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Ima~roject Well History File le XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. / ?/- _/ _~? Well History File Identifier Organizing ido,,~ X RESCAN Color items: ~h~)~/g2 Grayscale items: Poor Quality Originals: Other: Z~,~J~ p/~/-/~' NOTES: DIGITAL DATA [] Diskettes, No. Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL(~WINDY OVERSIZED (Scannable) D Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) of various kinds Logs [] Other Project Proofing .. ~OBIN VINCENT SHERYL MARIA WINDY BY; Scanning Preparation ? x 30: ~/~ + ~) BY: OBIN Production Scanning Stage VINCENT SHERYL MARIA WINDY Stage 2 BY~ (SCANNING ts COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE SA$1S DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES } PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION' ~ NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BEVERL~ VINCENT SHERYL MARIA WINDY DATE:/-~'-~..~/S' ~'~:) III IIIIIIIIIII II III RESCANNED BY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: IsI General Notes or Comments about this file: Quality Checked 12110/02Rev3NOTScanned.wpd ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES. GOVERNOR 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 Re: Location Clearance Work on Exxon's Alaska State Wells Dear Mr. Gardner: Reference your letter of November 17, 1999 on this subject. Our Petroleum Inspector Lou Grimaldi reported on the September 9, 1999 inspection trip to various Exxon State wells - copy attached. His report of the inspection trip states: "SU .M, MARY.: C! and G2 locations still need some work. Based on my observations, I recommend the Al, D 1, 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. ~ve 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-welts.doc D:'Pics'FlaxmanLFLAXMAN G-2 CELLAR.jpg (local'} - Microsoft Intemet Explorer Page 1 of 1 11,/17/'99 12:21:40 PM D:'xPics',Flaxman'NORTHSTAR F-1 PAD.jpg (local} - Microsoft Intemet Explorer Page 1 of l 11/17;99 12:21:21 PM 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. recommend the Al, D1 and F1 location clearances remain approved. Based on my observations, i 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:~Pics'~laxman'xFLAXMAN C-t VSP.jpg (local) - Microsoft Intemet Explorer Page Iofl 11 17/99 12:21:49 PM D: PicSxFIaxmanLFLAXMAN C-I PIPES.jpg (locai'~ - Microsoft Intemet Explorer Page 1 of l 11 17;99 12:21:57 PM D:X2ics',FlaxmamFLAXMAN C-l Plastic.jpg (local} - Microsoft Intemet Explorer Page 1 of l 11/17/'99 12:23:36 PM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson, Chairman DATE: September 10, 1999 THRU: Blair Wondzell, P. I. Supervisor FROM: Lou Grimaldi, SUBJECT: Petroleum Inspector Location Clearance Insp. Exxon Point Thompson Unit A1 PTD# 74-0014 -- D1 PTD# 80-0101 - G2 PTD# 82-0208 - F 1 PTD# 81-0__~¢.1_4J~ - 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 1 of 2 Alaska State Al: The A1 Location was very clean and although somewhat irregular, smooth enough to pass inspection. 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 G-2 locations still need some work. Based on my observations I recommend the D-l, G2 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.doc Page 2 of 2 Exxon Company, U.S.A. 1999 Remedial Work Completion Report Flaxman Island Area Well Re-Abandonment Project Beaufort Sea, Alaska ~&,~.~ (~,., Summary of Work Completed ~.~,z=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: AOC~C 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. Camp trash 1,800 lb Transported daily to Deadhorse for final disposal at 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, Transported in secure tanks and injected at Pad 3 non-hazardous. 475 bbl facility Diesel contaminated Transported in secure containers to Alaska Interstate gravel 994 yd3 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. AOC_,-CC sup report 99 ~2 COMPANY, U.S.A. POST OFFICE BOX 196601 · ANCHORAGE. ALASKA 99519-6601 · TELEPHONE (907) 561-5331 PRODUCTION DEPARTMENT ALASKA INTEREST _-:,MES 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, Beaufi Sea, Alaska Mr. Robert N. Christenson, Chairman Alaska Oil and Gas Conservation Commissicn 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. DMB:ddm ,/ c:~data\winword~lmb~enviro~pt.tom~federal-state agencies~Robert Chdstenson 4-9-99.doc ,/ / c: Mike Barker, Exxon Jim Haynes, DNR-DOG Jesse Mohrbacher, Fairweather / A DIVISION OF EXXON CORPORATION RECYCLE PLUGGING ~ LOCATION CT_,EAR.~CE REPORT State of Alaska \ '\ ALA~ 0IL & ~ CONSERVATION C0]~fISSION ?..~ ~To. ~/- r'-,,'o Lease /:J'C)L- ,~/'~'~.. _",.,'emcrand'~. To F~ ~ e: £gu. ci: ,((,,,/' f~-r, ~: Nots casir..c size, wt, debt_h, =mt vol, & procedure. -~= c.~_: 20~ ~ ~[~' ~/tr ~ ~ . ,, P. eview ~_e well file, ~ld' C~e!~U 011 plugging, well head s uacus, ~d location c!ear~ce - urcvide loc. clear, code. / I Il' / '~eii head c=~: .: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation COmmission TO: David Johnston~"- DATE: Chairman Blair Wondzell, P. I. Supervisor FROM' Chuck Scheve,~g;[~ SUBJECT: Petroleum Inspector THRU: 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# 81-0.140 C1 'PTD# 80-0046 Monday, August 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 inthe 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 e~tbe 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:TheG2 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-l, C-l, D-l, and G-2. Wells A-l, D-l, and F-1 were re-abandonments. The Commission has previously acknowledged that all 5 wells were properly abandoned. * After a 9/5/84 inspection, on 9/20/84 LC Smith approved "final abandonment" of Exxon's Alaska Sate well D-I * 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'I. 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'I and can make the following comments: * Well A-l: 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-l: 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, 'September 11, 1998 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnston, DATE: Chairman THRU: Blair Wondzeil, ~ FILE NO: P. I. Supervisor FROM: Chuck Scheve,==;~ ~' SUBJECT: Petroleum Inspector August 3, 1998 i99khcfe. DOC Location Clearance insp. Exxon Point Thompson Unit A1 PTD# 740014 D1 PTD# 80-0101 G2 PTD# 82-O208 F1 PTD# 81-O140 C1 PTD# 80-O046 Monday. Auaust 3.1998: i traveled with Rob Dragnich (Exxon), Gary Schuitz (DNR) and Bob Gardner (Fairweather) to inspect Exxon's Al, D1, G2, F1 and C1 locations in the Point Thompson Unit. 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,D1: 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~,~fle- remaining location them 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, g~,l'~ ccj.+-o~ 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~'~w · C~.4- e~ lorn ar ~ ,~ ~ 7- '-).9 Alaska Slate C1: The C1 location has what appears to be a partly open reserve nit 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 REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [ ] Operation shutdown [ ] Stimulate [ ] Plugging [ ] Pull Tubing [ ] Alter Casing [ ] Repair Well 2. Name of Operator EXXON Company, U.S.A. 3. Address P O Box 196601, Anchorage, AK 99519 5. Type of well: [ ] Development [ X ] Exploratory [ ] Stratigraphic [ ] Service 4. Location of well at surface 360' SNL, 1817' EWL, Sec 17, T10N, R23E, UM At top of productive interval 1294' SNL, 1304' WEL, Sec 18, T10N, R23E, UM At effective depth 360' SNL, 1817' EWL, Sec 17, T10N, R23E, UM At total depth 1197' SNL~ 1531' WEL~ Sec 18~ T10N~ R23E~ UM 12. Present well condition summary [ ]Perforate Total depth: measured 14,316' feet true vertical 13,173' feet X ] Other: Re-abandon 16. Datum Elevation (DF or KB) RKB 42 feet 7. Unit or Property Name Alaska State F 8. Well Number Exxon No. 1 9. Permit Number/Approval Number 81-140 10. APl Number 50-089-20019 11. Field/Pool Wildcat Plugs (measured) 13,900'-940', 13,580'-794', 12,815'-890' 12,250'-315', 11,850'-12,008', 55'-1,783' Effective depth: measured Surface feet true vertical feet Junk (measured) None Casing Length Structural 114' Conductor 2,108' Surface 6,901' Intermediate 12,096' Production 13,940' Liner Size Cemented MD TVD 30" Est. 300 sx pf 114' 114' 20" 11,300 sx pf 2,108' 2,108' 13-3/8" 1,700 sx pf, 250 sx G 6,901' 6,898' 9-5~8" 2,500 sx G 12,096 11,312' ,,, ORiE;iN E 12,841' Perforation depth: measured true vertical Tubing (size, grade and measured depth) None 13,874'-13,884', 13, 846'-13,868', 13, 794'-13,830', 12,924'-12,930', 12,890'-12,908', 12,544'-12,590', 12,313'-12,315', 12,052'-12,080', 12,008'-12,027', 1,783' (all squeezed) 12,783'-12,722', 12,759'-12,778', 12,714'-12,745', 11,985'-11,990',11,957'-11,972', 11,671 '-11709', 11,486'-11,488~, 11,277'-11,299', 11,241'-11,256', 1,783' Packers and SSSV (type and measured depth) F-1(~13,900', F-1(~13,590', F-1(~12,825', F-1(~12,330', F-1~11,895' 13. Stimulation or cement squeeze summary None Intervals treated (measured) None Treatment description including volumes used and final pressure None RECEIVED J' L O 1 1998 Alaska 0il & Gas Cons. Commission Anchorage 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. Subsequent to operation Attachments [ ] Copies of Logs and Surveys run None, well was re-abandoned. Status of well clasification as: Abandoned 16. IX] Oil [ ] Gas [ ] Suspended my knowledge Production Manager - Alaska [ ] Daily Report of Well Operations [ X ] Re-abandor,~l{ent report 17. I hereb.~~at the~nd corre~ e. best of Signed'/, ~--,.~--~-'--~2~ ~itle Form 10-40~v. 06/15/88 [] Service Date /Subtnit In Duplicate Summary of Operations Permanent Re-abandonment Exxon Company, U.S.A. Alaska State F-1 Flaxman Island Area, Beaufort Sea, Alaska Exxon Company, U.S.A. (Exxon) drilled the Alaska State F-1 well on North Star Island in the Beaufort Sea in 1981/82. At the completion of drilling and testing operations, the well was plugged downhole and at the surface for final abandonment. Since the mid 1980's, North Star Island and neighboring islands have undergone natural erosion and migration due to wave and storm action. A site inspection at the F-1 well site and three other Flaxman Island area wells (Alaska State A-l, D-1 and G-2) on October 25, 1997 revealed that several of the wells and related appurtenances had either been exposed by erosion or could be in the future. Exxon chose to re-abandon the F-1 well in compliance with current AOGCC abandonment regulations to ensure that the well is not exposed or impacted by future natural erosion of North Star Island. Figure 1 shows the final status of the Alaska State F-1 well. Figure 2 presents the final condition of the well in relation to sea and island level. The F-1 well was re-abandoned as part of a multi-well re-abandonment program that also included the wells Alaska State A-1 and D-1 on Flaxman Island. Final details for the A-1 and D-1 well re-abandonment operations are covered under separate Reports of Sundry Well Operations. The re-abandonment of the F-1 well included the following operations: . Excavation around the F-1 well to 17 feet below ground level and removal of the steel cellar. See Photo 1. . Cut away of the 30, 20, 13-3/8, 9-5/8, and 7 inch casing strings to remove the wellhead. Trimmed up all casing stubs to 17 feet below grade or five (5) feet below the toe of the slope of the island. See Photo 2. . Topped off the upper 18 feet of the 9-5/8 x 7 inch annulus with permafrost cement. Repeated this procedure for the 20 x 13-3/8 inch annulus to 80 to 17 feet below ground level. See Photo 3. . Picked up debris and backfilled the excavation. See Photo 4. Recontoured excavated area with slight mounding of soil over the excavated area to account for summer settling. A magnetometer survey of the F-1 location revealed no evidence of a second 30 inch structural casing on-site. . Final site cleanup and location clearance is scheduled for summer 1998 after snow cover has melted. All scrap steel recovered during the F'I re-abandonment program was sent for recycle. The F-1 wellhead and cemented casings were transferred to the North Slope Borough landfill for disposal. F1-404 06/15/98 NI Depths RKB RKB = 4.2' MLLW Grade -4.' MLLW NI Casings Cut end Removed to 17' BGL or -13' MLLW Permafrost Cement in 13-3/8' x 9-5/8' Annulus to 2,015' Non-freezing Flu. id 10.2 ppg CoCI2 Permafrost Cement in 20' x 15-3/8' Annulus to 1,900' 30" Structural Pipe O 114' F7:5'V Retainer O 520' 20' 133 #/FT K55 BTC Conductor ~ 2,1 Parrs & Bose Cement Plug in 7' Casing {I 1,783' 9.0 ppg Mud Estimated TOC {I 3,400' MD 15-3/8' 72tIl/FT LBO BTC Surface Casing ~ 6,901', Pit 16.5 ppg 15.8 ppg Mud 15.0 ppg Mud Estimated TOCO 9,4.00' TOC ~ 10,340' CBL Estimated TOCO 11,850' 15.6 ppg 15.8 ppg Mud ~ F_.ZSV Retainer @ 11,850' DIL F-1 Packer ~ 11,895' DIL 9-5/8" 4.3.5 & 4.7~/ft PrOtective Casing ~12,098' Parrs ~ 12,008'-027' & 12,052'-080' DIL EZSV Retainer ~ 12,250' DIL Perfs O 12,313'-315' DIL EZSV Retainer ~ 12,320' DIL F-! Packer ~ 12,330' DIL Perfs ~ 12,54~'-590' DIL EZSV Retainer @ 12,815' DIL F- 1 Packer ~ 12,825' DIL LEGEND Cement Mud CaCI2 NO SCALE FAIR/EXXON/EX498 1:1 15.6 ppg Mud-- 15.6 ppg Mud -- 15.9 ppg Mud TD 14-,316' Parrs ~ 12,924-'-930' & 12,890'-908' DIL EZSV Retainer O 13,580' DIL F- 1 Packer ~ 13,590' DIL Perf$ ~ 13,794'-830', 13,84.6'-868', & 13,874'-884.' DIL F-1 Packer ~ 13,900' DIL 7' 35#/ft P110 LTC Production Casing O 13,940' 6/15/98 Figure 1 EXXON Company U.S.A. Alaska State F-1 Wellbore $chemofic, April 1998 North Star Island ~ Sea Ice Surface / x(,/,'¥× I - - ~ ,-..~."':: i' ""," "',." :."". ' ~' ;'." '"."' '.",-. "'.:": :': ~'," '" :,'"'.' ~/"' ; .,~ .... _..o.., .......... ..;...,.. ._ ,- ....... ,. ,_...,...~ ..,. · ,.. . .... :' . ..~ ................ · ... ,.,. t....._. .............. .~ ..::. t ~ .... ,........;;~ ...., .~ ..,,-~..~. :.,.......-,....,::~..,:.~.,-....?:.-~.....~~~..,.,...: ..: ...... -.......~.., ....... . ....... .'.'~".' [ ~ ~__ Seafloor Coast. South I ~-- Island Toe / / ~ F-1 .,Well Cut and Removed / ~fo 17 Below Grade or ~-13' MLLW NO SCALE FAIR/EXXON/EX49BF1 1 ;1 6/1/98 Figure 2 EXXON Company, U.S.A, Alaska State r-1 Location, Elevation View, Looking East North Star Island, Beaufort Sea Photo 3: Top job cement on 20 x 13-3/8 inch annulus. 9-5/8 and 7 inch casings are located inside 13-3/8 inch casing below cement level. 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 to this matter. DMB:ddm Attachment c:~dat a\winword~d mb\enviro~ptt om~undry.doc A DIVISION OF EXXON CORPORATION Sincerely.., ~? RECEIVED ORIGINAL ,,:, 611~gg AJaska 0i~ & Gas Cons. Commission Anchorage RECYCLED E~-x~~ S~~e ~~-( E) ,ON COMPANY, U.S.A. POST OFFICE BOX 60626 · NEW ORLEANS, LOUISIANA 70160-O626 PRODUCTION DEPARTMENT OFFSHORE DIVISION JOHN P. CLEMENT, Itl 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: 81-140, Alaska State F, Exxon No.1. Please refer to the attached form (10-407) for plug and suspension details dated 5/30/82. TVB: j cv Attachment Sincerely, A DIVISION OF EXXON CORPORATION ' - ~ll~l STATE OF ALASKA '' bUl lUl:l lllm_ *' ALASKA ' ~ND GAS CONSERVATION C~ ~,~'~$1ON~ ... WELL COMPLETI ["OR RECOMPLETION AND LOG 'C 1. Status of Well OIL [] GAS I"1 "-"~ .... --=~)J;;~ 2. Name of Operator Exxon Corporal:ion 3. Address Pouch 6601, Anchorage, Ak. ._ Sec. 4. Location of well et surface 360' SNL & 1817' EWL, At Top Producing Interval 1294' SNL & 1304' WEL, At Total Oe~th 1197' SNL & 1531' WEb, ,)(j~/~/{ _, / . Classification of Service Well ABANDONED [~ SERVICE [] 7. Permit Number . 81-140 8. APl Number 99502 __ .;o- 089-20019 J LOt~, iuN _ 9. Unit or Lease N~me 17, T10N-R23E,UM., 'Sud=l YERIFIED Alaska State F 10. Well Numb~ Sec. 18, T10N-R23E, UM~8:H..-~ Exxon No. 1 11. Field and Pool Sec. 18, T10N-R23E, UM Wildcat 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. 42' KB [ ADb 312862 1,3. Date T.D. R,=hed 114. Date Comp., Susp. or Abend. IlS. Water Depth, if offshore I'e."o. o, Date Spudded CompletJonl 11-1-81 . I 4-3-82 I 5-30-62 [ ..NA feetMSL [ 4 14,316' (13173'T~D) Surface [YES~ NOD [ NA ,..,MD [ 1340' (KB) 22. Typ, El~t,ico, Oth~Log, Ru" Dual InductiOn, L6ng Space SoniC, Formatzo~ Density- Neutron, Dipmeter, Velocity Survey 23. ' CASING, LINER AND CEMENTING RECORD I SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" I 310 B 45' "114' - Est 300 sx perma] rost O 20" 133 K55 43' 2108' 26" 11,300 sx ~ermaf DSt 0 13-3/8 72 LB0 41" 6901' 17-1/2' 1750 sx claSs G 0 ' 9-5/8" 47 RS90 39' 12096' 12-1/4 2500 sx class G 0'" 7" 35" Pll0 37' 13940' 8-1/2" 1350 sx claSS G 0 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD " interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD} NA SEE ATTACHMENT 26. ACID, FRACTURE, ~EMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) / & KIND OF MATERIAL USED ·. AMOUNT SEE ATTACHMEIT 27. PRODUCTION TEST Date First Production i Method of Operation (Flowing, gas lift, etc.) FORMATION TESTS ATTAC~ED Date of Test Hours Tested PRODUCTION FORiOIL-BBL G:AS-MCF WATER-BBL I CHOKE SIZE GAS-OIL RATIO TESTPERIOD e! Flow Tubing Casing Pressure CALCULATED gab J OIL-BBL. GAS-MCF WATER-BBL IOIL GRAVITY-APl {corr) Press. 24-HOUR RATE -r j : 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. SEE ATTACHMENT t~ 10-407 '7-I -80 RECEIVED J U L - 2 1982 Naska 0il & Gas [;0ns. Cmnmission Anchorage CONTINUED ON REVERSE SIDE Submit in duDIicate ,o MEMORAb" UM Stat of Alaska ALASKA 0I~1~ .""qD GAS CoNsERvATION COMMI5% .ON C. V. Chatterton Chairman DATE: July 2, 1986 FILE NO.: D.ADA.31 THRU: Lonnie C. Smit TELEPHONE NO.: C~iss £oner Doug Amos Petroleum Inspector FROM: SUBJECT: Location Clearance Exxon Alaska St. F-1 Permit No. 81-140 Sec.. 17, TI ON, R23E, UM Exploratory Wednesday, June 18~ 1986: I traveled this date from Kuparuk to prudh~e ~ay and met wi~h Tom Burfford, Exxon representative. As the attached pictures show, the location listed above is in compliance with AOGCC regulations for location clearance. Therefore, I recommend that the Commission accept this well for final abandonment. I filled out an AOGCC Surface Abandonment Report for this location. The report and photos are attached. Attachments Rev 10-84) Telecopy No. (907) 276-7542 August 25, 1986 Mr. Tom Burford Exxon Company, U.S.A. P. O. Box 6601 Anchorage, AK 99502-0601 Final Location Clearance ermit fl] 4'0 Sec. 17, T10N, R23E, UM' Alaska State G-2 Permit No. 82-208 Sec. 35, T10N, R24E, UM Dear Mr. Burford: Our representative inspected the above referenced locations on June 18, 1986, and it was found that clean-up was acceptable. The casing had been cut off below ground level on the G-2 well, and a marker post was installed. On the F-1 well, a blind flange was installed on the casinghead below ground level, and a marker post was welded to the blind flange. The required information was bead welded on each marker post. Consequently, final location clearance of the Alaska State F-1 and Alaska State G-2 wells is approved. jo/A.HJH.27 .o 'ALASKA O£i, AND GAS tJt/aSERVA'£i~., ,.,,,:'1i"1.[:::15£oN ~ .'~' SURFACE ABANDC':',q'IENT REPORT ( 20 AAC 25, ARTICLE 2 FILE INFORMATION: Operator ~MO~] ' ~_~.~>. Date Downhole P & A. Address ~O, Surface Location of Well Permit No. ~O_Ft' F~'~JL, 1 ,t7 Ft. F~J4~L, se=. /7 , 20 AAC 2~.120: WELL ABANDONMENT MARKER: Dia. Steel Post (4"Min.) ~" Length (10' Min.) /~ Height Above Final Grade' Level (4' biin.i ~'% Top of Marker PiPe Closed with: Cement Plug Screw Cap Set: On Well Head w,"-, On Cutoff Casing , In Concrete Plug Distance Below Final Grade Level ~.~ Ft. in. Side Outlets: All Valves and Nipples Removed All Openings Closed , With Blinds ~"', With Cement APr No. Unit or Lease Name Wel 1 No. Field & Pool ~'~ Welds , Other INFORMATION BEADWELDEI) DIRECT~LY TO bb\RKER POST: (List Where Different from File Information) Operator ~~D~4 (.~', Unit or Lease Name .. ~~ ~~ Well ·Number . ~-~ , Surface LoCation of Well: ~ Ft. F~I~_ L, l~]'7. Ft., F~.ddjL, Sec lq , T /O ~, R 2_~_ ~: , ~/,___M 20 AAC 25.170: LOCATION CLEAN-UP PITS: ..... Filled In. w~, Liners Removed or Buried /, Debris Removed SURFACE OF PAD AND/OR LOCATION: Rough__, Smooth__, Contoured /, Flat Other , Compacted , CLEAN UP OF PAD AND/OR LOCATION: Clean.. ~, '~ipe Scrap__, Iron Scrap Paper , Other , Wood , Mud , Cement SURROUNDING AREA: Wooded , Brush Sand .... ~, Other , Tundra ~. , Grass , Dirt , Gravel CONDITION SURROUNDING A~EA: Clean ~,'Trash from 'Site Other , Trees and/or Brush from Clearing Site ACCESS RO~D: 'Dirt_ , Gravel ____,. Ice__ , Other CONDITION ACCESS ROAD AND SURROUNDING: Clean , Rough__, Smooth , Trash from Operations , Trees ·and/or Brush from Clearing Road __, Spoil from Clearing Road Other REMAINING TO BE DONE':. ~/?~AJ ~ RECOMMEI~D-APPROV. AL OF ABAaNDON~IEN'I?: 05/26/81 Yes ~, No Final Inspection ... ~ ~~~ ~~ `, , ~ ~ y~ ,~ ' ~, -; .. r ~. -~ ' • ~: '' ,~ x~~`". ~,,cxoN Ao~s,r~ ~TigT~ F-/ ,~/~LC.. SCHLUMBERGER OFFSHORE SERVICES 500 w. INTERNAT{ONAL ^IR?ORT ROAD ANCHORAGE, ALA$~U~ 99502 COMPUTING CENTER PRINT CENTER WELL NAME SERVICES · AI.,ASKA STATE F-1 T A'P E WELL NAME ' SERVICES - NO. OF BOXES: JOB NO.. : 7 '~. ADD'L TAPES : J()H~ OST,f£?X;?.E~! OF NO. OF BOXES: JOB NO. ' ADD'L TAPES ' WELL NAME · SERVICES ' WELL NAME ' SERVICES · NO. OF BOXES' JOB NO. · ADD'L TAPES : NO. OF BOXES- JOB NO. ' ADD'L TAPES ' WELL NAME · SERVICES · WELL NAME · SERVICES · NO. OF BOXES' JOB NO. · ADD'L TAPES ' SCHLUMBERGER COURI ER r'~ f;'-~? T I ~' ~' ~' l' NO. OF BOXES' JOB NO. ' ADD'L TAPES ' DATE DELIVERED ,R£CEIVED RECEIVED BY JA~ 0 6 1~8t~ ,. .... . ..... (.m & Gas (;(}ns. commJssio" E ON COMPANY, U.S.A. POUCH 6601 ,,, ANCHORAGE, ALASKA, 99,502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION D.H. JONES EXPLORATION COORDINATOR -- ALASKA September 6, 1985 Exxon' s Drillsites Inspection and Status Mr. Lonnie Smith State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Enclosed for your review and approvaI 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 SEP1 Alaska 0il & Gas Cons. Commission Anchorage ALASK ,L AND GAS CONSERVATION C ,,,~IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator Exxon Corporation 3. Address P. O. Box 6601, Anchorage, AK 99502-0601 4. Location of Well 360' SNL, and 1817' EWL, Sec. 17, TION, R23E, UM 5. Elevation in feet (indicate KB, DF, etc.) +4 MSL Ground I 6' Lj~a~[D~a~and Serial N°' 12. 7. Permit No. 81-140 8. APl Number 50- 089-20019 9. Unit or Lease Name Alaska State "F" 10. WelJ. N umber ~xxon No. I 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 l Alast~a 01i & Gas Cons. Con]mis. Anchorage Exploration Coordinator- Signed ~/~V v_ ~2~ Title Alaska The space below for Commission use Date 9/10/85 Conditions of Approval, if any: - Approved by ,~proved Copy By Order of COMMISSIONER the Commission Form 10-403 Rev. 7,1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate "' ' MEMOR , DUM St , .of Alaska TO: THRU: ALASKA OIL AND GAS CONSERVATION COMMISSION C. V/~t~ton D^TE: September 11, 1984 Chai~j~fB.../ FILE NO: Lonnie C. Smith ~~ C ommission~_~,~ . f-- FROM: Bobby Fosterrz~] SUBJECT: Petroleum Tn~pector TELEPHONE NO: 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 Att-achment/pictures in file 02.00IA(Rev. 10179) Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: ~- , Operator- ~ ~_--~~~ ~ i ~ D~te Suspended Address ~~ ~/_~/~.~/~/-'~_,~ ~ ~~ Su~f~ce n6~a~iOh o~ wei~iL ~ ~ ' ~ ~' permit NO. ~/-/~ - seC'-/7' T/P -~,-~~ ~ O.M. -uni~ or Lease Na~e Well No.. K-[ , ............ Condition' of Pits ....~ ~ / _~~__' Well head - Ail outlets plugged ~ No Well sign - Attached to well head Yes No Attached to well guard .. · Yes No Attached to , ~__~ Information correct ~ No Cellar - Opened Fil led Covered WaterWell - Plugged off Yes No Rat Hole Ol>an ' No Fi 1 led No Covered Capped Open Explanation _No No Ye s No Photographs taken to verify above conditions(~Yes~ No Work to be done to be acceptable Exp la na ton This well and location is~~cce~ta~ (unacceptabl~e) to be susPended for the period o ..~'--~19~t~aru- -~- ~ '~- _~ . Inspected bY:_~ /~ ~ ~~~3 , classified as Revised 8/24/82 ~~ ~X~(e~J - /~~~95,~9 S~i9 ~e ~ SeC ~ 7 ~ 1 la N`~ ~~3E , (1 m - ~vs~e~u~ ~~A .~W~ STATEOF ALASKA ~ ALA~ ', OIL AND GAS CONSERVATIO~ OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER ~1~ 2. Name of Operator 7. Permit No. Exxon Corporation 81-I40 3. Address 8. APl Number P. 0. Box 6601, Anchorage, AK 99502-0601 50-089-20019 4. Location of Well 360' SNL, and 1817' 5. Elevation in feet (indicate KB, DF, etc.) +4 MSI Ground 12. EWL, Sec. 17, T10N, R23E, UM 9. Unit or Lease Name Alaska State "F" 10. Well Number Exxon No. I 11. Field and Pool Wildcat I6. Lease Designation and Serial No. ADL 312862 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 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. RECEIVED SEP 1 0 1984 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify t~in~5-~e and correct to the best of my knowledge. Exploration Coordinator - Signed ~--(/'...~.~ ~ Title Alaska · The space below for Commission use Dateg/10/84 Conditions of Approval, if any: IIIItlIIAL $1t1[I BY LONIII[. C. SMIlit Approved Copy Returned -- By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate September 29, 1983 'Exxon Company, U.S.A. P. O. Box 6601 Anchorage, Alaska 99502 Re: Cleanup Inspection for the Following Wells~ Duck Island Unit I{o. 2, Sec. 8, T'llN, R17E, U.M. Duck Island Unit No. 3, Sec. 1O, TIlN, R17E, U.5i. Point Thomson Unit }~o. 1, Sec. 32, T10~, R23E, U.M. Point Thomson Unit ~o. 2, Sec. 3, T9N, }~22E, Point Thomson Unit }~o. 3, Sec. 34, %~10N, R23E, U.~.~. Alask~ State A-l, Sec. 27, Ti01~, R24E, U.M. Alaska State C-I, Sec. 14, T9I~', R23E, U.M. Alaska State D-l, Sec. 23, T10N, R23E, ~las~.$tate'F-~, Sec. 17, T10N, R23E, U.M. Alaska State C-2, Sec. 35, T10N, R24E, U.~4. Centlemen: Our representative inspected the above ten suspended and abandoned well sites for extension of cleanup on August 31, 1983. With the exception of Alaska State C--2, the cleanup of these well sites are satisfactory. Because the drilling rig was still on location at Alaska State G-2, a cleanup inspection could not be completed. Returned are eight approved 10-403's, Sundry '~gotices and ~eports on Wells, for all the lasted wells except for two which need no further approval. Alaska State G-2 has a year to go under 20 AAC 25.170(a) and Alas~ State D-I which (classified as aban- doned) has previously been granted an extension to August, 1984 for removal of the sheet piling. The 10-403's which you submitted for Duck Island ~nit ~:o. 1 and Alaska State D-1 are not necessary- and are returned unsigned. Duck Island Unit ~o. I was abandoned dcwnl~ole and Duck Island Unit ~-}o. 2 was sidetracked from the well kote of ~{o. 1. Conse- quently a 10-403 is not required for }~o. i. A subsequent inspection of each well will be necessar3. by August,' 1984. Sincerely, -_ tonnie C. Com~..i s sioner LCS/J~..~: lc: !03~ B MEMORA 'DUM Stat of Alaska ALASKA OIL AND -GAS CONSERVATION COMMISSION TO: C. V~e~ Ch ai~n ~ Thru: l--~n]~. Smith Coml ioner FROM: Bobby Foste~~ Petroleum Inspector DATE: 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 SuspeJded Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: .__ ~ ~ra-~-~ ~ ~... ~..~/~O. ~J ~ Da ts Suspended Address ~~' L/~ ~ ~3~~~ Surface ~a~0~Of ~e~i ...... ~ ..... Pe~-~- .Ft. F L, Ft. aPI No. S~C.~, T~ ~, ~3~ "'_[ M. Unit or Lease Nam~~ Wel 1 Field & Pool Condition of Pits .~,'//~ Well head - Ail outlets plugged Wel 1 sign - Attached to well head Attached to well guard Attached to Information correct ~ No Ye s No ~ No Cellar -' Opened ~ Yes No 'Filled ~ No Covered Ye s No WaterWell - Plugged off capped Photographs taken to verify above Ope n Rat Hole O~~Y~Ye s No Fi 1 led Ye s No Covered Yes No Exp la na ti on condi tions~ No Exp la na ton Work to be done to be. acceptable This 'well and location is .~-ceptab~ (un_acceptab~) to,be classified as suspendedinspectedfOr., theft-iq dby: [~/Of~i/' ,~r'~'~z/~Jtv/~~- 7/Q . ~~~~' '~/~?- _ 19~ Revised 8/24/82 10" Dwe~i~ L-~J~ To n~u0 P,T ~, o ~ 3o gLOw - Do wrs E+.Ip 2- 10314" ~~~ oP~N,r MgHU,4L ~gLYEtS r1 ~l~ r c7:~.., o~ e ~s~°\ ~Qc LD3~4° FNt,.i oPfsN,~(ri fZ&~'-oT& ~ GoN 2tistbL V~.V~ ~ 2~0 y; P 20" p,vse-rss~. EX~(~-J r1l.AskA STAi'~ F ~ ~.D. Co. (2~G, # S ~T` ! L t NE ~.cR. v6~.i-T-w(x .-- . ~, O~ ~ of ~ S 1, q ra O~ ~ --~ ='~ -= ~. _~ ~ , .- ."~ + -` . _~~~. =~:- - „' ~. TEE Fc,G: u-av~- G-tirour.-O D~~E~~R' L»~ eV1~-ina6s dt.1TS1DB 15L1°-+~-a w~c~,s. -~ ~'~. ' i! yl...~ EXPLORATION DEPARTMENT ALASKA/PA.ClFIC DIVISION D.H. JONES EXPLORATION COORDINATOR -- ALASKA July 26, 1983 Mr. C. V. Chatterton, Chairman State of Alaska Alaska Oil and Gas Conservation Commission' 3001-Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached for your approval are Sundry Notices for one year extensions of the suspended, status of the following Exxon wells. Point Thomson 1, 2, & 3 Duck ISland 1, 2, & 3 We would be pleased to arrange an inSpection tour of each of these locations for your representative sometime in late August. Please contact Mr. R. L. Westbrook at (907) 263-3742 ~to arrange a convenient date. Very truly yours, NB: ms 40/42 A DIVISION OF EXXON CORPORATION A(~ STATE OF ALASKA '~" ALASK iL AND GAS CONSERVATION C ,vlMISSION 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 360' SNL, and 1817' EWL, Sec. 17, T10N, R23E, UM 5. Elevation in feet (indicate KB, DF, etc.) +4' MSL Ground 6. Lease Designation and Serial No. ADL 312862 7. Permit No. 81-]40 8. APl Number 5o-g89_~00!9 9. Unit or Lease Name Alaska State "¥" 10. We~ Number Exxon 11. Field and Pool Wildcat 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). \ We request a one year extension to August 1984 of the suspended status of this well. We will arrange to have the location inspected by your representative on a yearly basis or until final abandonment. L 2 8 igg: Gas C0ils:~ C0tt]~'J.i$:!;i0F~ A~,chorag~ Approved Copy Returned Date 7/25/83 14. I hereby certify that~le fore~,oing is true and correct to the best of my knowledge. Signed Title Alaska The space below for Commission use Conditions of Approval, if any: Our representative inspected this w~ll site on August 31, 1983 and cleanup ~s acceptable for a suspended location. A subsequent inspection will be necessary by August, 1984. ORIGINAL SIGWED By Order of ~--~ Approved by ]]~ [~]~]~1[ J~. _~!_]'~ COMMISSIONER the Commission Date~'/- Form 10-403 Rev. 7-1 ~0 Submit "Intentions" ir] Triplicate and "Subsequent Reports"ir] Duplicate COMPANY. U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99,502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION D.H. JONES EXPLORATION COORDINATOR -- ALASKA March 18, 1983 Alaska State "F" Exxon No. 1 Surface Loc.: Sec. 17, TiON-R23E, UM ADL 312862 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: We were informed by the Commission that you do not have any subsequent report of abandonment cementing for five DST intervals or the suspension procedure for the above captioned well. The attached sundry notices are supplied to complete your records. Yours very truly, D. H. Jones 211B/68 Attachment A DIVISION OF EXXON CORPORATION C~M ,1 STATE OF ALASKA ALASK L AND GAS CONSERVATION MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator Exxon Company, U.S.A. 3. Address Pouch 6601, Anchorage, AK 4. Location of Well 360' SNL and 1817' EWL Sec. 17, T10N, R23E, UM 5. Elevation in feet (indicate KB, DF, etc.) +4.0 Mean Sea Level (Groun~d) 12. 7. Permit No. 81-140 8. APl Number 99502 50-089-20019 9. Unit or Lease Name Alaska State F 10. Well Number Exxon No. 1 11. Field and Pool I 6. Lease Designation and Serial No. ADL 312862 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 Casi'ng [] ' Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This is to document suspension of the well as proposed in our Sundry Notice dated 5/28/82. The 7" production casing was perforated at 1783' MD, a cement retain~f was set at 520' MD and Permafrost cement was circulated until clean returns were achieved out of the 7" x 9-5/8" annulus. A balanced cement plug was then set on top of the retainer to the surface. The wellhead was left as illustrated in our Sundry Notice dated 5/28/82. 