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Home My WebLink About169-0891a. 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): North Cook Inlet Unit 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- 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22. Logs Obtained: 23. BOTTOM 30" - 380' 16" H-40 621' 10-3/4" J-55 2,393' 7" J-55 3,047' 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 October 13, 1969 August 24, 1969 ADL 17589 N/A N/A 3,520' MD / 3,047' TVD99 NA 8,212' MD / 6,297' TVD N/A Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: Oil-Bbl: suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A Water-Bbl: PRODUCTION TEST N/A Date of Test: Flow Tubing - 65# 380' Surface 2,745' Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 40.5 / 45.5# 3,520' (TOW) Surface Surface DEPTH SET (MD) PACKER SET (MD/TVD) Surface CASING WT. PER FT.GRADE 23 / 26# 332004 TOP SETTING DEPTH MD Surface SETTING DEPTH TVD 2591502 BOTTOM TOP 15" Surface 22" HOLE SIZE AMOUNT PULLED 50-883-20031-00-00 NCIU A-11 332041 2586677 N/A CEMENTING RECORD 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7/16/2022 1302' FNL, 1023' FWL, Sec 6, T11N, R9W, SM, AK 1758' FNL, 915' FWL, Sec 31, T12N, R9W, SM, AK 169-089 / 322-048 / 322-136 Tertiary System Gas Pool 126.6' 3,520' MD / 3,047' TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas Driven Surface 621' 605 sx Conductor 735 sx Surface N/A SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 1231 sx9-5/8" TUBING RECORD WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Abandoned 7/16/2022 JSB RBDMS JSB 102722 RECEIVED by James Brooks at 4:27 pm, Sept 21, 2022 xGDSR-11/3/22 NCIU A-11 SFD 11/14/2022 As with NCIU A-09 and NCIU A-10A they were unable to get good cement into the IA through the punched tubing holes. So, as detailed on Sundry 322-136 the tubing was pulled and a CIBP was set in the 7-5/8" production casing, with 25' of cement atop it. -WCB 169-089 Abandoned WCB 4-27-2023 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A Top of Productive Interval N/A N/A Beluga 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Contact Email:cdinger@hilcorp.com Authorized Contact Phone: 777-8389 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: 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, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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. 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). 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. INSTRUCTIONS 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). Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): Formation at total depth: FORMATION TESTS Permafrost - Top This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Report. Signature w/Date: No NoSidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment For Monty MyersDigitally signed by Cody Dinger (2323) DN: cn=Cody Dinger (2323), ou=Users Date: 2022.10.25 14:42:00 -08'00' Cody Dinger (2323) Updated By: CJD 09/21/22 P&A Schematic North Cook Inlet Unit Tyonek Platform Well: NCI A-11 PTD: 169-089 API: 50-883-20031-00 Completion Equipment Information Item Depth MD Depth TVD ID OD Description 1 3,520’3,047’Whipstock 2A 3,539’CIBP 2B 3,837’3,051’CIBP Dump 50 Gal Cement on top (TOC @ 3,812’) 3 4,083’3,463’3.065 3.85 Straight Slot and Seal Units (10’ overall) 4,083’3,463’3.880 5.980 Otis “VSR” Hydraulic Set Retrievable Packer 4,096’3,472’3.969 5.740 Tubing Adapter and X-over 4 4,128’3,496’2.750 3.750 Otis X Landing Nipple 4,161’3,521’3.047 5.740 Tri-State High Pressure Pack-Off Overshot 5 4,182’3,536’4.00 6.00 Otis “RH”Hydraulic Set Retrievable Packer 6 4,318’3,637’2.75 Otis 3-1/2” “XA” Sliding Sleeve (Closed 12/5/10) 7 4,617’3,858’4.000 Baker Seal Unit 4,617’3,858’4.000 6.000 Baker Model “F” Permanent Packer 8 4,895’4,062’2.313 Otis 2-7/8” “XA” Sliding Sleeve (Open) 9 4,937’4,092’4.000 Baker Seal Unit 4,937’4,092’4.000 6.000 Baker Model “F” Permanent Packer 10 5,171’4,262’2.313 Otis 2-7/8” “XA” Sliding Sleeve (Closed) 11 5,211’4,290’4.000 Baker Seal Unit 5,211’4,290’4.000 6.000 Baker Model “F” Permanent Packer 12 5,536’4,514’2.313 Otis 2-7/8” “XA” Sliding Sleeve (Closed) 13 5,726’4,641’4.000 Baker Seal Unit 5,726’4,641’4.000 6.000 Baker Model “F” Permanent Packer 14 6,015’4,835’2.313 Otis 2-7/8” “XA” Sliding Sleeve (Open) 15 6,115’4,902’4.000 Baker Seal Unit 6,115’4,902’4.000 6.000 Baker Model “F” Permanent Packer 16 6,466’5,140’2.205 Otis “XN” Landing Nipple 17 6,497’5,161’3.725 4.987 WLREG Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) 30” Surf 380’ 16” 65 H-40 Surf 621” 10-3/4” 45.5 & 51 J-55 BTC Surf 2,745’ 7” 26 J-55 BTC Surf 77’ 7” 23 J-55 BTC 77’ 3,520’ (TOW) 7” 26 J-55 BTC 6,991’ 8,003’ Tubing Detail 4-1/2” 12.75 J-55 Mod EUE 8rd 3,870’ 4,083’ 3-1/2” 9.2 N-80 BTC 4,083’ 6,498’ Activity Date Ops Summary 3/4/2022 AKEL crew attends morning meeting and obtains permits, PJSM. Eline crew begins rigging up. Perform MIT-IA to 2200 psi for 30 minutes. Starting pressure 2284 psi, ending pressure 2280 psi - good test.,Finish rigging up eline and RIH with 3.70" gauge ring assembly. Drift and tag PBTD at 3892' uncorrected. POOH and inspect tools. Arm and RIH with 3' long 2" OD tubing puncher loaded with 19 shots. Punch from 3887-3890'. POOH and lay down tools, all shots fired.,Pump down tubing taking returns from the IA. IA initially on a vac. Establish returns from IA and shut in IA valve. Pressure test IA valve to 500 psi, good test. Open tubing and IA to check for flow, getting diesel returns from tubing side. Recover ~1 bbl diesel. Shut in tubing and IA. Rig up to circulate down the IA taking returns from the tubing at 7 gpm.,Circulate out ~4 barrels of clean diesel followed by ~3 barrels diesel / emulsion mix. Took 4 barrels of clean produced water returns. Secure well and SDFN. 3/5/2022 AKEL crew assembles and obtains permits, PJSM. Rig up eline. Check well for flow, IA and tubing are static.,Mix cement and fill 40' of 3.5" OD bailer with 17 gallons. RIH and tag PBTD @ 3892', pick up to 3870' and dump cement. POOH and re-arm dump bailer.,Mix cement and fill 40' of 3.5" OD bailer with 17 gallons. RIH and tag cement top @ 3870', pick up to 3850' and dump cement. POOH and lay down tools. Install tree cap on wireline valves.,Begin pumping drill water down the tubing with IA shut in until tool displacement is accounted for and 100 psi is built up on tubing side. Open IA and circulate out 40 gallons of cement while continuing to pump on tubing. Shut IA and trap 100 psi on tubing. Secure well and WOC. Estimated TOC is 3850'. 3/6/2022 AKEL crew assembles and obtains permits, PJSM. Rig up and check out Probe 1-11/16" radial CBL tool. Stand by for crane.,RIH with CBL tool, perform calibration and free pipe pass. Tag PBTD at 3847'. Log CBL off bottom but no cement is detected. It appears that the cement remained in the tubing during the IA displacement. POOH and RDMO eline. 3/16/2022 Spot eline equipment over from B-03 to A-11 and rig up. RIH with 4.5" jet cutter (3.5" running OD) and tagged at 3895', ~50' deeper than prior plugback depth (3847'). Appear to have made it down to the CIBP. POOH and disarm cutter.,RIH with 1-11/16" RCBL tool and perform free pipe calibration. Tag PBDT @ 3895'. Log out of hole but do not detect and cement behind pipe.,POOH and lay down tools. Secure well and SDFN while crane unloads boat. 3/17/2022 AKEL crew assembles and attends morning meeting. Obtain permits and hold PJSM. Warm up eline equipment.,Arm and RIH with 4.5" jet cutter (3.5" running OD). Cut tubing at 3870', good indication that cutter fired. POOH and lay down tools. Rig down and spot equipment on A-9.,Perform CMIT-TxIA to 2000 psi for 30 minutes. Starting pressure: 2104 psi. Ending pressure 2054 psi. Test passed. 4/22/2022 R/u circ eq. Circulated well STS (200bbls) with 8.4ppg drill water @ 3bpm/250psi. Returns clean 8.4ppg, S/d pump and monitored well static. R/d circ eq.,Set BPV on A-11. Nippled Down A-11 Tree and removed.,Installed blanking sub in hanger threads looked good. Installed BOPE stack and Risers. Hooked up choke and kill lines to mud cross.,Skidded carrier and racking mat over center of the well. Raised mast, scoped mast and tightened guy wires. Set koomy unit into place. Installed rig floor and finished RU for pulling 4.5'' tubing 4/23/2022 Connected Koomey control lines, M/u kill and choke lines, serviced rig and Inspected derrick, Installed tarps around cellar and warmed stack,R/u testing eq. , built test joint, function BOP's, flooded stack and purged BOPE, shell tested BOP's leaking on high test.,Troubleshot leak and found leak path at hanger seals, worked tools, Shell tested BOP's, good test.,Tested BOPE per Sundry as following: Annular 205-2500psi, Rams 250-3000psi, Valves 250-3000psi, tested gas detection and performed koomey drawdown test. Test was good. 4 1/2" TJ was used for testing. Witness waived by Jim Regg on 4/22/22 @ 4:32pm,L/d Testing eq. Pulled test dart and L/d TJ, Pulled BPV well static, P/u handling tools.,worked on BOLDS, had 1 LDS that seized,Pulled Hanger to rig floor 40k PUW no over pull. Terminated SSSV line and L/d Hanger and Landing Joint,POOH 4.5'' completion tubing F/3847' T/ Surface, L/d 124 joints and Cut JT was 21.80',R/U M/U AK EL 4/24/2022 Arm and RIH w/7" CIBP, tagged bottom @ 3,845', picked up to and set CIBP @ 3,837', tagged plug and confirm set, POOH L/d and inspect tool,,Mix and loaded 5" dump bailer with 25gals of 17ppg cement, RIH tagged CIBP @ 3837', picked up 15' and dumped cement on top of plug, POOH, Mix and loaded 5" dump bailer w/25gals of 17ppg cement. RIH t/ 3812' and dumped cement on top of plug, placing a total of 50gals on plug. M/u 5" bailer w/solid bottom, RIH and tagged TOC @ 3,812' confirming 25' of cement on plug @ 3,837',R/u testing eq. MIT-IA t/2500psi, charted for 30mins good test. R/d testing eq. MIT witness was waived by Jim Regg on 4/22/22 4:53pm Test Chart is in the DSM folder,Arm and RIH w/7" CIBP, correlated on depth with CBL 22APR1970, set CIBP @ 3,520', picked up 10' and RIH tag plug 3,520' to confirm set, POOH L/d and inspected tools. R/d EL and released crew.,Cleared and R/d work floor, removed eq. and racking mat for welder to make repairs,,Troubleshoot dead batteries on carrier, installed battery charger,Remove upper guy lines, scope down mast 1/2 way, unstring tuggers, man rider and drilling line off DW.,Prep carrier for transport, secured mast for laying over, removed lower mast guy wires, lower mast on to headache rack,N/D BOPE stack removing each section. removed riser and XO spacers,Installed dry hole tree,Cont'd Rigging down 404 and prepping carrier and skid beams for the boat. Removed walk ways off of carrier for boat transport. 4/25/2022 Perp eq. and loaded derrick, carrier, draw works and beam package on boat,Split up crew to offload boat on steelhead, Crew cont prep eq. and housekeeping,Loaded out work boat, cont housekeeping n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: NCIU A-11 North Cook Inlet Unit Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00028 NCIU A-11A PreDrill Spud Date: g RU for pulling 4.5'' tubing Tubing cut @3870' Passing PT on PC. -WCB RIH w/7" CIBP, tagged bottom @ 3,845', picked up to and set CIBP @ 3,837', tagged plug and confirm set, pgp y p Tag PBTD at 3847'. Log CBL off bottom but no cement is detected. It appears that the cement remained in the tubing during the IA displacement. They were unable to place cement in the IA. -WCB p gp pg Open IA and circulate out 40 gallons of cement while g continuing to pump on tubing. ,Perform CMIT-TxIA to 2000 psi for 30t@3870'PiPT PC Wy minutes. Starting pressure: 2104 psi. Ending pressure 2054 psi. Test passed. gg g y Punch from 3887-3890'. g t,POOH 4.5'' completion tubing F/3847' T/ Surface, ,Pump downp tubing taking returns from the IA. ,Mix cement and fill 40' of 3.5" OD bailer with 17pgp g gallons. RIH and tag PBTD @ 3892', pick up to 3870' and dump cement. POOH and re-arm dump bailer.,Mix cement and fill 40' of 3.5" OD bailer with 17 gallons. gg@ppp RIH and tag cement top @ 3870', pick up to 3850' and dump cement. ,Mix and loaded gg @ p p @ gg p g p 5" dump bailer with 25gals of 17ppg cement, RIH tagged CIBP @ 3837', picked up 15' and dumped cement on top of plug, POOH, Mix and loaded 5" dump bailer x gg @ p p @ gg p g pgppg gg@pp p w/25gals of 17ppg cement. RIH t/ 3812' and dumped cement on top of plug, placing a total of 50gals on plug. Rig up eline. gp They moved to the contingent step of pulling tbg and setting CIBP in the 7-5/8" casing, w/25' cement. -WCB 25' cement atop 7" CIBP confirmed. Passing "MIT-IA", confirming CIBP and cement plug. -WCB RIH and tagged TOC @ 3,812' confirming 25' of cement on plug @ 3,837',R/u testing eq. MIT-IA t/2500psi, charted for 30mins good test. R Tubing pulled. -WCB p g Drift and tag PBTD at 3892' uncorrected. ()pp Log out of hole but do not detect and cement behind pipe. CIBP set for whipstock. -WCB ,Arm and RIH with 4.5" jet cutter (3.5" runningj( ggg OD). Cut tubing at 3870', good indication that cutter fired. )gg Activity Date Ops Summary 7/14/2022 Skid rig from A-10B and center over NCIU A-11A. Secure rig. Fabricate and install stairs and landing. Modify flow line and work on rig acceptance chk list .;Remove dry hole tree. Install tbg spool and riser. Continue work rig acceptance chk list. Work boat. Clean pits and continue w/ flow line modification;Nipple up 13-5/8" 5M riser and BOPE stack. Continue work rig acceptance chk list. Clean pits and continue w/ flow line modification;Nipple up bell nipple and pollution pan. Install fill-up line and bleed off line. Check pre-charge on accumulator bottles. Continue work rig acceptance chk list.;Rig up to test BOPE. Make up test assemblies. Install test plug and fill stack with water. Flush Kill line and choke manifold. Continue work rig acceptance chk list.;Test BOPE per AOGCC/Hilcorp policy - 250/3000 psi for 5/5 charted min. Test upper rams, lower rams and annular with both 4" and 4.5" test joint.;Drilling - Inlet Water Use and Discharge Summary (bbls) Inlet Water Used Today: 0 Inlet Water Used Cumulative: 0 Discharge Today: 0 Discharge Cumulative: 0 Daily down hole loss: 0 Total down hole loss: 0;Metals Recovery (lbs) Today: 0 Cumulative: 0 7/15/2022 Continue and finish Testing BOPE per AOGCC/Hilcorp policy - 250/3000 psi for 5/5 charted min. Test upper rams, lower rams and annular with both 4" and 4.5" test joint. and build mud continue working rig acceptance check list;Preform accumulator draw down test continue build mud;R/dn test equipment. inspect and re- chk accumulator bottles pre charge, check for any leaking Shrader valves all good and continue build mud;Change out pop-off on koomey unit and install new annular regulator and inspect saver sub (good) and continue build mud;Level derrick (remove one 1/2" shim on ODS leg ) House clean all work areas and continue build mud;Install wear ring and M/up BHA #1 Clean out drift run. Continue build mud and work boat;RIH with BHA #1 f/ 292' t/ 765', picking up 4" drill pipe joints (12). Monitor well on trip tank - good displacement. Continue build mud, work boat and off-load cement pods;Cont. to RIH with BHA #1, cleanout assembly, f/ 765' and tag CIBP at 3539'. Monitor well on trip tank - good displacement. Continue build mud, work boat and off-load cement pods;Open and inspect suctions on mud pumps prior to beginning displacement to LSND. Continue to work boat and off-load cement pods;Displace well to 9.0 ppg LSND. 7.5 bpm, 700 psi. Wash and tag top of CIBP while displacing.;POOH with BHA #1, standing back drill pipe. Lay down bit, and scraper assembly. Monitor well on trip tank. Clean and clear rig floor.;Slip and cut drill line - cut 130' of 1-3/8" drill line. Remove and replace hose from load cell to weight indicator. Service top drive, drawworks and rig floor equipment.;Pressure test 7" casing to 2100 psi for 30 charted min.;Make up Whipstock / window milling assembly per WIS representative. Shallow test MWD tools and make up mills to whipstock. 7/16/2022 Finish Make up Whipstock / window milling assembly per WIS representative.;Rih slow 3 min std w/ whip stock assy on 4" dp out derrick t/ 3485' and fill pipe, monitoring well on trip tank w/ proper displacement;Brk circ @ 250 gom @ 850 psi and orient rih and trip and set whipstock off CIBP @ 3539' @ 21R HS and shear off. Up/Dn 103/98k;Calibrate flow sensor and align surface equipment for milling operations;Mill window in 7" as per W IS rep f/ 3520' t/ 3530' + 31' of new hole to 3561' at 250 gpm, 800 psi, 100 rpm, 3-5k Torque;Circulate 30 bbl High-vis sweep at 250 gpm, 800 psi. MW in/out = 9.0 ppg;Rig up and perform FIT. Top of window at 3520' MD, 3047' TVD, MW in/out = 9.0 ppg. Pressure up to 935 psi for an FIT 14.9 ppg EMW . Monitor OA during FIT - No pressure.;Rig down test equipment, flow check well - static and pump slug for pulling out of the hole.;Pull out of the hole and lay down milling assembly f/3520'. Lead mill 1/8" under, follow mill 1/8" under, and gage mill 1/16" under.;Make up stack flushing tool and flush stack, choke and kill lines.;Clean and clear rig floor. Service top drive and rig floor equipment.;Make up BHA #3, 6-1/8" drilling assembly per DD / MWD. 6-1/8" Smith X516, 1.5° Motor, and slimmed down MWD tool suite (DM, GM and TM HOC) to 528'. Shallow test MWD tools - good. Perform kick while tripping drill with rig crew - well secured at 1min 55 sec.;Trip in the hole with BHA #3 on 4" drill pipe stands out of the derrick f/528' to top of window. Orient motor at 3500' prior to exiting window. Slide through window with no issues.;Drill 6-1/8" hole per DD and wp04 f/ 3561' t/ 3625' (64' at 32 fph ave ROP) 254 gpm, 919 psi, 80 rpm, 5k tq, 95k up, 90k dn, 95k rot MW in/out = 9.0 ppg;Drilling - Inlet Water Use and Discharge Summary (bbls) Inlet Water Used Today: 254 Inlet Water Used Cumulative: 630 Discharge Today: 2 Discharge Cumulative: 2 Daily down hole loss: 0 Total down hole loss: 0;Metals Recovery (lbs) Today: 51.5 Cumulative: 51.5 n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: NCIU A-11A North Cook Inlet Unit Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00028 NCIU A-11A Drilling Spud Date: p @ ;Mill window in 7" as per WIS rep f/ 3520' t/ 3530' + 31' of new p hole to 3561' ;Rig up and perform FIT. Top p gp p p q g p gp p of window at 3520' MD, 3047' TVD, MW in/out = 9.0 ppg. Pressure up to 935 psi for an FIT 14.9 ppg EMW . Whipstock set. Window milled @3520-3530, plus 31' of new formation. FIT of 14.9 ppg. -WCB y p set whipstock off CIBP @ 3539' fp @ Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 4/20/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NCI A-11 (PTD 169-089) Jet Cut 3/17/2022 Please include current contact information if different from above. PTD:169-089 T36586 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.11 11:43:08 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wade Hudgens - (C) To:DOA AOGCC Prudhoe Bay;Regg, James B (OGC);Brooks, Phoebe L (OGC) Cc:Juanita Lovett;"AAO Offshore" Subject:HAK 404/NCIU A-11/BOPE Test Report 4-23-22 Date:Tuesday, April 26, 2022 5:55:27 PM Attachments:HAK 404 4-23-2022.xlsx Please see attached BOPE Test Report for NCIU A-11. Thank You, Wade Hudgens WSM, Rig 404 Hilcorp Alaska C: 903-331-6711 O:907-776-6754 whudgens@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1&,8$ 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:404 DATE: 4/23/22 Rig Rep.: Rig Phone: 907-776-6754 Operator: Op. Phone:907-776-6754 Rep.: E-Mail Well Name: PTD #11690890 Sundry #322-136 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250-3000 Annular:250-2500 Valves:250-3000 MASP:1154 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 13-5/8 5m P Pit Level Indicators PP #1 Rams 1 2 7/8 x 5 1/2 vbr's P Flow Indicator NA NA #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 2-1/16 5m P Inside Reel valves 0NA HCR Valves 2 2-1/16 5m P Kill Line Valves 2 2-1/16 5m P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0NA Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)1850 P Quantity Test Result 200 psi Attained (sec)19 P No. Valves 11 P Full Pressure Attained (sec)83 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 4 x 2200 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:4.