program depth. If you have any questions or comments regarding the above program changes, please contact the undersigned at your earliest convenience. Thank you for your prompt assistance in making these program changes during field operations. Sincerely, . Jesse Mohrbacher Fairweather E&P Services, Inc. 715 L Street, Suite 4 · Anchorage, AK 99501 907-258-3446 CC~ Clyde Baldwin, Exxon Mike Barker, Exxon STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [ ] Abandon [ ] Suspend [ ] Plugging [ ] Time Extension [ ] Perforate [ ] Alter Casing [ ] Repair Well [ ] Pull Tubing [ ] Variance [ X ] Other Re-abandon [ ] Change Approved Program [ 1 Operation Shutdown [ ] Re- Enter Suspended Well [ ] Stimulate 2. Name of Operator 5. Type of well: 6. Datum Eleva~on (DF or KB) EXXON Company, U.S.A. [ ] Development RKB 38 feet [X] Exploratory 3. Address [ ] Stratigraphic 7. Unit or Property Name P O Box 196601, Anchorage, AK 99519 [ ] Service Alaska State D 4. Location of well at surface: 8. Well Number 305' WEL, 1169' NSL, Sec 23, T10N, R23E, UM Exxon No. 1 At top of productive interval: 9. Permit Number Straight hole 80-101 At effective depth: 10. APl Number Straight hole 50-089-20015 At total depth: 11. Field and Pool Straight hole Wildcat 12. Present well condition summary Total depth: measured 13,050' feet Plugs (measured) 12,659'-12,898', 11,200'-11,600' true vertical 13,050' feet 9,908'-10,200', surface-150' Effective depth: measured Surface feet Junk (measured) true vertical feet None Casing Length Size Cemented MD TVD Structural 110' 30" Est. 600 sx pf 110' 110' Conductor 2,056' 20" 5,380 sx pf 2,056' 2,056' Surface 3,998' 13-3/8" 600 sx Df, 250 sx G 3,998' 3,998' Intermediate 10,082' 9-518" 1,680 sx G 10,082' 10,082' Production Liner Perforation depth: measured None true verticalRECEIVE[.) Tubing (size, grade and measured depth) ~ ~-L.~ NoneAL ORIGIN Packers and SSSV (type and measured depth) A[8$ka 0[! ~ . None 13. Attachments [X] Description of Sumary Proposal [X] Detailed Operations Program [ ] BOP Sketch 14. Estimated date for commencing operation 15. Status of well classification as: Abandoned March 15, 1998 16. If proposal was verbally approved [ ] Oil [ ] Gas [ ] Suspended Name of al)prover Date Approved Service Contact Enginee,~Narne/Nurnber: Jesse Mohrbacher/258-3446 Prepared By Name/Number: Jesse Mohrbacher/258-3446 17. I hereby ce~f~at the for~d correc,~the ~est of my knowledge Sign ~-~~~roduction Manager - Alaska ~'"A ~/"~ ~ Date J Commission Use Only Conditiorfrs of Approval: Notify Commission so representative may witness IApproval No,.~,~--,.~-? Plug integrity BOP Test Location Clearance Mechanical Integrity Test Original Sigrle~j~quent form required 10- David W. Johnston.~ ~ 1~, Approved by order of the Commission Commissioner Date -.- ,.,- Form 10-403 Rev. 06/15/88 _ Sub '~it I ~ Triplicate Approved Copy EXXON Company, U.S.A. Application for Sundry Approvals Alaska State D-1 Flaxman Island Area, Beaufort Sea, Alaska INTRODUCTION AND BACKGROUND EXXON Company, U.S.A. (EXXON) drilled the Alaska State D-1 well on Flaxman Island in the Beaufort Sea in 1981/82. At the completion of drilling and testing operations, the well was plugged downhole and at the surface. Subsequent to well abandonment, the D-1 location was also cleaned up and abandoned by pulling the protective sheet pile around the drill site and removing all equipment and debris. Since the mid 1980's, Flaxman Island and neighboring islands have undergone natural erosion and migration due to wave and storm action. EXXON performed a site inspection at the D-1 well site and three other Flaxman Island area wells (Alaska ' State A-l, F-1 and G-2) on October 25, 1997. The well site inspection.re~ealed that the D-I. drill site has eroded away and exposed the D-1 well and-an extra 30 inch:struCtural casing at the. waterline on the westem extent of Flaxman Island: 'The other wells are all on 'solid ground and in no immediate danger of being exposed'to'the sea; however, a 40 inch VSP pipe' at the G-2 location has been exposed at the waterline on the north side of Flaxman Island. · Figure 1 shows the locations of.the subject wells. . .... ~ EXXON has expressed a desire to re-abandon the D-1 well in compliance with current AOGCC abandonment regulations to ensure that the well is not exposed or impacted by future erosional events. The A-l, F-1 and G-2 wells will be re-abandoned for similar reasons in a multi-well program this winter season, however, the operational details for the A-l, F-1 and G-2 wells are covered under separate Sundry Notices. For re-abandonment of the D-1 well, it will be necessary to complete the following operations: . Using an air track drilling unit, drill out the D-1 well to 15 feet below grade (sea ice surface is grade). . Sever the well casings with explosives at 15 feet below grade and pull the well casings. 3, Use a similar procedure to remove the extra 30 inch structural casing at the D-1 location. The above work is in accordance with AOGCC regulations 20 AAC 25.105, 25.120, 25.170 and 25.172. AOG-CC D-1 Sundry 02/24/98 PROPOSED OPERATIONS PROGRAM . Mobilize all required personnel and equipment to the work location on an as needed basis. Set up camp and base at Pt. Thomson 3 location to commence the operations program. . Remove the well abandonment marker and drill out the 9-5/8 inch casing to 15 feet below surface with an air track drill. This will leave approximately 100 feet of cement surface plug existing in the D-1 well with non-freezing 10.2 ppg calcium chloride in the 9-5~8 inch casing from 150 feet RKB to 2,000 feet. EXXON hereby requests that the requirements for a 150 foot surface cement plug and kill weight fluid in the 9-5/8 inch casing be waived in this case for the D-1 well. See Figures 2, 3, 4 and 5 for the status of the D-1 well and location. . .' Lower an explosive charge into the well on rope to approximately 15 feet. Detonate charge to sever casing strings. Rigup the crane and vibratOry hammer to extract casing from the:: ground. Use steam to thaw the ground immediately surr°unding'the well to assist with removal if necessary. . Using the same drill out and casing removal procedure; remove the, extra 30 inCh structural casing at the D-1 well location. ,:, · '. . Pick up any remaining debris on location and demobilize equipment to Deadhorse or move to the next well in the program. 7. File a Report of Sundry Well Operations for the D-1 well with the AOGCC. 8. Conduct a location clearance visit with the AOGCC and other agency representatives the following summer. AOGCC D-1 Sundry 02/24/98 WASTE DISPOSAL . All liquid wastes recovered in the re-abandonment program will be transported in secure vacuum trucks to the Prudhoe Bay Pad 3 or other approved injection facility. Once delivered to the injection facility, the wastes will come under the control of the injection facility operator and will be disposed of in accordance with AOGCC, ADEC and EPA regulations. . All cleaning of waste hauling tanks and trucks will be done at Peak Oilfield Service Company's wash bay in Deadhorse. . Solid waste (i.e. cellar, wellhead, etc.) will be transported to the North Slope Borough Solid Waste Disposal Site .for disposal. , Diesel contaminated gravel will be segregated' and'transported to Deadhorse for thermal treatment or stockpiled on-site for fUrther, remedial evaluation. AOC-CC D-1 Sundry 02/24/98 I I III ~ III I SITE LOCATION '~ .. ~'i~'qco/~ ALASKA STATE F-1 '~"~'"~ ~ '"~/~ ~ ~ A~SKA: STATE D-1 ,o~ ro sc,~ ~~ / ~xxo~ ~o. ~ ~ ~~ ~ ~ / ~ ~ ~ ':..' .. CAMP BROW~mW PT. APPROX. SCALE IN FEET . ~.. FAIR/EXXON/FLAXMAN __ 1:8000 2/10/9B ,, ,, ,, u_, Figure 1 EXXON Company U.S.A. Flaxman Island .Vicinity I IIII I II I . II I IIII LLIL II J' II II . II /--Approximate Island Edge. 1980 D- 1 We'll ~-~ o~°" co~u~o~' . . F LA X M A N ISLAND ~ Drilling Pad Edge FAIR/EXXON/FLAXD1-2 1:1 2.124/98 Figure 2 EXXON Company, U.S.A. Alaska Slate D-1 Location, 'Plan View Flaxman Island, Beaufort .Sea /-- Approximate Edge, 1998 ... ,,, ., 0 50 1 O0 APPROX. SCALE IN FEET D- 1 Well 30" Sfrucfural Casing Casings to be Severed Approximately 15' Below Seafloor and Pulled ~35' NO SCALE FAIR/EXXON/FLAXD 1 -;~ 1:1 2/24/98 Figure 5 EXXON Company, U.S.A. Alaska State D-1 Location, Elevation View, Looking Northwest Flaxman Island, Beaufort Sea Sea Ice Surface Seafloor iiii iii ii I I'II II II II I I I IIII III II I I I I I I I I I I I I IIIIIII I · I I I I L ILIJIJII II I II D- 1 Well Flaxman Island Sea Ice Surface Sea Level MLLW ,v20' Seaflo°r To Mainland Coast, Southeast Well Casings to be Severed at Least 5' Below the Island Toe NO SCALE rAm/EXXOU/rL*X7 ~:~ 2/~7/Sa ....... , ,111 · _1 , , , , , i i 1,1 , , Il I I [ I .11 I I I IIII ~ - Figure 4 , EXXON Compeny, U.S.A. Alosko Stole D-! Locafion, £1evafion View, Looking Northeost Flaxrnen Island, Beaufort Sea All Depths RKB RKB = 58' MLLW Permafrost Horse Collar 20" x 13-5/8' fo 2,100'-- Cement Below 13-3/8" Shoe Permafrost LEGEND ~ Cement -'-] Mud ~ 10.2 ppg CaCI2 NO SCALE FAIR/£XXON/FLAXD 1-5 1:~ 2/~4/9s SR Permafrost Plug 0-150' in 9-5/8" Casing $0" Structural Casing {) 110' of Cemenf{) 150' +/- (RKB) Permafrost Cemenf to SurfOce 10.2 ppg CaCl2 fo 2,000' 20" 133 ~/ft K55 BTC Conductor Casing {) 2,056' Cemented to Surface TOC Approximately 5,000', Class 15-3/8" 72 ~/ft LBO BTC Surface Casing ¢) 3,998' 9.6 ppg Mud -15.7 ppg Mud TOC Approximately 7,500', Class G Plug top 9,908', 120 Sacks Class G HOWCO EZSV Retainer {) 9,976' 9-5/8" 45.5 ~/ft Pl10 LTC Protective Casing {)10,082' 11.5 ppg Mud --Plug Bottom ± 10,200' 15.7 ppg Mud 11,200 Top of Plug 200 sx Class G 11,600 Bottom of Plug ~----15.7 ppg Mud i ~i Sid.etrock {) 12,659~ 12,898' TD 0 15,050' 8-1/2" Hale Figure 5 EXXON Company U.S.A. Alaska State D-1 Weilbore Schematic Note: Current well status as of 25-Feb-98. Post sundry schematic fo follow with completion report. E~(()N COMPANY, U.S.A. POST OFFICE BOX 4279 · HOUSTON, TEXAS 77210-4279 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION August 29, 1986 Exxon Alaska ST D-1 BHC-AL Log Tape Mr. S. W. Gustafson 3301 C Street P.O. Box 6601 Anchorage, Alaska 99502-0601 This tape was checked by the Information Project and all the acoustic and gamma ray curves are recorded on the tape, with no gaps. The caliper curve does have some gaps because it was not functioning properly. Nothing can be done about this. BHL/ab Enclosure B. H. Laramore RECEIVED SEP0 8 lg86 Alaska 011 & Gas Cons. Commission Anchorage A DIVISION OF EXXON CORPORATION EXPLORATION DEPARTMENT ALASKA/PACl F lC DIVISlON EXXON COMPANY, U.S.A. POUCH 6601 Anchorage, Alaska 99502 TRANSMITTAL OF DATA FROM: TO: Bill Van Alen AOGCC 3001 .Porcupine Drive Anchorage, Ak. Material transmitted Exxon Alaska State 'D' Well No. 1 The material listed below is being transmitted via hand deliverv Core Chips Core #1 11,738'-11,746' Please acknowledge receipt of the above material by signing and returning the duplicate copy of this letter. RECEIVED JUN 2 0 985 Date Alaska 0il & Gas Cons. Commission Anchorage Roy Longstreet June 20, 1985 ;Date 4569-K MISSION GORGR PLACR SAN DIEGO, CA 92120-0890 TRANSMITTAL TO: Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. Mike Minder JOB 'NUMBER: 84-113 SHIPMENT ENCLOSURES: ExXon Alaska State C-1 EXX°n 'Alaska Sta~:e' D-'i Paly Slides Box 1 # 1-60 Box 2 # 61-121 Box 3 # 122-170, Core #1-10 Paly Vials Box 1 #1-104 Box 2 #105-150 #1-50 TAI vials Paly Slides Box 1 # 1-63 Box 2 # 64-125 Box 3 # 126-150 (SIGNATURE) Ch (DATE) Sent by: ., ~ . ... ........ ... ........ Received by: ~/~,.~ ........................... .. Please sign and return one copy. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM!~ISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 COMPUTER TAPE RELEASE AGREEMENT /. / Th~undersigned agrees to assume full responsibility for the safe ret~yn of the released computer tape. If t~ released tape ~se~nths~l~eO~otrO[tsda~aeg~adctehm~n~?dersigned wi~ll ~e financially " THIS DATE: ".%? // '\ . · 10108184' ' September 20, 1984 Exxon Company, U.S.A. P. O. Box 6601 Anchorage, Alaska 9950Z-0601 Re: Final Location Clean-up Inspection for Abandonment, Alaska State D-l, Sec. 23, T10N, R23E, UM. Gentlemen: Our representative inspected this location on September 5, 1984 and it was found that clean-up was acceptable and that a correct well marker was in place. Consequently, final abandonment to Alaska State D-I is approved. Sincerely, Commissioner lc~A.3e'.7 MEMORA qDUM Sta e of AlaSka TO: FROM: C. ~.l~tterton DATE: September 11, 1984 C~r~'~' FILE NO: "~ D.31.64 Lonnie C. Smith TELEPHONE NO: Commissioner SUBJECT: Inspect EXXON Locations Listed Below For. Final P&A. Wednesday, September 5, 1984: I inspected the locations listed below for 'f{~al' 'P&2~' with Junior Westbrook and Noreen Borys, Exxon representatives. As the attached pictures and P&A form show the locations and well markers meet AOGCC regulation 20 AAC 25.170 requirements. I recommend to the Commission that these locations and wells be accepte~ , ,~,:' ~" Alaska State G-2 Attachment/piCtures in file SURFACE AB~I)C'~IENT REP()RT 20 AAC 25, AR'CICLI~ 2 FILE INFO~SV~ION: Surface LgCati~fi of Wel'l - ' ~/ ~ Pen,'it No. ~- Sec._~ .., T'.~~, R~~,'. ~ bl'~ Unit or Lease Name ~/~~. '~'/~ Well No. ~,-/ 20 AAC 2~.120: WEI.L ABANDONHEN'r /-b~RKER: Dia. Steel Post (4"Hin.) ~ , Length (10' Min.) Height Above Final Grade Level (4' Hin.) Top of Marker Pipe Closed with: Cement Plug Screw Cap Welds Set: On Weii Head ~, On Cutoff Casing ~' , In Concrete Plug Distance Below Final Grade Level. ._~ Ft. in. Side Outlets: Ail Valves and Nipples Removed All Openings Closed ~, With Blinds ~-, I$i~h Cement INFOI~.IATION BEAIJWE1, DED D[I~,F,C*I.'F~I,Y TO HARKER POST: (List Where Different from File Infomnation) Operator Unit or Lease Name Well Number , Surface Location of Well: Ft. F L, Ft., F L, Sec_ , T , R , H 20 AAC 25.170: LOCATION CLEAN-UP PiTS: · ---~lled In ~./", Liners Rei~oved or Buried /" Debris Removed SUP, FACE OF PAl) At:D/OR .I.,OC~ATiON: Rough" , Smooth g../, COntoured ...... , Flat__, Con~pacted Other CLEAN UP";'OF PA?. Al.ID/OR LOCATION: Clean ..... ~_, Pipe Scrap __, Iron Scrap__ Paper. , Other , Wood , Mud , Cement S UR ROUND lng AREA: Wooded , Brush , T~ndra Sand _ Z./-~ Other --~" COteD [T ION SU)t. ROUI,iI} I_N('; Al{Ir, A: CleaO ~'; TraSh from Site Other , Grass , Dirt , Gravel , Trees and/or Brush from Clearing Site ACCESS ROA'D: Dirt_ , Gravel ~,. Ice ~, Other..~ CONDITION ACCESS ROAD Ah'D SURROUNI) ING: Clean , Rough , Smooth , Trash from Operations , Trees '~hd/or Br~~~ Clearing Road __, Spoil from Clearin~ Road Other .... ~~ / REHAINING TO BE DONE: . RECOHt. IEI'~D- APPROVAL OF A~ANDO~IENT: Yes.~' No INSPECTED BY _ , _. _ o5/26/~ Final Inspection DATE E) ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99602 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION D.H. JONES EXPLORATION COORDINATOR -- ALASKA September 6, 1984 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 nine Exxon drillsites located on the North Slope. The inspection trip to these locations was conducted on September 5, 1984 with your representative, Mr. Bobby Foster. We request that the status of the Alaska State D-1 drillsite be approved as permanently abandoned, all the other drillsites to be maintained as suspended. We are currently reviewing with the other working interest owners on the Alaska State G-2 well whether or not to file for permanent abandonment of this location. We will file a separate Sundry Notice for this pad'within the next few weeks. Very truly yours, NB2:25:ng Enclosures A DIVISION OF EXXON CORPORATION RECEIVED Alaska Oil & Gas Cons. commission Anchorage ~" STATE OF ALASKA ( ALA ,,A OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER~ 2. Name of Operator 7. Permit No. Exxon Corporation 80-101 3. Address 8. APl Number P. 0, Box 6601, Anchorage, AK 99502-0601 5o-089-20015 4. Location of Well 305' WEL and' 1169' NSL, Sec. 23, TION, R23E, UPM, North Slope, Alaska 5. Elevation in feet (indicate KB, DF, etc.) 13.0 MSL Ground 12. I 6 . Lease Designation and Serial No. ADL 312866 9. Unit or Lease Name Alaska State D 10. Well Number Exxon No. 1 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 I-~ 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). The subsequent report of abandonment for this well was filed on 2/18/82. location cleanup has been completed and all sheetpiling has been removed. request approval for final abandonment status of this location. The fi nal We RECEIVED sEPt o 1984. Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby c~to the best of my knowledge. ~' Exploration Coordinator - Signed Title A1 as ka The space below for Commission use Date 9 / 1 0 / 8 4 Conditions of Approval, if any: Approved by Approved Copy .Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION EXXON COMPANY, U.S.A. POUCH 6601 Anchorage, Alaska 99502 TRANSMITTAL OF DATA FROM: Roy Longstreet TO: Bill Va~ Alen AOGCC 2001 Porcu~ine Drive ~nehora_~e: 'Ak. _qqBOl Material transmitted',~ Exxon Alaska State D #1 The material listed below is being transmitted via hand delivery 4 Library Tapes & Listings for DIFL, CD'L, CDL/CNL, BHC/AC If t'l ~/~se acknowledge receipt of the above material by ~gning'Xand returning the duplicate copy of this letter. Date '_N. ~St~ O%t & Gas...~,.~.Cons. commissioa ,. ,~oy Longstreet' April !7, 1984 Date EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION EXXON COMPANY, U.S.A. POUCH 6601 Anchorage, Alaska 99502 TRANSMITTAL OF DATA FROM' Roy Longstreet TO: Ak. Oil & Gas Conservation Commission Attn: Bill Van Allen 3001 Porcupine Drive Anchorage, Ak. 99501 Material transmitted Exxon Alaska State D No. 1 The material listed below is being transmitted via Hand de i iver¥ 1 copy Inclination Survey I certify that Exxon Alaska 'D' State No. 1 was not intentionally deviated from the vertical. R. L. Longstreet Please acknowledge receipt of the above material by signing and returning the duplicate copy of this letter. MAR ]984 Date Alaska 0il & Gas Cons. R, L, Lon~street March 8~ 1984 Date EXXON COMPANY, U.S.A. ALASKA 'D' STATE NO. 1 INCLINATION SURVEY Survey Depth Survey Angle 483 1/4° 983 3/4° 1,455 3/4° 1,950 1-1/4° 2,100 1° 2,580 3/4° 3,050 1/2° 3,549 0° 4,000 1° 4,481 1° 4,975 1-1/4° 5,460 1-3/4° 5,959 2-1/4° 6,437 1-3/4° 6,931 2° 7,430 2-3/4° 7,720 2° 8,192 1-3/4° 8,459 1-3/4° Survey Depth 8,721 8,954 9,168 9,392 9,580 10,080 10,500 11,000 11,500 11,738 12,237 12,734 12,810 '12,584 '12,671 '12,685 '12,735 '12,805 '12,989 Survey Angle 1° 3/4° 1° 1° 1/2o 1/4° 1/2° 1° 1° 1° 3/4° 4° 4° 5-1/2° 4-3/4° 3-3/4° 3-3/4° 5° 5° *Sidetrack hole around junk RLL:et 3-8-84 RECEIVED MAR 0 !984 Alaska 0i~ & G~s Cons. Comrnissio~,~ A~shora§e EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION EXXON COMPANY, U.S.A. POUCH 6601 Anchorage, Alaska 99502 TRANSMITTAL OF DATA FROM: Roy Longstreet TO:,,Fran Jones Alaska Oil & Gau Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99201 Material transmitted The material listed below is being transmitted via Exxon - Alaska State Well D-1 Hand delivery f 1 Library Tape DIFL-GR-SP 50'-13~10 1 Library Tape BHC-AL 0'-13,060' 1 Library Tape CD-CN 3790'-13,100'~~ 1 Library Tape CDL 3790'-13,100' ~ ~T' ,f-~.! ~, .- ~ 7', ! -' / Please acknowledge receipt of the above{material by " signing and returning the duplicate copy of this letter. Roy, Longstreet February 17, 1984 Date ALASKA OIL AND GAS CD,~ISERVATIO~V COMMISSION DATE: TO: RE: Bill Sheffield Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501.;-319;2 TELEPHONE (907) 279,-1433 C We wish to bring to your attention that the Commission has not yet received the following required items on the subject well which our records indicated was completed _~- ./~- ~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. Sincerely, Cha±rman September 29, 1983 'Exxon Company, U.S.A. P. C. Box 6601 Anchorage, Alaska 99502 Re: Cleanup Inspection for the Following Wellsz Duck Island Unit I~o. 2, Sec. 8, Tll~, R17E, U.M. Duck Island Unit No. 3, Sec. 10, TIlN, R17E, U.}i. Point Thomson Unit }Jo. 1, Sec. 32, T10b~, R23E, U.M. Point Thomson Unit }~o. 2, Sec. 3, T9~-~, ~22E, U.5~. Point Thomson Unit }~o. 3, Sec. 34, %~10N, R23E, U.