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Home My WebLink About162-0281a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _0 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: N/A BF: N/A 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 99 (ft MSL) 22.Logs Obtained: N/A 23. BOTTOM 30"151 24"225 20"655 13-3/8"1,579 9-5/8"5,488 7"10,140 7"2nd Stg 618 5"Tie-back 9,911 5"12,164 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng Exploratory N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing N/A N/A Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information N/A PACKER SET (MD/TVD) 18 3,022 10,101 36" 18 None 6" None 30" Jetted into place Mudline 300 None Mudline Mudline 225Mudline Mudline 78 618 N/A 331161.4989 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A BOTTOM SIZE DEPTH SET (MD) Mudline Mudline 68 94 151 Mudline 655 54.5 132 1,579 132 23/26 132 10,325 132 50-883-10013-00-00 Cook Inlet St 17589 1-A ADL0017589 1250' FSL, 1950' FWL, Sec 6, T11N, R9W, SM, AK N/A 8/27/1962 12,676 / 12,422 136 / 136 126' 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 332928.7413 2583936.4484 N/A 6/25/1964 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 7/11/2023 162-028 / 323-307 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, None 8 1/2" TUBING RECORD 540 12,404 10,086 1600 3,022 9,925 30" None 6" N/AN/A 180 CASING 8 1/2" 300 None 810' FSL, 189' FWL, Sec 6, T11N, R9W, SM, AK 17 1/2" 1510 None 36/40 132 5,489 132 12 1/4" 600 None WT. PER FT.GRADE CEMENTING RECORD N/A N/A SETTING DEPTH TVD 2583521.9291 TOP HOLE SIZE AMOUNT PULLED Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 4:03 pm, Aug 07, 2023 Abandoned 7/11/2023 JSB RBDMS JSB 081723 xGDSR-8/31/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A N/A N/A Top of Productive Interval N/A N/A N/A N/A 31. List of Attachments: Wellbore schematic, Well operations summary, Photos 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Aras Worthington Digital Signature with Date:Contact Email:Aras.Worthington@hilcorp.com Contact Phone: 907 564-4763 Operations Manager 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: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. 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). 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. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. INSTRUCTIONS Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Authorized Title: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Authorized Name and Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.08.07 09:58:37 - 08'00' Dan Marlowe (1267) _____________________________________________________________________________________ Revision By: AJW 7/27/23 SCHEMATIC Well: Cook Inlet State 1A (17589) PTD: 162-028 API: 50-883-10013-00-00 TD 12,676’ MD 30” OKB to Mudline = 126’ 6 7 4 10 11 2 13-3/8” 5 5” 9-5/8” 7” 8 24” Casing Break 8900’–8985’ MD 9 20” 5” 3 1 PERFORATION / Squeeze DATA Top (MD) Btm (MD) Cement Squeeze 3150’ 3155’ 245 sx 3500’ 3505’ 250 sx 4075’ 4105’ 150 sx 5065’ 5085’ 200 sx 5153’ 5163’ 200 sx 5350’ 5355’ 200 sx 6108’ 6112’ 50 sx 6206’ 6226’ 50 sx 6328’ 6332’ 50 sx 10927’ 10947’ 40 sx 12300’ 12303’ 50 sx 12315’ 12348’ 50 sx 12364’ 12378’ 50 sx 54 sx pumped below cmt retainer at 12,387’ CASING DETAIL Size Wt Cmt TOC Top Btm 30” 68 Jetted Mudline Mudline 151’ 24” 94 300 sx Mudline Mudline 225’ 20” 78 1600 sx Mudline Mudline 655’ 13-3/8” 54.5 1510 sx Mudline Cut @ 132’ (6’ BML)1,579’ 9-5/8” 36/40 600 sx Mudline Cut @ 132’ (6’ BML)5,489’ 7” 23/26 300 sx 9,050’ Cut @ 132’ (6’ BML)10,325’ 7” 2nd Stg 105sx Mudline Mudline 618’ (CBL) 5” Tieback 18 540 sx 3,340’ 3022’ 10,086’ 5” 18 180 sx 10,630’ 10,101’ 12,404’ JEWELRY/COMPLETION DETAIL Number Depth MD Item 1 280’7” Cmt Retainer 13 bbls 15.8 ppg cmt on top; TOC dressed-off & tagged @ 136’ ORKB / 10’ Below Mudline 2 153’ & 295’ 7” x 9-5/8” Multi-string Mechanical Cuts 3 283’9-5/8” Stage Tool (Verified cement to surface in 9-5/8” x 13-3/8” casing via final mechanical cut) 4 2943’7” Cmt Retainer 13 bbls 15.8 ppg cmt on top TOC tagged @ 2626’ 5 3,045’ Cmt Retainer 5 sx cmt on top 6 3,833’ Cmt Retainer 10 sx cmt on top 7 5,025’ Cmt Retainer 15 sx cmt on top 8 5,320’ Model “N” Packer 15 sx cmt on top 9 10,883’ Model “N” Packer 10 12,280’ Model “N” Packer 11 12,387’ Model “K” Retainer Recovery of Sliplock wellhead, subsea wellhead, and 13-3/8” x 9-5/8” x 7” casing stubs from cut 6’ below mudline. Note cement on the outside of the 13-3/8 casing showing it was cemented to within a few feet of mudline 13-3/8” x 9-5/8” x 7” recovered stubs from 6’ below mudline showing solid cement in all annuli Rig Start Date End Date Rig 151 6/12/23 7/11/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Cook Inlet St 17589 1-A 50-883-10013-00-00 162-028 Arranging decks and Prep and r/up and install of first riser section. Dive # 1 to inspect leg scourer, port can good, and was unable to complete starboard inspection due to tide. Received call from dive boat with a concern of rigs air gap. Held conference call w/ all parties plan fwd dive boat to come back in on Pm high tide and measure rig air gap for workable room. Prep decks and skid cantilever back in to jacking position. Dive boat back at 15:45 hrs and measured working room and confirmed additional 5' of air gap was needed. Secure rig and prep to jack up 5 more feet for total air gap of 30'. Perform walk through and skid cantilever out 25'. Prep and skid cantilever to starboard side 18". R/U 78" spool and hang. Run 1/2" tugger line through spool and prep for plumb bob. R/U walkways, handrails. Run working ropes and tool ropes- stage and prep for dive #1. Dive boat arrived at 21:20 hrs unload 2 bits for plum and lowered tote with bolts. Dive was called off at 22:20 hrs due to weather and seas. Rig up service lines from rig floor to cantilever. R/U remaining handrails and stairways. Walked oncoming crew through Dive #1 procedure. Clean and paint around rig while waiting on weather. 112 Days Since Last Recordable Injury. Hold PJSM, perform final work through prior to skidding. Skid rig package 25'. Install service lines from cantilever to rig floor. R/U handrails, stairs and walkways. Organize deck and prep for boat. Unload boat leaving 20" risers on to clear deck space. Reorganize deck. Assist Global divers staging misc tools and equipment on lower deck. Prep for A- leg and diver tuggers to be installed and welded. Off load 20''risers from boat. Prep rig package to skid to starboard side and skid 18". Move rig floor drain tank into position and rig up drain hoses for rig floor and cantilever. 111 Days Since Last Recordable Injury 06/13/2023 - Tuesday 06/12/2023 - Monday Rig Start Date End Date Rig 151 6/12/23 7/11/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Cook Inlet St 17589 1-A 50-883-10013-00-00 162-028 06/14/2023 - Wednesday Clean and organize on rig floor and main deck. Chg/out 8" suction valve on mud pit #1. Prep riser and equipment for dive. Prep and paint floor in engine room. Hold pre-dive meeting w/ all involved for dive attempt #3 and dive #2. M/V sand island arrived on location 3rd time and deployed diver @ 11:03 hrs. for dive #2 and R/up down line and Tool line to well head. Rig deployed plumb bob via tugger line and diver confirmed only off 6" to the south (no rig correction made at this time) and diver disconnected plumb bob weight and attached center guide wire just under bell flare of well head and rig pulled taught. Diver out of water @ 11:34 hrs. Continue misc r/up and clean and paint and organize and prep for next dive. Hold pre-dive meeting w/ all involved for dive attempt #4 and dive #3 and Re check equipment and rigging, coms and job assignments and continue to wait on dive boat and tide. M/V sand island arrived on location 4th time and deployed diver @ 17:05 hrs for dive #3. Diver installed API ring. Rig deployed 78" riser section from rig floor. Diver oriented same and installed two Nuts on studs hand tight and released rigging on 78" riser diver out of water @ 17:58 hrs. Transfer BOP's from catwalk to and line up catwalk with V-door. Installed mouse hole. R/U 5" pipe handling equipment and P/U 1 stand of 5" DP rack back in derrick. Changed out bails, Doyons false bowl and 20" pipe handling equipment. P/U top flanged riser piece and installed crossover plate from 21 1/4" flange to 4 1/2 IF. Make up 5' pup to flange. P/U riser and set on rig floor to assist with dive operations. Held pre-dive meeting w/ all involved for dive #4 at 22:00 hrs. M/V sand island arrived on location 5th time at 22:50 and deployed diver @ 23:07 hrs. for dive #4. Diver disconnected guide wire from well and installed remaining nuts and star patterned bolts with 3/4" impact. Diver out of the water at 23:43 hrs. Lowered riser through rotary and torqued pup to 17K on crossover flange. Had to orient the pad eyes to make it through false rotary. Pulled out and L/D riser piece with 5' pup and flange still on. Worked boat. P/U Doyon double stack 20" power tongs to rig floor and R/U hoses. Swapped elevators from 5" to 20" side door elevators. Turn on hyd. power unit and test tongs. Hold PJSM, M/U 102' of 20" riser with 14' XO jt on the bottom and install 2 horizonal cam keys in each connections. P/U to rig floor and stage. Move and stage faring's on rig floor. M/V sand island arrived on location 6th time. Dive was called off due to seas. Will attempt again at 12:00 tide. Run guide wires through bottom flange and tie off. Install faring's on 14' xo jt and first 44' jt of 20" riser. Rig Start Date End Date Rig 151 6/12/23 7/11/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Cook Inlet St 17589 1-A 50-883-10013-00-00 162-028 06/15/2023 - Thursday Continue and finish install fairings on the 102' of 20" riser, and trouble shoot dyno-matic issue. Housekeeping and rig maintenance. PTSM and pre-dive meeting w/ new crew. M/V sand island arrived on location 7th time and deployed diver @ 12:02 hrs. for dive #5. Diver continued and finished tighten nuts on 78" riser section with 3/4" impact and started tightening nuts w/ high torque (not completed). Diver out of the water at 12:34 hrs. P/up and m/up dril-quip x flanged xo 20" joint @ 41.92 ' and install fairing on same parking 20" riser assembly at high derrick and above high water and wait on divers to install. Continue rig maintenance and prepping equipment. M/V sand island arrived on location 8th time and deployed diver @ 18:10 hrs. for dive #6. Diver continued tighten nuts w/ high torque. Diver out of the water at 18:48 hrs. Work boat and organize decks. R/U and hang tensioner cables to texas deck. Cont. R/U misc. equipment and hoses. Clean and paint. M/V sand island arrived on location 9th time and deployed diver @ 00:17 hrs. for dive #7. Diver finished tightening nuts w/ high torque, moved tool / guide lines to top of 78" riser spool and hooked up port side guide wire. Diver out of the water at 00:43 hrs. Clean and organize upper deck. Prep for next dive. Cont R/U of misc. equipment. Held meeting on rig floor with rig crew prior to dive meeting. Held pre- dive meeting with all parties. Lowered 20" riser down to flange, set slips and removed 5' pup. M/U stand of 5" pull slips and lowered riser down to wear second set of pad eyes were at Texas deck for tensioner cables to be installed. M/V sand island arrived on location 10th time and deployed diver @ 05:40 hrs. for dive #8. Diver hooked up starboard guide wire- pulled tight with tugger. 06/16/2023- Friday Continued Dive #8. Rig deployed 20" riser assembly. Diver installed two bolts and snugged up both before running out time. Rig pulled 10k over to stabilize in tide and deployed Texas deck and secured top of 20" riser assembly w/ four 10 ton chain falls. M/V sand island arrived on location 11th time and deployed diver @ 12:46 hrs. for dive #9. Diver installed two more bolts & nuts and tightened same for total of 4 Bolts tight w/ 1" impact and released both guide wires and rig retrieved same. Diver was able install all the rest of bolts just top nutted bolts before running out of tide, diver out water @ 13:20hrs. Re-pull 5k tension w/ blocks and re-tighten four 10 ton chain falls on top of 20" to stabilize in tide. Continue to work on install of riser tensioning system and stack up and tighten spools on deck for nip/up. M/V sand island arrived on location 12th time deploying diver at 19:06 hrs for dive #10. Diver installed all bottom nuts and impacted 90% of the bolts. Diver out of water at 19:57 hrs. Rig up hydraulic hoses to tensioner cylinders and function test. Rig up Starboard Aft tensioner cylinder after function testing wasn't able to function cylinders- trouble shoot issue. Cont. tightening bolts on 13 5/8" spool, CSG spool and mud cross spool on deck for nipple up. M/V sand island arrived on location 13th time deploying diver at 01:03 hrs for dive #11. Diver with impact and started torqueing with hytorc. Diver out of water at 01:32 hrs. Cont. trouble shooting cylinders, wound up bypassing manifold and all cylinders function properly. Installed both cylinders on the starboard side. Rig Start Date End Date Rig 151 6/12/23 7/11/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Cook Inlet St 17589 1-A 50-883-10013-00-00 162-028 06/17/2023 - Saturday Continued install of port aft cylinder and continued trouble shooting hyd functions. M/V sand island arrived on location 14th time deploying diver at 06:22hrs for dive #12. Diver finished torqueing 20" riser bolts with hytorc. Diver out of water at 06:53 hrs. Continued install of port aft cylinder and continued trouble shooting hyd functions. Welder working on flow nipple. Bump test gas system. M/V sand island arrived on location 15th time deploying diver at 13:38 hrs for dive #13. Diver finished Bow and port leg scour. Diver out of water at 014:10 hrs. Continue install Port side bow cylinder & welder continue working on flow nipple. Move choke and kill lines for N/U. Removed bolts, pulled and racked back 5" std in derrick with XO plate. R/D chain binders and chains from false rotary. Pull false rotary and mouse hole. R/U cables to topdrive. P/U already torqued BOP components (DSA, 13 5/8" spool, CSG spool and Mud cross spool) and lower down through the rotary down to riser. Sent down 2 men utilizing manrider to Texas deck through rotary. Orient and stab onto riser. Install lower nuts and begin torqueing. M/V sand island arrived on location 15th time deploying diver at 01:50 hrs for dive #13. Diver pick up drop weight and tooling at well head. Diver out of water at 02:01 hrs. R/U and utilize crane to tail annular in with topdrive and prep to hang off below rig floor. 06/18/2023 - Sunday Continue and finish to hang annular on trolley under rig floor and r/up for single gate. Welder continue fabricate flow nipple. Work boat, P/up and drift in single gate transferring weight from crane to chain falls and trolley in same and transfer weight to blocks. Lower and stab same on riser spools and bolt up. Welder continue fabricate flow nipple. Test all gas alarms (ok). P/up and drift in double gate under cantilever beam w/ crane and blocks lower and stab same on single gate and bolt up. Welder continue fabricate flow nipple. R/U to annular and rig down tie off lines. Lower and bolt up annular to double gates. R/U and lower CSG spool valve to texas deck. Install valve, bolt up and tighten connection. Pick HCR and manual valves to rig floor and start putting together. Working on torqueing BOP flanges from bottom up, Cont. to put HCR and manual valves together tightening with hammer and hammer wrench. Clean around upper deck clearing all misc. items and rigging. 06/19/2023 - Monday Finish torqueing BOP flanges from bottom up. Finish putting choke and kill assy. together tightening same on rig floor. Install choke assembly on side port of double gate. Install kill assembly on side port of double gate. Clean and organize pipe rack and prep for boat. Working on install choke hose. Finish torquing choke hose. Install kill hose and begin torquing. Work boat. Inspect rubber and prep flow nipple sleeve to be installed. Finish torquing kill line flanges. Install koomey hoses, charge accumulator and function test BOP's, all functions were good. P/U Flow nipple sleeve, lower below rig floor through rotary. Placed a bead of silicone on rubber and bolt down to flow box. Rig Start Date End Date Rig 151 6/12/23 7/11/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Cook Inlet St 17589 1-A 50-883-10013-00-00 162-028 06/20/2023 - Tuesday Continue and finish install btm plate of flow box. Install btm section of flow nipple on annular. Hook up trip tank fill and bleed off line to flow nipple. Hook up all 4 BB winches to Bop's. re-install rotary table (not coupled up). Install upper section of flow nipple and tighten up dresser sleeve. Work boat. Continue to tighten dresser sleeve and install Top bolts. Prep for BOP pre-test. Flood test stack ok but have leak on flow box. Repair leak on flow box while monitoring fluid in stack and build test jt. Cont. fixing leak on bottom pan sleeve. Test TT to stack and inspect bottom pan sleeve for leaks= no leaks. Finish M/U 2 7/8" test jt and valve assemblies. Drained stack due to test jt floating. Installed test plug filled stack and valves up with water. Charge up final accumulator bottle bank and break in bag by functioning annular 5x staging up bag pressure to 900 PSI. Fill up choke manifold and remove air from system. Shell test BOPs on 2-7/8" test jt as per sundry. Chase leak. Leaking between single gate and spool. R/up and retorque connection to spec. retest w/ same leak. R/up to change out API ring. 06/21/23 - Wednesday Continue nip/dn and lift stack at single gate to spool flanged connection. Inspect API ring and ring grooves (ring was twisted and flared, both groves had no obvious imperfections see photos in file) re-install new API ring and bolt and torque up same to specs. Continue torque bolts to specs and nip/up flow nipple to flow box. R/up 2-7/8" test joint and testing equipment. Flood stack and purge air and retest w/ same leak @ 1500 psi. Retorque and retest w/ same leak n/d low pressure riser, l/d choke/kill hoses and choke valves, split stack at top of single gate and move dbl gate and hydril off to the side. Cont. n/d single gate/drill spool and l/d same using crane and r/u slings to tail out from under rig. Set single gate on deck and n/d from drill spool- Inspect API ring and ring grooves (ring was twisted and flared again, both groves had no obvious imperfections see photos in file)Simop-l/d test jt and LP riser off rig floor. 06/22/23 - Thursday Continue set single gate on deck and n/d from drill spool- Inspect API ring and ring grooves (ring was twisted and flared again, both groves had no obvious imperfections see photos in file) Chk test spool and riser for level. Good both directions. Install double gate and annular on test spool and torque bolts to specs first round. Finish first round of torque sequence and perform 2nd round. Reinstall both choke and Kill valve assembly and hook up all 4 BB winches and install choke hose. R/d BOP handling equipment. Work boat P/U and break dwn 2-7/8" test jt. assy, M/U 5" test jt. assy. Run 5" test jt. and land out in test plug. Fill stack, choke manifold and top drive w/water. Shell test 16- 3/4" 5M BOp w/5"test jt. 250psi low/ 1400psi high for 5 minutes on chart. Pressure dropping and observed leak at surface of Hydril element. Massage element by opening and closing element while increasing annular pressure f/500psi t/1100psi. Cont. testing 16-3/4" 5m BOP w/5"test jt. t/250 low/ 1400psi high f/5min. each on chart. Test allcomponents-Hydril, 5" top rams, cmv's and chokes, choke/kill HCR's and manual valves, top drive IBOP's, floor valves and dart valves. Rig Start Date End Date Rig 151 6/12/23 7/11/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Cook Inlet St 17589 1-A 50-883-10013-00-00 162-028 06/23/23 - Friday Continued and finished Pre-testing 16-3/4" 5m BOP w/5"test jt. t/250 low/ 1400psi high f/5min. each on chart. Test all components-Hydril, 5" top rams, cmv's and chokes, choke/kill HCR's and manual valves, top drive IBOP's, floor valves and dart valves. with one failure. TDS IBOP having issue shifting. Chg out TDS Upper and lower IBOP. Work boat. Welder finished adding extension on lower 24" flow nipple N/U upper and lower bell nipples, adjust BB winches to center well. Run in 5" test assy, fill stack and choke manifold, top drive and test assy. Work out air from system while attempting shell test. Witness waived by AOGCC Rep. Jim Regg. Test 16-3/4" 5M BOP's, Choke manifold, top drive and floor valves t/250psi low and 1400psi high f/5min. on chart as per AOGC and Hilcorp policy. Koomey Draw down: initial press=3050psi, final press=2200psi, 200psi attained=23sec., full recovery=2min. 36sec., avg. bottle=23@2350psi. 16-3/4" 5m annular=23sec., 5" upper rams=21sec., blind rams=22sec.HCR's=2sec. R/D test equipment. 06/24/23 - Saturday Finish l/dn test equipment. C/O saver sub from 4-1/2" CDS-40 t/ 4-1/2" IF. Pressure up rigs HP mud system and check all connections and monitor sensor and gauges and pump up two sensor, good test t/ 4000 psi. P/up and m/up 5" donut test jt w/ side entry sub and slick line w/ 1-1/2" tool string w/ 2" RS w/ steel pin in sheer up position and lock in to 5" rams and test same t/ 1400 psi -good. Slack off riser tensioning system and monitor action in tide. Attempt test riser w/ test pump, pumped 63 gal t/ achieve 1540 psi w/ 100 to 130 psi per min initial loss rate and bleeding t/ 268 psi in 23 min while checking all above water connections- good. discuss options with town. Continue Pressure up t/ 1500 and monitor Loss rate w/ total of 2.8 bbls pumped and monitored bleed dn to 40psi and pressure dumped to 0psi in 2-1/2 hrs. Opened well and observed and monitored static riser. Attempt test riser w/test pmp pumped 66gal t/1450psi w/97 psi/min loss rate for first 10min.. Pressure up again pumping 17gal t/1495psi w/99 psi/min loss rate for first 10min.. Pressure up again pumping 18gal t/1445psi w/110 psi/min loss rate for first 10min. Let bleed down t/37psi and pressure dumps t/0 psi in2hrs. Opened well and monitored static riser. Observe static loss's of .4 bbl/hr. Rig Start Date End Date Rig 151 6/12/23 7/11/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Cook Inlet St 17589 1-A 50-883-10013-00-00 162-028 06/25/23 - Sunday Continued monitoring loss rate in riser. Initial static loss rate of .4 BPH. and slowing dn to .16 BPH R/dn slick line and side entry sub along w/ riser testing assembling. Remove riser lifting plate form std of 5" in derrick and rack back same. Waiting on weather to p/up rack back work string wind @ +35 mph w/ gust to 45 mph. Continue monitor loss rate and lower derrick belly finger in prep for racking back 2-7/8" dp. Winds have subsided enough to put cranes back in service. P/up Bha # 1 = 11-1/4 short catch O/S w/ no grapple and painted ID + XO + XO = 9.22' P/up 3 jts of 5" 19.5 # s-135 DP and run std out derrick + 10' pup and tag top of mandrel @ 193.85' RKB rolled off and swallowed t/ 194.55' (.70' ) R/up to blow well dry w/ air first circ was able to maintain 115 psi air pressure and recovered 59.8 bbls. Observe top water for bubbles none observed (water is still very rough and foaming) bleed dn air pressure open bag dump water from top of annular up to rig floor. Close bag and blow well dry second circ recovered more 8 bbls. for total of 67.2 bbls out of 70 bbls calculated. 2.2 bbls shy pressure up well t/ 115 psi and observe top of water for bubbles w/ same results. Bleed dn air pressure. Pooh rack back stands and inspect Bha w/ good indications of scrapes on painted ID tag of full swallow. R/up tong unit and handling equipment and prep. p/up rack back 2-7/8" PH-6 work string out of mouse hole t/550' RIH t/194' w/Yellow jacket 11-1/4 short catch O/S w/ no grapple and land out on depth, POOH and verify water level @27" and no apparent influx of water from Cook Inlet after evacuating water out at 15:30hrs. Close blind rams and pressurize riser w/120psi air, observe top of water for bubbles- none seen. Leave air on riser to insure riser is evacuated of water and create bubbles if leak exist for divers to witness on AM low tide. Crew perform environmental hazard hunt focusing on spill prevention: leaks, drips, equipment in poor condition, hoses, connections and containments. C/O old check valve on fill up line. Cont. p/up rack back 2-7/8" PH-6 work string out of mouse hole f/550' t/3300', 36 stds in derrick and 2 jts on the deck for 110jts total. C/O tong hanging line in derrick. Crew perform environmental hazard hunt focusing on spill prevention: leaks, drips, equipment in poor condition, hoses, connections and containments. Prep for dive on 20" riser and observe for air bubbles. Rig Start Date End Date Rig 151 6/12/23 7/11/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Cook Inlet St 17589 1-A 50-883-10013-00-00 162-028 06/26/23 - Monday Continue Prep for dive #12 and continue to hold 115 psi air pressure on riser under blinds (16 hr of hold time ) and rig maintenance M/V Sand Island on location for the 15 time for dive #12 diver in water 07:47 hrs. Inspected sub sea connection for bubbles inspect both flange connections and slip lock connection w/ no bubble observed. Diver out of water @ 08:05 hrs and relay info to town. Continue Rig maintenance changing out DWK line guide rope. Bleed off air pressure and open riser. RR bha #1 t/ 194.55' to confirm fluid level. Pooh inspect pipe and bha no fluid level found. Dry t/ 194.55'. Rih back in hole t/ 194.55' and R/up wire line side entry sub. Wait on orders continue with rig maintenance. M/V Sand Island on location for the 16 time for dive #13 diver in water 13:28 hrs. Diver torqued 12 of 16 bolts on top flange of 72" riser spool w/ no movement. Diver out of water @ 13:54 hrs. Wait on orders and continue with rig maintenance, work boat and take on cmt, expedite N2 and equipment. Orders to re-test riser t/500psi w/N2 and divers in the water to verify no leaks as soon as equipment and N2 arrives tomorrow afternoon. M/V Sand Island on location for the 17 time, current was to strong-try again in the morning. L/D wire line lubricator, POOH f/194' and rack back BHA#1. R/U 4.5" handling equipment and p/u, rack back 3stds(9jts dp). Rig maintenance and Pressure test 4.5"IF FOSV t/250 low-1400 high while waiting on N2 equipment. 06/27/23- Tuesday Continue Rig maintenance while waiting on N2 equipment. M/V Sand Island on location for the 17 time at 08:17hrs, attempted dive # 14 and aborted due to strong surface current. Diver in water at 0851 and out of the water at 0853. Wait on high tide. RR BHA #1, with over shot & no grapple. Tag on depth and drop on on depth at 194.55'. Pull out and no fluid observed on markers dry pipe. Dive boat on location at 1347 for high tide. Dive #15. Diver in water at 1405. Dive out of the water at 1425. Got all the remaining bolts checked. All upper flange bolts checked and no movement. Got minimal movement out of sliplock flange. Work boat with nitrogen equipment. SLB crew on location at 1700. Rig orientation. Go over plan. Rig up nitrogen equipment w/Schlumberger f/N2 pmp unit t/rig floor KLV#17 to BOP's, blinds closed, choke HCR closed and std pipe bleeder choke t/2"HP hose to dwn under rig outside. Cont. rig maintenance-c/o #2 pulsation dampener. Pressure test N2 lines to KLV #17 w/2500psi-good. M/V Sand Island on location for the 18 time at 0230 hrs for dive # 15. Schlumberger pressure up 20" HP riser t/250psi and maintain pressure w/N2 pmp. Divers checked sea floor, slip lock wellhead , 20" flanges X2 and csg connection with no visual sign of leaks (bubbles). Rig hand also looked for leaks from Lower walk-a-round on ocean surface water with no visual sign of leaks (bubbles). Diver in water at 0255 hrs and out of the water at 0315 hrs. Monitor bleed down of 20" HP riser on test chart, no pressure loss after 1hr. Bleed off N2 pressure from well to vent. Open up well and RIH w/BHA #1 and 5"dp t/194.55', Blow down f/ 5"dp thru annulus t/std pipe vent w/rig air. Rig Start Date End Date Rig 151 6/12/23 7/11/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Cook Inlet St 17589 1-A 50-883-10013-00-00 162-028 06/28/2023 - Wednesday Fill hole with FIW. Purge air our of system. Pressure test to 1400 psi staging up and monitoring Pressures. Last 5 min on chart showing 4 PSI per min. Sent chart to Jim Reg for approval to proceed on well. Approval Received by email at 1300. 500 Psi, 5 min 24 Psi Lost Total, 10 Min- 30 PSI Lost Total,15 Min- 34 PSI lost Total,20 Min 35 PSI Lost Total. 800 Psi- 5 Min- 14 Psi Lost Psi , 8 Min 16 Psi total Pressure lost. 1000 PSI 5 Min 18 Psi Total Pressure lost, 1290 PSI , 5 Min 40 PSI Total Pressure lost, 10 Min- 65 PSI Total Lost, 15 min- 83 Psi, 1440 5 Min 32, 10 Min- 52 Psi Total,Bump up to 1472 psi. , 8 Min- 34 Psi Lost Total. R/U Slick line adding 30' of 5'' Dp for lubricator' extension. M/U LIB & wire & Run through side entry sub. Test Lubricator to 1400 psi against TIW Valve. Found leak on side entry side connection. Tighten and retest Good. M/U 1.85 LIB & RIH. Tag btm and work spangs. POOH & Bump up. Break out extension and tool stuck in side entry sub. Attempt to work spangs from btm. No luck. Break off Bowen connection from side entry sub. Free tool. Inspect LIB. No impression from BPV. Only from trying to free tool from side entry sub. RIH with run #2 with 1.75 LIB. POOH & LIB showing small dibrese signs. M/U 1.75 Pump baler. RIH with #3 run. Work pump balor & POOH. Recover 1 cup + small debris. Scale & pipe junk. RR 1.75 Pump baler run#4, nothing recovered. Brk off bailer and run 1.75 LIB run #5, perfect impression of a 1"fishing neck. Brk off LIB. M/U 2"RS w/prong run #6, apply 550psi t/DP/annulus for equalizing, POOH -no-fish- but marks on the prong. RR 2" RS w/o prong run #7, apply 460psi back pressure. latch fish and hit jars 14X,sheared pin and POOH w/no-fish. Brk off 2"RS and p/u JUS run#8, apply 250psi back pressure, couldn't latch up, pooh w/fish. Brk off JUS and fish. P/U 1.68"gauge ring w/1.84 stab run #9, RIH t/1450'-1460'SL, wire line encounter resistance, work up and dwn w/no progress. POOH and l/d accelerator and p/u another weight bar. RR gauge and stab run #10, RIH t/1450'-1464'SL, work tool string up/dwn w/no progress. POOH and L/D tools. R/D slick line. Clean and clear rig floor. P/U fishing BHA #2. and RIH t/193.83'. Engage fish and work as directed by YJ fishing rep., working in right hand torq 1/4 turn at a time and overpulling in 5k increments to 20k over and 2 full turns into hanger. Rig Start Date End Date Rig 151 6/12/23 7/11/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Cook Inlet St 17589 1-A 50-883-10013-00-00 162-028 06/29/2023 - Thursday Continue to work 30k over pull on hanger. Discus options with Well head supervisor. Decide to try left hand rotation. Turned at 1/4 intervals and got torque at 1.5 turns. Continue to work 30K over pulls attempting to fire jars. Jars jus bleeding off slow. Discus options with Well head supervisor. Decide to Rot to the right 13 turns. Rot 2 turns at a time attempting to pull 30K over. At 13 turns pulled free. Stood back 5'' DP & 3 1/8 DC. Work BHA. Recovered fish. Hanger and 1 joint of 2 7/8 Tubing. L/D same from overshot. Pics in folder. Monitor well . Well static. Change top ram change to 2 7/8 & Prep for full bop test. BOP test witness waived by Jim Reg over the phone with Hilcorp well engineer. M/U 2-7/8 test jt and 2-7/8' floor valves x4, r/u test pmp and install test cap on top drive, set test jt w/plug in hole, fill stack/choke manifold w/FIW and purge air. R/U chart recorder. Test 16-3/4" 5M BOPE w/2-7/8" and 5" test jts w/FIW 250psi/low and 1400psi high 5min./charted. Test Hydril, upper 2-7/8" rams, Lower Blind rams, choke/kill HCR's and manual, CMV, top drive, koomey draw down and gas system. As per AOGCC and Hilcorp policy. 2 test complete @ 0500hrs, trouble shooting Hydril w/2-7/8" test jt. Isolate to Hydril/ manual kill and choke valves against floor valves on test jt. Pull test jt and inspect, small imperfections at sealing area on jt, M/U ported sub on btm of jt t/move sealing area and attempt t/re- test-fail, hydril bubbling around the sealing edge of the element and the case. Re-test w/1500 closing pressure @2000psi-fail. 06/30/2023- Friday Continue to attempt Test 16-3/4" 5M BOPE w/2-7/8" and 5" test jts w/FIW 250psi/low and 1400psi high 5min./charted. Unable to get test on 2 7/8 test joint on annular. Try and heat fluid. Massage annular cycling. Pressure up with various pressures trying to get it to hold. No luck. Visual leak at element. Swap test joints to 5''. Had to reset the test plug. Massage annular cycling. Stack fluid heating up utilizing camp hot water. Test annular on 5'' test joint against test plug. 250/1400 psi. Good. Receive approval from state to make clean run out on 2 7/8 utilizing the 5'' safety joint XO to 2 7/7 PH-6. Continue to heat fluid in the stack while. Continue Testing all other valves & components as per procedure against annular & 5'' Test joint to 250/1400 psi. Fail on manual kill valve-regreased and failed, close Kill HCR (will replace manual kill valve). R/D 5" test jt. and M/U 2-7/8" test jt., R/U to test blinds. Attempt to test Blind rams, LKV, manual choke valve to 250/1400psi. Fail on manual choke valve-re-greased and flushed valve- failed, close choke HCR (will replace manual choke valve). LKV fail, take off-line and service/grease and flush. Slow leak on blind rams, bleed off pressure and flush and function, re-test-good. Attempt to test 2-7/8" jt on Annular, massage annular cycling element and fill stack w/hot water, increase closing pressure to 1500psi, step up pressure in 200-300psi increments t/1000psi with no sign of stabilizing pressure. Bleed off pressure and l/d 2-7/8" test jt. Evacuate H2O f/stack and pull test plug. Start C/O upper 2-7/8" rams f/5" rams(for safety joint) and replace choke/kill manual valves. Rig Start Date End Date Rig 151 6/12/23 7/11/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Cook Inlet St 17589 1-A 50-883-10013-00-00 162-028 07/01/2023 - Saturday Change out failed Manuel Choke and kill valve. Change top rams from 2 7/8 to 5'' & Secure Texas deck same. Send in 2 3/8 hanger to wellhead supervisor to have pack off releasing tool manufactured. Test Lower kelly valve on top drive 250/1400psi f/5min. on a chart-good.M/U 5'' test joint & set test plug. Test 16-3/4"5M BOP-upper 5" rams against HCR choke/kill and 5"fosv 250/1400 f/5min. on chart-good, test Upper 5"rams against manual choke/kill valves and 2nd 5"fosv-good. Test chokes 9,10 and 12. Test Accumulator draw down. R/D test equipment, pump and pull test jt/plug. L/D same. R/U handling equipment for 2-7/8" BHA, Pre-job w/crew, Yellow Jacket and Parker Wellbore. M/U BHA #3 as per Fishing Rep., surface test mud motor, p/u bumper, jars and 6 DC. t/216'md (ORKB=126'md), monitoring displacement on the TT. RIH f/216'md (ORKB=126'md) t/775'md. (ORKB=685'md) 07/02/2023 - Sunday Continue to RIH with 4 1/8 BHA on 2 7/8 DP on elevators T/ 1132'. Build safety stand of 5'' with FOSV before washing and reaming. RIH on elevators T/ 1315'. Swap to 5'' wash stand & Stage up pumps to 3 bpm at 600 psi. Displace mud out of well & catch in sand trap. Mud coming back 9.0 Mixed with FIW. Doesn't look or smell bad. Pump total of 130 bbls before taking returns to pits. Wash down at 3 BPM F/ 1315' T/ 1464'. Tag at 1464' at 1K WOB & saw deferential pressure increase. P/U & wash back down through clean. Wash down to 1590' utilizing 5'' wash stand running 2 7/8 below. RIH with 2 7/8 on elevators F/ 1590' T/ 2043'. Make up wash stand and break circulation at 3 BPM with pressures starting at 780 psi and slowly dropping on the first 30 bbl pumped to 690 psi. Pump 130 bbl taking returns to active system. Still seeing diluted mud. 9.0 MW. RIH on elevators F/ 2043' T/ 2458'. Tag up 10K. Kelly up wash stand & wash down at 3 bpm seeing differential pressure for 3' then fell off. Wash down to 2505' & Circ liner clean at 3 bpm. Wash down to 2599'. Attempt to pull the 5'' to jockey stands for safety stand and MW is heavy on t he back side. Circ btm up. Check balance. Good. POOH with two stand of 5''. RIH with 2 7/8 & Continue washing dwn w/5" stds at 3 bpm @ 615 psi. F/ 2599' T/ 3129', soft tag w/10k dwn and 42gpm. Circulate B/U x2 @3bpm / 700psi. Dry tag top of plug @3129'DP w/15k set dwn (126' ORKB @ 0 tide) (194' 151 RKB). POOH f/3129' t/30', L/D clean out BHA as per Yellow Jacket Rep. P/U and M/U CBL and RIH T/ 3129', monitoring displacement on the TT. Rig Start Date End Date Rig 151 6/12/23 7/11/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Cook Inlet St 17589 1-A 50-883-10013-00-00 162-028 07/03/2023 - Monday Make CBL F/ 3129 ' to surface. Send logs to town. Looks like no cmt behind pipe. R/U Grease head for full pressure control. Space out with 5'' donut and 5'' Joints for lubricator extension. Shut top pipe rams on 5'' Donut. R/U E line through side entry sub. Load casing punch in pipe. Fill lines with water for pressure test. Close TIW to test against. Pressure test lubricator to 250/1400 psi. Good. RIH with Eline. Unable to get in to 5'' LT. Make several attempts but tool falling on side between 20'' & 5'' hanger. Work cable by hand and still unable to get it in due to magnets and decentralization. Decide to R/D wire line and R/U to run 5'' DP to wellhead then rig up same. R/D Side entry sub & Wireline. Break down stand of 5'' pipe for space out to wellhead. RIH with 5'' Donut joint 5 joints of 5'' dp & 20' DP pup to space out to rig floor. Tag top of 5'' hanger. Load wire in side entry sub & install punch tool with 3' of shots. 18 1/4 in shots. R/U E-line grease head, lubr. f/subsea wellhead t/Rig floor, E-line swivel & side door assy. RIH w/1.69"CCL & 6 shot/ft, 18 total, 3ft gun t/3096'ELM, P/U 10' and punch 5"csg f/3095'top shot t/3098' btm shot, w/well shut in and 527psi on csg. POOH w/e-line, w/Monitoring well f/30min. csg press bled t/223psi. Bleed off residual psi, open well. Break dwn Lubr., L/D guns-all shots fired. P/U new gun w/same set up (6 shot/ft, 18 total, 3ft long). RIH w/1.69"CCL and 3ft gun t/252' ELM, P/U 6' and punch 5"csg f/253'top shot t/256'btm shot, w/well shut in and no back pressure held. POOH w/E-line w/monitor well f/30min. no pressure build. Open well. L/D E-line tools and break down lubr., all shots fire. M/U Yellow Jacket 5"csg cutter and XO, as per Fishing Rep. RIH t/199, issues getting dwn, POOH and inspect tool-works fine, suspect friction pads. RIH again t/214, working down but still stacking out. POOH, L/D Yellow Jacket Cutter and P/U Bakers hyd. csg cutter w/3.75 cutters, surface test same-good. RIH w/3.75" Baker hyd. cutter t/3104', monitoring displacement on TT. Rig Start Date End Date Rig 151 6/12/23 7/11/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Cook Inlet St 17589 1-A 50-883-10013-00-00 162-028 07/04/2023 - Tuesday RiH with BHA #4 & set cutter on depth at 3104', Corrected RKB to ORKB 3104'-82'= 3022'. Establish parameters. ROT wt 80k. Rot at 50 RPM and stage up pumps to 3 blm at 580 psi, 1.5K TQ. Saw pressure jump to 1080 psi. Consult with baker and yellow jacket. Continue to stage up pumps to 4.5 BPM & 1500 PSI. Never saw an increase in tq. ROT 1.5 hrs total. Bleed off pumps and monitor well. Static. Inspect POOH F/ 3104' to surface. Inspect cutters. Cutters showing good sign of fully open and good cut. L/D cutter. Break down overshot BHA #3. M/U BHA #5. 5'' Spear & extension bumper sub, Jars, 3 - 4 3/4 DC, accelerator. P/U 5'' Donut & Break out BTC Xo for well control for 5'' casing. RIH & Engage 5'' Casing. Blocks & BHA 60K. Fish wt calculated at 55K. Start over pulls working wt up to 60 K over letting jars bleed off. No movement. Start jarring at 30K over working jar hits up to 60K over. 165K-180K Started making inches and continued jarring until pipe started working free on strait pulls. Working stand up 65' and back down getting free pipe movement at 125K. Shut down for derrick inspection & prep to L/D hanger & BHA. R/U wash down hoses. POOH with 5" hanger racking back 1 std of 5" DP and 1 std of 4 3/4" DC's. L/D accelerator and oil jars. Pulled up to hanger. Broke of hanger from pup jt and L/D with spear and bumper subs. PJSM, POOH sideways with 5" CSG. strapping on the way out. L/D 2 pups and 34 full jts. to projected 1744'. On the 16th jt out well started to u-tube shut down hole fill and well equalized, fluid level in the stack was down 8'. Pulled 4 more jts with hole fill off with no flow out of tbg. Turned hole fill back on with no other issues. Cont. POOH sideways with 5" CSG. L/D 43 more full jts for a total of 77 jts- 2 pups- 10.12' cut jt and 2.51' hanger. Total footage of CSG L/D 2905.41' plus 2.51' hanger= 2907.92'. Swap elevators to 2 7/8, change out parker power tong dies. Clear and clean rig floor. RIH with 2 stds of 2 7/8" drill collars and L/D. PJSM, M/U clean out BHA #6, 6 1/8" bit, bit sub, fishing jars, 1 std of 4 3/4" DC's and 2 XO's back to PH-6 for a total length of 111.75'. Rig Start Date End Date Rig 151 6/12/23 7/11/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Cook Inlet St 17589 1-A 50-883-10013-00-00 162-028 07/05/2023 - Wednesday RIH on 2 7/8 DP F/ 200. To 3013'. M/U 5 Stand and wash down and tag at 3027'. Wash & Ream down to 3048'. Driller noticed a DP pressure loss . Driller shut down and did a flow check. Well flowing out of the annulus. Driller shut in top rams. Pressures were checked on Dp & casing and were showing 0. Fluid wts in the pits showing active system wt climbed due to returns from old mud coming back heavy. Dp was dry. Well out of balance. Displace well to clean FIW. Monitor well. Static. Open up rams. Wash and ream to casing cut at 3104'. Circ clean at 10 BPM 25 RPM. POOH & stand back 4.75 DC, L/D BHA. R/U Eline for open hole CBL of 7 casing. RIH & perform CBL F/ 3050' to surface. Send logs to town. Looks like cmt from stage tool to 700'. Stage tool at +/- 270'. R/D Eline & install 5'' space out and pressure control for 7'' punch runs. R/U E-line and PT 250/1500 for 5 min each. Sim-ops pressure test cement unit and lines to rig floor T/3000 PSI- good test. RIH with 1.69" CCL W/18 shot 6 FSPF string shot to 3100'. Locate collar at 3075'. Correlate and apply 300 PSI on the annulus and fire punches, pressure after shot- 270 PSI. Top shot @ 3080' Bottom @ 3083'. POOH and Monitor well for 30 min. Pressure bled from 270 PSI to 80 PSI in that time. Opened choke no gain no flow well static. Change out punches and RIH with new punches T/3100'. Locate collar at 2985'. Correlate and apply 120 PSI on the annulus and fire punches, pressure after shot- 106 PSI. Top shot @ 2977' Bottom @ 2980'. POOH and Monitor well for 30 min. Pressure bled from 106 PSI to 56 PSI in that time. Opened choke no gain no flow well static. Change out punches and RIH with new punches T/290'. Correlate with stage collar @ 270'. Locate first collar above stage collar. Space out and fire punches .Top shot @ 238' Bottom @ 241' WLM. (Top Shot 30' Below Mud line. ) Monitored well for 20 min. No pressure. Opened choke well was static. R/D E-line pressure control equipment and 5" assembly. Monitor well via trip tank. Clear and clean rig floor. P/U and M/U 7" CMT Retainer and XO ( 6.99' ) RIH T/280' on 2 7/8" PH-6 DP. Rig Start Date End Date Rig 151 6/12/23 7/11/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Cook Inlet St 17589 1-A 50-883-10013-00-00 162-028 07/06/2023 - Thursday RIH as per Yellow jacket with 7'' cmt retainer on 2 7/8 PH-6 pipe T/ 2846'. Change handling equipment to 5'' & RIH with 5'' stands. Space out & R/U to set retainer & perform cmt job. Set retainer at 3025'as per Yellow jacket packer tool hand. Verified tool set & over pull 40K. Set down 10K. Pull out of retainer. R/U Circ lines. Sting in & try to establish circ through perfs for suicide squeeze. Pressure up to 500 psi max. Bled down to 350 in 5 min. Pressured up three times with same results. Consult with Hilcorp well engineer and AOGCC & decision made to set balanced plug on top of retainer at 3025'. Top of plug. Unsting out of retainer & prep for 13 bbl balanced plug. PJSM Spot balanced plug. Circ 50 bbl to verify tubing is clear. Good. Line up and fill lines. PT to 500/ 2614 psi. Good. Pump 5 bbl fresh water ahead, pump 13 bbl 15.8 ppg cmt (67 sks) followed by 5 bbl fresh water. Displace with 8 bbls of FIW. Break off circ lines & equipment. Pull out of balanced plug slow F/ 3025' T/ 2479'. M/U circ equipment and shut top rams on 5'' pipe. Reverse circ at 3 bpm 180 psi flushing lines from cmt job. Monitor well. Static. R/D circ equipment. POOH F/ 2479' to surface & l/D Running tool. 7'' plug tag AOCGG witness waived by Jim Reg at 2:52 7-6-2023 by phone call to drilling Forman. P/U and Remove 5" hanger from spear assembly. B/D spear assembly and clear and clean rig floor. M/U BHA #8, 6 1/8" bit, Jars, and std of 4 3/4" DC and RIH on 2 7/8" pipe T/2583'. M/U 5" std and WOC. Break circulation and pump 1/2 BU @ 4 BPM, 322 PSI no rotation. Wash down F/2583' T/2708 at 2 BPM, 87 PSI. At 2694' started to see pressure slowly increase to 125 PSI and 2-6K drag down to 2708' setting 17K down 2 times. PU 83K SO 83K. POOH T/2685' and circ 1.5 BU at 8 BPM, 1150 PSI. Racked back 2 stds of 5" DP T/2583' and monitored well while working boat. Prep rig floor to L/D 2 7/8" PH- 6 pipe. Took on fuel and drill water. Offload dirty fluid from Pit #2 to iso's. Serviced top drive. POOH laying down 2 7/8" PH-6 pipe F/2583' T/150', RIH with last 9 stds of 2 7/8" T/1132'. Cont POOH L/D 2 7/8" pipe F/1132' T/112'. Rig Start Date End Date Rig 151 6/12/23 7/11/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Cook Inlet St 17589 1-A 50-883-10013-00-00 162-028 07/07/2023- Friday L/D yellow jacket 6 1/8 plug tag BHA #8, R/D Parker Wellbore 2 7/8" power tongs and pipe handling equipment and remove from rig floor. B/D 5" safety std. Remove all unneeded equipment from rig floor. M/U Baker 5.5 Hydraulic cutter BHA #1 installing 7" x 9 5/8" multi-cutters, RIH locating collar @ 375'. Space out to 377', Cut 7" and 9 5/8" CSG. 212 GPM, 800 PSI, 100 RPM, 1.2K-1.5K TQ, Observing 650 PSI pressure drop. POOH and L/D Baker Hydraulic cutter BHA. Inspect cutters- good indication cutters fully opened to 12 3/8" OD. M/U YJ 7" Spear BHA #9 with 6.22" grapple, jars,1 std 4 3/4" DC, Accelerator and engage spear in 7" hanger. Start over pulls and working bumper sub back down setting 30K down. Jarring at 100K over free weight straight pulling to 190K with no movement. Release spear and swap jts around for space out on CSG Jacks. Re-engage spear, R/U CSG Jacks and Perform post jarring derrick inspection. Stage up pull weight on CSG Jacks starting at 200K up to 420K max pull. Attempted to free pipe multiple times with no movement. Discussion with well engineer to R/D and make another cut. R/D CSG jacks, Release spear and L/D spear assembly. Service and inspect top drive after jarring operations. M/U Baker 5.5 Hydraulic cutter BHA # 2 W/ 7" x 9 5/8" multi-cutters, RIH locating collar @ 237'. Space out to 235', Cut 7" and 9 5/8" CSG. 6 BPM, 920 PSI, 100 RPM, 1.2K-1.5K TQ, Observing 775 PSI pressure drop. POOH with Hydraulic cutter BHA #2, Inspect cutters- Good indications on cutter that blades opened fully to 12 3/8" OD. Mobilize YJ 7" spear assembly and Baker 6 1/4" jars. M/U Spear, spear extension and stop. Rig Start Date End Date Rig 151 6/12/23 7/11/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Cook Inlet St 17589 1-A 50-883-10013-00-00 162-028 07/08/2023 - Saturday M/U BHA # 6.22 Spear assembly with 6.25 jars, Bumper sub & accelerator. RIH & engage 7'' casing. had to rot to get in hanger. UP/DN 60K. Work over pulls up to 180K starting to jar at 100K over. Work jar hits up to 140K over and strait pulls to 220K. No movements. Hit jars 82 Times with no movement. Attempt to turn to the left. Stalled out at 7K. Turn to the right and disengaged grapple. Engage grapple. Perform rig inspection & Rig up casing jacks. Warm up jacks. Pull jacks up to 470K. Work jacks for 1.5 HRs. No movement. New spear on location able to pull up to max DP strength at 560K at 80% DP. R/D Jacks. Leave rams on rig floor. Disengage grapple. POOH & Change out spear. RIH and engage grapple. Decision was made to L/D spear BHA and RIH with 7" CMT retainer. POOH and L/D Spear assembly, 6.25 jars, Bumper sub & accelerator. R/D casing jack unit and remove rams from rig floor. Remove unneeded tools and equipment from floor. M/U Bakers 7' CMT retainer, 6 jts of 2 7/8" PH-6 and RIH to 362' on 5" DP. PU 60K SO 60K. Set retainer with 12 turns to the right slack off and pull to 100K ( 40K over ) 3x's. Turn right 4 turns set down 5K and pull free. Plug Set @ 362'. Center of element @ 360'. Sent notification to AOGCC for cmt tag at 21:00 hrs 7-8-23. R/U Cementing assembly with side entry sub. Attempt to establish circulation through cuts with no success. Un-stung from plug couldn't establish circulation through cmt line. Lined up through top drive and broke circulation at 2 bpm-45 psi. Stung back in to establish circulation through cuts with no success. Pressured up to 300 PSI 2x's with no bleed off. Cleaned out cmt line finding cmt plug above block valve below 90. Blew air and flushed lines. Rig cmt line back up. CMTR's pumped 5 bbls of fresh water. PT lines 806 psi low, 2565 psi high. Lined up and pumped 13 bbls of 15.8 PPG cmt (60 sks) 1.5 bpm 105 psi, displaced 2 bbls of FIW 1.5 bpm, 48 psi. R/D cement line and side entry assembly. POOH spacing out to 200' ( 5' inside 7" hanger ) Closed upper pipe rams and reversed out access cmt 2 bpm, 150 psi with 5 bbls of good cmt returns to surface. R/D cmt line open upper rams and circulate the long way at 2.5 bpm pulling out of 7" hanger and increasing rate to 8.5 bpm, 300 psi, 30 RPM's. R/D side entry assembly. POOH racking back 1 std of 5" DP and laying down 2 7/8" PH-6 pipe and retainer running tool. P/U Stack wash tool and xo and stand of 5" DP. Flush stack. R/B stand of 5" DP and L/D Stack Wash tool. Rig Start Date End Date Rig 151 6/12/23 7/11/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Cook Inlet St 17589 1-A 50-883-10013-00-00 162-028 07/09/2023 - Sunday R/D 2 7/8 Handling equipment. Clear floor. l/D 4.5 DP from Derrick. R/D Parker wellbore hyd unit. M/U BHA #13 6 1/8 Bit, DC & 5 DP & RIH to Hanger top at 196. RIH 5 to verify casing top free of cmt. Pull out of casing and circ 20 bbl to clear pipe. WOC. Remove Choke and kill hose from stack. Remove HCR choke and kill from stack. Remove half the bolts from BOPs Prep for N/D. WOC. Had Platform fire drill and the abandon ship drill. All hand reported to life boat. Wash down at 2 bpm through Hanger at 195'. Had to rot in. Wash down to TOC at 201'. Tag 15K. Drill cmt F/201' T/ 218' at 250 GPM 50 RPM, 75-150 FPH. Circ 7'' casing and riser clean at 600 GPM. Saw good cmt back. RIH & Tag at 218 at 2 BPM 17K. Good. POOH & L/D BIT. M/U 5.5 Hydraulic cutter with 7"x 9 5/8"x 13 3/8" multi cutter blades (Max OD= 21.338") RIH on 1 std of 4 3/4" DC and 2 stds of 5" DP T/214'. Pumped @ 7 BPM 1200 PSI and worked pipe to verify no collar in cut location. Shut down pumps. Start rotation 70 RPM, 1K TQ. Cut 7"x 9 5/8" x 13 3/8" at 7 BPM, 1300 PSI, 70 RPM, 1K-1.5K TQ. Increased pumps to 8 BPM, 1660 PSI. Observed 2 pressure drops of 650 PSI increasing pumps both times up to 11 BPM, 580 PSI with a final pressure drop of 240 PSI. POOH racking back 2 stds of 5" DP and 1 std of 4 3/4" DC's. Inspect cutter seeing good indication on blades fully opened with CMT residue on blades. P/U 6.22 grapple spear assembly, Bumper subs and RIH on 2 Stds of 5" DP. Engage Spear in 7". Drain stack and remove dresser sleave on bell nipple. 