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Home My WebLink About198-1421a. 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): GL: BF: Total Depth: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- TPI:x- y- 12. SSSV Depth MD/TVD:20. Thickness of Permafrost MD/TVD: Total Depth:x- y- 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: 23. BOTTOM 20"K-55 52 13-3/8"N-80 & K-55 4,343 9-5/8"S-95 11,817 7"S125 13,032 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 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, 8-1/2" DEPTH SET (MD)PACKER SET (MD/TVD)If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd):N/A SIZE 12-1/4" TUBING RECORD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 12/1/2021 198-142 / 319-192 50-133-20375-90-00 Wolf Lake 2 Fee CIRI 84-201 1183' FSL, 2265'FWL, Sec. 29, T7N, R9W, SM 2621' FSL, 488' FWL, Sec. 29, T7N, R9W, SM 8/28/20023800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 9/4/2002 Surface 35' HOLE SIZE AMOUNT PULLED suspension, or abandonment, 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 if necessary 2436055339056.1 1285' FSL, 2236' FWL, Sec. 29, T7N, R9W, SM BOTTOM 26" TOP 0 13,391 / 13,039 CEMENTING RECORD 17-1/2"0 339028.5 337283.6 TOP SETTING DEPTH MD 0 N/A SETTING DEPTH TVD 0 4,344 133 68 & 72 52 0 12,15147 & 53.5 13,383 0 11,5013211,826 Water-Bbl: PRODUCTION TEST N/A CASING WT. PER FT.GRADE Oil-Bbl: Per 20 AAC 25.283 (i)(2) attach electronic information Flow Tubing Sr Pet Eng Wolf Lake / Beluga-Tyonek Undef Gas Pool N/A Oil-Bbl:Water-Bbl: Date of Test: 2436157 2437521 Zone- 4 Zone- 4 Zone- 4 Sr Res EngSr Pet Geo N/A Gas-Oil Ratio:Choke Size: d 1 0 p dB fi L atttttacched Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Meredith Guhl at 2:52 pm, Jun 03, 2022 xG Abandoned 12/1/2021 MDG RBDMS 6/3/2022 MDG DSR-6/6/22SFD 8/12/2022BJM 11/30/22 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 7,010 - 7,038 6,975 - 7,003 31. List of Attachments: Wellbore Schematic / Well Operations Summary / P&A Photos 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Dan Marlowe Contact Name: Chad Helgeson Operations Manager Contact Email:chelgeson@hilcorp.com Authorized Contact Phone:907 777-8405 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: If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS 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, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at total depth: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, 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). INSTRUCTIONS Authorized Name: Authorized Title: Signature w/Date: 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). 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. 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. 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. Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2022.06.03 10:14:56 -08'00' Dan Marlowe (1267) Lease: State/Prov:Alaska Country:USA Angle/Perfs:11°-18° 226' 21' 2/16/2020 12/27/2021 CIRI (84-201) County or Parish:Kenai Peninsula Borough Angle @KOP and Depth:1º @ 5,700'Maximum Deviation:26.1º @ 8,400' Well Name & Number:WOLF LAKE #2 Date Completed:9/9/2002 Ground Level (above MSL): RKB (above GL): Revised By:Chad Helgeson Downhole Revision Date: Schematic Revision Date: WL - 2 Wolf Lake Pad 1,183' FSL, 2,265' FWL, Sec. 29, T7N, R9W, S.M. PBTD 0' MD 0' TVD 13 18 I Liner 7" S-125 32 ppf BTC Top Bottom MD 11,826' 13,383' TVD 11,501' 13,032' A Production Casing 9-5/8" S-95 53.5 ppf BTC 9-5/8" S-95 47 ppf BTC Top Bottom MD 0' 12,151' TVD 0' 11,817' Perforations: MD TVD Ft Zone SPF Date 6,095'-6,110' 6,090'-6,105' 15' Beluga 5 9/05/02 6,166'-6,176' 6,160'-6,169' 10' Beluga 5 9/05/02 6,202'-6,210' 6,195'-6,203' 8' Beluga 5 9/05/02 6,356'-6,379' 6,346'-6,368' 23' Beluga 5 9/05/02 6,392'-6,420' 6,381'-6,408' 28' Beluga 12 10/20/98 6,454'-6,466' 6,441'-6,453' 12' Beluga 5 9/05/02 6,506'-6,520' 6,492'-6,506' 14' Beluga 5 9/05/02 7,010'-7,038' 6,974'-7,001' 28' Tyonek 12 10/25/98 7,398'-7,468' 7,344'-7,411' 70' Tyonek 5 9/13/02 Casing Cementing Casing Lead Tail 20" 250 sx 13-3/8" 2445 sx 9-5/8" x 13-3/8" Annulus 300 sx 15.8 ppg 9-5/8" 700 sx 13.5 ppg 300 sx 15.8 ppg 7" 900 sx 15.8 ppg TD 14,451' MD 14,086' TVD Permit #: 198-142 (Re-Entry) API #:50-133-20375-90 Prop. Des: CIRI (84-201) KB elevation:247' (21' AGL) Spud:11/10/1984 TD:2/01/1985 Rig Released:2/22/1985 Tubing (LS) 2-7/8" L-80 6.5 ppf 8RD Top Bottom MD 0' 7,151' TVD 0' 7,109' Surface Casing 13-3/8" N-80 72 ppf BTC 13-3/8" K-55 68 ppf BTC 13-3/8" L-80 72 ppf BTC Top Bottom MD 0' 4,344' TVD 0' 4,343' Conductor Casing (Cemented) 20" K-55 133 ppf Top Bottom MD 22' 52' TVD 22' 52' FINAL P&A SCHEMATIC B LS Tree cap = 3-1/2" 8RD SS Tree cap = 3-1/2" 8RD Dual Cameron Hanger (14.4' RKB) LS Lift Threads = 3-1/2" 8RD SS Lift Threads = 3-1/2" 8RD 20" 13-3/8" 9-5/8" 7" Tyonek Perfs C 12 Tubing (SS) 2-3/8" L-80 4.6 ppf IBT Top Bottom MD 0' 6,010' TVD 0' 6,007' Jewelry (Long String) Depth ID 1.Top of 2-7/8" Tubing stub 5,731' 2.441" 1A. Cement Retainer w/ 58 bbls of cement 5,957' - below retainer 2.Baker 9-5/8" GT Dual Packer (shear at 70k) 5,991' 2.939"3. 2-7/8" Sliding Sleeve 6,037' 2.313" 4.2-7/8" X-Profile 6,077' 2.313" 5.Top of Blast Joints 6,088' 2.441"6.Btm of Blast Joints 6,527' 2.441" 7.Baker 194-32 DB Permanent Packer 6,861' 3.250"8.2-7/8" X-Profile 6,910' 2.313" 9.Top of Blast Joints 7,004' 2.441"10.Btm of Blast Joints 7,044' 2.441"11.Balanced Isolation Tool 7,110' 2.441" 12.TCP Firing Head 7,143' 2.441"13.WLEG 7,151' 2.441" 14.4-5/8" TCP Guns & Blank Spacer Guns 7,752' - 15.4-5/8" TCP Guns (36') & 10' 1-1/4" drop bar 8,023' - 16.Baker '6AA' CIBP 8,069' - 17.Old 12.0 ppg mud 8,070' - 18.Cement plug 11,385' - 19.EZSV Cement Retainer 11,485' - 10 8 7 Jewelry (Short String) Depth ID A. Top of 2-3/8" Tubing stub 5,729' 1.995" B.Baker 9-5/8" GT Dual Packer (shear at 70k) 5,991' 2.939" C.2-3/8" XN profile 6,008' 1.810" D. 2-3/8" WLEG 6,010' 1.995" Last tag on 2/2/20 was at 6,008'. 19 17 16 Tag Fill 2.0" DD Bailer 7,474' RKB 10/21/02 Beluga Perfs D 1 1A 2 3 4 5 6 9 11 14 15 Cleanout Fill 1.50" Coil 6,530' CTM 2/06/03 9-5/8" TOC Unknown P&A Plugs & Cement Depth I. CIBP w/ Cement to Surface 160' II. CIBP w/ 43 bbls of Cement on top 4,494' (TOC @ 3,849' on 2/14/20) III. 9-5/8" EZ Drill SVB squeeze packer 5,983' (Tagged TOC @ ~5,241' on 2/11/20) II III Good Cement: 3,300' - 4,100' Questionable Cement: 4,100' - 5,100' Ultrasonic Imager (10-16-98) Tyonek Perfs Casing Punches: 4,230' - 4,234'4,489' - 4,493' Casing Punches:155' - 159' Rig Start Date End Date 10/23/19 12/1/21 12/13/2019 - Friday MIRU SLB CTU 13 with 1.75" CT. Load 300 bbls of water in open top tank. Test 4-1/16" Quad BOP's to 250/3,500 psi for 5 minutes each. 24 Hour test witness notification sent to State on 12/12/19 @ 14:53 hrs. Witness waived by Jim Regg on 12/12/19 @ 16:13 hrs via email. Load 3x well houses and move to Swanson River Field. Location secure. SDFN. 11/12/19 - Tuesday PTW, JSA. Rig up AK E-line on SS. 180 psi on 2.375" tubing. PT 250/3000 psi. Pump 8 bbls down 2 3/8" tubing to kill well. Well on vac. Stab on well with E-line and 1.680" jet cutter. RIH with 1.680" jet cutter. Correlate to chemical injection sub @ 1599'. Tagged at 4057' RKB. Attempt to work tools down with no luck. POOH to surface. Rig down E- line. 11/13/19 - Wednesday SL arrive at Swanson office. PTW/JSA. Start and warm equipment. Depart for Wolf Lake. Spot equipment and RU SL unit.(Short string 2 3/8") RIH with 5'x1.75" DD bailer to 3924' KB. Work tool string and fall to 3969' KB. Set down Work tools and fall to 3979' KB. Continue to work tools to 4138' falling slowly. POOH from 4138' KB slight over pulls of 250 lbs up to 4000'. At surface. Bailer 1/2 full of sand/mudd.,RIH with same tools and 3' bailer extension to 4138'KB. Work tools to 4156' KB. POOH. Bailer full of sand/mudd. WHP slowly built to 450 psi. Bleed well down to tank. Monitor for flow. Returned 3 bbls. Well static.,RIH with same tool string. Found fluid level at 560'. Tag fill at 4139' KB. POOH bailer full of mudd. Empty bailer continue to bail at 4160' . POOH bailer full of mudd. RIH with bailer and work tools to 4165' KB. POOH bailer full of mudd.,Called town to discuss. Move SL to 2 7/8" long string. PT stack 250/3500 psi. RIH with 1.62" Gauge ring to 6005' KB. (Top of dual string packer). Work tools. Cannot pass depth. 300-400 lbs overpulls. POOH to surface. Previous attempts with SL made it through 6000' with 1" toolstring. Make up same 1" tool string. RIH with 4'x 1" Drive down bailer to 6000'. Work tools. Cannot pass dual string packer in 2 7/8" long string. POOH to surface. Bailer tip shows metal marks. Bailer full of fluid. No mudd or sand. Rig down SL. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Wolf Lake #2 50-133-20375-00-00 198-142 10/23/19 - Wednesday PTW, JSA with Hilcorp production group. Arrive and Wolf Lake with HAK hot oil truck. Rig up on IA or 2 7/8" + 2 3/8" x 9 5/8" annulus. Pressure test pump line to 250/4000 psi. Online down IA @ 1 bbl/min with produced water. Initial IA pressure was 120 psi. Bled down IA to bleed down trailer prior to pumping. Pressure start to climb after 5 bbls pumped. Slow pump rate to .65 bbls/min. Required test pressure was 3500 psi. At 3450 psi pressure broke over and continued to drop to 0 psi. Increased rate to 2.5 bbls/min. Not able to catch fluid/pressure after 20 bbls pumped. Close in IA gate valve. Rig down Hot oil truck. Sudden drop in pressure while performing IA pt could indicate Baker 9 5/8" GT dual packer elements failed or a collapsed tubing event occurred in the 2 3/8" or 2 7/8" annulus above packer which is set at 5,991' KB. Rig Start Date End Date 10/23/19 12/1/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Wolf Lake #2 50-133-20375-00-00 198-142 01/26/2020 - Sunday PTW, JSA with SLB , Cruz and HAK MIRU SLB CTU 13 wtih 1.75" CT. 24 Hr. BOPE test witness notification sent 1/25/20 @ 10:57 AM. Witness wiaved via email by Jim Regg on 1/25/2020 @ 11:33 PM. Included in witness wiaved email. Mr. Regg requests 48 hr notification for PT/tag of cement plugs. Start BOPE test. Test all rams and valves 250/3,500 psi. Perform accumulator draw down test. BOPE test complete. 12/14/2019 - Saturday PTW/JSA with SLB CT crew and Cruz crane op. Pick injector head. Make up 10' lubricator. BHA 1.5" OD x .6' roll on coil connector. 1.5" x 1.5' DFCV, 1.5" OD x 3' stinger, 1.5" OD x 3' stinger, 1.5" OD x .6' down jet nozzle. Stab on well. (2-3/8" short string) PT stack 250/3,500 psi. Open well. Tubing 340 psi, IA 0, OA 0 psi. Bleed well down to 0 psi. RIH. Returns/CT displacement indicate fluid is at surface. Tag Top of fill at 4,147' CTMD. Pick up clean. Establish circulation 1.1 bbls/min 3,750 psi. Getting 1:1's. Continue to clean out fill. Perform 300' wiper trips every 500'. At 4,829' lost returns for 3 bbls and then back to 1:1's. 5,660' stack 4k down while cleaning out at 1.1 bbls/min. Weight came back. Broke through sand bridge. FCO to 5,972' and park coil. Pump bottoms up. Returns clean to surface. Shut down pump and RIH without pumping from 5,972' to 6,080'. 70' outside of short string tubing tail. Pick up to 6,000'. Online down ct at 1.1 bbl/min. RIh and set 5k down at 6,080' CTMD. Attempt to pass depth with changing speed and pump rates of CT. Not able to pass 6080'. CT tags are hard and consistent. Either tagging fill or 2-7/8" long string tubing. POOH to surface. Perform injection test down 2-3/8" SS. 1 BPM 300 psi, 1.8 BPM 446 psi, 3.2 BPM 1100 psi. Blow down stack. Pump 3 bbls of diesel down SS. Close master and swab. Swap BOPE/injector head to 2-7/8" long string. Same 1.5" slim BHA. Shell test stack to 250/3,500 psi for 5 minutes each. RIH on long string. Reel level wind hydraulic hose fitting split. Shut down CTU unit. Hydraulic fluid contained in reel sump. Swap out fitting and clean sump with absorb. Continue in hole. Tag 5K down at 5,986' CTMD. Pick up clean. Attempt to pass with different speeds and pump rates. Set max 14K down at 5,986' CTMD. Not able to pass restriction above 9-5/8" dual string packer. POOH to surface. At surface. Perform injection test. 2 bbl/min 986 psi injection pressure. Close master and swab. Both strings have communication to formation. Monitored IA during both long string and short string injection tests. Pressure on IA remained 0 psi while pumping. Blow CT reel dry with N2 bottle racks. Pop Injector head off well. Install night cap on BOPE. Pump 3 bbls of diesel down LS for freeze protect. SDFN. Location secure. Rig Start Date End Date 10/23/19 12/1/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Wolf Lake #2 50-133-20375-00-00 198-142 PTW, JSA with SLB , Cruz, Hilcorp. Fire up coil equipment. Cruz crane not building fuel pressure. Halliburton cement ABT stuck on lease road. Crane running. Make up 1.75" CT dimple connector. Stab on well. Pump CT volume to clear any rust/debris. 33.7 bbls pumped. Pop off well. Make up 2.18" OD cement retainer. PT stack 250/3,500 psi. Open well. (Long string). Initial WHP 1,450 psi. IA 100 psi. RIH. Halliburton cementers on location. Spot in and rig up. Light tag with coil at 5,957'. Pu and saw 4.5K over pull. returns to surface. Close choke. Perform injection test down 2-7/8" tubing. 1 BPM @ 1,000 psi. Drop ball to set Cement retainer. Discuss cement procedure. Not comfortable with 2.5 hour cement setup time. Make calls to Halliburton Engineers and Hilcorp office. Do not set retainer. POOH to surface. Delay job due to cement setup time. Tagged up at surface. Ball recovered. Blow down CTU with N2 bottle racks. Freeze protect surface lines. Cover reel with ground thaw blankets. 01/28/2020 - Tuesday PTW, JSA with SLB, Cruz, Halliburton, HAK rep. Review job procedures and associated risks. Fire equipment. Wait for 3 vac truck loads from SRF. 70 bbls of fresh water, 140 bbls of produced water. Doyles fuel service on location. Load displacement tanks with 20 bbls of Neat Methanol. Pump 4 bbls of methanol down CT. Online with N2. Blow reel dry to ensure no ice plug. (Previous days N2 bottle rack blow down concluded less than desirable results.) Make up cement retainer. Stab on well. PT stack 250/3,500 psi. Bleed down. Open well and RIH. WHP 0 psi, IA 25 psi. CT stopped at 5,940' Pump 2 bbls of methanol then drop 1/2" ball to for cement retainer seat. Pump 35 bbls. Ball on seat. Pressure up to 3,000 psi and break over. Retainer set. Stack 4k down to confirm set. Pump down 2-7/8" tubing x 1.75" CT annuli to confirm integrity of cement retainer at 5,940'. Pressure up to 1,000 psi. Monitor pressure for 5 minutes. Good PT. Leave 1,000 psi on tubing x CT annuli. Halliburton online down CT for injection test. 1.2 bbls/min @ 1,700 psi. Fresh water 80*F. Shut down . Close HES block valve and PT cement lines to 250/4,000 psi, Start mixing cement. Shut down. HES cement truck going into parked regeneration. Wait for 30 minutes for truck to burn exhaust particulate filters. Online down CT with confirmed mudd scale weight of 15.8 ppg class G cement. Stable injection pressure at 1.3 bbls/min at 3,400 psi. After 40 bbls away. 7 bbls outside of CT retainer set at 5,940' pressure broke over from 3,400 psi to 2,300 psi. Shortly after IA pressure started increasing from 25 psi up to 2,000 psi. CT x Tubing annulus also increased from 1,000 psi to 1,680 psi while treating job. Possible thermal. 58 bbls of cement pumped. Pick up out of cement retainer 7.5K lbs normal up weight. Pulled free and sheared from cement retainer at 12.8K lbs. CTx tubing pressure dropping. POOH to surface. Tagged up. IA pressure dropped from 2,000 psi to 1,400 psi. (possible IA pressure increase from thermal and tubing ballooning, or communication with tubing x casing annulus). Pump methanol down tubing pressure up on Cement to 2,000 psi. Good quick PT. No change in IA pressure. Final IA pressure is 1,200 psi. 2-7/8" long string is freeze protected with 2,000' of diesel, swab and master closed. Online with N2 to blow reel dry. 1,500 scf/min. 33.7 bbls of fluid returned. Pop off well. Stack down lubricator and injector head. Location walk around complete. SDFN. SLB will be back in AM to rig down remaining CTU equipment. 01/27/2020 - Monday Cement job didn't go per plan. Appears to have established LS tbg x IA communication. -bjm After 40 bbls away. 7 bbls outside of CT retainer set at 5,940' pressure broke over from 3,400 psi to 2,300 psi. Shortly after IA pressure started increasing from 25 psi up to 2,000 psi. CT x Tubing annulus also increased from 1,000 psi to 1,680 psi while treating job. or communication with tubing x casing annulus) CT stopped at 5,940' Pump 2 bbls of methanol then drop 1/2" ball to for cement retainer seat. Rig Start Date End Date 10/23/19 12/1/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Wolf Lake #2 50-133-20375-00-00 198-142 01/29/2020 - Wednesday Arrive on location. PTW , JSA. Rig down SLB CTU 13. Load 2x iron racks, choke skid, BOPE skid, and SLB lubricator box on Weaver Bros step deck. Install production wellhead flanges on short and long string. Load United rentals man lift on weaver trailer. Send 400 bbl rain for rent tank to G&I for cleaning. Rig down Cruz Crane and load on lowboy trailer. All equipment off location. Co Rep perform location walk around. Latch up to united rentals heater trailer. Wolf Lake access rd gate locked. Return heater to united rentals. 02/01/2020 - Saturday Day prior AK E-line informed Hilcorp that the current E-line truck was broke down and planned to swap to a recently purchased E-line unit from down south. New truck had problems with acquisition system and E-line cable. Truck was also having generator problems. Tentative start time was 10 AM. E-line arrived on location at 1300 hrs. PTW, JSA with E-line crew. Spot in RU AK E-line. E-line boom truck will not scope out. Diagnose and continue with rig up. 9-5/8" IA showing 1,050 psi. 2-7/8" tubing (long string) on slight vac. Unable to get a pressure reading on 2-3/8" short string. Popped night cap and discovered ice above swab valve. Swab and upper master valve difficult to turn. Lower master valve functions as intended. Stab on well. PT lubricator stack 250/3,500 psi. RIH. 1-11/16" rope socket, 3 blade bow spring centralizer, 1- 11/16" CBL, BS centralizer, 1-11/16" CCL/Gama, bow spring centralizer with tapered bull nose end. Long string was previously jugged up with diesel and 60/40 methanol and tested to 2,000 psi post coil job. Didn't see wire displacement to surface until 1,600'. Where did the fluid go? Set down with E-line tools at 5,328'. ( Cement retainer set on CTMD @ 5,928'). Tagging 600' high. Pick up and work E-line down. Each attempt we gain 30' and grab a collar. Acting like green cement only no over pulls noticed. Weight indicator was inconsistent and bouncing erratically. Worked tools to 5,435' (+107') E-line uncorrected depth. Further depth gains halted. POOH to surface. Log OOH at 40 ft/min to 3,000'. E line coming up on 0' and no tag. Tagged up at surface. E line depth -400'. Something wrong with depth counter possibly indicating tag depths were 400' deeper than previous indications. With E-line tag at a questionable 5,435' + 400' of counter difference puts estimated depth at 5,835' indicating a high tag depth of 93' from CT retainer depth. Close upper master and swab valve. Bleed down 9-5/8" casing during E-line operations from 1,050 psi to 150 psi. At first IA was all gas. Last 250 psi was fluid and gas. Shut in to allow gas migration and allow fluid/gas to swap. Pop off well and lower tool string to inspect. No indications of green cement residue on tool string. Call town to discuss plan forward. While performing E-line operations AAO rig crew spotted generator and heater on short string. Results from E-line CBL indicated that there was no cement behind 2-7/8" tubing (long string). Many inconsistencies with E-line truck. Plan forward is to swap trucks and perform CBL runs in long string and short string to confirm (free pipe) cut depth. Rig down E-line unit. HAK 401 rig rep will arrive in AM to fire generator and heater to thaw ice plug on short string between swab and master valve. AK E-line will arrive with new truck and tools to attempt a more accurate intervention to confirm the results of the CTU retainer squeeze intervention. Location secure. SDFN. Long string was previously jugged up with diesel and 60/40 methanol and tested to 2,000 psi post coil job. Didn't see wire displacement to surface until 1,600'. Where did the fluid go? S Rig Start Date End Date 10/23/19 12/1/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Wolf Lake #2 50-133-20375-00-00 198-142 02/04/2020 - Tuesday Run electrical lines to eq. raise pit roof, install Gas- buster, run walkways, install skirting to carrier, Electrician repair derrick light cord, R/U pump lines, install insulation blankets, Raise derrick, & scope out, secure same. r/u weight indicator. R/U pvt system, troubleshoot same. 02/03/2020 - Monday Warm eq. & start PTSM. Level pad for eq. lay felt & liner, remove floor from carrier, spot rig t/well center. Install landings to mast, Spot, dragon heater, mud pump, choke house, dog house, parts conex, office shack & pits. unload eq. from trailers. SDFN. 02/02/2020 - Sunday On location, r/u heat on tree & thaw SS. Check well SS had 400 psi, 9 5.8 had 190, LS 0, bleed fluid & gas from SS t/275 psi, 9-5/8" dropped t/140, simops, r/u e-line on LS, PT 250/3,500 good RIH w/2.13" drift,, ccl, t/ 5,810', unable t/ work past. POOH Change out Drift t/1.74", R/U on SS, P/T 250/3,500, attempt to RIH, unable to work through tree, Mobe out methanol skid, fill lubricator & tree w/ methanol RIH w/e-line, tagged up on xn @ 6,008', POOH R/D, secure well, & location. SDFN. 02/05/2020 - Wednesday PTSM, Cont. r/u, Quadco on location finish r/u PVT sys & test good, r/u t/ Pump on SS. Attempt to get injection test on SS, pump 6.9 bbls @ 1.2 BPM, pressured up t/ 1,560, shut down, held f/ 10 min pressure stabilized @ 1,512, ann 1,300psi, bleed pressure off, converse findings with town, decide to attempt pressure test t/2,000psi. R/U to chart pressure test. Pump 1 bpm, & started injecting, Rates- 1 bpm, 475 psi, 2 bpm 830 psi, 2.9 bpm 1550psi, shut down, pressure bled down t/400psi. Pumped 27 bbls total Monitor LS static, install BPV, 70 psi on SS Bleed off 11 bbls & monitor, static,Test void t/250-5,000 psi good, install BPV in SS N/D tree, prep wellhead, plug injection ports, check lift threads on both hangers good, install plugs & blanking sub on SS, N/U BOPE, stack up mud cross, doublegate, single gate, unload accumulator & spot. SDFN & Night watch. 02/06/2020 - Thursday PTSM, stack up annular, tq. flange bolts, install choke & kill lines, r/u floor, install hand rails & hang skirting off floor f or BOPE. Hook up accumulator lines, bump test accumulator, mobed electrician down to change rotation on accumulator pump & wire up remote panel, m/u 2-3/8" test jt, & install. R/U total safety gas system calibrate & test good, function test BOPE, Repair hookload sensor. terminate heat trace lines for choke line. adjust timing on 4way valve for lower pipe rams. Fill surface lines & eq. w/test fluid, shell test BOPE repairing leaks as needed. Prep hyd lines to raise driller station. Blow down surface eq. Add mounting brackets to rig floor & hang stairs. Rig Start Date End Date 10/23/19 12/1/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Wolf Lake #2 50-133-20375-00-00 198-142 02/10/2020 - Monday PTSM, Warm Eq. Prime pump, check well static, POOH f/ 5,731' (e-line measurement) t/ 4,035' with LS- 2-7/8" 6.5# L-80 EUE 8 rd tubing, spooling control line. L/D chem injection sub. ( L/D 2 pups) Cont. POOH t/surface, full recovery t/ cut, recovered Hanger, xo pup, 185 jts, 2- pup jts, chem injection sub, & 5.53"cut jt = 5,718.72' total recovery. Clear floor , M/U Halliburton EZ drill SV cmt retainer & running tool, = 9.46', TIH t/ 163' , blow down surface lines & secure well for night. Night watch rig Move drillers landing up one station, r/u accumulator lines to upper rams, troubleshoot accumulator remote panel. Fill surface eq. with test fluid, function test annular, cont. troubleshoot & remote accumulator panel (made repairs to panel & tested good @ 14:30). Test BOPE as per Hilcorp & AOGCC expectations, test witnessed by AOGCC inspector Lou Laubenstein, tested w/ 2-3/8" & 2-7/8" test joints, 250 low 2,500 high on annular, 250 low 3,000 high on all other components, had 2 fp, k-1 valve & cmv. Blow down surface eq. Pull blanking sub, check BPV's & monitor well static, install brake linkage f/ carrier to driller station. M/U landing jt on LS, r/u e-line. RIH w/ E-line tools-2.25" jet cutter CCL, tag @ 5,733' ELM, attempt to work down, no go, make cut @ 5,731', good indication of cut, well u-tubed till balanced, monitored static. POOH. Night watch rig, fuel eq. R/U E-line, RIH w/ 1-23/32" jet cutter & CCL, set & fire cutter at 5,729', good indication it fired. POOH l/d spent cutter, R/D e-line. Wait on Day crew. 02/08/2020 - Saturday PTSM, monitor well static, r/u pump down SS, take returns up long string, R/U bails & elevators, prep area for pipe skate Circulate down SS, capturing freeze protect interface, Monitor well static, check annulus static, BOLD pins on SS hanger, pull hanger free @ 27k , monitor well, pull hanger to floor & L/D same. R/U gill tongs, pipe skate, spooler, dressing tongs for 2-3/8" & short one jaw, r/d gill tongs, dress McCoys for 2-3/8" & r/u on floor, blow down surface lines, spread containment for pipe rack. POOH f/ 5,729' t/ 5,077'', spooling chem line & removing bands. Secure well for night, blow down pump lines & night watch. 02/09/2020 - Sunday PTSM, R/D & Move pipe handler, spooler & power unit, re-arrange liner, spot catwalk, install beaver slide, & pipe racks. Cont. POOH l/d SS 2-3/8" 4.6# L-80 IBT tubing t/4,130', l/d chemical injection sub, last of chemical injection line missing clamps & appears to be hung at LS hanger Cont, POOH f/4,130' t/surface, recover 178 jts, 1-cut jt-7.63', chem injection sub, & 3 pup joints C/o handling eq t/ 2-7/8" m/u landing jt t/LS, BOLD pins, Pull LS hanger, unseat & pull @ 32k, recover remaining ctl line from SS, l/d hanger, secure well for night. 02/07/2020 - Friday m/u landing jt t/LS, BOLD pins, Pull LS hanger, unseat & pull @ 32k, BOLD pins on SS hanger, pull hanger free @ 27k , monitor well, pull hanger to floor & L/D same. POOH f/ 5,731' (e-line measurement) t/ 4,035' with LS- 2-7/8" 6.5# L-80 EUE 8 rd tubing, sp POOH l/d SS 2-3/8" 4.6# L-80 IBT tubing t/4,130', make cut @ 5,731', good indication of cut, w POOH f/ 5,729' t/ 5,077' M/U Halliburton EZ drill SV cmt retainer & running tool, set & fire cutter at 5,729', Rig Start Date End Date 10/23/19 12/1/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Wolf Lake #2 50-133-20375-00-00 198-142 02/13/2020 - Thursday PTSM, warm Eq. RIH f/ surface to tag CIBP set @ 4,494', PU & space out. up wt 25k, dn wt 23k. RU cement eq, PJSM with all involved. Fill lines pump 10 bbls fresh water, P/T lines t/2,500psi. Pump 43 bbls Premium plug cement 15.8ppg @ 2bpm, 15 psi,displace with 18 bbls water. POOH t/3,790'. Shut in & pressure up t/500 psi hold 30 min (pumped 7.5 bbls) bleed off get 4.5bbls back. POOH t/3,280', pump tubing volume, monitor well. POOH LD 2-7/8" tubing, LD 52 jts total t/1,838'. Night watch rig. 02/11/2020 - Tuesday PTSM, warm Eq, check well static, TIH w/ Halliburton 9-5/8" EZ Drill SVB squeeze packer on 2-7/8" tubing, t/5,727' up wt 32k dn wt 29k. R/U Break circulation. Pump down tubing 5 bbls good, set EZ Drill SVB squeeze packer @ 5,727', as per Halliburton tool rep, rotate & shear off running tool @ 69k. Sting back into retainer & set down 10k, attempt to get injection rate, pressured up t/ 1,200, s/d pressure held, bled, off, made 2 more attempts @ 1,750 & 2,050 PSI with same results, we unstung from retainer, pumped through tool good, closed annular & pressured up t/2,000 psi held f/ 5 min good. Stung back into retainer, set down 10k, make 3 more attempts to inject into formation @ 2,000 psi pressuring up, holding f/1-5 min monitor then bleed off with no joy. Called Town discussed issue, AOGCC was contacted by Engineer, discussed issue, decision was made to attempt a higher pressure. We pressured up 3 x with pressures 2,500-2,600psi with no luck. Communicated results t/town engineer, & to AOGCC, decision made to dump 100' of cmt on top of retainer. Rigged up Halliburton cmt, unstung from cmt retainer t/ 5,726', r/u return lines f/ Annulus. PJSM with all involved, fill lines, work on plugged valve, Pump 10 bbls water, PT lines t/250/1,500. Pump 7.5 bbls. Premium-G Plug Cmt 15.8 PPG, displace with 28 bbls water for balanced plug, monitor well till static. ETOC 5,621'. Disconnect lines, POOH l/d single & 2 pup jts, cont. POOH t/5,257' pulling dry. R/U Pump tubing volume @ 2.5 bpm, 500 psi. POOH t/ 5,075', secure well for night. Night watch rig. 02/12/2020 - Wednesday PTSM, Warm Eq., check well static, Cont. POOH f/5,075', t/ surface standing back 2-7/8" tubing, LD Halliburton retainer. Running tool good. Clear floor, RD catwalk, & slide, RU e-line, RIH w/ CCl /bailer, Tag CMT @ 5,241', POOH AOGCC inspector Brian Bixby witnessed tag RU fill hole & Test plug/casing t/2,000psi f/30 min good AOGCC inspector Brian Bixby witnessed pressure test RU e-line w/CIBP, Set @ 4,494' PU & re-tag t/verify, good POOH RU e-line w/casing punch 1- 9/16", RIH t/ top of CIBP @ 4,494', PU & shoot holes f/4,489-4,493', POOH all shots fired. PU 1-9/16" casing punch gun, RIH & set on depth shoot holes f/4,230'-4,234', POOH all shots fired, RD e-line. Secure well, Night watch rig. Tag CMT @ 5,241', & Test plug/casing t/2,000psi f/30 min good AOGCC inspector Brian Bixby witnessed pressure test R pressured up t/2,000 psi held f/ 5 min good. S /CIBP, Set @ 4,494' RIH t/ top of CIBP @ 4,494', PU & shoot holes f/4,489-4,493 Sting back into retainer & set down 10k, Pump 43 bbls Premium plug cement 15.8ppg @ RIH & set on depth shoot holes f/4,230'-4,234', set EZ Drill SVB squeeze packer @ 5,727', o AOGCC, decision made to dump 100' of cmt on top of retainer. R RIH f/ surface to tag CIBP set @ 4,494', Pump 7.5 bbls. Premium-G Plug Cmt 15.8 PPG, d . ETOC 5,621' Rig Start Date End Date 10/23/19 12/1/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Wolf Lake #2 50-133-20375-00-00 198-142 02/14/2020 - Friday PTSM. Start POOH. LD 2-7/8" tubing, LD 5 jts & lost air pressure. Trouble shoot air system, found rig compressor not building air, RU aux compressor to rig to continue work. Cont POOH. LD 55 jts. RIH w/36 stands 2-7/8" tubing. POOH. LD 2-7/8" tubing, 72 joints. Clear floor, move pipe handler, RU E-line. RIH w/CCL, & bailer, t/ tag TOC @ 3,849'. POOH. RU test csg/CIBP set @ 4,494' w/ cmt plug on top TOC 3,849', test 1,000 psi f/ 10 min good, blow down RU e-line w/CIBP, RIH put on depth @ 160' & set, PU re-tag good, POOH. RIH, w/1-9/16" casing punch put on depth, punch holes f/159'- 155', POOH. RD e-line. Secure well. Night watch. 02/15/2020 - Saturday PTSM, RU & check circ rates/pressure from 9-5/8'-13-3/8,' @ 1.2BPM 50 PSI, @ 2.5 BPM 100 PSI, @ 3BPM 165 PSI. RU cementers ,PJSM with all involved, fill pump lines & flush 10 bbls, PT lines & check trips on unit. Pump 26 bbls 15.8ppg Premium Plug CMT @ 1.5 BPM, 150psi. Flush lines, clean up unit, flush stack & blow down. Move driller consul, landing & stairs down one station. RD choke & kill lines, suck & cleanout pits, bleed down accumulator, RD accumulator lines. RD floor Nipple Down BOPE, NU dry hole tree. Night watch, snow removal. 