~i. Alaskm State A-I, Sec. 27, T101~, R24E, U.M. Alaska State C-l, Sec. 14, T9~, R23E, U.M. ~'Alaska State D-i' Sec. 23, T10N, R23E, U.M. Alaska State F-i, Sec. 17, T10~, R23E, Alaska State C-2, Sec. 35, T10N, R24E, U.k4. Centle~n: Our representative inspected the above ten suspended and abandoned well sites for extension of cleanuD on August 31, 1983. With th~ exception of Alaska State C--2, the cleanup of these well sites are satisfactory. Because ~e drilling rig was still on location at Alaska State ¢~-2, a cleanup inspection could not be completed. Returned are eight approved 10-403'~, Sundry '~otices and Reports on Wells, for all the listed wells except for two which need no further approval. Alaska State 0-2 has a year to go under 20 AAC 25.170(a) and Alaska State D-I which (classified as aban- doned) has previously been granted an extension to August, 1984 for rem. oval of the sheet piling. The 10-403's which }~u submitted for Duck Island Onit ~:o. 1 and Alaska .State D-1 are not necessary and are returned unsigned. Duck Island Unit ~o. I was abandoned dcwrd~ole and Duck Island Unit L'.o. 2 was sidetracked from the well ~ore of ~;o. 1. Conse- quently a 10-403 is not required for ~o. 1. A subsequent inspection of each well will be necessary by August, 1984. Sincerely, ..' · ._ Lonnie C. Sr~'~tk C o~ r~:i s s lone r LCS/J~5': lc: 103 ~ D MEMORAi DUM Statfu of Alaska ALASKA OIL AND -GAS CONSERVATION COMMISSION TO: C. ~terton Cha Thru: Lonnie C. Smith Commissioner F~O~: Bobby FOs ter~~' Petroleum Inspector DATE: FILE NO: TELEPHONE NO: SU BJ ECT: 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 91 Point Thomson 92 Point Thomson 93 Alaska State A-1 Alaska State C-1 Alaska State D-1 Alaska State F-1 Alaska State G-2 I recommend to the Commission that all these location's with the exception of Alaska State G-2 be accepted as suspended locations in regard to pads, pits, and well signs. Alaska State G-2 is not acceptable due to the rig still being on location. In summary, I inspected the above suspended locations. Attachments Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION:-- ~ , ~-~~~~~} /~/--~ . __~_'~. Date Suspended Address ~~- iL & ~/. ~ ~~~,~ ~. Sec.~.~_, T/D ~, R~~, []M. Unit or Lease Name~/~~-j~~' Wel 1 No~ ~ ~ Field & Pool ~,~/~ r~ ] Condition of Pad ~d Condition of Pits Well head - Ail outlets plugged No Wel 1 sign - Attached to well head ~ No Attached to well guard Yes No Attached to Information correct ~ No Cellar -' Opened Yes No Fi 1 led ~ No Covered Yes No _ . _ Rat Hole Ope ~6)/Z/~e s. NO Fi 1 led Ye s No Covered Yes No WaterWell - Plugged off capped Open Explanation ~_~__ _ Photographs taken to verify above condition~ No Exp la naton Work to be done to be acceptable This well and location'~ (unacceptab_le) to, be suspended for the p_~riod of.~/~~ ~ l~thru/~6/~ ~ Ins~cted b ~~ , Date: ~-¢/-- ~ ' classified as 19~. Revised 8/24/82 POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION D.H JONES EXPLORATION COORDINATOR -- ALASKA 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-1, ~!~D~I, 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 ALASK 'IL AND GAS CONSERVATION C vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER E][ 2. Name of Operator 7. Permit No. Exxon Corporation 80-101 3. Address 8. APl Number Pouch 6601, Anchorage, AK 99502 50-089-20015 4. Location of Well 305' WEL and 1169' NSL, Sec. 23, T10N, R23E, UPM, North Slope, Alaska 5. Elevation in feet (indicate KB, DF, etc.) 13.0 MSL Ground 6. Lease Designation and Serial No. ADL 312866 9. Unit or Lease Name Alaska State D 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: (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.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). - We request a one year extension to August 1984 of the suspended status of this well. We will arrange to have the location inspected by your repr'esentative on a yearly basis or until final abandonment. RE£E VED JUL 2 8 !983 Alaska 0il & Gas Cons. Commission Anchorage Signed Title Alaska Date 7/25/83 The space below for Commissi~n use Conditions of Approval, if any:~ representatzve znspected this w~ll site on August 31, 1983 and cleanup was acceptable for a suspended location. A subsequent inspection will be necessazy by August, 1984. Returned unsigned since already has extension approval on 10-403 dated April 7, 1983; By Order of Approved by COMMISSIONER the Commission Date__ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate E .ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVtSION D.H. JONES EXPLORATION COORDINATOR -- ALASKA April 7, 1983 Location Cleanup Alaska State D-1 Mr. C. V. Chatterton, Chairman State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: We hereby request a one year extension to cut off the sheetpiling below grade and complete the cleanup of the Alaska State D-1 location. This extension is requested because we are still evaluating our future plans for this area and would like to wait until the Alaska State G-2 well has been tested and evaluated before making a decision on this matter. Possible future use of the D-1 location as another exploratory drillsite will be con- sidered at that time. Our present status allows an extension until August 1983. We request a further extension to August 31, 1984 which would allow us to conduct the work during the barging season of 1984 if it is determined that we do not have a future need for this site. Yours very truly, NB: rms NPB/68 A DIVISION OF EXXON CORPORATION RECEIVED APR 1 1 1983 Alaska 0it & Gas Cons. Commission Anchorage ..... STATE OF ALASKA ~ ALASK ,~IL AND GAS CONSERVATION ., .dMIssION 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 305' WEL and 1169~ NSL, Sec. 23, T10N, R23E, UPM North Slope, Alaska 5. Elevation in feet (indicate KB, DF, etc.) 13.0 MSL Ground I 6. Lease Designation and Serial No. APL 312866 7. Permit No. 80-101 8. APl Number 50- 089-200]5 9. Unit or Lease Name 10. WeU Number Exxon No. 1 12. 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 r~ Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We request a one year extension to August 31, 1984 to cut off the sheetpiling below grade and complete the cleanup of this location. RECEIVED APR 1 1 1983 Approved Copy Returned/ Alaska 0il & Gas Cons. O0mmission 14. I hereby certify t~~regoing is true and correct to the best of my knowledge. Signed ~/~ V mL ' ~{~~'~'~"~//"/~ Title AK/Pacific Div. Rep. The space below for Corn issio" use Date 4-7-83 Conditions of Approval, if anyA previous extension was given to August 1983. An inspection will be required by August 1983 to check clean-up other than the sheet piling. An extension to August 1984 is granted to complete removal of the sheet piling. ORIGINAL 'SiI~N'[O By Order of Approvedby ...... ~ iL~i~ ~. ~.[, COMMISSIONER the Commission Date__~ff~'~ 7--S5 Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate February 4, 1983 Mr. D. H. Jones Exploration Coordinator-Alaska Exxon Company U. S. A. P. O. Box 6601 Anchorage, Alaska 99502 Dear Mr. Jones The Alaska Oil and Gas Conservation Commission has recently checked the records of wells completed since January 1, 1979. This review has revealed that the digitized data for certain logs run in a well is not on file with the Commission. The Oil and Gas Regulations require the operator to file, within 30 days after completion, suspension, or abandonment of a drillinE well, the digitized data, if available, for copying, for all logs run in the well except velocity surveys, experimental logs and dip- meter surveys. We ~uld request that you check your records to see if the data has been submitted to the Commission and, if not, that you comply with the regulation with regard to the following wells: Pt. Thomson Unit No.. 3 Thank you for your cooperation in this matter. Yours very truly, Harry W. K~ler Commi s s ioner BY ORDER OF THE COMMISSION b~ September 13, 1982 ~xxon Company U.S,A. Box 6601 ~chorage, Alaska 99502 Re: Clean-up Inspection Alaska State D-i, Sec. 23, T10N, R13W, Cent lem~n ~ (~r representative inspected this site on August t2, 1982. You hav~ asked for this location to be abandoned and you are correct in stating that the sheet piling will have to be cut-off below grade. A one year extension wi1! be granted for this purpose. Also, if it has not been done already the casing will have to be cutoff below the final grade ~!th the well marker properly a ttac4%ed. It was noted during this ir~pection that the general clean-up of various types and sizes of debris was ngt satisfactory and that grading was not finished. It is out'position that clean-up of this. nature should have been ac¢omplishe~ this season rather than delaying until next season. Sin,cerely, / .......... Lonnie C Commissioner LCS/JKT/glh COMPANY. U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION September 1, 1982 Mr. C. V. 'Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: On August 12, 1982 a representative of the AOGCC (Harold Hawkins) along with R. L. Westbrook and R. G. Dragnich, conducted an inspection of several of our drilling locations in the Pt. Thomson and Duck Island areas. During these inspections, the representative indicated that one-year extensions on suspended wells would be approved after 'the cleanup work was completed at these locations. We therefore submit, the enclosed photographs of our Pt. Thomson #3 and Alaska State C-1 drilling locations which indicate that the cleanup has been completed. We submitted Sundry Notices requesting extensions for these locations on August 10, 1982. Also attached are Sundry Notices requesting one-year extensions on our Pt. Thomson #1, Duck Island #2, Alaska State D-l, and Pt. Thomson #2 locations.. These are wells which we wish to carry as suspended rather than abandonments. The Pt. Thomson #1 and Duck Island #2 locations were inspected by your representative who indicated that extensions would be approved. As you recall, Duck Island #1 and 2 is a single wellhead and the AOGCC has previously approved the abandonment of Duck Island #1. The Alaska State~ D-1 location was previously submitted for abandonment approval on February 18,, 1982 and was also inspected by your representative. We understand that to obtain a final abandonment status for this location, the sheetpiling will have 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"~"{'"'i".'~...'.,~ . , Mr. C. V. Chatterton September 1, 1982 Page Two We also request clarification of the status of Mobil's West Staines #2 location. This' location was inspected by your repre- sentative and discussed at a meeting with Lonnie Smith and Jim Trimble of your office and Exxon representatives Dave Galloway and Rob Dragnich. Please advise Mobil as to the requirements for their obtaining a final abandonment for this location. · Very truly yours, D. H. Jones NPB,: sjm 6o/2 Attachments (' STAli-E 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 Pnuch 6601: Anchorage, AK 99502 4. Location of Well 305' WEL & 1169' NSL, Sec. 23, T10N, R23E, UPM North Slope, Alaska 5. Elevation in feet (indicate KB, DF, etc.) 13.0' MSL Ground 6. Lease Designation and Serial No. ADL 312866 12. 7. Permit No. 80-101 8. APl Number so-089-20015 9. Unit or Lease Name Alaska State D 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~ Request extension to :~eptembe~[ ' - --~15~)1983 to cleanup location. Approved 'Lop'/ Returned '14. ' hereby certify t~t-)the.f~}~_egoing is true and correct to the best ofmy knowledge. sm.~ ' Ti~,.Alaska/Pacific Div. Rep. The space below for Commission use Date 9/1/82 Conditions of Approval, if any: This location was inspected by our representative on August 12, 1982. A one year ex.tens-ion to August 1983 is granted to conDlete the removal of the sheet piling and complete clean-UP. ORIGINAL SIGNED R¥ Order of ¢,/c::~. ~ Approvedby BY lfl~l~l[ C.SMITH COMMISSIONER the Commission Date., Form 10-403 Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate MEMORANDUM " ALASF~A OIL AND GAS CONSERVATION COMMISSION C.~,;.~~[..~ ' ~ / FILE NO: 108A/D THRU: L hie C. Smith Commissioner TELEPHONE NO: st(ate of Alaska ,, 26, 1982 FROM:Harold Ro Hawkins Petroleum Inspector SUBJECT: Inspection for Extension of Clean-up Exxon Company U.S.A. Flaxman Island, Well No. D-] Sec. 23, TION, R23E, UM .T_h_u_r_s_d_ay_,_ A_u_~u_s_t_ ~!2_,__1_9_8_2_- I left Alaska St. G-2 location, subject of a previous report, to Exxon's D-1 well at Flaxman Island. Exxon will be asking for an extension of the clean-up time on this location according to Junior Westbrook, supervisor for Exxon. Picture #1 taken from the air to the east, pictures #2, 3, 4 shows general outlay of location from the east. 'These pictures show the fuel pit and plastic liner around southwest end of fuel pit, also the 12 x 12 planks for the support equipment for the rig. Thee northwest side of these pictures show the well marker, the metal container, and burnt wood. There is also debris of several kinds spread all over the drilling pad. Picture #5 shows the fuel pit a little better with the 12 x 12 piling and plastic liner. The cellar was full of mud and water, I could not get close enough to marker to get a close-up picture of well data. I filled out an A.O.G.C.C. field report which is attached. The pictures are also attached to this report. In summary, I inspected and took pictures of Exxon's location D-1 at Junior Westbrook's request. Extension request 10-403 should be submitted by Exxon shortly. 02-00IA(Rev.10/79) Suspended Well and Location Report 20 LAC 25, ARTICLE 2 FILE INFORMATION: Operator ~.~ ~'~ ~ . ~-69. ~/, ~,~_ Addre s s Date Suspended Surface Location of Well ~' .... Ft. F ?Pt/ L, //~ Ft. Pe rmi t No. F_~_~__L aPI No. 50 Unit or Lease Wel 1 No. Field & Pool Condition of Pad /~2~/7)C M/~z%qj l'm,~,q ,~ LD~'/3fF/.t. ~/= ~fW~t~/f~&_/_~'/.,q_$f' Well head - Ail outlets plugged Wel 1 Yes No sign - Attached to weI 1 head Yes No Attached to well guard Yes No .Attached to Information correct Yes No Cellar - Opened ~s ' No Rat Hole Open e~s No Fil led No Fil led No Covered Yes No Covered Yes No WaterWell - Plugged off Capped Open Explanation_ Photographs taken to veri~fy above conditions(Yes) No . Explanaton .7-~. ~'~!:~ Work to be done to be acCeptable ~F/JEnA~. f'~ ~,~uP ,'F/~, A~ ~=~/~/~C This well and location is (acceptable) ~tabl~~to be suspended .for the period of '19~'~hr-f~ ' ~' ~ . ' ,, / ~' .~ ~-,~ ..... Da te: z~'''~:t' ] :~: '"'~' .... classified as 19 . Revised 8/24/82 E) ON COMPANY. U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 March 18, 1982 Re: Exxon Alaska State 'D' Well No. 1 ADL 312866 North Slope, Alaska Dear Mr. Chatterton: We are attaching two copies of Form 10-407, Well Completion or Recompletion Report and Log, for the captioned well whiCh was plugged and abandoned on February 16, 1982. Also, we submit the following data: (1) One set of washed and dried samples from 90' to 13,050'. (2) One blueline and one sepia print of the complete mud log from 108' to 13,050'. (3) One composite sepia, one composite blueline print of the following open hole logs: Dual Induction Focused Log BHC Acoustilog Compensated Densilog-Compensated Neutron Diplog Compensated Densilog As soon as digital magnetic tapes are available from Dresser Atlas on the above logs, except the dipmeter, we will transmit a copy for your files. (4) Core chips taken at 1' intervals from the following cores: Core No. Ir, terval 1 11,738'-11,746' Please note that the above material is marked confidential and should be kept confidential in accordance with the provision of 20 AAC 25.537(d). RLL :et attachments Very truly yours, ~o~L. Longstreet RECEIVED MAR I 8 1982 Alaska Oil & Gas Cons. Commission Anchorage A DIVISION OF EXXON CORPORATION ' ' ALASKA;,,..,,..g AN:D GAS CONSERVATION d~ , .,~'ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOO 1. Status of Hell · OIL [] SUSPENDED [] ABANDONED E~ SERVICE [] Classification of Service Well GAS [] , .2. Name of Operator ' 7. Permit Number Exxon Corporation 80-101 3. Address 8. APl Number Pouch 6601, Anchorage, Alaska 99502 50-089-20015 4. Location of well at surface 305' WEL & 1169' NSL, Sec. 23, T10N-R23E, U.M. At Top Producing Interval NoAo At Total Depth 305' WEL & 1169' NSL, Sec. 23, T10N-R23E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 38' KB I ADL 312866 9. Unit or Lease Name Alaska State D 10. Well Number Exxon No. 1 11. Field and Pool Wildcat 12. Date Spudded 113' DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water Depth, if offshore 116. No. of Completions 11~"1-81 [ 2-1-82 2-16-82 IN.A, /set MSL I ' 0 ' .,7. Tota, De~;'th(MD+TVDI /,8. P,ugBackDepth(MD+TVDI 19. DirectionalSurvey 20. Depth where SSS~C'set 12,. Thickness of Permafrost 13,050' ND & T~CD Surface YES [] NO~] NoA. feetMD I 1210' from KB 22. Type Electric or Other Logs Run Dual Induction, Acoustilog, Compensated Neutron-Density, Dipmeter, Velocity Survey 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP 30" 310 B 133 K55 20" '13-3/8" 9-5/8" 72 43.5 L80 Pll0 SETTING DEPTH MD BOTTOM 35' 110' 35' 2056' 35' 3998' 35' 10082' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 27. None HOLE SIZE 26" CEM EN'I:'I NG RECORD Est. 600 $x permafro 5'380 sx permafrost AMOUNT PULLED ,0 0 17-1/2 600 sx class G 0 12-1/4 1680 sx class G 0 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) None PRODUCTION TEST IAMOUNT& KIND OF MATERIAL USED Date ;First Production. No Tests Date of Test / Hours Tested '' Flow T'ubing. '/Casing Pressure Press.'· r · 28. Method of Operation (Flowing, gas lift, etc.) PRODUCTION FOR [OIL-BBL I GAs-MCF TESTPERIOD I~ I . I CALCULATED' ]1~ {IOIL'I3BL , GAS-MCF 24,HQ,UR RATE-~ I " CORE DATA WATER-BBL CHOKE SIZE GAS-OIL RATIO WATER-BBL OIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core #1 11,738' to 11,746'..:. Rec 8' sittstone, shaley, poor p & p, no oil stain. RECEIVED MAR 1 8 1982 Alaska Oil & Gas Cons. CommissiOn Anchorage Form 10-407 Submit in dupli, Rev. 7-1-80 CONTINUED ON REVERSE SIDE MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Ter t iary Cur face Cur face None Paleocene 9579 9579 Pre-Miss 12,720 12,720 31. LIST OF ATTACHMENTS Well History 32. ~ hereby certify that the fore§oin§ is true and correct to the best of m¥ knowledge /~,~ j~6~'~~ Geological Si§ned Title Advisor Date 3/18/82 I NST R UCTI ONS 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. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be seParately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage .cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Suggested form to be insertcd in e "Active" well folder to check for tingly compliance witJ~ our regulatiop~. ' ' Oim~ator, Well Name-and Number R.~]uired Date Received Remarks Ccmple. ti~on RePOrt ..,. Yes ...... Registered Su~ey Plat ' y .... Drill St~ Test Re~:s , , . .... Pr~u~ion T~t Re~rts ' ., ~s R~ Yes , CURVE DATA LO. CATED IN THE APPENDIX ALASKA OIL AND GAS CONSERVATION COMMISSION C. V~~e/ton Chai~ THRU: L. C. Smith ~, ?!;~' , Commissioner Ben LeNorman ~' Petroleum Inspector March 17, 108A/A I 1982 Witness Plugging of 9 5/8" - 13 3/8" Annulas on Exxon's Alaska State D-i, Sec 23, T10N, R23E, UM. -- WILDCAT. Monday, March 8 - I departed my home at 4:20 PM for a 4:50 PM ShOWUp and 5':'50 PM departure via Alaska. Airlines Flt. #87 for Deadhorse arriving at 8z10 PM. Weather: -17"F, clear, light wind. Tuesday, Marc.h 9 - Plugging of annulas on D-1 began at 10:30 AM and was' compIe-~ed at 11..50 AM. Plug and abandonment report is attached. Wgd-ne~ay,~-March !.9 - Standing by on Sohio's X-18. Thursday, March 11 - B.O.P.E. tests on Sohio's X-18 were ~Pleted-,~ the'~SUbject of a Separate report. Friday, March 12 - B.O.P.E. tests on Sohio's D-17 were C~pl~ted'''~ ~he"~Ubject of a separate report. I departed Deadhorse '~a the Sohio charter at 1:10 PM arriving in Anchorage at 2:40 PM and at my home at 3:10 PM. In summary, I witnessed successful plugging of 9 5/8" - 13 3/8" annulas on Exxon's ~aska State D-1. O&G 4/80 Operator .. ~X)f.~9~ Company Repr ~&)~O ~F B~T~ Lease No, ~;~&& Well No. Total Depth /~. ~'~) Elevation/~.O'~-~ ~. Mud Wt. STATE ~F Al,a.q~'' '~, ALASKA OIL & GAS C('I~SERVATION COMMISSION Plug & Abandonment Report Date Drilling Pemit Sec. T-R ~. Cas ing: DriVe Pipe ~) "O.D. Set at ,;/~); Ft. w/ Pene. Conductor .~ "O.D. @ ~; ;~ Ft. Surface /~~ "O.D. Intermediate F "O.D. @/~ ~ ~ Ft. Production__"O.D. @ Ft. Plugging Data: 1. Open hole plugs: 2. Open hole isolation plugi 3. Perforation plugs (if any): 4. Annulus plugs (if any): 5. Casing stub plugs: 6. Surface plug: Casing removal: "casing cut at ' "casing cut at ' "casing cut at ' REMARKS: Inspector/s :~ ALASK/~ 'L AND GAS CONSERVATION C~i/IMISSlON ..~ '~ MONTHLY REPORT OF DRILLI#G AND woRKOVER O ERAI'IO#$ 1. Drilling well IX] Workover operation [] 2. Name of operator 7. Permit No. W. xxon Corporation 80-101 3. Address 8. APl Number Pouch 6601, Anchorage, Alaska 99502 50-089-20015 9. Unit or Lease Name Alaska State D 4. Location of Well at surface 305w WEL & 1169' NSL, Sec. 23, T10N-R23E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KB 30'I ADL 312866 10. Well No. Exxon No. 1 11. Field and Pool Wildcat For the Month of February · 19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks EOM Depth: 13,050'. Mo. Footage: 73'. Set a 200 sack cement plug in the 8-1/2" open hole from 11,240'-11,640'. Squeeze below a retainer set at 9976' with 95 sacks cement and placed 25 sacks on top of retainer. Displaced mud in 9-5/8" csg from 2000' to surface with calcium chloride water. Spotted a permafrost cement plug from 150' to surface. Install abandonment flange. Well plugged & suspended at 1600 hours 2/16/82. 13. Casing or liner run and quantities of cement, results of pressur9 tests 14. Coring resume and brief description 15. Logs run and depth where run 13,050': DIL, BHC Sonic, FDC-CNL, Dipmeter, Velocity Survey 16. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SlGNED ~~~~~ TITLE Geolog. ical~ Adv i sor. DATE 3/15/82 NOTE--Report on, his form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 -ALASKA ,I_ AND GAS CONSEFIVATION C ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS OTHER 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Exxon Company U.S.A. 80-101 3. Address 8. APl Number Pouch 6601, Anchorage, AK 99502 50-089-20015 4. Location of Well 9. Unit or Lease Name Alaska State D 305' WEL and 1169' NSL, Sec 23, TlON-R23E, UM 5. Elevation in feet (indicate KB, DF, etc.) 13.0 ft MSL Ground 6. Lease Designation and Serial No. ADL 312866 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 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). This is a notice of change of intended plans for the captioned well, and of work completed towards the changed plans. Rather than abandoning the well from TD to 4050 ft, as approved February 5, 1982, the well will be permanently abandoned. The permanent abandonment plans are shown in the attached sketch and described in the attached procedure. The abandonment, through Step 6, "is work completed. The work was done per verbal approval by Blair Wondzell' as described in phone conversation between; Robert G. Dragnich and Blair Wondmell February 13, 1982. The well will be permanently abando~ed when Steps 7 through 9 are completed. This will be done after the rig is mowed off the location prior to ice road break-up-1982. Until this time, the 13-3/8" x 9-5/8" casing annulus will be used for injection of waste fluids. The wellhead will be abandoned as shown in the attached sketch. The ~e~tions shown on the sketch are -approximate elevation of final abandonment. R E C E ~ Approvad F E B 2 2 1982 "~""'- ~ ~ ~laska 0il & Gas Cons. C0mmissJ0~ 14. I hereby Certify t ng is tru to the best O~ mY-knowledge. Signed ~'f/~'/'~ ~Z~~/ Title Div. Drilling Manager The space below fo~n~--use " Conditions of Approval, if any: NOTIFY (IIVIVf[SSION SO A REPRESENTATIVE CAN BE PRESENT ~0, WItlESS STEPS' 7-9. By Order Of .,,~____~____.~ Approved by BY ~.[~N~E ~,. SJ~I]'~ ..... COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Exxon No. 1 Permanent Abandonment The following work was done under verbal approval of Blair Wondzell, given February 13, 1982, per phone conversation between Blair Wondzell and R. G. Dragnich that date. The work'was also done as approved under original planned abandonment approved February 5, 1982. · Run in and set a 200 sack class G balanced plug from 11,604 ft. to 11,240 ft RKB. 2. Run and set a Halliburton EZSV retainer at 9976 ft. · Cement through the retainer, squeezing 95 sx below and leaving 25 sx above the retainer. This leaves class G cement from ± 10,200 ft to 9,908 ft RKB. 4. Test the plug to 1700 psi for 15 min. NOTE: Blair Wondzell waived requirement to witness the setting and testing of this plug February 14, 1982. · · Displace 15.7 ppg mud from 2000 ft to surface with 10.2 ppg CaC1 solution. 2 Set a 70 sack permafrost cement plug from 150 ft RKB to surface. The following steps are planned as final abandonment of the Alaska State D-1 wellbore: · Pump permafrost cement down the 13-3/8" x 9-5/8" casing annulus from surface to the 13-3/8" casing shoe. NOTE: This step will be completed prior to ice road break-up 1982, after the annulus has been used for waste fluid injection. · Blind flange the well head B-section as shown in the attached sketch. Place a dry hole marker constructed, attached and marked per April 1980 AOGCC regulations Article 2 section 120. The marker will be bead-welded as follows: EXXON CORPORATION ALASKA STATE D EXXON NO. 1 305 ft WEL 1169 ft NSL SEC 23 T10N R23E UM · Back fill the wellhead cellar with gravel to pad grade~c~lV~D! CMR: rms 210C/C AS ?~ANDONED (1) ALASKA STATE D EXXON No. 1 B Section Capped A Section Permafrost Plug 0-150 ft 30" Structural Conductor at 110 ft Permafrost cement to surface Permafrost horse collar 20"'x 13-3/8" to 2100 ft 10.2 ppg CaC12 to 2000 ft 20" 133 lb/ft K55 BTC conductor casing @ 2056 ft TOC approximately 3000 ft class G 13-3/8" 72 lb/ft L80 BTC surface casing @ 3998 ft 9.6 ppg Mud cement below 13-3/8" shoe (1) permafrost 13.0 ppg PIT 15.7 Ppg Mud TOC approximately 7500 ft class G Plug tOp 9908 ft 120 sacks class G HOWCO EZSV retainer @ 9976 ft 9-5/8" 43.5 lb/ft Pll0 LTC protective casing @ 10,084 ft 11.5 ppg Mud Plug Bottom ~ 10,200 ft 17.5 ppg Pit 15.7 ppg Mud 200 sack class G cement plug 11,240 ft - 11,604 ft (1) 13-3/8" x 9-5/8" annulus to be abandoned prior to ice road break-up-1982 15.7 ppg Mud 12,898 ft Sidetrack @ 12,659 ft TD @ 13,050 ft 8-1/2" hole 15.7 ppg Mud FEB 2 2 Alask~ Oil & Gas Cons. Comm~ssio~, .~LA.SKA, STATE D EXXON ~0. 1 WELLHEAD ABANDONMENT Well Marker per AOGCC Regulations Article 2 Sec. 120 April 1980 Pad Level 30" 28" Gravel Fill L Blind Flange Wellhead B-Section Wellhead A-Section 20" Conductor Casing -130" Conductor Natural Island Level Wellhead Cellar- Ba~kf ill with Gravel ' CONF) _TtAL _ STATE OF ALASKA !;" ' " ALASKA ('. AND GAS CONSERVATION C(3( vllSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERA I'I N well [] Workover operation [] !//'-~ Drilling F\ 2. Name of operator 7. Permit No. Exxon Corporation 80-101 3. Address 8. APl Number :Pouch 6601, Anchorage, Alaska 99502 50-089-20015 9. Unit or Lease Name Alaska State D 4. Location of Well atsurface 305' WEL & 1169' NSL, Sec. 23, T10N-R23E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KB 30' ADL 312866 10. Well No. Exxon No. 1 11. Field and Pool Wildcat For the Month of January ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks · EOM Depth: 12,977'. Mo. Footage: 997'. At 12,896' left 2-1/2 bit cones in the hole. While fishing for the cones we left 2-1/2 more cones, a l"xl"x2" piece off the bottom of a mill and a jet basket skirt (1.34' long) in the hole. Did not completely recover junk from hole. Placed a 175 sack class G cement plug in the 8-1/2" open hole from TD to 12,494'. Sidetrack hole kicked off at 12,659' using a dynadrill and a diamond sidetrack bit. 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run 12,897': DIL, LSS 16. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, r' /~ ~~~~ Alaslm 0il & Gas C0ns. C0mmjss[0. SIGNED _ TITLE Geoloqical Associate DATE 2-16-8~mch0rage' ~ form is requ or each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska NOTE--Report on Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1 ALASK L AND GAS CONSERVATION C . ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL ~] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. Exxon Corporation 80-101 3. Address 8. APl Number Pouch 6601, Anchorage, Alaska 99502 50-089-20015 4. Location of Well 305' WEL and 1169' NSL Sec 23, T10N - R23E, UM 5. Elevation in feet (indicate KB, DF, etc.) ]3.0 12. 6. Lease Designation and Serial No. AnT. 312866 9. Unit or Lease Name Alaska State D 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 [] [] Other [] Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 3. 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). This is notice of intention to abandon the captioned well from TD to 4050'. This well will be abandoned as shown in the attached wellbore sketch. ProcedUres for abandonment are also attached. When the well has been plugged back to 4050', it is planned to directionally sidetrack the D-1 wellbore from beneath 13-3/8" surface casing. The sidetracked D-1 wellbore will be drilled to a bottom hole location shown on our application for Permit to Drill Alaska State "D" Exxon No. 2 submitted February 1, 1982. We plan to begin abandonment operation February 5, 1982. RECEIYEI) Subsequent Work Reported on Form No./~3 Dated ---~1/~---~ F E B 0 5 1982 Alaska 0il & Gas Cons. Comml: Anchorage 14. ' hereby certify tJ;;~l; ~he foregoing~ue 9nd correct to Signed/'~; The space below for Commissi~%n~.use, se.~,// ' Conditions of Approval, if any: Notify the Cozmission so that a represent, itive_ean w~tness the e~ent pl~ ~d testis. ~pp~ved . ORIGINAL SIGNED BY tOfl'~E C. SMIT9 ~-'J- F~By Order of Approved by best of my knowledge. Title Division Drilling ManagerDate Form 10-403 Rev. 7-1-80 Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate PROi)OSED' ALASKA STATE D EXXON NO. 1 WELLBORE SKETCH AS ABANDONED TO 4,050' m 1,00.0 2,000 -- ~----B Section A Section f.~ 30" Structural Conductor @ 110' Permafrost Cement to Surface Permafrost Horsecollar 20" x 13-3/8" to 2,100' 20" 133#/'. K55 BTC Conductor ~ 2,056' 3,000 4,000 5,000 "' T0C Approximately 3,000' Plug Top 3,800' (To be Sidetracked ~ 4,050') 1 8" . - 3-3/ 72#/' L80 BTC Surface Casing ~ 3,998' 9.6 ppg Mud 13.0 ppg Pit lug to 4,300' k--9-5/8" Casing Cut to 4,200' and pulled 250 Sack Class G Cement Plug 6,000' ' ..... 7,000 -- 8,000 - 9,ooo -- 10,000 11,000 -- 12,000 -- 13,000 -- CMR: bsw 2/2/82 12,898 11.5 ppg +'Mud Weight T0C Approximately 7,500' Class G Plug Top 9,800' HOWCO EZSV ~'10,000' · 9-5/8" 43-1/2#/!. Pll0 LTC Protective Casing ~ 10, Plug to 10,230' %j.150 Sack Class G Cement Plug -' .)" 150 Sack Class G Cement Plug 11,200' to 11,600' .~ 15.7 ppg Mud Weight ~ TD ~ 13,050' 8-1/2" Hole 15.7 ppg Mud 084' - 11.5 ppg Mud 17.5 ppg Pit FEB 0 5 ]982 0il & Gas Cons, Commission Anchorage Alaska State D Exxon No. 1 Abandonment to 4050' This is a basic procedure for abandoning the D-1 wellbore from TD to 4,050'. The procedure begins following all evaluation of the 8-1/2" open hole. I · Run in and set a balanced cement plug from 11,600' to 11,200'. Total cement required - 150 sacks class G. 2. Run and set a Halliburton EZSV cement retainer to 10,000'. · Run in and cement through the retainer to the shoe (10,084') with enough cement to reach 10,230'. Pick up out of the retainer and leave cement on top of the retainer to 9,800'. Total cement required - 150 sacks class G. 4. Test 9-5/8" casing and cement plug to 1,000 psi. 5. Pick up to 4,300' and circulate mud back to 9.6 ppg minimum. · Nipple down the blowout preventer stack and nipple down and remove the C-Section. 7. Nipple up and test the BOP stack. 8. Run in and mechanically cut the 9-5/8" casing at 4,200'. · Spear the casing in the B-Section and pull out of the hole laying down casing. 10. Run in the hole to 4,300' and spot a cement plug from 4,300' to 3,800', "in and out", on the 9-5/8" casing stub. Total cement required - 250 sacks class G. 11. Dress the cement plug to 4,050' and directionally sidetrack the D-1 wellbore to the bottom hole location on the Permit to Drill Alaska State D Exxon No. 2 submitted to the AOGCC February 1, 1982. NOTE: The plug will not be dressed deeper than 3,900' until the approved Permit to Drill Alaska State D Exxon No. 2 is received. CMR: b sw 92/E 2/3/82 RECEIVED: FEB 0 5 1982 Alaska Oil & Gas Cons. Commission A~chorage ALASKA S~ATE D EXXON NO. 1 WELLBORE SKETCH 0 1,000 2,000 3,000-- 4,000-- · :. t:1'.1 .~o :... 5,000. 6,000-- 7,000-- 8,000-- 9,000" 10,000-- 11,000-- 12,000 13,000 --i2,898 ' CMR: b sw 2/2/82 C Section B Section A Section 30" Structural Conductor @ 110' Permafrost Cement to Surface Permafrost Horsecollar 20" x 13-3/8" to 2,100' 20" 133#/, K$5 BTC Conductor @ 2,056' TOC Approximately 3,000' Class G 13-3/8" 72#/, L80 BTC Surface Casing @ 3,998' 9.6 ppg Mud 13.0 ppg Pit TOC Approximately 7,500' Class G 9-5/8" 43-1/2#// Pll0 LTC Protective Casing @ 11.5 ppg Mud 17.5 ppg Pit 10,084 ' RECEIVED FEB 0 5 1,982 Sidetrack @ 12,659' TD @ 13,050' 8-1/2" Hole 15.7 ppg Mud Alaska Oil & Gas Cons. Commission Anchorage CONFi IAL CONFIDENTIAL .vllSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well~[~] Workover operation [] Name of operator Exxon Corporation Address Pouch 6601, Anchoraqe, Alaska 99502 Location of Well atsurface 305' WEL & 1169' NSL, Sec. 23, T10N-R23E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) KB 30' 6. Lease Designation and Serial No. ADL 312866 7. Permit No. 80-101 8. APl Number 5O-- 089-20015 9. Unit or Lease Name Alaska State D 10. Well No. Exxon No. 1 11. Field and Pool Wildcat For the Month of. December ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud da~e, remarks EOM Depth: 11,980'. Mo. Footage: 3,110 '. During the month mud weight was increased from 10.3 to 15.8 ppg. 13. Casing or liner run and quantities of cement, results of pressur9 tests 9-5/8" csg: Set at 10,082' & cemented w/1680 sacks class G cement. PIT at 10,094' did not leak off at 17.5 ppg EMW. '14. Coring resume and brief description Core ~1 11,738' to 11,746': Rec. 7.8' siltstone with no stain. 15. Logs run and depth where run 10,084': DIFL, CNL-CDL, Acoustic, Dipmeter 1 6. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED .. _____ TITLE Geological Associate DATE 1/15/82 e~poLr %r~h NOTE--R t is form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 · ' ~ STATE OF ALASKA AlaSka ~ AND GAS CONSERVATION CO_~ ;ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OpERATIONS; 1. Drilling well I--NJ Workover operation [] 2. Name of operator 7. Permit No. Exxon Corporation 80-101 3. Address 8. APl Number Pouch 6601, Anchorage, Ak, 99502 5o- 089-20015 4. Location of Well atsurface 305' WEL & 1169' NSL, Sec. 23, T10N-R23E, U.M. 9. Unit or Lease Name Alaska State D 10. Well No. Exxon NO. 1 11. Field and Pool Wildcat 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KB 30' ADL 312866 For the Month of. November ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud well 0001 hrs 11/1/81. EOM Depth: 8870' Mo. Footage: 8870' 13. Casing or liner run and quantities of cement, results of pressure tests 20" csg: Set at 2056' & cemented w/5130 sx permafrost. Top off w/250 sx permafrost. 13-3/8" csg: Set at 3998' & cemented w/600 sx class 'G'. 'PIT at 4015' leaked off at 13.2 ppg EMW. Ran PIT at 7244. Leak off occurred at 10.7 ppg EMW. 14. Coring resume and brief description 15. Logs run and depth where run 2100': DIFL, Acoustic, 4 Arm Caliper 4000': DIFL, Acoustic, 4 Arm Caliper 1 6. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ('-~" ~,~,t. ~ ~)/q~\ .~,~.~. Supervisor- SIGNED . /~ ,. TITLE Operations Geology DATE December 14, 1981 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 E ON. COMPANY. U.S.A. .. POUCH6601 ANCHORAGE, ALASKA 99502' P':'"'~' ::"" :~ November 24, 1981 EXPLORATION DEPARTMENT [ - LO/NS 81-159 ALASKA/PACI FIC DIVISION ~'~. Su[~. ~oc.: Sec. 17, ~10~, R23g, ~z ~E~~ BH Loc.: Sec" 18 T10N, R23E ~xxon ~laska Stato D ~ell ~o. 1 hO/~S ~0-226 Surf. ~oc.: Sec. 23, ~DB 312866 BH Boc.: Same Mr. Glenn Harrison, Director Division of Minerals & Energy Management Pouch 7-005 Anchorage, Alaska 99510' Dear Mr. Harrison: By this letter we are requesting an amendment of each of the subject plans of operation to permit the storage of a portion of the casing required for each of the drilling operations in progress in a manner which will require its extension beyond the drilling pad and onto the ice covered land area adjacent to each pad. As the casing stored in this manner will have been run in the hole at each location long before spring break-up occurs we foresee no possibility of an environmental disturbance of any kind occurring as a result of this procedure. Accordingly, we are requesting your permission to store casing in the manner described and your amendment of the operations permit to so provide for such storage. In the event there are questions or further information of any nature is required please do not hesitate to contact the undersigned and it will be provided. ~ ~' Yours very truly, Robert K. Riddle RKR:et cc: Ak. Oil & Gas Conservation Commission, Attn: Hoyle H. Hamilton Ak. Dept. of Environmental Conservation, Attn: Douglas Lowery Ak. Dept of Fish and Game, attn: J. Scott Grundy Div. of Forest, Land & Water Management, Attn: William Copeland · A DIVISION OF EXXON CORPORATION ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton Chairman Thru.- Lonnie C. Smith Commissioner Bobby Foster; ?~ l:~tr oleum Inspoctor November 18, 1981 Witness BOPE Test on Exxon's Alaska State D-1 Sec. 23, T10N, R23E, UM. Permit #80-101 S~un_day_ November.. r 15,_. 1981 - After witnessing the BOPE test on ExxOn's F-1 I went to D~i to witness the upcoming BOPE test. The BOPE test began at 2:30 p.m. and was completed at 5530 p.m. As the attached BOPE inspection report shows there were no failures. In summary I witnessed the BOPE test on Exxon's D-1. O&G 4/80 ~4 STA'['t': '~!' AI,A,qKA f YJ~ Oil, & GAS (".' ..;I:;RVATIO~; COt~,~oSIGN B.O.P.E. Inspection Rel)ort // Date // ................ ...... ~ ~" m ,:-'~c';M /~.:'?'Casir:g Set ~,..', General Housekeeping Reserve-pit . BOPE Stack Annular Preventer Pipe Rams Blind Rams ChOke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test. 'Results: Failures Test Pres sure ACCUtlULATOR SYSTEM !iFull Charge Pressure .%c9 c' I') psig Pressure After Closure/.'~ ' ~" psig 200 psig Above Precharge Attained: min.:-~O Full Charge Pressure Attained: ,.'~! N2 . ., -- .' ','~i" , .",.' .~"',') p s ig Controls: Master, ~~ Remote ~_:::~ Blinds switch cover.~t',...~: Kelly and Floor Safety Valves Upper Kelly / Test Pressure ~:~Y'~ / Lower Kelly Test Pressure ~-~ ,~""'J'.~9 Ball Type / Test Pressure Inside BOP / Test Pressure Choke Manifold .::Z ~ Test Pressure ~o. Valves No. flanges </t0 Adjustable Chokes ..... Hydrauically operated choke / T~-:'t-T':&' .?.,..... -~:s. Repair or Replacement of failed equipment Inspector/Commission office notified. Remarks': to be made Within .... days and Distribution orig~ - nO&GCC cc - Operator cc - Supervisor Inspector E] ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 PRODUCTION DEPARTMENT ALASKA OPERATIONS October 28, 1981 Mr. Hoyle H. Hamilton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Hamilton: Attached are two Sundry Notices which request approval to set the 20" 133 ppf casing at 2000' instead of 2200' on each the Exxon Alaska State D-i and F-1 wells. The notices also inform you of a change in our 20" casing running procedure. The slips and elevators available for running the 20" casing on both locations are rated to 150 tons. To allow for our overpull safety factor, we will allow a maximum hook load of 100 tons. The combination of setting 200' less of 20" casing, plus floating in the last five (5) joints (procedure change) will assure we stay below our maximum allowable hook load. Very truly yours, Drilling Manager RLS: sjm Attachments 295-663-665 cc: L. Smith (AOGCC) OCT 2 ]$8? r ~t~' '~, ~ ~kr~ Oil & Gas Cons. Co~m~ss~or~ A~chora¢~ A DIVISION OF EXXON CORPORATION STATE OF ALASKA ALASK IL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL I~ COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Exxon Corporation 80-101 3. Address 8. APl Number P. O. Box 2180, Houston, Texas 77001 50-089-20015 4. Location of Well 9. Unit or Lease Name Alaska State 'D 305' WEL and 1169' NSL Sec. 23, T10N-R23E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. +3.0' Mean Sea Level (Ground)I ADL 312866 12. 10. Well Number Exxon No. 1 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 E] 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). ._ Change 20" casing shoe depth to 2000' from 2200' plus revise 20" casing running procedure to "floating" in last 5 its. These changes are required in order to maintain the total maximum running hook load plus safety factor below the rated capacity of the 20" casing elevators and slips. RECEIVED OCT 2 9 ].~8} Alaska 0il & Gas Cons. Commission knch0rag~ fy ~ ~e~f 14. t hereby certi oregoil~g is true and correct to the best of my knowledge. Signed ~ ~ 1~~~%--'-~' Title Division Drilling Manager / The space below fo~,~ommi~ion use Conditions of Approval, ~f any: Approved Cop~ Approved by BY LONfll[ C. SMITIt Returned By Orde~ of COMMISSIONER the Commission D,te ,,/0/ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Royle H. Hamilto~ Chairman Thru.- Lonnie C. Smith / Commissioner Doug Amos f~"~ Petroleum Inspector ALASKA OIL AND GAS CONSERVATION COMMISSION October 23, 1981 Conduct Inspection oD_~Divert e r .S~.t~ em.s~ o_~o.n~ Well, ADCo Rig'No"~ ,--~-~ Alaska State F-I, ADCO Rig No. 5 and Sohio's Sag Delta #9 Well Nabors Rig No. 22E. Wednesday ~tober 14,. 198~ - I traveled this date from Anchorage to ~udhoe Bay. AS the attached pictures, No. 's 1-4 show, the diverter ~stem on ADCO Rig #4 Alaska State D-1 well, is installed and is in compliance with our requirements. As the attached pictures No.'s 5-9 show; the diverter system on ADCO Rig NO. 5 Alaska State F-1 well, is installed. There is some fitting left to be done on the line running to the mud pit. Pictures 5 and 6 show the remaining work to be completed. This system is in compliance with our requirements. As the attached pictures No. 