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181-150
1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): Beaver Creek / GL: 0' BF: 0' Total Depth: 1803' FNL, 1877' FEL, Sec 34, T7N, R10W, SM, AK 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 30"58' 20"502' 13-3/8" N-80 4,022' 9-5/8"N80 C75 P110 12,228' 7" P-110 14,674' 5" N-80 15,571' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, N/A 3388 sx cl G TUBING RECORD 652 sx cl G 15,889' 14,980' 2400 sx cl G N/A 11,326' 14,387' N/A N/A 450 sx cl G STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG WAG Gas 12/8/23 181-150 / 322-591 / 323-455Hilcorp Alaska, LLC 50-133-20346-00-00 Beaver Creek Unit (BCU) 06 FEDA028083 1178' FNL, 1497' FWL, Sec 34, T7N, R10W, SM, AK N/A 11/19/81 15,928' MD/15,610' TVD 0' MD / 0' TVD 0 317311.81 2434014.43 N/A 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 BC Oil, Beluga + Tyonek +Sterling Gas CASING WT. PER FT.GRADE 04/15/82 CEMENTING RECORD N/A N/A SETTING DEPTH TVD 2433360.70 TOP HOLE SIZE AMOUNT PULLED N/A 319208.17 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A BOTTOM SIZE DEPTH SET (MD) N/A PACKER SET (MD/TVD) 18 11,446' 14,681' 32 N/A 0' 47 & 53.5 0' 0' 502'0' 0' 68 & 72 12,410' 0' 0' 58' 0'4,022' Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 11:22 am, Jan 17, 2024 Abandoned 12/8/2023 JSB RBDMS JSB 020124 xGDSR-2/13/24 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 31. List of Attachments: Operations Summary, Schematic, Photos documenting casing cut-off/cement top/welded plate and elevation survey. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Chad Helgeson, Operations Engineer Digital Signature with Date:Contact Email:chelgeson@hilcorp.com Contact Phone:907-777-8405 Authorized General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Authorized Name and INSTRUCTIONS Noel Nocas, Operations Manager 907-564-5278 Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation Name at TD: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). No NoSidewall Cores: Yes No Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.01.16 11:54:51 - 09'00' Noel Nocas (4361) Updated by DMA 01-05-24 SCHEMATIC Beaver Creek Unit Well: BCU-06 API: 50-133-20346-00-00 PTD: 181-150 PBTD = 4,996’ MD / 4,996’ TVD TD = 15,928’ MD / 15,610’ TVD RKB to GL = 21.0’ Size Type Wt Grade ID Top Btm 30” Conductor Surf 20” 133# K-55 18.542” Surf 502’ 13-3/8” Surf Csg 68# K-55 12.415” Surf 3,025’ 13-3/8" Surf Csg 72# N-80 12.347” 3,025’ 4,022’ 9-5/8” Production Csg 47# N-80 8.681” Surf 5,755’ 9-5/8” Production Csg various various various 5,755’ 12,410’ 7” Liner 32# P-110 11,446’ 14,980’ 5" Liner 18# N-80 14,681’ 15,880’ 220” 13-3/8” 5” JEWELRY DETAIL No. Depth ID Item 1 102’ Pulled 9-5/8” casing from 102.18’. We filled the 13-3/8” and 9- 5/8” casing from 175’. 2 180’ 9-5/8” CIBP @ 180’ w punches at 172-178’ (9/22/23) 3 4,125’ 9-5/8” CIBP with cement to 3,900’ MD (9/21/23) 4 5,050’ CIBP w/ 35' of Cmt dump bailed on top. EL tag on 8/4/18 at 4,996' MD 5 5,983’ Cement Retainer w/ 6 bbls Cement on top of Retainer (Est TOC @ 5,898'); w/ 30 bbls Cement below Retainer 6 6,200’ Cement Retainer (not set) 7 6,200’ CIBP 8 6,981’ 9-5/8” Stage cementing collar 9 10,400’ Cement Retainer 2/21/1996 10 11,200’ Cement Retainer 1/17/1996 11 11,350’ Cement Plug 10’ 12 14,647’ CIBP w/ 220’ Cement 6/1982 13 15,280’ CIPB w/ 22’ Sand & Cement 5/1982 OPEN HOLE / CEMENT DETAIL 20" 26” Hole: 1500sxs of class G pumped with good returns (but none to surface). 2-3/8" pipe tagged cement in 30" x 20" annulus at 42’. Cemented back to surface 2-3/8" top job. 13-3/8” 17-1/2” hole: Cemented with 2000sxs of 14.2# class G followed by 400sxs of 15.8# class G neat. Approximately 400sxs excess cement returns to surface. 9-5/8" 12-1/4" hole: cemented with 1588sxs cement out shoe at 12,410' MD. Stage #2 from collar at 6,981’: Pumped 800sxs of 14.3# class G lead followed by 1000sxs 15.9# class G tail. No cement to surface. 3/16/03 USIT shows good cement up to 2750' MD, and stringers above that all the way to surface. Even 50% washout puts ToC above 2100' from volumetric calculations. 6 9-5/8” 4 5 7” PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD Amt SPF Date Comments Sterling 5,095' 5,115' 5,095' 5,115' 20' 3/2003 Sqz’d B-3 Sterling 5,132' 5,142' 5,132' 5,142' 10’ 3/2003 Sqz’d B-3 Sterling 5,174' 5,184' 5,174' 5,184' 10’ 3/2003 Sqz’d B-3A PERFORATION DETAIL – continued on following page JEWELRY DETAIL – LONG STRING No. Depth ID Item A 6909 80-40 k-0Anchor (latch only) B 6911 3.250” Baker 194 SAB 40-32 Pkr C 6965 2.813” Camco X-Nipple D 8962 2,813” Camco X-Nipple – PX plug set 3/4/2003 E 8987 Wireline Re-Entry 7 Top of Fill @ 10,079’ 3/21/13 A/B/C D/E 9 10 12 13 11 30” 8 3 1 Updated by DMA 01-05-24 SCHEMATIC Beaver Creek Unit Well: BCU-06 API: 50-133-20346-00-00 PTD: 181-150 PERFORATION DETAIL – continued from previous page PERFORATION DETAIL – SHORT STRING Zone Top MD Btm MD Top TVD Btm TVD Amt SPF Date Comments Beluga 6,018' 6,031' 6,018' 6,031' 13' Sqz’d UB-3 Beluga 6,080' 6,095' 6,080' 6,095' 15' Sqz’d UB-3 Beluga 6,112' 6,118' 6,112' 6,118' 6' Sqz’d UB-4 Beluga 6,125' 6,134' 6,125' 6,134' 11' Sqz’d UB-4 Beluga 6,140' 6,149' 6,140' 6,149' 9' Sqz’d UB-4 Beluga 6,165' 6,179' 6,165' 6,179' 14' Sqz’d UB-4 PERFORATION DETAIL – LONG STRING Zone Top MD Btm MD TopTVD Btm TVD Amt SPF Date Comments Tyonek 9,120' 9,155' 9,107' 9,141' 35' 6' 12/1996 *Isolated Tyonek 9,120' 9,155' 9,107' 9,141' 35' 6' 2/1997 *Isolated Tyonek 9,120' 9,140' 9,107' 9,126' 20' 6' 1/16/2008 *Isolated Tyonek 9,140' 9,155' 9,126' 9,141' 15' 6' 1/16/2008 *Isolated Tyonek 9,866' 9,886' 9,824' 9,844' 20' 6' 2/4/1996 *Isolated Tyonek 9,866' 9,886' 9,824' 9,844' 20' 6' 1/15/2008 *Isolated *2-1/8” Owen ShoGun NTX Charges PERFORATION DETAIL Zone Top MD Btm MD TopTVD Btm TVD Amt SPF Date Comments G-Zone 15,170' 15,200' 14,858' 14,887' 30’ Isolated G-Zone 15,085' 15,128' 14,775' 14,817' 43’ Isolated G-Zone 15,003' 15,050' 14,696' 14,742' 47’ Isolated Hemlock 15,520' 15,546' 15,204' 15,230' 26’ Isolated Hemlock 15,476' 15,506' 15,160' 15,190' 30’ Isolated Hemlock 15,414' 15,466' 15,099' 15,131' 52’ Isolated Hemlock 15,387' 15,407' 15,072' 15,092' 20’ Isolated Hemlock 15,345' 15,370' 15,030' 15,055' 25’ Isolated Hemlock 15,306' 15,326' 14,992' 15,011' 20’ Isolated Page 1/3 Well Name: BCU-006 Report Printed: 1/4/2024www.peloton.com Well Operations Summary Jobs Actual Start Date:9/17/2023 End Date: Report Number 1 Report Start Date 9/17/2023 Report End Date 9/18/2023 Operation Held PJSM Remove well barricade & level around well. lay out felt and liner. Set Base beam, spot carrier and rig equipment check well pressure 9-5/8 "0" 9-5/8 x 13-3/8 "0" and 13-3/8 x 20" "0" Prep and raise derrick Continue rigging up hoses and nipple up tbg spool 13-5/8 5m x 11"5m test void to 1500 psi good test. Nipple up 13-5/8 BOPE, torquing bolts, hooking up control lines, secure well for night. Report Number 2 Report Start Date 9/18/2023 Report End Date 9/19/2023 Operation Held PJSM Torque Bope bolts Install floor & rig up same, make up test 2-7/8 test joint.. Install test plug fluid pack BOPS. Test bops and related surface equipment to AOGCC AND Hilcorp specs to 250 psi & 2500 psi hi preform koomey draw down.one fail pass time on koomey recharge time re recharge pressure to 200 psi (60 sec) full recharge pressure (5minutes), trouble shoot koomey triplex pump check suction & discharge screens, check plungers and valves and seats, preform draw down test 200 psi Recharge time 27 seconds, full pressure recharge.127 seconds (Pass) Pull test plug, lay down same secure well for night. Report Number 3 Report Start Date 9/19/2023 Report End Date 9/20/2023 Operation PJSM Check well, "0" pressure check equipment. Pick up overshot for AS1x packer. On/ off tool, trip in hole tagged at 538 dpm corrected elevation 545 ft. pick up 2k to verify latch set 2k down on packer, put 1/4 turn into packer, close annular put 110 psi on backside with 2.0 bbl. 8.4 ppg fluid., Pick up on AS1X packer in 5k intervals for 1 ft. pressure bleed f/ 110 psi to 40 psi and held pick up 2 ft. to verify release, bleed off annulus, well static Let packer rubbers relax, finish installing Burm. Pooh lay down. 9-5/8 AS1x retrievable packer and over shot Make up 2-7/8 mule shoe, trip in hole picking up 2-7/8 work string to 3040 dpm secure well for night. Report Number 4 Report Start Date 9/20/2023 Report End Date 9/21/2023 Operation PJSM, check well static, inspect rig equipment. Continue TIH picking up 2-7/8 PH 6 7.9 # f/. 3040 ft to 5000 ft. P/up 28k s/o 28K tagged at PBTD 5000 ft. with 2K down. Rig up to displace 8.4 fluid to 9.0 ppg brine. Pump Displace 8.4 ppg fluid with 9.0 brine at 2.1 bpm at 450.psi pump 354 bbl. Check COM Lay down single pooh f/ 5000 ft. to 1219 ft. Secure well for night Report Number 5 Report Start Date 9/21/2023 Report End Date 9/22/2023 Operation PJSM check well (well static), change dies on backups on power tongs , transfer fluid from RFR tank to pits. Pooh with work string from 1,219 ft to surface. make up 9-5/8 CIBP and x/overs on 2-7/8 ph. 6 work string, Run in hole at 1 minute per stand to 4125 ft. p/u 26k s/o 26k Drop 1-1/4 ball, pump ball down on seat pressure up to 1734 psi CIBP stroked pick up 38k over to verify CIBP set, sheared off CIBP, slack off and verify CIBP set, set 10k down on same OK Rig up and MIT CIBP at 4125 ft to 1500 psi for 15 minutes with 1.3 bbl. pumped (good test) bleed off pressure got 1.3 bbl. back. PJSM with Fox Energy cmt crew, rig up cmt pump line, Mix and pump 75 sxs , 16.5 bbl. slurry of CL"G" cmt +.2% FFL 220 + .5% FCD 200, mixed at 15.3 ppg. with 1.23 yld, displace cmt with 22 bbls 9.0 ppg brine at 4.bpm final pressure 500 psi shut down pump, pressure bleed to "0" had full returns during cmt job, cmt in place at 5:06 pm, BLM inspector Quinn Sawyer witness CIBP setting at 4125 ft. the CIBP MIT to 1500 psi and the mixing and pumping of 225 ft cmt plug on top of CIBP. Pooh to 3668 ft, reverse out 32 bbls had trace of cmt on bottoms up rack back 1 more stand to 3602 ft. finish rigging down Fox energy cmt equipment secure well for night. Report Number 6 Report Start Date 9/22/2023 Report End Date 9/23/2023 Operation PJSM check well, well static, spot pipe skate and inspect equipment Pooh laying down 2-7/8 PH 6 work string from 3607 ft to surface p/up 26k s/o 26k API: 50-133-20346-00-00 Field: Beaver Creek Sundry #: 322-591 / 323-455 State: Alaska Rig/Service:Permit to Drill (PTD) #:181-150 Page 2/3 Well Name: BCU-006 Report Printed: 1/4/2024www.peloton.com Well Operations Summary Operation Prep floor to RIH with pipe out of derrick RIH with pipe out of derrick to 1,148 ft. Pooh laying out work string. RIG up Eline pick up 9-5/8 Legacy oil tools Part number 000-7710,002-60D 7.710 OD Big Boy Bridge plug suitable for 9-5/8" 29.3 - 53.5 ppf csg rated to 8000 psi at 300 deg F with 60 Duro rubber LOT # 102935, RIH setting at 180 ft top of plug, set back down on CIBP to verify it set, pooh with E-line, lay out setting tool. Allie Schoessler with BLM waived witness of setting the CIBP at 180 ft. E LINE RIH with 12 FT 1-9/16 perf gun loaded with 6 ft of shot 3/8 x 1/2 " shots at 6 spf 36 shots total punch hole from 178 to 172 ft. pooh Attempt to circulate down the 9-5/8 csg and up the 9-5/8 x 13-3/8 annulus pressure up to 1000 psi with .85 bbls bleed off attempt to circulate again pressure up to 1000 psi with .67 bbls pumped, attempt a third time to circulate pump .67 bbl. attempt to reverse circulate down the 9-5/8 x 13-3/8 annulus and up the 9-5/8 csg pressure up to 1000 psi with .32 bbls pumped. E-line build pref gun RIH with 19 ft. 1-9/16 tools string with 6'perf gun loaded with 6 spf of 1/2 x 3/4 shots total of 36 shots, perf the 9-5/8 csg at 178 ft to 172 ft pooh all shots fired. Attempt to circulate down the 9-5/8 csg and up the 9-5/8 x 13-3/8 annulus pressure up to 1000 psi with .67 bbl., bleed off and attempt second try, pressure up to 1000 psi with .32 bbls attempt third time pressured up to 1000 psi with .25 bbls pumped attempt to reverse circulate up the 9-5/8 x 13-3/8 annulus pressured up to 1000 psi with .14 bbl. pumped bleed off pressure. Rig down Eline and secure well of night. Report Number 7 Report Start Date 9/23/2023 Report End Date 9/24/2023 Operation Held PJSM check well (well static) Pump cellar out, remove flanges from csg spool attempt to check OA for fill with plump bob (no luck) Held pre job meeting & JSA for rigging up power swivel and csg cutter. Set power swivel HPU in place, pick up power swivel, pick up 9-5/8 csg cutter, RIH with 2-7/8 PH 6 work string to 150 ft. space out. Made cut on 9-5/8 csg at 150 ft., had good indication of cut. Lay down power swivel.. Pooh L/d 2-7/8 work string and 9-5/8 csg cutter. Pressure up on 9-5/8 csg to 1000 psi pressure bleed down slowly to 800 psi getting slight returns form OA, returns started increasing, pressure bleed to 400 psi, bumped pressure up to 900 psi, getting good returns, started circulating at 1.5 bpm at 400 psi, increased rate to 2.0 bpm 500 psi, increased rate to 2.5 bpm at 560 psi, increased rate to 2.8 bpm at 750 to 850 psi circulated total of 233 bbls Secure well for night Report Number 8 Report Start Date 9/24/2023 Report End Date 9/25/2023 Operation PJSM check well, (well static) fill 180 bbl. in RFR, R/U to circulate, down 9-5/8 out of the 13-5/8. Stage pump up to 3.5 bpm / 850 psi. Fluid coming back 8.4 ppg after surface to surface. Still getting pea sized hard mud coming back in returns, OA packed off and pressure increased to 1100 psi, shut down pump total of 87 bbls pumped, line up and reverse circulate pressured to 1100 psi broke free. Pump 4 bbls in reverse at 1.25 bpm at 315 psi, had discussion with Ops Engineer to move forward to pull 9-5/8 csg. . Rig down floor, stairs, fold up floor, nipple down 13-5/8 BOPE. & the 13-5/8 5m x 11" 5m tbg spool nipple up 13-5/8 4 ft riser on top of 13-5/8 csg spool lower floor Make up grapple on spear make up spear assembly rig up Parker csg tools. Spear into 9-5/8 csg p/up 5k increments over csg wt. (~7K) work up to 35k over, no movement continue to work csg to 35k over csg wt., with no luck. Rig up to circulate down the OA while working pipe to 35k over no movement. Release spear, and lay down, break off x/o and pup jt. R/d parker handling equipment add a 2 ft 13-5/8 m spool to well head for spacing for csg jack. Rig up Csg jack on well head and bolt down, set HPU and hook up Hyd lines. Report Number 9 Report Start Date 9/25/2023 Report End Date 9/26/2023 Operation PJSM go over casing jack procedure with crews, make up 3-1/2 IF pup on 9-5/8 csg spear and spear into 9-5/8 csg, p/u to 280k had 10" of movement, unable to circulate on OA, release from spear, lay down spear break off pup joints, load up on trailer to send to yellow jacket to get 5" Hwt Drill pipe bucked up on spear. Attempt to circulate down OA (3) times pressured up to 1000 psi each time and held. took .32 bbls to pressure up. first time and 0.18 bbls the last two times. Each Waiting on spear and 5" hwt drill pipe back to rig off load 5" Handling equipment and spear and rig up 5" handling equipment Pick up 9-5/8 spear and engage 9-5/8 csg, pull 40k with rig block, pick up to 307k got 6" of movement, worked up in increments up to 538k.had a total of 2 ft of movement, try to work csg, able to slack off but could not pick back up, had 6" of movement after slacking off. Release from spear and lay down spear, rig down csg jacks, rig up power swivel. off load csg cutter pick up 9-5/8 csg cutter and make cut at 100 ft from Ground level.. Rig down power swivel and lay out work string and cutter. Pick up 9-5/8 spear and 5" Hwt drill pipe engage spear. Pick up to 23K 12,300 over pipe wt. with rig blocks.no movement release spear and lay out 5" Hwt and spear, shut down for night. Report Number 10 Report Start Date 9/26/2023 Report End Date 9/27/2023 Operation PJSM rig down power swivel and move power unit, set and rig up csg jacks, R/up 5" handling equipment, P/up 9-5/8 csg spear and engage spear. in 9-5/8 csg API: 50-133-20346-00-00 Field: Beaver Creek Sundry #: 322-591 / 323-455 State: Alaska Rig/Service: Page 3/3 Well Name: BCU-006 Report Printed: 1/4/2024www.peloton.com Well Operations Summary Operation P/up 25k with RIG block, start jacking casing, casing started moving at 60K, stalled out after 5 ft pulled, increased jacks to 84k moved additional 5 ft. Had 5 ft of stump sticking up, decision made to get csg slips out of csg head. Release and lay down spear, rig down csg jacks, remove 13.5/8 spools, weld csg slips to csg, N/up 2 ft 13-5/8 spool on csg head, put csg jack base and bowl over stump onto spool. p/up spear and spear 9-5/8 csg. Pick up to 52k with rig block, csg overpull broke back to 38k, pick up to csg slips and remove same from csg, continue to pull and cut 9-5/8 csg laying out same, recovered 102.18 ft of csg R/down csg jack bowl and base, nipple up 3 ft spool, R/ down csg jack HPU and move same, rig down csg handling equipment and rig up 2-7/8 handling equipment. Make up mule shoe on bottom of 2-7/8 7.9 work string and RIH from surface to 175ft. Stage and rig up Fox cmt equipment and circulating hoses for cmt job. SDFN Report Number 11 Report Start Date 9/27/2023 Report End Date 9/28/2023 Operation PJSM check equipment and line ups, cementers taking on water from vac truck. PJSM with Fox cementing crew, break circulate bbls fresh water, pressure test lines to 700 psi, Mix and pump 96 sxs of CL "G" cmt 21 bbls slurry mixed at 15.3 ppg with 1.23 yld +.2% FFL220 +.5% FCCD200, cmt at surface at 20 bbls pumped; pumped cmt at 2-3 bpm at 100 psi, Pooh with work string from 175 ft. and rack back in derrick, top off 13-3/8 with 1 bbl. 15.3 ppg cmt total of 21 bbls pumped cmt in place at 0930 hrs. BLM Allie Schoessler waived witness of pumping surface cmt plug at 175 ft. to surface. via text at 08:24 hours, 9/27/23 Flush cmt pump hoses, equipment, R/d floor, nipple down 2'and 3' spools, nipple up 13-5/8 x 11" 5m tbg spool and blind flange, Rig down pits, and pump hoses, remove berm and load mix pit, centrifugal pump, cutting boxes, and choke house, lower pit roof, load up pits, pump, bang board and generator, move office. Held PJSM Scope down derrick and lay over derrick, secure lines, pin derrick, chain off block, move carrier off liner, remove foot and lower landings. Continue loading out rig equipment, and load out on trailers for move. install baricade around well and put well sign on same. Report Number 12 Report Start Date 11/14/2023 Report End Date 11/15/2023 Operation Pulled well head off of starter head. Cut windows through 20" accessed 13-3/8" cut off both casings with torch. There is 17 feet from cut to the hard cement in the 20"x 13-3/8" annulus. Cleaned up area and prepped for weld and cementing. Made notifications to AOGCC and BLM to witness wellhead cutoff before additional work to be conducted at 3:00PM. Report Number 13 Report Start Date 11/17/2023 Report End Date 11/18/2023 Operation Crews arrive on location, Meet wiht BLM inspector Quinn Swayer. Crews mixed 38 bags of cement, placed into 30" conductor annular. All casing full of cement. Cleaned up work area. Welded plate on Well with Well name, API #, PTD# and Hilcorp Alaska, beaded welded to the plate, see photos. Left weep holes in weld per BLM regulations. Report Number 14 Report Start Date 12/8/2023 Report End Date 12/9/2023 Operation McLane surveyors arrived in field. Set up control points. Surveyed the top of well marker plate to reference original grade. API: 50-133-20346-00-00 Field: Beaver Creek Sundry #: 322-591 / 323-455 State: Alaska Rig/Service: Cellar After Wellhead Cut 11/15/23 30" 20" 13-3/8" Cement at Surface – 13-3/8” Casing and 20” x 13-3/8” Annulus 11/17/23 Wellhead Cover 11/17/23 P.O. Box 468 Soldotna, Alaska 99669 (907) 283-4218 Fax (907) 283-3265 Email ahamilton@mclanecg.com Well BCU No. 6 Plug & Abandon Memo Date: 12/12/2023 To: Hilcorp Alaska LLC……………………………………Attn: Mike Erstrom From: Andrew Hamilton, PLS Project: Beaver Creek Unit (BCU) Pad 3 – Well No. 6 Plug & Abandon Survey Re: Project Summary This memo is for the plug and abandon effort for Hilcorp’s BCU No. 6 well located on BCU Pad 3 in Section 34, Township 7 North, Range 10 West, Seward Meridian, Alaska. A field survey was performed on December 8, 2023 by McLane Consulting Inc. (MCI). The scope of work consisted of locating the cut off BCU No. 6 well casing on BCU Pad 3 and collecting original ground measurements adjacent to the pad to confirm legacy data. To establish original ground elevation near the well casing, MCI compared legacy topographic survey data from the 2004 pad expansion design survey (performed by MCI) to the original ground survey measurements collected this survey, confirming the legacy 2004 survey data. Enclosed is Exhibit A which includes well casing cutoff detail with pad, original ground, and as-built casing cutoff elevations. x Mean pad surface elevation in vicinity of well casing: 160.9’ ± x Original ground elevation in vicinity of well casing: 158’ ± x Cutoff depth requirement: 3.0’ below original ground elevation x Minimum casing cutoff elevation: 155.0’ x Actual cutoff elevation: 154.6’ (As surveyed by MCI 12/8/2023) Please feel free to contact me if you have any questions or comments. Sincerely, Andrew Hamilton, PLS McLane Consulting, Inc. BCU No. 16RD BCU No. 9 CONTROL POINT 249 N: 2433547.53 E: 1457128.82 ELEV: 163.86' (NAVD 88 GEOID 12B) BCU No. 03RD BCU No. 11 BCU No. 10 ACC E S S R O A D BC 9 N: 2434050.79 E: 1457212.67 ELEV: 160.98' (NAVD88 GEOID 12B) SECTION 34 T7N R10W SM, AK BCU No.19 BEAVER CREEK UNIT PAD 3 BCU No. 24 BCU No. 23 BCU No. 18 BCU No.25 BCU No. 13 BCU No. 05RD BCU No. 6 P&A ASP NAD83 ZONE 4 N: 2433775.5 E: 1457332.4 ELEV: 154.6 (CUT OFF) 237024JOB NO.______________ 12/8/2023BGB 2001000 SCALE LOCATION: SECTION 34, TOWNSHIP 7 NORTH, RANGE 10 WEST, SEWARD MERIDIAN ALASKA ENGINEERING - TESTING SURVEYING - MAPPING P.O. BOX 468 SOLDOTNA, AK. 99669 VOICE: (907) 283-4218 FAX: (907) 283-3265 WWW.MCLANECG.COM DRAWN BY BEAVER CREEK UNIT PAD 3 BCU No. 6 WELL PLUG & ABANDON EXHIBIT-A CONTROL NOTE 1. HORIZONTAL: ALASKA STATE PLANE ZONE4 NAD83 (2011) EPOCH 2010 US SURVEY FEET. 2. VERTICAL: NAVD88 (GEOID12B). 3. PRIMARY CONTROL BC 9 N = 2434050.79 E = 1457212.67 ELEV. = 160.98 1 Junke, Kayla M (OGC) From:Chad Helgeson <chelgeson@hilcorp.com> Sent:Monday, January 8, 2024 10:18 AM To:McLellan, Bryan J (OGC) Cc:Casey Morse; Donna Ambruz; Scott Warner Subject:RE: [EXTERNAL] RE: BCU-06 P&A PTD# 181-150 (Sundry # 323-455) wellhead cutoff depth Attachments:Hilcorp BCU Pad # Well 6 P&A_Signed.pdf Bryan, We were compleƟng the paperwork for the closure on BC‐06 P&A and I remembered this email requesƟng us to reference this in the 10‐407. When we had the surveyors get a final depth of the welded on plate on the casing, the surveyors were able to find a 2004 survey for a pad expansion with an original pad grade referenced. We cut off BC‐06 3.4’ below the original grade on the pad. Based on this report, we will not be referencing this email in the 10‐407, however including the aƩached Surveyed document, as this depth meets the requirement of 20AAC25.170 in the 10‐407. Let us know if you have any quesƟons or need addiƟonal informaƟon on it. Regards Chad Helgeson From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, October 23, 2023 12:33 PM To: Chad Helgeson <chelgeson@hilcorp.com> Cc: Donna Ambruz <dambruz@hilcorp.com>; Mike Erstrom <merstrom@hilcorp.com>; Chad Johnson <chjohnson@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: [EXTERNAL] RE: BCU‐06 P&A PTD# 181‐150 (Sundry # 323‐455) wellhead cutoff depth Chad, Hilcorp has approval to cut off the well 7 Ō below current ground level and weld on the marker plate as described in your email below. The well will be listed as plugged, but site clearance not complete. Please note this in the 10‐407. The well must be cut off 3 feet below original ground level and meet all site clearance and marker plate requirements within one year of cessaƟon of producƟon and/or injecƟon operaƟons at this drill site. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250‐9193 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Friday, October 20, 2023 4:11 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Mike Erstrom <merstrom@hilcorp.com>; Chad Johnson <chjohnson@hilcorp.com> Subject: BCU‐06 P&A PTD# 181‐150 (Sundry # 323‐455) wellhead cutoff depth Bryan, As we discussed on the phone Hilcorp is requesƟng approval to complete the BCU‐06 P&A by cuƫng off the wellhead at the boƩom of the cellar (which is ~6Ō below the top of the cellar and 7Ō below current ground level) and welding a plate on top of the cemented casing strings with the marker plate as described in the sundry. This well and cellar are in close proximity to other flowlines, comm cables, and electrical lines and the excavaƟon area needed to safely excavate 7Ō below current grade looking for original grade and ensuring the wellhead is cut 3’ below original grade per 20AAC25.170 does not seem necessary at this Ɵme. This well is located on Pad 3 at Beaver Creek which has 13 addiƟonal wells on it which will need to be removed in the future when the field is done producing. We do plan to have the final cut plate surveyed with elevaƟon to have a record of depth when the original grade is confirmed someday in the future. Please let us know if we can have approval to cut the wellhead off near the boƩom of the cellar and backfill the cellar with gravel. We will make necessary noƟficaƟons for witness of cut off wellhead (Before any cement is added) and aŌer the plate is welded on. If you have any quesƟons or need any addiƟonal informaƟon, please let me know. I have aƩached a picture of the pad and you can see the close proximity BC‐06 is to the other wells. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 3 Chad Helgeson Operations Engineer Kenai Asset Team 907‐777‐8405 ‐ O 907‐229‐4824 ‐ C P.O. Box 468 Soldotna, Alaska 99669 (907) 283-4218 Fax (907) 283-3265 Email ahamilton@mclanecg.com Well BCU No. 6 Plug & Abandon Memo Date: 12/12/2023 To: Hilcorp Alaska LLC……………………………………Attn: Mike Erstrom From: Andrew Hamilton, PLS Project: Beaver Creek Unit (BCU) Pad 3 – Well No. 6 Plug & Abandon Survey Re: Project Summary This memo is for the plug and abandon effort for Hilcorp’s BCU No. 6 well located on BCU Pad 3 in Section 34, Township 7 North, Range 10 West, Seward Meridian, Alaska. A field survey was performed on December 8, 2023 by McLane Consulting Inc. (MCI). The scope of work consisted of locating the cut off BCU No. 6 well casing on BCU Pad 3 and collecting original ground measurements adjacent to the pad to confirm legacy data. To establish original ground elevation near the well casing, MCI compared legacy topographic survey data from the 2004 pad expansion design survey (performed by MCI) to the original ground survey measurements collected this survey, confirming the legacy 2004 survey data. Enclosed is Exhibit A which includes well casing cutoff detail with pad, original ground, and as-built casing cutoff elevations. •Mean pad surface elevation in vicinity of well casing: 160.9’ ± •Original ground elevation in vicinity of well casing: 158’ ± •Cutoff depth requirement: 3.0’ below original ground elevation •Minimum casing cutoff elevation: 155.0’ •Actual cutoff elevation: 154.6’ (As surveyed by MCI 12/8/2023) Please feel free to contact me if you have any questions or comments. Sincerely, Andrew Hamilton, PLS McLane Consulting, Inc. BCU No. 16RD BCU No. 9 CONTROL POINT 249 N: 2433547.53 E: 1457128.82 ELEV: 163.86' (NAVD 88 GEOID 12B) BCU No. 03RD BCU No. 11 BCU No. 10 AC C E S S R O A D BC 9 N: 2434050.79 E: 1457212.67 ELEV: 160.98' (NAVD88 GEOID 12B) SECTION 34 T7N R10W SM, AK BCU No.19 BEAVER CREEK UNIT PAD 3 BCU No. 24 BCU No. 23 BCU No. 18 BCU No.25 BCU No. 13 BCU No. 05RD BCU No. 6 P&A ASP NAD83 ZONE 4 N: 2433775.5 E: 1457332.4 ELEV: 154.6 (CUT OFF) 237024JOB NO.______________ 12/8/2023BGB 2001000 SCALE LOCATION: SECTION 34, TOWNSHIP 7 NORTH, RANGE 10 WEST, SEWARD MERIDIAN ALASKA ENGINEERING - TESTING SURVEYING - MAPPING P.O. BOX 468 SOLDOTNA, AK. 99669 VOICE: (907) 283-4218 FAX: (907) 283-3265 WWW.MCLANECG.COM DRAWN BY BEAVER CREEK UNIT PAD 3 BCU No. 6 WELL PLUG & ABANDON EXHIBIT-A CONTROL NOTE 1. HORIZONTAL: ALASKA STATE PLANE ZONE4 NAD83 (2011) EPOCH 2010 US SURVEY FEET. 2. VERTICAL: NAVD88 (GEOID12B). 3. PRIMARY CONTROL BC 9 N = 2434050.79 E = 1457212.67 ELEV. = 160.98 1 Regg, James B (OGC) From:Chad Helgeson <chelgeson@hilcorp.com> Sent:Thursday, November 16, 2023 10:57 AM To:Regg, James B (OGC) Cc:Chad Johnson; Michael Morgan Subject:BC-06 P&A completion inspection Attachments:BC-06 measurement to bottom of 20in x 13.375in annulus 11-15-23 one side of pipe.jpeg; BC-06 photo of bottom of cellar cut off 11-15-23.jpeg Jim, As we discussed last night we are planning on meeƟng the BLM at Beaver Creek pad 3 (Well 06) at 0800 tomorrow morning (11/17) to witness the tag of the cement before we add cement to the OA. Let us know if you can make it or if we need to reschedule a different day this weekend. AƩached are current pictures of the wellhead aŌer we removed it. Chad Helgeson Operations Engineer Kenai Asset Team 907‐777‐8405 ‐ O 907‐229‐4824 ‐ C The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Beaver Creek Unit 6PTD 1811500 AOGCC witness waived 11/17/2023; J. Regg 11/15/2023: BC-06 measurement to botom of 20” x 13-3/8” annulus (Hilcorp) 11/15/2023: BC-06 botom of cellar cut off (Hilcorp) CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Chad Helgeson Cc:Donna Ambruz; Mike Erstrom; Chad Johnson; Regg, James B (OGC) Subject:RE: BCU-06 P&A PTD# 181-150 (Sundry # 323-455) wellhead cutoff depth Date:Monday, October 23, 2023 12:33:00 PM Attachments:image004.png image005.png Chad, Hilcorp has approval to cut off the well 7 ft below current ground level and weld on the marker plate as described in your email below. The well will be listed as plugged, but site clearance not complete. Please note this in the 10-407. The well must be cut off 3 feet below original ground level and meet all site clearance and marker plate requirements within one year of cessation of production and/or injection operations at this drill site. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Friday, October 20, 2023 4:11 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Mike Erstrom <merstrom@hilcorp.com>; Chad Johnson <chjohnson@hilcorp.com> Subject: BCU-06 P&A PTD# 181-150 (Sundry # 323-455) wellhead cutoff depth Bryan, As we discussed on the phone Hilcorp is requesting approval to complete the BCU-06 P&A by cutting off the wellhead at the bottom of the cellar (which is ~6ft below the top of the cellar and 7ft below current ground level) and welding a plate on top of the cemented casing strings with the marker plate as described in the sundry. This well and cellar are in close proximity to other flowlines, comm cables, and electrical lines and the excavation area needed to safely excavate 7ft below current grade looking for original grade and ensuring the wellhead is cut 3’ below original grade per 20AAC25.170 does not seem necessary at this time. This well is located on Pad 3 at Beaver Creek which has 13 additional wells on it which will need to be removed in the future when the field is done producing. We do plan to have the final cut plate surveyed with elevation to have a record of depth when the original grade is confirmed someday in the future. Please let us know if we can have approval to cut the wellhead off near the bottom of the cellar and backfill the cellar with gravel. We will make necessary notifications for witness of cut off wellhead (Before any cement is added) and after the plate is welded on. If you have any questions or need any additional information, please let me know. I have attached a picture of the pad and you can see the close proximity BC-06 is to the other wells. Chad Helgeson Operations Engineer Kenai Asset Team 907-777-8405 - O 907-229-4824 - C The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error,you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above,then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systemsor data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 15,928'N/A Casing Collapse Conductor Conductor Surface 2,260 psi Production 4,750 psi Liner 10,760 psi Liner 10,490 psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Aras Worthington Contact Email:Aras.Worthington@hilcorp.com Contact Phone:(907) 564-4763 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 8/22/2023 15,889'1,208' N/A 15,572' N/A & N/A N/A & N/A 14,980' Perforation Depth MD (ft): 12,410' See Schematic 3,534' 5" See Schematic 14,674'7" 58' 30" 20" 13-3/8" 502' 9-5/8"12,410' 4,022' MD 6,870 psi 5,020 psi 502' 4,022' 12,228' 502' 4,022' Length Size Proposed Pools: 58' 58' N/A TVD Burst N/A 12,460 psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028083 181-150 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-133-20346-00-00 Hilcorp Alaska, LLC CO 237C AOGCC USE ONLY 10,140 psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Beaver Creek Unit (BCU) 06 Beaver Creek Unit BC Oil, Beluga + Tyonek + Sterling Gas N/A 15,610' 4,996' 4,996' ~1,711 See Schematic No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:04 am, Aug 14, 2023 323-455 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.08.11 17:05:59 - 08'00' Noel Nocas (4361) Provide AOGCC 24 hrs notice to inspect site clearance after P&A is complete. X DSR-8/14/23 CO 237D SFD Abandon Provide AOGCC 24 hrs notice for opportunity to visually witness cement in annuli at surface after cutoff. BOP test to 2500 psi SFD 8/21/2023 10-407 BJM 8/14/23 8/22/2023 GCW 08/21/2023JLC 8/21/2023 08/22/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.08.22 13:10:54 -08'00' RBDMS JBS 082423 Well: BCU-06 Plug and Abandon Rev1 Well Name: BCU-06 API Number: 50-133-20346-00-00 Current Status: Shut-In Gas Producer Permit to Drill Number: 181-150 First Call Engineer: Aras Worthington (907) 564-4763 (O) (907) 440-7692 (C) Second Call Engineer: Chad Helgeson (907) 229-4824 (C) Max. Expected BHP: ~2,230 psi @ 5,184’ TVD 0.43psi/ft to deepest Sterling perfs (isolated) Max. Potential Surface Pressure ~1,711 psi 0.1 psi/ft to surface Well Summary BCU-06 is a long term SI producer. Given the lack of future utility, Hilcorp is progressing with a full P&A of this wellbore. The goal of this project is to fully P&A the well. Notes Regarding Wellbore Condition x Inclination: Straight hole. MD = TVD x Pertinent History o August-2018 RWO to remove wellhead for offset rig-fit: EL set 9-5/8” CIBP at 5050' and dump bailed 35' cement on top. EL tag the next day at 4996' MD. MIT against 9-5/8” CIBP and cement to 2500psi passed Retrievable packer set at 518’ MD, and passed MIT to 2500psi passed o 2014-RWO Well left with 8.4# fresh source water x Cement: (See schematic for additional details) o ToC behind 9-5/8”: Good cement up to 2750’ MD. Stringers above that to surface o ToC behind 13-3/8”: To surface o ToC behind 20”: To surface Well: BCU-06 Plug and Abandon Rev1 RWO Plug and Abandonment Procedure: 1. MIRU Hilcorp rig #401 2. Ensure all annuli/casings are bled to 0psi, and fluid packed using 8.5# produced water. Confirm no- flow 3. NU BOP’s and test a. PT to 250psi low / 2500psi high / 2500psi annular b. Test to handle 2-7/8” workstring pipe 4. RIH on 2-7/8” workstring and pull retrievable packer from 518’ MD a. Should be equalized above and below packer as-is b. Hold ~100psi on casing above packer to ensure overbalance 5. Once free, confirm well is still fluid packed using 8.5# produced water 6. POOH and lay down packer a. Once packer is pulled OOH no further BOP tests will be required on the well. The well has two barriers: i. CIBP @ 5050’ MD with cement on top, MIT’d to 2500 psi ii. Kill weight fluid 7. MU 9-5/8” CIBP on workstring 8. RIH to ±4,125’ MD and set CIBP avoiding collars (needs to be at least 100’ below surface casing shoe) 9. Swap well over to 9ppg brine (300bbls) 10. Stack down weight on CIBP with workstring to verify its set 11. Lay in surface casing shoe abandonment cement a. Lay in 225’ of cement (16.5bbls) b. Should bring ToC to ±3900’ MD c. ToC needs to be at least up to 100’ above 13-3/8” shoe (3,922’ MD) 12. POOH and lay down workstring 13. RU EL 14. MU 9-5/8” CIBP and set at ±180’ MD 15. MU casing punch, and punch 9-5/8” casing at ±175’ MD 16. Establish circulation down the 9-5/8” casing and out the 9-5/8” x 13-3/8” annulus (OA). Max 9-5/8” pressure 1000 psi. 17. MU 9-5/8” Cement Retainer and set at +/-160’ MD 18. Rotate to the right to release from retainer 19. Sting back into retainer and circulate 14-15.8 ppg Class A or G cement down workstring and out OA a. Ensure good cement returns to surface from OA (should be ~11 bbls from 175’ to surface in OA) 20. Un-sting from retainer and circulate cement down workstring and to surface in the 9-5/8” casing a. Ensure good cement to surface (12 bbls to fill 9-5/8” casing to surface) 21. POOH and LD workstring. CONTINGENCY: If unable to establish circulation above, cut 9-5/8” casing @ ~150’ MD and pull casing OOH. Lay cement plug in 13-3/8” casing from 150’ MD to surface. 22. RDMO rig 401 Well: BCU-06 Plug and Abandon Rev1 Post Rig Abandonment Procedure: 1. Excavate cellar, cut off all casings 3’ below natural GL. 2. Create well abandonment marker per 20 AAC 25.120. The following must be bead-welded directly to the marker plate: a. Hilcorp Alaska, LLC b. PTD: 181-150 c. Beaver Creek-06 d. API: 50-133-20346-00-00 3. Set marker plate on the 30” conductor per 20 AAC 25.120 and collect GPS coordinates. 4. Photo document casing cut-off and welded Plate install. 5. Backfill excavation, close out location. Attachments: 1. Current schematic 2. Proposed Schematic 3. Current wellhead schematic 4. Yellowjacket BOP’s (13-5/8” 5M double) 5. AOGCC RWO Change Form Provide AOGCC 24 hrs notice for opportunity to visually witness cement in annuli at surface after cutoff. -bjm Provide AOGCC 24 hrs notice to inspect site clearance after P&A is complete. -bjm Well: BCU-06 Plug and Abandon Rev1 Well: BCU-06 Plug and Abandon Rev1 Well: BCU-06 Plug and Abandon Rev1 Well: BCU-06 Plug and Abandon Rev1 Well: BCU-06 Plug and Abandon Rev1 Well: BCU-06 Plug and Abandon Rev1 Well: BCU-06 Plug and Abandon Rev1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVE[ MAR 6 2020 1. Operations Abandon Lj Plug Perforations Lj 3�q� Fracture Stimulate LJ Pull Tubing jW(Operations shutdown LJ Performed: Suspend ❑✓ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Suspended Well Inspection0 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑✓ Stratigraphic❑ Exploratory ❑ Service ❑ 181-150 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20346-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028083 Beaver Creek Unit (BCU) 06 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Beaver Creek / Beluga Gas Pool - Tyonek Undefined Gas 11. Present Well Condition Summary: 4,996'; 5,898; 10,400; 11,200; Total Depth measured 15,928 feet Plugs measured 14,547; 15,280 feet true vertical 15,610 feet Junk measured N/A feet Effective Depth measured 4,996 feet Packer measured 518 feet true vertical 4,996 feet true vertical 518 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 58' 30" 58' 58' Surface 502' 20" 502' 502' Intermediate 4,022' 13-3/8" 4,022' 4,02' 5,020 psi 2,260 psi Production 12,410' 9-5/8" 12,410' 12,228' 6,870 psi 4,750 psi Liner 3,534' 7" 14,980' 14,674' 12,460 psi 10,760 psi Liner 1,208' 5" 15,889' 15,572' 10,140 psi 10,490 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth) AS1X Ret Pkr; N/A 518' MD 518' TVD N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments (required per 20 AAC 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations ❑� Exploratory❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-301 Authorized Name: Taylor Wellman 777-8449 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer(Dhilcorp.com Authorized Signature: Date: 3 %� - Contact Phone: 777-8420 f-- RBDMS-E-�-/ma fl a 9n9n Suspended Well Inspection Data Well: Beaver Creek Unit 06 Surface Location: 1302' FWL, 1420' FNL, Sec. 34, T7N, R10W, S.M. Permit to Drill: 181-150 API: 50-133-20346-00-00 AOGCC Inspection Date: 02/05/20 AOGCC Inspector: Guy Cook *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: Tubing pulled 8-03-18 • Condition of Wellhead: Good Condition, no signs of leaks or damage. The wellhead is blinded off at the tubing spool. There were two labeled gauges one was labeled OA and the other OOA, they were functional but labeled incorrectly they should've been labeled IA and OA. The labeling error was brought to the attention of the operator. • Condition of Surrounding Surface Location: Good gravel pad covered in snow and ice, no signs of oil/fuel present. • Follow up Actions Needed: Make proper label corrections on casing gauges, build and install roof to protect wellhead from weather elements. Both corrections completed 2/27/20 (see attached photos) Attachments: • Current Well Schematic • Picture(s) • Plat - % mile radius of wellbore (KEN Sept 2019) Size Pressure (psi) Tubing N/A N/A Casing 9 5/8" 0 Surface Cas 13 3/8" 0 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: Tubing pulled 8-03-18 • Condition of Wellhead: Good Condition, no signs of leaks or damage. The wellhead is blinded off at the tubing spool. There were two labeled gauges one was labeled OA and the other OOA, they were functional but labeled incorrectly they should've been labeled IA and OA. The labeling error was brought to the attention of the operator. • Condition of Surrounding Surface Location: Good gravel pad covered in snow and ice, no signs of oil/fuel present. • Follow up Actions Needed: Make proper label corrections on casing gauges, build and install roof to protect wellhead from weather elements. Both corrections completed 2/27/20 (see attached photos) Attachments: • Current Well Schematic • Picture(s) • Plat - % mile radius of wellbore (KEN Sept 2019) Suspended Well Inspection Review Report InspectNo: susGDC200210183459 Date Inspected, 2/5/2020 Inspector: Guy Cook Type of Inspection Well Name: BEAVER CK UNIT 06 Permit Number: 1811500 Suspension Approval: Sundry P 318-301 Suspension Date: 8/5/2018 Location Verified? 'ill If Verified, How? Other (specify in comments) Offshore? Well Pressures (psi): Tubing: IA: Ola: ` 4z- z Initial Date AOGCC Notified: 1/31/2020 Operator: Nilcorp Alaska LLC Operator Rep: Andy Graves Wellborn Diagram Avail? SKl Photos Taken? C Fluid in Cellar? v 0 BPV Installed? ❑ 0 VR Plug(s) Installed? ❑ Wellhead Condition Wellhead appeared to be in good condition. No signs of leaks or damage. The wellhead is blinded off at the top of the tubing spool. There were two gauges fabled OA and OOA that were functional, but labeled incorrectly. They should have been labeled IA and OA. I pointed this out to the operator and asked them to be labeled correctly. Condition of Cellar Cellar was filled with water when I arrived, from snow melt, as they had a heater on the wellhead to make visual inspection easier. The cellar showed no signs of petroleum products. The water was sucked out of the cellar and I inspected the wellhead from ground surface level. Surroundinry Surface Condition Good gravel pad covered in snow/ice with no signs of oil/fuel present. Comments Location verified by map. The well has no tubing hanger in it to set a BPV into. The IA and OA did not have VR plugs installed, as per operator, and the well pressures are monitored. I did point out to the operator that the well is not very well protected from the elements and asked that they wrap or cover the well to protect it. Pictures of the well attached. Supervisor Comments Initial inspection was due not later than 8/5/2019 per 20 AAC 25.110 Friday, February 14, 2020 Beaver Creek #6 Pad 3 1,164' FNL, 1,487' FWL 'f'h'a''l. Alaska. 11,11: Sec. 34, T7N, R1 OW, S.M. Permit #: 181-150 API #: 50-133-20346-00-00 Property Des: A-028083 -.: KB Evelation: 179' above MSL bt r+ c: KB: 27' (original) S. * AS -1X relievable packer with bull plug KB: 21' (workover 2003) ye threaded in bottom with on/offtool on top Spud Date' 3/4/2003 ,r > @ 518'08/04/18 Rig Released' (prig RKBI 95/8" N-80 BTC Top Too Bottom 14,980' CIBP @ 5,050' w/ 54' of Cmt. TOC- 4,996' 08/04/18 5,754' Tree cxn = 3-1/2" EUE 8rd MD 5,754' 6,355' 3' 5 -bolt crescent flange cap Lift threads = 3.725" MCA MD 6,355' ,' -• §!,:? N-80 53.lippf MD 6,983' 6,985' Cementing stage tool Sqz per's 5,095'-5,184' tested to 14.1 ppg EMW Abandonment Items (WO RKBI Includes: 1 - Cement Retainer, 5,983' MD 2 - Cement Retainer, 6,200' MD (not set) 3 - Bridge Plug, 6,200' MD Shortstrina Perfs: Beluga 6 031' (6017 6031' TVD) UB 3 Squeeze -6,,080'--6'0"L 46680-6 X412 -sub=1 response -e,%6--(11,119=(6140 6 11 X6166-64F3-ArBf 1)B-4Sgaeezed Tyonek 9 - 955' (9107-9141' ND) 6 spf (12/1996 ) 9,122 55 7.9141' ND) 6 spf (2/1997) 9,10'9,1'(9120040 07-9126' ND) 6 spf 60° phase d (1/16/20 2-1/8" Owen ShoGun NTX charges 9,140' -9,1 55' (9126-9141' ND) 6 spf 60° phased ,(1/16/2008) 2-1/8" Owen ShoGun NTX charges 9,88666' - 98 N 4 88'198 ' ) /1996) 99,624-9844ND6 spf 60° phased (1115/2008) 2-1/8" Owen ShoGun NTX charges Inactive Perfs: Sterling (above the dual packer): 5,095' - 5,115' (50955115' ND) (sqi d 3/03) B-3 5,132'-6,142- 15132-61 5132-61 42 ND) (sgz'd 3/03) B-3 5,174'-5,184' (51745184' ND) (sgz'd 3/03) B -3A G,Zone: 15,1750' - 115,2200' 1114,868-14,887' TVD) 1508- 51 4,75-14,817' ND) 15,003'-15,050'(1469-14742 ND) Hemlock: 15,520' -15,546' (15,204-15,230' ND) 15,476'- 15,506' (15,160-15,190' ND) 15,414'- 15,466' (75,099-15,131' ND) 16,387'- 15,407' (15,072.15,092' ND) 15,345' -15,370' (15,030-15,055' ND) 6 bbls Cement on top of Retainer (Est TOC @ 5,898') 30 bbls Cement below Retainer Fill at 10,079'(3/21113) PBTD MD = 4,996' ND = 4,996' SCHEMATIC Surface Casino (Orin RKB) 13-3/8" N-80 68ppf BTC 72ppf BTC To�1 Bottom MD 0' 4,022' ND 0'4,022' Con w/ 2,400 sks of Class G Production Casing (prig RKBI 95/8" N-80 BTC Top Too Bottom 14,980' MD 0' 5,754' N-80 47ppf MD 5,754' 6,355' C-75 53.5ppf MD 6,355' 6,983' N-80 53.lippf MD 6,983' 6,985' Cementing stage tool MD6,985' 8,565' 1-80 53.5ppf MD 8,565' 9,615' P-110 47ppf MD 9,615' 12,410' P-110 53.5ppf ND 0' 12,228' Cmt w/ 3,388 sks of Class G (1,588 sks 1st Stage, 1,800 sks 2nd Stage) Liner long RKBI 5" N-80 7" P-110 32 ppf BTC Top Bottom MD 11,446' 14,980' ND 11,326' 14,674' Cmt w/ 652 sks of Class G Liner (Orin RKBI 5" N-80 18 ppf BTC Tog) Bottom MD 14,681' 15,889' ND 14,387' 15,572' Cmt w/ 450 sks of Class G Well Name & Number: Beaver Creek Unit #6L ease: Notes: County or Parish: Cement retainer @ 10400' (1/21/96) State/Prov:I Frac stimulated the Tyonek D-1 TD F -M.,= 15,928' = 15,610' Angle @KOP and Depth: Cement retainer @ 11200' (1/17/96) Cement plug @ 11,360'- 11,560' CIBP @ 14647'capped w/ 200'cement (6/82) CIBP @ 15280' capped w/ 22' sand & cement (5/82) Maximum Deviation: interval (9866' - 9886') on 3/17/01. Placed 58,000 Ids of 20/40 Carbolite in 357 bbl of SuperRheogel in diesel. Date Completed: Well Name & Number: Beaver Creek Unit #6L ease: A - 028083 County or Parish: Kenai Peninsula Borough State/Prov:I Alaska C o untry:1 USA Angle @KOP and Depth: 1.0° @ 8,200' Angle/Perfs: 1°-16.5° Maximum Deviation: 16.50 @ 10,400' Date Completed: 03/24/03 Ground Level (above MSL): 158' 1 RKB (above GL): 27' Revised By: Donna Ambruz Downhole Revision Date: 1 518120141 Schematic Revision Date: 8/24/2018 y A l� ft 10 Suspended Well Inspection Review Report InspectNo: susGDC200210183459Z�f Date Inspected: 2/5/2020 ' Inspector: Guy Cook Type of Inspection: Initial Well Name: BEAVER CK UNIT 06 Date AOGCC Notified: 1/31/2020 Permit Number: 1811500 Operator: Hilcorp Alaska LLC Suspension Approval: Sundry # 318-301 Operator Rep: Andy Graves Suspension Date: 8/5/2018 Wellbore Diagram Avail? ❑D Location Verified? © Photos Taken? If Verified, How? Other (specify in comments) Offshore? ❑ Well Pressures (psi): Tubing: Fluid in Cellar? ❑O IA: 0 BPV Installed? ❑ OA: 0 VR Plug(s) Installed? ❑ Wellhead Condition Wellhead appeared to be in good condition. No signs of leaks or damage. The wellhead is blinded off at the top of the tubing spool. There were two gauges labled OA and OOA that were functional, but labeled incorrectly. They should have ✓ been labeled IA and OA. I pointed this out to the operator and asked them to be labeled correctly. Condition of Cellar Cellar was filled with water when I arrived, from snow melt, as they had a heater on the wellhead to make visual inspection easier. The cellar showed no signs of petroleum products. The water was sucked out of the cellar and I inspected the wellhead from ground surface level. Surrounding Surface Condition Good gravel pad covered in snow/ice with no signs of oil/fuel present. Comments J Location verified by map. The well has no tubing hanger in it to set a BPV into. The IA and OA did not have VR plugs installed, as per operator, and the well pressures are monitored. I did point out to the operator that the well is not very well protected from the elements and asked that they wrap or cover the well to protect it. Pictures of the well attached. Supervisor Comments Initial inspection was due not later than 8/5/2019 per 20 AAC 25.110 Friday, February 14, 2020 'U =y0 30 0 da C -0 O d N O Q � N N O 3 L � N d N Q 0 N N O) a C N U1 L N C Y cv C 3 0 c v u .