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Home My WebLink About174-014 e .I if ¡ ¡ FRANK H. MURKOWSKI, GOVERNOR .! l J f AItASIiA OIL AlQ) GAS ; CONSERVATION COMMISSION / ./ e r? .~ ~ i'!... L,.-J 1 J w 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 December 22, 2005 Doug Morgan EXXON Mobil Production Co. POBox 2180 Houston, TX. 77252-2180 Re: Alaska State A-I Alaska State A-2 Alaska State G-2 PTD 174-014 PTD 200-141 PTD 182-208 ',~f(" Ii. m..b~:"iiÞ~· ~¥'V6""tU~,:~_t:..- > f'" (1 ~,;;¡ ¡j;:¡ Dear Mr. Morgan: The Alaska Oil and Gas Conservation Commission ("AOGCC") completed a location clearance inspection of the above reference wells. The AOGCC inspection showed the location to be in compliance with 20 AAC 25.172 Offshore Location Clearance. The Commission requires no further work on the subject well or location. However, Exxon Mobil will remain liable if any problems should occur in the future with these wells. Final location clearance is hereby APPROVED for the above listed wells. cc: Richard Owen cc: Steve McMains cc: Well Files DEPT. OF ENVIRONMENTAL CONSERVATION DIVISION OF ENVIRONMENTAL HEALTH SOLID WASTE PROGRAM 410 WILLOUGHBY AVENUE JUNEAU, ALASKA 99508 http://www.state.ak.us/dec/deh Telephone: (907) 465-5153 Fax: (907) 465-5164 April 17 , 2003 Mr. Michael Barker ExxonMobil Production Company P.O. Box 196601 Anchorage, Alaska 99519-6601 S(:f.~.j"F:"} r .....~" 'l~'\:. t__ ! e, 'f¡rw r. LULU Reference: Issuance of Permanent Closure Approval for Inactive Reserve Pits located at Alaska State A-I and Alaska State G-2 located on Flaxman Island, North Slope \ '\ ~-O\ '-\ Dear Mr Barker: The Alaska Department of Environmental Conservation (ADEC) has completed review and public notice for permanent closure approval of the inactive reserve pits located at the above reference sites located on the North Slope. The closure applications and corrective action plans provided the required information describing the history and conditions of the reserve pits( s), results of required water sampling, an assessment of the potential risks posed by the drilling waste to human health and the environment as well as proposed corrective actions. Corrective actions are completed at these sites. ADEC coordinated field inspections and review of the closure plans with the appropriate land and resource managers. At these two sites, the drilling waste was excavated :ITom the reserve pit(s) and transported to a grind and injection facility for disposal. No drilling waste remains at the sites and it is expected that within a few years, the area of the empty pits will erode into the Beaufort Sea. ADEC has determined that these sites present no material or probable risk to the public health or the environment. Public notice requesting comments on the closure requests was published March 7 and 8, 2003 in the Anchorage Daily News and posted on the state web site March 7, 2003. No public comments objecting to closure approval were received in response to this public notice. ADEC has determined that the reserve pits at these sites meet the closure requirements of 18 AAC 60.440. Closure Approval Under authority of 18 AAC 60.440 (j), ADEC grants permanent closure approval to ExxonMobil Production Company for the inactive reserve pits at the following sites: e e Mr. Michel Barker ExxonMobil Production Company April 17,2003 Page 2 of3 Well Name(s) API Number MTRS Landowner Alaska State A-I 50-089-20003-00 Section 27, nON, R24E, UM DNR Alaska State G-2 50-089-20020-00 Section 35, nON, R24E,UM DNR Terms and Conditions This permanent closure approval is subject to the following terms and conditions: 1) In accordance with 18 AAC 60.440(1), the Department will require additional investigation, assessment, monitoring or remediation if new information regarding conditions at the reserve pit facilities indicates that further actions are necessary to protect human health or the environment. 2) The approval granted by this letter is for the inactive drilling waste reserve pit(s) only. Closure for the pad as a whole (if required) must be coordinated between the owner/operator and the appropriate land owner/manager. Any person who disagrees with this decision may request an adjudicatory hearing in accordance with 18 AAC 15.195- 18 AAC 15.340 or an informal review by the Division Director in accordance with 18 AAC 15.185. Informal review requests must be delivered to the Division Director, 555 Cordova, Anchorage, Alaska, 99501 within 15 days of the permit decision. Adjudicatory hearing requests must be delivered to the Commissioner of the Department of Environmental Conservation, 410 Willoughby Avenue, Suite 303, Juneau, Alaska 99801, within 30 days of the permit decision. If a hearing is not requested within 30 days, the right to appeal is waived. Sincerely, ELECTRONICALLY TRANSMITTED Glenn Miller Solid Waste Program Manager Glenn _ Miller@dec.state.ak.us cc: electronic only Harry Bader, ADNR, Fairbanks (Harry_Bader@dnr.state.ak.us) Tom Maunder, AOGCC, Anchorage (Tom_Maunder@admin.state.ak.us) Bruce Webb, ADNR, O&G Division, Anchorage (Bruce_ Webb@dnr.state.ak.us) Jack Winters, ADF&G, Fairbanks (Jack_ Winters@fishgame.state.ak.us) Kaye Laughlin, DGC, Anchorage (klaughli@jpo.doi.gov) Linda Nuechterlein, ADEC, Anchorage (Linda_Nuechterlein@dec.state.ak.us) Terry Carpenter, COE, Anchorage (Terry.A.Carpenter@poa02.usace.army.mil) e e Mr. Michel Barker ExxonMobil Production Company Louise Smith, USFWS, Fairbanks (Louise_Smith@fws.gov) Sheldon Adams, NSB, Barrow (Sheldon.Adams@north-slope.org) Rex A. Okakok, Sf. NSB, Barrow (Rex.Okakok@north-slope.org) April 17, 2003 Page 3 of3 ALASKA OIL AND GAS CONSERVA~ION CO~ISSION December 19, 2002 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276- 7542 F.E. Hand, Jr. Global Remediation, Major Projects - Upstream ExxonMobil 601 Jefferson KT 1244 Houston, Texas 77002-7901 Re: Final Location clearances Alaska State A-2 (PTD 200-141) Alaska State A-1 (PTD 174-014) Alaska State G-2 (PTD 182-208) Dear Mr. Hand: On August 22, .2002 our Inspector John Spaulding performed a final location clearance inspection 'of the recently abandoned Alaska State A-2. The A-2 well was plUgged and abandoned during this last winter season. Inspector Lou Grimaldi witnessed the pressure testing of the deep plug on March 8 and Inspector John Crisp witnessed the severing of the casing strings below the mud line on 'March 14. In addition tojnspecting the A-2 location, Inspector JOhn Spaulding also examined the locations of the State A-1 and G-2 as well. During the past several years, much activity has taken place on Flaxman Island with the "re- abandonment" of the State A-l, drilling and abandonment of.the disposal well State A-2 and the ultimate removal of the reserve pits at the A-1 and G-2 locations. During theses operations,i AOGCC Inspectors have performed a number of inspections, at 'this remote site. On this latest inspectiOn, Mr. Spaulding found the locations to be in satisfactory condition and :concluded that 'all wells be approved for final location clearance. The LoCation Clearance inspection.' showed the location to be 'in compliance with 20 AAc 25.172 (c) OffShore Location Clearance [natural island] and therefore the Commission requires' no further work on the subject Wells. However, Exxon Mobil remains liable if any problems were to occur in the future with any of the wells. If you have any questions or need further information, pleaSe contact me at 907-793-1250. Sincerely, Sr. Petroleum Engineer CC: Mr. Jeff Osborne, Fairweather E&P ' , MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor, /-~ DATE: Commissioner Tom Maunder, P. I. Supervisor THRU: August 22, 2002 Revised December 19, 2002 FROM: John Spaulding, SUBJECT: Petroleum Inspector Surface Location Clearances ExxonMobil Flaxman Island Auqust 22, 2002: I traveled to Flaxman Island to conduct final inspection on the Alaska State A-2 (PTD 200-141). In addition to that recently abandoned well, the locations of the Alaska State A-1 (PTD 174-014) and G-2 (182-208)locations were inspected as well. A great deal of time and money was spent on these locations last winter and it showed. Both locations have reserve pits that were reclaimed and approved by the ADEC. The reserve pits are near the ocean and will be reclaimed by natural forces' in the near future. The pad area and pits were in excellent condition. SUMMARY: I .recommend final approval for the Alaska State A-2 as well as continued clearance approval for the Alaska State A-1 and G-2 locations. Attachments: Photo's NON-CONFIDENTIAL location clearance Alaska State G-I&A-1 9-22-02is.doc ExxonMobil Production Corni: P.O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone Jacki iiliams, Jr. Producbon Manager, Alaska Interest Joint Interest U.S. E, on Mobil Production March 22, 2002 Mr. Judd Peterson Reserve Pit Program Manager Alaska Department of Environmental Conservation 410 Willoughby Avenue, Suite 105 Juneau, AK 99801-1795 Re: Status Update for the ExxonMobil Flaxman Island Reserve Pit Closure Project at Alaska State A-1 and G-2 'Dear Mr. Peterson: Enclosed is a status report for the ExxonMobil Flaxman Island Reserve Pit Closures Project. This report provides a brief discussion of ExxonMobil's work progress at Flaxman Island this winter. If you have any questio'ns or require additional information, please contact Mike Barker at 907-564-3691 or Buddy Hand at 713-656-9179. Sincerely, DMB:ddm Attachments dmb 2002~FIUudd Petemon Update 3'18.~1oc C~ Dr. Steve Amstrup, USGS Jim Baumgartner, ADEC John Bridges, USFWS Gordon Brower, NSB Glen Gray, DGC Rick Lanctot, USGS Tom Maunder, AOGCC Bill Morris, ADF&G Gary Schultz, ADNR Bruce Webb, ADNR DOG Kellie Westphal, ADNR, DMLW RECEIVED MAR 2 7 200Z A Division of Exxon Mobil Corp~ Attachment I ExxonMobil Production Company Flaxman Island Reserve Pit Closures Alaska State A-1 and G-2 Project Project Status Report, March 18, 2002 This project status update has been prepared to inform state, federal, and Borough regulatory staff of the current project status, and ExxonMobil's plan to complete the reserve pit closures during this winter season. Since the. last status report on January 11, 2002, ExxonMobil has completed ice road construction and we are now removing the wastes from the island for offsite disposal. Work Completed to Date Beginning in late November 2001, ExxonMobil's contractor, Alaska Interstate Construction (AIC), began constructing the ice road to Flaxman Island and reached the Flaxman Island region by late January 2002. A short (three-mile) on-shore ice road segment approximately four miles east of Bullen Point was built in order to avoid a polar bear den. A 21 bed camp was mobilized to Flaxman Island on February 3, 2002. Excavation of the reserve pits began on February 24, 2002. As of March 18, 2002, approximately 14 kcy has been hauled to the Grind and Inject Plant at the Prudhoe Bay Unit Drill Site #4. Excavation at the Alaska State G-2 reserve pit is complete and the work is currently focused on completing the Alaska State A-1 reserve pit prior to April 1st. Over 50 personnel are currently working on this project. Between ten to twelve large dump trucks are operating 24 hours per day. Other Information The USGS and USFWS have identified ten confirmed or possible polar bear dens between Tigvariak Island and the Canning River. Six of the possible dens are on Flaxman Island. A detailed polar bear monitoring plan has been developed in cooperation with the USFWS and USGS. As of March 18, bears have emerged from three of these dens. Extensive monitoring of these bears and the remaining possible dens is being conducted jointly with the USGS and USFWS. Fresh water use for the project began on January 10. To date, three of the five permitted sources have been used. Volumes used from each source are shown in the attached table. The Alaska State A-2 disposal well has been plugged and abandoned. This work was witnessed and approved by the AOGCC. Flaxman Island Ice Road Water Usage Summary '* 1/10/02 - 1/15/02 DUCK ISLAND MINE SITE 722,400 '" 1/16/02- 2/18/02 SHAVIOVIK RIVER MINE SITE 3,390,240 2/;I 9/02 C-1 PlY 384,720 ~20/02 C-1 PIT 262,080 2/21/02 C-1 PIT "' 193,200 2/22/02 C-1 PIT " ' 184,800 , , 2/23/02 C-1 PIT 102,144 2/24/02 C-1 PIT 33,264 2/28/02 C-1 PIT 128,688 ,. 3/1/02 C-1 PIT 149,184 3/2/02 C-1 PiT 42,000 .., 3/3/02 C-1 PIT 45,696 3/4/02 C-1 PIT , , 58,800 3/5/02 C-1 PIT 42,000 3/6/02 C-1 PIT 33,600 3/7/02 C-1 PiT 109,200 , . 3/8/02 C-1 PIT 100,800 .... 3/9/02 ,, , C-1 PIT 42,000 3/10/02 C-1 PIT 50,400 3/11/02 C-1 PIT 0 3/12/02 C-1 PIT 16,800, 3/13/02 C-1" PIT " 25,200 .. , , 3/14/02 C-1 PIT ,33,600 3/15/02 C-1 PIT 42,000 .3/16/02 ,, C-1 PIT ...... 25,2, 0(~ ,,, 3/17/02 C-1 PIT 33,600 " '3/18/02 C-1 PIT 33,600 , , , ,, ,. ,, , , , ,, , .... , , , , , , ,, -- , , ,, ,,, ,, '" ' ' ' "1 , · ,, ,,,, , ,, , , , , , , , , , ,,, , , , , ..... ,, , __ ,, , , , .... Total Gallons: 6,285,216 3/19/02 Page 1 Alaska State A-1 (74-014)Annulus Fluids • Subject: Alaska State A-1 74-014 Annulus Flui Date: Mon, 24 Jul 2000 :4 :19 -0 From: Tom Maunder <tom maunder@admin.state.ak.us> To: Blair Wondzell <blair_wondzell@admin.state.ak.us> Blair, As assigned, I have researched the files regarding the fluids left in the various annuli and the 9-5/8" production casing of the subject well. With two exceptions, I have found the information as presented in Fairweather's report of the winter work of 1998 to accurately show the various fluids left in the wellbore. The exceptions are discussed below. Refrigerated Conductor: 36 x 30 x 28 @ 80' x 54' x 80'. lFie refrigerated portion of this assembly originally had 50/50 ethylene glycol and water in the arculating system. Foam insulation was included as well and the entire assembly was cemented to surface outside the 36". There is no information on the 50/50 mix having been removed prior to the original abandonment. Fairweather makes no mention of encountering any fluid when the casings were severed and the pictures do not show anything unusual. 9-5/8" x 12-1/4" open hole: On Fairweather's diagrams, there is no notation of what fluid was in the hole when the 9-5/8" casing was cemented. According to Exxon's reports, 13 ppg mud was in the well when the casing was cemented. FainNeather's work would not have changed this. Following Fairweather's 1998 work, the only hydrocarbon fluid within the A-1 wellbore is Arctic Pack in the 13-3/8" x 9-5/8" annulusfrom 231' - 1996'. I have drawings depicting the originally abandoned condition and as modified by Fairweather in 1998. Let me know if you require further information. Tom 1 of 2 7/24/00 1:41 PM TONY KNOWLES, GOVERNOR ALAS ~ OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 2, 1999 R.C. Gardner Fairweather E & P Services, Inc. 715 L Street Anchorage, Alaska 99501 R.e~ 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: C1 and G2 locations still need some work. Based on my observations, I recommend the Al, D1, and F 1 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. As 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:LPics'xFIaxmamFLAXMAN G-2 CELLAR.jpg (local) - Microsoft Intemet Explorer Page 1 of 1 11/17/99 12:21:40 PM D:',~Pics'xFlaxman'xNORTHSTAR F-1 PAD.jpg {local) - Microsoft Intemet Explorer ['age 1 of 1 11/17/99 12:21:21 PM D:XPics'xFlaxman~FLAXMAN C-1 VSP.jpg (local) - Microsoft Intemet Explorer Page 1 of l 11/17/99 12:21:49 PM D:LPicsxFlaxmamFLAXMAN C-1 PIPES.jpg (local) - Microsoft Intemet Explorer Page I of l 11/17/99 12:21:57 PM D:LPics~Flaxman~LAXMAN C-1 PIastic.jpg (local)- Microsoft Intemet Explorer Page I of 1 11/17/99 12:23:36 PM MEMORANDUM TO: Robert Christensoni¢~0 Chairman State of Alaska Alaska Oil and Gas Conservation Commission DATE: September 10, 1999 THRU: Blair Wo ndzell,¢~.,.~ P. I. Supervisor II 2-9('9~r FROM' Lou Grimald ,~;~ SUBJECT: Petroleum Ins~)ector Location Clearance Insp. Exxon Point Thompson Unit A1 PTD# 74-0014 D 1 PTD# 80-0101 G2 PTD# 82-0208 F1 PTD# 81-0140 C1 PTD# 80-0046 Thursday, September 9, 1999: I traveled with Mike Barker (Exxon), Gar Caruthers (CH2M Hill), and Bob Gardner (Fairweather) 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 I 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 C-1 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:x, Pics'.Flaxman'xFLAXMAN G-2 CELLAR.jpg (local) - Microsoft Intemet Explorer Page 1 of 1 11/17/99 12:21:40 PM D:~Pics'xFlaxman',,NORTI-tSTAR F-1 PAD.jpg (local)- Microsoft Intemet Explorer Page 1 of 1 11/17/99 12:21:21 PM D:",,Pics'xFlaxmamFLAXMAN C-1 VSP.jpg (local)- Microsoft Intemet Explorer Page 1 of l 11/17/99 12:21:49 PM { D: Pics\Flaxman'\FLAXMAN C-1 PIPES.jpg (local) - Microsoft Intemet Explorer Page t of 1 11;17/99 12:21:57 PM D:\Pics'~Flaxman\FLAXMAN C-1 PIastic.jpg (local)- Microsoft Intemet Explorer Page 1 of l 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 /~,~r~-¢,-z~c~ ~_~ 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 casings 35,000 lb Transported to the NSB landfill. 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 April 13, 1999 Flaxman Island Area Well Site Re-abandonment Alaska State A-l, C-1, D-l, F-l, and G-2, Beaufl 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. Sincerely, DMB'ddm ' / C \data\, n;ord~:lmb\enviro~pt.torn\federal-state agencies\Robert Okristeeson ,-g-99.doc t . / c: Mike Barker, ' Exxon / ' Jim Haynes, DNR-DOG Jesse Mohrbacher, Fa~rweather A DIVISION OF EXXON CORPORATION RECYCLED 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 December 1, 1998 Alaska State A-l, D-l, and C-1 , ~..... 7,-I.o/ff Mr. David W. Johnston Chairman/Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Commissioner Johnston: RECEIVED ,1''- 7 1998 Anchorag~ This communication is in response to your I.etter 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-I, '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 additionl 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 RECYCLED 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',~data\wlnword~mb~agencte~Comml~toner John~ont 1 t .9-98,doc Sincerely, .... TONY KNOWLE$, GOVERNOI~ ALASKA OIL AND GAS 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 99519-66() 1 Re: Alaska State Al. D1 and C1 Dear Mr. Branch' One of our inspectors visited several Exxon exploratory well sites in the Pt. Thompson Unit on the North Slope during August this year. Rob Dragnich accompanied him. Several of thc sites require additional work as trbllows. Alaska Statc A I. (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 thc site. Alaska State D1 (AOGCC Permit 80-I0 I): The well is located on Flaxman Island. A large diameter pipe was visible in thc area of the drill site, which is now submerged, thc pipe is obscured by waves and may only be visible from thc air. Alaska Statc C 1 (AOGCC Permit 80-046): The location appears to havc a partially opened pit and sevcral six inch pipes standing in water on the southeast side of thc location, the casing may need to be cut offdceper below ground level. These sites have previously bccn approved bv thc state for abandonment. However, Exxon remains responsible for these sites and under 20 AAC 25.026 is not relieved of further claims by the Commission after abandonment. Accordingly, the Commission requests Exxon to undertakc appropriate remedial work to correct thc above deficiencies. Please advise the Commission when Exxon will undertake remedial work. Chairman ~OCATION CL ~AR~_N C~ REPORT State of Alaska 0IL & GAS CONSERVATION COMI~SSION :.?i No. ~fie i ! }Tame Lcc=_uicn Spud: 3/Z~/V~, TD: /~, ~-C& , Campietad .Review the well file, and' c_~ment on plugging, well head s uatus, a~d iccaZicm c!ear~ce - orcvide !cc. clear, code. ' Well head ~arker po~ . , j , q ' . Code MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnston, DATE: Chairman THRU: BlairWondzeil, ~ FILE NO: P. I. Supervisor FROM: Chuck Scheve,~' ~' SUBJECT: Petroleum Inspector August 3, 1998 i99khcfe. DOC Location Clearance Insp. Exxon Point Thompson Unit ~ 740014---~~ 01 PTO# 80.-0101 G2 PTD# 82-,.0208 F1 PTD# 81--0140 01 PTD# 80-.0046 Monday. Auc~ust 3.1998: I traveled with Rob Dragnich (Exxon), Gary Schultz (DNR) and Bob Gardner (Fairweather) to inspect Exxon's Al, D1, G2, F1 and C1 locations in the Point Thompson Unit. Alaska 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. r.;a.~,~ ~? CrJ.-~-o~ (cx~or; ('~7~- 9~o I~r 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 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. (-.,~:)~t"/',Q.~ c.;~'(--o~ lo~r"'1.5~'~7.-~ P~,'K~ 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. (..~'~ ~ c~--/- e~ loa.~ ar l'~ ~ 7- '-)..9 Al..a.s.ka. State C1: The C 1 location has what appears to be a partly open reserve oit 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 ~ ~:: '/fo '~.[.a. '~,~ /~zo.~. SUMMARY: It is my understanding that the above mentioned locations all have approved location clearances, if this is the case I 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. Attachments: Photos MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnston DATE: Chairman THRU' Blair Wondzell, ~~ P. I. Supervisor FROM' Chuck S cheve,t~[~,.e.~ SUBJECT: Petroleum Inspector August 3, 1998 FILE NO: i99khcfe. DOC Location Clearance Insp. Exxon Point Thompson Unit A1 PTD# 74-0014 D1 PTD# 80-0101 G2 PTD# 82-0208 F1 PTD# 81-0140 C1 PTD# 80-0046 Monday, August 3,1998: I traveled with Rob Dragnich (Exxon), Gary. Schultz (DNR) and Bob Gardner (FainNeather) to inspect Exxon's Al, D1, G2, F1 and C1 locations in the Point Thompson Unit. Alaska State Al: 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. 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 ef41ze 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. Alaska State C1: The C1 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. SUMMARY: It is my understanding that the above mentioned locations all have approved location clearances, if this is the case I 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. Attachments: 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-I, C-I, D-I, and G-2. Wells A-i, D-i, 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-I, D-i, 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-i: 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. Wondf~l, 'Septet%be1, 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. Thank you for your attention t° this matter. Sincerely, / . DMB:dOm ' ' Attachment / d L; L. 0 ~, 1998 c:~data~winwo~mb~enviro~pttom~undw.doc Alaska 0~[ & 8ss Cons, Comm~Ssio~ A DIVISION OF EXXON CORPORATION RECYCLED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operations performed: [ ] Operation shutdown [ ] Pull Tubing 2. Name of Operator 3. Address EXXON Company, U.S.A. P O Box 196601, Anchorage, AK 99519 [ ] Stimulate [ ] Plugging [ ] Perforate [ ] Alter Casing [ ] Repair Well X ] Other: Re-abandon 5. Type of well: [ ] Development [ X ] Exploratory [ ] Stratigraphic [ ] Service Location of well at surface 2982' EWL, 1542' NSL, Sec 27, T10N, R24E, UM At top of productive interval Straight hole At effective depth Straight hole At total depth Straight hole 6. Datum Elevation (DF or KB) RKB 41 feet 7. Unit or Property Name Alaska State A 12. Present well condition summary Total depth: measured true vertical 8. Well Number Exxon No. 1 9. Permit Number/Approval Number 74-14 10. APl Number 50-089-20003 11. Field/Pool Wildcat 14,206 feet 14,206 feet Plugs (measured) 12,900'-12,996', 12,450'-12,700' 10,650'-10,900', 3,200'-3,400', 66'-231' Effective depth: measured Surface feet true vertical feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Length 85' 824' 3,376' 11,076' 2,221' Size Cemented 30" 350 sx pf 20" 2,400 sx pf 13-3/8" 3,350 sx pf, 250 sx G 9-5/8" 2,250 sx G 7" 1,450 sx G MD TVD 85' 85' 824' 824' 3,376' 3,376' 11,076' 11,076' 12,997' 12,997' Perforation depth: measured true vertical 12,565'-12,610' @ 2spf 12,620'-12,635' @ 2 spf All plugged with cement. Same - straight hole Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary None Intervals treated (measured) None Treatment description including volumes used and final pressure None 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. 15. 17. Form Subsequent to operation None, well was re-abandoned. Attachments J 16. Status of well clasification as: [ ] Copies of Logs and Surveys run [ ] Daily Report of Well Operations [X] Oil [ ] Gas [ ] Suspended [ X ] Re-abandonm_,cnt report . I hereby certify th the foregoin ' d correct to e best of my knowledge Si~ln ed~'~~..~--'-'~Titl; Productio n Mana~ler - Alaska 10-4(~l-R~/. 06/15/88 ~ Abandoned [] Service Submit In Duplica~ ~ Summary of Operations Permanent Re-abandonment Exxon Company, U.S.A. Alaska State A-1 Flaxman Island Area, Beaufort Sea, Alaska Exxon Company, U.S.A. (Exxon) drilled the Alaska State A-1 well on Flaxman Island in the Beaufort Sea in 1975. At the completion of drilling and testing operations, the well was plugged downhole and at the surface. Prior to abandonment, diesel was placed in the 9- 5/8 inch casing from 1500 feet to within 25 feet of the surface. The diesel served as freeze protection in the event that the well was to be reentered at a later date. A 25 foot cement plug was set on top of the diesel. The A-1 wellhead was subsequently cut off in 1986 and a marker post affixed. Since drilling the well, Flaxman Island and neighboring islands have undergone natural erosion and migration due to wave and storm action. Exxon performed a site inspection at the A-1 well site and three other Flaxman Island area wells (Alaska State D-l, F-1 and G-2) on October 25, 1997. The well site insPection revealed several of the wells and related appurtenances had been exposed by erosion or could be in the future. Exxon elected to re-abandon the A-1 well in compliance with current AOGCC abandonment regulations to ensure that the well is not exposed or impacted by future erosion of Flaxman Island. Figure 1 depicts the final status of the A-1 well. Figure 2 presents the final condition of the well in relation to island level. The A-1 well was re-abandoned as part of a multi-well program that included re- abandonment of the Alaska State D-1 and F-1 wells. Final details for the D-1 and F-1 re- abandonment operations are covered under separate Reports of Sundry Well Operations. The re-abandonment of the A-1 well included the following operations: . Excavation to 6 feet below grade around the A-1 well to expose the well casings. Removal of the 36, 32, 28 and 20 inch casings to excavation depth to access the 13-3/8 and 9-5/8 inch casing strings. See Photo 1. . Dressed off the 13-3/8 and 9-5/8 inch casing stubs and install a 5000 psi WP slip on starting head on the 13-3/8 inch casing. Tested slip on head packoff to 1600 psi. . Installed a 7-1/16 inch, 5000 psi WP, double ram BOP stack fitted with one set each of blind and shear rams. See Photo 2. Tested the BOP stack to 600 psi maximum before pressure bled off through cement plug. No leaks in wellhead or BOP stack or pressure increase in annulus. AOGCC A-1 Sundry 06/15/98 , Rigged up coiled tubing lubricator, BOP's and injector head. See Photo 3. Made up a 2-7~8 inch motor and 6 inch mill and drilled out the cement inside the 9-5/8 inch casing. Chased cement plug downhole to 230 feet while milling on plug. No pressure on the 9-5/8 inch casing after drilling through plug. Pull out of hole (POH). o Run in hole (RIH) with coiled tubing to 335 feet. Encountered obstruction. Pressure tested against obstruction to 1200, 1400, and 1500 psi in 5 minute increments with no bleed off. POH. RIH to 355 feet and displace diesel with 15.4 ppg saltwater base, non-freezing mud. Plug at 335 feet disappeared. RIH to 454 feet and encountered impassable obstruction (possible collapsed casing). Pumped mud down coiled tubing allowing mud and diesel to swap past obstruction. Recovered approximately 110 bbls diesel in surface tanks. POH. , RIH with 2-7~8 inch motor and 9-5~8 inch casing underreamer. Underreamed upper 250 feet of 9-5~8 inch casing. POH and rigged down coiled tubing unit. , RIH with explosive 9-5~8 inch casing cutter to 205 feet below grade. Detonated charge and cut casing. Casing perforated but unable to be pulled free from well. Confirmed ability to circulate down 13-3/8 x 9-5~8 inch annulus and up 9-5~8 inch casing. . Rigged up batch cementing unit and circulated water down 13-3/8 x 9-5~8 inch annulus to clean up crude oil arctic pack in annulus. After cleanup of annulus, pumped a 140 sack (24 bbl) permafrost cement plug down the 13-3/8 x 9-5/8 inch annulus and up the 9-5~8 inch casing. Reverse circulated water at 35 feet through 2-7~8 inch tubing to clean out any cement above 35 foot depth. Bled off approximately 15 to 20 gal of water out 9-5~8 inch casing while cement plug u-tubed down annulus and up casing. AOGCC representative declined to witness cementing operations. WOC overnight. , Rigged up a 6 inch O.D., 50 lb Composition B explosive charge on rope and ran in well to 40 feet below grade. Detonated charge to sever casing strings. All strings cut with 32, 28, 20, 13-3/8, and 9-5~8 inch casings partially climbing out of hole due to explosive force. See Photo 4. Removed 36 foot long casing stubs from excavation. Inspected 13-3/8 x 9-5~8 inch annulus and found excellent quality cement in the annulus with no evidence of any residual crude oil in annulus. 