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Home My WebLink About169-100Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 12/12/2025 InspectNo:susKPS251022200223 Well Pressures (psi): Date Inspected:10/22/2025 Inspector:Kam StJohn If Verified, How?Other (specify in comments) Suspension Date:5/12/2025 #325-238 Tubing:0 IA:0 OA:0 Operator:Hilcorp Alaska, LLC Operator Rep:Zachary Rohr Date AOGCC Notified:10/14/2025 Type of Inspection:Initial Well Name:KENAI UNIT 21X-32 Permit Number:1691000 Wellhead Condition Wellhead was in good shape with all operational gauges, no leaks Surrounding Surface Condition Surface area was clean gravel no stains or sheen Condition of Cellar No Cellar Comments Location found with pad map Supervisor Comments Photos (4) attached. Follow-up to inspection done 8/21/2025 (Inspector Guy Cook) to confirm deficiencies corrected (blind flanges properly bolted; hydrocarbon-stained gravel removed; protectioin fior wellhead). Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Friday, December 12, 2025                2025-1022_Suspend_KU_21X-32_photos_ksj Page 1 of 2 Suspended Well Inspection – Kenai Unit 21X-32 PTD 1691000 AOGCC Inspection Rpt # susKPS251022200223 Photos by AOGCC Inspector K. StJohn 10/22/2025 2025-1022_Suspend_KU_21X-32_photos_ksj Page 2 of 2 Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 10/06/2025 InspectNo:susGDC250820115954 Well Pressures (psi): Date Inspected:8/21/2025 Inspector:Guy Cook If Verified, How?Other (specify in comments) Suspension Date:5/12/2025 #325-238 Tubing:0 IA:0 OA:0 Operator:Hilcorp Alaska, LLC Operator Rep:Zachary Rohr Date AOGCC Notified:8/20/2025 Type of Inspection:Initial Well Name:KENAI UNIT 21X-32 Permit Number:1691000 Wellhead Condition A little surface rust but in pretty good condition. Blind flanges improperly bolted. OA grease fitting missing cap. Surrounding Surface Condition Hydrocarbon stained ground immediately surrounding the wellhead; the rest of the surrounding area is clean. Condition of Cellar No cellar. Comments Zachary Rohr sent pictures of properly bolted IA flange and the grease fitting capped. Hydrocarbon stains still visible despite attempt by Hilcorp to improve. No protection for wellhead; flowline flanges remain improperly bolted. Supervisor Comments Photos (13); Unclear what was done to "clean up" the hydrocarbon stained gravel; blind flanges need to be correctly bolted Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Monday, October 6, 2025              Pad map used to verify well location 2025-0821_Suspend_KU_21X-32_photos_gc Page 1 of 7 Suspended Well Inspection – KU 21X-32 PTD 1691000 AOGCC Inspection Rpt # susGDC250820115954 Photos by AOGCC Inspector G. Cook 8/21/2025 (Except as noted) 2025-0821_Suspend_KU_21X-32_photos_gc Page 2 of 7 Wellhouse off the well Tree cap pressure gauge 2025-0821_Suspend_KU_21X-32_photos_gc Page 3 of 7 IA pressure gauge OA pressure gauge 2025-0821_Suspend_KU_21X-32_photos_gc Page 4 of 7 Blind flange bolting incomplete IA flange showing correct bolting Photo courtesy of Hilcorp after correctly bolting flange 2025-0821_Suspend_KU_21X-32_photos_gc Page 5 of 7 OA valve grease cap installed Hydrocarbon-stained gravel Photo courtesy of Hilcorp after cap installed 2025-0821_Suspend_KU_21X-32_photos_gc Page 6 of 7 Hydrocarbon-stained gravel 2025-0821_Suspend_KU_21X-32_photos_gc Page 7 of 7 Hydrocarbon-stained gravel somewhat cleaned up Photo courtesy of Hilcorp after "clean up" 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 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- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22.Logs Obtained: N/A 23. BOTTOM 20" H-40 57' 13-3/8" K-55 1,166' 9-5/8" K-55 5,053' 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 Sr Res EngSr Pet GeoSr Pet Eng N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 61# 6,446' Surface Surface 94# Surface 1,195' SIZE DEPTH SET (MD) PACKER SET (MD/TVD) Surface 40# Surface 57'Surface CASING WT. PER FT.GRADE 11/25/1969 CEMENTING RECORD N/A N/A SETTING DEPTH TVD 2372096.91 TOP HOLE SIZE AMOUNT PULLED N/A 274746.09 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A BOTTOM 50-133-20204-00-00 Kenai Unit (KU) 21X-32 FEDA028055 1867' FSL, 1106' FEL, Sec 32, T5N, R11W, SM, AK 464' FNL, 2044' FWL, Sec 32, T5N, R11W, SM, AK N/A 11/5/1969 6,450' MD /5,057' TVD 4,960' MD / 3,782' TVD 0' 276825.20 2369107.51 N/A 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 17. Field / Pool(s): Kenai / Sterling 4, Sterling 5.1, Sterling 6 Gas STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG WAG Gas 5/12/2025 169-100 / 325-238Hilcorp Alaska, LLC If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 1570 sx G12-1/4" TUBING RECORD 676 sx G17-1/2" 2,004'Kill String 2-7/8" Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment Received by J. Brooks at 7:59AM on 6/10/2025 Suspended 5/12/2025 JSB RBDMS JSB 062525 xGDSR-7/21/25BJM 10/7/25 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 31. List of Attachments: Operations Summary, Schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Stefan Reed, Operations Engineer Digital Signature with Date:Contact Email:stefan.reed@hilcorp.com Contact Phone: 206-518-0400 Authorized General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Formation Name at TD: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and INSTRUCTIONS Noel Nocas, Operations Manager 907-564-5278 Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.06.09 16:07:07 - 08'00' Noel Nocas (4361) Lease: State: Country:USAAlaskaKenai Peninsula Borough Well Name & Number:Kenai Unit 21X-32 KGF, Pad 43-32 Prepared By:D Ambruz Last Revision Date: County or Parish: 05/30/25 KB @ 0' CIW Tbg Hanger @ 16.8' 20", 94# Conductor driven to 57' 13-3/8", 61#, K55 Csg @ 1,195' Casing 9-5/8", 40# K55 & N80 Csg @ 6,446' Cmt'd w/ 1570 sks Class "G" ISOLATED ALL PERFS 5/8/25 Existing Perfs B-1 5316'-5369' (53') 5391'-5398' ( 7') B-2 5416'-5425' ( 9') 5432'-5448' (16') B-3 5488'-5524' (36') RePerf B-2 5438'-5448' (10') B-3 5488'-5524' (36') KU 21X-32 Kenai Gas Field Pad 43-32 C SCHEMATIC TD 6,450' MD / 5,057' TVD PBTD 5,570' MD / 4,275' TVD' Kill String 2-7/8" 6.5# Sealwock @ 2,004' 1/10/24 Packer debris @ 5,570’ 1/9/24 Damaged casing @ 5,308'-5,358' milled to 8-1/4" 12/21/23 TOC @ 4,960' (05/12/25) Page 1/1 Well Name: KEU KU 021X-32 Report Printed: 5/21/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50-133-20204-00-00 Field Name:Kenai Gas Field (KEU KGF)State/Province:ALASKA Permit to Drill (PTD) #:169-100 Sundry #:325-328 Rig Name/No: Jobs Actual Start Date:5/1/2025 End Date: Report Number 1 Report Start Date 5/5/2025 Report End Date 5/6/2025 Last 24hr Summary Fox CTU 9. Move from Paxton 13 to location. Off load equipment. MIRU. SDFN. Report Number 2 Report Start Date 5/6/2025 Report End Date 5/7/2025 Last 24hr Summary Fox CTU 9. PJSM and PTW. PU Inj and lubricator. Stab pipe, fill reel and shell test. Test BOPE to 250/3500 psi per Sundry. No failures. Witnessed by Bob Noble. Stack down Inj. Wait on cementers. Report Number 3 Report Start Date 5/7/2025 Report End Date 5/8/2025 Last 24hr Summary Complete PTW / PJSM. R/U to reverse out if needed during cement job. MIRU Fox cement pump. Fox has coil personnel shortage. Discuss plan forward w/OE. Decision made to postpone cement job until morning. SDFN. Report Number 4 Report Start Date 5/8/2025 Report End Date 5/9/2025 Last 24hr Summary Complete PTW / PJSM. M/U slick cement BHA. Shell test 250 psi low 4500 psi high. RIH w/1.75" DJN. At 4000' ctm, online down coil w/FW @ 2 bpm and took 83 bbls to establish returns at surface. 40% losses to formation. Dry tagged 9-5/8" obstruction @ 5,567' ctm. P/U clean 18k to 5,550' ctm. Online down coil w/15.3 ppg cement at 1.3 bpm while taking returns off CTBS. With cement @ nozzle begin laying in cement pulling 17 fpm. With 8 bbls layed in and coil full of cement the Fox cement compressor on bulk truck went down. Troubleshoot compressor for 40 minutes but unable to transfer dry cement product to batch mixer. Swap to FW displacement down coil 1.3 bpm and lay in remaining 22 bbl of 15 .3 ppg cement in 9-5/8" casing. Layed in total 30 bbls of cement w/23 bbls of returns. Calculated TOC = 5,247'. Pooh pumping PD. On surface flushed coil w/3x coil volume and drift pig. Recovered pig. Rack back injector head. SDFN. Report Number 5 Report Start Date 5/9/2025 Report End Date 5/10/2025 Last 24hr Summary Complete PTW / PJSM. M/U slick cement BHA. Shell test 250 psi low /3500 psi high. RIH w/1.75"DJN. Dry tagged @ 5,157' ctm. Verify tag 3k down. PUH to 5150' ctm. Pressure up tubing to 950 psi and monitor for 15 min, good test. Bleed WHP to zero. Layed in 10 bbls of 15.3 ppg Class G cement from 5,150' up to 5,025' (1.3 bpm / 17 fpm). Shut in CTBS. Pooh pumping PD. On surface, load & launch 1.75" pig and flush coil w/3x coil volume to return tank. Recovered pig. Blow down reel w/N2 (28k , 300 gal). RDMO Fox CTU. Report Number 6 Report Start Date 5/12/2025 Report End Date 5/13/2025 Last 24hr Summary Complete PTW / PJSM/ MIRU Pollard SL. PT SL PCE to 2000 psi as per sundry. Drifted w/2.25" cent & 2"x4' bailer, tagged TOC = 4960' KB. MIRU Fox coil pump. PT surface lines to 2000 psi. Circulate down tubing taking returns off IA, 11 bbls to establish returns off IA. MIT to 1780 psi, lost 20 psi first 15 minutes, lost 8 psi the second 15 minutes. MIT passed first attempt. Tag & test witnessed by AOGCC Sully Sullivan. RDMO Pollard and Fox. 325-238 -bjm Witnessed by Bob Noble. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KENAI UNIT 21X-32 JBR 07/18/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Very good test. Arvell Bass is very hands on. Test Results TEST DATA Rig Rep:Buddy MarshallOperator:Hilcorp Alaska, LLC Operator Rep:Arvell Bass Rig Owner/Rig No.:Fox 9 PTD#:1691000 DATE:5/6/2025 Type Operation:WRKOV Annular: Type Test:INIT Valves:Rams: 250/3500 Test Pressures:Inspection No:bopRCN250508161017 Inspector Bob Noble Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 2 MASP: 603 Sundry No: 325-238 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid P Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 0 NA Inside BOP 0 NA FSV Misc 0 NA 5 PNo. Valves 2 PManual Chokes 0 NAHydraulic Chokes 0 NACH Misc Stripper 1 1.75"P Annular Preventer 0 NA #1 Rams 1 Blind/Shear P #2 Rams 1 1.75" Pipe/Sli P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 2 2"P HCR Valves 0 NA Kill Line Valves 2 2"P Check Valve 0 NA BOP Misc 0 NA System Pressure P2900 Pressure After Closure P2250 200 PSI Attained P6 Full Pressure Attained P30 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)NA0 ACC Misc NA0 NA NATrip Tank NA NAPit Level Indicators NA NAFlow Indicator NA NAMeth Gas Detector NA NAH2S Gas Detector 0 0MS Misc Inside Reel Valves 1 P Annular Preventer NA0 #1 Rams P12 #2 Rams P11 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke NA0 HCR Kill NA0 9 9 9 9 99 9 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Stefan Reed Cc:Donna Ambruz Subject:RE: KU 21X-32 (PTD# 169-100) Sundry 325-238 Date:Monday, April 28, 2025 8:49:00 AM Attachments:image003.png Stefan, Hilcorp has approval to complete the sundried work no later than June 15, 2025. Note, the original due date was Jan 10, 2025. No further extensions will be given. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Stefan Reed <Stefan.Reed@hilcorp.com> Sent: Friday, April 25, 2025 11:04 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: KU 21X-32 (PTD# 169-100) Sundry 325-238 Bryan, As discussed, Hilcorp requests an extension to complete the work detailed in sundry 325-238 no later than June 15, 2025. Regards, Stefan Reed Operations Engineer Kenai Asset Team Cell: 206-518-0400 Hilcorp Alaska, LLC The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 6,450'5,570' Casing Collapse Structural Conductor Surface 1,540psi Intermediate Production 3,090psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Well shall be used only for production from the gas storage pool unless the requirements of SIO 7A and 20 AAC 25.252 are met and sundry approval for injection is obtained. Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Perforation Depth MD (ft): N/A See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Kenai Unit (KU) 21X-32CO 510C 5,053' 4,275' 9-5/8" 57' 20" 6,446' 5,057' 5,570' N/A; N/A Sterling 4, 5.1 Gas Pools 13-3/8" ~603psi 6,446' 1,195' Length Tubing Size: 1,152' May 1, 2025 Kill String 2-7/8"See Attached Schematic N/A; N/A PRESENT WELL CONDITION SUMMARY Perforation Depth TVD (ft):Tubing MD (ft): Size 1,195' MD 57' 57' 6.5# / N-80 TVD Burst 2,004' 5,750psi 3,090psi stefan.reed@hilcorp.com Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028055 169-100 50-133-20204-00-00 Proposed Pools: Kenai Hilcorp Alaska, LLC Stefan Reed, Operations Engineer AOGCC USE ONLY Tubing Grade: Other: CT Operations Chad Helgeson for Noel Nocas, Operations Manager 907-564-5278 206-518-0400 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.04.17 09:38:41 - 08'00' Noel Nocas (4361) 325-238 By Grace Christianson at 12:22 pm, Apr 17, 2025 Provide 48 hrs notice for AOGCC opportunity to witness TOC tag (max tag depth allowed is 5216' MD) and pressure test to 1500 psi. X 4/21/2030 Suspended SFD 4/21/2025 See variance request and comments in attached procedure. 10-407 CT BOP test to 3500 psi Only the CT contingency cement plug is approved with this sundry. The fullbore cement option does not meet any plug methods allowed in regulations 20 AAC 25.112(c)(1). DSR-4/17/25 Suspend X BJM 4/21/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.22 10:40:22 -08'00'04/22/25 RBDMS JSB 042125 Isolation Rev. 2 Well: KU 21x-32 Date: 3/25/25 Well Name:KU 21x-32 API Number:50-133-20204-00-00 Current Status:SI gas well Permit to Drill Number:169-100 First Call Engineer:Stefan Reed (206) 518-0400 (C) Second Call Engineer:Chad Helgeson (907) 229-4824 (C) Current Bottom Hole Pressure:997 psi @ 3940’ TVD (RFT from KBU 22-07Y 2015) Maximum Expected BHP:997 psi @ 3940’ TVD MPSP: ~603 psi (0.1 psi/ft gas gradient) Brief Well Summary: KU 21X-32 was brought online in 1969 targeting the Sterling Pool 4 & 5 with a dual string design. Peak production rates reached 20 MMCFD in 1971. Pool 4 & 5 allocated production rates were split 50/50 until 1984 when the long string (Pool 5) was shut in. Pool 4 (short string) remained on-line until 2006 when the well was taken off line due to water & sand production. In late 2023 an attempt was made to recomplete the well for Pool 6 production. The rig was unable to make it to the desired depth to due a well obstruction at 5570’ MD. A 2-7/8” kill string was set and the well was left shut in. Notes Regarding Wellbore Condition x 2-7/8” Kill string to 2,004’ MD x Damaged casing @ ~5318’-5368’ MD milled to 8.25” ID. x W/O Rig unable to mill past obstruction @ 5570’ MD x WL dump bailed cement on obstruction @ 5570’ MD w/ no issues. It is assumed that the obstruction is hard bottom. x Fluid level shot 31-Mar-2025 showing depth of ~1,400’ Objective: The purpose of this work is to isolate the Sterling Pool 4 and Sterling Pool 5.1. Hilcorp requests a waiver from 20 AAC 25.112 verifying plug location and integrity between Sterling Pool 4 and 5.1. The proximity (40’) of the uppermost Pool 5.1 perf and Lower Pool 4 perf make it operationally challenging to execute accurately as well as the inability to pressure test the plug isolating the 5.1. Hilcorp believes this procedure will confine any hydrocarbons to their original strata and will prevent any migration of hydrocarbons to freshwater or the surface. Top’s : Defined by KU 21-06 Sterling Pool 4: Top 5313’ MD (4058’ TVD), Base: 5461’ MD (4181’ TVD) Sterling Pool 5.1: Top 5461’ MD (4181’ TVD), Base: 5727’ MD (4413’ TVD) Eline/Slickline: 1. MIRU Unit 2. PT Equipment 3. RIH to confirm fluid level and tag TD. 4. RDMO. Send results to OE. Variance 20 AAC 25.112(g) for not verifying the deeper pool, Sterling 5.1 gas pool. -bjm Note: Hilcorp committed to either plugging or repairing the well by 1/10/2025 and requested a 60 day extension on 1/23/25 after their sundry Application submitted 1/17/2025 to suspend the well was rejected. See attached email. -bjm Pools 5.1 & 4 may be cemented with a single continuous plug if cement is placed by displacement method 20 AAC 25.112(c)(1)(C) from top of junk/fill to at least 100' above the top perforation. -bjm Isolation Rev. 2 Well: KU 21x-32 Date: 3/25/25 Fullbore (contingent on fluid level): 5. MIRU pump truck and PT equipment. 6. Pump water down kill string for injectivity test. Discuss details with OE before job. a. Note pressures and rates b. Monitor IA pressure 7. RDMO. Send results to OE. Cementing: 8. MIRU Cementing equipment. 9. PT equipment 10. Pump cement plug per the following pump schedule @ 2bpm. Confirm pump schedule with OE pending injectivity test results. Planned TOC ~4779’ (~537’ above top perforation.) a. 15bbls fresh water (pump until catch pressure) b. ~60 bbls 15.3ppg Class G cement ܥ݁݉݁݊ݐ ܪ݄݁݅݃ݐ: 0.0758 ܾܾ݈ݏ ݂ݐ ÷60ܾܾ݈ݏ = 791݂ݐ ݈ܲܽ݊݊݁݀ ܱܶܥ : 5,570݂ݐ െ 791݂ݐ = 4,779݂ݐ c. ~222 bbls fresh water ܱܶܥ ݐ݋ ܶݑܾ݅݊݃: 4,779݂ݐ െ 2,004݂ݐ = 2,775݂ݐ ܱܶܥ ݐ݋ ܶݑܾ݅݊݃ ܸ݋݈.: 2,775݂ݐ כ 0.0758 ௕௕௟௦ ௙௧ = 210bbls ܶݑܾ݅݊݃:2000݂ݐ כ 0.0058௕௕௟௦ ௙௧ = 11.6ܾܾ݈ݏ ܶ݋ݐ݈ܽ:210ܾܾ݈ݏ + 11.6ܾܾ݈ݏ = 222ܾܾ݈ݏ d. Flush lines and surface equipment e. RDMO Contingency: If no/low injectivity in step 6 (<2bpm): 11. MIRU Coil tubing unit 12. Test BOP’s to 250psi low/ 3500 psi high. This fullbore cement plan does not meet regulations for cased hole P&A plug per 20 AAC 25.112(c)(1). Isolation Rev. 2 Well: KU 21x-32 Date: 3/25/25 a. Provide AOGCC 24hrs notice to witness test 13. RIH w/ cementing BHA. 14. Lay in ~60bbls 15.3ppg Class G cement. 15. Pull to safety, circulating water. 16. POOH. RDMO. Fullbore/Slickline 17. MIRU Slickline and pump truck. 18. PT equipment to 2000psi 19. Load well with water, circulating out IA. 20. Slickline RIH tag TOC and Fullbore pressure test wellbore to 1500psi a. Provide AOGCC 24hrs notice to witness tag and pressure test. 21. RDMO Repeat steps as necessary to achieve desired cement height Attachments: 1. Current Schematic 2. Proposed Schematic 3. Coil BOP Schematic Cement to be laid in from top of junk at 5570' to ~4779' MD (791' above top perf) -bjm Lease: State: Country:USA Well Name & Number:Kenai Unit 21X-32 KGF, Pad 43-32 Prepared By:D Ambruz Last Revision Date: County or Parish: 02/08/24 AlaskaKenai Peninsula Borough KB @ 0' CIW Tbg Hanger @ 16.8' 20", 94# Conductor driven to 57' 13-3/8", 61#, K55 Csg @ 1,195' Casing 9-5/8", 40# K55 & N80 Csg @ 6,446' Cmt'd w/ 1570 sks Class "G" Existing Perfs B-1 5316'-5369' (53') 5391'-5398' ( 7') B-2 5416'-5425' ( 9') 5432'-5448' (16') B-3 5488'-5524' (36') RePerf B-2 5438'-5448' (10') B-3 5488'-5524' (36') KU 21X-32 Kenai Gas Field Pad 43-32 C SCHEMATIC TD 6,450' MD / 5,057' TVD PBTD 5,570' MD / 4,275' TVD' Kill String 2-7/8" 6.5# Sealwock @ 2,004' 1/10/24 Packer debris @ 5,570’ 1/9/24 Damaged casing @ 5,308'-5,358' milled to 8-1/4" 12/21/23 Lease: State: Country:USAKenai Peninsula Borough Well Name & Number:Kenai Unit 21X-32 KGF, Pad 43-32 Prepared By:S. Reed Last Revision Date: County or Parish: 03/28/25 Alaska KB @ 0' CIW Tbg Hanger @ 16.8' 20", 94# Conductor driven to 57' 13-3/8", 61#, K55 Csg @ 1,195' Casing 9-5/8", 40# K55 & N80 Csg @ 6,446' Cmt'd w/ 1570 sks Class "G" Existing Perfs B-1 5316'-5369' (53') 5391'-5398' ( 7') B-2 5416'-5425' ( 9') 5432'-5448' (16') B-3 5488'-5524' (36') RePerf B-2 5438'-5448' (10') B-3 5488'-5524' (36') KU 21X-32 Kenai Gas Field Pad 43-32 C PROPOSED TD 6,450' MD / 5,057' TVD PBTD 5,570' MD / 4,275' TVD' Kill String 2-7/8" 6.5# Sealwock @ 2,004' 1/10/24 Packer debris @ 5,570’ 1/9/24 Damaged casing @ 5,308'-5,358' milled to 8-1/4" 12/21/23 Planned TOC ~4779' 1 McLellan, Bryan J (OGC) From:Stefan Reed <Stefan.Reed@hilcorp.com> Sent:Thursday, January 23, 2025 10:39 AM To:McLellan, Bryan J (OGC) Cc:Davies, Stephen F (OGC); Roby, David S (OGC); Donna Ambruz Subject:RE: [EXTERNAL] KU 21X-32 (PTD 169-100) sundry application Bryan, Thanks for your time earlier, as discussed on the phone we would like an additional 60 days to determine future plans for this well and submit a more comprehensive plan. Regards, Stefan Reed Operations Engineer Kenai Asset Team Cell: 206-518-0400 Hilcorp Alaska, LLC From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, January 22, 2025 9:38 AM To: Stefan Reed <Stefan.Reed@hilcorp.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: [EXTERNAL] KU 21X-32 (PTD 169-100) sundry application Stefan, A couple of issues with the sundry application that you’ll need to address. 1. In box #1 of the sundry form, it says you are pulling tubing. There’s no mention of pulling tubing in the procedure, so I assume you decided not to pull tubing, correct? 2. You need to either comply with 20 AAC 25.112(g) to verify this plug integrity, or ask for a variance with alternative means of plug veriƱcation. 3. The well needs to be either 1) completed as a development or injection well with production tubing and packer; 2) suspended, which will require a second plug above the perfs; or 3) P&A’d. Let me know what you’d like to do? Thanks 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Note: The above questions are directed toward a sundry application submitted 1/17/25. That original sundry application was not compliant with suspension regulations. Hilcorp submitted a new suspension sundry application on 4/17/2025. -bjm 2 Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 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. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:32 Township:5N Range:11W Meridian:Seward Drilling Rig:N/A Rig Elevation:N/A Total Depth:6,450 ft MD Lease No.:FEDA028055 Operator Rep:Suspend:X P&A: Structual:20"O.D. Shoe@ 57 Feet Csg Cut@ Feet Surface:13 3/8"O.D. Shoe@ 1,195 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:9-5/8"O.D. Shoe@ 6,446 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:2 7/8"O.D. Tail@ 2,004 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Other 5570 ft 4960 ft 8.0 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing IA 1780 1760 1752 OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Eli Wilson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Cement plug was layed on an unknown obstruction in the 9-5/8" casing @ 5570 ft to 4960' MD, 356 feet above the top perfs . This well has a 2-7/8" kill string to 2,004 ft MD . May 12, 2024 Sully Sullivan Well Bore Plug & Abandonment Kenai Unit 21X-32 Hilcorp Alaska LLC PTD 169100; Sundry 325-238 Photos (2) Test Data: P Casing Removal: rev. 3-24-2022 2025-0512_Plug_Verification_KU_21X-32_ss             Plug Verification – Kenai Unit 21X-32 (PTD 1691000) Photos by AOGCC Inspector S. Sullivan 5/12/2025 KU 21X-32 Well Sign Wireline Depth Counter Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 3/14/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240314 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 13 50133205250000 203138 1/20/2024 AK E-LINE GPT/PL BCU 13 50133205250000 203138 1/4/2023 AK E-LINE JetCut/CBL BRU 221-35 50283201930000 223077 11/18/2023 AK E-LINE Perf HV B-13 50231200320000 207151 12/22/2023 AK E-LINE CBL IRU 41-01 50283200880000 192109 11/16/2023 AK E-LINE Perf KBU 22-06Y 50133206500000 215044 1/16/2024 AK E-LINE GPT/Perf KTU 32-07H 50133205110000 202043 10/27/2023 AK E-LINE PPROF KU 3-06A 50133207160000 223112 1/12/2024 AK E-LINE CBL KU 21X-32 50133202040000 169100 12/8/2023 AK E-LINE JetCut MPU CFP-02 50029212580000 184242 3/9/2024 READ CaliperSurvey NCI A-18 50883201890000 223033 12/8/2023 AK E-LINE Perf/GPT NIA NK-18 50029224210000 193177 12/13/2023 AK E-LINE IPROF PTM P1-13 50029223720000 193074 12/9/2023 AK E-LINE Cement TBU M-11 50733205900000 210145 1/8/2024 AK E-LINE Perf TBU M-15 50733204220000 190109 2/7/2024 AK E-LINE GPT/Perf Please include current contact information if different from above. T38615 T38615 T38616 T38617 T38618 T38619 T38620 T38621 T38622 T38623 T38624 T38625 T38626 T38627 T38628 KU 21X -32 50133202040000 169100 12/8/2023 AK E-LINE JetCut Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.15 11:38:35 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: * Install Kill String Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6,405 feet N/A feet true vertical 5,057 feet 5,570 feet Effective Depth measured 5,570 feet N/A feet true vertical 4,275 feet N/A feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)Kill String 2-7/8" 2,004' MD 1,823' TVD Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: Storage Pool Report Code is 448809. Brian Glasheen, Operations Engineer 323-639 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 brian.glasheen@hilcorp.com 907-564-5277 N/A measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 57' 10 Size 57' 0 500 0 00 0 Production Liner measured TVD 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 169-100 50-133-20204-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA028055 Kenai C.L.U. / Sterling 4, Sterling 5.1, Sterling 6 Gas Pools Kenai Unit (KU) 21X-32 Plugs Junk measured Length 57' 6,446' Casing Structural 5,053'6,446' Conductor Surface Intermediate 20" 13-3/8"1,195' 3,090psi 3,090psi 5,750psi 1,195'1,152' Burst Collapse 1,540psi p k ft t Fra O s 6. A G L PG , *Convert to Gas Storage Production Well Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Samantha Coldiron at 11:09 am, Feb 09, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.02.09 10:45:44 - 09'00' Noel Nocas (4361) DSR-2/13/24BJM 1/21/25 RBDMS JSB 021324 Page 1/4 Well Name: KU 021X-32 Report Printed: 2/8/2024www.peloton.com Alaska Weekly Report - Operations Jobs Actual Start Date:12/4/2023 End Date: Report Number 1 Report Start Date 12/4/2023 Report End Date 12/5/2023 Last 24hr Summary Mob CT Unit from Yard to location. MIRU on KU 21x-32. MU Wellhead XO for dual completion wellhead. NU BOP's, Function test. Shell test . Full BOP test per sundry. No failures. 24 hr notice given. Witness waived by Jim Regg. RD test eqpt. Secure the well. SD for the night. Report Number 2 Report Start Date 12/5/2023 Report End Date 12/6/2023 Last 24hr Summary Last 24 hrs: KU 21x-32, Scope FCO/Pull PX Plug: PJSM/Permit with Ops, Warm up equipment. PU Inj & stack Lub, Install YJ Dimple CTC, Pull test to 30K. Flood coil. MU JY MHA w/ Max od of 2.13, OAL of 9.25' , RIH past SL trouble spot at 5,285' no issues. Rolling pump at 1/2 bpm. while RIH. Cont RIH Tag good fill at 5365'. Increase rate to 1.0 bpm & wash down to 5476' Top of Prong. No returns to surface. Cont washing above the prong. POOH, MU Hyd overshot with 1-3/8 FN grapple & 2.30" OD Stabilizer. RIH, Wash over prong set down 5K PU with slight overpull, RIH to verify over prong with 7k & no pump. POOH. Break off the WH. No Fish Inspect overshot. Broken grapple. Contact OE, Coil unit blow down the reel & LD the Injector. Secure the well. Notify Pad operator of well status. Report Number 3 Report Start Date 12/6/2023 Report End Date 12/7/2023 Last 24hr Summary PJSM/Permit with Ops, Spot & RU Pollard Slickline. PT Lub, RIH with 2.25” LIB, RIH with LIB, Unable to pass thru 5288’ slm. POOH make up double knuckle. RIH tag fluid level at 4780’ , Tag top of prong for impression at 5482’ SLM, RIH w/ 2'' JDC to 5470'slm latch w/ tool friction bite only pooh pin partially sheared no metal marks. RIH w/ 2'' RB to 5470'slm (12’ higher than LIB) RIH w/ 1.75''x4' dd bailer to 5467'slm w/ tool to 5475'slm pooh full sand. RIH w/ 2''x4' dd bailer to 5461'slm w/ tool losing hole. POOH. Bailer full of sand. RD SL, secure well for the night. Report Number 4 Report Start Date 12/7/2023 Report End Date 12/8/2023 Last 24hr Summary PJSM/Permit with Ops, Warm up equipment. Flood coil. MU JY BHA with 2" Nozzle , RIH Rolling pump at 1/2 bpm. while Cont RIH Tag Light fill at 5430'. Increase rate to 1.0 bpm & wash down to 5468' Hard tag, not making hole. (Top of Prong). No returns to surface. Cont washing above the prong. POOH, MU 2" JDC with 2" GS Bait sub. RIH tag at 5476' setdown 5K. PU to 21K (5K) overpull, RIH set down 5K, PU with no overpull. POOH. PX Prong Retrieved . MU 2.5" HYD GS. RIH to retrieve PX plug body. Set down at 5268' (dog leg), PU with no overpull, Make several attempts to get past. Unable to get past 5286' Contact OE. POOH. From 5368'. RDMO Fox Coil. Secure well, Notify Pad operator of well condition. Report Number 5 Report Start Date 12/8/2023 Report End Date 12/9/2023 Last 24hr Summary AK Eline Permit and JSM with KGF Ops. Spot & RU Eline to short string. MU Lub & PT. RIH with 2.063" Jet Cutter. Correlate depth to Tubing tally. Make Cut above Paker at 5245' . POOH. RDMO Eline Report Number 6 Report Start Date 12/11/2023 Report End Date 12/12/2023 Last 24hr Summary Pol slick line for KU 21x-32 to Pull PX plug body . Permit/PJSM with Ops. Spot eqpt at location. RU & PT. RIH with 2.25" LIB. FL at 2250', Cont RIH to 5487' SLM, RIH with 2.25" magnet. Retrieve 1 of 8 grapple pieces. Run second LIB for impression of top of plug. RIH with 2.5" GR to retrieve PX plug body. Latch plug body 5487'slm, POOH. OOH with PX plug body & 7 grapple pieces. Disucssed plan with Ops lead. Rih with 1-3/4" bailer to 5544' slm. POOH with sand sample. RDMO SL. Secure well, Notify Well Pad Lead. Report Number 7 Report Start Date 12/12/2023 Report End Date 12/13/2023 Last 24hr Summary Set in containment, spot bean rig and equipment. Raised and scope derrick. R/u circulating lines. Bullhead 410bbls of produced water down LS. LS on vac. Report Number 8 Report Start Date 12/13/2023 Report End Date 12/14/2023 Last 24hr Summary Pumped Kill fluid and monitored well on vac then static. Set BPV in LS and SS. N/d tree prep hanger. N/u BOP's. R/u work floor and install winterization Report Number 9 Report Start Date 12/14/2023 Report End Date 12/15/2023 Last 24hr Summary Warmed up BOPE, Rigged up and attempt to shell test BOPE, good low test , leaked off on 2500 high test, Trouble shoot leak, found leak across hanger, repack void and test to 5000 k, Pull blanking subs and BPV install two way checks in L/S & S/S, test to 2500 psi ( good) preform shell test on bope to 250 line and 2500 psi high, contintue testing 13-5/8 5M BOPE to Hilcorp & AOGCC specs' to 250 low and 2500 psi high, with a 2-7/8 test joint, test made with water and held on chart 5 minutes each test ( no failures) , AOGCC inspector Austin McLoed witness test, perform Koomey draw down ( Passed), Rig down test equipment and Blow down surface lines, Rig up E-line test lubricator to 3000 psi RIH with 2.063 jet cutter to 5272 MD,make cut on long string, Report Number 10 Report Start Date 12/15/2023 Report End Date 12/16/2023 Last 24hr Summary E-line RIH on L/S with 2.063" jet cutter, set down at 5261' ELM, could not work past tight spot, Reconfigured tool string, able to work past tight spot, made cut on long string at 5272' MD. POOH cutter fired, set BPV in long string, Back out lock down pins, unseat S/S hanger with 36k, strip curculating head off pipe to remove hanger, lay out hanger, Install circulating head bowl, Rig up pipe handler on trailers. pooh laying 167 joints and cut piece of 2-7/8, 6.4#,N-80 seal lock tbg, slip and cut drill line 67.5 ft. check crown a matic, remove circulating head bowl, pull BPV in long string, make up landing joint in long string, and unseat hanger with 36k shear packer at 56k pick hanger up to floor pump tbg volume of 30 bbls down tbg and lay out hanger. Field: Kenai Gas Field (KEU KGF) Sundry #: 323-639 State: ALASKA Rig/Service:Permit to Drill (PTD) #:169-100Permit to Drill (PTD) #:169-100 Wellbore API/UWI:50-133-20204-00-00 pgp, g g, down pins, unseat S/S hanger with 36k,p gpp pooh laying 167 joints and cut piece of 2-7/8, 6.4#,N-80 seal lock tbg p, g , pg pg y p Rih with 1-3/4" bailer to 5544' slm. POOH with sand sample ,p make up landing joint in long string, and unseat hanger with 36k gj p ,, g ,g,pgg, shear packer at 56k pick hanger up to floor pump tbg volume of 30 bbls down tbg and lay out hanger. Page 2/4 Well Name: KU 021X-32 Report Printed: 2/8/2024www.peloton.com Alaska Weekly Report - Operations Report Number 11 Report Start Date 12/16/2023 Report End Date 12/17/2023 Last 24hr Summary Pump tbg volume 32 bbls no returns from IA, while letting packer elements relax, Pooh laying down 2-7/8 ,6.4#, N-80 seal loc, tbg, no Corrosion or solids, laid down 165 joints, repair lay down machine, lay down remaining tbg (2) joints, & the 9-5/8 RH2 dual packer, & cut piece, ( full recovery), Rig up and pick up fishing BHA #1, 8-1/8 overshot dressed with 2-7/8 grapple, continue in hole with BHA picking up 2-7/8 PH 6 work string to 4,712 ft. Report Number 12 Report Start Date 12/17/2023 Report End Date 12/18/2023 Last 24hr Summary Continued RIH with fishing BHA. Latch onto fish at 5,272' top of fish, Bottom of fish at 5,467'. jarring and working fish up hole from 5,467 bottom of fish to 5,362' bottom of fish, jarring at 100k (60K) over pulling up to 140k (100k) over, at 5,362 picked up on fish to 80k ( 40K ) over, weight dropped off to 42k continue to pooh to 5,270' with 42k up wt. Prep to Pooh. Report Number 13 Report Start Date 12/18/2023 Report End Date 12/19/2023 Last 24hr Summary Continue POOH racking back work string, laid down jars, lay out fish, pick up 8*1/8 packer mill, trip in hole with 2-7/8 Ph 6 work string, tagging fill at 5,313' dpm, laid out tag joint, rig up circulating hose, pump 30 bbls of 40 lb/bbl LCM pill. and displace same with 24 bbls 8.4 ppg water. got returns once pill was in place, shut down pump, monitor well loss rate at 1 bbl per hour Report Number 14 Report Start Date 12/19/2023 Report End Date 12/20/2023 Last 24hr Summary Monitor well 1-BPH loss rate, Reverse out 30 bbl pill, Capture in mix tank, Blow down lines, Rig up power swivel, RIH tagging up at 5,313 ft. pumping at 3 bpm at 500 psi, rot at 80 rpm, torque off bottom 2300 , torque on bottom 2300 to 4200 ft/lbs, Rot wt. 32k, up wt 38k, dn wt, 25k, work down to 5,315', fell free down to 5,327' taking wt and stalling work down to 5,327', stalling & picking up heavy, continue working down to 5,331 ft. Reverse out 187 bbls at 3.0 bpm at 475 psi, got back 5 lbs of fine shavings, no solids, total losses during reaming and circulating 5 bbls. Rig down power swivel and blow down lines, pooh to BHA, rack back drill collars, and lay out jars. Report Number 15 Report Start Date 12/20/2023 Report End Date 12/21/2023 Last 24hr Summary Finish L/D BHA, Mill warn on leading edge. no wear on face. Rig up slick line tagged 5,399 'with 2.25 bailer, worked to 5,400', , RIH & tagged with at 4.65 " GR tagged at 5,384',tagged with 8" GR junk basket at 5348 ft , tagged with 7" GR junk basket at 5373' slm, rig down slick line. pick up 6-5/8 bit, RIH to 5318 ' Cleaned out well f/ 5318 ft. to 5,469 ft. reverse circulate hole clean at 5,469 ft.. rack back power swivel. Report Number 16 Report Start Date 12/21/2023 Report End Date 12/22/2023 Last 24hr Summary POOH w/ 6 5/8" cleanout BHA, Change out BHA, Test gas alarms, RIH with 8-1/4 tapered mill, and 8-1/2 string mill BHA to 5308 ft dpm, rig up power swivel , wash and ream f/ 5,308 to 5,355 Report Number 17 Report Start Date 12/22/2023 Report End Date 12/23/2023 Last 24hr Summary Cont. running taper mill assy down t/ 5358', POOH t/3491dpm, rig up and test 13-5/8 5M BOPE to Hilcorp and AOGCC specs, to 250 low and 2500 psi high with 2- 7/8 and 3.5 test joints, test made with water and held 5 minutes on chart each test, preform Koomey draw down, AOGCC Jim Regg waived witness at 16:11 hours on 12,22,23. , rig down test equipment and blow down surface lines, install circulating head and bolt up same. Report Number 18 Report Start Date 12/23/2023 Report End Date 12/24/2023 Last 24hr Summary POOH l/d 2 7/8" wk string , laying down same, lay down tapered mill assembly, Mills looked good, no ledging, R/up Yellow jacket E-line Run in hole with caliper log to 5,440' ELM uncorrelated, log out of hole to surface, Rig down E-line, Rig up and to pick up BHA, Thimble on drillers side air hoist hung up on derrick board, bending off drillers side up 8", Brian Wilks and Jesy Diamond with Hilcorp maintenance team came out and inspected board, RIH with 2-7/8 out of derrick and lay down same. Service rig and prep to straighten derrick board . Report Number 19 Report Start Date 12/24/2023 Report End Date 12/25/2023 Last 24hr Summary Straighten Derrick board, & visual inspection, good. P/U taper/string mill BHA, RIh picking up 3.5 ph 6 work string tagging at 5,350' ft dpm rig up power swivel wash and ream f/ 5,350' ft to 5,356 ft. Report Number 20 Report Start Date 12/25/2023 Report End Date 12/26/2023 Last 24hr Summary Cont. reem & cleanout 9 5/8 casing from 5356' t/ 5,372', change out saver sub, continue to clean out 9-5/8 cag from 5,372' to 9-5/8 model D packer at 5,464 ft dpm, circulate hole clean, pumping in reverse lay out joint under power swivel, rack back power swivel in derrick, pooh with 3-1/2 ph 6 work string Report Number 21 Report Start Date 12/26/2023 Report End Date 12/27/2023 Last 24hr Summary Cont. POOH stand back 3 1/2" wk string. f/4920', lay down tapered mill & string mill, pick up 8-1/4 packer mill, TIH with same on 3-1/2 PH 6 work string to 5,447 ft dpm, pick up power swivel, make connection, break circulation took 20 bbls to get returns, milling on 9-5/8 model D packer at 5,466 ft. dpm with 70 rpm, 1500 to 2500 ft/lbs torque, pumping 2 bpm at 264 psi, P/u wt. 52k ,RT wt. 46k ,S/O wt. 42k Field: Kenai Gas Field (KEU KGF) Sundry #: 323-639 State: ALASKA Rig/Service: R/up Yellow jacket E-line Run in hole with caliper logg, to 5,440' ELM uncorrelated lay out fish ooh laying down 2-7/8 ,6.4#, N-80 seal loc, tbg, no Corrosion or solids, laid downpg 165 joints, Latch onto fish at 5,272' top of fish, Bottom of fish at 5,467'. ,,gg pick up 6-5/8 bit, RIH to 5318 ' Cleanedgg , , gg j , gg out well f/ 5318 ft. to 5,469 ft. reverse circulate hole clean at 5,469 ft.. pp , milling on 9-5/8 model D packer at 5,466 ft. Page 3/4 Well Name: KU 021X-32 Report Printed: 2/8/2024www.peloton.com Alaska Weekly Report - Operations Report Number 22 Report Start Date 12/27/2023 Report End Date 12/28/2023 Last 24hr Summary Cont. Milling on packer @ 5466'. to 5,469', pumping at 3 bpm at 250 psi, with 70 rpm at 3000 to 5000 k ft/lbs tq, P/up wt 52k , RT wt 46k, S/o wt 42k, Lost power swivel HPU. trouble shoot same, call for back up, change out P/S HPU, continue milling on packer f/ 5,469' to 5,470' broke thru wash down to 5,475'. circulate , pooh pulling 10 /12 over pick up wt. lay out joint of work string, wash and back ream f/ 5,447 ft. to 5,322' laying out singles Report Number 23 Report Start Date 12/28/2023 Report End Date 12/29/2023 Last 24hr Summary Cont. POOH t/ 5291' clean, L/D swivel, cont. POOH stand back 3 1/2" wk string. Change out BHA, pick up spear, trip in hole, change out power tongs, continue in hole To 5,248', load pipe skate with pipe Report Number 24 Report Start Date 12/29/2023 Report End Date 12/30/2023 Last 24hr Summary Cont. RIH t/engage packer @ 5475', POOH no recovery, rig up and test BOPS to 250 & 2500 psi. Report Number 25 Report Start Date 12/30/2023 Report End Date 12/31/2023 Last 24hr Summary Test BOPE 250/2500, with 3 1/2" TJ. witness waived by AOGCC Inspector Jim Regg, P/U Spear BHA. on 3-1/2 work sting, to 5,248', change Quick release on clutch, continue in hole to 5,466', rig up to wash, wash down to 5,485' latch fish, pooh laying out singles pumping at 3 bpm at 275 psi, from 5,485' to 5,341' Report Number 26 Report Start Date 12/31/2023 Report End Date 1/1/2024 Last 24hr Summary Cont. POOH f/5348', stand back 3 1/2" wk string. and BHA No fish, called out slick line, Run slick line tools found fish at 5,384 ' slm, clean out Id of fish with bailers and Brush, ran 6" LIB tagged fish at 5384 slm continue in hole to 5484 slm, found fill on top of fish at 5484' slm, attempt to clean out fill (NO JOY) rig down slick line, Gather clean out BHA and make up same. Report Number 27 Report Start Date 1/1/2024 Report End Date 1/2/2024 Last 24hr Summary M/U cleanout BHA, 2 7/8" stinger w/mule shoe. TIH on 3-1/2 PH 6 work string to 5,460' install circulate head element, wash down to 5,472' dpm, took wt, continue to wash down to 5,486 dpm,stack 10k down, reciprocate pipe up and down pumping down tbg, then reverse out, wash back down in reverse set down 10/15k down and reverse circulate clean, remove circulating head element, pooh with 3.5 work string, lay out BHA, rig up E line RIH with, caliper log setting down at 5,489 ft ELM work tool did not get deeper, make several attempts to get deeper bottom of tool at 5,489' cailper fingers at 5,483 ELM, open caliper fingers to ( 7.03) (Max opening of caliper fingers) pooh inspect tool (good) Rerun caliper tool with same results, pooh rig down E-line Report Number 28 Report Start Date 1/2/2024 Report End Date 1/3/2024 Last 24hr Summary R/U wireline, RIH w/ 3.5" DD bailer tag @ 5503 WLM, work tool, POOH recover 1 cup of metal shavings an silt. RIH W/ Magnet, 4.5" Magnet and 5.9" Swedge T/5,502' MD Retrieved 1 cup metal shavings. Run 2, 3.6" Swedge T/5,502' MD. Marks on bottom and sides of Swedge. Run # 3: 5.9" Swedge & 2.63" Magnet T/5,502' MD. POOH with metal shavings. Run #4: RIH W/2.63" Magnet T/5,504' MD POOH W/Metal filings. Run # 5 RIH W/LIB Tag at 5,504' MD, POOH, Rig down Slickline. PJSM, Slip And Cut 54' of Drill Line. M/U Yellow Jacket Milling Assembly, 4.55' reverse mill, X-O, two pup joints, Double pin crossover, crossover String Mill 6.50" XO-Bit Sub-String Mill 8.30" XO-Bumper sub-Hyd Jar-4 X Spiral DC's-ACC & XO. Total length 195.58' Report Number 29 Report Start Date 1/3/2024 Report End Date 1/4/2024 Last 24hr Summary R/U swivel, Clean out F/5,484' MD - T/ 5,559' MD. Torque 1,500-3,400 ft/lbs. Ream and wash with difficulty from 5,559' - 5,567' Report Number 30 Report Start Date 1/4/2024 Report End Date 1/5/2024 Last 24hr Summary L/d swivel, POOH L/d BHA #10 RIH with BHA # 11. M/U power swivel, Install circulating head. Est parameters tag up with 2k. Torque limit set at 1,000 ft/lbs. Stall rotary, noted pump psi increase. 2k additional up-drag. Stand back power swivel. Prep for TOOH. Report Number 31 Report Start Date 1/5/2024 Report End Date 1/6/2024 Last 24hr Summary TOOH with BHA #11, No Fish. Make caliper run via wireline could not get past 5,567' MD. M/U cement bailer RIH W/ cement. Drop cement on top of packer. TOOH// Rig Down wireline. Prep for BOP Test. Report Number 32 Report Start Date 1/6/2024 Report End Date 1/7/2024 Last 24hr Summary Tested BOPE as per Sundry. AOGCC witness waived by Jim Regg. M/U Piranha Mill Assembly. TIH. Tag cement, Wash & Ream cleaning out cement to top of packer 5,567' MD. Begin to mill up packer, Report Number 33 Report Start Date 1/7/2024 Report End Date 1/8/2024 Last 24hr Summary Serviced rig and eq. wait on Saver Sub and Pup Jts from Tubo, make up same. Resume milling packer at 5,568' MD. Hole started taking fluid at 80 BPH. Pumped LCM pill. Lined up to pump down tubing resumed milling. Lined up to reverse circulate losses reappeared. Continue milling packer at 5,570' MD. Report Number 34 Report Start Date 1/8/2024 Report End Date 1/9/2024 Last 24hr Summary Contiue Milling Packer Debris down to 5570', TOH for BHA change. Field: Kenai Gas Field (KEU KGF) Sundry #: 323-639 State: ALASKA Rig/Service: y Clean out F/5,484' MD - T/ 5,559' MD. as Su a y Cont. RIH t/engage packer @ 5475', POOH no recovery No fish, M/U cement bailer RIH W/ cement. Drop cement on top of packerMake caliper run via wireline could not get past 5,567' MD. caliper log setting down at 5,489 ft ELM , found fill on top of fish at 5484' slm y RIH w/ 3.5" DD bailer tag @ 5503 WLM, work tool, POOH recover 1 cup of metal shavings an silt. ,g Continue milling packer at 5,570' MD. Page 4/4 Well Name: KU 021X-32 Report Printed: 2/8/2024www.peloton.com Alaska Weekly Report - Operations Report Number 35 Report Start Date 1/9/2024 Report End Date 1/10/2024 Last 24hr Summary RIH with bit, Could not pass 5,570' MD. Decision made to lay down workstring run kill string. R.D.M.O. Report Number 36 Report Start Date 1/10/2024 Report End Date 1/11/2024 Last 24hr Summary L/d BHA, RIH Set 2-7/8" Killstring 2,004' MD. Landed on hanger RILDS. Rig down rig floor, Remove power swivel. N/D BOP's Report Number 37 Report Start Date 1/11/2024 Report End Date 1/12/2024 Last 24hr Summary N/u dry hole tree, RDMO, stack rig in KGF Field: Kenai Gas Field (KEU KGF) Sundry #: 323-639 State: ALASKA Rig/Service: See email conditions of approval in wellfile. Pool 4 must be isolated from Pool 5.1 within 1 year to minimize crossflow. -bjm Sy RIH with bit, Could not pass 5,570' MD. Decision made to lay down workstring run kill string Lease: State: Country:USA Well Name & Number:Kenai Unit 21X-32 KGF, Pad 43-32 Prepared By:D Ambruz Last Revision Date: County or Parish: 02/08/24 AlaskaKenai Peninsula Borough KB @ 0' CIW Tbg Hanger @ 16.8' 20", 94# Conductor driven to 57' 13-3/8", 61#, K55 Csg @ 1,195' Casing 9-5/8", 40# K55 & N80 Csg @ 6,446' Cmt'd w/ 1570 sks Class "G" Existing Perfs B-1 5316'-5369' (53') 5391'-5398' ( 7') B-2 5416'-5425' ( 9') 5432'-5448' (16') B-3 5488'-5524' (36') RePerf B-2 5438'-5448' (10') B-3 5488'-5524' (36') KU 21X-32 Kenai Gas Field Pad 43-32 C SCHEMATIC TD 6,450' MD / 5,057' TVD PBTD 5,570' MD / 4,275' TVD' Kill String 2-7/8" 6.5# Sealwock @ 2,004' 1/10/24 Packer debris @ 5,570’ 1/9/24 Damaged casing @ 5,308'-5,358' milled to 8-1/4" 12/21/23 Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/25/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240125 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# HV B-12 50231200310000 207123 1/3/2024 Yellowjacket GPT-PERF HV B-13 50231200320000 207151 12/13/2023 Yellowjacket SCBL HV B-17 50231200490000 215189 1/4/2024 Yellowjacket GPT-PERF HV B-16A 50231200400100 222070 1/12/2024 Yellowjacket GPT-PERF KBU 22-06Y 50133206500000 215044 12/5/2023 Yellowjacket GPT-PERF KTU 43-6XRD2 50133203280200 205117 12/4/2023 YELLOWJACKET GPT-PERF KU 21X-32 50133202040000 169100 12/23/2023 AK E-Line CALIPER TBU M-11 50733205900000 210145 11/10/2023 AK E-Line PL/PERF Please include current contact information if different from above. T38451 T38452 T38453 T38454 T38455 T38456 T38457 T38458 1/31/2024 KU 21X-32 50133202040000 169100 12/23/2023 AK E-Line CALIPER Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.31 09:35:23 -09'00' CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. You don't often get email from anthony.knowles@hilcorp.com. Learn why this is important From:Brooks, Phoebe L (OGC) To:Anthony Knowles Cc:Regg, James B (OGC) Subject:RE: [EXTERNAL] RE: KU 21x-32 BOP test Form Date:Tuesday, January 30, 2024 12:04:06 PM Attachments:Fox 8 12-04-23 Revised.xlsx Thank you. I changed the Rig No. to reflect 8, added 250 to low test pressure for the Rams, and changed the test finish date to 12/4/23 (instead of 12/1/23). Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Anthony Knowles <Anthony.Knowles@hilcorp.com> Sent: Thursday, January 25, 2024 10:30 PM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: RE: [EXTERNAL] RE: KU 21x-32 BOP test Form Phoebe, I apologize for missing the same boxes. I’ve update and returned the sheet with corrections. The workover operation is checked. BOP MISC is corrected & the Pressure after closure has been updated. Again, I apologize for the oversights. Anthony From: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Sent: Thursday, January 18, 2024 3:05 PM To: Anthony Knowles <Anthony.Knowles@hilcorp.com> Subject: [EXTERNAL] RE: KU 21x-32 BOP test Form The Pressure After Closure was left blank; please advise. Phoebe Brooks Research Analyst <ĞŶĂŝhŶŝƚϮϭyͲϯϮ WdϭϲϵϭϬϬϬ changed the Rig No. to reflect 8 added 250 to low test pressure for the Rams changed the test finish date 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. Some people who received this message don't often get email from anthony.knowles@hilcorp.com. Learn why this is important Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Anthony Knowles <Anthony.Knowles@hilcorp.com> Sent: Thursday, December 7, 2023 9:22 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: KU 21x-32 BOP test Form Anthony Knowles Well Site Supervisor Prudhoe Bay | Alaska Hilcorp Alaska, LLC Office: (907) 659-5580 Cellular: (907) 227-2297 Harmony: 2382 anthony.knowles@hilcorp.com alternate: Dan Scarpellla 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. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSub m it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:8 DATE: 12/4/23 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #11691000 Sundry #323-639 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3000 Annular: Valves:250/3000 MASP:1082 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 0NA Test Fluid Water Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 2 1.75" Hydrolic P Trip Tank NA P Annular Preventer 0NAPit Level Indicators NA P #1 Rams 1 Blind/Shear P Flow Indicator NA P #2 Rams 1 1-3/4" Pipe/Slip P Meth Gas Detector NA P #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 2 2"P Time/Pressure Test Result HCR Valves 0NASystem Pressure (psi)3000 P Kill Line Valves 2 2"P Pressure After Closure (psi)2350 P Check Valve 0NA200 psi Attained (sec)4 P BOP Misc 0NAFull Pressure Attained (sec)18 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4/1000 psi P No. Valves 5P ACC Misc 0NA Manual Chokes 2P Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 0 NA #1 Rams 29 P Coiled Tubing Only:#2 Rams 25 P Inside Reel valves 1P #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:2.0 HCR Choke 0 NA Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/03/23 10:44AM Waived By Test Start Date/Time:12/4/2023 14:00 (date) (time)Witness Test Finish Date/Time:12/4/2023 16:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Fox Test w/ freash water. Bottle precharge - 1350 psi. Recieved waive of witness from Jim Regg via email on 12/03 14:08 Jeremy Hart Hilcorp Alaska LLC. Anthony Knowles KU 21x-32 Test Pressure (psi): jeremyhart76@gmail.com anthony.knowles@hilcorp.com Form 10-424 (Revised 08/2022)2023-1204_BOP_Fox8_KU_21X-32 9 9 9 9 99 9 9 9 9 9 MEU -5HJJ 1 Junke, Kayla M (OGC) From:Brian Glasheen <Brian.Glasheen@hilcorp.com> Sent:Thursday, January 11, 2024 8:58 AM To:McLellan, Bryan J (OGC); Roby, David S (OGC) Cc:Donna Ambruz; Rixse, Melvin G (OGC) Subject:RE: [EXTERNAL] RE: KU 21X-32 AOGCC 10-403 323-639 PTD 169-100 Approved 12-01-23 Bryan, I have emailed our Well integrity ENGR Casey and he will include it on his regulatory tracking sheet to ensure it does not fall through the cracks. Thanks, Brian Glasheen Ops Engineer 907‐545‐1144 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, January 10, 2024 4:23 PM To: Roby, David S (OGC) <dave.roby@alaska.gov>; Brian Glasheen <Brian.Glasheen@hilcorp.com> Cc: Donna Ambruz <dambruz@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] RE: KU 21X‐32 AOGCC 10‐403 323‐639 PTD 169‐100 Approved 12‐01‐23 Brian, Could you confirm what Hilcorp will do to make sure the commitment to isolate the pools within a year does not fall through the cracks? Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: McLellan, Bryan J (OGC) Sent: Wednesday, January 10, 2024 3:38 PM To: Roby, David S (OGC) <dave.roby@alaska.gov>; Brian Glasheen <Brian.Glasheen@hilcorp.com> CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 Cc: Donna Ambruz <dambruz@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: KU 21X‐32 AOGCC 10‐403 323‐639 PTD 169‐100 Approved 12‐01‐23 Brian, Could you send the proposed wellbore diagram? Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Roby, David S (OGC) <dave.roby@alaska.gov> Sent: Wednesday, January 10, 2024 2:02 PM To: Brian Glasheen <Brian.Glasheen@hilcorp.com> Cc: Donna Ambruz <dambruz@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: KU 21X‐32 AOGCC 10‐403 323‐639 PTD 169‐100 Approved 12‐01‐23 Hi Brian, Your proposal to install a kill string and move off this well while two pools have open perfs and there’s no barrier to crossflow between these pools in the wellbore so that you can determine future plans for the well is acceptable to the AOGCC with the condition you state in the email below. Regards, Dave Roby (907)793‐1232 From: Brian Glasheen <Brian.Glasheen@hilcorp.com> Sent: Wednesday, January 10, 2024 9:00 AM To: Roby, David S (OGC) <dave.roby@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: RE: KU 21X‐32 AOGCC 10‐403 323‐639 PTD 169‐100 Approved 12‐01‐23 Dave, Do you mind replying and acknowledging our phone conversation that you agree to the plan below and if we do not pursue the below options, we will work to isolate each pool within a year? CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 3 Thanks Brian Glasheen Ops Engineer 907‐545‐1144 From: Brian Glasheen Sent: Tuesday, January 9, 2024 11:17 AM To: Roby, David S (CED) <dave.roby@alaska.gov> Subject: FW: KU 21X‐32 AOGCC 10‐403 323‐639 PTD 169‐100 Approved 12‐01‐23 Brian Glasheen Ops Engineer 907‐545‐1144 From: Brian Glasheen <Brian.Glasheen@hilcorp.com> Sent: Tuesday, January 9, 2024 10:42 AM To: melvin.rixse@alaska.gov Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: FW: KU 21X‐32 AOGCC 10‐403 323‐639 PTD 169‐100 Approved 12‐01‐23 Morning Mel, I hear you are covering for Bryan while he is out. We have reached a stopping point on KU21X‐32 and wanted to talk to you about the plan forward. We encountered an obstruction that we have not be able to get through at 5571’MD. Our target depth was 6300’MD. HC plans to run a kill string to 2000’ and will evaluate the well via non rig. There is a sidetrack option we would like to consider in the future and or resume rig activity after we get a clear picture of the obstruction at 5571’ MD. Please let me know if you have any issues with the plan above. Thanks Brian Glasheen Ops Engineer 907‐545‐1144 From: Donna Ambruz <dambruz@hilcorp.com> Sent: Friday, December 1, 2023 1:17 PM To: Brian Glasheen <Brian.Glasheen@hilcorp.com> Cc: Noel Nocas <Noel.Nocas@hilcorp.com> Subject: KU 21X‐32 AOGCC 10‐403 323‐639 PTD 169‐100 Approved 12‐01‐23 FYI – Please distribute as necessary. Thank you. 4 Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 ‐ Direct dambruz@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. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wade Hudgens To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay Cc:Donna Ambruz; Juanita Lovett Subject:HAK 401/KU 21x-32/BOPE Test Report/1-6-2024 Date:Sunday, January 7, 2024 5:59:25 PM Attachments:HAK 401 1-6-2024.xlsx Please see attached BOPE Test Report for HAK 401. Thanks, Wade Hudgens Well Site Supervisor-Ken (903) 331-6711 – C wade.hudgens@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. .HQDL8QLW; 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:401 DATE: 1/6/24 Rig Rep.: Brad Whitten/Ed Castagne Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #1691000 Sundry #323-639 Operation: Drilling: Workover: x Explor.: Test: Initial: Weekly: x Bi-Weekly: Other: Rams:250-2500 Annular:250-2500 Valves:250-2500 MASP:1082 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.NA Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 13-5/8" 5M P Pit Level Indicators PP #1 Rams 1 2-7/8"x5-1/2" var P Flow Indicator NA NA #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 4-1/16" 5M P Time/Pressure Test Result HCR Valves 1 4-1/16" 5M P System Pressure (psi)3000 P Kill Line Valves 3 4-1/16" 5M P Pressure After Closure (psi)1950 P Check Valve 0NA200 psi Attained (sec)25 P BOP Misc 0NAFull Pressure Attained (sec)106 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 @ 1950 P No. Valves 8P ACC Misc 0NA Manual Chokes 2P Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 29 P #1 Rams 9 P Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 0NA #3 Rams NA #4 Rams NA Test Results #5 Rams NA #6 Rams NA Number of Failures:0 Test Time:3.5 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 1/5/2024 7:04 AM Waived By Test Start Date/Time:1/6/2024 6:30 (date) (time)Witness Test Finish Date/Time:1/6/2024 10:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp Tested with 3 1/2" Test Joint HAK Wade Hudgens/Mark Brouillet KU 21x-32 Test Pressure (psi): wade.hudgens@hilcorp.com wade.hudgens@hilcorp.com Form 10-424 (Revised 08/2022) 2024-0106_BOP_Hilcorp401_KU_21X-32 9 9 9 9 9 9 9 9 9 9 9 MEU -5HJJ CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Harold Soule - (C) To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Donna Ambruz; Juanita Lovett Subject:HAK 401 12-30-23 Date:Sunday, December 31, 2023 8:43:53 AM Attachments:HAK 401 12-30-23.xlsx Thanks Harold Soule Cell 907-227-9400 401 Office 907-283-2580 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. .HQDL8QLW; 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmitt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:401 DATE: 12/30/23 Rig Rep.: Brad Whitten/Ed Castagne Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #1691000 Sundry #323-639 Operation: Drilling: Workover: x Explor.: Test: Initial: Weekly: x Bi-Weekly: Other: Rams:250-2500 Annular:250-2500 Valves:250-2500 MASP:1082 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.NA Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 13-5/8" 5M P Pit Level Indicators PP #1 Rams 1 2-7/8"x5-1/2" var P Flow Indicator NA NA #2 Rams 1 Blinds P Meth Gas Detector NT NT #3 Rams 0NAH2S Gas Detector NT NT #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 4-1/16" 5M FP Time/Pressure Test Result HCR Valves 1 4-1/16" 5M P System Pressure (psi)3000 P Kill Line Valves 3 4-1/16" 5M P Pressure After Closure (psi)1900 P Check Valve 0NA200 psi Attained (sec)22 P BOP Misc 0NAFull Pressure Attained (sec)110 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 @ 1900 P No. Valves 8P ACC Misc 0P Manual Chokes 2P Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 28 P #1 Rams 9 P Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 0NA #3 Rams NA #4 Rams NA Test Results #5 Rams NA #6 Rams NA Number of Failures:1 Test Time:3.5 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/28/23 6:22 PM Waived By Test Start Date/Time:12/30/2023 7:00 (date) (time)Witness Test Finish Date/Time:12/30/2023 10:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp Tested with 3 1/2" Test Joint, had on FP on inside choke line valve, service & re-test good. Tested Gas alarms 12-21-23 Hilcorp Alaska LLC Harold Soule/Ed Hooter KU 21x-32 Test Pressure (psi): hsoule@hilcorp.com wade.hudgens@hilcorp.com Form 10-424 (Revised 08/2022) 2023-1230_BOP_Hilcorp401_KU_21X-32 9 9 9 9 9 9 9 99 9 9 9 9 9 9 9 MEU 9 -5HJJ FP FP on inside choke line valve CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Harold Soule - (C) To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Donna Ambruz Subject:Hak 401 12-23-23 Date:Sunday, December 24, 2023 8:28:58 AM Attachments:HAK 401 12-23-23.xlsx Thanks Harold Soule Cell 907-227-9400 401 Office 907-283-2580 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. .HQDL8QLW; 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:401 DATE: 12/23/23 Rig Rep.: Brad Whitten/Kevin Reed Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #1691000 Sundry #323-639 Operation: Drilling: Workover: x Explor.: Test: Initial: Weekly: x Bi-Weekly: Other: Rams:250-2500 Annular:250-2500 Valves:250-2500 MASP:1082 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.NA Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 13-5/8" 5M P Pit Level Indicators PP #1 Rams 1 2-7/8"x5-1/2" var P Flow Indicator NA NA #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 4-1/16" 5M P Time/Pressure Test Result HCR Valves 1 4-1/16" 5M P System Pressure (psi)3000 P Kill Line Valves 3 4-1/16" 5M P Pressure After Closure (psi)2000 P Check Valve 0NA200 psi Attained (sec)24 P BOP Misc 0NAFull Pressure Attained (sec)100 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 @ 2000 P No. Valves 8P ACC Misc 0P Manual Chokes 2P Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 28 P #1 Rams 8 P Coiled Tubing Only:#2 Rams 8 P Inside Reel valves 0NA #3 Rams NA #4 Rams NA Test Results #5 Rams NA #6 Rams NA Number of Failures:0 Test Time:4.0 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/21/23 7:31 AM Waived By Test Start Date/Time:12/22/2023 23:30 (date) (time)Witness Test Finish Date/Time:12/23/2023 3:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp Tested with a 2-7/8" & 3 1/2" Test Joint, Tested Gas alarms 12-21-23 HAK Harold Soule/Ed Hooter KU 21x-32 Test Pressure (psi): hsoule@hilcorp.com wade.hudgens@hilcorp.com Form 10-424 (Revised 08/2022) 2023-1223_BOP_Hilcorp401_KU_21X-32 99 9 9 9 9 99 9 9 9 MEU -5HJJ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KENAI UNIT 21X-32 JBR 03/01/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 2-7/8 joint Test Results TEST DATA Rig Rep:Whitten/ReedOperator:Hilcorp Alaska, LLC Operator Rep:Hudgens/Hooter Rig Owner/Rig No.:Hilcorp 401 PTD#:1691000 DATE:12/15/2023 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopSAM231217132516 Inspector Austin McLeod Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 3 MASP: 1082 Sundry No: 323-639 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.NA Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 8 PNo. Valves 2 PManual Chokes 0 NAHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8 P #1 Rams 1 2-7/8"x5-1/2"P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 4-1/16"P HCR Valves 1 4-1/16"P Kill Line Valves 3 4-1/16"/2-1/16 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P2000 200 PSI Attained P25 Full Pressure Attained P95 Blind Switch Covers:PAll stations Bottle precharge P Nitgn Btls# &psi (avg)P6@2050 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P26 #1 Rams P8 #2 Rams P8 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill NA0       1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: * N2 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 6,446'5,570' Casing Collapse Structural Conductor Surface 1,540psi Intermediate Production 3,090psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Well shall be used only for production from the gas storage pool unless the requirements of SIO 7A and 20 AAC 25.252 are met. Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 907-564-5277 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writte n approval. Authorized Name and Digital Signature with Date: PRESENT WELL CONDITION SUMMARY Brian Glasheen, Operations Engineer AOGCC USE ONLY Tubing Grade: 6.4# / N-80 brian.glasheen@hilcorp.com Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028055 169-100 50-133-20204-00-00 Tubing Size: 2-7/8" LS Hilcorp Alaska, LLC Proposed Pools: 57'57' 6.4# / N-80 TVD Burst 5484' 5,750psi 1,152' Size 1,195' MDLength See Attached Schematic 3,090psi1,195' Tubing MD (ft): 5261' November 27, 2023 2-7/8" LS 57'20" 6,446' Perforation Depth MD (ft): Kenai Sterling 4 & Sterling 5.1 Gas 13-3/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Kenai Unit (KU) 21X-32CO 510C Sterling 6 Gas Storage 5,053' Storage Pool Report Code is 448809. RH-2 Dual Pkr, Baker Mod D Pkr w seal assy and locator; N/A 5,253' MD/TVD, 5,467' MD/ TVD; N/A, N/A 5,053'5,570'4,275' 9-5/8" ~1082psi 6,446' N/A m n P s 66 t 2 N *Convert to Gas Storage Production Well Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:55 am, Nov 22, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.11.21 16:45:41 - 09'00' Noel Nocas (4361) 323-639 Perforate New Pool P SFD 11/27/2023 Storage Pool Report Code is 448809. Gas Storage X November 27, 2023 Well shall be used only for production from the gas storage pool unless the requirements of SIO 7 A and 20 AAC 25.252 are met. and sundry approval for injection is obtained. 10-404 BOP test to 2500 psi. Submit 7" CBL results to AOGCC and obtain approval before perforating. 6450' * * From Completion Report dated 12/15/69 SFD DSR-11/22/23 Nov 22, 2023 Yes for CT contingency 12/1/23 Bryan McLellan CT BOP test to 2500 psi. BJM 12/1/23 *&:JLC 12/1/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.12.01 12:28:17 -09'00'12/01/23 RBDMS JSB 120423 Recomplete Well: KU 21x-32 Date: 11/15/23 Well Name: KU 21x-32 API Number: 50-133-20204-00-00 Current Status: SI gas well Permit to Drill Number: 169100 Estimated Start Date: 12/1/2023 Rig: 401 workover rig, Eline, coil First Call Engineer: Brian Glasheen 9075451144 Second Call Engineer: Chad Helgeson (907) 229-4824 (C) AFE Number: Job Type:Recomplete Current Bottom Hole Pressure: 1500 psi @ 4181’ TVD (Assumption SBHP will be obtained 6.9 ppg EMW) Maximum Expected BHP: 1500 psi @ 4181’ TVD (New perfs being added but lower pressure pool 6 ~ 245 psi) MPSP: 1082 psi (0.1 psi/ft gas gradient) Brief Well Summary: KU 21X-32 was brought online in 1969 targeting the Sterling Pool 4 & 5 with a dual string design. Peak production rates reached 20 MMCFD in 1971. Pool 4 & 5 allocated production rates were split 50/50 until 1984 when the long string (Pool 5) was shut in. Pool 4 (short string) remained on-line until 2006 when the well was taken off line due to water & sand production. Notes Regarding Wellbore Condition x SL drifted 5256’ SLM on the short string x SL drifted 5354’ SLM on the long string Objective: The purpose of this work is remove both packers, isolate Sterling Gas Pool 4 and Sterling Gas Pool 5.1 with cement and install new 7’’ tubing cemented in place to allow pool 6 production. Will only be used as a producer. Top’s : Defined by KU 21-06 Sterling Pool 4: Top 5313’ MD (4058’ TVD), Base: 5461’ MD (4181’ TVD) Sterling Pool 5.1: Top 5461’ MD (4181’ TVD), Base: 5727’ MD (4413’ TVD) Sterling Pool 5.2: Top 5727’ MD (4413’ TVD), Base: 6037’ MD (4688’ TVD) Sterling Pool 6: Top 6037’ MD (4688’ TVD), Base: 6300’ MD (4923’ TVD) Non-Sundry work SL: 1. RU to short string. Test lubricator to 250/3,000 psi. 2. SBHP 3. RU to Long string. Test lubricator to 250/3,000 psi. 4. Bail to PX plug 5. Pull PX plug 6. Drift to TD 7. SBHP Sterling Pool 6: Top 6037’ MD (4688’ TVD), install new 7’’ tubing cemented in place to allow pool 6 production. Will only be used as a producer. Recomplete Well: KU 21x-32 Date: 11/15/23 8. Shift sleeve open at 5460’ MD in LS Sundry work Coil Contingency: 1. RU to Long string. Test lubricator to 250/3,000 psi. 2. RIH with 1.75’’ nozzle and clean out to PX plug 3. Pull PX plug 4. RIH tag TD. Attempt to clean out if tag is high to TD. 5. RU to Short string. Test lubricator to 250/3,000 psi. 6. RIH with 1.75’’ nozzle tag top of fill or packer SL if not able to bail to PX plug: 1. RU to Long string. Test lubricator to 250/3,000 psi. 2. SBHP 3. Shift sleeve open at 5460’ MD Eline: 1. RU to Long string. Test lubricator to 250/3,000 psi. 2. Cut tubing at 5272’ MD (5’ below first full joint below dual packer.) 3. SWAP to SS 4. RU to Short string. Test lubricator to 250/3,000 psi. 5. Cut tubing at 5245’ MD (5’ above first full joint above dual packer.) Recomplete Well: KU 21x-32 Date: 11/15/23 Recomplete Well: KU 21x-32 Date: 11/15/23 Recomplete Well: KU 21x-32 Date: 11/15/23 Pre-Rig Procedure: 7. Circulate at least one wellbore volume through both the SS an LS with 8.5 ppg KCL/ Produced water down tubing, taking returns up casing. Brief RWO Procedure: 8. MIRU 401 WO Rig, ancillary equipment, and lines. 9. Set BPV in SS and LS. ND Tree. NU BOPE 10. Provide AOGCC 24 hrs in advance of BOP test 11. Test to 2000 psi with 2-7/8’’ and 3-1/2’’ test joints 12. Bleed any pressure off tubing and casing. Pull BPV. Kill well as needed. 13. MU landing joint or spear and BOLDS. 14. PU on the SS tubing hanger (Tubing has been cut and should be free to move) . 15. Recover the tubing hanger. 16. POOH and lay down the 2-7/8” tubing. a. Tubing will be inspected. 17. PU on the LS tubing hanger. 18. Attempt to pull tubing in the LS. a. Do not exceed 80 percent of 2-7/8” tubing. b. Packer is straight pull to release, pick up and release packer per vendor recommendations. c. Once packer releases stop and wait for 30 minutes to allow packer elements to relax. While waiting on packer elements, circulate at max rate down the tubing taking returns up the annulus a min of 2 bottoms up and expect packer gas to return. Close annular during this time taking returns to pits. If no returns are seen at surface while pumping continue to pump 2 bottoms up and allow the gas to migrate to surface. Wait 2-4 hours while maintaining hole fill down the tubing to allow gas to migrate to surface before POOH. 19. Recover the tubing hanger. 20. POOH and lay down the 2-7/8” tubing. a. Tubing will be inspected. 21. RIH with Yellow jacket fishing BHA 22. Latch 2-7/8’’ tubing stub and attempt to pull tubing out of packer seal assembly. 23. POOH and lay down the 2-7/8” tubing. 24. RIH and remove packer from 5467’ MD. ( POOH with packer and or push below 6,300 MD) 25. RU Eline a. RIH with 9-5/8’’ CIBP OD gauge ring b. RIH and Caliper well from TD to Surface c. RIH and set 9-5/8’’ plug at 5530’ MD d. RIH and set 9-5/8’’ cement retainer at 5460’ MD e. POOH 26. RIH to top of retainer and establish baseline WHP RIH w/ cement stinger on 2-7/8" work string per Brian Glasheen email 11/29/23 attached. BOP test to 2500 psi. -bjm Recomplete Well: KU 21x-32 Date: 11/15/23 27. RIH and sting in to cement retainer and pump cement until 1000 psi above base line injection WHP or 21 bbls of cement is pumped. 28. Un-sting from cement retainer. 29. POOH to 5000’MD 30. With nozzle at 5000’ MD, park and continue to pump cement until either 1) 20 bbls of cement remains in the WS or 2) a 1000 psi squeeze (over baseline injecting WHP) has been achieved. If 1000 psi squeeze is achieved a. Cut cement at surface, open choke, and lay in remaining cement in the tubing 1:1. b. With nozzle at safety, continue displacing cement into well until cement top is at ~5100’ MD or until 2000 psi squeeze (over baseline static WHP) has been achieved. c. Hold final squeeze pressure for 60 mins. d. Clean out cement back down to 5100’ with powervis. Plan to have at least 130 bbls of powervis contaminate on location. e. Keep choke pressure at ~50-75 psi above baseline WHP. If 1000 psi squeeze is not achieved. f. If after pumping all cement on location, 1000 psi bump is not achieved, open choke and lay in remaining 20 bbls of cement in the liner, 1:1, and PUH to safety. g. With nozzle at safety, perform a hesitation squeeze over the course of 60 minutes until cement has been down squeezed to ~5100’ MD. h. Hold final squeeze pressure for 60 mins (if time allows). 