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 4-22-22/09:32am Waived By Test Start Date/Time:4/23/2022 12:30 (date) (time)Witness Test Finish Date/Time:4/23/2022 16:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp Test was performed w/ 4 1/2" TJ, Annular close 19 sec Chad Johnson / Joe Steiner Hilcrop AK Wade Hudgens / Luke Moore NCIU A-11 Test Pressure (psi): whudgens@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0423_BOP_Hilcorp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a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y Samantha Carlisle at 7:48 am, Mar 16, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH ; %-0 ; 6)' %23 WHVW WR SVL $QQXODU WHVW WR SVL 6DPH WHVW SUHVVXUH IRU ERWK +LOFRUS ULJ DQG 6SDUWDQ XQOHVV ILUVW WHVW RI WKH VHDVRQ WKHQ WHVW WR 5:3 RI %23V '65 -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.03.23 11:30:21 -08'00' RBDMS SJC 033022 ŚĂŶŐĞŽĨtĞůůtŽƌŬ tĞůů͗EŽƌƚŚŽŽŬ/ŶůĞƚͲϭϭ ĂƚĞ͗ϯͬϭϱͬϮϬϮϮ tĞůůEĂŵĞ͗E/hͲϭϭZĞǀϭ W/EƵŵďĞƌ͗ϱϬͲϴϴϯͲϮϬϬϯϭͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗WƌŽĚƵĐĞƌʹ^ƵƐƉĞŶĚĞĚ>ĞŐ͗>ĞŐηϮ^tŽƌŶĞƌ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ϬϯͬϭϴͬϮϮZŝŐ͗ϰϬϰΘ^ƉĂƌƚĂŶϭϱϭ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍ϰϬϯĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ϮͬϭϭͬϮϮ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ŽŶŶĂŵďƌƵǌ;ϴϯϬϱͿWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϲϵͲϬϴϵ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ŚĂĚ,ĞůŐĞƐŽŶ;ϵϬϳͿͲϳϳϳͲϴϰϬϱ;KͿ;ϵϬϳͿϮϮϵͲϰϴϮϰ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗^ĞĂŶDĐůĂƵŐŚůŝŶ;ϵϬϳͿϮϮϯͲϲϳϴϰ;DͿ This change of program replaces step 9 to the final step of approved sundry #322-048. 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2/10/2022 JLC 2/10/2022 Jeremy Price Digitally signed by Jeremy Price Date: 2022.02.11 09:30:05 -09'00' RBDMS SJC 021122 tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůů͗EŽƌƚŚŽŽŬ/ŶůĞƚͲϭϭ ĂƚĞ͗ϭͬϮϳͬϮϬϮϮ tĞůůEĂŵĞ͗E/hͲϭϭ W/EƵŵďĞƌ͗ϱϬͲϴϴϯͲϮϬϬϯϭͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗WƌŽĚƵĐĞƌʹ^ƵƐƉĞŶĚĞĚ>ĞŐ͗>ĞŐηϮ^tŽƌŶĞƌ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ϬϯͬϭϱͬϮϮZŝŐ͗^ƉĂƌƚĂŶϭϱϭ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍ϰϬϯĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ŽŶŶĂŵďƌƵǌ;ϴϯϬϱͿWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϲϵͲϬϴϵ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ŚĂĚ,ĞůŐĞƐŽŶ;ϵϬϳͿͲϳϳϳͲϴϰϬϱ;KͿ;ϵϬϳͿϮϮϵͲϰϴϮϰ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗^ĞĂŶDĐůĂƵŐŚůŝŶ;ϵϬϳͿϮϮϯͲϲϳϴϰ;DͿ Current Bottom Hole Pressure: N/A Fluid Gradient, well isolated Maximum Expected BHP: 1,500 psi @ 3,463’ TVD 0.433 psi/ft gradient to surface Maximum Potential Surface Pressure: 1,154 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) ƌŝĞĨtĞůů^ƵŵŵĂƌǇ dŚĞE/hͲϭϭǁĂƐŽƌŝŐŝŶĂůůǇĚƌŝůůĞĚŝŶϭϵϲϵ͘dŚĞǁĞůůǁĂƐĐŽŵƉůĞƚĞĚŝŶϭϵϳϱĂƐĂĞůƵŐĂƉƌŽĚƵĐŝŶŐ ǁĞůů͘dŚĞƚŽƉũŽŝŶƚŽĨϳ͟ĐĂƐŝŶŐĐŽůůĂƉƐĞĚĚƵƌŝŶŐƚŚĞǁŽƌŬŽǀĞƌĂŶĚǁĂƐƌĞƉůĂĐĞĚŝŶϭϵϳϱ͘dŚĞƌĞŝƐĂ 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the attached Oct 2, 2002 correspondence, he says that “Subsequent abandonment plugs will be set when the sidetrack is begun”. This is where Hilcorp is at now. There is currently no cement in the casing above the top perf. Your next step to abandon A-11 is to cut tubing as deep as possible above the cement top in the tubing, set a CIBP just above the tubing stub and dump bail minimum 25’ of cement per 20 AAC 25.112(c)(1)(E). When you come back to sidetrack A-11 next year, that is what you should plan. The regulation calls for the plug to be within 50’ of the top perf, but I would consider an exception due to the existing cement blocking access inside the tubing. The proposed liner lap cement in the planned A-11A sidetrack does not meet AOGCC regulations as a P&A plug to isolate the existing wellbore from the future sidetrack. If you are not planning to drill A-11A this year, you should withdraw the application for PTD. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Sean Mclaughlin <Sean.Mclaughlin@hilcorp.com> Sent: Wednesday, September 1, 2021 9:01 AM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Monty Myers <mmyers@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Karson Kozub - (C) <kkozub@hilcorp.com> Subject: RE: NCI A-11 historical records Bryan, Below is for background information and historical perspective. Hilcorp Engineers have received feedback that some of the AOGCC submissions are sloppy and incompetent. Hopefully this information below demonstrates a thorough review of the well information was completed and the Sundry was submitted with understanding of plugging requirements of 20 AAC 25.112. We understand the AOGCC may have a different view or interpretation. Unfortunately we need to alter course for a third Tyonek well. A-11A was chose party because it had the lowest subsurface risk. The surface complexity of moving the rig and setting up for a drilling operation on a different leg is higher than originally anticipated. We need more time to plan the surface layout and equipment modifications if the Rig is on leg #2. The team has identified a target from A-01 and no rig more would be required. We will be sending over a Sundry and PTD application for A-01 ASAP. A-11 will be drilled next year. Would you like to put A-11 on the back burner or does it need to be withdrawn? Regards, sean From: Sean Mclaughlin Sent: Tuesday, August 31, 2021 6:22 PM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Monty Myers (mmyers@hilcorp.com) <mmyers@hilcorp.com>; Aras Worthington (Aras.Worthington@hilcorp.com) <Aras.Worthington@hilcorp.com>; Karson Kozub - (C) <kkozub@hilcorp.com> Subject: NCI A-11 historical records Bryan, I have attached the historical records for NCI A-11 for your review. I had understood that the operations conducted in 2002 met the requirements for plugging perforations per 20 AAC 25.112(c) (C) and 20 AAC 25.112(c)(E). AOGCC approval was given to conduct plugging operations without removing the bridge plug. This was completed with a test, tag, and an approved completion report stating “all perfs P&A’d”. I believed this met well plugging requirements stated in 20 AAC 25.112. This is further evidenced by the 2006 plan to prepare the well for Class II disposal. The plugging of existing perfs was honored and no additional plugs or cement was required in the approved Sundry. I have attached that Sundry and schematic for review as well. During the drilling phase there is an opportunity to provide another layer of protection. A CIBP, liner lap cement, and a liner top packer will also prevent the movement of fluid from the perforations below. This barrier is also important in future P&A operations. This is what I referred to as alternate plug placement per 20 AAC 25.112(i). Fluid movement from the parent well into the sidetrack was not deemed a risk because of the P&A of all perfs in 2002. Given the 2002 approved perforation plugging per 20 AAC 25.112 is a casing plug, cement, and tag required ahead of the sidetrack to meet 20 AAC 25.112? Regards, sean Sean McLaughlin Hilcorp Alaska, LLC Drilling Engineer Sean.McLaughlin@hilcorp.com Cell: 907-223-6784 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. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: 3800 Centerpoint Drive, Suite 1400 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): North Cook Inlet Unit / Tertiary System Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,212'N/A Casing Collapse Structural Conductor 670 psi Surface 2,090 psi Intermediate Production 3,270 psi 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 Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:kkozub@hilcorp.com Contact Phone: (907) 570-1801 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 Other: PB for Sidetrack 6,323' 3,946' 3,361' 1,154 psi 6,181'7" Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 10/5/2021 4-1/2" & 3-1/2" Daniel E. Marlowe See schematic N/A See schematic Tubing Grade: Tubing MD (ft): N/A Perforation Depth TVD (ft): 12.6 J-55 / 12.75 J-55 / 9.2 N-80 2,745' 8,003' Perforation Depth MD (ft): 8,003' 2,484' 621' 2,745' 379'380' 30" 16" 10-3/4" 621' TVD Burst 4,083 & 6,498 4,360 psi Tubing Size: MD 1,640 psi 3,580 psi 620' 169-089 50-883-20031-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC N/A N Cook Inlet Unit A-11 COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 Authorized Signature: Operations Manager Karson Kozub PRESENT WELL CONDITION SUMMARY Length Size 3,946' 380' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 6:49 pm, Aug 25, 2021 321-424 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.08.25 13:35:50 -08'00' Dan Marlowe (1267) See 20 AAC 25.990 (63) SFD 8/26/2021 SFD 8/26/2021 DSR-8/25/21 10-407onnRequired? Yes No Subsequennt Formm Req COMMMMIS SIO on eq COMMISSIO on eq COMMIS SIO XX Well Work Prognosis Well Name:NCIU A-11 API Number: 50-883-20031-00-00 Current Status:Producer – Suspended Leg:Leg #2 SW Corner Estimated Start Date:10/05/21 Rig:Spartan 151 Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:169-089 First Call Engineer:Karson Kozub (907) 570-1801 (M) Second Call Engineer:Katherine O’Connor (907) 777-8376 (O) (214) 684-7400 (M) Current Bottom Hole Pressure:N/A Maximum Expected BHP:1,500 psi @ 3,463’ TVD 0.433 psi/ft gradient to surface Maximum Potential Surface Pressure: 1,154 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary The NCIU A-11 was originally drilled in 1969. The reservoir was abandoned, and the well was suspended in October 2002. TOC was tagged at 3965’ MD and pressure tested to 1975 psi for 30 min. In September 2020 the well passed an MITIA to 1500 psi in order to renew its suspended status. The work proposed will set up the well for a sidetrack. Pre-rig work: 1. Fluid pack well as needed 2. MITIA to 3,000 psi and chart for 30 minutes 3. MITOA to 1,500 psi and chart for 30 minutes Procedure: 1.MIRU Spartan 151 2. Set BPV, ND tree 3. NU BOPE and test to 250psi low/3,000psi high. (PTD - MASP 2,876 psi) x *Notify AOGCC 48 hours in advance of test to allow them to witness. 4. RU EL pressure test lubricator to 250psi low/1,500psi high x Cut tubing at ~3600’ MD x RD EL x * Contingent – may be done pre-rig 5. Circulate well with produced water as needed 6. Pull 4-1/2” tubing, fishing as needed 7. RIH with clean out assembly, bit and scraper to ±3600’. x Circulate well clean 8. Set 7” CIBP at ±3530’ MD 9. Set whipstock at 3500’ and 15R ***Remaining Procedure to be included on the Permit to Drill for the sidetrack*** Phase II General sequence of operations pertaining to drilling procedure: (informational only) 1. Swap well to 10.3 ppg LSND mud. 2. Mill window with 20’ of new formation. 3. Perform FIT to 14.8 ppg EMW 4. PU 6-1/8” motor drilling assembly and TIH to window. SFD See 20 AAC 25.990 (63) SFD 8/26/2021 redrilling redrill TOC was tagged at 3965’ MD and pressure tested to 1975 psi for 30 min. +/-15' above tubing stub. Tag plug to confirm set. 8.a. Dump bail 25' of cement on top of CIBP. 3900', or as close as feasible to top perf. Remaining program is part of a PTD application, not included in this sundry. tubing cut depth. Well Work Prognosis 5. Drill 6-1/8” production hole to 9093 MD, performing short trips as needed 6. POOH w/ directional tools. 7. RIH w/ 4-1/2” liner. Set liner and cement. Circ wellbore clean. 8. Perform casing test to 2180 psi. 9. Run 4-1/2” completion. (Covered under separate sundry) 10. Land hanger and test. 11. ND BOPE, NU tree and test void Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic 4. BOP Drawing – Spartan 151 5. Fluid Flow Diagrams –Spartan 151 6. Sundry Revision Change Form Updated By: JLL 08/17/20 SCHEMATIC North Cook Inlet Unit Tyonek Platform Well: NCI A-11 PTD: 169-089 API: 50-883-20031-00 Completed: 05/03/1970 Completion Equipment Information Item Depth MD Depth TVD ID OD Description 38.90 38.90 3.958 6.000 FMC/OCT 6” 3M 4-1/2” 8rd x 4-1/2” BT&C Tbg Hanger 1 298’ 298’ 3.813 5.563 Halliburton SCSSV Landing Nipple (pulled SSSV 12/5/01) 2 4,083’ 3,463’ 3.065 3.85 Straight Slot and Seal Units (10’ overall) 4,083’ 3,463’ 3.880 5.980 Otis “VSR” Hydraulic Set Retrievable Packer 4,096’ 3,472’ 3.969 5.740 Tubing Adapter and X-over 3 4,128’ 3,496’ 2.750 3.750 Otis X Landing Nipple 4,161’ 3,521’ 3.047 5.740 Tri-State High Pressure Pack-Off Overshot 4 4,182’ 3,536’ 4.00 6.00 Otis “RH” Hydraulic Set Retrievable Packer 5 4,318’ 3,637’ 2.75 Otis 3-1/2” “XA” Sliding Sleeve (Closed 12/5/10) 6 4,617’ 3,858’ 4.000 Baker Seal Unit 4,617’ 3,858’ 4.000 6.000 Baker Model “F” Permanent Packer 7 4,895’ 4,062’ 2.313 Otis 2-7/8” “XA” Sliding Sleeve (Open) 8 4,937’ 4,092’ 4.000 Baker Seal Unit 4,937’ 4,092’ 4.000 6.000 Baker Model “F” Permanent Packer 9 5,171’ 4,262’ 2.313 Otis 2-7/8” “XA” Sliding Sleeve (Closed) 10 5,211’ 4,290’ 4.000 Baker Seal Unit 5,211’ 4,290’ 4.000 6.000 Baker Model “F” Permanent Packer 11 5,536’ 4,514’ 2.313 Otis 2-7/8” “XA” Sliding Sleeve (Closed) 12 5,726’ 4,641’ 4.000 Baker Seal Unit 5,726’ 4,641’ 4.000 6.000 Baker Model “F” Permanent Packer 13 6,015’ 4,835’ 2.313 Otis 2-7/8” “XA” Sliding Sleeve (Open) 14 6,115’ 4,902’ 4.000 Baker Seal Unit 6,115’ 4,902’ 4.000 6.000 Baker Model “F” Permanent Packer 15 6,466’ 5,140’ 2.205 Otis “XN” Landing Nipple 16 6,497’ 5,161’ 3.725 4.987 WLREG PBTD: 3,946’ TD: 8,212’ 30” RKB: MSL = 96’ 4225-26 (sqz) 3 4 6 7 8 9 10 11 12 13 CIBP @ 7,125’ 10-3/4” 7” 1 2 TOC @ 3,946 (10/2006) 14 15 16 16” CIBP @ 4,966 (12/01) not milled Cement retainer @ 4,623 Cement retainer @ 4,065 4254-4284 Stray 4306-07 (sqz) 4624-25 (sqz) 4657-4702 CI-1.0 4715-4805 CI-2.0 4816-4846 CU-3.0 4853-4867 CI-3.1 4977-4987 CI-5.0 5039-5089 CI- 5.1&6.0 5107-5137 CI-6.2 5845-5859 B-7 5871-5877 B-8 5899-5909 C-0.5 5930-5950 C-1 5962-5974 C-2 5248-5262 CI-8.0 5280-5285 CI-8.2 5289-5307 CI-8.2 5358-5368 CI-9.0 5399-5419 CI-10.0 5450-5460 CI-11.0 5468-5498 CI-11.0 6182-6197 D-3 6212-6218 D-3.5 6246-6266 D-4 6272-6278 D-5 6449-6464 E-8 7176-7196 J-7 7267-7277 J-2 5 X XN Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) 30” Surf 380’ 16” 65 H-40 Surf 621” 10-3/4” 45.5 & 51 J-55 BTC Surf 2,745’ 7” 26 J-55 BTC Surf 77’ 7” 23 J-55 BTC 77’ 6,991’ 7” 26 J-55 BTC 6,991’ 8,003’ Tubing Detail 4-1/2” 12.6 J-55 Mod BTC Surf 333’ 4-1/2” 12.75 J-55 Mod EUE 8rd 333’ 4,083’ 3-1/2” 9.2 N-80 BTC 4,083’ 6,498’ Updated By: JLL 08/24/21 PROPOSED North Cook Inlet Unit Tyonek Platform Well: NCI A-11 PTD: 169-089 API: 50-883-20031-00 Completion Equipment Information Item Depth MD Depth TVD ID OD Description 1 ±3,500’ ±3,028’ Whipstock 2 ±3,530’ ±3,051’ CIBP 3 4,083’ 3,463’ 3.065 3.85 Straight Slot and Seal Units (10’ overall) 4,083’ 3,463’ 3.880 5.980 Otis “VSR” Hydraulic Set Retrievable Packer 4,096’ 3,472’ 3.969 5.740 Tubing Adapter and X-over 4 4,128’ 3,496’ 2.750 3.750 Otis X Landing Nipple 4,161’ 3,521’ 3.047 5.740 Tri-State High Pressure Pack-Off Overshot 5 4,182’ 3,536’ 4.00 6.00 Otis “RH” Hydraulic Set Retrievable Packer 6 4,318’ 3,637’ 2.75 Otis 3-1/2” “XA” Sliding Sleeve (Closed 12/5/10) 7 4,617’ 3,858’ 4.000 Baker Seal Unit 4,617’ 3,858’ 4.000 6.000 Baker Model “F” Permanent Packer 8 4,895’ 4,062’ 2.313 Otis 2-7/8” “XA” Sliding Sleeve (Open) 9 4,937’ 4,092’ 4.000 Baker Seal Unit 4,937’ 4,092’ 4.000 6.000 Baker Model “F” Permanent Packer 10 5,171’ 4,262’ 2.313 Otis 2-7/8” “XA” Sliding Sleeve (Closed) 11 5,211’ 4,290’ 4.000 Baker Seal Unit 5,211’ 4,290’ 4.000 6.000 Baker Model “F” Permanent Packer 12 5,536’ 4,514’ 2.313 Otis 2-7/8” “XA” Sliding Sleeve (Closed) 13 5,726’ 4,641’ 4.000 Baker Seal Unit 5,726’ 4,641’ 4.000 6.000 Baker Model “F” Permanent Packer 14 6,015’ 4,835’ 2.313 Otis 2-7/8” “XA” Sliding Sleeve (Open) 15 6,115’ 4,902’ 4.000 Baker Seal Unit 6,115’ 4,902’ 4.000 6.000 Baker Model “F” Permanent Packer 16 6,466’ 5,140’ 2.205 Otis “XN” Landing Nipple 17 6,497’ 5,161’ 3.725 4.987 WLREG PBTD: 3,946’ TD: 8,212’ 30” RKB: MSL = 96’ 4225-26 (sqz) 2 4 5 7 8 9 1 0 11 12 13 14 CIBP @ 7,125’ 10-3/4” 7” 1 3 TOC @ 3,946 (10/2006) 15 16 17 16” CIBP @ 4,966 (12/01) not milled Cement ret ainer @ 4,623 Cement retainer @ 4,065 4254-4284 Stray 4306-07 (sqz) 4624-25 (sqz) 4657-4702 CI-1.0 4715-4805 CI-2.0 4816-4846 CU-3.0 4853-4867 CI-3.1 4977-4987 CI-5.0 5039-5089 CI- 5.1&6.0 5107-5137 CI-6.2 5845-5859 B-7 5871-5877 B-8 5899-5909 C-0.5 5930-5950 C-1 5962-5974 C-2 5248-5262 CI-8.0 5280-5285 CI-8.2 5289-5307 CI-8.2 5358-5368 CI-9.0 5399-5419 CI-10.0 5450-5460 CI-11.0 5468-5498 CI-11.0 6182-6197 D-3 6212-6218 D-3.5 6246-6266 