� O N u c v Y M O M N f6 d • • �r / n _ fist ` z-- _6 333 Wet evenr'r Avenue "�'" GOVERNOR ERROR SEAN I \R\I Li Anchorage, Alaska 9950, 3572 *:'� Main. 907 217', 1433 �' FS>10.- ,A, 9C/ /`. 547' Stan Porhola i Operations Engineer SCANNED AUG1 92014 L Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas—Tyonek Undefined Gas Pools, BCU 06 Sundry Number: 314-187 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 0 ' Daniel T. Seamount, Jr. Commissioner DATED this day of March, 2014. Encl. ` STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations 0 • Perforate 0 • Pull Tubing0 • Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ Atter Casing❑ Other: ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development 2 • 181-150 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic El Service 1116.API Number. Anchorage,Alaska 99503 50-133-20346-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 237 ' Beaver Creek Unit(BCU)06 Will planned perforations require a spacing exception? Yes ❑ No ❑., 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028083 ' Beaver Creek/Beluga Gas Pool-Tyonek Undefined Gas • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 15,928 • 15,610 • 10,400 10,338 10,400';11,200';14,547'; 15,280' N/A Casing Length Size MD ND Burst Collapse Structural Conductor 58' 30" 58' 58' Surface 502' 20" 502' 502 Intermediate 4,022' 13-3/8" 4,022' 4,022 5,020 psi 2,260 psi Production 12,410' 9-5/8" 12,410' 12,228' 6,870 psi 4,750 psi Liner 3,534' 7" 14,980' 14,674' 12,460 psi 10,760 psi Liner 1,208' 5" 15,889' 15,572 10,140 psi 10,490 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: SS 2.875"; Tubing Grade: 6.4#I L-80; Tubing MD(ft): 6,218'; See Attached Schematic See Attached Schematic LS 3.500";VS 1.750" 9.3#/L-80;HO-70 8,987';9,866' Packers and SSSV Type: Baker GT Dual Pkr; Packers and SSSV MD(t)and ND(It): 5,852'MD-5,852'ND Baker 194 SAB Pkr;N/A 6,911'MD-6,911'ND;N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑., Exploratory ❑ Stratigraphic❑ Development Li Service ❑ 14.Estimated Date for 15.Well Status after propsed work: 04/01/14 Commencing Operations: Oil ❑ Gas 0 ' WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned 0 Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email sporhola@hilcorp.com Printed Name Stan PorholaolTitle Operations Engineer 2 Signature _�C�d7�`✓t----- Phone 907-777-8412 Date J/o/AI COMMISSION USE ONLY ` Conditions of approval: Notify Commission so that a representative may witness Sundry Number Plug Integrity ❑ BOP Test Er Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3coo rsz go f �(e f - RBDM MAY 10 2014 Spacing Exception Required? Yes ❑ No12( Subsequent Form Required: io — Y Q LI ,�' .,/) _ - APPROVED BY / 0 4 Approved by: COMMISSIONER THE COMMISSION Date: .. s // / /1 111 Submit Form and Form 10-403(Revised 10/2012)3' 'I r'A�p�OR .Itdao IAor 12 months from the date of approval. -)X0 ments/S)Dup�7licat /7 • . Well Prognosis Well: BCU-06 Mewls Alaska,LLQ Date:3/22/2014 Well Name: BCU-06 API Number: 50-133-20346-00 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: April 1st, 2014 Rig: Moncla 405 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 181-150 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824(M) AFE Number: 1421087 Current Bottom Hole Pressure: — 1,295 psi @ 9,844'TVD (Static survey March 2013 base perf 9,986' MD) Maximum Expected BHP: —3,450 psi @ 8,372'TVD (Estimated based on offset wells) Max. Allowable Surface Pressure: —2,613 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#6 was drilled as a Grass roots oil exploration well in 1981.The oil intervals were found to be unproductive and the well was plugged back to test gas intervals in the Sterling in 1982.The Sterling was cement squeezed and the well recompleted in the Tyonek in 1996.This Tyonek interval was fracture stimulated in 2001.A workover was performed in 2003 to turn the well into a dual completion in the Tyonek and the Upper Beluga.A coil tubing velocity string was run down the long string to the Tyonek interval.The velocity string was pulled and replaced in 2007/2008 to add perforations in the Tyonek.The well has been shut-in since December 2006. The purpose of this work/sundry is to plugback the Tyonek interval, squeeze off the Upper Beluga and recomplete the Lower Beluga in the 9-5/8" casing. otG Notes Regarding Wellbore Condition • Last tag(Long String)at 10,079' SLM on 3/21/13 w/a 1.00" Pump Bailer. Coiled Tubing Procedure: 1. MIRU Coiled Tubing, PT BOPE to 3,000 psi Hi 250 Low. a. Rig up on 3.5" Long-String. 2. RU 1.75" coil BHA. \)1)1 �Q 3. RIH and latch onto coiled tubing velocity string hanger. 1 Nk 4. POOH with 1.75" coiled tubing velocity string from 9,866' MD. u ,pyi►''�' 5. RD Coiled Tubing. 7� 6. Turn well over to production. Slickline Procedure: 1. MIRU Slickline, PT Lubricator to 3,000 psi Hi 250 Low. a. Rig up on 3.5" Long-String 2. RU 2.70"gauge ring, RIH and tag fill/obstruction at+/- 10,079'. 3. Move to 2.875"Short-String. 4. PT Lubricator to 3,000 psi Hi 250 Low. • Well Prognosis Well: BCU-06 Hilcorp Alaska,LL Date:3/22/2014 a. Rig up on 2.875"Short-String. 5. RU 2.25"gauge ring, RIH to tubing tail at+/-6,218'. 6. RD Slickline. WO Rig Procedure: 7. MIRU Moncla#405 WO Rig. 8. Circulate well with 8.4 ppg lease water down long-string and short-string. 9. Set BPV. ND Tree. 10. NU BOPE.Set BPV.Test to 250 psi Low/3,000 psi High, annular to 250 psi Low/1,500 psi High (hold each valve and test for 10-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Notify BLM 48 hrs in advance of BOP test. 11. Bleed any pressure off tubing. Pull BPV. a. Circulate well with 8.4 ppg lease water. 12. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. BOPE connection is 11" studded top for lubricator on top of annular. ` 13. RU 3.5"Tubing Punch. - 14. RIH and punch long-string tubing at+/-6,900' MD. POOH.`7 i .5 15. RU 3.5" Radial Torch. 6. RIH and torch cut long-string tubing at+/-6,895' MD. POOH. 17. MU landing joint to short-string and pull 10k tension over string weight on tubing hanger. 18. RU 2.875"Tubing Jet Cutter. 19. RIH and jet cut short-string tubing at+/-5,830' MD. SS I a. Have backup cutters on location if tubing does not part. 20. RD Eline. 21. MU landing joint to short-string and pull tubing hanger. 22. POOH and lay down 2-7/8" short-string tubing. a. Lay down injection nipple and control line. - 23. MU landing joint to long-string and pull 60k overpull to release B r GT Dual Packer at 5,852'. 24. SOOH and rack back 3-1/2"tubing. a. 3.5"Tubing above dual packer is L-80. Below dual packer is P-110. b. Lay down injection nipple and control line. c. Lay down Baker GT Dual Packer. 25. MU dual-tubing handling equipment. 26. POOH and lay down 2-7/8", rack back the 3-1/2". a. Patch in long string is 21.6' long. 27. PU 5-3/4"overshot and jars. _piss LCAN tir 28. RIH w/3-1/2"tubing to top of cut tubing at+/-6,895'. 29. Circulate well clean with 8.4 ppg lease water. 30. MIRU Slickline, PT lubricator to 3,000 psi Hi 250 Low. a. BOPE connection is 11" studded top for lubricator on top of annular. 31. RU 3.5" PX Plug. RIH to X-profile at 6,965'and set PX plug. POOH. 32. RD Slickline. 33. Engage cut tubing. 34. Release K-Anchor at 6,909'from Baker SAB packer by picking up and rotating to the right. 35. PU 75'and dump 50'of sand on top of packer. 36. SOOH. Rack back 3-1/2"tubing. Lay down overshot. 37. PU 9-5/8"CIBP. /38. RIH w/3-1/2"tubing and set CIBP at 6,200'. • Well Prognosis Well: BCU-06 Hilcorp Alaska,LI) Date:3/22/2014 39. Tag CIBP w/10k down. POOH. Lay down 6,200' of 3-1/2"tubing. 40. PU 9-5/8"Cement Retainer. PU 6,000'of 2-7/8"workstring. 41. RIH w/2-7/8"workstring and set Cement Retainer at 6,000'. ✓ 42. Tag retainer w/10k down.Circulate well clean w/8.4 ppg lease water. 43. Sting into retainer. Establish injection rates and pressures. ,A 44. Mix and pump 30 bb_ I c�st below retainer. / fv 45. Unsting out of retainer. Reverse circulate clean. ° 46. POOH. Rack back 2-7/8"workstring, and retainer setting tool. 47. PU an additional 3,100'of 2-7/8"workstring. Lay down remaining 3-1/2"tubing. 48. If unable to locate adequate new tubing hanger for existing wellhead. a. PU 9-5/8" RTTS and set at 100' using tubing. POOH. b. Test plug to 1,500 psi. c. ND BOPE. d. ND 11" attachement spool (11" recompletion spool). e. NU BOPE and shell test to 250 psi low/3,000 psi high (before weekly test). 49. Wait on cement(total wait time estimated at 18 hours). 50. PU 8.25" bit and 4-3/4" drill collars. 51. RIH and tag cement retainer. Circulate well clean w/8.4 ppg lease water. 52. Drill out cement retainer at 6,000'-and 200' cement to bridge plug. 53. RU and test squeezed perfs to 13.5 ppg EMW. ✓ 54. Drill out bridge plug at 6,200'. 55. RIH and tag sand plug. 56. Reverse circulate sand out of well.Tag top of SAB packer. POOH. Lay down drill bit. 57. PU packer mill. 58. RIH to SAB packer at 6,911'. v 59. Mill packer and chase to bottom. 60. Reverse circulate clean. 61. SOOH. Rack back 2-7/8"workstring. Lay down packer mill. 62. MU packer spear. 63. RIH w/2-7/8"workstring and spear packer. POOH. Lay down packer and 3-1/2"tubing tail. 64. PU 9-5/8" Cement Retainer. / 65. RIH w/2-7/8"workstring and set Cement Retainer at 9,100'. 66. Tag retainer w/10k down.Circulate well clean w/8.4 ppg lease water. 67. Sting into retainer. Establish injection rates and pressures. 68. Mix and pump 55 bbl cement below retainer. 5-q' 69. Unsting out of retainer. Reverse circulate clean. 70. POOH. Lay down the 2-7/8"workstring, and retainer setting tool. 71. PU completion w/WLEG,X-profile, Hydraulic Packer, and Chemical Injection Mandrel. 72. RIH w/3-1/2"tubing, drop RHBC prong, pressure up to 3,500 psi and set packer at+/-7,500'. 73. Test tubing to 3,500 psi for 30 min. �® 74. Test casing/packer to 2,000 psi for 30 min. 75. Set BPV. ND BOPE. NU tree. Pull BPV. 76. RD Moncla#405 WO Rig. 77. Turn well over to production. 78. Replace IA x OA pressure gauge if removed (9-5/8"x 13-3/8"). Slickline Procedure: 79. MIRU Slickline, PT Lubricator to 3,000 psi Hi 250 Low. 80. RIH and pull prong from RHBC plug. POOH. Well Prognosis Well: BCU-06 Hilcora Alaska,LL' Date:3/22/2014 81. RIH and pull dummy valve from lower gaslift mandrel. POOH. 82. RIH and pull dummy valve from the chemical injection mandrel. POOH. 83. RIH and set live valve in chemical injection mandrel. POOH. 84. RIH and set pocket protector in the lower gaslift mandrel. POOH. 85. RIH and pull RHBC plug body from X-profile. POOH. 86. RIH w/2.5"x20' dummy gun and tag PBTD. POOH. Nitrogen Procedure: 1. MIRU Nitrogen Pumping Unit. RU flowback tank w/gas buster. 2. RU lines to annulus valve. PT Lines to 3,000 psi Hi 250 Low. 3. Pump Nitrogen down the casing and displace 6%KCI thru the lower gaslift mandrel and up the tubing into flowback tank. a. Estimated volume of displaced 6% KCI is 525 bbl. b. Leave 2,500 psi Nitrogen pressure on the tubing. 4. Rig down Nitrogen Pumping Unit. E-line Procedure: 5. MIRU E-line, PT Lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 6.5" OTIS. 6. RU 2.50" 6 spf HC wireline guns(will use 2 each 13'guns for 12 spf shot density). 7. Bleed tubing pressure down to below 2,400 psi,as directed by Reservoir Engineer. 8. RIH and perforate the Lower Beluga from 8,373'-8,386' (2 runs,total of 12 spf). a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using SLB DIL log dated 3/4/82. (Tie-in log depth is 8,373'-8.386'). ✓ d. Record tubing pressures before and after each perforating run. e. Distance to nearest well open in same sands=1,600'to BCU-19. f. Spacing allowance is based on CO 237,no closer than 1,320'. 9. RD E-line. 10. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic , Beaver Creek #6 ACTUAL Pad 3 • 1,164' FNL, 1,487' FWL SCHEMATIC Ifilcorp Alaska,LLC Sec. 34, T7N, R10W, S.M. Permit#: 181-150 API#: 50-133-20346-00-00 Surface Casing(Orin RKB) Property Des: A-028083 13-318•' N-80 68ppf BTC • KB Evelation: 179'above MSL 72ppf BTC KB: 27' (original) Ts Bottom KB: 21' (workover 2003) MD 0' 4,,0 2 ND 0' 4,022' Spud Date: 3/4/2003 . Baker Infection Nipple Cmt wl 2,400 sks of Class G Rig Released: w/dual checks,and 1/4" OD,0.049"wall SS control line Production Casing(Orig RKB1 VI SS-1162' 9-5/8" N-80 BTC Tree con=3-1/2"EUE 8rd 7TE` - • LS-1203' Tos opgm 3",5-bolt crescent flange cap • _� MD 0' 5,754' N-80 47ppf Lift threads=3.725"MCA •"a est" ' MD 5,754' 6,355' C-75 53.5ppf - MD 6,355' 6,983' N-80 53.5ppf MD 6,983' 6,985' Cementing stage tool , MD 6,985' 8,565' N-80 53.5ppf Sqz perfs 5,095'-5,184' - 4`'LMD 8,565' 9,615' P-110 47ppf tested to 14.1 ppg EMW # s!J MD 9,615' 12,410' P-110 53.5ppf • ND 0' 12,228' - - ____________----V - Cmt wl 3,388 sks of Class G Baker GT dual packer @ 5,852' (1,588 sks 1st Stage, 1,800 sks 2nd Stage) with 60K shear ring Shortstrina(WO RKB1 f, 13` a r Liner(Orin RKB) 2-7/8" L-80 6.4ppf EUE 8rd-Mod Tubing /I f f., 7'• P-110 32 ppf BTC r✓ (/«t///"'""" Toe Bottom -Baker injection nipple @ 1,162' =•. • • MD 11,446' 14,980' -GT dual packer @ 5,852' S''' wND 11,326' 14,674' -X-nipple at 5904' Cmt wl 652 sks of Class G ID=2.313" . 1 4 Wireline re-entry guide©6,218' / ti• 7 Liner(Orin RKB) V t . ✓ 5" N-80 18 ppf BTC Toe Bow y'� ' MD 14,681' 15,889' TU�� K p ND 14,387' 15,572' Cmt w/450 sks of Class G ' Lonastrina IWO RKB) :� ;� p 3.5" L-80 9.3ppf EUE 8rd-Mod Tbg Beluga trina Perfs: .S 94 D('Note: P-110 tubing between dual packer and SAB packer at 6,911'. 6,018'-6,031' (6017-6031'NO)UB-3 ' . I '•f q� 6,080'-6,095' (6080-6095'TVD)UB-3 .; i(r -Baker injection nipple @ 1203• Pressure response after firing gun. - -Baker GT Dual packer @ 5852' 6,112'-6,118' (6112-6118'TVD)UB-4 a- �y O H -CMU sliding sleeve @ 6254' 6,125'-6,134' (61255134'ND)UB-4 =r c J ID=2.813" 6,140'-6,149' (6140-6149'ND)UB-4 , 10'Seal assembly(OD=4.00") 6,165'-6,179' (61655179'TVD)UB-4 -80-40 K-Anchor @@ 6909' . -Baker 194 SAB 40x32 Packer @ 6911' Lonastrina Perfs: Fill at 10,079'(3/21/13) ID=3.250" Tyonek -Camco X-Nipple @ 6965' 9,120'-9,155• (9107-9141'ND)6 spf (12/1996) ID=2.813" 9,120'-9,155' (9107-9141'TVD)6 spf (2/1997) -Cameo X-Nipple @ 8962' 9,120'-9,140' (9107-9126'ND)6 spf 60°phased PBTD ID=2.813'• -PX plug set 314103 (1/1612008) 11,111MD =10,400' -Wireline Re-Entry @ 8987' 2-1/8" Owen ShoGun NTX charges -, - TVD=10,338' 9,140'-9,155' (9126-9141'TVD)6 spf 60°phased e Velocity String Tubing(hung from surface) (1116/2008) 1.75" coil tubing 2-118. Owen ShoGun NTX charges - - The velocity string blocks access to the permanent 9,866'-9,886' (9824-9844'ND)6 spf (214/1996) _ ® longstring completion jewelry shown to the right. 9,866'-9,886' (9824-9844'ND)6 spf 60°phased 2.25"ID Patch in longstring from 6161 to 6182.6 MD (1115/2008) Coil-1.75.OD,flash free,0.125"wall,HO-70 grade 2-1/8" Owen ShoGun NTX charges MD= 0'-9866' Inactive Perfs: ' Straightening bar and landing nipple at the coil • Sterling(above the dual packer): �.'i'. ' - 5,095'-5,115' (5095-5115'TVD) (sqi d 3/03)B-3 5,132'-5,142' (5132-5142'TVD) (sqz'd 3/03)8-3 __ 5,174'-5,184' (5174-5184'ND) (sqz'd 3/03)B-3A G-Zone: 1 L 15,170'-15,200' (14,858-14,887'ND) 15,085'-15,128' (14,775-14,817'TVD) • • F 15,003'-15,050' (14,696-14,742'TVD) T Ote : Hemlock: ;i a; Cement retainer @ 10400'(1/21/96) Frac stimulated the Tyonek D-1 15,520'-15,546' (15,204-15,230'TVD) - Cement retainer @ 11200'(1/17/96) interval(9866'-9886')on 15,476'-15,506' (15,160-15,190'TVD) TD Cement plug @ 11,360'-11,560' 3/17/01. Placed 58,000 lbs of 15,414'-15,466' (15,099-15,131'ND) MD =15,928' CIBP @ 14647'capped w/200'cement(6/82) 20/40 Carbolite in 357 bbl of 15,387'-15,407' (15,072-15,092'TVD) ND=15,610' CIBP @ 15280'capped w/22'sand&cement(5/82) SuperRheogel in diesel. 15,345'-15,370' (15,030-15,055'ND) 15,306'-15,326' (14,992'-15011'ND) - __ _ Well Name&Number: Beaver Creek Unit#6 Lease: A-028083 • County or Parish: Kenai Peninsula Borough - State/Prov: Alaska Country:I USA Angle©KOP and Depth: 1.0°@ 8,200' Angle/Perfs: I 1°-16.5° Maximum Deviation: 16.5°(®10,400' Date Completed: 03/24/03 Ground Level(above MSL): 158' RKB(above GL) 27' Revised By: Stan Porhola Downhole Revision Date: 3/21/2013 Schematic Revision Date 3/24/2014 _. _._ • IIBeaver Creek #6 Pad 3 PROPOSED 1,164' FNL, 1,487' FWL SCHEMATIC Hamra I I r Sec. 34, e T7N R1 OW, S.M. Conductor Casing(Oriq RKB) 30" Permit#: 181-150 Tom Bottom API#: 50-133-20346-00-00 MD 0' 58' Property Des: A-028083 ND t 58' WO KB Evelation: 179'AMSL Driven to Recusal Oriq KB:27' (original 1982) WO KB: 21' (workover 2003) 1 Su20ace Casing(Orig RKB) Spud Date: 11/19/1981 rot Bottom Riq Released:6/19/1982 MD 0' 502' Z 111MD 0' 502' Cmt wl 1,500 sks of Class G 3 II l� Top job from 42' Tree con:6-1/2"Otis Intermediate Casing(Oriq RKB) Sqz perfs 5,095'-5,184' MINT 13-318" N-80 68ppf BTC tested to 14.1 ppg EMW • 72ppf BTC Tom Bottom MD 0' 4,022' Completion Assembly(WO RKB) 4 ND 0' 4,022' Includes: i. Cmt w/2,400 sks of Class G 1-Gaslift Mandrel,1,500'MD G•,� 2-Chemical Injection Mandrel,1,750'MD "" Production Casing(Oriq RKB) /0 3-Gaslift Mandrel,3,000'MD 5 I'I 4-Gaslift Mandrel,4,500'MD �'l,6 1 ®1 9-5/8" N- TC 70 80 Bottom 5-Gaslift Mandrel,6,000'MD 1 6-Gaslift Mandrel,7,400'MD - Ill MD 0' 5,754' N-60 47ppf 6 )7 MD 5,754' 6,355' C-75 53.5ppf 7-DLH Hydraulic Packer,7,500'MD ti; o. ^, MD 6,355' 6,983' N-60 53.5ppf 8-X-Profile,7,517'MD lal 'fit t K'''-c MD 6,983' 6,985' Cementing stage tool 9-WLEG,7,530'MD I 1 /ca. �PAI MD 6,985' 8,565' N-80 53.5ppf -Cement Retainer,9,100'MD 7 J MD 8,565' 9,615' P-110 47ppf 7 _ _ 'td MD 9,615' 12,410' P-110 53.5ppf ad ND 0' 12,228' "w Cmt wl 3,388 sks of Class G Sqz perfs 6,018'-6,179' (' ) I (1,588 sks 1st Stage, 1,800 sks 2nd Stage) tested to 13.5 ppg EMW , 1=I • I Liner(Oriq RKB) Last i_g: 7" P-110 32 ppf BTC SLM To Bottom r MD 11,446' 14,980' Tool ND 11,326' 14,674' Date 3g(1 Cmt wl 652 sks of Class G Shortstrinq Perfs: / �3Liner(Oda RKB) Beluga = _ LB 31 /- 014.- 5" N-80 3p 18 ppf BTC Tom Bottom 6,018'-6,031' (6017-6031'ND) UB-3t MD 14,681' 15,889' 6,080'-6,095' (6080-6095•ND) UB-3 • 10 ► ► ND 14,387' 15,572' Pressure response after firing gun. - Squeeze 55 bbl ementr Cmt wl 450 sks of Class G Q 6,112'-6,118' (6112-6118'ND) UB-4 - - C below retainer 1 co 6,125'-6,134' (6125-6134'ND) UB-4 r t= 6,140'-6,149' (6140-6149'ND) UB-4 , 6,165'-6,179' (6165-6179'ND) UB-4 . - Tubing IWO RKB) , -112" L-80 9.3 ppf 8RD Longstrinq Perfs: ' Fill at 10,105'(5/19/07) Top Bottom Tyonek MD 0' 7,530' 9,120'-9,155' (9107-9141'ND)6 spf (1211996) )- - }? ND 0' 7,530' 9,120'-9,155' (9107-9141'ND)6 spf (211997) 9,120'-9,140' (9107-9126'ND)6 spf 60°phased " PBTD (1116/2008) �? A MD =10,400' 2-1/8" Owen ShoGun NTX charges ,1. • ND=10,338' 9,140'-9,155' (9126-9141'ND)6 spf 60°phased l" W1612008) , " 1 lIl 2-1/8" Owen ShoGun NTX charges �`. 9,866'-9,886' (9824-9844'ND)6 spf (2/4/1996) 9,866'-9,886' (9824-9844'ND)6 spf 60°phased - Perforations: (1/15/2008) , 1 Zone MD ND Size SPF Date 2-1/8" Owen ShoGun NTX charges 8. Inactive Perfs: LB-31 8.373'-8.386' 8,372'- 385' 2-1/2" 12 Proposed Sterling(above the dual packer): 5,095'-5,115' (5095-5115'ND) (sqi d 3/03)B-3 • 5,132'-5,142' (5132-5142'ND) (sqi d 3103)B-3 - 5,174'-5,184' (5174-5184'ND) (sqi d 3103)B-3A • - G-Zone: , L 15,170'-15,200' (14,858-14,887'TVD) . 15,085'-15,128' (14,775-14,817'ND)- , 15,003'-15,050' (14,696-14,742'ND) - , : Notes: Hemlock: *;- Cement retainer @ 10400'(1/21/96) Frac stimulated the Tyonek D-1 15,520'-15,546' (15,204-15,230'ND). + Cement retainer @ 11200'(1/17/96) interval(9866'-9886')on 15,476'-15,506' (15,160-15,190'ND)- TD Cement plug @ 11,360'-11,560' 3/17/01. Placed 58,000 lbs of 15,414'-15,466' (15,099-15,131'ND)• MD =15,928' CIBP @ 14647'capped w/200'cement(6/82) 20/40 Carbolite in 357 bbl of 15,387'-15,407' (15,072-15,092'ND)- ND=15,610' CIBP @ 15280'capped w/22'sand&cement(5/82) SuperRheogel in diesel. 15,345'-15,370' (15,030-15,055'ND) • 15,306'-15,326' (14,992'-15011'ND) - Well Name&Number: Beaver Creek Unit#6 Lease: A-028083 • County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:) USA Angle @KOP and Depth: 1.0°@ 8,200' Angle/Perfs: I 1°-16.5° Maximum Deviation: 16.5°l10,400' Date Completed: 03/24/03 Ground Level(above MSL): 158' RKB(above GL): 27' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date 3/24/2014 • , : ll Beaver Creek Moncla #405 BOP 3/12/2014 IIilrorp ‘1,1.1.a.ITC 1 WWI 3.98' Pp Hydril GK 11"-5000 All Ill !Wind liii ii LULU[1:_11 411 C6U lap. 2 7/8 -5 variables 4.54' 2m1111611111$111 m, 11."- 5000II �: Blind II * .7,= _La1111 iifill�ll al 2 1/16 5M Choke and Kill Valves 2.00' 10 �S. r -111'! 0- ,iiiiiiiu M Marathon MARATHON Oil Company February 5, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Beaver Creek Well: Beaver Creek #6 Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~,~ MAR ~ ~ 2008 ~~~ ~~` Attached for your records is the Sundry Report 10-404 for BC - 6 well. This sundry covers the Tyonek reperforating work performed under sundry # 307-269. The coil tubing velocity string was inspected, while removing it, in order to perform the reperforating operation. Signs of metal fatigue were apparent, so the tubing was replaced with a flash free designed tubing utilizing the same specifications of as the initial tubing. BC - 6 has not responded to the aforementioned operation. This is represented in section 13 of the 10-404 Sundry Report. Please contact us at (907) 283 -1371 if you have any questions or need additional information. Sincerely, ~~~-~ s,~ Kevin J. Skiba Production Technician Enclosures: 10-404 Sundry Report cc: Houston Well Fife Operation Summary Kenai Well File Current Well Schematic KJS DMD ~`~'f~'~ ' r STATE OF ALASKA '~~~8 ~i'~ ALA• OIL AND GAS CONSERVATION C M~SI N ~'`~~ O O ~~ REPORT OF SUNDRY WELL OPERATIONS ~ ~0 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Removed & Performed: Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver^ Time Extension ^ replaced velocity Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-enter Suspended Well ^ string 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development ~ Exploratory^ 181-150 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20346-00-00 7. KB Elevation (ft): 9. Well Name and Number: 21' Beaver Creek #6 - 8. Property Designation: 10. Field/Pool(s): `" F~ A - 028083' Beaver Creek Field /Beluga 8~ T onek Pools 11. Present Well Condition Summary: Total Depth measured 15,928' ~ feet Plugs (measured) 10400', 11200', 14647', 15280' true vertical 15,610' ~ feet Junk (measured) NA Effective Depth measured 10,400' ~ feet true vertical 10,337' ~ feet Casing Length Size MD TVD Burst Collapse Structural 0 0 0 0 0 0 Conductor 0 0 0 0 0 0 Surface 4,022' 13-3i8" 4,022' 4,022' 3,450 / 5,380 1,950 / 2,670 Production 12,410' 9-5/8" 12,410' 12,228' Multiple String Multiple String Liner 3,534' 7" 14,980' 14,674' 12460 10760 Liner 1,208' 5" 15,889' 15,581' 13940 13450 Perforation depth: Measured depth: 6,018' - 9,886' gross True Vertical depth: 6,017' - 9,843' gross SS: 2.875" L-80 6.4# 6,218' Tubing: (size, grade, and measured depth) LS: 3.500" L-80 9.3# 8,987' VS: 1.750" H070FF 9,866' Packers and SSSV (type and measured depth) Baker GT Dual packer w/ 60K shear ring 5,852' Baker 194 SAB 40x32 Packer 6,911' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 3 Subsequent to operation: 0 0 0 0 3 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ^Q Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil^ Gas Q WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-269 Contact Kevin Skiba (907) 283-1371 Printed Name Dennis M. Donovan Title Production Engineer Signature ~ Phone (907) 283-1333 Date February 5, 2008 Form 10-404 Revised 04/2006 ~~(r 4~~~~ r t~`~~ ~~~ Submit Original Only • lit #: 181-150 I_ 50-133-20346-00-00 ertv Des: A-028083 velation: 179' above MSL 27' (original) 21' (workover 2003) I Date: 3/4/2003 Tree cxn = 3-1/2" EUE 8rd 3", 5-bolt crescent flange cap Litt threads = 3.725" MCA ~ Sqz perfs 5,095'-5,184' ~ ~', tested to 14.1 ppg EMW Baker GT dual packer @5852' with 60K shear ring -~~ Beaver Creek #6 Pad 3 1,164' FNL, 1,487' FWL Sec. 34, T7N, R10W, S.M. L-80 6.4ppf EUE 8rd-Mod Tubing -Baker Injection nipple Q 1,162' -GT dual packer Q 5,852' -X-nlpple at 5904' ID = 2.313" -Wireline re-entry guide Q 6,218' Beluga 6,018' - 6,031' 6,080' - 6,085' Pressure response after firing gun. 6,112'- 6,118' 8,125' - 6,134' 8,140'- 6,149' 6,165'- 6,179' 8,120'- 9,155' 6 spf (1211996) 8,120'- 9,155' 6 spf (211997) 9,120'- 9,140' 2-118" 60° phased (111612008) Owen ShoGun NTX charges 9,140'-8,155' 2-118" fi0°phased (111 612 0 0 8) Owen ShoGun NTX charges 9,866' - 8,886' 6 spf (21U1996) 9,886'-9,886' 2.116" 60° phased (111512008) Owen ShoGun NTX charges lerling (above the dual packer): 5,095' - 5,115' (sgz'd 3103) 5,132' - 5,142' (sgz'd 3103) I 5,174' - 5,184' (sgz'd 3/03) 15,170' - 15,200' 15,085' - 15,128' 15,003' - 15,050' 15,520' - 15,546' 15,476'- 15,506' 15,414'- 15,466' 15,387' - 15,407' 15,345' - 15,370' Baker Infection NioDle w/dual checks, and 1/4" OD, 0.049" wall SS control line SS -1162' LS - 1203' • M MARATNOM Surlace Casind 13.318" N-80 68ppf BTC 72ppf 8TC Typ Bottom MD 0' 4,022' TVD 0' 4,022' Cmt wl 2,400 sks of Class G 9-518" N-80 BTC Tqp Bo m MD 0' 5,754' N-80 47pp1 MD 5,754' 6,355' C-75 53.5ppf MD 6,355' 6,983' N-80 53.5ppf MD 6,983' 6,985' Cementing stage tool MD 6,985' 8,565' N-80 53.Sppf MD 8,565' 9,615' P-110 47pp1 MD 9,615' 12,410' P-110 53.Sppf TVD 0' 12,228' Cmt wl 3,388 sks of Class G (1,588 sks 1st Stage, 1,800 sks 2nd Stage) Liner 7" P-110 32 ppf BTC Jsg Bottom MD 11,446' 1d,980' TVD 11,326' 14,674' Cmt wl 652 sks of Class G Liner 5" N-80 18 ppf BTC Tgp Bo om MD 14,681' 15,889' TVD 14,387' 15,572' Cmt w1450 sks of Class G Fill at 10,105' (5/19/07) PBTD MD = 10,400' TvD =10,338• 3.5" L-80 9.3ppf EUE 8rd-Mod Tbg Note: P-110 tubing between dual packer and SAB packer at 6,911'. -Baker Injection nipple Q 1203' -Baker GT Dual packer Q 5852' -CMU sliding sleeve Q 6254' ID = 2.813" 10' Seal assembly (OD = 4.00") -80.40 K-Anchor Q 6909' -Baker 194 SAB 40x32 Packer Q 6911' ID = 3.250" -Camco X-Nipple Q 6965' ID = 2.813" -Camco X-Nipple Q 8962' ID = 2.813" - PX plug set 314!03 -Wireline Re-Entry Q 8987' Velockv Slrine Tubino (hung from surface) 1.75" coil tubing The velocity string blocks access to the permanent longstring completion Jewelry shown to the right. 2.25" ID Patch in longstring from 6161 to 6182.6 MD Coil - 1.75" OD, flash free, 0.125" wall, HO-70 grade MD= 0'-9866' Straightening bar and landing nipple al the coil tubing tall at 9666' ID = 1.268" ) Notes: -~ - I Cement retainer @ 10400' (1/21/96) Frac stimulated the Tyonek D-1 TD L Cement retainer @ 11200' (1/17/96) interval (9866' - 9886') on MD = 15 928' Cement plug @ 11,360' - 11,560' ' 3/17/01. Placed 58,000 Ibs of , TVD - 15 610' CIBP @ 14647 capped w/ 200' cement (6/82) ' ' 20/40 Carbolite in 357 bbl of , CIBP 15280 ca ed w/ 22 sand & cement 5/82 @ PP ( ) SuperRheogel in diesel. Well Name & Number: Beaver Creek 6 Lease: Beaver Creek Field Municipalit Kenai Penisula Borou h Stale: Alaska Countr : USA Perforations MD : 6,018' - 9,886' TVD : 6,018' - 9,844' An le KOP and Depth: 2° / 100 ft 8,300' An le/Pens: Dated Completed: 3124/2003 Prepared B : Kevin Skiba Last Revison Date: 2/5/2008 • • Marathon Oil Company Page ~ of 5 :.Operations Summary Report Legal Well Name: BEAVER CREEK 06 Common Well Name: BEAVER CREEK 06 Spud Date: 11/21/1981 j '.Event Name: WORKOVER Start: 11/17/2007 End: 12/25/2007 Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Sub ~ ' Date From - To .Hours Code Code Phase Description of Operations ~ 11/17/2007 10:00 - 11:00 1.00 SAFETY MTG_ WBPREP MIRU wire line unit. Held PJSM and discussed operations with crew. Uptain work permit prior to start up. 11:00 - 12:15 1.25 RURD SLIK WBPREP MU 1.0" tool string with 1.25" GR. PT lubricator to 2500 psig, had leak. ~ i Shut pull the connection re-tape, MU to tree. Retest good test. 12:15 - 14:10 1.92 WORK SLIK WBPREP Open well RIH tagged top of plug at 9896' KBD. POOH. 14:10 - 14:45 0.58 DUMPB CMT_ WBPREP MU bailer to tool string, RIH to top of plug. Dump cement. POOH 14:45 - 15:20 0.58 DUMPB CMT_ WBPREP OOH, RIH to 9886' KBD. Dump cement. POOH ~ 15:20 - 17:30 2.17 RURD_ SLIK WBPREP Rig back wire line unit. Clean up around well head. PWS left lease 11/29/2007 08:00 - 09:00 1.00 SAFETY MTG_ CMPPUL Arrive Beaver Creek prod. office, obtain permit, review JSA for rig up. ~ 09:00 - 11:00 2.00 PREP_ LOC_ CMPPUL Prep location, remove wellhouse: 11:00 - 14:30 3.50 RURD_ COIL CMPPUL MIRU coil unit, tanks, flow back equip. 14:30 - 14:40 0.17 RURD_ COIL CMPPUL Notified Jim Regg @ AOGCC of BOPE test scheduled for 10:00 on 11/29/07, Mr. Regg said to consider test waived if not notified by inspector at end of working day. 14:30 - 17:00 2.50 SECUR WELL CMPPUL Secure well and location for night. Turn in permit. 11/30/2007 07:30 - 08:00 0.50 SAFETY MTG_ CMPPUL Objective of work: Lift velocity string and try to determine cause of annular communication. Arrive Beaver Creek prod. office, obtain permit, review JSA for pulling V.S. 08:00 - 10:30 2.50 RURD_ COIL CMPPUL Move in ops. cab, hook up all hydraulics. 10:30 - 11:00 0.50 TEST_ BOPE CMPPUL Function test hydraulics on BOPE's. 11:00 - 12:30 1.50 TEST_ BOPE CMPPUL Begin BOPE test. 12:30 - 14:00 1.50 TEST_ BOPE CMPPUL Well head valves leaking to much to get a test on BOPEs, call out Vetco to grease valves. M/U dimple CTC to 1.75" stinger while waiting. 14:00 -14:55 0.92 SERVIC EOIP CMPPUL Vetco on location to service tree valves. 14:55 - 16:05 1.17 TEST BOPE CMPPUL Resume BOPE test, starting w/ blinds. 16:05 - 16:25 0.33 SAFETY MTG_ CMPPUL ROPE test complete, review JSA for pulling V.S. 16:25 - 17:00 0.58 PULD ! BHA_ CMPPUL P/U injector, m/u 3" GS spear 17:00 - 17:15 0.25 TEST_ EOIP CMPPUL Go to well w/ injector, PT Bowen connection to 1500psi. 17:15 - 18:30 1.25 ENGAG FISH CMPPUL Open well and rih to latch hanger mandrel.Latch fish, pull 34k, no movement. Discuss w/ Vetco hand. Make phone calls. Decide to regroup and comeback in A.M. 18:30 - 19:00 0.50 SECUR WELL CMPPUL Secure well for night.Tum in permit. 12/1/2007 07:30 - 08:00 0.50 SAFETY MTG_ CTBG Arrive Beaver Creek prod. office, obtain permit, review JSA for BOPE test. 08:00 - 10:30 2.50 RURD_ COIL CTBG Move in ops. cab, hook up all hydraulics. 10:30 - 11:00 0.50 RURD_ COIL CTBG Function test hydraulics on BOPE's. 11:00 - 12:30 1.50 TEST_ BOPE CTBG Begin BOPE test. 12:30 - 14:00 1.50 RURD_ COIL CTBG Well head valves leaking to much to get a test on BOPEs, call out Vetco to grease valves. M/U dimple CTC to 1.75" stinger while waiting. 14:00 - 14:55 0.92 SERVIC EOIP CTBG Vetco on location to service tree valves. 14:55 - 16:05 1.17 TEST_ BOPE CTBG Resume BOPE test, starting w/ blinds. 16:05 - 16:25 0.33 SAFETY MTG_ CTBG BOPE test complete, review JSA for pulling V.S. 16:25 - 17:00 0.58 PULD_ BHA_ CTBG P/U injector, m/u 3" GS spear 17:00 - 17:15 0.25 TEST_ EOIP CTBG Go to well w/ injector, PT Bowen connection to 1500psi. 17:15 - 18:30 1.25 ENGAG FISH CTBG Open welt and rih to latch hanger mandrel.Latch fish, pull 34k, no movement. Discuss w/ Vetco hand. Make phone calls. Decide to regroup and comeback in A.M. 18:30 - 19:00 0.50 SECUR WELL CTBG Secure well for night.Turn in permit. 12/2/2007 08:00 - 08:45 0.75 TRAVEL TRCK CMPPUL Load up. Drive to Beaver Creek 08:45 - 09:15 0.50 RURD_ SLIK CMPPUL Sign in. spot !warm equipment 09:15 - 09:30 0.25 SAFETY MTG CMPPUL JSA Printed: 1/31/2008 8:18:03 AM • Marathon Oil Company Page 2 of 6 Operations Summary Report Legal Well Name: BEAVER CREEK 06 Common Well Name: BEAVER CREEK 06 Event Name: WORKOVER Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date From - To Hours Code Code Phase 12/2/2007 09:30 - 11:00 1.50 RURD SLIK CMPPUL 11:00 -11:25 0.42 TEST_ ROPE CMPPUL 11:25 -13:00 1.58 TRIP_ TOOL CMPPUL 13:00 -19:00 6.00 LOG_ OTHR CMPPUL 19:00 -19:15 0.25 LOG_ OTHR CMPPUL 19:15 - 19:30 0.25 RURD_ SLIK CMPPUL 19:30 - 20:30 1.00 TRAVEL TRCK CMPPUL 20:30 - 21:00 0.50 TRAVEL TRCK CMPPUL 12/5/2007 08:00 - 09:00 1.00 TRAVEL TRCK CMPPUL 09:00 - 11:00 2.00 WAITON WTHR CMPPUL 11:00 - 14:00 3.00 SECUR WELL CMPPUL 14:00 - CMPPUL 1216!2007 08:00 - 09:45 1.75 TRAVEL TRCK PLUGAB 09:45 -11:00 1.25 RURD SLIK PLUGAB 11:00 - 13:00 2.00 SETREL PLUG PLUGAB 13:00 - 14:00 1.00 WAITON CMT_ PLUGAB 14:00 - 14:30 0.50 PUMP_ CMT PLUGAB 14:30 - 15:45 1.25 DUMPS CMT_ PLUGAB 15:45 - 16:30 0.75 DUMPS CMT_ PLUGAB 16:30 -17:42 1.20 DUMPS CMT_ PLUGAB 17:42 - 18:25 0.72 DUMPS CMT_ PLUGAB 18:25 - 20:00 1.58 TRAVEL TRCK PLUGAB 1/5/2008 07:30 -08:30 1.00 SAFETY MTG_ CTBG 08:30 -13:25 4.92 RURD_ COIL CTBG 13:25 - 15:00 1.58 RURD COIL CTBG tL~ ~ ~ 15:00 -16:35 1.58 TEST_ BOPE CTBG 16:35 -17:00 0.42 SECUR WELL CTBG ,, ~~-'~+ 118/2008 08:00 - 09:30 1.50 SAFETY MTG CMPPUL 09:30 -12:00 2.50 RURD COIL CMPPUL 12:00 -12:30 0.50 RUNPU COIL CMPPUL 12:30 -15:00 2.50 RUNPU COIL CMPPUL 15:00 - 17:20 2.33 PUMP_ WTR CMPPUL 17:20 - 17:30 0.17 RURD_ COIL CMPPUL 17:30 -19:00 1.50 SECUR WELL CMPPUL 1/9/2008 07:30 - 09:15 1.75 SAFETY MTG CMPPUL 09:15 - 09:35 0.33 RURD_ COIL CMPPUL 09:35 -10:28 0.88 RURD COIL CMPPUL 10:28 - 10:55 0.45 RURD_ COIL CMPPUL 10:55 - 10:56 0.02 RURD_ COIL CMPPUL 10:56 - 11:05 0.15 RURD_ COIL CMPPUL 11:05 - 11:13 0.13 RURD_ COIL CMPPUL 11:13 - 11:45 0.53 RURD_ COIL CMPPUL 11:45 - 11:50 0.08 RURD_ COIL CMPPUL 11:50 - 12:00 0.17 RURD_ COIL CMPPUL 12:00 - 13:10 1.17 RURD_ COtL CMPPUL 13:10 - 14:20 1.17 RURD_ COIL CMPPUL Spud Date: 11/21/1981 Start: 11/17!2007 End: 12!25/2007 Rig Release: Group: Rig Number: 1 Description of Operations Rig up wrireline. Stand by for Pat (supervisor). Stab on Pressure test RIH w/ 1.22" LIB to set doom at 9870'. POOH. Impression of standing valve. Bleed well down and flow. Wait for well to stabilize. RIH w/ Pressure temp gauge to 0', stop for 3 min. continue in hole to 19,060'. Stop for 10 min. POOH to 0' stop for 3 min. aN at 60'/min. Download data. Rig down wireline. Road equipment to PWL. Fuel equipment End ticket for 12/01/07 Arrive at shop. Pick up equipment & cxew Stand by for wind Shut down for day. Went to leave -noticed diesel dripping off unit (fuel line Depart Beaver Creek Arrive at shop. Pick up equipment. Arrive at Beaver Creek. Sign in. JSA -permit. Spot unit Rig up siidcline RIH w! 1" SB w/ modified cement retainer (Steve Barrow & G & G machine shop design) to 9864' wrl -tap down -shear off -POOH. Stand by for cement Mix cement as per instructions RIH w/ 1.25" Dump bailer (15' long} to 9864' wl. Dump -POOH -good RIH w/ same to same -same -did not shear RIH w/ same to same -same -POOH -good RIH w/ same to same -same -POOH -good Rig down JSA -return to shop Arrive Beaver Creek prod. office, obtain permit, review JSA for BOPE test. RU CT unit. Function test hydraulics on BOPE's. Test BOP 2501500 psi. Good test Secure well for night.Tum in permit PJSM. Obtain Hot Work Permit. Discuss job scope. Start equipment PU BHA to latch v-string. Injector to well RIH (tree) and latch V-string. PU v-string. Hang off in slips and release GS. Kill well down CT and Prod tubing with 200 bbis KCI Freeze protect CT and tree with McOH. Secure well. Tum in permit. Sign out leave location. PJSM. Obtain Hot Work Permit Discuss job scope. Start equipment Bleed pressure off well. Tubing pressure 340 psi. Close choke. Monitor tubing. WHP 0 Bleed off 1-3/4"x 3-1/2" annulus. 305 psi. Close choke. Monitor annulus. 0 Open up to V-sMng. 305 psi. Pressure 291 bleed aff V-string. WHP 0. Close choke and monitor WHP and annulus. WHP 110 psi., annnlus 16 psi. Bleed off V-string and annulus to zero. Monitor pressure on V-string and annulus. Zero. Remove night cap. PU injector assembly from craddie and set on ground. Stab coil over goose neck and into injector asmbly, Printed: 3!3/2008 1:14:07 PM • Marathon Oil Company Page 3 of 6 Operations Summary Report ~~ Legal Well Name: BEAVER CREEK 06 Common Well Name: BEAVER CREEK 06 Spud Date: 11!21!1981 Event Name: WORKOVER Start: 11/17/2007 End: 12/25/2007 Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date I From - To I Hours ~ Code I Code I Phase I Description of Operations 1 /9/2008 14:20 - 15:00 15:00 - 15:30 1/11/2008 07:00 - 08:00 08:00 - 09:15 09:15 - 09:30 09:30 - 09:35 09:35 -10:15 10:15 -10:45 10:45 -10:55 10:55 -11:30 1!13/2008 11:30 -11:55 11:55 -12:00 12:00 -12:05 12:05 -13:50 13:50 - 14:20 14:20 - 15:00 15:00 - 15:30 15:30 -19:15 19:15 - 19:30 08:30 - 09:30 09:30 - 10:30 10:30 -11:00 1:00 - 12:20 12: -12:50 12:50 - 0 14:20 - 16:00 0.67 RURD_ COIL CMPPUL MU lubricator. Prep coil end. Apply Roll-on connector. 0.50 SECUR WELL CMPPUL Install night cap and pressure test Secure well and loc for the night. 1.00 SAFETY MTG CMPPUL PJSM. Obtain Hot Work Permit Discuss job scrape. 1.25 RURD COIL CMPPUL Start equipment. Bleed pressure off well. Tubing pressure 220 psi. 1-3/4"x 3-1/2" annulus 0 psi. 0.25 PUMP i WTR CMPPUL Pump 50 bbls 6% KCL down 1-3/4" x 3-1/2" annulus. Well dead. 0.08 PUMP WTR_ CMPPUL MEOH surface pumps and lines. 0.67 RURD COIL CMPPUL PU injector assembly. 0.50 RURD_ COIL CMPPUL MU lubrigtor. Prep coil end. Apply Roil-on connector. 0.17 RURD_ COiL CMPPUL Puff test Roll-on connector to 18K. Test good. 0.58 RURD, COIL CMPPUL Slip chains. MU lubricator. Shell test to 1000 psi. RIH. Latch hanger. Skwvly pull old coil over goose neck and onto reel. 0.42 RUNPU COIL CMPPUL Old coil parts at roll-on connector as pipe bends down over the bads side of spool. shut down. Install coil damps on each side of break. Connect damps w/ short nylon strap. 0.08 RUNPU COIL CMPPUL Contiue POOH with coiol. 0.08 RUNPU COIL CMPPUL Call Mr. Jim Regg w/ AOGCC. Give 24 hour notice of BOP Test Mr. Regg waives witness. 1.75 RUNPU COIL CMPPUL Continue POOH. 0.50 RURD COIL CMPPUL OOH w/ old coil. 0.67 PULD_ BHA CMPPUL Break out BHA. RD lubricator and injector Asmbly. 0.50 RUNPU COIL CMPPUL Install night cap. PTest cap. Test good. Secure well for the night. 3.75 RUNPU COIL CMPPUL Change out old coil spool. install new coil spool on CTU. 0.25 RUNPU COIL CMPPUL secure location. Tura in permit Sign out. Leave location. 1.00 SAFEI 1.00 RURD, 0.50 RURD, 1.33 RURD 0.50 RURD, 1.50 RURD COIL CMPPUL Start equipment. RU pump unit and hard lines. COIL CMPPUL Prep coil end for Dimple-on connector. COIL CMPPUL Stab coil into Injector assembly. COIL CMPPUL Install Dimple-on connector. COIL RURD I COIL 16:00 -16:15 I 0.25 (TEST` { 601;'E 16:15 -17:30 1.251 TEST 116:15 -17:30 125 TEST BOPE 17:30 - 18:00 0.50 SECUR WELL 07:00 - 07:30 0.50 SAFETY MTG_ 07:30 - 09:00 1.50 RURD COI 09:00 - 10:20 1.33 RURD tL 10:20 -12:30 2.17 RUR COIL 12:30 - 13:25 0.92 . D __ COIL 13:25 - 14:45 .33 JET N2_ 14:45 - 5 0.67 JET N2 :25 -15:45 0.33 JET N2_ 15:45 - 16:45 1.00 JET_ N2_ CMPPUL Trying to start Pump unit Circulate h glycol from tractor motor. Install battery charger on batten ump motors start. CMPPUL Try to prime up pump unit. frozen. Canny get fluid to pump. Pick up 15 bbsl of MEO vac trud<. Pump into displacement tanks of unit. Gravity ME throughout system. Thaw valves. Able tp pick up prime. CMPPUL Function BOP's. Function test good. Test Acculuiator. System 3200/ ing 1800 psi. Test good. PUL T OP's. Blinds 250/ 4500 psi. Test good. Test Pipe Rams 2501 500 psi. Test good. CMP L ure well. Tura in permit. Sign out leave location. PUL PJ Obtain Hot Work Permit Held PJSM and discuss Job scope. CMPPUL Start eq ' ent. CMPPUL PU Injector a bly go to well, WHP= 0 psig CMPPUL Problem starting fuild pump engine and keeping the engine running. CMPPUL Shell test to 1000 psig. test Open well. RIH with 1 3/4" coil, double checks and a 2" jet CMPPUL Coil at 2700', start N2 at 300 S .PIP= 110 psig, WHP= 0 psig. Continue running in hole with coil. CMPPUL Coil at 7800' CTM PIP increased to 245 p ' .Work coil down to 8500' CTM. PIP= 700 psig. Started getting returns ow bads tank. CMPPUL RIH with coil at 20 FPM. WHP= 240 psig, N2 and •d to flow bads tank. CMPPUL Coil at 9515' CTM, increased N2 rate up to 800 SCFM. Wo it down Printed: 313f2008 1:14:07 PM • Marathon Oil Company Page 2 of 5 .Operations: Summary.. Report Legal Well Name: BEAVER CREEK 06 Common Well Name: BEAVER CREEK 06 Spud Date: 11/21/1981 Event Name: WORKOVER Start: 11/17/2007 End: 12/25/2007 Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To I Hours ~ Code ~ Code Phase Description of Operations 12/2/2007 09:30 - 11:00 11:00 -11:25 11:25 -13:00 1.50 0.42 1.58 RURD_ TEST_ TRIP_ SLIK BOPE TOOL CMPPUL CMPPUL CMPPUL Rig up wireline. Stand by for Pat (supervisor). Stab on Pressure test RIH w/ 1.22" LIB to set down at 9870'. POOH. Im ression of standin valve. Bleed well down and flow. Wait for well to stabilize. 13:00 - 19:00 6.00 LOG_ OTHR CMPPUL RIH w/ Pressure temp gauge to 0', stop for 3 min. continue in hole to 19,060'. Stop for 10 min. POOH to 0' stop for 3 min. all at 60'/min. 19:00 - 19:15 0.25 LOG OTHR CMPPUL Download data. 19:15 - 19:30 0.25 RURD_ SLIK CMPPUL Rig down wireline. 19:30 - 20:30 1.00 TRAVEL TRCK CMPPUL Road equipment to PWL. Fuel equipment 20:30 - 21:00 0.50 TRAVEL TRCK CMPPUL End ticket for 12/01/07 12/5/2007 08:00 - 09:00 1.00 TRAVEL TRCK CMPPUL Arrive at shop. Pick up equipment & crew 09:00 - 11:00 2.00 WAITON WTHR CMPPUL Stand by for wind 11:00 - 14:00 3.00 SECUR WELL CMPPUL Shut down for day. Went to leave -noticed diesel dripping off unit (fuel line 14:00 - CMPPUL Depart Beaver Creek 12/6/2007 08:00 - 09:45 1.75 TRAVEL TRCK PLUGAB Arrive at shop. Pick up equipment. Arrive at Beaver Creek. Sign in. JSA -permit. Spot unit 09:45 - 11:00 1.25 RURD_ SLIK PLUGAB Rig up slickline 11:00 - 13:00 2.00 SETREL PLUG PLUGAB RIH w/ 1" SB w/modified cement retainer (Steve Barrow & G & G machine shop design) to 9864' wl -tap down -shear off -POOH. 13:00 - 14:00 1.00 WAITON CMT_ PLUGAB Stand by for cement 14:00 - 14:30 0.50 PUMP_ CMT_ PLUGAB Mix cement as per instructions 14:30 - 15:45 1.25 DUMPB CMT_ PLUGAB RIH w/ 1.25" Dump bailer (15' long) to 9864' wl. Dump -POOH -good 15:45 - 16:30 0.75 DUMPB CMT_ PLUGAB RIH w/ same to same -same -did not shear 16:30 - 17:42 1.20 DUMPB CMT_ PLUGAB RIH w/ same to same -same -POOH -good 17:42 - 18:25 0.72 DUMPB CMT_ PLUGAB RIH w/ same to same -same -POOH -good (~ f 18:25 - 20:00 1.58 TRAVEL TRCK PLUGAB t _ Rig down JSA -return to shop h ~W ~,t~~,ry-~t3t1~ 1/12/2008 08:30 - 09:30 1.00 SAFETY MTG_ CMPPUL PJSM. Obtain Hot Work Permit. Discuss job scope. 09:30 - 10:30 1.00 RURD_ COIL CMPPUL Start equipment. RU pump unit and hard lines. 10:30 - 11:00 0.50 RURD_ COIL CMPPUL Prep coil end for Dimple-on connector. 11:00 - 12:20 1.33 RURD_ COIL CMPPUL Stab coil into Injector assembly. 12:20 - 12:50 0.50 RURD_ COIL CMPPUL Install Dimple-on connector. 12:50 - 14:20 1.50 RURD_ COIL CMPPUL Trying to start Pump unit. Circulate hot glycol from tractor motor. Install battery charger on batteries. Pump motors start. 14:20 - 16:00 1.67 RURD_ COIL CMPPUL Try to prime up pump unit. Valves frozen. Cann't get fluid to pump. Pick up 15 bbsl of MEOH in vac truck. Pump into displacement tanks of unit. Gravity MEOH throughout system. Thaw valves. Able tp pick up prime. 16:00 - 16:15 0.25 TEST BOPE CMPPUL function test BOP's. Function test good. Test Accululator. System 3200/ Ending 1800 psi. Test good. 16:15 - 17:30 1.25 TEST_ ROPE CMPPUL Test BOP's. Blinds 250/ 4500 psi. Test good. Test Pipe Rams 250/ 4500 psi. Test good. 17:30 - 18:00 0.50 SECUR WELL CMPPUL Secure well. Turn in permif. Sign out leave location. 1/13/2008 07:00 - 07:30 0.50 SAFETY MTG_ CMPPUL PJSM. Obtain Hot Work Permit. Held PJSM and discuss job scope. 07:30 - 09:00 1.50 RURD_ COIL CMPPUL Start equipment. 09:00 - 10:20 1.33 RURD_ COIL CMPPUL PU Injector assembly go to well, WHP= 0 psig 10:20 - 12:30 2.17 RURD_ COIL CMPPUL Problem starting the fuild pump engine and keeping the engine running. 12:30 - 13:25 0.92 RURD COIL CMPPUL Shell test to 1000 psig. Good test. Open well. RIH with 1 3/4" coil, double checks and a 2"jet nozzle. 13:25 - 14:45 1.33 JET_ N2_ CMPPUL Coil at 2700', start N2 at 300 SCFM. PIP= 110 psig, WHP= 0 psig. Continue running in hole with coil. 14:45 - 15:25 0.67 JET_ N2_ CMPPUL Coil at 7800' CTM PIP increased to 245 psig. Work coil down to 8500' CTM. PIP= 700 psig. Started getting returns to flow back tank. Printed: 1/31/2008 8:18:03 AM • Marathon Oil Company Page 3 of 5 Operations Summary Report Legal Well Name: BEAVER CREEK 06 Common Well Name: BEAVER CREEK 06 Spud Date: 11/21/1981 Event Name: WORKOVER Start: 11/17/2007 End: 12/25/2007 Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Sub I ...Date From - To I Hours .Code Code Phase 1/13/2008 15:25 - 15:45 0.33 JET N2 CMPPUL 15:45 - 16:45 1.00 JET N2 CMPPUL 16:45 -17:15 0.50 JET_ N2_ CMPPUL 17:15 - 18:05 0.83 JET N2 CMPPUL 18:05 - 18:30 0.42 JET_ N2_ CMPPUL 18:30 - 19:00 0.50 JET N2 CMPPUL 19:00 - 20:15 1.25 JET_ N2_ CMPPUL 20:15 - 21:30 1.25 JET N2 CMPPUL 21:30 - 22:00 0.50 RURD COIL CMPPUL 22:00 - 23:00 1.00 SECUR WELL CMPPUL 1/14/2008 08:00 - 09:30 1.50 PERF CSG CMPSTM 09:30 - 12:00 2.50 SAFETY MTG_ CMPSTM 12:00 - 14:00 2.00 RURD COIL CMPSTM 1/16/2008 08:00 - 09:00 1.00 SAFETY MTG CMPSTM 09:30 - 11:15 1.75 RURD ELEC CMPSTM 11:15 - 11:25 0.17 RURD_ ELEC CMPSTM 11:25 -12:20 0.92 RUNPU ELEC CMPSTM .Description of Operations RIH with coil at 20 FPM. WHP= 240 psig, N2 and fluid to flow back tank. Coil at 9515' CTM, increased N2 rate up to 800 SCFM. Work coil down to top of perforations at 9866'. PIP= 1100 psig, PUH with coil. Work coil back up into the 3.5" tubing tail at 8987'. Coil at 8985' stop coil. PIP= 1245 psig and increasing. PUH to 8495' CTM, good returns to flow back tank. PIP=1330 psig, N2 rate at 800 SCFM. Total N2 pumped= 70, 000 SCF. Pressure dropping, RIH with coil. Work coil down to 9921' CTM. PIP= 1160 psig. Returns slowed down. Increased N2 rate to 1000 SCFM. PUH with coil, Cut N2 rate back to 500 SCFM. PIP= 890 psig. Coil at 7921' CTM. POOH with coil. Total fluid to flow back tank = 30 bbls. Coil at 4000 'CTM, returns slowed way down mostly N2 in flow back tank. WHP= 206 psig. Cut N2 rate to 0 and shut down pump. Continue pulling out of hole with coil. Coil at 20'. WHP= 280 psig when shut in at tree. Total N2 pumped 200,000 SCF. Break walking dogs, Bowen connection and rig back the injector. Secured area around the well. Cleaned up and secuued crane for night. Total returns to flow back tank= 40 bbls, WHP= 300 psig. Turn in permit. Sign out leave location. Expro arrived on location. Decided to wait till tomorrow because of the -19 degree temperature out side. Expro left lease. BJ coil tech operation personnel arrived on location. Held PJSM to discuss working to remove the BOP's and tree flanges. Uptain work permit. Rd BOP, removed the 3 1/16" X 3 1/8" X-over to have it drifted to the new velocity string hang off mandrel before running and hanging off the velociyt string. X-over removed. Tree secured and BJ left lease. Hold PJSM. Discuss Expro JSA. Discuss Hazards of working in the cold and snow. Watch slips, trips, and falls. Watch out for each other. MIRU Expro crane and E-line unit. PU lubricator. MU Gamma Ray/CCL to run drift/ tag/ correlation run. WHP 340 psi. PTest lubricator to 2500 psi. Test good. RIH w/ Gamma RayJ CCU 2.125" fluted centralizer GR. Tag TD @ 12:20 - 13:00 0.67 RUNPU ELEC I CMPSTM I OOH. Check GR. 2.25" OD. Change to 2.10" OD GR. 13:00 - 13:25 0.42 RUNPU ELEC CMPSTM OOH w/ Gamma Ray/CCU 2.10" O.D. blind box. 13:25 - 13:55 0.50 RUNPU ELEC CMPSTM RIH w/ Gamma Ray/CCU 2.10" O.D. blind box 13:55 - 14:20 0.42 RUNPU ELEC CMPSTM Ta fill 10,074'. Start Gamma Ray up pass. 14:20 - 15:13 0.88 RUNPU ELEC CMPSTM End up pass @ 8900'. POOH. 15:13 - 15:45 0.53 RUNPU ELEC CMPSTM OOH. 15:45 - 16:00 0.25 SAFETY MTG_ CMPSTM Hold Explosive Safety Meeting. Go to communications black out. Post signage and guard at entrance to location. 16:00 - 16:10 0.17 RURD_ ELEC CMPSTM Arm and Pu 20' pert gun. 16:10 - 16:25 0.25 RURD_ ELEC CMPSTM O-ring leak on Lubricator. Shut down and replace. 16:25 - 17:20 0.92 RUNPU ELEC CMPSTM RIH. w/ 20' of 2.125" Owen ShoGun, NTX charges, 60 degree phased spiral wound perforating guns. 17:20 - 17:25 0.08 RUNPU ELEC CMPSTM Pass thru 2.25" patch @ 6161-6182'. Continue RIH. 17:25 - 17:45 0.33 RUNPU ELEC CMPSTM Continue RIH. 17:45 - 18:05 0.33 RUNPU ELEC CMPSTM Run collar strip and tie-in to Expro Gamma Ray Log 1-15-08. 