's 10-15 show, the diverter system on Nabor's Rig #26E Sohio's Sag Delta #9, is installed and is for the most part in compliance with our requirements. I do not recommend that the Commission approve another diverter system with the type of 90· elbows used on this system. API RP53 recommends that for 90e turns, a targeted tee be used. This was the only problem area I found with this diverter system. In summary I conducted the inspection on the diverter ~fstems on Exxon's D-1 and F-1 wells and on Sohio's Sag Delta #9 well. As the attached pictures show the diverter systems are installed, and do meet our requirements as approved. There is still some fitting to be done on ~xon's F-1 well, as pictures 5 and 6 indicate. ' I recc~amend that the Commission not aPprove any more diverter systems with 90e elbows on the diverter lines. As per API RP53 these turns should be with targeted tees. COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 October 16, 1981 EXPLORATION DEPARTMENT ALASKA/PACIFIC-DIVISION Re: Exxon Alaska State "F" Well No. 1 LO/NS 81-159 Surf. Loc.: Sec. 17, T10N, R23E, UM ADL 312863 BH Loc.: Sec. 18, T10N, R23E, UM ADL 312862 ~n ~las~ state "D" W~ --LO/NS 80-22~ " Surf. Loc.: Sec. 23,'T10N, R23E, UM ADL 312866 BH Loc.: Same Mr.'Glenn Harrison, Director Division of Minerals and Energy Management Pouch 7-005 Anchorage, Alaska 919510 Dear Mr. Harrison: Today I met with Mr. William van Dyke and explained Exxon's desire to amend each of the subject plans of operation to provide for the cOmmencement of downhole drilling at each location on October 24, 1981 instead of November 1 as presently provided in each plan. As the several members of your staff who have visited each site will attest, each location has been completed, and the drilling rigs, Arctic Alaska Drilling Company Rig No. 4 (D-l) and Arctic Alaska Drilling Company'Rig No. 5 (F-l), as well as all necessary equipment and supplies have been on location and ready for the commencement of drilling operations for a period of several months. It is Exxon's belief predicated upon the experience gained in the drilling of each of the wells which we have drilled in the area of the subject operations, commencing with Flaxman Island State No. ! in 1975 throughout the drilling cf the four Pt. Thomson Unit wells, the last which was completed one year ago, that drilling operations could be commenced one week in advance.of the stated date, November 1, without any environmental risk or adverse consequences of any nature. Permafrost may be anticipated for the initial 1200 to 1500 feet and neither hydrocarbons, gas hydrates nor shallow hazards of any kind may be expected to be encountered in the formation which will be penetrated in either drilling operation were you to authorize our commencement of such operations one week in advance of the scheduled date. A DIVISION OF EXXON CORPORATION While this requested variance of one week from both the lease provisions and Exxon's plans of operation as previously submitted may seem of little consequence, especially if viewed in relation to the six and one-half months the AADCO Rig No. 4 has been on the Alaska State D-1 location, it is by no means incon- ceivable that such variance could provide just the required amount of additional time at the conclusion of the operations to permit the wells to be completed within the time constraints provided for the conclusion of drilling operations. We readily acknowledge that we have come to you with this request very late in this, the last month before the stated commencement date, however, you may be assured that any consideration which may be given to it will be sincerely appreciated. Yours very truly, Robert K. Riddle RKR:et cc: Ak. Oil & Gas Conservation Commission, Attn: Hoyle H. Hamilton Ak. Dept. of Environmental Conservation, Attn: Douglas Lowery Ak. Dept. of Fish and Game, Attn: J. Scott Grundy Div. of Forest, Land & Water Management, Attn: William Copeland August 25, 1981 Mr. Otto Raft Exploration Coordinator Exxon Corporation Po O° Box 2180 Houston, Texas 77001 Re: Alaska State D Exxon No. 1 Exxon Corporation Permit No. 80-101 Sur. Loc~: 305tWEL, 1169~NSL, Sec 23, T10N, R23E, Bottomhole ~o: S A M E Dear Mr° Rath~ Enclosed is the approved revised application for permit to drill the above re ferenced ~11. The provisions of the cover letter, dated November 14, 1980, accompanying the original approved permit are in effect for this revision. To aid us in scheduling field work, we would appreciate your notifying this office at least 48 hours before the well is spudded. We would like to be notified so that a representative of the Commission may be present to inspect ~? d.i~e~rter~.._syste.~ before the condUctor shoe is-drilled and also ~o-r~wi~tness"the testing of blowout preventer equipment before the surface casing shoe is drilled° Very truly yours, Ho2 H. Hamilton Chairman of Alaska Oil & Gas Conservation Commission Enclosure cc: Department. of Fish & Game, habitat Section w/o encl. Department of EnVironmental Conservation w/o/eric1. COMPANY. U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION Re: August 21, 1981 Exxon Alaska State "D" No. 1 Section 23, T10N-R23E, U.M. ADL 312866 Arctic Slope, Alaska Permit No.: Mr. Hoyle H. Hamilton, Chairman State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton: In response to our application of August 29, 1980, you issued a permit on November 14 for Exxon to drill the subject well. As a number of changes have been made, however, in the plans for the well since the issuance of the permit, we have elected to refile the application for Permit To Drill, 10-401, rather than to attempt to cover the changes by Sundry Notice. Accordingly, we are submitting such application in triplicate with this letter in lieu of that previously submitted and ask that the prior permit be cancelled. The well will be drilled by Arctic Alaska Drilling Company's Rig No. 4 instead of Parker Drilling Company's Rig No. 96 as previously stated. In all other respects the approved plan of operation, LO/NS 80-226, the vicinity and location plats and the statements made in our letter filed with our original application remain current, thus no substitution will be made at this time and none is anticipated. Yours very truly, Robort K. R'iddlo RKR:et enclosure c w/encl: EPA - Region Ten, Attn: Danford Bodien, P.E. North Slope Borough, Attn: Shehla Anjum DMEM, Attn: Glenn Harrison RECEIVEO A DIVISION OF EXXON CORPORATION AUG 2 1 198I Alaska Oil & Gas Cons. Commission Anchorage PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~[] R'EDRI LL [] DEEPEN [] lb. Type of well EXPLORATORY ~] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator Exxon Corporation , 3. Address P. O. Box 2180, Houston, Texas 77001 4. Location of well at surface 305' WEL and 1169' NSL Sec. 23, TlON-R23E, U. M. At top of proposed producing interval At total depth 9. Unit or lease name Alaska State D 10. Well number W (-~ Exxon. No, 1' ~:~ 11. Field and pool 5. Elevation in feet (indicate KB, DF etc.) / 6. Lease designation and serial no. +3.0' Mean Sea Level (Ground~ , ADL 31.?R66 Wildcat .... 12. Bond information (see 20 AAC 25.025) B-1 -4 Type 0il & Gas Conservati(~ttretv and/or number 5l 34049. State Bond File AmOunt $1 00,000.00 13. Distance and direction from nearest town 141 Distance to neares~ property Or lease line~ 15. [~istance to ne~3rJ~st ~l(~r~g gr.gJ3ml:)le, ted Ap. Er, 0.x. /~', NN~.. 01' 50 mi E of Deadhorse, AKre"es 1169' NSL of lease feet .... ~_xxon ~3 Pt.T)~m~nnfeet 16. Proposed depth (MD & TVD) 17. Number of acres in lease I 18. Approximate spud date ,, 14,300 (TVD)feet 4935.47 [ 1 l~._-L~81 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressurea ~::~ ps,g@ Surface KICKOFF POINT feet. MAXIMUM HOLE ANGLE °[(see20AAC25.035 (c) (2) 11526 _psig@]4_.300ft. TD (TVD) SIZE Hole Casing Weight 40" 26" ] 7-1/2',' ]2-1/4" [ 8-1/2" 30" 20" 13-3/8" 9-5/8" ,1 1" ..WT 133 72 43.5 29/32/3 22. Describe proposea program: Proposed Casing, Liner and Cementing Program CASING AND LINER Grade { COupling J Length BUtt~ 80 K-55 J I2,200' L-80 IButt I 4'00'0' P-110J LTC jlO,O00' i P,I'IOJLTc [i4,300' LONOUT PREVENTERS: / SETTING DEPTH MD TOP TVD J MD BOTTOM TVD · I I80' I 0 2 200' ' 0 I 4,000' i 0 ~ !lO,O00' ', 800/,14,300, ,,,J ............ QUANTITY OF CEMENT (include stage data) 20" annular blOwout preventer with diVerter Permafrost to surface 'ermafrost to surface ,Dorox. TO(]: 3.000' ,bbrox. TOC 7;000' 5001. abo.ve potential lines will be insta 'led on the conductor, as shown on the attached sketch. The diverter will be removed whi e opening the 17-1/2" hole to 26" to 2200'. The samediverter system will be used on the 20" conductor. A 13-5/8", 5000 psi WP annular BOP and three 13-5/8", 10,000 psi WP ram type preventers will be installed on the 13-3/8" casing as shown on the attached sketch, and will be used along with a 10,000 psi WP choke manifold during drilling and well testing. BOP installation and testing will be in compliance with Alaska State RegulatiOns effective April 13, 1980. Anticipated surface pressures are shown in the casing design section. Pressure on the 5000 psi WP annular BOP will never be allowed to exceed its design working pressure. If drilling progresses so that Exxon can demonstrate the ability to operate safely, and ice conditions justify, a request will be made for state aUthorization to continue drilling and downhole operations until May 15, 1982 as per State Lease Sti.pulation No. 9. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space bel~TM f(~r C'or~m~'ssi~n uSe CONDITIONS OF APPROVAL Samples required ! Mud log required Directional Survey required APl'-number ~,~Y ES [-1NO i [~yES []NO []YES Permit number Approval date go,- lot I tJ~'~ i~, I~° APPROVED BY ,COMMISSIONER DATE A,]~3_~t '25~ 1981-- by order of the Commission j. 50- ~ '~-'~-..,ooi',~~' SEE COVER LETTER FOR OTHER REQUIREMENTS ~' zo Form 10~,01 Rev. 7-1-80 Submit in tripliCate Alaska State D Exxon No. I SUBSURFACE INJECTION: After setting the 20" conductor below any possible freshwater sands and setting the 13-3/8" casing at 4000' through the major gravel zones, waste fluids will be injected from 2200' to 3000' down the 20" x 13-3/8" annulus. After setting the 9-5/8" casing into the pressure transition zone (10,000'), waste fluids and hydrocarbons will be injected into saltwater zones from 4000' to 7000' down the 13-3/8" x 9-5/8" annulus. CASING DESIGN CRITERIA: See attached'Wellbore Sketch for design Surface - 13-3/8" @ 4000' Burst - Considers gas gradient to the surface causing lost returns at the shoe assuming maximum expected leakoff gradient. External fluid weight 9.0 ppg. Casing Design Surface Pressure (CDSP) CDSP : (Max. shoe leakoff gradient - gas gradient) casing depth : (16.0 x .052 - 0.10) 4000' : 2,928 psi Permafrost FreezebaCk - Considers maximum external collapse gradient of 1.44 psi/ft and minimum internal fluid weight of 9'0 ppg. Maximum Collapse Pressure (MCP) MCP = (Max. external gradient - min. fluid gradient) max. permafrost depth : (1.44 - 9.0 x .052) 2500' = 2,430 psi Permafrost Thaw Subsidence - 13-3/8" 72#/ft L-80 Buttpost yield strain performance exceeds the requirements for Prudhoe Bay Field rules, based on worst case well spacing. Exxon Minimum Safety Factors Burst 1. 443 Collapse 1.00 Tension 1.50 PROTECTIVE 9-5/8"@ 10,000' Burst - Considers gas kick of sufficient intensity and volume to cause lost returns assuming maximum exPected leakoff gradient and casing filled with water. External fluid weight 9.0 ppg. Casin~ Design Surface Pressure (CDSP) CDSP = (Max shoe leakoff gradien~ - water gradient) casing depth : x - .aa x re,coo' RECEIVE = 5,548 psi AUG ? 1 1981 Alaska Oil & Gas Cons. Commissii Anchorago Alaska State D Exxon No. I Collapse - Considers surface pressure = 0 psi, internal fluid weight 8.33 ppg, and external fluid weight 12.5 ppg Maximum Collapse Pressure (MCP) MCP : (External fluid gradient- internal fluid gradient)casing depth - surface pressure (12.5 x .052 - 8.33 x .052) 10,000' - 0 2,168 psi Minimum Ex. xon Safety Factors Burst 1.zJz13 Collaspe 1.00 Tension 1.50 PRODUCTION 7"@ 14,300' Burst - Considers shut-in gas well surface pressure and formation pressure of'15.5 ppg. Casing Design Surface Pressure (CDSP)' CDSP = (Max. anticipated formation pressure - gas gradient) casing depth : (15.5 x .052 ·0.18) 14,300' = 8,952 psi Collapse - Considers surface pressrue = 0 psi, internal fluid weight = 0 ppg and formation pressure = 15.5 ppg Maximum Collaspe Pressure (MCP) MCP = (Formation pressure - internal fluid gradient) casing depth - surface pressrue (15.5 x .052 - O) 14,300 - 0 11,526 psi ,~'-z ~ -- ?tic Exxon Minimum Safety Factors Burst 1.312 Collapse 1.125 Tension 1.50 Maximum Anticipated Surface Pressure 8,952 psi Maximum Anticipated Bottom Hole Pressure 11,526 psi AUG 2 1 ]98] Alaska 0il & Gas Cons. Commission Anohora~le WELLBORE & CASING DESIGN SKETCH ALASKA STATE D EXXON NO. I l < O' ; 29#/ft P-1]~ LTC · , 8800' 32#/ft P-11( LTC 11,800'- 35#/ft P-111 LTC 30" Conductor @ 80' 20" 133#/ft K-55 Butt Conductor @ 2200' Waste fluids injection zone -z~o"~ -'TOC @ approximately 3,000' 13-3/8" 72#/ft L-80 Butt Surface Casing @ 4000' Waste fluids and hydrocarbon ~njection zone TOC @ approximately 7,000' 9-5/8" 43.5#/ft P-110 LTC Protective Casing @ 10,000' =--' 7" Production Casing @ TD RECE ¥ED AUG ? 1 TYPICAL 2000 PSI W.P. DIVERTER STACK AND LINE FOR USE ON 30" AND 20" CONDUCTOR CASING ALASKA STATE "D" EXXON NO. 1 Trip Tank~_ Flowline 2000 psi W.P. Annular BOP (~) Off location (~)To reserve pit 20" spool or 20" casing Minimum 6" diverter lines 30" x 20" swage 1. Full opening hydraulically operated val,ves interlocked such. that one diverter line valve will always be open before annular BOP is closed. 2. Full-opening manually operated'valves with one valve always in the Open position to control flow to reserve pit or off location. RECE ¥Ei AUG ? 1 1981 G~,~ Cons. Commissic Anchorage TRIP TANK ANNULAR BOP 5000 pst W.P. KILL LI RAM BOP SPOOL RAM BOP Pipe 10,000 psi W.P. Blind10,000 psi W.P. CHOKE MANIFOLD Co~po.~ent Spe.ct fjcatt..0ns Pipe 10,000 psi w.p. RAM BOP ~) 1. Screwed Plug or Gate Valve - 2" stze provtded wtth A-section 7. Screwed Plug Valve - 2" size 3. Screwed Tapped Bullplug with fieedle Yalve and Pressure Gage 4. Flanped Plug or Gate Valve - 7" size provided with wellhead 5. Flanged Plug Valve - 2" size with companion ¢lange to protect valve flange face 6. Flanged Plug or Gate Valve - 7" mtntmum stze 7. Flanged Hydraulically Controlled Gate Valve - 3" (10,000 8, Flanged Flapper Type Check Valve - 3" (lO,ODD 9. Flanged ftydrau~tcally Controlled Gate Valve - 4" mtnt~um size 10. Flanged Plug Valve - 4" m~ntmu~ size. Gate valve not acceptable. 11. Top of. Annular Preventer must be equipped with an AP! Flange Ring Gasket. All flange studs must be tn place. 12. The 1.D. of the Bell Nipple must not be less than the minimum ~.0. of the BOP stack NOTE: All valves on kill and choke lines 10,000 psi W.P. ' T_¥PICAL ARRANGEMENT OF, Im3,5/.8!' 10,000 PSI W.P. BOP STACK --FOR USE OF )3--3/8' SURFACE A. ND 9'5/8I" PRDTE'CTIvE i.. .AND 7mill PRI'ODUllCTION, cASING ..... ALASKA STATE"D" EXXON NO. ! mi u i i ii i mi i i i II i CONTINGENCY PLAN ALASKA STATE D EXXON NO. 1 The objectige of this plan is to outline major operating and contingency requirements to ensure a safe and efficient operation throughout the drilling act i v i ty. LOCATION The barrier island location was designed to accommodate the drilling rig, camp, and necessary supplies for a winter drilling operation. The location, which is enclosed with sheet piling and has a freeboard of 7 feet, is designed to resist ice override and is above the maximum indicated tide based on observations along the surrounding coast. The sheet piling will also provide erosion protection during summer storms. Based on the status of the well and ice conditions existing just prior to March 31, a request may be made at that time to continue drilling operations to no later than May 15. Otherwise, the rig and associated equipment will be placed on a standby status and all fuel and lube oil will be removed until remobilization during the summer and fall of 1982 for drilling operations November 1. POLLUTION CONTROL The location and operating plan will be designed to provide containment of all drilling operation effluents that could be considered as pollutants. An impermeable sheet will be placed under the drilling rig to collect and divert any liquid waste for proper disposal. Fuel will be stored in welded steel tanks located within an impermeably lined area. Sewage and kitchen waste water will be processed through a State approved biological treating system with excess sludge being incinerated and the disinfected liquid contained in a steel holding tank. Treated effluent may be used as drill water, if needed, with excess being injected as described below. A separate insulated steel holding tank will be provided to store the treating plant effluent in the event of a system malfunction. A flare pit will be located clear of the rig to permit emergency burning of any produced hydrocarbons resulting from well testing. A primary feature of the drilling plan will be to provide 20" x 13-3/8" and 13-3/8" x 9-5/8" annular injection capability. The well casing program is designed to set the 20" conductor casing through any possible freshwater zones and the 13-3/8" surface casing throughthe major gravel sections fOr injection of waste fluids to approximately 3,000 feet. The 9-5/8" protective casing will be set into the anticipated pressure transition zone and cemented to isolate the saltwater sand sections from below the surface casing shoe to approximately 7,000 feet for injection of lube oil, excess mud, melt water, waste waters, and well test liquids. The reserve pit will be maintained at aminimum level at all times to provide for containment of well fluids in the event of an upset. All pits will be pumped out to a minimum level and waste water injected into the injection zone before abandoning the location. The entire operation is planned so that no hazardous fluids associated with the operation will be discharged on the surface outside the location. Additional precautions will be taken to prevent drainage of hydrocarbon~o~;.h,e~ sea. After freezeup, the surface of the island will be sprayed with wate~f~V~D' AUG 21 198! Al.~ska Oil & Gas Cons. an impervious ice seal. This should prevent liquids spilled on the surface from draining downward into the gravel fill. Also, any spills will be cleaned up as soon as possible. Snow contaminated by toxic substances will be incinerated on site or hauled to a disposal site on shore. The island surface will be thoroughly cleaned after clearing the island of all drilling equipment. The drilling contractor will be required to develop a comprehensive site specific SPCC plan to prevent pollution as a result of any drilling rig operation. In addition, Exxon will have a site specific Oil Spill Contingency Plan which will outline responses to spills of any size which might occur. In addition to the impermeable sheet under the rig mats, drip pans and other containment measures are provided under the engines and rig machinery. Good housekeeping will be stressed on all parts of the location with emphasis on minimizing contamination of the peripheral drainage from the island. An on-site oil spill cleanup crew will be designated within the drilling crew. These personnel will be given instruction in the prevention and initial control of oil spills. Most minor operational spills of oil will be collected with sorbent material anddisposed of by incineration. Equipment and material, which will be listed in the SPCC Plan, will be kept on location for the purpose of building containment dikes and berms, for containing o~l spills reaching the water, and for oil spill cleanup and disposal. If required, additional personnel and equipment can be rapidly mobilized from either oil spill contractors or the Alaskan Beaufort Sea Oil Spill Response Body (ABSORB) Organization, of which Exxon is a member. For spills beyond the capability of the on-site cleanup crew to contain or clean up, the Exxon'North Slope Oil Spill Response Team, as outlined in the Exxon North Alaska Oil Spill Manual, will be activated to the degree required by the severity of the spill. WELL CONTROL AND PERSONNEL SAFETY Personnel safety and well control are the uppermost factors in well design and operational planning. Sufficient data are available to plan the well for evaluation of the geologic objectives, provide for subsurface disposal of waste water, and conduct a safe drilling operation. Exxon and key contract supervisory drilling personnel will be experienced in well control detection and procedures and will be graduates of a certified well control school. Abnormal pressure technology will be used to Predict and detect changes in formation pressure to permit adjusting the casing and drilling fluid program to control the well. Emphasis will be placed .on well control procedures and equipment to permit circulating out a formation influx in an orderly manner if it should be necessary. Any hYdrocarbons in the influx will be diverted to the reserve pit and either burned or later injected into the annulus. In the unlikely event of an unplanned upset resulting in uncontrolled well flow, the following basic procedures will be followed: 1. Divert well flow to the reserve pit as the first defense against a spill. When the safe working level of the pit is reached, switch the flow to the surrounding ice. After the well is under control, produced well fluids will be disposed of by injection into the annulus. The contaminated ice and snow will be cleaned up and incinerated or hauled to an approved disposal site. The capacity of the reserve pit will be maintained at a maximum, practical working capacity at all times by keeping mud and fluid levels at a minimum and pumping fluids into the injection annulus when possible, f E E VED AUG ? 