14. I hereby certify that t~e foreg/oing is true and correct to the best of my knowledge. Signed _ _ ,, Title Date 3- :2.1- 8 3 / The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL EX COMPLETED WELL [] OTHER [] 2. Name of Operator Exxon Company, U.S.A. 3. Address ?ouch 6601, Anchorage, 4. Location of Well 360' SNL and 1817' EWL Sec. 17, T10N, R23E, UM 5. Elevation in feet (indicate KB, DF, etc.) +4.0 Mean Sea Level (Ground) 12, 7. Permit No. 81-140 99502 I 6. Lease Designation and Serial No. ADL 312862 Wildcat Check AppropriateBox TolndicateNatureofNotice, Report, orOtherData 8. APl Number 5o-089-20019 9. Unit or Lease Name Alaska State F 10. Well Number Exxon No. 11. Field and Pool NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] , Perforations I--I Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [~] Repair Well [] Change Plans [] Repairs Made [] Other ]~l Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This is to document abandonment of the following four perforated intervals by means of squeeze cementing through a retainer. Proposed test interval #6 was not perfo.rated. Current Est. Date Test # Highest/Lowest Perf. (MD)-ft Retainer MD-ft TOC-.ft' Squeezed 2 13,794/13,882 13,580 13,545 5/02/82 3 12,890/12,930 12,815 12,780 5/13/82 4 12,544/12,590 12,250 12,210 5/20/82 5 12,008/12,080 11,885 11,850 5/29/82 14. I hereby certify~lRejt the f~regoing is true and correct to the best of my knowledge. _ ~~_ ~/~~ Exploration Coordinator- Alaska Signed Title The space below for Commission use Date 3-21-83 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev, 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate M EMORAI L UM State( of Alaska TO: FROM: FILE NO: . ComaLss.io~r SUBJECT: Edgar W. Sipple, Batroleum LnspeCtor March 17, 1983 of 700 SI~ ~..rma ~ 15.2 ppg Cement, inthe 13 3/~ x 9 5/8 casing on E~vn's Alaska Sec 17 T10gq R2-~, {]4 1983= I left Anchorage via Alaska Airlines fDr Pru~hoe Bay. I at EX~Dn's North Star Island at 8:30 p.m. ~he displa~ of the 700 SKS of B~rmafrost 15.2 ppg Cema_hr ~ at 2:00 a.~, March' 7, 1983. ~here ~as a break ~ of the fonm~cion of 3 BPM at 2000 psi. well had an injection, pressure of 1500 psi. During the displa~e~_nt of the ~ the highest pressure cbta/ned was 2500 psi, at the conclusion of the job the injection ~es'~ on the ~e/1 ~ss 2000 psi. ~he b0ttcm of the cement 2~17' in the 13 3/8 x 9 5/8 ~ing. ~ ~ell was being used as a disposa/ well fDr gr~ ~er, in the 13 3/8 x 9 5/8 ~m.ing. I also checked out the P&A manker~ It ~as in ccm~lianoe with ~tate of Alaska regulati~. 02-001AiRev. 10/79) - ' 4/so Company Repr ~--~J~o~Y ~D~-~ Dril_ling Permit Lease No.~"~,~ / Well No. ~.~ 0?.~w /~' Sec. T-R, /7- \SKA OII, & GAS CZ IISERVATION CO~MISSION Plug & Abandonment Repo~' Date ~-p- ~ Well . ~ ~' ~,: .~ ~..~ ~ Total Depth Elevation Mud Wt. Casing: Drive Pipe 30 "O.D. Set at //~ / " Ft. w/ / / {/ Pane. . Conductor '3 d[ "O.D. @ o~/4 ~ Ft. Surface /3 ~'O.D. @ &~/, Fa. Intermediate ~/f "O.D. @ /~D~/~ Ft. Production "O.D. @/~'~t. Plugging Data: 1. Open hole plugs: 2. Open hole isolation plug: 3. Perforation plugs (if any): 4. Annulus plugs (if any): ' 5. Casing st~ plugs: 6. Surface plug: Casing removal: "casing cut at ' "casing cut at ' "casing cut at ' , STATE OF ALASKA ALASK IL AND GAS CONSERVATION MMISSION SUNDRY NOTICe'S AND REPORTS GN WELLS 1. DRILLING WELL COMPLETED WELL OTHER 2. Name of Operator Exxon Company, U.S.A. 3. Address Pouch 6601, Anchorage, AK 4. Location of Well 360' SNL and 1817' EWL Sec. 17, T10N, R23E, UM 5. Elevation in feet (indicate KB, DF, etc.) +4.0' Mean Sea Level (Ground) 12. 7. Permit No. 81-140 99502 I 6. Lease Designation and Serial No. ADL 312862 Wildcat Check Appropriate Box Tolndicate NatureofNotice, Report, orOtherOata 8. APl Number 50_089-20019 9. Unit or Lease Name Alaska State F 10. Well Number Exxon No. 1 11. Field and Pool 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 hate of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This is to advise you that we permanently abandoned the 13-3/8" x 9-5/8" annulus with 700 sacks of Permafrost cement from 2015' to surface on 3-7-83. Outer valves on the "A" and "C" sections were removed and replaced with VR valves, as planned. The outer valve on the "B" section was cemented in place, however, and could not be removed. Final wellbore and surface abandonment sketches are attached. 14. I hereby certify thj~t~the foregp_ing is true and correct to the best of my knowledge. //~ff~~ /~~.~,~,_~. Exploration Coordinator-Alaska Signed - Title The space below for Commission use Date 3-9-83 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate a~d"Subsequent Reports" in Duplicate ALASKA STATE F- 1 Surface Abandonment Sketch AVM 2-11-83 Existing "B" Section Existing "A" Section 4" OD line pipe x 10' long Bead Weld Lettering As Follows: Exxon CO. U.S.A. ALASKA STATE "F" Well No. 1 1817' EWL, 360' SNL, Sec. 17 T10N, R23E, UM l~--- i+-ll" 10,000 psi blind flange · +--11" 10,000 psi Flange on Existing-"C" Section __VR Plugs 3-1/8" 5000 psi valve VR Plugs 20" 133 PPF Casing ALASKA STATE F-1 Final Wellbore Sketch A305 Perm.a frost c~m. ent from surface - 2015 NON-F'REEZING F'LUID 10.2 PPG CACL2 15.8 PPG MUD 1,5.0 PPG MUD ., ESTIMATED TOC ~ AT 9400' TOC AT 10,340' CBL ESTIMATED TOC A'I' J,J,aS0' PPG MUD -- 15.8 PPG .MUD ~ .:.-. , ~.,. !5.8 PPG .MUD !5.6 PPG MUD 15.9 PPG h,,IUD -....___ A. Section - capped Section Section 30" STRUCTURAL PIPE AT I 1,4' EZSV RETAINER AT 520' 20" 133 -~r/F'T. K55 BTC CONDUCTOR AT 2 108'. PIT 13.0 PPG PERF'S & BASE CEN'IEi',,IT PLUG AT 1783' 9.0 PPG MUD ESTIMATED TOC AT :3400' MD .13 3/8" 72 */FT. LBO BTC SURFACE CAS!NG AT 6901'. PIT 16.5 PPG EZsv RETAINER AT 11,850' DIL F-I PACXL'~ AT I 1,8g..~' DIL .9 5/8" 43.5 & 47"q~/F'T- PROTEJCTIVE CAS;NG AT 12,096', ~PIT 18.0 PPG PERFS AT 12008._O~7.& 126~:~._Osc~DiL EZSV I~L-'TAINER AT 12,250' OIL J~ AT 1E,313' - 315' DIL £Z.SV I:~ETAIN~R AT 12.320' DIL F-1 PA~ AT 1~,330' DI~ ~S AT 12,544' - 590' DIL ~SV ~al~ AT 12.81 F-1 PA~ AT 12.a~' D~L ~S AT 12,924' - g30' & 1E,agO' . eoe' ~V ~AI~ AT 13,S. eO' DIL F-1 PA~ AT 13.5gO' DIL .,PE.r:~c, AT 13,794' - 830' .13,84e' - 88~.', & 13.874'- 8~6' D~L F-1 PACI~E~ &T 13,9OO' DIL 7" 35 "/F.T. P1 10 LTC PP, O~UCTION CASING AT 1 3,940' TD '4,2 16' E (ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION D.H JONES EXPLORATION COORDINATOR -- ALASKA '1' February 23, 1983 Alaska State "F" Exxon No. 1 Surface Loc.: Sec. 17, T10N-R23E, UM ADL 312862 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commi s s ion 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: We were informed by the Commission that you do not have any record of final abandonment cementing of the 20" x 13-3/8" annulus for the above captioned well. The attached sundry notice is supplied to complete your records. Yours very truly, P~: sim 11o/T Attachment A DIVISION OF EXXON CORPORATION ALASK ,L AND GAS CONSERVATION C ,,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~3 OTHER [] 2. Name of Operator 7. Permit No. Exxon Corporation 81-140 3. Address 8. APl Number Pouch 6601, Anchorage, Alaska 99502 50- 089-20019 4. Location of Well 360' SNL and 1817' EWL Sec. 17, T10N-R23E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. +4.0' Mean Sea Level (Ground)I ADL 312862 12. 9. Unit or Lease Name Alaska State F 10. Well Number E××on No. 1 11. Field and Pool Wildcat Check ApprOpriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other 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). Documentation of cementing of 20" x 13-3/8" annulus: Date cement job performed: December 13, 1981 Volume used: 2100 sacks of Permafrost cement (348 bbl of slurry) Calculated interval filled with cement: Surface to 1900 ft. RECE VEO F E B 2 8 1983 "" A~aska 0it &Anch0rageGas 60n% O0mmissi0n 14. I hereby cert~ foregoing is true and correct to the best of my knowledge. ~~~ Exploration Coordinator - Signed Title Alaska The space below for Commission u-se . Date ~2/24/83 Conditions of Approval, if any: By Order of Approved by C©MMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASK ilL AND GAS CONSERVATION ,vIMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Exxon Corporation 81-140 3. Address 8. APl Number Pouch 6601, Anchorage, Alaska 99502 50- 089-20019 4. Location of Well 360' SNL and 1817' EWL Sec. 17, T10N-R23E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. +4.0' Mean Sea Level (Ground)I ADL 312862 12. 9. Unit or Lease Name Alaska State F 10. Well Number Ex×on No. 1 11. Field and Pool Wildcat Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] 'Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Documentation of cementing of 20" x 13-3/8" annulus: Date cement job performed: December 13, 1981 Volume used: 2100 sacks of Permafrost cement (348 bbl of slurry) Calculated interval filled with cement: Surface to 1900 ft. /.,~_.~('-//~~____ .....ft.'~ ~~/' ".~'~' .~ Exploration Coordinator - Signed Title Alaska The space beg:, for Commission Ge Date 2/24'/8S Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate : ( EX O:N USA PROPRI£TARy ALASKA OIL AND GAS CONSERVATION COMMISSION ~/ SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL [] OTHER 2. Name of Operator Exxon Company, U.S.A. 3. Address Pouch 6601, Anchorage, AK 99502 4. Location of Well 360' SNL and 1817' EWL Sec. 17, T10N, R23E, UM 7. Permit No. 81-140 8. APl Number 50- 089-20019 9. Unit or Lease Name Alaska State F 10. Well Number Exxon No. 1 11. Field and Pool 5. Elevation in feet <indicate KB, DF, etc.) ! 6. Lease Designation an~f~ri~lb~~. +4 0 Mean Sea Level (GrOund) · ' ADL · Wildcat 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] , Perforations [] Altering Casing Stimulate [] Abandon ]~] Stimulation [] Abandonment Repair Well [-] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10,407 with a submitted Form 10-407 for each completion.) D [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This is to notify you of our plans to permanently abandon the 13-3/8" x 9-5/8" annulus. The permanent abandonment plans are shown in the attached sketch and described in the attached'procedure. The AOGCC will be notified prior to setting the cement plug in the 13-3/8" x 9-5/8" annulus so that a representative can witness the operation. Subsequent Work Reported RECEIVED FEB 1 8.19'83 Alaska Oil & Gas Cons, Commission Anchorage //~'-~'-- /,F~-~-~ Exploration Coordinator Signed '~q-itle ..... , . _ The space below for Commission use - Alaska Date 2-18-83 Conditions of Approval, if any: Approved by ~'~0 COMMISSIONER Form 10403 Rev. 7-1-80 Approved Copy . Returned 8y Order of the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate PROCEDURE TO PLUG INJECTION ANNULUS ALASKA STATE F-1 SUBMITTED BY: APPROVALS: Engineer Engineerifig Operations Date Dat~ RECEIVED F£B 1 8 ]983 Alaska 0ii & Gas Cons. Commission Anchorage ALASKA STATE F-1 FINAL PLUGGING PROCEDURE · Notify the AOGCC 48 hours prior to commencing plugging operations to ensure that they have a representative present to witness operations, if they desire. · Rig. up Halliburton to the 3-1/8" 5000 psi "B" Section valve and test the lines against the valve to 3500 psi. · Establish injection down the 13-3/8" x 9-5/$" annulus ~y pumping 50-100 Bbls of Gray Water at 1 BPM. Initial in- jection pressure should be 2200-2300 psi, based on a 16.5 ppg PIT at the 13-3/8" casing shoe. NOTE: Ensure that all waste liquids are disposed of prior to beginning final plugging operations. . Follow the Gray Water with the following cement slurry: Blend: Amount: Density: Yield: Water: Thickening Time: Permafrost 700 sacks 15.2 ppg 0.93 cf/sack 3.5 GPS; 59 Bbls total fresh water from C-1 water source 6 hours NOTE: Prior to mixing cement, run a steam hose in the water truck to raise the mix water temperature. Use Attachment I to determine the mix water temperature required to obtain a slurry temperature of 45°F. Displace cement with 10 Bbls of 10.4 ppg corrosion inhibited CaC12 water· This will leave the top of the cement at ^ approximately 170'. inhibit CaC12 as follows: 25 gal/100 Bbl. Corexit 7720 10 gal/100 Bbl. Corexit 7675 ~°~/? These chemicals ~r~ at the Exxon pad. ,, Nipple down the D Sec,t, ion and remove the 7, casing packoff. Cut off the 7' casing stub above 7' casing slips and packoff, such that the stub does not interfere with the blind flange; .7. Blind flange the "C" Section and remove the outer 1-13/16" 10,000 psi valve. Remove the outer 3-1/8" 5000 psi valves from the "A" and "B" sections so that they can also be salvaged. Install VR plugs on the "A", "B" and "C" section side outlets. Alaska State F-1 Final Plugging Procedure Page Two 8. Install a well marker as follows: 4" diameter steel pole, capped on top At least 10' long, extending at least 4' above pad level Weld with supporting fillets to blind flange WOC for 24 hours. Pressure test to 2200 psi with CaC12 using the injection pump. Bead weld the following information on the marker above ground level: Exxon Co., U.S.A. Alaska State "F" Well No. 1 1817' EWL, 360' SNL, Sec. 17 Ti ON, R23E, UM 11. Back fill the cellar with gravel to pad level. AVM: sjm/rms 2/10/83 221A/20 Attachments 295-664-130 t EC£1V£D F£8 1 8 983 Alaska Oil & ~as Cons~ C°t~n~ission AnChorage 9O 80. 7O 60 50 40 SLURRY TEMPERATURE VS. MIX WATER and CEMENT. .SOLIDS TEMPERATURE Attachment I · f ambient temperature is less than - 30° F, use - :50 line. Desired Slurry : Temperature: 45° F Neat Permafrost :5.5 Gal. Water/Sack I0 20 '30 SLURRY 40 50 TEMPERATURE ('OF ) 6o 70 8O ~,,, A305. ALASKA STATE F-1 We!lbore sketch after,, proposed 13-3/8" x 9-5/8" annulus abandonment 10.4 ~pg CaCI? from - 170-ft C Section - capped Section A Section Permafrost cement from 170' - 2200'. 30" ,STRUCTURAL PIPE AT 114' EZSV RETAINER AT 520' 20" 13:3 .~/FT. K55 BTC CONDUCTOR AT 2108', PIT 15.0 PPG PERFS & BASE CEMENT PLUG AT 1783' 9.0 PPG MUD NON-FREEZING FLUID 10.2 PPG CACL2 .. 15.8 PPG MUD ESTIMATED TOC AT 3400' MD .13 3/8" 7~-~f_T. LBO BTC SURFACE CASING AT 15.0 PPG MUD \ ESTIMATED TOC ~ AT 9400' TOC AT 10,340' CBL- ESTIMATED TOC 15.6 PPG MUD .-., :,~.. · ,. ., .:~ :,. 15.8 PPg MUD 15.6 PPG MUD · " .-',~¥,:-,,H ' - ........ ~ 15.6 PPG MUD 15.9 PPG MUD EZS, V RETAINER AT 11,850' DIL F,'I PACX&"'~ AT 11.895' 9 5/8" 43.5 & 47¢t"/FT. PROTECTIVE CASING AT 12,096", PIT 18.0 PPG PERF'S AT 12008'-027' & 12052'-080'DIL £ZSV RETAINER AT 12.250' DIL PERF$ AT 1~,313' - 315' DIL £ZSV RETAINER AT 12.320' DIL · F-I PAC3<E3~' AT "1;:,330' PERF'S AT ¶2.544' - t~'90" DIL ~...ZS, V RE"rAIHE:R AT ¶ 42.B ¶ PE:RF"$ A'r t~..924' - 930' & 1~.890' - 908' DIL ;?_~V RETAINER AT 13,580' DIL F-¶ PACKER AT 13.590' PF.R¢$ AT 13,794' - 830' .13.846' - 868'. & 13,874' - 886' DIL F-1 PAC~E"R &T 13.9OO' DIL 7" 35 "/FT. P110 LTC PRODUCTION CASING AT 13,940' TD 14,316' ALASKA STATE F-1 Surface Abandonment Sketch 4" OD line pipe x 10' long Bead Weld Lettering As Follows: Exxon CO. U.S.A. ALASKA STATE "F" Well No. 1 1817' EWL, 360' SNL, Sec. 17 T10N, R23E, UM AVM Existing "B" Section ~'"-' }+-11" 10,000 psi blind flange ~ 't+--11" 10,000 psi Flange on ~ ' '' " " ion ~ I i ~ Ex~stzng C Sect ///;' ,,.--.- VR P lug s Existing 'A" Section VR Plugs !~ 20" ~ -- 133 PPF Casing 2-11-83 .. 'r 23'00 ~,~ G February 16~ 19~ Exxon COmpany U.S.A. P.O. Box 6601 Anchorage, Alaska 99502 Subsequent Reports, Sundry Notices and Re~orts on Wells (Form 10-403 ) For the following lists of 'Notice of Intention To:' Sundry Notices and. Report on Wells (for~ 10-403) this office does not have on record the U'Subsequent Report of~ ' defining the action taken on the approved intention. Please advise this office by Subsequent Report of the disposition of the intention. WeI 1 Alaska State F-I Alaska State F-1 Sincerely', / ..... / /"' ' 't : . 1~.: C~sstoner 516/82 $/28/S2 Brief Description of Intention t.7__'_-'. ' ': ...... -*:: .: ' ........ ; X." ' ,...' ............ ._.. .~, ,~, Perforate, production test, abandon 5 l~ervals Suspension proce~ur~ LCS/JKT/g lh MEMORANDUM State of Alaska TO: THRU: FROM' ALAS¥~/~IL~ND GAS CONSERVATION COMMISSIO~ DATE: C. Vl'q~er~ August 25, Cha[~~ ~~/~-. FILE NO: 108A/A ~nnie C. Smith ' Com~ssioner ~ ~ TELEPHONE NO: 1982 SUBJECT: Harold R. Hawkins Petroleum Inspector Inspection for Extension of C lean-up Exxon Company U.S.A. Well No. F-1 Thursday, August._ 12,_1982 - I left Anchorage at 8':30 a.m. by Alaska Airlines to Prudhoe Bay arriving at 10:00 a.m. and at Exxon's headquarters .at 10:05 a.m. We were taken to the location by helicopter. On the way to inspect clean-up and abandonments of several locations for Exxon Company U.S.A. Junior Westbrook, supervisor for Exxon, requested that I take pictures of Alaska State F-1. He said Exxon may be asking for an extension to clean-up the location. Pictures #1, 2 and 3 were taken from the air. From the air the location looked like it was well kept. The rig was Arctic Alaska No. 5. In summary, flying over Exxon Company's U.S.A. Alaska St. F-1 I took pictures of the location for the purpose of an extension for clean-up only at the request of Junior Westbrook. Exxon may be sending in a Sundry Notice 10-403 for an extension be fore long. 02-001 A(Rev.10/79) /~'~1 /d ~ V L/ l~ ~ ~ l7 ~ / ~ ~ -~ ~. ' U ~` - n.7 ~ ` '• :x ~' ~ ~'~. . ~r~ '~ :~ ~.a.. E; (ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION C IDENfiAL July 2, 1982 Re: Exxon Alaska State 'F' Well No. 1 ADL 312862 North Slope, Alaska Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: We are attaching two copies of Form 10-407, Well Completion or Recompletion Report and Log, for the captioned well which was plugged and suspended on May 30, 1982. Also, we submit the fol- lowing data: (1) One set of washed and dried samples from 60' to 14,316'. (2) One blueline and one sepia print of the complete mud log from 115' to 14,316'. (3) One composite sepia, one composite blueline print of the following open hole logs: Dual Induction Long Spaced Sonic Formation Density - Compensated Neutron Dipmeter (4) One digital magnetic tape of the following open hole logs: Dual Induction Long Spaced Sonic Formation Density - Compensated Neutron (5) Core chips taken at 1' intervals from the following cores: A DIVISION OF EXXON CORPORATION RECEIVED J L - 21,982 Mr. C. V. Chatterton Page two July 2, 1982 Core No. Interval 12,065'-12,081' 12,572'-12,618' 12,905'-12,915' 13,818'-13,826' 13,826'-13,833' 13,833'-13,838' (6) One copy of Sperry-Sun gyroscopic survey from surface to 13,900' and one copy of the dipmeter directional survey from 13,900' to 14,294'. Please note that the above material is marked confidential and should be kept confidential in accordance with the provision of 20 AAC 25.537(d). Very truly yours, D. H. Jones /~ DHJ:RLL:et attachments RECEIVED' J U L - ~ i982 Alaska Oil & Gas Cons. Commissior], Anchorage " cl' CONFIDENTIAL STATE OF ALASKA ~~ " "" ALACK ,~- AND GAS CONSERVATION MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG .., 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED ~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Exxon Corporation 81-140 3. Address 8. APl Number Pouch 6601, Anchorage, Ak. 99502 50_089-20019' , · 4. Location of well at s6rface Lr'~-~ATioNS-- 9. Unit or Lease Name 360' SNL & 1817' EWL, Sec. 17, T10N-R23E, UE VERIFIED Alaska State F At TOp Producing Interval .... ~urf~ .J~ i 10. Well Number ,Exxon No. 1 1294' SNL & 1304' WEL, Sec. 18, T10N-R23E, E~.H._F~__~ At Total Depth ~ 11. Field and Pool 1197' SNL & 1531' WEL, Sec. 18, T10N-R23E, UM Wildcat 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 42' KB ADL 312862 12. Date Spudded 13. Date T.D. Reached 14..Date Comp., Cusp. or Aband. J 15. Water Depth, if offshore J 16. No. of Completions I 11--1--81 4--3--82 5--30--82J NA feet MSLI 4 .... 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21, Thickness of Permafrost 14,316' (13173'TVD) Surface YES~ Noir] NA feetMD 1340' (KB) 22. Type E~ectric or Other Logs Run Du'al Induction, L'ong Space Sonic, Formation Densitya'' Neutron, Dipmet.er, Velocity Survey · , 23. CASING, LINER AND CEMENTING RECORD , , , ......... SETTING DEPTH MD CASINGSIZE WT. PER FT. GRADE TOP BOTTOM HOLESI;~E CEMENTING RECORD AMOUNT PULLED 30" 310 j B 45' 114' - Est' 300 sx' permaJ rost 0 .. ..... 20" 133 K'55 ' 43' '2108.' 26" 11,300 sx permaf]ost .0 13-3/8.' 72 ' ' L'80 41' '6901' 1'7-1/2" 1750 sx class G '0 9-5/8'" 47 RS90 39' 12096' 12-1/4 '2500 sx class G 0 7" 35 P'll0 37' 13940' 8-1/2" 1350 sx class G ' 0 24. Perforations open to Production .(MD+TVD of Top and Bottom and 25. TUBING RECORD irTterval, Size and number) ' SIZE DEPTH SET (MD) PACKER SET (MD) : SEE ATTACHMENT 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMouNT& KIN'DOF MATERIAL USED ' SEE ATTACHME: ~T ..... , , 27. " ' PRoDucTION TEST ' , ,, Date First ProduCtion . . ,.. JMethod of Operation (Flowing, gas lift, etc.) '' . . Date of Test Hours Tested PRODUCT ON FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE JGAS-OII' RATIO TEST PERIOD JJ~ . I Flow ,Tubing Casing Pressure CALCULATED jj~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (c0rr) Press .... 24-HOUR 'RATE ' J . . .... 28. COP E DATA , ,, , Brief description of lithology, porosity, fractures, apparent dips and presence o~ oil, gas or water. Submit core chips. SEE ATTACHMENT .... ' J U L - 2 1982 ' Ahska Oii &. Gas Cons. Commission ^richorag,, ~. ,.., , , , Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEoLoGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Tertiary Surface Surface Paleocene 9,805' 9,494' SEE ATTACHMENT Thomson Sd 13,793' 12,713' Pre-Miss 13,837' 12,751' 31. LIST OF ATTACHMENTS Perforations, Sqz Cmt Summary, Formation Test, Well History, Core Data' 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .., Title Advisor Date 7/2/82 . c,- - INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiPle completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. FORMATION TESTS EXXON ALASKA STATE F NO. 1 Page 1 CONFIDENTIAL TEST NUMBER DATE TYPE TEST INTERVAL CUSHION HOURS TESTED PROD'N FOR TEST PERIOD CHOKE SIZE FLOW RATE FLOWING TBG PRESS TBG SIZE IFP 1 4/13/82 Open Hole DST 13,940'-14,316' Nitrogen 8 hrs.'36 min. 1092 MCFG + 61 BC 7/64" (1) 2,975 MCFG/D & 152 BC/D (35.3©API Gty) 7256 psi 3-1/2" 9262 psi 10,156 psi 9715 psi 10,161 psi _ (1)Based on 4 hour stabilized test. 2 4/22/82 DST Through Perfs 13,794'-13,830' (4 spf) 13,846'-13,868' (4 spf) 13,874'-13,884' (4 spf) Nitrogen 92 hrs. 58 min. 16,920 MCFG + 939 BC 8/64" (1)4,235 MCFG/~ & 284 BC/D (34.8©API Gty) 7504 psi 3-1/2" 9661 psi 10,119 psi 10,109 psi 10,120 psi (1)Based on final 6 hours of a 3 day stabilized flow test. 3 5/7/82 DST Through Perfs 12,890'-12,908' (4 spf) 12,924'-12,930' (4 spf) Nitrogen 57 hrs. 52 min. 183 MCFG (Condensate TSTM) 3/64" to 4/64" (1) 64 MCFG/D 412 psi 3-1/2" 7279 psi 9306 psi 7478 psi 6018 psi (clock stopped) (1)Based on 4 hour stabilized test. TEST NUMBER DATE TYPE TEST INTERVAL CUSHION HOURS TESTED PROD'N FOR TEST PERIOD CHOKE SIZE FLOW RATE FLOWING TBG PRESS TBG SIZE IFP ISIP FFP FSIP 4 5/16/82 DST Through Perfs 12,544'-12,590' (4 spf) Nitrogen 25 Hrs. 7 Min. 178 BW 12/64" (1)210 BW/D 780 psi 3-1/2" 7162 psi 7870 psi 5718 psi 7785 psi (1)Based on 4 hour stabilzed test FORMATION TESTS EXXON ALASKA STATE F NO. 1 5A & 5B 5/21/82 & 5/23/82 DST Through Perfs 12,008'-12,027' 12,052'-12,080' Nitrogen Misrun Page 2 FIDENTIAL 5C 5/25/82 DST Through Perfs 12,008'-12,027' 12,052'-12,080' Nitrogen 16 Hrs. 7 Min. 83 BO + 70 MCFG 6/64" (1)137 BO/D (22° API Gty) GOR 1040 1590 psi 3-1/2" 5840 psi 8278 psi 5471 psi 8306 psi (1)Based on 4 hour stabilized test Exxon Alaska State "F" No. 1 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) Ail perforations squeezed with cement. 13,940' - 14,316' MD (12,841' - 13,173' TVD) OH 13,874' - 13,884' MD (12,783' - 12,722' TVD) 4 spf 13,846' - 13,868' MD (12,759' - 12,778' TVD) 4 spf 13,794' - 13,830' MD (12,714' - 12,745' TVD) 4 spf 12,924' - 12,930' MD (11,985' - 11,990' TVD) 4 spf 12,890' - 12,908' MD (11,957' - 11,972' TVD) 4 spf 12,544' - 12,590' MD (11,671' - 11,709' TVD) 4 spf 12,052' - 12,080' MD (11,277' - 11,299' TVD) 4 spf 12,008' - 12,027' MD (11,241' - 11,256' TVD) 4 spf RECEIVED J U L - 2 ].982 Alaska Oil & Gas Cons, Coinrnission Anchorage , Exxon Alaska State "F" No. 1 CO IE NTI 26. ACID 13,9 13,7 13,8 13,8 12,8 12,8 12,9 12,3 12,0 12,0 40' 94' 46' 74' 88' 90' 24' 13' 08' 52' FRACTURE, CEMENT SQUEEZE, - 14,316' - 13,830' - 13,868' - 13,884' - 12,890' - 12,908' - 12,930' - 12,315' - 12,027' - 12,080' Sqz w/200 Sqz w/200 Sqz w/150 Sqz w/200 Sqz w/200 Sqz w/200 ETC. sx class G cement sx class G cement sx class G cement sx class G cement sx class G cement sx class G cement ECEIYED J U L - 2 ~82 Alaska Oil & Gas Cons~ Co~'r]miss~on Anchorage CONFIDENTIAL Exxon Alaska State "F" No. 1 28. CORE DATA Core #1 12,065' - 12,081': Rec 6' ss, med-dk brn, vf-mg, good porosity with oil stain, dip 40°. Rec 6.9' sh & ss. Core #2 12,572' - 12,618': Rec 10.8' sh and 34.5' ss, med-dk brn, vf-fg, fair porosity with oil stain. Core #3 12,905' - 12,915': Rec 5' sltstn and 5' ss, dk gry, f-mg, fair porosity with oil stain. Dip 25°. Core #4 13,818' - 13,826': Rec 8' unconsolidated congl with oil stain. Core ~5 13,826' - 13,833': Rec 4' congl rubble, It to dk gry, good porosity with oil stain. Core #6 13,833' - 13,838': Rec 4' ss and 4' dolo, it to dk gry, vf-mg, poor to fair porosity with oil stain. Aiaska Oil & Gas Cons. Commission f~nchora~e EXXON ALASKA STATE "F" NO. 1 WELL HISTORY CONFIDENTIAL Spudded well on November 1, 1981. Drilled a 17-1/2" hole to 2160' and ran open hole logs. Opened hole from 17-1/2" to 26" and cemented 20" casing at 2108' with 10,000 sacks of permafrost cement plus a top off job of 1300 sacks permafrost. A pressure integrity test below the 20" casing shoe leaked off at 13.0 ppg EMW. Drilled a 17-1/2" hole to 6905' and ran open hole logs. Set 13-3/8" casing at 6901' and cemented with 1750 sacks class G cement. Pressured up to 16.5 ppg EMW below the 13-3/8" casing shoe and did not leak off. At 7200' the hole was kicked off to the west using a dyna drill. Directionally drilled a 12-1/4" hole to 12,065' and cut Core No. 1 from 12,065' to 12,081'. Drilled to 12,096' and ran open hole logs. Set 9-5/8" casing at 12,096' and cemented with 2500 sacks class G cement. Pressured up to 17.9 ppg EMW below the 9-5/8" casing shoe and did not reach leak off. Drilled an 8-1/2" hole to 12,906' and stuck drill pipe. Failed to get free with oil phase pill and black magic pill. Backed off at 12,509' and placed a 190 sack cement plug on top of fish. Dressed plug off to 12,403' where the hole was sidetracked using a dyna drill. FiSh in old hole is from 12,509' to 12,906'. Drilled to 12,572' and cut Core No. 2 from 12,572' to 12,618'. Drilled to 12,905' and cut Core No. 3 from 12,905' to 12,915'. Drilled to 13,811' ~nd cut the following cores: Core No. 4 Core No. 5 Core No. 6 13,811' to 13,826' 13,826' to 13,833' 13,833' to 13,838' Drilled to 13,950' and ran open hole logs. Set 7" casing at 13,940' and cemented with 1350 sacks class G cement. Pressured up to 17.1 ppg EMW below the ~7" shoe and did not leak off. Drilled out of 7" casing with a 5-7/8" bit and reached a final total depth of 14,316' on April 3, 1982. The following interval was tested from open hole: Test No. 1: 13,940' - 14,316' The following intervals were tested through perforations: Test No. 2: 13,794' - 13,830' 13,846' - 13,868' 13,874' - 13,884' Test No. 3: 12,890' - 12,908' 12,924' - 12,930' Test No. 4: 12,544' - 12,590' Test No. 5c: 12,008' - 12,027' 12,052' - 12,080' CONFIDENTIAL Test No's. 5A and 5B were misruns from the same perforated interval as Test No. 5C. Test interval No. 1 was squeezed below a retainer set at 13,651' with 200 sacks cement. The retainer and cement was drilled out to 13,903'. Test interval No. 2 was squeezed below a retainer set at 13,580' with 200 sacks cement. A block squeeze was performed through perforations 12,888' - 12,890' with 150 sacks cement. Test interval No. 3 was squeezed below a retainer set at 12,815' with 200 sacks cement. Attempted to squeeze test interval No. 4 below a retainer set at 12,320' but could not break down perforations. Block squeezed through perforations 12,313' - 12,315' below a retainer set at 12,250' with 200 sacks cement. Squeezed test interval No. 5 below a retainer set at 11,850' with 200 sacks cement. Perforated 7" casing at 1783' with a casing punch gun. Set a retainer at 520' and pumped 15 ppg permafrost cement through perforations and up the 7" x 9-5/8" annulus. Placed a permafrost cement plug from 520' to surface. Pumped 400+ barrels of calcium chloride water down the 9-5/8" x 13-3/8" annulus. The well was plugged and suspended at 2200 hours May 30, 1982. spepp -sun April 13, 1982 Mr. Roy Masonheimer Exxon Company, U.S.A. Pouch 6601 Anchorage, Alaska 99502 CONFIDENTIAL Re: Our Boss Gyroscopic Survey Job Nos. Boss-16931/16998 Well: North Star F-1 (SEC17 T10N R23E) Wildcat Field North Slope, Alaska Survey Date: April 6, 1982 Operator: John Samec Dear Mr. Masonheimer: Please find enclosed the "Original" and five (5) copies of our Boss Gyroscopic Multishot Directional Survey on the above well. This survey is a combination of gyro data from job no. Boss-16931 dated November 29, 1981 and gyro data from job no. Boss-16998 dated April 6, 1982. Thank you for giving us this opportunity to be of service. Sincerely, KA/pr Enclosures NL SPERRY-SUN, INC. Kirk Afflerbach District Supervisor CONFiDENTi · __. ...... ~ .... · ............. ~ ............................................. ..E;~:ER~'~._-_.':;L!hL NELL ~SL!FcVEYING. £:OF~:'K-~NY~ :i: ::::i::':: ' i:: :: ::: :: -': :.::: :::ii:.13 :(:~IqF:I,IOF;AC)E ::ALASKF4. i: . - ' '::: ~ X::~ON cOPtF?~Y~:I.:!:;:F;~:A:": ": :: :..::::: i]::: ;::. :':: 7::~::: : :: ::NOR TF.~ E;TAR. F- (:'-'=;E~:: t,.$ZLDC~T APR].'L G., 1'::°'-'./,_,.~. ,_lOB NUIdBER 'E.U.=,.=,- 16':T/:'.'::1 / 16 'P 'P ;3' - '-"-' ALA.'-z;K¢~ i<ELLY BUF;F.IZNC~ ELEV. = 42.01 FT. I"IEP~L--;LIRED VERT I C:~L VERT i C:AL :'[ NOL ]: N~'T' 1'. ON /01RECT I O1',1 :SEVER I TY F-~E F:TAI',IGLIL ~'q.R ...uuRD DEPTH DF._'PTH DEF'TH DEG M I N DEGREES DEG/'1 O0 NO,TI-.-! / :F_.~C~LI"t"H E~.S;T / NEFFi" Fi~EC:T T ON ® ® ® CONFIDENTI,N. i ......... ~RY__,_S. LIN .WELL ~SL!R.t~E¥ING_.COMPANY .................... I-'AGE. WILDC:AT rziPRIL 6, 1982 dOB NLIM£-~EF,~ ~LASF-':.'A KELLY BLISH I NG ELEV. -'.': 42.01 FT .................................................... OPERATOR~:'S~'4MEC .....................-, . ,...~. - . ~ ~, '""'il-':'TT'i. 2"% ........ ..'~';!:.:-~T~' .,. , ...... . ....... ,.__. ~ !::~:.:!VE.R~T:!~...A.L....:,SE.CTIUNZ~,~i~;;~LIL~TED'¥:~LONLt~:.~.~.z. IIti.L!~H'~i ~Z!b-..~ ..Z~'~,L:~I~O~ DIE.~R~E~:~ ::'.: :::'0: .:.:. · .. .... :~.~:.....~. · · - .. 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WILDC:AT APRIL 6, 1982 ,_lOB NLIMBER BOSS-16'~31/169'F~8 ALASKA KELLY BUSHING ELEV. = 42.01 FT. :~-.:.~: ::.:': .. . .:~: .:.... :. :: . ..., '"'' ... . :~...~.. · ...:-:].:.~-.:7:=,-.:~--- .--.:~-.::.,.=~ .... -]./~.-. · ...... ]...~ - .~-. . ...................... : -- TRUE '-1 "- .:, _IB-.:,ER TOTAL ~ , HE~.:,L RED VERT I [:RL VERT I CAL REC'/~NGi_iL~R L. UURD I NATE.:, HD-TVD VERT [ C~L DEPTH DEPTH liEF'TH NOF(TH/SOLITH ER.:,I' "" '/~EST D I FFEBEN]~ ......... k~L!.BRE' ..... ' ' ~-. ...... [ I DN . .................................................... ~ ... .. :. - ::::::::::: :: :::: : ::: :: :.:7 ::::::::::::::::::::::::: o ;' oo .. :::~:- .... ::~ ::.::.:.. ~ ... ~ :- . ~ ... 4~:.~::~ t:,--......::. '~.'I-~C~0:, 00: :::~.::~.-~:: :.':.-::::.~::::~:.~::, ~::'~-:~:~::~:,~: 6-> :'~, ........ ::~:~: ..'" ::~::- ":.:4,.~-?~,~2.. :[=", ::_'~.:.:.:'; ~_._9~_~:2~:: :'~::.__~___~ ..... ~L~C~(2 · ' ' .:':.:::"' 2042 2042.01 2000. O0 : 1. 'F':3 S 5.14 E O. 02 O. 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O0 27.02 .:,'-' 1._ :,, O0 E~."~ ,:,Y '~' O. 11 7144 7142.01 7100 00 '-'¢ c,.~ 27 '"' , . . c, l ..... ,,37 E '-' '"~ ~. ;.._, 0 08 · ~, ~ '~, .-~ -) .~," . . . .-,~ , - ,-. . ~ ,.~.~ .-, - . . ~= - ~.~:= .Z~4_. ~ ~=~ Z~.~2, ~,~&~ ..... .~.,~,..,._¢~) ...-~ ............... 1.,.~.~.,, .-.~_~.._.E .................................. .:,_,.. lc) ............................... u.. 1 .J ........................................ :::::::::::::::::::::: 734~ ":::: ': 73~2:;-:0 ~::/;::..: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::: '..':::.' 3"'/-,~ :".:'::: :..::: ...:':. o. 5::~-: ::::::::::::::::::::::::::::::::::::::::::::::::::,' · ." :::::'.:'::'::::.. :?...:...:':"::':' :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::.".: :::::':::~:..':::':'": ............................................. :?:' ::.' -.~ ;21 .................. ::: ".::'-:~,' :"~".'-' : ......... :":':- ' ~:.: ~:::." ' '" : · ':':: , - ~ .~ .: :'' .: ::::.:::::.::: ::.: ::::::::::::::::::::::::::::: ~ ~ 7 ::::.:-:.:::.::::-.: :.::::: 7~ 4~: :~:::.0. t:.:: ::::::::::::::::::::::::::::::::::: c~.O:., :. ~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :J ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~=, ~.:.:~. E. ::... '.:-..