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Home My WebLink About165-0011a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name:6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address:7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section):8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:9. Ref Elevations: KB: 17. Field / Pool(s): GL: 212.0' BF: ~206' 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" B 216' 13-3/8"J-55 2,000' 9-5/8"P110 N80 9,017 7" P110 15,500 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production:Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 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, 1000 sx, 850 sx12-1/4" TUBING RECORD 500 sx, 100 sx15500' 1985 sx, 15 sx 0 8,891' 18-5/8"0 8,118 MD/TVD 2,512' 8,220' SS 2-3/8" SIZE DEPTH SET (MD) N/A PACKER SET (MD/TVD) LS 2-7/8" 8891' N/A 26# / 29#0 BOTTOM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 3/28/2022 165-001 / 322-069 / 322-147 50-133-10029-00-00 Birch Hill Unit (BHU) 22-25 FEDA028407 1941' FNL, 1895' FWL, Sec 25 T9N R9W SM 1941' FNL, 1895' FWL, Sec 25 T9N R9W SM N/A 1/30/1965 15,550' MD / 15,486' TVD 0' MD/TVD 228' 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 357860.3 2501279.9 N/A CASING WT. PER FT.GRADE 5/15/1965 CEMENTING RECORD N/A N/A SETTING DEPTH TVD 2501279.9 TOP HOLE SIZE AMOUNT PULLED suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 8-5/8" 0 475 sx 0 43.5# N/A 357860.3 TOP SETTING DEPTH MD 0' 0'216' Per 20 AAC 25.283 (i)(2) attach electronic information 68# / 61# 9017' 0 0 78.6# 0'2000' N/A Water-Bbl: PRODUCTION TEST N/A Date of Test:Oil-Bbl: Flow Tubing Gas-Oil Ratio:Choke Size: Sr Res EngSr Pet GeoSr Pet Eng Birch Hill Field / Undefined Gas Pool N/A Oil-Bbl:Water-Bbl: G s d 1 0 p dB P L s (att Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Meredith Guhl at 2:06 pm, Apr 21, 2022 Abandoned 3/28/2022 MDG RBDMS 4/21/2022 xG DSR-4/22/22DLB 04/28/2022BJM 11/30/22 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name:6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address:7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section):8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:9. Ref Elevations: KB: 17. Field / Pool(s): GL: 212.0' BF: ~206' 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" B 216' 13-3/8"J-55 2,000' 9-5/8"P110 N80 9,017 7" P110 15,500 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 Birch Hill Field / Undefined Gas Pool N/A Oil-Bbl:Water-Bbl: Gas-Oil Ratio:Choke Size: Flow Tubing N/A Water-Bbl: PRODUCTION TEST N/A Date of Test:Oil-Bbl: Per 20 AAC 25.283 (i)(2) attach electronic information 68# / 61# 9017' 0 0 78.6# 0'2000' 43.5# N/A 357860.3 TOP SETTING DEPTH MD 0' 8-5/8" 0 475 sx 5/15/1965 CEMENTING RECORD N/A N/A SETTING DEPTH TVD 2501279.9 TOP 0 HOLE SIZE AMOUNT PULLED suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 357860.3 2501279.9 N/A CASING WT. PER FT.GRADE 50-133-10029-00-00 Birch Hill Unit (BHU) 22-25 FEDA028407 1954' FWL, 1835' FNL, Sec 25 T9N R9W SM 1954' FWL, 1835' FNL, Sec 25 T9N R9W SM N/A 1/30/1965 15,550' MD / 15,486' TVD 0' MD/TVD 228' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 3/28/2022 165-001 / 322-069 / 322-147 8891' N/A 26# / 29#0 BOTTOM 8,118 MD/TVD 2,512' 8,220' SS 2-3/8" SIZE DEPTH SET (MD) N/A PACKER SET (MD/TVD) LS 2-7/8" TUBING RECORD 500 sx, 100 sx15500' 1985 sx, 15 sx 0 8,891' 18-5/8"0 0'216' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 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, 1000 sx, 850 sx12-1/4" G s d 1 0 p dB P L s (att Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Meredith Guhl at 3:44 pm, Apr 14, 2022 SUPERSEDED Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval N/A N/A 31. List of Attachments: Operations Summary, Schematic, MIT-IA, Photo document casing cut-off/cement top/welded plate. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Dan Marlowe Contact Name: Aras Worthington Operations Manager Contact Email:aras.worthington@hilcorp.com Authorized Contact Phone: 907-564-4763 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at total depth: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). INSTRUCTIONS Authorized Name: Authorized Title: Signature w/Date: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2022.04.14 13:52:33 -08'00' Dan Marlowe (1267) Updated by AW 04/01/22 BHU 22-25 SCHEMATIC Birch Hill Unit Well BHU 22-25 Last Completed 6/09/65 Updated 3/07/88 TD = 15,500’PBTD = 15,486’ MAX HOLE ANGLE = 1.8° @ 10,066’ RKB: 228’ / GL: 214’AMSL KB –THF: 14.4’ D Tyonek 8 6 7 Hemlock 1 3 5 4 2 DV @ 7,083A B 9 TOL 8,891’ 10 Tag fill 8,752’ SLM 3/02/88 Casing & Tubing Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20”Conductor 78.6 B -Surf 216’26”475 sx Surf. 13-Ǫ” Surf Csg 68 J-55 12.415 Surf 720’18- ǫ” 1985 sx 15 sx Top Job Surf.13-Ǫ”61 12.515 720’2,000’ 9-ǫ” Prod Csg 43.5 P-110 8.755 Surf 2,582’ 12- ¼” 1000 sx 4,950’ Calc9-ǫ”43.5 N-80 8.755 2,582’5,586’ 9-ǫ”43.5 P-110 8.755 5,586’7,083’ 9-ǫ”DV Collar 7,083’7,085’ 9-ǫ”43.5 P-110 8.755 7,085’9,017’850 sx 7,083’Calc 7” Liner 26 P-110 6.276 8,891’10,951’ 8-ǫ” 600 sx 100 sx Liner Lap 12,125’ Calc7”29 P-110 6.184 10,951’15,500’ Tubing Cplg OD 2 Ǭ”, EUE 8RD 6.5 N-80 2.441 Surf 8,220’3.668” 2 Ǫ”, EUE 8RD 4.7 N-80 1.995 +/- 2800’2,512’3.063” JEWELRY DETAIL No.Depth ID OD Item 1 14.4’--Dual Tubing Hanger, Shaffer, 2-7/8” x 2-3/8” Unknown Lift x Suspension Threads, 2-1/2” Casasco BPV Profile 2 113’2.313”2.875”S Nipple, (2.313” I.D.), position #2 3 2,041’2.313”2.875”SNipple, (2.313” I.D.), position #1 4 8,065’--GLM, 2-7/8”, Camco MM 5 8,097’--Cast Iron Bridge Plug 6 8,107’2.438”3.688”CC Safety Joint, Brown J-Slot type (possibly kinked) 7 8,118’2.500”8.250”Packer, Brown Mod.HS-16-1, 5-1/4” Box x 2-7/8” 8RD Pin 8 8,156’--Plug, CA plug (C Lock Body only, No A-Prong) 9 8,156’--Camco ‘D” Nipple 10 8,220’--Venturi Shoe A 109’1.875”2.375”S Nipple, (1.875” I.D.), position #1 B 2,512’--Joint, 2-3/8” turned down to 1-5/8” PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf Comments 05/28/65 Tyonek 8,190' 8,220' 30' 4 Open 05/20/65 Hemlock 14,705' 14,706' 1' 5 P&A 5/25/65 05/23/65 Hemlock 14,710' 14,747' 37' 4 P&A 5/25/65 05/22/65 Hemlock 14,765' 14,820' 55' 4 P&A 5/25/65 20” 216’ 13-3/8” 2,000’ 9-5/8” 9,017’ 7” 15,500’ Calc TOC 7,083’ Calc TOC 4,950’ Tag cement plug 8,810’ RKB 5/26/65 Balanced plug 14,630’-14,860’ Calc TOC 12,125’ Liner lap squeeze 100 sx 10.7 ppg Mud 12.3 ppg Mud 12.3 ppg Mud Mud Mud Cement circ’d through casing punch @ 1900’ up 9-5/8”x 13-3/8”from 1900’to ~1800’MD Cement plug circulated into TxIA Tubing: 2950’MD (EL Tag 3/18/22) to 8032’MD (Tbg Punch) IA: 3000’MD to 8032’MD (Tbg Punch) Balanced Cement plug in 9-5/8”casing from 1705’MD (EL Tag 3/23/22) to 2100’MD Balanced Cement plug in 9-5/8”& 13-5/8”x 9-5/8”casing from Surface to 150’MD 8 9 10 6 5 4 9.0 ppg brine from bottom of cement plug @ 8032’MD to bottom of perfs @ 8220’MD CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Aras Worthington To:McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL] BHU 22-25 (PTD 165-001) 10-407 questions Date:Tuesday, November 29, 2022 2:10:21 PM Attachments:image001.png image002.png Yes – that is correct. Report date, for the work that occurred day prior. Aras From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, November 29, 2022 2:00 PM To: Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] BHU 22-25 (PTD 165-001) 10-407 questions Aras, The 10-407 shows these activities taking place on Mar 15 and Mar 17th. Are the dates on the below summaries representing the report date, for the work that occurred the day prior? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Tuesday, November 29, 2022 1:48 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com> Subject: RE: [EXTERNAL] BHU 22-25 (PTD 165-001) 10-407 questions Thanks Bryan. Below are screenshots of the corrected reports for 3/16 showing the tubing punch and depths and for 3/18 showing the correct cement volume. Aras 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, November 29, 2022 1:32 PM To: Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] BHU 22-25 (PTD 165-001) 10-407 questions Aras, If it’s just a couple minor corrections, I’d rather just update the one that’s already submitted. It will take way more administrative work to review a new 10-407. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Tuesday, November 29, 2022 1:22 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] BHU 22-25 (PTD 165-001) 10-407 questions Bryan, Apparently we have some reporting issues that didn’t get sorted out. I will work to get the 407 re-submitted with all the correct information. Short answers are: 1. The tubing was punched @ 8032-8035’ MD. 2. The cement volume pumped was 363 bbls. The report was typo’d as 263 bbls. I thought we had corrected that but apparently not. Apologies for the errors in the 407. We will re-submit once we get those corrected. Aras From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, November 29, 2022 9:51 AM To: Aras Worthington <Aras.Worthington@hilcorp.com> Subject: [EXTERNAL] BHU 22-25 (PTD 165-001) 10-407 questions Aras, A couple questions about the 10-407 for this well, Sundries 322-069 & 322-147. 1. Was the tubing punched before circulating cement? What depth was the punch/base of cement. It isn’t mentioned in the job summary reports. 2. The cement volume pumped for the deep cement plug was only 263 bbls vs. the amount in the sundried procedure of 368 bbls. Why the difference? Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 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 arehereby 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 andpermanently 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 arehereby 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 andpermanently 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 arehereby 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 andpermanently 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. Rig Start Date End Date 3/14/22 3/28/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BHU 22-25 50-133-10029-00-00 165-001 03/16/2022 - Wednesday 03/15/2022 - Tuesday Warm up equipment. PTW , JSA with crew. Vac truck pull water from cellar. Spot in HAK hot oi truck. Plan was to perform OA injection test first. 75 % of cellar ice block had thawed overnight. Remaining ice was still covering OA wellhead valve. Rigged up to 2 7/8" tubing string. PT pump lines. Grease high pressure block valves down stream of fluid pump. Online down 2 7/8" production tubing. Testing integrity from surface to the CIBP set at 8097'. Pressure up to 1187 psi and start 30 min test. BLM Representative on location to witness. (Required test pressure 1000 psi.) Ending pressure after 30 min. 1183 psi. Good test. Bleed down pressure. Swap pump line from tubing to IA. PT pump lines 250/3500 psi. Perform MIT on 2 7/8" x 9 5/8" casing. BLM witness on location. Required test pressure 1500 psi for 30. Starting pressure 2067 psi. Ending pressure after 30 min 2019 psi. Good test. Send PT test charts to town engineer. Spot 3x rain for rent tanks. I open top difuser, 1 closed top supply, 1 closed top paddle mixing tank. Wire in 480 V. Chip Ice to expose OA valve. Rig up pump line. PT lines 250/3500 psi. Open OA. 0 psi. Online 3 bbls pumped and pressured up to 1500 psi. Held 1500 psi for 35 minutes no bleed off. Called out AK-Eline for tubing punch. Bleed down OA pressure. Rig down pump line and install new bull plug and needle valve into OA 1/4 turn ball valve. Rig down hot oil truck and remove heater trailer from wellhead. AK E-line on location. PTW, JSA. MIRU. Spot in hot oil truck. Tie pump line into 2 7/8" tubing flow T. Rig up 1502 iron/hoses from 9 5'8" annulus to open top return tank. 03/14/2022 - Monday Move in Boom truck to assist wellhead rep. PTW, JSA. Remove tripod and spot on edge of pad. Wellhead Rep confirmed no BPV in 2 7/8" long string or in 2 3/8" heater string. Install Flange by bowen adapter on top of long string. Short string and long string confirmed fluid packed to surface. Continue thawing cellar to melt ice block. Mobilize HAK hot oil truck to location. 480 gen set to run mix tank mobilized to location. Prep 3x rain for rent tanks to mobilize to location in AM. HES cementing continue to blend cement. 3x transport loads filled into cement silo on location. 150 bbls of 90°F of fresh water from Swanson River fire water tank loaded into supply tank. Heater fuel topped off and wellhead tarped. Perform MIT on 2 7/8" x 9 5/8" casing. BLM witness on location. Required test pressure 1500 psi for 30. Starting pressure 2067 psi. Ending pressure after 30 min 2019 psi. Good test. S Online down 2 7/8" production tubing. Testing integrity from surface to the CIBP set at 8097'. Pressure up to 1187 psi and start 30 min test. BLM Representative on location to witness. (Required test pressure 1000 psi.) Ending pressure after 30 min. 1183 psi. Good test. B E-line tagged CIBP at 8115' MD (RKB=14.4') with tbg puncher. Punch tubing at 8032-8035' MD. See complete summary attached, report date 3/16/22. Incomplete daily report. Rig Start Date End Date 3/14/22 3/28/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BHU 22-25 50-133-10029-00-00 165-001 03/17/2022 - Thursday HES cementing crew arrive on location with offshore cementing package. Permit to work and JSA with crew. Well pressures Tbg 0 psi, IA 0 psi, OA 0 psi. Spot pump and leave on step deck. Unload auxillary equipment and air compressor. Remove night cap on well. Install 2.5" bowen x 1502 pump in sub. Rig up cementing equipment. Continue to load supply tank with fresh water at 80*F from Swanson River fire water tank. 393 bbls of fresh water in supply tank. Hold safety meeting with HES cementing crew, Cruz Vac truck drivers, BLM inspector, and Hilcorp reps. Discuss hazards with cementing. Review and discuss plan for a lock up scenario when cement hits the tubing punches. Line up cement pump down tubing taking returns from punches at 8032'-8035' and up the 2 7/8" x 9 5/8" casing (IA), to an open IA valve and an open top diffuser tank. Pump 2 bbls @ 2 BPM at 500 psi. Shut down pump. Close in swab and master on 2 7/8" tubing wellhead valves. Perform low and high pt 250/4200 psi. Good test. Blue print well characteristics and perform circulation test prior to cementing. 2 BPM 344 psi, 3 BPM 688 psi, 4 BPM 1030 psi, 5 BPM 1551 psi. Acceptable results. Cement wet at 12:32 PM. Confirm 14.0 ppg cement with HES, BLM rep, and HAK rep. Pump 263 bbls of 14.0 ppg class G cement, 1.52 yield , 7.72 GPS, with max rate and pressure of 5.5 bbls/min @ 1450 psi. Down on pump. Line up and launch wiper plug and displace with 17.5 bbls of fresh water @ 4 BPM 1450 psi. Shut down and simultaneously close 2 7/8" tubing master and swab valve and 9 5/8" gate valve and ball valve. OA pressure was monitored during cement job. 0 psi . Clean up cement pump and haul well returns to G&I facility. Weaver bros remove HES cement pump from location. Auxiliary equipment loaded on float trailer. Move HAK hot oil truck into position and prep paddle mix tank for 10.5 ppg well circulation. Inform G&I facility of cement placement. Execute plan to increase current 9.4 ppg mud to 10.5 ppg of OMW in compliance with regulatory agency requirements. Manifest Vac tanker. 320 bbls hauled to G&I for waste processing. H20 across tree. Cover and tarp wellhead and install heater trunks. Fuel support equipment on location. Review daily ops and forecast estimated road traffic to BMG construction. Perform location walk around. SDFN. See corrected daily report attached (report date 3/18/22) which confirms 363 bbls of cement pumped. - bjm 363 bbls cement pumped per attached email -bjm Rig Start Date End Date 3/14/22 3/28/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BHU 22-25 50-133-10029-00-00 165-001 03/18/2022- Friday AK E line on location. PTW , JSA with crew. MIRU e-line unit. BLM Regulator Allie S, and AOGCC state Rep Mr. Matt Herrera on location to witness CMIT of TBG x IA cement job to 1500 psi and tag of TOC. Hold tail gate meeting. Start MIT of the IA. Fill short string ( 2 3/8") heater string voild. 9 bbls pumped caught fluid. Start Pressure test at 2700 psi. 30 minute test ending pressure 2545 psi charted and graphed with hot oil truck.Tubing and OA were monitored during test. NO change in pressure. Both remained 0 psi. Bleed down IA. E line make up jet cutter for 2 7/8" tubing. Stab on well. RIH . Tag TOC 2876.4' Uncorrected. Corrected depth of 2950' Cut Tubing at 2750'. POOH with E-line. Rig down AK E-line and depart from location. Re position hot oil truck and prep for mud circulation. Rig up to OA. Attempt OA injection #2 Pressure climbed to 2500 psi. NO leak off. Bleed down/rig down pump line. Rig up hot oil truck and pump lines to tubing. IA return lines to open top tank. Weaver bros on location. Mobilize loader from road entrance to pad and assist unloading wellhead saw, DROT boom truck, Slips and elevators etc. Vac trucks arrive with 10.5 ppg heavy mud. Well will be filled and have 10.5 ppg between cement plugs as another barrier. Load Rain for rent blender tank and kick on paddles. Continue loading mix tank with mud. Total 250 bbls. Onine with 10.5 mud down 2 7/8" production tubing taking returns from tubing cut (7250') up IA to surface and open top diffuser tank. 5.5 bbls/min 569-870 psi. Displace remaining 9.0 ppg , from IA. 250 bbls circulated. Shut down hot oil truck. Clean lines from mix tank to hot oil truck, truck to wellhead and IA valve to rain for rent tank. Rig down hot oil truck and move equipment to prep location for pulling hanger and laying down completion in the AM. 03/19/2022 - Saturday PTW, JSA with crew. Perform wellhead work. Remove tree. Spot in crane pit liner tong crane, power tongs and powerpack, pipe rack trailer. Pull 2500' of 2 3/8" tubing (heater string). 80 joints of tubing pulled. Lay out on pipe rack trailer and install thread protectors. Secure location. SDFN. 03/20/2022 - Sunday PTW, JSA with crew. Fire equipment. Swap out handling gear for 2 7/8". 2750' (87.5 joints) of 2 7/8" tubing laid down. Call out AK E-line to run CBL. Rig up E line. Run in hole with 9 5/8" bond long tool. Estimated top of cement in OA 2050' right at the shoe. E line rigged back. Set new tree on well. Hammer up hanger flange. Depart location for the night. 80 joints of tubing pulled. Typo, tubing cut depth was 2750' md. -bjm 2750' (87.5 joints) of 2 7/8" tubing laid down. Start Pressure test at 2700 psi. 30 minute test ending pressure 2545 psi charted and graphed with hot oil truck.T Tag TOC 2876.4' Attempt OA injection #2 Pressure climbed to 2500 psi. NO leak off. B Run in hole with 9 5/8" bond long tool. Estimated top of cement in OA 2050' Uncorrected. Corrected depth of 2950' Cut Tubing at 2750'. Pull 2500' of 2 3/8" tubing (heater string) Rig Start Date End Date 3/14/22 3/28/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BHU 22-25 50-133-10029-00-00 165-001 03/21/2022 - Monday AK E-line crew arrive on location. PTW, JSA. Load 65 bbls of H20 into supply tank. Spot in hot oil truck and rig up to perform circulation test after casing puches. AK E-line crew rigging up pressure gear. Cut wire and re head through grease tubes. RIH with FN, weight bar CCL, Kick over tool, tubing punches. Max OD 2.125". Tool length 18'. Run down to 2200' and pull correlation pass. Tie into CBL log performed the previous day. Drop down to 2200' and pull log for shooting pass. Pull into position. 