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Home My WebLink About169-0991a. 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): North Cook Inlet / NCI GL: N/A BF: N/A Strlg Undefined Gas, Tertiary Gas & Undefined WDSP Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 130 (ft MSL) 22.Logs Obtained: N/A 23. BOTTOM 30"381 20" K-55 1,990 13-3/8" N-80 6,950 9-5/8" N-80 11,675 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 Gas-Oil Ratio:Choke Size: N/A Water-Bbl: PRODUCTION TEST N/A Sr Pet Eng Oil-Bbl: Water-Bbl:Flow Tubing Sr Res EngSr Pet Geo Date of Test: Oil-Bbl: N/A Surf 1,990 Per 20 AAC 25.283 (i)(2) attach electronic information 133 6,950 Surf Surf 3200 7,300 5760N/A GRADE 72 SETTING DEPTH TVD 40 332303.1 TOP SETTING DEPTH MD Surf 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 1142 sx N/A 24 DrivenSurf 2583952.3 TOP HOLE SIZE AMOUNT PULLED N/A N/A CASING, LINER AND CEMENTING RECORD 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 331948.4 2586727.0 N/A CASING WT. PER FT. 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, 3/16/1970 CEMENTING RECORD 50-833-20032-00-00 N Cook Inlet A-12 ADL0017589 1254' FNL, 929' FWL, Sec 6, T11N, R9W, SM, AK 1257' FSL, 1324' FWL, Sec 6, T11N, R9W, SM, AK N/A 10/22/1969 14910 MD / 14214 TVD 3050 MD / 3050 TVD 116 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 4/18/2022 169-099 / 322-137 See Schematic BOTTOM 1820 sx18.5 ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7,299 See Schematic DEPTH SET (MD) PACKER SET (MD/TVD) 4-1/2" 7" TUBING RECORD Surf 381 SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 12,032 Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Meredith Guhl at 1:18 pm, May 13, 2022 Suspended 4/18/2022 MDG RBDMS MDG 5/13/2022 xG MDG BJM 3/15/23 883 MDG 3/16/2023 DSR-5/13/22 Sidetracked 8/25/2022 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 31. List of Attachments: Operations Summary, Schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Dan Marlowe Contact Name: Chad Helgeson, Operations Engineer Operations Manager Contact Email:chelgeson@hilcorp.com Authorized Contact Phone: 907-777-8405 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at total depth: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). INSTRUCTIONS Authorized Name: Authorized Title: Signature w/Date: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2022.05.10 11:52:48 -08'00' Dan Marlowe (1267) _____________________________________________________________________________________ Updated By DMA 05-13-22 SCHEMATIC North Cook Inlet Well: NCI A-12 Last Completed: 11/11/1997 PTD: 169-099 API: 50-883-20032-00-00 CASING DETAIL Size Wt Grade Conn ID Top Btm 30”133 H-40 Welded 28.000 41’381’ 20”133 H-40 19.730 41’1,990’ 13-3/8”72 N-80 BTC 12.347 41’6,950’ 9-5/8”40 N-80 8.835 7,300’12,032’ LONG STRING TUBING DETAIL 7”26 J-55 ST/L 6.240 3,060’3,200’ 4-1/2”12.75 N-80 EUE 8rd 3.958 3,200’5,760’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 1 3,050’3,050’CIBP (04/05/22) 2 3,175’3,175'6.440 Halliburton Twin Flo Seal Assembly 3,200’3,200'8.000 Halliburton Twin Flow Packer (2-3/8” pulled) 3 3,496’3,496'6.220 “MSN” Seals & Seal Extension 3,500’3,500'8.000 Halliburton MWD Perm Packer & Tbg Adapter 3,504’3,504'8.000 Halliburton Seal Bore Extension & Tbg Adapter 3,507’3,507'6.256 Muleshoe Guide 4 3,750’3,750'3.958 Halliburton Seal NoGo Unit 3,750’3,750'8.000 Halliburton MWD Perm Packer & Tbg Adapter 5 4,003’4,003'3.813 Halliburton XD Sliding Sleeve - Open 6 4,068’4,068'3.958 Halliburton Seal NoGo Unit 4,069’4,069'8.000 Halliburton MWD Perm Packer & Tbg Adapter 7 4,132’4,132'3.813 Halliburton XD Sliding Sleeve - Closed 8 4,174’4,174'3.958 Halliburton Seal NoGo Unit 4,175’4,175'8.000 Halliburton MWD Perm Packer & Tbg Adapter 9 4,254’4,254'3.958 Halliburton Seal NoGo Unit 4,255’4,255'8.000 Halliburton MWD Perm Packer & Tbg Adapter 10 4,359’4,359'3.813 Halliburton XD Sliding Sleeve - Open 11 4,452’4,452'3.958 Halliburton Seal NoGo Unit 4,453’4,453'8.000 Halliburton MWD Perm Packer & Tbg Adapter 12 4,569’4,569'3.958 Halliburton Seal NoGo Unit 4,569’4,569'8.000 Halliburton MWD Perm Packer & Tbg Adapter 13 5,175’5,175'3.813 Halliburton XD Sliding Sleeve - Open 14 5,250’5,250'3.958 Halliburton Seal NoGo Unit 5,250’5,250'8.000 Halliburton MWD Perm Packer & Tbg Adapter 15 5,383’5,383'3.813 Halliburton XD Sliding Sleeve - Open 16 5,446’5,446'3.958 Halliburton Seal NoGo Unit – Length 7.29 OA 5,448’5,448'8.000 Halliburton MWD Perm Packer & Tbg Adapter 17 5,634’5,634'3.813 Halliburton XD Sliding Sleeve - Closed 18 5,757’5,757'3.725 Halliburton XN Nipple 19 5,759’5,759'3.985 Wireline Guide Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc) Depth (MD)Depth (TVD)Description 3,064’3,064’ 2/16/18 - 43 BBL Class G cement pumped – tagged @ 3,064’ – Suspect tubing integrity loss 5,935'5,935'EZSZ Plug Set w/1997 Workover 5,986'5,986'2-7/8" Tubing 6,833'6,833'Cement Retainer 11,965'11,616'Cement Retainer - PBTD _____________________________________________________________________________________ Updated By DMA 05-13-22 SCHEMATIC North Cook Inlet Well: NCI A-12 Last Completed: 11/11/1997 PTD: 169-099 API: 50-883-20032-00-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status STERLING 3,260' 3,370' 3,260' 3,370' 110' 02/16/18 Szq’d CI - STRAY 3,558' 3,568' 3,558' 3,568' 10' 6/10/1975 Szq'd CI - STRAY 3,577' 3,587' 3,577' 3,587' 10' 6/10/1975 Szq'd CI-A 3,604' 3,628' 3,604' 3,628' 24' 6/10/1975 Szq'd CI-1.0 3,820' 3,880' 3,820' 3,880' 60' 02/16/18 Isolated CI-2.0 3,896' 3,960' 3,896' 3,960' 64' 02/16/18 Isolated CI-3.0 3,982' 3,994' 3,982' 3,994' 12' 02/16/18 Isolated CI-4.0 4,014' 4,048' 4,014' 4,048' 34' 02/16/18 Isolated CI-5.0 4,090' 4,098' 4,090' 4,098' 8' 6/10/1975 Sliding Sleeve - Closed CI-5.0 4,106' 4,111' 4,106' 4,111' 5' 6/10/1975 Sliding Sleeve - Closed CI-5.1 4,116' 4,124' 4,116' 4,124' 8' 6/10/1975 Sliding Sleeve - Closed CI-6.0 4,141' 4,166' 4,141' 4,166' 25' 6/10/1975 Sliding Sleeve - Closed CI-7.0/CI-7.1 4,188' 4,238' 4,188' 4,238' 50' 02/16/18 Isolated CI-8.0 4,272' 4,282' 4,272' 4,282' 10' 02/16/18 Isolated CI-8.2 4,298' 4,316' 4,298' 4,316' 18' 02/16/18 Isolated CI-10.0 4,378' 4,390' 4,378' 4,390' 12' 02/16/18 Isolated CI-11.0 4,415' 4,440' 4,415' 4,440' 25' 02/16/18 Isolated A-3 4,475' 4,482' 4,475' 4,482' 7' 02/16/18 Isolated B-7 4,660' 4,668' 4,660' 4,668' 8' 02/16/18 Isolated E-3 4,973' 4,978' 4,973' 4,978' 5' 02/16/18 Isolated E-4 4,990' 4,995' 4,990' 4,995' 5' 02/16/18 Isolated E-5/E-6 5,010' 5,025' 5,010' 5,025' 15' 02/16/18 Isolated E-8 5,050' 5,057' 5,050' 5,057' 7' 02/16/18 Isolated E-9 5,064' 5,070' 5,064' 5,070' 6' 02/16/18 Isolated F-4 5,120' 5,135' 5,120' 5,135' 15' 02/16/18 Isolated F-5 5,150' 5,157' 5,150' 5,157' 7' 02/16/18 Isolated G-1 5,194' 5,204' 5,194' 5,204' 10' 02/16/18 Isolated H-1/H-1.2 5,292' 5,305' 5,292' 5,305' 13' 02/16/18 Isolated H-6 5,354' 5,372' 5,354' 5,372' 18' 02/16/18 Isolated H-8 5,394' 5,414' 5,394' 5,414' 20' 02/16/18 Isolated H-9 5,431' 5,436' 5,431' 5,436' 5' 02/16/18 Isolated I-3 5,466' 5,480' 5,466' 5,480' 14' 4/1/1993 Sliding Sleeve - Closed I-4 5,482' 5,490' 5,482' 5,490' 8' 4/1/1993 Sliding Sleeve - Closed I-7 5,514' 5,521' 5,514' 5,521' 7' 4/1/1993 Sliding Sleeve - Closed I-8 5,532' 5,540' 5,532' 5,540' 8' 4/1/1993 Sliding Sleeve - Closed J-2 5,564' 5,574' 5,564' 5,574' 10' 4/1/1993 Sliding Sleeve - Closed J-2.1 5,576' 5,584' 5,576' 5,584' 8' 4/1/1993 Sliding Sleeve - Closed J-3 5,592' 5,596' 5,592' 5,596' 4' 4/1/1993 Sliding Sleeve - Closed K-4.1 5,668' 5,674' 5,668' 5,674' 6' 4/1/1993 Sliding Sleeve - Closed M-4 5,757' 5,764' 5,757' 5,764' 7' 4/1/1993 Sliding Sleeve - Closed P-2 6,088' 6,096' 6,088' 6,096' 8' 4/1/1993 Isolated P-5 6,130' 6,150' 6,130' 6,150' 20' 4/1/1993 Isolated Q-2 6,180' 6,186' 6,180' 6,186' 6' 4/1/1993 Isolated R-6 6,330' 6,338' 6,330' 6,338' 8' 4/1/1993 Isolated S-6 6,441' 6,448' 6,441' 6,448' 7' 4/1/1993 Isolated T-2 6,540' 6,547' 6,540' 6,547' 7' 4/1/1993 Isolated T-6 6,641' 6,646' 6,641' 6,646' 5' 4/1/1993 Isolated U-5 6,718' 6,726' 6,718' 6,726' 8' 4/1/1993 Isolated U-7 6,748' 6,758' 6,748' 6,758' 10' 4/1/1993 Isolated V-1 6,790' 6,800' 6,790' 6,800' 10' 4/1/1993 Isolated Rig Start Date End Date 3/19/22 4/18/22 03/19/2022 - Saturday Rig up platform triplex on A-12. Perform passing MIT-IA to 2700 psi. Starting pressure was 2741 psi and 30 minutes later dropped to 2732 psi. Performed passing MIT-T on LS to 2000 psi. Starting pressure was 2111 psi and 30 minutes later dropped to 2076 psi. Performed passing MIT-T on SS to 2000 psi. Starting pressure was 2125 psi and 30 minutes later dropped to 2077 psi. Secure well. 03/23/2022 - Wednesday Spot eline equipment from A-10 and rig up. Arm and RIH with 7” tubing cutter (5.75” running OD). Tag up on TRSSSV at 412’. Operations bleeds off and pressures up valve to 4200 psi several times trying to open, tag up again. POOH and disarm cutter. RIH with 1-11/16” weight bar assembly and tag up in same spot. POOH, secure well and SDFN. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCIU A-12 50-833-20032-00-00 169-099 03/31/2022 - Thursday R/U S/L, Cycle SSSV several times appears to be opening, RIH w/5.81 GR t/505' good, POOH p/u 5.88 GR rih drift to tag @ 3071' WLM, POOH, R/D W/L , Unload boat. R/U e-line TOC @ 3065' WLM, P/U to 3060'WLM and cut tubing, POOH and R/D E-line. Circulate well with drill water @ 2.5 BPM. 04/01/2022- Friday Cont. circulate well @ 2.5 bpm to production till clean & balanced, pump 560 bbls monitor well 30 min good. R/D circulating lines, set BPV in short string, attempt to set BPV in long string unable to drift tree, troubleshoot finding had wrong size plug for application. arrange decks, prep wellhead room for tree removal, n/d adaptor spools from riser, install spacer spools to riser w/DSA. Receive proper size BPV for long string, prep same & install, N/D tree, remove SSV's, control lines, prep tree to pull. install 7" rams in upper doublegate. R/U & work tree free & pull. Clean wellhead and threads on hanger, Install X/O's and plugs on hanger. Install 2 spools, DSA, riser, mud cross, double gate, single gate and annular. Skid rig over well and torque Bop studs. Hook up Koomey lines, Choke and kill lines, raise and scope mast, Install floor and cont. R/U misc. equipment. 04/02/2022 - Saturday Con.t to Install and level floor over hole, R/U stairs and landings, winterize cellar, functions test BOP's, trouble shoo BOP controls, Prep to test BOP's and install 3 1/2" test jt. Test CMV's, 1 thru 10, HCR choke, HCR kill, to 250 low/ 3000 high. Test VBR's with 3 1/2" test jt., Blind rams, 7" rams, IBOP, TIW, and dart valve, P/U 2 7/8" test jt. and test VBR's to 250 low /3000high, test annular to 250 low / 2500 high. Perform draw down test. Wash and pump out BOP stack - M/U running tool on 3 1/2" jt. P/U running tool and pull blank subs. 04/03/2022 - Sunday Pull Blanking subs from short & long strings. Attempt to pull BPV from short string, unable to latch, re-pin pulling tool flush & suck out stack, troubleshoot & continue trying to latch BPV, with no joy, prep handling eq. f/2 3/8", M/U landing joint to short string, mobe tools from beach, re-size pulling tool to drift landing joint. Latch & pull BPV from short string & long string. L/D T-bar, m/u landing joint, p/u handling tools. Pull hanger free & cont pulling out of seals @ 19k seals free @ 16k, pull hanger to floor. R/U e-line w/tubing punch. RIH w/tubing punch and punch hole at 1785' WLM, POOH. R/D E-line. POOH with 2 3/8" tubing. Rig Start Date End Date 3/19/22 4/18/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCIU A-12 50-833-20032-00-00 169-099 4/05/2022 - Tuesday M/U E-line tool string , 13 3/8 CIBP, CCL,GR. RIH tag top of cut jt. p/u & set @ 3050' WLM. POOH r/d e-line. Clear rig floor, L/D handling eq. bleed down accumulator, r/d lines. Pull rig floor, prep & scope down mast, prep mast to layover, unspool D/W, tuggers & man rider, remove guy-lines, pull drove line, unbolt D/W, r/d pits & pump. l/d mast & prep for removal, break bolts on BOPE, pull circulating lines, prep loads for transfer to Bruce for rig leg move. N/D BOPE. N/U tree, continue prep loads for rig move. Backload Boat with Eq. to store on Bruce Platform for rig move, unload same on Bruce, prep mast, d/w carrier & misc eq to load on boat for leg move to A-02. 04/18/2022 - Monday MIT-IA to 2,750psi and charted for 30mins-good test, witness by AOGCC inspector Lou Laubenstein. 04/04/2022 - Monday Service Rig, c/o handling eq. t/7". M/U landing joint, pull hanger free @ 87k, string moving @ 72k, breakdown hanger & l/d same, m/u xo for safety valve , l/d landing joint. POOH l/d 7" completion tubing. Test casing to 2700psi for 30 min- good test. R/D tong and clear rig floor. M/U tool string and check tools, found short in cable, cut 330' of E-line and re-head. P/U tool string and RIH. Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 5/09/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NCI A-12 (PTD 169-099) CIBP 04/05/2022 Please include current contact information if different from above. PTD:169-099 T36565 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.10 10:07:36 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Harold Soule - (C) To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Juanita Lovett Subject:HAK 404 4-3-2022 Date:Monday, April 4, 2022 7:06:33 AM Attachments:BOP Hilcorp 404 4-3-2022 .xlsx Harold Soule Office 907-776-6754 Cell 907-227-9400 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward 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. NCIU A-12 PTD 1690990 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor:Rig No.:404 DATE:4/3/22 Rig Rep.:Rig Phone:907-776-6754 Operator:Op. Phone:907-776-6754 Rep.:E-Mail Well Name:PTD #1690990 Sundry #322-137 Operation:Drilling:Workover:x Explor.: Test:Initial:x Weekly:Bi-Weekly:Other: Rams:250-3000 Annular:250-2500 Valves:250-3000 MASP:1042 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1 P Housekeeping P Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec.P Ball Type 1 P Standing Order Posted P Misc.NA Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 13-5/8 5m P Pit Level Indicators P P #1 Rams 1 2 3/8/3 1/2 Flex P Flow Indicator NA NA #2 Rams 1 7"P Meth Gas Detector P P #3 Rams 1 Blinds P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 2-1/16 5m P Inside Reel valves 0 NA HCR Valves 1 2-1/16 5m P Kill Line Valves 2 2-1/16 5m P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi)2950 P CHOKE MANIFOLD:Pressure After Closure (psi)1550 P Quantity Test Result 200 psi Attained (sec)25 P No. Valves 11 FP Full Pressure Attained (sec)113 P Manual Chokes 1 P Blind Switch Covers:All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles # & psi (Avg.):4@2250 P CH Misc 1 FP ACC Misc 0 NA Test Results Number of Failures:2 Test Time:11.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/29/22 5:51 PM Waived By Test Start Date/Time:4/2/2022 16:00 (date)(time)Witness Test Finish Date/Time:4/3/2022 3:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp Tested with 2 3/8, 3 1/2 & 7" test joint, tested gas Alarm , Annular closing time on 2 3/8 T.J. 26 sec. Had FP on CMV #8 serviced & retested good, had grease fitting on CMV #4 leak, replaced fitting re-test good. Note: test time reflects test joint changes, troubleshoot & repair leak at hanger to test jt connection. Chad Johnson / Ed Castgine Hilcrop AK Harold Soule / Sam Menapace NCIU A-12 Test Pressure (psi): hsoule@hilcorp.com Form 10-424 (Revised 02/2022)2022-0403_BOP_Hilcorp404_NCIU_A-12          J. 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ϮϬ͟ϭϯϯ,ͲϰϬϭϵ͘ϳϯϬϰϭ͛ϭ͕ϵϵϬ͛ ϭϯͲϯͬϴ͟ϳϮEͲϴϬdϭϮ͘ϯϰϳϰϭ͛ϲ͕ϵϱϬ͛ ϵͲϱͬϴ͟ϰϬEͲϴϬϴ͘ϴϯϱϳ͕ϯϬϬ͛ϭϮ͕ϬϯϮ͛ >KE'^dZ/E'dh/E'd/> ϳ͟Ϯϲ:Ͳϱϱ^dͬ>ϲ͘ϮϰϬϲϭ͛ϯ͕ϮϬϬ͛ ϰͲϭͬϮ͟ϭϮ͘ϳϱEͲϴϬhϴƌĚϯ͘ϵϱϴϯ͕ϮϬϬ͛ϱ͕ϳϲϬ͛ ^,KZd^dZ/E'dh/E'd/> ϮͲϯͬϴ͟ϰ͘ϳ:Ͳϱϱ^,ǇĚƌŝůϭ͘ϵϵϬϲϳ͛ϯ͕ϮϬϲ͛ :t>Zzd/> EŽĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ/K /ƚĞŵ ^,KZd^dZ/E';t^d/^WK^>Ϳ Ϯϵϵ͛ϮϵϵΖϭ͘ϴϳϬ,ĂůůŝďƵƌƚŽŶyyK>ĂŶĚŝŶŐEŝƉƉůĞ ϯ͕ϭϵϴ͛ϯ͕ϭϵϴΖϭ͘ϴϭϬ,ĂůůŝďƵƌƚŽŶyEEŝƉƉůĞ ϯ͕ϮϬϬ͛ϯ͕ϮϬϬΖϭ͘ϵϵϬDƵůĞƐŚŽĞ'ƵŝĚĞĂŶĚ^ĞĂůƐƐĞŵďůǇ >KE'^dZ/E';WZKhZͿ ϲϬ͘ϲ͛ϲϬΖϳ͘ϬϬϬ&DdƵďŝŶŐ,ĂŶŐĞƌϮ͛dǆ^dͬ>yK ϭϰϯϱ͛ϰϯϱΖϱ͘ϵϬϬ,ĂůůŝďƵƌƚŽŶ͞WͲϮ͟dZ^^s Ϯϯ͕ϭϳϱ͛ϯ͕ϭϳϱΖϲ͘ϰϰϬ,ĂůůŝďƵƌƚŽŶdǁŝŶ&ůŽ^ĞĂůƐƐĞŵďůǇ ϯ͕ϮϬϬ͛ϯ͕ϮϬϬΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶdǁŝŶ&ůŽǁWĂĐŬĞƌ ϯ ϯ͕ϰϵϲ͛ϯ͕ϰϵϲΖϲ͘ϮϮϬ͞D^E͟^ĞĂůƐΘ^ĞĂůǆƚĞŶƐŝŽŶ ϯ͕ϱϬϬ͛ϯ͕ϱϬϬΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶDtWĞƌŵWĂĐŬĞƌΘdďŐĚĂƉƚĞƌ ϯ͕ϱϬϰ͛ϯ͕ϱϬϰΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶ^ĞĂůŽƌĞǆƚĞŶƐŝŽŶΘdďŐĚĂƉƚĞƌ ϯ͕ϱϬϳ͛ϯ͕ϱϬϳΖϲ͘ϮϱϲDƵůĞƐŚŽĞ'ƵŝĚĞ ϰϯ͕ϳϱϬ͛ϯ͕ϳϱϬΖϯ͘ϵϱϴ,ĂůůŝďƵƌƚŽŶ^ĞĂůEŽ'ŽhŶŝƚ ϯ͕ϳϱϬ͛ϯ͕ϳϱϬΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶDtWĞƌŵWĂĐŬĞƌΘdďŐĚĂƉƚĞƌ ϱϰ͕ϬϬϯ͛ϰ͕ϬϬϯΖϯ͘ϴϭϯ,ĂůůŝďƵƌƚŽŶy^ůŝĚŝŶŐ^ůĞĞǀĞͲKƉĞŶ ϲϰ͕Ϭϲϴ͛ϰ͕ϬϲϴΖϯ͘ϵϱϴ,ĂůůŝďƵƌƚŽŶ^ĞĂůEŽ'ŽhŶŝƚ ϰ͕Ϭϲϵ͛ϰ͕ϬϲϵΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶDtWĞƌŵWĂĐŬĞƌΘdďŐĚĂƉƚĞƌ ϳϰ͕ϭϯϮ͛ϰ͕ϭϯϮΖϯ͘ϴϭϯ,ĂůůŝďƵƌƚŽŶy^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ ϴϰ͕ϭϳϰ͛ϰ͕ϭϳϰΖϯ͘ϵϱϴ,ĂůůŝďƵƌƚŽŶ^ĞĂůEŽ'ŽhŶŝƚ ϰ͕ϭϳϱ͛ϰ͕ϭϳϱΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶDtWĞƌŵWĂĐŬĞƌΘdďŐĚĂƉƚĞƌ ϵϰ͕Ϯϱϰ͛ϰ͕ϮϱϰΖϯ͘ϵϱϴ,ĂůůŝďƵƌƚŽŶ^ĞĂůEŽ'ŽhŶŝƚ ϰ͕Ϯϱϱ͛ϰ͕ϮϱϱΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶDtWĞƌŵWĂĐŬĞƌΘdďŐĚĂƉƚĞƌ ϭϬϰ͕ϯϱϵ͛ϰ͕ϯϱϵΖϯ͘ϴϭϯ,ĂůůŝďƵƌƚŽŶy^ůŝĚŝŶŐ^ůĞĞǀĞͲKƉĞŶ ϭϭϰ͕ϰϱϮ͛ϰ͕ϰϱϮΖϯ͘ϵϱϴ,ĂůůŝďƵƌƚŽŶ^ĞĂůEŽ'ŽhŶŝƚ ϰ͕ϰϱϯ͛ϰ͕ϰϱϯΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶDtWĞƌŵWĂĐŬĞƌΘdďŐĚĂƉƚĞƌ ϭϮϰ͕ϱϲϵ͛ϰ͕ϱϲϵΖϯ͘ϵϱϴ,ĂůůŝďƵƌƚŽŶ^ĞĂůEŽ'ŽhŶŝƚ ϰ͕ϱϲϵ͛ϰ͕ϱϲϵΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶDtWĞƌŵWĂĐŬĞƌΘdďŐĚĂƉƚĞƌ ϭϯϱ͕ϭϳϱ͛ϱ͕ϭϳϱΖϯ͘ϴϭϯ,ĂůůŝďƵƌƚŽŶy^ůŝĚŝŶŐ^ůĞĞǀĞͲKƉĞŶ ϭϰϱ͕ϮϱϬ͛ϱ͕ϮϱϬΖϯ͘ϵϱϴ,ĂůůŝďƵƌƚŽŶ^ĞĂůEŽ'ŽhŶŝƚ ϱ͕ϮϱϬ͛ϱ͕ϮϱϬΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶDtWĞƌŵWĂĐŬĞƌΘdďŐĚĂƉƚĞƌ ϭϱϱ͕ϯϴϯ͛ϱ͕ϯϴϯΖϯ͘ϴϭϯ,ĂůůŝďƵƌƚŽŶy^ůŝĚŝŶŐ^ůĞĞǀĞͲKƉĞŶ ϭϲϱ͕ϰϰϲ͛ϱ͕ϰϰϲΖϯ͘ϵϱϴ,ĂůůŝďƵƌƚŽŶ^ĞĂůEŽ'ŽhŶŝƚʹ>ĞŶŐƚŚϳ͘ϮϵK ϱ͕ϰϰϴ͛ϱ͕ϰϰϴΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶDtWĞƌŵWĂĐŬĞƌΘdďŐĚĂƉƚĞƌ ϭϳϱ͕ϲϯϰ͛ϱ͕ϲϯϰΖϯ͘ϴϭϯ,ĂůůŝďƵƌƚŽŶy^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ ϭϴϱ͕ϳϱϳ͛ϱ͕ϳϱϳΖϯ͘ϳϮϱ,ĂůůŝďƵƌƚŽŶyEEŝƉƉůĞ ϭϵϱ͕ϳϱϵ͛ϱ͕ϳϱϵΖϯ͘ϵϴϱtŝƌĞůŝŶĞ'ƵŝĚĞ KƚŚĞƌ/Ŷ,ŽůĞ;tŝƌĞůŝŶĞƌĞƚƌŝĞǀĂďůĞƉůƵŐƐ͕ǀĂůǀĞƐ͕ƉƵŵƉƐ͕ĨŝƐŚ͕ĞƚĐͿ ĞƉƚŚ;DͿĞƉƚŚ;dsͿĞƐĐƌŝƉƚŝŽŶ ϯ͕Ϭϲϰ͛ϯ͕Ϭϲϰ͛ ϮͬϭϲͬϭϴͲϰϯ>ůĂƐƐ'ĐĞŵĞŶƚƉƵŵƉĞĚʹƚĂŐŐĞĚΛϯ͕Ϭϲϰ͛ʹ^ƵƐƉĞĐƚ ƚƵďŝŶŐŝŶƚĞŐƌŝƚǇůŽƐƐ ϱ͕ϵϯϱΖϱ͕ϵϯϱΖ^WůƵŐ^ĞƚǁͬϭϵϵϳtŽƌŬŽǀĞƌ ϱ͕ϵϴϲΖϱ͕ϵϴϲΖϮͲϳͬϴΗdƵďŝŶŐ ϲ͕ϴϯϯΖϲ͕ϴϯϯΖĞŵĞŶƚZĞƚĂŝŶĞƌ ϭϭ͕ϵϲϱΖϭϭ͕ϲϭϲΖĞŵĞŶƚZĞƚĂŝŶĞƌͲWd BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ͗:>>ϬϯͬϬϲͬϭϴ ^,Dd/ EŽƌƚŚŽŽŬ/ŶůĞƚ tĞůů͗E/ͲϭϮ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϭͬϭϭͬϭϵϵϳ Wd͗ϭϲϵͲϬϵϵ W/͗ϱϬͲϴϴϯͲϮϬϬϯϮͲϬϬͲϬϬ WZ&KZd/KEd/> ŽŶĞdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿ&dĂƚĞ^ƚĂƚƵƐ ^dZ>/E'ϯ͕ϮϲϬΖϯ͕ϯϳϬΖϯ͕ϮϲϬΖϯ͕ϯϳϬΖϭϭϬΖϬϮͬϭϲͬϭϴ^ǌƋ͛Ě /Ͳ^dZzϯ͕ϱϱϴΖϯ͕ϱϲϴΖϯ͕ϱϱϴΖϯ͕ϱϲϴΖϭϬΖϲͬϭϬͬϭϵϳϱ^ǌƋΖĚ /Ͳ^dZzϯ͕ϱϳϳΖϯ͕ϱϴϳΖϯ͕ϱϳϳΖϯ͕ϱϴϳΖϭϬΖϲͬϭϬͬϭϵϳϱ^ǌƋΖĚ /Ͳϯ͕ϲϬϰΖϯ͕ϲϮϴΖϯ͕ϲϬϰΖϯ͕ϲϮϴΖϮϰΖϲͬϭϬͬϭϵϳϱ^ǌƋΖĚ /Ͳϭ͘Ϭϯ͕ϴϮϬΖϯ͕ϴϴϬΖϯ͕ϴϮϬΖϯ͕ϴϴϬΖϲϬΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ /ͲϮ͘Ϭϯ͕ϴϲϲΖϰ͕ϰϰϬΖϯ͕ϴϲϲΖϰ͕ϰϰϬΖϱϳϰΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ /ͲϮ͘Ϭϯ͕ϴϵϲΖϯ͕ϵϲϬΖϯ͕ϴϵϲΖϯ͕ϵϲϬΖϲϰΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ /Ͳϯ͘Ϭϯ͕ϵϴϮΖϯ͕ϵϵϰΖϯ͕ϵϴϮΖϯ͕ϵϵϰΖϭϮΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ /Ͳϰ͘Ϭϰ͕ϬϭϰΖϰ͕ϬϰϴΖϰ͕ϬϭϰΖϰ͕ϬϰϴΖϯϰΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ /Ͳϱ͘Ϭϰ͕ϬϵϬΖϰ͕ϬϵϴΖϰ͕ϬϵϬΖϰ͕ϬϵϴΖϴΖϲͬϭϬͬϭϵϳϱ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ /Ͳϱ͘Ϭϰ͕ϭϬϲΖϰ͕ϭϭϭΖϰ͕ϭϬϲΖϰ͕ϭϭϭΖϱΖϲͬϭϬͬϭϵϳϱ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ /Ͳϱ͘ϭϰ͕ϭϭϲΖϰ͕ϭϮϰΖϰ͕ϭϭϲΖϰ͕ϭϮϰΖϴΖϲͬϭϬͬϭϵϳϱ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ /Ͳϲ͘Ϭϰ͕ϭϰϭΖϰ͕ϭϲϲΖϰ͕ϭϰϭΖϰ͕ϭϲϲΖϮϱΖϲͬϭϬͬϭϵϳϱ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ /Ͳϳ͘Ϭͬ/Ͳϳ͘ϭϰ͕ϭϴϴΖϰ͕ϮϯϴΖϰ͕ϭϴϴΖϰ͕ϮϯϴΖϱϬΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ /Ͳϴ͘Ϭϰ͕ϮϳϮΖϰ͕ϮϴϮΖϰ͕ϮϳϮΖϰ͕ϮϴϮΖϭϬΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ /Ͳϴ͘Ϯϰ͕ϮϵϴΖϰ͕ϯϭϲΖϰ͕ϮϵϴΖϰ͕ϯϭϲΖϭϴΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ /ͲϭϬ͘Ϭϰ͕ϯϳϴΖϰ͕ϯϵϬΖϰ͕ϯϳϴΖϰ͕ϯϵϬΖϭϮΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ /Ͳϭϭ͘Ϭϰ͕ϰϭϱΖϰ͕ϰϰϬΖϰ͕ϰϭϱΖϰ͕ϰϰϬΖϮϱΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ Ͳϯϰ͕ϰϳϱΖϰ͕ϰϴϮΖϰ͕ϰϳϱΖϰ͕ϰϴϮΖϳΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ Ͳϳϰ͕ϲϲϬΖϰ͕ϲϲϴΖϰ͕ϲϲϬΖϰ͕ϲϲϴΖϴΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ Ͳϯϰ͕ϵϳϯΖϰ͕ϵϳϴΖϰ͕ϵϳϯΖϰ͕ϵϳϴΖϱΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ Ͳϰϰ͕ϵϵϬΖϰ͕ϵϵϱΖϰ͕ϵϵϬΖϰ͕ϵϵϱΖϱΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ ͲϱͬͲϲϱ͕ϬϭϬΖϱ͕ϬϮϱΖϱ͕ϬϭϬΖϱ͕ϬϮϱΖϭϱΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ Ͳϴϱ͕ϬϱϬΖϱ͕ϬϱϳΖϱ͕ϬϱϬΖϱ͕ϬϱϳΖϳΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ Ͳϵϱ͕ϬϲϰΖϱ͕ϬϳϬΖϱ͕ϬϲϰΖϱ͕ϬϳϬΖϲΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ &Ͳϰϱ͕ϭϮϬΖϱ͕ϭϯϱΖϱ͕ϭϮϬΖϱ͕ϭϯϱΖϭϱΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ &Ͳϱϱ͕ϭϱϬΖϱ͕ϭϱϳΖϱ͕ϭϱϬΖϱ͕ϭϱϳΖϳΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ 'Ͳϭϱ͕ϭϵϰΖϱ͕ϮϬϰΖϱ͕ϭϵϰΖϱ͕ϮϬϰΖϭϬΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ ,Ͳϭͬ,Ͳϭ͘Ϯϱ͕ϮϵϮΖϱ͕ϯϬϱΖϱ͕ϮϵϮΖϱ͕ϯϬϱΖϭϯΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ ,Ͳϲϱ͕ϯϱϰΖϱ͕ϯϳϮΖϱ͕ϯϱϰΖϱ͕ϯϳϮΖϭϴΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ ,Ͳϴϱ͕ϯϵϰΖϱ͕ϰϭϰΖϱ͕ϯϵϰΖϱ͕ϰϭϰΖϮϬΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ ,Ͳϵϱ͕ϰϯϭΖϱ͕ϰϯϲΖϱ͕ϰϯϭΖϱ͕ϰϯϲΖϱΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ /Ͳϯϱ͕ϰϲϲΖϱ͕ϰϴϬΖϱ͕ϰϲϲΖϱ͕ϰϴϬΖϭϰΖϰͬϭͬϭϵϵϯ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ /Ͳϰϱ͕ϰϴϮΖϱ͕ϰϵϬΖϱ͕ϰϴϮΖϱ͕ϰϵϬΖϴΖϰͬϭͬϭϵϵϯ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ /Ͳϳϱ͕ϱϭϰΖϱ͕ϱϮϭΖϱ͕ϱϭϰΖϱ͕ϱϮϭΖϳΖϰͬϭͬϭϵϵϯ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ /Ͳϴϱ͕ϱϯϮΖϱ͕ϱϰϬΖϱ͕ϱϯϮΖϱ͕ϱϰϬΖϴΖϰͬϭͬϭϵϵϯ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ :ͲϮϱ͕ϱϲϰΖϱ͕ϱϳϰΖϱ͕ϱϲϰΖϱ͕ϱϳϰΖϭϬΖϰͬϭͬϭϵϵϯ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ :ͲϮ͘ϭϱ͕ϱϳϲΖϱ͕ϱϴϰΖϱ͕ϱϳϲΖϱ͕ϱϴϰΖϴΖϰͬϭͬϭϵϵϯ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ :Ͳϯϱ͕ϱϵϮΖϱ͕ϱϵϲΖϱ͕ϱϵϮΖϱ͕ϱϵϲΖϰΖϰͬϭͬϭϵϵϯ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ <Ͳϰ͘ϭϱ͕ϲϲϴΖϱ͕ϲϳϰΖϱ͕ϲϲϴΖϱ͕ϲϳϰΖϲΖϰͬϭͬϭϵϵϯ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ DͲϰϱ͕ϳϱϳΖϱ͕ϳϲϰΖϱ͕ϳϱϳΖϱ͕ϳϲϰΖϳΖϰͬϭͬϭϵϵϯ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ WͲϮϲ͕ϬϴϴΖϲ͕ϬϵϲΖϲ͕ϬϴϴΖϲ͕ϬϵϲΖϴΖϰͬϭͬϭϵϵϯ/ƐŽůĂƚĞĚ WͲϱϲ͕ϭϯϬΖϲ͕ϭϱϬΖϲ͕ϭϯϬΖϲ͕ϭϱϬΖϮϬΖϰͬϭͬϭϵϵϯ/ƐŽůĂƚĞĚ YͲϮϲ͕ϭϴϬΖϲ͕ϭϴϲΖϲ͕ϭϴϬΖϲ͕ϭϴϲΖϲΖϰͬϭͬϭϵϵϯ/ƐŽůĂƚĞĚ ZͲϲϲ͕ϯϯϬΖϲ͕ϯϯϴΖϲ͕ϯϯϬΖϲ͕ϯϯϴΖϴΖϰͬϭͬϭϵϵϯ/ƐŽůĂƚĞĚ ^Ͳϲϲ͕ϰϰϭΖϲ͕ϰϰϴΖϲ͕ϰϰϭΖϲ͕ϰϰϴΖϳΖϰͬϭͬϭϵϵϯ/ƐŽůĂƚĞĚ dͲϮϲ͕ϱϰϬΖϲ͕ϱϰϳΖϲ͕ϱϰϬΖϲ͕ϱϰϳΖϳΖϰͬϭͬϭϵϵϯ/ƐŽůĂƚĞĚ dͲϲϲ͕ϲϰϭΖϲ͕ϲϰϲΖϲ͕ϲϰϭΖϲ͕ϲϰϲΖϱΖϰͬϭͬϭϵϵϯ/ƐŽůĂƚĞĚ hͲϱϲ͕ϳϭϴΖϲ͕ϳϮϲΖϲ͕ϳϭϴΖϲ͕ϳϮϲΖϴΖϰͬϭͬϭϵϵϯ/ƐŽůĂƚĞĚ hͲϳϲ͕ϳϰϴΖϲ͕ϳϱϴΖϲ͕ϳϰϴΖϲ͕ϳϱϴΖϭϬΖϰͬϭͬϭϵϵϯ/ƐŽůĂƚĞĚ sͲϭϲ͕ϳϵϬΖϲ͕ϴϬϬΖϲ͕ϳϵϬΖϲ͕ϴϬϬΖϭϬΖϰͬϭͬϭϵϵϯ/ƐŽůĂƚĞĚ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ͗,ϯͬϴͬϮϮ WZKWK^ EŽƌƚŚŽŽŬ/ŶůĞƚ tĞůů͗E/ͲϭϮ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϭͬϭϭͬϭϵϵϳ Wd͗ϭϲϵͲϬϵϵ W/͗ϱϬͲϴϴϯͲϮϬϬϯϮͲϬϬͲϬϬ ^/E'd/> ^ŝǌĞtƚ'ƌĂĚĞŽŶŶ/dŽƉƚŵ ϯϬ͟ϭϯϯ,ͲϰϬtĞůĚĞĚϮϴ͘ϬϬϬϰϭ͛ϯϴϭ͛ ϮϬ͟ϭϯϯ,ͲϰϬϭϵ͘ϳϯϬϰϭ͛ϭ͕ϵϵϬ͛ ϭϯͲϯͬϴ͟ϳϮEͲϴϬdϭϮ͘ϯϰϳϰϭ͛ϲ͕ϵϱϬ͛ ϵͲϱͬϴ͟ϰϬEͲϴϬϴ͘ϴϯϱϳ͕ϯϬϬ͛ϭϮ͕ϬϯϮ͛ >KE'^dZ/E'dh/E'd/> ϳ͟Ϯϲ:Ͳϱϱ^dͬ>ϲ͘ϮϰϬϲϭ͛ϯ͕ϮϬϬ͛ ϰͲϭͬϮ͟ϭϮ͘ϳϱEͲϴϬhϴƌĚϯ͘ϵϱϴϯ͕ϮϬϬ͛ϱ͕ϳϲϬ͛ ^,KZd^dZ/E'dh/E'd/> ϮͲϯͬϴ͟ϰ͘ϳ:Ͳϱϱ^,ǇĚƌŝůϭ͘ϵϵϬϲϳ͛ϯ͕ϮϬϲ͛ :t>Zzd/> EŽĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ/K /ƚĞŵ ^,KZd^dZ/E';t^d/^WK^>Ϳ ϯ͕ϭϵϴ͛ϯ͕ϭϵϴΖϭ͘ϴϭϬ,ĂůůŝďƵƌƚŽŶyEEŝƉƉůĞ ϯ͕ϮϬϬ͛ϯ͕ϮϬϬΖϭ͘ϵϵϬDƵůĞƐŚŽĞ'ƵŝĚĞĂŶĚ^ĞĂůƐƐĞŵďůǇ >KE'^dZ/E';WZKhZͿ ϭцϯ͕Ϭϰϱцϯ͕Ϭϰϱ/W Ϯϯ͕ϭϳϱ͛ϯ͕ϭϳϱΖϲ͘ϰϰϬ,ĂůůŝďƵƌƚŽŶdǁŝŶ&ůŽ^ĞĂůƐƐĞŵďůǇ ϯ͕ϮϬϬ͛ϯ͕ϮϬϬΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶdǁŝŶ&ůŽǁWĂĐŬĞƌ ϯ ϯ͕ϰϵϲ͛ϯ͕ϰϵϲΖϲ͘ϮϮϬ͞D^E͟^ĞĂůƐΘ^ĞĂůǆƚĞŶƐŝŽŶ ϯ͕ϱϬϬ͛ϯ͕ϱϬϬΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶDtWĞƌŵWĂĐŬĞƌΘdďŐĚĂƉƚĞƌ ϯ͕ϱϬϰ͛ϯ͕ϱϬϰΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶ^ĞĂůŽƌĞǆƚĞŶƐŝŽŶΘdďŐĚĂƉƚĞƌ ϯ͕ϱϬϳ͛ϯ͕ϱϬϳΖϲ͘ϮϱϲDƵůĞƐŚŽĞ'ƵŝĚĞ ϰϯ͕ϳϱϬ͛ϯ͕ϳϱϬΖϯ͘ϵϱϴ,ĂůůŝďƵƌƚŽŶ^ĞĂůEŽ'ŽhŶŝƚ ϯ͕ϳϱϬ͛ϯ͕ϳϱϬΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶDtWĞƌŵWĂĐŬĞƌΘdďŐĚĂƉƚĞƌ ϱϰ͕ϬϬϯ͛ϰ͕ϬϬϯΖϯ͘ϴϭϯ,ĂůůŝďƵƌƚŽŶy^ůŝĚŝŶŐ^ůĞĞǀĞͲKƉĞŶ ϲϰ͕Ϭϲϴ͛ϰ͕ϬϲϴΖϯ͘ϵϱϴ,ĂůůŝďƵƌƚŽŶ^ĞĂůEŽ'ŽhŶŝƚ ϰ͕Ϭϲϵ͛ϰ͕ϬϲϵΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶDtWĞƌŵWĂĐŬĞƌΘdďŐĚĂƉƚĞƌ ϳϰ͕ϭϯϮ͛ϰ͕ϭϯϮΖϯ͘ϴϭϯ,ĂůůŝďƵƌƚŽŶy^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ ϴϰ͕ϭϳϰ͛ϰ͕ϭϳϰΖϯ͘ϵϱϴ,ĂůůŝďƵƌƚŽŶ^ĞĂůEŽ'ŽhŶŝƚ ϰ͕ϭϳϱ͛ϰ͕ϭϳϱΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶDtWĞƌŵWĂĐŬĞƌΘdďŐĚĂƉƚĞƌ ϵϰ͕Ϯϱϰ͛ϰ͕ϮϱϰΖϯ͘ϵϱϴ,ĂůůŝďƵƌƚŽŶ^ĞĂůEŽ'ŽhŶŝƚ ϰ͕Ϯϱϱ͛ϰ͕ϮϱϱΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶDtWĞƌŵWĂĐŬĞƌΘdďŐĚĂƉƚĞƌ ϭϬϰ͕ϯϱϵ͛ϰ͕ϯϱϵΖϯ͘ϴϭϯ,ĂůůŝďƵƌƚŽŶy^ůŝĚŝŶŐ^ůĞĞǀĞͲKƉĞŶ ϭϭϰ͕ϰϱϮ͛ϰ͕ϰϱϮΖϯ͘ϵϱϴ,ĂůůŝďƵƌƚŽŶ^ĞĂůEŽ'ŽhŶŝƚ ϰ͕ϰϱϯ͛ϰ͕ϰϱϯΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶDtWĞƌŵWĂĐŬĞƌΘdďŐĚĂƉƚĞƌ ϭϮϰ͕ϱϲϵ͛ϰ͕ϱϲϵΖϯ͘ϵϱϴ,ĂůůŝďƵƌƚŽŶ^ĞĂůEŽ'ŽhŶŝƚ ϰ͕ϱϲϵ͛ϰ͕ϱϲϵΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶDtWĞƌŵWĂĐŬĞƌΘdďŐĚĂƉƚĞƌ ϭϯϱ͕ϭϳϱ͛ϱ͕ϭϳϱΖϯ͘ϴϭϯ,ĂůůŝďƵƌƚŽŶy^ůŝĚŝŶŐ^ůĞĞǀĞͲKƉĞŶ ϭϰϱ͕ϮϱϬ͛ϱ͕ϮϱϬΖϯ͘ϵϱϴ,ĂůůŝďƵƌƚŽŶ^ĞĂůEŽ'ŽhŶŝƚ ϱ͕ϮϱϬ͛ϱ͕ϮϱϬΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶDtWĞƌŵWĂĐŬĞƌΘdďŐĚĂƉƚĞƌ ϭϱϱ͕ϯϴϯ͛ϱ͕ϯϴϯΖϯ͘ϴϭϯ,ĂůůŝďƵƌƚŽŶy^ůŝĚŝŶŐ^ůĞĞǀĞͲKƉĞŶ ϭϲϱ͕ϰϰϲ͛ϱ͕ϰϰϲΖϯ͘ϵϱϴ,ĂůůŝďƵƌƚŽŶ^ĞĂůEŽ'ŽhŶŝƚʹ>ĞŶŐƚŚϳ͘ϮϵK ϱ͕ϰϰϴ͛ϱ͕ϰϰϴΖϴ͘ϬϬϬ,ĂůůŝďƵƌƚŽŶDtWĞƌŵWĂĐŬĞƌΘdďŐĚĂƉƚĞƌ ϭϳϱ͕ϲϯϰ͛ϱ͕ϲϯϰΖϯ͘ϴϭϯ,ĂůůŝďƵƌƚŽŶy^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ ϭϴϱ͕ϳϱϳ͛ϱ͕ϳϱϳΖϯ͘ϳϮϱ,ĂůůŝďƵƌƚŽŶyEEŝƉƉůĞ ϭϵϱ͕ϳϱϵ͛ϱ͕ϳϱϵΖϯ͘ϵϴϱtŝƌĞůŝŶĞ'ƵŝĚĞ KƚŚĞƌ/Ŷ,ŽůĞ;tŝƌĞůŝŶĞƌĞƚƌŝĞǀĂďůĞƉůƵŐƐ͕ǀĂůǀĞƐ͕ƉƵŵƉƐ͕ĨŝƐŚ͕ĞƚĐͿ ĞƉƚŚ;DͿĞƉƚŚ;dsͿĞƐĐƌŝƉƚŝŽŶ ϯ͕Ϭϲϰ͛ϯ͕Ϭϲϰ͛ ϮͬϭϲͬϭϴͲϰϯ>ůĂƐƐ'ĐĞŵĞŶƚƉƵŵƉĞĚʹƚĂŐŐĞĚΛϯ͕Ϭϲϰ͛ʹ^ƵƐƉĞĐƚ ƚƵďŝŶŐŝŶƚĞŐƌŝƚǇůŽƐƐ ϱ͕ϵϯϱΖϱ͕ϵϯϱΖ^WůƵŐ^ĞƚǁͬϭϵϵϳtŽƌŬŽǀĞƌ ϱ͕ϵϴϲΖϱ͕ϵϴϲΖϮͲϳͬϴΗdƵďŝŶŐ ϲ͕ϴϯϯΖϲ͕ϴϯϯΖĞŵĞŶƚZĞƚĂŝŶĞƌ ϭϭ͕ϵϲϱΖϭϭ͕ϲϭϲΖĞŵĞŶƚZĞƚĂŝŶĞƌͲWd BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ͗:>>ϬϯͬϬϲͬϭϴ ^,Dd/ EŽƌƚŚŽŽŬ/ŶůĞƚ tĞůů͗E/ͲϭϮ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϭͬϭϭͬϭϵϵϳ Wd͗ϭϲϵͲϬϵϵ W/͗ϱϬͲϴϴϯͲϮϬϬϯϮͲϬϬͲϬϬ WZ&KZd/KEd/> ŽŶĞdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿ&dĂƚĞ^ƚĂƚƵƐ ^dZ>/E'ϯ͕ϮϲϬΖϯ͕ϯϳϬΖϯ͕ϮϲϬΖϯ͕ϯϳϬΖϭϭϬΖϬϮͬϭϲͬϭϴ^ǌƋ͛Ě /Ͳ^dZzϯ͕ϱϱϴΖϯ͕ϱϲϴΖϯ͕ϱϱϴΖϯ͕ϱϲϴΖϭϬΖϲͬϭϬͬϭϵϳϱ^ǌƋΖĚ /Ͳ^dZzϯ͕ϱϳϳΖϯ͕ϱϴϳΖϯ͕ϱϳϳΖϯ͕ϱϴϳΖϭϬΖϲͬϭϬͬϭϵϳϱ^ǌƋΖĚ 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ͲϱͬͲϲϱ͕ϬϭϬΖϱ͕ϬϮϱΖϱ͕ϬϭϬΖϱ͕ϬϮϱΖϭϱΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ Ͳϴϱ͕ϬϱϬΖϱ͕ϬϱϳΖϱ͕ϬϱϬΖϱ͕ϬϱϳΖϳΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ Ͳϵϱ͕ϬϲϰΖϱ͕ϬϳϬΖϱ͕ϬϲϰΖϱ͕ϬϳϬΖϲΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ &Ͳϰϱ͕ϭϮϬΖϱ͕ϭϯϱΖϱ͕ϭϮϬΖϱ͕ϭϯϱΖϭϱΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ &Ͳϱϱ͕ϭϱϬΖϱ͕ϭϱϳΖϱ͕ϭϱϬΖϱ͕ϭϱϳΖϳΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ 'Ͳϭϱ͕ϭϵϰΖϱ͕ϮϬϰΖϱ͕ϭϵϰΖϱ͕ϮϬϰΖϭϬΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ ,Ͳϭͬ,Ͳϭ͘Ϯϱ͕ϮϵϮΖϱ͕ϯϬϱΖϱ͕ϮϵϮΖϱ͕ϯϬϱΖϭϯΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ ,Ͳϲϱ͕ϯϱϰΖϱ͕ϯϳϮΖϱ͕ϯϱϰΖϱ͕ϯϳϮΖϭϴΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ ,Ͳϴϱ͕ϯϵϰΖϱ͕ϰϭϰΖϱ͕ϯϵϰΖϱ͕ϰϭϰΖϮϬΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ ,Ͳϵϱ͕ϰϯϭΖϱ͕ϰϯϲΖϱ͕ϰϯϭΖϱ͕ϰϯϲΖϱΖϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ /Ͳϯϱ͕ϰϲϲΖϱ͕ϰϴϬΖϱ͕ϰϲϲΖϱ͕ϰϴϬΖϭϰΖϰͬϭͬϭϵϵϯ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ /Ͳϰϱ͕ϰϴϮΖϱ͕ϰϵϬΖϱ͕ϰϴϮΖϱ͕ϰϵϬΖϴΖϰͬϭͬϭϵϵϯ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ /Ͳϳϱ͕ϱϭϰΖϱ͕ϱϮϭΖϱ͕ϱϭϰΖϱ͕ϱϮϭΖϳΖϰͬϭͬϭϵϵϯ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ /Ͳϴϱ͕ϱϯϮΖϱ͕ϱϰϬΖϱ͕ϱϯϮΖϱ͕ϱϰϬΖϴΖϰͬϭͬϭϵϵϯ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ :ͲϮϱ͕ϱϲϰΖϱ͕ϱϳϰΖϱ͕ϱϲϰΖϱ͕ϱϳϰΖϭϬΖϰͬϭͬϭϵϵϯ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ :ͲϮ͘ϭϱ͕ϱϳϲΖϱ͕ϱϴϰΖϱ͕ϱϳϲΖϱ͕ϱϴϰΖϴΖϰͬϭͬϭϵϵϯ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ :Ͳϯϱ͕ϱϵϮΖϱ͕ϱϵϲΖϱ͕ϱϵϮΖϱ͕ϱϵϲΖϰΖϰͬϭͬϭϵϵϯ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ <Ͳϰ͘ϭϱ͕ϲϲϴΖϱ͕ϲϳϰΖϱ͕ϲϲϴΖϱ͕ϲϳϰΖϲΖϰͬϭͬϭϵϵϯ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ DͲϰϱ͕ϳϱϳΖϱ͕ϳϲϰΖϱ͕ϳϱϳΖϱ͕ϳϲϰΖϳΖϰͬϭͬϭϵϵϯ^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ 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&KDQJHVWR$SSURYHG6XQGU\3URFHGXUHIRU:HOO1&,$37'6XQGU\;;;;;;$Q\PRGLILFDWLRQVWRDQDSSURYHGVXQGU\ZLOOEHGRFXPHQWHGDQGDSSURYHGEHORZ&KDQJHVWRDQDSSURYHGVXQGU\ZLOOEHFRPPXQLFDWHGWRWKH$2*&&E\WKHULJZRUNRYHU5:2³ILUVWFDOO´HQJLQHHU$2*&&ZULWWHQDSSURYDORIWKHFKDQJHLVUHTXLUHGEHIRUHLPSOHPHQWLQJWKHFKDQJH6HF3DJH'DWH3URFHGXUH&KDQJH1HZ5HTXLUHG"<1+$.3UHSDUHG%\,QLWLDOV+$.$SSURYHG%\,QLWLDOV$2*&&:ULWWHQ$SSURYDO5HFHLYHG3HUVRQDQG'DWH$SSURYDO $VVHW7HDP2SHUDWLRQV0DQDJHU 'DWH 3UHSDUHG )LUVW&DOO2SHUDWLRQV(QJLQHHU 'DWH • ' STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS MAR 1 2 2018 1.Operations Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing❑ ,:.. down 0 . g Performed: Suspend ❑ Perforate 0 Other Stimulate 0 Alter Casing❑ Ca •-A.• • d o ram 0 Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Cement 2-3/8"WDSP Tbq CI 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 169-099 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service 0 6.API Number: Anchorage,AK 99503 50-833-20032-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0017589 N Cook Inlet Unit A-12 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A North Cook Inlet/Tertiary Gas Pool 11.Present Well Condition Summary: Total Depth measured 14,910 feet Plugs measured 3,064&5935 feet true vertical 14,214 feet Junk measured 5,986 feet Effective Depth measured 3,064 feet Packer measured See Schematic feet true vertical 3,064 feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural Conductor 381' 30" 381' 381' Surface 1,990' 20" 1,990' 1,990' Intermediate Production 6,950' 13-3/8" 6,950' 6,950' 5,380 psi 2,670 psi Production 4,732' 9-5/8" 12,032' 11,675' 5,750 psi 3,090 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 2-3/8" 4.7/J-55 3,206'(MD) 3,206'(TVD) Tubing(size,grade,measured and true vertical depth) 7" 26/J-55 3,200'(MD) 3,200'(TVD) 4-1/2" 12.75/N-80 5,760'(MD) 5,760'(TVD) Packers and SSSV(type,measured and true vertical depth) See Schematic 12.Stimulation or cement squeeze summary: Intervals treated(measured): 3,260-3,370 Treatment descriptions including volumes used and final pressure: ( C Pumped 43 BBL Class G cement down 2-3/8"tubing with final squeeze pressure at 1,000 psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 79 2 Subsequent to operation: 0 0 0 80 10 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas 2 WDSPL❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ 3USP0 SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 318-016 Authorized Name: Stan W.Golis Contact Name: Michael Quick Authorized Title: Operations Manager Contact Email: mauick@hilcorp.com Authorized Signature: 5 Date: 3117—Re Contact Phone: (907)777-8440 ,S I,' 1,- 3-- `i—fd Form 10-404 Revised 4/2017 RBD MS LL I'd;A,`; 1 7, :319 Submit Original Only •H . Well: NCI North Cook A-12 Inlet SCHEMATIC LastPTD:Com169 ple 09ted9 : 11/11/1997 Hilcorp Alaska,LLC API: 50-883-20032-00 RKB:MSL=XX' CASING DETAIL I I Size Wt Grade Conn ID Top Btm 30"/ 1 I $y A \ _,30" 133 H-40 Welded 28.000 41' 381' 20 ; tgi 20" 133 H-40 19.730 41' 1,990 B 13-3/8" 72 N-80 BTC 12.347 41' 6,950' r,�, gi 9-5/8" 40 N-80 8.835 7,300' 12,032' Tag Cement -+ *, ., `'`'` TUBING DETAIL �u3,064' ' '- a ""' e2-3/8" 4.7 J-55 EUE 8rd 1.990 67 3,206' •�'a4 i.+4r Sa l n9 x tubing 3, 7" 26 J-55 EUE 8rd 6.240 61' 3,200' Suspect integrity loss'' 4-1/2" 12.75 N-80 EUE 8rd 3.958 3,200' 5,760 CI -sty a-n .5 4" Tag Fill @ ST JEWELRY DETAIL 3,857' _ _a-zo -aao No Depth Depth ID OD 1 a 0-40 (MD) (TVD) 6 a-5o SHORT STRING(WASTE DISPOSAL) Item =a51 A 299' 299' 1.870 Halliburton XXO Landing Nipple 7 irri a50g 3,198' 3,198' 1.810 Halliburton XN Nipple 8 C 3,200' 3,200' 1.990 Muleshoe Guide and Seal Assembly i 61 -0-70 LONG STRING(PRODUCER) =a-7.1 60.6' 60' 7.000 FMC Tubing Hanger 1 435' 435' 5.900 Halliburton"CP-2"TRSSV 93,175' 3,175' 6.440 Halliburton Twin Flo Seal Assembly 9 -8-a�.z ao 2 3,200' 3,200' 8.000 Halliburton Twin Flow Packer -a-1o.o 3,496' 3,496' 6.220 "MSN"Seals&Seal Extension 10 0 0 I a-11.3 11y 3 3,500' 3,500' 8.000 Halliburton MWD Perm Packer&Tbg Adapter 3,504' 3,504' 8.000 Halliburton Seal Bore Extension&Tbg Adapter i; =A-3 3,507' 3,507' 6.526 Muleshoe Guide ,� " ' 3,750' 3,750' 3.958 Halliburton Seal NoGo Unit 12'f 4 3,750' 3,750' 8.000 Halliburton MWD Perm Packer&Tbg Adapter ); &7, -5 5 4,003' 4,003' 3.813 Halliburton XD Sliding Sleeve-Open ' =ES,E-8 4,068' 4,068' 3.958 Halliburton Seal NoGo Unit 13 1❑i Ems,F-4 6 4,069' 4,069' 8.000 Halliburton Perm MWD PPacker&Tb Adapter F5,G1g p 14? 7 4,132' 4,132' 3.813 Halliburton XD Sliding Sleeve-Closed !a8 4,174' 4,174' 3.958 Halliburton Seal NoGo Unit i+1.1&1.z 4,175' 4,175' 8.000 Halliburton MWD Perm Packer&Tbg Adapter 15 M Y �IiQ Ha,Ka 4,254' 4,254' 3.958 Halliburton Seal NoGo Unit 16?;r t 9 4,255' 4,255' 8.000 Halliburton MWD Perm Packer&Tbg Adapter 17 10 4,359' 4,359' 3.813 Halliburton XD Sliding Sleeve-Open i4,452' 4,452' 3.958 Halliburton Seal NoGo Unit 18 13 I-4,1-7, 11 _i3 b2 4,453' 4,453' 8.000 Halliburton MWD Perm Packer&Tbg Adapter ' 19 ``--=,-' -K-4.i,3 4,569' 4,569' 3.958 Halliburton Seal NoGo Unit �, -K�4.1,M-4 12 EZSZ Plug '. 4,569' 4,569' 8.000 Halliburton MWD Perm Packer&Tbg Adapter @5,935 13 5,175' 5,175' 3.813 Halliburton XD Sliding Sleeve-Open it PP-2,P5' Q-2,RS, 5,250' 5,250' 3.958 Halliburton Seal NoGo Unit S8,T2 14 5,250' 5,250' 8.000 Halliburton MWD Perm Packer&Tbg Adapter rF T5' 15 5,383' 5,383' 3.813 Halliburton XD SlidingSleeve-Oen u�,v 1 P 13-3/8"Ay" * _ 16 5,446' 5,446' 3.958 Halliburton Seal NoGo Unit-Length 7.29 OA 5,448' 5,448' 8.000 Halliburton MWD Perm Packer&Tbg Adapter .:-..4,,;,�* 17 5,634' 5,634' 3.813 Halliburton XD Sliding Sleeve-Closed 18 5,757' 5,757' 3.725 Halliburton XN Nipple fi 19 5,759' 5,759' 3.985 Wireline Guide '*Z'". s - Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc) Depth(MD) Depth(ND) Description 9-5/8" ,.,**:.! 2/16/18-43 BBL Class G cement pumped-tagged @ 3,064'-Suspect 3,064' 3,064' tubing integrity loss 5,935' 5,935' EZSZ Plug Set w/1997 Workover PBTD:3,064' TD:14,910' 5,986' 5,986' 2-7/8"Tubing 6,833' 6,833' Cement Retainer 11,965' 11,616' Cement Retainer-PBTD Updated By:.ILL 03/06/18 • North ok • Well: NCICoA-12 Inlet II SCHEMATIC Completed: omelet d: 11/11/1997 PTD: Hileorp Alaska,LLC API: 50-883-20032-00 PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status STERLING 3,260' 3,370' 3,260' 3,370' 110' 02/16/18 Szq'd CI-STRAY 3,558' 3,568' 3,558' 3,568' 10' 6/10/1975 Szq'd CI-STRAY 3,577' 3,587' 3,577' 3,587' 10' 6/10/1975 Szq'd CI-A 3,604' 3,628' 3,604' 3,628' 24' 6/10/1975 Szq'd CI-1.0 3,820' 3,880' 3,820' 3,880' 60' 02/16/18 Isolated CI-2.0 3,866' 4,440' 3,866' 4,440' 574' 02/16/18 Isolated CI-2.0 3,896' 3,960' 3,896' 3,960' 64' 02/16/18 Isolated CI-3.0 3,982' 3,994' 3,982' 3,994' 12' 02/16/18 Isolated CI-4.0 4,014' 4,048' 4,014' 4,048' 34' 02/16/18 Isolated CI-5.0 4,090' 4,098' 4,090' 4,098' 8' 6/10/1975 Sliding Sleeve-Closed CI-5.0 4,106' 4,111' 4,106' 4,111' 5' 6/10/1975 Sliding Sleeve-Closed CI-5.1 4,116' 4,124' 4,116' 4,124' 8' 6/10/1975 Sliding Sleeve-Closed CI-6.0 4,141' 4,166' 4,141' 4,166' 25' 6/10/1975 Sliding Sleeve-Closed CI-7,0/CI-7.1 4,188' 4,238' 4,188' 4,238' 50' 02/16/18 Isolated CI-8.0 4,272' 4,282' 4,272' 4,282' 10' 02/16/18 Isolated CI-8.2 4,298' 4,316' 4,298' 4,316' 18' 02/16/18 Isolated CI-10.0 4,378' 4,390' 4,378' 4,390' 12' 02/16/18 Isolated CI-11.0 4,415' 4,440' 4,415' 4,440' 25' 02/16/18 Isolated A-3 4,475' 4,482' 4,475' 4,482' 7' 02/16/18 Isolated B-7 4,660' 4,668' 4,660' 4,668' 8' 02/16/18 Isolated E-3 4,973' 4,978' 4,973' 4,978' 5' 02/16/18 Isolated E-4 4,990' 4,995' 4,990' 4,995' 5' 02/16/18 Isolated E-5/E-6 5,010' 5,025' 5,010' 5,025' 15' 02/16/18 Isolated E-8 5,050' 5,057' 5,050' 5,057' 7' 02/16/18 Isolated E-9 5,064' 5,070' 5,064' 5,070' 6' 02/16/18 Isolated F-4 5,120' 5,135' 5,120' 5,135' 15' 02/16/18 Isolated F-5 5,150' 5,157' 5,150' 5,157' 7' 02/16/18 Isolated G-1 5,194' 5,204' 5,194' 5,204' 10' 02/16/18 Isolated H-1/H-1.2 5,292' 5,305' 5,292' 5,305' 13' 02/16/18 Isolated H-6 5,354' 5,372' 5,354' 5,372' 18' 02/16/18 Isolated H-8 5,394' 5,414' 5,394' 5,414' 20' 02/16/18 Isolated H-9 5,431' 5,436' 5,431' 5,436' 5' 02/16/18 Isolated 1-3 5,466' 5,480' 5,466' 5,480' 14' 4/1/1993 Sliding Sleeve-Closed 1-4 5,482' 5,490' 5,482' 5,490' 8' 4/1/1993 Sliding Sleeve-Closed 1-7 5,514' 5,521' 5,514' 5,521' 7' 4/1/1993 Sliding Sleeve-Closed 1-8 5,532' 5,540' 5,532' 5,540' 8' 4/1/1993 Sliding Sleeve-Closed J-2 5,564' 5,574' 5,564' 5,574' 10' 4/1/1993 Sliding Sleeve-Closed J-2.1 5,576' 5,584' 5,576' 5,584' 8' 4/1/1993 Sliding Sleeve-Closed J-3 5,592' 5,596' 5,592' 5,596' 4' 4/1/1993 Sliding Sleeve-Closed K-4.1 5,668' 5,674' 5,668' 5,674' 6' 4/1/1993 Sliding Sleeve-Closed M-4 5,757' 5,764' 5,757' 5,764' 7' 4/1/1993 Sliding Sleeve-Closed P-2 6,088' 6,096' 6,088' 6,096' 8' 4/1/1993 Isolated P-5 6,130' 6,150' 6,130' 6,150' 20' 4/1/1993 Isolated Q-2 6,180' 6,186' 6,180' 6,186' 6' 4/1/1993 Isolated R-6 6,330' 6,338' 6,330' 6,338' 8' 4/1/1993 Isolated S-6 6,441' 6,448' 6,441' 6,448' 7' 4/1/1993 Isolated T-2 6,540' 6,547' 6,540' 6,547' 7' 4/1/1993 Isolated T-6 6,641' 6,646' 6,641' 6,646' 5' 4/1/1993 Isolated U-5 6,718' 6,726' 6,718' 6,726' 8' 4/1/1993 Isolated U-7 6,748' 6,758' 6,748' 6,758' 10' 4/1/1993 Isolated V-1 6,790' 6,800' 6,790' 6,800' 10' 4/1/1993 Isolated Updated By:JLL 03/06/18 • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date N Cook Inlet Unit A-12 Pumping Unit 50-833-20032-00-00 169-099 2/15/18 2/23/18 Daily Operations: 02/15/18-Thursday Transport crew to Tyonek platform for cement job on A-12 2-3/8 short string. Unload boat w/schlumberger cement equipment and rig up same. 02/16/18- Friday PJSM w/cement crew. Continue rig up schlumberger pumping unit and take on FIW. Test surface equip 250/2500 psi and mix 15.8 ppg cement, total 43 bbls. Start pumping 12:30, CIP @ 1400 hrs. Shut down W/2 .5 bbls in 2 3/8" string and squeeze 1 bbl away @ 1000 PSI and EST TOC @ 2700 '. WOC for 12 hrs. 02/17/18-Saturday PJSM. Hookup test pump and test down the 2 3/8" short string @ pumped down string @ 20 gals min w/FIW and test cement @500 PSI for 10 mins. All good with no loss. R/D test equip. 02/18/18-Sunday No operations. 02/19/18 - Monday No operations. 02/20/18-Tuesday No operations. 02/21/18-Wednesday TGSM -JSA- PERMIT. RIG UP W/L- PT LUB 2000 PSI -GOOD. RIH W/3" X 4' DD BAILER TO 3064'KB WT TO 3067'KB- POOH. OOH W/ FULL BAILER WET CEMENT. RIH W/SAME TO 3067'KB WT TO 3069'KB POOH. OOH W/ FULL BAILER WET CEMENT. RIH W/SAME TO 3069'KB WT TO 3070'KB- POOH. OOH W/ 1 CUP CEMENT W/ HARD PIECES AND FLUID. RIH W/2.5" X 5' DD BAILER TO 30701KB WT TO 3071'KB - POOH. OOH W/ EMPTY BAILER (BROKE FLAPPER BOTTOM). RIH W/SAME (W/ BALL BTM)TO 30701KB WT TO 3072'KB - POOH. OOH W/ 1/2 FULL WET CEMENT. RIH WI SAME TO 3070'KB WT TO 30711KB - POOH. OOH W/ 1/2 FULL WET CEMENT. RIH W/3" X 4' DD BAILER TO 30661KB WT TO 3068'KB - POOH. OOH W 2 CUPS BROKEN UP HARD CEMENT AND 4 CUPS WET SOFT CEMENT. RIH W/SAME TO 3069'KB WT TO 3073'KB- POOH. OOH W/SOFT CEMENT AND HARD PIECES. RIG DOWN W/L-SECURE WELL FOR NIGHT. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date N Cook Inlet Unit A-12 Pumping Unit 50-833-20032-00-00 169-099 2/15/18 2/23/18 Daily Operations: 02/22/18-Thursday ATTEND MORNING MEETING -JSA- PERMIT-TGSM. RIG UP W/L. RIH W/3" X 4' DD BAILER TO 30731KB WT TO 30751KB - POOH. OOH WI 2 CUPS SMALL HARD PIECES. RIH W/3.5" GAUGE RING W/ KJ ABOVE TO 3070'KB WT TO 30711KB- POOH. RIH W/2.5" X 5' DD BAILER TO 30751KB WT TO 3078'KB POOH. OOH W/2 CUPS HARD CEMENT. RIH W/3" X 4' DD BAILER TO 3076' KB WT TO 3077'KB - POOH. OOH W/ LIQUIDS- NO SOLIDS. RIH W/SAME TO 30771KB WT TO 3079'KB POOH. OOH WI 4 CUPS HARD CEMENT. RIH W/3.5" GAUGE RING TO 3077'KB WT TO 3079'KB- POOH. RIH WI 3" X 4' DD BAILER TO 30791KB WT TO 30811KB - POOH. OOH W/6 CUPS HARD PIECES. RIH W/3" X 5' PUMP BAILER TO 30801KB WT TO 30831KB POOH. OOH WI 1/2 FULL SOFT CEMENT. RIH W/SAME TO 3080'KB WT TO 3084'KB POOH. OOH W/ 1 CUP WET CEMENT AND FLUID. RIH W/2.5" X 8' PUMP BAILER TO 3083'KB WT TO 3085'KB POOH. OOH WI LIQUIDS. RIH WI 2.25" STAR BIT WI 1.5" X 5' STEM ABOVE TO 3085'KB WT, CAN NOT GAIN HOLE -STICKY. RIH WI 3" X 4' DD BAILER TO 30851KB-VERY STICKY-GAIN NO HOLE - POOH. OOH W/ FLUID. RIH W/3.6" STAR BIT TO 3081'KB WT TO 3083'KB - COULD NOT GAIN MORE HOLE - POOH. ADD 5' STEM ABOVE OJ. RIH W/ 1" X 1' PRONG ON 1.5" X 5' STEM TO 3083'KB WT TO 3084'KB POOH. OOH WI PRONG COVERED IN HARD CEMENT. RIH W/3" X 4' DD BAILER TO 3083'KB WT TO 3085'KB POOH. OOH WI 1/2 FULL HARD CEMENT. RIH WI 2.5" X 8' DD BAILER TO 3085'KB WT TO 3086'KB POOH. OOH W/ EMPTY BAILER. RIG DOWN W/L-SECURE WELL FOR NIGHT. 02/23/18- Friday ATTEND MORNING MEETING -TGSM -JSA- PERMIT. STANDBY FOR CRANE. RIG UP W/L. RIH WI 1" X 1' PRONG ON 1.5" X 5' STEM TO 3086'KB WT TO 3087'KB- POOH. RIH WI 3" X 4' DD BAILER TO 3085'KB WT TO 3086'KB POOH. OOH W/2 CUPS CEMENT. RIH W/ PRONG STYLE WIRE GRAB TO 3086'KB WT TO 3088'KB - POOH. OOH WI CEMENT ON GRAB. RIH W/3" X 4' DD BAILER TO 3086'KB WT TO 3088'KB POOH. OOH W/2 CUPS CEMENT. RIH WI SAME TO 3088'KB WT TO 3089'KB POOH. OOH W/4 CUPS CEMENT. RIH W/SAME TO 3088'KB WT TO 3090'KB POOH. OOH W/ 1 CUP CEMENT. RIH WI 3.7" CENTRALIZER W/ PRONG WIRE GRAB TO 3079'KB WT- POOH. RIH W/ PRONG STYLE WIRE GRAB TO 3088'KB WT TO 3090'KB - POOH. RIG DOWN W/L- MOVE EQUIPMENT-CLEAN AREA. STANDBY FOR FLIGHT TO OSK. • 4,0",\I!j//„ v THE STATE Alaska Oil and Gas �w --s• 9 .4' .1of T L ®AT ^S Conservation Commission = ”' A 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALASv Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations Manager Hilcorp Alaska, LLC SCANNED CEB 0 6 20 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: North Cook Inlet Field, Tertiary Gas and Undefined WDSP Pool,NCIU A-12 Permit to Drill Number: 169-099 Sundry Number: 318-016 Dear Mr. Golis: • 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, Hollis S. French Chair DATED this/6 day of January, 2018. RSDS - 1 21318 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 16 2018 APPLICATION FOR SUNDRY APPROVALS 075 1/,3ali e 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ • RCiICwn❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other:Cement 2-3/8"WDSP Tbg ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ J"Development Q 169-099 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic CI ]+.-Service ❑ 6.API Number: Anchorage,AK 99503 50-833-20032-00-00 , 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055' Will planned perforations require a spacing exception? Yes ❑ No El' N Cook Inlet Unit A-12 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017589 North Cook Inlet/Tertiary Gas Pool&Undefined WDSP Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 14,910 14,214 5,935 5,935 1,155 psi 5,935 5,986 Casing Length Size MD TVD Burst Collapse Structural Conductor 381' 30" 381' 381' Surface 1,990' 20" 1,990' 1,990' Intermediate Production 6,950' 13-3/8" 6,950' 6,950' 5,380 psi 2,670 psi Production 4,732' 9-5/8" 12,032' 11,675' 5,750 psi 3,090 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 3,260-3,370(Disposal) 3,260-3,370(Disposal) 2-3/8" (Disposal) 4.7/J-55 3,206 zOC�� 3,558-5,764(Production) 3,558-5,764(Production) 7" (Production) 26/J-553 4-1/2" (Production) 12.75/N-80 5,760 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Packers(x 10)See schematic/Halliburton XXO Landing Nipple&"CP-2"TRSSV See schematic 12.Attachments: Proposal Summary El Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 1/30/2018 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GFy�, ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan Golis Contact Name: Michael Quick Authorized Title: OperationstiManager Contact Email: mauick hilcom.com J i�..�. Date: ( I 1 r / i a Contact Phone: (907)777-8440 Authorized Signature: / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: , w/,U( Plug Integrity ❑ BOP Test El Mechanical Integrity Test ElLocation Clearance ❑ Other: SE._bi in,. 1_t>ri4,fi.jccufrtetil. 04' t„ FLf ./7 47x<v— 5.,,r�t,C4� iel Or1 /re: cm S 4-4..-�. Post Initial Injection MIT Req'd? Yes ❑ No ❑ ,.,.„`�r,'a-6 ` Spacing Exception Required? Yes ❑ No ted' Subsequent Form Required: / 0 —j 0 'K RBD '3 �L--- F - 1 KU18 APPROVED BY Approved by: 6243CCOMMISSIONER THE COMMISSION Date: C I 3 T' lie t caw 1124/is 9I2 tbti/q /r ' i"2' -p' mc-p_ ./4,5p, Submit Form and Form 10-403 Revised 4/2017 Approved application is va �D, hoit oapproval. Attachments in Duplicate • n • Well Prognosis Well: Tyonek A-12 FIilcora Alaska,LL) Date: 1/15/2018 Well Name: Tyonek A-12 API Number: 50-883-20032-00 Current Status: SI Gas/Disposal Well Leg: N/A Estimated Start Date: January 30, 2018 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 169-099 First Call Engineer: Michael Quick (907) 777-8442 (0) (907) 317-2969 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) AFE Number: Current Bottom Hole Pressure: 1500 psi @ 3857' TVD (Fill tagged at 3857' December 2014) Max. Potential Surface Pressure: 1155 psi (1500 psi reservoir pressure in Sterling X sand) Brief Well Summary A-12 was drilled and completed in May 1970 and left in suspended status until gas production was needed. It was then re-completed in July 1975 throughout the Beluga and Sterling intervals with a single packer and single string of tubing. The well was worked over in 1994 to cement squeeze the open perforations from 3558'to 3628', re-perforate existing intervals and add new perforations. The well was completed as a dual string gas producer. In November 1997,the well was worked over to convert it to a dual string injector/producer,with DIO 17 being approved for Class II disposal into the Sterling sands from 3260'to 3380'MD. This is the wells current configuration. Class II disposal operations were suspended in May 2013 due to suspected communication between the 2-3/8" disposal string and the inner annulus, however the well would pass a MIT. Gas production was shut-in in October 2014. The purpose of this sundry is to abandon the Class II disposal perforations with a cement squeeze down the 2- 3/8" injection tubing, place a tubing plug in 4-1/2" production tubing at+/-3850', and perforate the Sterling X sand from +/-3430'to +/-3490' and return the well to production. Notes Regarding Wellbore Condition • 2-3/8" disposal short string had 1.75" gauge ring ran to 3217'with no set down on 1/25/15. • 4-1/2" production long string tagged at 3857'with a 1.75" DD bailer on 12/4/14. 2.6" swedge would �,,C C: --'-",not pass.3§5$'.'. :> S.4�)' F't(4r° vti (-La 1r 6e-L.J Cle-2.,c.R- `-}- (Ike, „ ) M,v - /, ZT'l P • +/-850,000 bbls were disposed of into the zone from 3260'to 3370' starting in November 1998. Procedure: 1. RU on 2-3/8" Disposal Short String and perform step rate injection test, not exceeding 2500 psi surface pressure. . P 2. MIRU wireline on 2-3/8" Disposal Short String, PT lubricator to 2,000 psi High/250 Low. SferS''1 3. RIH to tubing tail at 3206'with GR. POOH. RD wireline. 4. RU wireline on 4-1/2" Production String, PT lubricator to 2,000 psi High/250 Low. 5. RIH pull SSSV. POOH. LD SSSV 6. RIH with GR to tag(last tag 3857'), POOH. RIH with through tubing bridge plug to±3850'. Use Gamma/CCL to correlate. Consult Engineer prior to setting. Set plug. POOH. Note: confirm water level. yi- Pr ,��is ,,,A- 7. RIH and dump bail 25' of cement on top of bridge plug, POOH. 15-01) e 30 8. RU cement unit on 2-3/8" Disposal Short String, perform step rate injection test not exceeding 2500 psi surface pressure. • • Well Prognosis Well: Tyonek A-12 IIilcurp Alaska,Lb Date: 1/15/2018 9. Mix and pump+/-25 bbls (122 sxs) of 15.8 ppg Class G cement down the 2-3/8" Disposal Short String. Squeeze+/-5 bbls of cement into the disposal perforations from 3260' to 3370'. RD. Note: 13-3/8" by 4-1/2" annular volume from 3200'to 3500' is 39 bbls. • v 2-3/8" tubing volume is 0.00387 bbl/ft x 3206' = 12.4 bbl capacity 10. RU wireline on 4-1/2" Production String, PT lubricator to 2,000 psi High/250 Low. 11. RU wireline perforating guns. 12. RIH and perforate the following intervals: Zone Sands (Mp) Btm (MD) FT SPF Sterling X ±3,430' ±3,490' 60' 6 a. Final Perf tie-in sheet will be provided in the field for exact perf intervals. b. Correlate using Correlation Log. c. Use Gamma/CCL to correlate. Utilize Press/Temp tool if available. d. Record tubing pressures before and after each perforating run. 13. RIH w/SSSV and set in profile. 14. RD wireline 15. Turn well over to production. 16. Test SSSV per AOGCC requirements. Attachments: 1. Actual Schematic 2. Proposed Schematic North Cook Inlet Well: NCI A-12 tli . SCHEMATIC Last Completed: 11/11/1997 PTD: 169-099 Hilcorp Alaska,LLC API: 50-883-20032-00 RKB:MSL=)0(' CASING DETAIL 30"j ) I Size Wt Grade Conn ID Top Btm 1 4 A 30" 133 H-40 Welded 28.000 41' 381' 20 j i I ` h 20" 133 H-40 19.730 41' 1,990 Z B F 13-3/8" 72 N-80 BTC 12.347 41' 6,950' 2 111 41-' 1 9-5/8" 40 N-80 8.835 7,300' 12,032' O a .3 P4' TUBING DETAIL '`0 Id' r € -��"'g 33 0 2-3/8" 4.7 J-55 EUE 8rd 1.990 67 3,206' / t 7" 26 J-55 EUE 8rd 6.240 61' 3 Std j,' �` ' 4-1/2" 12.75 N-80 EUE 8rd 3.958 3,200' 5,760' .�7,G, t a-Stray CI'-A t 4 ` :AMEN It0-191 A",2,�1�� 1/i X /3 V JEWELRY DETAIL 5 1'=' -aao Depth Depth s' AI a-40 N0 (MD) (TVD) ID OD Item t & _q5o SHORT STRING(WASTE DISPOSAL) -q51 A 299' 299' 1.870 Halliburton XXO Landing Nipple Ste© 7 D 0-6.0 B 3,198' 3,198' 1.810 Halliburton XN Nipple 8i C 3,200' 3,200' 1.990 Muleshoe Guide and Seal Assembly { -a_Zo LONG STRING(PRODUCER) ' ` -, =a 71 60.6' 60' 7.000 FMC Tubing Hanger 1 435' 435' 5.900 Halliburton"CP- TRSSV 9 4 2 3,175' 3,175' 6.440 Halliburton Twin Flo Seal Assembly ? aao 2 _a-a2 3,200' 3,200' 8.000 Halliburton Twin Flow Packer 10gp =a-19111.0,0 3,496' 3,496' 6.220 "MSN"Seals&Seal Extension a- 11 3 3,500' 3,500' 8.000 Halliburton MWD Perm Packer&Tbg Adapter . • 3,504' 3,504' 8.000 Halliburton Seal Bore Extension&Tbg Adapter, =A3 3,507' 3,507' 6.526 Muleshoe Guide 4 3,750' 3,750' 3.958 Halliburton Seal NoGo Unit 12 < 3,750' 3,750' 8.000 Halliburton MWD Perm Packer&Tbg Adapter &7,E3 5 4,003' 4,003' 3.813 Halliburton XD Sliding Sleeve-Open 13 ,nil E-6 E 6 4 ,068' 4,068' 3.958 Halliburton Seal NoGo Unit F5,G-14,069' 4,069' 8.000 Halliburton MWD Perm Packer&Tbg Adapter 1411, 7 4,132' 4,132' 3.813 Halliburton XD Sliding Sleeve-Closed 4,174' 4,174' 3.958 Halliburton Seal NoGo Unit r+tla,H 8 4,175' 4,175' 8.000 Halliburton MWD Perm Packer&Tbg Adapter 1 =-7_1-1-6,HS H9 !( 4,254' 4,254' 3.958 Halliburton Seal NoGo Unit 16%- € 9 4,255' 4,255' 8.000 Halliburton MWD Perm Packer&Tbg Adapter 10 4,359' 4,359' 3.813 Halliburton XD Sliding Sleeve-Open r "r 18 ,.-XN 13,141-7, 11 4,452' 4,452' 3.958 Halliburton Seal NoGo Unit £76 1-8,J-2 4,453' 4,453' 8.000 Halliburton MWD Perm Packer&Tb Ada ter 1 s,' -.L2.1,J-3, g p -K-41,M4 12 4,569' 4,569' 3.958 Halliburton Seal NoGo Unit EZSZ Plug _ _ _ 4,569' 4,569' 8.000 Halliburton MWD Perm Packer&Tbg Adapter @5�, - Pz p5 13 5,175' 5,175' 3.813 Halliburton XD Sliding Sleeve-Open ® 42 R5, 14 5,250' 5,250' 3.958 Halliburton Seal NoGo Unit =S-6,T-2 5,250' 5,250' 8.000 Halliburton MWD Perm Packer&Tbg Adapter U-,,V 15 5,383' 5,383' 3.813 Halliburton XD Sliding Sleeve-Open 13-3/8"1 c 1c�0,_pre 16 5,446' 5,446' 3.958 Halliburton Seal NoGo Unit-Length 7.29 OA �`};0 rick;"V.qt•t. ct 5,448' 5,448' 8.000 Halliburton MWD Perm Packer&Tbg Adapter TO 6 17 5,634' 5,634' 3.813 Halliburton XD Sliding Sleeve-Closed ...14 -y 0 18 5,757 5,757' 3.725 Halliburton XN Nipple 19 5,759' 5,759' 3.985 Wireline Guide •,.... 4,1 =* Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc) g5/g, - ., ; , 2 Depth(MD) Depth(ND) Description . ' 03 5,935' 5,935' EZSZ Plug Set w/1997 Workover 5,986' 5,986' 2-7/8"Tubing PBTD:5,935' TD:14,910 6,833' 6,833' Cement Retainer 11,965' 11,616' Cement Retainer-PBTD Updated By:JLL 01/10/18 H . • North Cook Inlet Well:NCI A-12 SCHEMATIC Last Completed: 11/11/1997 PTD: 169-099 Hilcarp Alaska,LLC API: 50-883-20032-00 PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status STERLING 3,260' 3,370' 3,260' 3,370' 110' 6/10/1975 Open CI-STRAY 3,558' 3,568' 3,558' 3,568' 10' 6/10/1975 Szq'd CI-STRAY 3,577' 3,587' 3,577' 3,587' 10' 6/10/1975 Szq'd CI-A 3,604' 3,628' 3,604' 3,628' 24' 6/10/1975 Szq'd C1-1.0 3,820' 3,880' 3,820' 3,880' 60' 6/10/1975 Open CI-2.0 3,866' 4,440' 3,866' 4,440' 574' 11/1/1997 Open CI-2.0 3,896' 3,960' 3,896' 3,960' 64' 6/10/1975 Open CI-3.0 3,982' 3,994' 3,982' 3,994' 12' 6/10/1975 Open CI-4.0 4,014' 4,048' 4,014' 4,048' 34' 6/10/1975 Open CI-5.0 4,090' 4,098' 4,090' 4,098' 8' 6/10/1975 Sliding Sleeve-Closed CI-5.0 4,106' 4,111' 4,106' 4,111' 5' 6/10/1975 Sliding Sleeve-Closed _ CI-5.1 4,116' 4,124' 4,116' 4,124' 8' 6/10/1975 Sliding Sleeve-Closed CI-6.0 4,141' 4,166' 4,141' 4,166' 25' 6/10/1975 Sliding Sleeve-Closed CI-7,0/CI-7.1 4,188' 4,238' 4,188' 4,238' 50' 6/10/1975 Open CI-8.0 4,272' 4,282' 4,272' 4,282' 10' 6/10/1975 Open CI-8.2 4,298' 4,316' 4,298' 4,316' 18' 6/10/1975 Open CI-10.0 4,378' 4,390' 4,378' 4,390' 12' 6/10/1975 Open CI-11.0 4,415' 4,440' 4,415' 4,440' 25' 6/10/1975 Open A-3 4,475' 4,482' 4,475' 4,482' 7' 4/1/1993 Open B-7 4,660' 4,668' 4,660' 4,668' 8' 4/1/1993 Open E-3 4,973' 4,978' 4,973' 4,978' 5' 4/1/1993 Open E-4 4,990' 4,995' 4,990' 4,995' 5' 4/1/1993 Open E-5/E-6 5,010' 5,025' 5,010' 5,025' 15' 4/1/1993 Open E-8 5,050' 5,057' 5,050' 5,057' 7' 4/1/1993 Open E-9 5,064' 5,070' 5,064' 5,070' 6' 4/1/1993 Open F-4 5,120' 5,135' 5,120' 5,135' 15' 4/1/1993 Open F-5 5,150' 5,157' 5,150' 5,157' 7' 4/1/1993 Open G-1 5,194' 5,204' 5,194' 5,204' 10' 4/1/1993 Open H-1/H-1.2 5,292' 5,305' 5,292' 5,305' 13' 4/1/1993 Open H-6 5,354' 5,372' 5,354' 5,372' 18' 4/1/1993 Open H-8 5,394' 5,414' 5,394' 5,414' 20' 4/1/1993 Open H-9 5,431' 5,436' 5,431' 5,436' 5' 4/1/1993 Open 1-3 5,466' 5,480' 5,466' 5,480' 14' 4/1/1993 Sliding Sleeve-Closed 1-4 5,482' 5,490' 5,482' 5,490' 8' 4/1/1993 Sliding Sleeve-Closed 1-7 5,514' 5,521' 5,514' 5,521' 7' 4/1/1993 Sliding Sleeve-Closed 1-8 5,532' 5,540' 5,532' 5,540' 8' 4/1/1993 Sliding Sleeve-Closed J-2 5,564' 5,574' 5,564' 5,574' 10' 4/1/1993 Sliding Sleeve-Closed J-2.1 5,576' 5,584' 5,576' 5,584' 8' 4/1/1993 Sliding Sleeve-Closed J-3 5,592' 5,596' 5,592' 5,596' 4' 4/1/1993 Sliding Sleeve-Closed K-4.1 5,668' 5,674' 5,668' 5,674' 6' 4/1/1993 Sliding Sleeve-Closed M-4 5,757' 5,764' 5,757' 5,764' 7' 4/1/1993 Sliding Sleeve-Closed P-2 6,088' 6,096' 6,088' 6,096' 8' 4/1/1993 Isolated P-5 6,130' 6,150' 6,130' 6,150' 20' 4/1/1993 Isolated Q-2 6,180' 6,186' 6,180' 6,186' 6' 4/1/1993 Isolated R-6 6,330' 6,338' 6,330' 6,338' 8' 4/1/1993 Isolated S-6 6,441' 6,448' 6,441' 6,448' 7' 4/1/1993 Isolated T-2 6,540' 6,547' 6,540' 6,547' 7' 4/1/1993 Isolated T-6 6,641' 6,646' 6,641' 6,646' 5' 4/1/1993 Isolated U-5 6,718' 6,726' 6,718' 6,726' 8' 4/1/1993 Isolated U-7 6,748' 6,758' 6,748' 6,758' 10' 4/1/1993 Isolated V-1 6,790' 6,800' 6,790' 6,800' 10' 4/1/1993 Isolated Updated By:JLL 01/10/18 H . North Cook Inlet Well: NCI A-12 PROPOSED Last Completed: 11/11/1997 PTD: 169-099 Hilcorp Alaska,LLC API: 50-883-20032-00 RKB:MSL=XX' CASING DETAIL 3°"/ L 1 1 � n Size Wt Grade Conn ID Top BP I)30" 133 H-40 Welded 28.000 41' 381' try 20" 133 H-40 19.730 41' 1,990' B 13-3/8" 72 N-80 BTC 12.347 41' 6,950' 3�p 2 9-5/8" 40 N-80 8.835 7,300' 12.032 tiZR,"^+ * TUBING DETAIL sing ' �� x 2-3/8" 4.7 J-55 EUE 8rd 1.990 67' 3,206' 3f ing 7" 26 1-55 EUE 8rd 6.240 61' 3,508' U 4-1/2" 12.75 N-80 EUE 8rd 3.958 3,200' 5,760' 6 J�a- aA 4 mi � �log Plug a-1.o , JEWELRY DETAIL k� 5 ■ .` +3,850, -0-20 1) -a-3o No Depth Depth ID OD Item ` a-4o (MD) (ND) 11 I aso SHORT STRING(WASTE DISPOSAL) =051 A 299' 299' 1.870 Halliburton XXO Landing Nipple 0; 7 ' a�.o B 3,198' 3,198' 1.810 Halliburton XN Nipple 8 C 3,200' 3,200' 1.990 Muleshoe Guide and Seal Assembly -a-7.o LONG STRING(PRODUCER) =a-71 60.6' 60' 7.000 FMC Tubing Hanger 1 435' 435' 5.900 Halliburton"CP-2"TRSSV 9 , 3,175' 3,175' 6.440 Halliburton Twin Flo Seal Assembly , aao 2 _0a2 3,200' 3,200' 8.000 Halliburton Twin Flow Packer 10 ,i D N 0(11' -a-loo 3,496' 3,496' 6.220 "MSN"Seals&Seal Extension a-11.o 11 3 3,500' 3,500' 8.000 Halliburton MWD Perm Packer&Tbg Adapter 3,504' 3,504' 8.000 Halliburton Seal Bore Extension&Tbg Adapter , =A3 3,507 3,507' 6.526 Muleshoe Guide 4 3,750' 3,750' 3.958 Halliburton Seal NoGo Unit 12„ t 3,750' 3,750' 8.000 Halliburton MWD Perm Packer&Tbg Adapter ' B-7 Es l/!5 J 4,003' 4,003' 3.813 Halliburton XD Sliding Sleeve-Open E4,,ES& 14✓ =E-6,E-8 4,068' 4,068' 3.958 Halliburton Seal NoGo Unit 13 11 11 �P F4 ® 4,069' 4,069' 8.000 Halliburton MWD Perm Packer&Tbg Adapter r F-6 G-1 14,; 4,132' 4,132' 3.813 Halliburton XD Sliding Sleeve-Closed 44 4,174' 4,174' 3.958 Halliburton Seal NoGo Unit f 15 D0 is I+1.1&1.2, 8 4,175' 4,175' 8.000 Halliburton MWD Perm Packer&Tbg Adapter a DrV -HZ' r ,a 9 4,254' 4,254' 3.958 Halliburton Seal NoGo Unit 16 s 4,255' 4,255' 8.000 Halliburton MWD Perm Packer&Tbg Adapter I 10 4,359' 4,359' 3.813 Halliburton XD Sliding Sleeve-Open 17 DD.; 1. 4,452' 4,452' 3.958 Halliburton Seal NoGo Unit ,7i 18 r 7�N 1-3141-7,l 11 4,453' 4,453' 8.000 Halliburton MWD Perm Packer&Tbg Adapter '4 19 -J-21,,13, l K-4.1,M4 12 4,569' 4,569' 3.958 Halliburton Seal NoGo Unit �� 4,569' 4,569' 8.000 Halliburton MWD Perm Packer&Tbg Adapter EZSZ@5,935 �� --AMMO 5,175' 5,175' 3.813 Halliburton XD Sliding Sleeve-Open P-2,P-5, 42,R-6, 5,250' 5,250' 3.958 Halliburton Seal NoGo Unit =_s6,T-2 14 5,250' 5,250' 8.000 Halliburton MWD Perm Packer&Tbg Adapter LLi 1 5,383' 5,383' 3.813 Halliburton XD Sliding Sleeve-Open 13-30 . . . , 16 5,446' 5,446' 3.958 Halliburton Seal NoGo Unit-Length 7.29 OA 5,448' 5,448' 8.000 Halliburton MWD Perm Packer&Tbg Adapter ` , . '.Zi v ',. 