31. POOH 32. RIH with storm packer and set at 100’, test to 500 psi. 33. ND BOP, ND wellhead, Install new wellhead, Pressure test wellhead void, NU BOP, set test plug and test BOP’s. 34. RIH and pull 9-5/8’’ test/storm packer. 35. RIH with milling BHA and mill down to TD or below 6300’ MD. 36. Change out handling equipment, install casing crew tongs, and upper rams for handling 7” casing. 37. Perform BOP test on the 7” pipe rams on 7” test joint. 38. PU new 7’’ completion and RIH Colors indicate assemblies to be bucked up prior to RWO. Nom. Size ~Length Item Material Notes 7' Float L-80 7'' Joints L-80 7'' Space out PUPS L-80 7'' 1 joint L-80 7'' PUP L-80 Pressure test to 1500 psi. -bjm Will have 120 bbls of cement on hand to work with. Plan to pump enough to pressure up and then leave TOC at 5100 inside tubing to mill in future steps. -bjm Includes float shoe, 2 jts, float collar per Brian Glasheen email 11/29/23 -bjm Recomplete Well: KU 21x-32 Date: 11/15/23 7'' Tubing Hanger L-80 39. Space out and land the hanger. 40. Note PU (Pick Up) and SO (Slack Off) weights on tally. 41. RILDS. Lay down landing joint. 42. Prepare to cement 7’’ tubing in place. 43. Ensure 1:1 returns 44. Circulate corrosion inhibited brine between 7 X 9-5/8” annulus 45. Pump ~ 56-60 bbls cement and place between 7 X 9-5/8”to achieve TOC ~ 4316’MD (1000 feet above old perfs) 46. WOC 47. RU ELINE a. Perform CBL from TD to 3000’MD 48. Pressure up and test the 7’’ tubing to 1500 psi for MIT-T. Bleed off the tubing. Test the annulus to 1500 psi. Record and notate all pressure tests (30 minutes) on chart. 49. ND BOP, NU tree and test 50. RDMO Rig 401. Post-Rig Procedure: Coil: 1. RU Coil. Test lubricator to 250/3,000 psi. 2. Swap well over to N2. Reverse lift fluid from well. 3. RDMO Eline: 1. RU Eline. Test lubricator to 250/2,000 psi. 2. Perforate the below sands in pool 6 from the bottom up: 3. Pool Sand Top MD Btm. MD Feet Pool 6 Pool 6 C1 lower 6081 6138 57 Pool 6 Pool 6 C1 Upper 6039 6071 32 4. RDMO Perform CBL from TD to 3000’MD Submit results to AOGCC and obtain approval before perforating. - bjm Pump ~ 56-60 bbls cement and place between 7 X 9-5/8”to achieve TOC ~ 4316’MD (1000 feet above old perfs) Recomplete Well: KU 21x-32 Date: 11/15/23 Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Rig BOPE 401 Diagram 4. Existing Tree/Wellhead 5. Proposed Tree/Wellhead 6. Coil BOP Diagram 7. Nitrogen SOP 8. Blank RWO Changes Form Lease: State: Country:USA Kenai Unit 21X-32 KGF, Pad 43-32 Prepared By:Kevin Skiba Last Revision Date: County or Parish: 08/01/08 AlaskaKenai Peninsula Borough Well Name & Number: KB @ 0' CIW Tbg Hanger @ 16.8' 20", 94# Conductor driven to 57' 13-3/8", 61#, K55 Csg @ 1,195' Casing 9-5/8", 40# K55 & N80 Csg @ 6,446' Cmt'd w/ 1570 sks Class "G" TD 6,446' Existing Perfs B-1 5316'-5369' (53') 5391'-5398' ( 7') B-2 5416'-5425' ( 9') 5432'-5448' (16') B-3 5488'-5524' (36') RePerf B-2 5438'-5448' (10') B-3 5488'-5524' (36') KU 21X-32 Kenai Gas Field Pad 43-32 C 3 6 7 4 5 2 B 8 Short String Tbg Detail A. 2-7/8", 6.4# , N80 Tbg B. CX Mandrel @ 5181.04' Opened? 9/25/02 C. Mod RH-2 Dual PKR @ 5252.73' D. End No Go Nipple @ 5261.43'C D Long String Tbg Detail 1. 2-7/8", 6.4# , N80 Tbg 2. CX Mandrel @ 5210.07' 3. Mod RH-2 Dual PKR @ 5249.62' * Dogleg @ 5290' MD on 12/21/00 4. Blast Jts 5,298.27'-5,460.23' 5. CX Mandrel @ 5,460.23' 6. Baker Mod "D" PKR w/ Seal Asy and Locator @ 5,467.27' 7. "X" Landing Nipple @ 5472.75' *Set PX Plug on 12/21/00 8. EOT @ 5,484.13' SCHEMATIC Lease: State: Country:USAKenai Peninsula Borough Well Name & Number:Kenai Unit 21X-32 KGF, Pad 43-32 Prepared By:D Ambruz Last Revision Date: County or Parish: 11/10/23 Alaska KB @ 0' CIW Tbg Hanger @ 16.8' 20", 94# Conductor driven to 57' 13-3/8", 61#, K55 Csg @ 1,195' Casing 9-5/8", 40# K55 & N80 Csg @ 6,446' Cmt'd w/ 1570 sks Class "G" TD 6,446' New Perfs 6,081 6,138 6,039 6,071 Existing Perfs B-1 5316'-5369' (53') 5391'-5398' ( 7') B-2 5416'-5425' ( 9') 5432'-5448' (16') B-3 5488'-5524' (36') RePerf B-2 5438'-5448' (10') B-3 5488'-5524' (36') KU 21X-32 Kenai Gas Field Pad 43-32 Ct 3 6 7 5 8 Tbg Detail 7'' Tubing PROPOSED SCHEMATIC Target depth for 7" casing is ~6300-6400' MD. Kenai Gas Field KBU 21X-32 BOP Rig 401 11/14/2023 Choke and Kill valves 2 1/16 5M Mud Cross 4-1/16" 5M EFO Schrader 13 5/8-5000 Shaffer SL 2 7/8-5 ½’’ variables Blind 2-7/8” -5-1/2” variables and/or 7” pipe rams Kenai Gas Field KU 21X-32 Current 11/03/2023 Tree assy, dual block, CIW-F, 11 5M X 2 9/16 5M X 2 9/16 5M, prepped on 4 ½ center, 2 1/2'’ CIW seal pockets, ½ npt control line exits Casing head, CIW-WF, 13 5/8 3M FE top x 13 3/8 SOW btm, w/ 2- 2 1/16 5M EFO Valve, Ball type, 2 1/16 3M, HWO Tubing head, CIW-DCB, 13 5/8 3M x 11 3M, w/ 2- 2 1/16 5M SSO, X bottom prep Valve, CIW, 2 1/16 5M, HWO 13 3/8'’ 9 5/8'’ 2 7/8'’ 2 7/8'’ Tubing hanger, dual, CIW- DCB, 11 5M X 2 7/8 EUE 8rd lift X susp, w/ 2 1/2'’ type H BPV profile, 1/8 non cont control line ports in hangers Kenai Gas Field KU 21x-32 20 X 13 3/8 X 9 5/8 X 2 7/8 X 2 7/8 Kenai Gas Field KU 21X-32 Proposed 7’’ 11/14/2023 Valve, Ball type, 2 1/16 3M, HWO 13 3/8'’ 9 5/8'’ Casing head, CIW-WF, 13 5/8 3M FE top x 13 3/8 SOW btm, w/ 2- 2 1/16 5M EFO Tubing head, Cactus HPS, 13 5/8 3M x 11 5M, w/ 2- 2 1/16 5M SSO, HPS bottom prep Kenai Gas Field KU 21x-32 20 X 13 3/8 X 9 5/8 X 7 Valve, Master, WKM-M, 7 1/16 5M FE, HWO, EE trim Valve, Upper master, WKM-M, 7 1/16 5M FE, HWO, EE trim Valve, Swab, WKM-M 7 1/16 5M FE, HWO, EE trim BHTA, Otis, 7 1/16 5M FE x 9.5 Otis quick union top 7'’ Valve, Wing, SSV, WKM-M, 4 1/16 5M or 3 1/8 5M FE, w/ 15'’ Hydraulic operator Casing hanger, CW, 11 x 7'’ BTC box btm x 7.625'’ RH stub acme box top, w/ 9'’ od neck, 6 3/4'’ Cactus BPV profile, DD-NL material STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. H i l c o r p A l a s k a , L L C Hi l c o r p A l a s k a , L L C Ch a n g e s t o A p p r o v e d R i g W o r k O v e r S u n d r y P r o c e d u r e Su b j e c t : C h a n g e s t o A p p r o v e d S u n d r y P r o c e d u r e f o r W e l l K U 2 1 X - 3 2 ( P T D 1 6 9 - 1 0 0 ) Su n d r y # : X X X - X X X An y m o d i f i c a t i o n s t o a n a p p r o v e d s u n d r y w i l l b e d o c u m e n t e d a n d a p p r o v e d b e l o w . C h a n g e s t o a n a p p r o v e d s u n d r y w i l l b e c o m m u n i c a te d t o t h e AO G C C by t h e r i g w o r k o v e r ( R W O ) “ f i r s t c a l l ” e n g i n e e r . A O G C C w r i t t e n a p p r o v a l o f t h e c h a n g e i s r e q u i r e d b e f o r e i m p l e m e n t i n g t h e c h a n g e . Se c Pa g e Da t e Pr o c e d u r e C h a n g e Ne w 4 0 3 Re q u i r e d ? Y / N HA K Pr e p a r e d By (I n i t i a l s ) HA K Ap p r o v e d By (I n i t i a l s ) AO G C C W r i t t e n Ap p r o v a l R e c e i v e d (P e r s o n a n d D a t e ) Ap p r o v a l : A s s e t T e a m O p e r a t i o n s M a n a g e r D a t e Pr e p a r e d : F i r s t C a l l O p e r a t i o n s E n g i n e e r D a t e CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Brian Glasheen To:McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL] KU 24X-32 (PTD169-100) RWO sundry Date:Wednesday, November 29, 2023 4:06:54 PM Here are the answers listed below. Thanks and let me know if you have any other questions. I would like to get the coil work started ASAP if possible. Brian Glasheen Ops Engineer 907-545-1144 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, November 27, 2023 4:22 PM To: Brian Glasheen <brian.glasheen@hilcorp.com> Subject: [EXTERNAL] KU 24X-32 (PTD169-100) RWO sundry Brian, A few questions about this sundry. 1. Where is the planned bottom of 7” liner? It’s not written on the proposed wellbore diagram. ~ 6300-6400 MD 2. What are you running in hole with in step 26? 2-7/8’’ Work string with cement retainer BHA 3. What volume of cement are you planning to pump in step 27? We will have 120 bbls of cement on hand. Plan is to pump enough cement to pressure up and then leave cement ~ 5100 to mill in following steps. 4. Why aren’t you running a float collar/float shoe and dropping a wiper plug like on a normal cementing job in step 45? You are gonna end up with a bunch of contaminated cement and likely over-displace if you do it as written. I recommend speaking to a drilling engineer about how to set up this cement job. This is likely what the bottom of our 7’’ will consist of to allow for a good cement job with two plugs being dropped. 7-” Float Shoe 1 joint 1 joint – 7” Float Collar Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 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. 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From:McLellan, Bryan J (OGC) To:Brian Glasheen Subject:RE: KU 21X-32 AOGCC 10-403 PTD 169-100 Submitted 11-22-23 - Sundry Application Date:Friday, December 1, 2023 8:34:00 AM Attachments:image003.png Brian, Hilcorp has verbal approval to perform the CT work listed below as part of the sundry application received on Nov 22, 2023. FYI, this sundry will have number 323-639. Condition of approval: CT BOP test to 2500 psi. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Brian Glasheen <Brian.Glasheen@hilcorp.com> Sent: Friday, December 1, 2023 8:20 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: FW: KU 21X-32 AOGCC 10-403 PTD 169-100 Submitted 11-22-23 - Sundry Application Morning Bryan, Could I get a quick approval to do this coil contingency work below to help me prep for the RWO. We were unable to get the PX plug out and it will now require some coil work. Brian Glasheen Ops Engineer 907-545-1144 From: Donna Ambruz <dambruz@hilcorp.com> Sent: Wednesday, November 22, 2023 8:33 AM To: aogcc.permitting@alaska.gov Cc: Brian Glasheen <Brian.Glasheen@hilcorp.com>; Noel Nocas <Noel.Nocas@hilcorp.com> Subject: KU 21X-32 AOGCC 10-403 PTD 169-100 Submitted 11-22-23 - Sundry Application Application for Sundry Approval Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct dambruz@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. • Marathon MARATHON Oil Company May 15, 2008 • Marathon Oil Company Alaska Asset Team ~ > ;~"' ~~~, :~~~ ~ ~j KeOnaB AK 99611 ;,~ ~ u~ ~,., ti ~~~ ~~, `~~ ~ ' Telephone 9071283-1371 ~AY ~ ~ 2008 Fax 9071283-1350 ~'i0t1S. ~e0t"f1~'~l~~~~" ~~lask~ Oil ~ ~'~~or~~ ' ~ Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Submittal List Dear Mr. Maunder: ~nc t ~ ir ~h~~s~~c o ~~ ~~~-S S~~ ~ . e~ ~ ~~ °'~-` ~.~ ea.C_v~~ `~, 5 ~~ ~ ~ ~ ~~ ~.~~~ ~~- ~SS. ~p ~C~ ~70 ~~- ~~5~~~ ~.«O~~ ~~ ~e ~,~~- ~~ ~ ~..,o ~-j ~-~ ~.~-~ ~ Marathon and the AOGCC have had discussions on the follow-u re ortin needed to ~'~ 1-~ p P 9 close out 10-403 Sundry approved well work activities. Work has been ongoing to `~ /~1-~~ identify the suspect well activities and complete the appropriate reporting. Submitted for 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. ~ ; , ,; <<t . ~'~u`~ ., ~ l t~~.~ ~ i. ; ~~.,..'~:~ Sincerely, ' ~~./ ~ Kevin J. Skiba Engineering Technician Enclosures: 10-404 Sundry Submittal List cc: Houston Well File Accompanying 10-404 Sundries Kenai Well File KJS • M Marathon MARATHON Oil Company ~~~~~~~~ ,- ~-, MAY ~ ~ ~C;~: ~ • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 January 23, 2008 Aiaska Oi! ~~~~ +~:c~ s~o C~r~mi~sio~~ ~1r;~~is~r~g~ Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Kenai Gas Field Well: KU 21X - 32 Dear Mr. Maunder: Attached for your records is the10-404 Sundry Report for well KU21X - 32. The work was submitted under sundry #302-336. The well bore and surface flow lines were modified to allow annular flow from the short string from Pool 4. Please contact us at (907) 283 -1371 if you have any questions or need additional information. Sincerely, ~ Wayne . Cissell Well Work Over Supervisor Enclosures: 10-404 Sundry Report cc: Houston Well File Operation Summary Kenai Well File KJS KDW ' ~~ STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMM ION ~~~C,~ V C~ REPORT OF SUNDRY WELL OPERATIONS MAY ~ 6 2008 Sf~eka (1it JL f';~c (`nnc C`nmmiceinn 1. Operations Abandon Repair Well Plug Perforations Stimulate nt~gr ~ Convert to - ~ ~ Performed: Alter Casing ^ Pult Tubing ~ Perforate New Pool ~ Waiver~ Time E en~io~ annular flow 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 Development ~^ ~ Exploratory^ 169-100~ 3. Address: Stratigraphic ^ Service ^ 6. API Number. PO Box 1949, Kenai Alaska, 99611-1949 50-133-20204-00-00 7. KB Elevation (ft): 9. Well Name and Number. RT 90' above MSL- KU 21X-32 - 8. Property Designation: , 10. Field/Pool(s): ~'E.1~ A- 028055 Kenai Gas Field / Sterling Pool 4 11. Present Well Condition Summary: Convert well to annular flow Total Depth measured g~446~ ~ feet Plugs (measured) true verticai 5,p~~ . feet Junk {measured) 5,570' pushed dn retainer Effective Depth measured 5,570' feet true vertical 4,275' feet Casing Length Size MD ND Burst Collapse Structural 57' 20" 57' S7' Conductor Surface 1195' 13-3/8' 1195' 7152' 3090 psi 1540 psi Intermediate Production 6446' 9/5/2008 6446' S053' 5750 psi 3090 psi Liner Perforation depth: Measured depth: 5316' - 5524' True Verticai depth: 4061' - 4241' Tubing: (size, grade, and measured depth) 2-7/8" Lonq Strina N- 80 5261' 2-7/8" Lona Strina N- 80 5484' Packers and SSSV (type and measured depth) Model RH-2 Dual PKR 5253' Baker Mod D PKR w/seal asv and locator 5467' 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 knowiedge. Sundry Number or N/A if C.O. Exempt: 302-336 ~ Contact i Skiba (907) 283-1371 Printed Name Wa ne E. Cissell C Title Well Work Over Supervisor Signature Phone (g07) 283-1308 Date 01/23I2008 Form 10-404 Revised 04/2006 ~ ~ ~~~ ,~Us z c~ 21)09 ~~P~~ Submit Original Oniy ~ M Marathon MARATHON Oil Company January 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Kenai Gas Field Well: KU 21X - 32 Dear Mr. Maunder: r Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~~~~~~~~ MAY ~ 6 ZU0~3 Alaska C?il & Ga~ ~~~'~. ~~~~~~siot~ A~ncf~~P~~~ Attached for your records is the10-404 Sundry Report for well KU21X - 32. The work was submitted under sundry #302-308. The long string sleeve was shifted to allow the long string tubing to be used for flowing pool 4 gas, to production. Please contact us at (907) 283 -1371 if you have any questions or need additional information. Sincerely, ~.~~~~~~'' ~~UG ~ Qi ~,OC~~ G Wayne E. Cissell Well Work Over Supervisor Enclosures: 10-404 Sundry Report cc: Houston Well File Operation Summary Kenai Well File KJS KDW ~ ~ RE~~IiIE[J STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COM ON MAY REPORT OF SUNDRY WELL OPERA/~,TIONS ~ 6 Z~Q$ r#lC~SI(C~ Qit & C~ac ('nno l~..Y~•_ , 1. Operations Abandon Repair Well Plug PerForations Stimulate her ~ ool 4 Performed: Alter Casin Pull Tubin Perforate New Pool Waiver Time Ex~tR~ro 9^ g^ ^ ^ to long string Change Approved Program ~ Operat. Shutdown ~ Perforate ^ Re-enter Suspended Well ~ 2. Operator 4. Well Class Before Work: 5. Permitto Drill Number: Name: Marathon Oil Company Development ^~ Exploratory^ 169-100' 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20204-00-00 7. KB Elevation (ft): 9. Well Name and Number: RT 90' above MSL KU 21X-32 ' 8. Property Designation: , 10. Field/Pool(s): r fE'1S A- 028055 Kenai Gas Field / Sterling Pool 4 11. Present Well Condition Summary: Shift sleeve in long string to flow Poo14 gas to production Total Depth measured g,446' ~ feet Plugs (measured) true vertical 5,053' , feet Junk (measured) 5,570' pushed dn retainer Effective Depth measured 5,570' feet true vertical 4,275' feet Casing Length Size MD ND Burst Collapse Structural 57' 20" 57' 57' Conductor Surface 1195' 13-3/8' 7195' 1152' 3090 psi 1540 psi Intermediate Production 6446' 9/5/2008 6446' 5053' S750 psi 3090 psi Liner Perforation depth: Measured depth: 5316' - 5524' True Vertical depth: 4061' - 4241' Tubing: (size, grade, and measured depth) 2-7/8" Lona Strin~ N- 80 5261' 2-7/8" Lonq Strin~t N- 80 5484' Packers and SSSV (type and measured depth) Model RH-2 Dual PKR 5253' Baker Mod D PKR w/seal asv and locator 5467' 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 NIA 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 Q 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: 302-308 f Contact i Skiba (907) 283-1371 Printed Name W ne E. Cissell Title Well Work Over Supervisor Signature Phone (907) 283-1308 Date 01/23/2008 l~ ~h ~a.~ Form 10-404 Revised 04/2006 °'~i~~~ ~~, ,;;~L 'L ~ L~IOS Submit Original Only , MARATHON OIL COMPANY DATE: 9/25/2002 ~ `` DAILY WELL OPERATIONS REPOR~ ' FIELD: Kenai Gas Field FILL DEPTH/DATE: 5270' RKB TUBING: DATE LAST WL WORK: N/A 2 7/8 WELL #: KU 21 X-32 CASING: 9 5/8 TREE CONDITION: Good WORK DONE: Tag fill, shift "CX" Ptug WIRE TEST: 21 PRESEIVT OPERATION: Complete OTHER: WBS # CC.20284500 TOOL STRING: RS, KJ, Stem, Stem, KJ, Stem, OJ, SJ H~S. 7 WIRELINE CREW: Howeil/Smith PROD: X DRILL: RSO #: 455-864 SUMMARY OF OPERATIONS Ticket #: P-225 ~ Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. Pollard Wireline Inc. Pollard Wireline inc. Pollard Wireline Inc. Pollard Wireline Ina DAILY COST: CUM: REPORTED BY: IVlarathon Oil Company Alaska Region Domestic Production P.O. Box t 96t68 Anchorage, AK 99519-6'168 Telephone 9071561-5311 Fax 9071564-6489 October 23, 2002 Mr, Tom Maunder Alaska Oil & Gas Conservation Commission 3,33 W 7~h Ave Anchorage, Alaska 99501 Reference: KU 21x-32. Dear Mr, Maunder: Enclosed is the APPLICATION FOR SUNDRY APPROVALS form for well KU 21x-32, The proposed work is to convert the well into an optional Pool 4 annular well, The well is currently capable of Producing about 1.7 MMSCFD, The proposed changes could bring the rate to as high as 5.9 MMSCFD. Please find the attached procedure, wellbore diagram, and discussion of potential problems. The maximum erosional velocity would be expected at the valve recovery threads on the annular outlets. This velocity was found to occur at a rate of 6.2 MMSCFD while flowing the annulus from both side outlets, Marathon plans to prodUce the well below erosive limits. ~ %, I If you need any additional information, I can. be reached at 907-283-1333 or by e-maiIj~ dmtitus@marathonoil.com. ~t_~S~....~¢.__'--''/ Sincerely, Denise M. Titus Production Engineer RE£EIYED RECEIVED OCT 2 2O02 . OCT Al~slm Oil & G~ Cons. Oomm~ss~o~ An,d~o~e g0 'd qL'[9 gSg LO6 'ON ANYdI, IO0 'IIO NOH£¥8¥I,I kid 9E::i~I dStl*l ;gOOg-g;g-,I, O0 STATE OF ALASKA 10-402.XL$ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS '¢~"r/o/,, 1. Type of Request; Abandon Suspend ..-. OperalJon Shutdown Re-enter Suspended Well Alter Casing __ Repair Well__ Plugging__ Time Extension,__._. Stin~ulalo..,._ Change Approved Program .-- Pull Tubing..__.,. Variance__ Petfmate~ OthorX 2. Name of Operator 5. ¥~/pe of Well: " ' 6. I~;~[u~l EI0vation (DF or KD)' MARATHON OIL COMPANY Development ~X 17.3' .KB 3, Address '" ExploratoryI 7, Unit or Property NO'rna " ..... p, O, Box 190168, Anchorage, AK 995t9-6168 ......... 8tra[igraphic,_..., Kenai Unit 4. Location 0f Well at Surfuce ¢ ,v'" ~/ Service~ 8, Well Number ,, , 1868' FSL, 1129' FEL, SeC 32, T5N, R11W, SM KU 21x-325 At top of Productive Interval 9. Permit Numbe¢ 2540' FWL, 600' FNL, ,Sec 32, TSN, R11W, SM 69-100 -1 , .... Al Effective Depth 'I 0. APl Number Convert Well to Annular Flow '/ $0- 133-20204 At Total Depth 11. Field/Po01 Keno] Gas Field, Pool 4 12, Present Well Condition Summary ........................ Total Depth: moasurod 6446 feet Plugs (measured) true vodlcal 5053 feet Effective Depth'. measured 5570 feet Junk (measured) 5570` pushed dn retainer t~ue veH. i~l 4275 feet Casing LengLh Size Cemented Measured Depth True Ve~tlc:al Depth Structural 57' 20" Driven 57' 57' Conductor Surface 1195' 13.3/8" 676 sx Class G 1 I95' 11 Intermcdiate Production 6446' 9-5/8" 660 SX G 6446' ,-.-50,~3' Liner Perforation Depth: measured $Ieding Pool 4 (B1) 5316'~5369'; 5391 '-5398'; 5415L5425'; 5432'.5448' w/1/2" hole, 4spr, NCF 11 Keno shots RECEIVED true ye dical 4061 '4104'; 4122'.4128'; 4143'-4150'; 4156'-4170' Ogl' 2 3" Tubing (size, grade, arid measured depth) 2-?/8", 6,4ppi, N-80 tubing Alaska Oil & Gas Cons. Commission Pa~kem and 8SSV (type and measured depth) Model RH-2 Dual Packer ~ 5250' l'3,'~,it~chmenl, s Description sCr~mary of Prepo~'.4i-- Detailed Operations Progr'~r¥_ .X.. BOP Sketch .--., '--' ' 1'4. Estimated Date for Commencing Operation ....... 15, Status el~ Well Classification as¢ ...... t 1/I/2002 16, If Proposal was Verbally Approved Oil-.--. Gas ~X Suspended ..---. Name of Approver Date Approved Service !11, I hm'~l~y certi'(~"th'aTt-I~e roregoing'i~"truo and (;orrer~l to the best of my knowledge. ' .... .._s!g.ned_ ~ ~~~ Title Production Engineer Data 10/23/2002 FOR. ~I~MIS$1ON USE ONLY ............... CondltJon¢ of ~,;~';~1; Not'y,r Commission so represcntatJvo may wlLne'$$" IAI~;~)~,~I NO, ,.~,__ Plug Integrity__ BOP Test Location ClearanceJ ,,, Mechanical Integrity Test~ --'~ubsequent Form Required 10- ~-t,A,.'~_ Approved by Order of the Commission _ _Co~m. n]js.sioner Date Form l0-403 Nov. 06/hS/e8 -- ' [ 1~ ~'-'~ ~ {'"~. ]' ~ J /*~ t Subni~l~"~ iplicalu ~;0 'd qL[9 gag LO6 'ON AN~dNO0 lIO NOH£~N Nd 9g:g[ d.~H ~OOg-gg-£O0 Marathon Oil Company Alaska Region KU :21x-32 Kenai Gas Field, Pad 43-32 Convert to Annular Flow Procedure WBS # TA.02.07305.EXP ltistory: KU 21 x-32 produces fi'om the short side of its dual strings (Pool 4). Modeling sllows ifs l';.l{e can be improved by openi;~g a sleeve above the dual packer to allow ammlar flow. Objective: Modify wellbore and surface flowlines to permit annular flow from the short string, Procedure: I. RU pressure test skid to annulus. Pressure test casing to 500 psi lbr 30 minutes. , Bleed pressure off of backside, Open existing casing valve and loosen blind flange on opposite side of tubing head. Check for VR plug in outlet (will install if'needed). Pull blind flange and install remanufactured 2-I/16" 5M (customer property) valve on the outlet, Test against VR plug and remove leaving valve open. Install VR plug on opposite side of tubing spool and remove oki 2-1/6" 5M valve. Install llew 2-1/16" 5M valve, Test against VR plug and then remove. Close annul,'u' valves. ,, Fabricate and install surface lines as required to permit flow fi'mn the annulus Ihrough existing tlowlines using both side outlets. Connections from side outlets to llowline should be symmetrical. , MIRU wirellne service on long string. RIH, Close sliding sleeve at 5261', POOII. RIII to 5210' to shift annulus sleeve open, (FYI-plug is set below in tubing ~ 5473'). RDMO wireline. MIRU BJ Services N2 pumping unit, RU MOC flowback equipment to the ammlus. Circulate N2 down the tubing taking returns to the am'talus. Volume recovered should be 312 bbl. If volume is not achieved, RU N2 to the annulus and reverse circulate taking returns fi'om the tubing. A pressure limit ofS0~psi o~n the casing slmuld be observed for this step, '~ 6. MIRU wircline service to long string. Shift sleeve closed at 5210'. Rig offoflong strh~g and onto the short string. Open the slccvc at 5181', RDMO wircline service. I;'0 'ct qL[9 EBE LO6 'ON XV~ iNVcI~O0 "II0 NOH,LVHYN Ncl @E:~t O~M EOOE-EE-,i, O0 7. Begin producing via short string tubing to unload Pool 4. If unsuccessful, force water away using field gas source, If field gas does not provide enough pressure, MIRU BJ N2 service to bullhead N2 down short string. Charge formation in excess orSITP (about 500psi) prior to rigging down niirogen, 8. Once short string flow is established lhrough production, bring on annulus while flowing the shor~ string. 