1893.5' CCL stop. Shoot casing punches from 1900'-1903'. Good indication of fire. POOH to surface. Confirmed all 3' of punches fired. Rig down AK E-line and remove equipment from location. SLB CTU equipment staged on location. Notification of Cruz 100 ton crane mobilization called in at 1530 hrs. Awaiting harvest operator to cross flow line with crane. Harvest operator on site. 100 ton crane crossed flow line with no issues. RU cruz crane to support SLB CTU ops. Spot equipment. Start rig up on SLB CTU 1 (offshore skid equipment). HES cementing notified to blend cement. Fuel heaters and support equipment. Location walk around complete. SDFN. 03/22/2022 - Tuesday PTW, JSA with SLB CTU, Cruz crane operator. Start and warm equipment. Continue rigging up SLB coiled tubing unit # 1 with 1.75"x .156" wall for 14650'. Load supply tank with 220 bbls of fresh water. Rig up hot oil truck and circulate tank and heat to 87*F. SLB bops on well. Rig up hot oil truck to SLB pump in sub tied into the 9 5/8" casing. Fill void from completion displacement. 24.3 bbls caught fluid. Pressure up casing down 9 5/8" to 500 psi. IA and OA have communication. 500 psi on OA gauge. Add 500 psi more and hold at 1000 psi. Bleed down OA. Confirm 1:1 circulation by pumping 2 bbls down casing and up punch holes at 1900'. HES crew and equipment arrive on location. Unload HES trailer and spot baskets next to pump unit. Spot in/rig up cementing equipment to SLB CTU reel iron. Hold PJSM with SLB, HES, Cruz and HAK personnel. RIH with 1.75" CTU. BHA 2.0" OD ball drop nozzle with 4 x 1/4" side jets, 1.75" roll on coil connector. RIH to 2150'. PU clean. Stop coil in tension at 1900'. (coil corrected to RKB at surface). Pump 5 bbls of fresh water ahead and into CTU reel. Close inner reel valve. PT lines to 250/5500 psi. Cement wet at 14:15 hrs. Online down coil with 35 bbls of 15.3 ppg class G cement. 1 BPM 3678 psi. Cement at nozzle. PU OOH from 2100' laying in 35 bbls at 1:1 to 1630'. Shut down cement pump. Pick up coil to 1530' . Pump 3 bbls/min for 2 bbls to clean up CTU end. Close 9 5/8" annulus x 1.75" CT. Open 9 5/8" x 13 3/8" and displace 6 bbls of ODWM to reutrn tank. Confirmed 6.5 bbls of cement circulated into OA. Cement dropped in 9 5/8" Estimated cement top in 9 5/8" is 1711'. TOC in OA 1800'. POOH to surface with CTU. CTU tagged up at surface. Online down 9 5/8" to fill void of 3.9 bbls. Pump WHP up to 1052 psi. Squeeze pressure applied. No drop in pressure. Shut in master valve with 1052 psi trapped squeeze pressure. Rig down HES and SLB CTU 1. Trucks will arrive in the AM to rig out CTU equipment. AK E-line arriving at 11 AM for TOC tag and PT. Then punch casing at 150'. Attempt to establish circulation. Estimated cement top in 9 5/8" is 1711'. TOC in OA 1800'. Online down coil with 35 bbls of 15.3 ppg class G cement. 1 Pull into position. 1893.5' CCL stop. Shoot casing punches from 1900'-1903'. Good indication of fire. Open 9 5/8" x 13 3/8" and displace 6 bbls of ODWM to reutrn tank. Confirmed 6.5 bbls of cement circulated into OA. C PU OOH from 2100' laying in 35 bbls at 1:1 to 1630'. Shut down cement pump. Pick up coil to 1530' . Rig Start Date End Date 3/14/22 3/28/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BHU 22-25 50-133-10029-00-00 165-001 03/23/2022 - Wednesday Weaver Bros moving out SLB off shore CT equipment. PTW, JSA with AK E-line. Rig up hot oil truck. Pressure test cement plug down 9 5/8" casing. Initial pressure 487 psi WHP. (1050 psi left on well during cement squeeze). Pressure up to 1612 psi ending pressure 1578 psi. Good test. Bleed down. Arm tubing punches. RIH with E-line. Calculated TOC 1711'. Tag TOC at 1705' . Cement tag fills agency requirements. PU to 300' and log OOH. CCL to top shot 11.5'. Drop back down. pull into position and stop CCL at 137.7' Punch 9 5/8" casing from 149.2' -152.2'. POOH to surface. Rig up hot oil truck to 9 5/8" casing. Return line rigged up to OA, 13 3/8" casing. Online down casing taking returns up OA. Pumped 5 bbls to ensure good circulation. Rig down Hot oil truck. Secure well. SDFN. 03/24/2022 - Thursday PTW, JSA with CCI crew and Steam on wheels crew. Clean out cellar. Place large debris in lined mud boxes. Spray cellar with Steam on wheels. Clean cellar walls and wellhead. Crews off location. SDFN. Plan forward cement to surface from 150'. 03/25/2022- Friday Fire up hot oil truck. Hook up to suction side of supply tank and return over top. Heat 135 bbls of fluid from 47*F to 78*F. Halliburton cementers on location. PTW, JSA with crew. Spot equipment. OA to return tank rigged up. HES run iron. Hold pre cementing safety meeting. FIll lines pump 3 bbls ahead. PT lines low and high 580 and 2300 psi. Circulate 25 bbls to clean up casing clean water to surface. Cement wet at `12:43 pm. Pump 26 bbls of cement across 9 5/8" and 13 3/8" from 150' to surface. BLM witness good cement in returns. Transfer 3.4 bbls to vac truck. P&A water well. Rig down HES and depart location. RDMO hot oil truck. Pick up location and return rental air compressor. 03/26/2022 - Saturday Arrive on location. PTW , JSA, confined space and hot work permit completed with CCI welder and welder helper. BLM inspector on site. Check 9 5/8" and 13 3/8" Casing for pressure. 0 psi. Remove well cellar covers. Spot wellhead saw and power pack. Cut off C channel well support brackets. Start cutting wellhead. USFW representatives on site to check out access road and P&A operation. Wellhead cut off. Pull out of cellar with loader. No cement to surface in 9 5/9" casing. 13 3/8" casing cement down 2' . Lower shackle and string down 9 5/8" casing and set down at 65'. 25 bags of concrete on location. Mix and fill 9 5/8" casing and 13 3/8" casing. 23 sacks used to fill. Install cellar covers and heater trunk into wellhead cellar. Fuel Heater and clean up location. Depart location . 03/27/2022 - Sunday PTW, JSA, Hot work, Confined space permit completed. Weld marker plate on BHU 22-25. Document P&A with photos. Mix and add cement to water well. Cement 12' from surface. Excavate around water well to drop 5' below pad level. Cut and remove 6" casing. Weld on abandonment plate. Backfill water well. Remove 3' of cellar from 22-25. No contamination found. Back fill cellar with weed free dirt. Pump 26 bbls of cement across 9 5/8" and 13 3/8" from 150' to surface. Punch 9 5/8" casing from 149.2' -152.2' Pressure test cement plug down 9 5/8" casing. Initial pressure 487 psi WHP. (1050 psi left on well during cement squeeze). Pressure up to 1612 psi ending pressure 1578 psi. Good test. Wellhead cut off. Check 9 5/8" and 13 3/8" Casing for pressure. 0 psi. No cement to surface in 9 5/9" casing. 13 3/8" casing cement down 2' . Mix and fill 9 5/8" casing and 13 3/8" casing. 23 sacks used to fill. Tag TOC at 1705' BLM witness good cement in returns. Weld marker plate on BHU 22-25. Document P&A with photos. Rig Start Date End Date 3/14/22 3/28/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BHU 22-25 50-133-10029-00-00 165-001 03/28/2022 - Monday Remove debris from location. Load 4 wood cellar covers, Miscellaneous metal piping and 4 large pieces of well cellar. Hilcorp land man and Tyonek Native Representatives on location to inspect. BLM regulator arrive on location. Tyonek signed off on pad. BLM Rep. required fencing bundle found on previous visit to be removed from location. Continue to search for fence. Pulled all fence from 150 yards off location with choke cable and winch. BLM satisfied with location. Take final location pictures for reference. Burch hills 22-25 Plug and Abandonment completed. Notes: ATTEMPT TO PUMP DOWN OA 13 3/8" X 9 5/8". PRESSURE CLIMBED TO 2500 PSI AND HELD SOLID. NOINJECTION.Customer: HilcorpCustomer Contact: Cole BartlewskiLSD: BHU 22-25Job #:Date:Fluid Pumped:BHU 22-25Methanol , water2022-03-18 21:20Ticket #:Phone #:Operator:OA INJECTION TCOLE BARTLEW690-2854Total Fluid Pumped:315 USG Customer: HilcorpCustomer Contact: Cole BartlewskiLSD: BHU 22-25Job #:Date:Fluid Pumped:BHU 22-25Methanol , water2022-03-18 21:20Ticket #:Phone #:Operator:CMIT TBG x CasiCOLE BARTLEW690-2854Total Fluid Pumped:457.8 USG Date Comment Mar 18, 2022 - 11:20:24 AM P2 DIS PRESS: 2687 PSI, BLM, AOGCC srarting 2700 psi. After 30 minutes 2545 psi. Good pressure test. lost less than 10% Pumped 10.9 bbls to catch fluid. Final Readings (2022-03-18 12:03): B1 TOTAL: 0 USG PUMP TOTAL: 457.8 USG Notes: CMIT 9 5/8" casing 1500 for 30 min. OA cement shoe test.Customer: HilcorpCustomer Contact: Cole BartlewskiLSD: BHU 22-25Job #:Date:Fluid Pumped:BHU 22-25Methanol , water2022-03-23 14:22Ticket #:Phone #:Operator:CMIT 9 5/8" casinCOLE BARTLEW690-2854Total Fluid Pumped:42 USG Date Comment Mar 23, 2022 - 01:24:42 PM P2 DIS PRESS: 1612 PSI, Start MIT 1500 psi for 30 minutes. 9 5/8" casing. Testing shoe cement job. Holes punched at 1900' Mar 23, 2022 - 01:56:32 PM P2 DIS PRESS: 1578 PSI, good pt. Final Readings (2022-03-23 14:10): B1 TOTAL: 0 USG PUMP TOTAL: 42 USG BHU 22-25 Cement to Surface (1 of 2) BHU 22-25 Cement to Surface (2 pf 2) BHU 22-25 Welded Marker Plate BHU 22-25 Cellar Bottom & Plugged Well BHU 22-25 Removed Cellar Below Grade BHU 22-25 Cleared Pad 5HJJ-DPHV%2*& )URP6FKRHVVOHU$OOLH0DVFKRHVVOHU#EOPJRY! 6HQW7XHVGD\0DUFK$0 7R5HJJ-DPHV%2*& 6XEMHFW5H>(;7(51$/@5(%LUFK+LOO $WWDFKPHQWV%ULFK+LOO0DUNHU3ODWH,QVWDOOHGSQJ%ULFK+LOO&HPHQWWR6XUIDFHSQJ%ULFK+LOO %DFNILOOHG&HOODUSQJ :ŝŵ͕ dŚĞWΘĨŽƌŝƌĐŚ,ŝůůŝƐĐŽŵƉůĞƚĞ͘ dŚĞǁĞůůŚĞĂĚĐƵƚŽĨĨŝƐϰ͘ϴĨĞĞƚďĞůŽǁĨŝŶĂůŐƌŽƵŶĚůĞǀĞů͘dŚĞĐĞŵĞŶƚƚŽŽŬĂůŝƚƚůĞůŽŶŐĞƌƚŚĂŶĞǆƉĞĐƚĞĚƚŽĨŝƌŵ ƵƉĚƵĞƚŽƚŚĞĐŽůĚǁĞĂƚŚĞƌ͘ ,ĂĚƚŽĂĚĚŝŶƐŽŵĞĐĞŵĞŶƚĂĨƚĞƌĐƵƚƚŝŶŐƚŚĞĐĂƐŝŶŐ͘/ŚĂǀĞĂƚƚĂĐŚĞĚƉŚŽƚŽƐŽĨƚŚĞŚĂƌĚĞŶĞĚĐĞŵĞŶƚĂƚ ƐƵƌĨĂĐĞ͕ŵĂƌŬĞƌƉůĂƚĞŝŶƉůĂĐĞĂŶĚƚŚĞĨŝŶĂůďĂĐŬĨŝůůĞĚĐĞůůĂƌĂƌĞĂ͘ WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨǇŽƵŶĞĞĚĂŶǇŵŽƌĞŝŶĨŽƌŵĂƚŝŽŶ͘ ůůŝĞ &ƌŽŵ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗&ƌŝĚĂǇ͕DĂƌĐŚϮϱ͕ϮϬϮϮϱ͗ϯϱWD dŽ͗^ĐŚŽĞƐƐůĞƌ͕ůůŝĞDфĂƐĐŚŽĞƐƐůĞƌΛďůŵ͘ŐŽǀх ^ƵďũĞĐƚ͗Z͗΀ydZE>΁Z͗ŝƌĐŚ,ŝůů DƵĐŚĂƉƉƌĞĐŝĂƚĞĚ͘ :ŝŵZĞŐŐ ^ƵƉĞƌǀŝƐŽƌ͕/ŶƐƉĞĐƚŝŽŶƐ K' ϯϯϯt͘ϳƚŚǀĞ͕^ƵŝƚĞϭϬϬ ŶĐŚŽƌĂŐĞ͕<ϵϵϱϬϭ ϵϬϳͲϳϵϯͲϭϮϯϲ &ƌŽŵ͗^ĐŚŽĞƐƐůĞƌ͕ůůŝĞDфĂƐĐŚŽĞƐƐůĞƌΛďůŵ͘ŐŽǀх ^ĞŶƚ͗&ƌŝĚĂǇ͕DĂƌĐŚϮϱ͕ϮϬϮϮϱ͗ϯϮWD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗ZĞ͗΀ydZE>΁Z͗ŝƌĐŚ,ŝůů /ǁŝůůďĞŽŶƐŝƚĞĨŽƌƚŚĞĐƵƚŽĨĨ͕ĐĞŵĞŶƚƚŽƐƵƌĨĂĐĞĐŽŶĨŝƌŵĂƚŝŽŶĂŶĚƉůĂƚĞŝŶƐƚĂůůĂƚŝŽŶ͘ ZĞŐƵůĂƚŝŽŶƐĂƌĞƚŚĞƐĂŵĞĨŽƌƚŚŝƐƉĂƌƚ͘/ŚĂǀĞŶŽƉƌŽďůĞŵƚĂŬŝŶŐƉŚŽƚŽƐŽĨŝƚĂƐǁĞůůĂŶĚƐĞŶĚŝŶŐƚŽǇŽƵ͘ ůůŝĞ %LUFK+LOO8QLW 37' -5HJJ &ƌŽŵ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗&ƌŝĚĂǇ͕DĂƌĐŚϮϱ͕ϮϬϮϮϱ͗ϬϴWD dŽ͗^ĐŚŽĞƐƐůĞƌ͕ůůŝĞDфĂƐĐŚŽĞƐƐůĞƌΛďůŵ͘ŐŽǀх ^ƵďũĞĐƚ͗΀ydZE>΁Z͗ŝƌĐŚ,ŝůů dŚŝƐĞŵĂŝůŚĂƐďĞĞŶƌĞĐĞŝǀĞĚĨƌŽŵŽƵƚƐŝĚĞŽĨK/ͲhƐĞĐĂƵƚŝŽŶďĞĨŽƌĞĐůŝĐŬŝŶŐŽŶůŝŶŬƐ͕ŽƉĞŶŝŶŐĂƚƚĂĐŚŵĞŶƚƐ͕Žƌ ƌĞƐƉŽŶĚŝŶŐ͘ ƌĞǇŽƵƉůĂŶŶŝŶŐƚŽďĞƚŚĞƌĞĨŽƌƐƵƌĨĂĐĞĂďĂŶĚŽŶ͍/ĨǇŽƵǁŝůůďĞƚŚĞƌĞǁĞǁŝůůǁĂŝǀĞǁŝƚŶĞƐƐ͖ǇŽƵƉƌŽďĂďůǇĚŽƚŚĞƐĂŵĞ ĐŚĞĐŬƐĂƐƵƐʹĐŽŶĨŝƌŵĐŽŵƉĞƚĞŶĐĞŽĨĐĞŵĞŶƚƚŽƐƵƌĨĂĐĞ͖ƉƌŽƉĞƌĐƵƚĚĞƉƚŚ;ϯĨƚďĞůŽǁŽƌŝŐŝŶĂůŐƌŽƵŶĚůĞǀĞůͿ͖ĐŽƌƌĞĐƚŝŶĨŽ ŽŶŵĂƌŬĞƌƉůĂƚĞ;ƚŚĞǇĂůƌĞĂĚǇƐĞŶƚƵƐĂƉŚŽƚŽŽĨƚŚĞŵĂƌŬĞƌƉůĂƚĞͿ͘dŚĂŶŬǇŽƵ͘ :ŝŵZĞŐŐ ^ƵƉĞƌǀŝƐŽƌ͕/ŶƐƉĞĐƚŝŽŶƐ K' ϯϯϯt͘ϳƚŚǀĞ͕^ƵŝƚĞϭϬϬ ŶĐŚŽƌĂŐĞ͕<ϵϵϱϬϭ ϵϬϳͲϳϵϯͲϭϮϯϲ &ƌŽŵ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳ ^ĞŶƚ͗tĞĚŶĞƐĚĂǇ͕DĂƌĐŚϮϯ͕ϮϬϮϮϯ͗ϭϱWD dŽ͗^ĐŚŽĞƐƐůĞƌ͕ůůŝĞDфĂƐĐŚŽĞƐƐůĞƌΛďůŵ͘ŐŽǀх ^ƵďũĞĐƚ͗Z͗ŝƌĐŚ,ŝůů dŚĂŶŬǇŽƵ͘/ĂƉƉƌĞĐŝĂƚĞƚŚĞŽĨĨĞƌĂŶĚǁŝůůůĞƚǇŽƵ͘ :ŝŵZĞŐŐ ^ƵƉĞƌǀŝƐŽƌ͕/ŶƐƉĞĐƚŝŽŶƐ K' ϯϯϯt͘ϳƚŚǀĞ͕^ƵŝƚĞϭϬϬ ŶĐŚŽƌĂŐĞ͕<ϵϵϱϬϭ ϵϬϳͲϳϵϯͲϭϮϯϲ &ƌŽŵ͗^ĐŚŽĞƐƐůĞƌ͕ůůŝĞDфĂƐĐŚŽĞƐƐůĞƌΛďůŵ͘ŐŽǀх ^ĞŶƚ͗tĞĚŶĞƐĚĂǇ͕DĂƌĐŚϮϯ͕ϮϬϮϮϭϭ͗ϰϰD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗ŝƌĐŚ,ŝůů ,ĞůůŽ:ŝŵ͕ /ƚĂůŬĞĚǁŝƚŚDĂƚƚ,ĞƌƌĞƌĂůĂƐƚǁĞĞŬĂŶĚƐŽƵŶĚƐůŝŬĞǇŽƵƌƚĞĂŵŝƐƉƌĞƚƚǇďƵƐǇ͘/ĂŵĂƚƚŚĞŝƌĐŚ,ŝůůWΘĨŽƌ ƚŚĞĚƵƌĂƚŝŽŶŽĨƚŚĞƉƌŽũĞĐƚ͘ &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨƚŚĞƌĞŝƐĂŶǇƚŚŝŶŐǇŽƵǁŽƵůĚůŝŬĞŵĞƚŽůŽŽŬĂƚŝĨŶŽŶĞŽĨǇŽƵƌŝŶƐƉĞĐƚŽƌƐĂƌĞĂǀĂŝůĂďůĞĨŽƌ ƚŚĞƌĞŵĂŝŶŝŶŐŝŶƐƉĞĐƚŝŽŶƐ͘ ,ĂǀĞĂŐƌĞĂƚĚĂǇ͕ ůůŝĞ^ĐŚŽĞƐƐůĞƌ WĞƚƌŽůĞƵŵŶŐŝŶĞĞƌͬ/ŶƐƉĞĐƚŽƌ KĨĨŝĐĞ͗ϵϬϳͲϮϳϭͲϯϭϮϳ Ğůů͗ϵϬϳͲϮϬϮͲϮϰϰϱ ϮϮϮtϳƚŚǀĞ^ƚŽƉϭϯ ŶĐŚŽƌĂŐĞ͕<ϵϵϱϭϯ Birch Hill Unit 22-25 Surface Abandonment Page 1 of 2 Birch Hill Unit 22-25 (PTD 1650010)Photos Courtesy of BLMCement to Surface Marker plate installed Birch Hill Unit 22-25 Surface Abandonment Page 2 of 2 Backfilled well cellar 5HJJ-DPHV%2*& )URP5HJJ-DPHV%2*& 6HQW7KXUVGD\0DUFK$0 7R&ROH%DUWOHZVNL 6XEMHFW5(3UHLQVSHFWLRQLQVSHFWLRQ /ŶĨŽƌŵĂƚŝŽŶŝƐĐŽƌƌĞĐƚ͖ƚŚĂŶŬǇŽƵ͘ :ŝŵZĞŐŐ ^ƵƉĞƌǀŝƐŽƌ͕/ŶƐƉĞĐƚŝŽŶƐ K' ϯϯϯt͘ϳƚŚǀĞ͕^ƵŝƚĞϭϬϬ ŶĐŚŽƌĂŐĞ͕<ϵϵϱϬϭ ϵϬϳͲϳϵϯͲϭϮϯϲ &ƌŽŵ͗ŽůĞĂƌƚůĞǁƐŬŝфĐďĂƌƚůĞǁƐŬŝΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗dŚƵƌƐĚĂǇ͕DĂƌĐŚϮϰ͕ϮϬϮϮϭϬ͗ϮϲD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗WƌĞŝŶƐƉĞĐƚŝŽŶŝŶƐƉĞĐƚŝŽŶ 'ĞƚKƵƚůŽŽŬĨŽƌŝ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irch Hill Unit 22-25 Photo Courtesy of Hilcorp 3/24/2022 Abandonment Marker Plate From:McLellan, Bryan J (OGC) To:Aras Worthington Cc:Donna Ambruz; Cole Bartlewski; Regg, James B (OGC) Subject:RE: [EXTERNAL] RE: BHU 22-25 PTD 165-001 Sundry 322-069 Date:Saturday, March 19, 2022 12:03:00 PM Aras, You have verbal approval to proceed with the Change Approved Program Sundry submitted by Hilcorp Friday afternoon, 3/18/22, with one addition: If the contingency to punch casing in step 26 is necessary, you should flush the OA and circulate the entire OA to 10.5 ppg mud to prep the OA for cementing. All conditions of approval from the original sundry 322-069 still apply. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Saturday, March 19, 2022 9:26 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Cole Bartlewski <cbartlewski@hilcorp.com> Subject: Re: [EXTERNAL] RE: BHU 22-25 PTD 165-001 Sundry 322-069 Good Morning Bryan, Apologies for the weekend request but can we get verbal approval for the Sundry revision I emailed yesterday? We submitted it formally with Sundry Revision as well. We are on a very tight timeline to complete the P&A and remove the two-mile temporary road before breakup. We plan to be RU CT Monday if we can get that verbal approval. Please see below for operational update. Yesterday we performed the AOGCC and BLM witnessed CMIT-TxIA to 2500 psi (passed). Tagged TOC @ 2950’MD and jet cut 2-7/8” tubing @ ~2750’ MD. Circulated 250 bbls 10.5 ppg mud around TxIA. Plan Forward: Pull 2-3/8” tubing from 2500’ MD. Pull 2-7/8” tubing from cut at 2750’ MD. Punch casing @ 2500’ and RU CT to perform top two cement jobs. Thanks and Best Regards, Aras On Mar 18, 2022, at 10:40 AM, Aras Worthington <Aras.Worthington@hilcorp.com> wrote: Good Morning Bryan. Today’s update: Pumped 363 bbls of 14 PPG class G cement down 2-7/8” tubing and up 9-5/8” IA. Calculated TOC 3000’ in tubing and IA. Plan forward. RU AK E-line, RIH and tag TOC. PT tubing x IA to 2500 psi for 30 minutes with BLM and AOGCC witness. Jet cut tubing ~200’ MD above tag depth. Build 9.4 ppg mud to 10.5 ppg mud at G&I. Load into mix tank on location and agitate with paddles. Circulate surface to surface loading well with original drill weight mud of 10.5 ppg in compliance with BLM. I have edited/cleaned up the Sundry revision proposal a bit but materially it is the same as the one I sent yesterday. The only change from that version is that we will only perform the OA injectivity test to a higher pressure after pulling tubing out of the well. I would like to request verbal approval to do this and install the last two cement plugs with Coiled Tubing as described in the attached. We are also submitting this with a Change of Sundry form, but the program is the same as the one attached here. Thanks and Best Regards, Aras Worthington Hilcorp Alaska LLC Senior Technical Advisor for Alaska Operations Aras.worthington@hilcorp.com 907-564-4763 907-440-7692 mobile 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) <bryan.mclellan@alaska.gov> Sent: Thursday, March 17, 2022 8:47 AM To: Aras Worthington <Aras.Worthington@hilcorp.com> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: [EXTERNAL] RE: BHU 22-25 PTD 165-001 Sundry 322-069 Aras, What were the WHPs when you first opened the well up. I didn’t see them in the daily reports Joe sent out yesterday. Could you also send me the daily report from yesterday? It would be good if someone forwards me the daily reports going forward so I can keep up with the operation. I’m anticipating more change requests. This is not a requirement. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Aras WorthingtonF <Aras.Worthington@hilcorp.com> Sent: Thursday, March 17, 2022 6:25 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: RE: BHU 22-25 PTD 165-001 Sundry 322-069 Bryan, Apologies for the second revision request, but we have some equipment availability and weight constraints on the temporary road that we are trying to navigate, along with the short timeline on road removal after the P&A is completed. This revision is to have the option to use CT for the final two cement plugs. Nothing is changed with regard to cement/mud placement or volumes, just the means by which it is placed (CT instead of tubing workstring). Thanks for your help and consideration. Aras Worthington Hilcorp Alaska LLC Senior Technical Advisor for Alaska Operations, PE Aras.worthington@hilcorp.com 907-564-4763 907-440-7692 mobile From: Aras Worthington Sent: Wednesday, March 16, 2022 3:29 PM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: BHU 22-25 PTD 165-001 Sundry 322-069 Bryan, Please see attached revision as discussed earlier today. Changes to the original program are highlighted yellow. The original approved Sundry is attached for reference. Thanks and Best Regards, Aras Worthington Hilcorp Alaska LLC Senior Technical Advisor for Alaska Operations, PE Aras.worthington@hilcorp.com 907-564-4763 907-440-7692 mobile The information contained in this email message is confidential and may be legally privileged and is intended only forthe 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 suchvirus and other checks as it considers appropriate. <BHU 22-25 P&A Sundry Procedure V 8.0 03-18-22.pdf> 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 responsibilityis 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: 25 Township: 9N Range: 9W Meridian: Seward Drilling Rig: E-Line Rig Elevation: Total Depth: 15,500 ft MD Lease No.: FED A028407 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 216 Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 2000 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 9 5/8" O.D. Shoe@ 9017 Feet Csg Cut@ Feet Liner: 7" O.D. Shoe@ 15,500 Feet Csg Cut@ Feet Tubing (L/S): 2 7/8" O.D. Tail@ 8220 Feet Tbg Cut@ 2676 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Bridge plug 8097 ft MD 2876 ft MD 10.6 ppg brine Wireline tag Initial 15 min 30 min 45 min Result Tubing 0 0 0 IA 2700 2627 2545 OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: BHU 22-25 was drilled in 1965 and has been determined to be P&A per BLM. Well has two tubing strings: Long String 2 7/8" @ 8220 ft MD and Short String (Heat String) 2 3/8" @ 2512 ft MD. CIBP was set in LS and tubing punched, well circulated and cement pumped to approx. 3000 ft. Actual tag showed cement top in LS tbg at 2876 ft MD. Tubing cutter used to tag cement top and subsequent cut was successfully made @ 2676 ft MD. 2 7/8" tbg will then be pulled and subsequent plugs and cemented to surface per BLM regulations. BLM representative. March 18, 2022 Matt Herrera Well Bore Plug & Abandonment Birch Hill Unit 22-25 Hilcorp Alaska LLC PTD 1650010; Sundry 322-069 none Plugging Data: Test Data: P Casing Removal: Cole Bartlewski Casing/Tubing Data (depths are MD): rev. 11-28-18 2022-0318_Plug_Verification_BHU_22-25_mh 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. 