17 5,634' 5,634' 3.813 Halliburton XD Sliding Sleeve-Closed 411 18 5,757' 5,757' 3.725 Halliburton XN Nipple *, „it.--4, 19 5,759' 5,759' 3.985 Wireline Guide •��''` Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc) Depth(MD) Depth(ND) Description 9-5/8"*wwit'{` fe 5,935' 5,935' EZSZ Plug Set w/1997 Workover 5,986' 5,986' 2-7/8"Tubing PBTD:5,935' TD:14,910 6,833' 6,833' Cement Retainer 11,965' 11,616' Cement Retainer-PBTD Updated By:JLL 01/10/18 H . North Cook Inlet Well: NCI A-12 PROPOSED Last Completed: 11/11/1997 PTD: 169-099 flacon,Alaska,LLC API: 50-883-20032-00 PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status STERLING 3,260' 3,370' 3,260' 3,370' 110' 6/10/1975 Cemented STERLING X ±3,430' ±3,490' ±3,430' ±3,490' ±60' Future Proposed CI-STRAY 3,558' 3,568' 3,558' 3,568' 10' 6/10/1975 Szq'd CI-STRAY 3,577' 3,587' 3,577' 3,587' 10' 6/10/1975 Szq'd CI-A 3,604' 3,628' 3,604' 3,628' 24' 6/10/1975 Szq'd C1-1.0 3,820' 3,880' 3,820' 3,880' 60' 6/10/1975 Open CI-2.0 3,866' 4,440' 3,866' 4,440' 574' 11/1/1997 Open CI-2.0 3,896' 3,960' 3,896' 3,960' 64' 6/10/1975 Open C1-3.0 3,982' 3,994' 3,982' 3,994' 12' 6/10/1975 Open CI-4.0 4,014' 4,048' 4,014' 4,048' 34' 6/10/1975 Open CI-5.0 4,090' 4,098' 4,090' 4,098' 8' 6/10/1975 Sliding Sleeve-Closed CI-5.0 4,106' 4,111' 4,106' 4,111' 5' 6/10/1975 Sliding Sleeve-Closed CI-5.1 4,116' 4,124' 4,116' 4,124' 8' 6/10/1975 Sliding Sleeve-Closed CI-6.0 4,141' 4,166' 4,141' 4,166' 25' 6/10/1975 Sliding Sleeve-Closed CI-7.0/CI-7.1 4,188' 4,238' 4,188' 4,238' 50' 6/10/1975 Open CI-8.0 4,272' 4,282' 4,272' 4,282' 10' 6/10/1975 Open CI-8.2 4,298' 4,316' 4,298' 4,316' 18' 6/10/1975 Open C1-10.0 4,378' 4,390' 4,378' 4,390' 12' 6/10/1975 Open CI-11.0 4,415' 4,440' 4,415' 4,440' 25' 6/10/1975 Open A-3 4,475' 4,482' 4,475' 4,482' 7' 4/1/1993 Open B-7 4,660' 4,668' 4,660' 4,668' 8' 4/1/1993 Open E-3 4,973' 4,978' 4,973' 4,978' 5' 4/1/1993 Open E-4 4,990' 4,995' 4,990' 4,995' 5' 4/1/1993 Open E-5/E-6 5,010' 5,025' 5,010' 5,025' 15' 4/1/1993 Open E-8 5,050' 5,057' 5,050' 5,057' 7' 4/1/1993 Open E-9 5,064' 5,070' 5,064' 5,070' 6' 4/1/1993 Open F-4 5,120' 5,135' 5,120' 5,135' 15' 4/1/1993 Open F-5 5,150' 5,157' 5,150' 5,157' 7' 4/1/1993 Open G-1 5,194' 5,204' 5,194' 5,204' 10' 4/1/1993 Open H-1/H-1.2 5,292' 5,305' 5,292' 5,305' 13' 4/1/1993 Open H-6 5,354' 5,372' 5,354' 5,372' 18' 4/1/1993 Open H-8 5,394' 5,414' 5,394' 5,414' 20' 4/1/1993 Open H-9 5,431' 5,436' 5,431' 5,436' 5' 4/1/1993 Opera 1-3 5,466' 5,480' 5,466' 5,480' 14' 4/1/1993 Sliding Sleeve-Closed 1-4 5,482' 5,490' 5,482' 5,490' 8' 4/1/1993 Sliding Sleeve-Closed 1-7 5,514' 5,521' 5,514' 5,521' 7' 4/1/1993 Sliding Sleeve-Closed 1-8 5,532' 5,540' 5,532' 5,540' 8' 4/1/1993 Sliding Sleeve-Closed J-2 5,564' 5,574' 5,564' 5,574' 10' 4/1/1993 Sliding Sleeve-Closed J-2.1 5,576' 5,584' 5,576' 5,584' 8' 4/1/1993 Sliding Sleeve-Closed J-3 5,592' 5,596' 5,592' 5,596' 4' 4/1/1993 Sliding Sleeve-Closed K-4.1 5,668' 5,674' 5,668' 5,674' 6' 4/1/1993 Sliding Sleeve-Closed M-4 5,757' 5,764' 5,757' 5,764' 7' 4/1/1993 Sliding Sleeve-Closed P-2 6,088' 6,096' 6,088' 6,096' 8' 4/1/1993 Isolated P-5 6,130' 6,150' 6,130' 6,150' 20' 4/1/1993 Isolated Q-2 6,180' 6,186' 6,180' 6,186' 6' 4/1/1993 Isolated R-6 6,330' 6,338' 6,330' 6,338' 8' 4/1/1993 Isolated S-6 6,441' 6,448' 6,441' 6,448' 7' 4/1/1993 Isolated T-2 6,540' 6,547' 6,540' 6,547' 7' 4/1/1993 Isolated T-6 6,641' 6,646' 6,641' 6,646' 5' 4/1/1993 Isolated U-5 6,718' 6,726' 6,718' 6,726' 8' 4/1/1993 Isolated U-7 6,748' 6,758' 6,748' 6,758' 10' 4/1/1993 Isolated V-1 6,790' 6,800' 6,790' 6,800' 10' 4/1/1993 Isolated Updated By:JLL 01/10/18 • • Schwartz, Guy L (DOA) From: Michael Quick <mquick@hilcorp.com> Sent: Thursday, January 25, 2018 9:10 AM To: Schwartz, Guy L (DOA) Cc: Bettis, Patricia K(DOA); Roby, David S (DOA);Wallace, Chris D (DOA);Juanita Lovett Subject: RE: NCI A-12 (PTD 169-099) Guy— Thank you for the follow up on this sundry. 1. The NCI A-12 well on the Tyonek platform was shut in by CPAI in October 2014, due to the 4-1/2" production tubing being loaded with sand or other fill at 3857', CPAI attempted to but could not work past this depth with a bailer,so the well was shut in. It is likely that most of the annular space between the sliding sleeves and the 13- 3/8" casing is also full of fill, making either removal of the completion or a cement squeeze to the reservoir unlikely. Ox 2. Understand the requirement to submit a request to cancel DIO 17 for this well if it is able to successfully producegas.as. _ le_j) 3. Hilcorp will pressure test the bridge plug and cement, listed as step 7 in the sundry procedure,to 1500 psi for 30 minutes, charting the test. It is understood that this pressure test will not require notification for AOGCC witnessing. Please give me a call if you want to follow up on our discussion this morning. Thanks, Mike Michael Quick Hilcorp Alaska, LLC Operations Engineer Office 907-777-8442 Cell 907-317-2969 Email mquick(a�hilcorp.com Hilcorp A Company Built on Energy From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Wednesday,January 24, 2018 4:29 PM To: Michael Quick<mquick@hilcorp.com> Cc: Bettis, Patricia K (DOA)<patricia.bettis@alaska.gov>; Roby, David S(DOA)<dave.roby@alaska.gov>;Wallace, Chris D (DOA)<chris.wallace@alaska.gov> Subject: NCI A-12 (PTD 169-099) Mike, 1 I am reviewing the sundry submitted•lug perfs, squeeze disposal zone and ad perforations for gas production on A- 12. 1. I am concerned that the operation you are proposing is a "de facto" P&A for most of the well. There are quite a few open sleeves below and when the time comes to do the P &A the well it is unlikey that the plug w/cement at 3850 ft will is drilled up in order to squeeze off the lower perfs. 2. As part of the sundry approval Hilcorp will need to submit a request to cancel DIO 17 after work is completed. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). 2 • • Wallace, Chris D (DOA) From: Michael Quick <mquick@hilcorp.com> Sent: Wednesday,January 24, 2018 3:10 PM To: Roby, David S (DOA) Cc: Wallace, Chris D (DOA); Schwartz, Guy L (DOA); Bettis, Patricia K (DOA);Juanita Lovett; Larry Greenstein Subject: RE: Sundry application for NCIU A-12 (PTD 169-099) Mr. Roby — Thank you for your time discussing this well. We have a significant coal that is laterally extensive across the Tyonek platform wells, located approximately 10'TVD below the lowest disposal zone perforation. Based on a review of the injection history of this well, from the initial injection test that pumped 6 bbl/min at 1450 psi, to the average injection pressure for the year from 7/2010 to 7/2011 of 1450 psi (chart below), we do not believe that the disposal operation had pressures high enough to fracture the disposal sand. The coal below this disposal zone likely confined the disposal fluids to the targeted zone of 3260' to 3370'. String Nam• A- D Blast D•I• 7111201170 Dsyaw.v. 36S End Date 71 1011 Cook Inlet Production&Pressure Data 1603 _...,200 • •• 80 14x0 ♦ • • • • 160 1200 • • 140 1n00 120 8Q0 100 ii u g� h00 �,, ji • ED 400 11"."-"14fiL 20r‘ 20 J, .10 A,.g-1A S•p•10 C • ' a•(10 Am-11 F•tr11 Mar-11 Ap-1t may11 hae-?' wv ...los w • • • • • '' • • • • • • •• •• • •• • n • • N • • ••••w�• • •• • •• • • • • • •s • • + , 44 • •f 166•i • %• • • h • t % • • •• • • ., �m�1�•�•mrimp•td ato A,q.10 Sep-10 rx1-10 NO*10 C1ec.10 Jars I1 Feb-11 M0-11 ,1/4+-11 Mori11 1 • If the proposed Sterling X sand perforations do not produce gas, the well will be shut in. If the disposal fluids did migrate into the Sterling X sand, they would not be produced as the well does not have artificial lift capability, and based on the current disposal tubing pressure reading of less than 10 psi,this zone does not have the potential to flow to surface (see chart below). WM!A Oh?DAP IMO!PA 150 061a.110O7.O t' Mt'IU A o37 DIM'300041 PA ltd? rt a n I a — Please give me a call to discuss any questions. Thanks, Mike Michael Quick Hilcorp Alaska, LLC Operations Engineer Office 907-777-8442 Cell 907-317-2969 Email mquick(a�hilcorp.com Hilcorp A Company Built on Energy From: Roby, David S (DOA) [mailto:dave.roby@alaska.gov] Sent:Wednesday,January 24, 2018 11:22 AM To: Michael Quick<mquick@hilcorp.com> Cc:Wallace, Chris D (DOA) <chris.wallace@alaska.gov>; Schwartz, Guy L(DOA) <guy.schwartz@alaska.gov>; Bettis, Patricia K(DOA) <patricia.bettis@alaska.gov> Subject:Sundry application for NCIU A-12 (PTD 169-099) 2 • Mike, In reviewing the proposed work for the subject well and the information contained in the files for DIO 17 I notice that you're proposing to perforate and produce from the Sterling X sand,which according to the perf record for the well is 60'ND deeper than the perf interval for the Sterling disposal operations authorized by DIO 17. However, in the application for DIO 17 it was stated that the disposal interval was underlain by"...a laterally continuous zone od interbedded clay, siltstone,volcanic ash and coal that averages 170'thick..." so according to this your proposed productive interval is in the middle of the lower confining zone for the disposal operations. What evidence does Hilcorp have that disposal fluids have not migrated to the sands you're now proposing to produce? Thanks in advance. Regards, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Dave Roby at(907)793-1232 or dave.robv@alaska.gov. 3 • Hilcorp Alaska, LLC ' 3800 Centerpoint Drive Suite 1400 lfiR 3 it i` Anchorage,AK 99503 Phone: 907-777-8321 Fax:907-777-8580 March 27,2017 Ms. Cathy P. Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: NCIU Class II injection surveillance summary(DIO 17 and 33) Dear Ms. Foerster: Hilcorp Alaska, LLC ("Hilcorp"), as Operator of North Cook Inlet Field (effective November 2016) hereby submits the report required by DIO 17 (rule 4) and DIO 33(rule 6) establishing the DIO for the Class II Water Disposal wells at NCIU A-12 and B-01A, respectively for the calendar year of 2016. Surveillance Summary No fluid was injected into NCIU A-12 and minimal volumes were injected into NCIU B- 01A within the year 2016. A passing mechanical integrity test was performed on the well on 5/10/2015 and is required bi-annually to retain disposal approval status. Sincerely, 0° scamp APP 02017 Reis Edwards Reservoir Engineer Wallace, Chris D (DOA) From: Kautz, Rachel <Rachel.Kautz@conocophillips.com> Sent: Tuesday, April 14, 2015 9:18 AM To: Schwartz, Guy L(DOA);Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Tyonek A-12 (PTD#169-099) Diagnostics Chris/Guy, The wireline crew was unable to do the LDL on A-12 because they ran out of time on the platform. The well will remain shut in and secured until we can get back out there this summer to do the LDL. I will keep you posted on the future plans and dates. Regards, Rachel Kautz Well Integrity Engineer SCANNED APR 2 3 2015 ConocoPhillips Alaska 907-263-4409 From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Wednesday, April 01, 2015 10:11 AM To: Kautz, Rachel; Schwartz, Guy L (DOA) Cc: Senden, R. Tyler Subject: [EXTERNAL]RE: Tyonek A-12 (PTD #169-099) Diagnostics Rachel, Agree that the LDL may give a more definitive path and so approval is given for injection for this test. Assuming the LDL is negative or inconclusive, a passing State witnessed (or waived witness) MITIA would be required after stabilized injection is achieved and possibly an administrative approval under DIO 17 Rule 6 to continue injection operations. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, 1 .- -- WELL HISTORY FILE COVER PAGE XHVZS This page identifies o\"ersize material and digital infol11lation available for this individual Well History file and weather or not it is available in the laserFiche file. Please insure that it remains as the first page in this file. } & <i 09 i Well History File # Digital Data Added to laserFiche File 0 CD's - # 0 Yes 0 No - 0 DVD's - # 0 Yes [ No - 0 Diskettes - # [I Yes D No - Oversized Material Added to laserFiche File 0 Maps # IJ Yes IJ No - [I Mud logs # - IJ Yes IJ No [I Other # IJ Yes D No - General Notes or Comments about this file. If any of the infol11lation listed above is not available in the laserFiche file you may contact the Alaska Oil & Gas Conservation Commission to request copies. Please call Robin Deason at (907) 793-1115 if you have any questions or infol11lation requests regarding this file. - -- ---------- y- conocoPhiliips Alaska ConocoPhillips Alaska, Inc. Annual Class II Disposal Well Surveillance Report NCI A-12 June 30, 2014 In accordance with Disposal Injection Order (DIO) 17 Rule 4, ConocoPhillips Alaska, Inc. (CPAI) hereby submits the following information for North Cook Inlet (NCI) injection well A -12D, permit to drill numb :, authorized for injection of Class II disposal fluids. This report is based on a reporting period from June 1, 2013 to June 1, 2014. As of June 24, 2014 184 barrels (bbl) of Class II fluids, primarily produced water, were injected since the last report, July 1, 2013. No anomalous injection results were noted on this well during the year. All injected fluids during the identified reporting period were associated with leak diagnostics and testing, which were approved by the AOGCC prior to injection. The A-12 disposal string remains shut-in and isolated from injection service until the leak is repaired. See the attached Operating Parameter Trend Plot showing injection tubing pressure, injected volumes and inner annulus pressures. %ARMED NCIU A-12 June 2014 AOGCC Annual Surveillance Report Guidelines Operating Parameter Tred Plot —FTP NCI A -12D Production & Pressure Data —IAP —OAP June 2013 -June 2014 1400 1200 .N 1000 a 800 L N i VI 600 CL 400 _. 200 i 0 . Jun -13 Jul -13 Aug -13 Sep -13 Oct -13 Nov -13 Dec -13 Jan -14 Feb -14 Mar -14 Apr -14 May -14 Jun -14 -- -___. _. __------..�. —_ � .-- —♦—Injection Rate -- i 1 Ann —Injection Volume Ian NCIU A-12 June 2014 AOGCC Annual Surveillance Report Guidelines no go PERN nono g0 PENN IDINC WO g0 PENN no 90 VE -RN ID -IN C ;ono g0 no Carroll I Run Data 1 ID 41D6't50 RPE F, 5,986.0 5.985.91 0.43 FISH 2 7!8" TUBING SAK NCI A-12 6,833.0 6,632.8 ConocoPhillips 6,010 -- RPERF, 6.111<,118 Attributes 30.02CMT Retainer CEMENT RETAINER -PBTD M_ax An le & MD TD Perforations & hx;.832004200 e•S'e-0'S" RPERF, [�Ilf� FieldName COOK INLET Well Status cl (°) MD (hKBI (PROD 56.00 10.98 � 1 ActAlaska, �'. 1a 910o I Shot e,ata.ae Commence t H25 (ppm) ,Data Annwtalion End Date �KB.Grd (h), Rig R 1 Daie ` Bbn (TVD) - _.-- --- _.--.--- Dens SSSV. NIPPLE Top (kK8) ILa51 WO 1 V117997 i 5/11/1970 (kK8) tom Data (ah-• Annotation --[Depth (ftK81 End Dale (Annotation Last Mod By End DaT- to 3,320.0 Last Tag: WLM 4,845.0 5/312009 Rev Reason: ADJUST 2 3/8 RKB osboil 5!15/2013 RANGER. B" E'6, Tif Casing Description String 0... String lD ... ToP IkKe) Set Dapth ll... Sat Daplh ITUDI String Wt... String ... ung Th String TOP ThrdCONDUCTOR e,eGt SURFACE. -ETr vlV. ns I 30 28.000 41.0 381.0 381.0 133.00 H-40 WELDED Casin Descri 1 Stria 0... String ID ... g pion g Top EtKB Set Depth (f... Set Depth (TVD) ... String Wt... String- ) String Top Thrd - - CMT RW ir., her, CONDUCTOR 20 19.730 381.0 1.990.0 1.990.0 133.00 1 H 40 I Casing Description SURFACE String 0... String ID ...'Top 133!8 12.415 (ftK6) iSet Depth (f-.- Set Depth (TVD) String Wt WRg ... 41.0 6,950.0 6.949.8 72.00 N80 String Top Thrd 1 BTC CMI PLUG. 1A66 TO, 11At0 Casiny Description String 0... String ID ... Top ptKe) Set Depth If... Sal Depth (TVD) .,. String WL.. Stang .. String Top Thrd PRODUCTION 95/8 8.835 7.300.D 12.032.0 11.624.7 40.00 N-80 Tubing Description String 0... String ID Top (ItKB) Sol Depth (f.-. Depth (TVD) String WE.. SI ng .. String Top Thrd TUBING ( 7 6.240 Isar 60.6 3.508.0 3508.0 26.00 -55 ElIE8rd Top Depth ----- (TVD) Top Incl Nomi... lupi i,il _ Top (ftKB) IkKBI (`) Item Description Co_mm_ent ID (in) 60.6 60.6 -4.85 HANGER _ _ _ , FMC TUBING HANGER 7.000 xi � � ^" ` 435.5 435.5 -3.91 SAFETY VLV HALL BURTON'CP-2' TRSSV 5.900 3.175.4 3.175.4 0.31 SEAL ASSY HALLIBURTON TWIN FLO SEAL ASSEMBLY 6.440 IPF k-,r� 3,495.8 3,495.7 0.24 SEAL ASSY 'MSN' SEALS 8 SEAL EXTENSION 6.220 mrar, anew s.aw - 3.507.1 3,507.1 0.27 WLEG MULESHOE GUIDE 6.526 IP[nr. Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. allng ... String Top Thrd 1 rRe 4Eei " 1'ACNI _ TUBING 23/8 1.990 66.6 3,206.0 3,206.0 4.70 55 EUE-8rd 114 HE, P0. 1 u 'l.aw _ I'll Ell Top Depth (TVD) 1.0 -1 Nom'... i' -c'. Top (ftKB) (kK8) Deiption Comment ("1 Item Description ID (in) 299.5 299.5 -4.25 NIPPLE HALLIBURTON XXO LANDING NIPPLE 1.870 sw vi All Krr 44 �aru1<qn IP[Rr, 3,198.5 3,198.5 0.25 NIPPLE HALLIBURTON XN NIPPLE 1.810 SEAL -le 3.200.0 3,200.0 0.25 MULESHOE MULESHOE GUIDE AND SEAL ASSEMBLY 1.990 PAcnl R •.,re Tubing DescriptionString 0... String ID ... t ng.. Top (hKB) Set Depth (f... Set Depth (TVD),.. String Wt... S"..".. String Top Thrd n.,xe �ie SLAI.1%11 PACKER ASSY 41/2 3.958, 3.200 ,0 5,760.0 5,759.9 4.70 55 EUE-8,d nt I:E. Top Depth •>JJ -•%6] (TVD) Top Incl Nom'.., 1.]ubF4.a o Top (kK8) (ftl(B) P) Item Description Comment 10 (in) sleev[ai. uBn 3,200.0 3.199.9 0.25 PACKER HALLIBURTON TWIN FLOW PACKER 8.000 urear I.ar IKPERF,RF, I 3.499.8 3,499.7 0.25 PACKER HALLIBURTON MWD PERMANENT PACKER and tbg adapter 8.000 4A_,140 SEAL, •.16] 3,503.7 3,503.7 0.26 SBE HALLIBURTON SEAL BORE EXTENSION and Ibg adapter 8.000 PACKER, 4.153 3,749.8 3,749.7 0.62 SEAL HALLIBURTON SEAL no go unit 3.958 RPERF. 1.0 .. SEAL. •.(BB 3,750.5 3,750.5 0.63 PACKER HALLIBURTON MWD PERMANENT PACKER and tbg adapter 8.000 PACKER,4,668 RPERF, 4,003.3 4,003.2 0.50 SLEEVE -O HALLIBURTON XD SLIDING SLEEVE - OPEN 3.813 WERE. IAJ11,erB 4,068.4 4,068.3 0.50 SEAL 1HALLIBURTON SEAL no go unit 1 3.956 no go PERN nono g0 PENN IDINC WO g0 PENN no 90 VE -RN ID -IN C ;ono g0 no Carroll I Run Data 1 ID 41D6't50 RPE F, 5,986.0 5.985.91 0.43 FISH 2 7!8" TUBING se RRPERF 6,833.0 6,632.8 -0.07 CMT Retainer CEMENT RETAINER 6,010 -- RPERF, 6.111<,118 11,965.0 11,566.5 30.02CMT Retainer CEMENT RETAINER -PBTD RPERF, Perforations & Slots e•S'e-0'S" RPERF, Shot e,ata.ae RPERF, TOP (TVD) Bbn (TVD) Dens Top (kK8) Btm (tee) (SKIS) (kK8) tom Data (ah-• e,T18j.ERF RPERF, 3,260.0 3,320.0 3,260.0 3,320.0 Sterling, NCI 10/31/1997 5.0 6.J60aA00 cMT PLUG, -,ebb A-12 CMT RW Iner, e,eGt SURFACE. •,-0,660 CMT PWO.6,BG1 CMT PLW, J,110 CMT PLUG. CMT RW ir., her, Ae5 PRODUCTION, CMI PLUG. 1A66 TO, 11At0 SAK NCI A-12 ConocoPhillips "'`' KB-Gr-d(ft) iRig Release Dare - 5i11r1970 Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Thursday, April 10, 2014 1:33 PM To: 'Oksness, John T' Subject: RE: Tyonek A-12 (PTD# 169-099) Diagnostics John, As discussed, plan is approved as detailed below. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue Anchorage, AK 99501 (907) 793-1250 (phone) (907) 276-7542 (fax) chris.wallace@alaska.gov From: Oksness, Jolin T [mailto:Jolin.T.OksnessC&conocophillips.com] Sent: Thursday, April 10, 2014 11:14 AM To: Wallace, Chris D (DOA) Subject: Tyonek A-12 (PTD# 169-099) Diagnostics Chris — We have a crew on the platform and are performing diagnostics on Tyonek's Class II Disposal well A-12 (PTD# 169-099). PPPOT-T, POT -T, MIT -IA, MIT -T, CMIT-TxIA, and DDT -T testing have all passed with clear passing results. I'd like to request permission to pull the downhole plug and inject into the disposal string. While injecting, we plan to do a DDT on the IA and then try to establish a leak rate into the IA if the DDT fails. We suspect the one-way leak is through the packer at this point. When the diagnostics is complete, we will shut-in and isolate the disposal string while we determine our plan of action forward. Thanks, Jolin Jolin Oksness Well Integrity Engineer ConocoPhillips Alaska ATO -2054 Office: 907-265-1073 Cell: 907-230-7493 Wallace, -Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Friday, November 08, 2013 1:47 PM To: 'Oksness, Jolin T' Subject: RE: Tyonek Class II Disposal Well A-12 (PTD# 169-099) John, Let's get this well worked over and not add to the quarterly. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 (907) 793-1250 (phone) (907) 276-7542 (fax) chris.wallace@alaska.gov From: Oksness, Jolin T[mailto:Jolin.T.Oksness@conocophillips.com] Sent: Wednesday, October 30, 2013 10:13 AM To: Wallace, Chris D (DOA) Subject: RE: Tyonek Class II Disposal Well A-12 (PTD# 169-099) Chris — Do you require a quarterly report for Tyonek's A-12 per the long-term shut in requirement in Guidance Bulletin 10-02A? We are now going to be able to get over the well for diagnostics and repair but the MIT test date expired this month. We don't intend for this well to be shut in long term. We plan to get on the well in November and repair it ASAP to get it back online (with witnessed MIT -IA post -repair). I appreciate the clarification. Thanks, Jolin Oksness Well Integrity Engineer ConocoPhillips Alaska ATO -2054 Office: 907-265-1073 Cell: 907-230-7493 From: Oksness, John T Sent: Tuesday, October 22, 2013 10:35 AM To: 'Wallace, Chris D (DOA)' Cc: 'Jerry.C.Dethlefs@conocophillips.com' Subject: Tyonek Class II Disposal Well A-12 (PTD# 169-099) Chris — The 4 -year MIT for A-12 is due this month, however we will not be able to schedule the witnessed MIT -IA this month as the well remains shut-in since the TxIA communication was reported on 4/26/2013. Crane work on the platform has prevented slickline from getting over the well to set a plug and continue with our diagnostic and repair strategy. The north crane is now complete and we will now be able to continue with our diagnostic work. A plug will be set in the tubing with MIT -T, MIT -IA, and CMIT-TxIA tests to follow. T -POTS and IC -POTS have been completed and passed. Appropriate paperwork will be filed with our action plan pending the results of this next round of diagnostics. The well will not be put on injection service until the repairs are complete and a witnessed passing MIT -IA is complete. The well remains on the monthly report. Thanks, John Oksness Well Integrity Engineer ConocoPhillips Alaska ATO -2054 Office: 907-265-1073 Cell: 907-230-7493 • • Wallace, Chris D (DOA) From: Oksness, Jolin T[Jolin.T.Oksness@conocophillips.com] Sent: Tuesday, October 22, 2013 10:35 AM To: Wallace, Chris D(DOA) Cc: Dethlefs, Jerry C Subject: Tyonek Class II Disposal Well A-12(PTD#169-099) Chris— The 4-year MIT for A-12 is due this month,however we will not be able to schedule the witnessed MIT-IA this month as the well remains shut-in since the TxIA communication was reported on 4/26/2013. Crane work on the platform has prevented slickline from getting over the well to set a plug and continue with our diagnostic and repair strategy. The north crane is now complete and we will now be able to continue with our diagnostic work. A plug will be set in the tubing with MIT-T,MIT-IA,and CMIT-TxIA tests to follow. T-POTs and IC-POTs have been completed and passed. Appropriate paperwork will be filed with our action plan pending the results of this next round of diagnostics. The well will not be put on injection service until the repairs are complete and a witnessed passing MIT-IA is complete. The well remains on the monthly report. Thanks, Jolin Oksness Well Integrity Engineer y� ConocoPhillips Alaska �.p ACHED DEi 2 L0��`' ATO-2054 �,h• Office:907-265-1073 Cell:907-230-7493 1 • • Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878 @conocophillips.com] Sent: Thursday, June 30, 2011 6:15 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Dethlefs, Jerry C; NSK Well Integrity Proj; NSK Problem Well Supv Subject: NCI A -12D Annual Surveillance Report (169 -099) DIO 17 Attachments: NCI A- 12Dpdf.pdf Tom, The follow surveillance information is provided as required in DIO 17 Rule 4. NCI A -12D (169 -099) is permitted for class II disposal fluids and has had an estimated 57975 bbl of class II fluids, primarily produced water injected in the last 12 months. When in service the average injection pressure is approximately 1400 psi. While the well is shut in well head pressure is zero. Inner annulus pressure is approximately 500 psi and ranged from 420 to 760 psi during the year. The maximum recorded daily injection volume was 1001 bbls. See the attached Surveillance Plot showing injection tubing pressure, injected volumes and inner annulus pressures. No anomalous injection results were noted on this well during the year. Please let me know if you require any additional data. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 Cell (907) 943 -1687 NN JUL 1 ] 2011 7/1/2011 S N A -12D Start tring Date ame 7/1/2010 Days 365 End Date 7/1/2011 IA Cook Inlet Production & Pressure Data OA — WHP WHT 1600 , 200 1400 1111.11Mr1M111d111" •N•11••L •' 1• • •• . • • • •s •• • " • . • gi p 4 ■ ■ . • • • • • • w • • - 180 • - 160 1200 • • - 140 • 1000 - 120 N VI 800 - cu 111111 � III ___ 11 600 _ ''1 P' W 1 w-i U V A I I I - 60 400 - 40 200 - 20 I 0 •wrwwrwuw 0 Jul -10 Aug -10 Sep -10 Oct -10 Nov -10 Dec -10 Jan -11 Feb -11 Mar -11 Apr -11 May -11 Jun -11 Gas Vol Water Vol — InJ Vol • 1200 - .. -- -- - -._ . _ _. -- - - 1.2 1000 -- - • -- • • - 1 n 800 -- •— • • • • - • -- --0•— - -- - -- ••• - 0.8 soo • •• • • • • • • •- - as 2 a ao � • • •• " j • • • • r • • • • • • • • ♦ • o.a 12 zoo • • — - -. _ -- • -02 • o ° Jul -10 Aug -10 Sep -10 Oct -10 Nov -10 Dec -10 Jan -11 Feb -11 Mar -11 Apr -11 May -11 Jun -11 Date Wallace, Chris D (DOA) From: Regg, James B (DOA) Sent: Friday, May 17, 2013 6:00 PM To: Dethlefs, Jerry C Cc: Ortwein, Matt (Fircroft); Buck, Brian R; Wallace, Chris D (DOA) Subject: RE: Request to inject into Tyonek Class II disposal well A-12 Attachments: WSR 17-05-2-13.png Based on results of diagnostics performed to date, CPAI is approved to put NCIU A-12 (PTD 1690990) back into disposal service until Monday, 5/20/13 to perform additional diagnostics. Notify us (aogcc.inspectors@alaska.gov) immediately if you encounter unexpected annular pressures or injection rates. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Dethlefs, Jerry C[ma iIto: Jerry.C.Dethlefs@conocophiIIips.com] Sent: Friday, May 17, 2013 2:42 PM To: Regg, James B (DOA) Cc: Ortwein, Matt (Fircroft); Buck, Brian R; Dethlefs, Jerry C Subject: Request to inject into Tyonek Class II disposal well A-12 Jim: As per my call today, Tyonek Class II disposal well A-12 (PTD 169-099) has been shut-in since the previous report to the AOGCC on 4/26/13 (see below). Today a diagnostic technician was able to perform an MITIA to 2000 psi and it passed. Packoff testing also passed. The platform is just starting crane refurbishment and wireline work will not be able to be performed for approximately 4 months. Due to the crane issue, we are unable to set a plug to test the tubing separately. For the time being, all injection is routed to Class I disposal well A-13. CPAI would like approval to put A-12 back on injection over the weekend to see if communication exists or the pressure fluctuations were a thermal response. We will get in contact again on Monday to report on the well's performance and discuss a plan forward. Although A-13 appears to be working OK, having a backup well ready to go is highly preferable to the alternatives over the next few months. I do not have the MITIA test results on an official MIT form, but the pressures are listed in the attached Well Service Report. Thanks for you consideration of this request. Jerry Dethlefs ConocoPhillips Well Integrity Director 907-268-9188 04/26/13: Subject: Suspected communication on NCIU A-12, PTD# 169-099 Chris: This email is to serve as notice of suspected communication between the disposal string and the Inner Annulus of NCIU A-12 (PTD# 169-099). Yesterday, during a daily injection of disposal fluids down the disposal string of A-12, we observed the pressure on the IA increase to 1,155 psi. We have isolated the disposal string of this well and will not inject until further diagnostics and repairs can be made. Disposal fluids will be injected into permitted disposal well NCIU A-13 (PTD# 192-106). IA pressure on A-12 will be bled off and monitored. This well is a dual completion well with a 4-1/2� production string and a permitted class II 2-7/8� disposal string. The IA does not track when on production so the well will continue on production only. Attached is a well schematic and a plot of the T/IA/OA pressures. Following well diagnostics, appropriate paperwork will be submitted for any planned repairs to the well. Please let me know if you need any further information. Thanks, Jolin Oksness Wallace, Chris D (DOA) From: Oksness, Jolin T[Jolin.T.Oksness@conocophillips.com] Sent: Friday, April 26, 2013 10:28 AM To: Wallace, Chris D (DOA) Cc: Buck, Brian R; Arbelovsky, Steve F; Ortwein, Matt (Fircroft); Dethlefs, Jerry C; NSK Problem Well Supv Subject: Suspected communication on NCIU A-12, PTD# 169-099 Attachments: NCI A-12.pdf; A-12 field portal_plot.pdf Chris — This email is to serve as notice of suspected communication between the disposal string and the Inner Annulus of NCIU A-12 (PTD# 169-099). Yesterday, during a daily injection of disposal fluids down the disposal string of A-12, we observed the pressure on the IA increase to 1,155 psi. We have isolated the disposal string of this well and will not inject until further diagnostics and repairs can be made. Disposal fluids will be injected into permitted disposal well NCIU A-13 (PTD# 192-106). IA pressure on A-12 will be bled off and monitored. This well is a dual completion well with a 4-1/2" production string and a permitted class 11 2-7/8" disposal string. The IA does not track when on production so the well will continue on production only. Attached is a well schematic and a plot of the T/IA/OA pressures. Following well diagnostics, appropriate paperwork will be submitted for any planned repairs to the well. Please let me know if you need any further information. Thanks, Jolin Oksness Well Integrity Engineer ConocoPhillips Alaska ATO -2054 Office: 907-265-1073 Cell: 907-230-7493 Conoa;` hillips Alaska. tlx:. •-• Well Coni : -NCI A-12.11/2 Schemetic - Ac ANGER,51 NIPPLE, 2. CONDUCTOR, SAFETYV1-V.I36 CONDUCTOR, 301-1,800 SEAL ASSY. NIPPLE. 3.103-- _ MULESHOE, 3,101 PACKER 3200 RPERF, ].200-3,320 PERF, .370 SEAL ASSY. 3.108 PACKER, 3,500 WLEG, 3,50) SBE, 3,5w IPERF. 3.558-31550 IPERF. a,5TT3,50) IPERF. 3S.- A. SEAL, 3.)50 PACKER. 3,751 4.1— 11 IPERF. 4,11&1,124 attt Vt-5E� 5.3 5.414 RPERF. SEAL S43e, SEAL, 5,11) PACKER, 5,448 RPERF, ERT. 6A00.6p0 RPERF,. RPERF. 5.5145,52 RPERF. 5,532-6,610 RPERF, 5,5 RERF,RPER1 - 5,6 RPERF, 05e2 SLEEVE -C,, S., RPERF, NIPPLE, 6.)5) WLEG, S,)fie RPERF. UG'=RF.PL FI RPERF,, e,oese,aee RPERF. 0,130-0,150 RPERF. e,180E,10e RPERF, 0,330-0,330 RPERF, RPERF. e,fia3e,fi1) RPERF. 0,e11-0,010 RPERF, 0)18-0, RPERF. — RPERF. quG'UG, oS CAR PLee30 CMT RNeiner. 8.833 SURFACE. 11-0,850 CMT PLW. B.ew CMT PLW, ).110 CM II.w 1.800 CMT RMelnx, 885 PRODUCTION, 7,30612.032 CRIT RUG. ABB T0, t11 A10 SAK NCI A-12 Well Attributes D TD _ Wellbo API/UWI Field Name _ _ _ _ Well Status Incl MD (f1K8) Act Btm (ftKB) 508832003200 COOK INLET .0 PROD 56.00 10,985.01 14,910.0 Comment H2S (ppm)Date Annotation End Data KB•Grd (11) Rig Release Date SSSV: NIPPLE Last WO: 11/1/1997 5/11/1970 Annotation Depth(ftKB) End Dale Annotation Wat Mod By End Data Last Tag: WLM 4,845.0 5/31/2009 Rev Reason: WELL REVIEW osborl 11/262012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String... String Top Thrd CONDUCTOR 30 28.000 41.0 381.0 381.0 133.00 H-40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 20 19.730 381.0 11990.0 1,990.0 133.00 H-40 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Third SURFACE 133/8 12.415 41.0 6,950.0 6,949.8 72.00 N-80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth if... Set Depth (TVD)... String Wt.. String ... String Top Thrd PRODUCTION 95/8 8.835 7,300.0 12,032.0 11,624.7 40.00 N-80 Tubing Strings Tubing Description String 0... 'Siring ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... Shing Wt.. String ... String Top Thrd TUBING 2.66 1.990 55.2 3,200.0 3,200.0 4.70 J-55 EUE-81d Completion Details ... T* DeP1h TrvDi Topincl Noi Too IRKBI (ftKB) P) Item Dascrlplion Comment ID Ini., .7j...- ---- .. —.. ......e -... F. --.T-11 ....�1 ��. ��-.. 1.... -_. -_�...1...r ... _-....e .. -... -....e ... _-....-._. ...._ TUBING 7 6.240 60.6 3,508.0 3,608.0 26.00 J-55 EUE8rd etion Details•„ TopDepth (TVD) ITop Incl Ki... Too IftKBI (ftKB) I°I Item Description Comment ID -1 n) PACKER ASSY 4 1/2 3 958 3 200 0 5 760 0 5 759.9 4 70 J 55 EUE 8rd �Rtior) Details T p Depth (TVD) Top Incl SEAL no go unit MWD PERMANENT PA XD SLIDING SLEEVE - SEAL no go unit MWD PERMANENT PA XD SLIDING SLEEVE - SEAL no go unit MWD PERMANENT PA SEAL no go unit MWD PERMANENT PA XD SLIDING SLEEVE - SEAL no go unit MWD PERMANENT PA SEAL no go unit MWD PERMANENT PA XD SLIDING SLEEVE - SEAL no go unit MWD PERMANENT PA XD SLIDING SLEEVE - SEAL no go unit, lenght ('V11 Top11 Top IftKel 11c (ftKB) (°) I Description I Comment 1 Run Date ID (Int Perforations & Slots Shot Top (TVD) BM (TVD)Dens Top IRKBI 8"lftKBl IRKBI (RKB) Zona Date (eh- Tv1» Comment 6XIOC ~SAK Phillips Alaska. Inc. '- (TVD) Ido'I WLEG, 3,50] L SBE,3,50 (PERF. 3.568 PERF.RF, E — _ PERF. -- 3.801-3.820 — - SEAL .3.)50 PACKER. 3,761 PERE. 3.820.3800 PERP 3.0 .R F PERF 3.002-3,081 SLEEVE -0I 4003 ERF a0 SEAL, 4,088 PACKER, 4.009 PERF. 4, ,098 PERF. 4.106,6,111 PERF, 4,118 ,6,124 IMF— 4' 132 — 3.e684. 0 I,ER., _. SEAL. I,1)4 — - PACKER, 4,1)5-- - IPERF, 4,1081,230 — SEAL. 4.264— - PACKER,4.255—. -- IPERF. _ 42—.202 IPERF. _ 4.298-1.3 8 SLEEVE -0.4.350--- PERF, 4,378-41390 -EUFO, SEAL.4.152 PACKER,4,453 RPERF, 4,4)54,402 SEAL, 4.589 PACKER, 4.609 RPERF 4.880 WERE, 4.9Y}1... RPERF. 1,890. RPERF, 5,010.5,025 WERE, 5,0565,05) - _ - WERE. S. u.o)0 RPERF. 5.126 WERE, RPERF, 5,1 505,15) SLEEVE -0, 5.1)6 WERE. 5.194-5201 SEAL. PACKER. WERE. 5293d,3o5 RPERF, 5,364,6.313 SLEEVE -0,5,303 RPERF. 5.3945.414 WERE. 6,ER I.— 38 SEAL. 6.44) PACKER, E 065 RF, 5,4 ISO RPERF, RPERF, 5.5113,521 RPERF, 5.5323.510 RPERF, 5.5845,5)1 RPERF, s,s RPERF, &ERE. fi6,600 sLEEVEC,S. 831 BBB�RF, NIPPLE, 5,) 1 WLEG. S)fi9 RPERRF,F. 5.)5),6,181 —. PLUG:— FISH, E F. RPERF, e,o36a.o98 RPERF, 8.13IP RPEF. RF, 8,106 WERE. 8.3308,330 RPERF, ae9 a,44e RPERF. RPERF, RFERF, RPEWERE, , _ 0,)458,)68 RPERF, 0,)908,800 CMT RUG, S.S. CMI Re1ew> SURFACE950. CMTPLUG, 8,034 CMT PLUG, ),110 CArt PLUG, 11.980 CMI Rele�d, 985 PRODUCT". , NI ],300.12,032 CMi PLVG, 1,988 TD, 1x,010 12 A-12 1, NO A-12 NO A-12 Comment 5/11/1970 NCIU Production Plot — Cl FTP Cl Prod "Ir -- Cl Gas Vol '--I GAS LIFT 10L j 35000 500 — v 30000 400 25000 20000 , ` 1 300 m i a 15000 200 v M A 10000 y n 100 a- .. 5000 'L 0 Z 0 2001 2003 2005 2007 2009 2011 2013 Pressure Integrity -'I OAP CHAP 1400 1200 1000Ui N a a 7 „ 800 ^ �0cn N h LU 0. 600 �r � i 150 a 400 y. r' :� 100 O 200 j `r 2001 2003 2005 2007 2009 2011 Tyonek A-12 30-day test cycl~ Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, April 14, 2009 2:24 PM To: 'Tyonek Supervisor' Cc: DOA AOGCC Prudhoe Bay Subject: RE: Tyonek A-12 30-day test cycle ,~ ~~~ ~~i4`~r~~j Page 1 of 1 You may combine the SVS test on A-12 with the 90-day platform-wide SVS testing due on or about May 6. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 ~, From: Tyonek Supervisor [mailto:tyksupv@conocophillips.com] Sent: Tuesday, April 14, 2009 1:27 PM To: Regg, James B (DOA) Cc: NSK Prod Engr Specialist; Tyonek Supervisor; Micciche, Peter A Subject: Tyonek A-12 30-day test cycle Jim - Tyonek Platform has an upcoming 30-day test of the SVS on Well A-12 on 4-20-09 and an upcoming 90-day platform-wide SVS test on 5-6-09. As we discussed, would you please indicate your concurrence that ConocoPhillips does not need to perform the 30-day test on A-12 because of the close proximity of these two dates. Thanks in advance, Kenny Schramko Tyonek Platform Supervisor 907-776-2073 4/ 14/2009 Well Name Pre 2008 Survey Location NAD27 ASP 4 Northing Easting Post 2008 Survey Location NAD27 ASP4 Northing Easting Distance Moved NCI A-01 2,586,726.69 332,100.19 2,586,726.40 332,102.26 --- 2.09 -- NCI A-02 2,586,722.85 332,108.29 2,586,721.16 332,111.27 __ _ 3.43 NCI A-03 _ 2,586,728.60 _ 332,106.22 2,586,728.31 __ 332,109.43 _ _ 3.22 _ NCI A-04 2,586,719.62 332,105.09 2,586,718.58 332,108.09 3.18 NCI A-05 2,586,725.55 332,110.17 2,586,725.14 332,111.79 1.67 NCI A-06 2,586,719.66 332,102.09 2,586,719.22 332,104.19 2.15 NCI A-07 2,586,727.79 332,103.73 2,586,728.78 332,105.40 1.94 NCI A-08 2,586,720.56 332,098.31 2,586,722.44 332,101.65 3.83 NCI A-09 2,586,666.58 332,039.08 2,586,667.35 332,040.44 1.56 NCI A-10 2,586,670.21 332,040.91 2,586,673.71 332,044.17 __ 4.78 _ NCI A-10A 2,586,670.21 332,040.91 2,586,673.71 _ 332,044.17 4.78 NCI A-11 __ 2,586,670.23 ___ 332,039.14 __ 2,586,677.01 __ 332,041.75 ___ 7.27 ____ _ NCI A-12 _ 2,586,722.73 331,947.80 2,586,723.59 _ _ 331,994.15 46.36 __ NCI A-13 2,586,734.88 __ 331,993.50 _ 2,586,733.15 331,995.48 2.63 NCI B-01 2,586,730.03 331,999.80 2,586,723.04 331,998.16 7.18 NCI B-01A 2,586,730.03 331,999.80 2,586,723.04 331,998.16 7.18 NCI B-02 2,586,731.14 331,999.29 _ 2,586,729.60 332,001.86 3.00 NCI B-03 _ 2,586,731.69 331,986.37 2,586,726.81 331,991.70 7.23 NCI B-03P61 2,586,731.69 331,986.37 2,586,726.81 331,991.70 7.23 ,(~-~ - C~ ~ a~R Q 4 20d~ e ~~P_.~ ..____. r~ REV DATE BY CK APP SCRIPTION REV DATE BY CK P DESCRIPTION I 2/29/08 $A $ K WA MODIFY WELL HOUSE SCHEMA TIC, SHT.2 ADD MUD LINE ELEV., SHT.3 ?o ~ ~ 36 31 T 12 N 31 32 ~s ~ ~~ z ~~ 1 s ~ T II N s e N ~, Ro s. ro•~s• IY") SE . 6 1206' ~ SCALE: I"-1320' --6 -- ~ ~ o ~ ~ 1 6 6 5 12 7 ~ g GENERAL NOTES: ~~~~ OF ,q~ ~~~, ~~~~~"~ I. SEE SHEET 3 FOR COORDINATE TABLE i '~P •'~~~ ••''~`S~-~~~ ~ •~'. ` • 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND ~ •° Y ~j ~ ~ ~ ~ ~ ~ VERTICAL SURVEY DATA 49th % j ~ : 3. SECTION LINES AND TIES ARE BASED ON PROTRACTED ~ ""''""""""""""""""""""""" j VALUES. ~. ................................ .....i ~• c % KENNETH W. AYERS ~: • ~ ~• J'~. =,• LS-8535 ~,' ~, i SURVEYOR'S CERTIFICATE P •,,' A ••~ I~ ROFESSIONP~~ ~~ I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND ~~~,""~~~ LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DONE BY LOUNSBURY DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF & assoclaTES, INC. FEBRUARY 28, 2008. SURVEYORS ENGINEERS PWNNERS ~~ PHONE: (907J 272-5451 AREA: MODULE: UNIT: ConocoPhilli s NORT" C°OK INLET TYONEK PLATFORM Alaska, Inc. WELL CONDUCTOR AS BUILT CADD FILE N0. DRAWING N0: PART: REV: 08-005 AS BUILT 02/27/08 ~8~~5 /~S BU~L_T 1 of 3 1 i REV DATE 6Y CK APP SCRIPTION REV DATE BY CK P DESCRIPTION 1 2/29/08 SAS KWA MODIFY WELL HOUSE SCHEMATIC, SHT.2 ADD MUD LINE ELEV., SHT.3 v ~ ~r ~ ~` ¢ ~ 9 iW w9 60 s. 9'~' ~S sca a y~ ~j o ~~ `ss SCALE: 1"-30' a9 AA ESD 600 50 - ESD 600-51 A13 • Ip •B2 AB A•A• 83 : •p5 • A3~ 46 A12 BI : •A5 ' A4 • A2 WELL HOUSE 2 'p O ~ zp A~~ LEGEND: 9 ~ WELL p WELL CONDUCTOR 0 ESD (EMERGENCY SHUT OFF VALVE) GENERAL NOTES: I. SEE SHEET 3 FOR COORDINATE TABLE 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND VERTICAL SURVEY DATA LOUNSBURY 3. NO WELLS EXIST IN WELL HOUSE N0. 4 , AND IT WAS NOT & assoclaTES, irrc. AS BUILT SURVEYORS ENGINEERS PLANNERS 907 272 ~ P E 1 HON -5451 : ( AREA: MODULE: UNIT: ConocoPhilli S NORTH COOK INLET TYONEK PLATFORM Alaska, Inc. WELL CONDUCTOR AS BUILT CADD FILE N0. DRAWING N0: PART: REV: 08-005 AS BUILT 02/27/08 08 -005 AS BUILT 2 of 3 1 J 12/29/08 $Q$ {~wQ I I MODIFY WELL HOUSE SGHEMATIG, SHT.2 ADD MUO LINE ELEV., SHT.3 DATE ASP ZONE 4, NAD83, FEES NAD83 C~ OC~iAPHIC MLLW DESCRIPTION (POINT NO.) NORTHING FASTING LATITUDE LONgTUDE ELEVATION NqU W ELL TAG NO. WELL HOUSE NO. 1 1001 2586492 1472018 61 04 34.38 150 57 03.71 72.0 Conductor 1 1002 2586489 1472017 61 04 34.34 150 57 03.72 73.9 B3 1003 2586485 1472019 61 04 34.31 150 57 03.67 74.1 A12 1004 2586485 1472023 61 04 34.31 150 57 03.59 73.8 B1 1005 2586487 1472027 61 04 34.33 150 57 03.52 72.0 Conductor 5 1006 2586491 1472027 61 04 34.37 150 57 03.52 73.7 B2 1007 2586495 1472025 61 04 34.41 150 57 03.57 72.1 Conductor 7 1008 2586495 1472021 61 04 34.41 150 57 03.65 73.7 A13 WELL HOUSE N0.2 2001 2586437 1472060 61 04 33.84 150 57 02.83 71.9 Conductor 1 2002 2586433 1472059 61 04 03.38 150 57 02.84 71.9 Conductor 2 2003 2586430 1472062 61 04 33.77 150 57 02.79 71.8 Conductor 3 2004 2586429 1472066 61 04 33.77 150 57 02.71 73.4 A9 2005 2586431 1472069 61 04 33.79 150 57 02.65 71.9 Conductor 5 2006 2586435 1472069 61 04 33.83 150 57 02.64 73.3 A10 2007 2586439 1472067 61 04 33.86 150 57 02.69 73.3 A11 2008 2586439 1472063 61 04 33.87 150 57 02.77 71.9 Conductor 8 WELL HOUSE N0.3 3001 2586488 1472128 61 04 34.36 150 57 01.47 73.0 Al 3002 2586484 1472127 61 04 34.32 150 57 01.48 73.1 A8 3003 2586481 1472130 61 04 34.29 150 57 01.43 73.1 A6 3004 2586480 1472133 61 04 34.28 150 57 01.35 73.0 A4 3005 2586483 1472137 61 04 34.31 150 57 01.29 73.0 A2 3006 2586487 1472137 61 04 34.34 150 57 01.28 73.0 A5 3007 2586490 1472135 61 04 34.38 150 57 01.33 73.0 A3 3008 2586490 1472131 61 04 34.38 150 57 01.41 73.3 A7 50 2586540 1472069 61 04 34.86 150 57 02.69 72.7 ESD Valve 600-50 51 2586501 1472011 61 04 34.46 150 57 03.86 72.6 ESD Valve 600-51 100 2586572 1472123 61 04 35.18 150 57 01.58 115.3 Top center helipad -101' MUD LINE SURVEY NOTES: 1. ALL COORDINATES ARE ASP ZONE 4, NAD83, US SURVEY FEET. GEOGRAPHIC COORDINATES ARE NAD83. 2. ELEVATIONS ARE IN FEET, BASED ON MLLW, REFERENCED TO DRAWING N0. MPD- TY04-2021, SHEET I OF I, REV. 2 3. ALL AS BUILTS ARE TO THE CENTER OF EXISTING STRUCTURE. 4. WELL CONDUCTOR ARE VERTICALLY AS BUILT TD THE TOP OF A 1/4" STEEL LID, TACK WELDED TO THE TOP OF THE CONDUCTOR. 5. WELLS ARE VERTICALLY AS BUILT TO THE TOP OF THE LOUNSBURY LOWEST HORIZONTAL FLANGE ON THE WELL. & nssoc[nTES, INC. SURVEYORS ENGINEERS PLANNERS D PHONE: 1907) 272-5451 AREA: MODULE: UNIT: ConocoPhillips NORTH C°OK INEET TYONEK PLATFORM Alaska, Inc. WE~~ CONDUCTOR AS BUNT CADD FILE N0. DRAWING N0: PART: REV: 08-005 AS BUILT 02/27/08 08-005 AS BUILT 3 OF 3 1 MEMORANDUM ) TO: Jim Regg \01 I. j P.I. Supervisor <'11 7(Z-b¡ 0<: FROM: Lou Grimaldi Petroleum Inspector Well Name: N COOK INLET UNIT A-12 Insp Num: mitLG050705140509 Rei Insp Num: Well P.T. Packer A-12 Type Inj. W TVD 1690990 TypeTest SPT Test psi State of Alaska ) Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 06,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA lNC A-12 N COOK INLET UNIT A-12 o CO' \ 0q" " Src: Inspector Reviewed By: P.I. Suprv,>JB.f'- Comm NON-CONFIDENTIAL API Well Number: 50-883-20032-00-00 Permit Number: 169-099-0 Inspector Name: Lou Grimaldi Inspection Date: 7/5/2005 Depth 3200 15 Min. 30 Min. 45 Min. 60 Min. 1500 I 1500 620 620 Initial 1500 Pretest 1500 IS IA OA 12 800 IS 15 IS 12 Interval 4YRTST P/F P Tubing 1230 1230 1230 1230 1230 1230 Notes: IA already pressured up when I arrived, observed for thirty minutes with no decline. Bled IA to 620 psi (no gas-fluid packed) and observed for additional thirty minutes. Wednesday, July 06, 2005 SÇ/\NNED J\UG 0 92005 Page I of I Sf^T£()rÄV.öŸ¿~ ~S~ OIL AN~~ CONSERVATlØN COMMISSION .~lm.t'i~Tê$t Eo.MàItijÆ'Tô~1..~9~~~.,~~~~!i~J~i.~Þ.ìL~t~elÞ>~in~~;~;U$·! OPERAT()R: . conocophiRips FIELD UNIT J . PAD: NC(U.ð~12 £?fsposa1 Strfn¡¡ . DATE: JtjIy 5..2005 r:"':!~~::::;:1::';J,::/r: i:~:·iji::1:~ ~:V:: ¡::¡: :'::, ..:' '~r i·:rr.:·:;:;:~~:i::~~~.:.~~} ::::~~:;" ~:t." . ,.,.' ,. ": ~.: . ~ ' .. Ii. " rNJ., TaT:::, .... : ,,,1YO: " : . .... ¢A$NG: . ,.' ~ .. TEST;.· . CSG· . .: TaG··. 11J$.;... TBG· .: ST~ .p F ~ ":, .~Q.;;'·:).h:'~:',r~~t~~·; :¡:; :!:~L:j¡::~f~i~i·~1.~:::~>; =::' ~J.~.;.:.:iM~: ::; . .: .' : ~ w~~t~.. ;.. .~. =~. }:' , 1~'3IB~I72MN-802~·' ~ ' :::~'~~:" ;:~~., ;;:' . O~5- P ..,< COMMENTS: Well obsetVed as found, AppsnJnf competent IA casi~ OA 15 1 S 15 '5 A-12 ;s a _d~: lion well, PermJt18~ Class' U DisPOS,BI in 2 718- fbg et 32Bû'-3370' Gas Produclion in 4 112" t, bfJ. , 'from NCIU, . PTD~ GIycoI·7()Ð¡(3,200 . 1,230 .. . 1,230 . .1,239' 1,235 Well .: .\-12 : S p lWater 3(y~200 133/8" /72#/ ~D 2318. '800. 1,5f)O 620 620 620" -. 1050 P .. . I . _ - ... ,.. _. ill COMMENTS: Second portion aftest, BJeed IA to 62D psi and observe for OA 15 1 ~ 12 -'12 possfbI8 buildup ffom tubing leak. Appørent ~pètent tubing 0-4 . D.. o o N ('Y) f- W r¡ ~ w en cc ..J a.. :r TBG. INJ. FLUID CODES F :; FRESH WATERrNJ. G ::: GAS JNJ. 5 = SALT WATE'R INJ. N = NOT INJECTING E a: ('I) (\ Dlstdbutioo¡ orlg . Well fie c·~~ c . Database c· Trip Rpt FIe c - trispector .. 0) In o o N to o ..J ;:) " Sheet revlsedbyLG.·S/6IOO '~fb" ~c '.' ~~ -~ - y.:_-::._--- --:", C .,; '.' '-':C~..è..~_. .... ~... -' .' - .,. -. "l- ::_~~:. -_.-' _-.:...,p,,, 0__ -- Tr;sr1'X~t ... ....... _ .,< . . M:::ANNUlUS MoNITORING P=S1p A~UlUS PRESSURE TEST R=lm~ÄLRAf}i'TRÄCmsø~~; A;:;;TEMPEAATUR£:AN_{ti.t~t . ...... 0= DIFFERENTIAL TEMPERATURE TEST OÞERAt:QRf!EI"SI~".A··· "'~R:ÆJlfÔ}~IU~~~G. iØlØp DIEseL GL Ycot 9.2 SALT WATER 8.5 DRiLLING MUD OTHER ,AOGCCREPSIGNATURI: .'~.I.~ Louis R Grìmaldl -' ~:1'E$t; .(~ 4 . Year X WbmbYer .(¡ftþ~. 0.48 0.44'''''' .'> ijCAr\JNEL JUL 1 2 2005 MJ1~JJ:~12:fl~1~~ il~ (' I <0 q..- ó Cf9 ConocriPhillips Len G. Janson Senior Production Engineering Specialist Cook Inlet Area P.O. Box 66 Kenai, AK 99611 (907) 776-2046 June 29, 2004 Jim Regg Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue, Suite 100 Anchorage, AK 99501 RE: Annual Performance Report, Disposal Injection Order 17 NCIU We1l12-A Tyonek Platform 2003 Dear Mr. Regg: Rule 4 of the above listed injection order requires that ConocoPhillips file an annual report evaluating the performance of the disposal operation. NCro Well A-12 was utilized for disposal throughout 2003. During this period, 26,094 barrels of fluid were disposed, with no abnormal conditions noted during the injection program. Please do not hesitate to contact me at (907) 776-2046 should you have any questions or need additional information. . ~ Sincerely, ~.¿/ '- //;~ ,,/' .,/ / . / ." ¿ '::rV+-('t~ '. ///1 ~IJi6' ---- t/:..,// Senjøf Production Engineering Specialist /l' RECEIVED JUN 3 0 2004 Âlaska Oil & Gas Cons, Commission Anthoragí3 SCANNED OCT 1 02004 r W; f\-j'¿ lviollltormg uam !.-'-""U I f. l..IU..;S " r'\ ~ Hi Jim- It looks like outer annulus monitoring commenced more recently than the data I originally provided. I can add this to the summary table- in the mean time operators indicate the reading has been zero consistently. Shannon -----Original Message----- From: Thornton, David N Sent: Monday, April 26, 2004 To: Donnelly, Shannon Subject: RE: A-12 Monitoring 7:09 AM Data Shannon, A-12 was the last well we got a outer annulus guage on. As of 3-25-04 we have been putting the outer annulus pressure on our morning report. Just a note, it has been zero. If you need more info let me know, you know where I am. David for A-12 -----Original Message----- From: Donnelly, Shannon Sent: Monday, April 26, 2004 To: Thornton, David N Subject: FW: A-12 Monitoring 6:33 AM - $~ bùcs tor \)To 17tOO3 Data Hi Dave- ~'^ 5~b4- Do you take any data on the outer annulus? this. AOGCC is also looking for Thanks, Shannon -----Original Message----- From: James Regg [~ailto~jim Sent: Friday, April 23, 2004 To: Donnelly, Shannon Subject: Re: A-12 Monitoring regg@admin.state.ak.us] 2:56 PM Data No outer annulus (20" x 13-3/8") pressures monitored? Jim Regg Donnelly, Shannon wrote: Hi Jim- Attached is a summary of monitoring data pulled from the Tyonek morning reports (1/1/04 to 3/31/04). We discovered a few data entry errors in the casing pressure, which have been corrected. Due to the corrections, you may see some minor differences from the numbers previously reported on the monthly reports. These will be evaluated next week and updated as necessary. Please let me know if you have any questions. 10f2 4/26/2004 8:35 AM FW: A-12 Monitoring Data r"'\ ~ Thanks, Shannon «Tyo injection qry.xls» 2 of2 4/26/2004 8;35 AM ~ \'(\ t.J V 'S"- ~ a- ç ~~ 4(- ::J"# ~~ r'\ ~ ~¡;. ,i,,'~s( rT ,0 , <Z '" , ,,' .", : ,; , ,,' '~ " < 00, ,~ ", ~Q v~ ~ ~Q v~ ~ ~Q v~ ~ ~Q Vc% ~ ~Q v~ ~ ~Q v~ .! cu ~ C ~Q v~ ~ ~Q v~ ~ ~Q v~ ~ ~Q Vè ~ ~ ~Q V~ ~ ~Q V~ ~ 0 0 ~Q 0 VÇ¿ 1.0 =-L' , ',',,:', , " r " '~, I' " .. : : ' . -:]' '" ,. , " . , 'it.;; : ".. " ",,;. ~.:o ,':1,,( ,:',>, , , , '"", ,°. ': ,"~'A""'~'c:<',.i,:", ' ':,'..;, ,,;-f::',,>,',,""::' :ic.':':,':f',~~",::;,:', ,;Of,,"':':':';::':',' . .~:,:,::,~ ~.' I~' ~'~ " :: . :;:,:y ;'1 ::..:"::;C:" :':'~ " <:~':":""'" ,;' . 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' ,,', "'" " ; "C' ,', , " .:--. fi, .. , '" '..' :,,: "::,,,' .. "",;: f" " " " " , ' ' ",..".,..,,-,'; ;-<: .. '0' ,:',X1: "', " " , 0 0 1.0 N 0 0 0 N 0 0 1.0 T"" 0 0 0 T"" (!sd) 8JnSS8Jd 4-zs..o+ ND:-lÁ- A- - \"Z-- P11::>tt- J bq -eFt? String Cd 11'11 Hl'linj Date Comments Fluid Type 11'11 Rate 11'11 Vol Whp Csg Press Last Update Dt A,12D 0, 01/01/04 12,00 AM 0 0 0 0 02/02104 03,03 PM A-12D 0, 01102/0412'00 AM 0 0 0 0 02/02104 02,59 PM A-12D 0, 011031041200 AM 0 0 0 0 02/02/04 03,34 PM A-12D 0 01/04/04 1200 AM 0 0 0 0 02/02/0403'51 PM A-12D 0 0110510412:00 AM 0 0 0 0 02/02104 03,31 PM BJ Services pumped 1732 bbls of produced H2O and 150 bbls A-12D 8 011061041200 AM ofsea water PW 5,646, 1882 1900 200 02105104 02:44 PM A-12D 0 01/07104 12:00 AM 0 0 0 0 02/02/04 03:45 PM A-12D 0 01/081041200 AM 0 0 0 0 02/02104 03:41 PM A-12D 0 01/09/041200 AM 0 0 0 0 02/02/0403'38 PM ) A-12D 0 01l101041200AM 0 0 0 0 02/02/04 03:50 PM A-12D 0, 01/11/O41200AM 0 0 0 0 02/0310401:49 PM A-12D 16 01/12/0412'00 AM 0 PW 2,856, 1904 1860 0 02103104 11,28 AM A-12D 3, 01/13104 12 00 AM 0 PW 4,768, 596 1890 0 0210310411,31 AM A-12D 0 01/141O412ooAM 0 0 0 0 02103104 01 :45 PM A-12D 0, 01/15104 12,00 AM 0 0 0 0 02/03104 01 :09 PM A-12D 0 01/1610412:00 AM 0 0 0 0 02/03104 02:39 PM A-12D 0 01/171O412:00AM 0 0 0 0 021031040244 PM A-12D 0 01/181041200 AM 0 0 0 0 02/03104 01 :58 PM A-12D 0, 01/19/0412:00 AM 0 0 0 0 02/03104 02:01 PM A-12D 6 01/2010412:00AM 0 PW 2,620, 655 2000 0 01/22/0407,25 AM A-12D 5, 01/21/04 12,00 AM No Injection PW 2,625,6 547 1950 0 01/22104 07:48 AM A-12D 2, 01/22/04 12:00 AM 0 PW 7,632, 636 2000 0 01/25104 01'30 AM A-12D 0, 01/23/0412:00 AM No Injection 0 0 0 01/25/0401:27 AM ) A,12D 0 01/24/0412'OOAM No Injection 0 0 0 01/25/0412:22 AM A-12D 9 01/251O412ooAM 0 PW 3,061,33 1148 1900 0 01/26/041213 AM A-12D 5 01/2610412 OOAM 0 PW 2,764 8 576 1900 0 02/05104 02'42 PM A-12D 0 01/27/0412:00 AM No InjeeIJon 0 0 0 01/281O412:05AM A-12D 0 01128/041200 AM No fluids Injected, 0 0 0 01/29104 01'48 AM A-12D 0 01/29/0412 00 AM 0 0 0 0 02/03/0409,11 AM BJ Services Injected 566 bbls of produced H2O and 120 bbls of A-12D 5 01/30/0412 00 AM sea H2O, PW 3,2928 686 1675 0 01/31104 07:52 PM A,12D 0 01/31/04 12,00 AM No fluids injected, 0 0 0 02/01104 12 05 AM A-12D 0 02/01/0412'00 AM No fluIds Injected, 0 0 0 02/02/04 12:55 AM A-12D 0, 02/02/04 12'00 AM No fluids Injected, 0 0 0 03/10/0402'02 PM A-12D 0 02/03104 12 00 AM No fluids Injected 0 0 0 03/10/04 02 06 PM A-12D 0 02/04/04 12,00 AM 0 0 0 0 02/05/040216 AM A-12D 11, 021051041200 AM 0 PW 3,654,54 1675 1930 0 03/08/04 04:43 PM A-12D 1 02I06IO4 12 00 AM 0 PW 3,144 131 1900 0 03108104 04.44 PM A-12D 4, 02l07/O412,OOAM 0 2,556 426 1900 0 03108/04 04:45 PM INJ-1 4 02/07/0412,00 AM 0 PW 2,556. 426 1900 0 04123104 01: 11 PM A-12D 0 02/08/O412:00AM 0 233 1900 0 02/09/04 02:52 AM INJ-1 0 02/08/04 12,00 AM 0 PW 233 1900 0 04123104 01.12 PM ) A-12D 0, 02/09/04 12,00 AM 0 5 1900 0 02/10/041239 AM INJ-1 0 02109/041200 AM 0 PW 5 1900 0 04123104 0113 PM A-12D 12 02/10/04 12 00 AM This was B,J Injecting with their pump PW 3,290 1645 1930 0 02111/04 12:56 AM A-12D 0 02l11/0412,OOAM 0 0 0 0 02126/04 09:02 AM A,12D 0, 02/12/04 12'00 AM no water Injected today 0 0 0 02126/04 09:03 AM A-12D 0 02113/04 12'00 AM 0 0 0 0 02126/04 09:04 AM A,12D 5, 02114/0412 00 AM BJ Services Injected 1014 barrels of produced water, PW 4,8672 1014 1835 0 02126/04 09 04 AM BJ Services injected 697 bbls of produced water and 200 bbls of A-12D 4,25 02/15/041200 AM sea water PW 5,06541 897 1840 0 02126/04 09:05 AM A-12D 0, 02116/04 12:00 AM 0 0 0 0 02126/04 09,06 AM A-12D 0,75 02117/04 12:00 AM BJ Services Injected 155 barrels of produced water PW 4,980, 155 1850 0 02126104 09:07 AM A-12D 6,7 02l181O412,OOAM 0 PW 4,71402 1316 1850 0 02126/04 09 08 AM A-12D 2 02119/04 12:00 AM Using our Injection skid PW 1,164, 97 1150 0 03/01/0402:09 PM A-12D 95 02120/04 1200 AM Using our Injection system PW 939,78 372 1140 0 02128104 09:09 AM ) A-12D 05 02121/0412'00 AM Water Injected by BJ only PW 3,480 72 1200 0 02126/04 09:10AM A-12D 3, 0212210412:00 AM BJ Injected 172 bbls / Producbon Injected 134 bbls, PW 2,448, 306 1800 0 02126/0409'11 AM A-12D 4 02123/04 12 00 AM All Injected by BJ PW 3,000 500 1770 0 02126/04 0912 AM A-12D 2 02124/04 12:00 AM All PW Injected WIth our skid, PW 900 75 1100 0 02126/04 09'13 AM A-12D 0 02125/04 12,00 AM No fluids Injected, 0 0 0 02127/041242 AM A-12D 0 02126/04 12,00 AM No fluids Injected 0 0 0 02l27/O412'35AM A-12D 0 02127/0412:00AM No fluids Injected, 0 0 0 021281041225 AM A-12D 02 02128/04 12 00 AM BJ Services Injected 29 bbls of KCL fluid from B-1 coil tubing job, PW 3,480 29 1400 0 03/01/04 02 05 PM BJ Services Injected 221 bbls of well bore fluIds and 1179 bbls of A-12D 7 02129/04 1200 AM produced water, PW 4,800, 1400 1770 0 03110/04 0315 PM BJ Services Injected 252 bbls of produced water and 100 bbls of A-12D 175 0310110412:00 AM sea water, PW 4,82742 352 1840 0 03/02104 1233 AM A-12D 0 03102/04 12,00 AM No fluids injected, 0 0 0 03103104 12,36 AM A-12D 0 03/03104 1200 AM No fluids injected, 0 0 0 0310410412:19 AM A-12D 0 03/0410412:00 AM No fluids Injected 0 0 0 031051041242 AM A-12D 1.5 03105104 12 00 AM No BJ Injecbon PW 2,240, 140 1950 0 03/08/0404,55 PM A-12D 0 031O61O412,ooAM BJ Injected_1055_Bbls In 8_hrs, Wellinjecbon Press_1900 0 0 0 03108104 04'51 PM BJ Injected 800 Bbls in 6 hrs, WIth a tubing pressure of 1900 A-12D 0 03107104 12:00 AM pslg 0 0 0 03108104 04:49 PM A-12D 3 03lO8IO412:00AM 0 PW 2,384, 298 1100 0 03109/0412:05 PM A-12D 35 031O9/O412,ooAM 0 PW 2,21485 323 1900 0 04/23/O410:12AM A,12D 10, 03/10104 12:00 AM 0 PW 986.4 411 1700 0 04/231041011 AM ) A-12D 625 03/111O412:00AM 0 PW 1,10976 289 1200 0 04/231O41009AM A-12D 10 03/121041200 AM 0 PW 1,0032 418 1200 20 03/13104 12:31 AM Platform Injected 27 bbls prod fluid BJS injected 300bbls coil A-12D 25 03/13/04 12,00 AM tubing cleanout fluids and 100 bbls of seawater, DF 4,0992 427 1200 20 03/1410401:20 PM BJ pumped 351 barrels of produced water and 100 barels A-12D 2, 03/141041200 AM seawater for flush PW 5,412, 451 1735 0 03/151O41219AM BJ Injected 142 barrels dnlling fluid 900 barrels produced water A-12D 625 03/15/04 1200 AM and 100 barrels seawater PW 4,385,28 1142 1800 20 03/161041227 AM A-12D 2 03/16/0412,00 AM Injected 230 bbls dniling fluid and 200 bbls seawater DF 5,160, 430 1800 20 03/17104 1241 AM A-12D 1 03/17/0412'ooAM BJ Injected 45 bbls of well bore fluid and 100 bbls of sea water PW 3,480, 145 1820 0 03/1810408:28 AM A-12D 0, 03/18104 12:00 AM No InJecbon performed today, 0 0 0 03/19/0412:05 AM A-12D 0, 03/191041200 AM No Injecbon Performed Today 0 0 0 03l201O412:23AM A-12D 3 03/20/0412,00 AM Water Injected by BJ PW 2,248, 281 1900 0 03/20104 11'57 PM BJ Injected 742 BBlS, @ 1900 PSI for 5 hrs, Figures entered A-12D 4, 03121104 12:00 AM above are from our Skid, PW 882, 147 1900 0 03l2210412:03AM B-J injected 632 bbls well fluid and 900 bbls flush fluid at 1900 A-12D 8 03/22/04 12:00 AM psi. BJ Injected for 6 hours, PW 1,080, 360 1135 0 03/23104 08:38 AM Figures above are from our skid 1 BJ injected 423 bbls @ 1900 A-12D 4, 03/23104 12 00 AM psi in 3 hrs, PW 954, 159 1030 0 03/2410412:15 AM ) BJ mj 123 bbls wellbore fluids and 77 bbls sea H2O, Platform InJ A-12D 9,5 03124104 12:00 AM 355 bbls pw PW 1,402,1 555 1650 0 03/25104 0135 AM A-12D 11,5 03125104 12:00 AM Injected 500 bbls of produced water. PW 1,043.47 500 1020 130 03/26104 12'13 AM A-12D 0 03126/04 12:00 AM No fluids injected, 0 0 0 03/271O412:30AM A-12D 0 03/27/04 12:00 AM No fluids injected, 0 0 0 03/2810412:37 AM A-12D 0 03/28104 12:00 AM No fluids injected 0 0 0 0312910412,57 AM A-12D 8,5 03/29104 12,00 AM Injected 369 bbls of produced water, PW 1,041,88 369 1015 45 03/3010412:22 AM A-12D 11,3 03/30/0412'00 AM Injected 515 bbls of produced water. PW 1,0938 515 950 120 03/3110401:32 AM A-12D 0, 03/31/0412'00 AM No In¡eeIJon 0 0 0 04101104 12,51 AM ,~ ~ A OGCC Memorandum Date: April 21, 2004 From: DIO 17 Jim Regg, Petroleum Engineer 'R41. 