D-4 6272-6278 D-5 6449-6464 E-8 7176-7196 J-7 7267-7277 J-2 Tubing Cut @ ±3,600’ CIBP @ ±3,530’ Whipstock @ ±3,500’ 6 X XN Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) 30” Surf 380’ 16” 65 H-40 Surf 621” 10-3/4” 45.5 & 51 J-55 BTC Surf 2,745’ 7” 26 J-55 BTC Surf 77’ 7” 23 J-55 BTC 77’ ±3,500’ (TOW) 7” 26 J-55 BTC 6,991’ 8,003’ Tubing Detail 4-1/2” 12.75 J-55 Mod EUE 8rd ±3,600’4,083’ 3-1/2” 9.2 N-80 BTC 4,083’ 6,498’ Tyonek Platform A-11 Current 08/10/2021 Tubing head, FMC-TC-OO, 11 3M x 9 3M, w/ 2- 2 1/16 5M SSO Valve, Master, FMC-120, 4 1/16 3M FE, HWO, AA trim Valve, Upper master, SSV FMC-120, 4 1/16 3M FE, w/ FMC PA operator, EE trim Valve, Swab, FMC-120 4 1/16 3M FE, HWO, DD trim BHTA, Otis, 4 1/16 3M FE x 7.5'’ Otis quick union top 16'’ 7'’ Starting head, OCT-C29-L, 16'’ 3M x 16'’ SOW, w/ 2- 2 1/16 5M EFO Casing spool, OCT- C-29L-OO 16'’ 3M x 11 3M, w/ 2- 2 1/16 5M EFO Tyonek Platform A-11 16 x 10 ¾ x 7 x 4 ½ Valve, Wing, SSV, FMC-120, 4 1/16 3M FE, w/ 15'’ Axelson MHA operator, EE trim Tubing hanger, FMC-TC-EN- CL, 9 x 4 ½ EUE 8rd lift and 4 ½ IBT susp, w/ 4'’ type IS- BPV profile, 1- ¼npt control line port Adapter, FMC-A5P-CL, 9'’ 3M FE x 4 1/16 3M 4 ½’’ 10 ¾’’ 1. BOP Schematic 2. Choke Manifold Schematic Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: N Cook Inlet Unit A-11 (PTD 169-089)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. The drilling engineers will serve as quality control for steps 1 and 2. Geologist then Drrilling Engineer (QC) 3 When the Stat Tech receives "a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Stat Tech 4 When the Stat Tech receives any Form 10-407, they will check the History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Stat Tech 5 When the Form 10-407 for the redrill is received, the Stat Tech will change the original well's status from SUSPENDED to ABANDONED. Stat Tech 6 The first week of every January and July, the Stat Tech and one of the Geologists will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. Stat Tech Geologist X SFD 8/26/2021 SFD 8/26/2021 321-424 X 1 Carlisle, Samantha J (CED) From:Karson Kozub - (C) <kkozub@hilcorp.com> Sent:Tuesday, August 31, 2021 12:32 PM To:McLellan, Bryan J (CED) Cc:Aras Worthington; Carlisle, Samantha J (CED) Subject:RE: [EXTERNAL] NCIU A-11 (PTD 169-089) Plug for redrill Sundry application Hello Bryan, Thank you for reviewing the sundry. I will update the Sundry to ensure we meet 20 AAC 25.112(c)(1)(E). Regards, Karson Kozub Mobile: +1 (907) 570-1801 kkozub@hilcorp.com From: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Sent: Tuesday, August 31, 2021 11:37 AM To: Karson Kozub ‐ (C) <kkozub@hilcorp.com> Cc: Aras Worthington <Aras.Worthington@hilcorp.com>; Carlisle, Samantha J (CED) <samantha.carlisle@alaska.gov> Subject: [EXTERNAL] NCIU A‐11 (PTD 169‐089) Plug for redrill Sundry application Hi Karson, Please resubmit a Sundry for plugging this well with a compliant abandonment plug. You need to set the plug as close to top perf as possible and place cement on top per 20 AAC 25.112(c)(1)(E). Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250‐9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you 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. 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 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): North Cook Inlet Unit / Tertiary Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 8,212'N/A Casing Collapse Structural Conductor 670 psi Surface 2,090 psi Intermediate Production 3,270 psi 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 Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 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 Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size 3,965' 380' COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 169-089 50-883-20031-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC N/A N Cook Inlet Unit A-11 TVD Burst 4,083 & 5,162 4,360 psi Tubing Size: MD 1,640 psi 3,580 psi 620' 2,484' 621' 2,745' 379'380' 30" 16" 10-3/4" 621' 2,745' 8,003' Perforation Depth MD (ft): N/A 8,003' N/A Tubing Grade:Tubing MD (ft): N/A Perforation Depth TVD (ft): Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. N/A 4-1/2" & 3-1/2" Daniel E. Marlowe N/A 12.6 J-55 / 12.75 J-55 / 9.2 N-80 Other: Suspended Well Renewal 6,297'3,965'3,375'0 psi 6,181'7" Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Jody Colombie at 3:03 pm, Sep 03, 2020 320-369 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.09.03 13:47:01 -08'00' Dan Marlowe (1267) DSR-9/3/2020DLB 09/03/2020 X Suspended Well Renewal No form required * suspended status valid for 10 yrs (Next inspection required in 5 yrs ) Suspended gls 9/17/20 Comm. 9/18/2020 dts 9/18/2020 JLC 9/18/2020 RBDMS HEW 9/21/2020 Suspended Well Inspection Data Well: NCI A-11 Surface Location: 1302’ FNL, 1021’ FWL, Sec 6, T11N, R9W S.M. Permit to Drill: 169-089 API: 50-883-20031-00-00 AOGCC Inspection Date: 08/14/20 AOGCC Inspector: Mr. Lou Laubenstein Size Pressure (psi) Tubing 3-1/2” & 4-1/2” 4 Casing 7” 40 OA 10-3/4” 110 OOA 16” 0 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: x The A-11 well was drilled to a TD of 8,212’ with 7” casing in October 1969. A 4” completion was installed in April/May 1970. x Subsequent RWOs occurred in July 1975 to pull/replace existing completion with a 4” x 3-1/2” completion, July 1983 that installed 3-1/2” multi-packer completion, and most recently in May 1994 to replace 3-1/2” tubing above production packer with 4-1/2” tubing. x A-11 was suspended in October 2002. The reservoir abandonment left the well in the following condition: plug #1 set a cement retainer in 3-1/2” tubing at 4,623’CTM with 13.5bbl Class G cement pumped below and 0.5bbl cement on top of retainer; plug #2 set retainer in 4-1/2” tubing at 4,065’CTM with 15bbl cement pumped below retainer and 5bbl Class G cement laid above retainer for hesitation squeeze, performed hesitation squeeze, leaving 0.5bbl cement above retainer; tubing circulated with seawater and ~500ft diesel freeze protect. Abandonment plug was tagged at 3,965’ (est. 100ft cement above retainer) and pressure tested to 1,975psi for 30min. x The flowline has been removed and the well is not connected to the production facilities. x At this time there are no immediate plans to recomplete or sidetrack A-11. x Hilcorp requests that A-11 maintains suspended status due to it being located on an active gas platform, Tyonek, such that future gas development opportunities can be obtained from this wellbore. x Condition of Wellhead – Well looks good x Condition of Surrounding Surface Location: Good x Follow Up Actions needed: None Attachments: x Current Well Schematic x Picture(s) x Plat - 1/4mile radius of wellbore (tapered string) (IA MIT required for re-issue of suspend status .. done 9/17/20)) MIT-IA required and completed 9 /17/20. Updated By: JLL 08/17/20 SCHEMATIC North Cook Inlet Unit Tyonek Platform Well: NCI A-11 PTD: 169-089 API: 50-883-20031-00 Completed: 05/03/1970 Completion Equipment Information Item Depth MD Depth TVD ID OD Description 38.90 38.90 3.958 6.000 FMC/OCT 6” 3M 4-1/2” 8rd x 4-1/2” BT&C Tbg Hanger 1 298’ 298’ 3.813 5.563 Halliburton SCSSV Landing Nipple (pulled SSSV 12/5/01) 2 4,083’ 3,463’ 3.065 3.85 Straight Slot and Seal Units (10’ overall) 4,083’ 3,463’ 3.880 5.980 Otis “VSR” Hydraulic Set Retrievable Packer 4,096’ 3,472’ 3.969 5.740 Tubing Adapter and X-over 3 4,128’ 3,496’ 2.750 3.750 Otis X Landing Nipple 4,161’ 3,521’ 3.047 5.740 Tri-State High Pressure Pack-Off Overshot 4 4,182’ 3,536’ 4.00 6.00 Otis “RH” Hydraulic Set Retrievable Packer 5 4,318’ 3,637’ 2.75 Otis 3-1/2” “XA” Sliding Sleeve (Closed 12/5/10) 6 4,617’ 3,858’ 4.000 Baker Seal Unit 4,617’ 3,858’ 4.000 6.000 Baker Model “F” Permanent Packer 7 4,895’ 4,062’ 2.313 Otis 2-7/8” “XA” Sliding Sleeve (Open) 8 4,937’ 4,092’ 4.000 Baker Seal Unit 4,937’ 4,092’ 4.000 6.000 Baker Model “F” Permanent Packer 9 5,171’ 4,262’ 2.313 Otis 2-7/8” “XA” Sliding Sleeve (Closed) 10 5,211’ 4,290’ 4.000 Baker Seal Unit 5,211’ 4,290’ 4.000 6.000 Baker Model “F” Permanent Packer 11 5,536’ 4,514’ 2.313 Otis 2-7/8” “XA” Sliding Sleeve (Closed) 12 5,726’ 4,641’ 4.000 Baker Seal Unit 5,726’ 4,641’ 4.000 6.000 Baker Model “F” Permanent Packer 13 6,015’ 4,835’ 2.313 Otis 2-7/8” “XA” Sliding Sleeve (Open) 14 6,115’ 4,902’ 4.000 Baker Seal Unit 6,115’ 4,902’ 4.000 6.000 Baker Model “F” Permanent Packer 15 6,466’ 5,140’ 2.205 Otis “XN” Landing Nipple 16 6,497’ 5,161’ 3.725 4.987 WLREG PBTD: 3,946’ TD: 8,212’ 30” RKB: MSL = 96’ 4225-26 (sqz) 3 4 6 7 8 9 10 11 12 13 CIBP @ 7,125’ 10-3/4” 7” 1 2 TOC @ 3,946 (10/2006) 14 15 16 16” CIBP @ 4,966 (12/01) not milled Cement retainer @ 4,623 Cement retainer @ 4,065 4254-4284 Stray 4306-07 (sqz) 4624-25 (sqz) 4657-4702 CI-1.0 4715-4805 CI-2.0 4816-4846 CU-3.0 4853-4867 CI-3.1 4977-4987 CI-5.0 5039-5089 CI- 5.1&6.0 5107-5137 CI-6.2 5845-5859 B-7 5871-5877 B-8 5899-5909 C-0.5 5930-5950 C-1 5962-5974 C-2 5248-5262 CI-8.0 5280-5285 CI-8.2 5289-5307 CI-8.2 5358-5368 CI-9.0 5399-5419 CI-10.0 5450-5460 CI-11.0 5468-5498 CI-11.0 6182-6197 D-3 6212-6218 D-3.5 6246-6266 D-4 6272-6278 D-5 6449-6464 E-8 7176-7196 J-7 7267-7277 J-2 5 X XN Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) 30” Surf 380’ 16” 65 H-40 Surf 621” 10-3/4” 45.5 & 51 J-55 BTC Surf 2,745’ 7” 26 J-55 BTC Surf 77’ 7” 23 J-55 BTC 77’ 6,991’ 7” 26 J-55 BTC 6,991’ 8,003’ Tubing Detail 4-1/2” 12.6 J-55 Mod BTC Surf 333’ 4-1/2” 12.75 J-55 Mod EUE 8rd 333’ 4,083’ 3-1/2” 9.2 N-80 BTC 4,083’ 6,498’ tubing tested to 1975 psi (2002) MIT-IA 1700 psi done 9/17/20 1 Carlisle, Samantha J (CED) From:Katherine O'connor <Katherine.Oconnor@hilcorp.com> Sent:Thursday, September 17, 2020 9:20 AM To:Schwartz, Guy L (CED) Cc:Juanita Lovett Subject:RE: [EXTERNAL] A-11 NCI (PTD 169-089) Suspend renewal Attachments:MITIA A11 Barton Chart.jpg; A11 MIT.pdf HiGuy, AttachedistheMITIAbartonchartandMITformforAͲ11forsuspendedwellrenewal. Thanks KatherineO’Connor From:Schwartz,GuyL(CED)[mailto:guy.schwartz@alaska.gov] Sent:Wednesday,September9,202010:00AM To:KatherineO'connor<Katherine.Oconnor@hilcorp.com> Subject:RE:[EXTERNAL]AͲ11NCI(PTD169Ͳ089)Suspendrenewal Katherine, InordertorequalifyfortherenewedsuspensionanIAtestwillneedtobedoneonthiswellto1500psi.Onceyou havethatcompletedsendmethechartandyoushouldbegoodtogofor10moreyears. GuySchwartz Sr.PetroleumEngineer AOGCC 907Ͳ301Ͳ4533cell 907Ͳ793Ͳ1226office 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:KatherineO'connor<Katherine.Oconnor@hilcorp.com> Sent:Wednesday,September9,20209:25AM To:Schwartz,GuyL(CED)<guy.schwartz@alaska.gov> Subject:RE:[EXTERNAL]AͲ11NCI(PTD169Ͳ089)Suspendrenewal You’recorrect,thosearejusttbgtests.IhavenotbeenabletofindanyIAtestonthebooksforAͲ11.Iagree,Idon’t thinkthatwascommontotesttheIAaswell. Thanks Katherine 2 From:Schwartz,GuyL(CED)[mailto:guy.schwartz@alaska.gov] Sent:Friday,September4,202012:06PM To:KatherineO'connor<Katherine.Oconnor@hilcorp.com> Subject:RE:[EXTERNAL]AͲ11NCI(PTD169Ͳ089)Suspendrenewal Ithinkthedatayouhaveistestingthe4½”tubingagainsttheplug.Idon’tknowiftheywereinthehabitoftestingthe IAaspartofthe“envelope”backthen.NowwewouldtesttheIAandthetubingcementplugaspartofthepressure test. GuySchwartz Sr.PetroleumEngineer AOGCC 907Ͳ301Ͳ4533cell 907Ͳ793Ͳ1226office 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:KatherineO'connor<Katherine.Oconnor@hilcorp.com> Sent:Friday,September4,202011:16AM To:Schwartz,GuyL(CED)<guy.schwartz@alaska.gov> Subject:RE:[EXTERNAL]AͲ11NCI(PTD169Ͳ089)Suspendrenewal Can’tfindachartbutitwasdefinitelytested,preͲAOGCCandwithAOGCCwitness.(page63and69ofthestatefile).As youcanseeBͲ2wasalsotestedbutI’mstilldiggingintothathistoryanddiscussingwiththeoperatorswhodidthe inspectiontogetafullpicture. Thanks! Katherine Suspended Well— InspectionReview Reporf |nspec No: susLOL200817101416 Date Inspected: 8/14/2020 � Inspector: Lou Laubenstein Well Name: N COOK INLET UNIT A-11 Permit Number: 1690890 Suspension Approval: Completion Report ' Suspension Date: 10/9/2802 Location Verified? P/1 If Verified, How? Other (specify in comments) Offshore? se Type ufinspection: Subsequent _ Date 4OG[ZNotified: 8/8/2020 Operator: Hi|corpAlaska, LLC Operator Rep.- ScoltBumbaugh Wellbore Diagram Avail? Photos Taken? L| Well Pressures (psi): Tubing: 4 ' Fluid in Cellar? 1:1 |A: 40 BPV|n*toUed? El OA: 118 VRP|us(s)Installed? [] Wellhead Condition The wellhead is in good condition with no leaks or visible signs of leakage. The flowline has been removed and the well is blinded downstream of the wing valve. The instrument air lines that actuated the SSV and wing valve are removed and ^ were closed at the time of my arrival. All gauges were in good condition and working order during my inspection. Condition ofCellar Surrounding Surface Condition The Well room was clean and in good condition. Comments ' TyonekP|atfo/no. OOApressure 10psi. There isacement plug inthe tubing from 4,966to3964ft. ~' Supervisor Comments Wednesday, September 2, 2020 3 4 From:Schwartz,GuyL(CED)[mailto:guy.schwartz@alaska.gov] Sent:Friday,September4,20209:30AM To:KatherineO'connor<Katherine.Oconnor@hilcorp.com> Subject:[EXTERNAL]AͲ11NCI(PTD169Ͳ089)Suspendrenewal Katherine, CanyoulookintotherecordsandverifyiftheIA(7”x4½”)wasalsotestedandchartedwhentheysuspendedthewell in2002. 5 GuySchwartz Sr.PetroleumEngineer AOGCC 907Ͳ301Ͳ4533cell 907Ͳ793Ͳ1226office 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). 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. • STATE OF ALASKA AL ,KA OIL AND GAS CONSERVATION COM ,SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed Suspend r Perforate r Other Stimulate Alter Casing r r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Susp Well Inspect 2.Operator Name: 4.Well Class Before Work: P 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 169-089 3.Address: 6.API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r 50-883-20031-00 7.Property Designation(Lease Number). 8.Well Name and Number: ADL 17589 NCI A-11 9 Logs(List logs and submit electronic and printed data per 20AAC25 071): 10.Field/Pool(s): NORTH COOK INLET/BELUGA OIL 11.Present Well Condition Summary: Total Depth measured 8210 feet Plugs(measured) 3964 true vertical 6323 feet Junk(measured) None feet 4083, 4182, 4617,4937, 5211, Effective Depth measured 3965 Packer(measured) 5726, 6115, feet (true vertical) 3463, 3537, 3859, 4093,4291, true vertical 3375 4642, 4902 Casing Length Size MD TVD Burst Collapse CONDUCTOR 581 30 621 620 0 0 SURFACE 2705 10.75 2745 2484 0 0 PRODUCTION 7963 7 8003 6181 0 0 SCANNED *liJ lel 1 12 015 RECEIVED Perforation depth: Measured depth: Perforations P&A'd True Vertical Depth: Perforations P&A'd MAY 2 6 2015 Tubing(size,grade,MD,and TVD) 3.5, N-80, 6497 MD, 5162 TVD AOGCC 4.5 J-55, 4162 MD, 3522 TVD Packers&SSSV(type,MD,and TVD) PACKER-OTIS VSL HYDRAULIC SET RETRIEVABLE PACKER @ 4083 MD and 3463 TVD OTIS'RH' HYDRAULIC SET RETRIEVABLE PKR @ 4182 MD and 3537 TVD 5 BAKER MODEL'F' @ 4617,4937, 5211, 5726, 6115 MD and 3859, 4093,4291,4642,4902 TVD NIPPLE-HES SCSSV LANDING NIPPLE @ 298 MD and 298 TVD 12.Stimulation or cement squeeze summary: NA Intervals treated(measured). Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA Subsequent to operation NA NA NA 14.Attachments(required per 20 MC 25 070,25 071,&25 283) 15.Well Class after work Daily Report of Well Operations Ir Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16 Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r- WAG r GINJ r SUSP pi SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt. NA Contact MJ Loveland/Martin Walters Email N1878(a�conocophillips.com Printed Name MJ Loveland Title.; WI Project Supervisor ) > Signature Ph ne:659-7043 Date ;j 12_ / t Gvc�� Form 10-40 Revised 5/2015 G !�/S.— Submit Original Only �.vKr RBDMS ' MAY 2 9 2015 ConocoPhillips RECEIVED Alaska MAY 2 6 2.015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 �o AOGCC May 23, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry North Cook Inlet A-11 (PTD 169-089) Dear Commissioner Foerster: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. North Cook Inlet well A-11 (PTD 169-089). The well will remain suspended for future utility as a sidetrack candidate. The following documents are attached: - 10-404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs Please call MJ Loveland or Martin Walters at 659-7043 if you have any questions. Sincerely, MJ Loveland Well Integrity Project Supervisor ConocoPhillips • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: NORTH COOK INLET UNIT A-11 Field/Pool: N COOK INLET/BELUGA Permit# (PTD): 169-089 Sundry 310-433 API Number: 50-883-20031-00-00 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 5/3/1970 Surface Location: 1301' FNL, 1020' FWL Section: 6 Township: 11N Range: 9W Nearest active pad or road: NA Meridian: SEWARD Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: The Well is located on the Tyonek Platform -The platform is in good condition Pad or location surface: Well Room 2 is clean and in good condition Location cleanup needed: None Pits condition: None Surrounding area condition: Well Room 2 is clean and in good condition Water/fluids on pad: None Discoloration, Sheens on pad, pits or water. NA Samples taken: None Access road condition: NA Photographs taken (#and description): 3 Photos taken of NCI A-11 in well Room 2. Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition. Tree is clean and is good condition. Flowline has been removed and blinded. All valves appear operational Cellar description, condition, fluids: Clean, no fluid Rat Hole: None Wellhouse or protective barriers: Well Room 2 Well identification sign: Placard and stencil Tubing Pressure (or casing if no tubing): 0 Psi Annulus pressures: IA 120, OA 72, OOA 0 PSI Wellhead Photos taken (#and description): 3 Photos taken of NCI A-11 in well Room 2. Work Required: None Operator Rep (name and signature): MJ Loveland AOGCC Inspector: Waived 5/20/15 by Jim Regg Other Observers: Rachel Kautz Inspection Date: 5/21/2015 AOGCC Notice Date: 5/6/2015 Time of arrival: 12:00 Time of Departure: 13:00 Site access method: Helicopter I, , SAK NCI A-11 ConocoPhillips I . Well Attributes Max Angle MD TD 3 Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) lva,�,a`tt tc 508832003100 COOK INLET PROD 48.00 5,489.01 8,212.0 ,. ' Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Well Confg:-NCI A-11,17262012 70:07:38 AM SSSV::NIPPLE Last WO: 6/13/1994 5/3/1970 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WELL REVIEW osborl 11/26/2012 Casing Strings HANGER.39- Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD).. String Wt...String... String Top Thrd CONDUCTOR 30 28.000 40,0 380.0 380.0 Cuing Description Shing 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WE..String...String Top Thrd fil CONDUCTOR 16 15.062 40.0 621.0 620.6 65.00 H-40 Cuing Description String 0... Shing ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String WE..String...String Top Thrd SURFACE 103/4 9.690 40.0 2.745.0 2,484.3 45.50 J-55 BTC , . Casing Description String 0... String ID...Top(MKS) Set Depth(f...Set Depth(ND)...String Wt....String... String Top Thrd 1 PRODUCTION 7 6.600 40 0 8,003.0 6,181 5 23 00 J-55 ETC NIPPLE,286II Tubing Strings ` Tubing Description String 0... String ID...Top(ftKB) Set Depth(f.,.Set Depth(TVD)...String Wt...String.--String Top Thrd TUBING WO 1994 41/2 3.958 38.9 4,162.0 3,522,2 1260 J-55 EUE8r4MOD Completion Details i Top Depth (ND) Top Incl Nomi... Top(ftKB) (ftKB) (°) Item Description Comment ID(in) CONDUCTOR, 38.9 38.9 -28.41 HANGER FMC TUBING HANGER 3.958 40.3N 297.9 297.9 -17.97 NIPPLE HES SCSSV LANDING NIPPLE 3.813 CONDUCTOR, 40.621 4,082.7 3,462.8 41.69 PACKER OTIS VSL HYDRAULIC SET RETRIEVABLE PACKER 3.880 SURFACE. k 4,096.4 3,473.1 41.72 XO Reducing 3.500 40.2.745 4,128.1 3,496.9 41.78 NIPPLE OTIS IC LANDING NIPPLE 2.750 4,160,7 3,521.2 41.84 OVERSHOT TRI-STATE HIGH PRESSURE PACK-OFF OVERSHOT 3.047 1Tubing Description String 0... String 10...Top(ftKB) Set Depth(f...Set Depth(ND)... String Wt..,String.,. String Top Thrd 1.1 TUBING WO 1983 31/2 2.992 4,162,0 6,498.0 5,162.0 9.20 N-80 BUTT Completion Details PACKER.4.083 Top Depth ��/ (ND) Top Incl Nomi... Top(ftKB) (ftKB) Cl Item Description Comment ID(in) ' 4,182.3 3,537.4 41.89 PACKER OTIS'RH'HYDRALIC SET RETRIEVABLE PACKER 4.000 4,317.6 3,637.8 42.16 SLEEVE OTIS 2 7/8"'XA'SLIDING SLEEVE 2.750 4,617.0 3,859.0 43.00 PACKER BAKER MODEL'F'PERMANENT PACKER 4.000 NIPPLE.4,128 4,896.0 4,062.3 42.35 SLEEVE OTIS 2 7/8"'XA'SLIDING SLEEVE 2.313 ! ': 4,937.0 4,092.8 42.63 PACKER BAKER MODEL'F'PERMANENT PACKER 4.000 OVERSHOT. 5,171,1 4,262.9 44.17 SLEEVE OTIS 2 7/8"'XA'SLIDING SLEEVE 2.313 4.161 ' 5,211.0 4,291.4 44.65 PACKER BAKER MODEL'F'PERMANENT PACKER 4.000 5,535.7 4,514,6 48.00 SLEEVE OTIS 2 7/8"'XA'SLIDING SLEEVE 2.313 5,726.0 4,642.2 48.14 PACKER BAKER MODEL'F'PERMANENT PACKER 4.000 PACKER,4,182 6,015.4 4,835.8 47.85 SLEEVE OTIS 2 7/8"'XA'SLIDING SLEEVE 2.313 6,115.0 4,901.5 47.00 PACKER BAKER MODEL'F'PERMANENT PACKER 4.000 6,466.2 5,139.9 46.41 NIPPLE OTIS'XN'LANDING NIPPLE 2.205 SLEEVE,4.31e-- 6,497.0 5,161.4 46.54 WLEG WIRELINE RE-ENTRY GUIDE 3.725 Notes:General&Safety End Date Annotation PACKER.4.517 7/6/1983 NOTE:WORKOVER .MIIII I ra 10/3/2002 NOTE:WELL PLUGGED 8 ABANDONED TOC @ 3965' I 1/27/2011 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SLEEVE.4.898 ----- If 010. PACKER,4,937 , \ PdA CEMENT1 PLUG.3,965 SLEEVE.5.171 1 PACKER,5,211 1=/ I SLEEVE.5.536 I PACKER.5.726 Aire SLEEVE.6.015 PACKER,6,115 °' i I NIPPLE,6,466 WLEG.6.497 CEMENT SOZ, 3.965 PRODUCTION. 40-8,003- _.-.- TD.6,212 REV DATE BY CK APP L_ -.tIPTION REV DATE BY CK A: DESCRIPTION 1,, I if 36 3I T 12 N 31 32 11c 1 it4 1' ! 6 N T II N 6 5 N IF rti M ..56p 1206' SCALE: I"=1320' 0 CC CC I 6 6 5 12 7 7 8 GENERAL NOTES: •. OF . I. SEE SHEET .3 FOR COORDINATE TABLE :'P,` /.4. 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND j' �1 - \Y •j VERTICAL SURVEY DA TA s : 49th IN .% 3. SECTION LINES AND TIES ARE BASED ON PROTRACTED jell r / VALUES. % s /.P t KENNETH W. AYERS y�/ SURVEYOR'S CERTIFICATE �1♦f�o•,..••.Ls.,853s ••.o' Ar er • I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND -4, SStO:wie ilieLICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALLLOUNSBURY DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF ✓4 ASSOCIATES, INC. FJIITLTORN MINIM TWINLW FEBRUARY 28, 2008. PHONE: non 272•5451 1110/ AREA: MODULE: UNIT: ConocoPhillips NORTH COOK INLET 1 TYONEK PLATFORM Alaska, hic. WELL CONDUCTOR AS BUILT —CAOD FILE NO. DRAVNNG NO: PART: REV: 08-005 AS BUILT 02 27 08 08-005 AS BUILT 1 OF 3 0 REV DATE BY CK APP _ L. <IPTION REV_ DATE BY CK AI DESCRIPTION Ai'94 pr 's (c• SCALE: 1".30' Ak. ESD 600-50 ESD 600-51 WELL HOUSE 3 Af3 1Q •A= Al ALA •J• 05 • A]• A••N AI* •A5 AI A:• WELL. HOUSE I WELL HOUSE 2 -1, A-1'j �0• sQ 1Oos LEGEND: A-A! • WELL O WELL CONDUCTOR ESD (EMERGENCY SHUT OFF VAL VEI GENERAL NOTES: I. SEE SHEET 3 FOR COORDINATE TABLE 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND VERTICAL SURVEY DA TA LOUNSBURY 3. NO WELLS EXIST IN WELL HOUSE NO. 4, AND IT WAS NOT do ASSOCIATES, INC. AS BUILT :URVIYOR5 MINIM PLUMPS 40 PHONE: (O71 272-5431 110/ AREA: MODULE: UNIT; ConocoPhillipsNORrTH ,:c-00K INLET • tY'011Ek OrATFORM Alaska, Ingo WELL)CU14 UCt1TOR AS BUILT CADD FILE NO.,' I DRAWING-NO ✓PART: REV: 08-005 AS; BUILT 02/27/08 �.' O 005 A ;OIJIL I 2. OF 3. 0. w. 4 MOO a._f ski- ,,,,.•""+* .,,r - Sao, _ >1 , , illmre, .,.. fit / 117 t _ if '` / - - 1 ! t 107 ,4. 414 4 V t. x. t sill 4 es ' /\ ,r''''',...; 4111.00 k NCI A-11 PTD 169-089 ©ConocoPhillips Alaska, Inc This photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or published 4F, without express written consent 0 • 1 • • ' 0 • . • 4 . k . P, _ � F r lit I Aar A 4 of ,....� -.NW 1 O I�� - ' risissmb. ....� l i' i ir /4,,,, _ ____-,„,,„,p, r ,,,4 i_- 40* If A, 1164 ir r4,.,_ V*Itn ,7 4 r I f I n NCI A-11 PTD 169-089 ©ConocoPhillips Alaska, Inc This photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or published without express written consent of ConocoPhillips Alaska ° :z_ ' .-,,,, i.,_:,..-.,--..., --\!':„.'-f't\.--1.\\•-s:,11°,,..4:14:lkf,5\1\:itti§k'":':' '14''''''''''k48:1*:—Is'\ -.-— i kis OR, V- ' '.. ; ; .k 1 w ‘ " •• C. Alan 1x;,111 + * , - _ Alla RI• �M , ‘., ..,. ,, Ala eassain ism,. rp � �► m 1 Nifi ii. • - , .• A .7i;')I' iliWonomista..- 4 ti' ski now P .. - ' — ',N,,,,,,N,...*::,s\ AN, IR 101111100 ., r '41k4, ' 41pr iiiiii .. lopir . . v, ,,„ . •,. , , , , , ..,:„. _ ,.. ,. , MMI1R _ . , „.. , . r Iiii, ARkR k `"FZZ. s ... , .... .. illt ..,..,.. .. - , /. ', " ...., ,,,,:::' .,_ . .,.,... , T ' d __..,. yrs w; 1 4 i • V 2 11).:. i� i illeff10, 00100 NCI A-11 PTD 169-089 0,,c,onocoPhillips Alaska, Inc This photo is copyrighted by ConocoPhillips Alaska, Inc. and .r_.z. cannot be released or published . wt , ,without express written consenr . : of ConocoPhillips Alaska f • • SMITE (11 AELS,\SE[ 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 ..D C 5 ConocoPhillips Alaska, Inc. � P.O. Box 100360 1 Anchorage, AK 99510 Re: North Cook Inlet Field, Tertiary Gas Pool, NCI A -11 Sundry Number: 310 -433 JO 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. Sincerel ', o • . orm. n • m sioner DATED this '' day of January, 2011. Encl. • • M John Braden Cook Inlet Asset ConocoPhul ll 5 Email: ooh:( 7) 2634536 Email: john.c.bnadenaoonocophBips.00m 700 G. Street P. O. Box 100360 Anchorage, Alaska 99510 -360 December 20, 2010 Commissioner Dan Seamount State of Alaska RECEIVED Alaska Oil & Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 DEC 2 0 2010 RE: Renewal of Suspended Well 10-403 Status Aisucka & toss Cons. Commission North Cook Inlet Unit A -11 (PTD 169 -089) Anchorage Dear Commissioner Seamount: ConocoPhillips Alaska Inc. (CPAI) submits this request for renewal of the suspension status of North Cook Inlet Unit A -11 (PTD 169 -089) per 20 AAC 25.110. The well was visually inspected on September 10, 2010 by CPAI and by Inspector Bob Noble on November 14, 2010. A 10-404 was submitted for this well on November 22, 2010. As noted in the previously submitted 10 -404, the well has cement from 4,966 ft MD to 3,964 ft MD that will not allow migration of fluid that could threaten public health or impair the recovery of oil or gas. The plugging of the perforations was noted as acceptable by the Commission. The integrity of the existing plugs will be demonstrated by daily monitoring of pressures according to Conservation Order No. 507. The Tyonek platform is an active production platform and there are limited well slots for future wells. Hence, CPAI requests renewal of the suspension because this well has future utility as a sidetrack candidate. Sincerely, John C. Braden cc: Central Files Well Integrity Supervisor 0,1G OF ALASKA art ALASKOL AND GAS CONSERVATION COMMISS� 01 1 1 3 ' Zo t i APPLICATION FOR SUNDRY APPROVA AA 20 AAC 25.280 • 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool fl Repair w ell r Change Approved Program Suspend Rug Perforations r Perforate r Rill Tubing r Time Extension I✓ * Operational Shutdown r Re -enter Susp. Well J'"" Stimulate A lter casing 9 Other:Renew suspended status � , 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development pr Exploratory r 169 -089 3. Address: 6. API Number: Stratigraphic r Service r P. 0. Box 100360, Anchorage, Alaska 99510 50 883 - 20031 - 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 f7 NCI A -11 > 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 17589 i North Cook Inlet / Tertiary Gas Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD ( : ,T Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8212 &23-2-if ' r { 3965' 3375' 4065' 3965' Casing Length Size MD TVD Burst Collapse Structural 323 30" 380' 380' Conductor 584' 16" 621' 620' Surface 2708' 10.75" 2745' 2484' Liner 7966' 7" 8003' 6181' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): all perfs P&A'd 4.5" J -55 4083' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) Otis VSR 4065' MD, 3450' ND Halliburton SCSSV landing nipple 298' MD, 298' TVD 12. Attachments: Description Sunmary of Proposal Jam 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory ] Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/31/2010 Oil r Gas r WDSPL r Suspended 1 7 - 16. Verbal Approval: Date: WINJ — GINJ r WAG fl Abandoned r Commission Representative: GSTOR r SPLUG 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 , 41, Phone: 263-4536 Date 2.0 O`'-. (v Commission Use Only Sundry Number: � 0 (4 33 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test f Mechanical Integrity Test r Location Clearance Other: I2Nr$itaot-t 'IV ZO A14*C 7,5. I I Z j l( /at,� ` tied �, s,l Ievre f e w� ioki e DEC 2010 °�I 2 0 2 0 Subse Form Re i t/0m - 1."! / Alaska Gil & Gas Cons. Conxrusaion Anchorage ( APPROVED BY / 4 - Approved by: -.M ISSIONER THE COMMISSION Date: BDMS JAN 0' 011 ! ._ � /2. z/ ,r Form 10 -403 Revised 1/2010 S u b m it in Duplicate ORIGINAL • • ConocoPhillips NCIU WELL A -11 Completion Diagram !L:1 42 CASING 8 TUBING 621 , 6511 H-40 1540 630 293 10314" 40' 2715' 45.588516 J-55 BT. 3350 1970 531 7' 40' 77 268 J -55 BTSC 4660 4080 327 6991' 238 J -55 BTSC 4080 3080 7" 6991' 8003' 266 BTflC 4660 408, ,27 333' - Mod BTSC 6600 G , 10314 "@2745' M.nr 4.0 ] *o n63 Top t4 length Da HiPllon 10 OD PRODUCTION TUBING STRING B JEWELRY CPT top @ 3965' (10/2002) CMT Retainer 04065' g F 16 �� Otis VON packer@ 4003' • 42 297.89 2.48 wiw.noo 4s scssv tarwis N 90' 3.813 5.566 • 3.958 ' 3 953 3958 • Cook Inlet Sands LUE 2.994 Orlits I1' 3065 . g 16 r�� Otis RN hydr Meld pkr@ 4182' 36 408266 13.73 Otis "VW Hydraulic Set Retrievable Packer 3.800 5,980 3.969 5 740 ! 4225.26 (sad - I�Lirn /. 2992 3500 4254.4284 Stray 33 4120.12 159 Otis 'AC Landing Nipple 2.750 3.750 4306 -07 (838) • 2 992 3 500 f 1 - C 2992 3505 29 4182.32 4.52 Otis - RH" Hydraulic Set Retrievable Packer 4.000 0.000 a Baker" F" Perm 0104617' 2092 3,865 OSED 2.)5 I tie gals' 2.9 500 c 1624'25 (05%) 4 24 0617.00 2.08 Baker Model "F "Permanent Packer 4.000 661)0 -D -. lelrl X -Over. 3 065 4657 - 4)02 CI 22 4695.99 269 O.. .70 " AA - Sliding Sleeve OPEN 2.313 4715 -4805 CI-2,0 Tuhinq 8 x -Over _ ,. 4816 -4816 CF3.0 2� 4852 -4867 CI-3,1 19 4937.00 1.73 Baker Model "F "Permanent Packer 4.000 6000 - • r Over. 2.992 CLOSED 2.313 sx-wer 2 992 14 5211 00 1.99 Baker Model'F' Permanent Packer 4,000 6.000 r.,r, x.ovar 3,865 I n. ve CLOSED 2.313 ►� it I�� Baker 'P' Perm pkr @493T 2992 3500 011004666'(12701)not milled 10 572600 265 Baker 00401 "7" 8015120655 Packer 4.000 0.000 49J> - /98I CI -5.0 2952 3 865 5039 -5089 CA.61600 0 69'F,. .t. f]icz - " SA Shc11n0 Slur y■ 2.313 6107.513) C66.2 17 erosm 6 6115.00 267 Baker Model "F" Permanent Packer 4.000 6,000 la �� Baker "P" Perm pkr @5211' 4 6466.20 0.8 Otis "SW Landing Nipple 2.205 5248 - 5262 CI -S.0 5280 - 5285 01 -6.2 I 5288.5307 C1.8.2 5358 - 5368 CI -9.0 5399 -5419 CI-IOU 5450.5460 CI-11,0 Well History 5488 -5498 C6/1.0 7/70 -First Production from Cook Intel A. 1- 3.5 -11 12 gm 7/75 - CI A. 1 -3, 5•11, Beluga (Add Beluga) =roses 553836 (sqr) 763 -Run 3 02 inch Nb8g with multiple packers and sliding sleeves 10190 - Beluga well only 11.2,■ 10 �� Baker ',Perm Or @ 5726' 5/94 - Run 4 -12 inch tubing, well not ,00811orated due to multiple packers. Beluga well Beluga Sands 5/93 - Top of Fill 6505' 11/95 - Top of Fill 6363' (Lower Sleeve covered). 51345 -5859 0 -7 558 -Top of Fill 6366' (Lower Sleeve covered). 5871 -5877 6-8 1/97- Open CI1 -3 Sleeve at 4917' 5822 - 5909 c-as 659- Test 55 MMCFD813.5 BWPHr to flare 400 psi (U. CI and Beluga sleeves open) 5930 -5950 0-7 10/99- Could not get 2' gauge ring below 5987' 5962 -59)4 0 -2 11 /99- Closed Upper Cl sleeve. Test 300-350 BWPD from Beluga(01213)150 psi FTP 0 1/00 - Tag 1111415846', bail soft lo hard sand. Found indications Lower Cook Inlet sleeve open. Sr., closed all sleeves. Open lower Cook Inlet Sleeve at 5536', no flow. FL 1800', pressure up with gas. Open Upper Cook Inlet sleeve, well would not lbw. Check for fill TD 5101'. ball to 5106'. e .... Baker 'F"Pornl pkr @ 0115' Nov 11,2001 -Pun SCSSV Nov 28. 2001 - FCO 5497 - 5910', SL Tag 5720 RKB 8182 - 6197 9 -3 Nov 29. 2001 - Calpier log, found 3 holes @ 4988'4989' RKB 6212.6218 2 -3.5 Dec 1 .5,2001 - Set 2.187 Bddge Plug @4966. ConfkmxA sleeves @ 4896 open, Set SCSSV. 8246 -6266 dJ 68030ito flow wall, well Mee 12(5/01 -pulled SCSSV. Close 3.5"04 sleeve @ 4318'. Tag fine sand@ 4318' 2 9 srr 6272 -6278 23 Oct 1- 2,2002 - mil cement • 6449 - 6460 e-8 Oct 3. 2002 - complete P8A w /cement C1BP 7115 Oct 4,2002 - cement squeeze Oct. 9, 2002 - lag lop of cement @ 3965' 7267 -7277 (-2 726) -7277 J-I I k 7" @ 8003' Updated : 6)12)2004 By: Dan Bearden Total Depth 8212' PBTD'. 7,125' IFNI Tag. 4310 12 /2001 Well: North Cook inlet Unit No. A -11 10040on: Tyonek Platform, Cook InKt, Alaska F10: Ned@ Cook Inlet Unit J, • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 11/14/10 Inspector: Bob Noble Operator: CPA Well Name: NCIU A -11 Oper. Rep: Russ Allen PTD No.: 169 -089 Oper. Phone: 776 -2350 Location Verified? Yes - Oper. Email: r/,1�r If Verified, How? Other (specify in comments) � Onshore / Offshore: Offshore Suspension Date: 10/09/02 Date AOGCC Notified: Sundry No.: 302 -236 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing 0 Photos Taken? Yes IA 180 OA 0 Condition of Wellhead: Well head location was verified with the use of an as built. Wellhead looked to be in very good condition with no leaks. All lines were blinded off. Condition of Surrounding Surface The wellhead room looked to be in good condition with no signs of spills or leaks. Location: Follow Up Actions Needed: N %"JA d C) Attachments: p (2) REVIEWED BY: Insp.Sup �l1` I(I23� 10 Comm PLB 08/2010 2010- 1114_Suspend_NCIU_A- 11_bn.xls • Suspended Well Inspection — NCIU A -11 (CPAI) PTD 169 -089 Photos by AOGCC Inspector B. Noble 11/14/2010 A&- I ttr__- f x 9 1�P l" a John Braden Cook Inlet Asset Telephone: (907) 263 -4536 ConocoPh Email: johns. .corn 700 G. Street P. O. Box 100360 Anchorage, Alaska 99510 -360 November 22, 2010 NI0 v 2U Commissioner Dan Seamount RECEIVED State of Alaska kin 1/ 2 3 2010 Alaska Oil & Gas Conservation Commissionka Oj; con. Cu5SI0I 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501bAr�0 RE: Suspended Well Inspection (20 AAC 25.110) 10-404 Sundry North Cook Inlet Unit A -11 (PTD 169 -089) Dear Commissioner Seamount: Attached is the suspended well inspection documentation as required by 20 AAC 25.110 for North Cook Inlet Unit A -11 (PTD 169 -089). Bob Noble was on the Tyonek Platform November 14 and inspected the well at that time. In fulfillment of the requirement, the following documents are attached: • Form 10-404 for PTD 169 -089 • Letter authorizing delay of inspection • Report of operator survey per 20 AAC 25.110 • Wellbore Schematic • As -built Survey • Estimated Pore Pressure vs Depth Plot of the NCIU Area • Well Completion Report indicating perfs are P &A'd • 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, 'A q John C. Braden cc: Central Files Well Integrity Supervisor STATE OF ALASKA ` ALAS AND GAS CONSERVATION COMMISS& REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Lj Repair WellU Plug Perforations U Stimulate U Other U 20ACC25.110 Performed: Alter Casing ❑ Pull TubinO Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdowr❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ 169 -089 3. Address: P.O. Box 100360, Anchorage, Alaska 99510 Stratigraphic❑ Service ❑ 6. API Number: 50- 883 - 20031 -00— 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 17589 0% NCI A -11 - 9. Field /Pool(s): North Cook Inlet/Tertiary Gas Pool 10. Present Well Condition Summary: Total Depth measured 8212 feet Plugs measured 4065 feet true vertical 6324 feet Junk measured cmt @ 3965' feet Effective Depth measured 3965 feet Packer measured 4083' feet true vertical 3375 feet true vertical 3463' feet Casing Length Size MD TVD Burst Collapse Structural 323' 30" 380' 380' Conductor 584' 16" 621' 620 Surface 2708' 10.75" 2745' 2484 Intermediate Production N 2 3 M Liner 7966' 7" 8003 6181 + � vii & Gas Gans. UTIfir Perforation depth Measured depth all perfS P&A'D feet Anckrarg8 True Vertical depth all perfS P&A'D feet Tubing (size, grade, measured and true vertical depth) 4.5" J -55 4083' MD 3463' TVD Packers and SSSV (type, measured and true vertical depth) H SCSS land nipple 298' MD 298' TVD Otis VSR 4065' MD 3450' TVD 11. Stimulation or cement squeeze summary: Not Applicable Intervals treated (measured): 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: na 0 0 85 5 Subsequent to operation: na 0 0 85 5 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory[] Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations XXX 15. Well Status after work: Oil ft'\, Gas WDSPL I GSTOR E] WINJ E] WAG ❑ GINJ ❑ ��I 1 ) � SUsF c SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: None Contact John Braden Printed Name: John Braden Title: Staff Engineer n Signature Phone: 263-4536 Date '7Z RBDMS Nov 212010 Form 10-404 Revised 1012010 Submit Original Only I` (C(DPY John Braden Cook Inlet Asset Telephone.