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ĞǆŝƐƚŝŶŐĐŽŵƉůĞƚŝŽŶƉĂĐŬĞƌΛϴ͕ϭϭϴ͛DĂŶĚ/WŝŶƚƵďŝŶŐĂƚϴ͕Ϭϵϳ͛D ďĞƵƐĞĚŝŶƉůĂĐĞŽĨĂŵĞĐŚĂŶŝĐĂů ďƌŝĚŐĞƉůƵŐĂƚĂƐĞƚŚĞŝŐŚƚŽĨϳϮ ĨĞĞƚĂďŽǀĞƚŚĞĞǆŝƐƚŝŶŐƚŽƉƉĞƌĨŽƌĂƚĞĚŝŶƚĞƌǀĂů͘ dŚĞƉƌŽƉŽƐĞĚĐĞŵĞŶƚƉůƵŐŝŶ ƚŚĞƉƌŽĚƵĐƚŝŽŶƚƵďŝŶŐǆ/ŶŶĞƌŶŶƵůƵƐ;/ͿǁŽƵůĚďĞĨƌŽŵƚŚĞƉƌŽĚƵĐƚŝŽŶƉĂĐŬĞƌΛϴϭϭϴ͛DƵƉƚŽΕϯϬϬϬ͛D ;ΕϱϭϬϬ͛DŝŶůĞŶŐƚŚͿ͘ ,ŝůĐŽƌƉƌĞƋƵĞƐƚƐĂǀĂƌŝĂŶĐĞƚŽKŶƐŚŽƌĞKƌĚĞƌηϮ͘///͘'͘ϯ͘dŚĞƚƵďŝŶŐƐƚƵďǁŝůůďĞ ĐĞŵĞŶƚĞĚĨƌŽŵƚŚĞƉĂĐŬĞƌΛ ϴϭϭϴ͛DƵƉƚŽƚŚĞƉƌŽƉŽƐĞĚdK ΛΕϯϬϬϬ͛D;ĂĐĞŵĞŶƚƉůƵŐΕϱϭϬϬ͛ŝŶůĞŶŐƚŚͿ͘,ŝůĐŽƌƉƌĞƋƵĞƐƚƐƚŚĂƚƚŚŝƐ ƚƵďŝŶŐƐƚƵď ŶŽƚƌĞƋƵŝƌĞĂŶĂĚĚŝƚŝŽŶĂůĐĞŵĞŶƚƉůƵŐŽĨϱϬ͛ŝŶůĞŶŐƚŚĂďŽǀĞĂŶĚďĞůŽǁƚŚĞƚŽƉŽĨƚŚĞƐƚƵďΛ ΕϮϴϬϬ͛D͘ WƌĞʹ ZŝŐͬƌĂŶĞ tŽƌŬ͗ ϭ͘ WƌŽǀŝĚĞϳϮͲŚŽƵƌŶŽƚŝĐĞƚŽ>DŽĨƐƚĂƌƚŽĨWΘŽƉĞƌĂƚŝŽŶƐĂƐƉĞƌKŶƐŚŽƌĞKƌĚĞƌηϮ͘///͘'͘ Ϯ͘ WƌŽǀŝĚĞϮϰͲŚŽƵƌŶŽƚŝĐĞƚŽK'ƚŚĂƚWůƵŐĂŶĚďĂŶĚŽŶŵĞŶƚŽĨǁĞůůǁŝůůĐŽŵŵĞŶĐĞƉĞƌK' ƌĞŐƵůĂƚŝŽŶƐϮϬϭϭϮ;ŚͿ͘ ϯ͘ KƉĞŶǁĞůůŚĞĂĚǀĂůǀĞƐ ĂŶĚĐŚĞĐŬƉƌĞƐƐƵƌĞƐ͘ ϰ͘ sĞƌŝĨǇŝĨWsŝƐŝŶƐƚĂůůĞĚĂŶĚƉƵůůWsĂƐŶĞĐĞƐƐĂƌǇ͘ ϱ͘ hƐĞĐŚŽŵĞƚĞƌ ƚŽƐŚŽŽƚĨůƵŝĚůĞǀĞůƐŝŶĞĂĐŚƐƚƌŝŶŐŽĨƉŝƉĞ͘ ϲ͘ DŽďŝůŝǌĞǀĞŶƚƚĂŶŬĂŶĚďůĞĞĚĂŶǇŐĂƐĨƌŽŵǁĞůů͕ƌĞĐŽƌĚŝŶŐƐƚĂƌƚĂŶĚƐƚŽƉƚŝŵĞƐĨŽƌďůĞĞĚƐ͘ ϳ͘ DŽďŝůŝǌĞƉƵŵƉƚŽůŽĐĂƚŝŽŶ͕ƉƵŵƉďƌŝŶĞŽƌĚŝĞƐĞů;ƉĞŶĚŝŶŐďůĞĞĚƚŝŵĞƐͿĂŶĚŵĞĂƐƵƌĞǀŽůƵŵĞ ƉƵŵƉĞĚŝŶǁĞůů͘ƚƚĞŵƉƚƚŽƉƵŵƉŝŶƚŽK ;ϭϯͲϯͬϴ͟ǆϵͲϱͬϴ͟ͿǁŝƚŚĚŝĞƐĞůĂŶĚĞƐƚĂďůŝƐŚĂƉƵŵƉ ƌĂƚĞ͘EŽƚŝĨǇĞŶŐŝŶĞĞƌŽĨŵĂǆƌĂƚĞĂĐŚŝĞǀĞĚ͕ĚŽŶŽƚĞǆĐĞĞĚϭ͕ϱϬϬƉƐŝ͘ Ă͘ /ĨŝŶũĞĐƚŝǀŝƚǇŽĨĂƚůĞĂƐƚϭďƉŵŝƐĞƐƚĂďůŝƐŚĞĚ ĐĞŵĞŶƚƚŚĞKĐŽŵƉůĞƚĞůǇĂƐĨŽůůŽǁƐ͗ Ͳ ϱϬďďůƐĨƌĞƐŚǁĂƚĞƌ ǁŝƚŚ^ƵƌĨĂĐƚĂŶƚtĂƐŚ Ͳ ϱďďůƐDƵĚWƵƐŚ Ͳ ϱϬďďůƐϭϰƉƉŐ ůĂƐƐ'ĐĞŵĞŶƚǁŝƚŚ>D Ͳ ϭϬϬďďůƐϭϰƉƉŐŶĞĂƚůĂƐƐ'ĐĞŵĞŶƚ;ΕϭϮϯ ďďůƐƚŽƐŚŽĞΛϮϬϬϬ͛DͿ Ͳ ,ĞƐŝƚĂƚĞůĂƐƚΕϮϬďďůƐŽĨĐĞŵĞŶƚ sŽůƵŵĞƐ͗ ¾K;ϭϯͲϯͬϴ͟ĂƐŝŶŐǆϵͲϱͬϴ͟ĂƐŝŶŐͿĨƌŽŵϮϬϬϬ͛DƚŽ^ƵƌĨĂĐĞ͗ ϳϮϬǆϬ͘ϬϱϵϵďƉĨ нϭϮϴϬǆϬ͘ϬϲϮďƉĨ сϭϮϮ͘ϱďďůƐ dŽƚĂů͗ϭϮϯ ďďůƐ tĞůůWƌŽŐƌĂŵ tĞůů͗,hϮϮͲϮϱ ĂƚĞ͗ ϬϯͬϭϴͬϮϬϮϮ &ƵůůďŽƌĞ ϴ͘ D/ddƚŽϭϬϬϬƉƐŝ ĨŽƌϯϬŵŝŶƵƚĞƐ͘ ϵ͘ D/dͲdǆ/ƚŽϭϱϬϬƉƐŝ ĨŽƌϯϬŵŝŶƵƚĞƐ͘ EŽƚĞ͗dŚŝƐƐƚĞƉǁŝůůŝŶĨŽƌŵƚŚĞĚĞĐŝƐŝŽŶĂƐƚŽǁŚĞƚŚĞƌŽƌŶŽƚĂůůƚƵďŝŶŐŶĞĞĚƐƚŽďĞƉƵůůĞĚŽƌƚŚĞƚƵďŝŶŐĐĂŶ ďĞƵƐĞĚĂƐĂĐŽŶĚƵŝƚĨŽƌĐŝƌĐƵůĂƚŝŶŐŝŶƚŚĞĨŝƌƐƚĐĞŵĞŶƚƉůƵŐ͘ ^ůŝĐŬůŝŶĞ ϭϬ͘ ƌŝĨƚΘdĂŐƚŽƚŽƉŽĨ/WΛϴ͕Ϭϵϳ͛͘ ϭϭ͘ WƵůůŐĂƐůŝĨƚĚƵŵŵǇΛϴ͕Ϭϲϱ͛ ŽƌƉƵŶĐŚƚƵďŝŶŐΛĂƉƉƌŽǆŝŵĂƚĞůǇƚŚĞƐĂŵĞĚĞƉƚŚ͘ &ƵůůďŽƌĞ;ŝƌĐƵůĂƚĞͬ<ŝůůtĞůůͿdŚŝƐƐƚĞƉƚŽďĞƉĞƌĨŽƌŵĞĚ/ĨŶĞĞĚĞĚʹ ŝĨƚŚĞ 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tĞůůWƌŽŐƌĂŵ tĞůů͗,hϮϮͲϮϱ ĂƚĞ͗ϬϮͬϬϰͬϮϬϮϮ ƌĂŶĞŽƌZŝŐtŽƌŬ ϭϳ͘D/ZhĐƌĂŶĞŽƌƌŝŐĞƋƵŝƉŵĞŶƚͬƉůĂƚĨŽƌŵƐ ϭϴ͘ZhŽŶƐŚŽƌƚƐƚƌŝŶŐƚƵďŝŶŐŚĂŶŐĞƌ͘WƵůůŚĂŶŐĞƌĂŶĚΕϮϱϬϬ͛ŽĨϮͲϯͬϴ͟ƚƵďŝŶŐĨƌŽŵǁĞůů͘ ϭϵ͘ZhŽŶϮͲϳͬϴ͟ƚƵďŝŶŐ͘ ϮϬ͘WhƚĞŶƐŝŽŶŽŶƚŚĞϮͲϳͬϴ͟ƚƵďŝŶŐƐƚƌŝŶŐ͘ ¾/ĨƚƵďŝŶŐŝƐŶŽƚĨƌĞĞ͕ƌĞƉĞĂƚĐƵƚƐƚĞƉƐΛΕϭϬϬ͛DƐŚĂůůŽǁĞƌƚŚĂŶĨŝƌƐƚĐƵƚ͘ Ϯϭ͘ŝƌĐƵůĂƚĞƚŚĞƚƵďŝŶŐǆ/ŽǀĞƌƚŽϭϬ͘ϱƉƉŐŵƵĚ͘dŽƚĂůŵƵĚǀŽůƵŵĞΕϮϭϱďďůƐ͘ ϮϮ͘WƵůůƚƵďŝŶŐƵƉƚŽϮ͕ϭϬϬ͛D͘ Ϯϯ͘ŽŶƚŝŶŐĞŶƚƐƚĞƉ͗/ĨKĚŽǁŶƐƋƵĞĞǌĞǁĂƐŶŽƚƉĞƌĨŽƌŵĞĚĚƵĞƚŽŝŶƐƵĨĨŝĐŝĞŶƚŝŶũĞĐƚŝǀŝƚǇ ¾WƵŶĐŚĐĂƐŝŶŐΛΕϮϭϬϬ͛D Ϯϰ͘ZhĞŵĞŶƚĞƌƐ͘ŝƌĐƵůĂƚĞŝŶĂďĂůĂŶĐĞĚĐĞŵĞŶƚƉůƵŐĨƌŽŵϮ͕ϭϬϬ͛ƵƉƚŽϭ͕ϵϬϬ͛͘ ¾ϭϱďďůƐϭϰʹϭϱ͘ϴƉƉŐůĂƐƐ'ĐĞŵĞŶƚ;ĚŽǁŶƚƵďŝŶŐĂŶĚŽƵƚ/Ϳ͘ZĞĐŽƌĚǀŽůƵŵĞŽĨĨůƵŝĚ ƌĞĐŽǀĞƌĞĚͿ EŽƚĞ͗/ĨƚŚĞĐĂƐŝŶŐǁĂƐƉƵŶĐŚĞĚŝŶƐƚĞƉηϮϯ;ŝ͘Ğ͘ƚŚĞKŚĂƐŶŽƚĂůƌĞĂĚǇďĞĞŶĐĞŵĞŶƚĞĚ ĨƵůůǇͿƚŚĞŶĐŝƌĐƵůĂƚĞŝŶΕϯϬďďůƐƚŽƚĂůĐĞŵĞŶƚĂŶĚĐŝƌĐƵůĂƚĞϭϯďďůƐďĞŚŝŶĚƉŝƉĞ͕ƚĂŬŝŶŐ ƌĞƚƵƌŶƐĨƌŽŵƚŚĞK͕ƚŽƉůĂĐĞĐĞŵĞŶƚϭϬϬ͛ďĞůŽǁĂŶĚϭϬϬ͛ĂďŽǀĞƚŚĞ^ƐŚŽĞ͘ ¾WƵŵƉĨŽĂŵǁŝƉĞƌďĂůů ¾ϭϭďďůƐŽĨϭϬ͘ϱƉƉŐŵƵĚĚŝƐƉůĂĐĞŵĞŶƚ Ϯϱ͘WKK,ǁͬƚƵďŝŶŐ͕ůĂǇŝŶŐĚŽǁŶ͘ Ϯϲ͘Zh^ůŝĐŬůŝŶĞ͘Z/,ǁŝƚŚ'ZĂŶĚƚĂŐƚŽƉŽĨĐĞŵĞŶƚ;dKͿ͘ŶƐƵƌĞdKŝƐĂƚŽƌĂďŽǀĞϭ͕ϵϬϬ͛͘WKK,Θ Z^ůŝĐŬůŝŶĞ͘ 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¶0'WR¶0' %DODQFHG&HPHQWSOXJLQ´FDVLQJIURP ¶0'WR¶0' %DODQFHG&HPHQWSOXJLQ´FDVLQJIURP 6XUIDFHWR¶0' %DVH RI SODQQHG FHPHQW SOXJ DW */0 PG EMP tĞůůWƌŽŐƌĂŵ tĞůů͗,hϮϮͲϮϱ ĂƚĞ͗ϬϮͬϬϰͬϮϬϮϮ • Chevron September 22, 2010 Timothy C Brandenburg Drilling Manager Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7t" Avenue Anchorage, Alaska 99501 Re: Well Status Change Dear Commissioner, u Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com SEP 242010 AncbWW Union Oil Company of California uld like to report a change of status for well Birch Hill Unit 22-25 API 50-133-10029-00 PTD 165-001 from 'SUSP' to 1 -GAS". During a review of the wellbore cos, it appears this well does not meet the requirements for a suspended well per the revised Suspended Well Regulations 20 AAC 25.110. Please let us know if we can provide any further information by contacting myself at 263-7657 or Larry Greenstein at 263-7661. Sincerely, Timothy C. Brandenburg Drilling Manager Attachments Form 10-404 in duplicate and Actual Well Schematic. Union Oil Company of California / A Chevron Company STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Li Repair Well Plug Perforations Stimulate 0 Other � Well Status Change Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re-enter Suspended Well❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5y Permit to Drill Number: Name: Development 0 Exploratory ❑ Stratigraphic❑ Service ❑ 165-001 3. Address: PO Box 196247, Anchorage, AK 99519 . API Number: 50-133-10029-00 a Q 7. Property Designation (Lease Number): 8,�Vell Name and Number: FEDA028407 [Birch Hill Unit] Birch Hill Unit 22-25 9. Field/Pool(s): 4 Birch Hill Field / Undefined Gas Pool 10. Present Well Condition Summary: 8,810 (Cement) & Total Depth measured 15,500 feet Plugs (measured) 8,097 (CIBP) feet true vertical 15,500 feet Junk (measured) 8,156 (plug body) feet Effective Depth measured 8,810 feet Packer (measured) 8,118 feet true vertical 8,810 feet (true vertical) 8,118 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 216' 20" 216' 216' Surface 2,000' 13-3/8" 2,000' 2,000' 3,090 psi 1,540 psi Intermediate Production 9,017' 9-5/8" 9,017' 9,017' 6,330 psi 3,810 psi Liner 6,609' 7" 15,500' 15,500' 9,960 psi 6,210 psi Perforation depth: Measured depth: 8,190'-8,220' True Vertical depth: 8,190'-8,220' 2-7/8"(LS) / 2- 6.5# N-80(LS) / 4.7# 8,220'MD (LS) / 8,220'TVD (LS) / Tubing (size, grade, measured and true vertical depth): 3/8" (SS) N-80(SS) 2,512'MD (SS) 2,512 -TVD (SS) Brown Mod HS- 8,107'MD Packers and SSSV (type, measured and true vertical depth): 16-1 Packer (8,107'TVD) N/A N/A VOW 11. Stimulation or cement squeeze summary: Intervals treated (measured): SEP 2 4 2010 N/A Treatment descriptions including volumes used and final pressure: ifbmm �jl, Q fM N/A N/Representative 12. Daily Average Production or Injection D Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1140 psi 10 psi Subsequent to operation: 0 0 0 1140 psi 10 psi 13. Attachments: N/A 14. Well Class after work: Exploratory 11 Development0 Service ❑ Copies of Logs and Surveys Run 15. Well Status after work: Oil Gas 2 WDSPL ❑ GINJ ❑ WIN, ❑ SPLUG ❑ Daily Report of Well Operations N/A GSTOR ❑ WAG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Chris Kanyer 263-7831 Printed Name Tim th C. Brandenburg Title Drilling Manager Signa re Phone 276-7600 Date 9/21/10 Z Mt$DMS SEP 2 r RBf �A�.. SEP 2 4..10 Form 10-404 Revised 7/2009 Submit Original Only RKB: 228'/ GL: 214' AMSL KB — THF: 14.4' 1 20„ 1 N 216' �� y 2 13-3/8" A 3 2,000' B CBL TOC 6,550' 0 c CBL TOC t 7,083' 8 9 10 Tag fill 8,752' SLM 3/02/88 L� TOL 8,891' 9-5/8" 9,017' CBL TOC 14,500' 10.7 ppg �lud Birch Hill Unit BHU 22-25 Well BHU 22-25 Last Completed , Actual Wellbore Schematic 07/08 C a s i n n R T it h i n n Size Type Wt Grade ID Top Btm Hole Cmt Cmt To 20" Conductor 78.6 B Surf 216' 26" 475 sx Surf. 13-%" Surf Csg 68 12.415 Surf 720' 61 J-55 12.515 720' 2,000' 18-%" 1985 sx 15 sx Top Job Surf. 13 '/a" 9-%" Prod Csg 43.5 P-110 8.755 Surf 2,582' 12-'/" 1000 sx 6,550' CBL 9-%" 43.5 N-80 8.755 2,582' 5,586' 9-%" 43.5 P-110 8.755 5,586' 7,083' 9-'/" DV Collar 7,083' 7,085' 9 s/a°' 43.5 P-110 1 8.755 7,085' 9,017' 850 sx 7,083' CBL 7" Liner 26 P-110 1 6.276 8,891' 10,951' 8-%s 600 sx 100 sx Liner La 14,500' CBL 7„ 29 P-110 6.184 10,951' 15,500' Tubing CplCplX OD 2 %" EUE 8RD 6.5 N-80 2.441 Surf 8,220' 3.668" 2 %" EUE 8RD 4.7 N-80 1.995 Surf 2,512' 3.063" Tyonek Tag cement plug 8,810' RKB i 5/26/65 IF.W F. 1.R V LIFT A 11, No. Depth ID OD Item 1 14.4' - - Dual Tubing Hanger, Shaffer, 2-7/8" x 2-3/8" Unknown Lift x Suspension Threads, 2-1/2" Casasco BPV Profile 2 113' 2.313" 2.875" S Nipple, 2.313" I.D. , position #2 3 2,04 Y 2.313" 2.875" S Nipple, 2.313" I.D.position #1 4 8,065 - - GLM, 2-7/8", Carrico MM 5 8,097' 05/23/65 - Cast Iron Bridge Plug 6 8,107' 2.438" 1 3.688" CC Safety Joint, Brown J -Slot type(possibly kinked 7 8,118' 2.500" 8.250" Packer, Brown Mod.HS-16-1 5-1/4" Box x 2-7/8" 8RD Pin 8 8,156' - - Plug, CA plug (C Lock Body only, No A -Prong) 9 8,156' CamCn`D"Nipple 10 8,220' Venturi Shoe A 109' 1.875" 2.375" S Ni le 1.875" I.D. position #1 B 'L"' 512' Joint 2-3/8" turned down to 1-5/8" Liner lap squeeze 100 sx 12'3 ppg AIN Balanced plug Nlud 14,630'-14,860' PC A CLIA A T InN 1414QT(IR V Hemlock 12.3 ppg 7" Mud 15,500' _ ':gip TD =15,500' PBTD = 15,486' MAX HOLE ANGLE = 1.8° @ 10,066' BHU 22-25 Actual Well Schematic 3-07-88 doc Updated by STP 9-24-10 Interval Accum. Date Zone To Btm Amt SIA Comments 05/28/65 Tymek 8,190' 8,220' 30' 4 Open 05/20/65 Hemlock 14,705' 14,706' 1' 5 P&A 5/25/65 05/23/65 Hemlock 14,710' 14,747' 37' 4 P&A 5/25/65 05/22/65 Hemlock 14,765' 14,820' 55' 4 P&A 5/25/65 Hemlock 12.3 ppg 7" Mud 15,500' _ ':gip TD =15,500' PBTD = 15,486' MAX HOLE ANGLE = 1.8° @ 10,066' BHU 22-25 Actual Well Schematic 3-07-88 doc Updated by STP 9-24-10 0 • PETROLEUM NEWS • WEEK OF NOVEMBER 29, 2009 y 7+ 1 5 • ERP L0RAT 10N 8 PRODUCTION �C�T `j.,�,.` •` �`�� Chevron permitting Birch H ill pads, road cil North Swanson project includes evaluation of existing Birch Hill well, possible second pad between Birch Hill and Swan on River o }} N By KRISTEN NELSON The existing Birch Hill pad is approxi- In addition to the natural l gas flowline, YD Pctrolrum N- On the Web mately 105 feet by 305 feet and will be other utilities might be bled in the improved and enlarged to approximately pipeline trench: a 3- to 4-inc high - density 300 feet b 400 feet. The second ad, NS- polyethylene line for trans on of produced hevron Corp. subsidiary Union Oil See previous Petroleum News coverage. Y P P P' r C � Company of California is permitting "Swanson River gas satellites a go; A, would also be approximately 300 feet by water from the satellite to Swanson River development of natural gas resources at the chevron, Marathon moving ahead," in 400 feet. facilities; a 4- to 6 -inch steel secondary � LLA Birch Hill unit. Birch Hill, also referred to July 19, 2009, issue at product line for possible use as a redundant as the North Swanson River satellite, is in �.petroleumnews.comtpnads2385024 Fowline to Swanson River gas or water line; and electrical, communi- Southcentral Alaska on the Kenai 9.shtml If there are commercially viable quanti- cation or other service lines. Peninsula. "Unocal's Birch Hills development second ties of hydrocarbons, a flowline would be When production operations cease, pro - The company said in its plan of opera- on list," in June 1, 2003, issue at installed from the Birch Hill pad back to the duction facilities will be removed, wells tions that while the plan addresses the v— pevoleumnews.coMpnads9631758 Swanson River field gathering infrastmc- abandoned and surface sites restored. d 54.shtml development and production phases of the tire. Additional facilities would be installed project. "the production phase will only r at the well site as necess Additional wells "Unocal plans Swanson River gas field y' ,t rllf� occur if commercially viable quantities of expansion," in March 28, 2001, issue at The flowline would be a buried natural The company said additional wells may hydrocarbons are discovered in the area." wvwv .petroleumnews.com/pnacis0051956 gathering line from 4 inches to 10 inches in be drilled to fully develop the resource. Birch Hill has a shut -in Tyonek forma- 23.shtml diameter; it m ould be constructed from each "Current knowledge of the geologic tion gas well. In addition to Chevron, which of the satellite well pads along the roadway structures indicates a potential reserve accu- has a 78.71 percent working interest, CIRI to tie in with existing Swanson River infra- mulation of recoverable gas, which may Production Co. has a 19.68 percent interest the proposed ed pad pad and then proceed north to structure. The line would be approximately support more wells than initially planned. and Marathon Oil Co. has a 1.61 percent the p miles. roposg Birch Hill well w for a total of some 3.8 miles in length. depending upon reservoir quality." v` orking interest. well and then to the Installation would be in a trench along Additional development drilling is not 3.83 Chevron is the Swanson River unit oiler- the right of way. anticipated to occur until 2010 or later. • ator and has 100 percent working interest at Swanson River, which produces natural gas from the Sterling and Beluga formations, "In my opinion, Alaska DNR has one of the most and oil from the Hemlock formation. Tm 0 depleted Tyonek formation gas pools at Swanson River are used for natural gas stor- impressive subsurface teams in the country." age. An environmental the Sw anson River satellites impact statement was wrtt n f or the Sw Mark Myers, Former Director, U.S. Geological Survey projects The U.S. Fish and Wildlife Service issued a record of decision fa' the final EIS in 2004. The selected alternative for the - gravel access road was a 3.83 -mile road from Swanson River field to the existing - 1 ` OV Birch Hill unit 22 2 5 �ad access the existing natural gas weldor evaluation, Planned work includes vegetation clear- J ing and road construction in the fall and - wmter of 2009; well testing and drilling m - the winter ands rim of 2010; and facil spring Y construction in the spring an summer , d sum lei of P g 1 r 2010. - t s. {p 8r Possdde second pad The North Swanson River satellite f G' includes the Birch Hill unit, ante -well field. and the land between Birch Hill and the Swanson River field boundaries. In addition to installation of a gravel access road and pipelines to tie the existing Birch Hill well into the Swanson River field, if _ reserves warrant a second pad location mould be built along the right of way for - drilling and production activities. - - - The satellite is some three miles north- - - east of the northern Swanson River field • NO Yom of embfted ploftedo ?95pftlewe boundary. • 1677*m of eo=htwod Ludmtry expodem* - Access will be via existing Swanson - River field roads and the new road will • A tee of pet rolesIM _ �'n • an e0 _ originate from the ARCO Buftlehead right - of way to the location of the former We have the capacity, experience, and integrity to work with potential investors to give technical briefings and share our knowledge and non - confidential public domain O data. We provide insight into how state and federal agencies interact to help operators navigate smoothly through their exploration and development activities. Alaska: We're G` O pen For B usiness! "Alaska Department of NATURAL Division of Oil and Gas 550 West 7th Avenue, Suite 1100 RESOURCES Anchorage, Alaska 99501 -3560 te1:907- 269 -5800 U & GAS http: / /www.dog.dnr.state.ak.us /oil/ Chevron W W%..- 0. 0 March 31, 2009 Dale Haines Alaska Area Operations Manager Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Suspended Wells Dear Commissioner Foerster, �(-ks-C'C.3 � Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7951 Fax 907 263 7607 Email Daleah@chevron.com iaC l�B� phe SCAN= OCT 03 2014 Please find the attached corrections to the suspended and long term shut in well list as provided in your letter dated January 28, 2009. As per our discussion the submitted list needs to be expanded to include additional wells that may not currently be identified on the list provided by the Commission. We also provide the Commission with an annual shut in well report that is sent to Steve McMains. This report was mailed to the Commission on March 30, 2009. At this time I cannot validate that we have provided the Commission with a comprehensive list of all suspended wells so it is our intention to validate the two lists and to review our records to ensure that we have accurately responded to the request. We will therefore endeavor to provide a comprehensive list to the Commission in the next two weeks. Chris Myers will contact Jim Regg to discuss the scheduling inspections of the suspended wells in 2009. If you have any questions about this submittal, please contact myself. Sincerely, (-)�a'�_ Dale Haines Alaska Area Operations Manager Attachment Cc: Tim Brandenburg Chris Myers Dave Cole Union Oil Company of California / A Chevron Company http://www.chevron.com Corrections for the referenced list of suspended and long-term shut-in wells operated by UNOCAL. Well Name API# PTD Current Listed Status Corrected Status Bruce 18742 #40 50-733-20339-00 181-022 Suspended Shut -In SRU 14-15 50-133-10145-01 100-146 Suspended Shut -In SCU 243B-04 50-133-20489-00 199-055 Suspended Shut-in i i ALASKA OIL AND GAS CONSERVATION COM USSION i January 28, 2004 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 6019 I)ale Ifaines UNOCAL 1800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut-in Well Information Dear Mr. I faines: SARAN PALIN, GOVERNOR 33: 'J . 7th AVENUE. SUITE 100 AN:;HORAGE. ALASKA 99501-3539 PHONE (907) 279-1.433 FAX (907) 2767542 Enclosed are the Alaska Oil and Gas Conservation Commission's revised regulations regarding suspended wells (i.e., 20 AAC 25.110). Also enclosed is a list of suspended and long-term shut-in wells operated by UNOCAL. I'or each list, please verify the information for each well and provide any con•ections by April 1, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with .lim Regg at 907-793-1236 or jim.regg@alaska.gov. _• ov questions rnga rd'r?g this notice, please contact Tom M. ,,iundf r at 0117-793- 1250 or tom.maundcr@alaska.gov. Sincerely, Cathy P. Foerster Commissioner linclosures Operator Suspended and Shutt In Wells UNION OIL CO OF CALIFORNIA Field (:urrc•u( Dile of Permit A1'1 Number Well Mime S(atus S(aftls surface Loco ion.................................................... lxasc(s)................ BIRCH HILL 165.001-0 50-133-10029-00-00 BIRCH HILL UNIT 22-25 SUSP 3/7/1988 1836 FNL 1954 FWL Sec 25 T 9 N R 9 W SM FEDA028407 DEEP CREEK 207-123-0 50-231-20031-00-00 HAPPY VALLEY B-12 SUSP 11/25/2007 2908 FNL 293 FEL Sec 21 T 2S R 13 W SM FEE-CIRI 14 IV A - s GRANITE PT 196.045-0 50-733-20472-00-00 GRANITE POINT 52 SUSP 8/11/1997 2428 FNL 1298 FWL Sec 13 T ION R 12 W SM ADL0018761 196.013-0 50-733-20470-00-00 GRANITE POINT 54 SUSP 4/22/2006 2427 FNL 1303 FWL Sec 13 T ION R 12 W SM ADL0018761 197.145-0 50-733-20479-00.00 GRANITE POINT 55 SUSP 8/26/1997 2437 FNL 1303 FWL See 13 T ION R 12W SM ADL0374044 167-057-0 50-733-20046-00-00 GRANITE PT ST 11-24 SUSP 9/30!1997 2383 FNL 1368 FWL Sec 13 T ION R 12W SM ADL0018761 167-023-0 50-733-20018-00-00 GRANITE PT ST 18742 09 SUSP 9/16/1989 834 FNL 676 FEL Sec 12 T ION R 12 W SM AOL0018742 167-042-0 50-733-20032-00-00 GRANITE PT ST 18742 10 SUSP 9/29/1988 1948 FSL 1979 FWL Sec 31 T 11 N R 11 W SM ADL0018742 178-096-0 50-733-20119-00-00 GRANITE PT ST 18742 31 SUSP 10/7/1988 1945 FSL 1982 FWL Sec 31 T 11 N R 11 W SM ADL0018742 179-017-0 50-733-20441-01-00 GRANITE PT ST 18742 34 SUSP 9/20/1991 2012 FSL 1945 FWL Sec 31 T 11 N R 11 W SM ADL0018742 181-022-0 50-733-20339-00.00 GRANITE PT ST 18742 40 SUSP 4/21/1982 1948 FSL 1975 FWL Sec 31 T 11 N R 11W SM ADL0018742 195-005-0 50-733-20465-00.00 GRANITE PT ST 18742 52 SUSP 7/9/1995 730 FNL 682 FEL Sec 12 T ION R 12 W SM ADL0018742 MCARTHUR RIVER 169-095-0 50-733-20203-00-00 TRADING BAY UNIT D-20 SUSP 1/31/2007 672 FSL 1211 FWL Sec 6 T 8N R 13W SM ADL0018729 173-001-0 50-733-20248-00-00 TRADING BAY UNIT K-17 SUSP 4/20/2002 694 FSL 83 FEL Sec 17 T 9 N R 13 W SM ADL0017594 SWANSON RIVER 199-055-0 50-133-20489-00.00 SOLDOTNA CK UNIT 243B-04 SUSP 9/22/1999 2003 FSL 575 FEL Sec 4 T 7N R 9W SM FEDA028997 180-106-0 50-133-20232-01-00 SOLDOTNA CK UNIT 42A-05 SUSP 8/9/2006 1879 FSL 498 FEL Sec 5 T 7N R 9W SM FEDA028997 ' 182-199-0 50-133-20363-00-00 SOLDOTNA CK UNIT 428-05 SUSP 6/21/2006 1823 FSL 572 FEL Sec 5 T 7N R 9W SM FEDA028996 100-146-0 50-133-10145-01-00 SWANSON RIV UNIT 14-15 SUSP 1/28/1997 360 FSL 1680 FEL Sec 16 T 8 N R 9W SM FEDA028406 162-034-0 50-133-10148-00-00 SWANSON RIV UNIT 14-22 SUSP 10/5/1995 660 FSL 660 FWL Sec 22 T 8 N R 9 W SM FEDA028406 172-007-0 50-133-20237-00-00 SWANSON RIV UNIT 24-33 SUSP 4/1/1993 932 FNL 2089 vWL Sec 4 T 7 N R 9 W SM FEDA028399 162-030-0 50-133-10143.01-00 SWANSON RIV UNIT 41A-15 SI 8/26/1987 615 FNL 715 FEL Sec 15 T 8 N R 9W SM FEDA028384 203-074-0 50-133-20523-00-00 SWANSON RIVER KGSF 3 SUSP 8/22/2007 1754 FNL 4030 FEL Sec 27 T 8N R 9W SM FEQA028406 -. 