07/10/2023 - Monday Remove bolts from bell nipple dresser sleeve to allow for movement. Slack off winches and tension system. Work pick up wt to 220K. Started getting movement. Continue to work up and down until 17 of free travel at 170K. Circ through spear clearing out cmt and debris from cut & back side. No returns. Flush riser with FIW. Fluid dropped to sea level. Set back down. Hook up tension system & BB winches. Release grapple & POOH & L/D spear assembly. L/D 4.75 DC from derrick & unneeded 5'' DP. Break down Test joint. Clean and clear rig floor from handling equipment. Received email from AOGCC Jim Regg that the cmt tag witness is waived. Work boat. Prep equipment for removal. N/D Bell nipple and seal plates. Prep BOPs for N/D. Remove pull bell nipple & L/D Same. Install 16' lift plate and pick up slings to annular. N/D annular and double gates and tail out under cantilever utilizing crane. Remove cover and pull rotary table. Stage rotary table on deck. Remove rotary cover and polution flange from bottom of flow box. Remove valve from CSG spool. N/D and pull CSG spool, spacer spool and DSA assembly. R/U false rotary, remove all tools and equipment from Texas deck. Stage Doyon 20" false bowl on rig floor. Rig Start Date End Date Rig 151 6/12/23 7/11/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Cook Inlet St 17589 1-A 50-883-10013-00-00 162-028 R/U Doyon 20" double stack tongs. Modify false rotary beams to allow more space from rise flanges and fairings to go through. M/U 5" DP and lift plate to Riser top. Remove tensioner system from riser. Gather all tools and equipment to remove fairings and anti-rotation keys. Go through MP #3 and start removing 6" liners and prep for 6 1/2" liners while waiting on slack tide. Pull 20" riser removing fairings to rig floor and L/D. Break bolts and remove 78" riser spool from slip lock well head and L/D spool. Attack picking slings to well head and pull well head and cut casing and L/D same. R/D Doyon 20" handling equipment, false rotary w/associated equipment and prep for boat. Remove all tools, rope and unneeded equipment from Texas deck. Remove hydraulic lines and cap inlets to tensioner cylinders. Work boat back load Parker tong power pack, Doyon 20" handling equipment, 20" riser, DSA 16 3/4" Tubing spool and 13 5/8" spacer spool. Remove all 4 tension cylinders and metal slings, Install centrifuge in pits and set in place. Install toe caps on pre-load tanks for rig move. Lift Texas deck to skidding position and stow Choke, kill and koomey lines to Texas deck. Stage rotary on rig floor for install. 07/11/2023 - Tuesday 1 Regg, James B (OGC) From:Aras Worthington <Aras.Worthington@hilcorp.com> Sent:Wednesday, June 28, 2023 1:03 PM To:Regg, James B (OGC) Subject:Re: [EXTERNAL] RE: CI 17589-1A PTD # 162-028, Sundry # 323-307 Thanks Jim. Sent from my iPhone On Jun 28, 2023, at 12:52 PM, Regg, James B (OGC) <jim.regg@alaska.gov> wrote: You can proceed with P&A ops based on findings noted above. Sent via the Samsung Galaxy S21 Ultra 5G, an AT&T 5G smartphone Get Outlook for Android From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Wednesday, June 28, 2023 10:20:48 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Sloan Sunderland <ssunderland@hilcorp.com>; Steve Dambacher ‐ (C) <Steve.Dambacher@hilcorp.com> Subject: RE: [EXTERNAL] RE: CI 17589‐1A PTD # 162‐028, Sundry # 323‐307 Bryan, Jim: The divers finished re‐torquing both of the flanges below the water line yesterday. We saw no movement of the nuts on the upper flange, and minimal movement of the nuts on the bottom flange. We proceeded with the nitrogen test of the riser to 250 psi and divers inspected the sliplock wellhead and both flanges for bubbles and none were observed. This was on the 02:35 slack tide. The sonar scan of the entire riser also showed no bubbles, and none were seen at surface either. The nitrogen PT also held pressure and had little to no fall‐off, which was very different than the previous tests, so we bled down the nitrogen and re‐filled the riser with FIW. We proceeded with a pressure‐tested the riser to 1400 psi per the attached chart, going up incrementally to 1400 psi. The last time interval of the riser test on the chart conforms to the criteria we have in the Sundry, which is for a small‐volume pressure test or less than 10 psi/minute of pressure fall‐off. On the digital gauges the pressure loss was 5 psi/minute in this period. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 Hilcorp requests to proceed with the P&A operations. Thanks and best regards, Aras Worthington Well Integrity Manager, PE Hilcorp Alaska LLC Aras.worthington@hilcorp.com 907‐564‐4763 907‐440‐7692 mobile From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, June 27, 2023 3:34 PM To: Aras Worthington <Aras.Worthington@hilcorp.com> Cc: Sloan Sunderland <ssunderland@hilcorp.com>; Steve Dambacher ‐ (C) <Steve.Dambacher@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL] RE: CI 17589‐1A PTD # 162‐028, Sundry # 323‐307 Aras, Hilcorp has approval to proceed with the plan below, assuming there is no evidence of leaks external to the riser when the 250 psi pressure test with nitrogen is performed. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250‐9193 <image001.jpg> From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Tuesday, June 27, 2023 9:44 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sloan Sunderland <ssunderland@hilcorp.com>; Steve Dambacher ‐ (C) <Steve.Dambacher@hilcorp.com> Subject: RE: [EXTERNAL] RE: CI 17589‐1A PTD # 162‐028, Sundry # 323‐307 Bryan, We have successfully function tested all of the BOPE with the test plug in the spool below the BOPE to 1400 psi. We pulled the test plug and pressure‐tested the riser against the subsea wellhead by pressuring up to ~1500 psi eight times in an effort to get a passing pressure test to 1400 psi per the approved Sundry. We found no leaks above the water line during these tests. We pumped a total of ~5.5 bbls of FIW during the pressure‐tests with a leak rate of CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 3 <1 gpm. The pressure fall‐off was linear, indicative of a leak in the riser or a leak into the subsea wellhead. Additionally, the pressure fall‐off was getting worse with each test. We don’t think it is a good idea to continue pressure‐testing to 1500 psi because we appear to be breaking something down possibly in the well and we are well above frac gradient of the 13‐3/8” shoe with a 1400 psi pressure test with FIW. Trouble‐shooting the failing pressure test included: 1. Evacuating the riser with compressed air down to the subsea wellhead to see if fluid in‐flowed (it did not) 2. Pressure‐testing the riser with compressed air at 115 psi while visually observing the surface of the water at slack tide for any bubbles – none were observed. 3. Holding the pressure test with compressed air at 115 psi while divers visually examined the sliplock wellhead and both of the flanged connections of the riser below the water line (they found no leaks, i.e. bubbles) 4. Sonar scanning the entire wellhead and riser to look for bubbles (none were seen) 5. Divers re‐torque all 32 bolts on both of the flanged connections of the riser (this is currently in progress) 6. Bleed the pressure in the riser down and verify again that there is no fluid in‐flow (completed) We either have a leak from our pressure‐containment system sealed around the well or into the well and well completion. There are several possible leak paths into the well including: 1. The “Bridge Plug Valve” in the 2‐3/8” tubing and then into the 5” casing. 2. The 2‐3/8” tubing hanger and into the 5” casing 3. The open ports on the wellhead that go into the 5”x7” annulus (divers verified there is no plug in this port over a year ago and there hasn’t been a plug since ca. 1964 as best we know) 4. The 5” casing hanger and into the 5” x 7” annulus 5. The 7” casing hanger and into the 7” x 9‐5/8” annulus 6. The 9‐5/8” casing hanger and into the 9‐5/8” x 13‐3/8” annulus Our proposed plan forward is as follows: 1. Finish re‐torquing all of the riser bolts on the flanges below the water line 2. Check the riser for a change in fluid level again to ensure no leaks into the riser 3. Mobilize nitrogen unit to the platform 4. Pressure‐test the riser to 250 psi with nitrogen 5. Visually inspect the surface of the water at slack tide for bubbles while holding 250 psi on the riser 6. Divers to visually inspect the sliplock wellhead and the two flanged connections for bubbles while holding 250 psi on the riser 7. Divers to sonar scan the entire riser for bubbles while holding 250 psi on the riser If we find bubbles leaking from the riser or the sliplock wellhead, we will likely need to RDMO and come up with a revised plan for intervening in this well. We propose that if there are no bubbles observed on the 250 psi test with nitrogen that we proceed with bleeding down the riser, re‐filling with FIW, and equalizing the Bridge Plug Valve with slickline as per the approved sundry. If we cannot equalize or pull the slickline plug we propose to overshot the 2‐3/8” hanger with 5” drillpipe and the top‐drive for weight as per the approved sundry, and pull the hanger with the annular preventer cinched up around the drillpipe for contingent pressure control. Thanks for your consideration and best regards, 4 Aras Worthington Well Integrity Manager, PE Hilcorp Alaska LLC Aras.worthington@hilcorp.com 907‐564‐4763 907‐440‐7692 mobile From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, June 22, 2023 10:54 AM To: Aras Worthington <Aras.Worthington@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Shane Hauck <shauck@hilcorp.com>; Steve Dambacher ‐ (C) <Steve.Dambacher@hilcorp.com> Subject: RE: [EXTERNAL] RE: CI 17589‐1A PTD # 162‐028, Sundry # 323‐307 Aras, Hilcorp has approval to proceed with the single pipe ram/blind and annular BOP stack as described below. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250‐9193 <image001.jpg> From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Thursday, June 22, 2023 10:43 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Shane Hauck <shauck@hilcorp.com>; Steve Dambacher ‐ (C) <Steve.Dambacher@hilcorp.com> Subject: RE: [EXTERNAL] RE: CI 17589‐1A PTD # 162‐028, Sundry # 323‐307 Bryan, 1. Plan is to have 5” rams installed initially, and work with 5” drill pipe until we get the 2‐3/8” Tubing hanger and one‐joint of 2‐3/8” tubing out of the well. 2. Swap to 2‐7/8” rams and test for the 2‐7/8” drillpipe work (drift and weight test existing cement plug, cut 5” casing above existing abandonment plug) 3. Swap to 5” rams and test for pulling of the 5” casing with 5” drillpipe 4. Swap to 4‐1/2” rams for the 4‐1/2” drillpipe work (set 7” retainer and install add’l abandonment cement plug, weight test same, cut and pull 7” shallow, cut and pull 9‐5/8” shallow, set 13‐3/8” CIBP and contingent 13‐3/8” cement retainer, install surface cement job, weight test same, cut 13‐3/8” casing below mudline). Aras From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, June 22, 2023 10:18 AM CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 5 To: Aras Worthington <Aras.Worthington@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: [EXTERNAL] RE: CI 17589‐1A PTD # 162‐028, Sundry # 323‐307 What size pipe rams to you plan to have in the stack and when would you change them out? Annular preventer should be tested to the largest and smallest size casing you will pull through it. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250‐9193 <image001.jpg> From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Thursday, June 22, 2023 8:41 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: FW: CI 17589‐1A PTD # 162‐028, Sundry # 323‐307 Bryan, As discussed, we were unable to get a passing shell‐test of the BOP stack after two installations of new API rings between our bottom single gate ram and spool below yesterday. This stack was designed above and beyond regulatory requirements with three rams in an effort to minimize the changing of rams during the workover (P&A) operation. Since the bottom ram or the spool appear to be defective at the API ring junction, we propose to remove them from the stack and proceed with a two‐ram stack, three preventers in total including: 1. Pipe ram 2. Blind ram 3. Annular preventer This will comply with regulation 20 AAC 25.285 (c) (2) (A) for an operation with a maximum surface pressure of 3,000 psi or less. Additionally, as discussed Hilcorp requests that pipe rams not be required for the 7” and 9‐5/8” casings that will be cut and pulled shallow, from ~150’ – 200’ below the mudline after validating the deeper P&A plug in the well, and installing an additional P&A plug per the approved Sundry. These casing lengths to be pulled are in line with the spirit of 20 AAC 25.285 (c) (2) (A) (i) “one equipped with pipe rams that fit the size of drill pipe, tubing, liner or casing being used, except that pipe rams need not be sized to bottom- hole assemblies (BHAs) and drill collars;” The sections of casing being pulled are within the typical length of BHAs and drill collar assemblies used for similar operations. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 6 The revised BOPE diagram is shown below: <image002.png> Thanks and best regards, Aras Worthington Well Integrity Manager, PE Hilcorp Alaska LLC Aras.worthington@hilcorp.com 907‐564‐4763 907‐440‐7692 mobile The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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 7 email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:McLellan, Bryan J (OGC) To:Aras Worthington Cc:Sloan Sunderland; Steve Dambacher - (C); Rixse, Melvin G (OGC); Regg, James B (OGC) Subject:RE: [EXTERNAL] RE: CI 17589-1A PTD # 162-028, Sundry # 323-307 Date:Tuesday, June 27, 2023 3:33:00 PM Attachments:image002.png Aras, Hilcorp has approval to proceed with the plan below, assuming there is no evidence of leaks external to the riser when the 250 psi pressure test with nitrogen is performed. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Tuesday, June 27, 2023 9:44 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sloan Sunderland <ssunderland@hilcorp.com>; Steve Dambacher - (C) <Steve.Dambacher@hilcorp.com> Subject: RE: [EXTERNAL] RE: CI 17589-1A PTD # 162-028, Sundry # 323-307 Bryan, We have successfully function tested all of the BOPE with the test plug in the spool below the BOPE to 1400 psi. We pulled the test plug and pressure-tested the riser against the subsea wellhead by pressuring up to ~1500 psi eight times in an effort to get a passing pressure test to 1400 psi per the approved Sundry. We found no leaks above the water line during these tests. We pumped a total of ~5.5 bbls of FIW during the pressure-tests with a leak rate of <1 gpm. The pressure fall-off was linear, indicative of a leak in the riser or a leak into the subsea wellhead. Additionally, the pressure fall-off was getting worse with each test. We don’t think it is a good idea to continue pressure-testing to 1500 psi because we appear to be breaking something down possibly in the well and we are well above frac gradient of the 13-3/8” shoe with a 1400 psi pressure test with FIW. Trouble-shooting the failing pressure test included: 1. Evacuating the riser with compressed air down to the subsea wellhead to see if fluid in-flowed (it did not) 2. Pressure-testing the riser with compressed air at 115 psi while visually observing the surface of the water at slack tide for any bubbles – none were observed. 3. Holding the pressure test with compressed air at 115 psi while divers visually examined the sliplock wellhead and both of the flanged connections of the riser below the water line (they found no leaks, i.e. bubbles) 4. Sonar scanning the entire wellhead and riser to look for bubbles (none were seen) 5. Divers re-torque all 32 bolts on both of the flanged connections of the riser (this is currently in progress) 6. Bleed the pressure in the riser down and verify again that there is no fluid in-flow (completed) We either have a leak from our pressure-containment system sealed around the well or into the well and well completion. There are several possible leak paths into the well including: 1. The “Bridge Plug Valve” in the 2-3/8” tubing and then into the 5” casing. 2. The 2-3/8” tubing hanger and into the 5” casing 3. The open ports on the wellhead that go into the 5”x7” annulus (divers verified there is no plug in this port over a year ago and there hasn’t been a plug since ca. 1964 as best we know) 4. The 5” casing hanger and into the 5” x 7” annulus 5. The 7” casing hanger and into the 7” x 9-5/8” annulus 6. The 9-5/8” casing hanger and into the 9-5/8” x 13-3/8” annulus Our proposed plan forward is as follows: 1. Finish re-torquing all of the riser bolts on the flanges below the water line 2. Check the riser for a change in fluid level again to ensure no leaks into the riser 3. Mobilize nitrogen unit to the platform 4. Pressure-test the riser to 250 psi with nitrogen 5. Visually inspect the surface of the water at slack tide for bubbles while holding 250 psi on the riser 6. Divers to visually inspect the sliplock wellhead and the two flanged connections for bubbles while holding 250 psi on the riser 7. Divers to sonar scan the entire riser for bubbles while holding 250 psi on the riser If we find bubbles leaking from the riser or the sliplock wellhead, we will likely need to RDMO and come up with a revised plan for intervening in this well. We propose that if there are no bubbles observed on the 250 psi test with nitrogen that we proceed with bleeding down the riser, re-filling with FIW, and equalizing the Bridge Plug Valve with slickline as per the approved sundry. If we cannot equalize or pull the slickline plug we propose to overshot the 2-3/8” hanger with 5” drillpipe and the top-drive for weight as per the approved sundry, and pull the hanger with the annular preventer cinched up around the drillpipe for contingent pressure control. Thanks for your consideration and best regards, Aras Worthington Well Integrity Manager, PE Hilcorp Alaska LLC CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Aras.worthington@hilcorp.com 907-564-4763 907-440-7692 mobile From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, June 22, 2023 10:54 AM To: Aras Worthington <Aras.Worthington@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Shane Hauck <shauck@hilcorp.com>; Steve Dambacher - (C) <Steve.Dambacher@hilcorp.com> Subject: RE: [EXTERNAL] RE: CI 17589-1A PTD # 162-028, Sundry # 323-307 Aras, Hilcorp has approval to proceed with the single pipe ram/blind and annular BOP stack as described below. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Thursday, June 22, 2023 10:43 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Shane Hauck <shauck@hilcorp.com>; Steve Dambacher - (C) <Steve.Dambacher@hilcorp.com> Subject: RE: [EXTERNAL] RE: CI 17589-1A PTD # 162-028, Sundry # 323-307 Bryan, 1. Plan is to have 5” rams installed initially, and work with 5” drill pipe until we get the 2-3/8” Tubing hanger and one-joint of 2-3/8” tubing out of the well. 2. Swap to 2-7/8” rams and test for the 2-7/8” drillpipe work (drift and weight test existing cement plug, cut 5” casing above existing abandonment plug) 3. Swap to 5” rams and test for pulling of the 5” casing with 5” drillpipe 4. Swap to 4-1/2” rams for the 4-1/2” drillpipe work (set 7” retainer and install add’l abandonment cement plug, weight test same, cut and pull 7” shallow, cut and pull 9-5/8” shallow, set 13-3/8” CIBP and contingent 13-3/8” cement retainer, install surface cement job, weight test same, cut 13-3/8” casing below mudline). Aras From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, June 22, 2023 10:18 AM To: Aras Worthington <Aras.Worthington@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: [EXTERNAL] RE: CI 17589-1A PTD # 162-028, Sundry # 323-307 What size pipe rams to you plan to have in the stack and when would you change them out? Annular preventer should be tested to the largest and smallest size casing you will pull through it. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Thursday, June 22, 2023 8:41 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: FW: CI 17589-1A PTD # 162-028, Sundry # 323-307 Bryan, As discussed, we were unable to get a passing shell-test of the BOP stack after two installations of new API rings between our bottom single gate ram and spool below yesterday. This stack was designed above and beyond regulatory requirements with three rams in an effort to minimize the changing of rams during the workover (P&A) operation. Since the bottom ram or the spool appear to be defective at the API ring junction, we propose to remove them from the stack and proceed with a two-ram stack, three preventers in total including: 1. Pipe ram 2. Blind ram 3. Annular preventer This will comply with regulation 20 AAC 25.285 (c) (2) (A) for an operation with a maximum surface pressure of 3,000 psi or less. Additionally, as discussed Hilcorp requests that pipe rams not be required for the 7” and 9-5/8” casings that will be cut and pulled shallow, from ~150’ – 200’ below the mudline after validating the deeper P&A plug in the well, and installing an additional P&A plug per the approved Sundry. These casing lengths to be pulled are in line with the spirit of 20 AAC 25.285 (c) (2) (A) (i) “one equipped with pipe rams that fit the size of drill pipe, tubing, liner or casing being used, except that pipe rams need not be sized to bottom-hole assemblies (BHAs) and drill collars;” The sections of casing being pulled are within the typical length of BHAs and drill collar assemblies used for similar operations. The revised BOPE diagram is shown below: Thanks and best regards, Aras Worthington Well Integrity Manager, PE Hilcorp Alaska LLC Aras.worthington@hilcorp.com 907-564-4763 907-440-7692 mobile The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message inerror, 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 listedabove, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect itssystems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message inerror, 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 listedabove, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect itssystems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message inerror, 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 listedabove, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect itssystems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:McLellan, Bryan J (OGC) To:Aras Worthington; Regg, James B (OGC) Cc:Shane Hauck; Steve Dambacher - (C) Subject:RE: [EXTERNAL] RE: CI 17589-1A PTD # 162-028, Sundry # 323-307 Date:Thursday, June 22, 2023 10:54:00 AM Attachments:image002.png Aras, Hilcorp has approval to proceed with the single pipe ram/blind and annular BOP stack as described below. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Thursday, June 22, 2023 10:43 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Shane Hauck <shauck@hilcorp.com>; Steve Dambacher - (C) <Steve.Dambacher@hilcorp.com> Subject: RE: [EXTERNAL] RE: CI 17589-1A PTD # 162-028, Sundry # 323-307 Bryan, 1. Plan is to have 5” rams installed initially, and work with 5” drill pipe until we get the 2-3/8” Tubing hanger and one-joint of 2-3/8” tubing out of the well. 2. Swap to 2-7/8” rams and test for the 2-7/8” drillpipe work (drift and weight test existing cement plug, cut 5” casing above existing abandonment plug) 3. Swap to 5” rams and test for pulling of the 5” casing with 5” drillpipe 4. Swap to 4-1/2” rams for the 4-1/2” drillpipe work (set 7” retainer and install add’l abandonment cement plug, weight test same, cut and pull 7” shallow, cut and pull 9-5/8” shallow, set 13-3/8” CIBP and contingent 13-3/8” cement retainer, install surface cement job, weight test same, cut 13-3/8” casing below mudline). Aras From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, June 22, 2023 10:18 AM To: Aras Worthington <Aras.Worthington@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: [EXTERNAL] RE: CI 17589-1A PTD # 162-028, Sundry # 323-307 What size pipe rams to you plan to have in the stack and when would you change them out? Annular preventer should be tested to the largest and smallest size casing you will pull through it. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Thursday, June 22, 2023 8:41 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: FW: CI 17589-1A PTD # 162-028, Sundry # 323-307 Bryan, As discussed, we were unable to get a passing shell-test of the BOP stack after two installations of new API rings between our bottom single gate ram and spool below yesterday. This stack was designed above and beyond regulatory requirements with three rams in an effort to minimize the changing of rams during the workover (P&A) operation. Since the bottom ram or the spool appear to be defective at the API ring junction, we propose to remove them from the stack and proceed with a two-ram stack, three preventers in total including: 1. Pipe ram 2. Blind ram 3. Annular preventer This will comply with regulation 20 AAC 25.285 (c) (2) (A) for an operation with a maximum surface pressure of 3,000 psi or less. Additionally, as discussed Hilcorp requests that pipe rams not be required for the 7” and 9-5/8” casings that will be cut and pulled shallow, from ~150’ – 200’ below the mudline after validating the deeper P&A plug in the well, and installing an additional P&A plug per the approved Sundry. These casing lengths to be pulled are in line with the spirit of 20 AAC 25.285 (c) (2) (A) (i) “one equipped with pipe rams that fit the size of drill pipe, tubing, liner or casing being used, except that pipe rams need not be sized to bottom-hole assemblies (BHAs) and drill collars;” The sections of casing being pulled are within the typical length of BHAs and drill collar assemblies used for similar operations. The revised BOPE diagram is shown below: Thanks and best regards, Aras Worthington Well Integrity Manager, PE Hilcorp Alaska LLC Aras.worthington@hilcorp.com 907-564-4763 907-440-7692 mobile The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message inerror, 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 listedabove, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect itssystems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message inerror, 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 listedabove, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect itssystems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: Exploratory 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12,676 3,045' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Aras Worthington Contact Email:Aras.Worthington@hilcorp.com Contact Phone:907 564-4763 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 12,422 3,045 ~826psi 24" / 20"225' / 655' MD 225' / 655' 225' / 655' Length Size 151' 10,139' / 1,300'10,325' / 1,300' 12,404' 12,162' 1,579' 5,489' Perforation Depth MD (ft): 10,325' / 1,300' 5"12,404' 7" 9-5/8"5,489' 13-3/8"1,579' 1,579' 5,489' Proposed Pools: 151' 151' TVD Burst PRESENT WELL CONDITION SUMMARY 30" See schematic3,045 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 162-028 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-883-10013-00-00 Hilcorp Alaska, LLC Cook Inlet St 17589 1-A N/A N/A N/A Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 164' 6/1/2023 Otis Nipple w/Plug 133 (MD) 133 (TVD) Cemented Cemented 2-3/8" 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Operations Manager Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:20 pm, May 24, 2023 323-307 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.05.24 14:41:36 - 08'00' Dan Marlowe (1267) X DSR=5/24/23 X BOP test to 1400 psi Review CBL's with AOGCC to agree on casing punch or cut depth before making any casing punches or cuts. SFD 5/25/2023BJM 5/30/23 GCW 05/31/23 05/31/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.05.31 14:25:24 -08'00' RBDMS JSB 060123 Well P&A Well: CI 17589 1A Date: 05/24/2023 Well Name:CI 17589 1A API Number:50-883-10013-00-00 Current Status:Suspended Leg:N/A Estimated Start Date:June 1, 2023 Rig:Spartan 151 Reg. Approval Req’d?10-403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett 777-8332 Permit to Drill Number:162-028 First Call Engineer:Aras Worthington (907) 564-4763 (O) (907) 440-7692 (M) Second Call Engineer:Sean McLaughlin (907) 233-6784(O) (907) 233-6784 (M) AFE Number: Current Bottom Hole Pressure:~ 1236 psi @ 4,100’ TVD Based on A-15 RFT data of C.I. 6 sand ca. 2009 Maximum Expected BHP:~ 1236 psi @ 4,100’ TVD Max. Potential Surface Pressure:~ 826 psi (Based on 0.1 psi/ft Gas grad. to Surf.) Well History Well Cook Inlet State 17589 1A was drilled as a relief well for Cook Inlet State 17589 1 beginning in 1962 from an early drilling barge WODCO 2. Well control was lost during drilling operations from WODCO 2 on Well 17589 in August of 1962. Due to winter weather and ice the relief well 17589 1A was suspended in December 1962 and not drilled to TD. The following summer the relief well was TD’d and the blowout well was brought under control in October of 1963. There is reference in the well files to damaged 7” casing at 8800’-8900’ MD during the pumping of fluids during the well kill operations. A 5” liner was installed from 10,010’ MD to the subsea wellhead and cemented to re- establish well integrity. After the blowout was brought under control by pumping some 40,000 bbls of water int the relief well the deepest producing zone was abandoned and the well was suspended so that the barge rig could move back to well 17589 and finish the P&A in the Fall of 1963. Well operations on 17589-1A were commenced in April 1964. Prospective hydrocarbon producing zones were then sequentially tested from deepest to shallowest during the summer of 1964. After the testing of each set of perforations they were abandoned with cement squeezes, packers or cement retainers in the 5” casing. There are some records of weight testing retainers and casing pressure tests but the well records are not very detailed as monthly recaps were submitted to the State of Alaska and not daily reports. Perforation and plugging documentation to the State was found in the AOGCC well records to confirm the perforation depths, cement squeeze volumes, and associated retainers and packers with their cement caps. However, a retainer with a cement plug was not placed just below the mudline to complete the P&A of 17589 1A. The placing of this surface plug just below the mudline is the main focus of the proposed well work. The deeper formations below 10,000’ TVDSS tested black oil, gas and condensate and are over pressured (13-15 ppg) while the formations above 10,000’ MD TVDSS are dry gas producing with normal pressure gradient (9-9.5ppg). Review of the documentation of the production tests of formations from 6500’-3500’ MD made no mention of any significant water production and no oil production. The recorded bottom hole pressures from the recorded test data are indicative of a normal pressure gradient so it is a valid assumption that the lower abnormally pressured zones were successfully abandoned. Well P&A Well: CI 17589 1A Date: 05/24/2023 The subsea wellhead system and associated base plate were located 126’ from the original KB at zero tide and is a 1960 vintage Shaffer system that is set up for diverless operations. Dive work performed during summer of 2014 by ConocoPhillips (previous responsible Operator) developed the dimensional drawings of the wellhead and casing spools with the FOSV located on top of the wellhead spools. Marine debris and scale were cleaned from the exterior wellhead spools and the FOSV. It was also noted that the base plate is covered by at least 2’ of sediment (mainly silt) and cement. Work Accomplished in 2021 Spartan Rig 151 was placed on the location of Well 17589 1A on June 10, 2021. The placement of support equipment on the deck of Rig 151 and preparing for diver assist operations was completed on June 17, 2021. June 18-19: Divers prepared subsea wellhead to begin well work operations. June 20-22: 5” drill pipe was picked up and a 2 9/16”, 5K gate valve with a crossover back to 4 ½” IF connection was run and made up into the FOSV (full opening safety valve) located at the top of the Shaffer subsea wellhead assembly at 213’ RKB. Surface equipment and 5” DP to the 2 9/16”, 5 K gate valve successfully pressure tested to 250 psi low/1400 psi high. A hot tap assembly was placed on neck of FOSV below the ball. Hot Tap equipment successfully pressure tested to 250 psi low/2100 psi high. The FOSV hot tap revealed no pressure below ball, well on vacuum initially then static. The gate valve on the hot tap assembly closed to secure well. Hot tap equipment pulled to deck. June 23-25: WellTec tractor lowered on Eline in 5” DP. Gate valve opened and WellTec tractor tagged ball in FOSV at 214’ RKB. Milling of the FOSV ball commenced on June 23. Shortly after beginning milling operations began losing fluid, 1-2 bph depending on circulating pressure. The mill quit making progress and was pulled to find pilot section of the mill had parted and was left downhole. Multiple magnet and bailer runs with Eline were made to attempt to retrieve junk with no success. A second mill was picked up and run on the WellTec tractor with no success in making progress and fluid was still being lost when circulating. The tractor was pulled and laid down. Green dye was mixed with water and pumped down the 5” DP with diver positioned to check for leaks. No leaks were noted. A downhole camera was run and noted metal and metal shaving in the ball and along the edge of the ball remaining from the milling operation. A smaller magnet was run and retrieved a couple pieces of metal and shavings after multiple runs. June 26-27: Plan B was initiated. 1 ½” tubing with a 1.69” motor was picked up and run to complete the milling the ball of the FOSV. While milling the ball the fluid loss was 7-10 bph. A total of 4 mills were used with intermittent runs with magnets and bailers to clean out junk from milling operations to complete the milling of the FOSV ball. The FOSV was milled through to 1.87” ID. Fluid level in 5” DP appeared to mirror tide fluctuations. Well P&A Well: CI 17589 1A Date: 05/24/2023 June 28-29: Shut In on 5” DP and pressure test with 120 psi air pressure with diver in position to monitor for leaks. Leak noted immediately by diver and bubbles were seen at the surface of the Inlet. PU with 5” DP and found Shaffer auto connector is not latched onto the wellhead assembly. The auto connector was picked up with the FOSV to the rig floor. The FOSV was removed, and the auto connector cleaned up and sent to land for inspection. Diver noted no flow from the well with auto connector removed. June 30-July 3: Auto connector sent to the machine shop for inspection. Inspection found the two seals in poor condition and the release mechanism dogs that provide releasing of the locking assembly of the auto connector to the inner subsea wellhead assembly were damaged and so two new dogs were built at the machine shop based upon the dimensions of the damaged dogs. July 4-8: The rebuilt auto connector was sent back to Spartan 151 with the seals doped and put back in place as no duplicate seals could be found. The auto connector with a removable bell guide to assist stabbing over inner wellhead assembly was run on 5” DP and after multiple attempts with diver assist stabbed over the wellhead inner assembly. The auto connector did latch to the inner wellhead J-slot, but the diver noted the locking assembly did not engage. The secure latch via the J-slot was proved when 5” DP was pulled with 15,000 lbs. of tension above pickup weight of 60,000 lbs. The pressure test with 120 psi of air was unsuccessful as leak was immediately notice by the diver. Several more attempts were made to reset the auto connector with no success to obtain a pressure test. AOGCC was consulted and a request to defer the remaining P&A work until the 2022 open water season was granted. The auto connector was then shipped to the Cactus Wellhead fabrication facility in Bossier City, LA where it was inspected and re-built. After Hilcorp personnel inspected the rebuilt components of the auto-connector in Louisiana another series of dives were scheduled in the late Fall of 2021 to verify critical dimensions of the subsea wellhead both for the auto-connector and a backup option. Two days of dives were performed on November 14, 15 but the critical seal-section of the subsea wellhead had not been located or verified. A third day of dives was scheduled on November 16 and the seal section finally located. Initial measurements were taken of the seal section but ice conditions prevailed and precluded additional dives that season. During the winter of 2021/2022 new elastomeric seals for the auto-connector were manufactured with 70 and 80 durometer elastomers as well as in two different tolerances to offer as many options as possible to get the auto-connector to seal. Back up options to the auto-connector were also explored in conjunction with engineering support at Cactus. Due to the imprecise nature of diver measurements Hilcorp endeavored to obtain precise dimensions of the subsea wellhead needed for the manufacture of a better and more reliable sealing option than the auto-connector: A custom-designed slip-lock wellhead. Well P&A Well: CI 17589 1A Date: 05/24/2023 Work Accomplished in 2022 Design of a custom LiDAR “blackwater box” was completed by a diving vendor. Initial testing of the box at the Port of Anchorage (POA - which has the same opaque water as found at Tyonek) commenced in May of 2022. The test was partially successful, but the prototype box was re-designed based on that trial and within a few weeks a final design was manufactured. This was also tested at the POA in May with much greater success. In late May of 2022, the LiDAR box was successfully mobilized to the subsea wellhead to scan the entire sealing section. Five days and some 30 scans were necessary to map the entire sealing mandrel of the wellhead. This data was processed to make a full dimensional model of the subsea wellhead. Cactus wellheads was then able to complete their design for the sliplock wellhead. Unfortunately, it was found that all components of the sliplock wellhead could be obtained in time for manufacture and installation in the Fall of 2022, except for the custom elastomeric P-seals (these are of a different design than the auto-connector seals). Hilcorp informed AOGCC of this situation and requested time over the winter months of 2022/2023 to obtain the P-seals, finish manufacture and testing of the sliplock wellhead for a rig mobilization in the Spring of 2023 in the interest of reliable well control during the P&A rig intervention. AOGCC agreed to the proposed plan. Hilcorp mobilized divers to the subsea wellhead in the Fall of 2022 with a custom set of go/no-go gauge rings to ensure that the processed LiDAR dimensions were accurate and to ascertain the OD of the 2-3/8” tubing hanger (at the top of the wellhead). The LiDAR dimensions were verified to be accurate and the 2-3/8” hanger OD was measured. Testing of the sliplock wellhead is scheduled for mid-February 2023 (Done) to allow ample time for any final modifications needed as well as planning for installation of the sliplock. Work Accomplished in 2023 Testing of the sliplock wellhead was completed in March of 2023 to allow ample time for any final modifications needed as well as planning for installation of the sliplock. The sliplock wellhead was installed via a four-point moored barge in early May of 2023. A pressure- test between the dual P-seals was achieved to 1500 psi ensuring we have two tested pressure-seals around the subsea wellhead. Well P&A Well: CI 17589 1A Date: 05/24/2023 Path Forward 1. MIRU Spartan 151 2. Pull 2-3/8” tubing 3. Tag TOC in 5” casing 4. Cut and pull 5” casing 5. Punch 7” casing for deep cement job 6. Set 7” retainer and pump lower abandonment cement plug/squeeze 7. Cut and pull 7” casing above TOC 8. Cut and pull 9-5/8” casing above TOC 9. Install surface cement plug across 13-3/8” casing Well P&A Well: CI 17589 1A Date: 05/24/2023 Work Plan The Spartan Rig 151 will provide the work platform to complete the P&A of Well 17589 1A. Work is anticipated to begin in June of 2023 and take two to four weeks depending upon complications encountered. Three to four tugs will be utilized to mobilize the Spartan 151 from Rig Tenders to the location of Well 17589 1A. A Marine Surveyor, Rig Moving Specialist and positioning contractor will be utilized to track the movements of Spartan 151 and tugs to the well location at 61 deg 04.1156636’ N latitude and 150 deg 56.7077770’ W longitude and place the jackup accurately on location. Well 17589 1A and the Spartan 151 will be 2900’ SSE of the Tyonek Platform, 1715’ east of Well 17589 1 (blowout well) and 980’ west of the gas and oil lines that run from the Tyonek Platform to the East Forelands. Prior to the mobilization of Spartan 151 a hazards review of the seafloor at the well site has been performed to determine that the seafloor has topography and integrity to allow 151 to be jacked up and provide the work platform for the P&A of Well 17589 1A. Spartan 151 operations will be supported from OSK Dock in Nikiski, AK for both workboats and helicopters. Variance Requests from AOGCC Regulations 1.Hilcorp requests a variance to 20 AAC 25.172 (b)Request that the wellhead base plate and lower wellhead spool be allowed to remain in place. The base plate is covered by over 2’ of cement and sediment. The 13 3/8”, 20”, 24” and 30” casings are all cemented to the mudline. The remaining wellhead stub (after pulling the casing hangers) is proposed to extend about 3’ above the mudline. Variance to 20 AAC 25.112(c)(2) granted for 7 & 9-5/8" casing stubs. The 7" x 9-5/8" annulus and 7" casing will be plugged ~3100' and the surface plug will be placed from just above the casing stubs to mud line. These plugs will be equally effective in preventing fluid movement. There is no fresh water present in this subsea well. -bjm Variance approved. -bjm Well P&A Well: CI 17589 1A Date: 05/24/2023 North Cook Inlet State 17589 1A P&A Procedure 1. MIRU Spartan 151. Determine RKB for well work once jacking of Rig 151 completed (233’ RKB to mudline from initial RU).Notify AOGCC Inspector and Engineer once Rig 151 is set on location at Well 17589 1A. 2. RU 20” running tools and false rotary to PU and run 20” riser. 3. Deploy short 20”x 6’ riser ANSI 1500 flange with two air tugger guy cables MU to the top flange bolts 180 deg apart. Run down to the subsea wellhead to ~227’ RKB on slack tide. Diver-assist NU of short riser. Torque ANSI riser studs to 6308 ft-lbs. 4. MU the rest of 20” riser with ANSI 1500 flange. Thread guy wires through ANSI flange and riser shackles to guide riser into place. Install 4-1/2” IF x ANSI XO and lower 20” riser w/ drillpipe to the subsea wellhead to 221’ RKB on slack tide. 5. Divers to assist mating of the long 20” riser to the short riser @ 221’ RKB and MU ANSI 1500 flanged connection. Torque ANSI riser studs to 6308 ft-lbs. 6. MU 20” riser hydraulic tensioning system and pull in 1000# - 2000# increments the minimum tension required to quiet vibration of 20” riser caused by the Inlet current.Add or release tension as required to minimize riser vibration due to currents. 7. NU 16-3/4” BOP stack. Rams will be top down: Annular, Pipe ram, Blind ram, Pipe ram. Dress upper pipe ram with 2-7/8”, lower pipe ram with 5”. Note: Because there is only one joint of 2-3/8” tubing to pull out of this well, Hilcorp proposes to use the annular preventer and a TIW valve XO to the 2-3/8” joint should the BOPE need to be closed while pulling the one-joint of 2-3/8” tubing. 8. Install BOP test plug in tubing spool below BOPs. 9. Test BOPE to 250 low / 1400 psi high and record on a chart.Test to be witnessed by AOGCC. 10. Pull BOP test plug. 11. Close blind rams to pressure test riser. 12. Pressure-test the 20” riser and sliplock wellhead to 1400 psi.Test to be witnessed by AOGCC. Passing pressure test criteria for the riser will be a pressure fall-off of less than 10 psi/min after the pressure stabilizes to less than 10 psi/min over a five-minute interval with decreasing pressure fall-off during the test. 13. Keep blind rams closed and bleed off test pressure through choke line slowly. Note that due to the 1400 psi pressure test the BPV in the 2-3/8” tubing will trap pressure in the wellbore and may dislodge the 2-3/8” tubing hanger. 14. MU overshot (to catch between 8.775” and 8.9” OD) on 5” DP. 15. RIH and engage overshot on the 2-3/8” tubing hanger. 16. Close 5” pipe rams on DP with dog-knot rigged up below pipe rams or with SL rigged up on top of top drive (1400 psi of pressure on 5” DP = 27,500 lb-f) Dress upper pipe ram with 2-7/8”, lower pipe ram with 5”. This will be the first test on the 20" riser slip lock wellhead connection, applying a significant upward force on the slips. The pre-rig test was between two seals, so no upward force was applied to the slips. - bjm Approved. -bjm Well P&A Well: CI 17589 1A Date: 05/24/2023 17. RU Slickline, pump-in sub, and lubricator. MU and test lubricator to 1400 psi. RIH with LIB to verify plug type. 18. Pull “Otis BPV” @ +/-217’ RKB. Depending on equalization options, may need to put ~1400 psi on the riser to equalize the BPV function to avoid being blown uphole. 19. Monitor well after pulling plug.If pressure found, record pressure and notify AOGCC Inspector and Engineer. Bleed off pressure through choke manifold if required and fill hole. Record time to bleed off, fluid type and hole fill volume. Fill hole with fluid weighted to make well static. Monitor to ensure no pressure build up. (This step will be performed each time a casing is perforated, and pressure is found in the annulus.) 20. Break lubricator. LD plug. 21. Drift for E-line 1-11/16” tools as deep as possible. 22. RD Slickline. 23. RU Eline on 5” DP with full pressure control (grease tubes, pump-in-sub, & lubricator). Pressure-test lubricator to 1400 psi. 24. Punch the 5” casing as deep as possible (expected depth ~3100’ RKB). 25. Monitor well after punching the casing.If pressure found, record pressure and notify AOGCC Inspector and Engineer. Bleed off pressure through choke manifold if required and fill hole in stages (lubricate and bleed). Record time to bleed off, fluid type and hole fill volume. Fill hole with fluid weighted to make well static. Bullhead kill if necessary and feasible. Monitor to ensure no pressure build up. (This step will be performed each time a casing is perforated when pressure is found in the annulus). 26. Punch the 2-3/8” tubing @ ~243’ RKB/10’ BLM (Below Mudline) to vent any trapped gas below the tubing hanger. 27. Monitor well after punching the tubing. Bleed off pressure through choke manifold if required and fill hole. Record time to bleed off, fluid type and hole fill volume. Fill hole with fluid weighted to make well static. Monitor to ensure no pressure build up. 28. Punch the 5” casing @ ~273’ RKB/40’ BLM (Below Mudline). 29. Monitor well after punching the casing.If pressure found, record pressure and notify AOGCC Inspector and Engineer. Bleed off pressure through choke manifold if required and fill hole in stages (lubricate and bleed). Record time to bleed off, fluid type and hole fill volume. Fill hole with fluid weighted to make well static. Bullhead kill if necessary and feasible. Monitor to ensure no pressure build up. 30. MU CCL, GR and CBL. RIH with CCL, GR, CBL to +/- 3045’ RKB and log to 233’ RKB (233’ RKB for Spartan 151 to mudline from initial RU) to look for cement in 5” x 7” annulus. POH. 31. POOH and LD CCL, GR and CBL tools. 32. Pull 2-3/8” tubing hanger.Note: For the 2 3/8” tubing hanger to be pulled, the mechanism to release is most likely straight pull. No running or retrieving tools or procedures have been found. Method to release will be trial and error. 33. Increase PU weight in small increments and allow tension to distribute once 5,000 lbs of pull is reached. Continue until 2-3/8” tubing hanger has released and picked up free for 5’. Monitor well, note any pressure or flow from the well. Max bullheading pressure = 1400 psi per Aras Worthington 5/30/23 email attached. -bjm Max bullheading pressure = 1400 psi per Aras Worthington 5/30/23 email attached. -bjm Well P&A Well: CI 17589 1A Date: 05/24/2023 34. MU 4” - 4.125” bit on 2-7/8” workstring. Note this is also a drift for the 5” cement retainer which is 3.937” OD. 35. RIH to +/- 3100’ RKB (reports indicate 5 sx cement cap on retainer). Stack 15K down on cement plug to verify integrity of the P&A plug.Weight test to be witnessed by AOGCC 36. Mechanically cut 5” casing directly above TOC (if found) or if no TOC was located with the CBL then cut @ ~3000’ RKB. 37. Spear the 5” casing below the 5” hanger (approximately 220’ RKB). 38. Increase PU weight in small increments and allow tension to distribute once ~55000 lbs of pull is reached. 