-:-¥.. -::: :.:. o..=, c~-. 1,6 ~ CONFIDENTIAL ................... '. :3F~ERRY-SUN. WELL._SUF(VEYING~,.COMF'ANY F'AF~E W I LDC:AT ~PR I L 6· 1 '-'.-; o ...-'-"-' ,_lOB NI_IMBER' BR::::::;- ...... 1/-,9::: 1 / 1/:,'-:>9:3 ALASKA KELLY BUSHING ELEV. = 42.0i OF'ERATOR-SAMEC ............ .:: . ::: :: :::. ::.:. : ' '.:i! . TRUE :3UB-SEA TOTAL MEA.=,L RED VERT I CAL VERT I CAL RECTANGULAR COORD I NATES MD-TVD VERT I CAL DEF'TH DEPTH DEF'TH NORTH/SOLITH EAST/WEST D I FFERE::NCE . CORRECT I ON . _ .................... ......................................... : ...................... ............... .. ~ ........................................................ ~ ..... , ............................... ? .. · :. .:!ii: ,-., _=. · %.14 : ~ .-:::..' · :.: · 3.._4 ..::' ::' . 77.~':' 7742.01 7700 O0 '-"'--' . i ..- .... 66 S '.:;:3 · 24 E 1/--,. O0 4.62 '-'" ]. . -' '- _ _ 5.96 78/_-,3 7:_--:42. C],1 7,_-.(...K. O0 14'..-? 44..'_-, 6Y..':?,A E 21.96 ,_.777! ......... 7.942.... 01 ......... 7'F~OC.!.O0 .¢... 177. i0 S 41.70 E . :29.40 7.4.4 .... · : =:C}'=-" 'l '=' ' '~-~:" :':::. L-,': .;' ',~ :". :- =============================== ,.,;"7::': "' c::-::-;~.' :' :' :"""::::.::',:.;- ~=;T-'"7'::.-' '"T": .......... :7':- .,,,.-] "'~ -': .... :' ...... :': ?":' ";... ' ' ......... ...... ...... ::.::::: :.: ::: .::::: :,.,..,...,C. ,_,U4.- .0I ::::: ..... ::::::::::::::::::::::::::::::::::::::::.:E,::.:..:::.: ::.::.:.. ::::::::::::::::::::::: :. :::.: ':. 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O0 --,-- .. .22'"?. . .96 N 11 '4 /-",2 ,_-, ::::: :::.:::::' ,"~, ~': :.,-,~. ,-,: . ::: : ::.,---, ~ - ::::::::::::: ::::::::::: ::::::::::::::: :-.~,: ~-.: ::::: ~;',L',. :::: : ' · : · ---,.., ,--, ,--, ,--o · '. ' : :::::::::':::.:::: :::::.:::'.::i----:'----~---l~TM ::::.: O: '%, ':: ~: :::::: :::::::::::::::::::::::, , ::: ~ ::::::::::::::::::::::::::::::::::::::::::::::::::::: :.::"::::i!i Z:::::~"~:~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::: '~%::::::::! ~::::::::::: ':' ::::i::::: ;:::: ::::i :::: ::::: ': ~. ::::'::~ : :::::'::::::::::::: ::::::::::::::::::::: ,-, - ~ : :; :' : :: ::; : '. - .. CONFIDENTIAL ..................................................................... · --~r~E(~.:_,:,UN_..W~~URVEYI Nu L:O!dE ANY ................................................................. F.AL~_i W I LDCAT APR I L 6, 1982 JOB NUIdBER BOSS-.- 16931 / 16998 ALASKA KELLY BLISHING ELEV. = 42.01 F'T, , OF'ERA TOR-.SAME C TRiJE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL · DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST B I FEERE~E:E ............ CORBE~;;]] ~.Oi~ ............................................................. ...................... ,; · ...... .:.. ~,4.,.:.::0i:::-::.:::- ........ -:...¢::.,~.]-. ~ ]~]::.:.:..::: ....... -.-::-::.: ................ ~;I~,:~...,-i::-.-,-:: ................ :.: ........ ,-,~,5,:- -,&::W: ........ ...... ~,~.-., .-.,, :: .-,., ,-, · 9990 9642.01 :9600. O0 ~: 637.71. S 926.97 W 348.38 24.99 10115 9742.01 9700.00 660.80 S 997.85 W '373.11 24.73 10240 9842.01 9800.00 ~: 683.15 S 1069.71 W .._: ....... 378,2~ ...................... 25~16 ::::::::::::::::::::: : * ;m' ~ ~ .... : ; ~:/ '~: ': ~ . : ::: ~- ,:~ ~. :: , . ========================= :::~:~:~;~;: ~; :~::: ::;:: :: ,~ :::: ~.~ .... : ·-'~ .:'% :~:r; : .... -~':, ,:,,2 :; ~,~= '~, . ~:~.~6-~ :; :: ~:.: ~ y:~: 00. ::::::::::::::::::::::::::: tt 4~::.:::Z,¢.:~: W :.:::..:::-~: :::: .::: .: .4~-, . ._, .; ........... :: : ~,. 6= : . · · ;:'~: '::~:~ :::~::::/;::~::;~;:~i ::"~ ~::~; :::::::::::::::::::::::::: :~ ': ~ :::' t~t i~: ;:.' ::'~::::~:~::::~ : ':~:~ ::~' :' ~::~:;::: ~' "~'h !~;;~::~:~;~:.;~:.;~;;~::.::.~:;~ :~:.: ~!i ~::":;' "::;~;~::'~i~ :~::~:.;~?~;:~;~:~::: ~ ;~:~::::':;~;~:?~:::~;::~.'::: '. :? :~ :. :: :::: : ::;t; i::'~ ': :.. ::: ;-", ' ,-' ' : : : :: .' :: ::~:.~::~;~ 10745 10242.00 10200.00 765.17 S 1366.98 W 503.35 26.87 10871 10342.00 10300.00 784.44 S 1441.17 W 529.35 26.00 ' -' ,~,*~.' :~::.:::: : ', 'T* ::~ · :::: ::: - :' ~ ,::." ~ .: :::?: ::~?:~::~::::::::::::::::::::: ;:~-~:~::,~..~':.: ,~.' ::~,~,-: ,-., : ~:~ - ~": : · : ...N .-, . : ::¢~': '::Ct~; ':i'::::;j~:~ :~: ~/:: '; ::::::::::::::::::::::::::::::::::::: ............................................ ~:";~ )?'::~;:~:/::~::.::.::~: : ..:~ .... :, :. :. ,-,6 .:, :, ::. :: ' . 11508 10842.00 10800.00 871.06 S 1825.75 W 666.15 28,02 116:35 10942.00 10900.00 886.40 S 1902.51 W 693.14 26.99 ! :::::::: ::~:: .: :..~: :~"~ ~ : ":~; : :' : ::::.: : : :::'" : : :~ :::::::::::::::::::::::::::::::::::::: :~ ';:::::: *~ ~ '~ ~--~:: ~:~:~::;:::;::-~t i ~ ~::; '; ;~ :::: . : '. ::.::: i ,-~;: .--~ :;. '... · : ,-~ ~'~ · :':: CONFIDENTIAL i~. ~, ~ ,i I~' i ~.-. ,~ ' --. ~. -- ~ WILDCAT AF'RIL 6, 1982 dOB NUMBER )F,-'"-' /,D--', E, J,:,.:,- 1 :,; .:, 1 / 1 ....... ,_, ALASKA ' KELLY BUSHING ELEV. = 42.01 FT. ' OF'ERA ~OR T SA NEC . '1 ,-'! ' TR JE .:, _IB-.:.E~ TOTAL HE~SLIRED ~ERTZC~L VERTZCAL RECT~NGLIL~R COORDZNATES HD-TVD MERTZCAL ' DEPTH DEPTH DEPTH NORTH/SOLITH E~ST/NEST D Z FFERENCE CORRECT Z ON ::::::'::.:.......-:...:.:: ,-~..~4~.:' '.. . .:~. -,~.. :. , ~..:.:...; .:.:, -..... ~ ... ·-...:..:. ~:;. · .~:~,=~-,~ '~;- ,-. · :...: .~; ,~ '.:. .~,: .': . .. · ,, .. .,~ ::~ ._' .. .... : . .=,..., ,-,.- . . · · ~.: :..:..-.Z~.1*~.: ~ t..,4~-. 00::. .1 1.,,00, O0 ...:..: ~....... :...~.:~,..::~ ~ .... - zl Y5,.4~, N. 7Y1', 1c, ......... · ~.:,. ~,7 . ' '~'--~ '~ ' .~· ' .' ~4 ~'- ~ . ~_. .....;~,.~ . ~ ....... ,:~. · · ~. :,.:v: '.: . · . ..:~ . . ,~ ., , : "::..~ :. '.." I22.JL I i442',00~ ] 1'400, 0~):.::.;'. ??:/..?~:.: ~:~:8::~'.~0.. S -~:?~':"227P';:l~:"W ..:' · :.:"L:16~ i 5:?:'L:- · · 25. cb; ' ... 1 ©'-''-' ~ '~' .~.:,o4 11 O0 ~F]o O0 941 4t~ S · _4~. 11 2346 64 W 842 07 '~=~ '~1 12~(]::: 11642 00 11600.00 t~z48 ._~':; S '~ ':' - ' :::6/-, ~4~u 7'F~ W 24 7'F~ 126:2:0 11742 0C) 11700 00 '- "" ':' '-' 'q'-' "~( ........ -, ' .. ' :-'. '~ ~ · 0 '~ · , ~' · · ' ~:~ ' · .... '-' ...-"..: .-.'::.- .... ,~1~ :' .' ~ ~ ~.~ .: [-, - ~- .-,~-j ,-q - :-. 1 ~7~ 1. :.: 11 ,_,4~. UU..: 1.I,~,U0. (..H:} .:~..:.,:..~.::.~..::~.:.. ..... . Z4..,. I Z .::.:.. .,.. - :.. ~:....~.J...,u. ;~,.:,. ~ ..:... . ~,0~..:,o . .: .~ 1. U7 · . .' :.:'....' ::-" .-~i~,. .~:' ' ,~ ~'. ',.~":" ::.. :.: '-:..',?. ~ ~.'. '~ ~ :: .: ~.:'.: ....... ~ .~.::.:~:::':~i~;': .L: '~',.. :: ~.~.. ;~.' ~'.-,.~ ' [~ .':' · · ~...-, ~ : ~ .: ........ .?~ . .-~ . :. :.:..:. · . : ....'..:: .1 ~:,7~ ':'... :.. :.::'1.1 ... 4~, 00. '. :':'. :::. ~:I ~.00 ~. 00: :.~:..:.:::::::'::.:~:~:::~:::~:~:~::~'::~'::'~":~t~!:,.t:~:~:-..~ ~/::.~:,:,:-:::.~:.~:.-::::~.~::::'.'.~6~:.,'-6'=~':-. ~:-':::~-.~ .-:: ..'. ;~.:,U ~ 10 :. :.:..:..':.' .... : ....... : · ~U. 7~ .... ' :' ..:.'.. :..:: ....': :' ... ,:::~.' . :'' ':'.: - -~,q-l,:z-:,. :' :' .~ -' -~ ' "'. -"':-:-: :'- . .~ ,- ~" ~ -' '~::..~::::..: .::~::'.'::::.~?~':::~ :: .i~ ,~" ':¥': '-: '~ ~:::-.~..::: :~:LL~:::. ~ ~,"'~ ,~,~"'..,!,..' ,fi*' : · :.:- ' ..:: .... . :.:.' ~-,~: -.. ' ~ '. · " .~ ...:: .' :-., - : ': : ... : " .......... 1~.... ~ .:. i~04~..0U...:..-.-..I~0.00.00:-.'-..':.:..-::'- :'::-.-..'-: ,..~o6, '10 .-;:,.:.,-~:,.'.:-:...:.~6,:,~.~:'7z W' .:'. '- ..... ~.._,0, .:,/ ...... ::'.' - ~(~. 47" -':'~'..' .......... 1311 '" '-' 42 '~- ~ I~ 1 ..... O0 12100 O0 ~87.67 S ~7::,o, '~1 W 970 Fl I 1'~). '~4 ~,.~._,~ 12242,00 i'~':,F~O O0 '-'"'= 9:~ S ':'"'":' . _ ,_1~1 13352 12342. O0 12300. O0 '~7'~. 'F~ 1 S 2888,, 08 W 1010. 42 20.28 .......................................... '~"::'"': ':" :~l ','D'"' ':" '"~' ;';:" '":::' '~'= ~' ~"" '"::~':":~:'"'~:' ~ '::'~':"~z~ '":::::~ ~:'''*~;''':'''~ : :~ '~' ' ::: ~'~ ' ' =': ~'" ' "' ,':~ ,'~r:"" ' ' ' '' ' " ' : ' ~.' .:- ..::..'~.:~.~1 ,: ~ .. ~ :-:.:' 1 ~..,.4~, 00':.: 1 z;:~(.~(.], OU'~::.":~::~.:'::~.::::~:':.:~:~ ~::::~:~:~::.':~ ;~::~.. ~o'.~..:::.:,::::::::::::::::::::::::::::::::: i ~ :~,,~.-.W ~::::~ 10~,0 ~ ol .." -.. "~.::~'L:::::'.:~'.':i ~ · ,:,~ .' '.".:,':::" ::.::: ':::. '~: "F:'.: ::'. "' .-~ '.'" . -::: :':.: :':': ,~. · .": ~' '".~. ? '-.-~ ': '-'- ~.' '. ~'..:~.:: ::::~:::.-~.~:i~.~:~:::~::~:~.~tj~:~:~:~:.:':::::-::':~'J~:. ':L: · -~:-.::.:'"- .: :~: ~::~v'F:-!~.~::/~h-.::~:.:..~:::~. ~.:,?::~ -:' :.-~/.':' ':.~ :'::.... · :'.: ~"./:::: : -': .~ ..".:. :": ":" '-/:::' ." -- ' ' . ' '.:. :' .' ': :..'.: . .:':. .~ ". . . .: .. :.. .. . ~ . ~ . ...:. . ....i ~ · · :: ':':: :...-:.:.::..,-::::-.I ~ .e~ ,.: ~,":":".: :::.::.'~ -I .i.l'. :'.: '. ' ' .' .: .' ? I~.- ~I .. ..... i~ · - ~l ,.' . ' :: 1.~.71o - 1~E, 4~.,.O0 : 1.~6uu, Oo .............. - .......... · ...... :::.: 44 ~.:.-~7- - .,,- ::. ......... ::.. :~,0,:,~-, 76.. W. · -1~*~-,-.,,,,4· -.-. 1,,. 13826 12742.00 1 ~7(. u 0C) 929.01 S :~ 1 :~ 84 W 1084 ~;4 1 ..,. 70 · -'-/ 9 43 c- 1:~:cC~(]0_. . 12:z:OA_. _. 10 1~ z z. 4. 10 . 1'-'o. ._, 3171 .20 W 10'~3. '~4 9.40. -35~0.00 Exxon Company, U.S.A. Our Boss Gyroscopic Survey Job No. Boss-16931/16998 Well: North Star F-1 (SEC17 T10N R23E) Wildcat Field North Slope, Alaska Survey Date: April 6, 1982 Operator: John Samec Scale: 1" = 500' CONFIDENTIAL TRUE NORTH Surface Location ( 360FNL 1817FWL) -~o~o. oo _~o. oo -~o~o. oo -~ ~o. oo . ~ ~ m ~ ~ ~ m ~ ~ HORIZONTRL PROJECTION .-500. O0 -! 000. O0 Exxon Conl~any, U.S.A. Our Boss Gyroscopic Survey Job No. Boss-16931/16998 Well: North Star F-1 (SEC17 T10N R23E) Wildcat Field North Slope, Alaska Survey D~te: April 6, 1982 Operator: John Samec Scale: 1" = 3000' O, O0 3000.00 8000.00 9000.00 12000.00 15000.00~ - 3301.52'~ S73° 50' ~ 13900 30~30. O0 CONFIDENTIAL 60~0.00 VERT I CRL PROJECT I ON Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Operator, Wel'l Nan~ and Number Reports and Materials to be received by: -2?- Date Requir .ed Date Received Remarks Comp l etio n Report Yes · Well .History Yes 7--O X- 4Q'>' Z:_~.. t'~' G-- .... ......... ' ~ , , , .Core Description y~ ?- ~ ~- Z2k L..~, /":P- ..... Registered Survey Plat ?L~X Inclination Survey .//~' Dire~iOnal ~ey ~"~'::~'~' .' ,, , MEMOR -,NDUM, · TO: THRU: Edgar W. Sipple, FROM: Petroleum Inspector St[ e of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION C. ~~~ee rton Cha~a-~ Lonnie C. Commi ssioner DATE: June 9, 1982 FILE NO: 108A/I TELEPHONE NO: SUBJECT: Witness Plug and Abandonment at 11,850 Feet Exxon's North Star Island Exxon No. 1 S17, T10N, R23E, UM Permit No. 81-140 Saturday, May. 29,. _!9.8.2 - At 12:50 a.m. I witnessed the stabbing in of the EZ drill. With the drilling string weighing 165,000 pounds, I witnessed 55,000 pounds on the stabbing of the E.Z. Drill. The initial breakdown was from a pressure of 5900 psi at one bbls/min to a pressure of 4000 psi at two bbls/min. When the squeeze w~s .completed, there was a 4900 psi buildup. I left Exxon's ~]orth Star Island Exxon's No. l, to return to Sohio's Alaska State No. 1 at 4:30 p.m., subject of a separate report. In summary I witnessed the plugging of Exxon's North Star Exxon No. 1 on the cement plug set at 11,850 feet. 02-00IA(Rev.10/79) O&G #6 - 4/80 Operator Company Repr Lease No. A0z,,312~&Zwell No. Total Depth Elevation Casing: STATE {)F ALASKA A~" KA OIL & GAS CONSERVATION COMM~" 'ION Plug & Abandonment Report % Date Drilling Permit # ~ Sec. T-~/7- T/O/~ Mud Wt. 'Drive Pipe ~D" "O.D. Set at //~ Ft. w/ Pene. ~ "O ~ .. Conductor ~ .D. @ ~ f ~ Ft. Surface., /3 ~ "O.D. @ &~d/Ft. Intermediate .7~/~ "O.D. @ /~ ~ Ft. Production ~ "O.D. ~/~QFt. Plugging Data: 1. Open hole plugs: 2. Open hole isolation plug: 4. Annulus plugs (if any): 5. Casing stub plugs: 6. Surface piug: Casing removal: REMARKS: "casing cut at "casing cut at "casing cut at -? STATE OF ALASKA '.~ AND GAS CONSERVATIO~.~ ALASKA ,, .. ................................................ 2. Name of operator 7. Permit No. Exxon Corporation 81-140 3. Address 8. APl Number Pouch 6601, Anchorage, Alaska 99502 so-089-20019 4. Location of Well atsurface 360' SNL & 1817' EWL, Sec. 17, T10N-R23E~ ~ 5. Elevation in feet (indicate KB, DF, etc.) KB 40' 6. Lease Designation and Serial No. ADf, 312862 9. Unit or Lease Name Alaska State F 10. Well No. Exxon No. 1 11. Field and Pool Wildcat For the Month of Hay , 19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks EOM Depth: 14,316'. Mo. Footage: 0'. Perforated 7" csg at 1783 (4 spf) w/csg punch gun. Set retainer at 520' & pumped 15 ppg permafrost cmt through perfs & up 7" x 9-5/8" annulus. Pulled out of retainer and placed a permafrost cmt plug from surface to 520'. The well was plugged and suspended May 30, 1982 at 2200 hours. 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run RECEIVED 16. DST data, perforating data, shows of H2S, miscellaneous data See Attachment ~,0n~. c0i-nmissi Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~.~ 9._~r~1~ ~!~ TITLE Exploration Advisor DATE June 15, 1982 NOTE--Report on this(4Jorm is requiredrfl~%ach calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 16. DST data, perforating data, shows of H2S, miscellaneous data DST No. 2 bottom hole pressures: ISIP 10,119 psi, IF 9661 psi, FF 10,109 psi, FSIP 10,120 psi (clock stopped). Squeeze perfs below a retainer set at 13,580' with 200 sacks class G cement. Perf 12,888'~I'27~8~3U~'~'~ 5l~ck squeeze with 150 sacks class G cement below a retainer set at 12,875'. Drill out retainer and cement. DST #3 from perfs (4 spf) 12,890'-12,908' and 12,924'-12,930'. Ran nitrogen cushion to 5350 psi. On a 4 hour stabilized flow test the well produced gas at a rate of 64 MCF/day on a 3/64" to 4/64" ck with 412 psi wellhead pressure. ISIP 9306 psi, IF 7279 psi, FF 7478 psi, FSIP 6018 psi (clock stopped). Squeeze perfs below a retainer set at 12x815' with 200 sacks clasS G cement. DST #4 p~rf~~,~'~F~~~ .......... (~'~ spf). Pumped nitrogen Cushion to 5300 psi. On a 4 hour stabilized flow test the well produced water at a rate of 210 B/day on a 12/64" ck with 780 psi wellhead pressure. ISIP 7870 psi, IF 7162 psi, FF 5718 psi, FSIP 7785 psi. Could not break down per.fs below a ~etai_n~_r~DDt a_t~.~l~2D'. Perf 12,313'-12,315'. Block squeeze below a retainer set at 12,250' with 200 sacks class G cement. Perf (4 spf) 12,008'-12,027' and 12,052'-12,080'. First two attempts to test (DST No's. 5A and 5B) resulted in misruns. Pumped nitrogen cushion to 4200 psi for DST #5C. On a 4 hour stabilized test the well produced oil at a rate of 137 B/day on a 6/64" ck with 1590 psi wellhead pressure. ISIP 8278 psi, ~IF 5840 psi, FF 5471 psi, FSIP 8306 psi. Squeezed perfs below a retainer sek~a~.~8~ with 200 sacks class G cement. JUN - Oil & Gas Cons, Commissio. Anchorage E .ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION May 28, 1982 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached is our notice of intention to suspend our Alaska State F-1 well on North Star Island. The operations will begin following completion of drill stem testing as per our Sundry Notice dated May 6, 1982. Also attached are figures of the final wellbore, wellhead and abandonment well marker. Very truly yours, RLS: rms 84/M Attachment s 295-665-100 cc: A. L. Hermann A DIVISION OF EXXON CORPORATION 1 STATE OF ALASKA ALASKA AND GAS CONSERVATION C ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLXZ] OTHER [] 2. Name of Operator 7. Permit No. Exxon Corporation 81-140 3. Address 8. APl Number ?ouch 6601 Anchora§e, Alaska 99502 50_089-20019 4. Location of Well 360' SNL and 1,817' EWL Sec. 17, T10N, R23E, UM 5. Elevation in feet (indicate KB, DF, etc.) +4.0 Mean Sea Level (Ground 6. Lease Designation and Serial No. ADL 312862 9. Unit or Lease Name Alaska State F 10. Well Number Exxon No. 1 11. Field and Pool Wildcat 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] - Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other Suspend [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This is notice of intention to suspend the captioned well. The operations will begin followimg completion of the drill stem testing described on our Sundry Notice dated May 6, 1982. The procedure will be to perforate the 7" production casing at about 1790', set a cement retainer at 500t, pump cement in the 7" casing below the retainer to the perforations and up the 7" x 9-5/8" annulus to the surface. A balanced cement plug will then be placed on top of 'the retainer to the surface. Final abandonment of the 13-3/8" x 9-5/8" injection annulus will take place at a later date. The well will be abandoned as shown in the attached wellbore sketch, fig~ure The wellhead and abandonment marker detail are also attached in figure 2. RECEIVED Subseq~ent Wor~ 1Repor~ec~ 14. I hereby cer,~ Signed ~ MAY 2 8 i982 Alaska Oil & Gas Cons. Commission Anch0rag~ Date Title/~'~ ~t~__~' ~wv ,~ The spa~ for Commission use Conditions of Approval, if any: Approved Copy Returned ORIG,I A[ SlGN[D' ¢/-,r- BY Li]H~tiE C. SMITil By Order of Approved by COMMISSIONER the Commission · Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate FIGURE 2 · Alaska St ate F ~IOENTI~L (~.W~e~llhead Abandonment b~-/V ~f~P~'~fD ,~ ~oill Well Marker As Follows: Exxon Corporation Alaska State F Exxon No. I. 360 ft. SNL 1817 ft. EWL Sec. 17 T10N R23E UM 0.,o '(3. . 0 Approx. .14" P evel Gravel Fill Flan~ Wellh C-sect 102" Wellhe, ad B-sectio~ ] Wellhead ~ I ILI A- s e ~/t ion / I / I RE£EIVEB ~AY 2 8 Natural Level ^,' ,~,~-'~.~,ka Oil & Gas Cons. Commission Base Plug @ 1790 ft. (Perfs) Minimum Base Cement 2109 ft. 9.9 ppg Mud Calculated TOC 3400 ft. 15.8 ppg Mud FIGURE 1 Alaska State F Exxon No. 1 Final Wellbore Sketch C Section B Section __ A Section 30" Structural Pipe @ 114 ft EZSV Retainer @ 500 ft. 20" 133 lb/ft. K55 BTC conductor @ 2108 ft. Pit 13.0 ppg Non Freezing Fluid to be placed later. 15.0 ppg Mud 13-3/8" 72 lb/ft. LB0 BTC Surface Casing @ 6701 ft. Pit 16.5 ppg Calculated TOC @ 9000 ft. TOC @ 10,340 ft. CBL Estimated TOC @ 11,850 ft. MD Minimum Base Cement @ 12 008 gr. DIL ' _erfs. @ 12,008-027 12,052-080 ft. DIL 15.6 ppg Mud ,. Estimated TOC @ 12,210' MD ' ' 15 8 ppg Mu~ Estimated TOC @ 12,780 ft MD Minimum Base Cement @ 12,974 ft. DIL 15.6 ppg Mud Estimated TOC @ 13,545 ft. MD .. ~.. Minimum Base Cement @ 13,794 ft. DIL 15.6 ppg Mud TOC @ 13,903 ft. MD Minimum Base Cement 13,915 ft. MD 15.9 ppg Mud EZSV Retainer @ 11,885 ft. DIL F-1 Packer @ 11,895 ft. DIL 9-5/8" 43.5 lb/ft Pll0 LTC Protective Casing @ 12096 ft. MDI Pit 18.0 ppg EZSV Retainer @ 12,250' DIL Perfs @ 12,313-12,315 ft. DIL EZSV Retainer @ 12,320 ft. DIL F-1 Packer @ 12,330 ft. DIL __erfs @ 12,544-590 ft. DIL EZSV Retainer @ 12,815 ft. DIL F-1 Packer @ 12,825 ft. DIL Perfs @ 12,924-930 & 12,890-908 ft. DIL EZSV Retainer @ 13,580 ft. DIL F-1 Packer @ 13,590 ft. DIL Perfs @ 13,794-830 & 13,846-868 & 13,874-882 ft. DIL F-1 Packer @ 13,900 ft. DIL 7" 35 lb/ft Pll0 LTC Production ; Casing @ 13,914 ft. MD RE£EIVE TD @ 14,316 ft. MD MAY 8 Oit & G~s Cons° Commission COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION Ms. Kay Brown, Director Division of Minerals and Energy Management Pouch 7-005, 555 Cordova Street Anchorage, Alaska 99510 May 20, 1982 Exxon Alaska State "F" Well No. Surface Location: Sec. T10N-R23E, UM Bottomhole Location: T10N-R23E, UM Dear Ms. Brown: Exxon Company, U.S.A., in accordance with the May 14, 1982 decision by Commissioner Katz on Beaufort Sea Seasonal Drilling Restrictions, hereby requests approval of a change in the Plan of Operations for the Exxon Alaska State "F" Well No. 1 to allow for continued testing operations beyond the currently approved date of May 30, 1982. We wish to amend the Plan of Operations to provide that the second sentence of the first paragraph of the "Drilling Operations" section shall read as follows: DoWnhole operations necessary to complete cased-hole testing and abandonment of the well may continue beyond May 30, 1982. We have also submitted to the Alaska Department of Environmental Conservation a revised Oil Spill Contingency Plan which would provide for continued operations. We appreciate your past prompt consideration of our requests concerning operations on this well. It is our present expectation that these operations will be concluded by mid-June. In the event you or your staff have need of further information, please contact Mr. John Staffeld in our Anchorage office at (907)263-3713. - . Very truly yours, RS:jg Alaska Oil and Gas C° John~. ~'t~aaf~feld~~ ' nserv~~ ~m~~a c - t t 1 Alaska Department of Envir ' Alaska Department of Fish and Game c~~on of Forest, Land and Water Management A D~V,S~ON O~ ~XXON North Slope Borough ' ., STATE OF ALASKA , C0N Ft 13ENTIAL ALASKAi~i~ 'DGASCONSERVATIONCOM~t" SION 0~~~ MONTHLY REPORT DRILLING AND WORK VER OPERATI .. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Exxon Corporation 81-140 3. Address 8. APl Number Pouch 6601, Anchorage, Alaska 99502 50-089-20019 4. Location of Well atsurface 360' SNL & 1817' EWL, Sec. 17, T10N-R23E, UM 5. Elevation in feet (indicate KB, D,F, etc.) I 6. Lease Designation and Serial No. KB 40' I ADL 312862 9, Unit or Lease Name Alaska State F 10. Well No. Exxon No. 1 11. Field and Pool Wildcat For the Month of April ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks , EOM Depth: 14,316'. Mo. Footage: 136'. Currently in final shut in period of DST #2. 13. Casing or liner run and quantities of cement, results of pressur9 tests 14. Coring resume and brief description 15. Logs run and depth where run 14,316': DIL, LSS, FDC-CNL, Dipmeter, CBL. RECEIVED,. MAY i ? luoz Alaska Oii& Gas Cons. GommL~oll Anchorage. 16. DSTdata, perforatingdata, showsofH2S, miscellaneousdata DST ~1 from open hole 13,940'-14,316'. Ran nitrogen cushion to 5700 psi. On a 4. hr. stabilized flow test the well produced gas at the rate ot 2975 MCF/day & 152 bbls condensate/day on a 7/6'4" ck with 7256 psi wellhead pressure. ISIP 10,156 psi, IF 9262 psi, FF 9715 psi, FSIP 10,161 psi. Squeeze open hole below a retainer set at 13,651' with 200 sx class 'G' cement. Drilled out retainer & cement to ! ! ! ! ! ! 13,903'. DST #2~*~'perfs (4 spf) 13,794 -13,830 ; 13,846 -13,868 ; 13,874 -13,884 . Ran nitrogen cushion to 5900 psi. On the final 6 hours of a 3 day stabilized flow test the well produced gas at the rate of 4,235 MCF/day & 284 bbls condensate/day on an 8/64" ck with 7504 psi wellhead pressure. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED - TITLE Geological Advisor DATE May 17, 1982 NOTE--ReportJt;isform isrequiredforeachcalendarmonth, regardlessofthestatus, ofoperations,~and mustbefiledinduplicatewiththeAlaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 ReV; 7-~-80 Submit in dupliCate [' STATE Of ALASKA ALASKA .JL AND GAS CONSERVATION ~ .AMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL 2. Name of Operator 7. Permit No. Exxon Corporation 81-140 3. Address 8. APl Number Pouch 6601, Anchorage, Alaska 99502 50q~89-20019 / 4. Location of Well 360' SNL and 1,817' Sec. 17,T10N, R23E, 5. Elevation in feet (indicate KB, DF, etc.) +4.0' Mean Sea Level (Ground) I 6. Lease Designation and Serial No. ADL 312862 12. 9. Unit or Lease Name Alaska State F 10. Well Number Exxon No. 1 11. Field and Pool Wildcat Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] - Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment I-~ 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). Perforate, production test, and abandon 5 intervals described below. Each interval will be tested through 7" casing using a permanent packer set approximately 50' above the top 'perforations. Each interval will then be abandoned by setting a cement retainer directly above the permanent packer, squeeze cementing the perforations, and setting a 50' cement plug on top of the retainer. Subsequent Work Reported The anticipated test intervals are: om Fonm No./~-z/o~ Dated~_ DST #2 13,846'-13,868'; 13,874'-13,882'; 13,794'-13,830' DIL DST #3 12,890'-12,908'; 12,924'-12,930' DIL DST #4 12,544'-12,590' DIL DST #5 12,008'-12,027'; 12,052'-12,080' DIL DST #6 ~9,780'-9,794'; 9,814'-9,836'; 9, 861'-9,904'; 9,913'-9,924' DIL ' 14. I hereby cel~~j~t~true and correct to the best off.my knowledge. ~ ~~ Signed d'-/~ v Title ~ issi°nuse ~/ The spac for Comm 0il & Gas Cons, Conditions of Approval, if any: Approved -Opy Returned BY L~,~I!III g' ShtlIll By Order of Approved by. COMMISSIONER the Commission Date ~' -/~ -oC'~"- Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L Psl Psl PSI ~ o ~~/ ~i ~-Ps~ Ps~ Pst Soo o I ~{z.. z g~ PS/ goo PSI z 2g~"o Psi 3 ~?oo Psi 4 ,~(,,oo P P~5~ a r~ COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION April 22, 1982 Re: Exxon Alaska State "F" Well No. 1 Surface Location: Sec. 17, T10N-R23E, UM Bottomhole Location: Sec. 18, T10N-R23E, UM Ms. Kay Brown, Director Division of Minerals & Energy Mgmt. Pouch 7-005, 555 Cordova Street Anchorage, Alaska 99510 ~;~3' ( Dear Ms. Brown: Exxon Company, U.S.A. requests an extension of downhole operations for the subject well beyond the April 30, 1982 deadline specified in your letter of March 23, 1982. Sufficient time is needed to complete well testing and plugging operations. We anticipate that these operations can be completed during the first week of June, but at this time we limit this request to an extension to midnight, May 15, 1982, as per the Plan of 'Operations and lease stipulation No. 9. An extension has already been granted by the Alaska Department of Environmental Conservation for operations to continue through May 15, 1982 contingent on the status of bi-weekly reports on ice conditions. It is our hope a favorable decision on the issue of seasonal drilling restrictions will be issued shortly by Commissioner Katz and State Lease Stipulation No. 9 will be amended accordingly. In this event and in consideration of the need to continue operations on this well into June, 1982, Exxon intends to request approval by DMEM and ADEC to allow for the conclusion of downhole operations after May 15, 1982. Subsequent to the operations described in my letter of March 11, 1982, drilling and coring operations continued on the subject well. A string of 7 inch casing was set at 13,940 feet. Drilling was terminated at total depth of 14316 MD (13148 TVD) on April 3, 1982 with mud weight of approximately 15.9 lbs. per gallon. Logging operations were begun immediately and required approximately 4 days to complete. A testing program was begun thereafter and is in progress at the present time. E£EiVE Oil & Gas Cons. Coi~m.ts$ior/ An,chora,9~ A D~VISION OF EXXON C0RPO~ATiON Page two The critical need for evaluation of this well was discussed in my letter of March 11 and has not diminished. This testing program is essential to the planning and preparation for further exploratory activities in this area. Exxon's operations at Alaska State "F" No. 1 and at previous locations in the area continue to demonstate the ability to operate safely. We anticipate no change in this regard. Exxon is continuing to monitor break-up, climatic and ice conditions, assisted by Dr. Robert Llewellyn, and this information is being submitted on a timely basis to ADEC. Data acquired as of this date include aircraft flights over the major tributaries of the Sag, Kavik, and Canning Rivers on a twice weekly basis as well as daily monitoring of coastal road and ice conditions. Average surface temperatures during April have been near 0° Farenheit and the condition of the Exxon maintained ice road from East Dock at Prudhoe Bay to the North Star Island drillsite (F-l) is excellent. No indication of early break-up or thaw has been detected by any of the above surveillance. As mentioned in the previous extension request letter dated March 11, 1982 the average date for outflow from the Sag River which denotes break-up of the ice road is May 18 based on the last 10 years of observations. We believe that present conditions justify continued operations in the "winter mode" as described in our Plan of Operations and ADEC approved Oil Spill Contingency Plan through May 15. By monitoring Sag River ice conditions by aircraft overflights, we are able to predict ice breaking several days in advance. In recognition of the possibility that ice breakup may occur prior to completion of the testing and plugging of the subject well, we have prepared and will submit an appropriate amended Oil Spill Contingency Plan to the Alaska Department of Environmental Conservation. We further recognize that amendment is required of the Plan of Operations for this well for operations to continue past May 15 and will timely submit such amendment. We believe that technology is available which enables safe drilling operations year round in the Beaufort Sea area without seasonal interruptions, as demonstrated in our testimony and written documentation at public hearings held by the Department of Natural Resources on the question of seasonal drilling restrictions. In the event a continued drilling season were authorized without operational interruption, there is the possibility that Exxon would wish to commence drilling operations on a second well from the captioned location shortly after the conclusion of Well No. 1. The outcome of the testing program on Well No. 1 will be a major factor in this consideration. Page three In the event that you or your staff have need for further information, please contact Mr. John Staffeld in our Anchorage office at (907) 263-3713. Very truly yours, W. R. Warnack WRW:et cc: Alaska Oil and Gas Conservation Commission Alaska Department of Environmental Conservation Alaska Department of Fish and Game Division of Forest, Land and Water Management North Slope Borough RECEIVED APR ~ 6 i982. Ak~sk~ Oil & Gas Cons, Comrnissiml Anchorag~ M EMOR/ 'I IDUM To.at terton THRU: Lonnie C. Smi Commissioner FaOMMichael T. Minder Petroleum Engineer Sta(' e of Alaska ALASI<A OIL AND GAS CONSERVAT ION COMMI SS I ON DATE: April 22, 1982 FILE NO: TELEPHONE NO: SUBJECT:Witness Cement Plug and Pressure Test on Exxons ' s ~A 1 a~ska _St_at e F~ Well, Permit No. 81-140, See. 17, T10N, R23E, UM. _SaturdaY_,_Apri! 17, 1982 Harold Hawkins and I went to Exxon's Prudhoe office 'io 0biain' information concerning the plugback of above referenced well. We were told by Adolph Thomas, Exxon's operator at F-l, that we could not come out to the pad; after it was determined that we could (varified through Bxxon's Anchorage office) we were told the cementing would be finished before we could drive out; however, ~xxon arranged to fly us out. Then we were told by Adolph that they wouldn't be plugging till the next .day, Exxon set up a room for us in their Dalton camp. S1 1982 t//e called Adolph Thomas and discovered ',2~ an I/Z Drill cement retainer had been set in the ?" casing at 13,635' and 27 bbls of cement squeezed through it and that they were waiting on the cement to set up. We left the Dalton camp and flew to North Star Island in a twin Otter chartered by .F~/~k0~n. The purpose of this visit was to at least witness a pressure test on the cement plug across the ?" casing shoe. il 19 1982 The cement plug was drilled down to pressure test commenced at 3:15 A~; 5150 psig was placed in the ?" casing (with an initial loss of 50 psi during the first minute). The pressure held a.t 5100 psi- for the next 35 minutes, at which time the test was concluded. The inspection report, along with a well diagram and pressure data on the s~eeze job, is attached. Harold found that the choke manifold did not meet previous requirements of the ~ission concerning the remote operated chokes on the 10,000 pound manifold assembly nor was it con- sistent with API RP 53 specifications. He informed Adolph Thomas and Denis Lot t, Assistant,Operator, that one of the manual adjustable chokes would have to be replaced by a remotely operated chOke, which was agreed to by them. * In summary, we witnessed the successful pressure test of the 7" casing and of the plug set across the' shoe. 'taken as a result of conversations between Bxxon's - ~ ~ '~ Wond~el. O&G #6 4/80 STATE [~F ALASKA ON Plug & Abandonment Report! % Operator ~."~/,k/o ~ Company Repr O/-_--~/~/'~ Z~"~/-_ Lease'No. Well No. Total Depth /~ ~,~Elevation / Cas ing: Drilling Permit # Sec. T-R 7~ -- ./D~/ Mud Wt. '&'~ Drive Pipe "O.D. Set at Conductor ~O" "O.D. @ //~ Intermediate.. ]~Y~ "O.D. @ .~.