11'edaesday, Jaauar),14, :009 ,,% �I e 2 Gip/ 0�sn �r•ii -rPs;A.1/ Q'/ iesT''✓ Operator UNION OIL CO OF CALIFORNIA Field Permit AI't Number Well Dame Suspended and Shut In Wells TRADING BAY 190-041-0 50-733-20302-01-00 TRADING BAY ST A-20RD ti'ednesdnl-, Jantimy 14, 2009 Current Dale of Status Status Surface Localion.................................................... Lease(s)................................... SUSP 4/2311990 1604 FSL 559 FL -L Sec 4 T 9 N R 13 W SM ADI -0018731 20 AAC 25.1 t 0. Sasoended wells (a) if i[HOwcd under 20 AAC ?.105, the commission will, upon al)pl;C,+tion by t:1C operator under (b) of this section, approve the suspension of a well is (1) the well (A) encounters hydrocarbons of sufficient quality and quantity to indicate that the well is capable of producing in paying quantities, as reasonably demonstrated by well tests or interpretive formation evaluation data; for purposes of this paragraph, "paying quantities" means quantities sufficient to yield a return in excess of operating costs; (H) is a candidate for redrilling; (C) has potential value as a service well; or (I)) is located on a pad or platform with active producing or service wells; and (2) the operator justifies to the commission's satisfaction why the well shoulc not be abandoned, and, if the well is not completed, why the well should not be completed; sufficient reasons include the (A) unavailability of surface production or transportation facilities; (B) imprudence of security maintenance of a completed well in a shut-in status; (C) need for pool delineation and evaluation to detennine the prudence oi` pool development. (b) An Application for Sundry Approvals (Form 10-403) must be submitted :o and approved by the commission before plugging operations are begun; in a well for which suspension is proposed, except that oral approval may be obtained from the commission if it is followed within three days by the submission of an Application for Sundry Approvals for final approval by the commission. Approval will be conditioned as necessary to protect freshwater and hydrocarbon resources. An Application for Sundry Approvals must include (1) the reason for suspending the well and information showing that the applicable criteria for suspension under (a) of this section have been met; and (2) it statemcnt of proposed work, including (A) information on abnon-nally geo-pressured strata; (13) the manner of placement, kind, size, and location, by measured depth, of existing and proposed plugs; (C) plans for cementing, shooting, testing, and removing casing; (la) if the ;\hplic,;tion for Sundry Approvals is submitted after begi!:ning work, the manic of the representative of the commission who provided oral approva, and the date of the approval, and (E) other information pertinent to suspension of the well. (c) At the operator's request accompanying the submission, information submitted to show that the applicable criteria for well suspension under (a) of this section have been met will be kept confidential (1) for the period specified under -AS 1) 1.05.035 (c), if the inforrnaton is described in 20 AAC 25.071(7) ; or (2) for the time that the infonnation has value as a trade secret, if Tac infornnaticn is not described in 20 AAC 25 7j but is determined by the commissioi: to constitu.e a trade secret under AS 45.50.940 . (d) A well approved for suspension must be plugged in accordance with the requirements of 20 AAC 25.1.12, except that the requirements of 20 AAC 25.112(d) do not apply if (1) a wellhead is installed or the well is capped with a mechanical device to scal the opening; and (2) a bridge plug capped with 50 feet of cement or a continuous cement plug extendin; 200 feet within the interior casing string is placed at or above 300 feet below the surface; the commission will waive the requirement of this paragraph for a development well drilled from a pad or platform, if the commission determines that the level of activity on the pad or platf'omn assures adequate surveillance of that development well. (e) Until a suspended well has been abandoned or re-entered, the operator shall riaintain the integrity of the location, provide the commission with a well status report every five years, and clear the location in accordance with 20 AAC 25.170(a) (2) or (b) or with 20 AAC 25J 72(c) (2) or (d), as applicable. History: Eff. 4/2/86, Register 97; am 11/7/99, Register 152 Authority: AS 31.05.030 AE 0 AD D SARAH PALIN, GOVERNOR 1�T AUASHAA011L AND GAS 333 W. 7th AVENUE, SUITE 100 CD"SEj RVA ]IOT COMMSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 January 28, 2009 FAX (907) 276.7542 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 6019 Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut -In Well Information Dear Mr. Haines: ,400) OCT OS 2014 Enclosed are the Alaska Oil and Gas Conservation Commission's revised regulations regarding suspended wells (i.e., 20 AAC 25.110). Also enclosed is a list of suspended and long-term shut-in wells operated by UNOCAL. For each list, please verify the information for each well and provide any corrections by April 1, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with Jim Regg at 907-793-1236 or jim.regg@alaska.gov. If you have any questions regarding this notice, please contact Tom Maunder at 907-793- 1250 or tom.maunder@alaska.gov. Sincerely, Cathy P. Foerster Commissioner Enclosures Postal CERTIFIED M �.AIL. RECEIPT o(Domestic Er �lks�b �' �J A L USLE ti Postage $ $0.59 SPS PpS,� C3 Certified Fee 12.70 N C3 Return Receipt Fee i (Endorsement Required)2.20 O C! Restricted Delivery Fee C rU (Endorsement Required) $0 W ., cD AK ccc0 Total Postage 8 ' V5. Mi9 0111281 C3 Sentro Dale Haines M UNOCAL f` Sfreet, Apt. No.; or Po sox No. 3800 Centerpoint Dr. Ste 100 City Stets, LRr Anchorage AK 99503 MMEM • Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. • Print your name and address on the reverse so that we can return the card to you. E Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 A. gnature / �F � -^, ,,�� ff �At X, _` °}�, L �i ❑ ,�cc P.,,Received b��(Printed Name) -- C. Qa o h 1 9 4z' \) t <— -C T z E D. Is delivery address different from item 1? ❑ Y If YES, enter delivery address below: ❑ No S ice Type rtified Mail ❑ Express Mail ❑ Registered O'Return Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 2. Article Number (Transfer from service label) 7005 1820 0001 2499 6 019 PS Form 3811, February 2004 Domestic Return Receipt 102595-02-M-1540 Operator Suspended and Shut In Wells UNION OIL CO OF CALIFORNIA Field Current Date of Permit API Number Well Name Status Status Surface Location ................................ Lease(s).................................. BIRCH HILL 165-001-0 50-133-10029-00-00 BIRCH HILL UNIT 22-25 SUSP 3/7/1988 1836 FNL 1954 FWL Sec 25 T 9 N R 9 W SM FEDA028407 DEEP CREEK 207-123-0 50-231-20031-00-00 HAPPY VALLEY B-12 SUSP 11/25/2007 2908 FNL 293 FEL Sec 21 T 2S R 13W SM FEE-CIRI GRANITE PT 196-045-0 50-733-20472-00-00 GRANITE POINT 52 SUSP 8/11/1997 2428 FNL 1298 FWL Sec 13 T 10 N R 12W SM ADL0018761 196-013-0 50-733-20470-00-00 GRANITE POINT 54 SUSP 4/22/2006 2427 FNL 1303 FWL Sec 13 T 10 N R 12W SM ADL0018761 197-145-0 50-733-20479-00-00 GRANITE POINT 55 SUSP 8/26/1997 2437 FNL 1303 FWL Sec 13 T 10 N R 12W SM ADL0374044 167-057-0 50-733-20046-00-00 GRANITE PT ST 11-24 SUSP 9/30/1997 2383 FNL 1368 FWL Sec 13 T 10 N R 12W SM ADL0018761 167-023-0 50-733-20018-00-00 GRANITE PT ST 18742 09 SUSP 9/16/1989 834 FNL 676 FEL Sec 12 T 10 N R 12 W SM ADL0018742 167-042-0 50-733-20032-00-00 GRANITE PT ST 18742 10 SUSP 9/29/1988 1948 FSL 1979 FWL' Sec 31 T 11 N R 11 W SM ADL0018742 178-096-0 50-733-20119-00-00 GRANITE PT ST 18742 31 SUSP 10/7/1988 1945 FSL 1982 FWL Sec 31 T 11 N R 11 W SM ADL0018742 179-017-0 50-733-20441-01-00 GRANITE PT ST 18742 34 SUSP 9/20/1991 2012 FSL 1945 FWL Sec 31 T 11 N R 11 W SM ADL0018742 181-022-0 50-733-20339-00-00 GRANITE PT ST 18742 40 SUSP 4/21/1982 1948 FSL 1975 FWL Sec 31 T 11 N R 11 W SM ADL0018742 195-005-0 50-733-20465-00-00 GRANITE PT ST 18742 52 SUSP 7/9/1995 730 FNL 682 FEL Sec 12 T 10 N R 12W SM ADL0018742 MCARTHUR RIVER 169-095-0 50-733-20203-00-00 TRADING BAY UNIT D-20 SUSP 1/31/2007 672 FSL 1211 FWL Sec 6 T 8 N R 13W SM ADL0018729 173-001-0 50-733-20248-00-00 TRADING BAY UNIT K-17 SUSP 4/20/2002 694 FSL 83 FEL Sec 17 T 9 N R 13 W SM ADL0017594 SWANSON RIVER 199-055-0 50-133-20489-00-00 SOLDOTNA CK UNIT 2436-04 SUSP 9/22/1999 2003 FSL 575 FEL Sec 4 T 7 N R 9 W SM FEDA028997 180-106-0 50-133-20232-01-00 SOLDOTNA CK UNIT 42A-05 SUSP 8/9/2006 1879 FSL 498 FEL Sec 5 T 7 N R 9 W SM FEDA028997 182-199-0 50-133-20363-00-00 SOLDOTNA CK UNIT 426-05 SUSP 6/21/2006 1823 FSL 572 FEL Sec 5 T 7 N R 9 W SM FEDA028996 100-146-0 50-133-10145-01-00 SWANSON RIV UNIT 14-15 SUSP 1/28/1997 360 FSL 1680 FEL Sec 16 T 8 N R 9 W SM FEDA028406 162-034-0 50-133-10148-00-00 SWANSON RIV UNIT 14-22 SUSP 10/5/1995 660 FSL 660 FWL Sec 22 T 8 N R 9 W SM FEDA028406 172-007-0 50-133-20237-00-00 SWANSON RIV UNIT 24-33 SUSP 4/1/1993 932 FNL 2089 FWL Sec 4 T 7 N R 9 W SM FEDA028399 162-030-0 50-133-10143-01-00 SWANSON RIV UNIT 41A-15 SI 8/26/1987 615 FNL 715 FEL Sec 15 T 8 N R 9 W SM FEDA028384 203-074-0 50-133-20523-00-00 SWANSON RIVER KGSF 3 SUSP 8/22/2007 1754 FNL 4030 FEL Sec 27 T 8 N R 9 W SM FEDA028406 Wednesday, January 14, 2009 Operator Suspended and Shut In Wells UNION OIL CO OF CALIFORNIA Field Current Date of Permit API Number Well Name Status Status Surface Location.................................................... Lease(s)................................... TRADING BAY 190-041-0 50-733-20302-01-00 TRADING BAY ST A-20RD SUSP 4/23/1990 1604 FSL 559 FEL Sec 4 T 9 N R 13 W SM ADL0018731 Wednesday, January 14, 2009 DEPT. OF ENVIRONMENTAL CONSERVATION DIVISION OF ENVIRONMENTAL HEALTH SOLID WASTE PROGRAM 410 WILLOUGHBY AVE., SUITE 303 JUNEAU, ALASKA 99801 http ://www.state.ak.us/dec/deh Telephone: (907) 465-5162 Fax: (907) 465-5362 September 14, 2001 Ms. Lisa Pekich Senior Environmental Coordinator Phillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Reference: Issuance of Permanent Closure Approval for Inactive Reserve Pits located at nine exploration sites located on the North Slope, SouthCentral, and Interior Alaska Dear Ms. Pekich: The Alaska Department of Environmental Conservation (ADEC) has completed review and public notice for nine inactive reserve pit closure applications and requests for permanent closure approval. The closure applications provided the required information describing the history of the reserve pit(s), the present condition of the reserve pits(s), results of any required water sampling and an assessment of the potential risks posed by the drilling waste to human health and the environment. At these locations, the reserve pits have been backfilled and there is no exposed drilling waste. ADEC coordinated review of the closure requests with the appropriate land manager(s). Public notice requesting comments on the closure requests was published August 3 and 4, 2001 in the Anchorage Daily News and posted on the State Web Site August 2, 2001.. No public comments were received in response to this public notice. ADEC has determined that the reserve pits at these sites meet the closure requirements of 18 AAC 60.440. Closure Approval Under authority of I8 AAC 60.440 (j), ADEC grants permanent closure approval to Phillips Alaska 'Inc. for the inactive reserve pits at the following nine exploration sites: Well Name AP1 Number Beluga River Unit 212-25 ! Co 50L283-10025-00 Birch Hill Unit 22-25 ~,o~,~ 50-133-10029-00 Swan.Lake Unit# 2 ~ ~ 50-133-10021-00 06~4-~Falls Creek Unit # 1 (13-06) c,,~,~50-133-10005-00 Rainbow Federal # 1 ~>:~ bx 50-099-10004-00 Rainbow Federal # 2 ~' ~ Ix, 50-099-10005-00 ~,~%oKaliakh #212 RD ¢~' I~ 50-033- I0002-00/01 KRU West Sak SWPT #1*-jo~ 50-029-20915-00 West Sak River. State # 2 .~'~.-~50-029-20134-00 MTRS Sec. 25 13N, 10W,SM Sec. 25 09N, 09W,SM Sec. 3 07N, 006W,SM Sec. 6 01N, 12W,SM Sec. 31 08N, 05W,CR Sec. I 08N, 05W,CR Sec. 28 20S, 014E,CR · Sec. I 1 11N,10E,UM Sec. 22 IIN, 10E,UM - Landowner ADNR/ADF&G US~S US~S %x Private Property BLM ~k'~t,,.C3 { pge..~ DNR /~X"'ct,-.~ ! ?~<.~ e.,~ pnnled on recycled oaper Phillips Alaska, Inc. Ms. Lisa L. Pekich September 14, 2001 Page 2 Terms and Conditions This final closure approval is subject to the following terms and conditions: In accordance with 18 AAC 60.440(1), the Department will require additional investigation, assessment, monitoring or remediation if new information regarding conditions at the reserve pit facilities indicates that further actions are necessary to protect human health or the environment. 2) The approval granted by this letter is for the inactive drilling waste reserve pit(s) only. Closure for the pad as a whole (if required) must be coordinated between the owner/operator and the appropriate land owner/manager. Any person who disagrees with any portion of this decision may request an adjudicatory hearing in accordance with 18 AAC 15.200-310. The request should be mailed to the Commissioner of the Department of Environmental Conservation, 555 Cordova Ave. Anchorage, AK 99501. If a hearing is not requested within thirty (30) days of the date of this letter, the right of appeal is waived. If an adjudicatory hearing is requested and granted, this decision remains in full effect during the adjudicatory process. Sincerely, Heather T. Stockard Solid Waste Program Manager Heather Stockard @envircon.state.ak.us CCi Harry Bader, ADNR, 3700 Airport Way, Fairbanks, AK 99709-4699 Deborah Heebner, ADNR, 550 W 7t~ Ave. Suite 900C, Anchorage, AK 99501-3577 William Friar, BP Exploration, P.O. Box 196612, Anchorage, AK 99519-6612 Don McKay, ADF&G, 333 Raspberry Rd., Anchorage, AK 99502 Harold Pederson, 925 R Street, Anchorage, AK 99501 BLM, Ramone McCoy, BLM District Manager, Box 147, Glennallen, AK 99588 Claire Caldes, USFWS, Box 2139, Soldotna, AK 99669-2139 Charles Underwood, Marathon Oil Company, P.O. Box 196168, Anchorage, AK 99519-6168 ARCO Alaska, Inc. , Post Office B~.,_ 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 March 31, 1995 Mr. David W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Johnston, Re: Suspended Well Update ARCO Alaska Inc. ("ARCO") has compiled data pertaining to the 25 suspended wells described in your August 19, 1994, letter. Any additional suspended wells which were discovered during our research are also included in this update. I have attached an update on each well and grouped the wells by geographic area. If you have any questions, please call the ARCO Contact indicated for each geographical area or me at 265-6914. Sincerely, ,,~.,?'Senior Landmgn" JRW:hb Enclosures CC: M. L. Bill L. D. Brown H. R. Engel R. M. Lance T. W. McKay G. K. Phillips M. J. Reisterer ATO 1528 LAO 466 ATO 1918 ATO 1420 ATO 1202 ATO 496 ATO 1439 RECEIVED APR 1 4 1995 0il & Gas Cons. Commission Anch0ra: ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company Exploration Wells (ARCO Contact: Tom McKay 265-6890) ARCO hereby requests extensions of "suspended" status for the following wells. West Mikkelsen State #1, APl # 50-029-20278-00, Permit # 78-0017-0 This well was Certified Capable of Producing in Paying Quantities on February 15, 1979. Hemi Springs State #1, APl # 50-029-21056-00, Permit # 83-0181-0 .This well was Certified Capable of Producing in Paying Quantities on June 4, 1984. ~Birch Hill 22-25, Perrnit"#'~65:l This well was Certified Capable of Producing in Paying Quantities. Falls Creek #1, This well was Certified Capable of Producing in Paying Quantities on February 18, 1944. The following wells are scheduled to be plugged and abandoned: Delta State #1, APl # 50-029-20004-00, Permit # 68-0095-0 Delta State #2, APl # 50-029-20150-00, Permit # 74-0056-0 Put River State #1, APl # 50-029-20017-00, Permit # 69-0036-0 Kavik Unit #3, APl # 50-179-20004-00, Permit # 73-0027-0 Highland State #1, APl # 50-029-20199-00, Permit # 76-0017-0 Ravik State #1, APl # 50-029-20888-00, Permit # 82-0218-0 Sag River State #1, APl # 50-029-20002-00, Permit # ? Northwest Eileen State #1, APl # 50-029-20013-00, Permit # ? APR 'l 4 1995 Alaska 0il & Gas Cons. C0mnilssl0~ Anch0ra. ~ The following well is no longer operated by ARCO: Swanson River Unit #34-15, APl # 50-133-10142-00, Permit # 60-0041-0 ALASKA OIL AND GAS CONSERVATION COMMISSION PETROLEUM WELL RECORD 07/28/93 I PERMIT I API I WELL WELL I LEASE I CONFIDI I NUMBER I NUMBER I NAME I NUMBER ISRTI NUMBER I CODE 165-0001-0 1331002900 BIRCH HILL UNIT 22-25 010 FEDA028407 ~ I OPER OPERATOR I GEOLOGIC I ON-OFF I CODE I NAME I CODE I AREA I SHORE 1145000 UNION OIL CO OF CALIFORNIA 820 COOK INLET BASIN ON + ........................................................................ IFLDPOL FIELD AND POOL I b~ULTI-COMP I NUMB I LOG I CODE I NAb~E IFLD&POOLt FLD&POOLI COMP I LOCAL I ...... I ................................ I I ........ I ...... I ....... 1104500 BIRCH HILL, UNDEFINED 000000 000000 0 21D + ........................................................................ I UNIT UNIT I ELEVATIONS I DEPTHS ICODE I NA~E I CODEIFEETI CODEIFEETI MD I TVD I ...... 150230 BIRCH HI,LLS KB 228 00 15500 + ........................................................................ SURFACE LOCATION I BOTTOM HOLE LOCATION I IFEETIDIRIFEETIDIRI SECITWP I RNGIMERI FEETIDIRIFEETIDIRI SECITWP I RNGIMERI 11836 N 1954 W 25 09N 009W S 1836 N 1954 W 25 09N 009W S I + ........................................................................ I LATITUDE I LONGITUDE I FOOTAGE DRILLED IPERM ISSSv tDEGIMINI SEC IDEGIMINI SEC IYEARIFEET IYEARIFEET IYEARIFEET ITHICKIDEPTHI I 65 155o0 + ........................................................................ I INITIAL I FINAL I CURRENT I REQUIREMENTS I FRMI SALES I I CLASS I STATUS I CLASS I STATUS I CLASS I STATUS I SAMPLI MUD I SUR IOTHERITSTIACCTGI I EXP 1-OIL DEV 1-GAS DEV SI YES 000 I + ........................................................................ I PERMIT I PERMIT I DATE I DATE I STATUS I RECORD I I APPROVED I ISSUED I SPUDDED I COMP, ETCI DATE I LAST UPD I I 01/20/65 01/20/65 01/30/65 06/09/65 06/09/65 04/02/93 I + ................................................................. + ARCO Alaska, Inc. ~,.~--,.,. Post Office E 00360 Anchorage, ~.