18:05 - 19:15 1.17 PERF_ CSG_ CMPSTM Pull up into position a 9864' (CCL) to shoot @ 9866'- 9886'~OH) 20 Printed: 1/31/2008 8:18:03 AM r: • Marathon. O{{ Company Page ~ of 5 Operations Summary Report Legal Well Name: BEAVER CREEK 06 Common Well Name: BEAVER CREEK 06 Spud Date: 11/21/1981 Event Name: WORKOVER Start: 11/17/2007 End: 12/25/2007 Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date I From - To Hours I Code Code Phase Description of Operations 1/16/2008 118:05 - 19:15 I 1.171 PERF_ ~ CSG_ I CMPSTM I WHP 340 psi. WHP dropped 40 psi immediately, then came back to 1 /17/2008 1/18/2008 1 /19/2008 19:15 - 19:45 0.50 RURD_ ELEC CMPSTM OOH. RD. Shut well in for the night. 19:45 - 20:00 0.25 SECUR WELL CMPSTM Turn in permit. Sign out. Leave loc. 07:30 - 08:00 0.50 SAFETY MTG_ CMPSTM Hold PJSM. Discuss Expro JSA. Watch slips trips and falls. Obtain Safe Work Permit. 08:00 - 08:15 0.25 RURD_ ELEC CMPSTM Start equipment- Expro crane and E-line unit. WHP 340 psi. 08:35 - 08:45 0.17 SAFETY MTG_ CMPSTM Hold Explosive Safety Meeting. Go to communications black out. Post signage and guard at entrance to location. 08:45 - 08:55 0.17 RURD_ ELEC CMPSTM Arm 15' pert gun. PU lubricator and pert gun. 08:55 - 09:45 0.83 RUNPU ELEC CMPSTM RIH. w/ 15' of 2.125" Owen ShoGun, NTX charges, 60 degree phased spiral wound perforating guns. 09:45 - 10:35 0.83 RUNPU ELEC CMPSTM log thru tubing patch and tie-in to Expro Gamma Ray Log 1-15-08. 10:35 - 11:45 1.17 PERF_ CSG_ CMPSTM Pull up into position to shoot @ 9135-9150' (CH), 9140- 9155' (OH) 15'. 11:45 - 12:00 0.25 ~ RURD I ELEC I CMPSTM OOH. RU for third gun run. 12:00 - 12:10 0.17 SAFETY MTG_ CMPSTM Hold Explosive Safety Meeting. Go to communications black out. Post 12:10 -12:20 12:20 - 13:20 13:20 - 13:30 13:30 - 14:30 0.17 1.00 0.17 1.00 RURD_ RUNPU RUNPU PERF_ ELEC ELEC ELEC CSG_ CMPSTM CMPSTM CMPSTM CMPSTM signage and guard at entrance to location. Arm pert gun and PU lubricator. OT and RIH. Log and correlate perf gun. Pull into position and shoot @ 9115-9135'(CH), 9120-9140'(OH). WHP 340 psi. POOH. 14:30 - 15:30 1.00 RURD_ ELEC CMPSTM OOH. RD Expro. 15:30 - 16:00 0.50 SAFETY MTG_ CMPSTM Hold PJSM. Discuss BJ/Uoss JSA. Watch slips trips and falls. Obtain Hot Work Permit. 16:00 - 16:30 0.50 RURD_ COIL CMPSTM RU ASRC Crane and BJ. Stab coil thru Injector Head. 16:30 - 17:30 1.00 RURD_ COIL CMPSTM Uoss Welder install weld on coil connector. 17:30 -18:30 1.00 TEST_ EQIP CMPSTM Load and PTest coil to 2000 psi. 18:30 - 19:00 0.50 SECUR WELL CMPSTM Tum in permit. Sign out. Leave loc. 07:30 - 08:30 1.00 SAFETY MTG_ CMPRUN PJSM. Obtain Hot Work Permit. Held PJSM and discuss job scope. 08:30 -13:15 4.75 RURD_ COIL CMPRUN RU flanged XO's and BOP stack. PU lubricator and injector. MU velocity string BHA without pump out plugs. Stab on well. 13:15 - 14:30 1.25 RURD_ COIL CMPRUN Cool down N2 and function test BOP. 14:30 -14:50 0.33 TEST_ EQIP CMPRUN Shell test to 2000 psi. 14:50 - 15:30 0.67 RURD_ COIL CMPRUN Pull injector off well and make up x-nipple, WEG, and pump out plugs. Stab on well. Open well to gas buster to bleed off well pressure. 15:30 - 17:15 1.75 RUNPU COIL CMPRUN RIH velocity string to hang off depth at 9866 RKB. 17:15 - 19:00 1.75 RURD_ COIL CMPRUN PU to 9852' RKB. Close pipe and slip rams and set pipe on slips. Walk injector up and cut velocity string. Install hanger assembly and GS 19:00 - 20:00 I 1.00 I RUNPULI COIL 20:00 - 21:30 I 1.501 RURD I COIL 09:30 - 10:00 0.50 SAFETY MTG_ 10:00 - 13:15 3.25 RURD COIL 13:15 - 13:30 0.25 TEST_ EQIP 13:30 - 18:30 5.00 PUMP N2 spear. CMPRUN Stab on, pull test GS. Walk injector down and make up quick connect. Lower velocity string to 9864' RKB and tang hanger in bowl. Lock in lockdown screws and test hanger seals to 5000 psi. good test. Pump GS spear off hanger and pick up into lubricator. CMPRUN Rig back injector and secure well for night. Close permit and leave location. CMPRUN PJSM. Obtain Hot Work Permit. Held PJSM and discuss job scope. CMPRUN RD coiled tubing unit. Displace McOH from CT tail with N2. Release all equipmet except N2 and rerig pump and flow lines. CMPRUN PT lines to 2500 psi. Good test. CMPRUN Bullhead N2 down velocit rin to oas buster and tank. N2 unit lost seal in suction valve and shut down. Printed: 1/31/2008 8:18:03 AM • • Marathon Oil Company Page 5 of 5 i Operations Summary Report (Legal Well Name: BEAVER CREEK 06 .Common Well Name: BEAVER CREEK 06 Spud Date: 11/21/1981 Event Name: WORKOVER Start: 11/17/2007 End: 12/25/2007 (Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Code Phase Description of Operations 1/19/2008 13:30 - 18:30 5.00 PUMP_ N2_ CMPRUN Recovered 35 Bbls water. 18:30 -19:45 1.25 FLOW TEST CMPRUN Close tubing and open velocity string. Observe well. No flow after 75 minutes. 19:45 - 20:30 0.75 SECUR WELL CMPRUN Shut in well and release roustabout crew. Close permit and leave location. 1/22/2008 08:15 - 09:00 0.75 SAFETY MTG_ CMPRUN PJSM. Obtain Hot Work Permit: Held PJSM and discuss job scope. 09:00 - 10:35 1.58 RURD_ OTHR CMPRUN RU N2 pumper and N2 transport. RU iron to WH. Iron from tree to choke, and gas buster complete. 10:35 - 10:45 0.17 TEST_ EOIP CMPRUN PT Vines to 2500 psi. Good test. V string annulus 600 psi. Blow down annulus. Appeared to be N2. 10:45 - 14:50 4.08 PUMP_ N2_ CMPRUN Bullhead N2 down velocity string at 1200 SCF/min while flowing Tubing to gas buster and tank. Recovered 15 Bbls water. Pumped 272,000 scf. N2. 14:50 - 15:00 0.17 FLOW TEST CMPRUN Close tubing and open velocity string. V-string pressure 150 psi. Flow to gas buster. Observe well. No flow after 20 minutes. 15:00 - 15:30 0.50 RURD_ OTHR CMPRUN RD N2 pumper and transport. 15:30 - 16:00 0.50 SECUR WELL CMPRUN Shut in well and release roustabout crew. Close permit and leave location. Printed: 1/31/2008 8:18:03 AM BG06 Revised Op Summary~707.pdf Maunder, Thomas E (DOA) From: Skiba, Kevin J. [kskiba@marathonoil.com) Sent: Monday, March 03, 2008 1:27 PM To: Maunder, Thomas E (DOA) Cc: Skiba, Kevin J.; Mullin, Mickey Subject: BC-06 Revised Op Summary 111707.pdf Attachments: BC-06 Revised Op Summary 111707.pdf «BC-06 Revised Op Summary 111707.pdh> Tom, Page 1 of 1 Here is the revised operations summary for the work that was completed on BC-6 well. The coil removal remarks are stated on 1/11/2008. Let me know if you need anything else. Thank you for your coopera#ion, Kevin Slaba Production Technician Marathon Oil Company Office (907) 283-1371 Cell (907) 394-1332 Fax (907) 283-1350 ~, ~~5~~ ~~~ 3/1312008 Page 1 of 1 i Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, February 28, 2008 11:27 AM To: Maunder, Thomas E (DOA); Skiba, Kevin J. Cc: Donovan Jr, Dennis M. Subject: RE: BC-06 (181-150) -- 307-269 --AGAIN Kevin, Gvt your message, but got to run. Nat a problem regarding the timing on the revised reports. Send them by email when you can. Thanks for researching. As discussed yesterday, the summary just didn't seem complete. Tom From: Maunder, Thomas E (DOA) Sent: Wednesday, February 27, 2008 3:05 PM To: 'Skiba, Kevin J.' Cc: Donovan Jr, Dennis M. Subject: RE: BC-06 (181-150) -- 307-269 --AGAIN Kevin, I have further reviewed the operations report and it is hard to follow. There are breaks between work dates which is not unusual, but there appears to have been work done on some of those missing days. First day reported is 11/17 and next day is 11129. Was there work in between? There is a long break between 12/6 and 1/12. Not unusual for Christmas, but in the new year, they RIH deeper than the retainer set depth on 12/6. The 1/15 report is not included and that appears to be when they pulled the initial VS. Sorry about the "laundry list", but I think some days are missing. Thanks much. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Wednesday, February 27, 2008 2:50 PM To: 'Skiba, Kevin J.' Subject: BC-06 (181-150) -- 307-269 Kevin, I am reviewing the 404 for this well. The operational summary is identical for 11/30 and 12/1. Is this correct? Thanks, Tom Maunder, PE AOGCC 3/13/2008 · . ~V~VŒ lID~ ~~~~[K\&\ / I AI4ASIiA. OIL AlQ) GAS / CONSERVATION COMMISSION / ! SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276·7542 Kevin Skiba Production Engineer Marathon Oil Company PO Box 1949 Kenai, AK 99611-1949 \"4J\~ ISO Re: Beaver Creek Field, Tyonek Gas Pool, Beaver Creek 6L Sundry Number: 307-269 Dear Mr. Skiba: S!;ANNED AUG 1 72007 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ¡f¿ day of August, 2007 Enc!. ~ . . ~ M';; Marathon MARATHON Oil Company Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 August 13, 2007 RECEIVED AUG 1 5 2007 Alaska Oil & Gas Cons Com . . . mISSIon Anchorage Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations Installation of V-string 303-309 10-403 Application for Sundry Approvals Removal of V-string, Reperf, and Re-run V-string Field: Beaver Creek Field Well: Beaver Creek #6 Dear Mr. Maunder: Enclosed is the 10-404 for sundry 303-309. This sundry reports the installation of a 1.75" coil tubing velocity string to 9866' KB in the long string of Beaver Creek 6 dated October 15th 2003. Attached with the 10-404 is the operations summary report and current well bore diagram. We would like to request for the removal of the 1.75" V-string, reperforation of the existing zone, and re-installation of this same coil string to promote commercial sales gas. Please find a 10-403, operations procedure and wellbore diagram (as noted in above paragraph). The proposed wellbore diagram will be identical as the current one provided. Please send any sundries or pertinent documentation to Kevin Skiba at the above address listed. If you have any questions or need further information please call me at (907) 398-1362. Sincerely, þy;¡; Ár2 . Dennis Donovan Production Engineer Enclosures: 10-404 Sundry of Well Ops 303-309 (1) cc: Operations Summary Report (1) Current Well Schematic (2) 10-403 Request of Sundry Well Ops. (2) Detailed Operations Procedure (2) Houston Well File Kenai Well File DMD KJS ~ 07:5 þ/. . (j( f,/I.,·o1 ./S-ðJ II" I? ALASKA Oil AND 'G'i:s' CON~;;A~ON COMM'SS'Orfti R_ECE IVE D ì> APPLICATION FOR SUNDRY APPROVAL AUG 1 5 2007 20 MC 25.280 Abandon 0 Alter casing 0 Change approved program 0 ~. Operator Name: Suspend 0 Repair well 0 Pull Tubing 0 Operational shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Stratigraphic 0 Perforate ~18Ska Oil &Gh~S. CommisWmer [) Stimulate 0 Time ExteAmmdÏåge Remove v-string- / O repetf-set v-string Re-enter Suspended Well 5. Permit to Drill Number. 181-150 - I. Type of Request: I. Address: Marathon Oil Company Exploratory D Service 0 6. API Number. 50-133-20346-00-00 - PO Box 1949, Kenai Alaska, 99611-1949 8. Well Name and Number. '. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes 0 I. Property Designation: A-028083 - 2. -otal Depth MD (ft): 15,928' / Casing Surface Intermediate Liner Liner 'erforation Depth MD (ft): f 6,018' thru 9,886' (gross) 'ackers and SSSV Type: Total Depth TVD (ft): 15,610' / Length 4,022' 12,410' 3,534' 1,208' No [;] Beaver Creek #6 - 10. KB Elevation (ft): 11. Field/Pool(s): _ 21' RT-GL - Beaver Creek Field, Beluga and Tyonek Pools PRESENT WELL CONDITION SUMMARY '., Effective Depth MD (ft): Effective Depth TVD (ft): 10,400' 10,337' / MD TVD 4,022' 4,022' 12,410' 12,228' 14,980' 14,674' 15,889' 15,581' Plugs (measured): Junk (measured): - ,. þ 10400'.11200',14647'.15280' NIA Size Burst Collapse 13-3/8" 9-5/8" 3450 / 5380 Multiple String 12460 13940 1950 /2670 Multiple String 10760 13450 7" 5" 9-5/8" Multiple String Data: (Pipe-BurstlCollapse) 47#N80 6870/4750 - 53.5#C75 7430/6360 - 53.5#N80 793016620 - 47#P110 9400/5310 - 53.5#P110 1090017930 Perforation Depth TVD (ft): ¡-Tubing Size: Tubing Grade: Tubing MD (ft): 6,017' thru 9,843' (gross) SS: 2.875" ¡ LS: 3.500" 8S:6.4# L-80 / LS:9.3# L-80 6,218'/8,987' Baker GT Dual Packer with 60K Shear Ring Packers and SSSV MD (ft): GT Dual @ 5852' AND 194 SAB @ 6911' AND Baker 194 SAB 40X32 Packer 8/27/2007 14. Well Class after proposed work: Exploratory 0 Development [) Service 0 16. Well Status after proposed work: ;~-S~":> Oil 0 Gas [) Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 3. Attachments: Description Summary of Proposal 0 )etailed Operations Program [) BOP Sketch 0 5. Estimated Date for :ommencing Operations: 7. Verbal Approval: :ommission Representative: 8. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact 'rinted Name 1 Dennis M Donovan Jr Title Production Engineer I ;ignature )\... A /\}) Phone W-907-283-1333 Date <f \.r'V L' ~ .... F C-907-398-1362 ..........-.,) "-..) COMMISSION USE ONLY Date: Kevin Skiba (907) 283-1371 8/13/2007 :Onditions of approval: Notify Commission so that a representative may witness Sundry Number: .30'/ - ~ C:, 7 'lug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 '\ )ther. ~ L I.E L. ~C> \' \>~, ðo "'''''- ;).J:; ,~'\ ~ ~ -\- .\<, ~ÇQO,,~" ",:" \' k.~J c..T ßO\, ~\ a-a~~C-d-S-, ;)~~ ç; k~\- -\-0 4saD ~",>, Q'.>~\O-.V'....~ "b,""",' Fo,," R"",;cod, '-U-\ ~ fl .pproved by: APPROVED BY THE COMMISSION Date: g', 16,. ð1!- Form 10-403 Revised 06/2006 R\~\NA' RBDMS BFL AUG 1 7 2007 Submit in Duplicate . Well BC-6 Velocity String WO.07.15633.EXP Page 1 . Well BC-6 Long Velocity String Installation Pull Velocity String, re-perforate, and Run velocity string Beaver Creek Field, Pad 3 WBS #WO.07.15633.EXP Obiective - We plan to pull the 1 %" velocity string. RU Expro Wire Line Service and re-perforate the Tyonek perforations at 9120 to 9155' and 9866' to 9886'. Then run the 1 W' velocity string back in well BC-6l. Flow well to production. Back2round - Well BC-6 is currently completed as a dual producer in the Beluga and Tyonek Sands. The Well is currently not producing. An attempt to unload the well in May 2007 by pumping N2 down the velocity string and up the annulus was not successful. Procedure Pollard Wire line Services 1.) Hold PJSM and fill out safe work permit. 1. Move in rig up Pollard Wire Line unit. 2. Install wire line valve with pump in sub to Otis tree cap connection 3. Pressure test wire line valve and lubricator with pump to 2500 psig with fresh H20. 4. RIH tag top of profile with 1.25" GR to verify tubing open. 5. POOH, MU tool string to run the equalizing plug. 6. RIH with 1.25" tool sting with 1.188" equalizing plug set in KEP profile at 9866' MD. 7. Set plug, POOH with wire line tools. 8. RDMO Pollard Wire Line unit. BJ Coil Tech 2.) Hold PJSM and fill out safe work permit. *** Notify the AOGCC James Re22 (ä), 907-276-7542 (24 or lon2er) prior to testin2 the BOP's w. E. Cissell- 07-12-2007 , , . Well BC-6 Velocity String WO.07.15633.EXP Page 2 . 1. MIRU BJ 1 %" coil tubing and nitrogen. Conduct pre-job safety meeting. Spot. CTU with 1 %" CT work reel, pumping equipment, fluid and flow back tanks. RU pumping and flow back iron. Blend 300 bbl of 6% KCl. Stab CT work string in injector. Make up CT connector. Pull test CT connector to 15,000 lbs. Make up tool string with BHA to latch into the velocity string hanger. 3.) Nipple up BOPE and 4" work window, and test to 250/4500 psig. Test flow back iron 250/3500. 4.) Pull test GS profile connection to 18,000 lbs. Open slip rams. 5.) RIH with GS latch into coil head. PU _ weight to verify latched into coil. 6.) Back offset lock-down screws onto the hanger. PU coil head above BOP's, set tubing rams. BID velocity string. PU injector by walking up coil. Cut coil above and below the GS. MU dimple on coil connector. Reel coil onto working string. 7.) Rig back coil tubing. MIR Electric line. NOTE: Change out BHA to standardize the 1.3/4" BHA to ones built at GG Machine. Expro America 8.) Move in and rig up Expro America electric line unit. 1. Hold P JSM and fill out a Safe Work pennit. 2. Install wire line valve with pump in sub to Otis tree cap connection. 3. Pressure test wire line valve and lubricator with pump to 2500 psig with fresh water. 4. MU lubricator. 5. Hold PJ explosive safety meeting prior to anning gun. Go to, "Communication black out", on pad. 6. Pressure test wire line valve and lubricator with pump to 2500 psig with Methanol. 7. RIH with 2.125" Owen ShoGun, NTX charges, 60 deg. Phasing spiro wound, on a 1 11116" tool string. 8. Re-perforate from 9120' - 9155' MD and 9866' - 9886' MD. 9. Blow down well to 700 psig prior to perforating. 10. RDMO Expro. PU BJ coil tech 1.) Hold PJSM and fill out safe work pennit W. E. Cissell- 07-12-2007 . . Well BC-6 Velocity String WO.07.15633.EXP Page 3 2.) L\SQO þS \ \Xè ,~~~\ \ RU injector to WHA and pressure test WHA ~sig). RIH with coil tubing velocity string to 9862' locate the coil where the dimple on coil connector is in work window. Set BOP tubing rams and slip rams. Bleed off WHP above tubing rams, and verify that plug in the velocity string is holding. 3.) Open window access area. Install back up clamp on CT. Cut coil tubing velocity string. 4.) Install ABB Vetco coil hanger mandrel on top of velocity string. Make up mechanical GS profile tool string at end of CTU. Remove backup clamp and close window. Add additional lubricator to accept GS. RIH latch onto coil hanger with GS. 5.) Equalize pressure across tubing rams and open tubing rams. Pull test GS profile connection to 18,000 lbs. Open slip rams. 6.) Land coil hanger into tubing head and set lock-down screws onto the hanger. Release GS profile connection by setting down _ weight onto the coil tubing hanger. PU to verify that GS is released. Bleed off wellhead pressure to verify that the coil hanger is holding pressure. 7.) Pressure up velocity string with nitrogen to blowout coil tubing plug. Shut down nitrogen pumping when confident that the plug is removed. 8.) Flow well through coil tubing velocity string to flow back tame Œote: Can optionally circulate nitrogen down the coil tubing annulus if it has difficulty kicking off.) Verify tubing hanger assembly is holding pipe weight and pressure, then shut in well. RDMO coil tubing. 9.) Produce well to sales as per instructions of Production Engineer. 10.) Please call Wayne Cissell at 907-283-1308 with any questions. Contacts: Work Phone Cel Ken Walsh Wayne Cissell 283-1336 283-1308 398-3060 394-1324 W. E. Cissell- 07-12-2007 API: 50-133-20346 AOGCC: 1B1-150 RT -GL; 27.0' (Onginal) RT -GL: 21.0' (Workover 2003) 1164' FNL, 1487' FWL Sec34, TIN, R10W, S.M. Tree crn '" 3-1/2" EVE Brd 3", 5-bolt crescent flange cap Uft threads'" 3.725" MCA 8hortstnnq - 2.875",6.4#, L-80, EVE 8rd-Mod Tubing Baker injection nipple @ 1162' GT duai packer @ 5852' X-nipple at 5904' 10"'2.313" Wireline re-entry 9uide at 6218' 6080' - 6095' Pressure response noted after firjng gun. 6112' - 6118' 6125' - 6134' 6140' - 6149' 6165' -6179' LonostrinQ Perfs (Tvonek) 9120'·9155' (6 &pf, 12/96 & 2/97) 9866' - 9886' (6 &pf, 2/4196) Cement retainer @ 10400' Cement retainer @ Gmt plU9 11,360' - 11,560' CIBP @ 14847' capped w/200' cmt (6/82) CIBP @ 15280' capped w/22' sand & Gmt (5/82) Baker injection nipple w/ dual checks, and 1[4" 00, OJJ4!ì" wall 88 control line 88-1162' L8 1203' Coil -1.75" 00, 0.125" wall, HO-70 grade, flash present, 0' . 9B66' straightening bar and landing nipple at the coil tUbing tail at 9866' 10 '" 1.268' Frac ¡¡timulated the interval (9866' - 3[17[01. Placed 58,000 Ibs of 2D/40 Carboilte in 357 bbl of 8uperRheogel in diesel. LOMstring - 3.5", 9.3#, L-80, EUE 8rd-Mod TOg Note: 1'-110 tubing between dual packer and SAS packer at 6911'. Baker injection nipple @ 1203' Baker GT Dual packer @ 5852' CMU sliding sleeve @ 6254' 10 2.813" 10' Seal assembly (OD '" 4.00") 80-40 K-Anchcr @ 6909' Baker 194 "AS 40x32 Packer@ 6911' 10"'3.250" Camco X-Nipple @ 6965' 10 "'2.813" Cameo X-Nipple 8962' 10 '" 2.813" ~ plug set 314103 Wireline Re-Entry @ 8987' ,47 & 53.5 ppf, N-80, BTC @ 12,410' sks of class G (1588 sks 1st stage, 1800 sks 2nd stage) - 5754',47 ppf, N-80 ·6355',53.5 ppf, C-75 6355' - 6983',53.5 ppf, N-80 6983' - Cementing tool - 8565', 53.5 N-80 8565' - 9615', 47 9615' -12,331',53.5 ppf, P·110 Beaver Creek Field 4/28/2003 - 2J20/2007 dual 5095' -115' 5132' - 142' 5174' -154' IG-zone; 15170' . 200' 15085' - 128' 15003' - 050' Hemlock: 15520' - 546' 15476' - 506' 15414' -466' 15387' - 407' 15345' . 370' 15306' - 326' . . Page 1 of 1 Maunder, Thomas E (DOA) From: Skiba, Kevin J. [kskiba@marathonoil.com] Sent: Wednesday, August 15, 2007 3:08 PM To: Maunder, Thomas E (DOA) Cc: ddonovan@marathonoil.com; Cissell, Wayne E. Subject: RE: CT BOP test pressure-BC #6 Tom, The pressure stated in the well work procedure on page # 3 under item # 2 is a typo. The intended CT BOP test pressure is 250/4500 psi for both removing and installation of the velocity string. Thanks, Kevin Skiba Production Technician Marathon Oil Company Office (907) 283-1371 Cell (907) 394-1332 Fax (907) 283-1350 ------.--" --.--.-------.,. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, August 15, 2007 2:54 PM To: Skiba, Kevin J. Subject: cr BOP test pressure-BC #6 Kevin, In the procedure two values are given for the CT BOP test pressure. The initial test pressure is 250/4500 to pull the velocity string and then the stated test pressure is 250/2500 to run the velocity string. SL and EL test pressures are 2500 psi. Could you verify what the high cT test pressure is? Thanks, Tom Maunder, PE AOGCC 8/15/2007 · _.~ STATE OF ALASKA .?S, RECEIVED ALASKA Oil AND GAS CONSERVATION COMM ON }!:;. REPORT OF SUNDRY WELL OPERATIONS~tSAUG 1 5 2007 1. Operations Abandon U RepairWell U Plug Perforations U Stimulate U Al8~kacmrR.1 ~ as œQ~sSlOn Performed: Alter Casing D Pull Tubing D Perforate New Pool D WaiverD Time xtension ~ c~~ed Velocity Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspended Well '-- Strina 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Oil Company Development 0 Exploratory D 181-150 . 3. Address: Stratigraphic D Service D 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20346-00-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 21' RT-GL Beaver Creek #6 - 8. Property Designation: 10. Field/Pool(s): - A-028083 Beaver Creek Field. Beluaa and Tvonek Pools 11. Present Well Condition Summary: Total Depth measured 15928' . feet Plugs (measured) 10400',11200',14647',15280' true vertical 15610' . feet Junk (measured) N/A Effective Depth measured 10,400' feet SCANNED AUG 1 6 2007 true vertical 10,337' feet Casing Length Size MD TVD Burst Collapse Structural 0 0 0 0 0 0 Conductor 0 0 0 0 0 0 Surface 4,022 13-3/8" 4,022' 4,022' 3450/5380 1950/2670 Intermediate 12,410' 9-5/8" 12,410' 12,228' Multiple String Multiple String Liner 3,534' 7" 14,980' 14,674 12,460 10,760 Liner 1,208' 5" 15,889' 15,581' 13,940 13,450 SS Perfs: 6,018' to 6,179' MD· 9-5/8" Multiple String Data (Pipe-Burst/Coli) 47#N-80 6870/4750-- Perforation depth: Measured depth: LS Perfs: 9,120' to 9,886' MD_ 53.5#C-75 7430/6360 -- 53.5#N-80 7930/6620-- SS Perfs: 6,017' to 6,178' TVD - 47#p·110 9400/5310 -- 53.5#P-110 10900/7930 True Vertical depth: LS Perfs: 9,106' to 9,843' TVD SS: 2.875" 6.4# L-80 6,218' MD Tubing: (size, grade, and measured depth) LS: 3.500" 9.3# L-80 8,987' MD Packers and SSSV (type and measured depth) Baker GT Dual Packer @ 5852' with 60K Shear Ring and Baker 194 SAB 40X32 Packer @ 6911' 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 578 0 0 800 Subsequent to operation: 0 723 4 0 650 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run No Logs/Surveys Run Exploratory D Development 0 Service D Daily Report of Well Operations Included 16. Well Status after work: d S[] "> Oil D Gas 0 WAG GINJ DWINJ D WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: 303-309 Contact Kevin Skiba (907) 283·1371 Printed Name I Dennis M Donovan Jr Title Production Engineer I AJAA¿ (907)-283-1333 W Signature <, Y Yl n . Phon.e (907)-398-1362 C Date 13-Aug-07 Form 10-404 Revised 04/2006 o RIG I N A œBDMS BFL AUG 1 6 2007 Submit Original Only API: 50-133-20346 AOGCC: 181-150 RT-GL: 27.0' (Original) RT -GL: 21.0' (Workover 2003) 1164' FNL. 1487' FWL See 34, T7N, R10W. S.M. Tree cxn = 3-1/2" EUE 8rd 3", 5-bolt crescent flange cap Lift threads = 3.725" MCA Shortstrina - 2.875",6.4#, L-80, EUE 8rd-Mad Tubing Baker injection nipple @ 1162' GT dual packer @ 5852' X-nipple at 5904' 10 = 2.313" Wireline re-entry guide at 6218' Shortstrlna Perfs (Beluaa) 6018'·6031' 6080' - 6095' Pressure response noted after firing gun. 6112' - 6118' 6125' - 6134' 6140' - 6149' 6165'-6179'~ Lonqstrinq Perfs (TvonekJ 912Ò' - 9155' (6 spf, 12196 & 2/97) 9866' - 9886' (6 spf, 214/96) Cement retainer @ 10400' (1/21/96) Cement retainer @ 11200' (1/17/96) Cmt plug 11,360' - 11,560' CIBP @ 14647' capped w/ 200' cmt (6/82) CIBP @ 15280' capped w/22' sand & cmt (5/82) Well Name 8. Number: Coun or Parish: BC-6 - Dual Baker injection nipple w/ dual checks, and 1/4" 00, 0,049" wall SS control line SS -1162' LS - 1203' Surface Casing: 13-318", 68 & 72 ppf, N- 80, BTC @ 4022' Cmt w/2400 sks of class G Lonqstrina - 1.75" coil tubing velocity string hung from surface, The velocity string blocks access to the permanent longstring completion jewelry shown to the right. 2.25" 10 Patch in lonQstrinQ from 6161 to 6182.6 MD Coil- 1.75" 00, 0,125" wall, HO-70 grade, flash present, 0' - 9866' Straightening bar and landing nipple at the coil tubing tail at 9866' 10 = 1.268" Notes: Frac stimulated the Tyonek 0-1 interval (9866' - 9886') on 3/17/01. Placed 58,000 Ibs of 20/40 Carbolite in 357 bbl of SuperRheogei in diesel. Lonastrinq - 3.5", 9.3#, L-(\O, EUE 8rd.ModTbg Note: P-11 0 tubing between dual packer and SAB packer at 6911'. Baker injection nipple @ 1203' Baker GT Dual packer @ 5852' CMU sliding sleeve @ 6254' 10 = 2.813" 10' Seal assembly (00 = 4.00") 80-40 K-Anchor @ 6909' Baker 194 SAB 40x32 Packer@ 6911' 10 = 3.250" Cameo X-Nipple @ 6965' 10 = 2.(\13" Cameo X-Nipple @ 8962' 10 = 2,813" - PX plug set 3/4/03 Wireiine Re-Entry @ 8987' Prod, Casino: 9-5/8", 47 & 53.5 ppf, N-80, BTC @ 12,410' Cmt w/3388 sks of class G (1588 sks 1st stage, 1800 sks 2nd stage) 0' - 5754',47 ppf, N-80 5754' - 6355', 53.5 ppf, C-75 6355' - 6983', 53.5 ppf, N·80 6983' . Cementing stage tool 6985' - 8565', 53.5 ppf, N-80 8565' - 9615', 47 ppf, P-110 9615' -12,331', 53.5 ppf, P-110 Liner: 7", 32 ppf, P-110, BTC @ 11,446' -14,980' Cmt w/ 652 sks of class G Liner: 5", 18 ppf, N-80, BTC @ 14,681' -15,889' Cmt w/ 450 sks of class G BC-6 Kenai LeaSe: State/Prov, BHP: Dated Completed: Prepared By: Completion Fluid: Last Revison Date: 4/28/2003 - 2120/2007 Inactive Perfs Sterling (above the dual packer): 5095' -115' (sqz'd 3/03) 5132' -142' (sqz'd 3/03) 5174' -184' (sqz'd 3/03) G-Zone: 15170' - 200' 15085' - 128' 15003' - 050' Hem iock: 15520' - 546' 15476' - 506' 15414' - 466' 15387' - 407' 15345' . 370' 15306' - 326' . . Page 1 of 2 Marathon Oil Company Operations Summary R.êport 2.00 PREP _ LOC_ CMPRUN Install felt and liner 12.00 RURD_ COIL CMPRUN Held safety meeting. Spot and MIRU equipment. Pull and cut 1000' of pipe from hangoff spool (was different grade from previous hang off). Stab pipe and PU injector head to pull test Vetco CT connector (test for 1-3/4" connector failed on KU 14x-6 location). Grapple test good. Secure location and depart. Warm up equipment, get permit, conduct safety and procedure meeting. Pick up injector head. Wait on Veco welder. Weld CT connector and allow to cool. Test weld with BST 1-3/4" CT pressure test sleeve to 1000psi. Weld tested good. Pressure/function test slips and rams via killine. Choke not holding. Close block valve for test to 250/2500 psi MU tools including BST CT connector, G&G weight bars, and BST profile with aluminum pump off plug. MU lubricator and injector head to the well. Run in Hole with coiled tubing Stop 30' below desired hang off depth to ensure casing is clear. PUH to 9853' (30' plus 13' for space out from lock pins) for landing depth of 9866'. PU weight 13.5k Ibs. Hold meeting to discuss walking injector head up pipe. Check reel valve for pressure. Close slips/rams and bleed off. Break lubricator and walk up injector. Cut pipe above BOP and MU Vetco 1-3/4" CT connector and hanger. Install dual flapper and hydraulic GS on injector head side of pipe. PU injector head and latch GS spear into CT hanger profile. Measure actual space out to lock pins. Walk injector down and MU lubricator. 0.75 BLOWD EQIP CMPRUN PU pipe wt to neutral. Mark space out from counter head on pipe. Equalize pressure across slips/rams and open. 1.25 TRIP _ TOOL CMPRUN RIH and tag up at -7.5'. Measure tree and determine drift problem at 3-1/16" 10M DSA from tree to BOP. (Hanger OD=3.09") Shut down to discuss. Elect to PU pipe and modify hanger if possible (OD=3.09"). Alternative is to spool pipe out of hole to replace DSA on WHA. See comments in Comments/Learning Tab 3.50 TRIP _ TOOL CMPRUN PU pipe. Space out to get hanger back above BOPs. Close slips/rams and bleed down BOPs. Unchain injector and bring to ground. Pull hanger and CT tools. Rig back for the night with pipe in BOPs (slips/rams closed) and 1 section of lubricator with night cap. 1.50 TRIP _ TOOL CMPRUN Safety and procedure meeting. Start equipment 3.00 NUND WLHD CMPRUN Break tree cap and lubricator. No pressure on cxn indicating rams held. Pipe stub not visible above BOPs. Inspect w/light and see hanger connector sitting on slips/rams 22" below BOP top. Discuss forward plan. Use Vetco BPV bar as wrench to make up CT hanger w/ GS profile to hanger thread looking up. PU injector head and MU dual flapper, centralizer, and GS spear. Engage hanger with spear and walk injector head down pipe to MU lubricator. Pul test cxns to 15k Ibs and equalize BOPs. Open slipslrams and PU 9', Close slipslrams and bleed down above BOPs. Break xcn and PU lubricator. Install C plate and pipe clamps. Inspect pipe and break hanger from GS. 1.00 NUND WLHD CMPRUN Install new hanger and GS. Measure space out to lock screws. Walk injector head down pipe and MU lubricator. Pull test tools to 24.5k Ibs. Put pipe in neutral (pipe wt 13k Ibs). Mark space out on pipe and equalize across rams. Legal Well Name: BEAVER CREEK 06 Common Well Name: BEAVER CREEK 06 Event Name: RECOMPLETION Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date From-To Hours Godeîbcibe Phase 10/10/2003 10/12/2003 13:00 - 15:00 07:00 - 19:00 10/13/2003 11 :00 - 12:30 1.50 RURD_ COIL CMPRUN 12:30 - 14:30 2.00 RURD - COIL CMPRUN 14:30 -15:00 0.50 TEST_ EQIP CMPRUN 15:00 - 16:45 1.75 TEST_ BOPE CMPRUN 16:45 - 17:30 0.75 PULD - BHA_ CMPRUN 17:30 - 19:45 2.25 TRIP BHA CMPRUN 19:45 - 20:30 0.75 RUNPUL COIL CMPRUN 20:30 - 21 :00 0.50 RUNPUL COIL CMPRUN 21 :00 - 22:00 1.00 NUND WLHD CMPRUN 22:00 - 22:45 22:45 - 00:00 00:00 - 03:30 10/15/2003 07:00 - 08:30 08:30 - 11 :30 11 :30 - 12:30 Start: 1 0/1 0/2003 Rig Release: Rig Number: 1 Spud Date: 11/21/1981 End: 10/25/2003 Group: Description of Operations . - Printed: 8/7/2007 4:37:25 PM . . Marathon Oil Operations Summary Page 2·.of 2 2.00 TRIP _ TOOL CMPRUN RIH to near space-out mark on pipe. RIH to near mark. See very small indication of DSA (500Ibs). Run to -6" above mark. Begin pumping hydraulic oil in test port to act as indicator of hanger location. Pressure up and tag locator simultaneously. Run in lock screws. Not able to detect lock groove. PU and slack off pipe in an effort to engage lock groove. Inch into hole checking lock screw depth. Unable to detect groove. Slack off on pipe. Unable to get a pressure test. Attempt to PUH. Pipe friction stuck in hanger at or below locating shoulder. Set pipe in tension and close slips. Consider options with stuck pipe. Elect to apply heat to wellhead to free stuck hanger. RU frost fighter heater with blanket to wellhead. Heat tree. Hanger spool temp is 85 degrees. Open slips with pipe still in tension. Slack off on pipe and PU. Pipe came free. Decide to reattempt to land the hanger. PU pipe to ensure no stickng. RIH and tag shoulder to establish shoulder location/tag weight. Pressure test seals to 2500psi indicating hanger is w/ in 4" of desired depth. Unable to run in lock screw. PU 2' and RIH while pumping hydraulic fluid. Unable to catch pressure test. Reposition CT several more times to no avail. Able to get lock screws in but no pressure test. Pump plastic into pressure test void. Still unable to get pressure test. Check valve on test port not holding. Attempt to lubricate valve on test port with no success. Bleed off WHP. Tree plus CT bled off to Opsi without building back up. Indicates that bottom set of seals in mandrel are holding. Change out bad check valve with tree bled down. Pump 2bpm. Pump GS disconnect off of hanger. Rig down injector head and WHA. Reinstall tree cap. Secure location. Pump off plug to remain in CT overnight. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To SEAVER CREEK 06 SEAVER CREEK 06 RECOMPLETION GLACIER DRILLING GLACIER DRILLING Code Sub Code Phase 10/15/2003 12:30 - 14:30 14:30 - 18:30 4.00 TRIP - TOOL CMPRUN 18:30 - 19:00 0.50 TRIP - TOOL CMPRUN 19:00 - 20:00 1.00 TEST_ WLHD CMPRUN 20:00 - 20:15 0.25 TEST_ WLHD CMPRUN 20:15 - 20:45 0.50 TEST_ WLHD CMPRUN 20:45 - 21 :15 0.50 TRIP - TOOL CMPRUN 21:15-21:25 0.17 TRIP_ TOOL CMPRUN 21 :25 - 00:00 2.58 SECUR WELL CMPRUN Start: 10/10/2003 Rig Release: Rig Number: 1 Spud Date: 11/21/1981 End: 10/25/2003 Group: Printed: 8/7/2007 4:37:25 PM Marathon Oil Company Alaska Business Unit Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907~564-6489 October 6, 2003 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: BC 6L Dear Mr. Aubert: Enclosed is the 10-403 APPLICATION FOR SUNDRY APPROVALS form for BC 6L. The proposed work is to install a 1-3/4" CT velocity string to assist the well in lifting water in the Tyonek completion. //," This work is expected to begin Friday (10/10/03). If you need any additional information, I can be reached at 907-283-1333 or by e-mail at dmtitus@marathonoil.com. Sin.cerely, Denise M. Titus Production Engineer Enclosures ORIGINAL g:\cmn\d rIg\bc\wells\bc9~AOGCC01 .xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION GOMMI$SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend__ Operation Shutdown__ Re-enter Suspended Well~ Alter Casing Repair Well Plugging Time Extension Stimulate Change Approved Program Pull Tubing Variance Perforate Other X 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 1164' FNL, 1487' FWL, Sec. 34, T7N, R10W, S.M. At top of Productive Interval 1151' FNL, 1579' FWL, Sec. 34, T7N, R10W, S.M. @ 9107' TVD At Effective Depth 1234' FNL, 1925' FWL, Sec. 34, T7N, R10W, S.M. @ 10337' TVD At Total Depth 1796' FNL, 1889' FWL, Sec. 34, T7N, R10W, S.M. @ 15610' TVD 5. Type of Well: Development X Exploratory Stratigraphic Service Install velocity string 6. Datum Elevation (DF or KB) 185' KB MSL feet 7. Unit or Property Name Beaver Creek Unit 8. Well Number BC-61'"' 9. Permit Number 181-150 '/' lO. APl Number 50-133-20346 ' 11. Field/Pool Beaver Creek Field, Tyonek 12. Present Well Condition Summary Total Depth: measured true vertical 15928 feet Plugs (measured) 15610 feet 10400',11200',11360',14447',14647', 15260',15280' Effective Depth: measured true vertical 10400 feet Junk (measured) 10337 feet Fill - 10235 (3/29/2001) Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented 4022 13-3/8" 2400 sks 12410 9-5/8" 3388 sks 3534 7" 652 sks 1208 5" 450 sks Tyonek: 9120' - 9155', 9866' - 9886' MD Measured Depth True Vertical Depth 4022 4022 12410 12228 14980 14674 15889 15581 true vertical Tyonek: 9107' - 9141' 9824' - 9844' TVD Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 to 8998' Packers and SSSV (type and measured depth) Baker model 194 SAB 40x32 Packer @ 6911' Baker model GT dual packer at 5852' 13. Attachments Description Summary of Proposal .~X Detailed Operations Program BOP Sketch 14. Estimated Date for~0mmencing Operation 115. Status of Well Classification as: I 10-Oct-03 16. If Proposal was Verbally Approved Oil __ Gas .~X Name of Approver Date Approved Service 17. I hereby ce~fy that the foregoir)~-;i~ true and correct to the best of my knowledge. Signed iit/,~s~x~ll '~ ~~"~ Denise Titus Title Production Engineer Suspended Date 10/6/2003 FOR COMMISSION USE ONLY I Conditions of Approval: Notify Commission so representative may witness Plug Integrity__ BOP Test Location Clearance Mechanical Integrity Test S-~ubsequent Form Required 10--- Commissioner Date ORIGINAL, ..., . OCT .1. & 2003 BC-6 - Proposed V-String APl: 50~133-20346 RT-GL: 27 0' (Odgiaal) RT-GL: 21 0' (Workover 2003) 1164' FNL, 1487' FWL Sec 34, T7N, R10W, SM tree cxn = 3-1/2" EUE 8rd 3", 5 bolt crescent flange cap Lift threads - 3 725" MCA Bakerin)ec6on nipple w/dualchecksrand 1/4" CDr0049" WaI[SS control~ine LS 1203' Surface Casinq: 13-3/8", 68 & 72 ppf, N- I I~O, BTC @ 4022' ICmt w/2400 sks of class G iSqz peris 5095'-5184', tested to 141 ppg EMW ] ~-Baker GT dual packer @ 5852' iw~th 60K shear dn9 Notes: Frac stimulated the Tyonek D-1 intewal (9866' - 9886')on 3/17/01 Placed 58,000 lbs of 20/40 Carbolite in 357 bbl of SuperRheogel in diesel ShoP~tdnq Per~s (Be[uqa) LonqstrinR Peds(Tyonek) 9120'-9155'(6 spf, 12/96 & 2/97) 9866'-9886'(6 spf, 2/4/96) velocit~ stdng hung from sun'ace The velocity stdng blocks access to I~, the permanent Iongstan9 completion jewelry shown to the dght grade, flash present, ~t the coil tubing tail at 9866' 10' Seal assembly (OD: 180-40 K-Anchor ~ )6965' e Re-Ent~@8987' )0") Fill at 10,235' (3/29/01 ) !Cmt p~u9 11,36O' - 11,560' 31BP @ 14647' capped w/200' cmt 6/82) ~.r_E~__.C~s!.n.~q: 9-5/8', 47 & 535 ppf, N-80, BTC @ 12,410' Cmt w/3388 sks of crass G (1588 sks 1 st stage, 1800 sks 2nd stage) 0' - 5754', 47 ppf, 5754' - 6355', 535 ppf, C-75 6355' - 6983', 535 ppf, N-80 6983' - Cementing stage tooi 6985' - 8565', 53 5 ppf, N-80 8565' - 9615', 47 ppf, P-110 9615'- 12,331', 535 ppf, P-110 iLine~r: 5" 18 ppf, N-80, BTC @ 14,681' - 15,889' 7 iCmt w/450 sks of class G I IWell Name & Number: ICounty or Parish: I Perforations (MD) Angle/Peris I rBHP: IDated Completed: I Prepared By: BC-6 I Lease: Beaver Creek Field KenaJ I State/Prov. (TVD) Alaska ICountry: Angle ~3. KOP and Depth [ BHT: t Completion Fluid: 3/24/2003 JG Elier I Last Revison Date: I 4/28/2003 Steding (above the dual packer): 5095' - 115' (sqz'd 3/03) 5132' * 142' (sqz'd 3/03) 5174' - 184' (sqz'd 3/03) G-Zone: 15476'-506' 15414'-466' Well BC-61 Velocity String Installation Beaver Creek Field, Pad 3 WBS #WO.03.08983.EXP Ob,[eetive - Install a 1V4" velocity string in well BC-61 to improve liquid removal and improve production fi.om this Tyonek Sand completion. Background - Well BC-6 is currently completed as a dual producer in the Beluga and Tyonek Sands. A PX plug was set in the longstring in the X-nipple at 8962'. Wireline verified an obstruction in the tubing in the vicinity of the packer at 69 ?'. Coiled tubing will be used to clean out to the top of PX plug and pull the PX prong./ Slickline will pull the PX plug body. BJ Coiltech will then install the velocity string to the top of the Tyonek D-1 perforations at 9866'. Procedure MIRU BJ 13/4" coil tubing and nitrogen. Conduct prejob safety meeting. Spot CTU with 13/4" x 9500' CT work reel, spooling unit containing 10,200' of 13/4", 0.109" wall thickness, HO-70 velocity string, pumping equipment, fluid and flowback tanks. RU pumping and flowback iron. Blend 300 bbl of 6% KC1. Stab CT work string in injector. Make up CT connector. Pull test CT connector to 15,000 lbs. Make up toolstring with wash tool and motor head assembly. 2. Nipple up BOPE and 4" work window, and test to 250/4500 psi. Test flowback iron to 250/3500. . Bleed offWHP. RIH with well open to the flowback tank. Start fluid pump ~ 6000' while proceeding in hole watching for obstruction/fill at +6900'..(Note: Tubing capacity minus coil displacement to the obstruction at 6917' is 40 bbl. Tubing capacity minus coil displacement to the PX plug at 8962' is 51 bbl.) 4. After establishing top of obstruction increase pump rate to 3 bbl/min and wash off at 15'/min. At indication of fill removal hold and pump bottoms up at 3 bbl/min. 5. RIH watching for further fill at 30'/min and 1.5 bbl/min. When fill is encountered slow pipe rate to 15'/min and increase pump rate to 3 bbl/min. Wash to top of PX plug at 8962'. Circulate bottoms up at 3 bbl/min. (Note: Contingency plans for removal of debris on top of the plug should include availability of a Venturi junk basket in case the debris is made of metal fragments. Also, a contingency plan should be made for severing the 3 ½" tubing above the PX plug in case the plug is stuck.) 6. Stop fluid pump and start N2 pump at 1000 scfrn. Strap return tanks for fluid returns. Displace wellbore fluid for total recovery of ±81 bbl (assumes 30 bbl coil capacity). J. G. Eller- 5/19/2003 Well BC-6 Velocity bu-ing WO.03.08983.EXP Page 2 Stop N2 pump. Allow wellhead pressure to bleed to ±2000 psi before shutting well in. 7. Latch PX plug prong ~ 8962' by setting down pipe weight. Pull prong with straight pickup on the coil. Monitor WHP for indication that prong was removed. POOH. o RD injector and remove toolstring. Set injector on ground and chain and secure injector. Remove workstring coil tubing from injector and stab 13/4" CT velocity string in injector. MU pump-out plug and straight-bar onto the end of the velocity string. , MIRU slickline unit. Slickline will RU on top of coil BOPE (3-1/16", 10M Bowen). Conduct prejob safety meeting and test BOPE. RIH with 2½" impression block. Tag top of PX plug body at 8962', POOH. MU pulling tool for PX plug body and RIH. Latch plug body, POOH. RDMO slickline. 10. RU injector to WHA and pressure test WHA (2000 psi). RIH with coil tubing velocity string to 9866' less distance from coil tubing lock down pins to cut point on the coil. :.. 11. Set BOP tubing rams and slip rams. Slack off pipe weight to verify slips are holding string weight. Bleed offWHP above tubing rams, and verify that plug in the coil is holding. Open window access area. Install back up clamp on CT. Cut coil tubing velocity' string. 12. Install ABB Vetco coil hanger mandrel on top of velocity string. Make up mechanical GS profile tool string at end of CTU and latch onto coil hanger. 13. Remove backup clamp and close window. Equalize pressure across tubing rams and open tubing rams. Pull test GS profile connection to 18,000 lbs. Open slip rams. 14. Land coil hanger into tubing head and set lock-down screws onto the hanger. Release GS profile connection by setting down weight onto the coil tubing hanger. PU to verify that GS is released. Bleed off wellhead pressure to verify that the coil hanger is holding pressure. 15. Pressure up velocity string with nitrogen to blow out coil tubing plug. Shut down nitrogen pumping when confident that the plug is removed. 16. Flow well through coil tubing velocity string to flowback tank. (Note: Can optionally circulate nitrogen down the coil tubing annulus if it has difficulty kicking off.) Verify tubing hanger assembly is holding pipe weight and pressure, then shut in well. RDMO coil tubing. 17. Produce well to sales as per instructions of Production Engineer. J. G. Eller-5/19/2003 Lj' STATE OF ALASKA A .... (A OIL AND GAS CONSERVATION COl~ JSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well oILE---j GAS J~] SUSPENDEDr"--j ABANDONEDF---j SERVICE J---'J 2. Name of Operator 7. Permit Number MARATHON OIL COMPANY 181-150 3. Address 8. APl Number P. O. Box 196168, Anchorage, AK 99519-6168 50-133-20346 Classification of Service Well 4. Location of Well at Surface 1164' FNL, 1487' FWL, Sec. 34, T7N, R10W, S.M. At top of Producing Interval 1162' FNL, 1467' FWL, Sec. 34, T7N, R10W, S.M. @ 6018' TVD At Total Depth 1796' FNL, 1889' FWL, Sec. 34, T7N, R10W, S.M. @ 15610' TVD 5. Elevation in feet (indicate KB, DF, etc.) 27' RT-GL 12. Date Spudded N/A 7. Total Depth (MD+TVD) 15,926' MD, 15,610' TVD 6. Lease Designation and Serial No. A-028083 13. Date T.D. Reached N/A 18. Plug Back Depth (MD+TVD) 10,400' MD. 10,337' TVD 9. Unit or Lease Name Beaver Creek Unit 10. Well Number 11. Field and Pool Tyonek Un-named Beaver Creek Field ate Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions ,,~ ~ /~/¢,/ I N/A feetMSL two I;19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost /YesE]N° ~ I N/A feet MD I N/A 22. Type Electric or Other Logs Run USlT 23 CASING, LINER AND CEMENTING RECORD I SETTING DEPTH MD CASING13-3/8"SIZE WT.68PER& 72FT' GRADEN_80 IITOP0 BOTTOM4022, HOLE SIZE CEMENTING2400 sks RECORD AMOUNTN/A PULLED 9-5/8" 47 & 53.5 N-80, C-75, P-110 0 12,331' 3388 sks N/A 7" 32 P-110 11,446' 14,980' 652 sks N/A 5" 18 N-80 14,681' 15,889' 450 sks N/A 25. TUBING RECORD 124. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) Tyonek MD- 9120'-9155', 9866'-9886' MD Tyonek TVD - 9107'-9141', 9824'-9844' TVD SIZE DEPTH SET (MD) SS - 2.875" 6218' LS - 3.500" 8987' 26. PACKER SET (MD) 5852' (CT dual) 6911' (SAB single) ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) N/A L ~"~ OCT O cuu, 27. Date First Production 24-Sep-03 Date of Test 9~25~2OO3 Flow Tubing Pres. 750 Hours Tested 24 Casing Pressure 0 28. PRODUCTION TEST I Method of Operation (Flowing, gas lift, etc.) Upper Beluga Interval Test Results, Tyonek Interval Resumed Production on ~ 727 MSCFPD PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL ICHOKE'SlZE '~' IGAS-OIL RATIO TEST PERIOD· · 0 727 0.2 ] I N/A 24-HouRCALCULATEDRATE·· OIL-BBL GAS-MCF WATER-BBL lOlL GRAVITY-APl Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Interbedded sandstone, siltstone, shale, and coal Form l"~L'~j]? ......... Rev. 7-1-80 N:\drlg\kgflwelIs\KBU33-6~AOGCOMPL Tyonek.xls CONTINUED ON REVERSE SIDE Submit in Triplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered NAME MEAS. DEPTH TRUE VERT. DEPTH and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS Daily operations summary, wellbore schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,,~')~,~~f.~.,,,,c.,.~...~~ DonaldEynon Title Production Engineer Date 10/2/2003 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 (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 N:\drlg\sterling\su32-9~AOGCOMPL Tyonek.xls BC-6 APl: 50-133-20346 AOGCC: 181-150 RT-GL: 27.0' (Original) RT-GL: 21.0' (Workover 2003) 1164' FNL, 1487' FWL Sec 34, T7N, R10W, S.M. Tree cxn = 3-1/2" EUE 8rd 3", 5-bolt crescent flange cap Lift threads = 3.725" MCA Shortstrin.q - 2.875", 6.4#, L-80, EUE 8rd-Mod Tubing Baker injection nipple @ 1162' GT dual packer @ 5852' X-nipple at 5904' ID = 2.313" Wireline re-entry guide at 6218' Shortstrin.q Perfs (Beluga) 6018'- 6031' 4spf8/7/03 6080' - 6095' 4spf 8/7/03 6112' - 6118' 4spf 8/7/03 6125' - 6134' 4spf 8/6/03 6140' - 6149' 4spf 8/6/03 6165' - 6179' (4spf 8/4/03, 6spf 5/29) .Lon,qstrin,q Perfs (Tyonek) 9120' - 9155' (6 spf, 12/96 & 2/97) 9866' - 9886' (6 spf, 2/4/96) IFill at 10,235' (3/29/01) I Cement retainer @ 10400' (1/21/96) Cement retainer @ 11200' (1/17/96) Cmt plug 11,360' - 11,560' CIBP @ 14647' capped w/200' cmt (6/82) CIBP @ 15280' capped w/22' sand & cmt (5/82) I TD=15,928 ] Well Name & Number: County or Parish: I Perforations (MD) Angle/Perfs I Dated Completed: ~Prepared By: Baker injection nipple w/dual checks, and 1/4" OD, 0.049" wall SS control line SS - 1162' LS - 1203' Surface Casinq: 13-3/8", 68 & 72 ppf, N- 80, BTC @ 4022' Cmt w/2400 sks of c ass G ISqz perfs 5095'-5184', tested to 14.1 ppg EMW I Baker GT dual packer @ 5852' with 60K shear ring Longstrinq - 3.5", 9.3#, L-80, EUE 8rd-Mod Tbg Note: P-110 tubing between dual packer and SAB packer at 6911'. Baker injection nipple @ 1203' Baker GT Dual packer @ 5852' Tubing Patch Set in LS @ Top of patch set at 6161' KB and bottom of patch at 6182.6' KB, across Beluga perforations 6165'-6t79' MD ID=2.25" CMU sliding sleeve @ 6254' ID = 2.813" 10' Seal assembly (OD = 4.00") 80-40 K-Anchor @ 6909' Baker 194 SAB 40x32 Packer @ 6911' ID = 3.250" Camco X-Nipple @ 6965' ID = 2.813" Camco X-Nipple @ 8962' ID = 2.813" Wireline Re-Entry @ 8987' Prod. Casin.q: 9-5/8", 47 & 53.5 ppf, N-80, BTC @ 12,410' Cmt w/3388 sks of class G (1588 sks 1st stage, 1800 sks 2nd stage) 0' - 5754', 47 ppf, N-80 5754'- 6355', 53.5 ppf, C-75 6355' - 6983', 53.5 ppf, N-80 6983' - Cementing stage tool 6985' - 8565', 53.5 ppf, N-80 8565' - 9615', 47 ppf, P-110 9615' - 12,331', 53.5 ppf, P-110 Notes: Frac stimulated the Tyonek D-1 interval (9866'- 9886') on 3/17/01. Placed 58,000 lbs of 20/40 Carbolite in 357 bbl of SuperRheogel in diesel. L.i.ner: 7", 32 ppf, P-110, BTC @ 11,446' - 14,980' Cmt w/852 sks of class G Liner: 5", 18 ppf, N-80, BTC @ 14,681'- 15,889' I Cmt wi 450 sks of class G I BC-6 Lease: Kenai State/Prov. Alaska (TVD) Angle @ KOP and Depth BHT: I I Completion Fluid: 3/24/2003I J.G. Eller I Last Revison Date: I Beaver Creek Field IC°untry: 9/30/2003 DEE I Inactive Perfs Sterling (above the dual packer): 5095' - 115' (sqz'd 3/03) 5132'- 142' (sqz'd 3/03) 5174' - 184' (sqz'd 3/03) G-Zone: 15170' - 200' 15085' - 128' 15003' - 050' Hemlock: 15520' - 546' 15476' - 506' 15414' - 466' 15387' - 407' 15345' - 370' 15306' - 326' Daily Summary for Well: BEAVER CREEK 6 Report Report MD TVD Summary Date Number 2003 Recompletion Event: 28-Feb-03 1 04-Mar-03 2 07-Mar-03 3 10-Mar-03 4 11-Mar-03 5 12-Mar-03 6 13-Mar-03 7 14-Mar-03 8 MIRU slickline. Run static BHP survey. RDMO. Set PX plug at 8974'. Replace chemical injection valve at 966' with dummy valve. Load tubing with produced water. Set BPV, prep wellhead and tree. R/U rig. R/U rig. R/U rig. Fin RU drilling rig. Check for pressure & remove tree. NU BOPE. NU & test BOPE. Run free point, pipe free, attempt to back out of K-anchor @ 6907' WLM. Run chemical cutter, cut tubing @ 6886' WLM. POOH w/W/L. 15-Mar-03 9 16-M ar-03 10 17-Mar-03 11 18-Mar-03 12 19-Mar-03 13 Circulate hole to fresh water. POOH, LD 3-1/2" tubing. Prepare to PU fishing tools & DP. TIH w/fishing tools. Engage & release anchor f/pkr. Circulate B/U. POOH, recover fish. TIH w/bit. TIH to SAB pkr @ 6904'. Circ B/U. POOH. Run USIT log. TIH & set RBP @ 5270'. Set sand plug. Tag @ 5254'. Squeeze perfs @ 5095' to 5184'. Finish squeeze job. Reverse clean. POOH. TIH w/bit to 5016', test casing to 3000 psi. Drill cmt f/5016' to 5194'. Casing test failed. POOH for second squeeze attempt. TIH w/O/E DP. Peform inj test. Squeze perfs. POOH. TIH w/bit. WOC. Drill cement f/4948' to 5194'. 