10. Rigged up octagonal 50 lb Composition B charge and ran in 36 inch outer casing to 40 feet. See Photo 5. Detonated charge. Unable to pull casing with crane and backhoe. Steam thawed casing. Recovered upper 20 feet of 36 inch O.D. 3/16 inch wall casing. Casing recovered in small sections due to inability of thin wall casing to withstand pulling force. 11. Beat the remaining 36 inch casing stub down a minimum of 20 feet below grade after consultation with Blair Wondzell of the AOGCC. AOGCC A-1 Sundry 06/15/98 12. Backfilled the excavation and mounded the backfill approximately 10% to account for settling. See Photo 6. 13. Picked up all remaining debris on location and demobilized equipment to Deadhorse or other wells in the re-abandonment program. 14. A location clearance visit with the AOGCC and other agency representatives is scheduled for summer 1998 after the snow cover has melted. All liquid wastes recovered in the A-1 re-abandonment program were transported in secure vacuum tanks to Deadhorse and injected at Pad 3 in accordance with AOGCC, ADEC and EPA regulations. Waste hauling tanks and trucks were cleaned at Peak Oilfield Service Company's wash bay in Deadhorse. The A-1 wellhead and cemented casings were transported to the North Slope Borough Solid Waste Disposal Site for disposal. All clean scrap metal was sent for recycle. AOGCC A-1 Sundry 06/15/98 All Depths RKB RKB = 41' MLLW Grade ~15' MLLW $6", 32", 28", 20", 13 3/8" and 9 5 Casings Severed at 66' RKB Casing Cut/Perforated at ~ 2.31' All Casings Removed to 66' RKB Except 36", 3/8" Well Casing Removed to 4.6' RKB 36"x32"x28" Insulated/Refrigerated Structural Casing Cemented to Surface with .350 sx Permafrost Cement in 9 5/8" Casing and 13 3/8"x 95/8" Annulus from 231' to 66' RKB 824.' 20", 94#, H-,~O, Cemented to Surface with 2,4-00 sx Permafrost Plug #4-, 85 sx Permafrost 3,4-00' to .3,200' 1,996' 3,376' Cement Plug #3 10,900' to 10,650' 9,100' 10450' 10,776' Cement Plug #2 50 sx O 11,076' 12,4-50', 12,700' Cement Plug #1 100 sx G Squeezed Through EZ Drill 12,900' 12,997' F.O. Collar @ 1996' 13-3/8", 72#, N-80 Cemented with 3,100 sx Permafrost and 250 sx G, Cemented to Surface Calculated TOC Behind 9-5/8" Casing @ 9,100' CIBP 9-5/8", 4-3 & ~7#, S-95 & P-110, Cemented with 2,250 sx (~ Perfs, 2 spf, 12,565'-12,610' and 12,620'-12,635' EZ Drill Cement Retainer with 100 sx Class G Squeezed Below 7" Liner, 35#, S-95, Cemented w/1,4.50 sx Class G LEGEND 15.4 ppg Mud Cement Arctic Peck (Crude Oil Base) Diesel TD 14,206' 5-7/8" Open Hole NO SCALE FAIR/EXXON/£X498A 1 1:1 6/15/98 SR Figure 1 EXXON Cernpon¥ U.S.A. Alaska Sfofe A-1 Wellbore Schematic, April 1998 I I I Flaxman Island Sea Ice Surface Island Toe NO SCALE FAIR/EXXON/EX49BD4 1:1 ,5/28/98 I I I I Sea Level MLLW 56", 5/16" Wall, 20' Long Casing Left >20' Below Grade .~ "~. ~...-o,'~"'..:~. ,.. ,. · . ,.. ',.~ .'-'.~' ~ ', · ,:%'. ::"' ,.~* .. To Mainland ~25' ~ Coast, Southwest Seafloor A-1 Well Casings Severed at 40' Below Grade Figure 2 EXXON Company, U.S.A. Alaska State A-1 Location, Elevation View, Looking Southeast Flaxman Island, Beaufort Sea PhOto 1: Cutting away 36, 32, 28, and 20 inch casings Photo 2:13-5/8 inch 5000 WP psi wellhead section with from the A-1 well. 7-1/16 inch 5000 WP BOP stack installed. Photo 3: Rigging up coiled tubing unit on the A-1 well. Photo 4; A-1 well casings after being cut and blown out Photo 5: Rigging up octagonal 50 lb Composition B explosive charge at A-1 well for 36 inch outer _casing. Photo 6: Backfilling the A-t excavation. PRUDHOE BFIY HOTEL 'Il I21:659-2752 · 13'98 9-April-98 M.r. Blair Wondzell Senior Petroleum I.!ngineer Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Changes to Re-Abandonment Programs for Exxon Company, U.S.A. Ala.~ka SI.ate A-1 and D-1 ", Dear Mr. Wondzell' This letter confirms our telephone ~;onvet'sation yesterday regarding the referencexl wells. Well A- 1' During coiled tubing operations an ob~motion was encountered at 335' while running in the hole. The 9-5/8 ~ch m~ng w~s then pressure te~ted to 1200,1400, and 1500 psi in five minute intervals, wi~."no bleed offi We ~gr~d lhat no thrthcr penetration depth was neuessu~ in the well and that tl~e abandonment program could continue from 335 Well i)-!' While drilling out the originally plug, frown ,ement was encounler~ agreed that an additional 30 feet eoul~ drilled off tim existing plug, ifnecessa.~, ~nd replaced w~th competent pem~affo~.~ment pnot to euto~ at the program depth, If you have any questions or comments regarding lhe above program changes, plea..~e conlact the undersigned a~ your earliest cmnvenience. Thank you ~3 your prompt assistance in making these program changes during field opera.tions. ~':,,',,:,::,:', Sincerely, Jesso Mohrbacher Fairweather E&P Services, inc. 715 L Street, Suite 4 Anchorafle, AK 99501 907~258-3446 G'lyde B nldwin, Exxon Mike Barker, Exxon STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [ ] Abandon [ ] Suspend [ ] Alter Casing [ ] Repair Well [ ] Change Approved Program [ ] Operation Shutdown 2. Name of Operator EXXON Company, U.S.A. Address P O Box 196601, Anchorage, AK 99519 ] Plugging ] Pull Tubing ] Re- Enter Suspended Well 5. Type of well: [ ] Development [X] Exploratory [ ] Stratigraphic [ ] Service Location of well at surface: 2982' EWL, 1542' NSL, Sec 27, T10N, R24E, UM At top of productive interval: ] Time Extension [ ] Perforate ] Variance [ X ] Other Re-abandon ] Stimulate 6. Datum Elevation (DF or KB) RKB 41 feet 7. Unit or Property Name Alaska State A 8. Well Number Exxon No. 1 9. Permit Number 74-14 10. APl Number 50-089-20003 At effective depth: At total depth: 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner true vertical measured true vertical Straight hole Straight hole Straight hole 11. Field and Pool Wildcat 14,206 14,206 Surface Length 85' 824' 3,376' 11,076' 2,221' feet Plugs (measured) feet feet Junk (measured) feet None Size Cemented 30" 350 sx Df 20" 2,400 sx pf 13-3/8" 3,350 sx pf, 250 sx G 9-5/8" 2,250 sx G 7" 1,450 sx G 12,900'-12,996', 12,450'-12,700' 10,650'-10,900', 3,200'-3,400', surface-25' MD TVD 85' 85' 824' 824' 3,376' 3,376' 11,076' 11,076' 12,997' 12,997' 13. Perforation depth: measured true vertical 12,565'-12,610' @ 2spf 12,620'-12,635' @ 2 spf All plugged with cement. Same-straight hole Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) None Attachments IX] Description of Sumary Proposal [X] Detailed Operations P~b'~l'rarff' IX] BOP Sketch 14. 16. 17. Estimated date for commencing operation March 15, 1998 15. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Jesse Mohrbacher/258-3446 I hereby certify.t,l~lt the foregoing._Je-4r-ue..~d correcJ~'the best of my knowledge Sign ed ~¢.~~.~,,.,~.. ~~' ~'"'_.~. Ja---r-r~. E~r~ncl~ / ' ~ "-'- '"-~ Title Product on Mana~ler - Alaska Status of well classification as: Abandoned [ ] Oil [ ] Gas [ ] Suspended Service Prepared By Name/Number: Jesse Mohrbacher/258-3446 ... J Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location Clearance ~ Mechanical Integrity Test Subsequent form required 10- ~d~ [.Approved by order of the Commission Oi'lgillaj SJgilOd 8¥ Commissioner Form 10-403 Rev. 06/15/88 ~pproved Copy 0avid W, Johnsto~ Date IApproval No. ~. ¢ ¢¢'¢-~'"~/ Sub~it Ir~ Triplicat~ EXXON Company, U.S.A. Application for Sundry Approvals Alaska State A-1 Flaxman Island Area, Beaufort Sea, Alaska INTRODUCTION AND BACKGROUND EXXON Company, U.S.A. (EXXON) drilled the Alaska State A-1 well on Flaxman Island in the Beaufort Sea in 1975. At the completion of drilling and testing operations, the well was plugged downhole and at the surface. The A-1 wellhead was subsequently cutoff in 1986 and a marker post affixed. Diesel is also present in the 9-5~8 inch casing from 1500 feet to within 25 feet of the surface. The diesel was placed in the 9-5~8 inch casing for freeze protection in the event that the well was to be reentered at a later date. A 25 foot cement plug is set on top of the diesel. 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 A-1 well site and three other Flaxman Island area wells (Alaska State D-I', F-1 and G-2) on October 25, 1997. The well site inspection revealed'that the D,1 drill site has ' eroded away and exposed the D-1 well at the waterline on the weStern 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 A-1 well in compliance with current AOGCC abandonment regulations to ensure that the well is not exposed or impacted by future erosional events. The D-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 D-l, F-1 and G-2 wells are covered under separate Sundry Notices. For re-abandonment of the A-1 well, it will be necessary to complete the following operations: Using a coiled tubing unit, drill out the A-1 well through the 25 foot surface cement plug and displace the diesel in the 9-5~8 inch casing with kill weight mud. 2. Cut and recover 200 feet of 9-5/8 inch casing. , Mix and set a minimum 150 foot Surface cement plug in the 13-3/8 inch casing from 200 feet to 50 feet below grade. . Sever the well casings with explosives at 40 feet below grade and pull the well casings. Remove the cellar and backfill the excavation. The above work is in accordance with AOGCC regulations 20 AAC 25.105(i)(1 )(2), 25.120, 25.170 and 25.172. AOGCC A-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. . Excavate around the A-1 well to expose the well casings. Segregate any contaminated soils if found. Cut away the 30 and 20 inch casings to access the 13-3/8 and 9-5~8 inch casing strings. The 13-318 x 9-5/8 inch annulus is reported to contain arctic pack at the surface. Check for arctic pack or cement in the 13-3/8 x 9-5~8 inch annulus. Figure 2 shows the current status of the A-1 well. . It is possible that some cement was introduced to the 13-3/8 x 9-5~8 inch annulus during the 9-5~8 inch casing top job performed in 1986 and it will be important to ensure that any cement is not binding the two casing strings together at the surface. If the 13-3/8 x 9-5~8. inch annulus' is cemented and the 9- 5/8 inch casing is not free from the 13-3/8 casing at the surface, hot tap the 13- 3/8 inch casing approximately 3 feet below the top of the 13-3/8 inch casing to check for cement. Cut the 13-3/8 and 9-5~8 inch casings off below any cement . in the annulus or .chip out any cement binding the two strings together. Note: In the unlikely event that the 9-5/8. and 13-3/8 inch casing strings are permanently cemented together, the well abandonment cementing procedure will be modified to include setting a surface plug in the 9-5/8 inch casing and a standard top job on the 13-3/8 x 9-5/8 inch annulus. This will also preclude the use of explosives for cutoff of the casings. A supplementary procedure for this possibility is attached and approval for the supplementary program is hereby requested. . Dress off the 13-3/8 inch casing and install a 5000 psi WP slip on starting head on the 13-3/8 inch casing. Test the slip on head packoff to 60% collapse rating of the 13-3/8 inch casing. Leave an eight inch stub of the 9-5~8 inch casing above the 13- 5/8 inch flange. Install the wellhead B section (11 inch 5000 psi WP) on top of the 13-5/8 inch flange and energize the packoff to isolate the 13-3/8 x 9-5~8 inch annulus from the 9-5~8 inch casing. Test the packoff to 60% collapse rating of the 9-5~8 inch casing or 60% the burst of the 13-3/8 inch casing, whichever is less. . AOGCC A-I Sundry 02/24/98 On top of the 11 inch 5000 psi WP flange, install a 7-1/16 inch, 5000 psi WP, double ram BOP stack fitted with one set each of blind and shear rams. Test the BOP stack to 60% burst rating of the 13-3/8 inch casing or 60% of the 9-5~8 inch collapse rating, whichever is less. Figure 3 shows the BOP schematic for the A-1 well. o . . . 10. 11. 12. 13. 14. 15. On top of the 7-1/16 inch BOP stack, rig up coiled tubing lubricator, BOP's and injector head. Make up a motor and mill and drill out the cement inside the 9-5/8 inch casing. After drilling through the cement plug, check for pressure on the 9-5~8 inch casing. The closed circulating system will prevent any diesel under pressure from flowing back when the bit drills through the cement plug. Remainder of program assumes that any pressure can be bled off. Run in hole (RIH) with coiled tubing to 1500 feet. Pump kill weight mud (saltwater base, non- freezing) down tubing taking diesel returns at the surface into a vacuum unit. Pull out of hole (POH) and rig down the coiled tubing unit after all diesel is recovered. Send diesel to Prudhoe Bay for recycling. RIH with an explosive 9-5~8 inch casing cutter. Detonate charge and cut casing at 200 feet. Rig up 50 ton crane. Pull 9-5~8 inch casing,with crane. If unable to pull 9-5~8 inch casing, rerun casing cutter or rig up casing jacks or both to pull 9-5~8 inch casing. After pulling 9-5~8 inch casing, rig up coiled tubing unit and RIH with a motor and underreamer or a casing scraper. Clean up arctic pack from 13-318 inch casing wall by running up and down the top 200 feet of the well while" circulating the well. Circulate 13-3/8 inch casing to salt water at,200 feet. POH and lay down casing tools. RIH with coiled tubing and cementing nozzle to 200 feet. Rig up cementing unit. Mix and set a 150 sack (26 bbl) permafrost cement plug from 200 feet to 30 feet below grade in the 13-318 inch casing. Pull up and circulate saltwater at 40 feet to clean out any cement above this depth. Wait on cement for 6 hours and verify top of cement. Notify the AOGCC 24 to 48 hours prior to cementing operations in case they want to have a representative witness the placement of the cement surface plug. Rig up explosive charge on rope and run in well to 40 feet. Detonate charge to sever casing strings. Rig up casing jacks, crane and vibratory hammer to extract casing from the ground. Use steam to thaw the ground immediately surrounding the well to assist with removal if necessary. Backfill the casing hole and excavation. Mound the backfill 10% or more to account for settling. Pick up any remaining debris on location and demobilize equipment to Deadhorse. AOGCC A-1 Sundry 02/24/98 16. File a Report of Sundry Well Operations for the A-1 well with the AOGCC. 17. Conduct a location clearance visit with the AOGCC and other agency representatives the following summer. 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 tank washing 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. AOGCC A-I Sundry 02/24/98 I SITE LOCATION ~ . /--ALASKA STATE 'D-1 ~PT. THOMSON EXXON NO. 3 ' ' - ~ ~~~e ~ / PT. THOMSON UNIT ' ~.~- ~ ~. LEFFi . BROWN~W PT. Figure 1'. EXXON Company U.S.A. Flaxman Island Vicinity I .... I. _ . · IL_ _ All Depths RKB RKB = 4-1' MLLW 25' Top Cement Plug in 9-5/8" Casing ~85' Diesel in 9-5/8" Casing from 1,500' to 25' 824' 1,996' Plug #4, 85 sx Permafrost ,3,.376' .3,400' to 3,200' 9,100' 10450' Cement Plug #5 10,900' to 10,650' 10,776' Cement Plug #2 50 sx G 11,076' 12,450' 12,700' Cement Plug #1 100 sx G Squeezed Through EZ Drilt 12,900' 12,997' ~+++++++++4-++++~. ~ + + + + + + + I'++++++++++++++++ ~++4.+ ~.++ ++ + ++.~ ~ +++ ~'+~'+++++*+++'~ ~ + ++ +4.+++4.+4.++ + 4.~ ~'++++++++++++++++ ~+ ++ +4.4'+ ++ +4.++ ++~ ~++++++.++++4-++++ ~+++++++++++++++'~ ~++++++4.+++++++4.'~ Welded Steel Plate and Abandonment Marker 50" Insulated Structural Casing Cemented to Surface with 350 sx Permafrost 20", 94#, H-CO, Cemented to Surface with 2,400 sx Permafrost F.O. Collar @ 1996' 1,3-3/8", 72#, N-80 Cemented with 3,100 sx Permafrost and 250 sx G, Cemented to Surface Calculated TOC Behind 9-5/8" Casing @ 9,100' CIBP 9-5/8", 4-,3 & 47#, S-95 & P-110, Cemented with 2,250 sx (; Perfs, 2 spf, 12,565'-12,610' and 12,620'- 12,6.35' EZ Drill Cement Retainer with 100 sx Class G Squeezed Below 7" Liner, 35#, S-95, Cemented w/1,450 sx Class G LEGEND 15.4 ppg Mud Cement Arctic Peck (Crude Oil Base) Diesel TD 14,206' 5-7/8" Open Hole Note: Current well status es of 25-Feb-98. Post sundry schematic to follow with completion report. NO gCALE FAIR/EXXON/FLAXA 1-2 1:1 2/24/98 SR Figure 2 EXXON Company U.S.A. Al(]ska Sfafe A-1 Wellbore Schem(]fic ¢-1/16" 10.000 psi WP Coiled Tubing BOP's i I 6-1/8" 5,000 psi WP ~-. Lubricator 7-1/16', 5,000 psi WP x Otis COnnector J 7-1/16", 5,000 psi WP Blind Ram 7-1/16" 15,000 psi WP x 7-1/16" 5,000 psi WP Adaptor 7-1/16", 15,000 psi WP Shear Ram 1 11" 5,000 psi WP x 7-1 / 16" ,~5,000 psi/// WP Adaptor NO SCALE FAIR/EXXON/BOP 1:~ 2/21/98 SR II Figure 3 EXXON Company U.S.A. Alaska State A-1 BOP Schematic EXXON Company, U.S.A. Alaska State A-1 Supplementary Abandonment Procedure The following procedure has been prepared as an alternative abandonment program for the Alaska State A-1 well. This alternate approach may be required if the 13-3/8 x 9-5/8 inch annulus is cemented at the surface and the 9-5~8 inch casing is unable to be separated from the 13-3/8 inch casing. The following procedure begins subsequent to installing the wellhead on the 13-3/8 inch and 9-5~8 inch casing stubs. Alternate Abandonment Procedure . On top of the 11 inch 5000 psi WP flange, install a 7-1/16 inch, 5,000 psi WP, double ram BOP stack fitted with one set each of blind and shear rams. Test the BOP stack to 60% burst rating of the 13-3/8 inch casing or 60% of the 9-5~8 inch collapse rating, whichever is less . On top of the 7-1/16 inch BOP stack, rig up 'coiled tubing.lubricator, BOP's and injector head. Make up a motor and mill and drill out the cement inside the 9-5/8 inch casing. After drilling through the cement plug, check for pressure on the 9- 518. inch casing. The closed circulating sYstem will prevent any diesel under pressure from flowing back when the bit drills through' the cement plug. Remainder of program assumes that any pressure can .be bled off. . Run in hole (RIH) with coiled tubing to 1500 feet. Pump kill weight mud (saltwater base, non- freezing) down tubing taking diesel returns at the surface into a vacuum unit. Pull out of hole (POH) after all diesel is recovered and send diesel to Prudhoe Bay for recycling. . RIH with coiled tubing and cementing nozzle to 200 feet. Rig up cementing unit. Mix and set a 85 sack (15 bbl) permafrost cement plug from 200 feet to surface in the 9-5~8 inch casing. POH and rig down coiled tubing unit. Notify the AOGCC 24 to 48 hours prior to cementing operations in case they want to have a representative witness the placement of the cement surface plug. o Excavate around the A-1 well to 38 feet below island surface. This will require a benched excavation with appropriate egress. Cut away the 30 and 20 inch casings to access the 13-3/8 inch casing. Hot tap the 13-3/8 inch casing to ensure that it is not under pressure and confirm if free liquids (arctic pack) are present. Drain any free liquids through the hot tap valve. A-1 Supplemental Program 1 02/24/98 EXXON Company, U.S.A. Alaska State A-1 Supplementary Abandonment Procedure continued . . . , 10. Install an additional hot tap port approximately 20 feet above the lower hot tap valve. Reverse circulate the 13-3/8 inch annulus with saltwater to clean up arctic pack. Purge the 13-3/8 x 9-5~8 inch annulus with nitrogen. Cut two opposing oval shaped windows in the 13-3/8 inch casing to access the 9-518 inch casing. Perform these cuts with a salvage torch and keep clear of the cut in case the 13- 3/8 inch casing collapses due to the weight of the 9-5~8 inch casing inside. Cut the 9-5~8 inch casing completely. Cut the 13-3/8 inch casing and remove the wellhead and casings. Run in the 13-318 x 9-5~8 inch annulus with % inch pipe to 150 feet or until refusal is met. Rig up a flow nipple and circulate the 13-3/8 inch x 9-5~8 inch annulus to clean up any arctic pack in annulus. Be prepared to pump the returns to, the surface with a trash pump. .. ." Mix and set a permafrost cement plug in the 13--3/8 x 9-5~8 'inch annulus. Trim up the casing stubs to 38 feet below grade dePth. Backfill the excavation in reverse or'der that the material was removed. 'Mound the backfill 10% if possible to account for any subsidence during the summer thaw. Pick up all debris on location and demobilize the location. A-1 Supplemental Program 2 02/24/98 January 23, 1991 Telecopy Iqo. (907) 276-7542 Exxon Company USA F O Box 196601 Anchorage, AK 99519-6601 Re: Alaska Sta'~e A-1 API 50-089-20003-00 Dear Sir or Madam: In compliance with regulations set forth in Title 20, Chapter 25 of the Alaska Administrative Code, your company has dutifully submitted to the Commission sepias of various logs run on the subject well. However, due to age and frequency of use, sepias of the logs indicated below have deteriorated to the point that satisfactory prints can no longer be made from them. Accordingly, in the interest of upgrading the quality of material maintained for permanent reference in the Alaska well log library, the Commis- sion would appreciate receiving fresh sepias of the following logs: Dipmeter (computed or otherwise) Please direct any questions you might have in fulfilling this special request to Larry Grant at 279-1433. Thank you for your contribution toward maintaining a good State well log library. S .,~'~' /'" ,,..,:.. ..,,,:::,..," / /,~1 ,.,"./ ,Z ~,,,. .,~., .... ~ .... .~.~..r~..~,.- ...,,: // ,.r.i?/'" .? .~.'~'~,:',.,"'~,' ,~'.. ,."' .,,,,','~. / ,,~,.."' ,~" .......~ ,.?-..-.: ..... ~,¢' .... /' Robert ? 6randall Sr Petr Geologist jo/L.LJG.01-02 November 21, 1986 Telecopy No. (907) 276-7542 Mr. John P. Clement, III Drilling Manager Exxon Corporation P. O. Box 60626 New. Orleans, LA 70160-0626 Re: Final Location Clgarance Pt. Thomson Unit Well No. 1 Pt. Thomson Unit Well No. 2. Pt. Thomson Unit Well No. 3 Dear Mr. Clement: Alaska state A-1 Alaska State C-1 Our representatives inspected the above referenced locations on August 27 and September 12, 1986, and found'that cleanup was acceptable. Marker posts with the required information.bead welded on them were in .place, "~. Your. letters dated November 10, 1986 requested that we change the status of each of these wells from suspended to abandoned. Since there were no changes made to the well bores of these wells, we did change the status to abandoned on the "Well Completion or Recompletion Report and Log" which had previously been submitted for each well. Based on the above, we hereby approve the final location' clearance for the Pt. Thomson Unit wells Nos. 1, 2 and 3, Alaska State A-1 and C-1 wells. and the sincerely, ~ . Lonnie C. Smith' Co~issioner jo/A.HJH.47 E: ON COMPANY. U.S.A. POST OFFICE BOX 60626 · NEW ORLEANS, LOUISIANA 70160-O626 PRODUCTION DEPARTMENT OFFSHORE DIVISION JOHN P. CLEMENT, III DRILLING MANAGER November 10, 1986 Mr. Chad Chatterton Mr. Lonnie Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sirs: This letter is to request a change in status from suspended to abandoned for the following well: ADL 47556 State of Alaska, Exxon ~1, Alaska State "A". Please refer to the attached form (P-7) for plug and suspension details dated 9/21/75. TVB: j cv Attachment Sincerely, A DIVISION OF EXXON CORPORATION - " ' ...... ~ ~ u~u.~o~ ~o s~ .- WELL COMPLETiOH OR RECOMPLET~ON RiLr.ORT/~,~i~G* ADL-47556 · T¥~'£ oF ~LL: ~;~ " wIL~ ~gLL DI t Otb Lr~ -" ~/1~ Exxon Corporation . ~. O. 8ox 1~0, ~enver, Colorado State of Alaska I. 'W~ NO. ' Exxon ~1 Alaska State "A" 80201 ,o. r~ .,,..., 2982.' EWL & 1542' NSL of Sec. 27-TlON,R24E, UPM, North Slope, Alaska At top pr~. Intervil re~rted below · t tot,, dept~ As Above Wildcat ~., T., X~. M.. ,(~M OBJECTIVE) ec. 27-T10N-R24E UPI4 re-Miss ~ 74-14 41'KB 'I -- ~,, . '.~ I" · :,. ~ ~0 " ~ual Induction, Sonlc, Sonic ~pl~tud~, ~en~lty, .............. mm I m mm mi i m i ~ m imm m I m ~. CAS~G R~CO~ (Re~ ill utrlnIs Set In wth) ..... . . ~ ~.,,, I ,,.~,~. ~.,-.~-~" I ,~ ~ ,~, ,o~,,~,)'2400 zo" '! 94. IH-40 ! 824' 26" sx Permafrost I None ~3-3/8"I 72 IN~.~0 I 3,.~7p.'I 17,, 13350 SXm pe~afrmOSt~ 250"I' '' 9'5/8?' 43_ & 47 S-95& J 11,076' J I°h'',.. 2~50 sx Ciass G I None . ............. 12,565' to 12,610' and 12,620' to 12,635' 2 shots/ft, approximately 7/16" ID Same ~ 9a]. of 7~% HCl'+ I"),~%'HF" ]and 9,'000 9al. of die~e . ~0% HUSOL A m m m mm mm m m m m m m m m ~. PRODU~ION DATE FIRST PR~DU~ON i ~ODUCTION MEi[{OD (FIowhl~, g33 lift, pump~g--slze and type of pump) lWELL STATUS (Produc~ or ' ~ ,'~ i I ~.. ";;:": ~' '..:." ".'. ~, I.: ~' I .... ........ d --. ~ ...... .,.,,,. ,% ~.~ .i . Core data// ' / / 33, I be~e~ce~,~ ~ii tbe foregoio~~u'bed information lm comple~I~e~t ~i d~er,mined from ail availabl~ records ..... ~IC!,EI) - - ' '- TITb~ ' UATE .,,.. ,..,,..,,o.. .., ,,.... ,o, ,,,,,,o.., ,.,. o. ,,,., CONFiDENTIt L. ................... ..... 13. D&3'E SPUDDED it4. DATE T.D.. R.F,~C;ILF, D ItS. DA~ COALP SJ~SP O]~ AIyLr~. ] IPI uqged& ~uspenaea 3-23-75. g-6-75 ,, 1q-21-76 EICON COMPANY, U.S.A. POST OFFICE BOX 60626 · NEW ORLEANS, LOUISIANA 70160-O626 PRODUCTION DEPARTMENT OFFSHORE DIVISION September 26, 1986 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attention' Mr. Lonnie Smith Dear Mr. Smith' Enclosed you will find the Report of Sundry Well Operations for the six applications previously approved. It has been a pleasure having a working association with AOGCC and I look forward to having the opportunity to do so again in the future. If you have any questions about or need further information, please contact F. L. McCollum (504) 561-4982). Very ti ly yours T. V. Burford TVB' stp Enclosure A DIVISION OF EXXON CORPORATION STATE OF ALASKA ...~¢" ALAb\ .. OIL AND GAS CONSERVATION CO~', .... .~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing ~ Other L~ Final Location Abandonment 2. Name of Operator 3. Address Exxon Co., U.S.A. P. O. Box 60626 New Orleans, LA 70160-0626 4. Location of well at surface 2982' Sec 27, T10N-R24E UPM At top of productive interval At effective depth 5. Datum elevation (DF or KB) 10 ' GND Feet 6. Unit or Property name _ ADL#47556 State o:1: Alask; 7. Well number AK State Exxon .# 1 At total depth E.W.L. & 1542' N.S.L. of North Slope, Alaska 8. Approval number 329 9. APl number 50-- 089-20003 10. Pool Wildcat !i A" 11. Present well condition summary Total depth' measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Permanently plugqed to surface 7eeI Plugs (measured) feet feet Junk (measured) feet Size Cemented Measured depth True Vertical depth true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I herelpy certify that the f,.~regoing,.is true and correct to the best of my knowledge Signe~J J. p. Clement, III Title New Orleans Dri] 1 ing M~ Form 10-404 Rev. 12-1-85 "- Date 9/25/8 Submit in Duplicate THRU: FROM: MEM ~'~. ORA D M Sta,'t,,, of Alaska ALASKA 0,~ . AS CONSERVATION CO~,':~,;,,, :ON' TO: Co V. C~~ton DATE: September 5, 1986 Chairma~ F~LENO.: D.JFB.]7 /~f ,?. -"' Lon~ie C. S~ith / TELEPHONE NO.: Co, is S ioner SUBJECT: Loc~tio~ Clearance Exxon Alaska State A-1 ,~',- .... Pe~it No. 74 14 John F. Boyle '~' - Petroleum Engineer Asst Wednesday, August 27~ 1986: I traveled this date from Anchorage to PrUdhoe Bay and met with Tom Burford, Exxon representative. I visited the above listed location, and recommend it for final abandonment. I filled out an AOGCC Surface Abandonment Report which is attached. Attachment 2-001 A(Rev 10-84) FILE INFORMATION: Operator Address 'ALASi~B OIL AND GAS C()N,SERVATION COMMISSION .. SURFACE ABANDO:~bIENT REPORT i'"' 20 AAC 25, ARTICLE 2 Date Downhole P & A Surface Location of Well Sec...Q, / , T/O zx/, R %).~ ~',. U M. 20 AAC 2~.i20: WELL ABANDONMENT MARKER: Permit No AP1 No. Unit or Lease Name Wel 1 No. Field & Pool Dia. Steel Post (4"Min.) ~~zz Length (10' Min.) IO Height Above Final Grade' Level (4' Min.i ~ ~ Top of Marker Pipe Closed with: Cement Plug ~ Screw Cap Welds Set: On Well Head A-'"', On Cutoff Casing , In Concrete Plug _ Distance Below Final Grade Level Ft. in. Side Outlets: All Valves and Nipples Removed All Openings Closed~..~ , With Blinds ~..,"', With Cement , Other INFORMATION BEADWELDEI) DIRECT~LY TO MARKER POST: (List k~ere Different from File Information) Operator /z~I' ¥.. ~. 0 ~""; ' Unit or Lease Name ~ ~ .~:r"?,~ Well Number ~ ...... i , sUrface Location of Well: .~' ~.-. Ft. FC~__L, Ij-~l ~ Ft., FMJ L, Sec _D.') , T 1~ fl//, R ~.-/ {J~" , ~...~ M 20 AAC 25.170: LOCATION CLEAN-UP PITS: Filled In PO', Liners Removed or' Buried ~.t ! , Debris Removed SURFACE OF PAD. AND/OR LOCATION: Rough _.__., Smooth ~-~ Contoured Other Flat , Compacted CLEAN UP OF P~6~D AND/OR LOCATION: Clean ~", Pipe Scrap , Iron Scrap Paper__, Other , Wood , Mud , Cement SURROUNDING AREA: Wooded , Brush Sand__., Other , Tundra ~--"~, Grass , Dirt , Gravel CONDITION SUR[J~QUNDING AREA: Clean ~, Trash from Site Other ,, ,~ Trees.and/or Brush from Clearing Site ACCESS RO~D: ~' , Dirt , Gravel , Ice ,, CONDITION ACCESS ROAD AND SURROUNDING: Clean__, Rough , Smooth , Trash from Operations , Trees, and/or Brush from Clearing Road ..,.Spoil from Clearing Road Other t~/~ '~" REMAINING TO BE DONE: RECOMMEND-APPROV. AL OF ABANDONMENT: Yes , INSPECTED B 05/26/81 . No Final Inspection ?""t,.,, '~' / · DATE l .© ,/ AL ..A OIL AND GAS CONSERVATION COM:.. :.ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Q( Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate [] Other 2. Name of Operator Exxon Company U.S.A. 3. Address P.O. Box 196601 Anchorage, Alaska 99519-6601 At top of productive interval 4. Location of well at surface 2982' E.W.L. & 1542 N.S.L. of Sec. 27 TIO~ t~2.4E UPM, North Slope Alaska At effective depth At total depth 11. Present well condition summary Total depth: measured true vertical Permanently plugged to surface. feet Plugs (measured) feet 5. Datum elevation (DF or KB) 10 ' G~D feet 6. Unit or Prop, c,.r..t~' name 7. Well number Exxon No. 1 8. Permit number 74-14 9. APl number 50-- 089-20003 10. Pool Wi ] dcat Effective depth: measured feet true vertical feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth True Vertical depth RECEIVED true vertical AUG 1 5 1986 Tubing (size, grade and measured depth) Alaska Oil & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch L-2 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver tvtr. Lor~ie Sm.fL~h_ Auqust 15, 1986 Date approved July 8, 1986 15. I hereby cer~.