9. Test llow per instructions lhrougl~ tubing and annulus as indicated. cio 'd ciL[9 gl~ /.06 'ON ×¥d ANYdI400 ~lIO NOHJ,¥;8¥14 Md 9g:gI (].'ql'l ~O0~-$~-,LO0 .! WELL KU 2 lX '32 :_.>_,. CASING & ABAND'ONMENT DETAIL B-1 Sd. B-Z Sd. B-3 Sd, '1, Kelly Bushing at 0.0' II, CIW Tubing Hanger at 16.80' I11, 20", 94~ (3onductor Driven to 57' IV. 13-3/8', 61~, K-G5 CaalIlg at 1,195' V, 9-5/8~, 40~, K-55 & N-BO Casing TUBING DETAIL' LONG STRING: 2-7/8~ 6.4~, N-80 TUBING 1. 'CX' Mandrel at 5,210.07' Model RH-2 Dual Packer at 3, ~GX' Mandrel at 5,261,59' 4. Blast Joints From S,298.27' to 5,460,23' 5, '{3X" Mandrel at 5,460.2;3" 6, Baker Modol 'D' Packer W/Seal Assembly & Locator at 5,467.27' 7. ~X' Landing Nipple at 5,472.75* B. i~ottom of Long String at 5,484,1~' SHOR (3. DA TE 11/30t69 T STRING: 2.7/8"~ 6,4~, N-80 TUBING 'CX" Mandrel at $,181,04' Model RH-2 Dual Pa~ker at 5,252.73' 'N° No-Go Nipple PERFORATION RECORD INTERVAL 5,361'-5,398' 5,416~-5,425' 6,432'-5,446' 5,488'-5,524~ $,4eB'-5,448' 5,4BB'-5,$24~ CONDITION B-1 SAND, PRODI.ICTION B-2 SAND, PRODUCTION B-3 SAND, PRODUCTION REPERF. Et-2 SAND REPERF. B-~, SAND WELL KU 21X-32 WELL SCHEMATIC f.J,N~YN BAW ¢~D. APP~O, 90 'd CiLI9 ~8;~ LO6 'ON X~,...q ,iNYdPlO0 "ILO NOH,L¥~¥1,,I lid 9E::;~I d.'ZlFl E~OO;~-E:E~-J.,O0 WELL KU 21x-32 KENAI GAS FIELD, PAD 43-32 ANNULAR FLOW CONVERSION POTENTIAL PROBLEMS ADDRESSED This conversion will allow gas from the Sterling B-1 and B-2 Sands (Pool 4) in well KU 21x-32 to be produced up the 2-7/8" short string tubing and the 9-5/8" casing simultaneously. This is expected to increase gas deliverability at a low cost. Potential problems associated with this type of completion are addressed below. Potential Problem Solution Erosional Velocity Corrosion Surface Safety Controls Burst/Collapse of Casing The highest potential for erosive flow exists at the 2-1/16", 5M flanged outlets of the tubing head. Flow will be out both outlets of the tubing head to reduce velocity. Erosion could potentially occur if flow out both side outlets exceeds 6.2 MMCFD. "~b, Marathon plans to produce the well below erosive limits. Also, Marathon will conduct periodic UTT inspection of the wellhead and flowlines for signs of unusual wear. Partial-pressure of CO2 is less than 1.0 psi. If the partial pressures of CO2 is less than 7 psi the gas is generally considered non-corrosive. Furthermore, there is no H2S produced in the Kenai Gas Field. Corrosion of the casing is highly unlikely. The annulus will be produced via a separate flowline from the existing tubing completion. Surface safety controls will be similar to that of other Kenai Gas Field completions. Shut in pressure for Pool 4 is 199 psia. Pressures imposed on the 9-5/8" casing during this procedure will not compromise the integrity of the casing. Worst-case forces will not exceed 10% of the rated casing burst or collapse. Marathon OilCompany Alaska R~lion Domestic Production P.O. Box 196168 Anchorage, AK 99519-6156 Telephone 9071561-5311 Fax 9071564-64~9 September 24, 2002 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7"' Ave Anchorage, Alaska 99501 Reference: KU 21x-32 Dear Mr. Aubert: Enclosed is the APPLICATION FOR SUNDRY APPROVALS form for well KU 21x-32. The proposed work is to shift a sleeve in the long string to allow long string access to Pool 4 perfs. If you need any additional information, I can be reached at 907-283-1333 or by e-mail at dmtitus@marathonoil,com. Sincerely, Denise M. Titus Production Engineer DUPLICATE RECEIVED SEP 2 4 2002 gO 'd §LI9 gSg LO6 'ON X~J AN~dlAO0 '110 NOHJ,~;h"dgl lqd 6£:g0 .':Il]J, gOOg-~'g-d.'qS Marathon Oil Company Kertai Gas Field PO lBox 1949 Kenai, AK 996'11-t 949 Telephone (9137) 283-1300 Fax; (907) 283-6175 DATE: ~1!,-3,,~/0'''L'~ Fax Cover Sheet iii .i iiii i i ii i . . I iiii TIME:________.. , TO: FROM: ,, PHONE: ........ FAX:.,.,_.__9_O_7.=2~%- -6_175 REC'EIVED PAGES SENT (Including Cover Sheet) [ ] Response Requested [ ] Immediate REMARKS: SEP 2 4 2002 [ ] Information DUPLICATE [0 'd 9L[9 ESE LO6 'ON ×~dJ ^NYdNO0 'IlO NOHI.¥NYN NJ f~:~'n qnl 2nn~.-l~2-4qc: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 10-4'03 Open sleeve.Xl,,8 Type of Request: Abandon.,.,., Suspend~ Operation Shutdown Alter Casing ~ Repair Well Plugging__,. Change Approved Program Pull Tubing,.,.,._ Variance 2. Name of Operator MARATHON OIL COMPANY 3. Address P, O. Box 196168, Anchorage, AK 99519.,6168 4. Location Of Well al, Surface 1668' FSL, 1129' FEL, Sec 32, T5N, R11W, SM At top of ProducUve Interval 2540' FWL, 600' FNL, Sec 32, TSN, R1 lW, SM At El'fective Depth At Total Depth $, Type of Well: Oevoiopment_.,X Explomtor~ StraUgraphlo__ Service Lopen Pool 4 to Long string '12, Pres'~'t Weii'Condition Sumn~ary Total Depth: measured true vertical ... , _ in _ 6446 lc, et Plugs (i~easured) 5053 feet Re.enter SUspended Well...__ . Time Extension Stimulate Perforate Other X O, Datum Elevation (DF o~. Kg) 17,3' KB 7. Unit or P~'bp0r[y' Name Kenai Unit 8. Well Number KU 21X-32L&S 9. Permit Number 69.100 .,, ____ ~. APl Number 50- 133.20204 11. Field/Pool Kenal Gas Field, Pool 4 ,i Il Il Effeclive Deplh; measured true vertical 5570 feet Junk (measured) 5570' pushed dn relainer 4275 feet Casing 8truotuml Conductor Surface intermediate Produotion Liner Perforation Depth: measured true vertical Length Size Cemented Measured Depth 57' 20" Driven 57' 1 t95' .13.3/8" 676 sx Class G 1195' 6446' 9-5/8" 660 sx G 6446' SS: Sterling Pool 4 (61) 5316'-$369'; 5391',-5398'; (62) 5416'-5425'; 5432'-~48' w/'1/2" hole, 4spf, NCF 11 Kone shots LS: sterling Pool 5.1 (B3) 5438%5448'; 5488'-5524' SS: 4061'-41o4'; 4'122'4128'; 4143'-4150'; 4156'-4170' L$: 4'16%4173'; 4~17'-4257' Tubing (size, grade, and measured deplh) True Vertical Depth SS; 2-7/8", 6,4ppf, N.80 tubing to 5261' L$: 2-7/8", 6.4ppf, N-80 lubing tO 5484 11 §2~ Model RH-2 Dual Peeker @ 5250' 5053' Peekers and $S$V (type and measured depth) REC'EI'VEDI SEP 2 4 2002 13. AL'ta'~ment$ Desorip~ion Summary ~f PropOsal.__..' - Do~alled Opera-~o~s Program ' X_.:. BOP Ske[cl~ 14, Estimated Dale rot Commencing OperaUon 9/25/200:~ :1o. If Proposal was Verbally Approved Name of Approver Date Approved 15. StaLus ot Well Classification Oil Gas Service Suspended,.._.. 17. I hereby cerllfythat the foregoing is true and correct tO the best o1' my knowledge. _- Signed . Denise' Tilus Title ProducUon Engineer FOR COMMISSION USE ONLY Dale 0/24120¢)2 Conditions of Approval: Notify Commission so representaUvo may witness Plug Int~grity~ BOP Test Lot, etlon Clearance Mechanical Inlegrily Test~ S"--ubsequont Form Required lo- ORIGINAL SIGNED DY D Taylor Seamount Approved b.y.O, rder el~ the Commission Colrut dssionor 10-403 R.v. OOll5/,~JH ~0 'd §Lt9 DUPLI C, ,,TE ltloI1 ~:~;~ LO6 'ON XE..4 aNYdDO '110 NOH£~N~gI gld 6£:S0 3fl& ~OOg-l~g-d3$ Marathon Oil Company Alaska Region KU 21x~32L Kenal Gas Field, Pad 43-32 Open Sliding Sleeve WBS # TA.02.07305.EXP History: KU 21x-32 produces from the short side o£its dual 2-7/8" strings (Pool 4). A plug was set in the long string PX profile to shut offproduclion from tile water bearing ?oo1 5.1 (12/21/oo), Objective: Open sleeve to communicatc long string to Pool 4 as an altemale/additional flowpath, Proced[] re: 1. MIRU wireline uni~' on long s~ng. PU lubricator and tesl to 200psi. 2. Rill w/gauge ring to ensure tubing is clear to PX plug a~s~ag~'M_D. POOII. 3. RIH to slide open sleeve at CX mandrel ~ 5262'MD. POOH. 4, RDMO wireline t~O 'd 9L[9 ~88 LO6 'ON 9O B-I Sd. 6-2 Sd. B-3 Sd. WELL kU CASING & ABAND'ONMENT DETAIL 'i. Kelly Bushing at ih CiW Tubing Hanger at 16.50 Ill. 20', 94~, Conductor Driven to 57' IV, 18-8t8"1 Gl,;-, K-55 O==ing at 1,195' V. 9-5/8~, 40~, K-55 & N-BO Casl~g at 6,446~ TUBING DETAIL LONG STRING; 2-7/8; 6,4~, N-SO TItBING 1. 'QX' Malldret At 5,210.07' 2, Model RH-2 Dual Pseker at 3. 'OX' Man~rel ~t 8,261.59' 4. Blast Jot~ts From 5,2~8,27' to S,460.23' 5, ~CX' M~ndrel et 6. Beker Model 'D' Pa~ker WISeel Asaembly & Lo~tor ~t S,467.~7~ 7, ~X~ Landing Nipplo ~t 5~472.7~' B. Bottom of Long ~trlng ~1 5,48A.13' · .~HORT STRING: 2-7/8", 6,4~, N-EIO T~IBING A. 't3X' Manclrel at 5,1~1~04' B. Model RH-2 Dual Pauker ~t 5,252°72' C, 'N' Ne-Go Nipple at'576~1.43' PERFORATION RECORD DA TE IN TER VA L 11130/69 6,316'-5~368~ ~,416~-,5,425' 6,482'-5,448' 5,465'-5,524' 6,43 B'-,5,44 a' CONDITIOn! I~-1 SAND, PROD[lOTION a--2 SAND, PRODUCTION D-3 ~^ND, PRODUC'rlON REPERF. B--2 SA. NO RE[PERF. B-S SANID . HfV t PAll' __ CiL[9 ~SZ LO6 WELL KU 21X-32 WELL SCHEmATiC 'ON X~J Union Oil and Gas Div~-i,on: Western Region Union Oil Company ot ~J~lifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unlen June 5, 1984 Hr. C.V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Dear Hr. Chatterton: SUNDRY NOTICE INTENTIONS Attached for your approval are Sundry Notice intentions for KU 21X-32, KU ~4-~2 and KU 21-5, Kenai Unit. Rlease return the approved Sundry's to the undersigned. Very truly yours, Lawrence O. Cutting ENVIRONHENTAL SPECIALIST LOC/tj Attachments RECEIVED G~i & Gas Oons. oommbsion Anchorage STATE OF ALASKA ALASKA L AND GAS CONSERVATION C ' MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 69-100 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50_133-20204 4. Location of Well 1900'N & llO0'W of SE Cot., Sec. 32, TSN, RllW, SM 5. Elevat~_ i ngfdelt (indicateabove KB.MsL,DF etc.) 6. Lease Designation and Serial No. A-028055 9. Unit or Lease Name Kenai Unit 10. Well Number KU 21X-32 11. Field and Pool Kenai Gas Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing ,J~ Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). SEE ATTACHED ADDENDUM RECEIVED JUN 0 6 1985 Alaska 0il & Gas Cons. Commission Anchorage Signed La~vtence O. Cu'cT..tnq The space below for Commission use correct to the best of my knowledge. Title ENVIRONMENTAL SPECIALIST Date 06--04-85 Conditions of Approval, if any: Approved by ORIG!IAL Slllil' ... Bt' LOIttlIE :. SMIT! ~l~pproved C~y By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 13.) PROPOSED PROGRAM 2.) 3.) 4.) 5.) 6.) 7.) 8.) 9.) 10.) 11.) i2.) i~.) 14.) 16.) 17.) i8.) Move rig to 42-32 pad, KU 21X-32 and rig up. Kill well, install BPV's, remove tree, install and test BOPE. Pull and lay down existing completion assembly. Mill over and recover packer from + 5467'. Clean out to + 6446' ETD. Squeeze inter~al 5488-5524' for abandonment. Clean out squeeze and test to a 0.80 psi equivalent. Perforate Pool 6 C-1 Sand at 6040-6070' DIL. DST the C-1 Sand. If we~go to Step 12; if dry and productive continue with Step 10. Reperforate the B-1 Sands at the following intervals: 5316-5369' DIL 5391-5398' DIL 5416-5425' DIL 5432-5448' DIL Run dual 2 7/8" completion assembly as per proposed completion #1. Go to Step 17. If C-1 is wet. Squeeze interval 6040-6070' for abandonment. Clean out squeeze and test to a 0.80 psi/ ft. equivalent. Perforate the A-9 and A-lC Sands at 5120-5128' DIL and 5162-5170' DIL. DST A-9 and A-lC Sands. Run dual 2 7/8" completion assembly as per proposed completion #2. Install BPV's, remove BOPE, install and test dual tree. Place well on production. Rig down and move rig to next site. 7 E! FED JUNo. o ~985 &4Gas COns. nChorage COmmission PROPOSED COMPLETION KU 2 lX-32 133/8" CASING AT 1195' DUAL 2 7/8" TUBING f.~ DUAL PACKER BLAST J'OINTS A-9/A- 10 SANDS 5120'-5128' 5162'-5170' 5180'-5205' B- 1/B-2 SANDS 5316'-5369', 5391'-5398', 5416'-5425; 5432'-5448' SINGLE PACKER C- 1 SAND 6040'-6070' 9 5/8" CASING AT 6446' IF POOL 6 TESTS DRY IF POOL 6 DUAL pACKER BLAST JOINTS SINGLE PACKER TESTS WET Fig. I Union Oil and Gas [' -~,~ion:~ Western Region Union Oil Company of California 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 Telephone (907) 279-4511 union ApRil 14, 1970 HI, B KLV -~--~ FILE Mr. Thomas R. Marshall, Jr. State Petroleum Supervisor Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Flarshall: Enclosed are Forms G-I, P-7, 9-330 and bottom hole measurement data for Kenai Unit Well 21X-32L. Should you have any additional questions, please give me a call. R. C, Hartmann District Production Superintendent RCH:mgl Enc I osu res k'orn~ P-7 SUBMIT IN * STATE OF ALASKA (See other In- structions on OIL AND GAS CONSERVATION COMMITTEE reverse 'WELL COMPLETION OR RECOMPLETION REPORT AND LOG* _ la. TYPE OF WELL: oII, [] vAS WELL ;NELL ~ DRY ~ Other _ b. TYPE OF COMPLE~ON: w ~:LL 0V ~a ~ 2. NIXIE OF 0F~RATOR Union 0i~ Co. o~ Cai 3. ADDRESS OF OPERATOR 507 Northern Li.qhts Blvd. 4. LOC,~TION OF WELL (Report location clearly and in accordance with any State requirements)* Atsu~ace See P-7 Form Previously Submitted (12-15-69) At top prod. interval reported below At total depth 13. D.A. TE SPUDDED [14. DATE T.D. RE/~CHED !15. DATE COMP SUSP 01:~ ABAND. 1 · I-IOW 1ViANY* ROTARY TOOLS 22. PRODUCING INTERVAL(S) OF THIS COMPLETIOIXI--TOP, BOTTOM, NAME (MD AND TV]))* 5. API N~CAL CODE 50-133-20204 !6. LEASE DESIGNATION AND SERLkL NO. ^-028055 7. IF INDIA/X[, ALLOTTEE OR TRIBE NAiVIE 8. UNIT,FARNI OR LEASE NAME Kenai Unit 9. WELL NO. KU 2 IX-32L 10. FIELD A,ND POOL, OR WILDCAT Kenai Gas Field ~,~./ !11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 32, T5N, RIIW, SM 12. PERNIIT N'O. ELEVATIONS (DF, RKB, RT, GR, ~i-'C)* 17. ELEV. CASINGHEAD INTERVALS DRILLED BY CABLE TOOLS 23. WAS DIRECTIONAL SURVEY MADE 24. TI~PE ELECTF, IC AND OTHEt% LOGS RUN ~5. CASING RECORD (Report all strings set in w~ll) CASIaNG SIZE WEIGHT. DEPTH SET (MD) HOLE SIZE CF~A~[r,NTING RECOILD I A-MOUNT PULLEI~"" DATE FIRST PIT. ODUCTION TUBING REC,OFJD PRODUCTION January, 1970 DATE OF TI;ST, [HOURS TESTED "[CI'105[E SiZE ]PROD'II FOR 3-30-70 ~-~W, TUBING [CA~LNG PRESSURE [CALCULATED OIL---BBL. GAS---~ICF. ~ll ~ DiSPOS~TiOx O~ G,S (8old, used ]or ]uel, vented, etc.) ' Sold Pl%ODUCT1ON MEII{OD (Flowii*g, gas lift, pumping--size and type of pump) Flowinq - Gas Well OIL--EDL. G- I V¢'ELL STATUS (Producing or unuL-in) Producer WATEII~BBL. I GAS-OIL R.%TIO WATt--BBL. ~ OIL GRAViTY-MI (CO~.) TEdT WITNESSED BY [. Keen 32. LIST OF ATTACHMENTS ~See Open F]ow Potentia[ Test Report ,23. I hereby certify' that the for~go/~ and atta,~hed information is comple{~ and correct as determined from all-available records ..... smash./ j. e. Church ~T,.~. Production Engineer ~zr~ 4-14-70 *(See Instructions and Spaces for Additional Data on Reverse Side) General: This form is designed for submitting a complete and correct well completion report and tog on all types of lands and leases in Alaska. ~- Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in c, ther spaces on this form and in any attachments. Items.20, ~,nd '~2:: If this well is completed for separatc production from more than one interval zone ('multiple completion), so state in item 20, and in item 2'2 show the producing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- lng the ad~clitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). ' 34. SI. IMIVI~I~ OF' ~)R. MATION TF~'I'$ INCLUOI'~'(i'~N~:~RVAL T~TED, ~'~RE DATA ~~'OV~I~ OF OIL. GAS, WA~ AND MUD . . ~ . - 36. C~E DATA, AI~A'CII ORIE~ ~~S O~' LtTI,I~Y', POB.~:~Y., .~A~. A~~' ~: - ' . , ~, ,, .................. , ,~. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE i V~ELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: 0iL ~] 'i~XS W ELL W ELL Other b. TYPE OF COMPLETION: WELI, OVER EN BACK ~ESVR. Other ~ 2, NADIR OF OPERATOR Union Oil Co. of California 3. ADDRESS OF OPERATOR 507 Northern Lights Blvd. 4. LO¢^TION OF WELL (Report location clearly and in accordance with any State requirements)* (12-15-69) Ztsu~ace See P-7 Form Previously Submitted At top prod. interval reported below At total depth MD & TVD[20. I2' lViULTIiPLE COM~L.. HOW 1VI2%N Y* (See other In- st ructions on reverse side 13. DA. TE SPUDDED !14. DAT~I T.D. tLE~CHED 115. DATE CO,MP SUSP Ol~ ABAND. ! 18. 'COrrAL DEPTH, ~NLD & TVD ![9. PLUG,:B~CK 22. PRODUCING INTERVAL(S). OF THIS CO.1V/PI_,ETIO/q~TOF, BOTTOM, NAME (MD AND TV'D)* 16.' EleVATIONS (DF, RKB, I21'ROTARY TOOLS 5. API NUME, KICAL CODE 50-133-20204 6. T.F..A.qE Db~_$!GNATION AND SERIAL NO. A-02@055 7.IF INDIA~, ALLOTTEE OR TRIBE NA1ViE 8. UNIT,FAIklVI OR LEASE NAME Kenai Unit 9. WELL NO. KU 21-X-32S 10. FIELD A2/D POOL, OR WILJ3C'AT Kenai Gas Field 11. SEC, T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 32, T5N, RIIW, SM 12. PERMIT NO. RT, GR, ~3TC)*117. ELEV. CASINGPIEAD ,, , ~ INTERVALS DRILLED BY CABLE TOOLS 23. WAS DIRECTIONAL ! SURVEY MADE 24. TY-PE ELECTRIC AND OTHF_,I{ LOGSRUN 25. CASING RECORD (Report all strings set in well) CASI~NG SIZE WEIGHT. DEPTH SET (MI)) HOLE SIZE C~'~ILNTING RECOi:I,D I A2~IoUNT PULLED 26. LINER RiECOt{I) 27. TUBING REC.OPd2) SIZE TOP (MD) BOTTO}/I (5~[D) S~%CKS CEMEi~*T* SCi:LEtEN (MD) SIZE DEPTH SET (1V~D) ~ PACKER SET (MD) 28. PEH.FORATiONS OPFiN TO (interval, size and number) SilOT, FRACTURE, CF2,IENT SQUi2XZE, ETC. :? '~ (MD) AMOUN'f ~D }2IND OF ~A~AL US~ I i i i PRODU~IOH DATE FIRST February, 197~ Flowing -Ga$ Well . ~a~r or ~s~, ['~o~s T~Z~ ~[~OX~ S~ZE ~or'r¢ FO,a OX~. ~.~CF. I t i~s'r P~OD i FLOW, TUBING ICASLNG P~S~E [CAL~~ OI~BBL. ~I~D'ISPOSITIONOr GAS (80rd, used for tuel, vented, etc.)' So l,d 82. LIST O~ ATTACHMENT8 I V¢'ELL STATUS (Produckng or shut-in) Producer WATER--BI3I~. I GAS~OIL R~TIO [ TEBT WITNESSED BY L. Keen ~;ee Ooen Flow Potenti a I Test Reoort 33. I hereby 'certify that the foregoing and, attached tnfoi'matlon 18 complete and correct as ct~termined from all-available records ~ TITLE Production Enai neer s,,I , ~ Jr Et Chur9hcNsD - --~. i i i *(See Instructions and Spaces [or Additional Data on Reverse Side) 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: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth-measure- ments given in other spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prcducing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separat4~ report ('page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the adiditional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 21i: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). i, S4. SI./MMA. I~Y Of FOR1VfATIoN TF~T$ I~CL'~DIN(i INTERVA~ T~E', ~"~U~ DA~ ~ ~SV~I~ OF OIL~' GAS. WA~ AND MUD ' - . I . , . . . m i.J .... Ill .... 41 .L .Jm _l.JJm I.l_ I mill m I I '' i Il II I lll II -- I I I II I m I Il II I . , _,, ., ............... 20 40 50 60 7o 8o9o1,oo '?o S. 7. FIGURE No. UNION OIL COMPANY OF CA~~F;:~T?. W~STEt~N REGION ANCHORAGE DISTR~CT ~KENAI GAS~ FIELD` DELIVERABILITY AT THE ~-~-~-~-~-~-~-~-~gO /-'~,'~'~ WELL NO.' PO 0 L : ~ _.__ ,;", 5 6 i 8 9 t0 FLOW RATE, Q, mmscF/O(]y Q, mscF/D = INTERPRETATION BY DRAWN BY t SCAt, E 2O ( Pws~ -pwf~) [~- f/-?o ,. ~rm Ilo. P--4 REV. STATE OF ALASKA SUBMIT IN DUPLICATE 'HLB ~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF 'DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER 2. NAME OF OPtIRATOR Union Oil Company of California 3, ADI~'RESS OF OI~akw~ATOR 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 4. LOCA~ON O~ wF~LJ~ 43-32 Drilling Pad, 1900'N & ll00'W of SE corner Section 32, T5N, RllW, SM. ~. AP1 NUAIERICA.L CODE 50-1~3-20204 oKGTRM ~~--- 6. LEA~E DESI'bNA~'FIO~ AND ~L~/~( A~028055 REL .?. IF INDIAAT, ALOTTEE OR TRIBE NAME 8. LrNIT,F~RA{ OR LEASE Kenai Unit 9. %~ELL NO. KU 21X-32 10. FlED AND POOL. OR WILDCAT Kenai Gas Field 11. SEC., T., R.. M. (BO~i'OM HOLE OB.r~CTIVE) Sec. 32, T5N, RllW, SM. 12. PEI~MIT NO. 69-100 13. I~EPORT TOTAL D~IP/~H AT F2qD OF MON/~zt, CI-IA/~GES IN HOLE SIZE, CASING A_N-D CE/VIF2q~NG JOBS INCLUDING DEPTH SET A/ND VOLLrNIES USED, PEtLFO'~TIONS, TESTS ~ RESULTS, FISHING JOB~, JLrNK IAI HOLE AND SIDE-T1R2%CKED HOLE AND ANY OTI-IER SIGNIFICANT CH.A. NGES IN HOL~ CONT)ITIONS. KENAI UNIT 21X,32, DE~..E~.BER 1969 Ran 337 jts of 2-7/8" 6.4# N-80 seal lock tbg. Long String - 169 jts; hung w/tail @ 5480'. RH-1 pkr @ 5461'. RH-2 pkr @ 5245'. Short String - 168 its; stabbed into pkr @ 5245' w/tail @ 5256'. Rmvd BOE. Instld dual 10" 3000# xmas tree. Displaced mud w/wtr. Attempted to set btm single hydro set pkr on long string. Sheared out w/3700#, pkr failed, did not set. Unable to get thru X nipple to set plug w/wireline. POH. RIH w/wireline to check all sleeves in long string. Ail sleeves closed. Displaced wtr in hole w/mud. Circ & cond mud. Built up weight & viscosity. Removed xmas tree. Installed back pressure valves. Instld BOP's & RU kill, choke & accumulator lines. Pulled tbg, replaced faulty RH-1 pkr. Reran & landed long and short strings of tbg. Removed BOP's. Instld tree. Dsplcd mud w/wtr. Attempted to set btm single pkr. Surface indications show pkr did not set. Set X plug in LS tbg below pkr. Pressd to 5000#, noaevidence of pkr setting. Opnd sleeve, dsplcd wtr w/mud. Rmvd tree, instld BOE. Pulled short string & long string. RI w/Baker Model D retainer on wireline. Set @ 5463'. RI w/dp. Stabbed into pkr. Circ btwn LS & SS perfs. Communication behind csg..Sqz cmtd w/35 sx "G". CIP 4:I5 am 12/6/69. WOC. DO cmt stringers 5400-5463, retainer 5463-5465 & cmt 5465-5514. CO to 5560. D-A reperfd 5488-5524 & 5438-5448. Ran csg scraper to 5560. RI w/Baker Model D prod pkr on wireline. Pkr set @ 5015' while RIH. Drld on pkr @ 5015'. Unable to drilling pkr. POH. RI w/rotary shoe. Milled from 5015-5016. POH. Drld retainer 5016-5018. Pushed same to btm. Ran junk bskt & gauge ring on wireline. Set Baker Model D prod pkr @ 5466'. RIH w/seal assembly & locator on dp. Tstd perfs below pkr 600# OK. POH. ~--: . _ ~t'/:~ON OF C:~. ,'/",~ ........ ~ No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPO'RT O'F :DRILLING AND WOR'KOVER OPERATIONS WELL WELL NAME OF OPEB. ATOR 3. ADDRESS OF OPERATOR 4. LOCATION &F W~LL OTHER SUBMIT IN DUPLICATE ~.. API NI./AIERICAL CODE LEASE DESIGNATION AN-D SERIAL NO. 7. IF INDIA]~, ALOTTEE OR TRIBE NAME 8. LrNIT,F.~:iM OR LEASE NAME Kenai Unit 9. WELL NO. KU 21X-32 10. FIELD AND POOL, OR WILDCAT 11. SEC., T., R., Ai.. (BO~FTOM HOLE om.rmcTnrS) 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-I_A~NGES IN HOLE SIZE, CASING ANT) CE1VIENTING JOBS INCLUDING DEPTH SET AND VOLLrM~S USED, PER~O'R~TIONS, TESTS A_ND RESULTS, FISHING JOB~, JLrNK IN HOL~ AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CI-IANGF~ IN HOLI~ CONDITIONS. Ran & landed 2-7/8" tbg strings, Baker Model D @ 5466' & dual pkr @ 5420' rmvd BOE's. Instld & tstd xmas tree. Displaced mud w/wtr. Set plug in N nipple. Pressd short string. Set dual pkro Tstd dual pkr 1500# OK. Zero press on both strings, pressd long string w/gas from 21-5. Flowed & cleaned up both strings. LS open flow tbg press, 450#. SS open flow tbg press 1575#. RD test lines. Instld protective cover over xmas tree for rig move. RIG RELE,ASED ,,~@,,.,10:30 am 12/!1J_69,,. sm~~J~'~?.