20-Mar-03 14 CBU. Test perfs. Drill cmt to RBP. CBU. POOH. TIH, retrieve RBP, test casing/perfs, POOH. TIH w! stinger to C/O pkr. Circulate, sting in/sting out. CBU. 21-Mar-03 15 22-Mar-03 16 CBU. POOH LDDP. Set strom pkr. ND BOP. Install tubing spool. NU BOP. Replace element in annular preventer. Fin NU. Test BOPE. Ret storm pkr. LD BHA. Change rams. Strap & drift 2-7/8" & 3-1/2" production tubing. Printed - 10/2/2003 Daily Summary for Well: BEAVER CREEK 6 Report Report MD TVD Summary Date Number 23-Mar-03 17 24-Mar-03 18 Strap & drift tubing. Run dual 3-1/2"/2-7/8" production string. Finish running dual completion tubing & equipment. Latch K-anchor, shear out of PBR. Displace ST annulus to completion fluid. Sting into PBR, land tubing hanger. Set dual pkr, test below pkr, pkr set OK. Back out landing jts, set BPV's. 25-Mar-03 19 26-Mar-03 20 RD control line running equipment. Change rams in BOP. ND BOP. Install & test production tree. Set BPV's. RDMO. Finish RD, ready to move rig. 25-Apr-03 21 Pull BPVs, hang wing valves and SSVs, pressure test. 26-Apr-03 22 29-May-03 23S 30-May-03 24S 30-May-03 24L 01-Jun-03 25 26-Jun-03 26 29-Jul-03 27 30-Jul-03 28 31-Jul-03 29 Tag fill in LS at 6917'. Open sliding sleeve. Circulate nitrogen to purge wellbore. Close sliding sleeve. Run GPJCCL tie in log. Perf 6165'-6179', guns briefly stuck, POH. Run 2nd guns, stuck again, POH. RD e- line. RU slickline. Tag at 6165', correlated to X-nipple. Pressure up shod string tubing, and long string pressure tracks. RIH with LIB to 6175'. Indications of tubing damage. RD, move to Iongstring. RU slickline on Iongstring. RIH with 2.80" gauge ring, briefly tag at 6161'. RIH with 2.85" gauge ring, have to work through 6151'- 6161' WLM, which corresponds to short string perfs. POH, RDMO. Bleed off pressure on both strings. Run camera in Iongstring, observe perforated 3-1/2" tubing. Run camera in shod string, observed 2-7/8" tubing to be significantly split apart. POOH, RDMO. MIRU Schlumberger wireline. Surveyed shodstring and Iongstring tubing with POT-C and memory r~ Gyro to establish downhole tubular geometry. Wait on Schlumberger Coil Tubing Unit. Spotted and partially rigged up CT Unit. Wait on Schlumberger. Finished RU CT and N2. Finished RU CT. RIH with mill/motor to dress perf burrs in LS. Jet well dry to obstruction at 6942' MD. Printed - 10/2/2003 ,Daily Summary for Well' BEAVER CREEK 6 Report Report MD TVD Summary Date Number 01-Aug-03 30 02-Aug-03 31 03oAug-03 32 MIRU Pollard Slickline. Run LIB and pump bailer. [] Clean out fill in LS with coil tubing. Jet well dry. Trap 2000 psi nitrogen pressure on well. Pull PX prong/plug from X profile in LS. Run GR/CCL 5700-8800'. 04-Aug-03 33 Set Inflatable BP. Perf Beluga 6165'-6179' MD at 4 SPF. 05-Aug-03 34 Ran 2.75" OD gauge ring. Set Owen tubing patch in LS. 06-Aug-03 35 Pressure test LS patch. Perforate Beluga in SS with POT-C. 07-Aug-03 36 Perforate Beluga in SS with POT-C. 08-Aug-03 37 Pulled Baker Inflatable BP from LS with slickline. Printed o 10/2/2003 ~i STATE OF ALASKA ~i AL ,_.,A OIL AND GAS CONSERVATION CO ,SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well oILy] GAS~] SUSPENDEDE]] ABANDONED~ SERVICE[]]] 2. Name of Operator 7. Permit Number MARATHON OIL COMPANY 181-150 3. Address 8. APl Number P. O. Box 196168, Anchorage, AK 99519-6168 50-133-20346 Classification of Service Well 4. Location of Well at Surface 1164' FNL, 1487' FWL, Sec. 34, T7N, R10W, S.M. At top of Producing Interval 1162' FNL, 1467' FWL, Sec. 34, T7N, R10W, S.M. @ 6018' TVD At Total Depth 1796' FNL, 1889' FWL, Sec. 34, T7N, R10W, S.M. @ 15610' TVD 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 27' RT-GL I A-028083 12. Date Spudded 113. Date T.D. Reached N/A I N/A ! · , 7. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) [19. D~recbonal Survey 15,928' MD, 15,610' TVD 10,400' MD. 10,337' TVD / Yesr'-]N° [~ 22. Type Electric or Other Logs Run USIT 9. Unit or Lease Name Beaver Creek Unit 10. Well Number 11. Field and Pool Beluga Pool Beaver Creek Field 1~?~.~,6,.Me~~14. Da Comp., Susp. or Aband. 115. Water Depth,N/A if offshorefeet MSL 116. No. OftwoCOmpletions Depth where SSSV set 121. Thickness of Permafrost N/A feet MDI N/A 23 CASING, LINER AND CEMENTING RECORD I SETTING DEPTH MD CASING SIZE WT. PER FT. GRADEIITOP0 BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 68 & 72 N-80 4022' 2400 sks N/A 9-5/8" 47 & 53.5 N-80, C-75, P-110 0 12,331' 3388 sks N/A 7" 32 P-110 11,446' 14,980' 652 sks N/A 5" 18 N-80 14,681' 15,889' 450 sks N/A 25. 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) Beluga MD - 6018'-6031' 4spf, 6080'-6095' 4spf, 6112'-6118' 4spf, 6125'-6134' 4spf, 6140'-6149' 4spf, 6165'-6179' 10 spf MD' Beluga TVD - 6018'-6031', 6080'-6095', 6112'-6118', 6125'-6134', 6140'-6149', 6165'-6179' TVD SIZE SS - 2.875" LS - 3.500" 26. TUBING RECORD DEPTH SET (MD) IPACKER SET (MD) 6218' 5852' (CT dual) 8987' 6911' (SAB single) ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production 22-Aug-03 Date of Test Hours Tested 9/3O~2OO3 24 Flow Tubing Pres. 1650 IMethod of Operation (Flowing, gas lift, etc.) Flowing 28. IPRODUCTION FOR IOIL-BoBL ITEST PERIOD ~ IOIL'BBL Casing Pressure ICALCULATED 0 124-HOUR RATE---~ GAS-MCF WATER-BBL 5,956 53 GAS-MCF WATER-BBL ICHOKE SIZE IGAS-OIL I N/A OIL GRAVITY-APl (corr) RATIO Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Interbedded sandstone, siltstone, shale, and coal RECEIYFD OCT 0 6 2003 Form 10-407 Rev. 7-1-80 N:\drlg\kg~welI$\KBU33-6~,OGCOMPL Beluga.xls CONTINUED ON REVERSE SIDE Submit in Triplicate OCT 1 & 2 03 29. 30. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered NAME MEAS. DEPTH TRUE VERT. DEPTH and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS Daily operations summary, wellbore schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Donald Eynon Title Production Engineer Date 10/2/2003 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 (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 N :\drlg\sterling\su32-9~AOGCOMPL.xls BC-6 APl: 50-133-20346 AOGCC: 181-150 RT-GL: 27.0' (Original) RT-GL: 21.0' (Workover 2003) 1164' FNL, 1487' FWL Sec 34, T7N, R10W, S.M. Tree cxn = 3-1/2" EUE 8rd 3", 5-bolt crescent flange cap Lift threads = 3.725" MCA Shortstrin.q - 2.875", 6.4#, L-80, EUE 8rd-Mod Tubing Baker injection nipple @ 1162' GT dual packer @ 5852' X-nipple at 5904' ID = 2.313" Wireline m-entry guide at 6218' .Shortstring Peris (Beluga) 6018'- 6031' 4spf8/7/03 6080' - 6095' 4spf 8/7/03 6112' - 6118' 4spf 8/7/03 6125'- 6134' 4spf8/6/03 6140'- 6149' 4spf8/6/03 6165' - 6179' (4spf 8/4/03, 6spf 5/29) Lon~stdnq Perfs (Tvonek) 9120' - 9155' (6 spf, 12/96 & 2/97) 9866' - 9886' (6 spf, 2/4/96) IFill at 10,235' (3/29/01) I Cement retainer @ 10400' (1/21/96) Cement retainer @ 11200' (1/17/96) Cmt plug 11,360' - 11,560' CIBP @ 14647' capped w/200' cmt (6/82) CIBP @ 15280' capped w/22' sand & cmt (5/82) I TD= 15,928 Well Name & Number: County or Parish: Perforations (MD) Angle/Peris I Dated Completed: ,IPrepared By: BC-6 I Lease: Kenai I State/Pr°v' Angle @ KOP and Depth Baker injection nipple w/dual checks, and 1/4" OD, 0.049" wall SS control line SS - 1162' LS - 1203' ISurface Casing: 13-3/8", 68 & 72 ppf, N- 80, BTC @ 4022' Cmt w/2400 sks of class G ISqz peris 5095'-5184', tested to 14.1 ppg EMW I Baker GT dual packer @ 5852' with 60K shear dng Lon~strinq - 3.5", 9.3#, L-80, EUE 8rd-Mod Tbg Note: P-110 tubing between dual packer and SAB packer at 6911'. Baker injection nipple @ 1203' Baker GT Dual packer @ 5852' Tubing Patch Set in L$ @ Top of patch set at 6161' KB and bottom of patch at 6182.6' KB, across Beluga perforations 6165'-6179' MD ID=2.25" CMU sliding sleeve @ 6254' ID = 2.813" !10' Seal assembly (OD = 4.00") 80-40 K-Anchor @ 6909' Baker 194 SAB 40x32 Packer @ 6911' ID = 3.250" Camco X-Nipple @ 6965' ID = 2.813" Camco X-Nipple @ 8962' ID = 2.813" Wireline Re-Entry @ 8987' Prod. Casin.q: 9-5/8", 47 & 53.5 ppf, N-80, BTC @ 12,410' Cmt w/3388 sks of class G (1588 sks 1st stage, 1800 sks 2nd stage) 0' - 5754', 47 ppf, N-80 5754' - 6355', 53.5 ppf, C-75 6355' - 6983', 53.5 ppf, N-80 6983' - Cementing stage tool 6985' - 8565', 53.5 ppf, N-80 8565' - 9615', 47 ppf, P-110 9615'- 12,331', 53.5 ppf, P-110 Notes: Fmc stimulated the Tyonek D-1 interval (9866'- 9886') on 3/17/01. Placed 58,000 lbs of 20/40 Carbolite in 357 bbl of SuperRheogel in diesel. Liner: 7", 32 ppf, P-110, BTC @ 11,446' - 14,980' Cmt w/652 sks of class G Liner: 5", 18 ppf, N-80, BTC @ 14,681' - 15,889' Cmt w/450 sks of class G Beaver Creek Field Alaska IC°untry: I (TVD) BHT: I Completion Fluid: 3/24/2003 J.G. Eller I Last Revison Date: Inactive Peris Steding (above the dual packer): 5095' - 115' (sqz'd 3/03) 5132'- 142' (sqz'd 3/03) 5174'- 184' (sqz'd 3/03) G-Zone: 15170' - 200' 15085' - 128' 15003' - 050' Hemlock: 15520'-546' 15476'-506° 15414'-466' 15387'-407' 15345'-370' 15306'-326' I 9/30/2003 DEE I Daily Summary for Well: BEAVER CREEK 6 Report Report MD TVD Summary Date Number 2003 Recompletion Event: 28-Feb-03 1 04-Mar-03 2 07-Mar-03 3 10-Mar-03 4 11-Mar-03 5 12-Mar-03 6 13-Mar-03 7 14-Mar-03 8 MIRU slickline. Run static BHP survey. RDMO. Set PX plug at 8974'. Replace chemical injection valve at 966' with dummy valve. Load tubing with produced water. Set BPV, prep wellhead and tree. PJU rig. R/U rig. R/U rig. Fin RU drilling rig. Check for pressure & remove tree. NU BOPE. NU & test BOPE. Run free point, pipe free, attempt to back out of K-anchor @ 6907' WLM. Run chemical cutter, cut tubing @ 6886' WLM. POOH w/W/L. 15-Mar-03 9 16-Mar-03 10 17-Mar-03 11 18-M ar-03 12 19-Mar-03 13 Circulate hole to fresh water. POOH, LD 3-1/2" tubing. Prepare to PU fishing tools & DP. TIH w/fishing tools. Engage & release anchor f/pkr. Circulate B/U. POOH, recover fish. TIH w/bit. TIH to SAB pkr @ 6904'. Circ B/U. POOH. Run USIT log. TIH & set RBP @ 5270'. Set sand plug. Tag @ 5254'. Squeeze perfs @ 5095' to 5184'. Finish squeeze job. Reverse clean. POOH. TIH w/bit to 5016', test casing to 3000 psi. Drill cmt f/5016' to 5194'. Casing test failed. POOH for second squeeze attempt. TIH w/O/E DP. Peform inj test. Squeze perfs. POOH. TIH w/bit. WOC. Drill cement f/4948' to 5194'. 20-Mar-03 14 CBU. Test perfs. Drill cmt to RBP. CBU. POOH. TIH, retrieve RBP, test casing/perfs, POOH. TIH w/stinger to C/O pkr. Circulate, sting in/sting out. CBU. 21-Mar-03 15 22-Mar-03 16 CBU. POOH LDDP. Set strom pkr. ND BOP. Install tubing spool. NU BOP. Replace element in annular preventer. Fin NU. Test BOPE. Ret storm pkr. LD BHA. Change rams. Strap & drift 2-7/8" & 3-1/2" production tubing. Printed - 10/2/2003 Daily Summary for Well: BEAVER CREEK 6 Report Report MD TVD Summary Date Number 23-Mar-03 17 24-Mar-03 18 Strap & drift tubing. Run dual 3-1/2"/2-7/8" production string. Finish running dual completion tubing & equipment. Latch K-anchor, shear out of PBR. Displace ST annulus to completion fluid. Sting into PBR, land tubing hanger. Set dual pkr, test below pkr, pkr set OK. Back out landing jts, set BPV's. 25-Mar-03 19 26-Mar-03 20 RD control line running equipment. Change rams in BOP. ND BOP. Install & test production tree. Set BPV's. RDMO. Finish RD, ready to move rig. 25-Apr-03 21 Pull BPVs, hang wing valves and SSVs, pressure test. 26-Apr-03 22 29-May-03 23S 30-May-03 24S 30-May-03 24L 01-Jun-03 25 26-Jun-03 26 29-Jul-03 27 30-Jul-03 28 31-Jul-03 29 Tag fill in LS at 6917'. Open sliding sleeve. Circulate nitrogen to purge wellbore. Close sliding sleeve. Run GR/CCL tie in log. Perf 6165'-6179', guns briefly stuck, POH. Run 2nd guns, stuck again, POH. RD e- line. RU slickline. Tag at 6165', correlated to X-nipple. Pressure up shod string tubing, and long string pressure tracks. RIH with LIB to 6175'. Indications of tubing damage. RD, move to Iongstring. RU slickline on Iongstring. RIH with 2.80" gauge ring, briefly tag at 6161'. RIH with 2.85" gauge ring, have to work through 6151' - 6161' WLM, which corresponds to short string perfs. POH, RDMO. Bleed off pressure on both strings. Run camera in Iongstring, observe perforated 3-1/2" tubing. Run camera in shod string, observed 2-7/8" tubing to be significantly split apart. POOH, RDMO. MIRU Schlumberger wireline. Surveyed shortstring and Iongstring tubing with POT-C and memory r3 Gyro to establish downhole tubular geometry. Wait on Schlumberger Coil Tubing Unit. Spotted and partially rigged up CT Unit. Wait on Schlumberger. Finished RU CT and N2. Finished RU CT. RIH with mill/motor to dress perf burrs in LS. Jet well dry to obstruction at 6942' MD. Printed - 10/2/2003 Daily Summary for Well: BEAVER CREEK 6 Report Report MD TVD Summary Date Number 01-Aug-03 30 02-Aug-03 31 03-Aug-03 32 04-Aug-03 33 05-Aug-03 34 06-Aug-03 35 07-Aug-03 36 08-Aug-03 37 MIRU Pollard Slickline. Run LIB and pump bailer. [] Clean out fill in LS with coil tubing. Jet well dry. Trap 2000 psi nitrogen pressure on well. Pull PX prong/plug from X profile in LS. Run GPJCCL 5700-8800'. Set Inflatable BP. Perf Beluga 6165'-6179' MD at 4 SPF. Ran 2.75" OD gauge ring. Set Owen tubing patch in LS. Pressure test LS patch. Perforate Beluga in SS with POT-C. Perforate Beluga in SS with POT-C. Pulled Baker Inflatable BP from LS with slickline. Printed - 10/2/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS g:\cmn\drlg\bc\wells\bc9~AOGCC01 .xls 1. Type of Request: Abandon Alter Casing Change Approved Program Suspend Operation Shutdown Repair Well Plugging __ Pull Tubing. Variance Re-enter Suspended Well Time Extension Stimulate .. , Perforate Other X 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 1164' FNL, 1487' FWL, Sec. 34, T7N, R10W, S.M. At top of Productive Interval 1151' FNL, 1579' FWL, Sec. 34, TTN, R10W, S.M. @ 9107' TVD At Effective Depth 1234' FNL, 1925' FWL, Sec. 34, T7N, R10W, S.M. @ 10337' TVD At Total Depth 1796' FNL, 1889' FWL, Sec. 34, T7N, R10W, S.M. @ 15610' TVD 5. Type of Well: Development X Exploratory __ Stratigraphic m Service Install velocity string 6. Datum Elevation (DF or KB) 185' KB MSL feet 7. Unit or Property Name Beaver Creek Unit 8. Well Number SC-r:C'f 9. Permit Number 181-15o / lO. APl Number 50-133-20346 J 11. Field/Pool Beaver Creek Field, Tyonek 12. Present Well Condition Summary Total Depth: measured true vertical 15928 feet Plugs (measured) 15610 feet 10400',11200',11360',14447',14647', 15260',15280' Effective Depth: measured true vertical 10400 feet Junk (measured) 10337 feet Fill - 10235 (3/29/2001) Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented 4022 13-3/8" 2400 sks 12410 9-5/8" 3388 sks 3534 7" 652 sks 1208 5" 450 sks Tyonek: 9120'- 9155', 9866'- 9886' MD true vertical Tyonek: 9107' - 9141', 9824' - 9844' TVD Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 to 8998' Packers and SSSV (type and measured depth) Baker model 194 SAB 40x32 Packer @ 6911' Baker model GT dual packer at 5852' Measured Depth 4022 12410 14980 15889 True Vertical Depth 4O22 12228 14674 15581 RECEIVED MAY 2 1 2003 0i,~ & Gas Cons. 13. Attachments Description Summary of Proposal X Detailed Operations Program 14. Estim~e'8 Dat.¢ for Commencing Operation 15. Status of Well Classification as: / 5-Jun~3 16. If Pr~ap~'~as Verbally Approved Oil Gas X Name ~pprover ~. Date Approved Service 17. I hereby ~,fy that the fozg~,~g is true and correct to the best of my knowledge. Signed ~.._ _'~_~.~ ~,.., Gary Eller Title Production Engineer Conditions of Approv~al: '"No~ C~m mission so representati~?RmaCyO~MitnM;sSsSION UsE ONLY BOP Sketch Suspended Plug Integrity BOP Test X Location Clearance Mechanical Integrity Test__ Subsequent Form Required 10- Approved by Order of the Commission Form 10-403 Rev. 06/15/88 ~BDMS BFL ORIGINAL Date 5/15/2003 IAppr°va' N°~) ,..~../,.~ q Commissioner Date Su~mit~n Triplicate BC-6 - Proposed V-String APl: 50-133-20346 AOGCC: 181-150 RT-GL: 27.0' (Original) RT-GL: 21.0' (Workover 2003) 1164' FNL, 1487' FWL Sec 34, TTN, R10W, S.M. Tree cxn = 3-1/2" EUE 8rd 3", 5-bolt crescent flange cap Lift threads = 3.725" MCA Shortstrin.q - 2.875", 6.4#, L-80, EUE 8rd-Mod Tubing Baker injection nipple @ 1162' ,GT dual packer @ 5852' X-nipple at 5904' ID --- 2.313" Wireline re-entry guide at 6218' Shortstrin.q Perfs (Beluga) 6018' - 6031' 608O' - 6095' 6112' 6118' 6125' - 6134' 6140' - 6149' 6165' - 6179' Lon.qstrin.q Perfs (Tyonek) / 9120' - 9155' (6 spf, 12/96 & 2/97) 9866' - 9886' (6 spf, 2/4/96) Baker injection nipple w/dual checks, and 1/4" OD, 0.049" wall SS control line SS - 1162' LS - 1203' Surface Casing: 13-3/8", 68 & 72 ppf, N- 80, BTC @ 4022' ICmt w/2400 sks of c ass G ISqz perfs 5095'-5184', tested to 14.1 ppg EMW I Baker GT dual packer @ 5852' with 60K shear dng Notes: Frac stimulated the Tyonek D-1 interval (9866' - 9886') on 3/17/01. Placed 58,000 lbs of 20/40 Carbolite in 357 bbl of SuperRheogel in diesel. Lon.qstrin.q - 1.75" coil tubing ~,on~stdn¢~ - 3.5", 9.3#, L-80, EUE 8rd-Mod Tbgj velocity string hung from surface. "N,,ote: P-110 tubing between dual packer and//' The velocity string blocks access to "X SAB packer at 6911'. ~ the permanent Iongstdng completion jewelry shown to the Baker injbqtion nipple @ 1203' ~ Baker GT ker @ 5852' Coil - 1.75" OD, 0.125" wall, HO-70 grade, flash present, CMU sliding sleevb, x@ 6254' ~ 0'- 9866' ID: 2.813" ~/ Straightening bar and landing nipple 110' Seal assembly (OD ~)aX.00") at the coil tubing tail at 9866' 180-40 K-Anchor @ 69/09' ~ ID = 1.268" IBaker 194 SAB 40x/32 Packer~ 6911' ICamco X-Ni~51e @ 6965' X I ID = 2.8/1'3" ~ ine Re-Entry @ 8987' ~ IFill at 10,235' (3/29/01) I Cement retainer @ 10400' (1/21/96) Cement retainer @ 11200' (1/17/96) Cmt plug 11,360' - 11,560' CIBP @ 14647' capped w/200' cmt (6/82) CIBP @ 15280' capped w/22' sand & cmt (5/82) IWell Name & Number: County or Parish: Perforations (MD) I TD=15,928 Angle/Perfs I IDated Completed: IPrepared By: Prod. Casinq: 9-5/8", 47 & 53.5 ppf, N-80, BTC @ 12,410' Cmt w/3388 sks of class G (1588 sks 1st stage, 1800 sks 2nd stage) 0' - 5754', 47 ppf, N-80 5754' - 6355', 53.5 ppf, C-75 6355' - 6983', 53.5 ppf, N-80 6983' - Cementing stage tool '6985' - 8565', 53.5 ppf, N-80 8565' - 9615', 47 ppf, P-110 9615' - 12,331', 53.5 ppf, P-110 Liner: 7", 32 ppf, P-110, BTC @ 11,446' - 14,980' Cmt w/652 sks of class G Liner: 5", 18 ppf, N-80, BTC @ 14,681'- 15,889' Cmt w/450 sks of class G BC-6 I Lease: Kenai State/Prov. Alaska (TVD) Angle @ KOP and Depth BHT: I I Completion Fluid: 3/24/2003I J.G. Eller I Last Revison Date: I Beaver Creek Field IC°untry: 4/28/2003 I inactive Perfs Steding (above the dual packer): 5095' - 115' (sqz'd 3/03) 5132' - 142' (sqz'd 3/03) 5174'- 184' (sqz'd 3/03) G-Zone: 15170'-200' 15085'-128' 15003'-050' Hemlock: 15520'~546' 15476'-506' 15414'-466' 15387'-407' 15345'-370' 15306'-326' Well BC-61 Velocity String Installation Beaver Creek Field, Pad 3 WBS #WO.03.08983.EXP Objective- Install a 13/4" velocity string in well BC-61 to improve liquid removal and improve production from this Tyonek Sand completion. Background - Well BC-6 is currently completed as a dual producer in the Bel/uga and Tyonek Sands. A PX plug was set in the longstring in the X-nipple at 8962'.' Wireline verified an obstruction in the tubing in the vicinity of the packer at 6917'. Coiled tubing will be used to clean out to the top of PX plug and pull the PX prong. Slickline will pull the PX plug body. BJ Coiltech will then install the velocity string to the top of the f Tyonek D-1 perforations at 9866'. Procedure MIRU BJ 13/4" coil tubing and nitrogen. Conduct prejob safety meeting. Spot CTU with 1 ¥4" x 9500' CT work reel, spooling unit containing 10,200' of 13/4", 0.125" wall thickness, HO-70 velocity string, pumping equipment, fluid and flowback tanks. RU pumping and flowback iron. Blend 300 bbl of 6% KC1. Stab CT work string in injector. Make up CT connector. Pull test CT connector to 15,000 lbs. Make up toolstring with wash tool and motor head assembly. 2. Nipple up BOPE and 4" work window, and test to 250/4500 psi. Test flowback iron to 250/3500. . Bleed offWHP. RIH with well open to the flowback tank. Start fluid pump ~ 6000' while proceeding in hole watching for obstruction/fill at +6900'..(Note: Tubing capacity minus coil displacement to the obstruction at 6917' is 40 bbl. Tubing capacity minus coil displacement to the PX plug at 8962' is 51 bbl.) 4. After establishing top of obstruction increase pump rate to 3 bbl/min and wash off at 15'/min. At indication of fill removal hold and pump bottoms up at 3 bbl/min. o RIH watching for further fill at 30'/min and 1.5 bbl/min. When fill is encountered slow pipe rate to 15'/min and increase pump rate to 3 bbl/min. Wash to top of PX f plug at 8962'. Circulate bottoms up at 3 bbl/min. (Note: Contingency plans for removal of debris on top of the plug should include availability of a Venturi junk basket in case the debris is made of metal fragments. Also, a contingency plan should be made for severing the 3 ½" tubing above the PX plug in case the plug is stuck.) 6. Stop fluid pump and start N2 pump at 1000 scfm. Strap return tanks for fluid returns. Displace wellbore fluid for total recovery of 4-81 bbl (assumes 30 bbl coil capacity). J. G. Eller- 5/19/2003 Well BC-6 Velocity String WO.03.08983.EXP Page 2 Stop N2 pump. Allow wellhead pressure to bleed to +2000 psi before shutting well in. o Latch PX plug prong ~ 8962' by setting down pipe weight. Pull prong with straight pickup on the coil. Monitor WHP for indication that prong was removed. POOH. o RD injector and remove toolstring. Set injector on ground and chain and secure injector. Remove workstring coil tubing from injector and stab 13/4" CT velocity string in injector. MU pump-out plug and straight-bar onto the end of the velocity string. . MIRU slickline unit. Slickline will RU on top of coil BOPE (3-1/16", 10M Bowen). Conduct prejob safety meeting and test BOPE. RIH with 2½" impression block. Tag top of PX plug body at 8962', POOH. MU pulling tool for PX plug body and R1/-I. Latch plug body, POOH. RDMO slickline. 10. RU injector to WHA and pressure test WHA (2000 psi). RIH with coil tubing velocity string to 9866' less distance from coil tubing lock down pins to cut point on the coil. 11. Set BOP tubing rams and slip rams. Slack offpipe weight to verify slips are holding string weight. Bleed off WHP above tubing rams, and verify that plug in the coil is holding. Open window access area. Install back up clamp on CT. Cut coil tubing f velocity string. 12. Install ABB Vetco coil hanger mandrel on top of velocity string. Make up mechanical GS profile tool string at end of CTU and latch onto coil hanger. 13. Remove backup clamp and close window. Equalize pressure across tubing rams and open tubing rams. Pull test GS profile connection to 18,000 lbs. Open slip rams. 14. Land coil hanger into tubing head and set lock-down screws onto the hanger. Release GS profile connection by setting down ~ weight onto the coil tubing hanger. PU to verify that GS is released. Bleed off wellhead pressure to verify that the coil hanger is holding pressure. 15. Pressure up velocity string with nitrogen to blow out coil tubing plug. Shut down nitrogen pumping when confident that the plug is removed. 16. Flow well through coil tubing velocity string to flowback tank. (Note: Can optionally circulate nitrogen down the coil tubing annulus if it has difficulty kicking off.) Verify tubing hanger assembly is holding pipe weight and pressure, then shut in well. RDMO coil tubing. 17. Produce well to sales as per instructions of Production Engineer. , J. G. Eller-5/19/2003 Updated Surface Locations, Beaver Creek Subject: Updated Surface Locations, Beaver Creek Date: Tue, 20 May 2003 11:10:32 -0800 From: "Eller, John G." <JGEller~MarathonOil.com> To: "Bob Fleckcnstein (E-mail)" <bob_fleckenstein~admin.state.ak.us> CC: "Tank, Will" <WJTank~MarathonOil.com> '[ Type: Plain Text (text/plain) ~P.art 1.1 ]Encoding: quoted-printable I o fl 5/20/2003 11:30 AM Bob - Your question regarding the surface location of well BC-6 is similar to a question that arose recently regarding well BC-3rd. In an e-mail of 4/1/03, Will Tank described(' 'ou that the surface location of BC-3 was ~ 'e accurately assessed in 1992 using improved surveying methods. The same e~,.,anation applies to wells BC-6 and BC-5rd. ' for your convenience, I have tabulated below the updated surface coordinates for wells BC-3rd, BC-5rd, and BC-6. I want to emphasize that these are not new wells, but simply updated, more accurate surface locations for the old wells. Please update your files to reflect these surface locations. BC-3rd: 1227' FNL, 1501' FWL, Sec. 34, T7N, R10W, S.M. BC-5rd: 1195' FNL, 1495' FWL, Sec. 34, T7N, R10W, S.M. BC-6: 1164' FNL, 1487' FWL, Sec. 34, T7N, R10W, S.M. J. Gary Eller Operations Engineer Alaska Region, Marathon Oil Company 907-564-6315 RE: Updated Surface Locations, Beaver Creek Subject: RE: Updated Surface Locations, Beaver Creek Date: Tue, 20 May 2003 14:06:03 -0800 From: "Eller, John G." <JGEller~MarathonOil.com> To: "Bob Fleckenstein" <bob_fleckcnstcin~admin.state.ak.us> CC: "Tank, Will" <WJTank~MarathonOil.com> Bottomhole locations: BC-3 (original hole, not the 2003 redrill): 934' FSL, 3625' FWL, Sec. 27, T7N, R10W, S.M. @ 6387' MD BC-5rd: 723' FSL, 3195' FWL, Sec. 27, T7N, R10W, S.M. ~ 15,655' MD Bg2.-6: t~¢~' FAIL.,. 53.90.' F~,L~ Sec. 3&, T7N, R10W, S.M. ¢ 15,8'44-' F~D. ..... Original Message ..... From: Bob Fleckenstein [mailto:bob_fleckensteinOadmin.state.ak.us] Sent: Tuesday, May 20, 2003 11:29 AM To: Eller, John G. Subject: Re: Updated Surface Locations, Beaver Creek Gary, Please send me the revised bottom hole locations on the three wells as well. Thanks, BobF "Eller, John G." wrote: > Part 1.1 Type: Plain Text (text~plain) > Encoding: quoted-printable I ofl ,SGAi NEE 2 2003 5/20/2003 3:13 PM "SL STATE OF ALASKA f( .... ALA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well oILE--] GAsE~ SUSPENDEDE] ABANDONEDI--] SERVICE[--] 2. Name of Operator 7. Permit Number MARATHON OIL COMPANY 181-150 3. Address 8. APl Number P. O. Box 196168, Anchorage, AK 99519-6168 50-133-20346 Classification of Service Well 4. Location of Well at Surface 1164' FNL, 1487' FWL, Sec. 34, T7N, R10W, S.M. At top of Producing Interval At Total Depth 1796' FNL, 1889' FWL, Sec. 34, T7N, R10W, S.M. @ 15610' TVD 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 27' RT-GL I A-028083 9. Unit or Lease Name Beaver Creek Unit 10. Well Number BC-6 11. Field and Pool Beluga & Tyonek Pools Beaver Creek Field 12. Date Spudded 113. Date T.D. Reached 114.Date Comp., Susp. or Aband. 115' Water Depth, if offshore 116' No. of Completions N/A I N/A I 26-Mar-03 I N/A feet MSL ~ two 7. Total Depth (MD+TVD)18. Plug Back Depth (MD+TVD)MD. 19.Directional Survey~ ~--~ 120. Depth where SSSV set 121. Thickness of Permafrost 15,928' MD, 15,610' TVD 10,400' 10,337' TVD Yes, ,No, , N/A feet MD N/A 22. Type Electric or Other Logs Run USlT 23 CASING, LINER AND CEMENTING RECORD I SETTING DEPTH MD CASING SIZE WT. PER FT. GRADEIITOP0 BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 68 & 72 N-80 4022' 2400 sks N/A 9-5/8" 47 & 53.5 N-80, C-75, P-110 0 12,331' 3388 sks N/A 7" 32 P-110 11,446' 14,980' 652 sks N/A 5" 18 N-80 14,681' 15,889' 450 sks N/A 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) Beluga MD (proposed) - 6018'-6031', 6080'-6095', 6112'-6118' 6125'-6134', 6140'-6149', 6165'-6179' MD' Beluga TVD (proposed) - 6018'-6031', 6080'-6095', 6112'-6118', 6125'-6134', 6140'-6149', 6165'-6179' TVD Tyonek MD - 9120'-9155', 9866'-9886' MD Tyonek TVD - 9107'-9141 ', 9824'-9844' TVD 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) SS - 2.875" 6218' 5852' (GT dual) LS - 3.500" 8987' 6911' (SAB single) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production N/A Date of Test Hours Tested Flow Tubing Pres. Casing Pressure 28. IMethod of Operation (Flowing, gas lift, etc.) Beluga completion not yet perforated and producing IPRODUCTION FOR OIL-BBL GAS-MCF TEST PERIOD > CALCULATED IO L-BBL GAS-MCF 24-HOUR RATE ~. I WATER-BBL WATER-BBL ICHOKE SIZE IGAS-OIL OIL GRAVITY-APl (corr) RATIO Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Interbedded sandstone, siltstone, shale, and coal RECBVED 16 20¢ Form 10-407 Rev. 7-1-8~CANNED ~AY ~ 1 21 03 N :\drlg\kgflwells\KBU33-6~AOGCOMPLxls CONTINUED ON REVERSE ORI61NAL Submit in Triplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered NAME MEAS. DEPTH TRUE VERT. DEPTH and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS Daily operations summary, wellbore schematic, directional survey 32. I hereby ce~n"""~that the foregoing~ true and correct to the best of my knowledge \ 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 (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 N:\drlg\sterling\su32-9~AOGCOMPL.xls 2003 APl: 50-133-20346 AOGCC: 181-150 RT-GL: 27.0' (Original) RT-GL: 21.0' (Workover 2003) 1164' FNL, 1487' FWL Sec 34, T7N, R10W, S.M. Tree cxn = 3-1/2" EUE 8rd 3", 5-bolt crescent flange cap Lift threads = 3.725" MCA Shortstdn.q - 2.875", 6.4#, L-80, EUE 8rd-Mod Tubing Baker injection nipple @ 1162' GT dual packer @ 5852' X-nipple at 5904' ID = 2.313" Wireline re-entry guide at 6218' Sho~stdn.q Peris(Belu.qa) 6018'-6031' 6O8O'-6O95' 6112'-6118' 6125'-6134' 6140'-6149' 6165'-6179' Lon,qstring Perfs (Tyonek) 9120'-9155' (6 spf, 12/96 & 2/97) 9866' - 9886' (6 spf, 2~4~96) b1 .1 BC-6 Bakerinjection nipple w/dualchecks, and 1/4" OD, 0.049" wallSS controlline SS-1162' LS-1203 Surface Casin.q: 13-3/8", 68 & 72 ppf, N- 80, BTC @ 4022' Cmt w/2400 sks of class G Baker GT dual packer @ 5852' I with 60K shear ring I Lon,qstdn.q - 3.5", 9.3#, L-80, EUE 8rd-Mod Tbg Note: P-110 tubing between dual packer and SAB packer at 6911'. Baker injection nipple @ 1203' Baker GT Dual packer @ 5852' CMU sliding sleeve @ 6254' ID = 2.813" 10' Seal assembly (OD = 4.00") 80-40 K-Anchor @ 6909' Baker 194 SAB 40x32 Packer @ 6911' ID = 3.250" Camco X-Nipple @ 6965' ID = 2.813" Camco X-Nipple @ 8962' ID = 2.813" - PX plug set 314/03 Wireline Re-Entry @ 8987' Notes: Frac stimulated the Tyonek D-1 interval (9866' - 9886') on 3/17/01. Placed 58,000 lbs of 20/40 Carbolite in 357 bbl of SuperRheogel in diesel. IFill at 10,235' (3/29/01) I Cement retainer @ 10400' (1/21/96) Cement retainer @ 11200' (1/17/96) Cmt plug 11,360' - 11,560' CIBP @ 14647' capped w/200' cmt (6/82) CIBP @ 15280' capped w/22' sand & cmt (5/82) IWell Name & Number: County or Parish: Perforations (MD) Angle/Perf~ ,[ ,-.~---- BHP: I Dated Completed: Prepared By: I TD= 15,928 I Pred. Casin.q:9-5/8",47 & 53.5 pp~ N-80, BTC@12,410' Cmtw/3388 sks ofclass G (1588 sks lststage, 1800 sks 2nd s~ge) 0'-5754',47 pp~ N-80 5754'-6355',53.5 pp~ C-75 6355'-6983',53.5 pp~ N-80 6983'-Cementing s~ge ~ol 6985'-8565',53.5 pp~ N-80 8565'-9615',47 ppf, P-110 9615'-12,331',53.5 ppf, P-110 Liner: 7", 32 ppf, P-110, BTC @ 11,446' - 14,980' Cmt w/652 sks of class G Liner: 5", 18 ppf, N-80, BTC @ 14,681' - 15,889' I Cmt w/450 sks of class G I I BC-6 I Lease: I Kenai I State/Pr°v' I Alaska I (TVD) .... ~_n~]le..@~.KOP and Depth I BHT: I ' I Completion Fluid: 3/24/2003 I J.G. Eller I Last Revison Date: I Beaver Creek Field Ic°untry: I 4~28/2003 Inactive Perfs Sterling (above the dual packer): 5095'- 115' (sqz'd 3/03) 5132'- 142' (sqz'd 3/03) 5174'- 184' (sqz'd 3/03) G-Zone: 15170'-200' 15085'-128' 150O3'-050' Hemlock: 15520'-546' 15476'-506' 15414'-466' 15387'-407' 15345'-370' 15306'-326' Daily Summary for Well: BEAVER CREEK 6 Report Report MD TVD Daily Cost Summary Date Number Workover Event: 28-Feb-03 1 $3,725 04-Mar-03 2 $4,181 07-Mar-03 3 $1,330 10-Mar-03 4 $21,235 11-Mar-03 5 $20,300 12-Mar-03 6 $24,928 13-Mar-03 7 $20,943 14-Mar-03 8 $25,955 MIRU slickline. Run static BHP survey. RDMO. Set PX plug at 8974'. Replace chemical injection valve at 966' with dummy valve. Load tubing with produced water. Set BPV, prep wellhead and tree. R/U rig. R/U rig. R/U rig. Fin RU drilling rig. Check for pressure & remove tree. NU BOPE. NU & test BOPE. Run free point, pipe free, attempt to back out of K-anchor @ 6907' WLM. Run chemical cutter, cut tubing @ 6886' WLM. POOH w/W/L. 15-Mar-03 9 $79,759 16-Mar-03 10 $22,164 17-Mar-03 11 $46,312 18-Mar-03 12 $37,940 19-Mar-03 13 $42,567 Circulate hole to fresh water. POOH, LD 3-1/2" tubing. Prepare to PU fishing tools & DP. TIH w/fishing tools. Engage & release anchor f/pkr. Circulate B/U. POOH, recover fish. TIH w/bit. TIH to SAB pkr @ 6904'. Circ B/U. POOH. Run USIT log. TIH & set RBP @ 5270'. Set sand plug. Tag @ 5254'. Squeeze perfs @ 5095' to 5184'. Finish squeeze job. Reverse clean. POOH. TIH w! bit to 5016', test casing to 3000 psi. Drill cmt f/5016' to 5194'. Casing test failed. POOH for second squeeze attempt. TIH w/O/E DP. Peform inj test. Squeze perfs. POOH. TIH w/bit. WOC. Drill cement f/4948' to 5194'. 20-M ar-03 14 $26,512 CBU. Test perfs. Drill cmt to RBP. CBU. POOH. TIH, retrieve RBP, test casing/perfs, POOH. TIH w/stinger to C/O pkr. Circulate, sting in/sting out. CBU. 21-Mar-03 15 $24,696 CBU. POOH LDDP. Set strom pkr. ND BOP. Install tubing spool. NU BOP. Replace element in annular preventer. Printed - 5/15/2003 Daily Summary for Well: BEAVER CREEK 6 Report Report MD TVD Daily Cost Summary Date Number 22-Mar-03 16 $29,742 Fin NU. Test BOPE. Ret storm pkr. LD BHA. Change rams. Strap & drift 2-7/8" & 3-1/2" production tubing. 23-Mar-03 17 $30,111 24-Mar-03 18 $111,817 Strap & drift tubing. Run dual 3-1/2"/2-7/8" production string. Finish running dual completion tubing & equipment. Latch K-anchor, shear out of PBR. Displace ST annulus to completion fluid. Sting into PBR, land tubing hanger. Set dual pkr, test below pkr, pkr set OK. Back out landing jts, set BPV's. 25-Mar-03 19 $86,666 26-Mar-03 20 $131,266 RD control line running equipment. Change rams in BOP. ND BOP. Install & test production tree. Set BPV's. RDMO. Finish RD, ready to move rig. SOANN ,:l 2003 Printed - 5/15/2003 ,gENT aY: HP LASER JET 3'150; c) MARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY Alaska Business Unit I Beaver Creek 6 ~ ~ - ~._.%'" r~ 10-Mar-2003 PJU rig. 11-Mar-2003 PJU rig. 12-Mar-2003 PJU rig. 13-Mar-2003 14-Mar-2003 15-Mar-2003 16-Mar-2003 17-Mar-2003 18-Mar-2003 19-Mar-2003 20-Mar-2003 21-Mar-2003 22-Mar-2003 23-Mar-2003 24-Mar-2003 Fin RU drilling rig. Check for pressure & remove tree. NU BOPE. NU & test BOPE. Run free point. Attempt to back out of K-anchor @ 6907' WLM. Cut tubing @ 6886' WLM. Circulate hole to fresh water. POOH, LD 3 1/2" tubing. TIH w/fishing tools. Engage & release anchor f/pkr. Circulate B/U. POOH. Recover fish. TIH w/bit. TIH to pkr @ 6904'. Circ B/U. POOH. Run USIT log. TIH & set RBP @ 5270'. Set sand plug. Tag @ 5254'. Squeeze perfs @ 5095' to 5184'. Finish squeeze job. Reverse circ. POOH. RIH w/bit to 5016'. Test casing to 3000 psi. Drill cmt f/5016' to 5194'. Casing test failed. POOH for second squeeze attempt. RIH w/OE DP. Perform inj test. Squeeze perfs. POOH. RIH w/bit. VVOC. Drill cement f/4948' to 5194'. CBU. Test perfs. Drill cmtto RBP. CBU. POOH. RIH. Retrieve RBP. Test casing/perfs. POOH. RIH w/stinger to C/O pkr. Circulate. Sting in/sting out. CBU. CBU. POOH LDDP. Set packer. ND BOP. Install tubing spool.. N/U BOP. Replace element in annular preventer. Fin NU. Test BOPE. Retrieve packer. Change rams. Run dual 3 1/2"/2 7/8" production string. Finish running dual completion. Displace ST annulus to completion fluid. Sting into PBR. Land tubing hanger. Set dual pkr. Test below pkr. Back out landing its, set BPV's. Marathon OilCompany Alaska Business Unit P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 9071561-5311 Fax 9071564-6489 February 12, 2003 Tom Maunder AOGCC 333 West 7th Ave ' Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Attached is the Sundry Notices and Reports on Wells for Well Number BC-6, and the accompanying schematic and procedure draft. Marathon Oil Company proposes to recomplete Well BC-6, in the Beaver Creek Unit, from a single Tyonek producer to a dual producer in the Beluga and Tyonek formations. This recompletion is expected to begin on March 7, 2003. If you would like any other information, please contact me at 564-6315 or jgeller@ ma rathonoil, com. Sin~rely, ~, Production Engineer Enclosure bjv MAR 1 0.2D03 g:\cmn~rlg\bc\wells\bc9~AOGCC02.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation Shutdown Alter Casing Repair Well Plugging Change Approved Program __ Pull Tubing ~ Variance Re-enter Suspended Well Time Extension Stimulate Perforate X Other 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface ..,,~/'~ ~/" 1164' FNL, 1487' FWL, Sec. 34, T7N, R10W, S.M. At top of Productive Interval 1151' FNL, 1579' FWL, Sec. 34, T7N, R10W, S.M. @ 9107' TVD At Effective Depth 1234' FNL, 1925' FWL, Sec. 34, TTN, R10W, S.M. @ 10337' TVD At Total Depth 1796' FNL, 1889' FWL, Sec. 34, T7N, R10W, S.M. @ 15610' TVD 5. Type of Well: Development Exploratory Stratigraphic Service Recomplete as Dual Producer, Beluga/Tyonek 6. Datum Elevation (DF or KB) 185' KB MSL feet 7. Unit or Property Name Beaver Creek Unit 8. Well Number 9. Permit Number ~, 10. APl Number " 50-133-20346 ~ 11. Field/Pool Beaver Creek Field, Tyonek 12. Present Well Condition Summary Total Depth: measured true vertical 15928 feet Plugs (measured) 15610 feet 10400',11200',11360',14447',14647', 15260',15280' Effective Depth: measured 10400 feet Junk (measured) true vertical 10337 feet Fill - 10235 (3129/2001) Casing Length Size Cemented Measured Depth True Vertical Depth Structural Conductor Surface 4022 13-3/8" 2400 sks 4022 4022 Intermediate 12410 9-5/8" 3388 sks 12410 12228 Production 3534 7" 652 sks 14980 14674 Liner 1208 5" 450 sks 15889 15581 Perforation Depth: measured Tyonek: 9120' - 9155', 9866' - 9886' MD Beluga (proposed): 6018'-6031', 6080'-6095', 6112'-6118', 6125'-6134', 6140'-6149', 6165'-6179' MD true vertical Tyonek: 9107' - 9141', 9824'- 9844' TVD Beluga (proposed): 6018'-6031', 6080'-6095', 6112'-6118', 6125'-6134', 6,..1. ~0'~:~61.~9'~.~. 616.~'-61~79'~;3~/D Tubing (size, grade, and measured depth) ',.;.. ..~".:;.. ';~ '!.... 3-1/2", 9.2#, N-80 to 8998' Packers and SSSV (type and measured depth) r'.' Baker model 194 SAB 40x32 Packer @ 6911' 13. Attachments Description Summary of Proposal X Detailed Operations Progra~j~;t~;~! L!,!~! .d~ BOP~Sl~'e~h.',.!~ ~,.~ ~, ~..'.;;:" '';''1 14. Estimated Date for Commencing Operation 7-Mar-03 16. If Proposal was Verbally Approved Name ,e~,Approver I~ Date Approved 15. Status of Well Classification as: Oil ~ Gas X Service Suspended 17. I hereb~ the fore~g~is true and correct to the best of my knowledge. Signed '¥--..,...'X~,~,,\ ~'~..~,j~.. Gary Filer Title Production Engineer -- -N,~. FOR COMMISSION USE ONLY ~ ~..'Approval Conditions of Approval' Notify mmission so repres.entative may witness · .)ti?~.~O . "~~ '~ ..- -__ NO. I Plug Integrity BOP Test '~[/' Location Clearance Mechanical Int~ty Test "~bbsequent Form Required 10- Commissioner ' RBDNS BFL '/' ' '""" ; /' ,,, : r. ;' ,. , . . , Date 2/11/2003 Date SulJ~it-i~ Trip'cate FEB 19 2~. Marathon Oil Well BC-6 Recompletion BOP Stack IF,ow Nipple I ~ I IF,ow Line i i Preventer. '" I 13 5/8" 5M Double I Ram Preventer IPipe Ram I 2 1/16" 5M I ~--~ IBlind Ram I Check Valve I 12 1/16" 5M Manually I-- .... 131/8" 5M Hydraulically \ ' I Operated valves I > ~ I Operated Valva 113 5/8"'5M CrossI _.--~l > <II ' ~ 13 1/8" 5M Manually .,.pe.am. .Opera. ,Va.ve m Ram Preventer ~ ~ ~ I I SCANNED ~AR 1 0 2003 Well BC-6 Beaver Creek Field WBS RW.02.07945.CAP.CMP Recompletion as Dual Beluga/Tyonek Producer Objective: Recomplete well BC-6 from a single Tyonek completion to a dual comPletion.. '.." in the Beluga and Tyonek reservoirs. ':.' ...... . ~.' . ,'.!"i .~..' '.'.i., i"'" ' '"" :. ':' ' ..... '".::'":'! '., 1. MIRU slickline on well BC-6. Pressure test lubricator. Record 'SITP ~iisiC'i~"~t .'"'"' .......... time of fig-up. RIH with a 2Y4" gauge ting, tag fill, POOH. (l~l_ote': Fii~i~i~ts last tagged at 10,235' on 4/20/2001). RIH with PX plug body for-a~ 13'-~i~rofile-. Set PX plug in X-nipple at 8962', POOH. RIH with check-set to0!; v~ that the-i - PX plug body is set properly, POOH. RIH with an extended PX Prong, install in the PX plug body at 8962', POOH. Bleed surface-pressure to zero! and monitor long enough to verify that the PX plug is holding. - - :'.'-' ~ ' :' '.~ : ':' 2. RIH with a kickover tool for the he!~ injec.-t~ val Latch -~; ' ': .... ;~:-~: .~ 1~~ ~ ~ :i ':;; }i ~''' .~ ;::i ::~ and pull 1" chemical POOI:[ RIH:with~l]. dumm_-y:~;~ve, set ~n- mandrel, Pa~-~- up_:-~~ con~~ith the :' my Valvo:i;-ti0id~gq~.'---RDM0:giiek!ine. ;::---_--.<---? '- ?-_-!-7 :i, ~ Blend 12O~i:'0f 6~ii~ater:(22;:ib:~s/bbl of with 78 ~:.,..-.f-.--'~% ~:~~, off ~y y t~pp...ea:./,~_~-ss _ur~ ~:~ulus, ~d ~mpt t,o .... Do n0t:att~mpt ~o pmnp into the squeeze perfs, : 2all out Bleed off any remaining robing and annulus in the tubing hanger. Bleed off control line the by working the lock-down pins and making sure of the!¢l*I", 5M tubing head are not seized up. Pressure test tubing rig. Prior to ND tree confirm that no trapped pressure exists BPV. ND tree. Inspect lift threads on tubing hanger. (Note: Records that the lift threads are 3½" EUE 8rd. Inform Company Man immediately if lift threads are different than expected.) NU DSA (11", 5M x 13%", 5M) and 13%", 5M BOPs. Upper pipe rams should be equipped with variable bore (27A''- 5½" range), 5M pipe rams. Lower pipe rams should be equipped with 3'/-" z2 , 5M single pipe rams. Pull BPV, set 2-way check. Test BOPE to 250/3000 psi. LD test joint, pull 2-way check. ~C;'ANNED ~AR i 0 201}3 Well BC-6, Recompletion Procedure WBS - RW.02.07945.CAP.CMP Page 2 . RU elevators, spiders, dog collar, and integral tongs for pulling ~/-" ~ z2 , 9.2 ppf, L-80, buttress tubing. MU 3 ½" lif~ joint into tubing hanger· Load hole with 6% KC1 water· 7. MIRU APRS pipe recovery unit. Conduct prejob safety meeting. RIH with freepoint tool for 3 ½" tubing. Determine tubing freepoint. .'.. .. . a. If freepoint is well above the K-anchor, MU chemical cutter.with Safe .. firing head for 3½", 9.2 ppf tubing. Hole must be full of'b~ei.'.and no 'i:.....i'` i:':..' :" .. .? ~.'.'. '. differential to annulus. (Note: If a jet cutter is mn, could~!P6teiitially~:~ii:...;:.i?.:.:.:~':,.~.'i:iil .:,. out the K-anchor at 6909' while dressing off the jet cut.)':~:~:}:tieiiiri::~il;i''i.':i:i'~''?i:';': .... CCL. PU 30K lbs over pipe weight and cut tubing above-the fr~'~oi~i~?';:'.~}':i:.~'~('ii · · ' ' ~i~"~, POOH, RDMO APRS. Continue w~th procedure to wash.over::~ ~bmg to the top of the K-Anchor at 6909'. -~ ~ ::- ';iCi~?~ : ~ - b. If the tubing is free down to the K-Anchor, attempt toreleasethe -. - ~:-- K-Anchor by rotating the tubing to the right~i~ If anchor ~illinot releasei- chemical cut the 3½" tubing 30' above the K,Anchor (6~beiow coupling.:-:-: ~ -- . gj int) ~ ~ of full tubin o ~ ':~ ::~ ....' ... :. : . · , -:::c :. ' '~ : ~ ._ :': i - ..... :.:;:¥~:~ :::;~:i~- .:.:~ :;~:::~C:.:: -. 8. TOH laying down 3½ tubmg,~tubin~$~3 ½,9:2'!PPf, L-80~pomupset IBT,(:--)-. whichi.s-tated to 159.1 mlbs o~t strength (1000-,~)--._::'~C0upling-:.:-O--. D. :iS 4.250". (Note!:i'~6.-'?~¢~ to use ~d~cto~'~t~ stri~i~_:ju~ed:)i~:~e occasional r The--. bntrof:J~)~ould be cut ~:-,-_:-'-"iht-6:Piei:~!djunked._~dge Camco':ihji~'ction i~-anRrel to POii~ifOr ~" ~}~.-}i: ;,RD tubia_ g'~/!~ling e-q-ii~i~hent. RU ~ifig!e:e!e-vat6~ dips, and tongs for running :';~:-:4' 4 '-~' ~::' ::;':i'~'~'-~:' W ' : ~:' ::~ : ~- ' ': ' ' " ': ;:::-~ :-:. , 1 .0 ppf;:S:.:_-t35, H-T-_.38- orkstring~:&ay.3out~- tally, and rabbit 7200 of 4 PU j~s an_ d_-:.o..-..v_.ershot£0r.-_cu:t 3 ½ tubing. TI/I, engage cut tubing with overshot at 6879. R~ei~age K-AnCh0!;--Sy picking up on the anchor and rotating to the right. ~ ~ :=:~ ~'-~ ~ , If anch0iCWill'~ot rele':aS-e.-,_ jg as necessary to release anchor. TOH, LD overshot 2.. bit to the SAB packer at 6911'. Be aware of potential casing .cl._am. age in the squeeze perfs at 5095' - 5184', and the change in casing weight from 47 ppf to 53.5 ppf at 5754'. Circulate hole clean from the top of the packer. ToS. "::'~:~"" 12. MIRU Schlumberger. Tie in with DIL log of 2/3/1982. RIH with USIT log, log entire length of 9%" casing to the K-Anchor at 6909'. POOH. RDMO Schlumberger. J. Gary Eller - 2/11/2003 Well BC-6, Recompletion Procedure WBS - RW.02.07945.CAP.CMP Page 3 13. PU Baker retrievable bridge plug (OD ofRBP = 8.234") for 9SA'', 47 ppf casing. TIH on drill pipe. Set RBP at +5260' by rotating five tums to the fight while slacking offweight. Release from RBP by left-hand rotation. 14. PU off ofRBP. MIRU BJ pumping unit. Blend slurry sufficient for a 20' sand plug on top of the RBP (approximately 20 sacks). Sand plug will be a ... . . combination of 20/40 sand and silica flour. Lay in 20' sand plug on.top'Of'the.......::' ..'i.,....'. RBP, up to 5240'. PU two stands and shut down pumps to allow.sand:it01:settle. After allowing time for sand to settle, TIH and tag top of sand p!ug.~.':.i.":...:?:." ':"'"".:"':.'?" ':'" ""'.' 15. Blend 75 sacks of cement for squeeze as per BJ recommendati0n~ '"Lay ia':.ii75 sack cement plug up to 5030'. PU out of the cement several stands. Close t~ipipe ' ' : i',;,~,.' - rams. Apply squeeze pressure according to BJ recommendatiom :Top s~eeze pressure = 3000 psi. Bleed off squeeze pressure, open the pipe rams~ iC~ulate~i . out to clean up residual cement. TOH. ~ ~- ~----7 : - - .'~.~- i.-~ :_ ~ ':' : .~ 7' ._ 16. Wait on cement. - : ~-. :~ ::~ ;, ' ::~ :~-; ' 17. PU 8½" mill tooth bit. TIH and t~[ top--°f--c~ment:!Pr-'e-"-~Si ~e test~b!a-'-;~g to 300~.i:: psi prior to drilling out ceme~~ll ofit:c-~ent aem~g-:.~fl om squ-'_e..~ze~perfs to -':-f +5210,:~_-Pressure test squeezers to31~.*psi.::--tgt~t. Tf~ unsue~s~i~, repeat ?'' s.~__-.e_ez~_6~r~on. I~~; ~}~sfUl~-a-rin uikem ; cemd~-,~a sand plug ' T_;i-g/~DSg:t(bR-'.f'._~.~: re ol for RBP--'.-~'~d~:TIH.:~'E~6h-:,~d pall RBp. Retest .f :; !iii? i} ~i~iire '~}Y~_i:_..~:. ~ s~ oo psi..~}L~_.:,~i:(and-.-~etrieving tool. : ~}i~ii~ ass~nsis "stinger;i- ~ for ,9, SA'', 47-53.5 ppf casing, ;'-:::]((::.and jttnk-~~ T 'packer at~~)!-:insert the 2 stinger into the seal i:{::?~::Tb° ofth_e-.:-~:pac = 3.25 ) and.mrculate clean. TOH 3 stands. (.~. 2.0;!-Pu stormp]~r for ppf casing and RIH one joim. Set packer one joint !:-!:!i-:-:i.:--ibelow thi~gl 0°or b ion to the right and setting down weight. Release : ~,i~(;: from s-t-'~' --~i;ker b~tlnuing to rotate to the right. LD ming joint. 2'I:; ND.BOPE.' NU 11", 5M recompletion spool on top of existing 11", 5M tubing :~:-2 ;--_ head;: NU BOPE. Close blinds and test tubing head flanged connections to : -'.:-' 250~3000 psi against storm packer. Set test plug in new recompletion spool, test ~7~ f BOPE as needed to 250/3000 psi. Pull test plug. 22.PU one joint of drill pipe, engage and pull storm packer. LD storm packer. TOH laying down drill pipe. LD stinger, scraper, and junk basket. J. Gary Eller - 2/11/2003 Well BC-6, Recompleti0n Procedure WBS - RW.02.07945.CAP.CMP Page 4 · ~7Z ,~ 23 Close blind rams. Change out upper pipe rams to 3½" x ~/8 , 5M dual rams. Lower pipe rams will still be 3 ½", 5M single rams. Open blind rams, PU and set test plug in recompletion spool. Retest BOPE as needed. 24. 