02/16/2020 - Sunday Rig Down. Roll up electrical cabling. Load out Weaver trailers. R/D pits and mud pumps. /Load out choke and change houses. Load Koomey lines and HP hoses. Prep derrick for scoping down. Remove guy wires, R/D derrick board and unplug derrick lights. Load Koomey unit and Dragonfire heater on trailer. Scope down mast. Remove berming from around containment. Lay mast over. Continue loading rig equipment on Weaver trailers. Raise carrier jacks, secure all lines, secure walkways and handrails. Remove drillers and ODS landings. Remove doghouse from monkey board. Load out tool connex and fuel tank. Clean off and fold up pit liner. Night watch. Clean up location. Segregate and consolidate waste. 11/29/21 - Monday Safety meeting was held regarding the hazards associated with working in confined space and removing wellhead of Wolf Lake #2. Workers mobilized to site and removed grating to install access ladder and begin rigging up to remove the master valve on wellhead prior to commencing cutting. Depth of cut was above the cellar floor so no excavation was necessary to get to the required depth. Cutting commenced on the conductor,however progress was slower than anticipated. AOGCC was notified that the cutting was taking longer than expected and regular updates were sent from the field to the office. At 6 pm approximately 40% of the wellhead was cut through and work was stopped for the night. AOGCC was notified of the anticipated time for witnessing wellhead cutoff for the following day and crew went home for the night. Pump 26 bbls 15.8ppg Premium Plug CMT @ 1.5 BPM, t csg/CIBP set @ 4,494' w/ cmt plug on top TOC 3,849', test 1,000 psi f/ 10 min good, RIH w/CCL, & bailer, t/ tag TOC @ 3,849' RU e-line w/CIBP, RIH put on depth @ 160' &RIH, w/1-9/16" casing punch put on depth, punch holes f/159'- 155', POOH. Rig Start Date End Date 10/23/19 12/1/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Wolf Lake #2 50-133-20375-00-00 198-142 12/01/2021 - Wednesday Workers mobilized to Wolf Lake #2 wellhead after safety meeting and permit was issued. Cutting resumed on Wolf Lake #2 wellhead. Loader was rigged up to wellhead for when cut was complete. After wellhead was cut free, AOGCC was notified for witnessing the conductor and surface casing. Approximately 14 inches of void space was observed in the production casing. AOGCC witnessed wellhead after it was removed and cover plate was welded on. Crews cleaned up the work site at Wolf Lake #2 and then moved over to Wolf Lake 1RD to prepare for cutting the wellhead off on 12/3/2021. 11/30/21 - Tuesday Safety meeting was held prior to permit issuance. Workers mobilized to Wolf Lake Pad and resumed cutting continued on wellhead Wolf Lake #2. Several blades were broken and replaced as needed. Progress was again slower than expected. AOGCC was notified of the delay in progress. The work was stopped with approximately 80% of the wellhead was cut and workers demobilized at 6pm. After wellhead was cut free, AOGCC was notified for witnessing the conductor and surface casing. Approximately 14 inches of void space was observed in the production casing. AOGCC witnessed wellhead after it was removed and cover plate was welded on. Rig Start Date End Date 5/23/22 5/23/22 05/23/2022 - Monday The Permit to Drill (PTD) was incorrectly labeled on the abandonment marker plate. The PTD label on the marker plate for Wolf Lake #2 was fixed by grinding off the incorrect numbers, and then welding on the correct numbers. The plate was not modified beyond this correction. An updated photograph was sent to the AOGCC. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Wolf Lake #2 50-133-20375-00-00 198-142 Wolf Lake #2 Measuring to Cut Off Wellhead Board laid across Wolf Lake #2 cellar. Pad elevation 245.3’ Measuring tape used to verify height of well cover plate. Pad elevation 245.3’- (5’-4”) = 240.0’. Natural Grade or Original Grade = 246.7’. Reference McLane drawing for Wolf Lake #2 Wolf Lake #2 Cement to Surface Wolf Lake #2 Marker Plate Welded On Original marker plate photo taken 12/1/21. The PTD number in this photo is incor- rect. The correct PTD number is 198-142. Wolf Lake #2 - Marker Plate Welded On Updated marker plate photo taken 5/23/22. The PTD number in this photo has been corrected to 198-142. From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Thursday, March 3, 2022 3:29 PM To: Dan Marlowe <dmarlowe@hilcorp.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: [EXTERNAL] Wolf Lake Marathon #2 Surface Abandonment Reviewing photos from the surface abandonment inspection at WL-2 I noticed the marker plate has incorrect information. The plate shows PTD 193-142 (photo attached), the correct PTD # is 198- 142. This should be corrected. 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WKK,ƚŽƐƵƌĨĂĐĞ͘ĂŝůĞƌƚŝƉƐŚŽǁƐŵĞƚĂůŵĂƌŬƐ͘ĂŝůĞƌĨƵůůŽĨĨůƵŝĚ͘EŽŵƵĚĚŽƌƐĂŶĚ͘ZŝŐĚŽǁŶ^>͘ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ tŽůĨ>ĂŬĞηϮ ϱϬͲϭϯϯͲϮϬϯϳϱͲϬϬͲϬϬ ϭϵϴͲϭϰϮ ϭϬͬϮϯͬϭϵͲtĞĚŶĞƐĚĂǇ Wdt͕:^ǁŝƚŚ,ŝůĐŽƌƉƉƌŽĚƵĐƚŝŽŶŐƌŽƵƉ͘ƌƌŝǀĞĂŶĚtŽůĨ>ĂŬĞǁŝƚŚ,<ŚŽƚŽŝůƚƌƵĐŬ͘ZŝŐƵƉŽŶ/ŽƌϮϳͬϴΗнϮϯͬϴΗǆ ϵϱͬϴΗĂŶŶƵůƵƐ͘WƌĞƐƐƵƌĞƚĞƐƚƉƵŵƉůŝŶĞƚŽϮϱϬͬϰϬϬϬƉƐŝ͘KŶůŝŶĞĚŽǁŶ/ΛϭďďůͬŵŝŶǁŝƚŚƉƌŽĚƵĐĞĚǁĂƚĞƌ͘/ŶŝƚŝĂů/ ƉƌĞƐƐƵƌĞǁĂƐϭϮϬƉƐŝ͘ůĞĚĚŽǁŶ/ƚŽďůĞĞĚĚŽǁŶƚƌĂŝůĞƌƉƌŝŽƌƚŽƉƵŵƉŝŶŐ͘WƌĞƐƐƵƌĞƐƚĂƌƚƚŽĐůŝŵďĂĨƚĞƌϱďďůƐ ƉƵŵƉĞĚ͘^ůŽǁƉƵŵƉƌĂƚĞƚŽ͘ϲϱďďůƐͬŵŝŶ͘ZĞƋƵŝƌĞĚƚĞƐƚƉƌĞƐƐƵƌĞǁĂƐϯϱϬϬƉƐŝ͘ƚϯϰϱϬƉƐŝƉƌĞƐƐƵƌĞďƌŽŬĞŽǀĞƌĂŶĚ ĐŽŶƚŝŶƵĞĚƚŽĚƌŽƉƚŽϬƉƐŝ͘/ŶĐƌĞĂƐĞĚƌĂƚĞƚŽϮ͘ϱďďůƐͬŵŝŶ͘EŽƚĂďůĞƚŽĐĂƚĐŚĨůƵŝĚͬƉƌĞƐƐƵƌĞĂĨƚĞƌϮϬďďůƐƉƵŵƉĞĚ͘ ůŽƐĞŝŶ/ŐĂƚĞǀĂůǀĞ͘ZŝŐĚŽǁŶ,ŽƚŽŝůƚƌƵĐŬ͘^ƵĚĚĞŶĚƌŽƉŝŶƉƌĞƐƐƵƌĞǁŚŝůĞƉĞƌĨŽƌŵŝŶŐ/ƉƚĐŽƵůĚŝŶĚŝĐĂƚĞĂŬĞƌϵ ϱͬϴΗ'dĚƵĂůƉĂĐŬĞƌĞůĞŵĞŶƚƐĨĂŝůĞĚŽƌĂĐŽůůĂƉƐĞĚƚƵďŝŶŐĞǀĞŶƚŽĐĐƵƌƌĞĚŝŶƚŚĞϮϯͬϴΗŽƌϮϳͬϴΗĂŶŶƵůƵƐĂďŽǀĞƉĂĐŬĞƌ ǁŚŝĐŚŝƐƐĞƚĂƚϱ͕ϵϵϭΖ<͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϭϬͬϮϯͬϭϵ ϭϮͬϭͬϮϭ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ 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EŽƚĂďůĞƚŽƉĂƐƐƌĞƐƚƌŝĐƚŝŽŶĂďŽǀĞϵͲϱͬϴΗĚƵĂůƐƚƌŝŶŐƉĂĐŬĞƌ͘WKK,ƚŽƐƵƌĨĂĐĞ͘ƚƐƵƌĨĂĐĞ͘WĞƌĨŽƌŵŝŶũĞĐƚŝŽŶƚĞƐƚ͘Ϯ ďďůͬŵŝŶϵϴϲƉƐŝŝŶũĞĐƚŝŽŶƉƌĞƐƐƵƌĞ͘ůŽƐĞŵĂƐƚĞƌĂŶĚƐǁĂď͘ŽƚŚƐƚƌŝŶŐƐŚĂǀĞĐŽŵŵƵŶŝĐĂƚŝŽŶƚŽĨŽƌŵĂƚŝŽŶ͘DŽŶŝƚŽƌĞĚ/ ĚƵƌŝŶŐďŽƚŚůŽŶŐƐƚƌŝŶŐĂŶĚƐŚŽƌƚƐƚƌŝŶŐŝŶũĞĐƚŝŽŶƚĞƐƚƐ͘WƌĞƐƐ ƵƌĞŽŶ/ƌĞŵĂŝŶĞĚϬƉƐŝǁŚŝůĞƉƵŵƉŝŶŐ͘ůŽǁdƌĞĞůĚƌǇ ǁŝƚŚEϮďŽƚƚůĞƌĂĐŬƐ͘WŽƉ/ŶũĞĐƚŽƌŚĞĂĚŽĨĨǁĞůů͘/ŶƐƚĂůůŶŝŐŚƚĐĂƉŽŶKW͘WƵŵƉϯďďůƐŽĨĚŝĞƐĞůĚŽǁŶ>^ĨŽƌĨƌĞĞǌĞ ƉƌŽƚĞĐƚ͘^&E͘>ŽĐĂƚŝŽŶƐĞĐƵƌĞ͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϭϬͬϮϯͬϭϵ ϭϮͬϭͬϮϭ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ tŽůĨ>ĂŬĞηϮ ϱϬͲϭϯϯͲϮϬϯϳϱͲϬϬͲϬϬ ϭϵϴͲϭϰϮ Wdt͕:^ǁŝƚŚ^>͕ƌƵǌ͕,ŝůĐŽƌƉ͘&ŝƌĞƵƉĐŽŝůĞƋƵŝƉŵĞŶƚ͘ƌƵǌĐƌĂŶĞŶŽƚďƵŝůĚŝŶŐĨƵĞůƉƌĞƐƐƵƌĞ͘,ĂůůŝďƵƌƚŽŶĐĞŵĞŶƚd ƐƚƵĐŬŽŶůĞĂƐĞƌŽĂĚ͘ƌĂŶĞƌƵŶŶŝŶŐ͘DĂŬĞƵƉϭ͘ϳϱΗdĚŝŵƉůĞĐŽŶŶĞĐƚŽƌ͘^ƚĂďŽŶǁĞůů͘WƵŵƉdǀŽůƵŵĞƚŽĐůĞĂƌĂŶǇ ƌƵƐƚͬĚĞďƌŝƐ͘ϯϯ͘ϳďďůƐƉƵŵƉĞĚ͘WŽƉŽĨĨǁĞůů͘DĂŬĞƵƉϮ͘ϭϴΗKĐĞŵĞŶƚƌĞƚĂŝŶĞƌ͘WdƐƚĂĐŬϮϱϬͬϯ͕ϱϬϬƉƐŝ͘KƉĞŶǁĞůů͘ ;>ŽŶŐƐƚƌŝŶŐͿ͘/ŶŝƚŝĂůt,Wϭ͕ϰϱϬƉƐŝ͘/ϭϬϬƉƐŝ͘Z/,͘,ĂůůŝďƵƌƚŽŶĐĞŵĞŶƚĞƌƐŽŶůŽĐĂƚŝŽŶ͘^ƉŽƚŝŶĂŶĚƌŝŐƵƉ͘>ŝŐŚƚƚĂŐǁŝƚŚ 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ƚĞƐƚKW͕ZĞƉĂŝƌŚŽŽŬůŽĂĚƐĞŶƐŽƌ͘ƚĞƌŵŝŶĂƚĞŚĞĂƚƚƌĂĐĞůŝŶĞƐĨŽƌĐŚŽŬĞůŝŶĞ͘ĂĚũƵƐƚƚŝŵŝŶŐŽŶϰǁĂǇǀĂůǀĞĨŽƌůŽǁĞƌƉŝƉĞ ƌĂŵƐ͘&ŝůůƐƵƌĨĂĐĞůŝŶĞƐΘĞƋ͘ǁͬƚĞƐƚĨůƵŝĚ͕ƐŚĞůůƚĞƐƚKWƌĞ ƉĂŝƌŝŶŐůĞĂŬƐĂƐŶĞĞĚĞĚ͘WƌĞƉŚǇĚůŝŶĞƐƚŽƌĂŝƐĞĚƌŝůůĞƌƐƚĂƚŝŽ Ŷ͘ ůŽǁĚŽǁŶƐƵƌĨĂĐĞĞƋ͘ĚĚŵŽƵŶƚŝŶŐďƌĂĐŬĞƚƐƚŽƌŝŐĨůŽŽƌΘŚĂŶŐ ƐƚĂŝƌƐ͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϭϬͬϮϯͬϭϵ ϭϮͬϭͬϮϭ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ tŽůĨ>ĂŬĞηϮ ϱϬͲϭϯϯͲϮϬϯϳϱͲϬϬͲϬϬ ϭϵϴͲϭϰϮ ϬϮͬϭϬͬϮϬϮϬͲDŽŶĚĂǇ Wd^D͕tĂƌŵƋ͘WƌŝŵĞƉƵŵƉ͕ĐŚĞĐŬǁĞůůƐƚĂƚŝĐ͕WKK,Ĩͬϱ͕ϳϯϭΖ;ĞͲůŝŶĞŵĞĂƐƵƌĞŵĞŶƚͿƚͬϰ͕ϬϯϱΖǁŝƚŚ>^ͲϮͲϳͬϴΗϲ͘ϱη>ͲϴϬ hϴƌĚƚƵďŝŶŐ͕ƐƉŽŽůŝŶŐĐŽŶƚƌŽůůŝŶĞ͘>ͬĐŚĞŵŝŶũĞĐƚŝŽŶƐƵď͘;>ͬϮƉƵƉƐͿŽŶƚ͘WKK,ƚͬƐƵƌĨĂĐĞ͕ĨƵůůƌĞĐŽǀĞƌǇƚͬĐƵƚ͕ ƌĞĐŽǀĞƌĞĚ,ĂŶŐĞƌ͕ǆŽƉƵƉ͕ϭϴϱũƚƐ͕ϮͲƉƵƉũƚƐ͕ĐŚĞŵŝŶũĞĐƚŝŽŶƐƵď͕Θϱ͘ϱϯΗĐƵƚũƚсϱ͕ϳϭϴ͘ϳϮΖƚŽƚĂůƌĞĐŽǀĞƌǇ͘ůĞĂƌĨůŽŽƌ͕ Dͬh,ĂůůŝďƵƌƚŽŶĚƌŝůů^sĐŵƚƌĞƚĂŝŶĞƌΘƌƵŶŶŝŶŐƚŽŽů͕сϵ͘ϰϲΖ͕d/,ƚͬϭϲϯΖ͕ďůŽǁĚŽǁŶƐƵƌĨĂĐĞůŝŶĞƐΘƐĞĐƵƌĞǁĞůůĨŽƌ ŶŝŐŚƚ͘EŝŐŚƚǁĂƚĐŚƌŝŐ DŽǀĞĚƌŝůůĞƌƐůĂŶĚŝŶŐƵƉŽŶĞƐƚĂƚŝŽŶ͕ƌͬƵĂĐĐƵŵƵůĂƚŽƌůŝŶĞƐƚŽƵƉƉĞƌƌĂŵƐ͕ƚƌŽƵďůĞƐŚŽŽƚĂĐĐƵŵƵůĂƚŽƌƌĞŵŽƚĞƉĂŶĞů͘&ŝůů ƐƵƌĨĂĐĞĞƋ͘ǁŝƚŚƚĞƐƚĨůƵŝĚ͕ĨƵŶĐƚŝŽŶƚĞƐƚĂŶŶƵůĂƌ͕ĐŽŶƚ͘ƚƌŽƵď ůĞƐŚŽŽƚΘƌĞŵŽƚĞĂĐĐƵŵƵůĂƚŽƌƉĂŶĞů;ŵĂĚĞƌĞƉĂŝƌƐƚŽƉĂŶĞů ΘƚĞƐƚĞĚŐŽŽĚΛϭϰ͗ϯϬͿ͘dĞƐƚKWĂƐƉĞƌ,ŝůĐŽƌƉΘK'ĞǆƉĞĐƚĂƚŝŽŶƐ͕ƚĞƐƚǁŝƚŶĞƐƐĞĚďǇK'ŝŶƐƉĞĐƚŽƌ>ŽƵ >ĂƵďĞŶƐƚĞŝŶ͕ƚĞƐƚĞĚǁͬϮͲϯͬϴΗΘϮͲϳͬϴΗƚĞƐƚũŽŝŶƚƐ͕ϮϱϬůŽǁϮ͕ϱϬϬŚŝŐŚŽŶĂŶŶƵůĂƌ͕ϮϱϬůŽǁϯ͕ϬϬϬŚŝŐŚŽŶĂůůŽƚŚĞƌ ĐŽŵƉŽŶĞŶƚƐ͕ŚĂĚϮĨƉ͕ŬͲϭǀĂůǀĞΘĐŵǀ͘ůŽǁĚŽǁŶƐƵƌĨĂĐĞĞƋ͘WƵůůďůĂŶŬŝŶŐƐƵď͕ĐŚĞĐŬWsΖƐΘŵŽŶŝƚŽƌǁĞůůƐƚĂƚŝĐ͕ ŝŶƐƚĂůůďƌĂŬĞůŝŶŬĂŐĞĨͬĐĂƌƌŝĞƌƚŽĚƌŝůůĞƌƐƚĂƚŝŽŶ͘DͬhůĂŶĚŝŶ ŐũƚŽŶ>^͕ƌͬƵĞͲůŝŶĞ͘Z/,ǁͬͲůŝŶĞƚŽŽůƐͲϮ͘ϮϱΗũĞƚĐƵƚƚĞƌ>͕ ƚĂŐΛϱ͕ϳϯϯΖ>D͕ĂƚƚĞŵƉƚƚŽǁŽƌŬĚŽǁŶ͕ŶŽŐŽ͕ŵĂŬĞĐƵƚΛϱ͕ϳϯϭΖ͕ŐŽŽĚŝŶĚŝĐĂƚŝŽŶŽĨĐƵƚ͕ǁĞůůƵͲƚƵďĞĚƚŝůůďĂůĂŶĐĞĚ͕ ŵŽŶŝƚŽƌĞĚƐƚĂƚŝĐ͘WKK,͘EŝŐŚƚǁĂƚĐŚƌŝŐ͕ĨƵĞůĞƋ͘ZͬhͲůŝŶĞ͕Z /,ǁͬϭͲϮϯͬϯϮΗũĞƚĐƵƚƚĞƌΘ>͕ƐĞƚΘĨŝƌĞĐƵƚƚĞƌĂƚϱ͕ϳϮϵΖ͕ ŐŽŽĚŝŶĚŝĐĂƚŝŽŶŝƚĨŝƌĞĚ͘WKK,ůͬĚƐƉĞŶƚĐƵƚƚĞƌ͕ZͬĞͲůŝŶĞ͘tĂ ŝƚŽŶĂǇĐƌĞǁ͘ ϬϮͬϬϴͬϮϬϮϬͲ^ĂƚƵƌĚĂǇ Wd^D͕ŵŽŶŝƚŽƌǁĞůůƐƚĂƚŝĐ͕ƌͬƵƉƵŵƉĚŽǁŶ^^͕ƚĂŬĞƌĞƚƵƌŶƐƵƉůŽŶŐƐƚƌŝŶŐ͕ZͬhďĂŝůƐΘĞůĞǀĂƚŽƌƐ͕ƉƌĞƉĂƌĞĂĨŽƌƉŝƉĞƐŬĂƚĞ ŝƌĐƵůĂƚĞĚŽǁŶ^^͕ĐĂƉƚƵƌŝŶŐĨƌĞĞǌĞƉƌŽƚĞĐƚŝŶƚĞƌĨĂĐĞ͕DŽŶŝƚŽƌǁĞůůƐƚĂƚŝĐ͕ĐŚĞĐŬĂŶŶƵůƵƐƐƚĂƚŝĐ͕K>ƉŝŶƐŽŶ^^ŚĂŶŐĞƌ͕ ƉƵůůŚĂŶŐĞƌĨƌĞĞΛϮϳŬ͕ŵŽŶŝƚŽƌǁĞůů͕ƉƵůůŚĂŶŐĞƌƚŽĨůŽŽƌΘ>ͬƐĂŵĞ͘ZͬhŐŝůůƚŽŶŐƐ͕ƉŝƉĞƐŬĂƚĞ͕ƐƉŽŽůĞƌ͕ĚƌĞƐƐŝŶŐƚŽŶŐƐ ĨŽƌϮͲϯͬϴΗΘƐŚŽƌƚŽŶĞũĂǁ͕ƌͬĚŐŝůůƚŽŶŐƐ͕ĚƌĞƐƐDĐŽǇƐĨŽƌϮͲϯͬϴΗΘƌͬƵŽŶĨůŽŽƌ͕ďůŽǁĚŽǁŶƐƵƌĨĂĐĞůŝŶĞƐ͕ƐƉƌĞĂĚ ĐŽŶƚĂŝŶŵĞŶƚĨŽƌƉŝƉĞƌĂĐŬ͘WKK,Ĩͬϱ͕ϳϮϵΖƚͬϱ͕ϬϳϳΖΖ͕ƐƉŽŽůŝŶŐĐŚĞŵůŝŶĞΘƌĞŵŽǀŝŶŐďĂŶĚƐ͘^ĞĐƵƌĞǁĞůůĨŽƌŶŝŐŚƚ͕ďůŽǁ ĚŽǁŶƉƵŵƉůŝŶĞƐΘŶŝŐŚƚǁĂƚĐŚ͘ ϬϮͬϬϵͬϮϬϮϬͲ^ƵŶĚĂǇ Wd^D͕ZͬΘDŽǀĞƉŝƉĞŚĂŶĚůĞƌ͕ƐƉŽŽůĞƌΘƉŽǁĞƌƵŶŝƚ͕ƌĞͲĂƌƌĂŶŐĞůŝŶĞƌ͕ƐƉŽƚĐĂƚǁĂůŬ͕ŝŶƐƚĂůůďĞĂǀĞƌƐůŝĚĞ͕ΘƉŝƉĞƌĂĐŬƐ͘ ŽŶƚ͘WKK,ůͬĚ^^ϮͲϯͬϴΗϰ͘ϲη>ͲϴϬ/dƚƵďŝŶŐƚͬϰ͕ϭϯϬΖ͕ůͬĚĐŚĞŵŝĐĂůŝŶũĞĐƚŝŽŶƐƵď͕ůĂƐƚŽĨĐŚĞŵŝĐĂůŝŶũĞĐƚŝŽŶůŝŶĞŵŝƐƐŝŶŐ ĐůĂŵƉƐΘĂƉƉĞĂƌƐƚŽďĞŚƵŶŐĂƚ>^ŚĂŶŐĞƌŽŶƚ͕WKK,Ĩͬϰ͕ϭϯϬΖƚͬƐƵƌĨĂĐĞ͕ƌĞĐŽǀĞƌϭϳϴũƚƐ͕ϭͲĐƵƚũƚͲϳ͘ϲϯΖ͕ĐŚĞŵŝŶũĞĐƚŝŽŶ ƐƵď͕ΘϯƉƵƉũŽŝŶƚƐͬŽŚĂŶĚůŝŶŐĞƋƚͬϮͲϳͬϴΗŵͬƵůĂŶĚŝŶŐũƚƚͬ>^͕K>ƉŝŶƐ͕WƵůů>^ŚĂŶŐĞƌ͕ƵŶƐĞĂƚΘƉƵůůΛϯϮŬ͕ƌĞĐŽǀĞƌ ƌĞŵĂŝŶŝŶŐĐƚůůŝŶĞĨƌŽŵ^^͕ůͬĚŚĂŶŐĞƌ͕ƐĞĐƵƌĞǁĞůůĨŽƌŶŝŐŚƚ͘ ϬϮͬϬϳͬϮϬϮϬͲ&ƌŝĚĂǇ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϭϬͬϮϯͬϭϵ ϭϮͬϭͬϮϭ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ tŽůĨ>ĂŬĞηϮ ϱϬͲϭϯϯͲϮϬϯϳϱͲϬϬͲϬϬ ϭϵϴͲϭϰϮ ϬϮͬϭϯͬϮϬϮϬͲdŚƵƌƐĚĂǇ Wd^D͕ǁĂƌŵƋ͘Z/,ĨͬƐƵƌĨĂĐĞƚŽƚĂŐ/WƐĞƚΛϰ͕ϰϵϰΖ͕WhΘƐƉĂĐĞŽƵƚ͘ƵƉǁƚϮϱŬ͕ĚŶǁƚϮϯŬ͘ZhĐĞŵĞŶƚĞƋ͕W:^DǁŝƚŚ ĂůůŝŶǀŽůǀĞĚ͘&ŝůůůŝŶĞƐƉƵŵƉϭϬďďůƐĨƌĞƐŚǁĂƚĞƌ͕WͬdůŝŶĞƐƚͬϮ͕ϱϬϬƉƐŝ͘WƵŵƉϰϯďďůƐWƌĞŵŝƵŵƉůƵŐĐĞŵĞŶƚϭϱ͘ϴƉƉŐΛ ϮďƉŵ͕ϭϱƉƐŝ͕ĚŝƐƉůĂĐĞǁŝƚŚϭϴďďůƐǁĂƚĞƌ͘WKK,ƚͬϯ͕ϳϵϬΖ͘^ŚƵƚŝ ŶΘƉƌĞƐƐƵƌĞƵƉƚͬϱϬϬƉƐŝŚŽůĚϯϬŵŝŶ;ƉƵŵƉĞĚϳ͘ϱďďůƐͿ ďůĞĞĚŽĨĨŐĞƚϰ͘ϱďďůƐďĂĐŬ͘WKK,ƚͬϯ͕ϮϴϬΖ͕ƉƵŵƉƚƵďŝŶŐǀŽůƵŵĞ͕ŵŽŶŝƚŽƌǁĞůů͘WKK,>ϮͲϳͬϴΗƚƵďŝŶŐ͕>ϱϮũƚƐƚŽƚĂů ƚͬϭ͕ϴϯϴΖ͘EŝŐŚƚǁĂƚĐŚƌŝŐ͘ ϬϮͬϭϭͬϮϬϮϬͲdƵĞƐĚĂǇ Wd^D͕ǁĂƌŵƋ͕ĐŚĞĐŬǁĞůůƐƚĂƚŝĐ͕d/,ǁͬ,ĂůůŝďƵƌƚŽŶϵͲϱͬϴΗƌŝůů^sƐƋƵĞĞǌĞƉĂĐŬĞƌŽŶϮͲϳͬϴΗƚƵďŝŶŐ͕ƚͬϱ͕ϳϮϳΖƵƉǁƚ ϯϮŬĚŶǁƚϮϵŬ͘ZͬhƌĞĂŬĐŝƌĐƵůĂƚŝŽŶ͘WƵŵƉĚŽǁŶƚƵďŝŶŐϱďďůƐŐŽŽĚ͕ƐĞƚƌŝůů^sƐƋƵĞĞǌĞƉĂĐŬĞƌΛϱ͕ϳϮϳΖ͕ĂƐƉĞƌ ,ĂůůŝďƵƌƚŽŶƚŽŽůƌĞƉ͕ƌŽƚĂƚĞΘƐŚĞĂƌŽĨĨƌƵŶŶŝŶŐƚŽŽůΛϲϵŬ͘^ƚŝŶŐďĂĐŬŝŶƚŽƌĞƚĂŝŶĞƌΘƐĞƚĚŽǁŶϭϬŬ͕ĂƚƚĞŵƉƚƚŽŐĞƚ ŝŶũĞĐƚŝŽŶƌĂƚĞ͕ƉƌĞƐƐƵƌĞĚƵƉƚͬϭ͕ϮϬϬ͕ƐͬĚƉƌĞƐƐƵƌĞŚĞůĚ͕ďůĞĚ͕ŽĨĨ͕ŵĂĚĞϮŵŽƌĞĂƚƚĞŵƉƚƐΛϭ͕ϳϱϬΘϮ͕ϬϱϬW^/ǁŝƚŚƐĂŵĞ ƌĞƐƵůƚƐ͕ǁĞƵŶƐƚƵŶŐĨƌŽŵƌĞƚĂŝŶĞƌ͕ƉƵŵƉĞĚƚŚƌŽƵŐŚƚŽŽůŐŽŽĚ͕ĐůŽƐĞĚĂŶŶƵůĂƌΘƉƌĞƐƐƵƌĞĚƵƉƚͬϮ͕ϬϬϬƉƐŝŚĞůĚĨͬϱŵŝŶ ŐŽŽĚ͘^ƚƵŶŐďĂĐŬŝŶƚŽƌĞƚĂŝŶĞƌ͕ƐĞƚĚŽǁŶϭϬŬ͕ŵĂŬĞϯŵŽƌĞĂƚƚĞŵƉƚƐƚŽŝŶũĞĐƚŝŶƚŽĨŽƌŵĂƚŝŽŶΛϮ͕ϬϬϬƉƐŝƉƌĞƐƐƵƌŝŶŐƵƉ͕ 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ƐŝŶŐƚͬϮ͕ϬϬϬƉƐŝĨͬϯϬŵŝŶŐŽŽĚK'ŝŶƐƉĞĐƚŽƌƌŝĂŶŝǆďǇ ǁŝƚŶĞƐƐĞĚƉƌĞƐƐƵƌĞƚĞƐƚZhĞͲůŝŶĞǁͬ/W͕^ĞƚΛϰ͕ϰϵϰΖWhΘƌĞͲƚĂŐƚͬǀĞƌŝĨǇ͕ŐŽŽĚWKK,ZhĞͲůŝŶĞǁͬĐĂƐŝŶŐƉƵŶĐŚϭͲ ϵͬϭϲΗ͕Z/,ƚͬƚŽƉŽĨ/WΛϰ͕ϰϵϰΖ͕WhΘƐŚŽŽƚŚŽůĞƐĨͬϰ͕ϰϴϵͲϰ͕ϰϵϯΖ͕WKK,ĂůůƐŚŽƚƐĨŝƌĞĚ͘WhϭͲϵͬϭϲΗĐĂƐŝŶŐƉƵŶĐŚŐƵŶ͕ Z/,ΘƐĞƚŽŶĚĞƉƚŚƐŚŽŽƚŚŽůĞƐĨͬϰ͕ϮϯϬΖͲϰ͕ϮϯϰΖ͕WKK,ĂůůƐŚŽƚƐĨŝƌĞĚ͕ZĞͲůŝŶĞ͘^ĞĐƵƌĞǁĞůů͕EŝŐŚƚǁĂƚĐŚƌŝŐ͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϭϬͬϮϯͬϭϵ ϭϮͬϭͬϮϭ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ tŽůĨ>ĂŬĞηϮ ϱϬͲϭϯϯͲϮϬϯϳϱͲϬϬͲϬϬ ϭϵϴͲϭϰϮ ϬϮͬϭϰͬϮϬϮϬͲ&ƌŝĚĂǇ Wd^D͘^ƚĂƌƚWKK,͘>ϮͲϳͬϴΗƚƵďŝŶŐ͕>ϱũƚƐΘůŽƐƚĂŝƌƉƌĞƐƐƵƌ Ğ͘dƌŽƵďůĞƐŚŽŽƚĂŝƌƐǇƐƚĞŵ͕ĨŽƵŶĚƌŝŐĐŽŵƉƌĞƐƐŽƌŶŽƚ ďƵŝůĚŝŶŐĂŝƌ͕ZhĂƵǆĐŽŵƉƌĞƐƐŽƌƚŽƌŝŐƚŽĐŽŶƚŝŶƵĞǁŽƌŬ͘ŽŶƚW KK,͘>ϱϱũƚƐ͘Z/,ǁͬϯϲƐƚĂŶĚƐϮͲϳͬϴΗƚƵďŝŶŐ͘WKK,͘> ϮͲϳͬϴΗƚƵďŝŶŐ͕ϳϮũŽŝŶƚƐ͘ůĞĂƌĨůŽŽƌ͕ŵŽǀĞƉŝƉĞŚĂŶĚůĞƌ͕ZhͲ ůŝŶĞ͘Z/,ǁͬ>͕ΘďĂŝůĞƌ͕ƚͬƚĂŐdKΛϯ͕ϴϰϵΖ͘WKK,͘Zh ƚĞƐƚĐƐŐͬ/WƐĞƚΛϰ͕ϰϵϰΖǁͬĐŵƚƉůƵŐŽŶƚŽƉdKϯ͕ϴϰϵΖ͕ƚĞƐƚϭ͕ϬϬϬƉƐŝĨͬϭϬŵŝŶŐŽŽĚ͕ďůŽǁĚŽǁŶZhĞͲůŝŶĞǁͬ/W͕ Z/,ƉƵƚŽŶĚĞƉƚŚΛϭϲϬΖΘƐĞƚ͕WhƌĞͲƚĂŐŐŽŽĚ͕WKK,͘Z/,͕ǁͬϭͲϵͬϭϲΗĐĂƐŝŶŐƉƵŶĐŚƉƵƚŽŶĚĞƉƚŚ͕ƉƵŶĐŚŚŽůĞƐĨͬϭϱϵΖͲ 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Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Wolf Lake Abandonment Date:Monday, March 7, 2022 8:53:23 AM Wolf Lake Marathon #2 (PTD 1981420) Wolf Lake 1RD (PTD 2020880) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Chris Walgenbach <cwalgenbach@hilcorp.com> Sent: Monday, March 7, 2022 8:28 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com> Subject: Wolf Lake Abandonment Mr. Regg, I will make sure the data is corrected on both Wolf Lake well abandonment markers. I will have this completed by May 31st. This will give us some time for the snow to melt and the road to dry out. Thank You, Chris Walgenbach Swanson River Foreman 907-283-2541 Office 907-690-1727 Cell 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 deletethis 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. 1 Regg, James B (OGC) From:Dan Marlowe <dmarlowe@hilcorp.com> Sent:Thursday, March 3, 2022 4:19 PM To:Regg, James B (OGC) Cc:McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL] Wolf Lake Marathon #2 Surface Abandonment Good eye sir I will dig into it ASAP From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Thursday, March 3, 2022 3:29 PM To: Dan Marlowe <dmarlowe@hilcorp.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: [EXTERNAL] Wolf Lake Marathon #2 Surface Abandonment Reviewing photos from the surface abandonment inspection at WL‐2 I noticed the marker plate has incorrect information. The plate shows PTD 193‐142 (photo attached), the correct PTD # is 198‐142. This should be corrected. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 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. J. Regg; 3/3/2022 (PTD 1981420) THE S'1NIT ^'ALASKA GOVERNOR MIKE DUNLEAVY November 2, 2021 Mr. Taylor Wellman Kenai Operations Manager Hilcorp Alaska LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: OTH-20-008 Notice of Violation - Closeout Conduct of Operations Wolf Lake Marathon 2 (PTD 1981420) Dear Mr. Wellman: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov By letter dated June 2, 2020 Hilcorp Alaska LLC (Hilcorp) responded to a notice of violation dated March 10, 2020 regarding downhole abandonment operations on Wolf Lake Marathon 2 that resulted in a surface release of diesel freeze protect fluids from the well. Corrective actions outlined by Hilcorp included training to "provide an awareness of well control" for personnel occupying specific job functions within the Kenai Operations Team, namely the Production Foreman, Lead Operators, Wellsite Managers, and Downhole Operations Engineers. Additional information was provided to the Alaska Oil and Gas Conservation Commission (AOGCC) by email dated June 17, 2020 outlining the scope of the training program. An August 26, 2020 update noted a scheduling conflict with the Yd party vendor would delay completion of the training. In response to AOGCC's letter dated July 28, 2021, Hilcorp provided a list of personnel who completed the training and backup documentation. Hilcorp also provided the mitigation in place for the three personnel that have yet to complete the training. That mitigation must remain in place until these individuals complete the appropriate level of training. AOGCC agrees that well control training at a level appropriate to an individual's responsibilities may help to prevent recurrence of this violation. Hilcorp should complete training of the 3 individuals that are working under mitigating measures at the earliest opportunity. Hilcorp is encouraged to continue periodic training of personnel assigned to the positions of Production Foreman, Lead Operators, Wellsite Manager, and Downhole Operations Engineer. Hilcorp is also encouraged to develop a framework for continuing well control training of operations personnel. AOGCC considers this enforcement action closed. Regards, Jeremy Jeremy M. Price Commissioner, Chair Carlisle, Samantha J (CED) From: Schwartz, Guy L (CED) Sent: Wednesday, November 25, 2020 3:32 PM To: Taylor Wellman Cc: Carlisle, Samantha J (CED) Subject: RE: [EXTERNAL] RE: Docket Number: OTH-20-008 Wolf Lake Marathon 2 Response and Follow Up Information Follow Up Flag: Follow up Flag Status: Flagged Categories: Follow-up Taylor, Thanks for reaching out and updating the AOGCC on the training status that was required under Docket 0TH 2O-008. We understand the difficulties of trying to hold these in-person training sessions with COVID mandates in place. The AOGCC agrees with your target date of March 2021 for an updated target for the training. If training cannot be completed due to continued COVID restrictions reach out and update the Commission as needed. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guv.schwarfz@alaska.gov). From: Taylor Wellman <twellman@hilcorp.com> Sent: Wednesday, November 25, 2020 12:47 PM To: Schwartz, Guy L (CED) <guy.schwa rtz@alaska.gov> Subject: RE: [EXTERNAL] RE: Docket Number: OTH-20-008 Wolf Lake Marathon 2 Response and Follow Up Information Guy, Thank you for the conversation yesterday on this training. We held 2 of our planned 4 courses when the request from the Governor came through to limit gatherings to help prevent the spread of COVID. In response to this all of our in person training was cancelled. It especially pains me as there had been extremely good responses from the guys in attendance. From further discussions with the people who attended, an online version would be very detrimental to the learning. I could probably make it happen to meet our abut feel it would be a disservice and wanted to reach out. Completed: - Supervisory Well Control & Interventions Well Control Training (certified course for Company Person) — 36 people in total (mainly slope based personnel) - Production Awareness (course that was developed with the curriculum outlined in email below) — 9 of 18 targeted Kenai personnel o Remaining 9 personnel were scheduled but cancelled. 5 field and 4 town personnel. Schedule to resume: - Targeting March 2021. This is due to change based on restrictions that are in place/lifted. - Plans are to expand offering to additional areas for field staff. If this is unacceptable let me know and I will work to find another way. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC — Kenai Ops Manager Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: Schwartz, Guy L (CED)[mailto:guy.schwartz@alaska.gov] Sent: Thursday, September 3, 2020 3:23 PM To: Taylor Wellman <twellman@hilcorp.com> Subject: [EXTERNAL] RE: Docket Number: OTH-20-008 Wolf Lake Marathon 2 Response and Follow Up Information Taylor, The Commissioners are in agreement that you can extend the deadline for the required training for Hilcorp personnel until December of 2020. This training is to include the topics you list below as provided by your well control school provider. There will be no further extensions however, and the training must be completed by the end of this calendar year. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From: Chmielowski, Jessie L C (CED) <jessie.chmielowski@alaska.gov> Sent: Thursday, September 3, 2020 3:08 PM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Subject: Fwd: Docket Number: OTH-20-008 Wolf Lake Marathon 2 Response and Follow Up Information Begin forwarded message: From: Taylor Wellman <twellman@hilcorp.com> Date: August 26, 2020 at 11:17:14 AKDT To: "Chmielowski, Jessie L C (CED)" <jessie.chmielowski@alaska.gov> Subject: RE: Docket Number: OTH-20-008 Wolf Lake Marathon 2 Response and Follow Up Information Commissioner Chmielowski, I wanted to follow up with you on the status of this training course. There has been a scheduling conflict with our trainer for this course and I would request an extension for the completion of this training to mid-December. In the attached letter I had specified completion by mid-October. The reasoning for the extension is that the course was developed with a single provider and needs to be held through that provider and can't be accelerated with another company. I still hold this course in high priority and am committed to ensure that this training is provided and completed by our personnel as it will aid in our ability to ensure safe operations. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC — Kenai Ops Manager Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: Taylor Wellman Sent: Wednesday, June 17, 2020 4:31 PM To: iessie.chmielowski@alaska.gov Subject: Docket Number: OTH-20-008 Wolf Lake Marathon 2 Response and Follow Up Information Commissioner Chmielowski, I wanted to follow up to today's meeting with any additional information that is needed for the Wolf Lake Incident. Attached is the response from June 2. To add to this enclosed below is the more detailed scope of the course that we've worked with one of the well control providers to develop. For our rig/jointed tubular operations, our Wellsite Managers (Company Man) are well control certified. Listed in the response are positional titles for the personnel to attend. If you'd like me to provide a list of names this can be provided. Introductory Well Control • Basic principles - Geology, Pressure, Kicks, Blowouts • Barriers - BOP's, Accumulator, Control Equipment, Drills, Administrative • Calculations - Pressure, Volume, Capacity, • Fluids - Mud, cement, brine, pit management • Causes of kicks - Bottom hole pressure, formation pressure, permeability, lost circulation, tripping, swab, surge • Kick detection - Return flow rate, pit gain, ballooning, monitors, alarms, shutting in, d ive rters • Well control methods - Wait & Weight, Drillers, Volumetric, Lubricate & Bleed • Equipment - Pits, trip tank, mud treatment, manifolds, equipment testing, FOSV, IBOP, pumps, mud gas separator Workover • Reasons for workover - Maintain, restore, mechanical, recompletion, sand control • Workover tools - Hoist, rotate, fluids • Completion equipment - Wellhead, packers, SSSV's, nipples, locks, gas lift, sliding sleeves, SBR, PBR, tubing movement Snubbing • Unit components and specs • BOP's and BHA • Pipe light, balance point, buckling Coiled Tubing • Unit components and specs • Applications • Advantages and disadvantages • Damage mechanisms • Equipment - Tubing, injector head, hydraulics, console, BOP'S, accessories • Common problems Wireline • Unit components • Wire • Pressure control - Stuffing box, grease head, ball check • Auxiliary equipment - tree connections, tool traps, wireline valve, pump -in sub • Considerations - Well info, testing, displacement, fishing • No Simulation • No Certification Test Please share this with anyone if your office that you feel necessary and let me know what additional information would be helpful. It will be provided promptly. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC — Kenai Ops Manager Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com 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. 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. Hilcorp Alaska, LLC June 2, 2020 Daniel Seamount, Commissioner Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Docket No. OTH 2O-008 Notice of Violation Conduct of Operations Wolf Lake Marathon 2 (PTD 1981420) Dear Commissioner Seamount: Taylor Wellman Operations Manager - Kenai Asset Team 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907/777-8449 twellman@hilcorp.com RECEIVED JUN 0 3 2020 AOGCC Hilcorp Alaska, LLC ("Hilcorp") responds to your March 10, 2020 letter regarding the downhole abandonment operations on Wolf Lake Marathon 2 that resulted in a release of freeze protect fluids on February 7, 2020. This response is beyond the 60 day timeframe due to COVID-19, including interruptions in receiving mail, difficulty scheduling the training, and uncertainty on how and when trainings could be conducted in accordance with state COVID mandates. Scope To provide an awareness level of well control. This will include source of the pressure, pressure control equipment, and well control methods/practices. With respect to well control equipment, the aim is to cover the higher level function and differences between the equipment used during various intervention types (slickline, electric line, coil tubing, and rig operations). Schedule Training courses are being scheduled and will be held in the fall of 2020. These courses will be completed by mid-October 2020. Personnel Attending Training For the Kenai Operations Team the following Hilcorp personnel will be enrolled in this training: Production Foreman, Lead Operators, Wellsite Managers and Downhole Operations Engineers. Some of the personnel listed already have a more advanced level of certification and will not be required to participate. Docket No. OTH 2O-008 June 2, 2020 Page 2 of 2 If you have any additional questions, please contact me. Sincerely, HILCORP ALASKA Taylor Wellman Operations Manager - Kenai Asset Team THE STATE "1AI,AsKA GOVERNOR MIKE DUNLEAVY March 10, 2020 CERTIFIED MAIL — RETURN RECEIPT REQUESTED 7015 0640 0003 5185 7011 Mr. Taylor Wellman Hilcorp Alaska LLC P.O. Box 244027 Anchorage, AK 99524-4027 Re: Docket Number: OTH-20-008 Notice of Violation Conduct of Operations Wolf Lake Marathon 2 (PTD 1981420) Dear Mr. Wellman, Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Hilcorp Alaska, LLC (Hilcorp) performed plug and abandon operations at the Wolf Lake Marathon 2 well site pursuant to Sundry Approval 319-192 dated April 12, 2019. Wolf Lake Marathon 2 is located within the Kenai National Wildlife Refuge. Wolf Lake Marathon 2 was constructed as a dual -tubing production well. Workover operations were conducted by the Hilcorp 401 pulling unit. On February 20, 2020, the Alaska Oil and Gas Conservation Commission (AOGCC) was notified by the U.S Fish and Wildlife Service (USFWS) and the Alaska Department of Environmental Conservation (ADEC) of an 84 -gallon spill of diesel freeze protect fluid released from the well during wireline tubing cutting operations on February 7, 2020. Both USFWS and ADEC contacts expressed concern about an incomplete explanation provided by Hilcorp. AOGCC requested additional detail from Hilcorp on February 20, 2020. Hilcorp responded by email dated February 27, 2020 and explained that the well's diesel freeze protect fluids "u -tubed" from the tubing -casing annulus up the long string when cut. The cause of the spill has been attributed by Hilcorp to a failure to recognize the potential of the well to u -tube (due to a hydrostatic differential between the tubing and tubing -casing annulus) and failure to maintain full pressure control or install a pack -off during the cutting operation. The circumstances resulting in the release of diesel freeze protect fluids from Wolf Lake Marathon 2 is a violation of 20 AAC 25.526, "Conduct of Operations". By email dated March 4, 2020, Hilcorp provided corrective actions addressing the conduct of operations during the plug and abandon operations designed to prevent recurrence, namely Docket Number: OTH-20-008 March 10, 2020 Page 2 of 2 - revised default standards for E -line operations on a drilling or workover rig including full pressure control, conditions for pack -off use, and requirements for further discussion with the Hilcorp Operations Engineer if open hole operations are justified; and - raising awareness of pressure control during downhole operations for rig and non -rig workovers operations. The training scope, schedule and appropriate personnel to be trained are being developed. Within 60 days, Hilcorp is requested to provide to AOGCC the scope, schedule and appropriate personnel to be trained. The information request is made pursuant to 20 AAC 25.300. Failure to comply with this request will be an additional violation. The AOGCC reserves the right to pursue an enforcement action in this matter according to 20 AAC 25.535. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Sincerely, Daniel T. Seamount, Jr. Commissioner cc: AOGCC Inspectors Phoebe Brooks Lynnda Kahn — USFWS P.O. Box 2139 Soldotna, AK 99669 ivnnda kahn ,fws.gov Mike Evans — ADEC 555 Cordova Street Anchorage, AK 99501 tni.ke.evans(d>,alaska.gov Carlisle, Samantha J (CED) From: Taylor Wellman <twellman@hilcorp.com> Sent: Tuesday, April 14, 2020 10:16 AM To: Carlisle, Samantha J (CED) Subject: RE: [EXTERNAL] FW: NOV - Conduct of Operations, Wolf Lake Marathon 2 Samantha, Thank you very much for sending this via email. I know this is not the usual method and appreciate the extra efforts while in these difficult times of Social Distancing. I will get a response back to the needed parties. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC - Kenai Ops Manager Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: Carlisle, Samantha J (CED) [mailto:samantha.carlisle@alaska.gov] Sent: Tuesday, April 14, 2020 8:26 AM To: Taylor Wellman <twellman@hilcorp.com> Subject: [EXTERNAL] FW: NOV - Conduct of Operations, Wolf Lake Marathon 2 Taylor - We sent this to the Hilcorp PO Box on March 10, 2020. It was unclaimed and returned to us. Please see attached letter. Thank you, Samantha Carlisle Exert tine Secretary- III Alaska Chit and Gas Conservation Commission 333 West 711, Avenue Anchorage, AK 99501 (907) 793-1223 COM II)t_NIIAt_IIYNOIICV: This e-r,nzail messagr, i:nchrding any attachments, contains information from the Alaska .Oil and Cos C'onswrvafion Commission sion (A0(',C;C'_ ), `plate of Alaska and is for the sola use of the intendod recipient(s). It may contain confidential and/or prnc ile-ed intormation. `rhe wIauthorized r(�tVjeev, uses or disclkisure of such information nury violate state or Ik'detraI late'. I you 'Irk, a I I uIli ntemilcd recipient of ffik e -aurin, plkerse deete it, without first saving or fore ardinv, it, and, so that the A0( -,CSC is ask are of the mistake in sending i t to you, cont,ii t Samantha Car lisle it (907) X73-1�2 � ox `+a_ur >nth�t_C:=trlislc �_ril nska,�,og_. From: Carlisle, Samantha J (CED) Sent: Tuesday, March 10, 2020 9:02 AM Subject: NOV - Conduct of Operations, Wolf Lake Marathon 2 Please see attached. Samantha Carlisle E,Aecu,tive Secretary III Alaska Oil anil Gas Conservation Commission 333 West 711, Avenue Anchorage, AK 99501 (907) 793-1223 CQN111)l .N'11ALI IY N01107: This e> -mail messal;e, includin; any attachant�nts, contains irtior ni ation from the Alaska 0i.l and C as ConservaIi nn Commission ), State irf Alaska and is for the sole usC of the intondud rccipietrt(s). It Wray s:ontain coirfidential surd/or privitt't,ed- information. I'lle unauthorized review, use or disclosure of such information inat violate state or federal ltiiV. iii Vou are are urlinterlded recipient of this e-mail, p(eusc delete it, without first saving or torwarding it., and, so that the AC)C'CC is aware of the mistake in sending it to Veru, contactSam mtha Carlisle at (4 07 ) 79").-1223 or S�unrnih? C_ar task*1 rsha.f;o��.. Carlisle, Samantha J (CED) From: Taylor Wellman <twellman@hilcorp.com> To: Carlisle, Samantha J (CED) Sent: Tuesday, April 14, 2020 10:13 AM Subject: Read: [EXTERNAL] FW: NOV - Conduct of Operations, Wolf Lake Marathon 2 Your message To: Subject: [EXTERNAL] FW: NOV - Conduct of Operations, Wolf Lake Marathon 2 Sent: Tuesday, April 14, 2020 6:12:53 PM (UTC+00:00) Monrovia, Reykjavik was read on Tuesday, April 14, 2020 6:12:44 PM (UTC+00:00) Monrovia, Reykjavik. Schwartz, Guy L (CED) From: Schwartz, Guy L (CED) Sent: Friday, March 6, 2020 8:54 AM To: Taylor Wellman Cc: Ted Kramer Subject: RE: [EXTERNAL] Upcoming BLM P & A wells Taylor, Thanks for information below on your corrective actions to date on the incident at Wolf Lake 2. The responses satisfy the AOGCC's concerns about moving forward with the other P &A wells in the Swanson River Field. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guy.schwartz@alaska.gov). From: Taylor Wellman <twellman@hilcorp.com> Sent: Wednesday, March 4, 2020 3:44 PM To: Schwartz, Guy L (CED) <guy.schwa rtz@alaska.gov> Cc: Ted Kramer <tkramer@hilcorp.com> Subject: RE: [EXTERNAL] Upcoming BLM P & A wells Guy, Here are the list of changes and the actions that have been taken to date to address and prevent reoccurrence in the future. For our Kenai operations default standards for E -Line operations through a rig: full pressure control, conditions for pack -off use and requirement for further discussion if open hole operations are justified to be conducted with our company representative and the Operations Engineer. This has been rolled out to the Operations Engineers and our rig company representatives (Co. Man). Raising general awareness to pressure control during downhole operations. We had been working with MNW Consulting on a course to achieve this for RWO's and non -rig pressure control. We have just finalized the scope, scheduling and tagging which individuals will attend this course later this year. Current schedule is looking to be 3Q. - Current Co. Men have been engaged and incident review has taken place. If you have any questions or would like to discuss any of these actions in further detail please let me know. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC — Kenai Ops Manager Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: Schwartz, Guy L (CED)[mailto:guy.schwartz@alaska.gov] Sent: Monday, March 2, 2020 3:05 PM To: Taylor Wellman <twellman@hilcorp.com> Cc: Ted Kramer <tkramer@hilcorp.com> Subject: [EXTERNAL] Upcoming BLM P & A wells Taylor, The below wells in the SCU have approved sundries for final P & A. Since the Wolf Lake 2 incident involving a tubing cut without any pressure control Hilcorp proposed several changes to make sure this didn't happen again. Hilcorp may continue to proceed with abandonment these wells under the condition that those recommendations have been implemented. Please respond in writing with your summary of your action to date to address the issues. SCU 314-03 SCU 12A-10 SCU 13-09 SCU 43-09 Additionally, the AOGCC will require a weekly update of RWO activity forecast for the Kenai Penn. (similar to what we get for the North Slope now.) Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission jAOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guy.schwartz@alaska.gov). The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication maybe legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. 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. Overview Prior to the 84 gallon diesel/methanol spill at Wolf Lake #2, well plugging activities were conducted that involved the use of a coil tubing unit to set a retainer and cement the short and long production strings as well at the annular space (space between the casing and the production strings) to effectively isolate the production zones from upper well bore. When coil and E -line tasks were completed, diesel was pumped down the production tubing strings as freeze protection and water was in the annular space. After setting the retainer and cementing the well, an integrity test was made to confirm hydraulic isolation. Results from the integrity testing identified communication between the annular space and one of the production strings which resulted in water that was in the annular space to drop below the top of the well bore. Since the well tree was still connected to the well bore all fluids would remain in the well bore. Diesel weights about 7 pounds per gallon while water weighs 8.34 pounds. The Well Site Supervisor discussed the status involving communications between the production string(s) and the annular space Contract Drilling Supervisor. The Contract Drilling Supervisor was in charge of overall operations of the 401 workover rig. The 401 rig was staged on the well with the blowout preventer (BOP) on the well head. Synthetic liner was placed on the rig floor to capture small drips or leaks. Rig 401 began activities to cut the long string at about 5731 feet and after the string was cut heavier water (8.34 pounds) in the annular space displaced the diesel (-7 pounds) in the long string. This resulted in diesel spilling out of the well bore and onto the rig floor and downward into the well cellar. Although the synthetic liner on the rig floor was there to capture small leaks, it was not the primary cause for the well fluids spilling to the cellar as first identified. Some sienificant findines: 4.1. Improper decision making or lack of judgment —The Contract Drilling Supervisor did not consider the potential differential pressure between the long string and annular space although the Well Site Supervisor had that discussion with the Contract Drilling Supervisor. 11.1. Inadequate Work Planning - The Contract Drilling Supervisor did not consider installing a shooting flange or other recognized method to provide protection if it is not known if there is pressure on the well or its components. Had assumed that the there was no pressure. 15.1. Inadequate Horizontal Communication Between Peers - Coil and E -line work preceded work involving the 401 rig. It was communicated that after coil and E -line were completed, there was communication between one of the production strings and the annular space and that there was diesel in the long and short strings and water in the annular space. It was fully identified that the communication meant that there was differential pressure between one of the production strings and the annular space. Well Schematic The well schematic provides additional information for Wolf Lake #2 Schwartz, Guy L (CED) From: Taylor Wellman <twellman@hilcorp.com> Sent: Thursday, February 27, 2020 7:52 AM To: Schwartz, Guy L (CED) Cc: Ted Kramer Subject: RE: [EXTERNAL] Wolf Lake 2 spill incident (PTD 198-142) Follow Up Flag: Follow up Flag Status: Flagged Guy, Please find below an outline of the situation and events that led to the spill on Wolf Lake #2. Timeline/Sequence of Events: - Coil tubing performed a reservoir isolation (pumping through a cement retainer on the long string). Retainer at 5,940' and w/ 58bbis of 15.8ppg cement pumped. PT'd long string to 2,OOOpsi. Freeze protect long string with diesel while POOH. RD CT unit. - Load and kill down the short string. IA static. Bleed short string, IA, and long string to 0 psi. Set BPV. - 401 Rig RU. Set blanking plug. ND tree, NU BOP's. Test BOP's (full sequence of tests w/ dual VBR's on 2-3/8" and 2-7/8") witnessed by Lou Laubenstein. Pull blanking plug and BPV's. - EL RU through rig and go to cut the long string. Cut long string at 5,731' md. U -tubed from the IA up the long string to spill on the rig floor. - EL cuts the short string above the packer at 5,991' md. Short string and IA in communication. Well Condition During Spill: - Long String: Reservoir isolated with cement plug and 2,OOOpsi PT performed good. Hydrostatic column of diesel and 9.8ppg brine. - Short String/IA: Confirmed communication with IA. Pumping down the short string and direct pressure communication seen in the IA (expected past packer). Loaded, killed and Opsi. Hydrostatic column of 9.8ppg brine. Causes for spill: - Underbalance from the diesel freeze protect in the long string vs. the IA/short string. This was not recognized by our WSM and rig personnel. During the rig up of EL on the rig, full pressure control or a packoff was not installed. This is not our typical mode of operation. We have recently been working with different EL company and miscommunication between the EL company and our WSM led to them not installing a packoff. Once the cutter was on depth, it was recognized by the WSM that there was no packoff. Checking of pressures on SS/LS/IA = 0/O/Opsi, which led the WSM to believe that there wasn't an issue with proceeding with the cut. The hydrostatic column differential was missed, which led to the spill. Multiple issues have been identified and we are going through and tightening up for our Kenai operations: o Default standards for pressure control/packoff when using EL through the rig unless otherwise stated and/or discussions with Ops Engineer as to the unique circumstances otherwise. o Communication between multiple parties of well condition at each stage. This was conducted but investigating further if there are better ways to achieve this. o Re-evaluating our WSM's and rig supervision to see if we have the correct personnel in place. If you'd like to discuss any of these points please reach out. Thank you, Taylo r Taylor Wellman Hilcorp Alaska, LLC — Kenai Ops Manager Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: Schwartz, Guy L (CED)[mailto:guy.schwartz@alaska.gov] Sent: Wednesday, February 26, 2020 3:09 PM To: Taylor Wellman <twellman@hilcorp.com> Cc: Ted Kramer <tkramer@hilcorp.com> Subject: [EXTERNAL] Wolf Lake 2 spill incident (PTD 198-142) Taylor, Still waiting on more detailed fluid to surface. (2/7/20) Thanks, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office explanation on what happened on Wolf Lake 2 back several weeks ago regarding u -tubed CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guv.schwartz@alaska.gov). The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. 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. ff Hilcorp Alaska. LLC. Permit #: 198-142 (Re -Entry) API #: 50-133-20375-90 Prop. Des: CIRI (84-201) KB elevation: 247' (21' AGL) Spud: 11/10/1984 TD: 2/01/1985 Rig Released: 2/22/1985 LS Tree cap = 3-1/2" 8RD SS Tree cap = 3-1/2" 8RD Dual Cameron Hanger (14.4' RKB) LS Lift Threads = 3-112" 8RD SS Lift Threads = 3-1/2" 8RD Casing Cementing Casing Lead Tail 20" 250 sx 13-3/8" 2445 sx 9-5/8" x 13-3/8" Annulus 300 sx 15.8 ppg 9-5/8" 700 sx 13.5 ppg 300 sx 15.8 ppg 7" 900 sx 15.8 ppg WL -2 Wolf Lake Pad 1,183' FSL, 2,265' FWL, Sec. 29, WN, R9W, S.M. Casing Punches I 155'- 159' 13-3/8" A B C — D Jewelry (Long String) Depth ID 2. Baker 9-5/8" GT Dual Packer (shear at 70k) 5,991' 2.939" 3. 2-7/8" Sliding Sleeve 6,037' 2.313" 4. 2-7/8" X -Profile 6,077' 2.313" 5. Top of Blast Joints 6,088' 2.441" 6. Btm of Blast Joints 6,527' 2.441" 7. Baker 194-32 DB Permanent Packer 6,861' 3.250" 8.2 -7/8"X -Profile 6,910' 2.313" 9. Top of Blast Joints 7,004' 2.441" 10. Btm of Blast Joints 7,044' 2.441" 11. Balanced Isolation Tool 7,110' 2.441" 12. TCP Firing Head 7,143' 2.441" 13. WLEG 7,151' 2.441" 14. 4-5/8" TCP Guns & Blank Spacer Guns 7,752' - 15. 4-5/8" 1 CP Guns (36) & 10' 1-1/4" drop bar 8,023' 6.5 ppf 8RD 16. Baker'6AA' CIBP 8,069' MD 0' 17. Old 12.0 ppg mud 8,070' 7,109' 18. Cement plug 11,385' 9/05/02 19. EZSV Cement Retainer 11,485' 28' Jewelry (Short Strina) Depth ID 3.; omg Bottom MD 22' B. Baker 9-5/8" GT Dual Packer (shear at 70k) 5,991' 2.939" C. 2-3/8" XN profile 6,008' 1.810" D. 2-3/8" WLEG 6,010' 1.995" Tag Fill 2.0" DD Bailer 7,474' RKB 10/21/02 15— 17-- 19--- TD 14,451' MD 14,086' TVD 9-5/8" Good Cement: 3,300' - 4,100' Questionable Cement: 4,100' - 5,100' Ultrasonic Imager (10-16-98) Casing Punches 4,230' - 4,234' 4 489 - 4493' 9-5/8" TOC Unknown Beluga Perls (Squeezed & Isolated) Cleanout Fill 1.50" Coil 6,530' CTM 2/06/03 Tyonek Perfs(Squeezed & Isolated) PROPOSED SCHEMATIC Conductor Casing (Cemented) 20" K-55 133 ppf T -OD Bottom MD 22' 52' TVD 22' 52' Surface Casing 13-3/8" N-80 72 ppf BTC 13-3/8" K-55 68 ppf BTC 13-3/8" L-80 72 ppf BTC TOP Bottom MD 0' 4,344' TVD 0' 4,343' Production Casing 9-5/8" S-95 53.5 ppf BTC 9-5/8" S-95 47 ppf BTC Top Bottom MD 0' 12,151' TVD 0' 11,817' Liner 7" S-125 32 ppf BTC Toe Bottom MD 11,826' 13,383' TVD 11,501' 13,032' Tubing (LS) 2-7/8" L-80 6.5 ppf 8RD Too Bottom MD 0' 7,151' TVD 0' 7,109' Tubing (SS) 2-3/8" L-80 4.6 ppf IBT Top_ Bottom MD 0' 6,010' TVD 0' 6,007' 3.A Plugs & Cement Depth i. CIBP w/ Cement to Surface -160' II. CIBP w/ 250'+ of Cement on top -4,494' (TOC @ or above 4,244') TVD III. 9-5/8" Cement Retainer w/ -35' cmt on top -5,983' (TOC @ -5,948') Date Tyonek Perfs!Squeezed & Isolated) Perforations: WOLF LAKE #2 Lease: CIRI (84-201) County or Parish: Kenai Peninsula Borough MD TVD Ft Zone SPF Date 6,095'-6,110' 6,090'-6,105' 15' Beluga 5 9/05/02 6,166'-6,176' 6,160'-6,169' 10' Beluga 5 9/05/02 6,202'-6,210' 6,195'-6,203' 8' Beluga 5 9/05/02 6,356'-6,379' 6,346'-6,368' 23' Beluga 5 9/05/02 6,392'-6,420' 6,381'-6,408' 28' Beluga 12 10/20/98 6,454'-6,466' 6,441'-6,453' 12' Beluga 5 9/05/02 6,506'-6,520' 6,492'-6,506' 14' Beluga 5 9/05/02 7,010'-7,038' 6,974'-7,001' 28' Tyonek 12 10/25/98 7,398'-7,468' 7,344'-7,411' 70' Tyonek 5 9/13/02 PBTD 0' MD 0' TVD Well Name & Number: WOLF LAKE #2 Lease: CIRI (84-201) County or Parish: Kenai Peninsula Borough State/Prov: Alaska I Country: USA Angle @KOP and Depth: 1° @ 5,700' 1 Angle/Perfs 1 11°-18° Maximum Deviation: 1 26.1° @ 8,400' Date Completed: 9/9/2002 Ground Level (above MSL): 226'RKB (above GL): 21' Revised By: Stan Porhola Downhole Revision Date: 2/6/2003 Schematic Revision Date: 1 6/19/2014 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReggDATE: February 12, 2020 P.I. Supervisor 711 SUBJECT: SUBJECT: Well Bore Plug & Abandonment Wolf Lake Marathon #2 - FROM: Brian Bixby Hilcorp Alaska Petroleum Inspector PTD 1981420; Sundry 319-192 Section: 29 Township: 7N Range: 9W Drilling Rig: Hilcorp 401 Rig Elevation: Total Depth: 14451 ft MD Operator Rep: Harold Soule Suspend: Casing/Tubing Data (depths are MD): Conductor: 20" 0. D. Shoe@ 52 - Feet Surface: 13 3/8" O.D. Shoe@ 4,344 - Feet Intermediate: 5729 Feet 0. D. Shoe@ Feet Production: 95/8" 0. D. Shoe@ 12,151 - Feet Liner: 7" 0. D. Shoe@ 13,383 - Feet SS Tubing: 2 3/8" - 0. D. Tail@ 6010 - Feet LS Tubing: 2 7/8" - 0. D. Tail@ 7151 - Feet Plugging Data: Test Data: Meridian: Seward Lease No.: Fee - CIRI P&A: X Type Plug Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ 5729 Feet Tbg Cut@ 5731 Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Fullbore Bridge plug 5727 ft MD" 5241 ft MD 9.1 ppg brine Wireline tag NA NA Initial 15 min 30 min 45 min Raatilt Tubing 2200 2100 2150 IA 0 0 — 0 P OA NA NA NA Remarks: This is Plug #2. 1 witnessed the top of cement tag with slickline and bailer at 5241 ft MD. The sample from the bailer was good cement. Attachments: none rev. 11-28-18 2020-0212_Plug_Verification_WolfLk-2_bb From:Schwartz, Guy L (CED) To:Ted Kramer Cc:Donna Ambruz Subject:RE: Wolf Lake #2 P&A Procedure Revision PTD 198-142, Sundry 319-192 Date:Thursday, January 9, 2020 1:36:00 PM Ted, You have approval to modify the sundry as proposed in your attachment. In Step 6 add a pressure test of LS to 2000 psi /30 min after cementing. In step 25 add pressure test of the 9 5/8” retainer after cementing to 2000 psi/ 30 min /Chart. (This is the main reservoir barrier.) Update the MOC form and have this email with modified procedure on location. BTW .. the new schematic should show the 150’ cement in the OA ( 13 5/8” x 9 5/8”) to surface. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From: Ted Kramer <tkramer@hilcorp.com> Sent: Thursday, January 9, 2020 9:18 AM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: Wolf Lake #2 P&A Procedure Revision PTD 198-142, Sundry 319-192 Guy, Attached is the proposed procedure revision for Wolf Lake #2 P&A that has been discussed. Everything in Red constitutes the changes. Please let me know if these changes can be handled with the Change Form or will we need to resubmit the Sundry? Timing – once approved, we would like to get Coil tubing out next week and Rog 401 on the well right after coil finishes. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp-Alaska LLC Office – 907-777-8420 Cell – 985-867-0665 The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e- mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. 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. Well Prognosis Well: WL #2 Date: 01/09/2020 Well Name: Wolf Lake #2 API Number: 50-133-20375-90 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: May 1, 2019 Rig: 401 Reg. Approval Req’d? 10-403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 198-142 First Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (M) Second Call Engineer: Bo York (907) 777-8345 (O) (907) 727-9247 (M) AFE Number: Current Bottom Hole Pressure: ~ 3,505 psi @ 7,411’ TVD (Based upon a 0.473 psi/ft gradient to the deepest open perforation) Maximum Expected BHP: ~ 3,505 psi @ 7,411’ TVD (Based upon a normal gradient) Max. Potential Surface Pressure: ~ 2,764 psi (Based upon max. expected BHP and a 0.10 psi/ft gas gradient to surface) Brief Well Summary: Wolf Lake #2 (WL #2) was originally drilled (PTD 184-201), logged, and tested (DST) by ARCO in November 1984. Following logging and testing, ARCO P&A’d the well in February 1985. WL #2 was re-entered by Marathon (PTD 198-142) in October 1998 and the wellbore perforated in the Beluga and Tyonek sands. The wellbore completion isolated the two zones with dual packers on 3-1/2” tubing, with a sliding sleeve across the Beluga interval. First gas sales were in November 2001. In August 2002, the original Marathon completion was pulled, the wellbore cleaned out, and the Beluga and Tyonek intervals re-perforated (& zones added). A dual string completion was run, with the Beluga intervals producing from the Short String (2-3/8” tubing) and the Tyonek sands producing from the Long String (2-7/8” tubing). In October 2002, it was noted that the Tyonek sands were not producing, and that all gas production was coming from the Beluga formation (via the Short String). The Beluga intervals produced gas and water on a relatively continuous basis from October 2002 through October 2005, and has remained mostly shut-in since. WL #2 has had no production since August 2007. The purpose of this Sundry is to permanently P&A the Wolf Lake #2 well. Pre - Rig Work: Prior to moving the 401 workover rig onto location, Hilcorp attempted to run wireline down the 2-7/8” tubing string (Long String). Wireline was not able to pass through the dual packer at 5,991’. Coil tubing was then brought out in an attempt to gain access to the 2-7/8” tubing, but was also unable to pass through the dual packer. As such, Hilcorp is not able to punch holes in (for circulation purpose) nor cut off the Long String below the dual packer (above the lower permanent packer), as was previously proposed. This will make pulling the Long String out of hole, with the dual packer, extremely difficult. As a result, Hilcorp now proposes to abandon the well leaving the dual packer in place. Each tubing string will be abandoned separately, via squeeze cementing through cement retainers. Pump in tests were conducted on both tubing strings. The results were: a. Long String (2-7/8”) – 2.0 bpm @ 1,000 psi b. Short String (2-3/8”) – 3.2 bpm @ 1,100 psi Well Prognosis Well: WL #2 Date: 01/09/2020 1. Provide 24 hour notice to the AOGCC that Plug and Abandonment of well will commence per AOGCC regulations 20 AAC 25.112 (h). 2. RU Pump Truck. RU on the tubing and casing in order to conduct an IA pressure test to 3,500 psi on chart for 30 min. WL #2 is a dual string completion, so the Long String (2-7/8”) and Short String (2-3/8”) tubing will both need to be monitored during the IA test. Bleed down pressure. Coiled Tubing Unit: 3. MIRU coiled tubing unit (CTU) onto the 2-7/8” tubing string (Long String). 4. RIH with a 2-7/8” cement retainer, on 1-1/2” coil, to approximately 5,990’ (just above dual packer @ 5,991’). 5. RU cementers and squeeze the Tyonek perforations (by down squeeze method) with 58 bbls of 15.8 ppg cement. a. Note: Tubing + Annular volume = ~46 bbls. b. 25% excess pumped/squeezed to ensure perforation isolation. 6. POOH w/ Coil and WOC. 7. RU E-line on the Short String (2-3/8” tubing). 8. PU & RIH w/ Tubing Cutter to ~5,985’. 9. Cut Short String @ ~5,985’ & POOH. 10. RU E-line on the Long String (2-7/8” tubing). 11. PU & RIH w/ Tubing Cutter to ~5,985’ (just above cement from previous Tyonek cement squeeze) 12. Cut Long String @ ~5,985’ & POOH. Workover Rig 401: 13. MIRU Rig 401. 14. Notify AOGCC 24 hours in advance of test to extend the opportunity to witness. 15. Set back pressure valve. 16. ND wellhead, NU 13-5/8” BOP and test to 250 psi low & 3,000 psi high, annular to 250 psi low & 2,500 psi high. Record accumulator pre-charge pressures and chart tests. a. Perform Test. b. Test Dual VBR rams on 2-7/8” and 2-3/8” test joints. c. Submit completed form 10-424 to AOGCC within 5 days of BOPE test. 17. PU on Short String (2-3/8” tubing) and circulate the well with kill weight fluid. 18. POOH w/ Short String, laying down pipe. 19. PU on Long String (2-7/8” tubing) and once again circulate the well with kill weight fluid. 20. POOH w/ Long String laying down chemical injection sub and racking back pipe. 21. PU 9-5/8” Cement Retainer & RIH on 2-7/8” tubing. 22. Set Cement Retainer @ ~5,983’. a. 9-5/8” Cement Retainer should be set just above the 2-7/8” and 2-3/8” tubing stubs (@ ~5,985’). 23. RU cementers and squeeze the Beluga perforations (by down squeeze method) with 46.5 bbls of 15.8 ppg cement. c. Note: Tubing + Annular volume = ~37 bbls. d. 25% excess pumped/squeezed to ensure perforation isolation. Well Prognosis Well: WL #2 Date: 01/09/2020 24. Pull out of cement retainer and leave an additional 4 bbls of cement (~53’) on top of the retainer. 25. POOH w/ tubing, racking back pipe. WOC. Note: An Ultrasonic Imaging Log (run 10-16-98) indicates the 9-5/8” annulus has good quality cement behind pipe from ~3,300’ to ~4,100’ and questionable cement from ~4,100’ to ~5,100’. The 13-3/8” surface casing shoe depth is 4,344’. Considering the good quality cement 244’+ above the shoe, Hilcorp will not be able to circulate (down IA & up casing) a cement plug into place across the shoe. Hilcorp will however punch casing holes above and below the shoe and attempt to push cement into the IA, across the shoe (marginal cement on image log). 26. RU E-line. 27. PU & RIH w/ 9-5/8” CIBP to ~4,494’. Set same depth. POOH. 28. PU 1st casing punch and RIH to ~4,493’. Punch holes from ~4,493’ – 4,489’. POOH. 29. PU 2nd casing punch and RIH to ~4,234’. Punch holes from ~4,234’ to 4,230’. POOH. 30. PU and RIH w/ 2-7/8” tubing (open ended) to 4,493’. 31. RU cementers & place a 450’ (~33 bbls) plug of cement on top of the CIBP. 32. Pressure up 500 psi on the well and hold for 30 min. POOH & WOC. 33. RU slickline & RIH to tag top of cement. Verify that TOC is at (or above) 4,244’ to ensure at least 100’ of cement extends above the surface casing shoe. POOH & RD Slickline. 34. RU E-line. 35. PU & RIH with 9-5/8” CIBP. Set plug at 160’. POOH. 36. PU 3rd casing punch and RIH to 159’. Punch holes from 159’ – 155’. POOH. 37. RU cementers and circulate cement down the IA and up the 9-5/8” casing, through the holes at 159’ – 155’. WOC. a. If circulation can’t be established, PU & RIH with 2-7/8” tubing (open ended) and place a 160’ plug of cement from the CIBP to surface. POOH and lay down pipe. WOC. 38. Place dry hole tree on well. 39. RDMO Workover Rig 401. Post - Rig Abandonment Procedures: 40. Excavate cellar, cut off casing 3’ below natural GL. 41. Notify AOGCC 48hrs in advance. 42. Create well abandonment marker per AOGCC regulation 20 AAC 25.120. The following must be bead-welded directly to the marker plate: a. Hilcorp Alaska, LLC b. PTD: 198-142 c. Well Name: Wolf Lake #2 d. API: 50-133-20375-90 43. Set marker plate per 20 AAC 25.120, collect GPS coordinates. 44. Photo document casing cut-off and Welded Plate install. 45. Backfill excavation, close out location. Attachments: Actual Schematic Proposed Schematic BOPE Schematic RWO Sundry Revision Change Form Lease: State/Prov:Alaska Country:USA Angle/Perfs:11°-18° 226'21' 2/6/2003 6/19/2014 Date Completed:9/9/2002 Ground Level (above MSL):RKB (above GL): Revised By:Stan Porhola Downhole Revision Date:Schematic Revision Date: CIRI (84-201) County or Parish:Kenai Peninsula Borough Angle @KOP and Depth:1º @ 5,700'Maximum Deviation:26.1º @ 8,400' Well Name & Number:WOLF LAKE #2 WL -2 Wolf Lake Pad 1,183' FSL, 2,265' FWL, Sec. 29, T7N, R9W, S.M. PBTD 8,069' MD 7,979' TVD 14 19 A Liner 7" S-125 32 ppf BTC Top Bottom MD 11,826' 13,383' TVD 11,501' 13,032' B Production Casing 9-5/8" S-95 53.5 ppf BTC 9-5/8" S-95 47 ppf BTC Top Bottom MD 0' 12,151' TVD 0' 11,817' Perforations: MD TVD Ft Zone SPF Date 6,095'-6,110' 6,090'-6,105' 15' Beluga 5 9/05/02 6,166'-6,176' 6,160'-6,169' 10' Beluga 5 9/05/02 6,202'-6,210' 6,195'-6,203' 8' Beluga 5 9/05/02 6,356'-6,379' 6,346'-6,368' 23' Beluga 5 9/05/02 6,392'-6,420' 6,381'-6,408' 28' Beluga 12 10/20/98 6,454'-6,466' 6,441'-6,453' 12' Beluga 5 9/05/02 6,506'-6,520' 6,492'-6,506' 14' Beluga 5 9/05/02 7,010'-7,038' 6,974'-7,001' 28' Tyonek 12 10/25/98 7,398'-7,468' 7,344'-7,411' 70' Tyonek 5 9/13/02 Casing Cementing Casing Lead Tail 20" 250 sx 13-3/8" 2445 sx 9-5/8" x 13-3/8" Annulus 300 sx 15.8 ppg 9-5/8" 700 sx 13.5 ppg 300 sx 15.8 ppg 7" 900 sx 15.8 ppg TD 14,451' MD 14,086' TVD Permit #: 198-142 (Re-Entry) API #: 50-133-20375-90 Prop. Des: CIRI (84-201) KB elevation:247' (21' AGL) Spud:11/10/1984 TD:2/01/1985 Rig Released:2/22/1985 Tubing (LS) 2-7/8" L-80 6.5 ppf 8RD Top Bottom MD 0' 7,151' TVD 0' 7,109' Surface Casing 13-3/8" N-80 72 ppf BTC 13-3/8" K-55 68 ppf BTC 13-3/8" L-80 72 ppf BTC Top Bottom MD 0' 4,344' TVD 0' 4,343' Conductor Casing (Cemented) 20" K-55 133 ppf Top Bottom MD 22' 52' TVD 22' 52' ACTUAL SCHEMATIC C LS Tree cap = 3-1/2" 8RD SS Tree cap = 3-1/2" 8RD Dual Cameron Hanger (14.4' RKB) LS Lift Threads = 3-1/2" 8RD SS Lift Threads = 3-1/2" 8RD 20" 13-3/8" 9-5/8" 7" Tyonek D 13 Tubing (SS) 2-3/8" L-80 4.6 ppf IBT Top Bottom MD 0' 6,010' TVD 0' 6,007' Jewelry (Long String)Depth ID 1.Chemical Injection Sub 1,696' 2.441" 2.Pup Joint above Packer 5,977' 2.441" 3.Baker 9-5/8" GT Dual Packer (shear at 70k) 5,991' 2.939"4. 2-7/8" Sliding Sleeve 6,037' 2.313"5.2-7/8" X-Profile 6,077' 2.313" 6.Top of Blast Joints 6,088' 2.441"7.Btm of Blast Joints 6,527' 2.441" 8.Baker 194-32 DB Permanent Packer 6,861' 3.250"9.2-7/8" X-Profile 6,910' 2.313" 10.Top of Blast Joints 7,004' 2.441"11.Btm of Blast Joints 7,044' 2.441"12.Balanced Isolation Tool 7,110' 2.441" 13.TCP Firing Head 7,143' 2.441"14.WLEG 7,151' 2.441" 15.4-5/8" TCP Guns & Blank Spacer Guns 7,752' - 16.4-5/8" TCP Guns (36') & 10' 1-1/4" drop bar 8,023' - 17.Baker '6AA' CIBP 8,069' - 18.Old 12.0 ppg mud 8,070' - 19.Cement plug 11,385' - 20.EZSV Cement Retainer 11,485' - 11 9 8 Jewelry (Short String)Depth ID A.Chemical Injection Sub 1,599' 1.995" B. Pup Joint above Packer 5,980' 1.995" C.Baker 9-5/8" GT Dual Packer (shear at 70k) 5,991' 2.939" D. 2-3/8" XN profile 6,008' 1.810" E. 2-3/8" WLEG 6,010' 1.995" TOC (Est) 3,332'-4,322' 20 18 17 Tag Fill 2.0" DD Bailer 7,474' RKB 10/21/02 Tyonek Beluga E 1 2 3 4 5 6 7 10 12 15 16 Cleanout Fill 1.50" Coil 6,530' CTM 2/06/03 9-5/8" TOC Unknown Lease: State/Prov:Alaska Country:USA Angle/Perfs:11°-18° 226'21' 2/6/2003 6/19/2014 Date Completed:9/9/2002 Ground Level (above MSL):RKB (above GL): Revised By:Stan Porhola Downhole Revision Date:Schematic Revision Date: CIRI (84-201) County or Parish:Kenai Peninsula Borough Angle @KOP and Depth:1º @ 5,700'Maximum Deviation:26.1º @ 8,400' Well Name & Number:WOLF LAKE #2 WL -2 Wolf Lake Pad 1,183' FSL, 2,265' FWL, Sec. 29, T7N, R9W, S.M. PBTD 0' MD 0' TVD 13 18 I Liner 7" S-125 32 ppf BTC Top Bottom MD 11,826' 13,383' TVD 11,501' 13,032' A Production Casing 9-5/8" S-95 53.5 ppf BTC 9-5/8" S-95 47 ppf BTC Top Bottom MD 0' 12,151' TVD 0' 11,817' Perforations: MD TVD Ft Zone SPF Date 6,095'-6,110' 6,090'-6,105' 15' Beluga 5 9/05/02 6,166'-6,176' 6,160'-6,169' 10' Beluga 5 9/05/02 6,202'-6,210' 6,195'-6,203' 8' Beluga 5 9/05/02 6,356'-6,379' 6,346'-6,368' 23' Beluga 5 9/05/02 6,392'-6,420' 6,381'-6,408' 28' Beluga 12 10/20/98 6,454'-6,466' 6,441'-6,453' 12' Beluga 5 9/05/02 6,506'-6,520' 6,492'-6,506' 14' Beluga 5 9/05/02 7,010'-7,038' 6,974'-7,001' 28' Tyonek 12 10/25/98 7,398'-7,468' 7,344'-7,411' 70' Tyonek 5 9/13/02 Casing Cementing Casing Lead Tail 20" 250 sx 13-3/8" 2445 sx 9-5/8" x 13-3/8" Annulus 300 sx 15.8 ppg 9-5/8" 700 sx 13.5 ppg 300 sx 15.8 ppg 7" 900 sx 15.8 ppg TD 14,451' MD 14,086' TVD Permit #: 198-142 (Re-Entry) API #: 50-133-20375-90 Prop. Des: CIRI (84-201) KB elevation:247' (21' AGL) Spud:11/10/1984 TD:2/01/1985 Rig Released:2/22/1985 Tubing (LS) 2-7/8" L-80 6.5 ppf 8RD Top Bottom MD 0' 7,151' TVD 0' 7,109' Surface Casing 13-3/8" N-80 72 ppf BTC 13-3/8" K-55 68 ppf BTC 13-3/8" L-80 72 ppf BTC Top Bottom MD 0' 4,344' TVD 0' 4,343' Conductor Casing (Cemented) 20" K-55 133 ppf Top Bottom MD 22' 52' TVD 22' 52' PROPOSED SCHEMATIC B LS Tree cap = 3-1/2" 8RD SS Tree cap = 3-1/2" 8RD Dual Cameron Hanger (14.4' RKB) LS Lift Threads = 3-1/2" 8RD SS Lift Threads = 3-1/2" 8RD 20" 13-3/8" 9-5/8" 7" Tyonek Perfs (Squeezed & Isolated) C 12 Tubing (SS) 2-3/8" L-80 4.6 ppf IBT Top Bottom MD 0' 6,010' TVD 0' 6,007' Jewelry (Long String)Depth ID 1.Top of 2-7/8" Tubing stub 5,985' 2.441" 2.Baker 9-5/8" GT Dual Packer (shear at 70k) 5,991' 2.939"3. 2-7/8" Sliding Sleeve 6,037' 2.313"4.2-7/8" X-Profile 6,077' 2.313" 5.Top of Blast Joints 6,088' 2.441"6.Btm of Blast Joints 6,527' 2.441" 7.Baker 194-32 DB Permanent Packer 6,861' 3.250"8.2-7/8" X-Profile 6,910' 2.313" 9.Top of Blast Joints 7,004' 2.441"10.Btm of Blast Joints 7,044' 2.441"11.Balanced Isolation Tool 7,110' 2.441" 12.TCP Firing Head 7,143' 2.441"13.WLEG 7,151' 2.441" 14.4-5/8" TCP Guns & Blank Spacer Guns 7,752' - 15.4-5/8" TCP Guns (36') & 10' 1-1/4" drop bar 8,023' - 16.Baker '6AA' CIBP 8,069' - 17.Old 12.0 ppg mud 8,070' - 18.Cement plug 11,385' - 19.EZSV Cement Retainer 11,485' - 10 8 7 Jewelry (Short String)Depth ID A. Top of 2-3/8" Tubing stub 5,985' 1.995" B.Baker 9-5/8" GT Dual Packer (shear at 70k) 5,991' 2.939" C. 2-3/8" XN profile 6,008' 1.810" D. 2-3/8" WLEG 6,010' 1.995" 19 17 16 Tag Fill 2.0" DD Bailer 7,474' RKB 10/21/02 Beluga Perfs (Squeezed & Isolated) D 1 2 3 4 5 6 9 11 14 15 Cleanout Fill 1.50" Coil 6,530' CTM 2/06/03 9-5/8" TOC Unknown P&A Plugs & Cement Depth I. CIBP w/ Cement to Surface ~160' II. CIBP w/ 250'+ of Cement on top ~4,494' (TOC @ or above 4,244') III. 9-5/8" Cement Retainer w/ ~35' cmt on top ~5,983' (TOC @ ~5,948') II III Good Cement: 3,300' -4,100' Questionable Cement: 4,100' -5,100' Ultrasonic Imager (10-16-98) Tyonek Perfs (Squeezed & Isolated) Casing Punches: 4,230' -4,234'4,489' -4,493' Casing Punches:155' -159' Davies, Stephen F (CED) From: Davies, Stephen F (CED) Sent: Tuesday, July 23, 2019 10:25 AM To: Bo York; Ted Kramer Cc: Schwartz, Guy L (GED); Rixse, Melvin G (CED) Subject: Wolf Lake 1 RD (PTD 202-088, Sundry 319-191) and Wolf Lake 2 (PTD 198-142, Sundry 319-192) - Questions Bo and Ted, was contacted by the U.S. Fish & Wildlife Service (USFWS) at Kenai National Wildlife Refuge (KNWR) regarding Hilcorp's planned plugging and abandonment operations and location clearance inspections for Wolf Lake 1RD and Wolf Lake 2. On the approved Sundry Application for Wolf Lake 1RD, a hand-written comment added by AOGCC states that site clearance requires landowner approval from CIRI. On the approved Sundry Application for Wolf Lake 2, a hand-written comment added by AOGCC states that site clearance requires approval from BLM. Regulation 20 AAC 25.170 (a)(2) states that unless the operator demonstrates to the commission that the surface owner has authorized a different disposition to facilitate a genuine beneficial use, the operator shall (A) remove all materials, supplies, structures, and installations from the location; (B) remove all loose debris from the location; (C) fill and grade all pits or close them in another manner approved by the commission as adequate to protect public health and safety; and (D) leave the location in a clean and graded condition. KNWR is the surface owner and manager for the gravel pad (location) from which both wells were drilled. AOGCC's well history file for Wolf Lake 1RD contains a July 27, 2009 letter from CIRI to the AOGCC that states the paths for these two wells passes through CIRI mineral -interest acreage, and that CIRI holds the deep mineral rights along with the rights to any other non -oil and gas subsurface estate within the affected leases. The letter then requests AOGCC notify CIRI of any and all applications and actions involving these wells or leases. It is my understanding that BLM the has no subsurface jurisdiction regarding either of these wells. KNWR and CIRI have expressed interest in being notified or involved in all activities regarding these wells and leases. Questions: 1. When does Hilcorp plan to plug and abandon Wolf Lake 1RD and Wolf Lake 2? 