~J/ /~ =~ Dist. Drlg, Supt. DA~ 1/6/70 ,.. · ? ~ ~ I, J~, i~ L,,~'r~T_~'~v-! ,.,,,,., .................... NOT£--Repor[ o~ J~orm is rgquired for each cale~da~ month, ~egardless of the status ot opera%io~s, and must. be tiled in duplica%~ with the Division of Mines & Miae~als by %he 15th of the succeeding mo n%h, unless otherwise directed. UNION OIL & GAS DIVISION WESTERN REGION ANCHORAGE DISTRICT TO: STATE OF ALASKA TRANSMITTAL DATE' January 2, 1970 FROM- G.H. Lau~hbaum. Jr, WELL NAME' _Kena! Unit 21x-3z . Transmitted herewith are the following: Run No. Final Sepia Blue Scale 1 2I! Induction Electrical Log Dual Induction Laterlog BHC Sonic/Caliper Log BHC Sonic/Gamma Ray BHC Sonic/Caliper/Gamma Ray Log Formation Sonic Log (Fs) Compensated Formation Density Formation Density Log (Fd) Neutron Log Formation Neutron Log (Fn) High Resolution Dipmeter (HDT) CDM Safety Print CDM or Printout CDM or Polywog Plot CDM Polar Plots Proximity Microlog/Caliper Log Gamma Ray-Neutron Log Gamma Ray Collar Log Cement Bond Log Sidewall Neutron Porosity Log Laterlog 3 Mud log Core Descriptions, Conventional, No. Core Descriptions, Sidewall Core Analysis Formation Tests Directional Surveys Core Chips Sample Cut RECEI PT ACKNOWLEDGED' RETURN RECEIPT TO' ~ ~4,2, /~c.~ ~ DATE' / - '~'--/' ~x~ - Union Oil & Gas Division - Western Region Anchorage District -'- P. O. Box 6247, Airport Annex Anchorage, Alaska 9950.5 Attn: Rochelle Carlton Form ~o, P--4 STATE OF ALASKA OIL AND GAS CONSERVATIO. N COMMITTEE SUBMIT IN DUPLICkTE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. WELL WELL OTHER =. NA/~E OF OPE~%ATOR Union Oil Company of California 3, ADDRESS OF OPE/~ATOR 507 W. Northern Lights Blvd., Anchora~e~ Ak. 99503 4. LOCA/~ON OF WF_J~ 43-32 Drilling Pad, 1900'N & llO0'W of SE corner Sec. 32, T5N, RllW, SM. ~ ' ~ 8, ~IT,F.~ OR LEASE N~E --- Kenai Unit WELL NO. KU 21X-32 10. FJ.J~.,D A-MD PO{)L. OR WILDCAT Kenai Gas Field .... h. s~,d., T., R., ~., ¢~m~'O~ OB,m--,CTrVFD Sec. 32, T5N, RllW, SM' 12. PERMIT NO. 69-100 13. REPORT TOTAL DEI~TH AT F2qD OF MONTH, CPIA~N'OES IN ~O~E~Z~, q~SI~ ~ C~TING'JOBS INCLUDING DEPTH SET ~ VOL~ USED, P~O~TIONS, ~TS ~ ~S~:~~;~O~, J~K ~ HO~ ~D SIDE-~CKED HOLE A~ ~Y O~R SIGNIFIC~T KENAI UNIT 21X-32,.....NOVE~ER...1969 DIVI$10~ OF SPUDDED: 7:00 am 11/5/69. Drld 12-1/4" hole 8'-347' KOP. Drld & DDrld 12-1/4" hole to 1220'. Opened 12-1/4" hole to 17-1/2" hole 0'-1205'. Ran 30 j ts 13-3/8" 61~/ J-55 buttress csg. Hung w/ shoe ~ 1195'. Cmtd thru shoe w/476 sx "G" mixed with 1/2 cu.ft, perlite per sk, 6% gel, 1% D-31, 2%. CaCl2 followed by 200sx "G". Good returns to surf. W0C 8 hrs. Cut off csg, instld 12", S900 slip on weld Cameron csg head. Tstd 1500~/ 0K. Instld 12" 3000// Dbl Sba/f er & Hydril BOE. Kill & choke manifolds & flow lines. Tstd blind rams:,.& csg w/2500# 0K. RIH, tagged top cmt ~ 1146'. Tst BOP's 0K. Drld out cmt & shoe. C0 to 1220'. Drld 12-1/4" hole 1220'-34A0'. Worked pipe & spotted diesel around outside of collars, unable to free. RU dia-log. RIH, /nd free point. Backed off in btm of BS DA#1. ~ Dia-Log. Chained out of hole. PU da. RIH, stabbed into fish, began jarring. Broke brake band, unable to move pipe or to circ. RU Dia-Log. RIH to back off fish in order to circ to prevent sticking of fishing tools. Shot 8 top of fish to back off. Backed off collars of fishing string. Pulled to shoe. Repaired brake band again. RIH w/bent singles, screwed into fish, unable to braak circ or pull fish. Ran free point. Free @ top of fishing collars 2056'. Stuck @ 2080'. Backed off @ 2056'. POH. RIH w/oedp to 2056'. Mixed & pumped 140 gx "G" cmt 1% CFR-2, 15% sand. Theoretical top plug @ 1850'. CIP 6:50 pm 11/19~69. PU da. RIH to top cmt plug @ 1901'. Jumped plug. D & S 12-1/4" hole 1901'-6450'. Made 15 stand wiper trip. Circ& cond hole for logs'. RU & ran Schlum DIL, FDC'& SNP logs. Ran 156 jts 9-5/8" 40# J-55 and N-80 buttress csg. Hung w/shoe @ 6446'. Cmtd thru shoe w/910 sx Class "G" cmt, 1/2 cu.ft, perlite per sack followed by 360 sx "G" w/l% CFR-2 followed by 280 sx Class "G". Good cmt to surf. CIP 4:45 pm 1!_/28/69. Removed BOE, instld 12" 3000# x 10" 3000# Cameron tbg head. Reinstld BOE, tst OK. RI w/bit & scraper. Top cmt @ 6396'. Circ clean. Ran DA GRN correlation log. Perfd F~rm No. P-~ PAGE TWO R~V. 9-~7 STATE OF ALASKA SUBMrr m DUPLICATE ~. API NUA~ER/C~%L CODE O~[ ANQ GAS CONSERVATION CON~AIIIEE MONTHLY REPORT OF 'DRILLING AND WORKOVER OPERATIONS 6. LF~kSE DESIGNATION AXD SEqRIAL NO. 1. 7. IF INDIAA[ AiXDTTEE OR TRIBE NAME OIL ~ W,LL W,LL OTH,l~ 2. N~E OF OP~TOR 8. ~'IT,F.~ OR LEASE N~E UniOn 0il .ComP,any of California 3. ADDRESS OF OP~TOR 9. KU 21X-32 4. ~CA~ON OF W~ 10. FiE~ ~ND P~L. OR %VILDCAT 11. SEC., T., R., M., (BO/~OS{ HOI~E OBJEcrrvE) 12. PER1VIIT NO. 13. REPOI~T TOTAL D~T~{ AT F2~D OF MON~, CI-~'GES IN I~OLE SIZE, CASING ~ C~/NIE/~TING JOBS INCLUDING DEPTH SET ~ VOLUA~ USED, PF~OiR-~TIONS, T~TS ~ I%ESULTS. FISHING JOE, JI3~K IN HOi~E ~tND SIDE-T1R~CKED HOLE AND ANY O~rIER SIGNIFICANT CI~F~ 11~ HOI~ C~DNDITIONS. four 1/2" hpf w/4" carrier guns 5524'-5488' 5448'-5432' 5425'-5416' 5398'-5391' 5369'-5316'. RIH, PO & laid down dp. Ran dual 2-7/8" 6.4# N-80 seal lock tbg w/Guiberson single & dual hydro set pkrs. Now running tbg. · _DWI,SION OF OIL Al~ -v~' ~,. ~ -' .~F~. ~TL~ Dist, DrlK, Supt. mAT~ 12/15/69 NOTE--Report on~ f~rm-is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. UNITED STATES ~ DEPARTMENT OF THE INTERIOR GEOLOGICAi.. SURVEY Budge~ Bateau No. 42-R356,& Approval expires 12-31-60. LAND OFFICE .................................. LEASE NUMBER ................................. U~IT ........................................... LESSEE'S MONTHLY REPORT OF OPERATIONS. . . ~tate .................................. Co~,nt, y .................................... Field ................................................................ The followin~ is a correct report o1' operations and prodz~ctior~ (incl~din~ drillin¢ and prod~cin6~ wells) for the month of .......................................... ,19 ................................................................................ d~ent's address ................................ - ................................. Gompany _..~ ................................................... L .... ............................................................................................... $i~ned ................................................................ Phone ................................................................................... et~er~t's title ....................................................... SEC. AND A ~R NO. paO~vc~D: BARRE~S Or OIL OR&~Y (~ tho~.) GASOL~S~ WATER (~ (If d~, depth: ~ shut down. ~ O~ ~ ~P' R N WE~ C~. FT. OF OAS OA~ONS OP ~ARREL8 or RE~ARKS RECOVERED none, so state) &re ~d r~t of ~st for , ~nt~t of g~) . ' K~!:~_~l?~!_~__2~j4-~l:2_, N(~,yENBER 19.~,9[ con :_inued '' ca~:rie~ guns 55~!4'-5!g°',~o , 5448'-5432 , 5425'-5~16', 5393'-5391', 5369'-5316'. RI14, PC S l~d ~o~ c.p. Ran deal 2-~/8' 6.~(~ i'-80 seal 16ck tb~ w/Gu~berson si~gla [ du~l [r,dro. ~;et pkrs. , No~, turning tbg ~. . . No?~..--There were .................................... runs or sales of oil; ............................................ M cu. ft. of gas sold; runs or sales of gasoline during the month. (Write "no" where applicable.) NoTE.--Repor~ on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. l~Orxn 9-3.'29 (Janualw 1950) 16-.-.'~..5~r"S ~. ,. r. ov~..~r ..,~,.~ ~r~c, UNITED STATES DEPARTMENT Of THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No., Approval expire~ 12-31-f~). L~,~ omc~_.~'~g~_~. .... : ........ U.~T kena~ Unit 21X-32 LESSEE'S MONTHLY REPORT OF OPERATIONS ~ate .... ~%las~ ................... Coz~r~ty ...... ¥~n ~ ~. Bor~ ......... Field .... =____tlanai_.Gas_.Eiald= ................. ~ T]~e foHowin~ is a correct report of operations and prod~ctior~ (i~olwdin~ drillin~ and prod~ci~g wells) for the montlz of ....... ~.°__Y__e_m_.~!_c__r= .................. ,19.6_9__ ............................................................................. ,~er~t,' s address __5._O..7____!'[:__.~_°.r.__t..h_.e..r..n..__L__i..8.h..t..s_._.E..l_.y_d_.~ ........ Compan,. __U_:~.-~=~..~..]~t__C..9_D~£~'.{ of Ca.l. if i Anchorage, Alaska 99503 $i~r~ ' ~.E. Taliey) Pl~o~e ?79' ~.c~ ~ ~ .................. ~.~,~:_-__~.~_~x.: .............................................. ~.~.,,o ~, .. D~f.?/Ed Drlg, Supt, · .~v...~. ,~ ~,,.~.~v ....... ~ ......................................... .__A A.~rl) DA?$ Or. F~. oI~ OAs GALLONS 0F ~XgRr~,O~ ~ REMARKS OF ~ TWP. R ~GE WE~ BARRE~ OF O~ GRA~TY GA~OL~E ' ~W~ (~.'~/ (lf.~ng, de~th; if shu~ down, NO. P~onvcs~ (~ though) RECOVERED ~:~8~. ,,~ ~d r~ult of t~t for . .... - oon~t ~ ~) ' I '~' ' ' SPLDDED: 7:~,)0 an tl/5/~9'. ~1 'I~IONOFOI1 Dr~ld !~-1/~." hole o'.~47' KOP.'Drld ~ DDrld 12'1/4" ho:Lc 't~-~i~]~''''. Opened 12~!/4'' ' ~ ' '~" ~e 0' . ~. o~t 0-55 buttreas no!~ to 17-i/~ ho -i205 Ran 30 j ts 13-3 'g" ~ ~ csg. H~ng ~:'/shce g 1!95'. Cmtd thru shoe w/476 sx "G~' ~ixed wit!i 1/2 cu.ft. per:lite~ per sk~ 6% gel, 1% D-31, 2Z (',aClo~ follo..~ed by ?(~0_ sx "G". Good returns to surf. W~C 8 hrs. Cut off g.~g, ir~stld 12" S~'O0 slip on weld 2ameron csg heard, rstd 150~ OK, !nstld 12" 300(ii~ Dbl Shaffer & Hy~,ri! BOE. Kill & choke ma~ifol:is & flo,;, line~. Tstd b~ind ~ams & csg ,~ ...... ? ~lfi. Rill, tagged top cm~ ~ 1146' Ts~ BOP~s OK. Drl,t out cmt.& .shoe. CO to .220'. Dri. d i2-1/&" hole 1220'-3~I0' WOrked )ipe & spotted ([iese! arou:]d outsi~[e of coil.ars, unable' to' free. ~c;~ din-log. Rib, fnd free point. Bac,,:ed off J.n btm of BS DA~)I. RD . ~ pU ~ - Dia-Log C~:~a:tne~d out of hole da RIH, stab]bed into fish, be~.~an jarr' ~ . . 1~. Brcke b~ake ban~, unable to mc~ pip~ or to cir~z, ~&, D~a-Lo~. ~IH to back off fis~ in order to ~irc to prevent stickinE of fishin; tools. Shot ~ top of fish to ~>ack off. Backed of~ collars of fis~ainE s~r .n~. Pulled to shoe. ~ep~ire.~ b'r~ ke %and a,~ ' 5aln. KI~ w/b~nt ~in~/es, s~rewed int~ fis~., unable t~ break (irc or pull fish. Ran free point. Free ~ t:~p of fishm~ cellars 2056'. Stuck:~ 2080' ~., Backed off ~ 2056. PO~. ~H w/o~dp to 205~'. H~xed & pumpad 140 s~[ "C" cmt 1% CFR-2, 15~ san~. "heoretical top plu~ 8 18~0'. C~.~ 6: ~O pm !! !9/_69.. PU ~a. %IH ~o top cmt plu~ ~ 19~1'. Sumped plu~. D & S ~.2-1/&" hole 1901'- 64~0'. ,~ade 15 ~tand uipar trip Cir~ & cond hole for l~s. RU & ran Schlum DII, FD~ .& ~P ]~oEs. ~an 156 j t~ 9-5/S" 40~~ 3-55 and ~-~0 buttress caE, Hun~ ~ . ./2 cu.ft, perlite w/~oe ~ 64~6' Cmtd thru shoe ~/910 sx Class "~" cmt, pez sacc fo~.low~d by 360 sx "G" w/l% CFR-2 fo!linked by ~SO sx Class "G". Go~d.cm~ to surf. CIP 4~45 pm~!~/2~/~9-_ Removed BOB, in~.tld 12" 3000~/ x 10" 30(0~ C~mar,,n t~c head Reinst~[d EO~, tat OK. ~I w/bit ~ scraper Top cmt ~ ( 396. C[~'c c].ean. Ban DA C~N corr(:lation lo~. Perfd 'our 1/2" hpf w/4" NoTs.--There were .................................... mans or sales of oil; ........................................... M cu. ft. of gas sold; ...~ ..................................runs or sales of gasoline during the month. (Write "no" where applicable.) No?r..--Report on this form is required for each calendar month, regardless of the status of operations, and muss be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by ~he supervisor. · '~or~a 9-329 STATE~'~F A~ASI(~ i ~ SUBMIT iIN DUPLICATE" LONG STRING OIL AND GAS coN'~ERV~TIO~I UJ~,~ iii! ;:; ~ '~ " ...... structions on- " C.,~Mi.TEE reverse side) I ! 50-133-20204 WELL COMPLETION OR RECOMPLETION.~I ~RT ~ND LOG* !°'~-~'~'~x~°~''~ ' --' - ............ ~ :~ ~ [A-028055 TYPD OF W~'~[: on, ~ ~s ~ ~ ~" ' : ': l~.[~I~I~,~'rr-' ._ '- - - .- I .:Unxon 0~ Company Ca~xforn~a ~"~ ~ ~{ t ,507 ~. ~or~hern L~ghCs S[vd., Anchorage, ~l~ska~ 99503 LOCATION Or WELL ~Report location clearly and in accordance with any ~t~te r~quirements)* at ~,~,~ 43-32 Dr~l12ng Pad, 1868JN ~ 1~29'g ~o~ SE c~rner At top prod. interval reported belowm~ D~I :':q 1 2qa~ ~ ~ ~ :~:h~a* q ~: fearn corn r Sec. 32, T5N, R~[W, ~., ~ , ~ '; ~ '=:: Sec~ 3.2~ T5N, RilW, SM 2250'E & 495'S from NW corner Sec. ~2, T5N, RllW,~SM. ~'orm P--7 1.l~: D.A.TE SPUDDED 114. DATE T.b. REA~CId~D 115, DA, T~ CO'IViP, SUSP, O,R .A.B,AiNrD. 181 TOTAL DEPTH, M_D & TVD~I9. ~PLUG ~B~CK MD & TVD[20. IF 1V~JLTI~LE : . ~ r, ~ HOW ~Y* ~i PRODUCING ~T~V~(S), OF ~488}~ - 5524'~ U? per" Kenai B3 4217'TVD - 425Z~' ~ DIL~ FDC~ S~P & GR tron Correlation C~O SIZE 20" 13-3 9-5 SIZE PERFORATIONS LINER TOP ( 1V/~ ~ CASING RECOI~D (Report all strings set in DEPTH SET (MD) 57 1195 (MD) SA. CKS CEM~T* (Interval, size and numb ,~) ..CDF, RKB; RT, GR~:.:.~PC)*[{I?.'Ei~. C~SINGHE4D RT 90' above MSL ..... · :I, 7'2 70 )i' ': Tr0'BIi'~G 5488' - 5524' fopr ~!~2" hpf - : J i:, '": :. N " ' '- ~ .~ -.' I : ..: ,. :.. .=. el none .... ~' ::~ none (MD) 1.DATE FIRST PRODUCTION [ !I~RODEICTION METHOD (Flowhlg. gas lift. pumping--~ize amd type of. pump)cC ' [~/-EI~L qTA. ,~JS (~o~u~ or ~hut . ' J In pending in~tallation of surface facilities :~ ~. ~}' '~ ~;:.. '~: ~}:~?~'.~ ,.~/s~mf~ i~ '~ ,,,= o~ ,,,~. I~o~s ~.,,: ~' I~oxE size I~o~ ~R O~U .-~ O~r. t;?. ~ W*~~ fl G~-O~ ~O' ~ ~w 'mm~' ~s~o ~s~ lc~~ 'o~. J~ ! '.. =' I_ 1. : I ' l o= t ~,s~ o~' 32. A~ACHM~NTS ,,, ~ "~ 4 33., hereby~~d at~c~ i~mation 1. complete and corre,t a. determined from all=available records DiSt." iDrlg. Supt. 12/15/69 ~, , -- X~..E. ~y;r-'- *(~ Instructions and S~ce, [or AdditiOnal Data on ReVerse Side) 'INSTRUCTIONS General: This form is des.igned for' submitting a ~:omplete and correct .well completion"'report end. log on .. all types of lands and leases in Alaska. -.. '- ..: .:: ;.: _ _ Item:...16: Indicate which elevatio"n is used as. reference (Where not otherwise shown) '}'or depth measure- ;' ~ mentsZgiven in other spaces on this form arid in any attachments. ~ ':" .. _ , :. .;.: , - , · . -.~ Items 20, and 22:: If this well is comple.ted for separate production from more than --;one interval zone._. ' (multiple completion)., so state in item 20'~:' a~! in item 22 show the Prcducing interval, or:. intervals,~" ----. .top(~), bottom(~i a. nd name (s) (if/any) far'6nlf the interval reported in item 30;' Submit, a sepa~rate :i~eport - :': ' (page) on this f6ritn, adequa.tely!:_identified,Z;f0~-,each additiOnal interval :'to be' s,eperately produ.ced, show -' ing the additional' data pertinent' to such intervai. : z: -' -~ .... '..'~' ...... :'~' 'Item26: "Sacks Cement": Attached ..Sup~.le-.m.'"e;¥al records for this well sho~.d si~'dw"t'he CleYail:s-.of any mul: ...... '"~ ' : tiple stage cementing and the 'location Of the.c/~menting tool. -q . '- -: "' Item 28:-Sub'mi't a S~pnrate com..pletion..~ei~Sr~:0'~. this form for each:;:inte~gal 'to ~ selffarately produced. : (See instruction foX, items 20 and: 22 above.). ' ' -:'.-" "- --.- ..: SUMMA.RY · OF FORMATION TF~TS INCLUDING INTEt~VAL TESTED. P~URE DAT~ ~ .~-OV~ 'OF OIL G~. ...... ..=~ - 35. G~GIC MARK~ .... . .... . :. OIL CO. OF CALIFC-- NIA DRILLING REC. ORD ~- SHEET A PAGe' NO, LEASE Renai Uini t ' WELL NO 21;(-32 LOCATION ~.0-32 Drilling tau, 166~','-; & i129'W SPUD DATE :-;ov.5, 1969 COMP. DATE L,,'.c. , CONTRACTOR ~c, asta] L)ri~; ,~o,:.~.,,,,' RIG NO._ ' , ~E UNIT ~'-' ~,',:,'~ ] ?. ~r' ., ~'"' 'j ~',. ,i(' ..: DRILL PIPE DESCRIPTION :'-' 1-/ ..... PERMIT NO. 69 - i 0 0 T.D. 44 $0 ' DEVIATION (B.H.L.) COMPANY ENGINEER SERIAL NO A ...... "'5 ~ T.V.D. ~ r,, r; ), 50° ELEVATIONS: WATER DEPTH }:, ,';,) 1 7 B.T. TO OCE~4N:':FLOOP~ R.T. TO MLLW 05' R.T. TO DRILL DECK , //7 a T. TO nOD ZIC f BIT RECORD MUD VfEIJ./ DEPTH & DEVIATION DATE DEPTH 'NO. SIZE I~4AKE TYPE .~ SIZE OUT FEET HOURS ANN. JET DIRECTIONAL ~ ~ ,,,, I ~ 290 3 95 5 347 ].RR .~3~. 651 3(;4 3-1/2 ];bric 7.° 3()' 14' 1146 2RR 12-1/4' Reed YT3AJ 3-15 ~!396 250 ~-1/2 95 310" Cmt &'"shoe 15 !98~ 3R~{ " " " " 12274 289 4 g5 310 53~5' , 16 o?7a~.. . 4 [ ": (;lobe SS3A.'" 3196 q?9._, i3 95 %t()_ {5~°'~ ~,+'""3'[)'TVD 17 3~ a6 5 " Securi -v 53Sj Ti*c, ~0,., :. ] N iiOI, PI]U( I;AC i0 i 901 ' .... 20 !901 6 " hughes OSCS ~-15 "870 969 9-1/o [' 95 ..... 22 569i o "' Ree4 YT3AJ " 4682 99~ "'11-1/2 9q 2c'5 ........... 12/6/69] 5463 ~0 - ' .... , . .... ~ g-it* ~ 9 220 31C', )r-i!] pkr (ret:aJn~,r . / ~. Globe RT3GJ 13-15 t~465 '* ' ..... .~, )rid pkr & cmt _ 9 ~[.).16 15 8-i/" Se S4T 3~i6'I, ., ,,~)rld on retainer ~ ! curity OJ, I50 S 2 4-1/2 z. iS 1 , , ..... , , ~ ....... UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO, " LEASE Kana i Un i t ~ -32 WELL NO. ' lc · ,~ FIELD DATE I 1/28/69 (Cont'd.) 1/29/69 11/30/69 . , 12/ 1/69 E. T. D. 6396 6396 6396 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 9-5/8'! Casing Detail Bottom Top Length # Jts. Description 6446.00 6443.98 2.02 --- 6443.98 6402.31 6402.31 6400,49 6400.49 6398.45 6398.45 5262.10 5262.10 18.50 18.50 -0- 41.67 ! 1.82 --- 2.04 --- 1136.35~ 29 524'3.60 126 18.50 --- 4.12 6450.12 156 9-5/8" Howco float shoe 9-5/8" 40# N80 buttress casing. 9-5/8" Howco float collar 9-5/8" Howco differential self fill coila 9-5/8" 40# NSO buttress casing, 9-5/8" 40# K55 buttress casing Elevation--landed below K.B. Landed w/4.12' above K.B. Totals . . . ~ cmt w/l Circ'd Rigged up BJ Dropped btm plug. Pumped 910 sx class ' .... ' /2 c~.ft, perlite per sack, op gel, and I% nZl added, mixed to a 98# slurry, This was followed by 360 sx class "G" cmt w/t% CFR2 added, mixed to a 116~ slurry and tailed w/300 sx class "G" cmt mixed to a 118# slurry. Total slurry 26t2 cu.ft. Dsplcd w/2728 c.uft, mud using rig pump. Bumped plug w/2000#. Good rets to sfc (approx. 500 cu.ft.). Bled off casing. Floats. ok. C!P '2 , . ~'~ld Cameron CA ~:45 p.m., !1/28/69. Cut p:tcher nipple. Raised BOE Ino, t2"x9-5/8" slips. Set slips w/200,O00#. Cut csg. Instld .Cameron "DC-B" I?" ~'~ 0" '~'~ puuu~; WP x I~,~00# W? tbq head. Tested X Bushing at 3000#, ok. Instid adapter spool ~'o BOE. Re-instld DOE. instld kill, choke and accum, lines. Changed pipe rams. ]'es'ted b tind r~ms to 2500 psi. Testok. RIH w/csg scraper and b~t. Tagged plug at 6396'. PU 5'. Circ. Tested pipe rams, hydril, choke & kill llne to 2500 psi, Tes'ts all ok. Circ and cond. mud. POH, POH. Rigged up Dresser Atlas. Ran Gamma Ray Neutron'Correl. Log. Correlated w/Schl, logs. Perf'd four I/2" hpf w/NCF t'! kone shots 5524-5488', 5448- 5432 5425-5416' 53a8-5391' 5369-53i6' Riaged down Dresser Atlas. w/bit & csg scraper to 6560'. Circ & cor[d mud. POH. Laid ~own d,p. Rigged up & began running.long string jewelry & 2-7/8" tubing. Ran and landed 169 jts 2-7/8" 6.40# NSO Seal lock tbg to a total depth of 5480'. Single packer at 5461' and dual packer at 5245'. Ran eigh'f 2-7/8" blast joints across upper perforations. Tbg landed 16.80' below "0" (K.B.). Long String Tubing Detail Bottom Top 'Length # Jts. Description 5480.53 5479.83 .70 --- 5479.83 5469.71 10.12 --- 5469.71 5468.93 .78 --- '~68.93 5461.53 7.40 --- 5461.53 5456.13 5.40 --- 5456.13 5294.17 161.96 --- 5294.17 5262.89 31.28 I 5262.89 5257.49 5.40 --- 5257.49 5255.84 1.65 --- 5255.84 5245.52 10o32 --- 5245.52 5242.42 3.10 --- 5242.42 5211.37 31.05 I 5211.37 5205.97 5.40 --- 5205.97 19.32 5186,65 167 19.32 17.67 1.65 --- 17.67 16,.80 .87 --- 16.80 -0- 16.80 --- 5480.53 169 Shear sub 2-7/8" EVE 8 rd pup 2-7/8" 8 rd "X" landing nipple 9--5/8" RH I hyd. packer 2-7/8" CX mandrel (used sleeve) 8--2-?/8"SL x 3-5/8" OD blast joints 2-7/8"6.40// NSO Seallock tubing 2-7/8" mandrel (CX) (used sleeve) 2-7/8" EVE 8 rd x 2-7/8" EVE 8rd pup 9-5/8:'(2-7/8×2-7/8) RH2 Dual packer 2-7/8" EVE 8r'd x 2-7/8" Seal lock pup 2-7/8" 6.40// NSO Seallock ~'ubing 2-7/8" CX mandrel (used sleeve) 2-7/8" 6,40ff N~O Seal lock tbg 2-7/8': EVE 8 rd pup. 8~D x 2-7/8 8r,D~ CIW hanger (2-7/8 "~ ~ ~ Elevation--below K.B. 'Total UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO. LEASE Kenai Unit 21X-32 Kenai Gas Field Vy]~LL NO __ FIELD DATE 2/ !/69 Cont ' d. ) 2/.:2/69 2/ 3/69 2/. 4/69 2/ 5/69 2/ 6/69 E.T.D. DETAILS 'Of OPERATIONS, DESCRIPTIONS & RESULTS 6396 6396 6596 6396 6396 Ran and landed dual with long string 168 jts 2-7/8" 6.40# NSO tubing in short string, to a total depth of 5259'. Short Strino Tubino Detail Bottom Top Length #Jt's. Description 5259.t3 5258.43 5258.43 5257.33 5257.33 5248.63 In Packer 5248.63 5245.53 5245.53 5182.34 5182.34 5i76.94 5176.94 31.62 31.62 23.42 23.42 21.32 21.32 17.67 17.67 t6.80 16.80 -0- .70 --- !.!0 8.70 --- 1.45 --- 3.10 --- 63.19 2 5.4O --- 5145.32 166 8.20 --- 2.10 --- 3.65 --- .87 16.80 --- t68 Shear sub 2-7/8" "N" Nipple No Go 9-5/8"(2-7/8x2-7/8) RH2 dual packer Snap Latch 2-7/8 Seallock x 2-7/8 EVE 8 rd pup 2-7/8 6.40# NSO Seallock lubing ~-~/~ CX mandrel (used sleeve) 2-7/8 6.40# N80 Seallock tubing 2-7/8 Sealiock pup w/comb, collar 2-7/8 EVE 8 rd pup 2-7/8 EVE 8 rd pup CIW hanger Elevation Total Tubing landed w/Cameron DCB I0" Nom. tubing hanger 2-7/8" 8 rd x 2-7/8" 8 rd in Cameron DCB 13-5/8" x i0" 3000# WP tubing head. Removed BOE and , ~0~0~. WP 2-7/8 x 7 .~ dual s~ring xmas tree. BPV. Instal'ed Cameron I0" ~ n ~ " 2- /~" . T~sted to 30uu~, ok. Rigged up BJ DsDlcd mud in t~ole w/water. Displaced mud W/water. Attempted to set RHI packer through long si'ring. Pkr did not set,'Sheared sub w/3700#. RiH w/wireline twice atternp1'ing to set Plug in X nipple in order to pressure pkr. Unable to ge~ through X nipple to set plug. RIH w/wireline ?o check all sleeves in long string. All sleeves appeared to be closed. Dsplcd water in hole w/mud. Circ and cond mud. Took xmas tree off. Re-instal ted BPV and BOE. , Instal led kill, choke and accum, lines. Replcd rotary table Tested BC.E ok, at I000 psi. Ri~ged up and pul led short then tong string tubing. Changed the "X" nipple and RHi pkr in tong string. Rill w/long string then short string. Landed tbg w/BPV instal led. Began removing BOE. Removed BOE. Installed xmas tree.'Tested to 3000#,ok. Rigged up BJ. Dsplcd mud w/water. Lower or single pkr did not appear to set. RIH w/wireiine. Set X plug. Pumped into LS. Circ'd to sfc briefly. Pressure suddenly built to 5000 psi. Bled off pressure. RtH w/wireline to remove plug. Unable to retrieve plug after several attempts. Opened btm sleeve in LS. Dsplcd water in hole w/mud. Circ and cond mud. Removed xmas tree. Ins-tail BOE. Test 1200 psi, ok. Pull SS then LS tbg. Lfiid down pkr and sleeves Rig up Dresser Atlas. Set Baker pkr on wireline at 5463'. Pick up Baker locator and Seal ass'y and drill pipe, RIH. RIH. Stab into pkr, circ to sfc (outside of casing) w/400 psi. Pulled out of pkr. Circ. w/200 psi. Circ. Rigged up BJ. Stabbed into pkr. Pumped I0 bbls water ahead. Pumped 30 s× class "G" cmt. Mixed to a 118# slurry. Displc~ w/I bbl wtr and 75 bbls mud. POH w/o reversing. CIP at I1:15 a.m., 12/6/69. WOC until 8:00 p.m., 12/6/69. PU drill collars, and bit. RIH. Found light stringers of cmt 5400-5410' and 5455-5463'. Drld on pkr at 5463'. UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET PAGE NO. LEASE Kenai Unit WELL NO. 21 X-32 FIELDI , ' Keno i Gas F i e I d DATE 12/ 7/6(.) i2/ 8/69 12/ 9/69 ~2/10/69 E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6396 6396 6396 6396 Drld pkr 5463-5465' POH fOr bit change. RIH w/bit #13. Drld remainder of pkr and cmt. to 5514'. CO to 5560'. Circ hole clean. POH. Rigged up Dresser Atlas. Perf'd four I/2".. holes per foot with Ncr II Kone sleets from 5524- 5488' and 5448-5438' Rigged down Dresser Atlas. RIH w/9-5/8" csg scraper and bit to 5560'. Circ hole clean. POH. RIH w/Dresser Atlas wireline to set Baker model "D" retainer-produc- tion pkr. Pkr stuck at' 5015'. Set and released from tool. Rigged down Dresser Atlas. RIH w/bit #14 to drill out pkr. Drill on retainer for 5 hrs w/o penetration. POH. RIH w/mill. ~illed,~. on retainer. Milled on retnr. Made I'. POH. Laid'down mill. RIH w/bi1' #15. Dr-Id on retainer until dislodged same. Pushed btm portion of retnr down hole to 5570'-. Circ .hole clean. POH. Rigged up Dresser Atlas. RiH w/LTaker r,:u~u~'~l "D" retainer' prOduction pkr on wireline. Set' same at 5466'. Eigged down Dresser Atlas. RIH w/Baker iocator and seal ass'y on drill pipe. SCabbed into pkr. Pressured zone below pkr to 600 psi. Test ok. Pul led out of pkr. Ci'rc &cond mud for tbg. POH. Laid down d.p. POH. Laid down d..p. and collars. Rigged up to run *,'bg. Ran and landed LS tubing through Bake,,- pkr at 5466'. Ran and landed SS ting. Corrected tubing detail follows. Long String Bottom Top Length #Jts. Description 5454.13 5473.53 10.60 --- 2-7~: grd pup w/col lar 5473.53 5472.75 .78 --- 5472.75 5471.48 1.27 --- 5471.48 5467.27 4.21 --- (4.27) 5467.27 5465.63 1.64 5465.63 5460.23 · · 5.40 --- 5460.23 5298.27 161.96 --- 5298.27 5266.99 31.28 I 5266.99 5261.59 5.40 --- 5261 59 5259.94 1.65 --- · 5259.94 5249.62 10.32 --- 5249.62 5246.52 3.10 --- 5246.52 5215.47 31.05 I 5215.47 5210.07 5.40 --- 52t0.07 23.42 5186.65 167 '--~,42 t9.32 4.10 --- 19.32 t7.67 1.65 --- 17.67 16.80 .87 --- 16.80 -0- 16.80 --- 169 2-7/8EV 8rd "X" landing nicple 2-7/8EV 8rd x 3-1/2" Buttress w/coliar 4.750" Baker seal ass'y & !ocator (190-47) through Baker ~-~od. D 9-5/8" pkr (i94-47). (4.750.