25. Run dual completion string as follows· RU dual elevators, dual spiders, and two sets of tongs for running ,a/-'' ~/2 , 9.3 ppf, EUE 8rd-Mod tubing (longstring) and 2~", 6.5 ppf, L-80, EUE 8rd-Mod robing.".... (shortstring). Note that the 3½" longstring tubing consists of P-110 below'the .... dual packer and L-80 above the dual packer. Lay out, drift, and tallYi..tubing on'.:.......':.' .. ~' :.' .... separate pipe racks.{..;.!;ii ii !ii''I':. i:i'.:'""/'........': i}i'~::'i~ii'ii~.!.' ~ii' i:/'.: !il; !i::..,:.:'''':'I'I'''':''' K-Anchor seal assembly Scoop head +22 jnts ~'/-" - o/2 , 9.3#, P-110, EUE 8rd- Mod Wireline Re-entry guide. (±6200') . - ~ - - . - ' 2 - ' ~-) ~. ' - ~.: ~ - _ ±8 jnts ~- 2:*/'dY,.6;5#, LrS0~::-E'_UE 8rd-Mod . - ........ L--~:. -X' CMU sliding sleeve (pups?) X_--m_'-pPle With:pups, 2.3i---3,-;ID ? ~' ::4 : .. , ,- 2.813" X-profile, +6230' :--;. '~ ~--: :;LEAVE O.. -U~??? '::-~!----:-~--7: :-~:~"':: :: :'- ljm - 3 ~"~._~;.-~;--.3_~: ..... P-11 o, EUE 8rd~M6tt ': ?'.l~-':jfit ~ 2~'-7:'~_:--6~5_.~, L-8I~;:-E~i 8rd-Mod '--:' +9 jnts--~;3:~;-~;~9.:_.-3_-..~; P-110;(:~::'gi'd~Mod x/oi3W--'E~-gfd x 2~'~:-E~_-_E 8rd, bxp --_..:;;~_-::-: :-::~{:- _'-¥:c~.?:?-.:'-:~;-::;:.~ ;-: --'-:---'::---':':- 7'-~5:-:-::' :--~' :~':~:~ ';: ~---:: ~ }:-'i~: .--C:-7!- ¢ '~:~-:}:.- : :..~.!::~~.~.-~.P-!¢l~i.'--_.th. pUps------::---'-::C::!-':~ ')~:<:-:)- ~---::ii-'!:-~--:;: ~:-'"~-~--~'-: :~i;-.':_,'~.':~:_' '.~ ~-,' "-.'; '"~-: ~ ~-~-:.':-'- ~; :'~-.:~::,'~: ,}7::~-} {'i-~i :5~ :~:-~-,: :: ? : -:-3 y :'~' 7~-:; ' -~'c'.;:-~::5:l-jn_-'ts:~-3~'~ ---_'Xg~#, L-S0 :~---F_;tTE 8rd- '?*-1-52 jnt~:2~-!~;' 6.5#,~L-80, F. UE 8rd- ~'.:.~; ::_x/0i.!3 ½" mT;X:-3:-.~:Etm-----'Srd¢~iP- 110, bxp:::~ ~/oi_-2~'-'-:mT-~x 2~" EUE 8rd, P-110, bxp ¢:~!!~g~er chemi~ '_mj-~Ction:~-~' p_.pi_-e, + 1200' ~)-. Baker-- Chemical injection nipple, +1170' ..:~..:. ..... -:_'- -~- ~:-:~:~::~ :--~}~!~ -.~c · ~:-~¢~-:" _x_'/6, 3½" E~:sr-d.-~-::3½":~T,~-i 10, bxp ~X/0; 2~" EUE 8rd x 2~" IBT, P-110, bxp · :(!::!::~'--~ ~i!~39~jnts' - 3~::;-9.3#,-'''~::~ ~i~ f L-SO;-----'EUE 8rd-Mod +38 jnts - 2~", 6.5#, L-80, EUE 8rd-Mod :;~_.: ~-' :-_'~ ~': ~ ~- ~5;-x- :-s-: :'C: ~ :-~: ¢: '!~i~, .-space-out pupsS~ /(: '- :::-; ::'~'-:: :-: Space-out pups :~¢~-?-~:: ~_ -_- : ~ _-:r_ --c~ ~ :~:~:~: . '!i:iii:::Spl'it mandrel:tubing hange~With pup x/o, 3½" EUE 8rd x 2~" EUE 8rd, bxp ~:~;: i_: :: .:- :~i i :- Split mandrel tubing hanger with pup .- :.ac~,~:.,.."4a~_r ..;.:k*,~,:.,r:~ , . . : ~;~~n it ~s t~me to nm the chemical injection nipples, RU pneumatic banding ~: ~.r~ ~.,~".~:!.? · : ~S~:~'.:.'~ machine and dual sheaves for two spools of ¼", 0.049" wall, stainless steel :'i ~i~,'~ .... :.' control line. Tie the control lines into the chemical injection nipples and pressure test to 2000 psi. (Note: Confirm sheafing pressure with Baker.) Continue to TIH, banding the control lines with 2 bands per joint. J. Gary Eller - 2/11/2003 Well BC-6, Recompletion Procedure WBS - RW.02.07945.CAP.CMP Page 5 27. TIH with completion assembly until K-Anchor latches into the receptacle. PU to shear pins on anchor seal assembly. Install space out pups and split tubing hangers. Blend 380 bbl of packer fluid (one drum ofPetrolite CRW-132) and circulate into the annulus via the shortstring tubing. Sting back into tieback sleeve and land tubing. Engage lock-down pins to secure the tubing hangers. .. Pressure test the shortstring tubing to 500 psi to verify that the seals are properly... '. '. - stung in on the longstring tubing. ...;:..'. :::....': .'....' ....: .: . ... · .. .. 28. Set the GT dual packer by pressuring up the longstring tubing to"2.500.P~i'. one~"-.. the GT packer is set, bleed off the longstring tubing pressure. ~:.~e valve/t°'./:i.::i/:..:,:'.".:.... the casing annulus, and apply 500 psi down the shortstring tubing-to pres~Ure~'~i':tegt'''w::':'':''''':':''''':::'' the GT packer. When testing is complete, bleed off shortstring pressure ~d';~lose i:'~;~'~.. the casing annulus valve. "~ .?ii:~:: .... ~}~.' 29. Install BPVs in tubing hanger. ND BOPE, NU tree. Pull BPVs;:ingtatl 2-way ' ' checks in tubing hangers. Test dual tree to 3000 psi using methanol-:Pull 2-way: checks, reinstall BPVs. RDMO workover n'.g: : :: " - : ~ ~:: :-- : ' ': -, - : . , :,: ~ ; = .. -: . ': , :- ', -: .... ~ :/:: "-~ :" - '~ - :;~&:~, 30. RU scaffolding on BC-6. rinish~~ wing--Valves ana--'/SSVs and::tes{-!i0 3000 Pull BPVs. Pressure up on bo~{~emica~-irij¢ctioni%ial~61 lineS'~O._-!_5~00 psi to: shearout-mpture disks. ~-~ :~' -::::"i-:-}.'-:c!~-::' ?-.~--'~!':!' !:77:-'/'~::~';!! :: - :, :~_-/::: :-.:-:/:~ ~¥~ ;~.~ :-::- -. :~ ::-: ?: -/ :---.: i. . ~ :-?:: ::_ :_: 3t'.i'M~_ --U:s!iC-'!dine_ on ~~l~ssure tesr:lttbricator:-:.-iRiH wi~:~.:_2~,~" pump ::~:: :?:_b~l~; ::t__~g.t_.--orf.of rx ~~62. ~f tag:iS:high, bait'-a'~mple:'0~:fin- and POOH. r i. .: :-i-:-: '~:: :-:lc:sleeve. "l~qii_ --g~':.¢~~~ sleeve at-62-30' and":.:shffiC0~n while monitoring :~?!:.-: :i:..qongstrin~ir~g~alv~~sure test lines:~d lubricator to 3500 psi. Hold prejob :: !~:::j' ::-{_._'_-'i._safety ~ai~g~::circ t completion fluid asing nitrogen through the C~U .:-.i-~:' !:--;::!--':sliding si~:".-:-~axi pected nitrogen pressure is approximately 2500 psi, -&~-'~:::,:.:and total:e.S--ti:.'m~at~d r = 109 bbl. ^now nitrogen pressure on both strings :/::' ?i';.;ilo bleed'.*ff:~er cir~:~i~g out. RDMO nitrogen pump. ' :_3~'}Mm~:sli~kline on longstring tubing. R~ with shifting tool for eMU sliding .~ ;C :-:~Sle_eV-e~ :.. Close eMU sliding sleeve at 6230'. POOS. ~D~O slickline. !!3: :--" :!~: :-t/ ?:: 34.'~;-MIRU Schlumberger on the shortstring. Pressure test lubricator to 3000 psi using 'methanol. Conduct prejob safety meeting and go to radio silence. Perforate the following Beluga intervals with maximum under balance using 2", 4 spf, 0° phase hollow carder guns loaded with 6.5 grn Powerjet charges. Entrance hole = ". (Note: Max gun OD = 2.30" after firing.) Guns will be mounted on the POT-C orienting device. The POT-C should be field calibrated using 3¥/' and 2W' pup joints. J. Gary Eller - 2/11/2003 Well BC-6, Recompletion Procedure WBS - RW.02.07945.CAP.CMP Page 6 UB3- 6018' - 6031' (23') UB3 - 6080' -6095' (15') UB4-6112'-6118' (6') UB4- 6125' - 6134' (9') UB4- 6140'-6149' (9') UB4-6165'-6179' (14') 35. RDMO Schlumberger. Produce well to temporary flowback iroil':..t~i::~lean injecting methanol via chemical injection line as needed. Produ~:~'611 :t6.i ;,..:[: .... ;,:~,:..",' :.'....,~.,. ~ .> ~ ¢ ~; :,. '. per instruction of Production Engineer. - !!~',i!{::' ?.:'?:.~-- ' J. Gary Eller - 2/11/2003 BC-6 - Proposed APl: 50-133-20346 AOGCC: 95-092 RT-GL: 27.0' (Original) RT-GL: 21.0' (Workover 2003) 1164' FNL, 1487' FWL Sec 34, T7N, R10W, S.M. Tree cxn = 3-112" EUE 8rd 3", 5-bolt crescent flange cap Lift threads = 3.725" MCA IShortstrina - 2.875", 6.4#, L-80, EUE 8rd-Mod Tubing X-nipple at 5905' ID = 2.313" Wimline re-ent~j guide at 6200' Shortstrinfl Perfs (Beluaal 6018' - 6031' 6080' - 6095' 6112' 6118' 6125' - 6134' 6140' - 6149' 6165' - 6179' Lonastrina Perfs (Tvonekl 9120' - 9155' (6 spf, 12/96 & 2/97) 9866' - 9886' (6 spf, 2/4/96) IFill at 10,235' (3129101) Cement retainer ~} 10400' (1/21/96) Cement retainer ¢~ 11200' (1/17/96) Cmt plug 11,360' - 11,560' CIBP @ 14647' capped wi 200' cmt (6~82) CIBP ~ 15280' capped wi 22' sand & cmt (5~82) IBaker injection nipple wi dual checks, and '-. .,-' 11/4" OD, 0.049" wall SS control line '*'"~ ISu~face Casin=: 13-3/8", 68 & 72 ppf, N- ' ~ I [~,, 180, BTC (~ 4022' ICmt w12400 sks of class G ~lBaker GT dual packer ~ 5885' I I with 60K shear ring on=strin= - 3.5', 9.3#, L-80, EUE 8rd-Mod Tbg Note: P-110 tubing between dual packer and ~ '~j,~ ~ SAB packer at 0011'. CMU sliding sleeve @ 6230' ID = 2.813" 10' Seal assembly (OD = 3.25") 10' Tieback Sleeve with scoop-head 80.40 K-Anchor ~} 6909' Baker 194 SAB 40x32 Packer ~ 6911' ID = 3.250" Camco X-Nipple ¢~ 6965' ID = 2.813"? Camco X-Nipple (~ 8962' ID = 2.813"? Wireline Re-Entry ~ 8987' Prod. Casina: 9-5/8", 47 & 53.5 ppf, N-80, BTC ~} 12,410' :mt w/3388 sks of class G (1588 sks 1st stage, 1800 sks 2nd stage) 0' - 5754', 47 ppf, N-80 ~754' - 6355', 53.5 ppf, C-75 6355' - 6983', 53.5 ppf, N-80 6983' - Cementing stage tool 6985' - 8565', 53.5 ppf, N-80 8565' - 9615', 47 ppf, P-110 9615'- 12,331', 53.5 ppf, P-110 Liner: 7", 32 ppf, P-110, BTC @ 11,446' - 14,980' Cmt wi 652 sks of class G Notes: Frac stimulated the Tyonek D-1 interval (9866' - 9886') on 3117101. Placed 58,000 lbs of 20140 Carbolite in 357 bbl of SuperP, heogel in diesel. I TD = 15,928 Liner. 5", 18 ppf, N-80, BTC @ 14,681' - 15,889' :mt wi 450 sks of class G IWell Name & Number: County or Parish: Perforations (MD) Angle/Perfs I IDated Completed: IPrepared By: BC-6 Lease: I Kenai StatelProv. Alaska Angle @ KOP and Depth I I BHT: I I Completion Fluid: I 112411996I J.G. Ellar I Last Revison Date: I Beaver Creek Field Ic°untry: 1/23/2003 Inactive Perle Sterling (above the dual packer): 5095' - 115' (sqz failed) 5132' - 142' (sqz failed) 5174' - 184' (sqz failed) G-Zone: 1517O'-2OO' 15085'-128' 15003'-050' Hemlock: 15520'-546' 15476'-506' 15414'-466' 15387'-407' 15345'-370' 15306'-326' C;'ANNEE;i! O 2003 APl: 50-133-20346 RT-GL: 27.0' 11164' FNL, 1487' FWL 'Sec 34, T7N, R10W, S.M. Tree cxn = 3-112" EUE 8rd IProd.Tubing: 3-112", 9.2 - PPf, L I 80, BTC I I Perfs Upper Tyonek: 9120' - 9155' (6 spf, 12126/96 & 2/7/97) D-1 Tyonek: 9866' - 9886' (6 spf, 2~4~96) ,-. · BC-6 Camco injection mandrel @ 988' I wi 114" SS contro line I I ISurface Casintq: 13-3/8", 68 & 72 ppf, N- 80, BTC ~ 4022' Cmt wi 2400 sks of class G 80-40 K-Anchor ~ 6909' I Baker 194 SAB 40x32 Packer ~} 6911' ~ I I Camco X-Nipple @ 6965' ID -- 2.813"? I Camco X-Nipple @ 8962' ID = 2.813"? IWireline Re'Entry ~} 8987' Notes: Frac stimulated the Tyonek D-1 interval (9866' - 9886') on 3/17101. Placed 58,000 lbs of 20~40 Carbolite in 357 bbl of SuperRheogel in diesel. Inactive Pprfs Sterling (above the packer): 5095' - 115' (sqz failed) 5132°- 142' (sqz failed) 5174' - 184' (sqz failed) G-Zone: 15170'-20O' 15085'-128' 15003'-050' Hemlock: 15520'-546' 15476'-506' 15414'-466' 15387'-407' 15345'-370' 15306'-326' IFill at 10,235' (3/29101 ) ICement retainer @ 10400' (1/21/96) Cement retainer ~} 11200' (1/17/96) Cmt plug 11360' - 560' IProd. Casino: 9-5/8", 47 & 53.5 ppf, N-80, BTC @ 12,410' Cmt wi 3388 sks of class G ICIBP @ 14647' capped w/200' cmt (6~82) Liner: 7", 32 ppf, P-110, BTC @ 11,446' - 14,980' Cmt wi 652 sks of c ass G IClBP ~ 15280' capped w/22' sand & cmt (5~82) ILiner: 5", 18 ppf, N-80, BTC @ 14,581' - 15,889' Cmt w/450 sks of class G I TD = 15,928 IWell Name & Number: County or Parish: Perforations (MD) AnglelPerfs I Dated Completed: BC-6 I Lease: Kenai StatelProv. Angle @ KOP and Depth BHT: I I Completion Fluid: 1/24/19961 Beaver Creek Field Alaska Ic°untry: I 1 Summary by Unit: Field BEAVER CREEK Pool BEAVER CREEK, BELUGA Unit BEAVER CREEK Operator MARATHON OIL CO Individual Gas Well Production December, 2002 APl Well No Well Name Well No Conden (BBL) Wtr (BBL) Gas 0VICF) Days Cum Conden Cum Water Cum Gas 50133204820000 50133200060000 50133204450000 BEAVER CK UNIT BEAVER CK UNIT BEAVER CK UNIT 10 0 330 301,181 31 0 4,148 1-A 0 1228 142,434 31 0 114,512 9 0 94 175,912 31 0 31,514 3,707,266 12,248,485 16,202,787 Pool BEAVER CREEK, STERLING Unit BEAVER CREEK Operator MARATHON OIL CO Unit Total 0 1652 619,527 Pool Total 0 1652 619,527 APIWell No Well Name WellNo Conden (BBL) Wtr(BBL) Gas(MCF) Days Cum Conden CumWater Cum Gas 50133202840000 BEAVERCKUNIT 7 0 0 0 0 0 162,950 41,654,140 50133204450000 BEAVER CKUNIT 9 0 104 204,509 26 0 135 1,185,336 Pool Unit Operator Unit Total 0 104 204,509 Pool Total 0 104 204,509 BEAVER CREEK, TYONEKUNDEFINED BEAVER CREEK MARATHON OIL CO AP1 Well No Well Name Well No Conden (BBL) Wtr (BBL) Gas (MCF) Days Cum Conden Cum Water Cum Gas 50133203460000 BEAVER CK UNIT 6 0 0 33,081 31 0 3,795 4,825,634 Unit Total 0 0 33,081 Pool Total 0 0 33,081 Field Total 0 1756 857,117 .~GANN~D gAR I O 2003 Friday, February 14, 2003 Page I Marathon OilCompany Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 9071561-531 t Fax 9071564-6489 July 2, 2001 Mr. Tom Maunder AOGCC 333 West 7th Ave. Suite 100 Anchorage, AK. 99501 Report of Sundry Well Operations Dear Mr. Maunder: Enclosed is the Report of Sundry Well Operations for Well BC-6. If any other information, is required; please contact me at 907-564-631.5 or iaeller@marathonoil.com, Sincerely, Pmdud:i0n Erigineet RECF_. VED JUL 0 3 ~01 Naska Oit & GaS Coas. commissio~ Anchorage g:~cmn~drlg~kgf~wells~ku 11-Ss~AOGCC01a.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Abandon Suspend Operation Shutdown __ Re-enter Suspended Well__ Alter Casing Repair Well Plugging Time Extension Stimulate X Change Approved Program Pull Tubing Variance Perforate Other Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 1164' FNL, 1487' FWL, Sec. 34, T7N, R10W, S.M. At top of Productive Interval 1151' FNL, 1579' FWL, Sec. 34, T7N, R10W, S.M. @ 9107' TVD At Effective Depth 1234' FNL, 1925' FWL, Sec. 34, T7N, R10W, S.M. @ 10337' TVD At Total Depth 1796' FNL, 1889' FWL, Sec. 34, T7N, R10W, S.M. @ 15610' TVD 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum Elevation (DF or KB) 185' KB MSL feet 7. Unit or Property Name Beaver Creek Unit 8. Well Number BC-6 ~Numb~r~ I 10. APl Number ' 50-133-20346 11. Field/Pool Beaver Creek Field, Tyonek 12. Present Well Condition Summary Total Depth: measured true vertical 15928 feet 15610 feet Plugs (measured) 10400', 11200', 11360', 14447', 14647', 15260', 15280' Effective Depth: measured true vertical 10400 feet 10337 feet Junk (measured) Fill- 10370 (5/24/99) Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented Measured Depth True Vertical Depth 4022 13-3/8" 2400 sks 4022 4022 12410 9-5/8" 3388 sks 12410 12228 3534 7" 652 sks 14980 14674 1208 5" 450 sks 15889 15581 9120' - 9155', 9866' - 9886' true vertical 9107' - 9141', 9824' - 9844' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 to 8998' Packers and SSSV (type and measured depth) Baker model 194 SAB 40x32 Packer @ 6911' RECEIVED JUL 0 3 7.001 ,Naska Oil & Gas Cons. Commission Anchorage Intervals Treated (measured) Tyonek Pool: 9120'- 9155', 9866' - 9886' Treatment Description Including Volumes Used and Final Pressure 55,000 lbs of 20/40 Carbolite in 345 bbl of gelled diesel on 3/17/01 Final ISIP = 4252 psi. 14. Representative Daily Avera.qe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation 0 1000 0 0 750 Subsequent to Operation 0 30O 0 0 750 15. Attachments 116. Status of Well Classification as: Copies of Logs and Surveys run I Daily Report of Well Operation~ ~ Oil__ Gas ~ Suspended__ 17. I hereby ce~hat the foregoil~is true and correct to the best of my knowledge. Signed ~? _._~I;~1~ ~~ Gary Eller Title Production Engineer Form 10-404 Rev. 06/15/88 . ORIGINAL. Service Date 06/29/01 Submit in ,~ Duplicate -. 010519.XLS MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE I OF I DATE: 5/19/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 8102901 FIELD: Beaver Creek Field WELL#: BC-6 10370 TUBING: 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: good BENCHES OPEN: Deep & Upper Tyonek Coil tubing jetting & well flowback SUMMARY OF OPERATIONS Got our hands on a new swivel and installed onto the reel. Reinstalled inside reel valve and retested to 250/3000 psi. Stab injector head onto BOPs. Bleed well to zero, but still a slight gas blow. Held safety and operations meeting. RIH with coil tubing without pumping nitrogen. At 2000', start getting some clean diesel in the returns even though we're not yet circulating. Cool down and start pumping nitrogen at 350 SCFM. Continue to RIH while monitoring returns. Stop at tubing tail at 9000' and circulate nitrogen at 350 SCFM with 600 psi pump pressure. Liquid returns have been consistent but unimpressive at about 1 bbl/hr. Pump pressure and lack of returns indicate that the tubing is essentially dry. Increase nitrogen rate to 600 SCFM, RIH below all perfs to 10,000'. About 30 minutes after increasing nitrogen rate got several barrels of good returns but then the liquid rate fell back to it's former level. Total liquid returns for today = 11 bbl, total returns since fracturing = 132 bbl. Decide to 'close off return line and bullhead nitrogen into perfs. Shut in well, increase nitrogen rate to 1000 SCFM, and POOH. Bullheaded 144,000 SCF of nitrogen which should be roughly 1.5 tubing volumes. Final surface pressure = 1950 psi. CCH. Close master valve, blow down reel, RD coil tubing injector head. Reopened well to atmosphere. Blew down without carrying out any incremental fluid or showing any sign of trying to flow. SDFN. Vendor Equipment Daily Cost Cumulative Cost BJ coil and nitrogen $70,000 $70,000 To loft crane $1,800 $3,800 PTS sand buster, flowback hands $2,300 $9,200 R&K vac truck $720 $1,350 R&K fuel $0 $370 R&K light plant $0 $200' R&K trucking $0 $2,000 Misc. $500 $1,500 $o DAILY COST: $75,320 CUM: REPORTED BY: G. Eller -. 010516.XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF I DATE: 5/16/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 8102901 10370 FIELD: TUBING: Coil tubing jetting Beaver Creek Field WELL #: BC-6 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: good BENCHES OPEN: Deep & Upper Tyonek SUMMARY OF OPERATIONS MIRU BJ 1-3/4" coil tubing and nitrogen and flowback iron onto well BC-6. Tested BOPE and flowback iron to 250/3000 psi with fresh water. Witnessed by John Spalding with AOC~CC. After testing, blew reel dry with nitrogen. Note: In the past few weeks, have periodically tried to flow well BC-6 to the system following the fracture stimulation of 3/17/01. The well only produced about 300 MCFD and never unloaded any liquid since the last coil tubing jetting operation. Bled well from 1550 psi to zero. RIH with coil tubing without pumping nitrogen. Reach 1000' when we heard an unusual noise. Discovered that this new reel of coil tubing was equipped without a swivel on the drum. The noise we heard was a pressure sensor breaking near the inside reel valve. Without the swivel the reel was trying to spin the high pressure chicksan coming from the nitrogen pump. Shut-down coil, secured well, and removed the inside reel valve and other valving at the reel. POOH and RD coil tubing. Unable to continue until we get a swivel, which will have to be brought in from outside. Vendor Equipment Daily Cost Cumulative Cost BJ coil and nitrogen $0 $0 Toloff crane $2,000 $2,000 PTS sand buster, flowback hands $2,300 $2,300 R&K vac truck $630 $630 R&K fuel $370 $370 R&K light plant $200 $200 R&K trucking $2,000 $2,000 Misc. $1,000 $1,000 $o DALLY COST: $8,500 CUM: REPORTED BY: G. Eller ' MARATHON OIL COMPANY DALLY WELL OPERATIONS REI:~ . ( PAGE 1 OF 1 DATE: 4/20/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Beaver Creek WELL #: BC-6 10237' WL TUBING: 3 1/2" CASING: 9 5/8" 3/29/2001 TREE CONDITION: Good Tag fill, Bail & Run Lo~l~lin Tools BENCHES OPEN: WIRELINE CREW: F. Pollard/Butler Hrs. 12 SUMMARY OF OPERATIONS Drive equipment to Beaver Creek from KGF Arrive in Gas Field, sign in, spot equipment, rebuild Stuffing Box Have safety meeting at Office Rig up, test Lub & BOP's RIH w/1 3/4" DD Bailer to 10237' WLM, 10264' RKB, POOH, full of Frac Sand, remove OJ's, SJ's and Stem, pick up Protechnics multi-isotope logging tool. Open Swab Valve, RIH at 300' per min to 8500', slow to 25' per min to 10200', pull up to 8500' at 25' per min, POOH from 8500' at 300' per min Check information on tools Rig down, clean area Sign out Wire test' 22 turns Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. W/L Unit & Mast Truck $1,500.00 $1,500.00 Pollard Wireline Inc. DD Bailer $150.00 $1,650.00 DALLY COST: $1,650.00 CUM: $1,650.00 REPORTED BY: · MARATHON OIL COMPANY DALLY WELL OPERATIONS REF( ,' PAGE 1 OF 1 DATE: 3/29/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field WELL #: BC-6 10236' TUBING: 3 1/2" CASING: 9 5/8" N/A TREE CONDITION: Good Survey, fishing for Temp Gauge BENCHES OPEN: Complete WIRELINE CREW: D. Pollard/Doherty Hrs. 12 SUMMARY OF OPERATIONS Drove equipment to Beaver Creek Meet w/Supervisor, safety meeting Started R/U Started Bombs for flowing BHP survey RIH w/Tandem Gauges, making stops aaH w/Tandem Gauges, download Bombs RIH w/2.75" Overshot to 10235' W/L, POOH, full RIH w/2.50" DD Bailer to 10236' W/L, work tools, POOH, full RIH w/same to 10237' W/L, work tools, POOH full R/D Started moving equipment to main office Depart field Note: Comparison with report of 3/15/01 shows that approximately 5200 lbs of 20/40 sand from the frac of 3/17/01 fell into the rathole. Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. 12 hr min $1,500.00 $1,500.00 Pollard Wireline Inc. Tandem Gauges $800.00 $2,300.00 Pollard Wireline Inc. DD Bailer $150.00 $2,450.00 Pollard Wireline Inc. Fuel $149.00 $2,599.00 DAILY COST: $2,599.00 CUM: $2,599.00 REPORTED BY: Bob ' MARATHON OIL COMPANY DALLY WELL OPERATIONS REI~r ~' DATE: 3/23/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: PAGE 1 OF 1 FIELD: Kenai Gas Field WELL #: BC-6 TUBING: 3 1/2" CASING: 9 5/8" TREE CONDITION: Swab leaks Sample fluid & Survey BENCHES OPEN: Complete WIRELINE CREW: Dilly/Logston Hrs. 15 SUMMARY OF OPERATIONS Drive M/T and W/L Unit to Beaver Creek from KGF Safety meeting R/U, repack Stuffing Box, pressure test Lub & W/L Valve, Tree Flange leaked, tighten up and retest - good RIH w/10' x 1 3/4" DD Bailer to 10000', POOH, empty RIH w/same w/new bottom, POOH, empty RIH w/Quick Temp & Pressure Bomb to 10000', POOH, Quick Temp tool is gone RIH w! 2.25" Bailer to 9600', POOH w/1 3!4 quarts of fluid Start rigging down and cleaning area Tool Cost: Quick Temp N/C Pressure Temp $600.00 DD Bailer $150.00 Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. Unit 12 hr min $1,500.00 $1,500.00 Pollard Wireline Inc. 3 add hrs $300.00 $1,800.00 Pollard Wireline Inc. Tools $750.00 $2,550.00 DALLY COST: $2,550.00 CUM: $2,550.00 REPORTED BY: Wayne Cissell -j · 010319.XLS MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 3/19/2001 FIELD: FILL DEPTH/DATE: 10370 TUBING: DATE LAST WL WORK: WORK DONE: Jet with coiled tubing PRESENT OPERATION: Flow back OTHER: AFE 8102901 Beaver Creek Field WELL #: BC-6 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: good BENCHES OPEN: Deep & Upper Tyonek SUMMARY OF OPERATIONS RU BJ 1 3/4" CT and Nitrogen pumping Equip. Pwh=75 psi. Safety and operations meeting Begin P-test. Leaky knuckle. Bleed down and blow out lines and hammer up. Begin to pump again. Observe leak from double stud adaptor. SSV bonnet obstructs wrech movement to tighten nuts. Loosen and re-hammer DSA. Begin pumping again. P-test/Ftn test to 4000psi. Test fine. Blow down coil and lines w! Nitrogen. RIH w/CT. Stop to fix depth counter. RIH Pump nitrogen at 1200 scfm (min rate). Lose prime on nitrogen pump. Resume pumping at 1200 scfm Nozzle at approx. 9000'. Sit and pump. Get returns of mostly N2, some diesel Depth counter not working. Pump while working on depth counter. Increase rate to 2000 scfm PU to tubing tail and continue pumping watching for returns, still not much diesel POOH while pumping at 20D0scfm. OOH w/CT Rig back injector head. ND BOPs. Secure well SDFN. Pwh=0psi Recovered 52bbl thick diesel. Total recovery = 112 bbl. Vendor Equipment Daily Cost Cumulative Cost Veco Crane $3,840 $5,680 R&K Light plants (3) $200 $700 S & R Vac truck $1,955 $4,108 BJ Services CT/N2 crew & equip. $42,000 $62,000 Timberwolf Flowback crew $14,400 $15,576 Weatherford choke manifold $3,000 $20,000 R&K Vac truck $893 $893 Other l liner, misc $15,000 $15,000 Previous total $0 $284,922 DAILY COST: $81,288 CUM: $366,210 REPORTED BY: Titus 'l 0103,18.XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 3/18/2001 FI ELD: FILL DEPTH/DATE: 10370 TUBING: DATE LAST WL WORK: WORK DONE: Jet with coiled tubing PRESENT OPERATION: Flow back OTHER: AFE 8102901 Beaver Creek Field WELL #: BC-6 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: good BENCHES OPEN: Deep & UpperTyonek SUMMARY OF OPERATIONS MI BJ CT Equip. Pwh=4,50 psi. Decide to see if well will flow back on its own. Flowback lines frozen. Work to thaw. Call steam on wheels. Line and valves thawed out. Cancel steam. Open well and flow diesel through choke to tank. Pre,~ure building Pwh, max=lO00 psi. Still flowing diesel, but pressure tapering off. Begin to move in nitrogen pumping equipment. Coninue to monitor well pressure. Slow pressure taper, but still bringing up diesel. Continue rigging up CT and N2 Pressure dropped off to 0 psi. Recovered 60bbl diesel. Prep to SI well for night. CT crew still looking over equipment and making adjustments/repairs. Pump out all flowlines and freeze protect for night. Well secure for night. Vendor Equipment Daily Cost Cumulative Cost Steam on wheels House call $220 $220 Veco Crane $1,840 $1,840 R&K Light plants (3) $500 $500 S & R Vac truck $553 $2,153 BJ Services CT/N2 crew & equip. $2O,OOO $2O,0OO Timberwolf Flowback crew $1,1 76 $1,1 76 Weatherford choke manifold $17,000 $17,000 Misc $1,000 $3,000 Previous total 3/7-3/17 $0 $242,633 DALLY COST: $42,289 CUM: $284,922 REPORTED BY: Titus OI0317,XLS MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 3/17/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 8102901 1O37O FIELD: TUBING: Propped Frac Beaver Creek Field WELL #: BC-6 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: good BENCHES OPEN: Deep & Upper Tyonek SUMMARY OF OPERATIONS Mobilize frac crews. RU Stinger tree saver, Mac flowback iron, and Weatherford choke manifold. Held safety meeting. Set tree saver, SlTP = 0 psi. Pressure test frac iron to 8500 psi, test flowback iron to 5000 psi. RU onto 0-5/8" casing. CP = 1300 psi. Pump in, unable to get pressure test. Pressure falling off to 200 psi. Discuss options at length. The minifrac data and subsequent tracer log data suggest that we have tubing and packer integrity. Decide fo pump the gelled pad while continuously monitering annulus pressure. If pressure communication is noted, the plan is to abort the frac; otherwise proceed as planned. Pumped 4000 gal of Super Rheogel frac fluid in #2 Williams diesel at 10 bpm. Gel is loaded with 5 gpf gelling agent and 5 gpt crosslinker. Pad fluid has 3 gpt of breaker. Loaded tubing after pumping 30 bbls, continue pumping pad at 15 bp.re. No change in casing pressure, so continuing job. Stage proppant as follow: 2 ppg - 1000 gal (clean volume) 3 ppg - 1000 gal (clean volume) 4 ppg - 1000 gal (clean volume) 5 ppg - 2000 gal (clean volume, traced with Ir-lg2 ZW tracer) 6 ppg - 2000 gal (clean volume, traced with Ir-192 ZW tracer) 7 ppg -4000 gal (clean volume, traced with Ir-192 ZW tracer) flush - 5955 gal All propped stages contain same gel/crosslinker loading but has 4 gpt breaker. First 50 bbl of .flush was gelled, remaining volume is straight diesel. Proppant is 20/40 Carbolite. Pumped total of 58,000 lbs of proppanf which is 99% of design volume. Formation readily taking proppant, no signs at all of a screenout. Flush to the fop of the lower set of perfs (9866'). Final ISlP = 4252, 5-rain = 4072, 10-rain = 3845, 15-rain = 3482 psi. RDMO frac iron. Open well to attempt flow. Well on vacuum. Secure well, SDFN. Vendor Equipment Daily Cost Cumulative Cost BJ (actual) frac materials $82,886 $85,763 BJ (allocated) frac manpower & equipment $29,680 $42,369 Protechnics tracer $8,192 $11,742 .Weaver Bros. 72 bbl diesel $3,767 $44,336 S&R vac truck $960 $1,600 Pollard Wireline fluid heating, mast truck $3,974 $5,524 Central Emergency Svc. fire fighters $300 $600 Indirect $1,000 $2,000 Stinger tree saver $7,425 $7,425 Previous reports 3/7, 3/12, 3/14, 3/15 $0 $104,449 DALLY COST: $138,184 CUM: $242,633 REPORTED BY: G. Eller ,, MARATHON OIL COMPANY I DALLY WELL OPERATIONS REI:(' ~' PAGE 1 OF 1 DATE: 3/15/2001 FI ELD: FILL DEPTH/DATE: 10353' W/L TUBING: DATE LAST WL WORK: N/A WORK DONE: Tag fill, PDS tools PRESENT OPERATION: Complete OTHER: Kenai Gas Field WELL #: BC-6 3" CASING: 9" TREE CONDITION: Good BENCHES OPEN: WIRELINE CREW: D. Pollard/Tomlinson Hrs. 12 SUMMARY OF OPERATIONS Arrived at Marathon Meet w/Supervisor, held safety meeting Started Rigging up RIH w/2.30" GR to 10353' W/L, POOH OOH On stand-by awaiting parts for PDS RIH w! PD$ tool to 10000', pulled up slow, logging well OOH w/PDS tools Started Rig down Moved equipment to K-Beach Office Parked equipment Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. 12 hr min $1,500.00 Pollard Wireline Inc. 2.30" GR $50.00 PDS logging tool $3,120.00 DAILY COST: $4,670.00 CUM: $4,670.00 REPORTED BY: Wayne Cissell 010314.XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE I OF 1 DATE: 3/14/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 8102901 10370 Minifrac FIELD: TUBING: Beaver Creek Field WELL #: BC-6 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: good BENCHES OPEN: Deep & Upper Tyonek SUMMARY OF OPERATIONS MIRU BJ frac iron onto well BC-6. Two frac tanks were preloaded with 770 bbl of #2 Williams diesel. Held safety meeting. Pressure test frac lines to 6000 psi. Casing pressure is 1500 psi. $1TP = 1330 psi. Pump 75 bbl of diesel + 3 gpt FRO-18 + 3 gpt isopropyl alcohol (both for friction reduction) traced with 0.95 mCi/K of Sc-46 LZW tracer. Displaced traced material with 150 bbl of diesel loaded with the same friction reducer for a total load of 225 bbl. Two sets of perfs are open (9120' & 9866'). Loaded up tubing at 8 bpm with 1300 psi; tubing fully loaded after pumping 85 bbl. Treating pressure built to 4400 psi after pumping 155 bbl before we began injecting into the peffs. After pumping 170 bbl (tubing volume to the deepest pert is 142 bbl), shut down for ISIP and closure. Recorded ISlP of 3400 psi with much water hammer, and closure pressure of 6358 psi at 9866' (0.645 psi/fi) at a G-function of 1.1. Resumed pumping at 8 bpm and pumped final 55 bbl of diesel at 4600 psi treating pressure. Final ISlP = 3400 psi, closure = 6060 psi (0.614 psi/fi). Leave frac iron rigged up for frac on Saturday. Secure well; will not attempt flowback until after the frac. Vendor Equipment Daily Cost Cumulative Cost BJ (actual) frac materials $2,877 $2,877 BJ (allocated) frac manpower & equipment $12,689 $12,689 Protechnics tracer $3,550 $3,550 Weaver Bros. 771 bbl diesel $40,569 $40,569 S&R vac truck $640 $640 Misc. materials sorbent, choke beans, etc. $5,000 $5,000 Central Emergency Svc. fire fighters $300 $300 Indirect $1,000 $1,000 ' Previous reports 3/12 & 3/7 $0 $33,154 DAILY COST: $66,625 CUM: $99,779 REPORTED BY: G. Eller Marathon Oil Company October 13, 1997 Attention: Jack Hartz Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 RE: Multipoint Gas Well Tests Beaver Creek Unit Well BCU-6 Alaska I~ In Domest[. ,oduction P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Dear Jack: Attached in duplicate are copies of AOGCC Form 10-421 with results of a recent multipoint test for the above referenced gas well. This multipoint test is the first to be .conducted following the recent completion of permitted activities for this well: If you have any questions or require additional information, feel free to contact me at 564-6327. Reservoir Engineer H:\WP~ENGXBCU64PT. WPD Attachment A Subsidiary of USX Corporation Environmentally aware for the long run. AL~,. ~OILAND GAS CONSERVATION COM .SION GAS WELL OPEN FLOW POTENTIAL TEST REPORT la. TEST: INITIAL I X ~ lb. TYPE TEST STABLILIZED ~ NON STABILIZED ANNUAL [ J MULTIPOINT [, X [ CONSTANT TIME , SPECIAL ~ ! i OTHEP, ISOCHRONAL 2. Name of Operator 7. Permit No. Marathon Oil Company ~ '~'J- [ ~O 3. Address 8. APl Number 3201 C Street, Ste. 800, Anchorage, Alaska 99503-3934 50- 133-20346 4. Location of Well 9. Unit or Lease Name At surface Beaver Creek Unit 1487' FWL & 1164' FNL 10. Well Number Section 34, T7N, P,10W, S.M. BCU-6 11. Field and Pool Beaver Creek Field, Tyonek 5. Elevation in feet 16. Lease Designation and Serial No. 185'MSLI A-028083 12. Completion Date 113. Total Depth 114. Plugback T.D. 115. Type Completion (Describe) 4/97 15928 10406 (retainer) Single tbg. string/cased hole 16. Csg. Size Weight per foot, lb. I.D. in inches Set at ft. Perforations: From To 9.625 47 8.681 12410 9120-9155 Upper Tyonek 17. Tbg. Size Weight per foot, lb. I.D. in inches Set at ft. 9866-9886 Tyonek D-1 3.5" 9.3 2.992 8998 18' Packer set at ft' 119' GOR cflbbl' 120' APl Liquid Hydr°carb°ns 21' Specific Gravity Fl°wing fluid (O) 6911 .... 0.56 22. Producing thru: Reservoir Temp. °F. Mean Annual Temp. °F. Barometric Pressure. (Pa), psia Tbg. ~'-] Csg. ~--~ .121 33 14.73 23. Length of flow channel (L)9120 I Vertical Depth (H)19107 Ga. %C0210.2 %N20.6 %H2S10 Prover Uet;r runI Taps 24. Flow Data Tubing Data Casing Data Choke Prover Orifice Line Size X Size Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. (in.) (in.) psig hw °F. psig °F. psig °F. Hr. 1. 3.826 X 2 684 2.85 67 2350 53 - -- 24.000 2. 3.826 X 2 700 4.2 67 2200 53 - -- 24.000 3. 3.826 X 2 702 4.1 67 2060 53 .... 24.000 4. 3.826 X 2 702 4.6 72 1870 53 -- - 24.000 5. X Basic Coefficient (24-Hour) hwPm Pressure Flow Temp. Factor Gravity Factor Super Comp. Factor Rate of Flow No. Fb or Fp Pm Ft Fg Fpv Q, Mcfd 1. 46.6 44.2 698.7 0.9933 1.336 1.1447 2,057 2. 48.9 54.2 714.7 0.9933 1.336 1.1442 2,649 3. 55.6 53.6 716.7 0.9933 1.336 1.1424 2,981 4. 58.9 56.8 716.7 0.9887 1.336 1.1372 3,345 5. Fig 3-30 GPSA Temperature for Separator Gas for Flowing Fluid No. Pr T Tr Z Gg G 1. 1.0025 527 1.542 0.7632 0.56 ~, .... 2. 1.0259 527 1.542 0.7638 ~ i~ ~r~ ~ I ~/' J~ r~ 3. 1.0289 527 1.542 0.7663 Cdtical Pressure 682 ' "~ '~ ~' ''~' '~ ~, I~ 4. 1.0289 532 1.557 0.7733 Critical Temperature 342 Form 10-421 CONTINUED ON REVERSE SIDE R,v. Nlcti0rage Pc 2,950 Pc~ 8,702,500 Pf Pff 0 No. Pt PF Pc~ - Pt~ Pw Pw: Pc~ - Pw~ Ps Ps: Pta - Ps: 1. 2,350 5,522,500 3,180,000 - - - 0 0 2. 2,200 4,840,000 3,882,500 .... 0 0 3. 2,060 4,243,600 4,458,900 - - - 0 0 4. 1,870 3,496,900 5,205,600 .... 0 0 5. 0 0 25. AOF (Mcfd) 10,428 n 1.0193 Remarks: 4-point test conducted June 21-26, 1997, using wellhead gauge recorders. I hereby certify that the foregoing is true, and correct to the best of my knowledge. Signed~'~~....___. Title Reservoir Engineer Date 10/10197 DEFINITIONS OF SYMBOLS AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Q Tr T Z Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfdl hw/Pm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor = I/Z dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air = 1.00), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60° F.) per barrel oil (60° F) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back-pressure equiation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia · Shut-in pressure at vertical depth H, psia Static presssure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Flowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60°F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the MANUAL OF BACK-PI~I~SF.L;~ ~.. !'~ED OF GAS WELLS, Interstate Oil Compact Commission, Oklahoma City, Oklahoma Form 10-421 Rev. 7-1-80 (':,:.:'F ! Jii 1997 ..AJas..ka. ~il & Gas Cons, Gommis," ,Ancliorao Alaska ~ .n Domestic, ,'oduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 May 1, 1997 Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Wondzell: Please find attached Form 10-404, Report of Sundry Well Operations, for the BC-6 Workover. A 4-point will be performed on this well during the next couple of weeks and submitted to you following completion. If you have any questions, please contact me at 564-6315. Sincerely, Michael R. Olson Production Engineer Attachments cc: CEF '1¥NI91 10 A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown__ Stimulate Plugging__ Pull Tubing X Alter Casing Repair Well__ Perforate X Other X 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 196168, Anchora~le, AK 99519-6168 4. Location of Well at Surface 5. Type of Well: Development X Exploratory ~ Stratigraphic __ Service 1467' FWL, 1164' FNL, Sec. 34, T7N, R10W, S.M. At top of Productive Interval 1579' FWL, 1151' FNL, Sec. 34, T7N, R10W, S.M. {~ 9107' tvd At Effective Depth 1925' FWL, 1234' FNL, Sec. 34, T7N, R10W, S.M. ~ 10337' tvd At Total Depth 1889' FEL, 1796' FNL, Sec. 34, T7N, R10W, S.M. ~ 15610' tvd 15928 feet 15610 feet 12. Present Well Condition Summary Total Depth: measured true vertical 6. Datum Elevation (DF or KB) 185' KB MSL feet 7. Unit or Property Name Beaver Creek Unit 8. Well Number BC-6 9. Permit Number/~'e~a~eer 10. APl Number 50-- 133-20346 11. Field/Pool Beaver Creek Field Plugs (measured) 10400',11200',11360',14447',14647', 15260',15280' Effective Depth: measured 10400 true vertical 10337 feet feet Junk (measured) Fi11-10388' Casing Length Size Structural Conductor Surface 4022' 13-3/8" Intermediate 12410' 9-5/8" Production 3534' 7" Liner 1208' 5" Cemented Measured Depth True Vertical Depth 2400 SX 4022' 4022' 3388 SX 12410' 12228' 652 SX 14980 14674' 450 SX 15889' 15581' Perforation Depth: measured 9120-9155', 9866-9886' true vertical 9107-9141', 9824-9844' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3-1/2", 9.2~, N-80, 8998' Baker 194 SAB 40X32 Packer, SSSV - N/A ORIGINAL 13. Stimulation or Cement Squeeze Summary Cement Squeeze: 5095-5115', 5122-5142' Intervals Treated (measured) N/A Treatment Description Including Volumes Used and Final Pressure N/A 14. Representative Dai y Avera,qe Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation 0 0 0 0 Subsequent to Operation 4000 3 0 1780 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of Well Classification as: Oil Gas X Suspended Service 17. I hereby certify that the fo. rego~ng is true and ~7.ei'rect to the best of my knowledge. Si~.ned_ .~~~~/,~ Title Production Engineer Date 5/1/97 Form 10-404 Rev. 06/15188 Submit in Duplicate OPEI~TTON SU~I~RY REPORT t/ELL: BC 6 11/0 · 01/05/96 I 0 ACCEPTED RIG AT NIDNIGHT 1-4-96. RAN WATER LINE. FILLED PITS WITH WATER AND STARTED MIXING BRINE. 01/06/96 2 0 8.800 FINISHED NIXING 9.0 PPG BRINE· R/U SLICKLINE AND RETRIEVED PLUG AT 505~. R/U TO KILL WELL. REPAIRED RIG. CIRCULATED 9.0 PPG BRINE TO KILL WELL, 01/07/96 3 0 9.000 FINISHED KILLING WELL. SET BPV. gOULD NOT TEST. PULLED BPV. SET TUBING PLUG AT 505~. N/D TREE. N/U BOPE. STARTED TESTING BOPE. 01/08/96 4 5159 9.000 ATTEMPTED TO TEST BOPE. FOUND TUBING HANGER LEAKING. RETRIEVED TUBING PLUG AT 505~. CBU. PULLED AND L/D TUBING. STARTED TESTING BOPE. 01/09/96 5 5104 9.000 TESTED BOPE. P/U AND N/U KELLY. BHA. RIH P/U 3 1/2" DRILL PIPE. TAGGED AT 5104~. CIRCULATED AND REPAIRED ROTARY. DRILLED 1~ OF HARD CEMENT. CBU. 01/10/96 6 4860 9.000 CBU. POOH. BHA. TESTED HCR VALVE. FAILED. RIH OPEN ENDED AHD TAGGED AT 5106I. CBU. SQUEEZED PERFS WITH 13 BBLS OF CEHENT. FINAL SQ. PRESSURE 3000 PSI AT 1/3 BPM. HELD PRESSURE ON SQUEEZE. POOH. PULLED gEAR BUSHING. '.. 01/11/96 ? 4984 9.000 SET RETRIEVABLE BRIDGE PLUG AT 1003'. N/D BOP STACK. CHANGED OUT TUBING SPOOL, AND TESTED SAME. N/U BOP STACK. TESTED BREAK. RETRIEVE BRIDGE PLUG. N/U BIT, P/U DC AND HEAVY WT DP AND RIH. TAGGED CEMENT AT 4820'. TESTED CASING TO 2000 PS{. DRILLED CEMENT FROg 4820' TO 498~'. 01/12/96 8 5185 9.000 DRILLED CENENT FROg 4984' TO 5115'. CBU. TESTED PERFS TO 2000 PSI. DRILLED CEMENT FROg 5115' TO 5136~. LOST RETURNS, TOOK 100 BBLS TO FILL HOLE. CBU, LOSING RETURNS. MONITER NELL, LOSING 60 BPH. SPOT 40 BBL HI VIS PILL. NONITER NELL, LOSING 17 BPH. SPOT HI VIS LOg PILL. POOH 12 STDS. NONITER WELL, LOSING 1BPH. RIH TO 5136~. DRILL CENENT FROg 5136' TO 5185'. CBU. POOH. M/U DIVERTER TOOL AND RIH TO 5185'. CBU. 01/13/96 9 4?20 9.000 CIRCULATED HOLE CLEAN. MIXED 300 SX CEMENT AND SPOTTED SANE. POOH TO 4007'. SQUEEZED 27 BBLS (132 SX)'CENENT AgAY. gOC HOLDING PRESSURE. BLED OFF PRESSURE. POOH, L/D 68 JTS DP. TESTED BOPS. P/U BIT #2 AND RIH TO 4227'. 01/14/96 10 7550 9.000 gASHED/REAMED FROg 4227' TO 4750'. DRILLED CEMENT FROg 4750 TO 5185. CBU. TESTED CASING TO 2000 PSI. DRILLED CEMENT FROg 5185' TO 5245', WASHED TO 5265'. CBU. TESTED CASING TO 2000 PSI. POOH. P/U MILL AND BOOT BASKETS AND STARTED RIH. 01/15/96 11 11360 9.000 RIH W/ MILL, HIT TIGHT SPOT AT 5185'. REAMED TIGHT SPOT FROg 5185'T0 5188'. RIH TO 6386'. CBU. RIH TO 6930, MILL TAKING WT. CBU. REANED FROg 6930' TO 7562'. HILLED ON CEMENT BASKET,JUNK AND OPEI~T~ON SUN. N~RY REPORT WELL: BC 6 W/O . RETAINER AT 7362', RENDED TO 7608'. CBU. RIH TO 9073'. R/U TO CURCULATE. 01/16/96 12 11208 9.000 CBU AT 9073'. RIH TO 11,208'. CBU. POOH. L/D HILL AND BOOTBASKETS. P/U BIT AND CASING SCRAPER AND RIH. 01/17/96 13 11200 9.100 RIH gITH BIT AND SCRAPER TO 11,208'. CBU. POOH. P/U AND RIH WITH CENENT RETAINER TO 11,203'. SET SANE AT 11,200'. TESTED CASING TO 2000 PSI. PREP TO POOH. 01/18/96 14 11200 9.060 POOH. RIH WITH RTTS. SET RTTS AT 6990~. TESTED TO 4000 PSI. BLED TO 3000 PSI IN 14 NIH. TESTED BACKSIDE TO 2000 PSI. BLED TO 1650 PSI IN 8 NIH. RIH TO 10200~. SET RTTS AND TESTED TO 4000 PSI. BLED TO $000 PSI IN 2 giN. RIH AND SET RTTS AT 11166~. TESTED BELOU TO 4000 PSl. 01/19/96 15 11200 9.040 TESTED CASING TO 4000 PSI WITH RTTS AT 11166' AND 10787'. RTTS HUNG UP AT lO?&O'. CBU. TESTED CASING TO 4000 PSI AT 10730' AND 10400~. LEAKED OFF AT 10400~. POOH. RTTS DRAGGING. CBU AT 8592'. POOH WITH RTTS DRAGGING. L/D RTTS. 01/20/96 16 11200 9.000 L/D RTTS. RIH TO 11194' WITH BIT AND SCRAPER. CIRCULATED AND SWEPT HOLE. L/D 23 JTS OF DRILL PIPE. POOH. BHA. RIH WITH RETAINER. 01/21/96 17 10400 8.710 RZH WITH RETAINER AND SET AT 10400'. POOH. TESTED BOPE. RIH WITH RTTS AND SET AT 7000 PSI. TESTED BELOW TO 4000' AND THE BACKSIDE TO 2000 PSI. POOH. 01/22/96 18 10400 9.000 POOH W/RTTS. L/D DRILL COLLARS. RIH WITH BIT AND SCRAPER. REPAIRED DRAgWORKS. RIH TO 10395'. CIRCULATED AND SWEPT HOLE. PUNPED DOWN ACTIVE PITS. CLEANED ACTIVE PITS. 01/23/96 19 10400 8.550 FINISHED CLEANING PITS. NIXED 3~ KCL. DISPLACED HELL WITH KCL. POOH L/D DRILL PIPE. STARTED RUNNING 3 1/2" TUBING. 01/24/96 20 10400 8.550 RAN PRODUCTION PACKER ON 3 1/2" TUBING EXTERNALLY TESTING TO 5000 PSI. LANDED HANGER WITH TUBING TAIL AT 8998~. TESTED HANGER TO 1000 PSI. CIRCULATED AND INHIBITED THE 3X KCL. REVERSE CIRCULATED 10 BBLS OF DIESEL INTO ANNULUS. 01/25/96 21 10400 8.550 SET PACKER. TESTED CASING BELOg PACKER. SET BPV. N/D BOP'S. N/U AND TESTED TREE. RELEASED RIG. OPERATION SUMMARY REPORT: POST RIG WELL: BC- 6 .... ':'.DATE'~ .... : RpT .. ..'. :' i'D'EpTH . 'i".:MUD WT. DAILY OPERATIONS SUMMARY ':" :'" .... :.:...'" ' 2/2/96 RU HES braided line unit. Swab well down to 6010' md. P~ll dummy valve at 987' and install injection valve. 2/4/96 10385' RU SWS. PT to 1650 psig WHP. MU 2-1/2" HC, 6spf, 60 degree phasing. Perforate 9866-9886' (D-l) w/ 800 psig underbalance. Bring well on line. 3/8/96 10410' RU HES slickline unit. PT against flowing WHP (2700 psig). MU tandom electronic pressure/temperature gauges. RIH making 10 minute gradient stops. Hydraulic hose failed at 7500'. POOH. Replace hose. Retest to 2700 psig. making 10 minute gradient stops. Tag fill at 10410'. Record FBHP for 6 hours at 9876'. Q= 2.6 mmscfpd at 2794 psig. SI well and record 60 hr PBU. POOH. Return well to production. 12/19/96 10409' RU HES slickline unit. PT against SI WHP (3100 psig). MU tandom electronic pressure/temperature gauges. RIH. Could not get below 50' POOH. Add add'l 30# weight. RIH making 5 minute gradient stops. Tag fill at 10409'. Make 4 hour stop at 9876' POOH RD. Return well to production. 12/26/96 10409' RU SWS. MU 2-1/2" HC, 6 spf, 60 degree phasing. PT against SI WHP (3100 psig). RIH and perforate 9130-9155' (Upper Tyonek) w/ 1300 psig underbalance. Well flowing .26 mmscfpd while perforating. POOH. Return well to production. No change An rate or pressure. Q=3.2 nuascfpd at 2220 psig. 12/27/96 10409' MU 2-1/2" HC, 6 spf, 60 degree phasing. PT against SI WHP (3100 psig). RIH and perforate 9120-9130' (Upper Tyonek) w/ 1300 psig underbalance. Well flowing mmscfpd while perforating. POOH. Return well to production. No change in rate or pressure. 2/7/97 10409' ' RU SWS. MU 2-1/8" EJ3, 6 spf, +/-45 degree phasing. PT against SI WHP (3430 psig). RIH and perforate 9128-9155* (Upper Tyonek) w/ 500 psig underbalance. POOH. MU 2-1/8" EJ3 as above. RIH and perforate 9120-9128' (Upper Tyonek). POOH. Return well to production. Well slow to come on line. Stabilized rate at 3.4 mmscfpd at 2045 psig, no increase in production. 4/8/97 10409' Well test: 4000 mscfpd, 3 bwpd, 1780 psig. 4/16/97 10388' RU HES. MU tandom electronic gauge and RIH making gradient stops. Tag bottom at 10388' Record SBHP and POOH. SI WHP = 3407 psia. BC - 6 80-40 K-Anchor (6909 9-6911 0 OD:4 750 ID:S 25O) Baker 194 BAB 40X32 Packer (6911 0 6916 4, 008 125 ID3 250) Camco X Nippe (6965 9 6967 3 003 950 ID2613) Camco X Nipple (8961 5 8962 9 OD4 050 ID2 813) W~reii~le Reentry Guide (8997 3 6998 0 003 867 ID2 992) PeR (9120 0 9155 0) Pad (9866 0 9666 0) b~lt (10388 0 1O4OO 0 OD8 625) R¢,tai~e¢ (10400 0-10406 0 OD8 981) B 15 (7010') B 16 (7O5O') B 16L (7!30') 8 17 (7195') B 18 (7260') B 19 (7350') B-20 (7460') B 21 (7520') B 23 (7620') B 24 (78OO') U Tyonek D I (9866') Retainer (11200 0-! 1210 0 OD8 981 ) Cement (1136O 0 11446 0 OD 6 625) Packe¢ (11446 0-I 1453 00D8 961 ) Cement (11446 0 ! 156O 0 OD 6 168) P~oductior~ Liner (114460 [4960 0 OD/000 Wt32 00) Cement (14847 0~14647 0, OD:6 166) Bridge Plug (14647 0-14653 0 OD6 164) P¢oductioa Linet (14661 0 15889 0 OD5 000 Wt16 00) Ceme~t (1526O 0 1528O 0 OD4 016) Bridge Plug (15280 0 15266 0 OD4 016) APl 50-133-20346 5/1/97 MARATHON OIL COMPANY 3201 C Street, Suite 800 P.O. Box 196168 Anchorage, Alaska 99519-6168 Telephone: (907) 561-5311 Fax: (907) 564-6489 Letter of Transmittal March 12, 1996 TO: Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 FROM: Chick Underwood Exploitation Department WELL LOGS Descriotion .Prinl; KDU-4RD COMPLETION 'RECORD 2~6/96 2.5" HSD I I KBU 41-7 COMPLETION RECORD Beaver Creek Field 2/8/96 I I BC-6 COMPLETION RECORD 2/4/96 I TOTAL 3 Film 1 3 This data is considered confidential until the normal release date. (Marathon Oil) (Date) ~(Recei~ed~y) C/ (Date) Alasl (' Dom~ Juction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 February 23, 1996 Chief, Branch of Lease Operations Bureau of Land Management 6881 Abbott Loop Road Anchorage, AK 99507-2591 Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Gentlemen: Re: Beaver Creek Unit Tyonek Gas Production Marathon Oil Company, as Operator of the Beaver Creek Unit, is pleased to inform you that the recent workoverl,i~f..BCU Woll #6,.has been successful in establishing , '2~ ,,,.~h.2.' ~',1,:'4",:,,"1, f ', :~,, ,, ;':'. ~,.,,t, ,/..,,. ,'.!a, ,,'. ,, ,j,,,i~,,,,,~.,,; .:: . commercial gas production from' ~he"Tyonel( t~ormat~on at 9,866-86' MD. First production occurred on February 4, 1996. Completign and testing operations are still in progress and are expected to be continue for several months. Marathon is gathering geologic and engineering data to submit to your agencies for approval of a Tyonek Participating Area and Pool Rules. We will be communicating with you in the near future to ensure that all required reporting is completed. Meanwhile, if you have any questions please call m.e at 564-6327, or Brad Penn at 564-6428. /, I, /; L~'ndoii 'C. Ibele Reservoir Engineer FEB 2_ 6 LCI/kz:BC6LTR.WP Alaska Oil & Gas Cons. Comm'~lon Anohorage A subsidiary of USX Corporation Environmentally aware for the long run. MEMORANDUM State of Alaska, Alaska Oil and Gas Conservation Commission TO: David Johns n, DATE: January 20, 1996 Chairman THRU: Blair Wondzell, - FILE NO: A99JATDD.doc P. I. Supervisor ""4f FROM: Lou Grimaldi,-��— SUBJECT: BOPE Test, Pool rig#122 Petroleum Inspector Marathon Beaver Creek unit Well #BCU #6 PTDrSundry 95-052 Saturday, January 20, 1996: 1 traveled to Marathon's Beaver Creek field to witness the weekly BOPE test on Pool rig#122, which is working over BCU #6. I arrived at 1330 and the test got underway at 1500 and ended at approximately 1700. There were 3 valves on the choke manifold that failed to hold their pressure test. one had a body leak at the weep hole in the bonnet and the otheraaee� two had a minor drip exhibited at the line returning to the possum belly. The leaks in all these valves were minor and as the rig will be completing the well I allowed for three days repair time. The rig was in good shape and I found their test procedure to provide a good check of the individual BOP components. The area surrounding the rig was orderly and well kept. Summary: I witnessed a BOPE test on Pool rig #122 working over well #BCU -6. The test lasted 2 hours and there were 3 failures. Attachment: A99JATDD.XLS STATE OF ALASKA REMARKS: Three valve failures on choke manifold, repair valves and report to ACGCC.Kelly not needed, test if picked up. Good test procedure. Distribution: ong-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FI-0211-(Rev.12194) A99JATDD.XLS Lou Grimaldi OIL AND GAS CONSERVATION COMMISSION TEST DATA BOPE Test Report Tt Test OPERATION: Drlg: Workover: X Sundry QF-nF9 DATE: 1/20/96 Drlg Contractor: Pool Rig No. 122 PTD # Rig Ph.