(907) 263 -4536 5 COI'1 aimilli p Email: john .c.txaden@conocophillips.com 700 G. Street P. Q. Box 100360 Anchorage, Alaska 99510 -360 September 27, 2010 Commissioner Dan Seamount State of Alaska S E P 2 8 2010 Alaska Oil & Gas Conservation Commission 333 West 7 th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Scheduled Witnessed Suspended Well Inspection (20 AAC 25.110) North Cook Inlet Unit A -11 (PTD 169 -089) & NCIU B -2 (PTD 197 -210) i Dear Commissioner Seamount: I have prepared suspended well inspection reports for the above- referenced wells based on Operator inspections. Per the attached, the witnessed inspection will be delayed to November 14, 2010, when the Operator expects a Commission Inspector to be on the Tyonek Platform to witness sales meter calibrations. I will have the prepared suspended well report available for his review at that time and then submit the witnessed suspended well report within 30 days after inspection. Contact me at the above phone number or addresses if you would like to discuss this matter in more detail. Sincerely, John C. Braden cc: Central Files Well Integrity Supervisor • Page 1 of 2 Braden, John C From: Aubert, Winton G (DOA) [winton.aubert@alaska.gov] Sent: Monday, September 27, 2010 8:52 AM To: Braden, John C Cc: Grimaldi, Louis R (DOA) Subject: RE: Suspended Well Inspection John, If there are regularly scheduled AOGCC- witnessed inspections on the platform within the next two months (by the end of November, 2010), please redo the NCI A -11 and B -02 suspended well inspections, with AOGCC witness. If the next regularly scheduled witnessed platform inspections are more than two months distant, please submit A -11 and B -02 unwitnessed suspended well reports, based upon your recent (unwitnessed) inspections. Thank you, Winton Aubert AOGCC 793 -1231 From: Braden, John C [mailto: John .C.Braden @conocophillips.com] Sent: Monday, September 27, 2010 8:23 AM To: Aubert, Winton G (DOA) Subject: FW: Suspended Well Inspection Winton, I spoke with Tom on Friday. In spite of Lou's recommendation, Tom said this is in your shop. Thanks, John Braden From: Braden, John C Sent: Friday, September 24, 2010 7:48 AM To: 'Maunder, Thomas E (DOA)' Cc: Aubert, Winton G (DOA); Regg, James B (DOA) Subject: FW: Suspended well Inspection Tom, Per Louis suggestion, I am writing to request a wavier of suspended well inspection for IVCIU A -11 (PTD 169 -089) and NCIU B -02 (PTD 197 -210). The Operator has inspected the wells and found them to be in good mechanical condition. Pending your decision, I will finalize submit the suspended well report per 20 AAC 25.110 and submit. John C. Braden Cook Inlet Development ConocoPhillips Alaska, Inc. (907) 263 -4536 phone (907) 265 -1441 fax John .c.braden @conocophillips.com 9/27/20 R 0 • . Page 2 of 2 From: Tyonek Offshore Installation Manager Sent: Friday, September 24, 2010 7:09 AM To: Braden, John C Subject: RE: Suspended Well Inspection John, I just received a call from Lou Grimaldi concerning the suspended well inspection. He suggested that you contact Tom Maunder (793 -1250) about a waiver of inspection by AOGCC. Gary L. Smith // Tyonek OIM 907 - 776 - 2073// Fax 907- 776 -2044 "Remember at ConocoPhillips Alaska, Inc. our work is never so urgent or so important that we cannot take the time to do it SAFELY and in an Environmentally prudent manner." From: Braden, John C Sent: Wednesday, September 22, 2010 2:58 PM To: Tyonek Offshore Installation Manager Subject: Suspended Well Inspection Gary- I left a message for the AOGCC inspector to call me about suspended well inspection. He may call you. This is the same inspection that Dennis did last hitch on B-2 and A -11. We dropped the ball in not inviting the AOGCC to witness. If he calls you, please let me know. I have a package prepared for him to review if he wants to witness. If he waives the inspection, I need to note it in the final report. Thanks, John C. Braden Cook Inlet Development ConocoPhillips Alaska, Inc. (907) 263 -4536 phone (907) 265 -1441 fax john.c.braden @conocophillips.com 9/27/2010 North Cook Inlet Unit A -11 (PTD 169 -089) 20 AAC 25.110 (f) Report of Sundry Well Operations (Form 10404) 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; The well is located on the Tyonek Platform in Well Room #2. The well room is kept clean; there is no discoloration, fluid or sheen on the floor or in any nearby water. 2. A plat showing the location of the suspended well and any wells within one - quarter -mile radius of the wellbore; A plat showing the location of the Tyonek Platform and all wells on the platform is attached. There are no other operating or suspended wells within a quarter mile of the platform. 3. Well pressure readings, ifpracticable; Tubing: 5 psig. Inner annulus: 85 psig. Outer annulus 0 psig. 4. photographs clearly showing the condition of the wellhead and surrounding location; Photographs clearly demonstrating the condition of the wellhead are attached 5. an update of all information and documentation required in (20AAC25.110(b) of this section. 20AAC25.110(b) requires that the well meet the requirements of 20AAC25.110(a) in addition to including a wellbore diagram, information of geopressured or depleted strata and proposed work plan. In accordance with 20AAC25.110(a), the well is mechanically sound. Casing pressures demonstrate the integrity of the casing. The attached schematic of the well indicates the well has cement from 4,966 ft MD to 3,964 ft MD that will not allow migration of that could threaten public health or impair the recovery of oil or gas. The plugging of the perforations was noted as acceptable by the Commission in the attached Well Completion Report dated October 29, 2002. The integrity of the existing plugs will be demonstrated by daily monitoring of pressures according to Conservation Order No. 507. The Tyonek platform is an active production platform and there are limited well slots for future wells; hence, this well has future utility as a sidetrack candidate Attachments Wellbore Schematic As -built survey Pressure vs depth plot Tree Photos 17' `� CoTTOCOPhillips NCIU WELL A -11 Completion Diagram APM509J90J/0o F MC OCT a 1 Dark: F M CI 12" and .. 113" BTBC RKB -TXF: M 4x .6 MI KCL Cmm kn FIuW r11k ]O X NatUSrrol RKBSL : 110 380 ' TOC: : J90' dakU 1L11N WATER OEPTN: 130' RKaJIL: IRMOMIM CASINO t TUBING 18 @631' 9" b' Jaw X40 621' 65R 1510 630 3 1014' 40' IT4S 15.54851R J35 BT&C 3350 19]0 131 40' TT J -55 eTdC 0860 3080 J37 331 Jd5 BTdC 4080 3080 T' 6991' 800J' 26R 1080 BT 3660 J38 12.50rt Jd5 Mad BTBC 6600 6530 1J5 1014' a 3)45' T 433' J -55 4730 3980 J 19" 4083' Bd90' 1 a1R 4 44410 4130 4900 PROOUCTm TUBING STRING &JEVMLRY CMi a7P Q 3965' (1a2002) 45 0.00 3..90 Ebvatinn EMT Rebinw ®4065' 44 38.90 0.67 FMC I OCT6 3M 412 BN x41!2' 3- T - Flan... };3i3 8.000 Otla 1/gR packer @4094 43 39.57 25832 4 1/Y 12.6 lbi0 J-55 Moo ST &C Tubin. 3.950 5.563 44 9TSa a" xrnr.re as U13 LM 33 ' 3'.75 41 IL61EM }55 MM ST &C Turing 3.950 5.584 d 1 5 40 334.1 0.7 -- 412" -ELE BN x 412 BT &C 3. 4919 39 33 88 310.98 4 t•' ' 1-6 R 155 M d T J 458 5 Cook Inlet Sands M 4-M 0, x.aer 412 eracfa l!2•EUE 2.996 s. 31 4082.66 Strai M SM Locales eM See./ rib 10' pvaraA 34065 3.8 A OMa RN bydc rtnd Pk, 0 4163' 9 40a2M 1113 OW "Val/" RfIrNv4W ►.ealr 310a 0.000 35 409830 1.30 Tud Ape wand X-0ver 3.960 5.14(1 IIISI6 (s0zl b 4097.77 30.J 31/2' 91311 }55 Bunreas Tub: BX4Nar 2.992 J.SCC �y r 4331.1264 3bay 33 419.1 I" 00.W TM 179 3 yYY v j�. r ?'�' 4]06-07 (sue/ 32 4129.71 3086 31Z 92610 }55 Bultmsa TUbl BX -Over 2.902 3.500 b y ,tr !7441. 4160.67 1.33 T-t- H gU Pressure Pack4)OOVerabw 3.047 5140 41 00 1 e.J • 311 m 5 s T & v .99 I1 9144" PwR.r 09 7 2. f aaker'F "Farm pkr�K1T 106.84 tJO.]5 31/2 - 92661 Tubin MaA flints. X -Over. 2 3.885 I1] 9 195 UsJ 12 " "XA "Slid -closea1L101 CLOSED 15 ee.eun 1321,54 195.3 3112' 92 bM Nd0 Buttress TUN qvw d % 2492 J.500 p 461415 (aqz) d6 ^7.00 Baker Seal UNI 24 7 T P 4.09 0 2 4619.08 27891 3112' 9. rift 7-. Mast JOIn15.X-0.er. 2.992 3.885 165] -4]02 -.0 22 4495.99 2.09 Otia 1718 " '3 mkfl Skew OPEN 3.313 4715 -IBOS WO 21 .... 38.3 31!2' 91-1 44-80 BulVess TuNn aX -0vsr 2.992 3500 _ 4818.4840 Clio 2O 4937.00 Baiter Seal Unil 4852 -4067 0-31 1. *vie 1.73 YseMFPwmNwA laaNr AOBO a..a3 18 1938.7 n2.30 31291 bifl TUan BWal Joints.% 2.992 3865 17 5171.13 .69 M. 2118 ""%A"8liain Sbava CLOSED 2.313 16 5113.82 37.1 3112' B1Ib/fl ri/ N40 Buttress TUdn 8 %-Over 2.992 3.500 15 52!1.00 Baker Seel U 14 02119 1.9 agar klwd "PafNNrK P.oYw 4000 cm 13 52 322.12 31/2 91 bM Tulin . Ma5l.binb. X 2.992 3.865 13 535.]1 .69 Otis 3710 " "%A "Slitlin Shwa CLOSED .13 aakw "F" Perm pk7 1931 5538 40 101." 3 1 .- 91 NrI NAO Bu0rers T- d X-0vw 2.492 3500 Baker heal Unil CIPE i13fOt)nol milled 11 Ie0dsIT 1977 498] C- 9 5728.65 186976 3 11 91 - 1-D 3515 5039 -5009 C1 I0a.0 0 0015.11 2.69 Otia 2 ] /e "3(A" Sliai 51- 3.313 7 5137 CF&1 1 112 92 M,1 44-80 Buttress 1 6 %-Over 17 r 3akar SeA'Jnit .. 6 611100 .67 e.09 61 �'>7 34853 31!2 - Turin ...V X e, 2.992 3865 1 ekes - F"hrm grOD Sxt 1' 4 64GL20 M 0" 5x61.(10 30.0 J 1? 91WM NAO Buttress Turin 5 X -C�rer .."2 3500 5248 -5261 C140 902 0.98 Wimlire Re -Ent GuMe 3.725 4887 2. -5205 CF82 n498 End of TUe: 5269 530) C-Z -5368 CFa.0 5399 -Sala c"D0 sdw -s.bp C11f.0 W.B Hlido 5468 -5498 CI -11.0 410 - First Production from CaoM bbl k 1 -3,511 13 715 -CI A, 14 St t,"' (Add Beluga) 6638 -]9 (s9zJ 7183 - Run 3 -- taring wi1M1 muttlpb packer and sliding shaves 1-- -e0 Doty 1 B4kar "F• Perm qr @ 5]26 594 - Run 4112 i11h tubing wet rot rspedoreted due to muMOle paten. Beluga wet Beluga Sands - 3- TOpo1Fd650T 1/196 -Top 01 Fa 6363' (Cowes Sleeve caveretlJ" 58/55859 D1 590 -Top or FIII 8366 - (LOww Stew wveratl). 5811 - "1 04 197 -Open C11J Sbwe w 491T 5899 5909 c-0.5 999 -T- 5.5 MMCFD & 13.5 a-., to gene 400 psi (U. CI and Seluga sleeves open) 3930 5950 b 1099 - Cpub not get Y peuge" babes S., 5962 3974 c2 11199 - Cbeed Upper cl abwa, Tact 1M- 350 BWPD from Beluga (10 flan) 150 psi FTP Tag AN w 583%. bee aril to 6eN seM. Found mdicatlons Lower Cook Inlet A- open, osetl aN Aeaves. Open Lower Cask blot Sleeve x15536', no Aow. FL 1600'. prassum up witM1 gas. Open Upper Cook Intl slreve, wM weld rat flow. CYwck br nl TO 5101', bail 10 5106'. Baker F "Perm qrg 6115' tt, 2001 -PUe SCSSV Nov 28 2001 - FCO5491. 5910, SL Tag 5720' RKB 6182 -6191 0.3 Nov 29. 2001 - C47k9,Ida103 bobs a 4980'4909 RKB 6212: 8210 0.].5 Dec 15. 2001 - 8el 1.18' Brbge Plug ® 4966. Confirm XA abwes ®1896 B 4310' open..1 SE- 8216.6286 W AOempt to floes- weld- 12/5 -pu SCSSV. Cbse3.5Ms1ewe Tag -..@-S 6211 -621a 1 5 Oct 1- 2.2002 -mR Cemwrl - -.6464 " Ocl J, 2002- mmpble P6A wlcemanl IXt d. 2002 - cement squeeze Oct. 9, 2002 -tag too of cement 3965' 7116 - >196 41 726] -7277 f2 r cd aen, uPae.a : u1 xn0u q: mn T-1 Dpu&212 F. 1.125' FlT :431 e'1-1 ell: North Cook Inlet Unit No. A "11 Lwwiw. rwk PlaHwm. Cook Mel, A.A. FieM' NwM Cook Ink1 UNt JOB , I REVI DATE I BY I CK I APP DrWRIPTION I REV I DATE BY I CK I A DESCRIPTION I I I i 36 31 T 12 N 31 32 1 6 N T II N 6 s po N R ww f[ 1206' SCALE: ("_1320' I � 3 � o � � Ct 0 1 6 I 6 S 12 7 7 g GENERAL NOTES: �� OF 1. SEE SHEET 3 FOR COORDINATE TABLE � �'�•,.�� 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND AV i 49th •�'� VERTICAL SURVEY DATA � 3. SECTION LINES AND TIES ARE BASED ON PROTRACTED 0 ... ...... VALUES. o . . KENNETH W. AYERS i �♦ �` • , ': G� �� J� •'• LS -8535 •• AV SURVEYOR'S CERTIFICATE ��j o ' ° o ' :• AV I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND � �; � =��- LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL LOUNSBURY DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF do ASSOCIATES, INC. SURYMM ]I NGR76ZRS PGNNUS FEBRUARY 28, 2008. 0 '% PHONE: roo7) 272.5451 Ire" AREA: MODULE: UNIT: Conoc ®Pilips NORTH COOK INLET �✓ TYONEK PLATFORM Alaska, Inc. WELL CONDUCTOR AS BUILT CADD FILE 1J0. DRAWING NO: PART: REV: 08 -005 AS BUILT 02/2? 08 08 -005 AS BUILT 1 OF 3 0 REV I DATE BY I CK I APP OMMPTION IREVI DATE IBYICK IAW DESCRIPTION 9 �o x s ��ir SCALE: I " =30' 99 p p. L ESD 600 -50 ESD 600 -51 ® A13 WELL HOUSE 3 'O : 92 A® A�• 63 • ® 03 A6• A3•A3 A4• • ' HOUSE I WELL HOUSE 2 -14 ® AN A -1i ® • 2p A10 LEGEND: A - It • WELL 0 WELL CONDUCTOR ESD (EMERGENCY SHUT GENERAL NOTES: OFF VALVE) 1. SEE SHEET 3 FOR COORDINATE TABLE 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND VERTICAL SURVEY DATA LOUNSBURY 3. NO WELLS EXIST IN WELL HOUSE NO. 4, AND IT WAS NOT & ASSOCIATES, INC. AS BUILT SURMORS MINRRRS PIANNRRS '% PHONE. !9071 272 -5431 AREA: MODULE: UNIT: Con ®C® hflli S .,' NORTH COOK INLET TYOnEK PLATFORM Alaska, Inc. WELL CONDUCTOR AS BUILT CADD FILE NO. DRAWING NO: PART: REV: 08 -005 AS BUILT 02Z27/& 08 -005 AS BUILT 2 OF ,3 0 REVI DATE IBY ICKIAp7p DWnIPTION I REV I DATE I BY I CK 0W DESCRIPTION ASP ZONE 4, NAD83, FEET NAD83 GEOGRAPHIC MLLW DESCFBPTION (POINT NO.) NORTHING EASTING LATITUDE LONGITUDE ELEVATION Nau W ELL TAG NO. WELL HOUSE NO.1 1001 2586492 1472018 61 04 34.38 150 57 03.71 72.0 Conductor 1 1002 2586489 1472017 61 04 34.34 150 57 03.72 73.9 B3 1003 2586485 1472019 61 04 34.31 150 57 03.67 74.1 Al2 1004 2586485 1472023 61 04 34.31 150 57 03.59 73.8 B1 1005 2586487 1472027 61 04 34.33 150 57 03.52 72.0 Conductor 5 1006 2586491 1472027 61 04 34.37 150 57 03.52 73.7 B2 1007 2586495 1472025 61 0434.41 150 57 03.57 72.1 Conductor 7 1008 2586495 1472021 61 04 34.41 150 57 03.65 73.7 A13 WELL HOUSE NO.2 2001 2586437 1472060 61 04 33.84 150 57 02.83 71.9 A -15 Genefdeto. 1 2002 2586433 1472059 61 04 03.38 150 57 02.84 71.9 Conductor 2 2003 2586430 1472062 61 04 33.77 150 57 02.79 71.8 A -16 Gend=t" 2004 2586429 1472066 61 04 33.77 150 57 02.71 73.4 A9 2005 2586431 1472069 61 04 33.79 150 57 02.65 71.9 Conductor 5 2006 2586435 1472069 61 04 33.83 150 57 02.64 73.3 A10 2007 2586439 1472067 61 04 33.86 150 57 02.69 73.3 A11 2008 2586439 1472063 61 04 33.87 150 57 02.77 71.9 A -14 eondoatvra WELL HOUSE NO.3 3001 2586488 1472128 61 04 34.36 150 57 01.47 73.0 Al 3002 2586484 1472127 61 04 34.32 150 57 01.48 73.1 A8 3003 2586481 1472130 61 04 34.29 150 57 01.43 73.1 A6 3004 2586480 1472133 61 04 34.28 150 57 01.35 73.0 A4 3005 2586483 1472137 61 04 34.31 150 57 0129 73.0 A2 3006 2586487 1472137 61 04 34.34 150 57 01.28 73.0 A5 3007 2586490 1472135 61 04 34.38 150 57 01.33 73.0 A3 3008 2586490 1472131 61 04 34.38 150 57 01.41 73.3 A7 50 2586540 1472069 61 04 34.86 150 57 02.69 72.7 ESD Valve 600 -50 51 2586501 1472011 61 04 34.46 150 57 03.86 72.6 ESD Valve 600 -51 100 2586572 1472123 61 04 35.18 150 57 01.58 115.3 Top center helipad •n +r r sr r urr SURVEY NOTES: I. ALL COORDINATES ARE ASP ZONE 4, NAD83, US SURVEY FEET. GEOGRAPHIC COORDINATES ARE NAD83. 2. ELEVATIONS ARE IN FEET, BASED ON MLLW, REFERENCED TO DRAWING NO. MPD- TY04 -2021, SHEET I OF I, REV. 2 3. ALL AS GUILTS ARE TO THE CENTER OF EXISTING STRUCTURE. 4. WELL CONDUCTOR ARE VERTICALLY AS BUILT TO THE TOP OF A 114" STEEL LID, TACK WELDED TO THE TOP OF THE CONDUCTOR. 5. WELLS ARE VERTICALLY AS BUILT TO THE TOP OF THE LOUNSBURY LOWEST HORIZONTAL FLANGE ON THE WELL. & ASSOCIATES INC. 0� '% SURVEYORS LNGINRRRS ILANMRS PHONE: 19071 272 -5451 AREA: MODULE: UNIT: NORTH COOK INLET YO 'TN�EK PLATFORM ConocOPhillipS Alaska, Inc. WELL CONDUUCTOR AS BUILT CADD FILE NO. DRAWING NO: PART: REV: 08 -005 AS BUILT 02/27/08 08 - 005 AS BUILT 1 3 OF 3 0 North Cook Inlet Unit Estimated Pore Pressure \ —Pore Pressure - High ♦ A -10 \ ■ B -3 2,000 B -1 A -16 \ O N. Forelands + 17589 X A -15 4,000 + PorePressure @ NCIU, Tertiary Pool based on A -10, A -15, A -16, B -1, B -3, NCI St 17589 X + 6,000 II o 8,000 \ \ 10,000 \ \ + \ 12,000 Pore Pressure +\ N. Forelands No. 1 9700 psi @ 13282 \ Cl St 17589 1 -A 5236 psi @ 10927' \_ 14,000 2,000 4,000 6,000 8,000 10,000 Formation Pressure, psia STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RE COMPLETION REPORT AND LOG 1. Status Of Well Classification of Service Well Ol Goa 0 Suspended Abando Q Service 2. Name of Operator 7. Permit Number Con000PhOps Alaska, Inc. 69-89 / 302 -236 3. Address S. API Number P.O. Box 100360, Mchonap, AK 9951 MM 50-683-20031-00 4. Location of well at surface 9. Unit or Lease Name 1301' FNL,1020' FWL, Sec. 6, TI IN, ROW, SM CCP/ °LETi0H North Cook Hot Lk* At Top Producing Interval DATE 10. Well Number 645' FSL, 93T FWL, Sec. 31, T12N, ROW, SM - A-11 At Total Depth IB 11. Field and Pod 1773' FNL 928' FWL, Sec. 31, T12N, ROW, SM �'"^'� ' Cook Inlet Field 5. Elevation M 159 (Indicate KB, DF, sic.) Lease Designation and Serial No. Beluga Pod RKB 116' feet ADL 17689 12. Date Spudded 1 8. Data T.D. Reached 14. Date Comp„ Sump. Or Aband 15. W am Depth.11 dfshoro 1S. No. of Completions August 24,186'8 October 13,1969 May 3,1970 WA %W MS. 