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Home My WebLink About186-0101. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops ______Other: Suspended Well Inspection_ Development Exploratory 3. Address: Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6562 feet 3206 feet true vertical 6536 feet feet Effective Depth measured 3206 feet NA feet true vertical 3180 feet NA feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) N/A Packers and SSSV (type, measured and true vertical depth) N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:None 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: Josh Allely N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 josh.allely@hilcorp.com 907-777-8505 N/A measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 0 Size 97' 0 00 0 00 0 measured TVD 13-3/8" 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 186-010 50-283-20079-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA029656 Beluga River / Sterling-Beluga Gas Beluga Riv Unit 211-03 Plugs Junk measured Length Production Liner 3,140' 6,003' Casing Structural 3,115' 5,977' 3,140' 6,003' 97'Conductor Surface Intermediate 30" 20" 97' 433' 2,910psi 3,810psi 5,970psi 6,330psi 433' 433' Burst Collapse p k ft t Fra O s______O 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:14 pm, May 24, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.05.24 12:50:19 - 08'00' Noel Nocas (4361) KEN June 2020 Suspended Well Inspection Data Well: Beluga Riv Unit 211-03 Surface Location: 204' FNL, 158' FEL, Sec 4, T12N, R10W, SM, AK Permit to Drill: 186-010 API: 50-283-20079-00-00 Inspection Date: 4/27/23 AOGCC Inspector: NA Waived by Jim Regg Size Pressure (psi) Tubing NA NA Casing 9 5/8 0 OA 13 3/8 0 Other Notes: Condition of Wellhead: Tree is removed. Good condition, no leaks, valves operable. Cellar clean with light snow. Condition of Surrounding Surface Location: Clean, with snow. Follow Up Actions needed: None Attachments: Current Well Schematic Picture(s) Plat - 1/4mile radius of wellbore _____________________________________________________________________________________ Updated By: JLL 05/05/22 SCHEMATIC Beluga River Unit Well: BRU 211-03 PTD: 186-010 API: 50-283-20079-00 CASING DETAIL Size Type WT Grade Conn ID Top Btm 30" Conductor 310# K-55 Buttress 28" Surf 97' 20" Surface 133# H-40 Buttress 18.73" Surf 433' 13-3/8" Intermediate 68# S-95 Buttress 12.415" Surf 3,140' 9-5/8" Production 47# & 43.5# N-80 Buttress 8.681" Surf 6,003' TUBING DETAIL 2-7/8"Prod. Short String 6.5# N-80 EUE 8rd 2.441" 3,251 3,297' 2-7/8"Prod. Long String 6.5# N-80 EUE 8rd 2.441" 3,243 4,478 JEWELRY DETAIL Long String ID. Depth MD (ft.) Length (ft.) ID (in.) OD (in.)Description 3,241 9-5/8 CIBP w/ 35 cmt (3,206 TOC) 3 3,253 1.4 2.44 3.4 Baker 'CC' Safety Jt, right turn release 4 3,254 3.2 2.31 3.8 Otis 'XA' Sliding Sleeve 5 3,257 7.09 2.44 8.3 Baker 'HB' Dual Packer, 40k release 6 3,257 - - - WRP Plug topped by Cement Plug 8 3,656 3.19 2.31 3.7 Otis 'XA' Sliding Sleeve 9 3,659 8.51 2.44 8.3 Baker 'HB' Packer 11 4,044 1.06 2.31 3.7 Otis 'X' Nipple 12 4,045 3.17 2.31 3.7 Otis 'XA' Sliding Sleeve 13 4,048 8.51 2.44 8.3 Baker 'HB' Packer 15 4,466 1.05 2.31 3.7 Otis 'X' Nipple 16 4,467 3.17 2.31 3.7 Otis 'XA' Sliding Sleeve 17 4,470 8.51 2.44 8.3 Baker 'HB' Packer 18 4,992 - 2.44 - EZSV sqz w/ 50sx below 19 5,620 - 2.44 - Howco EZSV sqz w/ 50sx below 30 9-5/8 RKB to MSL = 103 RKB to GL = 16.1 TMD = 6,562 TVD = 6,536 PBMD = 4,992 PBTVD = 4,965 Max Angle = 12.7 deg @ 1,600 20 13-3/8 9-5/8 TOC @ 3,168 CBL 3/19/86 STRLNG A B C 1&2 E F1 B C F2 F3 F4 5 9 13 11 12 F1 17 18 19 3 4 H G F2 F2 6 BELUGA D D 8 15 16 Jet Cut Tubing @ 3,251 (SS) 3,243 (LS) 3,241 9-5/8 CIBP w/ 35 cmt cap - 4/25/22 3,265 2-7/8 CIBP(SS) Planned Whipstock for 2022 Sidetrack @ ± 3,185 Short String ID. Description Depth MD Length ID OD CIBP 3,265 B Baker Stab-in Stinger 3257' 0.67' 2.5" 3.375'' C Otis 'XN' Nipple 3295' 1.05' 2.205'' 3.668'' Fish ID. Description Depth MD Length ID OD F1 2.875" Weatherford WRP 4,045' - 2.875" F2 Otis 'XN' Nipple 4,732' 1.05' 2.2'' 3.67'' F3 2-7/8" Blast Joints 4,733' 246.25 2.44'' 3.68'' F4 Baker Shear Sub 4,980' .75' 2.44'' 3.67'' _____________________________________________________________________________________ Updated By: JLL 05/05/22 SCHEMATIC Beluga River Unit Well: BRU 211-03 PTD: 186-010 API: 50-283-20079-00 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Phase Date Status STRLNG A 3305' 3325' 3,280' 3,300' 20' 8 2 04/26/22 Isolated STRLNG B 3363' 3412' 3,338' 3,387' 49' 8 2 04/26/22 Isolated STRLNG C 3536' 3580' 3,511' 3,554' 26' 4 0 04/26/22 Isolated STRLNG C 3614' 3640' 3,588' 3,614' 26' 8 2 04/26/22 Isolated BELUGA D 3682' 3876' 3,656' 3,850' 51' 8 2 04/26/22 Isolated BELUGA E 4092' 4211' 4,066' 4,185' 21' 8 2 04/26/22 Isolated BELUGA F 4378' 4402' 4,376' 4,376' 14' 8 2 04/26/22 Isolated BELUGA F 4512' 4725' 4,486' 4,699' 31' 8 1 04/26/22 Isolated BELUGA G 5040' 5060' 5,014' 5,034' - 1 0 3/2/1986 Sqz & Plug BELUGA H 5675' 5745' 5,649' 5,719' - 0.5 0 3/2/1986 Sqz & Plug BRU 211-03 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): N/A GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 159' FNL, 179' FWL, Sec 3, T12N, R10W, SM, AK 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- 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 (ft MSL) 22.Logs Obtained: N/A 23. BOTTOM 30" K-55 97 20" H-40 433 13-3/8" S-95 3,115 9-5/8" N-80 5,977 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 Beluga River / Sterling-Beluga Gas N/A Oil-Bbl: Water-Bbl: Oil-Bbl: 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 Flow Tubing Gas-Oil Ratio:Choke Size:Water-Bbl: PRODUCTION TEST 4/5/1986 Date of Test: Per 20 AAC 25.283 (i)(2) attach electronic information 68# 6,003 Surf Surf 310# 133# 97 Surf 3,140 CASING WT. PER FT.GRADE 47# / 43.5# N/A 315839.3 TOP SETTING DEPTH MD Surf Surf TOP Surf Surf 315501.3 2619714.4 3/13/1986 CEMENTING RECORDSETTING DEPTH TVD 2619748.8 2/20/1986 6,562 / 6,536 3,206 / 3,180 HOLE SIZE AMOUNT PULLED 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 4/27/2022 186-010 / 322-119 50-283-20079-00-00 Beluga Riv Unit 211-03 FEDA029656 204' FNL, 158' FEL, Sec 4, T12N, R10W, SM, AK STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas BOTTOM N/A SIZE DEPTH SET (MD) PACKER SET (MD/TVD) TUBING RECORD Surf 433 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, Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment RECEIVED by James Brooks at 1:21 pm, 9/1/2022 Suspended 4/27/2022 JSB RBDMS JSB 091522 xGSFD 11/8/2022 Beluga Riv Unit 211-03 DSR-9/16/22 186-010 / 322-119 Suspended WCB 4/21/2023 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A Top of Productive Interval 31. List of Attachments: Well Operations Summary / Wellbore Schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Dan Marlowe Contact Name: Jake Flora Operations Manager Contact Email:Jake.Flora@hilcorp.com Authorized Contact Phone: (907) 777-8442 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: 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. 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: 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: Signature w/Date: 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 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: 2022.09.01 12:53:27 -08'00' Dan Marlowe (1267) _____________________________________________________________________________________ Updated By: JLL 05/05/22 SCHEMATIC Beluga River Unit Well: BRU 211-03 PTD: 186-010 API: 50-283-20079-00 CASING DETAIL Size Type WT Grade Conn ID Top Btm 30" Conductor 310# K-55 Buttress 28" Surf 97' 20" Surface 133# H-40 Buttress 18.73" Surf 433' 13-3/8" Intermediate 68# S-95 Buttress 12.415" Surf 3,140' 9-5/8" Production 47# & 43.5# N-80 Buttress 8.681" Surf 6,003' TUBING DETAIL 2-7/8"Prod. Short String 6.5# N-80 EUE 8rd 2.441" 3,251’ 3,297' 2-7/8"Prod. Long String 6.5# N-80 EUE 8rd 2.441" 3,243’ 4,478’ JEWELRY DETAIL Long String ID. Depth MD (ft.) Length (ft.) ID (in.) OD (in.)Description 3,241’ 9-5/8” CIBP w/ 35’ cmt (3,206’ TOC) 3 3,253 1.4 2.44 3.4 Baker 'CC' Safety Jt, right turn release 4 3,254 3.2 2.31 3.8 Otis 'XA' Sliding Sleeve 5 3,257 7.09 2.44 8.3 Baker 'HB' Dual Packer, 40k release 6 3,257 - - - WRP Plug topped by Cement Plug 8 3,656 3.19 2.31 3.7 Otis 'XA' Sliding Sleeve 9 3,659 8.51 2.44 8.3 Baker 'HB' Packer 11 4,044 1.06 2.31 3.7 Otis 'X' Nipple 12 4,045 3.17 2.31 3.7 Otis 'XA' Sliding Sleeve 13 4,048 8.51 2.44 8.3 Baker 'HB' Packer 15 4,466 1.05 2.31 3.7 Otis 'X' Nipple 16 4,467 3.17 2.31 3.7 Otis 'XA' Sliding Sleeve 17 4,470 8.51 2.44 8.3 Baker 'HB' Packer 18 4,992 - 2.44 - EZSV sqz w/ 50sx below 19 5,620 - 2.44 - Howco EZSV sqz w/ 50sx below 30” 9-5/8” RKB to MSL = 103’ RKB to GL = 16.1’ TMD = 6,562’ TVD = 6,536’ PBMD = 4,992’ PBTVD = 4,965’ Max Angle = 12.7 deg @ 1,600’ 20” 13-3/8” 9-5/8” TOC @ 3,168’ CBL 3/19/86 STRLNG A B C 1&2 E F1 B C F2 F3 F4 5 9 13 11 12 F1 17 18 19 3 4 H G F2 F2 6 BELUGA D D 8 15 16 Jet Cut Tubing @ 3,251’ (SS) 3,243’ (LS) 3,241’ 9-5/8 CIBP w/ 35’ cmt cap - 4/25/22 3,265’ 2-7/8 CIBP(SS) Planned Whipstock for 2022 Sidetrack @ ± 3,185’ Short String ID. Description Depth MD Length ID OD CIBP 3,265’ B Baker Stab-in Stinger 3257' 0.67' 2.5" 3.375'' C Otis 'XN' Nipple 3295' 1.05' 2.205'' 3.668'' Fish ID. Description Depth MD Length ID OD F1 2.875" Weatherford WRP 4,045' - 2.875" F2 Otis 'XN' Nipple 4,732' 1.05' 2.2'' 3.67'' F3 2-7/8" Blast Joints 4,733' 246.25 2.44'' 3.68'' F4 Baker Shear Sub 4,980' .75' 2.44'' 3.67'' _____________________________________________________________________________________ Updated By: JLL 05/05/22 SCHEMATIC Beluga River Unit Well: BRU 211-03 PTD: 186-010 API: 50-283-20079-00 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Phase Date Status STRLNG A 3305' 3325' 3,280' 3,300' 20' 8 2 04/26/22 Isolated STRLNG B 3363' 3412' 3,338' 3,387' 49' 8 2 04/26/22 Isolated STRLNG C 3536' 3580' 3,511' 3,554' 26' 4 0 04/26/22 Isolated STRLNG C 3614' 3640' 3,588' 3,614' 26' 8 2 04/26/22 Isolated BELUGA D 3682' 3876' 3,656' 3,850' 51' 8 2 04/26/22 Isolated BELUGA E 4092' 4211' 4,066' 4,185' 21' 8 2 04/26/22 Isolated BELUGA F 4378' 4402' 4,376' 4,376' 14' 8 2 04/26/22 Isolated BELUGA F 4512' 4725' 4,486' 4,699' 31' 8 1 04/26/22 Isolated BELUGA G 5040' 5060' 5,014' 5,034' - 1 0 3/2/1986 Sqz & Plug BELUGA H 5675' 5745' 5,649' 5,719' - 0.5 0 3/2/1986 Sqz & Plug Rig Start Date End Date HAK 401 4/1/22 4/27/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BRU 211-03 50-283-20079-00-00 186-010 04/01/22- Friday 04/02/22 - Saturday PJSM and PTW. Warm up equipment. Spot equipment and rig-up. MU CCL and 2-7/8" CIBP (2.10"OD), CCL to plug 7.7ft, stab on Short string (tubing #2). Pressure test lubricator 250psi/1500psi - Test good. RIH with CIBP, jewelry depths are showing 150ft too deep. POOH to run a jewelry log. Check E-line counter. MU 2.25" Gauge ring, spangs and CCL. RIH. Tag XN nipple at 3,295ft and pull jewelry log. POOH. MU CCL and 2-7/8" CIBP (2.10"OD), CCL to plug 7.7ft, RIH. Correlate and set plug at 3265ft in the short string. POOH. Fluid Pack 2-7/8" short string and pressure test to 1500psi for 30min - Test good. Bleed pressure to 0psi. RU Triplex to fill the IA (9-5/8" casing). The pump broke down, troubleshoot the pump with no luck. Move the pump to the mechanic shop. Lay down lubricator, secure well, and SDFN. 04/21/2022 - Thursday PJSM, finish prepping pad, pull bull rail, assist production in pulling Abandon heater pipe and flange and cover same. Lay down liner and felt, and line up carrier with well. Place choke and pump and pits. Spot base beam, removed SCSV on shot string side on tree for room to spot carrier, spot carrier and adjust base beam with jacks. Raise and scope derrick. Start running electrical lines, finish running pump hoses for pump hook up circ hose to IA, spot koomey house and office trailer, SDFN. Adam Earl with AOGCC called for timing to witness the BOPE testing . PJSM and PTW. Warm up equipment. Mechanic fixed triplex pump, valves had debris in them.;Fluid pack the IA with produced water. Rebuild E-line setting tools. Pressure test IA : (Long String (LS), Short String (SS), Heat String (HS) Initial pressures psi (LS/SS/HS/IA) (0/0/0/0) Starting pressures psi (LS/SS/HS/IA) (2811/10/2811/2811) 15 min pressures psi (LS/SS/HS/IA) (2803/10/2803/2803) 30 min pressures psi (LS/SS/HS/IA) (2795/10/2795/2795) MITIA 2795psi - Test good Bleed all strings to zero psi. M/U CCL and 2-7/8" jet cutter (2.06"OD). CCL to cutter 2.6'. Stab on Short string Pressure up short string to 400psi. Correlate and jet cut the short string at 3,251'. Saw good pressure response on IA when cutter was fired. POOH, jet cutter fired. M/U CCL and 2-7/8" jet cutter (2.06"OD). CCL to cutter 2.6'. Stab on Long string. RIH and Tag high. Call town and decide to cut as deep as possible. Jet cut the long string at 3,243'. POOH, jet cutter fired. R/D E-line. Secure well and turn back over to production SDFN Pressure test IA : (Long String (LS), Short String (SS), Heat String (HS) Initial pressures psi (LS/SS/HS/IA) (0/0/0/0) Starting pressures psi (LS/SS/HS/IA) (2811/10/2811/2811) 15 min pressures psi (LS/SS/HS/IA) (2803/10/2803/2803) 30 min pressures psi (LS/SS/HS/IA) (2795/10/2795/2795) MITIA 2795psi - Test good Fluid Pack 2-7/8" short string and pressure test to 1500psi for 30min - Test good. Short string jet cut @3251' (Sundry called for cutting @~3245'). -WCB Long string jet cut @3243' (Sundry called for cutting @~3245'). -WCB Jet cut the long string at 3,243'. POOH, j Correlate and set plug at 3265ft in the short string. POOH. Correlate and jet cut the short string at 3,251'. Saw good pressure response on IA when cutter was fired. POOH, MIT-T the short string to 1500 psi, per Sundry. -WCBEL set CIBP in short string @3265' (Sundry 322-119 called for setting it at ~3250'). -WCB stab on Short string (tubing #2). Passing MIT-IA, prior to either tubing being jet cut (and plugs in each string). -WCB MU CCL and 2-7/8" CIBP Rig Start Date End Date HAK 401 4/1/22 4/27/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BRU 211-03 50-283-20079-00-00 186-010 04/23/2022 - Saturday PJSM, bolt up choke and kill lines, install koomey lines and function test koomey, build 2-3/8, and 2-7/8, and dual test joints, perform shell test 250 psi, 3000 psi high for 5 minutes charted. Tested BOP, all test was 250 low for 5 minutes, and 3000 psi high for 5 minutes, tested annular and CMV's with 2-3/8 test joints, lower rams with both 2-3/8 and 2-7/8 test joints, test upper dual rams with 2-7/8 test joints, perform koomey draw down test and test GAS and PVT alarms, test was witness by AOGCC inspector Adam Earl. Review standing order for pulling dual string with AOGCC inspector. Pull two-way checks from heater string, long string and short string. Break down test joints and R/u handling equipment for 2- 3/8 heater string. 04/24/2022 - Sunday PJSM, check well for pressure, well static, line up to MIT. MIT 9-5/8 csg to 1500 psi for 30 minutes on chart (Good test). Rig up laydown machine and make up land jt in heater string. Work heater string up to 20k over several times no movement, pickup to 25k pulled free. Make up threaded bar into pack off puller holes and pull landing nipple to floor, then remove pack off plate. POOH slow with Heater string. Due to hanging up laid out total of 59 jts of 2-3/8, 4.7# N-80 Buttress tbg, Xn nipple and mule shoe. Had full recovery. Changed out handling Equipment to 2-7/8 and made up spear. Made up spear and, spear into short string, pickup to 20k work up to 40k several times pipe freed up, string wt. 20k, attempt to pull out of hole with short string, wt increased to 34k set back down and land short string in hanger. Released spear, made up landing joint in long string, pick up 2 ft, pulling both strings wt 34k work long string, turn pipe to the right and came free. Continue to work pipe having to work pipe in 5 ft. intervals to free same, 34k max wt., from cut at 3243 ELM to 2446 ft. Continue to pooh slow hanging up every 15 ft. having to work same f/ 2446 ft. to 1649 ft. Continue pooh, not hanging up as bad. Able to pull without working. Unable to work cut jt, thru hanger, install landing nipple and land cut joint in hanger, back out landing joint. SDFN. 04/22/2022- Friday Spot rain for rent tank and connect hoses, check well for pressure SITP "0" SICP "0". Circulate down L/S taking returns from IA to rain for rent tank, caught pressure right away and got return with 1 bbl pumped, continue circulating down L/S pumping at 3 bpm with 550 psi, 8.5 ppg return wt. Pumped total of 190 bbs, returns cleaned up, shut down pump well static. Line up and reverse circulate the Heater string and short string, pump 45 bbls total at 3 bpm at 250 psi. Shut down pump well static. Monitor well 20 minutes well static. Install two-way check and nipple down tree. Prep hanger and install blanking subs in S/S and heater string, the threads in L/S corroded. Nipple up 13-5/8 5m BOPs, change the 5" x 2-7/8 rams to 2-3/8 x 3-1/2 VBRs and install 2-7/8 Dual ram, nipple up DSA, spool with choke and kill valves, Double Bop with BLIND and 2-3/8 x 3-1/2 VBR's in top double, single BOPE with 2-7/8 dual rams, & 5k annular BOP, torque connections. SDFN. Made up spear and, spear into short string, pickup to 20k work up to 40k several times pipe freed up, string wt. 20k, attempt to pull out of hole with short string, wt increased to 34k set back down and land short string in hanger. Released spear, made up landing joint in long string, pick up 2 ft, pulling both strings wt 34k work long string, turn pipe to the right and came free. Continue to work pipe having to work pipe in 5 ft. intervals to free same, 34k max wt., from cut at 3243 ELM to 2446 ft. Continue to pooh slow hanging up every 15 ft. having to work same f/ 2446 ft. to 1649 ft. Continue pooh, not hanging up as bad. Able to pull without working. Unable to work cut jt, thru hanger, install landing nipple and land cut joint in hanger, back out landing joint. Prep hanger and install blanking subs in S/S and heater string, the threads in L/S corroded. Line up and reverse circulate the Heater string and short string, pump 45 bbls total at 3 bpm at 250 psi. Shut down pump well static. Monitor well 20 minutes well static. Install two-way check and nipple down tree. Circulate down L/S taking returns from IA to rain for rent tank, caught pressure right away and got return with 1 bbl pumped, continue circulating down L/S pumping at 3 bpm with 550 psi, 8.5 ppg return wt. Pumped total of 190 bbs, R/u handling equipment for 2- 3/8 heater string. MIT 9-5/8 csg to 1500 psi for 30 minutes on chart (Good test). Work heater string up to 20k over several times no movement, pickup to 25k pulled free. Make up threaded bar into pack off puller holes and pull landing nipple to floor, then remove pack off plate. POOH slow with Heater string. Due to hanging up laid out total of 59 jts of 2-3/8, 4.7# N-80 Buttress tbg, Xn nipple and mule shoe. Had full recovery. C Pulled heater string. Pulled long string. -WCB Per the Sundry's AOGCC's stipulations, KWF was circulated down all 3 strings (short, long, & Heater). -WCB Per the Sundry's AOGCC's stipulations, a TWC was installed in the long string's tubing hanger. -WCB Rather than TWC's, blanking subs were installed in the short string and in the heater string. -WCB Rig Start Date End Date HAK 401 4/1/22 4/27/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BRU 211-03 50-283-20079-00-00 186-010 Check well (static) sting into short string with spear and pull up to 24k, picking up at 22k, pull hanger bowl to surface, lay down tbg hanger, pooh with short string f/ 3251 to surface laying down short string. Laid down 101 joints and cut piece of 2-7/8 6.5# N-80 EUE tbg. Monitor well static. Rig down handling equipment tongs and lay down machine. Service, rig and mud pump, clean suction manifold. Rig up Alaska E-line and run-in hole with 8.26 -gauge ring and junk basket, tagging at 3220 ELM, run correlation pass, adjust log down 12 ft. Tagged Stump at 3249 ELM pooh junk basket clean. Make model 20 running tool and 9-5/8 CIBP Legacy oil tools Part number 000-7710-002 7.710 OD for 9-5/8 29.3 to 53.5 ppf casing rated 8000 psi at 325 deg F LOT# 88615. RIH with same at 100 fpm, log plug on depth set CIBP at 3241 ELM. Pooh with setting tool and SDFN 04/26/2022 - Tuesday Perform MIT on CBP set at 3241' ELM to 3000 psi on chart for 30 minutes, good test, AOGCC & BLM waived witness for test. RIH with CBL set up tool at 2067 ft. RIH tagging CIBP at 3141 ft. log repeat pass. RIH and tag CIBP. POOH running CBL from 3241 to surface. Swap out tool strings pick up 40 ft. dump bailer. Made 5 runs with 40 ft. x 4" dump bailer dumping 35 ft. of Accelerated NEO super slurry system P/N 0105-175-017 for 70deg - 175 deg service temp. cmt on CIBP at 3241 EST top of cmt at 3206 ft. ELM rig down ELine SDFN. 04/27/2022 - Wednesday Nipple down 13-5/8 Bops, remove dual rams from single gate Bops. Install dry hole cap and torque up same. Rig down derrick and scope down and lay down derrick. Move equipment off pad C. 04/25/2022 - Monday set CIBP at 3241 ELM. E-line and run-in hole with 8.26 -gauge ring and junk basket, tagging at 3220 ELM, run correlation pass, adjust log down 12 ft. Tagged Stump at 3249 ELM Perform MIT on CBP set at 3241' ELM to 3000 psi on chart for 30 minutes, good test, MIT on 9-5/8 CIBP passed. 9-5/8 CIBP tagged per AOGCC reqirement in sundry. CBL pulled from CIBP to surface. EL dumped 35-ft cement atop CIBP. -WCB Pulled short string. EL set 9-5/8 CIBP @3241 ELMD (Sundry specified~3240') -WCB sting into short string with spear and pull up to 24k, picking up at 22k, pull hanger bowl to surface, lay down tbg hanger, pooh with short string f/ 3251 to surface laying down short string. Laid down 101 joints and cut piece of 2-7/8 6.5# N-80 EUE tbg. s pick up 40 ft. dump bailer. Made 5 runs with 40 ft. x 4" dump bailer dumping 35 ft. of Accelerated NEO super slurry system P/N 0105-175-017 for 70deg - 175 deg service temp. cmt on CIBP at 3241 EST top of cmt at 3206 ft. RIH and tag CIBP. POOH running CBL from 3241 to surface. From:McLellan, Bryan J (OGC) To:Ryan Rupert Cc:Jacob Flora; Juanita Lovett; Howard Hooter - (C) Subject:RE: [EXTERNAL] RE: 10-403 Beluga River Unit 211-03 PTD 186-010 - Sundry_322-119_Approved_032322 Date:Thursday, April 21, 2022 10:51:00 AM Attachments:V2_BRU 211-03 RWO procedure_AOGCC(4-20-22) - bjm comment 21Apr22.docx Ryan, The procedure looks good, except for a typo on step 25 (see comment on attachment). I’ll attach this update to the sundry existing sundry. Send over the standing orders once you have them and then I can grant approval to proceed. 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: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Wednesday, April 20, 2022 4:45 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Jacob Flora <Jake.Flora@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Howard Hooter - (C) <Howard.Hooter@hilcorp.com> Subject: RE: [EXTERNAL] RE: 10-403 Beluga River Unit 211-03 PTD 186-010 - Sundry_322- 119_Approved_032322 Thanks Bryan. The attached revised procedure I believe addresses 1/3/4. I’ll get a copy of the revised standing orders to you BEFORE we pull the dual string. Also attached is the BOP schematic. Please let me know if anything else is needed. Thanks, Ryan Rupert Kenai Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, April 18, 2022 1:20 PM To: Jacob Flora <Jake.Flora@hilcorp.com> 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. Cc: Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: [EXTERNAL] RE: 10-403 Beluga River Unit 211-03 PTD 186-010 - Sundry_322- 119_Approved_032322 Jake, I always have concerns when pulling dual strings at the same time. How will you ensure the dual rams will align with the two tubing strings when the well starts flowing? The annular preventor won’t work. Here’s what we’ll need. 1. MITIA to 1500 psi after circulating the entire wellbore to kill weight fluid in step 11.a of the sundried procedure (Sundry 322-119). 2. Update standing shut-in orders to the driller and rig crew for closing in on dual pipe. Submit a copy to AOGCC prior to pulling dual string. 3. Perform Kick while tripping drill for shutting in on dual pipe before pulling out of the hole with the dual string. 4. Submit an updated BOP stack diagram (indicating ram types and sizes) and revised procedure to the AOGCC. You can either submit a new sundry or I can attach #2 and 4 to the existing sundry and then I’ll send an email approval if it looks good. 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: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Thursday, April 14, 2022 11:06 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Ryan Rupert <Ryan.Rupert@hilcorp.com>; EDHOOTER295@gmail.com Subject: 10-403 Beluga River Unit 211-03 PTD 186-010 - Sundry_322-119_Approved_032322 Bryan, We found a note in the wellfile that suggested we should be ready for pulling both 2-7/8 strings at the same time. Given that we are adding a dual ram to the BOP configuration, with the plan of having it available and tested if the strings will not pull individually (if the collars are catching on each other and won’t pull). Attached is an updated version of the BOP stack we intend to use. Please advise if you have any concerns regarding pulling the dual completion. I’ve copied Ryan as he is watching the 401 next week while I am on PTO, and our WSM Ed Hooter. Thanks, Jake Jake Flora | Kenai Ops Engineer | Hilcorp Alaska | 720-988-5375 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 herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Well Prognosis Version 2 (4/20/22) Well Name: BRU 211-03 API Number: 50-283-20079-00-00 Current Status: SI Gas Well Permit to Drill Number: 186-010 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (M) Second Call Engineer: Chad Helgeson (907) 777-8420 (O) (907) 229-4824 (M) Maximum BHP: 1293 psi (Based on 1/2/21 swab report) MPSP: 936 psi (with 0.1 psi/ft gas gradient to surface from 3574’ TVD) Current SITP: 570 psi Well Status SI gas producer since December 2021. Brief Well Summary Exhausted gas well that is being prepped for a rig sidetrack. Currently the well is open in the Sterling and Beluga of the Beluga River Undefined Gas Pool. The objective of this sundry is to use Rig 401 to pull tubing and plug back the 9-5/8” casing prior to sidetracking the well with Drilling Rig 147. Notes Regarding Wellbore Condition 2011 MITIA to 1500 psi passed 2/28/22 Long String: Bail fill, tag top of WRP at 3255’ with 2.25” GR, Short String: drift to XN at 3295’ w 2.25” GR Procedure 1. Review COAs in Approved Sundry 10-403 Form 2. RU E-Line to long string, PT lubricator to 1500 psi 3. MIT to 1500 psi 4. Jet cut tubing at ~3245’ 5. RU E-line to short string, set 2-7/8” CIBP at ~3250’ 6. MIT to 1500 psi 7. Jet cut tubing at ~3245’ 8. Provide AOGCC 48hrs advance notice of BOP Test Work to this point completed as-of 4/20/22 Well Prognosis Version 2 (4/20/22) 9. MIRU 401 workover rig 10. Set BPV or TWC in all 3 hangers 11. ND Tree 12. NU BOP and test to 3000 psi. 13. Circulate KWF throughout all tubing strings and casing 14. MIT-IA to 1500psi for 30 charted minutes 15. Pull and lay down 2-3/8” heater string 16. Unseat and attempt to pull each 2-7/8” tubing string individually 17. CONTINGENCY: If 2-7/8” long and short strings must be pulled together: a. Review standing orders for shutting the well in when closing on dual strings b. Perform a kick while tripping drill for shutting in on dual strings before pulling out of the hole with dual strings 18. Notify BLM with 48hrs advance for witnessing the 9-5/8” CIBP setting and testing 19. Notify AOGCC with 24hrs advance notice to witness the MIT on the 9-5/8” CIBP. 20. RU E-line, Set 9-5/8” CIBP at ~3240’ 21. Log CBL from CIBP to surface 22. MIT CIBP to 3000 psi 23. ND BOP, ND tubing head, NU new tubing head, NU dry hole tree 24. RDMO Rig 401 25. RU E-line, tag CIBP to verify depth, dump bail 35’ cement on 9-5/8” CIBP at ~3540’ (this step may also take place on the rig after step 13, time dependent) After Step 20. - bjm 26. Suspended operations until drilling rig moves on location ***Remaining Procedure to be included on the Permit to Drill for the sidetrack*** ***Sidetrack Wellbore will be named BRU 241-04*** Phase II General sequence of operations pertaining to drilling procedure: (informational only) 1. MIRU drilling rig 2. Monitor well to ensure it is static 3. ND Dry Hole Tree, NU BOP and test in accordance with Approved AOGCC PTD. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test) 4. Set CIBP & whipstock 5. Mill window 6. MU drilling BHA 7. Swap well to drilling fluid 8. Drill per directional plan 9. Run/Cement casing 10. Swap to completion sundry Attachments: 1) Actual Schematic 2) Proposed Schematic 3) Wellhead Diagram – Current 4) Wellhead Diagram - Proposed 5) Rig 401 BOP Diagram (updated with added dual rams) 6) AOGCC RWO Change Form The picture can't be displayed.The picture can't be displayed.The picture can't be displayed.The picture can't be displayed. 13-5/8"SPHERICAL ANNULAR HEIGHT: 45.28" WEIGHT: 12,806 LBS 13-5/8"TYPE U SINGLE BOP HEIGHT: 33.81" WEIGHT: 7,700 LBS 13-5/8"TYPE U DOUBLE BOP HEIGHT: 55.81" WEIGHT: 14,800 LBS 13-5/8"MUD CROSS W/ 4- 1/16" OUTLETS HEIGHT: 36" APROX. 