# 227-0421 Operator: Marathon Rep.: Pete Verga Housekeeping: P Well Name: B-6 Rig Rep.: Gary Goedich 250/5,000 Casing Size: Set @ Location: Sec. 34 T. 7N R. 10W Meridian Seward Test: Initial Weekly X Other Standing Order Posted P REMARKS: Three valve failures on choke manifold, repair valves and report to ACGCC.Kelly not needed, test if picked up. Good test procedure. Distribution: ong-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FI-0211-(Rev.12194) A99JATDD.XLS Lou Grimaldi TEST DATA Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Quan. Pressure PIF Location Gen.: P Well Sign P Upper Kelly / IBOP 250/5,000 Housekeeping: P (Gen) Drl. Rig P Lower Kelly / IBOP 250/5,000 PTD On Location P Hazard Sec. P Ball Type 1 250/5,000 P Standing Order Posted P Inside BOP 1 250/5,000 1 P BOP STACK: Quan. Test Press. P/F Test Annular Preventer 1 250/2500 P CHOKE MANIFOLD: Pressure PIF Pipe Rams 1 250/5,000 P No. Valves 15 250/5,000 F Lower Pipe Rams 1 250/5,000 P No. Flanges 34 250/5,000 P Blind Rams 1 250/5,000 P Manual Chokes 1 Functioned P Choke Ln. Valves 1 250/5,000 P Hydraulic Chokes 1 Functioned P HCR Valves 2 250/5,000 P Kill Line Valves 1 250/5,000 P ACCUMULATOR SYSTEM: Check Valve N/A 250/5,000 N/A System Pressure 3,000 P Pressure After Closure 1,500 P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 29 sec. Trip Tank P P System Pressure Attained 3 minutes 15 sec. Pit Level Indicators P P Blind Switch Covers: Master: P Remote: P Flow Indicator P P Nitgn.Btl's: Four Bottles Meth Gas Detector P P 2100 Average Psig. H2S Gas Detector P P TEST RESULTS Number of Failures: 3 ,Test Time: 2.0 Hours. Number of valves tested 19 Repair or Replacement of Failed Equipment will be made within 3 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Three valve failures on choke manifold, repair valves and report to ACGCC.Kelly not needed, test if picked up. Good test procedure. Distribution: ong-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FI-0211-(Rev.12194) A99JATDD.XLS Lou Grimaldi , STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon I Alter casing ~ Change approved program i Pull tubing --.X Variance ~ 2. Name of Operator ! 5. Type of Well: Marathon Oil Company ~ Development~ Exploratory ~ 3. Address Stratigraphic ~ P.O. Box 196168, Anchorage, AK 99519-6~168 Service__ 4. Location of well at surface 1487' FWL, 1164' FNL, Sec. 34, T7N, RIOW, S.M. At top of productive interval Suspend __ Operation shut61own Re-enter suspended well __ ,, Repair well ~ Plugging ~ "--Time extension ~ Stimulate ~ Perforate ~ Other .X.-- 1487' FWL, 1164' FNL, Sec. 34, T7N, RIOW, S.M. At effective depth Attotal depth ORIGINAL 2224' FWL, 17931 FNL, Sec. 34, T7N, RIOW, S.M. 6. Datum elevation (DF or KB) 185' KB MSL 7. Unit or Property name Beaver Creek Unit 8. Well number BC-6 9. Permit number R1-1RR 10. APl number 50-- ].33-203.46 11. Field/Pool Beaver' Creek' Fie1 d 12. Present well condition summary Total depth: measured true vertical 15,9 28' feet 15,610' feet Effective depth: measured 5159 ' feet true vertical 5159 ' feet Casing Length Size Structural Conductor Surface 4,022' 13-3/8" Intermediate 12,410' 9-5/8" Production 3,534 ' 7" Liner 1,208' 5" Perforation depth: measured i Plugs (measured) 5.1'59 ' Junk (measured) Cemented Measured depth 2400. SX . 4,02.2' 3388 SX 12,410' 652 SX 14,980' 450 SX 15,889' See attached true vertical True vertical depth 4,022' 12,228' 14.,674' 15,295' RECEIVED feet Tubing (size. grade, and'measureddepth) 3-1/2" N-80 e 4,992 Packers and SSSV (type and measured depth) Otis RH Hydraulic @ 4955 13. Attachmenis. Description summary of proposal __ Detailed operations program MAY 1 § 1995 N~ka Oil & Gas Cons, Commimloa ~or~, ;.~ BOP sket(~h 'L 14. Estimated date for commencing operation . ~ 10-5-95 -16. If proposal was verbally approved Oil _... . Name of approver Date approved Service' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge~ · Signed ~,--'-'~, ~ Title ,/~,,.../,~ 5~,?~. FOR COMMI$~'-ON USE ONLY COnditions of approval: Notify Commission so representative may witness plug integrity ~ BOP Test __~ Location clearance ~ Mechanical Integrity Test .._ Subsequent form required 10- ~o ~. Approved by order of the Commissioner -- Form 10-403 Rev 06/15188 Original Signed By David W, Johnston' 15. Status of well classification as: Gas ~ Suspended ,i i^"pr°v'''"°. Approved Copy Returned t.,ommlss~oner ' ' Form 3161)-5 "IMay 1989) U~ 'ED STATES (Other lnstructiod~ a re- DEPARTM ~ i' OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not ttse this form for proposals to drill or to deepen or plug back to a dl~erent reservoir. Use "APPLICATION FOR PERMIT--" for such pi~pos~L) WELL WELL OTHER 9. NAME OF OPERATOR Marathon 0il Company 3. ADDBBBS or OPnATOR PO Box 196168, Anchorage, AK 99519-6168 4. LOCATION Or %%ELL IReport location clearly and in accordanc~ with any State requirements? See also space 17 below.) At surface 1487' FWL, 1164' FNL, Sec. 34, T7N, RIOW, S.M. 14. PERMIT NO. J 15. EleVATIONS (Show whether DP., RT, Ga, et~.) 81-150 J 1RS' KRMS! 16. FORM APPROVED OMB NO. 1004-0135 Expires: September 30, 1990 LEAS! DESIGNATION AND Su&IAL NO. A-028083 IF INDIAN, ALLOTTEE OR TBIBg NAME UNIT AOBEEMBNT NAMB Beaver Creek Unit 8. It&IM OB LBASB NAMII Beaver Creek 9. WBLL NO. BC-6 '-~0. I'IBLD AND POOL; OR WILDCAT Beaver Creek Field X1. SIC., T., u., M., OIt BLt. AZID BUIVBY OB mA Sec. 34, T7N, RIOW, S.M. 12. COUNTY OB pautSHJ 13. STATB K~_n~i J AK Check Appropr,ate Box To Indicme'Nature of Notice, Report, or Other Data NOTICB OP' INTENTION TO: TEST WATER SHUT-OFB' II PUl,I, OR ALTER ('%SINO J~_..J .FRACTUaE TREAT ML I.~.IPI,E t'OMPI.ETE SllOOT OR ACIDIZB ABANDON* (Other) .. SUBBE(~UBN'I: RBPOIT 0~': ieSACTt'BE TREATMENT ALTERING CASINO SHOOTING OR A¢IDIZING ABANDONMENTS (Other) (NOTE: Report results of multiple completion on Well ('.repletion or Recompletion Report end Log form.) ! 7. I)ES('RIBE I'ROI'OSED OR CO.HI'I.F-TF-D OI't'-RATEO%'~: ((..'h,;trly ~tat. nil i)ertlrte,ut de, tails, and give pertinent dates, including estimated date or starting an, proposed work. If well is dimctionally drilled, give subsu~&ee loc&tit, ns and meas~ired and true vertteal depths tar all markers and ~ones perti- nent to this work.) * See attached addendum 18. I hereby certify that the foregoing is true and correct RECEIVED MAY 15 1995 ktaska 0il & Gas Cons. Commission (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE *See Inmuctions on Reverse Side TLtle 18 U.S.C. Section !001, makes kt a crhne for any person know£ngl)' and willfully to make ,'o an7 department or a .F, ency of the United States an.,,' false, fict~ttous er fraudulent statements or representations as to any matter with:.n its jurisdiction. BC-6 PERFORATION INTERVALS 5,095' - 5,115' 5,122' - 5,142' 5,174' - 5,184' 20' Sterling B-3 20' Sterling B-3 10' Sterling B-3A Abandoned Perforation Intervals 15,003' - 15,200' 15,306' - 15,540' All depths are measured Top of Sterling B-3 Top of G-Zone Top of Hemlock Static BHP: 1275 psi 6/92 G-Zone Hemlock 5,090' MD 15,003' MD 15,306' MD Squeezed 6-92 5,090' TVD 14,696' TVD 14,991' TVD G:\CMN\DRLG\BC6PERF RECEIVED MAY 15 1995 Akaska Oil & Gas Cons. Commission Anchor~ I~, ~LL: BCU-6 Origin=[ RKB: 27' Top o? Sterling: 5,062' ConDie~lon Dn~e. 9-6-82 Att ,~ept~$ ~re RKB MD to tod oF equiDmen't. MARATHON OIL COMPANY Beave~ Creek Un~ API #: 50-133-B0346 Moxlmum Hoie Angle: ! Deg. Angle Through Per,Cs: 0 ]]eg. ReFerence Log: ]]IL 3/4/8~ Tree C=o Thre=ms: 3-1/2' EUE Bt= DEPTH 505' 4,920' 4,955' 4,992' 5,159' 5,e34' OTIS XL Bail V~ive L=nffimg NiDDte ~// 1/4' SS Con~r'ot Line OTI~ RH Hyd. Eetr. P~ckep DTI~ Exp. ~he~p Sub ToD o? Cemefl~ Plug Through Tubing Bmdge Plug Interv=L Zone Fl' 5,095' - 5,115' B-3 20 5,122' - 5,13~' B-3 10 5,132' - 5,148' B-3 5,174' - 5,184' B-3A ~eit Type: Gas Nee ~-l ~orkover [] ReCom~te~on [] Mm 2.75' 2.75' 8.78' 8.90" CASING & TUBIN~ ~PF 8 12 4 4 Size Veloh~c Grocte 13-3/8' 68 & 72# N-BO 9-5/8° 47 & 53.3# N-BO 7° 32# P-tlO 5' 1B~ N-BO 3-1/8' 9.Eft AB-Mo~ Buttress N-BO SurFace 11,446' 14.681' Sur~oce 11,360' - 11,560' OPM 50 sks class 'G' cms (Squeeze¢t 6/9~) IP_410' 1~990' 15389' 4,992' 14,447' - 14,647' ]]PM 14,647' ])PM G-Zone 15,003 - 15,200' OIL 15,254' 15,260 - 15,280' VLM 15,290' ~/LM Hemlock p~rF~ 15,306' - 15,540' OIL RECEIVED 35 sks class 'G' 7' Bridge Plug MAY 1 5 1995 AL~ OiL & Gas Cons. Commission FiLL Cemen'~ PLug Through Tubmg Bridge Plug Revision O~te, 6/19/9~ Rev~ea By: TAM/evo Re~son~ CT Ceeent S~uee; Prev~us RevlsIO~ 5/6/9E WORKOVER PROCEDURE FOR BC-6 . . 1 1 J . al 1 10. 11. 12. 13. 14. 15. Bullhead KWM down tubing string. R/U slickline. Open sliding sleeve at 4920' and fill annulus with KWM. Set BPV. Move in and rig up workover rig. N/D tree. N/U BOP's and test 250/3000 psi. Clean out wellbore to retainer at 7550'. Squeeze Sterling perforations. Clean out wellbore to 10,200'. Set production packer at 9000'. Run 3-1/2" production tubing. Set BPV. N/D BOP's. N/U tree and test. Rig down and move out workover rig. Perforate Tyonek 'D' sand 9860' - 9890' MD. conservative rate. Run pressure buildup to determine skin and Kh. EOB, or EOB resin sand control. Based on performance, necessary. Flow for extended time at Determine need for stim frac, perforate and test Upper Tyonek 9125' - 9160' if G:\CMN\DRLG\BC6WOP RECEIVED MAY 15 1995 Alaska Oil & Gas Cons. Conllnission Anchom,'..~ -AV-R xEFK CNo. 6 PROPOSED WEL_BORE SCH -MA - ' 20", 133 ppf, K55, Vetco-L Csg @ 505' 13 3/8", 68 & 72 ppf, K55 & N-80 Butt. @ 4,022' Upper Sterling Sqz perfs (5,132' - 5,184') 1/2" tubing Set pocker opproximotely 9,000' I Cement top @ 11,360' ~ 7" liner top @ 11,446' MD $m~ 9 5/8" csg @12,410' "l I-~ 5" liner top @ 14,681' MD ~¥ 15 199§ .~ L~z~ b.. 7", 32 ppf, X-line P-110 liner @ 14,980' MD Amaska Oil& GasCorls, CoDIlii]8$]011 Anchora(.,.~ L 5", 18 ppf, Hydril N-80 & P-110 Liner to 15,889' MD / Suspected completion scenorio: Tyonek D Sand (9,B60' - 9,B90' MD). Perforote; extended flow test at conservotive rate; PBU to determine skin ond kh; determine need for stimfroc, EOB, EOB resin sand control. Uphole recompletion potential in Upper Tyonek (9,125' - 9,160' MD) dictoted by performance of the Tyonek D Sand. CAM 3/04-/95 Marathon Oil Company ,., Alaska{ ,on Domestic Production ORIGI ^ RO. Box 190168 Anchorage, AK 99519-0168 Telephone 907/561-5311 July 7, 1992 Mr. D. W. Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston.' Enclosed is the AOGCC "Report of Sundry Well Operations" with appropriate attachments for Beaver Creek Well #6. Should you have any questions.regarding any application or report please contact E. V. Oberts at 907/564-6436 ' Sincerely, Operations Engineering Supervisor LCI/EVO/crc Attachment cc E. V. Oberts H:\~p\Sundry. ltr I £CEIVE5 JUL - ~ ~92 .Oil & Gas Cons. Commission ~rlctlorage A subsidiary of USX Corporation STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown m Pull tubing m Alter casing 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 190168 Anchorage, AK 99519 4. Location of well at surface 1,320' FWL, 1,420' FNL. Sec. At top of productive interval 1,320' FWL, 1,420' FNL. Sec. Stimulate __ Plugging X Perforate __ RepaIr well __ Other At effective depth 5. Type of Well: Development Exploratory Stratigraphic Service 34-7N- lOW-SM 34-7N- lOW-SM At total depth 2,057' FEL. 2,049' FI,IL. Sec. 34-7N-10W-SM 12. Present well cbndition summary Total depth: measured 15,928 feet true vertical 15,610 ' feet Effective depth: measured 5,159 feet true vertical 5,159 feet Casing Length Size Structural Conductor 4,022' 13-3/8" Surface 12,410' 9-5/8" Intermediate 3,534 ' 7" Production 1,208' 5" Liner Perforation depth: measured 5,095' - 5,122' - true vertical ' Plugs (measured) Junk (measured) Cemented 2400 sx 1800 sx 652 sx 450 sx 5,115' MD 5,142' MD Tubing (size, grade, and measured depth) 3-1/2" N-80 @ Packers and SSSV (type and measured depth) 0T I S RH Hyd. 4,992' 13. Stimulation or cement squeeze summary 6. Datum elevation (DF or KB) 27' KB above GL feet 7. Unit or Property name Beaver Creek Unit 8. Well number BC-6 5,159 None 9. Permit number/approval number 92-1 10. APl number 50- 1 11. Field/Pool Do~ver Creek FiP1H R-7nn~ Measured depth 4,022' 12,410' 14,980' 15,889' True vertical depth 4,022' 12,228' 14,674' 15,295' 5,095' 5,122' - 5,115' TVD - 5,142' TVD RECEIVED JUL - 8 199 Alaska 0iJ & Gas Cons. C0rpmi~sion Anchorage IntervalStreated(measured) 5,132' - 5,2'34' Treatment description including volumes used and final pressure Squeeze #1: 16 BBL Squeeze #2: 11 BBL Cement @ 1200 psi. Cement ~ 1150 _Psi. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressu re Prior to well operation 984 203 0 75O Subsequent to operation 9399 28 2.3 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run ~ I Daily Report of Well Operations X Oil ~ Gas X Suspended ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10.404 i:~v 06/15/8~'~-' '~ - Service Title Operation_~ Fnai nppri no .~,,.n~vi ~nr SUBMIT IN DUPLICATE 5/27/92 5/28/92 5/29/92 5/30/92 5/31/92 6/1/92 6/2/92 6/3-4/92 6/5/92 6/6-9/92 6/10/92 6/11/92 - 6/25/92 6/26/92 6/27/92 6/28/92 H:\~p\Sundry. BC6 BEAVER CREEK UNZT NELL #6 RENED!AL SUHNARY RU E-line PT lubricator to 1700 psi. Run Gauge Ring to 5750' ELM. Run through-tubing bridge plug and set at 5234' ELM. Dump bail 50 lbs. lead shot and one run cement. Bail six more runs of cement. Est TOC e 5225' ELM. RD E-line. WOC, RU CTU and Cementers. Finish RU on well. PT all equipment to 4000 psi. Attempt to fill hole w/ 3% KC1. Could not establish returns. Spot 16 bbl cement across perfs, pull up into. tubing, squeeze approx. 7 bbl cement away. Contaminate cement in wellbore from 5160' CTM to surface. WOC, RIH and jet out contaminated cement. PT squeeze to 650 psi, bled off to 450 psi in 10 minutes. PT to 650 again, bled off to 450 in 5 minutes. Resqueeze necessary. RIH, hole full. Spot 11 bbl cement across perfs. Pull into tubing, squeeze approx. 1/4 bbl cement away. Contaminate as in first squeeze. POOH. WOC, RIH jetting out contaminated cement to 5160' CTM. Perform positive PT, identify communication to casing. Unload well to 4go0' with Nitrogen for negative test. Leave g30 psi on well overnight. Test held solid ~ 930 psi overnight. RD CTU and cementers. RU E- line unit. PT lubricator to 1500 psi. RIH and tag cement ~ 515g' ELM. Perforate 5122' - 5132' DIL and 5095'-5115' DIL at 8 SPF using 2-1/8" domed scallop guns. RD E-line. Attempt to kick off well. Attempt to flow well. Will not unload. Well shut-in. Shoot fluid level $ 4750'. Attempt to unload again. Low production rate will not unload water. RU E-line. Pt lubricator to 1600 psi. RIH w/ 2-1/8" 4 SPF strip gun. Perforate 5122' - 5142' DIL. POOH. RD E-line. Unload well and begin testing. Test wel 1. RU slickline unit and RIH with gauges. SI well for PBU. POOH with gauges. RD slickline unit. Unload well and turn over to production department. JUL - ~ 1997.. Alaska Oil & Gas Cons. Gomm'~ss't~ Anchorage .WELL~ BCU-6 Orlgln~L RKB: 27' Top oF Sterling. 5,062' Comp[etlon Date. 9-6-82 ALL depths are RKB MD to top oF equlpment. MARATHDN OIL CDMPANY Beaver Creek Unlt APl 44: 50-133-80346 Maximum Hole Angle: 1 Deg, Angle Through Per:Fs: 0 Deg. ReFerence Log.. DIL 3/4/82 Tree Cap Threads-' 3-1/2' EUE 8rd We[[ Type. Gas New gq Workover gq Recomp[et~on [X] DEPTH 505' 4,920' 4,955' 4,992' 5,159' 5,234' Interval 5,095' - 5,115' 5,122' - 5,132' 5,132' - 5,142' 5,174' - 5,184' JEWELRY OTIS XL Ball Valve L(xndlng Nipple W/ 1/4' SS Control Line DTIS XA Cimcu[atlng Sleeve DT[S RH Hyd. Retr. Packer DTIS Exp. Shear Sub Top oF Cement Plug Through Tubing Bridge P[u9 Min I.D. 2.75' 2.75' 2.78' 2.90' RE EIVF. D Stertln9 PerFs Zone F__T SPF B-3 20 8 B-3 10 12 B-3 10 4 B-3A 10 4 d UL - 8 1992 Alaska.OS.& Gas Cons. Commission ;A, nchorage (Squeezed 6/92) ~ize 13-3/8' 9-5/8' 7' 5' 3-1/8' CASING & TUBING Weioht 68 & 7244 47 & 53.3# 3244 18# 9.2# AB-Mod Buttress Grade N-80 N-B0 P-Il0 N-80 N-80 TOp SurFace SurFace 11,446' 14,681' SurFace BOttOM 4,088' 1~410' 14,980' t~889' 4,998' 11,360' - 11,560' DPM 50 sks class 'G' CML. 14,447' - 14,647' DPM 14,647' DPM G-Zone PerFs 15,003 - 15,800' DIL 35 .sks class 'G' cml. 7' Bridge PLug 1~254' WLM 1~260 - 1~280' WLM 15,280' WLM FiLL Cement PLug Through Tubing Bridge PLug Hemlock PerFs 1~306' - 15,540' DIL Revision Date: 6/19/92 Revised By: TAM/eva Reason: CT Cement Squee; Previous Revision: 5/6/92 Marathon Oil Company ,, Alaska _1~ Jn Domestic r'roduction ~ ~i~ ,~ ~ J j'~ ..~~ RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 Nay 19, 1992 Mr. D. W. Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Johnston.' Attached for your approval is an "Application for Sundry Approvals" for Beaver Creek Well BC #6. Should you have any questions or need any additional information regarding any application or report, please contact L. C. Ibele at (907) 564-6450. Sincerely, Ibele Operations Engineering Supervisor Attachments em\docs\m1\6 A subsidiary of USX Corporation RECEIVED M AY 1 91962 Alaska Oil & Ge.$ Cons. CommisSi°r~ Anc~'mrage (' STATE OFALASKA COMMli~b,ON O i'~f' '!''~''~ ~}~ A L ALAbKA OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter cas~ ng __ Repair well __ Change approved program __ Operation shutdown __ Re-enter suspended well __ Plugging ~ Time extens,on __ Stimulate __ Pull tubmg __ Variance __ Pedorate __ Other L. Type of Well: Development _~. Exploratory __ Stratigraphic __ 995 Service __ 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 190168 Anchorage, AK 4. Location of well at surface 1,320' FWL, 1,420' FNL, Sec. At top of productive interval 1,320' FWL, 1,420' FNL, Sec. At effective depth 34-7N-lOW-SM 34-7N-lOW-SM 34-7N-lOW-SM At total depth 2,057' FEL, 2,049' FNL, Sec. 6. Datum elevation (DF or KB) 27' KB above GL 7. Unit or Property name Beaver Creek Unit 8. Well number BC 6 t,,~ermit number :~-150 10. APl number 5o- 133-20346 11. Field/Pool Beaver Creek Fie'Id feet G-Zone 12. Present well condition summary Total depth: measured true vertical 15,928' 15,610' feet feet Plugs(measured) 7,550' Effective depth: measured 7,550 ' true vertical 7,550' Casing Length Structural Conductor 4,022' Surface 12,410 ' Intermediate 3,534' Production 1,208' Liner Perforation depth: measured true vertical 13 9 Size feet feet Junk (measured) N on e Cemented Measured depth True vertical depth 3/8" 2400 sx 4,022' 5/8" 1800 sx 12,410' 7" 652 sx 14,980 ' 5" 450 sx 15,889' 5,132' - 5,142' MD 5,132' - 5,174' - 5,184' MD 5,174' - 4,022' 12,228' 14,674' 15,295' 5,142' TVD 5,184' TVD Tubing (size, grade, and measured depth) 3 1/2" N-80 ~ 4,992' Packers and SSSV (type and measured depth) OTIS RH Hyd. @kr ~ 4tg55' 13, Attachments Description summary of proposal 14. Estimated date for commencing operation May 21, 1992 S"-- 2-~- ~ 2_ Date approved 16. If proposal was verbally.,approved ,/., Name of approver Detailed operations program __ BOP sketch -X. REEE!VED! 15. Status of well classification as: Oil_ Gas_Z. Suspended__ MAY 1 9 1992 Service Alaska 0il & Gas Cons, 17. I hereby certify that the~)~egoing is true and correct to the best of my knowledge. S ,neU T,.. OP. ,t on Enqineerinq Supv. o..¥ Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- '/-~" Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 06/15188 SUBMIT IN TRIPLICATE le e e e Be PROCEDURE TO CEMENT SQUEEZE STERLING B-3A RU E-line. Make gauge ring run. Set through-tubing plug e 5234' DIL. Dump bail 10' cement plug on top of plug. RU CTU and pressure test lines. Function test BOP equipment. RIH, circulating filtered 3~ KC1 water. Spot and squeeze a maximum of 8 bbls cement. Hold for 40 minutes, then bleed pressure to atmospheric pressure. RIH circulating contaminant to 5160' (between B-3 and B-3A sands). Circulate filtered 3% KC1 water taking returns at surface. POOH. WOC 24 hours. RIH, circulating hole clean w/ gelled 3% KC1 water. POOH. Pressure test squeeze to 500 psi surface pressure. If pressure test fails, resqueeze as necessary. RU E-line. Perforate upper B-3 intervals from 5095'-5115' DIL and from 5122' - 5132' DIL. Return to production. \oe63\la.doc RECEIVED MAY 1 9199t Alaska Oil & Anchorage WELl: BCU-6 Original RKB: P7' Top o? S~erling: Completion Date: All dep~h~ ~e RKB MD ~op oF equipment. i MARATHON OIL"(' 2ANY Beaver Creek Unlt AP! #: 50-133-20346 Maximum Hole Angle: 1 Deg. Angle Through Per~Fs: 0 Deg. ReFerence Log: I)]L 3/4/82 Well Type: Gas New [] Workover [] Re¢omple~ion [] DE;PTH 505' 4,920' 4,955' 4,992' 7,550' JEWELRY OTIS XL Ball Valve Landing Nipple W/ 1/4' SS Control Line OT!S XA Circulating Sleeve OTIS EH Hyd, Retr, Packer OTIS Exp, Shear Sub Howco EZ-SV Bridge Plug Min I.D. 2.75' 2.75' E~.78' 2.90' Sterllnq Per?s In'l:erval Zone F'I' SPF 5,132' - 5,142' B-3 10 4 5,174' - 5,184' B-3A 10 4 CASING & TUBING Size Welght Grade ToD Bo~tom 13-3/8' 68 & 72# N-BO SurFace 4,0/~P' 9-5/8' 47 & 53.3# N-BO SurFace lpg410' 7' 32ff P-ilO 11,446' 14,980' 5' 18# N-BO 14,681' 15,889' 3-1/2' 9.2ff AB-Mod BUTT N-BO SurFace 4,992' 14,447' - 14,647' OPM 14,6,47' DPM G-Zone PerFs 15,003 - 15,200' DIL MAY 1 9 1992 Alaska Oil & Gas Cons. Commission Anchorage 35 sks class 'G' cml. 7' Bridge Plug 15,254' WLM 15,260 - 15,280' WLM 15,280' WLM Fill Cement Plug Through Tubln9 Bridge Plug Hemlock PerFs 15,306' - 15,540' DIL Revision D~e: 5/6/92 Revised By, TAM/evo Reason: Update Previous Revision: 2/89 BEAVER CREEK Coiled Tubing Lubricator w/Associated BOPE -Double BOP w/1 1/2' Rama SO00 pal WP 0 Hydraulic Rama o Tree Cap Swab Valve ~ 2' Wing Valve Maater Valvea 3. 1/2' 5000 pal Chrlatmae Tree Seal Flange UAY 1 9 ~992 ~as~,.Oii .& Gas Cons. Gommissio~ '~m~ .,~, ........................ ,, l .... BEAVER CREEK Wireline Lubricator w/Associated BOPE Grease Head (Hydralically Activated) , Lubricator Manually Operated BOP ,. Tree Cap Swab Valve 2" Wing Valve 3-1/2" 5000 Chrl.tma. Tree Master Valve. RECEIVED MAY ~ 9 ~99~ Alaska Oil & Gas Cons. Commissio~ Seal Flange Alaska Oil & Gas (Jons. (,u~JmJssJU,, , ,, ,.. ,..: :..,: .. Bill Sheffield ' ' ii '" .... :~.'... Governor ''? i .... ~' ': '"' ; ' ~'' ; ~ .. '. . ;., .,' ~.'1 '.. ~ ALASKA. OIL AND 6AS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99 501~"31'9 2 TELEPHONE (907) 279.-1433 ANC~O~~_~ REC'D M).L. L wman .:A~, 1 2 1984 ; 'We wish to bring to your attention that the 'Commission has not yet.received the'following required items on the subject well which our records indicated was completed ,~--~,~--J~ . . .., Article 536(b) of"Title 20, Chapter 25, 'Alaska Administrative Code, stipulates that this material Shal:l be filed within 30 days after completion of 'a drilled well. Please submit the above missing material. Sincerely, Chairman JAN2 0.1.984 Naska.0il & Gas Co.s., CommJ~ion ~qchorage Y · 2,435,215.B X = 315,831.4 ~ .. 28. 2'/' 3 4 · · [ " . '"'F:'.""~'"~ '.'.')N ;54 -~. .:::.r.~:., ,,....."~ "!';',. "': .. A :.,' '" '" , .... :.,:.. i) · --'; ' I BEAVER CREEK NO. 6 · - I Surface Well Location [ 30"Casing" I Y = 2,455,960.6 ' '. ~ ~ X -- 317,280.5- - 1467' J. Elevation 158.1 (top of well geller) : N.T.8. Y ~-t Converg. 0"53'IG. 13G" ... / -t'-,F ~ - ' ' d Bm · /'(~'"'~ BEAVER CREEK NO. S -I,'V ~, · ' ' [s~o "u' - . . . / / BEAVER CREEK NO. 4 ~/~, e _.~<~?.~. ~ :~ ~~/~: l~''~' oo, ~,,.-.o,,..,H,o .oo...o..~.~.. C~ ~' ~ ~ . '"~/.-~' /' fy ~_.'. ,' · ~~,~ '"-.,,.ee~' & -~' -- %, ~ ,..~.',l; 0 ' '~ 2 I/2' Flare pipe .d,,& ,drab. II .. I I · ~. ~ ~71 .,.'--.~. T ~::: ,/i:, ;,",r:." .... -..'~.-;.., I..'. .... :;.-.."':/ :-,-L~/ . ..['/-~'.i '/..' '"',"'~'"'~ "'l ":' · ' ,' · .-~......_~ .- , '!~ ...... ,~... .... ,,,...-. '.."~.'-,, ..,'.:; . v .... '~", ,". ' -.. ,*' ,,,..,,.~.-_....: L'I,....:~ .i ...~..J~,,,., j>.:. }.~ ~ ~. ~! . -. ...., · .~--~~:~ p..:.~ ...~:., I~_..~-J° --_'-' ~u..'~ 1:',~'~-.".- '"Y ~r~/s"l~..o~vLf,,N" ~./. ""::.:.~:':.' >,':'j.a; -'.,' . .... ' .- -?:,- "-~-".'., .': 'L' lh .,~-i,'i'~.': :1 · .,;' ./"', ' .'1 ~::-.:;.;'.I,'.~'L Lit .,L :,'3':.I.,N:.:~.. i-J~.--t..:.:-:i..;.~~ ..... ~: :Il"'.:" ,':-"':~:'-, 'I,.;~.,;5:~PL.~ ..,'~',-~),, VICINITY MAP SCALE: I"-- I MILE LEGEND AND NOTES : ~ Existing well location (~. christmae tree ). 0 Surface location (~. 30" cooing ) I) Y and X values are AK STATE PLANE COORDINATES for Zone 4. 2) Elevation on the top of the well .cellar il . . 158.1 feet il in reference lo MEAN SEA LEVEL. · 3) Bearinge refer to true North~ except as ii MARATHON OIL COMPANY OPERATOR BEAVER CREEK NO. 6 Situated 1233 feet South and 1467 feet East from the NW corner of Protracted Section 34, T?N, RIOW, S.M. AK. in fha Kenol Peninsula Borough. SURFACE LOCATION · SURVEYED BY: McLone and A$$oc/ote$,/nc. Soldotn~ , AK 99669 'Dote of Survey I Scale I Book No. Nov. 75,, 19el ! i' = 40'I M B.C. 4- ? 7 i jiiR II I I I STATE OF ALASKA ALASKA (.L AND GAS CONSERVATION CG(i.,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 2. Name of Operator DRILLING WELL [] COMPLETED WELL "OTHER [] Marathon Oil Company 3. Address P.O. Box 102380 4. Location of Well Surface: Anchorage Alaska 99510 1320' FWL, 1420' FNL Sec. 34-?N-10W-SM 5. Elevation in feet (indicate KB, DF, etc.) 185' KB 12. 6.~ease Desionation and Serial No. - 028083 7. Permit No. 81-150 8. APl Number 50_133-203k6 9. Unit or Lease Name Beaver Creek Unit 10. Well Number BC #6 11. Field and Pool Beaver Creek Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF .INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Stimulate [] Abandon [] Repair Well [] Change Plans [] (Submit in Duplicate) Perforations [] Altering Casing Stimulation [] Abandonment 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 /q proposed work, for Abandonment see 20 AAC 25.105.170). Well BC #6 was drilled to a revised total depth of 15928' MD, 15610' TV'D. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,,~Jaska Oil & ~as Cons. . The space below for Com .miss on use Conditions of Approval, if any: Title Date Approved by. Form 10-403 COMMISSIONER By Order of the Commission Date Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL,EX OTHER [] 2. Name of Operator 7. Permit No. Marathon Oil Company 81-150 3. Address 8. APl Number P.O. Box 102380, Anchorage AK 99510 50- 133-20346 4. Location of Well Surface: 1320' FWL, 1420' FNL, Sec. 34-7N-lOW-SM 5. Elevation in feet (indicate KB, DF, etc.) __ 185' KB 12. I 6. Lease Designation and Serial No. A-028083 9. Unit or Lease Name Beaver Creek Unit 10. Well Number SC #6 11. Field and Pool Beaver Creek Field 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). Completion and testing program for BC #6 Hemlock Zone. 1. Ran logs, CBL/VDL, Gyro Survey, FDC/CNL/GR. 2. Perforated Hemlock Zone W~ 4 HPF: 15,520' - 15,546' FDC/CNL 15,476' - 15,506' FDC/CNL 15,414' - 15,466' FDC/CN$ 15,387' - 15,407' FDC/CNL 15,345' - 15,370' FDC/CNL 15,306' - 15'~326' FDC/CNL 3. Flow tested well with gas lift. Final rate: 40 BFPD, 80% WC. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed h ~--~' ~'~C'---~_ . Title ~/~~..~;' _ _ 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 (' STATE OF ALASKA ALASKA L,~L AND GAS CONSERVATION C(5,vlM ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE L L,~i[' OTHER [] 2. Name of Operator Marathon Oil CompanF 3. Address P.O. Box 102380, Anchorage AK 4. Location of Well Surface: 99510 1320' FWL, 1420' FNL, Sec. 34-7N-lOW-SM 5. Elevation in feet (indicate KB, DF, etc.) 12. I 6. Lease Designation and Serial No. A-028083 7. Permit No. 81-150 8. APl Number 50- 1 33-20346 9. Unit or Lease Name Beaver Creek Unit 10. Well Number BC #6 11. Field and Pool Beaver Creek Field 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). Perforate and reperforate Beaver Creek #6 G-Zone. .1. The G-Zone was perforated and reperforated at 4 HPF under drawdown at: 15003' - 150'50' FDC/C~L 15170' - 15200' FDC/CNL 2. Flow tested the well with gas lift. Final rate: 26 BFPD, 50~ WC. .ECEIVED Alaska 0il & Gas Cons. Commission Anchorage ' 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed g~'~"~ %'.'.-~_~.v-~ Title ~~.-L=:; The space below for Commission use ~ Conditions of Approval, if any: By Order of Approved by... COMMISSIONER the Commission Date Form 10~t03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE Of ALASKA (~ ALASKA ,LAND GAS CONSERVATION C ,,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS OTHER [] -')" 1. DRILLING WELL [] COMPLETED WELLXZ 2. Name of Operator Marathon Oil CompanF 7. Permit No. 81-150 3. Address 8. APl Number P.O. Box 102380, Anchorage, AK 99510 50- 133-20346 1320' FWL, 1420' FNL, Sec. 34-7N-lOW-SM 6. Lease Designation and Serial No. A-028083 4. Location of Well Surface: 5. Elevation in feet (indicate KB, DF, etc.) 185' KB 9. Unit or Lease Name Bea~er Creek Unit 10. Well Number BC #6 11. F{eld and Pool Beaver Creek Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~' Altering Casing Stimulate [] Abandon [] Stimulation [] ' Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). An open flow potential test was conducted and the report (Form 10-421) was submitted to AOGCC in December, 1982. 14, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~' ~"~' ~--~-.~c~'x~:~ Title The ~paee below for Commission use L--~"¥t¢3,~ (zeJ~ ~) Date 02/2. R Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date ............................. I Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate February 16, 1983 ~arathon Oil Company P.O. Box 102380 Anchorage, Alaska 99510 Res Subsequent Reports, Sund~y Notices and Reports on Wells '(For~, 10-403 } For the following lists of "Notice of Intention To:" Sundry Notices and Report on ~ells (form 10-403) this office does not have on record the. "'Subsequent Report ofF' defining the act4. on taken on the. approved tnterCcion. Please advise this office by Subsequent Report of the d/ spos it ion of the intention. ~ l___Az · eaver Creek Beaver Creek Beaver Creek .Beaver Creek Be.ave r Creek Marathon Date 9/8/82 9/t~/e2 5/24/82 Brief Descri~tion of Intention ' ... ~ :: ;u' :~ : ;~ .~ ._.~ ...._,. ,, .: .. . :~ ~ ................ . Open flow potential test Open flow potentia! test' Open f~ow potential test' Completion and testing progra~ Perforate and re~erforate LC. St,TI~I~lh .. Anchora~ )ivision Productibn Operations, United States Marathon Oil Company February 9, 1983 Mr. Harry W. Kugler Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-31'92 P.O. Box 2380 Anchorage, Alaska 99510 Telephone 907/274-1511 ~.~ ~ , frO.'~ . Dear Mr. Kugler: This letter is in response to your inquiry of February 4, 1983, concerning digitized data for certain logs run in Beaver Creek Well No. 6. As stated in the attached'letter to Mr. Douglass dated July 9, 1982, the digitized library tapes are not available for this well. In place of tapes, Marathon mailed to AOGCC one.(1) blueline and one (1) sepia of all 'logs run in Beaver Creek Well No. 6. We hope this will take care of this matter. Very truly yours, K. A. THOMA ..... Operation's Superintendent lyd Attachment RECEIVED FEB i 1983 Alaska 011 & 13as Cons, Commission Anchorage Anchor~. c. vision Production Exploration, U.S. & Canada Marathon Oil Company P.O. Box 2380 Anchorage, Alaska 99510 Telephone 907/274-1511 July 9, 1982 Mr. Russ Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Beaver Cree~ Well 6 Final Prints and Sepias of BC-6 Logs Dear Sir: Enclosed please find one(l) blueline and one(l) sepia of all logs run in Beaver Creek Unit Well 6. These are submitted in 'lieu of the unavailable digitized library tape as per your conversation on June 22, 198~', with Mr. John Barnes, Marathon Oil Company. Also included is a copy of the directional survey on this well. t' Sincerely, · D. F. Stover Operations Engineer JAB: lyd Enclosure FEB I, 0[~. & Gas Co~s~ Oommissio~ Anchorage February 4, 1983 ~.'.',r. K. A. Tho~.a Operations Superintendent }~arathon Oil Company ?, O. Box 2380 Anchorage, Alaska 99510 De ar ,Mr. Thoma: ~.te Alaska Oil and Gas Conservation Commission }..,,as recently checked the records of wells .completed since January 1, .1979. This review ha~ revealed that the digitized data for certain logs run in a well is not on file with the Commission. The Oil' and Cas Regulations require' the operator to file, within 30 days after completion, ~uspension, or abandonment of a drilling well, the digitized data, if available, for copying, for all logs run in the well except velocity surveys, experi~ental logs and dip- meter surveys. We would request that you check your records to ~ee if the data. has been. submitted to the Commission and, if not, that you com..ply with the regulation with regard to the following. well ~ Beaver Creek ~o. 6. Thank. you. 'for your cooPeration in thi.~ matter. Yours very truly, BY ORDER OF THE COM}'iI SS ION be ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT la. TEST: INITIAL. lb. TYPETEST ~ECEIvS~BILIzED[~ NON STABILIZED [-I~_~.- ANNUAL [] MULTIPOINT [] . CONSTANT TIME [] SPECIAL [] OTHER ,SOCHRONAE ~[]~( -~---~" 2. Name of Operator DEC 0 0 J'982 7. Permit No.~i ' Marathon 0il Company A~, ...... 81-150 · 3. Address ",-e~a uil (~ [Ji~S C0135, COl]ll~j$$iOj3 8. APl Number ~_:!' P.O. Box 2380, Anchorage, AK 99510 Anchorage 50- 133-20346 4. Location of Well 9. Unit or Lease Name At surface: Beaver Creek We]] Pad #3 Beaver Creek Unit ~'.~...!. 1320' FWL, 1420' FNL, Sec. 34-7N-10W-SM 10. Well Number J At Top Producing Interval: 1320'FWL, 1420'FNL, Sec. 34-7N- BC #6 ,, cO-~ 10W- SM 11. Field and Pool FILF.. At Total Depth: 2057'FEL, 2049'FNL, Sec. 34-TN-lOW-SM -_i. 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease Designation and Serial No. Beaver C reek Fi el d KB 185' above MSL I A-028083 12. Completion Date 11131::: T~lt~l~:~el~~ 114. Plugback T.D. 115. Type Completion (Describe) 09/05/82 li~'.~.~,.;;n 17550'MD,7550'.TVDI Single/Sterling Formation 16. Csg. Size Weight per foot, Ib~ ~ '~ v .1~.1~,. in inches Set at ft. Perforations: From To 9-5/8" 47 8.681 ]2,4]0 B-3 5]32' - 5142' DIL 17. Tbg. Size Weight per foot, lb. I.D. in inches Set at ft. 3-1/2I' 9.2 2.992 4,992 B-3A 5174'- 5184' DIL 18' Packer set at ft'4955 J 19' GOR cf/bbl' 120' APl Liquid Hydr°carb°ns, · 21. Specific Gravity Flowing fluid (G)__ 22. Producing thru: Reservoir Temp. o F. ' Mean Annual Temp. o F. Barometric Pressure (Pa), psia' ' ' Tbg. ~ Csg. [] I 12' " "' 20 14.64, ..' 23. Lenoth o' "ow ~h.n,e' (L) I Ver, io,, Depth (H) I%. I.%CO~ J %N~"I O~H~S I P,ove, I Met,,run I.~,,s . - 5137 5137 O. 557 0.06 O. 52 -- XX I F1 ange 24. Flow Data 'Tubing Data Casing Data . Prover Chok'e Pressure Diff. Temp. Pressure Pressure Duration o,f Line X Orifice Temp. Temp. Flow ,, No. Size (in.) Size (in.) psig hw o F. psig o F, psig o F. Hr. 1. 3.826 1.50 1886 35.64 39 ' "1887" 60. 1 :" ' 2. 3.826 1.75 1865 39.56 42 1862 60 . 1 '- 3. 3.826' 1.75" 1843 = 53.14' 42' "1846 60. 1 4. 3.826 l. 75 1792 93-90 44 1796 60 I ' ' ' 5. 3. 826 2. O0 ] 749 85.56 47 1750 '60' 1 . . Basic Coefficient Flow Temp. Gravity Super Comp. .I --~ Pressure Factor Factor Factor '"Rate of FlOw (24-Hour) hwPm Pm Q, Mcfd No. Fb or Fp Ft Fg. Fpv ' 1. 11.16 260.29 1901 1.021 1.340 I ..154 4586 2. 15.~9 272.71 1880 1.018 1.340 1 149 6578 ' 3. 15.39 314.22 1858 1.018 1'.340.' 1.147 7566 4. 15.39 411.92 1807 1.016 1.340 1.140 9839 ' s. 20.50 388.49 1764 1.013 ,.. 1.340. 1.134 12259 : Temperature for Separator for F lowing Pr T Tr Z Gas Fluid. No. Gg G 1. 2.'82 499' l.Zi5 0,751' ' - 2. 2.79 502 ].46 0.7.5'8". '" -- 3. 2.76 502 1.46 O. 760 Critical Pressure 673 '" ' " 4. 2.6~'. 50'.4 I · 4;7 0.7,69 CriticalTemperature 343' -- ~. 2.62~_ 50_Q_7__. 1.48' O. 778 .. ' . Form 10-421 CONTINUED ON REVERSE SIDE Submit in duplicate Rev. 7-1-80 Pc 1~22 Pc23694.1 Pf 2169 Pr24704.6 No. Pt 1. 1903 2. 1878 3. 1861 4. ]-8]"]' 25. __ Pt2 Pc2 - Pt2 Pw 3621.4 72.7 1912 3526.9 [ ]67.2 I ]896 __3.46_.3_.,. 3 J 23_~,8 I 1885 ....... L..5_Zs.9 _ 83] AOF (Mcfd) 439 ~ 200 Pw2 IPc2. Pw2 IPs '~6 g4.2 --~9->9 2164 1~5~)5.1 99.0 12163 3553.5 1140.6 12160 3433.0. 1261'1 I ~215653 33542 339.9 Ps~( 1000 ' ~ )pr2. ps2(] 000 4682.9J 217 4678.6 I 26.0 4665.6 39-a 4648. ~;6 4635 69.2 n O. 848 Remarks' AOF based on measured sandface pressures. I hereby certify that the foregoing.is true and correct to the best of my knowledge Signed~_~_.~ Title ..................................... ~--"-,a~ Date s) AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z DEFINITIONS OF SYMBOLS Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd/ Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor=-~/"iT~' .... dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air=1.000), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F.) per barrel oil (60 degrees F.) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back-pressure equation, dimensionless Field barometric pressure, psia Shu..t..-in' wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static pressure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Flowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60 degrees F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual Of Back-Pressure Tesdng Of Gas We/Is, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-42'1 i' Beaver Creek #6 Open F 1 ow Potent i a 1 Test 10_0__~__ ~._. 4_. 0 0 2.§_ .... i . . AOF = 439~2 MMSCFPD n = 0.8479 Q(MSCFD)=337.71(Pf2-Ps2~_]~ J I,O00's) zo_.O. g. 7_1 · 1.5 2 2.5 3 Run 11/18/82 0.8479 5 6 7 8 9 10 1. 1.5 2 2.5 3 4 5 6 7 8 ~' Q (MMSCFPD) TO: MEM""ORA, IDUM sta. of Alaska · ~ . ,.. ,. . ~ . ~ ..... ,., DATE: ~ '18~ ].982 ,¥ '-' ~ 'FILE NO: ~t~: :[x:mz~e C. Sm~.b'z FROM: ~"]arolc], Ro ~ . ..z .... 'TELEPHONE' NO:. " ': :' SUBJECT: .,~ . ... ,..,... , .. .. q ,- ~ .... . · -'"" ,(.. -'., , - r- .,- .,, . · ,.. ,~ .. ~ ,..... . ',"' 't~ To Witness Isoch~ Flow Test ~rathon Oil Co. ~ Creek Unit B. C. No. 6 ., ..,. 02-O01A(Rev.10/79) ALASKA ~ STATE OF ALASKA .? 0 I{ I G IN k.b .~ID GAS CONSERVATION C~. '[.. ~SION i(./~ ~ WELL COMPLETION OR RECOMPLETION h,~PORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS~X SUSPENDED [] ABANDONED [] SERVICE [] ~2. Name of Operator 7. Permit Number Marathon Oil Company 81-150 3. Address 8. APl Number P.O. Box 2380, Anchorage, AK 99510 50-133-20346 4. Location of well at surface Beaver Creek Well Pad #3 I LOCATiONS1 9' Unit or Lease Name " 1320'FWL, 1420'FNL, Sec. 34-7N-10W-SM VEriFiEDi Beaver Creek Unit At Top Producing Interval 10. Well Number 1320'FWL, 1420'FNL, Sec. 34-7N-10W-SM Surf' ~---~ At Total Depth B.H. ~ .. BC #6 ~, 11. Field and Pool 2057'FEL, 2049'FNL, Sec. 34-7N-10W-SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KB 185' Above MSLI A-028083 Beaver Creek Field 121 Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 11/21/81 04/15/82 09/05/82 -- feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost t5928'MD 15610'TVI 7550'MD 7550'TV! YES'IX NO[] -- feet MD -- 22. Type Electric or Other Logs Run I{DC/CNL/GR, CBL/VDL, SP/GR/DIL, Gyro 23. CASING, LINER AND CEMENTING RECORD . SETTING DEPTH MD .' CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 68 & 72# N-80 Surface 4022' 17-1/2" 2400 sx cl G to surface. 9-5/8" 47 & 53.5 N-80 Surface 12410' 12-1/4" 1st stage 1588 sx c] G ', ....... 2nd "sta~;,e'1800 ..sx c] G , '- 7" 32# P-110 11446' 14980' 8-1/2" 650 sx cl G 5" 18# N-80 14681' 15889' 6" 4.50 sx cl G · :24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD . . .... "' interva'l, size and number) Sterling Gas Sand .B-3 SIZE DEPTH SET (MD) PACKER SET (MD). Top Bottom 3-1/2''' 4992' 4955 ' 5132'MD (5132'TVD) 5142'MD (5142'TVD) ... .... ,..: . · B-3A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5174'~), (.5174!TVD),....5184':[~...'(5.1.841TVD) ,.. DEPTH INTERVAL (M. D) .AMOU,.NT. & KINDOF MATERIAL USED . ....... .o 2~5/'8" Ho..ilow Carrier Gun 4-:.~.~ F;" .....,. ' .. . . . .. ~.. .. .... .. . ,, . , , , 27. PRODUCTION TEST' : ...... Date F.iCst Production .'.': .'... . I...M,eth0d of. operation.;(Flowing, gas lift, etc.) 09/05/82 I 3-0 'MMCF o.f gas' flared t~' clean ou~ well. '"" ' ,, Date of Test Hours Tested PRODUCTION FOR Gl L-BBL GAS-MCF WATER-BB'L CHOKE SIZE [ GAs-OIL RATIO 09/05/82, ..7.,25 ..... . TEST.'.pERIOD,I~ 0 ' 39.00.. .. 0. 56/64 .I -- Flow ~ubl.ng Casing.'.Pressure ..L. CA.,LCULATED,' .Q.IL-BBL GAS-MCF WATER-BBL . OIL .G. RAVi.T,Y-API (corr) . ' Press. 1794 '0 .. 24-HOU.R RATE ~ ..i0.', "' .108,,70 .... 0 --. ' 28. CORE DATA . , _ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ' ' ., ,. . :. ,.'~.~ . : .. ', .. ;..'. '" ' ' .... ' "' ','. '.."," . ' .- " .... . . ,,. .... . .~ ,. ., ,.. .. ,. ., ,..,, SEP 2 0 1982 . . ,, ,, ,, , , .. " ...... "' Alaska Oil & Gas Cons. Colnmission _ Anchorage , .. 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. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~J~ ~' ~--~O,~,::..--~,v~ Title ~J/:~~.~; ~-~ ~ Date ('~..~'~ /)/--.J,/~Z .................................. I - ~ ' - ,~ 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 (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ,. FO,~' '~,~4_,. REV..--~a ~,-y D~:TE . 06-23-82 , . M 'RATHQN {:31m- CQMPANY HISTORY OF' OIL OR GAS wm='LL FIELD Beaver Creek WELL NO. 6 LEASE Beaver Creek PARISH STATE Alaska BLOCK SEC., 34 TWP. 7N R., 10W MEASUREMENTS TAKEN FROM COUNTY. Kenai Peninsula, Alaska 150 ' MSL ELEV. .. HISTORY PREPARED BY L. G. Hay~ood .T,T'E. Secretary I ToP OF OIL STRING ~ ELEV., TOP OF ROTARY TABLE ELEV. GRD. OR MAT ELEV. --. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. -. DATE 1981 11-11 - 11-19 11-20 11-21 11-22 11-23 11-24 11-25 11-26 11-27 11-28 11-29 11-30 12-01 12-0.2 : 58 'TD 93 'TD 421 'TD 507 ' TD 507 ' TD 507 ' TD 660 ' TD 1,568'TD 2,250'TD 2,775'TD 3,110'TD 3,600'TD 4,033'TD BEAVER CREEK WELL NO. 6 -(Marathon AFE'17t2) Moving Brinkerhoff Rig 54 and rigging up. Spudded well at 1030 hrs, 11-19-81. Drove 30" cond to 58' & CO w/ bit & HO.~ Fin driving 30" cond. -Braced 30" in cellar & NU flow lines. Drld to 93'. POH for BHA chg. Drld &surv 93'-421'-w/ trips @ 203' &·-385'. Drld &surv 421'-507'. Opened 17-1/2" hole to 26" to 505'. Made wiper trip.-Circ & POH. RU & ran 20" csg. Fin running 20" csg to 502'. Stabbed into shoe w/ DP stinger. 'Circ & thinned back. visc of mud.. Mixed & pumped 1500 sx cmt.. Good returns, but no cmt to surf--just contaminated mud. WOC & prep.for top job. RIH w/ 2-3/8" tbg between 20" &- 30". 'Tagged hard cmt @ 42'KB. Mixed cmt & pumped top job from 42' to surf--good cmt returns to surf. Cut off 30" & 20". Welded on Bradenhead & tstd. Presently NU diverter, 20" Hydril, & flow lines. Fin NU Hydril & diverter. RIH w/ 17-1/2" bit & tagged cmt @ 494'. Tstd·20" ·csg & Hydril--OK. Drld cmt, shoe, & 3' of new. hole. POH.- Ran gyro surv from surf to 490'. RIH & ran leakoff test to-12.6 ppg MW equiv. surv 510'-660'. Drld &surv 17-1/2" 'hole from ·660'-1568'. Drld &surv 1568' 2250'. - Drld & . ECEI'VEI) · . SEP 2 0 Drld &surv 2250'-2775'. Oil & Gas Cons. Commission Anchorage . · .. Drld &surv 2775'-2920'. Circ & POH. Ran back to btm w/ short BHA--hole OK. Ran gyro surv thru DP to- 2840'. Closure @ 2840'-is 12.47' @ .S 22a 59' W '(away from BC. #5RD). POH & chgd BHA. RIH & drld 2920'-3110'. Drld &surv to 3.479'. Tripped for new bit & dr'ld to 3600'. Drld &surv 3600'-4033'. Circ.- Made wiper trip to 20" csg shoe. RIH &. had 2' of fill. Circ to cond for csg. Well History - Beaver Creek Well No. 6 Page 2 12-03 4,033'TD 12-04 4,033'TD 12-05 4,033'TD 12-06 4,033'TD 12-07 4,275'TD 12-08 4,864'TD 12-09 5,518'TD 12-10 5,840'TD 12-11 6,350'TD 12-12 6,508'TD 12-13 6,642'TD 12-14 6,905'TD 12-15 7,195'TD 12-16 7,528'TD 12~17 7,767'TD 12-18 7,799'TD 12-19 7,911'TD 12-20 8,100'TD 12-21 8,218'TD 12-22 8,262'TD Fin C&C hole. POH w/ DP. Ran 13-3/8" csg to 4022'. RIH w/ DP & stabbed into FC. Circ & RU cementers. Fin RU & cmtd surf csg w/ 2000 sx gel slurry followed' by 400 sx C1 G neat. Good cmt returns to surf. CIP @ 0920 hrs, 12-03-81. POH w/ DP stinger. PU 20" Hydril & diverter & set slips. Cut off 13-3/8" csg & began NU 13-5/8" spool & BOPE. Compl NU BOPE. Presently testing & repairing leaks. Compl repairing BOP leaks--tstd BOPE--OK. MU'BHA & RIH w/ 12-1/4" bit. Circ & drld FC @ 3941'. Tstd csg OK. Presently drlg cmt below FC. Drld out cmt & shoe. Drld new fm to 4038'. Tstd 13-3/8" csg shoe to~!~ppg MW equiv. POH. Ran gyro surv on 13-3/8" csg from surf to 4000'. RIH & drld & surv to 4275'. Drld & surv 4275'-4844'. Tripped for bit. Drld 4844'-4864'. Drld & surv 4864'-5518'. Drld 5518'-5536'. Circ, surv, & POH. Chgd bits & RIH. Blew circuit breakers--repair temp. POH to csg shoe. WO breakers. RIH & drld & surv to 5840'. Drld & surv 5840'-6350'. Drld & surv from 6350'-6508' w/ Wiper trip @ 6423' & trip for bit @ 6479'. Drld 6508'-6629'. Ran gyro surv inside DP to 6468' to check well course in relation to BC #5RD. CBU. POH. RIH w/ bit #11. Drld 6629'-6642'. Drld & surv 6642'-6905' w/ wiper trip @ 6718'. Drld & surv from 6905'-7195' w/ wiper trip @ 7154'. Incr MW from 10.1 to 10.3 ppg due to connection & BGG. Drld & surv from 7195'-7528'. Circ & su.~v. Made 10-std short trip:__ Drld 7528'- 7639'' ~rom 1~~@ 7639' to control BGG (1120 units max). Drld & surv 7639'- 7767' . Drld 7767'-7774'. Made 10-std short trip. CBU w/ 38 units trip gas. POH w/ bit #11. Tstd BOPE. RIH-- hol~ C.K. 'Drld 7774'-7799'. Drld 7799'-7911'. Had 120 units gas from 7885'-7890'. Drld & surv 7911'-8100' w/ short trip @ 7927'. BGG aver 30-50 units. Drld 8100'-8'120'. Circ. Ran gyro on WL to 8060'. Made 10-std short trip. Drld 8120'-8218'. Drld 8218'-8250'. & oriented w/ steering tool. Circ & POH w/ bit #12. RIH w/ DD DD 8250'-8262'. £CE VED SEP 2 0 -~?_'-.s,?,,a b~ & ~as Cons. Co~r~ls~[o~ Wel. i Hi~tory - Beaver Creek Well No. 6 Page 3 12-23 8,325'TD 12-24 8,435'TD 12-25 8,517'TD 12-26 8,600'TD 12-27 8,723'TD 12-28 8,898'TD 12-29 9,005'TD 12-30 9,205'TD 12-31 9,444'TD DD 8262'-8276'. POH for new bit & RIH. Oriented BHA & DD 8276'-8325'. Drld 8325'-8334'. Surv & POH. LD DD & PU drlg assy. RIH & drld & surv 8334'-8435'. Drld 8435'-8517'. C&C mud & surv. POH & PU DD. RIH & ran steering tool on WL--no signal. POH w/ WL. Fin POH w/ WL. Reheaded--still no signal. Repaired steering tool & RIH on WL. Oriented & drld 8517'- 8577'. POH w/ steering tool--intermittent short. Chng out tOol. RIH w/ tool on WL. Direc drld 8577'- 8600'. POH & LD DD. PU new BHA & RIH. Reamed to btm.. Drld 8600'-8723'. Drld & surv 8723'-8898' w/ short trip @ 8746'. Presently POH to chng bit & BHA. Fin POH w/ bit #17. Tstd BOPE--OK. PU new BHA & RIH. Drld 8898'-9005'. Surv. Drlg ahead @ 0700 hrs. Drld & surv 9005'-9205' w/ wiper trip @ 9129'. Hole cond good. Drld & surv 9205'-9444'. Began wiper trip @ 0700 hrs. .- . 1982 01-01 9,567'TD 01-02 9,719'TD 01-03 9,819'TD 01-04 9,869'TD 01-05 10,043'TD 01-06 10,266'TD 01-07 10,403'TD 01-08 10,460'TD 01-09 10,737'TD 01-10 10,839'TD 01-11 10,942'TD Fin circ & surv. bldg assy & RIH. 9819'. Fin 10-std wiper trip. Drld 9444'-9567'. Circ & surv. Making 10-std wiper trip @ 0700 hrs. Fin 10-std wiper trip. Hole cond good. Drld 9567'- 9719'. Circ prior to surv & tripped for new bit. POH w/ bit #18. Chgd BHA to angle- Reamed 9632'-9719'. Drld 9719'- Drld 9819'-9837'. Circ & POH w/ bit #19. bridge @ 4420'. Washed thru bridge OK. Circ out @ 7110'. RIH & reamed 9767'-9837'. Drld 9837'-9869'. Drld & surv 9869'-10,043' w/ wiper trip @ 10,030'. Drld' & surv 10,043'-10,266'. Drld 10,266'-10,288'. Made wiPer trip--hole in good cond. Drld 10,288'-10,306'. Surv. Drld 10,306'- 10,403'. Drld 10,403'-10,460'. Circ, surv, & POH w/ bit #20. Hole in good cond. Tstd BOPE--OK. MU BHA & RIH w/ bit #21. Fin RIH w/ bit #21. Hole in good cond. Drld & surv 10,460'-10,737'. Drld & surv 10,737'-10,839' w/ short trip @ 10,771'. Drld 10,839'-10,492' w/ short trip @ 10,867'. RIH & tagged ECE!VE Alaska Oil & Gas Cons. -/~nchorago We~.l History - Beaver Creek Well No. 6 Page 4 01-12 10,956'TD 01-13 10,956'TD 01-14 10,956'TD 01-15 10,956'TD 01-16 10,956'TD 01-17 10;961'TD 01-18 ll,091'TD 01-19 ll,170'TD 01-20 11,340'TD 01-21 11,388'TD 01-22 11,487'TD 01-23 ll,612'TD 01-24 ll,612'TD 01-25 11,727'TD 01-26 ll,812'TD Drld 10,942'-10,956'. Circ & pumped hi-visc sweep. Sur~on WL. D~__~s~t.u~_w~/~bit @ 10,913'. Circ & ~rTM f~6~'-il.1 to ll~-~p~.