39. Continue increasing PU weight until 5” casing hanger has released and picked up free for 5’. Monitor well, note any pressure or flow from the well. 40. Pull 5” casing hanger and 5” casing to rig floor and LD same.Examine hanger to look at the mechanism used to lock hanger in place as this could provide a clue for the lock system for the remaining casing hangers. 41. Run BOP test plug. 42. Swap pipe rams out to 4-1/2” (upper) and 7” (lower) and test to 1400 psi.AOGCC Witnessed. 43. Pull BOP test plug. 44. MU 6-1/8” bit and drift 7” casing for cement retainer. 45. RU E-Line and Line wiper. MU CCL, GR and CBL. RIH with CCL, GR, CBL to +/-3000’ RKB and log to 233’ RKB (mudline) to look for cement in 7” x 9 5/8” annulus and verify stage tool depth 421’ RKB/188’ below mudline. Note that the 7” stage tool had 105 sx of cement pumped through it in two stages, so expect TOC will be at the stage tool. POOH. 46. RU E-Line with full pressure control. 47. Punch the 7” casing @ ~3000’ RKB (as deep as possible) 48. Monitor well after punching.If pressure found, record pressure and notify AOGCC Inspector and Engineer. Bleed off pressure through choke manifold if required and fill hole. Record time to bleed off, fluid type and hole fill volume. Fill hole with fluid weighted to make well static. Bullhead kill if feasible and necessary. Monitor to ensure no pressure build up. 49. Punch the 7” casing 100’ MD above the deeper 7” punch. 50. Monitor well after punching.If pressure found, record pressure and notify AOGCC Inspector and Engineer. Bleed off pressure through choke manifold if required and fill hole. Record time to bleed off, fluid type and hole fill volume. Fill hole with fluid weighted to make well static. Bullhead kill if feasible and necessary. Monitor to ensure no pressure build up. 51. MU 7” cement retainer and set in the middle of the two 7” punch depths. a. Sting into retainer and perform circulation test through retainer and out casing punches above. b. Pump 5-bbl weighted spacer. c. Circulate 5 bbls of 15.3-15.8 ppg Class G cement through the retainer and up 7” x 9- 5/8” annulus. d. Sting out of retainer and lay 3-4 bbls of cement on top. Reverse out any excess cement to ~50’ shallower than the upper 7” tubing punch. Review CBL with AOGCC and agree on punch depth prior to punching 7" csg. -bjm Max bullheading pressure = 1400 psi per Aras Worthington 5/30/23 email attached. -bjm Verified cement volume. -bjm This is the first time 7" x 9-5/8" annulus will be exposed to surface. -bjm Review CBL with AOGCC and agree on cut depth prior to making cut. -bjm Well P&A Well: CI 17589 1A Date: 05/24/2023 52. WOC for 500 psi compressive strength. 53. Dress off TOC as needed with a mill or bit and and stack 15K-lbs down on it.AOGCC Witnessed. 54. RU E-Line with full pressure control. 55. Punch the 7” casing @ ~243’ RKB/10’ BLM to relieve any trapped pressure in the 7” x 9-5/8” annulus. 56. Monitor well after punching casing.If pressure found, record pressure and notify AOGCC Inspector and Engineer. Bleed off pressure through choke manifold if required and fill hole. Record time to bleed off, fluid type and hole fill volume. Fill hole with fluid weighted to make well static. Bullhead kill if feasible and necessary. Monitor to ensure no pressure build up. 57. RD Eline. 58. MU 7” casing cutter. 59. RIH with casing cutter to 421’ RKB/188’ BLM (cemented stage tool depth)or above TOC (if deeper) and cut 7”. 60. MU spear assembly on DP. RIH and engage 7” casing hanger.Note: For all casing hangers to be pulled, the mechanism to release is most likely straight pull. No running or retrieving tools or procedures have been found. Method to release will be trial and error. 61. Increase PU weight in small increments and allow tension to distribute once 10,000 lbs of pull is reached. Continue increasing PU weight until 7” casing hanger has released and picked up free for 5’. Monitor well, note any pressure or flow from the well. 62. Pull 7” casing hanger and 7” cut casing to the rig floor and LD same.Examine hanger to look at the mechanism used to lock hanger in place as this could provide a clue for the lock system for the remaining casing hangers. 63. RU AK E-Line and Line Wiper. MU CCL, GR and CBL. RIH with CCL, GR, CBL and log from ~500’ RKB to 233’ RKB (233’ RKB for Spartan 151 to mudline) to look for cement in 9-5/8” x 13-3/8” annulus and verify stage tool depth @ ~390’ RKB/157’ BLM. POOH. 64. Set BOP test plug in tubing spool below BOPs. 65. Swap 7” ram to 9-5/8” casing ram and test 9-5/8” rams to 1400 psi.AOGCC Witnessed. 66. Pull BOP test plug. 67. RU E-line with full pressure control. 68. Punch the 9-5/8” casing @ ~263’ RKB/30’ BLM 69. Monitor well after punching casing.If pressure found, record pressure and notify AOGCC Inspector and Engineer. Bleed off pressure through choke manifold if required and fill hole. Record time to bleed off, fluid type and hole fill volume. Fill hole with fluid weighted to make well static (lube and bleed). Monitor to ensure no pressure build up. 70. POOH w/ Eline. 71. RIH with 9-5/8” cutter on DP. 72. RIH and mechanically cut 9-5/8” casing no shallower than 393’ RKB/160’ below mudline, above shallowest cement found by CBL. 73. MU spear assembly on DP. RIH and engage 9-5/8” casing hanger. Max bullheading pressure = 1400 psi per Aras Worthington 5/30/23 email attached. -bjm Review CBL with AOGCC and agree on punch cut depth before cutting 9-5/8" casing. -bjm Well P&A Well: CI 17589 1A Date: 05/24/2023 74. Increase PU weight in small increments and allow tension to distribute once 10,000 lbs of pull is reached. Continue increasing PU weight until 9-5/8” casing hanger has released and picked up free for 5’. Monitor well, note any pressure or flow from the well. 75. Pull 9-5/8” casing hanger and 9-5/8” cut casing to the rig floor and LD same. 76. MU 13-3/8” casing scraper or bit on DP. RIH to top of 9-5/8” casing stub. POH. 77. RU AK E-Line and Line Wiper. MU CCL, GR and CBL. RIH with CCL, GR, CBL to +/-393’ RKB/160’ BLM and log to 233’ RKB (233’ RKB for Spartan 151 to mudline) to look for cement in 13-3/8” x 20” annulus. POH.Send CBL to AOGCC and standby for approval to proceed. 78. RIH with 13-3/8” CIBP and set at ~393’ RKB/160’ BLM (or deeper if possible). 79. RIH with DP and spot balanced surface cement plug from 393’ RKB/160’ BLM (or at the top of the CIBP, whichever is deeper) to 233’ RKB/at mudline. a. Pump spacer ahead and behind cement. b. Approximately 25 bbls of 15.3 - 15.8 ppg Class G. c. Under-displace cement in drillpipe by ~1 bbl d. Slowly pull drillpipe out of cement. e. Reverse-out excess cement to 233’ RKB. 80. Rig down cementers & WOC. 81. RIH with 12.25” bit and dress off TOC to ~10’ below mudline (~243’ RKB) Tag cement plug with 15K-lbs to weight test and verify cement top.Witness by AOGCC. 82. Make up 13-3/8” casing cutter and mechanically cut casing just below 13-3/8” casing hanger (roughly 6’ below the mudline or 239’ RKB). 83. Pull BOP stack, 20” riser, and the slip-lock wellhead along with the 13-3/8” casing hanger. Note: Recovery of the 13-3/8” casing hanger will leave the baseplate with a stub extending ~3’ above the mudline. Note: Alternatively, if the 13-3/8” casing hanger cannot be pulled, RU diamond-wire saw and cut off the wellhead ~3’ above mudline. 84. RDMO Spartan Rig 151. Attachments: Current Schematic Proposed Schematic BOPE Stack Drillstem Tests & Pressures BHP estimates Sonar Survey Well P&A Well: CI 17589 1A Date: 05/24/2023 Well P&A Well: CI 17589 1A Date: 05/24/2023 Well P&A Well: CI 17589 1A Date: 05/24/2023 Well P&A Well: CI 17589 1A Date: 05/24/2023 Well P&A Well: CI 17589 1A Date: 05/24/2023 Well P&A Well: CI 17589 1A Date: 05/24/2023 Sterling C_1_6 Structure Map. The C_1_6 sand is the approximate sand that was perforated and flowed gas in CI State 175891-1A. This well is located approximately 966 ft. from NCIU A-15 (black line below). In 2009, pressure data was acquired in NCIU A-15 within this sand interval. The pressures acquired ranged from 1,185 psi to 1,236 psi. Well P&A Well: CI 17589 1A Date: 05/24/2023 Well P&A Well: CI 17589 1A Date: 05/24/2023 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:McLellan, Bryan J (OGC) To:Aras Worthington Subject:FW: [EXTERNAL] RE: Subsea P&A Revised Sundry Date:Tuesday, May 30, 2023 4:44:00 PM Will do. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Tuesday, May 30, 2023 4:38 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: Subsea P&A Revised Sundry Yes please – thanks Bryan. From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, May 30, 2023 4:26 PM To: Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] RE: Subsea P&A Revised Sundry Aras, As discussed, should I add a 1400 psi bullheading limit to the sundry in steps 25, 29, 48, 50 , 56? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Wednesday, May 24, 2023 4:06 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: Subsea P&A Revised Sundry Bryan, We finalized the Sundry and submitted today. We canceled the old submittal. Hilcorp Alaska, LLC Aras Worthington Senior Technical Advisor for Alaska Operations 3800 Centerpoint Dr., Suite 1400 Anchorage, Alaska 99503 August 3, 2022 Chairman Jeremy M. Price Alaska Oil and Gas Conservation Commission 333 West 7t' Avenue Anchorage, Alaska 99501 VIA EMAIL AND CERTIFIED MAIL RECEIVED AUG 0 5 2022 AOGCC Subject: Exploratory Field, Exploratory Pool, Cl 17589 1A Permit to Drill Number: 162-028 Dear Chairman Price, Hilcorp Alaska, LLC (Hilcorp) has been diligently working on the safe and compliant plug and abandonment (P&A) of heritage well Cook Inlet State 17589 1A (CIS 1A). The critical hurdle to safely completing the P&A is acquiring a seal around the vintage subsea wellhead to flange -up well control BOPE during the necessary de -complete phase of the rig work. Hilcorp proposes to use a newly designed custom slip -lock wellhead assembly to achieve this seal as previous efforts to get a seal have not worked. Hilcorp has expended significant effort, time, and money to date on attempting to complete the P&A of this legacy well. In June of 2021, Hilcorp mobilized the Spartan 151 Jack -up rig to the well. Roughly a month of efforts on the P&A yielded slow and eventually stalled progress. After hot -tapping the upper section of the Shaffer Type A Automatic Connector (STAC), the Fully -Opening -Safety -Valve (FOSV) was milled out with some difficulty, but ultimately with success. After milling operations, it was determined that the STAC was not sealing around the subsea wellhead as it was designed to do, nor was it properly latched into place. The STAC was pulled to surface and inspected. The primary elastomeric seals were found to be in poor condition along with several of the moving mechanical parts. New parts were manufactured in short order, but with the seals being unique to the design of the STAC, the only expedient option was to rerun the old seals. Ultimately the STAC could be successfully latched to the subsea wellhead, but it would not seal or pressure test precluding the necessary well control to continue the de -complete required for P&A. It was agreed with AOGCC to suspend the operation until the STAC could be fully re -built. The STAC was shipped to Cactus Wellhead, a specialized, first-rate wellhead company in Louisiana for that purpose. Cactus Wellhead reverse -engineered the moving parts of the vintage STAC and re -manufactured all parts of the STAC internals completely. Due to hurricane impacts on the third -party seal vendors, these seals took several months to manufacture and acquire. Ultimately, the STAC was fully rebuilt with new seals and successfully shop tested in May of 2022. In the meantime, after personally inspecting the re -manufactured parts of the STAC in Louisiana, Hilcorp also mobilized divers to the wellhead in the Fall of 2021 to verify measurements and the condition of the subsea wellhead both with an aim to verify the seal geometry that the STAC relies on to seal against, and to design and manufacture a completely separate, alternate sealing option for the STAG. The dives proved to exceed the limits of what can be achieved with conventional diver tools. Hilcorp worked with wellhead vendors, dive companies, subsea imaging companies, overseas modelling companies, and construction experts to explore other options to acquire the precise dimensions needed from the subsea wellhead. A Cofferdam installed over the wellhead was proposed to allow for LiDAR (Laser Imaging, Detection, and Ranging) scanning, but the permits required for installation of such a structure did not meet the timeline needed to execute the work in the Spring of 2022, when ice conditions in the Cook Inlet would allow for diving again. Two separate options were pursued in parallel as alternatives: An epoxy molding of the wellhead and a handheld UDAR "blackwater box". Equipment and materials for both options were designed, ordered, and delivered to Alaska in record time. A consultant in Norway, Lateral AS, specializing in deep sea epoxy integrity operations was contracted to engineer an epoxy suitable for the cold temperatures of the Cook Inlet and design a diver -friendly mold. The epoxy was tested to ensure the compound would cure at the subsea wellhead temperatures. Separately a mold cast was fabricated to suit the opaque diving conditions that prevail during diver installation. This proved to be challenging given the size and weight of each cast needed to mold each wellhead component. A mockup wellhead was fabricated and blackwater lab deployment of the epoxy and mold casting was tested three times. After the design was finalized the epoxy and mold castings were sent to Anchorage from Norway. The LiDAR "blackwater box" proved to be the first technology that proved up and delivered the results necessary. The system included a LiDAR scanning camera mounted inside a form -fitted aluminum box with active freshwater purging of the scan area to allow for LiDAR to scan the components of the subsea wellhead. Testing of a prototype in the Cook Inlet waters at the Port of Anchorage in May of 2022 informed the manufacture of a final design which was built and tested successfully, also at the Port of Anchorage in May. By the end of May 2022, divers were mobilized to the subsea wellhead and over the course of five days some 30 LiDAR scans were successfully completed to verify the sealing and latch dimensions of the wellhead. Processing and delivery of the LiDAR data was forecasted to take 14 days. This was still a very tight timeline to allow for design and manufacture of the alternate connector for delivery by the Fall of 2022, which was the agreed timeline for return to the P&A from AOGCC. Every effort was made to accelerate delivery, but LiDAR data processing consumed over 30 days which compressed the timeline even more. The final design of the new slip -lock wellhead, informed by the LiDAR data, requires two custom plastic -packed energize - able elastomeric "P-seals" as the sealing mechanism. This is a significant improvement over the vintage STAC design, which relies on only one self -energizing elastomeric seal over the wellhead. It is also worthy of note that later generations of the STAC incorporated two seals as well. We can assume that this improved the reliability of the later generations of the STAG. However, the original design does not have a large enough seal section on the subsea wellhead to incorporate two seals where the STAC engages, so two seals cannot be added to the STAC. The slip -lock design seals on a lower section of the wellhead where two seals can be engaged. Because the slip -lock wellhead is a custom design the P-seals for the slip -lock must be custom-made (as with the seals for the STAC). All components of the slip -lock wellhead can be sourced, manufactured, and delivered within the Fall timeline for the rig, but the P-seals cannot. They are a 14-week order -to -delivery item and all options to accelerate this timeline have been met without success. The industry continues to cope with raw material sourcing, commodity demands, supply chain, and transportation issues. After numerous meetings and discussions with Cactus Wellhead, Hilcorp is advised that the slip -lock wellhead can be manufactured and fully shop tested over the winter months. This would allow for the possibility of installation and pressure -testing on the subsea wellhead in the Spring of 2023 before the rig arrives which would greatly reduce the uncertainty of well control and the rig workover. And more importantly, would offer the assurance of two separate methods of attaining the critical seal on the subsea wellhead during the workover should one method fail. In spite of our best efforts over the last year to scan the wellhead for critical dimensions and manufacture this equipment we cannot deliver the new sealing equipment in due time for a rig intervention this Fall. Hilcorp has only one option to achieve this seal currently available, which is the re -manufactured STAG. We do not think it is advisable to move a rig over this well with only one sealing option to keep the well under control throughout the P&A work. Hilcorp appreciates that the AOGCC has granted several extensions to delivery of the final P&A. And while we are eager to complete this work and deliver on our commitments, we find it advisable to ask for another extension so that the work can be executed safely and compliantly, and most paramount, in the interest of responsible well control during the final rig intervention to complete the P&A. Hilcorp respectfully requests an extension to commence rig work in the Spring of 2023 to allow time for this work to be executed in the interest of a clean, safe, and seamless intervention and completion of the P&A. Sincerely, Aras Worthington (4643) Digitally signed by Aras Worthington (4643) DN: cn=Aras Worthington (4643), ou=Users Date. 2022.08.03 13:00:45-08'00' Aras Worthington Senior Technical Advisor for Alaska Operations Hilcorp Alaska, LLC Phone: 1-907-5 64-4763 Mobile: 1-907-440-7692 Email: Aras.Worthington@Hilcorp.com 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov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laska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov October 26, 2021 Monty M Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: OTH-20-014 Plugging and Abandonment of Cook Inlet State 17589 1A (PTD 162-028) Dear Mr. Myers: On March 6, 2018, the Alaska Oil and Gas Conservation Commission (AOGCC) sent a letter to Hilcorp Alaska, LLC (Hilcorp) requiring the plugging and abandonment (P&A) of the Cook Inlet State 17589 1A well (PTD 162-028) be completed by November 1, 2020. On March 27, 2020, Hilcorp requested an extension of the deadline to P&A the Cook Inlet State 17589 1A well from November 1, 2020 until November 1, 2021. Hilcorp stated that the COVID- 19 pandemic impacted its ability to complete the P&A operations in the May to October 2020 window due to the logistics of personnel from outside Alaska, extended delivery times for equipment, and potential delays in the scheduling of surveys of the Jack-up MODU. The AOGCC granted Hilcorp's request for an extension of time to P&A Cook Inlet State 17589 1A until September 1, 2021. On August 20, 2021, Hilcorp requested an extension of the deadline to P&A the Cook Inlet State 17589 1A well from September 1, 2021 until November 20, 2021 or when ice formation in the Cook Inlet became a concern, whichever came first. Hilcorp stated the current deadline could not be met due to the need to repair and rebuild the Shafer subsea wellhead Auto Connector. The AOGCC granted Hilcorp's request for an extension of time to P&A Cook Inlet State 17589 1A until November 20, 2021. On October 15, 2021, Hilcorp requested another extension of the deadline to P&A the Cook Inlet State 17589 1A well from November 20, 2021 until the open water season of 2022. Hilcorp states that additional time is needed for a second attempt to rebuild the seals on the Shaffer style auto connector and that it will provide a plan to complete the rebuild and testing of the auto connector to the AOGCC by December 15, 2021. Hilcorp also states that there are minimal risks to leaving the well in its current condition over the winter. Docket Number: OTH-20-014 October 26, 2021 Page 2 of 2 AOGCC grants Hilcorp's request for an extension of time to P&A Cook Inlet State 17589 1A until July 31, 2022. A plan to complete the rebuild and testing of the auto connector must be provided to the AOGCC by December 15, 2021. Hilcorp must submit a new Application for Sundry Approval (Form 10-403) for the plug and abandonment operations to include the information gained during the work performed in 2021. Sincerely, Jeremy M. Price Chair, Commissioner Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.26 11:26:24 -08'00' Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov August 31, 2021 Mr. Paul Mazzolini Drilling Engineering Advisor Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: OTH-20-014 Plugging and Abandonment of Cook Inlet State 17589 1A (PTD No. 162-028) Dear Mr. Mazzolini: On March 6, 2018, the Alaska Oil and Gas Conservation Commission (AOGCC) sent a letter to Hilcorp Alaska, LLC (Hilcorp) requiring the plugging and abandonment (P&A) of the Cook Inlet State 17589 1A well (PTD 162-028) be completed by November 1, 2020. On March 27, 2020, Hilcorp requested an extension of the deadline to P&A the Cook Inlet State 17589 1A well from November 1, 2020 until November 1, 2021. Hilcorp stated that the COVID-19 pandemic impacted its ability to complete the P&A operations in the May to October 2020 window due to the logistics of personnel from outside Alaska, extended delivery times for equipment, and potential delays in the scheduling of surveys of the Jack-up MODU. The AOGCC granted Hilcorp's request for an extension of time to P&A Cook Inlet State 17589 1A until September 1, 2021. On August 20, 2021, Hilcorp requested another extension of the deadline to P&A the Cook Inlet State 17589 1A well from September 1, 2021 until November 20, 2021 or when ice formation in the Cook Inlet becomes a concern, whichever comes first. Hilcorp states the current deadline cannot be met due to the need to repair and rebuild the Shafer subsea wellhead Auto Connector. AOGCC approves Hilcorp's request for an extension of time to P&A Cook Inlet State 17589 1A subject to the following conditions. Plugging and abandonment is to be completed by November 20, 2021. Because cold temperatures that impact BOPE performance may necessitate shutting down operations in advance of ice formation on the Cook Inlet, an update on the status of the repair of the subsea wellhead, the status of the well P&A and a contingency plan to secure the well over the winter in the event the P&A is delayed until 2022 must be provided to the AOGCC by October 15, 2021. Sincerely, Jeremy M. Price Chair, Commissioner Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.01 09:48:51 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 12,676'3,045' Casing Collapse Structural Conductor Surface Intermediate Production Liner (FISH) Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Paul Mazzolini pmazzolini@hilcorp.com 777-8369 12,422' 3,045' 3,045' 765 Multiple See Schematic Length Size COMMISSION USE ONLY Tubing Grade: Tubing MD (ft): Cemented 165' / 165' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 17589 162-028 3800 Centerpoint Drive, Suite 1400, Acnhorage, AK 99503 N/A 50-833-10013-00-00 Hilcorp Alaska, LLC Wildcat CI 17589 1A PRESENT WELL CONDITION SUMMARY 151' 151' N/A TVD Burst 196' MD 225' / 655' 1,579' 5,489' 225' / 655' 1,579' 25' 30" 24" / 20" 13-3/8" 99' / 529' 9-5/8"5,363' 1,453' 10,325' Perforation Depth MD (ft): 5,489' Cemented 10,199' 5" Perforation Depth TVD (ft): Tubing Size: 10,139'7" 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 6/4/2021 12,404'2,200' 2-3/8" 12,162' BPV / Otis Nipple w/ Plug Authorized Title: Drilling Manager Authorized Name: Monty Myers Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. 4.19.2021 By Samantha Carlisle at 3:41 pm, Apr 19, 2021 321-200 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.04.19 14:10:15 -08'00' Monty M Myers DSR-4/19/21 X 10-407 13-3/8" casing shoe plug waived per 20 AAC 25.112(c)(2) - No Aquifers. Wellhead removal within 2.5 feet of mudline approved per 20 AAC 25.172(b) DLB 04/19/2021 X Rig Inspection Required. X BJM 5/28/21 Send daily operational reports and CBL logs to AOGCC. 1343 BOP test to 1400 psi. dts 6/1/2021 See additional conditions of approval on next page. JLC 6/2/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.02 15:49:05 -08'00' RBDMS HEW 6/4/2021 Additional conditions of approval for Abandonment sundry #321-200, Well CI 17589 1A (PTD 162-028) 1. Provide well location coordinates and final casing height information to NOAA for inclusion on the “NOAA Navigational Chart – Cook Inlet” and provide evidence to the AOGCC in the 10-407 that the information has been submitted to NOAA. Cook Inlet State 17589 1A P&A Discussion History Well Cook Inlet State 17589 1A was drilled as a relief well for Cook Inlet State 17589 1 in 1963 from an early drilling barge WODCO 2. Well control was lost during drilling operations from WODCO 2 on Well 17589 in August of 1962 but due to winter weather and ice the relief well 17589 1A was suspended in December 1962 and not drilled to TD and the blowout not brought under control until October of 1963. There is reference in the well files to damaged 7” casing at 8900’-9000’ MD during the pumping of fluids during the well kill operations. A 5” liner was run and cemented from 10,010’ MD to the base plate at the mudline to re-establish well integrity. See Figure #1 Wellbore Schematic Well 17589 1A. After the blowout was brought under control the deepest producing zone was abandoned and the well was suspended due to the coming winter season in November 1963. Well operations were commenced in April 1964. Prospective hydrocarbon producing zones were then sequentially tested from deepest to shallowest during the summer of 1964. After the testing of each set of perforations they were abandoned with cement squeezes, packers or cement retainers in the 5” casing. There are some records of weight testing retainers and casing pressure tests but the well records are not very detailed as monthly recaps were submitted to the State of Alaska and not daily reports. Perforating and plugging documentation to the State was found in the AOGCC well record to confirm the perforation depths, cement squeeze volumes and associated retainers and packers with their cement caps. However, a retainer with a cement plug was not placed just below the mudline to complete the P&A of 17589 1A. The placing of this surface plug just below the mudline is a main focus of the proposed well work. The deeper formations below 10,000’ TVDSS tested black oil, gas and condensate and are over pressured (13-15 ppg) while the formations above 10,000’ MD TVDSS are dry gas producing with normal pressure gradient (9-9.5ppg). Review of the documentation of the production tests of formations from 6500’-3500’ MD made no mention of any water production, no oil production and no pressure anomalies noted from downhole gauges during 4 gas zone DST’s. The recorded bottom hole pressures from the recorded test data are indicative of a normal pressure gradient, so it is a valid assumption that the lower abnormally pressured zones were successfully abandoned. The subsea wellhead system and associated base plate is located in 126’ of water at zero tide and is 1960 vintage Shaffer system that is set up for diverless operations and does not have any annulus valve openings or exposed casing hanger lock down pins. As no annulus openings are available there is no simple, straight forward way to measure the possible shut in wellhead pressure. Access to the well to determine if there is shut in wellhead pressure will be through a full opening safety valve (FOSV) with 4 ½” IF threads that is in the closed position and is welded to a Series 1500, 5000 psi flange and nipple -up to a Shaffer casinghead spool. TOC @ 3340' MD per CBL Dive work performed during summer of 2014 by ConocoPhillips (previous responsible Operator) developed the dimensional drawings of the wellhead and casing spools with the FOSV located on top of the wellhead spools. Marine debris and scale were cleaned from the exterior wellhead spools and the FOSV. It was also noted that the base plate is covered by at least 2’ of sediment (mainly silt) and cement. See Figure 2 and Table 1 with dimensions. Most Recent Diagnostic Work In November 2019 dive work was performed and verified four critical items to prepare for 2020 P&A operations: 1. Thread type of the FOSV was proven to be 4 ½” IF. After cleaning the threads of the box of the FOSV a diver was able to fully make up a lift pin into that box. This will improve the ability to be prepared to “hot tap” the FOSV to check for shut in surface pressure. 2. The top flange is a 14”, Series 1500, 5000 psi. This flange is an option for connecting the riser to the Spartan 151 BOP stack. Verified by dimensions and number and size of studs and nuts. The adapter from the Series 1500 flange to the riser will fabricated. 3. Verified the subsea wellhead is at 88 degrees, so almost vertical which will aid in attaching the riser back to the deck of Spartan 151 and the BOP equipment. 4. Verified that no guideline posts are located on the base plate but lifting eyes are located on the top spool of the wellhead that could possibly be utilized to assist in guiding riser and equipment to the wellhead. Path Forward Work is progressing with well control specialists, wellhead specialists and fishing specialists to develop options and procedures to: 1. Check for shut in wellhead pressure (hot tap performed by divers with Wild Well Control equipment) 2. Mitigate pressure if found 3. Pull 2 3/8” tubing hanger and 2 joints of 2 3/8” tubing with an Otis plug in a nipple between the tubing joints after confirming no pressure. 4. Checking for cement tops and pressures in each successive annulus. Cutting casing releasing and retrieving the associated 5”, 7” and 9 5/8” casing hangers with associated casing joints to +/- 400’ below mudline or above top of annulus cent tops. 5. Set 13 3/8” CIBP, test casing to 500 psi and spot 150’ cement plug to 5’ below mudline. 6. Nipple down a wellhead casing spool 7. Weld P&A cap in place with appropriate well information Work Plan The Spartan Rig 151 will provide the work platform to complete the P&A of Well 17589 1A. Work is anticipated to begin in June of 2021 and take three to four weeks depending upon complicating factors. Three to four tugs will be utilized to mobilize the Spartan 151 from Rig Cut off casing spool at mud line. bjm May be ~2 ft above mud line - bjm. Tenders Dock in Nikiski, AK to the location of Well 17589 1A. A Marine Surveyor, Rig Moving Specialist and positioning contractor will be utilized to track the movements of Spartan 151 and tugs to the well location at 61 deg 04.1156636’ N latitude and 150 deg 56.7077770’ W longitude and place the jackup accurately on location. Well 17589 1A and the Spartan 151 will be 2900’ SSE of the Tyonek Platform, 1715’ east of Well 17589 1 (blowout well) and 980’ west of the gas and oil lines that run from the Tyonek Platform to the East Forelands. See Figure 3. Prior to the mobilization of Spartan 151 a hazards review of the seafloor at the well site will be performed to determine that the seafloor has topography and integrity to allow 151 to be jacked up and provide the work platform for the P&A of Well 17589 1A. Divers will inspect the seafloor and legs once 151 has been jacked up to ensure the rig has stable footing to accommodate the well work to be performed. Spartan 151 operations will be supported from OSK Dock in Nikiski, AK for both workboats and helicopters. Variance Requests from AOGCC Regulations 1. Request that a cement plug will not be required across the 13 3/8” casing shoe at 1579’ below mudline as there are no freshwater aquifers to protect in this area of the Cook Inlet. 2. Request the wellhead base plate and lower wellhead spool be allowed to remain in place. The base plate is covered by over 2’ of cement and sediment. The 13 3/8”, 20”, 24” and 30” casings are all cemented to the mudline. The wellhead spool will extend about 6’ above the mudline. A cap will be welded onto the casing hanger spool with the required well information. OK - No Aquifers. Request denied. Wellhead to be cut off as close to mudline as possible with external cutter (<2.5 ft above mudline) - bjm If 13-3/8" shoe fails a pressure test, the 9-5/8" casing stub will need to be cemented. North Cook Inlet State 17589 1A P&A Procedure 1. MIRU Spartan 151. Determine RKB for well work once jacking of Rig 151 completed (est. 175’RKB). AOGCC to perform Rig Inspection prior to performing well work. The AOGCC Inspector will be notified once Rig 151 is set on location at Well 17589 1A. 2. Divers to rig up hot tap saddle and hot tap assembly with bleed off pump in capabilities to Rig 151. Pressure test to 800 psi. Hot tap and check for wellhead pressure. Notify AOGCC Inspector and Engineer if pressure is encountered . Record pressure if encountered and bleed off same. Note: Utilize Alternative Method of calculating MASP of 765 psi to establish test pressure for well pressure control equipment, BOP’s, lubricator, wellhead connections, etc…) 3. Establish secure connection to FOSV (TIW) @158’ RKB (4 ½” IF connection functional) on subsea wellhead through DP (RKB Spartan 151 to mudline +/- 175’, determined at RU). 4. RU pump in sub with hardline tie in to Rig 151 choke manifold. 5. Rig up Eline and lubricator. Make up Welltec tractor with milling assembly to drill out ball of FOSV. Test lubricator to 800 psi. RIH with tractor to 158’ RKB and mill out FOSV ball. Record pressure if encountered. POH. 6. RIH with Eline to confirm location of the 2 3/8” tubing hanger @ +/- 162’ RKB and the plug in the Otis nipple @ +/- 192’ between the 2 joints of 2 3/8” tubing. POH. 7. RIH and using a single hole mechanical tubing punch, punch a hole in the 2 3/8” tubing. 8. Monitor well after the single hole punch. If no pressure found, pressure test to 1000 psi for 20 minutes and record test . If pressure found, record pressure and notify AOGCC Inspector and Engineer. Bleed off pressure through choke manifold if required and fill hole. Record time to bleed off, fluid type and hole fill volume. 9. Set plug in 2 3/8” tubing above Otis tubing plug to give 2 barriers. Test to 800 psi. POH 10. Disconnect drill pipe from new FOSV 11. Divers remove FOSV (flange connection to wellhead) 12. NU riser to subsea wellhead. Notify AOGCC Inspector to witness pressure test . NU and test riser/BOPE with VBR’s to cover 2 3/8” to 5” to 1000 psi (stair step test pressure to 1000 psi for all following pressure tests) 13. RU, test lubricator to 1000 psi and RIH to pull recent 2 3/8” plug. Monitor well for pressure. Attempt to pull original Otis plug before pulling tubing hanger. If unsuccessful unseat hanger and pull tubing with plug in place, only 2 joints of tubing to pull. 14. RIH with 98 joints of 2 3/8” tubing to +/- 3045’ (top retainer with 5 sx cement cap) and circ well to seawater or kill weight fluid as required. Record volume to fill hole and establish circulation. Check returns for weight and fluid type. POH. Plug set above tbg punch. Pressure test to 1400 psi. bjm Pressure test to 1400 psi. bjm Test BOP to 1400 psi. bjm Test to 1000 psi. bjm 15. NU lubricator on annular and test the above and 5” casing to 1000 psi. RU and RIH with 5” gauge ring. RIH with CCL, GR, CBL to +/- 3045’ RKB and log to 175’ RKB (175’ approximate RKB for Spartan 151 to mudline) to look for cement in 5” x 7” annulus 16. RIH with 5” casing punch and perf at 700’ RKB or above TOC to check for pressure in 5” x 7” annulus . If pressure is found, record pressure and notify AOGCC Inspector and Engineer. If pressure is not found, pressure test to 1000 psi to confirm wellbore integrity after 5” perforated. RIH with workstring and circulate seawater or kill weight fluid depending on if pressure is found. 17. RIH and cut 5” casing at 500’ below mudline or above TOC (+/- 675’ RKB). ND lubricator. 18. Install 5” casing rams and test breaks to BOPE to 1000 psi . Pull 5” casing with hanger. Casing jacks are available if needed. 19. NU lubricator and test lubricator and 7” casing to 1000 psi. RU and RIH with 7” gauge ring to 500’ below mudline (+/- 675’ RKB). RIH with CCL, GR, CBL and log from 675’ RKB to 175’ RKB to look for cement in 7” x 9 5/8” annulus and verify stage tool depth (188’ below mudline/ +/-363’ RKB). 20. RIH with 7” casing punch and perf at 500’ below mudline or above TOC (+/- 675’ RKB) to check for pressure in 7” x 9 5/8” annulus. Monitor well. If pressure is found, record pressure and notify AOGCC Inspector and Engineer. If pressure is not found, pressure test to 1000 psi to confirm wellbore integrity after 7” perforated. ND lubricator. RIH with workstring and circulate seawater or kill weight fluid if pressure is found. ND lubricator. 21. Install 7” casing rams and test breaks to BOPE to 1000 psi. 22. RIH with 4 ½” DP and mechanically cut 7” casing at 470’ below mudline or above TOC (+/-645’ RKB). Pull 7” casing and hanger. Casing jacks available if needed 23. Note: Not certain that top spool will need to be nippled down to access the 9 5/8” casing hanger but if it does a storm packer will be set and tested, all breaks will be pressure tested to 1000 psi and storm packer pulled prior to continuing well work. 24. RU lubricator and test lubricator and 9 5/8” casing to 1000 psi. RIH with 9 5/8” gauge ring to 470’ below mudline (+/- 645’ RKB). RIH with CCL, GR, CBL and log from 645’ RKB to 175’ RKB to look for cement in 9 5/8” x 13 3/8” annulus and verify stage tool depth (+/- 157’ below mudline/332’ RKB ). If nipple down of wellhead spool not required to access 9 5/8” casing hanger skip to step 29. 25. RIH with 9 5/8” storm packer on 4 ½” DP and set at +/- 500’ RKB and test to 1000 psi. POH. 26. Divers ND riser from top flange and ND / remove top 78” subsea wellhead spool 27. Divers NU riser to second flange connection. Test riser connection to subsea wellhead and 9 5/8” casing to 1000 psi 28. RIH and pull storm packer 1400 psi. Function pressure test casing rams. Test to 1400 psi. Test to 1400 psi. 1400 psi. Function pressure test casing rams. 1400 psi. 29. RIH with 9 5/8” casing punch and perf at 155’ below mudline (or deepest point above TOC in 9 5/8”x 13 3/8” annulus, +/- 330’ RKB) to check for pressure in 9 5/8” x 13 3/8” annulus. Monitor well. If pressure is found, record pressure and notify AOGCC Inspector and Engineer. If pressure is not found, pressure test to 1000 psi to confirm wellbore integrity after 9 5/8” perforated. RD lubricator. RIH and circulate seawater or kill weight fluid if pressure is found. 30. Install 9 5/8” casing rams and test breaks to BOPE to 1000 psi 31. RIH with 4 ½” DP and mechanically cut 9 5/8” casing at 150’ below mudline (+/- 325’ RKB), above stage tool or shallowest cement found by CBL. Pull 9 5/8” casing and casing hanger. Casing jacks available if needed 32. RIH with 13 3/8” casing scraper on 4 ½” DP to 325’ RKB 33. RIH with 13 3/8” CIBP and set at 325’ RKB or above TOC in the inner annuli. Pressure test casing to 500 psi. 34. Spot surface cement plug to 5’ below mudline @ 180’ RKB from 325’ RKB (150’ / 126 ft3 / 23 bbls / 110 sx Class G) 35. Rig down cementers & WOC. 36. Tag cement plug and weight test to verify cement top, witness by AOGCC. Waiver request to leave base plate and lower wellhead in place +/- 6’ above seafloor granted. (baseplate covered w/ 2’ of sediment, that includes cement) 37. Divers weld metal cap with well information to top flange of wellhead spool. Confirm with picture. 38. Information on P&A cap plate a. Operator Name b. Well Name c. Permit to Drill Number d. API Number with Suffix e. Well Location Coordinates 39. RDMO Spartan Rig 151 Superseded - steps 29-39 29. RIH with 9 5/8” casing punch and perf at 155’ below mudline (or deepest point above TOC in 9 5/8”x 13 3/8” annulus, +/- 330’ RKB) to check for pressure in 9 5/8” x 13 3/8” annulus. Monitor well. If pressure is found, record pressure and notify AOGCC Inspector and Engineer. If pressure is not found, pressure test to 1000 psi to confirm wellbore integrity after 9 5/8” perforated. RD lubricator. RIH and circulate seawater or kill weight fluid if pressure is found. 30. Install 9 5/8” casing rams and test breaks to BOPE to 1000 psi 31. RIH with 4 ½” DP and mechanically cut 9 5/8” casing at 150’ below mudline (+/- 325’ RKB), above stage tool or shallowest cement found by CBL. Pull 9 5/8” casing and casing hanger. Casing jacks available if needed 32. RIH with 13 3/8” casing scraper on 4 ½” DP to 325’ RKB 33. RIH with 13 3/8” CIBP and set at 325’ RKB or above TOC in the inner annuli. Pressure test casing to 500 psi. 34. Spot surface cement plug to 5’ below mudline @ 180’ RKB from 325’ RKB (150’ / 126 ft3 / 23 bbls / 110 sx Class G) 35. Rig down cementers & WOC. 36. Tag cement plug and weight test to verify cement top, witness by AOGCC. A revised waiver request to leave the base plate and 2’- 2.5’ of wellhead spool above mudline depending on how close diver can place saw to the mudline for the final cut has been granted. (baseplate covered w/ 2’ of sediment, that includes cement) 37. Divers weld metal cap with well information to top flange of wellhead spool. Confirm with picture. 38. Information on P&A cap plate a. Operator Name b. Well Name c. Permit to Drill Number d. API Number with Suffix e. Well Location Coordinates 39. RDMO Spartan Rig 151 170' below mudline - bjm Set top of CIBP at least 160' below mudline. Test to 1400 psi If pressure test of 9-5/8" x 13-3/8" annulus fails, an alternative plug will be required per 20 AAC 25.112(c)(2) bjm. Minimum plug height = 150 ft. Function pressure test casing rams. Attachment 3Cook Inlet State 17589-1A Formation Pressure Profile to Tyonek Platform Measured Formation PressuresTopBaseTopBaseNameFluid TypeFluid Specific GravityFluid DensityOriginal PressureOriginal PressureCurrent PressureCurrent PressureNCI A-14NCI A-15NCI A-16(MD)(MD)(SSTVD(SSTVD)(Name)Oil/Gas/Condensate(SG)(psi/ft)(psig)(ppg EMW)(psig)(ppg EMW)(psig)(psig)(psig)3,150 3,155 -3,025 -3,030 STERLING STRAY Dry Gas 1,332 8.46 889 5.65 ND 888.9 ND3,5003,505-3,374-3,379STERLING STRAYDry Gas1,4868.468895.06ND889.9ND4,0754,105-3,949-3,979STERLING 5Dry Gas1,7448.461,1505.581,2461,0501,1545,0655,085-4,939-4,959BELUGA GDry Gas2,1788.461,0804.202,2055255095,1535,163-5,027-5,037BELUGA HDry Gas2,2148.462,2148.46ND18371,5635,3505,355-5,224-5,239BELUGA H_5Dry Gas2,3028.462,3028.46NDND1,9246,1086,112-5,981-5,985BELUGA STRAYDry Gas2,6338.462,6338.466,2066,226-6,079-6,099BELUGA STRAYDry Gas2,6798.462,6798.466,3286,332-6,200-6,204BELUGA STRAYDry Gas2,7298.462,7298.4610,92710,947-10,601-10,620Tyonek CCondensate0.750.3275,1649.365,1649.3612,30012,305-11,938-11,942North ForelandOil0.820.3579,14614.739,14614.7312,31512,348-11,952-11,984North ForelandOil0.820.3579,16714.739,16714.7312,40412,676-12,039-12,305North ForelandOil0.820.3579,32314.739,32314.73Maximum Anticipated Surface Pressure CalculationAssumptions:1. Calculations assume noted sands are 100% gas (worst case)2. Calculations assume worst case event is complete evacuation of wellbore to gas.3. Anticipated fracture gradient @ 3500'TVD + 12.5 ppg EMW / 0.65 psi/ft (FIT NCIU B-3 for 13 3/8" shoe).4. Reports in 17589 1A well file list no issues with high pressures from deeper oil and condensate/gas zones so isolation is assumed for MASP calculations.5. NCIU A-15 RFT data from 2008 utilized as it is closest offset producer on Tyonek Platform.Fracture Gradient @ top perfs in 17589 1A with a full column of gas from top perfs to mudline:3025 ft SSTVD x 0.65 psi/ft =1966 psi1966 psi - [0.1 psi/ft x 3025 ft] =1663 psiMASP from Tyonek Platform well BHP's (Sterling) @ 3025 ft SSTVD with a full column of gas to mudline:889 psi - [0.1 psi/ft x 3025 ft] =586 psi889 psi - [2/3 x ( 0.1 psi/ft x 3025 ft)] + [1/3 x (0 .44 psi/ft x 3025 ft)] =243 psiAlternate MethodMASP from Tyonek Platform well BHP's (Beluga H) @ 5027 ft SSTVD with entire wellbore from there to mudline evacuated to gas:1837 psi - [0.1 psi/ft x 5027 ft] =1334 psi1837 psi - [2/3 x (0.1 psi/ft x 5027 ft)] + [1/3 x (0.44 psi/ft x 5027 ft)] = 765 psiAlternative MethodFormations & BHP : Tommy NenahloMASP Calc : Paul Mazzolini 12/16/2019Perf DepthsPressure PredictionInterval Description2008 RFT DataMPSP=3434 psi calculated from Beluga H minus gas gradient of 0.1 psi/ft due to dry gas reservoir fluid. bjm _____________________________________________________________________________________ Revision By: CJD 4/13/2021 SCHEMATIC Well: Cook Inlet State 1A (17589) PTD: 262-028 API: 50-833-10013-00 Last Completed: 7/8/64 TD 12,676’ MD 30” KB to MLLW = 20’ / KB to Mudline = 146’ 8 9 5 6 12 13 2,3,4 13-3/8” 7 5” 9-5/8” 7” 10 1 24” Casing Break 8900’ – 8985’ MD 11 20” 5” CASING DETAIL Size Wt Cmt Top Btm 30” 68 Jetted Surface 151’ 24” 94 300 sx Surface 225’ 20” 78 1600 sx Surface 655’ 13-3/8” 54.5 1510 sx Surface 1,579’ 9-5/8” 36/40 600 sx Surface 5,489’ 7” 23/26 300 sx Surface 10,325’ 5” Tieback 18 540 sx Surface 10,086’ 5” 18 180 sx 10,101’ 12,404’ PERFORATION / Squeeze DATA Top (MD) Btm (MD) Cement Squeeze 3105’ 3155’ 245 sx 3500’ 3505’ 250 sx 4075’ 4105’ 150 sx 5065’ 5085’ 200 sx 5153’ 5163’ 200 sx 5350’5355’200 sx 6108’ 6112’ 50 sx 6206’ 6226’ 50 sx 6328’ 6332’ 50 sx 10927’ 10947’ 40 sx 12300’ 12303’ 50 sx 12315’ 12348’ 50 sx 12364’ 12378’ 50 sx 54 sx pumped below cmt retainer at 12,387’ JEWELRY DETAIL Number Depth MD Item 1 133’ 2-3/8” Tubing Hanger 2 164’ 1 Jt 2-3/8” tubing 3 165’ 2-3/8” Otis Nipple w/Plug 4 196’ 1 Jt 2-3/8” tubing 5 283’ 9-5/8” Stage Tool 6 314’ 7” Stage Tool 7 3,045’ Cmt Retainer 5 sx cmt on top 8 3,833’ Cmt Retainer 10 sx cmt on top 9 5,025’ Cmt Retainer 15 sx cmt on top 10 5,320’ Model “N” Packer 15 sx cmt on top 11 10,883’ Model “N” Packer 12 12,280’ Model “N” Packer 13 12,387’ Cmt Retainer Superseded _____________________________________________________________________________________ Revision By: CJD 5/7/2021 SCHEMATIC ________________________ Well: Cook Inlet State 1A (17589) PTD: 262-028 API: 50-833-10013-00 Last Completed: 7/8/64 ____________ TD 12,676’ MD 30” KB to MLLW = 20’ / KB to Mudline = 146’ 8 9 5 6 12 13 2,3,4 13-3/8” 7 5” 9-5/8” 7” 10 1 24” Casing Break 8900’ – 8985’ MD 11 20” 5” CASING DETAIL Size Wt Cmt TOC Top Btm 30” 68 Jetted Mudline Surface 151’ 24” 94 300 sx Mudline Surface 225’ 20” 78 1600 sx Mudline Surface 655’ 13-3/8” 54.5 1510 sx 260’ Surface 1,579’ 9-5/8” 36/40 600 sx 3,970’ Surface 5,489’ 7” 23/26 300 sx 9,050’ Surface 10,325’ 5” Tieback 18 540 sx 3,340’ Surface 10,086’ 5” 18 180 sx 10,630’ 10,101’ 12,404’ PERFORATION / Squeeze DATA Top (MD) Btm (MD) Cement Squeeze 3105’ 3155’ 245 sx 3500’ 3505’ 250 sx 4075’ 4105’ 150 sx 5065’ 5085’ 200 sx 5153’ 5163’ 200 sx 5350’ 5355’ 200 sx 6108’ 6112’ 50 sx 6206’ 6226’ 50 sx 6328’ 6332’ 50 sx 10927’ 10947’ 40 sx 12300’ 12303’ 50 sx 12315’ 12348’ 50 sx 12364’ 12378’ 50 sx 54 sx pumped below cmt retainer at 12,387’ JEWELRY DETAIL Number Depth MD Item 1 133’ 2-3/8” Tubing Hanger 2 164’ 1 Jt 2-3/8” tubing 3 165’ 2-3/8” Otis Nipple w/Plug 4 196’ 1 Jt 2-3/8” tubing 5 283’ 9-5/8” Stage Tool 6 314’ 7” Stage Tool 7 3,045’ Cmt Retainer 5 sx cmt on top 8 3,833’ Cmt Retainer 10 sx cmt on top 9 5,025’ Cmt Retainer 15 sx cmt on top 10 5,320’ Model “N” Packer 15 sx cmt on top 11 10,883’ Model “N” Packer 12 12,280’ Model “N” Packer 13 12,387’ Model “K” Retainer Review of Well Perf DataTypeTop (MD)Btm (MD)Oil (bbls)Gas (MCFD)Water (bbls)SIBHP (psi)Cement Squeeze (sx)CommentsIsolation31053155245Isolation35003505250DST407541050502001875150DST50655085000200no flow/no pressure recordedDST515351630550002463200Isolation53505355200Isolation6108611250DST62066226000273650only drilling mud recoveredIsolation6328633250DST10,92710,9471444700523640no mention of water productionIsolation12,30012,30550DST 12,315 12,348 29 0 133 50no SIBHP recorded, 12,315'-12,378' tested togetherDST12,36412,378DST 12,404 12,477 66 192 2182 8546 54open hole DST, cement pumped below retainerNotes:no pressure anomalies noted in DST downhole gaugesperfs are jet shots, 4 shots/ft _____________________________________________________________________________________ Revision By: CJD 4/19/2021 Proposed Schematic Well: Cook Inlet State 1A (17589) PTD: 262-028 API: 50-833-10013-00 Last Completed: 7/8/64 PERFORATION / Squeeze DATA/ Cement Data Top (MD) Btm (MD) Cement Squeeze 110 Sx pumped above 13-3/8 CIBP to P&A 3105’ 3155’245 sx 3500’ 3505’250 sx 4075’ 4105’150 sx 5065’ 5085’200 sx 5153’ 5163’200 sx 5350’ 5355’200 sx 6108’ 6112’50 sx 6206’ 6226’50 sx 6328’ 6332’50 sx 10927’10947’ 40 sx 12300’12303’ 50 sx 12315’12348’ 50 sx 12364’12378’ 50 sx 54 sx pumped below cmt retainer at 12,387’ TD 12,676’ MD 30” KB to MLLW = 20’ / KB to Mudline = 146’ 4 5 8 1 2 9 13-3/8” 3 5” 9-5/8” 7” 6 24” Casing Break 8900’ – 8985’ MD 7 20” 5” CASING DETAIL Size Wt Cmt Top Btm 30” 68 Jetted Surface 151’ 24” 94 300 sx Surface 225’ 20” 78 1600 sx Surface 655’ 13-3/8” 54.5 1510 sx Surface 1,579’ 9-5/8” 36/40 600 sx ±325’ Cut 5,489’ 7” 23/26 300 sx ±645’ Cut 10,325’ 5” Tieback 18 540 sx ±675’ Cut 10,086’ 5” 18 180 sx 10,101’ 12,404’ JEWELRY DETAIL Number Depth MD Item 1 - Wellhead Spool 6’ above Mudline 2 325’ 13-3/8” CIBP 3 3,045’ Cmt Retainer 5 sx cmt on top 4 3,833’ Cmt Retainer 10 sx cmt on top 5 5,025’ Cmt Retainer 15 sx cmt on top 6 5,320’ Model “N” Packer 15 sx cmt on top 7 10,883’ Model “N” Packer 8 12,280’ Model “N” Packer 9 12,387’ Cmt Retainer Superseded _____________________________________________________________________________________ Revision By: CJD 5/7/2021 Proposed Schematic ________________________ Well: Cook Inlet State 1A (17589) PTD: 262-028 API: 50-833-10013-00 Last Completed: 7/8/64 ____________ PERFORATION / Squeeze DATA/ Cement Data Top (MD) Btm (MD) Cement Squeeze 110 Sx pumped above 13-3/8 CIBP to P&A 3105’ 3155’ 245 sx 3500’ 3505’ 250 sx 4075’ 4105’ 150 sx 5065’ 5085’ 200 sx 5153’ 5163’ 200 sx 5350’ 5355’ 200 sx 6108’ 6112’ 50 sx 6206’ 6226’ 50 sx 6328’ 6332’ 50 sx 10927’ 10947’ 40 sx 12300’ 12303’ 50 sx 12315’ 12348’ 50 sx 12364’ 12378’ 50 sx 54 sx pumped below cmt retainer at 12,387’ TD 12,676’ MD 30” KB to MLLW = 20’ / KB to Mudline = 146’ 4 5 8 1 2 9 13-3/8” 3 5” 9-5/8” 7” 6 24” Casing Break 8900’ – 8985’ MD 7 20” 5” CASING DETAIL Size Wt Cmt TOC Top Btm 30” 68 Jetted Mudline Surface 151’ 24” 94 300 sx Mudline Surface 225’ 20” 78 1600 sx Mudline Surface 655’ 13-3/8” 54.5 1510 sx 260’ Surface 1,579’ 9-5/8” 36/40 600 sx 3,970’ ±325’ Cut 5,489’ 7” 23/26 300 sx 9,050’ ±645’ Cut 10,325’ 5” Tieback 18 540 sx 3,340’ ±675’ Cut 10,086’ 5” 18 180 sx 10,630’ 10,101’ 12,404’ PERFORATION / Squeeze DATA/ Cement Data JEWELRY DETAIL Number Depth MD Item 1 - Wellhead Spool 2.5’ above Mudline 2 325’ 13-3/8” CIBP 3 3,045’ Cmt Retainer 5 sx cmt on top 4 3,833’ Cmt Retainer 10 sx cmt on top 5 5,025’ Cmt Retainer 15 sx cmt on top 6 5,320’ Model “N” Packer 15 sx cmt on top 7 10,883’ Model “N” Packer 8 12,280’ Model “N” Packer 9 12,387’ Model “K” Retainer Hilcorp CIW-U 13 5/8 10MShaffer 14'’ 1500 series spool 78'’ in length 126' Water Surface MLW Riser assy, Drill-Quip, 4 ea 40' section w/ H90 connectors 20'’ x .812 wall Riser, Drill-Quip, w/ H90 box connector x 14'’ series 1500 flange 20'’ x .812 wall Riser, Drill-Quip, w/ H90 pin connector x 13 5/8 10M flange 20'’ x .812 wall 13 5/8 10M 3 1/16 10M Manual and HCR choke and kill valves 13 5/8 5M Top CIW-U 180' 14' Rig 151 BOP stack and Riser Cook Inlet 1A 4/16/2021 2-3/8" - 5" VBR Blind rams Pipe rams Plug Cementing Program Cook Inlet State 1A Surface Plug version 1 5/26/2021 Rig : Spartan 151 Field : Prepared for : Prepared by : Paul Mazzolini Stephen Lauper Hilcorp Alaka 907 273 1765 slauper@slb.com 2 of 15 ABANDONMENT SCHEMATIC 3 of 15 PLUG OPERATION SUMMARY Overview of the cementing operation (temperatures, fluid types, rates and general notes) All depths take the rig floor as reference Well & Rig Information Rig Type : OffShore Objective :Abandon with Surface Plug form 325-ft MD Section MD : 1579.0 ft Rig Floor Elev 166.0 ft Section TVD : 1579.0 ft Mud Returns Depth : 146.0 ft Well deviation : 0.0 deg Design Considerations Liquid Add Squeeze Slurry FIW Well FIW Cement Type : Slurry Spacer Type : Wash Mud Type : Water Based / Fresh Water Slurry Dens. : 15.80 lb/gal Spacer Dens. : 8.59 lb/gal Mud Dens. : 8.60 lb/gal Volume Balance Model : Level Slurry Only Underdispl. : 0.0 bbl Pumping Schedule Fluid Name Stage Volume bbl Pump Rate bbl/min Stage Time hr:mn Comment Inj. Temp. degF Liquid Add Squeeze Slurry 25.5 1.0 00:26 68.0 FIW 1.2 1.0 00:01 68.0 Well FIW 0.9 1.0 00:01 68.0 Temperature Simulation Pre-job Circ. Rate : 10.0 bbl/min BHST 40.0 degF Pre-job Circ. Time : 00:30 hr:mn Simulated BHCT 67.4 degF 4 of 15 WELL DATA SUMMARY The cementing program incorporates the following data: All depths take the rig floor as reference Section MD : 1579.0 ft Rig Floor Elev 166.0 ft Section TVD : 1579.0 ft Mud Returns Depth : 146.0 ft Tubulars and Casing Hardware MD ft OD in Weight lb/ft Grade ID in Thread Collapse psi Burst psi Joint ft Prev Casing 1579.0 13 3/8 72.0 L-80 12.347 API 2670 5380 40.0 Workstring 325.0 4 1/2 16.6 S135 3.826 API 16800 17690 40.0 Note : previous casing (and riser) collapse and burst security not verified Open Hole Total OH Volume : 0.0 bbl Mean Diameter : 0.000 in Minimum Diameter : 16.000 in Mean Ann. Excess : 0.0 % Maximum Diameter : 16.000 in Mean Eq. Diameter : 0.000 in 5 of 15 Directional Survey Formation Top MD ft Bottom MD ft Bottom TVD ft Frac Top ED lb/gal Frac Bottom ED lb/gal Pore Top ED lb/gal Pore Bottom ED lb/gal Lithology Res. Fluid Name 166.0 1579.0 1579.0 21.74 21.74 8.33 8.33 Sandstone Temperature Name Top MD ft Bottom MD ft Bottom TVD ft Temperat ure degF Temp. Gradient degF/100ft Temp. Rel. Gradient degF/100ft Sea Current ft/min Surface 0.0 0.0 0.0 80.0 0.00 0.00 SeaLevel 0.0 66.0 66.0 80.0 -0.02 -0.02 10.13 SeaBed 66.0 166.0 166.0 58.4 -13.03 -21.61 10.13 BHST 166.0 325.0 325.0 24.0 -17.23 -21.61 0.00 Rock 325.0 1819.0 1819.0 47.9 -1.76 1.60 0.00 Rock 1819.0 1820.0 1820.0 47.9 -1.76 1.60 0.00 Rock 1820.0 1821.0 1821.0 47.9 -1.76 1.60 0.00 Rock 1821.0 3500.0 3500.0 74.8 -0.15 1.60 0.00 6 of 15 FLUIDS SUMMARY Fluids Type Name Density lb/gal Conditions K lbf.s^n/f t2 n Ty lbf/100ft 2 Drilling Fluid Well FIW 8.60 Manual 4.18E-5 1.00 1.00 Wash FIW 8.59 Manual 4.18E-5 1.00 1.00 Slurry Liquid Add Squeeze Slurry 15.80 Manual 8.18E-3 0.77 0.54 Slurry Dry Blend Squeeze Slurry 15.80 Manual 2.08E-3 1.00 38.15 * Rheology and density of compressible fluids are displayed at standard conditions, ie. P = 1 atm and T = 20 degC (65 degF) 7 of 15 FLUID PLACEMENT Volume Balance Objectives Volume Balance Model: Level Slurry Only Original Fluid: Well FIW Rat Hole Fluid: Well FIW Displ. Fluid: Well FIW Spacer Ahead: FIW set Total Volume to: 8.8 bbl Spacer Behind: FIW set Total Volume to: 1.2 bbl Top Slurry: Liquid Add Squeeze Slurry set Length to: 300.0 ft Annulus is not filled during POOH. Volume Balance Results String Volume: 4.6 bbl Underdispl.: 0.0 bbl Displ. Volume: 0.9 bbl TOC after POOH: 146.0 ft Cement Length after POOH: 179.0 ft Fluid Placement in Annulus Fluid Name Top MD ft Bottom MD ft Length ft Volume bbl Surface Density lb/gal Well FIW 146.0 146.0 0.0 0.0 8.60 Liquid Add Squeeze Slurry 146.0 325.0 179.0 23.0 15.80 Fluid Placement in Pipe Fluid Name Top MD ft Bottom MD ft Length ft Volume bbl Surface Density lb/gal Well FIW 0.0 60.2 60.2 0.9 8.60 FIW 60.2 146.0 85.8 1.2 8.59 Liquid Add Squeeze Slurry 146.0 325.0 179.0 2.5 15.80 Note: Surface densities of compressible fluids are calculated at surface conditions, ie. P = 1 atm and T = 80.0 degF 8 of 15 STATIC PULL OUT OF HOLE (POOH) POOH Summary Final DP depth : 0.0 ft Theoretical Top of Plug: 146.0 ft POOH Length : 325.0 ft Theoretical Plug Length : 179.0 ft POOH Speed : Plug Bottom : 325.0 ft Top of uncontaminated cement after POOH : 185.3 ft Uncontaminated cement length after POOH : 139.7 ft Contaminated cement length after POOH : 35.7 ft POOH Results Summary Note : Simulation assumes that fluids are free to balance themselves. 