2. Has Hilcorp contacted either KNWR or CIRI regarding the planned plugging and abandonment operations for these wells? 3. Does Hilcorp plan to meet with KNWR or CIRI representatives or involve them in planning or organizing the abandonment operations? 4. Does Hilcorp plan to invite representatives from these organizations to participate in the location clearance inspections that are required by 20 AAC 25.170? Thank you for your help. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 Davies, Stephen F (CED) From: Davies, Stephen F (CED) Sent: Tuesday, July 23, 2019 10:33 AM To: Kahn, Lynnda Subject: RE: Wolf Lake 1 RD (PTD 202-088, Sundry 319-191) and Wolf Lake 2 (PTD 198-142, Sundry 319-192) Hi Lynnda, Please accept my apologies for this delayed response. I sent an email to the operator asking about timing of the plugging, abandonment, and site clearance inspections for these two wells and whether they have contacted, or plan to involve, USFWS and CIRI in those operations. I will let you know when I hear something. Regards, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesPalaska.gov. From: Kahn, Lynnda <lynnda_kahn@fws.gov> Sent: Tuesday, July 9, 2019 3:34 PM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Cc: Stephen Miller <stephen_a_miller@fws.gov>; Sharon Yarawsky <syarawsk@blm.gov> Subject: Sundry 319-191 and 319-192 Wolf Lake 1 RD & 2 Hi Steve, I hope this finds you well, and am once again looking for some assistance. I am in receipt of 2 applications for Sundry Approval, e.g. Sundry 319-192 for Wolf Lake 2 and Sundry 319-191 for Wolf Lake 1 RD. For the Wolf Lake 1 RD well, the Sundry Application references that site clearance is required from CIRI for landowner approval, while the other Application (Wolf Lake 2 well) states that site clearance is required from BLM in reference to pad approval. However, the Kenai NWR is the surface owner and manager for the well pad on which both wells are located. CIRI is the sub-surface/mineral owner there, and to our knowledge, BLM has no down -hole jurisdiction. I'm hoping you can help me determine how to correct this on the P&A approvals from the State, as coordination on the P&A's with the Refuge would be appreciated. In addition, we must be involved in the surface reclamation efforts involving these 2 wells and the other remaining infrastructure located within Refuge boundaries. I'll look forward to hearing from you. Thanks Steve. LYNNDA KAHN Fish and Wildlife Biologist Kenai National Wildlife Refuge I U.S. Fish E wildlife Service P.O. Box 2139 1 Soldotna, AK _ 907.260.2818 - Office THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission Re: Wolf Lake Field, Tyonek and Beluga Undefined Gas Pool, Wolf Lake 2 Permit to Drill Number: 198-142 Sundry Number: 319-192 Dear Mr. York: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.olaska.gov Enclosed is the approved application for the 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, Daniel T. Seamount, Jr. Commissioner / DATED this day of April, 2019. RBDMS2f1'APR 2 3 2016 STATE OF ALASKA APR 12 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC on eer oa oon 1. Type of Request: Abandon ❑� Plug Perforations ❑ ` Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other StimulatePull Tubin ❑ g ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Aker Casing ❑ Venting Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑✓ Stratigraphic ❑ Service ❑ 198-142 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 �� ~ 50-133-20375-9-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes❑ No ❑� Wolf Lake #2 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): Fee CIRI 84-201 Wolf Lake / Tyonek and Beluga Undefined Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 14;451' • 14,086' 8,069' 7,979 2,764 psi - 7,143', 7,474' Casing i,Iy Length Size MD TVD Burst Collapse Structural Conductor 30' 20" 52' 52' 3,060psi 1,500psi Surface 4,344' 13-3/8" 4,344' 4,343' 3,450psi 1,950psi Intermediate Production 12,151' 9-5/8" 12,151' 11,81T 8,150psi 5,080psi Liner 1,557- 7" 13,383' 13,032' 11,640psi 10,760psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size & Velocity String: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic Tbg LS:: / SS: 2-3/8" Tbg LS: 6.5# L-80 / SS: 4.6# L-80 I Tbg LS: 7,151' / SS: 6,010' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker GT Dual Pkr & Baker 194-32 DB Permanent Pkr 5,991' MD & 6,861' MD 12. Attachments: Proposal Summary ,x Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 1, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned Q 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: So York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerfrDhilcorp com Contact Phone: 777-8420 Authorized Signature: Date: `� ,- 7�� 7 0`'1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ^- I PluIntegrity BOP Test Mechanical Integrity Test ❑ Location Clearance Other: 35-0 GS4- Post Initial Initial Injection MIT Req'd? Yes ❑ No ❑ �(f1 Spacing Exception Required? Yes ❑ No �qubsequent Form Required:/ - q(9FtBDMS [� APR 2 3 2019 ^ '/A APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date: z)123/ j /L �G 2 I Submit Form and Form t0-403 Revi ed 4/20 Approved applicat i v lit 1 o f he date of approval. achmen s it Duplicate U Hilmro Alaska, LU Well Prognosis Well: WL#2 Date: 04/04/2019 Well Name: Wolf Lake #2 API Number: 50-133-20375-90 Current Status: Shut -In Gas Well Leg: N/A Estimated Start Date: May 1, 2019 Rig: 401 Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 198-142 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Bo York (907)777-8345(0) (907)727-9247(M) AFE Number: Current Bottom Hole Pressure: Maximum Expected BHP: Max. Potential Surface Pressure: Brief Well Summary: - 3,505 psi @ 7,411' TVD - 3,505 psi @ 7,411' TVD - 2,764 psi (Based upon a 0.473 psi/ft gradient to the deepest open perforation) (Based upon a normal gradient) (Based upon max. expected BHP and a 0.10 psi/ft gas gradient to surface) Wolf Lake #2 (WL #2) was originally drilled (PTD 184-201), logged, and tested (DST) by ARCO in November 1984. Following logging and testing, ARCO P&A'd the well in February 1985. WL #2 was re-entered by Marathon (PTD 198-142) in October 1998 and the wellbore perforated in the Beluga and Tyonek sands. The wellbore completion isolated the two zones with dual packers on 3-1/2" tubing, with a sliding sleeve across the Beluga interval. First gas sales were in November 2001. In August 2002, the original Marathon completion was pulled, the wellbore cleaned out, and the Beluga and Tyonek intervals re -perforated (& zones added). A dual string completion was run, with the Beluga intervals producing from the Short String (2-3/8" tubing) and the Tyonek sands producing from the Long String (2-7/8" tubing). In October 2002, it was noted that the Tyonek sands were not producing, and that all gas production was coming from the Beluga formation (via the Short String). The Beluga intervals produced gas and water on a relatively continuous basis from October 2002 through October 2005, and has remained mostly shut-in since. WL #2 has had no production since August 2007. The purpose of this Sundry is to permanently P&A the Wolf Lake #2 well. Pre - Rig Work: 1. Provide 24 hour notice to the AOGCC that Plug and Abandonment of well will commence per AOGCC regulations 20 AAC 25.112 (h). \< 2. RU Pump Truck. RU on the tubing and casing and conduct an IA pressure test to 3,500 psi on chart tt" for 30 min. WL #2 is a dual string completion, so the Long String (2-7/8") and Short String (2-3/8") tubing will both need to be monitored during the IA test. Bleed down pressure. P,. L-- C Si"4r' 3. MIRU E -line, on the Long String (2-7/8" tubing). to i a - 4. PU & RIH w/ Tubing Punch to "'7,025'. Punch holes from -7,025' to -7,020'. POOH. 5. PU & RIH w/ Tubing Cutter to -6,528'. Cut Long String @ -6,528' & POOH. i3"taw '3j'f Sts. a. Note: Fill at "'6,530' in IA (2-7/8" x 9-5/8"). y 6. RU E -line on the Short String (2-3/8" tubing). 7. PU & RIH w/ Tubing Cutter to "'5,985'. Cut Short String @ -5,985' & POOH. 5� n Ililenvp Ah,,k., H, Workover Rig 401: Well Prognosis Well: WL#2 Date:04/04/2019 8. MIRU Rig 401. 9. Notify AOGCC 24 hours in advance of test to extend the opportunity to witness. 10. Set back pressure valve." 11. ND wellhead, NU 11" BOP and test to 250 psi low & 3,600 psi high, annular to 250 psi low & 0 psi high. Record accumulator pre -charge pressures and chart tests. a. Perform Test. b. Test Dual VBR rams on 2-7/8" and 2-3/8" test joints. c. Submit completed form 10-424 to AOGCC within 5 days of BOPE test. 12. PU on Short String (2-3/8" tubing) and circulate the well with 9.8 ppg kill weight fluid. Note: Because the Long and Short Strings were run separately, Hilcorp intends to pull the Short String prior to unseating the dual packer and pulling it with the Long String. (17Q 13. POOH w/ Short String, laying down pipe. 14. PU on Long String (2-7/8" tubing) to release the Baker GT Dual Packer (70K shear) @ 5,9911 . 15. RU pump truck and circulate the well with 9.8 ppg kill weight fluid. 16. POOH w/ Long String laying down chemical injection sub and racking back pipe. a. Pull Baker GT Dual Packer, set @ 5,991', and b. Pull Long String from tubing cut @ 6,528'. 17. PU 9-5/8" Cement Retainer & RIH on 2-7/8" tubing. �,.✓/1 18. Set Cement Retainer @ —6,525'. a. Cement Retainer should beset just above the 2-7/8" tubing stub (@ ^'6,528'), and b. Cement Retainer should beset below the bottommost Beluga perforation (@ 6,520'). 19. RU cementers and squeeze the Tyonek perforations (by down squeeze method) with 54 bbls of 15.8 ppg cement. a. Note: Tubing + Annular volume = —43 bbls. b. 25% excess pumped/squeezed to ensure perforation isolation. c. Also note holes punched in the tubing (^'7,025' to ^'7,020') opposite the upper set of Tyonek perforations, and d. TCP firing Head in the tubing tail @ —7,143' (which prevents running expandable plug above lower Tyonek perforations). 20. Pull out of cement retainer and leave an additional 4 bbls of cement (-53') on top of the retainer. 21. POOH w/ tubing, racking back pipe. WOC. 22. RU E -line. RIH 4J wt- 16Vz 1-6r c PJ..a *Z P KZ, 23. PU & RIH w/ 9-5/8" CIBP, to 6,085'. Set same depth. POOH. 24. PU & RIH w/ Dump Bailer. wail 35' of cement on top of CIBP (TOC @ — 6,050'). POOH. ate: An Ultrasonic Imaging Log (run 10-16-98) indicates the 9-5/8" annulus has good quality cement behind pipe from "'3,300' to —4,100' and questionable cement from ^'4,100' to —5,100'. The 13-3/8" surface casing shoe depth is 4,344'. Considering the good quality cement 244'+ above the shoe, Hilcorp will not be able to �D-ri � irculate (down IA & up casing) a cement plug into place across the shoe. Hilcorp will however punch casing h les above and below the shoe and attempt to push cement into the IA, across the shoe (marginal cement on im ge log). P 25. PU & RIH w/ 9-5/8" CIBP to —4,4/Set same depth. POOH. �3 H Hikwp Alaska, LU Well Prognosis Well: WL#2 Date:04/04/2019 26. PU 1't casing punch and RIH to "'4,493'. Punch holes from —4,493'— 4,489'. POOH. 27. PU 2nd casing punch and RIH to 4,234'. Punch holes from ^'4,234' to 4,230'. POOH. 28. PU and RIH w/ 2-7/8" tubing (open ended) to 4,493'. 29. RU cementers & place a 450' ("'33 bbls) balanced plug of cement on top of the CIBP. 30. Pressure up 500 psi on the well and hold for 30 min. POOH & WOC. [�� Or`!;z 31. RU slickline & RIH to tag top of cement. Verify that TOC is at (or above) 4,244' to ensure at least / o 100' of cement extends above the surface casing shoe. POOH & RD slickline 32. RU E -line. 33. PU & RIH with 9-5/8" CIBP. Set plug at 160'. POOH. 34. PU 3`d casing punch and RIH to 159'. Punch holes from 159'— 155'. POOH. 35. RU cementers and circulate cement down the IA and up the 9-5/8" casing, through the holes at h 1591— 1551. WOC. a. If circulation can't be established, PU & RIH with 2-7/8" tubing (open ended) and place a 160' balanced plug of cement from the CIBP to surface. POOH and lay down pipe. WOC. 36. Place dry hole tree on well. ^ L it wi+f' ern° cas t� 37. RDMO Workover Rig 401. G"�'�" 6 , � Post - Rig Abandonment Procedures: 38. Excavate cellar, cut off casing 3' below natural GL. 39. Notify AOGCC 48hrs in odvance. 40. Create well abandonment marker per AOGCC regulation 20 AAC 25.120. The following must be bead -welded directly to the marker plate: p Aas <a, LL b. PTD: 198-142 c. Well Name: Wolf Lake #2 d. API: 50-133-20375-90 41. Set marker p a e per 20 0, collect GPS coordinates. �'f"` ' 42. Photo document casing cut-off and Welded Plate install. 43. Backfill excavation, close out location. Attachments: " S lL Actual Schematic Proposed Schematic BOPE Schematic RWO Sundry Revision Change Form Fri WL -2 Wolf Lake Pad 1,183' FSL, 2,265' FWL, IlBcgrn At.]., LLC Sec. 29, T7N, R9W, S.M. 198-142 (Re -Entry) 50-133-20375-90 s: CIRI (84-201) (tion: 247' (21' AGL) T1 0/1 9 84 2/01/1985 ased: 2/2211985 LS Tree cap = 3-1/2" 8RD SS Tree cap = 3-1/2" 8RD Dual Cameron Hanger (14.4' RKB) LS Lift Threads = 3-1/2" 8RD SS Lift Threads = 3-112" 8RD Casing Cementing Casing Lead Tail 20" 250 sx 13-3/8" 2445 sx 9-5/8" x 13-3/8" Annulus 300 sx 15.8 ppg 9-5/8" 700 sx 13.5 ppg 300 sx 15.8 ppg T. 900 sx 15.8 ppg dewelry(Long -String) Depth ID 1. Chemical Injection Sub 1,696' 2,441" 2. Pup Joint above Packer 5,977' 2.441" 3. Baker 9-5/8" GT Dual Packer (shear at 70k) 5,991' 2.939" 4. 2-7/8" Sliding Sleeve 6,037' 2.313" 5. 2 -7/8"X -Profile 6,077' 2.313" 6. Top of Blast Joints 6,088' 2.441" 7. Btm of Blast Joints 6,527' 2.441" 8. Baker 194-32 DS Permanent Packer 6,861' 3.250" 9.2 -718'X -Profile 6,910' 2.313" 10. Top of Blast Joints 7,004' 2.441" 11. Btm of Blast Joints 7,044' 2.441" 12. Balanced Isolation Tool 7,110' 2.441" 13. TCP Firing Head 7,143' 2.441" 14. WLEG 7,151' 2.441" 15.4-5/8" TCP Guns & Blank Spacer Guns 7,752' - 16. 4-5/8" TCP Guns (36) & 10' 1-114" drop bar 8,023' - 17. Baker'6AA' CIBP 8,069' - 18. Old 12.0 ppg mud 8,070' - 19. Cement plug 11,385' - 20. EZSV Cement Retainer 11,485' - B 12 Jewelry (Short Stdng) Depth ID 4 5 A. Chemical Injection Sub 1,599' 1.995" 14- 4 -B. B.Pup Joint above Packer 5,980' 1.995" 72 ppf BTC C. Baker 9-5/8" GT Dual Packer (shear at 701k) 5,991' 2.939" 72 ppf BTC D.2-3/8"XN profile 6,006' 1.810" 4,344' E. 2-3/8" WLEG 6,010' 1.995" d E Belogn 53.5 ppf BTC 9-5/8" 5-95 Tag Fill 702 Tkd 2.0" DD Bailer 12,151' TVD 0' 7,474' RKB a 7 G eanout Fill 10/21/02 TD 14,451' MD 14,086' TVD TOC (Est) 3,332141,322' —2 9-5/8" TOC Unknown `yy,+✓ 5 `1 0- 15 17 19 Q ACTUAL SCHEMATIC Conductor Casing (Cemented/ 20" K-55 133 ppf 4 5 Bottom MD 22' 52' TVD 22' 6 Surface Casino a a 72 ppf BTC 13-3/8" K-55 e hSm 72 ppf BTC To Bottom MD 0' 4,344' L! 4,343' Production Casing E Belogn 53.5 ppf BTC 9-5/8" 5-95 47 ppf BTC 702 Tkd MD 0' 12,151' TVD 0' 11,817' a 7 G eanout Fill 32 ppf BTC TOR I MD 11,826' 1.50" Coil TVD 11,501' 13,D32 - 3,032'Tubing(LS) Tubing (LS) 2-7/8" L-80 6,530' CiM Top Bottom MD 0' 8 2/06/03 7,109' Beluga 5 10 7,010'-7,038' a v e c Tyonek Tyonek 12 10/25/98 11 7,344'-7,411' 70' Tyonek 5 9/13102 13 v i Tyonek 15 17 19 Q ACTUAL SCHEMATIC Conductor Casing (Cemented/ 20" K-55 133 ppf TOD Bottom MD 22' 52' TVD 22' 52' Surface Casino 13-3/8" N-80 72 ppf BTC 13-3/8" K-55 68 ppf BTC 13-3/8" L-80 72 ppf BTC To Bottom MD 0' 4,344' TVD 0' 4,343' Production Casing 9-5/8" 5-95 53.5 ppf BTC 9-5/8" 5-95 47 ppf BTC 702 Bottom MD 0' 12,151' TVD 0' 11,817' Liner 7" 5-125 32 ppf BTC TOR Bottom MD 11,826' 13,383' TVD 11,501' 13,D32 - 3,032'Tubing(LS) Tubing (LS) 2-7/8" L-80 6.5 ppf 8RD Top Bottom MD 0' 7,151' TVD 0' 7,109' Tubing (SS) 2-3/8" L-80 4.6 ppf IBT TOD Bottom MD 0' 6,010' TVD 0' 6,007' Perforations: WOLF LAKE #2 Lease: CIRI (84-201) County or Parish: MD TVD Ft Zone SPF Date 6,095'-6,110' 6,090'-6,105' 15' Beluga 5 9105102 6,166'-6,176' 6,160'-6,169' 10' Beluga 5 9105102 6,202'-6,210' 6,195'-6,203' 8' Beluga 5 9/05/02 6,356'-6,379' 6,348'-6,368' 23' Beluga 5 9/05/02 6,392'-6,420' 6,381'-6,408' 28' Beluga 12 10/20/98 6,454'-6,466' . 6,441'-6,453' 12' Beluga 5 9105102 6,506'-6,520' ' 6,492'-6,506' 14' Beluga 5 9/05/02 7,010'-7,038' 6,974'-7,001' 28' Tyonek 12 10/25/98 7,398'-7,468' . 7,344'-7,411' 70' Tyonek 5 9/13102 PBTD 8,069' MD 7„ 7,979' TVD Well Name & Number: WOLF LAKE #2 Lease: CIRI (84-201) County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: t° 5,700' An le/Perts: 11°-18° Maximum Deviation: 26.1' A 8,400' Date Completed: 9/9/2002 Ground Level (above MSL): 226' RKB (above GL): 21' Revised By: Stan Porhola Downhole Revision Date: 2/6/2003 Schematic Revision Date: 6/19/2014 N Hilcoru Alaska, LLC 198-142 (Re -Entry) 50-133-20375-90 CIRI(84-201) on: 247' (21' AGL) 2/01/1985 ased: 2/2211985 Casino Lead Tail 20" 250 sat 13-3/8" 2445 sx 9-518" x 13-3/8" Annulus 300 sx 15.8 ppg 9-5/8" 700 sx 13.5 ppg 300 sx 15.8 ppg 7" 900 sx 15.8 ppg P&A Plugs & Cement Depth A. CIBPw/ Cementto Surface -160' WL -2 -4,494' (TOC @ or above 4,244') 6,861' Wolf Lake Pad -6,085' (TOC Q -6,050') 2.313" 1,183' FSL, 2,265' FWL, -6,525' (TOC @ -8,474') 5. Btm of Blast Joints Sec. 29, T7N, R9W, S.M. 2.441" 6. Balanced Isolation Tool 7,110' 2.441" -' 7,143' 2.441" 8. WLEG 7,151' 2.441" '� • 7,752' - 10. 4-5/8" TCP Guns (36') & 10' 1-1/4" drop bar 8,023' Casing Punches A 8,069' - 12. Old 12.0 ppg mud 8,070' - 154' - 159' 20 - 14. EZSV Cement Retainer 11,485' - 6.5 ppf 8RD Good Cement: 5 V MD -8,528' 7,151' TVD -6,513' 3,300'- 4,100' Questionable Cement: i� tJ 4,100'-5,100' Ultrasonic Imager 13-3/8" 3 "; 3 (10-16-98) Casing Punches B \ 4,230' - 4,234' 9-S/8- TOC 4,489'-4,493' Unknown P&A Plugs & Cement Depth A. CIBPw/ Cementto Surface -160' B. CIBP w/250'+ of Cement on top -4,494' (TOC @ or above 4,244') 6,861' C. CIBP w/ 35' of Cement on top -6,085' (TOC Q -6,050') 2.313" D. Cement Retainer w/-53'cmt on top -6,525' (TOC @ -8,474') 5. Btm of Blast Joints Jewelry (Long String) Depth ID 1. Top of 2-7/8" Tubing Stub -6,528' 2.441" 2. Baker 194-32 DB Permanent Packer 6,861' 3.250" 3.2-7/8" X -Profile 6,910' 2.313" 4. Top of Blast Joints 7,004' 2.441" 5. Btm of Blast Joints 7,044' 2.441" 6. Balanced Isolation Tool 7,110' 2.441" 7. TCP Firing Head 7,143' 2.441" 8. WLEG 7,151' 2.441" 9.4-5/8" TCP Guns & Blank Spacer Guns 7,752' - 10. 4-5/8" TCP Guns (36') & 10' 1-1/4" drop bar 8,023' - 11. Baker'6AA' CIBP 8,069' - 12. Old 12.0 ppg mud 8,070' - 13.Cement plug 11,385' - 14. EZSV Cement Retainer 11,485' - CygP c VbSr or - C 4v]) ,a L'1 CL Bewga Osalared) MT Cleanout Fill 1.50"Coil6,530' CTM 2 2/06/03 PROPOSED SCHEMATIC Conductor Casing (C=52 20" K-55 T� MD 22' ND 22' Surface Casing 13-3/8" N-80 72 ppf BTC 13-3/8" K-55 68 ppf BTC 13-3/8" L-80 72 ppf BTC Top_ Bottom MD 0' 4,344' ND 0' 4,343' Production Casing 9-5/e" S-95 53.5 ppf BTC 9-5/8" 5-95 47 ppf BTC TOR Bottom MD 0' 12,151' ND 0' 11,817' Liner 7" 5-125 32 ppf BTC TOR Bottom MD 11,826' 13,383' ND 11,501' 13,037 Tubing(LSI 2-7/8" L-80 6.5 ppf 8RD Top Bottom MD -8,528' 7,151' TVD -6,513' 7,109' Tubing Punches / 7,020' - 7,025' tj -7610�p5 Tyaaeg (s9veeue & Isolated) Perforations: MD ND J Zone SPF Date 6,095'-6,110' 6,090'-6,105' 15' Beluga 5 9/05102 6,166'-6,176' 6,160'-6,169' 10' Beluga o, 5 9105/02 6,202'-6,210' 6,195'-6,203' 8. Beluga > 5 9/05102 6,356'-6,379' 6,346'-6,368' 23' Beluga 5 9105/02 6,392'-8,420' 6,381'-6,408' 28' Beluga to 12 10/20/98 6,454'-6,466' 6,4411-6,453' 12' Beluga 5 9/05/02 6,506'-6,520' 6,492'-6,506' 14' Beluga 5 9/05/02 7,010'-7,038' 6,974'-7,001' 28' Tyonek 12 10/25/98 7,398'-7,468' 7,344'-7,411' 70' Tyonek 5 9113/02 Well Name & Number: Ty°aek (Squeezed & Isolated) Lease:I CIRI (84-201 County or Parish: Tag Fill State/Prov: Alaska Country: 2.0" DD Bailer Angle @KOP and Depth: 1° @ 5,700' Angle/Perfs: 11°48° 7,474' RKB 26.1° 0 8,400' 10/21/02 9/9/2002 Ground Level (above MSL): 9 21' Revised By: Paul Winslow Downhole Revision Date: 10 3/29/2019 2 - t: 13 14 TO 14,451' MD 9-5/8�� PBTD 0' MD 14,086' ND 7" 0' ND ;'Lz Well Name & Number: WOLF LAKE #2 Lease:I CIRI (84-201 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 1° @ 5,700' Angle/Perfs: 11°48° Maximum Deviation: 26.1° 0 8,400' Date Completed: 9/9/2002 Ground Level (above MSL): 226' RKB (above GL): 21' Revised By: Paul Winslow Downhole Revision Date: 2/612003 Schematic Revision Date: 3/29/2019 HILCORP ALASKA 11" SM BOPE 11" 5M HYDRIL GK ANNULAR 47-7/8" TALL, FLANGE TO FLANGE 11" 5M CAMERON TYPE U DOUBLE GATE BOP DRESSED W/VARIABLE RAMS IN TOP DRESSED W/BLIND RAMS IN BOTTOM 54-1/2" TALL, FLANGE TO FLANGE 11" 5M DRILLING SPOOL W/2-1/16" & 4-1/16" 5M OUTLETS 24" TALL, FLANGE TO FLANGE —127' TOTAL STACK HEIGHT ANNULAR STYLE BOP SPECS: - 8.08 gallon open chamber volume - 9.81 gallon close chamber volume GATE STYLE BOP SPECS: - 3.4 gallons to open per gate - 3.5 gallons to close per gate - 7.3:1 closing ratio - 2.5:1 opening ratio HHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well: Wolf Lake #2 (PTD 198-142) Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first calf' engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By Initials HAK Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: +.O« IUam WPerauons manager Date AML a.au uperauons rngmeer Date 10,000,000 1,000,000 t Y C cO G G 100,000 LL u O N 10,000 c7 O 0 O ,n d to LL C 1,000 u :c 3 u v M 100 N 3 O r 10 1 i Jan -2000 HILCORP ALASKA LLC, WOLF LAKE MARATHON 2 (198-142) WOLF LAKE, BEL-TYON UNDEF GAS Monthly Production Rates Cum. Prod Oil (bbls): 0 Cum. Prod Water (bbls): 4,249 Cum. Prod Gas (mcf): 626,025 Jan -2005 Jan -2010 Jan -2015 —�- Produced Gas (MCFM) = GOR —+— Produced Water (BOPM) Produced Oil (BOPM) 10,000,000 d 1,000,000 0 O M O 100,000 Z 3 O 3 S 10,000 0 Z W d 1,000 O_ a M 100 CD 3 0 3 .e 10 =r 1 Jan -2020 SPREADSH EET_1981420_Prod-I nject_Cu wes_W ell_O il_V 120_20190415.xlsx 4/15/2019 • ~ • ~ Page 1 of I McMains, Stephen E (DOA) To: Chris Gay Subject: RE: Wolf Lake Wells Thanks for the clarification on the Wolf Lake 2 wetls. I change the number in your letter to match the permit number. From: Chris Gay [mailto:CGay@ciri.com] Sent: Wednesday, August 05, 2009 10:19 AM ~~~~~~ ~~~ ~,~ ~~~~ To: McMains, Stephen E (DOA) Subject: Wolf Lake Wells Steve, Per our conversation last week regarding CIRI's July 27th letter (see attached scan), the following table lists the Marathon well names as listed in the letter and the corresponding AOGCC names and API numbers. Please let me know if you need any further clarification. Thanks, Chris AOGCC Well Name Marathon Well Name API Number SOLDOTNA CK UNIT 22-32 Soldotna Creek Unit No. 22-32 50133100220000 SOLDOTNA CK UNIT 22A-32 Soldotna Creek Unit No. 22-A-32 50133100220100 WOLF LAKE ARCO/CIRI 1 Wolf Lake No. 1 50133203620000 WOLF LAKE 1 RD Wolf Lake No. 1 RD 50133203620100 WOLF LAKE ARCO/CIRI 2 Wolf Lake No. 2 50133203750000 WOLF LAKE MARATHON 2 Wolf Lake No. 3 50133203759000 Chris Gay Land and Resources Cook Inlet Region Inc ICIRII 2525 "C" Street, Ste. 500, Anchorage, AK 99503 PO Box 93330, Anchorage, AK 99509-3330 907-263-5517 (phone) 907-263-5190 (fax) The uiformation cont2ined in this CIRi e-mail message may be privi(eged: confidential and protected from disdosure. If you are not an intended recipient, please notity the se~~der hy reply e-mail and delete the message and any attachments immediately. Tiie use, disclosure. dissemination, distnbution or reproduction of this CIRI message or the information in it ar attach2d ta it by ~ny unintended recipient is unauthorized, strictly prohibited by the sender, and rnay be unlawf~d. ~ih2nk you. 8/5/2009 ~ _ ~ July 27, 2009 Mr. Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 W. 7`h Ave., Ste. 100 Anchorage, AK 99501 RE: Wolf Lake Gas Field CIRI Lease No. C-061504 and Lease No. C-061569 T7N-R9W, Sections 29, 30, 31 and 32 Kenai Peninsula, Alaska Dear Mr. Seamount: . Cook Inlet Region, Inc, ("CIRI") holds mineral rights within the Wolf Lake Gas Field drilling area ("Drilling Area") near the following wells ("Wells"): ~ ~~~ '~~' jWolf Lake No. 1 -~ ~~'~.~ 03:,~Wolf Lake No. 1 RD °s I~~( p~,~ j Wolf Lake No. ?. ~ ''~' ~~ ~ ~ r jL. Woff Lake No. > . ~ ~~~'1 '? ~~ '~ 9 ~f ~.: ~ (4~- ~,~,~Soldotna Creek Unit No. 22-32 ---_ ~ ~,~---~~ ~Soldotna Creek Unit No. 22-A-32 CIRI sold a portion of its Wolf Lake mineral interests in 2000 and another interest in 2003. CIRI continues to own the mineral interests between the Hemlock and Matanuska Formations (appraximately 12,456' to 12,080') in addition to the minerals lying beneath the Hemlock Formation (approximately 13,635' to the center of the earth). CIRI also continues to hold the rights to any other non-oil and gas subsurface estate within the boundaries of the leases and resource sales. The well paths for the above referenced Wells pass through CIRI mineral acreage. The purpose of this letter is to request that the AOGCC notify CIRI of any and all applications and actions involving the listed Wells or the Drilling Area. CIRI is interested in protecting its correlative rights as a significant mineral owner within the Drilling Area. As of August 26, 2003, CIRI has no active leases or integration of interests with other interest owners within the Drilling Area. 2525 "C" STREET, SUITE 500 = EO. BOX 93330 ~ ANCHORAGE, ALASKA 99509-3330 (907) 274-8638 ry FAX (907) 279-8836 ~ Web Sice: www.ciri.com ~ ~ AOGCC Notice of Drilling July 27, 2009 Wolf Lake Gas Field Page 2 Please send notifications pursuant to this request to: Kim Cunningham Director, Land and Resources Cook Inlet Region, Inc. 2525 C Street, Suite 500 Anchorage, AK 99503 Thank you for your assistance and please let us know if you have any questions or concerns. Yours truly, Cook Inlet Region, Inc. Chris Gay Land and Resources cc: Kim Cunningham, CIRI Tom Maunder, Petroleum Engineer, AOGCC Charles A. Underwood, Marathon • _ Marathon MARATHON ®'~ COI'Y1p1l1'/ May 15, 2008 Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 9071283-1350 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 ~ 1cs.~ ~ ~Z s ~e:,~cc *~ ~~ ~~ cr~~cr~\oc~Zcc~~ ~QS~~or ~~~-°:~~ Reference: 10-404 Sundry Submittal List Dear Mr. Maunder: ~~ ~a.~- O1 . ~o~vr~Et~"~SS~jS\v Marathon and the AOGCC have had discussions on the follow-up reporting needed to ~~ close out 10-403 Sundry approved well work activities. Work has been ongoing to identify the suspect well activities and complete the appropriate reporting. Submitted for 5~~~--~,,~ your records is a list of the completed reports along with the indicated 10-404 Sundries. I am continuing to work on the remaining sundry reports and plan to submit them upon their completion. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, Enclosures: 10-404 Sundry Submittal List cc: Houston Well File Accompanying 10-404 Sundries Kenai Well File KJS • M Marathon MARATHON Oil Company March 31, 2003 Mr. Tom Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t" Ave, Suite 100 Anchorage, AK 99501 Reference: Field: Wolf Lake Field Well: Wolf Lake #2 Beluga Completion Regarding: 10-404 Report of Sundry Well Operations Dear Mr. Maunder ~°~ ~ ~ ~.. r, . . . Enclosed please find the Report of Sundry Well Operations. The work was completed from February 4~' to March 15t", 2003. Attachments include the 10-404 and an operations summary. Gas volumes vented to atmosphere were noted on form 10-422 forthe months of February and March. After the enzyme treatment the well produced mud which plugged up our production facility and contaminated our dehydration unit. We then produced the well to a tank for clean-up, recovering approximately 35 bbls of mud. A temporary solids separator was installed to minimize the risk of plugging the facility again. If you require further information, I can be reached at 907-564-6318 or by a-mail at DEEynon@MarathonOil.com. Sincerely, -~, Donald Eynon Operations Engineer Enclosure: 10-404 Report of Sundry Well Operations Operations Summary Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 cc: CIRI Mailed 3/31 /2003 O:\EXCEL\AOGCCReport of Sundry Ops .XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~. Operations performed: Operation Shutdown _ Stimulate X Plugging Perforate Pull Tubing _ Alter Casing _ Repair Well _ Other_ 2. Name of Operator 5. Type of Well: s. Datum Elevation (DF or KB) MARATHON OIL COMPANY Development X 230' Pad Elevation feet 3. Address Exploratory_ 7. Unit or Property Name P. O. Box 196168, Anchorage, AK 99519-6168 Stratigraphic Wolf Lake Field _ a. Location of Well at Surface Service s. Well Number 1183' FSL and 2265' FWL, Section 29-7N-9W rs - -,: Wolf Lake # 2 At top of Productive Interval ~ ~ *"" ~ ~ ° R'~" ~ s. Permit Number/Appr va l Numb 1285'FSL, 2236'FWL, Sec. 29, T7N, R9W, S.M. p~y 303-026 C1- At Effective Depth ~o. API Number ^~`, :. 50-133-20375-90 At Total Depth ~ ~. Field/Pool 2621'FSL, 488'FWL, Sec.29, T7N, R9W, S.M. < ~,~; . ,- ; ~ ,,, : ,~ Wolf Lake Field/ Beluga Pool 12. Present Well Condition Summary C~ . ~ ,, Total Depth: measured 14,451 feet Plugs (measured) CIBP @ 8069' true vertical 14,086 feet EZSV @ 11,485' ~ Cement @ 13,200' Effective Depth: measu}ed 7752 feet Junk (measured) 31T of spacer and TCP guns @ 7752' true vertical 7681 feet Casing / Length Size Cemented Measured Depth True Vertical Depth Structural ~ 66' 20" 150 sx 66' 66' Conductor Surface 4332' 13 3/8" 2445 sx 4332' Intermediate Production 12152' 9 5/8" 1000sx 12152' 11818' Liner 1557' 7" 1000sx 13391' 13039' Perforation Depth: measured Beluga - 6095' - 6110', 6166'-6176', 6202'-6210', 6356'-6379', 6392'-6420', 6454'-6466', 6506'-6520' Tyonek - 7010' - 7038', 7398'-7468' true vertical Beluga - 6090'-6105', 6160'-6170', 6195'-6203', 6346'-6369', 6381' -6409', 6441'-6453', 6492'-6506' Tyonek - 6975' - 7003', 7344'-7411' Tubing (size, grade, and measured depth) 2.875", 6.5 ppf, N-80 to 7150' 2.375", 4.6 ppf, N-80 to 6009' Packers and SSSV (type and measured depth) Baker model GT Dual String retrievable packer at 5991' MD Baker model D permanent packer @ 6861' MD ~s. Stimulation or Cement Squeeze Summary Intervals Treated (measured) MD Beluga- 6095' - 6110', 6166'-6176', 6202'-6210', 6356'-6379', 6392'-6420', 6454'-6466', 6506'-6520' Treatment Description Including Volumes Used and Final Pressure Spotted 1500 gallons of BJ EZ Clean X:C Enzyme treatment across perforations and applied 1700 psi. 7a. Representative Daily Average Production or Infection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation 700 10 0 750 Subsequent to Operation 800 10 0 1000 15. Attachments 16. Status of Well Classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations X Oil Gas X Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. `~ ~~ Signed ~-r1e,~~" ~'' Donald Eynon Title Operations Engineer Date - yJ/ ~ 3 Form 10-404 Rev. 06/15/88 - ~ ~!,~ J B ~ 1 ~ f-,,. -. , Submit in Duplicat 1. ... g i , • DDATE DEPTH TVD OPSUMRMK • 2/4/2003 0:00 0 0 MI Spot BJ CT 2/5/2003 0:00 0 0 MI RU BJ Coiltech. Test BOPE and choke skid. 2/6/2003 0:00 0 0 RU BJ Coiltech. Test BOPE. RIH to 6430, tag fill. Circulate out 100' of fill to 6530 with 6% kcl and nitrogen. Spot BJ EZ Clean enrymes across perforations . POOH to 5500'. Attempt to jet well dry, foam in returns. Pump N2 to displace enryme. SWIFN 2/8/2003 0:00 0 0 Produce well to tank. Well died. RU BJ Coiltech. Jet well with Nitrogen recovering approximately 25 bbls of liquids. Flow to tank. SIWFN. 