4 ('V{ I Ot' To: Subject: Administrative Approval Request from ConocoPhillips - Beneficial Reuse of Domestic Waste Water and Treated Sanitary Waste The Commission received from ConocoPhillips a request for administrative approval under Disposal Injection Order (DIO) 17 to allow the beneficial reuse of domestic wastewater and treated sanitary effluent generated at the Tyonek Platfonn (North Cook Inlet Unit). Ms. Shannon Donnelly and I exchanged phone calls several times to clarify the request to use these effluent streams for flushing the Class ll-D well (A-12) after produced water injection. I called Ms. Donnelly and left a message requesting clarification about the injection frequency (and flush process), the estimated volume of sanitary and domestic waste streams that is generated and how much would go overboard. She returned my call and provided the following: Produced water will be injected in batches every 2-3 days; currently producing about 500 barrels water per day (this may go down as wells stabilize after the recently completed well work); Domestic waste water (1,300 gallons per day) and treated sanitary effluent (400 gallons per day) will be stored in tank (40 bbls per day); 100 balTel flushes (approximate) would follow each produced water injection; there would be flushes after each produced water injection; Goal is zero discharge for treated sanitary waste, domestic wastewater, and produced water streams except in upset and emergency situations. Second call to Ms. Donnelly later in day requested her to verbally characterize the mixing point for the domestic wastewater and treated sanitary effluent streams. I also asked if there have been any mechanical integrity testing on Well A-12 since the 11/8/01 MIT (next due 11/8/05). Ms. Donnelly returned my call and confinned the last MIT was 11/8/01. I advised it may be , appropriate to do another MIT to confinn integrity (I also recognized that there is perfonnance data from annular monitoring that may be relevant; I did not obligate an MIT but left the door open as part of our ongoing review). She agreed to check into the feasibility of doing an MIT. She also advised that the mixing point for domestic wastewater and treated sanitary effluent streams would be in the storage tank; she also clarified that domestic water is not treated prior to discharge now (and would not be prior to injection); sanitary effluent would be treated to same specs as if being discharged. f . .....,. ,-., /"'. ~ ~iUiPS Shannon Donnelly Senior Environmental coordinator Post office Box 66 Kenai, AK 99611 Phone~07)776-2092 Fax: (907) 776-2095 ' ' Email: Shannon.oonnelly@conocoPhtlhPs,com RECEIVED APR 2 1 2004 Alaska Oil & Gas Cons. Commission Anchorage April 19,2004 Jim Regg Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 Fax (907) 276-7542 RE: Administrative Approval Request for Beneficial Reuse of Treated Sanitary and Domestic Waste- Disposal Injection Order Number 17, North Cook Inlet Unit Dear Mr. Regg: ConocoPhillips is very interested in moving forward with a plan to beneficially re-use treated sanitary effluent and domestic waste (i,e, shower, sink, and galley water) at the Tyonek Platform as make up water lor necessary flushes 01 the on-board Class II disposal (A-12). The well was recently outfitted to enable real time disposal of produced water. Due to recent developments with the producing wells, Tyonek is experiencing an increase in both the volume of produced water and in the presence 01 produced sand and solids. Conducting a periodic flush 01 A-12 has been identified as an important measure in maintaining the disposal well. Maintaining the integrity of A-12 is criticai to the platform for tWo reasons. First, the well is a dual purpose well. II is bolh a producer as well as a disposal well. \I is a priority 10 avoid any complications that would interrupt production, Secondly. the increased water volumes at the platform surpass the handling capacity of the overboard produced water treatment system (OAF), forcing reliance on the injection well as the means for produced water disposal. ConocoPhillips has determined that treated sanitary effluent along with the domestic wastewater stream would be ideal make up fluid lor the Ilush operation. providing an efficient means to prevent the accumulation of solids and remove corrosive agents from the well tubing. ConocoPhillips is seeking an administrative approval from the Commission in support of this proposal. In the absence of an administrative approval, seawater will be used lor the flush operation (due to cost 01 obtaining Iresh water), although it is less desirable due to its own corrosivity. Beneficial re-use of the sanitary and domestic waste streams represents a positive step forward in terms of pollution prevention, in allowing the facility to eliminate two waste streams currently discharged to the environment. It is a creative solution to two challenges, in providing a means to obtain clean water for well maintenance while minimizing potential issues associated with overboard discharge. . . ,r--... r'\ April 19, 2004 Page 2 ConocoPhillips has considerable documentation regarding the quantity and quality of the sanitary and domestic streams over time and can provide verification that they are clean, non- hazardous, waters that constitute a reasonable alternative to fresh or seawater. A summary of the past two years' monitoring data collected for treated sanitary effluent under the NPDES permit is attached for your reference. Historically, both of these streams have been discharged to Cook Inlet as authorized under the Cook Inlet General NPDES permit (AKG285011). The sanitary treatment system would continue to be managed "on-spec" to meet NPDES discharge criteria in the event it were necessary to discharge the fluid rather than re-use it at any point. The volume of domestic and treated sanitary effluent generated at the platform is compatible with the volume required to conduct an appropriate overflush procedure. The fluid would be appropriately conditioned with biocide and oxygen scavenger to properly fulfill its overflush function. The necessary piping modifications can be made with a minimal investment of resources, and this approach could afford a nearly immediate solution to water management concerns. Thank you very much for your consideration of this proposal. Please do not hesitate to contact me (907) 776-2092 should you have any questions or additional information needs. Sincerely, ~~ Shannon Donnelly Environmental Coordinator ConocoPhillips Alaska, Inc. . , ,r--.... ,~ .. Bee: Len Janson Kenai Files: L3-73 (4-10) . . ' . r'\ ~ Tyonek Platform Sanitary Effluent Routine Monitoring Results 2002 and 2003 Summarized for Discharge Monitoring Results Submitted to EPA under Permit Number AKG285011 Month TSS BOD Total Residual (average mg/L) (average mg/L) Chlorine (average mg/L) January 02 12 19.4 4.1 February 02 14 21.6 7.4 March 02 40 8.8 5.2 April 02 9 14.3 1.1 May 02 13.5 10.2 1.5 June 02 9 8.1 1.6 July 02 3 1.8 2.2 August 02 9 21.8 1.6 September 02 11 11.1 1.7 October 02 6 8 1.0 November 02 6 10 .6 December 02 8 7.4 1.5 January 03 18.5 13.4 .9 February 03 18 9.8 1.2 March 03 10 7.6 1.9 April 03 11 7.7 1.3 May 03 14.0 7.0 1.7 June 03 11.0 12.1 1.7 July 03 37.4 27.8 1.8 August 03 15.5 5.6 2.9 September 03 11.5 19.1 4.3 October 03 13.4 22.6 3.9 November 03 28.3 23.0 4.0 December 03 26.7 24.1 3.2 AVERAGE 14.8 13.4 2.4 Sanitary Effluent Data Summary Tyonek A Platform NPDES Permit Renewal Sampling Results (mg/L unless otherwise noted) Parameter 6/9/2003 6/11/2003 6/13/2003 8/4/2003 8/8/2003 AVG Ammonia-N 5.14 2.20 2.63 0.533 0.958 2.2922 Antimony 0.001 U 0.001 U .001U Arsenic 0.00742 0.00424 0.00469 0.0073 0.00712 0.0062 Barium 0.0113 0.0105 0.0109 ( Beryllium 0.004 U 0.004 U .004U Cadmium 0.0005 U 0.0005 U .005U Chlorine 1.54 2.20 2.50 2.0800 Chromium 0.000716 0.001 0.0009 COD 47.1 42.7 38.4 42.7333 Copper 0.0636 0.0558 0.0577 0.0598 0.0628 0.0599 Cyanide 0.007 0.006 0.004 0.017 0.014 0.0096 DO 7.70 7.35 8.6 8.55 7.75 7.9900 Fecal Coliform (FC/100ml) 0 0 0 0.0000 Iron 0.04 0.03 0.0350 Lead 0.0002 U 0.0002 U .0002U Magnesium 13.3 12.1 12.7000 Mercury 0.0002 U 0.0002 U 0.000434 0.00013 0.0002 U 0.0003 Nickel 0.0053 0.00475 0.00399 0.0053 0.00458 0.0048 Nitrate-N 207 212 225 214.6667 pH (std. units) 8.37 8.24 8.19 7.63 6.58 7.8020 Phenols 0.079 0.075 0.021 0.0583 Phosphorus 16.8 19 17.9000 ( Selenium 0.00374 0.005 U 0.0037 Silver 0.001 U 0.001 U .001U TDS (mS as cond) 3.00 2.82 2.72 2.8467 Temperature CC) 19.7 20.5 20.1 20.1000 Thallium 0.000473 0.001 U 0.0005 TKN 3.47 2.04 2.06 2.5233 TOC 15.4 14.1 13.1 14.2000 Zinc 0.0734 0,0519 0.0490 0.144 0.246 0.1129 "U" indicates non-detect in analysis . . ~PR-19-2004 MON 01:18 PM ~ONOCO PHILLIPS 90777~5 P. 01 Cook Inlet Area Kenai, Alaska ~ ConocoPhillips - Facsimile Cover Sheet 'To: \. ~ ~rvï Company: A 0 (7( C Phone: Fax: 27 ~ - 75 Lt'-¿ Company: Phone: Fax: From: ShÚfltlOr"') þonneU,¡ ConocoPhillips Alaska ' 907-776-8166 907-776-2095 '7/ '" - Z°'1 2. Date: Pages including this cover page: 7'! 1c"It) L/ 5 .Ji..-n - At+Ctc.I'î<d i-:, +I-"'\e 1-e+ky of:- r-.eC¡vcsl- we... dí~c.u-::.~ +hl -~ rvlOI-Y""") j r'Ï::). '"'P-t~Vî k 'ov I=or S<è 1""/0\ \£15 0'1£" +he fures-\- ~ p provG. \. PI E'CI. ~.e.. \ e+ r>-ï c;:. Kn c> vV í.ç. 'ý 0 v \'\ c.. v-€ C. ~ '-) qve-:::,t-)O()":::t. '"ìYìc...rî\<:'" 'fç:;j....> fDv:-- 'I our Q.~s\~tunce. 3-ì c.. /Ì r'î 0 ..--.. RECEIVED APR '1 9 2004 Alaska Oil & Gas Cons. "." ' Anchor a 0." ,.jl1 REV/SED: 1/23/21)04 FOAM: OF-OOO1 A12 Acid Stirn Sundry - CANCEL Subject: A12 Acid Stirn Sundry - CANCEL From: "Venhaus, Dan E" <Dan.E.Venhaus@conocophillips.com> Date: Wed, 03 Mar 2004 16:14:08 -0900 To: "Tom Maunder (E-mail)" <tom - maunder@admin.state.alcus> CC: "Allsup-Drake, Sharon K" <Sharon.K.Allsup-Drake@conocophillips.com> ~CoS~DSS ':ja~-aG~ Tom, Further research has persuaded us to cancel the proposed acid stimulation on Tyonek disposal well A-12. The acid in question is from a cancelled job and we had proposed pumping it into the disposal well to enhance injectivity. However, historical and current injection shows little problem disposing of produced water volumes. Therefore acid may buy us little and could have potential downside. Please cancel A-12 sundry submitted March 2, 2004. Dan Venhaus Drilling & Wells Conoco Phillips Alaska, Inc. 907-263-4372 office 907-230-0188 cell This message is beingf3~ntl:>yç?Il()c:()Phillips E-mail virus filter. Content- Type:t~~t;~l~i~:1 l~nterScan _Disclaimer .txt . Content-Encoding: 7bit .'¡ SGAI~~[E[). MAH 1 5 2004 1 of 1 3/4/2004 6:49 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown D D 0 4. Current Well Class: ~\ t.C~\L\~ Development ~ Explor~tory D) 169-099 / Stratigraphic D Service 0 /: 6. API Number: (s~A~\\, 9. Well Na and Number: NCIU A-12/ (c:,"~S\\"; 1 O. Fi /Pools(s): N. ok Inlet Field/ Belu a Pool PRESENT WELL CONDITIO SUMMARY Effective Depth TVD (ft): lugs (measured) Junk (measured): 3558' 6823' 5986' MD TVD Burst D (ft): 58' - 6800' Packers and SSSV MD (ft): SSSV @ 370', pkr at 3200',3500',3751',4069',4175',4255',4453', 4569',5251',5440' 13. Well Class after proposed work: Exploratory 0 Development g"" Service 0 15. Well Status after proposed work: ~t)<.)<:J...\ c.o ,~\,~:::~p;- Oil D Gas ~ Plugged LJ Abandoned D WAG D GINJ 0 WINJ D WDSPL 0 '" ; t 1. Type of Request: Abandon D Alter casing D Change approved program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Suspend D Repair well D Pull Tubing 0 Plug Perforations Perforate New Pool P. O. Box 100360, Anchorage, Ak 99510-0360 7. KB Elevation (ft): 116' RKB 8. Property Designation: ADL 17589 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 14910' 14910' 3558' Casing Length Size Structural Conductor 3011 Surface Intermediate 2011 Production 13-3/8,11 Production 3d~D""~~"ù ~~ O;~~ Perforation Depth MD (ft): Perforatio 3558' - 6800' Packers and SSSV Type: Halliburton pkr, Otis SSSV 12. Attachments: Description Summary of ro os Detailed Operations Program D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true Printed Name Title Wells Engineer 263-4372 Signature Phone COMMISSION USE ONLY y Commission so that a representative may witness Mechanical Integrity Test D Location Clearance 0 Other: Subse ent Form Required: l-\ D L-\ l~ I" Approved by: COMMISSIONER Form 1 0-403 Revised 2/2003 ORtGtNAL uP 3131¡ ,(, i~ECEIVI~~[) 3 MAR 0 2 2004 Perforate D Stimulate 0 /" n ~~6ìà'?OI~pSidñJ r:igc: Other 0 /' 50-883-20032-00 Collapse 3811 1990' 6950' .~ ';'156 J -Ss- Tubing Grade: J-55 3. ::bò . Tubing MD (ft): 3175' /6800' Tubing Size: 7" /4.511 Contact Date 3 -2 -01 Sundry Number: BY ORDER OF THE COMMISSION Date: .¿~u~hJS $' NCI A-12 Disposal Well Acid Stimulation The following is procedure to pump 6000 gal 1 0% HCL acid stimulation on the Tyonek platform disposal well, A-12. 1. Ensure 10% HCL acid has been rolled and contains adequate corrosion inhibitor. 2. Hold safety meeting and ensure personnel have proper PPE. Identify location of water flush stations. 3. Pressure test line to 3000 psi. Pump the following fullbore treatment, with max pressure = 2500 psi: D 10 bbl freshwater pre-flush D 6000 gal 1 0% HCL wI corrosion inhibitor and iron control additives D 200 bbl + tubing displacement of freshwater or seawater. 4. Return well to disposal service. Well will be overflushed and not flowed back. 3/2/2004 NCIU A-12 WELL COMPLETION DIAGRAM P--- ~ ~ - BPV(Make, Type,OD) FIle 6318. IS-A RKB-THF (New) 55.29 Tb2Jhr.(Make, Type) FMC RKB-THF (Old): 40.77 Annuh.. Fluid: 8., ppI 2 % KCL Water with 70/30 Glyool RKß.SL : 132.00 381 TOC: Circulated to Surface WA'IERDEPTII: 100' RKB-ML : 232.00 Production Casing: 1990 30" 41 381 20" 41 1,990 133 Ib/ft - - 13 3/8" 41 6,950 72 Iblft N-ID BT&C ~30 2520 1231 ~ H'b'1on TwI...Ao St" Asumbly It 317' Paçker 0 3200 Tubin2 String: 7" 41 3,175 26 Ib/ft I-55 & L-80 AB-STIL 4660 4080 208 Sterling Perls 4In" 3,500 6,800 4,7 Ib/ft I-55 EUE 8rd 3260 - 3370 COMPLETION STRING Packer 0 3500 ~ Cook Inlet Sand. 10 0,00 19,48 Elevation Correction ~ 355 8 - 3568 CI.Stray 9 19,48 40,77 Elevation ~ (Sqz'd) 8 60,25 3,90 FMCTnbing Hang", + 2' BT&C x STlL Crossover ~ 3577 - 3587 CI-Stray 7 64,15 371.01 7" 26 Ib/ft I-55 STJL Tubing (Hoots + 3 Pup Ioints 6,240 7JXYJ ~ (Sqz'd) 6 435,16 16.69 HaIIiburtm "CP-2" 'IRSSV with Top & Bottom Subs 5.900 9.400 ¡¡¡¡ 3804 - 3628 CI-A 5 451.85 2723.20 7. 26lblft I-55 STJL Tubing (õJ Ioints) 6.240 7JXIJ (Sqz'd) 4 3175,05 30,70 Hal I iburtm Twin FIo Seal Assv. 6,220 7.940 r-'1 3 3205.75 289,65 4 ill" 12.75 \b/ft L-80 ROE 8rd TubinJ! (Hoínts+ 3 Pups) 3,958 4500 Packer 0 3751' 2 3495.40 11.36 ''M$N'' Seals (3) and Seal Extension (6.0' Length) 6.220 7.940 1 351J7 ,63 0.87 Muleshoe GWde (0,88' l.etWh) 6.256 7,945 - 3820 - 3880 CI-1.0 41 32G0.OO 4.81 HalliburtonMWD P'nn'oentPkr and Thg. Adapter, 8.000 12.090 - - 3896 - 3960 CI-2,O 40 3499.77 3.96 Halliburton MWD P'nn'oent Pkr and Thg. Adapter. 8.000 12.090 3982 - 3994 CI-3.0 39 3503,73 8,17 Halliburton Seal BoreExtension and Thg. Adapter. 8,000 12.090 34 - - 4014 - 4048 CI-4,O 38 3511,90 237,85 ~ - 4 In" 12.75 Ib/ft N-80 EOE8rdTubing (8 Its +2'Pup) 3,958 4500 r2£!!L'1 37 3149,75 0.79 Halliburton "No-Go" Seal Unit Length = 5.08 OA I 3.985 9500 Paçker 0 4069' 36 3758.S4 4.61 HalliburtonMWD P'nn'nentPkr and Thg. Adapter. 8,000 12,090 - 35 3755.15 248.12 4 ill" 12.75 Ib/ftN-80EOE8rdTubing (8 Its +S'&2'Pup) 3.958 4500 - 4090 - 4098 CI-5,O 34 4003.27 4.48 Halliburton' 'XO" Sliding SIee"" 3,813 5,600 - 4106-4111 CI-5.0 33 4OCfl,75 60,65 4 In" 12,75 Ib/ft N-ID B0E8[dTubing (2 Its +2'Pup) 3,958 4500 - 4116-4124 CI-5,1 32 4068,40 0.79 Halliburton "No-Go" Seal Unit Length = 5.08 OA I 3.985 9500 29 - 00000 - - CI-6.0 Closed - 4141 -4166 31 4°".19 4,61 HalliburtonMWD P'nn'nentPkr and Thg. Adapter, 8.000 12.090 r-l 30 4073,80 58,12 4 In" 12.75 Ib/ft N-ID EOE 8rd Tubing (1 Its + 4 Pup Its) 3,958 4500 Paçker 04175' 29 4131.92 4,48 Halliburton' 'XO" Sliding SIee"" 3,813 5,600 g - 28 4136,40 3154 4 ill" 12.75 Ib/ft N-ID EOE8rdTubing (1 Its +S'Pup) 3,958 4500 - 4188 - 4238 CI-7,O&7.1 Zl 4173.94 0.79 Halliburton "No-Go" Seal Unit Length = 5.0S OA 3,985 9500 Paçker 0 4255' 26 4174.73 4,61 Halliburton MWD P'nn'nentPkr and Thg. Adauter. 8,000 12.090 - 4272 - 4282 CI-8,O 25 4179.34 74,94 41n" 12.75 Ib/ftN-80EOE8rdTnbing (2 Its +10,2',2'Pups» 3,958 4500 - 24 4254,28 0.79 Halliburton "No-Go" Seal Unit Length = 5.08 OA 3.985 9500 - - 4298 - 4316 CI-8.2 21 00000 - 23 4255.07 4,61 Halliburton MWD P'rm'nent Pkr and Thg. Adapter. 8.000 12.090 - CI-10,O 4 ill" 12.75 Ib/ft N-80 EOE8rdTubing (3 Its +S'+2'Pups» Open - 4378 - 4390 22 4259.68 99.32 3.958 4500 - 21 4359.00 4,48 Halliburton ''XO'' SlidingSIee"" 3,S13 5,600 - 4415 - 4440 CI-11.0 20 4363.48 88,75 4 In" 12.75 Ib/ft N-80 EOE 8rd Tubing ( 3 Ioints) 3,958 4500 r-l 19 4452.23 0,79 Halliburton "No-Go" Seal Unit Len2th = 5.08 OA I 3,985 9500 Paçker 0 4453' g - Beluga Sand. 18 4453.02 4.61 HalliburtonMWD P'nn'nent Pkr and Thg. Adapter, 8.000 12.090 - 4475 - 4482 a-3 17 4457,63 111.02 41n" 12.75 Ib/ftN-80EOE8rdTubing (3 Its, + 10',10& 2'Pup) 3.958 4500 16 4568,65 0.79 Halliburton "No-Go" Seal Unit Length = 3.920A I 3.985 9500 Packer 0 4569' - 15 45".44 4,61 HalliburtonMWD P'nn'nent Pkr and Thg. Adapter. 8,000 12.090 4660 - 4668 b.7 14 4574,05 601.11 41n" 12,75 Ib/ftN-80EOE8rdTubing (20Its,+6'&2'Pup) 3,958 4500 - 13 5175.16 4,48 Halliburton ''XO'' Slidin2 S]ee"" 3,813 5.600 12 5179.64 70.08 4 ill" 12.75 Ib/ftN-80EOE8rdTubÍl1,lt (2Its,+10'~) 3,958 4500 - 11 5249.72 0.79 Halliburton "No-Go" Seal Unit Length = 3.96 OA 3,985 9500 - 4973 - 4978 e.3 - 4990 - 4995 $-4 10 5258.51 458 HalliburtonMWD P'nn'nentPkr and Thg. Adapter. 8.000 12.090 - 9 5255,09 lZl .65 4 In" 12.75 Ib/ft N-80 EOE8rdTubing ( 4 Its. + 6' & 2'Pup) 3.958 4500 - 5010 - 5025 e.5 & e-6 S 5382.74 4.48 Halliburton ''XO'' Sliding S]ee"" 3.813 5,600 7 5387,22 59,31 4 In" 12.75 Ib/ft N-80 BOE 8rd TubinJ! ( 2 Ioints) 3.958 4,500 - 6 544653 1,73 Halliburton "No-Go" Seal Unit Length = 7.290A 3.985 9,500 - 5050 - 5057 e.8 - 5064 - 5070 e-9 5 5448.U 4,62 Halliburton MWD P'nn'nentPkr aod Thg. Adapter. 8,000 12,090 - 5120 - 5135 1-4 4 5452,88 180.95 4 In" 12.75 Iblft N-80 EOE8rdTubing (6Its.+2'Pup) 3,958 5550 5150 - 5157 1-5 3 5'33.83 4.47 Halliburton ''XO'' Sliding SIee"" 3.813 5.600 13 - - 2 5638.30 119.19 3.958 00000 - 4 In" 12.75 Ib/ft N-80 EOE 8rd Tubing ( 4Ioints) 5550 ,.-- Open - 5194 - 5204 g-1 1 5757.49 1.68 Halliburton 4 V2" "XN" Nipple 3.725 5530 r"-"-l 5759,17 0,83 WireJine Guide 3.958 8.050 Paçker 0 5251' 57'°.00 FndofTubÍl1,lt - 5292 - 5305 h-1.1&1,2 5354 - 5372 h-6 - - 8 00000 5~4-5414 h-8 SHORT STRING DISPOSAL TUBING - - Open - 5431 - 5436 h.9 5 0,00 293.50 23/8" 4,7 Ib/ft CS Hydril I-55 Tubing 1.990 2,660 r"-"-'1 4 293.50 4,00 Halliburton Type ''XXO'' Landing Nipple 1,870 3.125 Paçker 0 5448' 3 2m.50 2895,00 2318" 4,7 ..1ft CS Hvdril I-55 Tubin2 1,990 2.660 - 2 3192.50 1.50 Halliburton 23/8" ''XN'' Nipple 1,810 3,125 5466 - 5480 . 1-3 1 3194.00 6,00 Muleshoe Guide and Seal Assembly 1,990 2315 - 5482 - 5490 . i-4 3200,00 Fnd of Tubing - Well History - 5514-5521' ¡.7 June 1975 - Original Completion with 4-1I2"X3-1I2" tubing at 6784', Commingled CI Stray, A, 1.0-11.0 & Beluga a-3 thro v-I - April 1994 Workover- Commingled CI 1.0-11.0 and Beluga a-3 thro v-I with 7" tubing set at 2700' and 2-3/8" siphon 5532 - 5540 i.8 - - 5564 - 5574 ]-2 string at 6794' - - 5576 - 5584 . J-2.1 PuIl4-1I2"X3-1I2" tubing string, Tubing full of drilling mud 5750'-6550'. Plugged with sand from 6550'-6785' 3 00000 - 5592 - 5596 . j-3 Reperforate/add perforations in Beluga from 4475'-6800', Flow 23 MMCFD & 80 BWPD (1500 0), PIP 672 psi. - Closed - 5668 - 5674 . k-4,1 Reperforate Cook Inlet from 3866'-4440', Flow 28 MMCFD & 40 BWPD, PIP 654 psi - ")(N. - 5757 - 5764 m-4 Squeeze CI Stray & AperforatioDS 3558'-3628', test to WOO psi., reverse test to 500 psi - November 19?7 Workover- Commingled CI 1.0-4.0, 8.0-11.0 and Beluga b-7 thro m-4 with 7"X4-1I2" tubing EZSV 0 5935' with multiple packers and SS's roo- Top 01 Fish 6088 - 6096 . p-2 October 1999 - Top of Fill 5933' - May 31, 2001- Tag fill @ 5875' WLM 0 5986' 6130 - 6150 p.5 - May 9, 2002- Tag fill @5792' WLM - 6180 - 6186 . q-2 - 6330 - 6338 r-6 - 6441 - 6448 s-6 2 318. Tbg - 6540 - 6547 . 1-2 - 6641 - 6646 1-6 - 6718 - 6726 u-5 - 6748 - 6758 u-7 - - 6790 - 6800 v.1 PBTD 6823' 'Perforations added during 1994 workover cap 6834' Updated By: Osborn 9/11/2002 I PBID: 6,823' Is\IDV: Sim'Cn; Babin'x ITb2Wt: 7.0" 26 Ib/ft I-55 STJL + 4 In" 12.75 Ib/ft I-55 Wen: North Cook Inlet Unit No. A-12 I November 18, 1997 Updated 11/18/97 Locatioo: CookInlet, Alaska Field: North Cook Inlet Unit FRD UIC File Review Date: Subject: July 29, 2003 Disposal of Detergent "KleenUp" used to Clean'Mud Pits ConocoPhillips Tyonek Platform Well A-12 (Class II UIC Well) North Cook Inlet Field PTD #: 169-099 Orders: AEO 4 DIO 17 Reviewers: Initiating Action: Jim Regg, Petroleum Engineer Approval of Product "Kleen Up" as Part of Rig Wash Review Summary 1. Tyonek platform is a standalone development in North Cook Inlet Unit (NCIU), approximately 30 miles SW of Anchorage in offshore Cook Inlet. 2. ConocoPhillips requested by electronic mail approval for the disposal of an effluent stream that would be generated as part of cleaning the rig's mud pits in NCIU A-12 (July 18, 2003); a. Fluid stream includes a detergent named "Kleen Up" (M-I Drilling Fluids Product) to enhance the capabilities of normal rig wash water; solids generated in the cleaning process will be segregated for transport to an onshore landfill. 3. ConocoPhillips' request includes data demonstrating that the detergent is non-hazardous; drilling fluids are eligible for Class II well disposal as an RCRA exempt waste. 4. Chronological Review: a. Tiered from File Review dated October 10, 2002 i. ConocoPhillips request for approval to dispose cement rinsate and other fluids that have not been downhole into NCIU Well A-12 b. Annual performance report for Well A-12 dated March 28, 2003. Technical Evaluation 1. Well integrity has been demonstrated by MIT in November 2001 (1500 psi, held 30 min) and injection performance data gathered by ConocoPhillips. There is no indication of waste fluids escaping from the disposal zone. 2. MSDS sheet for "Kleen Up" demonstrates the detergent is non-hazardous (copy attached). 3. Pit cleaning is a routine part of drilling, completion, and workover rig activities that must be performed to maintain the performance characteristics of the work fluid. . EPA publication "Exemt~tion of Oil and Gas Ext~loration and Production Wastes from Federal Hazardous Waste Regulations''~ states: a. "A mixture of an exempt waste with another exempt waste remains exempt." b. "Mixing a non-hazardous waste (exempt or non-exempt) with an exempt waste results in a mixture that is also exempt." Recommendation - This File Review indicates ConocoPhillips compliance with AOGCC regulations, permitting conditions, and DIO 17. - The fluids proposed for disposal in Well A-12 do not exhibit any hazardous characteristics- they are the result of proper well operation and sound engineering practice in the management and maintenance of E&P development wells. - EPA publication "Exemption of Oil and Gas Exploration and Production Wastes from Federal Hazardous Waste Regulations" provides for disposal of' exempt and nonhazardous (exempt and nonexempt wastes) waste mixtures as exempt wastes. The waste commingled waste stream of rig wash water, mud pit fluids, and Kleen Up is exempt and eligible for Class II well disposal. - Approval of ConocoPhillips' request for disposal of the commingled waste stream consisting of rig wash, mud pit fluids, and the detergent KleenUp is recommended. Attachment EPA 530-K-01-004; January 2002 Disposal of Class II Washwater at Tyonek Platform., Subject: Disposal of Class II Washwater at Tyonek Platform Date: Fri, 18 Jul 2003 13:27:55 -0800 From: "NSK Expl Env" <n1662~conocophillips.com> To: jim_regg~admin.state, ak.us CC: "Kuupik 5 Company Man" <Kuupik5CompanyMan@conocophillips.com>, "Shannon Donnelly" <Shannon. Donnelly~conocophillips.com> Jim, We are in the process of washing out some of the mud pits on the Tyonek platform. The purpose is to remove loose coating, scale, and residual mud from the platform open top mud tank interior and flow lines. A detergent will be added at the time of the washing and drill water will be used for rinsing. The liquid wash water and rinse water will be transferred over to the injection pits. All solids will be separated from the liquids with the solids being transported onshore for landfill disposal. The liquids from the cleanup will be injected down well A-12 (Class II well). We would like your concurrence that the detergent used for cleaning the pits is also acceptable for Class II disposal. A copy Of the MSDS for the product is attached. Thank-you for your consideration in this request. Chris Brown (See attached file: E1KLENUP.pdf) Chris Brown/Jason Charton Exploration Field Environmental Coordinators NSK 61 (Kuparuk) Slope #: (907)659-7217 Fax: (907) 659-7314 Cell: (907) 240-5717 Pager: 659-7000 #790 _), I Name: E1KLENUP.pdf E1KLE ..NUP.pdf Type: Acrobat (application/pdf) 1 of I 7/22/2003 11:35 AM M-I DRILLING FLUIDS MATERIAL SAFETY DATA SHEET KLEEN UP 1. IDENTIFICATION OF THE PRODUCT AND THE COMPANY SUBSTANCE NAME: KLEEN UP COMPANY IDENTIFICATION: M-I Drilling Fluids Pocra Quay, Footdee, Aberdeen AB 11 5DQ. TELEPHONE: 00 44 1224 584336 FAX: 00 44 1224 576119 2. COMPOSITION / INFORMATION ON INGREDIENTS INGREDIENT NAME CONTENTS HEALTH RISK (class) (R.No.) Polyethylene glycol ether <25 % None 2-Butoxy ethanol <10% Xn Water >70% None R22, 36/38 CAS No. 111-76-2 NOTES: This product is classified as irritant according to CHIP regulations. 3. HAZARDS IDENTIFICATION This product is irritating to eyes and skin. 4. FIRST AID MEASURES EYES: SKIN: INHALATION: INGESTION: Rinse immediately with plenty of fresh water for at least 15 minutes. Seek medical attention. Wash splashes from skin with soap and water. Remove contaminated clothing if soaked through and launder before re-use. Remove to fresh air. Do not induce vomiting in order to avoid the formation of foam, which can reach the respiratory tract. If vomiting is necessary give an antifoam (dimticone). 5. FIRE FIGHTING MEASURES EXTINGUISHING MEDIA: SPECIAL FIRE FIGHTING PROCEDURES: SPECIAL EXPOSURE HAZARDS IN FIRE: Water, carbon dioxide, dry powder or foam. Self contained breathing apparatus should be worn. Fire may produce noxious fumes. Safety Data Sheet for Kleen Up Page 1 of 4 6. ACCIDENTAL RELEASE SPILL CLEANUP METHODS: Absorb using sand, earth, sawdust or other absorbent medium. Place all absorbed waste into suitable containers for disposal. Try to prevent the product from entering drains or water courses. Wash down spillage area with plenty of water. 7. HANDLING AND STORAGE USAGE PRECAUTIONS: STORAGE PRECAUTIONS: STORAGE CRITERIA: 18. Avoid direct contact with the product. Do not eat or drink when handling the product. Store in closed containers in a well ventilated place. Protect from frost and store at room temperature. Plastic drums EXPOSURE CONTROLS AND PERSONAL PROTECTION TAKE MEASURES TO PREVENT: Spillages, skin and eye contact. EXPOSURE CONTROL LIMITS: 2-Butoxy ethanol MEL TWA 25ppm (120 mg/m3) RESPIRATORY PROTECTION: HAND PROTECTION: Not required under normal conditions of use. Use in well ventilated areas. Use a respirator with organic filter for high concentrations of vapour. Protective gloves made of rubber, PVC or nitrile should be worn. SKIN PROTECTION: Suitable protective clothing should be worn to prevent prolonged exposure. EYE PROTECTION: Goggles or splash proof chemical safety glasses should be worn. Provide eyewash station. 9. P~SICAL AND CHEMICAL PROPERTIES APPEARANCE: COLOUR: ODOUR / TASTE: pH: BOILING POINT / RANGE: MELTING POINT / RANGE: FLASHPOINT (deg C): FLAMMABILITY: AUTOFLAMMABILITY: EXPLOSIVE PROPERTIES: OXIDISING PROPERTIES: VAPOUR PRESSURE: RELATIVE DENSITY: SOLUBILITY(water and fat) OTHER: Liquid Colourless Slight odour. 6- 8.5 Approx. 100 deg C Not Determined > 100 (PMCC) Not Determined N/A Explosive limits not determined N/A Not Determined S.G. 1.02 at 20 deg C Soluble Safety Data Sheet for Kleen Up Page 2 of 4 10. STABILITY AND REACTIVITY NORMALLY STABLE CONDITIONS TO AVOID: Extremes of temperature. MATERIALS TO AVOID: Strong oxidising agents. HAZARDOUS DECOMPOSITION PRODUCTS Oxides of carbon on combustion 11. TOXICOLOGICAL INFORMATION TOXICOLOGICAL PROPERTIES INCLUDING SPECIAL HEALTH EFFECTS OF CONSTITUENTS: EYES: SKIN: INHALATION: May cause irritation in contact with eyes. May cause irritation in contact with skin. Not an inhalation hazard under normal conditions of use and at room temperature. 12. ECOLOGICAL INFORMATION POSSIBLE EFFECTS: BEHAVIOUR: ENVIRONMENTAL FATE: No available data. No available data. No available data. 13, DISPOSAL CONSIDERATIONS DISPOSAL METHODS: This product should be disposed of in accordance with local and/or national regulations. May be disposed of by landfill to an authorised site or by incineration. 14. TRANSPORT INFORMATION UN NUMBER: AIR IATA: IATA LABEL: SEA IMDG: IMDG LABEL: ROAD ADR: UK LABEL FOR CONVEYANCE: N/A No transport warning label required. Safety Data Sheet for Kleen Up Page 3 of 4 15. REGULATORY INFORMATION LABEL FOR SUPPLY: RISK PHRASES: SAFETY PHRASES: SPECIFIC EC CONTROLS: SPECIFIC UK LEGISLATIVE CONTROLS: Xi, Irritant R36/38 S26 Irritating to eyes and skin. In case of contact with eyes, rinse immediately with plenty of water and seek medical advice. 16. OTHER INFORMATION TRAINING ADVICE: RECOMMENDED USES AND RESTRICTION~ Used as a clean-up chemical. FURTHER INFORMATION: SOURCES OF KEY DATA: Suppliers' safety data sheets. OTHER: The data contained in this safety data sheet has been supplied as required by the Chemicals (Hazardous Identification and Packaging) Regulations, as amended, for the purpose of protecting the health and safety of industrial and commercial users who are deemed capable of understanding and acting on the information provided. The information herein is not exhaustive and should only be used as a guide to determine the best conditions for the safe use of the product. M-I Drilling Fluids is not responsible for any injury or liability resulting from the misuse of the product. Please ensure that it is passed to the appropriate person(s) in your company, who are capable of acting on the information. Revision Date: 11/12/96 Revision Number: 0-D Revised By: DR K.J.WALKER Safety Data Sheet for Kleen Up Page 4 of 4 Memory Multi-Finger Caliper Log Results Summary Company: PHILLIPS Well: Log Date: May 9, 2002 Field: Log No.: 4677 State: Run No.: I APl No.: Pipe1 Desc.: 4.5" 12.6 lb. J-55 Top Log Intvll.: Pipe1 Use: Tubing Bot. Log Intvll.: NCIU A-12 North Cook Inlet Unit Alaska N/A 3,459 Ft. (MD) 5,745 Ft. (MD) Inspection Type' Corrosive & Mechanical Damage Inspection COMMENTS · This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate that the interval of 4.5" tubing logged is in good to poor condition. Two holes are recorded in joint 138 and pup joint 142.1. Penetrations from 20% to 34% wall thickness are recorded throughout the remainder of the interval logged. The damage appears in the forms of Isolated Pitting with a shallow Line of Corrosion. No areas of significant cross-sectional wall loss are recorded throughout the logged interval. Deposits restrict the minimum measured ID to 3.55" in pup joint 142.2 and joint144. The distribution of penetrations is illustrated in the Body Region Analysis Page of this report. The field engineer reported erratic slick line pulling speed and many tool hang-ups durfng the log run. This resulted in several intervals of minimal recorded data where the tool experienced excessive acceleration upon pulling loose from the hang ups. These intervals include the sliding sleeves at 4, 003' and 4, 359.' The joint count numbering is an approximation based on the average joint length and the log start depth. TUBING - MAXIMUM RECORDED WALL PENETRATIONS · Hole (100%) Jt. 138 @ 4,286 Ft. (MD) Hole (100%) Jt. 142.1 @ 4,436 Ft. (MD) Corrosion (34%) Jt. 137 @ 4,218 Ft. (MD) Corrosion (30%) Jt. 136 @ 4,150 Ft. (MD) Line Corrosion (25%) Jt. 143 @ 4,495 Ft. (MD) TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS ' No areas of significant cross-sectional metal loss (> 10%) are recorded throughout the interval logged. TUBING - MAXIMUM RECORDED ID RESTRICTIONS · Deposits. Min. I.D. = 3.55" Jt. 142.2 @ 4,456 Ft. (MD) Deposits Min. I.D. = 3.55" Jt. 144 @ 4,532 Ft. (MD) Deposits Min. I.D. = 3.56" Jt. 164 @ 5,133 Ft. (MD) Deposits Min. I.D. = 3.57" Jt. 137 @ 4,220 Ft. (MD) Deposits Min. I.D. = 3.61" Jt. 143 @ 4,501 Ft. (MD) Field Engineer' S. Adcock Analyst: M. Lawrence Witness: N/A I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 'Fax: (28:[) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Well: A-12 Field: North Cook Inlet Unit Company: Phillips Country: USA PDS Report Overview Body Region Analysis Survey Date: May 9, 2002 Tool Type: MFC40 No. 00432 Tool Size: 2.75 No. of Fingers: 40 Analyst: M. Lawrence Tubing: Nora.OD Weight Grade & Thread 4.5 ins 12.6 ppf J-55 Nom.lD Nom. Upset Upper len. Lower len. 3.958 ins 4.5 ins 1.2 ins 1.2 ins Penetration and Metal Loss (% wall) mmJ penetration body ~ metal loss body 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 68) pene. 0 13 37 16 0 2 loss 36 32 0 0 0 0 Damage Configuration ( body ) isolated general line ring hole / poss pitting corrosioncorrosioncorrosionible hole Number of joints damaged (total = 51 ) 39 9 1 0 2 Damage Profile (% wall) penetration body metal loss body 0 50 1 O0 120 136 146 166 Bottom of Survey -- 177.2 Analysis Overview page 2 Well: Field: Company: Country: A-12 North Cook Inlet Unit Phillips USA PDS Caliper Minimum Diameter Profile Survey Date: 5/9/2002 Tool: MFC40 No. 00432 Tool Size: 2.7.5 inches Tubing I.D.: 3.958 inches Minimum Measured Diameters (In.) 2.75 2.85 2.95 3.05 3.15 3.25 3.35 3.45 3.55 3.65 3.75 3.85 3.95 I 120 123 125 126 129 132 134 135 136 137 137 139 141 142 143 144 145 147 150 153 156 159 162 165 167 167 169 170 172 174 177 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 ins 12.6 ppf J-55 Wall thickness: Body- 0.271 ins Upset ~ 0.271 ins Nominal ID: 3.958 ins Well: A-12 Field: North Cook Inlet Unit Company: Phillips Country: USA Survey Date: May 9, 2002 penetration body metal loss body ioint ' Penetrati~)n !Metal Projection Minimum ' Damage Profile No. Upset Bd@Up Body Loss Cplng 3ody ID Comments (% wall) inches inches inches % % inches inches inches O 50 lC '.i20 , , 0 0 0 , 0 0 0 0 0 ' ' 121 0 .04 .05 19 2 .12 ..17 3.71 Shallow corrosion. Lt. Deposits. 122 0 0 .03 10 'i .07 -!2 3.77 Lt. Deposits. Il "i23 0 ,,, .04 .05 19,, 3 .13, .14 3.75 Shallow corrosion. Lt. Deposits. 124 0 O ,. .04 ,16 4 .05 .10 3.81 Shallow c, orrosi0n. Lt. Deposits. 125 0 .06 .04 15 0 .11 .11 3.77 Shallow corrosion. Lt. Deposits. mi ,.,1,25.1 0 0 0 0 0 0 0 3.98 NO-GO SEAL 1, 25.2 0 0 0 0 0 0 0, 8.00 PACKER 125.3 0 0 .01 5 I 0 0 3.87 PUP 126 .02 0 .04 15 6 .06 .10 3.82 Shallow pitting. Lt. Deposits. ~ I ...127 .03 .05 .04 13 I .08 , ,..19 3.73 Shallow pitting. Lt. Deposits. · 128 0 0 .03 11 4 0 .08 3.81 Lt. Deposits. 129 0 0 .03 11 2 .08 .09 3.84 Lt., Depos, its. , ,130 0 0 .03 11 2 0 .06 3.84 Lt. Deposits. ill ..131 0 0 .03, 12 ,2 .05 .09 3.85 Shallow pitting. Lt. Deposits,. · 132 0 0 .04 15 4 0 .. 11 3.82 Shallow pitting. Lt. Deposits. ~ ! ,...133 . . 0 0 .06 22 4 0 .09 3.82 Isolated pitting.. Lt. Deposits. ]33.1 0 0 0 0 0 0 0 3.81 SLDNG SLV (N/A) ,134 .02 .06 .06 24 0 .24 .21 3.65 Corrosion., Deposits. 134.1 0 0 0 0 0 ,0 0 3.98 NC) GO SEAL ,.134.2 ,0 0 0 .... 0 0 0, 0 8.00 PACKER ,, ,135,. .03 .03 .04 1.4 1 .10 .22 3.68 Shallow corrosi0,n. Deposits. []1 135.1 0 0 0 0 0 0 0 3.81 SLDNG SLV (Closed) , , 136 .0,5 .06 .08 30 1 .20 .25 3.64 Corrosion. Deposits. 136.1,i 0 0 0 0 0 0 0 3.98 NC)GO SEAL , , 136.2 0 0 0 , 0 0 0 0 8.00 PACKER, 136.3 0 0 .03 10 I .10 ,. -09 3.81 PUP Lt. Deposits. [] 132 0 .06 .09 34 1 .15 .22 3.59,, ,C, orrosion~ Deposits. 137.1 0 0 , .03, 13 2 .13 .14 3.,75 Shallow pitting. Lt. Deposi,t,s. Il ,.1,37.2 0 ,,0 0 0 0 0 0 3.98 NOGO SEAL 13 7.3 0 0 0 0 0 0 0 8.00 PACKER 13 7.4 0 0 .01 2 I 0 .05 3.8,6 PUP LL Deposits. 139 , .06 .05 .04 15, 3 .20' .17 3.73 Shallow pitting. Lt. Deposits. ~ I 140 0 0 .04 13 I 0 .16 3.77 Shallow pitting. LL Deposits. · 140.1 0 0 0 0 0 0 0 ,3.81 SLDNG SLV (N/A) ',i41 " 0 0 .01,. '2 1 0 .05 3.90 142 0 0 . .01 3 1 0 0 3.90 ... 142.1 0 0 .29 100 10 0 .11 3.80 HOLE ! 142.2 .,05 .04 .07 24 1 .16 .41 , 3,.55 PUP Corros.ion. Deposits. 142.3 0 0 0 0 0 0 0 3.98 NO-GO SEAL ! 42.4 0 0 0 0 0 0 0 8.00 PACKER 142.5 0 0 .02 7 6 0 .07 3.85 PUP Lt. Deposits. 142.6 0 0 .01 3 0 0 0 , , 3.89 PUP I 143 0 0 .0,,7 25 2 0 ,.33 3.62 Line corrosion. Deposits. 144 0 0 .06 23 1 0 .32 3.55 Isolated pittin~ Deposits. ,,.145 0 0 .07 24 2 0 .07 3.86 Isolated pittinR. Lt. Deposits. ,.145.1 0 0 0 0 0 0 0 3.98 NC)GO SEAL 145.2, 0 0 0 0 0 0 0 8.00 PACKER "i 4~i.3 0 0 .01 2 0 0 0 3.90 pup Pipe Tabulations page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 ins 12.6 ppf J-55 Wall thickness: Body = 0.271 ins Upset = 0.271 ins Nominal ID: 3.958 ins Well: A-12 Field: North Cook Inlet Unit Company: Phillips Country: USA Survey Date: May 9, 2002 penetration body metal loss body Joint Penetration Metal Projection Minimum Damage Profile No. Upset Bd@Up Body Loss Cplng E~ody ID Comments (% wall) inches inches inches % % inches inches inches 0 50 10 146 0 0 .04 15 4 0 .14 3.80 Shallow pitting. Lt. Deposits. 147 0 0 .05 18 2 .08 .11 3.84 Shallow pitting. Lt. Deposits. · · 148 0 0 .05 19 I 0 .12 3.81 Shallow pitting. Lt. Deposits. 149 0 0 .06 21 1 0 .09 3.86 Isolated pitting. Lt. Deposits. 150 ~08 0 .05 20 I 0 .12 3.81 Shallow pitting. Lt. Deposits. 151 0 0 .05 20 3 0 .12 3.82 Isolated pitting. Lt. Deposits. 152 0 0 .04 14 I 0 .03 3.91 Shallow pitting. [] 153 0 0 .04 14 2 0 .11 3.82 Shallow pitting. Lt. Deposits. []l 154 0 0 .04 15 I 0 .06 3.89 Shallow pitting. Lt. Deposits. [] 155 0 .05 .06 21 I .08 .15 3.79 Isolated pitting. Lt. Deposits. 156 0 0 .05 18 I 0 .08 3.87 Shallow pitting. Lt. Deposits. 157 0 0 .05 20 I 0 .12 3.83 Isolated pitting. Lt. Deposits. 158 0 0 .05 18 2 .08 .17 3.77 Shallow pitting. Lt. Deposits. []· 159 0 0 .06 21 3 0 .21 3.72 Isolated pitting. Deposits. 160 0 .03 .06 24 3 .06 .18 3.76 Isolated pitting. Lt. Deposits. 161 0 0 .04 15 2 0 .05 3.88 Shallow pitting, lt. Deposits. []l 162 0 0 .05 19 3 0 .21 3.73 Shallow pitting. Deposits. 163 0 0 .04 16 I 0 .08 3.87 Shallow pitting. Lt. Deposits. 164 0 0 .05 20 I 0 .39 3.56 Isolated pitting. Deposits. 165 0 0 . .06 21 I 0 .20 3.75 Isolated pitting. LL Deposits. 165.1 0 0 0 0 0 0 0 3.81 SLDNG SLV (Closed) 166 0 0 .06 24 2 0 .13 3.81 Isolated pitting. Lt. Deposits. 167 0 0 .05 19 2 0 .13 3.83 Shallow pitting. Lt. Deposits. 167.1 0 0 .01 2 0 0 0 3.89 i PUP 167.2 0 0 0 0 0 0 0 3.98 NO-GO SEAL 167.3 0 0 0 0 0 0 0 8.00 PACKER 168 0 0 .05 18 3 0 .24 3.72 Shallow pitting. Deposits. 168.1 0 0 0 0 0 0 0 3.81 SLDNG S/V (Closed) 169 0 0 .06 21 1 0 .17 3.79 Isolated I~itting. Lt. Deposits. 170 0 0 .06 22 I .09 .21 3.72 Isolated pitting. Deposits. 170.1 0 0 0 0 0 0 0 3.98 NO-GO SEAL 170.2 0 0 0 0 0 0 0 8.00 PACKER 170.3 0. 0 .02 6 1 0 0 3.88 PUP 171 0 0 .04.. 15 I 0 .15 3.81 Shallow I~itting. Lt. Deposits. [] 172 0 0 .05 18 5 0 .22 3.72 Shallow pitting. Deposits. 173 0 0 .04 13 1 .12 .12 3.81 Shallow pitting. Lt. Deposits. [] 174 0 0 .04 14 4 0 .15 3.77 PUP Shallow pitting. Lt. Deposits. 174.1 0 0 0 0 0 0 0 3.81 SLDNG SLV (Open) 175 0 0 .03 11 I 0 .13 3.82 Lt. Deposits. [] 176 0 0 .01 4 2 0 .04 3.91 I 177 0 0 .01 5 1 .17 0 3.91 Deposits. 177.1 0 0 0 0 0 0 0 3.72 XN NIP 1.77.2. 0 0 0 0 ..0 0 0 3.96 WLEG . Pipe Tabulations page 2 Damage classification scheme Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 65% of circumference, but depth range does not exceed 1 * pipe ID Line - damage depth range exceeds $ ~ pipe ID, but extends less than 20% of circumference. General - damage depth range exceeds 1 * pipe IDand/or extends more than 20% of circumference. Isolated - damage depth range does not exceed 5 * pipe ID or extend more than 20% of circumference. Damage reporting threshold ~ 30 thou inches deviation in body, 50 thou in coupling. Modal Nine length -- 0.447 feel Pipe Tabulations 3 Well: A-12 Field: North Cook Inlet Unit Company: Phillips Country: USA Tubing: 4.5 ins 12.6 ppf J-55 PDS Report Cross Sections Survey Date: May 9, 2002 Tool Type: MFC40 No. 00432 Tool Size: 2.75 No. of Fingers: 40 Analyst: M. Lawrence Cross Section for Joint 138 at depth 4286.52 ft Tool speed = 87 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 92 % Tool deviation = 53 ° Finger 9 Penetration = 0.322 ins Hole due to Corrosion 0.32 ins = 100% Wall Penetration HIGH SIDE = UP Cross Sections page 1 Well: A-12 Field: North Cook Inlet Unit Company: Phillips Country: USA Tubing: 4.5 ins 12.6 ppf J-55 PDS Report Cross Sections Survey Date: May 9, 2002 Tool Type: MFC40 No. 00432 Tool Size: 2.75 No. of Fingers: 40 Analyst: M. Lawrence Cross Section for Joint 142.1 Tool speed = 104 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 92 % Tool deviation = 60 ° at depth 4436.38 ft Finger 7 Penetration = 0.292 ins Hole due to Corrosion 0.29 ins = 100% Wall Penetration HIGH SIDE TM UP Cross Sections page 2 Well: Field: Company: Country: Tubing: A-12 North Cook Inlet Unit Phillips USA 4.5 ins 12.6 ppf J-55 PDS Report Cross Sections Survey Date: May 9, 2002 Tool Type: MFC40 No. 00432 Tool Size: 2.75 No. of Fingers: 40 Analyst: M. Lawrence Cross Section for Joint Tool speed = 93 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 99 % Tool deviation -- 68 ° 142.2 at depth 4455.56 ft Finger 19 Projection ~ -0.405 ins Deposits Minimum I.D. = 3.55 ins HIGH SIDE = UP Cross Sections page 3 PDS REPORT JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf J-55 Wall thickness: Body = 0.271 ins Upset = 0.271 ins Nominal ID'. 3.958 ins Joint Depth Length Modal Mean ',lominal ~tominal Type No. ID ID ID OD feet feet inches inches inches inches 120 3573.65 22.06 0 0 3.958 4.500 121 3595.71 41.99 3.927 3.912 3.958 4.500 122 3637.70 27.66. 3.95.0. 3.935 3.958 4.500 123 3665.36... 27.85 3.91'5 3.897 3.958 4.500 124 3693.21 29.79 3.932 3.919 3.958 4.500 1.725 3723.00 26.57. 3.958 3.915 3.958 4.500 125.1 3749.57 6.34 3.985 3.985 3.985 4.500 To-go seal 125.2 3755.91 6.55 8.000 8.000 8.000 12.090 ~acker 125.3 3762.46 5.63 3.914 3.925 3.958 4.500 3up 126 3768.09 29.26 3.934 3.929 3.958 4.500 127 3797.35 32.66 3.934 3.924 3.958 4.500 128 3830.01 34.37 3.93'1 3.925 3.958 4.500 129 3864.38 31.29 3.949 3.941 3.958 4.500 130 3895.67 31.80 3.938 3.937 3.958 4.500 131 3927.47 25.08 3.933 3.928 3.958 4.500 132 3952.55 30.42 3.938 3.934 3.958 4.500 133 3982.97 29.51 3.935 3.931 3.958 4.500 133.1 4012.48 5.36 3.813 3.813 3.813 4.500 ~ldng slv 134 4017.84 6.34 3.958 3.904 3.958 4.500 134.1 4024.18 81.58 3.985 3.985 3.985 4.500 no-go seal 134.2 4105.76 4.91 8.000 8.000 8.000 12.090 )acker 135 4110.67 24.07 3.958 3.886 3.958 4.500 135.1 4134.74 13.75 3.813 3.813 3.813 4.500 ~ldngslv 136 4148.49 25.60 3.958 3.867 3.958 4.500 136.1 4174.09 24.83 3.985 3.985 3.985 4.500 ~o-go seal 136.2 4198.92 10.75 8.000 8.000 8.000 12.090 ~acker 136.3 4209.67 6.88 3.902 3.904 3.958 4.500 ~up 137 4216.55 32.85 3.958 3.886 3.958 4.500 137.1 4249.40 9.51 3.950 3.948 3.958 4.500 137.2 4258.91 2.24 3.985 3.985 3.985 4.500 mo-go seal 137.3 4261.15 4.55 8.000 8.000 8.000 12.090 packer 137.4 4265.70 15.13 3.915 3.920 3.958 4.500 pup 138 4280.83 27.83 3.958 3.890 3.958 4.500 139 4308.66 29.46 3.929 3.923 3.958 4.500 140 4338.12 29.11 3.927 3.920 3.958 4.500 Well: A-12 Field: North Cook Inlet Unit Company: Phillips Country: USA Survey Date: May 9, 2002 Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 140.1 4367.23 4..85 3.813 3.813 3.813 4.500 Sldng slv 141 4372.08 31.29 3.941 3.942 3.958 4.500 !42 4403.37 28.35 3.941 3.941 3.958 4.500 142.1 4431.72 11.53 3.912 3.914 3.958 4.500 142.2 4443.25 15.72 3.958 3.920 3.958 4.500 ~up 142,3 4458.97 2~23 3.985 3.985 3.985 4.500 ~o-go seaI '142.4 4461.20 8.86 8.000 8.000 8.000 12.090 ~acker 142~5. 4470.06 6.73 3.917 3.926 3.958 4.5.00 ~up 142.6 4476.79 9.77 3.921 3,926 3,958 4.500 3up 143 4486.56 33.89 3.934 3.931 3.958 4.500 144 4520.45 30.11 3.958 3.934 3.958 4.500 145 4550.56 29.93 3.940 3.938 3.958 4.500 145.1 4580.49 2.09 3.985 3.985 3.985 4.500 no-go seal 145.2 4582.58 7.95 8.000 8.000 8.000 12.090 )acker 145.3 4590.53 7.20 3.923 3.932 3.958 4.500 pup 146 4597.73 27.22 3,940 3,941 3.958 4.500 147 4624.95 38.09 3.938 3.941 3.958 4.500 148 4663.04 31.17 3.942 3.941 3.958 4.500 149 4694.21 22.61 3.945 3.946 3.958 4.500 150 4716.82 32.78 3.943 3.945 3.958 4.500 151 4749.60 34.08 3.940 3.941 3.958 4.500 152 4783.68 23.88 3.958 3.956 3.958 4.500 153 4807.56 26.64 3.936 3.937 3.958 4.500 154 4834.20 26.03 3.949 3.949 3.958 4.500 155 4860.23 47.06 3.943 3.943 3.958 4.500 156 4907.29 32.26 3.950 3.950 3.958 4.500 157 4939.55 12.55 3.954 3.956 3.958 4.500 158 4952.10 24.22 3.943 3.943 3.958 4.500 159 4976.32 31.24 3.939 3.939 3.958 4.500 160 5007.56 25.83 3.935 3.937 3.958 4.500 161 5033.39 31.10 3.952 3.952 3.958 4.500 162 5064.49 25.35 3.944 3.943 3.958 4.500 163 5089.84 27.92 3.953 3.952 3.958 4.500 164 5117.76 37.13 3.947 3.943 3.958 4.500 165 5154.89 20.36 3.952 3.952 3.958 4.500 Joint Tally page 1 PDS REPORT JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf J-55 Wall thickness: Body = 0.271 ins Upset = 0.271 ins Nominal ID: 3.958 ins Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 165.1 5175.25 35.13 3.813 3.813 3.813 4.500 ~ldngslv 166 5210.38 29.80 3.944 3.943 3.958 4.500 1.67 ..~240.18 23.85 3.943 3.945 3.958 4.500 167.1 5264.03 2.23 3.916 3.958 3.958 4.500 ~up 167.2 5266.26 22.10 3.985 3.985 3.985 4.500 ~o-go seal 167.3 5288.36 77.90 8.000 8.000 8.000 12.090 ~acker 168 5366.26 20.32 3.941 3.941 3.958 4.500 168.1 5386.58 3.38 3.813 3.813 3.813 4.500 ~ldng slv 169 5389.96 34.40 3.962 3.959 3.958 4.500 170 5424.36 23.21 3.942 3.941 3.958 4.500 170.1 5447.57 2.53 3.985 3.985 3.985 4.500 ..no'go seal 170.2 5450.10 7.47 8.000 8.000 8.000 12.090 )acker 170.3 5457.57 .2.04 3.913 3.985 3.958 4.500 pup 171 5459.61 28.63 3.952 3.952 3.958 4.500 172 5488.24 34.38 3.945 3.944 3.958 4.500 173 5522.62 98.61 3.944 3.943 3.958 4.500 174 5621.23 22.50 3.938 3.938 3.958 4.500 ~up 174.1 5643.73 4.01 3.813 3.813 3.813 4.500 ;Idng sly 175 5647.74 57.30 3.942 3.943 3.958 4.500 176 5705.04 37.32 3.949 3.949 3.958 4.500 177 5742.36 15.65 3.943 3.944 3.958 4.500 177.1 5758.01 30.26 3.725 3.725 3.725 4.500 (n 177.2 5788.27 N/A 3.958 3.958 3.958 4.500 ~,leg Well: A-12 Field: North Cook Inlet Unit Company: Phillips Country: USA Survey Date: May 9, 2002 Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches Joint Tally page 2 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 66 KENAI, ALASKA 99611 Cook Inlet Area Phone: (907) 776-8166 Fax: (907) 776-6240 North Cook Inlet Unit "A" No. 12 Phillips Petroleum Co. Tyonek Platform North Cook Inlet Unit, Alaska November 29, 2001 AOGCC 333 W. Seventh Avenue, Suite 100 Anchorage, AK 99501 ATTN: Mr. Tom Maunder Mr. Bob Fleckenstein Gentlemen: Please find attached a completed MIT State Test Form for the permitted Class II disposal well A-12 on PAI's NCIU Tyonek "A" Platform. A-12 is a dual completion well with disposal through 2 3/8" tubing into a shallow zone at 3260'-3370'. Should you have aha/questions or require additional information, please contact Len Janson at (907) 776-8166. Sincerely, C. Lindsey Clark Operations Manager Cook Inlet LGJ/klg CC' Brian Seitz -PAI Tyonek Supervisor STATE OF AL&SKA OIL AND GAS CONSERYAT[ON COMMISSION ......... ' ............. """""" '" '" .:....~...;.-.~. .... .~ '~' ""i~-'-'"~:-'- .... ......... ..'-, ~ .... .. ~ . -:, ~..~-. · .... .'C~..~.... *'~ ~.- ..- . · ..'_, ,...,. , .... ~..-~.. L".., .~-"'- -.,~. .... ~'~'"~ -"'~""'<'.~' :'~'":" ~ :'7: ;~"::'..U" :."-'-'~,~---':'::'~'-'-'" .:;"?-::~"":~.." :'~-'; '-":' '"":"'""~ ~"' '"" ":":"': .... ': -"" "';'-:~'" ":' .... ......... · ., ,.. ,,,, ,, weus: ,q.-/~ S f .... ~_oo~ , ~' -~'~,,, ~ l.s'~ o /s~ -/~.~ .~-~ ~ I~~ [] [] COMM~: PTD: ........................................ . . ~,,~..... I t [ I I I I°l I :..-,I I t .,,I~t~ COMMENTS: ~ ":':"'1 .... ..... I ! i t I I°l~ .~.': ~-' ~' ... ', I~1= CO~-: .... ...... ,. F = FRESH WATER [NJ. M = ANNULUS MONITOR~G DIESEL .!.. 0.00 G = GAS INS. ? = STD ANNXJLU$ PRESSURE TEST GLYCOL S = SALT WATEK ~N,. R -- INTERNAL gAD. TRACER SURYEY SALT WATER D = D~F~ENTIAL ~TURE TEST OTHER I 0.00 orig- Welt F'ge £ - c- Database ¢- Trip Ri~ Fde · AOGCC REP SIGNATURE: WELL ~: 4- Y~a~ Workov= Bla~ ~ ~ate Test Form STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 THE REQUEST OF PHILLIPS PETROLEUM COMPANY for an Aquifer Exemption Order for the North Cook Inlet Field. ) Aquifer Exemption Order No. ) North Cook Inlet Unit ) North Cook Inlet Field September 29, 1998 IT APPEARING THAT: 1.Phillips Petroleum Company ("Phillips") submitted an application, dated March 10, 1998, requesting that the Alaska Oil and Gas Conservation Commission issue an aquifer exemption for purposes of Class II disposal in the North Cook Inlet Unit A-12 well. Additional information requested by the Commission was received on July 10, 1998 and July 31, 1998. 2.The Commission published notice of an opportunity for a public hearing in the Anchorage Daily News on March 12, 1998. 3.The Commission did not receive any protest or request for a public hearing. 4.The Commission has jurisdiction in this matter under AS 31.05.030(h), 20 AAC 25.440, and 40 CFR 147, Subpart C - Alaska. 5.The Commission submitted a copy of Phillips' Aquifer Exemption application and a proposed order to the U.S. Environmental Protection Agency, Region 10, ("EPA Region 10") on August 7, 1998, in accordance with Section 14 of the November 22, 1991 Memorandum of Agreement between EPA Region 10 and the Commission. 6.EPA Region 10 did not object to the Aquifer Exemption Order for the North Cook Inlet Field. FINDINGS: 1 .In correspondence dated December 10, 1997, Phillips Petroleum requested an order authorizing Class II disposal into the Sterling Formation in the North Cook Inlet Unit (NCIU) A-12 well. 2.The NCIU is located offshore in Cook Inlet, approximately 30 miles southwest of Anchorage, Alaska and 5 miles due east of Tyonek, Alaska. 3.Wireline log analytical techniques, which are compliant with EPA recommended methods as described in "Survey of Methods to Determine Total Dissolved Solids Concentrations", (KEDA Project No. 30-956), were used to characterize formation water salinities in the NCIU. 4.A water sample taken from the Sterling Formation several hundred feet below the proposed disposal interval in the NCIU A-10 well, at a depth of 3,700' TVD cOntained 6230 mg/I TDS and 2940 mg/I chlorides. The physical sample compares to a wireline log calculated TDS concentration of 5933 mg/I. 5.Wireline log analysis from NCIU wells A-10 and A-12, calibrated to a fluid sample from the NCIU A-10 well, show the proposed Class II disposal injection zone contains freshwater with a total dissolved solids (TDS) concentration of between 3,000 and 10,000 mg/i. 6.Wireline log analysis in the NCIU A-12 well demonstrates formation water TDS increases with depth in the NCIU. 7.The bottom of formation waters with a TDS concentration of less than 3,000 mg/I in the NClU A-12 well has been estimated from wireline log analysis to be 2900' MD. 1 of 3 11/8/01 4:59 PM STATE OF ALA~SKA .,,,,~,, 8.The Pliocene-aged Steding Formation in the NCIU is composed of coarse-grained clastic intervals and interspersed relatively thin carbonaceous mudstones. Lithologic units are correlative throughout the unit. 9.The proposed Class II disposal interval in the A-12 well is between 3260' and 3380' MD, within highly porous and permeable fluvial sandstones and conglomerates of the Sterling Formation. 10.The proposed disposal interval is overlain and confined by approximately 95 feet of fined grained sediments below 2900' MD, which should prevent vertical migration of Class II wastes into formation waters with TDS content less than 3000 mg/l. 11 .Structural deformation has folded the Sterling Formation, causing at least 250' of relief in the proposed disposal interval. 12.Structural closure and the associated hydrostatic gradient will prevent lateral migration of Class II wastes beyond the NCIU. 13.The closest drinking water well to the NCIU is located onshore, approximately 8 miles to the northwest, in the Beluga River Unit. 14.The Tyonek platform in the NCIU is equipped with a seawater distillation unit. Distilled Cook Inlet water is used for human consumption. Occasionally, Phillips supplements the distilled water with freshwater brought to the platform by boat. Phillips has no plans to use the underlying aquifers as a source of drinking water. 15.Development of the freshwater aquifers below the NCIU by entities other than Phillips is economically impractical because of the offshore location, water depths and currents, drilling costs and readily available alternative freshwater sources onshore. 16.The Commission's authority to act in this matter is embodied in 40 CFR 147 Subpart C, the Alaska Oil and Gas Conservation Act (AS 31.05), and the Alaska Administrative Code (20 AAC 25.005 through 20 AAC 25.570). 17.Portions of aquifers beneath the Cook Inlet underlying the Granite Point, McArthur River, Middle Ground Shoal and Trading Bay fields, regardless of total dissolved solids content, were exempted for Class II injection activities by EPA under 40 CFR 147.102. CONCLUSIONS: 1 .Those portions of freshwater aquifers occurring beneath the North Cook Inlet Field do not currently serve as a source of drinking water. 2.Those portions of freshwater aquifers occurring beneath the North Cook Inlet Field are situated at a depth and location that makes recovery of water for ddnking water purposes economically impractical. 3.Those portions of aquifers occurring beneath the North Cook Inlet Field cannot reasonably be expected to serve as an underground source of drinking water. 4.Those portions of aquifers occurring beneath the North Cook Inlet Field at a depth below 2900' MD in the NCIU A-12 well qualify as exempt freshwater aquifers under 20 AAC 25.440. NOW, THEREFORE, IT IS ORDERED THAT the portions of aquifers in North Cook Inlet Field common to and which correlate with the interval below 2900' MD in the NClU A-12 well in the following tracts of land are exempt under 20 AAC 25.440. Seward Meridian TllN R9W sections 5,6, 7, North 1/2 and Southwest 1/4 of Section 8, North 1/2 of 2 of 3 11/8/01 4:59 PM STATE OF ALASKA Section 18. TllN R10W Sections 1, East 1/2 of section 2, East 1/2 of section 11, Section 12, North 1/2 of section 13. T12N R9W Southeast 1/4 of Section 19, East 1/2 and Southwest 1/4 of Section 20, West 1/2 of Section 21, West 1/2 of Section 28, Sections 29, 30, 31, 32 Northwest 1/4 of Section 33. T12N R10W Southeast 1/4 of Section 25, Southeast 1/4 of Section 35, and Section 36. DONE at Anchorage, Alaska, and dated September 29, 1998. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission Camille; Oechsli, Commissioner Alaska Oil and Gas Conservation Commission Aquifer Exemption Order Index 3 of 3 11/8101 4:59 PM ~ IAII: uP ALASKA I ILL~.I J' ~/VVJ wv. q,~Gtll*% STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE APPLICATION OF PHILLIPS PETROLEUM COMPANY for an order allowing the underground disposal of Class II fluids in the North Cook Inlet Unit A-12 well. ) Disposal Injection Order No. 17 ) ) North Cook Inlet Unit ) North Cook Inlet Unit A-12 well September 29, 1998 IT APPEARING THAT: 1. By letter dated December 10, 1997, Phillips Petroleum Company ("Phillips") requested authorization from the Alaska Oil and Gas Conservation Commission to dispose of Class II oil field waste fluids by underground injection into the North Cook Inlet Unit ("NCIU") A-12 well, located on the Tyonek Platform. Additional information requested by the Commission was received March 10, 1998. 2. The Commission published notice of an opportunity for public hearing in the Anchorage Daily News on December 22, 1997. 3. The Commission received no protest or request for a public hearing. 4. The proposed disposal project requires an aquifer exemption under 20 AAC 25.440. The Commission issued Aquifer Exemption Order #4 on September 29, 1998, after receiving no objection from the U.S. Environmental Protection Agency. FINDINGS: 1. Phillips is the operator of the NCIU. There are no other operators within a one-quarter mile radius of the proposed disposal injection project. The State of Alaska is the surface owner. 