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional urvsy 20. Depth when SSSV set 21. Thickness of Permafrost 8212' MD / 6297' TVD 4923' MD YES No WLRSV Q 298' 2. Type Electric or Other Loge Run IES, FDC, SNP & CSL CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30' Surface 380' Driven 16' 65# H-40 Surface 621' M. 605 sxClass G 10.314' 40.5#, 45.5# J-55 Surface 274F 15' 735 ox Class G 7' 239 & 26# J-55 Surface III= 9-5/8' 1231 ax Class G lbridge plug 0 4923', cement ruiner set w 4055' 24. Perforations open In Production (MD + TVD of Tap and Bottom and 25. TUBING RECORD Interval, she and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5' 333' & 4083' 4083', 4182' 461T 4937' 3.5' 1 6498' 5211',572W, 61 IF all perfs P&AV 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL W) AMOUNT & KIND OF MATERIAL USED 3M'- 4923' Class G cement plug 27. PRODUCTION TEST Date First Production Method of Operation pawing, gas 11% ft.) not applicable P&A Dale d Teat Hours Tested Production for 01.081. GAS-MC L RATIO WA Ted Period> Row Tubing Casing Pressure Calculated OL-SM GA84ACF WATER• 38L OIL GRAVITY - API (son) press. psi our Rate > 28. CORE DATA BrW dssalption d Ithology, porosity, fractures, appal dips seed Pressence d dl, gas or water. Submit core chips. WA Q � �`\ `� OCT 2 9"201 AWM Oil &onoft Co11111111110 .A7 - Laren 90-407 Rev. 71-80 CONTINUED ON REVERSE Stiff Screed In dupAah 1 ' POONs Oft • • 2s. 30. GEOLOGIC MARKERS FORMATION TESTS NAME kwk de kftrvai tested, pressure data. N flulft roemered and graft. MEAS. DEPTH TRUE PERT. DEPTH GOR, and dime of each phase. WA RECEIVED ocT 2 9 2002 p a0U& °" 91. LIST OF ATTACHMENTS Srunmary of Daily Operations 22. I hereby certify that the following Is hue and correct to the best of my krwMedge. Questions? call Area woftngtan 2656802 Sitpred Tide Web Date _A"gL- Area W Prepared by SfmmnA Dn" INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases In Alaska. Item 1: Gasification of Service wells: Gas Injection, water Injection, steam Injection, air Injection, salt water disposal, water supply for injection, observation, Injection for in-shu combustion. Item 5: Indicate which elevation Is used as reference (where not otherwise shown) for depth measurements given In other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in Item 16, and In Item 24 show the producing Intervals for the Interval reported In Item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such Interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lilt, Rod Pump, hydraulic Pump, Submersible, Water injection, Gas Injection, Shut -In, Other- e)lain. Item 26: If no cores taken, Indicate °none'. Form 1040Y - _ I y l r 1 09 / 101 "2010 y4 y 4 +r � �* 9/1 0 ' t ,w Iwo 09/10/2010 • t~c~#il~~~~ TRANSMfTTAL North Cook /n/et Unit deve%pment we//data FROM: Sandra D, Lemke, AT01808 TO: Christine Shartzer ConocoPhillips Alaska, Inc. State of Alaska P.O. Box 100360 AOGCC Anchorage AK 99510-0360 333 W. 7~' Ave, Suite 100 Anchorage, Alaska 99501-3539 RE: NCIU production logging DATE: 08/16!2010 Cook Inlet, Alaska i, fir;--, North Cook Inlet A-11(169-089-0) c70~~ ~- ~' ~'' ~~ ~ ~ ~ ~ " Proactive Diagnostic Services, Multi-finger caliper report and 3D data and viewer (.pdf format); 6/1 /2006 Inlet A-13(192-106-0) ~~~~ Proactive Diagnostic Services, Multi-finger caliper report and 3D data and viewer (.pdf format); 8/20/2009 To al/data recipients: ,~/ea~a ~~~r~, ~c~~> a~~`'s"~~~rf-~ fr,i~ ~. CC: Art Copol us, CP eologist Receipt: Date: . , , ~ ,,~ .~, .'a 'ter ~- ,. r°; J "; ~ ~ ;11 "I ~~ u ail ~ ~~ . >~.:9a,.~ , w =. ~> ~ ~- C.i~ Technical Data ;'~aragernent ~ lli~s ~ .~~nchora~e, ~/a.~ka ~ Ph, .~L~7.~~.~ ~'9~7 Sandra D LemkeCv~Conocophillips com Well Name Pre 2008 Survey Location NAD27 ASP 4 Northing Easting Post 2008 Survey Location NAD27 ASP4 Northing Easting Distance Moved NCI A-01 2,586,726.69 332,100.19 2,586,726.40 _ 332,102.26 __ 2.09 NCI A-02 2,586,722.85 332,108.29 2,586,721.16 332,111.27 _ 3.43 NCI A-03 2,586,728.60 _ 332,106.22 _ 2,586,728.31 332,109.43 __ 3.22 NCI A-04 2,586,719.62 332,105.09 2,586,718.58 332,108.09 3.18 NCI A-05 2,586,725.55 332,110.17 2,586,725.14 332,111.79 1.67 NCI A-06 2,586,719.66 332,102.09 2,586,719.22 332,104.19 2.15 NCI A-07 2,586,727.79 332,103.73 2,586,728.78 332,105.40 1.94 NCI A-08 2,586,720.56 332,098.31 2,586,722.44 332,101.65 3.83 NCI A-09 2,586,666.58 332,039.08 2,586,667.35 332,040.44 1.56 NCI A-10 2,586,670.21 332,040.91 2,586,673.71 332,044.17 4.78 NCI A-10A 2,586,670.21 332,040.91 2,586,673.71 332,044.17 4.78 _ NCI A-11 ___ 2,586,670.23 _ 332,039.14 2,586,677.01 332,041.75 __ 7.27 NCI A-12 2,586,722.73 331,947.80 2,586,723.59 331,994.15 46.36 NCI A-13 _ _ 2,586,734.88 331,993.50 2,586,733.15 331,995.48 2.63 NCI B-01 2,586,730.03 331,999.80 2,586,723.04 331,998.16 7.18 NCI B-01A 2,586,730.03 331,999.80 2,586,723.04 331,998.16 7.18 NCI B-02 2,586,731.14 331,999.29 2,586,729.60 332,001.86 3.00 NCI B-03 2,586,731.69 331,986.37 2,586,726.81 331,991.70 7.23 NCI B-03PB1 2,586,731.69 331,986.37 2,586,726.81 331,991.70 7.23 ~, • ~~ ~~~~ r~ REV DATE BY CK APP ESCRIPTION REV DATE BY CK P DESCRIPTION 1 2/29/08 SAS KWA MODIFY WELL HOUSE SCHEMATIC, SHT.2 ADD MUD LINE ELEV., SHT.3 x g ~ 36 31 'g9 T 12 N 31 32 ~ ~ a s,'i a°~ I 6 ~ T II I U 6 5 rw na N 5, IYYS' SEC. 6 1206' SCALE: 1"-1320' ---6- - ~ ~ o ~ ~ I 6 6 5 12 7 7 8 GENERAL NOTES: ;~ ~\~, ~~~~ OF I. SEE SHEET 3 FOR COORDINATE TABLE .• i~'~P'' ~• ~•''qs/I-111 ~ •••• •' 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND i •' ';~ 1~ • ~ ~ VERTICAL SURVEY DATA ' 49th ~. ~j r ~ ' ..... 3. SECTION LINES AND TIES ARE BASED ON PROTRACTED ~"""""""""""""""""""""4 ~ ~ VALUES. ............... ~• ~~ 'p~ KENNETH W. AYERS ~~ J'~,%• LS-8535 ~,' ~,~= II SURVEYOR'S CERTIFICATE I 1~~'FOp••.,,•~....~~„•.•••'NO~~i I 1 HEREBY CERTIFY THAT 1 AM PROPERLY REGISTERED ,,,1i ` `~i~~~~• AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL LOUNSBURY DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF & assoc[nTES, [rrc. FEBRUARY 28, 2008. SURVEYORS ENGINEERS PLANNERS ~' PHONE: 19071 272-5451 y.~ AREA: MODULE: UNIT: ConocoPhilli s NORTH COOK INEET p TYONEK PLATFORM Alaska, Inc. WELL CONDUCTOR AS BUILT CADD FILE N0. 08-005 AS BUILT 02/27/08 DRAWING N0: Og~~5 AS BU~~T PART: 1 of 3 REV: 1 i REV DATE BY CK APP ESCRIPTION REV DATE BY CK P DESCRIPTION 1 2/29/08 SAS KWA MODIfY WELL HOUSE SCHEMATIC, SHT.2 ADD MUD LINE ELEV., SHT.3 v ~ ~~ i ~~ 9 y~°~ ~ aaa nx n9 SO S. ro.u' SEG 6 JiS Z ~ / \/ O ~Q ~~ SCALE: 1"=30' a9 aa. O D 600 -50 ES ESD 600-51 O Ala 7 'p ~Bz A8 A•A• B3~ p5 • • • A3~ A6 AI BI : •A5 A4 • A2 WELL HOUSE 2 Op ~ zp A1O~ LEGEND: '~~ ~ WELL p WELL CONDUCTOR 0 ESD (EMERGENCY SHUT OFF VAL VEl GENERAL NOTES: 1. SEE SHEET 3 FOR COORDINATE TABLE 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND VERTICAL SURVEY DATA LOUNSBURY WELLS EXIST IN WELL HOUSE ND. 4, AND IT 3. NO WAS NOT & ASSOCIATES, INC. [~ A S B UIL T SURVEYORS ENGINEERS PLANNERS V PHONE: (9071 272-5451 ~,~ AREA: MODULE: UNIT: ConocoPhilli s NORTH °°OK ~N~ET p TYONEK PLATFORM Alaska, Inc. WELL CONDUCTOR AS BUIET CADD FILE N0. DRAWING N0: PART: REV: 08-005 AS BUILT 02/27/08 08-005 AS BUILT 2 of 3 1 REV DATE BY CK 1 2/29/09 SAS KWA MODIFY WELL HOUSE SCHEMATIC, SHT.2 ADD MUD LINE ELEV., SHT.3 DATE IPTION ASP ZONE 4, NAD83, FEES NAD83 GEOGRAPHIC MLLW DESCRIPTION (POINT NO.) NORTHING FASTING LATITUDE LONgTUDE .ELEVATION NqU W ELL TAG NO. WELL HOUSE NO. 1 1001 2586492 1472018 61 04 34.38 150 57 03.71 72.0 Conductor 1 1002 2586489 1472017 61 04 34.34 150 57 03.72 73.9 B3 1003 2586485 1472019 61 04 34.31 150 57 03.67 74.1 A12 1004 2586485 1472023 61 04 34.31 150 57 03.59 73.8 B1 1005 2586487 1472027 61 04 34.33 150 57 03.52 72.0 Conductor 5 1006 2586491 1472027 61 04 34.37 150 57 03.52 73.7 B2 1007 2586495 1472025 61 04 34.41 150 57 03.57 72.1 Conductor 7 1008 2586495 1472021 61 04 34.41 150 57 03.65 73.7 A13 WELL HOUSE N0.2 2001 2586437 1472060 61 04 33.84 150 57 02.83 71.9 Conductor 1 2002 2586433 1472059 61 04 03.38 150 57 02.84 71.9 Conductor 2 2003 2586430 1472062 61 04 33.77 150 57 02.79 71.8 Conductor 3 2004 2586429 1472066 61 04 33.77 150 57 02.71 73.4 A9 2005 2586431 1472069 61 04 33.79 150 57 02.65 71.9 Conductor 5 2006 2586435 1472069 61 04 33.83 150 57 02.64 73.3 A10 2007 2586439 1472067 61 04 33.86 150 57 02.69 73.3 A11 2008 2586439 1472063 61 04 33.87 150 57 02.77 71.9 Conductor 8 WELL HOUSE N0.3 3001 2586488 1472128 61 04 34.36 150 57 01.47 73.0 Al 3002 2586484 1472127 61 04 34.32 150 57 01.48 73.1 A8 3003 2586481 1472130 61 04 34.29 150 57 01.43 73.1 A6 3004 2586480 1472133 61 04 34.28 150 57 01.35 73.0 A4 3005 2586483 1472137 61 04 34.31 150 57 01.29 73.0 A2 3006 2586487 1472137 61 04 34.34 150 57 01.28 73.0 A5 3007 2586490 1472135 61 04 34.38 150 57 01.33 73.0 A3 3008 2586490 1472131 61 04 34.38 150 57 01.41 73.3 A7 50 2586540 1472069 61 04 34.86 150 57 02.69 72.7 ESD Valve 600-50 51 2586501 1472011 61 04 34.46 150 57 03.86 72.6 ESD Valve 600-51 100 2586572 1472123 61 04 35.18 150 57 01.58 115.3 Top center helipad -101' MUD LINE SURVEY NOTES: 1. ALL COORDINATES ARE ASP ZONE 4, NAD83, US SURVEY FEET. GEOGRAPHIC COORDINATES ARE NAD83. 2. ELEVATIONS ARE IN FEET, BASED ON MLLW, REFERENCED TO DRAWING N0. MPD- TY04-2021, SHEET I OF I, REV. 2 3. ALL AS BUILTS ARE TO THE CENTER OF EXISTING STRUCTURE. 4. WELL CONDUCTOR ARE VERTICALLY AS BUILT TO THE TOP OF A 1/4" STEEL LID, TACK WELDED TO THE TOP OF THE CONDUCTOR. 5. WELLS ARE VERTICALLY AS BUILT TO THE TOP OF THE LOUNSBURY LOWEST HORIZONTAL FLANGE ON THE WELL. & nssoc>aTES, [rrc. i ConocoPhilli s p Alaska, Inc. CADD FILE NC. DRAWING N0: 8-005 AS BUILT 02/27/08 AREA: SURVEYORS ENGINEERS PWNNERS PHONE: (9071 272-5451 MODULE: UNIT: NORTH COOK INSET TYONEK PLATFORM WELL CONDUCTOR AS BUILT 08-005 AS BUNT PART: 3 of 3 REV: 1 ConocoPhillips April 1, 2009 RECEIVED APR 0 3 2009 Alaska Oil & Gas Cons. ComrmssiOn Anchorop Cathy Foerster Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Frank Snyder Manager Onshore Exploration ConocoPhillips Alaska, Inc 700 G Street, ATO 1476 Anchorage, AK 99510 (907) 265-1138 (phone) (907) 236-4966 (fax) Frank.C.Snyder@conocophiIlips.com Hand Deliveried Subject: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut -In Well Information ConocoPhillips Alaska, Inc. (CPAI) is responding to the Alaska Oil and Gas Conservation Commission (AOGCC) letter date January 29, 2009 requesting CPAI to review the list of suspended, long term shut-in and observation wells operated by CPAI. CPAI has completed a detailed review of the suspended wells operated by CPAI. Attached is a list of CPAI suspended wells operated by CPAI. In summary CPAI added the following three wells to the list of CPAI operated suspended wells: Kuparuk River Unit 2F-20 Lisburne Exploration Tail _ Wes} Cncldl4iil Lookout #1 West Sak 444-0-5A c5, If you have any questions regarding Suspended Wells operated by CPAI, please contact me at 265-1138. Sincerely, Frank -Snyder Manager Onshore plora 'on Attachment Suspended Well Name API w1k & Colville River Colville River Unit Listed in AOGCC letter of Year January 29, 2009 Drilled Current Location Operator Surface location Nanuq 5 50-103-20414-00-00 yes 2002 CRU I CPAI Alpine Colville Riv CD4 -213 50-103-20540-00-00 yes CRU I CPAI Alpine Silverti 1J-14 50-029-22990-00-00 yes 2001 KRU CPAI Kuparuk N. Cook Inlet Unit B-02 Kuparuk Riv Tarn 2L-321 50-103-20286-00-00 yes 1999 KRU CPAI Kuparuk Kuparuk Riv W Sak 1 H-105 50-029-20727-01-00 yes 1982 KRU CPAI Kuparuk Kuparuk Riv W Sak J-133 50-029-23315-00-00 yes KRU CPAI Kuparuk Kuparuk Riv W Sak 1Q-101 50-029-23282-00-00 yes 2005 KRU CPAI Kuparuk Kuparuk Riv W Sak 3J-101 50-029-23283-00-00 yes 2005 KRU CPAI Kuparuk Kuparuk Riv Unit 2E-05 50-029-22423-00-00 yes 1993 KRU CPAI Kuparuk Kuparuk Riv Unit 2E-06 50-029-22415-00-00 yes 1993 KRU CPAI Kuparuk Kuparuk Riv Unit 2E-17 50-029-22419-00-00 yes 1993 KRU CPAI Kuparuk Kuparuk Riv Unit 3G-25 50-103-20244-00-00 yes 1997 KRU CPAI Kuparuk Kuparuk Riv Unit 3H -25A 50-103-20203-00-00 yes 1999 KRU CPAI Kuparuk Kuparuk Riv Unit WSW -01 50-029-20537-00-00 yes 1981 KRU CPAI Kuparuk ,Kuparuk River Unit 2F-20 No 1997 KRU CPAI Kuparuk L`mok InWi Unit N. Cook Inlet Unit A-11 1 50-883-20031-00-00 yes 1970 CI CPAI T onek Platform N. Cook Inlet Unit B-02 50-883-20090-01-00 es 1998 CI CPAI T onek Platform a0Z aOb-173 app-�200 /(?g-_-�26Z ,;?OA/ 2 28 aab-/o6 X05 - 156 157 /y3 - i - 9 //jP 14, 1<7-2.Oi6 �Wes><.Sak *PKW 500292072701 No 2004 KRU? CPAI Kuparuk �; /G9 dfF �77, 2/c, � 7 Listed in AOGCC letter Current or'Janua Year Lease Suspended Well Name API 29, 2009 Drilled Location Operator Surface location Longitude Latitude ExploratiAgells Drilled by ARCO, PPCO, CPAI, PAI Lookout #1 No 2001 GMTU CPAI l 6 NE- NPRA T11 N R2E Sec 36 5186.47' I . FEL 325.9' FNL 70.27 -151.539 Scout 1 50-103-20479-00-00 yes 2004 GMTU CPAI 670/ (.(J NE- NPRA T11 N R1 E Sec 20 5048.25' FEL 4709.74' FNL 70.2871 -151.962 noses Tooth C 50-029-20315-00-00 yes 2001 GMTU CPAI / L/ 9 NE- NPRA T1 ON R1 E Sec 3 4165.02' FEL 1914.93' FNL 70.2515 -151.8695 Spark 1A 50-103-20313-01-00 yes 2000 GMTU CPAI NE- NPRA T1 ON R2E Sec 8 2783.19' FEL 1608.09' FNL 70.2379 -151.6896 Carbon50-103-20477-00-00 yes 2004 GMTU CPAI T1 ON R1 E Sec 4 2162.24' NE- NPRA FEL 3421.7' FNL 70.247 -151.896 Puviaq 50-279-20008-00-00 yes 2003 NW NPRA CPAI T1 6N R1 OW Sec 35 444' v� • J�y FWL 1713' FNL 70.6992 -154.4118 Placer 1 50-103-20481-00-00 yes 2003 West of KRU ASRC T12N R7E Sec 33 5260.68' 0/ FEL 4271.52' FNL 70.3461 -150.3985 West Mikkelsen ST 1 50-029-20278-00-00 yes 1978 West of CPAI T1 ON R1 9E Sec 32 4281.06' % 7 Badami FEL 507.66' FNL 70.1833 -147.3851 r 1 Hemi Sprig 50-029-21056-00-00 yes 1984 South of KRU Pioneer T1 ON R11 E Sec 12 1319.86' •ST FEL 3960.87' FNL 70.232 -149.222 Gull Island State 1 50-029-20151-00-00 yes 1975 PBU BP T12N R1 5E Sec 28 5250.91' j -7 FEL 2375.94' FNL 70.366 -148.3675 Gull Island State 20/� 50-029-20195-00-00 yes 1976 PBU BP T12N R15E Sec 28 5220.88' FEL 2378.14' FNL 70.366 -148.3673 N.Staines River State #1 t 50-08920017-00-00 yes 1982 former PTU XOM T9N R24E Sec 8 3539.73' FEL 2647.11' FNL 70.1487 -146.1094 �^t ��t,TT �1 L>YmJxxL�►7�SKA 011L� A�,,��1D rrrccc�iEETl�t.a��7ccTT- January 29, 2009 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7004 1160 0001 3621 1861 James Rodgers ConocoPhillips Alaska Inc. PO Box 100360 Anchorage AK 99510-0360 \ lca.- oat 4. SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Request for Verification of Suspended, Shut -In and Observation Well Information �j�C A"M Dear Mr. Rodgers: This letter supersedes our correspondence of January 28, 2009. Enclosed are lists of suspended, long term shut-in and observation 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 orjim.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 • Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. • Print your name and address on the reverse so that we can return the card to you. • Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to: jawll 'U�Agent B. REIVeived by ( Printed Name) C. Date of Delivery D. is delivery address different from item 1? ❑ Yes If YES, enter delivery address below: ❑ No 3. Sewice Type 'in Certified Mail ❑ Express Mail ❑ Registered '19teturn Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 2. Article Number (Transfer from service labe, 7004 116 0 0001 3621 181=1 PS Form 3811, February 2004 Domestic Return Receipt 102595-02-M-1540 U.S. Postal Service,, CERTIFIED MAIL, i RECEIPT co (Domestic Mail only; No Insurance Coverage Provided) ra Ai k#�Jft 995kO-OXO ,, M Postage $ $0.4' S r -q �gp Pp 0 Certified Fee $2.70 02 S 1. Post n * ��i}late 9� 0 Return Reciept Fee (Endorsement Required) $2,20 .� n N t-3 —0 Restricted Delivery Fee (Endorsement Required) $0.00 19 rz� � Total Postage & Fees $ $5.32 01 99513", t3 Sent To - -- --' • ' • ' --- ------------- or PO Box No. • Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. • Print your name and address on the reverse so that we can return the card to you. • Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to: jawll 'U�Agent B. REIVeived by ( Printed Name) C. Date of Delivery D. is delivery address different from item 1? ❑ Yes If YES, enter delivery address below: ❑ No 3. Sewice Type 'in Certified Mail ❑ Express Mail ❑ Registered '19teturn Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 2. Article Number (Transfer from service labe, 7004 116 0 0001 3621 181=1 PS Form 3811, February 2004 Domestic Return Receipt 102595-02-M-1540 Operator Suspended, Shut In and Observation 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 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 15 E UM 176-013-0 50-029-20195-00-00 GULL IS ST 2 SUSP 4/22/1977 2378 FNL 59 FWL Sec 28 T 12 N R 15E UM 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 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 202-248-0 50-279-20008-00-00 PUVIAQ 1 SUSP 4/1/2006 1703 FNL 451 FWL Sec 35 T 16 N R 10W UM 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 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 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 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 19 E UM 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 202-042-0 50-103-20414-00-00 NANUQ 5 SUSP 4/5/2002 2342 FSL 283 FEL Sec 24 T 11 N R 4 E UM 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 204-228-0 50-029-20727-01-00 KUPARUK RIV U WSAK 1H-105 SUSP 12/18/2004 528 FNL 803 FEL Sec 33 T 12 N R 10E UM 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 205-156-0 50-029-23282-00-00 KUPARUK RIV U WSAK 1Q-101 SUSP 11/29/2005 1574 FNL 1160 FEL Sec 26 T 12 N R 9 E UM 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 12 N R 9 E UM 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 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 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 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 199-040-0 50-103-20203-01-00 KUPARUK RIV UNIT 31-1-25A SUSP 6/29/1999 1220 FNL 281 FWL Sec 12 T 12 N R 8 E UM 180-140-0 50-029-20537-00-00 KUPARUK RIV UNIT WSW -01 OBSW 4/1/1982 321 FNL 201 FEL Sec 9 T 11 N R 10E UM 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 NORTH COOK INLET Thursday, January 29, 2009 Operator Suspended, Shut In and Observation Wells CONOCOPHILLIPS ALASKA INC Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... 