2/10/2003 0:00 0 0 RDMO BJ CT 2/22/2003 0:00 0 0 Flow intermitantly for cleanup. Est 208 mcf vented. Slugs of mud in gas. 2/23/2003 0:00 0 0 Flow intermitantly for cleanup. Est 328 mcf vented. Slugs of mud in gas. 2/24/2003 0:00 0 0 Flow at est rate of 500 mcf for cleanup. Est 416 mcf vented. Slugs of mud washed out choke. SI 2/25/2003 0:00 0 0 Well SI, Repair choke, wait on solids separator. 3/11/2003 0:00 0 0 RU solids separator. 3/12/2003 0:00 0 0 Flow well to tank. Estimated 630 mcf vented to atmosphere. 3/13/2003 0:00 0 0 Flow well to tank and production facility. Estimated 415 mcf vented to atmosphere. Recover gas and mud. 3/14/2003 0:00 0 0 Flow well to tank and production facility. Estimated 650 mcf vented to atmosphere. Recovered mud and gas. 3/15/2003 0:00 0 0 Flow well to tank. Estimated at 320 mcf vented to atmosphere. Turn over to prodution flowing well through solids separator to facility. ~~ Marathon MARATHON Oil Company January 27, 2003 Mr. Tom Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 Reference: Field: Wolf Lake Field Well: Wolf Lake #2 Beluga Completion Regarding: Enzyme treatment to Beluga Completion Dear Mr. Maunder Enclosed please find the Application for Sundry Approval. The proposed coiled tubing treatment involves spotting enzymes mixed in a KCL base which targets polymers that were used during the Fall 2002 workover of the well. Attachments include a Sundry Notice, well schematic and a coiled tubing procedure. We hope to perform the job as soon as the BJ coiled tubing unit becomes available. If you require further information, I can be reached at 907-564-6318 or by a-mail at DEEynon@MarathonOil.com. Sincerely, ~~! ~ Donald Eynon Operations Engineer Enclosure: Sundry Notice Well Schematic Operations Program O:\EXCEL\WL2 Beluga EnzymeAOGCCsund.X~S p STATE OF ALASKA ~~ ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ,~~ ~ ut' APPLICATION FOR SUNDRY APPROVALS ~ Z`=~ 7. 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 _ 2. Name of Operator 5. Type of Well: s. Datum Elevation (DF or KB) MARATHON OIL COMPANY Development X Pad Elevation 230 feet 3. Address Exploratory_ 7. Unit or Property Name P. O. Box 196168, Anchorage, AK 99519-6168 Stratigraphic_ Wolf Lake Field a: Location of Well at Surface Service _ 8. Well Number 1183' FSL and 2265' FWL, Section 29-7N-9W Wolf Lake #2 At top of Productive Interval 9. Permit Number /~ Top of Pay (Tyonek): 1285' FSL and 2236' FWL, Section 29-7N-9W 198-142 / At Effective Depth 70. API Number 50- 133-20375 At Total Depth 11. Field/Pool 2621' FSL and 488' FWL, Section 29-7N-9W Tyonek/Beluga 12. Present Well Condition Summary Total Depth: measured 14,451 feet Plugs (measured) CIBP @ 8069' true vertical 14,086 feet EZSV @ 11,485' Cement @ 13,200' Effective Depth: measured 7752 feet Junk (measured) 317' of spacer and TCP guns @ 7752' true vertical 7681 feet Casing Length Size Cemented Measured Depth True Vertical Depth Structural 66' 20" 150 sx 66' 66' Conductor Surface 4332' 13 3/8" 2445 sx 4332' Intermediate Production 12152' 9 5/8" 1000sx 12152' 11818' Liner 1557' 7" 1000sx 13391' 13039' Perforation Depth: measured Beluga - 6095' - 6110', 6166'-6176', 6202'-6210', 6356'-6379', 6392'-6420', 6454'-6466', 6506'-6520' Tyonek - 7010' - 7038', 7398'-7468' true vertical Beluga - 6090'-6105', 6160'-6170', 6195'-6203', 6346'-6369', 6381' - 6409', 6441'-6453', 6492'-6506' Tyonek - 6975' - 7003', 7344'-7411' Tubing (size, grade, and measured depth) 2.875", 6.5 ppf, N-80 to 7150' 2.375", 4.6 ppf, N-80 to 6009' Packers and SSSV (type and measured depth) Baker model GT Dual String retrievable packer at 5991' MD Baker model FB-1 permanent packer @ 6861' MD 73. Attachments Description Summary of Proposal Detailed Operations Program X BOP Sketch 7a. Estimated Date for Commencing Operation 15. Status of Well Classification as: 2/4/2003 7s. If Proposal was Verbally Approved Oil Gas X Suspended Name of Approver Date Approved Service ~ 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Donald Eynon Title Operations Engineer Date 1/27/2003 FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so representative may witness ' Approval No. 35~CJ ~s ~ ~ ~ k a ~ cs Plug lntegrity <.~ ~ -[`~ BOP Test Location Clearance _ _ Mechanical Integrity Test_ Subsequent Form Required 10- ~C}~..~ ORIGINAL SIGNED BY ~ Approved by Order of the Commission Commissioner Date 9 ~ "~ Form 10-403 Rev. 06/15/88 S1Ubmit m ~rfpficate ~~~~~ED~ FFE3 F ~~ 20~? MARATHON Marathon Oil Company Alaska Region Well: Wolf Lake 2 Beluga Completion Wolf Lake Field Enzyme Treatment for Polymers WBS # 1/27/03 History: The Beluga interval was perforated during the October 1998 re-entry and additional perforations were added during the September 2002 workover converting the well to a dual completion. After being dually completed the Beluga interval has been slow to clean up, starting at 100 MCF/d and currently at 750 MCF/d, intermittently the well will produce at a 1.3-1.4 MMCF/d rate for 5-10 hours and then fall off. During the 2002 workover HEC and Zanthan polymers were used for sweeps to clean out the well bore. It is possible that these polymers could be plugging off the perforations. The Beluga interval has also produced an emulsion with water and fines. BJ is currently testing a water sample from the well for polymers. Objective: Cleanout Beluga interval and treat with BJ enzymes to remove HEC and Zanthan polymers from perforations. 1. MI 300 bbl bullet tank, flow back tank and flow back iron. 2. MI BJ Coiltech with 1 %2" CT equipment, and choke skid. Utilizing a clean vac truck, fill bullet tank with 6% KCL using fresh water from supply well. 3. RU BJ lubricator and BOP to short string side of wellhead. RU flow back iron utilizing BJ's choke skid. 4. RU 1 %" CT nozzle, checks, and disconnect on CT, stab coil into injector head, MU to BOP, circulate to tank through choke manifold. Fully function and pressure test BOP'S and choke skid to 150/3500 psi with 50/50 methanol mixture. Blown down 50/50 methanol mixture with Nz to holding tank as per BJ's recommended practice. 6. RIH with CT while holding wellhead pressure constant by adjusting choke. Pump N2 as necessary to maintain pressure on CT. 7. If fill is encountered start pumping KCL at .5 bpm and N2 at 350 scfm, following Circa program while RIH at .62'/min, cleaning out to 6530'. 8. Spot 35 bbls of enzyme mixture across perforations from 6,530' to 6,000 feet. ~l.~~&~N~~~ !~ ~~ k~ ~~ Z~lC3 • 9. POOH to 6000' and jet hole to unload any water while holding backpressure with choke. 10. POOH with coil while pumping NZ to hold pressure on well. 11. Shut in well with 200 psi more than shut in tubing pressure at start of job. 12. RD BJ Coiltech. 13. Open well to production after being shut in 24 hours. Maintain FTP of 1200 psi for a 50% draw down at Beluga interval. Contacts: Work Phone Payer Completion Don Eynon 564-6318 268-6953 Reservoir Eng Ralph Affinito 564-6303 231-3775 Geologist Bob Lanz 564-6427 • I ~ 3 1/2" EUE lift threads in boths sides of the dual hanger MARAZNOM 4 Dual hangers swedged 3 1/2" EUE to tubing string immediately below hanger Wolf Lake # 2 20" K-55 5' 133 Ib/ft Drive pipe 66' I I 2 7/8" Chemical Injection Sub @ 1696' 2 3/8" Chemical Injection Sub @ 1597 ~ 2 7/8 "EUE 8rd Long String Special Clearance Couplings 2 3/8 "Short String Improved Buttress Tubing with Special Clearance Couplings Production Tubing ~, 13 3/8" K-55, L-80 0' 68-721b/ft BTC 4322' Ip__. ~ ~_ GT Dual Packer 5991' MD 5987 TVD i ~+ -` 2 3/8" 1.875 XN (1.81" ID) Nipple (6008') and WLEG (6009' ~ I ~' 2 7/8" CMU 2.313 Sliding Sleeve @ 6037 '' 2 7/8" 2.313 X Nipple @ 6077 2 7/8 EUE 8rd Tubing/ Beluga Perforations Blast Joint Assembly ~. Original BHP 2914 psia m ~ 8095-6110', 6166-6176', 6202-6210', 6356- "~ 6379', 8392-6420', 6454-6466`, 6506- II 8520'. `1 9 5/8 Permanent Packer w/ SBE and Tu ' ~ concentric crossover 6860' MD 6831' bing Adaptor ;I , f ~ 2 7/8" 2.313 X Nipple }I 40' Blast Joints - ~+ Tyonek Perforations 7010-7038 ~ r~ Original BHP 3391 psia 2 Joints 2 7/8" Tubing BIT @ 7110' Joint 2 7/8" Tubing Auto Release Firing Head @ 7143' Bottom at 7151' ~ ~' r ~`~Tyanek Perforations 7398-7468' 7752' Calculated PBTD I! 80' 4 5/8" guns and 237' 3 3/8" spacer ,' Top of Guns and Baker 6AA ~ ,~ ' CIBP @ 8,069', tagged { 9/04/2002 ,~ J n cin" c nc n' I If ~ ~ ~ I 7" C_99F 94R~d' • • Marathon MARATHON Oil Company October 28, 2002 Mr. Tom Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Reference: Field: Wolf Lake Field Well: Wolf Lake #2 Regarding: Form 10-407 Submittal Dear Mr. Maunder Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 We have re-c_ ompleted the Wolf Lake # 2 well with a dual zone completion as per our approved workover procedure. Please find the enclosed Form 10-407 with attachments that include a well schematic, and a daily operations summary. Currently the Tyonek interval will not flow and is shut in while remedial options are being evaluated. The Beluga interval on the short string is being produced. If you have questions or require further information, I can be reached at 907-564-6318 or by e-mail at DEEynon@MarathonOil.com. Sincerely, Id :, Donald Eynon Production Engineer Enclosures: well schematic daily operations summary RECEIVED Nov o ~ 2002 Alaska 0il~& Gas Cons. Cammisslon AI1GItOrd~8 ,~ ., STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL GAS~X SUSPENDED ABANDONED SERVICE Classification of Service Well 2. Name of Operator MARATHON OIL COMPANY 7. Permit Number 198-142 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 8. API Number 50-133-20375-90 a. Location of Well at Surface 1183'FSL, 2265'FWL, Sec. 29, T7N, R9W, S.M. '-"E ~--°-- •C+):v PLE 3 !ON GATE ~ 9. Unit or Lease Name Wolf Lake At top of Producing Interval 1285'FSL, 2236'FWL, Sec. 29, T7N, R9W, S.M. ~.02. VEfilFtc~ ~'S:f 10. Well Number 2 At Total Depth ~ }=, ` '" fi,.._.-<. , ._ . . 2621'FSL, 488'FWL, Sec.29, T7N, R9W, S.M. 11. Field and Pool Wolf Lake Field 5. Elevation in feet (indicate KB, DF, etc.) 35' KB-GL 6. Lease Designation and Serial No. 84-201 Beluga/Tyonek Pooi 12. Date Spudded 8/28/2002 13. Date T.D. Reached 9/4/2002 14. Date Comp., Susp. or Aband. 9/9/2002 15. Water Depth, if offshore N/A feet MSL 16. No. of Completions two 17. Total Depth (MD+TVD) 13391 MD, 13039' TVD 18, Plug Back Depth (MD+TVD) 8069' MD, 7979' TVD 19. Directional Survey Yes X~No ~ 20. Depth where SSSV set N/A feet MD 21. Thickness of Permafrost N/A 22. Type Electric or Other Logs Run Gamma Ray Correlation 23 CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 133# K-55 0 66 26" In place N/A 13 3/8" 68&72# N-80&K-55 0 4332 17-1/2" In place N/A 9 5/8" 47&53.5# S-95 0 12152 12-1 /4" In place N/A 7" 32# S125 11834 13391 8-1/2" In place N/A 2a. Perforations open to Production (MD+ND of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 7150 5991 & 6861 Tyonek Sand: 7010' - 7038' DIL, 6975' - 7003' TVD,12 spf, 4-1/2" TCP 10/25/1998 2-3/8" 6010 5991 7398' - 7468' RST, 7344' - 7411' TVD, 5 spf, 4-5/8" TCP, 9/13/2002 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Shut In -Will not flow Date of Test Hours Tested PRODUCTION FOR TEST PERIOD ~ OIL-BBL 0 GAS-MCF 0 WATER-BBL 0 CHOKE SIZE 64 / 64 GAS-OIL RATIO N/A Flow Tubing Press. Casing Pressure 0 CALCULATED 24-HOUR RATES OIL-BBL 0 GAS-MCF 0 WATER-BBL 0 OIL GRAVITY-API (corr) N/A 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A R1..~~~ Y ~~ NOV 01 2002 Alas1ta031~&~G ch ra~~ ommissiof Form 1o-ao7 ,I Submit in Triplicate Rev.7-1-80 CONTINUED ON REVERSE SIDE RBD~S ®Fi .~ ~, H:\EXCEL\NRSFORMSWOGCOMPL.XLW f_ L • • 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. Tyonek 7010' - 7038' 6975' - 7003' ~~~1~E~ NOV 0 ~ 2002 Commissiar~ s A1~S1t~ 0ih&~ a, h9oa ~ ~ 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 Don Eynon Title Production Engineer Date 10/30/2002 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 H:\EXCEL\NRSFORMSWOGCOMPL.XL W ~- ~~ Daily Summary for Well: WOLF LAKE 2 Report Report MD TVD Summary Date Number Workover Event: 06-Aug-02 1 RU BJ Services, Pump HEC pill to kill well. Fill annulus and tubing with 9.3 ppg brine. Well dead. RD BJ. 10-Aug-02 2 Bleed off trapped gas on tubing and annulus. 24-Aug-02 3 RU BJ Services, Pump Flo-Vis pill with sized calcium carbonate to kill well. RD BJ. 27-Aug-02 4 Rigging up rig. 28-Aug-02 5 R/U rig. Observe pressure under BPV. Lubricate BPV out of well. Bleed pressure off of tubing and csg. Observe well. 29-Aug-02 6 Monitor well. Punch tubing 5880'-5882'. Could not reverse circ. Punch tubing 5863' -5865'. Reverse circ. 1 hole volume. N/D x-mas tree. N/U BOPE. Test BOPE. 30-Aug-02 7 M/U landing joint into TBG hanger. Attempt to release packer and pull 3.5" TBG. Work stuck TBG. R/U to run freepoint tool. Run Gauge. Run 2.7" TBG cutter. Pull TBG free below packer. Circ. out. 31-Aug-02 8 R/U short bales. POOH and L/D 3.5" 9.2PPF IBT production tubing and 9 5/8" Ret Hyd packer. P/U fishing BHA#1. Slip and cut drill line. Check brakes and crown-o-matic. 01-Sep-02 9 P/U 4" DP RIH to 1000'. POOH. Test lower pipe rams and run wear bushing. RIH to 1000'. P/U 4" DP while RIH. Mill 3.5" TBG F/5887' to 5897'. Pump sweep and circulate out. POOH and L/D mill assy. P/U overshot and jar assy. 02-Sep-02 10 P/U and M/U overshot BHA. RIH w/overshot. Repair hyd. hose on DP elevators. Engage fish. Fish would not go into grapple. POOH. M/U overshot assy w/hollow mill and 3' extra extension. Engage fish. latch fish. Pull fish free. Circ. out gas. POOH. 03-Sep-02 11 Lay down production equipment. PU packer plucker mill, TIH, mill tight spots at 6404' and 6590'. Mill FB-1 Packer at 6891', TIH to tight spot at 7200, Circulate. Printed - 10/30/2002 'f • • Daily Summary for Well: Report Report MD TVD Date Number 04-Sep-02 12 05-Sep-02 13 06-Sep-02 14 07-Sep-02 15 08-Sep-02 09-Sep-02 10-Sep-02 11-Sep-02 12-Sep-02 13-Sep-02 17-Sep-02 18-Sep-02 19-Sep-02 20-Sep-02 09-Oct-02 21-Oct-02 WOLF LAKE 2 Summary POH with FB-1 production packer. RIH with watermelon mill, milling tight spots in casing. CBU and POH with milling assembly. Pick up and RIH with perforating assembly. Log on depth with schlumberger. Drop bar and fire guns. j CBU. POH and lay down perforating assembly Test BOP, TIH with scraper and string mill. Repair Rig. TOOH, PU Perf guns. RIH with pkr assembly. Run GR-CCL to correlate pkr on depth. Set packer at 6861'. Release drill pipe from pkr and POH, laying down DP. Rig up to run 2 7/8" production tbg. 16 Run 2 7/8" tbg and blast joints.Run 1/4" ss chem injection line from 1700' to surface. Sting into packer and space out tbg. Land tbg in wellhead. Replace upper pipe rams with 2 3/8" rams and test same to 300/3000 psi. RIH with 2 3/8" tbg. 17 Run 2 3/8" production tubing. Circulate inhibited fluid into annulus. Space out and land tbg. Set dual packer. Pressure test annulus. Set back pressure valves. Nipple down BOPE and nipple up production tree. 18 Nipple up and test production tree to 5000 psi. Rig released at 12:00 9/9/02 19 Pulls BPVs from both strings. RU flowback iron. 20 Opened sliding sleeve, circulated completion fluid off the shortstring using nitrogen. Shortstring still unable to unload itself. Close sliding sleeve, pressure up on longstring with nitrogen. 20 Run BHPB, Perforate Tyonek Sand, flow well, run gauge ring confirming gun drop. 22 RU CT unit, test BOP's, jet well, Clean out scale plug, RD coil spool for new one. 23 Change out Coil Tubing Spools, Well Shut In. 24 Test CT BOP, Jet well to 7500' recovering 58.5 bbls fluid. RD CT, SWIFN. 25 Wellhead pressure zero psig, will shut in well until 9/23/02. 26 Tag fill at 7210 WLM, run BHPB. 27 Tag fill at 7210' WLM, fell through, bail at 7474' KB, Printed - 10/30/2002 • MN~~dN ~ 3 1/2" EUE lift threads in boths sides of the dual hanger Dual hangers swedged 3 1/2" EUE to tubing string immediately below hanger Wolf Lake # 2 20" K-55 5' 133 Ib/ft Drive pipe 66' 2 3/8" Chemical Injection Sub @ 1597' 2 718" Chemical Injection Sub @ 1696' 2 7/8 "EUE 8rd Long String ~° Special Clearance Couplings 2 3/8 "Short String Improved ~,; Buttress Tubing with Special Clearance Couplings Production Tubing 13 3/8" K-55, L-80 0' 68-721b/ft BTC 4322' ^._ . i ` ~_ `~ ''-' ~ GT Dual Packer 5991' MD ~ 5987 TVD ~ ~ _~ ~- a ' { _; ~j '. 2 3/8" 1.875 XN Nipple (6008') and WLEG (6009') j ` ~ a ~L~ ~ 2 7/8" CMU Sliding Sleeve @ 6037 ~; ' ~ ' 2 7/8" 2.313 X Nipple @ 6077 2 7/8 EUE 8rd Tubing/ Beluga Perforations Blast Joint Assembly srx. Original BHP 2914 psia Win. ~ u 6095-6110', 6166-6176', 6202-6210', 6356- 6379', 6392-6420', 6454-6466', 6506- 6520'. n ¢~. .v :~ ~ 9 5/8 Permanent Packer w/ SBE and I concentric crossover 6860' MD 6831' ND Tubing Adaptor j ~t, a ; 9 ~ 2 7/8" 2.313 X Nipple ~' 40' Blast Joints ~ Tyonek Perforations 7010-7038 m "~ Original BHP 3391 psia 2 Joints 2 7/8" Tubing BIT @ 7110' Joint 2 7/8" Tubing Auto Release Firing Head @ 7143' Bottom at 7151' ~~-Tyanek Perforations 7398-7468' 7752' Calculated PBTD e kI 80' 4 5/8" guns and 237' 3 3/8" Top of Guns and Baker 6AA ~ ~ . CIBP @ 8,069', tagged 9/04/2002 -~'. , o ~/a^ c_qF n' . f { ~ 1. .. ,_,_ 7" S-125 11834' M Marathon MARATHON Oil Company June 26, 2002 Mr. Tom Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 • Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 Reference: Field: Wolf Lake Field Well: Wolf Lake #2 Regarding: Workover to perforate additional zones. Dear Mr. Maunder Enclosed please find the Application for Sundry Approval. Attachments include well schematics and a workover procedure. Our current rig schedule forecasts a tentative start date of July 15, immediately following the Wolf Lake 1 reentry. If you require further information, I can be reached at 907-564-6318 or by a-mail at deynon@marathon.com. Sincerely, Donald Eynon Production Engineer Enclosure ~~~~~ ~1tlGZSR~ ~inl ~ :a ut~1=~+. U~.t:~icvtl.s:rl6f-` ARCfIQC~.7~ ~~~iVNE~ .!!JL ~ 2D02 f5{-~,~@ ~~ ~ ~ n$$ ~ ~ ~ • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 0:\EXCEL\WL2AOGCCsund.XLS ~_ _. :~ f ~. 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 X Other X 2. Name of Operator 5. Type of Well: s. Datum Elevation (DF or KB) MARATHON OIL COMPANY Development X Pad Elevation 230 feet 3. Address Exploratory _ 7. Unit or Property Name P. O. Box 196168, Anchorage, AK 99519-6168 Stratigraphic_ Wolf Lake Field a. Location of Well at Surface Service s. Well Number 1183' FSL and 2265' FWL, Section 29-7N-9W Wolf Lake #2 At top of Productive Interval 9.. Permit NurrlR~er Top of Pay (Tyonek): 1285' FSL and 2236' FWL, Section 29-7N-9W 1 At Effective Depth 70. API Number f 50- 133-20375 At Total Depth ~ ~. Field/Pool 2621' FSL and 488' FWL, Section 29-7N-9W Tyonek/Beluga 72. Present Well Condition Summary Total Depth: measured 14,451 feet Plugs (measured) CIBP @ 8069' true vertical 14,086 feet EZSV @ 11,485' Cement @ 13,200' Effective Depth: measured 8069 feet Junk (measured) 36' of TCP guns @ 8033' true vertical feet Casing Length Size Cemented Measured Depth True Vertical Depth Structural 66' 20" 150 sx 66' 66' Conductor Surface 4332' 13 3/8" 2445 sx 4332' Intermediate Production 12152' 9 5/8" 1000sx 12152' 11818' Liner 1557' 7" 1000sx 13391' 13039' Perforation Depth: measured Tyonek - 7010' - 7038' ~ ~ f' ~ ~ '~ sr f°' "'~ ..., ~ „ ~~ ~ ~ ~~,. ~, Beluga - (isolated) - 6392' - 6420' ` ~° ~"" ~ true vertical Tyonek - 6974' - 7001' Beluga - (isolated) - 6381' - 6408' ~=jj ~ `~ .:' ~ ,.~ y y i, Tubing (size, grade, and measured depth) 3.5", 9.2 ppf, N-80 to 7006' }~ {~ y Packers and SSSV (type and measured depth) Baker model HS retrievable packer at 5884' ~f.,, C'' ~ t] Baker model FB-1 permanent packer @ 6891' MD 73. Attachments Description Summary of Proposal Detailed Operations Program X BOP Sketch 74. Estimated Date for Commencing Operation 15. Status of Well Classification as: 7/15/2002 7s. If Proposal was Verbally Approved Oil Gas X Suspended Name of Approver Date Approved Service 77. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed r; .--~+~ ~ {?~.~- Donald Eynon Title Production Engineer Date 6/26/2002 FOR COMMISSION USE ONLY Conditions of Approgval: g ~tity Commission so repre ntative may witness 3~~~ PS ~ (3~'~ ,~.~. Approval No. ~O ~ _. ~ l Plu Inte ri BOP Test Location Clearance _ _ Mechanical Integrity Test_ Subsequent Form Required 10- t-}~'~'1 Ongmal Slgn~d By Approved by Order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Sub it Triplicate ~,. " ~-(~6~NPIEU JUt ~ ~ i'002 ,~ • • M MARATHON Marathon Oil Company Alaska Region Well: Wolf Lake 2 Wolf Lake Field Workover Procedure 6126/02 Problem: Tubing restriction at 5930' prevents adding additional Tyonek perforations. Objective: Pull production assembly and remove Model FB-1 Packer if fishing tools are required to pull production assembly. The well will be recompleted with a dual packer, 6 additional Beluga zones and one additional Tyonek zone. A. Pre-rig up killing procedure: If possible when rig is finished on Wolf Lake 1 utilize it to mix 9.3 PPG KCL brine and HEC viscous pill, as per M-I Drilling Fluids instructions. B. Rig up BJ services to pump 40 bbl, 9.3 PPG HEC viscous kill fluid down tubing string followed by 60 bb19.3 PPG brine, while monitoring annulus for communication. a. If no communication is seen, fill annulus with 9.3 lb/gal KCL brine and test packer to 1000 psig. b. If communication is seen the annulus may require up to 360 bbl to fill utilizing a lubricate and bleed process. Workover Procedure: 1) Bleed off pressure from tubing and annulus and install BPV in tubing string, and VR plug in annulus if needed. Bleed trapped pressure off control line. Have wellhead vendor prep bolts and nuts as needed for rig. Contact production personnel for future dual wellhead orientation. 2) MIRU Glacier Rig #1. 8100' of 4" 141b/ft HT-38 drillpipe drifted to a 2.3" ID will be needed. 3) ND tree and NU BOP equipped with 2 7/8"- 5.5" VBR rams on top and 4 DP rams on bottom. Have the existing tree shipped to Vetco for inspection and testing prior to use on well BC-11. 4) Pull BPV in tubing string. 5) Install two way check valve in tubing string. 6) Pressure test BOP to 250 psig low / 3000 psig high. 7) Pull 2 way check in tubing string. SC~IViUE~ Jt1L i ~ 2D02 • • 8) RU tubing tools and insta113.5' EUE 8rd landing joint, while ready to pump down tubing string, back out lock down lugs, pull approximately 40,000 lbs over string weight to release Baker HS hydraulic set packer. Anticipated string weight is 55,3001bs (64,500 lbs less 9,2001bs buoyancy with 9.3 PPG fluid). Maximum pull on a single string of 3 '/z N-80 Buttress tubing is 159,090. Recommend pulling to 80% of maximum, which equals 127,000 lbs. (6' of upward movement will remove seal from seal bore of bottom packer, which exposes the Beluga perforations if the sliding sleeve at 5929' is currently closed). a. If packer/tailpipe releases TOOH laying down tubing, 1/a" control line, gas lift mandrel, HS packer, blast joints and seal assembly. Install thread protectors on 3.5" tubing and send tubing in to be inspected for future use. RD tubing handling tools, change out slips tongs elevators for DP and proceed to milling of FB-1 packer, step # 23. b. If packer does not release continue to step 9. 9) RU APRS and run 1.35" free point tool, be aware of tubing restriction at sliding sleeve (5,929') below HS packer limits tubing access to above this point. Based on free point analysis and fishing hand recommendations, RIH with jet cutter and cut tubing below packer, see attached tubing tally run record. 10) Pull on tubing to see if packer can be freed. a. If packer comes free, TOOH laying down tubing, '/4" control line, HS packer and proceed to fishing tailpipe, step #20. b. If packer remains stuck RIH with chemical cutter to cut off tubing above packer based on free point analysis, RD APRS. 11) TOOH laying down tubing, '/4" control line, and gas lift mandrel. 12) RD tubing tongs and handling equipment. 13) Change out slips, elevators and tongs for DP. 14) RIH with the following, a. Baker 7 5/8"overshot with basket grapple dressed for 3.5" OD tubing b. 6 1/4" bumper sub c. 6 1/4" oil jars d. 6 1/4" drill collars e. 6 1/4" Accelerator £ 4" 141b/ft HT-38 drill pipe 15) Latch as per fishing hands recommendation, work drillpipe to free packer with jars. a. If packer comes free TOOH laying down HS packer, and proceed to step 20. b. If packer remains stuck release overshot and TOOH. 16) RIH with the following to mill over packer, a. Baker 8 3/8" washpipe b. 6 t/4" bumper sub • • c. 6'/0" oil jars d. 6 '/4" drill collars e. 4" 141b/ft HT-38 drill pipe 17) Wash over packer as per fishing hand recommendation, using 9.3 PPG brine to circulate, and HEC viscous pills as necessary to maintain circulation. POOH. 18) RIH with the following, a. Baker 7 5/8"overshot with basket grapple dressed for 3.5" OD tubing b. 6 '/4" bumper sub c. 6'/4" oil jars d. 6 '/4" drill collars e. 6 '/4" Accelerator £ 4" 141b/ft HT-3 8 drill pipe 19) Latch as per fishing hands recommendation, work drillpipe to free packer with jars. TOOH laying down packer. 20) RIH with the following to fish tailpipe, a. Baker 7 5/8"overshot with mill control grapple dressed for 3.5" OD tubing b. 6 '/4" bumper sub c. 6'/4" oil jars d. 6 '/4" drill collars e. 6 '/a" Accelerator £ 4" 141b/ft HT-38 drill pipe 21) Latch as per fishing hands recommendation, work pipe utilizing jars to free tubing. a. If tailpipe comes free TOOH laying down blast joints and 6" seal assembly. b. If tailpipe will not release consult fishing hand to either run washpipe or outside cutter to remove remaining tubing and seal assembly. 22) RIH with overshot, latch as per fishing hands recommendation, work pipe utilizing jars to free tubing, TOOH laying down overshot and fish. 23) PU 8.375" OD Baker mill for drilling up FB-1 packer, junk bumper sub, jars, 6'/4" drill collars, and drill pipe to packer at 6891'. 24) Drill up packer as per fishing hand recommendation, pumping hi viscosity sweeps if needed to remove cuttings. Push remains to 8020' +/-. Note: 36' of shot TCP guns, and 12' of firing head-drop/bar should be @ 8021',on top of Baker CIBP @ 8069'. 25) POOH with mill and drill collar assembly. 26) Hold pre job safety meeting for perforating hazards. PU Halliburton TCP guns on DP with radioactive marker to perforate new Beluga zones from 6095-6110', 6166-6176, 6202-6210', 6356-6379', 6454-6466', 6506-6520', with 4 5/8", 5 SPF Millennium Charges and 70° phasing as follows • • a. 15' of 5 SPF Millennium Charges with 70° phasing b. 56' of 3 3/8" gun spacer c. 10' of 5 SPF Millennium Charges with 70° phasing d. 26' of 3 3/8" gun spacer e. 8' of 5 SPF Millennium Charges with 70° phasing f. 146' of 3 3/8" gun spacer g. 23' of 5 SPF Millennium Charges with 70° phasing h. 75' of 3 3/8" gun spacer i. 12' of 5 SPF Millennium Charges with 70° phasing j. 40' of 3 3/8" gun spacer k. 14' of 5 SPF Millennium Charges with 70° phasing 1. Model 2D 1500 psi firing head m. Vent Sub n. X-over to 4" 141b/ft HT-3 8 DP 27) RU Schlumberger to correlate TCP guns with Gamma Ray to Dresser BHC log dated 1/26/85. RDMO Schlumberger. 28) Move DP to place guns on depth. Hold safety meeting. Close rams on DP prior to firing guns and monitor casing/tubing for flow, circulating viscous pill only if necessary to minimize losses, TOOH laying down TCP equipment. 29) TIH with mill and casing scraper to new PBTD, Circulate bottoms up. TOOH with drill pipe, scraper and mill. 30) RU slips and slip type elevators to handle 2 7/8" EUE 8rd SCC tubing. 31) RU Weatherford Tubing Services to makeup tubing to be run below packer. 32} Prepare to install guns across Tyonek interval from 7398-7468' (70') and Baker model D packer at 6860' as follows: a. 70' S SPF Millennium Charges with 70° phasing b. 263" of 3 3/8" gun spacer c. 3 3/8' Auto release firing head d. vent sub e. 2 7/8" EUE 8rd tubing f. blast joints to be placed across upper Tyonek interval g. 2 7/8" EUE 8rd tubing to space out guns on depth h. joint of 2 7/8" 8rd EUE tubing i. 2.313 X profile nipple j. joint of 2 7/8" 8rd tubing k. crossover, seal bore extension, Model D packer on pressure actuated setting tool run on drill pipe with radioactive marker in drillpipe connection. 33) RD Weatherford and change over slips and elevators for 4" drillpipe and RIH with DP. 34) RU Schlumberger, RIH with GR, correlate to Dresser BHC log dated 1/26/85, to place guns and blast joints on depth. RD Schlumberger. ~~~i1NEC~ JUL ~ ~ 2002 • • 35) TOOH laying down drillpipe. 36) Change out elevators, slips and RU tongs to run 2.875 EUE 8rd tubing with special clearance collars. 37) PU 3.25" locator seal assembly, 2.875" tubing, blast joints to be spaced across the Beluga perforations, 2.875" tubing, 2.313 X nipple, one joint 2 7/8" tubing, CMU sliding sleeve with 2.313 X profile and one joint of 2 /78" tubing. 38) PU 9 5/8" Model GT dual packer with long string and a 1.781 XN profile nipple on short string below dual packer, scoop head above dual on short string. 39) RIH on longstring 2 7/8" EUE 8rd with special clearance collars until 1900 feet is left to run, RU PWS to spool and band chemical injection line. PU chemical injection mandrel, with check valves and rupture disk, '/4 inch injection line, and collar protectors and band to tubing from 1900 feet to surface. Holding pressure on control line while tripping in hole. 40) RIH and tag up on top of packer while circulating down long string to check for seal assembly seating in packer. Measure required space out and install appropriate subs. Install landing mandrel (3.5" EUE 8rd) on long string and chemical injection line to mandrel. Land in wellhead. Install two way check in LS. (Dual wellhead is 3.5" EUE 8rd thread on both LS and SS so a cross-over is needed). 41) Install short string tubing hanger with 2-way check in tubing head. Change out top rams on BOP to 2 3/8". Pressure test rams to 250 psig low / 3000 psig high. Change out elevators, slips and tubing tongs to handle 2 3/8" tubing. Pull two way check and install BPV in long string, pull short string tubing hanger with two way check. 42) PU short string seal sub and 2 3/8" tubing. Place a 2 3/8" injection mandrel, with check valves, and''/a" stainless steel injection line to be placed 1850' from surface. 43) TIH to top of packer, measure required space out, install subs and landing mandrel on short string and chemical injection line to mandrel. Land in wellhead. (Dual wellhead is 3.5" EUE 8rd thread on both LS and SS so a cross-over is needed). Test both injection lines for integrity before proceeding. 44) RU Pollard Wireline Service to short string. RIH with slickline shifting tool to lock short string mandrel into dual packer, POOH with shifting tool. RIH on SS with PXN plug and set in 1.781 XN nipple below dual packer. 45) RU rig pump on short string and apply pressure to set dual packer, release pressure. 46) RU rig pump and pressure test annulus to 1000 psi. 47) RU slickline to SS, RIH with pulling tool to remove plug in XN nipple, POOH, RD PWS. 48) Set BPV in both strings and remove BOP. Install dual tree. Pull BPV, set two way checks. Test tree. • • 49) RDMO Glacier Rig #1. 50) Pull back pressure valves. 51) RU surface flow line with choke manifold from short string to open top tank. 52) RU PWS to long string, Pressure test lubricator. RIH and set PX plug in X nipple one joint below sliding sleeve. RIH with shifting tool for CMU sliding sleeve and open sleeve below dual packer. 53) RU BJ services to pump nitrogen down long string while taking returns up the short string to a tank. Approximately 2400 psi surface pressure will be needed to displace nitrogen to sliding sleeve. While recovering tubing volume of 60 bbl monitor short string for flow from Beluga perforations. 