2. Phillips is the only working interest owner within the NCIU. 3. Aquifer Exemption Order ~ exempts the portions of aquifers in North Cook Inlet Field that are common to and correlate with the interval below 2900' MD in the NCIU A-12 well. 4. Fluids to be injected will consist of Class II waste fluids associated with drilling, workover and production operations from the NCIU. 5. The NClU A-12 well was originally drilled and completed as a producing gas well in 1970. Phillips requests approval to dually complete the well as a combination production and disposal well. 6. The proposed disposal zone in within the Sterling Formation. The Sterling Formation is composed of coarse-grained clastic intervals with interspersed relatively thin carbonaceous mudstones. Lithologic units are correlative throughout the unit. 7. The proposed Class II disposal interval in the A-12 well is located between 3260' and 3380' MD, within highly porous and permeable fluvial sandstones and conglomerates of the Sterling Formation. 8. The proposed disposal interval is overlain and confined by approximately 95( of fine grained sediments, which will confine and prevent vertical migration of Class II fluids into non-exempt aquifers above 2900' MD in the A-12 well. 9. Structural deformation has folded the Sterling Formation, causing at least 250' of relief in the proposed disposal interval. 1 of 3 11/8/01 5:00 PM STATE OF ALASKA 10.Structural closure and the associated hydrostatic gradient will prevent lateral migration of Class II wastes beyond the NClU. 11 .The NClU A-12 well was constructed with 20" 133 Ib/ft K-55 casing set at 1,990' MD and cemented to surface, and 13 3/8(( 72 Ib/ft N-80 casing set at 6,950( MD. 12.Production tubing in the A-12 well consists of 7" 26 Ib/ft J-55/L-55 tubing from surface to 3,200' MD and 4 1/2" 10.5 Ib/ff J-55 tubing from 3,200' to 5,760' MD. A 2 3/8" 4.7 Ib/ft J-55 disposal tubing was run from surface to 3,206' MD. The well is equipped with multiple packers to isolate production zones and a "twin-flow" packer set at 3,200( MD to isolate pressure to the disposal interval. 13,A cement bond log was run on October 30, 1997, to confirm cement isolation of the disposal zone. The cement bond log, received by the Commission on September 8, 1998, shows good quality cement between 1940( and 5700' MD. 14.The NCIU A-12 passed a mechanical integrity test of the casing-tubing annulus on November 9, 1997. 15.The average disposal rate during peak activity is expected to be about 3000 barrels per day. An average of 300 to 500 barrels per day is anticipated to be disposed of throughout the life of the project, but may be higher, depending on level of drilling activity and amount of water produced with the oil and gas. 16.The maximum anticipated surface injection pressure is 2500 psi. The average injection pressure will range between 1500 and 1800 psi. 17.Fracture modeling studies indicate that the proposed disposal will not initiate or propagate fractures though the confining zone at injection rates and pressures. CONCLUSIONS: 1. The requirements of 20 AAC 25.252 for authorization to dispose of Class II fluids in the NCIU A-12 well have been met. 2. Waste fluids authorized for disposal under this order will consist of Class II waste generated from drilling, production and workover operations in the NCIU. 3. The proposed disposal operations will occur in permeable strata that can be expected to accept fluids at pressures less than the fracture pressure of the confining strata. 4. Waste fluids will be contained within appropriate receiving intervals by confining lithology, cement isolation of the perforated intervals, and operating parameters. 5. Surveillance of disposal rate and pressure, and casing pressure will ensure anomalous performance is observed and diagnosed. Abnormalities in operating conditions may indicate that fluid is not going where intended. 6. There are no aquifers being used as a source of drinking water within or near the NCIU. 7. Disposal into well the NCIU A-12 well will not occur into a non-exempt freshwater aquifer, and will not result in an increased risk of movement of fluids into a freshwater source. 8. The mechanical integrity of this well has been demonstrated in accordance with 20 AAC 25.412. 9. The cement bond log indicated uniform bonding and adequate coverage over the entire logged interval, from 1940-5700' MD. 10.Disposal operations in the NClU A-12 well will not cause waste or jeopardize correlative rights. 2 of 3 11/8101 5:00 PM NOW, THEREFORE, IT IS ORDERED THAT: Rule I Authorized Injection Strata for Disposal Class II oil field fluids may be injected into the NCIU A-12 well in conformance with 20 AAC 25, for the purpose of disposal into strata between the depths of 3260' - 3380' MD. Rule 2 Demonstration of Tubing/Casing Annulus Mechanical Inte.qrity The tubing/casing annulus must be tested for mechanical integrity in accordance with 20 AAC 25.412 prior to initiating injection and at least once every four years. A test surface pressure of 1500 psi or 0.25 psi/ft, multiplied by the vertical depth of the packer, whichever is greater, but not to exceed a hoop stress greater than 70% of the minimum yield strength of the casing is to be used. The test pressure must show stabilizing pressure and a decline of less than 10% in a thirty-minute period. The Commission must be notified at least twenty-four (24) hours in advance to enable a representative to witness pressure tests. Rule 3 Well Integrity Failure Whenever disposal rates, operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the Commission on the first working day following the observation, and obtain Commission approval of a plan for corrective action and Commission approval to continue injection. Rule 4 Surveillance Operating parameters including disposal rate, disposal pressure, annulus pressure and fluid volume must be monitored and reported according to the requirements of 20 AAC 25.432. An annual report evaluating the performance of the disposal operation must be submitted on or about July 1 of each year. RUle 5 Operational Criteria Maximum disposal rates shall not exceed 3000 bbls/day. Maximum surface disposal pressure shall not exceed 2500 psi. Rule 6 Administrative Action Upon request, the Commission may administratively revise this order upon proper showing that the change is based on sound engineering practices and will not allow waste fluids to escape from the disposal zone. DONE at Anchorage, Alaska and dated September 29, 1998. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission Camill~ Oechsli, Commissioner Alaska Oil and Gas Conservation Commission ..Return tO Disposal Injection Order Index 3 of 3 1118101 5:00 PM PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 NORTH AMERICA EXPLORATION AND PRODUCTION COMPANY March 10, 1998 BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING North Cook Inlet Unit "A" No. 12 PPCo. Tyonek Platform North Cook Inlet Unit, Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Ar~chorage, Alaska 99501 Gentlemen: Enclosed for your review is a three-dimensional fracture model of the Sterling Sand injection zone. The referenced well is the NCIU B-1 and has been used for cuttings re-injection over the past 6 months. The cuttings are disposed of through the 2-3/8" tubing string attached to the 13-3/8" surface casing. Also enclosed is a salinity profile based on the A-12 well data. The reservoir engineer has reviewed this and concluded that a salinity change occurs just above the Cook Inlet sands. The estimated total dissolved solids content is now lower than previously estimated, however, it is still above the 3000 ppm requirement. This report is intended as supplemental information to the previous application for the approval of the NClU A-12 well for cuttings re-injection. The structure map that was requested is still in progress. This will be submitted as soon as possible. Please refer to the letter dated February 12, 1998 for the data to justify this proposal. The referenced letter was requesting approval for the disposal of drill cuttings in the A-12 well. Should you have any questions, concerns or require any additional information, please contact Shonna Boyer at (713)669-7980. enc: cc: J. W. Konst W. L. Carrico P. R. Dean ® S. M. Boyer N. P. Omsberg North America Drilling Manager RECEIVED dUi't 1 G 1998 Alaska 0ii & Gas Cons. Commission Anchorage 381 1990 H'b'ton Twin-FIo Seal Assembl ~ 3175 Packer ~ 3200 Sterling Perfs 3260- 3370 Packer @ 3500 Cook Inlet Sands 3558- 3568 Cl-Str~ (Sqz'd) 3577 - 3587 (Sqz'd) 3604- 3628 CI-A (Sqz'd) Packer@3751' ~3820 - 3880 C1-1 3896 - 3960 CI-2 ~3982 - 3994 Cl-3 ~4014 - 4048 CI-4 Packer@4069' 4090-4098 CI-5 ~4106-4111 CI-5 ~4116-4124 CI-5 ~4141-4166 Cl-6 Packer@4175' ~.,,.:4188-4238 CI-7 Packer@4255' 4272-4282 CI-8 ~4298-4316 CI-8 ~4378-4390 C1-10 ~4415-4440 C1-11 Packer@4453' Beluga Sands ~4475-4482 '~ Packer@4569' ~.~ 4660 - 4668 ~4973 - 4978 ~4990 - 4995 ~5010 - 5025 "'E" ~.'~!5050 - 5057 'E" ~!5064 - 5070 'E' ~5120 - 5135 ~5150 - 5157 ~5194 - 5204 Packer@5251' 5292-5305 -H" ~5354-5372 'H" ~5394-5414 'H" ~5431- 5436 "l" Packer~5448' I 5466-5480 * 'r _-~.~5482-5490 * -r i ~5514-5521 * -I" ~5532-5540 -r _/ ' ~5564-5574 -j" ~5576-5584 * -j- ~5592-5596 * -J" f-~X~N" ~,_,,:~5668-5674 * -~ ~5757-5764 "M" @5986' ~6130-6150 ~6180-6186 * 'Q" ~6330-6338 ~6441-6448 "'S' 2 3/8" Tbg ~6540-6547 * "'S" -~6641-6646 "'T" ~6718-6726 ~6748-6758 -U" ~6790-6800 'U" !i? ................ iiiiiCIBP '6834' Jpdated 11118/97 AL WELL COMPLETION DIAL .... ~'M FMC 6 318" IS-A FMC Annulus Fluid: 8.6 ppg 2 % KCL Water with 70/30 Glycol RKB-SL: TOC: Circulated to Surface WATER DEPTH: 100 ' RKB-ML: Production Casing: 133 lb/fl 72 Ib/fl 132.00 232.00 Tubing String: 26 ib/fl 4.7 Ib/fl COMPLETION STRING Elevation Correction Elevation ~ Hanger + 2' BT&C x ST/L Crossover 7" 26 Ib/fl J-55 ST/L Tubing (9 Joints + 3 Halliburton "CP-2" TRSSV with Top & Bottom Subs 7" 26 Ib/fl J-55 ST/L Tubing (67 Joints) Halliburton Twin Flo Seal Assy. 4 1/2" 12.75 Ib/fl L-80 EUE 8rd Tubing ( 9 Joints + "MSN" Seals (3) and Seal Extension (6.0' Leal Muleshoe Guide (0.88' Length) Halliburton MWD P'rm'nent Pkr Halliburton MWD P'rm'nent Pkr : Halliburton Seal Bore Extension and Tbg. Adapter. I/2" 12.75 lb/fl N-SO EUE 8rd Tubing (8 Jts + 2' Halliburton "No-Go" Seal Unit Length Halliburton MWD P'rm'nent Pkr and 4 i/2" 12.75 Ib/ff N-80 EUE 8rd Tubin Halliburton "XD" Sliding Sleeve 4 1/2" 12.75 ib/ft N-80 EUEgrd' Halliburton "No-Go" Seal Unit Length Halliburton MWD P'rm'nent Pkr and 4 1/2" 12.75 lb/fi N-go EUEgrdTubing (I Jts +4 Halliburton "XD" Sliding Sleeve 4 1/2" 12.75 lb/fl N-80 EUE 8rd Tubing (! Jts + 8' Halliburton "No-Go" Seal Unit Lea Halliburton MWD P'rm'nent Pkr and 4 !/2" 12.75 lb/fl N-80 EUE 8rd Tubin Halliburton "No-Go" Seal Unit Length Halliburton MWD P'rm'nent 4 I/2" 12.75 lb/fl N-80 EUE 8rd Halliburton "XD" Sliding Sleeve 4 I/2" 12.75 lb/fl N-80 EUE 8rd Tubing ( 3 Halliburton "No-Go" Seal Unit Length Halliburton MWD P'rm'nent Pkr and Tb 4 !/2" 12.75 Ib/fl N-SO EUE 8rd Tubing ( 3 Halliburton "No-Go" Seal Unit Length Halliburton 1~ Pkr and Tb 4 1/2" 12.75 lb/fl N-80 EUE8rdTubin Halliburton "XD" Sliding Sleeve 4 1/2" 12.75 lb/fl N-80 EUE 8rd Tubing ( 2 Jts. + I Halliburton "No-Go" Seal Unit Length = 3.96 OA Halliburton MWD P'rm'nent Pkr and Tb 4 1/2" 12.75 lb/fl N-gO Halliburton "XD" Sliding Sleeve 4 I/2" 12.75 Ib/ff N-80 Halliburton "No-Go" Seal Unit Length ,= 7.29 OA Halliburton MWD P'rm'nent Pkr and 4 1/2" 12.75 lb/fl N-80 EUE 8rd Tubin Halliburton "XD" Sliding Sleeve 4 I/2" 12.75 N-80 EUE 8rd Tubin Halliburton 4 1/2" "XN" Nipple Wireline Guide SHORT STRING DISPOSAL TUBING 2 3/8" 4.7 lb/fl CS Hydril J-55 Tubing Halliburton Type "XXO" Landing Nipple 2 3/8" 4.7 lb/fl CS Hydril J-55 Tubing Halliburton 2 3/8" "XN" Nipple Muieshoe Guide and Seal Assembly 'Tubing 3820-3880 C1-1~ Beluga"A" 4475- 3896-3960 CI-2 " "B" 4660- 3982-3994 Cl-3 " "E" 4973- " "E" 4990- 4014-4048 CI~ " "E" 5010- 4090-4098 CI-5 " "E" 4106-4111 CI-5 " "E" 4116-4124 CI-5 Beluga"F" 4141-4166 CI-6 " "F" 4188-4238 CI-7 Beluga"G" 4272-4282 Cl-8 Beluga"H" 4298-4316 CI-8 " "H" 4378-4390 C1-10 " "H" 4415 - 4440 C1-11 ~ Beluga I s70i' ,3.125I ,990[' '2.660I ,8101 3.12~] I ,.~9oL ~.3~ 4482 Beluga"l~ 5532- 5540 4668 Beluga"J" 5564-5574 4978 ""J" 5576-5584 4995 5025 " "J" 5592-5596 5050-5057 Beluga"L" 5668-5674 5064-5070 Beluga"M" 5757-5764 5120-5135 Beluga"Q" 6088-6096 5150-5157 " "Q" 6130-6150 5194-5204 " "Q" 6180-6186 5292-5305 Beluga"R" 6330-6338 5354-5372 Beluga"S" 6441-6448 5394-5414 " "S" 6540-6547 5431-5436 Beluga"T" 6641-6646 5466-5480 Beluga"U" 6718-6726 5482-5490 " "U" 6748-6758 " "U" 6790-6800 PBTD: 6,823' [Supv: Sim't'n; Babin'x ]'Cog Wt: 7.0 "26 lb/fl J-55 ST/L + 4 I/2" 12.75 lb/fi J-55 Well: North Cook Inlet Unit No. A-12 November 18, 1997__ Location: Lower Cook Inlet, Alaska Field: ~Cook Inlet Unit PRE) Top of Fish @ 5986' 2 3/8" Tbg PBTD 6823' 381 1990 H'b'ton Twin-FIo Seal Assembl ~3175 Packer ~ 3200 Sterling Perfs 3260 - 3370 Packer @ 3500 Cook Inlet Sands 3558 - 3568 (Sqz'd) 3577 - 3587 (Sqz'd) 3604 - 3628 CI-A (Sqz'd) Packer@3751' ~3820~3880 C1-1 ~3896-3960 Cl-2 ~3982-3994 Cl-3 ~4014-4048 CI-4 Packer@4069' 4090-4098 CI-5 ~4106-4111 CI-5 ~4116-4124 CI-5 ~4141 - 4166 CI-6 Packer@4175' ~4188-4238 CI-7 Packer @ 4255' 4272 - 4282 Cl-8 ~4298-4316 CI-8 ~4378-4390 C1-10 24415-4440 C1-11 Packer@4453' Beluga Sands ~4475-4482 'A" Packer@4569' ~4660-4668 "'S" ~4973-4978 "'E" ~4990-4995 "'E" ~5010-5025 "'E" 25050-5057 "'E" ~5064-5070 "'E" 25120-5135 "'~ ~5150-5157 "'~ ~5194-5204 "'G' Packer@5251' 5292-5305 "'H" ~5354-5372 "'H" ~5394-5414 'H" ~5431-5436 Packer~5448' 5466-5480 * "'~- ~5482-5490 * -'~- ~5514-5521 * "'~" ~5532-5540 ~5564-5574 "'J" ~5576-5584 * 25592_5596 * .,j. 5668-5674 * "'~ 5757-5764 "'U" EZSV@5935' 8088-6096 * ~Q" ~6180-6186 * "'Q" ~6330-6338 "'R" ~6441-6448 "'S" ~6540-6547 * -'S- ~6641-6646 "'T' ~.,::6718-6726 "'U" ~6748-6758 'U" ~6790-6800 "'U" CIBP 6834' J ~iAL WELL COMPLETION DIA(~~ ~M BPV(MaI~e~: ~,e,OD) FMC 6 318" IS-A Tbg. Hgr.0VIake,Type) FMC Annulus Fluid: 8.6 ppg 2 % KCL Water with 70/30 Glycol TOC: Circulated to Surface Production Casing: 133 lb/it 72 lb/ft RKB-SL: 132.00 WATER DEPTH: 100 ' RKB-ML: Tubing String: 26 lb/ii 4.7 lb/ff COMPLETION STRING 232.00 Elevation Correction Elevation FMC Tubing Hanger + 2' BT&C x ST/L Crossover 7" 26 lb/ff J-55 ST/L Tubing (9 Joints + 3 Halliburton "CP-2" TRSSV with Top & Bottom Subs 7" 26 lb/it J-55 ST/L Tubing ( 67 Joints) Halliburton Twin Flo Seal Assy. 4 1/2" 12.75 lb/ii L-80 EUE 8rd Tubing ( 9 Joints' "MSN" Seals (3) and Seal Extension Muleshoe Guide (0.88' Length) Halliburton ~ P'rm'nent Pkr and; Halliburton MWD P'rm'nent Pkr and Tbg. Ada Halliburton Seal Bore Extension and 4 1/2" 12.75 lb/it N-80 EUE 8rd Tubing (8 Jts + 2' Halliburton "No-Go" Seal Unit Length Halliburton MWD P'rm'nent 4 1/2" 12.75 lb/it N-80 EUE 8rd Tubing (8 Jts + 8' Halliburton "XD" Sliding Sleeve 4 1/2" 12.75 lb/it N-80 EUE 8rd Tubing (2 Jts + 2' Halliburton "No-Go" Seal Unit Length Halliburton MWD P'rm'nent Pkr 4 1/2" 12.75 lb/it N-80 EUE 8rd Tubing (1 Jts + 4 Halliburton "XD" Sliding Sleeve 4 1/2" 12.75 lb/it N-80 EUE 8rd Tubing (1 Sts + 8' Halliburton "No-Go" Seal Unit Halliburton 1VIVID P'rm'nent Pkr and Tbg. Adapter. 4 1/2" 12.75 lb/it N-80 EUE8rdTubing (2 Jts +1 Halliburton "No-Go" Seal Unit Length Halliburton MVCD P'rm'nent Pkr and Tbg. 4 1/2" 12.75 lb/it N-80 EUE 8rd Tubing ( 3 Jts + Halliburton "XD" Sliding Sleeve 4 1/2" 12.75 lb/it N-80 EUE 8rd Tubing ( 3 Joints) Halliburton "No-Go" Seal Unit Length Halliburton lVlWD 4 1/2" 12.75 lb/it N-80 EUE 8rd Tubing ( 3 Jts. + IG Halliburton *'No-Go" Seal Unit Length Halliburton MWD P'rm'nent 4 1/2" 12.75 lb/it N-80 EUE 8rd Tubing ( 20 Jts. + Halliburton "XD" Sliding Sleeve 4 1/2" 12.75 lb/it N-80 EUE 8rd Tubing ( 2 Jts. + 1 Halliburton "No-Go" Seal Unit Length = 3.96 OA Halliburton 1VI%VD P'rm'nent Pkr and' 4 1/2" 12.75 lb/it N-80 EUE 8rd Halliburton "XD" Sliding Sleeve 4 1/2" 12.75 lb/it N-80 EUE 8rd Tubing ( 2 Joints) Halliburton "No-Go" Seal Unit Length = 7.29 OA Halliburton MWD P'rm'nent Pkr and Tbg. 4 1/2" 12.75 lb/it N-80 EUE 8rd Tubing ( 6 Jts. + 2' Halliburton "XD" Sliding Sleeve 4 1/2" 12.75 lb/it N-80 EUE 8rd Tubing ( 4 Halliburton 4 1/2" "XN" Nipple Wireline Guide End of Tubing SHORT STRING DISPOSAL TUBING 2 3/8" 4.7 lb/it CS Hydril J-55 Tubing Halliburton Type "XXO" Landing Nipple 2 3/8" 4.7 lb/it CS Hydril J-55 Tubing Halliburton 2 3/8" "XN" Nipple Muleshoe Guide and Seal Assembly End of Tubing. 3820-3880 C1-1 Beluga "A" 3896-3960 CI-2 " "B" 3982-3994 CI-3 " "E" 4014-4048 CI-4 " "E" 4090-4098 CI-5 .... E" 4106-4111 CI-5 " "E" 4116-4124 CI-5 Beluga "F" 4141-4166 Cl-6 .... F" 4188-4238 CI-7 Beluga"G" 4272-4282 CI-8 Beluga"H" 4298-4316 CI-8 .... H" 4378-4390 C1-10 " "H" 4415-4440 C1-11 Beluga"l" 4475-4482 Beluga"l" 5532-5540 4660-4668 Beluga ~" 5564-5574 4973-4978 ""J" 5576-5584 4990-4995 5010-5025 " ~" 5592-5596 5050-5057 Beluga"L" 5668-5674 5064-5070 Beluga"M" 5757-5764 5120-5135 Beluga"Q" 6088-6096 5150-5157 " "Q" 6130-6150 5194-5204 " "Q" 6180-6186 5292-5305 Beluga"R" 6330-6338 5354-5372 Beluga"S" 6441-6448 5394-5414 " "S" 6540-6547 5431-5436 Beluga"T" 6641-6646 5466-5480 Beluga"U" 6718-6726 5482-5490 " "U" 6748-6758 " "U" 6790-6800 PBTD: 6,823' ISupv: Sim't'n; Babin'x ITbg Wt: 7.0 "26 lb/ii J-55 ST/L + 4 1/2" 12.75 lb/it J-55 Well: North Cook Inlet Unit No. A-12 I November 18, 1997 11/18/97 Location: Lower Cook Inlet, Alaska Field: Cook Inlet Unit PRD :~TE OF ALASKA ALASKA OiL ~ND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 ~ Type of Request: Operation Shutdown ~ Stimulate Perforate X Pull Tubing Alter Casing ~ Other 2. Name of Operator: Phillips Petroleum Co. 3. Address: 6330 W. Loop South Bellaire, Texas 77401 4. Location of well at surface: 1254' FNL & 927.8' FWL At top of productive interval: 1254' FNL & 927.8' FWL At effective depth: 1254' FNL & 927.8' FWL At total depth: Not Applicable 11. Present well condition summary: Total Depth: measured true vertical Effective Depth: measured true vertical Leg 1, Slot 3 PPCo. Tyonek Platform Sec 6 - T11N - R09W North Cook Inlet, Ak. Sec 6 - T11N - R09W Sec 6 - T11N - R09W 5. Datum elevation (DF or RKB) RKB 116 Feet 6. Unit or Property Name North Cook Inlet Unit 7. Well Number A-12 8. Permit Number / Approval Number 69-99 9. APl Number 50-883-20032 0. Field / Pool Cook Inlet / Belu~la 14,910 feet Plugs (measured) PBTD 6,823' feet Junk (measured) 3,558 feet 3,558 feet Casing: Structural Conductor Surface Intermediate Production Liner Length Size Cemented Measured De~h True Vertical Depth 30" Driven 381 381 20" 1,142 sx 1990' 1990' 13-~8" 1820 sx CI"G 6950' 6950' Perforation Depth: measured 3,558 - 6,800' PerfsAdded- 3260'-70' true vertical 3,558 - 6,800' PerfsAdded- 3260-70' Tubing (size, grade and measured dept 7" 26 LB/FT J-55/L-55 Surface to 3,200' 4 1/2" 10.5 Ib/ft J-55 3,200 - 5,760' 2 3/8" 4.7 Ib/ft J-55 Surface to 3,206' (Disposal Tubing) Packers and SSSV ( type and measured depth) Hal. "AWR" Packers @ 5448', 5251', 4569', 4453', 4255', 4175', 4069', 3750', 3,500' TRSSV (~ 435' in 7" tb~l 12. Stimulation or cement squeeze summary Intervals treated (measured) 0RJ$INAL Treatment description includin~l volumes used and final pressure 13 Representative Daily Average Production or Injection Data OiI-Bbl Gas - Mcf Water- Bbl Prior to well operation 0 7.3 MMcf 0 'Hal. Twin-Fie @ 3200' (SEE ATTACHED DIAGRAMI RECEIVED JAN 1 2 1998 Alaska 0il & ~as Cons. Commission Casing Pressure Tubing ~e 130 psi 797 psi Subsequent to operation 0 19.8 MMcf 39 BBL 230 psi 807 psi 14. Attachments Daily Report of Well Operations copies of Lo~ls and Surveys Run: CBL forwarded previously 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~_~_,_0_~, ~ _["z~a.~._) Title ~'J% ~J"'J,Q L"~_~i,,,~/:]~__~=. Date J~'l~l'~ Form 10-404 Rev. 12/1/85 '" " SUBMIT IN DUPLICATE PHILLIPS PETROLEUM COMPANY HOUSTON, TEXAS 77251-1967 BOX 1967 NORTH AMERICA PRODUCTION DIVISION BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING December 30, 1997 North Cook Inlet Unit "A" No. 12 PPCo. Tyonek Platform North Cook Inlet Unit, Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Blair Wondzell Gentlemen: Enclosed for your consideration and approval are the Forms 10-404 and 10-407 for the NCIU A-12 well. A final well completion diagram and a daily report of well operations are included with these forms. Should you have any questions or require any additional information, please contact Paul R. Dean at (713) 669-3502 or Raj Hingorani at (713) 669-3554. ORIGINAL Regards, N. P. Omsberg North America Drilling Manager CC: J. W. Konst A. Lasche Central Files RECEIVED JAN '1 2 1998 Alaska 0ii & Gas Cor~s. c;ommission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS ~ SUSPENDED[~ ABANDONED [~ SERV~ ~, Producing Gas Well 2. Name of Operator~ ~ 7. Permit Number Phillips Petroleum Co. ~ 69-99 3. Address ,,,,,~.. 8. APl Number 6330 W. Loop South, Bellaire, TX 77401~~ t 50-883-20032 4 Location of well at surface ~ 9. Unit Name 1254' FNL & 927.8' FWL SEC 6-T 11N-R09W North Cook Inlet At Top Producing Interval 10. Well Number 1254' FSL & 927.8' FEL SEC 6-T 11N-R09W NCIU A-12 At Total Depth 11. Field and Pool 1254' FSL & 927.8' FEL SEC 6-T 11N-R09W 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Cook Inlet / Beluga RKB 116 ft. NCIU 12. Date Spudded 13. Date T.D. Reached 14. Date Suspended 15. Water Depth 16. No. of Completions 07/30/97 10/08/97 10/17/97 130 17. Total Depth 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. SSSV Depth 21. Thickness of Permafrost 15500 6,823(MD) 6,823 (TVD) YES [~ NO I~ KB 22. Type Electric Logs Run Cased Hole Schlumberger CBL and Depth Control Log 23. CASING, LINER AND CEMENTING RECORD Casing Size wt. per ft. Grade Setting Depth (MD) Hole Size Cementing Record Amount Pulled 30" 381 Driven 20" 133 K-55 1,990 24" 1142 sx None 13 3/8" 72 N-80 6,950 18.5" 1820 sx None 24. Perforations open to Production(MD+TVD of Top and 25. Tubing Record Bottom and interval, size, and number) Size Depth Set (MD) Packer Set (MD) 7" 3200' See Attached Diagram 13 3/8" casing perforated from 3260-3270 4 1/2" 3200'-5760 See Attached Diagram , (For purpose of cuttings disposal) 2 3/8" 3206' for cuttings disposal See Attached Diagram 26. Acid, Fracture, Cement Sqeeze, ETC. ...... I I I 27. PRODUCTION TEST Date First Production Method of Operation (flowing, gas lift, etc.) N^ Flowing Date of Test Hours Tested Prod. for Oil Gas Water-BBL Choke GOR Test Period FTP Casing Pressure Calculated Oil Gas Water-BBL Choke GOR 807 psi 230 psi 24 hr Rate 19.8 Mmcf 39 BBL 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 Rev 7-1-80 Submit in Duplicate 29 30 GEOLOGICAL MARKERS FORMATION TESTS Include interval tested, pressure data, all NAME MEAS. DEPTH TRUE VERT. DEPTH fluids recovered and gravity, GOR, and time of each phase. ,, 31. LIST OF ATTACHMENTS 32 I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~~- ~. ~ Title ~?. i~,c~ --~' ~ Date_ L~..,~. ~_ ,J ~_,~/. From 10-407 Rev 7-1-80 Legal Well Name: NORTH COOK INLET UNIT 00A-12 Common Well Name: North Cook Inlet Unit No. A-12 Spud Date: 10/22/69 Event Name: Workover Start: 10/13/97 , End: Contractor Name: Pool Arctic Alaska Rig Release: 04/26/94 Group: i Rig Name: Pool Arctic Alaska Rig Number: 429 10/22/97 00:00 - 01:00 1.00 MV v 00MMIR SKID RIG FROM NClU B-1 TO A-12. ***VERBAL APPROVAL FROM BLAIR WONDZELL ALASKA OIL & GAS. SUNDRY APPROVAL #397175 10/11/97. 01:00 - 10:00 9.00 WS 6 90WOVR BUILD 400 BBLS 8.5# 2% KCL + 2#/BBL XANVlS. WT 8.5# CHL 9600 PPM. RU LINES TO KILL WELL. RU 7" & 2" RISERS FROM TOP OF TREE TO RIG FLOOR. 10:00 - 12:30 2.50 WS 8 90WOVR PRES TEST RISERS 1500# & PUMP LINES 3000#. 12:30 - 13:30 1.00 WS 0 90WOVR SAFETY MEETING W/PRODUCTION & RIG CREW ON KILL PROCEDURE. 13:30 - 15:30 1.50 WS 5 90WOVR SITP 2" & 7" 900#. CSG ANNULUS "0" & STANDING FULL. PUMP DOWN 2" TAKING RETURNS THRU FLOWLINE TO PRODUCTION SEPARATOR, UNTIL FLUID TO SURFACE. PUMPED 170 BBLS KILL FULL & PRODUCED W'FR @SURFACE. PRODUCED VVTR = 8.5# CHL 5500 PPM. SD PUMPING. 15:30- 17:00 1.50 WS v 90WOVR SlTP 2 .... 0" & 7" 400#. SWITCH RETURN LINE FROM PRODUCTION TO RIG CHOKE MANIFOLD. CONTINUE TO PUMP KILL FLUID DOWN 2" TAKING RETURNS THRU 7". PUMPED TOTAL 316 BBLS W/PRES ON 7" DROPPING TO 125#. SD TO BUILD MORE KILL FLUID IN RIG PITS. 17:00 - 18:30 1.50 WS !v 90WOVR BUILD 300 BBLS KILL FLUID. SlTP 7" 125# INCREASED TO 500# SlTP 2""0". 18:30 - 22:00 3.50 WS v 90WOVR RESUME PUMPING KILL FLUID. LOST PARTIAL RETURNS W/175 BBLS PUMPED. PUMPED 318 BBLS & SHUT DOWN TO MIX MORE KILL FLUID. 22:00 - 00:00 2.00 WS v 90WOVR BUILD 300 BBLS KILL FLUID. SlTP 7" 0#, INCREASED TO 80 PSI BY MIDNIGHT. 10/23/97 00:00 - 03:00 3.00 WS v 90WOVR BUILD 300 BBLS KILL FLUID. SlTP 7" INCREASED 80# TO 500#. BLED OFF PRESSURE. 03:00 - 04:30 1.50 WS v 90WOVR PUMP DOWN 2" TBG 120 BBLS. NO RETURNS ON 7". SD PUMPING. 04:30 - 07:30 3.00 WS v 90WOVR BUILDING KILL FLUID & INCREASING XANVIS FROM 2 # TO 2.5#/BBL. 07:30 - 09:00 1.50WS v 90WOVR SlTP 7" 150# 2 ..... 0". BLEED OFF 7" START PUMPING DOWN 2". PRODUCED VVTR RETURNS APP 30 BBLS THEN NO RETURNS. PUMPED TOTAL 75 BBLS W/2.5#/BBL XANVIS. 09:00 - 10:00 1.00 WS v 90WOVR SD PUMPING. LEAVE 7" OPEN TO CHOKE MANIFOLD, VENTING OFF GAS. 2" TBG SLIGHT VACUUM. 10:00 - 10:30 0.50 WS v 90WOVR PUMPED 91 BBLS DOWN 2" TBG W/NO RETURNS. SD PUMPING. 10:30 - 16:30 6.00 WS v 90WOVR LEAVE 7" OPEN TO CHOKE MANIFOLD VENTING GAS. BUILD VOLUME & INCREASE XANVIS TO 3#//BBL. 16:30 - 00:00 7.50 WS v 90WOVR STARTED PUMP @ 4.25 BPM, ESTABLISHED CIRCULATION W/67 BBLS PUMPED, LOOSING 1.5 BPM. SLOWED PUMP TO 2.1 BPM, LOSSES DECREASED TO 0.8 BPM THEN DECR'D FURTHER TO 0.4 BPM. MIXING XANVIS TO RAISE CONCENTRATION IN FLUID RETURNING. 10/24/97 00:00 - 02:30 2.50 WS v 90WOVR CONTINUE PUMPING 2%KCL/3 PPB XANVIS KILL FLUID DOWN 2", TAKING RETURNS THRU 7" TBG, LOOSING 0.3 BPM. 02:30 - 10:00 7.50 WS v 90WOVR SD PUMP. BUILDING KILL FLUID VOL & RAISING XANVIS CONCENTRATION TO 3.5 PPR. 10:00 - 17:00 7.00 WS v 90WOVR RESUMED PUMPING KILL FLUID W/3.5 PPB XANVIS DOWN 2 3/8 Printed: 01/02/98 1:36:48 PM Legal Well Name: NORTH COOK INLET UNIT 00A-12 ~Common Well Name: North Cook Inlet Unit No. A-12 Spud Date: 10/22/69 Event Name: Workover Start: 10/13/97 End: Contractor Name: Pool Arctic Alaska Rig Release: 04/26/94 Group: Rig Name: Pool Arctic Alaska Rig Number: 429 10/24/97 10:00 - 17:00 7.00 ws v 90WOVR STRING, LOOSING APPROX 0.3 BPM. 17:00 - 20:00 3.00 WS v 90WOVR SD PUMP. REMOVE PUMP LINES FPJ TBG STRINGS. 2 3/8" TBG WAS STATIC. 7" TBG ON SLIGHT INTERMITENT VACUUM. OBSERVE WELL FOR 2 1/2 HRS. RU TO PUMP DOWN 2". ESTABLISH CIRC THRU 7" W/12 BBLS. 20:00 - 21:00 1.00 WS v 90WOVR CIRC DOWN 2" W/RETURNS UP 7". PUMPED 116 BBL LOST 8 BBL FLUID. 21:00 - 22:30 1.50 WS v 90WOVR SI 7" TBG.. OBSERVE WELL 1 1/2 HRS SITP ON 7" STRING = 0, 2 3/8 WAS STATIC. 22:30 - 00:00 1.50 WS v 90WOVR PREPARE TO SET BPV'S IN HANGER. REMOVED BELL NIPPLE, INSTALL MASTER BUSHING. CLOSED SWAB VALVES & BLOCKED/BLED PRESS OFF 7" FLOWLINE PRIOR TO PULLING 2 3/8" & 7" RISERS. 10/25/97 00:00 - 00:30 0.50 WS i e 90WOVR HELD PRE JOB SAFETY MEETING. 00:30-06:00 5.50 WS e 90WOVR SET 2 3/8 & 7" BP VALVES IN TBG HANGER. NDTREE. 06:00 - 14:30 8.50 WS e 90WOVR NU 13 5/8" 10M BOP STACK & INSTALL RISER. 14:30 - 21:30 7.00 WS u 90WOVR RU FMC & WORK TO PULL 2" BACK PRESSURE VALVE. EXPERIENCED DIFFICULTY GETTING RUNNING TOOL TO LATCH BPV. PU 2 3/8" RISER & RAN IT TO TOP OF HANGER TO SERVE AS A GUIDE FOR EXTENSION ROD ON RUNNING TOOL. OPEN PRONG. 2" SIDE STATIC. LATCH ONTO & PULL 2" BPV. 21:30 - 22:30 1.00 WS u 90WOVR FMC INTALLED 2" TEST PLUG IN HNGR BLED PRESS OFF 7" TBG. PULLED 7" BPV, THEN SET 7" TEST PLUG. , 22:30 - 00:00 1.50 WS 8 90WOVR TEST BOPE: ANUULAR, BLIND RAMS & ALL BREAKS TO 250/3000 PSI. TEST CHOKE MANIFOLD TO 250/3000 PSI WHILE WORKING TO PULL 2" BPV. 10/26/97 00:00 - 00:30 0.50 WS 8 90WOVR FINISHED TESTING BOPE. 250/3000#. 00:30 - 05:00 4.50 WS u 90WOVR PULL 7" & 2" TEST PLUGS 05:00 - 06:00 1.00 WS e 90WOVR RU 7" RISER & SCREW INTO DUAL HGR. 06:00 - 07:00 1.00 WS e 90WOVR BACK OUT HANGER HOLD DOWN PINS. 07:00 - 08:30 1.50 WS z 90WOVR RELEASE DUAL HGR W/160000k. PU 7" & 2" TBG TOTAL 78" W/MAX PULL 185K. 2" TBG BELOW TWIN FLOW HEAD APPEARS TO BE MOVING. 08:30 - 09:00 0.50 WS 2 90WOVR SET HGR BACK DOWN IN WELLHEAD. RD 7" RISER. RU 2" RISER. 09:00 - 10:30 1.50 WS 6 90WOVR RU WEATHERFORD TBG TONGS & EQUIPMENT. 10:30 - 11:00 0.50 WS 2 90WOVR PU ON 2" TBG, RELEASE FROM DUAL HANGER & SEAL ASSY IN TWIN FLOW HEAD. PULL 2" HANGER TO FLOOR & LD SAME. 11:00 - 13:00 2.00 WS 5 90WOVR FMC RU ON 2" SSSV CONTROL LINE. PUMPED OPEN SSSV. CIRCULATED OUT PKR FLUID FROM TWIN FLOW HEAD TO SURFACE. 13:00 - 13:30 0.50 WS 0 90WOVR SAFETY MEETING W/CREWS ON LD TBG. 13:30 - 17:30 4.00 WS 2 90WOVR POOH LD 2" TBG., CONTROL INE,SSSV W/FLOW COUPLINGS. CON'T POOH LD REST OF TBG & SEAL ASSY. 17:30 - 18:00 0.50 WS z 90WOVR i CLEAN RIG FLOOR & CHANGE OUT ELEVATORS. 18:00 - 19:30 1.50 WS z 90WOVR MU DP W/XO INTO 2 3/8/7" TBG HANGER. PU 31' PULLING 185000#, UNABLE TO WORK BACK DOWN. PUMPING @ 2.5 BPM TRYING TO WORK PIPE FREE. FLOW INCREASED. CHECK FLOW, WELL Printed: 01/02/98 1:36:48 PM iLegal Well Name: NORTH COOK INLET UNIT 00A-12 Common Well Name: North Cook Inlet Unit No. A-12 Spud Date: 10/22/69 Event Name: Workover Start: 10/13/97 End: Contractor Name: Pool Arctic Alaska Rig Release: 04/26/94 Group: Rig Name: Pool Arctic Alaska Rig Number: 429 10/2~/~7 1~:00 - 19:30 1.50 WS z ~0WOVR FLOWING. SHUT DOWN PUMP & SHUT IN WELL. SITP = 500 PSI SICP = 0. 19:30- 21:00 1.50 WS v ~0WOVR CIRCULATE BOTTOMS UP THROUGH CHOKE @ 2.5 BPM. TP = 500, CP = O. 21:00 - 21:30 0.50 WS g 90WOVR OBSERVE WELL FOR FLOW. CSG DEAD. TP = 500 PSI. OPEN STAND PIPE TO TRIP TANK TO BLEED OFF PRESS, HAD GAS AT SURFACE ON TUBING. SI STND PIPE. 21:30 - 22:30 1.00 WS v 90WOVR RESUME CIRCULATING ON CHOKE @ 5 BPM. PUMPED 7" TBG + ANNULAR VOLUME. 22:30 - 23:00 0.50 WS v 90WOVR SD PUMP & CHECK FLOW. WELL NOT FLOWING BUT GAS PERCOLATING UP THRU KILL FLUID. 23:00 - 00:00 1.00 WS v ~0WOVR RF=SUME CIRCULATING @ 5 BPM W/ HYDRIL OPEN. 10/27/~7 00:00 - 01:30 1.50 WS v 90WOVR CONTINUE TO CIRC OUT GAS CUT MUD. 01:30 - 02:00 0.50 WS g ~0WOVR OBSERVE WELL WHILE CIRC TRIP TNK ACROSS HOLE. HOLE TOOK 1.5 BBL/0.5 HR. 02:00 - 02:00 1.00 WS z ~0WOVR 1 HOUR TIME CHANGE. 02:00 - 02:30 0.50 WS ~ ~0WOVR ATTEMPT TO WORK PROD TBG ASSY FREE. PULLED 1 ~SK - DUAL HANGER 31' ABOVE HEAD. STUCK 2 3/~" TBG. 02:30 - 04:00 1.50 WS 5 ~0WOVR CIRCULATE & BUILD VOLUME - MINIMAL LOSSES. 04:00 - 04:30 0.50 WS 0 ~0WOVR HELD PRE JOB SAFETY MEETING & RU ALASKJ~ PIPE RECOVERY WL UNIT. 04:30 - 0~:00 1.50 WS z 90W©VR APRS RIH W/1 13/1~" JET CUTTER & COLLAR LOCATOR THROUGH 2" SIDE OF DUAL HANGER. CONTINUE RIH THRU TWIN FLOW ADAPTER & INTO 2" SIPHON STRING. TAG FILL @ ~10~' (WLM), LOCATE SLIDE SLEEVE @ $001' (WLM), CUT 2 3/8" @ 5~' (WI_M). POOH & RD APRS WL UNIT. 05:00 - 0~:30 0.50 WS 0 ~0W©VR CIRCULATE & HELD PRE JOB SAFETY MEETING. 0~:30 - 0~:00 1.50 WS r 90WOVR PU & PULL DUAL HANGER. LD 5 × 7" RISER JT & FMC DUAL HANGER. 08:00 - 1§:00 7.00 WS 2 90WOVR POOH, LD 7" PRODUCTION TBG STRING SCSSV & TWIN FLOW ADAPTER. 1§:00 - 15:30 0.50 WS 2 90WOVR CIRCULATE. CHANGE OUT HANDLING TOOLS AND TONGS. PUMP SLUG. 15:30 - 21:00 5.50 WS 2 90WOVR POOH, LD 2 3/~" SIPHON TBG ASSY. NOTE: LEFT 1/2 JT 2 3/~", SLIDING SLEEVE, 21 JTS 2 3/~" TBG, "XN" NIPPLE & WL RE-ENTRY GUIDE IN THE HOLE F/APPRO× 834' OF FISH. 21:00 - 22:00 1.00 WS ~ ~0WOVR RD WEATHERFORD'S TONGS & HANDLING TOOLS. CLEAR RIG FLOOR. 22:00 - 00:00 2.00 WS ~0WOVR PU BAKF=R'S MILLING ASSY: 12 1/~" SHOE, E×TENSION, DRIVE SUB, DBL PIN SUB, 3 - BOOT BASKETS, BIT SUB, BUMP SUB, OIL JAR, ×O SUB &WILL PU 10 DC'S. 10/2~/~7 00:00 - 03:00 3.00 WS 4 ~0WOVR PU 10 - ~ 1/2" DC's ON PKR MILLING ASSY. 03:00 - 03:30 0.50 WS 5 90WOVR WELL KICKING UP DRILL STRING - CIRC OUT GAS CUT MUD. 03:30 - 10:30 7.00 WS 4 90WOVR PUMP IN HOLE W/PKR MILLING ASSY 10:30 - 17:30 7.00 WS h 90WOVR TAGGED PKR @ 2748'. MILLED OVER TOP SLIPS & PKR ELEMENT. 17:30 - 21:00 3.50 WS 4 90WOVR TIH PUSHED PKR TO 3843'. UNABLE TO PUSH PKR ANY DEEPER. Printed: 01/02/98 1:36:48 PM Legal Well Name: NORTH COOK INLET UNIT 00A-12 Common Well Name: North Cook Inlet Unit No. A-12 Spud Date: 10/22/69 Event Name: Workover Start: 10/13/97 End: Contractor Name: Pool Arctic Alaska Rig Release: 04/26/94 Group: Rig Name: Pool Arctic Alaska Rig Number: 429 10/28/97 17:30- 21:00 3.50 WS 4 90WOVR D~G PKR BACK UP TO 3813'. UNABLE TO GO BACK DOWN. 21:00 - 21:30 0.50 WS 5 90WOVR MIX & PUMP DRY JOB. 21:30 - 22:30 1.00 WS 4 90WOVR POOH. D~GGING PKR UP THE HOLE 2 8TDS THEN LOST IT. 22:30 - 23:00 0.50 WS 4 90WOVR TIH SET DOWN ON PKR ~ 3~3'. STILL COULD NOT WORK PKR DEEPER. NOTE: RECORDS INDICATE THAT 13 3/8 IS PERFORATED F~ 3820 - 3880'. 23:00 - 00:00 1.00 WS 5 90WOVR ClRC OUT GAS CUT MUD, MIX & PUMP DRY JOB. 10/29/97 00:00 - 01:30 1.50 WS 4 90WOVR PUMP DRY JOB. POOH SLOWLY W/3 STDS. SWABBING DUE TO CLOSE TOLE~NCES & HIGH RHEOLOGY. ;01:30 - 07:00 5.50 WS 4 90WOVR SCREW IN W/TOP DRIVE & PUMP OOH TO 729'. 07:00 - 08:00 1.00 WS 5 90WOVR ClRCU~TE GAS CUT MUD. 08:00 - 08:30 0.50; WS 4 90WOVR PUMP OOH TO 450'. 08:30 - 09:30 1.00 WS g 90WOVR ClRC TRIP TANK ACROSS HOLE & OBSERVE WELL. GAS BREAKING OUT THROUGH WORK STRING. WELL WOULD NOT FLOW. 09:30 - 11:00 1.50 WS 5 90WOVR REVERSE ClRC GAS CUT FLUID. ~11:00- 12:00 .1.00 WS 4 90WOVR FINISH POOH. 12:00 - 13:00 1.00 WS 4 90WOVR LB WASH OVER MILL. MU SPEAR. 113:00 - 15:00 2.00 WS z 90WOVR D~INED STACK & FLUSHED IT W/ OBSERVED TOP OF PKR IN WELL HEAD. RIH W/SPEAR TO 55' & SPEARED PKR. 15:00 - 16:00 1.00 WS 4 90WOVR LD PKR & SPEAR. ~N WEAR BUSHING. 16:00 - 21:30 5.50 WS 4 90WOVR MU BIT & SC~PER. TIH SET DOWN ON SOMETHING ~ 3640' WORK PIPE & ROTATE. DISLODGED OBSTRUCTION. CONTINUE TIH SET DOWN AGAIN ~ 3849' (NOTE: PERFS ~ 3820 - 388o') 21:3o - oo:oo 2.50 ws 5 90WOVR PU TO 3840'. CIRCULATE AND THIN WORKOVER FLUID BACK TO 80 SEC FUNNEL VIS IN & OUT. 10/30/97 00:00- 00:30 0.50 WS 5 90WOVR FINISHED CIRCUITING. 00:30 - 01:00 0.50 WS 4 90WOVR START OUT OF HOLE. 01:00 - 03:30 2.50 RM m 90WOVR CLEAN RUBBER OUT OF TRIP TANK PUMP. 03:30 - 04:30 1.00 WS 5 90WOVR ClRC OUT GAS. 04:30 - 07:00 2.50 WS 4 90WOVR SLUG PIPE & POOH. 07:00 - 07:30 0.50 WS 2 90WOVR ~D BHA. 07:30 - 10:00 2.50 WS 2 90WOVR ~D 24 JTS OF CMT COATED DP. 10:00 - 12:00 2.00 Wi i2 90WOVR MU BULL NOSE TO 12 1/4" WATER MELLON MILL & WELD ON ST~PS. MU BHA. 12:00 - 13:30 1.50WS ~4 90WOVR TIH W/MILL TO 3500'. 13:30 - 21:30 8.00i WS h 90WOVR REAMED CSG F~ 3500 TO 5986' (TOF). REAMED TIGHT SPOTS 3849 - 3859', 3950 - 3965', 4048 - 4061', 4206 - 4218'. TAGGED TOF 5986'. PU 10'. 21:30 - 22:30 1.00; WS 5 90WOVR CIRCULATE BOSOMS UP. ClRCU~TE UP SAND F~ TOF. 22:30 - 00:00 1.50 WS 4 90WOVR START PUMPING OOH. 10/31/97 00:00 - 05:00 5.00 WS 4 90WOVR FINISHED POOH W/BULL NOSE & MILL. 05:00 - 06:30 1.50 WS z 90WOVR STOOD BACK DC'S. LD 1 DC, JARS, XO'S, BUMPER SUB, MILL & BULL NOSE. MILL WORN F/12 1/4" TO 12". 06:30 - 09:00 2.50 LG ~2 90WOVR RU SCHLUMBERGER & TEST LUBRICATOR TO 200 PSI. 09:00 - 14:30 5.50 LG I 90WOVR RIH W/CET-CBL-GR-CCL.TAGGED TOP OF FISH AT 5986'. SLIGHT OVERPULL ON PU. LOGGED UP TO 1950'. POOH WAS MISSING TWO ARM PIECES FROM Printed: 01/02/98 1:36:48 PM Legal Well Name: NORTH COOK INLET UNIT 00A-12 Common Well Name: North Cook Inlet Unit No. A-12 Spud Date: 10/22/69 Event Name: Workover Start: 10/13/97 End: Contractor Name: Pool Arctic Alaska Rig Release: 04/26/94 Group: Rig Name: Pool Arctic Alaska Rig Number: 429 ':~ i~i;~;~iici~i~ ~,~,~ ~~ ......................................................................... ............ ~ 10/31/97 09:00 - 14:30 5.50 LG 1 90WOVR TOOLS. APPROX 8" LONG BY 1/2" TO 3/4" WIDE BY 3/8" THICK. 14:30 - 17:30 3.00 LG z 90WOVR L/D TOOLS. ATTEMPT TO MU & RIH W/GAUGE RING JUNK BASKET BUT SCHLUMBERGER SENT WRONG SIZE GAUGE RING, SAID IT WAS ALL THEY HAD, SPECIAL FLIGHTED OUT SAME. EVALUATED BOND LOGS. 17:30 - 18:30 1.00 CM q 90WOVR RU SCHLUMBERGER TO RUN PERF'G GUNS. 18:30 - 19:00 0.50 CM 0 90WOVR HELD PRE JOB SAFETY MEETING. 19:00 - 21:30 2.50 CM q 90WOVR PREFORATED 13 3/8" CSG IN STERLING SAND FPJ 3260 TO 3320' W/ 3.67" HSC GUNS LOADED W/34 gm RDX SHOTS @ 5 SPF & 72 DEG PHASING (.36" HOLE). MADE 2 GUN RUNS. ALL SHOTS FIRED. CORRELATED W/ SCHLUMBERGER DIL DATED 11/5/69. 21:30 - 22:30 1.00 CM 6 90WOVR RD SCHLUMBERGER WL UNIT & LUBR. 22:30 - 00:00 1.50 WS 90WOVR MU BHA #4: BIT,SCRAPER, B/SUB, BUMPER SUB, JARS, 10 DC'S & XO'S 11/01/97 00:00 - 02:30 2.50 WS 4 90WOVR TIH W/BIT & SCRAPER. TOOK VVT @ 3868', 3911', 3972' & 4058'. SAT 25K DOWN @ 4218'. PULLED 35K OVER TO PU FPJ TIGHT PLACE @ 4218'. 02:30 - 03:00 0.50 WS 5 90WOVR ClRC & PUMPED DRY JOB. 03:00 - 06:30 3.50 WS 4 90WOVR POOH W/BIT & SCRAPER. PULLED 25K OVER @ 4058', THEN CAME OUT OK. 06:30 - 07:30 1.00 WS 2 90WOVR L/D BIT & SCRAPER & PU RTTS W/BYPASS. 07:30 - 10:00 2.50 WS 4 90WOVR RIH W/RTTS TO 3386'. 10:00 - 10:30 0.50 WS z 90WOVR SET RTTS & ESTABLISH INJECTION RATES AS FOLLOWS: 1015 PSI AT 1.0 BPM. 1110 PSI AT 2.0 BPM. 1190 PSI AT 3.0 BPM. 1300 PSI AT 4.0 BPM. 1380 PSI AT 5.0 BPM. 1450 PSI AT 6.0 BPM. 37 BBLS TOTAL PUMPED. 10:30 - 12:00 1.50 WS 5 90WOVR BLED OFF PRESSURE. UNSET RTTS & ClRC BU. 12:00 - 15:30 3.50 WS 4 90WOVR POOH W/RTTS & L/D SAME. 15:30 ~ 17:00 1.50 WC 8 90WOVR TEST CHOKE MANIFOLD, FLOOR VALVES, & TOP DRIVE FOR WEEKLY BOP TEST WHILE WAITING ON BOAT. 17:00 - 20:30 3.50 WS 4 90WOVR WELD STRAPS TO & RIH W/12 1/4" WATERMELLON MILL. 20:30 - 00:00 3.50 WS h 90WOVR REAMING W/VVTR MELLON MILL FPJ 3805 - 5010'. 11/02/97 00:00 - 02:00 2.00 WS h 90WOVR CONTINUE REAMING W/WATER MELON MILL TO 5950' W/NO TORQUE. 02:00 - 04:30 2.50 WS 5 90WOVR CBU. OBSERVE WELL FOR FLOW. 04:30 - 08:30 4.00 WS 4 90WOVR POOH & L/D MILL. IN GAUGE. 08:30 - 10:30 2.00 WC 8 90WOVR PULL WEAR BUSHING & SET TEST PLUG. 10:30 - 12:00 1.50 WC 8 90WOVR TEST BOP'S FOR WEEKLY. WITNESSES BY AOAG REP LOU GRIMALDI. 12:00 - 13:00 1.00 WC 8 90WOVR PULL TEST PLUG & RUN WEAR BUSHING. 13:00 - 14:30 1.50 CM v 90WOVR MU & MAKE TWO STAND DUMMY RUN W/EZSV SETTING TOOL. 14:30 - 18:00 3.50 CM v 90WOVR MU & RIH W/EZSV. SET EZSV AT 5950'. SET DOWN 5K ON PKR. OK. 18:00 - 20:00 2.00 CM 5 90WOVR CIRCULATE BOTTOMS UP. PUMP SLUG. DROP OPEN DRIFT. 20:00 - 21:00 1.00 RM c 90WOVR SLIP & CUT 112' DRILL LINE. 21:00 - 23:30 2.50 CM 4 90WOVR POOH & LD SETTING TOOL. 23:30 - 00:00 0.50 CM 6 90WOVR RU WEATHERFORD TOOLS TO RUN 1st PRODUCTION PKR ASSY. 11/03/97 00:00-00:30 0.50 ~ C ~1 V ~tD~VR HELD PRE JOB SAFETY MEETING 00:30 - 02:30 2.00 VR PU 1st PRODUCTION PKR ASSY: WL ENTRY GUIDE, "XN" NIPPLE, 4 JTS 4 TBG, 4 1/2" SL,D N SLeeVE, 6 JTS 4 TBS, 1 2" JA [,~ 2. 1,9 ) 8 TBS PUP, MWD PKR, RUNNING TOOL & 3- 5" DP PUPS. RD Alaska Oil & Gas Cons, Corem Printed: 01/02/98 1:36:48 PM Anchorage Legal Well Name: NORTH COOK INLET UNIT 00A-12 Common Well Name: No~h Cook Inlet Unit No. A-12 Spud Date: 10/22/69 Event Name: Workover Sta~: 10/13/97 End: Contractor Name: Pool Arctic Alaska Rig Release: 04/26/94 Group: Rig Name: Pool Arctic Alaska Rig Number: 429 11/03/97 00:30 - 02:30 2.00 CM 2 90WOVR W~ATHERFORD'S TONGS. 02:30 - 05:30 3.00 CM 4 90WOVR TIH W/1st PROD PKR ASSY ON 58 STDS OF 5" DP. 05:30 - 08:00 2.50 CM f 90WOVR RU SCHLUMBERGER WL UNIT & PACK OFF. CORRE~TE DP MEASUREMENT W/DIL DATED 11/5/69. 08:00 - 09:30 1.50 CM v 90WOVR SPACE OUT & SET 1st MWD PKR ~ ~48'. EOT ~ 5760'. 09:30 - 12:30 3.00 CM 5 90WOVR SHEAR BALL SEAT & CBU. 12:30 - 15:30 3.00 CM 4 90WOVR POOH W/RUNNING TOOL. SE~ING SLEEVE FROM RUNNING TOOL LEFT IN HOLE. 15:30 - 21:00 5.50 CM 7 90WOVR WO SCHLUMBERGER PERSONNEL & FISHING TOOLS. 21:00 - 00:00 3.00 CM z 90WOVR RU SCHLUMBERGERWL UNIT. PU MAGNET & RIH. TAG UP ~ 5447' THEN WORK DOWN ANOTHER 2 1/2' & SAT DOWN. POOH W/MAGNET. DID NOT RECOVER SETTING SLEEVE. PREPARE TO RERUN MAGNET. 11/04/97 00:00 - 15:00 15.00 FI 4 90WOVR RUN MAGNET AGAIN. NO SUCCESS. MAKE WIRE G~PPLE OUT OF 5/8" CABLE & RIH W/SAME. NO SUCCESS. MODIFY BAKER 11 3/4" MAGNET SKIRT AFTER UNSUCCESSFUL FLOOR TEST WHILE RERUNNING 5/8" CABLE SPEAR. POOH. NO SUCCESS. 15:00 - i9:00 4.00 FI 4 90WOVR RIH W/BAKER 11 3/4" MAGNET W/BTM SKIRT MODIFIED W/3/8" CABLE G~PPLES. WORK SAME. POOH. DOING ALL THIS WHILE WAITING ON SE~ING SLEEVE BEING MAGNA-FLUXED BY HALLIBURTON FOR NEXT PACKER ASSEMBLY. NO RECOVERY BUT GUIDE INDICATED THAT SE~ING SLEEVE HAD BEEN EVENLY UP INSIDE GUIDE. 19:00 - 20:30 1.50 FI 4 90WOVR ~D MAGNET ASSEMBLY. ~D SCHLUMBERGER. SET WEAR BUSHING. RU WEATHERFORD'S PWR TONGS. 20:30 - 21:00 0.50 CM 0 90WOVR HELD PRE JOB SAFE~ MEETING. 21:00 - 22:30 1.50 CM 2 90WOVR PU 2nd PRODUCTION PKR ASSY: MSG, SEAL ASSY W/LOCATOR SUB, 2 - JTS 4 1/2" TBG, SLIDING SLEEVE, 4 - JTS 4 1/2" TBG, 2 - 4 1/2" TBG PUP JTS, PKR & RUNNING TOOL. 22:30 - 23:00 0.50 CM 6 90WOVR RD WEATHERFORD'S PWR TONGS, ETC. 23:00 - 00:00 1.00 CM 4 90WOVR TIH W/2nd PRODUCTION PKR ASSY ON 5" DP. 11/05/97 00:00 - 03:00 3.00 CM 4 80CMPL TIH W/2nd PROD PKR ASSY ON 57 STDS DP. 03:00 - 04:30 1.50 CM v 80CMPL STUNG SEALS INTO PACKER AT 5,448'. DROP BALL. PRESS TO 2,000 PSI TO SET PACKER AT 5,251'. PULL TESTED TO 60,000~. 04:30 - 08:00 3.50 CM 5 80CMPL BLED PRESS TO 0. UN JAY F~ PKR. SHEARED OUT BALL ~ 2800 PSI. CIRCU~TE BTMS UP. 08:00- 10:30 2.50 CM 4 80CMPL POOH W/RUNNING TOOL. 10:30 - 14:30 4.00 CM 2 80CMPL RU WEATHERFORD. MU PKR ASSEMBLY ~ 3. 14:30- 18:00 3.50 CM 4 80CMPL RIH W/SAME ON DP. 18:00 - 19:30 1.50 CM c 80CMPL STUNG SEALS INTO PACKER ~ 2 AT 5,251'. SET HALLIB MWD PROD PACKER ASSY~ 3 AT 4,569'. PULL TESTED W/60,000~ PULL. SHEARED OFF & BLOWED BALL SEAT W/2600 PSI. 19:30 - 22:00 2.50 CM 5 80CMPL CIRC BU AT 4.2 BPM. HAD SMALL AMT GAS ON BTMS UP, BUT NOT AS MUCH AS PREVIOUSLY. 22:00- 00:00 2.00 CM 4 80CMPL POOH W/SE~ING TOOL. 11/06/97 00:00 - 00:45 0.75 CM 4 90WOVR FIN POOH. LD PKR SE~ING TOOL. o. o E( EI BROKEBITOFFSC~PERTOSENDSC~PERINONBOAT. 01:15 - 02:30 1.25 ~ MAKE UP HALLIB 13-3/8" AWR PACKER ASSY W/NO SLIDING SLEEVE (TO ISOLATE BELUGA SD PERFS 4475-82'). Printed: 01/02/98 1:36:48 PM ....... , ~ ~,,o nnn.~, c0~miS$~0~l Legal Well Name: NORTH COOK INLET UNIT 00A-12 Common Well Name: North Cook Inlet Unit No. A-12 Spud Date: 10/22/69 Event Name: Workover Start: 10/13/97 End: Contractor Name: Pool Arctic Alaska Rig Release: 04/26/94 Group: Rig Name: Pool Arctic Alaska Rig Number: 429 11/06/97 02:30 - 06:30 4.00 CM i4 90WOVR GIH W/PACKER ASSY ON 5" DP. 06:30 - 07:30 1.00 CM v 90WOVR STUNG SEALS INTO PKR AT 4,569'. 07:30 - 09:00 1.50 CM v 90WOVR SET PACKER BY DROPPING BALL, PRESSURING UP TO 2000 PSI FOR 30 MIN., PULL TESTING TO 60K OVER, UNJAYING, & SHEARING OFF AT 40K OVER. BLEW BALL SEAT W/2700 PSI. 09:00 - 11:30 2.50 CM 5 90WOVR CBU. 11:30- 13:30 2.00 CM 4 90WOVR POOH W/RUNNING TOOL. 13:30 - 16:00 2.50 CM 2 90WOVR RU WEATHERFORD & MU PKR ASSEMBLY # 5. PJD WEATHERFORD, 16:00 - 19:00 3.00 CM 4 90WOVR RIH W/SAME ON DP. 19:00 - 20:00 1.00 CM v 90WOVR STUNG INTO PKR #4 AT 4,453'. DROP BALL. PRESS TO 2000# 30 MIN TO SET PACKER #5 AT 4.255'. PULLED UP 50,000# & SHEARED LOOSE - TOOL WAS UN-JAYED. PRESS TO 2750# & SHEARED BALL SUB. 20:00- 22:30 2.50 CM 5 90WOVR CIRC BTMS UP. 22:30 - 00:00 1.50 CM 4 90WOVR POOH W/RUNNING TOOL. 11/07/97 00:00 - 00:45 0.75 CM 4 90WOVR FIN POOH W/SETTING TOOL AFTER SETTING PKR #5 AT 4,255'. 00:45 - 02:00 1.25 CM 2 90WOVR RU WEATHERFORD TBG TONGS & MU PKR ASSY #6. RD TONGS. 02:00 - 05:00 3.00 CM 4 90WOVR WIH W/PKR ASSY #6. 05:00 - 06:30 1.50 CM v 90WOVR STUNG SEALS INTO PKR #5 AT 4,255'. PRESS TO 2000 PSI 30 MIN TO SET PKR ~ff~ AT 4,175'. 06:30 - 09:00 2.50 CM 5 90WOVR CBU. 09:00- 10:30 1.50 CM 4 90WOVR POOH & L/D RUNNING TOOL. 10:30 - 15:00 4.50 CM 4 90WOVR R/U WEATHERFORD. MU & RIH W/PKR ASSEMBLY # 7. 15:00 - 16:30 1.50 CM v 90WOVR SET PKR # 7 AT 4069'. 16:30- 18:30 2.00 CM 5 90WOVR CBU. 18:30 - 20:00 1.50 CM 4 90WOVR POOH & L/D RUNNING TOOL. 20:00 - 00:00 4.00 CM 4 90WOVR RU WEATHERFORD TUBING TONGS. MU & WIH W/PACKER ASSY #8 W/10 JTS 4-1/2" TUBING & SLIDING SLEEVE. STUNG SEALS INTO PKR #7 AT 4,069'. PREP TO SET PACKER. NOTE: BLAIR WONDZELL W/AOGCC WAS NOTIFIED 08:30 11-6-97 ABOUT SATURDAY SCHEDULED WEEKLY BOP TEST. WILL FOREGO BOP TEST AND FINISH COMPLETING. 11/08/97 00:00 - 01:00 1.00 CM v 90WOVR DROP BALL. SET PKR #8 AT 3750' W/2000 PSI 30 MIN. PKR SET AT 750 PSI & SETTING TOOL RELEASED AT 1800 PSI. PRESSURED 2850 PSI TO SHEAR BALL SUB. 01:00- 03:00 2.00 CM 5 90WOVR CIRC; 200 UNITS GAS. 03:00 - 04:45 1.75 CM 4 90WOVR SLUG PIPE & POOH W/PKR SETTING TOOL. 04:45 - 06:30 1.75 CM 4 90WOVR MU PACKER ASSY #9. 06:30 - 09:30 3.00 CM 4 90WOVR RIH W/PKR # 9. 09:30 - 11:00 1.50 CM c 90WOVR STING INTO # 8 & SET PKR # 9 AT 3500'. 11:00- 12:30 1.50 CM 5 90WOVR CIRC BU. & SLUG. 12:30 - 14:00 1.50 CM 4 90WOVR POOH & L/D RUNNING TOOL. 14:00 - 15:00 1.00 CM 4 90WOVR MU PKR #10 (NO TAIL PIPE). 15:00- 18:00 3.00 CM 4 90WOVR GIHW/PKR#10. 18:00-19:30 1.50 CM v 90WOVR LOCATED PKR #10 AT 3200'. DROPBALL. PRESS 2000# 30 MIN TO SET PKR. PULL TESTED 60,000#. UN-JAYED & RELEASED SETTING TOOL W/45,000# PULL. SHEARED BALL SUB W/2700 PSI. 19:30 - 21:30 2.00 CM 5 90WOVR CIRC BTMS UP, 200 UN GAS. 21:30- 23:00 1.50 CM 4 90WOVR POOH W/SETTING TOOL. 23:00 - 00:00 1.00 CM 2 90WOVR PULLED WEAR BUSHING FROM WELLHEAD. MAKING UP SEALS ON 4-1/2" TBG & HALLIB TWIN-FLOW HEAD TO RUN IN ON 7" TUBING. Pdnted: 01/02/98 1:36:48 PM l)eratlons Summarv Repo Legal Well Name: NORTH COOK INLET UNIT 00A-12 Common Well Name: North Cook Inlet Unit No. A-12 ,Spud Date: 10/22/69 Event Name: Workover Start: 10/13/97 End: Contractor Name: Pool Arctic Alaska Rig Release: 04/26/94 Group: Rig Name: Pool Arctic Alaska Rig Number: 429 11/08/97 23:00 - 00:00 1.00 CM 2 90WOVR ~NOTE ON B-2 WELL: 1/2 GALLON OF OIL WAS BLED FROM 9-5/8" CASING AT 0 PSI. BLED 5 GAL WATER ONLY FROM ANNULUS TO BLEED PRESSURE FROM 450 PSI TO 0 PSI. 11/09/97 00:00 - 01:00 1.00 CM 2 90WOVR PU & RUN 9 JTS (289.65') OF 4 1/2" PRODUCTION TUBING W/SEALS ON BTM. 01:00 - 12:00 11.00 CM 2 90WOVR MU UPPER SEALS, TWIN FLOW, & RIH W/76 its (3094.21') OF 7" - 26~ - J55/L55 - STL TBG. P~CED SSSV AT 435' & TESTED SAME. 12:00 - 17:00 5.00 CM n 90WOVR STING INTO PKR ~ 9 & TEST LOWER SEALS TO 1000 PSI. OK. SPACED OUT & INSTALLED HANGER. ~N CONTROL LINE THROUGH HANGER & TESTED SAME TO 5000 PSI FOR 20 MIN. LANDED HANGER & ~N IN HOLD DOWN PINS. CLOSED SSSV, BACKED OUT LANDING JT, & RUN BACK PRESSURE VALVE IN 7" HANGER. 17:00 - 19:00 2.00 CM 6 90WOVR FMC INSTALL BPV IN 7" TUBING HANGER. RU WEATHERFORD & SWAP FROM 7" RUNNING EQUIPMENT TO 2-3/8" EQUIPMENT. NOTE: HALLIBURTON WELL TEST CREW WAS NOT ABLE TO RU ANY EQUIPMENT TILL 10:00 PM BECAUSE BOAT CAPTAIN OF THE M~ MONARCH HEARD ON THE WEATHER REPORTS THAT IT WAS PROBABLY ROUGH OUT HERE. IT WAS ONE FT WAVES HERE W/15 TO 20 KNOT WINDS ALL DAY. THE CAPTAIN NEVER CALLED OUT HERE TO ASK HOW THE WEATHER WAS. 19:00 - 00:00 5.00 CM 2 90WOVR MU SEALS & RIH PU 2 3/8" TBG. 11/10/97 00:00 - 01:30 1.50 CM 2 90WOVR Finished running seals & 2-3/8" disposal string. Landing nipple at 398'. 01:30 - 04:30 1.50 CM 2 90WOVR Spaced out tubing. Made up FMC hanger on 2-3/8". Began stinging into Hallib ~in-flow seal assy at 3189'. Hanger would not go fully into wellhead. Worked & got to go down 1/2' deeper. Wellhead man said this was where it should go. 04:30 - 05:30 1.00 CM 5 90WOVR Unstung seal assy. Reveme circ 20 bbl 70% methanol/30% KCL fluid down anls for freeze protection. 05:30 - 06:00 0.50 CM 9 90WOVR Pumped down anls below wellhead to att to test. Cim up s~ck w/no ~ress. 06:00 - 08:00 2.00 CM z 90WOVR Kept working tubing hanger & got to drop down fu~her into wellhead. 08:00 - 10:00 2.00 CM 8 90WOVR Pumped into anls to att to test. Press to 1200 psi & tubing hanger seal failed. Pulled up hgr & replaced seal. Relanded hanger & pedormed MIT test to 1500 psi for 30 min. ok. AOAG mp Lou Grimaldi witnessed test. 10:00 - 13:00 3.00 CM 1 90WOVR RU SLICKLINE & RIH W/1.85" DRIFT. UNABLE TO MAKE ANY HOLE DUE TO DRIFT FLOATING IN THICK COMPLETION FLUID. RIH W/ 1.85" OPEN GAUGE RING TO "XN" NIPPLE AT 3206' WLM. OK. POOH & RD SLICKLINE. 13:00 - 15:00 2.00 CM 0 90WOVR ~D RISER & INSTALL BACK PRESS VALVE IN 2 3/8" HANGER. 15:00 - 21:30 6.00 CM e 90WOVR N/D RISER, FLOWLINE, & BOP'S. 21:30 - 00:00 2.50 CM e 90WOVR Install 7" x 2" dual tree. 11/11/97 00:00 - 00:30 0.50 CM 8 90WOVR Fin NU tree body to wellhead. Test flange 3,000 psi 30 rain, OK. 00:30 - 06:45 6.25 CM e 90WOVR NU valves & lines to tree. 06:45 - 12:00 5.25 CM 8 90WOVR Had small amount of gas under 7" BPV. Bled off. Pull BPVs. Install test check plugs. Test tree to 2,500 psi on 2 3/8" side & 3000 psi on 7" side. tested 2" flowline to 2250 psi. production tested 7" flowline to 1100 psi w/ gas. Pull test checks. 12:00 - 16:00 4.00 CM 6 90WOVR RU riser through floor & ~ntinue RU Hallibu~on well testem while R !: C E I~~~ ,o pessure up on production string w/platform gas. Pressure ~ ~ickly to 1100 psi. Functioned sssv w/different surface pressures. Legal Well Name: NORTH COOK INLET UNIT 00A-J2 Common Well Name: North Cook Inlet Unit No. A-12 Spud Date: 10/22/69 Event Name: Workover Start: t 0/13/97 End: Contractor Name: Pool Arctic Alaska Rig Release: 04/26/94 Group: Rig Name: Pool Arctic Alaska Rig Number: 429 ,~ ................................ ~ ~ .................................................. 11/11/97 12:00 - 16:00 4.00CM 6 90WOVR SSSV appears to be working properly, slow feed to well to start. NOTE: AT 1:00 PM A SPILL DRILL WAS SIMULATED WITH GOOD RESPONSE TIME. 16:00 - 20:00 4.00CM 1 90WOVR Testing all Halliburton surface equipment while monitoring gas injection into 7" x 4 1/2" production string. 20:00 - 21:00 1.00CM 1 90WOVR Gas injection pressure 1120 psi. Closed off gas supply & monitored press on tubing. Bled to 1100 psi in 1 hour- indication of pushing fluid into perfs at very, very slow rate. 121:00 - 00:00 3.00CM 1 90WOVR Opened injection gas pressure back to tubing at 1140 psi. Observing well for indication of displacing fluid down tubing w/gas. Still 1140 psi. Prep to att to flow well. 11/12/97 00:00 - 01:00 1.00CM f 90WOVR Had 1140 psi induced gas press on tubing. Close off injection gas supply to well. Open swab valve to open to Hallib well-testing equip. By-pass separator so as to avoid having back pressure when try to rock well in. i Hallib gauge press was 1220 psi. 01:00 - 02:30 1.50CM f 90WOVR Opened well on 32/64" choke then incr quickly to full-open choke (48/64"). Tubing press bled quickly to 0 psi. No fluid, no continued gas flow. Observe well. No flow. 0 psi. 02:30 - 20:00 17.50 CM f 90WOVR Put induced gas pressure back on tubing. 1150 psi. WO coil tubing. Bled gas press off tbg before coil tbg arrived - no flow. 20:00 - 00:00 4.00CM 6 90WOVR Unload Dowell 1-1/2" coil tubing unit & RU. 11/13/97 00:00 - 04:00 4.00CM 6 90WOVR RU Dowel coil tubing unit. Connect Hallib well test line. 04:00 - 04:30 0.50CM 0 90WOVR Safety meeting. 04:30 - 05:00 0.50CM 8 90WOVR Test coil tubing BOPs & well test lines to test manifold to 2000 psi. 05:00-05:30 0.50CM 4 90WOVR GIH w/ coil tubing to1100'. 05:30 - 12:00 6.50CM 1 90WOVR Jetting w/nitrogen starting @1100' working down to 5600' (end of tbg @5760'). Pumped at various rates between 200 scf/min to 1500 scf/min. Recovered 120 bbls from well + 21 bbls from coil tubing (141 bbls total). Worked coil tbg up the hole in attempt to swab in well, not making any fluid. 12:00 - 13:00 1.00 CM 1 90WOVR SD nitrogen & observe well. 13:00 - 15:30 2.50 CM 1 90WOVR Tih w/coil tbg pumping 200 scf/min to 5810' ***50' below end of tbg. Didnot tag any fill. Increase pumping to 1500 scl/min, as pooh w/coil tbg. Ran out of nitrogen.Total recovery 128 bbls from well. Pulled above blind rams & shutin same. Sent in both tanks on workboat to be refilled. 15:30 - 22:30 7.00 CM 7 90WOVR Filled nitrogen tanks & returned to rig. 22:30 - 00:00 1.50 CM 1 90WOVR Loaded nitrogen onto rig. Connecting to coil tubing. 11/14/97 00:00 - 00:30 0.50 CM 6 90WOVR Fin connecting nitrogen to coil tubing unit. 00:30 - 03:00 2.50 CM 4 90WOVR GIH w/coil tubing to 5858' jetting w/nitrogen. POOH to 2875' jetting. Recovered 25 bbls, then dried up. 03:00 - 04:00 1.00 CM 1 90WOVR Observe well - no flow. 04:00 - 04:30 0.50 CM 1 90WOVR Pull coil out of hole. 04:30 - 07:00 2.50 CM 6 90WOVR RD coil tbg injector head & BOPs. Removed 5" DP riser from tree. 07:00 - 11:30 4.50 CM 1 90WOVR RU Hallib slick line. Test lubricator 2100#, ok. Ran shifting sleeve in 4-1/2". Put 1170# press on tubing from production gas. Opened sliding sleeve at 5383'. Press decreased to 1120 psi. 11:30-13:00 1.50 CM u 90WOVR Pooh w/wl shifting tool & rd same. 13:00 - 15:00 2.00 CM 8 90WOVR RU Halliburton testing equipment & test same to 2000# 15:00 - 16:30 1.50 CM u 90WOVR Open well to Halliburton test manifold, 1000#. Open well to flare, bled to I0# in 15 minutes. No fluid recovery. Observe well static for 1 hr. Si well. 16:30 - 17:30 1.00 CM 6 90WOVR RD Halliburton test equipment. 17:30 - 20:00 2.50 CM 6 90WOVR RU Dowell coil tbg unit. Printed: 01/02/98 1:36:48 PM Legal Well Name: NORTH COOK INLET UNIT 00A-12 Common Well Name: NOrth Cook Inlet Unit No. A-12 Spud Date: 10/22/69 Event Name: VVorkover Start: 10/13/97 End: Contractor Name: Pool Arctic Alaska Rig Release: 04/26/94 Group: Rig Name: Pool Arctic Alaska Rig Number: 429 11/14/97 20:00 - 21:30 1.50 CM 8 90WOVR Press test coil tbg & BOPs 2000# w/water. Displ water out of reel w/ nitrogen. Opened well - had 280 psi pressure, bled off quickly. 21:30 - 22:30 1.00 CM 1 90WOVR GIH w/coil tbg to 5000'. Begin pumping nitrogen 500 scfm while GIH to sliding sleeve at 5383'. 22:30 - 00:00 1.50 CM 1 90WOVR Jet w/1000 scfm nitrogen for 1/2 hr.. GIH to 5850' (below end of tbg) & then back up to 3000' (in 7" casing) while jetting. Recovered 3 bbls fluid by report time. 11/15/97 00:00 - 00:15 0.251 CM 1 90WOVR SD nitrogen after coil tbg up to 3000'. 00:15 - 01:00 0.75 CM u 90WOVR Observe well. Had some nitrogen flow & fluid recovery (total 7 bbls viscosified fluid)) after SD nitrogen. Back when displaced water out of coil tbg after testing, recovered only 16 bbl instead of the 21 bbls of coil capacity. Remainder probably fell into the riser and may be part of the recovered fluid. 01:00 - 01:45 0.75 CM 1 90WOVR ;Observing well. Was dead. 01:45 - 02:45 1.00 CM 1 90WOVR Had small blow; 12 psi on 80/64" choke - was gas (S.G. 0.56). Observed well. Blow stopped. 02:45 ~ 03:30 0.75 CM 1 90WOVR Pulling coil tbg out of hole. Had several on & off small gas blows, 03:30 - 05:00 1.50 CM 1 90WOVR Set back injector head & BOP stack. ND riser from tree. 05:00- 06:00 0.50 CM 1 90WOVR RU Hallib slick line 06:00 - 06:45 0.75 CM 8 90WOVR Tested lubr. Greased leaking valve on outet. Retested 2250 psi OK. 06:45 - 09:30 2.75 CM 1 90WOVR GIH w/shifting tool on 0.125" slickline. Press w/gas to 1150 psi. Shifted open "XD" sliding sleeve at 5,175' (Upper Beluga). Press still 1150#. POOH. RD wi. 09:30 - 12:00 2.50 CM !8 90WOVR RU Halliburton test equipment, pres test to 2000#. Open to manifold pres @1100# Open well bled to 0# in 15 min. Slight blow on tbg. 12:00 - 13:00 1.00 CM 6 90WOVR RD Halliburton test equipment. 13:00 - 15:00 2.00 CM 1 90WOVR RU WL unit. Pres test lubricator. Tih w/shifting tool to XD sleeve @4359' (Cook Inlet -8, 9, 10, & 11). Possible fluid level @2700'. Pres tbg to 1085#. Open sleeve pres drop to 1050#. POOH w/wi & rd same. 15:00 - 16:00 1.00 CM 8 90WOVR RU Halliburton test equip, pres test 2000#. Open well to manifold, 920#. Open well bled down 10 min. w/slight blow. 16:00- 17:00 1.00 CM 6 90WOVR RD Halliburton equipment. 17:00 - 19:45 2.75 CM 1 90WOVR RU Hallib slick line. Test lubr. GIH w shifting tool. Found fluid level at 2480'. Put 1075~ gas press on tbg. Opened sliding sleeve at 4003' (Cook Inlet 1,2,3 & 4). Press decr to 1050#. POOH & RD slickline. 19:45 - 20:30 0.75 CM u 90WOVR MU riser. RU well test equip. 20:30 - 00:00 3.50 CM u 90WOVR SITP 950 psi. Opened well at 20:40 on 66/64" choke. FTP decr to 120 )si, unloaded fluid, then FTP incr to 530 psi. Cont flowing well. Now on 68/64" choke: 490 psi FTP, 15.708 mmcfgd, 300 - 516 BWPD, total fluid to date is 48.7 bbls. 11/16/97 00:00 - 02:30 2.50 CM u 90WOVR Flowing Cook Inlet 1,2,3, & 4 sand. 02:30 - 03:00 0.50 CM 1 90WOVR Sand probe cut out. Shut in. Replaced sand probe & thermo-well. SITP 900 psi. 03:00 ~ 03:30 0.50 CM u 90WOVR Opened well again & cont flowing on 68/64" choke, Began making 5 - 10% sand, then decreased. Still making fluid (viscous fluid - not formation fluid). 03:30 - 04:00 0.50 CM 1 90WOVR Sand probe cut out again. 04:00 - 10:00 6.00 CM 1 90WOVR Flowed well til 09:45 on 68/64" choke: 670 psi FTP, 17.084 mmcfgd, 15 bwph. 10:00 - 14:30 4.50 CM 1 90WOVR RD Hallib test equip & moved WL unit out of way. RU coil tbg & test 2000#. WIH & set down at SCSSSV. POOH. Put bend in end of coil tbg. Went back in hole, OK. 14:30 ~ 18:00 3.50 CM 1 90WOVR Opened well on 48/64" choke, 3.8 mmcfg, while Printed: 01/02/98 1:36:48 PM Legal Well Name: NORTH COOK INLET UNIT 00A-12 Common Well Name: North Cook Inlet Unit No. A-12 Spud Date: 10/22/69 Event Name: Workover Start: 10/13/97 End: Contractor Name: Pool Arctic Alaska Rig Release: 04/26/94 Group: Rig Name: Pool Arctic Alaska Rig Number: 429 11/16/97 14:30 - 18:00 3.50 CM I 90WOVR GIH wi coil tbg. Started jetting w/nitrogen at 4000', 500 SCFM. GIH to 5810', below end of tubing. 18:00 - 20:00 2.00 CM 1 90WOVR Jetting at 800 - 350 scfm while flowing well on bypass, no choke; 480 psi, 5.4 mmcfgd, 8 - 20 bwph. 20:00 - 20:30 0.50 CM 1 90WOVR Pulled coil tbg up to 3900' (100' above top sliding sleeve). 