~/ Plugging Data: Ft. w/ Pene. Ft. Su.rface ~ "O.D. @ ~;Dg Ft. Ft : Production F ~ "O.D. (_~ /~/~Ft. 1. Open hole plugs: 2. Open hole isolation plug: 4. Annulus plugs (if any): 5. Casing stub plugs: 6. Surface plug: Casing removal: "casing cut at ' "casing cut at ' "casing cut at ' E , ON COMPANY, US.A: POUCH 6601 · ANCHORAGE, ALASKA 9950P EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION April 12, 1982 Change to Contingency Plan Alaska State "F" Exxon No. Exxon Corporation Permit No. 81-140 Surface Location: Sec. 17, R23E, UM RES ENG I1 'ENG/~ ~G"---- 3 ENG ,4 ENG -i' GEOL STAT Bottomhole Location: Sec. 18, T10N, R23E, UM C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99504 Dear Mr. Chatterton, Confirming my phone conversation with H. W. Kugler, April 6, 1982, we request your concurrence with a change to the contingency plan attached to the captioned permit. We wish to change the fifth sentence of the "Location" section paragraph on page one of the plan from; "Otherwise, the rig and associated equipment will be placed on a standby status and all fuel and'lube oil will be removed until remobilization during the summer and fall of 1982 for drilling operations November 1." To; "Otherwise, the rig and associated equipment will be placed on a standby status until remobilization in the summer of 1982 if required to complete testing operations." A DIVISION OF EXXON CORPORATION RECEIVED APR 1 6 ]982 A~as~ Ol! & _~as Cons. Com~issio. Anchorage C. V. Chatterton Page Two The intent of this change is to minimize required fuel transfers while maintaining safe storage of fuel and lubricants. As stated in the contingency plan the steel wall fuel tanks are set in an impermeably lined fuel pit, affording maximum safe containment of any fuel spills. The PIT volume is 110% of the maximum total tank storage volume. This means that each of the thirteen fuel tanks could rupture and 15 inches of precipitation fall before fuel tops the pit berm. We also feel that this change will increase the overall pollution safety of the operation. By not removing fuel from the location, we avoid duplicate fuel transfers of removing and replacing fuel volumes. Also, the barge to island overwater fuel transfer will be minimized. This change gives us maximum flexibility to complete testing operations and/or begin drilling operations on a second well from this locaion while maintaining safety and increasing overall pollution protection. J. A. Staffeld CMR: rms 210C/N 295-665-100 APR 1 6 ]982 Alaska 0tl & Gas Cons. Commission Anchorags ALASKA ANDGAS'CONSERVATION CO,, ~ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Exxon Corporation 81-140 3. Address 8. APl Number Pouch 6601, Anchorage, Alaska 99502 5o- 089-20019 4. Location of Well atsurface 360' SNL & 1817' EWL, Sec. 17, T10N-R23E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KB 40' ADL 312862 9. Unit or Lease Name Alaska State F 10. Well No. Exxon No. 1 11. Field and Pool Wildcat For the Month of. March ,19 82 12. Depth at end of month, footage drilled,, fishing jobs, directional drilling problems, spud date, remarks r EOM Depth: 14,180' (sidetrack hole). Monthly Footage: 1336'. Stuck pipe at 13,470'; came loose after spotting Black Magic outside of bottom hole assembly. Raised mud weight during month from 15.4 to 15.9 ppg. 13. Casing or liner run and quantities of cement, results of pressur9 tests 7" casing: Set at 13,940' and cement w/1350 sacks class G cement. to 17.1 ppg EMW and did not leak-off. PIT at 13,959' 14. Coring resume and brief description Core #3 12,905'-12,915': Core #4 13,811'-13,826': Core #5 13,827'-13,833': Core #6 13,833'-13,838': 5' sandstone w/oil stain, 5' siltstone. 8" congl w/oil stain. 4' congl w/oil stain. 4' sandstone & 4' dolo with oil stain 15. Logs run and depth where run 13,950': DIL, LSS, FDC-CNL, Dipmeter 1 6. DST data, perforating data, shows of H2S, miscellaneous data APR 15 1982 Alaska Oil & Gas Cons. CornrnissJo~ Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE-Report'~ ~on~his form is required for each calendar month, ~egardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 O~ STATE OF ALASKA ALASKA LAND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Exxon Corporation 81-140 3. Address 8. APl Number Pouch 6601, Anchorage, Alaska 99502 50- 089-20019 4. Location of Well 360' SNL'and 1817' EWL Sec. 17, T10N-R23E, UM 5. Elevation in feet (indicate KB, DF, etc.) _ +4.0 ' Mean Sea Level (Ground) 6. Lease Designation and Serial No. ADT, 312862 9. Unit or Lease Name Alaska State F 12. 10. Well Number Exxon No. 1 11. Field and Pool Wildcat Check Appropriate Box To Indicate Nature of Noti,ce, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ', Perforations [] A!tering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment r-~ Repair Well [] Change Plans E~ 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). Substitute the dipmeter log for the gyro as the final directional survey of the open hole interval 13914'-14316' MD. (Verbal permission received from Mr. Chatterton on 4/6/82.) Perform an open hole test of the above interval using a permanent packer set at 13,900' MD (14' above 7" casing shoe). Abandon the open hole using a cement retainer, set directly above the permanent packer, and squeezing cement below it. No cement will be plaCed on top of the retainer. Perform subsequent cased hole tests and abandonments. RECEIVED APR 0 8 1982 Naska 0il & Gas Cons. C0mmissi0n~ Anchorage 14. I hereby c~/~/t,_ht~~, .,-~ . , ut~and correct to th~ best of my knowledge.senior Signed ~~ Title The spa~..eaaerow for Commission Conditions of Approval, if any: ORIGiHAI. SIGNED Approved by COMMISSIONER Approved Copy Returned By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate JAY$. HAMMOND~ GOVERNOR I~EI'ARTMENT (,F NATI~RAL RESOI~R~ES March 23, 1982 MINERALS AND EIVERGY MANAGEMENT 555 CORDQVA STREET POUCH 7-005 ANCHORAGE, ALASKA 99510 (907) 276-2653 Mr. W. R. Warnack Exploration Department Exxon Company, U.S.A. Post Office Box 4279 Houston, Texas 77001 Reference: Alaska State "F" Well No. 1 LO/NS 81-159 Dear Mr. Warnack: I hereby grant you an extension of downhole operations for the subject well past March 31, 1982. The extension is for a period of approximately four weeks and will expire at midnight, April 30, 1982. This extension is contingent upon the approval by the Alaska Oepartment of Environmental Conservation of the Oil Discharge Contingency Plan for the well during the extension period. If the National Marine Fisheries Service determines that continued downhole operations during the extension period would result in a'violation of the Endangered Species Act or the Marine Mammals Protection Act, I will require the immediate suspension of downhole operations. In the event a blowout occurs during the extension period, the Director of the Division of Minerals and Energy Management, after consultation with the Oepartment .of Environmental Conservation, the Alaska Oil and Gas Conservation Commission and the lessee, may require the lessee to initiate steps leading to the drilling of a relief well (including, but not limited to, the hauling of gravel and moving of a drilling rig to the relief site) concurrently with other r~medial actions. APR 0 5 1982 Alaska Oil & Gas Cons. Camm/ss/on Anchorago Hr. W. R. Warnack Page 2 Hatch 23, 1982 Extensions beyond this initial extension period may be granted if you continue to demonstrate the ability to operate safely and ice conditions justify. The decision to grant further extensions, if any, will be made only after consultation with the Beaufort Sea Biological Task Force. In addition, a future extension may be granted if I find, after consultation with the Alaska Oil and Gas Conservation Commission, that continued operations leading to shut down are necessary to prevent loss of.well control or to insure human safety. The granting of this extension is consistent with the Alaska Coastal Management Act. Sincerely, JAY S. HAMMOND, GO VERNOR DEPARTMENT OF NATI~RAL RESOI~RCES MINERALS AND ENERGY MANAGEMEIVT 555 CORDOVA STREET POUCH 7-005 ANCHORAGE, ALASKA 99510 (907) 276-2653 March 23, 1982 Mr. W. R. Warnack Exploration Department Exxon Company, U.S.A. Rost Office Box 4279 Houston, Texas 77001 Reference: Alaska State "F" Well No. 1 LO/NS 81-159 Dear Mr. Warnack: I hereby 'grant you an extension of downhole operations for the subject well past March 31, 1982. The extension is for a period of approximately four weeks and will expire at midnight, April 30, 1982. This extension is contingent upon the approval by the Alaska Department of Environmental Conservation of the Oil' Discharge Contingency Rlan for the well during the extension period. If the National Marine Fisheries Service determines that continued downhole operations during the extension period would result in a violation of the Endangered Species Act or the Marine Mammals Protection Act, I will require the immediate suspension of downhole operations. In the event a blowout occurs during the.extension period, the Director of the. Division of Minerals and Energy Management, after consultation with the Department.of Environmental Conservation, the Alaska Oil and Gas Conservation Commission and the lessee, may require the lessee to initiate steps leading to the drillingof a relief well (including, but not limited to, the hauling of gravel and movin~ of a drilling rig to the relief site) concurrently with other remedial actions. APR 0 2 1985 Oil & Gas Con~, ~u~chom~ M~. W. R. Warnack Page 2 March 23, 1982 Extensions beyond this initial extension period may be granted if you continue to demonstrate the ability to operate safely and ice conditions justify. The decision to grant further extensions, if any, will be made only after consultation with the Beaufort Sea Biological Task Force. In addition, a future extension may be granted if I find, after consultation with the Alaska Oil and Gas Conservation Commission, that continued operations leading to shut down are necessary to prevent loss of well control or to insure human safety. The granting of this extension is consistent with the Alaska Coastal Management Act. Sincerely, RECEIVED AJaska Oil & Gas Cons. Commissio~ ,¢~nchomge CONFIDENTIAL EXXON ALASKA STATE "F" NO. 1 WELL HISTORY Spudded well on November 1, 1981. Drilled a 17-1/2" hole to 2100 feet and ran open hole logs. Opened hole from 17-1/2" to 26" and cemented 20" casing at 2056 feet with 5130 sacks of permafrost cement plus a top off job of 250 sacks permafrost. Drilled a 17-1/2" hole to 4000 feet and ran open hole logs. Set 13-3/8" casing at 3998 feet and cemented with 600 sacks class G cement. A pressure integrity test below the 13-3/8" casing shoe leaked Off at 13.2 ppg EMW. Drilled a 12-1/4" hole to 7244 feet and ran a pressure integrity test with leak off occurring at 10.7 ppg EMW. Drilled to 10,084 feet with a 12-1/4" bit and ran open hole logs. Set 9-5/8" casing at 10,082 feet and cemented with 1680 sacks class G cement. Drilled an 8-1/2" hole to 11,738 feet and cut core #1 from 11,738 feet to 11,746 feet. Drilled to 12,896 feet where 2-1/2 bit cones were left in the hole. While fishing for the cones we left 2-1/2 more cones, a l"xI"x2" piece off the bottom of a mill and a jet basket skirt (1.34' long) in the hole. Did not completely recover junk from hole. Placed a 175 sack class G cement plug in the 8-1/2" open hole from TD to 12,494 feet. A sidetrack hole kicked off at 12,659 feet using a dynadrill and a diamond sidetrack bit. Drilled an 8-1/2" hole to 13,050 feet and ran open hole logs. There were no production or drill stem tests performed. Set a 200 sack cement plug in the 8-1/2" open hole from 11,240 feet to 11,640 feet. Squeeze below a retainer set at 9976 feet with 95 sacks cement and placed 25 sacks on top of retainer. Displaced mud in 9-5/8" casing from 2000 feet to surface with calcium chloride water. Spotted a permafrost cement plug from 150 feet to surface. Install abandonment flange. -' -~ -~ ---:: - :- --'~:- RECEIVED MAR 1 8 ]982 AlasKa Oil & Gas Cons, Commission Anchorage ALASK/~ ~L AND GAS CONSERVATION '.4MISSION MONTHLY REPORT OF DRILLING AND wORKOVER OPERAI'ION 1. Drilling well I~ Workover operation [] _~. Name of operator 7. Permit No. Exxon Corporation 81-140 3. Address 8. APl Number Pouch 6601, Anchorage, Alaska 99502 50-089-20019 4. Location of Well at surface 360' SNL & 1817' EWL, Sec. 17, T10N-R23E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KB 40' ADL 312862 9. Unit or Lease Name Alaska State F 10. Well No. Exxon No. 1 11. Field and Pool Wildcat For the Month of February ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks EOM Depth: 12,844' (sidetrack hole). Mo. Footage: 739'. Stuck drill pipe on bottom at a drill depth of 12,906'. Failed to get free w/oil phase pill & black magic pill. Backed off at 12,509' & placed a 190 sx cmt plug on top of fish. Tag cmt at 12,398' & dressed off to 12,403' where the hole was sidetracked using a dyna drill assembly. Fish in old hole from 12,509' to 12,906'. Increased mud weight during the month from 14.7 to 15.4 ppg. 13. Casing or liner run and quantities of cement, results of pressur9 tests 9-5/8" csg: Set at 12,096' & cmt w/2500 sx class G. at 17.9 ppg EMW. PIT at 12,114' did not leak off 14. Coring resume and brief description Core #2 12,572'-12,618': 34.5' sandstone with oil stain; 10.8' shale. 15. Logs run and depth where run RECEIVEg 16. DST data, perforating data, shows of H2S, miscellaneous data 1 5 ]982 & 8as Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TITLE Geological Advisor DATE 3/15/82 NOTE--Report o~rthis form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the. Alaska Oil and Gas Conservation Commission by the 15th of the ~Jcceeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 E (ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION March 11, 1982 Re: Alaska State F-1 Beaufort Sea, Alaska Mr. C. V. Chatterton Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: As stated in the attached letter to Kay Brown, Director, DMEM, Exxon is requesting, as per State Lease Stipulation #9, approval of downhole exploratory drilling and testing activities past March 31 for the Alaska State F-1 well. If further information on this matter is desired, please contact Mr. John Staffeld in our Anchorage office at (907) 263-3713. John A. Staffeld JAS:et attachment A DIVISION OF EXXON CORPORATION RECEIVED, .MAR i 2 ]982 AJaska 0il & Gas Cons. Commission Anchorage MINERALS AND ENERGY MANAGEMENT RECEIVED JAY S. I'IAMMOtVD, GO V£RNOR FEB 2 2. 1 8t ~N~T.n'~ ~'T~rOx: DE_PT. X03 Wo NO~F~[ERI~I~['IG~TS ut. ANCHORAGE, ALASKA 99503 Suite 100 276-5113 February 18, 1981 Exxon Company U.S.A. Pouch 6601 Anchorage, Alaska 99502 Attention: Robert K. Riddle Reference: LO/NS 80-228 Alaska State E Well No. 1 Dear Hr. Riddle: The referenced lease operations as outlined in your letter of August 29, 1980 are approved subject to attachment f~l. Rlease submit a completion report within fifteen (15) days upon completion of these operations. Should a centrally located landfill for this area be further contemplated, we suggest you.contact the Department of Environmental Conservation, R.O. Box 1601, Fairbanks, Alaska 99707 with as'much lead time as possible. ~incerely, Glenn Harrison DirectOr 10-J3LH Attachment #1 February 10, 1981 LO/NS 8O-228 Exxon - Alaska State E Well #1 The Division of Forest, Land and Water Management hereby approves the above referenced lease operation subject to the following stipulations: · m 5 5~ The ice road and airstrip shall be constructed in such a manner as to minimize surface damage and will be of sufficient thickness to protect the tundra. Ice road routes shall be approved prior to being constructed. USGS maps of a scale of one inch equals one mile will be provided showing the routes of all ice roads constructed. Vehicles shall be operated in a manner such 'that the vegetation mat of the tundra is not disturbed. Blading or removal of tundra or vegetative cover is prohibited. Filling of low spots and smoothing by the use of snow and ice is allowed. Ice or snow bridges constructed at stream crossings shall not contain extraneous material (i.e.., soil, rock, brush, or vegetation) and shall be removed immediately after use or before expiration of this authorization. The banks of watercourses shall not be al te red. On tundra travel shall be subject to termination within 72 hours of notification by the Director of the Division of Forest, Land and Water Management or his designee for protection of surface vegetation. Pursuant to AS 46.15 the use of water from lake 8 in Sections 14 & 15, T.9N., R.23 E., U.M. is approved for this operation. Wfiliam H. CoPelan~d - District Manager MAR 1 2 ]~}~'2: COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION August 29, 1980 Re: Alaska State "E" Well No. 1 Section 17, T10N, R23E, UM ADL 312863 Arctic Slope, Alaska LO/NS: ~-~?~ Dr. Ross G. Schaff Acting Director Division of Minerals & Energy Mgmt. 703 West Northern Lights Blvd. Anchorage, Alaska 99503 Dear Dr. Schaff: Exxon Corporation filed today an application with the. Alaska Oil and Gas Conservation Commission for a permit to drill and the contingency plan for the subject well together with our check in the amount of $100.00 in payment of the required permit fee. Additionally, and in accordance with the requirements of'the subject oil and gas lease and applicable regulatiOns, we submit the following: (1) A plan. of operations describing the drilling pad, rig supply, water supply, waste and sewage disposal and pollution prevention. (2) Two area operations maps: Exhibit "A", scale .1"=.2000' showing the location and vicinity of the well and pad layout and Exhibit "B", scale 1"-10,000'. - showing sea ice road, Rolligon haul route and relationship of subject operation to those within Duck Island and Pt. Thomson Units. (3) Survey plat with X and Y coordinates as well as latitude and longitude. Lease stipulations necessitate a tWo season operation for the drilling of this well. As a consequence we shall construct the drilling pad during the winter 1980-81 as soon following receipt of your approval as weather conditions will permit the movement of construction equipment and materials to the site. Although the drilling rig has. not been selected at this time it is anticipated that we shall be able upon completion of the drill site construction to move the drilling rig, camp and supplies to the location over A DIVISION OF EXXON CORPORATION Dr. Ross G. Schaff Page two August 29, 1980 the sea ice road depicted on Exhibit "A". As an alternate, however, the rig and camp will be barged to the drill site in the summer of 1981. Drilling operations will be commenced with the barging of fuel and supplies to the drill site in late summer 1981, regardless of the mode selected for transport of the rig, and the well will be spudded on November 1,. 1981 in.compliance with lease stipulations. As approximately seven months will be required for drilling and testing, in the event drilling progresses so that Exxon can demonstrate the ability to operate safely, and ice conditions justify, a request will be made for state authorization to continue drilling and downhole operations until May 15, 1982 in accordance with State Lease Stipulation No. 9. Archeological and historical studies required by said stipulations are presently being contracted, for and will be completed before any construction activities are commenced. All data developed in such studies shall be made available to you for your files. We have been advised by the U.S. Army Corps of Engineers that a permit under Section 404 of the Clean Water Act will not be required for the subject operations hence we shall not be seeking, through COE permit procedures, a certificate of consistency with the Alaska Coastal Management Program. In the event,~ however, a similar application for certification may be required for this operation under these circumstances through your office please advise and we shall comply in whatever manner may be necessary to meet the state's requirements. , Yours very truly, RKR: et enclosure c: EPA Region X - Mr. Danford. G, Bodien, P.E. Alaska Oil & Gas Conservation Commission - Mr. Hoyle H. Hamilton · bc: A. L.. Hermann, A. V. Lockett, O. C. Rath, W. M. Selvidge, W. M. Taylor, W. J. Whaley EXXON COMPANY, U · S · A. PLAN OF OPERATIONS EXXON ALASKA STATE "E" (ADL 312863) WELL NO. 1 General This well will be drilled as a straight hole and will be located 1823 feet EWL, 355 feet SNL, Section 17, T10N, R23E, U.M. The drill site will be on the west end of North Star Island in the Beaufort Sea about 46 miles east of the Prudhoe Bay East Dock. The drill site will be constructed during the winter of 1980-81 and the well spudded on November 1, 1981. Approximately seven months will be required for drilling and testing. The drilling rig for this location has not been selected. Natural Environment North Star Island is located in the Beaufort Sea about three miles north of the Alaskan coastline. The surface of the island in the vicinity of Exxon's proposed drill site is a sandy gravel mixture with little vegetation. It has an average elevation of four feet above sea level. The depth of the permafrost in this area is expected to be about six hundred feet. There are no established roads, airstrips, housing, or other facilities in the area and, because of the nature of the terrain, heavy vehicular traffic can operate only during the winter season while the ground and surrounding sea ice are frozen. Prudhoe- Deadhorse is the nearest staging area and airstrip with permanent facilities for handling cargo and housing personnel. Arctic ciimatic conditions include relatively cold temperatures year-round. Strong winds, small annual precipitation, and visi- bility ,strongly influenced by the combination of winds and coastal sea ice condition are factors contributing to an eXtremely harsh environment. ' Temperatures vary from a high in the 40 to 6U°F range in the summer to a low of -50 to -60°F in the winter which, with the chill factor may reach -100°F or lower depending on the severity Of winds. Surface winds are predominantly from the east at an average velocity of 12 miles per hour along the coast with a velocity range of 35 to 50 mph associated with winter storms. Total annual, precip- itation is in the range of 4 to 6 inches which includes 12 to 48 inches of snowfall. Page 2 Various species of wildlife exist in the area. During the winter months, when the major part of activities are planned, wolves, wolverines, foxes, polar bears, and caribou may be present. Bird life is limited primarily to the raven, snowy owl, gyrfalcon, and ptarmigan, with waterfowl and most other birds having migrated from the area for the winter. Logistics Access to the proposed location during the winters of 1980-81, 1981-82, and 1982-83 will be provided by a sea ice road along the shoreline of the Beaufort Sea extending from Prudhoe Bay East Dock to a point approximately one mile east of Point Sweeney and continuing in northerly direction to the location. Additional ice roads will also be required in 1980~81 from the Sea Ice Road, at a point one mile east of Point Sweeney to the gravel source and also'to Lake No. 8 in Sections 22 and 23, T9N, R23E which will be the water source for construction operations. An ice road from the drill site to the water source for drilling operations, which will be located in Sections 14 and 15, T9N, R23E, will be required during the winters of 1981-82 and 1982-83. These road routes are shown by Exhibits "A" and "B" which are attached. Upon completion of drill site construction, the drilling rig, camp, and supplies will be moved in late winter 1981 to the location over ice roads. As an alternate, the rig and camp will be barged to the proposed North Star Island drill site in the summer of 1981. Additional supplies for drilling operations will be transported to the drill site by barge during the open water season in 1981 and 1982. After freeze up begins, personnel and supplies will be transported by helicopters and/or air cushion vehicles until ice roads and landing str. ips are completed. Traffic will be routed to avoid disrupting known active waterfowl~nesting and staging sites. An ice landing strip, approximately 2000 feet'long, will be constructed to facilitate air transportation during the winters of 1981-82 and 1982-83. During the winter, if bulky equiDment must be delivered on short notice or large shipments can be accumulated, an ocean ice landing strip for Hercules aircraft may be constructed on the sea ice. Page 3 Drill Site Construction Contingent upon regulatory approval, location preparation will commence in the winter of 1980-81 as soon as freeze-up is sufficient to facilitate movement of construction equipment to the job site. The proposed drill site will be a 340' X 450' sheet pile enclosed gravel fill. The elevation of the top of the gravel will be +7.0 feet. The sheet piling around the site will protect against erosion and wave overtopping in the summer and sea ice override in the winter. Approximately 20,000 cubic yards of gravel will be required for the drill site fill. This material will be obtained from a mine located in Section 14 and 15, T9N, R23E. The development and operation of this mine, which will be a central source of fill material for construction activites in the Point Thomson'area, will be covered by separate permit applications to appropriate government regulatory agencies. Rubber tired loaders and belly dump trucks will be used for the loading, hauling, and placement of material for the new location. Water for drill site construction will be obtained from Lake No. 8 in Sections 22 and 23, T9N, R23E, UPM. The proposed sequence for drill site preparation will be as follows: le Construct ice access road along shoreline of the Beaufort Sea from Prudhoe Bay to a point one mile east of Point Sweeney and on· to the gravel source and also to. Lake 8. · · Activate temporary construction camp for 40-60 persons at the gravel source and move in remainder of construction equipment from Prudhoe Bay. Construct ice road from a p°in~ one mile east of Point Sweeney to Alaska State "E" No. 1 location. · · Construct sheet pile enclosed gravel drill site. Move in drilling rig and camp during the spring or summer of 1981 as previously discussed. · Barge supplies to the drill site in the summer of 1981 and 1982. · ~ Construct 2000 foot long ice airstrip in the winter of 1981-82 and 1982-83. Construct ice road from the drill site to the water source in Sections 14 and 15, T9N, R23 during the winters of 1981-82 and 1982-83. Drilling Operations Drilling operations will commence with the barging of fuel and supplies to the drill site in the late summer of 1981 so that the well may be spudded on November 1, 1981. If drilling progresses so that Exxon can demonstrate the ability to operate safely, and ice conditions justify, a request will be made for state authorization to continue drilling and downhole operations until May 15, 1982 as per State Lease Stipulation No. 9. If the proposed well cannot be completed within the authorized 1981-82 interval, drilling operations will be temporarily suspended. All personnel, fuel, and lubricants will be removed from the drill site by May 30, 1982. Fuel and supplies will be barged again to the drill site in the late summer of 1982 so that drilling operations can resume on November 1, 1982. An impermeable plastic sheet will be installed under the drilling rig'to collect liquid drainage and direct it to the well cellar for recovery and disposal. All pits, except for the burning pit, will be lined with an impermeable plastic liner. The reserve pit will be used only for the emergency storage of excess drilling fluids. The wellbore will be designed for annular injection for the subsurface disposal of waste liquids. Water for drilling operations will be barged in during the summer or hauled from a proposed central water supply for the Point Thomson area to be located in Sections 14 and 15, T9N, R23E. The development and operation of this source will be covered by separate applications to appropriate government regulatory agencies. A snow melter may also be used to supplement rig water requirements. Potable water will be processed through a state approved wa~er treating unit before use in the camp. Disposal of Waste Materials The following waste material procedures will be observed during drilling operations. After completion of the well, any remaining materials will be promptly removed from the drill site. · Drilling Mud will be injected in the casing annulus or haUled to a state approved site for disposal. Page 5 2· · · Se · · · Cuttings. from the wellbore will be hauled to a centrally located landfill in the Point Thomson area for disposal. The development and operation of this landfill, to serve future locations in the Point Thomson area, will be covered by separate permit applications to appropriate government agencies. Sewage Effluent and Gray'Water: Sanitary sewage will be treated with a state approved sewage disposal unit. Treated effluent from this unit will be combined with gray water from the camp kitchen and bathrooms in a steel storage tank and used in drilling mud or rig wash water. A lined sanitary holding pit will be provided for the emergency storage of these liquids during upset conditions. Any surplus quantities of this liquid will be discharged in the casing annulus. Domestic Garbage will be disposed of in a state approved incinerator. Combustible Wastes such as paper, wood, and cardboard will be incinerated or open burned. Noncombustible Wastes sUch as scrap metal, batteries, drums, wirelines, etc. will be hauled to a state approved site for disposal. Well Test Fluids: Produced gas will be flared. Produced liquids will be injected in the casing annulus or hauled to a state approved site for disposal. Waste Oil will be injected in the casing annulus or hauled to a state approved Site for disposal. Surface 'Protection and Restoration Plan Surface transportation to the drill sit~ will be only over ice roads during the winter or by barge during the summer. Special procedures for drilling and subsurface equipment are required by the unique characteristics of the.permafrost area. Casing cement used through the permafrost zones is of special composition to reduce possibility of freezing and other casing problems. Casing is run and cemented through the permafrost, and in the event of production or interruption of operation, the uncemented casing must be protected by the use of non-freezing fluid. Page 6 At the completion of the well, the location and adjoining area will be cleared of all waste materials. Velocity Survey Prior to the completion of the well, a velocity survey, one of the essential components of the drilling operation, will be made. As this well will be drilled as a straight hole the procedure employed will require only' a40" diameter cased hole, 40 feet deep which will be located on the drill pad a short distance from the Well bore and will be filled with brine water just prior, to detonation. Experimentally, one pound charges of Nitromon primers or an equivalent amount of Primacord will be used as well as an airgun as the energy source; the Nitromon or Primacord serving the dual purpose of cavitating the hole and supplementing the airgun as the energy source. As a further alternative in the event neither of the above develop satisfactory data, we.propose to use a steel tank 10 feet in diameter and 20 feet high filled with water with the air gun as the energy source. Development Plans If oil is discovered in sufficient quantities to warrant future development, the Prudhoe Bay to Valdez oil pipeline will be the probable marketing outlet from the area. Oil and casinghead gas would be processed through central oil gathering facilities with oil being transported to the Trans-Alaska Pipeline System. If commercial quantities of gas are discovered, development of a gas market outlet will be related to studies to market gas from the Prudhoe area. AVL:ljm 7-24-80 EXXON COMPANY, U.S.A. PLAN OF OPERATIONS EXXON ALASKA STATE "F" (ADL 312862) WELL NO. i General This well will be drilled as a directional hole and the surface location will be 1,817 feet EWL, 360 feet SNL, Section 17, TiON, R23E, U.M. The proposed bottom- hole location will be 2,226 feet WEL and 1,879 feet SNL, Section 18, TiON, R23E, U.M. The drill site is on the west end of North Star Island in the Beaufort Sea about 46 miles east of the Prudhoe Bay East Dock. The drill site was constructed during the winter of 1980-81 and the well will be spudded November 1, 1981. Approximately 8 months will be required for drilling and testing. The drilling site was originally approved for construction and planned for the Alaska State "E" Well No. 1. It is now planned to drill the Alaska'State "F" Well No. I as the initial well from this location. The drilling rig for this location will be the Arctic Alaska Drilling Company Rig No. 5. Logistics Access to the proposed location during the winters of 1981-82 and 1982-83 will be provided by a sea ice road along the shoreline of the Beaufort Sea extending from Prudhoe Bay East Dock to a point approximately 1 mile east of Point Sweeney and continuing in a northerly direction to the location. An ice road from the drill site to the water source for drilling operations will be required during the winters of 1981-82 and 1982-83. Water sources for this well may be both Lake No. 8 and the abandoned gravel source. These road routes are shown by Exhibits "A" and "B" which are attached. Also seawater desalination units*may be used.to provide' water for drilling operations. Upon completion of drill site construction, some supplies were moved in late winter 1981 to the location over ice roads. The rig and camp,will be barged to the proposed North Star Island drill site in the summer of 1981. Additional supplies for drilling operations wil;1 be transported to the drill site by barge during the open water season of 1981 and 1982.. After freeze-up begins, personnel and supplies will be transported by helicopters and/or air cushion vehicles until ice roads and landing strips are completed. Traffic will be routed to avoid disrupting known active waterfowl nesting and staging sites. An ice landing strip, approximately 2,000 feet long, will be constructed to facilitate air transportation during the winters of 1981-82 and 1982-83. During the winter, if bulky equipment must be delivered on short notice, or large shipments can be accumulated, an ocean ice landing strip for Hercules aircraft may be constructed on the sea ice. * If desalini,zation units are used: ]~) the effluent will be discharged on-ice as opposed to under-ice, and 2)the intakes will be designed to avAi~l~ig~i~ant impingement and entrainment of fish eggs and larvae. MAR I 2'1982 Oil & Gas Cons, Commissiul"~ Drilling Operations This well is scheduled to be spudded on November 1, 1981. If drilling progresses so that Exxon can demonstrate the ability to operate safely, and ice conditions justify, a request will be made for state authorization to continue drilling and downhole operations until May 15, 1982, as per State Lease Stipulation No. 9. If the proposed well cannot be completed within the authorized 1981-82 interval, drilling operations will be temporarily suspended. All personnel, fuel, and lubricants will be removed from the drill-site by May 30, 1982. Fuel and supplies will be barged again to the drill site in the late summer of 1982 so that drilling operations can resume on November 1, 1982. An impermeable plastic sheet will be installed under the drilling rig to collect liquid drainage and direct it to the well cellar for recovery and disposal. All pits, except for the flare pit, will be lined with an impermeable plastic liner. The reserve pit will be used primarily for the emergency storage of excess drilling fluids and occasionally for small amounts of cement-contaminated mud. The wellbore will be designed for annular injection for the subsurface disposal of waste liquids. Water for drilling operations will be supplied by seawater desalination or hauled from water sources discussed above. A snow melter may also be uSed to supplement rig water requirements. Potable water will be processed through a state-approved water treating unit before use in the camp. Disposal of Waste Materials The following waste material procedures will be observed during drilling operations. After completion of the well, any remaining materials will be promptly.removed from the drill site. 1. Drilling mud wiil be injected in the casing annulus or hauled to a state- approved site for disPosal. 