~aska 99510-0360 Telephone 907 276 1215 August 22, 1991 Mr. Ken Rogowski State of Alaska Department of Environmental Conservation 3601 "C" stre% Suite 360 Anchorage, AK 99503 Subject: Oil Spill Prevention and Contingency Plan Birch Hill #22-35 Extension Well zz-zr- o~.F-- / Dear Mr Rogowsld: Enclosed for your review and distribution are five copies of the Oil Discharge Prevention and Contingency Plan for the Birch Hill ~22-35 Extension Well. Also attached is the Application for Approval for an Oil Discharge Prevention mad Contingency Plan. The Birch Hill project has already received a conclusive consistency determination from the Department of Environmental Coordination under State I.D. Number AK 901101-0lA. Approval of the Contingency Plan is one of the conditions that must be met for the project to be consistent. Please fill out and return the verification of receipt form attached to the Plan. The Birch Hill Well is similar to ARCO's proposed Buffiehead #1 Well, the Birch Hill Contingency Plan is modeled after the Bufflehead Contingency Plan which has already received conditional ADEC approval. Copies of this Plan are also being sent to those individuals listed at the bottom of this letter. If you have any questions, or require additional information, please contact me at 265- 6459. Sincerely, William J. Ca'ether Permit Coordinator WJG:Is Enclosures w/enclosure J. Frates, Robert Heavilin Gary Liepitz Alison Smith R. Thompson KNWR-Soldotna Oil Spill Office, Kenai Braxmgh-Soldotna ADF&G (Habitat Division) Anchorage AI)GC-Anchorage w/o enclosure Kevin Fenner Lonnie Smith KPB-Soldotna AOCd2C-Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED A U6 2 7 1911! Alaska 0il & Gas Cons. Commissien Ancfl0rag0 AR3B-6003-C ~ STATE OF ALASKA /' ALAS OIL AND GAS CONSERVATION COM, SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging ~ Perforate [] Pull tubing [] Alter Casing [] Other I~ TEMPORARY ABANDONMENT 2. Name of Operator Chevren U,$,A.; inc. (ARCO Alaska. Inc. is sub-operator) 3. Address P.O. Box 5043~ 5an Ramon~ CA 94583-0943 4. Location of well at surface 1954' FWL, 1836' FNL, 5ec.25, TgN, R9W, SM At top of productive interval 1954' FWL, 1836' FNL, Sec.25, T9N, Rgw, SM At effective depth 1954' FWL, 1836' FNL, Sec.25, TgN, R9W, SM At total depth 1954' FWL, 1836' FNL, Seco25~ TgN~ Rgw~ SM 11. Present well condition summary Total depth: measured 15500'ND feet true vertical 15500'TVD feet 5. Datum elevation (DF or KB) RKB 228 ' 6. Unit or Property name Birch Hill Unit Feet 7. Well number 22-25 8. Approval number 9. APl number 50-- 133-10029-00 10. Pool Tyonek "D" Sands Plugs (measured) ClBP @ 8097' Effective depth: measured 8810'ND feet true vertical 8810 'T. VD feet Junk(measured) None Casing Length Size Conductor 220' 20" Surface 1989 ' 13-3/8" P roducti on 9006 ' 9-5/8" Liner 6609 ' 7" Cemented Measured depth 475 sx Class G 235 'MD 1985 sx Class G 2000'MD 1st stage 850 sx 9017'MD 2nd stage 1000 sx Class G 600 sx Class G 8891 '-15500'MD True Vertical depth 235 'TVD 2000 'TVD 9107 'TVD 8891 ' -15500 'TVD Perforation depth: measured 8190'-8220' (not open to production) true vertical 8190'-8220' (not open to production) Tubing (size, grade and measured depth) 2-7/8", 6.5#/ft, N-80 8rd ~ 8220', 2-3/8", 4.7#/ft, N-80 8rd ~ 2515' Packers and SSSV (type and measured depth) Brown HS-16-1 (~ 8118' :'iAY 0 0il & Gas Cons. C:~mmis$10a 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including vol~umes used and final pressure 13. N/A Prior to well operation SUbsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Well Summa,[y) Daily Report of Well Operations J[] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 ,. Title Associate Engineer Date (Dani) SW03/75 Submit in Duplicate BIRCH HILL UNIT 22-25 WELL SUMMARY (TEMPORARY ABANDONMENT) Began operations 2/25/88. Tested hanger seals to 3000 psi, ok. Tested tree to 4000 psi, ok. Pulled BPV. Ran GR to 8156' (plug). Tested tubing to 3000 psi. (Witnessed by Joe Russell, BLM). Freeze protected with 3 bbls- diesel. Worked through ice plug. Tagged PBTD at 8752' WLM. Pulled CEV. valve from GLM at 8065'. Circulated 50 bbls 9.0 pPg brine down the tubing, taking returns out annulus. SITP = O, SICP : 325 psi. Bled annulus to O' psi. SI 13-3/8" x 9-5/8" pressure = 400 psi. Secured well. Opened well~ Circulated and weighted up until 9.0 ppg returns were obtained. Circulated gas out. Observed well - well dead. Set dummy in GLM at 8065'. POH. Pressured annulus to 2500 psi with tubing open for 30 minutes, ok. (Test witnessed by Joe Russell, BLM). Set CIBP at 8097' Pressured tubing to 2500 psi, ok. (Witnessed by Joe Russell, BLM). Dressed tree with gauges- and close all valves. Reset "derrick" and wrap same with wire fence. Temporary abandonment of Birch Hill Unit 22-25 completed 3/7/88. GRU13/8 4/20/88 BIRCH HILL UNIT BHU ~22-25 REMEDIAL WORK AGREEMENT This Agreement entered into and made effective this 29th day of October, 1987, 'between ARCO Alaska, Inc. ("ARCO") and Chevron U.S.A. Inc. ("Chevron") , hereinafter referred to as the "Parties". W I TNE S SETH WHEREAS, ARCO and Chevron are the major working interest owners in the Birch Hill Unit ("BHU") and said Unit is operated by Chevron; and WHEREAS, certain remedial work is required to restore casing integrity in well BHU ~22-25; and WHEREAS, Chevron desires that ARCO act as its agent and perform such necessary operations as hereinafter provided; NOW, THEREFOR]~, in consideration of the above premises, the Parties hereby agree as follows: 1. ARCO shall employ and supervise the necessary labor and equipment to perform such operations on well BHU ~22-25 as authorized by AFE No. 499455 (Exhibit "A") and any other associated remedial operations des- cribed in and funded by subsequent AFE(s) approved by Chevron and ARCO. Such work is hereinafter referred to as "Remedial Work". 2. ARCO will invoice Chevron, in accordance with acceptable accounting practices, for 100% of the costs incurred by ARCO in the performance of the Remedial Work. Chevron will pay such invoices within 30 days of receipt. Chevron may then seek reimbursement for such costs, as BHU Operator, through the BHU Joint Account. 6om~tss'to~ Cons, A~Chorage 3. ARCO shall be entitled to reimbursement for overhead in the amount of 3% of the costs incurred in performance of the Remedial Work and Chevron hereby waives its right to attach any percentage overhead charge to the subsequent joint account billing as would be customary in accordance with the Accounting Procedures attached as Exhibit "2" to the Birch Hill Unit Operating Agreement. 4. For operations conducted by ARCO hereunder, the non- liability provisions of the Birch Hill Unit Operating Agreement (Section 15.3) shall apply to' ARCO as if it were Operator of the Birch Hill Unit, i.e., ARCO shall not be liable to any other party for anything done or omitted to be done by it in the conduct of operations hereunder except in case of bad faith. The Working Interest Owners shall be responsible for their working interest share of any damages,, claims, or liability coming out of the Remedial Work hereunder', except in the case of bad faith.' ARCO AL.A~K~, ~N~ Name: /4/D ~c~r~ ~/.~ CHEVRON U.S~ INC. /./,p,,' . Name: J. J. Ander$ Title: Assistant Secretary , STATE OF ALASKA ''~'~, ALASK~ OIL AND GAS CONSERVATION COMlV,,_$1ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend 5~. Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator /t~C~ Chevron U.S.A., Inc.(/'e~,/~ 3. Address P. 0. Box 5043, San Ramon· CA 94583 0943 4. Location of well at surface 1954' FWL, 1836' FNL, 5ec.25, T9N, R9W, SM At top of productive interval 1954' FWL, 1836' FNL, Sec.25, TgN, R9W, SM At effective 'depth 1954' FWL, 1836' FNL, 5ec.25, TgN, R9W, SM At total depth 1954' FWL, 1836' FNL, Sec.25, TgN, Rgw, SM 11. Present well condition summary Total depth: measured true Vertical 1 5500' MD feet 15500'TVD feet 5. Datum elevation (DF or KB) RKB 228 ' 6. Unit or Property name Birch Hill Unit 7. Well number 22-25 8. Permit number 9. APl number 50-- 10. Pool Plugs (measured) None 133-10029-00 Tyo,nek 'D' Sands feet Effective depth: measured true vertical Casing Length Conductor 220' Surface 1989' Production 9006' 881 0 ' MD feet feet 8810'TVD Size 20" 13-3/8" 9-5/8" Liner 6609' 7" Junk (measured) None Cemented Measured depth True Vertical depth measured Perforation depth: 475 sx Class G 235'MD 235'TVD 1985 sx Class G 2000'MD 2000'TVD 1st stage 850 sx 9017'MD 9017'TVD 2nd stage 1000 sx Class G 600 sx Class G 8891'-15,500' 8891'-15500' 8190'-8220' true vertical 8190'-8220, Tubing (size, grade and measured depth) ~j~ 2-7/8" 6.5#/ft N-80 8rd @ 8220', 2-3/8" 4 7#/ft N-80 8rd BOP sketch Packers and SSSV (type and measured depth) Brown H5-16-1 (~ 8118' 12.Attachments Description summary of proposal [] Detailed operations program 13. Estimated date for commencing operation February 8, 1988 (road work)· February 20¢ 14. If proposal was verbally approved Name of approver 1988 (well work) Date approved 15. I hereby certify that the forego, ing is true and correct to the best of my knowledge Signed ~~..~ ~,/~L,_ .c~[~.UI,_,/ Title Associ ate Engi ne, e,r Commission Use Only ( TJ 8 ) Date 5A3/58 Conditions of approval Approved by Notify commission so representative may witness I ApprovalNo. ~).._D,--~0 [] Plug integrity [] BOP Test [] Location clearanceI Approved Copy Returned _ ORIGINAL SIGNED BY ,='-'?-~-~~ by order of LONNIE C. SMITH Commissioner the commission Date~-'~ ~ Form 10-403 Rev 12-1-85 ,..~ ~ Submit in triplicate BIRCH HILL UNIT #22-25 DISCUSSION The Birch Hill Unit #22-25 was drilled and tested in 1965 by Chevron, U.S.A. as operator of the Birch Hill Unit. The well was completed (see attached schematic) with a 2-7/8" production string and a 2-3/8" circulating string to the Tyonek "D" sands. A post completion four point test indicated that the well has an absolute open flow potential of 17.5 MMCFD with a shut-in tubing pressure of 3000 psi+. The well was shut-in due to lack of market since completion. Chevron conducted bottomhole pressure surveys and tubing/casing integrity tests from .8/15/83 to 8/29/83. The well was left shut-in with tubing plug set at 8156' in the 2-7/8" production string below the packer. A back pressure valve was set in the tubing hanger at.surface. ARCO Alaska, Inc. acting as an agent for Chevron (operator of Birch Hill Unit) inspected the 22-25 site in September, 1987. The wellhead was noted as having 1080 psi on the production casing/circulating string, a tubing pressure of 390 psi and a surface casing pressure of 350 psi. A minor leak was also detected in a packing port on the wellhead. At the request of Chevron, AAI returned to the site on 10/29/87, pumped out the cellar and attempted without success to bleed off the. existing wellhead pressures. Based on this information, it is concluded that a leak has developed in the packer or tubing string enabling formation gas to pressure up the production casing and circulating string. SA3/58a 2/1/88 ~II_L WL=I_L AND SPOT cEMENT ACROS:~ PERFR 1. RU lubricator and pull Cosasco plug fron tbg hgr. 2. RU slickline. GIH with 2.25' guage ring to CA plug in D nipple @ 8156. Be prepared to pump methanol if ice plugs are encountered. 3. Pull CA plug from D nipple. 4. Pull CEV valve from Camco MM glm @ 8065. 5. Shoot fluid levels on 2-7/8' tbg and PC to determine the approximate amount of brine needed to fill well. 6. Ciro down 2-7/8' tbg with 9.0 ppg brine, taking returns'out PC. Hold back pressure with choke. Circ until have 9.0 ppg returns. 7. Open 2-3/8' heater string. Bleed off any trapped pressure and tim down 2-7~8' taking returns out heater string. 8. Observe well and ensure it is dead. 9. RU wireline. GIH with chemical cutter and cut off tl~ tail ~ 8130. (This is about 5' below the pkr - it will leave about 60' to the ~ perf from the new tbg tail,) Log cut to ensure tbg tail fell to bottom. 10. Run through tt~ bridge plug and set same @ :18320'. Dump 2 gallons 11. of glass shot on top of bddge plug platform. Close BP vent tube. RD wireline. RU coiled tbg. GIH with same and spot cement from BP to .~ 8160'. Do' not squeeze any cement into perfs. Attempt to bleed off 13-3/8" X 9-5/8" pressure. If it will not bleed off, bullhead 9.0 ppg bdne down annulus. (The volume to the 13-3/8" shoe is :1=125 bbls- if annulus dies before pumping 125 bbls, stop pumping. 12. 13. Repair leaking packing port on top spool. (It is open to the tbg X 9-5/8' annulus) 14. Test all packoffs. Attempt to repair any that do not test. 15. Secure well. Leave well so that pressures can be monitored on all strings. . +- ~So J ~. K CWLIMII q.., el ~.,...,..+./ zo. /~,~' N07~.' /. ,o,~oo/./¢7'/~,u 7'/,/~/,~G. /$ g,7/a" 4. 7 4; /¢. ~ GUI a~ .(4 4 · , . . . ! o. K g., e/¥,,./..+-/ otis "4" NiP. e&as POSITIO~I 1~! . $ ~, O. K C~LtAII ~SPO' Union Science & Technology Division Union Oil Compan'. California 37.6 S. Valencia Avenue P. O. Box 76, Brea, California 92621 Telephone (714) 528-7201 April 15, 1981 Mr. William Van Alen Petroleum Geologist State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Dear Bill: Please find enclosed 171 thin sections of cuttings and cores borrowed from the State's samPle library. Also enclosed are the materials left over from thin section preparation. A list of the prepared thin sections is given below: R 8103 SOCAL N. Trading Bay #23-27 R 8t04 ARCO Trading Bay St. #2 R 8105 Pan Am N. MGS 18745 #1-A R 8106 Pan Am N. MGS 18745 #2 ' R 8107 Pan Am MGS 18743 #1 R 8108 SOCAL Birch Hills 22-25 R 8109 Shell SRS St #1 R 8125 Halbouty Halaska King Oil #1 R 8126 SOCAL Ivan River 44-1 cuttings 11080-11730' cuttings 11320-11720' cuttings 13060-13490' cuttings 13660-13990' cuttings 10080-10710' cuttings 14220-14950' core 15495-15682' core 10731-11017.5' core 13771-13807' We thank you very much for allowing us to borrow this material for the preparation of petrographic thin sections. · AST:js cc: George Stadnicky, Anchorage Best regards, A. S. Trevena February 4, 1981 Mr. Ceorge Sta~mic~y Union Oil Cc~pany of California F. O. Box 6247 ~d]orage, Ala~ 99502 P~: Fret~rstion of Fetr ~ogra~ic %hin-gectio~m frc~ Samples and Cores in State ¥~cll Staple Libra~%,. Dear Ceorge: Pursuant-to'OUr Fcbruary 4, 1981 discussion on tt.~e captioned subject, permission~ is hereby granted to Lb/on Oil Cc~.~?any of California-to cut a ma3~mum of 1 cc. of s~mples ~]d cores frc~ the fo]loving wells .for the sole pur~mse of F,rc~aring thin- sections ~,~ithin ~'~e designated inter%~ls, m~.~ject to ~'~.c c~nd- itions set forth tel~: Sa~le Set t,~o. ~?el 1 Int~va 1 187 1~3 135 154 83 8~ 94 SCCAL N. Trac~cLng Day #23-7 ~!qCO IYading Bay St. #2 Pan £,~ N. [.~CS 1.8745 #i-A ~n ~ N. HCS 18745 ~2 S~C,~ ~irch Hills Unit # Shell S?~ St. #1 11,050'-11,670' 11,320'-11,720' 13,060'-13,480' 13,670'-13,990' 10,070 '-10,710 ' 14,250'-14,970' 15,495'-15,684' (core) Cu~s frcm the State's set of s~nples of the aboYm wells are to ke made only out of ~c~e individual s~.~[::le enw~loi.~;s or in ~hich the total volu~.e of s~le material is ~;reatcr then 10 cc. U~ion will ~c.vide the State v,ith a list of the si;mcific se~ple footages frc~ v,~id~ ~,~terial was ek~cracted. L~.ion shall t~ar all costs ent~niled and will i~ovide Alas}kn Oil and Cas Conservation Ccn,'~mission wi~ a ccg~lete set of all thin-sections Frepared. All t/~in-sections and al 1 sar. y. le residue materials are to be received, by the Commission by approximately May 5, 1981. L'o sar.,101e material is to t.~ re- tained by Union. [~nion Oi'l C~..' c~ C.. .foz~ia -2- All materials are to be transmitted directly to. the Canmission and are not to be examined by other Farties. We are pleased to work %~th you in this mutually beneficial endeavor and look forward tO your ca~'s consistant exercise of care and good judgement in the handling of this limited quantity of well material. I know that you, Art and I under- stand that the 'State's ~11 sample library is public property and that granting Union permission to extract portions of material frcm this library for the purpose of preparing the indicated thin-sections enhances the value of the library and iS in the p~blic intere~t. Very truly yours, William Van Alen Petroleum ~ologist cc~ Mr. Art Trevena Union O!li' ..C~ of California 'P. O..B0x 76 .~ Brea, California MEMORAIVOUM Thomas R. Marshall, Jr. Petroleum Supervisor Division of Mines &Minerals Stere oF Alaska · DEPARTMENT OF NATURAL RESOURCES Division of. Lands 344 Sixth Avenue Anchorate, Alaska, 99501 Erle Mathis, Minerals Officer OAT£: SUBIECT: March 1, 1966 Birch Hill Unit Area Transmitted herewith is a copy of an Application for Approval of Initial Participating Area for the Birch Hill Gas Pool #1., and the Geologioal and Engineering report pertaining thereto as submitted to the Director of the U. S. Geological Survey. AVS:ra cc: Mr. Phil R. Holdsworth, Commissioner Mr. James A..Williams, Director Division of Mines &Minerals it-~ E C EIVED O!'vIsION ('DF. ^A!NES & MINERA,.L,$ /:\ ['.,~ C Fi O R A G IE PRODUCING DEPARTMENT TELEPHONE: 2 72-~ 46 I C. V. CHATTERTON DISTRICT SUPERINTENDENT ., · P. O. BOX. 7-1B39 ANCHORAGE ALASKA 99501 · February 24, 1966 . · . Mr. Roscoe E'. Be]~.:-.Direc'tor Division of Land'S State of Alaska 344 Sixth'Avenue · Anchorage~ Alaska Dear Mr'. Bell: In accordance With Section 33(e) cf the Unit Agreement for the Development and'Operation of the Birch Hill Unit Area, we enclose herewith'~ i~ triplicate, an "Application for Approval of Initial ParticiPating Area for the Birch Hill. Gas Pool ~i, effective date June-t4~('1965~', a~d Geological and Engineering Report per- taining thereto. This aoplication'has"been sub~:~itted to the Supervisor, I~. W. J. Linton, for apprOvai of the Director of the U. S. Geological Survey, pur:s~ant to Section ~[ of the Unit Agreement. Very truly yours ~.,-~" , ,./'t ~--L.I. ......... C. V. Chat2er%on D~ ~ ~,~zc ~ Superintendent EnclosUres PRODUCING DEPARTMENT TELEPHONE: 279-846 ! C. V. CHATTERTON DISTRICT SUPERINTENDENT P. O. BOX 7-839 ANCHORAGE ALASKA 99501 Birch Hill Unit Area Kenai Peninsula State. of Alaska No. 14-08-,0001-8693 for of ParticlDating Area for the ~rch Hill The Director United States GeOlogical Survey Washington 25, D. C. STANDARD ~gIL C~MPAN~ OF CALIFORNIA~ as Unit Operator for the Birch Hill Unit Agreement, approve~ by the Director ef the United States Geological Survey, effective June 9, 1965, pursuant to the previsions of Section ll thereof, respectfully submits for the approval of said Director, the selection of the felling described lands to constitute the Initial Participating Area for the Birch Hill Gas Pool ~1, (hereinafter referred to as "Birch Hill Gas Pool ~l"), to-wit: (Note: Initial Partici.pa~,.t.~in~ ?r._e~ ,fpr ..B~rch ~Ei.,.Ll.__Gas~Pee! ~1. effective Lands constituting said area: --~._ - ............--J-~ · . .- _ -. - ~_ __~ ,, Descriptions conform to the map marked Exhibit "1" attached hereto.) T.. 9 .N.,. R..9 Section 23: Section 24: Section 25: Section ~: Section 36: Seward Meridian Total lands constituting said Initial Participating Area comprise 940.00 acres, more or lesg. In ~pport ef this apDlicatien, the following numbered irons are attached hereto and by this reference made a part hereof: 1. An ownership map marked Exhibit "1", showing thereon the boundary of the Unit Area and e.~e proposed Initial Partici~t~ Area. 2. A Schedule marked Exhibit "2", showing the land entitled to partici- pate in the unitized substances produced from the Birch Hill Gas Pool ~l, with the percentage of participation of each lease indicated thereon. Applicant is submitting separately, in triplicate, a geological and engineering report with an accompanying geologic map supporting and Justifying the proposed Initial Participating Area as herein described. The proposed Luitial Participating Area for Birch Hill Gas Pool ~l is predicated upon knowledge and information first obtained upon the completion in paying quantities under the terms of the Birch Hill Unit Agreement on June 14, 1965, of Unit Well ~22-25, located in the SE~NW~, of unsurveyed Section 25, Township 9 North, Range 9 West~ Seward Meridian. A four-point open flow potential test of Unit Well ~22-25 was conducted on June 14, 1965 from perforations 8,190' to 8,220' which resulted in an open flow potential of 17,500 MCF/D. During this test the well flowed dry gas at a stabilized rate of 6,240 MCF/D, through a 20/64" bean with a 2405 psia surface tubin~ pressure. The effective date of this initial area shall be June 14~ 1965, pursuant to Section ll of the Unit Agree- ment. Consequently, applicant respectfully requests that the Director approve the here- inabove selection of lands to constitute the Initial Birch Hill Gas Pool ~1, Participating Area, to be effective June 14, 1965. Dated this day of :. .~ ._.___.___, 1966 ST~dIDARD OIL COMPANY OF CALIFORNIA -'"'~"'~,. j / ,'~" -"' , ' , , .~/ C.V. C~t.~TON) District Superintendent IN RE: Birch Hill Unit Area Kenai Peninsula, Alaska No. 14-08-0001-8693 Geological and Engineering Report to Accompany Application for Approval of the Initial Participating Area for the Birch Hill Gas. Pool #1 ~E.