20:30 - 00:00 3.50 CM u 90WOVR Cont to flow bypassing choke: 520 psi FTP, 9.466 mmcfgd, water decr from 5-10 bph to 0 bph. Getting Iow on nitrogen. Prep to POOH w/coil tubing. 11/17/97 00:00 - 01:00 1.00 CM 1 90WOVR POOH w/Dowell Schl coil tbg using last of nitrogen. Cont flowing CI 1,2,3, & 4 while POOH jetting. 01:00 - 02:30 1.50 CM 6 90WOVR SI well. RD coil tubing unit. 02:30 - 04:00 1.50 CM u 90WOVR Reconnect & test well test equip. Flowed on 60/64" choke @ 9-1/2 mmcfgd. 5-8 bwph. 04:00 - 06:00 2.00 CM 6 90WOVR Start to RU slickline. Replace sand-cut dump valve parts. Rig back up well testers. 06:00 - 13:30 7.50 CM u 90WOVR Flow well to cleanup. Sleeves open as follows: 4003' CI 1,2,3,4, i4359' CI 8,9,10,11 5175' UPPER BELUGA 5382' MIDDLE BELUGA ***NOTE: LOWER BELUGA open thru end of tbg @5760' Rates as of 1330 hrs: FTP 560# GAS 16.99 MMSCF/D WTR 96/190 BBL/D CHL 15000 SD 1 - 3% TOTAL WTR : 341 BBLS FOR ENTIRE FLOW TEST 13:30 - 15:00 1.50 CM 7 90WOVR SI well due to washouts on inlet line to test separator. Making repairs. 15:00 - 17:30 2.50 CM I 90WOVR RU Halliburton wi & test lubricator, TIH w/closing tool for top XD sleeve @4003' across Cl 1,2,3,4. Close sleeve & RD slickline. 17:30 - 00:00 6.50 CM 7 90WOVR RU dser from tree to Halliburton test manifold & test w/2200 psi while cont repairing separator. Press test 1000 psi from manifold to separator after installing repaired washed-out pipe sections.. 11/18/97 00:00 - 04:00 4.00 CM i7 90WOVR Continue repairing washed out separator inlet line. 04:00 - 05:00 1.00 CM u 90WOVR Flare pilot light would not operate. Routed production gas to pilot light. 05:00 - 13:00 8.00 CM u 90WOVR SlTP 950 psi. Opened well on by pass. Flow rate increased 8.9 mm to final rates as follows: FTP 490# GAS 16.9 MMSCF/D VVTR 163 - 236 BBL/D CHL 6500 SD 2 -3% TOTAL WTR THIS TEST: 88 BBLS ZONES OPEN: CI 8,9,10,11 & ENTIRE BELUGA SAND 13:00 - 14:00 1.00 CM u 90WOVR Increase back pressure on well to 740# to simulate going thru production equipment. Rates as follows: FTP 740# GAS 12.5 MMSCF/D VVTR 35 - 80 BBL/D SAND TRACE CHL 65OO PPM Printed: 01/02/98 1:36:48 PM Legal Well Name: NORTH COOK INLET UNIT 00A-12 Common Well Name: North Cook Inlet Unit No. A-12 Spud Date: 10/22/69 Event Name: Workover Start: 10/13/97 End: Contractor Name: Pool Arctic Alaska Rig Release: 04~26~94 Group: Rig Name: Pool Arctic Alaska Rig Number: 429 11/18/97 13:00 - 14:00 1.001 CM i u 90WOVR 14:00 - 16:00 2.00 CM 6 90WOVR SI well. RD Halliburton test line. RU wi lubricator & test same. TIH w/ closing tool & close XD sleeve @4,359'. POOH & RD WI. 16:00 - 17:30 1.50 CM 8 90WOVR RU Halliburton test equipment & test same. 17:30 - 00:00 6.50 CM u 90WOVR Flow well w/Baluga sands open thru sliding sleeves. By pass choke: initially 480 psi, 15.946 mmcfgd, 400 bwpd, 6-8% sand. By report time had improved to: FTP 520 psi, 17.143 mmcfgd, 120-240 bwpd, sand 3%, chi 6,500 ppm. Total water from Baluga = 58 bbls. 11/19/97 00:00 - 06:00 6.00 CM u 90WOVR Flowing Beluga sands final rate as follows: FTP 520#, GAS 17.7 . MMSCF/D, WTR 100 +- BBL/D, SAND 1-3%, CHL 6500 PPM. TOTAL WTR THIS TEST 99 BBLS. 06:00 - 07:00 1.00 CM u 90WOVR Increase back pressure on well to 760# to simulate going thru production equipment. Rate as follows: FTP 760#, GAS 7.8 MMSCF/D, WTR 20 BBL/D, SAND TRACE, CHL 6500. 07:00 - 09:00 2.00 CM 6 90WOVR SI well. RD Halliburton test line. RU wi lubricator & test same. TIH w/closing tool & close ×D sleeve @5175'. POOH & RD WL. ***Fluid level +- 4500' 09:00 - 11:00 2.00 CM 8 90WOVR RU Halliburton test equipment & test same. 11:00 - 14:30 3.50 CM u 90WOVR SITP 960# Open well. Flow 2 lower Beluga zones. Final rate as follows: FTP 530#, GAS 16.647 MMSCF/D, VVTR 158 - 196 BBL/D SAND 1 - 3%, CHL 6000 PPM. TOTAL WTR THIS TEST 20 BBLS. 14:30 - 15:30 1.00 CM u 90WOVR Increase back pressure on well to 750# to simulate going thru production equipment. Rate as follows:FTP 750#, gas 13.099 mmscf/d, wtr 0 -40 bbl/d, chi 6000, sand trace. 15:30 - 17:00 1.50 CM 8 90WOVR SI well. RD Halliburton test quipment. Ru wi lubricator & test same. 17:00 - 18:30 1.50 CM 6 90WOVR TIH w/closing tool for XD sleeve @5383' ***NOTE: fluid level @4650' Close sleeve. POOH RD WL. 18:30 - 19:00 0.50 CM 8 90WOVR RU Halliburton test equipment & test same. 19:00 - 00:00 5.00 CM u 90WOVR SITP 960# Flow test lower Beluga zone only. Initial flow rate as follows: FTP 530#, gas 17.978 mmscf/d, wtr 120 bbl/d, chi 9000 ppm, sand 2%, bs&w 8% (ddg mud filtrate?) 00:00 flow rate as follows: FTP 530#,. gas 18.296 mmscf/d, wtr 160 bbl/d, chi 5800 ppm, sand 3%, bs&w 3%. 11/20/97 00:00 - 05:00 5.00 CM u 90WOVR FLOW TESTING LOWER BELUGA ONLY. FINAL RATE AS FOLLOWS: FTP 520# GAS 18.296 MMSCF/D, WTR 159 BBL/D, SAND 1%, BS&W 1%, CHL 5800 PPM. TOTAL VVTR PRODUCED THIS TEST 58 BBLS. 05:00 - 07:30 2.50 CM u 90WOVR INCREASE BACK PRESSURE ON WELL TO 780# TO SIMULATE GOING THRU PRODUCTION EQUIPMENT. RATE AS FOLLOWS: FTP 780# GAS 13.548 MMSCF/D, WTR O, NO SAND. 07:30 - 09:00 1.50 CM 6 90WOVR SI WELL. RD HALLIBURTON TEST EQUIPMENT. RU WL LUBRICATOR & TEST SAME. 09:00 - 10:30 1.50 CM 6 90WOVR TIH W/OPENING TOOL FOR "XD" SLEEVES. TIH TAG FLUID @4560'. CONTINUE IN HOLE & OPEN "XD" SLEEVES AS POOH. OPENED SLEEVES AS FOLLOWS: 5383' MIDDLE BELUGA 5175' UPPER BELUGA 4359' CI 8,9,10,11 4003' Cl 1,2,3,4 NOTE: LOWER BELUGA ZONE OPEN THRU END OF TBG. "XD" SLEEVE 5634' CLOSED & "XD" SLEEVE @4172' Cl 5,6,7. CLOSED. 10:30 - 12:00 1.50 CM 6 90WOVR RD HALLIBURTON WL UNIT & LUBRICATOR. RU TESTING EQUIPMENT, TEST SAME. Printed: 01/02/98 1:36:48 PM Legal Well Name: NORTH COOK INLET UNIT 00A-12 Common Well Name: North Cook Inlet Unit No. A-12 Spud Date: 10/22/69 Event Name: Workover Start: 10/13/97 End: Contractor Name: Pool Arctic Alaska Rig Release: 04/26/94 Group: Rig Name: Pool Arctic Alaska Rig Number: 429 11/20/97 12:00 - 14:30 2.50 CM t 90WOVR SI WELL FOR PRESSURE BUILDUP. 960# 14:30 - 18:30 4.00 CM u 90WOVR SITP 960# OPEN FOR CLEANUP FLOW. ZONES OPEN, Cl 1,2,3,4 Cl 8,9,10,11 + BELUGA SANDS. FINAL FLOW RATE AS FOLLOWS: FTP 570#, GAS 20.195 MMSCF/D, W'FR 80 BBL/D, CHL 6500 PPM, SAND TRACE, BS&W 1 - 2% (DRLG MUD FILTRATE). TOTAL WTR THIS TEST 30 BBLS. 18:30 - 20:00 1.50 CM u 90WOVR INCREASE BACK PRESSURE ON WELL TO 740# TO SIMULATE GOING THRU PRODUCTION EQUIPMENT. RATE AS FOLLOWS: FTP 740# GAS 18.271 MMSCF/D, W'FR 80 BBL/D, CHL 6500, SAND TRACE BS&W .25%. 20:00 - 21:00 1.00 CM 6 90WOVR SI WELL. RD RISER TO RIG FLOOR. RELEASE WELL TO PRODUCTION. 21:00 - 00:00 3.00 CM u 90WOVR OPENED WELL UP THRU PLATFORM TEST SEPERATOR ON 108/64" CHOKE. FLOWING 19 MMCFGD, 50 BWPD W/800 PSI FTP @ 00:00 HRS. RELEASED RIG FPJ NCIU A -12 @ 00:00 HRS 11/20/97. 11/21/97 00:00 - 12:00 12.00 CM 6 90WOVR FINISH RD HALLIBURTON TESTING EQUIPMENT & PREPARE TO LOAD OUT SAME. SKID RIG TO NClU B - 2. FINAL REPORT '1 ....... Printed: 01/02/98 1:36:48 PM MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission David J~, Chairmam,~ Blair ' · ~~zell, P. I. Supervisor FROM: Lou G~r~a~i' ,'~ SUBJECT: Petroleum Inspector DATE: November 1, 1997 FILE NO: AX9JKAEE.DOC BOPE Test Unocal/Pool rig #428 Phillip's NCIU A-12 North Cook Inlet Unit PTD #69-0099 Saturday, November 01, 1997; I witnessed the weekly BOPE test on Unocal/Pool rig #428 which was working over Phillip's Petroleum Co.'s well NCIU A-12 in the North Cook Inlet Unit. I was notified of this test at my home, approximately 0630 hours this morning· I was on a 0830 helicopter to the platform. This is uncommon for the Phillip's personnel who usually give proper notification. The rig was close to testing when I arrived. I toured the area surrounding the rig and found it to be kept clean and orderly. The test once started went very well. I observed a test procedure, which insured all BOP equipment worked properly. The rig will set a bridge plug. Then complete this well. The next well should be back in the sunfish project. A witnessed BOP test at the higher test pressure should be witnessed. SUMMARY: I witnessed the weekly test of the BOPE on Unocal/Pool rig fl428. There were no failures observed. Test time 3 hours. Attachments: A98JDJDD.XLS CC: Walt Carrico (Phillip's Petroleum Co. drilling Supt.) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X Drlg Contractor: ~Pool ~ Rig No. ~ PTD # Operator: Phillips Rep.: Well Name: NCIUA-12 Rig Rep.: Casing Size: 13 3/8 Set (~ 6,950 Location: Sec.~ Test: Initial Weekly X Other 69-0099 DATE: 11/1/97 Rig Ph.# 776-6013 Marc Babineaux Rick Brumley 6 T. 11N R. 9W Meridian Seward Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Ouan. Pressure Location Gen.: P Well Sign P Upper Kelly / IBOP 1 250/5,000 Housekeeping: P (Gen) Drl. Rig P Lower Kelly / IBOP 1 250/5,000 PTD On Location P Hazard Sec. P Ball Type 1 250/5,000 Standing Order Posted P · Inside BOP 1 250/5~000 P/F P/F BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. 1 250/2500 1 250/5,000 1 250/5,000 I 250/5,000 1 250/5,000 P/F Test p Pressure 250/5,000 250/5,000 CHOKE MANIFOLD: P No. Valves 15 P No. Flanges 38 P Manual Chokes 1 P Hydraulic Chokes 2 2 250/5,000 P I 250/5,000 P N/A N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P 250/5,000 Functioned Functioned P/F ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure ~ System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: Twelve Bottles 3,000 I P 1,800 P minutes 24 sec. minutes 46 sec. P Remote: P 2100 Average Psig. Numbe~' 0f JSailuresi 0 ,Test Time:/'3.0~ Ho'~i;~. ~umber of valves tested 2f Repair or Replacement of Failed ! Equipment will be made within N/A days. otify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good test, Equipment in good shape. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES NO X Waived By: Witnessed By: Lou Grimaldi FI-021 L (Rev. 12/94) Ax9jkaee,xls PI~TD 8~23~ 133/8' 381 1990 TOC ~lt 1945 O~ Twin Flow D~ml PackM Cm~ Inlet Sands 38~0 - 3880 CL1 - 396O Cl.2 3982.39~4 Cl-3 [4014 - 4048 CI-4 4000. 4098 CLS -~4t0~. 4111 CI-5 ~41 is - 4124 :4141 - 4166 ci.6 4188.4238 Cl-7 4272 - 4282 Cl-8 .__~ 4290 - 4310 Cl-9 -~ 4378 - 4390 C1-10 4415- 4440 01-11 Beluga Sands "Upper' 4475 - 4482 4e73 - 4070 '-~eeo- 4~s -~5o~- 5o7o · ~5120- 5~94 - ~53~.s372 ~ - ~14 ~_~ * EXISTING WELL COMPLETION D.IA?..RAM ....... ~ e, OD " FMC 6 a/8" I$'..A 46d'2.0 r"- ~}~PV'a '~- RKB-DrlIIDeeIc ~_~__._. ~3,1d; 8.6 ppg__z"/. KCL'Wate~-'withTO/30.(~u,, I~B.$L: TOC; l~4S, ft,~m CJ~I, dated 05/03/70 WATER DE~YH; 120' R.~n~M~; :~:::~;:~' ']~:j:.ii:~: ~:iii~.~.~ .... :~.~':~;-:' ,~::~:::: ........ :::;:~! :.~:!:~:Y ~.~5!- :~:~::.'J~'. ................ ..=.:.~:+ >:.~:.=~:' ,~ ..... '.,..-..'...~/.~ ~ .... - .. 30" 41 ~$1 ,, . .,_ 20 ' 41 t,~)0 133 lb/fl , , ~.,, tm 3/8 ' 4i' ':_.... 6,~so 72i1~t N4'o BT&C 4?SO 2'~2{) .,. 1231 ._ .. , , Tubi-I ~a$; Short Sf~ ............. 7/' .... ~ ~1 2,rz~l 2~n/~ I. ~-ss i~m-s~/~ I 4~1,, 4o'~1 Tu~h~ S~nI :; ],~.~ S~Jn~" { .... iS 0,00' "~10.77 Lqcvadoa ]2 3~.3~ 8-03 ?" z~ ~t~ ]-~ STa. ~ ~ ..... ~.24o ...... 1 i 370,s6 11.36 H~bumm 'CP-2" TR$$V wi~h Top & Bo~m Sul~ ~.900 9.40o 10 3SI.TZi 5:21 7" 28'ib/fl $-55 ST_./~...TublngPup ......... 6,240 ?.000 $~ 2~94.69 ---1-~'~0' 7 ' 26 lb/It $-5~ ST/L Tubln~ Pup 6.240 ?.000 7 ...... 270~.65 0,65 Twin Flow l~c~i ........ ~,~70 ..... ~ 2~10;'~i~ 0,68 103/4' Coeelb~ .... _. ]0. TSo il,Tm~ 5' 2710,~8 5.37 ~ j/i ;' Pup .fuinl 10,000 10.7501 4 2716.35 1;:1~)'~edu¢of 103/4'~CT X 95/8" SOT ......... 8,840 1i.~3:~ 3 ...... ~7i~/,4S 1.71 ~waSc 9 S/S" SC/ X '~/" Sd:l' ~.~20 ~,62f 2 27]~. [~ ' ;f72-2' ""MSN" S¢~ (~) .............. - ..... 6,220 ?.~40 i ~--2723,38 ., 0.88 M~d~hwGui4¢ ..... ~,220 ?.~;~) ........... 2?24,26 ~d of,,~*mb~ ............... 2 2724.47 0:2-9 Bol~om Conn~to~ '"'~'"' ~,"~'000 9,164 ,, , , ,,, I 272,4.76 F~.d Of A~6{y ...... , , ,,,, , , {Long Siring Tubing' i0 0.00 40.77 i~l~'v"~on 1.9i0 9~ 40.77 3.43 FMC Tubing ~m~scr 1,~9~ .... 81 44.20 237.34, 23/8" 4.7iwIt 3-55 ~'S'H,rd Tubin~ 1;99~ 2.65~ 25L54, 4,95 2 3/8" CS tlyd ~o~ Coupt;n{ .......... Lgi0 ..... $ 288,55 4.73! 23/8' C$H),4 ~Coup~ .... 1.910 3.060 3 2703.99 0.82 "N~e" ~¢a~r 1.930 ~ ~?~:8b 4.~ "MSN" s~ ~ ................. ~,~': ~,~4~ I 2Toe.so 0.~ ~ Guide ].930 2,540 27~,34 ............ i.8?S 3.~ ,, .... ..... Lo.s s~_~ ' S¢~ H~d o 1,875 3.~0 1~ 2705.0~ 4,60 ~ ~ B~'~ n ' ' 2.5~ 3.246 lg 27~.65 0.66 ~ T~ ~W Head ........................... 1.995 3,0~ .... 16 2725.55 0.~7 X~ 23/8" B~ X 2~8" ~SfdP~ i,960 2,696 15 2q2&~ 62.~ 2 ~ "-~9'~ 3~ ~ 8rd Tt~ 1,995 3,063 ~ 14 27gg.~ 1.19 Ot~ 2 3~" 'X' Nipple 1.99S ~ 3~-9] ~,~ Z ~/~ ' 4,7 i~ ~;~-'g~ ~ tu~ ...... ].~, 3,063, l~ ~0~24 1~.Sl n~J~a 2~Z" i,910 3.~0 1~] 3~.85 2.~7 '~ "~" SIIdi~ ~lee~ 1.875; 3.090 9 ~7i.74 1~.~ 23/8" 4.?]b~ ~-JS ~~ z.~S .3.0~ '- 7 4~S,33 262,24 2 ~" 4.7 ~fl J-S~ E~ grd ~ .. ;~ ..... 6 4930.57 ~7.~ ~J0~a ~3/~" 1,910 3,060 4 5975.7l 2.~ O~ "~" ~ldl~ Sl~w 1.975 3.~9 2 6~.63 ~.38 O~ ] 3/0 .... XH" Hippie 1,7~ 3,0~1 ~94,71 ~d of Tu~ ~C Tubl~ ~g~ ~qulm ~" ~ Llffing ~ en SS and ~ 3~" BTaC on LS, HOT~ Al~nmeM Pi, in Tubi~he~ lea~ Pin h~ been ~bred, A n~ t~eb[head ,heold be in~l~d ea ~e a~ wor~er, , ,.~-..~ ............ C~K l~ ~S BELUGA SANDS "UppeC ~TS- 4~2 "LoweC ~14 · 5521 * 3~0 . ~ C1.1 4~ . 46~ 5532 - ~ - ~ CL2 4973 - 4978 95~ - S574 3~2 - ~ C~ 5576 · 55~ ' 4014.40~ C1.4 "Mi~' ~10. ~25 5592 - 55~ ' ~ - 4~ CI~ ~ - ~7 ~ - ~74 ' 41~-411~ CI-5 ~-~70 * 5757- 57~ 4116-4124 Ck5 5120-5135 ~8~-6~ 4141 - 4166 CI~ 51~- 5157 61~- 6150 41~ - 42~ eL7 51~ - 52~ El~ - 618~ 4272 - 42~ CI~ ~292 - 53~ 6330 - 6338 4~ - 4316 CI~ ~ - ~72 E~l - 8448 4378 - 4~ C1-10 5394 - ~14 6~0 - 6547 ' ~15 * ~0 C1-11 5431 - 54~ 6~1 - ~ - ~0 * 6718 · 6726 ~2 - ~ * 6r~ - 6758 67~ - ~ · New Pe~ons gu ~ 8'm'~: Ba~ ~ Wr ~-55 8 d 2 3/~" BIll Jo~ I ~d~: ~C~k ~ ~=~ ~d~ C~k ~ct U~ ,, ~ I 381 1990 TOO ~ 1945 Stealing Peris ~26o.337o Packer (~ 3so0' 3558 - 3366 3577 - 3581 (Sez'd) Cook Inlet Sands Paclmr~37H' ~820.3880 C1-1 ~3896-3960 Cl-2 ~3952-3994 CI-3 ~4014.4048 CI.4 Pac~r~40~ 4090-4098 4106-~1~1 0-5 , ~4116-4124 CI-5 ~4141 - 4166 ~cker ~ 41~' 4188-4238 Ch7 a~7~-4~8~ CJ~ ~4298-4316 437~-43~ C1-10 4440 C1-11 Pmcker~ ~luga~nds ~ ~ppe~ ~447~- 4482 ~4660-~68 ~d973-dg?8 5010.5025 ~s~o- ~o~7 ~5~4-5070 * ~50-5~7 ~5194-5204 Pack~~ 5292 5394-~414 543~-54~ PKker~ 5466-54~ * ~5482-5490" ~5514-5521 * ~5564-55T4 ~557e-5~ - 5757-5764 Pacl~rig15925' 6096 ~130.615D -"~6180-6166 -~6330o6338 6441.6448 6540.6547 6748-6758 679o-68oo Well: PROPOSED WELL COMPLETION FMC; 6~/r from ~ d~l 05/03/~ WATER DEPT~ 120 RKB-TBF; 48.77 ~2-3~: I le. Oe Tublnf Su, lnF & ~ $uba Ihllihr~en AWl[ F'm'a,mt l'kr 4 1~2" ! 2.'/5 lb/f~ 1.55 ~ bd Tub~j~ and ~ ]b~tomien Ihllibur. n AWl[ 4 I/2" 12,75 I~fl ~-$5 Hdliburbn WNo.C~" ,~sl Unit Ltnl[~ F,nllibuffnu "XD" S!i?.ag$1eav, 4 1/2- 12.75 lb./,,. 7.s5 4 1/2" 12,75 4 I/2' 12,75 "J~e-Ge# ~,.! Unit 4 !/2' 12.73 lb/fi: ~-55 ]~UEbd "i~'e-Ge" ~eal Unit 4 I/2" 12.75 lb/R 1-55 EUE8~ITUbLt~ ~nllibut~n "XDw ~lidJng Sit,we 4 1/2' 12.95 lb/fi: "Ne-C~" Seal Unit R~lllbu~t~n AWI~ 4 1/2' 12.75 lb/It ]hllibur~n "X])" 51idiag SI.ve 4 l/Z' ]Z?:~ lb'it WMlibUrtea A~Yi[ [~'nl~'ecet 4 I/2' 12.75 lb/fi: 1.55 EL~kdTuN~ ]hlliburl4)n "XD'~ $1idim~ SI#Ye 4 !/2' 12.?$ lb/It ~-$$ EUE 8rd Unit 12.75 lb/fi: "XD" $1idl.~ $1flw, I/2" 12.75 lb/it 1-55 ~llibudu AW~ 4 !/2' 12.75 i~tt 1.55 R-llibndm~ 41/~" 'XI~" NiJ)Jde ~820-3880 C1-1 3896-3960 Cl~ 3982-3994 CI-3 4014 - 4048 CI.4 4090-40~8 CI-5 410~-4111 CI-5 e116-4124 Ck5 414t -4166 CI-6 4188-4238 4272-4282 CI-8 4298-4316 CI.9 4378-4390 CH0 4415.4440 CH1 New Pedotffione 6.$23' J~upy;. Sm'~'t: l~bin'x No~h C~oklnl~t Unit Ne. ~-12 SHORT STRING DISPOSAL 4 1/2 ' 12.75 IMf 1.55 BUE Sd Tu~ "Upper 4475 · 4482 4650.4~8 4973 - 4978 "Middle~ 5010 - 5025 5632-5540 5564.5574 5576-5584 · 5592-5596 5050.5067 5668-5674 5064.5070 ' 5757-5764 5120.5135 6088-6096 5150.5157 6130-6150 5194-5204 6100-6186 5292-5305 6330-6338 5354-5372 0441 .6448 5394-5414 6540-6547 5431-5436 6641-6646 5466-5460 ~ 6718.6726 5482-5490 * 6748-6758 6790.6800 '[31~W~: ?.0'261b/tn 1-55 STfl. +41/2' i FiM~-'Cook Inlet Unit 25, lpg? PHI LL I~S, PET~ROLEUM COMPANY ', o, o',,.'~'(. ...................... l'h~J"weH"r~ame; Io'cot';~h" an'cl 'b~i~hoie"'refero'ni;'~ auto wOr~' furnished by the customee. -- ' ' ~-. '- __. - ...... . ' I ._ Illll , III_ _ -'- III I iiiiim_.. - IIII _. REMARKS .... .P,.g.;':. ~ . .{,1..~ l:~l iT") .'I'. [. : ~.R ON '"" '.'~ .............. .., . ., "- ,-. '-: .... !.,,~..]. i .0..~.; ~'~.j '-.,.. FURN i S~.~ OAT A .i Ai ER Ch~ge$ 'i~MudType' ~r Add-;tionbl Somgles ........ ~' ............... "t ........ ' "' .... "~ ......... Dole Sample No.. ' 'D~ ~ih'~D;i'i'leT ........... 7t_.F,%f!.~.[d..!'??~!?.'"]" ... ' ,] ," -"Db%fi" '~'vi~: ........ ..... ,.. ~ ..& ................. , ....... . ......... ph aFluid Loss ~' . mi ......... Scale C.h~nges "Type'L'og "" '", Depth ' Scale Up Hole , · L . ..... , ..... II I__.. mm i i I · ..... I I _ .. . Scale Down Hole'" 4 $_.~.o u r._c._.e ...,o_f ...S.._o.~.p,!e_ ........... ' ~' 'E.qu. ip.m, ent. _..R_~___~2i ..~.~_a..s: T~mp.. ¢'; ..... °F ....... '?'; ....... }'F"'R'~' '~[ .... T°°J':l'~'l~' ' i' Tool Position ~.R,~.,.."JLa,??2:.?".?' ,. '~" "~ F ....... F" ' ..... ~ F; "i ........... C ~ ' 'S't"~-D"O ~ K'" R,,,, 4, M, ea~.:r?emp' ra oF. "' °F 2 ..... DiT ' SY'/~ND'O~'F so,,,,e, n,,, R,..~ ST ~NbOP'F ....... ~ .., . .r .3 DIL , n,, ,,, I~HT ' r,, '"F' "r,," '~'F L~ ' ' DIT ........ t STANDOFF' 'i.: ~: YFF].~.~X.:L~';7'7:"FT." ";: ........ "i~ ........ ,~; ...... ~'~: ..................... ' .............. : ........-.~ -'- ,.,,. ..... , ..... ................. . · . . ' R,,, ,, ~Ht' , "' ;F; ,a , ~F . '' ? ' ..... T '' ~ ..... " ~,.,. N°.: O ~-C i T';/0 ...... Y HR'~ E - FOUR .................. - ' C~) ' C.D., uSE~}' ' ', U_'~:D:. ' ...... U§"~'D ....... "~"FTN .......................................... ' .................... $,O,: : ..~ I 5 . , "', ,~ J c,~ J Cl~ - . : .......... :,. ?. ................................................................. ".~ .Equip', PANEL No-:'DIP-X 1 t.~,r'. D iP-X~ ~Ji'3 Ot'i~-C .'21.2' Q.!_P"..X. .... L~J ..................... ~'~.~ , SONDENo.,D:- ~ ' ~. 0,'.:.-[5 lbS. DIS-B 7J DIS-B 146 ................... '.j~,.. IAPNo.:t.:;-'.r'.L. ~:-';;. FU,!P.,B ~-h~,'. Hr4P-(~, 33~ b.u',tP-(i"'2~2' s.~.~.: ~ z 2', "~ ......................... : ..... ~-' ' '..;:'. ..... ' ..... ' '"~' _ '_'" i.' ............ _"L' ~' ......... _" ...... FCh.ck one', filli~ in bi'one's-' ..h~te appl~c-~ble,' .... Ij'~'~, ~' ~., Surfo¢e de~ermin.d sonde errors u~ed lot ILM and ILD. . .J_~ j ILM and ILD sonde errors correcte~ for ,nth ......................... , ......... . ~' , .... , . , . v,,. . J,,.. ~..._._ ,. ..... ...,, ...... , .......... ~ .......... - ' 1' berehole s~gnal al Rm~ . ' '.... ['. i. i ..' .......... JE] ~£~ &nd lCD zer~s's~F]~"h'6i~"~i' depth '~f ....... - _:-., ,L ..... "- "'" ' -'-'~; -'-"-'"-; .... ~'~ ""-[.'~ '"-'~.i -~ .... ~="~ '"u,_,.:,_ ".~_~ .... - .... '~ -~-"' '-~ - I~[SiSTIVITY ohms- m~/m ,.. t.i ~;~ ,, 0 5O mmm~ ~! · m mm ~.~ m .... Other 't3~/"' ~,.. C0NDUCTIVIT¥ ~ 000 millimhos../m = .;~;...a..,~ dlf .............. .'- -- _ .,'., m L.~;f .... SPONTANEOUS.POTENTIAL ~ miJlivolts '" ... _~ , ......... . .......... ~ . ~ RECEIVED · of the dep~he ~t ~hich SWC, OCT 2,?. i9~Z Alaska Oil & Gas Cons. Commission 0CT-24-1997 1:3:18 PHILLI'PS PET,ROLEUI"I 'r']ot~t~-Fmm r-. ,~.,' I~.~.r I II~,.~,"I I1'.'~, ,, ~.. ] ~..f I~lln~l II IJ./I i .I ;i .i , 1, , ~ ~ ..~ ............ ii. ,., ii .i , .... $,8.R., £ 2 .................... ........ · · , ...... ' , ...... i..~, ............................ 'F-(~NecE one, filling i~i ,.,tonl,,s ,where apph¢obie; . ..'-.,.~ ...... ~Onc]e errors used for ILM and ...... ~ F~ Surfece determined ................ . ............. , ..~: ..... :.. ..... ' ................ I~ ILM ond' it, D'""~'~i-~ errors cor. r.e.c.'.e,,.d..t..o..r' ................. :.n,,c..n... !.~ ........· ............J.r~, . .... ~ · - . .,,,~,, --,,~.~ -.. , , armhole . hal at Rm-- · ....... ' ............. ........ , 'II~M 6'nd IL-Dzeros set in hole at depth of feet. millivolts ~ ' ~,CT IV ,T~oo . "c~i~m-s~ m'/m J millimhos..' m: 'oW,,,,.,:,v,,, .... · d AN,.~, , .~r, t,~.l;,' · I} I.___l- , Ill I Ill , .-- .... I ,,,, ..... ILD 0 lllll__.__iJIIIIlf ..... lilIlI! ...... IIIII 0 I.L-8 AVG. AMP. lO were taken are uncert~ n. .= ., , ,, . L ,. ,n ' /-., : -,.,. .__. .,,,,,_ -'." __- ~ ,, ; . Ad, II~' AU~'~ · , ' ' ,, ..,:, : /.i ...-'d'; ~"'~ .' ' .-,,,~'-,~ --! ...... ,t. lZ '" L..'~F ' -_ - .. i, ' ;' ._~' ¢ ,, :. , ~ ,, , .... l' ! '~ · . ! ....... '" ,, , : ..... i ' ,,, -- .~':- ~. ,. . 1, ' --- '" - 'i'. ..... s_.__. 0 0 ~HILLI~b ~I~UL~UI'I ; I i i ; · I I ! ; ' ! , , ' : I ! : · ; I ' I : I i i ! t ' ' ; ! I ~ i i ~ ' t ': ~ I ~ | I ! i ' I I | , ; C i , -' i , 0CT-24-1997 1~: 11 PHILLIPS P. ET~OLEUM 'r'~m~ too r. -~,, -,-, TOTRL P.14 PHILLIPS PETROLEUM COMPANY P. O. Box 1967 Houston, Texas 7'7251-1967 6330 We~ LoQp South ll.lla|re. T®xse 77401 October 24, 1997 North Cook Inlet Unit "A" No. 12 PPCo. T¥onek Platform North Cook Inlet Unit, Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. Blair Wondzeil Gentlemen' Enclosed for your consideration and approval are three copies of Form 10-403 (Application for Sundry Approval) and three copies of the tentative workover program for the A-12 well. Included in the program are the BOP schematic and the well control policy for the workover. The. Sundry Request is asking for approval to dual complete the referenced well into a combination producing well {as is planned), plus a Sterling Disposal Well as described on the attached procedure and weilbore'schematic, {This zone has been completed as a cuttings injection zone on the North Cook inlet Unit 'B" No. I and has worked great). A complete, detailed application for disposal usage will follow the Sundry Request. The reason it is not accompanying the request today is that Phillips has a drilling rig already on the well, working on the initially approved procedure. In order to get the wellbore mechanics set up, your approval is requested verbally so the appropriate steps may be performed as outlined in the procedure. Should you have any questions or require any additional information, please contact Paul R. Dean at (713) 669-3502, Regards, N. P. Omsberg North America Drilling Manager eric: CC: J. W. Konst (wenc) W. L. Carrico (w/o encl J. R, Soybel " ALA ,. iOIL AND 'GAS CONSERVATION COMMISSlC"-% APF. CATION FOR SUNDRY APt .. :OVALS 1. 'TYpe ~f-Request Abandon Suspend Alter Casing Repair Well _ Chan~e Approved Pro,c/ram x Pull Tubin,q 2. Name of Operator:. Phillips Petroleum Co. 3. Address: 6330 W. Loop South, Betlaire, Texas 77401 4. Location o1' well at surface: '~;~ek Platform Leg 1 Slot 3 1254' FNL & 927.8' FWL SEC 6-T 11N.R09W At top of productive interval: 1254' FNL & 927.8' FWL SEC 6-TlIN-RO9W At effective deft ( 11,100' MD; 9400' TVD) 1254' FNL & 927,8' FWL SEC 6-T11N-R09W At total depth: 1254' FNL & 927.8' FWL SEC 6-T11N-R09W 12. Present well condition summary Operation Shutdown ~ Re-enter Suspended Well Plugging Time Extension Stimulate. __ Varia...n,c.,e .... ,P., ,e,~orate.Other xx 5. Type of Well Development x Exploratory ~ Stratigraphic ,S,.ervice x ORIGINAL 6. Datum Elevation (DF or KB) RKB = 1t6 teat 7. Unit or Property Name North Cook Inlet Unit 8. Well Number A-12 i 9. Perl~i~'~'~b~:- I lao. m:'l-~um~er' ,, __ 50-88:3-20032 t 1. Pool Cook Inlet / Etelu,~a Total Depth measured 14,910' feet true vertical fee~ Plugs (measured) PBTD 6,823' Effective Depth measured 3,558' feet true vertical 3,558' feet Junk (measured) Casing Length Size Cemented Measured Depth True Vertical Depth Structural Conductor Surface Intermediate Production Liner 30" Driven 381' 381' 20" 1,142 sx 1990' 1990' 13-3/8" 1,820 sx 6950' 6950' Perforation Depth: measured true vertical 3,558' - 6,800' 3,$58' - 6,800' Tubing (size, grade, and measured depth) 7" 26 lb/It J-55 ST/L Tubing 2 318" 4.7 Iblff J-55 CS/Hydril Surface to 2,724'. Surface to 6,795', Packers and $SSV (type and measured depth) Halliburton" YWD" Permanent Packer (~ 2,719' with Twin-FIo Seal. Halliburton "CP-2" SSSV (~ 370.3§ and Type "Y~XO" WLRSV. Approval is requested pull the existing tubing strings and install a multiple packer production assembly to isolate zones of known water produ~ion. "* iN ADDITION, APPROVAL IS REQUESTED TO COMPLETE THE WELL AS A DUAL COMPLETION WITH A DISPOSAL ZONE COMPLETED AS DESCRIBED IN THE ACCOMPANYING PROCED,U,,,R, E AND WELLBORE SCHEMATI( Attachments ' Description summary of proposal _X_ Detailed Operations Program _X_ B-OP~ketch X i ~." E~timated Date for Commencing Operatior~: ....... 14. if proposal was verbally approved October 27. 1997 Name.of Al~,~rover,, f ' true 'a'n'~"'~'~ my DateA proved 21. I hemby~ that {n~ oregoing is to xhe best of ~owledge .... ' ' ~ Com~isslon U~e O~1~ ' ., Condifiqns of ~proval: . N~i~ Commission so representative may ~s ~ ~e~/~~-'1 'Approval No. _ NO- ~e~ ;< ~[~ Plug.lnt~d~ /BOP .Test Location Clearance -" ! dr~ginai Signeo By ~pp[oT~d by~er of the Commission ~,,,id W. Johnston Commissioner ,. Form 1~03 Rev. 061151~ SUBMW IN TRIPLICATE RECEIVED · FI ,L L-I-- i F ~ F KI I RI--II..K--.I--II' I PHILLIPS PETROLEUM COMPANY NORTH AMERICA E & P WORKQVER OPERATIONS WELL: AP! NO. FIELD: LOCATION: AFE: BUDGET ITEM: GROSS AUTHORIZATION: OBJECTIVE: Revision I North Cook Inlet Unit No. "A" 12 50-883-20032 North Cook Inlet Unit 1254' FNL & 927.8' FWL Sec, 6-T11N-RgW Leg 1; Slot 3; Tyonek Platform P-V196 2C ~ 2,970,000 COUNTY, STATE: Tyonek, Alaska AREA: Kenal Area WORKING INTEREST PPCO: 100 % Pull the Existing 7" and 2 318" Tubing Settings, Remove the Permanent Peeker, Run A Multiple Pecker Isolation System and Return the Well to Production. Procedure Revised to Run Cement Evaluation Logs, Perforate and Test Disposal Zone, then Complete Well as a Combination Producing/Disposal Well, ,, P. R. Dean DRILLING ENG. DIRECTOR J. R. Soybel DRILLING SUPERINTENDENT W. L. Carrico DRILLING MANAGER N. P. Omsberg OATE ~ ~, ,,,?, DATE DATE DATE _._ DISTRIBUTION: N.P. Omsberg J.R. Soybel (R) Central Files W. P. Carrico Development Supervisor (2) J.R. Jackson r) L. Airington J.P. Magee J.W. Konst W.N. Via (2) Pool Attic Alaska J.W. Spenoer P.R. Dean (Original) M.P. Gates ORIGINAL ( X ) REVISION ( ) ...... TIGHT HOLE: yES ( )... NO(X) , II RECEIVED ..... - :~. :.,"', ,- I'M 1 L,.L. 1 I-'~> t'"'l-' I I'~UI=.r'UI'I OBJECTIVE The objective is to pull the existing 7" and 2 3/8*' tubing strings , mill over slips and remove the existing Halliburton Model "YWD" packer; then clean the wellbore out to PBTD of 6,823'. The Sterling Disposal Sands will then be perforated and an injection test profile will be ran. Install packer settings as depicted on the Proposed Wellbore Schematic, then, each isolated interval is then to be individually flowed and cleaned up by opening the sliding sleeves, flowing, then closing the sleeve, starting with the lowest interval and working uphole. PRESEN~ STATUS The well was originally drilled in 1970 as the North Cook Inlet Unit No. A-15, to a total depth of 14,910'. The well is vertical to 7,000'. The well was plugged back to 6,823' and completed in ~he Beluga and Cook Inlet Sands as follows: Perforations Cook Inlet Sands 3558' - 3568' 3577' - 3587' 3604' - 3628' 3820' - 38807 3896' - 3960' 3982' - 3994t 4014' - 4048' 4090~ - 4098~ 4106' - 4111~ 4116' - 4124' 4140* - 4166' 4188' - 4238' 4272' - 4282' 4298' - 4316' 4378' - 4390' 4415' - 4440' Beluga Sands 4475' - 4482' 4660' - 4668' 4973' - 4978' 4990''- 4995' 5010' - 5025' 5050' - 5057' 5120' - 5135t 5150' - 5157, 5194' - 5204' 5292' - 5305~ 5354' - 5372' 5394' - 5414' 5431' - 5436' 5532' - 5540' 5564' - 5574' 5757' - 5764' 6130' - 61§0' 6330' - 6338' 6441' - 6448' 6641' - 6646' 6718' - 6726' 6748~ - 6758' 6790' - 6800~ Upper Cook Inlet Sands (3558-3568'; 3577-3587' and 3604-3628') were squeezed during the last workover in 1994. WELL D]%T~ RKB to THF RKB to SL Casing Fluid Production Casing Production Tubing NOTE : SCSSV : Tubing Hanger : Tubing Head : Casing Head : Production Packer : Bottom Hole Pres. : Surface Pressure : 41.00' 116.00' 9.0 lb/gal ~ % KCL Water 13 3/8" 72 lb/ft N-80 set @ 6,950' 7" 26.0 lb/ft J-55 AB ST/L @ 2,724' 2 3/8" 4.70 lb/ft J-55 CS Hyd @ 2,709' 2 3/8" 4.70 lb/ft J-55 EUE 8rd 2,710'- 6,795' Sliding Sleeve at $,975' is open. Halliburton "CP-2" 7" TRSSSV @ 370'. Otis "XXO" WLRSV @ 286'. FMC TC-1B-EN 12" x 7" Hanger Bushing. FMC TC-lC-EN 2 3/8" Hanger Coupling. FMC Type C-29-ET 20 3/4" 3M x 13 5/8" 3M FMC Type C-29-ET 20" SOW x 20 3/4" 3M Halliburton Model "YWD" Permanent Packer @ 2,719'. 1928 psi@ 6300' TVD. (5.9 lb/gal equivalent) 892 psi PROCEDURE . Notify State of Alaska as to Phillips Petroleum Company's plans for the workover. Skid rig over No. 12 slot, kill well with 8.6 lb/gal 2% KCl water / Flo-Zan polymer. Fill annulus with Kcl water. Bleed off any pressures and monitor same. Rig up to circulate dow~ the 2 3/8" tubing, taking returns up the 7" tubing through the choke manifold. Pump viscous fluid down 2 3/8" tubing and up the 7" until the 7" tubing pressure rises 500 p~i. Continue pumping down the 2 3/8", opening choke as required to maintain constant pressure on the 2 3/8" tubing until kill is complete. When well is stable, close the 7" SCSSV and pressure up to 500 psi on 2 3/8" to test the 7" SCSSV from below. Bleed pressure off 2 3/8" tubing and measure flow back. Re- pressure 2 3/8" tubing to 500 psi. Close 2 3/8" SCSSV. Bleed off pressure. Volume bled back should be less than before, confirming the 2 3/8" SCSSV is holding. Install BPV'S w/ blanking plug and test from above to 1000 psi. Remove XMAS tree, NU and test 13 5/8" 10M BOP equipment, utilize a 13 5/8" 3M x 13 5/8" 5M DSA and 13 5/8" 5M spacer spools as required to for spacing. Test the BOP equipment as per the attached "Well control" program. Rig up to pull tubing. Make I 1/2" wireline gauge run to determine extent of fill inside tubing. Close sleeve at 5975' and determine if circulation can be obtained. Release 2 3/8" tubing hanger assembly from the wellhead, work tubing and pull the siphon string from the Twin-Flow Adapter (packer). POOH with 2 3/8" tubing. Release the 7~ hbing hanger and pull the 7 ..,roduction tubing, SCSSV, Twin Flow Adapter and 2 3/8" siphon string, circulate out any gas from below the packer as the Twin-Flow Adapter and lower string of 2 3/8" tubing are pulled from the packer. . TIH with packer milling assembly. Mill over packer slips and recover Halliburton "YWD" permanent packer (or push entirely to bottom). POOH. MIRU Schlumberger. Run an accurate Cement Evaluation Tool / Gamma Ray /Collar Locator from PBTD to 3000.' for use in correlating and spacing out packers. If Cement Evaluation Log does not gave accurate indication of cement from 3500' to 3000', POOH and pick up retrievable bridge plug. set same @ 3,500' and pressure up 13 3/8" casing to 2,000 psi. Re-Run CET log from PBTD to 3000'. Disouss results of CET with Houston office and State of Alaska. If both concur that cement is adequate, proceed with perforating Sterling Disposal Zone 3260'- 3320' W/ 4 SPF. TIH with 13 3/8" bridge plug (if not already set in Step No. 6) and set same at 3450'. Take injection rates and pressures for I BPM through 6 BPM. Report rates and pressures to Houston office. Recover RBP. 8~ TIH with 12 1/4" bit and casing scraper for 13 3/8" 72 lb/ft casing. Clean out casing to PBTD of 6823'. Circulate hole clean and POOH. 9~ TIH with Halliburton 13 3/8" x 4 1/2" production assembly (TENTATIVE recommendation proposed on accompanying Proposed Wellbore Schematic). Run permanent packer assemblies individually. Set the uppermost permanent packer assembly at 3,450' ( + / - 30'). 10. Make up Halliburton muleshoe guide and Nitrile Molded Seal A~sembly on 7" tubing string. TIH with tubing and Halliburton Type "CP-2" TR SCSSV. Land seal assembly into the packer seal bore extension. Make up and run 2 3/8" Disposal Tubing String. Land same into Twin-Flo Seal Assembly. Space out and land tubings. After space-out, pull out of seal bore and circulate 30/70 methanol / Kcl packer fluid into the annulus. 11. Close SCSSV, install BPV, ND BOP equipment and NU and test 7 1/16" x 2 3/8" dual tree. Remove BPV. 12. TIH with wireline shifting tool. open sliding sleeves, starting with the deepest. Flow well until zone cleans up, obtain stabilized rate and pressure, then close in the well at the surface. Shut in at surface for 2 hours and obtain SITP. Close the sleeve and open the next sleeve above, until all producible intervals have been cleaned 13. Use nitrogen and, if necessary, coiled tubing to lower fluid level and get well kicked off. Unload well to flare and allow to clean up through the rental testing equipment prior to releasing w~ll production. Release drilling rig to next well. [11 [[[[ ~ ......... . .... Flewline Fill.up Line Kill Line 13 ~ GM Annular Preventer · 13 5/8' 5M x 13 &/8~ 10M Adapter ... I I 13 5/8" 10M Pipe or Variable Bore Pipe Rams J t 43 ~dB" t0M Blind Rams [~, )~'i" ~OM Dnllin. Sp°°I. Choke line H~R Valve Gate Valve I J G,tte Valve H~R Valve J 13 ~ 1OM Pipe Ram~ 13 6/8" 1OM Riser 13 6/8" 10M x 13 ~. GM DSAAdapter Flange t3 6M" 5M Spacer Spools (2) 13 Sm' ~/f X t3 6/8" 3M Adapter Flange 13 6/8" SM x ~0 $14" 3M Tubing Heal 20 314" 3M x 20" SOW Casing Head 20' Casing 13 5/8- 10M BOP and Riser System Use Dt.lng Werlmv~ Operations prd / October 18; 1997 ................. iii i lib _ . PHILLIPS PETROLEUM COMPANY North Cook Inlet Unit "A" No. t2 ! i 381 1990 TOC @ 1945 Halliburton YWD Packer {~ 2719' EXISTING WELL COMPLETION DI.'A~..C~AM ype, OD) F~-~' g3-T~ ~ ~ 2.-~'~PV's Tbg.l ~. ,M[ake,Type) FMC Annulus Fluid: 8.6 ppg 2 % KCL Water with 70/30 Glycol TOC: 1945' from CBL dated 05/0:3/70 WATER DEPTIt: 120 ' RKB-ML: RKB-DrlII Deck: RKB-TltF: 40.77 RKB-SL: 116.00 Production Casing: 41 41 381 1,990 133 lb/fl J~55 1420 2880I 473'01 6,950 72 Ib/fl N-go BT&C 2520 Tubing String: Short String 411 2,7241 . 26 Ib/fl I J-55 I AB-ST/L I 46601 Tubing String: Long String 40801 208 41 2,709 4.7 lb/fl ] J-55 2,710 6,795 4.7 Ib/fi I J-55 CS-Hyd (sp cOI EUE 8rd 6290 7040 6290 7040 COMPLETION STRING 3558-3568 (Sqz'd) 3577-3587 (Sq~d) 3604-3628 g (Sqz'd) Cook Inlet Sands 7 3820 - 3880 C1-1 73896-3960 CI-2 73982-3994 Cl-3 74014-4048 CI-4 74090-4098 CI-5 74106-4111 Cl-5 74116-4124 Cl-5 74141 - 4166 CI-6 74188 - 4238 CI-7 74272-4282 CI-8 74298-4316 'CI-9 ~4378-4390 C1-10 74415- 4440 C1-11 Beluga Sands "Uppe~ 24475- 4482 ~4660-4668 ~4973-4978 24990-4995 ~ "Middle" 25010- 5025 25050-5057 ~5064-5070 * 25120-5135 ~5150-5157 25194-5204 ~5292 - 5305 25354-5372 ~5394-5414 ~5431-5436 25466,5480 * ~5482~5490 * 2 "Lowe~ ~5514-5521 * 25532~5540 ~5564~5574 ~5576-5584 * ~5592-5596 * ~5668-5674 · ~5757-5764 26o88-6o96 · ~6130-6150 26180-6186 * ~6330-6338 26441-6448 ~6540~6547 * .~i6641-6646 ~6718-6726 ~6748-6758 26790-6800 PBTD 6823' ~IBP 6834' 13 3/8" @ 6950' o.oo 40.77 40.77 3.15 43.92 318.41 362.33 8.03 370.36 11.36 381.72 5.21 386.93 2307.72 2694.65 15.00 2709.65 0.65 2710.30 0,68 2710.98 5,371 2716.35 1,10! 2717.45 1.71 2719.16 4.22 2723.38. 0.88 2724.26 2719.00 5.47 2724.47 0.29 2724.76 0.00! 40.77 40.77 3.43 44.20 237.34 281.54 4,95 286.49 2.06 288.55 4.73 293.28 2410.70 2703.98 0.82 2704.80 4.00 27O8.80 0.54 ! 2709.34 2704.80 0.25 2705.05 4.60 2709,65 0.65 2710,30 15,25 2725.55 0.67 2726.22 62.50 2788.72 1.19 2789,91 1002.33 3792.24 198.61 399O, 85 2.87 3993.72 478.02 4471.74 156.65 4628.39 19.94 4648.33 282.24 4930.57 387.43 5318.00 657,71 5975.71 2,86 5978,571 8t4,06 6792.63 1.38 6794.01 0.70 6794.71 Short String Tubing Elevation FMC Tubing Hanger 7" 26 lb/fl J-55 ST/L Tubing 6.240 7" 26 Ib/fi J-55 ST/L Tubing Pup 6.240 Halliburton "CP-2" TRSSV with Top & Bottom Subs 5.900 7" 26 Ib/fl J-55 ST/L Tubing Pup 6.240 7" 26 lb/fl J-55 ST/L Tubing 6.240 7" 26 lb/ft J-55 ST/L Tubing Pup 6.240 Twin Flow Head 6.270 10 3/4 "'Coupling 10,750 10 3/4" Pup Joint 10.000 Reducer 103/4"SCT X 95/8" SCT 8,840 Swage 9 5/8" SCT X 7" SCT 6,220 "MSN" Seals (3) 6.220 Mul¢sho¢ Guide 6.220 End of Assembly Packe~' Assembly Halliburton "YWD" Packer 8.000 Bottom Connector End of Assembly Long String Tubing Elevation FMC Tubing Hanger 2 3/8" 4.7 Ib/fl J-55 CS 2 3/8" CS Hyd Flow Cou Otis l IXXO Type "XXO" 2 3/8" CS Hyd Flow Coupling 2 3/8" 4.7 Ib/fl J-55 CS Hyd "No-Go" Locator "MSN" Seals (4) Muleshoe Guide Long String (Lower) 1.910 1.995 1.910 1.995 1.930 1.930 1.875 1.875 Scoop Head 1,995 Seal Bore Extension 2.500 Twin Flow Head 1.995 2 3/8" 4.7 Ib/ft J-55 EUE 8rd Tubing 1.995 X-Over 2 3/8" BTC Box x 2 3/8" EUE 8rd Pin 1.960 2 3/8" 4.7 lb/fl J-55 EUE 8rd Tubing Otis 2 3/8" "X" Nipple 2 3/8" 4.7 lb/fl J-55 EUE 8rd Tubing Blast Joints 2 3/8" 1.995 1.995 1.995 1.910 Otis "XA" Sliding Sleeve 1.875 Blast Joints 2 3/8" 1.910 2 3/8" 4.7 lb/fl J-55 EUE 8rd Tubing 1.995 Blast Joints 2 3/8" 2 3/8" 4.7 lb/fl J-55 EUE 8rd Tubing 1.995 Blast Joints 2 3/8" 1.910 2 3/8" 4.7 lb/fl J-55 EUE 8rd Tubing 1.995 Otis "XD" Sliding Sleeve 1.875 2 3/8" 4.7 lb/fl J-55 EUE 8rd Tubing 1.995 Otis 2 318 .... XN" Nipple 1.790 Otis Pump-Out Plug & WL Re-Entry Guide End of Tubing 1.980 FMC Tubing Hanger requires 7" BT&C Lifting Thread on SS and 2 3/8" IIT&C on LS. NOTE: Alignment Pin in Tubinghead leaks. Pin has been replaced. A new tubinghead should be installed on the next workover. COOK INLET SANDS BELUGA SANDS "Upper" 4475-4482 "Lower" 3820-3880 C1-1 4660-4668 3896-3960 CI-2 4973-4978 3982-3994 Cb3 4014-4048 C1-4 "Middle" 5010-5025 4090-4098 C1-5 5050-5057 4106-4111 C1-5 5064-5070 * 4116-4124 CI-5 5120-5135 4141-4166 Cl-6 5150-5157 4188-4238 C1-7 5194-5204 4272-4282 Cl-8 5292-5305 4298-4316 Cl-9 5354-5372 4378-4390 CMO 5394-5414 4415-4440 C1-11 5431-5436 5466-5480 * 5482-5490 ' * New Perforations 5514-5521 5532-5540 5564-5574 5576.5584 5592-5596 5668-5674 5757-5764 6088-6096 6130-6150 6180-6186 6330-6338 6441-6448 6540-6547 6641-6646 6718-6726 6748-6758 6790-6800 PBTD: 6,823' [Supv: S'm'ton; Babin'x [Tog Wt: 4.7 Ib/fl J-55 Well: North Cook Inlet Unit No. A-12 } Location: Lower Cook lnlet~ Alaska , , Field: Cook !nlet Unit 8 rd + 2 3/8" Blast Joints April 25, 1994 PRD PBTD 6823' 381 1990 TOC {~ 1945 Dual Packer g~ 2719 Packer {~ 3500' 3558 - 3568 (Sqz'd) 3577- 3587 (Sqz'd) 3604- 3~8 (Sqz'd) Cook Inlet Sands Packer I~ 31'50' 3820 - 3880 C1-1 ~3896 - 3960 CI-2 Packer ~ 3970' 3982 - 3994 Cl-3 24014 - 4048 CI-4 Packer ~ 4070' 4090 - 4098 Cl-5 ~4106 - 4111 Cl-5 ~4116 - 4124 Cl-5 14141 - 4166 CI-6 i Packer {~4175' - 14188 - 4238 Packer ~ 4255' 4272 - 4282 Cl-8 ~4298 - 4316 CI-9 ~4378 - 4390 C1-10 ~4415 - 4440 C1-11 Packer {~ 4452' Beluga Sands ~ "Upper" ~4475- 4482 Packer ~ 4550, 4660 - 4668 ~4973 - 4978 ~4990- 4995 ~ "Middle'; ~5010 ~ 5025 ~5050- 5057 ~5064 - 5070 * ~5120 - 5135 ~5150 - 5157 ~5194 - 5204 Packer ~. 5250' 5292 - 5305 ~5354 - 5372 ~5394 - 5414 - 5436 Packer ~ 5450' 5466 - 5480 * ~5482- 5490 * ~ "Lower" ~5514- 5521 * ~5532 - 5540 75564- 5574 ~i5576- 5584 * ~5592 - 5596 * [5668 - 5674 * 5757 - 5764 Packer{~592~ 6088 - 6096 * !6130-6150 ~6180-6186 * ~6441-6448 ~6540-6547 * ~6641-6646 ~6718-6726 ~6748-6758 ~6790-6800 CIBP 6834' t i;~POSED WELL COMPLETION DIAGRAM ~ BPV(Make'i ~D) FMC 6 318" IS-A . ~ JRiO~-DrillDeck: ~ ~ ~ e' ~1C ' ' I~-~' 40 77 Tbg.~gr.[~a~., ~ yp ) ' ' ' Annulus Fluid: 8.6 ppg 2 % KCL Water with 70/30 Glycol - J~-su: 116.00 TOC: 1945' from CBL dated 05/03/70 WATER DEP~I: 120 ' /~B-~: Production Casing: 20 ' 4 ! 1,990 133 lb/~ 26 lb/~ ~.7 lb/~ COMPLETION STRING 3 5925.00 6.50 2 5931.50 874.00 I 6805.501 1.50I I eao7.001. I 3820- 3880 C1-1 J 3896-3960 Cl-2 7" 26 lb/it 1-55 ST/L Tubin~ Halliburton "CP-2" TRSSV with Top & Bottom Subs 7" 26 lb/it 1-55 ST/L Tubin~ Iialliburton "No-Go" Locator "MSN" Seals (3) and Seal Extettsion (1 (0.$$ ' Length) 451 3500.001 6.501 Halliburton A~/R P'rm'nent Plo' 44 [ 3506.50 [ 17.50 [ ltalliburton Seal Bore Exlension and Tbg. Adapter. 43[ 3524001 225.2014 1/2' 12.75 lb/it.J-55 EUE8rdTubing I 42 J 3749.201 0.80 JHalliburton "No-Go" Seal Unit LenglhJ = S.08 OA J 4] I 3750.00 J 6.50 J Ham~.no. AW~ P'rm'.e.t P~ a.d Xbg. Adapter. J 4O I 375~.50J 204.70l 4 1/2" 12.75 lb/it ~-55 EUE 8rdTubing J 39 J 3961.20 J 4.00 J liailiburton "XD" Sliding Sleeve J 3si 3965.20J 4.00J4 1/2" 12.75 lb/it ]-55 t 371 3969.201 0.80 Imllihn--o-"No-~" Seal U.it ~..¢hl= S.OS on Halliburton A~ P'rm'nent Plo' and 4 1/2' ]2.75 lb/it 1-55 EUE 8rd Tubinl~ Halliburton "X-D" Sliding Sleeve 4 I/2" 12.75 lb/it ]-55 EUE 8rd liburton "No-Go" Seal Unit Len tlallihurton A~,VR P'rm'nent Plo' and Tb 1/2" 12.75 lb/it J-55 EUEgrdTubi~ burton "XD" Sliding Sleeve 4 1/2" 12.75 lb/it ~-55 lialliburton "No-Go" SealUnit Lea Halliburton AW'R P~rm~nent Plo' and 4 1/2" 12.75 lb/it Halliburton "No-Go" Seal Unit Halliburton A'WR P'rm'nent Plo' and Th !/2" 12.75 lb/it ~-55 EUEgrd'l'ubin$ Halliburton "XD" Sliding Sleeve 4 1/2" 12.75 lb/it ~-55 EUE8rd llburton "No-Go" Seal Unit Len~lh Halliburton AWR P'rm'nent Plo' and Th 4 i/2" 12.75 lb/it 1-55 iburton "No-Go" SealUnit Len Halliburton A~V'R P'rm'nent Plo' and I/2" 12.75 lb/it ~-55 EUE8rdTubinJ~ Halliburton "XD" Sliding Sleeve 4 i/2" 12.?5 lb/it ~-55 EUE 8rd Tubing iburton "No-Go" Seal Unit tlalliburton AWR P'rm'nent Pkr and 4 i/2" 12.75 lb/fl ~-55 EUE8rd iburton "XD" Sliding Sleeve 1/2" 12.75 lb/it 1-55 llhurton "No-Go" SealUnit Lea Halliburton A~V'R P'rm'nent Plo' and Tbg, Adap 4 !/2" 12.75 lb/R ~-55 EUE 8rd Tubin$ Halliburton "XD" Sliding Sleeve I/2" 12.75 Ib/fl J-55 EUE Halliburton "No-Go" Seal Unit Le~ Halliburton AIArR P'rm'nenl Plo' and Tbg. Adapter, 4 I/2" 12.75 lb/it ]-55 EUE8rdTubin~ Halliburton 4 1/2" "XN" Nipple End of Tubinl~ "Upper" 4475 - 4482 "Lower" 8.000 12.090 8.000 J 12.090 3.9~ 3,982,l 9.500 s.000 1 12.09._0. 3.958 4,506 3.813 5.600 3.958 4.500 3.985 9.500 8.000 12.090 3,958 4.50~ I 3.750J 5.03~0 5514-5521 * 3982-3994 Gl-3 ~- 4014-4048 Cl-4 4090- 4098 CI-5 4106- 4111 CI-5 4116 -4124 CI-5 4141 - 4166 CI-6 4188-4238 CI-7 4272-4282 CI-8 4298-4316 CI-9 4378-4390 C1-10 4415-4440 C1-11 4660- 4668 5532- 5540 4973-4978 5564-5574 557G-5584 * "Middle" 5010-5025 5592-5596 5050- 5057 5668- 5674 5064- 5070 * 5757 -5764 5120-5135 6088-6096 5150-5157 6130-6150 5194-5204 6180-6186 5292-5305 6330-6338 5354-5372 6441-6448 5394-5414 6540-6547 5431-5436 6641-6646 5466-5480 * 6718-6726 5482-5490 * 6748-6758 6790-6800 * New Pedomtions PBTD: 6.823' [Supv: S'm'ton; Babin'x Well: North Cook Inlet Unit No. A-12 Location: Lower Cook Inlet, Aln~ica- JTbsWt: 7.0,261b/ft 1-55 ST/LSrd + 4 I/2" 12.751b/ J September 25, 1997 Field: Cook Inlet Unit PRD PHILLIPS PETROLEUM COMPANY P. O. Box 1967 Houston, Texas 7725 i-1967 6330 West Loop South Bellaire, Texas 77401 October 03, 1997 'Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn' Mr, Blair Wondzell North Cook Inlet Unit "A" No. 12 PPCo. Tyonek Platform North Cook Inlet Unit, Alaska Gentlemen: Enclosed fOr your consideration and approval are three copies of Form 10-403 (Application for SundrY Approval) and three copies of the tentative workover program for the A-12 well. Included in the program are the BOP schematic and the well control policy for the workover. Should you have any questions or require any additional information, please contact Paul R. Dean at (713) 669-3502. en'c: cc: J. W. Konst (w eric) W. L. Carrico (w/o enc) J. R. Soybel P. R. Dean ( w/enc )- Regards, N. P. Omsberg North America Drilling Manager ORI$1NAL RECE!VED 05 1997 ~aska 0JJ ,& Gas Cons. L;0.mm STATE OF ALASKA ALASK~ AND GAS CONSERVATION COMMISSI,¢~, , AppL,,.,ATION FOR SUNDRY AF. , ,OVALS -'1. Type of Request Abandon Suspend Operation Shutdown Re-enter Suspended Well . ' Alter Casing Repair Wel-~"- P~l.,ugging ~ Time Extension ~ Stimulate Chan e A roved Pro ram Pull Tul~in Varia_n.c.e .. 2. Name of Operator: 5~. Type of Well ,, ~ Development ~ I Exploratory ~ Stratigraphic ] Service Phillips Petroleum Co. 3. Address: 6330 W. Loop South, Bellaire, Texas 77401 4. Location of well at surface: Tyonek Platform Leg I Slot 3 1254' FNL & 927.8' FWL SEC 6-T 11N-R09W At top of productive interval: 1254' FNL & 927.8' FWL SEC 6oT11N-R09W At effective dept ( 11,100' MD ; 9400' TVD) 1254' FNL & 927.8' FWL SEC 6-T11N-R09W At total depth: 1254' FNL & 927.8' FWL SEC 6-T11N-R09W 12. Present well condition summary Total Depth measured 14,910' feet true vertical feet Effective Depth measured 3,558' feet true vertical 3,558' feet Casi'ng Length Structural Conductor Surface Intermediate Production Liner Size Cemented 30" Driven 20" 1,142 sx 13-3/8" 1,820 sx =erforate Other RKB = 116 feet 7. Unit or Property Name North Cook Inlet Unit 8. Well Number A-12 I9' Per~um--.b~) ~ ~ IO. APl Number 50-883-20032 _ 1. Pool Cook Inlet / Beluga Plugs (measured) perforation Depth measured true vertical 3,558' - 6,800' 3,558' - 6,800' Junk (measured) Measured Depth PBTD 6,823' ORIGINAL True Vertical Depth 381' 381' 1990' 1990' 0CT 0 6 1997 .Oil & Gas Cons, Cornrniss~ : , ~chorage Tubing (size, grade, and measured depth) 7" 26 Ib/ft J-55 ST/L Tubing 2 3/8" 4.7 Ib/ft J-55 CS/Hydril Surface to 2,724'. Surface to 6,795'. Packers and SSSV (type and measured depth) Halliburton "YWD" Permanent Packer @ 2,719' with Twin-FIo Sea Halliburton "CP-2" SSSV @ 370.36 and Type "XXO" WLRSV. Approval is requested pull the existing tubing strings and install.a multiple packer production assembly to isolate zones of known water production. November 01~ 1997 -- 14. If proposal was verbally approved ~ Name of A~--rover ' Date A roved I ~~~' ~~ i App.,rov,~a~ No, L.' ..~ ' pp · o Plug Integr,ty /"- BOP Test Locat,on Clearance ~_~.~ .,/'~--~ ~,~,~j~r~a] Signed By Ap r~ed b order of the Commission 0avid W. Johnston commissioner OBJECTIVE The objective is to pull the existing 7" and 2 3/8" tubing strings' and , remove the Halliburton Model YWD packer, clean the wellbore out to PBTD of 6,823' and install packer settings as depicted on the Proposed Wellbore Schematic. PRESENT STATUS The well was originally drilled in 1970 as the North Cook Inlet Unit No. A-15, to a total depth of 14,910'. The well is vertical to 7,000'. The well was plugged back to 6,823' and completed in the Beluga and Cook Inlet Sands as follows: Perforations Cook Inlet Sands 3558' - 3568' 3577' - 3587' 3604' - 3628" 3820' - 3880' 3896' - 3960' 3982' - 3994' 4014' - 4048' 4090' - 4098' 4106' --4111' 4116' - 4124' 4140' - 4166' 4188' - 4238' 4272' - 4282' 4298' - 4316' 4378' - 4390' 4415' - 4440' Beluga Sands 4475' - 4482' 4660' - 4668' 4973' - 4978' 4990' - 4995' 5010' - 5025' 5050' - 5057' 5120' -.5135' 5150' - 5157' 5194' - 5204' 5292' - 5305' 5354' - 5372' 5394' - 5414' 5431' - 5436' 5532' - 5540' 5564' - 5574' 5757' - 5764' 6130' - 6150' 6330' - 6338' 6441' - 6448' 6641' - 6646' 6718' - 6726' 6748' - 6758' 6790' - 6800' Upper Cook Inlet Sands (3558-3568'; 3577-3587' and 3604-3628') were squeezed during the last workover in 1994. WELL DATA RKB to THF RKB to SL Casing Fluid Production Casing Production Tubing SCSSV : Tubing Hanger : Tubing Head : Casing Head : 41.00' 116.00' 9.0 lb/gal 2 % KCL Water 13 3/8" 72 lb/ft N-80 set @ 6,950' 7" 26.0 lb/ft J-55 AB ST/L @ 2,724' 2 3/8" 4.70 lb/ft J-55 CS Hyd @ 2,709' 2 3/8" 4.70 lb/ft J-55 EUE 8rd 2,710'- 6,795' Halliburton "CP-2" 7" TRSSSV @ 370'. Otis "XXO" WLRSV @ 286'. FMC TC-IB-EN 12" x 7" Hanger Bushing. FMC TC-lC-EN 2 3/8" Hanger Coupling. FMC Type C-29-ET 20 3/4" 3M x 13 5/8" 3M FMC Type C-29-ET 20" SOW x 20 3/4" 3M Production Packer : Bottom Hole Pres. : Halliburton Model "YWD" Permanent Packer @ 2,719' . 1400 psi (7.8 lb/gal equivalent Max. Anticipated). R'~EIVED I · OCT 06 1997' PROCEDURE A!a$~a Oil & Gas Co~s. Comm~ss~ ~, An_cl~0mge ~otify State of Alaska as to Phillips Petroleum ~omp~n¥~s plans for the workover. · Skid rig over No. 12 slot, kill well with 8.6 lb/gal 2% KCl water / XanVis polymer. Fill tubings and annulus with KCl water. Bleed off any pressures and monitor same. Circulate high viscosity brine down long string tubing. Then circulate down the 7" tubing and out the 2 3/8" string. When well is stable, close the 7" SCSSV and pressure up to 500 psi on 2 3/8" to test valve from below. Bleed pressure off 2 3/8" tubingand measure flow back. Re-pressure 2 3/8" tubing to 500 psi. Close 2 3/8" SCSSV. Bleed off pressure. If volume bled back is less than before, valve is holding. · · Install BPV's w/ blanking to test from above. Remove XMAS tree, NU and test 13 5/8" 10M BOP equipment. Utilize a 13 5/8" 3M x 13 5/8" 10M DSA. Test the BOP equipment as per the attached "Well Control" program. Rig Up to pull tubing. Release 2 3/8" tubing hanger assembly from the wellhead, work tubing and pull the siphon string from the Twin- Flow Adapter (packer). Release the 7" tubing hanger and pull the 7" production tubing, SCSSV, Twin Flow Adapter and 2 3/8" siphon string. Circulate out any gas from below the packer as the Twin-Flow Adapter and lower string of 2 3/8" tubing are pulled from the packer. · TIH with storm packer or RBP. Set same at 1,000'. POOH. Repair existing tubing head (damaged alignment pins) at this time or replace and test the tubing head to-1500 psi. Install blanking plug in the short string side of the tubing hanger to isolate same when replaced. TIH with packer! 21ling assembly (Weatherf~ or Tri-State). Mill over packer slips and recover Halliburton .YWD" permanent packer. POOH. · TIH with 12 1/4" bit and casing scraper for 13 3/8" 72 lb/ft casing. Clean out casing to PBTD of 6823'. Circulate hole clean and POOH. · MIRU Schlumberger. Run Cased Hole RST (Carbon / Oxygen) Log from PBTD to 3700'. · TIH with Halliburton 13 3/8" x 4 1/2" production assembly (TENTATIVE recommendation proposed on accompanying Proposed Wellbore Schematic). Run permanent packer assemblies individually'. Set the uppermost permanent packer assembly at 3,450'. 10. Make up Halliburton muleshoe guide and Nitrile Molded Seal Assembly on 7" tubing string. TIH with tubing and Halliburton Type "CP-2" TR SCSSV. Prior to reaching the packer, circulate 70/30 methanol / Kcl packer fluid into the annulus. Land seal assembly into the packer seal bore extension. Test annulus to 1000 psi, then space out and land tubing, 11. Close SCSSV, install BPV, ND BOP equipment and NU and test 7 1/16" x 2 3/8" dual tree (NOTE: 2 3/8" dual part is blocked off with blanking plug installed in tubing hanger). Remove BPV. 12. TIH with wireline shifting tool. Open sliding sleeves, starting with the deepest. Flow well until zone cleans up, then close the sleeve and open the next sleeve above. 13. Use nitrogen.and, if necessary, coiled tubing to lower fluid level and get well kicked off. Unload well to flare and allow to clean up through the rental testing equipment prior to releasing well to production. Release drilling rig to next well. SECTION WELL CONTROL PROCEDURES This well is-a category 3 well, as defined in Phillips Completion Workover and Well Control Policy. As such two barriers must be in place during nipple up and nipple down operations. For all other operations two barriers, e.g. the BOP's, fluid column, etc. must be in place in order to conduct simultaneous operations. The BOP equipment is 10000 psi WP Class 4 as per Phillips Well Control manual. The bottom set of rams should be 5" pipe rams, the middle set will be blind rams and the top.set should be variable rams. Although the BOP is rated to 10000 psi, the riser and the wellhead are rated to 5000 psi. The BOP and choke manifold should be stump tested to 3000 psi. The BOP should be tested to 3000 psi upon nipple up and to 1500 psi on a weekly basis. The Alaska Oil and Gas Conservation Commission (AOGCC) should be notified prior to conducting BOP tests. The notification to AOGCC should be made early enough for them to witness the test if they desire. The maximum surface pressure for the well is 1071 psi. This pressure was obtained during the welltest of February 10, 1994. The well can be killed and stability maintained with 9.0 lb/gal fluid. Well control drills are to be conducted with each crew as per Phillips well control manual. Drills should be reported on the IADC daily drilling report and on Phillips Daily Drilling Report. This well produces from a series of very permeable sands. A small decrease in pressure at the perforations can result in very large flowrates. It is vital that good well control practices be followed during the course of this workover. Trip speed while POOH should be kept relatively slow to avoid any tendency to swab. Before any trip is made swab and surge calculations should be made based on the properties of the fluid in the hole. DO NOT exceed the running speed determined by the calculations. A detailed trip book comparing measured fill up requirements to the calculated requirements should be maintained for each trip. The cause for any discrepency between the actual and required fill up volume must be determined before continUing with the trip. MAINTAINING CONTROL OF THE WELL IS OF THE UPMOST IMPORTANCE, TRIP SPEED IS SECONDARY. The perforated intervals are below the Halliburton "YWD" permanent packer, therefore, 39' different intervals between 3518' and 6800' TVD are effectively commingled at the present time and cannot be isolated.. Ail of the zones presently perforated in this well can be killed with water. As a precautionary measure, a line should be ran from the annulus valves on the tubing head to supply workover fluid, drillwater, or seawater. This line can be used to supply workover fluid as discussed above or as a last resort can be Used to kill the well with drillwater or seawater. Pumping drillwater or seawater through the annulus valves should be considered only in an emergency situation as these fluids could result in formation damage. RISER AND BOP ARRANGEMENT r i 6M ANNULAR PREVENTER 1OM VARIABLE BORE PIPE RAMS KILL LI NE NCR ~LVE GATE I~LVE 1OM BLIND RAM8 DRILLING 8POOL (JHOKE LINE GATE ~ALYE H(~R M~LYE 6' 1OM PIPE RAM8 13 6/8' 1OM RISER ADAPTER X 13 6/8' 1OM TUBING HEAD 13 6/8' 6M RECEIVED G 1997 Cons. Cot ~ctlorage 381 1990 TOC @ 1945 Otis Twin Flow Dual Packer ~ 2719 FINAL WELL COMPLETION FMC 6 318' IS-A a, O' IS-A BPV'8 Annulus Fluid: 8.6 ppg 2 98 KCL Water with 70/30 Glycol TOLD: 1945' from CBL dated 05/03/70 WATER DEPTH: · RI[B-Drill Deck: RKB-THF: RKB-SL: 116.00 RKB-ML: Production Casing: lt9901 133 lb/ft 6~950 [ 72 lb/ft N-80 BT&C l 2520 Tubing String: Short String 411 2,7241 26 lb/ft I J-55 [ AB-SrfL I 46601 Tubin 41 4.7 lb/ft J-SS ] CS-Hyd 9P ¢~ 6290 4.7 ,b/ft J-55 I t=UfiSrd/ 6290 4O8O 7040 7040 COMPLETION STRING 13 3/6" @ 0050' (Sqz'd) 3577 - 3587 (Sqz'd) 3604 - 3628 (sq~c0 Cook Inlet ~ands 3820 - 3880 3896 - 3960 4014 - 4048 4106 - 4111 4116 - 4124 4141 - 4166 4188 - 4238 4272 - 4282 4298 - 4316 4378 - 4390 4415 - 4440 Beluga Sands 4475 - 4482 4660 - 4668 4973 - 4978 4990 = 4995 5010 - 5025 5050 - 5057 5064 - 5070 5120 - 5135 5150 - 5157 5194 - 5204 5292 - 5305 5354 - 5372 5394 - 5414 5466-5480* 5482 - 5490 * 5514 - 5521 * 5532 - 5540 5564 - 5574 5576 - 5584 * 5592 - 5596 * 5668 - 5674 * 5757 - 5764 6088-6096 * 6130 - 6150 6180 - 6186 * 6441 - 6448 6540 - 6547 * 6641 - 6646 6718 - 6726 6748 - 6758 6790 - 6800 Short String Tubing 40.77 Elevation 40.77 3.15 43.92 318.41 362.33 8.03 370.36 11.36 381.72 FMC Tubing Hanger 7" 26 lb/It J-55 ST/L Tubing 7" 26 lb/It J-55 ST/L Tubing Pup Halliburton "CP-2" TRSSV with Top & Bottom 5.21 7" 26 lb/It J-55 ST/L Tubing Pup 386.93 2307.72 2694.65 15.00 2709.65 0.65 J-55 7" 26 lb/It J-55 ST/L Tubing Pup Twin Flow Head 6.240 6.240 5.900 6.240 6.240 6.240 6.270 10.750 2710.30 0.68 2710.98 5.37 271635 1.10 10 3/4" Coupling 10 3/4" Pup Joint Reducer 10 3/4" $CT X 9 5/8" $CT 10.000 2717.45 1.71 2719.16 4,22i 272338 0.88 2724.26 9 5/R' SCT X 7"SCT 6.220 "MSN" Seals (3) Muleshoe Guide End of A~sembly 6.220 6.220 2719.00 2724A7 Packer Assembly 5.47 Halliburton "YWD" Packer 0.29 Bottom Connector 1.910 1.995 1.995 2724.76 End of Assembly Lon 40.77 Elevation 40.77 44.20 281.54 293.28 2703.98 270430 3.4~ FMC Tubing Hanger 237.04 2 3/8" 4.7 Ib/ft J-55 CS 4.95 2 3/8" CS Hyd Flow Coupling 2.06 Otis 11XXO Type "XXO" WLRSV LN 4.73 3/8" CS Hyd Flow Coupling 2410.70 2 3/8" 4.7 Ib/ft J-55 CS 0.82 "No-Go" Locator 1.910 1.875 1.910 1.995 1.930 27083O 270934 4.0O "MSN" Seals (4) 0.54 Muleshoe Guide 1.930 1.930 1.875 270430 2705.05 Long String (Lower) 0.25 Head 4.60 Seal Bore Extension 1.875 1.995 2.500 0.65 Twin Flow Head 1.995 271030 15.25 2725.55 0.67, 272622 62.50 2788.72 1.19 2789.91 10O2.33 3792.24 198.61 399035 2.87 3993.72 478.02 4471.74 156.65 462839 19.94 464833 282.24 4930.57 387.43 5318.00 657.71 5975.71 2.86 5978.57 814.06 6792.63 1.38 2 3/8" 4.7 lb/fi J-55 EUE 8rd Tubing X-Over 2 3/8" BTC Box x 2 3/8" EUE 8rd Pin 2 3/8" 4.7 Ib/ft J-55 EUE 8rd Tubing 2 3/8" 4.7 lb/ft J-55 EUE 8rd Tubing Blast Joints 2 3/8" Otis 'XA' Sliding Sleeve Blast Joints 2 3/8" 2 3/8" 4.7 lb/ft J-55 EUE 8rd Tubing Blast Joints 2 3/8" 2 3/8" 4.7 lb/ft J-55 EUE 8rd Tubing Blast Joints 2 3/8" 2 3/8" 4.7 lb/ft J-55 EUE 8rd Tubing Otis 'XD' Sliding Sleeve 2 3/8" 4.7 lb/ft J-55 EUE 8rd Tubing Otis 2 3/8 ' 'XN" Nipple 6794.01 0.70 WL , Guide 6794.71 End of Tubing 1.995 1.995 1.995 1.995 1.910 1.875 1.910 1.995 1.910 1.995 1.910 1.995 1.875 1.995 1.790 1.980 FMC Tubing Hanger requires 7" BT&C Lifting Thread on SS and 2 3/8" BT&C on IS. _K_ EL~ E I v L I./ Welk ] Supv: S'm'ton North Cook Inlet Unit No. A-12 Wt: J-55 Field: Cook Inlet Unit Location: Lower Cook Alaska 8 rd + 2 3/8" Blast Joints 1994 PRD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator: PhilliPs Petroleum Co. Operation Shutdown__ Stimulate__ Pull Tubing ,~,X Alter Casing 3. Address: P.O. Box 1967 Houston, Texas 77478 4. Location of well at surface: 1,254' FNL & 927.8' FWL At top of productive interval: 1,254' FNL & 927.8' FWL At effective depth: 1,254' FNL & 927.8' FWL At total depth: (PBTD ~ 6,823' Same BHL) Plugging .