~ theTregoing is true and correct to the b, est of ~y knowledge Signed - Commission Use Only Date Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Plan to convert Alaska State "A" #1 well from suspended to permanent status: 1. Lower wellhead below pad level and back fill with gravel. 2. Replace marker post. 3. Clear all debris from location. RECEIVED AUG 1 5 1986 Alaska Oil & Gas Cons. Commission Anchorage .3UM Stat," of Alaska Chairman ~ '-~ FI LE NO.' D.ADA. 43 THRU: Lonnie ,C. Smithies/' TELEPHONE NO.' Commissioner FROM. Doug A~os Petroleum Inspector SUBJECT: Clean-up Inspection Exxon Alaska St. A-1 Permit No. 74-14 For Final Abandonment Wednesday, June 18~ 1986: I traveled this date from Kuparuk to Prudhoe Bay and m~t with Tom Burfford, Exxon representative. The location listed above requires work as stated on the attached list and shown in attached pictures. I filled out an AOGCC Surface Abandonment Report for this location. It is also attached. ~2-001 A ( Rev 10-84) UJ.~, AND GA~ UL)~:-,k~itVAfi ......... :,,iLo, SURFACE ABANI)C:~MEN'[' REP()RT 20 ~AC 25, ~'r~C~ 2 { FILE INFORMATION: Operator ~o~ ~.~L~ Address ~o.~ a=gz>Dl Surface Location of Well Date Downhole P & A Permit No. 7-q~Z Ft. FaWL, ~647~ Ft. F gSL, Sec. Z~ , T 10 X[_, R2~-~_,. b~.M. 20 AAC 2~.120: I~LL ABANDONMENT MARKER: AP1 No. 50- Unit or Lease Name ~a.~!~ Field & Pool ~,"~ Dia. Steel Post (4"Min.) ~ ~t Length (10' Min.) /O~- Height Above Final Grade Level (4' Min.i ~-~>~ Top of Marker PiPe Closed with: Cement Plug Screw Cap Welds Set: On Well Head...' ~--"-, On Cutoff Casing , In Concrete Plug Distance Below Final Grade Level Ft. in. ~, ~o~ Side Outlets: All Valves and Nipples Removed _~ All Openings Closed ~, With Blinds ~ , With Cement ~, Other INFORMATION BEADWELDEI) DIRECT/LY TO b6\RKER POST: (List Where Different from File Information) Operator ~'A~O~4 ~::~, Unit or Lease Name A~. Well .Number ~_~ I , Surface Location of Well: 20 AAC 25.170: LOCATION CLEAN-UP PITS: Filled In tinO~, Liners Removed or Buried y~, Debris Removed SURFACE OF PAD AND/OR LOCATION: Rough ~-, Smooth__, Contoured , Flat t,,~ ........ , Compacted Other ~O-.~'~.,~~ ~'"~ 4,.~v~.w~t---~ ~,.4'~. , CLEAN UP OF PAD AND/OR LOCATION: Clean , Pipe Scrap , Iron Scrap Paper W/ , Other Wood ~' , Mud , Cement SURROUNDING AREA: Wooded , Brush , Tundra Grass__, Dirt Sand , Other , Gravel CONDITION SURROUNDING AR'EA: Clean .~,' Trash from Site Other , Trees and/or Brush frown Clearing Site__ ACCESS RORD: Dirt , Gravel __,. Ice__, Other CONDITION ACCESS ROAD AND SURROUNDING: Clean , Rough , Smooth , Trash frotn Operations Trees and/or Brush from Clearing Road Other ~k~l, / A' REMAINING TO BE DONE': RECObiMEND-APPROV. AL OF ABANDON~IENT: Yes , Spoil from Clearing Road , No /' Final Inspection INSPECTED BY 05/26/81 DATE dm' 1[~" ~ SUMMARY OF 1986 LOCATION CLEAN-UP WORK Location Pt. Thomson #1 Required for Suspension Required for Abandonment No work required -Remove valve & blind flange & needle valve -Level mound near well- head -Remove rat-hole below grade and cellar Pt. Thomson #2 No work required -Smooth down gravel mound near wellhead -Remove debris Pt. Thomson #3 No work required Alaska State A-1 No work required Alaska State C-1 No work required -No work required pro- vided wellhead is not too high after abandoning pit -Remove debris ,'-Lower wellhead -Cut off refrig pipes below grade -Remove valve & blind flange & needle valve Alaska State J-1 Remove trash -Remove sewage lift station -Remove debris-Regrade & smooth pad-Verify cellar filled with gravel - under water when inspected -Remove cellar boards 7/8/86 E~ON COMPANY. U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION D.H. JONES EXPLORATION COORDINATOR -- ALASKA September 6, 1985 Exxon's Drillsites Inspection and Status Mr. Lonnie Smith State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Enclosed for your review and approval are Sundry Notice forms 10-403 for ten Exxon drillsites located on the North Slope. We request that the status of the Duck Island pad drillsites be approved as permanently abandoned, all the other drillsites to be maintained 'as suspended. Very truly yours, NB3/13:ng Enclosures A DIVISION OF EXXON CORPORATION RECEIVED SEP 1 1 ~ Alaska 0il & Gas Cons. Commission Anchorage ~" STATE OF ALASKA .,' " ALASK/~' ,. AND GAS CONSERVATION C(. ,,,dlSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator Exxon Corporation 3. Address P. O. Box 6601~ A. nchorage~ AK 4. Location of Well 2982' EWL and 1542' NSL of Sec. UPM, North Slope, Alaska 5. Elevation in feet (indicate KB, DF, etc.) 10' Gnd 12. 99502-0601 27, TION, R24E, I 6 . Lease Designation and Serial No. ADL 47556 7. Permit No. 74-14 8. APl Number 50- 089-20003 9. Unit or Lease Name . State of Alaska 10. Well Number Exxon No. I "A" 11. Field and Pool Wildcat Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We request a one year extension to August 1986 of the suspended status of this well. We will arrange to have the location inspected by your representative on a yearly basis or until final abandonment. RECEIVED sEP 1 g' g ~,laska Oil & Gas Cons, Comlnlssl~ Anchorag(~ 7 g is true and correct to the best of my knowledge. Exploration Coordinator Signed ,- Title A1 as ka ~/ ,,-- u s~"' The space below for Commission Date 9/10/85 Conditions of Approval, if any: Approved by COMMISSIONER Approved Copy By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate August 15, 1985 Dr. Michael D. Wilson Alaska Research Associates 11440 W. 39th Place Wheat Ridge, Colorado 80033 Re: Preparation of Shale Compressibility Correlations through Boyless Law Porosity Analysis using Ditch Cuttings and Core Chips From State Sample Library. Dear Mike .. Your June 28, 1984, letter explains why only four of the nine samples of the ~~~~~'~"well analyzed; however, nothing was mentioned of twenty-eight samples that you cut from the Exxon Point .Thompson Unit No. 2 well. In your April 4, 1985, letter you stated that none of the twenty-eight cuttings from~this well were analyzed, but offered insufficient detail on why the.analysis was not prepared covering the specified interval sampled in this well; as agreed to in our letter dated July 18, 1984. Please explain in detail why none of the twenty-eight cuts Were ever analyzed. This would clear up any remaining uncertainties and conclude the Bulk Density Analysis project began June 18, 19.84. Sincerely, Michael T. Minder Petroleum Engineer dlf: A. MTM. 9 MEMORY'. Alaska TO: THRU: ALASKA OIL AND GAS CONSERVATION COMMISSION C. V./~~erton Chair~~ FROM: Bobby Fos t_err~b~; SUBJECT: Petroleum Inspector DATE: FILE NO: TELEPHONE NO: September 11, 1984 D.31.62 Inspect Suspended EXXON Locations Listed Below For Suspended Status. ._ Wednesday! September 5~ 1984: I traveled this date to Prudhoe Bay and met with Junior Westbrook and Noreen Borys, Exxon representa- tives.. As the attached pictures show the locations listed below are in compliance with AOGCC regulation 20 AAC 25.170. Therefore I recommend to the Commission that these wells be accepted as sus- pended from September 5, 1984 thru September 5, 1985. Duck Is land #2 Duck Island #3 Alaska State A-1 Alaska State C-1 Alaska State F-1 Point Thompson #1 Point Thompson #2 Point Thompson #3 Attachment/pictures in file 02-00IA(Rev. 10179) Suspended Well and Location RePort 20 AAC 25, ARTICLE 2 FILE INFORMATION: ~p~r~r - ~~~~_ : Date Suspended Address ,~~ /~6-/- -'/~~i~;~ ~ ~~ Surface ~noc~6~ 6f W~ll' - - ' Permit No. ~--/~ .... Sec.~, T~ ~_, R~~, ~ M. Unit or Lease Name~~~ · ' ' ' ) 0 " ' / ' Condition of Plt,$ _ - ,~D -- ~/ -- , . . - __ . ~ - _ ~- - _~]_ ~ ', _/~ ~~ ~¢~ ~... -~ _ _-_' . -_____ ~ ..... ,,-_ , ' ~ - _ , ........ Well head - All outlets plugged ~s) No Well sign - Attached to well head Attached to well guard Attached to ~ No Ye s No Information correct _ No Cellar - Opened ~Ye s No Fi 1 led ~e~ No Covered ~s No WaterWell - Plugged off Capped Ope n Rat Hole O[~n Yes No Fi 1 led Ye s No Covered Yes No Explanation Photographs taken to verify above conditions ~ No Expla naton Work to be done to be acceptable This well and location is (~_~ceptable)~unacceptable_) to be classified as suspended f.or the~od o~.19~thru ~~-- 19.~D~. Date: ,'--./ . Revised 8124/82 STATE OF ALASKA ~"~' ALASI~' ,,,~. AND GAS CONSERVATIONi'- J,v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator Exxon Corporation 7. Permit No. 74-14 3. Address 8. APl Number P. O. Box 6601, Anchorage, AK 99502-0601 5o- 089-20003 9. Unit or Lease Name State of Alaska 27, TION, R24E, 4. Location of Well 2982' EWL and 1542' NSL of Sec. UPM, North Slope, Alaska 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 10' Gnd I ADL 47556 10. Well Number Exxon No. I "A" 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 1~)-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We request a one year extension to' August 1985 of the suspended status of this well. We will arrange 'to have the, location inspected by your representatiVe on a yearly basis or until final abandonment. 14. I hereby certify that//,~foreg.~ngis)true and correct to the best of my knowledge. /~//~.~~_ ~~ ', Exploration Coordinator - Signed Title A1 aska The space below for Commission use Date 9/10/84 Conditions of Approval, if any: BY Ll)tif':l[ C. SMITH By Order of Approved by. COMMISSIONER the Commission jl~pproved Copy [~2eturned Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Septe~.%ber 29, 1983 Exxon Company, U.S.A. P. O. Box 6601 Anchorage, Alaska 99502 Cleanup inspection for the Following Wells: Duck Island Unit I~o. 2, Sec. 8, Tll~, R17L, U.~i. Duck Island Unit ~o. 3, Sec. 10, TllN, R17E, Point Thomson Unit ~o. 1, Sec. 32, T10~, R23E, U.~:. Point ~homson Unit ~;o. 2, Sec. 3, T9}~, R22E, U.~. Point Thomson Unit ~o. 3, Sec. Alaska State A-~, Sec. ~7, T~0N, ~24E, Alaska State C-l, Sec. 14, T9~, R23E, Alaska State D-l, Sec. 23, T10N, ~23E, U.~. Alaska State F-l, Sec. _17, T10~, R23E, Alaska State C-2, Sec. 35, T10N, R24E, U.~4. Centle[r~n: Our representative inspected the above ten suspended and abandoned well sates for extension of cleanui~ on August 31, 1983. With exception of Alaska State C--2, the cleanup of these well sites are satisfactory. Because the drilling rig was still on location at Alaska State ~-2, a cleanup inspection could not be completed. Returned are eight approved 10-403's, sundry .I{otices and ~eports on Wells, for all the listed wells except for two which need no further approval. Alaska State G-2 has a year ~o go under 20 AAC 25.170(a) and Alaska State D-1 which (classified as aban- doned) has previously been sranted an extension to August, 1984 for removal of the sheet piling. The 10-403's .%;hich you submitted for Duck Island 5nit ).~o. I and Alaska State D-1 are not nece=sar~' and are returned unsigned. Duck Island Unit L:o. I was abandoned ~c~nllole and Duck Island Unit ~.~o. 2 was sidetracked from the well ~ore of ~;o. 1. Conse- quently a 10-403 is not re.quired for ~-~o. 1. A subsequent inspection of each ~'ell will be necessary by August,' 1984. Sincerely, ' · Lonnie C ~ St,~t)'i Cor:~n:i s sioner LCS/J):T: lc: i03: ~) MEMORANOUM Stat of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Co V J ~terton DATE: Chai~~ Thru: Lonnie C. Smith Commi s s ione r FROM: Bobby Fos ter~ Petroleum Inspector FILE NO: TELEPHONE NO: SUBJECT: September 6, 1983 108B:Zl Inspect Suspended Exxon Location's Listed Below. Wednesday, August 31, 1983: I met with Tom Bruford, Exxon repre- sentative, this date and inspected the following suspended loca- tion's. Pictures were taken .and attached to each report. Duck Island #3 Duck Island #1 and ¢2 Point Thomson ¢1 Point Thomson ¢2 Point Thomson ¢3 Alaska State A-1 Alaska State C-1 Alaska State D-1 Alaska. State F-1 Alaska State G-2 I recommend to the Commission that all these location's with the exception of Alaska State G-2 be accepted as suspended locations in regard to pads, pits, and well signs. Alaska State G..-2 is not acceptable due to the rig still being on location. In summary, I inspected the above suspended locations. Attachments Suspended Well and Location Repor'c 20 AAC 25, ARTICLE 2 INFORMATION: _ . /~ FILE '0~ra~Or' ~~~O~ ~~~,., Date Suspended Address .~< ~_,_~_~-~/~O ~' ~~ ? Surface Location of Well -- -Permit No. ~~ Ft. F~~. L, ~~ Ft. F~n API No. ...... Lea se Name Sec.~?, T/~ ~, R~~, Z~ M. Unit or Well Field & Pool Condition of Pad ~~ Well head - Ail outlets plugged Well sign - Attached to well head Attached to well guard Attached to Information correct · d~ No Ye s No No Cellar -' Opened Yes ~Fil led ~ Covered WaterWell - Plugged off No No No capped Ope n Rat Hole Open ~~es No Fi 1 led Ye s No Covered Yes No Explanation.. /?/~ ~,~__ ~ .... Photographs taken to verify above condition~ No Explanaton Work to be done to be acceptable This well and location is a~~p[abl~ (unacceptab~) to,be classified as pended for the period o~, l~_~thru ~~;~,~_ 19~ . SUE . ~-...~__ ~ ~-.-, ~ ,-~ ~--j_ .. ~:~-~_ , Ins~'cted by: ~~ ~V. ~~ Revised 8/24/82 August 18, 1~383 Mr. clark L. Weaver Union Oil Company of CalifOrnia P. O. Box 6247 Anchorage, Alaska 99502~ Re: Geochemical Analyses on [)rill Cuttings and Core Chips in ~tate !?e!l Library -- Chevron ~.avearak Pt. f32-25 and Challenge Island No. 1. Dear Clark~ As a ~natter of record for our respective files, the '"Exxon Ala.ska State A-1 is not to be included a~ong the %~ells on %Jlich geochemical analyses are to be made on cuts of well sanpIes and core chips as outline~'~ in. my August 3, 1983 letter to you. As you know, no cuts were made on that ,~ell. William Van Alen Sr. Petroleun% Geologist b~ E E ON COMPANY, U.S.A. POUCH 6601 .ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION D.H JONES EXPLORATION COORDINATOR -- ALASKA August 9, 1983 Alaska State A-1 Extension Mr. C. V. Chatterton, Chairman State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: A review of our records indicates that Exxon's Alaska State A-1 well is currently carrying a suspended status. We wish to main- tain this status and hereby apply for an extension to August of 1984. We would be pleased to arrange an inspection of this location for your representative. Please contact Mr. R. L. Westbrook at 263-3742 to make the necessary arrangements. Very truly yours, NB: rms 40/45 A DIVISION OF EXXON CORPORATION STATE OF ALASKA ALASKA ,.)IL AND GAS CONSERVATIONC~.,MMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator Exxon Corporation 3. Address Pouch 6601, Anchorage, AK 99502 4. Location of Well 2982' EWL & 1542' NSL of Sec. 27, T10N, R24E, UPM, North Slope, Alaska 5. Elevation in feet (indicate KB, DF, etc.) _ 10' Gna 6. Lease Designation and Serial No. ADL 47556 7. Permit No. 74-14 8. APl Number 50-089-2000.3 9. Unit or Lease Name State of 'Alaska 10. Well Number Exxon No. 1 "A" 11. Field and Pool Wildcat 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] [] Other [~ Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). " We request a one year extension of the suspended status of this well. We will arrange to have the location inspected by your representative on a yearly basis or until finaI abandonment. 14. I hereby certify that tJl~ fore .~o~i. Qg.~S true and correct to the best of my knowledge. ~/~~~_~./~.~ Exploration Coordinator Signed . _ Title A1 a s k a The space below for Commission~se Date 9/9/83 Conditions of Approval, if anYOL~ representative inspected this w~ll site on August 31, 1983 and cleanup ~as acceptable for a suspended location. A subsequent inspection will be necessary by A~gust, 198~. %~?I/ .... ,, ~/~//'!/ "~. ,~1? By Order of ~'"~ 3 Approved by .: ../~,i/'-,~-~4.~-~' ;< \~-~-~-~' ,, COMMISSIONER the Commission Date i_'~_. ~. Form 10-403 u./' L Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate NC~ 23, '1982 Mr. Jamas Friberg, Supervisor Uni~ Oil Co. of Califc~ Brea, Califo~ .92621 Pursuant to o~r kk~ 18 d_~_'~sic~, pexr~issicn is t~y gl-anted ~~ Oil ~y of ~f~ ~ ~~t 'a ~~'1 '~. ~ ~ ~t~ f~ ~ S~'s ~t of ~ ~~ f= ~m .~ 0f ~c~g ~ay ~ ~~ ~ x-ray ~f~~ ~q~s ~i~ '~ ~si~~ ~~ ~ ~ fo~~g ~~, ~je~ ~ ~ ~l~lis~ ~~~: Set t~o. 138 204 20O 221 226 2~0 231 262 ;264 271 275 277 283 286 370 348 270 235 326 302 336 375 3~ Arco Arco B.P. Arco B.P. B.P. Arco Arco Gulf Colville Delta St. Itl '}~bil Kup. St. '7-11'12 Mobil W. Staines 'St. 18-9-19, zabil mkkel. Bay St. ~-9-19 Phc/n ~U~y Pt, #l Arco W. Sak River St. #1 Arco ~I[ - 7 Exxum Alaska St. 'A-1 Placid P. B. Sta~ %1 B.P. Sag Delta 31-10-16 Arco E. Bay St. ~hbil Ech~ Unit %1 B.P. Niakuk ~1 Arco P.B.U. 9-6 '' cities uwyayr Bay St. A#i (210 ft. ~ite ,. ~samP!es~),~ 8010-13260 6500-10790 6040-8940 4510-6740 6410-9020 5690-8050 5040-8540 6800-9580 '3070-7660 '5100-7700 10020-13390 10634-11751 5860-9140 '4120-7440' 6720-8080 12560-14185 5766-8840 7460'10535 7530-9490 '7090-12815 7040-10776 7200-9260 6330-11910 ~k~smber 23, 1982 tracted only frc~ those individual sample ',en~ 'in which ~aal ~ntant of cuttings is.grea~ than 10 o~. (No cuts are t~ be ex~racU~ 10 cc.).. ' 2. Union will provide t/~'Ccrmttssicn with a ~list of the d~pts in 3. Unic~ will provid~ th~ '~ccn~ssion with a ocpy of ~e c0mp~' clay minamlo~ analysis, al~ slid~ pre~,' a~l ~r~id~ aha ~1 ~r~ to be transmitS, direct to the CCun~ssion and not ex=ine~ ~ ou~id~ parties. W, , ~'" "-"' , ~' : f .... ,~, '. '." ', ,. , .... Im are plea~d to ~u~k with y6u iin this. ban~ficial proj~c~ =,~ look to your c~pany's c~n~~ ~i~ 5f car~ and 9 .~d, ju/~t., in ~ ~rocessin~ o£ this 'limi~ qu~n~ of ~1~ ~.ll'~~ial. 'I kno~ w~ both undarstand ~si~n to ~ porti~ of m~t~rial fan~ ~his ~. for th~ purpo~ PALYNOLOGICAL ANALYSES of Core Chips Mobil Mikkelsen Bay St. #13-9-19 Sec. 13-TgN-R19E (UPM). Humble East Mikkelsen Bay St. #1 Sec. 7-T9N-R21E (UPM)' Mobil West Staines St. #18-9-23 Sec. 18-T9N-R23E (UPM) Exxon 'Alaska'"St'. A-I Sec. 27-T10N-R24E (UPM) David I. Wharton Sohio Petroleum Company 100 Pine Street San Francisco, California 94111 June 26, 1981 PALYNOLOGICAL ANALYSES The following are the results of a palynological study of core samples from the indicated four Beaufort Coast wells in the State well library. The study was conducted by David I. Wharton, Sohio Petroleum Company, and reported to the Alaska Oil and Gas Conser- vation Commission June 26, 1981. The palynologic slides, within the respective intervals for each well, are available for refer- ence in the Commission's well sample library. MOBIL MIKKELSEN BAY STATE NO.1 (13-9-19) ( 8 s'l-f sY ) Five samples from cores No. 15 and No. 18 in the lower part of the Endicott Group, and three, samples from 'cores No. 19 and No. 20 in the Neruokpuk Group were examined. Core samples from the Endicott Group (15101'-15102', 15106'- 15109', 15115'-15120', 15123'-15129', and 15905'-15919') yielded poorly-preserved assemblages of miospores including Lycospora spp., .Corbulispora spp. Lophozonotriletes rarituberculatus an~] abundan~---I~h-s-6's-p-~'ites, wnlcrl lna~cate a p~5~51e Vlsean (late Osagian to early Chesterian) age for this interval~. Core samples from the Neruokpuk Group (16545 '-16546', 16573'-'16581, 16583'- 16.598') were devoid of any identifiable palynomorphs. HUMBLE EAST MIKKELSEN BAY STATE NO.1 .... (i'0-S'l'ides--l~~w. to 14,660~ One sample from core No. 2 in the higher part of the Endicott Group, and nine samples from cores'No. 3 and No. 4 in the Neruok- puk Group were examined. The sample from the EndicOtt GroUp (12696'-12698') contained a poor miospore assemblage including the forms Lophozonotriletes 'raitubercu!atus Densosporites~var.~iomarginatus, and Dloollsporl~es ~'{~'{nctus' The--ratter spec~'~ ~ ~-~-~,t%-i-~-~-~d to the l-~-~-~Sur- na~slan and early Visean (Osagian) of Western Europe. It has not been recorded previously from nort. hern Alaska, nor, as far as I am aware, from Arctic Canada. Its precise stratigraphic signifi- cance is therefore not known. Nine samples from the Neruokpuk Group (13896'-13878'; '13885'- " 13894' 13903'-13908' 14605'-14608' ' 14611'-14620' 14621'- ~ii.,!' 14629', 14631'-14639', 14641'-14645' and 14657'-14660') contained .~.' " no palynomorphs considered to be in place. Five of .these samples ,. ~ .... '' .'contained very small numbers of Visean miospores presumed to ? . represent contamination, in view of the nature of the accompany- ' ing kerogen which was quite atypical of the Endicott Group PALYNOLOGICAL ALYSES Sohio Petroleum Company June 26, 1981 Page 2 MOBIL WEST STAINES STATE NO.1 (18-9-23) (8 slides--13,125' to 13,326') Eight samples from cores No. 12 to No. 16 in the Neruokpuk Group were examined. These samples (13125'-13132', 13158'-13166', 13177'-13185', 13278'-13281'., 13283'-13292', 13297'-13301', 13312'-13316' and ' 13319'-13326') contained? nothing but highly carbonized organic debris of indeterminable origin. EXXON ALASKA STATE A-1 (40 slides--10,213' to 14,206') Thirty-five samples from cores No. 1 to No. 9 in the lower part of the Tertiary sequence and five samples from cores No. 12 to No. 14 in the~ Neruokpuk Group were examined. The samples from the Tertiary section spanned the intervals 10213'-10871' and 12428'-12756', those from the upper interval being substantially more fossiliferous than those from the lower (oil-producing) interval. The higher interval is characterized by consistent occurrences of the pollen general Alni~pollenites, Quercoidites, Tiliaepollenites, Caprifoliipites and Pterocayapol- lenites with sporadic occurrences of the dinoflagellates Spini- ~dini.um densispinatum, Senegalinium microgranulatum, Phelodinium magnificum and Wetzeliella articulata, the fungal spores Pesavis tagluensis and Ctenosporites eskerensis, and the pollen Betulae- .pollenites and Nudopollis. These assemblages are considered to indicate, an early to mid-Eocene age. The lower interval is characterized' by generally numerous and diverse fungal spores, including the formS Dicellaesporites, Multicellaesporites, and sporadic Pesavis tagluensis, nondescript disaccate pollen, the pollen Par~alniPolleni~es, and rare. organic-walled microplankton including _Spinidinium densispinatum, O~ligosphaerdium complex and Palaeoperi dinium sp. The scacity of triprojectate pollen which are generally frequent in the late Campanian to Maastrichtian of. Arctic North America, the absence of ~the pollen Wodehouseia which characterizes the late Maastrichtian .to earliest Paleocene of the. region, and of the Eocene and younger pollen Tiliaepol!enites which occurs consistently in the higher interval, together with the presence of the Paleocene to Eocene dino~lagellate Spinidin- ium densispinatum and the Paleocene .pollen Paraalnipollenites, all support a Paleocene age for this interval. David I. Wharton Sohio Petroleum Company. 100 pine Street San Francisco, California 94111 · CORE DATA Core #1 10,213-i0,273'. Rec. 60' shale and siltstone. No shows. Core #2 10,645-10,671'. Rec. 26' siltstone with thin shale partings and thin laminae of sandstone, vfg, siliceous, no porosity. No shows. Dip 50. Core #3 10,701-10,761'. Rec. 60' siltstone with thin shale partings and thin laminae of sandstone, vfg, siliceous, no porosity. No shows. Dip 7o. Core #4 12,427-12,463'. Rec. 22.5' shale with thin interbeds of sandstone, vf-fg, poor porosity with oil staining; 13.5' sandstone, vf-fg, fair porosity with oil staining. Horizontal dip. Core #5 12,468-12,557'. Rec. 10' sandstone, vf-fg, fair porosity with oil staining; 29' shale with thin laminae of siltstone; 9.5' sand- stone, vf-fg, fair porosity with oil staining, with thin interbeds of shale and siltstone; 9' shale with thin interbeds of sandstone; 28' sandstone, vf-fg, poor to fair porosity with oil staining, interbeds of shale and siltstone; 3.5' shale with interbedded s i 1 ts tone. Core #6 12,557-12,647'. Rec. 17 shale with interbeds of sandstone, vf-fg, poor to fair porosity with oil staining; 73' sandstone with inter- bedded shale and siltstone, sandstone is fg, poor to fair porosity with oil staining. Dip 3-4o. Core #7 12,647-12,737!. Rec. 2' sandstone, fg, fair porosity with oil staining; 88' shale with thin laminae of siltstone. Dip horizontal. Core #8 12,737-12,747'. Rec. 6' shale. Core #9 12,747-12,757'. Rec. 9' shale. , Core #10 12,946-12,951'. Rec. 4' quartzite, f-rog, fractured, bleeding oil and water, poor pinpoint porosity. Core #11 13,019-13,030'. Rec. 3' dolomite, f-xlyn, fractured, poor porosity, oil staining. Core #12 13,228-13,237". Rec. 9' shale with thin interbeds of siltstone and quartzite, vfg, fractured, bleeding oil. Dip 0-50. Core #13 13,948-13,970'. Rec. 22' shale with thin laminae of sandstone, vfg, no porosity, no shows. Dip 2-80. Core #14 14,175-14,206'. Rec. 31' shale with thin interbeds of siltstone, no shows. Dip 5-15o. OCT 2 1975 SOHIO PETROLEUM COMPANY Geological Services Laboratory 215 Market Street, Suite 1315 San Francisco, CA 94105 Tel: (415) 445-9555 TPJ~_NSMiTTAL OF MATERIAL coM~/~;'~.~ 1 ENG~._ ~ 2 ENG~ ,..-?.~ 3 Fbi"-" ~-] GEOL 3 GEO[~ --- STAT TE'~ ~ - 11 ST, CONFER: ,, FILF~ ADD. SS: State of Alaska Oil & Gas COnservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 DATE: October 9, 1979 YOUR REF: OUR REF: SENT VIA: CF Air Freight Airbill %185 682022 ATTENTION: Dr. William Van Alen We are sending the following material to you today: One package containing the remaining palynological slides from Alaska St. A-1 as folloWs: 6 (~3) slides: Alaska St. A-i, 12,747'- 14,206' acknowledge receipt by signing and returning the second copy of this letter. Thank you very much. Yours very trul J. iW. Dial, Laboratory Manager Sign_ ~' - SOHIO PETROLEUH COMPANY Geological Services Laboratory 215 Market Street, Suite 1315 San Francisco, CA 94105 Tel: (415) 445-9555 TRANSMITTAL OF ~ATERIAL State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 DATE~ Septen~er 26, 1979 YOUR REF: OUR REF: SENT VIA: ATTENTION: Dr. William Van Alen We are sending the following material to you today: One pac];age containing palynological slides to complete the set of slides we sent to you in July. We are sending slide #3 from each set as follows:~ 8 slides: W. Staines St. ~1 13,125'- 13,326' 10 slides: E. Mikkelsen Bay St. {Il 12,696'- 14,660' ~ slides: Mikkelsen'Bay St. 34 slides:~'~Alaska St. 60 slides total 15,101'- 16,589' 10,213'- 12,743' / lease acknowledge receipt by signing and returning the second copy of this letter. ~ Yours very truly, J. W. Dial, Laboratory Manager S ig n e ~: f.,/d;.~.. ~' "?.? ' /'zF Date: lC/7, ?' ALASKA OIL AND GAS CONSERVATION COAfil~/$SION' October 4, 1979 IA)" & ~A~fONO, GOVERNOR 3001 PORCUPINE DRIVE-ANCHORAGE, ALASKA 9950; Dr. David J. ~arton Sohio Petroleum Company 100 Pine Street Sah Francisco, California 94111 Dear Dr. Wharton: Thanks to your careful packing, the pollen slides reflected on the enclosed transmittal were all received in fine shape last week. in reviewing this material, we.note that t]~e set of "#3" slides from 12,747 to 14,206 frc~ the Exxon Alaska State A-1 were not included. Specifically, the following are the missing "#3" slides (regular palyomorph slides): 12,747'-756' 13,230'-237' 13,950'-963' 14,177'-181' 14,185 ' -194 ' 14,196'-206' Please let n~ know when you anticipate sending these slides and when we can expect receiving the outline of your stratigraphic conclusions. Yours sincerely, William Van Alen, Petroleum Geologist Conservation March 6, 1978 Re: Exxon Flaxman Island Well Mr. Robert Loeffler, Esq. Isham, Lincoln & Beale Suite 701 1050 17th N.W. Washtr~ton, D. C. 20036 Dear Bob: Attached are xerox copies .of the information in .our well file. on Exxon's Alaska State "A" Well No.. 1 which is located on Flaxman Island.. All of this information has now been released to the public with the two year of confidentialityhaving ex- pired on October 24, 1977. We:.havenot included copies of' the logs on this well which would reql~ire outside reproductio:n and are difficult to handle.. If you need anything else on this well, please advise. Sincerely, Di rector OK,:be Enclosures C~se rva t J c~ October q, 1977 ~r.i Gene Thompson c/o Robert Riddle Exxon Corporat i c~. Pouch 660] Anchorage, Alaska ~$02 Dear Sir: The ~el) ftIe on the Exxc~ Corporation #) A1.aska State "A" we. Il wt)) be re)eased to the public on. October 2)., 1~77. tn. the course of re- viewing the well f'! Ie we fina that the data on DST #1 and DST #2 to be incomplete, in .additfcm:, there is no data at all for ~/el) Test #3. ~/e would appreciate re. celvtn.g the complete descrJptic~ of these three tests et your earliest con~enien, ce. It wit1 not be nece.ssary~ to re subml t the. Form P-7. Yours very t r.uly, ~I rector E ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 PRODUCTION DEPARTMENT ALASKA OPERATIONS Re- December 30, 1976 United States of America vs. Exxon Corporation, No. A76-184, U. S. District Court -- Alaska O. K. Gilbreth, Director Alaska State Oil & Gas Division 3001 Porcupine Anchorage, AK 99504 Gentlemen' For your information on September 1, 1976, a Stipulation of Settlement was entered as a judgment in a civil action brought by the United States of America against Exxon Corporation alleging violations of the Federal Water Pollution Control Act of 1972 in connection with the Company's drilling operations on Flaxman Island, Alaska. This judgment, a copy of which is attached, remains in effect for a period of five years from September 1, 1976, and covers Exxon's exploratory drilling operations con- ducted within the geographical area described in the judgment. This is to.inform you that it is the policy of the Company to conduct its operations in strict compliance with this judgment and all applicable laws and regulations. Very truly yours,/~ William M. Barstow Accounting Manager WMB'db Attachment · . ?, 'C T ?'L kEV ................... SEC A DIVISION OF EXXON CORPORATION RECEIVED JAN - 8 lg77 Division of 0tt and ~a8 ~n~ervation A~ohot,~ ..1'ATE of ALASKA DEPARTMENT oF NATURAL RESOURCES Division of Oil and Gas To: [-- Hoyle H Hamilton~ Acting ~irector /~Y~P -' FROM: Ben LeNorman Petroleum Inspector DATE : September 13, 1976 SUBJECT: Location. inspection Exxon Alaska State A-1 August 30, 1976 - Departed my home at 7:00 AM for 7:30 AM showup and 8:30 AM departure via Wien flight no. 23 to Deadhorse. Met John Jackson, Exxon drilling operations superintendent, at the airport and discussed inspection of their Alaska_k~_~S~_~te A-1 and Canning River B,1. ~ ' · Departed Anchorage at 8:30 AM and arrived in Fairbanks at 9:20 AM where we deplaned in an effort to find .Bill Copeland of the Division of Lands who was to have joined us in these inspections. He could not be found. Shortly after reboarding the plane, the flight attendant delivered a handwritten note from Chris Guinn of ADL advising their representatives would not be able to join us on these inspections (note attached). Arrived in Deadhorse at 11:05 AM ~a.nd completed arrangements for. inspection of Exx.on's Canning River B-1 abandonment.. · Departed Exxon pad at 1:55 PM.via Sea-Ai..rmotive Bell 206-B helicopter for Flaxman Island. We were joined on the flight by. Johnny Crouch, Anchorage.