~' ID)w/flapper valve 2-7/8BV 8rd Box up x 3-1/2 EV 8rd pin down 2-7/8 CX mandrel (used sleeve) 8 2-7/8 S.L. x 3-5/8 OD blast joints 2-7/8 N 80 6.40# Seallock tubing 2-7/8 CX mandrel (used sleeve) 2-7/8EU 8rd x 2-7/8 EV 8 rd 9-5/8 (36-47#) (2-7/8 x 2-7/8) RP2 dual packer 2-7/8EV 8rd x 2-7/8 Seallock pup 2-7/8 6.40# N80 Seallock tubing 2-7/8 CX mandrel (used sleeve) 2-7/8 6.40# NaO Sealtock tubing 2-7/8 EV 8rd pup 2-7/8 EV 8rd pup CIW hanger (2-7/8 8rd x 2-7/8 8 rd) Elevation Joints total UNION-O L Co. Of CALIFORNIA DRILLING RECORD SHEET D PAGE NO.. , ' LEASE WELL NO.27X-32 FIELD .Kenn:i G.:~s: Fic!d DATE i1 E.T] D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS I'!, o t t o'.,r: T o p L e n ?. t b g I t s D e :; c r i r~ t: J. o ia 5262,53 5261.43 1.10 :526i. 43 52_~. 73 b 70 In Packer 5~5 5249 ~ ,'- 2,73 .6.~ 5249.63 5156.44 5186,44 51,8'1.04 5].81,.04 35,72 35,72 27,52 27 5~ ' . ~:. 23. q 2 23,42 21.32 21,32 17,67 17.67 16.80 16,80 -0- 1.45 3:10 63.!9 5.40 5145,32 S. 20 4.i0 2.i0 3.65 .87 16.80 166 16 $ 2-7/8" "N" NO CD Nipple, 9-5/8 (2-7/8 g rd x 2-7/8 8 rd) P,R-2 dual pkr 2-7/S snap latch 2-7/8 sc:a].llock x 2-7/g FITE o rd 2-7/8 6.4;i N-gO seal. lock tbg 2-7/8 CX ;.landred (used sleeve) a ,.. c'¢l ,.,. l lock tbg 2-7/g 6,4,: ~,--,., .... a . /,~ ].l pup w/co,:~b coil.ar 2-7/3 ?:U 8 rd pup ~-7/g EU g rd pup 2--7/S EU 8 rd pup CIW han¢zer El,vat ion Total Joi. nts NOTE: Top~n threads on top of ~,'°t~?,', hanger on Long Str4ng. pul_led, liowever, nipple ,,S. ll start straigiit and make up, Re~:~''~,~'! }3~' ' !d '~'' I?.U gJ d.lsplz-:c'ed mud ........ ~ .... ,.oL Inst Xmas Tree. Tested to .>000;'~ '"K .... ]u~, In :', i{[t')plc:, Pressd SS to ,:.>CO p~i. r-,mi w/~Fcr, Rib w/wzreline. Set p_ ~.., ......... pkr Set 0 1200 psi, Blt:ad off press, POli w/wJrc, l:ine, Tested upper pkr to .!500 psi do',,m annulus, No press incrc, ase on .ss, RD BJ no flow on long or short stri, ng. Prcssd long string from well 2]-5. Blo~.:ed ss until cleaned up. Blow,rd ].s from ss tl~ru btm sleew:,. RliJ w/wire- line. Closed btm sleeve in is. !;!owed ls ,entel c].o;~ned u}). 'Inst.,a , s. Surf press on both strings 1600 psi. Blowing ls did not draw do~:n ss press, Ri) test lines. Loaded out rental aqt~ipment, Instl. d protective cover over xmas tree for rig move. · · ~xlt, ""- ~'~" 10:30 am 12/!~./69 UNION OIL CO. OF CALIFORNIA DRILLING RECORD SH EE-F D PAC-,E NO .... LEASE KEN, A! UNIT WELL _-,O. 2 ' .,'- } ] FIELD DATE E.T. D. DE-FAI~ OF' O?E,:-&T';O.~-~.~ D~CRiPTIONS 8: RESULTS I t/ 5/69 I I/ 6/69 I I/ 7/69 i I/ 8/69 I I/ 9/69 I 1/10/69 II/t 1/69 through I i/t4/69 I 1/15/69 651 1220 1220 Opened 1096 t220 Opened 1205 1220 1220 /220 1985 X-._ ~ . Rig ,. =* ~.~. Ii/5/69. Spudded well KU 21' ~? i*- ]:as-ii :-T:;lmg Co · ~z _ ^ ..... Drilled and surveyed ~2- t,-- .: e -~ ~i~' :'-~. to PU ~,'~=c-i~l ~tu and Dynadrld from 347' to 65:'. :-'-. _a;: :.;~n Lynadrill. ...... ~' Jumped RIG w/t7-t/2" hole o~e~e-. ._= :_ 1.'- , .... -, .~- . . pin on drill pi~=. To~ ' ' ~- a- ~' RiH w/ Tri Sta-e f:.~;nt tools Cauaht fish Circ'~ n~q~ ~ ' ..... _ ~/;:s-. _a;: :3~n ~Tsnina tools ~n: :.a: drill n~pe. RIH w/hole opener, Opened '£- ':" -:'e -~ 17-i/2" from ~7~' ro t3~~. Jumped pin, Too of fish a- {£~". :~ ~/TFi S'ate fisning toots. Caught fish, Circtd, POH w/fish. La;d down fis~-: -cc-s a~ camaged d.p. R:H ~;'.:~ e otener. Opened 12-1/4" ho~e to 17-~''2'~ ;-:~- i;'55' to :205'. Cite': :--s u~. tZade short wiper tri~- C~rc'c. ~-'.: ::-: -' : -c, ~u~ csa PC-H. '-:~ cc-~-n H 0 Rigged up and ~an ~ ~ts ~;~- <-g~ ~:~-"sss cs~. Baker float shoe at !195~, Detail as fo ltows' Bottom ToD 1195.12 1193. i5 i."- -- !!93 15 il52 77 ~^ . . . ~u.5~ ; 1152.77 1151.i4 1.63 -- t!51 14 19 ~ Ii3~ ¢' -' 19,30 -0- i9.Z~ tl95.12 -:-' -" E,a<er Slid iT. =,oat sroe ~5-~.'5" 5~ <-55 Butt, casi~a ~-=::" =~ke~ float CO:i~r-~uTTress ~!e'~-~cn-~amded belo~ "S" K.5. (Landed Centralizers at ~I~:., 1i4~. ~!: -= '' , , ~., a~: 31 . Rigged u: 3.J. P~m:ed l0 ' ~ ~ ~ '' cu.ft, water ahead. Pumped $× c'a~$ "m'? cml w/i/2 cu .... ~erltte per sack,'6% gel, I¢'*.~ ~ 3t a,,~*¢ =~ .... ~-:~-' -~ aJ:ec, m~xed w/fresh ~t~, to a 96# slurry. This followed w/232 sx -:ass -2" c.m'~ w/2% CAS12 a:ceC, mixed w/fresh water to a Ii6Y s~:rmz. -cra~ s~arrv 1!92 cu.f1'. ~:s2iaced w/t76 bbls mud w/rig p..,,, _ u~D. Bcmze: ;. _: ~/15~3 :$i cood cmt. :eT~rns TO sfc. Bled off csg. Floats hefd. ~ - .-~ :.~ , I1/~/69. WOC 5 hrs. ~u pitcher nipple. Removed pitcher nl,~te, slip on csg head. Tested ~e~- ;c- :=~ ss;. Test' ok. Ins*Id cou:le Shaffer 12" 3000# BOP an~ hydrit ....... _ ~-~.~ csg ~c,cse. qemoved and tightened csg. Re-insT,c EC£. ;mst!= choke manifold .,/'Car'ercm HRC valve, and kill line. Instld accumulator lines, -';.~: ~..:) ?ir.e, a~.d ~".Tcher nip-:-ie, Test blind rams and choke manl¢~d.~, to ~'-~'"z:,..,~ :s;, .:x. ='-?. u2 and RIH w'/D~rtial ,~.~. Upa~;~'e thaw mud line. Pig shut :o-.~- ~-~7: -~.:~,-erizaT;on complete a? Down-completinc winter~zaT~¢- ~-.: re:alr,*g _..~., s Tested p i pe rams, ..... Mydr i I, ;f.e; ~' :cc-i, -;~ i i ann choke I i r::~s, -,¢ , :.,.~=D .. ,/alve to 2500 psi, ok Fount *~ ' " ~ , '' , ,~ ct--- ~- : z5 . - ~ cra: 'foat coi,a: a~ s~oe al' 1~95 Cleaned out to tzzd.;' dr:: =*: ..... s_-,'eve: ,?-I/4" hole - for bit and d a ch=fmC ~ - ~ - - ¢] -'~' ~ ' " ..... = ..... ~= : surveyed i2-i/4 ,.~-~.ie t395- 1985~, POH for d.a. cr~ar:e UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO. LEASE Kenai Unit WELL NO._' DATE E.T.D. DETAILS OF OPERATIONS. DESCRIPTIONS & RESULTS tl/I6/69 11/17/69 1t/18/69 11/19/69 I 1/20/69 II/21/69 /22/69 II/23/69 II/24/69 I 1/25/69 l 1/26/69 !1/27/69 11128t69 2612 3410 3410 3410 2345 4310 4310 4978 5985 6450 6450 6450 6450 POH. Added 12" stab. between monels. Rir. ,. Id & surv d iz-1/4" ho~e frcm _ . oTO~ build- i985-2274'. P0H for d.a. change. Chamme? sTg$ between ~or~e! to 6' ~ inc. RIH w/bit #4 ..... Drld & surv'd 12-!/~"-~,i~ 2274-~'z~d . ~?~ to chanme~ ~+m~, stab. RIH. Drld & surv'.d 12-1/4" hole ~525-2612'. D'rld & surv'd 12-t/4" hole 2612-3196'. ::.'~ for bit change. -F':H w/bit ~5. Drtd & surv'd 12-1/4" hole 3196-3A10' St~ck pipe while surveying at Worked pipe. Unable to free. Jars and :~;er sub not operating. Pumped 50 bbls diesel w'/~0 sx asphalt =--~ into hole. S:oTted 20 Dbls out- side collars. Staged remaining oil a~:rc×, i bbl Der 15 -i~. Oil did not - ~a~ked seem to help. Rigged up Dia Log, RIH ~c~ s ~ree point a" ~er s,jD. off at btm of bumper sub. Rigged dc~n ~ia Log. POH. -ql~ w/nwdp on btm w/fishing jars, bumper sub and 6 co!lars cn dp. Screwed irto ~ish at 228~' and started jarring. Brake band broke, u~azie to circ or m~ve pipe. Welded brake bands. Cont'd welding brake band. Rigged up 2ia ,o~. Run shot to sack off top of fish. Backed off above fishing collars. ::::led 12 stds. :imished re~airs to brake band. POH. R1H w/bent single c~ c.p. Unable to s~re~ into fish. POH. Straightened btm single slightly. A!H. Screwed into f;sn. Could not move fishing collars. Rigged up Dia Lo~. ~!G w/free~oint indicator, Ail collars stuck, BO at top of collars _~t 225~'. PGH, . RIG wZ^-en~,~ end d.p. to 2057'. RU BJ. Pumped t0 cu.ft, wtr ahea~. ~mped 140 sx c!ass "G" cm? w/l% CFR2, and 15% sand added, mixed w/fres' ~a-er to a 124/ slur~'y, dsplcd w/ 23 bbts mud. Pulled 5 stds. Circ'd. PSH. C~P 6:50 p.m., !'/19/69. Measure and-caliper monels, stab, drilling collars, and ",~':m. ~,~ake UD btm hole d.a. RIH. Found top of plug at 19~~. ~ td & surv'c !2-1/4" hole 1901- 2345'. Drld & surv'd !2-:t'~$" hol, 2345-2870'. u:,2,~ -..'or d.'a' and b;t change. PU reamer and RtH w/b!t 5'7. Prid & surv'C ~£-~/4" hole 2870-3~91'. Broke rotary shaft. POH to replace rotary. . Completed replcg .rotary. RIH. Drld & surv~''-~, ~,_, t2-1/4" hoI~ ~rom 36gl to 4t20'. POH for d,a. change. Repair rotar-/ szroket. RIH w/12" stab above bit. Drtd & surv'd 12-1/4" hole 4120-4310'. Drld & surv'd 12-1/4" hole 43t0-4682'. PS:~ to change btm stab. Sleeve to increase rate of drop. RIH. Drld & surv d ~2-1/4" hole 4~z-~78'. Drld & surv'd 12-I/4" hole 4978-5674'. :C~ To PU reamer above bit. Ri~. Drtd & surv'd 12-!/4" hole 5674-5985'. Made 5 std wiper trip thru tight hole. C;rc and cond mud. ]rid & surv'd 12-1/4" hole 5985-6450' Circ btms up. !,'a:e wiper trip to shoe. Circ & c. ond mud. Circ & cond. mud. POH for "E" Iocs.~ RU ~-~'~u:~.erser.~ 17 ~,,rs a?tempting to Icg w/o success. Called for replacement To.ois and truck frc.m Scht. RIH w/da. RIH Circ & cond mud P0H Ri~, ' ~ ~ ~' · .... ~ged up 2c~,i, Ran ulL, F:C, and ct,;r- togs Rigged down Schl, RIH, Cite & cond mud for csg. POH. POH. Laid down stab., collars, rmr, uo, ers & b.s. Ri~.:.:.,,,:~ ua and ran 156 jts 9-5/8" 40// NSO &K55 buttress csg, : ..... e: w/Howco f loa'~ shoe at 6446'. Centralizers. at 6426' , 6396' , 6356' , 5Z,!TM , ii6' , 76' , ,'~ _,='-. LEASE. ;,e~ai Unit N~'.21X-3~u- FI-ELD r'"'~';'~ Gas Field WELL CASII'~G & T _ UB,.',G RECORD SIZE I WEIGHT THREAD GRADE t 20" 94 ff 13-3/8"[ 61.~~ buttress K-55 a-2/,~i ar~:~ u,~r. tress 55 - 2-7/8" 6.. ~ sea] lock 6 4ff seail " . o-c~ N-SO DEPTH I~EMARKS 57' Driven Conductor 1195' 6i46' 5256' Baker Float Shoe on btm, YC BET j t 1 & 2 iiowco float shoe o,.,, btm, }io',,,'co FC & }iowco Diff. Self Fi. ll Col].ar ZEY jts 1 & 2 For pkr f sleeve detail, s:et' ~istorv ?ERFORATING RECORD _..1!/30/6) 5316-5369 ~ ~roduct:~ or~ O~en 5391_5398 [' .,, ,, ~ .~q16-54 5432-5448 ' ~ " Cmt between 54~o ~ ~~ " ,, oo-DD24' . 5438-544S ~Rcperfd - Open 54~8-552A ~ " " .. . I , '' , INITIAL PRODUCTION DA'rE INTE_RV AL NET OIL CU_T t " ., t ' ' ,, I ' .I - TYPE: Cameron WELL F~_FJ_~ AS$~I4BLY CASING HEAD: "WF" !2" 3000# WP, 13-3/8" OD slip on w/two 2" 5000# WP fig. CASING HANGER:__Slip & sea]. ass¥. CA 1.2" x'9-5/8" OD CASING SPOOL: DC-B 12" 3000# I~nPX~0" 3000# TUBING HEAD: DC-B 10" 3000# WP x 2-7/8" x 2-7/8" EUE 8 RD Dual tbg assy. TUBING HANGER: i0" 3000# WP TUBING HEAD TOP' "Cross.Type~' Campron F Gate dual string block Idg, btm flgd 10" 3000J-: WP I%%ASTER VALVES: w/2 - 2-9/16" bore master & 2 - 2-9/]6" bore' s;wa?, val. ve.q CHRISTMAS TREE TOP CONN.: 2-7/S" RUE $ RI) Fen, UNI(XN OIL CO. OF CALIFG.RNIA SHEET B MUD RECORD PAGE NO E Kenai Unit LEAS TYPE WELL NO, '- FIELD .-..eh,... :i DiSTRiBUTO DATE|J DEPTH WEIGHT[ VI.S.C. W.i.,. PH SALT OIL SA~D SOLIDS ' .. REM.ARKS 1i/5./~9 590 7~ 91 11.i '-8.5 340 - 5 - 6 1220 ~.0 87 10.,4 S.5 350 - O - , ,. .... 8 J~220 ~0 83 i~.4 9 330 - 6 - Opened t2-1/4" ~o]~". t-o 17-i/2"- ...... ......... , , 1 n I n~l _ !I 1270 79 ,+1 o 0 .~ 5 3 "' 12 ' .1985 ~ gl 41 6.0 12 5 330 - 3 - i6 2519 3z~ 48 '; 6 10 330" 0 5-1/2 - ., 17 3~10 ,,:) 48 ~ 8 9 5 ~00 - 6 - Fish ~ ~;.o.[e , ~)" ', i2 ~ ~ - .... 20 z~0) 75 39 S 0 ,5 ~3~ 3 2i - 3350 80 40 9.0 12 [ 3t~O - 8 - Desi]t. cr rtl.t~Pi~l ...... 22 '3691 79 57 7.0 ~ 9.5[ 380 - 4 - !'Lng de.~ander & d{..tsilt:er ' 23 4615 ~-). . 45 6.: ~ ~ 9.5 1200 - 2-1/4 ~_~, - '24 3235 ~ 77 55 5.2 }9.5 dSO - 2 12 25 0i70[ 79 70 a.8 ~),5 &lO - 5 15 ... 20 6450[ ,~;0 52 5.4 9.5 310 - 2 1..5 {:ond' for ]o:~s I g. ( ' · -- 27 6450 ~.0 50 0 0 9.5 320 ,~-, ]2 , ,. 2b 6450 80 55 O. 2 9.5 310 - 7t~ 12 ~;ond l'~r 9-5/A." '29 0450 79 45 ~;.0 9. 2~50 - 2t 30 645() 78 42 8 .() I0 350 TR t2 12/'2/(:,~ 6450 79 g0-55 8.0 9 ..... Prep to pul'[ tbg 4 '6390 79 48 8 ~1 300, 127 ,, 6 " 79 45 8 9 300 TR 7 "' 79 42 7,5 !0.5 3(~0 '1t 12 ~ , 5~ 25* 4{J b.O i2 gOO 'Tt{ 12 .. , ., ..... .., ,,, , . . . _ ., _ , ..... .... --- - _, . , . _ ., , , , , - ,.. - ~,, ~ ~,~M~.- : , , _ _ _ . . .... ...... . ...... ~.' .-- ... --t " . ' I .... ..... , ... , { - , %.,~,., ~,;.LL ~1~.1'4 I'LMW ~'MII:NIIAL I~bi Muit~-POI~T T~ST 'rest Initial ~ .&nnu~, ~ NI::FrORt Special Field I Reservoir Kenai Gas Field Pool 4 Operator Union Oil Company of California A-O28055 c'oun,y [ Lo~ti,,n 1900' N & I lO0' W of SE Corner, Kena{ { Sec. 32, T5N~ RI1W~..S.M.' I 96'P ~'F [9 5/8 40 8.835 6446' Test Date 7-23-75 J%Vell No. KU 2 IX-32S Total Depth T/~ay 6450 . 1.31' '53]6'-54 2 7/8 6.40 2 7/8 2.441 526 I O. 555 2920 0 . Pipeline Connection Nlkiski Pipeline ~lultlple Completion (Dual or Triple) Duo l · ,! , jType Taps Flanqe IType production from each zone Gas OBSERVED DATA Flow Data NO. of Flow j (Line) (Orifice) h Press.. Press. { Temp. Hours Size Size psig w pslg' t psig i 'F · , . .... . ..... ; si I { t 137.0 t ; 3.826 2.500 I !2.96 ~ !275 ~ : 64° 3.826 2.500 1 I 16.00 1253 I ~ 65° 3.826 2.500 I I 29.03 1168 ~ ,: 64° FLOW CALCULATIONS cient P ' Hr.) . m , 34. 147 34.147 Pressure psla 1343 1290 91.617 129. 300 142.436 2. 3. 34. 147 1268 4. 34...147 I 185.317 1183 t Flow Temp. I Gravity Compress. Factor I Factor Factor ' Rate of Flow F I F F ! Q .MCF D -t g Dy I 6.533 l. 3423 ] 1 · l 010 I 7153 ! 1.3423 t ].0981 t 9292 0..9962 O. 9962 '0.9952 t ._ 0.9962 PRESSURE CALCULATIONS 1.~423 1.3423 ! 1.1065 P ."1 P Cal. = ~v w (pslu) P~ P Q (F Q): (F Q): X 1-e-~ P'* P~ -- P= ' P ~ p .:t c c e w c w w P t e ,.:"- ) , :l · ~ Abs,)lute Potential i n 15,900 .~,er,n1 .4374 CERTIFICATE: I, the undersi&med, state that I am the enqineer of the Union Oi] Compaoy (company), and that ! am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated thereto are true. correct and cutup]ere to the best of my knowledge,a .~_~/~ C~- s~.__atu~ Gary E. Carl son VAS WELL OPEN FLOW POTENTIAL TEST REPORT Multi-POINT T~.ST Test Initial O Annual r"l Special Field J Reservoir Kenai Gas Field Pool 5.1 Operator Onion Oil Company of California JLease A-028055 ¢'ount¥ L~cation 1900' N & 1100' W of SE Corner, Kenai Sec. 32, T5N, RI1W, S.M. r'r,,,,uc,n~ Thr, R,,,,~'ol~ w~,h,d CS~. S,., J ,,'t/Ft. J~UG.i. cs~.jt t,,~p,,~,97.~, lUr' ' T,.,,pe~,~.,,~.r 9 5/8 40 j CompleLlon Date j 12- 11-69 I.D. j Set ~ 8.835 J 6446' Test Date 7-23-75 !V/ell No. KU 2 ]X-32L To(a! Depth T/Pay 6450' 36; f ~':'~": ,~88 TBG.2. 7/8Size Wi/Ft.6.40 2 O.D.7/8 ' 2.I'D'441 5480'Set @ (;as~ep~a~o~. Gra~lt)' ~e~6I~'~v~' Proc). 3041'aL Ga~-Liq,,idRalio bifFH) ~,':carbcape: BS1. iJ Li,4~i6, .(OD · Pipeline Connemlon Type Taps Nikiski P. ipeline Flanqe Multiple Completion (Dual or Triple) j Type production from each zone Dual J Gas _ _ , .......... i 1,1 ,Ill II I I I Il , II Il II I Ill Ill II I J Ill , , 111 , , , ,1 111 OBSERVED DATA Flow Data Time (Prover) (Choke) Press. Diff. Tubing .~o. of Flow I (Line) (Orifice) h Press. J Pre.ss. j Temp. HoursJ Size Size psig w pslg I ping i 'F i, ............ , "',.L'! ' ~ L8~.'.. i ..... 2. ~.0:.0".' "i ,, ';..'.. "!2., 0 it ,~.~ ! ...... . i'. .... ~6° ...... ~. i i 3.826 ' 2.500 , i. 5.29 13i5 i 65° s. I ! 3.826 ' 2.500 J 9.77 1275 i 65° ~-_ .... I J 3.826 2..500 j 22.80 I 165 j 65° FLO%V CALCULATIONS Coeffi- cient -(24 Hr.) ' ]4 .,,l,4. 7,, 2. ---~/h p Pressllre psla Flow Temp. j Gravity j Compress. Factor J Factor J Factor Rate of Flow F. ] 'F F ! Q MCF D t g pv : ,. , .... 53..520 1364 0.9943 ! 1.3423 i 1.1069 { 2700 34.147 ' 83.879 1330 0.9952 ! 1.3423 I 1.1055 I 4230 34.147 112.264 1290 0.9952 i 1.3423 ! 1.1026 i 5646 34.14~ 164.024 1180 0.9952 i 1.~423 J 1..094~ i 8188 PRE,St'RE CALCULATIONS Cal. ~ w w P: F Q (F Q)~ (F Q): X 1-e'~ P: P~ - P~ ' P ' 'lg' - (psis) .t c c c w e w w j F tJ c Ab~,)lute J'oteiltial j !! ] 5,900 MCI-','I')I · 5229 CERTIFICATE: I. the undersigned, state that I am th~' engineer of the Union 0J I Company (company). and that I am authorized by said company to make this report: and that this report was pre- pared under my supervision and direction and that the facls stated,t~erein are true. correct and complete ~o Slgnatur~ Ga r:y i. Ca r l son ~ .05 ~ '. 02 . O1 10 OAS FLOW RATE 2O 5O zoo GA.c )L OPEN FLOW POTENTIAL TEST PRESSURE CALCULATIONS (Supplement to Alaska'O & GCC Form No. G-I) Field Kenai Gas Field Operator Union Oil Company of California Reservol. r Pool ~.1 Lease A-028055 Test (I) (2) '(3) (4) Ps Pf (Ps2- pt2) Q No. msia 0~ie X I04 ;.~CF/D ~ ...,~ ,., ]~,,~,. ..... , , 1 1387 1364 6.33 2700 _ 2 1387 1330 15.49 4230 ...... -3 1,3,90 ...... 129~, 26.80 .,.5646 4 1390 ll8p ,' .... .~,.97 8188 Test Date 7-23-75 ;','eli ;~o. KU 21X-32L Sub-Surface Test Data -. Subsurface pressures measured. ~ S6bsurface pressures computed: 'Cullender-Smith ?,ethod of IvaC. (I) (2) (3) (4) Test Pws 0 . (Pws2_pw;f2) Q No. psia psia X I0-4 ,".!CF/~ .... · · , Nomenclature: Ps = Static surface pressure '~f___= Flowing surface pressure Pws ='Static bottom-hole pressure (mid-point of perforations) Pwf = Flowing bottom-hole pressure (mid-point of perforations) Q = Flow rate, MCr per day at 60~F and 14.65 psia 1-70 GAS r .... OPEN FLOW POTENTIAL TEST PRESSURE CALCULATiO;~S (Supplemen]r to Alaska'O & Gcc Form No. G-I) Field Reserve l.r Tesi Date Kenai Gas Field . Pool 4 ,. 7-23-75 Operator Lease ;';el I Union O_,i.1 Company of ,Ca,1 ifornia., ~. A-028055 .KU 21x-s.2s (I) (2) (3) (4) Test Ps pf (ps2_ pf2) 0 No. o~ i.a . D~ i ~,.. X I04 .. ~,.,"C~'/D.. · . I 1385 1343 11.46 4633 2 1385 1290 25.41 .,, 6533 ., 3 .... 1385 , , 1268 31.,04 7153 4, 1385 .1183 51.87 ,, 9292 · ,, Sub-Surface Test Data Subsurface pressures measured. Subsurface pressures computed: Cullender-Smith ?,ethod of lu~C. .... (I) ........ (2) (3) " (4'J Test Pws 0 ' (Pws2-pw~2) Q No. psia psia X 10-4 ~,~r~-.,,~ ~ , - , · . · Nomenclature- Ps : Static surface pressure -i~f~_: Flowing surface pressure Pws ='Static bottom-hole pressure (mid-point of perforations) Pwf = Flowing bottom-hole pressure (mid-point of perforations) Q = Flow rate, MCF per day at 60°F and 14.65 psia 1-70 Kenai Gas Field Back P? ~:~sure Tests Well N~,/21-325 Pool: 4 Survey Date' 7-23-75 1.O ' .10 .05 .J '.02 · .O1 1..o 2 5 l0 2o ~o lO6 GAS FLOW RATE }/IMCF/D GAS WELL OPEN FLOW POTENTIAL TEST REPORT PRESSURE CALCULATIONS (Supplement to Alaska 0 & GCC Form'No. G-I) Field ........... ReserVo,Lr Test Date Kenai Gas Field Kena,i Sterlinq Gas B°ol,4 "' 3-4-70 Lease Well No, Operator Union Oil Co. of Calif. Anchorage 028055 21X-32S Surface Test Data ,, , ' Test (I) (2) (3) ~) Ps ' .Pf' (ps2~f2) Q . ..No. . .... ~,$ia ,,,~S~, ,. X MCF/D , I 1565 1518 14.49 3781 . 2 1565 1480 25.88 5616 3 1565 1415 44.70 .. 7663 4 1565... 1335 .. . 66.70 9497 1-70 Sub-Surface Test Data Subsurface pressures measured. Subsurface pressures computed: Cullender-Smith Method of IOCC. (I) (2) (3) (4) Test Pws -Pwf (Pws2-pwf2) Q No. psia _]psta X 10-4 MCF/O i 1720 1692 9.55 3781 ..... 2 1720 1681 13.26 5616 3 1720 1661 " 19.95-- 7663 · 4 1720 1638 27.54 9497 , , , , Nomenc I ature: ps = Static surface pressure P:f' = Flowing surface pressure ' P~s =-"Static bottom-hole pressure (mid-point of perforations) Pwf = Flowing bottom-hole pressure (mid-point of perforations) Q = Flow rate, MCF per day at 60°F and 14.6~p~i~ ~ ;,, ~ ~ Form No. G-1 REVISED : JAN. I, 1969 STATE OF ALASKA OIL AND OAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE GAS WELL OPEN FLOW POTENTIAL TEST REPORT 4-POINT TEST Test Initial. [~] Annual D ~peclal Field j Reservoir Kenai Gas Field ! , ...... Ke~nai Sterling Ga Operator I Lease Union Oil Co. of Calif. AnChorage 028055 cuunty Kenai !L°cati°n 1900'N & IIO0'W of SE Corner Sec. 32' BorouqhI T5N~ R! IW~ SI~ ...... ,,. · ,~ I!?! [,69I 6450 Producing: Thru [ Reservoir [ Wellhead { C$0. Size [ ~,Vt/Ft. ] LD. T~G. [ CiG. Temperature ~' Temperature 96'r 175-80'F 9-5/8 40# 8.835 6446 TBG. Size 1Vt/Ft. I O.D. I LD. .... [ Set @ [ GasGravtty [ ivi. Proi. [ GL I Gas-LiguidH~drocarbon 2-7/8 6.40# 2-7/8 .... 2.441 5261' ~ef ~a~ ~ff~ ir,)2920 Ra.~ .MCF pr, Bbl. Pipeline Connection Type Taps Nikiski Flange Test Date 3-4-70 ~Vell No. 21X-32S T/Pay [ Producing 131' 5 ~T'~aL544 Gravity of Liquid (Apl) 0 ° Multiple Completion (Dual or Triple) { Type production from each zone Dua I ..... { Gas OBSERVED DATA Flow Data Time (Prover) (Choke) Press. Diff. Tubing Casing Flowing No. of Flow (Line) . (Orifice) h Press. Press. Temp. "' Hours ~ Size Size psig w pslg psig 'si ' ' 0 3.825 2.500 ' 1550" ' -"' _ ,.'"'1'550,'' . · Packer],,' -' ' ~. .~ I 3.825 2.500 1492 4.,.00 , [.503 Pa.c. ker .. 86.0 , , , :. . I ' ' 3.,825 ., 2.500 , 1447 , , 9.00 ..... !465 Packer 76° :. '-I ' ,' "3~825 2.500 '" 1379 ~ 17.64 1400 PaSker .', ', ,75'~ .t ,~ ~ I.' ,,'1' '3"825 2.500 I 1291 ...... 29.16 1.32,0 ........... Packer. , ,75° .... * I soch rona I ~ - '" FLOIV CALCULATIONS · Flow Temp. Gravity Compress. Coeffl- -~ h p Pressure Factor Factor Factor Rate of Flow ~0. cient F F F Q MCF/D (24 Hr.) I w m psia t g pv , ,. 34. 1468 77.6340 1507 .9813 I.~5423 '~' , 1.0827 . 3781 . ,.. .... ].] 34. 146~3 11'4.7070 i'462 .9'8~0 ' '1.3423" I.'0844 5616 a. 34. 1468 156.8330 13~'4 .... .9859" 'l .'3423 1'.'0'813 .... ' 7663'" ~. 34. 1468 ' 195'. 1'22.0 i306 .9859' 1.3423 .......I .0771 9497 , ' , , , ' r ' , ' , ~ " " J [ '1 IH , ' ~ ! , PRESSURE CALCULATIONS Absolute Potential { n 51,000 MCF/D .0. 732 the undersigned, state that ! am the P.rod. EngQ the Union Oi I Co. of Cai if. (company), and that ! am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein are true,/~-orrect and complete to si J.E. Church Form No. G-1 REVISED : JAN. I, 196~ STATE OF ALAS~ OIL AND GAS CONSERVATION COMMITTEE SUBMIT l~ DUPLICATE GAS WELL OPEN FLOW POTENTIAL TEST REPORT 4-POINT TEST Test Initial [~] Annual D Special , Field I Reservoir t T~est Date Kenai Gas Field Kenai Sterling Gas Pool 5.1 3-30-70 Operator l Lease f i %Yell Union Oil Co. of California Anchorage 02805 J 21-32L ('ounty [Location 1900'N & I'lO0'Wof S COrner c0~uo,~,t, ]~otalDepth" Borough Sec. 32 T5N, RI IW, SM . 12-11-69 ] 6450 36 ~gg[552~ 97 '~ ' 9-5/8 40~ 8.8~5 6446 ~ ,, , , Pipeline Connection Type Taps Niklskl r~anqe , , , ,, ~Iultiple C'ompletion (Dual or Triple) ] Type production f~m each zon~ OBSERVED Flow Data Time (Prover) (Choke) Press. Diff. TUbing Casing Flowing No. of Flow (Line) (Orifice) h Press. Press, Temp. Hours Size Size psig ' w psil!~ pstg 'F ~. I ,3.826" 2.500" 1498 4'00 1515 ,,, Packer , 65.0 2. I 3,826" 2'.500" ' !'444 9.61 ', 146'5 Packer ,, 64° 3. ', , ,,i , , 3.826" 2.500" '1379 14.67 1402 Packer 64° 4..... I . 3' 82r6'1.'. i r [ 2..5.00" , , 1359 .... 22.09 ....... !,.38,0,, ." i,',P.ackec '61'° * I soch rona FLO%V CALCULATIONS Coefft- , Flow Temp. Gravity Compress. Llo. cient -~/hw p Pressure Factor Factor Factor Rate of Flow (24 Hr.) m psia F F F Q MCF/D t g Pv ,. 3,4~ 1468, ' .7,7.8130' ' 1,513 0.9952 I,,.34~3' ' ,' .'1..0941 . 388'3 ,. 34.1468 118.3920 1459 0.9962 1.3423 I 1,,0954 , , 5922 3., 34.,1468 151.2560, 1394 0.996,2 1.3423 .... 1.09.54, , 7565 4. ,34.1468 190.619Q 1374 0.999,0 .... 1.3425 ............... 1.0909 ,,, 9,522 PRESSt:RE CALCULATION.