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ZƵŶͬĞŵĞŶƚĐĂƐŝŶŐ ϭϬ͘^ǁĂƉƚŽĐŽŵƉůĞƚŝŽŶƐƵŶĚƌǇ ƚƚĂĐŚŵĞŶƚƐ͗ ϭͿ ĐƚƵĂů^ĐŚĞŵĂƚŝĐ ϮͿ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯͿ tĞůůŚĞĂĚŝĂŐƌĂŵʹƵƌƌĞŶƚ ϰͿ tĞůůŚĞĂĚŝĂŐƌĂŵͲWƌŽƉŽƐĞĚ ϱͿ ZŝŐϰϬϭKWŝĂŐƌĂŵ ϲͿ K'ZtKŚĂŶŐĞ&Žƌŵ ΎΎΎZĞŵĂŝŶŝŶŐWƌŽĐĞĚƵƌĞƚŽďĞŝŶĐůƵĚĞĚŽŶƚŚĞWĞƌŵŝƚƚŽƌŝůůĨŽƌƚŚĞƐŝĚĞƚƌĂĐŬΎΎΎ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB W͘ϭ ƌĞĂƚĞĚǇ͗::ϱͬϭϬͬϮϬϭϲ ^,Dd/ ĞůƵŐĂZŝǀĞƌhŶŝƚ tĞůů͗ZhϮϭϭͲϬϯ >ĂƐƚŽŵƉůĞƚĞĚ͗ϰͬϱͬϭϵϴϲ Wd͗ϭϴϲͲϬϭϬ W/͗ϱϬͲϮϴϯͲϮϬϬϳϵͲϬϬ ^/E'd/> ^ŝǌĞ dǇƉĞ td 'ƌĂĚĞ ŽŶŶ / ƚŵ ϯϬΗ ŽŶĚƵĐƚŽƌ ϯϭϬη <Ͳϱϱ ƵƚƚƌĞƐƐ ϮϴΗ ϵϳΖ ϮϬΗ ^ƵƌĨĂĐĞ ϭϯϯη ,ͲϰϬ ƵƚƚƌĞƐƐ ϭϴ͘ϳϯΗ ϰϯϯΖ ϭϯͲϯͬϴΗ /ŶƚĞƌŵĞĚŝĂƚĞ ϲϴη ^Ͳϵϱ ƵƚƚƌĞƐƐ ϭϮ͘ϰϭϱΗ ϯ͕ϭϰϬΖ ϵͲϱͬϴΗ WƌŽĚƵĐƚŝŽŶ ϰϳηΘϰϯ͘ϱη EͲϴϬ ƵƚƚƌĞƐƐ ϴ͘ϲϴϭΗ ϲ͕ϬϬϯΖ ϮͲϯͬϴΗ ,ĞĂƚĞƌ^ƚƌŝŶŐ ϰ͘ϲη EͲϴϬ ƵƚƚƌĞƐƐ ϭ͘ϵϱϱΗ ϭ͕ϴϭϵΖ dh/E'd/> ϮͲϳͬϴΗ WƌŽĚ͘^ŚŽƌƚ^ƚƌŝŶŐ ϲ͘ϱη EͲϴϬ hϴƌĚ Ϯ͘ϰϰϭΗ ϯ͕ϮϵϳΖ ϮͲϳͬϴΗ WƌŽĚ͘>ŽŶŐ^ƚƌŝŶŐ ϲ͘ϱη EͲϴϬ hϴƌĚ Ϯ͘ϰϰϭΗ ϰ͕ϰϳϴΖ :t>Zzd/> >ŽŶŐ^ƚƌŝŶŐ /͘ ĞƉƚŚD;Ĩƚ͘Ϳ >ĞŶŐƚŚ;Ĩƚ͘Ϳ /;ŝŶ͘Ϳ K;ŝŶ͘Ϳ ĞƐĐƌŝƉƚŝŽŶ ϭ ϭϲ ϭ͘ϯϯ Ϯ͘ϯϭ Ϯ͘ϵ ϮͲϳͬϴΗϴZͲϮϳͬϴΗƵƚƚyK,ĂŶŐĞƌĨŽƌƐƚƌŝŶŐƐϭ ΘϮ Ϯ ϵϴϴ ϭ͘Ϭϲ Ϯ͘ϯϭ ϯ͘ϳ KƚŝƐΖyΖEŝƉƉůĞ ϯ ϯ͕Ϯϱϯ ϭ͘ϰ Ϯ͘ϰϰ ϯ͘ϰ ĂŬĞƌΖΖ^ĂĨĞƚǇ:ƚ͕͘ƌŝŐŚƚƚƵƌŶƌĞůĞĂƐĞ ϰ ϯ͕Ϯϱϰ ϯ͘Ϯ Ϯ͘ϯϭ ϯ͘ϴ KƚŝƐΖyΖ^ůŝĚŝŶŐ^ůĞĞǀĞ ϱ ϯ͕Ϯϱϳ ϳ͘Ϭϵ Ϯ͘ϰϰ ϴ͘ϯ ĂŬĞƌΖ,ΖƵĂůWĂĐŬĞƌ͕ϰϬŬƌĞůĞĂƐĞ ϲ ϯ͕Ϯϱϳ Ͳ Ͳ Ͳ tZWWůƵŐƚŽƉƉĞĚďǇĞŵĞŶƚWůƵŐ ϴ ϯ͕ϲϱϲ ϯ͘ϭϵ Ϯ͘ϯϭ ϯ͘ϳ KƚŝƐΖyΖ^ůŝĚŝŶŐ^ůĞĞǀĞ ϵ ϯ͕ϲϱϵ ϴ͘ϱϭ Ϯ͘ϰϰ ϴ͘ϯ ĂŬĞƌΖ,ΖWĂĐŬĞƌ ϭϭ ϰ͕Ϭϰϰ ϭ͘Ϭϲ Ϯ͘ϯϭ ϯ͘ϳ KƚŝƐΖyΖEŝƉƉůĞ ϭϮ ϰ͕Ϭϰϱ ϯ͘ϭϳ Ϯ͘ϯϭ ϯ͘ϳ KƚŝƐΖyΖ^ůŝĚŝŶŐ^ůĞĞǀĞ ϭϯ ϰ͕Ϭϰϴ ϴ͘ϱϭ Ϯ͘ϰϰ ϴ͘ϯ ĂŬĞƌΖ,ΖWĂĐŬĞƌ ϭϱ ϰ͕ϰϲϲ ϭ͘Ϭϱ Ϯ͘ϯϭ ϯ͘ϳ KƚŝƐΖyΖEŝƉƉůĞ ϭϲ ϰ͕ϰϲϳ ϯ͘ϭϳ Ϯ͘ϯϭ ϯ͘ϳ KƚŝƐΖyΖ^ůŝĚŝŶŐ^ůĞĞǀĞ ϭϳ ϰ͕ϰϳϬ ϴ͘ϱϭ Ϯ͘ϰϰ ϴ͘ϯ ĂŬĞƌΖ,ΖWĂĐŬĞƌ ϭϴ ϰ͕ϵϵϮ Ͳ Ϯ͘ϰϰ Ͳ ^sƐƋǌǁͬϱϬƐǆďĞůŽǁ ϭϵ ϱ͕ϲϮϬ Ͳ Ϯ͘ϰϰ Ͳ ,ŽǁĐŽ^sƐƋǌǁͬϱϬƐǆďĞůŽǁ ϯϬ͟ ϵͲϱͬϴ͟ Z<ƚŽD^>сϭϬϯ͛Z<ƚŽ'>сϭϲ͘ϭ͛ dD сϲ͕ϱϲϮ͛dsсϲ͕ϱϯϲ͛ WDсϰ͕ϵϵϮ͛Wdsсϰ͕ϵϲϱ͛ DĂǆŶŐůĞсϭϮ͘ϳ ĚĞŐΛϭ͕ϲϬϬ͛ DŝŶ/͘͘ ,ĞĂƚĞƌƐƚƌŝŶŐ͗ϭ͘ϳϵϭ͟ ^ŚŽƌƚƐƚƌŝŶŐ͗Ϯ͘ϮϬϱ͟ >ŽŶŐƐƚƌŝŶŐ͗Ϯ͘ϯϭ͟ ϮϬ͟ ϭϯͲϯͬϴ͟ dKΛ ϯϭϲϴ͛ ^dZ>E' ϭΘϮ >h' &ϭ &Ϯ &Ϯ ' , , , ϲ ϴ ϭϱ ϭϲ &Ϯ &ϯ &ϰ ϱ ϵ ϭϯ ϭϭ ϭϮ &ϭ ϭϳ ϭϴ ϭϵ Ϯ ϯ ϰ ,ĞĂƚŝŶŐ^ƚƌŝŶŐ /͘ ĞƐĐƌŝƉƚŝŽŶ ĞƉƚŚD >ĞŶŐƚŚ / K , KƚŝƐΖyEΖEŝƉƉůĞ ϲϬϱΖ ϭ͘ϬϱΖ ϭ͘ϳϵΖΖ ϯ͘ϬϲΖΖ , ϰϱĞŐƌĞĞDƵůĞ^ŚŽĞ ϭ͕ϴϭϳΖ ϭ͘ϴΖ ϮΖΖ ϯ͘ϬϲΖΖ ^ŚŽƌƚ^ƚƌŝŶŐ /͘ ĞƐĐƌŝƉƚŝŽŶ ĞƉƚŚD >ĞŶŐƚŚ / K KƚŝƐΖyΖEŝƉƉůĞ ϳϵϳΖ ϭ͘ϬϱΖ Ϯ͘ϯϭϯΖΖ ϯ͘ϲϲϴΖΖ ĂŬĞƌ^ƚĂďͲŝŶ^ƚŝŶŐĞƌ ϯϮϱϳΖ Ϭ͘ϲϳΖ Ϯ͘ϱΗ ϯ͘ϯϳϱΖΖ KƚŝƐΖyEΖEŝƉƉůĞ ϯϮϵϱΖ ϭ͘ϬϱΖ Ϯ͘ϮϬϱΖΖ ϯ͘ϲϲϴΖΖ &ŝƐŚ /͘ ĞƐĐƌŝƉƚŝŽŶ ĞƉƚŚD >ĞŶŐƚŚ / K &ϭ Ϯ͘ϴϳϱΗtĞĂƚŚĞƌĨŽƌĚtZW ϰ͕ϬϰϱΖ Ͳ Ϯ͘ϴϳϱΗ &Ϯ KƚŝƐΖyEΖEŝƉƉůĞ ϰ͕ϳϯϮΖ ϭ͘ϬϱΖ Ϯ͘ϮΖΖ ϯ͘ϲϳΖΖ &ϯ ϮͲϳͬϴΗůĂƐƚ:ŽŝŶƚƐ ϰ͕ϳϯϯΖ Ϯϰϲ͘Ϯϱ Ϯ͘ϰϰΖΖ ϯ͘ϲϴΖΖ &ϰ ĂŬĞƌ^ŚĞĂƌ^Ƶď ϰ͕ϵϴϬΖ ͘ϳϱΖ Ϯ͘ϰϰΖΖ ϯ͘ϲϳΖΖ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB W͘Ϯ ƌĞĂƚĞĚǇ͗::ϱͬϭϬͬϮϬϭϲ ^,Dd/ ĞůƵŐĂZŝǀĞƌhŶŝƚ tĞůů͗ZhϮϭϭͲϬϯ >ĂƐƚŽŵƉůĞƚĞĚ͗ϰͬϱͬϭϵϴϲ Wd͗ϭϴϲͲϬϭϬ W/͗ϱϬͲϮϴϯͲϮϬϬϳϵͲϬϬ WZ&KZd/KEd/> ^ĂŶĚƐͬŽŶĞ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ ŵƚ ^W& WŚĂƐĞĂƚĞ ^ƚĂƚƵƐ ^dZ>E' ϯϯϬϱΖ ϯϯϮϱΖ ϯ͕ϮϴϬΖ ϯ͕ϯϬϬΖ ϮϬΖ ϴ Ϯ ϯͬϭͬϭϵϴϲ KƉĞŶ ^dZ>E' ϯϯϲϯΖ ϯϰϭϮΖ ϯ͕ϯϯϴΖ ϯ͕ϯϴϳΖ ϰϵΖ ϴ Ϯ ϯͬϭͬϭϵϴϲ KƉĞŶ ^dZ>E' ϯϱϯϲΖ ϯϱϴϬΖ ϯ͕ϱϭϭΖ ϯ͕ϱϱϰΖ ϮϲΖ ϰ Ϭ ϲͬϭͬϭϵϵϰ KƉĞŶ ^dZ>E' ϯϲϭϰΖ ϯϲϰϬΖ ϯ͕ϱϴϴΖ ϯ͕ϲϭϰΖ ϮϲΖ ϴ Ϯ ϯͬϭͬϭϵϴϲ KƉĞŶ >h' ϯϲϴϮΖ ϯϴϳϲΖ ϯ͕ϲϱϲΖ ϯ͕ϴϱϬΖ ϱϭΖ ϴ Ϯ ϯͬϭͬϭϵϴϲ KƉĞŶ >h' ϰϬϵϮΖ ϰϮϭϭΖ ϰ͕ϬϲϲΖ ϰ͕ϭϴϱΖ ϮϭΖ ϴ Ϯ ϯͬϭͬϭϵϴϲ KƉĞŶ >h'& ϰϯϳϴΖ ϰϰϬϮΖ ϰ͕ϯϳϲΖ ϰ͕ϯϳϲΖ ϭϰΖ ϴ Ϯ ϯͬϭͬϭϵϴϲ KƉĞŶ >h'& ϰϱϭϮΖ ϰϳϮϱΖ ϰ͕ϰϴϲΖ ϰ͕ϲϵϵΖ ϯϭΖ ϴ ϭ ϯͬϭͬϭϵϴϲ KƉĞŶ >h'' ϱϬϰϬΖ ϱϬϲϬΖ ϱ͕ϬϭϰΖ ϱ͕ϬϯϰΖ Ͳ ϭ Ϭ ϯͬϮͬϭϵϴϲ ^ƋǌΘWůƵŐ >h', ϱϲϳϱΖ ϱϳϰϱΖ ϱ͕ϲϰϵΖ ϱ͕ϳϭϵΖ Ͳ Ϭ͘ϱ Ϭ ϯͬϮͬϭϵϴϲ ^ƋǌΘWůƵŐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ͗:>>ϬϯͬϬϴͬϮϮ WZKWK^ ĞůƵŐĂZŝǀĞƌhŶŝƚ tĞůů͗ZhϮϭϭͲϬϯ >ĂƐƚŽŵƉůĞƚĞĚ͗ϰͬϱͬϭϵϴϲ Wd͗ϭϴϲͲϬϭϬ W/͗ϱϬͲϮϴϯͲϮϬϬϳϵͲϬϬ ^/E'd/> ^ŝǌĞ dǇƉĞ td 'ƌĂĚĞ ŽŶŶ / dŽƉ ƚŵ ϯϬΗŽŶĚƵĐƚŽƌϯϭϬη<ͲϱϱƵƚƚƌĞƐƐϮϴΗ^ƵƌĨϵϳΖ ϮϬΗ^ƵƌĨĂĐĞϭϯϯη,ͲϰϬƵƚƚƌĞƐƐϭϴ͘ϳϯΗ^ƵƌĨϰϯϯΖ ϭϯͲϯͬϴΗ/ŶƚĞƌŵĞĚŝĂƚĞϲϴη^ͲϵϱƵƚƚƌĞƐƐϭϮ͘ϰϭϱΗ^ƵƌĨϯ͕ϭϰϬΖ ϵͲϱͬϴΗWƌŽĚƵĐƚŝŽŶϰϳηΘϰϯ͘ϱηEͲϴϬƵƚƚƌĞƐƐϴ͘ϲϴϭΗ^ƵƌĨϲ͕ϬϬϯΖ dh/E'd/> ϮͲϳͬϴΗWƌŽĚ͘^ŚŽƌƚ ^ƚƌŝŶŐϲ͘ϱη EͲϴϬ hϴƌĚ Ϯ͘ϰϰϭΗцϯ͕Ϯϰϱ͛ϯ͕ϮϵϳΖ ϮͲϳͬϴΗWƌŽĚ͘>ŽŶŐ ^ƚƌŝŶŐϲ͘ϱη EͲϴϬ hϴƌĚ Ϯ͘ϰϰϭΗцϯ͕Ϯϰϱ͛ϰ͕ϰϳϴ͛ :t>Zzd/> >ŽŶŐ^ƚƌŝŶŐ /͘ ĞƉƚŚ D ;Ĩƚ͘Ϳ >ĞŶŐƚŚ ;Ĩƚ͘Ϳ / ;ŝŶ͘Ϳ K ;ŝŶ͘ͿĞƐĐƌŝƉƚŝŽŶ цϯϭϴϱtŚŝƉƐƚŽĐŬ цϯ͕ϮϰϬϵͲϱͬϴ͟/Wǁͬϯϱ͛Đŵƚ;цϯ͕ϮϬϱ͛dKͿ ϯ ϯ͕Ϯϱϯϭ͘ϰϮ͘ϰϰϯ͘ϰĂŬĞƌΖΖ^ĂĨĞƚǇ:ƚ͕ƌŝŐŚƚƚƵƌŶƌĞůĞĂƐĞ ϰ ϯ͕Ϯϱϰϯ͘ϮϮ͘ϯϭϯ͘ϴKƚŝƐΖyΖ^ůŝĚŝŶŐ^ůĞĞǀĞ ϱ ϯ͕Ϯϱϳϳ͘ϬϵϮ͘ϰϰϴ͘ϯĂŬĞƌΖ,ΖƵĂůWĂĐŬĞƌ͕ϰϬŬƌĞůĞĂƐĞ ϲ ϯ͕ϮϱϳͲͲͲ tZWWůƵŐƚŽƉƉĞĚďǇĞŵĞŶƚWůƵŐ ϴ ϯ͕ϲϱϲϯ͘ϭϵϮ͘ϯϭϯ͘ϳKƚŝƐΖyΖ^ůŝĚŝŶŐ^ůĞĞǀĞ ϵ ϯ͕ϲϱϵϴ͘ϱϭϮ͘ϰϰϴ͘ϯĂŬĞƌΖ,ΖWĂĐŬĞƌ ϭϭϰ͕Ϭϰϰϭ͘ϬϲϮ͘ϯϭϯ͘ϳKƚŝƐΖyΖEŝƉƉůĞ ϭϮϰ͕Ϭϰϱϯ͘ϭϳϮ͘ϯϭϯ͘ϳKƚŝƐΖyΖ^ůŝĚŝŶŐ^ůĞĞǀĞ ϭϯϰ͕Ϭϰϴϴ͘ϱϭϮ͘ϰϰϴ͘ϯĂŬĞƌΖ,ΖWĂĐŬĞƌ ϭϱϰ͕ϰϲϲϭ͘ϬϱϮ͘ϯϭϯ͘ϳKƚŝƐΖyΖEŝƉƉůĞ ϭϲϰ͕ϰϲϳϯ͘ϭϳϮ͘ϯϭϯ͘ϳKƚŝƐΖyΖ^ůŝĚŝŶŐ^ůĞĞǀĞ ϭϳϰ͕ϰϳϬϴ͘ϱϭϮ͘ϰϰϴ͘ϯĂŬĞƌΖ,ΖWĂĐŬĞƌ ϭϴϰ͕ϵϵϮͲϮ͘ϰϰͲ ^sƐƋǌǁͬϱϬƐǆďĞůŽǁ ϭϵ ϱ͕ϲϮϬ Ͳ Ϯ͘ϰϰ Ͳ ,ŽǁĐŽ^sƐƋǌǁͬϱϬƐǆďĞůŽǁ ϯϬ͟ ϵͲϱͬϴ͟ Z<ƚŽD^>сϭϬϯ͛Z<ƚŽ'>сϭϲ͘ϭ͛ dDсϲ͕ϱϲϮ͛dsсϲ͕ϱϯϲ͛ WDсϰ͕ϵϵϮ͛Wdsсϰ͕ϵϲϱ͛ DĂǆŶŐůĞсϭϮ͘ϳĚĞŐΛϭ͕ϲϬϬ͛ ϮϬ͟ ϭϯͲϯͬϴ͟ ϵͲϱͬϴ͟dKΛϯ͕ϭϲϴ͛ >ϯͬϭϵͬϴϲ ^dZ>E' ϭΘϮ &ϭ &Ϯ &ϯ &ϰ ϱ ϵ ϭϯ ϭϭ ϭϮ&ϭ ϭϳ ϭϴ ϭϵ ϯ ϰ , ' &Ϯ &Ϯ ϲ >h' ϴ ϭϱ ϭϲ WůĂŶŶĞĚ tŚŝƉƐƚŽĐŬ Λцϯϭϴϱ͛ :ĞƚƵƚ dƵďŝŶŐΛ ΕϯϮϰϱ͛ ϯϮϰϬ͛ϵͲϱͬϴ/Wǁͬ ϯϱ͛ĐŵƚĐĂƉ ϯϮϱϬ͛ϮͲϳͬϴ/W;^^Ϳ ^ŚŽƌƚ^ƚƌŝŶŐ /͘ ĞƐĐƌŝƉƚŝŽŶ ĞƉƚŚD >ĞŶŐƚŚ / K /W цϯ͕ϮϱϬ ĂŬĞƌ^ƚĂďͲŝŶ^ƚŝŶŐĞƌϯϮϱϳΖϬ͘ϲϳΖϮ͘ϱΗϯ͘ϯϳϱΖΖ KƚŝƐΖyEΖEŝƉƉůĞ ϯϮϵϱΖ ϭ͘ϬϱΖ Ϯ͘ϮϬϱΖΖ ϯ͘ϲϲϴΖΖ &ŝƐŚ /͘ ĞƐĐƌŝƉƚŝŽŶ ĞƉƚŚD >ĞŶŐƚŚ / K &ϭϮ͘ϴϳϱΗtĞĂƚŚĞƌĨŽƌĚtZWϰ͕ϬϰϱΖͲϮ͘ϴϳϱΗ &ϮKƚŝƐΖyEΖEŝƉƉůĞϰ͕ϳϯϮΖϭ͘ϬϱΖϮ͘ϮΖΖϯ͘ϲϳΖΖ &ϯϮͲϳͬϴΗůĂƐƚ:ŽŝŶƚƐϰ͕ϳϯϯΖϮϰϲ͘ϮϱϮ͘ϰϰΖΖϯ͘ϲϴΖΖ &ϰĂŬĞƌ^ŚĞĂƌ^Ƶďϰ͕ϵϴϬΖ͘ϳϱΖϮ͘ϰϰΖΖϯ͘ϲϳΖΖ 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avid Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchrage, AK 99503 Tele: 907 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 3/17/2020 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 ELECTRONIC TRANSFER TRANSMITTAL WELL: BRU 211-03 (PTD 186-010) Log Type: SCHLUMBERGER CET LOG Log Date: 19-MAR-1986 Log Depths: 3050'-5914' File Format: PDF Filename: BRU 211-03 SCH CET 19-MAR-1986 (3050'-5914').pdf Please include current contact information if different from above. 186-010 T36421 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.18 09:07:09 -08'00' STATE OF ALASKA t AL,_KA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS \I 99i� 1 Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r OPL6-ItidnySfiiitldbwn r Performed Suspend r Perforate p Other Stimulate r Alter Casing r Chang��,,A�ir Oram r` Rug for Redrill r Perforate New Pool r Repair Well r" Re-enter Susp Well r' Other: TuDl xf 2.Operator Name 4.Well Class Before Work: 5.Permit to Drill Number ConocoPhillips Alaska, Inc. Development r,; Exploratory r 186-010 - 3.Address. 6.API Number. P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r- 50-283-20079-00 7.Property Designation(Lease Number): 8.Well Name and Number. A-029656 _ BRU 211-03 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Beluga River/Sterling Undefined Gas 11 Present Well Condition Summary: Total Depth measured 6562 feet Plugs(measured) 3257' true vertical 6536 feet , Junk(measured) 4045',4732',4733' Effective Depth measured 4992 feet Packer(measured) 3257, 3659,4048,4470 true vertical 4965 feet (true vertical) 3232, 3634,4022,4444 Casing Length Size MD ND Burst Collapse Conductor 97' 30" 97' 97' Surface 433' 20" 433' 433' Intermediate 3140' 13.375" 3140' 3114' Production 6003' 9 625" 6003' 5977' Perforation depth: Measured depth: from 3305-5745' True Vertical Depth: 3280'-5719' SCANNED .JUL 0 W l U15 Tubing(size,grade,MD,and ND) 2 875/2 375, N-80,4478/1819 MD, TVD Packers&SSSV(type,MD,and ND) 4 BAKER'HB' DUAL PACKERS @ 3257, 3659,4048,4470 MD and 3232, 3634,4022,4444 TVD NIPPLE-OTIS'X' NIPPLE @ 988 MD and 988 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured). no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2.2 MMscfd _ Subsequent to operation 2.7 MMscfd 14.Attachments(required per 20 AAC 25 070,25.071,&25 283) 15.Well Class after work: Daily Report of Well Operations p Exploratory r- Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work. Oil r Gas I✓ WDSPL r' Printed and Bectronic Fracture Stimulation Data r' GSTOR r WINY WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt 315-295 Contact Jav Maguire ,263-4551 Email Jay.C.Maquire(a�conocophillips.com Printed Name J v Maguire Title Wells Engineer Signature (.,....--,____ Phone 263-4551 Date U/L' /14 33 RBDMS\k JUL - 1 2015 53Z 7-6 It Form 10-404 Revised 5/2015 /4//fr Submit Original Only ✓ a ', SAK BRU 211-03 ConocoPhillips ® Well Attributes Max Angle&MD TD Alaska.INC. Wellbore AP W WI Field Name Well Status Incl C) MD(RKB) Act Btm(ftKB) 502832007900 BELUGA RIVER UNIT PROD 12.68 1,600.00 6,003.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Rekase Date SSSV:NIPPLE Last WO: 68.90 4/5/1986 Well Cantle:•BRU 211-03,613/201312:32:58 PM - -- Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 3,267.0 12/8/2012 Rev Reason:CMT Plug on top of WRP @3260' osborl 6/2/2013 HANGER,16 ,. Casing Strings ICasing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd ,_ - -- - ,-- -_- -- CONDUCTOR 20 18.730 16.0 433.0 433.0 133.00 K-55 BUTT ` -- - Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt-..String...String Top Thrd CONDUCTOR, SURFACE 133/8 12.415 16.0 3,140.0 3,114.6 68.00 K-55 BUTT 16-433 Casing Description String 0... String ID...Top(ftKB) Set Depth(f-.-Set Depth(TVD).°-String Wt...String...String Top Thrd NIPPLE,605W. PRODUCTION 95/8 8.681 32.0 6,003.0 5,977.0 47.00 S-95 Butt Tubing Strings Ta, Tubing Description String 0... String ID...Top(ftKB) Set Depth(8_°Set Depth(TVD)-.String WL..String...String Top Thrd NIPPLE 02,797 1 - TUBING1 27/8 2.441 16.0 4,478.3 . 4,452.4 6.50 N-80 EUE-8 RD - Completion Details Top Depth NIPPLE.988 . • (TVD) Top Incl Nomi... Top(ftKB) (ftKB) C) Rem Description Comment ID(in) 16.0 16.0 0.00 HANGER TUBING HANGER w/XO 2.313"TO 1.91" 1.910 SHOE,1,817 987.8 987.7 0.91 NIPPLE OTIS'X'NIPPLE 2.313 SURFACE, 3,252.7 3,227.2 1.55SAFETY JT BAKER SAFETY JOINT 2.441 163,140 3,253.8 3,228.3 1.55 SLEEVE OTIS SLIDING SLEEVEw/OTIS'XA'NIPPLE 2.310 I 3,257.0 3,231.5 1.55 PACKER BAKER'HE'DUAL PACKER 40K RELEASE 2.890 3,297.1 3,271.6 1.57 BLAST JT BLAST JOINT(OAL=119') 2.441 SLEEVE,3,254 3,597.1 3,571.5 2.08 BLASTJT BLAST JOINT(OAL=59') 2.441 CMT PLUG, snNGERI 1i!�® 3,656.1 3,630.4 2.00 SLEEVE OTIS SLIDING SLEEVEw/OTIS'XA'NIPPLE 2.313 3•�� FIJI 3,659.2 3,633.6 1.99 PACKER BAKER'HB'DUAL PACKER 40K RELEASE 2.890 PACKER,3.257- PLUG.3.257 iii- ,. 3,667.8 3,642.1 1.98 BLAST JT BLAST JOINT(OAL=119) 2.441 3,847.8 3,822.0 1.71 BLAST JT BLAST JOINT(OAL=40') 2.441 NIPPLE 42, II 4,043.6 4,017.7 1.81 NIPPLE OTIS'X'NIPPLE 2.313 3,296 4,044.6 4,018.8 1.81 SLEEVE OTIS SLIDING SLEEVEw/OTIS'XA'NIPPLE 2.313 IPERF, --- 4,047.8 4,022.0 1.81 PACKER BAKER'HB'DUAL PACKER 40K RELEASE 2.890 3,3053,325 4,087.2 4,061.4 1.86 BLAST JT BLAST JOINT(OAL=19.79) 2.441 IPERF. t.`"-I • SAK BRU 211-03 ConocoPhillips Alaska.Inc. Cmn6Ptullps KB-Grd(K) Rig Release Date 68.90 4/5/1986 Well Confio:-BRU 211-03,6/3/2013 12:32:58 PM - Schematic-Actual HANGER,16 Perforations&Slots Shot ,.., CE WZRM Top(TVD) Ste,(TVD) • Dens • Top(KKB)Bim(ftKB) (KKB) IRKS) Zone Date (oh.- Type Comment CONDUCTOR, 4,512.0 4,725.0 4,486.0 4,699.0 BELUGA F,BRU 3/1/1986 8.0(PERF OPEN,1 DEGREE 16433 211-03 NIPPLE.605 5,040.0 5,060.0 5,014.0 5,034.0 BELUGA G,BRU 3/2/1986 1.0 CMT SQZ&PLUG,DST 2,0 degree 211-03 SQZ phase NIPPLE az 797 u 5,675.0 5,745.0 5,649.0 5,719.0 BELUGA H,BRU 3/2/1986 0.5 CMT SQZ&PLUG,DST 1,0 degree — 211-03 SQZ phase NIPPLE,see Notes:General&Safety • End Date Annotation "..I 11/5/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.OREV SHOE,1.817 SURFACE. 16-3,140 SLEEVE.3,254 CMT PLUG, 3.253 STINGE3�—, I 91/1 PACKER.L . ,257 NIPPLE#2, 3,296 IPERF, 3,3053,325 - IPERF. 33633412 —'I A.3.503 3.5363,580 - - IPERF, 3,614-3.640 N SLEEVE,3,656 PACKER,3,659 IPERF, 3.6823.876 - NIPPLE.4.044 II FISH,4045 SLEEVE,4,045 PACKER,4,048 IPERF. 4,092-4,211 B IPERF, 4,378-4,402 NIPPLE,4.466 SLEEVE.4.467 PACKER,4470 _ IPERF, 4,512-4,725 FISH,4,732 FISH,4,733 CMT SOZ, --- —_- 5040-5,060 ---_- CMT SOZ__ 5,675-5.745 PRODUCTION, 32-6,003 TO,6,003 BRU 211-03 WELL WORK SUMMARY DATE SUMMARY 5/19/2015 CMIT T X IA= 1000- PASSED PRE-TEST PRESSURES LS = 10 SS = 60 IA= 3 OA=2 PUMPED 3 BBL TO THE IA INITIAL PRESSURES LS =1000 SS = 60 IA= 1025 OA=2 15 MINUTE PRESSURES LS = 1000 SS = 60 IA= 1000 OA= 2 30 MINUTE PRESSURES LS = 1000 SS = 60 IA= 1000 OA= 2 BLED BACK IA TO FLOW BACK TANK&ALL STRING PRESSURES TO ORIGINAL PRE- TEST SLU TAG © 2.205 XN @ 3297' KB W/2.26" GAUGE RING; 2" DUMMY GUN RUN W/ 5/20/2015 TWO PERFORATION RUNS THRU SHORT STING W/ ELU, CCL + OWENS 1-9/16" RTG, 5' LENGTH, 4SPF © 60 DEGREE PHASING GUN; EXITED SHORT STRING & PERFED LONGSTRING (c7 3310'-3315' KB ON BOTH RUNS 5/21/2015 POST-PERFORATING CMIT T X IA A PUMP 3 BBL FRESH WAS ER INITIAL PRESSURES LS = 1040 SS = 28 HS = 1080 IA= 1040 OA=2 15 MINUTE PRESSURES LS = 1030 SS = 28 HS = 1080 IA= 1030 OA=2 30 MINUTE PRESSURES LS = 1030 SS = 28 HS = 1080 IA= 1030 OA= 2 BLEED ALL PRESSURES TO PRE-TEST INITIAL; 30 MINUTES TO BLEED DOWN PRESSURES RU SLU WHA& FLOWBACK IRON FOR SWABBING 5/22/2015 13 SWAB TRIPS 1280'- 1830' W/2-7/8" SWAB MANDREL; SWAB 20 BBL TO SURFACE W/ LIGHT GAS RETURNS 5/23/2015 SLU SWAB 10 BBL FLUID TO SURFACE OVER 7 RUNS IN HOLE; WELL FLOWING @ END OF 7TH RUN ON 1"CHOKE @ 100 PSI WHP-2.0 MMSCFD; TURNOVER WELL TO PROD. OPERATORS & FLOW TEST PACK; SLU MOB OFF LOCATION W/FLOW @ 2.5 MMSCFD ON 1/4" CHOKE @ 340 PSI WHP 6/12/2015 SWAB WELL W/2-7/8" SWAB MANDREL; 10 TRIPS W/ 17 BBL FLUID RETURNED TO SURFACE W/ LITTLE GAS; DROP SOAP STICKS & SHUT IN FOR NIGHT i ,,OF 7•y� Gpw\��j�,,r THE STATE Alaska Oil and Gas ti�J ' of/� AS Conservation Commission a� l1 1T � ` gi ,, 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALArs'AP Fax: 907.276 7542 www aogcc alaska gov SCANNED MAY 2 0 2015 Jay Maguire l O Wells Engineer /' Q ConocoPhillips Alaska, INC. 1Q P.O. Box 100360 v Anchorage, AK 99510-0360 Re: Beluga River Field, Sterling Undefined Gas Pool, BRU 211-03 Sundry Number: 315-295 Dear Mr. Maguire: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, '---V--44 Cathy P. Foerster Chair DATED this iS day of May, 2015 Encl. 5 STATE OF ALASKA SKA OIL AND GAS CONSERVATION COMiviiSSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r� acture Stimulate r Pull Tubing r Operations Shutdown r Suspend r �c'Perforate Other Stimulate r Alter Casing r Change Approved Program Rug for Redrill r Perforate New Pool r Re air Well T ct,/ p r Re-enter Susp Well r Other: -4,A, i 2.Operator Name: 4.Current Well Class. 5.Permit to Drill Nuoa er: ConocoPhillips Alaska, Inc.• Exploratory r Development Jr. 186-010 3 Address Stratigraphic r Service 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-283-20079-00 7.If perforating, „... yik5 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool?406-AC S.0.5 Will planned perforations require spacing exception? Yes r No J / BRU 211-03 9.Property Designation(Lease Number): 10 Field/Pool(s): 1 ADL A-029656 • Beluga River/Sterling J(I l 11 PRESENT WELL CONDITION SUMMARY Total depth MD(ft). Total Depth TVD(ft) Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured): Junk(measured): 6562 6536 4992' 4965' 3257' 4045',4732',4733' Casing Length Size MD TVD Burst Collapse Conductor 97' 30” 97' 97' Surface 433' 20" 433' 433' Intermediate 3140' 13 375" 3140' 3114' RECEIVED Production 6003' 9.625" 6003' 5977' MAY 132015 5:46-‘6,8 Perforation Depth MD(ft). Perforation Depth TVD(ft): Tubing Size: Tubing Grade Tubing MD(ft): from 3305-5745' 3280'-5719' 2.875/2.375 N-80 4478/ 1819 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-4 Baker'HB'Dual Packers MD=3257,3659,4048,4470 and TVD=3232,3634,4022,4444 NIPPLE-OTIS'X'NIPPLE MD=988 TVD=988 12 Attachments Description Summary of Proposal J;� 13 Well Class after proposed work Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r 14.Estimated Date for Commencing Operations. 15. Well Status after proposed work. 5/16/2015 OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval. Date: GAS r WAG r GSTOR r SPLUG l-- Commission Representative. GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jay Maguire @ 263-4551 Email. Jay.0 Maquire@conocophillips com Printed Name Jay Maguire Title. Wells Engineer Signature Phone.263-4551 Date g-i 3..j5 Commission Use Only Sundry Number: Conditions of approval. Notify Commission so that a representative may witness -2`l5 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other. Spacing Exception Required? Yes ❑ No Er Subsequent Form Required: /L--Li Olt U APPROVED BY _ _ Approved by: P 9W-04- COMMISSIONER THE COMMISSION Date. 'S-4S 1-S A rov dRc togAtL12 months tr m the date of approval. Submit Form and pP � p � _ PP Form 10-403 Revised 5/2015 1'143 )yl�, S'i 11 4 Attachments inn puplicate Af RBDMScjt MAY 1 5 2015 Drift short string to 3320' MD and perforate long string. Look for pressure response at surface and if none is seen, repeat perforations. Swab well to test pack until constant flow is established. Let well flow to test pack for 5 days to determine if rate will be substantial enough to justify flowline hook ups. Perforating the long string will allow potential flow being blocked by the cement plug in the long string. The new flow path for the already perforated Beluga E & F sands will be up the long string through the perforations and to the short string.. Steps:(list service type and include any notifications) Pollard e-line: 1. CMIT TXIA to 1500 psi. (This must pass before continuing this work!) 2.Spot Pollard Unit on 211-03. Check in with production and field supervisors to confirm the job is safe to conduct. 3. RIH and perform a dummy drift gun run to 3320' KB. (441' 4. RIH with 19/16"" owens perf guns w/5 ft carrier,4 spf at 60 degrees and perforate at 3310' KB (Please make sure we are perforating at the same perfs in casing). Confirm the perf guns being run can penetrate the short string we are targeting. Look for pressure response at surface and if none is seen, repeat perforations. Re-run and perforate a second time if no pressure response has been seen. Call town. Pollard slick line: 5. Rig up pollard slick line on 211-03. 6. RIH and swab well to increase production. 7. Call town with production increase or results. 6. dt SAK BRU 211-03 ConocoPhillips Os Well Attributes �MaXAngleK MD Alaska,Inc Wellbore APUUWI Field Name Well StatusInc!(°) MD(ftKB) Act Btm(ftKB) • 502832007900 BELUGA RIVER UNIT _ _ PROD 12.68 1,600.00 6,003.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(It) Rig Release Date "' SSSV:NIPPLE Last WO: 68.90 4/5/1986 Well Config •BRU 2A2/c 6/31201312:32:58 PM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag SLM 3,267.0 12/8/2012 Rev Reason CMT Plug on top of WRP @3260' osborl 6/2/2013 HANGER,16 I IR Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String String Top Thrd CONDUCTOR 20 18.730 16.0 433.0 433.0 133.00 K-55 BUTT Casing Description string o... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR, SURFACE 133/8 12.415 16.0 3,140.0 3,114.6 68.00 K-55 BUTT 16433 Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd NIPPLE,605 II PRODUCTION 95/8 8.681 32.0 6,003.0 5,977.0 47.00 S-95 Butt Tubing Strings ae Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd NIPPLE e2,797 I TUBING 1 2 7/8 2.441 16.0 4,478.3 4,452.4 6.50 N-80 EUE-8 RD IP I IF Completion Details Top Depth NIPPLE,988 i( (TVD) Top Incl Nomi... Top(ftKB) (RKB) _ r) Item Description Comment ID(In) Pr 16.0 16.0 0.00 HANGER TUBING HANGER w/X02.313"TO 1.91" 1.910 SHOE,1,817 P 987.8 987.7 0.91 NIPPLE OTIS'X'NIPPLE 2.313 SURFACE, 3.252.7 3,2272 1.55 SAFETY JT BAKER SAFETY JOINT 2.441 16ACE, a3,i53 • !I �� 53.8 3,228.3 1.55 SLEEVE OTIS SLIDING SLEEVEw/OTIS'XA'NIPPLE 2.310 A 3,257.0 3,231.5 1.55 PACKER BAKER'FIB'DUAL PACKER 40K RELEASE 2.890 3,297.1 3,271.6 1.57 BLAST JT BLAST JOINT(OAL=119') 2.441 SLEEVE,3,2543,597.1 3,571.5 2.08 BLAST JT BLAST JOINT OAL=59' 2.441 CMT PLUG, _ 'k ( ) 3,253 STINGER R2, v1f 3,656.1 3,630.4 2.00 SLEEVE OTIS SLIDING SLEEVEw/OTIS'XA'NIPPLE 2.313 �' 3,2571 3,659.2 3,633.6 1.99 PACKER BAKER'HB'DUAL PACKER 40K RELEASE 2.890 PACKER,3,257 PLUG,3,257 ° '` 3,667.8 3,642.1 1.98 BLAST JT BLAST JOINT(OAL=119') 2.441 I 3,847.8 3,822.0 1.71 BLAST JT BLAST JOINT(OAL=40') 2.441 NIPPLE 02, I 4,043.6 4,017.7 1.81 NIPPLE OTIS'X'NIPPLE 2.313 4,044.6 4,018.8 1.81 SLEEVE OTIS SLIDING SLEEVEw/OTIS'XA'NIPPLE 2.313 (PERF,RF• Ls.PSC 4,047.8 4,022.0 1.81 PACKER BAKER'HB'DUAL PACKER 40K RELEASE 2.890 3,3053,325 ° 4,087.2 4,061.4 1.86 BLAST JT BLAST JOINT(OAL=19.79') 2.441 IPERF, _-_= 4,373.8 4,347.8 1.15BLAST JT BLAST JOINT(OAL=30') 2.441 3,3633,412 - - 4,465.6 4,439.6 0.81 NIPPLE OTIS'X NIPPLE 2.313 4,466.6 4,440.7 0.80 SLEEVE OTIS SLIDING SLEEVEw/OTIS'XA'NIPPLE 2.313 APERF, __.. 4,469.8 4,443.8 0.79 PACKER BAKER'HB'DUAL PACKER 40K RELEASE 2.890 3.5363,580 Tubing DescriptionString O... String ID...Top IRKS) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd TUBING 2 I 3.668 I 2.875 I 16.0 I 3,297.0 I 3,271.5 I 6.50 I N-80 I EUE-8 RD Com letion Details /PERF, Top Depth 3,6143.640 (TVD) Top Incl Nomi... ITop(ftKB) (ftK8) r1 Item Description Comment ID(in) SLEEVE,3,656 797.0 797.0 0.94 NIPPLE#2 OTIS 7(N NIPPLE 2.205 PACKER,3659 3,257.3 3,231.8 1.55 STINGER#2 BAKER STAB-IN STINGER 2.441 It 3,296.0 3,270.5 1I 1.57 NIPPLE#2 OTIS'XN'NIPPLE 2.205 3,6623,876 .'. _ HEATER TRI Details 238 'String995 Top 16.0) I�189.t Depth1f...ISet Depth(TVD)D)...IString Wt....5 4.70 ISN-80 !StringTopBTutt g 0' i3_I'=_ Top Depth (TVD) Top Mel Nomi... IIF Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 1' 605.0 605.0 0.56 NIPPLE OITIS'XN'NIPPLE 1.791 NIPPLE,4,041 ( 1,817.3 1,806.7 11.72 SHOE 45 DEGREE MULE SHOE 1.995 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc. Top Depth FISH,4,045 (TVD) Top Incl SLEEVE,4,045 Top(ftKB) (ftK8) (°) Description Comment Run Date 10(in) m, 3,257.0 3,231.6 1.55 PLUG WRP PLUG SET IN LONG TUBING STRING#1-TOPPED 10/23/2010 0.000 PACKER,4,048 BY CEMENT PLUG il 4,045.0 4,019.2 1.81 FISH 2.875"WRP 11/26/2009 0.000 !, It 4,732.0 4,706.0 0.58 FISH OTIS NIPPLE w/PXN PLUG W/O PRONG 11/5/1986 0.000 " 4,733.0 4,707.0 0.59 FISH 2.875"BLAST JOINTS&TUBING&BAKER SOS 11/5/1985 0.000 (PERF.-_. 4062.4211 Perforations&Slots Shot Top(TVD) Ben(TVD) Dans Top(MB)Btm(MB) (RKB) (MB) Zone Dab Shot Type Comment 3,305.0 3,325.0 3,279.6 3,299.5 STRLNG A,BRU 3/1/1986 8.0 IPERF Open,String 2,2 deg phase 211-03 (PERF,_ 3,363.0 3,412.0 3,337.5 3,386.5 STRLNG B,BRU 3/1/1986 8.0 IPERF Open,String 2,2 deg phase 4,376-1.402 211-03 3,536.0 3,580.0 3,510.5 3,554.4 STRLNG C,BRU 6/1/1994 4.O'APERF Open,String 2,2 deg phase;1-11/16" 211-03 oriented gun(no change in production or SITP) NIPPLE,4,466-- SLEEVE.4,467 3,614.0 3,640.0 3,588.4 3,614.4 STRLNG C,BRU 3/1/1986 8.0 IPERF Open,String 2,2 deg phase 211-03 PACKER.4.470 . 3682.0 3,876.0 3,656.4 3,850.3 BELUGA D,BRU 3/1/1986 8.O'IPERF OPEN,2 DEGREE PHASE 211-03 IPERF, ® 4,092.0 4,211.0 4,066.2 4,185.1 BELUGA E,BRU 3/1/1986 8.O'IPERF OPEN,2 DEGREE PHASE 4,512-4,725 211-03 FISH,4,732 11 4,378.0 4,402.0 4,352.1 4,376.1 BELUGA F,BRU 3/1/1986 8.0 IPERF OPEN,2 DEGREE PHASE 211-03 FISH,4,733 CMT SOZ, 5,040.5,060-Mll CMT SQZ,_ 5,675-5,745 MEI PRODUCTION, 328,003 N TD,6,003 - SAK BRU 211-03 ConocoPhillips di Alaska,Inc. CCM3 °""" KB-Grtl(R) Rig Release Date Well Conn,'-BRU 211alio--03,6/312013 12'.3256 PM 68.90 4/5/1986 SchemActual .a •� Slots HANGER.16 ! Perforations Top(TVD) Btm(TVD) SShot hot If Top(RKB)Ban(RED) (R B) (RKB) Zone Date (ah- Type Comment CONDUCTOR. 4,512.0 4,725.0 4,486.0 4,699.0 BELUGA F,BRU 3/1/1986 8.0 IPERF 'OPEN,1 DEGREE 16433 211-03 NIPPLE,605 11 5,040.0 5,060.0 5,014.0 5,034.0 BELUGA G,BRU 3/2/1986 1.0 CMT SQZ 8 PLUG,DST 2,0 degree -C ? 211-03 SQZ phase T NIPPLE 112,797 6675.0 6745.0 5,649.0 6719.0 BELUGA H,BRU 3/2/1986 a5 CMT SOZ 8 PLUG,DST 1,0 degree 211-03 SQZ phase NIPPLE gee d Notes:General&Safety End Date Annotation 11/5/2010 NOTE:VIEW SCHEMATIC w/Alaska Schemalic9.OREV SHOE,1,817 V SU1RF63,14ACE0, SLEEVE.3,254 CMT PLUG. 3,253 STINGER#2, 3,2571 PACKER,3,257-, PLUG, ,257— PLUG,3,257 :ra xi NIPPLE 42, 3,296 (\/rL IPERF, 4 ✓ ! 1 3.3053,325 P '�44e 3.3633. IPERF,412 3,5363,58 APERF0, EV IPERF, 3014-3,640 SLEEVE,3,666 PACKER,3,659 IPERF, 3,6923,876 1 I t 1 I NIPPLE.4.044 1� FISH.4.045 SLEEVE.4.045 PACKER,4.048 10.1- f 4,62PE4,211 IRF. _ • IPERF, 4,3784,402 I NIPPLE.4,466 SLEEVE 4,467-- PACKER,4,470 IPERF. 4,5124,725 _.. FISH.4.732 FISH,4,733 CMT SOZ, ;;�� 5,040-5,060-- ,®,,�,,.. s`, 5CMT S74S ifit PRODUDUCTIONCTION,, 32-6.003N TD,6003 r • ConocoPhillips Alaska 700 G Street Anchorage, Alaska 99501 May 24, 2012 RECEIVED MAY 2 5 2012 Alaska Oil and Gas Conservation Commission AOGCC 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner: Enclosed please find the Bureau of Land Management Form 3160 -5, Sundry Notices and Reports on Wells and Wellwork Summary Report attachment, for ConocoPhillips Alaska, Inc. Beluga River Unit 1$10-010 wel well 211-03. The documents are enclosed as a courtesy copy only. Sincerely, Jerry Dethlefs Vid.,.111N 0 6 2012 F.'> ;w yoqz • • Form 3160 -5 UNITED STATES FORM APPROVED (August 2007) OMB No. 1004 -0137 DEPARTMENT OF THE INTERIOR Expires: July 31, 2010 BUREAU OF LAND MANAGEMENT 5. Lease Serial No. A029656 SUNDRY NOTICES AND REPORTS ON WELLS 6. If Indian, Allottee or Tribe Name Do not use this form for proposals to drill or to re -enter an N/A abandoned well. Use Form 3160 -3 (APD) for such proposals. SUBMIT IN TRIPLICATE — Other instructions on page 2. 7. If Unit of CA/Agreement, Name and/or No. 1. Type of Well ❑ Oil Well m Gas Well 0 Other BRU 211-03 Name and No. 2. Name of Operator 9. API Well No. ConocoPhillips Alaska Inc 502832007900 3a. Address 3b. Phone No. (include area code) 10. Field and Pool or Exploratory Area 700 G Street, Anchorage, AK 99501 907 265 1464 Beluga River Unit 4. Location of Well (Footage, Sec., T.,R.,M, or Survey Description) 11. Country or Parish, State C -Pad, Section 4, T12, R10, M -S Kenai Peninsula, Alaska 12. CHECK THE APPROPRIATE BOX(ES) TO INDICATE NATURE OF NOTICE, REPORT OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION Notice of Intent ❑ Acidize ❑ Deepen El Production (Start/Resume) ❑ Water Shut -Off ❑ Alter Casing ❑ Fracture Treat ❑ Reclamation m Well Integrity Q Subsequent Report ❑ Casing Repair El New Construction ❑ Recomplete ❑ Other ❑ Change Plans ❑ Plug and Abandon ❑ Temporarily Abandon ❑ Final Abandonment Notice ❑ Convert to Injection ❑ Plug Back 0 Water Disposal 13. Describe Proposed or Completed Operation: Clearly state all pertinent details, including estimated starting date of any proposed work and approximate duration thereof. If the proposal is to deepen directionally or recomplete horizontally, give subsurface locations and measured and true vertical depths of all pertinent markers and zones. Attach the Bond under which the work will be performed or provide the Bond No. on file with BLM/BIA. Required subsequent reports must be filed within 30 days following completion of the involved operations. If the operation results in a multiple completion or recompletion in a new interval, a Form 3160 -4 must be filed once testing has been completed. Final Abandonment Notices must be filed only after all requirements, including reclamation, have been completed and the operator has determined that the site is ready for final inspection.) Beluga well BRU 211 -03 is a gas producer that has been shut -in due to tubing by annulus communication. Diagnostics show the short string had good integrity but the long string had penetrations both above and below the top packer This operation was to install a tubing plug in the long string to eliminate the communication above the top packer a allow well barriers to be tested A WRP plug was run into the long string and cement was dump bailed above it effectively eliminating the communication Subsequent tests show a passing MITIA and MITT on the short string the long string tubing plug is holding firm and the well is clear to be put back on production. See attached Wellwork Summary Report. 14. I hereby certify that the foregoing is true and correct. Name (Printed/Typed) Jerry Dethlefs 9"---4-"-11 Title Well Integrity Supervisor Signature Date 05/23/2012 THIS SPACE FOR FEDERAL OR STATE OFFICE USE Approved by Title Date Conditions of approval, if any, are attached. Approval of this notice does not warrant or certify that the applicant holds legal or equitable title to those rights in the subject lease which would Office entitle the applicant to conduct operations thereon. Title 18 U.S.C. Section 1001 and Title 43 U.S.C. Section 1212, make it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. (Instructions on page 2) • • ConocoPhillips Alaska, Inc. North Cook Inlet Unit The following is a recap of wellwork performed gas well BRU 211 -03 11/25/2011 RU LRS PUMP TO IA, PASSED IAxTUBING COMBO MIT, TUBING TRACKED IA, NOTIFIED PRODUCTION, JOB COMPLETE 11/11/2011 Rigged up and Ran SL into tag cement plug. Hard Tag encountered at 3253 SLMD, 4 feet of cement on top of WRP. Town Engineer called to consult about the amount of cement on the plug. Town stated this was enough to move forward with the IA test. Rigged up on the IA and PTed the lines, then pressure tested to 1000 psi on the IA. IA held 1000 psi for the duration of the 30 minute test. No draw down. Test passed, well freeze protected with glycol and turned back over to production. 11/10/2011 After a weather delay, CPAI rep and crew landed at BRU at 1200. After getting equipment rounded up and spotted on the pad, an ice plug was discovered in the LS at 1700. Well head was tented and a heater was routed into the well house and the well head was unthawed. At 2100 hours SL RIH and tagged the WRP at 3257' SLMD, and POOH. Cement was blended at 2300 and 4 dump bail runs were performed laying in approx 4 gallons of cement on top of the WRP. Unit laid back for the night, waiting on cement to set up before a tag run. Well Secured, Job in Progress 10/30/2011 RU BJ PUMPING UNIT AND BATCH MIXER, PUMP 45BBLS 40# HEC GEL DOWN LS, PUMP 45BBLS 40# HEC GEL DOWN SS, PUMP 12BBLS FRESH WATER IN TO IA AND BLEED TO OPSI, ALL PRESSURES @ 0, SHUTDOWN FOR NIGHT, IN PROGRESS 8/31/2011 DDT LS X IA ( FAILED), MIT -OA ( FAILED ) 8/19/2011 RIH with slickline to 3294' KB and latched the plug and prong. Removed plug out of the short string and Rigged up LRS to the OA. PTed OA to 1000 psi for 30 minutes, Recorded Results, MIT OA Pass. Rigged up on IA and PTed IA to 1000 psi for 30 minutes, pumped 110 bbls of fresh into the IA, Recorded Results, MIT IA Pass. 2 competent barriers tested. Well handed back to production to produce up the short string. Job complete. MIT OA Results MIT IA Results Pre MIT Pre MIT LS =425 psi LS =425 psi SS= 525 psi SS =525 psi IA= 417 IA= 417 psi OA= 0 OA =12 • • Initial Initial LS =425 psi LS= 1100 psi SS= 525 psi SS= 510 psi IA= 417 psi IA= 1021 psi OA= 1100 psi OA= 169 psi 15 Min 15 min LS =425 psi LS= 1150 psi SS= 525 psi SS= 510 psi IA= 417 psi IA= 1064 psi OA= 1100 psi OA= 159 psi 30 Min 30 min LS =425 psi LS =1150 psi SS= 525 psi SS =510 psi IA= 417 psi IA= 1095 psi OA= 1100 psi OA= 154 psi 8/18/2011 Ran in hole with a PDS 24 arm Caliper to 3285' SLMD and surveyed the Tubing, POOH at 50 fpm. Ran in and set a plug in the XN Profile at the bottom of the short string, 3296' KB. Pressure tested tubing to 1000 psi. Tubing Passed. Rig Down PWL and LRS for the evening. Job in Progress MIT Tubing Results: Pre MIT Tubing: 500psi IA: 450psi OA: 75psi Initial Tubing: 1000 psi IA: 420psi OA: 75psi 15 Min Tubing: 1000 psi IA: 420psi OA: 75psi 30 Min Tubing: 1000 psi IA: 420psi OA: 75psi 5/8/2011 RU LRS ON BRU- 211 -03 PUMPED 44 BBLS OF 3.3 PPB HEC -10 GEL DOWN SHORT STRING AT MINIMUM RATE. INITIAL PRESSURES; LONG STRING = 0 PSI, SHORT STRING = 190 PSI, IA = 0 PSI, OA = 0 PSI. FINAL PRESSURES WERE LONG STRING = 0 PSI, SHORT STRING = 125 PSI, IA = 0 PSI, OA = 0 PSI. JOB NOT COMPLETE. CONTINUING TO MONITOR PRESSURES IN AM. 5/7/2011 • • RU LRS ON BRU- 211 -03 PUMPED 44 BBLS OF 3.4 # /BBL HEC -10 GEL DOWN SHORT STRING AT MINIMUM RATE. INITIAL PRESSURES; LONG STRING = 0 PSI, SHORT STRING = 250 PSI, IA = 0 PSI, OA = 0 PSI. FINAL PRESSURES WERE LONG STRING = 0 PSI, SHORT STRING = 75 PSI, IA = 0 PSI, OA = 0 PSI. JOB NOT COMPLETE. CONTINUING TO MONITOR PRESSURES IN AM. 5/1/2011 Rigged up on 211 -03 and began pumping down the short string while bleeding off the IA. After pumping 172 bbls down the short string and the IA and short string reading 0, we rigged up on the long string. The long strings initial pressure was 550 psi before pumping down the short string but once we pumped down the short string it went on a vacuum. 