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 Thursday, January 29, 2009 SUSP 10/9/2002 1302 FNL 1020 FWL Sec 6 T 11 N R 9 W SM SUSP 9/29/2002 1249 FNL 980 FWL Sec 6 T 11 N R 9 W SM \L_" a*,-- c)C� Al i S SARAH PALIN, GOVERNOR r rA ALASKA OIL AND GAS / 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSI01V / ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 January 28, 2009 FAX (907) 276-7542 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1.820 0001 2499 5968 James Rodgers ConocoPhillips Alaska Inc. PO Box 100360 Anchorage AK 99510-0360 Re: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and i NES Shut -In Well Inforn-lation 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 tern 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 .lim 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 Provide( Tote+ Postepe b' � $5.49 0 �p r Ln WWTO James Rodgers ® ConocoPhillips Alaska Inc. Box No. or PO Box 100360 PO ciy,smta:ziP+e Anchorage AK 99510-0360 Ir Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. U Print your name and address on the reverse so that we can return the card to you. L- 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 X ❑ Addressee B. Received by (Printed Name) C. Date of Delivery 5 f FF �,t'4C� C� l r -1--0) D. Is delivery address different from item 1? ❑ Yes If YES, enter delivery address below: ❑ No '3C 0 3. Service Type E1 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 7`005 1820 D O 01 2499 5968 PS Form 3811, February 2004 Domestic Return Receipt 102595-02-M-1540 •Er For delivery information visit our website at Er K L U SE L ru Postage � s $0.59 0535 r�Nd $2.70Fee Qc«tMea Fee $2.20 e� t •a p� M ►+.. ti ru cE yea �� ' $0.00 Tote+ Postepe b' � $5.49 0 �p r Ln WWTO James Rodgers ® ConocoPhillips Alaska Inc. Box No. or PO Box 100360 PO ciy,smta:ziP+e Anchorage AK 99510-0360 Ir Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. U Print your name and address on the reverse so that we can return the card to you. L- 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 X ❑ Addressee B. Received by (Printed Name) C. Date of Delivery 5 f FF �,t'4C� C� l r -1--0) D. Is delivery address different from item 1? ❑ Yes If YES, enter delivery address below: ❑ No '3C 0 3. Service Type E1 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 7`005 1820 D O 01 2499 5968 PS Form 3811, February 2004 Domestic Return Receipt 102595-02-M-1540 Operator Suspended and Shut In 'Wells PHILLIPS PETROLEUM CO Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... 'EXPLORATORY 162-028-0 50-883-10013-00-00 COOK INLET ST 17589 1-A SUSP 5/15/1973 1250 FSL 2025 FWL Sec 6 T 11 N R 9 W SM ADI -0017589 PT THOMSON 181-069-0 50-089-20017-00-00 P.T.UN.N.STAINES RV. 1 SUSP 5/6/1982 2632 FSL 1742 FWL Sec 8 T 9 N R 24 E UM ADL0047572 Wednesdqy, January 14, 2009 Operator CONOCOPHILLIPS ALASKA INC Field Permit API Number Well Name Suspended and Shuck In Wells Current Date of 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 ADLO385175 200-056-0 50-103-20313-01-00 SPARK 1A SUSP 4/4/2001 1608 FNL 2497 FWL Sec 8 T 10 N R 2 E 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 19 E 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 4E UM ADL0380075 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 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 50-02923315-00-00 KUPARUK RIV U WSAK 1J-133 SUSP 8/13/2006 1622 FSL 2296 FEL Sec 35 T 11 N R 10E UM ADL0025661 ADL0380058 205-156-0 50-029-23282-00-00 KUPARUK RIV U WSAK 10-101 SUSP 11/29/2005 1574 FNL 1160 FEL Sec 26 T 12 N R 9 E UM ADL0025634 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 50-02922423-00-00 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 31-1-25A 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 12N R 7 E UM ADL0025552 Wednesday, January 14. 2009 ADL0380077 ADL0388903 ADL0025662 ADI -00256,11 1 Operator Suspended and Shut In Wells CONOCOPHILLIPS ALASKA INC Fleld 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 . . FRANK H. MURKOWSKI, GOVERNOR A"~ASIiA OILAlft) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Gary Eller Wells Group Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: North Cook Inlet Unit, Tertiary Gas Pool, NCI A-1I Sundry Number: 306-353 \ Igq- Dtöq Dear Mr. Eller: 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 also note that in order to be converted to a Class II disposal well, NCI A-11 must meet the requirements of 20 AAC 25.252 and in particular the external integrity requirements at 20 AAC 25.252 (6). A new disposal injection order ("DIO") specifically for this well or an amendment to existing DIO 17 must also be obtained. Approval of this work plan should not be construed as assuring approval of a disposal authorization. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely Chairman ? DATED this~ day of November, 2006 Enel. . . Gary Eller Wells Engineer Drilling & Wells ~ ConocdPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4172 October 12, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 ECEIVED ('¡('1 2 4 2006 l} l... I (i{ Gas Cons> Commission AnchoragR Subject: Application for Sundry Approval for NCI A-11 Dear Commissioner: ConocoPhil/ips Alaska, Inc. submits the attached Application for Sundry Approval for the North Cook Inlet well A-11. Our objective is to perform a rig workover in anticipation of converting the well to Class" disposal in. the same intervals in well ,/ A-12. We plan to submit a Class II disposal application in the future. If you have any questions regarding this matter, please contact me at 263-4172. JGE/skad .." RECEIVED W'å"tO( . n fì"C STATE OF ALASKA 7l () ('1 2, 4: ¿UÜU L.. ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICA TION FOR SUNDRY APPROV ~ska Oil & 20 MC 25.280 . {..I'·.....misslon Y;..H\'1 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Alter casing 0 Repair well 0 Plug Perforations 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 , 2. Operator Name: 4. Current Well Class: ConocoPhillips Alaska, Inc. Development 0· 3. Address: Stratigraphic 0 Perforate 0 . Waiver 0 Other 0 Stimulate 0 Time Extension 0 Re-enter Suspended Well ~ Exploratory 0 Service 0 5. Permit to Drill Number: 169-089 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes 0 No 0 NCI A-11 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 17589 . RKB 116' Cook Inlet Field 1 Beluga Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft}: Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8212' , 6297' '3965' 4065' Casing Length Size MD TVD 50-883-20031 ~OO 8. Well Name and Number: Burst Collapse Structural Conductor Surface Production 7" 380' 380' 621' 621' 2745' 2393' 8003' 6154' 323' 584' 2708' 7966' 30" 16" 10.75" Perforation Depth MD (ft): plugged Packers and SSSV Type: Otis VSR pkr @ Halliburton SCSSV landing nipple @ 13. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 15. Estimated Date for Commencing Operat 17. Verbal Approval: Commission Representative: Perforation Depth TVD (ft): Tubing Size: 4.5" Tubing Grade: J-55 Tubing MD (ft): 4083' November 15, 200'6 Date: Packers and SSSV MD (ft) 4083' 298' 14. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Service 0 . Plugged 0 . WINJ 0 Abandoned 0 WDSPL 0 Signature is true and correct to the best of my knowledge. Contact: Title: Phone 265-6958 Gary Eller @ 263-4172 Wells Group Engineer 18. I hereby c . Commission Use Only . ~.8 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test ~ Mechanical Integrity Test ~ Location Clearance 0 Other: c..O,,\c,.C\- L"-~~<t.L\-c~ ~ c....\\O~ ~~~€:<>~ ð~ o..t--.'i S.~()~t-~<{. ~":>¥\~, RBDMS BFt NOV () 1 2006 Subsequent Form Required: Approved by: Form 10-403 Revised 06/2006 APPROVED BY :h THE COMMISSION Date: ~,. '-tJ. ¿, ,,/ s~~n Duplicate $-~ Uß~ IO~Z>~ . . NCI A-11 WORKOVER PROCEDURE Objective: Mechanically prep well A-11 for Class /I disposal. Proposed Disposal Perfs: 3750'-3795' and 3872'-3892' MD Procedure Outline: 1.' Bullhead into the 7" x 10-3/4" casing annulus to confirm hydraulic communication to the 10-3/4" shoe at 2745' MD. 2. Drift tubing with slickline 01 3. Chemical cut or jet cut 4-1/2" tubing as deep as possible, estimated at 3965' MD based on top of cement 10/2002. 4. MIRU workover rig. NU BOPE. Pressure test BOPE to 250/3000 psi. (Note: All perfs in well are plugged. Maximum expected formation pressure = 9.0 ppg EMW at 3321'TVD = 1554 psi. Maximum anticipated surface pressure, assuming gas gradient, is 1222 psi.) 5. Pull 4-1/2" tubing above the cut joint. 6. Perf squeeze perfs at 3745'-3750' MD. 7. T/H. Establish circulation through squeeze perfs (if possible). Circulate cement through perfs taking returns up 7" x 10-3/4" annulus. Plan on placing 50 bbl of cement (±1000' if ~ ~~~a gauge hole). If unable to circulate, plan on conducting a ~ squeeze. ~o-J."'0,,~ \à\I~' \è\~ ~: PU bit and TIH. Drill out cement to 3800'. Pressure test squeeze. If pressure test ~c \-..~~~$C()\ <!:Â~\\\ passes, continue drilling out cement to PBTD of ±3965'. POOH. 10. MIRU e-line. Run a USIT/CBl log from PBTD up to 3200' MD. Decide from bond log " whether additional squeeze work needs to take place. RDMO e-line. 11. Run 4-1/2" completion with permanent packer. Completion will not include a SCSSV, but will include a nipple at±500' for an injection valve if it becomes necessary. 12. Circulate inhibited brine into fA. land tubing, set packer. Pressure test fA to 1500 psi. 13. NO BOPE, NU tree. RDMO workover rig. , ~ . ConocoPhilli.ps API: 50-883-20031 AOGCC: Lift thds: 4W' 1ST SPV: type H Wellhead: FMC 8/1, 5M Proposed Completion · Tubing = 4Y2/1, 12.6 ppf, L-BO, 1ST-Mod .3.813" X-nipple at 500' · Saker SABl permanent packer at 3550'. Includes 17' PBR and millout extension. .3.813" XN'-nipple at 3580 no-go = 3.725/1 · Re-entry guide at 3585' · Existing 4-112/1 tubing jet cut at top of cement at 3965' MD. .4-112/1 cement retainer at 4065' MD (10102) . Otis VSR packer at 4083' · Plugging of existing perfs performed 1012002. See 10-407 dated 10124102. Directional: Max hole angle: 46° at 2534' Angle at top perf: 42° at 3750' Max doglegs: 4.1 °11 00' at 911' Note: Tubing, casing, and completion details omitted below 4083' MD because has been plugged. See full we/lbore schematic for detail. . . Well: A-11 Field: NCIU PROPOSED x Conductor: 16/1,65 ppf, H-40 at 621' Surface Casinq: 10%/1,45.5 & 51 ppf, J-55 at 2745' Proposed Squeeze . Current cement top 3900' via CBl of 12/13/68. . Propose 50 bbl circulating squeeze from squeeze perfs at 3745'-3750', or block squeeze same interval if unable to circulate Proposed Perfs Sqz Perfs: 3745-3750 MD 3750' - 3795' MD (3215' - 3248' TVD) 3872' - 3892' MO (3306' - 3321' TVO) Production Casinq: 7", 26 & 23 ppf, J-55 at 8003' S)\I ~o\\~ ~ SSC\.7 . tv\~, PBTD = 3965' (1012002) .¡ TO = 8212' Last Updated: 12-0ct-06 Updated by: JGE " "' 42 ==: 380' 1~'" 16" @ 621' "'"- z, ~ " E ~,;' ~ 103/4"@2745' CMT top @ 3965' (1012002) CMT Retainer@ 4065' Otis VSR packer @4083' Cook Inlet Sands Ot~ RH hydr rtrvbl pkr @ 4182' 4225~26 (sqz) 4254 . 4284 Stray 4306-07 (sqz) Baker "Fit Perm pler@ 4617' CMTretai/'ler@4623' 4624·25 (sqz) 4657 - 4702 -Cf·1.0 4715 - 4805 Cl-2.0 4816 - 4846 CI-3.0 4852 - 4867 CI-3.1 19 Baker "F" Perm pier @ 4937' 17 CIPB@4966'(12/'01)notmllled ... _;~ 4977 - 4987 CI-S.D _ ~ ;~~~:~~~ ~;:::;&6.0 ~~ 14 ß JIBaker"Fltpermpkr@S2111 ;J "" -~~ 5248 ~ 5262 CI-8.0 _ R 5280 - 5285 C/-8.2 _." 5289-5307' C/-8.2 "'" :,¥, 5358 - 5368 al-9.0 ~ 5;'?99 - 5419 CI-10.D '~ 5450-5460 CJ-11.0 ----'- _ "" 5468-5498 C/-11.0 C"'='-'O·,XA.,· '~ !!: 'Æ 5538-39 (sqz) ~: ~ 10 8 i~ Baker "F" Penn pkr@ 5726' I Beluga Sands '1i 8 12 2: - 8~ Open 5845-5859 b..1 5871 - 5877 b-B 5899 - 5.909 c-O.5 59.30 - 5950 0-1 5962-5974 c-2 8 :~ s ~ .. ~ 6 2: i~ Baker "F" Perm pkr @ 6115' ·m :~l 6182 - 6197 d-3 . ~ ;:;:: ;:;; ~~.5 6272 ~ 6278 d-5 6449 - 6464 e-B 4~ -""- CISP "@"7;5 - . 717$-7196 1-7 7267 -7277 }2 P6TD 7956' 7"@8003' Total Depth 8212' . . Conoc6Phíllips NCIU WELL A-11 Completion Diagram Gas Producer FMC OCT SÎngfe Camp. FMC 41/2" ard X 41/2" BT&C Annulus Fluid: a,5 Ib/gal KCL Completion Fluid with 30 % Methanol TOC: 3900' Der CSL dated 12113/68 WATER DEPTH: iiii!!!:;ODiiiiiir i:!BottoITfi' nil;:"! :;WI1Wiilii:¡:!! .", ::Grade",::'r' !'¡i¡iiÍi:: !i:n'Conri~:n CASING & TUBING 30" 40' 16" 40' 103/4" 40' 7" 40' 7" - 77' 7" 6991" 4 112" 39' 4 1/2" 333' 1112' 1408" 120 ' ';:;¡ii!:": .,:id:!: !:!:i;¡:!·BûrsF::¡~:!!:i!H;ir - 380' 621' 2745' Tl' 6991' 8003' 333' 4083' 6498' !ifi"Ite:iïcithi!:L PRODUCTION TUBING STRING & JEWELRY 45 0.00 38.90 Elevation 44 38.90 0.67 FMC I OCT 6" 3M 4 1/2" 8rd x 4 1/2" BT&C Tubing Ha_ng~r 43 39.57 258.32 41/2" 12.61b/ft J-55 Mod BT&C Tubing 42 297.89 2,48 Halliburton .(.5" scssv LandJngNlpple; purred SSSV12/S/01 41 300.37 31,76 41/26 12.6 Iblft J~55 Mod BT&C Tubing 40 332.13 0.75 X-Over 4112" Mod EVE 8rd x 41/26 Mod BT&C 39 332.88 3748.98 41/26 12.6 Jb/ft J-55 Mod EUE 8rd Tubin 38 4081.86 0.8 X-Over 4 112- BT&C x 4 112" EUE 37 4082.66 Strai ht Slot Locator and Seal Units 10' overall) 36 40a2.66 13.73 Otis' "VSR" Hydraulic Set Retrievable Packer 35 4096.39 1.38 Tubinq Adapter and X-Over 34 4097.77 30.35 31/2- 9.2/b/ft J-55 Buttress Tubina & X-Over 33 4128.t2 1.59 Otis "X" Landing Nipple 32 4129.71 30.96 3 1/26 9.2 JbIft J-55 Buttress Tubing & X-Over 31 4160.67 1.33 Trf-State High Pressure Pack-Off Overshot 30 4162.00 20.32 31126 9.21bltt J-55 Buttress TLibin & X-Over 29 4182.32 .52 Otis "RW Hvdraulic Set Retrievable Packer 28 4186.84 130.75 3 1/26 9.2 b/ft Tubing, Blast Joints, X-Over. 21 4317.59 3.95 Otis 3 1/2" "XA" Sliding Sleeve - closed 12/5/01 26 4321.54 295.46 31/2" 9.2lb/ft N-80 Buttress TubinQ & X-Over 25 4617,00 Saker Sea! Unit 24 4617.00 2.08 Baker Model"F" Permanent Packer 23 4619.08 276.91 31126 9,2 bltt TUbinq, Blast Joints, X-Over. 22 4895.99 ,2.69 Otis 2 7/S" "XA" Sliding Sleeve 21 4$98.68 38.32 3 1/26 9.2Ib/ft N-80 Buttress Tubing & X-Over 20 4937.00 Baker Seal Unit 19 4937.00 1.73 Baker Model "F" perJ11anent Packer 18 4938.73 232.40 31/26 9.2 Iblft TUbina, Biasi Joints, X-Over. 17 5171.13 2.69 Otis 2 7/8" "XA" SlidlnQ Sleeve 16 5173.82 37.18 31/2- 9.21bltt N-80 Buttress Tubinç¡ & X-Over 15 5211.00 Baker Seal Unit 14 5211.00 1.99 Báker Model "F" Permanent Packer 13 5212.99 322.72 31/2" 9.2 Ibltt Tubin ,Blast Joints, X-Over. 12 5535.71 2.69 Otis 2 7/a" "XA" Sliding Sleeve 11 5538.40 187.631/2" 9.21blft N-80 ButtressTùbing&X-Over Baker Seal Unit 2.65 Baker Model "F" P~rmanent Packer 286.76 31/26 9.2Ib1ttTubing, Blast Joints, X-Over. 2.69 Otis 2 718" "XA" Sliding Sleeve 96.9 3 1/2" 9.21blft N-80 Buttress Tubing & X-Over Baker SeaJ Unit 2.67 Baker Model "F" Permanent Packer 348.53 3 1126 9.2 Ib/ft Tt.¡bfng, Blast Joints, X-Over. 0.8 Otis "XN6 Landing Nipple 30.02 31/2" 9.21b1ft N-80 Buttress Tubina & X-Over 0.98 Wireline Re-Ent Guide End of Tubing 65" 45.5# & 51# 26" 23" 26# 12.60# 12.15# 9.2" H·40 J-55 J-55 J-55 J-55 J-55 J-55 N·60 1540 3350 4660 4080 4660 6600 4730 4730 BT&C BT&C BT&C BT&C Mod BT&C Mo::>d Eve 8(d BT&C 10 5726.00 9 5728.65 8 6015.41 7 6018.10 6 6115.00 5 6117.67 4 6466.20 3 6467.00 2 6497.02 1 ·6498 400· First Production from Cook Inlet A, 1-3,5-11 7/75- CI A, 1-3,5-11, Beluga (Add Beluga) 7/83 - Hun 3 1/2 Inch tubing with multiple packers and sliding sleeves 10/90 - Beluga we1J only 5~94 - RUn 4-1/2 inch tubing, well nol reperforated due 10 multiple packers, Beluga well 6/93 - Top of FiJI 6505' 1//95· Top of FíJl6363' (Lower Sleeve covered). 5/96· Top· of Fill 6366' (Lower Sleeve covered). 1/97 ü Open CI 1-3 Sleeve at 4917' 9/99 ~ Test 5.5 MMCFD & 13.5 6WPHr to fJare 400 psi (U. CI and Be(uga sleeves open) 10/99 - Could not get 2" gauge ring below 5987' 11/99 - Closed Upper Cl sleeve, Test 300-350 BWPD from Beluga (to flare) 150 psi FTP 1/-00 ~ Tafl fill at 5848', baJJ soft to hard sand. Found Indications Lower Cook Inlet sleeve open, dosed ?JI sleeves. Open Lower Cook Inlet Sleeve at 5536', no flow. FL 1800', pressure up with gas. Open Upper Cook Inlet sleeve, well woul.d not flow. Check forfiU TD 5101', bail to 5106'. Nov 11. 2001 - Pull sessv Nov 28,2001 -"FeO 5497' - 5910', SL Tag 5720' RKB Nov 29, 2001 - 6ølpier log, found 3 holes @ 4988'-4989' RKB Dec 1·5, 2001 - Set 2.187- Bridge Plug@4966. Confirm XA sleeves@4896&4318' open, Se~ sessv. Attempt tQ flow wen; well died. 1215/01 - pulled sessv. Close 3.5- XA sleeve@4318'. Tag fine sand@ 4318' Oct. 1ü2, 2002 - mill cement Oct. 3, 2002 - complete P&A w/cement Oct 4, 2002 - cement squeeze Oct. 9, ~002 - tag top of cement @ 3965' '" Updated: 8/1212004 By: Dan Bearden PBTD: 7,125' Fm rag: 4318' 12/2001 Well: North Cook Inlet Unit No. A"11 Location: Tvonek Plalform, Cook Inlel, Alaska Field: North Cook inlet Unit I CLOSED API# 508832003100 RKB-DriJI Deck: RKB· THF: 38.9 RKß..SL: 116 RK6-ML : ,"" "Colfj' !'¡;i",:,Tensri'i:;i'l!! 630 293 1~70 531 4080 327 30aO 288 4080 327 6530 135 4980 134 4980 3.958 6.000 3.958 5.563 3.813 5.566 3.958 5.563 3..953 4.919 3.958 5.563 2.994 5.56 3.065 3.85 3.880 5.980 3.969 5.740 2.992 3.500 2.750 3.750 2.992 3.500 3.047 5.740 2.992 3.500 4,000 6.000 2.992 3.865 2.75 2.992 3.500 4 4.000 6.000 2.992 3.865 2.313 2.992 3.500 4 .1.000 6.000 2.992 3.865 2.313 2.992 3.500 4 4.000 6.000 2.992 3.865 2.31"3 2.992 3.500 4 4.000 6.000 2.992 3.865 .2.313 2.992 3.500 4 4.000 6.000 2.992 3.865 2.205 2.992 3.500 3.725 4.987 OPEN CLOSED CLO$ED JOB . . STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE APPLICATION OF PHILLIPS PETROLEUM COMPANY for an order allowing the underground disposal of Class II fluids in the North Cook Inlet Unit A-12 well. Disposal Injection Order No. 17 ) ) ) ) North Cook Inlet Unit North Cook Inlet Unit A-12 well September 29, 1998 IT APPEARING THAT: 1. By letter dated December 10, 1997, Phillips Petroleum Company ("Phillips") requested authorization :fTom the Alaska Oil and Gas Conservation Commission to dispose of Class II oil field waste fluids by underground injection into the North Cook Inlet Unit ("NCIU") A- 12 well, located on the Tyonek Platform. Additional information requested by the Commission was received March 10, 1998. 2. The Commission published notice of an opportunity for public hearing in the Anchorage Daily News on December 22, 1997. 3. The Commission received no protest or request for a public hearing. 4. The proposed disposal project requires an aquifer exemption under 20 AAC 25.440. The Commission issued Aquifer Exemption Order #4 on September 29, 1998, after receiving no objection :fTom the U.S. Environmental Protection Agency. FINDINGS: 1. Phillips is the operator of the NCIU. There are no other operators within a one-quarter mile radius of the proposed disposal injection project. The State of Alaska is the surface owner. 2. Phillips is the only working interest owner within the NCIU. 3. Aquifer Exemption Order #4 exempts the portions of aquifers in North Cook Inlet Field that are common to and correlate with the interval below 2900' MD in the NCill A- 12 well. 4. Fluids to be injected will consist of Class II waste fluids associated with drilling, workover and production operations :fTom the NCIU. 5. The NCIU A-12 well was originally drilled and completed as a producing gas well in 1970. Phillips requests approval to dually complete the well as a combination production and disposal well. 6. The proposed disposal zone in within the Sterling Formation. The Sterling Formation is composed of coarse-grained clastic intervals with interspersed relatively thin carbonaceous mudstones. Lithologic units are correlative throughout the unit. Disposal Injection Orderl17 North Cook Inlet Unit September 29, 1998 . Page 2 7. The proposed Class II disposal interval in the A-12 well is located between 3260' and 3380' MD, within highly porous and permeable fluvial sandstones and conglomerates ofthe Sterling Formation. 