~fe. ctiye.. Date:. J.u..ne 14~ 1965... The Director United States Geological Survey Washington 25, D. C. STANDARD OIL COMPANY OF CALIFORNIA, as Unit Operator under the Unit Agreement for the Birch Hill Unit Area, approved by the Director of the U.S.G.S, effective June 9, 1965 and pursuant to the provisions of Section 11 thereof, respectfully submits for approval of the Director it's Geolosical and Engineering Report for the Birch Hill Gas Pool #1. The Birch Hill Gas Pool #1 is a gas reservoir extending through a portion of Sections 23, 24, 25, 26 and 36, Township 9 North, Range 9 West, Seward Meridian. The gas accumulation is controlled by faulting on the western and southern flanks and by a gas-water contact on the northern and eastern flanks. Uell Birch Hill Unit #22-25, located in the SEk ~%, Section 25, Township 9 North, Range 9 West, Seward Meridian, was spudded on January 30, 1965 and pene- trated the pay sand from 8190' (-7,962') to 8,222' (-7,994'). The entire interval was gas productive with no gas-water contact present. Drilling con- tinued to a total depth of 15,500'. The well was then plugged back to 8,810' and completed through perforations from 8,190' to 8,220' with tubing set in a packer at 8,118'. A four-point open flow potential test run on June 14, 1965 resulted in an open flow potential of 17,500 MCF/D. During this test the well flowed dry gas at a stabilized rate of 6,240 MCF/D, through a 20/64" bean with 2405 psis surface tubing pressure. Production testing was continued until June 23, 1965, at which time the well was shut-in. The productive limits of the Birch Hill Gas Pool #1 are shown on the attached structure map (Exhibit A) with contours on top of the productive gas sand. Geophysical data and one field well (Birch Hill Unit #22-25) provide the trol for the structure map. Since tb£ entire pay sand was gas productive with- out an indicated gas-water contact an assumed contact was drawn parallel to structure contours in such a way as to outline an area of approximately 940 acres. This area is believed to be all that can reasonably be proved to be productive with the information now available. The proposed Initial Participating Area for the Birch Hill Gas Pool #1, as shown on the attached map, has been established by including therein those lands reasonably proved to be productive of gas in paying quantities, If any portion of an aliquot lO-acre subdivision was regarded as productive, (i.e., within the productive limits as defined above and shown on the attached map, Exhibit A) then such minimum subdivision was included within the Participating Area. Birch }{ill Unit Area Kenai Peninsula, Alaska Np. 14-08-001,8693... Page The effectiVe date .of the initial Participating Area for the Birch Hill Gas Pool ~;li as determined~nder the Unit Agreement, is established as June 14, 1965. Well Birch Hill Unit .~22-25, the first well capable of producing gas in paying quantities from the Birch Hiil Gas Pool #1, was completed on this date. After a thorough examination of available data, it is our opinion that the Birch Hill Gas Pool #1 is the only zone capable of economic oil or gas production with- in the above proposed Initial Participating Area. Dated this .... ~7 ~ day of January, 1966. STANDARD OIL COMPANY OF .CALIFORNIA BY: W. F.. WHITNey, JR. District Development & Reservoir Engineer, Alaska District Birch Hill Gas Pool ~1 Initial Participating Area, effective June 14, 1965. (Note: Descriptions conform to the map marked Exhibit "1" attached hereto. ) United States Oil and Gas Leases Lease Serial Number Lessees of Record: Working Interest Owners: Participating Acreage: Percent of Participation: Participating Land: ANOHOI~GE - 028].1.04 Standard Oil Company of California The Atlantic Refining Company Standard Oil C(anl:~n3r of ~liforni~ - ~{~j~ The Atlantic Refining Company .... -'- 530.00 56.383 T. 9 N.~ R. 9 W., S.M. (Unsurveyed) Sec. 25: ~_'_W-~', Sec. 26:,.~,.,...1~.=;~.~.~ Sec. 36: Lease Serial Number: Lessees of Record: Working Interest Owners: Participating Acreage: Percent of Participation: Participating Land: ANCHORAGE - 028407 Standard Oil Company of California The Atlantic Refining Company Standard Oil Company of California - ~0 The Atlantic Refining Cempany ..... 4oo.oo 42.553 Sec. 25: ~W~, w~ EXHIBIT-2 SCEEDULE -2- Lea~e Serial Numbers Lessees of Record: Working Interest Owners: Participating Acreage: Percent of Participation: Participating Land: A~CHORAGE- O28564 Union 0il Oompany of California Marathon Oil Company Union 0il Company of California - N~rathon Oil Company ............ 10.00 1.064 T..~..9.. N,? R. 9 W.,.. S.M. (Unsurveyed) Sec. 2B: SE~EI~E~-- TOTAL PARTICIPATING ACREAGE: 940.00 Forum P~7 - ~JBMIT IN DUP: ~,,~___.~ OF ALASKA OiL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: _ OIL ~] (;AS XVELL WELL ~ DRY L~ Other'__ b. TYPE OF COMPLETION: %VELL OVER EN BACK RESVR. Other NAME OF OPERATOR Standard Oil Co.mpany of California~ Western Operation's, Inc. ADDRESS OF OPERATOR P. O. Box 7-839, Anchorage, Aiaska 99501 LOCATION OF WELL (Re~or~, [ocatio~ e~e~r[~] (;~cZ i~ gccor~nce ~ c~ ~l~ate requirements)* At surface 1954' East and 1836' South from Northwest corner of 9W., .Seward B & M At total depth 14. PERMIT NO. { DATE ISSUED 'Jan. 18 E£i'ectlve: Jtay 1,('1~ ~ 5. LEASE DESIGNATION AND SERIAL'NO. · A-28407 6. IF INDIAN~ ALLOTTEE OR TRIBE NAME 7. UNIT AOREEMENT NAME Birch Hill 8. FARM OR LEASE NAME Birch Hill 9. WELL NO. 22-25 10. FIELD AND POOL, OR WILDCAT Wildcat' ' 11. SEC., T., a., M, OR BLOCK AND SURVEY OR AREA ~5-9N-9W-~.B. & M.' _ 12. BOROUGH · [ 13. STATE Kenai Penin.I Alaska Jan.30; !6 May 15, 1965 June 9, 1965 228' KB 214' 20. 24. TOTAL DEPTH, MD & TVD { 21. PLUG, BACI~ T.D., MD & ~JD 22. IF MULTIPLE COMPL., HOW MANY* 15,500 8810' ~ Sing le 23. INTERVALS DRILLED BY PRODUCINO INTERVAL(S), OF THIS COMPLETION--TOP, BOTTOM, NAME (MD AND TVD)* Four (4) ½" holes/foot 8190' - 8220' ROTARY TOOLS CABLE · TOOLS I ...... ... : · 95.WAS DIRECTIONAL SURVEY MADE Yes 26. TYPE ELECTRIC AND OTHER LOGS RUN I-ES, D.I.L., FDL, Microlog, Sonic, F.A.L., CDM, Mud-log 27, .WAS WELL CORED bio 28. CASINO SIZE 20" 13 3/8" 9 5/8" WE IGH T, . LB ./FT. 78.6q 61f~ and 68# 43.5# CASING RECORD (Report all strings set i~ weS) DEPTH SET ('MD) HOLE SIZE ' CEMENTING RECORD 216' ~'~-- ' 475 sacks . 2000' ~ ~8" I 1985 sacks 9017 12 1/4" '.I . 1850 sacks AMOUNT PULLED , 29. LINER RECORD -size TOP (MD) ROTTOM (MD) 1' 8891 15,500 SACKS CEMENT* 600 31. P~RFORATION RECORD (Interval, size aha number) 4- ½" holes/foot 8190' - 8220' (Open) DErT~'n~TERVAL (MD) 5: ~" holes at i4-,70~' (WSO)' Plugged." j889~' (Liner.. lap) 4 ~" holeS/foot 14,710' - 14;747 Plugge~ 4 ~' holes/foot 14,765' - 14,820 " 30. TUBING RECORD SCREEN (MD) SIZE DEPTH SET (I~iD) PACKER SET (MD) - 2 7/s,, z3; ' ' |-r- 2 7la" ~i ~H~at'ar strin~ ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. 33.* / PRODUCTION TE FIRST PRODUCTION [ PRODUCTION METHOD (~owinl~, ~ c~ ~ '. ] ' . . ~ May ~_~ ~965 FI'owing ............ DATE OF ~=ST } HouRs TESTED cache size I PROD'N. FOR TEST PERIOD 6- 14- cC,"- 1 16 / 64" ,, FLOW' TUI3~2q~'Z~:~M" [ CASINO PRESSURE CALCULATED l OIL----BRL'~ q -' /~ 24-HOUR 2~0 ,/ 0 , > 34. ma~osx~w~ o~ ~is (8old, used ]oryue~, v~nteg, ~tc.) - ~.. ................... . ...... ~, .aPed 35. LIST OF ATTACHMENTS AMOUNT AND KIND OF MATERIAL USED WATER--BBL.' .J OIL GRAVITY-API (CORR.) I TEST WITNESSED ,BY Mr. Vonder Ahe · InducCion EleCtrical log and mudlog transmitted by' Exploration Department' 36. I hereby certify that-the foregoing and' attached information is complete and correct as determined from. all available records ,..- / / ,,/~', ,/ /. // . , - . - · ,.,, .. , . / ...,,----.~_ffg::~l~.::. ~~ ' , . ~./ ,... /..,.--,,~ - .,~ ., . . . ..>,/ .....,... /.,. -~j-,, . /; , .. ........ A.,,~ ,.-.,¢,:~.. Si~NED .:~ m TITLE District. Superintendeo~ DATE ~ohr,,ary 1,q.: 1066 v~ CHATTERTON *(See Instructions and Spaces For Additional Data °n Reverse Side)" ' P. O. BOX 7-839 ANCHORAGE ALASKA 99.501 EXPLORATION DEPARTMENT ANCHORAGE DISTRICT R. I. LEVORSEN DISTRICT SUPERINTENDENT RECEIVED DIVISION OF Mt/'~ES & M~NERAI~ AN(~kIORAGE September 16, 1965 Standard Oil Company of California, Operator, Birch Hill Unit 22-25 Well Section 25, T-9-N, R-9-W, SM, Alaska; Nnd Log State of Alaska Department of Natural P~sources Petroleum Branch of Division of Nines & Ninerals 800 L Street Anchorage, Alaska Attention: Nr. T. R. N~rshall, Jr. Gentlemen: Enclosed are the following: 1. Nnd Log for the subject well from 215-15,500'; i folded sepia. 2. I folded blueline copy mud log from 215-15~500' for subject well. Yours very truly, R. I. Levorsen /~~-j~ ABS:sc Enclosure EXPLORATION DEPARTMENT ANCHORAGE DISTRIGT R. I. LEVORSEN DISTRICT SUPERINTENDENT P. O. BOX 7-839 ANCHORAGE ALASKA 99501 August 16, 1965 State of Alaska Division of ~nes & ~nerals 3001 Porc~ine Drive Amchorage~ Alaska Attention: Gentlemen: Hr. T. R. ~rshall, Jr. In accordance with the Oil & Gas Regulation ~200?.41c~.'the State of Alaska, ditch samples from the Standard Oil Co. of Califormta Birch Hill ~22-25 Well (Sec. 25~ T-9-N~ R-12-W, S.B & ~4. ) are hereby transmitted to the State of Alaska. Yours very truly, R. I. Levorsen ~=sc B~ceived by: .../~/~ ....................... .. P. O. BOX 7-839 ANCHORAGE ALASKA 9g 501 EXPLORATION DEPARTMENT ANCHORAGE DISTRICT R. I. LEVORSEN DISTRICT SUPERINTENDENT RECEIVED 965 AhlCHO~GE Augmst 6, 1965 STANI~ OIL COMPANY OF CALIFORNIA~ OPERATOR, BIRCN HILL UNIT 22-25 WELL~ SECTION 25, T-9-N~ R-9-W, S.N. FINAL IDGS State of Alaska Department of Natural Resources Petroleum Branch of Division of ~ines and ~inerals Anchorage, Alaska Attention: ~r. 'T. R. ~rshall, Jr. Gentlemen: Enclosed are the following: 1. Completion Report for the subject well. 2. One reverse sepia and one blueline copy of the Lithology Log from surface to total depth. 3. One reverse sepia and one blueline copy of the D~al Induction-Laterolog from surface to total depth. This completes the log information required on this well. D~tch samples will be delivered to the location designated by you. Please advise. Yours very truly, Levorsen ~ ~ A~BS: sc Enclosures COMPLETION REPORT - NEW WELL STANDARD_.. _OIL_C.OMPANY ..OF CALIF.O.,R, NIA . .WESTE.R.N.. OPERAT!O.NS IN.C, - OPERATOR ARENA: Kenai Peninsula, Swanson River Area, Alaska WELL NO~~h, Hill Un~ LOCATION: Surface: 1954' East and 1836' South from Northwest Corner - of Section 25, T. 9 N., R. 9 W., Seward B & M. ELEVATION: 228' K.B. K.B, is 15' above ground. DATE: June 22, 1965 LAND OFFICE: Anchorage Lease No.: A-028407 . BY: ,~... ........ . ,. ~, ~,- C. V, CHATTERTON, District Superintendent DRILLED BY: Coastal Drilling Company, Rig DATE COMMENCED DRILLING: January 30, 1965 DATE COMPLETED DRILLING: June 9, 1965 DATE OF OPEN FLOW POTENTIAL TEST: June 14~ 1965 Well shut in pending production facilities. TOTAL DEPTH: 15,500 '. JUNK: None PLUGS: 8810' - 8941' 14630' - 14860' 15496' - 15500' CAS ING: 20" cemented at 216' 13 3/8" cemented at 20001. 9 5/8" cemented at 9017'. 7" cemented at 15,500' top at 8891' Page 2 PERFORATIONS: 5 -'~" Jet holes at 14,705'. 4 - ~" Holes/foot 14,710' - 14,747'. 4 - ~" Holes/foot 14,765' - 14,820'. 4 - ~" Holes/foot 8190' - 8220'. WELL SURVEYS: 1. Schlumberger Dual Induction-Laterolog, interval 218' - 15,491'. 2. Schlumberger Induction Electrical Log, interval 9019' - 15,494'. 3. Schlumberger Proximity Log-Microlog, interval 2000' - 15,489'. 4. Schlumberger Compensated Formation Density Log, interval 2000' - 15,492'. 5. Schlumberger Sonic Log (Run #4 Borehole Compensated) 6. Schlumberger Formation Analysis Log 7. Schlumberger Continuous.Dipmeter 8. Schlumberger Cement Bond Log (in 9 5/8" casing)' 9. Schlumberger Cement Bond Log (in 7" liner) 10. Schlumberger Gamma. Ray-Neutron Collar Log 11. Exploration Logging, Daily Mud Log 217' - 15,494'. 9019' - 15,494'. 2000' - 15,'485'. 1900' 9020' 8500' - 15,481'. 7000' - 15,489'. 216' - 15,500'. FORMATION TESTS: HCT #1: WSO test at 14,705'. HCT #2: Production test 14,765' - 14,820'. HCT #3: Production test 14,710' - 14,747' and 14,765' - 14,820'. HCT #4: Production test 8190' - 8220'. COMPLETION REPORT Page 3 BIRCH HILL UNIT #22-25 Section 25, T. 9 N.., R. 9 W..,. Seward B_..& M. .... ' .~. STANDARD OIL COMPANY OF'"'CALIFORNIA, WESTERN OPERATIONS, Inc. OPERATOR .January 30, !965. Spudded at 11:45 A.M., January 30, 1965. Drilled 12~" hole to 218'. January ~1, 1965. 75-86 pcf mud. Opened hole t~ 26" to 216'. Conditioned hole. Ran and cemented 20", 78.6#, Grade "B", Buttweld seamless conductor at 216'. Casing equipped with Baker · Float Shoe and two centralizers on shoe joint. Cemented around shoe with 475 sacks of construction cement. Mixed cement in 25 minutes, displaced in 5 mins. with 28 cu. ft. water. Average slurry 118~. Full circulation. Good cement returns to the'surface. Used Halliburton equipment. Cut and recovered 14' 20" conductor. Welded on 20" landing flange. F..ebruary 1, 1965.. Welded on 20" series 600 Class III Blowout Preventors. Flanged up. February 2, 1965 Drilled mouse hole. Tested Shaffer Gate, Hydril Bag, 20" conductors Kelly Cock, Rotary hose, Stand pipe, fillup line and bleed lines. Ail OK. at 350 psi for 15 minutes. Made up 18 5/8" hole opener and 12%" pilot bit and drilled out cement and shoe and 6' from 216' - 222'. Laid down hole opener. Drilled 12~" hole to 232'. Exploration Logg~ng's Mud Logging unit commenced logging. F_ebru~ry 3, 1965. While drilling at 341', drill pipe became stuck. 'Worked pipe free, circulated and pulled out. Removed jets from bit and drilled ahead to 1127'. 74-81 pcf mud. February 4,. 1.9.6_5. Drilled 12~" hole to 2000'. CirCulated and conditioned hole. Ran Schlumberger Dual Induction-Laterolog 218' - 2000' and Sonic Log 217' - 2000'. Februa_ry 5 ~. ~11...965~, Ran 18 $/8" hole opener with 12~" pilot bit and opened hole to 1664'. 76-81 pcf mud. COMPLETION REPORT Page 4 BIRCH HILL UNIT #22-25 Section 25, T..9 N., .R- 9 W., Seward B & M 0I . COMPA CALI Om ZA, W ST . -OP r Tf6 'S,-Z c'. .... F~b_ruary ..6 & .7, 19_65. Opened hole to 18 5/8" to 2000'. Circulated and conditioned hole. Ran and cemented 13 3/8" casing as follows: CEMENTING ..DETA~IL Cemented 13 3/8" casing at 2000' in one stage around shoe with 1985 sacks cement using Halliburton and Alagco equipment. Mixed cement in 85 minutes. Displaced in 22 minutes with 1657 cu. ft, mud using.rig pumps, 'Mixed cement with 1440 cu. ft. water, average slurry ll5#/cu, ft. Bumped plug with 1700 psi. Full circulation and good cement returns to the surface. Cement in place at 4:30 A.M., 2/7/65. ~ookl~d.~e~ght before cementing 130,000# After cementing, before landing 127,000# At time of landing 120,000# at 12:15 P.M. 2/7/65. CASING DETAIL , 11 , ,, -- ~ __ K.B. to top of casing 19 joints 13 3/8", 68#, 8R, J-55, Rg. 3, Spang Seamless casing Cut and Recovered 31 joints 13 3/8", 61#, 8R, J-55, Rg. 3 Youngstown seamless casing including~ Baker Guide Shoe and Baker Flexiflow Float Collar K.B. O e_e~ 10.75' 723.00' 13.75' 709.25' 1280.00' Casing Landed At 2000.00' Removed BOPE. After cutting 20" conductor, noted that cement had dropped away in 13 3/8" X 20" annulus. Cement was 23' below cellar floor. Cemented annulus with 15 sacks cement, 1 sack sand, and gravel. Cut off 13 3/8" casing and welded on Shaffer 12" - 900 K.D. head with side outlets to sump. F..e..br.uary 8, 1965. Tested head with 3000 psi for 30 mins. - OK. Installed 12" - series 900, Class IV BOPE. ~ .F. eb.r. uary :9, !965. Tested all BOP equipment, Kelly Cock, Stand pipe, Kill lines and bleed line w/2500 psi - OK. ?e.bruar~ 10,__ 1~965. Made up drilling assembly and 12~" bit. Drilled out cement and shoe and drilled 12~" hole to 3455t. 71-79 pcf mud. COMJPLETION REPORT Page 5 BIRCH HILL UNIT #22-25 Section 25.,. T~.. 9 N_~'. R. 9 W._,_ Seward B & M STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, INC, - OPERATOR ~February_ 11, 1965~. Drilled 12~" hole to 4608'. Mud line to Kelly washed out. Repairing same. F_e~ruary 12 ~ ~I1~3,_ 1965. Drilled 12~" hOle to 5804'. ?jebrUary il4, 1._9.65. 79-81 pcf mud. Drilled 12k" hole to 5914'. Lost approximately 40 barrels mud. Regained full returns after one hour of drilling, Drilled ahead to 6067'. 81 pcf mud. Fe_.b_r_u. ary 15.-March 1, 1965. Drilled 12~" hole to 8902'. Had high gas kicks while drilling 8409' - 8455'. 80.5 - 85 pcf mud. ~arch 2, 1965. Drilled to 8927'. Pulled and found one wing missing from top driltrol. Drilled ahead to 9017'. 85 pcf mud. .~arch 3, 1965. Circulated and conditioned mud. Ran Schlumberger Dual Induction Latero/og, inter~al Sonic Log, interval Proximity Log-Microlog, interval Circulated and conditioned mud at 5264', 2000' - 9013' 2000' - 9009' 2000' - 9014' ~ar ch 4, 196_5. Ran to 9017' and conditioned mud. Ran continuous Dipmeter, interval Compensated Formation Density log, interval 2000' - 9012'. 2000' - 9014'. l!arch 5, !965. Ran 12%" bit to 9017' and conditioned hole for 9 5/8" casing. Ran 9 5/8" casing. COMPLETION REPORT Page 6 BIRCH HILL UNIT #22-25 ..Section 25.~ T~...9..N-, R. 9_J,f., Seward B & M STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, INC. - OPERATOR M~rch 6, 19~5. CEmeNTING DETAIL Cemented 9 5/8" casing at 9017' in two stages with 1850 sacks construction Shoe Stage Cemented with 850 sacks cement, treated with 0.5% HR-4 Retarder. Mixed cement in 27 minutes. Displaced in 55 mins. with 3752 cu. ft. mud. Used 578 cu. ft. mixing water, average slurry 116.5#. Preceded with 56 cu. ft. water. Used no bottom plug. Bumped top plug with 1500 psi. Full circulation. Cement in place at 5:40 A.M. 2nd Stage Cemented with 1000 sacks cement treated with 0.5% HR-4 through' ports at 7083' - 7085'. Circulated 55 minutes. Mixed 1000 sacks cement for 45 minutes. Displaced in 48 minutes with 2950 cu. ft. mud. Preceded with 56 cu. ft. water. Average Slurry 116#. Closed ports with 3000 psi. Cement in place at 9:13 A,M. _Npte: Lost circulation 8 min. before cement in place. Regained circulation after 3 minutes. Full circulation last 5 minutes. Used Halliburton equipment. Hooklpad W~ight before cementing After cementing before landing At time of landing CASING DETAIL 330,000#. 312,000#. 312,000#. ,, Oepth Above K.B. 65 joints 9 5/8", 43.5#, P-110, L8R, Rg. 2 74 joints 9 5/8", 43.5#, N-80, L8R, Rg. 2 37 joints 9 5/8", 43.5#, P-110, LSR, Rg. 2 DV Collar 48 joints 9 5/8", 43.5#, P-110, L8R, Rg 2 Casing Landed At -10.39' 2592.02' 2581.63' 3004.15' 5585.78' 1497.27' 7083.05' 2.00' 7085.05' 1931.95' 9017.00' 9017'. 00 ' Casing equipped with Halliburton Float Shoe, Halliburton Self-Fill Differential Collar and 18 centralizers. \, Removed BOPE and cut off 9 5/8" casing. Installed and tested secondary packoff to 3000 psi. OK. COMPLETION REPORT Page 7 BIRCH HILL UNIT #22-25 ~ection .25. T. 9,,N.~,, R.,,,9 W.,,,Se~ard B & M STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, INC. - OPERATOR march 7, 1965,. Installed Class IV BOPE and tested to 3800 psi for 15 minutes. OK. Ran to 6500' and tested Kelly Cock to 2500 psi. Ok. Laid down 44" drill pipe. Picked up 4~" rubbered Grade "G" drill~pipe. Tested pipe rams and Hydril w/2700 psi - OK.' Ran 8 5/8" bit and drilled out DV collar. Ran to top of float collar at 8973'. Tested w/2500 psi - OK. Drilled out cement and shoe. Drilled 8 5/8" hole to 9046'. 85 pcf mud. March 9-14~ 1.965. ' Drilled 8 5/8" hole to 10,051'. .M.a..r..ch' .15~ 1965. 85-87 pcf mud. Drilled 8 5/8" hole to 10,070'. Pipe tended to hydraulic up hole. Pulled pipe. Demonstrated partial swabbing effect. Broke circulation frequently to limit swabbing effect. Upon pulling found drill pipe protectors lost in hole. Ran back without replacing protectors. Conditioned mud in stages. Raised mud weight'to 90~ pcf. Drilled up protectors and drilled ahead to 10,176'. March, .1.6~ 1965. Drilled 8 5/8" hole to 10,252'. Installed new drill pipe protectors. M~_arch 17.-28. 1965. 89-91 pcf mud. Drilled 8 5/8" hole to 11,831'. On 3/19/65, pumped away 50 bbls water between 13 3/8" and 9 5/8" casing strings to check for disposal of sump water. Pressure built up to 1000#. Pumped away water at 600#. 