__ Repair Well 5. Type of Well Development X Exploratory Stratigraphic Service Leg 1, Slot 3 PPCo. Tyonek Platform Sec 6-T11N-R9W Perforate x Other X (Squeeze Perfs) _ __ O. Datum elevation (DF or RKB) RKB 116 Feet 7. Unit or Property Name North Cook Inlet Unit 8. Well Number A-12 9. Permit Number / Approval Number 69-99 10. APl Number 50-883-20032 11. Field / Pool Cook Inlet / Beluga 12. Present well condition summary: Total Depth: measured true vertical Effective Depth: measured true vertical 14,910 feet Plugs (measured) PBTD 6,823' feet ORIGINAL 3,558 feet Junk (measured) 3,558 feet Casing: Structural Conductor Surface Intermediate Production Liner Length Size Cemented Measured Depth True Vertical Depth 30" Driven 381' 381' 20" 1,142 sx 1,990' 1,990' 13 3/8" 1,820 sx 6,950' Perforation Depth: measured 3,558' - 6,800' true vertical 3,558' - 6,800' Tubing (size, grade and measured depth) Packers and SSSV ( type and measured depth) R'ECEllf 'D JAN 2 7 1995 Alasl~ Oil & Gas Cons. C0mmissl.0n ' ~chor~ '- 7" 26 Ib/ft J-55 ST/L Tubing Surface to 2,724'. 2 3/8" 4.7 Ib/ft CS Hydril Tubing Surface to 0,795'. Halliburton "YWD" Permanent Packer @ 2,719' with Twin-FIo Seal Assy. Halliburton "CP-2" SSSV ~ 370.36' and Type "XXO" WLRSV ~ 286.49'. 13. Stimulation or cement squeeze summary: 1) 200 sx Class "G" squeezed into perfs 3,558' - 3,628'. 2) 200 sx Class "G" squeezed into perfs 3,558' - 3,628'. Intervals treated (measured): Stray Sands; Cook Inlet "A" and Cook Inlet "B" (3,558'-3,568'); (3,577'-3,587'); (3,604'-3,628') Treatment description including volumes used and final pressure: Squeezed twice to 2,000 psi each time. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 12500 3.84 40 937 01/17/94 Subsequent to operation 0 17000 0.3 150 1006 08/09/94 15. Attachments: 16. Status of Well Classification as: Copies of Logs and Surveys Run__ Daily Report of Well Operations X Oil Gas X 15. I hereby certify that the foregoing is true and correct to the best of my knowledge: Suspended~_ Service Form 10-404 Rev. 06/15/88 Principle Engineer Date 19-Jan-95 SUBMIT IN DUPLICATE DAILY OPERATIONS REPOR' North Cook Inlet Unit No. A-12 DATE 04103194 ~OM. 05:00 DATE 04104194 FROM 06:00 12:00 13:00 01:30 02:30 DATE 04105194 FROM 06:00 14:00 17:30 20:30 22:00 Page I 05:00 12:00 13:00 01:30 02:30 06:00 TO 14:00 17:30 20:30 REPORT 1 4.00 0.00 1.00 0.00 REPORT 2 6.00 0.00 1.00 12.50 0.00 1.00 0.00 3.50 0.00 REPORT 3 HR5 $.00 0.00 3.50 0.00 3.00 0.00 1.50 0.00 8.00 0.00 DAYS FROM SPUD 0 OP CODE CM P 6 CM P 6 P 6 P 6 P 6 CM P f CM P f P f DAYS FROM SPUD 0 OP CODE Clvl P f CM P f P f P f P f P f CM P 6 Clvl P 1 CM P 1 P 1 P 1 P 1 P 1 P 1 P 1 CM P g C'M P g CM P 1 CM P 1 P 1 P 1 P 1 P 1 DAYS FROM SPUD 0 OP CODE CM P · CM P · P · P · P · CM P 9 CM P 9 P 9 P 9 P 9 P 9 P 9 CM P 1 CM P 1 P 1 P 1 P 1 P 1 CM P 1 CM P 1 CM P f CM P f P f P f P f P f P f P f P f PHAS_ E 90WOVR 90WOVR 90WOVR 90WOVR PHASE 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR PHASE 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR DEPTH DAYCOST 6823.00 11~.00 CUM COST 119~.00 OPER SKID POOL RIG 1 429 OVER WELL # 'A" # 12. RIG UP SLICKLINE. INSTALL LUBRICATOR AND TEST SAME TO 2500 PSI. ** 4 HOURS THIS PERIOD DUE TO CHANGE TO DAYLIGHT SAVINGS TIME. RIH WITH SLICKLINE (TAPERED I 1/2' SINKERBAR WITH SPANG JARS). TOOI~ STOPPED AT 5756'. POOH WITH SLICKLINE. DEPTH DAYCOST 6823.00 40138.$0 CUM COST 52126.$0 OPER FINISH POOH wrrH SLICKLINE. PICK UP AMERADA GAUGES AND RUN TO 5734'. GRADIENT STOPS EACH 200' TO 4934'. 500' STOPS FROM 4934' TO 434'. FLUID LEVEL IN WELL AT 4-/- 3600'. ** MEASUREMENTS ARE USING PRESENT RKB TO THI: OF 56.75'. RIG DOWN SLICIO, INE EQUIPMENT. RIG UP MUD LINES TO ANNULUS AND TUBING. FILL ANNULUS WITtt 16 BBLS AND TEST ANNULUS TO 400 PSI. THE SHORT SIDE OF HANGER Lq OPEN TO THE ANNULUS. PUMP XANVIS PILLS DOWN TUBING AS FOLLOWS: 70 BBLS 2% KCL FOLLOWED BY 3 70 BBL PILLS AND I 50 BBL PILL. TUBING PRESSURED TO 200 PSI AND HELD WITH THE LAST PILL, ** TOTAL WATER PUMPED IN WELL s 330 BBLS. BLEED TUBING TO 0 PSI AND OBSERVE WELL FOR STATIC FLUID LEVEL. OK. CLOSE SSSV. ATTEMPT TO SET BPV. BPV WOULD NOT PASS X-OVER BETWEEN SWAB VALVE AND BLOCK ON TREE. REMOVE SAME. SET BPV. REMOVE TREE. PREPARE TO SET BLANKING PLUG IN SHORT SIDE AND NIPPLE UP RISERS, BOPS AND ALL RELATED EQUIPMENT. DEPTH DAYCOST 6823.00 42419,00 CUM COST 94545.$0 OPER SET BLANKING PLUG IN SHORT SIDE OF HANGER, NIPPLE UP RISER AND 10M BOP STACK ON 13 518" 3M WELLHEAD. CHANGE PIPE RAMS. HOOK UP ALL RELATED EQUIPMENT. REPLACE BPV WITH BLANKING PLUG IN LONG SIDE OF HANGER. TEST BOPS AND ALL RELATED EQUIPMENT TO PPCO AND AOGCC SPECIFICATIONS. TESTED ALL EQUIPMENT TO 300 PSI LOW AND 3000 PSI HIGH. ALL EQUIPMENT TESTED OK. PULL BLANKING PLUG FROM LONG SIDE OF HANGER. ** AOC-~C wrrNESS TO TESTING WAS WAIVED BY BOBBY FOSTER OF THE AOGCC. SCREW INTO HANGER WITH 4 1/2" TUBING. MAKE UP SLICIO, INE TOOLS (PULLING TOOL FOR SSSV AND SPANG JARS). MAKE UP LUBRICATOR AND WXRELINE BOPS. TEST TO 1000 PSI. RIH AND LATCH ON TO SSSV AND ATTEMPT TO PULL SAME. WIRE BROKE AT ROPE SOCKET. POOH WITH SLICKLINE. ATTEMPT TO PULL TUBING. +/- 2 1/2' OF MOVEMENT. TUBING IS STUCK. RIG UP SLICKLINE. TEST LUBRICATOR. RIH WITH FISHING TOOLS. TAG UP ON TOOLS AT 651'. FISH OUT TOOL STRING. MAKE UP TOOLS. RIH AND LATCH SSSV AT 661'. SSSV CAME LOOSE AND FELL DOWN HOLE WHILE WORKING TOOLS AND PARTED WIRE AT ROPE SOCKE"F. Rl]t WITH FISHING TOOLS AND POOH wrrH BOTH TOOL STRINGS. SSSV PULLING TOOL HAD SHEARED OFF. MAKE UP TOOLS AND RIH. ,jAN 2 7 199b Oil & Gas Cons. Commission ,Anchor[." DATE 04/O6/94 FROM 10:3o 11:30 12:30 14:00 21:30 DATE 04107194 FROM 06:00 09:30 12:00 14:00 17:00 22:30 00:30 02:00 03:00 04:30 DATE 04/08/94 FROM 06:00 08:30 10:30 11:00 12:30 13:00 15:00 20:00 21:30 22:00 Pago 2 TO 10:30 11:30 12:30 14:00 21:30 09:30 12:00 14:00 17:00 22:30 00:30 02:00 03:00 04:30 06:00 7_9.0 08:30 10:30 11:00 12:30 13:00 15:00 20:00 21:30 22:00 REPORT 4 HRS 4.50 0.00 1.00 0.00 1.00 1.50 0.00 7.50 0.00 8.50 0.00 REPORT $ HRS 3.50 0.00 2.50 2.00 0.00 3.00 5.50 0.00 2.00 0.00 1.50 1.00 1.50 1.50 0.00 REPORT 6 2.50 2.00 0.00 0.50 0.00 1.50 0.00 0.50 0.00 2.00 0.00 5.00 0.00 1.50 0.50 0.00 2.00 DA~S FROM SPUD 0 DP CODE CM CM CM CM CM CM CM WC WC CM CM DAYS PHASE, 90WOVR 90WOVR 90WOVR 90WOVR ~0WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR FROM SPUD 0 DP CODE CM P 2 ClVl P 2 P 2 P 2 P 2 P 2 P 2 CM P 6 CM P 2 CM P 2 CM P 4 CM P 1 CM P 1 CM P 4 CM P 4 P 4 P 4 P 4 CM P 4 RM U m CM P 1 ClVl P 4 CM P 4 PHAS~E 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR DAYS FROM SPUD 0 oP COD~. CM P 4 CM P 4 CM P 4 P 4 CM P 9 CM P 9 CM P 4 CM P 4 CM P 9 CM P 9 CM P · CM P · CM P 7 CM P 7 P 7 P 7 P 7 P 7 P 7 P 7 CM P * CM P 9 CM P 9 P 9 CM P 9 PHASE 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR DEPTH DAYCOST 6823.00 44982.00 CUM COST 139~2730 OPER ATTEMPT TO PULL SSSV WITH NO $UCCE~. SHEAR OFF AND POOH WITH SUCKLINE AND TOOL STRING. RIO DOWN SUCKLINE EQUIPMENT. RIO UP APRS WITH STRONGER LINE TO PULL SSSV WHILE WORKING TUBING STRING AND A'rTEMPTINO TO FREE SAME. WORKING TUBING STRING. TUBING CAME FREE. TOH WITH LANDING JOINTS. LAY DOWN HANGER. START LAYING DOWN 4 1/2" TUBING. LAY DOWN 6 YrS. WELL STARTED FLOWING UP ANNULUS. 35 BBLS TOTAL INFLUX WHEN WELL WAS SHUT IN. CIRCULATE THRU TUBING AND SSSV VALVE IN TUBING AND CIRCULATE OUT OAS. MAX~UM OBSERVED TUBING PRESSURE = 150 PSI. MAXIMUM CASINO PRESSURE 410 PSi. NO LOSSES TO HOLE WHILE CIRCULATING. LAYING DOWN 4 !/2' AND 3 1/2" TUBING AND BLAST JOINTS. FOUND SSSV IN TUBING AT JT # 26 (871 '). NO VISIBLE DAMAGE TO "S' SSSV NIPPLE OR 'DKS' SSSV. DEPTH DAYCOST 6823.00 53123.00 CUM COST 192650.50 OPER FINISH LAYING DOWN 3 1/2" TUBING AND 4 1/2' BLAST JOINTS. TUBING WAS FULL OF DRILLING MUD FROM 5750' TO 6550' AND COMPLETELY PLUGGED WITH SAND PROM 6550' TO 6785'. ** FOUND A 3' SINKER BAR WITH THE BOTTOM SUB OF OTIS SHIFHNG TOOL IN 'Q" NIPPLE AT BOTTOM OF STRING. RIG DOWN CASINO TOOLS AND CLEAN UP RIG FLOOR. PICK UP PACKER ~O ASSEMBLY (BAKER CJ TIH. TAG UP ON PACKER AT 3455'. MILLING ON BAKER 'KB' PERMANENT PACKER. NO FRooREss BEING ~DE AFTER Fn~T 12'. TOH WITH PACKER MILLING ASSEMBLY. THE BOWEN HYDRAULIC JARS WERE PARTED IN THE MIDDLE OF THE BODY (NOT AT THE WORKING MANDREL). THE WASHPIPE SHOE HAD NOT BEEN TURNING ON THE PACKER. LAY DOWN JARS. TIH WITH PACKER MILLING ASSEMBLY. REPAIR WASHED OUT VALVE ON MUDLINE. MILL UP BAKER "KB" PACKER. TOH wrI'H 'CJ' PACKER MILLING ASSEMBLY AND BAKER "DB" PACKER. DEPTH DAYCOST 6823.~ ~7~.~ CUM COST 259425.50 OPER FINISH POOH W/DB PACKER. L/D FISHING TOOLS. TIH W/HALLIBURTON EZSV & SET O 3443' (ABOVE PERFORATIONS). **NOTE HOLE STANDING FULL OF FLUID & STATIC PRIOR TO SETTING EZSV. PRESSURE TEST 13 3/8' CASING & ET.~V TO 1200/ FOR 30 MINUTES GOOD TEST. POOH 5 STDS. PU 13 3/8" STORM PACKER. TIH 3 STDS & SET O 278'. PRF. SSURE TEST BELOW KITS AND STORM VALVE FOR 30 MINUTES. TESTED OK. NIPPLE DOWN RISER, STACK O 13 318" WELLHEAD FLANGE. P/U RISER & BOP STACK. REMOVE OLD AUGNMENT PIN FOR DUAL HANGER (PIN HAD BEEN PREVIOUSLY DAMAGED - PARTIALLY SHEARED OFF). INSTALL NEW AUGNMENT PIN AND PACKING. INSTALL 2 NEW ANNULUS VALVES ON THE 13 3/8' 3M CASINO HEAD. INSTALL ALL NEW PACKING AND PACKING TIGHTENING NUTS ON THE HANGER HOLD DOWN SCREWS. REldOVE VR PLUG AND INSTALL VALVE ON 20' CASING HEAD. NIPPLE UP RISER AND BOP EQUIPMENT. PRESSURE TEST CASINO, NEW VALVES AND PACKING ON HOLD DOWN BOLTS TO 1200 PS! FOR 30 MINUTES. ~ OK. SET TEST PLUG. TEST BOPS AND ALL RELATED ' '22:00' 00:00 01:00 DATE 04109194 FROM 06:00 10:00 10:30 13:00 15:00 18:00 18:30 20:00 20:30 02:00 04:30 DATE 04110194 FROM 06:00 06:30 11:00 14:30 16:30 18:30 DATE 04111194 FROH 20:00 22:00 05:00 DATE 04/12/94 FROM 06:00 06:30 08:30 10:00 12:00 13:00 13:30 h~ 3 01:00 02:00 10:00 10:30 13:00 15:00 18:00 18:30 20.'O0 20:30 02:00 04:30 06:00 06:30 11:00 14:30 16:30 18:30 06:00 20:00 22:00 05:00 TO 06:30 08:30 10:00 12:00 13:00 13:30 1.5:00 1.00 0.00 1.00 0.00 2.00 2.00 REPORT 7 C P 9 90WOVR P 9 P 9 P 9 CM P 4 90WOVR ClVl P 4 90WOVR CM P 4 90WOVR CM P 4 90WOVR CM P 4 90WOVR CM P I 90WOVR DAYS FROM SPUD 0 REPORT 8 HRS OP COD ,E. PHASE 4.00 0.50 2.50 2.00 3.00 0.50 1.50 0.50 5.50 0.00 2.50 0.00 1.50 REPORT 9 CM P I 90WOVR CM P 5 90WOVR CM P I 90WOVR CM P 4 90WOVR CM P 5 90WOVR CM P 4 90WOVR CM P 5 90WOVR CM P 4 90WOVR CM P I 90WOVR CM P I 90WOVR P 1 CM P 4 90WOVR CM P 4 90WOVR P 4 CM P 4 90WOVR DAYS FROMSPUD 0 REPORT 10 HRS OP COD__ E PHASE 0.50 4.50 0.00 3.50 2.00 0.00 2.00 I 1.50 0.00 14.00 0.00 2.00 7.00 0.00 1.00 0.00 0.50 2.00 1.50 2.00 0.00 1.00 0.50 0.00 1.50 0.00 CM P 4 90WOVR ClVl P I 90WOVR CM P I 90WOVR P 1 CM P 5 90WOVR Cid P 4 90WOVR Cid P 4 90WOVR CM P 4 90WOVR CM P 5 90WOVR CM P 5 90WOVR DAYS FROM SPUD 0 OP CODE Cid P 5 CM P 5 P 5 P 5 P 5 P 5 P 5 CM P 4 CM P q CM P q P q P q P q CM P q CM P q PHASE.. 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR DAYS FROM SPUD 0 OP CODE PHASE p q 90WOVR p q 90WOVR p q 90WOVR p q 90WOVR p q 90WOVR P q p q 90WOVR p q 90WOVR p q 90WOVR p q 90WOVR p q 90WOVR P q EQUIPMENT TO PPC ID AOGCC SPECIFICATIONS. TESTED ALL EQUIPIVI~AqT TO 300 PSi LOW AND 3000 PSI HIGH. ALL TESTS OK. ** STATE wrrNES~ TO TESTING WAIVED BY DOUO AMOS OF THE AOC~'C. TIH. SCREW INTO STORM VALVE AND CHECK FOR PRESSURE. OK. UNSEAT RTTS. TOH. IJD RTTS AND STORM VALVE. LAY DOWN EZSV SEITING TOOL FROM BOTTOM. PAJ BIT AND IUNK BASKET AND TIH. DRILLING ON EZSV AT 3443'. DEPTH DAYCOST 6823.00 41764.00 OPER DRILLING ON EZSV O 3443'. CIRCULATE OUT GAS THRU OAS BUSTER. FINISH DRILLING EZSV. P/U DRILL PIPE AND TIH TO 5802'. CBU (GAS CUT MUD FROM BOTTOM). TRIP IN HOLE TO 6207'. CBU. (GAS CUT MUD FROM BOTTOM). TIH TO 6670'. TAG UP ON JUNK. DRILLING ON JUNK FROM PACKER AND EZSV AND REAMING OUT FILL FROM CASINO FROM 6670' TO 6688'. TOH. CLEAN/UNK BASKET. BlT HAD EXTENSIVE CUTTER DAMAGE (GRADE 8-4 ON TEETH AND CONE lOCKED UP. DEPTH DAYCOST 6823.00 40916.50 CUM COST 301189.~0 RECEIVED JAN 2 7 1995 Alaska Oil & Gas Cons. Commisslo Anchon CUM COST 34210~.00 OPER TIH W/NEW BIT TO 6688'. DRILLING ON JUNK FROM PACKER & ET~V AND REAMING OUT FIlL IN CASINO (6688' - 6823') PBTD. PUMP 2 HI-VIS SWEEPS TO CLEAN 13 3/8' CASINO. POOH & L/D JUNK BASKET AND PIC~ UP CASINO SCRAPER FOR 13 3/8' 72~ CASINO. T1H W/BlT AND SCRAPER TO 6823'. CIRCULATE AND SWEEP CASING. WAITING ON DELIVERY OF PERFORATING GUNS. DEPTH DAYCOST 6823.00 35529.~0 CUM COST 377635.~0 OPER CIRCULATE AND WAIT ON DELIVERY OF TUBING CONVEYED PERFORATING GUNS. ** HELD SAFETY MEETING WITH HALLIBURTON, POOL ARCTIC AND PHILLIPS DRILLING AND PRODUCTION PERSONEL ON THE MAKEUP, CARE AND HANDLING OF TUBING CONVEYED PERFORATING GUNS. TRIP OUT OF HOLE WITH BlT AND SCRAPER. PICK UP 7" TCP GUNS TO PERFORATE 33 BELUGA SAND INTERVALS. GUNS ARE LOADED AT 12 SPF WITH 36 GM RDX CHARGES PHASED AT 60 DEGRFA~. GROSS INTERVAL = 2325'. NET PLANNED PERFORATIONS = 302'. PICK UP CASED HOLE DST TOOLS AND 'RA" SUB ABOVE TCP GUNS. DEPTH DAYCOST 6823 .tN) S3817.00 CUM COST 4314SI.S0 FINISH PAJ & M/U CASED HOLE DST TOOLS. TIH W~TCP GUNS & CASED HOLE TEST TOOLS. R/U SCHLUMBERGER TO CORRELATE GUNS TO DEPTH. CORRELATE PERFORATING GUNS WITH CCIJGR LOG wrrH FDC/GR LOG DATED I 1-5--69. SET TOP SHOT AT 4475'. BOTTOM SHOT AT 6800'. PJU TEST TREE AND ~ ALL LINES TO 4000 PSI. SET RTTS PACKER AT 4361 '. R/U BJ NITROGEN. TEST ALL N2 LINES TO 4000 PSl. PRF..~URE UP ON DRILL PIPE W/N2 TO OPEN VENT AND AcrlVATE PERF GUNS. MAX PRESS~ WITH N2 WAS 3000 PSI. BLEED ~ STRING PRESS~ 13:30 15:00 15:30 04:00 DATE 04/13/94 FRoM 10:30 11:30 22:00 01:00 02:00 04:00 DATE 04/14/~4 FROM 06:00 12:30 13:00 14:30 17:30 18:00 20:00 21:00 22:30 23:30 04:30 05:00 15:00 15:30 04:00 06:00 09:00 10:30 11:30 22:00 01.'00 12:30 13:00 14:30 17:30 18:00 20:00 21.-00 22:30 23:30 04:30 0.00 0.50 0.00 12.50 0.00 2.00 0.00 REPORT 11 I-IRS 2.00 0.00 1.00 0.00 1.50 0.00 1.00 10.50 0.00 3.00 0.00 1.00 0.00 2.00 0.00 2.00 0.00 REPORT 12 6.50 0.00 0.50 0.00 1.50 3.00 0.00 0.50 2.00 0.00 1.00 0.00 1.50 0.00 1.00 0.00 2.50 0.00 2.50 0.00 0.50 1.00 DAYS P q P q P q P z P z P z P z P z P z P z P z P z P z P z P z P z P z P z P z P z P z FROM SPUD 0 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR OP CODE CM P CM P P P P P P P P P P P P P P P P P P P P P P P P P DAYS PHASE. 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR. 90WOVR FROM SPUD 0 oP COD,E. CM P 5 CM P 5 CM P g CM P ~ P 5 ~ P 5 ~ P 5 ~ P 5 ~ P g P g ~ P 4 c'~ P 5 PHASE 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR TO 600 PSI. GUNS FL ; AT 1459 HOURS. OPEN 3° BY-PASS AND OBSERVE WELL. WELL KICKED OFF AT 1530 HOURS WITH FLUID TO SURFACE. FLOWING WELL FOR CLEANUP. 0400 READINGS: TUBING PRESSURE "747 PSIO PRESENT GAS RATE = 20784.88 MCFD CHOKE SIZE = 64/64 (1") WATER RATE = 80.16 BPD SALINITY = 7500 PPM SAND - .7 · TOTAL WATER RECOVERED - 243.3 BBLS · * OPENED CHOKE TO 128/64 (2") AT 0407 HOURS FLOWING WELL FOR CLEANUP ON 2" CHOKE. 0600 READINGS: TUBING PRESSURE -' 673 PSIG PRESENT GAS RATE ~ 23089.2 MCFD CHOKE SIZE = 128/64 (2") WATER RATE ~ 80,16 BPD SALINITY - 75OO PPM SAND - .7~ TOTAL WATER RECOVERED ~ 251.71 BBLS DEPTH DAYCOST 6923.00 $22&~6.00 JAr{ ?_ 7 9:95 /~s~ ~J~ & Gas Cons, .... ~.~,. ~oliol~''~ CUM COST 954308.50 OPER FLOWING WELL FOR CLEANUP ON 2" CHOKE TUBING PRF.~ = 672 GAS = 23266.3 MCFD CHOKE = 128/64 (2") WATER RATE = 80.16 BPD SALINITY = 7500 PPM SAND = .6~ TOTAL WATER RECO~ = 258.79 SI WELL FOR PRESSURE BUILDUP. MAX PRESSURE 1265# FILL DRILLPIPE W/77 BBLS & CASING BELOW PACKI~ W/116 BBLS TOTAL 193 BBLS.PU ON DRILLPIPE & CLOSE HY-DRO SPRING TESTER VALVE, PRESSURE DRILLP1PE TO 3600~ & SHEAR CIRCULATING SUB. CBU FROM IPO SUB ~4242' RELEASE PACKER 04361' WELL DID NOT TAKE ANY FLUID. CIRCULATE WELL THRU GAS BUSTER. CONTINUE CIRC THROUGH CHOKE WHILE RAISING MW F/8.6 PPG TO 8.9 PI~. RD TEST HEAD & MU TIW W/PUMP IN SUB WIOLE OBSERVING ANNULUS. ANNULUS FLOWING. CIRC BU AFFER OBSERVING WELL. CIRCULATE THRU CHOKE & GAS BUSTER. SHUT IN & OBSERVED PRESSURE BUILD UP OF 70 PSI. DEPTH DAYCOST CUM COST 6823.00 46697.110 1001006.30 oP~=~_~ INCREASE FLUID WT 8.9 TO 9.4. CIRCULATE THRU CHOKE & GAS BUSTER. SD PUMP OPEN HYDRa. ~ 9.4/IN & OUT. OBSERVE WELL 30 MINUTF. S. SLIGHT FLOW. CBU W/9.4/FLUID. SD PUMP - SLIGHT FLOW. INCREASE FLUID WT. 9.4 TO 9.6# CIRCULATE AROUND. OBSERVE WELL. WELL W/SLIGHT FLOW. CONTINUE CIRCULATING THROUGH CHOKE W/180 PSi BACK PRESSURE. OBSERVE WELL STATIC. POOH 5 SI'DS. HOLE TOOK PROPER FILL. TIH 5 STDS. CBU AFl'ER 5 STD SHORT TRIP. NO GAS. OBSERVE WELL STATIC. POOH W/23 STANDS. PROPER FILL UP TILL LAST 5 STANDS, WHICH DIDN'T TAKE ANY FLUID. W/25 STANDS STILL IN HOLE, CIRCULATED UP GAS BUBBLE THROUGH CHOKE. W/WP-I-L LINED UP ON TRIP TANK, LUBRICATED IN FLUID AS GAS MIGRATED OUT OF GUNS. PACKER AT 2250' & END OF GUNS AT 4715'. POOH W/5 STANDS. CIRCULATE OUT GAS AS EREAKING OUT OF GUNS. Page 4 DATE 04115/94 FROM 06:00 12:30 19:30 21:30 22:00 00:30 01:00 DATE 04116/94 FROM 06:00 06:30 08:30 09:00 16:00 16:30 20:30 21:30 23:30 01:00 02:30 DATE 04117194 FROM 06:00 15:30 16:00 TO 12:30 19:30 21:30 22:00 00:30 01:00 06:30 08:30 09:00 16:00 16:30 20:30 21:30 23:30 01 :iX) 02:30 15:30 16:00 17:00 REPORT 13 6.50 0.00 7.00 2.00 0.00 0.50 0.00 2.50 0.00 0.50 2.00 1.00 2.00 0.00 REPORT 14 0.50 2.00 0.00 0.50 7.00 0.00 0.50 0.00 4.00 0.00 1.00 2.00 0.00 1.50 1.50 0.00 3.50 0.00 REI'ORT 15 HRS 9.50 0.00 0.50 0.00 1.00 0.00 DAYS FROM SPUD 0 OP CODE, CM P 4 CM P 4 CM P 2 CM P 4 CM P 4 CM P 1 CM P 1 CM P 5 CM P 5 CM P 5 CM P $ CM P c CM P 4 CM P 4 P 4 PHAS.E.. 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR DAYS FROM SPUD 0 OP CODE CM P 4 CM P 8 CM P 8 CM P 2 CM P q CM P q P q P q P q P q P q CM P 0 CM P 0 CM P q CM P q CM P ~ P 6 P 6 P 6 ~ P 6 P q P q CM P u P ~ P u P u P u P u PHASE 90WOVR 90WOVR 90WO'VR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 00WOVR DAYS FROM SPUD 0 OP CODE CM P u CM P u P u P u P u P u P u P u P u CM P t CM P t CM P 4 CM P 4 P 4 P 4 P 4 P 4 PHASE 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR DEPTH DAYCOST 6823.00 63576.89 CUM COST 1064583.19 POOH TO DST TOOLS & 7" PERFORATING GUNS CIRCULATING OUT GAS AS NECESSARY. LAYDOWN 2375' 7' PERFORATING GUNS. ALL FIRED. MU & RIH W/BIT & SCRAPER. HIT FILL AT 6746', 85' OFF BOTTOM. PU KELLY & DRILL FILL F/6762' TO 6782' AND BROKE OUT OF FILL. GAS BUBBLE AT SURFACE. PU & CIRCULATE OUT GAS THROUGH CHOKE AND W~IGHT UP LIGHT FLUID FROM BOTTOM. MIH FLUID WEIGHT WAS 9.0 PPG. CIRC & COND TO 9.6 PPG. FINISHED WASHING TO PB'TD AT 6823'. CIRC BU WHILE CONTINUING TO CONDITION MUD. SLIP & CUT DRILL LINE, 112'. POOH W/BIT & SCRAPER. NOTE: ALASKA OIL & GAS REP DOUG AMOS WAIVED wrrNESS OF BOP TEST FOR 04/14/94. DEPTH DAYCOST 6g~3.114} 72S49.44 CUM COST 1137132.63 OPER FINISH POOH W/BIT & SCRAPER WEEKLY BOP TEST PER PPCO SPECS. WITNESS WAIVED BY DOUG AMOS ALASKA OIL & OAS. BREAKDOWN HALLIBURTON DST TOOLS FROM TEST #1. RU SCHLUMBERGER W1RELXNE & LUBRICATOR. PERFORATE 50'COOK INLEt WI4 RUNS 3896' - 3900' 4' 12 SHOTS/bT 22 GM 3846' - 3866' 20' 12 SHOTS/FT 22 GM 3826' - 3846' 20' 12 SHCfI'S/Fr 22 GM 3820' - 3826' 6' 12 SHOTS/Fr 22 GM HOLE STATIC AFTER EACH PERFORATING RUN. SAFETY MEffFING W/CREWS & HALLmUTON PERFORATORS MU & ~ W/HRS PERFORATING GUNS & PACKER ASSEMBLY ON $" DP TO PACKER DEPTH OF 3750'. RU SCHLUMBERGER & RIH TO CORRELATE GUNS. RD. SPACE OUT F/CORRELATION & PU TEST TREE. RU LINES TO MANIFOLD & TEST EVER~G TO 4000 PSI. INDIVIDUALLY TESTED SAFETY SHUT DOWN VALVE & FUNCHON TESTED SAFETY SLEEVE. RU KI NITROGEN EQUIPMENT & TEST LINE TO 4000. HELD SAFETY MEETING. PRESSURED UP ON TUBING WITH NITROGEN TO FIRE GUNS. GUNS FIRED PERFORATING COOK INLET PERFS FROM 3866' TO 4440'. POV OPEN. OPENED WELL INITIALLY ON A 32/64' CHOKE W/ GAS TO SURFACE IN 12 MINUTES. CONTINUED OPENING UP CHOKE TO 3% RATE AT REPORT TIME: GAS -- 25,704 MSCFPD FTP -- 663 PSI CHOKE -- 192/64 0') WATER RATE = 120 BPD SALINITY -- 91,000 PPM SAND -- 1.6% TOTAL WATER RF~OVERED -- 35.83 BBLS DEPTH DAYCOST 6g23.00 298624.00 CUM COST 1435756.63 oP~, FLOW TEST COOK INLET SANDS 3820' - 4440' FINAL FLOW RATE AS FOLLOWS GAS = 27,979 MSCFPD FI? --- 654 CHOKE ~ 3' BYPASS WATER -- 40 BPD SALINITY = 74000 PPM SAND -- .6% SAND TOTAL WATER RECO~D -- 54.96 BBLS SI WELL FOR PRESSURE BUILDUP. MAX PRF,,~qSURE 1057# IN 15 MINUTES. PRESSUR~ SLOWLY FALLING. PU DRILLPIPE & CLOSE HYDROSPRINO TESTER VALVE. BLEED DP TO ZERO. REMOVE TEST TREE. At~sta 0il & Gas Cons. Commission 17:00 DATE 04118194 ~'ROM 06:00 07:30 09:00 10:00 11:30 12:30 14:00 15:30 16:00 18:00 01:30 05:00 DATE 04/19/94 ROM. 06:00 08:00 10:30 14:00 15:30 16:00 16:30 17:00 IS:00 19:30 20:30 22:00 01:30 03:30 05:00 Pag~ 6 TO 07:30 09:00 10:00 11:30 13:30 14:00 15:30 16:00 18:00 01:30 05:00 TO 05:00 10:30 14:00 15:30 16:00 16:30 17:00 18:00 19:30 20:30 22:00 01:30 03-.30 05:00 REPORT 16 REPORT 17 13.00 0.00 1.50 0.00 1.50 0.00 1.00 0.00 1.50 2.00 0.00 1.50 0.00 1.50 0.00 0,50 0.00 2.00 0.00 7.50 0.00 2.50 1.00 1.00 2.00 2.50 3.50 0.00 1.50 0.50 0.50 0.00 0.50 0.00 1.00 1.50 1.00 1.5O 0.00 3.50 0.00 0.50 1.50 1.50 1.00 Cs,~ P u Cid P u P u P u P u P u P u P u P u 90WOVR 90WOVR DAYS FROM SPUD 0 OP CODE PHASE CM P u 90WOVR CM P u 90WOVR P u P u P u P u P u P u CM P t 90WOVR CM P t 90WOVR P t CM P z 90WOVR CM P z 90WOVR P z P z P z CM P 5 90WOVR CM P 5 90WOVR CM P 5 90WOVR CM P 5 90WOVR CM P 5 90WOVR P 5 CM P 5 90WOVR CM P 5 90WOVR CM P 4 90WOVR CM P 4 90WOVR CM P 5 90WOVR CM P 5 90WOVR CM P 4 90WOVR CM P 4 90WOVR CM P 4 90WOVR CM P 5 90WOVR CM P 4 90WOVR DAYS FROM SPUD 0 OPEN WELL TO FLO\ ~ ABOVE ALL PERFORATED INTERVAI~. 0558' TO 4440'). RATE AT 0600: GAS 27156 MCFPD FPP 662 CHOKE 3' (196/64) WATER RATE -- 90 TO 120 BPD SALINITY 22500 PPM SAND ' .15~ TOTAL WATi~ RECOVERF. D ~ 147 BBLS. DEPTH DAYCOST 68~3.0O 37583.7~ OPER FLOW TESTING FINAL RATES AS FOLLOWS GAS 27,049 MCFPD FTP 663 CHOKE 3' (196/64) WATER RATE 80-120 BPD SALINITY 25000 PPM SAND .15% TOTAL WATER RECOVERED 155.83 BBLS Sl WELL FOR PRESSURE BUILDUP. MAX PRESSURE 1065# IN 27 MINUTES. PRESSURE DROP TO 10571 IN 10 MINIITES & STABILIZE. FILL DRILLPIPE W/61 BBLS & CASING BELOW PACKER W/45 BBLS TOTAL 106 BBLS. PU ON DRILLPIPE & CLOSE HYDRO SPRING TESTER VALVE. PRESSURE UP TO 3600~ & SHEAR lpG CIRCULATING SUB. CBU THRU CHOKE & GAS BUSTER RELEASE PACKER 03470' HOLE DH)NOT TAKE ANY FLUID. CBU THRU CHOKE & GAS BUSTER OPEN HYDRIL & CBU. PU DRILLPIPE 1 IT. PACKER DRAGGING. SET PACKER & RELEASE. ANNULUS TOOK 21 BBLS TO FILL CLOSE HYDRIL CIRCULATE THRU CHOKE & GAS BUSTER OPEN HYDRIL - TIH 12 STDS W/CIRCULATING SUB ~,i491' CLOSE HYDRIL CIRCULATE THRU CHOKE & GAS BUSTER POOH W/DST TOOLS & GUNS CIRCULATING OUT GAS AS NECCESSARY. RIH W/BIT & SCRAPER TO 4500'. CIRC BU FOR SAFETY. CONTINUED IN HOLE TO PBTD AT 6823'. NO FILL. DEPTH DAYCOST 6823.0O 42O6O.0O OP CODE PHASE OPEI~. CM P 5 90WOVR CM P 4 90WOVR CM P 4 90WOVR CM P 4 90WOVR CM P 4 90WOVR CM P 9 90WOVR CM P 9 90WOVR CM P 9 90WOVR CM P 9 90WOVR CM P 9 90WOVR P 9 P 9 P 9 P 9 P 9 CM P 5 90WOVR CM P 4 90WOVR CM P 4 90WOVR CM P 5 90WOVR CM P 5 90WOVR CM P j 90WOVR CM P j 90WOVR r j P j CM 'P 5 90WOVR CM P 4 90WOVR CM P 4 90WOVR CM P 5 90WOVR CBU POOH W/BlT & SCRAPER TIH & SET EZSV 03653' TO ISOLATE & SQUEEZE OFF SANDS "STRAY' "A" 'B' 3558' - 3628'. TIH W/RI'rS PACKER TO 3643' PRESSURE TEST EZ~V TO 2000~ OK. POOH W/RTrS TO 3490' PRESSURE TEST CASING TO SURFACE 2(XX)/OK. RU DOWELL PRES TEST LINES TO 5000~. ESTABLISH INJECTION RATES AS FOLLOWS .6 BPM 800~ 3 BBLS PUMPED 1.0 BPM 950~ 2 BBLS PUMPED 5 TOTAL 1.5 BPM 1100~ 2 BBLS PUMPED 7 TOTAL SD PUMPING PRESSURE SLOWLY DROPPING. BLEED PRESS~ & RD DOWELL RELEASE RI'rS. HOLE STATIC. CBU POOH W/PACKER & LD SAME. PU & RIH W/CMT DIVERTER TO EZSV AT 3653'. CIRC & COND FOR CEMENTING. HELD PRE JOB SAFETY MEEtiNG. RU DOWELL & TEST LINES. MIXED, PUMPED, & SET A BALANCED CEMENT PLUG F/EZSV AT 3653' UP TO 3376' W/200 SX OF CLASS G CEMENT AT 16 PIN3. POOH 5 STANDS & SQUEEZED STRAY A & B PERFS F/3555' TO 3628' W/17 BBLS OF CEMENT. MAX SQUEEZE PRESSURE" 2000 PSI AT .15 BPM. HELD PRESSURE FOR 30 MIN. PRESS STABILIZED AT 1960 BLED BACK APPROX 2 BBLS. REVERSE OUT DRILL PIPE. POOH W/DIVERTER TOOL. PU 12 1/4" M1LL & RIH TO 3400', PU KELLY & CIRCULATE WHILE WAITING ON CEMENT CUM COST 147334~.41 CUM COST 1515400.41 DATE 04/20/94 08:00 09:30 10:30 12:30 13:00 15:30 17:00 18:00 19:30 22:00 00:30 01:00 02:30 03:30 04:30 05:30 DATE 04/21/94 FROM 08:00 09:00 10:30 12:00 DATE 04/22/94 FROM 06:00 06:30 07:30 08:00 08:30 10:00 13:30 14:00 15:00 16:00 18:00 20:00 21:30 01:30 DATE 04/23/94 FROM 06:00 07:00 10:00 13:00 16:00 17:00 Page 7 08:00 09:30 10:30 12:30 13:00 15:30 17:00 18:00 19:30 22:00 00:30 01:00 02:30 03:30 04:30 05:30 09:00 10:30 12:00 06:00 06:30 07:30 08:00 08:30 10:00 13:30 14:00 15:00 16:00 18:00 20:00 21:30 01:30 07:00 10:00 13:00 16:00 17:00 06:00 REPORT 18 2.00 1.50 1.00 2.00 0.50 2.50 1.50 1.00 1.50 0.00 2.50 1.00 1.50 0.00 0.50 1.50 1.00 1.00 1.00 0.00 0.50 REPORT 19 2.00 0.00 1.00 1.50 1.50 18.00 REPORT 20 DAYS FROM SPUD 0 REPORT 21 OP CODE PHASE CM P 5 90WOVR CM P I 90WOVR Cid P 7 90WOVR CM P I 90WOVR CM P 5 90WOVR CM P I 90WOVR CM P 5 90WOVR CM P I 90WOVR CM P 5 90WOVR CM P 5 90WOVR CM P I 90WOVR CM P 5 90WOVR CM P 9 90WOVR CM P 9 90WOVR P 9 P 9 CM P 5 90WOVR CM P 4 90WOVR CM P 4 90WOVR CM P 5 90WOVR CM P i 90WOVR CM P . 90WOVR P J ~ p j 90WOVR DAYS FROM SPUD 0 DEPTH DAYCOST 6823.00 36664.40 OPER CIRCULATING WHILE WAITING ON CEMENT. DRILL CEMENT F/3485' TO 3520'. CHANGE SHAKER SCREENS. DRILLING F/3520' TO 3541 '. CIRCULATE BU. DRILL CEMENT F/3541' TO 3569'. CBU & TEST UPPER STRAY PERFS TO 2000. OK. DRILL CMT F/3569' TO 3590'. CBU & TEST MIDDLE A PERIS. PRESS BLED OFF Fl2000 PSI TO 600 FSi IN 15 MIN. DRILL F/3590' TO 3630'. CIRCULATE BU. ESTABLISHED INJ~ON RATE W/FRESH WATER. 1330 PSI AT 0.5 BPM W/4 BBLS. 1900 FSI AT 1.0 BPM W/3 BBLS. PERIS BROKe. 1100 FSI AT 1.0 BPM W/3 BBLS. CIRC BU. POOH W/MILL. RIH W/DIVERTER SUB TO TOC AT 3646' (DPM). CIRC BEFORE CEMENTING. TEST LINES. PUMP 20 FW, 41 CIVFF (200 SX) AT 16.0 PPG, 3 FW, & DISPLACE W/54.5 BBLS OF 9.6 PPG TO BALANCE, WHILE HOLDING BACK PRESS W/CHOKE. POOH W/7 STANDS & RU TO SQUEEZE. DEPTH DAYCOST 6823.00 3589750 OP CODE PHASE OPER CM U j 90WOVR CM U j 90WOVR uj CM U 5 90WOVR CM U 4 90WOVR CM U 4 90WOVR ClVl U I 90WOVR DAYS FROM SPUD 0 ~ OP CODE PHASE CM U J5 90WOVR CM U 90WOVR CM U 9 90WOVR CM U c 90WOVR CM U 4 90WOVR CM U 4 90WOVR CM U 9 90WOVR CM U 9 90WOVR CM U 5 90WOVR CM U 4 90WOVR CM U 4 90WOVR CM U j 90WOVR CM U j 90WOVR CM U 5 90WOVR CM U j 90WOVR CM U j 90WOVR DAYS FROM SPUD 0 OP CODE CM U 4 CM U 5 CM U 4 CM P 4 CM P 4 CM P 4 CM P 2 CM P 2 P 2 P 2 P 2 PHASE 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 0.50 1.00 0.50 0.50 1.50 3.50 0.50 1.00 1.00 2.00 2.00 1.50 2.50 1.50 4.5O 0.00 HRS CUM COST 1552064.gl 1.00 3.00 3.00 3.00 0.00 1.00 13.00 0.00 CUM COST 1587962.01 ATTEMPTING TO RF. SQUEEZE STRAY, A, & B SANDS. PRESSURED UP TO 2000 FSI INSTANTLY. APPROX 1/2 BBL SQUEEZED. REVERSE OUT DP. POOH W/DIVERTER SUB. RIH W/MILL & JUNK BASKET & TAG CMT AT 3381'. DRILLING CEMENT F/3381' TO 3641'. DEPTH DAYCOST CUM COST 6823.00 914~9.60 1679421.61 OPER DRLG CMT F/3562' TO 3649'. CBU. TEST STRAY, A, & B PERFS TO 2000 FSI. OK. SLIP & CUT 195' OF DRILL LINE. POOH W/MILL. MU & R1H W/R'FFS,HYDROSPRING, & IPO. RU & TEST LINES & SET PACKER AT 3448'. NEGATIVE ~ PERFS TO 500 PSI DIFF. OK. SHEAR lpG & REVERSE OUT. RELEASE PA~. POOH W/TEST ASSEMBLY. Rig W/MILL & JUNK BASKET. DP, LO CMT F/3649' TO EZSV AT 3669'. DRILLING ON EZSV. CIRC OUT GAS RELEASED F/UNDER EZSV. CONTINUE DRILLING ON EZSV. BROKE THROUGH AT REPORT TIME. DEPTH DAYCOST CUM COST 6823.00 35176.80 1714598.41 OPER RIH TO BTM AT 6831'(DPM), AFTER DRLO E7_~V. CIRC BU W/SOME GAS IN RETURNS. WELL STATIC. POOH & L/D 8' DC'S. PULL WEAR BUSHING. RIH W/OTIS YWD PRODUCTION PACKER ON DP & SET AT 2735' (DPM) 2719' (ORKB). POOH. PU & RIH W/COMPLETION ASSEMBLY. IN HOLE AT REPORT TIME IS 95 JTS OF 2 3/8' EUE 8RD, 4.7 # TBG, 109 BLAST JTS W/2 NIPPLES, 2 SLIDING SLEEVES, PUMP OUT PLUG, & HALLIBURTON TWIN FLOW CONVERSION ASSEMBLY. 4081'. RECEIVED Gas Cons. Commissi.on , DATE 04/24/94 ~OM 06:00 12:00 14:00 20:00 22:00 23:00 00:00 03:30 DATE 04/2~/94 06:00 12:00 18:00 01:30 03:30 05:30 DATE 04/26/94 FROM 06:00 11:30 15:30 17:30 12:00 14:00 20:00 22:00 03:30 TO 12:00 18:00 01:30 03:30 05:30 11:30 15:30 17:30 06:00 REPORT 22 6.00 0.00 2.00 0.00 6.00 0.00 2.00 1.00 0.00 1.00 3 30 2.50 0.00 REPORT 23 HRS 6.00 6.00 0.00 7.50 0.00 2.00 0.00 2.00 0.00 0.50 0.00 REPORT ~4 5.50 0.00 4.00 0.00 2.00 12.50 0.00 DAYS FROM SPUD 0 OP CODE. PHASE. CM P 2 90WOVR CM P 2 90WOVR CM P n 90WOVR CM P n 90WOVR C'M P 2 90WOVR CM P 2 90WOVR P 2 CM P 5 90WOVR CM P 9 90WOVR CM P 9 90WOVR P 9 CM P 6 90WOVR CM P · 90WOVR CM P · 90WOVR CM P · 90WOVR DAYS FROM SPUD 0 OP CODE CM P · CM P 6 CM P 6 CM P i CM P i P i P i P i CM P 7 CM P 7 P 7 P 7 P 7 CM P i CM P i P i P i CM P i CM P i PHAS~ 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR DAYS FROM SPUD 0 OP CODE CM P i CM P i P i P i CM P i CM P i P i CM P 6 CM P 6 CM P 6 P 6 P 6 P 6 P 6 PHASE 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR 90WOVR DEPTH DAYCOST 6823.00 49087.6O CUM COST 1763686.01 OPER PU & RIH WI64 frs OF 7", 26#, J55, STL TBO, W/HALLIBURTON 'CP-2' TRSSSV AT 372'. HANG OFF 7" TBO & TEST CONTROL LINE. TEST SEALS & BACK OUT LANDING fr. TESTS GOOD. PU & RIH W/$4 frs OF 2 3/8', 4.7#, 155, CS HYDRIL TEe, W/HALLIBURTON "XXO" WLRSSSV AT 286.49'. SPACE OUT & TEST CONTROL LINE. MU LANDING TIS & CIRC IN 2% KCL/OLYCOL MIX. DRAIN STACK, LAND 2 3/8' HANGER, PRESSURE TEST TUBING & SEALS TO 2900 PSI. PUMP OUT PLUG W/2950 PSI. CLOSED BOTH 5S5V'5. RG/DN. RD FLOOR & SET BPV IN 2 3/8' TBO HANGER. ND BOP'S. NU 13 5/$" 3,000 PSI FMC DUAL O' X 2 3/8') TREE. DEPTH DAYCOST 6~3.00 2427(~.00 CUM COST 2006451.01 OPER FINISH NU TREE & TEST TO 3000 PSI. RU IX)WELL TO 2 3/8' TBG & 7" TO WELL ~. TEST LINES. PRE JOB SAFETY MEETING. KICKED OFF WELL BY PUMPING NITROGEN DOWN 2 3/8' TBG & TAKING RETURNS FROM 7" TO WELL TESTERS. RECOVERED 369 BBLS OUT OF 704 BBL,. 335 BBLS TO GO. FINAL RATE OF 25813 MSCFPD W/13 BWPH, DOWN F/160 BWPH. SHUT IN & BLEED OFF. REPAIR ALIGNMENT PIN IN CSG HEAD. PRESSURE TEST SAME TO 1500 PSI. OK. SWITCHED F/7' TO 2 3/8' W/FLOW LINE & TESTED SAME WHILE REPAIBING CSG HEAD. SWITH~ DOWELL TO 7% SAFETY MEETING HELD PRIOR TO CHANGE. OPEN UP WELL TO WELL TESTERS & CONTINUE FLOW TO CLEAN UP. FLOWING UP 2 3/$' TBO. IN]EC'rlNO NITROGEN DOWN 7' TO UNLOAD WATER. NO FLOW PRESSURE STILL BUILDING ON 7% SHUT IN & SWITCHED BACK TO FLOWING OUT OF 7' & PUMPING NITROGEN DOWN 2 3/8' TI~3. DEPTH DAYCOST CUM COST 6823.00 2S9431J? 226b'gg2.38 CONTINUED FLOWING WELL UP 7" FOR CLEAN UP. WATER RATE FELL TO 1.66 BPH WI32527 MSCFFD. TOTAL WATER RECOVERED 502 BBL$. 900 PSi FTP ON A 2' CHOKE. SWITCHED FLOWLINE OVER TO 2 3/8' SIDE & OPEN WELL. SLIGitT BLOW ONLY. OBSERVED WELL. NO FLOW. RIG DOWN DOWELL & HALLIBURTON EQUIPMENT. OFFLOAD ALL NITROGEN,COIL TBG, TUBULARS, ETC. IN PREPARATION FOR SKIDDING WHILE RIGGINO DOWN UNIT CRANE. JOB COMPLETE: RELEASED WELL TO PRODUCWION AT 0600 ON 04/26/94. Page 8 'XN' PBTD 6823' 133/8' ~ 6950' 381 1990 TOO @ 1945 Otis Dual Packer @ 2700 Cook Inlet Sands 3558 - 3568 3577 - 3587 3604 - 3628 3820 - 3880 3896 - 396O 3982 -- 3994 4014 - 4048 4090 - 4098 4106 - 4111 4116 - 4124 4141 - 4166 4188 - 4238 4272 - 4282 4298 - 4316 4378 - 4390 4415 - 4440 Beluga Sands 4475 - 4482 4660 - 4668 4973 - 4978 4990 - 4995 5010 - 5025 5050 - 5057 5064 - 5070 5120 - 5135 5150 - 5157 5194 - 5204 5292 - 5305 5354 - 5372 5394 - 5414 5466 - 5480 * 5482 - 5490 * 5514 -5521 * 5532 - 5540 5564 - 5574 5576 - 5584 * 5592 - 5596 * 5668-5674 * 5757 - 5764 6068 - 6096 * 8130 - 6150 6180 - 6186 * 6330 - 6338 6540 - 6547 * 6641 - 6646 6718 - 6726 6748 - 6758 6790 - 6800 PROPOSED WELL COMPLETION DIAGRAM FMC OCT RKB-Drill Deck: FMC RKB-TI-tF: AnnuhmFluid: 9.0 ppg 2 % KCL Water TOC: 1945' from CBL dated : 116.00 WATER DEPTH: 120 RKB-ML: Production Casing: 20" 41 1,990 133 lb/ft 13 3/8" 41 6,950 72 lb/ft Tubing String: Short String 7" I 411 2,7ool 261b/it I 2 3/8" 4.7 lb/ft 2 3/8" 4.7 lb/ft N-80 J-55 t AB-ST/L I 46601 4080 J-55 6290 7040 J-55 EUE 8rd 6290 7040 PROPOSED PRODUCTION TUBING STRINGS 0.00 40.77 Elevation 40.77 300,00 340.77 352.77 2700.00 2700.00 2710.00 12.00 2347.23 0.00 Short String 7" 261b/ft J-55 AB-ST/L Tubing Otis 7" SCSSV (Type TRSV-CP2) 7" 26 lb/ft J-55 AB-ST/L Tubing Otis Dual Twin-Flow Seal Assembly Otis Permanent Packer (Type BDH) End of Tubing 8 0.00 40.77 Elevation 7 40.77 250.00 6.00 2403.23 6 290.77 5 296.77 4 2700.00 2700.00 10.00 2710.00 4099.00 6809.00 6809.00 1.00 6810.00 Long String 2 3/8" 4.7 lb/ft J-55 CS-Hyd sp. clearance Tubing Otis 2 3/8" SCSSV (Type XXO-FXE Ser 10-W) 2 3/8" 4.7 lb/ft J-55 CS-Hyd sp. clearance Tubing Otis Dual Twin-Flow Seal Assembly Otis Permanent Packer (Type BDH} 2 3/8" 4.7 lb/ft J-55 EUE 8rd Tubing with Blast Joints across perfs. Otis 2 3/8 .... XN" Nipple End of Tubing 6.151 5.963 6.151 8.000 6.151 1.995 0.750 1.995 2.555 1.995 1.995 1.875 PRODUCTION PERFORATIONS COOK INLET SAND 3558 - 3568 3577 - 3587 3804 - 3828 3820 - 3880 3896 - 3960 3982 - 3994 4014 - 4048 4090 - 4098 4106 - 4111 4116 - 4124 4141 - 4166 4188 - 4238 4272 - 4282 4298 - 4316 4378 - 4390 4415 - 4440 1 1994 Cons, Commi.~lo. rl Anchorago BELUGA SAND ( * New Perfs) 4660 - 4668 4973 - 4978 4990 - 4995 5010 - 5025 5050 - 5057 * 5064 - 5070 5120 - 5135 5150 - 5157 5194 - 5204 5292 - 5305 5354 - 5372 5394 - 5414 5431 - 5436 * 5466-5480 * 5482 - 5490 * 5514 - 5521 5532 - 5540 5564 - 5574 * 5576 - 5584 * 5592 - 5596 * 5668 - 5674 5757 - 5764 * 6068 - 6096 6130 - 6150 * 6180 - 6186 6441 - 6448 * 6540 - 6547 6641 - 6646 6718 - 6726 6748 - 6756 6790 - 6800 PBTD: 6,823' ] Supv: ] Tbg Wt: 7" 26 lb/ft 2 3/8" 4.7 lb/ft Well: North Cook Inlet Unit No. A-12 ] March 03 ~ 1994 Location: Lower Cook Alaska Field: Cook Inlet Unit PRD PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 NORTH AMERICA EXPLORATION AND PRODUCTION COMPANY March 8, 1994 BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING North Cook Inlet Unit "A"-12 Phillips Tyonek Platform "A" North Cook Inlet, Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: North Cook Inlet Unit A-12 Workover Program Attached are three copies of the Application for Sundry Approvals, form 10-403, and three copies of the tentative workover program for the workover of the A-12 well on the North Cook Inlet Unit. Included in the program are the BOP schematic and the well control policy for the workover. If you have any questions concerning this workover or need any additional information please contact Paul R. Dean at (713) 669-3502. CC: A. R. Lyons ~ M. L. Jones (r) ~.. R. Dean J.F. Mitchell Central files D. C. Gill Drilling and Production Engineering Manager RECEIVED MAR 1 1 1994 Alaska 0ii & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Operation shutdown __ Re-enter suspended well __ Plugging ~ Time extenmon __ Stimulate __ --~ ~,~I Pull tubing ..3L Variance __ Perforate x Other __ or K;''~'' °B)~ 5. Type of Well: 6. Datum elevation (DF Development ~ I~,(.B = 116 ' feet 1. Type of Request: Abandon ~ Suspend __ Alter casing ~ Repair well ~ Change approved program ~ 2. Name of Operator ! Phillips Petroleum Company '1 Exploratory__ 3. Address Stratigraphic __ 6330 W. I,o~p gr~.; g~ll~ir~: 'r~ 77401 . Service__ 4. Location of well at surface Platform "A" Leg 1, Slot 3 1254' FNL 927.8' FWL Sec 6- TllN- R10W RECEIVED At top of productive interval 1254' FNL 927.8 FWL At effective depth MAR 1 1 1994 Same At total depth Alaska 0il & Gas Cons. Commission (PBTD - 6823' Same) Anchorage 7. Unit or Property name North Cook Inlet Unit 8. Welt number A-12 9. Permit number 10. APl number 50-- 883-20032 11. Field/Pool Cook Inlet/Beluga 12. Present well condition summary Total depth: measured true vertical Effective depth' measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 14,910' feet Plugs(measured) PBTD 6,823' feet 3,558 ' feet Junk (measured) 3,5 5 8 ' feet Length Size Cemented Measured depth 340' 30" Driven 381 ' 20" 1142 sx 1,990' 13-3/8" 1820 sx 6,950' measured 3558' - 6800' ~ueve~icaldepth 381' 1,990' 6,950' true vertical 3558' - 6800' Tubing (size, grade, and measured depth) 4½" 12.6 l'5/ft. J-55 Sort to 3,428' 3~" ~ 9.2 16/ft. J-55 345:3'- 6729' Packers and SSSV (type and measured depth) Baker "KB" @ 3433' RKB. Otis Type "DKS" @269 RKB 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch 14. Estimated date for commencing operatiOn April 15, 1994 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sign ed Gas x Suspended __ 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 required 10- /,1' 0/.4 Approved Copy Original Signed By Returned Approved byorderoftheCommission David W. Johnston '~ '-~ "~ -/~ [[co~'¢~missioner IAppr°valN°'¢ Z//-~7 .. ! Date '-'~/,'~ ? ~;'V SUBMIT IN'I~RIPLICATE Form 10-403 Rev 06/15/88 March 7, 1994 Houston, Texas North Cook Inlet Unit "A"-12 (formerly North Cook Inlet "A" No. 15 North Cook Inlet Unit Tyonek County, Alaska Tentative Procedure ® · · · ® · Skid rig over No. 12 slot, kill well with 9.0 lb/gal KCl water / XanVis polymer. Fill tubing and annulus with KCl water. Bleed off pressures and monitor same. Close SSSV. InStall BPV, remove XMAS tree, NU and test 13 5/8" 10M BOP equipment. Utilize a 13 5/8" 3M x 13 5/8" 10M DSA. Test the BOP equipment as per the attached "Well Control" program. Rig up to pull tubing. Release Baker seal assembly from the Baker Model KB packer at 3,477'. Pull 4 1/2" and 3 1/2" tubings and SSSV. TIH with Baker packer milling assembly (Baker Model CJ or equivalent) on 5" drillpipe and drilling BHA. Mill over packer slips and recover Baker "KB" permanent packer. POOH. TIH with 12" bit and casing scraper for 13 3/8" 72 lb/ft casing. Clean out casing to PBTD of 6823'. Circulate hole clean and POOH. Make up and TIH with tubing conveyed perforating assembly to reperforate the existing Beluga Sands and add the new intervals as marked with "*" as follows: 4475' - 4482' 4660' - 4668' 4973' - 4978' 4990' - 4995' 5010' - 5025' 5050' - 5057' * 5064' - 5070' 5120' - 5135' 5150' - 5157' 5194' - 5204' 5292' - 5305' 5354' - 5372' 5394' - 5414' 5431' - 5436' * 5466' - 5480' * 5482' - 5490' * 5514' - 5521' 5532' - 5540' 5564' - 5574' * 5576' - 5584' * 5592' - 5596' * 5668' - 5674' 5757' - 5764' * 6088' - 6096' - * 6180' - 6186' 6330' - 6338' 6441' - 6448' MAR 1 1%994 * 6540' - 6547' 6 6 41 ' - 6 6 4 6 ' A%a. Sk~, Oil & Gas Cons. Commission Anchorage 6718' - 6726' 6748' - 6758' 6790' - 6800' · · · Use Gamma Ray log to correlate guns on depth. Set packer and pressure up on tubing with nitrogen to fire guns. Unload well and flow for initial clean-up. Kill well and POOH with perforating assembly. 10. Make up and TIH with tubing conveyed perforating assembly to reperforate the existing Cook Inlet Sands as follows: 3820' - 3880' 3896' - 3960' 3982' - 3994' 4014' - 4048' 4090' - 4098' 4106' - 4111' 4116' - 4124' 4140' - 4166' 4188' - 4238' 4272' - 4282' 4298' - 4316' 4378' - 4390' 4415' - 4440' 11. Use Gamma Ray log to correlate guns on depth. Set packer and pressure up on tubing with nitrogen to fire guns. 12. Unload well and flow for initial clean-up. 13. Kill well and POOH with perforating assembly. 14. TIH with Otis 13 3/8" x 7" x 2 3/8" dual production packer and set on wireline at 2,700'. 15. Make up and TIH with 2 3/8" tubing and blast joints per the attached schematic. 16. Make up Otis Dual Flow packer head seal assembly onto the 2 3/8" tubing. Make up 7" tubing to the top of the Dual Flow Seal Assembly. TIH with 7" tubing and SC~q~_SSV. Land seal assembly into dual packer and - test annulus. Make up and run 2 3/8" tubing and SCSSV. Sting into seal assembly of dual packer. Test annulus, then pull out of seal assembly and circulate packer fluid into annulus. Space out tubings. 17. 18. Close SCSSV's, install BPV's, ND BOP equipment and NU and test 13 5/8" x 7 1/16" x 2 3/8" dual tree. Remove BPV's. Use coiled tubing (if necessary) and nitrogen to lower fluid level and get well kicked off. Unload well and allow clean up through the production testing equipment. Release workover rig to next well. NOTE: BHP at 3450 TVD is approx 1400 psi (7.8 lb/gal equivalent), somewhat less than the 9.0 lb/gal equivalent which will be used to kill the well during the recompletion phase. Anchomge SECTION WELL CONTROL PROCEDURES This well is a category 3 well, as defined in Phillips Completion Workover and Well Control Policy. As such two barriers must be in place during nipple up and nipple down operations. For all other operations two barriers, e.g. the BOP's, fluid column, etc. must be in place in order to conduct simultaneous operations. The BOP equipment is 10000 psi WP Class 4 as per Phillips Well Control manual. The bottom set of rams should be 5" pipe rams, the middle set will be blind rams and the top set should be variable rams. Although the BOP is rated to 10000 psi, the riser and the wellhead are rated to 5000 psi. The BOP and choke manifold should be stump tested to 3000 psi. The BOP should be tested to 3000 psi upon nipple up and to 1500 psi on a weekly basis. The Alaska Oil and Gas Conservation Commission (AOGCC) should be notified prior to conducting BOP tests. The notification to AOGCC should be made early enough for them to witness the test if they desire. The maximum surface pressure for the well is 1071 psi. This pressure was obtained during the welltest of February 10, 1994. The well can be killed and stablility maintained with 9.0 lb/gal fluid. Well control drills are to be conducted with each crew as per Phillips well control manual. Drills should be reported on the IADC daily drilling report and on Phillips Daily Drilling Report. This well produces from a series of very permeable sands. A small decrease in pressure at the perforations can result in very large flowrates. It is vital that good well Control practices be followed during the course of this workover. Trip speed while POOH should be kept relatively slow to avoid any tendency to swab. Before any trip is made swab and surge calculations should be made based on the properties of the fluid in the hole. DO NOT exceed the running speed determined by the calculations. A detailed trip book comparing measured fill up requirements to the calculated requirements should be maintained for each trip. The cause for any discrepency between the actual and required fill up volume must be determined before continuing with the trip. ~AINTAINING CONTROL OF THE WELL IS OF THE UPMOST IMPORTANCE, TRIP SPEED IS SECONDARY. The perforated intervals are below the Baker "KB" permanent packer, therefore, 39 different intervals between 3518' and 6800' TVD are effectively commingled at the Present time and cannot be isolated. Ail of the zones presently perforated in this well can be killed with water. As a precautionary measure, a line should be ran from the annulus valves on the tubing head to supply workover fluid, drillwater, or seawater. This line can be used to supply workover fluid as discussed above or as a last resort can be used to kill the well with drillwater or seawater. Pumping drillwater or seawater through the annulus valves should be considered only in an emergency situation as these fluids could result in formation damage. RECEIVED MAR ] I 1994 Oil & Gas Cons. Cemmission Anchorage RISER AND BOP ARRANGEMENT I I I I 6M ANNULAR PREVENTER KILI. I.I NE HI~R ~II~LVE GATE ~I~LVE 1OM VARIABLE BORE PIPE RAM8 1OM BLIND RAM8 DRILLING 8POOL GATE ~ALYE OHOKE LINE H(~R ~LYE 6' 1OM PIPE RAM8 13 6/8' 1OM RISER ADAPTER 11' 1OM X 13 6/8' 1OM TUBING HEAD 18 6/8' 6M X 11' 1OM RECEIVED Gas Cons. Commission ~chorage. PB'~D 682~ 13 3/8" @ 6950' 381 1990 TOC @ 1945 Baker packer Cook Inlet Sands 3558 - 3568 3577 - 3587 5896 - 3960 3982 - 3994 4014 - 4048 4106-4111 4116-4124 4141 - 4166 4188 - 4238 4272-4282 4298 - 4316 4378 - 4390 4415 - 4440 Beluga Sands 4475 - 4482 4660 - 4668 4973 - 4978 4990 - 4995 5010 - 5025 5050 - 5057 5120- 5135 5150 - 5157 5194 - 5204 5292 - 5305 5354 - 5372 5394 - 5414 5431 - 5436 5532 - 5540 5564 - 5574 5757 - 5754 6130 - 6150 6441 - 6448 6641 - 6646 6718 - 6726 6748 - 6758 6790- 6800 ~ EXISTING WELL COMPLETIOI"~AGRAM .~V(Make,Typ%OD) FMC OCT '~KB-l~rili Deck: Tbg. H~r.(Make,Tvpe) FMC RKB-THF: 40.7~ AnnulUs Fluid: RKB-SL: 116.00 TOC: 1945' from CBL dated 05/03~0 WATER DEPTH: 120 RKB-ML: Production Casing: 30" 41 381 20" 41 1,990 133 lb/ft 13 3/8" 41 6~950 72 Ib/ft N-80 Fubing Strfi 4 1/2" 41 3,454 12.6 lb/ft J-55 BT&C 5690 4330 415 3 1/2" 3,474 6,785 9.2 lb/ft J-55 BT&C 4980 3270 366 I I I PRODUCTION TUBING STRING 19 18 16 15 14 0.00 40.77 Elevation 13 40.77 198.79 4 1/2" 12.6 lb/ft J-55 BT&C Tubing 3.958 4.500 12 239.56 3.68 Otis 4 1/2" SCSSV (Type DKS) 4.750 11 243.24 3206.00 4 1/2" 12.6 lb/It J-55 BT&C Tubing 3.958 4.500 10 3449.24 5.17 Otis 41/2" "XO" Sliding Sleeve 9 3454.41 2.18 4 1/2" BT&C x 3 1/2" BT&C X-Over 2.992 5.000 8i 3456.59 21.17 Baker Seal Assembly 7 3477.76 4.00 Otis 3 1/2" "XO" Sliding Sleeve 6 3481.76 998.24 3 1/2" 9.2 lb/ft J-55 BT&C Tubing 2.992 3.500 5 4480.00 4.21 Otis 3 1/2" "XO" Sliding Sleeve 4 4484.21 1115.91 3 1/2" 9.2 lb/ft J-55 BT&C Tubing 2.992 3.500 3 5600.12 4.00 Otis 3 1/2" "XO" Sliding Sleeve 2 5604.12 1179.88 3 1/2" 9.2 lb/ft J-55 BT&C Tubing 2.992 3.500 1 6784.00 1.82 Otis 3 1/2" "Q" Nipple 6785.82 PRODUCTION PERFORATION INTERVALS COOK INLET SAHD BELUGA SAND 3577 - 3587 4973 - 4978 3604 - 3628 4990 - 4995 382O - 388O 5010 - 5025 3896 - 3960 5350 - 5057 3982 - 3994 5120 - 5135 4014 - 4048 5150 - 5157 4090 -4098 5194 - 5204 4106-4111 5292- 5305 4116-4124 ~D 5354-5372 4188 - 4238 5431 - 5436 4272-4282 5532- 5540 4298 - 4316 5564 - 5574 4378-43 ] ] 994 5757-5754 4415 - 4440 6130 - 6150 ~ta~Y,a Utt& Gas GonS. commission Anchorage ~1 - ~8 8718 - 8728 8748 - 6758 6790 - 6800 PBTD: 6,823' ] Sup~. I Tbg Wu 12.60 ib/ft N-80 8 rd Well: North Cook Inlet Unit No. A-12 I March 03 ~ 1994 l~0~aticg: Lower Cook Inlet. Alaska Field: Cgok Inlet Unit PRD Form 1'0-403 REV. 1-10~73 i i%~};~:~ ~i.~i i~:~ ~i ~!.~%~i ii '~ ~$ubmit"lntentions" in Triplicate it!}-,*'~'" L!:~ ~;'j' ,,~ ,,j .L~ ~~ ~,~:~& "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION COMMITTEE SUNDRY NGT~ESA,ND RETORTS ON WELLS (Do not use~t'~f~r~i'~f~/lJ~oposals to d rill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) o,- !--I -GAS r-~ WELL'' WELL OT.ER 2. NAME OF OPERATOR Phillips Petroleum Compan~ 3. ADDRESS OF OPERATOR P. O. Drawer 66 - Kenai, Alaska 99611 4. LOCATION OF WELL At surface Leg 1 Slot ~, FNL & FW%, Sec 6-11N-9W-SM BML 1225' FSL & FWL, Sec 6-11N 9W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RKB ll6' above MLLW or 1GO' above MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-283-20032 6. LEASE DESIGNATION AND SERIAL NO. ADL 17589 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME ~CIU 9. WELL NO. A-12 10. FIELD AND POOL, OR WILDCAT North Cook Inlet 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) See Item ~ BHL 12. PERMIT NO. 69-99 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL SUBSEQUENT REPORT OF: (Other) MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING ABANDON* SHOOTING OR ACIDIZlNG ABANDONMENT* CHANGE PLANS (Other) Plan Change (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. lc. SEE ATTACHED "DATLY REPORT DETATLED" --'j--3--'Ot~o E" ]_-_--_. CONFER.. FILE: /./ · __ 16. I hereby certify t~at the fore~i~rgSs~rue and correct s,GN/E 'tXl. ~;. ~orter TITLE S~. Petro]e~]m Rng~ · (Th~s space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side · . i.'=':i{~,. ~., .- .. ,.;,,t.::;;,, 'LEASE - NCIU WELL NO A-12" SHEET NO. .1 ;: ' ' ':~: " ' " . '- . '.':. " : TOTAL .... '~. ' ,~, .':... ",' "':..: ...'DA~ ' !' ' '.' DEPTH . , --'. ~.,,~ '~'. , '~-. . . : . -.:~ -...../~ - · . ":~. ..'. A~""13~ 1975"."~Present 0~eration:-"Spotting ri~ over A-i2 - . ,,~: ' ,' .. .... ':.~ened sleeve at 6871'~d ~toad tbg, close sleeve at 6871 flow tbg aro~d bottom ,,~.k :-.~ ' ': Alet well ciCa. up, Install ball valve ~d p~ we'ii.on test at 10:00 p.m., ~,~ell ~.~.,~:..:,,.,..,,~..-"' ~ '~ '.:,~,, floWingi ~ stea~.off,ofatwellt0 ~cfgd,A_9 test well 6 hrs. after cica'up. Rele~ed rig. ,?.::~,V. 'R~g.-_o~ skid to Well A-12, leg one, Now sli~ng over ho'!e. - ~ . . .', ... . . Aug:,' 14,": i9t5 _. Present '0Per:ation: Killing well ':':.: :- -"-Finished mo~ng'rig from A-9-leg 2, t°'.A-12 leg 1'. Rig'up..., Otis attempt to' ~,? ':'C' ::retrieVe )l'PlUg from .long string in ~.. Sleeve ,at 4441, tbg was plugged with s and. :.. ( S~'°rtOpen~ XOs t~'leeve'~ at ~4°53~in ~d circulate water with ll.3'mud down long'string, up '{ "::~ ~"~]'"::':"J ~}/-, ':-{: . .gs'~.':':: 'ReCOvered much s~d. oti'.~ opened~,xO sleeve at 3473' ab°Ye TZW '~.~'~:~:' .:~.. :~:: .:~::j,. ,. :::, ,{:~ '-.-Note:. Could ,-not get' do~ long string below. 4400 tbg s~'ded up inside' ~O.,above kill.well. :B~er'packer: at 4445, bottom of tbg 6807, TD 13 3/8 6820. - OPeration· ~xing mud .circulate to kill well NUBOP.~, 'Test .BOP/Riser. to 1600; ~.Xing mud g..hole; .P~eparato~ .'tO~.pulling Short strin~ .of tbg. . , . tg~'10ng:' S~in'g: bfly-tnb tbg,,on to ~sh~d.[m~xz})~' mud, P 'string:of..' ~bg ~.d 'derrick, ------- g svrtng.,i?'TbgL~as stuck, pull 't47,000 °n'tbg, ~" ~d strain relieved t© ~Bo,O00..: ~Or~ gBg O~g~of.h°Se ~:~ ,r 240 ~., ~g c~e free; Now 'pulling ~d St~ding back ~bg. ' ' )75 g s~d"out:of 13 3/8 casing. Rig.up Otis' to pull plug out of ~ sleeve ~' 'at"4441, no plug. Fo~d plug in XO..Sleeve at ~-467. Pressure up ab O ~e plug Aug ~.. 20, 19 1975 :: 'Present ~Operation: Running',ProduCtion String,. ~" Finish"cleaning Out casing to16820. Circulate.to 'clean. hole,., 3 1/2 tbg and 3 1/2 drill pipe, start, running Beluga. production string. COOH,': lay down resent',:'0peratiBn: Displacing mud 'in hole':with water , $i~?..~}::[:((.i. / .Finished. rUnning production string. ND BOP. Hook up Christmas tree and test to '~3000, pSi',~Otis opened 4 1/2".XASm~ at 34'73'in long string ~isptaced mud' out of i:~'.:/?~ [c~Sing above top packer up long string with sea water. Displace sea water packer with. 40 bbls. fresh water flwd bY 280 bbls ,of 10 wa~er. .. !ati.0n:'~', Preparing to pull.UT to'.cheCk coll · "displaCing~ ~ ,~ ~casing'with 10.5 PH FW" ?Pumped. in 12'bbI:~ ~iog-d'~'Otio on UT and set plug ~. "©" n.fa-~ie .... _ , :.--..~:. - '~ ;' conett, latch sea- on pUmPed out,, of-,se t: Pkr- '.ray in at 1600 psi.; Unable to ~et pkr~ :?~'Displ'aeed water in hole : 2 ' , · ~. ',...' ~,",:... DAILY REPORT DETAILED LEASE NCIU : TOTAL DATE~ DEPTH NATURE OF WORK 'PERFORMED WELL NO. A-12 . SHEET NO. 2 Aug. 21, 1975 Present oPeration: ND BOP and Riser Install BPV's in U and LT. ND Tree. NU 12" 900 series BOP's tested BOP's to Aug 1500 psi. Pick up UT. Had 31,000 lbs tbg weight. Coltett was not latched. Removed tbg hanger. Made up landing JT. Slack off UT and latched collett with 15,000 lbs weight down. PRessure up UT to-2300 psi to set TIW pkr. Close hydril. Pressure. UT to 2500 psi held for 25 min. Released tbg pressure. Pulled o.~t of collet with 12,000 lbs above weight spaced out. Add .91 ft to string. Ram_ ba].l valve dummy. Tested 1/4" control lines to 5000 psi. Landed tbg with 15,000 lbs weight on pkr'. Attempted to test UT. after landing with 2500 psi, the tbg would ~ :":':..:'~ pump out' of 'collett. Tested UT to 2125 psi with 13 3/8 annulus open to :!'!-["~'. ·':11 atmOsPhere, i Held test for 40 min. ReleaSed pressure installed BPV in .short strin~ 75.:::'present Operation: Preparing to displace 'mud.out of tbg and between the two pkrs ·/':t: !, before bringing in well. "~' !'~i. iND. BOp,S., 'NU Christmas tree. Test~d~tree to 3000 psi, tested TSIf, control-lines i~i~{0 40001'pSi',' tested 13 3/8" casing annulus, and.pkr.to 1500 psi for 30 min. O.K. Pulled plug from. Q nipple opened XA sleeve mon LTat. 3473'. Displaced 13 3/8" : annulus with' sea water. Spotted 10.',~ in followed with 1'6 bbls · ,.closed .XASteeve "at 3473, ~'st;'in~;' O'.~t: sl~.e-¢e at 4)~4i":,~d up sh'o'rt '~' string p o.,f tbg with-:.,lt~]:0....lb of :gas pressure. Had .:~'communicatinns between. 13 .3/. ..:'smd~is~ort' s~ri'~gJ:~"TeSting~ indicated that co_].. !i~ ~'let h'ad. Snapped out of.TIW, dual .P'~i~Le~.. Displace water..out of tbg ~,nd csg with '~Ud.'..,''Set'~piug; °n ~Q niPple 'on s'~"~!' :string. ', Installed"BPV~ ND Christmas tree. ~.' "Finish NU" tested BOP 1500 pickup 12,060 lbs above' weight' to pull loose. th UT, ,~ 25, 1975 WIH with: UT. spaced out with. 24,U00 lbs on pkr, Tested up collett 2500 .lbs for 30 i!~~!~d~sOpP ~nc~tdamllu~d u~r ~g ~% hTesStt~n~s3 3o/f8~ ~s.g and pkr to 1500 for " ot b ' Now preparing to bring ..- AUg~t'"26':/~975 Present Operation: Preparing to re-wOrk Well ' ~-~ ' )sed sleeve. 3473,. opened sleeve/4441, started displacing mud between TIW pkr ?'[-. ~: '": at:'.3509 and. Baker pkr at 4445 down long string, up short, Pressure equalized ~. :'~" : 6n' long string and csg. Finished diSPlacing mUd~ bleed PressUre off of long and short string. Pressure remained, on csg. (Pkr leaking from bottom) Went' ' "','~,'¥, -through series of tests, decided Pkr was leaking. il)preSent Operation: POOH with UT '- ~ CirCulate out water in both strings of tbg. DisPlace 10'5 PH water out of' 3/8"' annulus with 11,3 mud. Installed BPV in both strings. ND tree, NU BOP'S. ~ .:Tested BOP/BBer.'to 1425 psi.. ~Pulled UT collett out'of TIW pkr.With 24,000 lb. "Reversed out. UT. DALLY REPORT DETAILED LEASE ~CIU WELL NO. A-12 SHEET NO. TOTAL _DAT,~ DEPTH NATURE OF WORK PERFORMED Aug. 28, 1975 Present Operation: Waiting on packer repair POOH with short string. Pulled long string with max tbg. weight of 72,000#. Layed down TIW dual pkr. Sent to shop for repair. Set Otis plug in bottom of 3 1/2" tbg. section of long string. Tested to ]_,900 lbs. 30 min., O.IC. . Aug. 29~ 1975 Present Operation: Preparing to POOH with LT to check Baker pkr seal assembly ... Redress TIM dual Pkr. GIH with LT hydrotesting 4 1/2" tbg, checked 0.~.. Stung thru Baker pkr at 4450 RKB and lowered LT till seal loCator 4' above pkr. - Pressure up LT to 550 psi. Had communication in annulus. LoWered LT till :~., locator contacted pkr and pressured up again with same results. ii'Aug. 30, 1975 Present ~Operation: POOH LD UT Pulled to Baker seal assembly; redressed same. Found originaI seals in good ~i'""'i'"'"[ ' condition. Changed out XA sliding sleeve at 4)~41. Replaced one 20' blast joint at 3583. Went in hole with TIW dual pkr. Tested 4 1/2 tbg to 2,O00 psi, '~'~.., ',,...'i!]',.;..spaced out long.,:string pressured up below Bsker pkr at 4450'., Circ indicated . commUnications behind casing from below Baker pkr and above it, Made up TiW - - i ~.~ ",.?collett.seal'on 4" tbg. GIH. ",-i'.Water and..~isplaced sea water ~v~h 10~5 PH;water. Clos s~ieeve at . ?3442, open'XA sleeve at '44 . '.'~,--: :" ::,:.,.'.:' ',ept, i,: 1~75;~': ~:~iSplac~d.'d0Wn" long'..'st~Li~'g ,. :~t s~ ]g w,i~h.:fresh ~'at.e:~ WiH.set~:.p].z~:g~in ~'~'.,::: .~' ......... .. ,: .:. 'Q'nipple' located.:,in sho~: ; :pres ~d..UP:.:,UT'~d ./ ..., '. ,[ .,:.::, ' ? ::'/.'~[ . .'.', .' side one':h°ur. Pressure h~'ld O.K, :':.N° :presSure b:~id'up,.°U':"long:'string"0r short '~ . '~ .".' ~.~'~tring. :.. Tes~e~'below pkr.'.:P~ping sliding : . , ~:'~"44~1 had inst~t Commi~%ions aromdTIW dual Pkr. .' ~ressured.'~ sho'rt~' ....; :'string again .attempting to:.set pkr. Failed, Decided qo. complete we!l. as a '[..~: ~ ..'~[ .' .single with'CoOk Inlet ~d Beluga.co~ingled in the Wel~ bore similar to- other ' · .: NCIUwells. Displaced water with 11.3 mud to kilt well. DALLY REPORT DE ILE · . LEASE NCIU WELL NO. A-12 SHEET NO. TOTAL D, ATE DEPTH NATURE OF WORK PERFORMED Sept. 3, 1975' Present Operation: GIH with pkr. milling and retrieving tool. Change 4 1/2 rams in BOP. Release pkr. with 5700# puli over ~,~ei~at of stri~. Open 4 1/2" XO sleeve at 3473'. C&CM and build volume. Pull tbg. and pkr. out of hole. Pick up DP and make up pkr. milling and retrieving tools. Sept. 4, 1975 Present Operation: GIH W/DP to C&CM : WIH W/pkr. milling and retrieving tool and released Baker model KB pkr. at RKB tried to go down M/pkr. but got only 5'. Pulled up eight stds (.4~0') and pkr. hung. Reles~sed and mille~ pkr. loose again. Pulled u~ 4 more .~t.~"~ (240') and pkr. hung again'. Releaoed and milled again. COOH W/pkr. Had jar it 16ose several times in process. ....Sept, 5, 1975 .Present Operation: GIH W/3 1/2" tbg. :. WIH to:6700'. Hit barite fill-up. ~ash to bo~%om at 6820, C&CM 9 hrs. C00H LDDP. Ran gauge ring and junk basket on electric to 3540'. Set 13 3/8" ,,,.