9 of 15 10 of 15 WELL SECURITY Status Description Min. Pressure Margin psi at Depth ft at Time hr:mn Fracturing 0 0.0 00:00 Production/Influx 0 0.0 00:00 Success Burst 17660 146.0 00:28 Success Collapse 16764 228.0 00:02 Well Control 11 of 15 TEMPERATURE OUTPUTS BHST : 40.0 degF Simulated BHCT : 67.4 degF Static Temp at TOC : 62.7 degF Simulated HCT at TOC : 64.0 degF Temperature simulation initial condition: Geothermal profile Initial Condition Final Condition t = 00:28 hr:mn 12 of 15 BHCT and Interface temperatures 13 of 15 WELLCLEAN III WELLCLEAN III Maps Ű No cement slurry Slurry concentration is less than 10 % (by unit of volume). The concentration is below minimum threshold to consider that cement is present. Ű High risk of contamination Slurry concentration is between 10 % and 50 % (by unit of volume). There is no chance of finding hard cement when tagging within a few hours. Ű Medium risk of contamination Slurry concentration is between 50 % and 90 % (by unit of volume). It is possible to find some soft cement when tagging but it will be most likely not strong enough to kick off the well or even to provide a proper wellbore isolation. Ű Low risk of contamination Slurry concentration is between 90 % and 100 % (by unit of volume). Cement plug should be designed in such a way the target of the top of cement should be within the ‘green risk’ zone. Hard cement should be found in that zone once compressive strength has developed, i.e. after the duration determined by the lab tests at downhole condition. 14 of 15 Fluid Concentrations before POOH Average fluid concentration in annulus Average fluid concentration in pipe 15 of 15 FINAL CONTAMINATION RISK (AFTER POOH) POOH Summary Final DP depth : 0.0 ft Theoretical Top of Plug: 146.0 ft Theoretical Top of Plug (based on slurry volume) 146.0 ft Estimated TOC based on uncontaminated POOH simulation 185.3 ft Estimated TOC after POOH considering contamination during placement 182.0 ft Final Contamination Risk Note : Simulation assumes that fluids are free to balance themselves _____________________________________________________________________________________ PROPOSED 5” Drillpipe Well Tie-In _____ Well 17589 1A ____________ Size Type Wt/ Grade/ Conn Drift ID Top Btm 5” Drillpipe 19.50# / S / NC 50 3-3/4” Rig Floor 185’ 5” Crossover NC 50 x 2-9/16” 5K 3-3/4” 185’ 186.5’ 2-9/16” Gate Valve 5000 psi 2-9/16” 186.5” 188.5’ 5” Crossover 2-9/16” 5K x 4-1/2” IF 3-3/4” 188.5’ 190’ 4-1/2” FOSV 4-1/2” IF 3” 190’ __________________________________________________ THE STATE °fALASKA April 3, 2020 GOVERNOR MIKE DUNLEAVY Mr. David Wilkins Senior Vice President Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket No: OTH-20-014 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a og c c.o I a sko.gov Plugging and Abandonment of Cook Inlet State 17589 IA (PTD No. 162-028) Dear Mr. Wilkins: On March 6, 2018, the Alaska Oil and Gas Conservation Commission (AOGCC) sent a letter to Hilcorp Alaska, LLC (Hilcorp) requiring the plugging and abandonment (P&A) of the Cook Inlet State 17589 1A well (PTD 162-028) be completed by November 1, 2020. Hilcorp was also required to submit an application for Sundry Approvals for the procedure by January 10, 2020. Hilcorp's sundry application was approved on January 29, 2020. The approval expires January 28, 2021. On March 27, 2020, Hilcorp requested an extension of the deadline to P&A the Cook Inlet State 17589 IA well from November 1, 2020 until November 1, 2021. Hilcorp states that the COVID-19 pandemic has impacted its ability to complete the P&A operations in the May to October 2020 window due to the logistics of personnel from outside Alaska, extended delivery times for equipment, and potential delays in the scheduling of surveys of the Jack-up MODU. AOGCC approves Hilcorp's request for an extension of time to P&A Cook Inlet State 17589 IA. Plugging and abandonment is to be completed by September 1, 2021. An updated application for Sundry Approvals for the procedure shall be submitted to the AOGCC no later than January 29, 2021. Sincerely, i/k\� V AND APPEAL As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Hilcorp Alaska, LLC Post Office Box 744027 Anchorage, AK 99524-4027 3800 Centeryoint Drive Suite 1400 Anchorage, AK 99503 March 27, 2020 Phone: 907/777-8300 Fax: 907(777-8301 Jeremy M Price, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Re: Sundry Number: 320-016 Exploratory Field, Exploratory Pool, Cl 17589 IA Permit to Drill Number: 162-028 Dear Chairman Price: Pursuant to the approval of Sundry Notice 320-016 on January 29, 2020 to complete the P&A of Well Cl 17589 1 which became the property of Hilcorp Alaska, LLC pursuant to a Purchase and Sale Agreement between ConocoPhillips Company, ConocoPhillips Alaska, Inc. ("CPAI"), and Phillips Gas Supply Corporation, as Sellers, and Hilcorp Alaska, LLC, and Harvest Alaska, LLC, as Buyers, Hilcorp Alaska, LLC ("Hilcorp Alaska") became the operator of the North Cook Inlet Unit ("NCIU") and associated leases, including DNR Lease ADL 17589 on November I, 2016. The acquisition included the P&A of the suspended subsea well Cook Inlet State 17589 IA, API 50883100130000 (the "Well"). The AOGCC has previously extended the deadline for the completion of the P&A by Hilcorp Alaska to November 1, 2020, as approved by then -Chair Commissioner Foerster. Hilcorp Alaska has developed an approved procedure to complete the P&A in the allotted time using the Spartan Rig 151, Jack-up mobile offshore drilling unit ("Jack-up MODU") and enlisted input on equipment and procedures from well control specialist, Wild Well Control and Global Diving. While progressing the fabrication of materials, gathering the equipment and identifying personnel for the onsite well operations, the worldwide spread of COVID-19 has created significant challenges worldwide.. Hilcorp Alaska is now working diligently to comply with the Alaska Governor's mandate on persons entering Alaska, the other Federal and State mandates and the implications for our Vendors which are needed to support the preparation for and P&A operations of the Well. The significant items that need to be addressed surrounding the consequences of the COVID-19 pandemic are: 1) Personnel logistics: Approximately 70 personnel will be required to perform work on the Jack-up MODU during the different phases of the P&A operations with an average crew Jeremy M. Price, Chair Alaska Oil and Gas Conservation Commission March 23, 2020 Page 2 of 3 of 58 persons. Approximately 70% (49 of 70 personnel) will be traveling from outside Alaska (some may have been on international assignments) and would require the 14 day in-state quarantine once in Alaska. The requirement to access the 1960's subsea wellhead system to accomplish the final P&A requires personnel with a very specialized skill sets and thus the significant number of personnel from outside Alaska. Two examples are the Wild Well Control personnel, which travel internationally on a regular basis while the additional divers and support personnel (above those Alaska based) will need to come from Washington and California. The number of personnel brought into Alaska from outside the State increases the risk of the spread of COV1D-19 with persons they have contact with in Alaska. 2) The slowdown of the USA economy has effected businesses from which Hilcorp Alaska will procure equipment, fabricate materials for accessing the Well and transportation of those items to Alaska for the P&A operations and will extend delivery times that were initially quoted. 3) The scheduling of surveys of the Jack-up MODU for safety/emergency response equipment, cranes, camp facilities, and drilling rig equipment performed by Federal and State agencies, which are required prior to beginning well operations, could be delayed based upon workload and personnel available. 4) Coordination of the Well P&A operations around the optimal diving tides is critical due to the significant volume of work to be performed by divers while preparing and then accessing the subsea wellhead system. In the northem Cook Inlet the currents are extremely strong (10-12 knots) and slack tides short in duration (about 30-45 minutes) so optimal tide windows are key to safe and efficient diving operations. The ability to accurately develop a project execution timeline to coordinate the optimal tide window with the availability of the Jack-up MODU, specialized skill set personnel and equipment are all keys to a safe and successful completion of the Well P&A operations. The above items all add a level of uncertainty to establishing a coordinated timing of the optimal tide window with the availability of the Jack-up MODU and the required personnel and equipment. Hilcorp Alaska is deeply eoncemed that we cannot accomplish the P&A operations in the 2020 May — October operating window without being threatened by suspension due to ice formation in the Cook Inlet. The P&A of the 1960's vintage subsea wellhead system on Well 175891 A requires non-standard operations and involve personnel with very specialized skill sets to perform the work thus adding uncertainty to predicting the timeline required to complete the P&A. Hilcorp estimates that a minimum 100 day operational window is required for a safe and efficient preparation of the Jack-up MODU and execution of the Well P&A work. The uncertainty of the full impact of the COVID-19 virus; the timing of when the United States and state of Alaska will reach the peak of the pandemic and the recovery time required to attain a closer to normal business climate is a very significant unknown. Accordingly, Hilcorp Alaska Jeremy M. Price, Chair Alaska Oil and Gas Conservation Commission March 23, 2020 Page 3 of 3 requests approval from the AOGCC to allow the P&A of the Well to be deferred until the summer of 2021 with completion of all P&A operations by November 1, 2021. An added value of the deferral of the Well P&A to 2021 would be to free up additional funding for the drilling and completion of an additional gas well to support south central Alaska energy needs and infrastructure. Please contact Paul Mazzolini, Drilling Engineering Advisor at ;17-1275 with any questions. We look forward to discussing the request for deferral of the Well P&A at your earliest convenience. Sincerely, HILCORP ALASKA, LLC. David S. Wilkins Senior Vice President THE STATE Alaska Oil and Gas OfALASKA Conservation Commission GOVERNOR MIKE DUNLEAVY Monty Myers Drilling Manager Hilcorp Alaska, Inc. 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Exploratory Field, Exploratory Pool, Cl 17589 IA Permit to Drill Number: 162-028 Sundry Number: 320-016 Dear Mr. Myers: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.claska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. SincerelyPPrice gerey DATED this$�day of January, 2020. BBDMS (46-1 3 1 zazo �1 � �.I� r e.J STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 1. Type of Request: Abandon Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: . Permit to Drill Number: Hilcorp Alaska, LLC Exploratory Q • Development El Stratigraphic El Service ❑ 162-028' 3. Address: API Number: [6. 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-833-10013-00-00 7. If perforating: 8. Well Name and Number: s,,30 r4 d! fS 1 What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No Q CI 17589 1A " 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 17589 - Wildcat 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): 12,676' 12,422' 3,045' 3,045' 765 Multiple see schematic 3,045' Casing Length Size MD TVD Burst Collapse Structural 25' 30" 151' 151' Conductor 99'/ 529' 24" / 20" 2261655' 225'/ 655' Surface 1,453' 13-3/8' 1,579' 1,579' Intermediate 5,363' 9-518" 5,489' 5,489' Production 10,199' 7" 10,325' 10,139' Liner 2,200' 5" 12,404' 12,162' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Cemented Cemented 2-3/8" N/A 196' Packers and SSSV Type: BPV / Otis Nipple w/Plug Packers and SSSV MD (ft) and TVD (ft): 165' MD / 165' TVD 12. Attachments: Proposal Summary ❑✓ Wellbore schematic O 13. Well Class after proposed work: Detailed Operations Program BOP Sketch ❑� Exploratory ❑✓ - Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 5/15/2020 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned Q . 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Monty Myers Contact Name: Paul Mazzolini Authorized Title: Drilling Manager Contact Email: pmazzoliniQhilcorp.00m Contact Phone: 777-8369 Authorized Signat Date: O . 20 Z COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: SP15i I 3Z 1 01119 ds.LJI Plug Integrity BOP Test Integrity Test ❑ Location Clearan-cel El {MM��..,, /1 /MJechaniccal Other:" / !� .f- tri? sloe ao z�. 1►� i C�)CZ No AV-;Gs w/Imay'/ '0 + Post Initial Injection MIT Req'd2 ❑ No ❑ ll�'�^-1 ��-/`"`a `'''11r "'y 10 ^�y �"L Z O fA0— 2 174 as Ar ^T;"L' Inr t.l Spacing Exception Required? Yes ❑ No Subsequent Form Required: RBDMS O''JAN 3 120 1 APPROVED BY Approved by: COMMISSIO E T E OMMISSION Date: /� ;%t.C•' I vP (��iV \ I .� V !-: \ Submit Form and Form 10-40 is /2 1 (, PP application is valid for 12 months from the date of approval. Attachments Duplicate , _q . 7.v Cook Inlet State 175891A P&A Discussion History l Well Cook Inlet State 17589 1A was drilled as a relief well for Cook Inlet State 17589 1 in 1963 from an early drilling barge WODCO 2. Well control was lost during drilling operations from WODCO 2 on Well 17589 in August of 1962 but due to winter weather and ice the relief well 17589 1A was suspended in December 1962 and not drilled to TD and the blowout not brought under control until October of 1963. There is reference in the well files to damaged 7" casing at 8800'-8900' MD during the pumping of fluids during the well kill operations. A 5" linerwas run n and cemented from 10,010' MD to the base plate at the mudline to re-establish well integrity. See Figure #1 Wellbore Schematic Well 17589 1A. 7a - 300,) -fit r� cBL After the blowout was brought under control the deepest producing zone was abandoned and the well was suspended due to the coming winter season in November 1963. Well operations were commenced in April 1964. Prospective hydrocarbon producing zones were then sequentially tested from deepest to shallowest during the summer of 1964. After the testing of each set of perforations they were abandoned with cement squeezes, packers or cement retainers in the 5" casing. There are some records of weight testing retainers and casing pressure tests but the well records are not very detailed as monthly recaps were submitted to the State of Alaska and not daily reports. Perforating and plugging documentation to the State was found in the AOGCC well record to confirm the perforation depths, cement squeeze volumes and associated retainers and packers with their cement caps. However, a retainer with a cement plug was not placed just below the mudline to complete the P&A of 17589 1A. The placing of this surface plug just below the mudline is a main focus of the proposed well work. The deeper formations below 10,000' TVDSS tested black oil, gas and condensate and are over pressured (13-15 ppg) while the formations above 10,000' MD TVDSS are dry gas producing with normal pressure gradient (9-9.5ppg). Review of the documentation of the production tests of formations from 6500'-3500' MD made no mention of any significant water production and no oil production. The recorded bottom hole pressures from the recorded test data are indicative of a normal pressure gradient, so it is a valid assumption that the lower abnormally pressured zones were successfully abandoned. The subsea wellhead system and associated base plate is located in 126' of water at zero tide and is 1960 vintage Shaffer system that is set up for diverless operations and does not have any annulus valve openings or exposed casing hanger lock down pins. As no annulus openings are available there is no simple, straight forward way to measure the possible shut in wellhead pressure. Access to the well to determine if there is shut in wellhead pressure will be through a full opening safety valve (FOSV) with 4 X" IF threads that is in the closed position and is welded to a Series 1500, 5000 psi flange and nippled up to a Shaffer casinghead spool. Dive work performed during summer of 2014 by ConocoPhillips (previous responsible Operator) developed the dimensional drawings of the wellhead and casing spools with the FOSV located on top of the wellhead spools. Marine debris and scale were cleaned from the exterior wellhead spools and the FOSV. It was also noted that the base plate is covered by at least 2' of sediment (mainly silt) and cement. See Figure 2 and Table 1 with dimensions. Most Recent Diagnostic Work In November 2019 dive work was performed and verified four critical items to prepare for 2020 P&A operations: 1. Thread type of the FOSV is 4 %" IF. After cleaning the threads of the box of the FOSV a diver was able to fully make up a lift pin into that box. This will improve the ability to be prepared to "hot tap" the FOSV to check for shut in surface pressure. 2. The top flange is a 14", Series 1500, 5000 psi. This flange is an option for connecting the riser to the Spartan 151 BOP stack. Verified by dimensions and number and size of studs and nuts. The adapter from the Series 1500 flange to the riser will fabricated. 3. Verified the subsea wellhead is at 88 degrees, so almost vertical which will aid in attaching the riser back to the deck of Spartan 151 and the BOP equipment, 4. Verified that no guideline posts are located on the base plate but lifting eyes are located on the top spool of the wellhead that can be utilized to assist in guiding riser and equipment to the wellhead. Path Forward Work is progressing with well control specialists, wellhead specialists and fishing specialists to develop options and procedures to: 1. Check for shut in wellhead pressure 2. Mitigate pressure if found 3. Pull 2 3/8" tubing hanger and 2joints of 2 3/8" tubing with an Otis plug in a nipple between the tubingjoints 4. Checking for pressures in each successive annulus. Releasing and retrieving the associated 5", 7" and 9 5/8" casing hangers with associated casing joints to+/- 400' below mudline — 5J co,- �o A z x 9 --L-, 5. Nipple down a wellhead casing spool ` 6. Weld P&A cap in place with appropriate well information (w:'( ALJ Work Plan The Spartan Rig 151 will provide the work platform to complete the P&A of Well 17589 1A Work is anticipated to begin in May -June timeframe of 2020 and take two to four weeks depending upon complicating factors. Three to four tugs will be utilized to mobilize the Spartan 151 from Rig Tenders Dock in Nikiski, AK to the location of Well 175891A. A Marine Surveyor, Rig Moving Specialist and positioning contractor will be utilized to track the movements of Spartan 151 and tugs to the well location at 61 deg 04.1156636' N latitude and 150 deg 56.7077770' W longitude and place the jackup accurately on location. Well 17589 1A and the Spartan 151 will be 2900' SSE of the Tyonek Platform, 1715' east of Well 17589 1 (blowout well) and 980' west of the gas and oil lines that run from the Tyonek Platform to the East Forelands. See Figure 3. Prior to the mobilization of Spartan 151 a hazards review of the seafloor at the wpll site will hp ✓ performed to determine that the seafloor has topography and integrity to allow 151 to be jacked up and provide the work platform for the P&A of Well 17589 1A. Divers will inspect the seafloor and legs once 151 has been jacked up to ensure the rig has stable footing to accommodate the well work to be performed. Spartan 151 operations will be supported from OSK Dock in Nikiski, AK for both workboats and helicopters. )t Variance Requests from AOGCC Regulations -r-- �� js1� 1 F 1. Request that a cement plug will not be required across the 13 3/8" casing shoe at 5[JO, below mudline as there are no freshwater aquifers to protect in this area of the Cook Inlet. GIC —dla /-Ip..y'e.r.r 2. Request the wellhead base plate and lower casing spool be allowed to remain in place. The base plate is covered by over 2' of cement and sediment. The spool will extend 4'- 5' above the mudline. A cap will be welded onto the casing hanger spool with the required well information. The 13 3/8", 20", 24" and 30" casings were cemented to the mudline. Z-0 Q4& Z-5- «z -Cl /6) -�/.2 b-zti North Cook Inlet State 175891A P&A Procedure 1. E /l 1 MIRU Spartan 151. Determine RKB for well work once jacking of Rig 151 completed _ (est. 175'RKB)<-- ksF,r Establish secure connection to FOSV (TIW) @158' RKB (4%'gIF connection functional91 on subsea wellhead through DP (RKB Spartan 151 to mudline +/-175', determined at RU) 1-+e,TA'0 7 Open valve to check for pressure and gain access to well. DP rig up on jackup includes FOSV, pump in sub with hard line back to choke manifold a. Functionality of FOSV confirmed prior b. New FOSV torqued up to FOSV on wellhead RU lubricator and test lubricator to 800 psi. RIH to confirm location of the 2 3/8" tubing hanger @ +/-162' RKB and the plug in the Otis nipple @ +/-192' between the 2 joints of 2 3/8" tubing S. RIH and using a single hole mechanical tubing punch, punch a hole in the 2 3/8" tubing 6. Monitor well after the single hole punch. Bleed off pressure through choke manifold if required and fill hole 7. Set plug in 2 3/8" tubing above Otis tubing plug to give 2 barriers. Test to 800 psi k, WASP of 765 psi) 8. Disconnect drill pipe from new FOSV 1 9. Divers remove FOSV (flange connection to wellhead) /9" FI ---1, I 10.NU riser to subsea wellhead. NU and test riser/BOPE with VBR's to cover 2 3/8" to 5" to 1000 psi (stair step test pressure to 1000 psi for all following pressure tests) 11.RU, test lubricator to 1000 psi and RIH to pull recent 2 3/8" plug. Monitor well for pressure. Attempt to pull original Otis plug before pulling tubing hanger. If unsuccessful unseat hanger and pull tubing with plug in place, only 2 joints of tubing to pull. 12.RIH with 98 joints of 2 3/8" tubing to+/- 3045' (top retainer with 5 sx cement cap) and circ well to seawater or kill weight fluid as required. Record volume to fill hole and establish circulation. Check returns for weight and fluid type 13. NU lubricator on annular and test the above and 5" casing to 1000 psi. RU and RIH with 5" gauge ring. RIH with CCL, GR, CBL to +/- 3045' RKB and log to 175' RKB (175' approximate RKB for Spartan 151 to mudline) to look for cement in 5" x 7" annulus 14.RIH with 5" casing punch and perf at 700' RKB to check for pressure in 5" x 7" annulus. RIH with workstring and circulate seawater or kill weight fluid depending on if pressure is found. Pressure test to 000 psi to confirm wellbore integrity after 5" perforated. /PORIH and cut 5" casing at 0' below mudline (+/- 675' RKB). ND lubricator. Pull 5" casing with hanger. Casing jacks are available if needed. 4 s &X 16.NU lubricator and test lubricator and 7" casing to 1000 psi. RU and RIH with 7" gauge ring to 500' below mudline (+/- 675' RKB). RIH with CCL, GR, CBL and log from 675' RKB to 175' RKB to look for cement in 7" x 9 5/8" annulus and verify stage tool depth (188' below mudline/+/-363' RKB). ✓ 17.RIH with 7" casing punch and perf at 500' below mudline (+/- 675' RKB) to check for pressure in 7" x 9 5/8" annulus. Monitor well. ND lubricator. RIH and circulate seawater or kill weight fluid if pressure is found. Pressure test to 1000 psi to confirm wellbore integrity after 7" casing perforated. ND lubricator. 18.lnstall 7" casing rams and test BOPE to 1000 psi. 4l'19.RIH with 4 %" DP and mechanically cut 7" casing at 470' below mudline (+/-645' RKB). _ Pull 7" casing and hanger. Casing jacks available if needed 0. U lubricator and test lubricator and 9 5/8" casing to 1000 psi. RIH with 9 5/8" gauge ring to 470' below mudline (+/- 645' RKB). RIH with CCL, GR, CBL and log from 645' RKB to 175' RKB to look for cement in 9 5/8" x 13 3/8" annulus a5d"verify stage tool depth (+/- 157' below mudline/332' RKB). ao n. sEr r' °ac lc�4rN1) rrsrl x'78 ` F21.131H with 9 5/8" casing punch and pert at 155' below mudline (+/- 330' RKB) to check for pressure in 9 5/8" x 13 3/8" annulus. Monitor well. RD lubricator. RIH and circulate seawater or kill weight fluid if pressure is found. —3� 22.lnstall 9 5/8" casing rams and test BOPE to 1000 psi % CI 51a 23.RIH with 4 %_" DP and mechanically cut 9 5/8" casing at 150' below mudline (+/- 325' u'�- 3Z�" RKB) or above stage tool or shallowest cement found by CBL. Pull 9 5/8" casing and casing hanger. Casing jacks available if needed 24.RIH with 13 3/8" casing scraper on 4 %' DP to 325' RKB 25. RIH with 13 3/8" cement retainer and set at 325' RKB. Pressure test casing to 800 psi 26.Spot surface cement plug to 5' below mudline @ 180' RKB from 325' RKB (150'/ 126 ft3 / 23 bbls / 110 sx Class G) 27. Rig down cementers & WOC. c� 28.Tag cement plug and weight test to verify cement top, witness by AOGCC. (Request J waiver to leave base plate and lower wellhead in place +/- 5' above seafloor (baseplate /)?AG` covered w/ 2' of sediment, that includes cement) 29.Divers weld metal cap with well information to top flange of wellhead spool. Confirm with picture 30.RDMO Spartan 151 O t s w m � � � v 0 v > � c v `v a w a to a o m a m m m c � o_ m a N n v u N m N 0 m N CQ E�..dO._�o60 a�a 40 o z o ` vg 0 0 n C m N m q o 0 N m o m 3 w a .cw w is � d a r a a m c .? IQ m m u E v o 3 3 c 3o m 3 44000 0 m w w v ¢ v hH� m« v k µ m c a o 2 29w c w v 14 Q ¢ z u �.-irvm viri � IR �'a ZZ.miN�m w Z m vl m m p y o Z O N a ti Q m m m p p a o O p Z u'ai0 ae`�mn nn nvi vi vic rocora ro�amH.aiH n u U O_ W c`^ -w e e m e m m m m av`h aavama^.,cv m � Q �ma ro a ro rororo°�.i .<.i vrvto�m aNmmm�ton { d ei rl .Y N N N N N V1 O1 Ol O1 0 L a� ry vni vni uni p •- m m m m a s 0 0 0 0 u' n ro w m O O O O 40. 6 V1 y a - o f N N a - au 2'2'22'22'2'2'2'.0000 � u n a ra r r r a a a Z Z W W W J T L L L J J R W ~ tf aI aI m~ Z Z Z � m� ommmo`amon m N [h Irtl til a'' Vf [n � 1p O .ti N N is ei a` c n 0 ry n a m ry ry m n o m m o ommmorvmory '� >.F mmtn y vi vi vi �cd�ti �ti o', o age p m o o m m� mmdvi vi �i to como,Ni `�`Ni Q o uoi g n m o 0 o m N om E r$ ao 0 �-� 6 criMC ui tri vi �.Nr O t s w m � � � v 0 v > � c v `v a w a to a o m a m m m c � o_ m a N n v u N m N 0 m N CQ E�..dO._�o60 a�a 40 o z o ` vg 0 0 n C m N m q o 0 N m o m 3 w a .cw w is � d a r a a m c .? IQ m m u E v o 3 3 c 3o m 3 44000 0 m w w v ¢ v hH� m« v k µ m c a o 2 29w c w v 14 Q ¢ z u �.-irvm viri � IR .55 vw'.b s sma and HCR �,N, S YaruWas Hilcorp 14laska — Cook Inlet State 176881A WILD Wei. End of Dive Survey Report REVISION 1 Dal% 081911014 Figure 6.3 Wellhead Schematic with Measurements Wild Well • A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center • 2202011 Center Court • Houston, Taxes USA77073 Phone: 281.784.4700 • Fax 281.784.4750 E -mall: wlldwell@WIdwell.com • www.WIdwell.com Page 13 of 20 HIICOrp Alaska — Cook Inlet State 176691A Wr.D Weu End of Dive Survey Report REVISION 1 oennor Date: 0e1181204 Item Summary of Description • Measurements Measurement Note Len hts 1 Top of TIW to TIW ball sub seam 15-3/8" 2 TIW ball sub seam to gussets 7-1/4" 3 TIW ball sub seam to top flange 11-5/8" 4 Top Flange Thickness 6-1/8" 5 Top flange gap 1" 6 2nd wellheadspool 78-3/4" 7 R-1720 auto connect barrel 41-7/8" 8 Gap between auto connection 3/4" !� 9 R-1720 auto connect mandrel to 6-3/8" 10 Top of bottom gussets to baseplat(61-7/8" 197-1/2" Total Wellhead Length We and OD s 11 ID of TIW ball throat 1-11/16" 12 ID of TIW threaded box 5-1/4" 13 OD of TIW below the ball sub seam 6-1/8" 14 OD of top flange 29-1/8" 15 OD of top flange nut 3-5/16" 16 OD of top flange bolt 2-1/8" 17 OD of 2nd spool 18-1/2" 18 OD of 1720 auto connect barrel 16-1/2" 19 OD of bottom auto connect mandrel 23-1/8" Count 20 Number of top flange bolts 16 Inclinatlon 21 East side of 2nd spool 1/4 bubble to the east 9-3/4" leveler 22 South side of 2nd spool bubble on edge to the north 9-314" leveler Figure 6.2 Wellhead Measurements Wlld Well • A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center • 2202011 Center Court • Houston, Texas USA 77073 Phone: 281.784.4700 • Fax 281.784.4750 E•mall: wlldwell@wlldwell.com • www.wildwell.com Page 12 of 20 `� _[��Uta fIfN12 3-111V 1A ]4011^ a�n 1fl KB to MUM =20'/ KB to Mudline=146' 5' TD 12,676' MD A( - SCHEMATIC Well: Cook Inlet State SA (17589) PTD: 262-028 API: 50-833-10013-00 Last Completed: 7/8/64 Revision By: CID 1/8/2020 PERFORATION CASING DETAIL Number Depth MD Size Wt Cmt Top Btm 30" 68 Jetted Surface 151' 24" 94 300 sx Surface 225' 20" 78 1600 sx Surface 655' 13-3/8" 54.5 1510 sx Surface 1,579' 9-5/8" 36/40 600 sx Surface 5,489' 7" 23/26 300 sx Surface 10,325' 5" Tieback 18 540 sx Surface 10,086' 5"1 18 1 180 sx 10,101' 12,404' Revision By: CID 1/8/2020 PERFORATION JEWELRY DETAIL Number Depth MD Item 1 133' 1 2-3/8" Tubing Hanger 2 164' 1 J 2-3/8" tubing 3 165' 2-3/8" Otis Nipple W/Plug 4 196' 1A2-3/8"tubing 5 283' 9-5/8" Stage Tool 6 314' 7"Stage Tool 6108' 3,045' Cmt Retainer 5 sx cmt on top 8 3,833' Cmt Retainer 10 sx cmt on to 9 5,025' Cmt Retainer 15 sx cmt on top 10 5,320' 1 Model "N" Packer 15 sx cmt on top 11 10,883' Model 'N" Packer 12 12,284 Model "N" Packer 13 12,387' Cmt Retainer Revision By: CID 1/8/2020 PERFORATION /Squeeze DATA To (MD) Btm(MD) CementSqueeze 3105' 3155' 245 sx 3500' 3505' 250 sx 4075' 4105' 150sx 5065' 5085' 200 sx 5153' 5163' 200 sx 5350' 5355' 200sx 6108' 6112' 50sx 6206' 6226' 50sx 6328' 6332' som 10927' 10947' 40 sx 12300' 12303' sosx 12315' 12348' S05x 12364' 12378' 50 sx 54 sx pumped below curt retainer at 12,387' Revision By: CID 1/8/2020 KB to MLLW=20'/ KB to Mudline=146' 30' 2 S. TD 12,676' MD S Proposed Schematic 300 s Well: Cook Inlet State 1A (17589) PTD: 262-028 API: 50-833-10013-00 Last Completed: 7/8/64 PERFORATION /Squeeze DATA/ Cement Data Top (MD) CASING DETAIL Number Size Wt Cmt Top Stint 30" 68 Jetted Surface 151' 24" 94 300 sx Surface 225' 20" 78 1600 sx Surface 655' 13-3/8" 54.5 1510 sx Surface 1,579' 9-5/8" 36/40 600 sx ±325' Cut 5,489' 7" 23/26 300 sx ±645' Cut 10,325' 5" Tleback 18 540sx ±675' Cut 10,086' 5" 18 180 sx 10,101' 12,404' PERFORATION /Squeeze DATA/ Cement Data Top (MD) JEWELRY DETAIL Number Depth MD Item 1 - Wellhead Spool 4' above Mudline 2 325' 13-3/8" Cement Retainer 3 3,045' Cmt Retainer 5 sx cmt on to 4 3,833' Cmt Retainer 30 sx cmt on top 5 5,025' Cmt Retainer 15 sx cmt on top 6 5,320' Model "N" Packer 15 sx cmt on top 7 10,883' Model "N" Packer 8 12,280' Model "N" Packer 9 12,387' 1 Cmt Retainer PERFORATION /Squeeze DATA/ Cement Data Top (MD) Btm MD) Cement Squeeze 1105x. pumped above 13.3/8 Cmt Retainer to P&A 3105' 3155' 245 sx 3500' 3505' 250 sx 4075' 4105' ISOsx 5065' 5085' 200 sx 5153' 5163' 200 sx 5350' 5355' 200 sx 6108' 6112' 50 sx 6206' 6226' 50 Sx 6328' 6332' 50 sx 10927' 10947' 40 sx 12Z 12303' 50 sx 12315' 12348' SOsx 12364' 12378' 1 50 sx 54 sx pumped below cmt retainer at 12,387' ReV151on By: CID 1/8/2020 Cook Inlet #11A Current Condition )01'Huck 12/17Y2014 AJI depths in RKB -Zero Tide" ConocoPhillips Water Depth -126"'Zero Tide" Top Base Plate at 126' "Zero Tide" Jetted Into Place@ 151' 2 -- -01 Jt. 2-3 8" tubing with Otis BPV in nipple 25 Sx on top of HOWCO MOD D.C. Retainer - _ _ 9-5/8" Stage Collar @ -283' No cement behind ------ - W" Stage Collar @-314', -700' cement pumped 8-27-63 Mi htbeal-180' wn6iclin re orfs 15 Sx on top of Model N 20" 75 oof @ 655', TOC estimated near surface 30" hole (undemeamed 12-YV), 1600 Sx Class A 133/8" 54.5 aof @ 1,579', TOC estimated near surface 9-5/e" 3640 oof @ 5,489' 17.5" hole (undemeamed 12-^/."), 1510 Sx Class A / N 5 Sx on top of D.C. Retainer 3,150'-3,155' Peds, SQZ 245 Sx- through retainer @ 3,045' Stray - 3,570' 3,500'-3,505' Parts, SOZ 250 Sx- tested for circulation with 5,300' perts No circulation established, May go through 95/8" given Injection rates 10 Sx on top of D.C. Retainer Dry Gas, tight. 2�,J7,36 psi, 8.5 ppg suspect (MDT m�eeasured -110 ppg) 4,075'-4,105' Paris, SQZ 150 Sx- through retainer If 3,883' Dry Gas. 1,899 psi, -9.0 ppg (`t ppg curteM) 25 Sx on top of HOWCO MOD D.C. Retainer 2 sx sand, 10 sx cement on top of Model N to -10,761' 7" casing damage from kill operations (Burst, Compression?) @ -8,800-9,000' MD. 5" 18 no/ Inner string @ 10,086', TOC +1-3,340' from CBL 540 in: Class D, 113% Halad-9, some could have exited at damage. 5" J&L Extreme NS 18# ID = 4.276", Drift = 4.151", Joint OD = 5.360", Collapse = 8550 psi Buret = 8550 psi, TY = 422 kips, JY = 432 kips 0.0177 bbl/ft 7" 23"29# BTC @ 10,325', TOC -9,700' from Temp log 8-2353 300 sx Class D 844' 29# S-95, 3,212' 26# S-95, 5,338' 23# S-95, 801' 26# N-80 10,927'-10,947' Perfs, SQZ 40 sx through Model N @10,883' 12,300'-12,305' Perfs, SQZ 50 sx through Model K @12,250', milled to 12,378' 12,315'-12,348' Perfs, Tested SQZ 50 -through h Model N 12,300'-12,305' Perts, Tested 9 @ 12.280' Retainer at 12,387'12,404', TOC could be near liner to14p 180 sx Class D, 1 % Halad 9 4-118" hole @ 12,676, Cemented through retainer @ 12,387' 54 sx Class A. Cement probably didn't exit DP. 5,065'-5,085' Paris, SQZ 200 Sx - Before 5,153' set of parts 5,153-5,163' Perfs, Tested, SQZ 175 Sx through retainer @ 5,025' Dry Gas. 2,463 psi, -92 ppg (1.3 ppg current) 15 Sx on top of Model N 5,350'-5,355' Paris, SQZ 100 Sx, 100 Sx- through Model N @5,320' Tested for circulation with 3,500' perfs, No simulation established, don't know if these go through 9-5/8", but probably do given injection rates. 9-5/e" 3640 oof @ 5,489' TOC below 5,000'? 12.25" hole, 600 Sx Class A 6,108'5,112' Perfs, SQZ 50 Sx- Squeeze parts to test 6,206-6,226 Interval -"-" - 6,206'5,226' Perfs. Tested SQZ 50 Sx, TOC in casing (a; 6,050' 6,328'-6,332' Parts, SQZ 56 Sx - Squeeze parts to test 66 206-6,226 Interval Ann. TOC 6,220' from Temp log, Interior TOC tagged (a) 6,302' 7/20/64 Dry Gas, tight. 2�,J7,36 psi, 8.5 ppg suspect (MDT m�eeasured -110 ppg) 2 sx sand, 10 sx cement on top of Model N to -10,761' 7" casing damage from kill operations (Burst, Compression?) @ -8,800-9,000' MD. 5" 18 no/ Inner string @ 10,086', TOC +1-3,340' from CBL 540 in: Class D, 113% Halad-9, some could have exited at damage. 5" J&L Extreme NS 18# ID = 4.276", Drift = 4.151", Joint OD = 5.360", Collapse = 8550 psi Buret = 8550 psi, TY = 422 kips, JY = 432 kips 0.0177 bbl/ft 7" 23"29# BTC @ 10,325', TOC -9,700' from Temp log 8-2353 300 sx Class D 844' 29# S-95, 3,212' 26# S-95, 5,338' 23# S-95, 801' 26# N-80 10,927'-10,947' Perfs, SQZ 40 sx through Model N @10,883' 12,300'-12,305' Perfs, SQZ 50 sx through Model K @12,250', milled to 12,378' 12,315'-12,348' Perfs, Tested SQZ 50 -through h Model N 12,300'-12,305' Perts, Tested 9 @ 12.280' Retainer at 12,387'12,404', TOC could be near liner to14p 180 sx Class D, 1 % Halad 9 4-118" hole @ 12,676, Cemented through retainer @ 12,387' 54 sx Class A. Cement probably didn't exit DP. COOK 6NLET STATE 17589 01A trra 10 .I-scelel"�// r� Bnmte•nP:+irn q.e.rani�W V —I 1S 1/f M' Sencc SSUO Plnnye a YDP M _ I.IM 5'Go.inq e.nywr ----------- la -5"", 8Caa1 - - i 1 -114. c.sMu wanes 141/Y 1� a,.ran N 1r.D AaPo (:aanp[I FY[agNcel - - --- S1aRfrzar •rnp __ 1 a.. M.1w 9C z". 20. 13-3,8- •1 f' S - T -1;w 5n:8' p.w PL1. Two lWnlp tuLrrrp Inptpltpp Y -,La' i r.M'vj I BPV .1%0 .1 FaOruur W 9It lu.nl of ww v. Schwartz, Guy L (CED) From: Paul Mazzolini <pmazzolini@hilcorp.com> Sent: Tuesday, January 14, 2020 2:33 PM To: Schwartz, Guy L (CED) Subject: Removal of Wellhead Spool Guy, Below are the steps written to explain the removal of the 78" subsea wellhead spool and NU of the riser on the 2nd flange connection on the subsea wellhead. I put these steps in after Step #20, as gauge ring is run before RIH and set of 9 5/8" packer. I. RIH with 9 5/8" retrievable packer on DP and set at +/- 500' RKB and test to 1000 psi 2. Divers ND riser from top flange and ND / remove top 78" subsea wellhead spool 3. Divers NU riser to second flange connection. Test riser connection to subsea wellhead and 9 5/8" casing to 1000 psi 4. RIH and pull retrievable packer Let me know if this works. I am still looking for verification on height above mudline and will let you know what I find. Let's consider this height 7' until I am able to verify. Thanks Mazz The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Schwartz, Guy L (CED) I�- From: Paul Mazzolini <pmazzolini@hilcorp.com> Sent: Tuesday, January 14, 2020 1:55 PM To: Schwartz, Guy L (CED) Subject: RE: [EXTERNAL] Cl 17589 #1A (PTD 162-028) Guy, There will be no modifications to Rig 151 so BOPE and choke manifold will not change. My apologies as the top flanged section of the subsea wellhead will be removed by divers after the 7" casing and casing hanger are removed. The riser back to the BOPS on Rig 151 will be made up to that flanged connection for work in the 9 5/8" and 13 3/8" casings. I will add those steps to the procedure and get you a revised copy if that works. Mazz From: Schwartz, Guy L (CED) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, January 14, 20201:37 PM To: Paul Mazzolini <pmazzolini@hilcorp.com> Subject: [EXTERNAL] Cl 17589 #1A (PTD 162-028) Paul, Are there rig mods ongoing on the Spartan 151? If so, are the BOPE and choke diagrams going to change? Also, I am confused where there wellhead will be capped after the casings are pulled. There is a flange near the 9 5/8" hanger but not sure if that is what you were referring to in the procedure and there is no mention of taking the upper 78" spacer spool off. As I mentioned the CBUs for the well can be digitized here if you track any paper copies down. 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@claslko.gov), The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. oF 1,4 THE STATE Alaska Oil and Gas ��.,-s�a•��, o /` SKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 * Main: 907.279.1433 ALAS'� Fax: 907.276.7542 March 6, 2018 www.aogcc.alaska.gov Certified Return Receipt 7015 0640 0003 5185 5857 Mr. David Wilkins Senior Vice President Alaska Hilcorp Alaska, LLC 18 3800 Centerpoint Drive, Ste 1400 Anchorage, LtJ Anchorage, AK 99503 Re: Docket No: OTH-18-014 Plugging and Abandonment of Cook Inlet State 17589-1A(PTD No. 162-028) Plugging and Abandonment of Swanson River Unit 23-22 (PTD No. 160-017) Dear Mr. Wilkins: By letter dated January 22, 2018,Hilcorp Alaska,LLC(Hilcorp)requested that the Alaska Oil and Gas Conservation Commission(AOGCC) allow the plugging and abandonment operations of the Cook Inlet State 17589-1A (PTD No. 162-028) to be included with the OCS exploration drilling program planned in 2020 utilizing a jackup rig. As proposed, abandonment would be completed by December 31, 2020. Sundry application(Sundry No. 315-165) granted March 23,2015 approved continued suspension status of Cook Inlet State 17589-1A until December 31, 2018. The well is located on State of Alaska oil and gas lease ADL 17589 which Hilcorp, as current owner and operator, acquired on November 1, 2016. Hilcorp proposes to substitute the Swanson River Unit (SRU) 23-22 well (PTD No. 160-017) for plugging and abandonment in lieu of Cook Inlet State 17589-1A. Operations for the plugging and abandonment of SRU 23-22 would be completed by December 31, 2018. AOGCC approves Hilcorp's request to delay plugging and abandonment of Cook Inlet State 17589-1A, with plugging and abandonment to be completed by November 1, 2020. An Application for Sundry Approvals for the procedure shall be submitted to the AOGCC no later than January 10, 2020. U.S. Postal Service' CERTIFIED MAIL° RECEIPT N Domestic Mail Only `a For delivery information,visit our website at www.usps.com`a. t.r7 co Certified Mail Fee ------- ra $ Ui Extra Services&Fees(check box,add lee as appropriate) ❑Return Receipt(hardcopy) $ ftil 0 Return Receipt(electronic) $ - Postmark O 0 Certified Mail Restricted Delivery $ Here 0 Adult Signature Required $ 0 Adult Signature Restricted Delivery$ Q Postage Mr. David Wilkins Senior Vice President Alaska 141 Hilcorp Alaska, LLC r- 3800 Centerpoint Drive,Ste. 1400 Anchorage, AK 99503 P orm 3800,April 2015 PSN 753o-02-000-9047 See Reverse for Instructions • Docket No: OTH-18-014 • • March 6,2018 Page 2 of 2 An Application for Sundry Approvals for the plugging and abandonment of SRU 23-22 shall be submitted to the AOGCC by July 1, 2018. Abandonment of SRU 23-22 shall be completed by December 31, 2018. Sincerely, l Hollis S. French Chair, Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. . • • Post Office Box 244027 Anchorage,AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Phone: 907/777-8300 Hilcorp Alaska, LLC Fax:907/777-8301 January 22, 2018 RECEIVED Hollis French, Chair iAN 3 0 2018 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue AOGCC Anchorage,Alaska 99501 Re: Substitute P&A Well for Cook Inlet State 17589 lA Dear Chair French: Pursuant to a Purchase and Sale Agreement between ConocoPhillips Company, ConocoPhillips Alaska, Inc. ("CPAI"), and Phillips Gas Supply Corporation, as Sellers, and Hilcorp Alaska, LLC, and Harvest Alaska, LLC, as Buyers, Hilcorp Alaska, LLC ("Hilcorp Alaska") became the operator of the North Cook Inlet Unit ("NCIU") and associated leases, including DNR Lease ADL 17589 on November 1, 2016. Part of the acquisition included the suspended subsea well Cook Inlet State 17589 1A,API 50883100130000 (the "Well"). The AOGCC had previously established a deadline of December 31,2018,for CPAI to plug and abandon the Well as communicated by AOGCC to CPAI in AOGCC Sundry 315-165 dated March 25,2015 and signed by Commissioner and then-Chair Foerster. Hilcorp Alaska has been developing a plan to complete the P&A in the allotted time using a Jackup mobile offshore drilling unit ("Jackup MODU"). While we have not yet identified and procured the Jackup MODU, we have prepared an initial cost estimate and base procedure for the P&A of the Well. On October 1, 2017, the Bureau of Ocean Energy Management ("BOEM") awarded Hilcorp Alaska 14 leases("OCS Leases")located in the Outer Continental Shelf("OCS") in Lower Cook Inlet, as the result of OCS Sale 244-Lower Cook Inlet on June 21,2017. Following the award of the OCS Leases, Hilcorp Alaska began developing a full season program to more effectively utilize a Jackup MODU. The program will include drilling one or more wells in prospects identified on the OCS Leases. The identification of well bottom hole locations will follow gradiometry and seismic surveys. Long lead permits are a key component to determining the timing to begin the execution of this program. The gradiometry survey will be flown this spring. However, the permitting for the seismic survey will require much more additional time. For instance, it will take approximately nine months to obtain the Incidental Harassment Authorization (IHA)which protects endangered marine mammals such as the Cook Inlet Beluga whales. This is insufficient time to allow our planned seismic program to be performed in 2018 and thus it will be delayed until 2019. The data from the seismic program will be utilized r • • Chair Hollis French January 22,2018 Page 2 of 2 to generate the drilling location(s) for the Jackup MODU during the drilling program which is now projected to be undertaken in 2020. Accordingly,Hilcorp Alaska requests approval from the AOGCC to allow the P&A of the Well to be included with the OCS exploration drilling program in 2020,with the deadline for P&A of the Well set at December 31,2020. Hilcorp Alaska understands the importance of AOGCC's focus on plugging and abandoning idle wells. With this understanding,Hilcorp Alaska proposes to substitute an idle well for plugging and abandonment in 2018. The proposed well is SRU 23-22, API 501331015001 /PTD 1600170 in the Swanson River Field("SRF"). This well is not on a list of wells that has been discussed with the AOGCC for P&A. We propose to develop a P&A procedure for SRU 23-22 and submit a sundry for that project to the AOGCC. Hilcorp Alaska is preparing a plan to P&A onshore Kenai Peninsula wells in 2018. We propose to add SRU 23-22 to this list with the P&A of the well to be completed by December 31, 2018. project or Paul Mazzolini, at 777-8369 to discuss the p } contact the Project Lead, Please answer questions the AOGCC may have. Sincerely, HILCORP ALASKA, LLC David ilkins Senior Vice President Alaska tiOF THS �,w\71 y/,�'7 THE STATE Alaska Oil and Gas � �.—z��, of Conservation Commission ____ ALASI�:A ._ f tt-:_-_--,-;,,-*-=_ - 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF Main: 907.279.1433 ALASYj Fax: 907.276.7542 www aogcc.alaska.gov Drew Huck scow l(pat)D� Sr. Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Wildcat Field, Wildcat Pool, CI 17589 lA Sundry Number: 315-165 Dear Mr. Huck: 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, / / . 11,e___,,..04.