~~treated w/ 4.ppb Sol~--~tex. C~rca 1 lona'-~hi-v~"~'~isc sweeps (13.5 ppg & 150+ visc) & rec lots of coal (sharp, splintered pieces). No up jar action, but able to bump dwn. Cont circ & working stuck DP. Circ hi-visc sweep. Rec coal & cly. RU WL to run FPI. Had problems w/ tools & panel--chgd out same. Ran FPI--found free pt in 2nd DC from top. Backed off @ btm of top DC. Prep to POH. Cont fishing operations. TOF: 10,428' POH & rec 15 jts HWDP, XO, jars, t stab, & 1 DC (505.13'). Left 484.72' fish in hole. MU & RIH w/ fishing assy. Screwed into fish @ 10,428'. Jarred on fish w/ I jet plugged. Cleared jet to circ w/ full circ. Jarred on fish 7-1/2 hrs w/ no movement. Circ prior to running FPI. TOF: 10,428' CBU. RU WL & ran FPI. No chg-- still stuck 1 DC below TOF. Mixed 70 bbls Black Magic @ 11.5 ppg & spotted around BHA. Presently soaking BHA in Black Magic. Soaked fish in Black Magic--total 18 hrs soak time. Jarred twice on fish, then came free. Circ & worked pipe. POH & rec entire fish. LD fishing tools. Testing BOPE. Fin tstg BOPE--OK. MU slick BHA & jars. RIH & staged into hole. Hole OK to 10,407'. Washed & reamed 10,407'-10,956'. Drld 10,956'-10,961'. C&C hole & mud. POH w/ bit #22. Hole OK. MU drlg assy. Fin MU BHA. RIH--hole OK. Washed &-reamed 50' to btm. Drld 10,961'-11,091'. Drld 11,091'-11,149'. Circ, dropped surv, & POH w/ bit #22R. Hole OK. RIH & drld 11,149'-11,170'. Drld 11,170'-11,340'. Hole cond good. Drld 11,340'-11,367' w/ short trip @ 11,356'. decr to 2 FPH. Circ, surv, & POH w/ bit #23. OK. RIH & drld 11,367'-11,388'. ROP Hole Drld 11,388'-11,487'. Circ, surv, & POH w/ bit #24. Hole OK. RI H. RIH w/ bit #25 & reamed 35' to btm. Drld 11,487'- 11,612'. Circ prior to trip. CBU, surv, & POH w/ bit #25. Hole OK. Tstd BOPE-- could not retr test plug. Cocked in csg spool. PU BOP & retr plug. Retstd BOPE & flange--OK. RIH w/ bit # 26. Fin RIH w/ bit #26. Hole in good cond. Reamed 45' to btm. Had 5' of fill. Drld 11,612'-11,727'. Drld 11,727'-11,812' w/ short trip @ ll,735'--hole OK. Oil & Gas Cons. .Anchorage WeI~l History - Beaver Cr~ Well No. 6 Page 5 01-27 ll,920'TD 01-28 12,040'TD 01-29 12,080'TD 01-30 12,164'TD 01-31 12,258'TD 02-01 12,274'TD 02-02 12,370'TD 02-03 12,404'TD 02-04 12,410'TD 02-05 12,410'TD 02-06 12,410'TD 02-07 12,410'TD 02-08 12,410'TD 02-09 12,413'TD 02-10 12,443'TD 02-11 12,583'TD 02-12 12,627'TD 02-13 12,687'TD 02-14 12,847'TD Drld 11,812'-11,920' w/ wiper trip @ ll,829'--hole OK. Had 2 hrs dwntime to repair low drum clutch air & to repair waShed out union in mud line. Drld 11,920'-12,040' w/ wiper trip @ ll,985'--hole OK. Drld 12,040'-12,046'. Circ, surv, & POH w/ bit #26-- hole OK. RIH. Reamed 40' to btm. Drld 12,046'- 12,080'. Drld 12,080'-12,164' w/ wiper trip @ 12,135'--hole OK. Drld 12,164'-12,258'. Circ prior to short trip. Made 15-std short trip--hole OK. Drld 12,258'- 12,265'. Circ, surv, & POH w/ bit #27. TstdlBOPE-- OK. RIH & washed &-reamed 30' to btm. Drld 12,-265'- 12,274'. Drld 12,274'-12,370'. Drld 12,370'-12,396'. Circ & POH. Several spots w/ 25-30,000~ drag. RIH. Reamed 36' to btm.. Hole OK on trip in. Drld 12,396'-12,404'. Drld 12,404'-12,410'. circ.& made 17-std wiper trip-- hole OK. Circ & POH. Ran ~Sp/DIL/GR from logger's TD @ 12,405' to 13-3/8" shoe @ 4-022'. Started : running Sonic/GR/Caliper from 12,405'-3800'. Ran OH logs. Run #3 Density/Neutron/Caliper from 12,410'-surf. RD loggers. MU BHA & RIH--hole OK. Circ. POH to run 9-5/8" csg. POH w/ DP & BHA. Chgd out pipe rams to 9-5/8". Started running 9-5/8" csg. Fin running 307 jts 9-5/8" csg. Circ & pumped 1588 sx cmt on 1st stage. Opened stage clr & circ tr cmt to surf. Cmtd 2nd stage w/ 1800 sx cmt. Displ w/ mud. Fin displ 2nd stage & closed s~age tool w/ 3100#. Had clabbered mud returns, no cmt to surf. CIP @ 0740 hrs, 02-07-82. PU BoPE & set 9-5/8" slips. Cut off csg. NU spool, tstd, & tstd BOPE. PU 8-1/2" bit, new BHA, & RIH. RIH w/ bit & drld stag c!r @ 6981'DPM. Tstd csg OK. Drld cmt 11,933' to FC @ 12,334'. Tstd csg OK. Drld FC, cmt, & new fm to 12,413'. Drld 12,413'-12,424'. .. LOT ...... ~ Drld 12-424'-12,443'. C&C hole. POH. MU new BHA & RIH instlg new DP rubbers. Fin reaming 30' to btm. Drld 12,443'-12,583'. Drld 12,583'-12,627'. Circ. shoe. Chgd lnrs in mud pumps. Surv & POH w/ bit. Pulled into 9-5/8" RIH to 12,627'. Fin POH w/ bit ~31. Chgd BHA. RIH & reamed 12,583'- 12,627'. Drld 12,627'-12,687'. Drld 12,687'-12,847' w/ wiper trip @ 12,741' to 9-5/8" csg shoe. SEP 2 0 ..... ,,:, o Q.~o P_nne P. nmrnieei~n WelI History - Beaver Creek Well No. 6 Pa~e 6' 02-15 12,982'TD 02-16 13,1.18'TD 02-17 13,163'TD 02-18 13,374'TD 02-19 13,656'TD 02-20 13,830'TD 02-21 13,861'TD 02-22 13,972'TD 02-23 14,115'TD 02-24 14,243'TD 02-25 14,375'TD 02-26 14,383'TD 02-27 14,591'TD 02-28 14,618'TD 03-01 14,720'TD 03-02 14,808'TD 03-03 14,880'TD 03-04 14,890'TD 03-05 14,893'TD Drld 12,847'-12,982' w/ wiper trip @ 12,900' to csg shoe--hole OK. Drld 12,982'-13,005'. Circ, surv, & POH to 9000' to retr surv. RIH & drld 13,005'-13,118'. Drld 13,118'-13,161'. Made short trip to shoe. Hole OK. Drld 13,161'-13,163'. C&C for trip. Surv & POH. Tstd BOPE--OK. MU BHA & RIH. Fin RIH. Washed & reamed 12,923'-13,163'. Repaired leak in standpipe conn. Drld 13,163'-13'374'. Circ, surv, & pulled into csg. Retr surv w/ WL. RIH @ 0700 hrs. Fin RIH after retr surv. Drld 13,37'4'-13,656'. Circ, surv, & POH to csg shoe. Retr surv tool w/ WL @ 0700 hrs. Retr surv w/ WL. RIH & drld 13,656.'-13,830'. Drld 13,833'-13,835'. Made short trip. Lost pump press when back on btm. POH. Had lost 1 jet nozzle. RIH w/ mill tooth bit & 2 JB's. Washed & reamed to btm to clean hole. Drld 13,830'-13,861'. Drld 13,861'-13,869'. Circ, surv, & POH--hole OK. Rec pieces of bit %33 & junk in basket. MU bit & RIH. Drld 13,869'-13,972'. Drld 13,972'-14,115' w/ wiper trip @ 14,039'. Drld 14,115'-14,163'. Circ, surv, & pulled to csg shoe. Retr surv & RIH. Drld 14,163'-14,243'. Drld 14,243'-14,258'. Circ & made 20-std wiper trip--hole OK. Drld 14,258'-14,375'. Drld 14,375'-14,383'. Circ & dropped surv. POH to csg shoe & retr surv. RIH. Had 2 hrs rig repair. CBU & POH. Tstd BOPE & RIH. Hole OK. Reamed new bit to btm. Fin reaming to btm. Drld 14,383'-14,591'. Drld 14,591'-14,615' w/ short trip @ 14,599'. Circ, surv, & POH. RIH w/ JB--washed & reamed 30' to btTM. Drld 14,615'-14,618'. Drld 14,618'-14,720'. Drld 14,720'-14,808' w/ wiper trip @ 14,732'. Drld 14,808'-14,880' w/ wiper trip @ 14,821'. Hole OK. Drld 14,~8~'-14,890'. Tripped to 9-5/8" shoe--hole ~&/CBU gas cut mud w/ 200 units. ~ ~.0~~3~ Made 15-std wiper trip--CBU 18 u~nits g~. ~ RU loggers & ran DIL/SP/GR from 14,876' WLM~ csg shoe (12,410'). Made OH log run %2 for BHC Sonic/GR from 14,876'WLM to shoe. Made OH log run.#3 FDC/CNL/Caliper from 14,876'WLM to 3810'. Log correlation w/ Wells 4 & 5RD show expected top of productive G Zone @ 14,998' DPM. RIH w/ bit %38, washed & reamed 14,830'-14,890' w/ 10' of fill on btm. Plan to drill to approx 14,980' before running 7" lnr. Oil & Gas Cons. Commissior~ ¢~nchorage well History - Beaver Creek Well No. 6 Page 7 03-06 14,980'TD 03-07 14,980'TD 03-08 14,980'TD 03-09 14,980'TD 03-10 14,980'TD 03-11 14,980'TD 03-12 14,980'TD 03-13 14,980'TD 03-14 14,980'TD 03-15 14,980'TD 03-16 14,980 'TD .~ ~_,,~ q~ .% GaS COILS. &~,.,......'i.,. Drld 14,893'-14,980'. Circ. Made wiper trip to shoe. RIH & circ to run-7" lnr. Fin cond hole, surv, & POH. RU & ran 73 jts 7", 32# lnr. Running lnr @ 0700 hrs. Fin running 7" lnr onDP to 14,980'--no fill on btm. Circ. Pumped 35 bbls mud flush ahead of 650 sx Cl G cmt + additives. CIP @ 2030 hrs,.03-07-82. Released lnr hgr tool, pulled 5 stds, & rev out cmt contam mud. Lnr landed @ 14,980' W/ top @ 12,024'. POH. Testing BOP @'0700 hrs. . Fin testing BOP. RIH. Cut drlg line. WOC. RIH & tagged soft cmt @ 11,940'. Washed green, contam . cmt to 11,966'. WOC. Washed contam cmt to 11,980'. Cleaned from 11,980' to TOL @ 12,024'. CBU & POH. . . POH w/ 8-1/2" bit. Tripped 9-5/8" csg scrpr to lnr top @ 12,024'. MU DST assy & RIH w/'3716' wtr cushion. Set RTTS @ 11,970'. Ran dry test on lap. Had light blow during final flow period. Died off. Could not open circ vlv. to rev cushion after dry test. Prep to POH. Began POH W/ test tools--rev sub opened. Rev'd out wtr cushion. POH' & LD tools.. Charts indicated' lnr lap leaking. RIH w/ bit to TOL @ 12,024'. Circ & rec gas, trace oil. & cut mud to 7.2 ppg. Circ to work gas out of mud. Checked--no flow. Made 5-etd short trip. CBU w/ mud cut to 10.4 ppg. Circ, incr MW & working gas out of ~u~ ' Cont circ & incr~12'~7#, _ to 13.~.-"~Made 10-etd short trip. MW ~ut to 11.9~ w_/.----1400 units gas. Circ & broke gas' out o~mud~ ....... Main'~'ained MW @ 13.1 ppg. Made 20-etd short-trip. MW cut to 10..8% w/ 3000+ units gas for 15 min. Circ & broke 'gas out of mud. POH. MU & RIH w/ 9-5'/8" cmt rtnr to sqz lnr' lap. Fin RIH & set cmt rtnr @ 11,977'. C&C gas cut mud. Attempted to break dwn lnr lap w/ 7000% w/o succ w/ wtr. Surged & repress several times-& lap began to take 1/4 to 1/2 BPM @ 6350 to 7100%. Press finally locked up @ 7500%--unable to PI or clear lap by back surging. Press began leaking thru tool .jts to annls. PU out of rtnr & circ to cond mud prior to POH. Circ spotted wtr out of hole. POH. Found 2 tool jts in 5" DP washed out slightly. MU test-tools. RIH w/ 3600' fresh wtr cushion. Stabbed into rtnr @ 11,977' & opened tool. Surged. & backflowed thru lnr lap to clean lap of trash. . Cont backflowing to CU lnr lap--died @. surf @ 0830 hrs, 03-14-82. POH. _Filled DP w/ wtr. Press & sheared out rev sub. Rev out mud,. sd, cmt, &,coal. Fin POH. Test tools possibly plugged. Dressed test tools & RIH w/'3600' cushion to surge &.backflow lnr lap 2nd time. At 11,640', test string began filling from annls. POH to ck tools. Fin POH w/ test string--found let jt of 5" DP.collapsed 589' above test tools. Redressed tools. RIH w/ test tools w/ 3600' of fresh wtr cushion. Stung into cmt rtnr @ 11,977'. Opened tool & backflowed thru lnr lap attempting to clean lap. Had medium blow initially & died after 2 hrs. PU out of rtnr-& rev out. Rec cushion + thick contam mud. POH. RIH w/ stinger for cmt rtnr to attempt to PI lnr lap. Well History - Beaver Creek Well No. 6 Page 8 03-17 14,980'TD 03-18 14,980'TD 03-19 14,980'TD 03-20 14,980'TD° 03-21 14,980'TD 03-22 14,980'TD 03-23 14,980'TD 03-24 14,980'TD 03-25 14,980'TD 03-26 14,985'TD 03-27 14,985'TD Stabbed into rtnr @ 11,977' &'attempted to break dwn lnr lap .W/ wtr @ 7500#. Could not break. Pulled out of rtnr. & rev wtr. POH. RIH w/ drlg assy to rtnr. ~~---"~~.9~-~g~ Drld on rtnr & raised MW to 1311 p~; . " Fin drlg cmt rtnr @ 11,9-7-'. POH. Tstd BOP--OK. RIH w/ 6" bit on 4-3/4" DC's. Drld pieces of rtnr & 6' hard cmt inside 7" lnr. Circ & clean hole. POH w/ 6" bit. Fin POH w/ 6" bit. RIH w/ mill & polished inside tie-back-'sly 12,024'-12,030'. Circ & POH. Ran 15 jts 7", 32#, tie-back lnr W/ tie-back'stem,-clr, & lnr-hgr. Presently.circ prior to cmtg. After circ, stung tie-back..stem into 7" tie-back sl%. Seals would not test in slv. POH. w/'7" tie-back lnr. WO new tie-back stem from North Slope. 'MU new stem, shoe jts, landing clr, 15 jts 7",'32# csg (total) & lnr hgr. Presently RIH w/ 7" tie-back lnr. Fin RIH w/ 7" tie-back lnr. Circ. Tstd tie-back stem in tie-back sly @ 12,024'--seals held OK. Cmtd tie-back lnr W/ 170 sx. Stabbed stem into slv@ 12,024'. Set lnr hgr @ 11,446'. Pulled 5 .stds & rev circ--rec no cmt. Pulled.10 stds, closed BOP's & held press 6 hrs. POH. MU BHA. RIH W/ 8-1/2" bit & tagged cmt @ 11,078'. CO to ll,103'--cmt not firm. Circ while WOC. WOC. Drld cmt ll,103'-ll,446'TOL. Circ. & POH. Tripped 9-5/8" csg scrpr to TOL. RIH w/- 6" bit. Unseated pkr' & POH w/ test tools. Fin RIH w/ 6" bit. Drld 2' of cmt in top of 7" lnr. RIH & tagged hard cmt.@ 11,864" (41' above landing clr). Circ'& POH. MU & RIH w/ test tools W/'3800' fresh wtr cushion. Dry tstd 7" x 9-5/8" lnr lap. Appears dry at surf. Fin POH w/ test string. Charts confirmed-dry test of lnr lap @ ~1,446'. LD 8-1/2" tools. Tstd BOPE-- OK. RIH w/ 6 bit-& encountered firm cmt @ 11,864'.. Drld cmt & landing clr @ 11,905'. ·Ran out of hard cmt @ 12,039''(btm of tie-back sly @ 12,030'). CBU. POH w/ 6" bit. Fin POH w/ 6" bit. RIH w/. 6" bit-& 7" csg scrpr to 12,008'. CBU. POH. RIH W/ test string W/ 41. stds-.-' (3800') fresh wtr cushion & set pkr @ 11,900,~., Ran - : dry test on 7" tie-back sly/stem @ 12,024'--surf indications-show no flow,(dry test). Releasing. pkr. _ & prep to POH w/ test string. .. Released pkr & POH 'w/ test string. LD tools. RIH w/ 6" bit & drld cmt 14.,763' thru landing clr@ 14,851', FC @ 14,935',. & shoe @ 14,978'. Drld 5' fm & ran shoe test.to.14.1 ppg. Circ & prep to POH. Circ. POH w/ 6" bit. RIH w/ csg scrpr & scrpd- 7" lnr to 14,950'. Circ hole clean. POH. MU & RIH w/ test string. -_ · Well History - Beaver Cre~ Well No. 6 Page 9 03-28 14,985'TD 03-29 14',985'TD 03-30 14,985'TD 03-31 15,069'TD 04-01 15,096'TD 04-02 15,240'TD 04-03 15,256'TD 04-04 15,366'TD 04-05 15,441'TD 04-06 15,536'TD 04-07 15,570'TD 04-08 15,570'TD Fin RIH W/ test string. Displ mud from string W/ fresh wtr W/ pkr @ 14,930'. Ran test on shoe of 7" lnr to assure high press oil sd @ 14,635' was isolated. Rev out wtr. POH W/ test string. MU 6" drlg assy & RIH. Fin RIH W/ '6" bit-& drlg assy. CBU. 'Dumped surf mud pits. Cleaned mud pits & lines. Began mixing potassium chloride mud system. Mixed KC1 mud system during past 24 hrs. Have 1075 bbls mixed--need 1200 to 1250 bbls before displ ligno mud from well W/ KCl. Fin mixing KCl mud.& displ ligno w/ KCl. 14,985'-15,069'. Drld 15,069'-15,078'. POH w/ bit %44. Chgd BHA. RIH & drld'15,078'-15,096'. Drld Tstd BOPE. Drld 15,096'-15,240'. Drld 15,240'-15,256.'. CBU. POH w/ bit %45. RIH to 6000' &'cut drlg line--attempted to fill DP, but jets plugged. POH & unplugged bit. RIH- & tagged fill @ 15,156'. Washed & reamed to btm. Drld 15,256'-15,366'. Pulled into csg shoe--lst, std off btm very tight. Circ system clean while inside csg shoe. POH. MU bit %47 & RIH. Fin RIH to csg shoe. Repaired mud tank line. C&C mud. RIH. & tagged fill @ 15,217'. Washed-& reamed to 15,262' but hole sloughing in. Pumped hi-visc sweep & pulled to csg shoe to circ out sweep. Rec coal & sd. RIH. Washed & reamed to 15,366'. Drld 15,366'-15,441' while incr visc. Drld 15,441'-15,454'. POH to 7" shoe, 30,000% overpull. Circ. RIH & tagged fill @ 1'5,261'. Washed-& reamed to 15,454-(bridge 15,261'-271' remainder soft fill) , Drld'15,454'-487' & treated mud'system w/ Soltex. Spotted hi-visc pill across OH & pulled to csg shoe. RIH' (2' bridge @ 15,287'). Drld 15,487'-15,536' w/ ROP @ 13-21 FPH. Drld 15,536'-570'. POH to csg. shoe & circ. Began to POH for bit, but orders chgd. RIH to cond hole to log. Tagged fill @ 15,250'. Washed to 15,570'. Circ & PU to csg shoe. Circ, ran back & tagged tight spot @ 15,436'. Washed to 15,570'. Circ & sptd hi-visc pill across OH. POH to shoe' Circ & ran back & tagged tight spot @ 15,494'. Washed to 15,570', Circ & spotted hi-visc pill. POH to shoe & circ. Circ. RIH & tagged fill @ 15,522' (ledge?). Washed to 15,570'. Swept hole w/ 30'0+ visc pill. Pulled to shoe. RIH & tagged fill @ 15,436'. Washed thru 2' bridge & washed to 15,570'. Swept hole. w/ 300+ visc pill. Rec chunks of coal & sltst as large as.a fist. Pulled to shoe & ran back & tagged ledge @ 15,486'. Rotated thru. RIH & tagged fill @ 15,564'. Circ hi-visc sweep. POH. Circ & cond to clean hole of fill. . . . Anchorago Well History - Beaver Creek Well No. 6 Page 10 04-09 15,570'TD 04-10 15,570'TD 04-11 15,680'TD 04-12 15,776'TD 04-13 15,780'TD 04-14 '15,852'TD 04-15 15,928'TD 04-16 15,928'TD 04-17 15,928'TD 04-18 15,928'TD 04-19 15,928'TD 04-20 15,928'TD Circ w/ bit inside csg shoe--rec sml pieces coal, alt, & sd. RIH & set dwn @ 15,490'. Reamed thru several times. Washed to 15,570' Circ &-pulled to shoe. Hole OK. RIH & tagged 15,510'. Washed to 15,570'. Washed to 1.5,570' w/o reaming. Circ OH clean. Pulled to shoe. ~Circ & rec sml pieces coal, alt, & sd. POH. RU & ran Dual Laterolog/ SP/GR--could not work below 15,360'. Ran log across G-Zn (top @ 15,002'WLM). Fin running DLL/SP/GR. Run 92: BHC Sonic/GR/Caliper from 15,327'WLM. Run 93: FDC/CNL from 15,285'WLM. RD loggers. Tstd BOPE. MU drlg. assy & RIH W/ bit 948. Tagged @ 15,515'. Washed to 15.,570' w/ .no problem. Drld 15,570'-15,680' W/ 1-1/2 hrs dwntime due to rig repair. Drld 15,680'-15,776'. Circ POH w/ bit 948. Role OK. MU BHA & RIH W/ bit 94~. Fin RIH to 15,245'--hit bridge. Washed-& reamed thru bridge, but hole would slough in each t_i_ime~ _r~e_am%ng. Pulled to-csg shoe. Circ& incr~ C10."l-"~pg using-salt. RIH-& reamed bridge 15,245'- 3~]"~& cleaned hole W/ hi-visc sweep. Fin washing .- & reaming to 15,776'. Drld 15~776'-15,780'; cleaning hole w/ hi-visc sweeps. Drld 15,780'-15,852' w/ no problems. Drld 15,852'-15.,928'. Circ & spotted hi-visc pill across OR. Pulled to csg shoe--hole OK. RIH w/ no problems. Circ & prep to spot hi-visc pill prior to POH to log. Circ'& spotted hi-visc pill in OH. POH. Hole OK, except @ 15,'650'--worked thru w/ little trouble. RU loggers. RIH w/ DLL/SP/GR--could not work below 15,235' (1 attempt w/ hole finder & 1 attempt w/o hole finder). RD WL. MU BHA'& RIH to cond hole for lnr. Fin RIH & tagged ledge. @ 15,232'. Washed & reamed to 15,440' then RIH to 15,928' w/ little washing , · .Circ hi-visc sweep & rec coal & sd. Spotted hi-visc pill across OR. Made wiper trip to shoe & to TD w/ tight spots (ledges?) @ 15,232' & 15,650'. Had 5' fill. Spotted hi-visc pill--POH. Ran 2'7 jts . ... 5" csg & hgr eqpmt. 'RIH on DP @ 0700 hrs. - --' '-'-~'".. . Fin RIH w/ 5" lnr on DP. Could not work lnr deeper_ " than 15,889'. Cmtd w/ 450 ex. CIP @ 0100 hrs, 04-18-82. Pulled 10 stds & rev out tr cmt. .POH w/. setting tool. Fin POH w/ lnr setting tool. Tstd BOPE. RIH w/ 6" bit--bit dropped tong.die in hole. POH w/ bit. RIH w/ 5-1/2" magnet. Circ @ 13,718' & 14,376'-- no cmt. RIH to top of 5" lnr @ 14,681'--no cmt on top of lnr. POH w/ magnet. Fin POH w/ 5-1/2"0D magnet--no rec. PU 2-7/8" DC's & 2-7/8" DP. RIH w/ 4" magnet. Tagged firm cmt inside 5" lnr @ 15,300'--would not wasy away. POH--rec 1 piece of tong die (a-prox 1/3 of die), 1/2 o~ ~taining bolt for tong die, and 1/2 of DP rubber pin.~~~g 4" magnet. Well History - Beaver Creek Well No. Page 11 04-21 15,928'TD 04-22 15,928'TD 04-23 15,928'TD 04-24 15,928'TD 15,842'PBTD 04-25 15,928'TD 15,842'PBTD 04-26 15,928'TD 15,842'PBTD 04-27 15,928'TD 15,842'PBTD 04-28 15,928'TD 15,842'PBTD 04-29 15,928'TD 15,842'PBTD 04-30 15,928'TD 15,842'PBTD 05-01 15,928'TD 15,842'PBTD 05-02 15,928'TD 15,842'PBTD 05-03 15,928'TD 15,842'PBTD RIH w/ 4" magnet, run #3. Washed & rotated 15,300'- 15,362'. POH & rec 1 piece of tong die, 1 piece of 1/4" bOlt, & 1 compl 3/8" bolt. MU 4" bladed mill & JB & RIH. Milled on cmt' & junk from 15,362'- 15,438'. Milled on junk & cmt 15,438'-15,492'.. Circ & POH. Rec remainder of tong die & DP rubber pin. RIH w/ bit #51-(4-1/8"). Drld cmt 15,492'-15,587'. Drld hard cmt 15,587'-15,638'. Circ. POH w/ 4-1/8" bit. RIH W/ bit #52. Drld- cmt 15,638'-15,784'. Fin drlg cmt to 15,842'. 'CBU. POH w/ bit. Ran FDC/CNL log across 5" lnr. POH. Presently running CBL. Fin running CBL--log indicated top of cmt '6 15,t32~ w/ no cmt thru lnr lap area. Ran gyro to 15,800'. MU & RIH w/ retr pkr on DP & set above 5" lnr lap @ 14,649'. Broke dwn & estab PI rate @ 2-1/2 BPM @ 4000#. POH w/ pkr. Fin POH w/ pkr. Ran gauge ring & JB. Ran & set cmt rtnr on WL @ 14,616'WLM (14,622'DPM). RIH w/ rtnr stinger. Mixed & sqzd 5" lnr lap w/ 200 sx cmt to final press of 4900#. CIP @ 0030 hrs, 04-26-82. Got 155 sx below rtnr. Rev out 45 sx cmt. Circ. POH w/ rtnr stinger. Fin POH w/ rtnr stinger. Tstd BOPE--OK. MU 6" bit & BHA. RIH--had 2' cmt on top of rtnr. Drld rtnr @ 14,622'. Drld cmt to top of 5" lnr @ 14,681'. Circ & POH w/ bit #53. Fin POH. MU 4" junk mill & 5" scrpr. RIH & CO 5" lnr to 14,760'. Tstd csg strings to 3000#--0K. POH. MU DST tools & RIH filling w/ WC. Fin RIH w/ test tools w/ 4000' WC. -Ran dry test on 5" lap. POH. Dumped cushion. Chart recorders had not recorded BHP. MU & reran test tools w/ 4000' of cushion. Set pkr @ 14,545'. _Opened tool @ 0450 hrs, 04-29-82, to repeat test. Compl 5" lnr lap test. Released pkr & POH w/ test string. RIH w/ 4-1/8" bit & 2 JB's.. Reamed thru 5" lnr to CO remainder of cmt. Circ to clean hole. POH w/ bit. POH w/ 4-1/8" bit. Rec sml pieces of 7" cmt rtnr in junk subs. RIH W/ dressed tie-back slv on top of 5" lnr w/ polishing mill. POH w/ mill. RIH & dressed 5" lnr PBR w/ polishing mill. POH. RIH w/ 6" bit & 7" csg scrpr. Fin RIH w/ bit & 7" csg scrpr to top of 5" lnr @ 14,681'. POH. RIH w/ bit & 5" csg scrpr to btm of 5" lnr @ 15,842'. Circ to clean lnr. Displ mud from well w/ fresh wtr (rev circ). Mixed & spotted 60 bbls, 6% KC1 across 5" lnr back into 7". POH w/ bit & 5" scrpr. POH w/ 5" csg scrpr. LD 2-7/8" DP & 3-1/8" DC's. Ran GR & JB to top of 5" lnr. MU PBR seal assy & Dkr & RIH on DP. Stabbed PBR into receptacle in -- 5" lnr & set pkr @ 14,668' to isolate 5" lnr lap. S EP 2 o i j82 A!~ska Oil & G~, Cons. Commission Anchorag~ Well History - Beaver Creek Well No. 6 Page 12 05-04 15,928'TD 15,842'PBTD 05-05 15,928'TD 15,842'PBTD 05-06 15,928'TD 15,842'PBTD 05-07 15,928'TD 15,842'PBTD 05-08 15,928'TD 15,842'PBTD 05-09 15,928'TD 15,842'PBTD 05-10 15,928'TD 15,842'PBTD 05-11 15,928'TD 15,842'PBTD 05-12 15,928'TD 15,842'PBTD 05-13 15,928'TD 15,842'PBTD 05-14 15,928'TD 15,842'PBTD Fin POH & LD remainder of DP & DC's. RU & ran 2-7/8" prod tbg & GL eqpmt. Had 243 jts run @ 0700 hrs. Fin running prod tbg & GL eqpmt. Spaced out to land tbg. Lost 8 hrs due to defective tbg hgr~ replacement hgr not available--made repairs @ machine shop. Landed tbg & tstd seals in pkr to 3000#--OK. ND BOPE & presently NU Xmas tree. Fin NU & test prod tree. Connected flowline & control & GL line--tstd lines. Began unloading well @ 4:00 PM, 05-05-82. Fin unloading well dwn to 1st orifice vlv @ 12,135'. Loaded tbg w/ 40 bbls to provide 1500# drawdwn. RU WL & tstd lub. RIH & perfd Hemlock .w/ 4 HPF from 15,520 '-546 'FDC/CNL meas. Presently .POH w/ perf gun. POH w/ expended perf gun (run #1). Gun stuck in BV nipple @ 289'. Worked stuck gun & inj oil dwn tbg string holding tension on WL--press incr on tbg above gun--packing off. Worked gun up hole to 100'WLM. Could not work up or dwn. Inj oil-- bled press off tbg & annls. Attempted to pull out of rope socket w/ 2900# (should pull out @ 2000#) but unable to pull out. At 0700 hrs, able to pump by stuck gun without packing off. Worked stuck gun--RU & pumped 10 bbls diesel into tbg past WL fish. No movement. Pulled WL & parted-- rec approx 100'. RIH w/ IB & tagged @ 48' below RT. POH. Blk showed wire. RIH w/ 2" blind box & jarring dwn on fish. RU & pumped 8 bbls diesel dwn tbg. No movement in fish. Jarred dwn on WL fish @ 48' below RT--no movement. RU lines & filled tbg & annls w/ wtr to kill well. Set BPV & ND Xmas tree. NU & tstd BOPE. MU landing jt & pulled tbg & hgr. Found WL fish 10' below hgr--stuck w/ WL wrapped around tool. Rec 22' expended gun & CCL & decentralizing magnet. Lost 4' of gun & 4' of wt bar in hole. RIH w/ 2-1/4" gauge ring on WL & stoDped @ 4179' GLM #2 POH & RD WL. POH w/ 2-7/8" prod tbg & found 2 pieces (17") of expendted gun in GLM #2. POH w/ tbg looking for remainder of fish. Fin POH w/ prod tbg--did not find other pieces of .WL fish. RU WL & RIH w/ 2-3/4" gauge ring (broach) to assure prod pkr clear. Ran 2-3/4" WL GR/broach--could not get into PBR seal assy @ 14,662'WLM. RIH w/ magnet on WL & rec sml piece gun & 4 sml pieces wire. Reran 2-3/4" GR--unable to get thru PBR. Ran 2" dummy perf gun w/ 2-1/8" bullnose & got thru PBR seals OK. RIH to 15,635' OK. POH & RD WL. MU new pkr seal assy '& RIH on 2-7/8" prod tbg. Cont running 2-7/8" prod tbg & GL equipmt. Insp each tbg connection as RIH & LD jts w/ questionable thrds. Running 2-1/4" broach thru tbg. Have a total of 197 its & 12 GLM's run @ 0700 hrs. SEP 2 0 '.'-" A!~sk~ Oil & Gas Cons. Commission f~,r~chorage we'll History - Beaver Creek Well No. 6 Page 13 05-15 15,928'TD 15,842'PBTD 05-16 15,928'TD 15,842'PBTD 05-17 15,928'TD 15,842'PBTD 05-18 15,928'TD 15,842'PBTD 05-19 15,928'TD 15,842'PBTD 05-20 15,928'TD 15,842'PBTD 05-21 15,928'TD 15,842'PBTD 05-22 15,928'TD 15,842'PBTD 05-23 15,928'TD 15,842'PBTD 05-24 15,928'TD 15,842'PBTD Fin RIH w/ 2-7/8" prod tbg & GLM's. Tagged pkr @ 14,668', spaced out tbg, landed tbg & tstd seals--OK. NU BOPE & NU Xmas tree. Fin NU Xmas tree. Hooked up & tstd lines to prod test eqpmt. Began unloading well. Had 450 bbls unloaded @ report time. Fin unloading well to 1st orifice vlv @ 12,135'. Circ lift gas w/ no indication of fm fluids from perfs 15,520'-546'. Loaded tbg to allow 500# drawdwn to wellbore. RU & tstd lub. RIH & perfd Hemlock 15,476'-15,506' w/ 4 HPF. POH w/ gun w/ no problem. Unloading tbg to test Hemlock. Tstd Hemlock perfs 15,520'-546' & 15,476'-506!. No fluid entry from fm. Blew dry lift gas around._. Loaded tbg to provide 500# diff to wellbore. Perfd additional Hemlock 15,414',466' w/ 4 HPF & TP incr 0 to 680# after perfg this zn. Unloaded tbg to test perfs until tbg blown dry & circ lift gas around. Reloaded tbg to provide 500# diff to wellbore & RIH to perf additional Hemlock. Perfd Hemlock 15,387'-407'-, 15,345'-370'-, & 15,306'-326'FDC/CNL. SOS pulled out of rope socket in lub after last run. RIH w/ sinker bars to 15,650'--no obstructions. POH & prep to prod test Hemlock. Fin POH w/ WL & RD lub. RU to prod test Hemlock. GL well to test eqpmt & rec 50 bbls fluid (load wtr--no oil) which is volume in tbg dwn to 1st orifice vlv @ 12,135'. Blew dry gas around. SI well 8% hrs. .Resumed GL @ 0500 hrs, 05-20-82. No fluid recovery @ 0700 hrs. Blowing dry gas around. Contacted USGS & state DOGC requesting permission to abandon Hemlock zn. While awaiting approval, cont GL Hemlock to prod test eqpmt. Prod from well incr. Cont testing. Prod test @ 0700 hrs, 05-21-82: 38 BFPD @ 90% WC. Plans are to attempt to obtain USGS & state approval to abandon Hemlock w/ thru-tbg plug. Cont to test Hemlock. SI @ 1140 hrs, 05-21-82. Final rate 40 BFPD @ 80% WC. Rec approval from MMS (formerly USGS) & state DOGC to abandon Hemlock perfs w/ thru-tbg plug. RU line to WH. PI 52 bbls wtr. Bled off trapped gas. PI. additional 36 bbls--bleeding off trapped gas. Fin bleeding off trapped gas & filled tbg. RU & RIH w/ thru-tbg BP on WL. Attempted to set @ 15,280' above Hemlock perfs. POH. BP still on setting tool. RIH w/ BP on WL & set @ 15,280'. POH. RIH w/ WL bailer, but unable to get below 3730'. POH & repaired tool. RIH w/ bailer--unable to get below 13,830'. POH w/ bailer. Fin POH w/ WL bailer (40' x 2"). RIH w/ sinker bars on WL & worked thru spot @ 13,830' w/ no problems. POH. RIH W/ bailer (40'- x 2") & stopped @ 14,235'. Made 3 additional runs w/ various lengths & OD bailers, but never got below 14,235'. Presently RU to run bailer w/ plans to pull tbg to abandon Hemlock if WL procedure is not successful. Alaska Oil & Gas Cons. Commission imchorago Weli H~story - Beaver C~'~k Well No. 6 Page 14 05-25 05-26 05-27 05-28 05-29 05-30 05-31 06-01 06-02 06-03 06-04 06-05 15,928'TD Fin RIH w/ 2"OD bailer (21'OA)--could not get below 15,272'PBTD 14,268'. POH. RIH w/ 10' of 1-5/8" bailer (17'OA) & successfully got thru tbg. Dumped sd from bailer on top of thru tbg BP & POH OK. Made 4 additional bailer runs dumping sd & then set dwn & tagged plug @ 15,274'WLM. Made 1 run w/ bailer dumping cmt on top of sd--presently making 2nd bailer run w/ cmt. 15,928'TD Fin cmt bailer run 92 & made 8 additional cmt bailer 15,272'PBTD runs to compl a 5' sd & 10' cmt plug as required by MMS. WOC before checking top of cmt plug. CIP @ 0600 hrs. 15,928'TD WOC 6 hrs. Tagged top of cmt plug @ 15,260' (BP @ 15,260'PBTD 15,280', 5' sd plug & 15' cmt plug). POH w/ empty bailer & RD WL. WOC 9 hrs to allow .cmt to set. Bled off static TP @ surf from 7509 to 09. SI to observe press. TP built to 2259 in 2-1/2 hrs. Presently unloading dwn to 1st GLM to get oil out of tbg string & test plug for abandonment as per MMS stipulation. 15,928'TD Unloaded oil entrained w/ gas from tbg (rec 11.4 15,260'PBTD bbls oil). Filled tbg w/ wtr & bled off gas to allow well to go static for plug test. RU & RIH w/ sinker bar on WL & tagged cmt plug @ 15,260'--cont to bleed off gas & fill tbg w/ wtr. POH & RD WL. Will observe well as static to satisfy abandonment stipu- lation & then unload tbg to perf G Zn. 15,928'TD Tstd Hemlock abandonment plug (15,260'-280') according 15,260'PBTD to MMS stipulations--OK. Unloaded tbg for drawdwn. Perfd G Zn 15,003'-050' & 15,170'200'FDC/CNL meas w/ 4 HPF under drawdwn conditions RU & began testing G Zn rec load wtr @ 0700 hrs. Rec @ rate of 369 BPD. 15,928'TD Unloaded well & testing G Zn @ rate of 25 BFPD, 7 BOPD, 15,260'PBTD & 18 BWPD (70% WC) @ 0600 hrs. 15,928'TD Cont testing G Zn. Rate @ 0700 hrs: 34 BFPD, 14 15,260'PBTD BOPD, 20 BWPD (60%WC). 15,928'TD 15,260'PBTD Cont testing G Zn. Rate prior to SI: 16 BPD, 6 BOPD, 10,BWPD (62% WC). SI well @ 1000 hrs, 05-31-82. Loaded tbg w/-30 bbls KC1. RU WL & tstd lub. RIH & reperfd G Zn @ 15,200'-170' & 15,050'-020'FDC/CNL. Started RIH w/ gun 93 to shoot 15,020'-003' (final perf run). 15,928'TD Fin reperfg G Zn 15,020'-003'FDC/CNL. RD WL & RU 15,260'PBTD to test we-1. Began unloading @ 1400 hrs, 06-01-82. Had unloaded'30 bbls KC1 load wtr & 1 hr test @ 0700 hrs: 22 BFPD, 9 BOPD, 13 BWPD-(60% WC). 15,928'TD 15,260'PBTD Cont tstg G Zn on GL. Rate @ 0700 hrs, 06-03-82: 24 BFPD, 7 BOPD, 17 BWPD (70% WC). Cum prod test past 24 hrs: 25.5 BWPD, 10.1BOPD, 15.4 BWPD (60% WC). 15,928'TD Cont tstg G Zn on GL til 11'00 hrs, 06-03-82. Final 15,260'PBTD rate: 26 BFPD, 13 BOPD, 13 BWPD (50% WC). SI well @ 1100 hrs. Loaded tbg & annls w/ 3% KCl wtr & bled off lift & prod gas. RU pump unit. Tstd lines & started PI to G Zn perfs to estab rate. Currently PI @ 1/4 BPM @ 4150 psi--will verify rate. 15,928'TD Cont G Zn PI test. Pumped 5 bbls w/ surf press incr 15,260'PBTD to 5000#. Press bled to 42509 in 12 min. Bled off press. Set BPV, ND tree, NU & tstd BOPE. PU tbg & C&C KC1 wtr. POH LD tbg. Gas_~._.~. ~C°ns' Commission Well History - Beaver Creek Well No. 6 Page 15 06-06 06-07 06-08 06-09 06-10 06-11 06-12 06-13 06-14 06-15 06-16 15,928'TD Fin LD 2-7/8" compl equip. Chgd pipe rams & tstd 15,260'PBTD blind & pipe rams to 5000#. MU pkr retr tools & RIH PU 3-1/2" & 5" DP to retr 5" lnr lap isolation pkr. 15,928'TD Fin RIH. Retr 5" lnr lap isolatiOn pkr & POH. 15,260'PBTD RIH w/ 4-1/8" bit & 2 boot baskets to 15,270'DPM, 15,253'WLM. C&C WO fluid & POH. 15,928'TD Fin POH after CO run. Made 2 runs w/ gauge ring & 15,260'PBTD JB. Rec half of a pkr rubber. MU Vann gun assy & HOWCO test tools. RIH & filled 55-1/3 stds w/ WC. 15,928'TD RU HOWCO tst tree & lub. RIH w/ GR/CCL & located 15,260'PBTD RA marker. Adjusted pkr depth to 14.,558'DPM to place Vann guns on depth. Opened APR vlv, rechecked_ depth correlation, made drift run thru all tst tools. POH w/ WL. Dropped Vann firing bar. Guns did not fire. Tagged bar 16' above firing pin w/ GR/CCL. POH. RD SOS & RU Otis braided line unit. RIH w/ pulling tool to dislodge Vann firing bar. Otis stranded line @ 1683'. 15,928'TD Rec stranded Otis WL & tool string. RIH w/ 1-1/4" 15,260'PBTD OS on SOS. Tagged Vann firing bar as before--btm of bar 16' above firing pin. POH--no rec. Made 2nd run w/ no rec. Chgd to 1-3/4" OS & RIH. Attempted to latch fish @ same location. POH--no rec. RIH w/ 1-3/4" IB--tagged fish & POH. No impression. WO WL bailer. 15,928'TD MU Otis hydrostatic bailer & RIH. Sat dwn @ same 15,260'PBTD depth as before. Spudded to shear disk & POH. Disk did not shear. Chg to a lighter shear disk & RIH. Spudded @ same depth & POH. Rec 1/4 cup of tbg scale, remainder oily wtr (possible hard fill). RIH w/ Otis chisel-pt bailer. Spudded 4 times & stuck. Jarred for 9 hrs & pulled out of rope socket. Rec WL. WOO. 15,928'TD WOO. RIH w/ jet cutter & cut 2-3/8" tbg @ 14,900' 15,260'PBTD WLM. POH & RD WL. Rev WC, RD tst tree & POH. LD DST tools. Left Vann gun fish in hole. 15,928'TD LD DST tools & 2-3/8" tbg. WO fishing tools. MU 15,260'PBTD 2-3/8" OS, RIH & engaged Vann gun fish @ 14,959'. Opened circ sub & POH. Rec Vann gun assy, firing bar, & WL tool string, Had 30' of scale on top of Vann firing head. LD 3-1/8" DC's. 15,928'TD LD DP & hydrowashed. Tstd BOPE. MU & RIH w/ Vann 15,260'PBTD gune & tst string. 15,928'TD RIH w/ Vann guns & tst string on DP. Filled 67-1/3 15,260'PBTD stds w/ WC. Fin RIH, RU tst tree & lub. Set pkr. Annls fluid level dropped, had blow on DP. Filled annls w/ 59 bbls. Released pkr, prep to POH checking for leak. 15,928'TD POH looking for hole in tst string. Found seal out 15,260'PBTD of expansion (slip) jt. Ck Vann guns, redressed tst tools, RIH & filled w/ 67 stds of fresh wtr. Press tstd string to 1000#--0K. Fin RIH. RU tst head & lub. Ran & located w/ GR correlation. Set pkr @ 14,547'DLL. Press annls to 2000# & opened APR vlv. Ran thru w/ WL tools OK. POH w/ WL tools. _. We!i History - Beaver cre~k Well No. 6 Page 16 06-17 06-18 06-19 06-20 06-21 06-22 06-23 08-30 08-31 09-01 09-02 09-03 09-04 09-05 15,928'TD Fin POH after checking that APR vlv was open. 15,260'PBTD Dropped Geo-Vann firing bar--no surf indication of guns firing. RIH w/ WL OS & latched firing bar-- bumped dwn w/ no indication of guns firing @ surf. POH & rec bar. RIH w/ chisel-pt bailer. Drove dwn on firing pin. No surf indication of-guns firing. POH w/ bailer & RD WL. Press annls to 2700# & opened APR rev circ sub & rev out. Released pkr & circ. POH w/ test tools. All Vann guns had fired. Presenlty LD test tools. (Charts indicate a 424 psi incr during flow period of 11-1/4 hrs or approx 19 bbls of influx. 15,928'TD Fin LD DST tools & analyzed charts. WO tools. RIH ll,360'PBTD w/ 7" rtnr (BP) on DP & set @ 14,647'DPM. Spotted 35 sx cmt on top of rtnr to abandon G Zn. Est TOC 14,447'. POH & spotted 50 sx cmt fromll,560'-360'DPM to plug across 7" x 9-5/8" lnr lap. POH LD DP. 15,928'TD Fin LD DP & RD drlg eqpmt. NE BOPE & NU tat dry hole ll,360'PBTD tree. Cleaned mud tanks. Rig released @ 0600 hrs, 06-19-82, upon completion of cleaning mud tanks. Presently RD & prep to move out rig. 15,928'TD Cont RD drlg eqpmt. LD derrick @ 1600 hrs, 06-19-82. ll,360'PBTD Loading out eqpmt to mo%e rig out. 15,928'TD Cont RD. MORT ll,360'PBTD 15,928'TD Cont RD. MORT ll,360'PBTD 15,928'TD Fin loading out all Brinkerhoff/Signal Rig 54 & ll,360'PBTD beginning to CU location. FINAL REPORT 15,928'TD FIRST REPORT ll,360'PBTD of well. Moving rig and eqpmt in for completion 15,928'TD Fin RU M-W Rig #12. Accepted rig @ 2200 hrs, 08-30-82. ll,360'PBTD ND Xmas tree & NU BOPE. 15,928'TD Fin NU BOPE. Tstd BOPE'-OK. MU bit & scrpr. PU ll,360'PBTD 3-1/2" DP & RIH. 15,928'TD Fin PU DP. POH w/ bit & scrpr from 7700'. MU BP & ll,360'PBTD RIH to 7550'DPM. Set BP & POH to base of planned Sterling perfs. 15,928'TD DispI 9.7 ppg KC1 from 5500' w/ fr wtr. Spotted 50 ll,360'PBTD bbls 3% KC1 across Sterling B-3 & B-3A.. POH LD DP. RU to run.tbg. Ran hydr pkr, circ slv, 3-1/2" AB mod Butt tbg. 15,928'TD Fin running 3-1/2" AB mod, Butt tbg string. Set hyd 7,550'PBTD retr pkr @ 4955' w/ BV nipple @ 500' & 1/4" control line to surf. (No BV in place in nipple.) Tstd pkr to 2200%. Set BPV. ND BOPE & NU & tstd tree. Mixed pkr fluid. RU WL to open circ sly. 15,928'TD Open circ slv@ 4920'. Circ pkr fluid dwn tbg & into 7,550'PBTD annls. Displ w/ N2. Tstd surf lines--OK. Closed circ sly. Perfd Sterling B-3 & B-3A (5132'-42' & 5174'-84'DIL) w/ 4 HPF & +400% diff to wellbore. Unloaded well & tstd. Hydrates forming dwnhole & well froze off twice. Inj methanol dwn 1/4" control line to SSSV nipple @ 500' (no vlv in place). Thawed well OK. Well cont to prod OK w/ methanol inj. ~~ ~ ~ 0700 hrs: 10.87 MMCFPD, 1783% TP, 0 BWPD. SEP 2 o Oil & Gas Cons. Commission .~chorag~ TUBI, NG../C.A~ I, NG DETAIL Item Description No. ' oec .Jts Size Wt Thread Grade Range C,ond i,t i on Length From To . . , ~, ~ ~ ~ , ~'~,~ .' - s,~' '"" . , .. . . , , , ., , ~ , . .. . , . . . i , - . i . ~ ........ ,, Remarks: 8EP · ..A!,'t.$ka Oil &'Gas Cons. Coinrnisslor~ Anchorage :, '"~'"~ WELL NO.: Bc We DATE: . q.~.~ _ BY: TUBI,NG./CA,~ I. NG DETAIL .... ' ~~.~1~ k WELL NO.: . ~) ~. DATE: BY: 'I'G~ Item Description Se1 i No. "~ .Jts Size Wt 'Thread G ra,de Range Condition Length From To , . &~ ' q,~ ~. Pup a,/~" o+~ c.~ / ~. ~ C~o- ano") ~',~s ~ +qqa.~a.','.,.. ,. , . .:.. :. , , 54~3 ~. ~ ~t~ - ~5t8o)~ , .. ,,, . -' ~'r~,~.. ,, . Oona Remarks: . 'ancho/a,q-~', OotarniSaion s:,'~RATHON OIL COMPANY BEAVER CREEK NO; 6 GMS .......... BEAVER-CREEK- KENA'I'v--A[.AKA GMS, 0-1.5,800 MIl ~ SURVEYOR CAMERA N0o-1-666 HICKMAN, JOB NO: AO482G04~ JAHN DATE RUN; 4-24-82 1~ F. C E t ¥1!!O GYRO NO; 286 24'DEB A/U NO; 298 FORESIGHT;-S14---40W ~EEEiVED Alaska Oil & G~ Cons. Com~iss[o~ ~chorage APR 2 6 1982 Operations Superintende.nt VERTICAL SECTION CALCULAT ..~:..~:.. RECT_.[~N,~ S ~:~ ':~;D'~'i''i~' .... .'.:.-i'~ .............................. · A ~RO~NE ~PANY RECORD OF SURVEY F:P~-~-U S 0 F---~U 'RUP~-U RE =M ET~IOD MARATHON OIL-- COMPANY-- BEA'VER CREEK NO; 6 GMS BEAVER CREEK KENAI, ALAKA JOB NO; AO482G0433 CONFiLLTA~ION TIME DATE 10;12;24 26-APR-82 TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL. SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEF'TH ......ANGLE-..DI-RECTION-LENGTH ..... DER.TH----SEQTION ....... ~UD C-O-O-R D--I--N-A--T---F~.-D~.ST~NCE--~I. RECT~.~EUERIT.' FEET D M D FEET FEET FEET FEET FEET FEEl* .D M DG/IOOF' O, ...... 0 ...... 0 ........... 0 .................. 0., 0-,-00 .... 0-,-0~---=1-73,.00 ......... 500, 0 0 0 500,500,00 0,00' 327,00 1000, 0 15 S 36 W 500, 1000,00 -0,34 827,00 1500, 0 15 .-S ....5-W ............. 500, ........ 1499,.~ ......... 0-,~44 .... 1326+.99 2000, 0 0 0 500. 1999,99 '-0,20 1826,99 .~00, ....... 0 0 ....... 0 .................. 500, ...... ~499-o-99 ....... 0,~0---2-326-~9-9 ..... 3000. 0 0 0 500, 2999,99 -0,20 2826,99 3500, 0 0 0 500, 3499,99 -0,20 3326,99 0,00 0,88 S 2-,-9.0--$ 3,98 S .3..,.98--S 3,98 3,98 0,00 0+0~ ....... ~--0 .... 0,.00.. 0,00 0o00 0 0 0,00 0,64 W 1,09 S 36 0 W 0,05 1,49 W 4,25 S 20 30 W 0,05 '1~-~9--~ ....... 4~ 2.5. -S-2040-4~--0~b0..- Z,49 W 4,25 S 20 30 W 0,00 Z,49 W 4,25 · 4000, ....... 1 --- 0 .... S- 82---W ........... 500,----39-9--9-,-9-7- .......4-,.1.3 .... 3826+~97--~4.,59--S - 5-,81--W-~-----7-,-.40~-S-.5-1~.2-W~O.,*.20 .... 4100, 0 15 N 71 W 100. 4099,96 -5,18 3926,96 4,48 S 6,88 W 8,21 S 56 55 W 0,79 4300 0 45 N 4~ W 10~2~2~9,~~~:~~=.4~~~ ~~~~96:W 9 96 S &4 4 W 0 82 4oo, o 4500, ...... 4600, I 0 N 80 ~ 100, 4a99,92~ -11,03 44~~:RO~NE~SA~.~ 12,25 ~ 12,43 S 80 22 ~ 0,31 -4700, ......0.-30 ...... N-35--W ............... 1-00.,--46~,--9~----1~2&----4526-~ 4800, i 0 N 34 W 100, 4799,90 -13,30 4626,90 4900, 0 45 N 82 ~ 100, 4899,89 -14,73 4726,89 --.5~0, .......O--30---N-26-W ~00.,-~499~88 .... t. 5~3----482~-8-8 ~._~0, 0 45 S 78 W 100, 5099,88 -16,73 4926,88 1-o-40--S--~-3.~3--W---~13-,40--S-84----t--~-J ...... 0~4--. 0.32 S 14'07 W 14,07 S 88 42 W 0,50 0,47 N 15,32 W 15,33 N 88 15.W 0,75 ~,-08--.N-~l~.~7-W -. 1~,~2-1~N--8~ ..... 1.53 N 17.08 W 17.15 N 84 54 W ~?~;'9 5200, ......... 0---45 .... N---72---W .......... 100~--.5-1-~-9-+87 ~7~-98 .... 502&~87 ~59--.N .... ~8,3.7---W----1-8-,-44 -N-8~-. 3-44----0~9 ........ 5300, 0 30 N 10 W 100. 5299,86 -18,87 5126,86 2,38 N 19,05 W 19,20 N 82 53 W 0,68 5400, 0 30 S 61W 100, 5399,86 -19.61 5226.86 2,70 N 19,73 W. 19,91 N 82 13 W 0,81 .-5500, .......... 0 .45 ....N-.53 W ......... 100-,-~549~,-85-- ..... 20,6--1---5326-~85~-~-,~-~-N------20.,J6--~-----2.0-,.~4---N--82--24--W -0--71 ....... 5600, 0 30 N 7 E 100, 5599,85 -21,29 5426,85 3,73 N 21,16 W 21,49 N 80 i W 0,66 --.5700, ........ 0 ...... 0 .... O- .100~ 569.-9-,-84 -~i~-37----§S2&-o84-~----4-~1-~--N-~2-1~4-1--W :-.2-~,-52 ..... N---78--~l---H- -0.,.50... 5800, 1. 0 N 56W 100, 5799,84 -22,21 5626,84 4,65 N 21,83 W 22,32 N 77 59 W 1,00 5900. I 0 N 51 W 100, 5899.82 -23,86 5726,82 5,69 N 23,24 W 23,92 N 76 15 W 0,09 -..6000, .......1 .... 0 ...... N-16 W ......... 100,----59-9~-81. -25,20 5826,8t .7-~i.2-N .... 24~4-8-W- 2§~2! N--7-3--3& W 0~60 ...... 6100, I 0 N 48 W 100, 6099,79 -26,52 5926,79 8,58 N 25,10 W 26,52 N 71 7 W 0,55 '~ARATHON OIL-COMPANY ........................... BEA~ER CREEK NO; 6 GMS BEAVER CREEK KENAI, ALAKA JOB NO; AO482G043~ ~OMPUTA~I-ON-- TIME DATE 10;12;24 26-APR-82 -. TRUE ~F£ASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEPTH ANGL. E -DIRECTION --LENGTH .... DEF,-TH--==-SE.CT--ION .........TVD ......... C--8--O--~--D--t--N-A-T-E--$--E~I-STANCE--Dt RECT-I-GN--SEUER.t.T! FEET D M D FEET FEET FEET FEET FEET FEET D M DG/IOOF: 6200, '" 1 '0 ' 'N"-36"- W .......... 100', .... 6-199",-78 ...... 28'v02- .... '6026~"78 ...... 9','88-N ---26',-26-W ........28~-06 ..... ~-6~--2~"~ ....... 0',"2i'- 6300, 1 0 N 44 W 100, 6299,76 -29,50 6126,76 11,21 N 27,~8 W 29,59 N 67 44 W 0,14 6400, 1 0 N 45 W 100, 6399,75- -31,05 6226,75 12,46 N 28,61 W 31,20 N 66 28 W 0,02 6500,- - 1 15 - N-48 W .... 100, ....64~9-,--7~--~~-2.~-82---~S26~--7~-~-1-S,.81--N ..... SO-,-O~--W~-S.~-,-O5 ..... N----6S--1--8--W .......... 0,26- 6600, 0 45 N 2 W 100+ 6599,71 -J3~97 6426,71 15,35 N '~0~75 W 34,37 N 63 29 W 0,91 ~00, ..... 1- 15 ---N--Z2 W .............. 100~ ....... ~-~--7-0 .... 6800, 1 0 N 11 W 100~ 6799,68 -36~19 6626,68 18,81 N 31+97 W 37~10 N 59 ~1. W 0,48 6900, 1 15 N 20 W 100, 6899,66 -37,27 6726,66 20,71 N 32,49 W ~8,53 N 57 30 W 0,31 7000, ......... 1'-' 0 ...... N---~2 '-W ........... 100 *---'69'99','64 -'~8'*-6'~826~-64~ g2-,-4-7--N .... S~--S~ .... ~G,~2---N--56----~~O,-~4 ..... 7100, 1 15 N 16 W 100, 7099,62 -39,93 6926,62 24,~6 ~-.- ............ ~ ,- ~,,~ W 41 89 N 54 ~7 W 0,40 ~.<.:~:-:~-. ~ :~= - ~ ~ . ..= . 7200, ........ 1 ...... 0 .... N- 23--W-- =--....~:. ...... ~.-~.--....--'-.~-~:: ~ , ..... . ~~-W 4J-~-~i : N-~~~~-g8.-- : 3-~g:~'~ ~ - _ ~ <:., -,~. ,: ~ ~: -.. ~;.-:~.~ = ~: .. 7400, 1 0 N 25 W 100'~~99,57 -'-4~j~~~Z~~m~~~j~:~~~ '~12' W 45,19 N 52 42 W 0,65 ~:~tu... = .~=~.-..<.. ~-~.... . ~<:... ..W 46,88' N 52 21 W 0,62 7600, 1 0 N 24 W 100, 7a99,54 -45,94 742~ ~?/'RO~'~.~~ 37,98' W - 49,66 N 49 53 W. O, 35 7700, ...... 1.-15 ---N --25 W ........... i O0, .... 7~9-9~-S-2- -4~--~~52-6-, 5~-- ~.~7-9~ ..... 38~B--W-- --S~-441 ~N-4~7--.B - ~-5 ..- 7800, 1 0 N 21 W 100, 7799,50 -48,55 7626,50 35,60 N 39,56 W 53,22 N 48 1 W 0,26 7900, 0 30 N 28 W 100, 7899,49. -49,43 7726,49 J6,79 N 40,10 W 54,42 N 47 28 W" 0,51 -- 8~0 · ...... i---O ~N---41--E ...... 100-~-999-,WG~~7~Gg~8~gG~-~ ~0, 0 45 N 2 W 100, 8099,47 -49,62 7926,47 ~9,41 N J9,47 W 55,78 N 45 2 W 0 8200, -~.-~ 0 -45 .....N.-7-~.--E .......... 100~l-~9~6 ~-4.9~2~ 8026,~6 40~O.-N~ - ~.8~~~5~_9~ -N~--4-9 ~ ~~_.. 8300, 3 0 N 88 E 100, 8299,40 -46,~6 8126,40 40,94 N 35,54 W 54,22 N 40 58 W 2,28 8400, 4 0 N 86 E 100, 8Z99,22 -40,65 8226,22 41,26 N 29,44 W 50,69_ N ~5 ~1 W 1,01 -.8500, ..... 5 ..... 0 -N--8S--E ............. 8600, 8 30 S 87 E 100, 8598,20 -22,27 8425,20 42,08 N 9,88 W 4~,23 N 1~ 1~ W ~162 .... 8700, .... 1.0--45---S-81--E ......... 100-,---8&9-6~78 8800, 11.45 S 77 E 100, 8794,86 8900, 12 30 S 73 E 100, 8892,63 ----9000-.,.---1~----0--S.73-..E .100, 89~0-,--1-6 9100, 13 45 S 74 E 100, 9087,45 -5,-~2---85~:78 . 40~-a~4--N~--~a~7_4_£ 4O-~-O---N ? 2~-.~ 2:~46 .... 13,45 8621,86 J6,61 N 25,88 E 44,84 N J5 15 E 1,27 ~4,4~ 8719,6~ ~1,18 N 46,17 E 55,71 N 55 58 E 1,1~ '79,62 8914,45 18,16 N 89,45 E 91,'28 N 78 J2 E 0,78 H A F,',A I'HO.N 01L.--.COHF'ANY- ...... I:'~I_"EAVER CREEK NO: 6 GMS BEAVER CREEK ~{ENAI, Al_AKA JOB NO: AO482G0433 C.O~tFJU-- liA-T-I~O N TIME DATE 10:12,'24 26-AF'R-82 TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEF'I'H .ANGLE--- D I RECT ION-- LENGTH .... DE~T.H_ ~ E.CII.DN ..... I~D .... C-i)-.O-_~--II_.I--~-~--~T--8~-~I.S~ NC~__ILIR EC.T_I~QN_S E~E.~ I T FEEl' D H D FEET FEET FEET FEET FEET FEET D M DG/1OOF 9200 · -. 14 ... 45 .... S ].4 - E ........... 100 · ..... 9-1.84.,.37 .... 104,22 ......~-011-, 37_ ............... 11.,37__N ..... 113.,.11_E .......11:~.~-&8 ..... N..-84_/.6._E:__.l_,.O0... 9300. 15 15 S 76 E 100. 9280.96 130,07 9107.96 4,67 N 138,11 E 138,19 N 88 4 E 0,72 9400. 16 15 S 78 E 100. 9377.21 157.12 9204.21 1.43 S 164.56 E 164.57 S 89 30 E 1.14 9500, 16 30 S 78 E.. 100+ .... 9473+15 ...... 185+-17 .... ~300,15 ............... 7,-29-.S ............ 192,.14-..E .......... 192,27_ .... S.__87....50.....E ......... 0,25 9600. 16 0 S 78 E 100. 9569.16 213.01 9396,16 13,11 S 219.51 E 219,90 S 86 J5 E 0+50 ~00, 16 15 -S 78 E ........100, ...... ~665,2.2 ........ 240,64 ......-9.49-2+2-2 ............. 18.,.8~-8-~246-+6-%.-~ ..... -24%+4.-0 ....... 8~5~-~--.~----~.5. 9800. 16 30 S 77 E 100, 9761.17 268.71 9588,17 24.99 S 274.20 E 275.33 S 84 48 E 0.38 9900. 16 30 S 77 E 100. 9857+05 297,01 9684,05 31,38 S .301,87 E 303,50 S 84 4 E 0.00 10000, -. - 16 --30 --- S--76-E .......... 100 · ...... V952.,-93 ......... 325,33---9-7-7-9-.,-93 ...... 38,01 ..... S ....32V-,4-~--5 .... 33-1-.+.67----8-83-25-~-0+28.- 10100. 16 15 S 77 E 1.00. 10048.87 353.44 9875.87 44,5~ S 356,90 E 359,67 S 82 53 E 0,38 :-.::-. :.....~ , ~i~= ............ 10200~-. 15 45 .... S--Y6.--E-- 1 '~" ~'~:77 E 413,8S S 81 5~ E 0,37 10400, 16 30 S 74 E lO0':~J:lO337,43 435,:3:?.1'.01~4:,..~3.:::~..:~5,.!:..~87 43~:j33 E 441,17 S 81 31 E 1,04 10500 17 0 S 72 E 100,~i~0433~1'~~'~:~~,~8~*~7~'~6~ S ' ~---~.:',. ..... ~:~..~:.., ' '~ 6 ~ '- ' ~ : ,..~ .=.= :-.:~,.: .~_~' _... ~ '...-. ' ~: ' '~.~- ~ - 10600 lY 45 S 72 E 100 10528 62 494 , 10700, 18 15 .-S-72 E ......... 100, ..... 1.0623,.73 ......... 524-o94-~-10450-+-~3 ...........92.,33-S .......... 521-,-68-5 .......529.,-7~--:-.-S-.--~.-58.--..~----0-~50 10800. 19 0 S 73 E 100, 10718.49 556,87 10545.49 101,94 S 552,14 E 561,47 S 79 32 E 0,82 10900, 19 45 S 72 E 100, 10812.82- 590.05 10639.82 111,91 S 583,78 E 594,41 S 79 9 E 0,82 ..:1.!"00, ....19--30 ....S.--.72-.--E .......... 100.,-.t0907,01 ....... 623,-63---10-7-34-,-01 .... 122-,.-2~-S-~-61-5-,-F~-E-----62?,7~---$-~8--4~**E----O~...5- l~..JO. 20 0 S 71 E 100. 11001,13 657,42 10828,13 133,01 S 647,77 E 661,28 S 78 24 E 11200,... 20 30 --.S-.70-E ........... 100, ..... 110~4+95-----~92~-02-..1-092l-,-9~ .... 1-44-,5~-S ......... 680-,~9--E~.695.~58 ....... 8-~8---0-E:----0.,-6-1- 11300. 20 15 S 70 E 100. 11188.69 726.81 11015.69 156.47 S 713.11 E 730.08 S 77 37 E 0.25 11400. 20 15 S 70 E 100. 11282.51 761.39 11109.51 168.31 S 745.63 E 764.39 S 77 17 E 0.00 11500°- 20 30 S-70 E ......... 100,--11376,~5- ~6,-1-8 ......1-1203,-25 ...... 180,22-$ ....... 7~8-,-35-E 7.98,94 .... S''--~'~8--''E ..... 0''--25--' 11600, 20 30 S 70 E 100. 11469,92 831,18 11296,92 192,20 S 811,26 E 833,71 S 76 40 E 0,00 11800, 20. 30 S 70 E 100, 11657,25 901,14 11484,25 216,73 S 876,86 E 903,25 S 76 7 E 0.35 11900, 20 30 S 70 E 100. 11750,92 936.13 11577.92 228.70 S 909,77 E 938,08 S 75 53 E 0,00 12000, 20 45 --S 69 E .... 100, ..... tl.844-,-51 .... 12100. 21 0 S 69 E 100. 11937.95 1006.90 11764.95 253.81 S 976.03 E 1008.49 S 75 25 E 0.25 · -.tAR~THpi'; OIL. COMPANY ....................................................................................................................... COMF'UT.AT-ION .............. i~'AGrE---NO; ........ '4.- 8EA~JER CREE'K NO: 6 GMS JOB NO; AO482G0433 TIME DATE .' BEAVER CREEK KENAI, Al. AKA 10; 12;24 26-APR-82 TRUE · 4E'ASURED DRIFT DRIFI' COURSE VERTICAL VERTICAL SUBSEA R E C l' A N G U L A R C L 0 S U R E DOGLEG DEF'TH ANGLE DIRECTION LENGTH ..... DEPTH ..... SEG~T-tON ............... TVD ........... C--G----O---R--B---I---N-A--T---E-S--D-I-STANGE ......... DI.RECT-t--ON-SEVER--ITt FEET [, M r_l FEET FEEl' FEET FEET FEET FEET D M DG/100F'] 12200, 20 45-S 67 E -100,--12031--,-39 ..... 1042-,--43---1--1858:~-39 .......... :[2300, 20 15 S 67 E 100, 12125,05 1077,31 '11952,05 280,84 S 1041,30 E 1078,51 S 74 54 E 0,50 12400, 20 30 S &5 E 100~ 12218,7~ 1111,~2 12045,7~ 2~5,00 S 1073,11 E 1112,~2 S 74 38 E 0,74 12500+ 20 30 S 65 E 100, 12~12+46 .... 1146-,66--1213~,-46 ...... 30~-+80----S ........ 1-104,85----E ....... 11-4-7,-46 ...... S--74---20--E ........ 0,-00 12600, 20 45 S 65 E 100, 12406,05 11'81,61 1~')~.~-,05 324,6~ S 1136,77 E 1182,23 S 74 4 E 0,25 1~0, 20 45 S- 65 E ..... 100, .... 124~-, 5-7 ...... 121- 6--, --P 6 -- -1-2 ~ 26 --, 5-7 ...... S-~-~-~56--S ..... -1--1'68,-'88-E ...... ~2-1~-,--2~----S-7-S-48-~----~0 ..... 12800, 1~ 45 S 66 E 100, 125~3,38 1251,13 12420,38 354,01 S 1200,38 E 1251~4~ S 73 ~4 E 1,06 12~00, 18 45 S 66 .E 100, 12687,7~ 1283,~1 12514,7~ 367,42 S 1230,4~ E 1284,18 S 73 22 E -1,00 13000, 17 45 S-67 E ....... 100,--12782-,.76 ...... t31-5.~-0-7--~1260~-.,.7-6 ....... -3-7-9-,--~1---S ...... 125-9.,~-1--E ..... 1-~1-5,--~7 .... S---7-3-1~E ...... t-,.-.0~ ..... 13100, 16 45 S 67 E 0 ~ ~ i 0+ 1~878,~6 ..... 1344,60 1~70~,~6 3~1,~0 S 1~.86,~1 E 1344,76 S 7~ 4 E 1,00 ' ~ .. :~ ~'~ ~Y~ .::~ ' lSSO0, 17 15 S 66 E 100'., 1~06~5 1402,~4:.128~:~5 ..414,88 ~ 1~:~.65 E 1402~42 S 72 48 E 0~50 -.... . ~. ~. ~5.' - . ~,. 13600, 17 45 S 66 E 100, 13356,02 14~1,20 1318~=~-~.:~:~:~_~!:..~?~:3_-:~.~- 1421,30 E 14~1,21 S 72 23 E 0,50 :[3700, 18 0 S 67 E 100,-1-3451-,-1-9--152-1,-74--t-3278,-t-9 ........... 46-3-,-4-7----S ........ t-449-,-4-5-E ..... 1-52t--,-74 .... $--7-2--i6--E-----0~--40-. 13800, 18 0 S 67 E 100, 13546,30 1552,52 13373,30 475,55 S 1477,89 E 1552,52 S 72 10 E 0,00 13900, 18 0 S 68 E 100, 13641,41 1583,31 13468,41 487,37 S 1506,44 E 1583,32 S 72 4 E 0,31 14"~0,--18.-.0 .... 8-68 E ........ 100, .... t-3736-,.-5t ..... 16-14.,13----t-3563-,5t~-498.o-9.