~. Baker mOdel KB permanent pkr. at 3477' on electric line. ".Sept. 6, 1975 WIH W/tbg. ~Located~aker pkr. at 3433', spaced out and set tbg. at 6729'. . Drop Q plug:in tbg. ~and attempt to .pressure test tbg, 'Could not. WIH ~'/'wl. :?" ' ""."i'::,':F0~'d SS a6 3453' open. Close. PU %bg. to 2000 ps~. for 30 min. O.K. PU " . ~ ~,. ~nul~ to 1500 psi. for 20. min. ~ :Sept..: 7, 1975 Pull:..Q plug and pressure under Baker Pkr,.to 500 psi.'ifor 30 min. O.K. Install BPV. ND BOP'NU tree. Test tree 3000 psi. 0.I~. WIH W/wL. Open XO SS at .. 3428'. Run dummy ball valve.: Test 1/4"'..TSV C°ntrol line t°.4000 psi. :.Dis01ace mud in-annulus with SW. Displace SW with '10'.5 pH PW. Pump in 12.' drum~ of methanol .in annulus. Sept.' 8, 1975 'Close X0 Ss at 3428'. Open x0 ss at 3453'. Flow 4 hours thru 1./4" choke cleaning well up thru SS at 3453'. Close this sleeve, Open X0 SS at .4467 R[(B. Would not unload. Left this sleeve open and re-open sS at 3453'.. Unload heavy mud. Close SS at 3453' foUr separete times in attempt'~to get. well to unload -- - ithru SS at 4467'~ Now on fifth try. Sept. 9, 1975 ' PreSent Operation: Attempting to clean up well, .. Alternating closing and opening of SS at 3453' and 4467' in attempt to get well ..' to unload. Finally quit lifting any mud from 3453. Run WL to end of tbg. Tbg .. . open. Close both sleeves, pump 110 BFW down tbg. putting 30 B~ Outside. Open SS at 3453'~ Unload EST 75 BW and 20 BM and quit lifting any liquid. Close SS at 3453' and open SS at 4467'. Flowed a pencil size stream of mud for one hr. and died. Open SS at 3453' and recover EST 50 BM. Close SS at 3453'. Open SS at 4467'.~ Had not started to unload at report time. Plan to re-open SS at. 31-t-57' ~ after. 2 hrs. and kick out liquid buildup above it. When this technique fai].s to recover liquid, will pump more water in. ' DAILY 'REPORT DETAILED ' LEASE NCIU WELL NO. A-12 SHEET NO. TOTAL DATE DEPTH NATURI~ OF WORK PERFORMED Sept. 10, 1975 Present Operation: Fishing for WL Tools and Wire Alternated closing and opening SS at 3453' and 4467'. At one o'clock p.m. got well to come around thru SS at 4467' and started alternating closing and opening SS at 4467' and 5600'. Did this 4 times recovering 20-25 B~.iI each time. Blow line cut out down stream of choke. Repair. WL failed whi_~.e attempting to open SS at 4467', losing about 4000' of .092 OD WL plus sic'eve shifting tool jars and sinker bar in tbg. Rig up WL fishing tools. Sept. 11, 1975 Present Operation: Attempting to clean up well Fished and recovered all wireline and wireline tools. Ran WL to bottom, tbg clear to TD. Resume alternately opening and closing SS at 4467' and 5600'. Recover 15-20 BM each time. Now on 4th try to get it to blow around 5600' level. Sept. 12, 1975 Present Operation: Fishing for 200' WL -';' Alternated closing and opening SS at 5600' and 4467' recovering 15-20 BM each , time for 3 times. At 6 p.m. WIH W/WL to open SS at 4467'. Upon .openings · tools were blown up hole approximately 800', before lodging in 3 1/2 tbg. with ~)~"~ :' shifting tOols located above part of WL. ~IH ,W/WL 'fishing tools and z ~ecov,TM~.~ .i~..,:~.,:.,..: shifting tools, leaving about 200' of wire in tbg. GIH with spear to recover ~- WL at 8 a.m. i':i". Se , t975 Recovered WL fish. Resume closing and opening of SS at. 4467' and 5600'. Did this 3 times, recover 10-15 BM each time. At 8 p.m.'well started unloading from 5600' SS. UnlOaded about 30-40 BM. WIll to close SS at 5600'. Hit mud restrictiOn at 3370'. WIH and removed r'estriction. Closed SS at 5600~ to get mud forced up tbg from end of tbg at 6729' t~o above 5600' level. Open SS at 5600' and recover 15-20 BM. Do this twice. Sept."i4, 1975 Had blow line cut 'out. SI well while unloading from 5600', repair line. Resume closing and opening SS at 5600'. While GIH W/WL to open SS at 5600'~ inadvertently opened SS at 3453' Tools were blown up hole -to 2600' where they hung up. Started fishing for WL tools and wire line at 3_300 hrs. Sept.. 15,'1975' Present Operation: Fishing for WL and tools. Have recovered about 2L~00' of WL. Still have to recover about t000' of wire and tools. Sept. 16, 1975 Present Operation: W0 braided line unit to fish with. Fished and recover about 250' of .092 slick line. Also recovered sinker bars that were above SS shi~fting tool. While fishing for WL, left spear in hole. Have latched into fish two times but can't move W/.092 slick line. Have to shear off each time~ Braided line unit will be required to pull harder, Form' 911 1-69 Printed in U.S.A. DAILY REPORT DETAILED LEASE NCIU TOTAL DAT[[ DEPTH NATURE OF WORK PERFORMED WELL NO. A-L2 SHEET NO. 6 ,~ Sept. 17, 1975 Present. Operation: GIH W/Braided Line to fish. .- Mobilize~braided line unit and transport to platform. Rig up WL znait an('~ ~"~ : -power pack. GIH W/braided line. Latch on to fish at 3500'. Pulled up /~:,~" " to 3400'. :Fishing tool Sheared off in safety joint. C00H and re-pin ?,'.~?ili:, - safety j Oint for more pull. pt.i 18, 1975'~. PreSent 0perati.on: Preparing to set collar stop above fish. _ :~'~', Fished and recovere~ spear at 3400'. RecOvered all the wireline. Fished. i~ : for shifting tool W/3' of~sinker bar below at 6727'. COOH w.it~ fishing ~neck of shifting tool, leaving bottom half of shifting tool plus sinker bar /'.'still' in hole at Q nipple at 6727'. Will set Coll. ar stop above to prevent " Possible uphole~movement of shifting tool s~nd then open SS at 3453', 4467t~ '~.]),':~i'~ .'~d 5600' "and install special ported side~ door chokes in SS and put on t~rod.ucti "Sept. 19, 1975 Present Operation: Attempting to set TSV at 259' RKB. Check closure status of SS at 5~00, 4467, and 3453'.' Set "~" plug in SS -, · at 3453. Bled tbg. down and change trim in master gate which started leaking. ..... Remove.X plug from SS at 3453'. Set-collar stop in 3 1/2 tbg. collar at 6700' Open SS at 5600, 4467~ and 3453'. Set SDC W/ 25/64 'side ports'~.in F~i~ i:~:i.i at 5600. Set SDC W/ 24/64 side ports in SS at 4467. Set SDC W/ 23/6h. side !,.'.': :.ports at 3453.. Have tried 3 times .to set TSV in nipple. :,-'?.Sept. 20, 1975 Ran'SS shifting tool thru TSV nipple several times to dislodge suspected dt'ied -'"'~':: mud that was keeping TSV from seating. Ran TSV- set'-at 259 RKB. Close valve after 'seating. Bled off tbg. pressure 500 psi. Watch 30 min.. - no buildUp. TSV holding 0 K. Open TSV and turn thru overboard line at 1100 hrs. '~". ... Flow overboard ! 1/2 hrs. No significant amount of liquid lifted. SI " well 30 min. Start flow test at ]300 hrs. Sept. 22, 1975 · Rig released 0700 hrs. 9/23/75. Start rig down and demobilization. Sept. 23, t975~ Rigging down and demobilizing Brinkerhoff rig No. 31. Form 911 (. 1.69 Printed in U.S.A. .i .,~ ~":-.~ .,,'+ , ~'" '"'*' ....... ' '~;' ' ." ': ' '. ',' '.t..' :ii: ..... ~i', '~','.t(~', ,,. '..[.,,:.~.~,,,..:..,, ..'"~.'. OIL AND GAS CONSERVATION C~M~ITTEE ~0-283-2003.2 SUNDRY NOTICES AND~~~ ~LS ~17589 (Do not use this form for pr~~~r to deepen Use "APPliCATION FOR PERMIT~" for such proposals.) WEL~ OTHER Z NAME OF OPERATOR 8. UNIT, FARMOR LEASE NAME Phillips Petrole~ Comply NCIU 3. ADDRESS OF OPERATOR 9. WELL NO. P. 0. Drawer 66 - Kensi ~ 99611 A-~ 4. LOCATION OF WELL · 10. FIELD AND POOL, ORWILDC~ ~ At surface No~h Cook Inlet Leg i Slot 3~ ~.5~I ~L ~ 928! ~L= Sec 6-1~-gw-s~ 11. SEC.,T.,R.,M.,(BOTTOMHOL~ECTIV~)_.~ BHL 1225' ~L & 1293 ~L, Sec 6-1~ 9W, SM See Item ~ BHL 13. ELEVATIONS (Show whetherDF, RT, GR, etc.) 12. pERMIT NO. ~ ll6' above ~W or l~' above ~L 69-99 CheCk Appropriate Box To Indicate Nature of Notice, Re )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Clean out and Perf (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 1§. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of . starting any proposed work. SEE ATTACHED "DAILY REPOE~ DETAILED" 16. I hereby certifyJ, l~at the/f~eg~olng~s true and correct ~~ N. F,. Porter Sr. Petroleum Engineer TITLE DATE lO/l/?5 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE See Instructions On Reverse Side DATE DAILY REPORT DETAILED LEASE NCIU WELL NO. A-12 SHEET NO. TOTAL DATE DEPTH NATURI[ OF WORK PERFORMED Aug. 13, 1975 Present Operation: Spotting rig over A-12 Opened sleeve at 6871 and unload tbg, close sleeve at 6871 flow tbg around bottom let well clean up. Install ball valve and put well on test at 10:00 p.m. , well flowing steady at 20 mmcfgd, test well 6 hrs. after clean up. Released rig. Rig down off of well A-9, skid to Well A-12, leg one. Now sliding over ho'le. Aug. 14, 1975 Present Operation: Killing well Finished moving rig from A-9 leg 2, to A-12 leg 1. Rig up. Otis attempt to retrieve plug from long string in XA sleeve at 4441, tbg was plugged with sand. Open XO g!eeYe at 4053 and circulate water with 11.3 mud down long string, up shoat strings. Recovered much sand. Otis opened X0 sleeve at 3473 above TIW packer and pumped 11.3 lb mud down long string and up 13 3/8 annulus to kill well. Note: Could not get down long string below 4400 tbg sanded up inside above Baker packer at 4445, bottom of tbg 6807 TD 13 3/8 6820. Aug. 15, 1975 Present Operation: Mixing mud Finish circulate to kill well NU BOP. Test BOP/Riser to 1600. Mixing mud volume and filling hole. Preparatory to pulling short string of tbg. 8/16/75 Pulling long string of tbg. Finished mixing mud, pull short string of tbg and sand in derrick, latch on to lnng string. Tbg w~as stuck, pull 147,000 on tbg. Moved 4" and strain relieved to 130,000. Work tbg out of hole in this manner for 240 ft. Tbg came free. Now pulling and standing back tbg. Aug. 17, 1975 Cleaning sand out of 13 3/8" casing. Rig up Otis to pull plug out of XA sleeve at 4441, no plug. Found plug in XO sleeve at -467. Pressure up above plug and retrieve same. Rest of tbg plugged with sand and pockets of trapped gas. Finished pulling tbg With 3 1/2 drill pipe on top. Sting through Baker packer at 4426, finish GIH. Hit fill up in 13 3/8 casing at 6491 wash to 6805 by reversing. Aug. 18, 1975 Present Operation: Running production string Finish cleaning out casing to 6820. Circulate to clean hole. COOH, lay down 3 1/2 tbg and 3 1/2 drill pipe, start running Beluga production string. Aug. 19, 1975 Present Operatinn: Displacing mud in hole with water Finished running production string. ND BOP. Hook up Christmas tree and test to 3000 psi. Otis opened 4 1/2" XASS at 3473 in long string displaced mud out of casing above top packer up long string with sea water. Displace sea water above top packer with 40 bbls. fresh water flwd by 280 bbls of 10.5 PH fresh water. Aug. 20, 1975 Present Operation: Preparing to pull UT to check collett and respace Finished displacing casing with 10.5 PH FW. Pumped in 12 bbls o~ethanol into casing. Rigged up Otis on UT and set plug in "Q" nipple. Attenrpted to set TIW hydraulic packer. Collett latch seal on UT pumped out of seat in pkr at 1800 psi. Collett will stay in at 1600 psi. Unable to set pkr. Displaced water in hole with 11.3 PPg mud. Form 911 1~69 Printed in U.S.A. DALLY REPORT DETAILED LEASE NCIU WELL NO. A-12 SHEET NO. TOTAL DATE DEPTH NATURE OF WORK PERFORMED Aug. 21, 1975 Present Operation: ND BOP and Riser Install BPV's in U and LT. ND Tree. NU 12" 900 series BOP's tested BOP's to 1500 psi. Pick up UT. Had 31,000 lbs tbg weight. Collett was not latched. Removed tbg hanger. Made up landing JT. Slack off UT and latched collett with 15,000 lbs weight down. PRessure up UT to 2300 psi to set TIW pkr. Close hydril. Pressure UT to 2500 psi held for 25 min. Released tbg pressure. Pulled o~t of collet with 12,000 lbs above weight spaced out. Add .91 ft to string. Ran ball valve dummy. Tested 1/4" control lines to 5000 psi. Landed tbg with 15,000 lbs weight on pkr. Attempted to test UT after landing with 2500 psi, the tbg would pump out of collett. Tested UT to 2125 psi with 13 3/8 annulus open to atmosphere. Held test for 40 min. Released pressure installed BPV in short string. August 22, 75 Present Operation: Preparing to displace mud out of tbg and between the two pkrs before bringing in well. ND BOP's. NU Christmas tree. Tested tree to 3000 psi, tested TSV control lines to 4000 psi, tested 13 3/8" casing annulus and pkr to 1500 psi for 30 min. O.K. Pulled plug from Q nipple opened XA sleeve on LT at 3473'. Displaced 13 3/8" annulus with sea water. Spotted 10.5 PH FW in annulus, followed with 16 bbls alcohol, closed XA sleeve at 3473. $. 8/23/75 Displaced 11.3 mud' pumping FW down long string. Out sleeve at 4441 and up short string. Started displacing water out of tbg with 1300 lb of gas pressure. Had communications between 13 3/8" casing and short string. Testing indicated that col- let had snapped out of TIW dual packer. Displace water out of tbg and csg with mud. Set plug on Q nipple on short string. Installed BPV, ND Christmas tree. Aug. 24, 1975 Finish NU tested BOP 1500 pickup UT, took 12,000 lbs above weight' to pull loose. C00H with UT. Aug. 25, 1975 WIH with UT spaced out with 24,000 lbs on pkr. Tested up collett 2500 lbs for 30 min. ND BOP installed Christmas tree. Tested 13 3/8" csg and pkr to 1500 for 30 min. displaced mud out of csg and both strings of tbg. Now preparing to bring in well. August 26, 1975 Present Operation: Preparing to re-work well Closed sleeve 3473, opened sleeve 4441, started displacing mud between TIW pkr at 3509 and Baker pkr at 4445 down long string, up short. Pressure equalized on long string and csg. Finished displacing mud, bleed pressure off of long and short string. Pressure remained on csg. (Pkr leaking from bottom) Went through series of tests, decided ~kr was leaking. Aug. 27, 1975 Present Operation: POOH with UT Circulate out water in both strings of tbg. Displace 10.5 PH water out of 13 3/8" annulus with 11.3 mud. Installed BPV in both strings. ND tree, NU BOP's. y~..... Tested BOP/t~er to 1425 psi. Pulled UT collett out of TIW pkr with 24,000 lb. Reversed out UT. Form 911 1-69 Printed in U.S.A. LEASE NCIU DAILY REPORT DETAILED WELL NO. A-12 SHEET NO. TOTAL DATE DEPTH NATURE OF WORK PERFORMED Aug. 28, 1975 Present Operation: Waiting on packer repair POOH with short string. Pulled long string with max tbg. weight of 72,000#. Layed down TIW dual pkr. Sent to shop for repair. Set Otis plug in bottom of 3 1/2" tbg. section of long string. Tested to 1,900 lbs. 30 min., O.K. Aug. 29~ 1975 Present Operation: Preparing to POOH with LT to check Baker pkr seal assembly Redress TIW dual pkr. GIH with LT hydrotesting 4 1/2" tbg, checked O.K. Stung thru Baker pkr at 4450 RK]B and lowered LT till seal locator 4' above pkr. Pressure up LT to 550 psi. Had communication in annulus. Lowered LT till locator contacted pkr and pressured up again with same results. . Aug. 30, 1975 Present Operation: POOH LD UT Pulled to Baker seal assembly; redressed same. Found original seals in good condition. Changed out XA sliding sleeve at 4441. Replaced one 20' blast joint at 3583. Went in hole with TIW dual pkr. Tested 4 1/2 tbg to 2,000 psi, spaced out long string pressured up below Baker pkr at 4450'. Circ indicated communications behind casing from below Baker pkr and above it. Made up TIW collett seal on 4" tbg. GIH. 8/31/75 Went in hole with short string, tested 4 1/2 section 2000 psi. spaced out W/20,000# on collett landed UT. ND BOP's, NU Christamas Tree. Tested tree to 30'00. psi. and 1/4" lines to 4000 psi. WIH with Otis tools, pull dummy ball valve to ~o~[3' 'ft..'open' KO' S]li~Ling sleeve at. 3442'., displaced 11.3 mud with sea. water and displaced sea water with 10.5 pH water. Closed XO sliding sleeve at 3442, open XA sleeve at 4441. Sept. 1, 1975 Displaced down long string out short string with fresh water. WIH set plug in Q nipple located in short string. Pressured up UT and sheared hydraulic piston in TIW dual pkr with 700 psi, after waiting 2 hrs. for temperature to stabilize down hole. Pressured up UT to 3000 psi. Collett jumped out. Repressured short string tbg. to max 3300 psi. while holding 1500 psi. on 13 3/8 annulus. Released pressure on short string. Held pressure on 13 3/8 casing and pkr from top- side one~ hour. Pressure held O.K. No pressure build-up on long sLring or short string. Tested below pkr. pumping down long string through sliding sleeve at 4441 had instant communications around TIW dual pkr. Pressured up short string again attempting to set pkr. Failed. Decided to complete well as a single with Cook Inlet and Beluga commingled in the well bore similar to other NCIU wells. Displaced water with 11.3 mud to kill well. Sept. 2, 1975 Finished displacing water with 11-. 3 mud. Installed BPV ND Christmas tree. NU BOP's and tested to 1500 psi. Pulled short string out of collett with 24,000 lb. above weight of pipe and C00H. Form 911 1-69 Printed in U.S.A. DAILY REPORT DETAILED LEASE NCIU WELL NO. A-12 SHEET NO. 5 TOTAL DATE DEPTH NATURE OF WORK PERFORMED Sept. 10, 1975 Present Operation: Fishing for WL Tools and Wire Alternated closing and opening SS at 3453' and 4467'. At one o'clock p.m. got well to come around thru SS at 4467' and started alternating closing and opening SS at 4467' and 5600'. Did this 4 times recovering 20-25 BM each time. Blow line cut out down stream of choke. Repair. WL failed while attempting to open SS at 4467', losing about 4000' of .092 OD WL plus sleeve shifting tool jars and sinker bar in tbg. Rig up WL fishing tools. Sept. 11, 1975 Present Operation: Attempting to clean up well Fished and recovered all wireline and wireline tools. Ran WL to bottom, 6bg clear tS TD. Resume alternately opening and closing SS at 4467' and 5600'. Recover 15-20 BM each time. Now on 4th try to get it to blow around at 5600' level. Sept. 12, 1975 Present Operation: Fishing for 200' WL Alternated closing and opening SS at 5600' and 4467' recovering 15-20 BM each time for 3 times. At 6 p.m. WIH W/WL to open SS at 4467'. Upon opening, tools were blown up hole approximately 800', before lodging in 3 1/2 tbg. with shifting tools located above part of WL. WIH W/WL fishing tools and recover shifting tools, leaving about 200' of wire in tbg. GIH with spear to recover WL at 8 a.m. Sept. 13, 1975 Recovered WL fish. Resume closing and opening of SS at 4467' and 5600'. Did this 3 times, recover 10-15 BM each time. At 8 p.m. well started unloading from 5600' SS. Unloaded about 30-40 BM. WIH to close SS at 5600'. Hit mud restriction at 3370'. WIH and removed restriction. Closed SS at 5600' to get mud forced up tbg from end of tbg at 6729' to above 5600' level. Open SS at 5600' and recover 15-20 BM. Do this twice. Sept. 14, 1975 Had blow line cut out. SI well while unloading from 5600', r'epair line. Resume closing and opening SS at 5600'. While GIH W/WL to open SS at 5600', inadvertently opened SS at 3453'. Tools were blown up hole to 2600', where they hung up. Started fishing for WL tools and wire line at 1300 hrs. Sept. 15, 1975 Present Operation: Fishing for WL and tools. Have recovered about 2400' of WL. Still have to recover about 1000' of wire and tools. Sept. 16, 1975 Present Operation: WO braided line unit to fish with. Fished and recover about 250' of .092 slick line. Also recovered sinker bars that were above SS shifting tool. While fishing for WL, left spear in hole. Have latched into fish two times but can't move W/.092 slick line. Have to shear off each time. Braided line unit will be required to pull harder. Form 911 1-69 Printed in U.S.A. -. DAILY REPORT DETAILED LEASE NCIU WELL NO. A-12 SHEET NO. TOTAL DATI~ DEPTH NATURE OF WORK PERFORMED Sept. 17, 1975 Present Operation: GIH W/Braided Line to fish. Mobilize braided line unit and transport to platform. Rig up WL unit snd power pack. GIH W/braided line. Latch on to fish at 3500'. Pulled up to 3400'. Fishing tool sheared off in safety joint. C00H and re-pin safety joint for more pull. Sept. 18, 1975 Present Operation: Preparing to set collar stop above fish. Fished and recovered spear at 3400'. Recovered all the wireline. Fished for shifting tool W./3' of sinker bar below at 6727'. C00H with fishing neck of .shifting tool, leaving bottom half of shifting tool plus sinker bar still in hole at Q nipple at 6727'. Will set collar stop above to prevent possible uphole movement of shifting tool and then open SS at 3453', 4467', and 5600' and install special ported side door chokes in SS and put on production. Sept. 19, 1975 Present Operation: Attempting to set TSV at 259' RKB. Check closure status of SS at 5600, 4467, and 3453'. Set "X" plug in SS at 3453. Bled tbg. down and change trim in master gate which started leaking. Remove X plug from SS at 3453'. Set collar stop in 3 1/2 tbg. collar at 6700' Open SS at 5600, 4467, and 3453'. Set SDC W/ 25/64 side ports in SS at 5650. Set SDC W/ 24/64 side ports in SS at 4467. Set SDC W/ 23/64 side ports at 3453. Have tried 3 times to set TSV in nipple. Sept. 20, 1975 Ran SS shifting tool thru TSV nipple several times to dislodge suspected dried mud that was keeping TSV from seating. Ran TSV- set at 259 RKB. Close valve after seating. Bled off tbg. pressure 500 psi. Watch 30 min. - no buildup. TSV holding O.K. Open TSV and turn thru overboard line at 1100 hrs. Flow overboard 1 1/2 hrs. No significant amount of liquid lifted. SI well 30 min. Start flow test at 3300 hrs. Sept. 22, 1975 Rig released 0700 hrs. 9/23/75. Start rig down and demobilization. Sept. 23, 1975 Rigging down and demobilizing Brinkerhoff rig No. 31. 'Z . Form 911 1-69 Printed in U.S.A. , ,. Form 10o403 REV. 1-10-73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL 2. NAME OF OPERATOR Phillips Petroleum 3. ADDRESS OF OPERATOR ?. 0. Drawer 66, Kenai 4. LOCATION OF WELL At surface Leg 1 Slot 3, 1254' FNL & 928' FWL, Sec 6'llN-gW-SM BHL.;1225' FSL & 1293 F~L, Sec 6-11N 9W, SM ~. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RKB 116 ' above i_.,.,N or 100' above MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re '~ ..... C. GEOL 5. APl NUMERICAL CODE I___.._J_..I.. 5o-28 -2oo52 6. LEASE DESIGNATION AND /'--j-~ [N~ i' I ,.,,~- ~. ~' ---, 'J' ' 8. UNIT, FARM OR LEASE NAME 9. WELL NO. 10. fIELD AND POOL, OR WILDC~ ~o~ Coo~ ~et ....... 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) See Item 4 BHL 12. PERMIT NO. 69-99 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L_--J PULL OR ALTER CASING L___! FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF [~] REPAIRING WELL FRACTURE TREATMENT~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Plan ~m2ge (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form,) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Original plan s~fomLt~ed 5/'~' ~._:/ ~.~ indi~a,~,~d our intent to complete as a' dual. This was attempted, but we have been unable to obtain a packer seal with the 4 1/2" x 4 1/2" x 13 3/8" dual packer at 3509 RKB. Dual 13 3/8" packers are a specialty item and delivery is 90-120 days. Therefore, we propose to complete this well as a single in the following manner: 1. Kill Wellwith 11.3 ppg mud 2. Pull 4 1/2" x 4" short tbg string. Pull 4 1/2" x 3 1/2" long tbg string with TIW Dual pkr attached 3. Mill and retrieve or push to bottom the Baker model ~2B single pkr at 4450' RKB 4. Set Baker model KB permanent pkr about 3450' RKB 5. Re-run 4 1/2" x 3 1/2" long tbg string with Otis subsurface safety valve set about 242' RKB 6. Install Sree, test pack off, clean up well and complete as a single well commingled in Cook Inlet and Beluga 7. Run 4 pt BPT following clean up , 8. Utilize as producer Operation started 9/2/75 i~ ~s confi iirms cal~.~._~ Mr. Hamilton 9/2/75 advising ..change in plans. " ~-'"~ going i;s true and 16. I hereby cert~f~a~._~e fore ./ N: E- Porter (Th~s space for State office use) DATE 9/2/75 APPROVED BYl . CONDITIONS OF ~,PPR~AL, IF ANY: See Instructions On Reverse Side 2,~torned FOrm STATE OF ALASKA OIL AND GAS CONSERVATIO, Ni COMMITTEE "Subsequent Reports" in Duplicate ..~-~ ~ 5. API N~CAL CODE 50-283-20032 6. LEASE DESIGNATION A-ND SERIAL NO. SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PEdtJ~IT~" for such proposals.) ADL-17589 1. 7. IF INDIA.N, A.LJ_~TTEE OR TRIBE NAME 0IL [-~ GAS [~ WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FAi:UVI OR LEASE NAME Phillips Petroleum. Company. NCIU 3, ABBESS OF OPERATOR 9. IV]ELL NO. P. 0. Drawer 66, Kenai, JCl. aska 99611 A-.12 4. LO:CATIO'N. O,F WELL 10. F~ A~rD POOL, OR WILDCAT At surface ~g 1, Slot 3', 1254' FNL & 928' FWL, Sec. 6, TllN~ North Cook Inlet R9 W, S.M. BHL 1225' FSI, & 1293 F~, See. 6, TllN, 1t9 W-. SM 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) See Item ~ BBL 13. ELEVATIONS (Show whether DF, RT, GR, etc. :12. PEIL~/IT NO. RKB ll6' from MLLW ] 69-99 14. Check Appropriate Box To I~ndi'cate Nlature ~f I¢oti'ce, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR ~'ELL PULL OB ALTER CASINO MULTIPLE COMPLETE ABANDONs CHANOE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERINO CASING SHOOTING OR ACIDIZING ABANDONMEI~(T$ (Other) NOTE: Report results of multiple completion on Well ompletion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. SEE ATTACHED "DAILY REPORT DETAILED" DIR 16. I hereby is true and TITLE i' i' C~OL 1 3 G~OL 1 ~EV SEC )NFER: I FtLE: (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DJ'¢:$!C.,iq C F OIL AND GAS ANCHORAGE DATE See lnstrucfions On Reverse Side NCIU' LEASE .. .... [ :J.- -.. D EJ~FH. NATURE OF,woRK ~~ED DAILY REPORT DETAILED . , WELL NO, A-12 SHEET NO, SVua r(-, · -' -o 6820:'::-- , O''~& ~' ' ": '-~f'~:~'~-,: ,.: 20. ~. r~nin~ ~-er t~ing. T~g~ bottom before locatin~ ~!,_~l~ '-' ~/. ..(.-;prep'to OYE with'l~er t~ing strfn6.-- 7 h~ C & C,. 15 h~ _ .-..~."_ ._ '"O00H sI~Iy to p~vent swebbfng. 2 hr~ BU OTi, ~n6 r~ WL . '- ~ . ~': ~?. ., ~ '?:':L::::'-" ,: ['6~07.:'~'::.::Lt ~o~o,ed o~ 66 Jtm of B 1/2" 9.2~ J-N5 bu~t -v- - :ilg.Jt~ o~ h::l/2'' ~.6~ ~-80 b~t tbs, 28 ~ 20' ~nd 27 - 10' '/~.. - off'l~,N,:' OD x ~0' ID blast Joint with B 1/2" butt Box P oonnection~ '" aCroms the perforated 'i~t~al~. otim ~'Q" nipple at 6805. ' '.?..- '. '"' ~e~ locater at ~4h5. ~is 'XO" sli&in~ sleeves at 5600, 4h67, -~' ': ~-' "~.20~4. Otis "~'_~:. sliding sleeve at l~2~1 ~d 31~TB. Oti~ 4 ~. ~- ' '- t~in~ safety valve at ' ' · . .r~' ' · I~t~n~ ~ & cat, tic for packer fled, 2 hfs space out ~d lend ~ J~:...:~ ......'~-set in ~ pamker at 3509 P~ ~th ~' composed off 103 Jt~ of '~,"~-'.':, ". 4"10,2~ J-55 butt, tbg ~d g its of 2 1/2" 12.63/ N-80 butt tbg. ~ . ~' - .- · ..,(,:. . Otis ~ 1/2" tubing eafeSy v~ve mt 257' ,. ;:~ hfs nipple dram BOP ~d riser ~d install tree test tree '-.,-.~" ._ . , ';, to '3000 psi. ~,, ~, "?"' '," ' '' '~:~'alve in LT at 263' ~, Open "XA" ~!~ding sleeve at 4h41' '-:- ,~-~. 5 hrs'..nipple ~ to tbg/c~ing ~ulus ~d reverse mud out ........ ~rith sea vmter. ': : - .... SHd ~ to' Well' lOe' . -'",/ ~"'5 ~s m~-,caustic watere ~splace cas~ to p~ at 3515e 8 ~s · '-"' :-"-- ~ cloSed~'slid~ sleeve at ~510. ~t "Q" phg at 3515 ~ sho~ .., -..str~. Set P~ w/2500 psie ~l Q phg ~ess up l~O psi on ;, ~ sho~ str~ to test ~ at ~50. ~ b~l valves ~d release rig. 11 hours RD and skid rig. .- ,:Si,i ~ q ',~,_ DIVISION OF OIL AN~ OAS A~,~ - ,. . 7:?' ??' :," ::-:- '.:~' '. DAILY REPORT DETAILED ' LEASE t~I.J WELL NO. A_~ _ SHEET NO. .'. . " ' '".7.(:: ':' ?'..;D~¢'~H OF WORK '~ERF'ORMED ': -':~ 6820.~ ; [~ '..' .,;'[.'~ 1/2'hrs finish p~ling ~d LD ~,' ~ 1/2 h~ release and p~.l '.'/ ~.Days FR..SPu~il.'_.' 2 .... TI~ dual' pkr ~nd LD:.llO its 4 1/2" tbg. Pkr drug., all the ~ ' .... '' '.-' · ,'.' '. ~'~ ~ hrs,. rig~ng ~d te~t Hydril to' 1700 psi. 5 1/2 hfs rig ,: ~: ,~.... :-..' ".,. ~., r~r ~ BOP closing ~-it. ..',.'::..,'~'~s.~ BD~4.-;.3 ~ ~-'fini~h test BOPs ~d riser to ~000 psi. ~ h~ PU 12" · · :' bit, 1~ Bf8 csg ~crapor ~d 10 3/h ~B, B - 4 B/4" DC ~d 215 ?'~:..,~:/-;: ,~.'..': ._~'?17~ , : .::~_,~jts. ~ 1/2 ~,' Tag bottom 682B' 2 hrs ~splaee 800 bbl of ':'? -" ~".~9~. ~b / ~5/ %2 I2/~ /2z / ss / 8.0 / ~oo /oo ~gt.~ 6~'~..::?.- ' ,"",'74~-O 'm~d ~, 3 h~ ~H, l~ h~ re~ove ~ltnS nipple, '.~'.::,.. ;:. ..... : '". :~ Schl~er~r test lubricator to 1500 psi. 10 h~ Perf DIL DEP~ 6¥p0- ~KK~0 6748- 6758 6718 - 6726 66~1 - 6646 64~1- 64~.8 .... "',/.; ..- 6330 - 6338~ 674-9 - 6719 - 6727 66kl- 6647 6443- 61,50 6331 - 6339 - . - 5757 - 5764 .... :..- 5564 - '-' "' '", 55t2- 61232 - 6152 5759- 5766 5566- 5576 5534- 551~2 -'. ':-::;': . :: .5m !- - ' - ,--::. ,':'. ;:.- . "::~'?.; :'-:,.:' 5, ,~.,," -_.:'-. "' '. 535 ~ - 5372 5355 5373 ..,.: .:.:~ :::,?:~,:.?",.:..?,?..::::;:'~:~:?:' :-' ..:: 529~ .; 53o5~ 5289 5302 ,,: , . , ..,. - ,::,-:.{ ~ . .' : . . -', : - .. -. :~ ~ ~ ' ':""'- ":' ' :" ..... :' "' "':': :'~'?" "~"'"' :":':"- ' ' "- I' ~ 5118 , :.'.' . .~ ::: <".~',." :.":.. ~.:,"_-'~- .-, '-" ::, 5~0 .. ~ 35.. -' 5133 .' .".: ~:~::~:".:'. ,', :' '.":'. :.:,:::~,, ::'.:.' :..,:;.:.~':':. ::.-:' .:...:",: :::':: 5050 :'~-5o57:~ 5o~,.8' - 5055 :- -:".'..:-;:-...'.~..:.:?":::}::_~,:?, ::.::':-::.:. ::::::::::::::::::::::::::: "::C- .5oZO, ~ '5025 ~ . 5008 5023 ::. ::::::::::::::::::::::: : ., : ,;:[::?:::.:-..::.': : -:'::::: ?-: ':.::.j'.",.'<~O',, b-995~ .'.' . 498~- ~993 :::...: ! ! J .' _ ':,-~:~::'~ ~.: '::~ .:7':..?':Z:J.~:~:~/:~:'<' q:::..::-v,:~?::~% :..t~,,-j..:}. :::::~:,.~..?-" ?.:; :.::: :;:;.:-'.L :' ;,: :::~,, ::% %7 ?:?..:'. ':':::..:: :_. ;'. -..:: :.., -.::. ':"-.;: ,. 2. '- :' :, . ii~$ i?.LEASE '- -" ' TOTAL DAILY REPORT DETAILED WELL NO. A-12 SHEET NO. . DA~ DEI~TH NATURE' OF.WORK PERFORMED .. - , ~ spQd,~'~- 6. M~ D~ta: ll.~J/.~7 / 7.2 /'2/32 / 23 / 27 / 8.0 / 500 / 0 / ; -~ - -"~ Cook ~le~: . ' ::-;..,(.~.f.,: . u.-' .... -:-?,:": ~ ~378 - :~89'0 ~" 1J376 - 4388 ' '". :;:. ..... ... .. ,, ~.272 - h282 / 4270 - ~280 ,,;".': ,-'"'.- ~188- ~238~ ~186 - t~236 · :_.. : : . ..:.,~....,: - ~o- hz66-~ ~38- ~16]~ ~:.'." · :;~:';:"--.~1o6- ~111¢ ~1o~- ~o -: :"-._~ .' 'bo9o- ~o98/ ]~o9o- ~o98 .. -- 6:,.-'...: : '" ':~ 3896' ~60/ 389t~ - 3958 ' ':': :~;~. ): '.::.: :., '.'.1.::: ),:..-'- .... ~ 3820 ~ 3880 ~ 3817 --- 3877 ' '-,;-. ~Olj 3628~ 3601 3625 .:,-,-,,. - ..... , : ':" ~-'- 3577- 3587~ 357~- 358l~ '~ '":~::' '" -"'" - - -3558 ' 3568 / 3555 - 3565 · . '~ "." . ....' 1 Z/2"hrs RD 8~Z~erger ~d hook ~ flow ~ne, · .'. "-.'' . ':2 3/~: GIH. -~ 6 h~ C ~d,,~ g~ ~.mud. - ' -2 !/2~,h~ 'LD DP. -[' - ' L' '.' ~ :.. '' .... -.,.. ,~~ .,' ' .Mud,Dat~: 11;'4 /-28 / 7.0 / 2/3.~ / 23 / 8.0 / 500 / 0 D~s Fr SPud .~ 7 R~&ng ~n~ String of ~. ' :' 6 h~-LD ~. , . . , , 7 h~'. ~ S~!~ber~r r~ ~" gauge ring ~d ~ to h500' . ~..._~.. ~ ele~ric' i~e - set B~er ~del EB mt ~450' ~ on electric . . :-:.["_,. .' ,. l~e. 11 hrs r~ing l~er t~ing ~tring. .: . . '. ... J . -. , ~. ,- . . .:.. , : -.' ~. . : . ':'~ , _ ..1.':'-' :' ~ ' ' Form 911' .1-69', Printed'in U~S.A: .,' , · .:¢' ?-:. '.:i:. :..~ ~: ~ ,:'DAI SE: NC~'t~i.:..,':':,,~,, W-ELL NO. A-12 SHEET NO. . :: .. ~,: - ,. . . ~ .: . ' ? :.~ 'TOTAL '" - "' ' NAT. URE-OF wO'~ ~'ERFOR~ED . . - . ' ~,., : - - ,,~st~ct~e ~d ~ on Leg 1. ~I ~ ....I ~ [ ~ ~ : ~:~ad~Out pa~ of ~g ~d offload on pl~tfo~. :'.~0~/~5 ..~,~?,-~""~ '::- · ~:."L R'~ee"derrlck~ c~tinue ri~ing ~. Tieing in electricity, . water,-fuel and air lines. :. :.:... '" Rig:up '75%. complete. Skid rig to A-12, electrical hook-ups, - '. welding modifications, miximg mud. Delivering to platfo~.~ ?'~:.~:~ · ~rill pipe, tubing:, blast its, pups, and service company ' equipment , Ni~PPling up BOP'. e~d mixing mud. Tieing in flow line and mud line ~ Finish .nippling up. Mixing. mud. Expect to start pulling short string tubing arouu~ noon. · . Pulling UT. 6 hrs pull end LD 8' Jts, 4 112 tbg and 75 its ~'" tbg. 18 hrs'nipple up, down end back up. Continuing to mix mud. Form P--3 ( P~EV. 9-30~ 9 . STATE O'F ALASKA S~brnit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION COMMIT'I'EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not usc this form /or proposals to drill or to deepen Use "APPLICATION 'FOR i)'EP,~iT~-'' 'for such 'prol~osalS.) · ~. API NUiVIEI~C.~ CODE Eo-~3-~oo32 6. LF-,A~E DESIGNATION AND SERIAL NO. .&DL-17.689 1. 7. IF INDIA_N, ALLOTTEE OR TRIBE NA/VlE OIL ~ GAS ~ WELL L_- WELL ~ OTHER 2. NAME OF OPERATOR ~ps Petz~leu~ Compaq. 3. ADDRESS OF OPERATOR P. o. D~awa~ 66~, K~nai~ ~~ 996~ 4. LOCATION OF %V~L ~u~.~ ~g 1, ~ 3,. ~Sk' ~ &9~' ~ ~. 6, ~; RgW, S.~ 13. ELEVATIONS (Show whether DF, RT, GR, etc.~ ' 8. UNIT, FARM OR LEASE NAME 9. WELL NO. 10. FIELD .~ND POOL, OR WILDCAT Norkh Oook ~x~l.et 11, SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) See Item ~ BHL 12. PEPdViIT NO. ~ort, or Other NOTICE OF INTENTION TO: TEST WATER 8HUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPI,ETE SII00T OR ACIDIZE -- ABANDONs REPAIR WELL CHANGE PLANS ~Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZINO ABANDONMEI~T* (Other) (NOT=.: Report results of multiple completion on Well Co~_. n~,Aetton "' or Recompletion Report and Log form.) 15. bESCRIBE Pn0POSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. 1, ~up, ~alt16 3/~".- ~~~~s~ ~ ~,- ~~~ble gate ~~~s. ~~e water ~th 1t,0- ~,5~ ~d. Te~ ~ ~ ~s~. P~f~ate Cook Est p~ ~'- 3.~5~' 3. ~ra~ ~fs, ~m~l~ J~baS~t &g~ r~,. ~ 13 ~8" B~r ~ 4. Ran eombination $~ X ~ lo~ tubing string with 0~is subsurface safety valve set about 242' RK~ and TI~ ~lal Pac~ about Run combination ~ X ~. uppe~ %Ubir~ St~ with O~is ,S~bsurface safety valve set about 212' RKB and sting ir~o Ti~ Pa~k~r. ~. ~all t~ee aml d~pl.ace ~ud with ~ate~, ~ssu~e ~n ~ SI~ T~ pa2ke~, 6, Clean up t~luga and ~:hen Oo~k Inlet th~o$ LT,. '?, ~m 4 po~ut BP~ on. each zone. ~ pae~ leakage tes~. 8, ~l~e as ¢omb~natf~n dual ~ce~~ ~es~~. mon~t~ ~ell, Test packo££. Est/mated start of operations ~/26/75 16. e ob, eer.~that/%he fore/l~ ', true and correct ~hi. space for State~e use) /j ( i ,[, [ /' / ~ . ~ / ' APPROVED BT ,/~ TITLE Senior Petroleum Eng~e~ DATE ~_ 19, 1975 CONDITIONS OFk.A/PPROVAL, IF ~NY: TITLE See instructions On Reverse Side PHILLIPS PETROLEUM ANCHORAGE, ALASKA 99501 ~ 515"D" STREET EXPLORATION AND PRODUCTION DEPARTMENT September 9, 1970 COMPANY I.I 3L:NG [ '~GEOL I REV --. I DRAFT 1 SEC CONFER: FILE: Division of Mines & Minerals Department of Natural Resources State of Alaska 5001 Porcupine Drive Anchorage, Alaska 9950~ Attention: Mr. T. E. Marshall, Jr. Gent !emen: Attached, please find Form P-7, Well Completion or Recompletion Report and Log, Chronological Well HistorM, Electric Log (Blue Line and Sepia)and Mud and Lithology Log (Blue Line and Sepia) for NCIU Well #A-12 (formerly #A-15). Yours truly, JBG: jo Attachment s P.~LIPS? , PETROLE~U~~OMPANY John B. Gipsdn, J/ Dms~rmc/ /n~' ~ ~t Office Manager ~ P--7 SUBMIT IN DUPI. ICA'I '/ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE reve,'~e side) W£LL cOMPL£11ON OR R£COMPL£11ON R£PORI AND LOG* I,. TYPE OF WELL: OIL E:] nAS [~ [::] . WELL · WELL -- -- D~-'i' - Other [':: "' ~' b. TYPI/: OF COMPLETION: ~' ?'. I ; " WELL OVER EN BACK .~'--n~svR. ~ ~ Other NAME OF OPERATOR Phillips Petroleum Company 515 "D" Stre~et~ Anchorage? Alaska 9950~:' 4. LOCATION OF WELh (Report location clearly/ and i~ acoordanoe with any Et~te requirements)* Rqw S M ., o At top prod. lnt~r~al r~o~ed below Top of PaF: 3558' ~, 3558' TVD S27' At totaldep D) BHL: 6a20' ~, 6~ ':"T~' SS0' 13. DANTE SPUDDED 5. AP1 N~CAL CODE APl 50-2S3-2OO32 6. I~,ASE DESIGNATION AND SERIAL NO. ADI,-17589 9. IF INDIA2q', A/J.Z)TTEE OR TRIBE NAME 8. UNIT,FARM OR LEASE NAME North Cook Inlet Unit 9. WELL NO. A-12 (Formerly A-].5) 10. FIELD ~ POOL, OR WILDCAT North Cgok Inlet, 11. SEC., T., R., M., (BO'I"I~M HOL~ OBJECTIVE) BHL: 1225) FSL & 1293 Sec. 6, TllN, RgW, S.M. ,. 9,9-~9 3-16-70 5-11-70 [RKB 1]_6' From MLL~? ~ .... INTERVALS DRILLICD BY ].0-22-69 18. TOTAL DEPTH, MI3 & TVD ~9. PLUG B~CK MD & rYDS0. = ~ULTm~ CO~mL., I _ '-' / 6apo,' ~m Aapn, ~vDt - Rota~ ~. PRODUCING IN'r~VAL(S), OF ~IS ~M~TIO~, BOSOM. N~E (~ AND " ra[l lhF dTIAi NO~ ~gRPORA~D DILI,~ FDC, GRS, ,S~ Dipmeter ~' CAS~G RE~ (Be~ all strines set In 26"[ 1lA2 Sx 'G' Grot 20" 0.Dj [ '}133# · 1J-55 J I989.69' 13-3/8" '0.)3. J ' 72# IN-80 J69Lg, sq' 26, LINER ~CO~ ' ~8. PE~O~TIONS OP~ ~ ~OD~cflO~ (Interval, ~lze ~nd number~ '.-/ ,-- ~. , .t .., .,' . NO~~ ) DATE 'FIRST PRObUCmOH [ mODUCTION ME'I'HOD (Flowm.g, gas lift,_.pumpmg--size and type of 4 NOT :PEJ{FOR~D CABLE TOOLS ! 23. 'WAS DIRECTIONAL SURVEY MADE Yes A.MOUNT PULLED 12" J235l,. aw ,q, nmi, 7300' I J 27. TUBLNG RECORD O.D. I 3500,2 34 ; Y ACID, SHOT, F~'URE, C~ENT SQUEEZE, ~C. DIilPTIt IN'TERVAL (B~D) J AMOUNT /d~lD KIND OF MA.'/'ERIAL USED ,! J WELL STATUS (Producin~ or shut-in) Shut In DATI~ OF Tm/iT, ) II-iOU~iS TESTED '[CHOXE SIZE IPROD'N FOR OI~BEL. G~CF. WA~B~. J G~-OIL ~O ' J , , · , l~sT P~oD ] .... J I - ." !~ :-' I - i ~ J J' " .... '1 - - l 31. DISPOSI'TiON O GAS (80~, Ulgd ~OF gl, vented, etc,) TEST WITNESSED B~ ---- .~ -. ',1 } -- J t 32 LIST OF ATTA~HMENT~ ~ _ __ . ' . .... ~./? 1. Electric ov ~dioactivity ~ {Sepia, Blue Line) Mud or Litholo~v Loa (Sepia, ~](p.e~ Lin'e). 2, Chro~lo~ical We]]. }{istogv. - o,- 33. I hereby cert~y/t~at the foregoing ~d attached information is complete~nd correct aa determined from all:available records ' ) . ~ i - -- (See Instructions and S~ces for Additional Data on Reverse Side) / INSTRUCTIONS ~ ' General: This form is designed for submitting a complete and correct well completion report end log or{~ a all types of lands and leases in A~laska. _ ~ , · ., ' Itm:_ l&: Indicate which ele~ati6n is used as reference (wh~ere not otherwise,~hown)zfor depih measure~- i "-n ment~ given in ether spaces aa this form arid in any attachments. ' . ~ ~ Items 20, nnd 22:: If this well is completed for separato production from more than,one interval.~ zone, (multiple completion), so state in item 20, and in item 22 show the prc. Jucing int~r~l, o~ intc~rval~ ' top(s), bottom(s) and name (s)-(if(any) for only the interval reported in item 30. Submit ~ separate report . (page) on this form, adequately identified, for each additional inte~v~al to be seperat~ely produced, S~how-- ing the additional data pertinent to such. !nterval. 'L ........ 5- ~ Item26: "S~cks Cement": Attached supplemental records ~F6r':this well should show the details of any mul- tiple stage cementing and the' location of-th~ c~ementing -tool.-, - . Item 28: Submit a separate completion report on this for~ .for each interval to be separately produc~. L ~ (See instruction for items 20 and 22 above).'" : ...... - ,~ - -~ . . .... ~ .,...., ~ ~ > 34. SU1VIMA.~Y OF FOI~I'ATION 'I~.,STS INCLUDINO"'INT]~.VAL"I'F.,STED, PRESSURE DAT~ ~ ~~:OF OIL, O~. ;' ~ WA~ AND MUD ~' TM ~ ~ '~ '~ :- ' ..... ~ : ~AS. ": ~ NO ~STS RUN '~:~,. ..... .,~" Up~r 0ooM .In~et ~ 3558' 3558' ' ~ Cook Iglet ~;:, ~818' ~818 ' "~ ~ ' - ~ Beluga ;' - '~ - _ - , - -O '5 : ~ 38. ~ORE DATA. A~ACIi BRIEF D~CRIP~ONS OF LITHOLOGY. .POROSITY. FRAC~R~, 'APP~NT DI~S , · , ~ AND D~F~C~D SUOWS Or OiL. G~ On ~A~. · D ~ Core ~!~l 11.,134~ ~ 11,'!68' ' Cut 34' Rec. 22' ~ ~ · 2%' ss - it g~, ~f... gr slty,, clayey, scat. pebb!ebi, friable: in ~rt, ~le yel fluor & Cut. - l~ sltst 'dk bm,' g~, carb. mod hardo , - _ Core ~2 ~,933' - ~,979' Cut ~6' Rea g6" ' : .... ;t : : · '~ · .~ &6' ss, '1~ gr f-m gr, friable in pa~, congl,, chyey in. ~, weak t~. ~ vel fluor~ & cut Some dead n~l stain '- v'.; , . . CHRONOLOGICAL ~..~ELL HISTORY NCIU Well #A-12 (Formerly #A-15) lO/22-23%9 1969' Spudded ~!,, hole & drld to 1967' & rmd to 26" 10/2 /69 2021, lO/2 -26%9 2021, Dr!d 26" hole to 2021'. Ran 20" csg. Set @ 1989'. Cmtd w/g&2 sx Type "G" cmt mxd w/prehyd Gel wtr. Tailed in w/200 sx T.vpe "G" Neat cmt mxd w/20 bbls 2% cc wtr. Cmt circ. lO/27-69 11/1-5/69 11/6/69 1900' PBTD 6965' 6965' HOWCO plug @ 1956'. Press. tstd csg & BOP rams to 2000 PSI. Drld 17½" hole to 5384'. Drld J-t~l" hole to 6965' . Ran 13-3/8" csg. Set @ 69~9.55'. Cmtd w/1600 sx Type "G" cmt mxd w/d% prehyd ~J~ Gel. Followed w/120 sx Type "G" cmt mxd w/20 bbls Y~Y. Cmt circ. 11/9-.30/69 97~8' Drld 12" hole to 97g8'. 22/1-2o%9 11,168, 12/21/69 11,2 o, 12/22-31/69 !l, 869' 1-1/9-70 11,878' 1-10/L4-70 11,878' 1-15/16-70 11,878' Drld 12" hole to 1!,!68'. Crd~Fr ll,13g' to 11,168' rec 22' , ' Drld i~'2.!'" hole to 1!, 869'. out top 10,77~'~.~;~.' ~H w/overshot, stuck overshot, backed off, top of f~['~.j~0,616'. Screwed into up~r fsh, jarred loose. COOH~. ~.ft 1 ~ cutter & pin in hole. I~H & wshd to top of ~hj~ 10,777'. ~tched onto fsh & jarred loose. COOH & ~ fs~'~ft all 3 cones & sha~s in hole. 5~H. '.'~,: & wshd to TD. ~CM. '~,~}.t w/j~ bskt, rec 1 cone. ~n DILL],~ Sonic ~g, Density ~g & S~ ~g. Reran Sonic Log. ~n j~ bskt, rec 2 cones complete. 1-17/21-70 12,050' Rind & drld to 12,O50'. Started out of hole, pipe stuck. Spotted Pipe Lax & Bit Lube while jarring on fsh. Jarred loose & COOH. 1-22-70 22, O 50 ' 1-23-70 11,986 ' PBTD Ran DILL Log, RU to run csg. Ran 9-5/8" csg, set @ 12,032'. Cmtd w/706 sx Type "G" cmt mxd w/d35 bbls prehyd 10% Diacel 'D' & 2% HR-7 ~..~I. Tailed in w/6~8 sx Type "G" cmt mxd w/lO5 bbls prehyd 2% HR-7 ~"J. CHRONOLOGICAL I~LL HISTORY NCIU Well #A-12 (Formerly #A-15) (Cont'd) 1-24./26-70 12, O 50' Ran CBL I1,~38' - 6900'. 1-27/31-70 12,092, Drld on jnk on btm. Ran bskt, no rec. Milled on jnk. 2-1/5-70 12,10~ ' Fshd for ink on btm. Set 50 sx cmt plug on btm. Plug no good. Wshd out plug to TD. Ran second plug on btm. TOC 11,931'. Plug no good. Set 78 sx plug. TOC 11,979'. Drld cmt out to 12,038'. Sidetracked hole. 2-6/16-70 12,96~+' Dr!d o2 hole off plug. 2-17-70 12,998 ' Cut Core #2, 12,933' - 12,979'. 2-18Z3- -7o 4,268, Drld 8½" hole to 1~,268'. Ran DILL Log. 3-~/16-70 lA, 910 ' ~1. · Drld 02 hole to lA,910' 3-17-70 ~2,, 910' Ran FDC & GR Logs. Took sidewall cores as follows: ]2.,900', 1L,86g', 1A,8~8', 1~,802', ]2+,778', 1~,765', 1~,722', lA,711', ~,708', 1L,69~', 1A,665', 1L,635', ]2+,590', IA,567', 1~,538', ]2,,530', lg,gg8', 1L,376', 1A,187', 13,256', 13,2~O', 12,~2', 12,~35', 12,060', 12,0~7'. -lS/21-70 11,927' PBTD Spotted 75 sx Type "G:' cmt plug w/CFR-2 13,650' - 13,850'. Spotted 80 sx Type "G" cmt plug w/CFR-2 !3,O00' - 12,800'. Spotted 80 sx Type "G" cmt plug w/CFR-2 12,270' - 12,270'. Set E-Z drill cmt retainer 11,965'. Sqzd 90 sx Type "G" cmt w/CFR-2 below retainer & 10 sx cmt above retainer. 3-22/2&-70 11,927' PBTD Cut 9-5/8" csg @ 7620' & 6911'. latched onto 9-5/8" csg w/spear. Rec 176-2/3 jts csg. Latched onto 9-5/8" csg ~ 6911'. Could not pull. Cut csg @ 7300'. Rec 9 its & 2 pieces 9-5/8" csg. 3-25/27-70 7110' PBTD Set 300 sx Type "G" cmt plug w/CFR 7660' - 7110'. Hung g½" DP & tbg in well. 3-27/5-1-70 7110' PBTD Temporarily Suspended.. 5-2/3-?0 7110' PBTD WIH. Ran CBL 69&0' - 1900'. Set E-Z drill cmt retainer @ 6833'. Sqzd 287 sx Type "G" cmt w/CFR-2 below pkr. Left 13 sx on top of plug. Max. holding press., 260~. Press. tstd csg, O.K. Phillips assumed well for comple- tion as' gas well. 5-h/Il-70 6820' PBTD R~n g½" & combination g½" & g" dual string tbg. Pkr leaking. Reran tbg strings, set @ 3501'. Bail Valves sei.. @ 29~.' & 26!'.__ Temporarily Suspended. ~ !O/2L,/69 2021, Dr!d 26'? hole to 2021'. / I0.12~ =/oo ..-2 ~ _, . 2 02 ! ' P, an 20" cs~. Set w/orehvd C~ '~r. Tailed in ' .... "~" ~'==' cmt .... ~xd w/20 bbls 2~ cc v~r. Omi circ. I0/2v-6 a i0.I28-5!!69 lqO0' PBTD . _. ' .. B~,. rams 2000 PSI. HOWCO olu.ff ~ 195o'. P~ess. tstd csg & au to I,.': hole to 5384' 11.1,_-5/69 6965' Drld 17~" hole to696.5'. 11/6/69 6965' .Ran 13-5/8" csg. Set ~ 6929.55'. Cmtd w/16OO sx Type "G:: cmt mxd w/h% prehyd WrY Gel. Follov2d w/120 sx Type "G" cmt mxd w/20 bbls Yd. Cmt circ. 11/9-30/69 97~8' Dr!d 12" hole to 97&8'. 12/!-20/69 11,168' Dr!d 12" hole to 11,168'. 71_2./21/69 I1,250' Crd'Fr !!,13g' to 11,168', rec 22'. 12/22-31/69 11,869' 1-1/9-70 11,878' Dr!d ~'" hole to 1!, 869' ! '~:., · ~,~ile,-'.,~ulling pipe out of hole, pipe parted, top of fsh 10,777E. l:fIH w/overshot, stuck overshot, backed off, top of fsh')!O,616'. Screwed into upper fsh, jarred loose. COOH -Left I rmr cutter & pin in hole. TfIH & wshd to top of fshZL~i !O.777'. Latched onto fsh & jarred loose. COOH & LD fsk. j:.~Left all 3 cones & shanks in hole. · ,.i.~ . · ~SH. ?~m~ &'wshd to TD. C;~Cii. 7~{ w/ink bskt, rec I cone. · ~0~ C Ran '~ ? Sonic Log, 9ens~t? Lo~ ~- Si? Log R~,'an ~ ' Lo~. P~n jr~ 'osk,~.~ r~c o,_ cones complete. !-22-~0 12,050 ' Ran UI,_-, Lo~ m: to -*m. ~s~ · .... · = _ . · .... ; · ' . _z.: 9 .... ~ ..... ," Pan ..... 9-5,IR" cs~, set :--"~ 7~ ,032' . t'~+d.,~...,. :.r/?Ob, sx ,...,m~. . "q-" .... ~ .... · ' , . . ~ ..... . ~. , ..... , ...... · ,, · Tailed ~_... wloA.b., sx m,~p~... . "G" cra+, mxd '..r/!05 ~-~...,_= p~h,rd. , .. ,.., ,, 1-2&./~ o-?~, 12,0 50 ' or. '"""" '" "~.--.,.4 on ~k 2-1./5-70 ~ ? ~ OL' Fsh~. for ink on b~m. Set 50 sx cmt oluz on btm. :-"~' no good ~,',~sh~ out ~ .a. TD. . p±uo to ?~n second plu~ on btm. TOC ll, q3!'. Plu~ no good. Set 78 sx plu.~. TOC 11,979'. Dr!d cmt out to 12,038'. Sidetracked hole. 2-6/16-~0 12, ~6~' Dr!d _."~ hole o~e o~u~ '-~ 12 933' -12 97~' Cut Core ~.~, , . . 12,268' Dr!d 8!" hole to 1~,268' ?~n DILL Loz 3-~/16-70 IL, 910 ' Drld ~*!" hole to 12,910' . 3-17-70 lk, 910 ' Ran FDC & GR Logs. Took sidewall cores as follows: 1L,900' 1L 86g' lg 8~8' lg,802' 1L,778' 1L,765' 14,722', 14,7!1', ]2+,708', lA,69&', 1L,665', 1L,635', 12,590', 14,567', lg,538', 1L,530', lg,ggS', lg,~76', 1L,187', 13,256', 13,2g0', 12,gL2', 12,g35', 12,060' 12,0~7'. 3.-zs/2z-7o Il, 927 ' PBTD Spotted 75 sx Type "G" cmt plug w/CFR-2 13,650' - 13,850'. Spotted 80 sx T.vpe "G" cmt plug w/CFR-2 13,0OO' - 12,800'. Spotted 80 'sx ~Type "G" cmt plug w/CFR-2 12, ~70' - 12,270'. Set E-Z drill cmt retainer 11,965'. Sqzd 90 sx Type "G" cmt w/CFR-2 below retainer & l0 sx cmt above retainer. 11,927' PBTD Cut 9-5/8" csq @ 7620' & 69!1'. latched onto 9-5/8" csE.w/spear. Rec 176-2/3 its csg. Latched onto 9-5/8" csM ~ 6911'. Could not pull. Cut csg @ 7300'. Rec 9 ,its & 2 pieces 9-~,/8" csg. ?!!0 ' PBTD 7Ll©' Pored Temoorar~ 7~,- Suspend. ed ":~H. Pan CBL 69&0' - 1900'. Set E-Z drill cmt retainer ~ A~~-' 2nzd 2~27 sx r~ ,~,, cr~ .¢/owo_o ~=1o~.~ okr. ~ ~ .... ,..eSS. ~ , . le~ ~, ~ s:~ on top o~ O!u~. 5~x. ho!din~ p~ ~600,~ PresS. ,~s.~. cs~, ,.~.K. °h;l~=,. ~ __:.~ ass~.~.ed '~,,. ~._ _eot com~!e-. 5-~/!!-?0 6820' Pn~ Pan &%" & combination &-.i', & L2? du~.! strinz tbg. Pkr '~ 29/~' ~' 2.~1.' m~m~o~,r Sus~ewded I I 11,13&-35 . f ~#A-15 N.C.I.UNIT · CORE #1. ll,1]A - 11,168 Cut 3&', Recovered 22' Described by C. R. Seewald ,, FILE ss- It gy, vfg, slty, clayey, mod hd, calc, SA, mod srtd, ' poor to fair porosity and permeability, qtz, feldspar, abdnt gm, brn, and blk rock fragments, tr mica, .abdnt buff to wht soft weathered feldspar, uniform pale '... yell fluor, free pale yell cut fluor. 11,135-36 ss - As above w/sctd coal fragments, and thin carb laminations ' 1/32" to 1/16,, thick. 11,136-37 ss - it ~y, f-rog, sctd pebbles up to 1" diam., 10-15% clay ".[...':; matra, poor to mod sorting, SA-SR, qtz, weathered feldspar, green & black rock fragments, friable, g°~d.'i".[~'i:, i.;'ii.:.:;:i!!?.i)[.'- . P&P,, pale yell fluor,.., free blue-wht cut fluor, .'.'...i.~.i..,/..!i.]::i,::.:.:....i ..'.'i.:.:: 11,137-&O ss - As above except sli calc, less friable, yell-gold' fluor, bleeding pale yell cut fluor. : . -' :..4":~ i:.' . · ..-:-:. f/.:.' , .' 1/,0-/+2 ss - Like 11,136-37 above. -:' .'-'"."...:i! '"' ,'-" .... ' '"".'~'-:-" - , .:. '. ' 11,1/,2-44 ss- Like 11,136-37 above, except less friable /20-25~ · - clay matrix. - -.., .. '-...,.:.,.:...,:-;.'./.:: ..... ',r~?.;.'.,.'.: - · ' ' ~- "' :' '.',.'. , .-,L.,..,.,' ,-" ,,-~;.'.''?~ ~..," · - '. .. .- .. '. . . ' ' ,/i;-' i!'.~i.~.?. ":'i; ll,l~-&6 -.'.-,'.'!-' ~: ..... .' ss- It gy, f-mg, [0-i5% clay matrix, poor tO'mod srtd, SA-SR, very friable, good to excellent P&P, .'. pale · .. fluor & cut fluor. · .... : :..~......L..;~.,....:..'. :..;....,..:.:?::: ,.:.. ' ' ~ ' ' .. ~ . .: .!-':,' .' '~, .. .... . ~[.~....: ,, ...~ fair-?&P, poor to mod srtg, pale 7ell fluor, stremh.~ :'-. yell cut' fluor, 'thin carbona¢~ou~ lami. na~ions :In bo~go~ ' foot o ' ':.' ''~ ?." ' · ' - ' · :" -'- ' ' ..... ; ...... . ': i '": ' :'; ' !." ;:';': :,.:..?...'..~ ;,., i . ';~. ':, ~ i; ;,.".-' clyst- dk brn-gy, mod hd, slty, slt sdy, carb, w/b~ carb 'Streaks. .. 11,148-&9 11,149-50 11,150-56 11,156-62 11,162-68 ss - Like 11,1~6-&8 above, w/abdnt coal fragments, coal .. laminations, and some interbedded coal. .. Not recovered? (Ground u.p sandstone & small shale fragments at 11,150 indicate some core was lost here. Probabl~ mostly friable ss on basis of coring rate. ) ss - It gy, f-rog, friable, sli slty, 10-15% clay matrix, SA-SR, mod srtg, good P&P, qtz, weathered feldspar, abdnt black rock fragments, sctd coal fragment in bottom foot. Pale blue-wht fluor & cut fluor Not recovered? Probably tight sandstone or claystone on basis of coring rate. 12,937-38 38 min/ft' ~ 2. o/, 2~L3 6 .7. ....../ .. ,. · ,., tI r.4- 12 91¢3-U+ 1~, ~ m~.r,. -. .... ,,~-,.,,- ~.. ,ed ~.: t, aT, '~ '-, s!i fri., vfn-fn, subang.' ;.'...,' . w. ~-t,d.. mzaa., c~rb., 10% wh. clay : "'....'.,: :', '.":::. /T~] ,~'k~ ~ ~ 4 · ' ':'-.:.:':.':.:~},,LF'~ ~ ............... ,, , ...... ca!c., pr. per.. no show. '". .... ,' '. ....- .. i~-:-. .... ' ' .;;' ~ ~ · ' ': ' ":.:-~ ~.' L"" ' , · · ..' .', ..:Ct,' ... :.., a~ &~]~O'~'~ ~.0 ~OW. ' ' ~:;'" ::':' '..:.w.'..,..., ,' . - .,..~. :,:-". :.:.- -~ :.;':.q':,-,. as above, w/seat, qtz pbls Up~o 25 ~, ~, , ;.'., ,..... .~ .: .-:: hd., c].av.~ no show. ~...,:......."" ' ''-'"":-' ' .- · ' '"'-': ~':::'::".t - . . ' ..~ ·, , ~ .: ~ ,:.',' -..+ . ~- e~ ~d h~-eob~..le [~ & ~ed' &"' ' ..... b;':..'.'~,' ,--.,, ,~.- .... ~ .... ~,irz g~:.:rk .v. ::..:~,,' :':: . · . , ,.. ,. grs. ) ,matter. fn-med, subrnd. 'prly. clay (Kalonite !0~), hd. tight, sc...'lt.{'::~e].l:".:"~:~'~?.'~) · ...or, 1~. ~e-1 w, cut.. pr. show ..... -.~,,,,.,,....,...,. ...... .-,. . . · · ~ ' J.-'l".~x ~:~ ~'~":~:' · . ' .: , :..: .y~t..,?,~ t~:,.. FL'-': '.~:L.-:' ~o ~ ~ " 4 . ', ' ~: ',' '~'~"."'~(; ': ,' . +' · . ~ . , . .:. ~ ,. w/wzdeZ:, sca,,, sub~n~ g~anules,. ~a~r M~ clay 3%, ~d per, tr. perm.,' dead. oil,.:.,~v,:.:..'. st~brnd-r~d pbls, prly srtd , "mqca'.'2 car6;,{(~(~'t~i~[~;~r:';?t- ~ ~ ~ I '" ', -' '.' . ', .... '"',fi' W~ ~ .~ ',' ~ ~ ~ .' '. ',.:' :'"' ' ':-' ,. . ~ . .... .. ,,,., ,,.. .... ~ ~ ...,..', .~ -. ~ '~ ~I ~ r q '.rl~ ~ ~ '." i':'r" ' . ~ . - _ , ,: .... , ,...., .,..-. !1~ cttt . . ' ~ ,. . ':: :,.'.'~,.. 't,.,. ';~:%: ;. ..... :~ ~:. ~ ~.q: -' · . ''., . · · - . -. ,..- -.;, -.. -.:/:~?u:,;~..;~,'~ ~ ' z, ~ /~ ~r ' ' ~ .... ' . f-w ?t.d, v. ca~h, e ~i.ca, "wh ci.a~r 8%,' . . ~ _ __ .... ,j.~. ,... ~,o~~ ~ ~' qf "~ ~'~, ~ r ' . '..: ;.'L..', ':...': ~ .... ~ ,,c.:, ..... .re,.1 ,.L,.O,., Z~. leil wh.:::.,.,..,.......:- a~i',, pr,' Sl'~m,,, - .,,::: '...,..".r :'] '..' :..', ;':: .-. ,. ... .~ ....... . . ,,: ..... . '. . ..... .. ... ?a, Zt. F:7;~ ail ~7i. nub~n~, med. ~.~ -..-.....::::..: , .. w. wrtd., ce.~b.?, tm. mioa, wh. oZey 5~, -- '".:. - ~_). - ~ ,...~ ~ -. ~ .. .. . ,.. 5lq OW. "" '" :. , --' ..... · .'~.:.':';. . . , ,:.: -:'- , , · . . l'fl ~'~, ~ ~ ~ '~ -tell ' "" -- ~-. ~ ~ · ~ --,-~ . - W~~ ~, ~ L, ~r] .... OW ' ' . - . . .' ss. It..C~'-.~ ~.rz. subang-subrnd, med.c.gr.~ =-,. ...... a . carb ? (b].k carb. c]yst grs), , ...;, ... " ~'~ [~ "-. '"" "' :' '..'7.. '-'..' ,.; .,. .. ...--, ' . ...1 ~ ?,] :~'¢ '~ .',~ ., .,, ~'.~ 12,9!,.6-47 ! !. 0 .m in/f t O. 0 min,lft i~ .12,956~51 '.i..'.. ;.:~ 5.5 min/fff · . 12,9-ql-q2 ' .'-'ii ' ~ ' ' . 3.o re_in/fi · . ,~.,~.~ It. ~;......, sIi. i, subang-subrnd .fn-grn., ~'-~-'- ~t,~ ,-r~, c]?r ~,:,~ _ . ...'~:: ,..~.~.j , ........... ... .f-~d pot, it yell wh '~,,or, v. it ~]l wh cut ~uor, -, ;..:~,, ....,. ~ ._ . pr. show ;~ :", '::'.'? ., ...'. '.~. '. .. ss. a.a abowe, b~i~a yell fl.uo~, br~te YeZI' wh fZnor c~:t ve~ brn cut It tan sLn..-.' :' .~-.. "' - . ., ~ ¢, -~-~ ff . ' )...., ~.... .. . ~ S a h ore. . . . .., .Z :~ (: ,.',",.L .,: :.'!. :47..'h~'~.. · ' , ". .7"; .... '. . · .. · ' ' .' ,-",-4r.~:-- . ' '.:' " · '- .: "',~.: ,':.'.. ~.",':..' ~.~;.r.;~:"'~?.:' ~ ,. , ~ ~, /~ * ~- - ~ · . . ~, ~... .... ;...... - ,~. · ,,,--~Z] ...... wh ent finor, pr-f.' show. ss, e.s above, inc. in plol. , ,yell. f!uor~ faint Wh cnt fluor.,,- : . - . ..?. 'ss~ as a.bove,-deci' pb].. above. '"' "- ~'-' ~, "~.'..:{ . . , . , } .' '[' ~& .'~ ss. as above, lt'., gry., sli 'f~i~"~'suban meal-phi_. (up to !2 mm), abdnt blk carb'.~?;' ~ . -'nr]v srtd .wh clay 8% ~er _,,. ~,ve]--1. wh · fluor. It yell wh-. flu°b~'' -' ' ].2,"C)~'2,.~ :':'/.,' :,.:; {].i.-. '8. ~. ;~.'~'/.~+. :'/-'.;. '. '--. 'j: .:::~ ~ 2'-'"~s ;'a?O'~r~' ~" ~;~";:~: ;,2~O'"e~¢' · · ....... -', :" : ........ .;..;:: '..-'".: .-.. -' .... : ": - f-gal, srtd,, show"as .abOve. . .. _ ...... ~ ~:':~}':{' , : .... ~ '"' ....."'"~ m~.n/ .... _ :'.. :. ss, it. gry., sli.:fri. -' a.bove: vf~ c].~y l~.~ f-6d, po~.~ show as'.'abO+~';' ........ ' " ' ..... · ' · ' · ' ' :'.'. .... ~ a,,-a.,o~e~ w,. clay 2/,,, bPm~e ..... e ,._~ wi c~ .... bO, ~ . f--~. show, ...:~ ' ' . ~ ' .' ~ . ' - " w, srtd., w/b/k, . ~.~r.~. a.s above, tr ~n Clay~' ...;:.:::.2.}_:~.'.'. . f, pot..-sportF brite yell f].no~ w/l%. ~{(.~,:-:-',..:;}:.."?/[:,._ ~:~l] wh c~i; ~r show. · '- ........... ""' .... : " .':; ".:..'X-- 9 56-~7 ~. ~:~ m:}'.:.n/fi:. 12~ ........... . ].2, e:-w :2 ., _., ~ 1.2,9..'. ~-3., 12,959--40 12,960-gI. 2~ · .. ~s... a.s eb~,-e, .. suban~,...~:, med-c.gr., fair Srtd., ~'".~,. :¥'~"':'],:.~..: ....... tit:or ~,,/r~, ...... yell wh :cut fluor, , ~tlOW. :.. ~)i'... ;.. :i." '~ ~ ' .-: ~° -~- a~)ove 8}'.,ot< as above. ''.:~ .... 7' .."~'""~ : "" "' ' . ~ .-... .:~ O%r~= , ..;. :. ~ ~. , ...': .... : .-''; ss, a.s above, w/widely scat,, pbls. '. ..- .. - . '.' .; .... ss. reed it..~: fluor, s!i fri, subang~sub~d~ fn-med gr, pr]? srtd., abdn% blk ?s as above~' ..- .... . . -., ~v~ ,'-~ I ~ ,ol. or ~ 2!,. If" ~-' . .--<'--". .. .... ~','-'..~. sS... c~l., ~. ~..~ ., nd. w. cmt, calc. vfn and md, pbls (t? .~.o 30 mm) (gr .'., pbls, qtz phis), show as above, .:....~:}...-) ...- 5rs, pr].y srtd., bik grs as above, tr. wh. :..~.?~..:,.' '. c.].a.,,~ f. pot,, it y~i! wh fluor w~fa~t yell'.~'[~'::)~ ~,:b ct~t fluor, pr-no shew, ......:'... .- '.L L", 12, 96Z:.-65.75 ].I,~ -~-/~ ,'p ' , . _ .:;.,. ~... ss. as above, w/sea~. 5a~6e ~ls. 'uP'%6"[O --- It[ yell wh fluor w/It 7eli wh cut fluor)..,~?..:/.;.'~ . F.r'. SHOW. A_:. " ~' '"'5 '~ - ..' '.. ~ . 12 ~6~ 75-66 o.., , ,, ~. ' ~ rain/Ct ss, as above, w/co~l !amin~tions'~ ,. .-... -.;..,j,:'~" , ,, (03-65 5,, ~ '." or ' '::" O,S ~boKre '. '-', ". :*" ,. > ',2~ :"..... . : _..... . , w/orzte yell wh fluor cut., it tan.:' ,, ..'--J;i., ~ '~. 2-" ] . ;" i "~ ' .'"' ~'.' ,.'~ - . ... .[ .'.. . ,.. .,. .... , ' ' 12,96~69 ' 2,2'min/ft ' ss, as above, pr. snow, "' ........ ... - . .,.-',,... : ..- . .- .... ~._ : .. -. _. :.,,. .(,?_ ,..~','[ ~ w/wide].7 sca~; p¢ls..', 12.960-~0 ' o.6 m~,,/C+ ss,-as above, . . ~ . . .. · -. .... ~ ~ -- ~, .'~' ~" .,. .........: ......~.'. ,.'-.:'-:..'j .~. . as. aoove. '." .. -~. . ...- . . ,. ....:..:.. . ,::.:.~..,.:,--'-' .,,..,..:...,::.....--, ' - '. '-~ '. .... -' _. >. ' .t -' ".. . i. .... : [ ' ' '-' ' ;" ' ' ' ' '~' ;..>t""t':: .... 12' 97~7!'::-',.-.'.(..-.':'-/2 6 -~,-/~' '; .... "' :- .. --- .... ..~ · ::?-.: .:-:.'.:'.~.:,' ...... '.:-.:".:-..::._ .- : ':" as s. bo~e; wh'cia~..~.'~dl '.por., ' ' " ' . .: · . .-v -.:. -::.: .-:/~.'..-: :- ::..:'-:'.above,' .-: ".'.'[ . ';:::. ~. 0-.......';"? ). ,.:' . '.:.: "'~.-~,i~:h:-,..,}?:'::"~:" .~ ~' ~:" ~., 5 . .... _ .... ..:-... :~..: ..: 5,: ........... /-, <::-.:.. :.?...:.::~:,..-:.~,,, .,~ ~..bove, wn .clay 10% "pr-f,.~ P{ ........... ,- .... .'./ :. :'t:" : ::'.-:'- .... ':.It yell-wh fltlo~,";tr'.ye!l Wh cut"fluO ~ ':[. .., '.-._ . ~. : . ' ~ . : '"- p~, ~.o i~o show;'.." ' :':" .. '.'"~ '.: '",., 12,97<--73 - -'.. 2.1 mzn/'f't . ss. as above, pr-f, pot., med' ~. . -- . :':.. '.. -) .:.... .... .. :,;~..;..:(';: ~ ~ "' ~"-' ,,,- , ...... ~ :',-- ss. as aoove, w/inc.in pbls 0 , pr;~por show as above. ...... ...... .....;.,..;...,.-:. .... ' - .. t,'Q~ ,.,,.,' / ~ ~ / , 12,974-75 ,,*, 2 m:_..,, :. :, ss. as above, .. , :..-...,: .<,,:,.,: ~-* . -'.;,v - ~, s,.. as abo,re - ., - · · - ' · . .. ~.. ,...: .- , . ,, .~ . . ,~ : '. .,.- ". ..... ;,''] '7.' ' ~,t.:.,../ 2. :. : c~l ~ ~' . ~.~, grsr. hd.. w cruz, wh. clay."' · . . :. -. .,.... . .-.. ~ ~' --. ~',,',::.' Kemeth W, Sloan ~ : F C [ ~i ~'' "' ""':':: '.~. ~ .~ , ,-.--~-, ..... · .' t' :' ~. ':' · ~i j_ .;- ,U,' U. · .:~.. ,'- . ..' ' , " ..... ,7 ...... "d gaff .... . . ,, .. .. .. .. -A' e. ':' ~:,, ,90o ssa O/s") iL, S02 (l/2") ¥.RYV~LLE-PHILLIPS /fA-15 NCIU ~orth Cook Inlet Field - Cook Inlet. Alaska SIDEWALL COP~ DESCRIPTION -' · sand size mat~e~iai composed of qtz, chert, coal, and~'.dk rock fragments. So~.e It gv to gv-grn, hard tuffaceous .or.. siliceo~'.'i!'' .. ::' ... ;.;' .-~:-~.:' ..."' material. '~'-'/~.. i":':[' iiii'~ :.'.~ :!': ~..' ". [ ii !i! i:i'?'"'",:i['''I'''~ :: '"~' 'i.