___ ____ Cathy P. Foerster Chair DATED this day of March, 2015 Encl. RECEIVED STATE OF ALASKA MAR 2 4 201 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A"'S 3f 25 ✓� 20 AAG 25.280 x'10 GCC 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension 0, Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ConocoPhillips Alaska,Inc. _ Exploratory Q , Development ❑ 162-028 • 3.Address: Stratigraphic ❑ Service CI6.API Number P.O.Box 100360,Anchorage,Alaska 99510 50-883-10013-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No LI CI 17589 1A 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL 17589 . Wildcat . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12,676'- 12,422' " 3045' - 3045' - Top plug @ 3045' 3045' Casing Length Size MD TVD Burst Collapse Structural 28' 30" 151' 151' Conductor 99'x 529' 24"x 20" 225'x 655' 225'x 655' Surface 1453' 13.375" 1579' 1579' Intermediate 5363' 9.625" 5489' 5489' Production 10,199' 7" 10,325' 10,139' Tie back/Liner 9960'/2200' 5" 10086'/12,404' 9909'/12,162' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): all perfs cemented all perfs cemented 2.375" na 37' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): BPV 126'MD/TVD+/- • 12.Attachments: Description Summary of Proposal ❑✓ • 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 111 ' Stratigraphic❑ Development❑ Service ❑ 14. Estimated Date for 12/31/2015 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended Q- 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Drew Huck @ 265-6828 Email Andrew.Huck@cop.com Printed Name Drew Huck Title SR. Drilling Engineer SignaturePhone 265-6828 Date r C.Ya------ ''--.)Z.77 /2.3/I S— COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `c ^\(42c Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: S4 s ;rel._i SV- -G._s CI ro4,e._.J C-4-11..-E..( OA_c_. 3/ � z-c 12 Spacing Exception Required? Yes ❑ No 21 Subsequent Form Required: N %E-- ' BY Approved by: , f �(4v� COMMISSIONER THE COMMISSION Date:3, ,/,5 3--Pi 15 I ?/Q ' lb- Submit Form and Form 10-403(Rev.-ed 10/2012) Aggro() •�aG l AI onths from the date of approval. Attachments in Duplicate RBDMS °Q - 3 2015 m-91 �- /W6 .3-As 41 RECEIVED MAR 2 4 2015 Chip Alvord Drilling Manager ConocoPhillipsDrilling &Wells AOGCC 700 G Street,99501 P.O. Box 100360—Suite ATO 1570 Anchorage,Alaska 99510-0360 Phone(907)265-6120 March 23rd, 2015 chip.alvord@conocophillips.com Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Request for Renewal of Suspension Status Cook Inlet State 17589-1A (PTD 162-028) Cook Inlet, Alaska Dear Commissioners: Pursuant to 20 AAC 25.110(n) and our discussion with Commission staff on 12/18/2014, ConocoPhillips Company (COP) requests a renewal of the suspension status of Cook Inlet State 17589-1A (PTD 162-028), the discovery well for the North Cook Inlet field reservoir. Attached please find the following; Attachment 1 - Sundry Number 312-384 Approval (suspended status approved until December 31, 2015) and Attachment 2 - 10-403 Application for Sundry Approvals. Due to the location of the subsea wellhead, it is COP's opinion that permanent abandonment will require the use of a jack-up rig. When COP submitted our 2012 request for renewal of suspension status two jack-up units had recently arrived in Cook Inlet (Spartan 151 and Endeavour- Spirit of Independence). COP made significant efforts to determine rig suitability, availability and whether either unit would meet COP's safety requirements. In November 2014, the Spirit of Endeavor left the Cook Inlet. Furie Operating Alaska, LLC, which has the Spartan 151 under contract, recently notified COP that it will keep the Spartan 151 through the 2015 season. In the absence of a suitable, available rig, COP will not be able to meet the December 31, 2015 deadline. COP has begun preparing the Cook Inlet State 17589-1A P&A procedure, which will allow us to promptly initiate P&A activities when a suitable jack up unit is available. Accordingly, we request that the Commission grant, under authority of 20 AAC 25.110 (n), a renewal of the suspension status until December 31, 2018 per 20 AAC 25.110 (g). Please refer questions to Drew Huck at 907-265-6828 orAndrew.Huck@cop.com. Sincerely, k Chip Alvord Drilling Manager Drilling and Wells Cc: Attachment 1 Sundry Number 312-384 Approval Attachment 2 10-403 Application for Sundry Approvals Huck 12/17/2014 Cook Inle, MA Current Condition '✓ All depths in ftKB"Zero Tide" ConocoPhil lips ,„ ,.,,:,•:,,..„.,„, „....,1„,„ _. ,,l �'` Water Depth 126'"Zero Tide" Top Base Plate at 126'"Zero Tide". ow 30"Structural Casing Jetted Into Place@ 151' _._ ♦1 Jt.2-3/8"tubing with Otis BPV in nipple II 11111 24"94 ppf @ 225',TOC estimated near surface Mill 30"hole,300 Sx Class A,5%CaCI .8-5/8"Stage Collar @-283'No cement behind "Stage Collar @-314',-700'cement pumped 8-27-63 Might be at-180',conflicting reports 20"75 ppf @ 655',TOC estimated near surface 30"hole(underreamed 12-W),1600 Sx Class A 13-3/8"54.5 ppf @ 1,579',TOC estimated near surface 17.5"hole(underreamed 12-''%"),1510 Sx Class A 5 Sx on top of D.C.Retainer 3,150'-3,155'Perfs,SQZ 245 Sx-through retainer @ 3,045' ® 3,500'-3,505'Perfs,SQZ 250 Sx-tested for circulation with 5,300'perfs Stray-3,570' No circulation established,May go through 9-5/8"given injection rates 10 Sx on top of D.C.Retainer 4,075'-4,105'Perfs,SQZ 150 Sx-through retainer @ 3,883' Dry Gas.1,899 psi,-9.0 ppg(-1 ppg current) {Top Beluga-4,400' 25 Sx on top of HOWCO MOD D.C.Retainer _ 5,065'-5,085'Perfs,SQZ 200 Sx-Before 5,153'set of perfs 5,153'-5,163'Perfs,Tested,SQZ 175 Sx through retainer @ 5,025' Dry Gas.2,463 psi,-9.2 ppg(1-3 ppg current) 15 Sx on top of Model N 5,350'-5,355'Perfs,SQZ 100 Sx,100 Sx-through Model N @5,320' Tested for circulation with 3,500'perfs,No circulation established,don't know if these go through 9-5/8",but probably do given injection rates. 9-5/8"36-40 ppf @ 5,489' TOC below 5,000'? 12.25"hole,600 Sx Class A 6,108'-6,112'Perfs,SQZ 50 Sx-Squeeze perfs to test 6,206-6,226 Interval III 6,206'-6,226Perfs,Tested SQZ 50 Sx,TOC in casing a 6,050' 6,328'-6,332'Perfs,SQZ 50 Sx-Squeeze perfs to test 6,206-6,226 Interval Ann.TOC 6,220'from Temp log,Interior TOC tagged to 6,302'7/20/64 Dry Gas,tight.2,736 psi,8.5 ppg suspect(MDT measured-10 ppg) 1 7"casing damage from kill operations(Burst,Compression?)@-8,800-9,000'MD. 5"18 ppf inner string @ 10,086',TOC+/-3,340'from CBL 540 sx Class D,1/3%Halad-9,some could have exited at damage. 5"J&L Extreme NS 18# ID=4.276",Drift=4.151",Joint OD=5.360",Collapse=8550 psi Burst=8550 psi,TY=422 kips,JY=432 kips 0.0177 bbl/ft j ip.. 7"23-29#BTC @ 10,325',TOC-9,700'from Temp log 8-23-63 :2 300 sx Class D 844'29#S-95,3,212'26#S-95,5,338'23#S-95,801'26#N-80 2 sx sand,10 sx cement on top of Model N to-10,761' B 10,927'-10,947'Perfs,SQZ 40 ax through Model N @10,883' 12,300'-12,305'Perfs,SQZ 50 sx through Model K @12,250',milled to 12,378' 12,315'-12,348'Perfs,Tested @ 12,280'N Model g th sx through 12,300'-12,305'Perfs,Tested SQZ 50 Retainer at 12,387' 5"18 ppf @ 12,404',TOC could be near liner top @ 10,101' 180 sx Class D,1%Halad 9 - 4-1/8"hole @ 12,676',Cemented through retainer @ 12,387' 54 sx Class A. Cement probably didn't exit DP. , w,P 71%%/�s9 THE STATE Alaska Oil and Gas 1 �'"` of LA Conservation Commission , , GOVERNOR SEAN PARNELL 333 West Seventh Avenue ta.., �p Anchorage,Alaska 99501-3572 Main:907.279.1433 Fax: 907.276.7542 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Wildcat Field, Wildcat Pool, CI 17589 1A Sundry Number: 312-384 Dear Mr. Alvord: 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. Please note that the conditions of approval set out in the enclosed form grant a three year time extension of the "Suspended" status of the well, not the requested ten year extension. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission 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, 4/6% k9 J Cathy V. Foerster Chair DATED this ' .--14--, /day of October, 2012. Encl. Tom Brassfield Staff Drilling Engineer RECEIVED Drilling&Wells P.0.Box 100360 OCT 0 9 201Z Anchorage,AK 99510-0360 ConocoPhillips Phone: 907-265-6377 AOGCC October 3, 2012 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Request for Renewal of Suspension Status Cook Inlet State 17589-1A(PTD 162-028) Cook Inlet, Alaska Dear Commissioners: Pursuant to 20 AAC25.110(n), ConocoPhillips Company (COP) requests a renewal of the suspension status of Cook Inlet State 17589-1A(PTD 162-028), the discovery well for the North Cook Inlet field reservoir. The well head was inspected by divers on August 3-�, 2010, and the inspection report required by 20 AAC 25.110(f) (Form 10-404) was filed on September 28, 2010. As noted in the Form 10-404 report, all perforations are already squeezed. The top cement retainer is set at 3045' KB and has five (5) sacks of cement on top. For over forty years, the wellbore has been isolated from the surrounding formations without loss of integrity and has not allowed migration of fluid that could threaten public health or impair the recovery of oil or gas. The current suspension status was requested in December 2010 and expires December 31, 2012. Because of the location of this subsea wellhead, permanent abandonment will probably require the use of a jack-up rig. With the recent arrival of two jack-up units in the Cook Inlet, COP is in the process of determining rig suitability and availability over the next several years and assessing the necessary site clearances that would be required to set down over the Cook Inlet State#1A wellbore. If a rig appears both suitable and available, there will also be an extensive rig vetting process to determine if either unit meets COP's safety requirements. In addition, we are considering whether alternative options for performing abandonment operations might be feasible. Accordingly, we request that the Commission grant, under authority of 20 AAC 25.110(n), a renewal of the suspension status until December 31, 2022 per 20 AAC 25.110(g). cyfraaa 1 Sincerely, 1>z, 3/ &o'S _ •1/�fj� -. / 1, /0.4.I2i T. J. Brassfield Staff Drilling Engine-r Drilling and Wells TJB/skad STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r� Perforate New Pool r Repair well r Change Approved Program r Suspend r Plug Perforations r Perforate r Pull Tubing T Tima Extension r Operational Shutdown r Re-enter Susp.Well r Stinvlate 1-- Alter casing- T OtttesTlme extension for renewal of suspenfb 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory F, 162-028 3.Address: Stratigraphic r Service j 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-883-10013-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No F..7 17589 1A 9.Property Designation(Lease Number): 10.Field/Poof(s): ADL 17589 Wildcat 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured) 12676 12422 3045' 3045' 3045,3883,5025,5320,10883,12280,12837 3045' Casing Length Size MD TVD Burst Collapse STRUCTURAL 25 30" 151' 151' CONDUCTOR 99,529 24"x20" 225'x 655' 225'x 655' RECEIVED SURFACE 1453 13.375" 1579' 1579' INTERMEDIATE 5363 9.625" 5489' 5489' OCT 0 9 201Z PRODUCTION 10199 7" 10325' 10139' AOGCC TIE BACK LINER 9960 5" 10086' 9909' PRODUCTION LINER 2200 5" 12404' 12162' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): all perfs cemented all perfs cemented 2.375 na 37 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) BPV 126'MD and 126'ND 12.Attachrrenls: Description Summery of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch J'"" Exploratory r+ Development r Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/31/2012 Oil r Gas r WDSPL r Suspended (W 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tom Brassfield @ 265-6377 Email: Tom,J.Brassfleldleconocoohillios.com Printed Nye t Alvord .6 Title:Alaska Drilling Manager 1 Sfgnaturk �• � -p 4 11,011d Phone:265-6120 Date id4/0,,i 4 ll! ✓✓✓ Commission Use Only Sundry Number:3 I 2;53 1 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r MechanicalalIntegrity Test r LocationioClearance/F Other: e S& p� S71., l J 1,1p AOt/[�/ 4.e_ i[ DaG.. 3i, Zo 45 Spacing Exception Required? Yes No❑ Subsequent Form Required: ,V D I JE 7': j r ,f APPROVED BY t Approved by: (i .'',7ijy� ✓ COMMISSIONER THE COMMISSION Date: /') / 2- — `? Approved application is valid for 12 onthsfrrom th d e o royal. Form 10-403(Revised 10/ 012) up( `�` Submit Form and Attachments in Duplicate V or rift THE STATE Department of Natural Resources o Division of Oil and Gas 4 = - • fALAS� 550\\est 7 'Avenue,Suite 1 100 Otc' e Anchorage.Alaska 99501-3650 t " - Main 907 269-S800 GOVERNOR BILL WALKER F'ax 907269-8939 January 30, 2015 ConocoPhillips Alaska, Inc. SEJ+P i\: 0 Sam Widmer, Environmental Coordinator P. O. Box 100360 Anchorage, Alaska 99510-0360 RE: Plugging and Abandoning Cook Inlet Well 17589#lA (CI#1A) on Oil and Gas Lease ADL 17589. Dear Mr. Widmer: On December 5, 2014, the Division of Oil and Gas (Division)received a Unit Plan of Operations (Plan) application requesting approval for plugging and abandoning(P&A) ConocoPhillips Alaska, Inc. (ConocoPhillips) Cook Inlet 17589#1A(CI#1A)well. The Division reviewed the request with the appropriate statutes,regulations and lease terms in accordance with Alaska Statute 38.05 and Alaska Oil and Gas Leasing Regulations(11 AAC 83). A Plan approval is not required from the Division of Oil and Gas for the proposed activity. The Division recognizes that additional authorizations may be required by other agencies prior to plugging and abandoning the identified well. A summary of the Division's administrative record for the CI#1A well is noted below for informational purposes. History and Overview: The CI#1A well was first drilled and tested from 1962 to 1964 and suspended at the close of the 1964 season. Current Alaska Oil and Gas Conservation Commission(AOGCC)regulations require if the current owner no longer has plans for future development, the well must be permanently P&A. ConocoPhillips objective is to bring the well into compliance with AOGCC's regulations and to utilize the Spartan 151 or the Endeavour—Spirit of independence offshore drill rig for abandonment operations. Location of well site: The well is located 6.5 miles due east of the village of Tyonek in the North Cook Inlet Unit in Southcentral Alaska and about 31 miles northeast of Nikiski (Figure 1). The water depth is approximately 107 feet deep. The well is located within Seward Meridian,T 11N,R 9 W Section 6 with GPS coordinates 61°4 '6. 95"N 150°56'42. 46" W. Land Status: The State received title to the project area under the Tide and Submerged Lands Act of 1953 (P.L. 31, 83rd Congress,First Session; 67 Stat. 29). Administrative Record: The Cook Inlet 17589#IA well is part of the LAS 18180 case file. The lease file associated to this well is ADL 17589. If you have any questions,please contact me by email john.easton@,alaska.gov or by phone at (907)269-8815. Sincerely NQS John Easton Natural Resource Specialist Attachments: Figure(s) 1-2: Figure of Cook Inlet Well 17589#IA ecc: Jim Regg,Guy Swarts; AOGCC Cilff Larson: ADNR DMLW Laurie Silfven,Tim Law;ADEC Virgnia Litchfield; ADF&G Administrative Record: The Cook Inlet 17589#1A well is part of the LAS 18180 case file. The lease file associated to this well is ADL 17589. If you have any questions,please contact me by email john.easton(a;alaska.gov or by phone at (907) 269-8815. Sincerely, John Easton Natural Resource Specialist Attachments: Figure(s) 1-2: Figure of Cook Inlet Well 17589#lA ecc: Jim Regg, Guy Swarts; AOGCC Cilff Larson: ADNR DMLW Laurie Silfven, Tim Law; ADEC Virgnia Litchfield; ADF&G Attachments: Figure(s) Well 17589 STA Lorogiuide.-150.950693 Latitude-61.076206 1 1114. • • a Well 17589-#1AT Legend Plug and + Wet 17589 fi1A Abandonment F figure 1 t? 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WA 41;f ,. 4;t•-• ,-,;, A4':•`Z-,'.1...4.:.••.. .. f.7,'•::ei,'--,--- ...I ,.,,,_..,_._, ;.7:;.',,::.":":.;:iit,' fr,,,,,,..„,_ ,,„., ,...,.. ,-.._..-- ..,- - - .- -• . - ,,A,,:,,,:;,-,-1-,,,,,::-' ,„.,,:r1,4t.-i, „,,i,';',„,,,,'... --;'-;-?6-'-iiqf ......?1,...,„,i'.; ,,e4'''.•,E-:!,,:-"',.,-;:.°;.,'-,''.':,- A "4,„-.KL., A.."1!..,-- . 5• ,',7;,,,ey..4 •-F.*7,1i.,:..''':.,.-.,'; a;„.,4,..,„, ..,..•,",-- .- r ' '' '.. '...'r*. 4,....,:e::::71:....7.,.l'.'t',';'7,r.r.""*.V.fr,., *It-W f,',W;=1,11,A,. 0 '";;;44`, 1.• ,fl''..,,,,LX4,4 ;,;'16i;,,:i: COOK INLET ST 17589 1-A 1:•?....li:) -. , ,i.a.;..;,..!,-,...)w ,Tyonek „.....22,.....4,..::.,...„4..i,,i _,,, 7•IrriN,4., -,-..7' --'. 4 1111 , . .. .... ,. . :i'• . . . S...,',Z,...r VV4!',,,,,';,,,`.p,id,1,,',1\04a, :;•4';',11,,$:,'F,A:`,-"- -,,...4.-I ... ' ... . *.-. ..:..-...!.-kcitti 1North • Well 17589 1-A — Unit Boundary STATE OF ALASKA ALA, A OIL AND GAS CONSERVATION COMI_ 310N REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Repair Well LJ Plug Perforations 0 Perforate ❑ Other D Well Inspection Performed: Alter Casing El Pull Tubing El Stimulate-Frac 0 Waiver I=1 Time Extension El Change Approved Program ED Operat.Shutdown El Stimulate-Other ❑ Re-enter Suspended Well El 2.Operator ConocoPhillips Alaska,Inc. 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development ❑ Exploratory Q✓ 162-028 3.Address: P.O.Box 100360,Anchorage,AK 99510 Stratigraphic 0 Service 0 6.API Number: 50-883-10013-00 7.Property Designation(Lease Number): 8.Well Name and Number: RECEIVED ADL 17589 CI 17589 1A M 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): JAN 2 1 2015 NA Wildcat 11.Present Well Condition Summary: A )GCC Total Depth measured 12,676' feet Plugs measured Top @ 3045' feet v true vertical 12,422' feet Junk measured feet Effective Depth measured 3,045' feet Packer measured na feet true vertical 3,045' feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural 25' 30" 151' 151' Conductor 99',529' 24"x20" 225'x 655' 25'x 655' Surface 1453' 13-3/8" 1579' 1579' Intermediate 5363' 9-5/8" 5489' 5489' Production 10199' 7" 10325' 10139' Tie Back Liner 9960' 5" 10086' 9909' Prod Liner 2200' 5" 12404' 12162' Perforation depth Measured depth See schematic feet True Vertical depth feet Tubing(size,grade,measured and true vertical depth) 2..375"@ 37'MD/37'TVD Packers and SSSV(type,measured and true vertical depth) Top cement retainer @ 3045'MD/3045"TVD+6 others BPV @126'MD/126'ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): See schematic Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory El Development Service ❑ Stratigraphic 0 Daily Report of Well Operations 16.Well Status after work: Oil ❑ Gas LI WDSPL L GSTOR 0 WINJ LI WAG LI GINJ LI SUSP Q SPLUG L 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: Contact Tom Brassfield @ 265-1463 Email Andrew.Hucktc7i conocophillii s.com Printed Name Drew Huck Title Sr. Drilling Engr Signature 0,ff—.v 2t/1 Phone 265-6828 Date i` 2 i �` IJ Form 10-404 Revised 10/2012 �. RBDM�� Submit Original Only JAN 2 1 2015 Tom Brassfield Consultant Drilling Engineer Drilling&Wells RECEIVED P.O. Box 100360 Anchorage,AK 99510-0360 ConocoPhillips JAN 21 2015 Phone: 907-265-6377 AOGCC January 20, 2015 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Suspended Well Inspection Cook Inlet State 17589-1A (PTD 162-028) Cook Inlet, Alaska Dear Commissioners: As follow up to our discussion with Guy Schwartz on 12/18/2014, ConocoPhillips Company, hereby submits Form 10-404 Report of Sundry Well Operations and well inspection information for the Cook Inlet State 17589- 1A (PTD 162-028) from the inspection performed at the location from 7/19/2014 thru 7/28/2014. The following is a summary of the well inspection information; • The "End of Well Dive Survey Report 2014" including photographs of the wellhead. Please note that no anomalies were identified by the visual inspection, but no pressure readings/indications could be taken due to existing wellhead cap and the closed FOSV. • Miscellaneous Dive photos with references to the wellhead • A wellbore schematic • As-built survey and surrounding reference points As discussed with Mr. Schwartz, due to uncertainty regarding rig availability and suitability, ConocoPhillips Company intends to submit a 10-403 Application for Sundry Approval request for an extension of suspended status this spring. ConocoPhillips would like to request that the above information be kept confidential at this time. Sincerely, NJA4-- T. J. Brassfield Consultant Drilling ' ngineer Drilling and Wells Enclosure ConocoPhillips Alaska-Cook Inlet State 17589 1A WILD WELL End of Dive Survey Report REVISION 1 Date: 08/18/2014 ConocoPhillips ConocoPhillips Alaska Cook Inlet, AK State 17589 #1A End of Well Dive Survey Report 2014 Operator: ConocoPhillips Alaska Operations: American Marine Services &Wild Well Control Inc. (Wild Well) Project: 2014 Summer Dive Survey 2014-229 Cook Inlet#1A Wild Well•A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center • 2202 Oil Center Court • Houston,Texas USA 77073 Phone:281.784.4700• Fax:281.784.4750 E-mail:wildwell@wildwell.com• www.wildwell.com Page 1 of 20 ConocoPhillips Alaska—Cook Inlet State 17589 1A WILD WELL End of Dive Survey Report REVISION 1 Date: 08/18/2014 Table of Revisions Rev Description of Reviewed/ No. Date Change Prepared By Position Approved Position by 0 8/18/2014 W.Boone Sr Well Engineer Word Edits 1 8/18/2014 W. Boone Sr Well Engineer Table of Contents Well Operations 1 8/21/2014 Stephen Breaux Manager—Marine Well Services Wild Well•A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center • 2202 Oil Center Court • Houston,Texas USA 77073 Phone:281.784.4700• Fax:281.784.4750 E-mail:wildwell@wildwell.com• www.wildwell.com Page 2 of 20 ConocoPhillips Alaska—Cook Inlet State 17589 1A WILD WELL End of Dive Survey Report REVISION 1 Date: 08/18/2014 Table of Contents 1. Acronyms 3 2. Executive Summary 5 3. Background Overview 6 4. Mobilization 7 5. Diving Operations 9 6. Dive Survey Conclusion 14 7. Images 15 Wild Well•A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center • 2202 Oil Center Court • Houston,Texas USA 77073 Phone:281.784.4700• Fax:281.784.4750 E-mail:wildwell@wildwell.com• www.wildwell.com Page 3 of 20 ConocoPhillips Alaska—Cook Inlet State 17589 1A WILD WELL End of Dive Survey Report REVISION 1 CONTROL Date: 08/18/2014 1. Acronyms T&A Temporary Abandonment P&A Plug and Abandonment PBTD Plug Back Total Depth FOSV Full Opening Safety Valve TIW Texas Iron Works Lbs. Pounds OD Outside Diameter ID Inside Diameter DN Dive Vessel WH Wellhead OPs Operations Wild Well•A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center • 2202 Oil Center Court • Houston,Texas USA 77073 Phone:281.784.4700• Fax:281.784.4750 E-mail:wildwell@wildwell.corn• www.wildwell.com Page 4 of 20 ConocoPhillips Alaska—Cook Inlet State 17589 1A WILD WELL End of Dive Survey Report REVISION 1 Date: 08/18/2014 2. Executive Summary ConocoPhillips Alaska contracted American Marine Services to conduct a summer 2014 dive survey on the Cook Inlet#1A subsea well as part of the Phase II portion of the plug and abandonment planning for the well. Planned operational steps were: Diver Inspection/Cleaning and video survey of all wellhead areas to determine anomalies and obtaining measurements of the wellhead components / Determine if the top wellhead section was open to the sea and recover the top flange for future reconnection and P&A plans / Gather data for Current and Tide profiling/Identify guideline connection points of base plate. ConocoPhillips Alaska contracted Wild Well Control, Inc. for onsite project management and certain specialty tools to accomplish the survey of the well in preparations of future P&A operations. These services included tools to measure wellhead components and recover the top wellhead cap for flange connection verification. Mobilization of the dive vessel and work barge began on July 7, 2014 in the Port of Anchorage. Vessels were on site with anchors set on July 19, 2014 and so began dive operations. Dives were conducted during periods of slack tide and daylight in zero visibility conditions at the wellhead depth. Accumulatively, 24 dives were made in 10 days. One planned dive was suspended due to weather conditions. Dive operations included: • Verifying subsea wellhead location. • Installing Current Profile Recorder on seafloor. • Surveying the wellhead base plate and cleaned the bottom portion of wellhead. • Installing Subsea Diver Scaffold over the wellhead. • Cleaned marine growth from all exterior wellhead components. • Probed top wellhead valve and videoed wellhead components for anomalies. o Valve was found to be closed. o No wellhead anomalies were detected. • Obtained measurements of exterior wellhead components (see attachment). • Surveyed the seafloor near the wellhead. • Recovered Current Profile Recorder and Subsea Diver Scaffold to surface. Dive operations ended on July 28, 2014 and all vessels returned to the Port of Anchorage. De-mobilization of all vessels began on July 29, 2014. There were no reportable incidents or accidents with one first aid issue (hypoglycemia) involving a Tug boat personnel. Wild Well•A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center • 2202 Oil Center Court • Houston,Texas USA 77073 Phone:281.784.4700• Fax:281.784.4750 E-mail:wildwell@wildwell.com• www.wildwell.com Page 5 of 20 ConocoPhillips Alaska—Cook Inlet State 17589 1A WILD WELL End of Dive Survey Report REVISION 1 CC NT", Date: 08/18/2014 3. Background Overview Pan American completed drilling the subsea Cook Inlet 1A Well in 1963 as a relief well to the subsea blowout Cook Inlet 1 Well. The well was T&A'd in August, 1964 with a 3000' PBTD. One joint of 2-3/8" tubing with an installed Otis bridge plug valve was set on a hanger in the 5"casing. r Figure 3.1 Wodeco II Drilling Barge As per Alaska State regulations, the well must be properly abandoned at the top of the wellbore. The last dive survey video conducted on the well on August 8, 2010 showed large deposits of marine growth or metal deterioration on the wellhead. There appeared to be an abnormality above the top wellhead flange that indicated the 'fully open safety valve' (FOSV or TIW) was breached. No measurements of the wellhead were gathered. The age and make of Shaffer style wellhead makes it uncertain as to how to reconnect to it for P&A operations. Wild Well'A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center 2202 Oil Center Court Houston,Texas USA 77073 Phone.281.784 4700 Fax.281.784.4750 E-mail:wildwell©wildwell.com www.wildwell.com Page 6 of 20 ConocoPhillips Alaska—Cook Inlet State 17589 1A WILD WELL End of Dive Survey Report REVISION 1 C C n i R l i Date: 08/18/2014 4. Mobilization American Marine Dive began mobilization of the Dive vessel "Shamrock" and the Foss Barge 379 at the NorthStar dock in the Port of Anchorage,AK beginning on July 7,2014. The barge was outfitted with a four point anchor system (15000 lbs each on the bow and 12000 lbs each on the stern) and a Tool Handling Cantilever. Equipment mobilization was completed on July 17, 2014 but vessel departure was delayed until July 19,2014 due to unfavorable forecasted weather conditions at the well site. The vessels (Dive vessel, barge and two Tugs)and crews departed the Anchorage Port at 00:30 hours on July 19, 2014 and arrived on site at 06:00 hours. All anchors were set west of the ConocoPhillips pipeline utilizing both tug boats. The initial anchor spread was adjusted by repositioning the#2(northwest)and the #4 (southeast) anchors to allow the barge better heading flexibility. The Tug Stellar Winds was released and diving operations began that same day. EQUIPMENT MOBILIZED: Equipment Vendor Barge, 4-Point Anchor System (Winches, anchors Foss and swivel fairleads), 55 ton Crane, work station cantilever Dive Spread, Subsea Cleaning Tools(water blaster, American Marine Dive hyd brushes, chippers), Subsea Camera, High Pressure/Low volume HPU, Subsea Diver Scaffold 500 barrel Frac Tank Atigun Current Profile Recorders, Survey (Hipat & Etrac beacons, Monitors, Mapping) Flange Removal Tools (Nut splitter, flange Wild Well Control spreader), OD&ID calipers VESSELS: Vessel Vendor Purpose Tug Boat Emmett Foss Foss Barge Transport&Support Tug Boat Stellar Winds Cook Inlet Tug&Barge An anchor tractor. Assisted with anchor setting and recovery (released when not in use) Dive Vessel"Shamrock" American Marine Dive Dive Operations Foss Barge 379 Foss Equipment storage, Mooring and Work Station support for Dive Operations Wild Well•A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center • 2202 Oil Center Court • Houston,Texas USA 77073 Phone:281.784.4700• Fax:281.784.4750 E-mail:wildwell@wildwell.com• www.wildwell.com Page 7 of 20 ConocoPhillips Alaska—Cook Inlet State 17589 1A WILD WELL End of Dive Survey Report REVISION 1 Date: 08/18/2014 ANCHOR SPREAD: Wild Well•A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center • 2202 Oil Center Court • Houston,Texas USA 77073 Phone:281.784.4700• Fax:281.784.4750 E-mail:wildwell@wildwell.com• www.wildwell.com Page 8 of 20 ConocoPhillips Alaska—Cook Inlet State 17589 1A WILD WELL End of Dive Survey Report REVISION 1 Date: 08/18/2014 5. Diving Operations American Marine Diving operations were conducted off of their DN Shamrock during periods of slack tide and in daylight in zero visibility conditions at the wellhead depth. The Foss Barge 379 assisted diving operations with onboard storage of hydraulic tools, hydraulic power units, power washer, hoses, 55 ton crane, fresh & potable water storage, portable light stations and a Survey Station. A cantilever was installed on the Foss Barge 379 as a work station with power sheives to assist in the recovery of hoses. Communications between vessel personnel were by handheld radios and line of sight, when possible. Survey beacons were installed on the Subsea Current Profiler, Subsea Dive Scaffold and the Diver. Prior to starting all dive operations the Foss Barge 379 crew positioned the barge work cantilever over the wellhead. As the tide current was decreasing, the DN Shamrock would moor to the Foss Barge 379 with it's bow located at the barge's work cantilever. The down-line to the wellhead was transferred from the barge and secured to the dive vessel's bow tugger. Job Safety Analysis were held with the dive and barge crews and final dive preparations were completed while waiting on the beginning of the slack period of tide current as the tide shifted from High or Low stages. Realtime tide current was gathered from Etrac's Current Profiler installed on the Foss Barge 379 and monitored on screens located at the Shamrock's Dive Control Station. Tide current was also continuiously recorded on Etrac's Current Profiler positioned 25' south of the wellhead on the seafloor. Divers entered the water when the decreasing tide current reached 0.75 knots and worked on bottom until either the maximum depth excustion time was reached or the tide current shifted and began increasing. The High tide slack times were longer in duration than the Low tide slack times. Dive duration times averaged 38 minutes. Water depths to the top of the wellhead were 92 feet during Low tide and 112 feet during High tide, measured by diver pnuemo. There were a total of 24 dives completed at an average of 2.4 dives/day. The fabricated Subsea Diver Scaffold was placed over the wellhead to a stable platform for the diver to work at all locations of the wellhead. It also served as direction orinitation to the diver in the no visibility conditions. It had four levels and measured 8'4"x 8'4"x 20'. The base plate of the wellhead was found to be covered with 18" to 24" of silt, gravel, large rocks and a layer of cement. Some broken cables were embeded in the cement. After consulting with ConocoPhillips Representative, it was decided not to clean the debri from the base plate during this dive campain. The seafloor depth 25 feet around the wellhead ranged from 106 feet to 109 feet during Low tide. Debris found was a horizontal tree trunk to the south, a large bolder to the northwest and pieces of pipe to the north of the wellhead. The 1" to 2" marine growth on the wellhead was cleaned by use of a handheld pressure washer and a hydraulic wire brush. The pressure washer was the most effiecent. The wellhead components were cleaned allowing measurements to be documented, visual inspections conducted and video recorded. After discussion with ConocoPhillips Representatives, other methods of detail cleaning (needle gun, small wire drill)were not necessary for meeting the dive survey objectives. Five video surveys were taken of the wellhead using a 3.5 to 1 high definition camera with a fresh water flow to flush away the silty sea water between the camera lens and the wellhead. Three of the videos were for the purpose of surveying the cleaned wellhead for anomalies and for indentification of wellhead components. The definition and sound of these videos were of better quality than the video surveys taken In 2010. The anormalies and the possible valve handle detected on the top wellhead valve in the 2010 dive survey were not present on the videos taken of the cleaned wellhead. Veiwing into the threaded pin box of the top wellhead valve,the valve was found to be in the closed position and the threads appeared to be right handed. The side accuator of the valve was in the closed position and no excrusion of inner seals were visible. The seams of the valve's various sub components were visible. Welded verical flat bar keepers were found on the these seams. Gussets were found in two locations on the wellhead: 1)from the bottom of the top wellhead valve to the top flange and 2)on the bottom of the wellhead to the base plate. Two video surveys were conducted for gathering and recording vetical wellhead component lengths utilizing a measurement tape. The inside and outside diameter measurements of the wellhead components Wild Well•A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center • 2202 Oil Center Court • Houston,Texas USA 77073 Phone:281.784.4700• Fax:281.784 4750 E-mail:wildwell@wildwell.com• www.wildwell.com Page 9 of 20 ConocoPhillips Alaska—Cook Inlet State 17589 1A WELD WELL End of Dive Survey Report REVISION 1 Date: 08/18/2014 were taken with calipers that were adjusted and locked in place by the diver on bottom and sent to the surface for measuring. The measurements are found in Figures 5.1 and 5.2. Once each dive was completed and the diver was safely in decompression, the down-line was transferred back to the Foss Barge 379 and the DN Shamrock moved away from the barge to await the next slack tide current. Wild Well•A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center • 2202 Oil Center Court • Houston,Texas USA 77073 Phone:281.784.4700• Fax:281.784.4750 E-mail:wildwell@wildwell.com• www.wildwell.com Page 10 of 20 ConocoPhillips Alaska—Cook Inlet State 17589 1A WILD WELL End of Dive Survey Report REVISION 1 s., N.G, Date: 08/18/2014 Dive Dive# Date Tde Pneumo Top Duration Dive Ops H/L of WH (minutes) 1 19-Jul L 92 30 Located wellhead and established down line 2 20-Jul L 37 Installed Current Profileronseafloor 3 20-Jul H 112 40 Survey and parial cleaning of base plate 4 20-Jul L 39 Clean portion of wellhead bottom with pressure washer Probed inside of top of FOSV w/1"probe,hit 5 21-Jul L 43 hard 6"to 8"down. Cleaning bottom of wel l hea d w/hyd brush. 6 21-Jul H 44 Landed Diver Scaffold over wellhead 7 21-Jul L 46 Adjust scaffold and began securing same. 8 22-Jul L 89'top of 46 Secure scaffold,pressure wash inside& scaffold outside of FOSV,notice valve accuator Video FOSV,visual on closed ball and 9 22-Jul H 109 48 accuator,no outside cracks,visual on sub seams 10 23-Jul H 38 Pressure wash FOSV and top flange 11 23-Jul L 91 35 Clean FOSV,flange nuts&bolts and 2nd level of scaffold w/hyd brush Video#2,complete FOSV,visual on rt hand 12 23-Jul H 114 44 threads,top flange&gap,2nd level of scaffold.No cracks detected. Tested Blue Veiw Sonar on Dive Helment 13 24-Jul H 37 Cleaned 2nd scaffold level w/pressure washer,began pressure washer on 3rd level 14 24-Jul L 36 Swapped out down line,tested BlueVeiw sonar 15 25-Jul H 36 Finished pressure washing wellhead Video#3,from top flange to bottom of auto 16 25-Jul L 36 connect barrel,took level measurements- wellhead leaning to the SW. 17 25-Jul H 38 Video#4,measured lenghts of FOSA components. Changed out down line. 18 26-Jul H 34 Video#5,Took vertical measurements of wellhead. Recovered tools from bottom. Set OD and ID 19 26-Jul L 35 calipers on FOSV and sent to surface for measurements Set OD calipers on flange and spools and sent 20 26-Jul H 40 to surface of measurement.Coated inside threads of FOSV w/protectant. Counted 16 bolts in top flange. 21 27-Jul H 43 Attached lift rigging to scaffold. Began backing out scaffold centralizing bolts 22 27-Jul L 33 Recovered bottom Current Proflier to surface, Surveyed 25'radius around wellhead. 23 27-Jul H 36 Recovered dive scaffold to surface. 24 28-Jul L 25 Attempted to install cover cap on FOSV. Did not fit. Recovered down I i ne from wellhead. Figure 5.1 Dive Summary Wild Well•A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center • 2202 Oil Center Court • Houston,Texas USA 77073 Phone:281.784.4700• Fax:281.784.4750 E-mail:wildwell@wildwell.com• www.wildwell.com Page 11 of 20 V);4 ConocoPhillips Alaska—Cook Inlet State 17589 1A WILD ELL End of Dive Survey Report REVISION 1 CONTROL Date: 08/18/2014 Summary of Wellhead Measurements Item Description Measurement Note Lenghts 1 Top of TIW to TIW ball sub seam 15-3/8" 2 TIW ball sub seam to gussets 7-1/4" 3 TIW ball sub seam to top flange 11-5/8" 4 Top Flange Thickness 6-1/8" 5 Top flange gap 1" 6 2nd wellhead spool 78-3/4" 7 R-1720 auto connect barrel 41-7/8" 8 _ Gap between auto connection 3/4" 9 R-1720 auto connect mandrel to 6-3/8" 10 Top of bottom gussets to base plate 61-7/8" 197-1/2" Total Wellhead Length IDs and OD s 11 ID of TIW ball throat 1-11/16" 12 ID of TIW threaded box 5-1/4" 13 OD of TIW below the ball sub seam 6-1/8" 14 OD of top flange 29-1/8" 15 OD of top flange nut 3-5/16" 16 OD of top flange bolt 2-1/8" 17 OD of 2nd spool 18-1/2" 18 OD of 1720 auto connect barrel 18-1/2" 19 OD of bottom auto connect mandrel 23-1/8" Count 20 Number of top flange bolts 16 Inclination 1/4 bubble to the 21 East side of 2nd spool east 9-3/4" leveler bubble on edge to the north 9-3/4" leveler 22 South side of 2nd spool Figure 5.2 Wellhead Measurements Wild Well A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center 2202 Oil Center Court Houston,Texas USA 77073 Phone:281.784.4700• Fax:281.784.4750 E-mail:wildwell@wildwell.com www.wildwell.com Page 12 of 20 ConocoPhillips Alaska—Cook Inlet State 17589 1A WILD WELL End of Dive Survey Report REVISION 1 CONTRGL Date: 08/18/2014 COOK INLET STATE 17589 #1A Shaffer DPSV(in Closed pos:Gon) 15-3/B" 6-1/8" I I 7._1/4- 14"Series 1500 flange__ .. .. _ •5"ON DP Box Crossover 29-1/8" TubingHanger-- onger-- 18-1/2" 5"Casing Honger • 7"Caning Monger�-- ,`., t�;l 78'Spacer Spoo!-...,` ■�'Y{1 78-3/4" 9-5/8'Casing Hunger- FF O� 41 7/8" 18-1/2" R-1720 Auto Connect Borrel-- x, r3r4- 1t 1 R-1720 Auto Connect Mandrel-- { I .� • 23-1/8. 510851ter fine NIP I 1 1 2 \ 61-7/8" :n l Bose Plate II Base Plate � 1 [ 20' II 13-3/8' _ 9-5/8" 1131 7. 5" A 2-3/8"TubIng____._.........._.,..�. Too joints of tubing inctalkd BPV Installed al bottom of first joint of tubing t(i 11 Figure 5.3 Wellhead Schematic with Measurements Wild Well•A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center • 2202 Oil Center Court • Houston,Texas USA 77073 Phone:281.784.4700• Fax:281.784.4750 E-mail:wildwell@wildwell.com• www.wildwell.com Page 13 of 20 j ConocoPhillips Alaska—Cook Inlet State 17589 1A WILD WELL End of Dive Survey Report REVISION 1 Date: 08/18/2014 6. Dive Survey Conclusion American Marine Services mobilized the Foss Barge 379 and the SN Shamrock from July 7 to July 17, 2014. Due to a weather delay the vessels arrived on the well location on July 19, 2014 and began diving operations. Diving operations were concluded on July 28, 2014 and demobilization of the vessels began on July 29, 2014. OBJECTIVES MET: • Wellhead was cleaned of Marine growth • The well's FOSV was probed and found to be in the closed position. • The wellhead was inspected and a video record was taken of the cleaned wellhead. No anomalies were observed and the FOSV was visually confirmed to be close. There was no handle on the FOSV. • ID's and OD's of the wellhead components were taken and recorded. • The tide current was recorded during the entire dive survey campaign by Etrac. • The seafloor was surveyed in a 25' radius around the wellhead. Water depth ranged from 107'to 109'. Rock,tree and pipe debris was found by the survey. OBJECTIVES NOT MET: • Due to the FOSV being in the closed position and no anomalies detected. o The top wellhead flange was not removed and recovered. The top wellhead flange design can only be identified by the well records and the measurements taken. o No probe or camera could be ran inside the tubing string. o No Magnetic Particle Testing was warranted. • The base plate was not completely cleaned of debris and the guideposts were not inspected by direction of ConocoPhillips Alaska. The Alaska Oil and Gas Conservation Commission has indicated a variance can be obtained not to remove the wellhead and base plate below the seafloor. Cement was found on the top of the base plate. Wild Well•A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center • 2202 Oil Center Court • Houston,Texas USA 77073 Phone:281.784.4700• Fax:281.784.4750 E-mail:wildwell@wildwell.com• www.wildwell.com Page 14 of 20 AConocoPhillips Alaska—Cook Inlet State 17589 1A WILD WELL End of Dive Survey Report REVISION 1 Date: 08/18/2014 7. Images i Tti Il :':,:114,!:-„, ' !t f I •d 4 . : / s� DN Shamrock Foss Barge 379 and Tug Emmett Foss ' ---.r---,„.--:--+ om :' 1111110i—st4".Fit—-7 Iiir '• .. 4t tom+ .nom- -: -C . ' - -i- --.1,,,,- !Iliilif ....i. ` V ``"" .,,, '7 /'.— 4 r , 4 "a c 64 L' ah p ''''''.4 mow.-� 1 • ' F. l i I 1 'Ob. ,•'` ^ Barge Cantilever Work Station Subsea Current Profiler Recorder Wild Well•A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center • 2202 Oil Center Court • Houston,Texas USA 77073 Phone:281.784.4700• Fax:281.784.4750 E-mail:wildwell@wildwell.com• www.wildwell.com Page 15 of 20 ConocoPhillips Alaska-Cook Inlet State 17589 1A WILD WELL End of Dive Survey Report REVISION 1 CONTROL Date: 08/18/2014 t f ,-,.........._—••••man'_- e. J 4'i ' ' :�•-. lit \ ,i eao .14 - -'-- � t /' ....•- t } .. ,.; t ° '-. kap .._.__ ,'++..'..t Pressure Washer Nut Splitters and Flange Spreaders /04-i—M . 01, 4110-..- 11111116..' _-12_.._—__— 111: fIlf i L.- ." irl is Subsea Dive Scaffold Wild Well•A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center • 2202 Oil Center Court • Houston,Texas USA 77073 Phone:281.784.4700• Fax:281.784.4750 E-mail:wildwell@wildwell.com• www.wildwell.com Page 16 of 20 ConocoPhillips Alaska—Cook Inlet State 17589 1A WILD WELL End of Dive Survey Report REVISION 1 NFA G L Date: 08/18/2014 i .:.'1,4,,,,.:,,ra'F'.', - , i. ri, , / ,,, , '' f i:' ■■■jilt.....►. .�_ 1 +i erg91,,,,,,,', Vz # YeA y=.+?34.4- #$, 5« n a i Inside and Outside Calipers Diver , .,.;:f:::,....4-4N-,,,... 7% . a " • ,:::-.4077,' 7,3.'. * � ~, 4 ° Yt mom• 4. FOSV in Closed Position FOSV Threads(uncleansed) Wild Well•A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center 2202 Oil Center Court • Houston,Texas USA 77073 Phone:281.784.4700• Fax:281.784.4750 E-mail:wildwell@wildwell.com• www.wildwell.com Page 17 of 20 ConocoPhillips Alaska—Cook Inlet State 17589 1A V1NLD WELL End of Dive Survey Report REVISION 1 00 H T R O,, Date: 08/18/2014 y / , z ` a �, �, . 1 H1 4_ f , ` ' I H1 1 t 'r 3SS _ • -aM b� / , Ilk F1 , .I t Y l .`I k' ., _ FOSV Actuator Key Slot Top Flange Nut and Bolt Tr �" �'1 x7. t' '', `„4 '',::: s .!;,i,-(*,,,,,„-.1= Spool Condition South Level µ 1 H1 L.H1 1G' .P.,1 West Level Length from Top Flange to Base Plate Top Wild Well•A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center • 2202 Oil Center Court • Houston,Texas USA 77073 Phone:281.784.4700• Fax:281.784.4750 E-mail:wildwell@wildwell.Com• www.wildwell.com Page 18 of 20 ConocoPhillips Alaska—Cook Inlet State 17589 1A WILD WELL End of Dive Survey Report REVISION 1 CONTROL Date: 08/18/2014 a„ "I I, .:- — —_MC iun rm dot :. Yttit ra. ol ,„ Tq!name Wh; tMy DNet 1 Tpt Cea'Inp 1 Diver'1 Tot etd "rRr Drier 1 Tpt slt:d by ib ph Drve 2 4t d -.7 575 h; =.a 0E,'::: TF T t''-'q 65351 Q 757 ,.. 9 ,rxu. me.s,, -iv:.:, ,';',',tnn t7 on. �—a m � -.,... , w rm',w:aro am: ree an. ,:,. __—��___._._.._.�.�______ .__ w'a� r mocs aim �-- _.. -- r.f6�::7 : T.:1y rw a a ♦an w1 taoi asa �g�. x ed > u n. Caul wdn' �# ' k `�• sxl i rI w„ ++w aeez; s es ona se n ens wr .a :. zw ne ISO eau esd 'r w H x., vie..! k .,.,r,C, . a,n IC : x,.z..._:. ' v,�si , .x.TS'`?4.�e.4jr :k#St# ifk# cilli °r4 . '"w�1 is .: y n i .+,... z Figure 7.1 Screen shot of Dive Control's Monitoring Instrumentation North pieces of drill pipe 106'few 107' fs 107' fsw 107' fsw large rock 108' fsw Wellhead 107' fsw 107' fop mall rocks 25' \ 107' fsw 109' fsw yy 12" rock 108' fsw 108' fsw horizontal tree South Figure 7.2 Seafloor Survey Summary Wild Well•A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center • 2202 Oil Center Court • Houston,Texas USA 77073 Phone:281.784.4700• Fax:281.784.4750 E-mail:wildwell@wildwell.com• www.wildwell.com Page 19 of 20 ConocoPhillips Alaska-Cook Inlet State 17589 1A WILD WELL End of Dive Survey Report REVISION 1 CONTROL Date: 08/18/2014 Anchorage )iSlrICt H1(3 TI9ES LOW TII)ES '..'.... A1M 4'T 1"r.1 6"l' ANl F'T 1`r- Fl 1 T 41,10:12 27.8 10:58 28.9 4:46 3.9 5:09 0.1 2 W -0.10:49 26.9 11:35 28.5 5:24 3.6 5:42 0.9 3 T •.11:32 25.8 6:06 3.5 6:18 2.1 4 F . 0:14 27.8 12:22 24.6 6:50 3.5 6:58 3.8 5 S •-► 0:59 27.0 1:22 23.5 7:41 3.7 7:45 5.8 6 S ►480. 1:55 26.3 2:34 22.9 8:43 3.8 8:45 7.4 7 M 3:01 26.1 3:56 23.4 9:59 3.0 10:04 8.0 8 T 4:04 26.6 5:14 24.711:06 1.6 11:13 7.3 9 W ••► 5:01 27.8 6:13 26.4 12:07 0.0 10 T 5:54 29.3 7:03 28.0 0:11 6.3 1:05 -1.5 11 F + 6:43 30.7 7:48 29.2 1:10 5.1 1:59 -3.0 12 S - 7:31 31.8 8:31 30.2 2:07 3.7 2:48 -4.2 13 S __- 8:19 32.5 9:13 31.0 2:58 2.3 3:34 -5.0 14 M - 9:07 32.7 9:54 31.7 3:47 1.0 4:18 -5.1 15 T - 9:55 32.5 10:37 32.2 4:34 -0.1 5:01 -4.6 16 W -- 10:44 31.7 11:22 32.3 5:21 -0.7 5:43 -3.3 17 T 11:36 30.3 6:09 -0.8 6:27 -1.3 18 F -. 0:12 31.7 12:35 28.4 7:00 -0.3 7:14 1.3 19 S 1:08 30.5 1:47 26.5 7:57 0.6 8:10 4.1 20 S •- 2:12 29.0 3:10 25.3 9:04 1.4 9:20 6.4 21 M ►er. 3:20 27.7 4:38 25.310:24 1.5 10:43 7.4 22 T •4110 4:28 27.1 5:48 26.311:41 0.7 11:59 6.9 23 W•40 5:29 27.1 6:41 27.3 12:39 -0.4 24 T •-40 6:19 27.5 7:23 27.8 0:54 5.9 1:25 -1.1 25 F •40 7:00 28.1 7:57 28.2 1:38 5.1 2:05 -1.2 26 S •0 7:36 28.7 8:24 28.5 2:17 4.6 2:41 -1.1 27 S 8:11 29.3 8:51 29.0 2:51 4.2 3:13 -0.9 28 M •• 8:46 29.5 9:20 29.5 3:22 3.6 3:45 -0.7 29 T •4. 9:21 29.4 9:53 29.8 3:53 2.9 4:15 -0.4 30 W -0 9:56 28.9 10:25 29.6 4:27 2.3 4:46 0.2 31 T .4.10:31 28.1 10:57 29.2 5:04 1.9 5:16 1.1 12 $Anchorage.Knit Arm,Alaska 5y 12C: 18:x: 26 Figure 7.3 Anchorage Tide Table July 2014 Wild Well A SUPERIOR ENERGY SERVICES COMPANY Drilling Technology Center 2202 Oil Center Court Houston,Texas USA 77073 Phone:281.784.4700• Fax:281.784.4750 E-mail:wildwell@wildwell.corn• www.wildwell.com Page 20 of 20 CI CD ,5.€ , i $ $ < A . ii I • t . 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T .. ‘ k 1 , Huck 12/17/2014 Cook IniG.. #1A Current Condition IF- All depths in ftKB"Zero Tide" ConocoPhil l i ps „+ 1 iii i'l!i p33 d8' ldliiiil i I`l,{lllJ,iiii ii Water Depth-126'"Zero Tide" it i .....:: 3 i....of a.io 'l _ d Pill Mil Base Plate at 126'"Zero Tide" 30"Structural Casing Jetted Into Place@ 151' Elitin- 1 Jt.2-3/8"tubing with Otis BPV in nipple II 24"94 oof @ 225',TOC estimated near surface 30"hole,300 Sx Class A,5%CaCI �. :-5/8"Stage Collar @-283'No cement behind "Stage Collar @-314',-700'cement pumped 8-27-63 Might be at-180',conflicting reports IL 20"75 oof @ 655',TOC estimated near surface 30"hole(underreamed 12-%"),1600 Sx Class A 13-3/8"54.5 oof @ 1,579',TOC estimated near surface 17.5"hole(underreamed 12-%"),1510 Sx Class A 5 Sx on top of D.C.Retainer I I I 3,150'-3,155'Perfs,SQZ 245 Sx-through retainer @ 3,045' i III 3,500'-3,505'Perfs,SQZ 250 Sx-tested for circulation with 5,300'perfs I Stray-3,570' No circulation established,May go through 9-5/8"given injection rates 10 Sx on top of D.C.Retainer 4,075'-4,105'Perfs,SQZ 150 Sx-through retainer a 3,883' Dry Gas.1,899 psi,-9.0 ppg(-1 ppg current) {Top Beluga-4,400' 25 Sx on top of HOWCO MOD D.C.Retainer _ -. 5,065'-5,085'Perfs,SQZ 200 Sx-Before 5,153'set of perfs 5,153'-5,163'Perfs,Tested,SQZ 175 Sx through retainer @ 5,025' Dry Gas.2,463 psi,-9.2 ppg(1-3 ppg current) 15 Sx on top of Model N 5,350'-5,355'Perfs,SQZ 100 Sx,100 Sx-through Model N @5,320' Tested for circulation with 3,500'perfs,No circulation established,don't know if these go through 9-5/8",but probably do given injection rates. 9-5/8"36-40 oof @ 5,489' TOC below 5,000'? 12.25"hole,600 Sx Class A 6,108'-6,112'Perfs,SQZ 50 Sx-Squeeze perfs to test 6,206-6,226 Interval li: 6,206'-6,226Perfs,Tested SQZ 50 Sx,TOC in casing lad 6,050' NI 6,328'-6,332'Perfs,SQZ 5b Sx-Squeeze perfs to test 6,206-6,226 Interval Ann.TOC 6,220'from Temp log,Interior TOC tagged®6,302'7/20/64 Dry Gas,tight.2,736 psi,8.5 ppg suspect(MDT measured-10 ppg) 7"casing damage from kill operations(Burst,Compression?)@-8,800-9,000'MD. i. 5"18 oof inner string @ 10,086',TOC+/-3,340'from CBL 540 sx Class D,1/3%Halad-9,some could have exited at damage. 5"J&L Extreme NS 18# ID=4.276",Drift=4.151",Joint OD=5.360",Collapse=8550 psi Burst=8550 psi,TY=422 kips,JY=432 kips 0.0177 bbl/ft I 7"23-29#BTC @ 10,325',TOC-9,700'from Temp log 8-23-63 300 sx Class D 844'29#S-95,3,212'26#S-95,5,338'23#S-95,801'26#N-80 2 sx sand,10 sx cement on top of Model N to-10,761' 10,927-10,947'Perfs,SQZ 40 sx through Model N @10,883' 12,300-12,305'Perfs,SQZ 50 sx through Model K @12,250',milled to 12,378' 12,315-12,348'Perfs,TestedSQZ 50 sx throw h Model N 12,28012,300-12,305'Perfs,Tested g @Retainer at 12,387' 5"18 oaf @ 12,404',TOC could be near liner top @ 10,101' 180 sx Class D,1%Halad 9 4-1/8"hole @ 12,676',Cemented through retainer @ 12,387' 54 sx Class A. Cement probably didn't exit DP. Ai i r 11.x32 r Irl •• S1pS .11 ,14 CooK L,Ift 7p,'.„ v Li3T 1I I I I I i 27 i 26 25 30 Iiu77E 2.9 28 I I I f I I - --------I---------I ---- ----I --- Lb I 1 I � I u-i I I 34 35 36 0 31 32 33 ' o I I I In . I I - 61°04148.68( T. 1 2 N ----t----- - ------j--- -- ----- -- T. II N. • 6 5 I 4 2024.9 ,--1-0- C OK INLET STbTE No.IA I• 3 2 I 61°04=09,0001. I 1 I I 150°56-34.394i 0 COQK INLET STAT No,I 393.5 1- 61°04.