54) RIH on long string with shifting tool for CMU sliding sleeve and shut sleeve below dual packer. 55) RU BJ and pump down long string to pressure up against PX plug to 2400 psig. 56) RIH with pulling tool on long string and pull PX plug. 57) Monitor Beluga zones for stabilized production (1.5 MMCFPD at 1500 psi required to unload well up short string). When stabilized, RD surface flow line from short string and RU surface flow line and choke manifold from long string to open top tank. 58) Open long string to tank to bleed pressure down to 1200 psi. (A 50% under balance would be 1790 psia at perforations.) 59) RU and pressure test Halliburton drop bar lubricator. Install listening device to wellhead to confirm bar drop. Drop bar to fire guns. 60) Monitor well for indication of gun detonation, open well to flow at minimum draw down until stabilized (2.2 MMCFPD at 1500 psi is required to unload), utilizing methanol injection as required, then connect to permanent flowline from well to production facility. S~AI~INE~ JUL ~ ' 200 M MARATHON Wolf Lake # 2 Current Wellbore 26 2002 • Gas Lift Mandrel Blast Joint Assembly Production Tubing Perforting Gun Baker 6AA CIBP @ 8,069' 3.5" 9.2 Ib/ft Production Tubing • 20" K-55 5' 133 Ib/ft Drive pipe 66' 13 3/8" K-55, L-80 68-721b/ft BTC Hydraulic Packer Baker CMU Sliding Sleeve @ 5929' ~~ ~.. ~~ Perforations 6 39a -~ ~~~' Production Seal Unit Baker F6-1 @ 6891 2.813 X Profile Nipple @ 6933 Perforations Tynonek 7010'-7038' 9 5/8" 47-53.5 Ib/ft .--- ^---_~~.. 7.. 0' 4322' S-95 0' BTC 12152' S-125 11834' v a ~ a M MARAT11OM _ Proposed Dual Wolf Lake # 2 • Chemical Injection Subs 2 7/8 "EUE 8rd Long String Special Clearance Couplings Production Tubing 2 7/8 EUE 8rd Tubing/ Blast Joint Assembly 2 7/8 EUE 8rd Tubing/ - Blast Joint Assembly Pup Joint Debris Barrier Auto Release Firing Head Blank Gun Assembly Perforting Gun Baker 6AA CIBP @ 8,069' a • 20" K-55 133 Ib/ft Drive pipe ial oduction Tubing / 2 3/8 " AB Short String w/ Special Clearance Couplings Production Tubing 13 3/8" K-55, L-80 68-721b/ft BTC Dual Packer 5990' MD 5987 TVD Sliding Sleeve Beluga Perforations Original BHP 2914 psia Exisiting - 6392-6420' Proposed Beluga - 6095-6110', 6166- 6176', 6202-6210', 6356-6379', 6454- 6466', 6506-6520'. 9 5/8 Permanent Packer 6860' MD 6831' TVD Tyonek Perforations 7010-7038 Original BHP 3391 psia Proposed Tyonek Perforations 7398-7468' 0' 4322' 9 5/8" S-95 0' 47-53.51b/ft BTC 12152' , .--- •---~,.. 7., S-125 11834' 5' ss' M Marathon MARATHON Oil Company December 4, 2001 Tom Maunder Alaska Oil & Gas Conservation Commission 333 W. 7th Ave., Ste 100 Anchorage, AK 9501 Dear Mr. Maunder: AlaskaF~on Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 /~$~ '~/j~ wry :~~ ~:~ G ® ` I `~! w ~i~: ~~~} ~~ ~~ The attached sundry notification (#301-323) is provided to document the first gas sales from the Wolf Lake #2 well, which is operated by Marathon Oil Company. Production to sales began November 17, 2001. Please contact me if I can be of further assistance. Sincerely, Gary Eller Advanced Production Engineer ~~C~~ ~/ ~~'~ ~ Lu ~I ~! ~ Gas Cons. ~~assio And A subsidiary of USX Corporation Environmentally aware for the long run. g:\cmn\ddgUcgf\wel Is\ku 11-Ss\AOGCCOI a.xls • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS t. Operations performed: Operation Shutdown Stimulate_ Plugging_ Perforate_ Pull Tubing _ Alter Casing Repair Well _ Other X 2. Name of Operator 5. Type of Well: 6. Datum Elevation (DF or KB) MARATHON OIL COMPANY Development_ Pad Elevation 230 feet 3. Address Exploratory X 7. Unit or Property Name P. O. Box 196168, Anchorage, AK 99519-6168 Stratigraphic_ Wolf Lake a. Location of Well at Surface Service_ 8. Well Number 2265' FWL, 1183' FSL, Sec. 29, T7N, R9W, S.M. # 2 At top of Productive Interval 9. Permit Number .8~~2UT~~ ^ /~Z Lg At Effective Depth Notif of First Production y to. API Number 50- 133-20375 -. p At Total Depth tt. Field/Pool 488' FWL, 2621' FSL, Sec. 29, T7N, R9W, S.M. Tyonek t2. Present Well Condition Summary Total Depth: measured 14,451' feet Plugs (measured) CIBP at 8069' true vertical 14,086' feet EZSV @ 11,485' cement 13,200' Effective Depth: measured 8069' feet Junk (measured) 36' of TCP guns at 8037' true vertical feet Casing Length Size Cemented Measured Depth True Vertical Depth Structural 66' 20" 150 sx 66' 66' Conductor Surface 4332' 13 3/8" 2445 sx 4332' Intermediate Production 12152' 9 5/8" 1000 sx 12152' 11818' Liner 1557' 7" 1000 sx 13391' 13039' Perforation Depth: measured Tyonek - 7010' - 7038' ' ' ~\ j / ~ Beluga (isolated) - 6392 - 6420 , true vertical Tyonek - 6974' - 7001' Beluga (isolated) - 6381' - 6408' " ' •-, ~-• ~ t t- .- ,. ~"~` ' '~ '~ ~ ~~'~ Tubing (size, grade, and measured depth) 3-1/2 , 9.2 ppf, N-80 to 7006 " - Packers and SSSV (type and measured depth) Baker HS retrievable packer C~ 5884' r118~1I~c'~l:OfiS.~OffN~lI55i0X'' Baker FB-1 permanent packer @ 6891' AOGf10~2t1~ t3. Stimuiation or Cement Squeeze Summary Intervals Treated (measured) N/A Treatment Description Including Volumes Used and Final Pressure N/A ta. Representative Daily Average Production or Infection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation 0 0 0 0 0 Subsequent to Operation 0 3500 0 0 1500 t5. Attachments ts. Status of Well Classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations Oil Gas x Suspended Service 1 ~. I he by certi at the foregoing ' true and correct to the best of my knowledge. Signed J.Gary Eller Title Production Engineer Date 12/04/01 Form 10-404 Rev. 06/ /68 J Submit in Duplicate RBDMS 8Fl • ;~ARa~wnN • Wolf Lake Field Well #2 Marathon Oil Co., Alaska Region KB-GL: 35.0' 2265' FWL, 2621' FSL Sec. 29, T7N, R9W, S.M. 20", 133#, K-55 @ 66' (cut off @ 5') ac~ Cmt w/ 150 sks class "G" ~~ ~.~~. >.~ ~; lc a- `hoar Otis SCSSV mandrel 987' ~ ~ ~'' ~ @ ~-' ~ ~ ~ X 13-3/8", BTC casin 4322' w/ X-profile (ID = 2.813") g @ ~~ ~ .~ ,- € ~°~"• ~~ ~ 0' -1979', 72#, N-80 ,~ 1979' - 3676', 68#, K-55 2676' - 4322', 72#, L-80 Cmt w/ 2445 sks class "G" Tubing: 3-1/2", 9.2#, N-80 joints 1 - 116 are AB-Mod. Butt. McMurray gas lift mandrel @ 5839' points 117 - 169 are regular Butt. (Dummy valve installed 10/25/98) points 170 - 229 are special clearance butt. ' ~,,_ ~ Baker HS retrievable packer @ 5884 ~ ~, Note: Likely to have been onset during perforating on 10/26/98. X Baker CMU sliding sleeve @ 5929' w/ X-profile (ID = 2.813") Note: Slickline hung-up in sliding sleeve on Beluga Perforations 10/31/98 with 2.70" gauge ring, and probably 6392' - 6420' DIL (12 spf, 10/20/98) shifted sleeve into the open position. Steel blast joint 6385' -6424' OD = 4.50" Baker FB-1 permanent packer @ 6891' TDT X-nipple @ 6933' ID = 2.813" End of tubing @ 7006' Tyonek Perforations 7010' - 7038' DIL (12 spf, 10/25/98) ~ 0 36' of 4-5/8" TCP guns @ 8033' ~ ~ plus 10' of 1-1/4" drop bar Baker "6AA" CIBP @ 8069' .~ ~_ ~ " r= ~. ~ Old 12 ppg mud cleaned out to 8200' ._.~ ~----~ ~ ~ Cement plug @ 11,385' EZSV Retainer @ 11,485' Top of 7" liner @ 11,834' 9-5/8", 5-95, BTC casing @ 12152' 0' - 174', 53.5# 174' - 11,126', 47# 11,126' - 12,152', 53.5# Cmt w/ 1000 sks of class "G" ~~_~ ` ~ ~~,\ Cement plugs 13200' to TD -~ ~- ` ~ ~ ti~ 7", 32#, 5-125, BTC liner 11,834' - 13,391' ~ ~r ~ ~~ Cmt w/ 1000 sks class "G" Last Rev: JGE, 3/9/99 TD = 14,451' -NOV-16-~2001'FRI 0500 PM MARATHON. OIL: COMPANY FAX NO; 907 283 6175 P, 01 .-~. . ~. Kenai Gars 1°ie{d .....~~' Pta Box'19~'r9 ~.~ r~il~"~~.~"1i~~ _ `Kenai, AK 99611-19h9 1. 1+,~r~~.'u~~fr°F~~"3I(~ ~,;~~~ ~~om~~r~~- TGIGphone (907) 283-'13G0 F'a~ (907) 283-6175 ~°"v ~~ Nr~,r ~.~ .... -~-_ _r - -~ NOU 16 2009 f.,;t7~,~f'I~~JY'~_._._._.~~f~~~~a~~..._~,,... ..~ .,. Alaska0~~&ud~;~.;ou~, „~,:~,:~,,. , ,~ F~'I!c'C-.r;; ;r1=t~~f (Irt~lcacJir~g C~vE:r ~hi~:et) ~:._`+ ~„ [ .i f+c~~;,u>ri::~c~ t~~c~~l2slr..c1 [ ~ Imm~rycli~te [ ] Infcarmati~n Only ; ,.: t\~V~~~~ NQV-16-2001 FRI 0500 PM MARATHON OIL COMPANY FAX N0, 907 283 6175 P, 02 ,. - - "a. '+_ ~T'Al-~ OF ALASKA Al_~;SECA C}1(_ At~J~ GAS ~;C~NS~Ct1/FrTI~Oiv COMMISSION {. ~~'P1..1~1~TIN F~~F~ StJ~I®R~C APPFi~VALS 1 'hyi.~ s,f ^,~+,tiir:.i; .~ ~. P+b<~n+,irrn w.~- ~ uu,r+~nd-~--._p~rrat,on Shutdown _ Re-enter Stspended lN[II M . r~tt,:r r:, t€,in~ ~ Rt:nrair V6'cff _ Ffacl;~inp_ Time "xtenslon^ Sllmulate (:hsn;7eaAtsptovedf'ro3rs,m 1'ut1'fubinp V~rinnce Perforate Oiht~r X WN§.h; , t:+1`atir . r ~_~--~_ ~. ^~~- 5, t'yp+? M V'lell; 6; D~stum ElevatioltM(DF or N;B) - ~+ f d~112>1'f l ~r a€ f l'>:L GCd;.ii'Q.NY Development X Pad Elevatiutt ?.!Q f ~~! r .~.~-- ...... .,.-... ......, ..~...-_.........-_...,,W~-.~ .~....~..,,,,..._ _.__. ... ~, A.lrtr~~ >-, Expiorataty_ 7. Unit or Property Narnc -+. Cs. i3t-.x ti:f ts:P,_l~,n;;horat's~~~At< aSJ~~'13.6183 SG<sll~raphic W41f t_akc ,, M. -_ ~ Ler~.riutt t,t'(ti4'ti c~i .,;x€3tWv ... --- 3eMco ^ a. Weft Number t ~+<•i'•,` t WI , 1113' L:Y:, f;~:4. ;y`~, 1'%N, r~JW, S.M. r ., ft 2 ,_,~..,~,..._-..,, ,~.1 t+ 1~ t~tf res,iut,tit,'+. la,h:ay„1 ...:._~._~~..~, .._ _ ... -~.n.,~r ~9. Pern Nuisik,er ~ I~I~ns ~r~ ~o fil~v+r well Co pt'oduc~lot~ 8 01 ~~~~~-~ '~ .";t [ +G; h't. Cs;;ai1 .r ^y 10. API Numk:er ~~~_~ ",t },st.r{ I7~,,'i!'t "'. 11. Fieldif'ool "~+. hU`/l.,'i'i+yl I ~,I , ,~ ort 77?d, ft'.3W, I~i.fvi. Tyonek i7 l,i~ ...rst't1F(r~'1i..t,.r.i...r„n"un',rn.rry~ 1'.„1~,i l`+y:ti' : ii:r.-t:',i!re<i 11,~i a1' tact' Plugs (inedsurcd) C10P at8069' • t>:~E; V'.atical 14,Gi'1u fl~fa E7_SV i~ 11,485' ' cement 13,201)' 1: li: 'ai;:: i>,.•r~t;ti; ~±e~.+~~irt;d E<BG3' fact Junk (mca~ured) 36' of TCP gUn9 at 803T true' vertt~:~at feet l'.. !t ~'7 Lr+ii3th uixa CemenC~~ci Mr3asured Depth True Vertical Dcptis 'r~tru tt;,,l G+~ 20" 150 sx 66' ci6' • Ciltti.r~: ; 4332' 13 31ii" 24-1 ~x 4332E Itst+::,th,~tL.t~ ' is+.,lur,.`;rnis 1215:?' 9518" t000sx 12152' 110118' ' ~ l inr•r iG~ , 7" 1AQO sx 13391' 13039', t',:,w,rbc~11 C~.•r++i1: rtr~~.,ccsro,l 'rygrrclc- r0I0'. x0.3£1' ,, , Eiclu3a (SOtaled) . G397 - G 1/0' ' uu4 vrrrti+:al Tyonek • G9/4 - 7001' ~ 9. + flolug3 (k~.ili~i'8(J) - 63!}}1' - fi$t,17y 1'sl,ir.p (;'~ •, c;i :, Is:, nn:1 r,:t•;+ytitrc;d dr:ptiti) S-1/?'; 3.2 ppF, N• GO to 7006' NOV 16 X00 ' .Ca~'1~.',.; .:rrd u",:~1! (lyl:~ oral stn;cteurur] depth) U:ther HS ratrigVaLlo Pgcher ~ `ad[3~' . Dalccr FB•1 p,arm~tzant packFr ~ 6fl91' AIaSICd nll $c C~1S t;UttS t,~t:,+t ~tr:~~'+, ' 11 .~+tt~a~;tns~laYt'., ~~•~~~+~ ~-~-~~ ~(~o~,:ri~rtion Summary of Prgpo~at' ~ Drtailed Opcrr[ioslrs E'rogram BOP S itch ' jd. t~ .tbu: t. d is+s!c: fur (3r.Imi iurlCina d}~erakt~lsl 1G. Status of W':.ll ClasoiBcatian as: : 'iia.~~h ~'rulin=,;d k•:^x L': i!.,,+i~y /1pt)tUV+;d ....:....~..-..__.._ O+1 _ Gas X 5uspen•~ed tV'iY24 NI r+~ ~.rta';f•r Dsttc Approved Servie® i T l l5t•:It:t7j~ Ct vrtiy tl;!t tt+,1 f Yf!`c3<il,;,~ is t111N h(+tlCGrtr'Ct fghw taH9d Gf sts3r knpwledge. ' .,..:>•,trlc,l ..,,,,..•~, -_..__....... ..~_~._.WaynaGisNtl tstla En~in~fir~Technlcian _~^ Date ,11117/2001 .. _ FAIT CCiMMISSIQN USA CENLY ...` .~.,...._,_. £:ry;,tilinn . c.f Ap 1ra~ „i: ~ i~'+ ,iy Cgsnrnisnirn rrr rirl.+rc crrfative rn.•ry wlt,t>_..r. ~~ nPPrgval No~~ 1 ~ 3 a 3 ' Fiu~rtrria~3td% i8C3F "l?st _ LOCrstionClearanc.e ~.~ din. nru;i+:+114rtF-n~lty T~•s:+tP_~ ~' v:d~~r;~{ur:nl f'rrrn Require, 1t)-~ ' la>fs.:~re:d I'y K'rt+~•:,f 4u;hat nlrr,,;5ipn ft.c:+ U-L:v Commtssloncr D~rte .,~ „ f e. ~, ~,<',~a, to, , o ;st,•`Yr - . ».»„~.~.~-- -r- -...».»....- ~.._~ ~~ Suhrnit In Trlplicato ORIGINAL M Marathon MARATHON Oil Company January 23, 2008 [~Q~ ~. ~ ~~~i~~ Alaska Oil ~ Anct ®~ ~cae Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Wolf Lake Well: Wolf Lake #2 Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Attached for your records is the 10-404 Sundry Report for WL-2 well. This sundry covers the venting of gas during well cleanup completed under sundry #301-297. Please contact us at (907) 283 -1371 if you have any questions or need additional information. Sincerely, Wayne E. Cissell Well Work Over Supervisor Enclosures: 10-404 Sundry Report cc: Houston Well File Operation Summary Kenai Well File KJS KDW STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIONM~Y ~ 6 2008 REPORT OF SUNDRY WELL OPEI~~C~as Cons. Cammission A ....6r nrnnt~ 1. Operations Abandon Repair Well Plug Perforations Stimulate r ~ Vent Gas During Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Well Cleanup Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2.Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Oil Company Develo ment Ex lorato ~ P ^ p ry Q 198-142 - 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20375 9t~[.b 7. KB Elevation (ft): 9. Well Name and Number: 261' Wolf Lake #2 - 8. Property Designation: 10. Field/Pool(s): N/A Wolf Lake/ Tyonek 11. Present Well Condition Summary: Vent gas during well cleanup for 4 hours. Total Depth measured 14,451 feet Plugs (measured): CIPB @ 8089' true vertical 14,086 feet EZSV @ 11,485' Cement @ 13,200' Effective Depth measured 8,069 feet true vertical 7,979 feet Junk (measured): 36' TCP gun at 8037' Casing Length Size MD TVD Burst Collapse Structural 66' 20" 615' 66' 3060 psi 1500 psi Conductor Surface 4332' 13 - 3/8" 4332' 4431' 3450 psi 1950 psi Intermediate Production 12152' 9 - 5/8" 12152' 11818' 8150 psi 5090 psi Liner 1557' 7" 13391' 13039' Perforation depth: Measured depth: 7010' - 7038' Gross, 6392' -6420' Isolated True Vertical depth: 6974' - 7001' Gross, 6381' -6408' Isolated Tubing: (size, grade, and measured depth) 3-1/2" N - 80 7006' Packers and SSSV (type and measured depth) Baker HS retrievable packer 5884' Baker FB-1 Permanent Packer 6891' 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 N/A N/A N/A N/A Subsequent to operation: 0 N/A N/A N/A N/A 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil^ Gas^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 301-297 Contact i Skiba (907) 283-1371 Printed Name Wayn E. Cissell Title Well Work Over Supervisor C Signature Phone (907) 283-1308 Date 1/23/2008 ~~, ~~t~ `~ ~Q~S iR ~'~,01~ l; ~' li_ ism ,S- o-off' Form 10-404 Revised 04/2006 Submit Original Only MARATHON OIL COMPANY DATE: 10/24/2001 FILL DEPTH/DATE: _ DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 FIELD: Wolf Lake WELL #: WL #2 TUBING: 3 1/2" CASING: 9 5/8" TREE CONDITION: Good BENCHES OPEN: Tyonek Blow down well to open top tank WIRELINE CREW: Hrs. SUMMARY OF OPERATIONS 1150 1400 RU chicksan, choke to open top tank. Blew down well to open top tank to verify any liquids and well conditions Start WHP= 2600 psig., Annulus = 1050 psig 1155 WHP=2250 psig, Annulus = 1050 psig 1200 WHP=2100 psig, Annulus = 1050 psig 1210 WHP=2050 psig, Annulus = 1050 psig 1220 WHP=2050 psig, Annulus = 1050 psig 1230 WHP=2050 psig, Annulus = 1050 psig 1245 WHP=2050 psig, Annulus = 1050 psig, no water 1300 WHP=2050 psig, Annulus = 1050 psig, no water 1315 WHP=2050 psig, Annulus = 1050 psig, no water 1330 WHP=2050 psig, Annulus = 1050 psig, no water well no change in pressure or water rate RD iron Vendor Equipment Daily Cost Cumulative Cost DAILY COST: CUM: REPORTED BY: Wayne Cissell Oct-1T-O1 10:27am From-V~ARATHON 0 +9155646469 T-514 P.02/04 F-120 " ~ ~ t'~ STATE OF ALASKA 'u~~~lui ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICIa-TION FOR SUNDRY APPROVALS ~lo ~~~ ~~`c' 1, Type of fiequest. Abandon Suspend Operation Shutdown _ Re-enter Suspended Well Aher Casing .--.- Repair Well_ Plugging- Time Extensior_ StimulatQ~ Change Approved Program _ Pull Tubing _ Varidnca_ Perforate- Other X 2. Name of Operator 5. Yype of Well: s. Datum. Elevation (0F ar Ks) MARATHON OIL COMPANY Gevebpm®nt _•___•_____~„ fs®t Pad E,evation 230 3. Address Ekploraroty XX - 7, Unit or Praperky Name AK 99fi19-6168 Box 186168 Anchorage P O Stratigraphic Wolf Lake ~ , . . , a. Location of Well at Surface Service- a. Well Number R9W, S,M, 1183' FSL Sec 29 77N 2265' FWL ~ 2 , . , , , At top of Productive Interval 9. Pe umber At Effective Dapkh Vent Gas During Well Cleanup to• API Number ~~ ~ ~ t 50. 1 33-20 37 5 AtTotal papth tt. Flold/Pool 488' FWL, 2621' FSL, Sec. 29, T7N. R9W, S.M. Tyonek 12, Present WaH Condition Summary Tote! Depth: measured ta,a51' ~ feet Plugs (measured) GIBP at t?Ot39' ,rue v®rtlcal 14,086' feet EZSV (~ 11,485' cemenk 1s,2DO' Effective Depth: measured 8069'. foot Junk (measured) 36' of TCP guns at 8097 true vertical feet Casing Length Size Cemented Measured Depth True Vertical papth Structural tom' 2l)" 150 aX 66' eta' Conductor Surface 4332' 13 3/8" 2446 sx 4332' Intennediato Production 12152' 9 i3l8" 1000 sx 12152' 11818' Liner 166T 7" 1000 ax 13391' 18039' ' ~ ~ ~ ~ ' ' - 7038 ~ ; Perforation Depth: measured Tyonek - 7010 Beluga (isolated) •6392' • 6420' `` true vertical Tyonek - 6974' - 7001' _ Beluga (isolated) - 6381' - 64ott' ~ `~' ~ ~ ~ ~Q (1~ Tubing (size, grade, and measured depth) 3-112", 9.2 ppf, N-80 to 7006' ~1 tl Paokere and SSSV (type and measured depth) Baker HS retrievable packer ~ 6884' ~ oil & Gas lU®ns. ConltnfS5lorf Baker f'B-1 permanent packer ®6891' Anchorage 13. Attachments Description Summary of Proposal X Detailed Operations Program BOP Sketch 14. Estimated Date far Commencing Operation 15. Status of Well Classification as: 22-Oct-ot t6. If Proposal was Verbally Approved Oil _._. Gas X Suap®nded~ Name Approver Date Approved Service 17. 1 hereby ',y that the foregoln true and correct to the beat of my knowledge, Signed Gary Eller Title Production Engineer pate rxtfi FOR COMMISSION USE ONLY Conditions of Approval: n~fyC mmission so repreaentatly©may witness '~~Q pS~ H~Pnsi Approval No. 30 ~ _ an •-1 `~ ( _ Plug Integrity BOP Tost t.ocagon Clearance- Mechanical Integrity Test subsequent Form Required to•~ Original Signed 6~ Cammy IJeCh$ll Commissioner oats ® (.1 ~ roved by Order of the Commission Cuh if in Tri licnrr] Form Lagoa Rev. t~16Ba ~~-o~ ORIGINAL = Oct-17-O1 10:27am From-~1ARATNON OI +9155646489 T-514 P.08/04 F-120 • Wolf Lake #2 -1Vlarathon Oil Company `Venting During Well Cleanup Qctober 17, 2401 Summary: The objective of this procedure is to unload well WL-2 to an open top tank for a period of hours prior to producing the well to sales. This flowback will allow the well to clean up fluids and debris before producing the well to the production separator and sales meter. The Tyonek Sand perfs in well WL-2 were last tested at 3 MMCFA in Qctober 1998. It is anticipated that the duration of this flowback event will be 24 hours or less. Pending successful flowback of the WX..r2 well, Marathon anticipates producing First gas to sales within a few weeks. 1Vlarathan will inform the AOGCC once the well is produced to sales. G.Eller-10/17/2001. S,~T1~ ~~.ao0 ~S~ Ptc- C~ae-•.~~1,1~r- b~~ p~n+c ~o l ~-~ ~3o c'7 ~~~ i ~w~~c..~~ v P~~'tc-r~c~.M. o~- c.~c7 ~ b ~- ~~e~ ~ 30p~ g ~ , P ~~ KB-GL: 35.0' 2265' FV1L, 2621' FSL Scc. 29, T7N, R9W, S.M. S\'.a .~ -~~a'~e.ar Qtis SCSSV mandrel @ 987 ~. ~,., - w/ X-profile (113 = 2.813") ~. "~ ~,.ao~-.~-.~,) Tubing: 3-l l2", 9.21{, N-80 joints 1 - l l6 are A33-Mod. Butt. Joints 117 -169 arz rzguiar J3utt. - - - Jotnts 170 - 229 are spzeial clearance butt. ~._-. BoluAa Perforations 6392' - 6x20' pII. (12 spl; 10/20/98 ) 20", 133N, K-55 @ 66' (cut otF Q 5~ Ctnt w/ 1 SO sks class "4" 13-3/8", BTC casing ([~ 4322' 0' - ] 979', 72#, N-80 1979' - 3676', G8#, K.-55 2676' - 4322', 72#, L-80 Cmt w/ 2445 sks alas "G" McMurray gas lift mandrel (a~ 5839' ' (I?uttutty valve installed 110/25/98) Baker IBS reuicvablC packer ®5884' Note: Likely to have bccxt onset dating perforating an 10/26/98. Baker CMU sliding sleeve Q 5929'. tv! X-profile (ID = 2.813") Note: Slickl-tte hung-up in sliding sleeve an 10/3]/98 with 2.70" gauge ring; and probably sl-i13cd sleeve into the open posrtxon. Stccl blast joust 6385' -6424' OD = 4.50" Baker FB-1 permanent packer (c~ 6R91' TAT X-nipple @ 6933' ID - 2.813" lend of tubing Q 7006' onek Perforations 701 ' - 7038' DIL (12 spf, 10/25!98) 0 r - ~ ~. ~ i ~ ~t ~,~~ ~, =~T,,T'~L\ r ~~ Last Rev: JGE, 3!9/99 TU= 14.451' 3b' of 4-5/8" TCI' guns @ 8033' plus 10' of 1-I/4" drop bar Baker "6AA" CIBP @ 8069' Old 12 ppg znnd clcanCd out to 8200' Cement plug (~ 11,385' EZSV Retainer @ 11,485' Top of 7" litter Q 11,834' 9-S/8", 5-95, BTC rasing @ 12152' 0' -174', 53,5# ] 74' -11,126', 47# 11,126' -12,152', 53.5# Cmt w/ 1000 sks of class "G" Cement plugs 13200' to T'D 7", 32#, S-l2S, BTC liner 11,$34' -13,391' Cmt w/ 1009 sks class "G" M Marathon MARATHON Oil Company June 23. 1999 Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 The following logs are enclosed: .., ~ `1 .~ Alaska ~on Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907!561-5311 LETTER OF TRANSMITTAL Wolf Lake #2 1 1) Wolf Lake #2 RST- Sigma Mode October 16, 1998 Run: One Marathon Oil Company 2) Wolf Lake #2 Ultrasonic Imager Cement Mode October 16, 1998 Run: Two Marathon Oil Company Please sign and return confirming you have received these documents; ~_. MARATHON OIL COMPANY ~--~ -~ Kirsten K. Game! ?~ ,,~ ~ Received $y:' ~~~' "~ Enclosures '"~~~k~ ~;~ ~ ~~~s ~~ Date: wr rr n ..__ Print Reproducibl 1 1 A subsidiary of USX Corporation Environmentally aware for the long run. • M Marathon MARgTHON Oil Company November 17, 1998 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99513-7599 Reference: Wolf Lake #2 Sterling Unit #32-9 Dear Mr. Wondzell: Alaska n Dourest roduction P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Please find attached the Well Completion or Recompletion Report and Log, well schematic, survey calculation and field worksheet and daily reports for the above referenced wells. If you have any questions, please feel free to call me at 564-6315. Sincerely, J. . E r -- Pro ti n Engineer M:\WP\OPNS98WGE101. Enclosure xc: CEF Well Files . ,~» ~» ~~~ ~ ~~~ ~~~ ~~~ .b 4~~~~ ~a~~.~ .~ A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALA OIL AND GAS CONSERVATION C011~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL GAS^X SUSPENDED ABANDONED SERVICE 2. Name of Operator MARATHON OIL COMPANY 7. Permit Number 98-142 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 8. APt Number 50.133-20375-90 4. Location of Well at Surtace 1183'FSL, 2265'FWL, Sec. 29, T7N, R9W, S.M. COPvtPL~TOfV ~ 9. Unit or Lease Name Wolf Lake At top of Producing Interval 1285'FSL, 2236'FWL, Sec. 29, T7N, R9W, S.M. ~t j q V . IFiEll ~ ,~, f 10. Well Number 2 At Total Depth 2621'FSL, 488'FWL, Sec.29, T7N, R9W, S.M. ~ ~ 11. Field and Pool Wolf Lake Field 5. Elevation in feet {indicate KB, DF, etc.) 27.8' KB-GL 6. Lease Designation and Serial No. 84201 Beluga/Tyonek Pool 12. Date Spudded 10/5/1998 13. Date T.D. Reached 10/15/1998 14. Date Comp., Susp. or Aband. 11/1/1998 15. Water Depth, if offshore N/A feet MSL 16. No. of Completions one 17. Total Depth (MD+TVD) 13391 MD, 13039' TVD 18. Plug Back Depth (MD+TVD) 8205' MD, 8104' TVD 19. Directional Survey Yes X^No ~ 20. Depth where SSSV set N/A feet MD 21. Thickness of Permafrost N/A ' 22. Type Electric or Other logs Run USIT, TDT (cased-hole logs only) 23 CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOdiE1~J(~'aS C 20" 133# 0 66 26" In place N/A t1C Oi' 13 3/8" 68&72# 0 4332 17-1 /2" In place N/A 9 5/8" 47&53.StF 0 12152 12-1 /4" In place N/A T' 32# 11834 13391 8-1 /2" In place N/A 24. Pertorations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number} SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2", 9.2# 7006' 5884' & 6891" Beluga Sand: 6392' - 6420' DIL, 6381' - 6409' TVD 12 spf, 41/2" tubing-conveyed guns 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Tyonek Sand: 7010' - 7038' DIL, 6975' - 7003' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12 spf, 41 /2" tubing-conveyed guns N/A N/A 27. PRODUCTION TEST Date First Production 21-Oct-98 Method of Operation (Flowing, gas lift, etc.) Flowing Date of Test 10/21/1998 Hours Tested 6 PRODUCTION FOR TEST PERIOD OIL-BBL 0 GAS-MCF 200 WATER-BBL 0 CHOKE SIZE 32164 GAS-OIL RATIO N/A Flow Tubing Press. 1320 Casing Pressure 0 CALCULATED 24HOUR RATE OIL-BBL 0 GAS-MCF 800 WATER-BBL 0 OIL GRAVITY-API (corr) N/A 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A i~ y~V ~ommi Form 10-407 Submit in Triplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE N:W rlg\wells\w12WOGCOMPL.XLW 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. Beluga 6392' -6420' 6381' - 6409' Final rater 800 MCFD, 0 BCPD, 0 BWPD, 1320 psig FTP, flowed for 6 hours Tyonek 7010' - 7038' 6975' - 7003' Final Rate: 2900 MCFD, 0 BCPD, 100 BWPD, 2700 psig FTP, flowed for 13.75 hours 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 Title ~~ ~, Date ~j~ V INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on ali 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\wells\w12W OGCOMPL.XLW MARATHON Wolf Lake Field Well #2 Marathon Oil Co., Alaska Region KB-GL: 35.0' 2265' FWL, 2621' FSL Sec. 29, T7N, R9W, S.M. 20", 133#, K-55 @ 66' (cut off @ 5') Cmt w/ 150 sks class "G" Otis SCSSV mandrel @ 98T x w/ X-profile (ID = 2.813") 13-3/8", BTC casing @ 4322' 0' - 1979', 72#, N-80 1979' - 3676', 68#, K-55 2676' - 4322', 72#, L-80 Cmt w/ 2445 sks class "G" Tubing: 3-1/2", 9,2#, N-80 joints 1 - 116 are AB-Mod. Butt. McMurray gas lift mandrel @ 5839' points 117 - 169 are regular Butt. (Dummy valve installed 10/25/98) points 170 - 229 are special clearance butt. ' \'C ~ ~~ Baker HS retrievable packer @ 5884 Note: Likely to have been onset during perforating on 10/26/98. x Baker CMU sliding sleeve @ 5929' w/ X-profile (ID = 2.813") Note: Slickline hung-up in sliding sleeve on Beluga Perforations 10/31/98 with 2.70" gauge ring, and probably 6392' - 6420' DIL (12 spf, 10/20/98) shifted sleeve into the open position. Steel blast joint 6385' - 6424' OD = 4.50" Baker FB-1 permanent packer @ 6891' TDT ~-~--{ X-nipple @ 6902' ID = 2.813" End of tubing @ 7006' Tyonek Perforations 7010' - 7038' DIL (12 spf, 10/25/98) /o ~ 36' of 4-5/8" TCP guns @ 8033' ~~ r~ plus 10' of 1-1/4" drop bar -- Baker "6AA" C1BP @ 8069' %~~ ~; ~ ` ~ -~, ~ Old 12 ppg mud cleaned out to 8200' ~ ~~~ ~ --=' ~ L Cement plug @ 11,385' '--__-~_,-_` ____ EZSV Retainer @ 11,485' / Top of 7" liner @ 11,834' 9-5/8", 5-95, BTC casing @ 12152' 0' - 174', 53.5# 174' - 11,126', 47# 11,126' - 12,152', 53.5# Cmt w/ 1000 sks of class "G" - ,- ~~ -_, ~ ~' ~ \,\ Cement plugs 13200' to TD `~ :. ^~~~ ~>>~ 7", 32#, 5-125, BTC liner 11,834' - 13,391' ~~ ~ ~ ~ -, J\ Cmt w/ 1000 sks class "G" Last Rev: JGE, 11/16/98 ____ TD = 14,451' ~~ • • Wolf Lake #2 6 Oct: Accept rig, weld on and test starting head. NU BOP's. 7 Oct: Finished N/U BOPE. Pertormed system pressure test. Repaired leaks. Test BOPE. 8 Oct: Tested BOPE 250 psi low and 5000 psi high test. Annular high test 3000 psi. Test plug wouldn't pass through annular. Changing out element. 9 Oct: Finished changing annular element. Finished BOP test. P/U BHA. Drlg cmt f/25' to 125' top of 9-5/8" csg. Lay down 8" DC and BHA. 10 Oct: RIH to 125'. Cleaned out 9-5/8" casing to 602'. POOH. RIH and washed over 9-5/8" casing to 195'. 11 Oct: POOH. Ran collar locator. RIH with casing backoff tool. Backed off casing at 174'. POOH. RIH w/spear. POOH w/casing. 12 Oct: Layed down casing. Ran 4 jts 9-5/8" csg. Screwed into backoff and test to 1000 psi. N/D BOPE and set slips. N/U tubing spool. 13 Oct: Finish N/U BOPE. Repaired accumulator. Tested BOPE. RIH P/U 3-1 /2" DP breaking circulation every 500'. 14 Oct: TIH to 6604' MD, circulating out thick mud as needed. 15 Oct: Wash/ream to 8205' and circulate. Install trip tank, TOH. 16 Oct: PU casing scraper, TIH. Swap out mud in hole and pits for 4% KCL. TOH. 17 Oct: TOH. Ran RST and USIT logs. Tested BOPE. 18 Oct: RIH w/e-line gauge ring; set down @ 7180'. Finish test BOPs. TIH w/mill, work thru tight casing, TOH. 19 Oct: Set CIBP at 8070'. Held safety mtg, ran TCP StimGuns and DST tools. Correlate gun depth with a-line. 20 Oct: Position guns and install test head and flowlines. Wait for equipment. Fire guns, attempt to flow well. 21 Oct: Conduct DST. Flow well for 6 hours at 800 MCFD, shut in for 12 hour buildup. 22 Oct: Finish pressure buildup. Catch gas samples, kill .well. TOH. Pump and bleed to release trapped gas. 23 Oct: Bleed off trapped gas. TIH, raise fluid weight from 8.6 to 8.9 ppg. TOH laying down drill pipe. t' Wolf Lake #2 (Continued) 24 Oct. Lay down drill pipe. Set packer on electric line. PU and TIH with 3-1/2" tubing. 25 Oct. Finish TIH with tubing. Set packer, land tubing. ND ROPE, NU and test tree. 26 Oct: Unable to displace. Pull gas lift valve, displace tubing with nitrogen. Drop bar to perforate. Attempt to set plug. 27 Oct: Slickline unable to get past 400'. Set a BPV in tree, bled down, release rig for demobilization. 31 Oct: Pull BPV. Open well to flow, but freezing problems hindering operation. Shut in to build pressure. 1 Nov: Flowing well. Shut in. RIH with gauge ring. Tag obstruction, POOH. Resume flow, shut in for buildup. r4 ~ SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA ARCO ALASKA. INC. NOLFLAKE A2 WILDCAT n~.nsr~n VERTICAL SECTION CALCULATED ALONG CLOSURE MEASURED DEPTH O r' 100 200 300 400 300 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2 ~"00 COMPUTATION DATE FEBRUARY 4. 1985 TRUE SU8-SEA COURSE VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEG MIN 0.00 -261.00 0 0 100.00 -161.00 O 47 199.98 -61.02 0 58 299.97 38.97 1 10 399.95 138.95 O 54 499.94 238.94 O 5b 599.92 338.92 U 55 699.90 438.90 1 17 799.86 538.86 1 49 899.80 638.80 2 13 999.73 738.73 2 7 1099.67 838.67 1 56 1 199.61 938.61 1 53 1299.56 1038.56 1 33 1399.53 1138.53 1 27 1499.50 1238.50 1 1 O 1599.48 1338.48 1 25 1699.45 1438.45 1 8 1799.43 1538.43 1 7 1899.42 1638.42 O 43 1999.41 1738.41 0 42 2099.41 1838.41 O 27 2199.40 1938.40 U 29 2299.40 2038.40 0 26 2399.40 2138.40 0 11 2499.40 2238.39 O 26 2599.39 2338.39 0 19 2h99.39 2438.39 U 18 2799.39 2538.39 0 34 ?_899.38 2638.38 0 43 Q ~ ~~~ PACE i DATE C)F SURVEY FEBRUARY 2. 1985 BOSS GYROSCOPIC SURVEY JOB NUMBER Ak:-E~0-50012 KELLY BUSHING ELEV. 261.00 FT. RATOR-~AMEC OPE ~ ~~~~~t,~~ COURSE DOG-LEG SEVERITY TOTAL RECTANGULAR COORDINATES VERTICAL DIRECTIO DEGREES N DEG/ 1 C-<- NORTH/SOUTF~ EAST/WEST SECTION N 0. 0 E O. 00 0.00 0.00 0. GO ~ N 19.14 W 0.79 u. 65 N 0.23 57 0 W W , 79 1 N 7.64 W 0.26 2.15 03 4 N N . U. 70 W N N 1. 5 75 14 W W 0. ~4 Ci.37 . 5.82 N 0.92 W q_ 37 N . 25.44 W 0.19 7.32 N 1.47 W 5.74 28 7 N 39.64 W 0.23 8.68 ~ N 2.34 i 53 W W . 9.16 N 36.35 W 0.37 10. L 1 N , 30 5 W 11.83 N 44. 5 W 0.58 12.27 81 14 N N . 7.77 W 15. 35 N 44.35 W O. 40 34 C- . 17.70 N 10.22 W 19.07 N N 35.85 75 44 W W . 0.36 20.40 N 12.50 W 22.54 N . 47.94 W 0.1 22.72 N 14.93 W 25. $9 8~~ 28 N 43.35 W 0.38 24.32 N 17.09 4 W W . 41 31 N 29.35 W 0.38 26.91 N 1$.6 60 19 W . 33.46 N 19.25 W U.37 28.98 15 31 N N . 20.26 W 3S • 3 3 N N 14.94 85 12 W W O• ~-8 0.29 . 33.33 N 20.80 W 37.12 N . 26.55 W c~.27 35.17 N 1.46 W 38.79 31 40 N 59.25 W 0.64 36.37 N 22.44 W W . 54 41 N 44.55 W 0.18 37.13 N 23.41 22 24 W . 42.54 N 68.64 W 0.35 37.72 25 38 N N . 24.79 W 43.32 N N 27.44 75 43 W W 0.34 0.14 . 38.90 N 25.25 W 44.09 N . 60.85 W O. 27 39.26 N 25. bb W 44.63 fi8 44 N 94 26 E U.47 39.68 N 25.63 W . N . 64 29 E 0.11 40.28 N 25.32 W 45.00 N . 55 42 E O.U6 4U.73 N 24.99 W 45.03 N . 55 31 E 0. 2a 41.36 N 24.54 W 4 N . 52.55 E 0..x'7 42.17 N 23.78 W 5.00 PAl3E 2 SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA C1ATE OF SURVEY FEBRUARY 2, 1985 ARCO ALASKA, INC. COMPUTATION DATE BOSS GYROSCOPIC SURVEY NQ~t_FLAKE /t2 FEBRUARY 4, 1985 JOB NUMBER AK-BO-50012 1all.pCAT KELLY GUSHING ELEV. 261.00 FT. /!~__g5K(n r]PERATOR--SAMEG VER1 A ~rnL SECT 1 C1-•1 CALCULATIFD A~_.ONG CLOSI_If~F TRUE SUB-SEA CO URSE COURSE DOQ'CEU SEVER I T Y RECTANGUL T C) T AR AL COORDINATE S VERTICAL ~Ac1.1r>~ A, 1fERT I CA1__ VERTICAL I NCL I N AT I ON . D IRECTION DEGREES C~EC~/ 1 ~~~' NOR 71-~~0-_i Tll EA`~T/4JFST ~Ft~' I I ON 1'll. A~F ~r~r r _f~ li DFFTII DEO I 1IN .. 