2. Cuttings from the wellbore will be temporarily stored on the surface of North Star Island and later hauled to a centrally located landfill in the Point Thomson area for disposal. The development and operation of this landfill, to serve future locations in the POint T~omson area, will be covered by separate permit applications to appropriate government agencies. 3. 'Sewage effluent and gray water. Sanitary sewage will be treated with a state-approved sewage disposal unitowned by Arctic Alaska Drilling Company. Treated effluent from this unit will be combined with gray water from the camp kitchen and bathrooms in a steel storage tank and used in drilling mud or rig wash water. A 25,000-gallon sewage effluent tank will be provided for the emergency storage of these liquids during upset conditions. Any surplus quantities of this liquid will be discharged in the casing annulus.- 4. Domestic 9arbage will be disposed of in a state-approved incinerator. 5. Combustible wastes sUch as paper, wood, and cardboard will be incinQ, rQ.t~e.d~.,o~ open burn. ed. RE[E MAR 1 2 0i~ & Gas [,on~ .6. Noncombustible wastes such as scrap metal, batteries, drums, wirelines, etc., will be hauled to'a state-approved site for disposal. 7. Well test fluids. Produced gas will be flared in accordance with the air quality control permit issued by theADEC. Produced liquids will be injected down the casing annulus or otherwise disposed of in accordance with said permit. 8. Waste oil will be injected in the casing annulus or hauled to a state- approved site for disposal. Surface Protection and Restoration Plan Surface transportation to the drill site will be primarily over ice roads during the winter or by barge during the summer. Rolligons and other applicable forms of transportation will be used in the spring and fall and prior to full ice road construction. Special procedures for drilling and subsurface equipment are required by the unique characteristics of the permafrost area. Casing cement used through the permafrost zones is of special composition to reduce possibility of freezing and other casing problems. Casing is run and cemented through the permafrost, and in the event of production or interruption of operation, the uncemented casing must be protected by the use of non-freezing fluid. · At the completion of the well, the location and adjoining area will be cleared of all waste materials. Development Plans If oil is discovered in sufficient quantities to warrant future development, the Prudhoe Bay to Valdez oil pipeline will be the probable marketing outlet from the area. Oil and casinghead gas would be processed through central oil gathering facilities with oil being transported to the Trans-Alaska Pipeline System. If commercial quantities of gas are discovered, development of a gas market outlet will be related to studies to market gas from the Prudhoe area. DRP 'cf 9/2/81 RE[EIVED MAR 1 © 0i~ &. Gas (.,ohs, uomml~.-~l Alaska Island Duchess Island ~,~,~'~~I~,,SEEDETAiI_FOB....:~ 481' NORTH STAR ISLAND PROPOSED /I Lat. 70°13'38.14'' J ~ J~'( Long. 146°21'37.68'' ' y: 5, 937,797' x: 455,334' j I I I I I k 27 26 :560' I ALASKA STATE F-I S 17, T ION,R2 5E,UM DETA I L ill . =1 MILE RECE .- MAR 1 2 T CERTIFICATE OF SURVEYOR Gas Co Anchor I hereby certify that I am properly registered and licensed to proctice land surveying in the State of Alaska and that this plat represents a Iocotion survey mode by me or under rn'y direct supervision and thor all detoils ore correct. 8-1-80 _ DATE /,.~U'-R"'V E YO~ ..... 25 36 TOPO FROM FLAXMAN IS'LAND(A-4 & A-5), USGS REVISED Well Name REVISED Surface Location PROPOSED WELL LOCATION 7/8/8~ 3/5/8~ ,..,;.,,: ALASKA STATE F I COHiD3~'~TED IN SECTION 17 , TION, R23E, U.M. FOR EXXON COMPANY U.S.A. BY BESSE, EPPS 8~ POTTS ANCHORAGE~ A.LASKA 3_44 - 1352 99o-oo'7="-,c '"'· - MEMORANDUM ' DEPARTMENT OF NATI~RAL RES MINERALS AND ENERGY ~UBJECT ' . d~RCES MANAGEMENT November 3, 1981 JA YE. HAM/I//ONO, GOVERNOR IF'ICE NO. Pouc~ '7-005 Exxon Company U.S.A. .t.:*. Pouch 6601 .- ' Anchorage, Alaska 99502 Attention: Robert Riddle Landman Reference: LO/NS 81-159 Alaska State F Well No. 1 Dear Mr. Riddle: The referenced lease operations ,as outlined in your letter of October 16, 1981 are approved subject to the stipulations set forth on attachment #1. A completion report must be filed within fifteen (15) days upon completion of these operations. Verbal approval of these .activities given October 27, 1981 is hereby confirmed. These activities, with the stipulations, are consistent with the Alaska Coastal Management Program. Lessee is reminded that stipulation #9 of the Beaufort Sea lease stipulations as attached to ADL 312863 is to be followed. William Van Dyke Petroleum Manager Attachment SAFETY SFOR EYEI YONEEYEI R Attachment #1 October 27, 1981 LO/NS 81-159 Exxon: Alaska State F-1 Wel 1 The Division of Forest, Land and Water Management hereby approves the above referenced pemit subject to the following stipulations: -1. All surface activities shall be conducted in accordance with the approved plan of operations for Alaska State E Well #1. 2. The drilling start up date must not be in violation of the Federal/State Joint Beaufort Sea Oil and Gas Lease Sale Stipulations.' F~er~ic/k L. Smith North Slope Area Manager COMPANY. U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION September 16, 1981 Re: Exxon Alaska State "F" Well No. 1 Surf. Loc.: Sec. 17, T10N, R23E, UM ADL 312863 BH Loc.: Sec. 18, T10N, R23E, UM ADL 312862 Mr. Glenn Harrison, Director Division of Minerals & Energy Management Pouch 7-005 Anchorage, Alaska 99510 Dear Mr. Harrison: By letter dated August 29, 1980 to Acting Director Ross G. Schaff. Exxon filed a plan of operation for the drilling of a well to be located on North Star Island on State of Alaska oil and gas lease, ADL 312863, designated "Alaska State 'E' Well No. 1." Your letter of February 18, 1981 granted approval to said plan of operation which had meanwhile been assigned lease operations number LO/NS 80-228. By a similar letter, likewise dated August 29, 1980 to the acting director Exxon filed a plan of operation for the drilling of a well to be located on Alaska Island on State of Alaska oil and gas lease, ADL 312861, designated "Alaska State 'F' Well No. 1." .On October 7, 1980, however, we advised Dr. Schaff that it had become necessary to defer planS to commence operations on the Alaska Island lease and withdrew our application for his approval of the drilling operations plan. We now propose to drill an additional well not previously applied for and have designated it Alaska State "F, Well No. 1, utilizing the designation of the prior well withdrawn by our letter of October 7, 1980. The plan of operation for the new Alaska Stat~"F'' Well No. 1 is virtually identical with the plan which you have approved for t~e Alaska State "E" No. 1 with but one important exception, the "F" No. 1 well will be directionally drilled, southwesterly from the surface location in Section 17, T10N, R23E, UM on North Star Island, to a bottom hole location in Section 18, T10N, R23E, UM in the adjacent Exxon oil and gas lease ADL 312862. In accordance with your approval of the "E" No. 1 plan of operation two cellers and two conductor strings were installed at the time the drilling pad was · constructed enabling the "F" No. 1 and the "E" No. 1 to be drilled consecutively. Although, as stated, the "E" No. 1 plan of operation has been approved, we are herewith resubmitting what is essentially the same plan, together with the Plat of Survey and Area Operation Maps, Exhibits A and B, for the Alaska State "F" No. 1 Well, and ask that this plan now be approved for the subject well not- withstanding the fact that all construction described therein has been ~~V~ A DIVISION OF EXXON CORPORATION MAR 1 2 1982 Oi!, &. Gas Cons,' Commiss] Mr. Glenn Harrison Page two September 16, 1981 accomplished, Arctic Alaska Drilling Company's Rig No. 5 is on location and all facilities are in order awaiting the commencement of drilling operations in compliance with stipulation number 9 of the respective oil and gas leases. Yours very truly, RKR:et enclosures c w/encl: EPA, Region Ten, Attn: Danford G. Bodien, P.E. Ak. Oil & Gas Conservation Commission, Attn: Hoyle H. Hamilton Ak. Dept. of Environmental Conservation, Attn: Douglas Lowery Ak. Dept. of Fish & Game, Attn: J. Scott Grundy Div. of Forest, Land & Water Management, Attn: William Copeland bc w/encl: A. L. Hermann, A. V. Lockett, N. J. Johnson, O. C. Rath, R. H. Weaver, R. D. Wilson RECEIVED MAR 1 2 Alaska Oil & GaS Cons~ Con, mission Anchorage COMPANY, U:S.A. POST OFFICE BOX 4279 · HOUSTON, TEXAS 77001 EXPLORATION DEPARTMENT GULFIATLANTIC DIVISION ALASKA/PACI Fie DIVISION 1./oR. WARNACK PE:R M ITTING~ March 11, 1982 Exxon Alaska State "F" Well No. 1 Surface Location: Sec. 17, T10N, R23E, UM Bottomhole Location: Sec. 18, T10N, R23E, UM Ms. Kay Brown, Director DiviSion of Minerals & Energy Management Pouch 7-005 Anchorage, Alaska 99510 Dear Ms. Brown: Exxon Company, U.S.A., requests an extension of the 1981-82 drilling season beyond March 31, 1982 as provided for in our Plan of Operations and lease stipulation No. 9, to furnish sufficient time to complete (1) drilling, (2) well logging, testing, plugging, and (3) equipment removal from location of Alaska State "F" Well No. 1. This well is being drilled from a surface location on Exxon's oil and gas lease ADL 312863 (North Star Island) to a bottomhole location on Exxon's oil and gas lease ADL 312862. Drilling operations have been in accordance with the Plan of Operations approved by the Division of Minerals and Energy Management (copy attached), the Alaska Oil and Gas Conservation Commission permit to drill, and other necessary state and federal regulatory requirements. Alaska State "F" Well No. 1 is presently drilling below 13,700 feet (measured depth) through 9-5/8 inch protective casing set at 12,096 feet (measured depth). The current mud weight is 15.7 pounds/gallon which is similar to that required on previous wells in the area at this depth and no further significant increases are anticipated. Subsurface pressures are as predicted, and there are no unusual conditions which adversely affect our well control capabilities. It is critical that sufficient time is authorized during the 1981- 82 season to allow this well to penetrate and evaluate the remaining prospective section. This must be accomplished, if Exxon is to plan needed future exploratory wells and to construct the necessary drilling locations in a timely manner. It is likely that operations on the captioned well will be required beyond March 31, 1982. The "General Section" and the "Drilling Operations Section" of Exxon's approved Plan of Operations discusses the probability 'that an extension would be needed to complete this well, as per lease stipulation No. 9. RECEIVEO A DIVISION OF EXXON CORPORATION MAR 1 2 1982 Alaska 0il & Gas Cons. Commission Anchorage We believe that technology is available which enables safe drilling operations year round in the Beaufort Sea area without seasonal inter- ruptions, and that no significant adverse environmental affect will result, as demonstrated in our testimony and written documentation at public hearings held by the Department of Natural Resources on the question of seasonal drilling restrictions. In this instance, however, we do not anticipate it will be necessary for operations on this well to continue beyond May 15, 1982 and therefore limit this request for an extension terminating on that date. Exxon's past experience demonstrates its ability to operate safely in this area. Since 1977, Exxon has drilled six other wells within seven miles of the State "F" No. 1 location without significant technical or environmental problems. The present "F"-i drilling operation is progressing in a safe manner, and we anticipate no change in this regard. Exxon, in conjunction with Dr. Robert Llewellyn, is continuing to obtain and evaluate data on ice thickness throughout the area. This data can be made available to you, if desired. We believe that present ice conditions justify continued operations. Our ice road and airstrip are currently in excellent condition, and we do not anticipate a change in this condition prior to May 15, 1982. Operations can continue in a "winter mode" as described in our plan of operations and ADEC approved oil Spill contingency plan until about May 18. Therefore, no modification is required of either of these plans. Based on data from the last 10 years, May 18 is the average date when outflow from the Sag River curtails sea ice road transportation to the site. According to our records, Sag River breakup at the coast, has occurred earlier than May 10 on only one occasion since 1971. By monitoring the progress of the Sag breakup from the foothills toward the coast by aircraft overflights, we are able to accurately predict the actual date several days in advance. When this event occurs, we will terminate operations or provide an appropriate contingency plan for approval. We appreciate your early consideration of this request. In the event that you or your staff have need for further information, please contact Mr. John Staffeld in our Anchorage office at (907) 263-3713. S~n.cerely, ~ . W. R. ~Warnack WRW:hcw c - Alaska Oil and Gas Conservation Commission Alaska Department of Environmental Conservation Alaska Department of Fish and Game Division of Forest Land and Water Management North Slope Borough RECElVEO MAR i 2 1982 Oil & Gas Cons. 6ommission Anchora[l~ ,. STATE OF ALASKA CONFI[ i AL ALASKA lk _ AND GAS CONSERVATION C~ ,vllSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERAT-IrONS · Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Exxon Corporation 81-140 3. Address Pouch 6601, Anchorage, Alaska 99502 4. Location of Well atsurface 360' SNL & 1817' EWL, Sec. 17, T10N-R23E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KB 40' ADL 312862 8. APl Number 5O-- 089-20019 9. Unit or Lease Name Alaska State F 10. Well No. Exxon No. 1 11. Field and Pool Wildcat For the Month of January ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks EOM Depth: 12,105'. Mo. Footage: 1397'. Stuck Schlumberger FDC-CNL tool at 9970'. Recovered tool by cutting and stripping over wireline. Increased mud weight during the month from 10.9 to 14.7 ppg. 13. Casing or liner run and quantities of cement, results of pressur9 tests 14. Coring resume and brief description Core #1 12,065'-12,081': Rec 6' sandstone with oil stain on bedding plane; 6.9' shale and siltstone. 15. Logs run and depth where run 12,105': DIL, LSS 16. DST data, perforating data, shows of H2S, miscellaneous data i',~ L RECEI¥E '" FE B-17 Nas~ O~t ~~' Commission /~chorago 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TITLE Geological Associate DATE 2/16/82 ' ':NOTE--R'e;ort ~{'t~is f~rrn is re~u~ed for'each calendar month, regardless of the status of operations, and must be filed in duplicate with the Ala{ka' Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 E ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION January 29, 1982 Re: Exxon Alaska State F-1 Permit No. 81-140 Mr. Lonnie Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached for your information and files is a Sundry Notice amending the Permit to Drill or Deepen Form 10-401 for the above captioned well. Although triplicate filing is all that you require, we have included four copies of the notice so that you may return to us a signed copy for our files. John A. Staffeld JAS: e t attachments RECEIVED F E 8 0 111982 Alaska 0il & Gas Cons. C0aaission Anchorage A DIVISION OF EXXON CORPORATION STATE OF ALASKA C-~,M ALASKA~'.~IL AND GAS CONSERVATION MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator Exxon Company, USA 3. Address Pouch 6601, Anchoraqe, 4. Location of Well 360' SNL and 1817' EWL Sec. 17, T10N-R23E, UM 5. Elevation in feet (indicate KB, DF, etc.) , 42.0!,, KB 12. Alaska 99502 7. Permit No. 81-140 I 6 . Lease Designation and Serial No. ADL 312862 8. APl Number 50-089-20019 9. Unit or Lease Name Alaska State F 10. Well Number Exxon No. 11. Field and Pool Wildcat Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [][] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The 1.6-3/4" BOP stack was changed on January 28, 1982, to a 13-5/8" BOP stack as shown on'~'h~ed sketch. The new stack consists of a 5,000 psi WP annular preventer and three 10,000 psi ram preventers. The new stack was installed on 13-3/8" casing and will be used for all subsequent drilling and testing operations on this' well. R£t£1FE FEB 0 1 ]982 Oil & ~as Cons. A~lchorage C°m/~iSSio~ 14. I hereby certify is true and corre the best of my knowledge. STigned.. ~ Tide Dr±ll±ng Manager he s~ace below for L'~ri~on use Date Conditions of Approval, if any: Approved by ORIG!NAL 'SIGNED BY LONNIE C. SMITH Approved Copy Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate TRIP ' '('~- ~] ~ TANK ~ ANNULAR BOP 5000 pst W.P. KILL LIN RAM BOP SPOOL RAM BOP Pipe 10,000 psi W.P. O® Blind 10,000 psi W.P. CHOKE MANIFOLD Component Specifications pipe lo,oDD psi w.P. eD. (D (D · · I · 2. 3. 4. 5. · 7. 8. 9. 10. Screwed Plug or Gate Valve - 2" size provided with A-section Screwed Plug Valve - 2" size Screwed Tapped Bullplug with Needle Valve and Pressure Gage Flanged Plug or Gate Valve - 2" size provided with wellhead Flanged Plug Valve - 2" size with companion flange to protect valve flange face Flanged Plug or Gate Valve - 2" minimum size Flanged Hydraulically Controlled Gate Valve - 4" minimum size Flanged Plug or Gate Valve - 4" minimum size. Top of Annular Preventer must be equipped with an API Flange Ring Gasket. All flange studs must be in place. The I.D. of the Bell Nipple must not be less than the minimum I.D. of the BOP stack. NOTE: All valves on kill and choke lines 10,000 psi W.P. TYPICAL ARRANGEMENT OF 13-5/8" 10,000 PSI W.P. BOP STACK FOR USE ON 13-3/8" PROTECTIVE AND 9-5/8" PROTECTIVE AND 7" PRODUCTION CASING RECEIVED FEB 0 11982 Oil & Gas Cons. CommissJun Anchorage l< i! ALASKA OIL AND GAS CONSERVATION COMMISSION Chat Chatterto~ O Chairman Co~ss~oae~ Edg~ W. Sip~le, Jr Petrole~ Inspector February 1, 1982 Witness BOPE test on 'EXXon' s Alaska State FI · sec. NW4, T10N, R23 MUM Artic Alaska Rig No. 5 Wednesday, January 27, 1982: I !eft ~An~.chorage for Prudhoe Bay via Alaska Air Lines to witnesS a retest on EXX0n's AlaSka State Fi, Artic Alaska Rig No. 5. U~0n arrival at the drill site, they were in the process of nippling.:~up' the BoPE stack. The purpose of this retest~ was: During a regular weekly BOPE test, a crack was noticed in the 16 3/4 ~.x. 13 5/8 10,000 PSI spool, (see attached drawing). ~ The BOPE test commenced a~t"~4:30 .p~.m. and was concluded at 10:00 p.m. There were no failures. The .t esot was 'completed satisfactorily. I filled out the A.O.G.C.~ BOPE test report which is attached. In summary, I witnessed th~ retest of t~he BOPE on Exxon's Alaska State Fl. EWS ~ vd1 f' ~TATE OF AI ASF~\ ALASKA OIL AS COMSERVATI~ :!I C(~.~FffSSION B.O.P.E. Inspection Rqxprt · Permit #. ~!- /VD !3~ Casin9 Set @ ~ ~_~ ~rillinq Contracto~ /~.~_1¢ ///m$_~ , Rig ~'--Repre~ntative-~~ location, Ceneral ~9 K[ ] -- fell Sign. _~K ~eneral Housekeeping o Bt ~eserve pit D~, .. ~ig ~_ , ACCL%IUIATOR SYSTEM · Full Charge Pressure ~Ooo Pressure After Closure_/_ Test Pressure 5-o00 ( va __L:V¢_. ft. psig psig Funp incr. clos. pres. 200 psig --o,--min AZ sec. Atta : Kelly and Flor Sa. fe~ Valves - ~per Kel~. I/ Test ~essure ~r Kel-ly % / , Test ~es~ i/ ~11 ~pe ..... Test [~essure I~ide ~R,., / ~ Test ~--" %est Pressure_...~--O0_~3 Choke ~nifold No.'-Valves_/..~ No. f langes~__2=. jAdjustable Chokes ~-'.. O__F,~C_~_~LiC_..4~:tx_~4$.~ _ iepair or Replacement of failed equipment to be made within_--o-"-days and'~~ ~ ' i~~LF - [nspector/Canmi~sion office notified. ?istribution ~rig. - AO&CCC ~c - ~C~x~ r~tor :c - Supervisor ALA,SKA ~' . AND GAS CON,SERVATION CO~ AISSION Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Exxon Corporation 81-140 3. Address 8. APl Number Pouch 6601, Anchorage, Ak. 99502 50-089-20019 4. Location of Well atsurface 360' SNL & 1817' EWL, Sec. 17, T10N-R23E, UM 5. Elevation in feet (indicate KB, DF, etc.) KB 40' 6. Lease Designation and Serial No. ADL 312862 9. Unit or Lease Name Alaska State F 10. Well ,No. Exxon No. 1 11. Field and Pool Wildcat For the Month of December ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks EOM Depth: 10,708'. Mo. Footage: 6905'. At 7200' the hole was kicked off to the west using a Dyna Drill. 13. Casing or liner run and quantities of cement, results of pressur9 tests 13-3/8" csg: Pressure te'st to 2800 psi for 30 min., OK. to 16.5 ppg EMW & did not leak off. PIT at 6918'. Pressure up 14. Coring resume and brief description 15. Logs run and depth where run RE'CEIVFD JAN 8 198 16. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE-Report or, his form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 · CONFIDENTIAL r ' ALASKA AND GAS CONSERVATIONoC~~ ilSSlON MONTHLY REPORT OF DRILLING AND WOVER 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Exxon Corporation 81-140 3. Address 8. APl Number :Pouch 660i, Anchorage, Ak. 99502 50- 089-20019 9. Unit or Lease Name - Alaska State F 4. Location of Well atsurface 360' SNL & 1817' EWL, Sec. 17, T10N-R23E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KB 40' ADL 312862 10. Well No. Exxon No. 1 11. Field and Pool Wildcat For the Month of. November ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud well 0001 hrs 11/1/81 EOM Depth: 6905' Mo. Footage: 6905' i13. Casing or liner run and quantities of cement, results of pressur9 tests 20" csg: Set at 2108' & cemented w/10,000 sx permafrost. , PIT at 2160' leaked off at 13.0 ppg EMW. 13-3/8" csg: Set at 6901' & cemented w/1750 sx class 'G'. Top off w/1300 sx permafrost. · 14. Coring resume and brief description 15. Logs run and depth where run 2160': DIL, LSS, BHC Sonic, 4 Arm Caliper 6900': DIL, LSS, 4 Arm Caliper, Temp Survey 1 6. DST data, perforating data, shows of H2S, miscellaneous data DEC 1 ? 198,3 Oil & ~Gas Cons ' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~'~ !J .~Y~ ~J /'~.~' TITLE OperationsSUpervis°r Geoiogy- 'SIGNED ~' DATE December 15, 1981 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 ALASKA OIL AND GAS CONSERVATION COF~4ISSION Hoyle H. Hamilto ' ~' December 7, 1981 Chairman THRU :Lonnie C. Smith Commissioner Ben LeNorman Petroleum Inspector Witness BOPE Test on Exxon's Alaska State F-i, Sec. 17, T10N, R23E, UM Wildcat Sunday, November 29, 1981:i,departed my home at 3:30 p.m. for a 4:00 p.m. sh°Wup'~.a'.5:00 p.m.L-d6Pa~t~re'~'via wien~flight'%i9for Deadhorse arriving at 6:40~'~,m~. ~ ..... ..... Weather~'-9°F', hi"h~ overcast,' light wind. Monday, November 30, 198I:-' Plumbing problems plagued this initial ~£pple-up 0f"16 3/4" h~dri~.~reg~ters"0h~'the'~13 3/8" 72£LB L-80, December 1, 1981:'' At 10:00 a.m. we decided to isolate the ~k ~6~teSting~"Durin~he initial~ pressure up to 5000 psig rgughnecks"reported a ViOlent Shaking of' the stack, so violent man~e%~6dg~6d~"~areal ~(The~staCk'weighs 130,000 pounds.) A measU~ent"~"~ta~en'fr0m~th?'top'Of the. rotary t~ble to the top 0~i~h~'20~'caSing"head whiChi'~when'Cgmpare to a previo?s measurement~:~indi~ated'~'~e'Sta6k had'risen'8~'3/4,,i Based o'~...,th~s datum we as~ed'~'tha%,~'(1)"%h6~Sl£pS~had"failed and the entire string (6901')"~6f:~'i3'3~8.'~h&dslinned"~dOWh'hOie~ (2) the 13 3/8 had parted somehWere between the to' of the cement (at 3500') and We decided to pressure uP'~he packoff to determine if the slips ten minutes, which elimin~%~d'~hi~'~0ssi~illty~~ The'~iil~'iine: was then nippled up to th~'"~20" ~uias a~d"~sixty'barr61~ of mud was pumped at approximatei~ 975'~pS! wi~ no returns through'the 13 3/8". ~ - . ~ased o9 the preceding dat~.We made the following assumptions; (1) A. ice plug in the v b% Or hoSo' Oi. "frO he"out ide Valve and into the wing valve on'th~ C~oke~.~ine;~th~s e~laining the vibration of the stack, (2~"~eihitial m6asuremen%S"made'from the t?p of the rotary tab~6~t0~e~t0~'~'0f~the~'20,'casing head were ~n error, and (3) the Testing resumed at 10:00 P.m? and .... Wednesday, December 2, 1981; . . was completed at 12-30 a.m. BOPE ~nspe~tion ~eport is ~%&c~ed~ - - ' Ben LeNorman ~ s Memo -2- December 7, 1981 Witness BOPE Test on Exxon' s Alaska State F-1 Sec. 17, T10N, R2$E, UM Wildcat I departed North Star Island via Bell 205 helicopter at 7510 a.m. and arrived at Exxon's DeadhOrse heliport at 8:4.5'a~m. I departed Dea~horse via Wien flightl.' %16 at 9~20 a.m. arriving in Anchorage at 11=00 a.m. and at my ho~me"at"ll~30 a.m, In s~maary, I witnessed su¢~cessful BOPE tests on Exxon~s Alaska S tare F- 1. ~' · ............ BL ~vdl 4/81 STATE OF ALASNA ALASKA OIL & -CAS CDNSERVATION CC~-gLISSION B.O.P.E. Inspection Report Operator ~Xx Well /P-~z~ ~/< ~ _~__7-~ 7-~' ~-~ ~tion: Sec ~il ling ~n~a~or~ Representative ~2~3 ~/,;~ A- L-~w~z,~- Pe rmlt #. .~/ "~" /~/}PCasing Set @ ~ ~0/ ft. Rig ~ ~ Repre~ntative ~~' ~ ~~--/,w~S ACCLE!U[_ATOR SYSTEM .... ]Pressure After Closure .J O~ o psig psig Location, -General__ Well Sign Cenera 1 Housekeeping Reserve pit Rig POPE Stack Annular Preventer Pipe Rams- __-~ Blind Rams Choke Line Valves__ H.C.R. Valve__ -'~-- Kill Line Valves Check Valve__ Test Pres sure Pu~p incr. clos. pres. 200 psig min ~,o sec. Full Charge Pressure Attained: ~? min.~o sec. N2 ~c, ~-_-~- ~/~,~3 psig Controls: ~i~ster ~) ;~ R~.t_e__~_.,~ .... B!._i .n.c].%_..._s~v.. i~_c~v_%_r_//~ __ Kelly and Floor Safety Valves Upper Kelly .Test Pressure Lo~er Kelly. Test Pres sure Ball 1]fpe__ Test Pressure Ins ide POP_ Test Pres sure Choke Manifold Test Pressure No. Valves / ~ No. flanges A~j ustable Chokes ~ Hydrauically operated choke / Pi stribut ion orig. - AO&CCC cc - Operator cc - Supervisor Test Results: Failures / Test Time' ~ , hrs Repair or Replacement of failed equipment to be made within_ ~9-- days Inspector/Ccmmission office notified. Remarks:.. ~/~_c~.~- .. ~;:'7";,g,,',~,3 /?,~-/-.jT~,.-', /~~~~- ~ ~-~-m-7-?~ Inspector II::::I ON COM-PANY, U.S.A. POUCH 6601 · ANCHORAGE, AI_ASKA 99502' EXPLORATION DEPARTMENT- ALASKA/PACIFIC DIVISION November 24, 1981 Exxon Alaska State F Well No. 1 LO/NS 81-159 Surf. Loc.: Sec. 17, T10N, R23E, UbI ADL 312863 BH Loc.: Sec. 18, T10N, R23E, UM ADL 312862 Exxon Alaska State D Well No. 1 LO/NS 80-226 Surf. Loc.: Sec. 23, T10N, R23E, UM ADL 312866 BH Loc.: Same Mr. Glenn Harrison, Director Division of Minerals & Energy Management Pouch 7-005 Anchorage, Alaska 99510 Dear Mr..Harrison: By this letter we are requesting an amendment of each of the subject plans of operation to permit the storage'of a portion of the casing required for each of the drilling operations in progress in a manner which will require its extension beyond the drilling pad and onto the ice covered land area adjacent to each pad. - As the casing stored in this manner will have been run in the hole at each location long before spring break-up occurs we foresee no possibility of an environmental disturbance of any kind occurring as a result of this procedure. Accordingly, we are requesting your permission to store casing in the manner described and your amendment of the operations permit to so provide for such storage. In the event there are questions or further information of any nature is required please do not hesitate to contact the undersigned and it will be provided. ~ :: Yours very truly, Robert K. Riddle 'RKR:et Ak. g Dept of Fish and Game, Attn: J. Scott Grundy Div. of Forest, Land & Water Management, Attn: William Copeland ~-~ A DIVISION OF EXXON CORPORATION ALASKA OIL AND GAS CONSERVATION COMMISSION Hoy le Chairman c. Commissioner Bobby Petroleum Ins~ctor November 18, 1981 Witness/~PE Test on xxon Sec. 17,--~10N, R23E, UM. Permit #81-141 Friday Noyember 13,_ 1981 - This BOPE stack is nippled up on the 20" COnductO~ Pi'~i '~t"consists of two sets of 5" pipe rams, one set of 13 3/8 casing rams, one set of blind rams, and one annular preventer, all 16 3/4" bore. As the attached BOPE inspection report sh~ws the choke manifold was tested to 5000 psi. The BOPE stack was tested to 1500 psi because there was not a 20" x 13 3/8" hanger spool used, therefore a test plug could not be used. Due to many delays caused by shortage material, nippling up the new stack, and having t° break and retighten several flanges the BOPE test finally began at 3:00 a.m. November 15, 1981 and was completed at 6200 a.m. In summary I witnessed the BOPE test on the 20" conductor at Exxon' s D-1. O&G ~ 4 4/80 , - S'FA'['E ¢)~' ' ~' - .... - ALASKA OIL & GAS CQ;;SI~RVATIOII COt'iMISSION' B.O.P.E. Inspection Report OPerator-- ~--~.~ O t~) RcpreJentative :/' ~;f/:~ Location: Sec lq Tif~R~QC,.'