-03.630::1/v/J��-1 ---- ----- -- --- -j--------- 150°57107.550� N I I 0 I o of I 10 II i 12 I '` 7 8 9 I - I N -�- I -- -I-------- I —1--- 1 --------- I I I I I I I i I I 15. i 14 I 13 I 18 i 17 16 I I I I i I 1 L --1---------1--- --I-------- ---I--------J Scale I = I Mile • Certificate of Surveyor '!,,F �°A - I hereby certify that I am properly registered and lic- V;,'• "�N.° 471. ensed to practice land surveying in the State of Alaska 4� ,� ;,. tP,� 0'4l 't and that this plat represents a location surveyed by me, f?e :I,: 3 area -=e.ait as of 5:00A.M., 28 May,1962 and that all dimensions a # � .A� other details are correct. ' ' Y"° DATE ,CERTIF1 D IA n Q IZft 'e�Q Avii,y')1 , 51 Date Surveyor NOTE: PLAT AMENDED TO SHOW THE LOCATION OF COOK INLET The Surveyed Location Of STATE No• IA AS OF 9 :00A.M., 5 SEPT. 19G2 COOK INLET STATE NO. 1 Surveyors Note (in S.W. 1/4 of Sec.6,T. 11 N.,R.9W.,S.M.) Surveyed For . The location of COOK INLET NO. I was surveyed by use PAN AMERICAN PETROLEUM of Tri-Station Monuments BELUGA and TERRACE estab- CORPORATION lished by the U. S. 29 th Engineers, 1944 a 1942 resp. P.O. BOX 712 ANCHORAGE, ALASKA SURVEYED BY F.- . M. Lindsey • REGISTERED LAND SURVEYOR 650-S ' 1405 NORTHERN LIGHTS BLVD. ANC HORAGE,ALASKA .— �< z o CDL o tI- el e1 so cg aOen 1 1o V 9 O fo A 0 no I 0 :, g 4 0 1� is 11 s° $ C N s n o H C w I l i rn I-- F 1. =7 2 n Ir. 4 '4'i . Pi" ,o$• 4°0 .;r - U '4 0 .t+r! v. •d� .......11, ! d! ..... ! C. L •e! 6 rr1.! 41. fte I�0 6 ari w w t, I.1) (7.5 N O O N 1-4 - .E •l z ,-1 en M n cn U J W - [T LL + l.] t I . . I . . I . . I . . . u�•.• • MANIX 1iit.i.ii 140.161/ Brassfield, Tom (Solsten XP) From: Huck, Drew Sent: Wednesday,January 07, 2015 10:48 AM To: Winfree Sr, Mike B (Fairweather); Brassfield, Tom (Solsten XP) Subject: FW:CI#1A Meeting Summary and Information Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. ATO 1566 907-265-6828 907-343-9790 (Cell) 303-328-5835 (Home) 918-662-1804 (Fax) From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, December 18, 2014 11:09 AM To: Huck, Drew Cc: Winfree Sr, Mike B(Fairweather); Alvord, Chip Subject: [EXTERNAL]RE: CI #1A Meeting Summary and Information Drew, I concur with your points below. Get us an inspection report(10-404) and follow up with a sundry request for extension of past Dec 31,2015. I will talk to Cathy and give her an update on your progress. I understand the rig issue... you will need the right window of opportunity in order to do the wellwork . Once you rig up and pull trash cap there is not a good "stopping point" option until you finish. Submitting an 10-403 this spring for P&A is also a good idea. It gives me ample time to review and you will be ready to go in case a rig opportunity opens up in summer 2015. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Huck, Drew [mailto:Andrew.Huck@conocophillips.com] Sent: Thursday, December 18, 2014 10:30 AM To: Schwartz, Guy L (DOA) Cc: Winfree Sr, Mike B (Fairweather); Alvord, Chip Subject: CI #1A Meeting Summary and Information 1 { • Guy, Please find attached a current and proposed schematic that are updated with the latest information we have, as well as a dimensioned picture of the wellhead (not to scale) recreated from the drawing we have and measurements taking during this summer's survey. I've also attached the slides from today's meeting for reference. To summarize topics discussed: 1. We discussed the background and general overview of how we would complete P&A of this well. 2. We discussed the inspection and preparatory work completed this year to get ready for P&A of this well. 3. We discussed rig availability, especially in light of Endeavour's recent departure. We highlighted the need for a sufficient window for the work as there are no clear breakpoints during operations until the surface plug is in place. 4. We discussed COP's intention to submit a 10-404 Suspended well inspection report as well as a 10-403 requesting an extension from the current December 315t,2015 deadline during or before the spring of 2015. We would likely try to submit this in the January to March window if that sounds reasonable. 5. We discussed COP's intentions of submitting a 10-403 in or around March 2015 to perform the actual wellwork in the hope that a slot would open up for us to use a jackup rig in the summer of 2015. Please let me know if I've missed anything and thanks for taking the time to meet with us. Regards, Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. ATO 1566 907-265-6828 907-343-9790 (Cell) 303-328-5835 (Home) 918-662-1804 (Fax) 2 5/14/2014 PT /6z -0Z8' r. 0. ConocoPhillips Fm"--- „„ ! Aar Cook Inlet State " .: •'� 17589 #1A • i - P&A Overview IfMay 14,2014 III Cook Inlet #1A Background Summary "Relief”well for Cook Inlet#1 Blowout in August 1962,both drilled by WODECO II(barge rig)for Pan Am. mo Drilling of 1A began in August 1962,just after blowout. After a break over the winter,drilling resumed in 1963,with TD reached in September 1963(Cook Inlet#1 blowing out the whole time). m Pumped kill fluid into formation,damaged ( casing. Several weeks later,while still working ;= ;„2 to fix casing,blowout died. Moved to blowout fl '' and"P&A'ed"as well as possible, pumping ` ,r cement around 200'(no pipe or wellhead located). ▪ Came back to lA in 1964 season to test well. Tested numerous zones, P&A'ed from the bottom up. ▪ Left top plug above highest known hydrocarbon zones(@-3,000'),left well suspended. • . Conoc41rolkps 1 V 5/14/2014 A LLL ix ' "" IflL.L.1�VIVA I rBNCI, I A-14 i I A-f1 ..,, NCl i. ( �� I. 34 A-}3 Nr r f 0. IIMMIMA- . JP' ';, , 10 / � i L,i�l1// r NClA�3 �,�1.4a! • 1=05 o �oj ADLO 7S_;• �� 1 ° f!� CPCO 931E ,��.w`.� s ADL01 17591 17591 NCI •' ti OP .• NCI' r•" CPC PC )C1 1 ST1 S�1} .� �.' Ai WeliiiiiiMVA +s 1=1111 � wasGIF. 93190 -12 12 1A.—A•DL01O 9 ` 93190 0 Cook Inlet#lA Surface NCI: r(I) 1711M•11 01 41 Cook Inlet#1 Surface O 41 CP O 9 and#1&#1A BHL NCI: a 9 .� ough pipelines Geotechnical Data O LocationsT �r _ ... - ` .c, ._ .10 /az .. LAND 1 _/ ---) Ili/ I maw 0 ''-----:"0.5 1 ....-k_-2 o0 1 Miles ''Current Well Schematic -- ::—.7.' _ — - a11a' --- mac 4 --________ ill w. ..r.-.___. Hai VIII_.. -1'I ;ii llII ■ A ; Ei , ...... = iiit '1'„. ilii cor,ocoanados 2 IF 5/14/2014 Phase 2: Wellhead Preparation—Summer 2014 ▪ Survey immediate area around well (2000' x 3000'). ▪ Tactical Dive inspection of wellhead. ▪ Inspect drill pipe safety valve. ■Threads ,�0 • Position of valve(open/closed) • Measurements --+_+_ --` - -7'w— ▪ Clean entire wellhead assembly(high :.�'".- 1 pressure water jet). -/ Ill Re inspect wellhead. Clean inside of tubing to plug depth. Inspect inside of tubing with camera (e- line). ▪ Remove any unnecessary equipment (depends on damaged equipment). ▪ Install corrosion cap. ▪ Move off location. Survey Area rSq-1S ,NCI-0- . ,4,1,,,NCI A.a CI# R '. CI#1 . k. . Feet 1820 Tyonek Pipeline Survey • P1e"°tm 8,10188 some of Alaska * Well Looaltons ly"tkk Matfett -'Non*Phibrm ♦ Cook Inle[ "/Tyorek Nadine Rc 1 PeKenZa {t om 1,comoers - fJ/f 'N.—.-102-Lowest 0 l o....w.m.tort 1.A6-IE9trest •�ti... o :::!•i�11'::I: ..... ..... CmcxoPtltlhps 3 5/14/2014 Phase 3: High Level P&A Methodology—Summer 2015 ▪ Gain access to the well. ill Check for pressure on 2-3/8"x 5" annulus. ▪ Flange up with riser to rig. le Pull tubing. w Run bond log in 5" casing. Check for pressure on 5"x 7" annulus(review CBL to determine depth). RIH and perforate the 5", 7" and 9-5/8"casing with deep A ` penetrating charges at the 13-3/8"casing shoe. ▪ Squeeze cement in 9-5/8"x 13-3/8"annulus, 100'above and 100' below shoe. Remove the 5",7" and 9-5/8'casings down to 316' (180' BML). Set a bridge plug in 13-3/8" casing at 306'and spot 150'of cement on top of plug (ETOC= 30' BML). WOC and test. 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AM WO , ;• 4111/1 C O •_ V 27-0 /(c,z _o?...ei) ConocoPhillips Alaska Original X WILD WELL Cook Inlet State 17589 #1A Proposed DIRECTIONAL DATA TUBULARS SIZE WT GRADE TOC DEPTH WELLHEAD DATA KOP 0 RKB DRIVE 30 151 TYPE MAX DEV 0.0 ° RKB CONDUCTOR 24 94 225 W P MAX DOGLEG ° RKB CONDUCTOR 20 75 655 DEV AT PERFS 0.0 ° RKB SURFACE 13-3/8 54.5 1,579 TREE CAP RETURN TO VERTICAL RKB 1ST INT. 9-5/8 36-40 5,489 FLANGE 2ND INT. 7 23-26 10325 THREAD ELEVATIONS PRODUCTION 5 18 12404 TH -ML FT TBG HANGER TH-MWL FT Tubing String 2-3/8 4.7 -60' BML BPV PROFILE WD 126 FT BTM FLANGE DEPTH(RKB) DESCRIPTION OF EQUIPMENT ID OD Mudline Base Plate * 't e ij ,'� .d, " 1 Joint of 2-318"Tubing with Otis BPV in nipple '�' s 151 30"Drive Pipe 30 225 24",94#Conductor 24 ,;1 283 9-5/8"Stage Collar-no cement behind F 314 7"Stage Collar-cement night be at-180';conflicting reports A' ' 655 20",75#Conductor 20 •4 . Ik': 1579 133/8",54.5#Surface Casing 13.375 3000' PBTD (Estimated) 3150`-3155'(Squeeze Perfs)5 Sx on top of D.C.Retainer .3 . I 3500'-3505'(Squeeze Perfs)10 Sx on top of D.C.Retainer ' 4075'-4105'(Squeeze Perfs) _ I5065'-5085',5153'-5163'(Squeeze Perts)25 Sx on top of D.C.Retainer _1 5350'-5355'(Squeezed Perfs) 15 Sx on top of Model N . I: 5489 9-518",36-40# 1st Intermediate Casing 9.625 (1225"hole,600Sx Class A) . 6108'-6112',6206'-6226',6328'-6332'(Sqeezed perfs) -8000-9000 7"Casing Damage From Kill Operations(Collapse?) 10086 5-1/2",18#Production Casing 5 11 H ' 10325 7",23-26#2nd Intermediate Casing 7 (300 Sx Class A,TOC-9700'from Temp log) 10927'-10947'(Squeezed Perfs) III12300'-12305',12315'-12348'(Squeezed Perfs) 0,....4 12404 5-112",18#Production Casing 5 Blowout Sands @-12400 MD/TVD 12676 4-118"hole Date: 4-Mar-14 Prepared By: J- David Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, May 22, 2014 2:44 PM To: 'Huck, Drew' Cc: Regalado,Todd A;Walter Boone (wboone@wildwell.com);deby@wildwell.com Subject: RE:Cook Inlet#1A Follow-up Drew, Correct .. no cement plug is necessary at the surface casing shoe per 20 AAC 25.112(C)(3) since there is no freshwater aquifers in area. Also, I discussed casing cut off with Commissioner Foerster and she agrees that cut-off at ML is acceptable but will require a variance request in the sundry application. No sundry is required to do the dive work and wellhead inspection we discussed last week. Guy Schwartz Senior Petroleum Engineer SCANNED AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at (907-793-1226) or(Guy.schwartz@alaska.gov). From: Huck, Drew [mailto:Andrew.Huck@conocophillips.com] Sent:Thursday, May 22, 2014 1:46 PM To: Schwartz, Guy L(DOA) Cc: Regalado,Todd A; Walter Boone (wboone@)wildwell.com); deby@wildwell.com Subject: Cook Inlet #1A Follow-up Guy, I wanted to follow up on our discussion of Cook Inlet 17589#1A to confirm what we had talked about. We discussed our plan of performing dive work this summer(July/August 2014)to clean and inspect the wellhead in preparation for permanent abandonment of this well, including possible removal of parts of the wellhead cap if appropriate. You indicated we should not need a sundry for this initial work. We also discussed that cement across the surface casing shoe at 1,579' MD was not needed as there are no shallow aquifers here and breaking down the shoe by squeezing cement may not be a desirable choice. Can you confirm that you agree here? Also,we were curious if cutting the wellhead off at mudline via an exterior diamond wire saw was an acceptable alternative to 5' below mudline via an interior cut. In this case,we would bring cement in the 13-3/8"all the way to mudline and leave the baseplate and below intact. Regards, Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. 1 w w \� 7 s 9 THE STATE Alaska Oil and Gas �� 4-,1 °fALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue 0- Q. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. b ( ia P.O. Box 100360 Anchorage, AK 99510 Re: Wildcat Field, Wildcat Pool, CI 17589 1A Sundry Number: 312 -384 SCANNED JAN 16 2013 Dear Mr. Alvord: 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. Please note that the conditions of approval set out in the enclosed form grant a three year time extension of the "Suspended" status of the well, not the requested ten year extension. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission 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, G• Cathy P. Foerster Chair DATED this it day of October, 2012. Encl. • • Tom Brassfield RECEIVED Staff Drilling Engineer RECE1 Drilling &Wells �•� OCT 0 9 2012 AncOhorage, AK 100360 ConocoPh AOGCC Phone: 907 - 265 -6377 October 3, 2012 Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Subject: Request for Renewal of Suspension Status Cook Inlet State 17589 -1A (PTD 162 -028) Cook Inlet, Alaska Dear Commissioners: Pursuant to 20 AAC25.110(n), ConocoPhillips Company (COP) requests a renewal of the suspension status of Cook Inlet State 17589 -1A (PTD 162 -028), the discovery well for the North Cook Inlet field reservoir. The well head was inspected by divers on August 3 -7, 2010, and the inspection report required by 20 AAC 25.110(f) (Form 10 -404) was filed on September 28, 2010. As noted in the Form 10 -404 report, all perforations are already squeezed. The top cement retainer is set at 3045' KB and has five (5) sacks of cement on top. For over forty years, the wellbore has been isolated from the surrounding formations without loss of integrity and has not allowed migration of fluid that could threaten public health or impair the recovery of oil or gas. The current suspension status was requested in December 2010 and expires December 31, 2012. Because of the location of this subsea wellhead, permanent abandonment will probably require the use of a jack -up rig. With the recent arrival of two jack -up units in the Cook Inlet, COP is in the process of determining rig suitability and availability over the next several years and assessing the necessary site clearances that would be required to set down over the Cook Inlet State #1A wellbore. If a rig appears both suitable and available, there will also be an extensive rig vetting process to determine if either unit meets COP's safety requirements. In addition, we are considering whether alternative options for performing abandonment operations might be feasible. Accordingly, we request that the Commission grant, under authority of 20 AAC 25.110(n), a renewal of the suspension status until December 3 , 2022 per 20 AAC 25.110(g). a „�.( f p� Sincerely, Dec, 3! Zo'S - jii&-jaA.A../j T. J. Brassfield Staff Drilling Engineer Drilling and Wells TJ B /skad • STATE OF ALASKA AV ALI4 OIL AND GAS CONSERVATION COMMI�N � , APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair well r Change Approved Rogram r Suspend r Rug Perforations r Perforate r Pull Tubing r Tirre Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing �°� 9 ! Other.Time extension for renewal of suspend 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory p+ 162 -028 • 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 883 - 10013 -00 • 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require spacing exception? Yes r No 17 CI 17589 1A • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 17589 . Wildcat • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured) 12676 • 12422 • 3045' 3045' 3045, 3883, 5025, 5320, 10883, 12280, 12837 3045' Casing Length Size MD TVD Burst Collapse STRUCTURAL 25 30" 151' 151' CONDUCTOR 99, 529 24 "x20" 225' x 655' 225' x 655' R C E i D SURFACE 1453 13.375" 1579' 1579' 0 1 0 � 1 " INTERMEDIATE 5363 9.625" 5489' 5489' OCT 0 9 2012 PRODUCTION 10199 7" 10325' 10139' TIE BACK LINER 9960 5" 10086' 9909' AOGCC PRODUCTION LINER 2200 5" 12404' 12162' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): all perfs cemented all perfs cemented 2.375 na 37 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) BPV 126' MD and 126' TVD 12. Attachments: Description Summary of Roposal f;► 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: • 12/31/2012 Oil r Gas r WDSPL r Suspended F 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tom Brassfield @ 265 -6377 Email: Tom. J.Brassfieldeconocoohillips.com Printed Na, e i Alvord / Title: Alaska Drilling Manager Signatur . T vi 4 11 „,, Phone: 265 -6120 Date >a1/ 044 2..._ Commission Use Only Yll Sund ry Number: /�� 2� � of approval: Notify Commission so that a representative may witness V III Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r S'l -� 4--r p ray - c-a0 t.c.. t J Dec.. 3 1 ) Z-0 / Other: SG( s��w,Q 1 Spacing Exception Required? Yes❑ No ❑ Subsequent Form Required: N 0 NE. 7 APPROVED BY Approved by: (.” COMMISSIONER THE COMMISSION Date: /(,)_ iZ — / Approv • .,;,,= ' -tion is valid for 12 months from the date oval. t iVi ll 1 ° - 4 ° 3 �' � • �� y Form and Attacs iDcate o cr ��t 0� GIN A Ebmit 194 //yp • • o[F tatuEti SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279-1433 FAX (907) 276 -7542 John Braden Staff Engineer ConocoPhillips Alaska, Inc. a P.O. Box 100360 Anchorage, AK 99510 Re: Wildcat Field, Wildcat Pool, CI 17589 1A Sundry Number: 310 -432 Jr Dear Mr. Braden: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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. 'ncerely, Daniel T. Seamount, Jr. Chair DATED this . day of January, 2011. Y rY Encl. • • • John Braden Cook Inlet Asset Telephone: (907) 263 -4536 C onocoPhuHups Email: Ohn.c.Gradenaconocophinips.eon 700 G. Street P. 0. Box 100360 Anchorage, Alaska 99510 -360 December 20, 2010 Daniel T. Seamount, Chair, Commissioner Alaska Oil & Gas Conservation Commission 333 West 7 Avenue, Suite 100 RECEIVED Anchorage, Alaska 99501 DEC 2 0 ZOO Alaska Oil & Gas Cons. Commission RE: Request for Modification of Deadline Anchorage Cook Inlet State 17589 1 -A (PTD 162 -028) Dear Chairman Seamount: Pursuant to 20 AAC 25.110(n ), ConocoPhillips Company requests an extension of time for requesting a renewal of the suspension status of Cook Inlet State 17589 1 -A (PTD 162 -028), the discovery well for the North Cook Inlet reservoir. The well was inspected by divers on August 3 -7, 2010, and the inspection report required by 20 AAC 25.110(0 (Form 10 -404) was filed on September 28, 2010. As noted in the Form 10-404 report, all perforations are squeezed. The top cement retainer at 3045' KB has 5 sacks of cement on top. For over forty years, the wellbore has been isolated from the surrounding formations without loss of integrity and has not allowed migration of fluid that could threaten public health or impair the recovery of oil or gas. Because of the location of this subsea wellhead, permanent abandonment will require the use of a jack -up rig, and no such rig is currently available. In addition, we are considering whether alternative options for performing abandonment operations are feasible as well as whether to seek an exception from the statewide rules for this well under 20 AAC 25.505 and .540. Accordingly, we request that the Commission grant, under authority of 20 AAC 25.110(n), an extension of time for requesting a renewal of the suspension until December 31, 2012. � � yn cQ S r w U 4 k id yp Sincerely, 424/4to, , John C. Braden CC: Central Files WEXP: 508831001300 Admin (1004197142) Well Integrity Supervisor INGA- STATE OF ALASKA fir /toll ALASKA AND GAS CONSERVATION COMMISSION i ,1( . w APPLICATION FOR SUNDRY APPROVALS 1 ' t 20 AAC 25.280 O 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend J Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other:Extension of time for requesting 17 rene o f su spens i on 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory 17 162 -028 • 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 883 - 10013 - 00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r. CI 17589 1A ` 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 17589 r Wildcat 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): (Junk (measured): 3045' 12676 • 12422 ` 3045' 3045' 3045', 3883', 5025', 5320', 10883', 12280', 12837 Casing Length Size MD TVD Burst Collapse Structural 25' 30" 151' 151' Conductor 99', 529' 24" x 20" 225' x 655' 225' x 655' Surface 1453' 13 -3/8" 1579' 1579' Intermediate 5363' 9 -5/8" 5489' 5489' Production 10199' 7" 10325' 10139' Tie Back Liner 9960' 5» 10086' 9909' Production Liner 2200' 5» 12404' 12162' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): all perfs cemented 2.375" 37 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) BPV @ 126' MD, 126' TVD 12. Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory 17 Development r Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/31/2010 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r" 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Braden @ 263 -4536 Printed Name John Braden Title: Staff Engineer Signature Phone: 263 -4536 Date Z(.} 19 l0 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness J Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: 14 yt B u/ a- ( O r wr2 t t S (..LS 124,4 G+ t? r.. ±19 f &ry 1� eC4c1 h lA (Z a i V eFoQ40: 1- , 1 to Zo kW- 2S. t tO (fti) . U t ® C 2 0 2010 Subsequent Form Required: 1 4 01 ,, k. . Alaska Oil & Gas Cons, C[jip>lpjssjol} Anchorage APPROVED BY Approved by: � a / OMMISSIONER THE COMMISSION Date: / / 5/ f RBO 8 JAN Form 10 -403 Revised 1/2010 Q6 2 G N A L Submit in Duplicate „, ConocoPhillips September 27, 2010 Commissioner Dan Seamount • John Braden Cook Inlet Asset Telephone: (907) 263-4536 Email: john.c.braden@conocophillips.com 700 G. Street P. O. Box 100360 Anchorage, Alaska 99510-360 State of Alaska SEP 2 8 ?010 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 A kaM&6ftCMLC@"*On Anchorage, Alaska 99501 Ando RE: Suspended Well Inspection (20 AAC 25.110) 10-404 Sundry Cook Inlet State 17589 1-A (PTD 162-028) Dear Commissioner Seamount: 7 O Attached is the suspended well inspection documentation as required by 20 AAC 25.110 for Cook Inlet State 17589 1-A (PTD 162-028). I received the final report from the divers on Sept 16, 2010. In fulfillment of the requirement, the following documents are attached: • Form 10-404 for PTD 162-028 • Report of on-site survey per 20 AAC 25.110 • Wellbore Schematic • As -built Survey • Note Waiving Inspection by AOGCC Representative • Estimated Pore Pressure vs Depth Plot of the NCIU Area • Tree Photos If you need clarification or more information regarding this suspended well inspection, you may contact me at the above phone number or addresses. Sincerely, John C. Braden • CC: Central Files WEXP: 508831001300 Admin (1004197142) Well Integrity Supervisor 0 STATE OF ALASKA ALASKP& AND GAS CONSERVATION COMMIS,* REPORT OF SUNDRY WELL OPERATIONS wGA- 11 Z411o1n 1. Operations Performed: Abandon Repair w ell Rug Perforations Stimulate `°' Other r'i 20 AAC25.110 After Casing j Pull Tubing "` Perforate New Pool Waiver Time Extension i Change Approved Program Operat. Shutdown j j Perforate Re-enter Suspended Well I- 2. Operator Name: 2. 4. Current Well Status: 5. Per it to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory Iv— Stratigraphic Service 162-028 3. Address: API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-883-10013-00 7. Property Designtion: 8. Well Name and Number: ADL 17589 Cl 17589 1A 9. Field/Pool(s): "', Wildcat 10. Present Well Condition Summary: ALL DEPTHS REFERENCED TO MEAN SEA LEVEL (126) 3045', 3883', 5025', 5320', Total Depth measured 12676 feet Plugs (measured) 10883', 12280', 12837' true vertical 12422 feet Junk (measured) Cmt @ 3045' Effective Depth measured 3045 feet Packer (measured) na true vertical 3045 feet (true vertucal) na Casing Length Size MD TVD Burst Collapse Structural 25' 30" 151' 151' Conductor 99', 529' 24" x 20" 225'x 655' 225'x 655' Surface 1453' 13-3/8" 1579' 1579' Intermediate 5363' 9-5/8" 5489' 5489' Production 10199' 7" 10325' 10139' Tie Back Liner 1 9960' 1 5" 10086' 9909' Production Liner 2200' 5" 12404' 12162' Perforation depth: Measured depth: all perfs cemented 3105'-3155', 3500'-3505', 4075'-4105', 5065'-5085', 5153'-5163', 5350'-5355', 6108'-6112', 6206'-6226', 6328'-6332', 10927'-10947', 12300'-12303', 12315'-12348', 12364'-12378' True Vertical Depth: all perfs cemented 3105'-3155', 3500'-3505', 4075'-4105', 5065'-5085', 5153'-5163', 5350'-5355', 6107'-6111', 6204'-6224', 6325'-6329', 10726-10744', 12061'-12064', 12076'-12108', 12124'-12137' Tubing (size, grade, MD, and TVD) 2.375", 37' MD and 37' TVD x Packers & SSSV (type, MD, and TVD) cement retainer @ 3045' MD, 3045' TVD +G °{{8�S BPV @ 126' MD, 126' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicablet�tiMi�,lA�! Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 na na Subsequent to operation 0 0 0 na na 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Explorato� w'\, Development r Service 15. Well Status after work: A1J" n � Oil Gas WDSPrL � Daily Report of Well Operations XXXX GSTOR l WAG f— GASINJ _ WINJ SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Braden (@_ 2634536 Printed Name John Braden Title Staff Engineer Signature ��fPhone: 263-4536 Date n &-f - c-� RBDIIAS SEP 2 8 Mf;4� Form 10-404 Revised 7/2009 Submit Original Only Cook Inlet State 17589 1-A (PTD 162-028) 20 AAC 25.110 (f) Report of Sundry Well Operations (Form 10-404) 1. Description and condition of the wellhead and surface location, including any discoloration, fluid or sheen visible on the ground or in any nearby water; This subsea well is located 1250 ft S, 2025 ft W of Sec 6, TI IN R9W, SM. The wellhead survey was accomplished on 8/3/10 through 8/7/10 with four separate dives. The inspection consisted of (a) locating the wellhead, (b) tactile inspection of wellhead and base plate, (c) video inspection of wellhead and base plate, (d) cathodic protection survey. The AOGCC witness of the inspection was waived, per the attached note. (a) Divers found the wellhead and recorded the GPS coordinates for the riser as Lat 6100 55.0395 N, Long 150 51 11.9165 W. (b) The glacial silt in the Cook Inlet waters causes effectively zero visibility. Divers performed a tactile inspection noting damage (dents, cracks, pitting, debris, surface coating condition, marine growth, etc.). Tactile survey found no damage on the wellhead, base plate or any welds inspected. All flanges and bolts were intact, with flanges evenly spaced and no noticeable corrosion or damage. There was a 1/8" to 1/4" marine growth "crust" over the base plate and tree. The base plate was covered with rock and debris. A diagram of the wellhead and base plate prepared by the divers, with inspection notes, is shown below in the attachments. The divers supplemented the tactile survey with video that used supplied fresh water to increase visibility. (c) Twenty photographs taken by the divers are shown in the attachments. They range from the base plate to the top of the wellhead as a compliment to the tactile inspection. (d) Cathodic protection inspection measured -1.151 volts, indicating good corrosion inhibition to the components. 2. A plat showing the location of the suspended well and any wells within one -quarter -mile radius of the wellbore; An as -built of the original location as well as a plat showing the location of the Cook Inlet State 17589 1-A well relative to the Tyonek Platform is attached. There are no operating or suspended wells within a quarter mile of the Cook Inlet 17589 1-A. 3. Well pressure readings, if practicable; No pressure readings were taken, due to the nature of the wellhead and inspection. 4. Photographs clearly showing the condition of the wellhead and surrounding location; Twenty photographs taken by the divers are shown in the attachments. They range from the base plate to the top of the wellhead to compliment the tactile inspection. 5. An update of all information and documentation required in (20 AAC 25.110(b) of this section. 20 AAC 25.110(b) requires that the well meet the requirements of 20 AAC 25.110(a) in addition to including a wellbore diagram, information of geopressured or depleted strata and proposed work plan. In accordance with 20 AAC 25.110(a), the tactile inspection found that the wellhead and base plate are mechanically sound. The attached schematic of the well, which is based on original drilling reports, indicates all perforations are squeezed. The top cement retainer at 3045' KB has 5 sacks of cement on top. The wellbore is isolated from the surrounding formations and should not allow migration of fluid that could threaten public health or impair the recovery of oil or gas Attachments Diver's Wellhead and Base Plate Diagram Wellbore Schematic As -built survey Location Map Relative to Tyonek Platform Note Waiving Inspection by AOGCC Representative Pressure vs Depth Plot of the NCIU Area Tree Photos "Iii 1'" w l mv:13t-1 tl r2_oti DOTS ARE N AND TOW ram HAS LNM DEPMM FLANGE QM IS EVEN DOTS ALL Dr AND TMRT ND DANAM ONPIPE pIP VALVE OC GAP EVEN ANNA= OC �E�S LNMT DEPOSITS ON SURFACE 81 &VEL ENT AN CEMENT DOCK ODAETS OC VASE PLATE SS AMD BELOW NUMJME EASE PATE CABLES ANI WOOD DENHS ON DOTTOI • 0 C*k Inlet State 1A (17589) jo OTIS BP Valve @ 126' Base Plate @ 126' RKB 30" Casing @ 151' Jetted into Place I I jjrjjj I I ' 24" Pipe @ 225'w/300 Sx Cmt in 30" Hole 1 Jt 2 3/8" tbs 20" Casing @ 655' w/1600 Sx Cmt in 24" Hole 13 3/8" Casing @ 1579' w/l510 Sx Cmt in 17 12" Hole 3105'- 3155' Perf Prod, SQZ 245 Sx Cmt 3045' Cmt Retainer, 5 Sx Cmt on top I I � 13500' - 3505' Perf Prod, SQZ 250 Sx Cmt 3883' Cmt Retainer, 10 Sx Cmt on top I I Fgw ',075'- 4105' Perf Prod, SQZ 150 Sx Cmt 5025' Cmt Retainer, 15 Sx Cmt on top L065- - 5085' Perf Prod & Died, SQZ 200 Sx Cmt 153' - 5163' Perf Prod, SQZ 200 Sx Cmt 5320' Model "N" SQZ 15 Sx Cmt on top 350' - 5355' Perf Prod, SQZ 200 Sx Cmt 9 5/8" Casing @ 5489'w/600 Sx in 12 1/4" Hole 6108'- 6112' Perf Prod, SQZ 50 Sx Cmt 6206'- 6226' Perf Prod, Stim, HCL/HF, SQZ 50 Sx Cmt 6328'- 6332' Perf Prod, SQZ 50 Sx Cmt Casing Break 8900' - 8985' 10,101' 5" Casing @ 10,086'w / 540 Sx Cmt 7" Casing @ 10,325'w/300 Sx Cmt in 8 1/2" Hole 10,883' Model "N" Packer 1:=j 10927'- 10947' Perf Good Prod, SQZ 40 Sx Cmt 12,280' Model "N" Packer 12300'- 12303' Perf No Prod, SQZ 50 Sx Cmt 12315'- 12348' Perf No Prod, SQZ 50 Sx Cmt 5" Liner @ 12,404' w/180 Sx in 6" Hole 12364'- 12378' Perf No Prod, SQZ 50 Sx Cmt 12,387' Cmt Retainer SQZ 54 Sx Cmt 12,676' TD 0 0 KtLr-I v P . _ _ l� � Anchorage, Alasb _�� SEP 12 Dope. of N"" 1 27 11 26 25 1 30 1 29 1 28 Co I 34 .1 35 i 36 �� 31 32 11 33 0 11I i I 1 !21 61.04!48.68 " 1 7. 12 , I1 5 I 4 I j 2024.9 OK INLET STkTE No.I A I 3 1 2 ( 1 6 1 610-04=09.000 I I I I I 1150486-34.3941 1 1393.5 1 ------1-- I I COOK INLET STATIE. No_I_ 1 1 61404-03.630e I 1 I I 1 ♦13048 -07.580 1 N 1 1 I 10 11 .1 12 1 7* 8 1 9 1 i- 15 14 1 13 18 17 16 ------ ——1---------1---------1--------i--------I--------� Scale I" = I Mite Certificate of Surveyor I hereby certify that I am properly registered and lic- ensed io practice land surveying in the State of Alaska and that this plat represents a location surveyed by me, as of 5:OOA.M.,28 May,1962 and that all dimensions Q other details are correct. ��.► .7. /-9 0A j DATE ERTIR IA 1i0i0�/96 �. /9 mss?. Date Surveyor NOTE: PLAT AMENDED TO SHOW THE LOCATION OF COOK INLET STATE No. I A AS OF 9:00 A.M., 5 SEPT. 1962 Surveyors Note ..The location of COOK INLET NO.I was surveyed by use of Tri -Station Monuments BELUGA and TERRACE estab- lished by the U.S. 29th Engineers, 1944 .a 1942 resp. �I The Surveyed Location Of COOK INLET STATE NO.I. (in S.W. 1/4 of Sec.6,T. It N.,R.9W.,S.M) Surve ed Fot PAN AMQRIICCAORATION OLEUM SURVEYED BY F.• M. Lindsey REGISTERED LAND SURVEYR 680-5 1405 NORTHERN LIGHTS ®LVD. ANCHORAGE.ALASKA 0 10 AEA 5-31-13'F CPAI,ICPC s2 1 t 9 -aft 12 ; 10 831727 ADL 391268 AD 175W ADL 1122 THE 1. RENAISSANCE RENAISSANCE f E.N.AISSANGA,` , RUTTER-WIL13A1 }CS { x 5-31_13 ..-31-13 . ADL391269 ,2-28-67 31-12 9-3010 91270 22 .390567 ADL390384 icpco :BB EXP RENAISSANCE, RUTTERVILBANKS 08-31167 , Ti -30-09 30 29 91195927 ADLO17590 31-13 ADL390099 i . , ?'CO.V� CPiCO 3 I a1�.:u.*;at,,,,, 32 „3 34 1..,' �' ,IJltTIT _'91351 c. � M..ad• I ISSANCE sf��_ 1-WILBANks 931970 ; � o ` 5 08-31-67 3 30-10 ' ADL03783-1 _390382 C0061V A ST 1758971 CPCO I - 6 -31- 101 'If ' 08-31-67 t. 911 452 9 I 14 �v 1 1tDLOa 874116 ��-931 05- 740 ADL017589 I SANCE RENAISSANCE, ILBANKS RUTTER-WILBANKS RENAISSAN - a 12-31-08 2, 19 JTTERNYILBA ConocoPhillips Alaska, Inc. 9928 ADL389927 Cook Inlet 0 1 2 State 1 A' Wel ISSANCE, RENAISSANCE, 1lVILB I KS RUDER-WILBPVI S _ sq,jE IN MILES 29 Location ` 3-3-09 09030202A00 0 0 Page 1 of 2 Braden, John C From: Kanady, Randall B Sent: Friday, July 16, 2010 11:38 AM To: Braden, John C Subject: FW: Cook Inlet State 1A (162-028) Suspend Well Inspection Notification I'll call you after lunch... From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, July 16, 2010 11:31 AM To: Kanady, Randall B Cc: Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay; Davies, Stephen F (DOA) Subject: RE: Cook Inlet State 1A (162-028) Suspend Well Inspection Notification 10-404 (not sundry) must be filed w/in 30 days after completing well -site inspection. An AOGCC Inspector will not accompany ConocoPhillips on this inspection. You indicate "potential water sampling"; what is controlling that decision? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Kanady, Randall B [mailto:Randall.B.Kanady@conocophiliips.com] Sent: Friday, July 16, 2010 11:02 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Davies, Stephen F (DOA) Cc: Braden, John C; Aubert, Winton G (DOA) Subject: RE: Cook Inlet State 1A (162-028) Suspend Well Inspection Notification Tom, I believe the new reg. require a 10 day notification, for wells suspended before January 1, 2009, for a wellsite inspection. The wellsite inspection needs to be completed by September 31, 2010. A sundry is required to be filed 30 days after the required inspection. Randy From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, July 16, 2010 10:44 AM To: Kanady, Randall B; Regg, James B (DOA); Davies, Stephen F (DOA) Cc: Braden, John C; Aubert, Winton G (DOA) Subject: RE: Cook Inlet State 1A (162-028) Suspend Well Inspection Notification Randy, According to the new suspended well regulations, I believe a sundry is required in advance of this activity. I don't expect there will be any issues with your plan, but it is best to "dot the is and cross the is". Tom Maunder, PE AOGCC 9/22/2010 • Page 2 of 2 From: Kanady, Randall B [mailto:Randall.B.Kanady@conocophillips.com] Sent: Friday, July 16, 2010 10:31 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Davies, Stephen F (DOA) Cc: Braden, John C Subject: Cook Inlet State 1A Suspend Well Inspection Notification ConocoPhillips is providing AOGCC notice of the wellhead inspection of Suspended Well Cook Inlet State 1A, API 50-283-10013. The inspection is planned for August 2-4. It will take 1 day to motor out from the Anchorage dock to the Cook Inlet State 1A location. 1 day to conduct the inspection and 1 day to motor back. There is no helicopter access to the boat that will be conducting the inspection. The wellhead is in —130' of water and is located close to the Tyonek Platform. The scope of the inspection is: UT of the wellhead, video of the wellhead and potential water sampling. Please let me know if an AOGCC inspector will want to participate on this inspection or if you have any question regarding this inspection. Randy Randall Kanady, P.E. Drilling and Wells ConocoPhillips Alaska Office: 907-263-04126 Cell: 907-830-0742 randall.b.kanady@conocophillip.com 9/22/2010 2,000 4,000 6,000 0 U) 8,000 10,000 12,000 14,000 North Cook Inlet Unit Estimated Pore Pressure + PorePressure @ NCIU, Tertiary Pool based on f? A-10, A-15, A-16, B-1, B-3, NCI St 17589 �—lie x X + \ \ \ \ \ + 1 Pore Pressure N. Forelands No. 1 9700 psi @ 13282 \ CI St 17589 1-A 5236 psi @ 10927' 0 2,000 4,000 6,000 8,000 10,000 Formation Pressure, psia 1 + PorePressure @ NCIU, Tertiary Pool based on f? A-10, A-15, A-16, B-1, B-3, NCI St 17589 �—lie x X + \ \ \ \ \ + 1 Pore Pressure N. Forelands No. 1 9700 psi @ 13282 \ CI St 17589 1-A 5236 psi @ 10927' 0 2,000 4,000 6,000 8,000 10,000 Formation Pressure, psia PHOTOGRAPH LOG INSP. (STR. NO. - TYPEXR. - NO.) NO.: 2010 Conocophillips Well bead subsea DATE: August 06,2010 Page 1 STRUCTURE: Well Head At Tyonek Platform INSPECTORS) STEVE STUART Tbn Wood AMERICAN MARINE CORP. UIPMENT : RIVER HANDHELD UNDERWATER DIGITALVIDEO LOCATION PHOTO NO. FILM TYPE ASA I ISO ROLL NO. BOT. DEPTH DWG. NO. CMNT. NO. F1 STOP FOCUS Rocks and vel at base plats. Also 1 NIA NIA DIGITAL NIA 1WA 130 FT. Well Head 1 1 2 rout or cement was evident Weld at Base Plate and Riser. Some 2 1 2 calcarious deposits evident: At base plate and riser weld. 3 1 2 On Base Plate after excavation by 4 1 2 diver. I 1 Weld at the base plate. Calcareous 1 5 1 2 Its on riser. Annulus between 30 Inch and 24 inch 6 I 1 1 2 riser sections. I I Gusset at bottom of vMl head riser. .ially bund by gravel on base pi. 7 1 2 Calcareous deposits tett the surface 8 1 2 of the well head. I 1 Calcareous deposits on the pi3per S 1 2 riser section.112 inch thick in area. Flange bolt surface on upper flange. 10 1 2 COMMENTS: 1 All photos were taken from a digital imaging device. 2. No cleaning was performed in preparation for the inspectiion. 3. Video was taken in the as is condition, as requested by company representitive. PHOTOGRAPH LOG INSP. (STR. NO. - TYPE,YR. - NO.) NO.: 2010 Conocophiilips Well Head Subsea DATE: August 06,2010 Page z STRUCTURE: Well Head At Tyonek Platform INSPECTOR(S): STEVE STUART Tim Wood AMERICAN MARINE CORP. 'UIPMENT : DIVER HANDHELD UNDERWATER DIGITALVIDEO LOCATION PHOTO NO. FILAR TYPE ASA I ISO ROLL NO. BOT. DEPTH DWG. NO. CMNT. NO. F/ STOP FOCUS Top edge of well head. No dings 11 NIA NIA DIGITAL NIA WA 130 FT. Well Head 1 1 2 evident. Calcareous deposits. Calcareous deposits on riser. No 12 1 2 corrosion found. 1 1 Feature on side of well head riser. 13 1 2 Some light marine growth evident. Top riser surface. Poly down line 14 1 2 at the top of photo. Surface of lower riser. 15 1 2 Surface of lower riser at bottom 16 1 2 Rifler at the base plate. Grout or rent on bay piate. 17 1 2 Marine growth inside of pipe at top 18 1 2 of wellhead. E=I Marine growth inside of 8 Inch pipe 19 1 2 Top Flange Solt (typical) With some 20 1 2 deposits and N ht marine rowth. COMMENTS: 1. All photos were taken from a digital imaging device. 2. No cleaning was performed in preparation for the inspectiion. 3. Video was taken in the as is condition, as requested by company representitive. 0 Racks at Base Plate At Base Plate and Riser 0 0 At Base Plate and Riser 0 a 0 • 0 • Gusset at Bottom of Well Head Riser I • 0 Calcareous Deposits on Surface of Well Head 9 • 0 Flange Bolt H Top of Well Head H$/H6/ie HEAD SURVEY ji i!^@a A h, 0 • • I� 0 Surface of Lower Riser im 0 • A9 F- L 0 9 Marine Growth hv-J(l(-,, of t"� Inch • 0 Marine Growth Inside of 8 Inch v 0 • Top Riser Section 0 0 Top Flange Boit FEW �(t)_- a2CK" SARAH PALIN, GOVERNOR L. II - ..� Ll LrL 1 ALASKA OIL AND GAS � 333 W. 7lhAVENUE, SUITE 100 CONSERVATION COMMSSION / ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279.1433 January 28, 2009 FAX (907) 276-7542 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 5968 James Rodgers ConocoPhillips Alaska Inc. PO Box 100360 SCANNED OCT 0 3 2014 Anchorage AK 99510-0360 Re: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut -In Well Information Dear Mr. Rodgers: Enclosed are the Alaska Oil and Gas Conservation Commission's revised regulations regarding suspended wells (i.e., 20 AAC 25.110). Also enclosed are a list of suspended wells and a list of long term shut-in wells operated by ConocoPhillips Alaska Inc. and your predecessor. For each list, please verify the information for each well, and provide any corrections by April 1, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with Jim Regg at 907-793-1236 or jim.regg@alaska.gov. If you have any questions regarding this notice, please contact Tom Maunder at 907-793- 1250 or tom.maunder@alaska.gov. Sincerely, Cathy P. Foerster Commissioner Enclosures CERTIFIED MAIL,.. RECEIPT (Domestic Mail Only; No Insurance Coverage Providec 117 -r N"F* L USE Poeupe i 10.51 05 .q a Nd S C3 CWWW Fee $2.70 0 iiehro Recept Fee '0 (Enaoreanenl1114giiiiiiso $2.20 m Him iv a ®`D ru &lige — f0.0H cc >a 9� CO is w Fnawe a • $5.49 0 0 James Rodgers E3 _� ConocoPhillips Alaska Inc. orPO w,� PO Box 100360 W z ' Anchorage AK 99510-0360 Ile Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. e Print your name and address on the reverse so that we can return the card to you. * Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to: James Rodgers ConocoPhillips Alaska Inc. PO Box 100360 Anchorage AK 99510-0360 A. Signature � gent ❑ Addressee B. Received by ( Printed Name) C. Date of Delivery D. Is delivery address different from item I? 11 Yes If YES, enter delivery address below: ❑ No 3. gervice Type 'EI Certified Mail ❑ Express Mail ❑ Registered Return Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 2. Article Number (Transfer from service label, _ 7005 1820 0001 2499 5968 PS Form 3811, February 2004 Domestic Return Receipt 102595-02-M-1540 Operator PHILLIPS PETROLEUM CO Field Permit API Number Well Name Suspended and Shut In 'Neils *EXPLORATORY 162-028-0 50-883-10013-00-00 COOK INLET ST 17589 1-A PT THOMSON 181-069-0 50-089-20017-00-00 P.T.UN.N.STAINES RV. 1 Wednesday, January 14, 2009 Current Date of StatusStatus Surface Location .................................................... Lease(s)................................... SUSP 5/15/1973 1250 FSL 2025 FWL Sec 6 T 11 N R 9 W SM ADL0017589 SUSP 5/6/1982 2632 FSL 1742 FWL Sec 8 T 9 N R 24 E UM ADL0047572 Operator Suspended and Shut In Wells CONOCOPHILLIPS ALASKA INC Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... *EXPLORATORY 203-218-0 50-103-20477-00-00 CARBON 1 SUSP 4/23/2004 1765 FSL 2125 FEL Sec 4 T 10 N R 1 E UM FED -NPR -A 174-057-0 50-029-20151-00-00 GULL IS ST 1 SUSP 4/1/1976 2376 FNL 29 FWL Sec 28 T 12 N R 15E UM ADL0034626 176-013-0 50-029-20195-00-00 GULL IS ST 2 SUSP 4/22/1977 2378 FNL 59 FWL Sec 28 T 12N R 15E UM ADL0034629 183-181-0 50-029-21056-00-00 HEMI SPRINGS ST 1 SUSP 4/3/1984 1320 FSL 1320 FEL Sec 12 T 10 N R 11 E UM ADL0028249 201-049-0 50-103-20315-00-00 MOOSE TOOTH C SUSP 4/6/2001 1915 FNL 1115 FWL Sec 3 T 10 N R 1 E UM FED -NPR -A 202-248-0 50-279-20008-00-00 PUVIAQ 1 SUSP 4/1/2006 1703 FNL 451 FWL Sec 35 T 16 N R 10 W UM FED -NPR -A 201-007-0 50-103-20363-00-00 RENDEZVOUS 2 SUSP 4/28/2001 1707 FNL 2523 FWL Sec 6 T 9 N R 2 E UM FED -NPR -A 204-006-0 50-103-20479-00-00 SCOUT 1 SUSP 3/28/2004 571 FSL 232 FWL Sec 20 T 11 N R 1 E UM FED -NPR -A 200-200-0 50-029-22990-00-00 SILVERTIP 1J-14 SUSP 4/27/2001 1453 FSL 2406 FEL Sec 35 T 11 N R 10E UM ADL0385175 200-056-0 50-103-20313-01-00 SPARK 1A SUSP 4/4/2001 1608 FNL 2497 FWL Sec 8 T 10 N R 2E UM FED -NPR -A 178-017-0 50-029-20278-00-00 W MIKKELSEN ST 1 SUSP 11/11/1978 503 FNL 999 FWL Sec 32 T 10 N R 19E UM ADL0047527 COLVILLE RIVER 206-173-0 50-103-20540-00-00 COLVILLE RIV NAN-N CD4 -213 SUSP 4/1/2008 2942 FNL 303 FEL Sec 24 T 11 N R 4 E UM ADL0380075 ADL0380077 ADL0384209 202-042-0 50-103-20414-00-00 NANUQ 5 SUSP 4/5/2002 2342 FSL 283 FEL Sec 24 T 11 N R 4E UM ADL0380077 ADL0388903 KUPARUK RIVER 198-262-0 50-103-20286-00-00 KUPARUK RIV U TARN 2L-321 SUSP 6/18/2007 205 FNL 806 FEL Sec 22 T 10 N R 7 E UM ADL0380053 204-228-0 50-029-20727-01-00 KUPARUK RIV U WSAK 1 H-105 SUSP 12/18/2004 528 FNL 803 FEL Sec 33 T 12 N R 10E UM ADL0025639 206-106-0 50-029-23315-00-00 KUPARUK RIV U WSAK 1J-133 SUSP 8/13/2006 1622 FSL 2296 FEL Sec 35 T 11 N R 10E UM ADL0025661 ADL0025662 ADL0380058 205-156-0 50-029-23282-00-00 KUPARUK RIV U WSAK 1 Q-101 SUSP 11/29/2005 1574 FNL 1160 FEL Sec 26 T 12 N R 9 E UM ADL0025634 ADL0025641 205-157-0 50-029-23283-00-00 KUPARUK RIV U WSAK 3J-101 SUSP 12/17/2005 1205 FSL 565 FWL Sec 3 T 12N R 9 E UM ADL0025630 193-179-0 50-029-22423-00-00 KUPARUK RIV UNIT 2E-05 SUSP 4/25/1994 605 FSL 160 FWL Sec 36 T 11 N R 9 E UM ADL0025664 193-169-0 50-029-22415-00-00 KUPARUK RIV UNIT 2E-06 SUSP 4/25/1994 630 FSL 160 FWL Sec 36 T 11 N R 9 E UM ADL0025665 193-174-0 50-029-22419-00-00 KUPARUK RIV UNIT 2E-17 SUSP 4/25/1994 642 FSL 160 FWL Sec 36 T 11 N R 9 E UM ADL0025665 196-118-0 50-103-20244-00-00 KUPARUK RIV UNIT 3G-25 SUSP 8/8/1997 2538 FNL 20 FWL Sec 24 T 12 N R 8 E UM ADL0025547 199-040-0 50-103.20203-01-00 KUPARUK RIV UNIT :3H -25A SUSP 6/29/1999 1220 FNL 281 FWL Sec 12 T 12 N R 8 E UM ADL0025524 204-014-0 50-103-20481-00-00 PLACER 1 SUSP 4/11/2004 1009 FSL 19 FWL Sec 33 T 12 N R 7 E UM ADL0025552 lVednesdap, Januar), 14. 2009 1 Operator Suspended and Shut In Wells CONOCOPHILLIPS ALASKA INC Meld Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... NORTH COOK INLET 169-089-0 50-883-20031-00-00 N COOK INLET UNIT A-11 197-210-0 50-883-20090-01-00 N COOK INLET UNIT B-02 Wednesday, January 14, 2009 SUSP 10/9/2002 1302 FNL 1020 FWL Sec 6 T 11 N R 9 W SM ADL0017589 SUSP 9/29/2002 1249 FNL 980 FWL Sec 6 T 11 N R 9 W SM ADL0017589 3 PHILLIPS PETROLEUM DRAWER 66 KENAI, ALASKA 99611 NORTH AMERICA PRODUCTION Kenai Profit Center August 15, 1996 Blair E. Wondzell, PE Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 9950 i -3192 Subject: Suspended and Other Wells COMPANY RECEIVED AUG 1 9 1996 Alaska Oil & 8.2,3. Cons. Ccmmission Anchorage COMM _8_ES ENe SRENG NRO S~A~~~ ~STAI _ FILE 6O40 r"" roZ Dear Mr. Wondzell, As per to your letter on this subject dated July 15,1996, AOGCC records indicate that Phillips Petroleum Co. has four wells that need work and/or location inspections in 1996. Item Well Name & No. Loc, sec, T, R, M Description of What's Needed 1 Sunfish #3 2 Cook Inlet St :# 1 A 3 P.T.U.N. Staines R l 4 Sullivan # 1 Sec 6, 1 IN, 9W, S Sec 6, 1 IN, 9W, S Sec 8, 9N, 24E, U Sec 10, 22S, 21E, CR. Suspended well Suspended well Susp. Well, WH rptd leaking' Susp. Well, no surface plug The following are Phillips' plans for each well: 1. Sunfish #3, 93-076. This well is suspended pending further evaluation and/or development of the Sunfish formation. . Cook Inlet St. #1A~ PTD 62-028. An intensive search for additional information is being made within Phillips' Kenai, Houston, and Bartlesville offices. Once those searches are complete a proposed plan for this well will be transmitted to the AOGCC. . PT Unit N. Staines River #1, PTD 81-069. Plans and procedures for well plug and abandonment and site remediation are being developed. Once completed the plans and procedures will be transmitted to the appropriate agencies for approval. P & A Operations are tentatively scheduled for 1996 - 97 with Site Remediation planned for 1997) Blair Wondzell, AOGCC Suspended and Other Wells' August 14, 1996, Pg. 2 of 2 . Sullivan #1, PTD 00-051. This well location was reviewed in July, 1993, in accordance with the Alaska Department of Environmental Conservation (ADEC) June 1991 guidelines entitled Interim Site Assessment Gttidance for I, aclive Drilli,g [,I/aste Sites. A three member field team spent 4 hours trying to locate the Sullivan #1 well site in heaw foliage near the Little River and Lare Glacier. A GPS, quadrangle topographic map, field compass, and air Support were used to establish (with an accuracy of 75 feet) the wellhead location. The surrounding 300 by 500 foot are was searched for remnants of a wellhead, reserve pit, and well site debris. No apparent evidence of the wellhead or reserve pit could be found. Additionally, no evidence of leakage, seepage, or vegetation stress could be found.'- Based on the July 1993 site review no further action is recommended for the Sullivan #1. The findings ora benefit and impact evaluation estimated that the impacts of .implementing an action plan would exceed the benefits of an action plan. No further action is warranted because actions implemented to reduce an already negligible risk would create more risk to human health and the environment than the no action alternative. A copy of the 1993 site assessment is available for your review. If you have any questions concerning these wells please contact Len Janson of this office (907-776-8166). Sincerely, Phillips Petroleum Company ~Ken ~t~od~t ~enter Manager cc~ P Dean L Janson S Arbelovsky S Mc Gee file E14-6(1) E14-2 El4-1 E1-2~05) N. STAINES RIVER STATE #1 SULLIVAN SUNFISH #3 TONY KNOWLE$, GOVERNOFI ALASKA OIL AND GAS CONSERVATION CO~I~HSSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 15, 1996 Mr. John Landrum Phillips Petroleum Company Drawer 66 Kenai, Alaska 99611 Subject: Suspended and Other Wells Dear Mr. Landrum' Our Location Clearance Status records show that Phillips Petroleum Co. and Phillips Kerr have some Wells that need location inspections and two wells that need well work. Our records, copy attached, show the following wells need work and/or' location inspections in 1996: Item Well Name & No. Loc. sec. T. R. M Description of What's Needed 1 Sunfish//3 2 Cook Inlet St #lA 3 P.T.U.N. Staines R 1 4 Sullivan //1 Sec 6, 11N, 9W, S Sec 6, 11N, 9W, S Sec 8, 9N, 24E, U Sec 10, 22S, 21E, CR. Suspended well Suspended well Susp. well, well head reported leaking Susp, well, no surface plug 1. Sunfish #3.93-076. Our records show this well suspended - surface location is Platform "A", Leg 1, Slot 6. well appears to be properly suspended with the formation abandoned and a surface plug from 500' to 300'. No additional action appears necessary to maintain as "suspended"; however, please advise as to your plans for this well. 2. Cook Inlet St. #lA, PTD 62-028. our records show this well was drilled from a barge. Several intervals were production tested; as testing moved up hole, the last-tested interval was squeezed before perforating the next interval. The upper most interval tested and squeezed was 31 50 -31 55' (sqz'd w/245 sacks). The final daily report: "8/2/64 Moved drilling barge off location. Well is shut in producing well." Our records do not indicate any subsequent work done on the well or any plugs shallower than 3150' - as such, this well is not properly abandoned. If you have additional data, please provide us a copy; tell us of your. plans for this well. 1Mr. John Landrum Phillips Petroleum Company 2 July 15, 1996 3. PT Unit N. Staines River #1, PTD 81-069. Leon Lynch, DNR, reported surface valve leaking problems with the P. T. Unit North Staines River #1 well. Following his lead, Fairweather submitted a report to the Commission for the work they had done last summer; this data showed significant pressure on the inner and outer annuli and showed well head equipment that was deteriorating to the point of leaking. This well is in violation of AOGCC regulations, 20AAC25. Within 30 days, please advise this office of your plans to correct the deficiencies. 