1 198i Oil & Ga.s Cons. Commissien ^nchora~o 2. Finalize plans for drilling a relief well from previously determined available locations specified in the site specific Oil Spill Contingency Plan. Site selection will be strongly influenced by the bottom-hole location of the flowing well at the time of loss of control. 3. Ignite well fluids at the wellhead, if the situation warrants, only after discussion with proper governmental agencies and Exxon management. Major supplies of mud, cement, casing, fuel, and miscellaneous supplies will be transported over winter roads or flown directly to location prior to breakup. After breakup, if required, light consumables will be transported by heli- copters. Tubulars and wellheads, along with gravel for preparing a relief well location, will be maintained at a suitable location in the area. In the extremely unlikely event of an out-of-control well, both the Exxon North Slope Well EmergencY Response Team and the North Slope Oil Spill Response Team, as outlined in the previously mentioned Exxon North Alaska Oil Spill Manual, will be activated. The Well Emergency Team will be responsible for performing all well control functions which includes all surface well control procedures, as well as plans for rapid implementation of an appropriate relief well plan.. The Oil Spill Response Team will be responsible for taking immediate action to minimize environmental damage and to institute cleanup operations as required. The Exxon North Alaska Oil Spill Manual contains detailed oil spill scenarios, detection, containment, and cleanup information. An outline of a relief well plan is contained in the site specific Oil Spill Contingency Plan for the well. The basic plan involves construction of a location and drilling a directional well designed to penetrate the flowing zone near the original wellbore. DRP: cf 7/27/81 AUG ? Oil 8'. G~.'; Cons. r 27 PROPOSED ALASKA STATE LAT. 70° 12' Og. 3:> LONG 146° 12' 25.56 y- 5~923,678 x- 474,307 SE~ ~TA Il. F'O~ LOC,4T/ON ~eouforf WITHIN ~ 38 4e I" =1 MIL E ALASKA STATE D-I I '- 305' I hereby certify that lam properly registered and licensed to proctice land surveying in the Stateof Alaska and that this plat represents a location survey made by me or under my direct supervision and that all details are correct. 7-24-80 TOPO FROM FLAXMAN IS. (A-4), AK USGS '~ORVEYOfR / / DATE REVISED Surface Location 3/26.A31 REVISED Surface. Locat.i..On ......... 3{_5 ,/~1~.. PROPOSED WELL LOCATION ALASKA STATE D-I LOCATED INSECTION 23~,,T ION, R2$_E.U.M. FOR EXXON COMPANY U.S,A. · . BESSE, EPPS t~ POTTS ANCHORAGE, ALASKA 344 -1352 IIIIIII II I Ill Illll i la ....... , COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 907/276-4552 Alaska Department of Environmental Conservation P. O. Box 1601 Fairbanks, AK ~701 Attention: Mr. Doug Lowery April 21, 1981 Gentlemen: An oil spill occurred at Exxon's Alaska State D-1 location at 1115 AST on April 17, 1981. Pursuant to 18 AAC 75.100 under authority of AS 46.03.020 (10) (A) and AS 46.03.755, this letter constitutes written confirma- tion of the telephone report made by Mr. J. B. Willis to an automatic telephone recorder at the Alaska Department of Environ- mental Conservation at 0903 AST on April 18~ 1981. The information required by 18 AAC 75.110 follows: 1. Date and time of discharge: April 17, 1981 at 1115 AST. · Location of the discharge: Exxon Alaska State D-I, at the West end of Flaxman Island. Sec. 23, T10N, R23E, UM. · Persons causing or responsible for discharge: None. Discharge was due to equipment failure. 4. Type and amount of discharge: 1-1/2 to 2 gallons of diesel f~_~ ., 5. Cause of discharge: Loose fuel line in the generator house· · Environmental damage: None. Discharged fuel remained on the drill pad. ® A DIVISION OF EXXON CORPORATION Cleanup actions undertaken: Diesel fuel was picked up with absorbent and contaminated gravel, scooped up. All contaminants were placed in plastic bags· Alaska Department of Environmental Conservation April 21, 1981 Page Two e Location, method and date of disposal of discharge and cleanup material: Contaminan~ts were given to the North Slope Borough for incineration. · Action taken {o prevent recurrence: Fuel line has been tightened. Please contact me at (907) 276-4552 for any additional information you may require. Very truly yours, ~ann JRH:sjm 240-910' ~- cc: Mr. Hoyle Hamilton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99504 R. K. Riddle R ECEIVED Alaska Oil & Gas Cons. Commission Anchorage .) November 14, 1980 Mr. A. R. Hermann Division Drilling Manager Exxon Corporation P. O. Box 2180 Houston, Texas 77001 Re: Alaska State D Exxon No. 1 Exxon Corporation Permit No. 80-101 Sur. Loc.~ 364tWEL, 1189tNSL, Sec 23, T10N, R23E, UM. Bottomhole Loc.~ S A M E Dear Mr. Hermann~ Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are required. A directional survey is not required. If.available, a tape containing the digitized log information, shall be submitted on all logs f6r copying except experimental logs, velocity surveys and dipmeter surveys, Many rivers in Alaska and their drainage .systems have been classified as important for ~e spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder {Title 5, Alaska Administrative code)... Prior to commencing operations you may be contacted by the Habitat Coordinatores office, Depar~nt of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. A. R. Hermann Alaska State D Exxon No. I -2- November 14, 1980 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 Labor is being notified 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 would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, Ho~ H. Hamilton Chairman Of Alaska Oil & Gas Conservation Commission Enclosure cc= Department of Fish & Game, Habitat Section w/o encl. Department of Environmental COnservation w/o/eno1. Department of Labor; Supervisor, Labor Law Compliance DiVision w/o eno1. EICON COMPANY, U.S.A. POUCH 6601 - ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION October 24, 1980 J_.l STAT~ J J JISTAT ' '-- · j Request for Variance to CONFER: Regulation 20AAC 25.035(C)(2) · Mr. Hoyle H. Hamilton, Chairman State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton: In letters dated August 29, 1980, Exxon filed applications for permits to drill the following Arctic Slope wells: !_)~Point Thomson Unit No. 6 ~~-~aska Stat~ As stated in the permit applications, Exxon plans to use a 13-5/8" inch 5000 psi working pressure annular BOP as part of the blowout preventer system whose other components are rated for 10,000 psi. Although this is in accord with widely accepted safe industry practice and with American Petroleum Institute guidlines, it is in technical violation of Miscel- laneous Boards, Commission regulation 20 AAC 25.035 at para- graph (C) (2). Exxon requests a variance to this regulation to. allow use of the 5000 psi WP annular preventer on these:four.~wells. A full discussion of the technical aspects of'-'°ur position was recently submitted to you in the form of a letter requesting revision of the subject regulation. This letter is included as an attachment for your reference in considering this request. RAM: jrh 240-500-200 Very truly yours, Robert K. Riddle A DIVISION OF EXXON CORPORATION E P'. zxOi' COMPANY. U $.A. POUCH 6601 ' AI'ICHORAGE. ALASKA q9502 (907) 276 4552 ALARKA OP~_ RAi'IO~JS WI S! F__RN DIVISION W M(~'~II TA~Lr)P r)t,I FI^T I¢)Nq . September 23, 1980 State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Dri. ve Anchorage, AK 99501 Gentlemen' Exxon requests reviSion of the recently enacted MisceJlaneous Boards, Commissions regulation 2.0 AAC 25.035 Bl. owout Prevention Equipment which at paragraph (c) (2) requires, in part, "the working pressure of any BOP and associated equipment must exceed the maximum surface pressure to which they may be subjected;..." On the surface, this appears to be an entirely reasonable requirement and little or no comment was raised during the review period prior to enactment. Careful consideration now reveals that the requirement is contrary to existing prudent drilling practice since "any BOP" includes the annular preventer whose working pressure might be required to exceed 5,000 psi depending upon interpretation of the undef~n'ed term "maximum surface pressure" and the unclear wording "to which they may be subjected." Current safe BOP selection practice for drilling higher pressure wells entails selection of ram-type preventers with a working pressure exceeding the anticipated surface pressure for any casing on which they are installed and selection of t:he annul, ar preventer to exceed the anticipated surface pressure which would be encountered in well control operations. The Jntended use of the annular preventer is ,to' prov-ide in.iLeal, closure on any part of a drill stri. ng at relatively low pressure, in the evenL of a well kick, to permit the operator to analyze the problem. 'Fhe operator would then proceed with well control operati, ons t~sing -the ~'am-type preventers and/or t:.he annular prevent:er del>ending on pressures an(] thc condition of the well. With current: technology in equipment, abnormal pressure detection-and well control tra~.ning, the initial pressure will ~ormally not exceed ]_,000 2,000 psi, and if well control procedures resu].t in t>ressures in excess of 2,000 to '2,500 psi, prudent operating practice is to conduct the well control operation using the ram-type prevent;ecs thus effectively ~solating the annular preventer from the higher pressure. That .is to say, the annular preventer would not be subjected to pressures exceeding 5,000 psi. A DIVI$10,I OF EXX(JN COFIt'OrlAIION ~tate of Al.,:~ska September 23, 1. ) Page 2 There have been no documented ol)erational instances where an annular preventer having a working pressure greater than 5,000 psi would have prevented a blowout, yet ]~teral interpretation of the subject regular;ion could result in the requirement for such a preventer. By design and operational usage, an annular preventer i.~ i. ntended to provide for a l~m~ted range of functions under low to moderate pressure, i.e. , ].ess than 5,000 psi. A regulat, ory requirement for a greater than 5,000 psi_ working pressure annular preventer distorts the purpose an(l operational usage of the annular preventer, potentially jeopardizing well contro'l, and safety under high pressures. Moreover, it is projected that several years would be required to design, shop test, and opera- tionally validate the reliabi]~.ty of 10,000 psi annul, ar pre- venters of the ]6-3/4 inch or 18-5/8'inch sizes required 'in some drilling programs. This regulat~ion could limit the ava~lal')~l£ty of rigs for sche(luled exploration dri]li, ng programs, require t~se of prototype equi~pme'nt (luring well contr()l operaLions, and ~:(,sult in no tangible advancement in . technology or increased safety. Attached for your review is a genera] discussion of' I:~lowout preventer equipment and the use of preventers in well .control. In view of the problems discussed above, Exxon requests that 20 AAC 25.035(c) (2) be revised as follows' "the working pressure of any ram-type BOP and assocJ, ated equipment must exceed the anticipated surface pressu~-e of any casing string on which ~t .i.s to be used and the wot'king pressure of any annul, ar BOP must exceed the pressure to which it may be subjected in well control operations; marion submitted w~th Form 10-40] must inc].ude anticipated formation pressures to be encountered, the anticipated surface pressure for each casing string, anticipated pres-. sures to which the annular preventer may be subected in well control operations, and the criteria used to determine these pressures consistent with 20 AAC 25. 030 Casing an(] Cementing; We believe the above requirement: more clearly~ states the estab- ].ished crJ. teria for selection of BO[~ equipment and wi]_[ allow for the differing methods of program design now used by industry. Although we realize that your decision must be based on t:he merits of the case, we would like to point out a recent- i~recedent :involving a USGS OCS regu].ation. Tills was a BOP ~-e(luirement essential].y identical to 20 AAC 25.0.35 (c) (2.) which was revised along the lines proposed. Your consideration of this proposed revision is respectfully requested. TLP/RAH/kI~ A t t a c hmen L 28-Z- Yours very truly, W. Honte Taylor GENERAL DESCRIPTION OF BLOWOUT PREVENTER EQUIPt'IENT AND USAGE A blowout' preventer (BOP) system consists of several engineering designed components that can be systematically operated in the event of unexpected flow from a well. The BOP system is used initially to close- a well in, and thereafter to hold back pressure on the wellbore, while circulati, ng a mud weSght of sufficient hydrostatic pressure under controlled conditions to overcome the influx. Figure 1 is a schematic of a BOP system, commonly referred to as a BOP stack. The basic components are similar: a wellhead connect.~on to thc previously set and cemented casing strings; pipe ram preventers; blind ram; an annular preventer; and a system of lines and valves to direct fluid into or out of the BOP when various components of the system are functioned for well control operations. The number and position of tl~e pipe rams and blind ram may var5, with particu].ar re¢:luirements of a given well, the operator's well, control procedures, and to some extet~t., on the complexity of the BOP system. The size, shape and control of the BOP system are specifically designed for a part'icu].ar rig. Ma_jot changes to a BOP stack often involve changes in handling procedures and auxiliary rig equipment. The pipe rams, blind ram, and annular preventers are designed and used primari].y for closing and sealing functions. They a'lso have features that provide for redundancy and secondary funct, ions. Figure 2 is a schematic of the primary sealing method of the pipe rams, blind ram, and annular preventer. Pipe rams are semicircular concave faced components having primary sealing surfaces designed 'to match the outside diameter of the particular pipe in use. Blind rams are so'lid faced com- ponents, with elastic and metal sealing surfaces for closure and sealing wi th nothing opposite the ram. Some blind rains are equipped with pipe shearing blades which can close, she. ar, and effect a seal. The rams are opened and closed by positive con- trolled operating fluid applied to the ram piston. The annular preventer is equipped with a large 'ring of c']ast:J.c sealing materSal (rubber or neoprene) designed to close on ot>cn hole or around any size or shape, pipe. The primary closing method is positive operatSng pressure applied to a shaped piston resulting in a "squeezing out" effect of the elastic element. -Depending on the design of particular annul, ar prevent, ers, well- bore pressure from below may also act on the piston t:o "pressure assist" the squeezing of the el. ement. The primary opening con- trol. method is positive operating pressure apt~lied to t:.he shaped piston to reverse its travel and allow the element to relax to its normal, configuration. The signSficance of the desSgned oper- ational features of the annular preventer is discussed below. OP ERAT 1 ON S During normal drilling operations, control of the well is main- tained by using adequate hydrostatic pressure from thc mud column in the wellbore, monitoring of various drilling parameters, and through proper crew training. As stated previously, the blowout preventter system al. lows for closing in a well when unexpected flow occurs. Thc BOP unit is intended to provide the operator with a series of a.lternative operational, functions, by use of the individual components, to control the influx by circulating fluid in the wel]bore. The control of the wellbore depends on properly designed equipment, prudent operation of the equipment, and proper training of personnel performing the task. Pipe rams are considered the primary means oF seal i. ng around drill pipe and the ,blind rams for sealing on open hole. t~ccog- nizing the adverse mechanical effect that could occt~r if the pipe rams were closed on other than their designed pipe size. or [f t:he blind rams were closed on other than open hole, the a~nul, ar preventer was designed to allow initial c.].osing around i_rre.~ular sizes an(] shapes. It is, therefore, generally the first preventer to be closed in an emergency. We].]_ control can then be trans- itioned in an orderly fashion t() the primary pipe rams £or long term sealing and operational control. Figure 3 is the closing-in procedure emp'loyed by Exxon. It -is similar to the procedure used by any prudent drilling operator. Figure 4 represents calculations of various condit;ions of gas infux that would have to occur prior to closing t-he a'nnu]ar preventer in Order for it to be subjected to initial pressure greater than 5,00'0 psi. With operators and crews trained for abnormal pressure detection and we]] control in accordance with current standards, the likelihood of unexpected flow o'f the intensity and volume reflected by the example is extreme].y remote. For example, the pit volume increase alarm normally would have a sensitivity of 10 bbl. or less. Response time for a trained drilling crew to chec'k the well for flow and properly close the annular preventer -i s two mJ n. or less. Assuming influx rate equivalent to 20,000 bbl per clay, t:he total influx prior to shut in would be 38 bbl, which is much less than the va].ues shown in Figure 4. Accordingly, the a~xnul, ar l~reventer .woul~l not- be subjected to in.itia], closed-:in pressures great'er than 5,000 psi . ~_.~l~_~__~.]~9~.:i~p..~._i[..~_...~.t)e_9-~erat:or[ t ici )ate f'ac9 ---. ...... I ..... .s sur >ressures excee<lin, ..... r2[~_fi.?_[._2 500 t?sJ, t'he [~'i:I~9_ ...................... L-....: ...... :__: _: ...... ~ :__.:_.g ', ........... ............. rams arc [19?~.j.q~.[y__.~se(1 for t~.f'j.~j}.~.l'_Y ~..~.~.~ng_.and co~tt, ro I , Fun(: ing of either of: the pipe rams or I:lind rams ~'~"[]'-'~"s¢)']~'[~ annular p_Feventer .from any subseqtj.e.~3t high well pressures trial might occur during contro~ operations. A secondary feature designed for and operationally engineered into the use of a blowout preventer system (the primary function is again to provide sealing) is the ability of moving pipe into or out of the wellbore under pressure. This procedure, called "stripping", is not a common occurrence during well control but is a desirable alternative t.o have available under some circumstances. It can be safely handled with existing components of the BOP system and tra:ined crews. In some situations, strip- ping can be performed with the pipe rams or with the annular preventer or w~th a combination of the preventers. Due to ~t:s infrequent occurrence, the stripping procedure i s genera] ]y employed only after consi~der.ab l.e forethought and planning. Figure 5 shows a fundamental calculation to determine if strip- ping is a viable alternative. If there is an insufficient down- ward force (fro~n the weight of the pipe already in thc hole) to overcome the upward force generated by the unexl~ectc~t 'influx, stripping cannot be performed and snubbing operations become the alternative. This is a less frequent occurrence and speci, a]ty. companies and equipment are necessary to perform t:he procedure. If stripping is a viable and necessary opt ion, a hist. ot-Scal. preference, under low wellPore pressure, has been to strip with the annular preventer. This procedure is somewhat less com- plicated, under low pressures, and reduces the possibility of damage to the primary sealing ram preventers that would be used for subsequent control operations once stripping has been com- pleted. A .generalized discussion of stripping with an annular preventer is presented in this paragraph. Recall that the annular pre- venter has a ring of elastic material, squeezed by a shaped piston upon application of pressure from the control accumu].ator and/or by wellbore pressure assist. The hig}~er the well pressure, the tighter the element ]s squeezed to maintain a pressure seal. As pipe is moved' through the annular preventer, friction from the pipe body and the passage of the larger OD pipe tool joints causes wear of the element. The higher t. he wellbore pressure and the required closing p'ressure, the greater the wear. The greater the wear, the great..er the closing pressure must be to maintain a seal. For the annular preventer designed with well pressure assisting hydraulic closing pressure, the closing presst~re can be reduced to min~rnize friction (and thus wear) between t. he element a~d the .pipe and tool. ,joint. At re]at-i, vel. y hSgh well. t>o're pressures (2,000 to 2,500 psi), the hydrauli, c closing pressure can no ].onger ]>e reduced sufficiently to prevent excessive wear due pipe mox, ement through the element. Depending on the size of the o enin pres ute i stead f annular preventer and pipe in use, .... p_ ....... g. s n o closing pressure would have to be applied to the prey.enter to avoid excessive element friction and wear. App].ySng opening pressure is consJ tiered to be an extremely hazardous procedure since a fluctuation in well pressure could allow the preventer to suddenly open. Even if the pipe rams were immediately closed, uncontrol.]ed flow could jeopar(lize rig and crew safet'y. 