170 bbls were pumped down the long string. All gauges read 0 psi well was monitored over night. Gauges remain at 0 psi. RDMO. Job complete and turned back over to the DSO 10/23/2010 MIRU HES E -line unit. RIH and set 2 7/8" Weatherford WRP @ 3260' mid - element. (Set in the middle of Baker HB dual string packer). TIFL/ draw -down test (FAILED). Bled IA from 570 down to 460 psi in 45 minutes (would not bleed further). LS tubing and ST tubing both tracked down w/ IAP. SI bleed and monitored pressure, WHP's returned to original start pressure in 6 minutes. 10/18/2010 Attempted injectivity test of OA up to 1500 psi, OA pressured up w/ 3 bbls of fluid, unable to pump into well to establish a steady injection rate. Well will not pass an MIT -OA. 10/9/2010 MIRU POLLARD W/L EQUIPMENT. RIH W/ 2.25" G -RING TO 3,800'WLM (3,816'RKB) DRIFT TBG FOR PDS SURVEY, NO PROBLEMS, POOH. RIH W/ PDS MPLT BHA TO 3,750' MD WHILE FLOWING STRING #2 @ 2.4 MMSCFD 560 PSI. MAKE PASSES @ 40,80,120 FPM FROM 3,000 TO 3,750'MD. MAKE STOPS @ 3,000', 3,100', 3,200', 3,300', 3,400', AND 3,740'MD. POOH. DRIFT TUBING TO WRP @ 4,056'RKB WITH 1.91" G- RING, NO PROBLEM, SECURE WELLHEAD, RDMO POLLARD. 7/28/2010 Attempt to fish out Weatherford WRP @ 4056'. Very sticky at depth, lost spangs temporarily. Attempted to straddle sticky location with 11' of 1.5" baited stem w/ pulling tool on bottom. Fish fell from 4056' to 4067' wlm. Baited stem stuck, decision made to leave fish, RDMO. 7/27/2010 Swedge open tight area w/ 2.25" swedge from 3816' - 3830 wlm. Found tubing damage from dropped cutter bar @ 4036' wlm, appears to be peeled tubing from LIB marks. Able to drift w/ 2.25" swedge. Called to have additional swedges sent from Kenai. LDFN 7/24/2010 MADE ONE ATTEMPT TO FISH WRP FROM 4042' SLMD WITH WEATHERFORD PULLING TOOL. LOST SPANGS AND JARS AFTER ONE HIT, ATTEMPT TO REGAIN TOOL ACTION BY WORKING WIRE (FAILED), DROPPED 1.25" CUTTER BAR (ALL WIRE RECOVERED), PICKED UP FISHING STRING AND WAS ABLE TO RECOVER STUCK STRING, LAY DOWN FOR THE NIGHT, RETURN IN THE AM. (IN PROGRESS) • • 7/23/2010 MADE SEVERAL ATTEMPTS TO FISH WRP @ 3266' KB, SHEARED 2 OUT OF 3 DAWGS ON WFT PULLING TOOL, ABLE TO PUSH WRP TO 4056' KB, ARRANGE FOR NEW PULLING TOOL FROM WEATHERFORD, LDFN, (IN PROGRESS) 7/22/2010 MADE THREE ATTEMPTS TO FISH WRP @ 3247' SLMD WITH WEATHERFORD PULLING TOOL, CONTINUED TO SHEAR PULLINH TOOL PIN WITH 5/16" HARDEND STEEL. LAY DOWN LUBRICATOR AND SECURE WELL. RETURN IN THE AM (IN PROGRESS) 7/4/2010 MIT -OA to 1000 psi failed. Initial OA FL @ 300' +/- caught fluid at 17 bbls away and OA started to pressure up. OA integrity broke down @ 400 psi and the OA bled down to 0 psi. OA caught pressure two more times but broke down each time, pumped a total of 28 bbls of diesel down the OA. Bled OAP back to 180 psi. 6/17/2010 T -POT ( FAILED ), T -PPPOT ( FAILED ), IC -POT ( PASSED ), IC -PPPOT ( PASSED ) 6/17/2010 MADE ADDITIONAL THREE RUNS TO FISH WEATHERFORD WRP @ 3,270'RKB WERE UNSUCCESSFUL. DECISION MADE BY TOWN ENGINEER (ART C.) TO ABORT S/L OPERATIONS, LEFT WRP @ 3,270'RKB. JOB COMPLETE. 6/1612010 MIRU POLLARD S/L UNIT. MADE TWO RUNS TO FISH WRP PLUG @ 3,276'RKB WERE UNSUCCESSFUL, RDFN, SECURE WELLHEAD, JOB IN PROGRESS. 6/15/2010 MIRU POLLARD S/L UNIT. MADE FIVE ATTEMPTS TO PULL 2.875" WEATHERFORD WRP @ 3,270'MD, WERE UNSUCCESFUL, SECURE WELLHEAD, RDMO POLLARD, WILL RETURN ANOTHER DAY TO FISH PLUG, JOB IN PROGRESS. 5/19/2010 Ran in hole w/2.30" GR set down about XN Sleeve ran bailer to see if fill not fill -ran LIB got impression of ? Found out on 11/26/09 A WRP was set 4/12/2010 WORK STRING DETAIL: (1 '1/2 ") RS, KJ, 15' Stem, KJ, OJ, Spangs DEBRIS LEFT IN HOLE: NONE SUMMARY OF WORK: Ran 1.70" GR to 3,357' WLM (3,373' KB) tagged fill. Ran Static BHP Survey to 3,290' KB STATE OF ALASKA ALASKAOL AND GAS CONSERVATION COMMISON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon l Repair w ell r Rug Perforations r Stimulate r Other wo Annular Solids Plug Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved R - ogram r Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: _ ConocoPhillips Alaska, Inc. Development J Exploratory ° ploratory 186 -010 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service f 50- 283 - 20079 -00 b 7. Property Designation (Lease Number): 8. Well Name and Number: ADLA- 029656 '� — BRU 211 - 9. Field /Pool(s): Beluga River / ' I lam. GAs 1 1_13 10. Present Well Condition Summary: Total Depth measured 6562 feet Plugs (measured) 3296 true vertical 6536 feet Junk (measured) 4045, 4732, 4733 Effective Depth measured 4992 feet Packer (measured) 3257, 3659, 4048, 4470 true vertical 4965 feet (true vertucal) 3232, 3634, 4022, 4444 Casing Length Size MD TVD Burst Collapse Conductor 97' 30" 97' 97' Surface 433' 20" 433' 433' Intermediate 3140' 13.375" 3140' 3114' Production 6003' 9.625" 6003' 5977' eu .. .,....,,,,, ,,, ,,, x. Kecelv Perforation depth: Measured depth: see attached list , (` True Vertical Depth: , O yY►MtS 6 fS6 t (d %' potiOtage Tubing (size, grade, MD, and ND) 2.875, 2.375, N -80, 4759', 3297' MD, 4733', 3272' TVD Packers & SSSV (type, MD, and ND) 4 Baker 'HB' Dual Packers @ 3257, 3659, 4048, 4470 NO SSSV 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut -in Subsequent to operation shut - 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development R7 0 Service r Stratigraphic 1- 15. Well Status after work: Oil r Gas` r.7 WDSPL F Daily Report of Well Operations XXX GSTOR F WINJ F WAG F GINJ F SUSP F SPLUG F 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Jerry Dethlefs Ca 265 -1464 Printed Name Jerry Dethlefs Title Well Integrity Director Signature L j Phone: 265 -1464 Date ///_57/a / J RBDMS JAN 13 2012 / /.i3./ Form 10-404 Revised 10/2010 Submit Original Only odie '.,/}---- BRU 211 -03 Well Work Summary DATE SUMMARY Beluga well BRU 211 -03 is a gas ducer that has been shut -in due to tubingOannulus communication. Diagnostics show the short string had good integrity but the long string had penetrations both above and below the top packer. This operation was to install a tubing plug in the long string to eliminate the communication above the top packer a allow well barriers to be tested. A WRP plug was run into the long string and cement was dump - bailed above it, effectively eliminating the communication. Subsequent tests show a passing MIT -IA and MIT -T on the short string, the long string tubing plug is holding firm, and the well is clear to be put back on production. 11/10/11 At 2100 hours SL RIH and tagged the WRP at 3257' SLMD, and POOH. Cement was blended at 2300 and 4 dump bail runs were performed laying in approx 4 gallons of cement on top of the WRP. Unit laid back for the night, waiting on cement to set up before a tag run. Well Secured, Job in Progress 11/11/11 Rigged up and Ran SL into tag cement plug. Hard Tag encountered at 3253 SLMD, 4 feet of cement on top of WRP. Rigged up on the IA and PTed the lines, then pressure tested to 1000 psi on the IA. IA held 1000 psi for the duration of the 30 minute test. No draw down. Test passed, well freeze F 4_ . Q(- protected with glycol and turned back over to production. 11/25/11 RU LRS PUMP TO IA, PASSED IAxTUBING COMBO MIT, TUBING TRACKED IA, NOTIFIED PRODUCTION, JOB COMPLETE 1 • j a BRU 211 -03 A600PI# 50- 283 - 20079 -00 1 } { } 2x { HA ConocoPhillips i l Gas Producer Annulus Fluid: Diesel �B Bua /Comp, Heater String Max Hole Angle: 12.7° @ 1,' Spud Date 2/20/86 Sect. 3, T12N, R1OW, NW 1/4 (BHL) RKB to Ground: 16.1' Last Completion 4/5/86 (71c ei ASP @ Beluga: 2,619,687; 315,825 RKB to SL: 103.' Schematic Rev. 6/30/04 ■ id [ 2 y 3t' CASING & TUBING Hole by TDT le Description OD Btm. Weight Grade Thread Size Cement } { 2z Surface Csg. 20" 433' 133 # /94 #K- 55/H -40 Buttress 26" 475sx "G ". Rtns to surface. if I A Intermediate 13 3/8" 3,140' 68. # K -55 Buttress 17 1/2" 2030sx "G ". Rtns to surface. B Prod. Casing 9 5/8 6,003' 47 #/43.5# S -95 Buttress 12 1/4" 1130sx "G" @shoe. Non surf B Heater String 2 3/8" 1,819' 4.7 # N -80 Buttress Prod. Tbg. 2 2 7/8" 3,297' 6.5 # N -80 EUE 8rd Prod. Tbg. 1 2 7/8" 4,501' 6.5 # N -80 EUE 8rd * Tubing cut @ 4501. * Str. Lbl. Top JEWELRY& FISH Length ID OD H A 605' "XN" Nipple, Otis 1.05' 1.791" 3.063" lg I 1 j'94 H B 1,817' 45° Mule Shoe 1.80' 1.995" 3.063" lh [] [] 2 x 797' "X" Nipple, Otis 1.05' 2.313" 3.668" 11 Y 2 y 3,257' Stab -in stinger, Baker 0.67' 2.50" 3.375" 1j D 2 z 3,295' "XN" Nipple, Otis 1.05' 2.205" 3.668" D All a 16' Tbg. Hanger w/ Butt to 8rd XO for Strings 1& 0.79' 1.91 "/2.313" D 1 b 988' "X" Nipple, Otis 1.06' 2.313" 3.668" 1 c 3,253' Safety Jt, Baker "CC" 1.40' 2.438" 3.375" 1 d 3,254' SS -XA Sliding Sleeve, Otis "XA" Nipple 3.20' 2.31" 3.668" lk I E 1 e 3,257' Pkr Packer, Baker "HB" Dual, 40k release 7.09' 2.441" 8.28" 1 f 3,297' Blast Joint, 2 -7/8" 119.' 2.441" 3.675" 1 g 3,597' Blast Joint, 2 -7/8" 59.' 2.441" 3.675" 1 h 3,656' SS -XA Sliding Sleeve, Otis "XA" Nipple 3.19' 2.313" 3.668" 1L } { 1 i 3,659' Pkr Packer, Baker "HB" Dual, 40k release 8.51' 2.441" 8.28" lm p 0 1 j 3,668 Blast Joint, 2 -7f8' 119? 2.441" 3.675" In 1 k 3,848' Blast Joint, 2 -7/8" 40.' 2.441" 3.675" to I Ei NOTE: Tbg leak below 4044' discovered 6/9/86. 1 L 4,044' "X" Nipple, Otis 1.06' 2.313" 3.668" 1 m 4,045' SS-XA Sliding Sleeve, Otis "XA" Nipple 3.17' 2.313" 3.668" 1p I ] 1 n 4,048' Pkr Packer, Baker "FIB ", 40k release 8.51' 2.441" 8.28" 1 o&p 4,087' & 4,200' Blast Joint, 2 -7/8" 19.79' 2.441" 3.675" 1 q 4,374' Blast Joint, 2 -7/8" 30.' 2.441" 3.675" 1 r 4,466' "X" Nipple, Otis 1.05' 2.313" 3.668" 1 s 4,467' SS-XA Sliding Sleeve, Otis "XA" Nipple 3.17' 2.313" 3.668" lq _I E 1 t 4,470' Pkr Packer, Baker "HB ", 40k release 8.51' 2.441" 8.28" it } { Cut tbg. 4,732' FISH Nipple, Otis w/ PXN plug w/o prong 11/5/86 1.05' 3.668" is [] [][] 4,733' FISH 2 -7/8" Blast Joints & tubing & Baker shear sub 247.' 2.441" 3.675" It C Pressure Datum: Sterling 3450' 5S: 3,579'MD Beluga 4000' SS: 4,129'MD TT @ 4501' PERFORATIONS, FILL & PLUGS Net Incline E Zone MD SS Depth Status Date SPF Ft. Mole A 3305' - 3325' 3177' - 3197' Open, Str. 2 03/86 8 20' 2° B 3363' - 3412' ' - ' Open, Str. 2 03/86 8 49' 2° C 3536' - 3580' 3407' - ' Open, Str. 2 06/94 4 26' 2° C 3614' - 3640' 3485' - 3511' Open, Str. 2 03/86 8 26' 2° E D 3682' - 3876' 3553' - 3747' Open 03/86 8 2° 4732' Cut tbg E 4092' - 4211' 3963' - 4082' Open 03/86 8 2° F 4378' - 4402' 4249' - 4273' Open 03/86 8 2° 4992' F 4512' - 4725' 4383' - 4596' Open 03/86 8 10 % -- ;", .:,;M-', i PLUG 4,992' 4,863' EZSV at 4992', sqz w/ 50sx below 1° G 5040' - 5060' 4911' - 4931' Sqzd & plugged. DST 2 03/86 1 1° PLUG 5,620' 5,491' Howco EZSV at 5620', sqz w/ 50sx below 03/86 0° H 5675' - 5745' 5546' - 5616' Sqzd & plugged. DST 1 03/86 0.5 0 5620' TAGS Str 2 6/14/94 3632'WLM Scallop gun, no tag. Str 1 2/12/03 4980'RKB 1.75" Bailer z f/Af .0 `= W ed 6/3/93 4981'RKB 1.75" Bailer 0 f. Jun - Unable to pull plug in XN. Tbg leaking above. Set plug In X Nipples © 4466' then 4045'. Determine leak below 4044'. v1 Nov Unable to pull plug in XN nipple w/ WL or CTU. Cut tbg. Tag top of fish at 4732'. PBTD 6462' e.., Oct -87 300 -400 psi in 9x13 csg annulus. Source of gas Sterling A. 13 3/8" shoe @ 3140', top of A @ 3121', CET showed no cmt over sh FC commgm,I. Jun -94 Per?d upper C sand with 1- 11/16" oriented gun. Gun wet & severely split. No change In produdton or SITP. SAK BRU 211 -03 . . ConocoPhillips 141 Well Attributes ax Angle & MD TD Wel!bore API /UWI Field Name Well Status Ind (°) MD (ftKB) Act Btm (ftKB) 502832007900 BELUGA RIVER UNIT PROD 12.68 1,600.00 6,003.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' _ SSSV: NIPPLE Last WO: 68.90 4/5/1986 Well Conan - BRU 211 -03. 8 21/20115.0921 PM Schematic - Actual Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: ADD NIPPLE AND REVISE ID'S ninam 8/21/2011 Casing Strings HANGER, 16 J IL `J, Casing Description String 0... String ID ... Top (ft(B) Set Depth (f.. Set Depth (TVD) ... String Wt... String ... String Top Thrd I SURFACE 20 18.730 16.0 433.0 433.0 133.00 K - 55 BUTT Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd INTERMEDIATE 133/8 12.415 16.0 3,140.0 3,114.6 68.00 K - 55 BUTT NIPPLE, 16 Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE, PRODUCTION 95/8 8.681 32.0 6,003.0 5,977.0 47.00 S - 95 Butt 16433 l I Tubing Strings Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd NIPPLE,605 jf TUBING2 3.668 I 2.875 I 16.0 I 3 I 3,271 I I I EUE -8 RD Completion Details I Top Depth (TVD) Top Incl Noml... NIPPLE, 791 Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 16.0 16.0 0.00 NIPPLE OTIS 'X NIPPLE 2.313 791.0 791.0 0.93 NIPPLE OTIS 'XN' NIPPLE 2.205 NIPPLE, 988 3,257.3 3,231.8 1.55 STINGER BAKER STAB -IN STINGER 2.441 I 3,296.0 3,270.5 1.57 NIPPLE OTIS'XN' NIPPLE 2.205 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SHOE, 1,817 TUBING 1 2 7/8 2.441 16.2 4,759.0 4,733.0 6.50 N -80 EUE -8 RD Completion Details Top Depth NTERMEDIATE, (TVD) Top Inc' Nomi... 183,740 Top (ftKB) (ftKB) (1 Item Description Comment ID (In) oll 162 16.2 0.00 HANGER TUBING HANGER 2.313 1 988.0 987.9 0.91 NIPPLE OTIS 'X NIPPLE 2.313 SLEEVE, 3,254 3,252.9 3,227.4 1.55 SAFETY JT BAKER SAFETY JOINT 2.441 3,254.0 3,228.5 1.55 SLEEVE OTIS SLIDING SLEEVEw/ OTIS 'XA' NIPPLE ' 2.310 STINGER, AM.' 3,257.2 3,231.7 1.55 PACKER BAKER 'HB' DUAL PACKER 40K RELEASE 2.441 4=.1 3,297.3 3,271.8 1.57 BLASTJT 2.441 WRP, 3,260 3,597.3 3,571.7 2.08 BLASTJT 2.441 PACKER, 3,257 i 3,656.3 3,630.6 2.00 SLEEVE OTIS SLIDING SLEEVEw/ OTIS 'XA' NIPPLE 2.313 i- i 3,659.4 3,633.8 1.99 PACKER BAKER '14B' DUAL PACKER 40K RELEASE 2.441 3,668.0 3,642.3 1.98 BLAST JT 2.441 ®- 3,848.0 3,822.2 1.71 BLASTJT 2.441 NIPPLE, 3,296 ) PLUG, 3,296` `I ��l 4,043.8 4,017.9 1.81 NIPPLE OTIS 'X' NIPPLE 2.313 . 4,044.8 4,019.0 1.81 SLEEVE OTIS SLIDING SLEEVEw/ OTIS 'XA' NIPPLE 2.313 (L_ 4,048.0 4,0222 1.81 PACKER BAKER 'HB' DUAL PACKER 40K RELEASE 2.441 LN 4,087.4 4,061.6 1.86 BLASTJT 2.441 4,2002 4,174.3 1.33 BLASTJT 2.441 4,374.0 4,348.0 1.15 BLAST JT 2.441 Il ) 4,465.8 4,439.8 0.81 NIPPLE OTIS 'X' NIPPLE 2.313 SLEEVE, 3,656 4,466.8 4,440.9 0.80 SLEEVE OTIS SLIDING SLEEVEw/ OTIS 'XA' NIPPLE 2.313 EN 4,470.0 4,444.0 0.79 PACKER BAKER 'HB' DUAL PACKER 40K RELEASE PACKER, 3,659 .c Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I I I I HEATER STRING 23/8 1.995 605.0 1,819.0 1,808.4 4.70 N -80 Butt Completion Details Top Depth (TVD) Top Inc! Nom'... Top (coca) Voce) ( °) Item Description Comment ID (in) i 605.0 604.9 0.56 NIPPLE OITIS'XN' NIPPLE 1.791 1,817.2 1,806.6 11.72 SHOE 45 DEGREE MULE SHOE 1.995 NIPPLE,4,044 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth FISH, 4.045 (TVD) Top Inc! Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) SLEEVE, 4,045 3,260 3,234.6 1.55 WRP WRP PLUG SET IN LONG TUBING STRING #1 10/23/2010 0.000 3,296 3,270.5 1.57 PLUG PLUG IN XN PROFILE @ BOTTOM OF SHORT STRING 8/18/2011 0.000 PACKER,4,048 1881741=.9. 4,045 4,019.2 1.81 FISH 2.875 "WRP 11/26/2009 0.000 4,732 4,706.0 0.58 FISH OTIS NIPPLE w/PXN PLUG W/O PRONG 11/5/1986 0.000 � 4,733 4,707.0 0.59 FISH 2.875" BLAST JOINTS 8 TUBING 8 BAKER SOS 11/5/1985 0.000 I LJ 1 Notes: General & Safety End Date Annotation 11/52010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.OREV I l I I ® _ NIPPLE. 4.466 - - a,- SLEEVE, 4,467 PACKER, 4,470 a l FISH, 4,732 VP 1 FISH, 4,733 -- --• PRODUCTION, 32-6,003 TD,6,003 TRANSMITTAL Be/uga River Unit deve%pment we//data FROM: Sandra D. Lemke, AT01808 TO: Christine Shartzer ConocoPhillips Alaska, Inc. State of Alaska P.O. Box 100360 AOGCC Anchorage AK 99510-0360 333 W. 7"' Ave, Suite 100 Anchorage, Alaska 99501-3539 RE: Beluga River Unit production logging DATE: 08/16/2010 Cook Inlet, Alaska BRU224-13 (permit 173-037-0} ~~ l ~ Proactive Diagnostic Services, Multi-finger caliper report and 3D data and viewer; 8/28/2007 ,~(~roactive Diagnostic Services, Production profile; 7/18/2008 U 211-03 (permit 186-010-0) ~ pp ~ ~ active Diagnostic Services, u ti-finger caliper report and 3D data and viewer; 6/4/2008 ~roactive Diagnostic Services, Gas Entry Survey; 6/5/2008 BRU 212-35T (permit 198-161-0) ~G(j (~. i~ Proactive Diagnostic Services, Production profile; 7/17/2008 ~. BRU 212-24 (permit 172-015-0) ~t~~ (o Proactive Diagnostic Services, Multi-finger caliper report and 3D data and viewer; 9/22/2005 BRU 243-34 (permit 208-079-0} ~~O c~ d t~ Proactive Diagnostic Services, Production profile; 9/2/2008 scare and CC: Art Co I s, Geologist Receipt: transmi~ai pia e-aeaa/l to ~~e a-ra~ar/address Date: ~.~.Q r~- r, 6 `~; vIa-ie~:~:.~rca1 data ~?an eno ~~~J~e, ,Aiaska ~ Ph..~13~?~.~ ~'7 Sandra.D,LemkeCa~eonocophi/lips com • ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 3, 2010 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: • ~~~~~~Q ;~~ i; a 201~J ~taska t~! ~ has Cam. Cession ~~C~~rage ~~ 1~ (; r~ ~ {~ ~ ~ 1 Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. Beluga River Unit we11211-03 PTD 186-010 for continued production with known tubing by production casing communication. Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, s `-~~ ~` ~ 1V~J Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMIS APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Pf'rforate New Pool ("' Repair w ell r Change Approved Program Suspend r Rug Ft'rforations r Phrforate r Pull Tubing r Time Exten '"n r Operational Shutdow n r Re-enter Susp. Well r Stimulate Alter casin r g r- Other: Flow well w xIA cal 2. Operator Name: 4. Current Well Class: 5. Permit to Drill ber: ConocoPhillips Alaska, Inc. Development ~ . Exploratory r' 186-010 3. Address: Stratigraphic ~'" Service 6. API Num r: P. O. Box 100360, Anchorage, Alaska 99510 -283-20079-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r BRU 211-3 9. Property Designation: 10. Field/Pool(s): ~ /~lf~t1~' ~ ~~~ ADL A-029656 Beluga River - St ' ~'~~ /C< 11. PRESENT WELL CONDITION SUMMA Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (mea red): Junk (measured): 6562. 6536 • 4992' 4965' 499 ', 5620' 4732', 4733' Casing Length Size MD TVD Burst Collapse Conductor g7' 30" g7' 97' Surface 433' 20" 433' Intermediate 3140' 13-3/8" 1 3114' Production 6003' 9-5/8" 5877' Perforation Depth MD (ft): Perforation Depth D Tubing Size: Tubing Grade: Tubing MD (ft): see list attached see list attached 2-7ia", 2-7ia"s~ 2-sis" N-80 aso~', szs~, & ials' Packers and SSSV Type: ack S ( and TVD (ft) 4 Baker'HB' packers 3 D, 4 48' MD, 4470' MD no SSSV 12. Attachments: Description Summary of Proposal 13. Well Class fter proposed work: Detailed Operations Program r BOP Sketch E~loratory r Development r Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/15/201 Oil r Gas r WDSPL (- Suspended r 16. Verbal Approval: Date: WINJ ~ GINJ ~ WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and orre to the best of my knowledge. Contact: Perry Klein/ MJ Loveland @ 759-7043 Printed Name MJ LOVeland ~ ~'~~ Title: NSK Well Integrity Supervisor Signature ~~~-.*~~~~~ Phone: 659-7043 Date ~~~t~j l(~ C mmi i n nl Sundry Number:~D~~(~ `` ``ff Conditions of approval: No ' Commission so that a representative may witness OO Plug Integrity r' P Test r Mechanical Integrity Test r Location Clearance r Other: ~~ ~ ~~~ iJ $~` ~ ~ ~ ~ Z ~ 1 Subsequen orm Required: I~ska irk! ~c Gays Cer-~. C>issi APPROVED BY ;~tf'if:~l~rc~~~ Approved by: COMMISSIONER THE COMMISSION Date: ~ ~ ~~~'~ Form 10-403 ReiD~'r~ Au~ ~ 6 z0'a 0 R { G I N A L Submit in Duplicate C~ BRU 211-03 pertorations PTD 186-010 MD TVD 3305'- 3325' 3279'-3299' 3363'-3412' 3337'-3386' 3536'-3580' 3510'-3554' 3614'-3640' 3588'-3614' 3682'-3876' 3656'-3850' 4092'-4211' 4066'-4185' 4378'-4402' 4351'-4375' 4512'-4725' 4486'-4699' • • • ConocoPhillips Alaska, Inc. Beluga River Well 211-03 (PTD 186-010) SUNDRY NOTICE 10-403 APPROVAL REQUEST August 2, 2010 Purpose This application for Sundry approval for Beluga River Unit well 211-03 (PTD 186-010) is for the continued operation of the well with long string tubing by production casing communication for a time period not to exceed 2 years or until a rig or non-rig workover can be planned and successfully executed. This is similar to the annular flow approvals for wells in this area where the flowing tubing pressure will be contained by the production casing. Beluga River Unit well 211-03 (PTD 186-010) was drilled and completed in 1986 as a gas producer. In May 2008 long string tubing leaks were reported to the AOGCC. Subsequent two years of active diagnostics indicated multiple leaks from a suspected cause of sand erosion in the long string at various depths above and below the top packer. It is also possible the packer is leaking around he long string; however this has not been confirmed. The reservoir pressure is less tha~'.700 si and can easily be killed with a diesel gradient or any un-weighted fluid. Normal op,_ ing pressures for this well are: Tubing/ Inner Annulus /Outer annulus = 510/580/0 ~ psi. There are too many tubing leaks to effectively patch therefore a rig workover or non-rig repair is required. This Sundry approval is for the interim time between now and when a repair can /: effectively be executed CPAI is currently actively pursuing anon-rig repair in 2010 and a rig repair if needed and economically justifiable in 2011 or 2012, contingent on approvals from all BRU working interest owners, additional evaluation, and results of non-rig repairs. If neither the repair or the workover are successfully executed within the time period of this sundry then the well would be shut-in and secured upon expiration of the sundry. -~ One non-rig repair option being investigated is to set a plug in the long string at the top packer and flow the well entirely up the short string. This work will take several months to execute. Due to possible packer leak and the location of the leaks in the long string above and below the packer, sealing off the long string may not be achieved. However if it is achieved ConocoPhillips would close the Sundry as the well would then have full integrity through the short string. Barrier and Hazard Evaluation Tubing: The 2-7/8" 6.5# N-80 long string tubing to the Beluga formation does not have integrity to the top packer @ 3257' due to multiple leaks. The 2 7/8" short string tubing to the Sterling formation has integrity to the top packer based on an MIT conducted 6/4/2008. The 2 3/8" heater string tubing is open ended above the packer at 1819'. Production casing: The 9 5/8" 47# and 43.5# N-80 production casing has integrity to the top ~ packer @ 3257' MD based upon 500 psi differential pressure between the production casing and the intermediate casing. The 47# production casing has an internal yield rating of 6870 psi and the 43.5# casing has an internal yield of 6330 psi. Intermediate casing: The 13 3/8" 68# S-95 intermediate casing has integrity based upon the / passing a negative pressure (draw down) test with 500 psi differential between the production casing and intermediate casing completed 7/8/2010. A positive pressure test is not possible due to the lack of a cement shoe in the casing annulus. However the annulus holds a column of • kill weight fluid, which would leak off if there were integrity issues in the casing. The 68# casing has an internal yield of 5970 psi. Surface casing: The well is completed with 20" 133# K-55 & 94# H-40 surface casing in the upper portion of the hole with an internal yield pressure rating of 3060 & 1530 psi. The surface casing is set at 433' MD and was cemented to surface. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the production casing. Second barrier: The intermediate casing which extends below the top of the Sterling formation is the secondary barrier should the production casing fail. Third barrier: The surface casing is the tertiary barrier should both the production casing fail and the intermediate casing fail. Monitoring: Each well is monitored daily for wellhead pressure changes. Any deviations from current annular pressure trends require investigation and corrective action, up to and including a shut-in and kill of the well. Proposed Operating and Monitoring Plan 1. Well will be produced from the long string and the short string with known leaks in the long string tubing above the top packer. 2. Monitoring Well Head pressures daily and record data for trending. 3. Completing Quarterly outer annulus fluid levels to ensure KWF is maintained in the production casing by intermediate casing annulus. 4. The well will be shut in should the mechanical condition change and the AOGCC will be notified. 5. Successfully execute a rig workover or a non rig repair within 2 years or shut-in and secure well upon expiration of the sundry and re apply for AOGCC Sundry approval for continued operations. H A 605' "XN" Nipple, Otis 1.U5' >../91" S.UbS" H B 1,817' 45° Mule Shoe 1.80' 1.995" 3.063" 2 x 797' "X" Nipple, Otis 1.05' 2.313" 3.668" 2 y 3,257' Stab-in stinger, Baker 0.67' 2.50" 3.375" 2 z 3,295' "XN" Nipple, Otis 1.05' 2.205" 3.668" All a 16' Tbg. Hanger w/ Butt to 8rd XO for Strings 181: 0.79' 1.91"/2.313" 1 b 988' "X" Nipple, Otis 1.06' 2.313" 3.668" 1 c 3,253' Safety Jt, Baker "CC" 1.40' 2.438" 3.375" 1 d 3,254' SS-XA Sliding Sleeve, Otis "XA" Nipple 3.20' 2.31" 3.668" 1 e 3,257' Pkr Packer, Baker "HB" Dual, 40k release 7.09' 2.441" 8.28" __ - ___ _ ___ 1 f __ 3,297' - -- Blest Joint, 2-7%8"~------------------------------- --119.'--- -- 2.441"-- 3.675" - 1 g 3,597' Blast Joint, 2-7/8" 59.' 2.441" 3.675" 1 h 3,656' SS-XA Sliding Sleeve, Otis "XA" Nipple 3.19' 2.313" 3.668" 1 i 3,659' Pkr Packer, Baker "HB" Dual, 40k release 8.51' --~ ~--~------~----------~-~--- 2.441" 8.28" ~--- --~ -- ____ __- 1 j __ _ 3,668' ~ --~------ Blast Joint, 2-7%8'`------- 119.` 2.441r' 3.675'' 1 k 3,848' Blast Joint, 2-7/8" 40.' 2.441" 3.675" NOTE: Tbg leak below 4044' discovered 6/9/86. 1 L 4,044' "X" Nipple, Otis 1.06' 2.313" 3.668" 1 m 4,045' SS-XA Sliding Sleeve, Otis "XA" Nipple 3.17' 2.313" 3.668" 1 n 4,048' Pkr Packer, Baker "HB", 40k release 8.51' 2.441" 8.28" 1 o&p 4,087' & 4,200' Blast Joint, 2-7%8" 19.79' 2.441" 3.675" 1 q 4,374' Blast Joint, 2-7/8" 30.' 2.441" 3.675" 1 r 4,466' "X" Nipple, Otis 1.05' 2.313" 3.668" 1 s 4,467' SS-XA Sliding Sleeve, Otis "XA" Nipple 3.17' 2.313" 3.668" 1 t 4,470' Pkr Packer, Baker "HB", 40k release 8.51' 2.441" 8.28" Cut tbg. 4,732' FISH Nipple, Otis w/ PXN plug w/o prong 11/5/86 1.05' 3.668" 4,733' FISH 2-7/8" Blast Joints & tubing & Baker shear sub 247.' 