4. Sullivan #1, PTD 00-051. Our records on this well indicate the top plug is at 1 25'.. If your records show differently, please provide us with the additional data; otherwise, plan to place the surface plug in this well and notify us of the opportunity to perform a location clearance inspection. Sincerely, Blair E. Wondl~l, PE Senior Petroleum Engineer cc: Paul Dean Attachments 6/07/96 ALASKA WELLS LOCATION CLEARANCE STATUS PAGE 1 PERMIT 00-0050-0 00-0051-0 00-0109-0 NEW COD LOC CLEAR D'CLEAR-PRE Z'NOT-PLUGGED 4-RDY-FOR-INSP · OPERATOR WELL NAME PHILLIPS KERR SULLIVAN 2 SULLIVAN 1 SULLIVAN STRAT 1 PHILLIPS KERR WELL SEC TWP RNG MER STATUS 09 22S 021E C P&A 10 22S 021E C P&A 20 22S 022E C P~A 6/07/96 ALASKA WELLS LOCATION CLEARANCE STATUS PAGE 2 OPERATOR PHILLIPS PETR PHILLIPS PETR PERMIT 82-0042 93-0076 62-0028 66-0025 65-0030 73-0016 76-0059 81-0069 NEW COD WELL NAME TERN A - SRS 1 SUNFISH 3 COOK INLET ST 17589 1-A COOK INLET ST 18741 2 COOK INLET ST 18740 1 N TYONEK ST 58838 1 BIG RIV A-01 P.T.UN.N.STAINES RV.1 LOC CLEAR C*CLEAR-UW __S*SUSP~EL~ .... Y*COND-UK C*CLEAR-UW C*CLEAR-UW 6-CLEARED 6-CLEARED WELL SEC TWP RNG STATUS 19 10N 010W P&A 06 lin 009W SUSP 06 liN 009W SUSP 08 liN 009W P&A 11 liN 010W P&A 25 13N 011W P&A 15 495 068W P&A 08 09N 024E SUSP STATUS DATE 8/28/82 4/02/94 5/15/73 5/1s/v3 5/15/73 8/12/73 3/25/77 5/06/82 ** THIS LIST EXCLUDES WELLS WITH LEASE FED-NPRA ** KENAI PROFIT CENTER P.O. Drawer 66 K'~nni A~' QQ~11 MEMO FROM ENGINEERING DEPARTMENT May 29, 1996 RECEIVED MAY 3 1 1995 Alasla 011 & ~as Con& Oommi~ion Alaska Oil and Gas Commision From: Sandy McGee Phillips Petroleum Copy of State Form 407 for North Cook Inlet Unit State Well lA (17589). FROM PHILLIPS PETROLEUM CO. TO l- ~ ~&bz~ oJr OE)z~r.~Y~ZL ....... o - · .. / i ii i ] Il Il n ~. _ ....... i il mi mm · ~is is to repaut =Permzm~t Ab~zdo~t" of t~e s~bJee~ well. This well .---..~.,~ ~r~'~''~ ~ f'"..,'-.W----I RECEIVED ~_ ¢~-" I~ ~. MAY 5 11996 l~' ~'~ ',1'~"'~,~ ~-~-~~~.~m~,~ . ~raoe .......... .... Reservoir En~jae~ ~Ati~tiom -- TOTAL P. 001 ALASKA OILAND GAS CONSERVATION COMMISSION PETROLEUM WELL RECORD 05/03/96 NlJq~BER NUMBER NAME NUMBER SRT NUMBER ------ 62-0028-0 8831001300 COOK INLET ST 17589 1-A 020 ADL-17589, OPER OPERATOR CODE I NAME 135000 PHILLIPS PETROLEUM CO + 820 GEOLOGIC AREA COOK INLET BASIN FLDPOL 000000 UNIT 00000 + FIELD AND POOL NAME I MULTIiCOMP I NUMB ILOG FLD&POOL FLD&POOL COMP LOCAL UNIT NAME 000000 000000 0 1SA -+ CODE FEET CODE FEET MD TVD ............................ liB 9 00 12676 12422 -+ 1250 S 2025 W 06 liN 009W S 0802 S 0333 W 06 lin 009W S +- -+ ......................... I DEPTH 16~ 4 9-00 150 56 34.o0 62 11419 63 7296 64 119 +- + EXP i-OIL EXP SUSP EXP P&A YES 000 +- + APPROVED ISSUED SPUDDED ........................... 08/29/62 08/29/62 08/27/62 + COMP, E DATE o7/o8/64 05/15/73 RECORD LAST UPD o/ 0/8o lc-apfm 10~an95 State of Alaska., OIL AND GAS CONSERVATION COMMISSION ~TO No. '(a 2. - Oo ~ Memorandum To File: API No. ~--0 -- ~ 5 -- /06>/~. -Od) · we].~ N~ ~~ ~ ~~ ~ ~ /7~~ /-~ ~ _l ~-7~ ~nd Date ~,. , ~ ~ Note casing size, wt, depth, ~t vol, & prooedure. Liner: ~" '~ /D~ JOY Perf intervals - tops: g~ .7~F ~7 lot ~Z7 - 47 Review the well file, and comment on plugging, well head status, and location clearance - provide loc. clear, code. Signed Date ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 15, 1994 Julia Conant St Paul/Seaboard 300 S Wacker Dr Ste 1600 Chicago, IL 60606-6701 Dear Ms Conant: We have completed an audit of\all Pan American/Amoco operated wells drilled within the State which, according to our files, hav'eq~t been assigned a successor operator. Our records lack a description of any abandonment work conducted on the following two wells. Well Name Permit Number APl Number Redoubt Shoal State 22064 #1 COOk:.lnlet state !..7589 #1~A :' 66-46 50-733-10024 62-28 50-883-10013 Please provide documentation that addresses plugging and abandonment of these wells. The Commission will judge the adequacy of a plugging and abandonment program based on regulations in effect at the time the work was conducted. I have included a brief summary of the historical evolution of Alaska plugging and abandonment regulations. If you have any questions or comments, please contact either me or Blair Wondzell at the phone number above. Sincerely, Robed P Crandall Senior Petroleum Geologist c: Stephanie Falley - Amoco Corp, Chicago PHILLIPS PETROLEUM DENVER, COLORADO 80202 ~I~CSECURITY LIFE BUILDING 1010 EXPLORATION AND PRODUCTION DEPARTMENT COMPANY May 15, 1973 Subject: North Cook Inlet Unit Abandonment of Expendable State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 9950& Attention: Mr. Homer L. Burrell, Director Gent lemen: This is in reply to your letter of April 23, 1973, to Mr. J.P. Denny regarding abandonment of certain expendable wells in the North Cook Inlet Unit, which have been classified as suspended. Attached are copies of Sundry Notices (Form 10-~03) for the reclassification of the following listed wells from "suspended" to "permanently abandoned". ~Cook I~nlet State ~1.7589 Cook Inlet State #187&0 Cook Inlet State #187~1 Well No. 1 Well No. 2 Very truly yours, T.C. Dough~ Sffpervisor Reservoir Engineering and Unitization Section TCD:rc Attachment DIVISION ,~ ,.; ,','.,.iL /...ND GAS ANCHORAGE ~Form 10-403 REV. '1 - t0-'t5 . Submit "Intentions" in Triplicate / & "Sul~equent 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 ~'EP,.~iT-L' 'for such'p~o~)osal$0 WELL W]eLL OTH~I~ 2.NAME OF OPERATOR Phillips Petroleum ,C. om~any (formerly Pan ~American 3. ADDRESS OF OPEI~.ATOR Petroleum Corporation) 1010 .Security Life Buildtng~ Denver,. Colorado 80202 4. LOCATION OF WELL it su.-fac~ 12~9.6' FSL and 202~.9' FWL of Section 6" TllN, RgW, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc. KB-20~ Above MLtY/~ or 127' Above Floor Plate 14. Check Appropririte Box To I,nclicate N~ture of NOtice, Re "~. APl NU/VIF. P,~CAL CODE 50-283-1O013 NOTICE OF INTENTION TO: SHOOT OR ACIDIZ~ ABANDONs ~Other) $. LF_,ASI~ DESIGNATION AND SERIAL NO, ADL-17589 ?. IF IN-DIA~W, A3~LOTTEE OR TRIBE NAJVL~ 8. UNIT, FARNI OR LEASE NAME · Norbh Cook Inlet Unit (17589) 9. WELL NO. 1-A I0. FIELD A~D POOL, OR WILDCAT Wildcat .. sec., T., R., ~., (~OT~OM ~O~ OBJ~-OT~VE, kk8.5' So~th and 1691.7' We~ o/' sur~-ace location 12. PERA'I/T NO. 28-~2 )ort, or Other DM', ' BaOOTINO OP. &CIDIZINO , ABANDON MgI~T$ (Other) (NOTS: Report result~ of multiple completion on Well Completion or Recompletion Report and Lo~ form.) 15. DESCRIBE PROPOSED OR COMPLZTED OPER&TIONB (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an)' proposed work. This is to report "Permanent Abandonment" of the subject well. This well was previously classified as "Suspended" ~ as reported by Pan American '~ Petroleum CorPOration (Amoco Production. Company) on the Well Completion Report (Form P-7). Drilling information, productive zones, etc., were reported on said Form P-7, and a letter to Mr. Roscoe E. Bell, Re: Lease No. ADL-17589, Cook Inlet State No. 1 and l-A, dated November 6, 1963. DIV!SlON OF OIL AND GAS ANCHORAGE 16. I hereby certtfy..~,~Tthe f~--oi~~nd SIGNED ~T,/-' (Thi. ,pace for State offi~ u~ APPROVED BT CONDITION~ OF APPROVAL, IF A~: Reservoir Engineering and TITLE Unitization Supervisor DATE ~9.y 15, 1973 TIT~E DATE See Instructions On Reverse Side Apr'| ! 23. I973 Inlet Wol Is ~. J. P. Benny Ph! I i lps Petroleu~ Comply I0t0 ~ttty Life Bld~. Dear We p~evtousty ~ co~s~.=4~mded w~th Amoco P~od~ctton Company regarding a~a~t of ~rtaln wells t. hat have been classified as sus~ed. ~. has ~t'Sed us that ~ no longer operate the fol Io~lng ~el ts In GoOk lnl et s~a~ · J 7~,,,.,~11 NO. t-A ~ l.~tef-State t!8740 ~el! NO. ! Cook tnl-e~ S~e ~-1874t Well No,. 2 Our fi les reflect ~o paper work havl~g been ft led sho~lng a chan~ of ~ra~r, ~~, sJ~e y~ appmr~tly ~ ~erate ?~e ~lls ~ ~ld II~ fo t~qalre ~f -~ plan for ~lts ha~ b~ ~Iod l~ a su~ or f'~ ~verat years we ~=t that ~ ~v{~ ~r r~ds oN d~e~lne a mfice ~ ~dr fora t~-~3, ~ples of ~!ch are at--ed, to fo~l~y P ~ A ~ r~e ~ f= the ~lve ~~s. If not we ~td app~l-.' a~e ~ e~la~ti~ es ?o ~y they ~ ~ ~.rMed at this ftc. $1;gerelY, .~ Hoaer L. Burrell D I rector .J ~'o~ ;__--- V. z/co ~5, o ~:, 1-/7o0 810 lt.A. Lyen SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) oil [] GAS WELL WELL OTHER NAM E OF 0 PERATOR Pan American Petroleum Corporation ADDRESS OF OPERATOR P.Oo Box 779, Anchorage, Alaska 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surfece 1127 :.'ft. from bi Line and 1555 fto from E Line, Seco 6, TllN-R9W, S oI',~o 14. PERMIT NO. 15. ELEVATIONS (Show whether DF, ET, OR, et~) ADL 17589 6. IF INDIAN; ALLOTTEE OR TRIBE NAME 7. UNIT AGREEMENT NAME 8. FARM OR LEASE NAME CI State 17589 9. WELL NO. 1 10. FIELD AND POOL, OR WlI,DCAT Cook Inlet 11. SEC., T., R., M., OR BLK. AND SURVEY OR AREA ;ec. 6, TllN-R9W, 12. BOROUGH '] 18. STA~E Alaska 16. Check Appropriate Box T° Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF II PULL OR ALTER CASING I I FRACTURE TREAT ~__ MULTIPLE COMPLETE SHOOT OR ACIDIZE l-- ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZINO ABANDONMENT* (Other) Change of Name NoTE: Report results of multiple completion on Well ompletion or Recompletion Report and Log form.) 17. DESCRIBE PROPOSED OR coMpLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones perti- nent to this work.) * .. Well name formerly Cook Inlet No. iA Form P o . -.~ prepared to reflect change of name which now includes state lease number° 18. I hereby certify that the foregoing is true and correct f, DATE APPROVED BY ~ ~"-" w ~' ''f' CONDITIONS OF APPROVAL, IF ANY: TITLE Executive Secretary DATE March 16, 1965 *See In,truction~ on Reverse Side PLUGGING RECORD (Yell. ~,llended until ll~rlng of l~)ik Operator Name of Lease Cock Inlet S~t~ Location of Il of IV Application 'to drill this well was filed Date plugged:TM N~~ S, 1961 Name of each IAddress P. O. Be~ 77~ Y~ell' No. ] Field & Reservoir lAI Vl I~k~t Sec-Twp-Rge or Rlock & Survey County Yhir/ ' ~u/lelat Div. Character of well at completion (ini,~tal production): Oil (bb~yt ~ [~ ~da~e Dry? Amount well producing when plugged: Oil (bbls/day) ' I Gas (MCF/day) Not m' I ! &ak ie Depth interval of each formation CASING RECORD 'Water (bbls./day) Size, kind & depth of plugs used Indicate zones squeeze cemented, giving amount cement. I Pulled out (ft.) S~p~ipe 'l Put in well (it.) =o,, t [ 0 Left .in well (ft.) Give depth and method of parting casing (shot, ripped etc) , ;Packers and shoes KB 'WO tldt" tO BP Was well filled with mud-laden fluid, accordin~ to regulations~ ,] ~AMES AND ADDRESSES OF ,~J~CENT ~EASE OPE~TORS OR 0~NERf Name Address OF THE SURFACE Direction from this well: In addition to other information required on this form, if this well was plugged back for use as a fresh water well, give all pertinent details of plugging operations to .base of fresh water sand, perforated interval to fresh water sand, name and address' of surface owner, and attach letter from surface owner authorizing completion of this well as a-water well and agreeing to assume full liability for any subsequent plug- ging which might be required. Use reverse side for additional detail File this form in duplicate with the Commission, CERTIFICATE: I, the undersigned, state that I am the-~~[~,of the ~ll~, (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein ar/e. true, c~rect and complete to the best of my knowledge. Alaska Oil and Gas Conservation Commission Plugging Record Form No. Authorized by Order No. I Effective October 1, 1958. ....................... ~,,1 , L ,. II i , I I Il /~' ' .......... "-'. PLUGGING RECORD (well '- sPended untii spring of ]96/+) Operator { Address Pan American Petroleum,Co, rpor. ation. .,,., P. 0. Box 779 Anchorage~ Alaska l~ame of Lease .... [ W;II~To. ! Field & Reservo,r Cool( I,,~]et State ,. , IA Wildcat Location o¢ ~Vell S~-Tw~-Rge or Block & Surve~ ~ 'County- Th rd SE of SW Sec. ~ Tll'N~ R~W~ Seward Meridian, JJudicial .0iv. ~an ~merlc~n Petroloum Corp. ~es ~oll ha not boen tost d. , Date plugged: ...... I Total dept~ ~ Amount well producing when plugged: Il 2,q77 aD o, (bbls/day) [ G~ (~CF/day) Wato~ (bb]s./day) November 5, 1963 , 112.2q2 'TVD ' Not hn~l ,cahl~ . ~ame of ~ch formation con- Flui~ content ~f-~each fo~ation Depth interval of each ~o~atlon Size, kind & depth of plugs used taining oil or gas. Indicate Indicate zones squeeze cemented, which formation ope~ to well- ~vlng amount cement. bore. at time of plugging . . , ~ ..... . . , , bore) a t 12,375 '.[B. Cement ' ..................plug in 5" ! inet at .282~'_ wi th cement m above to 2675'. m . m mm, m ~ m Size pipe Put in well (ft.) Pulled out (ft.) Left.in well (ft.) ~ Give dep~ and Packers and sh~es ~ ' method of pa~tng 30~ 25 * 0 25 ~ I ~=in~ (=hot, 24" 99~ ,.. n 99~ .... ~pedete) MeaRurement fr~ bare plate 20~ 529! 0 ' 529~ KB "zero tide" to BP 126' 5" 9960' 0 , 9960' 5" liner 9q75' - 12,278'aA~F ~l~te 0r ., Yes , Ngg determined , ,12~.,404' KB ,,, NAMES ~D ADDRESSES OF .~JACENT L~SE OPERATORS OR OWNERS O~ THE SURFACE Name Address Direction from this well: . . ,, , , ,,, S he ] ] 0 i ] C~pany ~nchora~e ~ A ] as ka Wes t ,,,, ,, ~ ,~ In addition to other information r~uired on ~s fora, if this well w~ plugged back for use as a fresh water well, give all pertinent d~a{ls of plugging operations to.base of fresh water sand, perforated interval to .fr~h water sand, name and address' of surface owner, and attach letter .from surface owner authorizing completion of this well as a-water well and agreeing to assume full liability for any subsequent plug- ging which might be required. ' , , Use reverse side for additional detail. File this form ~ duplicate with the Commission. CERTIFICATE: I, ~e ~dersi~ed, state that I am the D ] S ~ ~ ~ u p t, of ~e ~0 Amc r i ca ~ Pet ro l cum (company), ~d that I ~ author~ed by said company to make ~is repo~; ~d that this report was pre- pared ~der my supervision ~d ~rection and that the facts sta{ed ~ere~re~ and complete to Si~at~~~~ ~aska Off and Gas Conservation Commission Plugg~g Record Fora No. Au~or~ed by Order No. 1 Effective October 1, 1958. O~t~ber 22. 196A Aa~.-hor~, Atsska AIL 17:589 (Tour lb. 1868~) hr ~r. miaL~ ro~l~ ~ble o~ t~ om rate. ~ein~ a~ the Very Italy y~ure. TEST:.~ RESULTS Cook Inlet State No. 1-A (Attachment to LESSEE'S MONTHLY REPORT OF OPERATIONS for month of ,h_, ly, 1964) 7/3/64 7/1216.~ 7/14/64 Tested Intervals 12,315-48, 12,364-78, well flowed 64 hours, 55 mlm~tes on 1/4" choke prod~.Jclng 29 bbls of oil (40.5° qravlty) and 133 bbls. of water. Gas production was too small to measure. Equival~.nt produclnq rat~s are I1 bbls. of oil and 49 bhlso of water per day. Production tested Interval 10,927 - 47 with following results: Surface Hours Choke Produced Surface Da I ly_ Production Rate Pressure [p..~.[~ .O_.l_l__~.b._b, ls_.,) [a..s_.._(H_CF_.)_ .G..O_.R_ 1/4" 2 2200 IR7 1018 5400 3/8" 6 1200 281 1200 4260 I/2" 8-I/4 I000 374.4 2970 7924 The gravity of the oil produced was 56° APl. D~Jring this test some liquids were lost out of the oas flare, line. This tested was witnessed hy Messrs. T. R. Marshall and Karl VonderAhe. Second test was conducled in the IO,927 - 47 interval with the following results. Surface Hours Choke Produced Sorface 0|I Average Dally Rate _Pr~.s..u.r_e..LOs__.L) p__C_o.d~.c.e_.d_...(.e.a_lS.) O[.!_(.b,.b3..s.), .~_a_.s_(.M_C.E) G,O.R... 1/4" 3-I/2 2125 41.0 281 2118 7540 3/8" 5-1/2 1650 101.4 442 3510 7940 1/2" 6-1/4 . 1175 144.3 554 4700 8480 Average gravity of produced oil was 56.4° APl. The following data was obtained from the bottom hole p~essure recorder. Inlttal hydrostatic presser, re Initial Shut-in pressure (1 hour) Initlal flowing pressure (1/4" choke) Final flowlng pressure (1/2" choke) Final shut-tn pressure (6-1/4 hours) Final hydrostatic pressore Mr. Karl VonderAhe witnessed this test. 8832 ps i 5236 psi ' h815 ps I 2815 psi 5160 ps i 8832 ps i Tested Interval 6,206 - 26, recovered 2240' drilling mt~d. triP 3985, ISIP not readable, IFP 2015, FFP 2015, FSIP 2736, FHP 3985. Tested Interval 5065- 85, no flow. 7/27/64 7~28~64 7/~9/64 Tested Interval 5t53 - 63 with following results: Surface Hours Surface Gas F I ow .,. C__h~.k_e .... Produced Pressure (.p__~,l~).. .R.a.t~.,_M_C,F_/_D..- 1/8" 3 2150 407 !/4" 2 1800 2725 3/8" 4- I/2 1325 5500 No liquids were recovered. The following data was obtained frem the bottom hole pressure recorder: lnltial hydrostatic pressure Initial shut-in pressure (1-1/4 hours) Initial flowing pressure Final flowing pressure on l/8" choke Final flowing pressure on I/4" choke Final flowlng pressure on 3/8" choke Final shut-in pressure (2 hot,'r~) Final hydrostatic pressure Tested interval 4075 - 4105 with following results: 3350 ps i 24/~ ps i 1828 psi, 2432 ps i 2281 ps I 1969 psi 24~3 psi 3333 ps I Surface Hours Surface Gas F Iow Choke Prod. ced P__r..es__.s.p.,r.e_~ Rate HCF/O 3/8" 1 950 5020 1/4" I 1550- 2/+85 No liquids were recovered. The following data was obtained from the bottom hole pressure recorder: Initial hydrostatic pressure Initial shut-In pressure (l ho, r) Initial flowing press.re Final flowing pressure Final shut-tn pressure (2 hours) Final hydrostatic press.re 2642 ps ) 1899 ps I 1~84 ps i 1827 ps i - 1875 ps i 2642 ps I Second test conducted in 4.075 - 4,105 interval with followlnq results: Surface Hours Surface Gas F low ,c,.e.d_ ,.. 1/2" 7 940 4575 3/8" 2-1/4 990 3290 I/4" 2-3/4 1575 1509 No liquids were recovered. -3- 8/2/6~ The following data was obtained from the bottom hole pressure recorder: Initial hydrostatic pressure Initial shut-In pressure (1 hour) Initial flowing pressure Final flowing pressure Final shut-ln pressure (1 hour)~' Final hydrostatic pressure 27/~0 psi 1850 ps I 158O ps i 1815 psi --1850 ps I 2600 ps I l~oved drilling barge off location. ~/ell is d~ut in producing well. / /FORM 4?0 2-57 PAN AMERICAN PETI OLEUM ( ORPOI kTION Post Office Box 779 Anchorage, Alaska, 99501 September 11, 196/4 RECEIVED SEP 1.. 19t 4 DIVISION OF MINES & MINERAI~. ANCHORAGE Department of Natural Resources Division of Mines and Minerals c/o St. Mary's Residence 8th and L Streets Anchorage, Alaska, F i 1 e: AE P- 702-/~00. I NF RE: Completion Report Cook Inlet lA ~/ell Gentlemen: Attached for your information and file, please find three copies of a well cempletion report for Cook Inlet No. I-A well, along with copies of the well history, directional survey, logs and llthologlcal log. One set of well sample cuttings was furnished to you on July 8, 196~. The well completion report form includes spaces for production test data, including fluids recovered during the test period and the calculated 2ti hour test rate. The attached forms have been completed by showing the 2/~ hour rate at the stabl ized rate of production. Simllarly, the fluids recovered during the test period are shown as the amount of fluid which would have been recovered during the period at the stabilized flowing rate. P~C: cs A t ta chmen ts You rs~l y, A. E. Piper Oistrlct Superintendent CC: Mr. R. M. Morrow, Tulsa /-330 ~f: .... ' "~'~ ' ' ~8) UN..,"ED STATES SUBMIT IN DUPL1 ~; :~ (See other ln- DEPARTMENT Of INTER,Or' structionson GEOLOGICA~SU RVE~ ~;' reverse ~iae) WELL COMPLETION OR RECOM ETION REPORT ;AND LOG * ~. ~=..~E~ ............... o~ ..... ~ .... ~*~-~ .................... ~ ............. "'~: an~ Gas ~ W~LL ~ w~ ~ DRY ~ Other ~ ~ELL OVER ~N ~ACK n~SVR. Other~ ,.. 2. N~ME OF OPERATOR ~'~; ; ' : ~ .' ; Pan A~rlca. Petroleum ~ ~ ~,Cor"ora*~on ; ~: · 3. A~DRESS OF OPERATOR ' i P. 0. Box 779, Anchor~, Alaska 4. LOCATION OF WELL (Re~ort location clearl~ an~ in ac~da~ce witk a~ Form approved. Budget Bar~u Ne. 4_~2-~R855.5. 5. LEA~%DESIG~A~I~N AND" SE~L AOL .17589 -6. z~ Z~OZA~, A~O~Z OR ,~ NAME _ . . ~ ~'l~&" ~" -."' -- -- ~VEY ! RgW, S .H ~ ~ 12,676 R.D., 12,~22' ~D. ~.S' South ; 169q.7' West ~ ~ ~ · . · 1~4. PERMIT NO. : ,DATE-ISSUED oT surface lOCation. I~ , : . I ~ [~ 28-62 : ~ ;' 8-29-62 - - - -6q ~u ,,ne - I 7 "~. ......... .'-- 20. T~AL D~H, MD & ~ I 21. PLU0, BA~ T.D., ~ & ~ ~22 Ir MULTIPLE COMPL., ~ [~. INTERVALS ~ I [~ ¢~ HOW MANY* [; [ DRILLED BY I ~a.a Ray-Neutron,Electrical Lq ~.nt Bond L~;,~p]o Log Hud.~'.U~¢ ~ ' , 29:' ~ LINER RECORD u ~. :~ ::: ]i30. TUB~ 5":' Liner 10,101 ~ 12,4~ KB 18~ None: 8 ~-" .......................................................... x---~ ......... ~-::' ~ ~ ',-~- .~ ..~.. ~:?:. : ,. - .-~:- _ , -_ ~,~ ~ '~ ~ ~ODOO~ION~ ~:~ - .- .... I R~ S I~-~u ~szm IP~DSNr FOR OI~L. : . -~ . [GAS--MCF. 7-11 · ~7-12-64 I ~ I I/2 I~~o~ ~ 128.~'~:-.~ 1020.~ ~,1~", ~_,:_~n I ~ I ~ I ~:,.-~, ~ I ~~. "L.1. i~ ~- I- ' 24-SOOa .A~ " ~ ' O N l l: ' ~.' ~~. o~_~z,a (~_ ~a~.~or.$~.~L~te~, ~¢~.)_ ~_...~ ........... : '" :T':7: "r '~si~"~z~aa~o["~ '~r ' -": ' " ~el.~l History,Directio~ Survey,Elec,L~,G~a aa~;N'eUtron~ Li thol~lcb['L~:-~ 1 Set-~[! samples 36. I~hereby earthy that the forg~'~and at~ched information is complete and eo~e~I ~-gi ~etermined from a ~ / ~ . "--::-:':~': ,'_.' .,,: - :-. -_:,:.- --,.-., . -- . *(See Instructions ~nd Sp=ces lot Addilion~l D=fa;°n Reverse Side):" ~ (See Attached Sheet) -'- INSTRUCTIONS -. ~ · ':- General: Th~ form is desi~ne~ for submitting a complete and correct well 'completiOn rePortiand log on alt':tTpes :of lands~nd lease'-to either a Federal or both, pure, ant to appHc~Me ~.edera! ~d/or State laws. ~d re~.lations.' Amy'neeessa~7 s~ia! in~.~.~ons co/~.'ee~p~n'~ the use '.DE tM~ fo~m ~nd Ll~e nu~ subnJitted, particularly with .regard to local, area, or regional:.procedures and practices, either, are Sho.i~n below or'will be ~ssued by,."or may be obtain~l and/or State-.office. Sec'instructions ~n 'items 22 and 24, and:'83, below. ' regarding separate :rep0kts for s~parate completions. ;-5 ' "~ If ndt' filed p.rior t6.the .time' this sUmmary record is submitted; copies Of ~all!i~ur'ren.tly:_'hvailable logs (drille~; geol0gis~s, sample and"core analysis, all t~es. tidn and pressure ..t&sts, and directional surveys, should be attached heretO; .to.:the ex.tent required by applicable ~FedeY~l and/or Sthte l~ws and regulatior should be listed on this form, see item 35. ' .... ;.: ::: .... {$~m ...4: If'there ar~ no applicable State requirements, locations on Federal or Indian land Should be degcribed in accordance with'~Fedeffa-q requirementS. or' Fed'eral office for specific instructions. . - ....... ' I$¢m 18: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on th~ form and Jn an.-. I~m~ 22 and 24: ~f this well.i~ .complef~l for separate production from more ~han one interval ~one (multipli~',completion)-;' so state in item;[22, anal. in: it~tn :2..! interval, or 'i~ter~ats, top(s), bottom(s)., and .name(s) (if anY) for only the interval reported in item 33. ~Ubmit a separate report (page) o.-n for each additional interval to be separately produced, showing the additional data .pert'merit.to such interval : ' '-:' : .... ' .... I~¢m 29: "SaCks ~ement": Attached supplemental records for. this well should show':the details of any multiple stage.cem_~.~ting and the locati0~ of the ceme- I$~m ]3: Submit a separat~ completion report on this form for each interval to be Separately ~koduced. (See instruction, for items 22 and 24 above,'.) SH0~-ALL IMPORTANT~ 'ZONES OF POROSITY AND CONTENTS THEREOF; CORED I~-ERV~L~'; ~D ALL' Dg~L-STEM TESTS, INCLUDi~O 38. .. . GEOLOGIC DEPTH INTERVAL ~S~ED~ CUSHION USED~ ~IME ~OOL OPEN~ FLOWING AND SHUT-IN PRESSURES~ .AND ~COVERIES . .FORM A~I~N T~P:" BOTTOM DESCRIPTION, ' ~ ' ~ '"" ' ~ : '~ ' '~ :' ~'~ '" ' ~ ~ MEAS. -'' , "7' '' ;: . ?~'~ .... , ~' ~'.' -": , ; ' .') ~ . . ~ . · '-'. ~... .:~ : ......... Ple~se..refer.tc attached 'DST ~ tsesu.]:,,~ n:.~ ....... ... · ... . . ._ . ' of ~or°sity. ant '.contents .hereOf No ~oreS'."~er~ .... · ...... .' ~ . ~, _ ,; ' · ; - .~ ', -.., ' - . ..: ~.., ' . ..-. . ..... ,. .. · .... ,.% ' ; ..,' ' . -.,~ ' · .. . . .... ; ~ ..~ · ...... . ~ ~' . · ~,. · ..., . ~ - ~ , ,, , Form 9-330 (Rev. $-68) · U~ ~'ED STATES systat IS nO~LI DEPARTMEnt NTERiORI (Seeotherin-structlons on OF THE I GEOLOGICAL sUrVEY Ia. 3. i. LOCATION OF WELL (Report location elearlll and in accordance IvitA a~ll Stat~ requirementS)* WELL COMPLETION OR RECOMPLETION REPOT ~ND LOG* +¥PE OF COMPLETION: { WELL OVER EN ,ACK nESVR. Otherl N~ME OF OPERATOR ~t surface t top prod. Interval reported below ~t total depth , 14. PERMIT NO. DATE ISSUED Form approved. Budget Bureau No. 42-R355.5. 5. LEASE DESIGSATION 'AND SEA'AL NO. f.. . 6. i~ INDIA~, ALLOTTEE OR ~a~gl _ _. .- S. ~A~ OR- LEA~E NAME ~ook I~n I et~ s ta t~, ~ ~.- . 107 FI~ AN~ POOL, ~0~ WXL~C~ 15. DX~"'~P'0~ 2°' T~rAL m~'rH' ~O & ~VO I 21' PLUO' RACaC T'~" Mn & ~W~ I 22' IF MULTIPLE COMPL'!' '' HOW MANY* ~ 2~. PaODUCING INTEaYAL(S), OF THIS COMPLETION--~OP, EOTTOM, NAME (~D AND TV;D)* .~:, ~ Perfs: 10,927-47; 5,153-63; 4,075-4,105 ~ :,~-~ CASING RECORD (Report a~ stri~'g~ ~e,~, in' lvell) ..~ TUBING ~t~CORD 26,~T~YPE ELECTRIC AND OTHER LOGS RUN CASING SIZE WEIGHT, LB./FT. DEPTH SET (MD) 29;~: LINER RECORD 31. PERFORATION RECORD (Interval, size ang number) SIZE TOP (MD) BOTTOM (MD) SACKS CEMENT$ I SIZE - I DEPTH-IN*Ei~'~AL ! (MD) 33? ~ PRODUCTION· DATETF-IR-ST_PRO~D-UCTIO-N / PRODUCTION METHOD (Flowing, gas lilt, p~tmptng--gize 'a~d t~lPe o! pltmp) - ~.' { ~El~r~. STATUS (P~od~tOt~ 'o~ August :2.1,1962-blowou~ .................................... -'-. :- t" of Cnn~ Inlet Nn_{ Y~{i Flowing -,. : 1: ,'- Shut-In '~' ~[OF'~ES~ - - ]-HOURS TESTED CHOKE SIZE PROD N. FOR OI~BBL. ~:-~ ~ O*S ~e~. W~R~a,~. · ".I"_0AS~0IL ai~!O 7 28-64I ] - ] 13/8 - l/I > I ·: -:_ .i; ~, - i o~ 5" s{/ :-: :. . -. FLOW'i 24-HOUR RATE ' 950 i 1550 Pkr. . > N.iI 5020 ,i -2/485 Nil . . 34. D~SPO .S!.TION OF. O~$. (.Sold,.uS.6.d !0.r./~el,. ~en~e~l,_e~C..) ......... , I TEST WITNESSED: 3§. LI~ST OF ATTACHMENTS is complete and eorree_t-as determined from all available records 28. I ihereby eertLfy that the foreggj~-~n~d~ attDehed information ~ ~ ~ITLE . Data on Reve,se Side)'~' '- ..... *(See Instructions and Spaces Ear Additional INSTRUCTIONS · General: This form is designed for submitting a complete and correct well completion report and [bg on all!types-bf lands and leases to either a Federal.agency or or both, pursuant to applicable Federal and/or State laws· a~.d regulations, i Any necessary special~ instru~t~0ns concerning the use o£ this form. and tli~-number submitted, particularly with regard to local, area, or regional'procedures and practices, eithe~ are shown b~low or'will,be issued by, or may be obtainda, fr~m, and/or State office. See instructionson items 22 and 24, and 33, below regarding separate reports for separate completions. · If !not filed prior to the time this suniIhary record is submit~i copies..of all .curren.tly avallabl~ log~". (drillersi geologists, sample and core analysis, all t~e~i~electEic/etc~ tion and pressure tests,· and :directional surveys, should be attached heretoi to the extent required., by applicable Federal and/or State laws and regulhtiqns. ~ should be listed on this:form, see item 35. -. ....... ~ " - ....... _ -~ lte. m 4: IfTthere are no applicable ~-'tate requirements, l°cati~ns on Federal or Indian land Shoui~t .be des~¥ibed in accordance with Federal requirem~ht~,: or Federal'office for specific instructiSfls, · - :- . ; .~i ~ ......... - ~ lie. m-J8: Indicate which elevatiou':is u~ied a§ reference (where not otherwise [shOwn) for dePth-measurements given ih' other: spaces on this form~[nd i~_.any att~hmei:' I~emS 22 and 24: If th{s well is '~mplef~l for separate production from' m~o~e than one interval zone (multiple co~pleti6n), So:State in item 22, and[ in':iti~tn 24 sho~ interval, or intervals, top(s), b0tt0m(s): and name(s) (if.afiY:) for Only~the interval reported in item $3. Submit a '.separate report (Page) On tlfi.~-fo '.rj.m,~adequately for each additional interv_a..1 to be separately~ prodUced, showing the addi.ti~,nal data Pertinent to such interval. '--' :~ ' ."~" ~i ':' '*~': "~ item 2~: "Sacks Cement": .Attached supplemental records, fOr .this well should show 'the details of any multiple sf~ge dementing and the location of tl~e cem'%htin~"'~ool. .l~em 33: Submit a separate completion report on this form for each interVil to be separately produced. (See instruction for'items 22 and 24 ibove.-): . - : ~7.I, SUMMARY OF POROUS zoNEs: ' ; ' ? SHO~' ALL IMPORTANT ZONES OF POROSITY AND CONTENTS THEREOF; CORED INTERVALS; AND ALL-DRILL-S~EM ~ESTS, INCLUDING 38. GEOLOGI~ MAR~RS '.~"" DE~H. INTERVAL TESTED,'...CUSHION usED,. TIME' TOOL OPEN,' .FLOWING AND:. SHUT-IN~ ........ PRESSURES, A~. ~ RECOVERIES FORMATION , '. . ', ' · :. :',. ::"', I :: ' ' . :., .. .... ~orm 9-330 '(Rev. 5-~3) U~, (EDSTATES SUBMIT IN DUPLI ,~* E~ h R~OR (See o~her in- ~ DEPARTM T OF t E INTE ~ struetfons on ~ ,.;.~ ~ ~ reverse side) ~ GEOLOGICAL SURVEY ~;;~ ; ; la. WELL COMPLETION OR RECOMpLETION REPOT TYPE.~_QF ..W~LL: ............ Q.~h .....~ ....... ~A~ ..... ~ ........ "' b. TYPE OF COMPLETION: NEW E~ WORK WELL OVER E~ 2. ~AME OF OPERATOR DEEP- [~ PLUG DIFF. EN BACK RESVR. Other! AND LOG * 3. A~DRESS OF OPERATOR 4. LpCATION OF WELL (Report location clearlll and in accordance with any State requi~e~t~)* ~t su~ace ~ ~ . ~t top prod. interval reported below t~ total dep~ ~ ~ 15. ~e~ S~OD~ .... F 1B:-b~ T.V. R~ACH~D Form approved. .., Budget B0xeau No. 42-R855.5. 5. LEAI~E DESlO~JATIO~I -AND. r:_SERIAL NO. .. .. 6. IF I~DIAN, A~LOTTEE OR _~RIB~ NAME . ;~ C~k/ I n!e t.]$ ta_te... ,.'. ] ~' :: -: . HOW MANY* : 24. P~ODUCING INTERVAL(S), OF THIS COMPLETION--TOP, BOTTOM, NAME (MD AND T~D)~ 63; 4,075 "4?05 -.;~ , .; (c , y .,, I , , Perfs: 10,927-/+7; O 26~ T~PE ELECTRIC AND OTHER LOGS RUN CASINO SIZE 29i; SIZE TOP (MD) WEIOHT, LB./FT. LINER RECORD BOTTOM (MD) 31. PERFORATION RECORD (Interval, size and n~mber) SACKS CEMENT* SCREEN: (M~' a2. DEPTH 'IN~ER~AL i (MD) AMO.U~' X~), I~i~D O~ MAT]~RI&~qU*ED ............................. r ......... ' ;~ '" ..- + - ; :- .'. : i , . . : - : '] . ,_ , ugust_21, 1962-b1~ ......................... '"'; ' 1. ~.~-~.~ ~-: . of C~k !nl~t Nh_ f"~ll Flowing ..... ..' ~ . o,~ lot ~s~ - - ' i ~v~s i~i{Efl I CHOKE SIZE I PROD'N. FOR OI~BBL. I .' ~ ~aS MCF' W~a~a~: ~ . , ~..~ ~..,o~ ';" ~50.9 - 227 Ir: .- ...... .... FLOW. i ~INa t~S. I CASlN~ PRESSURE CALCULATED OI~BBL. GAS~MC~.: ~ATER BBE.: 2,so., oo,, 2sl Pkr. . > ] Nil 1~o7,272~,55o~ Nil 34. I)~SPOSITION OF GAS (gold, ~sed for ~ue!, vented, etc.) 35. LiST OF ATTACHMENTS ·EST WITNEs'BEDB~ 36. I hereby certify that the foregoing and attached information is complete and eorredt :A~ determined from all. aVafiab.l~ reeo~,~s. SIGNED *(See Instructions and Spaces for Additional Data'On Reverse ~INSTRUCTIONS ~-n~ral: This form is designed for submitting a complete and correct well 'completion report~and ~og on all~'types, bf lands and leases to either a Federal agency or a State '.both, pursuant to applicable Federal and/or State laws and regulations. Any necessary specia~ instru6tions c~ncerning the use of this form and the. number of Lbmitted, particularly with regard to local, area, or regional'procedures and practices, either are'Shown below or will be issued by, or may be obtaine~' from, the local ~d/or State office. See instructions on items 22 and 24, and 33, below regarding separate rePorts :. for separate completions. ,i.L - ~ inot filed prior to the time this summary record is submitted, copies of all'currently availabl~ logs (driller~, geologists, sample and core analysis, all types~elect~ic, etc~). )n and pressure tests, and 'directional surveys, should be attached hereto, to the extent required, by applicable Federal-and/or State laws and regulati0ns. All att~cf Lould be .listed on this form, see ~t~h 35. ~- .' ~ : ~c ~ ~m 4: Ig.:there are no applicable S,tate requirements, loeati0ns on Federal or Indi~'~nd shoUl~ bp described in accordance with Federal requirem~i. Co~Sult 1~:~' r..Federaiioffice for speCific inStructions. - ..... ::'~ .... ~ ~' ~ ..... ~m:.]8: Indicate which elevation is used as reference (where not other~qise shown) for depth measurements gEVeri'ifi:other spaces on this form-:and i~u~a~y · mi. 22 aad 24: If this well is_complet~i for separate prOduction from m-oke than one interval zone (multiple completion), So,state in ibem 22, and. in-irWin 24 sho~ the ~terVal, or: intervals, top(s),, bottom(s)' and name(s) (if. any) for onlY'the interval relx)rted in item 33. Submit a '~.~eparate report ('page) on this:f6~m,:.adeqUatelyii(~:. ,r each additional interval tO,~be separately produced, showing the additional data:pertinent to such interval. :'" '. : - -. - ~ : ,_~ :!: ~ '~m 2~: ',Sacks Cement": Attached supplemental records-for this welt sli~)uld show: the details of any multiple stage cement'~mg and the location of the cementing" ~ol.' '~m ~: Submit a separate Completion report on this form for each interval to be separatelY, produced. (See instruction for items 22 and 24 above.) . .. : i --, "~.~ . ~ ! ; . ! .... · L, SUMMARy OF POROUS ZONES: ' < .... !'.]-~ . "~ ' , ; SHO~' ALL IMPORTA~ ZONES Or POROSITY AND CONTENTS ~HEREOF; CORED INTERVALS; AND ALL DRILL-S~E~ES~S, INCLUDINa~ 38. GEOLOGIC MARKERS ~ .... '~" ~ DEptH INTERVAL TESTED, ~CUsHION USED, TIME' TOOL OPEN~.~;~oWING AND SHU~-IN PRESSURES, AND RECOVERIES " : ~ ~ ~. FORM~TION .'.TOP~ ", BOTTOM ' ' ' DESCRIPTION, CON~E~TS,. E~. ~ ~ 2.~, ~'~'.'~ -- . TOP'. ~ ' : ....... .: ~'-'._, ' :" ' ~ ' NAME , ~.. .., "' ~ ~ ~ '~ ~[ MEAS. 'DEPTH . ~ ~ ~ : :~: ?~ .'.: , '; ~ -- ..;~~ ~ -. ; ". . ~ ,-,.~ :~:; ~ ..... . · . , .~: % ~ ' .' ..... · ~ , i~ ..... · , ~ . ,, ;,,;,,, , ...... . , : :"~ . .U.S. GOVERNI~ENT PRINTING OFFICE: 1963~0-683636 · . ' ".~.' ! . , ~: ,'...~ ,-:, ~ ~ ; L :.- ~'~i .,.~, .~, ~.. · 21. Plug, Back MD and TVO 12,676 MD - 12,280 TVD 31. Perforation Record (Interval, size and number) 12,300,- 05 with 4 JSPF 12,364 - 78 12,315 - 48 10,927 - 47 " 6,328 - 32 " 6,108 - 12 " 6,206 ' 26 " 5,350 - 55 " 5,153 - 63 5,065 - 85 " 4,075 - 4,105 '" 3,500 - 05 " 3,150 - 55 " 32. Acid, Shot, Fracture, Cement Squeeze, Etc. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 12,387 -TO 12,300 - 05 12,315 - 48, 12,364-78 10,927 - 47 6,328 - 32 6,108 - 12 6,206 - 26 5,3510- 55 3,500 - 05 5,065 - 85 5,15'3 - 63 and 5,065-85 4,07'5 - 4,105 3,150 - 55 Squeezed with 54 sacks cant. Squeezed wi th 50 sacks cmt. Squeezed with 50 sacks cmt. Squeezed with 40 sacks cmt. Squeezed with 50 sacks cmt. Squeezed with 50 sacks cmt. Pumped in 35 cu. ft. diesel, 440 gal. mud acid, 13 gal. Morflo, 50 gal. MCA Squeezed with 50 sacks cmt. Squeezed wi th 200 sacks cmt. Squeezed with 250 sacks Pumped in 64 gal. control fiD and diesel. Acidized with 440 gal. acid. Squeezed with 200 sacks. Squeezed wi th 200 sacks. Squeezed wi th 150 sacks Squeezed with 245 sacks. DIRECTIONAL .SU2VEY COOK INLET lA WELL "R':ECEIVE D .. S.Ep. 1 ~ 1954 .~-~-64 · ..... .. .. .~ ..... ~_~; ..... :.~ :.~j, COMPLETION P.O. ~OX 6803 MOHAWK 4~2206 . . ' ' HOUSTON. TEXAS 77OO5 Cooks Inlet Anchorage NO._ Relief W~ll.. ....... ST,~TE 'Al9ska · -5'666 '$8o2 5949 6008 '6080 · . ~;z4o ..-. 6222 627~ :' 63!0 63 5o E,~5o. 658o 6653 6743 6923 7oo5 7~83 7246 7330, 757o 766o- 7~97 ?972 , ~ooh - 'a03f DEPTH 5579.90 56'65.~6 5801o79 5880.74 5948.63 6007,49 6079.,~. '6138.94 6193 -47 6220.25 6272~-83 6307.53 6347 639~.67 64n.45 6642.99 ~7~8.59 6820 ~17 6898~16 704~.12 7142.61 7201~81 7280.99 7366.64 7588.98 7670.72 7762.99 7809 ~67 7880.%8 7910~97 7942 DRIFT ANGLE ~ 45· 2 O0 -2' 00' 3'~5 4 oo .. 5 oo." 5 30. 7 3o 7. zS.'. 7 ~.~ 7 3o 8 O0 8 Z5 8 3o Zo ~-5' 12 30 13 ~-5 '~.6 15 18 oo ~9 15 '20.00 2O 00. 20 O0 20 O0 19.3O ~9 45. 21 O0 ~ 45 22 00 2~. 45 a~ ~5 21 O0 19 O0 !8 ~5 1.7 4'5 17 ~o D|R ECTION OF DRIFT N N N N N N N N N N N N N · S S S S S s S 'S S S S S S s s s S S S S S S s s S 87°W. 67 W 78 w 65 .w 56 w 58w 64 w 6!.w 7.9 w ~4. w 81 w 79 w 82 w 75w 67 w 65w 67 W 64 w 64 W 6~ w W 63 W 66 w 64 ~'~ 68 W 66 w 69'W 68 .W 69 W 68 w 70 W NORTH 3 .~3 .05; 6.5~ 7.40 8.22 7.92 7.15 3.33 CO-ORDINATES 12.32 12.19 lO 8.63 2.99 .02 3.0!. 5.92 '13.90 26.10 '.l~o .~_z 51.67 63.38' 7.3 .!! 88.13 97.58 108.99 1'22.9 5 138.11 ~5.~2 ~%8.o5 17!.32 ~84.~-8 191.18 200.33 203.92 2O 7.69 2~4.68 . E,AST , . , 14.09 16.72 · , 2O, 36 3o,i.:~ 40 47°::5 5o° :L7 )c) 71, 6i, 29 66,79 7!.oi 73 76~00 100,9 !07, 12 ~, 9 S !. 79, ?'. 0 230 286 ::7 3c)~.." 50 51~..i; 550, ':: o. . OPERATOR [) l~ PT H · -8188 $26L,,. 8307 ./$378 c OM PLET I ON Page '2 P.O. BOX 6803 MOHAWK " HOUSTOI~. TEXAS 77005 ' · · Pan. AmerCe. can Pet~._'_Co._r_p_~.__._LEASF Cooks Inlet · . COUkTY An'chorag. e VENTICAL DEl'TH 8'!98.68 8265..o7 8324,72 8768,91 '8842.96 8887°87 8943.~7' 9o!7o7o 9o8oo97 9 2o ! o 71. 9317.62 94~: ~9 962> .8! 9722.82 977ZoSg 9859 994!.80 9997. ~ zoo59 .?z zoo92.3 ~ ~0Z29.88 Z0308.80 ~oh~4~o3 890~ 8981 9027 9160 9 22 ~ 9350 9470 9600 9672 97~6 ..9789 9892 9943 3.0120 !0!78 !0243 10277 10302 10316 lo3 ~4 zofoo Zo6o8 DRIFT I AN~,LE o'''.,, 19 O0. 20 00. 20 45 20 00. 18 0o- ~7 45. !6 00.. 16 O0 ~ ~5 l~ oo ~ oo ~ oo !3 oo DIRECTION OF DRIFT s.75w s 74 w s74w' s 71 w s73'w s 7¢¢w S76W' s 76 w s'77 W s77w S78W S 7'8W S68W z6 oo I s 73 w !6 ooi. s 74 w -. 16 00 !6 30 .16 00 !7 O0 z6 '15" ~5 45 !5 z5 .I 13 o0 13 O0 s75w s75w s76w s76w s 74:w S75W s76w s 74'w sy8w S79W STATEly= A ~..s_s_]¢s_ ................ CO-ORDINATES SOUTH · .223.22 229.62 233 .Ne 24o.35 2~.75 2~2o87 258.57 261o.65 26~ o~2 26? .~8 269.96 273.33 275.70 279 °42 285.83 289.73 294.'65 3o1.2o 306.78 318.38 .329.00 '354.12 35~.86' 365.!6 369 .og- 376.32 38z.84 385.7i 39o.3~ 392.93 394.69 39~.62 398.37 · ','EAST Ye f'.'5 i I- i602,83 , 62~).72 l' ! l. 687°4o "~ 7o5.i9 , 723 I 73.~ ~ 7~,. oo '~ .7~;. 3 o 789 78~, 795'.~3' 8~S ~9 90~ ,~ 93 7, 990 .,~ · .io~,.~5 !093 .,~ ill~ ,9O l!26'., L,.i !16,3 . 1!64.,24 1173 ~ 1229., ,. I I I 1 I P~O. BOX 6803 -~ ....... ~.¢,-] .... ~ Page 3 . MOHAWK 4-2206 " HOUSTON .TEXAS 77OO~ · . '~,~,aATOR [g,~,~,~.~_e_t~ -uO, p_,.. ..... [EASE ¢ooks,%~!~ ..... -,.~ COUNTY "k .. N O.R~ 1!_¢.£~,' ~.!l .. ...... Anch. o_ra g( ........STATE A ia_ sk~._. ................. rejected ~,~ojectcd' '~,. 'O£PTH' DEI-'TH - ,, ~o888 10867.37. ~3fioo' ~i s 78% -~.11'o34 zo828.79 ~3 '3o '~ s 79 w ~'1i333 llll8.~7 15 4~" .i S 83 W 1!397 1!1~8~48 .14 4~': S 81 W ' 1!621 11398.93 12 ~2z97 .kz98o. ~238~ zaz22.sz..l.i2 ).o' N 8~ w , I !2NO4 12162.69 ! 12 30 N 84 W' i ' I ze477 '12233.961i2 30 '" . . , ~ 84w 12676 ~Z422.24 -. ' ! ASS~D ASS~ ~'.. - ' - I o~os~: z7o9.9~ s 74°,38 ~o w - . ~- 10927 10724.74 13 30 i s 79 W . ... (Top o~ ; ,... perf's). " : .[ ! , o I CO-OR DI NAT ES $-OU TH 422.001 h29.39 J 43o.28, 441.03 ' 4J7,18, 4j9.36 J I I 454.68: . ~8.53 j ; 1 I 42~.63, I ! t- 13 25'. 09 ! !4o5-~4 !42i.'73 · '!470. 1~!S'6~,. _ 1588..~ ~1624.74 1691.67 · i ,, 1300.56 J . aNC 'ONAGE FILE Date State of Alaska Department of Natural Resources DIVISION OF MINES AND MINERALS Petroleum Branch See° 6 . T. 11 N INDIVIDUAL ~-~LL RECORD m. ...... $~___. Mcr idi an Permit No. 2~-62 Issued 8-29-62 Location (Surface) . , Lease No. ~ or ~er ~et~S~_e _ _ Loc. S ud Date~ ~ 2 .... p . .~ Drilling ceased S u sp ended ~~ ~ andoned Completed (F~G,"~'~'-P'~) ~~ IP ___2~ ...... B/D, f Vertical: 12~422' Total Depth 1'_2~_6_76 Gray ~_~PI Cut Gas .... 4:500 .MCF/D, Casing: Size Depth Sx Cmt 30'" 25 20~' 529' 1600 9 5/8" 5363~ 600 5'~ ltne~: 10101-12404 180 GEOL~IC Surface Perf: ps-~, 10~ 927'-10~947" (4h/ft) · TP 1150 psi ,~ 12' -12,385' -1~2~0~ PRODUCT IV~ HORIZONS Depth Contents · WELL STATUS Year Jan Feb M~r_ .~ _ A?___r~ay .... J~n. e__~_J~u_:l_~ Aug Sept Oct Nov ? D~c ~ LOCATION: LEASE NO'* ADL 17589, COOK INLET STATE SURFACE LOCATION 1249.6' N OF S LINE., 2024.9' E.OF W LINE SECTION 6,~TOWNSNIP 11N', RANGE 9W, SEWARD HERIDIAN WELL N ISTORY PAN AM COOK INLET STATE NO, IA WELL 8/27/62 11/30/62 4/23/63 5/20/63 6/8/63 6/12/63 9/28/63- 10123163 11/5/63 4/2'5/64 Spud 4:30 P. M. Ice puShed barge off location November 30, 1962. Well suspended for winter, at 11,549' TDo Operation commenced. Stuck drill string at 12,064' TO. Gas was obtained at surface when fishing tool run to relieve differential sticking of fish. The flow was choked with a 2-inch valve which was one-half open. Plug back and drilled hole from 5,700 to 10,376' and set 7" casing to 10,325' on 8/20/63 Drilled to 12,404'. Set 5" liner 10,101' - 12,404' on 9/19/63. Drilled to 12,477'. Pumped 40,000 barrels salt water with batches of tracer materials, acid, and a friction reducing additive into open hole section 12,404.- 12,477'. Blowout died 8:00 A. N. on 10/23/63. Suspended well for winter. Operations commenced. Clean out to T0'12,477'. Ran DST of open hole 12,404-12,477' as follows: · . Date: Tool opened June 11, 1964. Packer set at 12,351'. Full water cushion.. Recovered water cushion and turned prodUction into test barge. Flowed on 1/4" choke 'for 2 hours at rate of 75 bbls. of fluid per hour with 1100 psi flowing surface pressure. 0ii content not measured. Flowed on 3/8" choke for 15 hours, shut in I hour, re- opened on 3/8'i:' 'choke 'and flowed for 27 hours. RecoVered total of 66 bbls.'oil, 39° APl gravity, and 2182 bbls. of water testing 18,O00 to 20,000 ppm NaCl. Flowing surface pressures ranged from 200 psi to 500 psi; EqulValent pro- duction rates are 34.6 bbls. of oil and '1250 bbls. of water per day. Estimated gas production was 192 'MCF per day re- sulting in a GOR of 5500 cu. ft. per barrel. -2- The following data was obtained from the bottom hole pressure recorder: · Initial hydrostatic pressure Initial flowing pressure Flowing pressure after I5 hours Shut-in pressure after I hour shut in Flowlng pressure after 16 hours of second flow period 9672 ps i 9115 psi 6225 ,ps i. 8546 psi 6752 ps i 7/3/64 7/12/64 Note: Clock stopped after 16 hours of the second flow period had elapsed. . . This test was witnessed by Messrs. T. R. Harshall and Karl ¥onderAhe. · . Tested intervals 12,315-/48, 12,364-78, well flowed 64 hours 55 minutes on 1/4" 'choke 'producing 29 bbls. of oil (40.5° gravity)'and~133 bbls. of'water. Gas pro- duction waS 'too'small to'measure. Equivalent producing rates are 11 bbls. of oil and 49 bbls. of water per day. Production tested interval 10,927-47 with following results: Surface Hours Surface Dai'ly Production Rate Choke Produced Pressure. (psi) ,0_il (bbls.,,L)' Gas (MCI=) GO___~R 1/4" 2 2200 187 1018 5400 3/8" 6 1200 281 1200 4260 1/2'i' 8 1/4 1000 374.4 2970' 7924 The gravity of the oil produced was 56° APl. During this test some l iqulds we~.e lost out the gas flare l lne. · . This test was witnessed by Messrs. T. R. Marshall and Karl ¥onderAhe. 7/14/64 Second test waS conducted in 10,927-47' interval with the following results: ~ Surface Hours Surface 011 Average Da i.ly Rate Choke Produced Pressure (l~S.i) Produced (b.b. ls)Ot1~)~-) GO__~R 1/4" 3-I/2 2125 '41.0 281 2118 7540 3/8" 5-1/2 1650 101.4 442 351o 7940 I/2" 6-1/4 1175 144.3 554 4700 8480 Average gravity of produced oil-was 56.4° APl. The following data was obtained from the bottom hole pressure recorder: Initlal hydrostatic pressure Initial shut-in pressure (1' Hour) Inl rial -flowing pressure ~(1/4':' choke) iftnal flowing pressure (1/2" choke) Final shut-in pressure (6-1/4 hours) Final hydrostatic pressure Mr. Karl VonderAhe witnessed this test. 8832 psi 5236 ps i ~8 I5 ,ps i 2815. psi 5160 ,ps i 8832 ps i //, 7/27/64 7~28~64 · . Tested interval 6,206,'26~ Recovered 2240' drilling mud. IHP 3985, ISIP not readable, IFP 2015, FFP 2015, FSlP 2736, FHP 3985. Tested interval 5065- 85. no flow. Tested interval 5153-63 with following results: Surface Hours Surface Gas F Iow Choke Produced Pressure (psi) Rat~e~ HCF/O , 1'/8" 3 2150 407 1/4':' 2 1'800 2725 3/8" 4-1/2 1325 5500 No liquids were recovered. · . The following data was obtained from the bottom hole pressure re cor de r: Initial hydrostatic pressure Initial' shut-in pressure (1-1/4. hours) Initial flowing pressure Final flowing pressure on 1/8"' choke Final flowlng pressure on 1/4" choke Final' flowing pressure on 3/8':' choke Final shut-in pressure (2 hours) Final hydrostatic pressure 3350 ps i 24/48 psi 1828 ps 1 2432 ps i 2281 psi 1969 ps i 2463 psi 3333 ps i Tested interval 4075 - 4105 with following results: Surface Hours Choke Produced Surface Gas Flow .Pres,s. ure (ps, i) Rate~,. MCF/D 3/8" 1 950 5020 1/4" 1 1550 2485 No 1 iquids were recovered. The following data was obtained from the bottom hole pressure recorder: Initial hydrostatic pressure Initial shut-in pressure (1 hour) Initial 'flowing pressure Final flowing pressure Final shut-in pressure (2 hours) Final hydrostatic pressure 2642 ps i 1899 psi 1684 ps i 1827 ps i 1875 ps i 2642 ps i -3- /2.-, 7/29/64 8/2/64 Second test conducted in 4,075-4,105' interval with following results: Surface Hours Surface Gas Flow Choke Produced Pressure (psi) Rate MCF/O 1/2" 7 940 4575 3/8" 2-1/4 990 3290 1/4. 2-3/4 1575 1509 No liquids were recovered. The following data was obtained from the bottom hole pressure recorder. Initial hydrostatic pressure Initial shut-in pressure (1 hour) Initial flowing pressure Final flowing pressure Final shut-in pressure (1 hour) Final hydrostatic pressure 2740 ps i 1850 ps i 1580 ps i 1815 ps i 1850 psi 2600 ps i Moved drilling barge off location, Well is shut in producing well. LOCATION: LEASE NO, ADL 17589, COOK INLET STATE SURFACE LOCATION 1249.6' N OF S LINE., 2024°9' E OF W LINE SECTION 6,_TO¥/NSHIP llN~ RANGE 9W, SEWARD MERIDIAN · WELL HISTORY PAN AM COOK INLET STATE NO. lA WELL 8/27/62 11/30/62 4/23/63. 5/20/63 6/8/63 6/12/63 9/28/63- 10/23/63 11/5/63 4/25/64 Spud 4:30 P. M. Ice pushed barge off location November 30, 1962. Well suspended for winter, at 11,549' Operation commenced. Stuck drill string at 12,064' TD. l~as was obtained at surface when fishing tool run to relieve differential sticking of fish. The flow was choked with a 2-inch valve which was one.-half open. · Plug back and drilled hole from 5,700 to 10,376' and set' 7" casing to 10,325' on 8/20/63 Drilled to 12 404' Set 5" liner lO, lOl' - 12,404' on 9/19/63. l~rill~d to 12,477'. Pumped 40,000 barrels salt water with batches of tracer materials, acid, and a friction reducing additive into open hole section 12,404.- 12,477'. Blowout died 8:00 A. M. on 10/23/63. Suspended well for. winter. Operations' comn~enced. Clean out to TD'12,477'. Ran DST of open hole 12,404-12,477' as follows: . . Date: Tool opened June II, 1964. Packer set at 12,351'. Full water cushion.. RecoVered water cushion and turned prodUcti_on into test barge. Flowed on 1/4" choke 'for 2 hours at rate of 75 bbls. of fluid per hour with 1100 psi flowing surface pressure. Oil content not measured. Flowed on'3/8" choice for 15 hours, shut in 1 hour, re- opened on 3/8" 'choke 'and flowed for 27 hours. Recovered total of 66 bbls.'oi1, 39° APl gravity, and 2182 bbls. of water testing ~to ~ppm NaC1. Flowing surface pressures ranged from 200 psi to 500 psi; Equivalent pro- duction rates are 34.6 bbls. of oil and'1250 bbls. of water per day. Estimated gas production was 192'MCF per day re- sulting in a CiOR of 5500 cu. fto per barrel. -2- The following data was obtained from the bottom hole pressure recorder: Initial' hYdrostatic pressure Initial flowing pressure Flowing pressure after 1:5. hours Sliut-in pressure after 1 hour shut in Flowing pressure after 16 hours of second flow.period 9672 ps i 9115 psi 6225 .psi. 8546 ps i 6752 ps i 7/3/64 7/12/64 '7/14/64 Note: Clocl~ stopped after 16 hours of the second flow period had elapsed.. · . -This ~:est was'Witnessed by MesSrs. T. R. Marshall and Karl VonderAhe. · . Tested intervals 12,315-48, 12,.364-78, well flowed 64 hodrs 55 minutes, on 1/4"'choke"producing 29 bbls. of oil (40.5° gravity) 'and.133 bbls. of' water. Gas pro- duction waS'too'small to 'measure. Equivalent producing rates are 11 bbls. of oil 'and 49 bbls. of water per day. · . Production tested interval 1'0,927-47 with following results: Surface Hours Surface Dai'ly Production Rate Choke Produced Pressure~_[.p.s~i) _O~il__~bJ~s~_)_ G_,a~s_~) .G_OR_ 1/4" 2 2200 ', 187 1018 5400 3/8" 6 1200 281 -.-1200 4260 1/2'" 8 1/4 1000 ,~ 374.4 2970 7924 The gravity of the oll produced was 56° APl. During this test s(~me liquids were lost out the 9as flare line. . . This test was witnessed by Messrs. T. R. Marshall and Karl VohderAhe. Secdnd test was conducted in 10,927-47, interval with the following results: Surface Hours Surface 0 i 1 Chol<e Produced Pressure__(_p_s_~i) Produced ,[b_b l_~s)~__'~.l_.(_~12_ l__~.~G-a~~) ~GO~R i/4" : 3-1'/2 2125 '41'.0 281 2118 7540 3/8" 5-1/2 1'650 101.4 442 3510 7940 i/2,' 6-1//+ 1175 144.3 554 4700 8/~80 ~ . · Average gravity of produced oil 'was 56°4° APl. The following data was obtained fromm the bottom hole pressure recorder: Initial hydrostatic pressure Initial shut-in pressure (1 Hour) Initi'al 'flowing pressure '(1/4" choke) IT. inal flowing pressure (1/2" choP, e) Final' shut-in pressure (6-I/4 hours) Final hy. drOstatic pressure Mr. Karl VonderAhe witnessed this test.. 8832 psi 5236 ps i 481'5 .ps i 2815, psi 5160 ,psi 8832. ps i 7/27/64 7/28/64 -. Tested interval 6,206,-26: Recovered 2240' drilling mud. IHP 3985, ISIP not readable, IFP 2015, FFP 20'15, FSIP 2736, FHP 3985, Tested interVal 5065- 8'5, no flow, . . Tested interval 5153'63 with following results: SUrface Hours Surface Gas F low Choke Produced Pres su r ~e_ _( p~ s_ _i ) 1'/8" 3 2150 407 1/4'? 2 1'800 ' 2725 3/8'_' .. 4-1/2. 1325 5500 No liquids were recovered.. . . The following data was obtained from the bottom hole pressure recorder Initial hydrostatic pressure Initial' shut-in pressure (1-1/4. hours) tniti'al flowing pressure Final fl'owing pressure on 1/8" choke Final flowing pressure on 1/4'.' choke Final flowing pressure on 3/8'.' choke Final shut-in pressure (2 hours) Final hydrostatic pressure 3350 ps i 2448 ps i 1828 psi 2432 ps i 228'I ps i 1969 psi 2463 ps i 3333 ps i Tested interval 4075 - ~105 with following results: Surface Hours Choke Produced 3/8" 1 950 1/4" I 1550 Surface Gas Flow Pressure .~si) Rate, MCF/D 5020 2485 No liquids were recovered. . The following data was obtained from the bottom hole pressure recorder: ~ Initial hydrostatic pressure Initial shut-in pressure (1 hour) Initi'al fl°wing pressure Final flowing pressure Final shut-in pressure (2 hours) Final hydrostatic pressure 2642 ps i 1899 ps i 1684 ps i 1827 ps i 1875 ps i 2642 ps i -3- 7~29/64 8/2/64 Second test conduCted in 4,075-4,105' interval with following results: .. Surface Hours Surface Gas Flow ChOke Produced .Pres s u re__(j~_s~ Rate MCF/D I/2" 7 940 4575 3/8'~' 2-I/4 990 3290 1/4'.' 