'It.would be a matter of c. hance at t. his time whether a too] joint were. opposite the closing pipe ram thus damaging it beyond subsequent sealing capability. For the annular preventer designed without wellbore assist, increasingly higher hydrau].ic closing pressures are required to maintain t.I~e seal at higher and higher well pressures. Figure 6 shows results of shop t. ests of the wear on an element (stripping cycles to failure) relative to increasing well. bore pressure a~d the resulting increase in closing pressure, Note the drastic reduction in element life when well. pressure is [ncc'eased from 1.,500 to 3,000 psi. While the results of t:he tests may vary somewhat among preventers, the size pi. pc used or t. be L.3't)e of element installed, ~t Js Exxon's posJt'..4on t. ha~. thc t'esL is strongly indicative of_ t.he results that will 1. be obtained at higher well pressures, l.n other words, the st:ri, pl)ing wear' life of an annular preventer is greatly reduced ar. increased we'l lbor. e pressures. Of equal significance is the. need for ~he e.lement t:o maintain its seali, ng capability when 'repeated]y m~)ving t. he smaller diamet:er pipe body, then the larger diamct;er tool. joi. nt and then the sma].]er diameter pipe body again through the pre- renter. The element's abili~.y to maintain a ~e'al under this procedure is rel. ated to t:he amount of wear and_ pressure t.~)which it J.s s~b.j ec t. ed. AT[ though a provision is avai labl e for' "sl±ghv. ly" reducing ~he amount of closing force on t. he e.lemcnt as tt!e tool joint, starts through, the open:lng and closing se.q~ences of an annular preventer are not total'l.y positive. Tills 4. s due t.o the larger seal Lng and piston areas involved, t. he amou~t, of probable wear, and the relacivel, y large £1uid operatihg volumes. For these reasons, it is Exxon's normal policy not; to attempt stripping operations using an annular prevent;er, regard]ess its pressure ratJ~.g.; when weli pressure exceeds psi. Our pratt: i ce tls supported by the experience of Ot-['~ Engineering Corporation's worldwide stripping and snubbing oper- ations. Otis' views on t:he subject are reflected j.n the Jr letter of February 11, 1.980, F2guce 7. Supporting documentation can also be found in API Recommended Practices for Blowout P~;event:~on Equipment' Syst. ems RP53 Page 16, l"~ure 8. Prevent'et; syst:em arrange.meats [-o~- 5,000, ]0,000, and ~5,000 psi. ptTessure may utilize annular preventers rated for 5,000 pst. In summary, by (les.ign and operat'.ioi~:~l, usage, an ant~ular preventer .is intended tr~ l~rovide Cor a l. imi. te(l range of functions t~t(ler low t.o modernl e l~r'e~t~re, i . e. , l. ess t hah 5,000 l)si . A ~-egu'l at ory reclu'iremet~t for a great'er than 5,000 l)s4. working i)ressure annul,~r i)revenLer (l'ist()rt.s the l;ur'l)ose and ol>erat'.ional, usage o[C the annul ar preventer, p.ot eat ia I ly .jcr)l)ard~zZng we] ]. cony r'o'[ and safety under high pressures. Hor(".over, it is projected that several years would 1)e re(lu'ired t:o desZgn, shop test, and oper- ationally va[idaEe the reli. at)i].it:y of 10,000 psi annular pre- vent. ers of the .16-3/4 .inch o~: 18-5/8 inch sizes requi, red in so,ne drill. Lng programs. This regul, atZon could Z~miC the a'vaZl, al)/l~ty of rigs for schedu].ed exp]orat-ion drilling p~ogran~s, require use of prototype equipment during well control operati, ons, and result in no tangible advancement in technology or increased safety. TLP/RAM/rms 211-A Y= 5,927,807.05 X= 469,345.05 Y= 5,922,527.57 X = 469, 328.99 ii SECTION 23 T. ION.,R 23E.,U.M. 363.63~ Y = 5,927,787. 44 X = 474,622.49 Y= 5,922,507.98 X= 474,608.43 I": 2000 FEET NOTES I. Location of well site was accomplished by using U.S.C. 8' G.S. Stations"HOBSON 1949" and "RODA 1949". 2. All dimensions and coordinates are in feet. 3. Elevation existing ground at well site 3.6 feet, mean Lower Low Water Datum. Elevation established by tidal observation 3/10/80. CERTIFICATE OF SURVEYOR '1 hereby certify that l 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 direct supervision and that ali details (]re correct. DATE '~ ~- SURVEYOR . ALASKA STATE PLANE ZONE 3 Y= 5,923,698 X = 474,248 GEODETIC POSITION LAT. 70° 12' 09.51"N LONG. 146° 12'27.28"W REVISED WELL LOCATION 7-25-80 REVISED TITLEBLOCK 8, DIMENSIONS 6-24-80 WELL-LOCATION DESCRIPTION 1188.80 FEET NORTH OF THE SOUTH LINE AND .363.65 FEET WEST OF THE EAST LINE, SECTION 25, T. I0 N.~ R23E.~ U.M, ALASKA '1185.81 FEET NORTH OF THE SOUTH LINE AND 3788.20 FEET EAST OF THE WEST LINE TRACT 114~ BEAUFORT SEA. ILwl LOCATION SURVEY FOR ALASKA STATE D WELL NO. I LOCATED IN THE BEAUFORT SEA AREA I I I i i I [ IIII i SURVEYED FOR EXXON COMPANY U.S.A. SURVEYED BY INTERNATIONAL TECHNOLOGY LIMITED ANCHORAGE, ALASKA HOUSTON,TEXAS . OBI COMPANY. U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION August 29, 1980 Re: Exxon Alaska State "D" No. 1 Section 6~6 -..T9~.; R23E, UM ADL 312 Arctic Slope, Alaska ' LO/NS: Dr. Ross G. Schaff Acting Director Division of Minerals & Energy Mgmt. 703 West Northern Lights Blvd. Anchorage, Alaska 99503 Dear Dr. Schaff: Exxon Corporation filed today an application with the Alaska Oil and Gas Conservation Commission for a permit to drill and the contingency plan for the subject well together with our check in the amount of $100.00 in payment of the required permit fee. Additionally, and in accordance with the requirements of the subject oil and gas lease and applicable regulations, we submit the following: (1) A plan of operations describing the drilling pad, rig supply, water supply, waste and sewage disposal and pollution prevention. (2) Two area operations maps: Exhibit "A", scale 1!'=2000' showing the location and vicinity of the well and pad layout and Exhibit "B", scale 1"-10,000'- showing sea ice road, Rolligon haul route and relationship of subject operation to those within Duck Island and Pt. Thomson Units. (3) Survey plat with X and Y coordinates as well as latitude and longitude. Rig availability as well as lease stipulations necessitate a two season operation for the drilling of this well. As a consequence we shall construct the drilling pad during the winter 1980-8.1 as soon following receipt of your approval as weather conditions will permit the movement of construction equipment and materials to the site. The Parker Drilling Co. Rig No. 96 presently on location at the Alaska State "C" No. 1 site will be moved to this drill site prior to the 1981 spring break-up and immediately following the completion of the "C" No. 1 well. Drilling operations will be commenced with the barging of fuel and supplies to the drill site in late summer 1981 and the well will be spudded November 1, 1981 in compliance with lease stipulations. /~'~:~:::~F~ ~.:.~~ ~ .... A DIVISION OF EXXON CORPORATION Dr. Ross G. Schaff Page two August 29, 1980 Archeological and historical studies required by said stipulations are presently being contracted for and will be completed before any construction activities are commenced. All data developed in such studies shall be made available to you for your files. We have been advised by the U.S. Army Corps of Engineers that a permit under Section 401 of the Clean Water Act will not be required for the subject operations hence we shall not be seeking, through COE permit procedures, a certificate of consistency with the Alaska Coastal Management Program. In the event, however, a similar application for certification may be required for this operation under these circumstances through your office please advise and we shall comply in whatever manner may be necessary to meet the state's requirements. Yours very truly, RKR:et enclosure c: EPA Region X - Mr. Danford G. Bodien, P.E. Alaska Oil & Gas Conservation Commission - Mr. Hoyle H. Hamilton U.S. Army Corps of Engineers - Colonel Lee R. Nunn T Y P IC A(" BLOWOUT PREVEf:TER STAGK CHOKE LNE IV ANNULAR BELL NIPPLE PIPE RAM KILL LINE BLIND RAM PIPE RAM WELLHEAD FIGURE I P I'PE RAM BLIND RAM ANNULAR .~ OPERATING PISTON ~ PIPE RAM -~ SEALING ELEMENT _-~ /.~__ OPENING L., !,..,.,F FLUID FLUID I ,/"F-''~ OPERATING · ~ PISTON BLIND RAM SEALING ELEMENT .~_~OPE NING FLUID ..~___CLO SIN G FLUID OPENING FLUI D~_r-- CLOSING ,/¢'-'t FLUID ELASTIC SEALING ELEMENT ~ / · OPENING CHAM BER ~__ PISTON -- PREVEN*~ BODY ' FIGURE ' e LAND, PLATFORM & JACK.UP OPERATION FULL BO~ STACK ON COMPETENT C.A~NG CLOSING-IN PROCEDURE I'F ANY OF THE FOLLOWING' OCCUR: _ 1. HOLE NOT TAKING CORREC'T AMOUNT Ol~ MUD ChW TRIP. 2 GAIN' IN PIT VOLUME INCREASE FLOR ACROSS SHALE--~HAKER, 4 E~q ~ L L lNG BREAK, 5 INCREASE OR DECREASE IN PUMP PRE.~JRE. GAS CUT MUD OR CHLORIDE INCREA.SE. l. PICK UP KELLY FEET UNTIL TOOL .IOIN'q' CLEARS ROTARY TA'BL E 2 5~UT DOWN MUD 3 CHECK WELL FOR IS WELL FLOWING NO---- WELL IN AS FOLLOWS NOT~F¥ SLt~ERINTENDE NT &ND TO, C)L PLJSHE~ ~MMED~ATELYJ OPEN CHO}~ ' i!CE VAL\~ 0I{ BOP J CONTROL PANEL I CLOSE ANNULAR BOP 1 CLOSE al'"lOK ES J RECORD SHLrT-IN DC ~kND C5~ J PRE.RES. AND PIT LEVEL GAIN CONTROL WELL AS DIRECTED J RESUME OPERATIONS AS DIRECTED FIGURE 3 REQUIRED INFLUX FOR INITIAL WELL SHUT-IN PRESSURE TO EQUAL 5,000 PSI Well ~D-Ft Barrels Of Gas Influx Drilling With A With A Mud Wt-ppg 2.PPg Kick 4 ppg Kick 13,000 10.0 389 242 15,000 12.0 293 156 17,000 14.0 227 98 WELLBORE CONFIGURATION 5 inch drill pipe 9-5/8 inch casing 540 ft., 6-1/2 inch drill collars 8-1/2 inch hole. Fi gure 4 LENGT(" OF PIPE THROUGH ANNULAR REQUIRE(' FO Vs WELLBORE STRIP PRESSURE 16 14 12 I0 8 6 4 2 0 FRICTION IOpp9 MW' YANCE) 0 2 4 6 8 I0 WELL PRESSUREmlOOOpsi FIGURE STRIPPING TEST RESULTS 18 3/4" AND 16; 3/4"- 5000 PSI ANNULAR . 1500 00 PSI ~ CLOSING 1000 CHAMBER PRESSURE PSI [~ iiili I I 500 ,, 0 WELL PRESSURE NATURAl. OR NI'TRILE 11 6'3/8 TOOL JOINT ON 5OO PSI 6.8 ELEMENTS 5 TM DRILL PIPE 0 5OO IOO0 1500 STRIPPING CYCLES EXXON COMPANY, U. S. A. PLAN OF OPERATIONS EXXON ALASKA STATE "D" (ADL 312866) WELL NO. 1 General This well will be drilled as a Straight hole and will be located 364 feet WEL, 1189 feet NSL, Section 23, T10N, R23E, U.M. The drill site will be on the west end of Flaxman Island in the Beaufort Sea about 50 miles east of the Prudhoe Bay East Dock. The drill site will be constructed during the winter of 1980-81 and the well spudded on November 1, 1981. Approximately six and a half months will be required for drilling and testing. Parker Drilling Co. Rig No. 96 will be used to drill this location. This rig, along with a 70 man camp, will be moved from Alaska State "C" Well No. 1 which is about four and a half miles south of the proposed location. Natural Environment Flaxman.Island is located in the Beaufort Sea about two and a half miles north of the Alaskan coastline. The surface of the island in the vicinity of ExXon's proposed drill site is a sandy gravel mixture with little vegetation. It has an average elevation of three feet above sea level. The depth of the perma- frost in this area is expected to be about six hundred feet. There are no established roads,, airstrips, housing, or other facilities in the area and, because of the nature of the terrain, heavy vehicular traffic can operate only during the winter season while the ground and surrounding sea ice are frozen. Prudhoe- Deadhorse is the nearest staging area and airstrip with permanent facilities for handling cargo and housing personnel. Arctic climatic conditions include relatively cold temperatures year-round. Strong winds, small annual precipitation, and visi- bility strongly influenced by the combination of winds and coastal sea ice condition are factors contributing to an extremely harsh environment. Temperatures vary from a high in the 40 to 60°F range' in the summer to a low of -50 to -60°F in the winter which, with the chill factor may reach -100°F or lower depending on the severity of winds. Surface winds are predominantly from the east at an average veloc- ity of 12 miles per hour along the coast with a velocity range of 35 to 50 mph associated with winter storms. Total annual precip- itation is in the range of 4 to 6 inches which includes 12 to 48 inches of snowfall. Various species of wildlife exist in the area. During the winter months, when the major.part of activities are planned, wolves, wolverines, foxes, polar bears, and caribou may be present. Bird life is limited primarily to the raven, snowy owl, gyrfalcon, and ptarmigan, with waterfowl and most other birds having migrated from the area for the winter. Logistics Access to the proposed location during the winter of 1980-81, 1981-82, and possibly 1982-83 will be provided by a sea ice road along the shoreline of the Beaufort Sea extending from Prudhoe Bay East Dock to Point Thomson No. 3 and continuing in a northerly direction to the location. Additional ice roads will also be required from Point Thomson No. 3 to Alaska State C-1 and the gravel source in the winter of 1980-81. An ice road from the location to the water source will be required during the winter of 1981-82 and possibly 1982-83. These road routes are shown by Exhibits "A" and "B" which are attached. The drilling rig, camp, and supplies will be moved in 1981 from Alaska State "C" No. 1 to Point Thomson No. 3 by 'truCk over ice roads if C-1 is completed prior to the breakup of the ice roads. As an alternate, the rig and camp will be moved in the summer of 1981 by Rolligon over the tundra to Point Thomson No. 3 and then barged to the proposed Flaxman Island drill site. Additional supplies for drilling operations will be transported to the drill site by barge from Prudhoe Bay during the open water season of 1981 and possibly 1982. After freeze up begins, heli- copters will be used for the movement of supplies until an ice road can be completed. Most personnel will be transported by helicopter and possibly air cushion vehicles prior to the completion of the ice road. Traffic will be routed to avoid waterfowl nesting and staging sites. An ice landing strip, approximately 2000 feet long, will be constructed to facilitate air transportation during winter operations. During the winter, if bulky equipment must be delivered on short notice or large shipments can be accumulated, an ocean ice landing strip for Hercules aircraft may be constructed on the sea ice. Page 3 Drill Site Construction Contingent upon regulatory approval, location preparation will commence in the winter of 1980-81 as soon as freeze-up is sufficient to facilitate movement of.construction equipment to the job site. The proposed drill site will be a 340' X 450' sheet pile enclosed gravel fill. The elevation of the top of the'gravel will be +7.0 feet. The sheet piling around the site will protect against erosion and wave overtopping in the summer and sea ice override in the winter. Approximately 27,000 cubic yards of gravel will be required for the drill site fill. This material will be obtained from a mine located in Sections 14 and 15, T9N, R23E. The development and operation of this mine, which will be a central source of fill material for construction activities in the Point Thomson area, will be covered by separate permit applications to appropriate government regulatory agencies. Rubber tired loaders and belly dump trucks will be used for the loading, hauling, and placement of material for the new location. Water for drill site construction will be obtained from Lake No. 8 in Sections 22 and 23, T9N, R23E, UPM. The proposed sequence for drill site preparation will be as follows: l® Construct ice access road along shoreline of the Beaufort Sea from Prudhoe Bay to Point Thomson No. 3 and on to the gravel source in Sections 14 and 15, T9N, R23E. e · Activate temporary construction camp for 40-60 persons at the gravel source and move in remainder of construction equipment from Prudhoe Bay. Construct ice roads from (1) Point Thomson No. 3 to Alaska State "D" No. l~location and. (2) the gravel source to Lake 8 in Sections 22 and 23, T9N, R23E. · · Construct sheet pile enclosed gravel drill site. Move in drilling rig and camp during the spring or summer of 1981 as previously discussed. Page 4 · · Barge supplies to the drill site in the summer of 1981 and possibly 1982. Construct 2000 foot long ice airstrip in the winter of 1981-82 and possibly 1982-83. Drilling Operations Drilling operations will commence with the barging of fuel and supplies to the drill site in the late summer of 1981 so that the well may be spudded on November 1, 1981. If drilling progresses So that Exxon can demonstrate the ability to operate safely, and ice~.~ conditions justify, a request will be made for state authorization to continue drilling and downhole operations until May 15, 1982 as per State Lease Stipulation No. 9. If the proposed well cannot be completed within the authorized 1981-82 interval, drilling operations will be suspended until November 1, 1982. All personnel, fuel, and lubricants will be removed from the drill site by May 30, 1982. Fuel and supplies will be barged again to the drill site in the late summer of 1982 so that drilling operations can resume on November 1, 1982. The drill site layout is shown on Exhibit "B". An impermeable plastic sheet will be installed under the drilling rig to collect liquid drainage and direct it to'the well cellar for recovery and disposal. All pits, except for the burning pit, will be lined with an impermeable plastic liner. The reserve pit will be used only for the emergency storage of excess drilling fluids. The wellbore wil1 be designed for annular injection for the subsurface disposal of waste liquids. Water for drilling operations will be barged in during the summer or hauled from a proposed central water supply for the Point Thomson area to be located in Section 14, T9N, R23E. The development and operation of this source will be covered by separate applications to appropriate government regulatory agencies. A snow melter may also be used to supplement rig water requirements. Potable water will be processed through a Met-Pro water treating unit before use in the camp. Disposal of Waste Materials The following waste material procedures will be observed during drilling operations. After completion of the well, any remaining materials will be promptly removed from the drill site. l· Drilling Mud will be injected in the casing annulus or hauled to a state approved site for disposal. Page 5 · · · · · · Cuttings from the wellbore will be hauled to a centrally located landfill in the Point Thomson area for disposal. The development and operation of this landfill, to serve future locations in the Point Thomson area, will be covered by separate permit applications to appropriate government agencies. Sewage Effluent and Gray Water: Sanitary sewage will be treated with a state approved Met-Pro 14000 Series sewage disposal unit owned by Parker Drilling Co. Treated effluent from this unit will be combined with gray'water from the camp kitchen and bathrooms in a steel storage tank and used in drilling mud or rig wash water. A lined sanitary holding pit will be provided for the emergency storage of these liquids during upset conditions. Any surplUs quantities of this liquid will be discharged in the casing annulus. Domestic Garbage will be disposed of in a Smokatrol Model 200 Incinerator. Combustible Wastes such as paper, wood, and cardboard will be incinerated in the Smokatrol unit or open burned. Noncombustible Wastes such as scrap metal, batteries, drums, wirelines, etc. will be hauled to a state approved site for disposaI.' Well Test Fluids: Produced gas will be flared. Produced liquids will be injected in the casing annulus or hauled to a state approved site for disposal. Waste Oil will be injected in the casing annulus or hauled to a state approved site for disposal. Surface Protection and Restoration Plan SUrface transportation to the drill site will be only over ice roads during the winter or by barge during the summer. Special procedures for drilling and subsurface equipment are required by the unique characteristics of the permafrost area. Casing cement used through the permafrost zones is of special composition to reduce possibility of freezing and other casing problems. Casing is run and cemented through the permafrost, and in the event of production or interruption of operation, the unCemented casing must be protected by the use of non-fr~ee-zing fluid. Page 6 At the completion of the well, the location and adjoining area will be cleared of all waste materials. ~ . · Velocity Survey Prior to the completion of the well, a velocity survey, one of the essential components of the drilling operation, will be made. As this well will be drilled as a straight hole the procedure employed will require only a40" diameter cased hole, 40 feet deep which will be located on the drill pad a short distance from the well bore and will be filled with brine water just prior to detonation. Experimentally, one pound charges of Nitromon primers or an equivalent amount of Primacord will be used as well as an airgun as the energy source; the Nitromon or Primacord serving the dual purpose of cavitating the hole and supplementing the airgun as the energy source. As a further alternative in the ~vent neither of the above develop satisfactory data, we propose to use a steel tank 10 feet in diameter and 20 feet high filled with water with the air gun as the energy source. Development Plans If oil is discovered in sufficient quantities to warrant future development, the Prudhoe Bay to Valdez oil pipeline will be the probable marketing outlet from the area. Oil and casinghead gas would be processed through central oil gathering facilities with oil being transported to the Trans-Alaska Pipeline System. If commercial quantities of gas are discovered, d~velopment of a gas market outlet will be related to studies to market gas from the Prudhoe area. AVL:ljm 7-24-80 E .ON COMPANY, U.S.A. POUCH 6601 · ANCHOR.