2.441" 3.675" Pressure Datum; Sterling 3450' SS: 3,579'MD Beluga 4000' SS: 4,129'MD PERFOR.4TIONS~ FILL & PLUGS Net Incline Zone MD SS Depth Status Date SPF Ft. Angle A 3305' - 3325' 3177' - 3197' Open, Str. 2 03/86 8 20' 2° B 3363' - 3412' - Open, Str. 2 03/86 8 49' 2° C 3536' - 3580' 3407' - ' Open, Str. 2 06/94 4 26' 2° C 3614' - 3640' 3485' - 3511' Open, Str. 2 03/86 8 26' 2° s ConocoPhillips ,Gas Producer Dua/ Comp, t Heater String Sect. 3, T12N, R10W, NW 1/4 (BHL) ASP @ Beluga: 2,619,687; 315,825 CASING & TUBING BRU 211-03 API# 50-283-20079-00 Annulus Fluid: Diesel Max Hole Angle: 12.7° @ 1,600' Spud Date 2/20/86 RKB to Ground: 16.1' Last Completion 4/5/86 RKB to SL: 103.' Schematic Rev. 6/30/04 lyo% by TDT Description OD Btm. Weight Grade Thread Size Cement Surface Csg. 20" 433' 133#/94# K-55/H-40 Buttress 26" 475sx "G". Rtns to surface. Intermediate 13 3/8" 3,140' 68. # K-55 Buttress 17 1/2" 2030sx "G". Rtns to surface. Prod. Casing 9 5/8 6,003' 47#/43.5# S-95 Buttress 12 1/4" 1130sx "G"@shoe. Non surf Heater String 2 3/8" 1,819' 4.7 # N-80 Buttress Prod. Tbg. 2 2 7/8" 3,297' 6.5 # N-80 EUE 8rd Prod. Tbg. 1 2 7/8" 4,501' 6.5 # N-80 EUE 8rd * Tubing cut @ 4501. Str. Lbl. Top 1EWELRY& FISH Length ID OD F 4378' -4402' 4249' - 4273' Open 03/86 8 2° ----------------------~------------------------------------------------------------------------------------------------ o -• F 4512' - 4725 4383' - 4596' Open 03/86 8 1 PLUG 4,992' 4,863' EZSV at 4992', sqz w/ 50sx below 1° G 5040' - 5060' 4911' - 4931' Sqzd 8t plugged. DST 2 03/86 1 1° PLUG 5,620' 5,491' Howco EZSV at 5620', sqz w/ 50sx be low 03/86 0° H 5675' - 5745' 5546' - 5616' Sqzd ~ plugged. DST 1 03/86 0.5 0° TAGS Str 2 6/14/94 3632'wLM Scallop gun, no tag. Str 1 2/12/03 4980'RKB 1.75" Bailer 6/3/93 4981'RKB 1.75" Bailer Jun-86 Unable to pull plug in XN. Ttg leaking above. Set plug in X Nipples ~ 4466' then 4045'. Determine leak bebw 4044'. Nov-86 Unable to pull plug in XN nipple w/ WL or CTU. Cut tbg. Tag top of fish at 4732'. Oct-87 300-400 psi in 9x13 csg annulus. Source of gas Sterling A. 13 3/8" shoe @ 3140', top of A @ 3121', CEi showed no cmt over sh Jun-94 PerPd upper C sand with 1-11/16" oriented gun. Gun wet & severely split. No change in producitOn or S1TP. Page 1 of 1 Aubert, Winton G (DOA) From: NSK Well Integrity Proj (N1878~conocophillips.com] Sent: Monday, August 16, 2010 8:50 AM To: Aubert, Winton G (DOA) Subject: Retraction of Sundry request to produce Beluga River wells 211-03 (PTD 186-010), and 224-23 {PTD 184-137) Winton, Per our conversation 8/6/2010 regarding the 10-403 sundry request to produce Beluga River wells 211-03 (PTD 186-010), and 224-23 (PTD 184-137} CPAI would like to formally retract our request for sundry approval to operate the wells with tubing by inner annulus communication. The reservoir has a pressure of less then 700 psi and is incapable of building pressures in excess of those specified in the Sustained Pressure Guidelines Conservation Order # 506 (2000 psi and 1000 psi in the inner and outer annulus respectively). As discussed there is nothing for the State to give sundry approval for at this point in time thus the there is no requirement fora 10-403 sundry approval to produce wells 211-03 and 224-23. CPAI will continue to monitor and report on the wells as per Alaska Administrative Cade 25 and CO #506. Sincerely, Perry Klein Well Integrity Projects Supervisor 907-659-7043 8/15/2010 Lvaubu i~avvi vain ~.i a-~ \; ~ Regg, James B (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, May 15, 2008 1:39 PM To: Regg, James B (DOA) Subject: FW: Beluga River Unit 211-3 ~ 1°C~--CiIO ia~clvtt From: Braden, John C [mailto:John.C.Braden@conocophillips.com] Sent: Thursday, May 15, 2008 12:23 PM To: Maunder, Thomas E (DOA) Cc: Ennis, J J; NSK Problem Well Supv; NSK Well Integrity Field Supv; Walters, Martin N.; Jepsen, J Scott; Clark, Lindsey L; BRU Supv; Pollard, Donald W Subject: Beluga River Unit 211-3 ~~AIVIVEi~ ib1~Y ~ ~ 200$ Tom- Well BRU 211-3 (permit #1860100, API# 502832007900) appears to have communication between String #1 and the inner annulus. Diagnostics are under way. String #1 is shut-in with~a-PX ('lug at 3254'MD; the sliding sleeve is closed. We are waiting on results of a temperature log. The foruv~~~ j~j;~rwi,~;to run a caliper log to evaluate options for patching the leak. Please let me know if you have any questions. Sincerely, John C. Braden Cook Inlet Development ConocoPhillips Alaska, Inc. (907} 263-4536 phone (907} 265-1441 fax john.c.braden@conocophillips.com 5/ 15/2008 MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE AOGCC PACKING SLIP One box contains' BRU 224-3¢- '~mal Neutron Decay Log (TDT-P) Tape, Sepia, Blueline Print ~)L/ '~N~t~ating Record ~"'U,' Sepia, Blueline Print BRU 232-~6 ,~"h~ Tape, Sepia, Blueiine Print al Neutron Decay Log (TDT-P) ~.,~L Tie-In Log ~ Sepia, Blueline Print ~mal Neutron Decay Log (TDT-P), ~ape, Sepia, B,ue,,ne Print y~/ /~~~forating Record ~~lJ'~' ~' S~~~liU~t~Print,... ' 7594' ' ~las.~ Oil & 6as Cons. Commissicn BRU 21 2-24 mal Neutron Decay Log (TDT-P) _~.ape, bepla, Blueline Print ¢ t~~er Fl°w L°g (WFL) V~¢ ~ ~ Tape, Sepia, Blueline Print O.e rints ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 27g-1433 TELECOPY: (907) 276-7542 July 26, 1994 Mark H Wittow Preston Gates & Ellis 420 L St Ste 400 Anchorage, AK 99501-1937 Re: Z-Energy Spacing Exception Request Dear Mr Wittow: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River-Unit 22,~-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficient. jo/rpc~z-energy ALASKA OIL AND GAS · CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 Paul Craig, President Z-Energy Inc 2900 Boniface Pkwy #610 Anchorage, AK 99504-3132 Re: Z-Energy Spacing Exception Request Dear Mr Craig: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 2t2-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open hOle well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a wdtten submission would be insuffic~'~.~___.~~ Chairman ~ jo/rpc~z-energy ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 Rosanne M Jacobsen, Atty ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Z-Energy Spacing Exception Request Dear Ms Jacobsen: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit' 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. if you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficient. David W Joi~nston \ .-'-- ~ Chairman ~ jo/rpc~z-energy ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 D A Grove, BRU/Kup Staff Mgr ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Z-Energy Spacing Exception Request Dear Ms Grove: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficient. Chairman ~ jo/rpc~z-energy ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 11, 1994 Mr. David Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston' Subject: Report of Sundry Well Operations for BRU Well #211-3 Perforation (Approval #94-135) On June 14, 1994 ARCO Alaska, Inc. successfully completed the perforation of two additional Sterling 'C' sands on BRU 211-3. The two intervals were 3536 - 3546' and 3564 - 3580' MD. Enclosed are the Report of Sundry Well Operations, a Well Service Report, and a well schematic. The logging data will be forwarded under separate cover. If you require additional information, please call Brian Noel at 263-4879 Sincerely, D. A. Grove Beluga/Kuparuk Staff Manager DAG/BN:fl (086) Attachments CC: A. J. Durrani, L. S. Mathis, Shell Western E&P, Inc. Chevron USA, Inc. RECEIVED JUL 1 4 't994 Alaska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing 2. Name of Operator Stimulate __ Plugging Perforate X Alter casing Repair well Pull tubing Other ARCO Alaska, Inc. J3. Address P. O. Box 1 00360, Anchorage, AK 99510 4. Location of well at surface 204' FNL & 1 58' FEL of Sec. 4, T12N, R1 OW, SM At top of productive interval 181' FNL & 140' FWL of Sec. 3, T12N, R1OW, SM At effective depth 181' FNL & 176' FWL of Sec. 3, T12N, R1OW, SM At total depth 1 59' FNL & 179' FWL of Sec. 3~ T12Nr R10W~ SM 12. Present well condition summary Total Depth: measured 6562' true vertical 6536' 5. Type of Well: Development Exploratory Stratigraphic Service X 6. Datum elevation (DF or KB) 103'KB feet 7. Unit or Property name Belusa River Unit 8. Well number BRU 211-;] 9. Permit number/approval number 86-001 0 / 94-1 35 10. APl number 50-283-20079-00 11. Field/Pool Belu~la River-Sterling feet Plugs (measured) 4992', 5620' feet Effective depth: measured 4992' true vertical 4965' feet feet Junk (measured) 256' tubing tail /jewelry on bottom Casing Length Size Structural Conductor 97' 30" Surface 438' 20" Intermediate 31 44' 13-3/8" Production 601 0' 9-5/8" Liner Cemented Driven 475 sxs 2030 sxs 1130 sxs Measured depth True vertical depth 97' 97' 433' 433' 3140' 3114' 6003' 5977' Perforation depth: measured 3536-3546', 3564-3580' MD true vertical 3510-3520', 3538-3554' TVD Tubing (size, grade, and measured depth) 2-7/8" 6.5#, N-80 both strings String #1 @ 4759' Packers and SSSV (type and measured depth) See Attached Well Schematic String #2 @ 3297' 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A RECEIVED JUL 1 4 1994 AlaSka 0ii & Gas Cons. Commission Anchorage Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 6000 40 1125 Subsec]uent to operation 15. Attachments Copies of Logs and Surveys run ~ Daily Report of Well Operations. X 60O0 4O 16. Status of well classification as: Oil __ Gas X Suspended ~ Service_ 1125 17. I herebyAertify that the foregoing is true and correct to the best of my knowledge. Signed-Il .q, ~ ,~)-]/~ Title Belu~]a / Kuparuk Staff Mana~ler [orm 10-404 Rev 06/15/88 Date -) /(( /c~l~L SUBMIT IN DUPLICATE ,,.;0 Alaska, Inc..~,-~ Subsidiary of Atlantic.Richfield Company . .,ELL Z//"' ~' IPBDT CONTRACT(~ REMARKS WELL SERVICE REPORT IFIELD, c.J~TRICT - STATE OPERATION AT REPORT TIME /?.'dO Anr, hoiag~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots J Signed _MARKS CONTINUED: ~$: /_~- 00.'15' -3,-/' DESCRIPTION o~,,,/,,,,.../ . DAILY ACCUM. TOTAL RE¢£1VED JUL. 7 4 1994 AJaska Oil & Gas Cons. Commission Anchoraoe Alaska Inc. Bell River Unit BRU 211-3 Spud Date: 3/86 Last Compl: 4/5/86 Schematic Rev: 10/24/91 NE1/4 Sec.4, T12N, R10W SM 1 A 2 B I c 3 1 4 lOS G s C~,n$. C ~mmi , 9 I =l I 13 14 I 1~6 I 1~7 I 1~8 19 20 ~ 22 ~ 23 I I 241 I 25 ~ PBID=d992' 1~=6562' J JUL Alasl~ Oil & 4 $ ? 8 ]0 APl#: 50-283-20079-C0 Original RKB (Depth ReD: Ground Level: Maximum Hole Angle: Angle at Perforations: 103' 82' 12.66° 2° Well Type: Gas Producer Annulus Fluid: Diesel Top of Sterling: 3121' ASP: 2619684,315795 Dual w/heater string Jewelry Depth Lenath EauiDment O.D. I.D. -- 1 16' 0.79' Hanger - 2.313 2 16' 0.54' 2 7/8" 8RD-2 7/8" Butt XO 2.875 2,441 3 988' 1,06' Otis "X" Nipple 3.668 2,313 4 3253' 1,40' BOT "CC" Safety Jt. 3.375 2,438 5 3254' 3,20' Otis" XA" Sleeve 3.75 2.31 6 3257' 7,09' BOT "HB" Dual Pkr. 8.28 2.441 9 3656' 3,19' Otis "XA" Sleeve 3.668 2.313 10 3659' 8,51' BC)T "HB" Pkr. 8.28 2.441 13 4044' 1,06' Otis "X" Nipple 3.668 2.313 14 4045' 3.17' Otis "XA" Sleeve 3.75 2.313 15 4048' 8,51' BOT"HB" Pkr. 8.28 2.441 19 4466' 1.05' Otis "X" Nipple 3.668 2,313 20 4467' 3,17' Otis" XA" Sleeve 3.75 2.313 21 4470' 8.51' BOT "HB" Pkr. 8.28 2,441 22 4510' 1,05' Otis "XN" Nipple 3.668 2,20 24 4706-' (Items 7,8,11 2 7/8" Blast Jt. 3.675 2,441 12.16.17.1823) 25 4757' 0,75' BOT Shear Sub 3.668 2,441 A 16' 0.79 Hanger 2.313 B 16' 0.54' 2/78" 8RD-2 7/8" Butt XO 3,675 2,441 C 797' 1.05' Otis "X" Nipple 3.668 2.313 D 3257' 0.67' BOT Stab-in Stinger 3,375 2,50 E 3295' 1.05' Otis "XN" Nipple 3,668 2,205 AA 16' 0.79' Hanger - 1.91 BB 605' 1,05' Otis "XN" Nipple 3.063 1,791 CC 1817' 1.80' 45° Mule Shoe 3,063 1,995 Casing and Tubing Description Size Weiaht Grad~ Thread To o Bottom Surface Casing 20" 133#/94# K-55/H-40 Butt 433' Intermediate 13 3/8" 68# K-55 Butt 16' 3140' Production Csg 9 5/8" 47#/43.5# S-95 Butt 16' 6003' Production #1 2 7/8" 6.5~(1) N-80 EUE-8 RD 16' 4759' Production #2 2 7/8" 6.5~(2) N-80 EUE-8 RD 16' 3297' Heater 2 3/8" 4,7#(3) N-80 Butt 16' 1819' Perforations Net Production Zone DIL Depth TVD Depth Density Footage Interval Status lower A 3305'-3325' 3279'-3299' 8 SPF 20' String 2 Open B 3363'-3412' 3337'-3386' 8 SPF 49' String 2 Open C 3536'-3580' 3510'-3554' 4 SPF 26' String 2 Open 6/94 3614'-3640' 3588'-3640' 8 SPF 26' String 2 Pkr Open D 3682'-3876 3656'-3850' 8 SPF 51' Strin~ 1 Pkr Open lower E 4092'-4211' 4065'-4184' 8 SPF 21' String 1 Open upper F 4378'-4402' 4351'-4375' 8 SPF 14' Strinq 1 Pkr Open lower F 4512'-4725' 4485'-4698' 8 SPF 31' String 1 Open 5/2/91 10/2/92 5/7/94 Tag Datq String 2 String 1 2.3" gauge ring, XN at 3320' WLM 11/5/86 WL, top of tbg tail at 4732'WLM 1.7" gauge ring to 3200' WLM 5/2/91 1.5" bailer, tbg tail 4752', fill 4996' RKB 2.22" gauge ring, XN at 3285' WLM 6/3/93 1.75" bailer, fill at 4981' RKB 2.195" gauge ring through XN Note: Could not pull XN plug set at 4510' on 4/1/86 Tbg cut at 4501' on 11/5/86, tagged top of fish after cutting 7/11/94 .~RCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 12, 1994 Mr. David Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Subject: Submittal of Application for Sundry Approval to perforate BRU 211-3 Attached is an Application for Sundry Approval to perforate two additional sands in the Sterling 'C' zone on BRU 211-3. Please refer to the attached perforating procedure and well schematic for details of the operation. If you require any further information, do not hesitate to call Brian Noel at (907) 263-4879. Sincerely, D. A. Grove BRU/Kuparuk Staff Manager DAG:BDN:fl (071) Attachments CC: A. J. Durrani, L. S. Mathis, Shell Western E&P, Inc. Chevron U.S.A., Inc. RECEIVED MA"f' 2 5 1994 h~as.~. !ail & Gas Cons. Commission ~chorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATIO-N FOR SUNDRY APPROVALS Operation Shutdown_ Re-enter suspended well _ _ Plugging_ Time extension _ Stimulate __ Pull tubing _. Variance _ Perforate X Other 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 204' FNL & 158' FEL of Sec. 4, T12N, R10W, SM R E C E IV E At top of productive interval 181' FNL & 140' FWL of Sec. 3, T12N, R10W, SM 2 $ i994 At effective depth 181' FNL & 176' FWL of Sec. 3, T12N, R10W, SM ¢-',i~;3i'~ Vii & Gas Cons. 60mr At total depth Anch0ra.e.. ~ 159' FNL & 179' FWL of Sec. 3, T12N, R10W, SM 12. Present well condition summary Total Depth: measured true vertical 6562' feet Plugs (measured) 6536' feet 6. Datum elevation (DF or KB) 103' KB feet 7. Unit or Property name Beluga River Unit 8. Well number BRU 211-3 9. Permit number 86-0010 10. APl number .,,~,5,,0- 2 8 3- 2 0 0 79- 0 0 ~l~tU. '~:ield/Pool Beluga River/Sterlinc~ 4992', 5620' Effective depth: measured 4992' feet Junk (measured) true vertical 4 9 6 5' feet Casing Len gt h Size Cemented Structural Conductor 9 7' 3 0" Driven Surface 438' 20" 475 sxs Intermediate 31 44' 1 3-3/8" 2030 sxs Production 601 0' 9-5/8" 1130 sxs 256' tubing tail / jewelry on bottom Measured depth True vertical depth 97' 97' 433' 433' 3140' 31 14' 6OO3' 5977' Perforation depth: measured Current: See Attached Well Schematic Proposed: true vertical Current: See Attached Well Schematic Proposed: Tubing (size, grade, and measured depth 2-7/8" 6.5# N80 both strings String #1 @ 4759' Packers and SSSV (type and measured depth) See Attached Well Schematic 3536-3546', 3510-3520', String #2 @ 3297' 3564-3580' MD 3538-3554' TVD 13. Attachments Description summary of proposal Detailed operation program X BOP sketch 14. Estimated date for commencing operation June, t994 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as' Oil __ Gas ~; Service Suspended 17. I herel~ry'~?ertify I, t /~ Sic~ned /,~/'- / that the foregoing is true and correct to the best of my knowledge. I1 ~ Title Beluga River/Kuparuk Staff Manager FOR COMMISSION USE ONLY Date Conditions of approval' Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance Mechanical Integrity Test _ Subsequent form require 10- /-/,,'Oy Approved by the order of the Commission t~ngina! Signeo ,_-:-, f)avid W. Johns'..:)r Commissioner IApproval ~ _ /'~ ~ I. Date q. / '/ Form 10-403 Rev 5/03/89 Approved Copy Returned SUBMIT IN TRIPLICATE WIRELINE PERFORATING PROCEDURE BRU 211-3 BR 36 May 12, 1994 Objectives: Perforate additional Sterling sands below string 82 tubing tail in each well. Deliverability test string #2 after perforating is completed. Well Status: Current status, pressures, perforating depths, tubing restrictions, and gauge ring data are on the attached well data summary sheets and well schematics. Perforating procedure: 1. Shut in well (both strings) 2-3 days prior to perforating to obtain SITP. o Before beginning operations, hold a safety meeting with all personnel involved and obtain detail description of all wireline tools to be run in well. o MIRU electric line unit. Record SITP of both strings on WSR. Rig up lubricator on string #1 and pressure test to 2000 psi per wellsite supervisor's instructions. o Make-up TDT-P/GR/CCL tool string for tie-in log of string #1. RIH and log from 4400' - 2800' KB. Tie into CET/GR log dated 3/19/86. Se Use log to c°nfirm well schematic's location for string #1 tubing collars, packers, and jewelry. Correlate distinctive GR trace of coals to resistivity (DIL) and cement bond (CET) logs noted on well data sheet to verify depth of dual packer. o Rig down lubricator from string #1, rig up on string #2 and pressure test to 2000 psi per wellsite supervisor's instructions. o Make-up tool string of perforating gun, decentralizer, mechanical orientation sub, and CCL. Turn off radios, phones, and electric welders before arming perforating guns. Note: Gun #1 is 16' - (3564-3580'). Shallower interval to be shot on second run. o RIH to tubing tail with well SI. Tie-in with tubing tail and dual packer. Do not go below tubing tail until depth adjustments have been made. o Slowly drop out tubing tail, correlating with long string tubing collars and CET log referenced on well data sheet. Attempt to tie-in while running downhole, thus eliminating the need for upward logging passes. Note: If tie-in is questionable, consider dropping below interval to be perforated just enough to log up and reconfirm perf gun location. Minimizing down/up movement lessens the chance of hanging up on long string (#1) before firing. RECEIVE[ MAY 2 ~ 199,~ Ala$~,i1.0ii & Gas Cons. .... "~ch0rago BRU 211-3 BR 36 - Perforating Procedure May 12, 1994 10. 11. 12. 13. 14. Once tied-in, park gun at proper depth. Confirm that mechanical arm is fully open, if not bounce line and tool string to change gun's orientation. Once gun is positioned and full extension of mechanical arm confirmed, open wing valve to flow well and establish an underbalance. Maximum drawdown: AP of 100 psig from SITP (min. FTP) or 5 MMcfd (max. rate). Note choke setting, rate and FTP, then fire perf gun. After shooting, close wing valve and slowly pull perf gun up and into tubing. Finish POOH, check gun and record depths of any misfires. Repeat the gun run if necessary. Note SITP for both strings on WSR, then bring string #2 on at same choke setting as before. Flow for at least 30 minutes, monitor and record choke setting, flow rate, FTP. If first run was successful and hole conditions acceptable, pick up second perf gun (10') for run #2 (3536-3546') and repeat steps #7 through #13. Tie-in as above and shoot from CET depths shown in bold print. Note any changes in FTP, flow characteristics, and SITP following each run. 15. After completion of second run, RDMO lubricator and electric line unit. Return well to production: 16. Bring well on slowly and monitor for associated sand and/or water. Produce well until stable rates are attained. 17. Conduct a step rate test of the newly perforated zones using the enclosed form. Maximum recommended drawdown: AP of 200 psig from SITP (min. FTP) or 12 MMcfd (max. rate). 18. Send copy of WSR(s) and step rate test information to Brian Noel, ATO 1282. RECEIVE[.,, MAY 2 $ ]994 Oil & Gas Cons. Cornm~ss~t:r, 'Anchorage WELL DATA SUMMARY SHEET BRU 211-3 BR 36 Objective: Perforate additional Sterling C sands below the Ishort stnng'"-9 tubing tail to increase the well's deliverability. Well Status: BRU 211-3 is a dual string producer. The well was drilled and completed in 1986, targeting the Beluga sands. Although the D-F proved productive, three Sterling sands were perforated for additional rate. The well currently produces 8 MMcfd with sand from string gl and 10 MMcfd from string #2. Two additional Sterling C sands (239' and 267' below the short string tubing tail) are not completed, but have similar E-log responses as the completed intervals. The Sterling cement bond is good, the sands are high on structure, and no water has been produced from Sterling offsets to date. The sands appear gas bearing and a minimum incremental of 2 MMcfd could be realized. Latest Tags String #2 Surface Pressures: Reservoir Pressures' Casing size: Tubing size OD (ID): Min. ID String #2 2.3" gauge ting, XN nipple at 3295' MD on 5/2/91 2.28" and 2.22" gauge ring, XN nipple at 3285' WLM on 5/7/94 2.195" gauge ring ran through no go with no problems, 5/7/94 String #2 String gl 1202 psia (4/8/94) 1278 psia (4/8/94) String #2 String gl 1306 psia @ 3460' TVD (3473' MD) - mid perf 4/94 1475 psia average from 3/86 RFT 1403 psia @ 4177' TVD (4204' MD) - mid perf 4/94 9-5/8" String gl and #2 2-7/8" (2.441") 2.205" ID - Otis 'XN' nipple @ 3295' MD Perforation Data: Tie-in Log: 03/19/86 Schlumberger CET (Run #3, CET is on depth with DIL) DIL: 03/14/86 Schlumberger (5"- Run #2) Run No. 1 2 ZONE Intervld (MD-CET) Interval (MD-DIL) Length C 3564-3580' 3564-3580' 16 C 3536-3546' 3536-3546' 10 SPF 4 4 RECEIVE[ IAY 2 Aiasl .0il.& Gas Cons. C0mmlssi0r, ...... ' ~,rlchorage ..O Alaska, Inc. BRU 21 1-3 Spud Date: 3/86 Last Compl: 4/5/86 Schematic Rev: 10/24/91 NE1/4 Sec.4, T12N, R10W SM 15 10 21 1 ~A ~ IB i I c I 3 l ,DJ ID 9 13 14 1~6 18 19 20 ~ 22 ~1 241 I 25 PBID=4992' ~/~=~955'~ 1D:~62' A Bell 3 River Unit 103' API : 50-283-20079-00 Original RKB (Depth Ref): Ground Level: Maximum Hole Angle: Angle at Perforations: 21' 12.66° 2° Well Type' Gas Producer Annulus Fluid: Diesel 3121' Top of Sterling: ASP: 2619684,315795 Dual w/heater string Jewelry 1 16' 0.79' Hanger 2 16' 0.54' 2 7/8" 8RD-2 7/8" Butt XO 2.875 3 988' 1.06' Otis "X" Nipple 3.668 4 3253' 1.40' BOT "CC" Safety Jt. 3.375 5 3254' 3.20' Otis" XA" Sleeve 3.75 6 3257' 7.09' BOT "HB" Dual Pkr. 8.28 9 3656' 3.19' Otis "XA" Sleeve 3.668 10 3659' 8.51' BOT "HB" Pkr. 8.28 13 4044' 1.06' Otis "X" Nipple 3.668 14 4045' 3.17' Otis "XA" Sleeve 3.75 15 4048' 8.51' BOT "HB" Pkr. 8.28 19 4466' 1.05' Otis "X" Nipple 3.668 20 4467' 3.17' Otis" XA" Sleeve 3.75 21 4470' 8.51' BOT "HB" Pkr. 8.28 22 4510' '1.05' Otis "XN" Nipple 3.668 24 4706-' (Items 7.8,11 2 7/8" Blast Jt. 3.675 12,16,17,18,22) 25 4757' 0.75' BOT Shear Sub 3,668 A 16' 0.79 Hanger B 16' 0.54' 2/78" 8RD-2 7/8" Butt XO 3.675 C 797' 1.05' Otis "X" Nipple 3.668 D 3257' 0.67' BOT Stab-in Stinger 3.375 E 3295' 1.05' Otis "XN" Nipple 3.668 AA 16' 0.79' Hanger - BB 605' 1.05' Otis "XN" Nipple 3.063 CC 1817' 1.80' 45° Mule Shoe 3.063 Casing and Tubing 2.313 2.441 2.313 2.438 2.31 2.441 2.313 2,441 2.313 2,313 2.441 2.313 2.313 2.441 2.20 2.441 2,441 2.313 2.441 2.313 2.50 2.205 1.91 1.791 1.995 Descriotion Size Weiaht Grade Thread Too Surface Casing 20" 133#/94# K-55/H-40 Butt Intermediate 13 3/8" 68# K-55 Butt 16' Production Csg 9 5/8" 47#/43.5~ S-95 Butt 16' Production #1 2 7/8" 6.5~(1) N-80 EUE-8 RD 16' Production #2 2 7/8" 6.5#(2) N-80 EUE-8 RD 16' Heater 2 3/8" 4.7#(3) N-80 Butt 16' Perforations Net Zone DIL Depth TVD Depth Density Footage lower A 3305'-3325' 3279'-3299' 8 SPF 20' B 3363'-3412' 3337'-3386' 8 SPF 49' lower C 3614'-3640' 3588'-3640' 8 SPF 26' Bottom 433' 3140' 6003' 4759' 3297' 1819' D 3682'-3876 3656'-3850' 8 SPF 51' lower E 4092'-4211' 4065'-4184' 8 SPF 21' upperF 4378'-4402' 4351'-4375' 8 SPF 14' lower F 4512'-4725' 4485'-4698' 8 SPF 31' Production Interval Status String 2 Open String 2 Open String 2 Pkr Open String 1 Pkr Open String 1 Open Strin.q 1 Pkr Open String 1 Open Taa -- String 2 5/2/91 2.3" gauge ring, XN at 3320' WLM 0/2/92 1.7" gauge ring to 3200' WLM 5/7/94 2.22" gauge ring, XN at 3285' WLM RL CEJV . 5" gauge r'ng thr°ugh xN Note: Could not pull XN plug set at 4510' on 4/1/86 Tbg cut at 4501' on 11/5/86, tagged top of fish after cutting 2 b 199 Gas Cons. Commissmr~ : ~chorane Data String 1 11/5/86 WL, top of tbg tail at 4732'WLM 5/2/91 1.5" bailer, tbg tail 4752', fill 4996' RKB 6/3/93 1.75" bailer, fill at 4981' RKB 5/12/94 E-Line BOPE's Grease Head/ Hydraulic Packoff ~-- Lubricator Extension Manual Rams Swab Valve -~,~ o~ & Gas Cons. commission Anchorage Double Master Valves Wellhead SOUTHCE'~'iRAL.~ REGIONAL OFFICE 3601 C STREET, SUITE i350 ANCHORAGE, AK 99503 7988 May 5, - Mr. Pete Hellstrom ~-O1~ ARCO Alaska, Inc. P.O. Box 10360 Anchorage, AK 99510-0360 RE: Beluga Rese~;e Pits, Final Closure: BRU 232-9 = 8423-BA013 and BRU 211-3 & 224-34 = 8~23-BA005 Dear Mr. Hellstrcm: Thank you for sending me the photographs cf the closed reserve pits a= Beluga. i would like to point out that there was an error in the peL-mit identification number of pit BRU 211-3 on the photographs. Pit BRU 211-3 was assigned permit number 8~23-BA005 and not 8~23-BA005 as indicated on the photos. Please make these corrections on your copies to prevent future confusion. Again, thank you for the final closure photographs of the reserve pits. Sincerely, H~ Friedman Regional Solid Waste Program Manager HF:h CC-.' Leste~- Leatherberry, ADEC - S~ldotna ARCO ALASKA, INC. Cook Inlet/New Ventures Engineering TRANSr, IITTAL COI'IPANY' . ,~~ ~ ~ COMPANY' DATE' H ,..--,,1, ~ .~ 7 WELL NAME' Transmitted herewith are the following' PLEASE NOTE' BL = Blueline, S = Sepia, F = Film, T = Tape, PC = Photocopy aJ Receipt Acknowledgment' Alast.'.a Oil & Gas Cons. Commission Return Receipt to' ARCO Alaska, Inc. AT.TN: Judy Boegler AT0.-579 Po§~ Office Box 100360 Anch~orage, AK 99510 Precision Wireline P.O. Box 3905 ~ $olclotna, AK 99669 TIME DEPTH PRESSURE TEMP. Field ID. ~~~ Depth of Instrument Tubing ~~ Date No. 1 [~_~ Date No. 2 LT-~O Inst No. 1 ~~ Inst ~o. 2 ,, Off Depth (Date/Time)[2_~O_~ Shut in (Date/Time) Remarks: ,Precision Wireline P.O. Box 3905 ~ Soldotna, AK 99669 TIM E DEPTH PRESSU RE TEMP. Field I.D. ~~~ Well I.D. Casing PSI Purpose Depth of Instrument Inst No. 1 ~~H At Depth (Date/Time) ~/~/83e ~.o I ~ :~ I ¢: c , %~ot 1 ~ ~. o% ~o,.~ off Depth (Date/Time) ~q ~ Shut in (Date~ime) Remarks: [Precision Wireline P.O. Box 3905 ~ ~;olQotna, AK 99669 TIME DEPTH PRESSURE TEMP. Depth of Instrument Tubin~ ., . Date No. 1 Date No. 2 Inst No. 1 Inst No. 2 At Depth (Date~ime) Off Depth (¢at,~ime)[~3~~[ ~0~ Shut in (Date/Time) Remarks; Precision Wireline P.O. Box 3905 ~ $oldotna, AK TIME DEPTH PRESSU RE TEMP. Casing PSI /~¢ M200' ~~,q'~ ~ [,~ --, Depth of Instrument Tubing Date NO. I ~-~ ., Date No. 2 Inet No. 1 Inst No. 2 G ~ Depth (Date/Time) ~Z~/~ At Off Depth (Date/Time)~~ Shut in (Date/Time) Remarks: ARCO ALASKA, INC. Cook inlet/New Ventures Engineering TRANSHITTAL TO' COMPANY- DATE: FROM: COMPANY- WELL NAME' Transmitted herewith are the following- PLEASE NOTE: BL = Blueline, S = Sepia, F = Film, T = Tape, PC = Photocopy RECEIVED Receipt Acknowledgment' MAR- 4 !~87 .~ .-'- Alaska Oil & Gas Cons. Commission Return Receipt to- ARCO Alaska, Inc. ATTN- Judy Boegler AT0.-579 Poi~ Office Box 100360 Anchorage, AK 99510 ' STATE OF ALASKA ALASKA ,JIL AND GAS CONSERVATION C~ ,~IMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT la. TEST: INITIAL I~ lb. TYPE TEST STABILIZED [] NON STABILIZED ANNUAL E] MULTIPOINT ~] Rr~,~,l~ ED CONSTANT TIME E] SPECIAL ~ OTHER ISOCHRONAL 2. Name of Operator t987 Permit NO. ARCO Alaska, Inc. '- · 86-0010 3. Address P.O. Box 100560, Anchorage, AK 99510_~011&GasC0ns. C0mmissi°r 8. APl Number 4. Location of Well 5~ch~r~ge so- 285-20079 ,. 9. Unit or Lease Name Surface Beluga River ~ni.t 158' W & 204' S of NE Corner Section 4, TI2N, RIOE, SB&M lO. We, Number Top of Producing Interval BRU 211-3 gtrinn 140' E & 181' S of NW Corner Section 3, TI2N, RIOE, SB&M 11. Fie~d and Pool Beluga River - Sterling 5. Elevation in feet (indicate KB, DF etc.) 6. Lease Designation and Serial No, G.L. = 85', K.B. = 103' A-029656 12. Completion ~ate 13. Total ~e~th 14. ~lu~back T.D. lB. Tgpe Complotion {~e~cribe} 4-5-86 6562~ ~D 4992~ ~ Dual S~rlnn ~q 1~. C~. Size ~ei~ht ~er foot, lb. I.D. in inche~ Set at ft. ~erforation~: Fro~ To 9 5/8" 45.5 8.755 6003 . 3305 - 3325 17. lb~. Size ~ei~ht ~er loot, lb. I.D. in inche~. Set at ~t. 3363 - ~4 ~ 2 2 7/8" 6.5 2,441 3296 36!4 - 3257[ .....[ 556 22. Producin~ thru: ~eservoir Temp. o F. Mean gnnual Temp. o F. Barometric ~res~ure Tbg, ~ Csg. ~ 77°F 0 3200' 33°F 14,65 ps i a 23. Length of flow channel (L' ~ Vertical Depth (H, ' G~. [ °ACO~ ~ "' N2 ~ %H2S ~ Prover I Meterrun J Taps 3200 5174 i ,556 Trace Trace -- 4" Flange 24. Flow Data Tubing Data Casing Data Prover ~ts~Fe ~r Pressure Pressure Duration of Line X ~ifi~ ~eae" Di~.l ng Temp. Temp. Flow No. Size (in.) Size ~.~ psig o F. P~s~ o F. psig o F. Hr. hu ~. 4.026 x 2.0 790 4.1 82 1371 60 N/A N/A 2. 4.026 x 2.0 790 5.3 80 1354 62 , " " ? 3. 4.026 x 2.0 795 6.7 80 1333 6~ " " 2 ~, ' 4.026 ~~ ~ ~,~ ~800 8.4 79 1302 63 " " Basic Coefficient S~a~ i c Flow Temp. Gravity Super Comp. ~~Ga~C0[~. Ocm~is~ pu Read ing Factor Factor Factor Rate of Flow No. F b'o ~a~ Pu Ft Fg Fpv Q, Mcfd ~. 90.38 26.24 6.4 .980 I .341 I ,053 3282 ~. 90.38 33.92 6.4 .981 I. 341 ~ _~54 ~25 I 3. 90.38 42.88 6.4 .981 I, 3~ I ~ I ~a . 5, I · Includes Me+er Cons+ant (M) = ~.472, / Temperature for Separator for Flowing Pr T Tr Z Gas Fluid No. Gg G I .22 542 I .58 .902 2. I. 22 540 I. 57 .900 3. i .22 540 I .~7 .... 900 Critical Pressure 673 4. I. 24 539 I . 57 .899 Critical Temperature ~4~O' 5. Form 10-421 CONTINUED ON REVERSE SIDE Submit in duplicate Rev. 7-1-80 Pc 1406 pc2 pf 1519 pr2 2307.4 No. Pt Pt2 Pc2 - Pt~ Pw Pw2 Pc2 - Pw2 Ps Ps2 X I O- pf2 . Ps2x 1 0-3 1. 1501 2253.0 54.4 2. 1493 2229.0 78.3 3. 1484 2202.3 105. I 4. 1472 2166.8 140.6 5. 25. 54,000 0. 746 AOF (Mcfd) n Remarks' Gas composition from offset producer Bottom hole pressures obtained at setting depth I he~e . . of 320Q' MD (3174' TVD) . C ~_0.982 MCFD/psia2 by certity that the foregoing ,s true and correct to the best otmt/ Knowleage __ Signed ~'~ /----~--~' Title /.~-.~Cl [,,';'vl['~A. /"'~-'1.,'~.~, Date ' - - L/ 1'0- DEFINITIONS OF SYMBOLS Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps- Pt Pw Q Tr T Z AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd/~ Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor=-x/1/Z dimensionless F lowing temperature factor, dimensionless ' Specific gravity of flowing fluid (air=1.000), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ratio, cu. ft..of gas (14.65 psia and 60 degrees F.) per barrel oil (60 degrees F.) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back-pressure equation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static pressure at point of gas measurement, psia Reduced pressure, dimensionless Flowing Pressure at vertical depth H, psia Flowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60 degrees F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual Of Back-Pressure Testing Of'Gas We/Is, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. BRU 2 1 1-3~2 'Four Point Back Pressure Test 12/30/86 ~ 2 10 1,000 2 3 10,000 100:000 RECEIVED Q(MCFD) 3 4 5 6 7 8 910 _Alaska Oil & Gas Cons, Commissiort Anchorage 1 a. TEST: 2. Name of OPerator 7. Permit No. ARCO Alaska, Inc. 86-0010 3. Address P.0. Box 100360, Anchorage, AK 99510-0360 , STATE OF ALASKA "~"~ .,? ~.