3`00 2999.37 2738.37 1 6 N 44.64 E E 0. ^~ 1 0 17 43.:24 44.48 N N 22.60 21.29 W W 44.75 44.51 3100 3099.35 2838.35 0 57 N 48.85 E . 20 0 45.75 N 19.98 W 44.L9 3200 3199.33 2938.33 1 7 N N 43.25 14 SU E . C-.28 46.96 N 1£x.72 W 44.07 3300 3299.32 3038.32 0 52 N . 25 47 E 0. 3~? 48.15 N 17.37 W 43.77 3400 3399.30 3138.30 1 ? O N . 44 42 E 0. 1 `~~ 46.55 N 15.97 W 43,56 3500 3499.28 3238.28 1 5 N . 55 42 E 0. 3 3 50.74 N 14. S3 W 43.46 3600 3599.27 3338.27 0 45 N . 64 64 E . ; 5 3 3700 3699.2b 3438.26 U 49 N . 75 57 E i ~ 0. 52. G N 1:1.4 W 42. 5:C 3800 3799.25 3538.2S 0 57 N . $5 56 E O.0? 53.19 N ~U ig W 3900 3899.23 3638.23 O 57 N . 94 60 E 0- 21 . 41.50 4~J00 3999. 2.2 3738.22 0 45 N . 35 78 E O- ~`0 S4. 44 ~ ~=c, 41 W 40.74 4100 4099.21 3838.21 0 55 N . 85 84 . E 0.13 54. b7 N b. $'~ W 39.71 4200 4199.20 3938.20 0 5U N . 75 60 E 0"a3 55.20 N ~, 32 W :1$.82 4300 4299.18 4038.18 1 6 N . 35 74 E 0. -~`~ 55,94 N 3.53 W 37.89 4400 4399.16 4138.16 1 8 13 N . 44 6$ E ~~•1r ~ v N 4500 4600 4499.14 4599.12 4238.14 4338.12 1 1 20 N . 64.14 E 0.ib 7,5 47 58 1`1 0.46 E 35.77 9 1 'L1 N 67.14 E O. C-8 . q 4700 4699.09 443$.0 2:j N 64 47 E 0. 4 7 59.76 N , 61 E 33.96 4800 4799.07 4538.07 1 6 N . 85 42 E U.31 h1.29 N 6.17 E 33.71 4900 4899.04 4638.04 1 N . 5 46 E 0.21 62.79 N 7.65 E 33. 5U 5000 4999.02 4738.02 1 18 52 N . 75 43 E 0.44 64.13 N 9.00 E 33.29 5100 5099.00 4838.00 0 '~8 N . 64 30 E 0.23 65.41 N 9.95 E 3.~..~5 5200 5198.99 4937.99 0 N . 75 2'1 E C-. i b hh. 95 N 10.71 E ~4. ~1 5300 5298.97 5037.97 1 U N . 44 7 E 0.37 b8.37 N 11.11 E 5400 5398.96 5137.96 0 42 N . 25 b E C-. ~~4 69.87 N 1 1 .2'~ E • c 7 1U i6 5500 5498.95 5237.95 1 2 ' N . 14 4 W 0. 1'? 71.64 N 11.33 E . . Sb00 5598.93 5337.93 0 ~9 N . 85 17 W 0.:~G 73.53 N 10.93 E 37.69 5700 5498.91 5437.91 1 14 N . 94 44 W 2. 9! ~ 77.00 N 8.17 E ~2; ~-~ 5800 5798.80 5537.80 3 56 ! N . 55 57 W '3- `' ~ ~c3. 02_ N 0, 10 E ^.;~c~p ,ASR. ?8 5b37. 2$ 7 lO . PAGE 3 SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA DATE OF SURVEY FEBRUARY 2. 1985 ARCO ALASKA. INC. COMPUTATIaN DATE BOSS GYROSCOPIC SURVEY Wpl_FLAKE M2 FEBRUARY 4. 1985 JOB NUMBER AK-BO-50012 NILDCAT KELLY BUSHING ELEV. = 261.E>v FT. Ail A51'A OPERATOR-SAMEG VERTI~'/1L SECT~~-td CALCULATED ALONG GLOSl.1RE TRUE SUB-SEA CO URSE N COURSE N D DOG-LEu S TuT AL /' O~, S V HEASUItED VERTICAL VERTICAL INDEGN AMIN DEGREES DEOR100 NORTANSOU TH WEST T' EA SF_CTION DEPTH DEPTt-1 DEPTH 6000 5996.96 5735.96 10 49 N 56,75 W 3.15 91.75 41 102 N N 13.39 29.49 W W 68.06 87.28 6100 6095.08 5834.08 11 26 N 56.25 W 0.64 54 0 . 69 113 N 46.38 W 107.51 6200 6193.00 5932.00 11 `59 N N 56.25 94 54 W W . O. 2a . 125.39 N 63.46 W 128.15 6300 6290.83 6029.83 11 54 N . 25 54 W 0.31 1:37.48 N 80.47 W 148.98 6400 6388.62 6127.62 12 10 N . 14 57 W O. ~'4 149.62 N 98.30 W 170.48 6500 6486.27 6223.27 12 44 N . 44 63 W 3.12 161.56 N 119.49 W 194.47 6600 6583.25 6322.25 15 27 N . 85 67 W 2.28 173.15 N 145.23 W 221.7$ 6704 6679.16 6418.16 17 22 N . 55 66 W O.6S 184.89 N 173.15 W 250.87 6800 6774.46 6513.46 17 53 46 N . 85 66 W 0.14 197.00 N 201.28 W 280.37 6900 6669.66 6608.66 17 17 48 N . 44 66 W 0.13 209.12 N 229.34 W 309.$1 7000 6964.87 6703.87 7 58 N . 25 66 W 0.17 221.44 N 57.48 W 339.44 7100 7060.04 6799.04 1 N . 14 66 W 0.2~- :233.96 N 285.$6 W 369.38 7200 7155.11 6894.11 18 17 10 22 N . 85 64 W 0.88 246.61 N 313.64 W 398.95 7300 7250.33 6989.33 56 N , 14 66 W 0.43 258.85 N 340.48 W 427.52 7400 7345.87 7084.87 16 16 35 N . 94 bb W 0.42 270.33 N {66.94 W 455.32 7500 i 7441.62 7180.62 17 43 N . 66 55 W 1.15 281.913 N 394.05 W 483.72 7600 7537.17 7276.17 15 7371 18 43 N . 68.44 W 1.15 293.93 N 422.94 W '513.71 7700 7800 7632.15 7726.73 . 7465.73 19 11 N 67.55 W U. 5`S 306.10 N 453.06 W 544.79 90 576 7900 7820.95 7559.95 19 55 N 67.44 W 0.74 318.91 N 483.99 05 516 W W . 610.55 8000 7914.63 7633.bs 20 57 N 65.55 W 1.17 7'? 332.77 18 348 N N . 549.85 W 646.54 8100 8007.48 7746.48 22 40 N 65.14 W W 1. 91 1 . 365.12 N 586.17 W 685.43 8200 8099.08 7838.08 24 34 4 N N 64.85 94 63 W . 1 25 383.51 N 624.52 W 726.82 8300 8189.58 7928.58 25 26 ~ 11 N . 85 63 W . 0.42 402.78 N 663.86 W 7!9.53 8400 8279.47 8018.47 50 8108 25 25 N . 63.35 W 0.79 422.13 N 702.86 W 812.03 8500 8600 8369.50 8439.78 . 8198.78 25 30 N 62.85 W 0.23 441.59 N 741.20 W 854.0° 03 896 8700 8550.14 8289.14 25, 13 N 62.75 W 0.27 461.17 N N 779.31 53 816 W W . 937.27 8800 8644.87 8379.87 24 30 N 61.85 W 0.81 - 480.71 ~ 1~! . °9 852 W °77.71 P^nn 87.31.48 8470.98 24 1 O N 62.55 W U. 4 , 9.93 ~' . SPERRY-SUN WELL SURVEYING COMPANY PACE 4 ANCHORAGE ALASKA QATE OF SURVEY FEBRUARY 2, 1985 ARCO ALASKA. INC_ COMPUTATION DATE BOSS GYROSCOPIC SURVEY Npl_FLAKE N2 FEBRUARY 4. 1985 `SOB NUMBER AK-E+O-50012 NILDCAT KELLY HUSHING ELEV. 261.00 FT. Aw- n`-'~~~'~ OPERATOR-SAMEG VERTICAL SECTInn~ CALCULATED ALONG CLOSURE TRUE SU8-SEA COURSE N COURSE DIRECTION DOG-LEG SEVERITY TOT RECTANGULAR AL COORDINATES VERTICAL HEASURFD VERTICAL VERTICAL INCLIN DEO ATIO MIN DEGREES DEC/1C~~~ NORTH/SOU TFI EnST/WEST SECTION DEPlf1 hF_PTH DEPTH 9000 88?3.20 8562.20 24 11 N 62.64 W 0'04 7 16 $5 W 58 1U1~7 9100 8914.64 8653.64 23 34 N 61.64 W 0.74 76 0 53 ,69 06 557 N N . 959.$2 W . 1096. 7i 9200 9006.41 8745.41 23 13 N N 59.94 5 60 W W . ~?6 O . 576.67 N 993.78 W 1135.45 9300 9098.40 8837.40 22 22 57 30 N . 35 59 W . U.53 596.16 N 1027.14 W 1173.66 9400 9190.64 8929.64 22 1 N . 75 5$ W 0.53 615.64 N 1059.63 W 1211.17 9500 9283.18 9022.18 02 9115 21 36 N . 57.75 W 0.56 635.19 N 1091.22 W 1248.03 9600 9700 9376.02 19 9469 . 9208.19 21 O N 56.64 W 0.71 654.86 N 1121.76 W 1284.14 9800 . 9562. 'S7 9301.37 20 56 N 56.73 W 0.07 674.51 N N 1151.67 11 1181 W W 1319.76 1354.98 9900 9656.10 9395.10 20 29 N 55.94 W 0.53 54 0 694.10 41 713 N . 1209.78 W 13$9.41 10000 9749.94 9488.94 19 56 4 N N 56.14 5 55 W W . 40 0 . 732.61 N 1237.83 W 1423.30 10100 9843.98 9582.98 19 8 9 N . 75 53 W . U. 77 75?.02 N 1264.95 W 1456.59 10200 9938.25 9677.25 19 18 45 N . 75 52 W 0.52 771.45 N 1290.98 W 1489.05 10300 10032.80 9771.83 52 18 45 N . 53 35 W 0.1~ 790.77 N 1316.67 W 1621.17 10400 10500 10127.50 30 10222 9866. 9961.30 18 26 N . 53.44 W 0.31 809.78 N 1342.27 W 1553.03 . 10600 . 10317.30 10056.30 18 3 N 52.55 W 0.47 828.63 N 1367.28 W 1584.33 10700 10412.30 10151.30 18 17 N 51.85 W 0.31 847.75 N 1391.92 0 W W 1615.52 26 1646 10800 10507.40 10246.40 17 31 N 51.25 W 0.79 866.86 75 885 N N 1416.0 01 1439 W . 1676.03 10900 10602.90 10341.90 17 7 N N 49.94 75 47 W W C-.56 02 1 . 904.67 N . 1460.67 W 1704.77 11000 11100 10698_70 10794.90 10437.70 10533.90 16 15 19 19 N . 45.75 W . 1.14 92`.34 N 1480.54 W 1731.95 11200 10891.50 10630.50 14 28 N 45.85 W 0.85 941.26 N 1498.96 W 1757.54 11300 10988.60 10727.60 13 21 N 45.25 W 1.12 958.09 N 1516.13 12 W W 1781.48 1804 19 11400 11085.90 10824.90 13 4 N 43.44 W 0.5C- 974.44 N N 1532. 54 1547 W . 60 1826 11500 11183.30 10922.30 i3 5 N 42.44 W 0.23 30 0 991.01 48 1007 N . 1562.92 W . 1848.91 11600 11280.80 11019.80 12 56 7 N N 43:64 14 45 W W . 38 0 . 1023.59 N 1578.71 W 1871.32 11700 0 11378.20 60 11475 11117.20 60 11214 13 12 49 N . 45.14 W . 0.~=~0 1039.43 N 1594.63 W 1893.66 1180 i f 900 . 1 1573.10 . i 1312.10 12 59 N 45.25 W 0. 1 ~~ 1055.18 N l b 10.49 W 1915.88 PAGE 5 SPERF2Y-SUN WELL SURVEYING COMPANY ANCHGRAGE ALASKA DATE OF SURVEY FEBRUARY 2. 1985 ARCO ALASKA. INC. COMPUTATION DATE 80SS GYROSCOPIC SURVEY iIOLFLAKE NZ FEBRUARY 4. 1985 JOB NUMBER AK-BO-50012 WILDCAT KELLY BUSHING ELEV. 261.04 FT. AI__ASI<n OPERATOR-SAMEC VERTICAL SECTION CALCULATED ALONG CLOSURE TRUE SUBSEA CO URSE N COURSE AIRECTION DOG-LEG SEVERITY TOT RECTANGULAR AL GOURDINATES VERTICAL HEASURFD VERTICAL VERTICAL INCLIN DEG ATIO MIN DEGREES DEG/1i)~~ NORfl1/SOU TH FAST/WEST SE(:'TION IlEPT~~ DEPTH DEPTH 12000 11670.50 11409.50 13 15 N 47.94 W 6.67 1076.76 67 1086 N N 1626.98 1643.76 W W 1938.51 1961.55 12100 11767.80 11506,80 13 29 N 45.14 W W 0. 6v 08 1 . 1103.20 N 1659.36 W 1984.08 12200 11863.20 11604.20 12 48 N N 41.44 85 43 W . 0.68 1119.24 N 1674.12 W 2005.64 12300 11962.70 11701.70 12 22 47 N . 25 39 W 1.83 1134.21 N 1687.46 W 2025.42 12400 12060.70 11799.70 10 N . 25 33 W 1.41 1148.62 N 1698.09 W 2042.75 12500 12159.10 11898.10 9 52 . 5 W O ~2 1162.77 N 1707.50 W 2058.96 12600 12257.60 11996.60 9 41 N N 34. 44 35 W • 0.6h 1176.18 N 1716.80 W 2074.61 12700 12356.30 12095.30 9 4 N . 75 27 W 1.27 1189.23 N 1724.86 W 2089.09 12800 12435.10 12194.10 8 36 N . 25 24 W 0.53 1262.60 N 1731.38 W 2102.56 12900 12554.00 12293.00 8 30 N . 5 19 W 0.82 1216.07 N 1736.74 W 2115.19 13000 12652.90 12391.90 8 it N . 55 7 W 1.72 1230.20 N 1740.05 W 2126.64 13100 12751.90 12490.90 8 35 . 5 1 W 97 6 1245.11 N 1741.16 W 2136.88 13200 12850.70 12589.70 8 37 N N . 85 4 E . 1.C~G 1260.45 N 1740.64 W 2146.10 13300 12949.50 12688.50 9 3 N . 35 6 E 0.35 1276.32 N 1739.08 W 2154.87 13400 13048.30 12787.30 9 18 N . 45 0 E 0' 13500 13146.90 12885.90 9 0 ib 31 N . 8 55 W 9~ 1•.~. 1309.52 N 1739.41 W 2175.98 s 13600 13245.40 12984.40 1 15 N . 14 14 W 1.65 1327.19 N 1742.95 W 2189.84 13700 13343.80 13082.80 10 10 41 N . 85 21 W 1.46 1344.44 N 1748.58 W 2205.05 13800 13442.10 13181.10 10 35 N . 64 25 W 0.71 1361.33 N 1756.01 W 2221.45 13900 13540.40 13279.40 9 31 N . 44 16 W 1.92 1377.55 N 1762.33 W 2236.56 14000 13638.90 13377.90 8 59 N . 44 14 W 0.63 1393.06 N 1766.62 W 2249.64 14100 13737.60 13476.60 N . 5 15 W 0.54 1407.73 N 1770.48 W 2261.86 14200 13836.40 13575.40 8 27 N . 44 12 W 41 1 142C-.86 N 1773.72 W 2272.63 14300 13935.50 13674.50 7 5 N . 55 10 W . 0.99 1432.12 N 1776.03 W 2281.50 14400 14034.80 13773.80 6 7 8 N . 7'S 12 W 0.95 14 {4 , 74 N 1776.57 W 2283. S7 t ~-~! ~5 1 X1059. 70 13798.70 6 . FT~~RT7.4TVTA1_ DISF'LACI=MEPIT ~ 2283.57 FEET AT NORTH 51 DFG. ~? MIN. WEST AT MCi - 14425 TI/F CAl_CU'T_A"TION PROCEDURES ARE bASEG ON THE USE OF THREE DIMFNSTONAL RARIUS OF CURVATURE METHOD. SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA ARCO ALASKA. INC. 1~IOit_FLAKE !12 WILDCAT ALASKA PAGE 6 DATE OF SURVEY FEBRUARY 2, 1985 COMPUTATION GATE FEBRUARY 4, 1985 JOB NUMBER AK-BO-50012 KELLY BUSHING ELEV. 261.00 FT. ~~PERATOR-SAMEC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH MEASURED ~PT1-1 O 1000 2000 3000 4000 5000 6000 7000 6000 9000 10000 11000 12000 13000 14000 14425 TRUE SUB-SEA VE L TOTAL CO D I VER AL pEPTH NOFcTHNSOUTH EASTNWEST ERENC'E DIFF ON CORRECT PTN DE 0.00 -261.00 O.OU 0.00 2 W 0.00 27 0 0.27 999.73 738.73 17.70 N 10.2 41 23 W . 0.59 ~~'32 1999.41 1738.41 37.13 24 43 N N . 22.60 W 0.63 C-.04 2999.37 3999.22 2738.37 3738.22 . 53.96 N 9.76 W 0.78 0.15 4999.02 4738.02 62.79 N 7.65 E 0.98 04 3 2,05 5996.96 5735.96 91.75 N 13.39 W W . 12 35 i2.Oy 6964.87 6703.87 209.12 N 229.34 05 516 W . 85.35 SC-.23 7914.65 7653.65 20 8562 332.77 518.79 N N . 889.36 W 176.80 91.45 8823.20 9749.94 . 9488.94 713.41 N 1209.78 W 250.06 7~i.26 27 51 10698.70 10437.70 904.67 N 1460.67 W W 101.33 51 329 . 28.18 11670.50 11409.50 1070.76 7 N N 1626.98 74 1736 W . 347.07 17.57 12652.90 90 13638 12391.90 13377.90 1216.0 1377.55 N . 1762.33 W 361.12 14.05 . 14059.70 13798.70 1434.74 N 1776.57 W 365.32 4.2U THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS ~~F CURVATURE METHOD. Ai2C0 ALASKA+ INC. NOIFL.AKE M2 WILDCAT ALASKA SURED TH • O 261 361 461 361 661 761 861 961 1061 1161 1261 1361 1461 1561 1661 1761 1861 1961 SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE FEBRUARY 4, 1985 PAGE 7 DATE OF SURVEY FEBRUARY 2, 1985 JOB NUMBER AK-BO-50012 261.00 FT. KELLY BUSHING ELEV. OPERATOR-SAMEC INTERPOLATED VALUES FOR EVEN 100 FEET OF SU6-SEA DEPTH TRUE VERTICAL SU8-SEA L VE TOTAL / CO / _ DIFFERENCE CORRECTION DEPTH DEPTH SOUTH NORTH WEST EAST 0.00 -261.00 0.00 0.00 W 0.00 0 03 0.03 261.00 0.00 3.22 22 5 N N 0.68 0.76 W . O.OS 0.02 361.00 100.00 . 74 6 N 1.20 W ~ U7 461.00 200.00 . 20 8 N 1.94 W _ 0.01 361.00 300.00 00 400 . 9.51 N 3.01 W 0.09 0,01 661.00 00 761 . 500.00 11.37 N 4.44 W 0.12 0.03 05 0 . 861.00 600.00 13.73 N 6.72 9 3$ W W 0.17 0.24 . 0,07 961.00 700.00 1 b. 53 47 19 N N . 11.57 W 0 - ,~ 1 0.07 1061.00 00 1161 500.00 900.00 . 21.86 N 13.98 W 0.37 O,U6 0 05 . 1261.00 1000.00 24.06 N 16.37 16 18 W W 0.42 0.46 . 0.04 1361.00 1100.00 26.05 4 N N . 34 29 W 0.49 0.03 1461.00 1200.00 28.2 23 30 N . 20.01 W ? ~ 1561.00 00 1661 1300.00 1400.00 . 32.58 N 20.63 W 0.54 - O . 1761.00 1300.00 34.50 N 21.12 W 0.56 5£~ 0 0'02 t-.u2 1861.00 1600.00 36.12 N 22.02 W W . 59 O O. O1 1961.00 1700.00 36.79 N 23.0$ . ARCO ALASKA. INC. HOL.FLAKE M2 NILDCAT ALASKA MEASURED ~PTH • 2061 2161 2261 2361 2461 2561 2661 2761 2861 2961 3061 3161 3261 3361 3461 3561 3661 3761 3861 SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE FEBRUARY 4 , 19135 PAGE 8 DATE OF SURVEY FEBRUARY 2. 1985 JOB NUMBER AK-EEO-50012 261.00 FT. KELLY BUSHING ELEV. OPERATOR~-SAMEG INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA VERTICAL TGTAL RECTANGULAR COORDINATES MD-TVD VERTICAL VERTICAL DEPTH NORTH/SOUTH - EAST/WEST DIFFERENCE CORRECTION DEPTH 2061.00 1800.00 37.61 N 23.93 W 0.59 bU O 0.01 O.OU 2161.00 1900.00 37.95 N N 24.64 05 25 W W . 0.60 0.00 2261.00 2000.00 00 2100 38.69 39.20 N . 25.55 W O.bU 0.00 2361.00 2461.00 . 2200.00 39.42 N 25.77 W 0.60 0.00 00 U 2561.00 2300.00 40.08 N 25.43 W W 0.61 0 61 . 2661.00 2400.00 40.57 N 25.13 . 61 0 U.00 2761.00 2500.00 41.02 N 24.75 W W . 62 0 0.01 2861.00 2600.00 41.88 71 42 N N 24.16 23.12 W . 0.62 0.01 2961.00 3061.00 2700.00 2800.00 . 44.06 N 21.77 W 0.64 0.01 01 0 3161.00 2900.00 45.20 N 20.50 W 0.66 68 0 . 0.02 3261.00 3000.00 46.58 N 19.17 W . 69 0 0.01 3361.00 3100.00 47.62 N 17.95 47 16 W W . 0.71 0.02 3461.00 3200.00 49.01 37 50 N N . 15.23 W 0.73 0.02 3561.00 00 3661 3300.00 3400.00 . 51.30 N 14.28 W 0.74 0.01 . 3761.00 3500.00 51.96 N 12.96 W 0.75 0.01 01 0 3861.00 3600.00 52.84 N 11.56 W 0.76 . PAGE 9 SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA DATE OF SURVEY FEBRUARY 2. 1985 -_- Ai2C0 ALASKA. FLAKE M2 NOI INC. COMPUTATION DATE 1985 JOB NUMBER AK-BO-50012 ,. MILDCAT FEBRUA RY 4. KEL LY BUSHING ELEV. ~ 261.00 FT. ALASKA OPERATOR-SAMEC INTERPOLATED VALUES FOR EVEN 100 FEET vF SUB-SEA DEPTH TRUE SUB-SEA VE L TOTAL I CO _ F A8URED VERTICAL DEPTH NORTH/SOUTH WEST EAST/ ERENCE DIF CORRECTION ~TM DEPTH 3961 3961.00 3700.00 53.72 N 10.20 01 ~ 9 W W o. 77 0.78 0. vi 0.01 4061 4061.00 3600.00 54.32 N 62 N 54 . 7.45 W 0.80 0.01 4161 4261 4161.00 4261.00 3900.00 4000.00 . 54.85 N 5.96 W 0.81 0.01 02 0 4361 4361.00 4100.00 55.74 N 4.26 3 W W 0.83 95 0 . 4461 4461.00 4204.00 56.30 N 2.3 34 0 W . 0.87 0.02 4561 4561.00 4300.00 57.11 N . 78 1 E 0'89 4661 4661.00 4400.00 58.12 N 3 N . 92 3 E 0.92 U_v3 4761 4761.00 4500.00 59.1 75 N 60 . 5.67 E 0'95 4861 4861.00 4600.00 . 19 N 62 7.02 E 0.97 0.02 4961 4961.00 00 5061 4700.00 4800.00 . 63.72 N 8.60 E 1.00 0.03 SObi 5162 . 5161.00 4900.00 64.86 N 9.63 E 1.01 02 1 0.01 0.01 3262 3261.00 5000.00. 66.33 N 91 N 67 10.46 11.05 E E . 1.04 0.02 3362 S4b2 5361.00 00 5461 5100.00 5200.00 . 69.19 N 11.21 E 1.04 0.01 3362 . 5561.00 5300.00 70.98 N 11.37 18 E E 1.06 08 1 v. 002 5662 5661.00 5400.00 72.75 N 36 N 75 11. 70 9 E . 1.13 O. OS 5762 5761.00 5500.00 . . ARCO ALASKA. INC. N~01..FLAKE M2 WILDCAT ALASKA 1"~ASURED ~PTH • 5862 3963 6065 6167 6269 6371 6474 6376 6680 6785 6890 6995 7101 7206 7311 7415 7520 7625 7730 SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE FEBRUARY 4. 1985 PAGE I0 DATE OF SURVEY FEBRUARY 2. 1965 JOB NUMBER AK-PO-50012 KELLY BUSHING ELEV. 261.00 FT. OPERATOR-SAMEC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE VERTICAL SUB-SEA VERTICAL TOTAL RECTANGULAR C OORDINATES MD-TVD VERTICAL DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 5861.00 5600.00 80.49 N :#. 8b E 1.45 45 2 0.32 1.01 5961.00 5700.00 8$.20 57 98 N N 7.96 23.75 W W . 4.23 1.77 6061.00 6161.00 5@00.00 5900.00 . 109.92 N 40.73 W 6.29 2.06 6261.00 6000.00 121.78 N 58.31 W 8.52 2.23 22 2 00 6361 6100.00 133.99 N 75.63 W 10.73 . . 6461.00 6200.00 146.52 N 93.50 W 13.09 2.36 6561.00 6300.00 158.82 N 114.14 W 15.95 2.86 6661.00 6400.00 171.01 N 139.97 W 19.96 4.02 6761.00 6500.00 183.16 N 169.16 W 24.85 4.89 6861.00 6600.00 195.91 N 198.73 W 29.91 5.05 6961.00 6700.00 208.62 N 228.20 W 34.93 5.02 7061.00 6800.00 221.57 N 257.76 W 4u.01 5.08 00 7161 6900.00 234.74 N 287.63 W 45.20 5.19 . 7261.00 7000.00 248.03 N 316.66 W 50.18 4.98 7361.00 7100.00 260.71 N 344.69 W 54.81 4.62 7461.00 7200.00 272.59 N 372.25 W 59.21 4.41 7561.00 7300.00 285.01 N 401.04 W 64.02 4.80 7661.00 7400.00 297.52 N 432.04 W 69.46 5.45 ARCO ALASKA INC. MQLFLAKE N2 NILDCAT ALASKA ASIXiED ~PTH • 7836 7942 8049 8158 8268 8379 8490 8601 8712 8822 8931 9041 9150 9259 9367 9476 9583 9691 9798 SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA ---- COMPUTATION DATE FEBRUARY 4~ 1985 PAGE 11 DATE OF SURVEY FEBRUARY 2. 1985 JOB NUMBER AK-BO-50012 261.00 FT. KELLY BUSHING ELEV. OPERATOR-SAMEC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE VERTICAL SUB-SEA VERTICAL TOTAL RECTANGULAR COORDINATES T MD-TVD DIFFERENCE VERTICAL CORRECTION DEPTH DEPTH NORTH/SOUTH EAST/WES 7761.00 7500.00 310.66 N 464.08 W 75.29 61 81 5.82 7861.00 7600.00 324.30 12 340 N N 497.41 532.38 W W . 88.70 7.09 7961.00 8061.00 7700.00 7800.00 . 357.73 N 570.43 W 97.14 8.44 13 10 8161.00 7900.00 377.45 N 612.13 W W 107.27 41 118 . 11.15 8261.00 8000.00 39$.77 32 420 N N 655.71 699.25 W . 129.54 11.18 8361.00 8461.00 8100.00 8200.00 . 441.85 N 741.72 W 140.35 10.76 65 10 8561.00 8300.00 463.51 N 783.85 2 W W 151.00 12 161 . 10.12 8661.00 8400.00 485.04 N N 824.6 56 864 W . 170.81 9.69 8761.00 00 8861 8500.00 8600.00 505.94 526.59 N . 904.44 W 180.44 9.62 . 8961.00 8700.00 547.33 N 942.90 W 189.57 9.13 8 $1 9061.00 8800.00 568.76 N 980.05 W W 198.38 93 206 • 8.55 9161.00 8900.00 589.90 98 610 N N 1016.58 1051.96 W . 215.07 8.15 9261.00 00 9361 9000.00 9100.00 . 632.01 N 1086.19 W 222.84 7.77 . 9461.00 9200.00 653.13 N 1119.13 W 230.23 32 237 7.3y 7.10 9561.00 9300.00 674.18 N 1151.17 W . ARCO ALASKA. {+OI..FLAKE r2 MI I,DCAT ALASKA PAGE 12 SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA DATE OF SURVEY FEBRUARY 2. 1985 INC. COMPUTATION DATE _ _ FEBRU ~ KELLY BUSHING ELEV. ~ 261.00 FT. OPERATOR-SAMEC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH SIJRED ~PTH 9905 !0011. 10118 10224 10329 10433 10540 10646 10731 10856 10960 11064 11168 11271 11374 11477 11579 11682 11784 TRUE VERTICAL DEPTN 9bb 1.00 9761.00 9861.00 9961.00 10061.00 10161.00 10261.00 10361.00 10461.00 10561.00 10661.00 10761.00 10861.00 10961.00 11061.00 11161.00 11261.00 11361.00 11461.00 SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES DEPTH NORTH/SOUTH EAST/WEST 9400.00 9300.00 9600.00 9700.00 9800.00 9900.00 10000.04 10100.00 10200.00 10300.00 10400.00 10500.00 10600.00 10700.00 10800.00 10900.00 11000.00 11100.00 11200.00 695.13 N 715.64 N 736.12 N 756.69 N 777.24 N 797.56 N 817.47 N 837.32 N 857. bb N 877.45 N 897.25 N 916.86 N 935.77 N 953.48 N 970.24 N 987.18 N 1004.19 N i 020.77 N 1037.08 N 1182.63 W 1213.12 W 1242.86 W 1271.32 W 1298.59 W 1325.78 W 1352.63 W 1378.60 W 1404.51 W 1429.11 W 1452.51 W 1473.89 W 1493.31 W 1511.48 W 1528.14 W 1544.04 W 1559.78 W 1575.87 W 1592.27 W MD-TVD DIFFERENCE 244.23 250.77 257.09 263.08 268.75 274.35 279.79 285.00 290.29 295.15 299.75 303.87 307.48 310.66 313.41 316.07 318.72 321.36 324.00 VERTICAL CORRECTION 6.91 6.54 6.32 5.99 5.66 5.61 5.44 5.21 5.28 4.86 4.60 4.12 3. bl 3.17 2.75 2.66 2.65 2.63 2.64 SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA Amp ALA~(A, INC. - COMPUTATION DATE {~pI-FL-aCE *Z FEBRUARY 4 ~ 1985 NILOCAT ALASKA PAGE 13 DATE OF SURVEY FEBRUARY 2. 1985 JOB NUMBER AK-BO-50012 261.00 FT. KELLY BUSHING ELEV. OPERATOR-SAMEC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL RECTANGULAR C OORDINATES MD-TVD VERTICAL VERTICAL VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION TFi DEPTH DEPTH 11687 11361.00 11300.00 1053.21 N 1608.50 32 1625 W W 326.58 329.25 2.59 2.67 11990 11861.00 !1400.00 2069.27 52 1085 N N . 1642.60 W 332.03 2.78 12093 11761.00 11500.00 00 11600 . 1102.49 N 1658.74 W 334.74 2.71 12193 12296 11861.00 11961.00 . 11700.00 1118.96 N 1673.86 W 337.21 30 339 2.47 2.09 12400 12061.00 11800.00 1134.25 N N 1687.50 27 1698 W W . 340.95 1.65 12301 12161.00 11900.00 1148.90 25 1163 N . 1707.83 W 342.42 1.47 12603 12261.00 12000.00 00 12100 . 1176.79 N 1717.23 W 343.77 1.35 12704 12805 12361.00 12461.00 . 12200.00 1190.02 N 1725.27 W 344.97 09 346 1.20 1.12 12907 12561.00 12300:00 1203.55 N 1731.81 12 1737 W W . 347.16 1.06 13008 12661.00 12400.00 1217.17 57 1231 N N . 1740.23 W 348.25 1.09 13109 12761.00 12500.00 00 12600 . 1246.67 N 1741.19 W 349.39 13210 13311 12861.00 12961.00 . 12700.00 1262.27 N 1740.48 W 350.61 91 351 1.21 . 13412 13061.00 12800.00 1278.40 N N 1738.85 10 1738 W W . 1.33 13314 13161.00 12900.00 1294.72 38 1312 N . 1739.84 W X54_92 1.57 13613 13717 13261.00 13361.00 13000.00 13100.00 . 1330.21 N 1743.71 W 356.47 1.66 SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA ARW ALASKA. INC. ~/p1.,FLAKE 112 III LDCAT ALASKA COMPUTATION DATE FEBRUARY 4. 1985 PAGE 14 DATE OF SURVEY FEBRUARY 2+ 1985 JOB NUMBER AK-BO-50012 KELLY BUSHING ELEV. 261.00 FT. OPERATOR-SAMEC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH gSURED TRUE VERTICAL SUB-SEA VERTICAL TOTAL RECTANGULAR C OORDINATES MD-TVD DIFFERENCE VERTICAL CORRECTION ~PTH DEPTH DEPTH NORTH/SOUTH EAST/WEST 13819 13461.00 13200.00 1347.74 N 1749.90 W W 358.19 93 389 1.72 1.74 13920 13561.00 13300.00 - 1364.80 N N 1757.67 38 W 1763 . 361.43 2 0 1 14022 13661.00 13400.00 1381.11 65 N 1396 . 1767.55 W 362.72 . 5 + 14123 14224 13761.00 13861.00 13500.00 13600.00 . 1411.26 N 1771.43 W %~5 U 14325 13961.00 13700.00 1423.96 N 1774.41 W 57 W 1776 364.71 365.32 . 0.62 14425 14059.70 13796.70 1434.74 N . THE CAL CULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE BAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS f r M Marathon MARATHON Oil Company November 4, 1998 Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 The following logs are enclosed: Tape Description Wolf Lake 1) Wolf Lake #2 Packer Setting Record Oct. 22, 1998 ~~ ~~ ~w~~ Please sign and return confirming you have received these documents. MARATHON OIL COMPANY Kirsten K. Gamel Enclosures Prii t~ Received ~ ~ ~ ~~ Date: { Alask Domestic ~-roduction P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 LETTER OF TRANSMITTAL .~~~ ~~ ~bG`J '..~ ~~ ~3 ~iaW~a C°ia ~ ~~n~rs~.~bns. ~w:c~~?I?~~i~r? A subsidiary of USX Corporation Environmentally aware for thtyfbi~f~. SENT BY~Marathon Oil Compatty ;I1- 3-98 ;lO~OIAM ; Anchora e~ 907 276 ?542;# 1/ 2 Alaska Re~on Domestic roduction a Marathon P.O. fox 186168 ruiun~oM Oil Company Anchorage, AK 99519-6168 Telephone 907/561-5311 FAX COVER LETTER l7ATE: / l _ 03 PLEASE DENVER THE FOLLOWING TO: Name: Company: /9-Q ~ J Fax No.: a ~- Number of Pages {l~cfuding co-re~rpege): FROM: Name: i.ocation/Extension: ,~f~ ~ ._~ Fax Nv.: 907/564-6489 NOTE: ~ ' ~` ~, ii ~ ~~ s; ~, 8 Wqg. !f tlansmissiian Is not complete, please cell 907/561y311. A subsidiary of USX Corporation Environmentally aware for the lung run. SE7V'I' BY=Marathon Oil Company ;11- 3-98 ;10~02AM ; • Marathon Mu~o. Oil Company November 3, 1998 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Wondzell: Anchors e~ Alaska Reg pomestic Production 907 276 7542;# 2/ 2 P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Marathon has consistently demonstrated the highest standards for personnel safety and environmental protection and we are genuinely concerned with the Inspection report on the Cook Inlet Drilling equipment whiff was under contract to us for our Wolf Lake operations. Be assured we will address these items with Cook Inlet Drilling, and encourage you to do so likewise. Each organization should be held responsible and accountable for their equipment and personnel. ff and when Marathon has the need to utilize the services of Cook Inlet Drilling, a through review of their equipment will be required. In addition, we welcome your, or your representatives', participation in this review andlor system testing. There has been a long, and positive, relationship between AOGCC and Marathon. It is a relationship based on respect and performance. We will do everything in our control to ensure our operations continue tv maintain the standards which you are accustom and expect from us. Please do not hesitate to contact either myself or P. K. Bergs if you have any concerns or comments relative to our operations. Sincerely, W. C. Barron Operations Superintendent Ims M:NNP10PN8~18B113.WPD . ,~ ~~ ~ ~®~ ~ ~ 9.~9~~ ;` A subsidiary of USX Corporation Environmentally aware for the long run. - 198 142-0 W OLI• I..Ati l", MD 13391 TVD 13039 .~.. iJJ-rv.~/J-iv ~•+ . ...:~inV1V V1L l,V . ___ _- Completion Date: 11/1/98 Completed Status: i- l ~S Current: Microfilm Roll / Rc / - - - - -_.- _ _ S ud 10/5/98 P __ 3leva tion: BK 0028 Name Interval Run Sent Received T/C/D L PACKER SETT RCD l BL 7230-8212 _ __ __ CH 5 11!4/98 11/6/98 L PLUG STT RCD 3 BL 7940-8150 CH 5 L RST 1 10/22/98 10!26/98 5400-8212 CH 5 10/21/98 10/22/98 L 1'CP CORRELATION 4 BL 5700-6050 CH 5 10/22/98 10/26/98 L US[T 2 BL(C) 35-8205 CH ~~ 5 10/21/98 10/22/98 R BOSS GYRO SRVY SPERRY 0-14425 . OH 11/16/98 1 ]/19/98 Alaskon Domestic Production M Marathon ~~r~op Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 October 22, 1998 LETTER OF TRANSMITTAL Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 The following logs are enclosed: / Tape Description ~ 17~ ~ ~~`~ ~'e c.E-v c ( Prints Wolf Lake ~' ~ ~ Z, 2) Wolf Lake #2 Plug Setting Record 1 October 18, 1998 3) Wolf Lake #2 TCP Correlation Record 1 October 19, 1998 K«~-~~ ~ec.~ SL's ~..Q ~~~~ ~. ne~Q s , ~~, ~~~ ~ ~~ ~g9~ 1 ~om'~~~10'' L,o-~r', ~ AI2-~"-~'Oil l~ rage 2/~f l9~ Please sign and return confirming you have received these documents MARATHON OIL COMPANY Kirsten K. Gamel Enclosures Received Date: A subsidiary of USX Corporation Environmentally aware for the long run. M Marathon AuRAT110R Oil Company October 21, 1998 Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 The following logs are enclosed: Taoe Descri tion Alaska r. Domestic roduction P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 LETTER OF TRANSMITTAL Kenai Gas Field ~~ . OS ! 1) Kenai Gas Field KU 43-6A Tubing Puncher 2 3/8 4.7 # Tubing September 11, 1998 Wolf Lake 2) Wolf Lake #2 Ultrasonic Imager Cement Mode C(~ • ~ `~12 ctober 16, 1998 3) Wolf Lake #2 RST- Sigma Mode October 16, 1998 s~.~ ~~ o~ ~~s~. ~ o S -~-~ 1 ~~ Please sign and return confirming you have received these documents. MARATHON OIL COMPANY Kirsten K. Gamel Enclosures Rece1 Date: A subsidiary of USX Corporation Prints 1 1 1 OCT 22 1998 Oii ~ ~~ ~s• CommisslQtt Environmen y aware f~~ run. ~ y~~ i ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission '~ TO: David Johns DATE: October 12, 1998 ~ Chairman ~~ , THRU: Blair Wondzell, ~` ~ FILE NO: A99JJGFE.DOC ~~ P. I. Supervisor ~..,~+ FROM: Lou Grimaldi, v~ SUBJECT: BOPE Test CC-1 Petroleum Ins~ctor Marathon Wolf Lake #2 y ~~ ns Swanson River ` ~ salad a~ li'~~~ `, ~ G o~Q~ - ~~~ PTD #98-0142 ~ ~-~~ Tuesday, October 6, 1998: I witnessed the initial BOPE test on CC-1 which n~ ~ , ,~~ was preparing to work over Marathon well #Wolf Lake #2 in the Swanson ~L ~ {,` ~ River Field. The rig was ready to test when I arrived and we began immediately. The rig had numerous failures and the test spanned three days and a total of twenty- four hours. Failures included both upstream valves on the choke manifold hydraulic choke leg, the hydraulic choke itself, a flange leak downstream of the hyd. Choke, the hydraulic choke panel had numerous problems and was unreliable for sensing choke position and pressure, the lower Kelly valve failed to hold any pressure and ended up having to be replaced. The most alarming failure was the Koomey unit that on initial observance had its regulators set incorrectly. I decided to bleed the system down and start from scratch and test all of its components. I found that the gauges that shows the accumulator bottle pressures had been adjusted to read a passing pressure when this was not the case, approximately 1100-psi high. The Annular preventer gauge had also received this treatment and read 500-600 psi low. The Accumulator bottles precharge were checked which showed three bottles completely failed and three others whose filler nozzles leaking N2. I advised changing the bad bladders, cleaning the nozzles on the leaking bottles, and calibrating the panel gauges. I returned the following day after I was informed that the Koomey had been repaired. I had them bleed the Koomey down again and found more bad bottles and the gauges still had not been reset. I asked if the bladders had been changed and was informed that only one had been changed. We shut down again for more Koomey repairs. This time I observed repairs and gauge calibrations. The Koomey passed its subsequent retest. A99JJGFE.DOC page 1 of 2 a 1 A99JJGFE.DOC page 2 of 2 The location was half covered with water due to all the rains we have been experiencing lately. The layout of equipment was good and was the best part of the whole experience. The BOP stack was tested with no failures observed. This would be a favorable note for the rig except it was a rented DSR stack. The H2S and Methane detectors were not functional during the initial test but were hooked up and operational by the conclusion on the last day of the test. This was a very poor showing even for this rig, I feel that at sometime in the past the accumulator gauges had been adjusted to read what we would need to see in order to pass the test. This rig should be watched closely for this type of problem. A complete overhaul would definitely help. SUMMARY: I witnessed the initial test of the BOPE on CC-1 working over Marathon well # Wolf Lake #2 in the Swanson River Field. There were Nine major failures observed. Test time 24 hours. Attachments: A99JJGFE.XLS CC: Pete Berga (Marathon drilling supervisor) NON-CONFIDENTIAL A99JJGFE STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: DATE: 10/6/98 Drlg Contractor: Inlet Drilling Rig No. CC#1 PTD # 98-142 Rig Ph.# 2 -0421 Operator: Marthon Rep.: Scott Asay Well Name: Wol Lake #2 Rig Rep.: George Brewster Casing Size: Set Location: Sec. 29 7N R. 9W eWal' Test: Initial X Weekly Ot i~ TEST DATA Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: QUan. Pressure P/F Location Gen.: P Well Sign P Upper Kelly / IBOP 1 250/5,000 P Housekeeping: P (Gen) Drl. Rig P Lower Kelly / IBOP 1 PTD On Location P Hazard Sec. ~ Ball Type 1 P Standing Order Posted P Inside BOP 1 P BOP STACK: Quan. Test Press. P/F Test Annular Preventer 1 250/2500 P CHOKE MANIFOLD: Pressure P/F Pipe Rams 1 250/ ,000 P No. Valves 11 250/5,000 F Lower Pipe Rams 1 P No. Flanges 32 F Blind Rams 1 P Manual Chokes 1 unctioned Choke Ln. Valves 1 P Hydraulic Chokes 1 HCR Valves 1 P Kill Line Valves 2 P ACCUMULATOR SYSTEM: Check Valve N/A / System Pressure 3,000 P Pressure After Closure 1,550 MUD SYSTEM: Visual Alarm 200 psi Attained After Closure min S 43 SeC. Trip Tank P P System Pressure Attained 2 min'S~6 SeC. Pit Level Indicators P P Blind Switch Covers: M2Stel': P Remo~P Flow Indicator P P Nitgn. Btl's: Four bottles @ 2500 Meth Gas Detector F F H2S Gas Detector ~- F TEST RESULTS umber o Fai ures: 9 ,Test Time: 24 Hours. Um er 0 Va V2S eS a 23 Repair or replacement o Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOCCC Commission Office a : a~- 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: still not been Poor test. Accumulator failed Distribution: orig-Well File YES X NO c - Oper./Rig c -Database 24 HOUR NOTICE GIVEN c -Trip Rpt File YES X NO c -Inspector Waived By: Witnessed By: LOU Grimaldi Page 1 ALASSA OIL A1~TD GAS COI~TSERQATIOI~T COAIlrIISSIOIQ September 2, 1998 TONY KNOWi.ES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 W. C. Barron Operations Superintendent Marathon Oil Company F O Box 196168 Anchorage, AK 99519-6168 Re: Wolf Lake #2 Marathon Oil Company Permit No: 98-142 Sur. Loc. 1183'FSL, 2265'FWL, Sec. 29, T7N, R9W, SM Btmhole Loc. 2621'FSL, 488'FWL, Sec. 29, T7N, R9W, SM Dear Mr.Barron: Enclosed is the approved application for permit to re-enter the above referenced well. The permit to re-enter does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling. below the surface casing shoe. must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission at 279-1433. David W. Johnston BY ORDER OF dlf/Enclosures COMMISSION cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ;, SEMf SY~Marathon Oi[ Company 8-26-98 2~04PM ; Anchorage-~ 907 276 7542;# 1/ 4 Alaska Region Domestic Production Marathon P.O. Box 196168 s.