- based Exxon representative in charge of services. Arrived over Flaxman Island at 2:35 PM where Photo No.. 1 was taken of ..the pad looking due north. Photo No. 2 was taken nor-i:hwe~'-t-~'t°~ta.rd the pit area. Phot~ No. 3 was taken 'lOOkS'rig northwest showing the stilling pond, well mark-e~"an~J- Photo No. 4 was taken at ground level showing the well marker and Exxon r~epres~e~ntatives. Photo No. 5 is a panoramic view. of. the pad taken from the south edge of the -p-ad.-'~'Ph61t6 No. 6 is. a. n~n~.r~mir ,,~-,, ~ ~, " ' '' H. H. Hamt 1ton -2- September 13, 1976 Sep~mber 8, 1976.- We were advised this date by Mr. John Jackson of Exxon that Alaska State A-1 would continue on a suspended status. A field inspection report was prepared noting approval of cleanup of debris and levelling of the pad at this location. A copy was mailed to Mr. Jackson and a copy attached to this report. In sun, nary, inspection was made and approval given for cleanup of debris and leveling of the pad on Exxon's suspended location Alaska State A-1 Flaxman Island. Attachment BLN :bJm cc: Bil 1 Copel and Alaska Oivision of Lands, Fairbanks Drlg. permit No.~'.,/~ 'Operator ~ .... Alas Oil and Gas Conservation CommitiJ Field Inspection Report ; ~ ~J ~ ~ ~] Well/~~ Represented bY,..}~CA~2 Name & Number Satisfactory Yes No Item () () () () () () () () () () ( )' () () () () () Type Inspection ( ) Location,General 1. Well Sign 2. General Housekeeping 3. Reserve Pit-( )open( )filled 4. Rigl)~ Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ()' We:ll Test Data 7. Well NoS. , , , 8. Hrs. obser , , Sati s'factory Yes No () () () () () () () () () () () () () () ,__ () () Type Inspecti on Item ( ) BOPE Tests 15. "Casing set @ 16. Test fluid-( )wtr.---]--~")mud ( ) oil 17. Master Hyd. Control Sys.- psi9 18. N~ btls. , , , _psig 19 R~mote Controls 20. Drilling spool- "outlets 21. Kill Line,( )Check valve 22. Choke Flowline ( ) HCR valve 23. ChOke Manifold No valvs flos 24. Chokes-( )Remote( )Pos.(~dj~ ( ) ( ) 9. BS&W__, , , ( ) ( ) ( ) ( ) 10. Gr: Bbls. ( ) ( ) , ~ '__ '('.) Final Abandonment ( ) ( ) ( ) ( ) 11. P&AMarker :( ) () ('~:'~,~') ~',"(,,, )' 1,2 .W,a~,er~ 'W~e~ll,:~,( )Capped<, ,:)pl~,u.gged ,~,(,.~)' ,( ) (') ( ) .13. Clean-up ) (') () ()' 14. Pad'leveled ) .( ) 25. Test Plug-( )Hellhd( )cs.o( )none 26. Annular Preventer.,_____psio 27. Blind Rams, ps 28. Pipe Rams ~.psig 2,9,..,-.. Kel-1 ~,& 30, LOwer Kelly Valve ______psig 31, Safety..FlOor Valves--Z-(--TBV ()Dart ~.~,',..i' Total ins ?i'":i::"%.Rema r k s .,:~]'...~.' .... '- .,',"': ',::>.,.' ,/ ,,'~'~" ~.'?...~'",~b:.,~ ~' ,.. ,~_ ~.~ · . e i::' CC ' Notify in days or when ready mber leaks and/or'e ). failures ..... ., ,, ....... ~,,~ ..... ,,,..? :.'./.;~:~,~.~ Inspected by ...... :': .... '~' . ,.-, ~-Date_~ ..U_i'UZED. STATES DISTR',CT COURT. %t'~ 21IE U,N!TED STATES DISTRICT COURT -~' ?,,'~ o~ ALAS~, ~L~,,j,.~,o.~o~.t~l.../.,_,,,,.f.~,...,,.,.~l,.~o,.----,-o , . ,. · ~.O,,'THE DISTRICT OF ALASKA UNITED STATES OF 7d-IERICA ' Plaintiff, EZXON CORPOP, ATION, d/b/a EXXON CO2.~;uNqr, USA · : Defendant. ) ) ). ) _ CIVIL NUHBEK ' - - STIPULATION OF SETTLEHE~IT A>ID OKDEK - ~he Unit.ed':States, plaintiff, and the Exxon Corpora'tion, by counsel, -_ · o . . agree tha~ an order to the-following effect be. entered-.i~ settlement of this . . action: . ' -- 1. The Exxon Corporation shall pay to th& United States the sum of . . . $100,000 as a. civil penal.ty. . ' . · · . 2. (a) Application for ExPloratory Drilling Operations- . . (1) .Ex.xon Corporation shall 'apply..Tt'o the Environm~_ntal Protection . _ Agency for NationAl Pollutant Discharge Elimination System. permits for discharge . {nto. navigable"waters of t~e United States t80 days in advance of the proposed o · beginning date of any discharge from exploratory drilling operations unless . _ .'vermission.for a later application date has be~ granted by the 'Regional - .. . . · Administrator. This' stioulation of settlement, is applicable to &xplorator? - dri!iing operations co. nductea within the follo'~.~ing geographic parameters' . - .o - · 'On the-'east, on a line ~ltowin~.141°.l.°ngitude; on tire south, on a line · foklowing '69~ latitude; oh the west, on a 1.ine following 156° longitude; · · · bord'e~ed on-the north'by· the boundary.-line of the territorial .se'a, as defindd . in 33 u.S.C.A. § 1362 (8). . -' .. . '. (2) The NPDES applications shall cover all point 'source discharg · · · -of pollutants associated with the exploratory drilling operation. %'his shall include but not be limited 'to the following' a) Sanitary ~as res, .. o · b) Water Treatment plant wastes, ¢) Deck ahd/or pad drainage runof~ d) Process wasteWaters- R M P :_,-. STII",JI.ATIO:-i- Peer, 1 of 5 SE'P 7 1976 iufor.uation (such ~. draQings and ,,.-.l,s), si,ali, be ].uded.x-~ith ~.l~.e app].icc~tions · showing the p~_o,.~,osed location of all ~aste sources and tre[~[ment facilitics~-a description ~ t]'..e tO/pa-of treat~?.ent facilities, propOsed, .a descuiption of.the effluent char'ac.ter~.stics of each proposed discharge, and dra.~'in*, ancl/c~r maps. · sho~,ing the proposed location-of the point sources of discharges to navigable ~aters of the United States· (3} With the NPDES application for point source discharges of . - ' pollutants, Exxon shall' provide information on .drzll~ng rig effluents', · defined to include deck drainage, subsurface formation waters, drill~_ cuttings, . .and drill muds. This information sh~llinclude at least the following' . . - . . ~~ ~ 0 . . a) A description, including ~aps ar.d d · ~= f each - · of. the ~aste sources and the' proposed treatment:'and control meas6re-for each · .. . . Source. .' · b) A description of the proposed reserve pit, inclu'Jing .- - · . maps .and drawings,' construction methods and m~terials>' des. ign 'criteria f~r o . · . . · determining 'its capacity, and procedures for handling surface and infiltratior~ · ~aters (including sno~' and permafrost melt runof, f) in the drai?.age area of - the pit. - · · . c) A contingency plan for Controlling the unauthorized · . .. -discharge of drilling r. ig effluents .in the event of "kicks" or - "blowouts" of -. the uell. ' · . . · · (b) Drilling: '. . ... (1) . lhere shall be no dis.c.harg~. 'of po~!utants to the navigaBIe. \ uaters'of the United State~ fro{. the reserve pit excep~ 'as ~uthorized.by .- }~PDE$-p~rmit. An NPDES permit for ~;~,rface runoff: and/or iBfiltration ,~ate~'s - collected in the reser've pit ~ust have been ~pPlied for prior to any discha, rg.e$ _' · · .. to the navigable waters of the United States. {2) There shall be no discharge'o£ "dr£11ing rig effluentS". · · . . · containing free' oil to the reserve pit with the intent that such drilling r. ig. o · - effluents be discharged into the navigable waters of the-United States. Dr'i!ling : : - treated to ....... n ..... ~ary ~ . rig effluents shall- be contained, c'ontro~'~°~! 'and, '~F .... - prevent aay unautl~orized discharge of .pollutants, including free oil, into -- :' · 'nav~.gable waters of the. United States. .. · STIPULATION- Page 2 of 5 t~ use of a rese~~ ~it, shall bc ,.~-,.intained in ~ designated reserve capacity is ade~i'.~ately maintain~d. This can be _ a'c6omp!ishad.by E×xon by any of the following measur~-s~' · ~ a) Providing for evacuation of surface runoff and/or . · infiltration waters entering the resqrvc pit in accorda~,~ce with the NPbES permit. · b) . Providing a multicell 'pit or multiple re~erve pits . with sufficiefit reserve capacity' to store all. surface runoff and infiltratior~. · uate~' and raax£nu~ expected volumes of drilling muds witltou~ any unauthorized discharge of 5 pollutants to ~aters of the United States-- -' - . c) Spec. i~ically submitting information to EPA. on any. - . -. other mo~sureS the Company proposes to. Use to prevenf any unauthorized discharge. · 'of pollutants' fr.°~' the reserve.p{t to the navigable ~,~aters of the United States., (4) Ail discharges of pollutants to_navigable waters' of the . United States f'rom .explor.'atory drilling operations by Exxon .shall .- · compliance with the terms and conditions of the ~,FDE., permit issued for. that . particular'drill site. . -. (c) Notification and Reporting. - . (1)'' EXxon Jhall provide contemporaneously to EPA Copies of' -. mppiicatio~s for exploratory drilling permits submitted to any of the following: · . . Alaska' Departmen~ of Natural Resources,. United States Geological Survey, and any.. · . Alaska Native' Regional Corporation. Copies o'f applications· need not include ' confidential subs'urface information- For operations on which I~PDES. permits I~ave - . b~en-issued, monthl); reports in accordance ~-ith the terms and cond-.itiqns 'of the .. . 'issued I~DES permit shall be submitted to EPA. EPA shall be notified withi~ two · weeks after drilling, operations are completed. Any' proprietary .or confidential .- . . information furnished in 'compliance with this Stipulation' of Set..tlement ~ncI Orale w'ili be processed by EPA under its policy and regulations con'cerning matter ' _ Claimed to be confidential. . (.2) Exxon shall immediately .notify EPA by telephone at .- _ (206)4f, 2-1213 of the occhrrence of any unauthorized o~ unpermitted discharge ' or violations involving permitted disct~argc.s. Exxon shall provide EFA with · the following information in writing witl,in, five working days of such notification' Cause of noncompliance; .z STIPULATION - Pag'e 3 of 5 · ~.). A descrip.t[:}[~ o~ rl~e noncor:.. .ying cl:[scl~arg;~, itc im0act ,,.~on~,~_~n~ receiving waters,' &) Anticit~ated ti~.~e t]~e condition of noncompliance is · expected to continue~ or if such condition has bean corrected, [']~a duratior~ of th-e period of noncompliance; · discharge; and Steps taken to reduce and' eliminate the noncomplying · e) Steps to.be tauten to prevent recurrence of the condition of noncompliance.. · 'Nothing herein shall be construed as ti~iting tt?- rights of the federal gova. rnment or its agencies with respect, to any of its r. ights o'r remedies under . the Federa!'Wa~o~ Pollution· Control Act or this Stipulation of S~tle~en~~ and · · · Older ~o~- the violation of any federa'l la~,~, regulation, 'order, or NP~)ES permit, . or of' this Stip'u!~tion of Settlement and Order; provided, however, that neither . the fe~le, ral governmen~ nor its agencies s~.~al! put'sue' -an action -;n. Un±ted _ . States .District Court pursuant to 321 U.S.C.A.' § 1~I9 for a ¥io~ation o£ )3 "' U.S.C.A, [1311 si-mu!t, aneously with an action in United District Court for . . · contempt of this..S.tipulation of' S~ttlement and Order, when both actions ,- .. - are Based on the sam~-factual., conduct, act, or-omission.. 'In case of a . . dispu[e involving ghis paragraph, tine park±es agree that upon motion' the- . · . · ._-.-- court may resolve the than controversy. . -' . · 3. .This' stipulation of settlement shall be effective for five years - · commencing' from the date the order approving this stipula.tion of set. tlement, i~ .. · o · signed by the court. If' at any tim? any conflict~exists Bet~.:een this stiput~tior o[ settlement and ani; federal leu', regulation, order, or 1,I~DES permit, said - · /au, ~egulation~ order or permit must be complied, with. Any percy may. move o to 'amend this decree to make 5ts terms consistent, u~th said la.v,, regul~t:ion, order or-permit. DATED this · Alaska. day of , 1976 at Anchorage, STIPULATION- Page 4 of 5 ':'" --.-i . . - _ . ' E)glON-Corporation · :v' : .__.x.: ~ >/.::;M/'d."> ,'L_' Tit, Ie: /JOHN L. LOFTIS,~]'Ri · Senior Vice-~resid. ant O":' Exxon Comoan~, U.S.A. - (a division of Exxon Corporation) o. IT IS SO ORDERED, this o . . . · o .. ORDER 'Attorney for Defenda~/~ ' .. Attorney' for Defendant ~-~ o o , 1976--- . UNITED STATES DISTRICT JUDGE .o · '". STIPULATION- Page 5 of 5 _ j ~ ~ ~ in g civil action brought by the United States of America. . against-Exxon Corpok-ation alleging violations of the Federal Water · ~ ~ f 1972 This judgmcut remains Pollutzon Con_ro~ Act o period of five years from September 1, 1976~ and covers Ezxon's . - . - . ~~, drillinD ·operations conducted in the following geographical ~ ~he ~est~ on a line foilo~ing 141° longitude; on the South, on a line following 69° latitude; on the ~,lest, - o~ a line following 156° longitude; and bordered by the north boundary by the line of the territorial sea, as defined in 33 U.S.C.A. ~ 1362 (8). This area is further-delineated on the attached plat. !f the comp~}[~ fails to core.with the requirements of this judgnent, it could ~ecom~ sub. ct to severe civil and criminal penalties; - . and its employees and a~nts having responsibilit~for the operations eou%d be subjected to'fines and possible jail sentences. .-The requirements of thi___~s~__j_~_u~_~g!nent are divided into thr_e._e_ ~pDEs AppLiCATIONS, EXPLORATORY DRILLING OPEP=%TiONS, and NOTIFICATION 'AND REPORTING. " ~pDEs APPLICATIONS . 1. Exxon must apply to the appropriate regional administrator of . the Environmental Protection Agency (~PA) for national pollutant discharge · . . elimination system permits (NPDES Permits) for discharges of pollutan'ts into the navigable waters of the U. So1 180 days in advance of. the proposed disch'arge unless a la'ter application date has been granted by the regiona% administrator. . · 2. The application shall cover all point-source discharges of pollutants~2 including but not limited to sanitary waste, water treatment plant waste, deck and/bt pad drainage runoff waters, and process waste ~aters. -Navigable waters of the U. S. broad!¥ defined and includes tributaries · thereof; interstate waters; intrastate lakes, rivers, and .streams wNich are utilized by interstate travelers, for recreational or other pt:rposas, or which are utilized for ind~astrial purposes by industries in interstate commerce~ or . from which fish or shell fish are ta..e~n or sold in interstate commerce · 2pollutant broadly defined and includes d'~-edg'ed spoiI~ solid waste~ i tions chemical incinerator residue, sewerage garbage ~ewa~_e sludge, mun . ~.¥c materials~ heat, wastes, geological materials, radioac~' wrecked or discarded equipment, rock, sand, cellar dirt. and industrial wa.~te. 3. The application shall be on appropriate EFA forms (Short Form or ~,~her~ required, Long Form ), and shall include iofo.rmation (and drawings and maps) relating a. a description of the pOllutant, its effluent characteristics, and type of treatment facilities and control measures contemplated, b. "drilling rig effluents" (defined to include deck drainage', subsurface formation'waters, drill cuttings~ and drill mud) c. proposed locations of all point-source discharges into the navigable ~.~aters, and proposed locations of all treatment facilities and Control measures, d. a description of any proposed reserve pit, including the n~ethod · . · .~ and materials used in construction, design criteria for determinin.~_:its Capacity,. rand procedures for handling surface and infiltration waters (including sno~.; and perma frost melt runoff) in the draianage area of the pit, e. a contingency plan for controlling unauthorized discharges in thc event of "kicks" or "blowouts" of x.~ells · EXPLOP~iTORY DRILLING OPE?~TIONS 1. During the course of exploratory drilling~ oper. ations~ all discharges of pollutants to the navigable ~aters shall .be in compliance ~zith the terms and conditions of the NPDES Permit issued 'for ~hat particular drill site~ - . 2. ~?nenever exploratory drill.lng operations involve the use of a reserve pit, the Order prohibits: -. . a.. any discharge of pollutants from the reserve pit. into the nav. igable ~aters except as authorized hy an ~,rPDES pe. rmit. Additionally, a permit for surface runoff and/or infiltration. waters collected in the reserve pit must have been applied for prior to any discharges. b.~ any discharge of ':drilling rig effluents" containing free oil to the reserve pit with 'the intent tha°t such' effluents . be discharged into the navigable ~'aters. Drilling rig effluents must be contained, 'controlled, and if necessary, treate~ prevent any unauthorized discharge, including free oil, into the navfgable The reserve pit must be maintained in a manner such that its designated reserve capacity is adequately maintained. This can be. accomplished by.any of the following measures-: a. providing for evacuation'of surface runoff and/or infiltration waters entering the reserve pit in accordance with the NPDES . permit~ . b. providing a multicell pit,., multiple reserve pits ~ith sufficient reserve capacity to store all.surface runoff and infiltration waters and. maximum expected volumes of drilling muds.without any unauthorized diseharga~ c. specifically submitting information to the EPA on any other . measure Exxon proposes-to use to prevent a~y unauthorized - discharge from the reserve pit. _ NOTIFICATION ~Q~D FJEPORTING 1o 'Whenever. Exxon makes application for exploratory drilling _. permits ~to 'the S'tate~ IJSGS~ or any 'Alaska Native' Regional, it shall contemporaneously provide the EPA with a copy of such application. The application need n. ot include confidential subsurface information. 2. _~-Upon issuance of a permit, Exxon must submit to the EPA. mont.___~hly · .. ~s in accordance with the terms and conditions of' such e~_~t and . · . Exxon' must notify the EPA within two weeks after drilling operations-are completed. 3. Exxon must immediately notify the EPA by telephone at (206) ~42- 1213 6f the occurrence of any unauthorized or unpermitted discharge or violatidns involving permitted discharges and provide the EPA ~ith the follo~ng information in writing within five x~orking days of such notification: a. cause of noncompliance, b. a description of the noncomplymn~ discharge, including impact on receiving waters, -3- c. anticipated time the condition of noncompliance is ex?acted to continue, or if such condition has been correc~e duration of the period of noncompliance, . d. steps taken to reduce and eliminate the noncomplying discharge~ e, steps to bm taken to prevent reoccurrence of the conditio~ of - noncompliance° tt should be emphasized that this judgment does not 'e>[cuse Exxon . from otherwise complying with other applicable regulations and notificatior~ requirements ~ .. -4- ,,, ,,, ,., ; ,,, ..... ,· .... 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' : ~' / ,"~ L'.'~. :' .' ~ %. ," ' ' , ~" * , , '" ' - .' ,' '-'} - ~',;"~,"' H.'/ '.,, ~ '~' "" :' '"'" : ~ .... ,,,...... . .,. ~' . % . ,, · , . ,...:,..,. ,. . ~ ~.".'.'~ :-, ~ ..... ~.~ .... , .... . , . ... , ,.,: . . ... ;.,~ ,,.~ ,. .,~ ~ "~ ....':~. ~' ~... ~ ...... . ~ ............ { ~ .~, ,, , , , . ,,~ , M I ~' ~ ~ ~' '....'~. l.." ,.- ,' ' ~ , i " ~ ' , I , ~ - ,~', · , A , " '".'>* , 'i / ".. ~ .~'*' ,. - .... . , ~ , - ,,., . . ,, ,, ,' { ~ ' " ' , . . , .,t. . ,'- , ~; ...... , ,./, · t " ~ , ,', i ,~ .' I- q ~ .,-.~: ..,- ,, , - , , ,,.~ ,, , ..,~ ,...:,, 'F' '"-~ -~'' '.',~' ' :~.' ,"'.:. , ,, '..;.., . ~; ' c A ~ ,~ p, ,~' ~, · / ,~'2 ,~ ........... · ~ ~.~. ,. .... .. ' s z~, ~ ~'?~,~'~ ¥~ , :~;.::.~:~..:~..: .::.:./,.,..... ,~ .... ; .......................... ~"'/, "~ .... ~:.-;,~ ..~ ,,~ ~' "" " ~ ~?=.:U&L".~'L?~ ~. :...., ,'. ',, ') ..... . ,.~ ~ , ~ ....... ~ .... ~ ~ ~, , ~ ; ",=.. ,.,:.. ............. · ,.. ' '., _ ........... .= .............". ;~.,.' ~ ~ , ' ' X ; ~:~u~a '- .. , ~_ . ~..~" ..-,~ ., .'-::-:"..,' ' ', ~/, ~- I-?0 STATE Of'" ALASKA OIL AND GAS CONSERVATION COMMII-I'EE SUBMIT IN DUPLICA'I~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS API NUA. IERICA_L CODE 50-089-20003 LEASE DESIGNATION AND SERIAL N'O. ADL-47556 1. ? IF IAIDIART. AI-,OT"I-EE O~{ TRIBE BLAME o,L J-l °"' []] o,,,~,, Wildcat WKLL waLL 2. NAME OF OPIiiI:~TOI{ 8.L.~IT F.~,A{ OR LEASE NAME Exxon Corporation State of Alaska 3. ADDRESS OF OPERATOR 9 WELL NO P. O. Box 120, Denver, Colorado 80201 Exxon #1 Alaska State "A" 10 FI]FL,ID ,a_ND POOL. OR WILDCAT 4 LOCATION OF WELL 2,982' EWL & 1,542' NSL of Sec. 27, TlON, R24E, UPM North Slope, Alaska Wildcat il SEC, T.. R.. 1%f. (BO'I"I'OM HOLE O~-F, CrrV~ Sec. 27-T10N-R24E 1'~. PERMIT NO 74-14 L_ 13. REPORT TOTAL DI!iPTM AT END OF MONTH. CH,ANGES IN HOLE SIZE. CASING AND CEiViF. JqT!NG JOBS INCLUDING DEPTH SET AND VOLLrMES USED. P~ORATIONS. ~TS ~ ~SULTS FISHING JO~ JI~qK ~ HO~ AND SIDE-~ACKED HOLE ~ND ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS MONTHLY REPORTS FOR FEBRUARY, MARCH, APRIL & MAY, 1976 CONFIDENTIAL The report filed 2/6/75 indicated that the location was ready for inspection; however, a recent visit to the location indicates additional clean up will be required after the thaw. 5/16/76' 5/17/76' 5/19/76- Flew to Flaxman Island - State "A" location needed additional clean up. Obtained approval for open burning from ADEC. Flew clean-crew into location, collected and burned a large pile of wood and trash. Flew into location and carried out metal trash. The location will require additional clean up after-the spring thaw. A request for inspection and approval of cleanup will be made afterwards. "~NOTE --R~J~ is/~qulred for each calendar month~,~'egordless of the status of o~erations, and ' art on this form must ~ filed ~n duplicate with the ffl and gas conservation commlffee bx the 15~ of the $uoc~dlng month, unle~ otherwisa ~irected. !2/12/75 ~t'~?r~'--checkis.~ ic~ thickness for rig m~ve, Actiwt~ ~ for rig ~ve. 12/29175 · ~.~.~~r sta~t~ opeming road on th~ ic~_ to Fl~_~an Island~ 1/22/76 ~i~d m~w~out of rig and camp, January 6, 1976 Ex~nn ~, U.S~ P.O. Box 440 Anc~~, Alaska 99510 LO~ 74-9 ALaska Stat~ "A" ADL-47556 Attend: Bobert K. Riddle The a~c/.vities, outl/ne~ in your le~ of December 31, 1975, are ~_r~ ~. all operatin~ areas ~t De .main~ and left to '~%e satis~ach%on of the director. bec: NC District, Copeland F&G, Grur~y D~C, Lowery Labor, Leland Div. O&G D COM, ANY, U.S.A. POST OFFICE BOX 440 · ANCHORAGE, ALASKA 99510 EXPLORATION D .F. PAR'r N*,ENT December 31, 1975 Re' A.D.L. 47556 Exxon #1 Alaska State "A" Mr. Pedro Denton Chief of Minerals Division of Lands Department of Natural Resources 323 East 4th Avenue Anchorage, Alaska 99501 Dear Mr. Denton' In our letters to you of October 16 and December 10, 1975 we have described the termination of Exxon's plan of operation for the subject well being the move- ment over a Beaufort Sea ice route of Nabors Alaska Drilling Inc. Rig.#9 and all camp equipment and other materials incidental thereto, from the subject lease to the Arco-Exxon Prudhoe Dock and thence by existing road to Nabors Prudhoe WarehOuse and yard. We wish by this letter to confirm a discuSsiOn with you of this date concerning a change in such demobilization plans insofar as they concern the said Nabors Alaska equipment and materials. As a result of an agreement recently executed by BP Alaska, Inc. with Nabors Alaska Drilling, Inc., providing for the employment of said Rig #9 in the drilling of BP Alaska's "Sag-Delta" drilling operation on BP Alaska's lease ADL 28337 (1000' S. and 749'E from N.W. CDr., Sec. 4 T. llN. R. 16E. U.P.M.), the said rig and all materials pertaining thereto will not be returned via the Arco-Exxon Prudhoe Dock to Nabors warehouse and yard, but will leave the Beaufort Sea ice route at a point in the vicinity of said BP Alaska lease ADL 28337 and move by the most convenient route to the surface location of BP Alaska drilling operation. Should there by any questions or additional information required relative to this request, please do not hesitate to call the undersigned. Robert K. Riddle RKR:js cc: Messrs. Herman Schmidt, BP Alaska G. D. Thompson L. A. Dodd G. B. Hi ckok A DIVISION OF EXXON CORPORATION ~-~ ~~~ ............ · ............. '~ .... ,.~'F · ~'~.: ~ ~ ~ ~ ........ 74-14 9/25./75- 9/28/75 ~~i=i-~-~-~n-:,p-its as advised by copy of toca. tioa .status letter dated Octo~r' t975. Installed f~nce around reserve pit. 9/28175- 9130/75 Fin-'~-S~hed'":'Cieani~g e~round location. Deactivated sewer plant and fresh ~aterg~er~ unit. )~0v,~j all personnel except ~tch crew off location aP~l went to suspended operai;ion. ' Location statos and plan as advised in location status ',:~'~:~ter dated ~ber 16~ 1975. I0ii/75- 10t9/75 imstJti~--S-~'5'r~ty alarm system in c~mp a~.d location and tested $~ame. Sys~em completely operable.' Met with Alaska' Sta'b~ Troopers Steuart and Nickel amd reviewed syst~ and proc~du,re$.. Th.~ will be final ~e~o'rt until remo.bilization for rig ~ve in Feb~ary o'.r ~h, 1~76, You ~'ilt ~ advis~ of. any pt,n ~g.es s~uld the~ ~cur, To WESTERN EXPLORATION DIVISION EXXON COMPANY, U.S.A. TRANSMITTAL FORM Alaska Oil & Gas Conservation Commission Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 From Gene D. Thompson Well Exxon #1 Alaska State "A" Date 10-17-75 Transmitted herewith are the following for the subject well: quantity Item Interval Remarks 2-2", 2-5" Dual Induction Log Induction Electric Log Sonic Log w/S.P. 2-2'"~ 2-5" Sonic Log w/G.R. 2-5" Formation Density Log w/G.R. Sidewal 1 Neutron 2-5" Neutron Density Continuous Dipmeter Continuous Dipmeter, Computed Continuous Dipmeter Printout Proximi ty-Mi cro 1 og Perforating Depth Control Cement Bond Log Cased Hole Neutron Temperature Log Synergetic Logs 2 Mud 1 og s Sidewal 1 Cores Sidewall Core Description Sidewall Core Analysis ~Conventional Cores Core Description Core Anal ys i s Unwashed Cutti.ngs 1 Set Washed & Dried Samples Sample Description Canned Cuttings Drill Stem Test 826-14,201 ' 824-14~201' 3,375-141,204' ..3,.375-14,204' 1 Blueline, 1 Sepia 94-14,206' 1 Blueline~ 1 Sepia 1 Bluelinel, 1 .Sepia 1 Set Core Chips '2 Copi.es Form P-7~ Well Completion or Recomp16tion Report and Log Receipt Acknowl edged ~/~(~~_~/~~.,. ,1jiBlueline, 1 Sepia 1 .Bluel Ln.e., 1 .Sepia Date Return signed receipt to: Exxon Company, U.S.A. P. O. Box 120 Denver, Colorado 80201 Attention: Mr. John R. Switzer OOT :2 1 1975 E (ON COMPANY{ U.S.A. POST OFFICE BOX 120 · DENVER, COLORADO 80201 E x P LO R,,'~,] WESTERN DIVISION October 17, 1975 Mr. O. K. Gilbreth Alaska Oil & Gas Conservation Committee Division of Oil and Gas Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir' We are attaching two copies of Form P-7, Well 'Completion or Recompletion RePort and Log, covering the suspension of our #1 Alaska .State "A" well, Also attached are copies of well logs, mud logs, cuttings, and core chips. Please note that all material is marked "Confi~dential," We request that this material not be released for two years as pr~ided by regulation, Very~_ true, ours, ~// ' ~' ~ j~..,~"' Gene D. Thompson WAG'mg Attachments A DIVISION OF EXXON CORPORATION WELL COMPLETION OR RECOMPLEi'ION RLr'ORT ~'~:':i'~O~G* pe ' · la. TYPE L;F %'ELL: ' ":i.,~'?:- [--]--~'~ - [_~ DR* [_J Other SuS nded WELL ~ WELL b. TYPE OF COMPLETION: WELL OVER lin BACK EE~VR. Other 7. NAME OF OPI'RATOR Exxon Corporation reverse 3. ADDRESS OF OPERATOR P. 0. Box 120, DenYer, Colorado APl NtINtEJUCAL CODw- 50-089-20003 ADL-47556 7. IF iNDIaN, ~~ OR TRIBE 8. UNIT,F~ OR ~SE NA~IE State of Alaska . ., . 80201 ,o. Fm~ ~D ~OO~.. O~ LOCATION OF WELL (Report location clearl~l and in accordance with any ~tate requirementa)* ' ! I ,,,,~a~e ?_982 EWL & 1542 NSL Of' Sec. 27-T10N,R24E, UPM, North Slope, Alaska At top prod. interval reported below At total depth As Above 9. WELL NO. Exxon #1 Alaska State "A" Wi 1 dcat SEC., T., R., M., (BOXI'OM HOLE OBJECTIVE) Sec. 27-110N-R24E UPM Pre-Miss 12. PEP~IT NO. 74-14 13. D~.TE SPUIJDED [14; DATE T.D.' ~ClrLED [15. DATE CO.M_P SUSP OR A~klNr]~. 