~v¢, ,¢~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT INITIAL I~ lb, TYPE TEST STABILIZED [] NON STABILIZED,~,'/ ANNUAL [] MULTIPOINT [~ CONSTANT TIME U I SPECIAL [] OTHER, ISOCHRONAL[~ I 4. Location of'Well Surface 158' W & 204' S of NE corner section 4, TI2N, RIOE, SB&M Top of Producing Interval 140' E & 181' S of NW corner section 3, TI2N, RIOE, SB&M 5. Elevation in feet (indicate KB, DF etc.) [ 6. Lease Designation and Serial No. G L = 85' K B = 103' I A-029656 · · ~ · · 12. Completion Date [13. Total Depth 14. Plugback T.D. 4-5-86 I 6562' MD 4992' MD 16. Csg. Size Weight per foot, lb. I.D. in inches Set at ft. 9 5/8" 43.5 8.755 6003 17. Tbg. Size Weight per foot, lb. 2 7/8" 6.5 18. Packer set at ft. [19. GOR cf/bbl. 3660; 4049; 4470I -- 22. Producing thru: Tbg. I~ ' Csg. [] 23. Length of flow channel (L) 4200 24. Flow Data -- NO. 1. 2. 3. 4. 5. Prover Line X ~ifi~e Size (in.) SiLFeI ~.~ 4.026 x 2.5" 4. 026 x 2.5" I.D. in inches Set at ft. 2.441 4759 20. APl Liquid Hydrocarbons ---- Reservoir Temp. o F. 90°F @ 4200' Vertical Depth (H) ! Ga. '! %CO? ! "" N2 4174 i .556 iTrace iTrace eter ressure psig 810 820 _ Diff Re~:lihg hu 8. APl Number 50- 283-20079 9. Unit or Lease Name Beluga River Un it 10. Well Number BRU 21 I -3 Str ing _//I 1 1. Field and Pool 2.8 4.1 r~eeter mp. 'oF. 70 64 Tubing Data Pressure ~sig ps~a 1563 1536 4.026 x 2.5" 880 5,5 60 1460 4.026 x 2.5" 820 6.3 57 1416 Beluga River - Beluga 4512--452z 4706-4725 No, Basic Coefficient (24-Hour) * Fb or Fp 148.89 148.89 hu pIj 17.64 25.83 Static Reading Pu 6.3 6.3 F Iow Temp. Factor Ft 0.991 O. 996 148.89 36.30 6.6 I .000 , 148.89 40.64 6.45 I .003 15. Type Completion (Describe) Dual String Gas Producer Perforations: From To 3682-3697 4092-4102 3717-3726 4200-421 I 3773-3778 4378-4388 2~.~pe4c~c~Ta~vity Flowin~'~,~T&402 .556 Mean Annual Temp. o F. Barometric Pressure (Pa), psia 336F 14.65 psi % H2S Prover I Meter run / Taps -- 4" I ~'1 ange Casing Data Duration of Temp. Pressure Temp. Flow ° F. psig ° F. Hr. 73 N/A N/A 2 73 " " 2 71 " '" 2 70 " " 2 Gravity Factor Fg Super Comp. Factor Fpv 1.058 1.065 . 1.064 . Rate of Flow Q, Mcfd 3680 5~36 771g 8659 1.341 1.341 * Includes Meter Constant (M) : 4.472 Temperature ! i'.~./~ for Separator for Flowing Pr T Tr Z ~ 4 L987 Gas Fluid No. ' Gg G 1 I 18' ': 530 0 :: 1.5'5 ¢(~s.~-~ ,, ~ . -. ~Vliliili~ ;j0~ 2. I. 18 5-24 0 I. 53 ' .89 ;~arag~ ~. 'i1.29 520.0 1.52 .88 CriticalPressure 67~ n~ia 4. ~ I . 24 5 1 7.0 [ . 5 1 , 88 Critical Temperature 343 ' R 5.~ ~ ~_ Form 10-421 CONTINUED ON REVERSE SIDE Submit in duplicate / pf2 3147_1 ~1 103 pf2 . ps2 X!O- ' Pc 1601 Pc2 Pf 1774 No. 25. Pt Pt2 AOF (Mcfd) 107,000 Remarks: pc2 - pt2 Pw Pw2 pc2 - pw2 Ps 1758 1750 1736 177q PS2xlQ-3 3090.6 3062.5 3013.7 ?989:4 56.5 84.6 133.4 157:7 n 0.845 Gas composition from offset producer. Bottom hole pressures obtained at setting depth of 4200' MD (4174' TVD). C = 0.360 MCFD/psia2 I hereby certify that the foregoing is true and Correct to the best of my knowledge Date AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z DEFINITIONS OF SYMBOLS Absolute Open Flow Potential.. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd/-X/hwPm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor=-x/1/z dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air--1.000), dimensionless Specific Gravity of separator gas (air--1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F.) per barrel oil (60 degrees F.) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back--pressure equation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static pressure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Flowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60 degrees F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual Of Back-Pressure Testing Of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. £~Q ~ L ,' ' ' I ' ' '' ' : · ; ~' ' I i i''l ' ' ' ' ' ' " ~' Ii , ~ . m,'-- · · , , , , ....... t.I ,, . I I. 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' .... rr'.T , -' ~~ i~ ~ l~ ~; ~ii~'il~i ~ ./~~' ; :i:~ I I,I i~l' ;-, "~;:;'~; ;;~' ' ""' ..... ' · ~ ........ I .... -~--: i~,~:~ , · , ,~: :;-; , : ; : . , , . . . ,, , ' ' .... · ' ''''~ : '. i ; ~iiI ii~ i!;J iii!ii!; Jill iii; '' '. '~:1~ ~; -~.- ~. -~ ~ , , , , i " ' ........ " ' ~ .... ~ " 'il'l~,I''' "' ~ ' : ' ;iii i . ,.~i~ ' ....~ , , . - : · ~ '~'- ; I ..................... ~ .......... i-i i~l':ll ,~1~~,il ~;~ ~ , , .... :-- sel eJnsseJd Moe8 lu!od Jnod L L nUEi ARCO ALASKA, INC. Cook Inlet/New Ventures Engineering TO' ADDRESS' LOG TRANSMITTAL FROM' DATE: WELL: Please find the following logs enclosed- Log Blue Line *** Sepia *** Folded Rolled Mylar Tape Recei pt Acknowledgment: Return Receipt to- ARCO Alaska, Inc. ATTN' Judy Boegler AT0-579 Post Office Box 100360 Anqhorage, AK 99510 Form 3160--5 (November 1983) (Formerly 9--331) U~?-'~'9STATES SUBMIT IN (Other lnstruetlont re DEPARTME! OF THE INTERIOR ver~ side) BUREAU OF LAND MANAGEMENT Form approved. Budget Bureau No. 1004--0135 Expires_ August 31, 1985 LEARR DIRION&TION AND gIRI~L NO. A-029656 6. IF INDIAN, ALLOTTEI OR TIIBE NAME 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.) l. 7. UNIT AOREgMINT NAMI O,L [~ GAS [] OT",R Beluga River Unit WELL WELL 2. NAME OF OPERATOR 8. F~'nM OR LIAgl NAME ARCO Alaska, Inc. 3. ADDRESsa OF OPERATOR 9. W~LL P. O. Box 100360 Anchorage, Alaska 99510-0360 BRU 211-3 4, LOCATION OF WELL (Report location clearly and in accordance with any State reqHirements.* See also space 17 below.) At surface 158' W & 204' S of NE Corner Section 4 T12W, R10W, SB&M 15. E~VA~ONS (Show whether OF, ~, Gk ~) G. L. = 85' K.B. = 103' 14. PERMIT NO. 86-0010 10. FIELD AND POOL, OR WILDCAT Beluga River - Sterlin~ 11. abc., T., R.0 M., 01 BLK. ~ Section 3, T12N, R10W 12. ~UNTr aa P~IsaJ 13. STATE SB&I Kenai[ AK 16. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT 5IULTIPLE COMPI,ETE SHOOT 0R ACIDIZ] ABANDONs REPAIR WELL CHANGE PLAN~ (Other) 8UBHIQUBNT uupouT OF: WATER SHUT-0FP I !~ REPAIRING WILL FRACTURE TREATMENT j j . ALTERING CASING SHOOTING 0n ACIDIZING J J ABANDONMINTo (NOTE: Report results of multiple completion on Well Completion or Recompletion RepoFt and I~ form.) ion X iT. v~sc~.Isr PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionall¥ drilled, give subsurface locations and measured and Irue vertical depths for all markers and ~oaea pertl- neat to this work.) s This is to notify that BRU 211-3 commenced production beginning December 24, 1986. RECEIVEI) JAN 2 3 1987 OJJ & 6as C0~. Commission 18. I hereby certify that the foregoing la true and cot:rect (This space for Federal or State office useJ APPROVED BY CONDITIONS OF APPROVAL, IF AIRY: TITLE DATE *See Instructions on Reverse Side Title 18 U.S.C. Section !001, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. Instructions General: This form is designed for submitting proposals to perform certain well operations, and reports of such operations when completed, as indicated, on Fed- eral and Indian lands pursuant to applicable Federal law and regulations, and, if approved or accepted by any State, on all lands in such State, pursuant to applicable State law and regulations. Any necessary special instrnctions concerning the use of this form and the number of copies to be submitted, particularly with regard to local, area, or regional procedures and practices, either are sh.wn below or will be issued by, or may be obtained from, ~he local Federal and/or State office. .. Item 4: If there are no applicable State requirements, locations on Federal or Indian land should be described in accordance with Federal requirements. Consult local State or Federal office for specific Instructions. Item 17: Proposals to abandon a well and snb.~equent reports ~f al,an(i.nment should include such special information as is required by local Federal and/or State offices. In additi.n, such proposals and reports Should Include reasons for lhe abandonment; data on any former or Present productive zones, or other zones with present significant fluid contents not sealed off by cement or otherwise- depths (top and bottom) and method of placement of cement plugs; mud or other material placed belo~v, betxveen and above plugs; amount, size, method of parting of any casing, liner or tubing pulled and the depth to top of any left in the hole; method of closing top of well; and date well site conditioned for final inspection looking to approval of the abandonment. PRIVACY ACT The l:'~riva¢.y Act of 1074 and the rep, elation in 43 CFR 2.48(d) provide that you be furnished the following information in connection with information required by this appl. ication. AUTHORITY' 30 U.S.C. 181 ct. seq., .~5,1 el. seq., 25 U.S.C. et. seq.; 43 CFR 3160. PRINCIPAL PURPOSE: Thc, inforrnatton is to be used to evaluate, when appropriate, al:~provu applications, and re'port c'omplc'lion of secondary well operations, on a Federal or Indian lease. ROUTINE USES: (I) l';vuluatu' Iht cquiprncnt and procedures used during the proposed or completed subsequent well operations. (2) Request and grant approval to perform those aclions covered by 43 CFR .}162.3.-.2(2). (3) Analyze future applications to drill or modify operations in light el data obtained and methocls used. (4)(5) Information from the r(;cord and."or the record will be transferred to appropriate Federal, State, local or foreign agencies, when relevant to civil, criminal or regulatory investigations or pros- ecutions. EFFECT OF' NOT PROVIDING INFORMATION: Filing of this notice and reportand disclosure of the information is mandatory once an oil or gas well is drilled. Thc Paperwork Reduction Act of It}80 (.14 U.S.C. 3501, et. seq.) requires us to inform you that: This inl'()rmation'is I)uin[:. (:ull¢('l~,(l in order to evalur:te proposc, d and/or completed sub- sequent well operations on Federal or Indian oil and ~as leases. This informaticm will b~, m.;cd to rt:p.orl suhsequunt operations once work is completed and when requested, to obtain apprc>val fo.r subsequent operations not previously authorized. [-,?,c.~por~,~c~ to this r(:quesl is; rnan~latorv for the specific types of activities specified in .:1.~ CI"N Part 3160. , .. ~ U.S. Gove=nment Pzintin~ Office:lq83-776-O0914702 R8 ARCO ALASKA, INC. Cook Inlet/New Ventures Engineering TRANSM I TTAL COMPANY' DATE- FROM: COU,AU¥- WELL NAME- Transmitted herewith are the following. PLEASE NOTE- BL = Blueline, S = Sepia, F = Film, T = Tape, PC = Photocopy Receipt Acknowledgment' JAN 2 ~' ~oo. Naska 0t~ & Gas ~,u~ Oommission Date: Return Receipt to- ARCO Alaska, Inc. ATTN- Judy Boegler AT0-579 Po§t Office Box 100360 Anchorage, AK 99510 ' ARCO ALASKA, INC. Cook Inlet/New Ventures Engineering TRANSHITTAL COMPANY: DATE- FROM: COMPANY- WELL NAME' Transmitted herewith are the following' PLEASE NOTE' BL = Blueline, S = Sepia, F = Film, T = Tape, PC = Photocopy RECE!VE_ Receipt Acknowledgment' JAN 2 .t ]987 Al~.~ka Off & tt~~. Commission Return Receipt to' ARCO Alaska, Inc. ATTN: Judy Boegler AT0.-579 Po~t Office Box 100360 Anchorage, AK 99510 ' Anchorage, Alaska 99510-0360 L';C'J':~ Tele ~' ~.-~ .;.._~. -%~ .... ~ discussed dur[n~ our ~tober 22, [9S6 telephone conversat[on~ ARCO Aleska~ Inc. has essumed responsibility ~or operation o~ both the 5wenson River ([ncJud[n~ the ~Idotn~ Creek Unit) end ~lu~a River As part o~ this new respons[b[Hty~ we w[II be conduct[n~ equipment end test[n~ to ver[~y the status o[ the equ[pment that is Jocated in both ~e specific re~son ~or my c~tI w~s to discuss and provide notification o[ ~our planned ~s well tes[s. Dur[n~ our convers~t[on~ I indicated thet these tests coutd be~n es e~rty as Fr[dey~ ~tober 2~ Mr. Bill MacClarence Alaska Department of Environmental Conservation #37 "E" Street, SeCond Floor Anchorage, AK 99701 RE: Gas Well Testing, BelUga River Field Dear Mr. MacGlarence: The open burning is now scheduled to begin on or after Wednesday, October 29, 1986 and will be conducted at various flowing rates with sufficient volume to clean up any brine or water that may be in the wells. After the wells have been cleaned up, flowing will continue in order to gather well rate/capacity information. The flow duration during clean up and testing is unknown and is dependent on the producing capacity of each well. The estimated flow period is six to twelve hours with an estimated maximum of 2# hours. The maximum expected producing rate is 2 MM scf/d. Each well clean up/test could require two to four days to complete. The estimated Btu/scl is 1000. After the clean up and testing, the wells will be gas producers for the Beluga River field. The wells to be tested are: BRU 232-9 BRU 22#-3# BRU 211-3 BRU 24134 Because these are gas wells, the open burning should not produce black smoke. Should black smoke occur in excess of 20% capacity, the flow will be pinched back or the well will be shut in as needed. This planned activity is regulated by 178 AAC 50.030 and because black smoke will not be produced a permit is not required. This letter and the attached map are sent lot your information. Should you have a question, please call me at 265-6176. Sincerely / Peter N. Hellstrom Sr. Environmental Coordinator PNH/pw RECEIVED A[[achmen[ Cc: C. Chatterton, AOGCC ~ OCT 3 1 1986 Alaska 0ii & gas Cons. O0mmissi0n Anchorage ARCO A;as~:a 'nc. ,$ a S,.~s.d,ary of APanlJcR,chhe:dCompany i -I, BELUGA z,2-z, RIVER UNIT ,~ I ~ / ~ ,,-.,. I ~ RETTY CRE, BELUGA RIVER BRIDGE- PRETTY CREE ZlZ .Il i i i i ! ro d~ ~· ENST,4R METERING El OEHYDR,~TIONj J ~oH~SE 77' EXP.~NSION 1 & ~- OCT 5 ~: 1986 ,~ Oit & Gas ConS. Commission Anchorage i STATE OF ALASKA ~'---' ALASKA ~. AND GAS CONSERVATION CO ..MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well · OIL [] GAS [~ SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number _ Chevron U.S.A. Inc. 86-0010 3. Address 8. APl Number P. O. Box 107839, Anchorage, AK 99510 50-283-20079 4~ Location of well at surface 9. Unit or Lease Name 158' W & 204' S of NE Corner Section 4, T12N, R10W, SB&M Beluga River Unit At Top Producing Interval ~ 10. Well Number 152' E & 177' S of NW Corner Section 3, T1.2N, R10W, SB&M BRU 211-3 At Total Depth 11. Field and Pool 179' E & 159' S of NW Corner Secti:on 3, T12N, R10W, SB&M Beluga River- Beluga 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. G.L. = 85' K.B. = 103'I A-029656 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 2-20-86 3-13-86 4-5-86 MA feet MSLI 2 17. Total Depth (M D+TVD)'18.Plug Back Depth (MD+TVD)1'9. Directional SurveY6562 '; 6536 ' 4992 '; 4965 ' YES ~] NO [] [ 20. Depth where SSSV setNA feet MD I21' Thickness °f Permafr°stNA 22. Type Electric or Other Logs Run D IL / SFL/SP / GR/BHC- SONIC / CTG/LDT / CAL/D ITE/SDTA/RFT ' s / CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" 310 24 ' ' 97 ' Driven 20" 94# H-40 22' 433' 26" 475 SKS C1 "G" 13 3/8" 68# ... I~55 ' 20" 3140~ 17 1/2" 2030 SKS C1 ."G" 9 5/8" 43.5#'~ S-95 18' 6003' 12 1/4" 1130 SKS C1 "G" 24. Perforations o, pen to Production (MD+TVD of Top and Bottom and 25. TUBING ~R E'C~D -. , interval, size and number) . . SIZE DEPTH SET (MD) PACKER SET (MD) 2 7/8" 4759' 4470'/4049'/3660' See Attached 2 3/8" 1819' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ,-_ . . . DEPTH. INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED .r . 5745'-5675' 50 SKS C1 "G" Below Rtnr @ 56 5060'-5040' 50 SKS C1 "G" Below Rtnr . 27. See Attached PRoDuCTION TEST Date First Product on.. - '~ '~'1 Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO ~... i . TEST PERIOD ~ .. OIL~B'BL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow ~'U,bing Casing Pressure CALCULATED . Press..~ . 24-HOUR RATE ~ 28. MIA CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. : · 'Maska 0il & G~.s ConS. '~', ~_0' )2' Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate~ 29. ,3O. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sterling 1508' 1504' DST #1.- 5745'-5714' 5700'-5675'. A 3138' 3112' Perforated 1 .47" JSP2F 3/19/8 and tool B 3330' 3304' opened with a 300 PSI underbalance N2 cushion C 3484' 3458' at 11:22 p.m. 5:13 FP and 0:00 SIP. IFP=2508 Top Beluga (D) 3641' 3615' PSI FFP=717 PSI NGTS and 1523' fluid rise. E 3911' 3885' DST #2: 5060'-5040'. Perforated 1 .47" JSPF F 4263' 4236' 3/21/86 and tool opened with a 170 PSI under- G 4814' 4787' balance N2 cushion at 9:50 a.m. 4:10 FP and H 5290' 5263' 7:00 SIP. IFP=2211 PSI FFP= 190 PSI FSIP=2329 PSI. GTS at 2:44 p.m. Max rate= 35 MCFD and final rate=10 MCFD 12/64" choke FTP=2 PSI. 595' fluid"~ise'~ 31. LIST OF ATTACHMENTS Supplementary Record 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ..... _ .. Title Sr. Are Engineer Date iNSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". STATE OF ALASKA ¢- -" ALASKA ~..L AND GAS CONSERVATION C~-....~-¢ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ~ OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Che. v-ron U.S.A. Inc. 86-0010 3. Address 8. APl Number P. O. Box 107839, Anchorage, AK 99510 50- 283-20079 4. Location of well at surface 9. Unit or Lease Name 158' W & 204' S of NE Corner Section 4, T12N, R10W, SB&M Bc_l~,~n R~v~ Unit At Top Producing Interval 10. Well'NUmber - 140' E & 181' S of NW corner Section 3, T12N, R10W, SB&M BRU 211-3 At Total Depth 11. Field and Pool 179' E & 159' S of NW Corner Section 3, T12N, R10W, SB&M Beluga River - Sterling 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. G.L.=85' K.B.=103' A-029656 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. / 15. Water Depth, if offshore 116. No. of Completions 2-20-86 3-13-86 4-5-86I NA feet MSLI 2 · 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD} 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafros't 6562 ' ~ 6536 ' 4992 '; 4965 ' YES ~ NO [] NA feet MDI NA 22. Type Electric or Other Logs Run DIL/S~/SP/GR/BHC-SONTC/CNT~/T,DT/CAI,/DTTE/RDTA/R~T' a/CRT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH ME) CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" 310¢~ 24 ' 97 ' Dr ~ v~ 20 94# H-40 22' 4_33' 26" 475 SMR Cl "G" _ 13 3/8" 68~ K-55 20' ' 3140' ]7 1/2" 2030 SMR C] "C." 9 5/8" 43.5# S-95 18' 6003' 12 1/4" 1030 SKS Cl "G" 24. Perforations open to Production (MD+TVDof Top and Bottom and 25. TUBING RECORD · interval,size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3640'-3614'; 3614'-3588'; 26' .41" 8 JSPF 2 7/8" 3296' 3258' 3412'-3363'; 3386'-3337'; 49' .41" 8 JSPF 2 3/8" 1819' 3325'-3305'; 3299'-3279'; 20' .41" '8 JSPF26. NA~ ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ,,. ,.. . ,. . -: 27. PRoDDcTION TEsT Date First.Production ..... ~' ' ' ' I Method.of.:Operation: , (Flowing, gas lift, etc.} I : Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 4/4/-86 ~9.5 . TEST PERIOD e 0 ~2 0 32/64 NA Flow Tubing Casing.Pressure CAL,C. ULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press~1.160 0 ' -~ 24-HOUR RATE ~! 0 6,586 0 NA 28. ]~A CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · . .: - ; · - AIasK~ Oil & Gas Cons. C:'~ ~,m!~,ion Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplic~'~_~~ 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sterling 1408' 1504' A '3138 ' 3112 ' B 3330 ' 3304 ' C 3484 ' 3458 ' Top Beluga (D) 3641' 3615' E 3911' 3885' F 4263 ' 4236 ' G 4814 ' 4787 ' H 5290' 5263' · . 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed__ ~~x~.4 _ Title._ Sr. Area EngineezOate B"'&~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water suPply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". SUPPLEMENTARY RECORD Perforations open to Production: MD TVD 4725'-4706' 4698'-4679' 19' 4524'-4512' 4497'-4485' 12' 4402'-4398' 4375'-4371' 4' 4388'-4378' 4361'-4351' 10' 4211'-4200' 4184'-4173' 11' 4102'-4092' 4075'-4065' 10' 3876'-3854' 3850'-3828' 22' 3778'-3773' 3752'-3747' 5' 3726'-3717' 3700'-3691' 9' 3697'-3682' 3671'-3656' 15' .41" .41" .41" .41" .41" .41" .41" .41" .41" .41" 8 JSPF 8 JSPF 8 JSPF 8 JSPF 8 JSPF 8 JSPF 8 JSPF 8 JSPF 8 JSPF 8 JSPF Production Test: Intervals: 1. 4725'-4512'; 2. 4402,-4092'; 3. 3876'-3682' PRODUCTION FOR TEST PERIOD Hours Oil Gas Water Choke Interval Date Tested BBLS MCF BBLS Size I 4/1/86 12 0 1562 2 4/3/86 53 0 511 3 4/4/86 11.5 0 368 Calculated 24 HR. Rate Tbg CSG Oil Gas Interval Press Press bbls MCF Gas/Oil Ratio 0 32/64 0 24/64 0 16/64 NA NA NA i 1320 0 0 7,663 2 1350 0 0 2,637 3 1260 0 0 1,052 Water BBLS Oil Gravity-API (Corr) 0 NA 0 NA 0 NA "'--- .... STATE OF ALASKA '--' '"'-" ALA...~ JIL AND GAS CONSERVATION CON, ..ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging ~ Perforate j~ Pull tubing ~ Alter Casing ~,' Other ~ ~ 2. Name of Operator 5. Datum elevation (DF or KB) Chevron U.S.A. Inc. K.B. = 103 Feet 3. Address 6. Unit or Property name P.O. Box 107839, Anchorage, AK 99510 Beluga River Unit 7. Well number BRU 211-3 4. Location of well at surface 158' W 7 204' S of NE Cor. Sec. 4, 12N 10W, SB&M At top of productive interval 140'E & 181' S of NW Cor. Sec. 3, 12N 10W, SB&M At effective depth 182' E & 166' S ofNW Cor. Sec. 3, 12N 10W, SB&M At total depth 179' E & 159' S of/NW- Cot. Sec. 3~ 12N 10W, SB&M 11. Present well condition summary Total depth: measured 6562 feet Plugs (measured) true vertical 6536 feet 8. Approval number 9. APl number 50-- 283-20079 10. Pool Beluga and Sterling See Attached Effective depth: measured 4992 feet true vertical 4965 feet Casing Length Size Structural Conductor 73' 30" Surface 411 ' 20" Intermediate 3120' 13 3/8" 5985' 9 3/8" Production Liner Perforation depth: measured 3325'-3305' See Attached 3299'-3279'. true vertical Junk(measured) Cemented Measured depth Driven 475 Sks 2030 Sks 1030 Sks 97' 433' 3140' 6003' 3412'-3363' 3386'-3337'; 3640'-3614' 3614'-3588' True Vertical depth 97' 433' 3114' 5977' Tubing (size, grade and measured depth) 2 7/8" 6.5# N-80 (d 3297' & 4759' 2 3/8" 4.6# N-80 1819~ Packers and SSSV (type and measured depth) Brown: HB 4470', 4049', 3660'; HS-17-7, c 3258' 12. Stimulation or cement Squeeze summary See Attached Intervals treated (measured) Treatment description including volumes used and final pressure 13. NA Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~44_,~/___~ Title-Acting Area Operations SuperintendentDate Form 10-404 Rev. 12-1-85 Submit in Duplicate SUPPLEMENTARY RECORD Perforations open to Production: MD TVD 4725'-4706' 4698'-4679' 19' 4524'-4512' 4497'-4485' 12' 4402'-4398' 4375'-4371' 4' 4388'-4378' 4361'-4351' 10' 4211'-4200' 4184'-4173' 11' 4102'-4092' 4075'-4065' 10' 3876'-3854' 3850'-3828' 22' 3778'-3773' 3752'-3747' 5' 3726'-3717' 3700'-3691' 9' 3697'-3682' 3671'-3656' 15' .41" .41" .41" .41" .41" .41" .41" .41" .41" .41" 8 JSPF 8 JSPF 8 JSPF 8 JSPF 8 JSPF 8 JSPF 8 JSPF 8 JSPF 8 JSPF 8 JSPF Production Test: Intervals: 1. 4725'-4512'; 2. 4402'-4092'; 3. 3876'-3682' Interval Date I 4/1/86 2 4/3/86 3 4/4/86 Tbg CSG Interval Press Press 1 1320 2 1350 3 1260 PRODUCTION FOR TEST PERIOD Hours Oil Gas Water Choke Gas/Oil Tested BBLS MCF BBLS Size Ratio 12 0 1562 0 53 0 511 0 11.5 0 368 0 Calculated 24 HR. Rate Oil Gas Water bbls MCF BBLS 0 0 0 0 7,663 0 0 2,637 0 0 1,052 0 32/64 NA 24/64 NA 16/64 NA Oil Gravity-API (Corr) NA NA NA Drilling Morning Report test C~O SUi Set 0 MD TVD EMW Line~ -2 ....... ~et 0 MD TVD- TOP 0 MO TVD Pm ~/Ml CL CA ~z lime Il i i iii i ,-- ii Olaf M 0 k~le Di~fi~ TVD C~diMl~ "~ S .... il i i ii i ii I · No gila Type ~l. NO. JOlt In Out F~t Hrs. WO9 . lotel [eng;h (H.W.D.P.: ) ~,~t; of , ii mi i i, Pump L~r, er ~troke SPM Prffiure GPM Jet VoL Ann. Vel. Bit ~P Pump HHP iiii ii ii i ......... ~ , CO. tH1 t,CD- 3 i~.,d ~ CC-Morn. i Last Casing S~ze Region ICh. Code (.,OA 4 ' ,.,~"~--'~ Days Drag Set @ z(~.3 Drilling Morning Report W~:'5' ~'~/~ ]Field ~/-(.d~'/~' ~t~,~---~ TVD ( ~,,~,~.~ PBTD)']Proposed TD ~3 7 MD ~ ~ TVD DFS Total Rot Hrs Hrs. y Y Days Hrs. Rot. Wt. P'U Wt. I Slac~ off w~ MO ~t77 ~vo s,o, ~,~, ~MW Cum Rot. Hrs.: On Casing Liner Set @ JSince Last Cal. Depth Worst Wear ]% Rem Wt. CO Gel WL Pm W;. Material HTHP I Pf MI IGel Icaust,c MD TVD -TOP @ !ther Avg. Drilling Type ]Fv Lig. CIs. Max. Drilling n MD Angle Drectmn ! Set No. TVD Size j Type Totai Length (H.W.D.P.: ) ITrip Chlorides Remarks Coordinates MD IMBT lex bme lEI Stab Salt ICaCl~ Consists of VS TVD SPM Pressure GPM I Je,. Vel. Operations Covering 24 Hours Ending @ Midnight Ann. Vel. Bil HHP Pump HHP Daily Mud IDrill H~O Rig _- -- 0 '" Cum Mud ~ ~/~..~,,,,~ [Daily Tangible Po! H~O uel I' Cum Tangible Oaily Well 301 .~,~,~..-.-lC.,. WelI,~l ?~..)1 fTt Bulk Wt. jBulk Cml. JTo,,' AoPr. ~ d~~ . ~o~ C,O 12]1 fog 3 851 Printed ,ng S A ' CC-Morn. Las[ Cas,ag S,ze q ~ Set @ CO Cum Rot. Hrs.: On Casmg bner Ge! Wt. Material Ilher Avg. Drilling MD ~ ~ ~ TVD ( ~ DFS mTo, , Ro, H,s. Hrs. 73 Days Hrs., /S ~ ~ JSince Last Cal. ~D TVD -TOP ~ ~D TVD ~' C~ tType IFV J PV Y P HT HP FC JSoi,ds ~,o o,m ~.~ Sand J~BT PH I ICL ~CA Ex brae El Stab Ijcaust~cj . Lig. CIs. Sail CaCl~ Pf;Mf Gel Total L~nath ~..~ Drilling Morning Report D,v,s,on A4 4--r/{A Ioate IPage PraDosed TD PBTD) ~'?~7 MD ~, t,'~l-"~) TVD J"/~' ~/i~-,5'~. t//]~g n?/}/'/~l/~/-~' Trmp Trip Chlorides Remarks Max: Drilling / M O Angle Direction ]'VD Type I Ser. No_ ,nt Consists of (H.W.D.P.: ) Coordinates V S out I Feet Bit HHP Pump HHP Liner j Stroke SPM - Pressure GPM Jet Vel. Ann. Vel. Operations Caverinc 24 Hours Ending @ Midnight I P. 0.0 5'.'3d ~1 Daily Mud Drill H20 IR~g Mud Daily Tangible JCum Tangible Oaily Well Pot H,O ' IFuem Bulk Wt. )Bulk Cml. CC,Morn. Dep-',h ICh. Code ~ 4.6 5-0/5'~ I ,./~, Torque Field Las,, Cas,nD Size Cum Rot Hrs.: On Casing Liner Set @ Days Hrs. IDFS Drag Set @ ~ ~,~ JSince Lasl Cal. MD W?,- CO ~"/l~ ~) Type Gel WL jIHT HP F,..~ Pm IRm. WI. Sohds Wt. Malarial Other ,~vg. Drilling J MD jTotai Length Pr;Mr IGel /ICaustic Max. Oriiling JConn Trip Angle Oirect~on i Type Set. No. i Jets TVD g~WSlOn PBTD) Proposed TO Days P,'U Wt. 5'?77 Drilling Morning Report lOaje IPage ',/-.!-g~ I of / Hrs. J /~' 5'//Z. TVD [Oepth Worst Wear % Rem I Slack Off WI TVD JShoe Tesl EMW TVD - TOP @ MD TVD IFV ]PV YP I CA Ex Lime jE, s,,,, CIs. Sail ICaCi~ Remarks Coordinams Out Feet VS ITnp Chlorides (H.W.D.P.: Consists of SPM Pressure GPM Jet Vel. Ann. Vel. B~t HHP Hrs. Operations Coverinc 24 Hours Ending ~ Midnight Pump HHP 3:30 - d:30 17:~ - - 21:3o Daily Mud Drill H~O Rig - o - JCum Mud IPot HzO ~ ~,i ,.~, ~Fu e' Oaily Tangible ]Cum Tangible Io"'k w'' Well JcumWell JBulk Cml. Appr. ~JJ ~ 6 I Acc~denls P,,nled ,n U S A 'raj3 ~lnBl IlaM Al!e0 O~H md ] pnW LUng """' {~" pnW Al]el D~H IluO J iq6!up~R ~ §u!pu] sJnoH b~ §uua^o3 suo!mJad0 dHH duJnd dHH 'laA 'uu¥ 'laA iar' nd9 aJnssaJd RdS ( :'d'a'M'H) lo sls!suo3 dwnd I i laaj in0 Ul 'ON 'Jas adA1 j ' i SA saleu!pJoo3 s){JeLUaj:l] sapuolq3 d!J1 0Al uoIDaJ!0 d!JlI 'uuo3 .,¢'l"]"lntCNfl 4~ I ~13e3J lies 'si::) -raj a!lsne3 qms J]J a~l x] ¥3 13 / Hd 1818J pucS o, tJ ,o sP]'°sI ' 3JI dHiHr/'4~-:0~ aA1 @ dO1- OAI O~ @ ),aS LL 63' o~ £C~27 ~ ~.s l, Jodal:l liu!uJOlAI §UJllPO 03{ iM Jau:Jj ~u,se3 u0j ~ :SJH 'ioB u. Jn3 ~' ~/~_~""'~ a~!s ~u,s~3 ~se~j anbJ°i ~- I I'(, ~ ~1~7 IIBM NO2)O~N3 ~u~oLUo~ 'uJoil-33 ~ 'CC-Morn. Company J oep,,h Torque ~ J Cum Rot. Hrs.: , I I On Casing L,ner Wt. Set @ Pm Wt. Material Other JAvg. Onlling MD CO Pti Mt Gel MD Days IDrag ich. Code JRegion TVD ( 4l/~' ~'~ PBTD) ]Proposed TD Hrs. IDFS Set ~ 6~'0 ~ Days JSince Last Cai. Rot. Wt. P,"U Wt. 1 MD ~ ? 7',7 IDepth Worst Wear MD TVD- TOP @ HT-HP FC / caustic Drilling Morning Report Io'v's'°" Total Rot Hfs Hrs. ,/~ '~ /~--.. J Slack OH Wt. TVD ]Shoe TesJ Rem EMW ITvpe FV JPV ISolids 1%Oil I?c Sand Lig. cIs. ISalt MD tYP TVD Max. Drilling }Conn. Angle Direction Trip JTrip Chlorides ]Remarks TVO Coordinates V S Total Length Type Set. No. Jets (H.W.D.P.: ) In I Oul Feet Consists of SPM Pressure GPM Jet Vel. Ann. Vel. BH HHP Pump HHP Operations Coverin( 24 Hours Ending @ Mldmght /-5 ~-.o1~ ?~. £ 17otY Daily Mud..,.- ~2 ."' Cum Mud ~,,.~.~,.~ Daily Tangible Cum Tangible Dally (WellT~/'~5~ JCum Well,~;~ Drill H,O Pat H,O iF.el ]Bulk Wt. JBulk Cmt. JTotal Appr GO 12~t :CO 3 ~35~ Primed :r. U S A ' CC.Morn. ~ DOL ICh. MD Days Code Region IF~eld Hrs. DFS Drilling Morning Report o,v,~,o, ~/~ ~.~.~ ,~e... ,~ .',~t v.~-r '"" '~'~ ~' >'~'- ;/' / of PBTB) ] {~ '~' .; MB {~'. TVD Days Hrs. IT°lal Rot. Hfs Last Casing S~ze Cum Rot Hrs. On Casing Liner Set @ IDrag Set @ ISince Las'[ Cal. MD Rot. WL P~U WL MD Depth Worst Wear TVD-TOP @ TVO Ish°e 1'esl JSlack Off WL I% Rem MD EMW TVD Wt ~ Pm Wt Material I,'.her w ~,vg. Oriihng CO WL PIiMf Gel [HT-HP I Caustic FC Type ICL Lig. Solids Max. Drilling Iconn. ITrip % Oil Trip Chlorides FV % Sand IPV IY P lEI Stab CaCl~ Ex Lime Salt Remarks MD Total Length Angle Direction Type Set. No. TVO Consists of (H.W.D.P.: ) Coordinates Out Feet VS SPM Pressure GPM [ Jet Vel. Ann. Vel. Bit HHP Pump HHP Operations Covering 24 Hours Ending @ Midmght I Drill H20 Pot H20 /~ig ,3 5/-'~ ~' IFuel IDaily Tangible ' / ~ -?c,' .~ Cum Tangible Daily Well ~,/~, .~ ~ [Cum Well :;,y'_~ ~%-~_<~/ ¢ GO ~2!1 Pnnled in U S A ICum Roi Hrs.: Casing Drilling Morning Report MD ICh. Code k~,~/L~o/~ ~ TVD ( IField ,~ z O~vision : ' Proposed TO -~'/'? 7,;? 'PBTO) MO r" 0 --,-~) ' L~: ~ ~, TVD Days Drag Hrs, JDFS IRot. Wt. Set @ ~0'0 :~ Lmer Set @ ISince Last Cal. MD ~: ? 77 IOepth Worst Wear IP'U Wu MD TVD- TOP @ Hrs. Total Rot. Hfs Slack Off WI TVD ]Shoe Test EMW Rem. MD TVD WI. Pm ICO IPf, Mf Gel WI. Matenai I,:her IHT HP ~,austic CL {CA I Lig. Cls. Sand IMBT IPH tx Ume Salt Stab CaCI~ Avg. Drilling ~ax. Orlilmng Trip . I Trmp Chlorides IRemarks Angle .Direction ]'VD Coordinates V S Total Leng[h Set. No. i Jets In 1 Out Feet d (H.W.D.P.: ) Consists of SPM Pressure GPM Jet Vel. Operations Coverin( 24 Hours Ending @ Midnight Ann. Vel. Bm! HHP Pump HHP Drill H~O IRig I Cum Mud IPot H~O CC-Morn. JCompany -, . , .-- ;.j .-:. - :_~.:~ '. . -. .~ OOL Torque Last Casing S,;e ._~ Cum RoL Hfs ~ On Casing Liner I 5 MD Days Drilling Morning Report ... ,., IProposed ID ,.,, --,-.. -. .. :'--"- TVD ( ":' "" ;;' - -' I~BTD) '.-- --. MD " ' .... ,, ]DFS }To,al RD, Hrs Hrs. -~ ~ Days Hrs. /~";~ '~ Wt. IPiU W!. IOrag Depth Worst Wear !SnceLast Cai TVD 1Sh°e Test J~'c Rem Set @ MD TVD -TOP @ ~m ]PIiMf Wt. Material ]Gel ),,her IStack Otf W! ~vg. Orilling MO TVD EMW I TotaJ Length MD TVD ICaus tic lig. CIs. Salt · "S": ./ IY P let Stab CaCl~ Angle Direction TVD Coordinates V S I I Jets Type Set. No. (H.W.D.P.: ) SPM Pressure "I Consists of Out Feel GPM Jet Vel t Ann.I Vel. Operations Coverm( 24 Hours E ~ding @ Midnight . Bd HHP Pump HHP Daily Mud ICum Mud Dnll H~O Pot H~O I Fuel I Rig _ ~ .