2-3/4 1575 1509 No liquids were recovered. The followin~! data was-obtained from the bottom hole pressure re co r de r. ' Initial hydrostatic pressure Initial shut-in pressure (1 hour) Initial flowing pressure Final .flowing pressure Final shut-in pressure (1 hour). Final hydrostatic pressure 2740 ps i 185o ps i 158o psi 1815 ps i' 1850 ps i 2600 ps i Moved drilling barge off location'. Well is shut in producing wel 1, . ~\q\%\O~ ~- ~. , 'OPERi~70R P~ American Pet. Co~p..~ID~E ·Cooks Inlet FIELD COMPLETION Page.1 P.O. BOX 68,03 MONAwK HOUSTON. TEXAS ?7005 lEAS ~ R lED VlE R'l'li~ A t,, DRIFT DIRECTION DEATH OIEPTH ANGLlE OF DRIFT EE8o [' 557~,9o 2 O0 -2 O0 3'15 4. oo ..500. 5 3o 7 30 7 '7 15 ? 3o 8 O0 8 15 8 15 8 3O ~o ~5 !2 30 i3 15 16 15 '18 O0 19 15 '20 O0 19 45 20 O0 20 O0 2O 00 19.3o 3.9.45 21 00 a~ 45 22 O0 m. 45 a~ ~5 21 O0 !9 O0 ~8 ~5 ~ 4~ 17 30 COUNTY Anchorage N 87°W N 75W N67W N78W ~ 65.w ~ 56w ~ 58w N 59W N'64 W N 61.W N79W ~84w N 81W N ?9W 882W S75W S69W S67W $65W S67W $64W $ Id' S65W S66W S66W s6~w S 6oW s 63'w S66W s$4.w s68w s66w s69w s67w S 68.W s 69W sg8w s70w NO..~ Relief, ~__~e.l! ......... ST,~TE Alaska __ CO.ORDI NATE.~ 3.13 .05 6.53' 7'4°I 8.22 7.92 ?.~5 3.33 12.32 12.19 1~.~8 ~o.84 10.26 8.63 2.99 .02 3.01 5.9~ 13.90 26.10 51.67. 63.38 7.3.11 88.13 97.58 108.99 122.95 138.11 ~5.~ 171.32 ~84.~8 191.18 200.33 203.92 20 7 · 69 z~4.68 5666 ~755 "5'802 5881 6008 6080 -61~o 6195 ,' 6222 6275 6310 63 50 63 80 6395 6475 f.55o. 6~8o 6653 6923 7oo5 '7o75 7~8~- 'Tz4~ 7330. 74z~ '7%z5 757o 7660 ~84'7 7897- 7972 , 8oo4 8037' 5665.86 5754-82 5801.79' ~a~o.7~ 5948.03 6007 -49 6079.22 6138.94 6193 -47 6220.25 62?2,83 6307.53 6347.14 6370.83- 6391.67 6543.71 6572.9-1 6642.99 6728.59 6820.17 6898.16 70~.~2 7142.61 7201.81 728O .99 7366.64 7463.73 7505.53 75'8.8.98 767o.72 7762.99 78O9.67 788o.58 79!o.97 Ze~2.4o 0007.25 / . I · . 1l, .09 , 19.3 5 1. i '20. :36 ~ 23..56 1. 27.06 3O ~o,,?~ 47.!9 56 ?~' 61.29 66.79 7!.oI 76.00 85.97 100 '9 ! !07.15 !2 ~ 9 6 ! 79 · 7O eoS.~ 230.75 2 ~ 6.3 7 .3o5.73 3 9 ~ · ~ o 439 ('~ ~' ]'. 502.34 515 'YSo 56c ' 7 579 ,,:, 8 7 6 5 4 3 4 5 6 7 8 910 2 3 4 5 6 7 8 910 / ~00 ?©~ 00 0 4 5 6 7 8 910 · : ? 2 6 "'/ 8 9 10 2 3 4 5 6 8 9 10 2 3 4 5 6 7 8 9 10 ~ 6 7 13 9 10 /oo.. ~mo WELL RECORD INVENTORY Fi e l d:North Cook Inlet Locatt.on _. ~_!IN-R9W, Sec_, 6, Ol~t~.&~e~. & We~ 1 Name: Drilling Pelt t: Survey Plat: : .AbfOCO 'Production Co, .... ' ...... mi ii · i · m ' mm .... C I ..State. 1758.9,../~I-A Monthly Reports (P-3): Completi on Report (P~7) :' Well History: ~, Individual Well Record Other: Mi s ~ 1.1 aneous: le 2. 3. 4. 5. 6. 7. 8. ~viation Survey(s): 9, Well Logs: _(1) GR (2) ~.s _(4) NEUT ( 5 ) (7} (8) (_10) Total Pages: i i i ~1 mill W , No,. Pages m ii UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Form approved. Budget Bureau No. 42-R356~5. .A.o OmcE .... &n._q_h_.o_.r_.a_g.e= L~. NUM.£. __AI)_L__I_Z.5_~9. ............ UH,T Cook_In'l er ._St ate__!_-_A__ LESSEE'S MONTHLY REPORT OF OPERATIONS State ..... A!a~_ka ..... ~ ........... Co~ty _.~99_k____~n__!_~_£___B__a__s_.~__n__. ?ield ....... _~._~__l__d_.c._a_.t.. ............................................. The followi~ is a correct report of operations and prod~etio~ (i~el~di~ drillin~ and prod~ci~ 2l~ent's address ............ B_o_,__~_7__~_ ......................................... Company_ ~_u__m__ Corp_. ........................ .... ....................... ...... ..................... Pl~or~e .................... B._.R___8__-__6_.~O..1._ ............................................. ./l~eut's title I)tstf,~tt Superintendent SEC. AND sw z/4 Sw 1/4 Sec. 6 PBD 12. ). Pao~uos o~1 BARRELS OF OIL :ed and SI GRAVITY P Cu. FT. oF Gas (In thousands) oducer. a~achmen~ (~ALLONS OF (}ASOLENR RECOVERRD BARRRL8 OF WA~Ra (If none, so stats) None DIV: REMARKS (I! drilll~, depth; if shut down, oauae; date and result o! test for saaoltne content o! gas) ECEIVED SEP 1 4 t964 ;ION OF MINES & MINERAL~ ANCHORAGE No?E.--There were .......... 1~0 ........................ runs or sales of oil; .................. !!_O. ........................ M cu. fi. of gas sold; ................ _~_._Q ........................ runs or sales of gasoline during the month. (Write "no" where applicable.) No~,.--Report on this form is required for each calendar month, regardless of the status of operations, and mus~ be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9-~29 16--25766-9 U.S. GOVERNMENT PRINTING OFFICE (January 1950) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY ~ Form approved. ~ Budget Bureau 1~o. 42-R356.5. ~. omc~ ..~_n..c...h_o_.r__a__g_e. ~, Nu,~.~, .___._&_D._.L.._!.7._5..8_~. ........ ,,,, L4___ LESSEE'S MONTHLY REPORT OF OPERATIONS The followi~ff is a correct report of operation.s and prod~ction. (incl~din.g_ drillin.~ an.d prodz~cin~ wells) for tl~e montT~ of ....... ~ ...................... ~__up.~___, 19.(~:$_, ............................................................................. Jffen.t's address ,_ ................. ~_.___~_.~_~__o__x____7__7__9__ .................. Compan.y ___~A__n__~.a~____~.e_troleum Corp. Ph, on, e .................................... _B__~_.8_.-__(?__4__O._i_ .......................... e'" .~;~.,.. Distr i~ Suoerintendent ,//~ n,t o ,,,, ......................................................... SEc. AND ......... ~ OF ~ TWP. RANGE WE~J~ D~ CU. FT. or GAs GALLONS O~' BA~aZt~ O* REMARKS NO. PROnO0eD BARRE~ Or O~ GRAVITY (~ thomaS) OASOL~E WATER (~ (If dry, d~th; if shut down, once; ~ECOVERED no~o, SO ~ate) date ~d r~t of t~t for g~o~e tenet SW 1/4 llN' 9W lA 0 0 . 0 0 ' 0 None sw ~/4 Sec. 6 TD iZ,6~'6~. PB]) 1Z 385~. Recovered fish and raniDST of, cpen hole interval 12,404-, ~7. Deepene~ we:l to IZ,~76~ Ran E log 12,676~ to 12,~11~. Ran GRN 112,676~ to 11,900~. Set Model K etaiher 12,~85'. Squeezed ~ith 54 sx (;lass A ])lus 1% ~talad-9. Perforated 12,300~ to I2 305) w/4JSP]r, and squeezer below Madel K at 12,250~ w/50 sx Class A plus 1% ~tala~[-9' ~plus 1% Sodium Bo].~e. Milled Mr;del K ard drille~ out cement. Perforati~d I ;,36,~~ - I2,3~8* and 12,315~ - i2,348~ xr/4 JSP]'. CO tC 12,385~. ' No?~..~There were ..... , ...... __n__o_ ..................... runs or sales of oil; ............. _lq=__O. ............................. M cu. ft. of gas sold; ................... __n_.o_ .......................runs or sales of gasoline during the month. (Write "no" where applicable.) No~E.~Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. 1950) 16--25706-9 u.S. COYERNMENT PRINTIHa OFFICI* FORM 470 2-57 PAN AMEmCAN PETROLEUM C0P. POP. ATION Box 779 Anchorage, Alaska 99501 July 8, 1964 Mr. Thomas R. Marshall, Jr. State of Alaska Department of Natural Resources Division of Mines and Minerals c/o St. Mary's Residence Eighth Avenue and L Street- Anchorage, Alaska 99501 Dear Sir: Transmitted herewith are washed ditch samples from the following Pan American wells: ¢ook. Lnlet~-:_~cate No, !_,_A.- from 12,477 feet to .... ~2,676 fe~t' Romig Park Inc. No. 1 well - from 100 feet to 11,560 feet. TD of this well was 11,566 feet. These samples are being transmitted in accordance with the State Oil and Gas Regulations. We request that they be kept confidential for a period of 2 years, as provided in the above- mentioned RegulatiOns. CLC:ln Ver~y truly yours~ R. W. Craig // District ~~tion Superintendent District Superintendent RECEIVED JUL 1 3 DIVISION OF MINES & MINERALS ANCHORAGE PANAMEmCAN PETI OLEUM COI POP-ATION P. O. Box 779 Anchorage, Alaska June 19, 1964 File: AEP-545-400.1 Re: Abandonment Cook Inlet #1 By Testing Cook Inlet #lA State of Alaska Department of Natural Resources Division of Mines and Minerals c/o St. Mary's Residence 8th and L Street Anchorage, Alaska Gentlemen: RECEIV[:D JUN 2 z 19 ,I DIVISION OF MINE5 & MINFRAL$ ANCHORAGE After studying your letter of May 28, we agree with your suggestion that we perform a test for communication between Cook Inlet No. 1 and No. 1-A at a Shallower depth. Since you do not have the backlog of well history and technical data on this well our files afford us, we have taken the liberty of making minor adjustments in your procedUre for mechanical purposes only. Since the 9 5/8" casing set at 5,489' was cemented with 600 sx, and since we feel that 75 percent fill-up is the most that could~be e~ected, we believe the top of cement behind the 9 5/8" casing could not beabove 3,800'. To increase the possibility of testing in a sound primary cement Job, we will perforate the zone 4,075' to 4,108~ (correlates to 4,013' to 4,045' in the No. 1), which is in the same basic group of sands as that suggested in your letter, 3,780' to 3,932' correlating to 3,740' to 3,892' in the No. 1. Your points concerning remedial cement squeezes between casing strings are well taken and will be performed prior to testing. We plan to: dtm;bln (1) Block squeeze over the interval 5,540' - 45 through perforations.' '(2) Perforate 4,600' 05, 3,500' - 05, and Circulate cement in the 9 5/8" - 7" annulus. (3) Blodk the perforations 3,500' - 05. (4) Perforate 4,074' - 4,106' and DST these perforations. Thank you for your help in this matter. Yours A. E. Piper District Superintendent UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY ~ ~ Form approved, l~~ Budget Bureau No. 42-R856.5. ....,, omc~ ...... ~__c_~.o_ ~..a_g.e. ....... L~,s. ,u~.~..~D_L.__l_7_5_8_9 ....... u.n- __ _c:._ .o__q_k___ ~.1_ _e__t._ _S__t_ .a._.t_.e..__l__A__._ ~V~S~ON O~ ~S S, ^~c~ESa3EE'S MONTHLY REPORT OF OPERATIONS The followinff is a correct report of operations and production (inch~dinff dritlin~ and prod~cin~ wells) for tI~e mont]~ of ................................. _M___a_g_, 19._6__4_., ............................................................................. /1fleet's address .......... ?_.____o_.__~_o__x___7__7_?_ ........................... ................................ . .... A~_~_o_~___A_~__~_ ~ ~_ .................. s~ne~ __~~~- ..................... ~o~e ......................... _~__R____S_:___6_~_0_~ ..................................... ~ent"~~s tit~e ....... SEC.~ O~'ANDI~ r~WP. RANGE WELL~o, Pao'.c~..D~ea BARE,~ Off O~ ORA,TY i CU..__ ---- ---- .F~' OF OAS~ECOVEREDOALLONS (In thou~ands~ GASO~E WA~ER (~ (If ~U~, d~; ~ ~hut dowa, oa~e; state) date ~d r~t of trot for g~ol~e none, ~o 1/4 11~ 9W lA 0 0 ~ 0 0 0 None ~/~ ~ , -. 6 I 1Z, 4'?7. Fis hing I 1 SW SW Sec TD No?-,.--There were ................ ~_o___j ............... runs or sales o~ oli; ................... __1)__O_ ...................... M cu. ft. of gas sold; ..................... _I~_Q ................... runs or sales of gasoline during the month. (Write "no" where applicable.) No~.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. For~n 9-~29 (January 1950) ~6--25766-9 u.s. ~ow~,~,~ ~,m'nN~ o~r~c,' Box 779 Cook Zolet Coo~ Inlet Gentiemen: ~ el~ct:ric loss on the Cwo yells fhow a sand body :Ln No. X-A between 3780' m~d 3932' Chat coFre~i.te$ vAch one :in No. I bat~aa 37400 and 3892' v~th about a ten foot sha,l~ ~ near the middle. A teat aC Chis vould prove lack of ccmsnuni~t~ up the Imle and vould alao prove th,it the shallover u~s Zha.ve no~ ~n p-ra~~ up by the ~t Co an extent that vould be .h~zargoua .Co ~tu~ drillin~ op~raCiona. To iosure a euccoas£ul bast, a squeeze Job betr~aen sCri~ ~ a ~inc 50 f~oC or so b~l~ ~ld ~ VeL7 truly, K.L. V~mder~e Anchorage, Tou~ teeter 4/20/64 Cook Inlac ~I-A lsl, aase ~t plaaa for Che ope-ra~us Lu the ~I-A veil prov- that ~ ~I uell ~ properly shut off. Thomas R. Karstmll, Jr. FORM 4'70 2.57 PANAMEmCAN PETI OLEUM CORPOP. ATION P. O. Box 779 Anchorage, Alaska April 20, 1964 File: AEP- 332-WF Re: 1964 Operations Cook Inlet No. IA Section 6, TllN, R9~, S.M. State of Alaska Division of Mines and Minerals c/o St. MarY's' Residence 8th and L Street Anchorage, Alaska Attention: Mr. T. R. MarShall, Jr. Gentlemen: This is to advise that Pan American intends to resume operations on the subject well on or about May 27, 1964. Plans are the same as were set out in our Application to Suspend dated November 4, 1963 and approved on November 6, 1963, by your Mr. Tom R. Marshall, Jr. The same drilling equipment and blowout prevention equipment will be used. Yours very J~, A. E. Piper District Superintendent dis:lng RECEIVED' APR 211965 Petroleu'm Branch Division of Mines and /~inerals Alar~a Dept. of Natural. Re,~our~e~ UNITED STATES DEPARTMENT~ OF THE INTERIOR GEOLOGICAL SURVEY Form approved. Budget Bureau No. 42-R356.5. ,.~ OmCE _.._A___n._c__h__o.._r_.a_g.~. .......... LEASE NUMBER ___ ~Di~ -1_?-58-9 ....... LESSEE'S MONTHLY REPORT OF OPERATIONS The followin~ is a correct report of operations and production (incl~di~ dritli~ al~d prod~cln~ J~e~t's address ....... ~ ....~ ....~_~__7_~_9_ .............................. Company . ~~_._~9.rp. Phone ....................... -~-~--~-~-~ ...................... ~ ................ J~e~t' ~ ' ~ ~Vs title ~~~~pe~te~d~t ..... SEC. AND ~o~ ~ 1/4 ~W 1/4 ?i~.~c. 6 .rD 12, 47 No. lA ~de -- cern duri BARBEL8 Or OIL snt plug a: ag Deceml ORAVITY 0 ,8! r~ Cu. FT. OF GAS (In thousands) 0. Initial 963. (~ALLONS OF OASOLINE RECOVERED report a BARREL8 OF none, so state) None rte r well REMARKS (If drliUn~, depth; if shut down, oause; date and result Of te~t for ga~oliae content o! gas) operations !~lo~E.--There were ................ _rl~ ................. runs or sales of oil; ............ ~O .............................. M cu. £(;. of gas sold; .......... ILO .......................... runs or sales of gasoline during the month. (Write "no" where applicable.) /'(OTE.--Report on ~his form is required for each calendar month, regardless of the status of operations, and must be filed in ~b;~i~:a!o with the supervisor by the 6th of the succeeding month, unless otherwise direcged by ghe supervisor. L' ~:, ;::h ;~ -¢,~9 16~25766-9 U. 5. GOVERNMENT PRINTING OFFICE · ,, · , ,VJL...X.,,,.r'~ "l S -- ~ r~,.,iL.I..I. JIYI k..,k./Krk,.,/K/'~ ! U.S.^. ~x INI~^COM?^N¥ COM~UNIC^IION ~ Hr'. T. R. H~shall, Jr., ~ of A~ska LOC^T~ON Aacho~se / ~/~JECT MESSAOE FILE TTansm/tt=d lmee~th is 1 ~opy emch o£ the ~811 ~stor~es J~or Pan Americiu*s Cook Cook Inlat 1~o. I-A uolls. Esch H~tory coat. Ins the foll~!ng: LOCATION ~ 779, ~chor&~ Alasl~ 99501 REPLY t~c~ipt; acknovled~d. ADDRESSEE: RETAIN THIS COPY Box 779 :~ C~ok Inle~ Pan American l~Zrolmm ~orpora~ion saspemJe~ ~n ~ .bo~ wll o~ 1115/63. file ~s ~. Harshall, J~. l~ecro leun Geolostst: UNITED STATES DEPARTMENT' OF THE INTERIOR GEOLOGICAL SURVEY Form approved. Budget Bureau No. 42-R356.5. ~ u,~,~, _.~_.~.!~. ............. u,,~ .... ~_. ~3.~_~_._~.~.~_~_~___!~ LESSEE'S MONTHLY REPORT OF OPERATIONS The follOugn~ is a correct report of operations and production (incl~di~ff drillin~ a~d producinff wells) for tke mo~tk of ....... ~9_V~_~_L ................. ,19__~, ................................................................................ ~e~t'~ ~aa,e~ ........ ~,__:P,:,~__!/~ ................................. eo~v _~..___.~~.~__~~~..~2.~.._ ~_9_b~:~_~_~._A !~_~_ ................................... ....................... ........ ........................... Phone ..................~ .... ~_~.$~_6_~0_~____: ..................................... J~e~t' s t~tle .~.~.9.~.._~_~.~.~.~9.~ ........ sw sw 1/4 Sec. 6 TD 12 pres Packer BARRELS Or OIL ] GRAVITY 0 0 ~d 11-5-63, Fi S~t cemi~nt p cement ab ~ve t, Cu. F~. or GAs (In thousands) h left in ug in 5" 1 2,675'. (]ALLONS Or QASOLINE I~ ie. COVERlrD hole 8,31 iner fr~ BARREL8 OF WA~.I~ (If none, so state) No~e i4' to lC 7,710' REMARKS (I! drlllini:, de, th; if shut down, cause; date and r~ult o! t~t for gasoline content o! ,406' w~ile to 7,980'o No?E.--There were ............. ~_ .................... runs or sales of oil; ........ _~_0_ ................................. M cu. ft. of gas sold; ........... -~-~: ............................. runs or sales of gasoline during the month. (Write "no" where applicable.) -No~r..~Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the sUcceeding month, unless otherwise directed by the supervisor. :!~:i. )tm 9-829 ~nuary 1950) 16--25766-9 u.s. ~OVr~S~I~IT Pm,~s~ o~lc~ UNITED STATES DEPARTMENT' OF THE INTERIOR GEOLOGICAL SURVEY ;' .~-~ Form approved. ( ~ ~ Budget Bureau No. 42-R356.5. LA,.~ OFFICE ..... _ .A_ .n_ _c_ _h_ _o_ _r.p_~ .e ........... u.rr __Cook._/nJ.e.t-.$_r-am---]A-- LESSEE'S MONTHLY REPORT OF OPERATIONS The followi~ is a correct report of operations and prod~ctio~ (incl~di~ drilli~ a~d producin~ wells) for t]~e montT~ J~e~t's adgress Anchorage, A las ka S~ed ___~~~_-: ....................... .................................... .............................. ...... ................................................................................... S~IC. AND I ro~o sw 1/4111~ SW 1/4I' Sec.6 ] We'll S att PRon~ol~n 0 ~ded , '1 GRAVITY B&RR~L8 OF 01~ lur lng monlh.0 Cu. F~. or GAs (In thousands) 0 na I repor (]ALLONS OF GASOLINE ~ECOVEEED until c BARREI~ 01~ none, so state) None hange of REMARKS (If drllUng, depth; if ~hut down, oause; date and result of test for gasoliae oontent of well status RECEIVED No~E.--There were ............. ~_0_ ..................... runs or sales of oil; ................... _N_.0_ ....................... M cu. ft. or gas sold; ........... ~_0_ .............................. runs or Sales of gasoline during the month. (Write "no" where applicable.) :~°~.L--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate W~th the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. (January 1950) " : ~25766-9 other oil operm~-ors ha~ ~ pi~eri~ In ~ ~ We l~er oil K. L, VonderAhe November 25, 1963 We have altered the plugging record for the Cook Inlet No. lA well to clarify the setting depths for the 5" liner and bridge plug. The revised plugging record is attached. The bridge plug depth of 12,375' was referenced to the kelly bushing whereas the liner depth of 9975 to 12,278' was referenced to the base plate. The liner depth is 10,101 to 12,40/~' using the kelly bushing as a reference point. This reflects the base plate to KB measurement of 126' at zero tide. Very truly yours, A. E. Piper EWU: ds c A t tachmen ts FORM 470 2-57~ PANAME1HCAN PETI OLEUM C01H P. ATION P. O. Box 779 Anchorage, Alaska · ~CiF~er 12, 1963 NOV Division of Mines and Minerall _~ Dep~. o~ Natural Re.~omce~' F i l e: AE P- 733-WV Re: P1 ugg lng Record for ,_,Cook,., ,,,I,n let_ No,. ,lA ,,We,.11,.. State of Alaska Dept. of Natural Resources Division of Mines and Minerals 329 Second Avenue Anchorage, A 1 as ka ATTENTION: Tom Marshall, Jr. Dear sir: We are herewith transmitting for your information and file a pluggi.n9 record for the Pan American Cook Inlet No. IA well. The well was suspended for the winter months on November 5, 1963. Very truly yours, A. E. Pi per EWU: ds c .- UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS T~e followi~ is a eorreet report of operations a~d prod~etio~ (inel~di~d drilli~ a~d prod~ein~ wells) for the mo~th of ...... _Q_q_t_p_~..r_ ...................... 19__6_.3__, ............................................................................ ./lde~t's address ................... P__:__~.~. Box 779 Oompany___, _.., ..., _______._.._..._ .___.P.~' _.A~r.i..c~..._~et~oleum Corp.. ~ 8'6401 Phone .......................................... : ........................................d~ent' s title .Di~y. xi_cx._.~n.pm_rJ, aten. de. atl ..... Ov. F~. o~ GAS O~I,tONS OV BAB~ELS Or RE~IARK8 SBt. i~ No. PRODVOBD * RE~VRRBD ~O~O, ~ S~tO) ~M ~ m~t ~ ~t f~ ~e ~ OF ~ ~WP. RANGE WE~ DaYs BAtEE~ OF O~ ' OBA~Y (~ tho~) GASO~E WATBB (~ (M ~, ~: ff ~ut ~n, oa~; - · _ ~W 1/4 !iN 9W lA 0 0 0 0 0 None ~W ~/4 C ~e .'6 ~D 12,~.77. Pre~arii~g to c-ernest squeeze ~" li~er b~low 10,1)1'. ~ped total of )7,400 bar~'els ~lt wage]. 7" casing failed inter~'al 8.,900~' - 8~99 '. Lost 4,000 )arrel~ muc and sall; wa~ r ~rough hole In casing. Set 5" ;as~g t~ 10~086' with ~.40 sa,..ks ('~l.ass D 1]~3~ ~ la~-9 fOr cereal'- b°~d log ov~r 5'i~'~ ~asiHg - top"c~ent 340 ' ~ ' NOV 1963 Pe~ro]( om Br~nch Div~slon o~ ~ nes and A a~ka Dept. c Natural Resour~ No?~..--There were ............. _~._o_ ..................... rum or sales of oil; ........... L___N_.°_ ........................... M ou. ft. of gas ~old; ............ ..N,o. ............................ runs or sales of gasoline during the month. (Write "no" where applieable.) No?~..--Report on this form is required for eaah e~lend~r month, regardless of the status of operations, and mu~t be filed in duplicate with the supervisor by the 6th Of the sueeeeding month, unless otherwise directed by the supervisor. y 1950) 16--25766-~ U.S. GOVERNMENT PnINTI.G OeKICE SUBJECT FILE MESSAGE the £o11~_~ (1 blueJine print and I cook h~et so. 1. - z. ~-. s. ? ~ 5", mina 1. c~ ,; ........ FRO/~ .. ~, ~ DATE LOCATION ~ 7~"~! ~-,I~011L~I! ~l,.llJr~l 1.1./7163 REPLY A~RESSEE: RETAIN THIS COPY DATE COIIPOIIATION _ 4, 196~ · ¢ File: AEP-7OS-WF Re:Appllcatlon tO Suspend Cook Inlet No. lA Well Stat{: of Alaska . Dept. of Natu?l ReSour~s Division of RiMs and lt~nera]s 329 SeCond AV~nue Anchorage, AlaSka - ATTENTION= Tom Harsha]~, Jr. Bpprova] please find two copies of an application your to s~Spend Cook inlet N~. lA ~]l. It is believed im~ritive to c~p]ete~ aband~n~nt e~rations )n the Cook Inlet ~o. ] blo~ut ~]l before Winter. In view of the limlted ~riod _to operate in Cook Inlet before winter, the ~odeco II dril]ing vess~-] Is being moved Im~diately to.the No. Plans to_test t~'C°°k ~nlet No. IA ~l] are t~refore being post-p0ned until next sprmg, return one cop~ of our application to sus~nd~-the Cook Inlet Ne. lA ~1]. Very truly yours, ~. [. ~lp~r ~C:dsc Attach~nt / APPLICATION TO DRILL [] DEEPEN / ~E OF COMPANY OR OPERATOR // Pan American Petroleum Corporation APPLICATION FOR PERMIT TO DR~LL, DEEPEN OR I-~.UG BACK PLUG BACK ~] Sus'p. end DATE November 4, 1963 Address City State P. O. Box 779 Anchorage A 1 as ka ,. DESCRIPTION OF WELL AND LEASE Name of lease I ~Vell number ! I Elevation (ground) Cool< Inlet State I lA ~ Sea ]eve] _ Well locaUou (give footage from section lines) Section~townshtp~ran~e or block & survey 1249.6' N of S line, 2024.9' E of W Field & reservoir (If wildcat, so state), Wildcat (relief well) line, Sec. 6,. TllN, R9W: SM Ic°untYThird Judicial Division. Distance, in miles, and direction from nearest town or post office 25 miles southwest of Anchorage Nearest distance from proposed location to property or lease line: 2024.9' east of west lease boundary feet Distance from proposed location to nearest drilling, completed or applied--for ~vell on the same lease: · 1720' N 71°30'46'' E of Cook Inlet No. ~'n~.~t~. Tota] Depth: _12,252 TVD 12~77 MD Number of acres in lease: 5022 S-13-6-8 Rot~ary or cable tools Rotary Approx. date work will start , November 4~ 1963_ Number of wells on lease, including this well. completed in or drilling to this reservoir: None If lease, purchased with one or more wells drilled, from whom purchased: Name Address Not applicable Status of bond $150,000 Nationwide BOnd on file in Central Nationwide Bond File - BLM, Washington D. C. Remarks: (If this is an application to deepen or plug back, briefly describe work to be done, giving present . producing zone and expected new producing zone) The well is being suspended in view of the approaching Inlet ice conditions and the need to complete permanent abandonment of the Cook Inlet No. 1 well during this drilling season. There is open hole section in the well from 12,404' to 12,4'77' MD. A bridge plug has been set in the 5-inch liner at 12,375' with a cement plug in. the interval 7710-7980'. This cement plug has held 10,000 lbs weight and 2500 psi pressure. A Baker Model M packer has also been set at 2825" with cement above to 2675'. The top of the 5-inch casing hangel will be capped with provision in the capping equipment to test for pressure prior to re- moving. It is planned to production test the well next spring° Dist. Prod. Supt. of Pan American Petroleum CERTIFICATE: I, the undersigned, state that I am the of the (company), and that I am authorized by said cornpany to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein are.. true, correct-~and complete to the best of my knowledge, f/....,, k~ (' ~ / ./'J./ , Signature Permit Number: ~ ~ -- ~ ~ , ~otice: ~efore send~ in this form be sure that you have ~iven all in[ormafion requested. ~uch ~necessary correspond- ence.will thus be avoided. See Instruction on ~ever~e Side of Form Alaska Oil and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form No. Authorized by Order No. I Effective October 1, 1958 ~o~ ~ SW sw Sec. 6 ~qOo 9. ~0,089 UNITED ' ~ ro ..... ' ~ ' rat al)Proved GEOLOGICAL SURVEY RiOR LESSEE's NTHLY RT OF OPERATIONs .................................. ~o~t~ ~ok ~aleC ~he /ollowi~ i~ a eorr , WellsJ/or the .... Ret report ot ..... ' ...... Field-.. Wildcat ~ress ....... 2"--0'--~o~ 7!9 · 1~ 63, Prod~etio~ .......................... ~Chorage, A1 Phoae ........................ ' asks" BR 8-6401 .... - .... etrole (In tho~ands) 0 0 0 from 12 ' 5" liner in on end 12,477 ' ' r arid 1.IL, kil~ Set kef Mode ';Nw,~rtl lZ Haled ' Packer at on Sept d set al 10,069~ 1963. · Mines Minezals N°~r"~There were No No~-rT~'~:~;T .................. run .... runs or sales f .. duplicate ~:.L ."P. r~ on this form L o ur SaJes of ...... _ 0 011, ~0 ~P~ ~ a- ,~u rne SUperv~or ~"-~ required for ea~uune during; the ..... / ~ one 8~Pervisor eted bv 18~2~768~ U, $, GO~E~N~Ni ~INTING OFFICE UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Form approved. Budget Bureau No. 42-R356.5. __...,~._ ~.o__.~_~.__~. ............ ~.~ _~_.~.?~ .............. ._g_9_9.~__~a~.. P~_.~.~A LESSEE'S MONTHLY REPORT OF OPERATIONS The followin~ is a correct report of operations and prod~ction (incl~dinff drillin~ a~d prod~cin~ wells) for tke month of ......... ~_~ ..................... , 19__~.~_, .............................................................................. J~e~t's adg~ess ..... ~_~___q~__'g~__~:J~ .................................... Company Anchorage ~iff~ed ........ ~~~.n..~~ ............. ~o~e ..................... ~__~=~ ............................................ ~t's tuze_.~.~_E~.~3_._~_~9~9~ ....... SEC. AND ~ 1/4 SW 1/4 Sec. 6 TD 10,6 Cement. No. DrJ[lli D&yi~ PRODUOBD 0 BARI~Ls Or O~ mn 7" casir I Cu. FT. or GAS GRAVITY (II1 thousands) 0 0 set at 10,195 GALLONS O~' GASOLINE RECOVERED with 30 REMARKS (If drilling, depth; if ~hut down, oause; date and result of t~t for gasoline eontent of BARR~I~ OF WATER (If none, so state) NONE 0 sacks )il Well Class D 19611 Dlvldml ~etroleum Branch d Mines: ond Mlnerels' ei)t. of Natu~rai Resource~ No~E.--There were ................. _N_-O- ................. runs or sales of oil; ................ J~0 .......................... M cu. f~. of gas sold; .............. __~__q .......................... runs or sales of gasoline during the month. (Write "no" where applicable.) NO~E.~Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Fern 9-~29 (January 1950) 16--25766-9 O.S. GOVEnNMENT PRIHTZNO OFFICE UNITED STATES DEPARTMENT' OF THE INTERIOR GEOLOGICAL SURVEY Form approved. Budget Bureau No. 42-R356.5. ~o omc~ _._A~.__.c_h__o._.r.a_g__e ............... m,~, u~,,~ ..,A~.._.-__z._7.!s. ? ............... U,,T __.q .o.9__k___~_.Z._e._g_..S_ ~A _e.. :~_L_A. LESSEE'S MONTHLY REPORT OF OPERATIONS Tt~e followin~ is a eorreot report of operations and prod~etion (i~ol~din_~ drillir~ and prod~oi~ wells) for tl, e mor~tl, of ........... JuLy ........................, 19_63, ......................................... :>--- ............................. ,/l~ent's address ____P__:___O__:___B__o__x___JJ?_ ...................................... Company ..................... P~.?_L.~._~... .............................. .............................. mm ed ........ ..................... Pl, o~e ................... B---R--:-8----6---4--O--1- ....... - .... : ................................. ~l~er~t' s title ~_~r&cT~_.au~arim:enden: ......... ~EC. AND sw L/4 sw Sec 6 TD 10,5, bottom lA hole 7/23/63 RANGE Dr£1 ,sh ~ GRAVITY ecrac ~ri§ n BO~ Cu. FT. oP OAS (In thousands) 0 J,ced hole h~ hal lA from 7/4 (~ALLOI~S OF GASOLINE RECOVERED BARRELS OF WA~ER (If none, so state) NONE :.d origiJ not bro] 53 and f: RE1VIARK8 (If drtlltnz, d~pth; if Ehut down, oauze; date and result of te~t for gasoline eontent of $~) lal lA hole below con ~nto original :om 7/22 to [RIVED .s fez lor~ , e. H~ve to 7/10/ Petr, ,leum Bronch No~E.--There were NO runs or sales of oil; NO M cu. ft. of gas sold; NO runs or sales of gasoline during the month. (Write "no" where applicable.) No~E.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Fox'In 9-~9 16--25766-9 U. ~. GOVERNMENT PRINTING OFFICE (January 1950) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY .' i A.pprov~l expires 12-81-60. ~AND OFFICE ....... .Al~C.~}_~g~ ........ LFJ~E NUMBER ..... -~--- .-~73-~R ........ us,v .~.o_k__In le_L __S_~ate___#_L~ __ LESSEE'S MONTHLY REPORT OF OPERATIONS State ........ Alaska ............. Co~n, ty __Co.o.k__Inl.e.t.__t~ain__ F/e/d ................. Wil~taat .................................... Tl~e followin~ is a correct report of operations and prod~etion (inel~din~ drillin~ and prod~cin~ wells) for the montI~ of ..................... June- ............ , 19_63, ............................................................................ · ~lee~ t' s address ___J~o:~_229_ ................................................. Corr~p~r~y _PAI~~~..COR2 ..... .............................. ............................. .... ................... Pl~o~e ................... BR__8----6401 .............................................. ,/l~ent' s title ..... SEC. AND BABEEL~I OF OIL (~RAYITY (~ASOLINE WATEB (~ ~ ~, d~ ff ~ut d~n, ~ or ~ Twr. RANGE W~ DaYs CV. FT. Or GAS G~NS Or BARBE~ Or RE~ARK8 NO. ~Du0,. (~ tho~&) RE~VERED none, ~ 8~) ~ ~d ~t ~ ~t for S~ ~ 11N 9W lA 0 0 0 0 0 None Sec 6 TD 86~2*. Drilling. U]~able ~o recover s~uck pip( ~n interval 605.~ - 7420*. Se~ ~hree cem(m~ plugs arou]~d StuCk pipe and ~n open l~ole abo~e ~o 569' using 526 sacks Cla~;s D ceme~ an, 47 sacks sand. Dri11 8 ].]2" side,rack ho .e ~rom 5696' 8692* S~rvey at ~685* ~.D.: ~gIe 16° S76O~, T~) 1556.13 Closure 803.97~ S70o3~W, [Coordina:es S::67~38* ~7~8.32~. .: Anchora ~e, Alaska ]OL 9 1963 ' E4~ ~ M~es and Minerals No~m.--There were ................ _~Q., ...............mas or sales of oil; .................... 3Io_ ..................... M cu. ft. of gas sold; ............... _N__o ........................... runs or sales of gasoline during the month. (Write "no" where applicable.) NoT~..--Report on this form is requ~ed for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. FOrl~ 9-329 ~Iuary 19~0) 16--2575~-8 U.S. GOYBRNM~NT PI~NTING OFFICS Approval expires UNITED STATES L~.o OFF,CE _.Aa~_hQr~ge_ ................. DEPARTMENT OF THE INTERIOR LEASE NUMBER.~D.L_.~7_~ ............... GEOLOGICAL SURVEY STATE REPORT LESSEE'S MONTHLY REPORT OF OPERATIONS State ......... _Af~_sk_a_ ............. eo~ty ___._C_.o_~!c_.L_a%_e_J;__~_a__s_in_ ~e~d ......... ~. i~._l_.d_.c..a..~_. ........................................... TI~e foltowi~ is a correct ~eport of operations a~d prod~etio~ (i~ol~di~ drilli~ a~d prod~ci~ wells) for ~I~e ~r~or~tI~ of ............. ~__'.~.__ ....................... , 19__6__3_, _ ........................................................................... ~l~e~'s address P* 0., Box 7'79 Gem an PAN.__~...~___~~.IERICA~I~-TROL~{~:. CORP,, ................................................................... p Y ........................................... Pl~o~e ................. _B__I~____8_.-___~___O__~_. ............................................... J~e~t' s title ..DJ~_~riC_~__~.l~B~z:.in~_~.a~_ll~_ ...... SEC. AN~ Daxs Ov. FT. o~' GAs GALLONS Or BARRELS 0r RE~/IARKS ~ oF ~ ~r. RANGE WE~ BABEE~ Or O~ GRAVY GASOL~E WATER (~ (~ ~. ~: ~ shut d~n. NO. PaoDoomv (~ tho~) ~E~VERBD none, ~ 8~) ~ ~d muir ~ t~ ~ o~t ~ ~) SE~- 1~ 9~'1 ~ 0 0 0 0 0 None Sec'6 Pu~ed[, se::~c(~d ~d re-r~ subsea~ BOPs, Reco~re ~ 7" cgs:ng string. Conditioned ho%e ~'o pr,~ot~s TI lL519~. Dmil:.ed 8 ~/2" ho%e ~o 12,06~ ~b ~1,~2t TD. S~y 12,0~i~ ~: Azure ~o~ S~f. ~',oor~nates S459 , ~[15~, 6~, c%os~e ~662.3~ S70o58~W. Stu(:k pipe on trip o~ ~,f ho~e. Bi~ a~ 7420~ 1,~., ~op of fish a2 6080~. ~qmshi~g o~r p: , . .. .., NoT~..--There were ............ ~_0 ...................... runs or sales of oil; ............ ~_0_ .............................. M cu. ft. of gas sold; ................ __N_Q ......................... runs or sales of gasoline during the month. (Write "no" where applicable.) NO?E.--Report on this form is required for each calendar month, regardless of the status of operations, and must be flied in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. 9-329 ~(Y~nuary 19~0) 1HS?6H U.S. r~OVI~RNMENT PRINTIN60FFICi~ UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS Tl~e followi~ is a eorreet report of operatior~s a~d prod~etior& (i~el~dgr~ d~lli~ and prod~ei~ wells) for ghe mont~ of ........ A~_ ...................... , 19~ ............................................................................... ~'~ ~aa,~. ___~-__9.=~.~__?_?_~_ ..................................... co~u ............................. ............................. su~a ........ ~~~ ....................... paoue ................... ~__~;~P~_ ............................................. a~e~e'~ tit;e_.~t7~~~aaeat ....... SEC. AND BARREI~I OF OIL GRAVI~Y GASOLINE WATER (~ (~ ~, ~th: ff shut down, ~; ~ O~ ~ ~Wp. RANOE WE~ D.xs CU. F~. OF OAS G~NS O~ BA~ O~ RE~ARKS NO. Pao~uo.~ (~ tho~) R~COV2RRD none, ~ s~) ~ ~d ~, et . ~t of Sec, 6 Co~e~acin 4~1~9/63 resu~Tedpos~.tion of well lo,:ation tc set buc r f~ ~ggi~ u] operations c )ntinued f(~r ~ai~er of :aonth. PetroleUm Oivislo a o5' Minos Al~sku Dept. of ~c~tut'c~i No~E.--There Were ......... re.O__ ........................ runs or sales of oil; ............... }JD_ .......................... M ou. ft. of gas sold; ............... _N__0__ ......................... runs or sales of gasoline during the month. (Write "no" where applicable.) NoTE.mReport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplieat~ with the supervisor bY the 6th of :the suoeeeding month, unless otherwise directed by the supervisor. 9-329 ~4~al:lUary 19fi0) 10--25700-8 u.s. oovta. M~.v PaINVmO OVrfcg .... iXL'%.,L/ V LI.~ NOV 30 1962 _ . APPLICATION FOR PERMIT TO DRILL, DEEPEN OR PLUG BACK Petroleum_ Branch Pan American Petrol'~~ COrpOration Address ApPLICATION~ TO DRILL [] DEEPEN [] Anchorage OiLy Anchorage ~ PLUG BACK ~ Suspend DATE Nayembe~ 29 State Alaska.' Box 712 'DESCRIPTION OF WELL AND LEASE Name of lease ] Well number APL 17589 ' ' ' '' ~ I lA Elevation (ground) ~rell location (give footage from section lines) Sectton--Lownship--range or block & survey 1249.6' N. of.S.-line, 2024.9~ E. of W. line, Sec. 6,T llN, R ~W,. s~ Field & reser¥o!~ (l~f ~-j.ldcat., so state) -: . 2~ .: .~ J County Wildcat Distance, in miles, and direction from nearest town or post office . _ Nearest distance from proposed location Distance from proposed location to nearest drilling, to property or lease line: completed or applied~for well on the same lease: feet ..] Proposed depth: I Rotary or cable tools 12,300 ft. I Rotary 545,4'N & 16~.4' E, of Co~k InletSta~m 1. IApprox. date work will start Number of acres in lease: 5,022 8-13-6-8 Number of wells on lease, including this well. completed in or drilling to this reservoir: If lease, purchased with one or more wells drilled, from whom purchased: Name Address Status of bond $150,000 Nationwide Bond on file in Central Nationwide Bond File - BLM, Wash., D.C. Remarks: (If' this is an application to deepen or plug back, briefly describe work to be done, giving present producing zone and expected new producing zone) Insurance underwriters have ordered drilling stopped on Cook Inlet lA Well, and we are preparing to run 7" casing to present total depth of 11,549'. Propose to set concrete plugs at total depth of 7" and at surface. Operationg to be resumed as soon as weather permits in spring. If weather prohibits this program bridge plugs will be set in the bottom and top of 9 5/8" intermediate casing. Area Foreman CERTIFICATE: I, the undersigned, state that I am th~ of thePan Am. er-icon Petrole'tt~ Corp. (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein are true, correct and complete to Signature Permit Number:. See Instruction on Reverse Side of Form Alaska Oil and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form 1~o. P-1 Authorized by Order No. 1 Effective October 1, 1958 _.CON.FIDENI"iAL UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS Form approved. ~'~ Budget Bureau No. 42-R856.5. _ A~ohorage ~. aD OFFICE .... Tl~e following is a correct report of operations and production (inol~din~ drillin~ and prod~oing wells) for tl~e mont]~ of ...... ~'_?_~0.~ ..................... , 19---~-, ............................................................................ .4gent's address ............ ~-7~ ....................................... Company ~~_a_~_ .................................... Si~ned .... ~ .............. phone ____~ll__~6_t4A~2k ........................................................... J~ent' s title ..................... AZ~& ]'$r~ .......................... WELL D~s CU. FT. O~ GAS !GALLONS OF BAr~ar~ or REMARKS SEC. AND r~WP. RANGE NO. P~oo~cmo ~AR~ OF O~ GRA~Y (~ though)~ GASOL~E WA~ER (~ (If ~, d~; ~ ~ut down, ease; ~ OF ~ RECOVERED none, so state)da~ ~d r~teon~tof of~tg~)f°r g~o~z .. ~/~~ ~ ~a~ o o o o ~ I ' ~, ' ' ' ' ~*' : ' GAl ..20'"~, ' ~0..~'8 T:~., -~ ..;2 ~'. g" ...... .:: ~v-e~e~. . ~: ~909' · C:Loaure. -~, ~ $9~9 for. ~ ~ . . ~ ~/~ ~ ~ ~'1--~' ~ve~et ~ ? 2~-** ~lo~re ~ ~'~,gb, ran ~es~ ~oo~ o~ee~ ~i[ p~),e ~ ~ 2~0 P~I:. Tef;te~ v~ve,~ ~d k~Ll line to ~ . : '~20 &~, ~mre~ ~ 74:~0' '..~d 7~,89' Cio~ure ~ 7~, 1~/12 ~ 7750' ~1~. ~u~, ~ ~9,~- ~e ~.~e~;e~ ~L,~ 760~.:~. C~osur, ~ ~aS.~. XO/Z~ ~ 8~8 ~Z~. ~ ~os~,~, ~ ~;~o.t~, ~ 8i)~':~9. ~,t 8~,8-, ~vo 8~~.2o'. lo/16 ~'~ 85~ ~s. [~,9-;!* '/=io~=e ~ ?6~,~e Di~.~ed ~d ~ rotor ~ o~e~ f3oor, tested au$o, ,lo~-" ",~ ~,- ~t19..~" ~heak,~~ ~V. 1{~9 ~D 89~0' ~arwe~ ~ 8881, Closure ,-~ 860.12, ~tire bet':om ~oie ~e~ebl~ ~fl~,'~a- lO/aa TD 9~76' drlg, S~v~s e 9014', ~VD 88~.)'I.~+' O~Lommre 89'7.2~'. ~vey~ 9150' TV]O 9022'. Glo~ur~ 935.36' Surve~ ~ 9252~ TV~) 91~5~k'. :~O/a3 TD ~463' ~$~=ve~ ~ ~)463' ~D 9324.78' Closure 101 ~O-P~;i ~L'~ :~te:~. 1~)/24 · TD ~0 i~l.g,:' ~ea.i~. SurveF ~ 957~' ~ 9532.30 Gl :!~mr.' ~n,~6:77-e~_,~eke~ ~=~ 1Oz~g ~'D 9~' s~.~ey ~ 9796~ ~D 9645.~O. Olosu ~d ed ,0 ~o~ .96 No~..--There were ........... ~O ...................... runs or salea of oil; .................. _~-- ......................M cu. ft. of Gag cold; ................. ~ .......................runs or ames of gasoline durMg the month. (WHte "no" where applicable.) No~r.--~port on ~his form is requked for each calendar month, regar~ess of the s~atus of operations, and must be flied in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. ~ 9-829 1H576~ U.S. GOVERNMENV PRINTING OFFICE (January 19~) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Form approved. Budget Bureau No. 42-R856.5. L...~D OFFICE .................................. LSA~ NUMSER ................................ UNIT ........................................... LESSEE'S MONTHLY REPORT OF OPERATIONS State .................................. Go~,r~ty .................................... Field .................................................................. T]~e followin~ is a correct report of operations and prod~ction (ir~cl~di~ drilti~ arid prod~ci~ wells) for ti~e zr~ont]~ of .......................................... , ]9 ................................................................................... .4Eent' s address ................................................................... Corr~pany ............................................................ .............................................................................................. Si~ned ................................................................ P]zone ................................................................................... ~Eer~t' s title ....................................................... ~ 0F ~ ~WP, RANGE WELL BAR~E~ O~ O~ GRA~Y OU. F~. OF GAS No. (~ thous~&) GASOL~E WATER (~ (If &~, d~th; if shut down, ease; Pnoovc~o RECOVERED none~ 8o state) . key ~t ~ 69;~ w~d .~. ~t~..to. ~.. W~t ~ .hole ~' pilot No~..--There were ............. ~ ................... runs or sales of oil; ................ ~0 ......................... M cu. ft. of gas sold; ............... ~ ......................... runs or sales of gasoline during the month. (Write "no" where applicable.) No~E.--R~port on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9-329 (January 1950) 16--25766-9 U, So 60V~*RNMI~NT PnlNTIN; OrglCg /' UNIT: ED STATES ~.~ omc~~~~a · ........ , ~~ ~ &, "DEPARTMENT OF THE INTERIOR o~ o~SSEE S MONTHLY ~RT OF OPERATIONS ~ ...... ~~ .............. 0o~ _~__~~__~~ ~ ............. ~~ ..................................... T~e fotlo~g is ~ correct report of operations a~d prod~ctio~ (i~ol~di~ drilli~ a~d prod~ei~ wells) for tke mo~tk of ....... ~~~_ .............. ,19__~, ............................................................................ ~'~ ~e. .... ~=__~ .............................................. Co~p~y .... ............................... ~~~,--~~ ......................... Si~ed ........... ~__~:_~~ ......................... Pko~e ......... ~~~ ........................................................ J~e~t's title ...... ~__~~ ...................... S'O'"D1 ~ ....... 1 . or. FT. oF GAs GA~LONS OF BAJ~I~EL80]~ REMARKS ~ OF ~ ~WP. RANGE WELL Dtrs BAR~ OF O~ GRA~TY GASOL~E ~ATER (~ (If ~, d~tht ff shut down, ea~e~ N0. (~ though) RECOVERED none, so s~te) ~ ~d r~ult of ~t for g~o~e eon~nt of m.~te~l ~:~:~,.~ <XfieF .~ ~,.. ~/6 t~ ~t, .~l~g, 12 ~": 'hole, ~pe ~t' :~:~mle ~ ~2 ~"'b:~t .~ ~ 9" boll~$ hit cem~mt ~ 175 ft, ,t~ted ~ri~g ~'~ 3=~ ~' '~/7 '~ 8~ .~t.~ .Ring ~th 2~,~' 9~t l'e~or, Mo trouble ~f ~--~r. '~n:~,~~ed' ~o. ~o ~t,~' ~ ~. ~per bxa~os to 7;~o ~t. [o~ee~ee :~s~.'p~'.~ e ~Ld i~~ed rot~ table. 9~,~ TD 1811 ft, X~. a~ter:L~ ~o h,)ld'a0re Ve~:~.- 9~'~' ~D ~X950 t~i~ed ~ o] eek blo~ut ~rev, 12~. "' ' ' .... ' No~E.--There were ...................................... runs or sales of oil; ............................................. M cu. ft. of gas sold; ............................................. runs or sales of gasoline during the month. (Write "no" where applicable.) l~o?v..--Report On this form is required:for each calendar month, regardless Of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Fern 9-829 ($anuary 1950) 16~25706-9 U, g. GOVERNMENT PaIN?lNG OFFICE UNITED STATES ~DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Form approved. Budset Bureau No. 42-R856.5, ,, omc,~ Az11~e,Fmge ._. u,,,._~:~:.~_e~..a.~--~-A LESSEE'~ONTHLY REPORT OF OPERATIONS State .................................. bqog-~tY .................................... Field .................................................................. The followi~E, is a correct report of operations a~d prod~etio~ (i~el~di~E drHl~ a~d prod~eg~E wells) for tke mo~tk of ........................ : .................. , :19 ....... _ ........................................................................... .~,~~-_ ................ : ..... : ..... ~ ............. : ..................... ~i~:~---~~ ........................ phone .................................... : ........................................... :._. J~e~t's title ....................................................... Ou. FT. OF (}AS (In thousands).. REMARKS date and.reault of. test ~or gasoline e~ute~t o~' gas) leave No?E.--There were ~ runs or sales of off; 1~ · M ou. ft. of gas sold; ................ :]~ ....................... runs or sales of gasoline during the month. (Write "no" where applicable.) No?~..--Repor~ on this form is required~ for each calendar month, regardless of the status of operations, and must be flied in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Forint 9-3~9 16--25766-9 O.S. GOVZIINMIENT ea~wrl.e OFFICE (January 1950) UNITED STATES DEPARTMENT OF 'THE INTERIOR GEOLOGICAL SURVEY Form approved. Budget Bureau No. 42-R856.$. LESSEE'S MONTHLY REPORT OF OPERATIONS Wild, at ......................... S~a~e ~~ __ &o~r~y ~00~ I~e~ B~ Field Tke followi~ is a oorreo~ repor~ of operations a~d prod~o~io~ (i~ol~di~ drilli~g a~d prod~ei~ ............................... ............................................ -~ore ~ ~~ .................. ~ie~' s iitle ..~--~~ .......................... ~0 AND -- [ ....... ~WELL ~ BA~RE~ OF O~ ~ ~Avx (~ thous~) [ RECOVereD [ none, so s~a~e) o~nt o~ of ~0" ~i~e ~d ~ather ~o rou~ to bee ~n o~erat~on, ~-U~ weather at ni~t ~$used ~e.l~. ~, ~d to use ~'mud~ ~de trip ~ ~h B~er re.or. o~ag up. Atte~t,,d to ~n 2~" casing. ~ Fear, 2~" fl~n~e erM~e~ ~ ~ hours reputing ~ m~onOof stud pipe S~p bla~ee'. ~e, foot wel~ blades on ~r~ re.er, Loo~ one ~ide blew li~e- ~chorage, AI~ ska Division o ines an~ Minerals Alaska Dep1 of Natural Resource, NoT.There were ...........-~--~- ...................... runs or sales of oil; ......................................... M cu, it, of gms mold; ............................................. runs or ss. les of gasoline during the month. (Write "no" where applicable.) be filed in NOTE.--RepOrt on this form is required for each' calendar month, regardless of the status of operations, and must duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. 16---25766-9O.S. GOVZRNMENT pRIt~TINe o[Irl¢[ : Form 9-329 APPLICATION F~' PERMI¥~TO DRILL,. DEEPEN OR PLUG BACK .... . APPI~IC~TION TO .-DRIL~L,,~. DEEPEN [] NAME OF COMPANY OR OPERATOR City. - State ' !~' ;':-iJ".. ,_~..~- ';:c~:- :' ~ :~ : D~SCRI'PTION /OF WELL AND LEASE - IVe~l-lo~-~-~~ (give footage from section'li~ .... "'~etion--townshipLr~"g'e'or' bloc'k & survey Field & reservo~ (If,~ildcat,. so s~e)~'~<~ .. ..~:. :--~-~ ~- ~ - ~.:~o~$~ .... .. - . Distance, in miles, and direction from nearest town or post office Nearest distance from proposed location to property or lease line: feet -Proposed depth: Number of acres in lease: Rotary or cable tools Distance from proposed location to nearest drilling. cSm~lete~or_~appllqd~for well om. the ~ame leo, se: _ ~4&.¢ ~ and ~.4 1';~t: ed' Approx. date work ~lll ~tar~ Number of w~lls on lease, inc]udin~ this well, eompl~ or drillin~ to this r~ervoir: feet If lease, purchased with one or more wells drilled, from whom purchased: Name Address Status of bond Remark[~ (I~' this is gn application to deepen or Piug;baCk, briefly describe. Work to be done, giving presen~- producing zone and expected new producing zone) " RECEIV ~chorage, Alaska SEP ].962 Division of Mines and Minerals Alaska Dept. oi Natural Resources CERTIFICATE: I, the undersigned, state that I am the~[[q[~ J~~ the ~ ~l~n ~['~/l~[[["~, (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein are true, correct and complete to the best of my knowledge. Signature Permit Number: Approval 'Date: Approved By: , Alaska 0il and Gas Conservation Commission Application to Drill, Deepen or Plug Baok Form No. P-1 Notice: Before sending in this form be sure that yo~ have given all information requested. Much unnecessary correspond- ence will thus be avoided. See Instruction on Reverse Side of Form Authorized by Order No. 1 Effective October 1, 1958 r 1 I I I I I I ' I I I I I I olc~ I I I I 30 I I I I I- I 31 I I 61004'48.68 I Kt:LI:IV Anchorage, Alaska ~ of_Mi~e,a, lpqd. Minerals Alas~. Dept. of Nattulil Resou~s 27 . ¸'26 34 55 25 36 0 13 18 I I 28 29 I ! I I I ~ 15 ' 14 ~ I I I I I ' I I I t L _L I 32 I 53 I I I Imm m mmm m mmmmmmm I I Certificate of Surveyor 5 I 4 C¢iOK INLET ST~.TE Nc. lA ~ 61°-04'- 09.000, _ 150°-56-$4.3941' I 8 1'7 Scale I": I Mile 16 T. II N. I hereby certify that I am properly registered and lic- ensed fo practice land surveying in the State of Alaska and that this plot represents o location surveyed by me, os of 5:00A.M.,28 May, 1962 and that oll dimensions 8, o, er e,o,Is o orr e c,. Dote Sur~.eyor ~ NOTE: PLAT AMENDED TO SHOW THE LOCATION OF COOK INLET STATE No, IA AS OF 9:00A.M., 5 SEPT, 196~ Surveyors Note by use esta b- reap. ..The location of COOK INLET NO. I was surveyed of Tri-Station Monuments BELUGA and TLR-RACE .lished by the U.S, ?_.Dth Engineers, 1944 ~ 194g The Surveyed Location Of COOK INLET STATE NO.I (in S.W. V4 of Sec.6, T. II N.~R.9W.,S.M.) Surveyed For PAN AMERICAN PETROLEUM CORPORATION P.O. BOX 712 ANCHORAGE ALASKA SURVEYED BY E. M. Lindsey REGISTERED LAND SURVEYOR 650-S 1405' NORTHERN LIGHTS BLVD. ANCHORAGE,ALASKA ~ Jamem A. Williams Donald D. Bruce Augus% 29, 1962 Well No. "C~k Inlet-State" 1-A Pan American Petroleum Corp., Opt. Enclosed is an ap~rove~ application for permit %o drill the subject well, together with the permit fee of $50.00. DDB:ks APPLICATION FOR PERMIT TO DRILL, DEEPEN OR PLUG BACK ..' ,:'_ :_: - .: :'~', i APPI~ICA~ION ~TO DRII~'-~, DEEPEN [] NAME OF COMPANY OR OPERATOR ~':. - ~ ;:,d'?~ -: ..~ ~- ~-2£~: - .-~- ~ .(~ ,. ' . :L : - -. PLUG BACK [] D~TE State Name of lease { lVell number I Elevation (ground) ~i~~:~-" ~it~''~::''~ ~: ': :~ ....... ' ~] ~t~A XYell location (give footage from section lines) Section--townsh{p--range or block & survey Distance, in miles, and direction from neares~ town ~r pos~ office Nearest distance from proposed location [ Distance from proposed location to nearest drilling, lease: wellonlhe same to property or lease l'ine: completed or shelled--for Proposed depth la,O0~' Number of acres in lease: Rotary or cable tools feet Approx. date work will start Ana~a~ ~, X96a Number of wells on lease, including this well, completed in or drilling to this reservoir: If lease,' purchased with one or more wells drilled, from whom purchased: Name Address Status of bond Sl~O,O00,. ~attonv!de tto~ ~-~Xe ~ G~t~al ~a~on~do ~ad F~e-~. ~. D. ~. Remarks: (If this is an application to deepen or plug:back, briefly describe work to be done, giving present producing zone and expected new producing zone) CERTIFICATE: I, the undersigned,, state that I am tb~8~ F~S'~the (company), and that I am authorized by said company-to make this report; and that this report pared under my supervision and direction and.that the facts staied therein are true, correct and CO~ ~9 1~ the best of my knowledge. ~.~~ , P~sr~ieum Branch Permit Number: Approval Date: Notice: Before sending in this form be sure that you have given all information .requested. Much unnecessary correspond- ence will thus be avoided. See Instruction on Reverse Side of Form Signature -'.-,,l~.:~n of /~ines and Minerals Alaska Oil and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. I Effective October 1, 1958