~ ~ CaL w w (psla) P~ F Q (F Q)' (F Q)-' X 1-e-s Pa 1~ -- ps p p :t c c c ~v c w w P ,. '-I See Attached 4. Absolute Potential n AN,CHOi~AC ~ 67,000 ~CF/D 0.500 CERTIFICATE: X, the undersigned, state that I am th~ Prod. E~-Qr of the Union Oi I Co. (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein are true, correct and complete to the best of my knowledge. ~ / ' si~nature/ J. ' E. Church o . 2 ' ' 3 4, '5 "6 7 8 9.I0 20 30 40 50 60 7o 8o9oioo ~00 L' 2 3 ~ 5 6 7 8910- ' . .... """' ' FLOW RATE, Q, mmscF/Day . · ' . ':"..~i'".'~*' ,' . .'; ..... ' ..... ,., - " FIGURE 'No. --.' '-" '-' UNION Ot'~_.. COMPANY .... OF CA~ ~FORNtA . . . DELIVERABILITY AT THE WELL NO. POOL DATE i - 2~ OWNER UNION OIL CO, CAS lNG E. Oo MYERS j WIRE LINE SERVICE P.O. Box 57 Kenai, Alaska 99611 283'7819 r,E~ Kenai Gas Field ELEV. SUBSURFACE PRESSURE SURV WELL N^,~E 21 x _32_L____ ~^TE: 3-30-70 LINER DE~RIPTION: ZERO POINT if Perfs, 5488'-5524' DEPT. 6446' ~S,NG~T^,L:?. ?/8", eX ma~rel 5210', 9 5/8 (2 7/8 x 2 7/8) zo,~ U~ Kena~ R H 2 ~al 52a9',. cx mandrel 5261', 2 7/8" x 3 5/8 0 D blast joints 5298~-~60~ cx ~60' 1~7 Baker m~el .~72' point test Element 4200~ K-2,3402 60 hr clock ,.~:K u~,~ 55.5rl' __M^X,MU,., ~MPE,^'~RE 101° of~ 5506' Time Hours 0 2 4 6 8 lO ~sll Head Pressure 1600~ 15oo~ STABILIZATION PERIOD GROSS OIL RATE B/D NET OIL RATE B/D -FORMATION GAS MCF/D GOR C FT/bBL CIRCULATED GAS MCF/D OIL DrY GRAVITY °APl BEAN SIZE CASING PRESSURE TUBING PRESSURE · 4 point test, · 13oo~ Pre S sllr~ ~ 550~' 180Of 1700,~ 16oo~ Hung ins_t. ~ 5506' TLme Depth Defl. Press. SI WHP SI 5506' Flow WHP Flow 5506' SI ~HP 1555~ .823 !7'~3 .820 SI 55_06' . 821 Flow WHP Flow 5506' .819 SI 5~06' ~.822 ~P ..Flow 550_6' .817 SI $I 5506' '. 821 FI_ow l~_dP Flow ~-5Q6' · 81~ S I W.~p SI 55o~_. 822 Beab -- i5ie i% 1727 ~- i56~ ..... 1729 ..... i7~5 i56o~ ]-73] iuog~ ~% 1720 1729 138D# 9 5~; !710 156_2j~ .... ... 17~1 Myers E. G. MYERS WIRE LINE SERVf' E P.O. Box 57 Ken~i, Alaska 99611 283-7819 OWNER UNION OIL CO. r,E~Kenai Gas Field. SUBSURFACE PRESSURE SLIR WELL NAME 21 X 32 L CAS,~G ~LEV. °ATE: 4--1--70 ~,.ER DESCR,~,ON: ZERO ~O,NT 17' Perfs, 6488'- 5524' OEPTH 6J~h6' ~B,N~OZT^,L2 7/8", CX ~ndrel. ~ 5210',9 5/8" (27/8"x27/8") zo~ ..~r EeDai R H 2 D~I 52~ cx ma~rel 5261',2 7/8"x~5/8" 0 D blast joints 5298'-~60', cx mandrel ~60', l~ Ba~er m~el "D" P.K.R. ~67', X niople ~72' · Run static ~radient survey 0t Vertical Depth 1000' 2000' R~A~S: Element 4200~ K,2,3402 3 .hr clock P=K uP~ 5571' ~AXIMUm TEMPERATURE 101° '~'~ Pressure PSIG 1500# i600~!~ ~700~ 1800~ STABILIZATION PERIOD GROSS OIL RATE B/D NET OIL RATE B/D FORMATION GAS MCF/D GOR CFT/BBL CIRCULATED GAS MCF/D OIL DRY GRAVITY °AP! BEAN SIZE CASING PRESSURE TUBING PRESSURE M. DEPTH V. DEPTH PRESSURE GRADIENT 3000' 4000' o o 1574 _1_015 ]000 1610 2~9~ 2000 1~_8 .083~_ ~g4' 8 I~ 0 O0 1718____~0j_2 ~506 42~7 1727 ~8 4250 1731 5571 4279 1750 5000' Myers ow.¢~ U NION OIL CO, E. G. MYERS P.O. Box 57 Kenai, Alaska 99611 283'7819 ¢lE~K~nai GaS Field StJBSURFACE PRESSURE S JP,¥J WELL~AME 21 X 32 L ¢^s~,~ ~u~v. pA~E: 4-1-70 Per_rs_..5488' - 5524' ' 8~r) t DEPT. 6446 ~,~TA,-'2 7/8"," cX mandrel 5210', 9 5/8" (2 7/8"x27/ ZONE Upper Kenai R H 2 ~hml 52/*9', cx mandrel 5261', 2 7/8"x35/8" 0 D blast ,joints 5298'-5460',cx mandrel 5g~-~'" 194-47 Baker model "D' P.K,R. g~67', .nipple 5472'. ~rtical Depth 1000' 2000' PURPOSE REMARKS:: Pk?,K U~ ~ Run static gradient survey. E]ement 4200~ K-23407.3 hr clock 5%71' ~Ax,~um T~:M~'E~A'r~RE 101° .~ -~7/~.~ 5571' M Pressure PSIG 1500~ 1600~ 1700# 1800,~ STABILIZATION PERIOD GROSS OIL RATE B/D NET OIL RATE B/D FORMATION GAS MCF/D GOR c FT/BBL CIRCULATED GAS MCF/D :,OIL DRY GRAVITY °APl BEAN SIZE CASING PRESSURE -TUBINg PRESSURE m. DEPTH V. DEPTH PRESSURE GR'ADIENT 3000' ~,000' '0 0 ].568 ~ ..... 1000 1601 ' 033 22_94 _ 2000 I6~4.1 . 040 3~"~'7 3000 1684 .043 .... 524.8 ~000 1717 ,033 __ 5482 4200 172__2 i ' 0 2 5 f506 423~ 1724 .054 5338 425__0 1728 · 30B _ 5571 42?9 1743 .5].7 __ 5000' Myers GAS WELL OPEN FLOW POTENTIAL TEST REPORT PRESSURE CALCULAT IONS (Supplement to Alaska 0 & GCC Form~No. G-I) Fi el d . Reservo~Lr Kenal .Sterll ng - Oas Test Date Kenal Gas Field ' · oper~.tor Lea~Ol :,'o. 5.: Union Ol I Co, of Cai lfornla An~hor~qe _t3~R0~5 -~1¥_~1 Surface Test Data Test (I), (2) , (3) (4) ps Pf. (ps2' pf2) Q No. ~sia 'ps?a . X I~4 MCF/D · I 1570 1530 2 1575 1480 29.02 3 ~?~ !417 .. ~7,27 7555 ,, 4 1575 1395 5~6 9522 Dead welght tester measurement 1-70 Sub-Surface Test Data Subsurface pressures measured. Subsurface pressures computed: Cullender-Smith Method of IOCC. (I ) (2) (3) (4) Test Pws .Pw f (Pws2-pw f 2 ) Q No. p's i a .. ~.l~S I a X 10 _4 MCF/O · .~- I 174R t '7,~ 2.09 2 1744 1740 I- 3g , 5922 3 ~ 7a~ ! 735 3.83 4 1744 17~5 6.59 9522 Nomenclature: . ps = Static surface pressure P~' = Flowing surface pressure ' ' PWs =."Static bottom-hole pressure (mid-point of perforations) Pwf = Flowing bottom-hole pressure (mid-point of perforations) Q = Flow rate, MCF per day at 60°F and 14.65 psia ~NCLE SEVEeIT¥ LISTANCE -'DEPARTURE ::(::.' 1-':ig'E!>_'" ' :: ' 3.. 2'8 N 1 45' N 2'tW 3,95.98. ": 304.'98. N' ':' 0.86E" 4.01 N 4.26.94 ,--': '3~5'941 ._ ~%~-~';- ...... ' O,05E. 5.1,3 N 0 4.57.~'81, . B66'.8,~,, '. 6.167N--... 1.GSW 6.76 N ._ ~. 6~ E.55 N ., "- '11.16 N 5~9.5'~ -45'8.5~ ..... ::-!:''6-O'g~ 14.14 N 579.35 ~8~,.3,, I~.51N'_., 8.08W 17.4q .N 610.08 519.08 18.90~ : 10.29W 21.52 N 611 7 30',~*' 33W _ = 1.2'8 ....... 21. 1 ....b'.dcc ............. 1,77 12.46E 2.542 2.66 .61E ~.54~ 4.14 9.21W 2.518 6.03 16.16~ 2.~I~ 21.52W 1.966 10.80 25.51W 3.23q 13.9C 27.53~ 2.S74 17.30 2 ........ ';4'3 3 .......... 21 ;'3 801 .. ' , . 830. ::- 781',68 690.68 32.~7N 21.cgW =o 13 b ~C.37N 29.45~ &9.~7 N 59.48 8621,.':". 14 45' 893 ' - 16 30' N 32W -'-'- 856.60 886,33 795.33 924 18 15' N 31W ~.:-1040 .- 22 30' N 1164' 25 45' N 32W 765.60 '54.741 39'67W 67.61 ~.; 35.91W __7~_~ ............ 67~:~.!_ E2,29N 44.21W 76.3~ N 35.36k 5.711 76 .._ 915.77 824.77 70.61N 49.21W 86.67 N 34.87~i .......... 5_?~5 ................. 1022.94 931,94 1.0~.66N 72.07~ 13C.39 N 33.55W 3.663 130._28_ 1134.63 1043.63 154.35N~ 100.62~ 184.25 g7 1 N 32W 11_,t.41 109~'.41 176 Oqi\ 1.14.26W 209 8¢ N ~2.96W 2 ~7~ 209 60 1305.~ 27 45' ~ 33W 1~9.63 116e.63 209.28~ 1~5.76W 249 46 1396" 27 45' N 35W 1~40.17 1249.17 243,.99N,' 160.06W 291.81N 33.26W 1.023 291.49 1501 3C 30' N 36N ~'1-4-30,54 1339.64 287.i1~: 191,3~:W 3z~5,05 ,"; 33 61'7 ~4 45' N 36W ~1521~..95 1434.95 340,60~ 230.25W 411.12 N 34 765 .40 15' N 36~ 1638'.91 1547.91 41'7.96~ 286.46W 506.71 N 34 %~85 50 0' h: 3'7W 1'7.~:0.32 1689.~2 5~?~.561~ 387.88W.. 675.11 ., >,~ 35 2112__ 52_ 0' :,~ _,~6W 1858.51 1767.51 63a'.52~,: 44-6.71W 77=¢.17 ~:,, 1~4>b,57 733,99'N '.519,70W 899.~6 N 2266 53 45' 32,1e~ 1.6c~ 7 5.1C 35.30W i.136 ~99.30 -286.46 P L tL,'.¢ (:., a E ~, A L, r~, 1912 45 45' 1944 46 C~ '~ _1_9.7~ ........ 46 11' TC MC = 178'5 L .... _T_V.._[:__..--._ .! 538_.,_:,_9_--.LA~T._IT]d~C_.:= ......51__7 -__9_6~_ _~'E_C.'"'"~ff_L_::__= .......... N 36!~'~ 17-41,46 1650,46 503.141- 348.35~: 61l,gG ~ 34,6914 O,CCC 611'81- N 36;'! 1763.69 1671'.69 52!.76.~! 361.$t?W 63n.9:_~. N 34.74h 0.751 634.83 N 3614 v~- ' ' ' 9" . -' ,' ~4-7° 1,0.3.7q 16::.74 ~ ...... 5.3S.71N 374.19~ 6=< c: ~' ~: 0 86; 655.78 .. ........................... . -- ~, i ~ ~ -3 · . ~ - :~ ~6~; 1~'::~.0~;,., 1797.09.. ~'29.24h; 439.g61.~ '767.._.~[ *,, :.~.96',, C.4g:q ' '767.68- 3 · -22 :-23.76'5'7 ' 2285-57'.~'-.:.1'O86'.O9N.~ :--.3I_'37 3274.36 .132'8.7'8 2030-.80N 1453.30~' '. 2497.25 N 37'W -'3:562"64: 3471--67 .'` 2.18~,36N I572..03W ; 2694.4S' N .35.6.9N: -..I..0,75 ;2694.45: -, 4803' '42 4'5;' :- N 36~ ---3652.9~ :..3561.96 -.-22=~' ~'~: .... "I621.11W'-:'-:2777.97 N..35-7C~ 1.9'1'4: ,. ' 4991'~, ' 29C1:'31' N., 35.?i.W ,,'. 0.9'3C. '. 2901',28;j~. ~::;i:-5428 _'.-._:..~2:,: '~C' ..--.N 36~ : .-:' 415:1. 98'- _-'-4060.'98~ :!::~:2558.61N'-:';;~I8~;I_';0:~/~h!';:;:!3i'52'''12'-::':N>!35'7~Wi'il`'-~i~2.,409 ~7 3152' ~ 5674 ' 27 15' N 36~ 4370.68 -4279.68-- -2649.73N 1907.24W 3264.75 N 35.7'4W 2-134 32'64.74: .i · ~ 5985:".,.:'-27 0' 'N .38H ' :4647.78 4556.78. ;.' 2760.-9-9N- 1994.1,6W '-',3405.85 N 35.8'3N ~'-~ .6450 ';'-26'45~ '.' N..38W 506~o02- ' A972.02-''-,2925 , , .9~:~: ,2123.02~_ 3615.00 bi 35.96W ~ CLOSURE 3615.00 N 35- 58' i~ : "- ..'" '-:' .,- , ' . . - - 3405.84 0-053 3615.00, {0 -- LNION (~C8, OF CALIF. Kb 2IX-32 WELL CCi~PLETIC. N REPORT -~ *--~-'~ ~ ..... .......;. ;~j t- ~TF; '.'.._~ T~D ':" LSU~,_~_A :.. LfiTITUDE DEP'.fiRTUR~- DIFFERENCE 91. ~91;00 - ' * -- : = ~7~%'E:: ..... ~:'":'~~ .... - - · ........ 300.00 ~ -:. .77-,.-' --.-. n-_~;~::. : '0 · 91_ 491,.00 . ~00.00 8.'6fin .... 2" ~ 8.~ - 'C 92 591.00 5r'r' ...... O0 93 ..... 2_ .69.1. OC i-6 '"'- 6,00.00 28.84N - " ,... _.. ' 18.93,, .? ' 94 N '- ~ 9n 05 - 99 9~ lb ' 1091.00 1000.00 ~7 - ' 119i.00 1100.C0 -136 o _.,ON t79.00N -116.09~ 1 .:~ 0 1291 · 00 55 1391.00 74 .14'91 . O0 )2 - 1591.00 '-6 '_1691,00 )2 1791.00 ,7 1200.00.~_ 222.80N -145.22W q9 1300.00 268.21'N ' -177.66W 64 --- i~ .............. 1400.00, _. ~20.v~N. -2t6oCu~ ,.~" 19 · 1500',00 '::'385.15N : .-262.62W ..... -'_--II1 28 .................................... 1600.00 457.54N -323.81W . 15.5 44 1700.00 '- 563.61N -39~>.~I~ ~ 211 56 ' .......................... 1891.00 1800.00 669.36N -472.75W 276 65 0 1691.00 1600.00 461.23N -317.90W 149 1791.00 1700,00 545.00N -378.76W 193 1891.00 1800.00 631.82N -441.90W 1991.00 1900.00 720.51N -508.74W 289 2091.00 2000.00 814.11N -572.03W 340 -127 44 51 2 2191.00 2100.00 7 2291.00 2200,00 .1002.5:5N -707.64;~ 445 55 3 2~91.00 2491.00 2~91.00- 2691 O0 2300 O0 llCC.4~N -77...7,. 5[:z C~ ..... 2500.C0 129q IVN -,1--.° 4 73W 616 ~5 ............. 2600.C0 13qT.19N -~33.37W 672 56 -" 2_7__9 t :_00 2700.00- "lqq4.8I'N-..:~=1051.7-3~ 728 2891.00 2800.00 15qO.61N - 1 t 21.. 60':,~- 78'7~ 2991.00 2900.6'C ._~6;~,4_..9.p~/. .,~192.~'9;~ 83,? 5697 ,:,'3391.'00:-' .' ..3300'00 '-:.,- 2051.28N -1'468.73.k .... lO4a 4¸7 31. 1528°91~ ' ' 1 85 42 36:91.00 :-:- 164:0 '__5 q ~__._-:. i--i -:i'-'i' :__.-]( :! 16'2 . 34 3'791.00 3'700.00: 2352.9~N · ~ -1.69.1 ° 63~ ' . 1195 33 .3891.00 ' '3800.00 2417 56N -1738.5,.,~. 1223 28 124~ 23 3991..00 3900.00 2475.64N 40,91.00' 400-0.00' i 2527.l~N -18i~-'.~.~,.19~ ' ' 1265 1$ 16 12 419'1'00 .... 4100,00 :: /-.'-2574,86N: -18'5:2].8q~ ,-:-.-' . 1281 4-391,00 '. 4300.00 ,.'.-' 2657.89N -1913.61W . 1.306 13 · ~ ; 5809 ' 449'1.00 · ,~ . 5921 4400.00 2698.04N -19.44.gsw 131~ 12 4591.00 ' ~4500.00 2738.19N -1976.35W 13'3C 12 6145 4-691.00 4600.00 2778o16N -200'7. ~7~ 13q2 4791.00..' '4700.00 ' 2817o88N -2038.61W 1354 1'2 6257 6369 -2069.64W 1366 4891,~0.0 . '4800.00. i.-2857.59N 12 4991.00 -4900.00 2897.31N -2100.67~ 1378 12 - 12 .~ll tO 9 ~ . ~'~]~ --,--_L:.]:]_~..]-: ":, "-~' .~' '"- ' ' ' 'i"-".'~~' ..... "" ~'"?-'-(- ~:' .':' '~. ':'--:~!--':~'L;" '.--- -.~-.";'--'~"' " '' ~7]]]~ . . UNLI~__~.IL_~L' ~:E' CALIF. KU 21X~2 ' WELL CCMPLETIO~~'REPORT 12/C l'-~" LATITUDE:- 'DEP-ARTURE~.i~ ..DIFFERENCE RR ~ OEPT? ,' _.TV_.D' ':: . _.SU~ SEa CC P/~GE 1 · I C&L ECTI,3r~ _ 2o_oo 200(: 1802.00 1711.00 554.69N -'385.80W- . 198 -13 ' 3000 245'9.06 , 2368.00 1-168'.26N .... 823.07W;'"-".' -'.: i-~ ;: '400~ ~,!0'1.00~: -3OlO.O0---...1789.48N' ..-1271.~5W ~ . 5 O00 '.'-- 3801. O0: '.;.-- ': 37 lO. O~ . - . ~ . - ... 5~t " 899 ~58 1339 z 3 AT ,STATE OF ALASKA- Oil' fa 6as Di_v~s~on 2 Direct{on:al .qurv~y~ w/horizo:~tal & ve ctical pl.o~ 'UNION KENAI UNIT 21X-S2 · , ~ , /2 ~ C"' ~-.'" , , KEITH H. AfiLL£L GO~E~LB _ · ') 1015 bYTE£b'ATIO~.L A!RPO~T P, OA~ RF_.L A~tCH&?AGE ~.~502 November 1'9, 1969 Mr. Wayne Rodges, Landman Union Oil Company of California 2805 Denali Street Anchorage, Alaska 99503 Re: Kenai Unit KU 2]X-32 Union Oil Co. of Calif, Operator Dear Mr. Rodges: In reference to the subject drill-site, the following stipulations are required to preserve and protect fish and game resources: · Prior to start of drilling, a gravel pad will be constructed. Access to this site shall be by all-season gravel road. . Prior to the beginning of drilling, a sump of sufficient size to contain all waste fluids will be constucted. This sump -must be lined with material impervious to oil and oil products at all seasons during the year. Prior to abandonment of the site, the sump must be cleaned of all oil and covered. . The operator must dispose of all waste, including garbage, by burning with non-combustible~material and unburned residue disposed of in a manner and a location acceptable to the Alaska Department of Fish and Game, i.e.., in some locations burial may be required, in others removal from the site may be necessary. . Sewage and waste water will be disposed of by lagooning or the cesspool-septic tank method. No stream or body of water will have any sewage or waste water added to it. . The Habitat Biologist's Office, 1018 West International Airport Road, Anchorage, Alaska 99502 wilt be notified prior to closing of this location. · cerely ~yo.Jr ~ / Robe~?d. ~ienhe]d Habi fat Bio]eg is'~ cc: B. Hilliker H. Burrell P. Denton r, ov 2 o 1969 Form REV. ) STATE O,F ALASKA Subrrdt "Intentions" in Triplicate & "Subsc~quent Reports" in Duplicate OIL AN'D GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir Use "APPLICATION FOR PEH/~IT-~" for such proposals.) . WELL WELL OTHER 2. NAMEOFOPERATOR Union 0il Comoanv of Cal±fornia 3. ADDRESSOFOPER~TOR- 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 4. LOCATION O~ WELL Atsurface 43-32 Drilling Pad, 1868'North & l129'West from SE corner Section 32, T5N, RllW, SM. .. 13. ELEVATIONS (Show whether DF, RT. Gtl, etc. HLB - · 5. AP! NUIVIEP~CAL CODE TRM OKG 6. LJEA~E DESIGNATION AND SE~ NO. HWK .......... A-028055 REL '/. IF INDIAN, ALLOTTEE OR TRIBE NAME UNIT. FARM OR LaT. ASE N~VI~J LE Kenai Unit 9. WELL NO. Kenai Unit 21X-32 ' lo. F~,D ~ ~-OOL, oR WILDCAT .... Upper Kenai Kenai Gas ~'meAa-Ga~ Sand~ ' n: SEC.; T, R., ~., (S~ ~O,~ O~E~IVE) Sec..32, TSN, RllW, SM. 12. ~'EPa~T NO. RT 90' above MSL 14/ Check Appropriate Box To InState Nlature af N~tke, Report, ~r 'Other rData NOTICE OF INT]~NTION TO: SUBSEQUENT R~POR~ OF: FRACTURE TREATMENT ALTERING CASING SHOOTING. 0R ACID~ZING ABANDONMEKT* (Other) No~:,'ReP0rt results: of multiple completion on Well ompletio.n :or Recompletion Report and Log form.) TEST WATER SHUT-OFF I I PULL OR ALTER CASING I I FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE J~ ARAND, ON~' REPAIR WELL I "' CHANGE PLANS (Other) Change Surf. Loc. 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pe:rtin'ent dates,..including estimated date of starting an}. proposed work. - This notice reflects change of surface location: only,~ wi'th bottom hole locations remaining unchanged: ~,~ ',~ 9rigina.!ly Submitted: 43-32 Drilling Pad, 1900'North &li00'West from SE corner Section 32, T5N, RllW, SM. Actual Location; 43-32 Drilling Pad, 1868'North &~li29'West from SE corner Section 32, T5N, RllW, sM. Coastal Drilling Contractor Spudded well 7:00 am 11/5/69. 16. I hereby Certify~ .-the f~i~ l~ true and correct ;,:-~ - , -- _ (Thtl space ,or~t~~e~ TITLE . D~ .~f. D~'I g; S,,.nC. DATE 11/10/69 DATE //-/ / / - See lnstrucfions On Reverse Side Ai~;-'r~'ed Copy Re~'urned Union Oil and Gas DJ, ' '~)n: Western Region Union Oil Company of California 2805 Denali Street, Anchorage, Alaska 99503 Telephone (907) 277-1481 ~-~ October .31, 1969 union Division of Oil and Gas 3001 Porcupine Drive AnchOrage, Alaska 99504 Attention: Mr. Homer L. Burrell U. S. Geological Survey P. O. Box 259 Anchorage, Alaska 99501 Attention: Mr. W. J. Linton KENAI UNIT AREA State of Alaska KU 31-32 Well Gentlemen: Union Oil Company of California, as Operator of the. Kenai Gas Field, proposes to drill the KU 21X-32 well from the 43-32 surface pad and bottomed at 2,350 feet East and 290 feet South from the Northwest corner of Section 32, T5N, .RllW, S.M. The initial target is Pool 4, being appro~i~...t;.~!y~ 2,290 feet from the nearest gas well completed in the same Pool i~3~'32)'~ ....'~'6Ts proposed well does nOt conform to Statewide well , dista~'~-"~'f~'quirements and, therefore, we respectfully request an emergency order be granted to allow the immediate commencement of KU '21X-32 based on the f'ol lowing reasons: . This well is required 1~o meet anticipated deliverability requ i rements. 5 . e The proposed location will provide for maximum gas sand development with no water present in the Programmed completion pool. Other locations considered with 3,000 feet standoff from existi.ng completions could not be drilled because of mechanical limitations in drilli.ng to favorable bottom hole location, and Completion would be at a near accumulation limit, increasi~ng risk of the well. With completion in the gas pool with water there would be a possibility of coning water into the well. ~ ~'a located t The only excessable producti n facilities availabl re a the 43-32 pad. i~FiCE~IV~i) Robert T. Anderson District Land Manager Union Oil Company of California 2805 Denali Street,//~tchorage,X Alaska 99503 Telephone (907) 277-1481 union .October 31, 1969 State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska Attention: Mr. Homer Burrell Re: STATE OF ALASKA KENAI UN IT KU WELL 2 lx-3 2 Gentlemen: We attach hereto Emergency Order request together with P-1 Form Drilling Permit for our proposed KU 21x-32 well. Please disregard and cancel our previously filed Drilling Permit and Emergency Order request on KU 31-32 well and apply the $50.00 fee to this Drilling Permit. Thank ~ou. Yours very truly, HV~R/nr enclosure Robert T. Anderson District Land Manager By: ~ ___._-. Form 401 ANC-A (New 7/67) Division of Oil and G~~· U. S. Geol~ogical Survey - 2 - October,31, 1969 The above reasons were integrated in testimony presented to the Conservation Committee in hearing on proposed Field Rules for the Kenai Unit, October30, 1969 and we request that such testimony be considered in rendering your decision. Very truly yours, Robert T. Anderson District Land Manager ~ayn~~es ~ ._ · TYP~ OF WOBIK b. TYPE OF WELL OIL [--] WILL STATE O.F ALASKA OIL AND. GAS CONSERVATION ,COMMITTEE 2. NAME OF oPERATOR Union Oil Company of California SUBMIT IN 'rRIPLIC, (Other instructions on reverse side) APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK DRILL [-Xl DEEPEN I-q PLUG BACK [] '"~8,IiN O L~ M U LT IPL~ WELL 13. ADDRESS (~F OPEKATOR 2805 Denali Street, Anchorage, Alaska 99503 lJljJ ~J~j~ LOCATION OF WELL ~lY~ ur v,b ~ ~ ~-~*.~ ~-~2 ~il]in9 ~e~ - ~00'~ ~ ~lO0'W of ~~~e~. ' ' 1o~;~0~t'~.~ - 25~5~[. S 700~S from the ~ corner Sec. 32, 15~, R]I~, S.g. · DISTANCE IN MILES AND DIRECTION F.'~OM NEAREST TOWN OR POST OFFICE* 7 miles South of Kenai, Alaska 14. BOND INFORMATION: TYPE Statewidesuretya-d/orNo. United Pacific Insurance Co. B-55372 15. DISTANCE FROM PROPOSED* Il6. NO, OF ACRES IN LEASE LOCATION TO NEAREST J 3 24167 PROPERTY OR LEASE LINE, FT. 290 ' J 2, (Also to nearest drig, unit, if any) TO NEAREST WELL D.RILLING, COMPLETED, J OR APPLIED FOR. FT.. 2290' J 6325!HD,5020TVD 50-133-20204 r . 20" Conductor 30' Driven ~ 1~.½" i3-3/8" 61#, . . J-55 1200' 1000 sacks.- to surface 1Il _ ' .... 12~ ,9 ~/8" 40// j&N 6325'l 2~00 s~'ck~'" to surface , i , ,, , Program as follows: Drive 30' -20" conductor. Drill 17½" directional hole to 1200'. Run & cement 13-3/8'l casing. Install '12" series 900, 3000# Hydril, double Shaffer & Hydril with 80 gal. accumulator. Test BOE to 3OOOJ/. Drill 12¼" directional hole to.63251TMD. Rum "E" logs.,.run & cement 9-5/8" casing. Install 12" series 900 x 10" series 900 head. Reinstall & test 12" series 900 BOE. Run correlation log. Perforate upper Kenai B-I, B-2 and B-3, B-4, or C-1 and C-2 sands as directed. Run Dual 3½"tubing strings with single & dual Hydro-set packer.s & complete as follows: Short String completion Upper Kenai B-I, B-2 interval, Poo14 - est. top 5250'MD & 4060'VD. Long string completion either B-3, B-4 interval (Pool 5-1) est. top 5450 MD, 42251VD, or C-1, C-2 interval (Pool 6) est. top 6000 MD, 47lO'VD contingent on sand development and water table position. Bottom Hole Location: 2350'E.&290'S from NW IH ABOVE SPAC~ DI~RIBE ~O~S~ PR~R~: If ~I ~ to dee~n or plug ~, give ~ on p~sent p~u~ive zone ~d cot. Sec. 32 p~ ~w pmdu~ive ~. If p~l ~ W drill or ~n d~ ;o~ly,. give pe~en~ ~ on ~bsu~a~ ~t~ ~d meas~d ~d ~ue venial dept. Gi~ ~ P~. T5N ,R11W, ~. I hereby ~y tl~ the ~~ ~~ S.M. ma~m"//~~ ~ October 31, 1969 ~ Landman (~his spa~ ~r S~offi~ ~) COND~ONS O~ ~V~, I~ ~: 21. ELEVATIONS (Show whether DF, RT, GR, etc.) 22. APPROX. DATE WORK WILL START* RT 90' above MSL November 1, 1969 8, UNIT~FARM OR LEASE NAME Kenai Un i t 9. WELL NO. KU 21 X-32 -10. FIELD' AND POOL, OR WILDCAT Kenai Gas Field ll SEC., T.. R.. M. (BOTTOM HOLE OBJECTIVE) Sec. 32, T5N, RllW, S.M. 12. ~mo,,-t $100,000.00 17. NO. ACRES ASSIGNED TO THiS WELL 320 20, ROTARY OR CABLE TOOLS Rotary JSAMPLES AN~ CORE CHIPS [] Y~S NO DIRECTIONAL SURVEY '~[ Y~S [] NO See ~ansmittal ~tter AP~ROV~ ~v_ *See 'Instructions On Reverse Side DAT~ 11/6/69 6. LEASE DIESIGNATION A2~D SEI~IAL NO. A-O28055 7. IF INDIAN, ..kI.,I.~TTEE OR TH/BE NAME 33- 30 44- 30 PBHL ...-,.~ ~; TMD 6_3_~_', '-~ , TVD 5020 ", K TARGET A TMD 5250~ ',\ TVD 4060 \ \ \ D.U.I "K DU~3 N / / 4:5-12 14 -6 + / / / / / / 21'-7 KDU-4 43 -7 :~ K.D.U. 2 · + T 5N- RIIW T4N--R IIW UNION. OIL COMPANY OF CALIFORNIA ALASKA DISTRICT WELL LOCATION PLAT KENAI GAS FI ELD ZIX-32 DATE: OCT 31,1969 SCALEi i" = 2000' · 0 2000' 33- 30 \ \ · ~t4 4- 30 ~J .._.r.~21X - $2 PBHL TVD 5020 \0~ _..TARGET A fTMD 5950~, T VD 4060 $ 3- 32 ~ \\\ D_IVI~ON OF \ \ \ \ ~K DU-3 T 5N- RIIW T4N--RIIW N KD.U~ 14 -i/~ 21-7 iiiii ~ f KDU-4 / 43-12 43 -7 :~ K.D.U. 2 'UNION OIL COMPANY OF CALIFORNIA ALASKA DISTRICT WELL LOCATION PLAT KENAI (;AS FIELD21X'32 DATE: OCT 31,1969 0 2ooo' SCALE; I" = 2000' ~ company Lease & We11 No. ~Z~x ~ A~ ~ ~ 2-_ ..... CHECK LIST FOR NEW WELL PERMITS Yes No Remarks' 1. Is well to be located in a defined pool ................. 2. Do statewide rules, apply ........................ f)~4 . 3. Is a registered survey plat attached .................. 4. ~ well located proper distance from property line ........... %~ 5. Is well located proper distance from other wells ............ ~ 6. Is sufficient undedicated acreage available in this pool ........ 7. Is well to be deviated ......................... ~'~ 8. Is operator the only affected party ................... 9. Can permit be approved before ten-day wait ............... 10. Does operator have a bond in force ................... ll. Is conductor string provided ...................... 12. ~ enough cement used to circulate on conductor and surface ...... 13. Will cement tie in surface and intermediate or production strings 14. Will cement cover all possible productive horizons ........... 15. Will surface casing cover all fresh water zones ............ 16. Will surface csg. internal burst equal .5 psi/ft, to next string 17. Will all casing give adequate safety in collapse and tension ...... lB. Does BOPE have sufficient pressure rating ............... Additional Requirements: ~ ~le~ oK~/~r TRM , O*7~, REL ,._,.~ KLV OKG L4._L_ ] j , . . ' : I ~ j ' j - I _ ' t- 1 _j J [ _ · . _:,L:;'L'_L:i__-_:.:. _::].2_:LZ_!.,ZZ_ "~'-_.._~ ,. _:'"* :'" _:L.L.; _!:'L. :"!_; _':' .. l'~;'_:.- :"-L"i :. [: i.-'i J +_~.~_.L. j I ~ , : CALIFORNIA COMPUTER PRODUCTS, ING. ANAHEIM, CALIFO!~NIA C:dART NO. 707 1 --i-FF- ' : ' : .... i ' i.~.. i CALIFORNIA CO.~?UTER~PRODUCTS, INC. i ANAH EthYl, CAMFO~NtA CHART NO. 401 10 Dt¥:/INCH .... :~: u,': A.