116. I~-LgVATIONS (DF, RKB, P~T, 3-23-75 [ 9-6-75 IPlugged & Suspended I 41' KB : 19-21-.75 . ~ . 18. TOT~L D~-~H, I~D & TVD l'. PLUG, I~LA-CK MD & TVD r. I-~ IVk'ULTIPLE C01VLPI'., [21. 14,206' MD Surface ~ow~. ,o:,,, ~oo~ , ! GR, ~l'C)' ~17. l~r.F~r. CASIAIGPIEAD i ---- .. , INTERVALS DRILLED BY A11 I ~,'~L~ ~OOL~ %VAS ~:' SURVEY ~ADE Ro 22. PRODUCING IXT~RVAL(S), OF THIS CC, MPLETIOI~I--TO1P, BOTTOM, NA.1ViE (lVI'D AND TVD)* 0 . .. , 24. TYPE ELECTRIC A_N'D OTI-il5~ LOGS. RUN · , Dual Induction, Sonic, Sonic Amplitude, Density, Compensated Neutron, Dipmeter, Velocity - 25. ' .... . --- C~SLNG I~OOR~) (Report ali strings set i~ CAS~G SIZE [ WEIGh[ :rFT, ~ -GRADE J DEP: SET (D) i HOLE S~Ej C:%ILNTING RECOD ~ ~MOUNT PULLD ~ ..... [ 94. IH-40 j '82~' ...... 2'6" ..... {2400 sx p6rmafrost NOne. 13-3/8". ~[ '7~' ~ ! ~ [N"~0 II 3,37~~,.,,," [ ' ~ 17'' "~3350sx Class G sx Perm'a~r°st' 250 '9_5'/8h 43 ~ '4'7 I""s-95~ '1'1,07g '"' 12~" 2250 sx Class ~ "~o~'e i i~ i i iiii iiii iII i llll ii ' ii ii i i i i ii i i 'L i ii ~. ~.:~ ~co~ P-] t 0 I ~. ~u~ ' 7""' 10,776' 1'2,~97' ~1450 C1 ~ 12,565' to 12,610' and 12,620' to 12,635' 2 shots/ft, approXimately 7/16" ID .sc: <=D, I s:z . [ DEPTH SET <IVID) I PACt{.ER SET (MD) ACID. SiIOT, FR.AC'~IU~E. C~IENT SQUEEZE, C. D~llI IMT~V~ (MD) [ AMOUNi' ;~ND KiND OF ~A5'E?S~ Same I 1200 qal. of 75g HC1, 9000 [gal. of 7%% HCl + 1%% HF and 9,000 gal. of diesel with .... 10% MUSOL A ~ iiiii 'i i i ~ i i j i ii111 i Ill nell II II III I lira ~O. I~RODUcTIOIg DATE FIRST PI%eDUCTION [ ~ODUCTION MEIHOD (Flowh~g, gas lift, pump~g--size and type of pump) WELL STA'~US (Produc~ or ~nut-in) ~{OXE SIZE IPgOD'N FOR OIbBBL. G~CF. WA~B~. GA~-O[L 1 _ '~,DISPOSITION 0F ]TEST WITNESSED BI I Core dat~/ . // - : (~ /' / i ...... ~visZ°n PriDJp!.Mgr. DATE 10-17-75 *(see Instructions and Spaces for Additional Data on Rev,~erse Side) / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- mentsgiven in ether spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate praduction from more than one inlerval zone (multiple completion), so state in item 20, and in item 22 show the p~c-Jucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional ,nlm vel to be separately, produce'J, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for leis well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). ~T~'I'S IN('LUI)IN(; INTERVAL TV~'FED. PI{V~'~SURI~ DATA Algv'D fL,~.OV~RIF-~ OF OIL. GAS, WA'I~r~ AND MUD DST #1, 12,997' to 13,182' (open hole). BH Pressure 10,140 psi and recovered 85 bbls. salt water (40,500 ppm C1). DST #2, 12,565' to 12,610' and 12,620' to 12,675' (Perforations)- BH pressure of 9,850 psi and recovered 1,586 barrels of 23.1°API gravity oil and 1,390 MCF of gas. ~ ~i. COLOR DATA. A3q'ACit flRIIC~ DgSCI~IPITIONS O? LITIIOLO~¥, POI1ORITY. ~RAt--rUIt]~S. APPARgNT DIPS --lit I · · i Il Il II _ See attachment 19g'i"ZCq'lgl} ~IRr}w~ Or OIL, GA~ Oft ! 35. Tertiary Eocene Lower Cretaceous Pre-Mi ss. GEOLOGIC MARK~ MEA$ Surface 11,040' 12,836' 12,924' EE ON COMPANY, U.S.A. POST OFFIOE BOX 2180-HOUSTON. TEXAS 77001 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION CRANDALL D. JONES MANAGER October 25, 1977 Request for Minimum Royalty Status ADL-47556 Mr. Joseph Green Director, Division of Minerals and Energy Management Department of Natural Resources State of Alaska 323 East 4th Avenue Anchorage, Alaska 99501 Dear Mr. Green The Exxon No. 1 Alaska State "A" Well located on lands covered by State ~f Alaska Oil and Gas Lease ADL-47556 has been completed and is capable of producing hydro- carbons in paying quantities. Attached for your infor' mation is a table showing testing results. The potential test of September 14, 1975, was witnessed by a representative of the State Division of 'Oil and Gas (now Division of Oil and Gas Conservation). In accordance with the lease provisions, it is requested that the lease be placed on minimum royalty status. It will be appreciated if you will furnish us with a Decision Letter to that effect. Yours very truly, Attachment cc' Mr. O. K. Gilbreth, Director State of Alaska Division of Oil and Gas Conservation Test Number Date Type Test Interval Cushion Test Period S.I. Period Recovery Flowing Tubing Pres. Surface Choke Tubing Size BH-Gauge I .H.M.P. F.I.F. F.F.F. F.C.I. S.I.F. S.F.F. S.C.t. F .H.M.P. . E~t. B.H.P. ., TESTING DATA ' Exxon t;1 Alaska State "A" Sec. 27, TION, R24E, UPM North Slope, Alaska 8- 2{)-75 O1)c~ lloJe I).S.T. 12,997'-13,182' 8000' water 18 minutes 2 hrs. 45 minutes 8000' water cushion and 85 barrels of salt water (40,500 ppm. C1) Closed chamber blank 2 7/8" 12,985' 10,363 psi 9,720 psi 9,527 psi 10,1!1 psi .. 10,359 psi 10,140 psi ' 9-11 5 D.S.T. thru Perf. 12,565'-12,610' 1 6 1 1 6 b and ~ 8 600 ps 1/2" 2 7/8" 12,532 10,410 4,395 5,887 9,791 6,661 5,173 9,779 10,199 9,850 2,620'-12,635' 000 ' water hours and 17 minutes hours 000' water cushion, 411 a. rrels oil 22.8° gray. API 4 MCFG GOR 934:1 i psi psi psi psi psi psi psi psi psi 9.-14-75 Potential thru Perf. 12,565'-12,610' 12,620'-12,63.5' 12,565' Diesel 11 hrs. and 15 minutes 12,5 of o 1,01 1500 15/3 2 7/ None None None None None None None None None 9,850 psi 65' diesel, 1175 bbls il 23.1° gray. A~-' a~ S MCFG. GOR: 864._. psi E ()N COMPANY. U.S.A. POST OFFICE BOX 2180. HOUSTON, TEXAS 77001 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION October 10, 1977 Re' Testing Exxon #1 Alaska State "A" North Slope, Alaska " 12: .'-', ', : Mr. R. K. Riddle Pouch 6601 Anchorage, Alaska Attached is the testing information on the Exxon No. 1 Alaska State "A" as requested by Mr. O. K. Gilbreth. G. B. Hickok GBH'mg Attachment A DIVISION OF EXXON CORPORATION TESTING DATA Exxon #1 Alaska State "A" Sec. 27, T10N, R24E, UPM North Slope, Alaska Test Number Date Type Test Interval #1 8-20-75 Open Hole D.S.T. 12,997'-13,182' Cushion 8000' water Test Period 18 minutes S.I. Period 2 hrs. 45 minutes Recovery 8000' water cUshion and 85 barrels of salt #2 9-11-75 D.S.T. thru Perf. 12,565'-12,610' 12,620'-12,635' 6,000' water 10 hours and 17 minutes 14 hours #3 9-14-75 Potential thru Perf. 12,565'-12,610' 12,620'-12,635' 12,565' Diesel 11 hrs. and 15 minutes 6000' water cushion, 411 12,565' diesel, 1175 b~, barrels oil 22.8°grav. AP1 of oil 23.1° gray. AP1. and water (40,500 ppm. C1) and 384 MCFG GOR 934:1 1,015 MCFG. GOR: 864:1. Flowing Tubing Pres. Closed chamber 600 psi 1500 psi Surface Choke blank 1/2" 15/32" Tubing Size 2 7/8" 2 7/8" 2 7/8" BH-Gauge 12,985' ,~/~12,532' None I.H.M.P. 10,363 psi 10,410 psi None FiI.F. 9,720 psi 4,395 psi None F.F.F. 9,527 psi 5,887 psi None F.C.I. 10,111 psi 9,791 psi None S.I.F. 6,661 psi None S.F.F. 5,173 psi None S.C.I. 9,779 psi None F.H.M.P. 10,359 psi 10,199 psi None Est. B.H.P. ~10,140 psi 9,850 psi 9,850 psi NOTE' D.S.T. #2 shown on P-7 form reported cumulative oil produced (1,586 barrels) for both 9-11 and 9-14 1975 tests. GBH' mg ~ ?~?~ 10 - 10 - 7 7 :~-- = --~ ~'~'~ Dr. O. E. Gene Dickason U. S. Environmental Protection Agency Room G-66, 650 W. 4th Avenue Anchorage,. Alaska 99501 October 17, 1975 Dear Dr. Dickason' Re- Flaxman Island, Alaska, Drilling. Site Exxon would like to clarify its reasons for filing Sections I, II, and III, Form C, NPDES application dated July 23, 1975, for its Flaxman Island facility. As you recall, when you and Mr. Ray Morris contacted our Denver office on July 16, 1975, Exxon reported that it had pumped approximately 12,960 barrels of water from its reserve pit at the Flaxman Island drillsite to the Beaufort Sea. You were advised that: 1. Exxon was experiencing a large influx of runoff water into the reserve pit and the influx had raised the water level to such a height that the reserve pit could not be used as a first line of defense in the event of a major well control problem. 2. The water discharged was primarily a mixture of runoff water with some drilling fluid effluent water. 3. Exxon's disposal plans were to inject the excess water into a casing-casing annulus but that the inner casing string had not yet been set. 4. Exxon would notify your office prior to any subsequent discharge, should the need arise prior to setting .the casing which would allow injection. Mr. Morris advised that Exxon should, as a gesture of good faith, file an application for a permit to discharge water from the reserve pit even though drilling operations would probably terminate before EPA approval was granted, since 120 days or more is generally required. Exxon complied, although it did not then nor does it now appear that a permit was required. OCT 2 ! I975 Dr. O. E. Gene Oickason Page 2 October 17, 1975 As you will 'note, an abatement application (Section III, Form C, NPDES) was filed with Sections I and II, and stated how future reserve pit discharges would be eliminated, including a time schedule. Pumping of the discharge terminated July 7, 1975. The plan was approved by the Alaska State Division of Oil and Gas on August 7, 1975 and implemented following such approval. Drilling operations were terminated September 21, 1975. Accordingly, Exxon f, ormall,~/ withdraws S~c~ions I. II. and III~ Form 3. N~DFS Applicatio~ for Permi~to Discharge Wastewater dated 'July 2J, 1975 for the Exxon #l Alaska State "A" drilling site. Very truly yours, Robert K. Riddle RKR:jh cc: U.S. EPA, Region X Attn: Mr. Michael Garcia Dr. Ernst W. Mueller Mr. O. K. Gilbreth Mr. John Janssen I:: ON COMPANY. U. S.A. POST OFFICE BOX 120 - DENVER, COLORADO 80201 EXPLORATION WESTERN DIVISION ! ,;";LL:;JC~ October 16, 1975 Mr. Pedro Denton Chief, Minerals Section Alaska Department of Natural Resources Division of Lands 323 East Fourth Avenue Anohorage, Alaska 99501 Dear Mr. Denton' Re: Location Status ADL 47556 Exxon #1 Alaska'State "A" Operations at the referenced drillsite location were suspended with all rig crews moving out September 30, 1975. A two-man watch crew will remain on location through the 1975-76 winter to monitor any activities'which may occur, Authorized activities at the site during the winter include cooking and living for.the watch crew, daily communication from location to Exxon's Prudhoe Bay facility, and weekly surveillance flights to the island. A joint meeting was held on. October 8, 1975, with Alaska State Troopers to initiate and agree on the surveillance program during this suspended period until the rig and equipment can be moved off over the ocean ice in 1976. _Operational Equipment The rig and 50-man camp at location were left intact but demobili.zed. ' for winter. Electricity generation equipment, consisting of one gene~a:.tor', packa'ge,''': ''''':'::''':~:'' which has two - 200 KW generators, was left operational to provide for operating four camp buildings, mechanical shop, rig lights, runway lights, and observation tower. Fuel and Water Approximately 30,000 gallons total of diesel fuel are stored in two steel fuel tanks in the fuel storage area and the ~ig day tank. This fuel is used to power the generator and will. be necessary W. hen the drilling contractor remobilizes to finish tearing down and nioving Out Fresh water is stored in the water purifying tank in the Met-Pro' unit'for"use by the watch crew. ' ' , . OCT ii 1 197,5, ' A DIVISION OF EXXON CORPORATION Mr. Pedro Denton Page 2 October 16, 1975 Sewage Disposal All garbage will be burned in the incinerator with the ashes collected and stored in steel drums for later disposal. Human waste will be processed through an Incinolet Model TRM-IV electric toilet. The waste is collected in a plastic bag, incinerated to an ash or residue within the unit, and collected in a pan below the processing unit. This ash will be emptied along with kitchen garbage and burned through an incinerator. Any remaining ash in the incinerator is handled as outlined above. Kitchen and shower water will be piped directly to a nearby small sump with no intermediate processing. Location Cleanup Status The two small burn pits on location have been backfilled~and mounded with gravel. The reserve pit was pumped to as low a level as possible and left open. A barbed wire fence was constructed around the open reserve pit to protect stray caribou. No trespassing signs have been erected at four places around the location. The attached photographs were taken in early September, 1975 (Photograph #1)~and February, 1975 (Photograph #2). Photograph #1 shows the location prior to demobilizing the facility. The two burn pits circled in the upper right have been backfilled.' The orange tanks in the center have been moved from where they are shown in the picture to the graveled area as depicted by the arrow. Photograph #2 shows the location during active winter operations. RS: mg Attachments cc: O. K. Gilbreth, Alaska Div. of Oil & Gas R. K. Riddle H. Po Bushnell You will be kept advised of any location status change. -- ..Gene~)._~ Thompson ~ CORE DATA Core #1 10,213-i0,273'. Rec. 60' shale and siltstone. No shows. Core #2 10,645-10,671'. Rec. 26' siltstone with thin shale partings and thin laminae of sandstone, vfg, siliceous, no porosity. No shows. Dip 5o. Core #3 10,701-10,761'. Rec. 60' siltstone with thin shale partings and thin laminae of sandstone, vfg, siliceous, no porosity. No shows. Dip 70. Core #4 12,427-12,463'. Rec. 22.5' shale with thin interbeds of sandstone, vf-fg, poor porosity with oil staining; 13.5' sandstone, vf-fg, fair porosity with oil staining. Horizontal dip. Core #5 12,468-12,557'. Rec. 10' sandstone, vf-fg, fair porosity with oil staining; 29' shale with thin laminae of siltstone; 9.5' sand- stone, vf-fg, fair porosity with oil staining, with thin interbeds of shale and siltstone; 9' shale with thin interbeds of sandstone; 28' sandstone, vf-fg, poor to fair porosity with oil staining, interbeds of shale and siltstone; 3.5' shale with interbedded siltstone. Core #6 12,557-12,647'. Rec. 17 shale with interbeds of sandstone, vf-fg, poor to fair porosity with oil staining; 73' sandstone with inter- bedded shale and siltstone, sandstone is fg, poor to fair porosity with oil staining. Dip 3-~4o.. Core #7 12,647-12,737!. Rec. 2' sandstone, fg, fair porosity with oil staining; 88' shale with thin laminae of siltstone. Dip horizontal. Core #8 12,737-12,747'. Rec.. 6' Shale. Core #9 12,747-12,757'. Rec. 9' shale. Core #10 12,946-12,951'. Rec. 4' quartzite, f-rog, fractured, bleeding oil and water, poor pinpoint porosity. Core #11 13,019-13,030'. Rec. 3' dolomite, f-xlyn, fractured, poor porosity, oil staining. Core #12 13,228-13,237'. Rec. 9' shale with thin interbeds of siltstone and quartzite, vfg, fractured, bleeding oil. Dip 0-5o. Core #13 13,948-13,970'. Rec. 22' shale with thin laminae of sandstone, vfg, no porosity, no shows. Dip 2-8o. Core #14 14,175-14,206' Rec. 31' shale with thin interbeds of siltstone, no shows. Dip'5-15o OCT 2 ! 1@75 ] E) ON COMPANY, U.S.A. POST OFFICE BOX 120 · DENVER, COLORADO 80201 EXPLORATION WESTERN DIVISION GENE D DRILLING MANAGER October 16, 1975 Mr. Dale Wal 1 i ngton State of Alaska Department of Environmental Conservation Pouch 0 Juneau, Alaska 99801 Dear Mr. Wallington' Re: Exxon #1 Alaska State "A" ADL 47556 Suspended Operations Sanitar~, Facilities As per telephone conversation between you and Exxon's R. K. Riddle on October 13, 1975, during which you verballY approved our plan for water, garbage, and waste disposal at the subject location, t'he following information is submitted. Operations were suspended at the subject location September 30, 1975. During the time from September 30, 1975, through February or March, 1976, a two-man watch crew will remain on location. Waste disposal facilities for these two men include- .. lo An' Incinolet Model TRM-IV electric toilet for both liquid and solid waste. 2. One of the large incinerators for the 50-man camp was .left operational. 3. Piping for kitchen water and shower water goes directly to..a.small sump adjacent to the quarters. 4.. The Met-Pro unit for the 50-man camp was deactivated, .~...~.winterized, and will not be used while only the watchmen ..are on location. a DIVISION OF EXXON CORPORATION 5..~Potable water was stored in steel tanks on location ..:prior to suspending operations. ~ ~~ ~L~ OCT 11975 · D "' ,£ Mr. Dale Wal lington Rage 2 October 16, 1975 All human body waste will be processed through the Incinolet unit which electrically incinerates it to an ash or residue which is collected in a pan below the unit. This residue is then incinerated again through the large incinerator. All kitchen garbage and trash will be processed through the large incinerator. Any ash remaining in the incinerator will be collected and stored in metal drums for later disposal. Thank you for your consideration in this matter. You will be advised of any changes in the outlined plan. Very t~fy y lhompson cc: ~r. O. K. Gilbreth Alaska Div. of 0il & ~as ~r. R. K. Riddle O~L AND GA~ CONSL~VATION ...... : ~.:, , .. ~ ~. . ~ ,~_ :-~_ . ~xon ~r~ration P. O. ~x 1~0, Denver, ~lo. ~ZOl ~~ '' ..... ~ ........ 298~~ EWL & 1542' ltSL of ~. 27-110N-R24E U~ ~rth Slope, Alaska _~LY REPORT OF OPERATIONS FOR SEPTE)4BER 1975 Drilled 5-7/8" ~le to')3,948~. ~t ~re #I3 f~ 13,948-13,g70'. ~t 22' . , rec 22 OJt 3t' · ,rec, 31' 9/6/75- 9/8/75 ~~i--OgS. ~n DIL, ~nic, F~-CNL, and Di~ter~ in 7" liner. ~ pre, ring ~ squeeze c~t ~l~ liner. Set c~t re~iner a.t t2,900~ 'Squeezed 100 sacks Class G 2600 psi... c~nt bel~ ¢~nt retai~r at 12,900'. Changed to g-7/8" r~s. and ~st~ BOP s~ck and c~ke mnifold ~ 300 psi and ~ psi. _ Perforat~ ~r ~ll.~re sket~ of 9/4/75. ~n OST ~g. ~lete test d.a~ will ~ fu~ish~ aith Fo~ ~idiz~ ~r-su~ry ~tice dat~ g/g4/75, a~ ran ~tl Test ~3. ~ss ~uglas of the ' Division of Of) and ~s ~s fu~is~ test da~ ~ wtt~ss~ t~ test. Test data to . ~ furni sh~ on Fo~ P~?. Y · , CONFiDE 'JTiAL : EXXOI~ ~l ALASKA STATE PAGE ~ ljjjl~]e/zs- 9/2~/7s · J~lugged and S~sPer~ted ~elt .per Sundry Notice dated 9/Z4/75. midnight 9/21/75. Released rig at ~bors rig crew finished deactiviting rig. Rig was left complete)y rigged up. 9./25/75 Cid~r~ihg-~'-~'"~-mUnd location. Backfilling burn pits. SPEC[AL ITI~ Du~ng the pe---"~--'~~rtod .from g/l/75 to 9/15/75, pumped an estimated total of 17,466 barrels of reserve pit water into the 9-5/8 x 13-3/8" annulus. SLaY OF OP[N BU~I~ 812.3/75 8/Z8/75 g/3/75 9/19/?t g/~0/75 9/Zt/75 ~/25/75 Wind Speed And Direction . ~5 Bbl s ~ Oil l 0 Knots, i( 25 Bbls,. Oil 10 Kl~Ot~, W I5 8b15. Oil l~ Knots, J4E 25 Bbls. Oil lO K~ot$, W lO Bbls. Oil, Gas Flare IO Knots, SW 5 Bbls. Oil, Gas Flare 10 Knots, NE 4,5 Sbls. Oil 14 Knots, SW 60 Bbl s. Oil t 2 Knots, SW 80 Bbls. Oil 16 Knots, SW SO Bbls. Oil. 14 Knots, NE t O0 Bbls. Oil ' 18 Knots, SW 30"Bbls. Oil 18 Y~ots, SW ~is s~Y' has been sent to ~r. E~nst Krueger of the Alask~ State Department Environmanta) Conservation per Condition 2 of AQC-370A Penait t~ Open Burn. · ~, ,'~ ~ E OF AL.ASK-A ©t L AND GA4i O0~$ERYATION t:;O)~.TTE'~ ~JNDRY NOTICES AND REPORTS ON WELLS 14, .. State of Alaska Exxon ,¢I Alaska State ~ildcat ~, T,, ~., ~,, (~O~ Sec. 27-Ti ON-R24E SUBSEQU~T REPOT 0[ ~ELL ~SPE~IO~ 9/g/ 5: ~t c~t re~iner a:t 1~,~3' and s. eJeeze cme:nt:~ 7'. casing with lDO sacks Class G + 0~4% ~R~7 + 0. t% ¢F~-2~ 9/t6/75: Spott~ 50 sacks class' G + 0,3% HR-7 + 1.0% CFR-2 fr~ 12,,700' , ~ , 12,4,50 9/I8/75; Spotted 60 sacks Class G + 0,2% HR-7 + l~O') CFR,,,.2 across liner top f~ 10,876' to 10,465'. Tagged top of c~t at )0~465~ with wi. reline.. 6~ 9/t8/75: Set wire. line bridge plug in,9-5/8" casing at 10,460', Tested casing to 300D psi for 30 minutes. 9118/75: P~ped p~d:uced oil. into 9-5/8" x 13--3/8" annulus and 'foll~d ~.ith 300 barrels of Oil Base, ~nc., arctic casing pack. 9/!8/75: Differentially tested wireline bridge plug to 1~50 psi for 30 ~o flo~ back. - Sundry Notice and Reports -~xon ~l Alaska Stat~ Subsequent Report of Well Suspension and acidiztng Page 2 7. 9/18/7.5: Squeezed g,5/8" x 13-3/8" annulus with 300 sacks pe~.rmafrost cement through F.C). tool at lgg6'. ~qaxi~m pressure 1000 psi, mini~ 900 psi. ~.nulus pressure was 25 psi throughout job. Closed F.O~ tool and tested casing to 3000 psi. . . 8. g/ZO/75: Spotted cement plug in 9-5/8" casing from 3400' to 3ZOO' using 75 s.ac~ permafrost cement. 9/20/75: Displaced mud (n 9-5/8" casing with diesel oil frc~ lO. 9/21/75: Spotted cement plug in top Z5~ of g-5/8" casing using IO s~cks permafrost cement. g/21/75: ~em°ved BO~'s and installed wellhead cap and ~ei) marker. Released rig. g-~4~75:. Performed acid jobon perforated interval f~ I~,566~ to 12,610' a.nd '1Z,620~ to lg',635~' as follows: Puaq~ l'gO0 gallons'of 7~J(~. ~t followed by 9000 gal)ohs by 9000 gallons of diesel oil ~ith )0~ by volume ~SOL. A. Initial. injection ~as 7200 psi and average injection rate was 2~3 BP~ at ~ psi, M EMORANDU'M DEPARTMENT OF NATURAL RESOURCES TO: 0:o K. Gtlbretb, Director THRU: Hoyl · H. Hamt 1 ton Chief Petroleum Engineer FROM' Russell A. Douglass Petroleum Engineer (on contract} State of Alaska DATE: September 18, 1975 FILE NO: TELEPHONE NO: SUBJECT:Field Trip to Flaxman Island, Alaska State No. A-1 Well Site Thursday September 11, 1975 - I' traveled to Flaxman island to observe Operations on' ~e-AlaSkal State No. A-1 Well. I left Anchorage at 10:30 AM and arrived at Prudhoe Bay at l:lO I met Gene Thompson of Exxon at the Arco hangar and we discussed current operations. I fl.ew to the well site on charter, aircraft arriving at 6:30 PM. ! had dinner with Buck Irwi'nEand Bill Grieves (both of Exxon). I told them my purpose was to witness well operations for the next few days. From September 12 to SePtember 14, I observed operations on the Flaxman island location. 'I also .reviewed procedures and Alaska regulations with various Exxon reprelsentattves during ~y trip. I departed the location on MOnday morning September' 15, 1975. Confidential information observed during the trip 'i.s in the' Alaska State No. A-1 well file. in s~ry,, I witnessed well site .operations on Alaska State No.. A-1 from September' ll to September 15 (AM), 1.975 PAD ':'be (~)R63072 ~, plugs through Pi~g ~3 set per t;~ attached . Pun wirelfne gauge ring a~ junk ~sket a~ i~.g Up of plug ¢3' ~1D,dDD' '~ . , . B-33 (~c+~ricide)~ PJit out )~i~ d~. ~ile ?umi'ng ~bing,. dis~s~ ~f all ~zcept 3~ ~~lm o~. oil in s~a~.~n~ ~n~lus. .. m m ......... .. ~.= ~ix {a~t 3~ ~~ls of oil ln~ Oil ~s~, Inc., ~ing . .. . i'n. ~lm ~ 35~'. Se~ ~ a~U O~mb~SS~ displace ~d i.n drill. Pl~.. . . ~,_~ial test ~tth ~ter, ar~ close b~ss, ~is ~ll place f~ drill pi~, m) m 7. P~ll up to l~r'F,O, t~ol at 1gDO" and ~tsplace drill pipe with · 07~ N. tz~i a ~ m ~ e~ ~S too1. 8. ~ith annul:s v~lve dosed, c~-m~t 9,5/8" x 13-3/8' annulus WitJ~ .IDO ~ack~ m ' of ~~fmst ~ent. m~ni'tor ~nnuius pre~su,-m ~hii~ squme, zin9. If pressu~ d~ps ~ 0 psi, stop c~mnting. Cut. casing to 3800 psi. . ' i2 Go in hole ~bq op~-~ drill pip~ to 3400 5~t ~ ' . . 2 barrels of fr~h ~t~.r a~ad of c~t ~.-~d displace c~nt ~it.h 13. Puli out of plug ~41 up to 1500~ -~nd r~ve~se' out with ~ter. CoF~tinua ravarsfnq, until clan ~ter t~. £oming. ou~, ..P:ot~te Pip~ While reversing, 'Plugging Operations Plan.i~ Exxon #1 Alaska State "~" ~{ Page 2 14. Reverse water out of hole with diesel oil. Reverse until water-free diesel is coming out. 'Rotate pipe while reversing. 15. Pull out of hole laying down all drill pipe. Fill hole with diesel while pulling out except last 3 stands. This should leave _+ 30' of 9-5/8" void. · . 16~.~ Place top cement plug, using 10 sacks permafr~6st cement. 17. Install- capping flange, valve. RS: mg 9-18-75 SE? ! 8 ' 975 CONFIDENTIAL STATF- OF ~c~.~t~l o'f p~F~sed pi~. change f,~.,~q Sund~' ~tice dat~ 9-8-75 and 'film it~,_s )9 'f..h~,~gh ~l ~f ~ductian Teat!rig.and Su~pa;.~d)ng O~a~ions dat_~ a~J ".~e,l~-~re-. ~ ~.:mJtic' dated 9-4-7~ ~iil be changed F~_r ~h.a attac~c~d revJ~d F:,,-~-i:.== ~Q C?er~ti.~s Pl~_n a~ revis~ ~)t~m Sch~.~ti' SEP 1. 8 1975 7' ?.7 EO STATE OF A~ GA~ ~RYAT~ON Exxon Corporation State of Alaska ........ ) .... · .... . . LiI '~- I Exxon ~i Alaska State P. O. Box .20, Denver, Colorado 80201 ~,,~. ~ Wildcat 9/! 17~ Dri')ied ~7/8" hole to t3, . OILS. ,v-,.,', :, - ' ~ 9!5/75- g/8/?J. Ran ~(re!ine !~gs. ~n D[L, Sonic, ~-C~, ~nd Di~t~. ~t c~nt ~- -..~~..~, ,..~ ~~ ~ A~,~ ~'~, .... ~ ~proved Copx Retu~d m ..... PR..O~JCT!ON TESTiN(; & SUSP~D!.,~ OPERA~ E~ON ~! AL~.SKA STATE -~A' ~ELL DATA: SE~ ATTAC~D WELL~ SKETCH. PROCI~E; Log o.m~n-hol~, ~ ~f nonp,-oduc~ive, lay dram ~t/$" ~ri!l coll.~rs on ~ast tr~p in open ho~e. 2. Run ~iretine gauge ring and junk basket for' 7"~ -3~ liner ~ 12,920' +/-. Do not run through float collar. hun Ho~co ~driil cm~ent retainer on Schlumberger wireline armt set.at !2,900' +/-. ~n 5"/~" dritl pi~ amd sting into retainer. T~st a~u!us end set%lng to 1500 psi. ~tabiish inj~tion rate of t½ to 2 BPMo 1SC<) psi annulus pressure for b~ckup if irdecti~ pn~ssure .is greater than 3000 psi. 5~ SqueeZe 7, shoe and lm~er fo_rmations ~th lDO sacks Class G + 1.~ CFR-2 + 0.4% ~-7 mixed to 15.8 ppg ~ith fresh rater. P~ tim ~ 4 hours. P~ecede ce~mnt with '3 barrels fresh ~ater. ' .... 7. tnsta!l 2-7/8"'tubtng rams in upper a~ !o~er ram imm~v~nters. ~bve' blinds to midd)e r~m preventer.. Test casing to 3000 psi against biind'ra~. Test BOP stack and manif~!d t~ 5O0O psi and 300 psi. Rig up Schl~rger gr~se s~at tubr(cat~r a~d test. to 5000 psi. Perforate 7' liner as directed using (" Xy~jet gun. tl. Pick up .)kmmo DST assembly per 2-7/8", 8.7 ppf, ~ue ~ 3~ ft.-'ib. ~ pins and ~x~ ~th ~~kote 70~ Have ~dril ins~tl CB r'i~s on rack prior ~ pickt~ up ~bing. Drift ~bi~g ~ 2-l/8" either on rock or in V~r.. Run 6000' fresh ~ater cushion. Set packer such., that co~t~! he~d is ~t floor level. P~d ~st ~t be ~ tha.~ 5' ~ve rig floor for ~se of c~r~t(o~s. procedure .~iil ~ fur~ished as requirt~-. 15. 16. 17. 19. Afte~ t~esting, mm 5"/3~~ ~nat~n d~'Jl s~ing ~o 3Z,7~: ~"-~1 ci~late e~d condition mud. .Spot b~lanced cement plug from 12,700* to iZ,4~'. ~u9 ~ ~ist ~ ~t~. ~te pJ~ ~fle s~fn9 pl~. ~n 3 bbls. ~~ a~ i ~t. ~ht~ plug. ~li ~t of plug ~ up ~ t~' ~i~ ltn~ ~p ~ ~me out. Ci~!a~ ~' ~iti'On m~; '"S~ c~t plug f~ t~' ~t~ liar ~p ~ tO0' a~ve liar ~p usi~ ~ sacks of Class G + !.O~ C~*Z ~ ag plug w/l~Z~ ~i~t. Pull out ~ h~le. P.U cast iron bridge plug a~ sst in g-5/8", 47 ppf casing at using Schiu~be~er ~rel inc, P.Uo ~ t~ol and set at 10,500'. Pressure test bridge ~lug an~ cement pl~js to 3000 psi for 30 minutes. bypass and displace ~Jd in drill pil~m with f~esh ~ater ~e. b~ss a~ diffe~tially test li~ bp. ~i cliff--rial ~st, ~!d ~iff~ti~t ~t - g--~-75 ~2' ~L & 1~2' ~l of Sec. 27-TI~R24E U~ ~th Siope, Alaska ~~'e ~, 12,747-1Z,757',. O~t !0~o ~cov~ 9~. 8/2/75 - 8/_3/75 8/4/75 - 816/7S '~ri11~ 8¥ -h~t~ tO 1Z.998'. 8/6/75 - 8./_10/75 '~-~!-~-~-=i~S. Velocity survey, OIL, S~nic, ~c~ Class G + 1.~ Tes~ B~'s ~ 3~ psi a~ 5~ psi. P~SE Z ' ~iited 5..,:7jg~'- }role *._.o 13,18Z~'. ~ wi:. 15..i ppg. F~n cited ~ DST #1. Pack~ set at 12,~13,1~'. ~t~ ~le ms~ r~o~: !0,1~ psi aft~ 15.0 p~ ~ival~t ~ ~i~. T~l ~ 8/23/?$ - 8124/75 '~illN~ ~-7/8" hole to 13,228'. 8124/75 'Cu{ ~:'Pe. ~1~., 13,228-13,Z37'. Cut g', recovered, g'. 8124175 - 8t31175 ~'i]i~ 5-7/~'-~ie ~ ~3,'g]8'. ~ ~. 15.3 pm. ~C~ J)~t"~, ~(~ri~ ~io~I f~ 8/13/75 to 813'1/75 ~ t, ot~l of $3,5~ bbls,,, of F-~serVe' pit'-liquid into g-.518" x 13-318' annulus. Annulus breagd~i pressure 700 psi. Average pu~ in pressure ~ms 250 psi at t~te of 75 bbls. pe~ hour. 9/5/75 y~ U,~-uulc) (~-V. 08-/3) ~ MEMORANDUM DEPARTMENT OF NATURAL RESOURCES Division of Oil and Gas O.K. Gtlbreth, Jr. Director .,,j/.~:~ ~" THRU: Hoyl e H. Hami 1 ton Chief Petroleum Engineer FROM: Russell A. Douglass Petrol.eum Engineer (on contract) State of Alaska DATE: FILE NO: August 19, i975 TELEPHONE NO: SUBJECT: Waste Water Injection, Exxon's Flaxman Island State A-1. Tuesday August 12, 1975 - Buck Irwin (Exxon) called this morning. He informed th~ Division that theY were preparing to inject their reserve pit water in the 9-5/8" annulus on the Flaxman .Island State A-1 well. I made reservations on the 1:45 PM Wten flight. I also obtained the files con- cerning the well and discussed the trip with Hoyle. I left Anchorage at 1:45 PM arriving in Prudhoe Bay ,at 4:35 PM. I then boarded the Exxon Twin Otter for the flight to Flaxmn Island. I asked the pilot if he would fly over the Exxon East Mikkelson Bay State No. 1 enroute to Flaxman Island. He did and I shot a ~~ picture 'of the abandoned location from approximately 400 feet altitude {Picture I arrived on Flaxman Island (Picture #2)about 5.:'30 PM where I met Buck Irw'in. The crew was changing rams in one of the BOP'.s when I arrived. I took .a walk around th.e lpcatton taking pictures of the reserve pit and burn pit {Pictures ~4 and #5). I then discussed the operation wi.th Buck Irwin and Floyd Nix after dinner. They were authorized to pump at, a maximum surface pressure of 2000 pslg but were doubtful whether that would be necessary. A small gas driven, centrifugal pump was to be used to pump the fluid from the reserve pit {Picture #3). This would be pumped into Halt.burton tanks, and then pumped down the hole with Hal iburton pumps. Pumping was started at 8:48 PM. Surface pressure remained 0 for approximatedly 15 minutes then rose to 1250 psig in about 5 minutes. The pressure then leveled off-.for a couple of minutes then started to decline. At 9:15 PM a leak was detected at the wellhead and the pumps were shut down, The leak was repat'red and pumping began again at 10:lO P~4. Pressure rose to 1200 psig in a few minutes and started to decline t~ediately. Wednesday August 13, 1975 - Injection 'pressure at midnight was 900 psig and i'n- J~e-c-ttrofi--),a~~ was' appr°xi-~ateiy 5.5 bbl~min. At 12:45 AM injection pressure was 750 psig with the injection rate between 5 and 6 bbls/min. At 10:00 AM injection pressure was 600 psig at the same rate of injection. By 4:00 PM, approximately 6000 bbl. s of fluid had been injected. ~)R63072 .