~unw~ qil Company Anchorage, AK 99519-6168 7eiephone 9071561-5311 Fa-x cov~R ~rr~R DATE: ~"`'' Z G - ? ~ PLEASE DELIVER THE FOLLOWING TO: FROM: Name: ~-{~C ,c. r I.OCatEOn/Exteinslon: ~~ ~- ~ j Fax No.: 907/564-6489 NOTE:~~... ~ .~ ( t err .~ ~ 2 ~ ~~9~ ,~~ K bensmission is not complete, please call ~07/s67-5377. A subsidiary of USX Corporation Environmentally aware for the long run. ,: • M Marathon MARATHON Oil Company July 22, 1998 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99513-7599 Reference: Application for Permit to Drill Dear Mr. Wondzell: ~~~ Enclosed is the referenced document you requested for the Wolf Lake # 2 well. On April 30, 1998, an Application for Sundry Approvals was submitted for the reentry of this well and you informed us that a Permit to Drill was required because the well had been permanently abandoned. Please advise if additional information is required. Sincerely, ~---~ '~~~C W. C. Barron Operations Superintendent e~ a 25" ,5'6k - 6 3 2S Enclosures Alaska Domesti oduction P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 ~~,_ ~ 199 Ayssska Oii & Gas Cons. Commission Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. g:\cmn\drlglsterting\su32-9\AOGCCPTD.XLW STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COM~ION PERMIT TO DRILL 210 AAC 25.005 1a. Type of Work Drill Re-Drill Re-Entry® Deepen 1b. Type of well. Exploratory^X Stratigraphic Test Development Oil Service Development Gas Single Zone Multiple Zone® 2. Name of Operator MARATHON OIL COMPANY 5. Datum Elevation (DF or KB) (Pad) 230' (est) feet ~0. Field and Pool 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 s. Property Designation 84201 - ~T~ 4. Location of Well at Surtace 1183'FSL, 2265'FWL, Sec. 29, T7N, R9W, S.M. 7. Unit or Property Name Wvtf take 11. Type Bond (see 20 AAC 25.025) Blanket Surety At top of Productive Interval 1285'FSL, 2236'FWL, Sec. 29, T7N, R9W, S.M. 8. Well Number # 2 Number 5194234 At Total Depth 2621'FSL, 488'FWL, Sec.29, T7N, R9W, S.M. 9. Approximate Spud Date 9/1/1998 Amount $200000 12. Distance to Nearest Property Line(top of pay) 1285 feet 13. Distance to Nearest Well 500 feet 14. Number of Acres in Property 640 15. Proposed Depth (MD and ND) 8000' MD, 7915' TVD feet t5. To be Completed for Deviated Wells IGckoff Depth 5700 feet Maximum Hole Angle 26 ° 17. Anticipated Pressure (sae 20 nnc 25.o3s (e) (2)) Maximum Surface 2500 prig at Total Oepth (rVD) 7915' 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 26" 20" 133# 66 0 0 66 66 In place 171!2" 133/8" 68872# 4332 0 0 4332 4332 In place 121/4" 95/8" 47853.5# 12152 0 0 12152 11818 In place 81/2" 7" 32# 1557 11834 11558 13391 13039 In place ~~~~~~~~ SSk~a ail & Gas Cons. CommisslOrt o ~ ~ ` AJ Anchorage 20. Attachments Filing Fee^X Property PIat~X BOP Sketch~X Diverter Sketch Re-entry Program~X Drilling Fluid Program Time vs Depth Plot Refraction Anafysis~ Seabed Report 20 AAC 25.050 Requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~~ ~1 ~ Title Operations Superintendent Date 7/22/1998 Commission Use Only Permit Number _~~jl API Number 50-/3',~-z,p,_3 7S_ 5'p Approval Dat ~ a - $ See Cover Letter For Other Requirements Conditions of Approval Samples Required Yes ~No Mud Log Required Yes ~No Hydrogen Sulfide Measures Yes ~No Directional Survey Required Yes ~No Required Working Pressure for BOPE ~2M ~3M ®SM ~10M ~15M Other: iJ1 i4~i11~; ~i{~I(Ctl CSy by order of 9~~+ / Approved by ®$ Commissioner the Commission Date Fom, to-aot izev. tz-1.85 -' ° Submit in Triplicate g:tcmnW rlglsterlinglsu32-9V10GCCPTD.XLW STATE OF ALASKA A OIL AND GAS CONSERVATION CONI!!!J'SION PERMIT TO DRILL 210 AAC 25.005 1a. Type of Work Drill Re-Drill Re-Entry^X Deepen 1b. Type of well. Exploratory~X Stratigraphic Test Development Oil Service Development Gas Single Zone Multiple Zonea 2. Name of Operator MARATHON OIL COMPANY 5. Datum Elevation (DF or KB) (Pad) 230' (est) feet 10. Field and Pool 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 6. Property Designation 84201 4. Location of Well at Surtace 1183'FSL, 2265'FWL, Sec. 29, T7N, R9W, S.M. 7. Und or Property Name Wolf Lake 11. Type Bond (sae 20 AAC 25.025) Blanket Surety At top of Productive Interval 1285'FSL, 2236'FWL, Sec. 29, T7N, R9W, S.M. 8. Well Number # 2 Number 5194234 At Total Depth 2621'FSL, 488'FWL, Sec.29, T7N, R9W, S.M. 9. Approximate Spud Date 9/1/1998 Amount $200000 12. Distance to Nearest Property Line(top of pay) 1285 feet 13. Distance to Nearest Well 500 feet 1a. Number of Acres in Property 640 15. Proposed Depth (MD and ND) 8000' MD, 7915' TVD feet t6. To be Completed for Deviated Wells KH;koff Depth 5700 feet Maximum Hole Angle 26 ° t7. Anticipated Pressure (see 20 AAC 25.035 (e) (2)) Maximum Surface 2500 prig at Total Depth frVD) 7915' 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 26" 20" 133# 66 0 0 66 66 In place 171/2" 13 3/8" 68872# 4332 0 0 4332 4332 In place 121/4" 9 5/8" 47853.5# 12152 0 0 12152 11818 In place 81/7' T' 32# 1557 11834 11558 13391 13039 In place ~~~~~vEa Alaska Oil & Gas Cons. Commission t..~ ~ ~ ~ ~ ~ ~T Anchorage 20. Attachments Filing Fee^X Property PIat~X BOP Sketch~X Diverter Sketch Re-entry Program^X Drilling Fluid Program Time vs Depth Plot Refraction Analysis Seabed Report 20 AAC 25.050 Requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge r--`~ Signed ~~~~ Title Operations Superintendent Date 7/22/1998 Commission Use Onl Permit Number Lit ~ API Number 50-/3 -Z6 3 ? ~_ ~~ Approval Date G1 / ~ Y -- ~'g See Cover Letter For Other Requirements Conditions of Approval Samples Required Yes ®No Mud log Required Yes ~No Hydrogen Sulfide Measures Yes ~No Directional Survey Required Yes ~No Required Working Pressure for BOPE ~2M ~3M ®SM ~tOM ~15M Other: Url~ln~l i31~fP~fa +,i~, . David W. Johnston by order of ~~ J ~~ Approved by Commissioner the Commission Date Form 10-007 Rev. 12-t-85 Submit in Triplicate MARATHON OIL COMPANY WOLF LAKE # 2 RE-ENTRY PROCEDURE -Reestablish road and pad. Drill water well. Install sewage holding tank. -Locate and excavate around the well. Install new cellar if old one has been removed. -Weld on 13 3/8" casing stub and a 13 3/8" 5M x 13 5/8" 5M SOW head.(May or , maynot have to weld on 20" casing stub to support casing head). -Lay location liner. -Move in and rig up rig. -Nipple up BOPE and test(notify AOGCC 24 hrs in advance). Mix gel water. -Drill cement plug from surface to top of cut off 9 5/8" casing(100' from surface) with 12 1/4" bit. -Dress off top of 9 5/8" casing. Wash over top of casing to insure no cement is between 9 5/8" and 13 3/8" casings. -Clean out cement in 9 5/8" casing. Rackoff cut joint. Run 9 5/8" casing and screw in. Pull +/- 75K and set slips.(note: casing patch will be on location as a backup) -Nipple up tubing head and test. Test ROPE. -Clean out 9 5/8" casing below production interval to sump packer setting depth. Test casing. -Run USI bond log(gives casing condition) and any other logs required by Geologist. -Squeeze as necessary. -Run 8 1 /2" bit and scraper to sump packer setting depth. -Circulate and displace mud with completion fluid. -Set sump packer. -Run tail pipe, packer and tubing. -Circulate and inhibit packer fluid. -Land hanger and set packer. Test. Set BPV. -Nipple down ROPE and nipple up tree and test. -Test well.(may test well with rig standing by.) July 21, 1998 SENT BY~Marathon Oll Company 8-26-98 2~05PM : anchora~e~ MARATHON O!L COMPANY WOLF LAKE # 2 RE-ENTRY PROCEQUiRE -Reestablish road and pad. grill water welt. lnstalt sewage holding tank. 907 276 7542: 2/ 4 -Locate and excavate around the well. Install new cellar if old one has been removed. -Weld on 13 3/8" casing stub and a 13 3l8" 5M x 13 5I8" 5M SOW head.(May or maynot have to weld on 20" casing stub to support casing head). -Lay location liner. -Move in end rig up rig. -Nipple up ROPE and test(natify AOGCC 24 hrs in advance). Mix gel water. -Drill cement plug from surface to top of cut off 9 5/8" casing(100' from surface) with 12 1 /4" bit. -Dress off top of 9 5/8" casing. Wash over top of casing to insure no cement is between 95/8" and 13 3J8" casings. -Clean out cement in 9 5/8" casing. Rackoff cut joint. Run 9 5l8" casing and screw in. Pull +!- 75K and set slips.(note: casing patch will be on location as a backup) -Nipple up tubing head and test. Test ROPE. -Clean out 9 5/8" casing below production interval to sump packer setting depth. Test casing. -Run USI bond log(gives casing condition) and any other logs required by Geologist. -Squeeze as necessary. -Run 81/2" bit and scraper to sump packer setting depth. -Circulate and displace mud with completion fluid. -Set sump packer. -Run tail pipe, packer and tubing. -Circulate and inhibit packer fluid. ~:.-, 4.4 :..-µ ~- ;BUG " ~?~$ -Land hanger and set packer. Test. Set BPV. ~~ ~,~ ~ G2s ~~ ~~~ -Nipple down ROPE and nipple up tree and test. -Test Beluga and Tyonek gas sands, see proposed wellbore diagcam.(may test well with rig standing by.) July 24, 1998 ' S)riVT BY:Marathon Oll Company : 8-26-98:2:05PM AnchoraQe~ 907 276 7542: 3/ 4 MARATHON OIL COMPANY WOLF LAKE # ~ EtE-ENTRY PROCEDURE -Evaluate test results. If test results are positive applicable Permits will be submitted to develop the field. This procedure could take one to one and a half years followed by construction of the pipeline. If test results are negative the sidetrack potential will be evaluated and upon final negative results the well will be plugged and abandoned. July 24, 1998 SENT BY-Marathon 011 Company 8-26-98 2~05PM Anchorage 907 276 7542:# 4/ 4 WG~r LAKE #2 PROPOSED WELLBORE SCHtMATIC 7/21!98 20" cut off 5' l,efow grade_ 20" 133 ppf cemented at 6f3'. 13 3/8" 88 8 72 ppf at 4358' RKS. 3 1/2" Production tubing. Production packer and tall pipe. Beluga: Tyonek: Sump packer +l- 8000' and/7515' tvd. TOC at 11385' RKB. R©tainer at 11485' RKB. Reestablished pad surface. Note: original RKB 31' above pad. 8100'-8135' and 8095'•6129' tvd 6190'-8200' and 6163'-6193' tvd 6385'-6385' and 6354'-6374' tvd 6445'-6472' and 6433'-6459' tvd 7010'-7038' and 8974'-7001'tvd 7390'-7480' and 7336'-7423• tvd 9 518" 53.5 8 47 ppf, S-95, BTC at 12154' RKB. ~~, ~_ ~~1G "~';, '~g~ Alaska ~3i1 ~ Gas C~i~. Ccmrri~-~;-t° TOC 13200' RKB. 7" 32 ppf liner 1184D' RK6 to 13391' RKB. W~F LAKE #2 EXISTING WELLBORE SCH~ATIC Well marker. Existing ground surface. 7/21 /98 20" and 13 3/8" cut off 5' below grade. Cement plug from surface to 150' from surface. Bottom of plug 50' into 9 5/8" casing. 20" 133 ppf cemented at 66'. Note: original RKB 31' above pad. 9 5/8' cut off at 100' from surface. 13 3/8" 68 8 72 ppf at 4358' RKB. 9 5/8' casing full of 12.8 ppg mud. No oil in mud. TOC at 11385' RKB. Retainer at 11485' RKB. 9 5/8" 53.5 & 47 ppf, S-95, BTC at 12154' RKB. FIT 12.7 ppg EMW. Casing set in 12.3 ppg mud. TOC 13200' RKB. 7" 32 ppf liner 11840' RKB to 13391' RKB. Note: Cap and marker post welded onto 13 3/8". Plate welded on top of 20" x 13 3/8" annulus. W~LAKE #2 PROPOSED WELLBORE SCH nAATIC 7/21 /98 cut off 5' below grade. Reestablished pad surface. 20" 133 ppf cemented at 66'. Note: original RKB 31' above pad. 13 3/8" 68 & 72 ppf at 4358' RKB. 3 1/2" Production tubing. Production packer and tail pipe. Beluga: 6100'-6135' and 6095'-6129' tvd 6190'-6200' and 6183'-6193' tvd 6365'-6385' and 6354'-6374' tvd 6445'-6472' and -_ 6433'-6459' tvd Tyonek: 7010'-7038' and 6974'-7001' tvd 7390'-7480' and 7336'-7423' tvd Sump packer +/- 8000' md/7915' tvd. TOC at 11385' RKB. Retainer at 11485' RKB. 9 5/8" 53.5 & 47 ppf, S-95, BTC at 12154' RKB. TOC 13200' RKB. 7" 32 ppf liner 11840' RKB to 13391' RKB.. J . I ~„ ~ ~. ~~ ~~ ~ ~,. o.:~, Mud T~ ~ - s....r I ~ o L36~S • a~.Kra _ i ri.T a,y-e O~,~aL cacKE . ~_-~ M~o ,, (~ nl C ~ I , ~° t r ~ DoG aovsc i ~ m I t. 1 ~ - - R16 SHELTER ~~ ~- -_-.° ~_• 1 enu rt~6wtAST Doh MovSE ~ suOSiRUGTUae tAT WALK ~ ! Generai Purpose Worksheet ~~1e ~blNet fPa~s No. Cf t,r- "Ifile IBr Oace i ~r z t- W Y 4 ~ ~ W M ac y ~_ ~- i Y .1 ~a ,' o . v y tr.?, Z ~ W ~ u ~y H ~ ~ L. _' '~ 'a. m~ :1 ~ a;l~l ~ ~ ' ~II~ ~ I ~ ~. ~ , i ; ~~~ ~ ~: m. .j ~ --n c~mlK''`~ ~~ , I ~ N n' I i ~ : ~ n ~ ri I ~ .o y =1 2 Z ~ a ct Z ~! ~ w .* ~1(fY ,= Q. as ~ `~~l~~~ait_I o y i .t. i ~ v~ ~ ~ ~ i ~, ? ~ 2a_ U y a i ~ ~ .. ~ ~ _ ~- 1. ~ o: r J, I: h i• r~ ~,, ~ #F`.~ R ~ .` .. naae.eza~ ~ ~ ~ Q- i . ~; . ~ .~'` :' ~: i :• t a ~~ ~~ _ ~~ ~! I ~ ~ ~ ~ I ~ ~ ~ i ~ i ~ ~ ~ ~ i ~ 1 ~ i ~ ~ ~ r~ ~ I , r ~ i I ~ , ~ t I W I ! . 1 ~ ~ o! +; r sae _ ~ ! ~• ~ +~ ( E of ~ g ~ f ;, W ~ ~^ ~ ~ ~I a ~ j .•. a ~ i ~ env r m 7 '~ ~ ~~ n w a r ~ ~ ~ ~n f ,~ _~~ ~~~ . ya sc : _'` .~ ~. sc MI ~ V ~ I Fo ~ :~I Z .1 ~ ~ cT~i ~ ~ ' w i0 A T~ C N ~ ~ ~~`4 o r ~ ~ _ • ~ ~ °,~' t.., W ~ ~ u' ~ a W ~C l o ~ ~~ ~ . s s ~ '" 3 ~ ~ 4 DS~01w~ PROFILE 13 518" S,OOO.P. BOP ST+4CK 3 ~ ~©an~ KI L L Y~LIt ES 441S~i6 lb ~~~ ~ 3" S QOtI~ CHQ~E Y~L1~~S D~~ Nates: BOP side outlets are 4`- 5,044 R-39, ~4dapters i~ar side outlets to 3" - 5,40q~ F~35 are available. Adapters to hubbed or lower pressure wellheads sre a~vsilable. /~ ~a~ _ KENAI (C-3) QUADRANGLE ~~~ ALASKA-KENAI PENINSULA EtOROUGH ~t'P 1:63 360 SERIES (TOPOGRAPHIC) ~`~' i 151° n to v IKENAI D-31 A s w. 55' 50' 35ooooFEET 45 28, 27 ~ ~ 26`'~'s 2~ ~ h 30 29 28 0 27 2 ~' din 20 2 / 3 ~ 60 C,-'. ~ --_- ....__. / r\ t _. ---_1 ._-- `----_ a--____. .----. \4y .--_ -.. ---- t ij;'----$Tanks ~w i .-. -___..-~--rsd .,5~~ t D ~.......~k~ -+~- --- - ___ _ L=v J^~ ~1) iJ' G> I\ v ~. ~ ~ ~j _ I ~, Sim 'veri ~ieo~\_ J .,... ~~. sQ ....:` o o P~ i nn c~ , 3 ~ I 33 r~F } ,:34 ' } 35 ~ ~ 31 32 0 5 / " 3 ~__ R i v e r3.1 I \ A /'~ .ly r .I ,:` .r'~. / ~~ n ~ ~ ~ ~- -~so, TAN. i . o / ° ~ I l . ~ ~, °° ~ ~'~...aryy. _.....;' o I ~....: !~ nr ~~ (~ ~,. l'~j52 --'~ _ /~~ i •o,N ~~ !~- "' tttrrr ) o ~X' ~ ~ <:. 125 `- ;~' o e L IELD ,a, ,~ _ ~" z ~~J~, H _ ) I ~ ~\ ~ -_` ' ;-_~ 5 ~~- -- --rcY~-~ ~~- ~ \ ~ n~~ k I s~ ~ o~ ~ ~yk 7A 2~ l ~~, rEE~ ~ ~ ~' ~.`~-\I~ 3 ,.. f 2 I5 ~_- -fi - ~?s~.-..- ~5 I 4 `yo ~ `.3 f~ 1 6 ~Plmer e ~ ~ ~ ° ~,,, ~) ~ - ;, ., :.. ~ ~ ° ss ;i , ° • V ' a~ _ ,. _ -., ... ~ 1 .. :., ~ ~ ry~ .: ~ is 8 y~.. ~ ,iL>C(L'Ln 1107A) ~t~~,-. ~ ~ ~.., l ~ ~ V-~_. ~~. , G~. ro~n i r -C~ ~~ I ( ~~7 0 `.~ ~ . -:. _ ,~~ \ _~:~ti~ .. . _. _: - - -- - ----- - - _. ---- - - -- - -' - rake --10 1 - -. ,- I , ° ~,. : / .. .. : ; .~ ~ ~ ; 9 ~ !` (~ 10 ~~~ )) 11' . 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Q438' ~~ ~ i ~ ~ o ~ ~. ~a _~ \ u~ J JJJ ~ J~ ~2~ ~~ 2~~r' 'dt ~ ~J° 0(24 \so 19 ~\ ; ~ 2 2 ~~ l _i2 i 24 ~ ~ ~ ~19 ~' e o ~ r ..: -.,.. O- ~ ~`~z'~p ) :I ~ 263 O __ W (-.o_o a (/ -" 5°/ ... -....., ~.. ~~. ~ ` - .- ~ x396/ _3 `. _-_ ,T ~~ ~ - --Q- _~_: - -- - -- _ . _ I -~_ - -- _ - cr- ~ C'r _ _ ~~ \ L 28~s° ~ 27 ;, ~) ~ ~ p O ~~' 29 O ~8 <: ~ 27 .: 5 ~ 30. 35 ' a Q` d u ~ O oc~ ° V ~,~ / --30 J -- _ ~~ - -- - - 1' VVl ~ .. ... ~N . '..... .: -~ I ~ f 0 r~ ~s o C ~ o l y° ti ~ : , C~ ~, ~>~ ~ $3 34 ~ i 35 ~ ~,~ 31 ti f~ o ~~ ~ 34 ti 35 ~ < ~J ° ... _ 0o rj" L .... ~ z5° i 260 q{~~,~ , ~ - ~ O ~ .O. o O 250 U ~ /v? i• \" ~~-~ / O; ~ ~.:~ c :.,~° ~~ ~ O ,, ~ e Q ~ '~°~ s 1 `ii t ,~~ , ~ i ~~~ ~~/ ~ ~ IO)`IAL 0 9 ~ ~ GE p~~NDARY r e N . _. I -~ ~ ~- Ca kec ~_ _. ;~ ~50 .... - Gr a oo' / 15 N. ~-, ~ I c ~ ~ ~~,; ~ I a h~ 1 ~ !/ °~ ~ 2 ~ ~ ~ /~ iandl _ i /~ ~p'~ CJy I ~, _-, - :V,_, .' p}~~-~ ~ V 1 - 1 ,. I.: fba ~~ ~: /~ } ~4 ~ 1 nt ~ 1 o$tr ~` ' -aoo^ -- I° ' - 25°~ ~ , c~ v I `~ ~~Z 1 30 { N 2 ~'r ,..I._J" 'T ~/.~ ~ "~~~I~y'b¢`~ ~_. '®eF..aN .. r. N ry~''C//I '3- ~ 2 ,.\~ 15o I 6 ~ ( I ~ ° I ` °o I ser.~''"¢ Lake t _,I °rJ e ~ ~°~~ ~I d ~ ~`/ ' n ~ g~ i ~. ~, z ~ ':\ ( T( / ' - .. _. ~_ __~2RZ ._~~) Ir.-~_~__.F.~:~ -~ C~ ~ ~I ~° - Pty' k_O\B/NSON 1- . ~ J ROAD 054 ~-__~/? x~. 0¢ I L~_.~__ ~,~ ,......: ~.} / 1 .._ ~ '' J _' ~'~~/ ?S ~ I~ ~ d p i _ 90°'~~ _-L__-PI_PEL E ~~ 1 \I~ > Y e - I I L i 1 p~ J 4y ~l I M 1 ~,(~ ~ //n~~. ' °' 9 I C.~ i , We °. _ ~ ~,:1 i -512 (I \~ I . ~ 1~ 293. ~ ° .._ c ~Jl'@Y200~:.'I p S ~. ~ _ 1 ii --J .' I I t - ~~ I rl. ~ I ea ~ I. [~% ~ I° ° 1 ° a. d ~ . 1 n j - r 1 ~ 1 f ee ~ , x~~ , 1 "'' I 0 g° ;( ndin ~ ~ r_ ~.1 a l~'n ~~ `ao L> J ~ ~::,~r ea ~~ i- PA I a...lA'ke I 2 n $ ~59 is ~` j~~ i ,o 1 2y r <. ° ~ t 1 d x ~ .' I ~ ~ .... .t tandingStnp~.: I ' _ _ '- ~ r ~ ~ ~ r ~ ~---~ _~1~ ~ _~~ ' ~ ~ -- 1_ ~ ~ - I o - ~- I - -' ~ - - ~ =- -'-- - ---- ~ I yo'~~ 1 Mackeys Lakes '` ~~,2y ' ,y ~ A0o %~ I °' zz5 `~` Q -- y ~~ SENT BY=Marathon Oil Company 8-26-98 ; 2~05PM Anchorage-~ 907 276 7542;# 2/ 4 MARATHON O!L COMPANY WOLF LAKE # T RE-ENTRY PROCEDURE -Reestablish road and pad, Drill water well. install sewage holding tank. -Locate and excavate around the well. Install new cellar if old one has been removed. -Weld on 13 3/8" casing stub and a 13 318" 5M x 135/8" 5M SOW head.(May or maynot have to weld vn 20" casing stub to support casing head). -Lay location liner. -Move in end rig up rig. -Nipple up BOPE and test(notify AOGCC 24 hrs in advance). Mix gel water. -Drill cement plug from surface to top of cut off 9 5/8" casing(1 QO' from surface) with 12 1/4" bit. -Dress off top of 9 518" casing. Wash over top of casing to insure no cement is between 95!8" and 13 318" casings. -Clean out cement in 9 5/8" casing. Rackoff cut joint. Run 9 5/8" casing and screw in. Pull +/- 75K and set slips.(note: casing patch will be on location as a backup) -Nipple up tubing head end test. Test ROPE. -Clean out 9 5/8" casing below production interval to sump packer setting depth. Test casing. -Run USI bond log(gives casing condition) and any other Ivgs required by Geologist. -Squeeze as necessary. -Run 8112" bit and scraper to sump packer setting depth. -Circulate and displace mud with completion fluid. -Set sump packer. -Run tail pipe, packer and tubing. -Circulate and inhibit packer fluid. -Land hanger and set packer, Test. Set BI~V. -Nipple down ROPE and nipple up tree and test. ~~~~ AUG 2 6 i~~8 Alaska Ou ~ GasCons. Gx~rliasip8 Andl Test Beluga and Tyvnek gas sands, see proposed wegbore diagram.(may test well with rig standing by.) July 24, 1998 •SENT BY~Marathon Oil Company 8-26-98 2~05PM Anchorage 907 276 7542;# 3/ 4 !~ i MaRATHON OIL COMPANY WOLF LAKE # 2 FtE-ENTRY PROCEDURE -Evaluate test results, If test results are positive applicable Permits will be submitted to develop the field. This procedure could take one to one and a half years followed by construction of the pipeline. !f test results are negative the sidetrack potential will be evaluated and upon final negative results the well will be plugged and abandoned. July 24, 1998 '5ENT BY~Marathon Oil Company 8-26-98 2~05PM Anchorage 907 276 7542;# 4/ 4 WCs~F LAKE #2 PROPOSED WELLBORE SCHtMATIC 7121198 20" cut off 5' below grade_ Reestablished pad surface. 20" 133 ppf cemented at fi6'. Note: original RKB 31' above pad. 13 3/8" 68 S 7Z ppf at 4358' RKB. 3 1l2" Production tubing. Productlon packer and tail pipe. Beluga: 8100'-8135' and 8095'-8129' tvd 6190'-8200' and B 183'-B 193' tvd 6365'-6385' and 6354'-637x' tvd f445'-6472' and 6433'-6459'tvd Tyonek: 7010'-7038' and 6974'-7001'tvd 7390'-7480' and 7336'-7423' lvd Sump packer +/_ 8000' md17915' tvd. TOC at 11385' RKB. R©iainer et 11485' RKB. 9 5/8" 53.5 8.47 ppf, S-95, BTC at 12154' RKB. ~~~ AUG ~ 6 X998 Alaska Oil ~ GasCOng. i~~~r~ ~rtd~ol~ TOC 13200' RKB. 7" 32 ppf liner 11840' RK6 to 13391' RKB. WL" ~F LAKE #2 EXISTING WELLBORE SCH~IC Well marker. 20" and 13 3/8" cut off 5' below grade. Existing ground surface. 7/21 /98 Cement plug from surface to 150' from surface. Bottom of plug 50' into 9 5/8" casing. 20" 133 ppf cemented at 66'. Note: original RKB 31' above pad. 9 5/8' cut off at 100' from surface. 13 3/8" 68 & 72 ppf at 4358' RKB. 9 5/8' casing full of 12.8 ppg mud. No oil in mud. TOC at 11385' RKB. Retainer at 11485' RKB. 9 5/8" 53.5 & 47 ppf, S-95, BTC at 12154' RKB. FIT 12.7 ppg EMW. Casing set in 12.3 ppg mud. TOC 13200' RKB. 7" 32 ppf liner 11840' RKB to 13391' RKB. Note: Cap and marker post welded onto 13 3/8". Plate welded on top of 20" x 13 3/8" annulus. W~LAKE #2 PROPOSED WELLBORE SCTIC 7/21 /98 20" cut off 5' below grade. 20" 133 ppf cemented at 66'. 13 3/8" 68 & 72 ppf at 4358' RKB. 3 1/2" Production tubing. Production packer and tail pipe. Beluga Tyonek Sump packer +/- 8000' md/7915' tvd. TOC at 11385' RKB. Retainer at 11485' RKB. Reestablished pad surface. Note: original RKB 31' above pad. 6100'-6135' and 6190'-6200' and 6365'-6385' and 6445'-6472' and 7010'-7038' and 7390'-7480' and 9 5/8" 53.5 & 47 ppf, S-95, BTC at 12154' RKB. 6095'-6129' tvd 6183'-6193' tvd 6354'-6374' tvd 6433'-6459' tvd 6974'-7001' tvd 7336'-7423' tvd TOC 13200' RKB. 7" 32 ppf liner 11840' RKB fo 13391' RKB. U' ~'' ~ - 3 -- .~ ~ . ~, v ,, General Purpose Worksheet r~i,'.~o,e« ' ~_ ";File 'C q, Z 2 Q l ~r z Y ~ ~ W ac y Z ,o . v M ~ ~ Yf } ~ ~*~- ~ • ~ 1~ t2 Q ~_ _ ...t a ~ u ~, ~ o~ v o y I ~ ~ Kati. ~ i ~? y.~ t ~ i • ~ ~ ~ =~ t ~ ~ ~. ~. J• ~ ~ ~~ ~ . , s: , J~ ~ a;trn`= m ^ f a-~ ~ (~ 11 3 I ~~ ~ ' I i_ . ~+. , ~ o .~ + ' + w c ~ ~ .o:.y ~ ~ _ . m. = n n; miK~ =1~ ~ m~ ~ i H n~ ~ I ~.a ~ ~ Q ~ N u1 ~~0,~~ ~ E "' Z z Z~ a ti ~ (` H H3 Z ~j L~ ' O -~ u ~ ~ -1 ~ ~ v Q~~°I ~ ~ ~ ; a9s rvo. Y ,7 ,^ i. ..Y '.. ~h.S.;. " oace • -~~~~ ~:) ~~+/ • V ~` •~ ~ ~ s i J s .. ___.._ ~,y ~~ 4 ~ _. r 1 41 I' i r i ~ _ ~, ~] i ~ ml i ~! J ~ I +i I ~ ~ ~ ~ ' ~ J ~ ~ r I i i ~ ~ I ~ i I ~ I ; ~ ~ I (' j r - i I ~ ~ ~ W ~ ~ ~ L K1 J1 ! ~ . ~ ~ ~! I o~ ~ ~~ ~ I ~• I s ~ ~ ` I ~ W Y a p 3 ~ = ~~ ;; a i ~ v; ~{ ~ m ~ ` ~, h M w ~ ~ If1 11~p Z ~+ S' 7q 7R ~''i ~ ~ ~ ?! ` I A ' ~ ~^I h++ a 1q ~1 i ~ Y V ! I o p ~ .1 ~ O b ~ W • O ~ el ' W • T v v • F- • ~i / , :. F ~ ~ u' LL ~ ~ W S ~ = Y ~ µ £ ~ LL ~~ ~ "` 3 ~ ~ ~ 4 DSI~1W PROFILE 13 5I6" 5,000+. BOP STACK ~~~~~ ~~~ ~~~ x1~ n ,~~ ~, o .. ~~~~ .. ,,.~ . . ~~~Q~ 3 " 5000 KILL Yr~LI~ E$ 1 ea, qOC~ '`'~ so~ zo 3" SQ~O~ -~ CFlf3t<E Y~LYES . T STtra~ x Sru17 /r~r,~! ~. ~~ ~ '~~ ~~ ~Ia~: BCIP side outlets are 4`- 5,040" R-39. ~4depiers i+or side auitets tv 3" - 5,400" P..3g sr~e available. Adapters to hubbed or 1 aver pressure wellheads are suet lsble. tiro. l .~ l ~. ~ fi`r`-' 4~€ 15 ~ 16 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re: THE APPLICATION OF Marathon ) Conservation Order No. 433 Oil Company for an order granting ) an exception to spacing requirements of ) Marathon Oil Company 20 AAC 25.055(a)(2) to re-enter the ) ARCO Wolf Lake #2 exploratory well. ) Wolf Lake No. 2 July 29, 1998 IT APPEARING THAT: Marathon Oil Company in correspondence dated May 19, 1998, requested an exception to the well spacing provisions of 20 AAC 2~.055(a)(2). The exception would allow re-entry of the ARCO Wolf Lake #2 exploratory well, which is less than 1500' from a section line. 2. The Commission published notice of opportunity for public hearing in the Anchorage Daily News on June 4, 1998 pursuant to 20 AAC 25.540. ~. No protests to the application were recei~•ed. FINDINGS: 1. The ARCO Wolf Lake ~2 exploratory well is a straight hole located approximately 2265' from the west line and 11$3` from the south line in Section 29, T7N, R9W, Seward Meridian. It is about three miles due south of the Swanson River oil field on the Kenai Peninsula. 2. Offset owners Cook Inlet Region, Inc., ARCO Alaska, Inc., Anadarko Petroleum Corporation, Union Oil Company of California and Union Texas Alaska, LLC have been duly notified. 3. An exception to the well spacing provisions of 20 AAC 25.055 (a)(2) is necessary to re-enter this well. CONCLUSION: Granting a spacing exception to allow re-entry of the ARCO Wolf Lake #2 exploratory well will not result in waste nor jeopardize correlative rights. Conservation Order No."~~~3 • July 29, 1998 Page 2 NOW, THEREFORE, IT IS ORDERED: Marathon Oil Company's application for exception to the well spacing provisions of 20 A.AC 25.05 (a)(2) for the purpose of re-entering the ARCO Wolf Lake #2 exploratory well is approved. DONE at Anchorage, Alaska and dated July 29, 1998. ~ ~.K; 9 ~°~,~ I j ~'t ' } ~ ~. ~~ ~% ~i' ~" r~ ., _„_ ~.~: ~~~ ~,~,r David W. Johnston, Ch irm-~ ~_~~ Alaska Oi~and Gas Con ervation Commission Robert N. Christenson, P. E., Commissioner Alaska Oil and Gas Conservation Commission AS 31.0.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may the with the Commission an application for rehearing. A request for rehearing must be received by 4:30 P!~1 on the 23~`' daV following the date of the order, or next working day if a holiday or weekend, to be timely tiled. The Commission shall Brant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the tinal order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10`x' day after the application for rehearing was tiled). OPERATOR CITY STATE Check request No. ANC 4/29/98 A (nrs) Filin Fee for Permit to Drill ~~ 9 Wolf Lake No. 2 Marathon Oil Company - • • • • • P.O. Box 196168 ANCHORAGE ALASKA 99519-6168 NON-REPORTING • 100% REPORTABLE INTEREST IF mfr ~ REPORTABLE RENTS - INDICATE SERVICES OR TYPE OF NON-EMPLOYEE COMP. PAYMENT PRIZES, AWARDS, OR - - - - - - - DAMAGES ,;~ ~; . • Memorandum Oil and Cas Conservaiion Commission To: R. A. Douglass Fm: Jack Hartz `1 ~' Subj: API Number Duplication in Well History Database 1~-~ '~t'~-' -?~„_G~ tee- -.e-~,-~^~-~-~ G~r+~'~-0 J'~ ~~~ State of Alaska October 2, 1992 This note is to inform you of a problem with duplicate API numbers existing in well history database. To date we have found 17 cases of duplication. The problem is caused by two situations; 1.) an abandoned well is taken over by a different operator than who originally drilled the well and performs one or more regulated operations; 2.) a well is deepened with little or no offset from the coordinates of the original hole (Case 7 , p .14 of Bulletin D 12A) . Both of these situations require a new permit under our regulations. however, API standards do not dictate any change to the original API Number. This results in multiple permit numbers issued against the same API number. In Alaska's well record system, a new permit number requires a separate record in our data base and thus results in duplication of API numbers in these situations . Joan Miller has noted this problem on printouts of the annual well status report . In addition, there were several instances noted in PA databases . Errors occur when production records listed by API number are matched to a well history record of an abandoned well with the same API number. The well may have been plugged and abandoned by one operator, then reentered, deepened and / or completed in a different reservoir by the same or different operator. If the reentered well required a new permit, production from the new completion may be reported for the original hole which was abandoned . Unfortunately some of this data goes into the public domain and at times a significant amount of effort is required to find and rectify the errors. Recommendation Bob Crandall and I agree that we can give the reentered or deepened wells an API code which will be unique and honor the intent of the API ,~ t Page 2 MEMO FORM standards. We propose to use the 11th and 12th digits of the API number and code reentered or deepened wells with digits in the "90" series in the sidetrack code slot. In addition, we can add a designator such as RE or DPN to the well's common name if appropriate. Both these flags will add a unique identifier to wells in these categories . An example of how the problem appears and how the solution works follows: Permit # API Number Well Name Number Status Original: 80-0141-0 283-20068-00 Lewis River D-1 P&A Current 89-0072-0 283-20068-00 Lewis River D-1 WDSPL Proposed: 89-0072-0 283-20068-90 Lewis River D-1RE WDSPL We discussed this proposal with C.O. Liles, a staff member at API, who agreed verbally with our approach. He noted that the 90 series has no reservations according to API standards . We feel this solution can be applied universally within Alaska in a simple, straightforward manner. Changes can be made easily to our data base, however, operators must be notified before the changes are made public so our records and their reports will be consistent If this meets with the Commission's approval, let me know so the appropriate changes can be made. xc: Bob Crandall Enclosure • WELL PERMIT CHECKLIST COMPANY WELL NAME 2 PROGRAM: exp ^ dev ^ redrll ^ serv ^wellbore seg D ann. disposal pars req [7 FIELD & POOL ~~, INIT CLASS ~J, ~ GEOL AREA ., ~2~, UNIT# /L aQ, ON/OFF SHORE a~1 ADMINISTRATION 1. Permit fee attached ....... . ............... ~ .-~ ~ / 1 ~ ~ 2. Lease number appropriate . .................. ~ N - /~ f ~ , , ~ / 3. Unique well name and number .................. Y N T i r ~ ' 4. Well located in a defined pool .................. Y 5. Well located proper distance from drilling unit boundary. ... Y 6. Well located proper distance from other wells.......... N ~ / I 7. Sufficient acreage available in drilling unit............ Q~ N ~, Z9 ~, ~.~..~~.~e... ~ .~ ! ~ ~' ~3 3 w ~ c.~ 8. If deviated, is wellbore plat included ............... C7Y N ~ Q 9. Operator only affected party ................... Y 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order........ Y A R 12. Permit can be issued without administrafive approval...... CSS~ ~ 13. Can permit be approved before 15-day wait........... Y ENGINEERING 14. Conductor string provided ................... N 15. Surface casing protects all known USDWs. .......... N 16. CMT vol adequate to circulate on conductor & surf csg..... Y N /'xj~~in,~ 17. CMT vol adequate to tie-in long string to surf csg........ Y N 18. CMT will cover all known productive horizons.......... N 19. Casing designs adequate for C, T, B 8 permafrost. ...... N 20. Adequate tankage or reserve pit ................. N 21. If a re-drill, has a 10-403 for abandonment been approved... -j`-id-/~A 22. Adequate wellbore separation proposed ............. I ~r~ ~~ f.~1 !f 23. If diverter required, does it meet regulations .......... N 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ................ Y N APPR DATE 26. BOPE press racing appropriate; test to pstg. N 27. Choke manifold complies wlAPl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown........... Y N 29. Is presence of H2S gas probable ................. Y GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. .... Y N 31. Data presented on potential overpressure zones ....... Y ~~ ~ 32. Seismic analysis of shallow gas zones ............. N ~'~/r~ , 33. Seabed condition survey (ifoff-shore) ............. Y N AP 34. Contact name/phone for weekly progress reports ....... Y N ~ ~f (exploratory only] ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste ... Y N Nod ~~~ . to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 AAC 25.252 or 20 AAC 25,412. Y N GEOL /Y: ENGINEERING: UIC/Annular COMMISSION: Z~ ~ }- A~ Commentsllnstructions: t uQSfn~ ~- ~n~rh~r~-ts ~ ( ~ RP Ci BEW ,~ WM wM DWJ JDH RNC tm (y,~ Cr~ "'(~P'r,- T, 41~u t ~ ~ r~ ~7ro-~o-~. CO Br %°G • a M:cheklisl rev D5129198 d1CC:lmsoBlcelwordianW lanalchecklist