~tl U~ . ~O~Casin9 See 0~/O(~ ft. · , ~cation, General ~ --- 1_0/'" General Housekeeping Reserve' pit ~L/ BOPE Stack, Annular Preventer Pipe Rams Blind Rams Choke Line ·Valves H.C.R. Valve Kill Line Valves Check Valve " Test Results: Failures Test pres shire / Uo~ ..... /.~oo ACCUtlU I~\TOR SYS Tilt-1 _'lFull Charge Pressure:'it'.F'~L'? psig ,,~ il, Pressure After Closure/!.'~:~/... ',."'.~ psig 1200 psig Above Precharge Attained:- Full Charge Pressure.Attained: .~' · / /'~ '~ ' ' '~ / ~/'~.c . ' -" .I~"' "' :/,. :,"C~ ' ,I...~' ' N2 .... . , . Controls: MaSter__?.~_ ~ ps ig Re,no te~¢~ ~. l~l inds switch~ ' ~.._.. ............ ..--.=.~.~..:_~.- .- ==---~_ ....... _ , Kel.l.y___and Floor__S._a,.f_e L~L Va1 yes Upper Kelly Test ~ressurq_ Lower Kelly.., / Test Pressure ,'~:',," Ball Type Z~ Test Pressure ,'[',," Inside BOP_ f.., Test Pres sure Choke t'lanifold_Ly ~'D' / No. valves /'/~ Test Pressure No. flanges ~Z/~2 Adjustable Chokes~__" llydrauically opera ted choke · Repair or Replacement of failed equipment to be made within ..... days and ! /'. · Inspector/Commission office notified. :A :,'- ," ' ' '.:: :-.>." Remarks: ' ~ ~?-" '/. ;,,,~ ,,,, , . ..~ , /...:' ~,,:,... .... · z ,,'~.; · t:> : : './?: · f- )P ~. /:~ '?.X~?.,..', · :~'~ ' ~" 1 ' ...... . ..... ...7 . ,:.,- ':.~ .... ., Distribution · orig - AO&GCC cc - Operator cc - Supervisor E ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 PRODUCTION DEPARTMENT ALASKA OPERATIONS October 28, 1981 Mr. Hoyle H. Hamilton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Hamilton: Attached are two Sundry Notices which request approval to set the 20" 133 ppf casing at 2000' instead of 2200' on each the Exxon 'A!la~ska ::S:~:~te D-1 and F:~i wells. The notices also inform you of a change in our 20" casing running procedure. The slips and elevators available for running the 20" casing on both locations are rated to 150 tons. To allow for our overpull safety factor, we will allow a maximum hook load of 100 tons. The combination of setting 200' less of 20" casing, plus floating in the last five (5) joints (procedure change) will assure We stay below our maximum allowable hook load. Very truly yours, Drilling Manager RLS: sjm Attachment s 295-663-665 cc: L. Smith (AOGCC) RECEll/ED Alaska Oil & Gas Cons. Commission Anchorage A DIVISION OF EXXON CORPORATION _"'-) STATE OF ALASKA ..... ALASK IL AND GAS cONSERVATION C(uMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Exxon Corporation 81-140 3. Address 8. APl Number P. O. Box 2180, Houston, Texas 77001 s0-089-20019 4. Location of Well 360' SNL and 1817' EWL Sec. 17, T10N-R23E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. +4.0' Mean Sea Level (Ground)I 'ADL 312862 12. 9. Unit or Lease Name Alaska State 10. Well Number Ex~on No. 11. Field and Pool Wildcat Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing ~;) . Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation F1 Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed OPerations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Change 20" casing shoe depth to 2000' from 2200' plus revise 20" casing running procedure to "floating" in last 5 its. These changes are required~in order to maintain the total maximum running hook load plus safety factor below the r.ated capacity of the 20" casing elevators and slips. OCT 2 9 Alaska Oil & Gas Cons, Colf~rnissio~ Re. ported ~'~ Oat~ ~~) ~cb0rage 14.he,hereby certilfY th ~/~~egin/~s true and correct to the best of mY knowledge- The space below for Co--use Conditions of Approval, if any: Approved by ORIG~)IA[ SIGNED BY lOflNIE C. SMITH Approved '~ Return~; By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1.80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ALASKA OIL AND CAS CONSERVATION COMMISSION Hoyle H. Hamiltoq/~ Chairman .. / Thru: Lonnie C.~ Smith~-~ Commissioner /-- Poug Amos Petroleum InsPector October 23, 1981 Conduct Inspection on Diverter Systems on Exxon's Alaska State D-1 Wel 1,_~No. 4, 'an Sohio ~ -ag -elta. 99 Well Nabors Rig No. 22E. Uednesday October 14, 1981 - I traveled this date from Anchorage to Prudhoe Bay. As the attached pictures, No.'s 1-4 show, the diverter system on ADCO Rig #4 Alaska State D-1 well, is installed and is in compliance with our requirements. As the attached pictures No.'s 5-9 show; the diverter system on ADCO Rig }~o. 5 Alaska State F-1 well, is installed. There is some fitting left to be done on the line running to the mud pit. Pictures 5 and 6 show the remaining work to be completed. This system is in cOmpliance with our requirements. As the attached pictures No.'s 10-15 show, the diverter system on Nabor's Rig #26E Sohio's Sag 'Delta #9, is installed and is for the most part in compliance with our requirements. I do not recommend that the Commission approve another diverter system with the type of 90° elbows used on this system. API RP53 recommends that for 90° turns, a targeted tee be used. This was the only problem area I found with this diverter system. In summary I conducted the inspection on the diverter systems on Exxon's D-1 and F-1 wells and on Sohio's Sag Delta #9 well. As the attached pictures show the diverter systems are installed, and do meet our requirements as approved. There is still some fitting to be done on Exxon's F-1 well, as pictures 5 and 6 indicate. I recommend that the Commission not approve any more diverter systems with 90° elbows on the diverter lines. ~s per API RP53 these turns should be with targeted tees. E (.ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION October 16, 1981 ....... Re: n Alaska State "F" Well [ .... LO/NS 81-159 Surf. Loci: Sec. 17, T10N, R23E, UM ADL 312863 BH Loc.: Sec. 18, T10N, R23E, UM ADL 312862 Exxon Alaska State "D" Well No. 1 LO/NS 80-226 Surf. Loc.: Sec. 23, T10N, R23E, UM ADL 312866 BH Loc.: Same Mr. Glenn Harrison, Director Division of Minerals and Energy Management Pouch 7-005 Anchorage, Alaska 99510 Dear Mr. Harrison: Today I met with Mr. William Van Dyke and explained Exxon's desire to amend each of the subject plans of operation to provide for-the commencement of downhole drilling at each location on October 24, 1981 instead of November 1 as presently provided in each plan. As the several members of your staff who have visited each site will attest, each location has been completed, and the drilling rigs, Arctic Alaska Drilling Company Rig No. 4 (D-l) and Arctic Alaska Drilling Company Rig No. 5 (F-l), as well as all necessary equipment and supplies have been on location and ready for the commencement of drilling operations for a period of several months. It is Exxon's belief predicated upon the experience gained in the drilling of each of the wells which we have drilled in the area of the subject operations, commencing with Flaxman Island State Not ! in 1975 throughout the drilling of the four Pt. Thomson Unit wells, the last which was completed one year ago, that drilling operations could be commenced one week in advance of the stated date, November 1, without any environmental risk or adverse consequences of any nature. Permafrost may be anticipated for the initial 1200 to 1500 feet and neither hydrocarbons, gas hydrates nor shallow hazards of any kind may be expected to be encountered in the formation which will be penetrated in either drilling operation were you to authorize our commencement of such operations one week in advance of the scheduled date. A DIVISION OF EXXON CORPORATION While this requested variance of one week from both the lease provisions and Exxon's plans of operation as previously submitted may seem of little consequence, especially if viewed in relation to the six and one-half months the AADCO Rig No. 4 has been on the Alaska State D-1 location, it is by no means incon- ceivable that such variance could provide just the required amount of additional time at the conclusion of the operations to permit the wells to be completed within the time constraints provided for the conclusion of drilling operations. We readily acknowledge that we have come to you with this request very late in this, the last month before the stated commencement date, however, you may be assured that any consideration which may be given to it will be sincerely appreciated. Yours very truly, Robert K. Riddle RKR:et cc: Ak. Oil & Gas Conservation Commission, Attn: Hoyle H. Hamilton Ak. Dept. of Environmental Conservation, Attn: Douglas Lowery Ak. Dept. of Fish and Game, Attn: J. Scott Grundy Div. of Forest, Land & Water Management, Attn: William Copeland OCT 2 0 Oil &,~_a~ Co~s. Co~i$~io~ ~c~orage, September 29, 1981 Mr. A. Lo Hermann Division Drilling Manager ~xxon Corporation Pouch 6601 Anchorage, Alaska 99502 Alaska State F, Hxxon No. 1 E~xxon Corporation Permit No. 81-140 Sur. Loc.~ 360*SNL, 1817~EWL, Sec 17, T10~, R23~, Bottomhole Loc...- 1879tSNL, 2226WWEL, Sec 18, TION, Dear Mr. Hermann~ Enclosed is .the approved application for permit to drill the above referenced well. Well samples and a mud log are required. A directional survey is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except exPerimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations Promulgated thereunder (Title 5, Alaska Administrative .Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the .regulations promulgated thereunder (Title 18, Alaska Administrative COde, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. A. L. Hermann Alaska State F, Exxon -2- September 29, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office at least 48 hours before the well is spudded. We would like to be notified so that a representative of the Commission may be present to inspect the diverter system before the conductor Shoe is drilled and also to witness testing of blowout preventer equipment before surface casing shoe is dri I led. In the event of suspension or abandonment, please give this office adequate advance notification so that w~ may have a witness present. Very truly your s, ~ ono~miit.~¥ ORDER OF THE CON~M;SS:ON Chairman Alaska Oil & Gas Conservation Commission cc: Departmen.t of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. E ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 PRODUCTION DEPARTMENT ALASKA OPERATIONS September 18, 1981 Exxon Diverter System Practices Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attention: Mr. Lonnie C. Smith Gentlemen: This is to clarify our diverter design and operating prac- tices in response to inquiries from the Commission. The system used on all of our state leases meets the require- ments of 20 AAC 25.035 (b) (1) and is illustrated schematically in the .attached figure. The main features of the system as it' will be set up on our Alaska State D-1 and F-1 wells are as follows (note: a similar system was Used tO drill the surface hole on Duck Island Unit Well No. 3 earlier this year): · The valve marked No. 1 on the attached figure is a full-opening "knife-type" gate valve with a 3000 psig hydraulic operator. This valve is normally closed to prevent drilling fluid from entering the diverter line and blocking it by freezing. The hydraulic system is interlocked with the annular BOP controls, such that the valve opens be'fore the annular closes. 2. A single 10 inch flanged diverter line extends · northward from the well, through the rig sub- structure, and outside to the vicinity of the reserve pit. At this point, the line branches with one path going straight to the reserve pit, and the other heading off the location to the west· The well would be diverted to the reserve pit with wind from the two prevailing directions (ENE or WSW) or from the south. Only in the unlikely event of wind from the north would it be · necessary to divert off the location to keep gas . . from blowing toward the rig. ~!:ska Oil & Gas Co~s. Commi~. Anchorage A DIVISION OF EXXON CORPORATION Alaska Oil and Gas Conservation Commission September 18, 1981 Page Two · The valves marked No. 2 in the figure are manual lever-operated "knife-type" full-opening gate valves. The one on the reserve pit line is main- tained in the open position and will be marked with a sign reading: KEEP OPEN EXCEPT WHEN DIVERTING OFF LOCATION In order to prevent an inadvertent discharge off the location, the second valve is maintained in the closed position and will be marked with a sign reading: KEEP CLOSED EXCEPT WHEN DIVERTING OFF LOCATION Mechanical latches are used to maintain the valves in either the fully open or fully closed posi- tions, as required. · Photographs of the manual valve manifold which will be used on both D-1 and F-1 are enclosed. These have been annotated on the reverse side to explain what is shown. Please let us know if you need any further information on the diverter system or our operating procedures.~ We would be happy to show you the equipment first hand after it is set up in late October. RAM: sjm Attachments TYP I CAL 2000 PSI W.P. DIVERTER STACK AND LINE FOR USE ON 30" Trip Tank 20" spool 30",. x 20" swage Flowl ire Off location 2000 psi W.P. ~ Annular BOP '~" ' J-t O (~)To reserve pit II1: ~1; :!~ =~~:~~ Hinimum 6" diverter lines 1. Full opening hydraulically operated valve interlocked such that the diverter line valve will always be open before annular BOP is closed. 2. Full opening manually operated valves with one valve always in the open position to control flow to reserve pit or off location.~ ,~rEIVED~, ~Al~sk:~ :.,: c',,-:i~;4~s Cons. CommJsslOi1 Anchorage ALASKA OiL AND GAS CONSERVATION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] R'EDRILL [] DEEPEN l-1 lb. Type of well EXPLORATORY I'~ DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE [] MULTIPLE ZONE 2. Name of operator Exxon Corporation 3. Address Pouch ~6601, ..A__nchorage, .Ak~ 99502 ~.~. ~p 4. Location of wei~ ~t ,~r-~ace-~ .......... ~ 0//~ ~, ~ (~/~9~.~ 9. Unit or lease name 360' SNL and 1817'-EWL Sec 17, TlON-R23E, U.M. _ a~O, Alaska State F At tOp of proposed producing interval ~f~O;;;~, CO~/~,~ 10, Well number 1518, SNL and 1264' WEL Sec 18, T10N-R23E, U.M. ..Exxon No. ;I At total depth ~'O~. Field and pool 1879' SNL and 2226, WEL Sec 18, T10N-R23E, U. M. 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. +4.0' Mean Sea Level (Ground)l ADL 312862 Wildcat 12. Bond information (see 20 AAC 25.025) , B-1-4 TYPe0il & Gas Conservatio~retvand/ornumber5134049~ State Bond File Amount' $100,000.00 13. Distance and direction from nearest town ! 14. Distance to nearest property or lease line ~t' ~)istance to nearest drilling or compl_eted I /'~i~ ~north nf Exxon #1 . 45 mi. east of DeadhorsE~'es AK 481 feet ' we Pnin~ Thnrnqnn teat 16. Proposed depth (MD & TVD) I 17. Number of acres in lease ......... 16.500(MD), 15,400(TVD),feet 5,589.35 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 7,100 feet. 21 20. Anticipated pressures MAXIMUM HOLE ANGLE 30 o i(see 20 AAC 25.035 (c) (2) 18. Approximate spud date 11-1-81 9..640 psig~ , Surface _~L2~12._psig@~ ~_ ~{')Oft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH ' ' TOP TVD I MD BOTTOM TVD ',o I ', 70, ,._0J ,2,200' ',O / 17,000 16,000/13,250/E2,500' I QUANTITY OF CEM..ENT t (include stage data) J Permafrost cmt t° surf, ace Permafrost Cmt to surface Hole j Casing 40"1 30" _ 26" t,, 20" .16-1./41 13-3/8 12-1/41'9-5/8" '8-1/21' 7" Weight Grade !" WT 133 K-55 " 72 L-80 43.5/47 P-110/RS~¢ 32/35/38 P- 110 Coupling Length I 70, Butt 12,200' Butt 17,000 LTC/Bu t t'l 3';~5~'! LTC 16,500 22. Describe proposea program: BLOWOUT PREVENTERS' A MD 12 ,420/11, ,830/152)0443)0/165d(Y15.400 ' 20" annular blowout [~revent6 will be installed on the conductor, as shown on the attached sketCh. removed while opening the 17-1/2" hole to 26" to 2200'. type will inst Apri Pres pres and Approx T0C 5000' j Approx T0C 9000' ! 500'above potential HC}one r with diverter lines The diverter will be A 16-3/4", 5000 psi WP annular BOP and three 16-3/4", 10,000 psi WP ram preventers will be installed on the 20" casing as shown on the attached sketch, and be used along with a 10,000 psi WP choke manifold during drilling and well testing. BOP allation and testing will be in compliance with Alaska State Regulations effective 1 13, 1980. Anticipated surface pressures are shown in the casing design section. sure on the 5000 psi WP annular BOP will never be allowed to exceed its design working sure. If drilling progreSses so that Exxon can demonstrate the ability to operate safely, ice conditions justify, a request will be made for State authorization to continue drilling and downho~ operations until May 15, 1982, as per State LeaSe Stipulation No. 9. 23. I hereby certify that ,he fo~gJ:)in.g is ttue and correct tO the best of my knowledge . The space below for Com~ . CONDITIONS OF APPROVAL Samples required I Mud log required ]~YES []NO I ]~YES •NO Permit number I Approval date ~/-/~0 j 09/29/81 Directional Survey required ~,yES []NO APl number SEE COVER LETTER FOR OTHER REQUIREMENTS Seotember 29; lqR1 APPROVED BY Form 10-401 ,COMMISSIONER by order of the Commission DATE Rev. 7-1-80 Submit in triplicate CONTINGENCY PLAN ALASKA STATE "F" EXXON NO. I The objective of this plan is to outline major operating and contingency requirements to ensure a safe and efficient operation throughout the drilling activity. LOCATION The barrier island location was designed to accommodate the drilling rig, camp, and necessary supplies for a winter drilling operation. The location, which is enclosed with sheet piling and has a freeboard of 7 feet, is designed to resist ice override and is above the maximum indicated tide based on observations along the surrounding coast. The sheet piling will also provide erosion protection during summer storms. Based on the status of the well and ice conditions existing just prior to March 31, a request may be made at that time to continue drilling operations to no later than May 15. Otherwise, the rig and associated equipment will be placed on a standby status and all fuel and lube oil will be removed until remobilization during the summer and fall of 1982 for drilling operations November 1. POLLUTION CONTROL The location and operating plan will be designed to provide containment of all drilling operation effluents that could be considered as pollutants. An impermeable sheet will be placed under the drilling rig to collect and divert any liquid waste for proper disposal. Fuel will be stored in welded steel tanks located within an impermeably lined area. Sewage and kitchen waste water will be processed through a State approved biological treating system with excess sludge being incinerated and the disinfected liquid contained in a steel holding tank. Treated effluent may be used as drill water, if needed, with excess being injected as described below. A separate insulated steel holding tank will be provided to store the treating plant effluent in the event of a system malfunction. A flare pit will be located clear of the rig to permit emergency burning of any produced hydrocarbons resulting from well testing. A primary feature of the drilling plan will be to provide 20" x 13-3/8" and 13-3/8" x 9-5/8" annular injection capability. The well casing program is designed to set the 20" surface casing through any possible freshwater zones and set the 13-3/8" protective casing through the major gravel sections for injection of waste fluids to approximately 5,000 feet. The 9-5/8" protective casing will be set at 12,500 feet and cemented to isolate the saltwater sand sections from below, the surface casing shoe to approximately 9,000 feet fOr injection of lUbe oil, excess mud, melt water, waste waters, and well test liquids. The reserve pit will be maintained at a minimum level at all times to provide for containment of well fluids in the event of an upset. All pits will be pumped out to a minimum level and waste water injected into the injection zone before abandoning the location. The entire operation is planned so that no hazardous fluids associated with the operation will be discharged on the surface outside the location. Additional precautions will be taken to prevent drainage of hydrocarbons to the sea. After freezeup, the surface of the island will be sprayed with watef~i~E~ SEP 1 6 1981 Alaslm Oil & Gas Cons. Commission Anchorage an impervious ice seal. This should prevent liquids spilled on the surface from draining downward into the gravel fill. Also, any spills will be cleaned up as soon as possible. Snow contaminated by toxic substances will be incinerated on site or hauled to adisposal site on shore. The island surface will be thoroughly cleaned after clearing the island of all drilling equipment. The drilling contractor will be required to develop a comprehensive site specific SPCC plan to prevent pollution as a result of any drilling rig operation. In addition, Exxon will have a site specific Oil Spill Contingency Plan which will outline responses to spills of any size which might occur. In addition to the impermeable sheet under the rig mats, drip pans and other containment measures are provided under the engines and rig machinery. Good housekeeping will be stressed on all parts of the location with emphasis on minimizing contamination of the peripheral drainage from the island. An on-site oil spill cleanup crew will be designated within the drilling crew. These personnel will be given instruction in the prevention and initial control of oil spills. Most minor operational spills of oil will be collected with sorbent material and disposed of by incineration. Equipment and material, which will be listed in the SPCC Plan, will be kept on location for the purpose of building containment dikes and berms, for containing oil spills reaching the water, and for oil spill cleanup and disposal. If required, additional personnel and equipment can be rapidly mobilized from either oil spill contractors or the Alaskan Beaufort Sea Oil Spill Response Body {ABSORB) Organization, of which Exxon is a member. For spills beyond the capability of the on-site cleanup crew to contain or clean up, the Exxon North Slope Oil Spill Response Team, as outlined in the Exxon North Alaska Oil Spill Manual, will be activated to the degree required by the severity of the spill. WELL CONTROL AND PERSONNEL SAFETY Personnel safety and well control are the uppermost factors in well design and operational planning. SUfficient data are available to plan the well for evaluation of.the geologic objectives, provide for subsurface disposal of waste water, and conduct a safe drilling operation. Exxon and key contract supervisory drilling personnel will be experienced in well control detection and procedures and will be graduates of a certified well control school. Abnormal 'pressure technology will be used to predict and detect changes in formation pressure to permit adjusting the casing and drilling.fluid program to control the well. Emphasis will be placed on well control procedures and equipment to permit circulating out a formation influx in an orderly manner if it should be necessary. Any hydrocarbons in the influx will be diverted to the reserve pit and either burned or later injected into the annulus. In the unlikely event of an unplanned upset resulting in uncontrolled well flow, the following basic procedures will be followed: 1. Divert well flow to the reserve pit as the first defense against a spill. When the safe working, level of the pit is reached, switch the flow to the surrounding ice. After the well is under control, produced well fluids will be disposed of by injection into the annulus. The contaminated ice and snow will be cleaned up and incinerated or hauled to an approved disposal site. The capacity of the reserve pit will be maintained at a maximum, practical working capacity at all timeS by keeping mud and fluid levels at a minimum and pumping fluids into the injection annulus when possible. ~E~EIVED SEP 1 6 19B! 'Almsl~ Oil & Gas Cons. Commission Anchorage ' t 2. Finalize plans for drilling a relief well from previously determined available locations specified in the site specific Oil Spill Contingency Plan. Site selection will be strongly influenced by the bottom hole location of the flowing well at the time of loss of control. 3. Ignite well fluids at the wellhead, if the situation warrants, only after discussion with proper governmental agencies and Exxon management. Major supplies of mud, cement, casing, fuel, and miscellaneous supplies will be transported over winter roads or flown directly to location prior to breakup. After breakup, if required, light consumables will be transported by heli- copters. Tubulars and wellheads, along with gravel for preparing a relief well location, will be maintained at a suitable location in the area. In the extremely unlikely event of an out-of-control well, both the Exxon North Slope Well Emergency Response Team and the North Slope Oil Spill Response Team, as outlined in the previously mentioned Exxon North Alaska Oil Spill Manual, will be activated. The Well Emergency Team will be responsible for performing all well control functions which includes all surface well control procedures, as well as plans for rapid implementation of an appropriate relief well plan. The Oil Spill Response Team will be responsible for taking immediate action to minimize environmental damage and to institute cleanup operations as required. The Exxon North Alaska Oil Spill Manual contains detailed oil spill scenarios, detection, containment, and cleanup information. An outline of a relief well plan is contained in the site specific Oil Spill Contingency Plan for the well. The basic plan involves construction of a location and drilling a directional well designed to penetrate the flowing zone near the original wellbore. DRP 'cf 7/27/81 RECEIVED SEP 1 6 Alaska OJt & Gas Cons. Commission ~chorage Alaska State F Exxon No. i SUBSURFACE INJECTION: After setting the 20" casing below any possible freshwater sands and setting the 13-3/8" casing at 7000' through the major gravel zones, waste fluids will be injected 'from 2200' to 5000' down the 20" x 13-3/8" annulus. After setting the 9-5/8" casing at 12,500', waste fluids and hydrocarbons will be injected into saltwater zones from 7000' to 9000' down the 13-3/8" x. 9-5/8" annulus. CASING DESIGN CRITERIA: See attached Wellbore Sketch for design Surface - 20" @ 2200' Burst - Considers gas gradient to the surface causing lost returns at the shoe assuming maximum expected leakoff gradient. External fluid weight 9.0 ppg. Casing Design Surface Pressure (CDSP) CDSP = (Max. shoe leakoff gradient - gas gradient) casing depth = (15.0 x .052 - 0.10) 2200' : 1,496 psi · Minimum Exxon Safety Factors Burst 1.312 Collapse 1.00 Tension 1.50 Protective - 13-3/8" @ 7000' Burst - Considers gas kick of sufficient intensity and volume to cause lost returns .assuming maximum expected leakoff gradient and casing filled with water. External fluid weight 9.0 ppg. Casing Design Surface Pressure (CDSP) CDSP = (Max. shoe leakoff gradient - water gradient) casing depth : (16.0 x .052 -8.33 x .052) 7,000" : 2792 psi Collapse - considers surface pressure = 0 psi, internal fluid weight 8.33 ppg and external fluid weight 10.5 ppg. Maximum Collapse Pressure (MCP) MCP = (External fluid gradient- internal fluid gradient)casing depth - surface pressure (10.5 x .052 - 8.33 x .052) 7,000' - 0 790 psi RECEIVED SEP 1 6 198] Alaska Oil & Gas Cons. Commission Anchorage Permafrost Freezeback - Considers maximum external collapse gradient of 1.44 psi/ft and minimum internal fluid weight of 9.0 ppg. Maximum Collapse Pressure (MCP) MCP: (Max. external gradient - min. fluid gradient) max. permafrost depth (1.44 - 9.0 x .052) 2500' 2,430 psi Permafrost Thaw Subsidence - 13-3/8" 72#/ft L-80 Butt post yield strain performance exceeds the requirements for Prudhoe Bay Field rules, based on worst case well spacing. Exxon Minimum Safety Factors Burst 1.312 Collapse 1.00 Tension 1.50 PROTECTIVE 9-5/8" @ 12,500' TVD (13,250' MD) Burst - Considers gas kick of sufficient intensity and volume to qause lost returns assuming maximum expected leakoff gradient and casing filled with water. External fluid weight 9.0 ppg. Casing Design Surface Pressure (CDSP) CDSP = (Max. shoe leakoff gradient - water gradient) casing depth : (18.0 x .052 - 8.33 x .052) 12,500' = 6285 psi Collapse - Considers surface pressure = 0 psi, internal fluid weight 8.33 ppg and external fluid weight 12.5 ppg Maximum Collapse Pressure (MCP) MCP = (External fluid gradient- internal fluid gradient)casing depth - surface pressure (12.5 x .052 - 8.33 x .052) 12,500' - 0 2,710 psi Minimum Exxon Safety Factors Burst 1.312 Collapse 1.00 Tension 1.50 PRODUCTION 7' @ 15,400' TVD (16,600 MD) RECEIVED SEP 1 6 1..q 1 Naska Oil & Gas Cons. Commission Anchorage Burst -Considers shut-in gas well surface pressure and formation pressure of 15.5 ppg. Casing Design Surface Pressure (CDSP) CDSP = (Max. anticipated formation pressure - gas gradient) casing depth = (15.5 x .052 - 0.18) 15,400..' : 9,640 psi Collapse - Considers surface pressure = 0 psi, internal fluid weight = 0 ppg, and formation pressure = 15.5 ppg Maximum Collapse Pressure (MCP) MCP = (Formation pressure - internal fluid gradient) casing depth - surface pressure (15.5 x .052 - O) 15,400 - 0 12,412 psi Exxon Minimum Safety Factors Burst 1.312 Collapse 1.125 Tension 1.50 Maximum Anticipated Surface Pressure 9,640 psi Maximum Anticipated Bottom Hole Pressure 12,412 psi SEP 1 6 19 1 Al~sk~ 0~ 8, Gas Cons. commissio~ Anchorage WELLBORE & CASING DESIGN SKETCH ALASKA STATE F EXXON NO. 1 O* · 32#/ft P-11[ LTC ~--11,800'--' 35#/ft P-11~ LTC (12,420' MD' +--14,300'--~ 38#/ft P-11( LTC (15,310' MD ~ 30" Conductor @ 70' 20" 133#/ft K-55 Butt Surface @ 2200' Waste fluids injection zone TOC @ approximately 5000' t13-3/8" 72#/ft L-80 Butt Protective Casing @ 7000' Waste fluids and hydrocarbon injection zone ' TOC @ approximately 9000' 9-5/8" 43.5#/ft P-110 LTC Protective Casing @ 6000' 9-5/8" 47#/ft RS-90 Butt Protective Casing @ 12,500' 13,250' MD 7" Production Casing @ TD RECEIVED SEP 1 6 Oil & Gas Cons. Commission Anchorage TYP ! CAL ~oo0 ~s~ ..~d~v~~ s~c~ ~.~ USE ON 30" ALASKA STATE "F" EXXON NO. 1 Trip Tank~_ F1 owl i ne 2000 psi W.P. Annular BOP (~) Off location (~)To reserve pit 20" spool 30" x 20" swage Minimum 6" diverter lines RECEIVED SEP 1 6 1~~t Naska Oil & Gas Cons. Commission Anchorage 1. Full opening hYdraulically operated'valves interlocked such that the diverter line valve will always be open before annular BOP is .closed.~ 2. Full opening manually operated valves with one valve always in the. open position to contro~ flow to reserve pit or off location. TANK (~~000 pst W.P. KILL RAM BOP Pipe 10,000 pst W.P. Co,~onent SJ~e...ct ficattons RAM BOP Blindl0,000 pst W.P. RAM BOP Pipe 10,00O psi W.P. CHOKE MANIFOLD 1. Screwed Plug or Gate Valve - 2" stze provtded with AoSeCtton 2. Screwed Plug Valve- 2" stze 3. Screwed Tapped Bullplug with ~leedle Valve and Pressure Gage 4. Flan.oed Plug or Gate Valve - 2" size provided with wellhead 5. Flanged Plug Valve - 2" size with companion flange to protect valve flange face 6. Flan.oed Plug or Gate Valve - 2" minimum size 7. Flanged Hydraulically Controlled Gate Valve - 3" 8. Flanged Flapper Type Check Valve - 3" 9. Flanged Hydraulically Controlled Gate Valve - 4" minimum size 10. Flanged Plug Valve - 4" minimum size. Gate valve not acceptable. 11. Top of. Annular Preventer must be equipped with an APl Flange Ring Gasket. All flange studs must be in place. 