- .......... .~:.... .......... ,&,., O. K. Gilbreth, Jr. R.A.Douglass - Field Trip Report Waste Water Injection- Exxon Page 2 August lg, 1975 Thursday August _14 ,. 1975 - Injection pressure was down to 500 psig and the rate between 5 and 6 bbls/min. By 5:30 AM 18,000 bbls of fluid had been in- jected. Plans were to continue pumping until the fluid in the reserve pit, the fuel tank pit, and the burn pit had been put away. This would probably take two more days. After all fluid had been put away the annulus would be shut-in and the surface pressure monitored. Plugging of the annulus would not take place until drill- ing was completed and possibly more fluid would be pumped down the hole prior to this. I completed a Field Inspection Report for Buck Imvin and will send a copy to the Exxon office in Anchorage and a copy is attached. I flew to Prudhoe Bay at 8:45 AM and met Mr.. McCraw at the Exxon base camp. I waited here for my return flight to Anchorage. I flew to Anchorage at ll:O0 AM arriving at 1:30 PM. In summary, I witnessed injection of reserve pit fluids (mostly water) into the annulus between the 9-5/8" .and 13-3/8" casings in the Flaxnmn Island State No. A-1 well. The formations below the 13-3/8" shoe at 3376 feet took the fluid easily at a rate between 4 and 6 bbls/minute with a surface pressure ranging from 400 psig to 1250 psig. Operator Alaska vii and Gas Conservation Committ~= Field Inspection Report Well Name & No. Drilling Permit Number Inspected by Operator' s Rep. , . ,,_ , Contr. Rig No. Satisfactory Yes () Item Satisfactory Item No Yes ( ) 1. Well Si~n ( ) ( ) 2. Safety Valves-Floor ( ) ( ) 3. Safety Valves-Kelly ( ) ( ) 4. Safety Valves-Subsurface ( ) ( ) 5. BOP Closing System ( ) ( ) 6, Remot~ Controls ( ) ( ) 7. Drilling Spool-outlets ( )' ( ) 8. Flow Lines ( ) ( ) 9. Kill Lines ( ) ( ) 10. Manifold Chokes ( ) No ( ) 11. Manifold Pressure Test ( ) 12. BOP Pressure Test ( ) 13. Reserve Pit ( ) 14. Pit Berm ( ) 15. Location Berm ( ) 16. Fuel Berm ( ) 17. Operations off "Pad" ( ) 18. "General Housekeeping" ( ) 19. Abd. Marker in place ( ) 20. Water Well covered Date ATTACHMENT A SUMMER EQUIPMENT & MATERIAL STOCKPILE REQUIREMENTS EQUIPMENT REQUIREMENTS- (Normal Operations) 1. Aircraft - Twin Otter will be used to transport material and supplies up to a maximum 4,000# payload. All Personnel will be moved via Twin Otter. An all-weather airstrip will be maintained at the site to facil.itate summer Twin Otter operations. 2. On-Site Support. .Equipment 2- 966 Front Loaders. 1 - Combination Flat Bed Truck with winch and detachable water tank MATERIAL STOCKPILES 1. Mud Supplies a. Barite - Minimum lO,O00 sks w/l,600 sks in Halliburton P-tanks ' for bulk system. b. Bentonite - Minimum 3,000 sks. c. Lignosulfonate - Minimum 500 sks. d. Lignite -~Minimum 500 sks. e. Lost Circulation Material - Minimum 500 sks. f. Casing Pack Material - Minimum Requirements for 150 bbl. mixture. 2. Cement - Minimum of 3,000 sks ~of Class G. 3. Casing & Tubing - 14,000' of 9-5/8" for engineered intermediate casing 16,000' of 7", 35#, S00-95, Hydril SFJ-P 3,000' of 5", 18#, N-80, Hydril FJ-P 16,000' of 2-7/8", 8.7#, N-80, Hydril PH-6-CB 4. Drill Pipe & Collars 16,000' of 5", 19.5#, Grade E&G 3,000' of 3½", 13.3 ppf, Grade E drill pipe 900' of 4-1/8" x 2" drill collars 5. Fuel - 240,000 gals. in steel tanks 200,000 gals. in bladder tanks Exxon #1~ Alaska State Summer~ Operations and . ;...,~jency Plan Page 2 B. Contract helicopters for moving equipment too bulky for Twin Otter transport. C, Contract Hercs for continuous supply movement from Anchorage or Fairbanks. Emer. gency Preparednes.s A. Maintain weekly inventories of critical material. B. Maintain at least 25,000 bbl~ below ground reserve pit capacity at all times. If runoff water creates an unsafe level, install a pump with submerged suction, such that only water is discharged. Before discharging any water, run retort analysis to determine if oil is present. If no oil is present, pump off excess. Main- tain hourly check on discharge to be certain it is only water. At first indication of change in discharge, shut down. Maintain daily record of reserve pit chloride content. If 9-5/8" casing has been set, pump excess reserve pit water into the 9-5/8" x 13-3/8" annulus. C. Maintain an adequate supply of. sorbent material on location for cleaning any minor oil spillage. D. Maintain 1600 sks of barite in Halliburton bulk tanks for emer- gency use only. RS:bt Form 10-403 REV. 1'-10-73 Subml t "1 ntentions" In Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) FnNFIDENTIAL 5. APl NUMERICAL CODE 50-089-2003 6. LEASE DESIGNATION AND SERIAL NO. ADL-47556 :7. IF INDIAN, ALLOTTEE OR TRIBE NAME WELLI~--I WELLL~.J OTHER Wildcat NA 2__ NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Exxon Corporation State of Alaska 3. ADDRESS OF OPERATOR 9.WELL NO. Exxon No. 1 P. O. Box 120 Denver, Colorado 80201 Alaska State "A" 4. LOCATION OF WELL At surface 2982'of W line and 1542' N of S Line Sec. 27, T1ON, R24E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 10' GR 14. Check Appropriate Box To Indicate Nature of Notice, Re~ 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., t., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 27, T1ON, R24E, UPM 12. PERMIT NO. 74-14 3orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF l--.--I PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other)Disposal of waste water into casin SUBSEQUENT REPORT OF= FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE= Report resu ts of multiple completion on Well Completion or Recompletion Report and Log form.) 15, DESCRIBE,PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. As runoff water in the reserve pit is approaching an unsafe level, preventing the maintainance of a safe minimum below ground pit capacity, it will be necessary for Exxon to commence on or before August 3, 1975 to pump excess reserve pit water into the 9 5/8". X..13. 5/8" casing annula as depicted in the attached .well bore schematic drawing. The 9 5/8" protection casing was run and cemented on July 18, 1975. This will now permit disposal of waste water into porous salt water sands below the casing set at 3375'. Pumping equipment is on standby and will be used to keep level and maintain storage capacity capable of handling an emergency situation in the Summer Operations and Contingency Plan also attached. installation surface a safe pit as outlined ,~)..., , 16. I here In~ I, / // '" (This space for State~office use)~ ~ ¢ '" .. Approved ~e Instructions On Reve~eSide CONFlu mlAL Returned PA~ ~ circulation of t~ casing pack fluid ~ii~hout danger of losing permeable sands below. ~e 1~-3/8" casing shoe. 'CONFIDENTIAL ~xxon Co' r.fx~ration ADL-47556 , ~ { ~"~' ' - ' ' ' ':. 'u': ~ ' ,;:' ' , ,, ,~ ..... , , ,.,, ) .,, ~ t~,~ :.,h ,< ; ,::,'::,,F,,. ~-. ', ,>' ,, '",, v <~. ........ ,.~ ........ ,, ,,~ in tm~ 9"6/8" X iQ--3/B" anmlus, w~ pro.se m pmt~t thi~ annulus at ti~ of roll Place 300' +/- cemnt Plug in 9-5/8" x i3-3/8" annulus through !~er '.',:: ,, Ha!!i~rton ~.0~ tint"collar at 1996~. ~;i~ 1~ sacks of Halii~n p~frOs:~ C~nt. TeSt c~% j~ ~/~0 p.sj p~ssure un annulus, 2. O~ 'u~ F,Q, c~ ~liar at 1~3' a~ circulate a~ulus full of ~id .,. Arctic b. sing~ck, oil base fluid, Circulate ~ck: fluid until ~r is l~s F~n ~7/8" tubing as kilt string fro~ top of 7" liner to surface and hang in wellh~d; See at~ached wellbore schematic for details on suspended , (~ntinu-ed on Page ~'~"~i~ we~lheaa section '~h d~i'~ pi~ i~ hole. amd ~ .~,F'~~'~' ~ ~ t '23t 75 71Pai ~ ~ Ce. re ~6 f~ t2,~,557~ Le 12~547'~ Q~t 90'~, recoYer~ . '~' '~ Cu'~ 9e'~ ~ ...... ~< ,. 7/28/75 'i"}: ......... ':""'" ........ '"'-" ........ . - ~..: .;- . . ~ .. .. . -.- ~ .-'".~;N"" · '. : ~:..e ' .. ..... ~. ,:- ...... ':. _.~. . , .. . . .. , . "- ~ - .~,:.:.... :..- .. · ~ ~'Ym s~~.' .... = . ...... · . :... - ..? '- .I- .I. ,..- ~:,- ): .: · .> ~ .'~, .'.,~'.:'- ~ ~.. · ~. Z', ...... '.~- 7'"'-. ': ~ : =" . ~c:.,. ~.~'~,'. :....~ .~ · . .. 7::. '.':,~.~ '..,' : ~ . ' ~ ., r - . CONFIDENTln . ! I ,~'-uu1B (~-V. 08-/3) ;, FROM: MEMORANDOM DEPARTHENT OF NATURAL RESOURCES Divtston of 0il and Gas Th: O.K. Gilbreth, Jr;~,¢ ~ Director THRU: Hoyl e H. Hamil ton ~ Chief Petroleum Engineer~ John C. Mi 1 let ~c'~ Petroleum Engineer State of Alaska DATE: FILE NO: August 1, 1975 TELEPHONE NO: SUBJECT: Investigation of Reported Pollution at Exxon - Alaska State "A" No.1, Flaxman Island, North Slope. This office receded a report, which originated from an anonymous phone call to a federal agency, that oil pollution of the-beach and sea had occurred on the north side of Flaxman Island near the .Exxon -. Alaska State "A" No.1 explor- atory drilling well. As a result of this report Exxon officials contacted Mr. O. K. Gilbreth on July 18, 1975, and admitted pumping about 13,000 barrels of water from their reserve mud pit onto the sea ice on the seaward side of the island. This was done without requesting permission from, or advising respon- sible state or federal agencies.. Mr. Thompson, of Exxon in Denver, stated that 'they had maintained a close.control observing pH and chloride content and that no oil had escaped while pumping from the pits. Later we learned that extrane- ous water had nearly filled .their reserve pit during sp6tng thaw and the level 'was pumped down. to be prepared to handle a possible emergency well flow.. On July 22, 1975, Hr. Gtlbreth, Hoyle Hamtlton and. myself met with Pedro Denton ' of Di"vi. sion of Lands and Commander Lauren Go'rden of the U.S. Coast Guard. Information on. the Exxon action .was exchanged and plans, for an investigative trip were finalized... , Wednesday July 23, !97_5 - I departed Anchorage.. at 10:00 AM :by commercial' .air- craft-'in the cOmpa.~ of Commander Lauren Gordon, Ray Mo'rrts .o:f Federal Environ- mental Protection Agency, and Bob Rt.dd:le,. Exxon' s landman in Anchorage. John Ja..nseen o.f Alaska Department of Environmental Qu:'ality joined 'our group at. Fairbanks. Exxo:n's lease foreman, Mac :McCraw, met us on arrival at Oeadhorse at 12:30' PI~ .and 'escorted our group to. :Exxon's chartered 'Twin. Ot:ter. After a 25 minute flight we landed at .the Exxon - Alaska State "A" No. 1 drilling well on Flaxman Island at. l :'lO PM. {See Photos 1 and 2). ,, Mac and :Bob Riddle. introdUced,, our four-man inspection .team 'to the two Exxon drilling superintendents, Dick .Moore and Buck Irwin..After lunch all seven of :us .proceeded to inspect the ;.area. . . The reserve pit had' about fo:ur feet of freeboard at the highest berm point and about two feet :at the lowest. A steady, breeze had a thick layer of heavy oil concentrated at one e.nd of the reserve pit {Photo 3} leaving about 50~; of the .surface clear of oil {Photo 4). 'The center, flare pit, also had a layer of thick oil o.n the surface and two roughnecks were trying to pump this oil in. to the reserve pit {See Photo. 5). A burn. pit {Photo 6) had been formed beyond the flare, pit to burn the oil because they considered .the flare pit too close to the rig to do this safely. All three pits can be seen i'n Photo 7. Exxon had ordered an oil skinner from the South 48 and expected it today or tomorrow. Dick explained that they plan to skim the oil off the flare pit and (~)R63072 O. K. Gilbreth, Jr. J. C. Miller-Field Trip Report Exxon-Flaxman Island Page 2 August l, 1975 reserve pit, put the oil in the burn pit and burn it. They intend to pump future accumulations of mud and water in the reserve pit, down the casing for subsurface disposal. Ray caught samples for analysis of the heavy oil and of the mud fouled water at the reserve pit surface. {See Photo 8). We walked to the seaward beach where the reserve pit was pumped onto the sea ice. Evidence of clean-up was on the beach such as pieces of absorbent mats and several small boards. {See Photo 9). One board was coated with what could be oil. Thin bands of mud were on the water surface near the bank and there was a small thin slick of a darker substance that could be oil. (See Photo 10}. Ray caught a sample of the dark liquid for analysis and comparison with oil from. the reserve pit. No oil was visibleon the bank. If oil had been pumped into the sea here it appeared that the volume was small and/or the clean-up .was good. I walked the beach in both directions from the disposal spot. In a couple of places I saw thin bands of mud on the water next to the bank. In general, there was a two to three foot thick layer :of very black soil underlying the tundra. The soil was sloughing alongthe bank. {See Photo ll). Under the soil was gravel and in some places sand. (See Photo 12}. On the .day of our trip the prevailing wind was directly toward the seaward beach we were inspecting. (See Photo 13). We checked the sewage treatment plant and sewage lagoon (Photo 14). These appeared in good condition. We boarded the Twin Otter at 4:00 PM. Bob Riddle explained that this well was "Very Confidential", that we had seen what very few Exxon people have seen, that they had held nothing back and would show us anything else that we wanted to see. Bob requested that we keep what we'd witnessed within our organizations and away from the press since their well was adjacent to a proposed lease sale area. We arrived at D.eadhorse at 4:40 PM and departed on the 5:15 PM Wien flight which landed in Anchorage at 7:45 PM. On this trip I was part of a joint state-federal team to investigate reported oil pollution on the seaward side of Flaxman Island. I saw two very small sheens on the water at two separate spots and evidence of clean-.up operations. I also saw sporatic .bands of drilling mud on the water surface next to the beach. I saw no evidence of environmental damage. Attachments ATTACHMENT A SUMMER EQUIPMENT & MATERIAL STOCKPILE REQUIREMENTS EQUIPMENT REQUIREMENTS- (Normal Operations) 1. Aircraft - Twin Otter will be used to transport material and supplies up to a maximum 4,000# payload. All personnel will be moved via Twin Otter. An all-weather airstrip will be maintained at the site to facilitate summer Twin Otter oper.ations. 2. On-Site Support Equipment 2 - 966 Front Loaders 1 - Combination Flat Bed Truck with winch and detachable water tank MATERIAL STOCKPILES 1. Mud Supplies a. Barite - Minimum lO,O00 sks'w/1,600 sks in Halliburton P-tanks for bulk system. b. Bentonite - Minimum 3,000 sks. c. Lignosulfonate - Minimum 500 sks. d. Lignite - Minimum 500 sks. e. Lost Circulation Material - Minimum 500 sks. f. Casing Pack Material - Minimum Requirements for. 150 bbl. mixture. 2. Cement -Minimum of 3,000 sks of Class G. 3. Casing & Tubing - 14,000' of 9-5/8" for engineered intermediate casing 16,000' of 7", 35#, S00-95, Hydril SFJ-P 3,000' of 5", 18#, N-80, Hydril FJ-P 16,000' of 2-7/8", 8.7#, N-80, Hydril PH-6-CB 4. Drill Pipe & Collars 16,000' of 5", 19.5#, Grade E&G 3,000' of 3½", 13.3 ppf, Grade E drill pipe 900' of 4-1/8" x 2" drill collars 5. Fuel - 240,000 gals. in steel tanks 200,000 gals. in bladder tanks July 28, 1975 ~r. Gene D. Thompson Exxon Company P. O. Box 120 Denver, Colorado. '80201 Re: Flaxman Island Discharge Report Dated July 22.,. 1975 Dear Mr. Thompson: I ihave just received a copy of your report to Mr.. Dickason regarding the waste water discha~e at Flaxman Island from June 25, 1975 to. July 7, 1975. I want to add to some of the info~ation contained in that report. As you know', I was. kept abreast of ~e operations regarding safety and do~nholeproblems at approximat.e weekly intervals during~is period. However, to clarify your report, I had no knowledge whatsoever about any discharge to ~%e sea until.July 18, 1'975 'when you advised me by phone that you were prepartng a letter to Mr. Dickason regarding water which had been pumped o.%~t of the pits. to the seaward side of the island.. At that time you verbally assured me that your people h. ad"maintained close control'' and that no. oil had been pumped with the water. I wanted to clarify because your letter might be construed 'to indicate that I was completely aware of this problem (of discharge) Wh.sn in fact, ii had no knowledge nor was I i:nforme.d until after the fact. Sincere ly, O. K. Gilbreth, Jr~W Director Mr.. Gen.eDickason, Director U. S. Environmental Protectio~ Agency ,Mr. Ernst ~Ueller, Commissioner Department of Environmental Conservation ~r..John Janssen, Department of Environmental COnservation, Fairbanks ~r. Guy R. Martin, Commissioner Department of Natural Resources OKG:,: cha ', .... ., EXXON #1 ALASKA STATE "A" SUMMER OPERATIONS AND CONTINGENCY PLAN The overall objective of this plan is to detail sufficient operating 'and contin- gency requirements and planning to ensure a safe and efficient operation during breakup and summer months. Logistics - Major supplies of mud, casing, cement, fuel, and miscellaneous sup- plies w'ill be transported over ice and stockpiled prior to spring breakup. During breakup and summer months, light consumables will be resupplied by Twin Otter. If necessary, major consumables and fuel will be resupplied by barge during summer shipping season. Prior to breakup, move out all support equipment not required for sum~er opera- tions. (See Attachment A.) Water - An Aqua-Chem 600 gallon/hour Vapor Compression-Distillation unit will be operating prior to breakup. The unit will utilize sea water and distill it into fresh water for camp and boiler use. .Sea water and reserve pit water will be used for drilling mud makeup. Recycle as much reserve pit water as possible to minimize chlorides in mud and maintain low pit level. As weather warms and lakes form on island, use this water for camp and mud makeup, if required. Maintain 30,000 gallons of fresh water in one steel tank for use during cementing operations. Conting.encj/and Pollution Control Plan A. Minor Pollutant,on Location:. All drainage frOm the rig will be directed toward reserve pit as a collection area. Any minor spill of oil will be collected using sorbent material for disposal in burn pit and burned. B. Controlled Well Kick: 1. Measure pressures and raise mud weight sufficiently to contain well. If mud weight cannot be raised high enough withOut loosing returns, a barite plug will be pumped to kill well. 2. While circulating out influx, all severely contaminated mud, if oil contaminated, will be diverted to burn pit for bUrning. C. Uncontrolled Well Flow: 1. Divert flow to burn pit as first defense against spill. As burn pit fills, divert flow to reserve pit. A minimum of 25,000 bbls containment capacity must be maintained at all times in the reserve pit for this emergency. 2. Make preparations for drilling a relief well from a site on the western section of the island. 3. If situation warrants, after discussion with Exxon management' and proper government agencies, ignite the well. · Emergency Log.i..sticsl A. Contract additional Twin Otters for moving mud and cement materials.~ Exxon #1 Alaska State "~"{'~ Summer Operations and (~'~' aingency Plan Page 2 B. Contract helicopters for moving equipment too bulky for Twin Otter transport. C. Contract Hercs for continuous supply movement from Anchorage or Fairbanks. Emergencj/ Preparedness A. Maintain weekly inventories of critical material. B. Maintain at least 25,000 bbl, below ground reserve pit capacity at all times. If runoff water creates an unsafe level, install a pump with submerged' suction, such that only water is'discharged. Before discharging any water, run retort analysis to determine. if oil is present. If no oil is present, pump. off excess. Main- tain hourly check on discharge to be certain it is only water. At first indication of change in discharge, shut down. Maintain daily record of reserve pit chloride content. If 9-5/8" casing has been set, pump excess reserve pit water into the 9-5/8" x 13-3/8" annulus. C. Maintain an adequate supply of sorbent material on location for cleaning any minor oil spillage. D. Maintain 1600 sks of barite in Halliburton 'bulk tanks for emer- gency use only. RS:bt // \ / , 23 No. I ALASKA T I I I i I I I I i ! I I ~ ~9 I 2o I I I I I I 3o I 29 ! 28 I I I I' I I I I R.24E. 14 ~2 23 I I I ~,/~/~ EXXON N,o. I ALASA STATE 27 LA[: 7C° II 21.06" ' LONG. = lZl. 6° 00' 42.41" X: 498,537 Y = 5,918,728 i I ! I 31 I 32. I 33- I ~ I I I I I I I I I I ~ I I I' I ! L 34 I I I 35 I 36 I I I I I I ~ I I i I I ~ 25E. T ION. T. 9N. 'i SCALE: I"= IMILE CERTIFICATE OF SURVEYOR · I hereby certify that ! am properlY registered and licensed to practice land surveying in the State of ,Alaska and that this ,plat represents a location survey made by me or under my supervision, and tha~ all dimensions and other details ore correct. Date, SURVEYOR I lrllll Iiii i I II EXXON No. I ALASKA STATE '~A" Locoled in $E.I/4 PROTRACTE. rJ SEC. 27 T..I..'..,I~I., N 24E. IJMIAT~.MEI~IDIAN J~CL Surveyed for EXXON COMPANY U.S.A. SurVeye~ by E M LINDSEY 8~ ASSOC. LAND & HYDROGRAPHIC SURVEYORS 2502 West Northern Light's Boulevard Box 4-081 Anchorage Alaske' ~ .... --__:: £ ~D-:-~: :.-':7: ~ :: :~:'__ FOR AGENCY USE I Implementation Schedule and 3. Actual Completion Dates .... provide dates ImPosed by schedule and any actual dates of completion for implementation steps listed below. I:ndicate dates as accurately as possible. (see Instructions) 'h:~: .~ '-'" ~mpiementation Stem -.- ... :, .~.......a. Preliminary plan complete i. -'(' ; t..-:'? ' ",..i'!.:-"' i;b. Final plan submission ~." "i, --: :' -.- 'c. Final plan complete ~' ' i; ",..: ~'~" '" ' ' :t~ .~ .i.' ' d. Financing complete & contract awarded ~ ~' e. Site acquired '~':~" ......... ...... . f.' Begin action (e.g., con. ruction) g. End action (e.g., construction) h. Discharge Began I. Operational level attained 2. Schedule (Yr./Mo,/Day) 3. Actual Completion (Yr./Mo./Day) 75 / 7 /22 -----/ / . ! . ! ,,/__-...! · ,,./ ,., / 7._ ', /_...__! .. , Elimination of discharge into the Beaufort Sea will be achieved by utilizing casing-casing annulus for disposal of excess reserve pit water. EPA Form 7550-23 (7-73) STANDARD FORM C - MANUFACTURING AND COMMERCIAL FORM APPROVED OMB Noo 158--R0100 FOR AGENCY USE SECTION 1TI. WASTE ABATEMENT REQUIREMENTS & IMPLEMENTATION (CONSTRUCTION) SCHEDULE This section requires information on any uncompleted implementation schedule which may have been imposed for construction of waste abate- ment facilities. Such requirements and implementation schedules may have been established by local, State, or Federal agencies or by court action. In addition to completing tile following items, a copy of an official implementation schedule should be attached to this application. IF YOU ARE SUBJECT TO SEVERAL DIFFERENT IMPLEMENTATION SCHEDULES, EITHER BECAUSE OF DIFFERENT LEVELS OF AUTHORITY IMPOSING DIFFERENT SCHEDULES (Item la.) AND/OR STAGED CONSTRUCTION OF SEPARATE OPERATION UNITS (Item lc), SUBMIT ASEPARATE SECTION III FOR EACH ONE. Improvements Discharge Serial Number Affected List the discharge serial numbers, assigned In Section II, that are covered by this implementation schedule. b. Authority Imposing Require- ments Check the appropriate item indicating the authority for Implementation schedule. If the identical implementation schedule has been ordered by more than one authority, check the appropriate items. (see Instructions) Locally developed plan Areawide Plan Basic Plan State approved Implementa- tion schedule Federal approved water quality standards implementa- tion plan. Federal enforcement proced- ure Or action State court order Federal court order Facility Requirement. 5pacify the 3-character code of those listed below that best describes in general terms the require- ment of the implementation schedule and the applicable six- character abatement code(s) from Table II of the Instruction booklet. If more than one schedule applies to the facility because of a staged construction schedule, state the stage of con- struction being described here with the appropriate general action code. Submit a separate Section III for each stage of const ruction planned. 001 LOC []ARE r')BAS r-JsQs I--]WQS [--]ENF J-]CRT [] FED 3-character (general) 6-character (specific) (see Table I I ) DSTOPD FOR AGENCY USE . . No formal Federal or State requirements were issued prior to our plan to eliminate discharge. New Facility Modification (no Increase In capacity or treatment) Increase in Capacity Increase In Treatment Level Both increase in Treatment Level and Capacity Process Change Elimination of Discharge III-1 NEW MOD INC INT ICT PRO ELI E PA Form 7550-23 (7-73) This section contains 2 pages. FORM APPROVED OMB No. 158.-R0100 STANDARD FORM C - MANUFACTURING AND COMMERCIAL SECTION'IT- BASIC DISCHARGE DESCRIPTION IFOR AGENCY USE J Complete this section for each discharge Indicated In Section I, Item 9, that Is to surface waters. This Includes discharges to munlcipalse~,-erage systems in which the wastewater does not go througr~ a treatment works prior to being discharged to surface waters. Discharges to wells r~ust be described where there are also discharges to surface waters from this facility. SEPARATE DESCRIPTIONS OF EACH DISCHARGE ARE REQUIRED EVEN IF SEVERAL DISCHARGES ORIGINATE IN TIlE SAME FACILITY. All values for an existing discharge should berepre- . Sentatlve of the twelve previous months of operation. If this Isa proposed discharge, values should reflect besteng~neerlngestlmates. ADDITIONAL INSTRUCTIONS FOR SELECTED ITEMS APPEAR IN SEPARATE INSTRUCTION BOOKLET AS INDICATED. REFER TO BOOKLET BEFORE FILLING OUT THESE ITEMS. Discharge Serial No. and Name a. Discharge Serial No. (see instructions) Discharge Name Give name of 'discharge, if any. (see Instructions) Previous Discharge Serial No. If previous permit application was made for this discharge (see Item 4, Section I), provide previ- ous discharge serial number. Discharge Operating Dates &. Discharge Began Date If the discharge described below is in operation, give the date (within best estimate) the discharge began. Discharge to Begin Date If the discharge has'never occurred but Is planned for some future date, give the date (within best esti- mate) the discharge will begin. Discharge to End Date If dis- charge is scheduled to be discon- 'tinued within the next 5 years, give the date (within best esti- mate) the discharge will end. 3.' Engineering Report Available Check if an engineering report is available to reviewing agency upon recluest. (see Instructions) Discharge Location Name the political boUndaries within which the point of discharge is located. State . County (If applicable) City or Town Discharge Point Description Discharge is into (chec~c one): (see Instructions) Stream (includes ditches, arroyos, and other Intermittent watercourses) Lake Ocean Municipal Sanitary Wastewater Transport System Municipal Combined Sanitary and Storm Transport System IE PA Form 7550-23 (7-'73) 001 Discharge From Reserve Pit To Beaufort Sea 19756 YR MO YR MO 1975 8 YR MO ., · Alaska _~orth Slope I"]ST R ['ILKE I~OCE o [-IMTS DMCS Agency Use lI-I 'Thta section contains 9 pa~e.~. Municipal Sto~m Water Transport System Well (Injection) Other If 'other' is checked, specify Discharge Point-- Let/Long Give the precise location of the point of discharge to the nearest second. Latitude Longitude Discharge Receiving Water Name Name the waterway at the point of discharge.(see instructions) If the discharge Is through an out- fall that extends beyond the shore- line or is below the mean Iow water line, complete item 8. Offshore Discharge a. Discharge Distance from Shore b. Discharge Depth Below Water Surface* 9. Discharge Type and Occurrence a. Type of Discharge Check whether the discharge is con- tinuous or intermittent. (see instructions) b. Discharge Occurrence Days per Week Enter the average num- ber of days per week (during periods of discharge) this dis- charge occurs. c. Discharge Occurrence--Months If this discharge normally operates (either intermittently, or continuously) on less than a year-around basis (excluding shutdowns for routine mainte- nance), check the months dur- ing the year when the discharge is operating. (see instructions) Complete Items I0 and 11 if "inter. mittent" is checked in Item 9.a. Otherwise, proceed to Item 12. 1.0. Intermittent Discharge Quantity State the average volume per dis- charge occurrence in thousands of gallons. I 1. Intermittent Discha~e Duration and Frequency a. Intermittent Discharge Duration Per Day State the average number of hours per day the discharge is operating. b. Intermittent Discharge Frequency. State the average number of discharge occur- rences per day during clays when discharging, 12. Maximum Flow Period Give the time period In which the maximum flow of this discharge occurs. EPA Form 7550-23 (7-73) DISCHARGE SERIAL NUMBER - 001 [] ST$ r-lW£L I--loTH 70 OEG ll MIN 21,:06SEC 146 DEG 00 M~N 42.41sEc Beaufort Sea For Agency Use For Agency U~e Major Minor Sub 5 feet 0 ,feet [] (con) Continuous [] (iht) Intermittent ~days per week [~JAN ~r'-] FEB [] MAR [-;]APR []MAY [~JUN [~JUL [~AUG []SEP [] OCT [] NOV [] DEC 303e The discharge is continuous while,pumping, however, discharge occurs only for period required to lower reserve pit to acceptable level. This section does not readily apply to this type operation ',,, . thousand gallons per discharge occurrence. ..... hours per day . ~dlscharge occurrences per day Fro m J]Jg_~Z t o A u._~o~u s t month month ' 11.9 DISCHARGE SERIAL NUMBER 001 {' FORM A PP'ROVED OMB No. I58-R0100 FOR AGENCY USE 13. Activity Description Give a narrative description of activity producing this (~lscharge.