91-95 pcf mud. .M. ar.ch 2.9, 1965. Drilled ahead to 11,832'. Circulated and conditioned mud. Ran Schlumberger Dual Inductlon-Laterolog, interval Ran Schlumberger Sonic Log, interval Ran Schlumberger Proximity log-Microlog, interval Ran Schlumberger Formation Analysis Log', interval 9017' - 11,832' 9018' - 11,832' 9018' - 11,832' 9019' - 11,806' ~a.rch ,3,0, 1.9,6,5. Circulated and conditioned mud. Ran Compensated Formation Density Log, Interval Ran Continuous Dipmeter, Interval Ran Cement Bond Log (inside 9 5/8" casing) Interval 9018' - 10,832' 9017' - 10,831' 1900' - 9020' COMPLETION REPORT Page 8 BIRCH HILL UNIT #22-25 Section 25.~. T. 9 N.~ R..9 W..~ Seward B & M STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, INC. - OPERATOR Ran 8 5/8" bit. Cleaned out fill 11,825' - 11,832'. Drilled 8 5/8" hole to 10,864'. 94 pcf mud. ~arc.h' L3.1 - April _13, 1965. P=iZl~d 8 ~$/8" holQ '~ 13,485'. 93-94 p¢~ m~d. ~pr~il 1.4.~ 1965. Drilled to 13,494'. Circulated and conditioned mud. Ran Proximity Log-Microlog, Interval Ran Dhal Induction-Laterolog, Interval Ran Sonic Log, Interval Ran Formation Analysis Log, Interval 11,838' - 13,490'. 11,836' - 13,488'. 11,838' - 13,476'. 11,806' - 13,487'. ~p. ril.l~.~ 1965. Circulated and conditiohed hole. Ran Compensated Formation Density Log, Interval Ran Continuous Dipmeter, Interval 11,834' - 13,487'. 10,200' - 13,485'. April 16., .19.65. Drilled 8 5/8" hole to 13,567'. Drilled on junk, believed to be pad off Schlumberger tool. 93 pcf mud. ~pril 17.~ 1965. Ran junk sub and drilled on junk'to 13,584'. ~pril 18 - 26, 1965. Drilled 8 5/8" hole to 14,434'. A.Pril. 27, 196.5. 93 pcf mud. 93-93.5 pcf mud. Lost approximately 50 bbls mud while drilling at ~t4,440'. Mixed lost circula- tion material and regained full circulation. Drilled ahead to 14,492'. 93 pcf mud. A.p. ri! 2.8 - May 3, 196..5,. Drilled 8 5/8" hole to 14,951'. Circulated and conditioned mud. 93 pcf mud. COMPLETION REPORT PAGE 9 BIRCH HILL UNIT #22-25 Section 25,~ T. 9 N., R. 9..W._, Seward B & M STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, INC. - OPERATOR Lost 1 cone and outer bearings off two cones off bit #82. Ran Dual Induction-Laterolog, Interval Ran Sonic Log, Interval Ran Compensated Formation Density Log, Interval Ran Formation Analysis log. Interval Ran bit and reamed 14,900' - 14,940'. 13,483' - 13,946' 13,476' - 14,950' 13,487' - 14,949' 13,487' - 14,947' May..5..,. 1965. Reamed to 14,945'. Circulated and conditioned mud. Ran Continuous Dipmeter, Interval Ran Proximity Log-Microlog, Interval 13,484' - 14,950' 13,487' - 14,947' Ran Bit and junk sub. Drilled on junk. Drilled 8 5/8" hole to 14,958'. 93 pcf mud. May ~.~ !965. Drilled to 14,974'. Recovered cone and some bearings. Drilled to 15,054'. 93 pcf mud. May 7 - 12~ 19.6.5. Drilled 8 5/8" hole to 15,495'. Circulated and conditioned mud. --May 13, 1965. Ran Induction Electrical Log, Interval Ran Dual Induction Laterolog, Interval Ran Sonic Log, interval Ran Proximity Log Failed. Ran Formation Analysis Log 92-93 pcf~mud. 9019' - 15,494' 14,946' ' 15,491' 14,950' - 15,494' 14,950' - 15,494' Conditioned mud. ~ Ran Compensated Formation Density Log' Ran Continuous Dipmeter Ran Proximity Log-Microlog 14,949' - 15,492' 14,950' - 15,485' 14,947' - 15,489' -May i.5~ ....1965. Ran 8 5/8" bit and drilled to 15,500' T.D. Circulated and conditioned mud. COP~LETION REPORT . Page 10 BIRCH HILL UNIT #22-25 Section....25..:, T. 9 N,, R.~ 9..W.~ ~ .Se.ward -B & M STANDARD OIL COMPANY OF CALIFORNIA, WESTErN'OPeRATIONS, INC. - OPERATOR ~ay !6, 196~5. Laid down approximately 6000' of 4~" drill pipe. Ran 6609' of 7" liner. CB __MENACING,,, ,DE..~AIL~ Cemented 7" liner around shoe with 600 sacks of cement, treated with 0.5% HR-4 Retarder. Mixed in 40 minutes, displaced in 62 minutes with 2080 cu. ft. mud. Used 402 cu. ft. mixing water. Average slurry 116#. Preceded with 56 cu. ft. water. Used no bottom plug. Bumped top plug with 2000 psi. Full ~irculation. Used Halliburton skid equipment. CASING DETAIL ,, Top of 7" liner at 8891' 41 joints 7", 26#, P-Il0, LSR (Including hanger & sleeve) 2060' Bottom 109 joints, 7", 29#, P-110, L8R (Including shoe & collar) 4549' Casing Landed At 15,500' Casing equipped with Brown Type V Float Shoe, and Brown Baffle collar at 15,412'. Brown "MC" Hanger at 8891'. May 17., .... 1965. __ Ran Halliburton 9 5/8" RTTS tool on 4~"~16.60# drill pipe and tagged 7" liner top at 8891'. Picked up and set tool at 8780'. Obtained breakdown on lap with mud at 2400 psi at 4 bbls/min, rate. Mixed and pumped 100 sacks construc- tion cement treated with 0.4% HR-4 Retarder. Preceded cement with 5 bbls water, and followed with 2 barrels water. Displaced cement with 128 bbls mud. Cleared tool w/4 bbls and used hesitation method last 2 bbls. Pressure built from our initial of 2200 psi to maximum of 4200 psi. Cement in place at 5:50 P.M. Reversed circulation.and pulled out. ~ay 18.~... 196~. Ran 8 5/8" bit and located top of cement at 8788'. Cleaned out cement to 8801' (top liner). Pulled and measured out of hole. 93 pcf mud ~ay ,19, 1965. ~, Ran 6" bit and drilled out cement inside 7" liner. Ran in and drilled out float collar at 15,453' and drilled out to 15,486'. Circulated and conditioned mud and pulled out. Exploration Logging released at midnight. 93 pcf mud. COMPLETION REPORT Page 11 BIRCH HILL UNIT #22-25 Section 25, T. 9. N,.~ R. 9 w., Se. ward B & M STANDARD OiL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, INC. - OPERATOR May 20, 1965. Ran Schlumberger Gamma-Ray Neutron Collar Log 7000' - 15,489' and Cement Bond Log 8500' - 15,481'. Jet perforated 5 - 4" holes at 14,705'. Ran TesC~, ~ay 21~.1965. HCT #1, WSO test on 5 - 4" jet holes at 14,705'. Tool assembly: 2 outside BT recorders, 5' of 2 7/8" perf'd tail pipe, 7" type "C" Hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorders, hydrospring teste= and dual closed in valve. Ran on 8010' of 4~" 16 60# and 6616' of 3~", 13 30~ 2 , · drill pipe. Used 6707' of water cushion. Set packer at 14,651' with 17" of tail to 14,668'. Opened tester at 8:50 P.M. for 5 min. pressure release. Very faint blow 2 mins., then dead. Shut in tester at 8:55 P.M. for 60 min. ISI pressure period. Opened tool to surface at 9:55 P.M. for 90 min. flow test. Opened tester for 60 min. -o~. Closed tester and surged perf's for 5 min. Re-opened tester for 30 min. - No blow. Shut in tool at 11:30 P.M.'for 30 min. FSI pressure. Pulled packer loose at 12 midnight. Pulled and recovered 210' fluid rise, all normal drilling fluid. Final Pressure Data: _ p~pth Gaug~ _IH ISI IF* . FF FSI FH Top inside 14,654' 9708~ 7251 3119 3249 3742 9656 Bottom inside 14,658' 9682 7231 3088 3223 3727 9623 Top outside 14,681' 9734 7282 3221 3352 3795 9664 Bottom outside 14,685' 9710 7252 3287 3297 3744 9653 *Field Pressures Conclusion: Some partial plugging during first ~0 min. flow. WSO at 14,705' - OK. Pulled tester. Ran 6" bit and circulated and conditioned mud. _May ~.22, & ~23, 1965. Ran Schlumberger gun out jet perforated interval 14,820' - 14,765' with 4 - ~" holes/foot. HCT #2, Production test on 4-~"H/F 14,765' - 14,820'. Tool Assembly: Same as ~~i. Ran on 8810' of 4~" and 6616' of 3~" drill pipe. Used 6707' of water cushion. Set packer at 14,651' with 17' of tail to 14,668. Opened tester at 2:15 P.M. for 5 min. pressure release. Weak blow 5 minutes. Shut in tester at 2:20 P.M. for 60 min. ISI pressure period. Opened tool to surface at 3:20 P.M. for 5 hr. 36 min. flow test. Closed in 3:50 - 3:56 when opened by-pass... Dead 3:20 - 3:59 weak blow 3:50 - 4:25, dead 4:25 - 9:00 PM. Shut CO~LETION REPORT BIRCH HILL UNIT ~j22-25 Page 12 Section 25~ T. 9 N.,_R.j_ 9.,..W., Seward B & M STANDARD OiL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, INC. - OPERATOR in tool at 9:00 P.M. for 60 min FSI pressure. Pulled packer loose at 10:00 P.M. Recovered 270' net rise, all drilling fluid. Final Pressure Data: Depth_Gauge _IH. ISI IF FF FSI FH Top inside 14,637' Bottom inside 14,641' Top outside ' 14,664~ Bottom outside 14,668' 9686 5303 3100 3222 3958 9544 9711 5338 3130 3248 3983 9569 9715 9356 3155 3283 4017 9594 9706 5327 3126 3248 3976 9572 Ran 6" bit and circulated and conditioned mud. Jet perforated with holes/foot 14,710' - 14,747'. ~.ay_24,.1965. _~_tlCT_f~t,_-Production test of perf'd intervals 14,710' - 14,747' and 14,765' - 14,820'. Tool Assembly: Same as test #1. Ran on 8810' of 4½" and 6616' of 3%" drill pipe. Used 6707' of water cushion. Set packer at 14,651' with 17' of tail to 14,668'. Opened tester at 6:50 A.M. for 5 min. pressure release. Good - medium blow. Shut in tester at 6:55 A.M. for 4 hrs. ISI pressure period. Opened tool to surface at 10:55 A.M. for 6 hrs. flow test. No Blow. Shut in'tool at 4:55 P.M. for 2 hrs. FSI pressure. Pulled packer loose at 6:55 P.M. Recovered 220' net rise all drilling fluid Final Pressure Data: ~ Depth Gauge_ IH IS___~I IF FF FSI ~ F~_. Top inside 14,637' Bottom inside 14,641' Top outside 14,664' Bottom outside 14,668' 9606 6565 3069/3147 3069/3158 4066 9514 9590 6553 3067/3139 3067/3147 4050 9502 9640 6613 3130/3202 3133/3211 4116 9537 9637 6594 3122/3167 3122/3175 4078 9544 Conclusion: Tight Zone ~ay 25, 196~. Ran open ended drill pipe to 14,963'.~ Circulated and conditioned mud. Spotted 10 bbls low PH pill at 14,963' Pulled to 14,860' and equalized 40 sacks cement. Preceded cement with '{0 bbls water, followed w/3 bbls water, and 161 bbls mud° Cement treated with 0.5% HR-4 Retarder. Estimated top of cement at 14,630'. Pulled to 9038' and spotted low PH gel pill. Pulled to 8941' and equalized 50 sacks cement. Cement treated with 0.3% HR-4 Retarder. Preceded cement with 8 bbls water and followed w/1 bbl water and 80 bbls mud. Pulled five stands and backscut~led. No cement. Laid down 3~" drill pipe. 92 pcf mud. CObfPLETION REPORT BIRCH HILL UNIT #22-25 Page 13 Section 25, T. 9 N. R. 9 W., Seward B & M STANDARD OIL COMPANY OF C~LIFORNIA, WESTERN OPERATIONS, INC. - OPERATO~ ~ 26 & 287 1965. Ran 8 5/8" bit and located top of cement at 8810'. Pulled to 8780' and ~f~ circulated and conditioned mud. Perforated 9 5/8" casing with 4 - ~j" jet holes/foot 8190' - 8220'. ~an tester.. HCT #4 Production test 4 - ~" JHPF 8190'~ 8220'. T~o~ assemb%~] ~--~ntsi~-~corders, 5' of 2 7/8" perf'd · tail pipe, '~C'~ ~yp~ Hookwall pa~k~r, VR safety joint, hydraulic jar~, ~ in~td~ BT recorders, hydrospring tester, 5/8" down hole bean and dual closed-in valve. Ran on 8132' of 4L" 16.60# DP. Used 460' of water cushion Set packer at 2 , ' 8158', with 17' of tail to 8175" Opened tester at 8:10 P.M. for 5 min. pressure release. Strong blow of air for 5 min. Shut in tester at 8:15 P.M. for 90 min. ISI pressure period. Opened tool to surface at 9:45 P.M. for 38~ hour flow test. Shut in tool at 12:00 Noon 5/28/65 for 120 min FSI pressure. Gas to surface immediately. Turned to flare. Water cushion an~ rat hole ~nd put flare out. Re-lit flare and well produced slugs of water cushion and rat hole mud next 20 min. then cleaned up. After next 10 min. condensate appeared with the gas and flow rate stabilized. Produced thru %" SFC positive choke, 2700 psi tubing pressure (Field calculation rate = 3710 M/D) after well had been open 2 hrs. 45 min. ~" orifice. (field to surface - put thru flow prover. Observed 72 psi thru ~ calculation rate = 3860 M/D). Attempted to flow well thru %" surface positive choke, observed stabilized pressure of 2300 psi (field calculation rate = ~,~40__0 M/D)_sur_face shut-in pressure 3100 psi. 1/8" surface positive choke observed tubing pressure 3050 psi. Final Pressure Data: ~ept.h GBuge IH ~ ISI IF FF _FSI Top inside 8143 Bottom inside 8147 Top outside 8170 Bottom outside 8175 *Field pressures 5261 3845 1388/1196 989/3277 3728* - 5249 3836 1420/1197 1017/3227 3718' 5274* 5265 3839 1582/1294 1105/3258 3747* - 5278 3850 1592/1306 1127/3240 3683~ 5253 Recovered 135' net rise, including 130' muddy water with scum of distillate and 5' of sand. Water tested 35 G/G Na CL. May 29,~ 1965. Ran 8 5/8" bit to 8810'. Circulated and conditioned mud. Reduced mud weight to 80 pcf. Hauled in tubing to location. ~ay 30% 1,965. Hauled tubing. Made up Baker Model "C" Retrievable Bridge plug. Ran in and set a~ 8000'. Tested to 1500 psi - 5 min., OK. Hauled tubing. COMPLETION REPORT BIRCH HILL UNiT 22-25 Page 14 ~.ection ~5., T.. 9 N..,.R. 9 W., Seward B & M STANDARD OiL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, INC. - OPERATOR ~June 1~..196~. Hauled tubing, laid down 4~" drill pipe. June 2, 1965. Picked up 'and ran 2 7/8" :ubing. 'Tubing stopped at 7435' Pulled tubing. R~n Retrieving tool and located bridge plug at 7435'. (P{ug formerly set at 8000') (NOTE: Either did not get completely off of bridge plug when initially set or relatched on to same when laying down drill pipe, and inadvertently pulled and set bridge plug up hole at 7435'). ,June 3~ 1965. Released bridge plug and reset same at 8000'. Circulated at 7962'. June 4 &_ 5.~ !96~5. 80 pcf mud. Circulated at 7962' and pumped sump. ~une 6, 1965. " Removed BOPE and installed tubing head. Reinstalled BOPE and tested w/2500# - OK. Ran 2 7/8" tubing and Baker Model "H" retrieving tool. Attempted to work plug at 8000' loose.~ ~ ~une 7., 1965. Worked bridge plug loose and retrieved same. Conditioned mud at 8532'. 1965. Ran 2 7/8" production tubing as follows: TUBING DETAIL K.B. to landing flange Pup joint 3 joints 2 7/8", 6.5#, N-80 8R Rg. 2 tubing Otis "S" Nipple in pos. #2 61 joints 2 7/8" tubing as above Otis "S" Nipple in pos. #1 191 joints 2 7/8" tubing as above Camco bR~ Mandrel Assembly 1 joint 2 7/8" tubing as above Brown CC Safety joint."J" slot type 2 7/8" pup joint ~Brown 2 7/8" X 9 5/8" HS-16-~ packer 1 joint 2 7/8" tubing as above~-~, Camco D NipPle 2 joints 2 7/8" tubing as above Venturi Shoe Tubing Landed' at 14.40' 2.67' 95.45' 1.60' 1927.04' 1.59' 6022.17' 13.09' 28.93' 2.87' 7.90 6.97 31.02 0.93 62.32 .67 8219.62 K.,B. Dep t_h 17.07 112.52 114.12 2041.16 2042.75 8064.92 8078.01 8106.94 8109.81 8117.71 8124.68 8155.70 8156.63 8218.95 8219.62 COMPLETION REPORT BIRCH HILL UNiT f~22-25 Page 15 Section 25, T. 9 N., R. 9 W., Seward B & M STANDARD OiL COMPANY OF CALIFORNIA~ WESTERN OPERATIONS, INC. - OPERATOR HEATER STRING K.B. to landing flange Landing flange 3 joints 2 3/8", 4,7~, N-80~ 8R, gg. 2 ~nbin~ Otis "S" Nipple in pos. #1 76 joints 2 3/8" tubing as above 1 joint 2 3/8" tubing turned to 1 5/8" Heater String landed at Removed BOPE and instalied and tested x-mas tree. K.B. DEPTH 14.40 .67 15.07 94.14 109.21 1.53 110.74 2370.51 2481.25 31.17 2512.42 2512.42 June 9, 1965. Tested x-mas tree to 5000 psi. - Ok. Displaced dOwn annulus with fresh water. Well would not flow. Pumped in additional 100 bbls water, and well started flowing. Ran wireline and set packer. Flowed well. Shut in at 5:00 P.M. Laid down flare line. Rig released at 12:00 midnight, 6/9/65. ~u.qe ~14, 196.5. Ran Open Flow Potential test. Flowed dry gas at following rates: Rate Bean Size Tubing Press_ure_ 1. 3420 MCF/D 16/64" 2630 psi 2. 5950 MCF/D 20/64" 2390 psi 3. 11150 MCF/D 32/64" 1630 psi 4. 13240 MCF/D 45/64" 1089 psi SRH:cap S. R. HANSEN ', State of Alaska Department of Natural Resources DIVISION OF MINES AND MINERALS Petroleum Branch INDIVIDUAL WELL RECORD Operator .Standard Oi.,,.1..Co. of Ca.l. ifkocation Lease No. A-028407 or Owner Birch Hill Unit Release Date: 7-14-67 Sec. T. R. 25 9N 9W Meridian Permit No 65-1 Issued 1-20-65 (Surface) 3q0o' w ~ 1980' ~. of SW cot: sec- 25 Loc. (Bottom) Well No. 22-25 Area Spud Date 1-30-65 Drilling ceased 6-9-65 Total Depth 15~,5Q9 _ ,, Suspended Abandoned Elevation . 215' K.B ...... Completed (F-GL-P) 6-14-65 IP B/D, Grav .565 API, Cut % G as _ 3400 MCF/D, Be an Casing: Size Depth Sx 16/64, CP psi, Cmt Perf:5%__@ 14~05 W.S.O. TP 2700 psi Plugs: 14860'-14630' 40 sx. 20".. 216' 13 3/8" 2000' 475 *_4-%,'hD f. 14765-1~820' 1985 * 14747 '-14710' 8941' -_8810' 50 sx. 9 5/8" , 9,017: 155oo' 1850 100 @ ' gbp?: 600 (a shoe 8190' -8220' GEOLOGIC FORMATIONS Surface Lowest Tested Name PRODUCTIVE HORIZONS Depths Contents * Nonproductive Year Jan Feb Mar Apr May June WELL STATUS Test of perf. 8190'-8220': BEAN. TEMP. 16 -520F... 20 -38°F ~? _.-9 °.F 45 +23~F July Aug Sept Oct Nov Dec - ~ : ~ : - ,, , ", ' "~ : '~' ' I '"'--" ' , , Ti Po .2640 psi,.. 2390 psi. I ~0 p.~i. 1075 psi. 64 +34~F 600 psi. 14,500 Remark s: Contractor~ Coastal Drillin~ Company. Ri~ No. 5 UNITED STATES DEPARTMENT OF' THE INTERIOR GEOLOGICAL. SURVEY Budget Bureau N0. 42-R36616~ ~ Approval 0xplres 12--81-~0. Anchorage LAND OFFICE .................................. ~E NUMBER .......................... -------~-- ; Birch Hill Unie UNIT ............................................ LESSEE'S MONTHLY REPORT OF OPERATIONS ,State .... _ _A_ .1..a_ ~...k_.a_ ~ ................ Co~n,~y Kenai' 2rield Wildcat T~e foZlowi~ is a eorree~ report of opera~io~s a~d prod~e~io~ (ir~e~di~ drilli~ a~d prod~ei~ wells) for tke mo~tk of .............. JD.O~ ..................... , 19~._, ............................................................................ Jge~' s address _.~ .... Q .... ~..l~ ................ : ..................Company Anchorage, Alaska .~ , i ~ '~"'~ ~ ' ~o~ ...~3_~_r}Ag_l_ .............................................................. ~'~ a a~ _.~_%~.%~A.!~.ia~.~.5~3.5~. ...... SrO. ANO { I BAR1L~L8 OF OIL GRATITY GASOLIN:E WATER (H (If drmlnz, depth: If shut do ...... ~ Or ~ TW~. ~N~ W~ Da~s O~. F~. Or GAS GALLONS or BA~a~ og It ARK8 Ho. PaoovomD (~ ~0~) da~ ~d r~ult of t~t for s~l~o . ~ ,, , CONFIDENTIA~ - t:XPL('~TOR~ WELL , Birch Eill ~nit 22-25 Removed ]~OPE ~.nd installed tubin~ head. Ran 2 7/8" 25-TgN-Rgw producCi,)n tu~.ing. Shoe at 8220 , Packer at 8118'. SE~ Ran 2 3/~" Hel,ter String to 2512 . Removed BOPE and ~ installe,i and tested x-~s tree. Displaced down ~ annulus ~ith ~resh water. Fl~e~ well. Set packer. Rig televised June 14, 1965 Ran open flow potential ~est. Flied ~d;y gal at following ratel : Ra :e Bean Size , Tubing Pressure 2. 5950~ MCF/I 20/64" 2390 psi 3. 11150 MCF/i 32/64" 1630 psi 4. ~32~0 ~CF/Z -' 45/64" ~089 psi ~( I'~,.. ANCHORAGE' NoT~.--There were ...................................... rum or sales of oil; ............................................. M cu. ft. of gas sold; ............................................ runs or sales of gasoline during the month. (Write "no" where applicable.) NoT~,.--Repor~ on this form is required for each c~lendar month, regardless of tho status of operations, and must be filed in duplicate with the supervisor by the 6th of the suoceeding month, unless otherwise directed by the supervisor. (laauary 19lO) l~-.~r,?6e"~ U.S. eOVa##ma#? eallCtl#e OFFICe FLOW TEST STANDARD OIL CO. OF CALIFORNIA WELL BIRCH HILL 22'25, KENAI PENINSULA June 14, 1965 When arrived at well location well was flowing gas through 16/64 bean from perforations 8190' to 8220.' Four 1/2" holes per ft. Pressure bomb hanging 8190'. 12:28 p.m. On 16/64 bean T.P. 2640 psi, -52°F-~/5/ofv~,300 MCF- 12:54 p.m. Changed to 20/64' bean (T.P. 2400 psi). 1:35 p.m. Pulled pressu~:e bomb up to 4100'. 1:35 p.m. 20/64 bean, T.P. 239D ps~ -38°F~'~ 5,950 MCF 2:20 p.m. Changed to 32/64" bean. (T.P. 208~0. psi) 3:10 p.m. 32/64 bean T.P. 1630 psi -2~F .... -~~.' 11,150 MCF' 3:13 p.m. Opened with 45/64 bean. (T.P. 1160. psi). 3:29 p.m. 45/64 bean. T.P' 1075 psi. +23°F-~':'~};~: i3,240 MCF 3:53 p.m. Opened with 1" bean. (F.P. 650 psi) 4:02 p.m. 1" bean. T.P. 600 psi +34°F-~. ;~<~o?s',' 14,500 MCF Gravity of gas - .565 The flow rates shown were calculated after the pressures appeared to be stabilized following change of beans. Test witnessed by: UNITED STATES Approval explr~ 12-31-~0, ~ F/ ~, ' GEOLOGICAL SURVEY um .... .~.~b..~.[[..~[~. ....... 