~,~ .-_ IRig Ph~.e.... - I Daily Tangible ICum Tangible IDalIy Well - ICum Well . ,,. IBulk Wt. ]Bulk CmL )To~al Appr. .. , .. ] Rep./, ,-' . ~ ]Accidents Drilling / : .,,. _ "/~.' '-.. ' : .-: -. C,O 121! ,CD Pr,hied :n g S A CC-Morn. j~ JTnrnue ,.~S..:; 0 ? MD .:,, Days Last Casing Size Cum Rot Hrs: On Casing Liner [~ei Wt. Matenai Other !Avg. Drilling MO Set @ CO IWL Pf,Mt Gel Max. Drilling Angle No. J, Size I Total Length ich. Code JOrag Set @ ~ :'/> T V D ( //..r?,7 ISince Last Cal. Caustic IDFS -- ; Hrs. '"'- Days Direchon HI'-HP Drilling Morning Report Type Ser. No. MD I Div]s~on .- , :...,,Ar- FC Rot. Wt. PBTD) iPr°p°sed TO ~.-$.':'" '.; ? MD .' 7, ~- ' ) TVD P/U Wt Urs, MD TVD Oepth Worst Wear 17o Rem I Tolal Rot. Hrs Slack Oft Wt Shoe Tesl EMW iType Conn. ITrip TVD TVD - TOP @ MD TVD .... / ISoilds ~/e Oil I% SandEx L,me ICL/~'.'~'~-z''' CC~' I bg. Salt MBT I Y P IPH ~/~ El Stab CaCI~ (H.W.D.P.: ) ,nI Consists of Trip Chlorides Remarks Coordinates VS Feet SPM Pressure I GPM I Jet Vel. I I Operations Covering 24 Hours Ending @ Midnight Ann Vel. 8~t HHP Pump HHP IDrill H~O Rig Daily Mud _ Cum Mud - ..-; --,. ~ ,~: ,-~- ~7 - . _-.~'? IPm H~O JFuel -, Rig Ph~e--. , : -~.,-~ .- ~ Tangible Cum Tangible Da,l¥ Well~.. -'-' "> / Well-'~,7 -'~ / ],u,,w,. I"""CmL I,,,, Drilling Rep. ? -,: . IAcc'dents '-"'.. -, .', ". "". ' _' ' ,-"?' ~. ~ ~-: .-'>_ ~r ~:.,, -.. szuap!oo¥ , ~ ~ : 'dab 6U!llU 'iuJ3 ,,nB{ 'lM ~ln81 ,an, J OZH ~odJ I · --- - ~ ..... '-~ IlaMLun3 '':' c"IIBM^HBO pn~ Zl!ea OZH IlUO I ...., ,~,~?;'/ ~ ' · ' 7 ' " " '- '~' '* ~ ~ · ; .~ .;,,,--. m F '" "? .: '~'' .' ";"' '¢ZU' ..~ ~.'//a.L ~-,~ _~::,,-;? ~ ', · , ;~.~ ? ,.? -~ ':">'"":> .... '7 , , . . . , _ _..? . . , . , "' ::': ' -' '"'"" '-' ? ' .... ~' : ..... ':'--" '""-'-'"": - ~ :~"~' " ~ ~' ~ ' ?",",~ I -", ~ I 'q§,uP!V~§u,pu3sJnoH~§ulJa^OgSUo,'eJado I 'sJH I OHN dLUnd OHH i!B la^ 'uu¥ la^ ]ar I/~dg aJnssa,d I/~d§ a:~oJi§ Jauil duJnd . [ SA ~o s]s!Suo3 ( :'d'O'M'H) laa:l ~no Ul I · oN -iaS adL1 saleu~pJoo3 OA1 uoqg@J!O a!Euv s~Je,,,auI saP,JOlq3 CI,J1 d,JlJ 'uuoDj Du,IIU{3 'xe~ qe~s 13 awll x3 ¥3 '" 13 acJ^j OIAt @ dOl- aAl aA1 M~3 lsat ~oqs CAI alAl SJH 108 I8i0i ~ ;' ''~' Plmj J ' l~/Jd m., a6ed f ' '- 2:-' a~e0 ' : /"c'~/ · ,,,? ,. '~; '.,' [ : t, UOiSiAi{3 ~Aodatl §u!u~olN §U!llPO sJoJ 'SJH o~ le3 isel a~u!sJ las BeJoJ sAea O~ apo3 'q31 Wd 1Mr {a9 03J :7 .///7 '~M JAW1{ :'SJH '108 uJngj az!s 6u,se3 ]seii @ ~,aS anbJO1 100 ~' q!dao IlaM 'u JoIN-33 CC-Morn. I "_-- b ~ MD ,DOL Z( ..f_'? Days !Torque IOrag Last Casing S~ze --~..., ,,/,;~-' ~.' Region Ch. Code , ./~'. ,.,,._...,.,,~ ,, ../ :. ': ..... ! (,/ ./T,5,-'.,~- ~' ..... > , ~: .4 · ~_,z' _>-'-, d TVD ( L/'_ ~:.,'"'_ . .5' i~'BTD) Proposed iD Hrs. ~ Days Rot. Wt. P;U Wt. Drilling Morning Report Set @ ~ r',m Rot Hrs.: ISince Last Cal. ,..- ~_ ,,, _ i,-,; ~ ,' 'v/,: .~' ~ :: .~' O'?.; MD (: '??,~,"', TVD Total Rot Hrs · · ,' Hrs. ,'z, -, , JSlack OH Wt .., Shoe Tesl MD '" '/-/ / TVD EMW Liner ~W~. · / ?. -- ,Gei Pm Wt. Material ilhe[ Set @ CO WL Pf;MI HTHP / iCausuc MD FC Type Depth Worst Wear I% Rem TVD - TOP @ MD TVD ,/ PV Sand lex brae Salt MBT ~,vg. gnihng MD I No. S~ze T.~ta! Lengm Max. Drilling Angle Conn. Direction Ser. No. ITrip TVO Jets I (H.W.D.P.: · ~ / /, / Solids I% Oil Lg.C L/'" :'J :~C"?d'"' IcA CIs. ,n ; ITrlp Chlorides Out Remarks Coordinates Feet VS S PM Pressure Consists of ) GPM Jet Vel. I 24. Hours Ending @ Mldmght Ann. Vel Bit HHP J Pump HHP OPerations Coverin( Daily ~,,d ICum Mud I ~'i-?I ':-'? -'"'" JDrill ",0 - I Pot H~O ; "' Fuel I Rig ,,~..? .: ;;,-- /t~-:~/~' JRlg Phone ... - ( :5~.-, ? ) - ,. Tangible Cum Tang,hie Oaily Well.~._.. .... .7~.~ ~..?.~ ~,,..)._.~. ' "; '"' ~ j--, / ,~t- '~' ,' ~ ~_ .'."~:r..' ', ~r-x,,,.. ~,"~ GO ~211 ..CO 3 55i (~ ' ~ f// "r" Pr;hied ;nd ,S A ! Drilling Morning Report Company .~ / <-- .,,I Region Oivlsion ~. Oate..., ~ ..,- of Well ,. ,""'/ ~ L ', ,. ''~//" ~ Ch. Code ~..t,//~.~/.~ ~ ~, /.~ ~ Field ~,~,(~,~ ,.~,,,.~x~ . ....... Proposed TD PBTB) MD ~ ~ ~ TVO OOL ~, ~ OFS ~' "~ ~ (_, Hrs. / (' ~ Days Hrs. ~ ~ Days . C · - Torque ~Orag ~Rm. Wt. P:UW: , . '~ EMW Cum Rot. HRS.. Depth Worst Wear J:~ Rem On Casing JSince Las[ Cal. Uner Set @ TVD - TOP @ MD TVD Wt /"'7 :') CO MD /~:;'.'?'-'~ () Caust,c JL,g. C,s. Salt Pm YP El Slab CaCI~ Wt Ma[er~al thor ~,vg. Drilling Max. Drilling Total Lengm M O Angle Oirectmn TVD Coordinates Type Set. No. I (H.W.D.P.: ) Consists 0f Out Feet VS !1 J~ Pump Liner Stroke SPM Pressure GPM Jet Vet. Ann. Vel. Bd HHP Pump HHP Operations Coverim 24 Hours Ending L~ Midnight ~)/). ,.,., - -,~.~? ~lCum Mud -'-', J OaJJy ~ Oa,ly Mud _/.? ,..~' & .? (/~/~ ./ Tangible Rig Cum Tangible Daily Wel ~ c ,..,-, . ,...- o,, . JBulk Wt. ]Bulk Cmt. JTota, Appr. ~ Rig Phg~ P',nled ,c U S A ICh. Code Days Torque LasI Casing Size Cum RD,. Hrs.: Drilling Morning Report Olvision 4 '../.r ~, Regm L~.L,/p. ~ . v ]P~opos~d ~D ~ -., (~" P.U WI /~.~ ..-, ~. <; .... [Shoe Tes[ Set @ ,_-.n; .,> MD ., , ~ / TVD~ EMW [Depth Worst Wear ]%Rem lSince Lasl Cal. On Casmg JLmer Set @ Wt. ~ ...~ CO Gel ]WL MD TVD- TOP @ MD TVD Pf;MI ¢ 4- 1 ' 'l .fi, ' i ':iX.. · ~l~. c ~.- Salt icao, Gel Causbc - Lig. JMax. Or,iiing Conn. .Trip JTrip Chlorides Remarks Angle Direchon TVD Coordinates V S No. ! S,ze oral Length Type i Ser. No. ! JeTs In Ou: Feel (H.W.D.P.: ) Consists of SPM Pressure GPM Jet Vel. B~I HHP Pump HHP I "~i Pump =1 ! I DnerIS,:roke I I Operalions Covenng 24 Hours Ending @ Midnigh! Ann. Vel. Rig /].~ ~' ~'" ~ ~c? IRig Phone . --. [Or,lling Rep. ...... -??" '-' '. ~ ~ ~ JDady Well ,.~ ( 7'~,"'JCum We',,,;",(',, . /'".., j' M 7' ~ ' "'-7--'"~ 1 Accidents I GO 2]' ,CD :? 55, Pt cleo r. d § A · CC-Morn. LCompan¥ ~ OOL ,.- '~" Torque '/7 Days i Last Casing S:ze Cum Rm..Hrs.: ~On Caslnq ILiner Pm Wt. Matenai ):her Avg. DrlilJng No. I S~e ToTal Length MD iDrag Set @ lSince Last Cal. Set @ ~o ZbF C 0 WL iHT HP IRot. Wt. IPf/Mf Gel MD P;U Wt Max. Drilling ]Conn. JOepth Worst Wear Drilling Morning Report OlvlslOn Total Roi. Hfs Hrs. J Slack Off W! TVD JShoe Test Rem MD EMW TVD -TOP @ MD TVD ICaustic FC jType I /'~'~ Solids % Od Lig. CIs. FV Sand [MBT Ex brae Salt Angle Direction V S Type Set. No. (H.W.D.P.: I PqW. Y P Stab CaCb Trip [Trip Chlorides IRemarks TVD Coordinates i Jets in 1 Consists Feet SPM Pressure GPM Jet Vel. Ann. Vel. 24 Hours Ending @ Midmght ~.. BII HHP Pump HHP "1'12-:, 4'3-7.~-- Daily Mud Drill H~O IPo! H~O 'CC-Morn. Oep.th ~ ~. ,OOL 13 Torque 'Last Cas,ng S,ze ~> ~/~ Cum Rot. Hrs.: On Casing ! ilL!net Set @ 0 c?, ~ WLC Days Pm Wt. Material Ither Avg. Onihng Max. Drifting M O Angle Drilling Morning Report J Proposed TO ~ ~ ~ MD ~ S ~ TVD ( ~0 PBTD) d/~ 7IMD ~X~ OFS Toial Rot Hrs ~ Hrs. ~0 Days '~ ~0 Hrs.I /~ ~ */* Depth WorsJ Wear % Rem JSince LasJ Cal. MD TVD-TOP @ MO iHT HP FC ICaustlc $ohds I ~."O Oil Lig. * CIs. Ex Lmme E1 Slab Sail CaCl~ of / TVD EMW TVD IConn. ITrip Trip Chlorides Oire¢,ion TVO Remarks Coordinates V S I I Total Length Size Type Ser. No. (H.W.D.P.: f- -, Out Feet Consists of ..~ , ,~,?! SPM Pressure GPM Jet Vel. Opermions Covering 24 Hours Ending @ Midnight Ann. Vel. I HHP ! Daily Mud IDrill H~O CC-Morn. Company Wetl Oepth Torque Last Cas,ns Size ? ~/~., Cum Rot. Hrs.: On Casing Lhqer Set @ · ICO Pm Wt. Material )ther Avg. Drilling No. To:al Length Days Drilling Morning Report MD ~"~',~ ~, TVD ( Hrs. ~ / Days Drag IRot. Wt. P,'U Wt ISince Last Cal. 1Diws~on _..~"~j 0 PBTD) Proposed TO .s ?.:7, Depth Worst Wear MD MD Date ..-) I Page -:, -,.~e-Z~I / of I Total Roi Hrs. 'd ~' © Hrs. / -.' ,.~ Slack Off W[ TVD Shoe Test Rem TVD EMW TVD -TOP @ I,v 1%0il 1%sand Salt MD MBT Max. Drilling YP El Stab CaCIz TVD Conn. Trip Chlorides Remarks Trip I TVD M O Angle Direction Coordinates V S In Out Type Ser. No. j Jets Consists of (H.W.D.P.: ) IFeet SPM Pressure GPM i Jet Vel. Operations Covering 24 Hours Ending @ M~dnight Ann. Vel. Bit HHP Pump HHP CC-Morn. Company Oeo..:h iDOL j Torque Drilling Morning Report ICh. Code MD Days IOraq Proposed TD ~~ TVD ( ~~ PBTD) ~ ~ MD of / TVD Last Cas,ng S,ze ¢ _¢//~ ", i£um Rot. Hfs: ion Casing iLmer i Set @ Set@ c/~'~f,'/-'L~_~ MD -"57 7;7' /' TVD ISh°e ]'est 1Depth Wors' Wear tic Rem !S ~nce Last Cal. MD TVD -TOP @ MD EMW TVD jGel CO tCausuc L~g. CIs. IPm iWt. Matenai ]Other Avg. Ortihng MD (3, iE! Stab CaCU Max. Ordhng i Totm Length Angle O,rection TVD Coordinates V S Type Ser No. I iJets (H.W.D.P.: I Consists of -,1: :]C"C' '"'l Out Feet . o SPM Pressure GPM ~ Jet Vel. Operations Covenn( 24 Hours Ending ~ Midmght Ann. Vel. B~I HHP Pump HHP Daily Mud JCum Mud I I P,.r, led .r, d S t~ ~ ~'~,~ MD ~5.~6 TVD ( Drilling Morning Report o,v,s,o ~.~.., A ]Proposed TO ~ ~ .~ ~ r~ ~' PBTD) r~, ~ ~ MD ~¢0 TVD / . lTotal Rot Hrs ~C~ Hrs. /~_, ~ '~ i l CC-Morn, we~, g~f ;/I'~ I ~Dep:h DFS ._ ~ ]OOL ~ ~ Days Hrs. ~ / Days ,~orque }Drag IRot. Wt. JP'U Wt. ]Slack Off WL Last Casing Size Cum RoL Hrs.: }Oep,h Wor,[ Wear 0¢ Casing }Since Last Cal. TVD -TOP @ [.ner Set @ MD Wt. Material i Gel , Caustic Lig. I lO,her IAvg. Drdling V!ax. Drilling Conn. Trip Trip Chlorides }Remarks l EMW MD TVD NO. J~,,~ iTotal Length i Size Angle J. O~rect~on i Ser No. Type : Jets TVD · Coordinates V S In J Out I (H.W.D.P.: ) Cons,sts of Feel Pump I Liner S.~roke I' SPM Pressure GPM Jet Vel. Ann. Vel. Bd HHP Pump HHP Operations Coverinc 24 Hours Ending @ Midnight /'/~C ('/'3PO 5 . Oaiiv Mud /) __ Drill H~O Cum Mud Pot H~O Total Appr. ~,,,6 .r..'/,' .~/00 ,, Acc~denls Pnn!ed ,n ,j S A CC-Morn. ICompany Torque [rum R~t. Hrs.: [~n Casing rLmer Set ~ Days Drilling Morning Report IDiViSlOn i!"g'°n Hrs. Ia°t' ..~'~ Days I Drag Wt. Oepth Wors[ Wear ~S~nce Las[ Cai. ~ Rem l°ate3_/?_,¢ Mrs. iTota, Rot Hrs //,~..~.. ~ MD TVD-TOP @ MD tSlack Off W',. /'of) TVD EMW CO FV PV Wt. Material }Gel ICaustic Llg. CIs. Other MBT TVD Stab CaCI~ M O Angle Directien 1-VD Coordinates V S ' ITo',al Ler, gth I Type ] Ser No i Jets I ] (H.W.D.P.: ) Consists of Ou[ Feet SPM Pressure GPM Jet Vel. Ann. Vel. t Operations Covering 24 Hours Ending ~ Midmght Bit HHP Pump HHP /,.~/,f M TYP£ Drill H~O Tangible ible HzO Fuel Bulk Wt. Bulk CmL Total Appr. 121! ,CO Pr,riled ,nd CC-Morn. Dep.',h i~ DOL Days Code Field Drilling Morning Report IOiv,s,on ALASk'A I Proposed TD PBTD) 6 ~,.~ 7 MD ~ ~0-~) TVD Hrs. IDFS Days Hrs. IT°tal Rot Hrs i'~' ]Torque ]Last Cas,ng Size ~Vt. Material I '= Avg. Drilling Length Drag Set @ 'IR°" w, JSince Last Cai. MD MD IP/U Wt .S777 iDepth Worst Wear Slack Oil WI TVD lSh°e Tesl 1% Rem. CO JWL 6 PI/Mf Gel JHT-HP Max. Drilling leben_ 0.6 Caustic Angle Direction Type ] Ser. No. JJets TVD-TOP @ / /& * o,, [ig. Cms. FV PV v"7 ¥o Sand MD (H.W.D.P.: ) ITrip JTrip Chlorides ]Remarks Ex Lime Sal! YP El Stab CaCl~ TVD Coordinates V S In I ou, Feet Consists of EMW TVO SPM Pressure GPM Jet Vel. Ann. Vel. Bn HHP Pump HHP Operations Covering 24 Hours Ending {~ Midmght Drill H~O Pot HzO Rig/~5~ ~ 5'? Daily Tangible ICurn Tangible rw,, 3e~ 0~[ J~,m w,,, 6~,% ~, GO 121t CD 3 Pr,riled .n U S A CC*Morn, iCompan¥ DOL 30 Oays Hrs. A Y Days Drilling Morning Report Cum Rot. Hrs: [Depth Worst Wear On Cas,rig q ~ JSince Las, Cal. -- ] -- liner Set @ MD TVD -TOP @ Tolal Roi. Hfs Hrs. /75'/1' I S~ack Shoe Test Tvo /2, ~ EMW ~m 0 ~'~ ~ / 0.~ W~. Mamnal ~ ~ei ~ga.sUc I Avg. Drilling ~ ~ax. Drilling ~ - ~ ' M D Angle OirecUon Rem. MD TVD ig. CIs. {Trip /6 [ Trip Chlorides _.__ {Remarks TVO Coordinates /.~ ] Pum i Hrs. :-qF · 'V ! i ] Liner I StrokeI 1~f14 R F1- TOOL, SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP I Operations Covering 24 Hours Ending @ Midnight t~ltl lZ) <IR( 4-¢0N0 t.fOt5 ~DR r_A.r//V¢, ffAO 7' FIZL off ~01'1~'1, Drill H~O //~,~, Cum Mud ~(,~ ~;~,f~ IDail, Tangible ICum Tangible 1211 ~CO 3 85~ P,,nted .n ;J $ A CC:Morn. Drilling Morning Report MD In°g'°" ~eS-/'ER/V ~,v,s~on ] Proposed TO OFS Total Ro~ Hrs ~0 3/lY Days iOrag Set @ .~j ~G Jsince Last Cal. TVD JShoe Tesl Depth Wors! Wear ~ ] % Rem MD TVD · TOP @ MD [Gel ~ / WL HT HP I 3/'~//3 I F-:~ I - Pm ' Pf/MI Wt. Material ~ ~Ge[ Other ~ iAvg: Onlhng Max. Drilling Conn. M B Anglo Olreoion LFC / ¢.'7 ICaustic: /5- 1~P lO, Trip '~)~1~ Trip Chlorides .----- Remarks TVD Coordinates VS of/ TVD EMW TVD ! SPM Pressure GPM J Je', Vel. Ann. Vel. Oil HHP I I Operations Covering 24 Hours Ending @ Midnight Pump HHP AlYO ~.OIvO /-AOZ£ £bt~ r 17'07 1'~ 6dNFI/~M, / Daily Mud Drill H~O Cum Mud Pot H~O SO !21~ 'CO 3 851 P, n~ed :n J S A ' CC-Morn. Company MD Drilling Morning Report 6~ £ ~; r~ tf iy AL A ~14A ICh. Code [Field IOote IPage i P~oposed T~ . g ~ 2 7 TVO ( PBTD) g ?'3'7 MO ~ ~'(..~ TVD DFS JTotal RoT Hrs. , /3 , /~o -/~o J s~ ~r 1.;2 Ir I~ ~ ~,o~ W~ ?'~ leo~ MD /~SOe/~/0 - ~ MD J~ TVD Wt. Material ~ . Lig. CIs. OTher M D Angle DirecTion TVD CoordinaTes V S J g LS I .~~ 1 n~'Z, I" I" ' I e~m ~'~e '~P I -~ I : I -I,: I -1 - 1 - 1 Hrs. J ' ' Opera[ions Covering 24 Hours Ending ~ Midmght 2t.5-- Pot HzO Daily Tangible Cum Tangible IDailyWe~ ICumWell ~u~, t"~'~''' I~''~'' ~.7~1~,~' ,,,:~./'~, ~ 7~-- Pr:nred P J S A 'CC-Morn. On Casing Liner Drilling Morning Report J ~roposed TO - MD ~ ~ ~ TVD ( PBTD) ~ ?~7 MD ~ ?~O TVD Days Hrs. ~ / Days ,y~ ~ Hrs. /.~ ~ / 4/.5-4' Set @ 3 i YO MD 3// Y TYD JShoe Tes, I ~' 0 EMW Jgep,,h Worst Wear J!/o Rem ~ JSince las~ Cal. ~ ~ Set @ MD TVD - TOP @ MD TVD 0 HT-HP ~ iFC 0 Pr, Mr . Wt. Matenal Gel jCaustic Other X PO u;s 5'~d,~ A~- A - 1 Avg. Drilling Conn. I I JTotaiLength 1151,29 {H.W.D.P.: gl~.41 J co.~=o~ ol'r, ~s'"/rl,,e. g"i~v~EL , ~~. ~o~' -. ~. ~* . ~ -~ ~, , , Hrs. .ll~ : Liner Stroke I i SPM Pressure .5"Y /gOo i GPM Jet Vel. Ann. Vel. I .377 . ;?q.Z '?/ P~ J io706 1 I Operations Covering 24 Hours Ending @ M~dnlght Bi[ HHP '.2 2~' Pump HHP ORILt..~O F/5"~37' T/617f''~- gWAbf//v~: IY6c. J /iW..~.. o,y <ONNW, rtotys'. FOR Daily Mud Orill H~O Pot H~O Mud Daily Tangible IC.mTangible ]Daily Well Fuel IBulk Wt. JBulk Cmt. Rig Ph°n~'~Jl'~,)'~) '~"'~" ~7~3/'~/f ]Drilling Rep' ~" ~'I'-c(-~K Drilling Morning Report 81¢~ Ril-3 ~4 O- ~o/ s-~ ~Z~ ~ ~tuE~ -I/Ti I o~ I Proposed ID Cum Rot. Hrs.: Depth Worst Wear ~% Rem On Casing ~ 1Since Last Cal. -- liner Set ~ M~ 1~ · 10~ ~ M~ 1~ ~t. Material ~ Gel Caustic Lig. CIs. Salt Avg. Drilling D~ Max. glling 80 IC° ' 's~/d Z~ Chl°rideL ~V~ M O Angle Direclion TVO Coordinates V S BLS No. Size Type Ser. No. Jets In Out Feet Hrs. WOB RPM T B O Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel. B,t HHP Pump HHP Hrs. Operations Covering 24 Hours Ending ~ Midnight Fl5 ' T/r ' _ [Accidents Pr.med ,n U S A CC-Morn. Company O/'/~'dROA/ ash BI{ 6[ ~11-3 loot ~ ,~ Days ~orque IDrag I Last Casing Size 'Cbm Rot. Hrs.: On Cas,ng ~"ff' 7 brier Set @ I ~,'iI. ',later,al 3 3 Gel Drilling Morning Report I · Proposed TO ~/& ~ TVD ( PBTD) ~ f a7 MD ~ Y~ TVD DFS Total Roi Hfs Hrs. /~ o~v, Y?g H,,. I~1'~ Rot. Wt. Shoe Tesl ]Since Lasl Cal. MD TVD - TOP @ MD TVD /.,~ PV YP Lig. Sis. Sail CaCI~ iAvg_ Drilling I MD Max. Orilhng Conn. Trip JTrip Chlorides Remarks Angle Oirec'aon TVD Coordtnales VS No. Siz~ Type / In Out Feet I Hrs. Operations Covering 24 Hours Ending ~ Mldmght ' T/qlS3'-, t~t~51t~ll F/Y~dg' T/Yq.~3: tw4S#~fl + REAM,El? F/q~q~' TO ~ Daily Mud Drill H~O Mud Pot H~O CC-Morn. Hrs. ~ ~ Irorque _/~ Drag a~ ~ Drilling Morning Report Io, I. / '2~ ~V A- 3//Y Tvo Sho~ iner Set @ MD 6% 2' H~-,P__ TVD -TOP @ MD Slack Off Wt. //,.~ K 12.0 m ,~ IPI!MI 7~' Wt. Material 3yO Gel IFC ICaust~c El Stab CaCl~ Avg. Dnlhng /'~ Trip Chlorides ~ Remarks M D Angle Direction TVD Coordmales ' VS TVD I IlL& iZ~" /,'t4LF-- F/¥E36' ~. gl~ FO~ ~,~/t~£/~ 17~1P. EMW TVO I No. Type Ser. No. In Out Feet Ope[a~ions CoYenng 24 ~ours [nOmg @ M~dmght r/'i Y~ / ". · - ~'~zL s'~~iW~-, sz4ck' OFF- P/~ E6~LY -~ Daily Mud ~ Cum Mud Po! H~O J Fuel Bulk Wt. P,,med ,nd S A CC-Morn. Company MD Ch. Code Regmn ~"Ol TVD Field Drilling Morning Report Divis)on Proposed TD TVD iTorque Days Hrs. ]DFS I-2 Days P~U Wt. Hrs. ]Total Rot. Hfs Last Casing Size Cum Rot. Hrs.: On Casing Uner 5-* Nt. Materiai ]ther Avg. Drilling ]Since Lasl Cal. IDeplh Worsl Wear Shoe Test .TVD Rem. EMW Set @ HT-HP PI/Mf MD __ IFc / .Y Causti~ TVD- TOP @ MD TVD Max. Drilling gOO 3 ~;~-'~0 Trip Chlorides .-- IRemarks MD Angle Olreclion TVD Coordinates V S I Type Ser. No. In Out Feet I To,a~ Le,g,, //,.,<'/,S'O ' _. (H.W.D.P.: c~/~ I j Pump J Liner I Strokej SPM Pressure GPM I Jet Vel. ¥1~ 320 Ann. Vel. I ! Bit HHP J Pump HHP :.,l~yI ~37' Operations Covering 24 Hours Ending [~ Midnight ~- CONO f'l~D C~t. tlLE I,U~lgHitV(,-. d? ~ q.5' PY~ T~ ~oTrR~. 'ILL Drill H~O Cum Mud Pot H20 Cum Tangible Bulk Wt. J Oally Well IBulk Cmt. Total Appr. Accidents GO :2~l 'ZD 3 gS~ Pqnled p LIS A ;C-Morn. Company Region Well ~ ~ ~ ~ 1 / -- x~ ~ Ch. Code ~ Torque _ __ ~Drag Cum Rot. Hrs.: On Casing 21'/2. IS'nco Lastca,. 2It& Liner Set @ MD Drilling Morning Report /~ Days Wt. 311'/ coRR£c'r~'~ Total Rot. Hrs. P/U Wt. /a S'" K J Slack TVD [Shoe Test ] % Rem IPage / /o0 Oil WI. of/ TVD MD TVD Depth Worst Wear TVD- TOP @ Avg. Drilling Lig. CIs. Trip ~ ]Trip Chlorides I M O Angle Direction TVD 33~3 N 23.?q "/3PV /7 Ex Lime Salt El Stab CaCI~ Coordinates V S 3~ 2,. 9R 307. 323. ¥7 Type Ser. No. ,,~qo ,.~'"..~ (H.W.D.P.: ¢1t'/' R. 2 In Out Feet Consists of SPM Pressure -GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Operations Covering 24 Hours Ending I~ Midnight 3~ i / //Ad .~IV4I.,L = I ~ud G0-1211 lCD.3 851 Pnnled m U S.A CC-Morn. ~ IT°rque 2l OaySiorag Hrs. IR°t' /¢ Days LastCasingSize Set~ 31gO ~ 311Y Depth Worst Wear [Since Last Cal. ~ Cum Rot. Hrs.: On Casing /3% Liner Set @ MD TVO- TOP @ Drilling Morning Report O,vision AL-AXK,q Proposed TO ITotal Rot. Hrs. Slack Off Wt. Shoe Test TVD 1~. 0 ~- EUW % Rem ~ MD TVD Other ' Max. Dr~ling MO Angle J Direction J Trip .-- Trip Chlorides IVO -Type Ser. No. xl-~ ~os E-R 95-.5-1 Jets ,?-13 Total Length-/i~.q?. ,o~"~ (H.W.D.P.: S P M Pressure G PM Operations Coverin[ j~ J*P ~fl J'"lO.;] Stab CaCl~ .-.-- Coordinates Remarks NId. H VS Jet Vel. Ann. Vel. 24 Hours Ending @ Midnight Bit HHP IPump HHP OuT OLd Daily Mud ~. 3 0 ~ Cum Mud .~3,i ¥ ~ ~, Daily Tangible Cum Tangible Daily Well y~.! ZSToTta }Cum Well CC-Morn. Company CHFU don Depth ..~ DOL Torque Casing Size Cum Bot. Hrs.: On Casing Liner (,ISA Ch. Code Wt. Material Other MD Drilling Morning Report Days Drag Set @ Region ~,~ ~/"'~-~/V ]Division b..'Aig '- SOl 5--6JE~e~d I~£La6'A t¢16q~-i~, TVD ( PBTD) JProposed TD DFS Hrs. iy Days Rot. Wt. P/U s.,~ 3t ISince Last Cal. S//Y Depth Worst Wear TVD ]Shoe Test /2- 0 /0~"._ EMW I % Rem. ~ MD TVD- TOP @ MD TVD :CO Pr/Mr Gel HT-HP ICaustic .__ Conn. ~.0 JTrip J/~J///Jr Direction TVD Avg. Driiling '4 '4 M D Angle Jets 3-/3 ql~. ~ No. J Size Type ' Set. No. Consists [¥P 7 JPu El Stab CaCb J Trip Chlorides/~//!1' ]Remarks Coordinates ~ I V S D ES i {.~ ~. , d~.~ I ' C;*, ~k~t'''' ' ' I SPM Pressure / S'o"¢ GPM ¥/o Operations Coverin[ Jet Vel. Ann. Vel. 24 Hours Ending @ Midnight Bit HHP Pump HHP · rook ~t~Fti£fl NHILE ,41't'Ft-1t~711Y'(- ~ QOK~( I~¢(,'N, ~llOO~/' ~J~5'~-.7'-7'¢/~L. ~iH. TOOL P?FD @ sANE ~Ac~, aNACLE ~ NO~ pA.~, P¢o~ - ~/O ~L. ' t ¢ / Drill H~O Cum Mud Daily Tangible Pot H~O Fuel Bulk Wt. Bulk Cmt: ' ---IRig Ph°ne (.~07] ?¢6- ~¢ 73 L. g7¥? .' Total Appr. ~ ~./i ~,~ Accidems / GO 1211 lCD 3 85J Pnn~ed m US A. CC-Morn. Company (~ ~.E.~,~[~I ~,,~.,~}~f /el BR~ 2,11-3 Oep,h '-3t¢3 MO 3i37 IDFS /? ,,,. 1,3 Drilling Morning Report Region (.~ES"?~-/'~N Division AL/tSi(i~ Proposed TD lTmal RoL H~s. IP/U Wt. ]Slack Off Wt. Cum Rot. Hrs.: Depth Worst Wear ]% Rem. On Casing ISince Last Cal. Liner Set @ MD TVD-TOP @ MD TVD Wt. 0 IFV PV Wt. Material gel [Caustic Lig. 61s. ' Sal~ ther Avg. Drilling Max. Drilling Angle ]Trip Trip Chlorides IRemarks Direction TVD Coordinates V S .M D I Type Ser. No. Jets In J Out L~- lie O?F--/V cw~ Jr Feet SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Operations Covering 24 Hours Ending @ Midnight H i (, H t~R E wS u g ~_ ~E.r T ./¢d Pn¢, "TE $'/'-~ /J A iy4,'o' z ,or ~ VA I.. VE AIl40 Daily Mud 0 ]Cum Mud /~, ~,,~ JDaily Tangible Rig BS~ ¢-- ~--~,, RigPh°ne~"J'O'7) 7~'o/ -¢VJ~ Cum Tangible Daily Well 3 ~,/0 $-iTmaI ]Bull<Wt. ]BulkCmt. Appr. ~/ {~'/./(5~0 Drilling Rep. g.t. WILCO< ~Accidems ~°~e GO 1211 lCD-3 851 Printed ~n USA CC-Morn. Drilling Morning Report ~ J Proposed TO ~ep~h ~/6J MD ~77 TVD I ~Ol ~F~7 MD ~?¢~:~ 'rvo ~ I~°~' ~°~'''~' x~ OOL DFS / ~ ~ ~0 Hrs. / ~ Days Hrs. Days Torque Drag ]Rot. Wt. P/U WL ]Slack Off Wt. Last Casing Size /~ ~/~ "~et ~ ~{~O/ MD ~//~ TVD ~Shoe Test EMW Cern ~et. Hrs.: Depth Worst Wear 1% ~em. On Casing [Since Last Cal. liner Set $ M~ 1~ - lOP $ ~ 1~ ~'- ~.v ~o ~~ ~' ~/~d~x I~v ~ I~v ~ ~ a7 Pm PI/Mf CL CA Ex Lime El Stab ~t. Material Gel ]Caustic tig. CIs. Salt CaCl~ ~ther ~ Avg. Drilling Max. Drilling ~Conn. ~Trip Trip Chlorides Remarks M D Angle Direction TVD Coordinates V S D LS ! ~o. Size lyre Set. No. Je~s In Out [eet Hrs. WOB ~M I ~ G Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Hrs. Operations Covering 24 Hours Ending ~ Midnight ~ [~,J.C. ~z~'.g.~l~ ~,~ I/~ v.f~cs . e. . Prmled ~n U SA CC-Morn. OOL /: Days Hrs. /( Days Cum RoL Hfs: - IDepth Worst Wear On Casing ISince Last Cal. Liner Wt. Material Other TVD- TOP @ Drilling Morning Report I§lack Off Wt. Shoe Test TVD EMW % Rem. MD TVD lex bme El Stab Salt CaCI2 Avg. Drilling M D Angle Direction TVD Coordinates Jets Out Feet Ser. No. VS (H.W.D.P.: ) Consists of J I SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP ~o Operations Covering 24 Hours Ending @ Midnight C.t/ o/oo o,.,.g 5 Drill H20 Rig Mud Cum Mud Pot H20 IFuel jBulk WI, IBulk Cml. ITOtal Appr' ~/~ ~/~/y '~0 r. GO 1211 lCD 3 851 CC-Morn. lCompany ~/_~.~ ~ Depth ~/& ~ DOL Torque Region ICh. Code Days Drag TVD ( OFS / 0 Hrs. Rot. Wt. Last Casing S~,e L/:~ ~¢ Set ~ ~'~£ Cum Rot. Hrs.: On Casing Set @ Liner wt. ?,~'7 Ic° JSince Last Cal. MD Wt. Material Other Ge Caustic. Max. Drilling .7.~ Angle Avg. Drilling MD IField Total Length Type Set. No. MD Drilling Morning Report Days Depth Worst Wear P/U Wt. TVD -TOP @ I,o,,. ] Conn..,~ 0 '-" JTrip Direction TVD Jets In Consists of Hrs. To~al Rot. Hrs, ~"~c~ TVD ~Shoe Test % Rem of / TVD EMW MD TVD Trip Chlorides Coer, linates /7, :3'3' ~j Out J Feet Hrs. W SPM Pressure GPM Jet Vel. Operations Covering 24 Hours Ending @ Midnight ¢ Ann. Vel. I Bit HHP Pump HHP f u,,-0 Daily Mud .~. ?(~ JCum Mud Drill H~O JPot H~O Rig ~ 5Z .~ -?8 CC-Morn. Company (l ~',lJ'/"0~ ~ ~"//~ ICh. Code 6dA ~ 5'0/5'~ ~e~d Depth I Last Casing Size MD Days IDrag Set @ Cum Rot. Hrs.: On Casing ISince Last Cal. inet Set @ TVD ( Hrs. DFS JRot. Wt. 9 Drilling Morning Report Date Page JTotal RoL Hrs. Hrs. 7~ JSlack Off WI. Days / 7 ¢ PIU Wt. Depth Worst Wear MD TVD- TOP @ Gel t ,~ / 0 WL/ ? -2 HT-HP ~ FC , ..~ Pm Wt. Material PI/Mf Gel / IS°lids 5 % Oil Caustic Lig. CIs. Max. Drilling Conn_ Trip Trip Chlorides Other Angle Avg. Drilling Direction TVD TVD Ish°e Test l% Rem. MD MD 1% Sand ///L/ EMW TVD Ex Lime Salt Remarks Coordinates A,/ F ? ~ ,~. :~ f' ¢ . 7.2 / ~ . ¥'~ ' .,V .2 ~ 5( 06' £ M BT~,?~ JPH .~., 5' aND. Size Type Ser. No. Jets In Out Feel ,.~ [, -~ 72" I ~-~'~7'C_~ ~ ~V~J~/ ..~-/~ /~',~20 /~~j I Length //~, ~ ~ (H.W.D.P.: ) Consists of VS SPM Pressure GPM Jet Vel. Operations Covering 24 Hours Ending @ Midnight Ann. Vel. J 4"'~/ J '"'~ ~,~)' Bit HHP Pump HHP ? Drill H~O Mud _,(',~ J ]Cum / ~.~ ~'~-' J Daily Tangible Cum Tangible Daily Wel,~,? 8 7 ~ ~ Cum Well CC-Morn. · IRegion Company /'..~.~.' z'a~,.', ~/- GP: ]Ch. Code Depth DOL //-/ Days MD Torque TVD ( Hrs. IDFS IDrag IField Last 'Casing Size >5:2_0 Set @ z./_;. _~_ Cum Rot. Hrs.: On Casing ISince Last Cai. Rot. Wt. MD Drilling Morning Report IOivision Daze..~ -~ JPage , ,~. - ..,,,. -7 ~ ~,~: · I J ~BTD) IPr°p°sed D Days .... -' -:., P/U Wt. g'?.: '? MD j'?~ Hrs. JTota[ Rot. Hrs. JSlack Off Wt. of / TVD Depth Worst Wear TVD ]Shoe Tesl % Rem. EMW Liner Set @ MD CO Gel ,.~.-,/, WL [HT-HP FC / .x.,, ::o ~, . ¥ .-- wt. Material Other TVD- TOP @ JSolids ~.. 7 , Oil tCL 5C'-0 ICA Lig. CIs. IFv / TO Pv r? ! rl Sand Ex Lime Salt MD TVD · ~-'/. '<'- dj El Stab CaCI~ Avg. Drilling Max. Drilling Conn. Trip M D Angle Direction TVD Trip Chlorides IRemarks Coordinates Q. 5':/'/L/ / L" , ~ p: .,tx NO. Size Type Total Length ~(/~:-(~. ~.._ ~...~ I In Out /'_~'~'o Consists of Feet Hrs. I WI S P M Pressure G PM Jet Vel. Ann. Vel. Bit HHP Pump HHP Operations Covering 24 Hours Ending @ Midnight ¢ Daily Mud Drill H~O C ' Igum Mud ] 7[ ~'~ < I Daily Tangible Cum Tangible Daily Well ?: ,G -~ ~/ Cum Well 6] O ..j~ ~ ~ Wt. ~ - _p_ -, 60 ~2]] ~CD-3 851 :': ~'? P,,med a U S.A. . CC-Morn. Iwell /:7/{~I ,P//:~ = Torque JDrag I J Last Casing Size ~ ~ ,,,, Cum Rot. Hrs.: On Casing Liner Set @ ~vt. t~.~ co ICh. Code Set @ ISince Last Cal. MD Drilling Morning Report of / TVD , .~ ~. ITo.ROI. Hrs. Days .~ .~' ~:' Hrs. I · Shoe Test ~/'~_~ Tw Depth Worst Wear 1% Rem EMW Material Ither MD -~-,/kV CO Type ICaustic TVD-TOP @ MD TVD ,~. PV I % Sand f' ¢/~,~/ Ex brae Salt ~'; ? IY P lEI Slab CaCI~ Drilling MD Max. Drilling Conn. Trip Trip Chlorides Angle Direction TVD Remarks Coordinates Feet Hrs. I WI VS OLS /y'. o/ ,B ] RPM I T B J6 , fO '?~ , - '2 / NO. Size Type Set. No. i Jets I In I 0u, Tmal Length (H W D P" Consists of --- ; -*S · - i '' ; -.- / "z SPM Pressure GPM Ann. Vel. Bit HHP Pump HHP '-/7 _3 Operations Coverim Jet Vel. 24 Hours Ending @ Midnight , / 2'0 ~'' ;sh~. Daily Mud~.¢,,'?;~'7'~ '~ Drill H~O Cum Mud IPot H~O IDaily Well.o .<..---z --~ / JCum Well ~/f~ ...~ :;. ,.',/o <: ?Ze. - ITotal Appr. : ,/ .... ,,< CmL Accidents ,"~-A/~.~ :,..:.'. . . 60 1211 !CO 3 851 Pnnled ~n U S A. CC-Morn. Company Well Drilling Morning Report I Region ICh. Code~,~,,~ PBTD) Proposed TO IDivisi°n /'-//0,5 U..rt (>( ,2 i/ IField MD [ 30_.~ TVD ( DOL Torque J DFS Days Hrs. IJOrag JRot. Last Casing Size Set @ /-j 5'_,'2 ~ MD Cum Rot. Hrs.: On Casing Liner JSince Last Cal. Set @ MD Days / 0 ~- IP/U Wt. 9'7: ' IOepth Worst Wear Hrs. IT°'"' Hrs. TVD JShoe Test I% Rem. EMW TVD - TOP @ MD TVD Pm (~ , q Wt. Material ther ~/~.- ~O JType IHT-HP __ FC ( Pf/Mf ~,Li~ I d, ~(-~ Gel Caustic JCL Lig. Solids q _,<'(~ Sand ,,~/y MBT ~,.$ PH /0, ..~ Ex Lime IEI Slab Salt /CaCl, ~.vg. Drilling MD -'1 //.? /~./5- Max. Drilling Conn. Trip Angle Direction J No. I Sizej Type lTotal Length Ser. No. TVD I Jets In (H.W.D.P.: ) _lTrip Chlorides JRemarks Cool inates VS DLS .-- O, '~"%Il /" /,? Pressure GPM Jet Vel. Ann. Vel. Operations Covering 24 Hours Ending @ Midnight Bit HHP Pump HHP 4 - / / ' ' ' /-'.: ). Drill H~O' Pot HzO CC-Morn. ICh. Code DOL Torque Drag Last Casing Size IRegion ./.- IField TVD ( Hrs. IRot. Wt. Drilling Morning Report ' Date ~ .,, , J Page ,. ~IPr°p°sed TO PBTD) ~' ~ ~ 7 MD ~ ~)(_,~ TVD Days '",~"~"' Hrs. Total Rot. Hrs. mP/u W' m ~ ~,~00 ISlack Off Wt.~ / ~ ~,.% Cum Rot. Hrs.: On Casing Set @ -//:t,_); " TVD Shoe Test 1Depth Worst Wear I% Rem. Liner Set @ JSince Last Cal. CO Material Ither MD TVD -TOP @ MD /(2_~ < jPV % Sand //~,, O. ICaustic - CL ~'£,5~) ICA Lig. CIs. EMW TVD IMBT,.j,?Z,.~- I,H /(~.-/,? Avg. Drilling MD ~ax. Drilling Angle J No. ] I Type JTota Length Conn. Direction Trip TVD Trip Chlorides ]Remarks Coordinates Out Feet /c:37 5.2. '~ .5:'7 ' 5'51' VS DLS - (H.W.D.P.: Consists of SPM Pressure GPM Jet Vel. Ann.i Vel. I Operations Covering 24 Hours Ending @ Midnight Bit HHP Pump HHP .. _,,'7 - Drill H~O Rig ,.- ?~',? GO 12tl (? " ' : Punled Jn CC-Morn. iDepth DOL Torque Days Code bu,4 ~/' .~' .-,'~ TVD ( PBTD) Hrs. DFS ~/ Days IRot. Wt. Drilling Morning Report Date.,,) .-~ ..:, .---.- Page IProposed TD MD ¢~ Total RoL Hrs. TVD Last Casing Size IDrag P!U Wt. < ~ O~C) Slack Off Wt. 'L7".~'~, ...,," TVD ShoeTest fl'O '" Cum Rot. Hrs.: On Casing Liner Wt. ~ ~el Pm i./ V,/t. Material Set @ Set @ ISince Last Cal. MD Depth Worst Wear ther co _Z-/~-: WL / ~ HT HP,~ Pf/Mf O, 7 / Ge Type Caustic TVD-TOP @ ]% Rem. /. / Solids L/" i% Oil Lig. CIs. MD EMW Avg. Drilling MD 'mai Length Max. Drilling Angle onn. Direction Type Set. No. (H.W.D.P.: ITrip TVD Jets In I Consists of TVD VS ITrip Chlorides Remarks Coordinates Feet S P M Pressure GPM '_~0 / Jet Vel. Ann. Vel. Bit HHP Pump HHP Operations Covering 24 Hours Ending @ Midnight gaily Mud Drill H~O Cum Mud 7 :~!~ I Tangible Cum Tangible IPot H~O Bulk Wt. Rig Pho(~,~ 7') ~(-~ Drilling Rep. /4/'~:~: >~ .~"Z C/Z/ GO 1211 lCD 3 cc..o,.. Drilling Morning Report D0L ~ Days Hrs. Days ~ ~ · IDES .~ Hrs Total Rot. Hrs. Torque 1Drag Rot. WI. P/U WL Slack Off Wt. ~7 Shoe Test Las, ~asing Size ~" Set 0 ~ ~ ' MD ' Tva EMW Cum ~ot. Hrs.: Oepth Worst Wear I% ~em. On Casin~ lSince last Cal. liner Set ~ MD TVD - TOP ~ MD TVD Pm IPf/Mf ~ ,7 CL iCA Ex bme [1 Stab ~ , / ~./5 / 7¢0 Wt. Material Gel Caustic lig. CIs. Salt CaCb ' ~"~"--"--~ / ~ ~,'c~ ¢ .~ &vg. Drilling Max. Drilling Conn. Trip Trip Chlorides Remarks M O Angle Direction TVD Coordinates V S OLS No. Size Type Ser. No_ I Jets In Out Feet Hrs. WOB RPM I B G lotal [en~h {H.~,DP.: } Consists o[ Cum~ liner S~mke S~M ~ressure G~M Jet Vel. ~nn. Vel. Hrs. Opm~tions Co~erin~ 24 H6urs [n~in~ ~ - q ~ !/' - ' ' ' (/- - ~'&' ' : ~ . // / ' [-.- 60 1211 iCO 3 85~ Pr,riled :n U S A CC-Morn. Company ~,~ Torque Cum Rot. Hrs.: On Casing Liner Pm Wt. Material Other IAvg. Drilling MD DOL ~"~ Days Last Casing Size IRegion ~/~' ;~"~ / TVD ( DFS Hrs. ]Dra~ Se, ~ ? ? ~ ]Since Last Cal. Set @ MD Drilling Morning Report __, Date ., ]Page IF~e'd ~e~:,,-.. ~',~.~.r [ ,Z-,2/- ~,1 17 I~roposed TO .... Days · MD ~ -] t TVD Shoe Test ]Depth Worst Wear CO ~./~'L~ 6~ Type WL /~, ~,( HT-HP.___ FC ~ Gel Caustic Max. Drilling Conn. ITrip Angle Direction TVD of l TVD TVD-TOP @ MD Solids ~/,,~ .~ % Oil 0 I% Sand FMW TVD Trip Chlorides Remarks Coordinates V S Total Length Type Ser. No. In Out Feet 1~"' " Consists of ) ~.-.- 3" Operations Covering 24 Hours Ending @ Midnight Ann. Vel. Bit HHP I Pump HHP I Daily M"d/?~5.