(see Instructions) This is a wildcat drillinq well locatio'n with a max- imum reserve pit water storage limit of approximately 2,800,000 gal. Of this limit, 1,050,000 gallons must .......... be maintained empty as a first containment defense in ........ the event of an uncontrolled well flow. The influx .of spring runoff water into this reserve pit creates a situation whereby the level in the pit is too high_ to yield an acceptable limit of void for the contain- ment of an uncontrolled flow and therein lies the reason for discharqe. 14. Activity Causing Discha~e For each SIC Code which describes the activity causing this discharge, Supply the type and maximum amount of either the raw material consumed (Item 14a) or the product produc'ed (Item 14b) in the units specified In Table I of the Instruc- tion Booklet. For SIC Codes not listed in Table I, use raw material or production units normally used for measuring production.(see I~structions) There is, no.SIC code for this operation. a. Raw Materials Maximum Unit Shared Discharges SIC Code Name Amount/Day See Table I) (Serial Number) ,,, , , -- , · , b. P','odUcts Maximum Unit Shared Discharges SIC Codd Name Amount/Day See Table I) (Serial Number) ........... L: E PA F~rrn 7550-2:3 (7-731 11-3 ' DISCHARGE SERIAL NUMBER 001 FOR AGENCY USE 15. Waste Abatement a. Waste Abatement Practices Describe the waste abatement practices used on this discharge witl~ a brief narrative. (see instru cfi b. Waste Abatement Codes Using the codes listed in Table II of the Instruction BooKlet, describe the waste abatement processes for this discharge In the order in which they occur if possible, Narrative: The water in the reserve pit is bein9 recycled for use in the mud system. Had runoff water not been introduced, the discharge would probably not be reauired. (~)o ~,,.,e~cl , (2) (4) , (5) (7) , (s) (~o) , (11) (13) , (I4) (16) , (17) (19) , (20) (22) , (23) (3) (6) (9) (12) (15) (18) (21) (24) (25) EPA Form 7550-23 (7-73) ' FORM APPROVED · DISCHARGE SERIAL NUMBER OMB No. 158--~0100 ( oo' (' ~ . JFOR AGENCY USE · ~6. Wastew,t,,Ch,,,~,ristl-- TO be furnished' when final chemical analysis is rUn. Check the box beside each constituent which Is present in the effluent (discharge water). This determination Is to be based on actual analysis or best esttmate.(see Instructions) Paramctcr ~ Paramctcr Color Copper 00080 X 01042 , Ammonia iron 00610 01045 Organic nitrogen Lead 00605 01051 Nitrate Magnesium 00620 00927 ' Nitrite Manganese 00615 01055 · Phosphorus Mercury 00665 71900 ' ' Sulfate Molybdenum 00945 01062 Sulfide Nickel 00745 01067 , Sulfite Selenium 00740 01147 Bromide Silver . 71870 01077 Chloride Potassium 00940 X 00937 Cyanide Sodium 00720 00929 Fluoride Thallium 00951 01059 Aluminum Titanium 01105 01152 , Antimony Tin 01097 01102 , Arsenic Zinc 01002 01092 Beryllium Algicides* 01012 74051 Barium Chlorinated organic compounds* 01007 74052 Boron Pesticides* 01022 74053 Cadmium Oil and grease 01027 00550 Calcium Phenols 00916 32730 ,, Cobalt Surfactants 01037 38260 , , Chromium Chlorine 01034 50060 · Fecal coliform bacteria Radioactivity* 74055 ' 74050 *Specify substances, compoun, ds and/or elements in Item 26. l%sticides (inzcticides, fungicides, and rodenticides) must be reported in terms of the acceptable common Pesticide Labels, 2nd Edition, Environmental Protection Agency, Washington, D.C. 202~_~:JJ~urt~19~r~, requi~ed by Subsection 162.71b) of the Regulations for the Enforcement of the Federal[]lh'~"~ctiL'~le? Fungicide, and Rodenticide Act. ' * il '"'~,~i ' · ' dt~._ L., (, EPA Form 7550-23 (7-73) 11-5 DISCHARGE SERIAl_ NgMBER .... OO1 ~ ~o. AGE.cv 17. Description of Intake and Discharge For each of the parameters listed below, enter in the appropriate box the value or code letter answer called for.(see Instructions) In a0dition, enter tl~e parameter name and code and all reQuire~ values for any Of the following parameters if they were checked In Item ammonia, cyaniae, aluminum, arsenic, beryllium, caami~, chromium, copper, lead, mercury, nickel, ~lenium, zin~ phenols, oli and and chlorine (residual). ,. . Influent Effluent ~ ~ ,~- g ..- ._ Palameter and Code (l) (2) (3) (4) (5) (6) (7) (8) mow* Not Not C~o~s p~r da~ 19,000 26,000 42,000 Avail- Avail- 1/7 1 NA ooos6 a b 1 e a b 1 e ~ · u~ts NA NA NA NA NA NA NA 00400 ~ ........... Temperature (w~teO o v NA NA NA NA NA NA NA NA 74028 ,, ~ ,.. ~ Temperature (su~er) o ~ NA NA NA NA NA NA NA NA 74027 Biochemical Oxygen Dem~d (BOD 5~ay) ,n~ ' NA NA NA NA NA NA NA NA 00310 ................ CAemiml Oxygen Demand (COD) md] NA NA NA NA NA NA :NA NA 0O340 .... TotM Suspended (nonffite~able) So,ds mdi NA NA NA NA NA NA NA NA 005 30 , ., . ,,,. Specific Conduct~ ~ micromho~cm at 25° C ~A ~A ~A ~A ~ ~A NA 00095 .... Settleable Matter (residue) m~ NA ~A NA NA ~A ~A ~A ~A 00545 ......... ,, .......... *Other discharges sharing intake flow (serial numbers).(see instructions) E PA'Form 7550-2~ (7-73) II-6 , FORM APPROVED OMB No. 158--R0100 DISCHARGE SERIAL NUMBER 001 , FOR AGENCY USE 17. (Cont'd.) Influent Effluent Parameter and Code .- ~.~ ~ :;> ~ ~ ~ ~ < "' (1) (2) (3) (4) (5) (6) (7) (8) '... · , _., · , · 18. 19. Plant Controls Check if the fol- lowing plant controls are available for this discharge. Alternate power sou rce for major pumping facility. Alarm or emergency procedure for power or equipment failure Complete Item 19 if discharge is from cooling and/or steam water generation and water treatment additives are used, Water Treatment Aflditives If the discharge is treated with any con- · ditloner, Inhibitor. or algicide, answer the following: a. Name of Material(s) Name and address of manu- facturer Quantity (pounds added per million gallons of water treated). E] APS [] ALM See 26 Additional Information'. · EPA Form 7550-23 (7-73) 11-7 Cl. Chemical composition of these ~'~ additives (see Instructions). Complete Items 20-25 If there Is a thermal dlscllarge (e.g.. associated with a steam and/or power generation plant, steel mill, petroleum refinery, or any other manufacturing process) and the total discharge flow Ir, 10 million gallons per day or more. (see Instructions) 20. Thermal Discharge Source Check the appropriate item(s) Indicating the source of the discharge. (see instructions) Boiler Blowdown Boiler Chemical Cleaning Ash Pond Overflow Boiler Water Treatment -- Evapora- tor Blowdown Oil or Coal Fired Plants-- Effluent from Air Pollution Control Devices Condense Cooling Water Cooling Tower BIowdown Uanu factu ri ng Process Other 21. Discharge/Receiving Water Temper- ature Difference Give the maximum temperature difference between the discharge and receiving waters for summer and winter operating conditions. (see instructions) Summer Winter 22. Discharge Temperature, Rate of Change Per Hour Give tl~e maximum possible rate of temperature change per hour of cliscl~arge under operating con- ditions. (see instructions) 23. Water Temperature, Percentile Report (Frequency of Occurrence) in the taDle below, enter the temperature which is exceeded ~.0% of the year, 5% of the year, 1% of the year and not at all (maximum yearly temperature). (see instructions) Frequency of occurrence a. intake Water Temperature (Subject to natural changes) b. Discharge water Temperature 24. 25. Water Intake, Velocity (see Instructions) Retention Time Give the length of time, In minutes, from start of water temperature rise to discharge of cooling water. (see Instructions) DISCHARGE SERIAL. NUMBER Not Applicable [] BLBO' , I-'IBCCL ' ' "" I--IAPOF .; []EPBD []OCF. D'~ONO [] CTBO [] MFPR [] OTH R . . ~°F./hour 10% 5% 1% Maxlmum ,,, oF oF oF oF oF oF oF oF feet/sec. minutes EPA Form 7550-:23 (7-73) ][l-8 ..... ¢ 26. Additional Information 19 DIscHARGE SERIAL NUMBER 001 Information FORM APPROVED OMB No. 155-R0100 ~ ~o~ Ao%c~ ;:sE I Water from Drillin~q Ri_q & Drilling Mud System Contains the Followin9 Dissolved Chemicals' Caustic Soda (Sodium Hydroxide) Sodium Carbonate Sodium Bicarbonate Lignosul fonate Lignite Undissolved solids are: barite, bentonite, and drill cuttings. Water from Boiler Discharge Contains' 0.5 gal. per 9000 gal/day a chemical trade named Iso-Dex from DuBois Chemical, Cincinatti, Ohio. The quantity of each constituent is not available at this time. The following chemicals are present in this material' Sodium Hydroxide Sodium Carbonate Hydrazine Sodium Sulfite Polyacrylate Li§nin Sul fonate After introduction into boiler, the Hydrazine is reacted to hydrogen 9as and the Sodium Sulfite is reacted to sodium sulfate. The prime function of this chemical, is scale inhibition. The manufacturer states this chemical is accepted for use in food processing plants. NATIONAL POLLUTANT DISCHARGE ELIMINATION SYSTEM APPLICATION FOR PERMIT TO DISCHARGE WASTEWATER "FORM APPROVED OMB Noo 158-I~0100 FOR AGENCY USE STANDARD FORM C - MANUFACTURING AND COMMERCIAL SECTION I. APPLICANT AND FACILITY DESCRIPTION Unless otherwise specified on this form all items are to be completed. If ar, item is not applicable indicate 'NA.' ADDITIONAL INSTRUCTIONS FOR SELECTED ITEMS APPEAR IN SEPARATE INSTRUCTION BOOKLET AS INDICATED. REFER TO BOOKLET BEFORE FILLING OUT THESE ITEMS. Please Print or Type Exxon 1. legal ,Name of Applicant uorpora~i on (see Instructions) Mailing Address of Applicant (see Instructions) P. 0, Box 120 Number & Street City Denver State Col orado zip Code 80201 Applicant's Authorized Agent (see instructions) Name and' Title Number & Street Address City State ZIp Code Telephone Gene D. Thompson Division Drillin9 Manager P. 0. Box 120 'Denver Colorado 802O1 Area 4. Previous Application Code If a previous application for a National or Federal discharge per- mit has been made, give the date of application. Use numeric designation for date, 303 761-6470, Ext. 346 Number ' ,,lilt 9 R 1975 I certify that I am familiar with the information contained In this application and that to the best of my knowledge and belief ,;u¢~ irlf;)r;,hit,ou Is true, complete, and accurate. P. F. Sollars Printed Name of Person Signing ORI'GINA£ p Signature of Applicant or Authorized Agent Western Exploration Division Manager Title 75 7 23 Y R ...J/tO DAY Date Application Signed 18 U.S.C. Section 1001 provides that: Whoever, in any matter within the jurisdiction of any department or agency of the United States knowingly and wilfully falsifies, conceals or . covers up by any trick, scheme, or device a material fact, or makes any false, fictitious or fraudulent statement or representation, or makes or uses any false writing or document knowing same to contain any false, fictitious or fraudulent statement or entry, shall be fined not more than $10,000 or imprisoned not more than five years, or both. DAY m m m FOR AGENCY USE " '".'. "' ':. : ' :'..'. : '. OFF}CE: .... J. EPA ~e¢on ~tin'}ber ...... . ..... .. .. . . · .... This section contains 3 pa~es. EPA Form 7550-23 (7-73) Facility/Activity (see instructions) Give the name, ownership, and physical location of the plant or otl3er oPerating facility where dis- charge(s) does or will occur. Name Ownership (Public, Private or Both PuDlic and Private) Check block if Federal Facility and give GSA Inventory Control Number Location Street & Number City County State Nature of Business State the nature of the business conducted at the plant or operating facility. Facility Intake Water (see instruc- tions) Indicate water intake volume per day by sources. Estimate average volume per day in thousand gallons per day. Municipal or private water system Surface water Groundwater Other* Total Item 7 *if there is intake water from 'other,' specify the source. Facility Water Use Estimate average volume per day in thousand gallons per day for the following types of water usage at the facility, (see instructions) Noncontact cooling water Boiler feed water . Process water (including contact cooling water) Sanitary water Other* Total Item 8 *If there are discharges to 'other,' specify. If there is 'Sanitary' water use, give the number of people served. EPA Form 7550-23 (7-73) FOR AGENCY USE Exxon #1 Alaska State "A" Drillinq Location []PUS []pRv []Bpp [] FED 2982' EWL & 1542' NSL~ Sec. 27-TlON-R24E North Slope Alaska Wildcat drilling location in search of undiscovered hydrocarbons. AGENCY USE 3O 15 45 thousand gallons per day thousand gallons per day thousand gallons per day thousand gallons per day thousand gallons per day Estimate of runoff water entering reserve pit. 1.0 9,0 thousand gallons per day thousand gallons per day 3.0 22.0 35.0 thousand gallons per day tl3ousand gallons per day thousand gallons per day thousand gallons per day 9,000 GPD are used for rig washdown and drilling mud - makedp, ~-d--[~';-1]O'D'"' L~PU in Clf6-f-f6-s-~f-~-a-l~--~'-fl-T2-tion uni~ people served I-2 All Facility Discharges and other Losses; Number and DischarcJe (see instructions) Volume Specify the number of discharge points and the volume of water discharged or lost from the facility accorcling to the categories below. Estimate average volume per day in thousand gallons per day. Surface Water Sanitary wastewater transport system Storm water transport system Combined sanitary and storm water transport system Surface Impoundment with no effluent Underground percolation Well Injection Waste acceptance firm Evaporation Consumption Other* Facility discharges anti volume Total Item 9. *If there are discharges to 'other,' specify. Number of Discharge Points 2 1 1 * Water Total Volume Used or Discharged, Thousand Gal/Day 17.2 FORM APPROVED OMB Noo 158--R0100 FOR AGENCY USE 45.0 lost to wellbore while drillin9. 10. Permits, Licenses and Applications List all existing,' pending or denied permits, licenses and applications related to discharges from this facility (see instructions). Issuing Agency For Agency Use Type of Permit Date Date Date I E'xpiration or License ID Number Filed Issued Denied Date YR/MO/DA YR/MO/DA YR/MO/DAI YR/MO/DA i.::' "."': ::" 'm .'.. .." · (~"' ':'::"'"". :' "': ": ~ .: :?:.::':: ::':;:'~ '.:'. :' :'.' .:'..~dr: ::' ~.;:'. .... ~'" ..'.¥: '~-~ ::' :.':.:.":. '. '.'.'.:'~.:. '. :m:" ::.'::.' '/:: ~..'.: ::.::. ~' '~i .'. '~ :' :.:. ! ~.:':.:''.. . .i.:m:~': ..:.: !'.: :' _State of " . .... .. Permit to 74-14 74-2-27 74-3-11 · Alaska ' ... Drill Dept. of Sewage & 75-2-5 -Environ. . ....... ~uL~ble - Cons. Water Unil'.s - 75-3-4 75-5-6 ~Dept' of .... Permit to AQC-370 75-3-4 75-6-4 75-7-31 Environ. ' ...... Cons. I ...... Open Burn I. 2. 3. 11. Maps and Drawings Attach all.required maps and drawings to the back of this appllcation.(see Instructions) 12. Additional Information !i~i~ ~::i:! Item Number. 8 Information 1, O~O00 GPD net discrepancy reflects runoff water intake not used for. any process. 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POST OFFICE BOX 120 · DENVER, COLORADO 80201 EXPLORATION WESTERN DIVISION GENE D THOMPSON DRILLING MANAGER July 22, 1975 Mr. Gene Dickinson, Director United States Environmental Protection Agency Room G-66, 605 W. 4th Avenue Anchorage,,Alaska 99501 --1 I- ---[ ~'~b~.oL "[ ...... _J .... 1 ....... f CONFER: Dear Mr. Dickinson' Re: Flaxman Island Sump Water Discharge into Beaufort Sea As requested by your office on July 16, 1975, we are sending you the following information regarding the subject discharge. During the period from June 25, 1975, to July 7, 1975, approximately 12,960 barrelS of Surplus water were discharged into the Beaufort Sea from the sump of our Exxon #1 Alaska State "A" wildcat location at 2982' EWL and 1542' NSL of Section 27-TlON-R24E, North Slope, Alaska. The site is on Flaxman Island which is approximately 60 miles east of Deadhorse, Alaska, and approximately 4 miles offshore in the Beaufort Sea. The subject discharge was a mixture of runoff water, introduced by spring thaw, and drilling rig effluent water. The charaCteristics of the water were reported to Mr. Ray Morris on July 16, 1975, and are shown in Attachment I. We have, on occasion, used water from a nearby lake and found the chloride content to be 1300 ppm, which compares with that in the discharged effluent. Sump water has been reused extensively for drilling fluid makeup from the beginning of breakup; however, the runoff water .influx around the location is significantly more than the rig use and the resultant buildup occurred. The dischargewas required when the sump volume approached a limit which'Exxon felt would not allow enough reserve capacity to render it useful as a first defense against a flow from the drilling well and/or a possible Oil spill. Mr. O. K. Gilbreth, DireCtor, Department of Natural Resources, Division of Oil and Gas, State of Alaska, has been kept current on Exxon's operations at Flaxman Island during this critical phase while drilling across breakup. As we discussed, Exxon's present drilling operations may extend into September, 1975. We are, however, evaluating alternate methods for effluent A DIVISION OF EXXON CORPORATION ','~r. Gene Dickinson, Direc?~ United States Environmeni~ ?rotection Agency Page 2 July 22, 1975 disposal and it will not be necessary to discharge into the Beaufort Sea again. If an unforeseen emergency should require immediate attention, your office will be contacted and Exxon will act in accordance with EPA direction. In accordance with your request, we are submitting NPDES, Application for Permit to Discharge Waste Water. We are also submitting a preliminary Section II, Basic Discharge Description, report. Laboratory analysis of the chemical composition of the discharged waste water should be completed by August 1, at which time we will furnish your office with a copy. Exxon has requested permission from the Alaska Department of Natural Resources to dispose of future runoff and waste water between the 9-5/8" x 13-3/8" casing annulus. The 9-5/8" protection casing was run and cemented in the Flaxman wildcat on July 18, 1975. This installation will now permit disposal of waste water into salt water sands below the surface casing set at 3375'. Pumping equipment is on standby to perform this routine operation and will be used to keep the reserve pit pumped down and maintain the necessary storage capacity in the event of an emergency, as outlined in our Summer Operations and Contingency Plan attached. If you desire additional information or would like to discuss this matter further, please do not hesitate to contact the undersigned at telephone numbers 303-761-5686 (office) or 303-758-1991Ve~ours~_(h~m_e). ~ GDT/RS:mg ~ Attachments ~. cc: Mr. Ernest W. Mueller w/attach. ~ . Mr. O. K. Gilbreth w/attach.,im~j~ Mr. John Janssen w/attach. ~-'I.~m~~_ ATTACHMENT I CHARACTERISTICS OF WATER AT EXXON #1 ALASKA STATE "A" DISCHARGED INTO BEAUFORT SEA Total Suspended Sol ids Total Dissolved or Emulsified Oil 0.1% or less (Centrifuge) None (Retort Anal ys i s ) CHLORIDES CONTENT DATE TITRATION (ppm) 6/25/75 2400 6/26/75 2400 6/27/75 2400 6/28/75 2300 6/29/75 2300 6/30/75 2350 7/1/75 2000 DATE TITRATION (ppm) 7/2/75 1950 7/3/75 1700 7/4/75 1600 7/5/75 1300 7/6/75 1300 ,. 7/7/75 1300 NOTE' Pump suction was positioned below fluid level such that there were no oil or drilling muds pumped out of the reserve pit to the Beaufort Sea. RS :mg 7/16/75 1~, .tm No. STATE OF~i -ASKA ,{ ~- OIL AND GAS CONSERVATION CO,~EE ~ 5~-089-20003 &ND WO2KOV~R OP~RAJ}~3 ADL-47556 . o:~ ~ "*' ~ Wildcat 2. N.~_M.~ OF OP~---~kTOi~ Exxon Corporati on 3 A. DDP~KS:S OF OP~TO~ P.O. Box 120 Denver,. Colora.do 80201 4 ~C~ON OF W~ 2982' of ~ line and ]542' N of S L~ne Sec. 27, T10N, R24E, U.P.N. State of A1 aska , 74-14 13 I~E~O.~T TOT~.L D~iw~I I~T F.~JD OF ~[O.~'TE{. CH.&NGF..~ IN' HOLE SIZE, CAS1NG AND C~..4T.~TZNG JO~S IN'ZLI2DI.~:G DE'PTH SET A~,-D VOLU'~I-I~ USED. PIKFII~'OP. ATIONS. 'I-rZ-SS'S .~'~-D R&,SB'LTS FISE.IIN'G JO~'~8 JU~'K IN ~IOI-~ ANE)SIDE-T~I. ACKEZ)HOLE A.N'D A.~x;Y OTi-EK~ SIGNIFICANT C'f~4_.~G~.~ KN HOL~ CON-DiTI,DNS 6-1-75 to 6-6-75 Drilled from ]2,048 to 12,427 whi]e raising mud rate 10.0 to ]1.4 lbs. per ga]. · 6-6-75 Cut core #4 from 12,427 to 12,463. Encountered abnormal pressure zone as mud was gas cut. Shut in well and recorded 200 PSI on drill pipe and 430 PSI on casing Raised mud weight to 12.0 lbs. per gal. · 6-7-75 to 6-10-75 Circulated and conditioned mud through core barrel off bottom. Separated low volume of gas through mud gas separator with small amount of free oil off mud pit. Ran Schlumberger temperature at collar log through drill pipe and determined no sub-surface flow between zones. 6-10-75 to 6-23-75 Circulating and conditioning mud from 12.0 to 13.3 lbs. per gal. Maximum percautions were rigidly followed to insure safety to men and well. On 6-18-75 a State Oil and Gas and Exxon meeting was held in Anchorage between Mr. O. K. Gilbreth, Director, State of Alaska Division of Oil and Gas, Mr. P. F. Sollars, Exxon Division Exploration Manager, and Mr. G. D. Thompson, Exxon Drilling Manager. The State was advised that Exxon had encountered abnormal pressures at approximate same depth as near by wildcat and that Exxon was maintaining full control in the manner of a prudent operator. A weekly report system to Mr. Gilbreth was established. 6-23-75 Spotted 250 barrels of 16.0 lbs. per gal. mud cushion on bottom from 12,350 to 11,2~'0 and trippe to recover core. Cut 36 feet with full recovery. Continued on Page 2 / l~ I .~.e.'eb:, ce~.'~y t~t the £Ck~.k"~...4fzue ~ ~ m~-. U ~ U :- Inompson s,c-,~~ ~ /'~-~¢'~"~/~-~ Exxon Drilling Mana,er . r,~ July.1 1975 ' ~? ............. .' : - ". '-:=-~'-7- - - - ....... --~ ................... / CONFIOmTI / OIL AND GAS CONSERVATION CO~WClTI'EE 1. ~.LL ~ o~. Wildcat 5 AP[ NUME~IC;~L CC, DE 50-089-20003 ADL-47556 NA 2. lx'A_ME OF [xxon Corporati on 3 ~iDD~F~S$ OF P.0. Box ]20 Denver, Col ora[do 80201 ¢ LOC~qON OF 2982' of W line and 1542' N of S Line Sec. 27, T10N, R24E, U.P.M. State of Alaska 9 WE~ NO Exxon No. 1 Alaska gtat~ "A" Wildcat I: SEC T.. R..%,I (BO'i'TG,%! HOLE O BJ'~'_,C~ r,4-F.,) Sec. 27, TI0N, R24E, 12 P~MIT ~'O 74-]4 P.]~3>O.~? TOTAL D~-oTI-! P~T E~N'D OF MON~. CH~NGF3 Z~' HOLE SIZE. CASING AND C~tF~TfP;C¢ JO~S INCLUDING DE~H SET AN~ VOL~ USED. F~OP-~TIO'NS, ~STS ?~%--D ~SULTS FiSHIN'G JO~ JUNK [~' HO~E AND SIDE-~.ACKED HOLE ~%'D ~%*Y O~R SIGNIFICANT ~;G~ ~ ~qO~ CON~[TI,DNS Page.. 2 6-24-75 to 6-26-75 Tripped in hole with rock bit to condition mud. Spotted 135 barrel..,~19 LB per ga%,,/ bari te pill #1 from 12,350 to 11,800 ft. with 185 b~k~els of 17 lb. per(3_9ff. cushion 'abo~e. Pulled out of hole, rigged up Schlumberger and raB~'BI~ sonic, density-neUtron, and dip-meter log from 12,295 to casing at 3375 ft. k_~', ...... 6-26-75 to 6-30-75 Trip in hole and conditioned mud. Spotted barite pill #2 of 235 barrels of 20 lbs. per gal. slurry from 11,585 to 10,835. Now cutting mud weight back from 13.3 to 12.8 lbs. per gal. and conditioning hole to run 9 5/8" casing to approximately 11,400 feet. ,-.~.~:4,.~, ,:~-~ .~r~~.,=~ ~'~ ~. Mr. G. D. Thompson h form ~3 u~r~d ~ac~ colander n~n~h~re~or~ f the ~tntu~n~ o~rat ond O1t o~d CONFIBENTIAE :,,=~ .-,-o p--4 STATE O~ ~'MSKA .~'--'V.o~ - I - 70 OIL AND GAS CONSERVATION COtv~\I-FI'EE SL;P..M[T L~' DUF'L[CftTE =~-- ~,_~ ~ o~._, Wildcat qON FIDENTIAL , 50-089-20003 I.~iASig D--~'3iG.M.:xT'IO.X .-\ND SERiAl. ~O ADL-47556 IF I.x;DiA,~I ALOTTEE. OR TRIBE NA Exxon Corporation 3 A.DDP. E.q$ OF P.O. Box 120 Denver,_Color~do 80201 4 LOCATION OF W?r.L 2982' of W line and 1542' N of S Line Sec. 27, T1ON, R24E, U.P.M. C-NiT F.-'~R.M O?l i,EASE State of Alaska Exxon No. 1 .~!aska Stat~ "A" 10 5'£~D .~D POOL°. L)~ ~Vii,OC~T Wildcat Sec. 27, TION, R24E, UPH 1~ P~o,a~,IIT NO 74-14 · -~ "mq ~OJ,g SIZE. CA..q. ING AND C]?,[E'2'~'F~'?fC, JO~.$ INCLUDING DE~ 13. ~.=__~T TC)T.~ D~I ~kT ~2JD O~ ~.iON'~{. C,.[~,N~..~ SET A~ VOL~ US~ P~-OP~TIO'NS. ~,STS ~-%~ KESULTS FZSHI'hrG JO~ JUNK IN HOLE AND SIDE-TR. ACKED ~%'D ~%'Y 0~ SIGNIFIC~T ~TO~ ~ I~O~ CON~iTI'DNS Report for Period 5-1-75 to 5-31-75 Drilled from 7,775' to 12,048' 5-15-75 Cut core #1 from 10,213' to lO 273' 60' cut 60' recovered 5-18,75 Cut core #2 from 10,645' to 10,671' 26' cut, 26' recovered' 5-20-75 Cut core #3 from lO,701' to 10,761' 60' cut 60' recovered On 5-2-75 and on 5-28-75 tested Ram BOP, choke manifold and lines to 5,000 p.s.i, and 300 p.s.i. Tested Hydril to 300 p.s.i, and 3,750 p.s i. g'/9 ON~ 110 ~t0 NOiglAIiI NflP i ~'e- b ,' c~ t_b~xt, tho fore~.oLng k~ t~f~'~a corr,ec-t ; :' ....... ..... c . ........ , .... CONFIDENTIAL Form 5,'o. P---4 IL..'rV. ~- 1-70 ,I,' STATE O~{. .~SKA OIL AND GAS CONSERVATION CO/V~I~EE $';B,%I1-F L~; gL?LIC/LTE MONTHLY R;.POR? OF DRILLING AND WORKOVER UP;RATIONS 1. o,~ .~ G,, i~ Wildcat 'Pt i:LL ~ ~J;LL ,..--.., OTH~I~ 2. NA.ME OF Exxon Corporation ADDRESS OF OP~R~.TOR P.O. Box 120 Denver~ Colorado 80201 LOCAT/ON OF W~J3- 2982' E of W line and ]542' N of S kine Sec. 27, TION, R24E, U.P.M. 50-089-20003 L-?~&$E DESiGI~A%'ION AND S~I,~L ~O ADL-47556 iF INDiA~ A~'/~E O~ TRIBE ~E NA State of Alaska ~ wz~O[xxon No. ] Alaska 5tare "A" W~]dcat 1~ SEC. T,. C0NFIDmTIAL Sec 10N, R24E 74-14 SET A-~q~) VOLLq~'I'ES L'S~ PE~O~TIO~S. ~-SYS ~--O R}ZSUL~ FIS}{I;~iG JO~ ,II~K LN' HOI.~ AND SIDE-~.ACKED HOLE ~'D ~Y O~R SIGNIFIC~T ~~ ~ ~O~ OO~ITIONS Monthls Report For April 1975 4-I to 4-7 Opened 17 1/2" hole to 26" hole from 85' to 824'. Ran and cemented 20 joints of 20" 94~ p.f. H-40 casing at 824' using a total of 2400 sacks of permafrost cement. Obtained full neturns with 100% excess. 4-7 to 4-9 Nippled up 20" Hydril 3000 ~ diverter system. 4-9 to 4-13 Drilled 17 1/2" hole from 824' to 3378'. Ran Schlumberger DILSP log 3378' to 824 Ran integrated Sonic-Gamma Ray log ro~ 3378' to 824' and Gamma Ray log from 824' to surface. 4-13 to 4-19 Ran and cemented 89 joints of 13 3/.8" N-8(~72# p.f. casing with 3100 sacks of permafrost and 250 sacks of Class G cement. Obtained full returns. Nippled up three 13 3/8" 5000# working pressure ram preventers and one 13 3/8" Hydril BOP. John C. Miller inspected BOP test. Tested 13 3/8" casing to 3000 p.s.i. 4-19 to 4-30 Drilled 20' to 3398' and tested casing seat to 13.5# per gal. mud weight equivilant. Held ok. Drilled from 3398' to 8026'. Operations at end of month' Drilling 12 1/4" hole with 10# water base mud. ~" ~' r y~ ...... ,~_~.~ ............ - ~-_ ~ - _ .~ ..... ~ :__~__~: ~ _ NOTE --Report on this term i~ req,~lred for each colander ~nth~ regordles~ of the mtotus of ooermtiens, a~d must ~ filed lo duplicate with fha oil and gas conm~r~atlon / 02-001B (REV, 08-73) MEMO TO: FROM: RANDUM DEPARTMENT OF NATURAL RESOURCES ~ Diiis.ion of Oil :and Gas~/'. ....... O.K. Gtlb~th, Jr.' J~l~~~ Director ~ Hoyl e H. Hamil ton -¢¢///~-. ,. Chief Petroleum Engin~ John. C. Miller ~C ~ Petrol e~ Engineer~' : ....... State of Alaska DATE: FILE NO: April 23, 1975 TELEPHONE NO: . . SUBJECT: Field Trip Report - BOPE Tests,.-. on Arco - W. Sak River State No, 6,.. and Exxon - Alaska State "A" No.., ]. North Slope., m m ...... ~ m~'[~ M~'~ ~M mm m I m~ m I Im ' ':-. April 15, 19.75 -I ~aveled..t~..,the North slope ..t~.. test blowout: preventer equi'p-',!i.i!il;,iii~!:".:.",:''' '.! · ..... · ::_ ~nt and.. inspect d~lling operations, at the captioned., exploratory wells .... .,I .- T...:~left. Anc~ge by c~ri'ca,l.., ai~raft at ,1:45, PM and -landed.at~ Deadhorse at ..... - 4:30. PM..c.:I caught:;the Arco bus ,to their.O~raUons. Center'... Bud Fuller,. an .. Arco:.log 'analyst:,:from~..Dal. las..and I we~. flo~:...in Arco.~.Sl Twin. Ot~r~ to the fCe m:~:~]].]~';"~'~"~:?;',~]~',',;' :.:-~ .~. airstrip that se~es;both:,No~.3 and. No.. 6 West Sak River State wells .... Vehicles...,~::....~.~.~ .... frm bo~-wells ~t.~.~e.,plane~,~..~ud.~nt to No..3 and I..~nt to.Roan Rig No..., 26..?'t~.~]]:;~ ~] p,she~ i~ ~pby"s office ~e ,~$s~ed..br~e~y, .~en [ a~e. suppe~ and. ...... was ~signed a ~. After:.supper I went to the rig. Dowe:l.1 was finishing a.'r :~,,~' :.- top' c~nt job on the 9-5/8". su~ace, casing... The BOP, s had b~.n set.. in place ..... ...~. They we~ p'~paring to cut of%.:the casing and nipple up ..... ..~ ...... r . I took a tour a~und the location. All operations were on the g?vel pad which was pretty clean.' The~ was a large, deep,, well diked ~serve p~t, a diked test' · .~ ~.?;?~:.,~.,~,~m~,?..' ~..:.~'. pi t,~.~.aad.~'~.m~.: di ked:~ :l ag~m. wh i ch..., caught:: ef~l uent,:>~fr~., the s~a ge. trea ~en t pl ant.. '"~ .... ~': m'Two"la~rge, rectangular` steel. welded, diesel fuei..'.tanks were in.a. diked dep~ssion. I saw howell si .. · .. Nippling up continued through ,the night and earl~ mo~.ing.~ ... _ April 16, 1975' At ll:30 ~. the t~l pusher announced .that all external leaks ...... -. ?. had been StoPPed and that,they we.~ ready to .test.. A test plug had been. set · ' in ~e. drilling s~ol,.. The blind rams were closed and the .outside choke, mani-:... ..... · .. fold valves we~ c)osed. P~ssure a't 3000 psig was applied though the kill ".. line, using' mud and' ~he mud p~ps. to the blind r~, choke line, and choke .m,~.-.,~:~,:.... ml m ~nifold.;.m. There:were ho,leaks.,. Each choke manifold valve, the ~nual. adjust- ,' :'~'+"r~.;~. valve, we~- successfully testedat 3000 psig .... ~:,~...inside. choke line valve heldm m .~,...~ ' 2500 psig. but when.' pressur~ ,,to 3000 psig it:bled down~, to zero ..in 3 minutes, m I ' ~e valve was ope~ted several,.