12. The 1.0. of the Bell Nipple must not be less than the minimum I.D. of the BOP stack. NOTE: All valves on kill and choke lines lO,O00 psi W.P. TYPICAL ARRANGEMENT OF 16-3/4" .lO,O00 PSI W.P. BOP STACK FOR .USE ON 20" .SUREAC_E AND. 13-_3/R" AND_g-5/F~" P~LI]'FC_TIVE AND 7" PRODUCTION CASING ALASKA STATE"F" EXXON NO. 1 RECEIVED SEP 1 6 1981 Naska Oil & Gas 0ons. Commission Aflchorag8 Alaska Island Duchess Island PROPOSED j ALASKA STATE F-I Lot. 70°1:5' :58.14" Long. 146021'37.68" y= 5~ 932,797' x: 45523:54' I AR ISLAND · c:~. I 28 y- 27 ' 26 i 25 I :360' I I" = i MIL E 'l 35 36 l 1 TOPO FROM FLAXMAN ISLAND(A-4 a A-5), USGS RECEIVED ALASKA STATE F-I S 17, T ION,R2 5E,UM DETAIL 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 direct supervision and that all details are correct. DATE /~U"R"V E YO~ REVISED REVISED SEP 1 6 198] Well N a ~,,i,,.. ~l 7/8/8 I Surface ~d~l & Gas Cons. Comrrli$siorl 3/5/81 PROPOSED W E L~li~l~'~l~l 0 N ALASKA STATE F-I LOCATED IN SECTION 17 ~ T I0 N, R23E, U.M. EXXON FOR COMPANY U.S.A. BY BESSE, EPPS 8~ POTTS ANCHORAGE~ ALASKA ~..44- 1:552 E ,ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION September 16, 1981 Re: Exxon Alaska State "F" Well No. 1 Surf. Loc.: Sec. 17, T10N, R23E, UM ADL 312863 BH Loc.: Sec. 18, T10N, R23E, UM ADL 312862 Mr. Hoyle H. Hamilton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton: Exxon Corporation submits the following in regard to the captioned well: (1) State of Alaska, Oil and Gas Conservation Commission Permit to Drill, Form 10-401, in triplicate with triplicate copies of the location plat and contingency plan. (2) Exxon Check No. 3495, dated August 29, 1980, in the amount of $100.00 in payment of the required permit fee. Con6urrently with this application, we are filing.with the State Division of Minerals and Energy Management the following: (1) A Plan of Operations describing the drilling pad, rig supply, water supply, waste and sewage disposal and pollution prevention. (2) Two area operations maps: Exhibit "A", scale 1" = 2000' showing the location and vicinity of the well and pad layout and Exhibit "B", scale 1" = 10,000' showing sea ice road, Rolligon haul route and relationship of subject operation to those within Duck Island and Pt. Thomson Units. (3) Survey plat with X and Y coordinates as well as latitude and longitude. This well will be directionally drilled southwesterlY from the surface location on Exxon's oil and gas lease ADL 312863 (North Star Island) to a bottom hole location on Exxon's oil and gas lease ADL 312862. The sheet pile enclosed gravel fill site has been constructed with two cellers and two conductor strings So that the subject well and the Alaska State "E" No. 1 may be drilled consecutively. As stated in our application to the Division of Minerals and Energy Management, Arctic Alaska Drilling Company's Rig No. 5 is on location and all facilities are in order awaiting commencement of drilling operations in compliance with stipulation number 9 of the respective oil and gas leases. Yours very truly, ECEIVED Alaska Oil & Gas Cons. Commisslort A. chorage RKR: et A DIVISION OF EXXON CORPORATION C w/encl: EPA, Region Ten, Attn: Danford Bodien, P.E. E ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION September 16, 1981 Re: Exxon Alaska State "F" Well No. 1 Surf. Loc.: Sec. 17, T10N, R23E, UM ADL 312863 BH Loc.: Sec. 18, T10N, R23E, UM ADL 312862 Mr. Glenn Harrison, Director Division of Minerals & Energy Management Pouch 7-005 Anchorage, Alaska 99510 Dear Mr. Harrison: By letter dated August 29, 1980 to Acting Director ~Ross G. Schaff Exxon filed a plan of operation for the drilling of a well to be located on North Star Island on State of Alaska oil and gas lease, ADL 312863, designated "Alaska State 'E' Well No. 1." Your letter of February 18, 1981 granted approval to said plan of operation which had meanwhile been assigned lease operations number LO/NS 80-228. By a similar letter, likewise dated August 29, 1980 to the acting direCtor Exxon filed a plan of operation for the drilling of a well to be located on Alaska Island on State of Alaska oil and gas lease, ADL 312861, designated "Alaska State 'F' Well No. 1." On October 7, 1980, however, we advised.Dr. Schaff that it had become necessary to defer plans to commence operations on the Alaska Island lease and withdrew our application for his approval of the drilling operations plan. We now propose to drill an additional well not previously applied for and have designated it Alaska State "F" Well No. 1, utilizing the designation of the prior well withdrawn by our letter of October 7, 1980. The plan of operation for the new Alaska"state "F" Well No. 1 is virtually identical with the plan which you have approved for the Alaska State "E" No. 1 with.but one important exception, the "F" No. 1 well will be directionally drilled, southwesterly from the surface location in Section 17, T10N, R23E, UM on North Star Island, to a bottom hole location in Section 18, T10N, R23E, UM in the adjacent Exxon oil and gas lease ADL 312862. In accordance with your approval of the "E" No. 1 plan of operation two cellers and two conductor strings were installed at the time the drilling pad was constructed enabling the "F" No. 1 and the "E" No. 1 to be drilled consecutively. Although, as stated, the "E" No. 1 plan of operation has been approved, we are herewith resubmitting what is essentially the same plan, together with the Plat of Survey and Area Operation Maps, Exhibits A and B, for the Alaska State "F" No. 1 Well, and ask that this plan now be approved for the subject we~~ withstanding the fact that all construction described therein has bee~%~VED A DIVISION OF EXXON CORPORATION SEP 1 6 ]98! Naska 0il & Gas Cons. Commission Anchorage Mr. Glenn Harrison Page two September 16, 1981 accomplished, Arctic Alaska Drilling Company's Rig No. 5 is on location and all facilities are in order awaiting the commencement of drilling operations in compliance with stipulation number 9 of the respective oil and gas leases. Yours very truly, RKR:et enclosures c w/encl: EPA, Region Ten, Attn: Danford G. Bodien, P.E. Ak. Oil & Gas Conservation Commission, Attn: Hoyle H. Hamilton S£p 1 6 1981 Oil & oas cons. AnChorage C°mrniesion EXXON COMPANY, U.S.A. PLAN OF OPERATIONS EXXON ALASKA STATE "F" (ADL 312862) WELL NO. I General This well will be drilled as a directional hole and the surface location will be 1,817 feet EWL, 360 feet SNL, Section 17, TION, R23E, U.M. The proposed bottom- hole location will be 2,226 feet WEL and 1,879 feet SNL, Section 18, TiON, R23E, U.M. The drill site is on the west end of North Star Island in the Beaufort Sea about 46 miles east of the Prudhoe Bay East Dock. The drill site was constructed during the winter of 1980-81 and the well will be spudded November 1, 1981. Approximately 8 months will be required for drilling and testing. The drilling site was originally approved for construction and planned for the Alaska State"E" Well No. 1. It is now planned to drill the Alaska State "F" Well No. I as the initial well from this location. The drilling rig for this location will be the Arctic Alaska Drilling Company Rig No. 5. Logistics Access to the proposed location during the winters of 1981-82 and 1982-83 will be provided by a sea ice road along the shoreline of the Beaufort Sea extending from Prudhoe Bay East Dock to a point approximately 1 mile east of Point Sweeney and continuing in a northerly direction to the location. An ice road from the drill site to the water source for drilling operations will be required during the winters of 1981-82 and 1982-83. Water sources for this well may be both Lake No. 8 and the abandoned gravel source. These road routes are shown by Exhibits "A" and "B" which are attached. Also seawater desalination units*may be used to provide water for drilling operations. Upon completion of drill site construction, some supplies were moved in late winter 1981 to the location over ice roads. The rig and camp will be barged to the proposed North Star Island drill site in the summer of 1981. Additional supplies for drilling operations will be transported to the drill site by barge during the open water season of 1981 and 1982. After freeze-up begins, personnel and supplies will be transported by helicopters and/or air cushion vehicles until ice roads and landing strips are completed. Traffic will be routed to avoid disrupting known active waterfowl nesting and staging sites. An ice landing strip, approximately 2,000 feet long, will be constructed to facilitate air transportation during the winters of 1981-82 and 1982-83. During the winter, if bulky equipment must be delivered on short notice or large shipments can be accumulated, an ocean ice landing strip for Hercules aircraft may be constructed on the sea ice. * If desalinization units are uSed: 1) the effluent will be discharged on-ice as opposed to under-ice, and 2) the intakes will be designed to av~i~(~~i~)ant impingement and entrainment of fish eggs and larvae. SEP 1 6,1981 Alaska 0il & Gas Cons. Commission Anchorage 'j Drill ing Operations This well is scheduled to be spudded on November 1, 1981. If drilling progresses so that Exxon can demonstrate the ability to operate safely, and ice conditions justify, a request will be made for state authorization to continue drilling and downhole operations until May 15, 1982, as per State Lease Stipulation No. 9. If the proposed well cannot be completed within the authorized 1981-82 interval, drilling operations will be temporarily suspended. All personnel, fuel, and lubricants will be removed from the drill site by May 30, 1982. Fuel and supplies will be barged again to the drill site in the late summer of 1982 so that drilling operations can resume on November 1, 1982. An impermeable plastic sheet will be installed under the drilling rig to collect liquid drainage and direct it to the well cellar for recovery and disposal. All pits, except for the flare pit, will be lined with an impermeable plastic liner. The reserve pit will be used primarily for the emergency storage of excess drilling fluids and occasionally for small amounts of cement-contaminated mud. The wellbore will be designed for annular injection for the subsurface disposal of waste liquids. Water for drilling operations will be supplied by seawater desalination or hauled from water sources discussed above. A snow melter may also be used to supplement rig water requirements. Potable water will be processed through a state-approved water treating unit before use in the camp. Disposal of Waste Materials The following waste material procedures will operations. After completion of the well, any promptly removed from the drill site. be observed during drilling remaining materials will be 1. Drilling mud will be injected in the casing annulus or hauled to a state- approved site for disposal. e Cut~!ngs from the wellbore will be temporarily stored on the surface of North Star Island and later hauled to a centrally located landfill in the Point Thomson area for disposal. The development and operation of this landfill, to serve future locations in the Point Thomson area, will be covered by separate permit applications to appropriate government agencies. e Sewage effluent and gray water. Sanitary sewage will be treated with a state-approved sewage disposal unit owned by Arctic Alaska Drilling Company. Treated effluent from this unit will be combined with gray water from the camp kitchen and bathrooms in a steel storage tank and used in drilling mud or rig wash water. A 25,000-gallon sewage effluent tank will be provided for the emergency storage of these liquids during upset conditions. Any surplus quantities of this liquid will be discharged in the casing annulus. 4. Domestic garbage will be disposed of in a state-approved incinerator. · Combustible wastes such as paper, wood, and cardboard will be incinerated or · open burned. RECEIVED SEP 1 6 1981 ~19.qka Oil & Gas Cons. Commission 6. Noncombustible wastes such as scrap metal, batteries, drums, wirelines, etc., will be hauled to a state-approved site for disposal. 7. Well test fluids. Produced gas will be flared in accordance with the air quality control permit issued by theADEC. Produced liquids will be injected down the casing annulus or otherwise disposed of iq accordance with said permit. 8. Waste oil will be injected in the casing annulus or hauled to a state- approved site for disposal. Surface Protection and Restoration Plan Surface transportation to the drill site will be primarily over ice roads during the winter or by barge during the summer. Rolligons and other applicable forms of transportation will be used in the spring and fall and prior to full ice road construction. Special procedures for drilling and subsurface equipment are required by the unique characteristics of the permafrost area. Casing cement used through the permafrost zones is of special composition to reduce possibility of freezing and other casing problems. Casing is run and cemented through the permafrost, and in the event of production or interruption of operation, the uncemented casing must be protected by the use of non-freezing fluid. At the completion of the well, the location and adjoining area will be cleared of all waste materials. Development Plans If oil is discovered in sufficient quantities to warrant future development, the Prudhoe Bayto Valdez oil pipeline will be the probable marketing outlet from the area. Oil and casinghead gas would be processed through central oil gathering facilities with oil being transported to the Trans-Alaska Pipeline System. If commercial quantities of gas are discovered, development of a gas market outlet will be related to studies to market gas from the Prudhoe area. DRP-cf 9/2/81 RECElVEO SEP 1 6 1981 _ Alaska Oil & Gas Cons. CommiSsion Anchorage Alaska Island ---t Duchess Island ®-~'- ~ s~ ~r~/~ FO~ ...~J~-~ )) ~o~r~o~ PROPOSED ALASKA STATE F-I Lat. 70°13' 38.14" .on~. ,~o~'~Z~" ! 25 so 29 I I 27 26 I 25 :560' I ALASKA STATE F-I S 17, T ION,R2 3E,U~ DETAIL ] L I '-._ TOPO FROM FLAXMAN ISLAND(A-4 & A-5), USGS ," =, E RECEIVED 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 direct supervision and that all details are correct. _ DATE /,~U'-R"V EYO~ ' ' REVISED REVISED SEP 1 6 lgSl Well Name Surface Location i i1~) R 0 ~1~1~ I~ ~LI~Ei_~ i:ia~missi0 n Anchorage 7/8/8) ALASKA STATE F-i LOCATED IN SECTION 17, TION, R23E, U.M. EXXON FOR COMPANY U.S.A. BY BESSE, EPPS & POTTS ANCHORAGE, ALASKA 3_44 E ON COMPANY. U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 PRODUCTION DEPARTMENT ALASKA OPERATIONS September 1, 1981 Alaska Department of Environmental Conservation P. O. Box 1601 'Fairbanks, AK 99701 Attn: .Mr. Doug Lowery Gentlemen: An oil spill.occurred at Exxon's Alaska State F-1 drill site at 2030 ADT on August 27, 1981. Pursuant to 18 AAC 75.100 under authority of AS 46.03.020 (10) (A) and AS 46.03.755, this letter confirms the telephone report made by J. R. Hinn to Ms. Gloria Thomas at 0930 ADT on August 28, 1981'. The information required by 18 AAC 75.110 fOllows: 1. Date and time of discharge: August 27', 1981 at 2030 ADT. · Location of the discharge: Exxon's Alaska State F-1 drill pad Located on North Star Island, Lat 70o13'38'' Long. 146012'37''. e Persons causing or responsible for discharge: None. Discharge was the result of equipment failure. · Type and amount of discharge: Approximately 1/2 gallon of hydraulic oil was discharged onto the gravel drill pad. Cause of discharge: Defective valve. Equalizer valve body burst on a Portable Hydraulic Power Pack. 6. .Environmental damage: None. Hydraulic oil remained on the gravel pad. ECEIVED SEP - 3 1981 Alaska Oil & Gas Cons. Commissk. Anchorage A DIVISION OF EXXON CORPORATION Alaska Department of Environmental Conservation Page Two ® Cleanup actions undertaken: Absorbent was used to remove the hydraulic oil from a puddle of water standing on the gravel pad. No gravel was contami- nated and all oil was recovered from the water. Contaminated absorbent was placed in plastic bags. e Location, method and date of disposal: Plastic bags containing contaminated absorbent were placed in drums and transported to Exxon's Deadhorse Warehouse on August 28, 1981. Contaminants were given to the North Slope Borough for incineration on August 28, 1981. · Action taken to prevent recurrence: Defective valve has been replaced. Please contact me at (907) 276-4552 for any additional information you may require. Ver,; truly yours, JRH:sjm 240-910 cc: Mr. Hoyle Hamilton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 R. K. Riddle RECEIVED SEP - 3 I98I Alaska 0ii & Gas Cons. Commission Anchorage COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION Re: October 7, 1980 ' Section 10, T10N, R22E, ADL 312861 I ST"~'T T' Arctic Slope, Alask~ LO/NS: 80- 227 ~ -' ' ..... ~ ., Dr. Ross G. Schaff Acting Director Division of Minerals and Energy Management 703 West Northern Lights Blvd. Anchorage, Alaska 99503 Dear Dr. Schaff: Circumstances have occurred which require that Exxon defer for the present the plans to commence operations on the above oil and gas lease as outlined in our letter of application to you of August 29., 1980. As we are unable to state at this time the precise details regarding a resumption of plans for such operations, we are by this letter withdrawing the application for the respective approvals issued bY your office for this activity and will refile such application at a future date when we are in a better position to do so. We sincerely regret any inconvenience this change in plans may have caused you or your staff. Yours very truly, RKR: et C: EPA Region Ten, Attn: Danford G. Bodien., P.E. Alaska Oil & Gas Conservation Commission, Attn: Hoyle Hamilton Ak. Dept. of Environmental Conservation, Attn: D. Lowery Div. of Forest, Land & Water Mgmt., Attn: W. Copeland Dept. of Fish & Game, Attn: J. Scott Grundy OCT 1 5 1980 A DIVISION OF EXXON CORPORATION E) ON COMPANY. U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION October 7, 1980 Re: Alaska State "F" Well No. Section 10, T10N, R22E, UM ADL 312861 Arctic Slope, Alaska Mr. Hoyle H. Hamilton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton: Circumstances have occurred which require that Exxon defer for the present the plans to commence operations on the above oil and gas lease as outlined in our letter of application to you of August 29, 1980. As we are unable to state at this time the precise details regarding a resumption of plans for such operations, we are by this letter withdrawing the application for the permit to drill the subject well and will refile such application at a future date when we are in a better position to do so. We sincerely regret any inconvenience this change in plans may have caused you or your staff. Yours very truly, RKR: et c: EPA Region Ten, Attn: Danford G. Bodien, P.E. A DIVISION OF EXXON CORPORATION E) , ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION Re: Au:gust 29, 1980 Exxon Alaska State "F" Well No. 1 Section 10, T10N, R22E, UM ADL 312861 Arctic Slope, Alaska Permit No.: Mr. Hoyle H. Hamilton, Chairman State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton: Exxon Corporation submits the following in regard to the captioned well: (1) State of Alaska, Oil and Gas Conservation Committee Permit to Drill, Form 10-401, in triplicate with triplicate copies of the location plat and contingency plan. (1) Exxon Check No. 3495, dated August 29, 1980, in the amount of $100.00 in payment of the required permit fee. Concurrently with this application, we are filing with the State Division~of Minerals and Energy Management the following: (1) A plan of operations describing the drilling pad, rig supply, water supply, waste and sewage disposal and pollution prevention. (2) Two area operations maps: Exhibit "A", scale 1"=2000' showing the location and vicinity of the well and pad layout and Exhibit "B", scale 1"=10,000' showing sea ice road, Rolligon haul route and relationship of subject operation to those within Duck Island and Pt. Thomson Units. (3) Survey plat with X and Y coordinates as well as latitude and longitude. This well, situated in the easterly portion of Alaska Island will be drilled as a straight hole in the winter 1981-82. Contingent upon regulatory approval the sheet pile enclosed gravel fill site will be prepared as soon as Weather conditions in the winter of 1980-81 permit. Although the drilling rig has not been selected A DIVISION OF EXXON CORPORATION Mr. Hoyle H. Hamilton Page two August 29, 1980 at this time it is anticipated that we shall be able upon completion of the drill site construction to move the drilling rig, camp and supplies to the location over the sea ice road depicted on Exhibit "A". As an alternate, however, the rig and camp will be barged to the drill site in the summer of 1981. Drilling operations will be commenced with the barging of fuel and supplies to the drill site in late summer 1981, regardless of the mode selected for transport of the rig, and the well will be spudded on November 1, 1981 in compliance with lease stipulations. As approximately seven months will be required for drilling and testing, in the event drilling progresses so that Exxon Can demonstrate the ability to operate safely, and ice conditions justify, a request will be made for state authorization to continue drilling and downhole operations until May 15, 1982 in accordance with State Lease Stipulation No. 9. Yours very truly, RKR: et enclosures c: EPA - Region Ten, Attn: Danford Bodien, P.E. C Obq JfY STATE D;'.. ~E DESIGN BY ~CASING SIZE HCLE sIZE >IJD b~. I . h~fD GR.-i ~fYD 'Jr. II )~/g. HYD. GR. II ?zi/£t. M.S.P. 'Bottom Top Wt. Grade ~nraad / 70, o .. .... 7-0 2. Zoo ..4. ,.,;_ :,.u,4 TDF COLL~3SE CO LL~==SZ W£ !GHT TENSION ~"~'~" W/ ~F~ -top of ST~:':C~E , P?~SS. ~ P~SiST. W/O BE section TEi.fSiOi~ bolt~ tension lbs:-- 'lbs 1030 lbs ~i.~ Formulae: Co!lapse resistance in tension X (Collapse press~e ratify) · Burst Pressure = ~L$P + Depth ( }{yd. Gr. II BF (Bouyancy Factor) = 1. oo - ( o..o15 3 x '..:u~ wt. ~) CDF EDF ??ZCE CC ¥370 z? 70o /~'"'o o '~:~' , ,¢ ¢'~''''e- Calculations: Xol Toaa: Cost ,' o. CHECK LIST FOR NEW WELL PERMITS Company ~Z~2z-~, Lease & Well No. /~/~j/~ ITEM APPROVE DATE (1) Fee (2) Loc" (3) Admin 2, 3. 4. 5. 6. 7. 8. thru 1 ' 10. · 11. (5) 'L-'t'2i thru ~4) 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24, 25. Is conductor string provided ,. . Is enough cement used to circulate Will cement'tie in surface and intermediate or production str Will cement cover all known productive horizons .: .......... Will Surface casing' protect fresh water zones .............. [ Will all casing give adequate safety in collapse, tension and YES NO Is the permit fee attached .......................................... : Is well to be located in a defined pool ............. Is well located proper distance from other wells .. 11',, ' Is sufficient undedicated acreage available in this pool ...... Is well to be deviated and is well bore plat included ............... Is operator the only affected party ................................. /~ . Can permit be approved before ten-day wait .......................... / t~ ....... ~n. gs ,~?~. ,~ · · · · · e e e e Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ ,,~. Is adequate well bore separation proposed. .......................... Is a diverter system required ..................................... Are necessary diagrams o£ diverter and BOP equipment all:ached i. . ~',, Does BOPE have suffic±ent pressure rating - Test to~. ' ! " Does the choke manifold comply w/AP1 RP-53 (Feb,78),:,'? ....... Additional requirements '~ eeete ieee e i eeee le I Iee eee.e'e~ ~eee,eeee,ee ~eeee · Additional Remarks: ~z~ ,~[ ~/ a~-r?-~ ~.f~,~ ,,~ ~.~~' REMARKS Geology: Eng in e,er~_~ing JAL (~. J KT~~,~ r~v:' 03/10/81 INITIA~ [GEO.' UNIT [ON/OFF POOL ,,C.LASS. ,STATUS AREA ' NO. : SHORE ....... , ...... - CHECK LIST FOR NEW WELL PERMITS Oc~y ~2~Cq-~ I tern .~Approve Date Ye s (1) Fee.. ~_~ ~-/L-Fo 1. Is the permit fee attached ......................................... ~~ / 2. Is well to be located in a defined pool ............................. (2) Loc. No 3. Is a registered survey plat attached ............................... .~< 4. Is well located proper distance frcm property line .................. 5. Is well located proper distance frcm other wells..i ................... 6 Is sufficient undedicated acreage available in this pool ......... ~ . 7. Is well to be deviated ................................. 8 Is operator the only affected ~y ..... i]].i ]i ........ 9. Can permit be approved before ten-day, wait. ................... i i i iii i~ .... 10. Boos operator have a l~nd in force ............ . . ..... 11. Is a conservation order needed ...................................... 12. Is administrative approval needed ................................... 13. IS co~uctor string provided ........................................ ~... 14. Is enough cement used to circulate on conductor and surface ......... (4) ca, 15. Will cement tie in surface and intermediate or production strings ... ~ .... 16. Will cement cover all known productive horizons ..................... ~ .... 17. Will surface casing protect fresh water zones ................ , ...... ~ ...... 18. 19. Will all casing give adequate safety in collapse, tension ~ burst..~L~ Does BOPE have sufficient pressure rating,- Test to/o~.0 o~spsig . .~ Approval Receded: A~ditional Requirements: ,Geol.: WVA Engineering: LCS __ BEW~ rev: 03/05/80 Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No 'special'effort has been made to chronologically organize this category of informatiOn, ~ .... ~CHSU~BERGER----* ~mmmmmemmem~emmmmemmm~ LIS TAPE VERIFICATION 5ISTING LVP OlO.HO1 VERIFICATION 5ISTING PAG~ ** REEL HEADER SERVICE NANE :SERVIC DATE ;82/04/28 REEL NAME :REEL ID CONTINUATION ~ :01 PREVIOUS REEL COMMENTS :REEL COMMENTS ** TAPE HEADER SERVICE NAME :SERVIC DATE ~82/0&/28 ORIGIN :1070 TAPE NAME :63004 CONTINUATION ~ :01 PREVIOUS TAPE COMME~TS :TAPE COMMENTS ** FILE HEADER FILE NAME :$ERVIC.O01 SERVICE NAME : VERSION # DATE : MAXIMOM LENGT~ : ~024 FILE TYPE PREVIOUS FiLE ** INFORMATION RECORDS MNEM CONTENTS CN : EXXO~ CO~,PANY USA WN : ALASKA STATE FN : WILDCAT RANG: 23E TOWN: lOM SECT; 17 COUN: N.$LOPE STAT: ALASKA CTRY: USA MN_~ COMTENT$ PRES: DILOOIF RECORD TYPE 047 UNIT TYPE CATE SIZE CODE 000 000 018 065 000 000 016 065 000 000 008 065 000 000 003 065 000 000 003 065 000 000 002 065 000 000 008 065 000 000 006 065 000 000 004 065 UNIT TYPE CATE SIZE CODE 000 000 007 065 LVP OIO.HO1 VERIFICATION LISTING RECORD TYPE 047 ** RECORD TYPE 047 ~ ** COMMENTS ** SCHLUMBERGER PACIFIC COAST COMPUTING CENTER COMPANY = ~:XXOM COMPANY - USA WELL = ALASKA $TATE FIELD = WILDCAT CODNTY = N. SLOPE STATE = ALASKA TAPE ~ 800 BPI JOE ~ 10707,63004 RUN #5, LOGGED 4-APR-82 BOTTOM LOG INTERVAL TOP LOG INTERVAL CASING-LOGGER BIT SIZE TYPE DENSITY 14297.0 FT. 13914.0 FT 7 iN. ~ 13~14 5 875 I~ 15.9 LB/G LVP OlO.HOl t VERIFICATION LISTING PAGE VISCOSITY = 43,0 S PM = 11.6 FLUID LOSS = 4.0 C3 RM ~ ~EAS. TEMP. = 1.285 RNF ~ ~AS. TEMP. = 0.5i0 R~C ~ ~EAS. TEMP. = 2.386 RN ~ bHT = 0.458 MATRIX LI~ESTONE ** DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE REPR CODE 9 4 65 0 ! 66 SERVICE SERVI E UNIT ID ORDER ~ LOG DEPT FT 0 SFLU DIL ~- OHM~ 7 ILD DIL- OR~M 7 ILM DIL- O}.l~ 7 SP DiL~ MV 7 GR LIB GAPI 7 NPHI FDM ...... PU 42 RHOB FDN ........... G/C3 42 DRHO FDN .......... G/C3 42 CALl FDN .... 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DRHO NCNb GR C2 SP DRHO 13400.0000 I97,7312 O 0190 291~0000 5~,3i25 -999.2500 CALf FCNL DT GR 13300.0000 225.5t88 0,0034 29~2.0000 58,2030 -999.2500 SFbO GR CALF FCNL DT GR 13200 229 -0 2828 62 -999 000 5OO 011 000 828 .250 SFLU GR CALI FCNL DT GR 13100 232 - 0 292~ 59 -999 .0000 .0000 .0146 ~0000 3384 .25O0 SFbU GR CALl FCN5 DT GR 13000 236 -0 ,0000 .2275 .0200 SFLL~ GR CALI 5ISTING -999. 2500 ~.8306 61.7422 NPHI 12,1953 GR 966,5000 LTL -999,2500 -999,2500 5,2109 52.6250 NPHI 13.2578 GR 1089.0000 DTb -999.2500 GR -999,2500 4.2695 53,3125 NPHI 15.9531 GR i053.0000 DTL -999.2500 GR -999.2500 3,5029 !LD 51,3125 NPHI 16.4688 GR 985,0000 LTL -999.2500 GR -999.250C 4.54!0 ibD 58.2030 NPHI 15.1328 GR 947.5000 LTL -999,2500 GR -999.2500 4.6680 62.8281 NPHI 15.32~1 GR 963.0000 DTL -999.2500 GR -999.2500 5,3083 59.3384 NPHI 14.7266 GR 943.5000 DTL -999,2500 GR -999.2500 5.6229 60,0313 NPHI 13.5076 GR 3,9842 IL~ 25,5859 RHOB 59 1250 NRAT 85!9102 DT -999 2500 C! 4,9414 IL~ 23,7793 RHOB 51.3125 NRAT 81,4375 DT -999,2500 C! 4,1523 IbM 23,7305 RHOB 49,2813 NRAT 80.2187 DT -999.2500 C1 3,7040 IbM 26,6602 RHOB 51,6875 NRAT 88.0391 DT -999.2500 1465 RHOB 54. 1562 NRAT 81.8159 DT -999.2500 C1 4 4766 IbM 22",7539 RHOB 59.9062 NRAT 82.2813 DT -999,2500 C! 4,914~ 25,097 RHOB 56.9062 NRAT 82,6504 DT -999.2500 Cl 5.1620 22,5098 54,i250 NRAT ~A PAGE 3 9398 2 6309 2 B086 85 7529 -999 2500 4 ~477 2 859 2 7O90 81 5313 -999 2500 4 1445 2 5371 2 7051 80 1562 -999 2500 3.6282 2 5605 2,8672 87,06~5 -999.2500 4 2385 2 5820 2 7813 81 9949 -999 2500 4 4258 . 2.5488 2.6504 82,8750 -999.2500 4 7917 2 5234 2 7793 82 6016 -999 2500 5.1588 2.5371 2.6367 LVP OiO.HO1 ~'ERIFICATIO~ NCNb 30~2.0000 FCNL GR 60.0313 DT C2 -999.2500 GR DEPT 1290o.0000 SFLU SP 21~,8657 GR DR~O -0,0107 CALl NCNb 3558,0000 FCNb GR 42,8555 DT C2 -999.2500 GR DEPT 128,00.0000 .... SFLU SP 2'40,5371 DRHO '0~0068 CALF NCNb 2898,0000 FCNb GA 59.0859 DT C2 -999.2500 GR DEPT ~2700.0000 SFLU SP 243.1250 GR DRHG 0.0068 CALI NCNb 2788.0000 FCNL GR 62.5391 DT C2 -999.2500 GR DEPY 12600 0000 SFLU SP 251~1016 GR DRHO -0,0186 CAbI NCNb 2800~0000 FCNL GR 55.9922 DT C2 -999.2500 GR DEPT 12500.0000 SFLU SP 249.1250 GR DRHO -0.0]56 CALl NCNb 2778.0000 FCNL GR 54.2813 DT C2 -999.2500 GR DEPT 12400.0000 SFLU SP 252.1250 GR DR}{O -0.0142 CALI NCNb 2666.0000 FCNL GR 54.6406 DT C2 -999,2500 GR DS~ 123oo oooo SFLU SP 259io~oo G~ DRMO 0 0078 CALf NCNb 2888.0000 FCNL GR ~0,§07~ D~ C2 -999.2500 ~R DEPT 12200.0000 SFLU LISTING 1052.0000 DTL -999.2500 GR -999.2500 13.4899 42.8555 9.6641 GR 1228.0000 DTL -999.2500 GR -999.2500 5.766i ILD 59.0859 NPMI 15.2109 GR 935.0000 DTL -999.2500 GR -999.2500 3.86!2 62.539~ 16.9844 GR 889,5000 DTb -999.2500 GR -999.2500 4.2028 ILD 55.9922 MPHI 13.8125 GR 825.50O0 DTL -999,2500 GR -999,2500 5.0078 54.2813 13.5859 GR 816.5000 DTL -999.2500 GR -999.2500 4.3906 IbO 54.6406 NPHI 13.7813 GR 775,500¢) DTb -999.2500 GR -999.2500 4,2383 ILD 60.5078 NPHi 20.9531 GR 857.5000 DTL -999.2500 GR -999.2500 6.523~ IbD 81.4944 DT -999.2500 C1 11.1554 22,6074 RHOB 38.9687 NRAT 84.3535 DT -999.2500 C1 5.6176 25.8301 55.1562 NRAT 83.2803 DT -999,2500 C1 4.1094 IbM 28.2715 RHOB 57.3438 NRAT 82.1703 DT -999.2500 C1 4 1426 IbM 26i4160 RHOB 57 06251 NRAT 83.3809 DT -999.2500 Ci 4.9023 IbM 28.2227 RHOB 56,0313 N'RAT 289.4375 DT -999.2500 C1 4.8750 IbM 31.2500 RHOB 47.1562 NRAT 84.2813 DT -999,2500 C1 4 ~234 29 .' 992 RHOB 54.1562 NRAT 84.5000 DT -999,2500 6.4922 PAGE 8~) 1418 : soo II 7935. 2 4043 2 6445 83 8037 -999 2500 5.4998 2.5254 2.8184 83.8594 -999.2500 4 404' 2 ~293 2 9531 82 3890 -999 2500 4 1221 2 4902 2 8516 84 0566 -999 2500 4 8320 2~4629 2.9512 213.3125 -999'2500 4.5664 2 4766 3 1172 84 2500 -999 2500 4 4258 2 4941 3 0039 84 6875 -999 2500 6.5820 LVP OIO.HO1 VERIFICATIO~ SP 257,0000 GR DRHO -0,0181 CALl NCNb 2964,0000 FCNL GR 54,2187 DT C2 -999.2500 GR DEPT 12100.0000 SFLU NCNb 251 0000 FCNL GR 61.9687 DT C2 -999.2500 GR DEPT 12000,0000 SFbU SP -26,7813~ GR DRHO '999,25.00 CAbI NC~qb -999,.2500 FCNb GR 54,2500 DT C2 -999,2500 GR DEPT 11900.0000 SFLU SP -27,4531 GR DRHO -999,2500 CALI NCNb -999,2500 FCNL GR 59.8652 DT C2 -999,2500 GR DEPT 11800,0000 SFBU Sp -27,9375 GR DRHD -999.2500 CALI NCNB -999,2500 FCNL S~ 63,5938 DT 72 -999,2500 GR )EPT 11700,0000 SFLU !$P -32,4688 GR )RHO -999,2500 CALI ~CNL -999.2500 FCN~ ~R 63,9004 DT 72 -999,2500 GR DEPT 11600,0000 SFLU SP -34,9062 GR DRHO ~999 2500 CALl 4CNL -999~2500 FCNL ~R 64.5000 OT ~2 -999.2500 GR )EPT 11500,0000 SFLU ~P -35,3750 GR 3RHG 999 2500 CALl ]CNL :999:2500 FCNb ;R 62,2422 DT 22 -999,2500 GR blSTING 6 2 86 -99 -99 6 73 -99 -99 6 -99 -99 -99 -99 6 -99 -99 -99 -99 7 -99 -99 -99 -99 6 =99 -99 -99 -99 7 -99 -99 -99 -99 6 -99 -99 -99 -99 4.2187 1,0000 $,0000 9,2500 9,2500 4,3~72 1,9687 8,390~ 7.5000 9,2500 9.2500 6.3955 4,8672 9.2500 9.2500 9,2500 9,2500 4,4717 6,3281 9.2500 9.2500 9.2500 9,2500 4,2~81 0,45~1 9,2500 9.2500 9.2500 9.2500 3,4946 6.9219 9,2500 9.2500 9.2500 9.2500 3.5195 3.2969 9.2500 9.2500 9.2500 9.2500 3.5757 5,7344 9,2500 9,2500 9.2500 9.2500 NPHI GR DTL GR NPHI GR DTL GR ILD NPMI GR OTb GR NPMI GR DTL GR NPHI GR DTL GR NPMI GR GR ILD NPHI GR DT5 GR ILD NPHI GR DTL GR 29.4922 RM[)B 51,2500 NRAT 227.3750 DT -999.2500 C! 4 8398 I~h~-~ 34:9121 aHOa 72,1250 NRAT 87,0000 DT -999,2500 Ci 6,3438 IbM -999,2500 RHOB -999,2500 NRAT -999,2500 DT -999,2500 2500 RHOB 999,2500 NRAT -999,2500 DT -999.2500 Ci 4.6523 IbM 99.2500 DT -999.2500 Cl 3,9609 IbM -999.2500 RHOB -999,2500 NRAT -999,2500 DT -999.2500 Cl 3,7461 IbM -999,2500 RHOB -999.2500 NRAT -999.2500 DT -999,2500 C1 3.8242 IbM -999 2500 RHOB -999:2500 NRAT -999.2500 DT -999,2500 Cl PAGE 2.4238 3.0195 . 86,3438 999,2500 4766 4355 3 3184 78 3750 -999 2500 6 3594 -999 2500 -999 2500 87 9687 -999 2500 4 9023 -999 2500 -999 2500 8~ 6250 -999 2500 4 .9023 :999 2500 999 2500 82 0000 -999 2500 4 1133 -999 2500 -999 2500 83 4734 -999 2500 3 8301 -999 2500 -999 2500 . 86 3750 999 2500 . 