- ICum Mud Drill H~O ]Pot H20 IFuel CC-Morn. Region Drilling Morning Report Company Weft Depth DOL Torque MD ¢u,4 ,d :5'0 ,, Days Ch. Code TVD ( DFS Hrs. / Last Casing Size ~) ti Cum Rot. Hrs.: On Casing Set @ MD Days ~0 PIU Wt. ?7/ Depth Worst Wear Liner IDrag MD Set @ [Since Last Cal.. IRot. Wt. TVD -TOP @ Total Rot. Hrs. Hrs. TVD Shoe Test I% Rem. MD EMW TVD Gel/y/ ~ ~,, WL _~, IHT-HP ~ FC ~ Pm ~,. / ~ Pr/M! Wt. Material Gel Ither 0,/ / Caustic Avg. Drilling Max. Drilling MD Angle Direction Conn. ITrip Trip Chlorides I TVD Ex brae ~ El Stab Salt CaCI~ Remarks Coordinates VS Type Ser. No. Out Feet Total Length Consists of , .,~ ~ (H.W.D.P.: ) /~'~" ~;;¢-, ~l~,._~a,~ ~- ~"~c., /-/'~"~d~ SPM Pressure GO Operations Covering 24 Hours Ending @ Midnight / Bi[ HHP Pump HHP Daily Mud ~ ~1 f Cum Mud Drill H~O I Pot H~O Da,~ Tangible FUel Cum Tangible Daily Well ,..~,~)~,~,--(,~ ]Cum We,7 ~ ~.~ Z.~;~- ~1~ (]0 1211 lCD 3 85) Prm~ed m U S A. CC-Morn. Company ~/l~,lj j~,l~! US~ Depth DOL ~, Days Torque Region Rot. Wt. Last Casing Size Cum Rot. Hrs.: On Casing MD ~q t TVD IDrag ---- PBTD) ]Proposed TO 0 Days ~_ P/U Wt, ?-?' IOep[h Worst Wear Drilling Morning Report JTotal Rol, Hrs. Hrs. / IStack Off WI. Hrs. IDFS I Shoe Test TVD EMW Set@ Rem. ]Since Last Cal. Liner Pm WL Set @ wt. Material Other Pf)Mf Gel MD Caustic. TVD- TOP @ MD TVD ]% o, 0 Li§. CIs. Ex Ume Salt lEI Stab CaCI~ Avg. Drilling Max. Drilling Conn. No. J Size J Trip M D Angle Direction TVD V S Type Ser. No. JTrip Chlorides ]Remarks Coordinates Out Feet (H.W.D.P.: ) Coosistsof /¢' "~" t~','/7/''' ,/ DLS S P M Pressure G PM Jet Vel. Operations Coverim 24 Hours Ending I~ Midnight Ann. Vel. Bit HHP Pump HHP IFuel IDaily Tangible ICum _Tangible JDaily We~l~,)0 ICum Well ~ 7_~p d ],ulk Wt. IBulk CmL JTmal Appr. y~' ,<,,~'F~ GO 121t lCD 3 85} Prmled ,n U S A ;C-Morn. Depth DOL ~ Days Torque Last Casing Size ,,,~,(,.) tf Cum Rot. Hrs.: On Casing iner Set @ MD Wt. ]CO Gel WL I Region ICh. Code Field /~/~'~B~D Proposed TD ) TVD ( Drilling Morning Report J DFS Hrs. Days Drag JRot. Wt. PIU Wt. I Set @ I Depth Worst Wear I% Rem. ]Since Last Cal. Hrs. ]Total Rot. Hrs. ISlack Off Wl. TVD Shoe Test MD TVD -TOP @ MD EMW TVD Type FV IPV YP I ExLime JEISlab /Caustic Lig. CIs. Salt ]CaCI~ Other ~ lArD. Drilling MD Length Angle Direction TVD Coordinates V S Type Ser. No. (H.W.D.P.: ) Consists of SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Operations Coverinc 24 Hours Ending @ Midnight Daily Mud Drill H20 Cum Mud JPot HzO CC-Morn. Drilling Morning Report Iroosed ID Depth MD TVD ( PBTD) '&i 7 7 MD TVD DOL ~ Days Hrs. Days . DFS Hrs IT°tal RoL Hrs. ~ Torque IOra9 ]Rot. Wt. ]P/UWt. ~SlackOffWL Last Casing Size ~0 Set ~ q 7 ~O TVO ~Shoe Tes, EMW Ion Casin~ JSince last Cal. liner Set ~ MD TVD - TOP ~ MD TVD Wt. ICO Type IFV IPV ~YP Gel IWL IHT-HP IFC Solids ~%0il I% Sand IMBT IPH Pm PffMf GL CA Ix Ume ,['1 Slab Wt. Material Gel }Caustic LiD. CIs, Salt gaCl~ Other M D Angle Direction TVD Coordinates V S D LS No. Size Type Set. No. Jets In Out Feet Hrs. WOB RPM T B G total Length (H.W.D.P.: ) Consists of Pump Liner Stroke SPM Pressure GPM Je~ Vel. Ann. Vel. Bit HHP Pump HHP Hrs. Operations Covering 24 Hours Ending ~ Midnight , -. GO 1211 ~CO 3.85l Primed in U.S.A. CC-Morn. Company Depth OOL ~ 1i-3 Ch. Coed Days Drilling Morning Report IPage of TVD Torque Region Division Field Date I Proposed TD MD TVD ( PBTD) ~ i '7 '7 MD DFS Total Rot. Hrs. Hrs. Days Hrs. IDrag Rot. Wt. iPIU Wt. Slack Oil Wt. '7~ MD TVD Shoe Test Last Casing Size Set @ EMW Cum Rot. Hrs.: On Casing Liner Wt. Pm Wt. Material Ither Set @ CO WE Depth Worst Wear I% Rem. ISince Last Cai. I MD TVD- TOP @ MD TVD Type FV PV Y P HT-HP FC Solids % Oil %Sand [MBT [PH Pf/Mf I CaC ~ Ge ICaustic Lig. CIs. Salt Drilling MD I No. Size I fotal Length Max. Drilling Conn. Trip I Trip Chlorides Remarks Angle Direction TVD Coordinates V S Type Ser. No. (H.W.D.P.: ) Consists of SPM Pressure GPM ] Jet Vel. Ann. Vel. Bit HHP Pump HHP Operations Covering 24 Hours Ending @ Midnight Daily Mud Drill Cum Mud Pot H~O Rig Phone CC-Morn. Company Well Depth DOL Torque Last Casing Size Cum Rotl Hrs.: On Casing MD Days IDrag Liner Set @ JRegion ICh. Code 'C4JA_~ TVD ( Hrs. IDFS I~ot. Wt. Set @ jSince Last Cal. MD Drilling Morning Report IDiwsion Proposed TO ~ PBTD) ~ t '7 7 MD TVD MD ITotal Roi. Hrs. Days Hrs. I PIU Wt. TVD [Shoe Tesl IDepth Worst Wear l%Rem Slack Off WI. EMW TVD -TOP @ MD TVD YP PH Gel Pm Wt. Material ,ther CO ]WL PI/Mf Gel [HT-HP ICaustic I Type FC CL Lg. Solids Oil JFV JMBT Ex bme Sah tel Siab CaCl~ Avg. Drilling Max. Drilling Conn. M D Angle Direction Trip Chlorides Remarks Coordinates I-,-< ]Total Length Ser. No. (H.W.D.P.: ) I I Consists Feet VS S SPM Ann. Vel. Bit HHP Pump HHP Pressure GPM Jet Vet. Operations Coverinl 24 Hours Ending 1~ Midnight ~/,~,,~¢',~_,9 ~JP ,.bRA · Daily Mud Drill H20 JCum Mud JPot H20 I Daily Tangible JCum Tangible JDa~y We,/0~, _<~ ~um Well JFuel ]Bulk Wt. ]Bulk Cml. IRig Phone 'JO 7' ~'' ~ ~;~ JOrilling Rep. ~~ ~~ JAcciOents ./~ G0 1211 ICD-3851 Pnnmd m USA. CC-Morn. Drilling Morning Report Company Well Depth MD DOL Days Torque Last Casing Size Cum Rot. Hrs.: On Casing Liner Wt. Gel Pm Set ~ CO WL Pf/MI Gel Wt. Material Other ]Region ~ ~,/~"¢'" ~_j~ A) Div,sion A/.~L.%/¢ I TVD ( PBTD)~]Pr°p°sed TD MD ~DFS Hrs ~Total RoL Hrs. Hrs. Days . ]Rot. Wt. IPIU WL Tes~ ICh. Code IDrag Set @ IPage ~ of I IHT HP TVD MD EMW Depth Worst Wear % Rem ]Since Last Ca!. MD TVD - TOP MD TVD Type FV IPV YP FC %Oil %Sand iMBT IPH /Caustic. ilAs. ES:Ii.me EclaScIIib Avg. Drilling MD Max. Drilling Angle Conn. trip ]Trip Chlorides IRemarks Directior TVD Coordinates V S Total Length Ser. No. In ] Out Feet (H.W.D.P.: ) Consists of SPM Pressure GPM Jet Vel. Bil HHP Pump HHP Operations Coverin{ 24 Hours Ending @ Midnight Ann. Vel. I Daily Mud Drill H~O ICum Mud IPot H~O Rig Phone CC-Morn. Depth MD DOL Days Torque Last Casing Size Cum Rot. Hrs.: On Casing iNer Set @ Gel Pm WL Pr/Mi Gel Wt. Material Ither IRegion TVD Drilling Morning Report o, Proposed TD ( PBTD) MD TVD JDrag Set @ ISince Last Cal. DFS Hrs. Days IRot. WI. MD IOepth Worst Wear MD TVD- TOP @ IType Caustic Total Rot. Hrs. Hrs. MD TVD PV IY P %Sand jMBT JPH Solids CIs. JEx bme El Slab Sail CaCI2 Avg. Drilling Max. Drilling M O Angle Conn. Direction ITrip Chlorides Remarks total Length Ser. No. In J Out Feet (H.W.D.P.: ) Coordinates V S Consists of SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Operations Covering 24 Hours Ending @ Midnight Daily Mud_ Cum Mud Drill H20 J Pot H20 Daily Tangible Cum Tangible JDai,y Well JCum Well 'h°neC/o7 7'g~ ~7.~Z R'P~,.,.,.~:Z¢~ .~-~::t¢,,,.~ ,~/~ GO 1211 16D.3-85~ Pnnted in d SA. TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF CLASSIFIED MATERIALS DATE: ~_ x~ _ ~, Alaska Oil & Gas Conservation Com mission Attn: Mr. W.M. Van Alert 3001 Porcupine Dr. Anchorage, AK 99501-3192 WELL NAME: We are sending the material tabulated below. Please acknowledge receipt and return one copy to: Mr. j. L. Weaver Chevron U.S.A. Inc. 3001 C Street Anchorage, AK 99503 ' ,, " ," - ~ / 1" ,, L" ,,%" " " ,11. i I t I! .1.I' RECIPIENT PLEASE ACKNOWLEDGE COMPANY: BY: DATE: ka Oil & Gas Cons. Commission Anchorage Senderss Instructions:- These transmittal sheets are made on NCR (No Carbon Required) paper with three sheets per set. Retain one copy for originator's file. Include one copy with transmitted material. Send original under sepa- rate cover to addressee. (If sending by air freight, put air bill number on backside of envelope.) Please use ball-point pen when filling out this fom. . EXP- 180-8 (CD- 2-82 ) Printed in U,S,A, ?~'- STATE OF ALASKA .~--. ~:~_~ ALASKA C.....AND GAS CONSERVATION CO .,'ISSION ~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS¥ · Drilling well [~ Workover operation [] 2. Name of operator Chevron U.S.A. Inc. 3. Address P.O. Box 107839, Anchorage, AK 99510 4. Location of Well atsurface 158' W & 204' S of NE Corner, Section 4, T12N, R10W, SB&M 7. Permit No. 86-10 8. APl Number 50- 283-20079 9. Unit or Lease Name Beln¢~ Riv~.r lInit 10. Well N~~. 5. Elevation ~in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. G.T._ = 85' kT.R: : 10.3'I A-029656 BRU 211-3 11. Field and Pool Beluga River- Sterling & Beluga For the Month of March ,19 86 -12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks TD = 6,562', Footage: 3,711', PBTD = 4,992' 13. Casing or liner run and quantities of cement, results of pressure tests Ran 3 its 9-5/8" 47# S-95 BTC & 138 its 9-5/8" 43.5# S-95 BTC casing = 6006' set at 6003'. Cement with 1130 sks C1 "O" + 3% KCL .9% HR-9 at 15.3 PPG. CIP at 5:45 PM 3-16-86 with 3,000 PSI. 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/BHC Sonic/SP/GR/SFL 6560' - 3142' CNTG/LDT/GR/CAL 6562'- 3142' RFT's 3182'- 5694' 48 Readings DITE/SDTA/GR Tool Failed R[C[IVED Alaska Oil ~'~, gnchc:?e ,1 6. DST data, perforating data, shows of H2S, miscellaneous data DS'[' #1 5?45' - 5714' 5?00' - 56?5' 1-1/2" JSP2' No gas to surface, Had 1598' fluid rise. ]::)8'1' #2 5060' - 5040' 1-1/2" JS?F F, stimate 10 MCF/D 12/64" choke FT?: 2, 78! 406' fluid rise. ?erforated the following intervals with 5" casing gun 8 - .41" JS?F: (see back side) 17'1 hereb~t.~ei°rTingistrueandc°rrectt°thebest°fmY kn°wledge' Superint~endentArea Operations SIGNED ,____~~t~l/~-"-/"''~ TITLE_ DATE NOTE--F~eporton this form is required for each calendar month, regardless of the status of operations, and must be/~iled in duplicate with the Alaska Oil and ~as C~l~servation Commission by the 15th of the succeeding month, unless otherwise directed. o~ Form 1 Submit in duplicat TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF CLASSIFIED MATERIALS Alaska Oil & Gas Conservation Com mission Attn: Mr. W.M. Van Alen 3001 Porcupine Dr. Anchorage, AK 99501-3192 DATE' WELL NAME' We are sending the material tabulated below. Please ackngwledge receipt and return one copy to' ' .1 Mr. J. L. Weaver Chevron U.S.A. Inc. 3001 C Street Anchorage, AK 99503 !( , tf ! l -- RECIPIENT PLEASE ACKNOWLEDGE COMPANY' BY' DATE: ~"///Alaska Oil & Gas Cons. Commission A~chgr~ge Senders~ Instructions:- These transmittal sheets are made on NCR {No Carbon Required) paper with three sheets per set. Retain one copy for originator's file. -Include one copy with transmitted material. Send original under sepa- rate cover to addressee. (If sending by air freight, put air bill number on backside of envelope.) Please use ball-point pen when filling out this form. ~EXP-180-8 (CD-3-82) Printed in U.S.A. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL [] 2. Name of Operator Chevron U.S.A. Inc. 3. Address P.O. Box 107839, Anchorage, AK 99510 4. Location of Well 158' W & 204' S of NE Corner Section 4, T12N, R10W, SB&M 5. Elevation in feet (indicate KB, DF, etc.) G.L.=85' ' K.B.= 10Y I 6 . Lease Designation and Serial No. A-029656 OTHER [] 7. Permit No. 86-10 8. APl Number 50-- ?.g 3-?.gg79 9. Unit or Lease Name Belu~:a River Unit 10. Well Number BRU 211-3 12. (Submit in Triplicate) Perforate [~ Alter Casing ]~] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 11. Field and Pool Beluga River - Beluga Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 1, There are no commercial shows of hydrocarbons or shows of fresh water below 6000'. We propose to set 9-5/8" 43.5# SS-95 BTC casing at 6000' +/- and cement from 6000' to 2600' +/-. Perforate and test the following zones. If the zones are not productive, a retainer will be set 50' above the top perforation and sufficient cement to cover the perforations will be squeezed below the retainer: A. DST#l: 5745' - 5714', 5700'- 5675' 1-1/2" JSP2' B. DST#@: 5060'- 5040' 1-1/2". JSPF . ,r.-CF. IVED 77-£ ?',,,) Atas~a 0il & Gas Cons. commisslorl · Date 14. I hereby certify that thefloregoing is true and correct to the best of my knowledge. ~/~f~//f'~l/~""/- Area Operations Signed Title Superintendent The space below for Commission use Conditions of APproval, if any: Approved by By Order of COMMISSIONER the Commission Date ~'~~~ Submit "Intentions'· in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 Rev. 7-1-80 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Chevron, U.S.A. Inc. 86-10 3. Address 8. APl Number P.O. Box 107839, Anchorage, AK 99510 5o-283-20079 4. Location of Well 158' W & 204' S of NE Corner Section 4, TI2N, R10W, SB&M 5. Elevation in feet (indicate KB, DF, etc.) G.L. = 85' K.B. = 103' 12. 6. Lease Designation and Serial No. A-029656 9. unit or Lease Name Beluga River Unit 10. Well Number BRU 211-3 11. Field and Pool Beluga River Beluga & Sterling Check Appropriate Box To Indicate Nature of Notice, Report, or Other Da~ NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [X Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See the attached. RECEIVED APRO 19116 .~, Itch ~ r398 14. I hereby cer_,t~y ~_hat t~ forego_~ing is true and correct to the best of my knowledge. Si§ned _ .. _ Title Superintendent The space below for Commission use Conditions of APproval, if any: . ....... ~. By Order of Approved by COMMISSIONER the Commission Date Date ~-- .... --'~ ~(~ Submit "intentions" in Triplicate and "Subseauent Reports" in OuplicatI Form 10-403 Rev. 7-1-80 CHEVRON U.S.A. INC. WESTERN REGION ALASKA- AREA WELLWORK ORIGINAL SUMMARY r'"! OI~ECTIVE · PR(X:EDURE ~UMMARY LOC.' TYPE WELL' SUPPLEMENTAL SUMMARY ~ NO, WELL DATA' PROGRAM K.B. I(~ T.D. ~4)~'~. PBTO CASING' ~ PERFORATIONS' </~'70~:~ ' -- ~'~Z,~" ~/,.'~/~,,' -' %/'~'"'~_~[/~' DETAILS ATTACHED _ Distribution: RECEIVED Original to Well-File o,,,. s.,:,,,,.t,,,,:,.,, e,,,. <~ APR 0 .~ ]986~ ~'-~ ~ Field Office (I} Engr. Technician (I) · CHEVRON U.S.A. INC. WESTERN REGION ALASKA A.REA WELL,W(~ ~DI.JRE ~;UMMARY PROGRAM (CONTINUED): DETAILS ATTACHED I-1 DIstribution: original to Well-File Drip, Sul)erintendent InCr. ($) Field Office {I) Prll~Orlr (I) Engr. Technician {I ) RECEIVED Prep, ore. dI APRO :~ 1986 //, Alaska 0il & Gas Cons. Commissi°~lXOved Anchor~!!e ' Date ' CHEVRON U.S.A. INC. WESTERN REGION 'ALASKA AREA WELLWqf~K PR~DURE SUMMARY w~. ~'~Zut &il- ~ - ~ ~ o~ CONTINUED): DETAILS ATTACHED I:::] DIstribution: Original fa Well-File Orlg, Superintendent Engr. ($) Field Office (I) PreDorer (I) [ngr. Teghfligion (I) RECEIVE1) Prepar d Date D(3fe IK<.I.~,~ 10 X 10 TO THE INCH- ? 10 INCHES ~<£uF~E. ~ Ess~. co ...... ,x.u,, , 46 0700 STATE Off ALASKA ~ M--NTHLYO ALASKAOL-AND GAS CONSERVATION CC '/IISSION REPORT F DRILLING AND WORKOVER OPERATIONSI 1. Drilling well I~ Workover operation [] 2. Name of operator 7. Permit No. Chevron U.S.A. Inc. 3. Address P.O. Box 107839, Anchorage, Alaska 99510 4. Location of Well at surface 158' W & 204' S of NE Corner Section 4, T12N, R10W, SB&M 5. Elevation in feet (indicate KB, DF, etc.) G.L.: 85' K.B. = 10Y 6. Lease Designation and Serial No. A-029656 86-10 8. APl Number 5o- 283-20079 9. Unit or Lease Name Beluga River Unit 10. Well tq'o. BRU 211-3 11. Field and Pool , Beluga River - Beluga For the Month of February ,19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth = 2851', Footage Drilled = 2833', Spud 4:00 A.M. 2-20-86 13. Casing or liner run and quantities of cement, results of pressure tests Run 11 its 20" 94# H-40 BTC casing = 437.6' set at 43Y. Run 4½" DP and sting into float collar. Cement with 275 sks C1 "G" + 6% gel 2% CaC12 at 13.6 PPG. Tail in with 200 sks C1 "G" + 2% CaC12 at 15.8 PPG. Displace with 5.5 BBLS fresh water - CIP at 6:00 AM 2-22-86. Circulated 200 sks good cement returns to the surface. 14. Coring resume and brief description N/A 15. Logs run and depth where run N/A :.. : .:,-. 1VED ,1 6. DST data, perforating data, shows of H2S, miscellaneous data N/A APR 0 2 1986 ^iaska Oil & Gas Cons. Com~ssion Anchorage 17. I hereby cer. tify that the foregoing is true and correct to the best of my knowledge. t' Area Operations Superintendent ' TITLE DAT 't on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska onservation Commission by the 15th of the succeeding month, unless otherwise directed. Submit in duplicate TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF CLASSIFIED MATERIALS Alaska Oil & Gas Conservation Corn mission Attn: Mr. W.M. Van Alen 3001 Porcupine Dr. Anchorage, AK 99501-3192 DATE: WELL NAME' · We are sending the material tabulated below. Please acknowledge receipt and return one copy to: Mr. J. L. Weaver Chevron U.S.A. Inc. 3001C Street Anchorage, AK 99503 m RECIPIENT PLEASE ACKNOWLEDGE COMPANY: BY: DATE: Deve lopmeng Geologi st Senders' Instructions:- These transmittal sheets are made on NCR (No Carbon Required) paper with three sheets per set. Retain one copy for originator's file. Include one copy with transmitted material. Send original under sepa- rate cover to addressee. (If sending by air freight, put air bill number on backside of envelope.) Please use ball-point pen when filling out this form. EXP-180-79 (CD-2-85) Printed in U.S.A. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 86-10 3. Address 4. Location of Well P.O. Box 107839, Anchorage Ak. 99510 8. APl Number 50- 283-20079 9. Unit or Lease Name OTHER [] 158'W & 204'S of NE Corner Section 4, T12N, RIOW, SB&M Beluga River Unit 10. Well Number BRU 211-3 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Be1 uga River, Be1 uga G.L. 85' K.B. 103' A-029656 i 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See Attached Final Survey Plat RECEIVED 1 1986 011 & GaB Cons. ~mml~ Anchorage 14.,hereb~t)y.~q~/// /~~ .-~"~thattlef°reg°ingistrueandc°rrectt°thebest°fmYAreakn°wLedge' , ~~ Signed ~.~ _.,~_.~ ~. ~..~.~ ~ ~ Title Operations Superi ntendentDate The space~w~for Commission use Conditior~ APproval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate WELL SURVEY Pro-312 COUNTY OF ~/7.:~/ CITY OF ELEVATION: t~ROUIIO CONCRETE 14AT DERRI Cl[ FLOOR A L T E R N A T E 0 I $ IJ It ¥ Ir ¥ E D L 0 C A"I' I 0I · LOCAT I DEl I ~I&T I OI LOCAT 1011 CO01011tATEI NOV Ir .1. X: ,Z,,~ .,<'~ /. .-%- . , , . ,11 , , .I, , , I - - · , I I I I I '~l~': I I I . · I I I II II _ · · · , , , ................. . '.~" ·~ ', - · ....RECEIVED _ _ MAR 1 4 1986 ~ $ TI ~ Anchorage ,d~O ~7 ,. C.C. DIV. FILE Pllll?ll IIIU.S.A. SURVEYOR U~r"~,~ ,,.~"avO,.~¢ #AIIIT. Flit. KAINT. ~UPT. / ~ DATE /~' ~/::) ~'6 DATE i)&TE PR'O. 312 (2500.CD. I- 58) ~ Chevron U.S.A. Inc. §00:1 Bollinger Canyon Road, San Ramon, California Mail Address: P.O. Box 5043, San Ramon, CA 94583-0943 Production Department : WeStern Region January 16, 1987 Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, AK 99501 FILE: Attention: Mr. Chat Chatterton 'Gentlemen.' . I.CROFILId Enclosed, per your request, are the followin / '~---. · - .... : Date ..... ~..~ ,~~__~~__ Drill Stem Test 2. BRU 212-18 Completion Report 3. BRU 241-34 Sundry Notice Any further questions may be addressed to Mr. Jess Brookley (415) 842-0321. Sincerely, · Col tart Manager, Non-Operated Joint Ventures MA:skw Enclosures RECEIVED' FEB 0 2 1987 Rlaska Oil & Gas Cons. 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IIII~HH%SS [)D-HH EXPLANATION l'll4E, IIR PSIA DEG F ~3/~ 21-HR SOUEEZE PRESSURE 9~42,3J~ 21-141', START FLOt~ 15~57~ ~) 21-14R END FI.O~f & START SIIUT-IN 23~' 3~3~) 21-HR END .~IIIJT-llt g~27,3~) 22-HR IIYDROSTATIC HUD 5.533 2438.2 93.4 9.142 2479.5 !~1.4 !1.975 2245.7 ioi.9 18.217 226.4 102.B 25.325 2350.3 103.5 26.725 2428.7 193.5 ARY OF FLOW PERIODS START END START END ELAPSED ELAPSED DURATION ~RESSURE PRESSURE OD TIHE, IIR TIHE, IIR IIR PSIA PSIA 11.975 IB.217 6.2.42 2245,7 226.4 ARY OF SIIUTIN PERIODS START END S'FART EHD FltlAL FLOW E~-~PSEI) ELAPSED DURATION PRESSURE PRESSURE PRESSURE PRODUCING OD ( E, IIR TIHE, IIR IIR PSIA PSIA PSIA TIHE, ItR , 18.2t7 25,325 7.1~8 226.4 2350.3 226.4 6.242 . 0£ L~ E H t.,...I--1 h2 t 91 J .... j ............ ~ .................. j ............. i, ...................... ii ............. il ......................... : ........... Ii ............ E-II2 tlNI1 U:J^Itt NOUA~]II3 8! 6 9 ~ ] l _--1H lsd O0001 : III3UaU3 1~ OLOS : Hia30 SOOS · 'ON IN~HR~ISN! tt9SSI~[ 'ON IUOa]U Oq3]~ 9Oq 3]OHNOIIO o, Eli (./1 215. C~' cD c~ WELL TEST DATA PRINTOUT *************************** D REPORT · t 14556G ~NY 't: CItEVRON ELL ~ BELUGA RIVER UNIT 211-3 IttSTRUHErlT # ~ 8421~ CAPACI[Y [PSl ] ~ t~TOJ~R. DEI"rll [FT] ~ 4988.JB PORT OPENING ~ INSIDE L POINT ]NFORrlATION TIHE BOT IIOLE BOT ltOLE OF DAY DATE ELAPSED PRESSURE TEHP. IIII~HH~SS DD-HI,I EXPI. ANATION TII, IE, IIR PSIA. DEG F 5[ ~4~ 21-HR tlYDROSTATIC HUD 6,k 12~ 21-HI! 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I ! t : i , i f , .... oa 6[ h'8 [l'h 1'6 l'8 I I I I I I I I (HI-Il "-U I-r'l O3 Z~ Fq F-I ~.~.c ~o -~=~-u ] [ U I-I] 1~7 0'001 0'0 0'1 , O1 '0 UN SI'L 01 Og'O :qONUU ':JI,411 1~ 10].1 UN Lg'O;~ 13.1. ;~t~'gl :'~9NUU 31tI, 1 O3SaU'I'~ 1Old U[S.1 6'601 ;l-lMd] 3UflSS3UJ MO]J ]UNI:I ; t" NIlfllIS BlgS§ 'QN IN]NflUISNi J9SS~I 'ON IUga3U 0931J g-ti8 llNfl U3A[U ugf193fl ; 993H NOUA3H3 : ~NUaHQ3 109ci go] 009 CD CD CD 0 0'01 ( U I-.I) 0'I IV gIESg 'ON 1N3NnUlSN! JgSShl 'ON IUOJ3U a93IJ ~-11~ 1]Nfl U3AIU UOfi93B : 993H NOUA3H3 : ANUJHOg BH §I'L gl E6'O :3ONUU 3H11 Iv 109d Bt1LE'O~ Ol SI'hi :3ONUU 3Nil O3~dU93 lOqd UISJ 6'681 :(JMd) 3UflSS3Ua HOgJ 9UNIJ ; l" NIIfltlS 109cl 909 009 01 '0 C~ C) 0 C) March 19, 1986 Mr. Vince Angell Chevron USA Inc. P.O. Box 107839 Anchorage, Alaska 99510 Re: Boss Gyroscopic Survey Job No. AK-BO-60020 Well: BRU 211-3 Beluga River Survey Date: March 18, 1986 Operator: J. Samec I -. Mr. Angell: Please find enclosed the "Original" and six (6) copies of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Enclosures Sincerely, Ken Broussard District Manager NL Sperry-Sun, Inc. NL Sperry. Sun/NL Industries, Inc. RO. Box 190207, Anchorage, Alaska'99519-0207, Tel. (907).522-1737 . L~'LO~ '---~'~68'~ 0~'0£~ ............................ ~/Z,'.:.. ~"6~'~£~ ..... : ........... S Z~'~. .e,.', ......................., [ ~ . ,'~ ~/9.... ,'....,"_';, '' ":" ,..~ t; 'zl 69 Z. i3'" N ............. ~ .................................... --.""" .... Z ................ '"" ' ' ,'~c. /9'1: 3 01:~78 N 3"-'~ Y"8 ~,T. ............... ~ 6--"'J '"'8<..'"' -- ~7~ '"'"! -- 3 ""08 "Z ~"-"~ 3 ~'zo,T. ~ O0'~-':''' ' c.c. J~ 0 3 '~" ' ~,::::, /8 S $ ~ 0 J ' ~. 08 J ~ 7..:"3 ' 08~ OOE:~ 3-6 F'"'~81 .........:9"'Z I ' "~ .................... m~'". ~ .................... ~-'~'~' J . 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BELUGA RIVER ALASKA INC. --SPERRY=SUN-WELL-SURVEYING_COMPANY ANCHORAGE ALASKA COMPUTATION_DATE MARCH 19. 1986 VERTICAL SECTION CALCULATED ALONG CLOSURE PAGE 3-- DATE OF SURVEY MARCH 18. 1986 BOSS-GYROSCOPIC-SURVEY dOB NUMBER AK-BO-60020 KELLY BUSHING ELEV. = 100.00 FT. OPERATOR J.--SAMEC .................................................... TRLIE' ................ SLIB...~EA MEASURED VERTICAL VERTICAL (, -~PTH DEPTH DEPTH COURSE ...... CO.t..!RSE .... INCLINATION DIRECTION BEG MIN DEGREES DOO=LEO__ TOTAL_ SEVERITY RECTANGULAR COORDINATES VERTICAL DEG/IO0 NORTH/SOUTH EAST/WEST SECTION 5900 5873.84 5773.84 0 5 N 9.80 E 0.18 1.92 S 332.55 E 332.56 HORIZONTAL DISPLACEMENT = 332.56 FEET AT SOUTH 89 DEG. 40 MIN. EAST AT MD = 5900 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. 'OOHJ.3W 3~FIJ.~A>Jh3:10 SFIIQt~ qt~NOISN3WIO 33~JHJ. ~10 3Sfl 3H.I. 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(:0~ ................................. · 0 O0 ' 0 O0 ' 0 O0 ' O0 T- O0 ' 0 0 NOfi:J~UBO:J ..... 3ON3U_'_q_4jfd'--i~N/i$~ .... Hifgb.~?HiBoN----Niaaa 9gO I£B3fi G^I-ON $31gNIOBOO3 BgqAONglO3B 993IIB3fi "Hld3a .................... Hia~" ':i ...... ! 9~:31 ±~3A GS~lgS~,.' Hl83O M3S-BflS ~0 &33~ OOI N383 ~0~ S3119W8 G3i~qOaW3&NI 'l~ O0'OOI 33W~.S--'P-~Ol~BaO = '~393 ONIHS~8 AqqBX 0~009-08-~ ~38WigN 80P 986T 'ST H3~W ASA~A$ ~0 Bl~G 986T '6T HOgaN 3iVO-NOIi~I~aWOO ~S~q~ BO~OHON~ AN~aWO3---ONiABA~AS-.-q~BM.-NAS=A~BaS ...... H~3G ~3S-8195 ~0 ~33d OOI N3~3 BO~ S3flq~ GS±~qO~S~NI '1~ O0'OOI : '^393 ONIHSA~ Aqq3X O~O09-O~-N~ ~3~AN 986I '8I HOgaN ABACAS ~0 3i~G 986t ~6I H3~W 3i~G-'NOIl~iA~WO3 ~S~3~ 3O~OHON~ AN~WOO---ONiABABA$-qq3M-NAS~A~Ba$ '3NI '~'S'A NO~A3H3 O0 '0 O0 O0 00' 0 rO '0 _Z:.O '0 ~0 '0 I 0"0-- ~0 '0 tO '0 IO '0 ~0 '0 t?O '0 ~0 ~0 fO 90 '{3 60 80 '9~. 90 ~0 '9~ 00'00~ 00'009; 999~ O0'O0~g O0'OOGG 9~g9 ~0~' ~ ................. 00" ~'00~" .... ~ ................. 9~.~" ~ 00~ O0 008S 9~S 3 6~ "'1;,88 $ .;:3. L "'lz O0 ' O01 c:: O0 ' 00~.~ 9~Z~ } ......... .... -'"'" O00S 30 O01S 9'c. I S ~ '~ee ..................... ~'"-~'[""9,~ ..................... o¢)' ............................ . i .... , ....... ~ ................... ;"~ ; ..... 00'006~ O0'O00G 9~OG 00'008~ 00'006~ oo"OOi~ ................. 00'oo8~ ................ 0~8~ .................................. 00"009~ 00'00£~ O0'OOS~ 00'009~ O0~ O0~ ............... O0~ OOs~ ............. 9~ ................. O0"OOC~ 00'00~ 00"00~ 00'00~ HlaBO ~3S-SAS ~0 133~ OOI NBA3 BO~ SBAq~A OBl~90aBBINI 'iN O0'OOI = 'A393 ONIHSA8 Aqq3~ 0~009-08-~ ~38WIgN 80P 986I '8I HO,~W ^$^~A8 :10 Bl~G SiVa-NOIi~iAaNOJ ~S~q~ 3O~OHON~ AN~WO3-ONIABA~AS-9-1BM"NAS=A~B~S- '3N I ........................................................................................... ~.~SPERRY=SUN. WELLSURVEYING_.COMPANY ANCHORAGE ALASKA CHEVRON U.S.A. INC. _ BRU 211.3 ........................................ COMPUTATION. DATF BELUGA RIVER MARCH 19, 1986 ALASKA PAGE__8 DATE OF SURVEY MARCH 18, 1986 dOB NUMBER AK-BO-60020 KELLY BUSHING ELEV. = 100.00 FT. OPERATOR_.d.__SAMEC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ........................ TRuE ............ TOTAL ,,, MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD ....... _{ ~EF'TH .......................... DEPTH .................. DEPTH .......... NORTH/SOUTH ......... EAST/WEST DIFFERENCI~___ VERTICAL CORRECT I ON ....... 5726 5700. O0 5600. O0 2.02 S 332.35 E 26.16 O. O0 ...................... 5826 ......... 5800.. 00 ........... 5700:O0 ................................ ~: 00 $ .......... D3~, _4. 7.. E ......................... 26...i_ 6 __0:O0 5'-200 5873.84 5773.84 1, ~2 S 332.55 E 26.16 O. O0 _. THE. CALCULATION., pROCEDURES, USE__ A....L_,I. NEAR .,INTERPO.L..AT!ON. BETWEEN .................. THE NEAREST 20 FOOT MD CFROM RADIUS OF CURVATURE) POINTS Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, AND Reports and Materials to be received by: ~ .... .~.~- Date Required Date Received Remarks C°mpleti°n Rep°rt ! Well History , Mud Log Core Chips ~-'~, Core Description Registered Survey Plat Inclination Survey . Drill Stem Test Reports 7~ '~0--: /X-/ ~- ~" .. roa.= ion ports Log Run Digitized Data xn~ome~ 'H lITE '~ · lOUa o/a uoT3~nz~suoo le3ua~uoxTnuR ~o 'l~u~ o/a uoTQ~S 2~2TqeH '~m~O ~ ~s]~ ~o ~q 'ad!d mo2~npuo~ ~q~ Fo ooq~ aq2 moiaq ~u!II!~P aaoF~q ~u!~sa; ss~u~!a X~m uo!ss!mmoo ~q2 ~q2 os uo!2~Iye~su! 2u~md!nb~ 'p~!nb~ s! m~s~s a~A!p ~ ~tI~~ 'P~II!ap s! ~oqs oq X~m uo!ss!mmo0 aq2 go oA~2~2uasa=da~ ~ ~q2 os 2uamd!nba uo!2uaAa=d 2nomoIq aq2 Fo uo!2~ll~2su! ~ui~uatmno~ o~ mo!ad ~g a~!FFo s!q2 X~!2ou as~aid 'Maom PIa!g ~u!Inpaq~s u! sn p!~ o~ aaq2o moa~ za~i Xq paa!nbaa s2-~.m~ad i~uo!2!pp~ u!~2qo o2 paau al q~qoad ag2 moa~ noX ~{~!u~apuz. 2ou saop II!aP o2 27~-~ad 'Ilam paoua~aFaa aAoq~ ii.zap o2 2!m.xad aoF uo!2wox, idd~ paAostdd~ aq; si_ pasoIou.q ~90£-0I~66 ~MS~elV 'o$~aoqouv 6gSi0l xo~ '0 'd 'ouI 'V'S'I1 ~uapuo~u!aodns suo!~xod0 986I '~ Xa~nu~F STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE APPLICATION OF CHEVRON ) U.S.A. INC. for an order ) granting an exception to the) acreage spacing requirements) of Title 20, AAC 25.055(a) ) (3), to permit the drilling ) of two wells in the Beluga ) River Field. ) Conservation Order No. 215 Beluga River Field Beluga River Gas Pool, undefined. December 11, 1985 IT APPEARING THAT: Chevron U.S.A. Inc., operator of the Beluga River Unit, submitted an application, dated October 4, 1985 requesting an exception to 20 AAC 25.055(a)(3) to permit the drilling of two Beluga River Unit (BRU) wells numbered 211-3 and 224-34. The referenced regulation permits only one gas well per governmental section and requires a minimum distance of 3000 feet between wells drilling to or producing from the same gas pool. · The BRU No. 211-3 well will be the second well in Section 3, T12N, R10W, SM. and the BRU No. 224-34 will be the second well in Section 34, T13N, R10W, SM. and will be only about 1530 feet from the BRU No. 211-3. · The exceptions are necessary to develop field deliv- erability rates sufficient to meet contractural sales demand. · Notice of the application was published in the Anchorage Times on November 25, 1985. 5. There were no protests to the application. FINDINGS: I · The drilling of more than one well per governmental section in the Beluga River Gas Field and at a distance of less than 3000 feet apart will not decrease the ultimate recovery of gas. · The requested exceptions are in an approved unit operation and the correlative rights of all concerned are protected. Conservation Order ~-~o. 215 Page 2 December 11, 1985 CONCLUSIONS: The requested exception will not create waste and the correlative rights of all owners are protected. NOW, THEREFORE, it is ordered that: Chevron U.S.A. Inc. is exe_~pted from the requirements of 20 AAC 25. 055 (a) (3) for the drilling, completing, and produc- ing of the two Beluga River Unit wells numbered 211-3 and 224-34. DONE at Anchorage, Alaska and dated December 11, 1985. Alas a 1 and as Conservation Con~nission Harry W. K~gler, Commissioner Alaska Oil and Gas Conservation Commission Lonfiie C. Smith, 'C~mmissioner Alaska Oil and Gas Conservation Corrrmission · EI'[ E:c~Z 'ON a.l.1]ss~ ® _ . -- · '¥'STI NI :::lCl¥~ i , .. 0 _ o0 ://-b ~ STATE OF ALASKA ALASKA O,~ AND GAS CONSERVATION CO,, v~ISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work. DRILL [] REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [~ SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator Chevron U.S.A. Inc. 3. Address P.O. Box 107839, Anchorage, Alaska 99510 4. Location of well at surface +158'W & +204'S of NE Corner Section 4, T12N, R10W, S.B.&M. At top of proposed producing interval +200'E & +200'8 of NW Corner Section 3, T12N, R10W, S.B.&M. At total depth +200'E & +200'S of NW Corner Section 3, T12N, R10W, S.B.