~...~ti~s.~ g~as~,;.and.~t~ted:with ,no improvement,:%?~ Carl Robison called around and.]oca.~d ano~er:3 inch.,, 5~O,.:.pound ~anged at' the Arco Prudhoe Bay hangar.,m..::.The Arco Twin Otter', left the rig ai~tr, ip i~diately to get the replace~nt.,.valve..Testing other components, continued']',: "~ The blind ra~ were,, opened '.':. a,~ joint of. drillJpipe was 'sc~d .. into the test plug. and the pipe' r~s we~.'closed ...... The pi~ rams.~ tested wi~out leaking -'..,~ .... .. at 30~ psig. ' The hydril was"cl'osed and successful, ly tested at 1500 psig. The .... · drill pipe joint was r~ved leaving the test plug in.' placem for-testing the 3" .. replac~nt valve,;t~ The kell.~:.was pic~d up and a test', connection was. installed ~~m~ m on the botts.. The'lower kelly, valve and then~the ~,l,ly. cock we~, each saris-, . ,l ...~ ' 2~ factorily tested at 3000 psig. trols and the remote controls. the open position. ..... The BOP's were Operated with the main con- The floor valves were operated and left in At 6:45 PM the 3" valve, arrived by air from Prudhoe. Removal of the leaky valve was already in progress.. Replacement was completed at 12-30 AM. This valve was tested at 3200 psig. without leaking. All testing was com- plete at t2:45 AM. ~pril 17. 1975- I completed a ."Field Inspection Report" indicating that all items were satisf~ctor~ except that the well sign was missing and must be"'in- stalled-, I left a copy of the report at the-rig .with Carl Robison. mailed a copy to Dick iCnowles ,::. Arco District Drilling Engineer in. Anchorage,. and a copy is attached.. ,~.,-- , ...... ...~ ,'~;,LAt 7:30 AM I ca)led,~..Gordon Ash~ood. Exxon drtl~ling foreman,, at the. Alaska State "A." ~1o.. I exploratory drl. lltng well on Flaxman Island. He said they were. ntppltng,~ up their blowout preventer equipment and would be. ready to start testtng,.in several,' hours,...:~,.., I told him, I'd,. be there, soon and made the necessary . , .,, - ,. . , ]:'!" ! left'the Arco-~est Sak. Rtver State No.. 6 ~e~l with a mud logger at 8:25 Ne drove by West ~k:'£i. ver'~State No.33 for. so~a out§oing people and. then. to the airstrip.. The. Arco Twin O~er delivered us to Deadhorse. ! found. ~he Exxon expediter and, after.'a l-]/2 hour wait, left fo~ Flax~an !sland in an Exxon. contrac~ Twin: Otter.. with three Baroid' mud loggers, and a load o~ supplies.. W~ st~pped at A~co"s Prudhoe Bay airfield for fuel, then. continued on t:o the Exxo~ Flaxn~n !sland a~rstrip adjacent to Nabors No, ~ rig and ca=p. Ne arrived a~ l1:55. AH'... assigned al ' Imom. I took a tour' around the area to check out drilling operations, the camp. and nippling up progress.. The island is' quite large compared, to the size of the drilling pad. The island elevation where the rig' is setting is about Il feet above sea level plus. five feet of gravel pad on the. tundra.. Water. is deep enough,on, the north, seaward side, to accomodate supply barges in the summer,. The reserve pit, flare pit,~ sewage lagoon,, and fuel supply pits were ~well diked. The diesel fuel oil .is. now contained in five 2400 gallon steel welded tanks amd two partially filled 50,000 gallon pillow tanks. They will add three 30,000 gallo~ steel~.welded tanks from Ex,on - Canning River "B" Well, making a total capacity of 310,000 gallons. One pillow tank is in a small pit which is' being.lined with a thin impermeable lining. This pit is connected by a.truck access ~.~ through the dike to a large, adjacent .lined pit which, will contain~..'alt othe~ fuel tanks. They plan to.~empty the pillow tanks first and not refill:'? them, Exxon's "Plan of Operations" dated 2/26/74 attached 'to for~ lO-401 "Pemit to Drill. or Deepen". states "All fuel will be stored welded, steel tanks located in .the impermeably lined fuel pit, which has a capacity of 40% over the to. tal..:volume of fuel iStore(~"'-' ': I. see no problem' with the operation.with both pits. l.'.Ined.~ if the lining is strong enough, unless Division of Lands objects, ~....The camp utilizes a sewage treatment plant. All operations were on the pad.., and. housekeeping was satisfactory. There was no well sign. Exxon is using a technique on the ~ell borrowed from the' Canadian Arctic operators. They installed 60' of refrigerated and insulated conductor. The pipe is 36" OD and 28" ID. Its intended to prevent melting the perma- frost with the~ warm drilling fluids. See attached Schematic drawing.. April 18, 1975 - Gordon called me at 6:30 AM to start testing. The BOP stack, starting at the bottom, was casing head, spool with valved outlet, pipe rams.. blind rams, spool with outlets for kill line and choke line, pipe rams, and hydril on top. The choke manifold was in a separate heated metal building near the rig. Three flow lines went from the choke, manifold building to the burn pit. and were also valve~ to route well effluent back through a degasser before going' to the pit. For testings. Exxon used a small high pressure pneu- matic piston pump. Water was used when testing BOP's and diesel for the choke manifold, t~,hem ! arrived at the.. rig floor the.~.test plug was screwed onto a special-: pipe: joint, and.' was set in the 13-3/8" casing., head with the top. pipe rarest' closed and:. outside: spool.., outlet valves closed, Pressure was applied between the test plug and pipe rams through aside connection in the: special ..~ pipe joint above.~the~-rig' floor, and out of slots above the.. test plug, Exxon's pal.icy ts to test: BOP'"s?at' a low pressure, say. 200 pstg, before, going to rated . pressure,. This ts':.to insure.BOP's would not leak at.the pressures generally.. encountered with:.:a.?klck'~./... The pipe rams held the. 200 psig but when pressure was. tacreased~the.~::kelly~' valve on.. top of the special pipe. joint leaked, While the. drilltng...,~.crew.,..instal'led another kelly valve I walked, a little way' from the rig to get a better look, at a small., herd of 18 caribou: grazing a couple hundred yards, from the camp.. When I drew near they circled to the other side of' the camp ..... ' " .- i. By 11:30 AM they had tried two other kelly valves and both kelly cocks avail- able on the rig. One rebuilt kelly cock did not leak below 2000 psig, but ali others leaked at lower pressures. A 14al. ltburton valve was used on top of the'. special test joint until it' started to:.'leak, then a bull plug stopped that leak. The top pipe rams. and Outside spool valves were pressured to 5000 psig. The'. pressure leaked down 250. psig, or 5:~, in l0 minutes. The inside spool valves were c)osed (hydraulic.operated valve was on the choke line} and pressured to. 5000 ps. ig, ~ihis: bled down 200 psig., or 4~, in. l0 minutes. The ~dril was closed and pressurecl, to. 5000 psig. This bled down. gSO psig. or 5~. in lO min- utes, The bottom pipe rams were closed, pressured to 5000 psig, and bled slowly as before-r.. ))he toolpusher', Kelly Gaff, made. a.careful 'investigation and found four packing ttuds on the well head leaking..slightly. These wen tightened. The test was repeated without leaking The special pipe~joint was removed leaving the test pl'ug in the 13-3/8" casing:~' head.: ~ The test pump was:.reconnec.ted into the lower spool.. The. 5000 psig test' pressure was applied., between the. test. plug and the closed blind rams... Four ~ore small leaks, ~ were stopped at a flange and three packing studs. Pressure bled down 80 pstg. or 1.6%,,, in. 10 .minutes.. The welder was Still' building the choke manifold' and the toolpusher had sent ~'the plane after~more kelly cocks and kelly, valves' so .testing was..delayed from 5:30 PM until the next'morning. 4. AprFil 19, 1975- The welder finished the choke manifold' at 8:30 AM. The entire new manifold w~s pressured with diesel but it bled off rapidly, The problem valve ,~_s iso!at~d and disassembled. A s:-~ll amount of ice was in the bottom of the valve preventing complete seating of the gate. The valve was warmed with steam before it functioned properly. Each valve in the mani- fold, b~m manual adjustable chokes, the Swaco Super choke, and choke line were satisfactorily tested at 5000 psig. The Swaco choke was closed manually. The Swaco man worked on his equipment for two days and left without adjusting the remote controls. The choke manifold and choke line was left full of diesel.. The tool pusher had his crew connect' the .two kelly valves, flown in the .pre-. vious day, to the test plug and pneumatic pump. One leaked and the oth6r tested satisfactorily at 5000 psig.. The kelly cock from Exxon-Canning River. . . 'IBI'I NOi. I will-be brought here, installed,, and tested at 5000 psig.. A kelly- valve will also..be obtained' and tested, for. a. floor valve.. In the' meantime ...... _ a kelly cock and a kelly floor valve, both which held pressure up to 2000 pstg m ~ ..... without l.eaking-~-will be used....These two vel.yes along with the. other kelly i. .... cock- and four..'kelly~.val..ves, will be sent to. town to be rebuilt .............. . ......... ~ m The remote BOP'" controls' were operated. Time. to open and close BOP's was measured. The floor valves,were checked..Testing' was complete, at. 9:45 I discussed the deficiencies below with Gon~on Ashwood and noted them on mY "Field Inspection Report~. {1) Well sign must be posted.~ {2) Replace kelly cock and kelly floor valve. Test these valves a~ 5000 ps,g, and advise me of the results.. {3) Make Swaco choke remote controls operational. {4) Finish installation of impermeable pit. liner. I left a copy of the report' at the rig with Gordon,~ mailed a copy to Gene Thompson, Exploration Drilling Manager in Exxon's Denver office, a~d a copy is attached.. April 20, 1975 - I boarded Exxon's contract Twin Otter at 8:30 AM for the 30 ~=ii"nute'-f)i~ht to Deadhorseo Although on stand-by,. I was able to depart Deadhorse on-the 10:30 AM' Wi. en:commercia.1 flight to Anchorage arriving at 12:45 PM. On April 24, 1975, Dick Moore, Exxon drilling, foreman, on Flaxman Island, advised me by' phone that they had received the kelly cock from Exxon - Canning River No. 1, The valve was installed and tested at 5000 psig without leaking. The Swaco. choke remote controls had been fixed and were operating properly.. The. well si gm. had been ordered. lin SUI~, I visited two exploratory dr, Il'lng wells on the North Slope; Arco - West Sak River State. No... 6 and Exxon - Alaska State "A" lto.. 1. I tested blowout preventer-eq, uipment~ and checked drilling operations on both wells~ At Arco's well all items, were' satisfactory except ..the well sign which was missing'--..~,. and must be posted. Exxon had the.following deficiencies: (1) Missing well sign must be posted,'' {2) Kelly cock amd kelly floor valve must be. replaced, satisfactorily'tested at 5000 psig and this' office advised of the test. results'. {3) Make Swaco choke remote, controls operational and (4) Complete install,at, on. of impermeable pit liner-in small fuel pit. The kelly cock and Swaco... choke deficiencies' have s:bsequently been corrected.~ Attachments Jr.:be iPEFRL ~ ERA c6 SCHEIv]~ TIC · O UC TOR TO ~IP£VL:NI ,ii' iL TING 6~ I~ b - I" Glycol I~/8"C~s;~_9 :el P/ 3000' z} -:22-7.{ Alas. ~ nil 'and Gas Conservation Commi,. Field Inspection Report Operator .:, ~..~¥:.~, ,,~., .....,,-~,~,,, Well Name & No. :' , ..... Drilling Permit Number Inspected by ,~,~:¥?~ ~ ,, ,:" ~' //',~' ~ Operator' s Rep. ~: ....... ~' ~ ;~ ~ , .., ~,~, ~:,,,~, ~ ~ ,,.? ~vV;;~.,,~,~,: ,,, ~,.,, Contr. Rig No.. Satisfactory Item Satisfactory Yes No Yes No ( ) ~ 1. Well Sign ¢'O ( ) ( ) ~ 2. Safety ValveS-Floor ,(,Y~ ( ) ( ) (×).;~,~ 3. Safety Valves-Kelly (>:) ( ) ( ) ( ) 4. Safety Valves~Subsurface (>0 ( ) ¢,~) ( ) 5. BOP Closing System ( ),~/~,~(;'( ) (;',) ( ) 6. Remote Controls ~W0 ('~) ( ) ( ) 7. Drillint Spool-outlets (~ ( ) ) 8. Flow Lines (~ ( ) ~( ) 9. Kill Lines ( ) ( ) () () Manifold Chokes Item 11. Manifold Pressure Test 12. BOP Pressure Test 13. Reserve Pit 14. Pit Berm 15. Location Berm 16. Fuel Berm 17. Operations off "Pad" 18. "General ~oUsekeeping'' 19. Abd. Marker in place 20. Water Well covered n~,-~ .'¢o. ~,--4 STATE ~ AI.ASKA L="V. CO N FI B EN TI AL SuBMrT L~ IDL.'PLICAT'~ OIL AND GAS CONSERVATION COMMI1-FEE AP! NL-JiE:~ICAL CODE 50-089-20003 l,~'-t',$E DES:G,'C,k .-'ION AN'D SE!K, I.~L ~'O. ADL-47556 {VIONTHi. Y REPORT OF DRILLING AND WO~IKO¥'~{~ OP.=RATiONS 1. {7 IF I?,IDiA),~ ALO'Ti-Z.E ONTRIBE NAWIE =,:,_~. L_J ,~,.~. ~ o,,,,,Wildcat NA l 2. NA..ME OF OP~--q4%TOi~ I 8 UNIT F.~_RAI air LEAS'" N.~ME Exxon C~rporation State of Alaska 3. A. DDRESS OF OPER.~%TOR P. O. Box 120 Denver, Colorado 80201 4 LOCA~ON OF WEJ..,L 2982' E of W line and 1542' Sec. 27, TION, R24E, U.P.M. N of S Line ~ ~----~ ×o Exxon No. 1 Alaska qtato "A" l0 F/FJ~D ~--%'D F'OOI,. O~{ ~%'Ii,DCAT =_~li 1 dear n szc T. ~ M (aO~OMHO~ 0~~ Vertical 74-14 13. REPORT TOTAL D~-!. AT E2ND OF ,'VION'I-~I, CI-,rt%NGES IN HOLE SIZE CA$1NG AN-D C.EDvI'?..I~TIP;G JO,~.,.q INCLUDING DEP'I"H SET A2~-D VOLLq%fES USED PEP~FOP~ATIONS. "i'F, STS ~..N-D I~E,CULTS FISHING JO~. Jbq~K L'~ HOi/g AND .SIDE-~-R&CKED A..%'D. A_NY OTI-7~iR. SIGNIFICANT CI.-LA. NGIi;S IN t{OL~ COi%,-D!TIONS . Monthly Report for March 1975 $ ..... N .-:' . "',i.'"'N' ' 3-1-75 to 3-14-75 - Rigging up and building winter airstrip ~ ~ ,~.,,,j..~ ~., ? ..... ., ..... 3-15-75 to 3-23-75 - Drilled 40" conductor hole to 56' G.L. Comongod ~Sgh 350 sacks pormafrosg comon~ '~ ........ :~' :'?. r.::~"..~.~ q'' ~, "~ ~'"~ ~pp]ed up 20" Hydr~l and d~verter l~ne ~," ' s ',~'~ ......... . Spud at 4:45 p.m. 3-23-75 3-24-75 to 3-31-75 - Drilled 17½" hole to 800' T.D. Removed 20" Hydril, opening 17½" hole to 26" at 115' (6:00 a.m. 3-31-75) l~,. I hereby ~e~_~y th. at the fore.eo~e ts true a. nd correct s~oh~~,~ </~~< .~ Attorney-In-Fact ~ April 2, !975 CONFI. DENTIAL E)( ON COIVfPANY, U.S.A. POST OFFICE{ BOX 1'!'(' March lO, 1975 State of Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 Gen tl emen' Re: Exxon #1 Alaska State Attached in duplicate is Monthly Report of Drilling and Workover Operations for the subject well. All operational information on the status of this well will be released through the Exxon Western Exploration Division Office in Denver. Please direct your questions or comments to Mr. Gene D. Thompson (303-761-6470 X 3'46) or Mr. J. R. Sprouse (303-761-6470 X 345) or by mail to Mr. G~ne D. Thompson, Exxon Company, U.S.A., P. O. Box 120, Denver, Colorado 802~. Very tr~ Y°urs, ..... m~son RS'bt 3/10/75 A I)IVlSION OF EXXON COFIPORA'FIQN 1975 ]Po~ ~To. P---4 R._~V. $- I-?0 STATE OF' ALASKA OIL AND GAS CONSERVATION COMMITrEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SU'BMrr IN DUPLICATE API NI~.ffERICAL CODE #50-089-20003 LEASE DESiGAIA ~--ION AND SERIAL NO. ADL-47556 1. 7 IF INDiAIJ. ALOT[£E OR TRIBE NAME oi~ ~ °" 7-] o?.- Wildcat NA W~LL ~LL 2, N~E OF OP~TOR 8 L~IT F.~ OR LEASE Exxon Corporation State of Alaska 3. ADDRESS OF OPERATOR 9 WELL .~'O P. 0. Box 120 Denver: Co]or.ado {~020] Exxon #1 Alaska State "A" 4 LOCATION OF WELL l0 FIFJ~D A_ND POOL. OR WILDCkT Wildcat 2982' EWL & 1542' NSL of Sec. 27-T10N-R24E ~ SEC.T..R..~ff.O~C~.~_~ (BO=O~,HO~ Sec. 27-T10N-R24E UPM North Slope, Alaska 12. PEFL~IT NO 74-]4 13,REPORT TOTAL DEPTH AT END OF MONTH, CH~A. NGES IN HOLE SIZE, CASING AND CF~%/LENT!NG JOBS INCLUDING DEPTH SET AlXrD VOLLrlVIES USED, PEH2'OP~TIONS, TF-STS A_ND RESULTS FISHING JOB~ JLa'ArK L~ HOLE AND SIDE-TR.ACKED HOLE AND A/~IY O~-I~R SIGNIFICANT CI-IA_~GES IN HOLE CONDITIONS 2-5-75 Began road clearing operations and location snow clearing. 2-14-75 Road to location open. 2-16-75 Snow cleared from location, working on ice air strip, rigging up. 2-28-75 Ice runway complete, building all weather air strip. Rigging up. 3-7-75 Rigging up 90% complete. All weather air strip 30% complete. CONROEmlAI.. 14. I herebyc~a,~z ~t., I,J~~t the I g ' rue and correct sr~.z~~~J(~"~,~~T,.~. Sr. En§ineer ~ ...... 3/10/75 I( t -/ .................... NOTE --Report on this form is required for each coltndar ~nth~ regardless of the ~to~us of operation~, and ~ust ~ filed in duplicate ~ith the oil and got conlervation commi~ee by the 15th of the nuec~ding month, u~l~ otherwi,~.'~rected. /' DEPARTMENT OF. NATURAL RE$OU~CE~ WILLIAM A. ECAN, Co,ernor DIVISIO,~ OF LANDS, 323 E. 4TH AVE~tUE, A~(CHO)~AGE 99501 ~rch 27, 1974 Exxon Company P.O. P~o:< 440 Anchorage, Alas]~% 99510 Ps: l>IS T~ 74-19 ~LX~on ]>.~o 1 , "" Gentlan~_n: ~e modifications plains sutmmitt~l in your letter dated P~arch lg, 1974, for t2~e plan of operations approved in our letter of ~.'~3rch 22, 1974, are hereby approved. Sincerely, F. J. ~g~l, Director BY:' P~.!ro Denton C~ef, ;~Line~als Section cc: Jay ~strar~, ADF&G George ~bllett, I~ District Office Dale $'~llington, Environmental Conservation Dean ~tion, Water Resources DEPARTMENT OF. NATURAL ~k~rch 22, 1974 ~xon CDr _~mny P.O. Box 440 Anchorage, 3klasP~ 99510 Re: NS LO 74-19 Exxon Ab. 1 klaska State "A" WILLIAM A. EGAN, Covernor DIVISION OF LANDS, 323 E. 4TN AVENUE. ANCH02 Your plan of operations submittal in your letter of ?2zrch 4, 1974, and modified by yol~ letter of ~,~urch 13, 1974, is hereby approved subject to the follo%~hu9 stipulations: 1.~taterial shall be removed only from exposed (d~atered) bars or inactive' (dry) channels of the stream to t~he existing ice or v~ter . level in the stream. 2. After ccmpletion of material removal, mining sites shall be grade~ level %~th .potholes and depressions filled to prevent fish. entrapment. 3. An~ time after April 15, 1974, the use of ground contact veflmicles shall be subject to tenuination within 72 hours of notification by the director. 'l~us, within 72 _hours from notification~ all such vehicles must be parked in summer storage areas and ~he director ,, notified of the location. 4. All operating areas s~hall be maintained and _upon com~.letion of operations left in a condition satisfactory to the Director. ,5. Sincerely, F. J. KEF~AN, Director PEDRO DENTON ~ef, M~er~ Sec6on BY: Pedro Denton Chief, blinera!s Section Free use of material is allowed under the condition tJ~t if well is a dry hole, the material and the fac~ity constructed with the material will revert to the state upon c~letion of operations. If the well is capable of production and permanent and exclusive use of the material is desired, a nk~terial contract shall be obtained from the Division of I~%nds, 323 E. 4th Avenue, Water Resources Section. ~ ...... · ",,'"' ;.?,!,~, ?:, cc: ADP&G, District Ofc., Water Resources, Div. of O&G, T__~_bDr Dept. March II, 1974 Re: Exxon No. I Alaska State Exxon Corporatlon, Operator Permit No. 74-14 Mr. Gene Thompson Exxon Corporat ion P. O. Box 120 Denver, Colorado 80201 Dear Sir: Enclosed is the app.roved application fo'r :permit to d.rlll the above referenced well, on or about April I, 1974, at a location in Section 27, Township ION, Range 24E, U.~. Well samples, core chips and a mud log are required. A directional survey is not required. Many rivers In Alaska and their drainage systems 'have been .classified as important for the spawning or migration of anadromous flsh. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated there-. under (Title 5, Alaska Administrative Code).. Prior to commencing operations you may be contacted by the Habitat Coordtnator"s :office, Oeparfmen. t of Fish and Game.. Pollution of any waters of the State ~ prohibited, by AS 46, Chapter 03, Article 7 and the regulations promulgated thereunder (Title: 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Ac'f, as amended. Prior to commencing operations you may be contacted by a .representative of the Department of Environmental Conservation. I:n ~h.e event of suspension: or abandonment please glve this office, adequate advance notification so that w'e may have a witness present. 'Very truly ¥o.urs, ,. Homer L. Burrell Cha i rman Alaska O! I and C~3s Conservation Committee ,HLB:pj Enclosure cc: Department of E~aa and Game, Ha.bltat Section w/o an:ct. Department of Environmental Conservation w/o anti. Porto I0'-- 401 1R~V. I -- 1--71 (Other instructions% reverse side) STATE OF ALASKA F(~/~a.~$}~. d OIL AND GAS CONSERVATION ,COM IIM'~-~E ii PERMIT TO DRILL OR DEEPEN lie. TYP~ OF WOIeK DRILL b. TYP~ OF WELL OIL r~ OA~ ~] WELL WELL DEEPEN [-1 d c a tzo,.~'"cL' F-I """~'~"',.o,,. Fl NAME OF OPERATOR Exxon Corporation 3. ADDRESS ~ OPEP,.ATOR P. O. Box 120, Denver, Colorado 80201 4. LOCATION OF WELL ^t~ur~a~e 2982' EWL & 1542' NSL Nor'th Slope, Alaska At proposed prod. zone Same of S~c.27-TlON-R24E UPM 13. DISTANCE IN MILES AND DIRECT[ON FROM NEAREST TOWN OR POST OFFICE* APl #50-089-20003 $. 6. LE.~SE DIr!~IGNATION A.N'D S~ NO. ADL 47556 IF IN'DIA.N, ALJ.,O'l-'r~:~: OR TI~LBE N~ NA 8. UNIT~FARM OR LEASE NA. ME State of Alaska 9. WELL NO. ExxonNo.1 Alaska State"A I0. FIELD AND POOL, OR WILDCAT Wildcat rbon I.SEC., T,, R,, M., (BOTTOM HOLE OBJECTIVE Sec.27-T10N-R24E 12. 50 Miles East of Deadhorse '~.(~efl~ I~F°~Pa*~I°6:0 n s e r v a t i o n B o n d T¥~E S,ret~a,d/o~No5134049(State Bond File Ne.B-l-4 ~o,,.~ $100,000 15. DISTANCE FROM PROPOSED*~C~ ~' ~ ~ anL ~ i~.NO. OF ACR~ IN LEASE 17. NO. ACRES ASSIGNED LOCATION TO NEAREST ~ ~ ~ ~ ~ ~ m ' ~ ~ TO ~iS WELL ~o~ o~ ~s~ ~, ~. ~ 7 5 5 7' ~ (Also to nearest drig, unit, ii any) ~ 2560 640 TO NEAREST WELL D~IL~ING, CO~PL~T~. ~ ~ ~ ~[ of ~ob~l ~est StaSheS St. ~ 15,500' Rotarg 21. ELEVATIONS ~Show whether DF, ~T, G~, ete.~ ~. APP~OX, D~TE WORK WILL,STArT 10' aR gpr~l 1, 1974 23. '" PROPOSED CASING AND CEMENTING PROGR~ SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRA]Z~E SETTING DEPTH quantity of cement ~6" ~ 30" "½" Wall ~ LP 60'' +- T.o Surface /:~ ~. _ 26" 20" 94# H-'40 800,+- To SUrface 17½" 13-3/.8',', 72#" N-80 30'00'1~ lo Surfade ~/?, .,:'F,. - 147, SO0-9.~ 12,(J00~' 500' Ablovelp°'tential Hy'dr'oca 12¼" 9 5/,8 !3 '15~3' 5 ' ~,_~87~ I 'Zone .... ,. 8½" 7" 35 S00-95 TD 500' Above Potential H~;'c['f'6-d'hrbon Lone BLOWOUT PREVENTERS 20" Series. 900(3000 psi WP)Hydril with di~:~"~"6"'f"-l"~ will be installed on the 30" & 20" casings. One 13,5/8" Series 1500(5000 psi WP) Hydril and three 13-5/8" Series 1500(5000 psi WP) ram type preventers will be installed on t'he 13-3/8" & 9-5/8" casings., The annular preventer will be pressure tested to 60% of rated working pressUre and the ram-ty.pe preventers will be pressure tested to full working pressure on initial installation on each ca'sipyg string and once weekly thereafter. (Continued on Attached Sheet) IN ABO. V'E/~AL"E Di~I~rC~o~BE ~0~0~~: I' ~.1 Is to dee~.n ',lv, ~ .o, prese,, p~u,ive ZO~ "d pro~ ~ew proa~j~e ~..A_~_~ ~ ~,,~.,a~uL ~ a~n a~ec~onaiiy, give p~r~ent ~ on subsu~a~ ~at~ ~d ,meaa~d ~d ~ue ve~ical~. ~lve mo~ut P~.Ve~mgram., ' 2~-~ h~r~t~, that the Fo~oin~'an& Corre~ ' ' , (This space fo ~~ ~te ~ftee u~) ,, ~ CONDI~ONs OF ~P~V~, IF SAMPL~D CORE CHIPS R~Ui~ [ M,UD LO'G [ ~ ~U~~: ' ~Y m so [ ~Y~ m ~o[ SEE TRANSMITTAL LETTER DI~ION~ SURVEY R~~ A.P.I. ~C~ COD~ (This space Instructions On Reverse Side :TL~DiV!~inn Drilling Mgr. March II, 1974 ' A.PPROV~ DA"r~ Chairman. March II, 1974 E )( ON COMPANY, U.S.A. POST OFFICE BOX 440 · ANCHORAGE, ALAS~<A 99510 EXPLORAIION D E PARTI',~ EN"r March 4, 1974 Re: Exxon No. I Alaska State "A" S.E. 1/4 Section 27, TION, R24E, U.P.M. A.D.L. 47556 Arctic Slope, Alaska Mr. Homer L. Burrell Director, Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Burrell: In accordance with the Oil and Gas Conservation Regulations for the State of Alaska, we s ubmi t herewi th the fol 1 owing: (1) State of Alaska Oil and Gas Conservation'Committee Permit to Drill, Form 10-401 in triplicate. (2) Exxon Check No. 3837 dated February 27, 1974 in the amount of $100 in in payment of the required permit fee. Concurrently with this application we have also filed with the State Division of Lands the following: (1) A plan of operations describi.ng the location construction, rig move and resupply, waste and sewage disposal, pollution prevention and measures which will be taken to prevent erosion. (2) Plats prepared by F.M. Lindsey & Assoc., Land & Hydrographic Surveyors, scale 1"=1 mile and 1"=1000', showing the route of the move over Beaufort Sea shore"ice as well as possible gravel and water sources and existing well location and gravel airstrip (Mikkelsen Bay and Bullen Point). It is our plan, State approval permitting, to commence location work in early April 1974 though actual drilling operations may not be commenced until the winter of 1974- 1975. RKR: jeh CC:w/o enc. Mr. L.A. Dodd w/o enc. Mr. Dorsey Hawkins Yours very truly, Robert K. Riddle for Gene D. Thompson Division Drilling Manager A DIVISION OF EXXON CORPORATION R, 23 E. 3O I I 2O 29 ~2 21 £8 33 R.24 E. ~5 ~2 .~-~ EXXON No. I ALASA STATE "A" 27~" ~" LA'T; = 70° I1' 21.06" LONG. = lZl'6° 00' '~2.41" X = 498~537. Y = 5~918,728 i I 3,~ 35 I I I I t I I R. 25E. TION, T9N. SCALE: I"= IMILE CERTIFICATE OF SURVEYOR I hereby certify that I am properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me or under my supervision, and that all dimensions and other details are correct. Date SURVEYOR EXXON No. I ALASKA STATE '~A" Located in SE I/4 PROTRACTED SEC, 27 TION R 24E UMIAT., MERIDIAN AK_ Surveyed for EXXON COMPANY U.S.A. I I I- Surveyed by F.M. LINDSEY 8[ ASSOC. LAND ~ HYDROGRAPHIC SURVEYORS J2502 West Northern Lights Boulevard Box JAnchoroge Ala?_~a~ Exxon No. 1 Alaska State "A" Section 27-TlON-R24E Continued. All BOP's. will be functionally tested once each day. PERMA-FROST ANNULI PROTECTION PLANS' All permafrost interval will be left with a production is indicated. uncemented casing non-freezing fluid annuli wi thin the if commercial Exxon #1. Alaska State Plan of Operations Location Construction: The gravel drilling site will be approximately 300' x 500' x 5' thick and will require approximately 30,000 cu. yds. of gravel. The gravel will be taken from one or more of the sites shown on the attached map. Gravel'movement will be with rubber-tired belly dumps over ice road and ice (frozen to bottom 5'-6') as shown on the attached map. An all-weather, 4' thick gravel road will be constructed on the island as indicated requiring 14,000cubic yds. of gravel. Pit excavations will consist of a 225' x 150' x 10' deep location sump, 40' x 60' x 6' deep flare pit, 60' x 60' x 6' deep impermeably lined fuel pit, and a 40' x 60' x 6' deep emergency sewage lagoon. All pits will be gravel diked. Excavated topsoil or tundra will be stockpiled and, after backfilling and leveling pits, will be spread over the loca- tion as it is available. State approval permitting, location work will begin in early April, 1974, and will requSre approximately 20 days to complete. Rig Move and Resupply: The rig move Will be over Beaufort Sea shore ice, which will be either frozen to bottom or a.minimum of 5' thick and is planned to take place immediately upon completion of the drill site. Actual drilling opera- tions may. not begin until the winter of:1974-1975. .If all equipment cannot be moved this winter (1974), some stockpiling and equipment movement will be done by barge in July and August, 1974. Rig resupply during winter drilling will be by cats and ~sleds, trucks, and air. Crews will be transported by air. ~ ~ Waste and Sewage Disposal: · . A Met-Pro physical chemical sewage disposal unit, with incinerator, will be installed at the.campsite. Ail combustible wastes will be incinerated. Non-combustible wastes.will be compacted in trash com- pactor and held on location for burial in the reserve pit at time of cleanup. Ail excess drilling fluid, cuttings, etc., will be placed in the location sump. 0ily waste from DST' s, etc., will be piped to the flare pit and burned. Pollution Prevention. All fuel will be stored in welded, steel tanks located in the imperme- ably lined fuel pit, which has a capacity of 40% over the total volume of fuel stored. It is anticipated that any minor pollution will be contained on loca- tion and burned in the flare pit. Measures to Prevent Erosion: The approach onto the island will. be either gravel filled or snow and ice filled, which should prevent erosion. All travel will be over ice~ ice roads, or 42 thick gravel.roads, which should prevent damage to vegetation and erosion. RS/ch 2-26-74 : " Company Lease & Wel 1 No. ,,m~.~,,:~ ~-'--/,~ K,~ ~ '~- / CHECK LIST FOR NEW WELL PERMITS Yes No Remarks · Is well to be located in a defined pool ................. 2. Do statewi de rul es apply ............ 3. 4. 5. ............ ~K Is a registered survey plat attached ................... Is well located proper distance from property line ........... ~x~ Is well located proper distance from other wells ............ ~ 6. Is sufficient undedicated acreage available in this pool ........ ?____~ 7. I s wel 1 to be deviated ......................... //~>~ · Is operator the only affected party ................... ~ Can permit be approved before ten-day Wait ............... ~K lO. Does operator have a bond in force .................... l l. Is conductor string provided .............. . ........ 12. Is enough cement used to circulate on conductor and surface ...... 13. Will cement tie in surface and intermediate or production strings 14. Will cement cover all possible productive horizons ............ 15. Will surface casing cover all fresh water zones ............ ]6. Will surface csg. internal burst equal .5 psi/ft, to next string 17. Will all casing give adequate safety in collapse 'and tension ...... i8. Does BOPE haVe sufficient pressure rating Additional Requirements: ~}~ ~¢ .~_~J~r/ m/~/~