3 9297 999 2500 -999 2500 85 2500 -999 2500 LVP DEPT SP DRHO C2 DEPT SP NCNL GR C2 DEPT SP ~CNL 22 SP )RHO ~CNh SR DEPT 5P ~CNL ".2 DEPT DRHO ~C~JL ?2 )EPT 3P DRHO ~CNL 22 3P OiO.HO1 VERIFICATION 11400,0000 SFLU -35,9375 GR -999,2500 CALl -999,2500 FCNL 60,1758 DT -999,2500 GR 11300.0000 -3~.9375 -99 ,2500 -999,2500 56,4805 -999,2500 11200,0000 -39,9375 -999,2500 -999,2500 62,8281 -999,2500 11100,0000 -38,4688 0,0107 2656,0000 68,6250 -999,2500 11000.0000 -41,5000 0,0283 2472,0000 72,4375 -999,2500 1O900,0000 -41,8437 0,0527 3099,8750 52,3984 -999,2500 10800,0000 -40,9375 0.0331 2890,5000 63,9893 -999,2500 10700,0000 -42.9687 0,0366 2928,0000 SFLU GR CALI DT GR G~ CALI FCNL DT SFLU GR CALl FCNL D~ GR '$FLO GR CALl FCNL DT GR SFLO GR CALl FCNL DT GR SFLU CALf FCNL DT GR GR CALl FCNL LISTING 3 58 -999 -999 -999 -999 58 -999 -999 -999 -999 3 55 -999 -999 -999 -999 3 65 21 798 -999 -999 3 67 21 656 -999 -999 4 62 21 998 -999 -999 4 61 21 992 -999 -999 3 72 21 960 .9375 .8047 .2500 ,2500 ,2500 ,2500 ,6250 .5156 .2500 .2500 .2500 .2500 ,7256 ,6719 ,2500 ,2500 ,2500 ,2500 .8223 ,4063 ,7i88 ,0000 ,2500 ,25O0 ,0840 ,8437 ,7031 ,0000 ,2500 .2500 ,3369 ,1719 ,7031 ,7500 ,2500 ,2500 ,2734 ,2109 ,7031 ,7500 ,2500 ,2500 ,8960 ,0781 ,7031 ,5000 ILL NPHI DTL GR ILL NPHI GR LTL GR NPHI GR DTL GR NPHI GR LTL GR NPHI GR DTL GR NPHI GR DTL GR ILL NPHI GR DT5 GR NPHI GR DTL 4.3203 -999,2500 RHOB -999,2500 NRAT -999.2500 DT -999.2500 C1 4,8047 ILM -999,2500 RHDB -999.2500 NRAT -999,2500 DT -999,2500 C1 4,3984 -999,2500 RHOB -999,2500 NRAT -999,2500 DT -999,2500 C1 4 6250 27:5391 RHOB 62,4063 NRAT -999,2500 DT -999,2500 C1 3,8164 33,0566 RHOB 64,1875 NRAT -999,2500 DT -999,2500 CI 5,1719 ILM 24,6902 RHOB 58,4922 NRAT -999,2500 DT -999,2500 Ci 5.0898 IbM 22 7966 RHOB 63:0547 NR~T -999,2500 DT -999,2500 Ci 4,8164 25 6836 RHOB 69;1250 NRAT -999,2500 DT PAGE 4 5703 -999 2500 -999 2500 85 4336 -999 2500 25,5938 999~2500 -999,2500 83,2471 999,2500 4,70~1 : 9 . soo 99'2500 85,6719 -999.2500 4 7852 2 2910 3 0469 85 5000 -999 2500 i: 7031 3516 8 8750 -999,2500 5 3750 2 4579 2 8543 82 0635 -999 2500 5 0586 2 4799 2 7275 81 0439 -999 2500 4:8711 4043 2,9199 83,5093 5VP GR C2 -99 DEPT 1060 SP GR 5 C2 -99 DEPT i050 SP DRHO NCNL 269 C2 -99 DEPT 1040 SP DRHO NC~L 265 .~R 6 22 -99 )EPT 1030 SP -4 ~ICi'J L 260 3R 5 Z2 -99 3EPT 1020 SP ~CNb 261 ~,R 5 22 -99 )EPT 1010 SP -3 DRHO ~CNL 257 ~R 5 :2 -99 ~EPT 1000 SP -3 :)RHO ' !CNI~ 224 ~R 5 22 -99 )£PT 990 ~P -6 VERIFICATION LISTING 6.4531 DT -99 9.250O GR -99 0.0000 SFLU 3.4688 GR 5 0.0249 CALl 2 6.0000 FCNL 100 9 2266 DT -99 9]2500 GR -99 0.0000 SFLU 6.9062 GR 5 0.0435 CALl 2 2.0000 FCNL 93 3,5000 DT -99 9.2500 GR -99 0,0000 SFLU 7.9062 GR 5 0.0529 CALI 2 9,1250 FCNL 79 5.0684 DT -99 9.2500 GR -99 0.0000 SFLU 1,4688 GR 5 0.0147 CALl 2 0.3750 FCNL 77 4.9062 DT -99 9.2500 GR -99 0,0000 SFLU 1.9375 GR 5 0.0366 CALI 2 0.2500 FCNL 69 8,5625 DT ~99 9,2500 G~ 99 0.0000 SFLU 8.406j GR 6 0 0264 CALI 2 9i5703 FCNL 72 2 7227 DT -99 9 2500 GR -99 0.0000 SFLU 9.9375 GR 5 0.0103 CALl 2 2.0000 FCNb 62 5.5000 DT -99 9.2500 GR -99 0.0000 SFLU 1 2.3438 GR 4 9.2 9.2 4.1 5.8 1.7 5.5 9.2 9.2 4.2 4,9 1.7 3.5 9.2 9.2 3.5 4.8 1.7 6.0 9.2 9.2 3.6 1.7 4.5 9.2 9.2 5.5 1.7 6.8 9.2 9.2 3.8 2.7 1.7 9.2 9,2 3.9 4.3 i.7 3.5 9.2 3.1 6.3 500 500 484 4~7 031 000 500 500 793 6R7 188 000 500 500 928 047 039 938 5 O0 5O0 797 000 500 50O 350 625 750 5OO 5O0 164 656 344 0 O0 5 O0 500 595 9O6 000 5OO 50O 465 125 GR NPHI GR DTL GR ILO NPHI GR DTL GR NPHI GR ILD NPMI GR DT5 GR ILD NPHI GR iLD NPHI GR DT5 ILD NPHI GR DTL GR NPHI -999.2500 C1 5.1797 25.3906 65.1250 NRAT -999.2500 DT -999.2500 C! 4.8008 22.9980 RHOB 54.8~25 NRAT -999.2500 DT -999,2500 C! 4.3828 27.8734 RHOB 68.4297 NRAT -999.2500 DT -999,2500 4.6172 28.3728 RHOB 67.8857 NRAT -999,2500 DT -999.2500 C! 4.5469 32.3563 RHDB 61.3164 NRAT -999.2500 DY -999,2500 4 7695 30~3802 RHOB 6! 5508 NRAT -999~2500 DT -999.2500 C1 4.7969 ILM 32.9102 RHOB 51.7813 NRAT -999 2500 DT -999~2500 C1 12 6484 -999~2500 RHOB PAGE -999.2500 5 ~727 2 922 2 9023 79 ~289 -999 500 4 9062 2 4961 2 7441 79 7813 -999 2500 4 3555 2 3736 3 0660 87 2117 -999 2500 4 5859 2 3399 3 0999 83 8125 -999 2500 4 4844 2 3478 3 3665 82 8125 -999 2500 4,6445 2 3471 3 234O 81 3955 -999 2500 4 7383 2 3066 3 4043 85 2500 -999 2500 14.~469 -999. 500 LVP NC~L DEPT SP DRHO NCNb C2 DEPT SP ,{CNL ~R ~CNL 32 DEPT DRHO J4CNL DEPT 3P DRHO 4CNL )EPT 3P 3RHO {CNL '2 ~P )RHO !CNL 0lO.HO1 VEHIFICATION -999.2500 CALl -999.2500 FCNL 43.1250 DT -999.2500 GR 9800.0000 SFLO -35.4375 GR -999.2500 CALI -999.2500 FCNL 58.5000 DT -999.2500 GR 9700.0000 SFLU -33.9375 GR 999 2500 CALl 55.2129 OT -999.2500 GR q600.O000 SFLU -37.4063 GR -999.2500 CALI -999.2500 FCNL 58.8437 OT -999.2500 GR 9500.0000 SFLO -36.0000 GR 99.2500 FCNL 58.8437 DT -999.2500 GR 9~0 0000 SFLU ,7:0000 GR 99.2500 FCNL 53.1689 DT -999.2500 GR 9300.0000 SFLU 36 4063 GR 99!25oo ~999 2500 FCNL 57.5859 DT -999.2500 GR 9200.0000 SFLU -38.5000 GR -999.2500 CAbI -999.2500 FCNL 63 3457 DT -999~2500 GR LISTING -999.250~ GR -999.2500 DTb -999.2506 GR -999.2500 5.14!~ ILD 56.3203 NPHI -999.2500 GR -999.2500 DTL -999.2500 GR -999.2500 4.4854 ILD 65.1016 NPHI -999.2500 GR -999.2500 DTL -999.2500 GR -999.2506 4.1748 ILD 57.664{ NPHI -99~.2500 GR -999.2506 DTL -999.2500 GR -999.2500 4.0869 ILD 59.6953 NPHI -999.2500 GR -999.2506 DTL -999.2500 GR -999.2500 5.28!3 ILD 58.2031 NPHI -999.2500 GR -999.2500 OTb -999.2500 GR -999.2500 3.9575 58.7344 NPHI -999.2500 GR -999.2500 DTL -999,2500 GR -999.2500 3.3960 ILD 56,8047 NPHI -999.2500 GR -999,2500 DTL -999.2500 GR -999.2500 -999.2500 NRAT -999.2500 DT -999.2500 C! 6.8086 ILM -999,2500 RHOB -999,2500 NRAT -999.2500 DT -999.2500 C1 5.5195 IbM -999.2500 RHOB -999 ~500 NRAT -999:500 DT -999.2500 Ci 5.1758 IbM -999.2500 RHOB -999.2500 NRAT -999.2500 DT -999.2500 C! 4,8516 -999.2500 RHDB -999.2500 NRAT -999.2500 DT -999.2500 C1 5 941~ IbM -999!2500 RHOB -99'9 2500 NRAT -999.2500 DT -999.2500 CI 4.5781 -999.2500 RHOB -999.2500 NRAT -999.2500 DT -999,2500 C1 3.9375 -999 500 Cl PAGE -999,2500 85,1250 -999.2500 6 0547 -999 2500 -999 2500 88 0000 -999 2500 . 5,4258 999,2500 -999.2500 . 82,5625 999.2500 5 2070 -999 2500 -999 2500 82 7188 -999 2500 4 7617 -999 2500 -999 2900 82 I875 =999 2500 5 7578 -999 2500 -999 2500 85 3125 -999 2500 4 3477 -999 2500 -999 2500 85 2752 -999 2500 3 6289 -999 2500 -999 2500 88 4805 -999 2500 10 LVP 010.HO! VERIFICATION LISTING PAGE DEPT 9100.0000 SFLU SP -37,9687 GR DRhO -999.2500 CAbI NCNb -999.2500 FCNL GR 84.7500 DT C2 -999,2500 GR DEPT 9000.0000 SFLU SP -37.0313 GR DRH[) -999,2500 CAL~ NCNL -999.2500 FCNb GR 64,2500 DT C2 -999,2500 GR DEPT 8900.0000 SFbU SP -37.9687 GR 9RHO -999 2500 CAbI NCNb -999~2500 FCNL ~R 70.1680 DT 22 -999.2500 GR )EPT 8800.0000 SFLO SP -37,4688 GR )RHO -999,2500 CALl gC~L -999,2500 FCNL ~R ~4.8150 DT ~2 -999.2500 GR 3EPT 8700.0000 SFLO iSp -37 5313 GR )RHO -999~2500 CALl gCNL -999.2500 FCNL 3R 64,3750 DT 22 -999.2500 GR )EP~~ 8600,0000 SFLU 5P -35,9375 GR )RHO -999 2500 CAbI ~CNL -999!2500 FCNL 3R 59 4375 DT ~2 -999,2500 GR 8500.0000 SFLU 40 4375 GR -~99: 2500 CALl -999,2500 FCNL 60,85i6 DT -999,2500 GR DEPT 8400.0000 SFLU 5P -41..5000 GR )RHO -999'2500 CAbI ~CNL -999.2500 FCNL ~R 62,5938 DT 3,8779 ILL 55,4453 NPMI -999,2500 GR -999,25o0 OTb -999,2500 GR -999,2500 3.6631 61.4844 NPHI -999,2500 GR -999,25n0 DTL -999,2500 GR -999.2500 3.4370 IbD 63.1328 NPHI -999.2500 GR -999.2500 DTL -999.2500 GR -999.2500 3,02!0 62,3281 NPHI -999,2500 GR -999,2500 OTb -999,2500 GR -999,2500 3,2563 68.1250 NPHI -999,2500 GR -999.2500 DTL -999,2500 GR -999.2500 3,5576 ILO 59,3047 NPHI -999,2500 GR -999,2500 LTL -999,2500 GR -999,2500 3,5752 57,9766 NPHi -999,2500 -999,2500 DTL -999,2500 -999.2500 3,5054 ILD 61,0391 NPHI -999,2500 GR -999,2500 LTL -999,2500 GR 4,4805 IbM 999 2500 RHOB -'999: 2500 -999,2500 DT -999,2500 Ci 4 0977 IbM -999:2500 RHOB -999,2500 NRAT -999,2500 DT -999o2500 CI 4,2383 IbM -999,2500 RHOB -999.2500 NRAT -999,2500 DT -999,2500 CI 3,4434 IbM -999,2500 RHOB -999,2500 NRAT -999 2500 DT -999: oo 3,7480 IbM -999.2500 -999,2500 NRAT -999.2500 DY -999.2500 4,1523 IbM -999,2500 RHOB -999,2500 NRAT -999,2500 DT -999,2500 4,0820 IbM -999,2500 RHOB -999,2500 NRAT -999,2500 DT -999,2500 C! 3 2168 -999:2500 -999.2500 NRAT -999,2500 DT -999,2500 C! !641 99,2500 87,2817 -999,2500 3 8~25 -999 2500 -999 2500 89 0625 -999 2500 4 0547 -999 2500 -999 2500 87 5671 -999 2500 3 2148 -999 2500 -999 2500 9O 7813 -999 2500 3 6270 -999 2500 -999 2500 90 4063 -999 2500 3 9590 -999 2500 -999 2500 88 7188 -999 2500 3 8066 -999 2500 -999 2500 91 8750 -999 2500 3 2246 -999 2500 -999 2500 91 7813 -999 2500 LVP OiO.H()I VERIFICATION C2 -999.2500 GR DEPT 8300.0000 SFLU SP 43 8750 GR NCNL -999 2500 FCN5 ~GR 67~7500 DT C2 -999.2500 GR DEPT ~200.0000 SFLU SP -47.9062 GR )RHO -999.2500 CALl ~CNL -999.2500 FCNL ~R 57.7227 DT ~2 -999.2500 GR DEPT 8100.0000 SFLU 5P 50.0313 GR DRi{O ;99.2500 CAhi ~CNL :999.2500 FCNL ZR 59.2500 DT 122 -999.2500 GR DEPT 8000.0000 SFLU ~P -52.9062 GR )RHO 999 2500 CALl ~CNL ~ ' 999.2500 FCNL ~R 5~.5~9~ DT ~2 -999.2500 GR DEPT 7900.0000 SFLU SP -55.4375 GR DRHO -999.2500 CALI ~CNL -999.2500 FCNL ~R 48 3066 DT ~2 -999~2500 GR }EPT 7800.0000 SFSU 3P -62.9687 GR )RHO -999.2500 CA~I 'CN5 -999,2500 FCN5 ;R 50.0625 DT ~2 -999.2500 GR )EPT 7700.0000 SFbU 3P -61.9687 GR )RH[~ -999.2500 CALl iCNL -999.2500 FCNL 'R 62.4688 DT ~2 -999.2500 GR ~EPT 7600.0000 SFLU P -54.4688 GR RHO -999.2500 CALI LISTING -999,2.5()0 2.9033 53.6328 NPHI -999.2500 GR -999.2500 DTb -999.2500 GR -999.2500 3.6152 60.7031 NPHI -999.2500 GR -999.2500 DTb -999.2500 GR -999.2500 3.4727 57.6328 NPHI -999.2500 GR -999.2500 OTb -999.2500 GR -999.2500 3.643i 57.5938 NPHI -999.2500 GR -999,2500 DTL -999.2500 GR -999.2500 3.7793 I5~ 52.9062 NPHI -999.2500 GR -999.2500 DTL -999.2500 GR -999.2500 3.5454 ILO 49.5000 NPHI -999.2500 GR -999.2500 DTb -999.2500 GR -999.2500 3.6436 !bO 53.8047 NPHI -999.2500 GR -999.2500 DTL -999.25OO GR -999.2500 3.6733 ILD 50.0547 NPHI -999.2500 GR 3.5254 IbM -999.~500 RHOB -999.2500 NRAT -999.2500 DT -999.2500 Cl 4.0547 IbM -999.2500 RHOB -999.2500 NRAT -999.2500 DT -999.2500 Cl 3.5000 Ib~ -999.2500 RHOB -999.2500 MRAT -999.2500 DT -999.2500 C1 3.8496 ILM -999.2500 RHOB -999.2500 NRAT -999.2500 DT -999.2500 C2 4.3398 IbM -999.2500 RHOB -999.2500 NRAT -999.2500 DT -999.~500 C! 3.7012 IbM -999.2500 RHOB -999.2500 NRAT -999 2500 DT -999'.2500 C! 4.1055 -999.2500 RHOB -999.2500 NRAT -999 2500 DT -999~2500 C1 3.8047 IbM -999.2500 RHOB -999.2500 NRAT 3,3574 -999,2500 -999'2500 90.4375 -999.2500 3 5996 -999 2500 -999 2500 93 ~562 -999 2500 2 8437 -999.2500 -999 2500 93 2778 -999 2500 3 4609 -999 2500 -999 2500 . 93 0000 999 2500 3 5566 -999 2500 -999 2500 88 2715 -999 2500 3 5586 -999 2500 -999 2500 94 5625 -999 2500 4 0117 -999 2500 -999 2500 97 5313 -999 25O0 3 8125 : :25oo 99.2500 12 LVP C2 SP NCNb C2 DEPT SP DRHO NCNL GR C2 DEPT SP DRHO NCr~L 9R )EPT SP ,~CNL DEPT ~P ~CNL JEPT )RHO ~CNL ;R .~2 DEPT ~P DRHO -~2 DEP~ OIO.HO1 VERIFICATION -999.2500 FCNb 58.6563 DT -999.2500 GR 7500.0000 SFLO -71.1875 GR -999.2500 GR 7400.0000 SFLU -107.4375 GR -999.2500 CALl -999.2500 FCNL 31.6719 DT -999.2500 GR 7300,0000 SFLU -71.2500 GR -999.2500 CALI -999.2500 FCNL 42.2285 DT -999.2500 GR 7200.0000 SFLU -59.4063 GR -999.2500 CALI -999.2500 FCNb 47.0874 DT -999.2500 GR 7100 0000 SFLU -87~9375 GR -0.0297 CALI 2275.5000 FCND 42.8750 DT -999.2500 GR 7000.0000 SFLO -71.1250 GR -0.0094 CA5I 2329.6250 FCNb 63.2813 DT -999.2500 GR 6900.0000 SFbU -76.7500 GR -0.0073 CALf 2292.0000 FCNL 51.6602 DT 9.3393 GR 6800.0000 SFLU LISTING -999.2500 LTL -999.2500 GR -999.2500 4.767~ iLD 52.7188 NPHI -999.2500 GR :999'2500 DTL 999.2500 GR -999.2500 3.3633 ILD 32.4922 NPHI -999.2500 GR -999.2500 LTL -999.2500 GR -999.2500 3.7388 ILD 40.20~1 NPHI -999.2500 GR -999.2500 LTL -999.2500 GR -999.2500 3.3472 46.148~ NPHI -999.2500 GR -999.2500 LTL -999.2500 GR -999.2500 4.1890 45.2109 NPHI 13.1953 GR 653.2500 DTb -999.2500 GR -999.2500 4.6152 52.3750 NPHI 13.0918 GR 686.2031 LTL -999.2500 GR -999.2500 3.5562 ILL 56.6328 NPHI 15.1562 GR 571.0000 DTL -999.2500 GR 66.8873 3.2188 -999.2500 DT -999.2500 Ct 4.1406 -999.2500 RHOB -999.2500 NRAT -999.2500 DT -999.2500 C1 1.9355 IbM -999.2500 RHOB -999.2500 NRAT -999.2500 DT -999.2500 Ci 2.5703 -999.2500 RHOB -999.2500 NRAT -999.2500 DT -999.2500 C! 3.4648 999.2500 RHOB -'999.2500 NRAT -999.2500 DT -999.2500 C! 2.3301 ILM 34 3948 RHOB 48:0781 NRAT -999.2500 DT -999.2500 C! 2.9824 IbM 33.8684 RHOB 54.1360 NRAT -999.2500 DT -999.2500 C! I 969! ILM 40: 391 RHOB 47.7500 NRAT -999.2500 DT -999.2500 C! 9.4462 IbM -999 500 4 6328 -999 2500 -999 2500 93 7375 -999 2500 2 3027 -999 2500 -999 2500 93 6375 -999 2500 3,1504 -999,2500 -999 2500 98 4063 -999 2500 3 6426 -999 2500 -999 2500 101 1875 -999 2500 3 2773 2 3350 3 2392 97 8937 -999 2500 3 5859 2 4406 3 2113 95 8125 -999 2500 .0625 3'3867 ,6055 95 6875 10:1064 2.3989 13 SP NC~L C2 DEPT SP DRHO NCNL GR C2 DEPT SP DRHO NCNL ~2 SP :)RHO ~C~L 3 R ~2 )EPT SP ~CNL ~2 DEp1~ 3P )RHO 4CNL ]2 DEPT 3P DRHO ;CNL :2 )EPT 3P ICNL OiO.HO1 VERIFICATION -14.5000 GR ~99i2500 CALI 99 2500 FCNL 74 3225 DT 16.5972 GR 6700.0000 SFbU -15.2500 GR -999.2500 CALl -999.2500 FCNb 7]..7026 DT 16.1981 GR 6600.0000 SFLU =41.7500 GR -999.2500 CALI =999.2500 FCNL 54.0164 DT 16.03~7 GR 6500.0000 SFLU -16.2500 GR 999 2500 CALI 2999:2500 FC~h 72.1219 DT 15.96~6 GR 6400.0000 SFbU =27 7500 GR -99912500 CAbI -999 2500 FCNL 66 8202 DT 16.0089 GR 6~00 0000 SFbO 925ooo -999.2500 CALI -999.2500 FCNL 62 4884 DT 15:8292 GR 6200.0000 SFBU ~44 2500 GR - 9912500 CAUI -999.2500 FCNL 54.9004 DT 15.7027 GR 6100 0000 SFLU -39i7500 GR -999 2500 CALI -999 2500 FCNL 63.3164 DT 15.4~13 GR LISTING 73.6735 NP~I -999.2500 GR -999.2500 -999.2500 GR 79.1475 2.9903 ILD 70.4745 NPHI -999.2500 GR =999.2500 DT5 -999.2500 GR 79.1250 1.7533 IbD 46.0820 NPHI -999.2500 GR =999.2500 DTL -999.2500 GR 56.7648 2.8~22 ILD 68.3751 NPHI -999.2500 GR -999.2500 DTb -999.2500 GR 70.0215 3.1025 63.6766 NPHI -999.2500 -999.2500 OTb -999.2500 GR 67.2715 2.6775 ILD 63'2767 NPHI -999.2500 GR =999.2500 DTb -999.2500 GR 62.5078 2.6531 ILD 51.6803 NPHI -999.2500 GR =999.2500 DTL -999.2500 GM 51.4111 2.5808 62 5769 NPHI -999:2500 GR -999.2500 DTL -999.2500 GR 62.4880 -999.2500 -999.2500 NRAT -999.2500 DT -999.2500 Ci 2.6575 IbM :9999 99:2500 DI' -999.25OO C1 1.2042 IbM -999.2500 RHOB -999.2500 NRAT =999.2500 PT -999.2500 CI 2.5379 -999.2500 RHOB -999.2500 NRAT -999.2500 DT -999.2500 C1 2.4688 -999.2500 RHOB -999.2500 NRAT -999 2500 DT c 9978 IbM '999 2500 NRAT -999:2500 DT -999.2500 C1 1.9256 IbM =999.2500 RHOB -999.2500 NRAT -999.2500 DT -999.2500 2.1703 IbM =999.2500 RHOB -999.2500 NRAT -999'2500 DT -999.2500 C! PAGE -999.2500 -999.2500 97.2505 16.2488 2 4889 -999 2500 =999 2500 102 8088 16 4555 ! 3804 -999 2500 -999 2500 i03 6500 15 8035 2 4889 -999 2500 -999 2500 102 4893 16 0766 2 5586 i999 2500 -999 2500 96 267! !5 8470 2 ~087 -999 2500 -999 2500 99 2261 15 6174 2 0893 -999 2500 -999 2500 98 0500 15 8470 2,2285 -99912500 -999.2500 97.1934 15~8470 14 DEPT SP DRHO NCNL GR C2 D£PT SP DRHO NCNL GR C2 QEPT SP )RHO ~CNI. J )EPT SP .~CNL DEPT ~P )RHO ~CNL "2 DEPT ~P DRHO 4CNL )EPT DRHO 4CNL 3EPT ~P )RHO OIO.HO1 VERIFICATION 6000.0000 -38,2500 GR -999.2500 CA -999.2500 FC 69,0508 15.8511 GR 5900.0000 SF -40.2500 GR -999.2500 CA -999,2500 FC 64.9197 DT 15.9616 GR 5800.0000 SF -41 7500 GR -999:2500 CA -999,2500 FC 64.5430 DT 16.1035 GR 5700.0000 SF -48.5000 GR -999.2500 CA -999,2500 FC 56,3694 D~ ~5,7251 GR 5600,0000 SF -63 2500 GR -999~2500 CA -999,2500 FC 48,7~48 DT 16.5766 GR 55OO,O0O0 SF '71 7500 GR -999i2500 CA -999 2500 FC 35,91~8 DT 16,9952 GR 5400,0000 SF -39,5000 GR -999 2500 CA -999:2500 FC 70.92~5 DT 15.9616 GR LU NL LU I.I LU bi LU N5 LU N L LU NL 5300,0000 SFbU -45 5000 GR -999~2500 CASI -999,2500 FCNL 2.3976 65,6759 NPHI -999.2500 GR -999,2500 DT5 -999,2500 GR 59.3549 2.8296 I~D 56,3788 NPMI -999.2500 GR -999.2500 DTL -999,2500 GR 58.9885 2.4197 60.2776 NPHI -999.2500 GR -999.2500 DTL -999,2500 GR 59.1885 2,2480 I~D 59.8777 NPHi -999.2500 GR -999.2500 DTL -999.2500 GR 58.5886 1,8190 46,8817 NPHI -999,2500 GR -999,2500 DTL -999.2500 GR 46,0906 1.4856 35,3853 NP~I -999.2500 GR -999.2500 -999.2500 GR 34.9375 2,0129 66.4757 NPHI -999,2500 GR -999,2500 DT5 -999.2500 66,9873 2,5808 57,2785 NPHI -999.2500 GR -999,2500 DT5 1.8732 IbM -999.2500 RHOB -999.2500 NRAT -999,2500 DT -999.2500 Ci 2,3i48 lLM -999,2500 RHOB -999,2500 NRAT -999,~500 DT -999.2500 C1 1.9978 -999.2500 RHOB -999.2500 NRAT -999.2500 DT -999.2500 1 6167 -999:2500 RHOB -999,2500 NRAT -999,2500 DT -999.2500 Cl 1,2609 -999,2500 RHOB -999,2500 NRAT -999,2500 DT -999.2500 C1 0.7742 I5M -999,2500 RHOB -999,2500 NRAT -999.2500 DT -999,2500 C1 1.9614 IbM -999.2500 RHOB -999,2500 NRAT -999.2500 DT -999.2500 C1 1,9795 IbM -999.2500 RHOB -999.2500 NRAT -999,2500 DT PAGE ! 9953 -999 2500 -999 2500 102 6500 15 9618 2.3989 -999.2500 -999.2500 t00.2500 16.0766 2.1087 -999.2500 -99912500 102.0500 16,3063 ! 8030 -999 2500 -999 2500 102 4500 16 1914 I 4454 -999 2500 -999 2500 1i0 O50O i7 0525 I 0666 -999 2500 -ggg 2500 I17 45OO 17 6180 9589 -99 2500 -999 2500 110 8500 16 3637 2 1087 -999 2500 -999 2500 105 8500 15 LYP O10.HO/ VERIFICATION LISTING GR 61.9443 DT C2 15.8197 GR -999.2500 GR 57.3888 DEPT 5200.0000 SFLU SP -53.5000 GR DRHO -999.2500 CALf NCNL -999 2500 FCNL GR 57~6504 DT C2 15.7724 GR 1,9944 57.6784 NPHI -999.2500 GR -999.2500 DTL -999.2500 GR 52.88Q5 DEPT 5100.0000 SFLU SP -70.2500 GR DRHO -999.2500 CALl NCnb -999.2500 FCNL GR 35 6108 DT C2 17:6084 GR 1.3929 36.0850 NPHI -999.2500 -999.2500 DTL -999.2500 GR 37.1191 DEPT 5~00.0000 SFLU SP 69.2500 GR DRHO -999.2500 CALI NCNL -999.2500 FCNL ~R 32.5098 DT 22 lq,7931 GR 2.3109 31.586~ NPHI -999.2500 GR -999.2500 DTL -999.2500 GR 30.9930 )EPT 4900.0000 SFLU iSP -64.0000 GR 3RHO -999.2500 CALl ~CNL -999.2500 FCNL ~R 38.4785 DT 22 18.0902 GR 36.5648 36.6849 NPHI -999.2500 GR -999.2500 DTL -999.2500 GR 37.3919 )EPT 4800.0000 SFLU Sp -68.2500 GR 3RHO -999.2500 CALI ~CNL -999.2500 FCNL ~R 39,0219 DT ~2 18.4687 GR -1.1066 32.2862 NPHI -999.2500 GR -999,2500 DTL -999.2500 GR 39.6916 )EPT 4!00 0000 SFLU Sp -~5:2500 GR )RHO -999.2500 CALl ~CN& -999.2500 FCNL ~R 55.9169 DT ~2 16,t508 GR 2.4421 52.8799 NPHI -999.2500 GR -999.2500 DTL -999.2500 GR 60.5883 )EPT 4600.0000 SFLU ~p 42.2500 GR )RH[] -~99.2500 CALl ~CNL -999,2500 FCNL ~R 74.1064 DT ~2 15.8143 GR 2.2480 ILD 69.4748 NPHI -999.2500 GR -999.2500 DTL -999.2500 GR 73.]348 JEPT 4500.0000 SFLU ~p -48.2500 GR 2.1~66 ILD 60.2776 NPHI -999.2500 C1 1.3953 ILM -999.2500 RHOB -999.2500 NRAT -999.2500 DT -999.2500 Ci 0.5874 ILM -999.2500 RHOB -999.2500 NRAT -999.~500 DT -999.2500 C1 1.1085 ILM -999.2500 RHOB -999.2500 NRAT -999.2500 DT -999.~500 C1 3.6339 I5M -999.2500 RHOB -999.2500 NRAT -999.2500 DT -999.2500 C1 0.7531 -999.2500 -999.2500 NRAT -999.2500 DT -999.2500 C! 2.0349 -999.2500 -999.2500 NRAT -999'2500 DT -999.2500 C1 9~ 4917 -9 :2500 RHDB -999.2500 NRAT -999.2500 DT -999.2500 C~ 1.7084 -999.2500 RHO~ PAGE 16.1914 l .5704 -999' 500 107 78373 15 47O 0 8710 -999 2500 -999 2500 1~7 0840 16 8003 i 5417 -999 2500 -999 2500 104 6500 20 8988 5.0584 -999,2500 -999 2500 16.7081 0 9290 -999 2500 -999 2500 151 8000 18 6025 2 0702 -999 2500 -999 2500 118 2617 16 0766 . 1,9953 999,2500 -999 2500 122 2959 15 6174 500 I6 LVP DRH~ NC~L C2 DEPT SP DRM[3 NCNb GR C2 DEPT SP DRHO NCNb C2 QEPT SP ~R ~2 SP gCNL ~R )EPT )RHO 22 ~2 )EPT 3P 'R VERIFICATION -999,2500 CALl -999.2500 FCNL 59,6582 DT 16.3873 GR 4400,0000 SFLU -43.0000 GR -999,2500 CALI -999.2500 FCNL 63.3192 DT 15.4736 GR 4300,0000 SFLU -54.2500 GR -999.2500 CALX -999.2500 FCNb 49.3149 DT 15,7724 GR 4200,0000 SFLU -bl.5000 GR :999.2500 CALl 999.2500 FCN~ 38,8390 DT 18.2794 GR 4100,0000 SFLU -31,0000 GR -999,2500 CALI -999,2500 FCNL 64,2271 DT 16,0562 GR 4000,0000 SFLU -26,0000 GR -999,2500 CALX -999,2500 FCNb 53,57~3 DT 15,8197 GR 39oo oooo SFbu -29]0000 GR -999,2500 CALI -999,2500 FCNL 42,5129 DT 15,9558 GR 3800,0000 SFLU -29 5000 GR -999~2500 CALI -999 2500 FCNL 53~3162 DT 15,9466 GR -999.2500 GR -999.2500 DTL -999,2500 GR 56.5889 2,3323 ILD 59,2779 NPMI -999.2500 GR -999,2500 DTL -999,2500 GR 55,8945 2,1667 55.6790 NPHI -999.2500 GR -999.2500 DTL -999.2500 GR 5~,9896 1,4993 37,6845 NPHI -999,2500 GR -999,2500 DTL -999,2500 GR 34.1925 2,2274 ILD 63,1767 NPHI -999,2500 GR -999,2500 DTL -999,2500 GR 59.0885 1.994~ IbD 56,0789 NPHI -999.2500 GR -999,2500 DTL -999,2500 GR 58.7383 1,1911 ILD 41,0835 NPHI -999,2500 GR -999,2500 DTL -999,2500 GR 37,5479 2,1272 52,4800 NPHi -999,2500 GR -999,2500 DTL -999,2500 GR 53,3965 -999.2500 NRA~ -999,2500 DT -999,2500 C1 2,0727 IbM -999,2500 RHOB -999,2500 NRAT -999,2500 DT -999.2500 CX ~,4212 -999.2500 RHOB -999,2500 NRAT -999.2500 DT -999,2500 0.7813 IbM -999,2500 RHOB -999,2500 NRAT 999 2500 DT '99922500 Cl 2,0349 IbM -999,2500 RHOB -999,2500 NRAT -999,2500 DT -999.2500 C! 1,5439 -999,2500 RHOB -999.2500 -999.2500 DT -999,2500 C1 0.6806 IbM -999,2500 RHOB -999,2500 NRAT -999.2500 DT -999,2500 Ci 1,3573 32bM -999,2500 RHOB -999,2500 NRAT -.999,2500 DT 999,2500 CI PAGE 17 -999.2500 10i.2500 16.1914 i479 -99 2500 -999.2500 113 4297 15 6748 1.6293 -999~2500 -999.2500 115,4541 16'0192 10280 -9992500 -9992500 124 6500 18 4877 . 1. .999,~770500 -999.2500 110,9492 16,3063 1.7219 -999,2500 -999.2500 116.3438 16,3063 0 8472 -999 2500 -999 2500 116 2000 15 9478 . 15560 9992500 -9992500 122037i 157896 LV? OlO.H01 VERIFICATION DEPT 3700.0000 SFL(J 5P -30.2500 GR DRi{(] -999.2500 CALl NCnb -999.2500 FCNL GR 54.1196 DT C2 16.3251 GR DEPT 3600.0000 SFLU SP -31.0000 GR DRHO -999.2500 CALf NCNL -999.2500 FCNL GR 34.9951 DT C2 18.4687 GR DEPT 3500.0000 SFDtJ SP -38.2500 GR DRHO -999.2500 CALX NCNL -999.2500 FCNL GR 29.2089 DT C2 18.1848 GR DEPT 3400.0000 SFLU iSP -33.0000 GR DRHO 999 2500 CALI NCnb :999~2500 FCNL GR 45.3965 DT 22 16.3873 GR )EPT 3300.0000 SFLU !$P -11.7500 GR )RHO -999.2500 CALl ~CNL -999.2500 FCNb ~R 67.6404 DT 22 15.6305 GR )EPT 3200.0000 SFLU SP 14.7500 GR )RHO -;99.2500 CALI OCNL -999 2500 FCNL SR 57:3174 DT 22 15.8280 GR )EPT 3~00!0000 SFLU 5P 15 25O0 GR )RHO -999 2500 CALl ~CNL -999.2500 FCNL ~R 68.4619 DT 22 15.8670 GR )EPT 3000.0000 SFLU 5P -19.7500 GR ')RMO -999.2500 CALI 'CNL -999.2500 FCNL ~R 53.1161 DT ~ISTING 2.2897 47.2816 NPHI -999.2500 GR -999.2500 LTL -999.2500 GR 52.619[ t.4188 ILL 38.6~42 NPSI -999.2500 -999.2500 -999.2500 GR 39.4~!6 1.2821 ILL 31.0866 NPHI -999.2500 GR -999.2500 LTL -999.2500 GR 30.3535 1.9401 46.0820 NPHI -999.2500 GR -999.2500 -999.2500 GR 4~.7913 2.3109 60.2776 NPHI -999.2500 -999.2500 DTL -999.2500 63.7878 1.7055 64.1764 NPHI -999.2500 GR -999.2500 -999.2500 GR 60.1~31 1.2132 63.6766 NPHI -999.2500 GR -999,2500 DTL -999.2500 GR 68.5~70 1.3425 45.1813 NPHI -999.2500 GR -999.2500 -999.2500 GR ~.3953 ILM -999.2500 RHOB -999.2500 NRAT -999.2500 DT -999.2500 Ci 0.6620 ILM -999.2500 RH£}B -999.2500 NRAT -999.2500 DT -999.2500 C~ 0.6207 ILM -999.2500 RHOB -999.2500 NRAT -999.2500 DT -999.2500 C! 0.9306 ILM -999.2500 RHOB -999.2500 NRAT -999.2500 DT -999.2500 Cl 1.8560 ILM -999.2500 RHOB -999 2500 NRAT -999:2500 DT -999.2500 C1 !.5872 -999.2500 RHOB -999.2500 NRAT -999.2500 DT -999.2500 C! 1.~607 ISM -999.2500 RHOB -999.2500 NRAT -999.2500 DT -999.2500 C! 1.0684 IbM -999.2500 RHOB -999.2500 NRAT -999.2500 DT -999.2500 C! PAGE ! 5849 -999 2500 -999 2500 113 6500 15 9800 0.9036 -999,2500 -999~2500 136,0500 18'7747 -99~ 7943 2500 -999 2500 135 9580 17 4602 t,1588 -999 2500 -999 2500 133 4500 15 3878 1 6444 -999 2500 -999 2500 133 4500 15 8778 I 5417 -999 2500 -999 2500 139 2100 15 8470 1272 -99:2500 -999.2500 129.8828 15,6174 1,2023 -999 2500 -999 2500 128 8000 ~5 6476 LYP O~O,HO! VERIFICATION LISTING C2 16.021~ GR 46.4648 DEPT 2900,0000 SFLO SP -27 5000 GR DRHO -999~2500 CALI NCNb -999.2500 FCND GR 43.1131 DT C2 15.8670 GR 1,9944 ILO 46,7818 NPHI -999,2500 GR -999,2500 LTL -999,2500 GR 42,991! DEPT 2800,0000 SP 21 0000 - 9 . 5oo GR 57.1173 DT C2 16.1035 GR 1,9944 53.2798 NPHI -999,2500 GR -999,2500 LTL -999,2500 GR 55,98q0 DEPT 2700,0000 SFLU SP -31.2500 GR :DRHO -999 2500 CALl NCNL -999:2500 FCNL GR 35,4107 DT ~C2 15,7393 GR 1,3801 ILO 34,8854 NPHI -999,2500 GR -999,2500 DTL -999,2500 GR 38,0508 !DEPT 2600,0000 SFLU !SP -34,7500 GR iDRHO 999,2500 CALl NCNL :999,2500 FCNL 13R 28.0085 DT 72 17,0023 GR 0,9463 29,9869 NPHI -999,2500 GR -999.2500 DTL -999,2500 GR 29,5932 i)EPT 2500,0000 SFLU SP -31,5000 GR )RHO -999 2500 CALl ~CNL -999:2500 FCNL ~R 41,3828 DT 72 17,0969 GR 1,8700 37,2847 NPHI -999,2500 GR -999,2500 DT5 -999,2500 GR 30,9930 )EPT 2400,0000 SFLU ~P -13,2500 GR )RHO 999 2500 CALl ~CNL :999:2500 FCNh ;R 60,4746 DT ~2 16,2454 GR 1,9581 I~D 65,276~ NPHI -999,2500 GR -999,250u DT5 -999,2500 GR 6~,5870 )EPT ~00.0000 SFLU ~P 30,0000 GR DRHO 999,2500 CALI ~CNL -999,2500 FCNb ;R 34,5137 DT ~2 17,9365 GR 2,3976 ILL 33,5858 NPHI -999,2500 GR -999,2500 LTL -999,2500 GR 37,7671 )EPT 2200,0000 SFLU 5P -19,5000 GR 3RHO -999.2500 CALl !.9581 ILD 53.1798 NPHI -999,2500 GR 1,4212 -999.2500 RHOB -999,2500 NRAT -999,2500 DT -999,2500 Cl 1.3203 IbM -999,~500 RHOB -999, 500 NRAT -999,2500 DT -999.2500 C1 0,8646 -999,2500 RHOB -999,2500 NRAT -999,2500 DT -999,2500 CI 0.5407 ILM -999,2500 RH~3B -999,2500 NRAT -999 2500 DT 0 9745 ISM :9999i2500 RHOB 99 2500 NRAT -999,2500 DT -999.2500 C1 t.4881 ILN '999,2500 RHOB -999,2500 NRAT -999.2500 DT -999,2500 Cl 99~,3825 ISM - . 2500 RHOB ~999,2500 NRAI 999,2500 DT -999,2500 CX 1.2266 -999,2500 RHOB -999,2500 NRAT PAGE -99~ 4859 2500 -999 2500 129 2500 16 0766 1 406i -999 2500 -999 2500 131 6500 15 8470 . 0,9376 .999,2500 -999,2500 143,6500 15,8470 0 ,6982 -999:2500 -999,2500 ~36,0500 16,5359 1 2360 -999 2500 -999 2500 143 8125 16 4211 i 5136 -999 2500 -999 2500 142 6543 16 4211 1 7539 -999 2500 -999 2500 I16 2500 17 5261 1,4322 -gg9,2500 -999,2500 19 LVP OlO,HOl VERIFICATION NCNL -999.2500 FCNL GR 56.2170 DT C2 16,0089 GR DEPT 2100,0000 SFLU SP -23,0000 GR DRHO -999.2500 CALl NCNL -999.2500 FCNL GR 25.9033 DT C2 17,0436 GR DEPT 2000,0000 SP -22,9451 GR DRHO -999,2500 CALl NCNL -999,2500 FCNL 3R 31.7790 DT C2 17,3329 GR 9EPT 1~00,0000 SFLU iSP 14,9651 GR )RHO -999,2500 CALf ~CNL -999,2500 FCNL ~R %5,3722 DT ~2 17,5562 GR )EPT 1800.0000 SFLU 5P -24,9402 GR DRHO -999,2500 CALf ~CNL -999,2500 FCNL gR 34,9142 DT 22 18.1005 GR DEPT 1700,0000 SFLU SP -19.7032 GR )RHO -999,2500 CALI JCN5 -999,2500 FCNL ~R 42,4768 DT ~2 17,8413 GR ]EPT 1600,0000 SFLU ~P -24 4414 GR )RHO -999i2500 CALI 'CNL -999 2500 FCNL 'R 38 5712 DT ~2 18.41i3 GR 'fP%' 1500,0000 SFLU 'P 23,6933 GR RHO -~99,2500 CaLl Ct~L -999,2500 FCN~ R 46,6877 DT 2 18.0313 GR EPT 1400.0000 SFLU LiS~'ING -999.25oo DTL -999.2500 GR 49,7900 99999,0000 23,18~0 NPSi -999,2500 GR -999,2500 DTb 156,483~ GR ~9,294~ 1,802~ ILD 34,3701 NPHX -999,2500 GR -999,2500 DT5 i47,75~ GR -999,2500 ~,$028 ILD 48,0484 NPHI -999.2500 GR -999,2500 DTL 151.2383 GR -999,2500 1,4321 33,6697 NPHI -999,2500 GR -999,2500 DTb ~55,3848 GR -999,2500 1,54!6 ILD 43.4889 NPHX -999,2500 GR -999,2500 165,0098 GR -999,25~0 ~,5558 ILD 41.7353 NPHi -999,250n GR -999,2500 DTL 161,1646 GR -999,2500 1,72!7 49,18~2 NPHI -999,2500 GR -999,2500 DTL 157,9189 GR -999,2500 i.6442 IbD -999,2500 DT -999,2500 C~ 99999.0000 -999,2500 RHOB -999,2500 NRAT -999,2500 DT 27,3147 Cl ~,5275 -999,2500 RHOB -999,2500 NRAT -999,2500 DT 32,9888 C! 1.5135 -999,2500 R~OB -999,2500 NRAT -999,2500 DT 44,7404 CI 1.0765 -999 2500 RHOB -999:2500 NRAT -999.2500 DT 38.4042 C1 1 4190 -999:2500 RHOB -999,2500 NRAT -999,2500 DT 43,8634 1.2705 -999,2500 RHO~ -999 2500 NRAT -999i2500 39 I102 C1 500 RHOB -999,2500 NRAT -999.2500 DT 54,8257 Cl 1,5275 PAGE 145.7006 15.6174 0 9817 -999 2500 -999 ~500 156 809 17 4260 1,5417 -999 2500 -999 2500 141 9844 17 3588 . I 4454 999 2500 -999 2500 148 9059 17 3297 i 1066 .-999 2500 999 2500 151 0660 17 7726 -99~ 3932 2500 -999 2500 162 7565 17 2498 I 2589 .-999 2500 999 2500 154 .0061 17 7997 . 1 3804 999.2500 -999 2500 160 4064 17 3498 1,3677 2O bVP SP DRHO N C N i~ GR C2 DEPT SP DRHU NCNb GR C2 DEPT SP DRHO NCNb C2 DEPT SP DRHO NCNb C2 DEPT SP 3RHO ~CNL 22 SP ~ICNL 22 )SPT DRHO ~C~'~L 3EPT ~P 3RHO ]CNL ;R 0 i 0. H 01 · VERIFICATION -25.1895 GR -999 2500 ~AB~ - u 25oo CNh 51,8b18 D""~ 17.7937 GR 1300.0000 SFLU -32 4214 GR -999~2500 CALI -999.2500 FCNL 25.9676 DT 21.0338 GR 1200,0000 SFbU -34.1671 GR '999,2500 CALl -999,2500 FCNL 35.6377 DT 19.1573 GR 1100 -27 -999 -999 2O 0000 SFLU :9327 GR .2500 CALI .2500 FCND .9325 DT .3461 GR 1000.0000 SFbU -36.1621 GR -999 2500 CALl -999i2500 FCNL 29 5241 22.6718 GR 900.0000 SFLU -39.4040 GR -999,2500 CALI -999.2500 FCNL 25.1139 DT 25,1098 GR 800.0000 -30,9252 GR -999.2500 CAbI -999,2500 FCNL 24,3247 DT 34.8012 GR 700.0000 SFLU -39 6534 GR -999:2500 CALi -999,2500 FCNL 30,0250 DT 25,7987 GR LISTING 49 -999 -999 162 -999 11 22 -999 -999 142 -999 2 36 -999 -999 169 -999 2 45 999 162 -999 3O -999 -999 168 -999 14 20 -999 -999 165 -999 18 24 -999 -999 -999 8 34 -999 -999 172 -999 .2500 .2500 .8293 .250o ,797& .3578 ,250U .2500 ,39~0 .2500 ,0134 .4745 ,2500 ,2500 ,996b ,2500 .2695 ,3302 2500 :2500 ,8783 ,2500 ,9188 ,5998 ,2500 .2500 ,9199 ,250o .9587 ,7796 ,2500 .2500 .0625 ,2500 ,5245 .1114 .2500 .2500 ,3218 ,2500 ,9497 ,0194 .2500 .250o .973i .2500 GR DTL GR ILD NPHI GR DTL GR NPHi GR DTb GR ILD NPHI GR DTL GR ILD NPHI GR DTL GR NPHi GR DTL GR NPHI GR OTb GR NPHI DTL GR -999.2500 RHOB -999.2500 NRAT -999,2500 DT 55.2677 Ci 6,3081 XLM -999.2500 RHOB -999.2500 HRAT -999.2500 DT 25,7975 C1 1.6903 IbM -999,2500 RHOB -999,2500 NRAT -999,2500 DT 37.8999 C1 3. 1618 -999.2500 RHOB .-999,2500 NRAT 999,2500 DT 49.4751 Cl 3,1328 IbM -999,2500 -999.2500 NRAT -999.2500 DT 30.t824 C! 21.4699 IbM -999.2500 RHOB -999,2500 NRAT -999.2500 DT 23.605~ C1 2.3,9787 -999,2500 RHOB -999.2500 NRAT -999,2500 DT 24,7451 11.7995 -999.2500 RHDB -999,2500 NRAT -999.2500 DT 29.9183 PAGE 21 -.999.2500 999.2500 145 0558 1724498 5 5976 -999 2500 -999 2500 107 9541 21 3242 2500 999,2500 168,4117 I8;7097 2.3121 -99'9,2500 -999.2500 136,7054 19,7638 3 3420 -999 2500 -999 2500 155 3062 22 3037 8643 99,2500 99,8539 24,3987 9 4624 -999 2500 -999 2500 200 5581 29 8478 5 2966 -999 2500 -999 2500 158 6992 24 8236 'l bVP VERIFICATIO~ LISTING PAGE 22 DEPT SP DRHO NCNB GR C2 6 00.0000 SFLU 45,8878 GR 99,2500 CALI 99.2500 FCNL 27,7449 DT 31.5085 GR DEPT NCNb GR C2 5 00,0000 SFLU 37,1596 GR 99.2500 CALI 99 2500 FCNL 6423973 DT IS.2154 GR DEPT SP DRHO NCNb GR C2 O0 0000 SFLU 4521397 GR 99 2500 CALI 9922500 FCNL 4!,4258 DT 27.1336 GR DEPT 300 SP -53 DRHO -999 NCNb -999 GR 34 C2 29 ,0000 SFLU ,11~7 GR .25 0 CALl .2500 FCNL 1468 DT DEPT 200 SP -5~ DRHO -999 NCNb -999 GR 35 C2 22 .0000 SFbO 8653 GR .2500 CAB~ .2500 FCNL .3198 DT .1169 GR DEPT SP -13 DRHO -999 NCNb -999 GR 23 C2 -999 0000 SFbB 7182 GR 2500 CALl 2500 FCNb 7444 DT 2500 GR DEPT 49.5000 SFLU DRHO ~99,2500 CALl NCNB i 99,2500 FCNb GR 17~7473 DT C2 -999,2500 GR SERVICE NAME 3.0754, ibD 29,4600 NPHI -999.25o0 GR -999.2500 DTL 2,7169 GR -999,2500 1.0375 65.7599 -999,25o0 GR -999,2500 DTL 173.43~ GR -999,2500 1.6142 iLD 2500 GR -999,2500 DTL 0.2190 GR -999,250O 3.4347 35.2469 NPHI -999.2500 GR -999,2500 DTL 198.3975 GR -999.2500 1.9586 35,7730 NPHI -999.2500 GR -999,25O0 6.3072 ILD 23.5854 NPHI -999.2500 GR -999,2500 DTL 61.2662 GR -999.2500 2245.5874 ILD 4.82~6 NPHI -999.2500 GR -999,2500 DTL -999.2500 GR -999,25O0 2,99i8 -999.2500 RH~B -999.2500 NRAT -999 ! C! -999',2500 RMOB 66.72.76 1.6443 IbM -999,2500 RHOB -999,2500 NRAT -999.2500 DT 36.8012 C! 4.7853 IbM 999,2500 RHOB ~999.2500 NRAT -999.2500 DT 33.4650 2,0700 -999,2500 RMOB -999,2500 NRAT -999,2500 DT 31.9364 327'7,5845 -999,2500 RHOB -999,2500 NRAT -999.2500 DT 23,7804 CI 8,~154 Ib~ -999, 500 RHOB -999.2500 NRAT -999.2500 DT -999.2500 C1 2 7542 -999 2500 -999 2500 186 8575 BO 4819 I 0568 -999 2500 -999 2500 169 5898 18 0122 1 6444 -999 2500 -999 2500 147 6059 26 5758 3 1915 -999 2500 -999 2500 I40 8056 26 2134 I 9953 -999 2500 -999 2500 153 2561 21 9491 99999 0000 -999 2500 =999 2500 57 502~ =999 2500 99999,0000 -999,2500 -999,2500 149.8560 -999.2500 DVP OIO.HO1 YERIFICATIOr~ LISTING PAGE 23 DATE : MAXIMU~ LENGTH : 1024 NEXT ~'ILE NAmE : ** TAP~, TRAILER ** SERVICE NASE :SER¥IC DATE :82104/28 ORIGI~ :1o70 TAPE ~A~E :63004 CONTINUATION ~ :0! NEXT TAPE NA~E : COM~ENI$ :TAPE COMMENTS ~ REEL TRAILER *~ SERVICE NAME :SERVIC DATE :~2/04f28 DRIGiN : .~EEL .r,~A{,4E :REEL ID ~ONTIN[iATiON # :01 ,~EXT REEL NAME : .O~,'~E~TS :REEL CSMMENTS ********** E(]F ********** EOF F? DEG 13900.0 * 29.0 13910.0 * 29.0 13920.0 * 29.1 13930,0 * 29'I 13940,0 * 29.1 13950.0* 29'4 13960.0 * 29~6 13970.0 * 29.4 13980 0 * 29.4 1,4000 14010 0 40204030 § 4040 0 4050 0 14060 14070 § 4080 0 40'90 0 4100 0 4110 0 1 4130 4140 41'50 14160 ~ 14170 14180 0 14190 0 14200 t4210 ~ 14220 ~ 142~0 14240~ 142501~ 14260,~ 14270. 14280~0 ~ 27, 14290.0 * 27' 14294.0 * 27. 28 28 28 28 ~8 * 28 * 27 * ~7 * ~7 30