~5-S----t-535,-09--E--t-6:4.~,--t.4 .... S-~3~O---E----~-~ 14...,..,0, 17 15 S 67 E 100, 13831,82 1644,31 13658,82 510,54 S 1563,06-E 1644,33 S 71 55 E O"..::-.:-.i 14200, 17 15 .-S. 66 E ........100., ...... 1392:+32----1~73,.82 13~54,32 .... 522-+-,.~6--S ...... 15-90.,-2~--E---1-&-73~85~21--4.9 E------O~30 .... 14300, 17 15 S 66 E 100, 14022,82 1703,30 13849,82 534,42 S 1617,35 E 1703,36 S 71 43 E 0,00 14400, 17 30 S 66 E 100, 14118,26 1732,98 13945,26 546,57 S 1644,63 E 1733~07 S 71 37 E 0,25 14500, 17 15 S 66 E ........100,--14213o69 .... 1-~62-,.67----14040,-6~ ......... 558,-Yl .... S ...... 16.~1-~-~1 ~--~-~&2~-80~--S-~.Z-31--E--- ....... 0-,.25-.- :[4600, 16 45 S 67 E 100, 14309,32 1791,77 14136,32 570,37 S 1698,72 E 1791,92 S 71 26 E 0,58 14700, ........ 16.-45 ...... S-66---E ............. 100+ .... 1-4.405+~8 .1-820.+.44.-.--14232-,-08- -58~+-86.-$---1-~25-+-1-~~82~+&4~-$-%1~22-~-0+2-~ ..... 14800, 16. 0 S64 E 100, 14501,02 1848,41 14328,02 593,78 S 1750,70 E '1848,66 S 71 16 E 0,94 14900, 16 0 S 63 E 100, 14597,15 1875,66 14424,15 606,08 S 1775,37 E 1875,97 S 71 9 E 0,28 -15000+ .... 15-30 .....S &l E ......... 100+-l-46~3-,3~----1~02+.~-.-14520+3~. : &1-8+~.2--S 1-7-9-g+~;~.E---1.~O2~-:~-~7;I~--1--E-~-O~-7.4 ...... 15100, 14 45 S 60 E 100, 14787,93 1927,92 14616,93 631,~7 S 1822,05 E 1928,43 S 70 53 E 0,79 dARATHO~! OIL-COMF'AN¥ ................................ BEA'VER C.REEK NO: 6 GMS BEAVER CREEK KENAI, Al_AKA ~0~ NOI AO482G04~ CQNF~UT~I~N TIME DATE 10;12;24 26-APR-82 TRUE '~EASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G.U L A R C L 0 S U R E DOGLEG DEF'TH ......ANGLE DIRECTION-LENGTH ........ DEP-TH .... SE~T.I.ON ....... ~.VD ....... ~-O-.O--R--[L-I-~-A--T--F_,-,.,~LD-I.S~ANCE .... LDI. REC%ION-~EgER.I-T.t FEET D M D FEET FEET FEET FEET FEET FEET D M ' DG/IOOF] 15200. 11 30 - .S 6~ E ........... 100. .... 1-4887-..~0 ....1-9-50,23 .... 147-14-,30 ........... 642-.50-,-S~1842.-00-.E ..... 1..950-,..8:~- ...... S--7-O--.46-.-E ............. 3.32, .. 15J00, 15400. 15500. 15600, lttl'~O0. 15800, 9 0 S 58 E 100. 14985.70 1967.65'14812,70 651.26 S 1857.48 E 1968.34 S 70 41 E 2.65 6 45 S 68 E 100. 15084.75 1981.15 14911.75 657.47 S 1869.67 E 1981.90 S 70 38 E 2.63 5 0 N 88 E 100. 15184.22 ........ 1991.22-..15011.-2~ ......... 659...2~.,-S ........ 1.87.9..,68--..E ........ 1.991o.93 ...... S---ZO---40--E ............ 2.98- 4 45 N 5J E 100, 15283.86 1997.87 15110.86 656.44 S 1887,56 E 1998.45 S 70 49 E 2.94 5 15. N 37 E ... 100,...1538~,48 ...... 2001-,..8.4 ..... 1-5210.,.48 .......... 650-,-.~0.-$ ..... -1-89~.-,-7~-.E ....... 2002-,-25 ......... $-.7.1 .... ~--E ........ 1.~;8-.. 6 30 N 21 E 100, 15482,95 2003.83 15309,95 641,38 S 1898,65 E 2004,05 S 71 20 E 2,05 s'ROJECTED TO-15842--ND ............................... ~:::~':'!:ii': ..... ':::'-::1,1~:~ ~ .- ..,~-,:~.-,,, .:~,::,._.. ............... . .... _ ....................... ??7 42~i.?~'~524,68 200~:.,:0:9~'-~.b!'.:~8;~?~:~:6.,::~-~i~ 1~j35 E 2004,25 S 71 28 E FINAL CLOSURE - DIRECTIONI S 71 DEBS 28 MINS 14 SECS E ...... DISTANCE ~ .............. 2004-.25--.-F. EET ............................................. 15842. 6 30 N 21 E 15q,9,~ '" 0,00 Suggested form to be inserted in each "Active" well folder to check for tin'~ly con~liance with our rc~julations. Ope. rat6r', 'Well Name a~d Number Reports and Materials to be received by: /~ --~ ~-< ~2, ' · ~ Date Required Date Received Remarks Completion Report Yes ~--~-. d~- ~ ~'~,ii'"' ~' ,/ Well History Yes _s. ~.~.~ /~,'a . ........................... - . --.. ,~."~ ... Core C~ips -.' . .... ' 2 '~,~' . -~:,..:~.. .... .. Inclination Survey ,~ t ,? '- ..., ,:~ Directional Survey ~.~ ¢' p / ? /, ~.__.~,& ~ ~ ~ .,.,.,, Drill. Stem Test Reports ~.-~/P'" .,, .. ~s R~. Yes ..... ~ ..... ~ ... Digi~.~Z~ rata _~ ~ ~.~. .. ALASKA ,," AND GAS CONSERVATION C ,~MISSIO SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ OTHER [] 2. Name of Operator 7. Permit No. Marathon Oil Company 81-150 3. Address 8. APl Number ?. O. Box 2380, Anchorage AK 99510 50-133-20346 9. Unit or Lease Name Beaver Creek Unit 1233 ' FNL, 10. Well Number SC ~6 11. Field and Pool I 6. Lease Designation and Serial No. Beaver Creek Field A-028083 Check AISpropriate Box To Indicate Nature of Notice, Report, or Other Data 4. Location of Well Beaver Creek Pad ~3 Surface: 1467 'FWL, Sec. 34-TN-10W-SM 5. Elevation in feet (indicate KB, DF, etc.) KB 185' above MSL 12. 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 anv proposed work, for Abandonment see 20 AAC 25.105-170). It is Marathon's intention to conduct an open flow potential test on Well ~6 upon completion of well workovers in the field. The testing should be completed'by the end of October, 1982. 14.' hereby certify t. hat the foregoing is true and correct tO the best of my knowledge. 2~_._/~_0~ Signed '~ -j,~-.,/- Title ~,.,~ .~ ~ The space below for Commission use vi -- Date Conditions of Approval, if any: An extension of time for clean-up is given until September 15, 1982. An inspection by a representative of the Commission will be necessary by August 15, 1982. ORIGlllA't' $1GliEll By Order of Approved by tOIililEC. SIilTil COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Repor{s" i n Duplicate 3" 50~)0 #. Gate valve' ! BC #6 · Suspended June 18, 1982 , · 9.7 ppg KC1 Drilling mud · Liner Top @ 14,681' .MD ., · ., 7" 'Liner Shoe @ 14,980' MD' · · · ,. ,,. A!~ska':Oil & Gas Cons.. commission Anchorage .;. 5" Liner Shoe'@ 15,889' MD 50 SX Class G 11,360' - 11,560' DPM · 35 SX Class G Top.of Cement @ 14,4'47' DPM 7" Bridge Plug @ 14,647' DPM 'G~Zone perforations ".,.' 15,003' - 15,,050', DLL 15,085' - 15,128' DLL 15,170' - 15,200' DLL .' , .. '" ":i".!: "'"', .?:'.::'F ' ' ,, '. ., ;' ,. Fill @ 15,254' WLM Top of cement plug @ 15,260~ WLM Bridge plug @ 15,280' . Hemlock Zone perforations' 15,306' - 15,326' DLL 15,345' - 15,3707 DLL 15.,387' - 15,407' DLL 15,414' - 15,466' DLL '" 15,476' - 15,506' DLL 15,520' - 15,540" DLL ~ STATE OF ALASKA , ALASKA( _ AND GAS CONSERVATION C(~ MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~[ OTHER [] 2. Name of Operator Marathon Oil Company 3. Address ?. 0. ;SOX 2380~ Anchorage AK 99510 4. Location of Well Beaver Creek Pad #3 Surface: 1467'FWL, 1233'FNL, Sec. 34-7N-10W-SM 5. Elevation in feet (indicate KB, DF, etc.) KB 185' above MSL 12. I 6. Lease Designation and Serial No. A-n_ 9R083 7. Permit No. 81-150 8. APl Number 50- 133-20346 9. Unit or Lease Name Ro~v~ Creek U?_it 10. Well Number RC ~6 11. Field and Pool Sterling Gas 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). T,P ~ 1~,, gZS' ~ L : /3-~ 20" ~ k ~ ~z IL ~s ~a~ho~'s ~Lea~on ~o ~e-eate~ Lhe well, eel a p~oduc~oa packe~ and ~un a sia~Ie s~ag oE p~oduc~oa ~ub~as. ~he S~e~l~g Gas Seeds ~11 Lhea be pe~Eo~aLed 4 ~, 0~ phas[ag, ~om 5132'-5142'DI% aad 5174 '-5184 '9I%. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~--~. ~:~/&~F~. Title -- -- The space below for Commission use Conditions of Approval, if any: Approved by. Form 10-403 Rev. 7-1 ~80 Approved Copy Returned ..... By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" i n Duplicate .l GEOPHYSICAL/GEOLOGICAL DATA'[. TRANSMITTAL LIST IDATE July 12, 1982 FROM: MARATHON OIL COMPANY Operations D.F. Stover ADDRESS P. O. Box 2380 Anchorage, Alaska 99510 VIA Hand delivered QUANTITY ~ ONE SIGNED COPY TO THE ABOVE ADDRESS TO: COM~,ANY JADDRESS Mr. Russ Douglass Alaska Oil and Gas Conservation Commissi, 3001 Porcupine Drive Anchorage, AK 99501 JDATE SHIPPED DESCRIPTION BC #6 Record of Survey BC #6 FDC CNL PORO 5" sepia BC #6 FDC CNL'PORO 5" blueline BC #6 FDC-GR-5" sepia BC #6 FDC-GR-5" blueline BC #6 BHC-GR-5" sepia BC :#6 BHC-GR-2" blueline BC-GR-5" sepia. BC.#6 BHC-GR-5,' blueline DI-SFL 2" sepia . DI-SFL 2" blueline CPL 2" sepia CPL 2" blueline DI-SFL 5" sepia DI-SFL 5" blueline BCSL 2" blueline BCSL 2" sepia. DI-SFL 5" blueline DI-SFL 5" sepia Cased ~ole FDC/CNL/GR 5" hluel~ne .. RECEIVED BY July 12, 1982 lllaska 0il & Gas Cons. tlnCborage DATE FORM NO. AN-2 GEOPHYSICAL/GEOLOGICAL DATA TRANSMITTAL LIST CONTINUED Page 2 DATE FROM: DEPT. ADDRESS VIA 1 1 MARATHON OIL COMPANY ISEN DER P. O. Box 2380 Anchorage, Alaska 99510 Hand delivered QUANTITY SE RETURN ONE ED COPY TO THE ABOVE ADDRESS TO: COMPANY DESCRIPTION Cased Hole FDC/CNL/GR 5" sepia BCSL 5" blueline BCSL 5" sepia CFDL Gamma-Gamma 5" blueline CFDL Gamma-Gamma 5" sepia Cased Hole FDC/CNL/GR 5" blueline Cased Hole FDC/CNL/GR 5" sepje_ 'Dual Laterolog 5" blueline Dual Laterolog 5" sepia Cased Hole FDC/CNL/GR 2" blueline Cased Hole FDC/CNL/GR 2" sepia CPL 2" blueline CPL 2" sepia . Dual Laterolo§ 2" blueline DATE SHIPPED Dual Laterolo~ 2" .sepia Cased Hole FDC/CNL/GR 2" bluel~ne Cased Hole FDC/CNL/GR 2" sepia DI-SFL 2" blueline DI-SFL 2" s~pia FORM ND. AN-2 RECEIVED BY Al3sk~. Oil & Gas Cons. Cor;m'dssiol~ Anchorage DATE GEOPHYSICAL/GEOLOGICAL DAT A~L' TRANSMITTAL LIST CONTINUED. Page 3 DATE FROM: MARATHON OIL COMPANY TO: DEPT. J SEND£R ADDRESS ~DORESS P. O. Box 2380 Anchorage, Alaska 99510 VIA Hand delivered QUANTITY 1 CNFD 5" blueline 1 CNFD 5" sepia .. SIGNED COPY TO THE ABOVE ADDRESS RECEIVED BY DATE SHIPPED DESCRIPTION · ~,laska Oil & Gas Cons. Commission .knchora~ DATE FORM NO. AN-2 STATE Of ALASKA ALAI~KAL,L AND GAS CONSERVATION C WIMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL Name of Operator Marathom Oil Company Address ?. O. ;Bo:< 2380, A_nchorage, AK 99510 COMPLETED WELL [] OTHER [] Location of Well Beaver Creek Pad #3 Surface: 1467' FWL, 1233' FNL, Sec. 34-7N-10W-SM Top of G: 1852' FNL, 3266' FWL, Sec. 34-7N-10W-SM TD: 1870' FNL, 3367' FWL, Sec. 34-7N-10W-SM 5. Elevation in feet (indicate KB, DF, etc.) KB 185' Above MSL 12. 6. Lease Designation and Serial No. A-028083 7. Permit No. 81-150 8. APl Number 50- 133-20346 9. Unit or Lease Name Beaver Creek Unit 10. Well Number BC #6 11. Field and Pool Beaver Creek Field 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). Beaver Creek #6 G-Zone Abandonment The non-productive G-Zone was abandoned on June 17, 1982, as specified.on the attached well schematic. The last production from this zone was 19 Bbls of fluid in 11-1/4 hours. It is our intent to suspend operations on BC #6 until a workover rig is contracted to test the Sterling gas sands. Verbal permission for tb.e zone abandonment was received by D. F.'Stover on June 17, 1982, from..R. Douglass of Alaska Oil and Gas Conservation Commission and R. Golf of Minerals Management Service. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed. ~~. Title. The space below for Commission use Conditions of Approval, if any: Approved by f EEEIVEf) JUN 2 8 ~982 A!aska Oil & Gas Cons. Co~issio~ ~nc.horag~ . Form 10-403 Rev. 7-1-80 Date COMMISSIONER Returned By Order of the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 3" 5000 ~/ Gate valve' · , 7" Liner:.Top @ 11,446: MD'~ . .. 9-5/8" Casing Shoe @ 12,410.' 'M~- 5" Liner Top @. 14,681' MD ., .,. ., 7" ·Liner Shoe @ 14,980' MD' ' .. 5" Liner Shoe' @ 15,889' MD ! 9.7 ppg KC1 Drilling mud · ka Oil & 6as BC ;'~6 . Suspended June 18, 1982 50 SX Class G 11,360' - 11,560' DPM 35 SX Class G' Top.of Cement @ 14,4'47' DPM 7" Bridge.Plug @ 14,647' DPM G-Zone perforations .. 15,003' - 15,.050' DbL. 15,085' - 15,128', DLL 15,170' - 15,200' DLL 15,306~ - 15,326' D~' C°ns-'C°mm~s~345' - 15,3707 15,387' - 15,407' DLL' 15,414' - 15,466' DLL 15,476' - 15,506' DLL 15,520' - 15,540" DLL Fill @ 15,254' WLM Top of Cement plug @ 15,2607 WLM Bridge plug @ 15,280' Hemlock'Zone perforations Marathon Oil Company ., Anchora,~ ,vision Production Exploration, U.S. & Canada P.O. Box 2380 Anchorage, Alaska 99510 Telephone 907/274-1511 June 9, 1982 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK .99504 Attached for your approval is our notice of intention to perforate Beaver Creek Well #6. DFS:bgh DAN STOVER Operations Engineer I ECEIVED JUN 1 0 ]982 Alas~ Oil & Gas COns. AnChorage C°n~n~i~s[on STATE OF ALASKA ALASKA(" ,L AND GAS CONSERVATION C[ ,IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL 2. Name of Operator Harathon 0il Company 3. Address P.O.Box 2380, Anchorage, Alaska 99510 4. Location of Well COMPLETED WELL [] 7. Permit No. 81-150 Beaver Creek Pad #3 Surface- 1520' FWL, 1420' FNL, Sec. 54, T7N, R10W, SM Top of G' 1980'FNL, 3125'FWL, Sec. 34, T7N, R10W, SM TD: 2118'FNL, 5565'FWL, Sec. 54, T7N, R10W, SM 5. Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. MSL A-.028083 ~2. OTHER [] 8. APl Number s0-155-20346 9. Unit or Lease Name Beaver Creek Unit 10. Well Number BC #6 11. Field and Pool Beaver Creek .Field 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 pePtinent dates, including estimated date of starting an' proposed work, for Abandonment see 20 AAC 25.105-170). It is our intent to perforate and reperforate Beaver Creek Well #6 in the G-Zone on June 7th and 8th, 1982, with 3-3/8"' Vann guns . 4HPF 360© phasing, under drawdown, as follows' ' ' Perforate; 15,085'-15,128' FDC/CNL Reperforate; 15,170'-15,200' FDC/CNL 1S, 003' -15,050' FDC/CNL Verbal approval was received on June 7, 1982, from Russ Douglas (AOGCC) and 'from Joe I)ygas (MMS), by W. J. Laverdure. JUN 1 o i982 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Alaska 0il & Gas Cons. Commission Anchorage Signed ~ ~-t~-~'~' The space below for Commission use Conditions of Approval, if any: Date .. Approved by_ Form 10-403 ORIG!ffA[' SlGltED' I~Y .:.O~t;;lE C. SMITII COMMISSIONER Approved Copy Returned the Commission Date Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA Ct ALASKA(,.-IL AND GAS CONSERVATION MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator COMPLETED WELL [] OTHER [] Marathon Oil Company 3. Address P.O.Box 2380, Anchorage, Alaska 99510 4. Location of Well Beaver Creek Well Pad #3 Surface: 1320'FWL, 1420'FNL, Sec. 34, TTN, R10W, SM Top of G: 1980*FNL, 3125'FWL, Sec. 34, TTN, R10W, SM. TD: 2118'FNL, 3363'FWL, Sec. 34, TTN, R10W, SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. A-028085 KB 185' above MSL 12. 7. Permit No. 81-150 8. APl Number 5o-133- 20346 9, Unit or Lease Name Beaver Creek Unit 10. Well Number BC #6 11. Field and Pool Beaver Creek Field 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 K--'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). SEE ATTACHED 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. RECEIVED JUN ! o B82 Alaska Oil & Gas Cons. Commission Anchorage The space below for Commission use Conditions of Approval, if any: Approved by__ , Form 10-403 ORIGI~At' SlGPlED~ BY LOHHIE C. S~IT]I Approved Copy Returned ' By Order of COMMISSIONER the Commission Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate On May 21, 1982, it was proposed to abandon the non- productive Hemlock perforations at 15,520'-15,546', 15,476'-15,506', 15,414'-15,466', 15,387'-15,407', 15,345'-15,370', and 15,306'-15,326', by setting a thru-tubing bridge plug at 15,280' and setting a 5' sand and 10' cement plug to achieve zone isolation. On May 22, 1982, a thru-tubing bridge plug was set at 15,280' WLM. Five feet of sand and fifteen feet of cement plug were set on top of the bridge plug by May 26. The top of the sand and cement plug was tagged at 15,260' WLM on May 27 and May 28. On May 29, 1982, the plug was tested by observing no flow at 0 psi tubing pressure.' The abandonment was witnessed periodically by J. Russell of Minerals Management Service. Verbal permission for this zone abandonment was re- ceived by D. F. Stover from B. Hauser of Minerals Management Service and L. Smith of Alaska Oil and .. Gas Conservation Commission on May 21,1982. I £C£1v O JUN 1 I$ 2 'Alaska Oil &linChorag~Gas'c°ns' .Co~il~is$ion · . STATE OF ALASKA . {v~/i'~..~..,. ALASKA ( . AND GAS CONSERVATION CO(. ,'IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS' · Drilling well ¢{~ Workover operation [] 2. Name of operator 7. Permit No. Marathon Oil Company 81-150 3. Address 8. APl Number P. O. Box 2380, Anchorage AK 99510 50- 133-20346 4. Location of Well at surface 1320' FWL, 1420' FNL, Sec 34-7N-lOW-SM 5. Elevation in feet (indicate KB, DF, etc.) Est. 150' Above MSL 6. Lease Designation and Serial No. A-028083 A-84 For the Month of, ~RIL ,19. 82 9. Unit or Lease Name Beaver Creek Unit 10. Well No. BC #6 11. Field and Pool Beaver Creek Field .'12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 15,928' TD 859' Drilled during April 13. Casing or liner run and quantities of cement, results of pressure tests Ran 27 its 5" 18#, ?-110 .liner with shoe at 15,889' Cemented with"~50 sks Class G. and'top of liner at 14,681'. 14. Coring resume and brief description NA 15. Logs run and depth where run CBL/VDL ,Gyro Survey FDC/CNL/GR 15,842~-14,681', 12,810'-11,046' Surface -.15,800' 15,826'-14,500' ~16. DST data, perforating data, shows of H2S, miscellaneous data NA 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED_ _ m ' K.A. Thoma TITLE O?eration, s SuperintendentDATE April 30, 1982 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and 'must be filed in duplicate with Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Rev. 7-1-80 . Submit in duplicate STATE OF ALASKA ALASKA(,_,L AND GAS CONSERVATION C ,,AMISSION SUNDRY NOTICES AND REPORTS ON WELLS 2. Name of Operator DRILLING WE LI.~ COMPLETED WELL [] OTHER [] Marathon Oil Company Address P. O. Box 2380, Anchorage AK 99510 Location of Well Beaver Creek Well Pad #3 Surface: 1320' FWL, 1420' FNL, Sec 34, T7N, R10W, SM Top of G: 1980' FNL, 3125' FWL, Sec 34, T7N, R10W, SM TD: 2118' FNL, 3363' FWL, Sec. 34, T7N, R10W, SM 5. Elevation in feet (indicate KB, DF, etc.) J6. Lease Designation and Serial No. USL A-029093 A-84 12. 7. Permit No. 81-150 8. APl Number 5o- 133-20346 9. Unit or Lease Name Beaver Creek Unit 10. Well Number BC #6 11. Field and Pool Beaver Creek Field 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). The proposed completion and-testing, program for BC #6 is: 1. Run cased hole density/neutron log, cement bond log, and gyro survey. 2. Pressure test casing and run a 5" lap test. 3. Run gas lift completion equipment and sting into polished bore receptacle at top of 5" liner. 4. Perforate the Hemlock from 15,347'-15,513'*. 5. Gas lift test the Hemlock for 48 hours or until stabile. a. If the Hemlock. is we~t, pull tubing, P&A the Hemlock, and rerun the gas lift completion equipment before proceeding to Step #6. 6. Perforate the G-Zone from 15,003'-15,050' and 15,170'-15,200'. 7. Gas lift test the combined production until stabile. 8. Run a base production profile log. 9. Gas lift test the well for 60 days and run a production profile log. The estimated starting date for the proposed procedure is 04-22-82. * to be adjusted after density/neutron log ~P~ /tlaska Oil & 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~, ~/~e~, The space below for Commission use Conditions of Approval, if any: Approved Form 10-403 BY LON~IE I~. SMITi~ COMMISSIONER ' APproved i, Eetumed the Commission Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Ouplicate BEAVER CREEK ' , . , KB 185' ---ASL I .... ~ .... . ..... ~ ~-...._~__ · '----.'- ............ ~.-.-:--.--. .......... --4._' ._.L~i_.. ; / ' ~ : J !' ~ , · , ' ........ 't -- - .................. --._~. ', ,.. ,. , , , . ' ...... ~'-"7'" ,-r- ............. ~' .......................... l ~ - . , ' ...................................... i" . , ~ : . t . I . . ' ' . ' ' : , . . ; ' , ~ .. · ' "";'~'"'1' .... , ..........,"T--~' .... ... ..................... . , .. West Forelands ..................... ~._.~5,867 Z,,ID ..... 15 5~4 TV TV depths to be adjusted after gyro April 20, 1982 Ope rat o r Thin-Sections of Core Chips Well Name and Number' Number of Thin Sections Top Interval Represented Bottom Interval Represented Amoco Production Co. Amoco Product ion Co. Albert Kaloa #1'- MGS 17595 #4 1 43 13067 7'342 13068 8611-8612 Ashland Oil Inc. West Channel #1.3 9268 9268 Atlantic Richfield Co. Atlantic Richfield Co. Atlantic Richfield Co. Atlantic Richfield Co. Atlantic'Richfield Co. Atlantic Richfield Co. Atlantic Richfield Co. Atlantic Richfield Co. Atlantic Rich field Co. Atlantic Richfield Co. Atlantic Richfield Co. Atlantic Richfield Co. Atlantic Richfield Co. Delta State #1 Delta St. #2 Gull Island Itkillik River Unit #1 Kavik Unit #3 Kup River State-#1 Prudhoe Bay St. #1 .Sag River State #1 S.E. Eileen State #1 Tooiik Fed. #1 W. Beach St. #2 W. Foreland Unit #3 West Sak River #1 10 39 51 '2 15' 9 22 27 2 4 40 9 3 9367 9418 12576 14716-14717 4945 9232 8821 9220-9230 11003 10355 9507 '9171-9172 9815 9925.5 9518 12799 14724-14739 5440 10509 9868 10013 11009.5 10519 9621 9283-9284 9844 British Petroleum British Petroleum British Petroleum British Petroleum Britisl~ Petroleum British Petroleum British Petroleum British Petroleum British Petroleum British Petroleum British Petroleum- East Ugnu #1 Kemik Unit #2 Niakuk # 1 Prudhoe Bay #G-3 Prudhoe Bay Unit #H-2 Prudhoe Bay Unit #N-1 Put River #J-1 (9-11-13) Put River #33-12-13 Sag Delta #31-10-16 Sag Delta #1 (33-12-16) Ugnu #1 14 29 25 25 11 8 33 4 19 42 5 875O 6160 10861.5 8608 8701 88O0 8540 8959 10332 9253 8408 9744 6224 11639 9317 9246 9155 11568 9256 13865 1021U 9145 Chevron Kavearak Pt. #32-25 18 6908 6967 Colorado Oil & Gas Co. Colorado Oil & Gas Co. Colorado Oil & Gas Co. Core Hole #2 Core Hole #4' Mal-aspina #lA 5 '3 8 4395-4410 5320-5326 4862-4872 5544-5551 5320-5326 13816-13823 File: Beaver Creek #6 On April 21, 1982 the Cc~mission met with Marathon representatives Dan Stover, Mr. Campbell, and Guy Gadonsky. The meeting concerned cc~mingling of production of the Hemlock and "G" zones in Beaver Creek #6. The producing pool at Beaver Creek has not been defined. A hearing would have to be held to define the pools before cc~ningling could be approved. Prior to cc~mingling the Cc~ission could approve a production test to determine Hemlock and "G" zone productivities. Attached are notes frcm the meeting and a wellbore schematic of~Creek #6. ~.d.Wr 7 1~ 7oo'$5 ) ) .... 9-5/8" casing shoe , . ................. ~ ...... ~ ........ ~ ..... .... ' ' "._ },'....!.~J...!iner. shoel .......... ..... i ................... : ........................... [ ....... ". ....... : ....... ', ...... ! ..... .~....~ ~.. Lower Main G-Zone ........ ~_,. '~ ...... ~ ..... · ................ r ........ T ....... · '" '.. ........ ............ · T:~>-'~-.--- Hemlock ............ ~'~ ~. Wese Forelands · . . 5" liner shoe .......... 11,446 MD '. .............. .............. , ....... 'f2"i'~'iO'"~ .... :. ","':':'"':":':-':": .... : .................... i , · ' F .............................. " ............ ~ .................... ............. ' ...... 1' .................. ' ........................................... ~ ........................... .... , .............. *' ....... I :T''''- ''4 ............... '~ ................................ ~ .......... ~ '+'- ............ '~---~ I " : ' , , '",. ~ I ' i ~ . . ' ' ~= 002 MD " ! "~' ........... i .......................... ~, . ......... ,~ ....... : ...................... , , , , , , . .......... : ....... : ....... : ..... : ........... : ....... ,. ...... ....... ,. ....... ............. - .......... , ~ , , i ' ! .... ! . . · ................................. i ...................... . ' I i ........ · ....i ....................... ................. ~: .... ; ..... : ............... .i ................ : ........i .................... : · ..~ ..., ........................... ' . ...... .1 ................................... ....... ~.__15,347 MD . .... i ...... ~... ~ .....: ............ : .......... i ...... ~ ........ ..................... ,..--~ ...................... i ...... } ............... ' ...... ; ................. ! ............ 1 ............................. , ........................ - ................... " i ........................ ! .................... i..:: ..................... ~ ................ .., ; i ......................... : .......... , ..... :.. ¢...~ ........................... .! ....... T ........................................................................................ ...... !, 1.5,867 ............... ~ ................... ..... i .............. '.' i I 15,889 MD . . i t ' ................... ~... ' :. 2 i ': : ~ ................... '~ ................. ! '.. . ............... ......... r ....... ~ .............. STATE OF ALASKA ALASKA { . AND GAS CONSERVATION cq[~ MISSION SUNDRY NOTICES AND REPORTS ON W =LL$ DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 2380, Anchorage, AK 99510 4. Location of Well Beaver Creek Well Pad #3 Surface: 1320' FWL, 1420' FNL, Sec. 34, T7N, R10W, SM Top of G: 1980' FNL, 3125' FWL, Sec. 34, T7N, R10W, SM TD: 2118' FNL, 3363' FWL, Sec. 34, T7N, R10W, SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KB 185' above MSL I USL A-029093 A-84 12. 7. Permit No. 81-150 8. APl Number 5o-133-20346 9. Unit or Lease Name 10. We{{ Number BC #6 11. Field and Pool Beaver Creek Field 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 SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] 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). Based upon open hole log correlations, it is proposed to drill Beaver Creek #6 to a revised total depth of 16,000' MD, 15,667' TVD 'in order to enable complete testing of'all potentially productive zones. The well was formerly permitted to a total depth of 15,860' MD, 15,494' TVD. Verbal approval of the revised depths was received from R. Douglas by D. Stover on April 12, 1982. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. RECEIVEO APR 1 6 1982 AJaska Oil & Gas Cons. Commission, Anchorage The space below for Commission use Conditions of Approval, if any: Title Operations Superintendent Approved Copy Date Approved b~/ Form 10-403 Returned BV Order of COMMISSIONER the Commission Date Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA :FNDGAS CONSERVATION CO '" JSSION ALASKA MONTHLY REPORT DRILLING AND WORKOVI=R OPI=R_4_TI_ · Drilling well Workover operation [] 2. Name of operator Marathon Oil Company 3. Address P. O. Box 2380, 4. Location of Well at surface 1320'FWL, Anchorage AK 99510 1420'FNL, Sec 34-7N-10W-SM 5. Elevation in feet (indicate KB, DF, etc.) Est. 150' Above MSL 6. Lease Designation and Serial No. A-028083 A-84 7. Permit No. 81-150 8. APl Number 50- 133-20346 9. Unit or Lease Name 10. Well No. BC .#6 11. Field and Pool Beaver Creek Field For the Month of MARCH ,19 82 !.12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 15,069'TD 261' Drilled during March 13. Casing or liner run and quantities of cement, results of pressur9 tests Ran 73 jts 7" liner w/ shoe @ 14,980', toD_ @ 12,024'. Cmtd w/ 65'0 s~ Cl G. Unable to get lnr lap seal @ 12,024' so ran 15 jts tie-back lnr. Cmtd w/ 170 sx C1 G & successfully dry tstd lnr lap @ 11,~46'. · 14. Coring resume and brief description NA 15. Logs run and depth where run DIL/SP/GR from 14,876' - 12,410' BHC Sonic/GR 14,876' - 12,410' FDC/CNL/Caliper 14,876'- 3,810' .16. DST data, perforating data, shows of H2S, miscellaneous data NA RECEIVED. APR 0 5 1982 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Alaska Oil & Gas Cons. Commission Anchorage SIGNED . K. A. ThO~LE..Operations Suoerinten~h~t April 2, 1982 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 Rev. 7-1-80 Submit in duplicate · STATE OF ALASKA ALASKA ("' . AND GAS CONSERVATION C(]['"' 'VllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well I~X 2. Name of operator Workover operation [] Marathon Oil Company 3. Address P. O. Box 4. Location of Well at surface 2380, Anchorage AK 99510 1320'FWL, 1420'FNL, Sec 34-7N-10W-SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Est. 150' Above MSLI A-028083 A-84 ,19 82 For the Month of. FEBRUARY 7. Permit No. I-'~'~ 81-150 8. APl Number J~/ 50- 133-20346 9. Unit or Lease Name Beaver Creek Unit 10. Well No. BC #6 11. Field and Pool Beaver Creek Field '12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 14,618'TD 2,360' Drilled during February 13. Casing or liner run and quantities of cement, results of pressur9 tests Ran and cemented 9-5/8" casing with shoe @ 12,410'. 14. Coring resume and brief description NA 15. Logs run and depth where run SP/DIL/GR from loggers TD @ 12,405' to 13-3/8" shoe Sonic/GR/Caliper from loggers TD @ 12,405' to 3800' Density/Neutron/Caliper from 12,410' to surf @ 4022' ,1 6. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. RECEIVED MAR 0 5' 1982 Alaska Oil &An.h..._':Gas Cons Cor~is%~' ,, SIGNED .... TITLE' '~'/~,~",~,,~, ~c:~(~4~-T~ DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate With~th'e Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Rev. 7-1-80 Submit in duplicate STATE OF ALASKA ALASKA {r" _ AND GAS CONSERVATION C(](" MISSION MONTHLY REPORT OF DRILLING AND WORKOVER _ · Drilling well [KIX Workover operation I-I 2. Name of operator Marathon Oil Company 3. Address P. O. Box 4. Location of Well at surface 1320 'FWL, 2380, Anchorage AK 99510 1420'FNL, Sec 34-7N-10W-SM Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Est. 150' Above MSLI A-028083 A-84 7. Permit No. 81-150 8. APl Number 50- 133-20346 9. Unit or Lease Name Beaver Creek Unit 10. Well No. BC ~6 11. Field and Pool Beaver Creek Field For the Month of, JANUARY ,19. 82 · 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 12,258'TD 2,814' Drilled during January Successfully fished stuck drill pipe from 10,913'. Resumed drilling with no adverse effects. Presently drilling ahead. 13. Casing or liner run and quantities of cement, results of pressure tests NA 14. Coring resume and brief description NA 15. Logs run and depth where run NA .1 6. DST data, perforating data, shows of H2S, miscellaneous data NA YlE, I~', ,,' - 1982 Naslm Oil & Gas Cons. C~mmJssloa A~chorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. D.~~' ~. Operations SIGNE K.A. Thoma TITLE Superintendent DATE Februar_~ 2, [982 . NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate withthe Alaska" Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed.. Form 10-404 Submit i~ duplicate Rev. 7-1-80 , STATE OF ALASKA ALASKAC( AND GAS CONSERVATION CO( IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATI_ N . ,. Drilling well ~ Workover operation [] 17 2. Name of operator Marathon Oil Company 3. Address P. O. Box 2380, 4. Location of Well Anchorage AK 99510 at surface 1320'FWL, 1420'FNL, Sec 34, T7N, R10W, SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Est. 150'KB ahov~ MST.I A-028083 A-84 7. Permit No. 81-150 8. APl Number s0- 133-20346 9, Unit or Lease Name Beaver Creek Unit 10. Well No. BC #6 11. Field and Pool Beaver Creek Field For the Month of,, DECEMBER ,19 81 :12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 9444'TD 6334'Footage drld 12-01-81 - 12-31-81 No significant problems during the month Of December, 1981. 13. Casing or liner run and quantities of cement, results of pressur~ tests 13-3/8" casing set @ 4022'. Cmtd w/ 2400 sx cmt. Press tstd csg shoe to 14.0 ppg equiv. 14. Coring resume and brief description NA 15. Logs run and depth where run NA ,16. DST data, perforating data, shows of H2S, miscellaneous data NA RECEIVED, JAN- 4 1982 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Alaska 011 & Gas Cons. C0mnlissi0n Anchorage . ~__,,~. ~,~ Operations :SIGNED - K. A. ThOmaT~TLm Superintendent DATE 12-31-81 '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 Rev. 7-1-80 Submit in duplicate { "L,, STATE OF ALASKA ' ALASKA ~LAND GAS CONSERVATION C(~,,dMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 2380, Anchorage AK 99510 4. Location of Well At Surface: Beaver Creek Well Pad #3 7. Permit No. 81-150 12. 8. APl Number 50-- 133--20346 9. Unit or Lease Name Beaver Creek Unit 1320' FWL, 1420' FNL, Sec 34, T7N, R10W, SM lO. Well Number At top of proposed producing interval: BC #6 2100' FEL, 1800' FNL, Sec 34, T7N, R10W, SM 11. Field and Pool At total depth: 1800' FEL, 1860' FNL, Sec 34, T7N, R10W, SM Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Estimated KB 1~0' above MSLI USL A-028083 A-84 Beaver Creek Field 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). It is proposed tO: (1) Drill Beaver Creek Well #6 to a revised total depth of 15,860' MD; 15,494' TVD - an increase in depth of 630' MD, 594' TVD as compared to the original permit, and (2) Revise the casing program to include a 5" liner. The 7" liner setting depth would 'thus be reduced from 15,230' MD/14,900' TVD to 14,900' MD/14,587' TVD. The 5" liner is expected to be 18#/ft, P-110 Hydril FJ, and will extend from 14,700! MD, 14,399' TVD to 15,860' MD, 15,494' TVD. Estimated cement volumes are approximately 650 sacks for the 7" and 120 sacks for the 5". Other parameters and conditions of the original permit will remain unchanged. The purpose of the above changes is to enable the testing of additional intervals which were not anticipated initially. R E C E ~ VE D~ %C, scquent Wor]~ Reported JAN- 4 1982 on Form No ..... Dated , / /~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge, aia~[ 0ii & Gas Cons. C0amjssi01t Signed ' Title Operations Superintendent Date Dec. 18, 1981 The space below for Commission use Conditions of Approval, if any: Approved ORIG'NA[ SIGNED Returned .... - °' .... . COMMISSIONER the Commission Date .............. Form 10-403 Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate MONTHLY REPORT F DRILLING AND WORKOVEROPERATIONS · Drilling well Workover operation [] 2. Name of operator Marathon Oil 3. Address Company P. O. Box 2380, Anchorage AK 99510 4. Location of Well at surface 1320'FWL, 1420'FNL, Sec 34, T7N, R10W, SM 6. Lease Designation and Serial No. A-028083 A-84 5. Elevation in feet (indicate KB, DF, etc.) Est. 150 'KB 7. Permit No. 81-150 8. APl Number 50- 133-20346 9. Unit or Lease Name Beaver Creek Unit 10. Well No. BC No. 6 11. Field and Pool Beaver Creek Field For the Month of. November ,19 81 '12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1030 hrs, 11-19-81. Depth as of 0700 hrs, 11-30-81: 3110'MD 13. Casing or liner run and quantities of cement, results of pressur9 tests 20" casing set @ 502'. Cmtd w/ 1500 sx cmt. Press tstd csg shoe to 12.6 ppg equiv. 14. Coring resume and brief description N/A 15. Logs run and depth where run N/A 16. DST data, perforating data, shows of H2S, miscellaneous data N/A RECEIVED;. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. DEC- 2 1981 Alaska 0il & (;as Cons. Commission.' A~ch0rage Operations .. Superintendent 11-30-8 1 SIGNED_ ' TITLE DATE F 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 direc:~ed. orm 10-404 Rev. 7-1-80 Submit in duplicate' September 30, 1981 }~r. ~e A. Thoma Operations Superintendent Marathon Oil. Company P. O. Box 2380 Anchorage, Alaska 99510 Re ~.. Beaver Creek.. Unit, Be' No.. 6 Marathon Oi.1 .Company permit No. 81-150 Sur. Loc.~ 1320mF~L,. 1420~FNL, Sec 34, TTN, R10W, SM. Bottomhole Loc. ~ 2000'FEL, 1820'FNL, Sec 3.4, TTN, R10W, SM. .Dear .Mr. Thoma ~ . , Enclosed is the a'ppr°ved application for permit to 'dri'11 the above referenced well. · Well samples and. a mu~ log are not r~quired. A directional . survey is required.. If available, a tape .containing the digitized log 'information shall be submitted on all logs for. copying except, experimental log.s, velocity surveys and' dip.meter. 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, Ala.ska 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 1'8, 'Alaska. Administrative Code, Chapter 70) and by t'he Federa! Water Pollution Control Act, as amended. Prior to Mr. K. Ao Thoma Beaver Creek Unit, BC No.6 -2- September 30, 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 within 48 hours after the well is spudded. We would also like to be notified so lthat a repre- sentative of the Commission may be present to witness 'testing of blowout .preventer equipment before surface casing shoe is drilled. In 'the. event of suspension o= abandonment, please give this office adequate advance notification so that we may have a witness pr~s.ent. Very truly yours, Hoyl ami !ton. Chairman of 'BY ORDER' OF' TW~ Cor, lUIS$10H Alaska Oil & GaS Conservation Commission Enclosure cc: Department of Fish & ~ame, Habitat Section w/o encl, Department of Environmental Conservation W/o/eno1. September 24, 1981 Mr. K. Ao Th oma Operations Superintendent Marathon Oil Company P.O. Box 2380 Anchorage, Alaska 99510 Dear ~,r. Thoma: Enclosed. is Marathon's check for $100 that accompanied the permit application for the Beaver Creek Unit #6 well. Please return a check for $100 made payable to the "Department of ~eVenue." For your information the name of our agency is the Alaska Oil and Gas Conservation Commission. The Alaska, Division of Oil and Cas Conservation is no longer .in existence. Sincerely yours, Ancl~' .ge Division ProducL1on Operations, U.S. & Canada Marathon Oil Company P.O. Box 2380 Anchorage, Alaska 99510 Telephone 907/274-1511 September 17, 1981 Mr. L. C. Smith Alaska Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage AK 99501 BEAVER CREEK WELL No. 6 Enclosed is our Application for Permit to Drill for the subject well'.' Accompanying this application is our check for $100 for filing fees. If you require any additional information, please contact me. KAT: jmo Enc I osures Operat ions Superintendent STATE OF ALASKA~ " ALASKA [,.~ AND GAS CONSERVATION CCI,..MISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work. DRILL )~ lb. Type of well EXPLORATORY I-] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL~ SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator Marathon 0il Company 3. Address P. O. Box 2380, Ancho._..r._a_ge AK 99510 4. Location of well at surface Beaver Creek We I I Pad ~3 9. Unit or lease name 1320'FWL, 1420'FNL, Sec 34, TTN, R10W, SM Beaver Creek Unit At top of proposed producing interval 10. Well number 2100'FEL, 1800'FNL, Sec 34, T7N, RIOW, SM BC #6 At total depth 11. Field and pool 2000'FEL, 1820'FNL. Sec 34. T7N: RIOW. SM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. Est. KB 150'..MSL USL A-028083 A-84 Beaver Creek Field 12, Bond information (see 20 AAC 25.025) Type B I an ket Surety and/or number B-2-16~5-724-1 Amount . 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nee{est drilling or completed 11.5 mi, NE of Kenaimiles 2100'FNL feet well 1600 feet 16. Proposed depth (MD & TV D) 171'~mber of acres in lease 18. Approximate spud date 15.230'MD. 14. 900 tTVl~eet 2560 11-(31-~1 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures /-t~7~"~ psig@ -- Surface. KICK OFF POINT 8500 feet. MAXIMUM HOLE ANGLE 1 8°°~,(~ee 20 AAC 25.035 (c) (2) ~'J~OO ~ psig@~.~ft. TD (TVD) Proposed Casing, Liner and Cementing Program .. SIZE CASING AND LINER SETTING DEPTH QUANTJ'T-~. OF CEMENT Hole Casing Weight Grade Coupling Length MD , TOP TVD MD BOTTOM TVD (include stage data) _~0" 309.72 13 75 Surface 75~, 75 . 26" 20" 133 K-55 Vetco-I 500 Surface 5001 500 Approx 800 sx 17-1/213_3/8,, 68/72 K55/N8CButt 4000 . Surface 40001 4000' Approx 2900 sx 12-1/4 9-5/R" 47/53.!N-80/P-liO.Bu,~t12500 Surface 125001 11960 Approx 3000 ex' (2 s~ 7,, 32 P-110 X-line ' 2900 12330,~, 11810 1523011 14900 Approx 700 8-1/2 SX' 22. Describe proposed program: BC ~/6 will be directionally drilled to an estimated total depth of 15,230'MD; 14,900'TVD. The Well Program is attached. Also attached are the following documents: Blowout Prevention Equipment Systems Structure Map , Directional Program 'SEP Location Layout The existing drilling pad will be used (BC 3); no pad extens.ion, is~k~nO~le~Gasc°ns'c°mmissiOn Anchl~lllal~3~e are .no wellbores within 200' of the proposed wellbore other .than vertical portions of existing wells BC 5RD and BC 3. 23. I herebv certify that the foregoing is true and correct to the best of my knowledge . SIGNED /~ ~ K. A. THOMA TITLE 0perat ions Superi ntendeneATE "9/I 7/81' ~ The space b~lo~ ~'or Commission uscV~'l~'~'~, CONDITIONS OF APPROVAL · Samples required Mud log required Directional Survey required I APl number []YES ~JO F]YES [~NO ~,Y ES []NOI Permit number Approval date oOj--/~ SEE COVER LETTER FOR OTHER REQUIREMENTS 13q/.30/81_ BY....~~~~~~~~~~~ ' ,COMMISSl ONER DATE =qe[~_e_m___l~__~' ~13; 1 qB1 APPROVED by order of the Commission 'g) Form 10-401 Submit in triplicate Rev. 7-1-80 MARATHON OIL COMPANY WELL PROGRAM Well Field Beaver Creek No. 6 Beaver Creek Field Coord i nates: Surface 1320'FWL~ 1420'FNL~ Sec 34~ T7N~ RIOW~ SM Top of Objective 2100'FEL~ 1800'FNL~ Sec 34~ T7N~ RIOW, SM KB Elevation Est. 150'MSL Ground Elevation MSL Total Depth 14~900' TVD 15~230' MD Avg. Angle 18° 57' Course.S79°E GEOLOGICAL PROGRAM Estimated Fm Tops MD TVD B-2 5~035' 5~035' B-4 5,225' 5~225' BC 8,095' 8~095' Main G 14~913' 14~600' Hemlock 15~198' 14~870' Estimated Total Depth 15~230' 14~900' Coring Program No cores will be cut. DST Program Logging Program: Conductor Surface No open hole DST's will be run. Not applicable. Not applicable. I ntermed iate or Production Run SP/GR/DIL~ Sonic/Caliper/Density/Neutron~ Gyro Liner Well Program Page 2 Conductor DRILLING PROGRAM Drive 30" conductor to 75'KB. Drill 17-1/2" hole to 500'KB and open to 26". Set 20" casinq. Surface Drill 17-1/2" hole to 4000'KB and set 13-3/8'" casinq. I ntermed i ate or Production Drill 12-1/4" hole to 12,500'KB and set 9-5/8" casinq running a staqe collar at 6000'KB. Liner Drill 8-1/2" to 15~230'KB and set 7" casinq. DIRECTIONAL PROGRAM Kick off at 8500' and build angle to 18°57' along a course S79°E and hold to TD. Size 30" 20" 13-3/8" 9-5/8" CASING PROGRAM Hole Set At Wt. Footage Grade Thrd S i ze 75' 309.72 75' B 500' 133 500' K-55 Vetco-L 26" · 5~500' 68/72 4,000' K55/N80 Butt 17-1/2" 12~500' 47/53.5 12,500' N-80/P-IIO Butt 12-1/4" WOC T i me Cement 800 sx 2900 sx 3000 sx - 2 stages Liner 7" 12330'-15230' 32# 2900' P-110 X-line 8-1/2" 700 sx MUD PROGRAM From To Wt. Vis. W.L. pH Type Mud O' 4000' 9.5-10.0 60-120 Gel/Benex 4000' 12500' 10.0-11.5 50-70 Gel/Li§no 12500' 15230' 10.5-12.5 50-70 Gel/Ligno Treatment Remar ks: COMPLETION PROGRAM Run a DST lap test~ run a CBL across zones of interest, run gyro from TD to surface. Set a permanent packer above G Zone and complete with lift equipment. RECE,vcu SEP 2 198I BLOWOUT PREVENTION EQUIPMENT SYSTEMS Diverter System The diverter system will consist of a 20" x 2000//, Iow pressure, annular preventer and a 8" diverter flow line utilizing a full-opening hydraulically remote control led valve that will automatically open when the diverter is closed. The diverter line will branch out into two 8" lines after leaving the sub-structure. These lines will be oriented in two different directions in relation to the prevailing wind. Each vent line will have a full opening butterfly valve, which will be pinned in the open position and labeled to insure it stays open. In the event of diversion operations, the upwind vent line will be closed off manually, al lowing the control led diversion of gases down wind. If there is no wind, both vent lines will remain open. The butterfly valves will be checked daily by the drilling supervisor to insure they remain in an open position. The diverter system will be used while drilling below the 20" casing. After setting 13-3/8" casing the system outlined below will be instal led. See diagram #1. Blowout Preventer Stack System The blowout prevention equipment will consists of two (2) each 13-5/8" pipe and one (I) each blind ram hydraulic preventers (5000 psig WOG) and a 13-5/8" Hydril annular type preventer (5000 psig WOG). See diagram #2. The ram-type preventers will be tested to the rated 'working pressure of the stack assembly or to 70 percent of the minimum internal yield pressure of the casing, whichever is lesser. The annular-type preventer will be tested to 70 percent of the rated working pressure. The equipment will be tested when it is instal led, before drilling out after each string of casing is set, not less than once each week while drilling, and following repairs. The U.S. Geological Survey, Deputy Conservation Manager for Onshore Field Operations will be notified prior to the testing procedure so that a representative may witness the test. The blowout preventers will be actuated daily and once each round trip. A blowout prevention drill will be conducted weekly for each drilling crew. All drilling personnel will be familiar with the blowout prevention equip- ment before starting work on the well. Supervisory, as well as other required drilling personnel, will post their current certification for blowout prevention training at the well site. RECEIVED SEP 2 3 1981 Alaska Oil & Gas Cons. Commission Anchorage "i REEEiVED SEP 2 3 1981 Gas Cons. Commissiou Anchorage i-5~'x sooo" AN NU. LAR, 5000 ~o~tbL~ ~^Ts Pipe Rc~w,s ~ F5 ,s'S x 5ooo~ 5ooc::,* ~ l-''! PRF. vm~"roe, ~ sooo '"! L ,5" x 50o0~-'~ U N IT ,~ 4~ 760 ACRES · , . ANCHORAGE DIVISION BEAVER CREEK FIELD RECEIV STRUCTURE MAP SEP TOP OF MAIN"G" ZONE 5AND ~chomgo ,. .. . SURFACE . . TMD '- 0 TVD = 0 ' ' ' DEP'-O .... . . BEAVER CREEK 6 _AEE 1712 _. SCALE: = 2000' .....................i ' ..... i .... - ....I~ .... '--+. ............ :-- '~ ............... ~ ~ ....... -.-t ...... ~:- · t"351". .... suP~^c~:"~:"'!: ....... : ............ ; .... ! ............... -:- "' ' ..... i ................................... '! ........,320'FWL .... :-i ........ : .................... ::J":'":': ....... --'i .............. 4()00- TMD ". ' - ......... .; 1420 FNI; ....... ! ,---~--' ............. , ~-' .......... : :...~... :::-: :._ :-i-~':.':., ............ -"~ ........... : ....~ ~ ..... L.~. 20oo" EEL--- .......... :i :.__.- ...Z_~_ : : : ..................................... : '_ -' "! '- '- ......... I-- 1820' F'NL .... I I "° ' t ., , i ..................... t ........................... . i .:__:::.:::: :..:_::...::: .:_:-------'-- ....... _:_,":.::_:_::-.,_'._'.::'L:.-': ......... :_::.:_:" '~._ ......... TMD=9431 :I ' - I ....... - ..... ...................... ~:. ~ ' ?.. ............. .::._ ; :. .........: ;"' .......... '. .......... i i!:i: :! ii !_ }:-..-'.~.~i !iii i !! i:'i!!': ::--:'::' !'': :'-':"-:':: -' ................ ~ ' 'DEP :150 : - ..... ........ · ; I ·t . ....... J ........ - ~.--~ . f ........... w ................ I ......................° ............... 'f''i ::: :' :': :'i'" ": ,'~0~ +"~': i ......... ~ ........ --! .......... ... ............ ~ .................. i :::-:-:: :..::: i-- ': :.: :': :I::::: ::-:: 1 ::': :':: '-: ~. :---:--.1 ........ '-"-: ........ ,- ........ : ............... 1 i~ · ~ ........ I, ............... .' ......... .: ........... ~ ............... ~-- · .- ................ .........................~ ? --::.-' .. :'!..r.--:-.-----'-:I .......... i ................. ~ ........... : ........... ~ .... 2. 2:..- ! · _ o ~ ....... I TARGET .......... ~. .... . ..... !.. ........ i° . ............. · ............... .......... ~ ....... TM ~ = !4¢!5 ................. '.' ..................... ..... I ' ' ' T¥~14500 ..... : ....... .: : ......... ........... · :'' i''.X..'' ~[P=mOO --' ..... , --~.-- -- · · .-... TB .............. - ............................. T~B -' 1§~50 .... ' ...... - ......... ' TVD'-14~O0 ' ' ' ' ..... - . . · . ~ · . . · . · D£~'-- 2000 ' ' ' . AVERAGE ANGLE = 18`0 57' .......... SECTION VIEW'- S?9~E ........... RECEIVED SEP 2 3 198! Alaska, 0it & Gas Cons. Commission Anchorage i.- , r' .... : ......... ; .......l :.':".,:": ,:'.: :. I,"' i- ! · . : '!' CHECK LI'ST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE .... /E'2 thru 8) 1. Is the permit fee attached .............. 2. Is well to be located in a ool 3. Is well located proper distance from property line 4. Is well located proper distance from other wells . . 5. Is sufficient undedicated acreage available in this pool .. 6. Is well to be deviated and is well bore plat included ..... 7. Is operator the only affected party ....................... 8. Can permit be approved before ten-day wait ................ (3)' Admin ~.(::,,~:' ~' %'~'-.~, ! 9. (.9/thru 11) · 10. 11. (12 thru 20) 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. (5) BO PE l~.~-~_~_~,~. ~/Z-M.]I~I' -(21 thru 24') (6) Ad d: ~_ ~/,?-EI/,I~( 2 5. eeee®eele eeeeeeell eeeelleee YES NO Does operator have a bond in force ............... Is a conservation order needed .... ~ J !221 2 i2iiiiii i 2 1 Is administrative approval needed .. [.[ ...'.''' . .. ~ ~'.''. Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ................ · ..... Will surface casing' protect fresh water zones ..... Will all casing give adequate safety in collapse, ;g2;~;~ i~'~g;~-;.. 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 of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ,~-o~d) psig ..~__ Does the choke manifold comply w/API RP-53 (Feb.78) .................. 'Additional requirements Additional Remarks: G.eol ogy: Eng in~er,.ing: ' . JAL ~.~..,. rev: ";03/10/81. INiTIA'L GEO'. UNT'r ON/OFF POOL CLASS STATUS AREA NO. SHORE , --