~(' ,~. -.:-- ::.;'~'~': .. o .. -'...' .... ." . . : 1~,778· 0/Al,) "' CoaI and sandy tuff -'80% of core is coal · blk, shiny, .,-....; ..... /~'. mod ad, crumbly; rest-of sample is sandy tuff which ;is ~ '' ': "'~ ':' bedded interlaminated and generally intermixed w/the 'coal' /: . .. . . ~..~ - , . · ...... Tuff is light tan, light grey~ and grn-gy, mostly soft and ....~-: ~.--.:-~' crumbly w/~e hd. siliceous tuffaceous material "Tuff contains - :~.~..~. 10-20%, f-vcg sd (qtz, chert, and dk'rock fragments).;:~'!ii.'Sand..:., :i': "i:' :"'?i:': ? _ii~i'~ -.,-.i~' "grains a~e randomly' scattered throughout .the ~ ' .~: ' ~i..:.':.)~i .:. ~(;.-::.~??:?j. :,~:-P&le yellow fl-or. -~":..~ i'!;,..~.-~.;; ~..i:i'/.-:J:': i:~:i:i ;[...! ~ :--~.ii ;i'[.i.':Ji': i i:~J'i]':'~ . . : . ;. '-'-..:.": .' .. ]:':-':;'~ ~?.':?:~.... ::' ..:~ -:.-:... ¥ .... -:-';;i-. 2:.(:-;-:-:2~q.:..;.': ;'..'i ~i.:-:r.:2~::.:/61· .~)'ii :::.. ~ ?..-.~'..'~.-;.::.:.-~..~:..~ f -~'~' - -'~ - - -~ ;;-';~ ?'-:-~"-:~'~-:~;"?are ' qtz, '- ~ r' chert;? ~.nd dk rock" .fra~ent s,~. ~ : , .' .. ~. ,~ ~ ...,:, .' . __la, 7~ ~ -' '~ ' -·Pulled off.'~ - . ...... : ' '~ ~'"':'" .- . , .... ": .,, .~. ......... .:..'.....:?...,..~ ~,70B ~ .:.:"(: .... No ~ecove~. ' ..... : -.. .....- .'.?':"' ~ . ... ......... ..... .,: :~:' ;-........:. ;.....:.'~:[;.?:.... './ .... :.... ' 1~,69~?(3/&") Shale - bro~ish-blk, mod hd, carb., sctd small coal fragments;'-";:7~ laminations and small ~oal fra~ents. ' ... '.'.. . "- -. . ,- ..... " . . · . , .... ', · · . '.'.,.-:;:..('~..,~.,,..~;k; Clvst- med ._~Z, hd, blocky, bent, - .'-'? . . . . ~ . : .. ,..... Clyst ~ reed ~r, soft to fzm; cr~bly, contazns thzn c0al .... .. '~ - . . ' laminations and small coal f~a2ments~ bent, - ..... /..-.'". ,'..':'..:";.:';>~.~:/~.~.'.: c%sz. soft o bZZ, 60-70 bz e- een tnff, w/floatin~ ~e~bles to ~/2" diam, and c~ sd' .-Pebb[es:'afid'~ 63 f? (l/2,,). lA, 590 ? 538 ? 53O ? and dk rock frap~.~ents). No recover-. No rec ove~z. (Looks vem~ similar to la,900' core). .- ..... · Tuffaceous congl - reed gy, fO~ qtz, chert and ign rock pebbleS' :!' ;'.';':')~'i.:[: (I/~" max, dia..m.. ); 10~ sd of same Composition. AO% ~y and ';...~. gy-grn, c~mbly tuffaceous material. ,. ):..'i::i/'.( TM '.':,[:' i[. '""' - : ' ': '~ .";.? ' .... ~ '. "':'.:i ' Clyst reed gy. mod ',h'd blocky, bent, abndt sm, coal fragment ":" .... :'~ - s. :f [. ':; ,.'i;:,'; :' '..' .. · ~ ' ', Pulled off, '".'.,: '.,. ; ;.: ,' ;.-' '. -'?,.-.., . :~.."~'' .. sandy clyst - Dk g~.,, bent,., mod hd, kO% vf-mg sd (qtz,-chert,'.'"[¢;i:!?.':':.;: ,3767 lg,!87 ? 13,256 ? - 12,&~2 ? ~ ~ '; ,-.., ,. ...... .. ,,/...,,.'.f~* . ., ~To recove. , ' · ..?.: ** - ,, , , ... · -*. RS -med. ~,~, vf-fg, l~O~. fy bent. clay matrix, poorly srtd, .f.j,.( .... - ..:::':":".!)'/"i:,:..'[j'.;,*' SA-SR low P&P, ored otz and chert, w/se blk and grn rock "': ..... : ' fra~ents-; coal framments and tr mica. No Show. ' .':[~:~ .'d--" :""' '"' ., NO recovel~.,-. · "-, · .',** .. · . . .*/..'... , ,*: '.* . .., ,~'.:- ; * N*o recovel~z, * ~ .... .. ,, , . . ., ....~ ,~ .*,.* ....... -. '...: o ..' . . ' -. . . . · .' , · .* . ~* ./[.,., .. ",': ~ *.,y'~'~?.;'..'.. Ve~: claye.v ss - reed ~.y, vfg, &0-50% gy clay matrix, fmrm,'...: abdnt rounded cinnamon brown grains,se dk grn grains. Pulled off. . ' ' ": · . : .... ,..- . . ;.....,.~ .,......: .. ,.; :, ';;' f, ' ~: Pulled off. · .... .. · ~ . .... Clayey ~s - 1-t ~7.;, fg, 20-30~o ~.~ bent. clay' matrix~ 'poorl7 srgd, low ?&P, friable, pred. qtzo w/se chert, 'blk and.'.',.'.. 12,~3 5 ? . ~.. .,. .grn rock frag.~,and sand size coal fragments, brt yel..! fluor · .- . . -,f;' * . 12~097 ~'. :? No recovery. .,-;'. , [..'.','..i .: ., -,?~'"¥':'...-,~ "'~;"'~' · " " ' " ' '":.' - ..... '' ": "'; ~ ' " " ' ....... "' ' - ' ,"/'"':':~ ~; NOTE:'--As indicated'by (?), some of the depths 'at which SWC's Were taken are uncertain. The Schlumberger engineer-stated that he fired 27 shOts,: however, when--the bullets were removed, he found that all 30 bullets :: '. had been shot.- Apparently' some shots were double shots, but~: Schlumberg~' .. ~ .:.';.:-~*:':i'icould not dete~ine which shots these were. Because "of the poor core . ~.,.-jrecovery, the correct depths of most recovered samples .cOuld ;notlbe '~"C' ~ .;~ .... , .'-;~,-u...f*, ~:--"~ . ,'::). ~.-:.:-,~% ,.. ~.f~3,'~-'T', .- ,.~:-'*.'-.'~ . ; '~i_ *. '".~.._- ¥ .*,.,: '..'.... ;)77,,;: j'..'~', ,'fi ' . , : . _ ..,.. .... ..:,, .. ,~. -. ., :-,,;:~.:-....~,::-~-~..~ . ..:.:..._ ~ .. .,-.. ~ . ~..j... ~_.:. :'...; .~,..,,.: ::.. -,..~?,,. C.'-R.~'See~ .* .".:?~" .... "-~ '" '- ' ' '.' :"; "' - ' ':.".".-' ...'. . · .... :'.'.. . :i. ~: :.: ;. :: __~q, Z970 "'"-': :'- "'" : ' ' '"' ' '":'" '""': ~'' ~-~:ch . .. . . . . : - .... -. ~ '. -. .., . .."~. SYMBOl. OF SERVICE REPORT of SUB-SURFACE DIRECTIONAL SURVEY CX:)blPANY WELL NAME N. COOK ....... INI_F',T LOCATION JOB NUIvlBER AM 2- 270 TYPE OF SURVEY DATE SINGLE SHOT FEB 1970 SURV~ W J. PATTERSON aNCHORAGE ~r PHIl I TPC PFTR{"I F~ ,CC ~ lc~' - ........................... - - - ~ h~EL ~C~PLFTIEK p~ PRFPARE~ BY ~CS 3/'2~__- ~--~. ......... - T~ C__~__ S____0JL ........ _1_2_4 -_9_9 Zi._99_ i. 6_95 ....... 2_._73 l~._ 5---zO __S __3_G_.. 2_1_~ ....... _0_~ 66 C !5'---K_XC_E lqg-..9~9____~AS_.~g t_.585 2 7__1~ 5..33 S___31Z~l._h p_,_ 1~ ~ ~ . -- ................. -- - -~ ~ .......... 1_7__~._9~ ....... 7A._~.~ ............... 4 525 ......... 2.62_~_ ~--23__S___3_C _. C_P...b__.. 0 25!.. $ ZL4_E 19 9 ~c19_ ......... _9_9 ._9__9__ _ A._86S -----_Z._iS.~ .......... 5 =.2_._B__$ ~..B_. 19½ .... ___L. 7_72 C !0' $ ~6F ~-24--qcz-- !74-__9.9__ ___ZL~Z2..~- 2.4~-W ~.~q _C;, 2_~.5~k' .... 1 C_ZCJ .... 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': . _. - "' . - -- -- SURVEY . ~ ' . ,... _. ,---'~%.~: ~-*~:: ~B N~BER. ,-'--:'"'~:,:--"-" ~E OF SUR~ ;::'-:"".. ~. AM 11'$469.~ '{, ~-.~ --' '~'~' SINGLE SHOT NOV-DEC 1~9 . ,' , t' .... ,, ' J~,h .~ ...... t.. ~ ,~. ,~ .~ DIRECTIONAL SURVEY REPORT FOR PHILLIPS PETROLEUM COMPANY CHERRYVILLE CORPORATION TYPE OF SURVEY: Surwell Gyroscopic Multishot SURVEY DEPTH: FROU .,. 381 --FT. TO _670o NCIU ---wE~ NO. A-15 LEAS£:. FIELD: N, or%h Cook Inlet (Tyonek Area) COUNTY/PARISH Kenai STATF.. Alaska DATE OF SURV£Y,, N°¥e,mb,er,,9' 1969 . ~os .o. SU-3-16536 OFF~C£:, Anchorage~ Alaska · ..... ? · . . . -PHI~ LL-IP-S--- CH-, E R R Y-V-l- L LE_CORP .......... A..----1- 5 ..... _NCI_U .............. N 0 R I H.-C 00-K~I N L-E I .......... ALASKA. PAG_E 1 __9 ~flVf_MBER I9_6_9 ..... S_URV_E_Y_D AffE .......... __V_E.RIiCALS_ECI_i_0_N CQEP_UiED AL0._NG CL._QS_UAiiL SP_ERR Y--SJJN_WELL_SUR.V_E_Y_iNG_C~ A N Y -~lJ-___3-1653L6 R E C_0RD ~U_B_V_E_Y TRUE__ M E-ASURED V_ERI-ICAL DEPTH DEPTH ! 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ZO0.O0 .............. =-.31.76S O.O~E ......................... ]. ...................... 0 Z~Q Z.- ............. 7~,D_Q.IIO ................. Z ~.0,0.0_ ......... ,-_3.9_._6_ZS_ ................... L2.._1 ~ 2 ] 150~ .................. ~50O._OO .... '/_~,O0. O0 __-'q~ o.q. 2 S 31.8bE ............... 4 ........................................ Z 760? ....................... 16QO.. O0 ........... 7500.00 ....... -<~9 .")2S .. ~6 o.50E .................... ? 3 7815 ............................. 780.0.00 .... 7.1ZOO. O0 ..... -Z~.[?3 Z05.OqE ....................... l~ ..................................... 7921 ........... 790Q. O0 ....... 7~0.0.. O0 ...... -98. IO~S 1.31..33.F- ........................ 2L BO21 J:lO. Ofl.('_O CL ........... I..~O.D_...Q'2 .......... _,.. LZ_L. ~,.S ............ _I.~D_..I. LE 2_] 6 B t35 .............. 8.100 o 0 O ............ 8000. CO ..... _-- ~.4 ? ,].45 .......... 1,9_ ~ ,90:' ............................ _3..5 ................................... 8245 ................. 8200.._00 ........ __8100.0.!~... -1'lq. ',LS S 227..2ztE ............... : ....... 4_5 ...................................... LO_ ........ B355 ................. 8300.0Q "'-~nO.,Oo. -Z~3 .:t"~S _262 Gg~ ~5 _..LO. B~6~, ........ 8/,_00,00 a.J~O. O0 -231. ::,3S 295.63E .................. 6~t ................................ 9 ............................................. (]57] ............... 85_QQ. 013 ............ ,~,~.JJO._(]O ....... ,-,,'59.5;'.5_ . 32~.2.0~ .................... 7.3 ............................ ~, 1 ._SbS ........ 3_:~..~. ~ 0 .8.1 8 1] ~ 8 L ....................... 86 O0-,.aG .............. 8~C 0.,_0-0_ ..........-_2 ' - ~- '> ' - ,B789 ............. 8700.00 8bO0.O0 .... -315.67S 8897 ............... 1:1800. O0 .......... 8_-fOO. O0 .......... -.343.3<+S 900~ ............ 8900.00 ...... 9111 9000.00 ....... 92[a ............. 9100.00 .... 3.89.2")E ......................... ~ 9 ............................. [l ........ ~tll..~lE 97 8_ .q' 45 · 0 L E 1 C ~ ? 4'/0.7'~E .................... Ill Z ............ -' ._ I,,, J: L L .C ,D ~ i' L t: .1 I ~ N. R. E P INTERP.CLAT~D VALUES FUR. ._VE,~ tO~J.FEE[...~F__SUB SEA..OEPTH :ASURED TOTAL C.UORD iNA. T E.S .................. ........ a.~.~ ..... ~,:~ ........ L A'[.I ~i- U[; E . E~EPARTURE ........... D J F E~R E~_C.E. ~ z~.3..1 ...................... 93.00. O0 .............. 9.200 ._O.O .......... -~ ~.3.63S .5~. 24~ ................. 1.3 l ~5 .................... 9500.00 .............. 9q-OO,.gO ........~5z,5.3/5 .... 58, Z.89~i ............................... 1.~ ~'ZSI .................... 9bO0.O0 ....... 9500.~0 ~.571.30S .... ~09.0~' _ .......... 151 ]~ ................... ~..,g.Q ........... 9.Z~..Q....&Q .......... ~.b-.] .... z.Z~ ............ bad .... 8 ~. ~. ]0~ ............................. 990.0,00 .......... 9800 ,_.0~ .... ~b62 ,.'1.5 S 669, ~9 E' ............................ LZ0' ] [79 .............. ~ 0.GOQ,_O0 ............ 9:9_00.,. 9_0 ...... :~70 [, ':~.~L) S 688 · ? [E ................................ ~:'l~ ~28_8 ............/QIOO.O0 ........... iOOOO. O,O ............... ~.7.~.0... ~l S .... 107,085 ............................... 18.8 ~']ga .................. I020Q,..00 ..... l 0 lO0.,.00, ........... _~ 1.8 L. 3JS_ ..... 7Z3 ,._~ IE: ................................ L98 JS0~ ............ 10]00.00 .... 10E00.00 ..... ,a. 2./, i~ ~ S ?3a,.9JE .......................... 206 312~ LO.50O.O0 ......... 10(*0.0.00 ............. ~90~..T6.S ..... 763,18~ ............. ~ ............................ 22 ~ Dg46 .............. 10700,00 ...... 10600...00 ........... ~g99,32S .... 7'~5,26c ........................ 2~6 1057 ................. 1.~ 800,_.00 .......... 10_700 ,_00 ......,_i ~ q- 6 ,g(~S ..... 718,3 5E ........................... 2..5~ 1.Z7._% .......................... Z L~.~,.~ ~ .... ~ Q~ 00 .- e 0 ....... =.LIA3~. 1. Z~ ............... [ 1.9..,.2 ~ 1~90 .......... llIOO, O0 ........... I 1.000.. ~ ...... ~.1191,.~2S ..... l~3,~5~ 290 t502 .................... t 1200.~0 .......... lllOU.O0 ......... ~[2qO.~S ........ 7b~7,I52 .... Z ............. 3_02 1121.. [l~O0..O0 __ 11300.00 _=_13~3.0)S 7~.1.80E ....... ....... ..................................................... ;,-; E.-L-L C LI ~'~. P L. E 'T I C ;',,i R E P. C___R T ..................... P,,~GE.:-,_ __I_._. ..................... ~,.,., ...... , ................................... INTER. P..EL,.~IEE....¥ALUES .FOR_ E.V~.,hl 1000 ..FEE].._ QE._MEASURED ..... DEP_TH ......................... ~HILLIPS PL.I'RQLLUM C.[I. A,t~ ¥,i~2LL CL1MPLEIJ~N R, PI PREPARED J.i ~ .... IVD SUb ~t=_,~, LAI'.JlUL'.i~ .~ lURE D[FF. ER. ENCE (1OO ............................ 1999.D. 0 ............. 18.99.0.2 ........... =21 ....4iS ......... -.tS 65~ ............................... 1 ............................. I000 ............................ 8896. OO ......... 87_96. O0 .............. r369.., 4.8 S ...... 44. q. OOE .....................~.~_~ ............................. .... ~ )OOQ ................... _9834.~0Q ................ 9J3~.~0 .............,~38 56S ..... 6S7,8Z .........................165 ........................... 62 ............................ ~ '- ~OOQ .................. l_QT~8..OQ ............ I_O.64~..:G 0._ -1022.70S 1.7.'l..~. ~ ........................ :_. 252 ........................................ ~OQO .................1~633.00 1~.533, QO .... - 1~7.~9.. ~ 1S 7~6.22E ............. ]~7 .......... ]. t _r _ . VE]RTI~N_ E~TID~ LL UP Ii' HYDRIL GK I ' SE.R;ES ~o0o % RA:4-TYPE BOP SERIES (SL1NO RAMS) S.RLC. SPOOL SE~IES RAM-tYPE BOP.SERIES - (P!PE RAMS)'. OP. LG. SFOOL ---- PIPE FI.AI,IS Ch&KE MANIFOEO. Q. $" SERIES GOO VALVE SERIES-600 VALVE 2" ~,fUO R.~_.~SURE GAUGE O~t SERIES ~0o STEEL TEE a'~ SER~ES~Oo x z" 'SER~ 600 STEEL CROSS '.- Z" sEInEs bOO POSiTiVE CHOKE 2"'SERIES' 600 AOJUSTABLE CHOKE . PH!LLI, p.s PETROLEUM COMPANY PRODUCTION .OEPARTMENT . . 2000 P.S! WORKI,~.JG PRESSURE. f3L. OWOUT PREVENTER HOOK-UP ('SEI~IE~' 600 FLANGES OR BETTER) TI':" ;.'" .~';' ~' '"' .... '--,-'i.,:... ' ' .- I · :2:t,::.,':.!-L',, :'"-.:': :'~:~L,:":- ' .- . -o CHOKE MflNIFOLD FOR ' DOU[~I..E PR[-.'V E N'I' E R S 4" SERIES~ 1500 VALVE 2" SERIES 1500 VALVE .- 2" MUD PRESSURE GAUGE 0,".~ 4"X SERIES 1500 S'FEEL TEE CROSS ISOO POSITIVE CHOY, E 2." SERIES 15OO ADJUSTABLE CHOKE ('~ 4" SERIES 150'3 X 2" SERIES 1500 .. ~ S'T E'E L : PHILLIPS COn',F'ANY PRODUCTION D EPA R T i',/, ENT 5000 PSl \:/OR,(IN" ' o PR,-_..aunc'. BLOV/OUI' '~"" ,-',~,:v E,~'i- , (SERIES 1500 Ft. ANGZS OR BETTER} Double PrevenLers are used vrith f];ange~ side 'outlets for choke lmanifo].d an:t fil].up line connections.. Form P--3 H.EV. 9-30-6 9 STATE O'F ALASKA Submit "Intentions" in Triplioate ~ "Subsequent Reports" in Duplicate OKG OIL AND GAS CONSERVATIO. N Co,MMrrl'EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION 'FOR ~]/iR~-v~iT~-~' 'for such 'pi;o~)osal~.) O,L g oas WELL WELL OTHER 2. NAME OF OPERATOR Ph/~]~ps Petrole~ Company 3. ADDRESS OF OPERATOR .~15 "D" Street, Anchorage, Alaska 99~01 4. LOCATION OF WELL At sur£ace L~g 1, Slot 3, 125&.1' FNL, 927.8' FWL, Sec. 6, TllN, R9W, S.M., North Cook Inlet, Platform "Tyonek" Too of PaY: 1281.3' FNL, 916.5' FWL, Sec. 6, TllN, Rgw, S BH.L: 130&.&' FNL, 902.2' FWL, Sec. 6~ Tll~...~ R9W, S.M. 13. ELEVATIONS (Show whether DF, RT. GR, etc. RKB ll6 i From ~ 14. Check Appropriate Box To I,ndicate N~t'ure of N~ti'ce, Re 5. AP1 NUMF.,EICAL CODE API 50-283-20032 HWK ._ 6.LE~E DESIGNATION A. ND SEB. IAL ADL-17 589 ---------'""-- 7. IF INDIA.N, ALLO'i-rI~E OR TRIB[~'~.!VI~-~,~ I 8. UNIT, FARM OR LEASE NAME ' North Cook In,et Unit 9. WI~,L NO. #A-12 (Formerly #A-15) 10. FIELD AND POOL, OR ~VII_,DCAT North Cook Inlet 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) ,Mo See Left 12. PEI~IV[IT NO. 99-99 NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPL[ COMPI,ETE ABANDONs CHANOE PLANS ~Other) ~o~, or Other D~ta r FRACTURE TREATMENT [_~l ALTERING CASINO 8HOOTING OR ACIDIZINO ABANDONMENT* (Other) {NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. In order to have wells numbered in sequence drilled, Well #A-15 is beLng renumbered Well #A-12. ~ ,,,- ' '1 (This ,pic~ for State O~ce~)/ ' . I .--~, CONDITIONS 0F~[PP~OV~L, IF A~: ~' ~tU,,'~ ~ In~rudions ~ Rever~ Side District Office Manager DATE June 23; 1970 JON2 4 DIVISION OF OIL AND GAS ANCHORAGE CHERRYVILLE CORPORATION · 100 Security Life Building Denver, Colorado 80202 TRM OKG ~LV May 26, 1970 State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Phillips Petroleum Company & Cherryville Corporation No. A-15 Well, Section 6, T-11-N, R-9-W, S. M., North Cook Inlet, Platform "T¥onek" Gent 1 emen .' This is to advise.that Cherryville Corporation has conveyed all their right, title and interest in the captioned well to Phillips Petroleum Company 'and hereby request that they be relieved of all responsibilities and liabilities. lease reflect the correct ownership of the captioned well in the appropriate~ ~....reCords. Very truly yours, GGB/jw cc: Mr. H. W. Patterson Phillips Petroleum Company 1230 Security Life Buildi.ng Denver, Colorado 80202 CHERRYVILLE CORPORATION ;/ ~ Form P~3 ~ REV. 9-30-67 · SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this £orm £or proposals to drill or to deaF, eh or-plug back to a dif£terent Use "APPLICATION FOR PEE/VIIT~" ~or such proposals.) 1. oI~ Q GAS [~ WELL WELL OTHER 2. NAME OF OPERATOR Phillips Petroleum Compan~r · 3. ADDRESS OF OPERATOR ~' . 515 "D"" Street, · Ancherage~ Alaska 99501 ~r~a~e Leg 1, Slot 3, 125&.1' FNL, ?27,8' FWL, Sec. ~,~?. TllN, Egw, ~.. $.~,, ~North Co®k Inlet,. -?iai fermi: T.o~ef pa.v: 1281.3' ~.FNL..,~. 916.5'; ~,. 13. ELEVATIONS '(Show whether DF, RT, GR, etc. j · ~B 116. ' /. .Prom. Mi~W . ., . APl 50-283-20032 ~UV ~~ HWK No~h Cook I~et U~I~~ ' -- ~. ~L NO. , . ~ ~.. , , · , .... 11. SEC.. T., R.. M.. ~(~M .- ":' .':; 69-9~ "'' .... C~ck Appro~iate ~x To I,ndi'cate Nizture of N~ti'ce~ Re ,o~,. o~, Oth~ ~t~ NOTICE OF INTENTION TO; FRACTURE TREAT MULT!PL~ COMPLETE SHOOT OR ACXDIZE ABANDON' ' REPAIR WELL CHANGE PLANS ~Other) WATER SIIUT-OFF.~:'; -,~ ' ..... -, R~PAIRINO WELL ":' '[ ~ i~ ALTE'"NO FRACTURE TREATMENT SHOOTING .OR ACne'ZING %b ~ ABANDONME~Te see ~1~ (Other) ' (~OT~ :'Report results 'of mulflpl~, eomDl~flon on Well 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, .including .~tlma.t.'~d date of starting an}' proposed work. ~.:' ¢:, ' ..... 5 ,- Temporarily Suspended. ...... ,.-. '" ~ ~'~ ~r,._....__..... ~. :' ' .. '7' 5-2/3-70 ~H, .~n CBL 6.9~0' - 1~0'. ~t E-Z dri~?;cement ~aiher ~t 6~3". ~ueezed 2~ sx ~ "G" c.e~n% w/~FR.2-'~be.l~.~cke~;'. ~'"13 sx on'top 0f plug. ~. heldi~ press, ..2~;~ ~Ss. tez~d cast~,: O.K. P~l~ps assmed ~we~ for compl, tien ~s: g~.s ,~:~; t.:. 5-i/n-7o. mn i~" & ~ombi~tion,.~i" & ~" d~l str~] tU~. ~*~er le~i~,'. tub~g ~rz~s,' set at 3501'. ~hll' Vai~s~:'.se.t ,'a~'.'~29~ ~ 261'. ' Tempo~rily .Sus~nded. : :' ?- '~'' " :'~; ~:. ':' TITLE Dist. 0re. l~_r. , DATE May 12,-1770 APPROVED BY CONDXTlrONS OF APPROVAL, IF ANY: TITLE DATE See lnstrucfions On Reverse Side Approve"] Copy R.eturr, od 11,134-35~ 11,135-36 11,136-37 11,137-40 ~H I LLI ~'C HE Iq~YV i'L I2~' CORP. ....... ~A-15 N.C.I.UNIT copz #1 11,134- 11,168 Cut 34' Recovered 22' Described by C. R. Seewald ss - it gy, vfg, 'slty, clayey, mod hd, calc, SA, mod srtd, poor to fair porosity and permeability, qtz, feldspar, abdnt gm, brn, and blk rock fragments, tr mica, abdnt buff to wht soft weathered feldspar, uniform pale yell fluor, free pale yell cut fluor. ss - As above w/sctd coal fragments, and thin carb laminations 1/32" to 1/16,' thick. ss- it ~y,-f-rog, sctd pebbles up to 1" diam., 10-15% clay matra, poor to mod sorting, SA-SR, qtz, weathered feldspar, green & black rock fragments, friable, good P&P, ~.pale yell fluor, free blue-wht cut fluor. ss - As above except sli calc, less friable, yell-gold. fluor, bleeding pale yell cut fluor. ss - Like 11,136-37 above. . 11,142-44 11,1&4-46 11,146-48 ss - Like 11,136-37 above, except less friable w/20-25% clay matrix. ss - it gy, f-mg, io-15% clay matrix, poor to mod srtd, SA-SR, very friable, good'to excellent P&P, pale yell fluor & cut fluor. ss - it gy, vf-fg, sli slty, 20-25% clay matrix, SA, poor to fair P&P, poor to mod srtg, pale yell fluor, streaming yell cut fluor, thin carbonaceous laminations in bottom foot. 11,148-49 11,149-50 n,150-56 11,156-62 3.1,162-68 .clyst - dk brn-gy, mod hd, slty, sli sdy, carb, w/blk carb ~'Streaks. ss - Like 11,146-48 above, w/abdnt coal fragments, coal .. laminations, and some interbedded coal. Not recovered? (Ground up sandstone & small shale fragments at ll,150 indicate some core was lost here. Probably mostly friable ss on basis of coring rate.) ss - it gy, f-mg, friable,-sli slty, 10-15% clay matrix, SA-SR, mod srtg, good P&P, qtz, weathered feldspar, abdnt black rock fragments, sctd Coal fragment in bottom foot. Pale blue-wht fluor & cut fluor Not recovered? Probably tight sandstone or claystone on basis of coring rate. 11,13A-35 11,135-36 11,136-37 11,137-38 11,138-39 n,139-~o 11,141-42 11,142-~3 11,1~-~5 11,145-~6 11,.1~6-&7 11,147-~8 11,148-~9 n,1~9-5o ~ 11,15o-51 11,151-52 Corin~ Time (minutes per each foot ) 28 minutes 12 ,, 26 ,, 29 ! 14 ,, , 13 " ~ 12 " 13 " 14 " 14 " 16 " 15 " .... -~--i _19 " ·17 " ll " 9 " 11,152-53 11,153-54 11,154-55 11,155-56 11,156-57 11,157-58 n,158~59 11,159-60 11,160-61 11,161-62 11,162-63 11,163'64 11,164-65 11,165-66 11,166-67 11,167-68 16 minutes 13 " 18 " 20 " 18 " 19 " 18 " 15 12, ... 12,936-37 23 12, 93~39 ': .;' '. ;',':.2,' ?' '. ;; ',~'?'/'",,'.,.:;h"-'!~?:-~l~:~."[' ........... "' "';; ,' '., ,.,"., !,'.:.':'.61':::'t:' :;:i;. , ' ' ,,: ~ ;",.';'::~',,,": ~ .' '- ;". :': ~' ~i ':", .:'Y~",i: '2 ~, .' ':-'.t:'. ' ' ..... ,. :,, ;., ,~; .] ,;,,: .. - ~ . . . .,.~.,,.~, :. , . , .: .,~,,[ ,, :'. '~ .,. ,'-~, :'t' ':1 [" ',. ;.'L "'.' , .1 ~'/:' ;', ...,~, i.' .:.t '~',' ~,. :.: .~:,':t'. , ' '1' .: .," , ~ , ', ~ .' , ':¥': :' - t - ~ ~ r C 9 - ~, ' ~ " - ' ~'~" ~ ~',",'" .";' ' :~' 2.'" L;' .J' ["~: ,:)' ,~ ...., neff ~..L amr.~. , s].: ~.P].. ~ ~fn-.fn~. s~ban~.., ,.,:; .... ...,., ..,.,.?.... ~ ,,,: ..... . - ~.~ ~ "(~ ~ ~ · ', ; ,.'-, ;l.."x' ,".', .... :,'. ~..~, ~,,,,c, , m).-.., car .... ]0.o wh. cia ........ ' · .,,",.... ~ ' ~ "' / -' , '" / ' ~' (Ifa].onite?), s!i. ea.]_c,, p~. por,~ , . 'I /. ,1'', ~ 1. ';; ':. ,i ~-' ;' ;, , . ' ,,~ a,s above, no show, . '~ , ' ' ' Nd. ~ cla.v, no snow, ..' t' f;'~'' ',~'.'[.': ': ':;.'.'.~>,'?.'. '.".- ~ ~ "1- ~ 4 ~ e ~ ....'., '~ .: : v c ...... ,, (r~.~:~o,,zue 10;u), hd. ~/ght, so. 'l~.."~elI":.'.?}i-".:?.'i:: ~ ~ ~ ' , ...... ~.; .... o~, 1~, yezl wh cut,. pr. s~ow. ' z ' ' , ' , . '. -~ ..q ','. t. ~ j.. ~ ,,'~.. ;,'.. (,' ,'_ ' ss. reed it g~, sli fri,,, ang,.., tn-meal". .gr"'; ..........., :.,',' .. :. ',,':,,, ;.'b~ :'..:.. , .,. -. ., . w/widely', scat,, subrnd g~anu]..e~_ ,...~ ~ai.r sP~d.'~ "",n.:.{~...u?~':-.,:' wh a!ay a:~' sd pop t,r. perm. dead oiZ~'~-. ..,. ~..:::~.. hr. yei.! rltm~, hr yei]. wh cut, fluoP~ zell '." ....... : .... "; ,? ........ ~ .... ~:, (,:~0~, ..",. ,', .' ::H,'; ';';~-~' ' ~s, It grv: firm, aha,, fn gr,, w/srtd,'"':[..:,/'.'("~:{: carb.~ mica, w:h.c]..ay 8~, f, por., tr y'cl! :libor, no cut. 'pr show. . . :{'-:'.'2" ',":':' · , , : ,'. ,: ':..,. -,, ,.., .,.,~ .-'.. 2..:.~r., _.,,. ss. It. gP,',. ~].:. fri, ang. fn-med gr;'~ s~}brnd~rnd ~,bl~ priy srtd , m~ca. ~ oarb,, .... . ..... ,, ;. - .,_ ......... ~ ~2 s ,, ',". yell f~uor, dP, yell wh aut, fl.tmr, yeli'.'~':' f- ~1~ ~+ , : . . . ;.., .~' ~ · ..... . :': :.-- ~%:,' .... . . ,.. i". 'i" .i .,' .. ,,:. · ' - ' ' . ' '.~ h.:'.i ':i 't. : ~' · ':,. '.."."~; ;' ": ~ ' ' ' ~ ', '~' ' : .... ~ ,':,'.' .lb :'~ "., , ' .,.-~.. o ..... c ....., c~:.r ..... ~ m.~.ea~ wh el~M 8/~'.:~;..; ......... ': :.:- · per.. zce~t,, Ii, yei]. ~.1~..o,~ lt. yel~.'Wh',"~i~.'i,..;,,.~..,, ~...,'. c~d' r nhnw ' :'.:.~;.,.:'.:-.., . ;'.{{2',.'.'.' .' ..... P ............' ss~ It, gry;~ sli fri ""'"' .....' ...... :'""'"":"'" ~ .' , ,ubang, med. gr. w, wrt, d., carb,?, tr. m~.ca, wh.' clay id. ~o~-,; It,, ~,'e~] wb f].uor,; no cut, no SHOW. '"'}": ~;'' "j::.:':?,'.:,'3 ';'.. :;:','~ ; ,.:/,:. ,, :, (,. f....j...,?. ~. ss t ]_t,. ~V. ' ' ' :" "':' ~:':;"" '"" ~':""' '~'~ ' wh e,,+ Sc} sh. ow , .u, ,~, ] t,, ~r:m~,, fri, subang-subrnd, - 'S ' · ' `'''} ::'" :::"' .{'' 12,946-47 ]..!. 0 ~in.lft !2~ 997-A8 '~" 9.0 12,949-50 19.6 mim/P.h. ].2, 9'5]- fi~ 3.; ~ min/ft ].2,95~-53 s. 3 12,953--f/4 8,8 mitb/ft', .. 12,95/~-5~ r:. p, min/f-b 12, 9~f-~6 12,956-57 ' - 12, O~o ~ 12,959-50 12,960-61,2.5 6 O .... n/_~ ..- ~, 5 re:tn/fi fi. ~ mn/f,, ,, ~,~ . ..~ .' , .~ ,, ,/, ,; '.;,, ,.~,, ,, %' .... : ,~;~,~j~,- , · ~ . ' , . ',"' ,; "," ":"'~ '~' ,, ":.,h '~;' 'iI'? . ~.~.~ ' '- ' ~ . .. , ,,' .r-. ,~.,,. ~ ,:': '~ '~'h'" ,l .... .~'~'%~;.,':':b . , . ' "' ' ' " ' "~ ",', ,':' ~.i" ,~ '/,~ ':~ ) .. . .. e~ . / . ~ ". , i ' ' ~'. ' , ~ '~ ,,YH, ',~: :.-", f]mor, v. it vel.! wh tnt fluor, pr.. .' :.":J,j ' ': .;": I: U.L ?:J.)'~ ~!.:'~ . ,.'.:;%.~.~ :,-.. ,..~.,-~ a.s above, brite, yell fluor, brite ']~ell"';'. wh flmor c~:~,, Me]_l btm. cut, ].t tan Stn";'S?Z2,' '"' med. q t gry ali ~r.~ : fn-~bl mm) pr].y srtd, subs.ng-rnd; a dnt blkC' 7,r,st, gl'S?, %r mica wh C] axr ~o/f--~c] n~ . - ~ .. above. as above, w/sharp contact gd-fr. Sh. , :. t ?.~ ,, % ss.. as above, scat. brite Yell ftuor,:.'i yell wh cut fidcor, pr-.~, show. ......~°, as above, ...... ~nc i.t~ pbl. grs, (40%] ye]..]...f!uor~ faint wh ctrt. fluor, pr. show;....i' .ss. as above, dec. phi., grs .].02~. show a}P OVe. - . ., ~ '.,. t.,.t~. :.!~t-' ss. as above, ].t.-gr~., sli fri, ~.~a, . ~ ,~ -~ ] o . . o_.,,., ,,..:,,,:,.,,~.:,-~'p~.,:.., e~yst, Mg-$, ~.. pr!~. srt, a., wb czar 8~, :':t~d;'; pr, snow, ' : .. ; '.' ,:v:'},{:', ,',, '., '.? ';'.';,,::~'/. {.'.- - -", . ~ .. ' . .;(' fi/,:,..', - ' ' . , ' ss~ as abave~ meal ~r w/wzdeZy 'seat. ~b].s.','?.;'. .... Z-xzd. srt, d.,~ show as above. , , , "' , ,.:?,'.::,:~..:': 'h,:':::':":,?:';~.':~:, f~--~e .,,' ~k~.~,...., .:....,~:. ~,.-. t.. ,,..-. ' subrDd-rnd, c-sbl, pr~v srt~ ~ blk' ~rs a's';::." s, oove. wa c]a.'v 6.~',~ f-~d. pot . show as , :,...., ,.:.:.,. s, b'it ,.,~zf,~.~v~ql~-~- .... wh cut Z?.uor. t-6d. show. -. b: .":' :' .{.L'. ':7 ":".q,:: ",...,.".., f. pot, ~ ~+ ~' ~ ' ' "~ '" .... ' ' ' ' op .... ~,:~ b~zt, e yell fl.~mr w/l~,'P'.:.. Nell wh c~d' ¥~.~ ~- w. . .,L' ,. ..:.':. ,,,:::,'::"i'.' ' . · ..' , . ,lq '.{t:.', ' ., ' ; ,,', ".,, :":-.~::.¥~./, - .,:.-' - . . ,., ., ~ . , ~bang, med-c.gr., fazr.:srtd,~..,.t,;~:.?~,..:....},..,~...' .z-:t, veal tit:or w/reed yell wh :gut t~uor; s h ow, . ss, a.s above ~d. pot, show as abo~e,"::~:.k:i.','::'.,':':/. "', '~ ".{ "3, '~ ' ~' ' ' '" , ~ ~ ~ ~ ab ore. :' ' :- ~ ,'-: ~', '"~ ',.::, ;.i',, '. '.) . .., .:..?.." :: ,' ", -,, .-,.., " ' " s~ as above, w dely scat, s. :'.' .... ' ~¢ ~ ' ¢ ' · . :. :.,.'~:..::,.,-.,.. . ,' : -. ~n-med ¢~, p~!Z st'rd.., akan5 bZk ~rs _. ~ o~m · , , '¢ ])OV~ o.~01< &,..~ aloovo. . ..... ..: - .: .': ..~ :':, .:..'..: ~::~'_.' :.. ,. , ,- ' . -.,. . ' , . ............... vfn and md. 9bls (t~? to 30 mm) -'i ' ' ~ ~ ': ': ' · ~,b}_s, qf, z ...pbls~ ), s~ow as above. ..~..~.~ 2 96~'6~,... ~.~ .. ~ 10~~.,~ ,.,~.~ ~,/m'~. ,,, ss~: !t'. ~,..~,. sli fri , ang-subrnd[, ..... clay, f, pot., it, ?i~ ~d~ fluor w~faint.'.~ ~ ' wb cut fluor, pr-~o s~ow. - ~; ~2,q6/...-6q.,75 '-II,~~,~,~n/~, ~. aa as abo~e w/scat ].argo pbls.'":Up'::~'S'~O a* ' y'ell wh fluor w/It yell wh cut: fInor 12, ~&~,,~. ~,~-,.,, ;'~ 6.'~ rain/fi .... ~,, as aioove~ w/coal laminations ].2~66-67 7,& mln/~.~; ss~ as above (63-6~.7~), gd. ~or,,.,s , . :. ,L,..~ . ~.,, '~ -r.m . . :. '..:~ ,, · ,.,. 7~,' .-~', ' ' . . . ~ ;J '-,,,/ .. , ' ' ' .' · · ' ' :" *',",'f.'; yo ¢-~b ..... / -~.n/z~ s~, &s above~ g&. ~or., Z~-med yel]...?~.o~*'.':; ; ..... ' ' w/'brite vela wh · ¢luor -' cut.'_, it tan "'s~n,. ' ¢ ~/ '-'~ ..... .~ '¢, , ~ ' ".:' ,'~,/';.,';;t .' :',' ' '- · . .' .-.. . " .' ' . . .'~' 12. 968-69 2.2 min/f'~ ..... , ' ' ' ', . · ..... ~ c~o 8.bc),o~ ~. S~O~. ' . ' ','~ ..'-":':',~,',.'"~",'."~ ':'.;. :' :':~:"~:::'. .- ~,, _ ..... ss, a.s above, ~,/wid. e3.y scat. ' - a s 8.t)o%~e, . " ' : ' ' . '. ' f'?-',,.: '--:'(' .': ".:",' t.,'. ::)[:":/,.,:-.,? .. ' :', ' ' " ' ' · . '.,. . . . :',:,'"~.'t., '.' ,)..":'..,i..¢.('::'.'~ ~'? '.; . grs~ pti? srt, d., bloc coal & blk Cl~st ~ ~ ~ ' '~r'~ r~ ~r ~':~/ ' ' "' /"' *~ ':"' ""~ "::" . a.b olre. ' ., :: , ,,,'; :;(",:,,/::~: . , ·. , :- , ' ,r: ,. %:. :,~., · ~,t,. ;; ,,:.,.~.?.~.., .'.,. ,' ' ' ' , , '~'., i.'¢,f;;,.,' .'~,;',,,' ' f.1 ,'.,.':' ':.'.' ' ,,,,, ......... otc, wa clax 10o r-f. OreI ,'' .... ', ....... ' ".-':":" , ,., . ~ - ~,. p. P &t yell wh fl~mr, 'bt yell w~ cut r:~r_ !t ?e]..l wh cut fl~,~or, pr. :sho~t;'")'.':~;::':','tt':';:,~..~:~'.';?:::?. , . ( ,,,,, ':. ,,'..:;' ,,..., , .,,, t ,'.?,,. ,.j,:~.,:/ ,:'"f?O ' 12,973-74 ~ o "'*~/f'b ~s ~. , . . .. . ,.,:..,,,,....:.,.:..,,..~ .... :, .... ....,:1. .... a :ove, bZs (30¢);' ",' "-~'" ~ ..... ~ &~ ,:..]~0~ e~ . . .. ....... , .. .... ...,.~.., ......... · ' ' ¢ ....... ~'o~ . as abc ,e, . .' : . . ..: ~'?,:;,.¢,-, ':(:'v.::~.".,r'v~¢,..f;t.'v~......:,.L o 7 ~q , ~lir~/'f~:, ; . ,. ' ......,.~F".'".." ": : cgl,,..It gry. hd.. ~.~ cmt, wh: cla~r.~'~:"':l~,.-'?',.,-";~::"?~';~:'~(.:?~'?''::''::' e-cobble grs~ tight t,r fl., no cut,,.~'n'O":'~sho~ ... -. ~.,,[ . ,...' ,-,. * February q~ n ~-~ t~ ', ",f','" ; · A¢~C~O?AC;~,,, ,, ,,:,-.:, .., ~ . .. . ,, ' .. . .. '[ . . .............. .... . :, . ( .. - . . . . .... . , -!i/":~' (~jj.U:~.... ~ [". '[~(.~. ~i(~.~?i~ i Cook Inlet, _Alaska . ~ . . , SIDEWALL COP~-. DESCRIPTION... . · ]2~,900 '(3/2").-'( ~:Shale -'brownish-black, mod hd, carb, contains' thin coal laminations and small coal fra~ents. 14,86A-:. (3/8,,)/.] . Clyst - ned ~' hd.~ blocky, bent. 1~,848. (1/2")~.-:.."ClYst- ned gy," soft' to' fi~;' '" cr~bly, contains thin coal ' '" laminations.and small coal fragments, bent. · '~ ~: 1~,802 (1/2"): Congl..tuff -. blue-gm, soft and cr~bly, 60-70~ tuff w/floating ~ebbles to 1/~" dian and cg sd Pebbles" ~ :..~ ~.: : . ~ ,. .,. g,., gy-grn, .hard tuffaceous or s~l~ceo~.. 12;778 (3~R''). :'~..:.Coa1 and sandy tuff -'80% of~ Core is c°al.- blk, shiny,' soft 7. . ~:~ ~:~:.:'. '['~ mod-hd, c~mbly; rest-of sample is s~dy tuff which is '.~) .. :" .':'.:~':~.[: bedded,.' interlaminated and .generally intemixed w/the coal.' . '~' "~j ':" :::.. Tuff is light tan, light gre~r, and gm-gy, mostly Soft and ".'. :'- '~ ~:." trebly w/~e hd, SiliCeous t~ffaceo~s materisl. Tuff ': .'.: 10'20~f-vcg sd' (qtz, chert, and dk rock fragments). S~d'.' -/ '-:'~.~ ' ')~' .'7 grains are ~and. om].Y scattered throughout t~e tuff ~,,~ 14,765 (~/1~,,)_'..~ SdF clyst 2 ].t gv, bent, Soft, 30'20~ vf-rg sand;' sd ' ' "' ': are qtz, g~r chert, and dk rock' fra~ents. - . .. .: ; . .' "· .,' · 1~,722 ~ t' :.. ~led off. ' ... · .. ~ . . .j ..' ., ., ; ~',..;?~.'?' lA,711-? : ' ' Pulled off .' .... 1~,708 ? [:" No recovery. :" · :. ""-;:::':':~;:':?'."*." . :. e ,..,.,. ~a,6947(~/~,,) -(~[.Shale ; bromish-blk, mo~ ~a. carb., sct~ small co~l fragments ' ~ . (Looks very simil_ar to 1~,900' core). 14,6657(1/4") :'.... ~ffaceous congl- med'gy, fO% qtz, chert and ign rock'~bble~' (I/4" max. diam. ); 10% sd of same composition, dO% ~ and g~-grn, c~mblTf tuffaceous material. ' ' i : ..~ '~ 1~ 8~?'(1/~;',) Clyst-'ned Sv. mod h~, blocky, bent,, abndt sm. ' ..... ' ~ ,,. coal fragment 1~,590 ?.: '. ~lled off, ' ' · ,' . ' : "' :",;',',/;~',~.:': 14,5677(1/4")''[' sandy. clyst - Dk gy, bent., mod hd, AO~ vf-mg sd :(qtz,. c~ert,.,:..~.~..:?.......~: ;.:.,.,..:. ' . .':'-:.. ~ ::and dk r"ock fragm~'~'nts). "' . ' . '.:.:.:. 12,~8 ? ".:':' :: ::.' No recove'~. ;" :.~.'.~ -, ~; 12,~0 ? ' ' .:' N° recoVerY' ~ ' .' ~ i' . .......... ' " ~- /~,~C~'~O,~.i~e.~-. :'..'~.[~,... . ........... .. No recover~. ' ~ . ' ~ "',.:.' : ..... "./([ 14,3767 (1/A") .~s - reed gy, vf-fg, ~0~ gy bent.' clay matra, poorly' srtd, SA-SR, ].o~'P&P, 'o~ed. otz and chert, w/se blk and grn rock fra~ents~ coaI ~ragme~ts and tr mica.' No Show. · " ' ' ' "-:':" ' ' ' , " ~, ~" :' ,~' b,' lk 187' ? ' ' ~ ' ; :'"?'~' . . . ,' . ,,, ' '' · ' '' , ,:.- "'i',. '~j; : ' .] . ', ~S,2~07(~/~") VeW'clayev ss - reed ~, v~g, ~SO~ ~ clay maZ~",' fire." abd~t rounded cinnamo~ ~ro~ grains, se dk ~rn grai~s. N~ ].2,222 ? ~ -.~ Pulled off.' '"";';:" . f~ ~ -,' 3.2,060? (S,/8") Clayey ~s _ 1-t ~r. fg, 20-S0~ ~ bent. clay matra, SA-SR, '.'[:).~;~?,:?(:[~?./[':"J':[; poorly srtd, 1~ ~&P, friable, '~red. qtz. ~/se chert, blk grn rock frag..and sand size coal fragments, brt yell fluor. ? · No recovery. : . .. ~ ~ ': 'I '12,047 . NO~: As indicated b~ (?), some of the depths 'at which SWC's were taken are ,. Uncertain. The Schlumberger engineer stated that he fired 27 shots, : however, when the bullets 'were ~emoved, he found that all }0 b~lets had been shot, Apparentl?' some shots were double shots, but Schlumberger could not dete~ine which shots these were. Because of the poor core . recove~ the correct depths_ of most recovered samples could not be ': ...... dete~ned with certainty. . .. C. R." Seewald ' . ~.~rch 17, 1970 Form 1~. STATE O,F ALASKA Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION ,COMMITTEE . SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PER1VIIT--" for such proposals.) 1. 0IL [-~ OAS [] WELL WELL OTHER 2.NAiVIE OF OPERATOR Phillips Petroleum Company 3' ADDI~ESS OF OPERATOR ~ ~ Anchorage Alaska 99501 515 "D" ot~eet~ . , _ 4.LOCATION. O,F WELL Atsurface Legal, Slot 3, 1254.1' FNL, 927.8' M~, Sec. 6, ' T2.1N, R9W, o.M., North Cook Inlet, Platform "Tyonek"' Top of Paz: 12~1.3' FNL, 916.5' F%IL, Sec. 6, TllN, Rgw, s.: BH__L: 130~.g' FNL, 902.2' ~".fL, Sec. 6, TllN, Rgw, S.M. ~3. ELEVATIONS (Show whether DF, RT, GR, etc. !5. API NUMERICAL CODE OKG ~ o- s -2oo 2 s . nv $. LEASE DESIGNATION AND ~.~ ADL-175~9 ~LE ~, 8. UNI'r, FAI~VI OR LF~ASE NA~V[E North Cook Inlet Unit 9. WELL NO. #A-15 10. FIELD AAN-D POOL, OR WILDCAT North Cook Inlet 11. SEC., T., R., M., (BOTTOM HOLE · OBJECTIVE) See Left 12. PERMIT 1VO. RKB 116' From kff,Ti~ 69-99 · 14. Check Appropriate Box To [nc[ica~e N!ature of rCoti'ce, Re )ort, or Other 'Data NOTICE OF INTENTION TO: FRACTURE TREAT j j MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONS ' REPAIR ~,'ELL CHANGE PLANS (Other) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state ~11 pertinent SUBSEQUENT REPORT OF: WATER SHUT-O,, ~-~ REPAIR,NG WELL J 8soOTING OR ACIDIZINO ~ ABANDONM~T' J (Other) ' See Below (NoT~: Report results of multiple com~letion on Well Completion-or Reeompletion Report andLO~ form.) details, and giVe pertinent dates, including estimated dste of starting proposed work. Re-enter well, run Cement Bond, Log, set cement retainer at approximately 6850', lay 300 sx cement plug Fr 7110' to approximately 6830', test casing. If casing tests O.,K., Phillips can assume operations and proceed to perforate and squeeze any zones dictated by CBL follov~ing positive tests of casing after squeeze well. Run dual Combination gl,, and g" tubing string and temporaril.~z suspend and ho~d for future thru tubing completion as a gas well in North CoOk Inlet Field. (This sp~c~ for State q~ice use~ CONDITIONS OF APPROVAL, District Ore. Mgr. May l, 1970 See 1,nstructions On Reverse Side Approved Copy Retu,'ned Form No. RENU. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT [N DUPLICA~1E MONTHLY REPORT OF 'DRILLING AND WORKOVER OPE:RATIONS WELL WELL OTHER NAME OF OPERATOR Phillips Petroleum Company ADDRESS OF OPERATOR 51~ "D" Street, Anchorage, Alaska 99501 LOCA'I~ON OF WELT. Surface.: Leg 1, Slot 3, 125~.1! FNL, 927.8' 5'~, Sec. T~iN, Rgw, S.M., North COok Inlet, Platform "Tyonek" Top o£ Pay: 1~,500~ 1,]], /J+,O00~ TVD, 2.300~ From.South E~st' Lines', Sec. 6, T23~,: R9W, S.M. LEASE DESIGNATION AND ?. IF INDIA]~, ALOTTEE OR TRIBE NAME F~LE 8.UNIT,FA/:~ OR LEASE NAME North Cook InZet Unit 9. WELL NO. 10. FIELD A_ND POOL. OR WILDCAT 11. SEC., T., R., M., (BO'I~I'OM HOLIE OB,rmcu'~ Sec. 6, TllN, RgW, S.M. 12. PEP, dVIIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA~NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET A/VD VOLU/VIES USED, PERFORATIONS. TESTS A_ND RESULTS. FISHING JOBS, JLrNK IN HOLE A2qD SIDE-TRACKED HOLE AND ANY OTH2ER SIGNIFICA.NT ~ES IN HOL~ CONDITIONS. 3-27-70 7, llO' PBTD 3-1/3-7o L4,268, 3~4/16-7o 14,910, 3-17-7o 1~, 91o ' .3-18/21-70 Temporarily Suspended. Drld 8½" hole to 14,268'. Drld 8½" hole to 14,910'. Ran DILL I~g. Ran FDC & GR Log~. Took sidewall cores as follows: 1~,900', 14,864', 1~,8~+8', 14,802', 13+,778', 1~+,765', L4,722', 1~,711', 13+,708', 13+,69~', 14,665', 13+,635', 14,590', 1~,567', 1~+,538', 14,530', 14,~J+8', 14,376', 14,187', 13,256', 13,2~0', 12,43+2', 12,~35', 12,060', 12, OZ~7'. Spotted 75 sx Type "G" cmt plug w/CFR-2 13,650- - 13,850'. Spotted 80 sx Type "G" cmt plug w/CFR-2 13,000' - 12,800'. Spotted 80 sx Type "G" cmt plug w/CFR-2 12,$70' - 12,270'. Set E-Z drill cmt retainer 11,965'. Sqzd 90 mx Type "G" cmt w/CFR-2 below retainer and l0 sx cmt above retainer. 3-22/2~-70 3-25/27-70 Cut 9-5/8" csg @ 7,620' and 6,911'. Latched onto $-5/8" csg w/spear. Rec 176-2/3 jts csg. Latched onto 9-5/$" csg at 6,911'. Could not pull. Cut csg @ 7,300'. Recevered 9 jts& 2 pieces 9-5.8" csg. Set 300 sx T~rpe "G" cmt plug w/CFR 7,660' - 7,110'. Hu~ug ~½" DP & tbg in AHCHO2AG~ 14.1 hereby ce~~tl~he £or_ego'~'l~e ~d ~ sm~ /~'~/~=~ Distric% Oft, ~r, ..~ Aoril 21. 1970 , /l,' ,' '/ - ' TE--Report on t~is form is required for each calendar month, regardless of the status of operations, and must ~ filed in duplicate ~ the Division of Mines & Minerals by the 15th of the succeeding month, unless othe~ise directed. i St~e Of Alasl~a , Division of Oil & Gas P.O. BOX 21~7 · ANCHORAGE:. AI.ASKA * TRANSMITTAL Dear Sir: We have transmitted this date via Personal Deliver./, , ~,Tashed , .samples from theI Phillips Petroleum - N. C,. I. A-15 (4 Boxes) Intervals :12,000-14,910 Core Included Atlantic Richfield - Nora Federal 520" htervaxs: 11~ 090-17, CO;APANY _ March..26. 1970 Please acknowledge receipt by returning one copy of this transmittal. Receipt acknowledged Very truly yours, Remarks: F~rm REV. Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE C~F ALASKA OIL AND GAS CONSERVATIO,Ni ,COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug hack to a diffierent reservoir. Use "APPLICATION FOR PE~.~/[IT--" for such proposals.) ELL WELL 2. 'NAME OF OPERATOR Pht 11 !ps Petrole~m CompanT-cherryvi! le Cor~ooration 3. ADDRESS OF OPERATOR ~15 "D" Street, Anchora~.e~ Alaska 99501 4. LOCATIO'N. O,F WELL At surface Leg 1, Slot 3, 125&.1' FNL, 927.8' FWL, Sec. 6 T13.N, Rgw, S.M., No~..,h Cook Inlet Unit, Platform "Tyonek" 13. ELEVATIONS (Show whether DF, RT, GR, e~c, P~iB _116 ' From ~T,T.W Check Appropriate Box To I~ndi'ca~e Nlature ~ N~ti'c'e, Re FRACTURE TREAT MU~T!~LI COMPLETE SHOOT OR ACIDIZE ABANDONs REPAIR W~LL CHA~ PLANS ~O~h~r) See ~1o~ . 5. API N~CAL CODE API. 50-283-20032 _._.._ l~[Z_.~ , ADL-17 589 7. IF IND;A-~, ~'r'r~E OR ~BE N~ 8. UN~T~ F~ OE ~SE N~E ~o~h Cook ~e~ U~ WATER SI{UT-O~ FRACTURE TREATMENT SaOoTINo OR ACIDIZINO (Other) 9. w~uL NO. A-l 10. FIELD A/~D POOL, OR WILDCAT W.i ~dcat 11, SEC., T., R, M., (BOTTOM HOLE OBJECTIVE) TllN, R?W, S.M. 12. PERMIT 1~. 69-99 .~rt, or Other 'Data auBsmqUENT REPORT 0~: ALTERING CASINO ABANDONM EBiT$ NOTE: Report reeults of multiple completion on Well ompletion or Reeompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OP~!~,~'S (Cleavl. y state all pertinent details, and give pertinent dates, including estimated date of starting an}' proposed work. This wet.~ was drirLed to a TD of lA, glO~ MD, 1A,200.6~ TTD w~th a btm hole location of 1,221~ FSL, 1,29~~ FWL, Sec. We plan to plug and abandon the open hole from btm of 9-5/8" csg @ 12,032' & plug back into 13-3/8' csg as follows: 1. Set 75 sx Type "G" cmt plug using pre-mxd CFR-2 wtr @ 14,580' - 14,390'. 2. Set 60 sx Type "G, cmt plug using pre-mxd CFR-2 wtr @ 13,0OO' - 12,850'. 3. Set 60 sx Type ,G" cmt plug using pre-mxd CFR-2' wtr @ 12,&70' - 12,320'. Set cmt retainer @ 11,965' & squeeze w/90 sx plug (230') below retainer & l0 sx on top of retainer. 5. Cut 9-5/8" csg @ approximately 7,600' & pull. Set approximately 300 sx plug @ 7,600' - 7,130'. 6. Set E-Z drill retainer @ 6,930'. Squeeze 100 sx Type "G" cmt below retainer, 7. Suspend operations temporarily for other work. The above verbally approved by O.K. ~ilbreath, Jr. March 17,R E [ E ]V E O (This space go~ State off/ce CONDITIONS OF APPROVAl, MAR 2 3 1970 DIVISION CF OIL ANCHORAG! Dist. Ofc. ~gr. DAT~ March 20, 1970 See lnstrucfions On Reverse Side Appro',,~d CcFy Returned TO: Memo to Files FROM: O. K. Gilbreth, Jr.~'~'~ Chief Petroleum Engineer DEPARTbiENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS DATE: March 16, 1970 OKG KLV HWK ...... REL ~ FILE ,., SUBJECT: Cherryville Corporation No. 1 North Cook Inlet Field Bill Woodruff of Phillips called at 3 p.m., March 16, 1970, to obtain approval on a plugging program for the sujbect well. TD of 14,910' had been reached, drilling with 15.2-pound mud; 9 5/8" casing is set at 12,032 feet. The hole has been logged to TD and no commercial production is indicated at TD. There is a 10-foot sand stringer apparently at the top of the Hemlock from 14,530' to 14,540' with a wet stone from 12,930' to 12,970' and a 20-foot possible productive zone 12,045' to 12,065'. A 20-foot string from 12,430' to 12,450' looks like it might be hydrocarbon-bearing. Phillips proposed the following abandonment program: 1. Laying a plug from 14,430' to 14,580', 12,850' to 13,000', 12,320' to 12,470'. 2. In the bottom of 9 5/8" casing at 11,065' set a cement retainer and squeeze out leaving 10 sacks on top of retainer. 3. Pull up to 7,600' and cut casing. Pull and recover casing. Cement bond log indicates a good bond up 9,920'. 4. 13 3/8" is set at 6,949' and cemented all the way to the top with cement circulated. There is nothing in the open hole from 6,949 to 7,600'. Propose to lay 100-sack plug from 7,600' to 7,500' and set retainer in bottom of 13 3/8" casing at 6,900' and squeeze, leaving 10 sacks of cement on top of retainer. The well might possibly be recompleted as a gas well depending on negotiations with the Cherryville Corporation. This program was approved by phone and P-3 form will be submitted. OKG: my Form No. REV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT O:F 'DRILLING AND WORKOVER OPERATIONS SUBMIT IN DUPLICATE ( .ldcat) W~LL ~ GA8 W~LL 2. N~E OF OP~TOR Phillips Petrole~ ~mpany - Cher~ille 3. ADDRESS OF OP~TOR - 4. ~o~ ~ w~ Surf~o~: ~g 1, Slot 3, ~S&.l' ~, 927.8' ~, Sec. T]]N, RgW, S.M., No~h Cook I~e%, P~%f~ "~onek" Top of Pay: ~,~ East L~e~, Sec. APl NuMEmCAL"~ODE API 50-283-20032 HLB KL¥ REL 7.IF INDIA]~,ALOTTEE O1~ TRIBE NAME FILE · 8.I/NIT,FAPLM OR LEASE NA3~E North Cook Inlet Unit 9. WELL NO. A-15 10, FIELD AND POOL. OR WILDCAT Wildcat 11. SEC., T., R., 1%{., (BOTTOM HOLE OBJECTrVE) Sec. 6, T1]N, R9W, S.M. PERMIT NO. '' 69-99 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CE1ViENTING JOBSINCLUDING DEPTH SET A/Xq~ VOL~ USED, PERFORATIONS. TESTS A_N-D PLESULTS. FISHING JOB~, JUNK IN HOLE A_ND SIDE-TI:LACKED HOLE AND A2~Y OTHER SIGNIFICANT CI-{AN-~ES IN HOI~ CONDITIONS. 2-28-70 1~, 069 ' Drl~ 8½" hole. 2-1/5-70 12,104' 2-6/16-70 12,933' Fshd for jnk on btm. Set 50 sx cmt plug on btm. Plug no good. Wshd out plug to TD. Ran second plug on btm. T0C 11,931'. Plug no good. Set 78 sx plug. T0C 11,979'. Drld cmt out to 12,038'. Sidetracked hole. Drld 8½" hole off plug. 2-17-70 12,979' 2-18/28-70 14,069' Cut Core #2, 12,933' - 12,979' Drld 8½" hole. RECEIVED I AR 17 ANCHORAO~ //-, .. v ,/ // NOTE~Report on ~hi5 form i~ required for each calendar month, regardless of ~he status of operation% anO must ~ filed in duplicate the Division of ~ines & ~inerals by ~he ~5~h of the succeeding month, unless othe~ise directed. Form No. P--4 REV. 9-~0-6~ STATE OF ALASKA SUBM~ IN DUPLi¢A.T~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF :DRILLING AND WORKOVER OPERATIONS O,L ~ GA. [] OT"'-" (Wildcat) WELL __ WELL 2. NA_ME OF OPEi~ATOR Phil ] ~ps Petroleum Compan~ - Cherryvi] ~ e Corporation 3. ADb'BESS OF OPERATOR 515 "D" Street; Anchorage; Alaska 99501 4. LOCATION OF WELL Surface: Leg 1, Slot 3, 125~.1' FNL, 927.8' ?WL, Sec. 6 TllN, R9W, S.M., North Cook Inlet, P1Afo~ "Tyonek" Top of Pay: 14,500' MD, 1~,000' TVD, 2300' From South & East Lines, Sec. 6, TllN, R9W, S.M. APl NUi{ERICAL CODE ~I 50-283-20032 L~SE DESI'O~A~ON ~XD ADULT 589 8. UT~'IT,F;~INI OR LEASE NAME North C~ok Inlet Unit g. WELL NO. 10. FIF. T.T~ AND POOL, OR %VILDCAT Wildcat 11. SEC., T., R., M., (BO'I~FOM HOLE OB.rF, CTnrE) Sec. 6, TllN, R9W, S.M. 12. PEI~lVIIT NO. 69-99 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUATES USED, pEP,~ORATIONS, TESTS A/xl]D I~ESULTS. FISHING JOB~, JUNK IN HOLE AND SIDE-TR~C~D HOLE AND A_NY OTI~IER SIGNIFICANT CHANGES IN HOLI~ CONI)ITIONS. 1-~1-70 12,100' Milling on junk. 1-1/9-70 11,878' 11,878' While pulling pipe out of hole, pipe parted, top of fish 10,777'. %"~[H w/overshot, stuck overshot, backed eff, t~p of fish 10,616'. Screwed into upper fish,~ Jarred l~ose. COOH. Left i reamer cutter and pin in hole. ~fIH & washed to top of fish at 10,777'. Latched onto fish and Jarred loose. COOH and LD fish. Left aL1 ~ c~nes and shanks in hole. WIH. Reamed and washed to TD. C&CM. WIH w/junk basket, recovered 1 cone. 1-15/16-70 ll, 878' _Ran DILL, Sonic Log, Density Log and SNP Log. Reran Sonic~ Log. Ran Junk basket, recovered 2 cones complete. 1-17/21-70 12,0 50 ' Reamed and drilled to 12,050'. Started out of h.ele, pipe 9rick. Spotted Pipe Lax and Bit Lube while jarring on fish. Jarred loose and COOH. 11-22-70 12,050 ' 11-23-70 12,050 ' Ran DILL Log. Rig up to run casing. Ran 9-5/8" casing, set at 12,032'. Cemented w/706 sx Class 'G" cement mxd w/&35 bbls prehydrated 10% Diacel 'D' and 2%~HR-7 fresh water. Tailed in w/6~8 sx Class "G" cement mxd w/lO5 bbls prehydrated 2% HR-7 fresh water. 11-2&/26-70 Ran CBL 11,~38' - 6900'. 1-27/30-70 12,090' Drld on junk on btm. Ran bskt, no recovery. Killed ®n junk. 1/31/70 /7 12,090' Milling on junk. 14. ' hereby certify ~/the .f~regoin,~ tru/~l~eorrect SIC - with e Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. PHILLIPS PETROLEUM COMPANY ANCHORAGE, ALASKA 99501 ~ 515 "D" STREET EXPLORATION AND PRODUCTION DEPARTMENT :ILE December 9, 1969 Division of Mines & M~nera!s Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 9950~ Attention: Mr. T. R. Marsha!l, Jr. Gent temen: Attached, please find original and one copM of Form P-~, Monthly Report of Drilling and Workover Operations for Phillips Petroleum Company-Cherr~i!le Corporation NCIU ~1! #A-I~. Yours truly, JBG: jo Attac~ent s PHILLIPS PETROLEUM CO~A~ gistric~ Office Manager Fown No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF ~DRILLING AND WORKOVER OPERATIONS SUBMIT IN DUPLICA'rK AP1 NUA{ERICAL CODE 50-283-20032 6. LEASE DESIGNATION AND SERIAL SD:L-1758? 7, IF INDIA]~', ALOTTEE OJ{ TRIBE NAME 8. UI~'IT,FA1RA4 OR LEASE NA~IE Ner~h aeek Inlet Uni% 9. WELL NO. #A-15 10. FlED AND POOL, OR WILDCAT Wilde. at NAME OF OP]51%ATOR ~~ps Petreleum Cem~-Oherryville Cer~er~tien ADDRESS OF OPEi~ATOR ~15 "D" Street, Anchera~e. LOCATION OF WELL - - Sur. face~ ~g 1, slet 3, ~S&.i',' FNL, 927.8' FWL, Sec. 6 TI]N, RgW, S.H., N~r~h C,s~k ~t, Platform "Tyenek" 11, SEC., T,, R., M., (BOttOM HOI.~E OBJZcrnrE) Sec. 6s TllN, RgW, S.M. ,, 1~. PEtkMIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN I-IOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET ~ VOLUiVfES USED, PERFORATIONS. TESTS A/ND RESULTS. FISHING JOB~. JUNK IN HOLE A_ND SIDE-TI~LACKED HOLE AND A~qY OTHER SIGNIFICA/%TT CI-IA_~-~ES IN HOL~ CONDITIONS. 10/31/69 538/+' Drla te 538/+'. xol 169 1~0' PBTD 538~' Spudded 17~" hele & drld te 1967' & rind t~ 26". Drld ~" hele te 2021'. Ran 20" ~ecg. Set mx~ w/prehydrated Gel w~r. Tailed in w/200 ax Class "G" Neat ~m~ mx~ w/20 bbls 2% cc w~r. grot cir~. HOWC0 plug ~ 1956'. Press. tstd esg & BOP ram~ te 2000 PSI. Drld 17~" hole to ':1969 DIVISION OF OIL AND GAS ANCI'IOI~G~ 14. I hereby ce~l~the ~or(~oing~t~:~ c-orrect ' ' s,smm. ~/4~//~ ~~~ ~. 0fo. ~r. nA~ Neve~er ~, 1969 , // ~ ''- '- ~l~, ,' ' ' NOTE~Report on ~his form ig required for each calendar month, regardless of the status of operations, an~ must ~ filed in duplicate ~th the DiVision of Mines & Minerals by the 15th of the succeeding month, unless othe~ise directed. PHILLIPS PETROLEUM ANCHORAGE, ALASKA 99501 ~ 515"D" STREET EXPLORATION AND PRODUCTION DEPARTMENT COMPANY HLB TRM ~'~ ~ . OKG KLV FILE .._ ' Division of Mines & Minerals Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 9950~ Attention: Mr. T. R. Marshall, Jr. Gentlemen: Attached, please find Sperry-Sun Directional Survey Report for Phillips Petroleum Company-Cherryville Corporation NCIU Well No. A-15. Yours truly, JBG: jo Attachment (2) PHILLIPS PETROLW. UM COMPANY // District Office Manager 1018 INTER~A TIONAL AIRPORT ROAD AHCHORAGE 99502 FILE October 21, 1969 Mr. John B. Gipson Phillips Petroleum Company Cheeryvil le Corporation 515 "D" Street Anchorage, Alaska 99501 Dear Mr. Gipson: Re- North Cook Inlet Unit #A-15 Phillips Petroleum Company Cherryvil le Corporation, Operator In reference to the subject drill-site the following stipulations are required to protect fish and game resources' ~. 1. No material foreign to the environment will be discharged from this platform. This includes garbage, trash, refuse, petroleum and/or its products, drilling mud, and-debris. t Oil industry operations in this area are not to interfere with commercial fishing. " 3~ i The Habitat Biologist s Office, lO18 West International Airport Road., Anchorage, Alaska 99502 will be notified on completion of the subjeCt drilling operation. Statement- The m~ .... g~; ,u,~ .~,ng provisions do not relieve the lessee and/or his contractors or assignees of any responsibilities or provisions required by law or regulation of the State of Alaska or the federal government. i969 OiL ~ND GAS RJk'J:bb cc' Hiqli Denton Burrei i OIL AND GAS CONSERVATION CONVv~ITTEE MONTHLY REPORT O'F :DRILLING AND WORKOVER OPERATIONS PEP.~TOR Petrole~'m C~ny - ~er~l le Cn~n~.~ n~ )F OP~TOR ~treet~ ~chora~e: Alna~a ~g l, Slot 3, ~5~.1' F~, $27.~' ~, ~c. ~, S.M., Ne~h C~k I~et, P~tfe~ "~enek" ~: ~,5~' ~, ~,O~' ~, 23~' From South ~s, Sec. ~, TIIN, R~, S-M. FILE ...... ADL-l?589 T. IF INDIA]~, ALO1 i }.,iL O~ TRIBE NAME ll.'~'~m"~"m~..~.. M.. (BO'I'T'OM HO12E o~,rEcTr~_.~ Sec. 6, TIIN, RgW, 5.M. 12. PER,MIT HO. 69-99 'OTAL DEPTH AT END OF MONTH, CHA. NGES IN HOLE SIZE, CASING A!N-D CE1VIENTING JOBS INCLUDING DEPTH VOL~ USED, PF_JRFORATIONS, TESTS A_ND I{ESULTS, FISHING JOB~. JUNK L~ HOLE AND SIDE-TRACKED HOLE ' OTHER SIGNIFICANT CH_A. NGES IN HOL~ CON'DITIONS. 11,869' Drld 12" hole to 11,869'. 11,168' Dr~ 12" hole 11,869'. Cored from ll, 13& to 11,168', Rec 22'. /69 11,869' Drld ~" h°le to 11,869'. ~'/ - ~'~'--' / 'lend. month r e-ardle~s of (OTE--Report on this form is required for each ca r , 9 the status of operations, ane must ~ filed in duplicate he Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed, Porto No. P--4 REV. 9-30-6~ STATE OF ALASKA SUBMIT IN DUPLICATE OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT O'F :D.RILLING AND WORKOVER OPERATIONS o.. G,,. © oT.E,,(m:Lc'Lcat) WELL WELL 2. NAME OF OP]~R. ATOR Phillips Petroleum Company-Oherryvil!e ~O~porati~n 3. ADDRESS OF OPER.~TOR 515 "D" Street. Anchorage. LOCA~ON OF W~ Sur~acel Le~ l~ Slot ~~, g.M., North ~ok Inlet, P~tfo~ "Tyonek" '--'-- HLB _ TR~ _ AP1 NU*YmmC.~L bODE KLV ' API ~0-283-20032 HWK LEASE DESIGNA~ON AND S~[NO~ ADL-17589 --- -- ~. IF ,Nm^~, ^LOT~E ok TRm~I~- 8. U/~IT,FA~ OR LEASE NA3~E Nor%h Cook Inle% Unit 9. WELL NO. A-15 10. FIELD AND POOL, OR WILOCAT n. s~.c., w,, ~., x~., mo~o= no~ o~ Sec. 6, T~, R%~, S.M. 1~-. PERMIT I~O. 69-99 13. REPORT T(~TAL DEPTH AT END OF MONTH, CI-L~NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS. FISHING JOBS, JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CIiANGF. S IN HOI-~ CONDITIONS. 11/30/69 974S' 11/1-5/69 696~' 1116/69 11/9-30/69 Drld 12" hole to 9748'. Drld 17½" hole to 6965'. Ran 13-3/8" csg. Set @ 6949.55'. Cmtd w/1660 sx Type "G" cmt mxd w/4% prehydrated ~ gel wtr. Followed w/120 sx Type "G" cmt mxd w/20 bbls FW. Cmt circ. Drld 12" hole to 9748'. 1 o1969 · D_IVi~ON OF OIL ~ N 14. I hereby certif rego~ correct __ ' maNgO ~----- -/~'~'~ Dist. Otc, T.'~r. DATE December 9, ~9~9 t' / '-'-_1//- - i~E--Report on this is each regardless the status operations, and must t)e in duplicate ~quired calendar form for month, of of file~ with the Division of Mines & Minerals by the ~Sth of the succeeding month, unless otherwise directed. DIVISION OF OIL AND GAS October 15, 1969 North Cook Inlet Unit #A-15 Phi I 11ps Petroleum Coa~any - Cherryvl I le Corporation, Operator ,Mr. John B. Gipson Phi I ! ips Petroleum Company - Cherryv i ! I e Corporat i on 5 t 5 "D" Street Anchorage, Alaska 99501 Dear SI r: Enclosed Is ~he approved application for perait to drill the above referenced well on October 15~. 1969, fro= North Cook Inlet platfor~ Tyonek. Well samples, core chips and a directional survey are required. Sufficient ~nt shall be used on the 13 3/8" casing, to cover all potentially productive Intervals. On the 9 5/8" casing sufficient cement shall be used to fill 1,000 feet above the shoe, tn view of the hlgh pressure gas prevlously encountered at that depth. Each electric log, sepia, and print, flied pursuant to AS 31.05.O30 and the applicable regulations, shall Include the calibration file and the mechanlcal zefo positions of all log traces~ both before and after the log. run. Each log shall sho~ all format data Including (i) type of fluid In the hole, (2) changes in mud type and additional samples, (3) scale changes, (4) equlp~ent data, and (5) equipment use~. In the event of suspension or abandonaent, please notify thls office adequately in =dvance so that we ~ay have a witness present. truly yours, Enclosure Hoaer L. Burre l I Chairaan cc: {t~artaenf of FI sh and Gaae w/o eac I. Oepar~nt of Labor w/o enc l. SUBMIT IN TR! TE (Other instructior. Form P--! reverse side] tRJDV. 9-30-67 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE' ,. APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK la. TYPE OF WORK DRILL [~ DEEPEN ~ PLUG BACK b. TYPE OF WELL WELL vA-ELL OTHER ZONE ZONE 2. I~AME OF OPEIq~TOR Phillips Petroleum Company_ Cher~ille Corporation 3. ADDRESS C~F 515 "D" Street, Anchorage, Alaska, 99501 TlfliF,~eRgw, S.M., North 0ook Inlet, Platform "Tyonek". At proposed prod ~o~e 14,500~ MD, 14,000~ TVD, 2300' from South & East Lines, Se~. 6, TllN, R~, $.M. !0. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 6, T12J~$, R~, S.M. 13. DISTANCE IN MILES AND DIRECTION FiIOM NEAr{EST TOWN OR POST OFFICE* 12. 10.5 miles East of Tyonek, Alaska I4.TYpEBOND IT~/~T:~N: Surety~L~IVand/or No. St&re ],~id~ ~nd ~-Z (~h~~ne Co~tto~)~o~, ~~~~ Im No. OF ACRES IN LEASE ~ NO. ACRES ASSIGNED 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST ~ TO THiS WELL P~OPERTY OR LEASE LI~E, FT. 2~' 5~' 1~ (Also to nearest drig, unit, if any) I8. DISTANCE FROM PROPOSED LOCA~ON* !9. P~QPOSED DEPT~ 20. ROTARY OR CABLE TOOLS TO NEAREST WELL DRILLING, COMPLETED, 15~1 ~ ~c~iy NOIU ~ 15,~' '~D ~~ 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 22. APPROX. DATE WORK WILL START* RKB 116 ' From MLLW 10-15-69 23. PI%OPOSED CASING AND CEMENTING PROGRAM SI; OF HOLE SIZE OF CASING WEIGHT PER FOC~ GRAI~E SETTING DEPTH QUANTITY OF CEMENT 1. Deviation required to reach BHL from ~rma~nt. platform. 2. There a~ no effected operators. 3. BOP Specification attached. g. Intervals of intere~ will '~ perforated and ~ ~ stimulated.. NOTE: BHL: 1980' ?~ Ms, ~c. 6, TllN, ~W, S.M. IN ABOVE SPACE DESCRIBE PI%OPOSED PROGRA1Vi: If pro.posal is to deepen or plug back, give data on present productive zone and propo.sed new' productive zofle. If pro,p6sai is to drill or deepen direct [onally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout:![p[~eventer program. 24: I hereby certify thz~ the Fort~going Js .~ue ~hd Correct · /..+' .~< ~ ' ...... ~to~r 9, 1969 SIGNED_ (This space for State office use) ~/ CONDITIONS OTH_Ei:t REQUIREMENTS: SEE TRANSMITTAL LETTER SAMPLES AND CORE CHIPS REQUIPJ~I) ~ YES [] ~st. Oft. Mgr. DIRECTIONAL SURVEY REQUIRED [] YES [] NO A.P.I. NUMERICAL CODE z69-99 PFXQ1VIIT NC). APPROVAL DATE APPROVED B~~ Tn~ Chairman *See b~trucfion, On Revere Side October 15, 1969 ~A~, October 15, 1969 LtlL I I I [ I [ .... LII]I III ' ' ~ I II1[ I ] I I I I I I II "0 A-II PSHL .Z 12 II I I 13 lull I II j 18 T ~ 8 AD/_ /8?4/ GRID PHILLIPS PETROLEUM COMPANY 6~§ "D" STREE? ANCHORAG£ ,ALASKA PLAT OF NORTH COOK INLE:T UNiT TYONEK PLATFORM DRWN. N, d. Powell Company ~"~'~I'~ , ' Lease & Well No. /J - /~" CHECK LIST FOR NEW WELL PERMITS Yes No Remarks 1; Is well to be located in a defined pool ................. 2. Do s tatewi de ru 1 es apply ......................... ~.K 3. Is a registered survey plat attached ....... ~ .......... 4. Is well located proper distance from property line ........... ~ .5. Is well located proper distance from other wells ............ ~,~ · zs i ..... .6. sufficient unded cated acreage available in this pool ........ -~, '", ~ . Is well to be deviated' '" Y~ '" !.~ · · · · · · · · · · · · · · · · · · · · · · · · · . '~ affected party ~ :'8, Is operator the only · · · · · · · · · · · · · · · · · · · .9..~ Can pemtt be approved before ten-day wait ............... ':'10. . Does operator have a bond in forCe ...... . ,... Is conductor s rtn :<.12, :Is enough cemen~ used a~e on conductor and surface ...... : ~'en ~ngs 3 "::Will t tie in surface and intermediate °r production str . . ~..~.,,. "' ; "~,~: " ctive: h'6rtzons' :'Will"Cement cOver all possible produ .......... 15. ~11 ~urface casin~ cover all fresh ~ater zone~ ............ ..)6.- Will surface csg. internal burst equal .5 psi/ft, to next string .... 17. Will all casing give adequate safety in collapse and tension ...... :::18..Does BOPE have sufficient pressure rating ............... Additional Requirements: Approval Recommended: TRM ~ EEL