'LESSEE'S MONTHLY REPORT OF OPERATIO S DIVISION OF Mir',4L~5 & M[NERALg , , , ANCHORAGE ......... ............ .................. ........ ................................... ~e follo~ ~ a correot repor~ of operatio~ a~ prod~tio~ (i~ol~din~ dfflli~d a~d prod~n~ well~) for t~e mont~ oF ........................... ~ .......... ,1~_~_, ........... .............. .... . ....... ......... Anchorage, Alaska 99~01 - -' .......... 'J'"/'; ~'~, -' ~' ' ....... So. FT. Or OAI GALLOlqS Or BARBBL0 Or REMARKS · SEC. AND TWF. R~NOB WBLL D&U BABRIBL9 OF O~ ORA~Y ~lIO~l WATBB (~ (U ~, d~: if shut d~n, ~ O~ ~ NO. M (~ th~) RB~VBBBD none, ~ l~te) ~u ad ~t a ~ f~ e~t ~ m) ) '., CO ~1DE~ ~T~ 2~ T9N a9W ~ Drilled 8 5/8" hole to 1~,9~1'. fan logs, Drilled ~o S~ ' ' Ran logo. Drt led to 15,500', to'~al deptt. Ran 160 Joints ~ .. 7" line~ to 1~ 500*. To~ at 8891'. ~._ lt.ner cemented atom shoe vith 600 rocks. Sqteezed li:~er lap ~,ith 100 sacks. F: ' pressure 12~ ~si. Clea~ed out c,~ment to 15,486'. Ran ~ Ray-Neut=vn Co'.[lar lo8 a~d Cement' Bond lot. ~et perforated . 5-~" holes at L4,705'. tan HCT ~L. Reco~'ered 210' drillinl ' fluid. WSO - )K. Jet p~rforated with ~-~;" holes/foot 1~76~ :-. 14820'.. lan Ht:T ~2. Opined test,~r for 5 hrs. 36 mins. . . period. Recow~red 270* i rilli~ ~luid. ~'et perforated viii ', , , ~-~" holeis/ioo:: 14747 ~ -11710~. R~m HCT ~,. Opened tool · ' 6 hour fl~ pe::iod. Recovered 2~I)~ drilltnE fluid. ~n op~ ~ ' ' ~ . ended drilI pil)e and equtlized 10 sacks c~ment at 11860~. Esti~ted top ~f cement ~t 14630~ Pullei to 89~1~ and eqm . tzed 50 sacks :e~nt. Lccated 'to~ of cement at 8810', Jet . · . performtei 9 5,~8'' casing ~ith i-~* holes/t'oot' 8190'-8220'. . ; . Ran HCT ~. S**t packer ~t 8158' '~ened C0ol to surface .. ~ to sur/ac~ ~,~diat}ly. Flied v.~ll clem,. Fl~ed 3~00 -- . .at 2700 p~i tul,ing pressure thr~,~h ~" be~ n. Fl~ed veil · -: '. 38~ h~rs, ~::led testex and con, litioned md, ~; Prepari~ to c(~plete well. ' ~ - .~ . U. 5. Fish & ~:.ldlife Se~vi~e - ~ A. Tro~er (1) C. ~. Perry (1', R. R. RitCer Files - P. coduc:,ng, Explo~a~ion, Liind ,, , , , ,, , , , , ,, , , , , Lnal NoTs.--There were runs or sales of off; ....................................... ~. M ou. ft. of I~s sold; runs or sales of gasoline dmdng the month. (W~ "no" where sppli~ble.) Norn.--Report on this form is required for e~oh emlendsr month, regsrdlem of tho .tmtns of operetlons, snd must bo filed in duplieste with tho supervtm~ by tho Otb. of tho mtoooodtuf month, unlem otherwise direoted by tho Sulmrvioor, Gao Form approved. Budget Bureau No. 42-R1424. U'-'-N}r--~' STATES (Other Instruction' \re* DEPARTME[ OF THE INTERIOR ,eras side) GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug hack to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) OIL ~'~ GAS WELL WELL [--] OTHER Exploratory HAME OF OPERATOR Standard 0il Company.. of California, W.0.X. ADDRESS OF OPERATOR P. O. Box ?-839~ Anchorage, Alaska LOCATION"OF WELL (Re~rt location clearly gnd in accordance with any 8ta~ requiremen~.* ~ also space 17 below.) At surfa~ X95~* Ease and 1836' South from HorChwesc corner of Section 25, T. 9 H., R. 9 ~., S.B.~. 14. PERMIT NO. 16. 15. EU~VATIONS (Show whether DF, ET, OR, et~.) 213.6' Gr. Check Appropriate Box To Indicate Nature of Notice, Repo., or Other §, LEAHE DESIGNATION AND SERIAL NO. A-028607 :: ': ~' ,-.- 8. FAR~t Oa LEASE'NAME*; .'~; ~' '~ ~ '~ .,, ~.. _. , . 10. FI~LD:A~D PO~, OR WIL~AT ./.. ..... .. Ke~i' ~B'0 ro~h~J ,,/Alaska . NOTICE OF II~q~NTION TO: TEST WATER SHUT-OFF [ [ PULL OR ALTER CASINO FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON~ REPAIR WELL CHANGE PLANS SuEsmi~UmNT R!FO_R~' Ob': -? := -., SHOOTING On ACIDIZING ~ ~ ,~ABA~DOaM~{!' ? I I (Other) I I (NOTE: Report results ~f 'm~ilfl~lE eSmple{don :bR. Well (Other) ~lU8 back completion or ReeompR~lon ~rfand ~qfo~'m.):': ~ _ · 1~, DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all perttneut details, and give pertinent dates, ~eludi~' OtJmated"date ~f~ktartlnf any proposed work. I~ well is di~ction~y drill~, give subs~e I~tions and meamtred and true vertical., dept~., ~1. ma~ke~._ ~d~ne~rti-,~ nent ~ this work.) * ~g ~a ~ m Re. Notice cE intention to change plans, dated Hay 19, 1965. 1. Cemented 7" liner at 15,500', top at 8891'. 2. Obtained breakd~ on lap and squeezed with 100 sacks c~en~. 3. Cleaned out to 15,689' 4. ~ressure tested cas~ Co 3000 pst. 0K. 5. Ran Cement Bond Los and Gamma Ray-Neutron Collar Log. 6, Tested WSO at 14,705'. OK. ~ II ~ I 7. Per~oraCed v/ i ~ holes/foot 1~,710 1~,7~7 and 1~,765 and r~ productiOn tests. Ho hydrocarbons. 1. B~dge .~th cement 14,860'-1~,e30' and 89~0-8800 2. Will~rocee~o test .the inte~al 8220-8190...-- r ....... ~ District Su erintendent (This space for F~er~ or S~te o~ CONDITIONS OF ~PROVA~ ~ ~'1 *See Instructions' on Revere Side jUN ]]965 Df'VI,SION OF Mll'.ii~S & MINERALS ., ANCHORAGE · Form 9-331 (May 1963) t~'~X-TED STATES SUBMIT (Other instru¢ DEPARTI~ ~T OF THE INTERIOR verse side) GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use '*APPLICATION FOR PERMIT--" for such proposals.) O'~.WE~,. [--] O,Sw,~.~. []] O~,ER ~.xploratory NAMB OF OPERATOR Standard Oil Company of California, Western 0perations~ Xnc, ADDRESS OF OPRRATOR P. O. Box 7-839, Anchorage, Alaska 99501 LOCATION OF WELL (Report lo~atlon clearl-y and in accordance with any State ;~uirements.° See also space iT below.) At surface 1954' East and..!8360 South from Northwest Corner of Section 25. T. 9 N., R 9 W., SB&H Form approved. Budget Bureau No. 42--R1424. §. bEABE DESIONATION AND SERIAL '.~ A-028407, ..-: 14. PERMIT NO. [[ 15. ELLWATIOlqS (Show w_hethmr DF, liT, SE, Cie,) · ./i ---. :':;.:-.-:'.- --' ..... 213.6 Gr. 6. IF INDIAN, ALLOTTEE ~R.,~uLnm NAIdB , ?, UNIT'AGREEMENT NAME · ..* · f · BirCh Hill. ' 8, FIRSt OR IT, EASE .NAME" -' . 9. WIlL NO;' . 22-25 . .... ~tldc~t~ 8UBVB~ OR ~BA - . ~ .L 12. COU~TI OB PARISH[ 18,:,STATE Kenat .: ;~ Peninsula : 1 :'A~ s~ Ched~ Appropriate Box To Indicate Nature of Notice, Repoa, or Other Dora ..... .- -- TLC'.0 ...... : ..- _ -- - · . ~. ~ ' ~., : '' ,' J ',' , (Other) ' [ [ ~]~tio~'~r R~ompl~lon R~'~d ~S fo~) [: _. 17. ~Escamm ~no~osE~ aa co~m,m~m9 o~ma,~s Cie, .ly state nil pertinent details, and si~e pertinent da~s, ~elu~ln~['~i~ated' dat~ ~..s~rtin~ I dri~ ~ iv, su~e l~tions and measur~ and tm, rertlca~dept~ propos~ work. If w~l b dl~on~ y ' g a ~ c ~ ~ ~ ~ :,, ~[ ,,', :4 ' neet ~ ~is wor~) * - ' ~ ~ ~ :: ~ :~ ~, :-' -: ~ T.~ 9 5/8"cemented at 9017 · Drilled Depth: 15,500 · Propose: -- ~a~~ ' ' 1. Run i6600' o[ 7" liner to 15,~00~. [i, ji~ a,a. ':' ": · -- 2 Cement around shoe with 600 sacks ce~nt. ;:: :: ,. 2' :;'-:~ ;-' "' 3 Obtain breakdown of lap and squeeze vi~h es~iu~ed 100 sfck8 ~nS~r~c~l'0n cement. e 4. C~mn out to top of ce~nt inside liner st ear.ted 15,~00". 5 Pressure test lap to 3000 psi "'"-- 6 Run Ce~nt Bond and..-Oa~':RaY Neutron CoXla~ logs, ..... ?. obtain Wso at 14,705~. 8 Test Silected intervals between 14,820'-14,709' & 8230' 9 Complete or abandon as indicated, _. CONDITIONS ~'~F'/PPB0¥&L~ IF ANY: " '-----".. ' :: .. ':~-. ......*See Inslmeflon6 on Reverse Side = _ . -- - .,.,. ~ District Superintendent ' :VA~':'-: N~Y-~!9~ ..... :;!965 C' " ".' .'\ ~.,.-. ~', ..Il . , .. ,~ C' "~ UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY · LESSEE'S MONTHLY REPORT OF OPERATIONS State .... 4~a~s.~ .................. ~o~nty ....... .~..~..~..d._9.a..t._ ............. '. Field ........... g~R[_~r$.~pr~ ........ ' Tke /ollo~n~ is a eorreo~ report of operations and production (ineludi~d drillin~ and produced wells) for tke month of .................. .b~.~.~ ............. ,19..~.~., ............... Corn any ~eatern ~rat ~,~_~/lnc, , ............................... ............................... ,,,, ..... tho,, ................ .~.L.~.:P39.L ............................................... -' ':" -'"'c , , Or. Ft. ov OAs GALLONS OV BA~RBLO or REMARK8 ...... T~ ~ -~x~o~-,~o~Y ~ Drilled 8 5t8" hole 1: ,027~-13s493~. Ran logs. Drilled 8 S rS", hole t~ 1~,717'. Drillt~ ah.~ad. RECE!VFD AK CHO~eA~E USgs~'~ ~. J. Liat~n (2) State . ~. R. ~r~hall (1) C. ~. Perry (1) Files - Pro,]ucing gxp'Loration NoTB.--Thero were ' runs or sales of oil; ............................................ M ou. ft. of pa sold; ........................................... runs or sales of pzoUne during the month. (Write "no" where &pplioable.) NoTB.--Report on this form is required for e~oh eslendar month, regardlen of the ststus of operations, and must be filed in duplieate with tho lupervisor by tho 6th o! tho auooeedin~ month, unless otherwise direoted by the supervisor. . , ..: Form 9-331 U N~'~ED STATES DEPART/~~ OF THE INTERIOR '~/~'~'e~ld~';~trnc? ~,n re- ---GEOLOGICAL SURVEY (May 1963~ SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for quch proposals.) 01~ WELYo [~ GAS w,LL [--i OT.E~ Exploratory 2. NAMB OF OPERA~0R , Stand~rd Ofl C~pany of Cal~fornf~ ~st~rn Op~rat~on,~ Inc. ADDRE88 O~ OP~RA~OR P. _0, Box 7-839 Anchorage~ Alaska 99501 4. Loc~w~ o~ wg~b (Report location clearly and In accordance with any 8tote requires,hts.* See also space 17 below.) At surface 1954' East and 1836' South ~romNorthaas~ Corner Section 25, TgN, R9W, Seward Bbii 15. ELEVATIONS (Show whether DF, RT, OR, eta.) 213.6 OR 14. PEBMI~ NO, !6. Form approved. Budget Bureau No. 42-R142~. 028~7 I~DIAN~. ALLOTTBB OR T~IBB ~AMB 7. UNIT AOIIEE,%IMNT NAMB,. Birch HiII 8. FARM OR I,I~ASE NAME Birch Hill 9. WELL NO.' #22-25' 10. FIIOLD A,.~D Pooro OR WII, D(~AT ~ildcat ~ lB0. ~,, B. M,, 0it BLK. AND 25, TON', ROW, SB&M 12. COUNTY OR PARIfIHI 18, STATE Zenai I I Pentn~nla I .Alaska Check p~ppropriate Box To Indicate Nature of Notice, Report, or Other Data ' NOTICE OF INTENTION- . TEST WATER SHUT'OFF F_i_---] PULI~ OR ALTER CASINO F_F_F_~_~-- FRACTURE TREAT t~l 8H~T OR ACIDIZ, ]--I ABANDON* ~o~or) [niece vast, ~aCer be~een SUBSEQUENT REPORT OF: WATER SHUT-OFIF ~ / REPAIRINO WmLI, FRACTURE TREATMENT ALTI~RING CASINO. ~HOOTING OR ACIDIZINO ABANDONM~NT~ (Other) (cNoT~.: Report. results of multiple' completion 'on Well (,mptctlon or ~ecompletlon Report and Log. for.m2). : ......... DESCRIBE PROI'OSED OR COMPI.ETED OPERATIONS (Cleltrly state nil l.,rtlnvnt details, and giro pertinent dates, including' estialated date of starting any proposed work. If well is directionaily drilled, give subsurface locations and my. outed and true vertical depths for fill marker~ and zones perti- nent to this work.) * · .. . (Per telephone conversations Linton-Wunnicke-Whitney 3-22-65) ," ,,- Propose inject waste water from subject well drilling operations into'. 13 3/8 X 9 5/8 casing annulus. 13 3/8" casing cemented to surface ' ': at 2000' 9 5/8" casing cemented in two (2) stages shoe at 9017' "' second stage at 7085'. Estimate top second stage 3500' - 4000*. ". ' , , (Top cement will be located with cement bond log prior to injection). .., Injection will be into sands between 2000' and top of 9 5/8" : ' annulus cement. All sands exposed to injection are indicated to non hydrocarbon bearing and below any future fresh water sources Present surface road conditions preclude use of. vacuum trucks or other surface' transp0r-~[/~"-meth0ds to dispose of wasteWater. ,;R -[-C · TITLR District Superintendent *See Instructions on Reverse Side E,:IVfD i965 DIVISION Oi: ~fl',,IES & MINERALS · .- UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY ~rT~ Budget Bureau No. 42-R~LL Approval expfre~ 12-31~0. LESSEE'$ MONTHLY REPORT OF OPERATIONS The followind is a correot report of operations and production (invl~dind drillini[ and prod~oin~ wells) for the month of ............. ~l~ent's address ........ _P~ .._ .. _0..._ _ .~ .o.,...7..-..8..3..9. .............. .............................................................................................. ,, Anchorage, Alaska 99.501 8tdned ........ ~.....~;-.~2~-~'~RTON.~. .... ~. ......... Phone ................. BR..'/.-__fzZ01 .............................................. /l~ent' s title D.Ls~.rir=t~..~tper. tnl:endenl: ........ BEc. INO B&RRETA OF OIL ORkVlTY OASOLINB WATEK (If (If drflllnL des)th: if shut down. ~ Or ~/ TWF. RAt(OB WELL DAu OU. FT. Or OAS OALLOt(S Or ~ARRKLO or REMARK8 No. raoDuono (In thousnndn) RECOVBuBD none, so state) dsm mad result d , . , . ,. CONFID, ,:NTIA! ~ st 25 T9N Rgb' . 1~; Drillel 12%" hole 8,/18 -901,/~. Ran 10~s. . Ran an l cemented 9 5]8' casing at 9017' in two sC. tges ~ith 850 sa:ks arou~td shoe and 1000 sacks :ement through Df at 7081 ~. Installed m.d tested B)PE. Dr: l~ed 8 hole t,I 11,~ 32'. Ran togs. D:'illed 8 i hole ~. 12,(~27'. Drilli',~ ah~ ad. ~ DISTR] BOTI0 U.$.G.$. -~. H. Soysler (2) ~b&t. ate- T. .~. Narshall (1) U.S. l~t. sh a~d ~/ildlif~ Service -~. A. ~royer (1) C. ~. Perry (1) R. It. ~titce : (1) , Files ~ Pr)ducing Ex )loration,=. ............. , ...... NoTn.--Them were ...................................... runs or sales of oil; M ou. ft. of gas sold; runs or sales of p~oline during the month. (Write "no" where spplieable.) NoT~.--Report on this form is required for e~eh e~lendar month, regardless of the st~ttm of operations, and must be ~ed in duplicate with tho supervisor by.the 6th of tho suoceedin~ month, unless otherwise direoted by tho supervisor, (3~mum'y IM)) I~--nStO04 w.o. ~v~nm~v ~mvm* ot~0o, UNITED STATES DEPARTMENT OF THE INTERIOk GEOLOGICAL SURVEY Approval expires ~.~ o,.c~ .._~.n_.c.k°.?__g_~ ............. U.,T ..... .s..!.r.~b...8~.l..1...~.n..:i,~.: ..... LESSEE'S MONTHLY REPORT OF OPERATIONS State ......... A1..a..s..k..a._ ............ ~o~,nty .................................... Field .................. ~_$.l..d..c..a..t. .................................. Tl~e following is a correct report of operations and prod~otio~ (i~eludi~g drilling a~d prod~cind wells) for tke montk of .............. ~~.~ ............ ,19.~., ...................... ~$~DJ~X~._.0_~_~._.QO.,_,...~...~O.~_~, ~Ee~t's address r.O. Box 7-839 ................................................................. ~a. ~-,' E'~'.';~ Pl~o~ .................................. }_8...~_t.{.~9.~. ............................. ~'~ ~ -~~l~l--~}~In~e~en~ ....... Szc. AXD W~ D~ Bl~a O~ Om O~%rrv Co. F~. or Oie OA~[O~S Or Btaas~ ov 'REMARKS" ~ or ~ ~W~. ~NGB ~0. Pnoeeon~ (~ thO~) OAsorm~ WA~E~ (H (If d~ll~, d~th; ff shut down, ~BCOVBRRD none, 80 S~) ~M ~d muir of t~t for f~lho ~nMt of ~) . CONFI',)E~L - I XPLO~TO~Y WELL . s~k'{ i ." · . ' 0rill,~d 12%" h.o]e 218'-2,)00'. .. Ran D~lal Induct~on-ElecC~ical Lo~ and Sonic Log. . ' ·" 3pene,i hole to ]~8 5/8" f~com 218' to 2000', ' ' Cement:ed 13 3/8" casi~ ~C 2000' ~ith 1985 .sacks ,- [ .: cement'. Installed and t ~sted BOI'E. { ' Drill ~d 12~" hole 2000'-~718*. . ! Drill Lng ahead. . . ' ~.. ~ .... ~ISIR [B~IIO~'~ . 't · Irate-~' R. ~rshall - 1 . . . ] . ' .:.. ~. S. Fish & ~ildlife - ~. I. Tr~,yer - 1 "' '- " C.W. Perry - 1 ., .' , ', ~ R~R. Ritcer- 1 I . ' . . · Files '~oduci~g ~, ~ c- ~, · . . . Explorat ion ~ , 'z: ?' c / "[ i .... '. DIVtSIOiN q)t .',',, , : .... t,:, .., ,~ a/,,i,~;~/tl.S I Ah CHO~Gf ....... ,, ., ., NoTm.--There were ...................................... runs or sales of oil; ............................................. Mou. ft. of gas sold; ...................... [ ...................... runs or sales of gasoline during the month.' (Write "no" where applioable.) l~IoT~.--l~eport on this f6rm is required {or each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the 8ueeeedin~ month, unless otherwise direoted by the supervisor. Forth 9-829 , (January 1~) 14---~74~4 u.s. eOVl~#l~ ~,~l#/J#e et,Fill ,/ Budget Bureau Approval UNITED STATES ~ o~,c~. DEPARTMENT OF THE INTERIOR . e~ GEOLOGICAL SURVEY UmT .... ~c~--H~ LESSEE'S MONTHLY REPORT OF OPmRATI©m Sgate .......... ~Las ~ ............... Cou, gty .................................... m,-, foHowi~ ~s a correct report of operations and prod~ctio~ (i~cl~di~ driHi~ and prod~ci~ .weZ~s) for ~e ~o~h o/ ..... ~~ ....................... , WesCe~ Ope~ac~ons~ Inc. · . ,, ~. O. Box 7-~39 ............................. I RANGE ~ ~EC. AND TWP. NO. Pacco;om, 2~ TgN Rgw ~JARIIEL8 OF OIL CONFi S, Drill Ran D] U,S, File GRAVITY ! 'flY' ,~:" "" "',~.'" I GASOLINE I WATZR DENTIJAL - EX?LODATO~Y WELL UNIT q/22- ~.5 30, "hole to :ed 20" landin Mr. M. H. T. R. Ma Wildlife (1) L965 36" conduc 218' amc opened at 216' flange ion :or se~ aC 31'. :o 26" to 216'. iwith 475i sacks cement. Soyster (2) Service~- Mr. Wi~tard Troyer (i) "" '- C AN No~g.--There wer~ ......................................runs or sales of oil; ............................................. M cu. ft. of gas sold; ............................................... runs or sales of gasoline during ~he month. (Write "no" where applicable.) Nc.r~:.--l~eport 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, u~e~ otherw~e directed by the supervisor. Jaauar~ 20~ 1965 so~ - Ol~raror truly Thorns R. Karslmll~ Jr. ~leum Geologist FORM ~A-IB 95M. 3J64 MEMORANDUM State of Alaska TO: J-- FROM: DATE : SUBJECT: 3ammxT 20~ 1965 ,ge~eell location Birch Rfll gn.tt ~22-25 ~; r- . . · Birch Rtl! gnlt ~22-25 a~d a check J~or the £tli~g fee J~ the amount o~ ~50.00. ~t~ch. 2 Form SA /"~"~" iIISIIfO. RANDUM To: I-- THomas R. Marshall, Jr Petrol. cum Geologist FROM: Norris C. Bakk~, Jr Minerals Officer DATE: SUBJECT: / Proposed Birch Hill Unit & ~ Contraction of the East Umiat Unit. The enclosed application for Designation of Unit Area and Depth of Test' Well for the proposed Birch Hill Unit area and information relating to the proposed Contraction of East Umiat Unit area is submitted for your information and files. Copies of each decision will be greatly appreciated. ars. RECEIVED JAN J-u 19~5b DIVISION O~ MINES & MiNEP, AL~ ANCHORAGE APPLICATION FOR PERMIT TO DRILL, DEEPEN OR SLUG BACK II~ · APPLICATION TO DIIILLiJ~ DEEPEN 0 PLUO BAO~ 0 Petroleum , O~on of Mines . Standard Oil Company of California, ~estern 0pera. tions~ lac. January Address . . ,', City ~ ' State P, 0. Box 7-839 AnchoraEe~. Alaska ' DESCRIPTION OF WELL AND LEAS~ , ,,. , , ., , ,. , N~me of lease ................ J ~Vell number J Elevatlo~ ~~~,l.,.~c,i_'1 022-25I 200' 3300' N'& 1980' ~ast off SouCh~es~ Co~ner of Section 25~ ~. g N.~ R. FJelfl ~ reservoir (If wildcat, .o state) I County WildcatI Kenai PeninsUla , - ....... Distance, In miles, and direction ~rom nearest to~ or ~ost o~lee Ap~roxim~tely"21 miles North of Stt~li~, Alaska Nearest distance from ~roposed location Distance from ~ro~osed location to nearest drilling, to property or Isaac line: eom~ieteQ or m~plied--~or w~ll on the same 660 feet , First Well feet Proposed depth; [ Ro~ or cable tools [ Approx. date work will start i~,800'i...]. ..... Ro~a~[ February 1, 1965... Number of acres in I~se: Humber of wells on lease, including this well, comDleted in or dNiling to this r~ervolr: 2560 - - ' . , ,, ' , ,, ,, If lease, purchased with one or more Name Addr~s wells drilled, from whom purchase: ,, Status of bond ~one Reauired Remarks: (If ~his. is an application to deepen or plug back, b~fl~ d~cflbe work 'to be done, ~vlng present p~aucmg zone and ex, coted new ~roduoing ~. . . ; CERTIFICATE: l, the undersigned, state that I am thp o! the (company), and that I am authorized by said company to make this report; and that this report was pre° · pared trader my supervision and direction and that the fac~ ~;at~ therei~n ar~.h~ue;~corregt and complete to ..... ,4_ ' · . Sl~rec, V. C TTERTON- Dist. Supt. Als. Dist, 65-1 Permit Number: Petroleum Geologist Notice: Before sending in this form be sure that you have given all information requested. Much unnecessary correspond- ence will thus be avoided. See Instruction on Reverse Side of Form Alaska Oil and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form Ho. P-1 Authorized by Order No. 1 Effective October 1, 1958