&M. 5. Elevation in feet (indicate KB, DF etc.) [ 6. Lease designation and serial no. Estimated KB = 100' [ A-029656 12. Bond information (see 20 AAC 25.025) Type State Wide surety and/or number U80-61-55-21 9. Unit or lease name Beluga River Unit 10. Well number BRU 211-3 11. Field and pool Beluga River Field, Beluga Amount $500,000 13. Distance and direction from nearest town 9 Miles NE miles 16. Proposed depth (MD & TVD) 6900' TVD 6927' MD feet 14. Distance to nearest property or lease line TVD 500' feet 17. Number of acres in lease 1387.18 Acres 15. Distance to nearest drilling or completed TVl~ell BRU232-4 2850 feet 18. Approximate spud date January 10, 1986 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 10 Ol(see20AAC25.035 (c) (2) -2~_~-- psig@--0' Surface 3310 psig@6900 ft. ~ (TVD) 21 ! Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT SIZE Hole Casing 30" ~ 26" 20" 17½" 13-3/8" 12¼" 9-5/8" 12¼" 9-5/8" Weight 1" Wall 94 68 4O 43.5 22. Describe proposed program: CASING AND LINER Grade / Couplingl Weldec~ -40 r-55 / -80 ! N-80 ! STC Length 80' MD TOP TVD 22' 378' 22' 3177' 5006' 122, 20' ~20' 19' 119' 1902' 5025' 15000' MD BOTTOM TVD 400' I400'80"' 31~7' I 3150' 5025' ~ 5j300' 6927' 1,/900' (include stage data) Driven 700 sks 2100 sks 1st Stage = 900 sks 2nd Stage: 400 sks SEE THE ATTACHED DRILLING PROGRAM RECEIVED 0CT0 4 I985 Alaska Oil & Gas Cons. Commission Anchorage Area Operations / SIGNED TITLE Superintendent The space~el~vv'for Commissio~ use CONDITIONS OF APPROVAL Directional Survey required I~YES []NO DATE Samples required Mud log required []YES [~10 I-}YES ~lO Permit number Approval date ¢j~o .~ ~ ..~ 01/,03/86 Form 10401 / IAPI number 5o-~g_~-z o~77 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE January 3, 1986 by order of the Gommission Submit in triplicate PROPOSAL FOR WELL OPERATIONS PRO 316-1 FIELD: Beluga River PROPERTY AND WELL: SURFACE LOCATION: Beluga River Unit 211-3 (proposed) +/-158'W and +/-204'S of NE Corner Section 4, T12N, R10W, S.B.& M. TARGET LOCATIONS: At -3520' VSS: +/-200'E and +/-200'S of NW Corner Section 3, T12N, R10W, S.B.& M. At TD (-6800' VSS): +/-200'E and +/-200'S of NW Corner Section 3, T12N, R10W, S.B. & M. ELEVATION: (Estimated) G. L. = 82' K.B. = 100' BLOWOUT PREVENTION CONSIDERATIONS: 1. Potential Problems A. Water flows: .No water flows are anticipated. Be Gas Entries: No high volume gas flows are expected above 3000'. Coal seams can be encountered anywhere from the surface to T.D. A controlled penetration rate, degass,r, and rotating head should elim- inate any gas encountered while drilling through coal seams or through the productive intervals. Ce Lost Circulation: Lost ciruclation is not anticipated with the programmed mud weight. De Stuck Pipe: Coal seams should be drilled and reamed with care. Do not stop moving the pipe in coal seams. E. Precautions: Ail kicks should be handled by the normal procedure. Drilling crews should be made aware of these methods prior to spudding. Kick and BOP drills should be practiced tourly or more often and noted on the tour sheets. An adequate supply of weight materials should be kept at the well at all times. . Maximum Anticipated Formation Pressure: .. Pressure (PSI) Mud Wt. (PPG) Gradient (PSI/ft) Depth (TVD) 1450 7.7 .40 3620' 1970 9.2 .48 4100' 3310 9.2 .48 6900' ® Maximum Anticip. ated Surface Pressure: 2620 PSI RECEIVED Alaska Oil & Gas Cons. Con]mission Anchorage . Blowout Prevention Equipment: (Minimum) A. 30" Conductor: None Anticipated . B. 20" Casing: 21-1/4" 2000 PSI Diverter with two (2) 10" lines for down wind venting at any time. C. 13-3/8 Casing: Class III 5000 PSI BOPE D. 9-5/8" Casing: Class IH 5000 PSI BOPE DIRECTIONAL CONSIDERATIONS: Directionally drill to within a 200' radius of the target of 200' S and 200' E of the NW Corner of Section 3, T12N, R10W, S.B.&M. at -3520' VSS to -6800' VSS as per the following directional plan and the attached plats: 1. Drill a vertical hole to near 500' MD, -393' VSS. . On a course of N89.36OE kick off at 500'MD. Build the hole angle at 1 degree/100 Ft. to a total.hole angle of 9.3 degrees to 1430' +/- MD, -1326' VSS., 75' of drift. 3. Hold the 9.3 degree hole angle to 2717'+/- MD, -2595' VSS, 283' of drift. . Drop the hole angle at 1 degree/100' to +/- 3647' MD, -3520' VSS, 358' of drift. 5. Hold the hole angle at 0 degrees to +/- 6927' MD, -6800' VSS, 358' of drift. RECEIVED o 1985 ~.., .,. ~aska 0il & ~as Oons. ~,.,,,~mss~on Anchora~ lm 2. 3. 4. 5. Bm . . . 10. 11. 12. 13. 14. 15. PROGRAM Drive +/- 80' of 30" eonduetor. Drill a 17-1/2" hole to 400' +/o. Open the 17-1/2" hole to 26" to 400' +/-. Circulate and condition the hole for 20" OD casing. Rig up and run the 20" OD 94 #/Ft. H-40 BTC casing as follows: A. Guide shoe on the bottom. B. Stab in float collar one joint up. C. Thread lock the guide and float equipment. D. Run centralizers 5' above the shoe, 5' above the float collar, and then every other joint back to the surface. Cement the 20" OD casing as follows: A. Run the stinger on 4-1/2" hevi-wt, drill pipe and 4-1/2" drill pipe, and stab into the float collar. B. Circulate the capacity of the drill pipe. C. Pump 40 BBLS of fresh water. D. Pump sufficient Class "G" + 6% Gel and 2% CaC12 at 13.6 PPG to circulate cement to the surface. E. Tail in with 200 sacks of Class "G" + 2% CaC12 at 15.8 PPG. F. Displace the cement with fresh water. If the float collar does not hold, hold pressure and check for initial set every 2 hours. G. WOC for eight (8) hours prior to cutting off the 20" OD casing. Cut off the 30" OD conductor and 20" OD easing. Weld on a 20-1/4" 2000 PSI x 20" well head, and test to 500 psi. NiPple up the 20-1/4" 2000 PSI diverter with two (2) 10" lines venting in opposite directions. Function test the diverter and valves. The BLM and AOGCC may witness and will need 24 hours notice. Trip in the hole With a 17-1/2" bit. Prior to drilling the float equipment, test the casing to 250 PSI. Drill a 17-1/2" hole to 500' +/-. Trip in the hole with a 12-1/4" bit and building assembly. Drill a 12-1/4" hole to 3177' +/- MD (-2950' VSS) as per the attached directional considerations. Condition the hole for logs, and prior to pulling out of the hole, obtain a 1/2 gallon mud sample. Rig up Schlumberger, and run logs as directed by the well site geologist. Trip in the hole with the 12-1/4" bit and 17-1/2" hole openeF~ ~O~ltV~~ to 17-1/2" to 3177'. alaska 0it & Gas Cons. Commission Anchorage 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Condition the hole for casing. Rig up and run the 13-3/8" OD 68#/Ft. K-55 BTC casing as follows.- A. Float shoe on the bottom. B. Float collar one joint up. C. Thread lock the float equipment. D. Centralizers 5' above the shoe, 5' above the float collar, every other joint through build and drop sections, and every other joint through the 20" casing. Cement the 13-3/8" OD casing as follows: A. Circulate the capacity of the casing prior to cementing. B. Pump 40 BBLS of fresh water. C. Pump sufficient Class "G" + 6% Gel at 13.6 PPG to circulate cement to the surface (hole caliper plus 35% excesS). D. Tail in with 200 sacks of Class "G": + 2% CaC12 at 15.8 PPG. E. Displace the top plug with drilling fluid, and bump the plug to 1500 PSI over displacing pressure. F. WOC for eight (8) hours prior to cutting off the easing. Perform top job if cement did not circulate or if cement falls. Cut off the 20" OD easing and 13-3/8" OD casing. Weld on a 13-5/8" 3000 PSI x 13-3/8" well head. Test to 1500 PSI. Nipple up' the Class III 5000 PSI BOPE. Test the rams, manifold, and surface valves to 5000 PSI. Test the annular BOP to 3000 PSI. The BLM and AOGCC may witness the test and will need 24 hours notice. Trip in the hole with a 12-1/4" bit. Prior to drilling the float equipment, test the casing to 1500 PSI. Drill the float equipment and 50' of new formation. Perform a leak off test. Record the results on the IADC tour sheets. Drill a 12-1/4" hole to TD or as directed by the field geologist. Condition the hole for logs. Prior to pulling out of the hole, obtain a 1/2 gallon sample of the mud. Rig up Schlumberger, and run logs as directed by the well site geologist. Condition the well for casing. Run the 9-5/8" OD easing a follows: A. Float shoe on the bottom. B. Float collar two joints up. C. DV tool at 4700' +/- MD. Coordinate with geologist. D. From 6927'-5025' (MD): 1902' 9-5/8" 43.5 #/Ft. N-80 BTC casing. E. From 5025'- 0' (MD): 5025' 9-5/8" 40.0 #/Ft. N-80 BTC casing. F. Centralizers 5' above the shoe, 5' above the float collar, 5' below the DV tool, and 5' above the DV tool. RECEIVED Alaska Oil & Gas Co[is. OofllmJssJon 28. 29. 30. 31. 32. 33. 34. G. Centralizers on 80' spacing from 200' below to 200' above any produc- tive zones and on 80' spacing across the bottom 500' of the 13-3/8" casing. Coordinate with the geologist. H. Thread lock the float equipment and DV tool. Cement the 9-5/8" casing as follows: A. Circulate at least the capacity of the casing and at least good clean bottoms up. Make sure any gas is circulated off. B. FIRST STAGE: ® . . Preflush as required. Class "G" + retarders, friction reducers, and water loss control additives mixed at 15.8 PPG, 0% free water, and water loss at 200 cc or less. Circulate the cement to the DV tool. Displace the top wiper plug with drilling fluid, and bump the plug to 2000 PSI over displacing pressure. Check that the floats hold, and drop the DV tool opening bomb. Circulate the DV tool until first stage cement takes initial set. C. SECOND STAGE: . 2. 3. 4. .Preflush as required. Sufficient Class "G" as in step 28.B.2 above. Bring the top of the cement up into the 13-3/8" casing. Displace the closing plug with drilling fluid, and bump the plug to 2000 PSI over displacing pressure. D. Reciprocate the pipe in 10' strokes while cementing the first stage. Set the casing slips through the BOP's; nipple down the BOP's, cut off the 9- 5/8" casing; nipple up the 13-5/8" 3000 PSI x 11" 5000 PSI tubing spool; and test to 5000 PSI. Nipple up the Class III 5000 PSI BOPE. Test the rams, manifold, and valves to 5000 PSI. Test the annular BOP to 3000 PSI. The BLM and AOGCC may witness the testing and will need 24 hours notice. Trip in the hole with an 8-1/2" bit and tandem casing scrapers. Clean out the 9-5/8" easing to PBTD as directed. Test the easing to 2000 PSI. Run a CET log and cased hole logs as directed from PBTD to the top of the cement inside the 13-3/8" easing. Run a gyroscopic survey from PBTD to surface. A testing and completion program will be provided after logging. VWA:mw 9/30/85 V. W. ANGELL RECEIVED Alaska Oil ~ Gas Cons. Cor,qrnissiofi Anchorage -~' ....................................t t ~ ......... ~ ........ ~ : __ '__~_ ----~:- ----h~-- ~ _ . I :~-~ ---~ - ~{Oluu~.x'~"~..~,~..~': ..... '.::.~ ,~.., : ....... ~ ...... :__~_~ .... ~ ~ ~ '1 ' ~ ~~ ....... ~ ......... f .... ~ ....... ~ - - . ~ ....... ~ ...... ~. - ~' -- ~ ........ J--~-;_-~ .~- ~_~T:~~;~C2~L_~2~ ..................... , - - -: .......... ~. i ~ ~1 ~ ~ _~ .... .... ~ .......... i . -~ - - , · - - · .......... ~-~ ~ -- h -~ ..... ' : ; _ .... . ...... ~ - . ~ . ; ........ , ...... ~ ......... ~ ....... ~ _~_. · _ ~ .... : ' ' ' ' I ' . · ' ' t ~ ~ I .... ''' 1' ' : .... : ................. I .......... +--- - - ~ -~ ' ........ ~ ....... i - ~ - ~ ~ ~ -~ ' ....... ' - - I .... ~ J :::: : -:;' : : - : : : : : : i :~:: -:4 :::7:;-~:__c:--__%-% .... ~--__~ .... ~.- : : I :-- . ~ . - . : . -i. -x .... '_~% ....... '. .... ': ' j ' "' ' ~ : ' I ' I '-* ' , ! , j I , ~ : i ; .......... , ............... t ....... ~ ....... ~ ....... i ..... ~--~ ....... ~-. ~ ........ ~-- t ~ ~ ' ' ; i ; --~ .... ~--' ~--~- -I ~'--T:~-F -; .... ~ ............ + ......... , ...........~ ~_ _ ' ~h~ _L ~ __~ .... : ..... ............ : ' - ........ : ........... ' ........ ~ -._ ~ ..... ~_ ~ __~ .~ __;' _~ ~ .... t ~- - - : ~ ~ , ~ I ' ' ~ ~; : ~ .... ~ ........ ~ .. .~ --., ........ . ....... ~ ............. ~ ......... ~ .... ~ -~ .... ~ .... ~ :. i . . :, ' ': : ;1-' ; 't-'~'-i ...... :':: :-:%-: .... ~-:'--~7-:~ ........ 1 ..... : .... ~ ..... : ' ............ I - -,--- : --- 4 .... ¢ : .... ~ ...... 4 ..... ~__Z_~_~- ~--!-----%---~%--- ........ ~ ................ ,-, ~ ............. ~- __~ ........... ~ .... ~-~-~ ....... ~._~ .... ~ ''; ;' ' ;' I ...... ,' ' ' ','-; ~ .... :-;:--'%-7 ..... ~ .............. ,'-- , ,' .............. .-:.i,. : ' : - · ~ '- ::-: - -t .... ~ .. i._:_~. _.~ ._;_~: ....... ~_;_'_~ .... ~_+__ i ; L-~- "4 .......... ...... ~ ~ ~ ~ , , ~ _ ~ · i ~ ,- .... , ...... , ..... ~ . . ~ ..... ~ ........ ~ ........ ~_~ ~ _~ , ~ ~ ........ ~ ..... .:.:~...:~ .... :. ..: .: ... : : ..... ~. .' : . ~ ..... :_i~i:: :-:-:i .... : :,--7 : .... ' .... , .................. ~tZ ....... , ...... ~ .... ~ ............... ~ , .... : ':;:i'": .... t "'; ..... ;';-": ": "' "' ~ ..... :'-L-- : .... ~-~ :-:: ...... ~ ' d~ ~~~,- . - .... .......... ~ - · - -- -~ --~ ....... ~ ......... ~ ...... ~ ...... I ~-~~ :~ - ~ .... ~ .... .::: :: : ' : ...... ~ - -i ....... ~ ....... + ........ ~ ......... ' .... ~ , ! - _. ~ :: ..... :.. d .... :.:..~...,, .... ~ .... ' .: .:... ...... ~ ~ ~ . ~ . ~ .. -: ! .... ! .......... 't" 'i .... t ............. : ........ ~ ...... :~::-- :::~ :-:: :--:--':-i - i. :: I~0 L_ T ! ~BIS.AS H..Z, IH~AIO ,,OE o~ l"I V 8 ,,01 !~ O00E-,o£ S~NI"I t~'~ J.t:l~l^l 0.01 'V' S"rl NOb~A.~ H.9 'N~WO SXMA4-1V SI ~NO IVHI OS ~I.~HJ.~DOI 0_~'ic1~03 -~8 'I'IIM S~A-IVA 'I-IV8 ,,01 '1 I ~OJ..On ONO::) ,,0£ -'"'4- ~ ..-. -. ,~.- -.--.'~- 9N IS ~..9 '0 '0 ,,OZ A40S ,, Og ISa O00Z- ~$dooog:,Z ~9N~TH ,se O0OZ ',74 oz I I ANNULAR PREVENTER 135/8" 5000 psi 13 '78"-5000 psi 5/8"-5o00 psi DOUBLE GATE ~."- 5000 psi KILL LINE 2"' 5000 ps i BLIND RAMS PIPE RAMS MUD CROSS SPOOL · --13 5/8"'5000 psi 3"- 5000 ps i ~3"' 5000 psi TO MANIFOLD BULL PLUG 13 5/8"' 3000 psi ~,2"'3000 psi BLIND FLANGE SOW 20" · · CEMENT *., L%. -.; .I.I.i.=L ' · 4) . I I I 30" CLASS ]~' BOP (B) Chevron CHEVRON U.S.A. BRU 2"- 5000 psi KILL LINE"~ 2"- 5000 psi BULL PLUG ANNULAR PREVENTER i 3 5/8"-5000 psi 'e---13 5/8 "- 5000 psi 135/8 "- 5000 psi DOUBLE GATE' BLIND RAMS PIPE RAMS TUBING HEAO I I I I I SOw · '-13 5/8"-5C00 psi ~ 11"-3000 psi .,-3". si 135/8"- 3000 psi psi BLINO FLANGE 3"- 5000 psi ! TO MANIFOLD Chevron CHEVRON U.S.A. · · I, CLASS ~.13 ~'8" CEMENT II TTr BOP (C) __ Alaska Oil & Gas Co~s. to~;~m~ss~on BRU (~:8-g-(::]5) ~:-g L£-OI:Id ~AYU-.'IPI I .J- Z-91g-OJcl 'qA~lno ss3ago~la '!"!3/~ 9N I'1'11 BO SNOIIYB3aO '1"13,~ BO_-i 'I¥SOaOBcl SI33HS--7'--JO-7--133Hg FORMATION EVALUATION PROGRAM BRU 211-3 Geologic Markers: Sterling Formation Beluga Formation Total Depth A -3030 VSS B -3230 VSS C -3370 VSS D-3520 VSS E -3780 VSS F -4160 VSS G -4680 VSS H -5160 VSS I -5850 VSS -6800 VSS Mud Logging: None Required Samples: NOne Required Coring: None Required Fora ion Evaluation Program Belu~_ River Field, BRU 211-3 Page 2 of 4 WELL SECURITY CLASSIFICATION: "Confidential" No information will be released except by Production Department in conformance with existing policy. WELLSITE DEVELOPMENT GEOLOGIST: Per duty schedule. Wellsite log evaluation, including bottomhole temperature extrapolations, will be required. Wellsite geologist to maintain detailed chronology of logging operation as per Wellsite Geologists' Procedure Manual. Correlate to offset wells and prepare R+ vs. OD crossplots for Sterling Fro. (Zones A, B, & C). WIRELINE LOGGING: (SERVICE COMPANY) Schlumberger Kenai Office (907)776-8155 David Rebol, District Manager Anchorage Office (907)562-2654 Floyd Bettis, Account Manager A® General Instructions: 1. All logs are to be digitally recorded. e A 1/2 gallon sample of circulated drilling fluid is to be obtained by Schlumberger engineer immediately prior to pulling drill pipe for logging operations. Sample is to be measured for Rm, Rmf, and Rmc by Schlumberger. e Two maximum recording thermometers are to be used on ail logging sondes run in hole. Record both thermometer readings in "remarks" section of log heading. me All log calibrations are to be recorded and printed on 5" = 100' scale logs. e e 0 Logging engineer to record time (hour, date) that each sonde started logging off bottom. Blue line prints for each log run are to be made at the wellsite. See Part III for distribution requirements. Log scales are to be recorded at top and bottom of all field and final prints. e 2" = 100' and 5" = 100' logs are to be printed with separate headings. ge A quality control checklist is to be completed for each log run and attached to the 2" DIL-SFL or 2" DLL-MSFL film. 10. 11. Record all logs with heavy weight pen. If there are changes in digital tape format, or labeling, it should be coordinated with C.W. Trent, (415)680-3408. For. ion Evaluation Program Beluga..{iver Field, BRU 224-34 Page 3 of 4 Be Log Run #1: Intermediate TD to shoe of 20" casing (3050' MD, -2930' vss, 12¼" hole) 1. DIL-SFL-GR: 2" = 100' Log: 5" = 100' Log: Resistivity linear 0-50 ohmmeters Conductivity linear 0-1000 millimhos Resistivity logarithmic 0.2-2000 ohm meters GR scale 0-150 API units SP 10 millivolt divisions *Display SP & GR in Track #1 for 2" and 5" logs. Show SP as a solid line curve. If SP response is positive, reverse the SP presentation to + left - right. ® BHC Sonic: 50-150 microsec/ft, transit time scale Run in combination with DIL. 3. Have sidewall core gun available for possible use. Ce TD Log Run: TD to shoe of 13-3/8" csg (6927' MDt -6800' vss~ 12¼" hole) 1. DLL-MSFL-GR: 2" = 100' Log: Resistivity linear 0-50 ohmmeters Conductivity linear 0-1000 millimhos 5" = 100' Log: Resistivity logarithmic 0.2-2000 ohmmeters GR scale 0-150 API units SP 0-10 millivolt divisions Compute synthetic ML *Display SP & GR in Track #1 for 2" and 5" logs. Show SP as a solid line curve. If SP response is positive, reverse the SP presentation to + left - right. Eliminate amplified curve. Display shallow (LLS) & deep (LLD)later log curves on 2". Display LLS, LLD, and MSFL on 5". 0 BHC Sonic: (SDT, if available) Display caliper and bit size in Track #1. Display SP and GR as correlation curve in Track #1. Display tension curve in Track #3. Use 50-150 microsecond transit time scale. Transit time to be integrated and recorded. a) If DIL-SFL is run, then record BHC in combination with same. e OCT o Oil & Gas Cons. Con, mission Anchorage LDT-CNL-GR: Record LDT at 1.2" sampling interval. Display LDT as two logs. Log 1: display CNL, LDT (in ¢ units 0-60%), and correction curve in Tracks 2, 3, and 4. In Track 1, display SP, GR, and caliper (SP may be played back from prior run). Fort .on Evaluation Program Belur,~ River Field, BRU 211-3 Page 4 of 4 II. Log 2: display SP, GR, and caliper in Track 1. Display PE curve, tension, and LDT (1.65-2.65 gr/cc) in Tracks 2, 3, and 4. Compute Cyberlook at wellsite. Rw - 3.4 ohm-m at 68OF N=2, M=1.73, A=l.13 4. PML: e RFT: 'l~sure measurements in selected sand intervals to be specified by wellsite geologist. Log is not to be run under adverse hole conditions. Quicklook Horner extrapolations are to be prepared at wellsite. Sidewall Coring: (SWS) a) To be specified by wellsite geologist. b) +50 SWS should be sufficient (one trip in hole w/tandem guns). Take SWS at every RFT pressure set depth. e) Bullets are to be designed for most efficient recovery. The formation is soft and the sands are often unconsolidated. Combination bullets with extra long cables may be advis- able. d) Sample sands predominantly, but scatter 3-4 samples from TD to csg shoe in claystone intervals. e) Where sufficient sample is recovered (1/2" +) send to PTS for routine analysis. Choose 3 Beluga Fm. Sand samples for CEC analysis; PTS 4450 W. 50th Avenue Anchorage, AK 99502 (907)243-2822 DRILL STEM TESTING: Cased hole testing is anticipated in this well. Evaluation will be on the basis of wireline log analysis. Formation test instructions, fluid sampling, and hydrogen sulfide analyses are to follow terms of C.N. Segnar Formation Test Procedure letter of December 17, 1982. k£C£1V£D ~las~a Oil ~ Gas Cons. Anchorage BRU ~-11-3 DRILLING FLUIDS PROGRAM 26" Hole Mud Type Spud Density (PPG) 8.8+/- Funnel Viscosity (Sec/Qt) 100+/- Plastic Viscosity (CPS) Yield Point (#/100 Ft2) Gel Strength, Initial Gel Strength, 10 Min. pH 9.0+/- C1 (MG/L) Fresh Water Loss (API) NC 17{" Hole 1 9.0 120-80 20+/- 40+/- 10+/- 40+/- 9.0+/- Fresh NC 12 ¼" Hole 9.2-10.1 40-50 12-18 10-15 3+/- 10+/- 9.0+/- 18,000 10-5 . Chrome Free Lignosulfonate as required Non-Dispersed Polymer with 6% KC1 PROGRAM 1. Spud 17{" pilot hole with a fresh water - gel spud mud. 2. Drill to the 20" casing point with viscosity as required for gravel. 3. Open the 17{" hole to 26" with the same mud. . Drill out below the 20" casing with a 12¼" bit with a lightly treated mud with a viscosity of 100+ for gravel. . Drill to the 13-3/8" casing point with viscosity as required for gravel and coal. 6. Condition the mud to logging conditions prior to reaching the casing point. 7.. Condition the well for logs. Make a wiper trip into the 20" casing. 8. Open the 12¼" hole to 17{" with the same mud. e Drill the cement, float equipment, and 50' of new formation with the same mud. Treat as required for cement contamination. 10. After taking a leak off test, displace the hole with a non-dispersed polymer system with 6% 'KCL. 11. It will be very important to maintain the drilled solids as low as possible with this system. All solids control equipment and agitation equipment must be working at all times. Fluid density will be increased with barite additions and not with an increase in drilled solids. kECEIVED Alaska 0{i & Gas Cons. CommissJo. Anchorage ._ I '1 "' I/I ; ! . I //~ u.s. SURVEY5596 " I CHEVRON- ARCO - SHELL ' I A-029657 ~/,~' · - il /- iT-~ J '" xT.V.D 6705' ' '~-~/f~"7'II'CHEVRON-ARCO-SHELL ' ~' '/'i I '",," // '"°'--'~'~' . - ' ~ ' J '" ,,_ C-_--.._e"~-Z .... " , , , --,EASE I A-ozge56 . !_/// ,, , . ~ ~.o. 53oe'/// . I ' UNIT -~ I///" BOUNDARY ' 244- ,ri ,~/~4f _~ ~S~.,.//- CHEVRON-ARCO-SHELL __,__,; t ~.,,~/-"~'~-'... ~,-,~ ., : // -'x, '. '" ..... ~--,f/ + '~.~.'~,'~' -! ~ ! /// ~ !~/I ' ~ ' 8 [~.mm ~ 9 ' J [ '""' ' '--I0 · J I I---///: I ' ~ i~/ .'. /-'-'~'-'- ' ltl - ' I ! ' .. I l~ ~ ~ '"' · ' -- DR~Z2-"~¢¢ CFI, CHEVRON U.S.A. INC. DR ~Pr,. PROPOSED-LOCATION u:-~t OPR'G. DEPT. APPROVED BRU 224-54 ~ 211-5 ~sk, Oil & 6as Cons. SE~ 4, TI2N, RIO W, SEWARD B ~ Anchorag9 E,6... OEPT.- W.O. s.o A P- A- 261-0 Printed in U.S.A. GO-580-AB (CD-1-74) Drilling Fluids Program BRU 211-3 Page 2 12. 13. 14. 15. Mud density should be kept as low as possible to prevent formation damage. the rotating head should facilitate keeping gas off the rig floor and from below the substructure. See the attached curve for determination of density required. Maintain laminar flow around the drill pipe and drill collars if hole conditions permit (fill, sloughing, etc). Estimate that 90 fpm around drill pipe should suffice. The PV/YP ratio should be kept in the 1.2+/- range. VWA:mw 9/26/85 RECEIVED Oil & Gas Cons. Commission Anchorage Chevron Chevron U.S.A. Inc. 3001 C Street, Anchorage, AK 99510 Mail Address: P.O. Box 107839, Anchorage, AK 99510 Phone (907) 786-~600 Land Department October 4, 1985 STATE OF ALASKA PERMIT TO DRILL BRU 211-3 & BRU 224-34 BELUGA RIVER UNIT, ALASKA Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: Chevron U.S.A. Inc., on behalf of itself, ARCO Alaska, Inc., and Shell Western E&P, Inc., proposes to drill the subject wells at a location as shown on the attached plat. For your consideration and approval we submit, in triplicate, State of Alaska Oil and Gas Conservation Commission form "Permit to Drill", Form 10-401, and our check in the amount of $200.00 for the two applications. As shown on the attached plat, the proposed wells will be located on U.S. Oil and Gas Lease A-029656 as follows: Well BRU 211-3 Surface Location: + 158'W and + 204'S of the NE corner of Section 4, T12N, R10W, S.B.&M. Bottom Hole Location: + 200'E and + 200'S of the NW corner of Section 3, T12N, R10W, S.B.&M. Well BRU 224-34 Surface Location: Bottom Hole Location: + 258'W and + 204'S of the NE corner of Section 4, T12N, R10W, S.B.&M. + 1970'E and + 800'N of SW corner of Section 34, T13N, R10W, S.B.&M. The surface locations and bottom hole locations fall within the boundaries of the Beluga River Unit. RECEIVED ocr o 19t AI~L~& Oil & Gas Cons. Commis~..il ^n~horage Alaska Oil and Gas Conservation Commission October 2, 1985 Page Two Pursuant to the Alaska Oil and Gas Conservation Commission Regulations and the applicable statutes of the State of Alaska, Chevron U.S.A. Inc., as Unit Operator, hereby requests the Alaska Oil and Gas Conservation Commission to issue an order allowing exception to Title 20, Alaska Administrative Code, Section 25.055 to permit the drilling of subject wells at the proposed locations. Chevron U.S.A Inc., ARCO Alaska, Inc., and Shell Western E&P, Inc., each owns an undivided one-third (1/3) interest of the subject lease and are the sole owners of all leases on the sections directly and diagonally offsetting the sections to where the subject wells are to be drilled. ARCO Alaska, Inc., and Shell Western E&P, Inc. were notified of this application with a certified copy of this letter. There are no other working interest owners or operators which would be affected by granting the spacing exception on the subject wells. Chevron U.S.A. Inc., as the Unit Operator, believes that the Permit to Drill Applications and the exception that has been requested are necessary and desirable in order to efficiently drain the reservoir. The gas that the new wells will produce is needed to continue to meet our obligation to Chugach Electric Association, Inc., and to meet Shell's new commitment to Alaska Pipeline Company, a subsidiary of Enstar Natural Gas Company, which has built a 20" gas transmission line from Beluga River to Anchorage. JET:fm Attachments: ~.L. Weaver (1) Two (2) AOGCC Permit To Drill Applications (2) Two (2) BLM Permit To Drill Applications (3) Drawing AP-A-261-0 cc: ARCO Alaska, Inc. (Certified Mail No. P175-864-147) Attention: Mr. John C. Harvard P.O. Box 100360 Anchorage, Alaska 99510 Shell Western E&P, Inc. (Certified Mail No. P175-864-148) Attention: Mr. B. E. Barnard P.O. Box 527 Houston, Texas 77001 RECEIVED o 19 15 Alaska Oil & Gas COns. Commission Anchorage STATE OF ALASKA THIRD JUDICIAL DISTRICT J. L. Weaver, being first duly sworn, UPon oath deposes and says that he is the Area Operations Superintendent, Production Department, employed by Chevron U.S.A. Inc., and to the best of his knowledge and belief that the facts stated herein and shown on the accompanying plat are true, and that the accompanying plat is drawn to scale and correctly reflects plat pertinent and required data. J. L. Weaver Subscribed and sworn to before me this dayof ~~ , 1985. Farah Melanson, Notary Public State of Alaska My Commission Ex~ires Feb. 6_, !989 Notary Fublie in and for the State of Alaska RECEIVED OCT 0 I985 Alaska Oil & Gas Cons. Commission Anct~orage NEW. WELL "i"'iAPPROVE ' DATEi" ~..,i'~': ( 1 }-Fe e /0-2-~ff"~ 1. .(2) .LOC'.: ,.,~_~. ~(~2 thru 8) e 3, 4.: 5' 6, (10 and .12) (I~ thru 21) (22 thru 26) 13. .14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Company '~ Lease .& .Well No. · (.'..:i':!(.(:.'??....~..'.-,,:=,~'. ':.?.,:~.. '. '., :':.: . ~ ' ,. YES NO '' REMARKS' · . e" 'ach d Is th permit fee att e ..... ,.... ...................... , .......... ~o , · Is well to be cate in a de ne poo ...................... , ...... Is well located proper· distance from property line .................. Is well located .proPer distance from other wells . ~ ........... ~ .....· __ Is sufficient undedicated acreage available in this pool ..... . .... .. ~ .. Is well to be deviated and is we'llbore plat included ................ Is operator the only affected party ................................. , Can permit b'e approved before ten-day wait .......................... Does operator have a bond in force · '~.~' ' ' ' , Is administrative approval needed ..... ~ ~.n.~. ~.~, ~ ~b~ ~,,V-~ Is the lease number appropriate ...... / , . Is conductor string provided ' eeeeeeeelee~ee~e~eeeeeeeeeeeee~eee®ee®®® Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings .,. Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked, off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore, separation proposed ............................ Is a diverter system required /4~ eeeeeeee~eeeeeeeeeeeeeeeeeeeeeeeeeeeee® Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test t° ~~' psig ,. ~ Does the choke manifold comply w/API RP-53 (Feb.78) ...... ' ............ Is the presence of H2S gas probable ................................. Additional requirements .............................................. Additional Remarks: Geo ~. Engi~i,n,~: H~'~ LCS WVA~ MTM ~-' HJH ~ rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX~ ,. No specialeffort has been made to chronologically · · = · .. organize this category of information. U 'u -;:- i-- .-;:- L,'~ u -;;- II Ii II II II II I 4:- -;t~ -X- -~i-II II II II -;;- -;,'- 0 LLJ t~ tTJ -,',?-il 1! FI-FI f 1'! c.~ f11 ~;- · · · · [:7 ~ ~;- ¢;- ~ ;;- ( -~ % ;;- ~;--~ ~;- ;? iii -II II j-;. 0 t'7...~ C) C-~ 0 C~O C~ 0 CD 0¢2.) 0 0 0 0 C.2 0 0 ri] -TI H ~ k--'i LJ -i11-"-: L~J I.~) OMI ~ 0 t-'~ ~ i'-J C.~ ~ ~ k)li"-~H[',,~HI-'~'I"~'[',,J['',J C=,~ 0 "~ CL~ ~') 0 O 0 0 C_3 0 0 C) (1:~ Z fl CJ -II C-; L) 11~ "X- O' U, O' --J ¢7, (3- C'~ t~) ~-. v, · v. ~,. !11 'tl (-~ f-..h- CT, c.~O O0 O0 6,"~ O00C~Oc/) O00C~ O0000C~O000~;L3 O000000C) O0 -H OOCDO0~Oc~O0~; ;fl ~ll/t~J{ 'O -}t - il -U G-ii/) -t~ f_-, "J 31 '11 -(J (.-_} (/I (-j itl --41 Il ;Aji -{1 L J} (y) l-_) I-~l H i i1 /0 TI jr> _~: :r:- d:: Z :zj -4 r- G) I~.J r- -g rl'l ,--,{ ~ "U rD. I I '...IL/ ~.L~ ---~ --t £,J ~Jo .,' ,J ¢2.) C.., 0 f'il I--i '11 LJ I I ~ 0 ~j U~ ~ 0 ~o~~ 0 L~ Ui ~ 0 C::: (/) itt rll F) (...[. 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