~GE, AI_~SK,~ 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION Re: August 29, 1980 Exxon Al_ask/a State "D" No. 1 Section/l~, T~ R23E, UM ADL 312866 Arctic Slope, Alaska ~'~ Permit No.: Mr. Hoyle H. Hamilton, Chairman State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton: Exxon Corporation submits the following in regard to the captioned well: (1) State of Alaska, Oil and Gas Conservation Committee Permit to Drill, Form 10-401, in triplicate with triplicate copies of the location plat and contingency plan. (2) Exxon Check No. 3493, dated August 29, 1980, in the amount of $100.00 in payment of the required permit fee. Concurrently with this application, we are filing with the State Division of Minerals and Energy Management the following: (1) A plan of operation describing the drilling island, rig, supply, waste and sewage disposal, and pollution prevention. (2) Vicinity and location plats. This well, situated at the westerly end of Flaxman Island, will be drilled as a straight hole by Parker Drilling Company Rig No. 96. Contingent upon regulatory approval the sheet pile enclosed gravel fill site will be prepared as soon as weather conditions in the winter of 1980-81 permit, and the rig and camp shall be moved thereon from the Alaska State "C" No. 1 location immediately following its completion. In compliance with lease stipulations the spudding of the well will be deferred until November 1, 1981. RKR:et enclosures c: EPA - Region Ten, Attn: Yours very truly, Robert K. Riddle Danford Bodien, P.E. U.S. Army Corps of Engineers - Attn: Col. Lee R. Nunn A DIVISION OF EXXON CORPORATION , , Forrh .~G.40] REV. 9-1-78 C SUBMIT IN TRIPLICAT~I (Other instructions on ~w~s~ side) STATE OF ALASKA ., APT ~50-0R9-2001 ALASKA el L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL OR DEEPEN DEEPEN El SINGLE Or. ER Wi 1 dcat zoNE ~ ruNE u la. TYPE OF WORK DRILL ~ b. TYPE OF WELL 2. NAME OF OPERATOR Exxon Corporation 3. ADDRESS OF OPERATOR P. O. Box 2180, Houston, Texas 77001 5. 6. LEASE DESIGNATION AND SERIAL NO. ADL 312866 ~7i~ tF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Alaska State D 9. WELL NO. Exxon No. 1 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECI'IVE) 4. LOCATION OF WELL At surface 364' WEL and 1189' NSL Sec. 23, TlON-R23E, U.M. At p~oposed prod. zone 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 50 miles east of Deadhorse, Alaska 14. BOND INFORMATION: Oil and Gas Conservation, 5134049 State Bond File B-l-4 TYPE Surety and/or No. ' Amount$100,000.00 15. DISTANCE FROM PROPOSED * 16. No. OF ACRES IN LEASE 17. NOACRES ASSIGNED LOCATION TO NEAREST TO THIS WELL PROPERTY OR LEASE LINE, FT. 118 9 ' NSL o f Lea s e 4,935.47 .... (Also to nearest dfig, unit, tf any) 18. DISTANCE FROM PROPOSED LOCATION 19. PROPOSED DEPTH 20. ROTARY OR CABLE TOOLS TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. Approx.12,9OO'NNE of Exxon #3Pr.Thomson 14,300' Rotary Sec 23 TlON-R23E, U.M. 12. 21. ELEVATIONS (Show whether DF, RT, CR, etc.) +3.0' Mean Sea Level (Ground) 22. APPROX. DATE WORK WILL START Location 1-1-81 Spud ]l-l-81 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 4.0" 36x32x28 Insulated .Re"riaera ;ed 85' To surface with permafrost cemer 26" 20" 94 K~55 800' To surface with permafrost cemet 17-l/g" 13-3/8" 72 L-80 3,300' To surface wil;h .permafrost cemer 12-1/4" 9-5/8" 43.5 P-110 lO,O00' Approx. TOC 7,000 8-1/2" 7" 29/.32/35 P-110 8,800/11,800/14,300' 500' above potential H( it ~nt ~nt zone BLOWOUT PREVENTERS. A 20" annular blowout preventer with diverter lines will be installed on the insulated conductor, as shown on the attached sketch. The diverter will be removed while opening the 17-1/2" hole to 26" to 800'. The same diverter system will be used on the 20" con- ductor. A 13-3/8", 5000 psi WP annular BOP and three 13-5/8", lO,O00 psi WP ram type preventers will be installed on the 13-3/8" casing as shown on the attached sketch, and will be used a. long with a lO,O00 psi WP choke manifold during drilling and well testing. BOP installation and testing will be in compliance with Alaska State Regulations effective April 13, 1980. Antici- pate_d surface pressures are shown in the casing design section. Pressure on the 5000 psi WP annular BOP will never be allowed to exceed its design workino pressure. If drilling progr~ so that Exxon can demonstrate the abil~tj/ to operate safelj/, and ice qond.itjons jus.tlfy, a reau.~st ~ll.bg~made for.~tate, author.i~at~o.n.to ~.ont~nue drilling and aownno/e operam;lons unl:l I- May lb. IN ABOVESPACE DESCRIi~ PROPOSED PROGRAM: If l]tOposal is to deepen give data on present productive zone and proposed productive zone. If proposal is to drill or deepen directi°nally, ~ive pertinent data on subsurface locations and measured and true SIGNED (This space for State office u~ CONDITIONS OF APPROVAL, IF ANY: SAMPLES AND CORE CHIPS REQUIRED ,, i~s [] No DIRECTIONAL SURVEY REQUIRED ["lYES ~NO PERMIT NO. APPROVED BY MUD LOG ~YES E] NO OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE APPROVAL DATE *See Instruction On Reverse Side November 14, 1980 DATE 11/14/80 ~/?~ CASING PI~R I~O CASING SIZ~ EC!2, SIZE' CASING A~rD ~JBIN3 DESIGN STA_q~ · HYD OR. i ~u~ '~. II ~-'/g. HYD. OR. II t! 13 3/~ " INTER VA L Bottom Top Wt. DESCR_iPTiON WEIGHT TENSION W/ BP_ -top of ST~XENG2~H Grade 5~r,r e ad W/O EF section TEl/SiON lbs lbs !030 lbs 3.3oo 0 3300 72 Z- F t~ TDF COLLAPSE COLLtu~SE P~SS. ~ PZSIS?. bottom tension psi ~si CDP BUP£T _ ~. z z grL~J~ BDF PRESSURE I 'fz ~Zb:~24 YIELD psi psi PPZCE .=ER CCZ .d -) Y=Tensile Load/Pipe Yield Strength t-O .2 ,1: 6 g ~ 0 ; - i:--' --1 i: };.: :. :':;.'.:1';:: :";"~' I. · ................. ::1 '. ' I .k':.",i.?;'it .... , ..... , ........ I ...... , .... , .... ~ :.:. .--------w .-- -: ~ .--r 'r -:: :. ~ _..'----7.. . ."--u'!,. -:. 7 ~.. .--'~-', ~ ...., .. l'..:!.".': ':~ *it; ':;:i ' '~:' : ", 1.:'.'.;.::.!'.:':''.'..:!'.:;:Xl;::'.~[i:::l7 .';;:: .............. ~ ................. i"' F...~:. ,75'.. i I , ":;:i '"t-:-:: :':::]:::'":':'1'":.':'" '"~.i" .~; ..... r~-.---. ~ 7.55~5'!~ i:.~.';~ :,?'t4..' .~..=.'-.'4 ~ I. ......... ; .... I .... "" ..... ~" '1; '~'~'' -' ::::'::" --., :.::. ~:::t!::: ~--~ ...... ,:. :..-_: "~.--:~-~, '":.~"_:.1 · -.:: .?. --::l'::'J:.;'] ".'' J,tt.,;"*" :t:'{,,.;:l,;;~:};,;:l'' ' .0, ..... , .... ..,.., ...... Formulae: Collapse resistance in tension X (Collapse pressure ratify) Burst Pressure = ~P + Depth ( Hyd. Gr. II --.5) BF (Bouyaney Factor) = ~.oo - (o.oz53 x ~4ua wt. z) ~m o 5zo /32 0 I,&_ .qoo ' ~/zo >3 l. Cl gg'-lo _z2,-/&o /,3 Calculations: Tokai Cast Alaska State D Exxon No. 1 ,' , " Af'~ nfo SURFACE INJECTION: er setting the 9-5/8" casing i ~' the pressure tran- sition zone (lO,O00'), waste fluids and hydrocarbons will be injected into saltwater zones from 3300' to 7000' down the 13-3/8" x 9-5/8" annulus. CASING DESIGN CRITERIA- See attached Wellbore Sketch for design Surface - 13-3/8" ~ 3300' · Burst- Considers gas gradient to the surface causing lost returns at the shoe assuming maximum expected leakoff gradient. External fluid weight 9.0 ppg. Maximum ~ Pressure {MSP} MSP: (Max. shoe leakoff gradient- gas gradient) casing depth {16.0 x .052 - O.lO) 3300' 2,416 psi Permafrost Freezeback - Considers maximum external collapse gradient of 1.44-psi/ft and minimum internal fluid weight of 9.0 ppg. Maximum Collapse Pressure {MCP) MCP = (Max. external gradient - min. fluid gradient} max. permafrost depth {1.44 - 9.0 x .052) 2500' 2,430 psi · Permafrost Thaw Subsidence - 13-3/8" 72#/ft L-80 Butt post yield strain performance exceeds the requirements based on worst case well spacing. · a Safety Factors Burst 1.443 Collapse 1.O0 Tension 1.50 PROTECTIVE 9-5/8" @ lO,O00' Burst- Considers gas kick of sufficient intensity and volume to cause lost returns assuming maximum expected leakoff gradient and casing filled with water. External' fluid weight 9.0 ppg. Maximum ~u~ Pressure (MSP) MSP: (max. shoe leakoff gradient- water gradient) casing depth : {19.0 x .052- 8.33 x .052) lO,O00' = 5,548 psi Collapse - Considers surface pressure: 0 psi, internal fluid weight 8.33 ppg and external fluid weight 12.5 ppg Maximum Collapse Pressure (MCP) .A!aska State D Exxon ~. i Mcr: (External fluid gradient- internal fluid gradient) casing depth - surface pressure {12.5 x .052- 8.33 x .052) lO,O00' - 0 2,168 psi · ~ Safety Factors Burst 1 ,,443 Col lapse 1.00 Tens ion 1.50 PRODUCTION 7- e 14,300' Burst- Considers shut-in gas well surface pressure on kill weight packer fluid and external fluid weight of 15.5 ppg. Maximum ~ pressure (MSP) MSP: (Max. kill wt. fluid gradient - gas gradient) casing depth (15.5 X .052 - 0.18) 14,300' 8,952 psi Collapse - Considers surface pressure: 0 psi, internal fluid weight : 0 ppg and external fluid weight = 15.5 ppg Maximum Collapse Pressure (MCP) MCP: (External fluid gradient - internal fluid gradient) casing depth - surface pressure -- (15.5 X .052 - O) 14,300 - 0 : 11,526 psi · ~ Safety Factors Burst 1.312 Collapse 1.125 Tension 1.50 WELLBORE & CASING DESIGN SKETCH ALASKA STATE D EXXON NO. I P-11C LTC 8800'--~- ~ft.P-11C LTC ' 36" x 32" x 28" Insulated Conductor @ 85' 20" 94 #/ft- K-55 Butt Conductor ~ 800' 13-3/8" 72#/ft L-80 Butt Surface Casing @ 3300' Waste fluids and hydrocarbon injection zone TOC ~ approximately 7,000' 9-5/8" 43.5#/ft P-110 Butt Protective Casing @ lO,O00' 7" Production Casing @ TD TYPICAL 2000 PSI M.P. DIVERTER STACK AND LINE FbR USE ON "30" AND 20'" CONDUCTOR CASING ALASKA STATE D EXXON NO. I Butterfly Valve Flowline mb_ Trip T?_k 2,000 psi W.P. Annular BOP (~) To Burn Pit or Snow Containment Area Minimum 6" Diverter Line 20" Spool or 20" Casing To Reserve Pit 28"x 20" Swage '~Full opening hydraulically operated valves interlocked such that ~i'e~ diverter line valve will always be open before Annular BOP is closed. ~Fullopening, normally open valves to control flow to reserve and burn pits . KILL LIN I TRIP TANK l ANNULAR BOP 5000 pst W.P. RAM BOP Pipe 10,000 psi SPOOL RAM BOP ~ m "~ Blind10,000 pst W.P. Pipe 10,000 psi W.P. CHOKE MANIFOLD O® ® Co ,mponent Speci fications 1. Screwed Plug or Gate Valve - 2" size provided with A-section 2. Screwed Plug Valve - 2" size 3. Screwed Tapped Bullplug with Needle Valve and Pressure Gage 4. Flanged Plug or Gate Valve - 2" size provided with wellhead 5. Flanged Plug Valve - 2" size with companion flange to protect valve flange face 6. Flanged Plug or Gate Valve - 2" minimum size 7. Flanged Tee - 2" minimum size 8. Flanged Flapper Type Check Valve - 2" minimum size 9, Flanged Hydraulically Controlled Gate Valve - 4" minimum size 10. Flanged Plug Valve - 4" minimum size. Gate valve not acceptable. ll. Top of Annular Preventer must be equipped with an AP1 Flange Ring Gasket. All flange studs must be in place. 12. The I.D. of the Bell Nipple must not be less than the minimum I.D. of the BOP stack. NOTE: All valves on kill and choke lines lO,O00 psi W.P. TYPICAL ARRANGEMENT OF 13-3/8" 1.p,O00 PSI W.P. BOP STACK FOR USE OF 13-3/8" SURFACE AND 9-5/8" PROTECTIVE AND 7" PRODUCTION CASING ALASKA STATE D EXXON NO. I CONTINGENCY PLAN ( ALASKA STATE D EXXON NO. 1 The objective of this plan is to outline major operating and contingency require- ments to ensure a safe and efficient operation throughout the drilling activity. LOCATION The barrier island location.w~ill.be designed to accommodate the drilling rig', camp, and necessary supplies for a winter drilling operation. The location, which will be enclosed with sheet piling and will have a freeboard of 7 feet, is designed to resist ice override and is above'the maximum indicated tide based on observations along the surrounding coast. ~The sheet piling will also provide erosion protection during summer storms. Based on the status of the well and ice conditions existing just prior to March 31, a request may be made at that time to continue drilling operations to no later'than May 15. Otherwise, the rig and associated equipment will be placed on a standby status'and all 'fuel and lube oil will be removed until the following late summer when it will be remobilized for recommencement of drilling operations November 1. POLLUTION CONTROL The location and operating plan will be designed to provide containment of all drilling operation effluents that could be considered as pollutants. An impermeable sheet will be placed under the drilling rig to collect and divert any liquid waste .for proper disposal. Fuel will be stored in welded steel tanks located within an impermeably lined area. Sewage and ki'tchen.'waste water will be processed through a State approved biological treating system with excess sludge being incinerated and the disinfected liquid contained .in a'steel holding tank. Treated effluent may be used as drill water, i'f needed, with excess being injected as described below. A separate sani'tary holding pit will be provided to store the treating plant effluent in the event of a system malfunction. A test pit will be located clear of the rig to permit burning of hydrocarbons resulting from an upset as well as routine burning as per the Plan of'Operations. A primary feature of the drilling plan will be to provide 13-3/8" x.9-5/8" annular injection capability. The well casing program is designed to set 13-3/8" surface casing through the major gravel sections and below any possible freshwater zones. The 9-5/8" protective casing wi~ll be set into the anticipated pressure transition zone and cemented to isolate the saltwater sand sections from below the surface casing shoe to approximately 7000 feet for injection of lube oil, excess mud, melt water, waste waters, and well test liquids. Liquid levels in the sanitary -.holding pit and burning pi't will be maintained below pad level to prevent migration of any liquid out of the pit while the reserve pit will be maintained at a minimum level at all times to provide for'containment Of well flui'ds in the event of an upset. All pits will be pumped out to'a mini'mum level and waste water i'njected i'nto the injection zone before abandoning the location. The entire operation is planned so that no fluids associated with the operation will be discharged on the surface outside the location. Additional precautions will be taken to prevent drainage of hydrocarbons to the sea. After freezeup, the surface of the island will be spray, ed with water to form an impervious ice seal. This should prevent liquids spilled on the surface from draining downward into the gravel fill. Also, any spills will be cleaned up as soon as possible. Snow contaminated by toxic substances will be incinerated on site or hauled to adisposal site on shore. The island surface will be thoroughly cleaned after clearing the island of all drilling equipment. The drilling contractor will be required to develop a comprehensive site specific SPCC plan to prevent pollution as a result of any drilling rig operation. In addition to the impermeable sheet under the rig mats, drip pans and other containment measures are provided under .the engines and rig machinery. Good housekeeping will be stressed on all parts of the location with emphasis on minimizing contamination of the peripheral drainage from the island. An on-site oil spill cleanup crew will be designated within the drilling crew. These personnel will be given instruction in the prevention and initial control of oil spills. Most minor operational spills of oil will be collected with sorbent material and disposed of by incineration. Equipment and material, which will be listed in the SPCC Plan, will be kept on location for the purpose of building containment dikes and berms, for containing oil spills reaching the water, and for oil spill cleanup and disposal. If required, additional personnel and equipment can be rapidly mobilized from either oil spill contractors or the Alaskan Beaufort Sea Oil 'Spill Response Body (ABSORB) Organization, of which Exxon is amember. For spills beyond the capability of the on-site cleanup crew to contain or clean up, the Exxon North Slope Oil Spill Response Team, as outlined in the Exxon North Slope Emergency Manual, which is in final preparation, will be activated to the degree required by the severity of the spill. WELL CONTROL AND PERSONNEL SAFETY Personnel safety and well control are the uppermost factors in well design and operational planning. Sufficient data ane available to plan the well for evaluation of the geologic objectives, provide for subsurface disposal of waste water, and conduct asafedrillingoperation. Exxon and key contract supervisory drilling personnel will be experienced in well control detection and procedures and will be graduates of a certified, well control school. Abnormal pressure technology will be used to predict and detect changes in formation pressure to permit adjusting the c~sing and drilling fluid program to. control the well. Emphasis will be placed on well control procedures and equipment to permit circulating Out a formation influx in an orderly manner if it should be necessary. Any hydrocarbons in the influx will be diverted to the test pit and either burned or later injected into the annulus. In the unlikely event of an unplanned upset' resulting in uncontrolled~ well flo~, the following basic procedures will be followed: 1. Divert well flow to the reserve ~i.t as the first defense against a spill. When the safe working level of the pit is reached, switch the flow to a containment area on the ice constructed with snow and ice retaining walls. After the well is under control, produced well fluids will be disposed of by injection into the annulus. The contaminated ice and snow will be cleaned up and incinerated or haul'ed to an approved disposal site. The capacity of the reserve pit will be maintained at a maximum, practical working capacity at all times by keeping mud and fluid levels at a minimum and pumping fluids-into the injection annulus when possible. · 2'.. Finalize plans for drilling a relief well. from previously determined available locations. Site selection will be strongly influenced by the bottom hole location of the flowing well at the time of loss of control. Major supplies of mud, cement, casing, fuel, and miscellaneous supplies will be transported over winter roads or flown directly to location prior to breakup. After breakup, if required, light consumables will be transported by heli- copters. Tubulars and wellheads, along with gravel for preparing a relief well location, will be maintained at a suitable location in the area. In the extremely unlikely_~vent of an out-of-control well, both the Exxon North Slope Well Emergency Response Team and the North Slope Oil Spill Response Team, as outlined in the previously mentioned Exxon North Slope Emergency Manual, will be activated. The Well Emergency Team will be responsible for performing all well control functions which includes all surface well control procedures, as well as plans for rapid implementation of an appropriate relief well plan. The Oil Spill Response Team will be responsible for taking immediate action to minimize environmental damage and to institute cleanup operations as required. The ABSORB Oil Spill Contingency Plan Manual, which is in final preparation, contains detailed oil spill scenarios, detection, containment, and cleanup information. An outline of a relief well plan, which will be site specific, will be contained in the Drilling Program for the well. General information concerning relief well planning and logistics will be contained in the Exxon North Slope Emergency Manual. The basic plan will involve construction of either an onshore or offshore location and drilling a directional well designed to penetrate the flowing zone near the original wellbore. Since drilling ahead operations, which are the most likely time for a well control problem to occur, will cease by March 31, sufficient time exists prior to breakup to construct a well location and to move in a rig and supplies for a relief well. Following breakup, rig supply can be performed with barges. As mentioned previously, contingency tubulars and gravel dedicated specifically for relief well use will be maintained at a location in the vicinity. These tubulars are designed to permit pumping kill weight fluid at a sufficient rate to kill a blowout in the Pt. Thomson/Beaufort Sea area. All relief well plans are predicated on emergency-.approval of all phases of the operation by all state and federal regulatory agencies. -3- Y= 5,927,807.03, X= 469,3,4:3.05 Y= 5,922,527.57 X = 469, 3.28.99 SECTION 2_.3 T. ION.,R 23E.,U.M. ;563.63.~ Y= 5,927,787.44 X= 474,622.49 Y= 5,922~507.98 X= 474,608.43 = 2000 FEE? NOTES I. Location of well site was accomplished by using U.S.C. & G.S. Stations"HOBSON 1949" and "RODA 1949". 2:. All dimensions and coordinates ore in feet. 3. Elevation existing ground at well site :3.6 feet, mean Lower Low Water Datum. Elevation es. toblished by tidal observation 3/10/80. ALASKA STATE PLANE ZONE 3 Y= 5,923,698 X= 474,248 GEODETIC POSITION LAT. TO° 12' 09.51"N LONG. 146° 12'27.28"W CER.T!,FICATE OF SURVEYOR 'i hereby certify that ! om properly registered and licensed to practice la~cl surveying in the State of Alaska and that this plat represents a location survey made by me or under my direct supervision and that all details are correct. DATE SURVEYOR ! i ..... ~,~- ---- --3 I J _~' WELL LOCATION DESCRIPTION 1188.80 FEET NORTH OF THE SOUTH LINE AND 363.63 FEET WEST OF THE EAST LINE, SECTION ~5, T. IO .N.~R23E.~ U.M.~ ALASKA 1185.81 FEET NORTH OF THE SOUTH LINE AND 3788.20 FEET EAST OF THE WEST LINE TRACT 114, BEAUFORT SEA. REVISED'WELL LOCATION 7--25-80 LOCATION SURVEY FOR ALASKA STATE D WELL NO. LOCATED IN THE BEAUFORT SEA AREA _ iii I SURVEYED FOR EXXON COMPANY U.S.A. ......... ~UR~YED BY ...... INTERNATIONAL TECHNOLOGY LIMITED ANCHORAGE, ALASKA HOUSTON,TEXAS PHILLIP ..~ .SIzr. R.P lr. February 11, 1980 Mr. H. J. Flatt Exxon Headquarters Drilling Manager Exxon Company, U.S.A. P. O. Box 2180 Room 3005 }{ouston, TX 77001 Dear Sir' With reference to your' inquiry regarding the use of large bore annular preventers, Otis has had no experience stripping pipe using any annular type preventer above 10 3/4 I.D. We have had some e×periences down through the years with emergency stripping of drill pipe, sizes 3 .1/2 through 4 1/2, using the 7 1/16 I.D. annular preventer under 3,000 psi, but in each case we elther had adequate pipe in the hole or our conventional snubbing equip- ment available for stripping purposes. We regularly strip 1.315 O.D. through 2 7/8" O.D. using a pre- sized, molded stripper element similar to Hydrll's RS Stripper, Composite Catalog, Page 3674. Most routine offshore workover is conducted with 1.315 O.D. pipe stripped through a molded stripper element sized to fit 4 1/16 bore equipment~ 3~000 psi maximum, We have used dual element stripping techniques but employ this method to lengthen element life as opposed to increasing working pressure ranges. Stripping with either the molded or annular type presents major problems.when considering the change in areas as the Jolnt upset moves through the seal area from two standpoints: 1) Sufficient pipe weight must be' present to pull the Joint through the seal area, and 2) Strict attention must be placed on the type of Joint used. No square shoulders must be present and a very shallow angle must be used for the diameter transition. I would suggest that smaller pipe diameters in relation to large bore annular preventers could present a problem unless the elastomerlc material Is adequately backed up by metal. One other· concern is the tendency for the elastomeric materials to flow easily when the pressure differential approaches or exceeds the modulus of elasticity. This means that without near perfect metal backup, higher pressure sealing is not practical. We experience a certaln amount of difficulty in the ram type preventer as well, and must be constantly aware of and accommodating to the metal backup configuration. Otis Engineering Corporat,on A 14ALLI~URTON Com,o, lr~, Fi gure 7 Mr. H. J. Flatt Page Two February 11, 1980 One point I Bhould mention is, the industry also uses the term stripping to indicate the movement of pipe through ram type BOP'B. I have assumed in your inquiry we are talking about annular type equipment as opposed to ram type equipment. Our.principal experience has been with ram type equipment, using f~ipe sizes up through 7" O.D. and pressure up through 18,000 psi. 5'be large pipe has been stripped with ram type BOP's against 2,000 psi and the smallest pipe has been associated with ram type BOP's and 18,000 psi. We would, if required to rig up on an existing stack, test all BOP's including the annular to rated working pressure but would not attempt to strip more than 5,000 psi using a 7=1J16 .I.D. annular preventer. We believe,increases in bore will reduce this maximum drastically as 18 3/4 I.D. is reached. I hope the foregoing is useful in helping you arrive at a decision but if additional information is necessary, please contact me. Yours very truly, OTIS ENGINEERING CORPORATION Philllp S/Sizer PSS:mc cc: Mr. Homer Davis [ I CL I CH FIG. ARRANGF:.M F~NT CH Triple }lam Type Prt, vent~.rs, Rt. 1 R i C Fl('. '2.I).5 A R R ,\ N (; F; .M E N T C t ttt d R A ' (.' tt A ' 'P~nnular pr~v~,nter. A. may have 5M wr~rkmg pre**ure rating. Ct_ (I 1) I I [, CH · FI(;. 2.I).6 A Il lt..\ N(; F; 51 Fi NT CH ltd }{ti :\'Cl. TYPICAL BLOWOUT PREVENTEI¢ AI{R:\NGEMISNTS F()}~ SM, 105I, ANI) 15,51 t~:\TEI) WOI~I,~ING SER\':ICE- SUBSEA INSTALLATION CL I 1 R CH FI{;. 2.I).7 ,\ R tt ,.\ N (; E 51 E N'F CH ItdlLdA'A'CL CHECK LIST FOR NEW WELL PERMITS Item .Approve Date (1) Fee ~~ ~ ~/v-~ / (2) IzDc. /~/~ 9'/~-[o Yes No 1. Is the permit fee attached .......................................... ~ -- 2. Is well to be located in a defined pool ............................. e e · · 4. Is well located proper distance frcm property lin ....... ~'5. Is well located proper distance fron other wells .................... 6. Is sufficient undedicated acreage available in this pool ............ 7. Is well to be deviated .............................................. 8. Is operator the only affected party ................................. 9. Can permit be approved before ten-day wait ......................... / 10. Does operator have a bond in force .................... , ............ ._~/~ ~'11. Is a conservation order needed ...................................... 12. Is administrative approval needed ................................... 13. Is conductor string provided ........................................ ~ Remarks 14. Is enough cement used to circulate on conductor and surface ......... ~ (4) Cas. g. ~ q-7_.3-8~0 (5) BOPE .~ Additional Requirements: Approval Recommended: 15. Will cement tie in surface and intermediate or production strings ... '16. Will cement cover all known productive horizons ..................... 17. Will surface casing protect fresh water zones ....................... 18. Will all casing give adequate safety in collapse, tension and burst.. .q'Oo~ /3~/8" 19. Does BOPE have sufficient pressure rating - Test to ,o~o, q ~/~ psig .. Geology: Engin~ring: HWK ~ LCS 7d~ B~ JAL~_ rev: 03/05/80 CHECK LIST FOR NEW WELL PERMITS Company ITEM APPROVE DATE (1) Fee (2) Loc (3 > Admin ~w~/ ¢- 7/~¢~/ (9/thru 11) (4) Casg _~~ q']¢/~ -~2 thru 20) (5) BOPE~ru~'~-~/24) (6) Add: 1. Is the permit fee attached ....................................... 2. Is well ~o be located in a defined pool .................... ; 3. Is well located proper distance from property line ..... i][ ][ i ' ''' ''i 4. Is well located proper distance from other wells ....... i ' 5. Is suffi'cient undedicated acreage available in this pool . 6. Is well to be deviated and is well bore plat included .. 7. Is operator the only affected party ..................... 8. Can permit be approved before ten-day wait ............. 9, 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. '22. 23. 24. YES NO REMARKS · .. ,, Does operator have a bond in force .............. ~. Is a conservation order needed ..... ~{[{{~{i!iii{i{i[~i![~.i.i!.i~... ~ Is administrative approval needed .... .~ Is conductor string provided ........................................ (~z 25. Is enough cement used to circulate on conductor and surface ........ Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons .................... 1 surface casing protect fresh water zones ................ - ...... Wil Wil Is Is Is 1 all casing give adequate safety in collapse, tension and burst.. this well to be kicked off from an existing wellbore ............. old wellbore abandonment procedure included on 10-403 ............ adequate well bore separation proposed ........................... Is a diverter system required ........................... Are necessary diagrams of diverter and BOP e~ulp~;~; ;~;ac~e~ . Does BOPE have sufficient pressure rating - Test to /¢gfOE2 ps'.~g. Does the choke manifold comply w/API RP-53 (Feb.78) ...... Additional requirements .............................................. Additional Remarks: ~ ,~~ ~ ~-.~ ~ ~o ~ Geology: Engineering: HW~ /5~ LCS ~gw~ WVA~ JAL</~ / ~ev: 03/10/81 .... I~IT IAL' I GEO. UNIT' " bN/OFF POOL CLASS STATUS .i AREA,, NO. SHORE Well History File APPENDIX Im'orrnation of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXl ,, No special'effort has been made to chronologically organize this category of information. ,o )"~UNi:' (iF TAPE01 RE r.:"~D E-R'F~)R ON '-~-q~.~ = DUi'~P ENDED ALASK& STATE g-t ........ 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' ........... 2 ................................................................................. ................... ................................................................... ............................ ............................................................................................................................................................................................................................... ................................ ................. PAGE 1 XX3N COMP'~NY U.S.a. ~--~KA- ~T~T: u-1 70.0 0.00 0.001839.44 0.00 3.49 0.54 48.77 15.12 90.O 3.0;3 0.0014)07.63 0.04 3.54 0.62 13c~.:....~,.~.~] .................... .:...~..,1.~..:...,1.,...:.~..t~,~e,..~,. ........ J._.~..g.........0. ................ ~..,.....0.....0.. ............... ~....,..g.R.:!.(-, e.:].., ~..? ....... O, 6...7.. ............... R...,_.~_.5__ ............ .P._,.._.5...Z..._._!_O_R_,_O.:_q_ ...... .z_....?._..,_s._?_ 11'3. '.3..;"'. 0'3 O. 031 4 ~3, .3.3 3 . ~.; .g .67 3 . §'/. ,,=~_ · 05 ,?.5.a=,. .,. 120.0 O.O0 n nn 235.39 2.49 2.74 4,25 70,06 25.17 ~...~....x.? ' '~ ...... '~ "'" :)3.54 ~?_~..u ............. :.,_'_.....~...~,. .......... .V............u.....~ ....... Z 67. .............................................................................................................. . ........ ~- ....... ,.=, .................................................................... 140.0 O.OO 0.00 36e.24 2.76 2.Q7 2.71 67.74 27.67 ' _ l_~.g_,._o. ...... _0.. q_o_ ............... g_,,._0...:.0_.....~...4....~__,....3...~ ................. _3.......?_.~ ............. _3._.._ 5--7 ........ .~_,._.Q..~ ...... ~_5_7_._.3_. s. _. ?8.: 8__% ................................................................... ......... %..6..g...,...g ............ ?..,..g ~ .......... 0.., .0.0. .... 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S 1 '~ .' 7 5' '0"7"0" ;"g ..... ...94~ .............. .... ~.4 ........ 3~ ) · 7u~'~ ......... ~ .................. 336. L. 4~' .................. 3.4',d .......................... ~.~7=~ ........ '~ ......................................... 2.~8~';: .................... O~.14~'"""~ ............................................... 70.7~ ................. ~' ......................................................................................................................... ~~0'~-&-~.b0 342.09 45.3.0~ 4.09 2'.92 '2;'21 40;Z'~ "65.8'$ ~'"~'~ 294.54, 312.m5 384.'72 3.40 3.20 2.60 53'80' 7 ~I . 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DEPTH CFOC CILM CiLD RFOC R]:LM R ]:'L O ' SP GR -'-~-i~'-2 .......................................................................... ~ v A ~ z ............. -- T'Z.-5'-0"-;'"0---'"'~"~"-;"3-:~' .... ~',S'0 ;"~"? ...... ~"~'~'"';'"~"~' ................... ~-';Z-'.~ ........... ~-TT~ ........ ~-~ ..... -~-&-'7~,- ...... ~-~-,-~-'~-' ......................................................................................... 7---~60,0 273.75 398,17 527,51 3,65 2.51 1~90 36,34 60,60 ?-~'~'0";'-~-'"-~'~-'~'":"~'"~ ........ ~"~"~"~""~"~ ........ ~'"?'~"~'~"~ .................. ~"~'?'~ ............... -~"'~'"~-:~ ........... ~-~'"~--i .......... 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ZT~:~:~F:~:~'~:~$~~~~~ 7~::~'~:.:?~: .................................................... .......................................................................................... . . . ..'.' .... . .,....'.' ......' i,...' :~....~:, ....:~'..,...~',..~'.,..~,~,:~.,.~.~:, ....... ~30.0 357.68 323~:'~ 32'8~.0~'~,~.:L~.:~ 3,0~,~ : 3~t'.0,' ~6..,~'?' '~3.,.35,~ ;,.,. ~.... .............. : .?..~ ............... ,.,.,~ ~,~,..: .... : ..... ~,-. :::,,.. ,.~,:,~ ~,.,.-.~, .~- ..... ~:,~ . . .... ?-~' ~", ~:~.~.~, ,,~.: ..................................................................... ~o. o z~. 6 ~ ~o. F'~ ~..~',~.~ ...'.', ::~:~..~ ~:..~-; :.....~.~.'.~ ,~..;:..... :'~. ~h.~.~. o': o ..... Z::..ZJ.':.L....;: .... ~'~"~-0"';'"0 ..... ~--8"~'"~"'~"~'""~'~"8'"~ 70 z 63. ~ 1 3. ~ 9 ~. ],~ ~, 3. ~ 76.0~~. 56 . ~"z'"~'"~, u.u ''~ ............................ 30~. 3 ~; .................. :~ .........., ~ 8, ~~"( ........... 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Mv A p z 7740,0 335,26 303,99 280,58 2,98 3,29 3,56 86,8'9 7'0,69 ' ,7750.0 311.63 ~5.56 269.72 3.21 3.35 3.71 88.11 75.56 ~..~.~.? .................... }....,...~...~ ......................... ,. ............. : ............................................................................................................................................................ 7770,3 289,61 2~6,89 227.76 3,45 4.05 ~.39 87.38 73,61 _ T~"'0";'"0' ............. ~"g"~'T"~"~'~'~'"~""'"'~"'"5'"'6T~0' ................ ~"~""~"'";"~'~ .................... ~"~T~~ ....... ~]~.~ 7790.0 ~92,85 20~, I 2 2~ 5,08 ...... }..~..~..1 ...... }.y.~9_ ..... ~.~..8_ ........ ~.~..~.~. _.._~_~-~?-.~ ......................................................... .'m m m ~ ,~m ~ M ........ 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PAG=~ 22 XXON COMPANY U.S.A. L4SKA ST4TE 0-1 DE'PT'M CFOC CILM CILD RFOC RI'LM ,~I'LD ' SD ' GR -~T~ ................................................................... 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Sm, GR .... ?:'Y7 ,~ v ~ ~ ~ ...................... 3020.0 28.91 64.85 50.94 34.59 15.41 19.63 -63.20 112.02 3030.0 32.99 70.89 65.t9 30.32 14.11 15.34 -59.Z, 9 115.28 3040.0 37.40 72~'~'~ 64.52 ~_6.74 13.82 15.30 -60,9? 131,87 3060.0 41.33 72.66 60.80 24.19 13.76 18.45 '58.51 13'1.24 -:~-'0-?-0""~'"~ ............. ~"' ;f'"~'"~' ~ ......... 7'"2'";'89 ........... ~ 2' ";"5' '3 ............. ~' ~"'~'"' ;i"';5 ............ ':;!-" ~,';'" ~",~ .......... ;'i'" ~" '; "~'-9-"-:'"~,'"'~" ;"'~'"; ....... ;i'§':'¥-'~"-~.'-E ....................................................................................................... .... . . . .:~..: ~. ,,,~. ~_ o.:~. ,....~, ~. ~ .............................. ' - .......................... 'i~ ........ T-" :' ..................................... ~',,' "~"~ ...... ~.:',~- ..~c..?~ ' - ~ , · . .... . .. . , .. . . .~. .?, .~.., ,.,, ,,:,:....,.:~ :!,:~/.: . . :., ¢-;¥,.1¢¥-~, ~,~,~ ..~..,~:'¢;~ \~ ~.:;....' .~ · ............ · .... ' . ,..: '. ..... 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',.~,L.,,,,;' *,~,',~,,,~',;"' ~:'~.~ o,i~:~",,~ i.:~;,~ ,'.~,.~;~,~,; *~,;L~:;'.; "~:.~.:~,~:~." ............................................................................. ........ ,,,t~,.",..~ .?:.:?,. :~.,.::.,t ....................... ..................................................................................... · · .' ., .... ' . ', ' .. · · . 'v. '"' .: ?:., ..... ~"'":"i: .... ~ '?: '~,. ~"',,.,i'.,~''~' ¢":;~;~'?"r'""','"~'"~'"':~'~'~"~"?"':~'~''~', ...... "" ......... ~ .... 4, ~':.' '"?- ...'?.'~., · ....... :'~'~ ........... ""': ....... ~"' ":"' .......................................................................... ":4.;:'~, '... ',: :' '~',,:,' ' >"" ................................................................................. ~XXON COM,~ANY U.S.A. - ......... &LASK,~ ST.~TE ~-1 ~'L~r'~'~- NORTh, SL,3~E,, AL~S,~\ '"'3 "COR V'_- S : SR ~C r~, ~ L · ',. 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ALASKA STATE 3-1 I'LDCAT NORTH SLOP:, ALASKA\ ..... 5':60;0 131 .07 0.00 36.63 630.0 1!1 .30 O.O0 20.51 :?640 ~ O- .......... ~7-T'.:_.?'O ................................. ~";'"~ :~ ...................... -~'~'~'"'1'~ ...................................................................................................................... ....... ~ ~'"'~'"';"0' i'"$' 2': "~ ? 0: '~ O ........................... ~'"~:'"::'~"~ '--~%-0-7'~ ...................... ~-"~"?--_'"~,"Z; ................... O ;"~"~' ................................ ~."~"";"-~-~ ....... ~'"~":;~u.u'~' .................................. 1 z, ~. ~+ :,' ........ :"'";: ............. u.uu'~' ..... ':' ';~ ....................... ;x~ ~. ,., ~,'"'":;~ ........ '.~"~0 . 0 1 56 . 1 6 0 · 0 0 24.4 2 ........ ~, ........... 1u.~ ......... :~ ....................... 131 .-~,"~ '~ ....... ~=. ".. ..... .=.O,D~':: '.:"' '"' ....... 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XXON COMPANY U.S.~. ALASKA STAT~ 0-1 iLDCAT NORTH SLOPE, ~L~SK~\ ......................... . ......... TO 6--0-T5 1 6 5 . 0 5 0 . 0 O 2 8 . 9 4 T' 0'?' ~"';' "~ ....................... i" 5" 4'";' '?' ~ ....................... ~ ";" ~' O ................... ~'~";'" ~"'~ .................................................................................................................................................................................................................................... --~"~'"'-~ ~ · ~ ~u ~ ~ , ~ F 1 0 ~ u, ~ ............ -i"'~-~'-;'"~'"~' ........................ 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'~"~ ~ ............................................. ~ ........ ~ :~'~'i~ '~ ............................................. ..... ~-'~' ';'"'~"'~ ................................................ ~ ........................................................................................................ XXON COMP&NY U.S.~. ALASKA STAT: g-1 ~LDCAT NORTH SLOPE, ALASK2\ ............................ l .......................... 1550,0 159.4'0 0.00 29.91 T"~-?'~-;':3- ........................ T'"~'5'";'":~ ~ ............................... '~":'"".'YO .......................... 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'~LASKA STATE D-1 ~'~T ................................................... ~-ORTn SLOP~-, ALASKA\ ~-'0"' 0 89.06 9.~.0 69.50 2580,0 eS. 0~. 9,11 67.56 2610.0 84.5~ 10.08 57.11 ~-~-~-O. ,~' .................... 1,,,0.44h- ............................... 10 · ~5_ 65.25 2' '~'"'~"~'" ;"~ .............................. ~"~ '"~' '.~ '~ .............. ~'"' ~'"','"'6'"'~ ....................... 6'"~'" ~""~'"~ ............................................................................................... i 2-6-~'b-7,.0- ............ ~'~7;-4'~ ....................... -;f"O-':"'~;'~ ........................ ~'-ZQ--:i"~ ...................... ? ............. : ..................................................... ~"zJ"~'O'"; '~ ............................ ~" ~ '" ;" i '~ ........................ 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