8. The proposed disposal interval is overlain and confined by approximately 95' of fine grained sediments, which will confine and prevent vertical migration of Class II fluids into non-exempt aquifers above 2900' MD in the A-12 well. 9. Structural deformation has folded the Sterling Formation, causing at least 250' of relief in the proposed disposal interval. 10. Structural closure and the associated hydrostatic gradient will prevent lateral migration of Class II wastes beyond the NCill. 11. The NCill A-12 well was constructed with 20" 133 lb/ft K-55 casing set at 1,990' MD and cemented to surface, and 13 3/8" 72 Ib/ft N-80 casing set at 6,950' MD. 12. Production tubing in the A-12 well consists ofT' 26lb/ft J-55/L-55 tubing from surface to 3,200' MD and 4 1/2" lO.5lb/ft J-55 tubing from 3,200' to 5,760' MD. A 23/8" 4.7Ib/ft J- 55 disposal tubing was run from surface to 3,206' MD. The well is equipped with multiple packers to isolate production zones and a "twin-flow" packer set at 3,200' MD to isolate pressure to the disposal interval. 13. A cement bond log was run on October 30, 1997, to confirm cement isolation of the disposal zone. The cement bond log, received by the Commission on September 8, 1998, shows good quality cement between 1940' and 5700' MD. 14. The NCill A-12 passed a mechanical integrity test of the casing-tubing annulus on November 9, 1997. 15. The average disposal rate during peak activity is expected to be about 3000 barrels per day. An average of 300 to 500 barrels per day is anticipated to be disposed of throughout the life of the project, but may be higher, depending on level of drilling activity and amount of water produced with the oil and gas. 16. The maximum anticipated surface injection pressure is 2500 psi. The average injection pressure will range between 1500 and 1800 psi. 17. Fracture modeling studies indicate that the proposed disposal will not initiate or propagate fractures though the confining zone at injection rates and pressures. CONCLUSIONS: 1. The requirements of20 AAC 25.252 for authorization to dispose of Class II fluids in the NCill A-12 well have been met. 2. Waste fluids authorized for disposal under this order will consist of Class II waste generated from drilling, production and workover operations in the NCill. 3. The proposed disposal operations will occur in permeable strata that can be expected to accept fluids at pressures less than the fracture pressure of the confining strata. 4. Waste fluids will be contained within appropriate receiving intervals by confining lithology, cement isolation of the perforated intervals, and operating parameters. Disposal fujection Order. 17 North Cook fulet Unit September 29, 1998 . Page 3 ? Aµrl ' 5. Surveillance of disposal rate and pressure, and casing pressure will ensure anomalous performance is observed and diagnosed. Abnormalities in operating conditions may indicate that fluid is not going where intended. 6. There are no aquifers being used as a source of drinking water within or near the NCIU. 7. Disposal into well the NCIU A-12 well will not occur into a non-exempt freshwater aquifer, and will not result in an increased risk of movement of fluids into a freshwater source. \ V'\ -b \A'fi- The mechanical integrity of this well has been demonstrated in accordance with 20 AAC\ 25.412. I The cement bond log indicated uniform bonding and adequate coverage over the entire I logged interval, from 1940-5700' MD. J' 10. Disposal operations in the NCIU A-12 well will not cause waste or jeopardize correlative rights. . NOW, THEREFORE, IT IS ORDERED THAT: - tž'>e.J./ç~eeJ fh- u: D;;;O , ,. - .~:~(t?r '5Dh~. I'1J ¡",.+üv.J Cu,~fui\þ<J Rule 1 Authorized fuiection Strata for Disposal .- " ~ ~ e1<'œei- J'vtk'sp ,;v/~Z.S"t.. '31kO~~I~II oil field fluids may be iniected into the NCIU A-12 well in confo- P/<.C~~Zev J4: ."bi".e. ~ r ~ - M.:t,- !,.¿M.,rz 20 AAC 25, for the purpose of disposal into strata between the depths 3260' - 3380' MD. I vÌ¡t?:Kv- CqL G!~ C).+i-¿- t,vet·t c~- cÞz.Ä,..~ ~ íríJ ~ fSi'itd¡:; r; 8. L) Rule 2 Demonstration of Tubing/Casing Annulus Mechanical futegrity The tubinglcasing annulus must be tested for mechanical integrity in accordance with 20 AAC 25.412 prior to initiating injection and at least once every four years. A test surface pressure of 1500 psi or 0.25 psi/ft. multiplied by the vertical depth of the packer, whichever is greater, but not to exceed a hoop stress greater than 70% of the minimum yield strength of the casing is to be used. The test pressure must show stabilizing pressure and a decline of less than 10% in a thirty- minute period. The Commission must be notified at least twenty-four (24) hours in advance to enable a representative to witness pressure tests. Rule 3 Well futegrity Failure Whenever disposal rates, operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the Commission on the first working day following the observation, and obtain Commission approval of a plan for corrective action and Commission approval to continue injection. Rule 4 Surveillance Operating parameters including disposal rate, disposal pressure, annulus pressure and fluid volume must be monitored and reported according to the requirements of20 AAC 25.432. An annual report evaluating the performance of the disposal operation must be submitted on or about July 1 of each year. Disposal Injection Orde. 17 North Cook Inlet Unit September 29, 1998 . Page 4 Rule 5 Operational Criteria Maximum disposal rates shall not exceed 3000 bbls/day. Maximum surface disposal pressure shall not exceed 2500 psi. Rule 6 Administrative Action Upon request, the Commission may administratively revise this order upon proper showing that the change is based on sound engineering practices and will not allow waste fluids to escape rrom the disposal zone. DONE at Anchorage, Alaska and dated September 29, 1998. David W. Johnston, Chainnan Alaska Oil and Gas Conservation Commission Camillé Oechsli, Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the lO-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). . . North Cook fulet Unit A-II (169-089) Note to File October 31, 2006 ConocoPhillips (CPAI) has submitted a sundry notice (306-353) requesting to perfonn work on NCIU A-II. CPAI intends to cut and pull the tubing from the well, perfonn remedial squeeze work and re-complete the well with the intention of obtaining approval to convert the well to Class II disposal service. A-ll was drilled some 35 years ago and was completed in 1975. During its life, 3 workovers have been conducted on the well. All perforations in the well were plugged in October 2002 and the well suspended pending assessment of further utility. CP AI had been considering sidetracking the well, but based on the sundry application that does not appear to be the current option. CP AI is planning an ambitious set of operations for the well. fu particular it appears that CP AI has concerns with the cement surrounding the 7" casing and plans to attempt a cireulating squeeze or failing that a conventional squeeze to provide isolation. They are basing these plans on the original cementing reports as well as a bond log run in 1970. Aceording to the CP AI engineer, he has plans to run a new bond log however only after he has perforated the casing and attempted to squeeze. It is my opinion that it is unlikely that CP AI will be able to successfully complete all the tasks planned and that the wellbore construction following this work will have difficulty meeting the integrity requirements for a disposal well. CP AI is the owner of the well and has advanced a workover/completion proposal. It is their belief that they can accomplish the tasks proposed. I recommend approving their proposal, however a statement should be added to transmittal letter reminding CP AI that the well will still have to meet the integrity requirements of20 AAC 25.252. ~~ Tom Maunder, PE Sf. Petroleum Engineer PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 A. Worthington Phone (907) 265-6802 Fax: (907) 265-6224 October 22, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations NCIU A- 11 (69-89 / 302-236) Dear Commissioner: 'Phillips Alaska, Inc. submits the attached Well Completion Report for the recent P&A operations on the Tyonek well NCIU A-11. If there are any questions, please contact me at 907-265-6802. Sincerely, A. Worthington Wells Engineer Phillips Alaska Inc. AW/skad WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r--I Gas r'-I Suspended I'~ Abandoned I--1 Service r-] 2. 'Name of Operator 7. Permit Number ConocoPhillips Alaska, Inc. 69-89 / 302-236 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-883-20031-00 4. Location of well at surface 9. Unit or Lease Name 1301' FNL, 1020' FWL, Sec. 6, T11N, R9W, SM F r,~ ~T[0~ ...... '-,-, North Cook Inlet Unit At Top Producing Interval 1 ~,.~T~ ~! ~~' i ~ 10. Well Number 645' FSL, 937' FWL, Sec. 31, T12N, R9W, SM A-11 AtTotal Depth .t~,~. ___ ~ ll. FieldandPool 1773' FNL.,~927' FWL, Sec. 31, T12N, R9W, SM ~ .... . .. Cook Inlet Field 5. Elevation in f~et (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Beluga Pool RKB 116' feetI ADL 17589 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions August 24, 1969 October 13, 1969 May 3, 1970 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 8212' MD / 6297' TVD 4923' MD YES r-] No []'IWLRSV @ 298' 22. Type Electric or Other Logs Run lES, FDC, SNP & CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 30" Surface 380' Driven 16" 65# H-40 Surface 621' 22" 1605 sx Class G 10-3/4" 40.5#, 45.5# J-55 Surface 2745' 15" 1735 sx Class G ,,,, 7" 23# & 26# J-55 Surface 8003' 9-5/8" 1231 sx Class G bridge plug @ 4923', cement retainer set at 4065' 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 333' & 4083' 4083', 4182', 4617', 4937', 3.5" 6498' 5211 ', 5726', 6115' all perfs P&A'd 126. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 3965' - 4923' Class G cement plug 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) not applicable P&A Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I N/A Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press, psi 24-Hour Rate > , , 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. ~ 30. ~, " GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. N/A , RECEIVED OCT 2 9 2002 Alaska Oil,& Gas Cons. Commissior~ Anchorage 31. LIST OF ATTACHMENTS Summary of Daily Operations 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Aras Worthington 265-6802 Signed ~~ Title Wells Enoineer Date ~/~,/~ ' Prepared by Sharon AIIsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". FOrm 10-407 Date Comment NCI A-11 Event History 10102/02 10/03/02 10/04/02 10/07/02 10/09/02 MADE VENTURI JUNK BASKET RUN, NO RECOVERY. RAN 2.3" HALLEY MILL TO BRIDGE PLUG @ 4923' CTM - MILLED FOR 6 HOURS - POOH MILL SEVERELY WORN - ADD 2.5" CEMENT RETAINER AND SE'I-rING TOOL TO STRING AND RIH TO 4623' CTM (MID JOINT BELOW PACKER) SET CEMENT RETAINER. STAB INTO RETAINER WITH STINGER, PUMP 13.5 BBLS CEMENT BELOW RETAINER, LAY 0.5 BBLS CEMENT ON TOP OF RETAINER. PULL UP TO 4500' CTM AND DISPLACE COIL AND WELL WITH SEAWATER. CIRCULATING SW AT REPORT TIME. CIRCULATE 3 BOTTOMS UP TO ENSURE CEMENT IS CLEARED FROM WELLBORE FOLLOWING FIRST CEMENT STAGE - RIG DOWN CTU - RIG UP SL TO SHIFT SLEEVE OPEN @ 4318' MD - RIG DOWN SL - RIG UP CT - MAKE DEPT CORRELATION RUN - PUMP 10 BBLS SEAWATER INTO FORMATION AT 1 BPM AND 700 PSI - A'I-I'EMPT TO SET 3.5" RETAINER @ 4113' RKB - RETAINER DID NOT SET AND IT WAS LEFT DOWNHOLE - PUMP 7.5 BBLS SEAWATER INTO FORMATION AT 1 BPM AND 600 PSI - SET 4- 1/2" RETAINER @ 4065' RKB. PUMP CEMENT SQUEEZE THROUGH RETAINER. PUMPED 15 BBLS BELOW RETAINER, SAW NO PRESSURE INCREASE, STUNG OUT AND LAYED IN 5 BBLS ABOVE RETAINER FOR HESITATION SQUEEZE (RETAINER IN FLAPPER VALVE TYPE THAT ALLOWS PUMPING DOWN THROUGH). WAITED ON CEMENT 45 MINUTES, PERFORMED FIRST SQUEEZE PUMP IN, 1.5 BBLS, SAW WELLHEAD PRESSURE INCREASE TO 500 PSI, SD, PRESSURE BLED SLOWLY TO 0 PSI. IN SECOND HESITATION STEP AT REPORT TIME. COMPLETED HESITATION SQUEEZE BELOW RETAINER AT 4050' CTM. LEFT 0.5 BBLS CEMENT ON TOP OF RETAINER. FLUSHED COIL AND WELLBORE WITH 3+ BOTTOMS UP SEAWATER (160 BBLS) TO GET CLEAN RETURNS TO SURFACE. POOH, FREEZE PROTECTED WELL WITH 500' DIESEL CAP. P&A COMPLETE, WILL PT AFTER CEMENT CURES. PRESSURE TUBING FROM 0 PSI --> 1975 PSI WITH 40 GAL 60/40 GLYCOL. LOST 25 PSI IN 30 MIN, GOOD TEST. BLED TO ZERO PSI. PRE-STATE WITNESSED PRESSURE TEST COMPLETE. TAG CEMENT TOP AT 3965', EST 100' OF CEMENT ABOVE RETAINER. Page I of I 10/16/2002 Re: NGIU A-11 Revised P&A Procedure Subject: Re: NCIU A.11 Revised P&A Procedure Date: Wed, 02 Oct 2002 13:57:03 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Aras Worthington <ajworth@ppco.com> CC: John C Braden <jbraden(~ppco.com>, Brian Seitz <bseitz@ppco.com>, Paul M~:,7olini <pmazzol(~ppco.com>, Scott D Reynolds <sreynol2@ppco.com> Aras et al, I have looked at the proposed change in the abandonment of the subject well. You have indicated that it has proven difrmult to mill up the BP at 4966' and 2 days has be expended thus far. You seek to halt further milling operations and commence plugging the well at the BP. 20 AAC 25.112 (c) (C) allows plugging above junk... "if the objectives of this subsection are met." 20/aac 25.112 (c) (E) provides for plugging using a BP and cement... "if the perforations are isolated from the open hole below." Based on review of the wellbore condition and the cited sections of the regulations, your proposal to change the abandonment procedure and conduct plugging operations without removing the BP is approved. Good luck with the operations. Please call with any questions. Tom Maunder, PE 'AOGCC Aras Worthington wrote: > Tom, > Attached are a revised P&A Procedure and a rough well diagram showing the > state of the well after the proposed P&A as requested. > > Thanks foryour help, > Aras (See attached file: NCIU A- 11 Intended P&A. doc)(See attached file: NCIU A-11 Proposed P&A Diagram. xls) Name: NCIU A-11 Intended P&A. doc NCIU A-11 Intended P&A. doc Type: WINWORD File (application/msword) Encoding: base64 Name: NCIU A- 11 Proposed P&A Diagram. xls NCIU A.11 Proposed P&A Diagram. xls Type: EXCEL File (application/msexcel) Encoding: base64 Tom Maunder <tom_maunder@ad~in.state.ak. us> sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission I of 2 1012/2002 1:57 PM Re: NC.tU A-11 Revised P&A Procedure Subject: Re: NCIU A-11 Revised P&A Procedure Date: Wed, 2 Oct 2002 13:17:21 -0800 From: "Aras Worthington" <ajworth~ppco.~m> To: Tom Maunder <tom_maunder@admin.state.ak.us> Tom, 1 of 2 You are correct; the intent was to clean out to the B.P. & mill it up. We are cleaned-out to it and have been milling with no success_for two solid days now. ~? ~ ~.,.(~ % ~ cc~v~'~ ~'~'~% ,..~.3c~rk. Aras Tom Maunder <tom_maunder@admin.state.ak.us> cc:T°: Aras Worthington/PPCO~Phillips Subj.: Re: NCIU A-11 Re~ P~ Pro~dure I have not pulled the file on this wee bu~uld ~ou refresh how me BP gm in there.~ cleanHad it ~n pla~ ~me time ago?? As I remember, the intent was out the sand on top of the BP and ~en drill it out. Is that corral? Thanks. AmS Wo~hington wrote: > A~ached am a mvis~ P~ Pr~edum and a ~ugh ~11 diagram show~ > ofthe we//a er e pm sed > ~anks f~your help, > (~e ~.ch~ file: NCIU A-11 Intended P~.d~)(~e a,ached file: NCIU .............................................................. NCIU A-11 Intended P&A.doc Type; WINWORD File (application/msword) Encoding: base64 Name: NCIU A- 11 Proposed P&A 10/2/2002 1:30 PM , Re: NC~ A-11 Revised P&A Procedure Diagram.xls > NCIU A-11 Proposed P&A Diagram. xls (application/m sexcel) > Encoding: base64 (See attached file: tom_rnaunder.vcf) Type: EXCEL File Tom Maunder <tom maunder@admin.state.ak.us> sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 10/2/2002 1:30 PM NCIU A-11 Intended P&A Procedure for rig Sidetrack Objective: Permanem Plug and Abandonment of aH zones that are currently perforated for rig sidetrack next Spring. Intended Procedure: 1. Clean-out sand to top of CIBP ~ 4966'. 2. Shi~ all sliding sleeves above CIBP open. 3. Set Cement Retainer near packer ~ 4617'. 4. Pu.mp cemem through CT & cement retainer to P&A the wellbore below. Lay 10' of cement on top of retainer. 5. Set Cemem Retainer in packer ~ 4083'. 6. Pump cement through CT & cement retainer to P&A perfs below. Lay 10' of cement on top of retainer. 7. Tag TOC with sliekline & Pressure-Test to 2000 psi WHP. Note: This procedure represents a deviation from the original submitted procedure due to extreme difficulties in milling the CIBP ~ 4966'. Four milling runs were made on the C1BP and several mills were destroyed attempting to mill the CIBP. The CIBP is now considered the "top ofjunk' in the wellbore. NCIU A-Il Proposed P&A ?erfs: 4225'- 4307' Per~: 4657'-4867' Per~: 4977'-5137' Per~: 5248'-5498' Perfs: 5845'- 5947' Per~: 6182'-6464' 2745' 10 3/4" Packer Packer 4182' Sliding Sleeve ~ 4318' Packer 4617' Sliding Sleeve ~ 4895' Packer 4937' casing 4083' Proposed Cement Retainer ~ 4083' Grey Denotes Cement Q~ CIBP 4966' Sliding Sleeve @ 5171' Packer 5211' Sliding Sleeve ~ 5536' Packer 5726' Sliding Sleeve ~ 6015' Packer 6115' Proposed Cement Retainer @ 4617' Tubing 4 1/2" to 6083' 3 1/2" to 6498' Per~: 7126'-7277' CIBP 7125' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor, ~j/'~ DATE: Commissioner Tom Maunder, /~_~ P. I. Supervisor ~,O1~ 5-~:~'D THRU: October 11, 2002 FROM: John Spaulding, SUBJECT: Petroleum Inspector Plug 'and Abandonments PAl Tyonek Platform Wells Non Confidential October 11,, ~.002: I traveled to PAl's Tyonek platform to witness the plug and abandonments of the bottom hole locations in preparation for eventual sidetracking and workovers of the following wells. In previous conversations PAl's rep, Jack Kralik asked how much presSure I wanted to see on the well upon my arrival, I requested that 500psi or at a mina positive pressure be displayed. All well were in the near area of 500psi. · ~A~lOWas pressured from 500 psi to 1150 psi and held for 30 .min. with no bleed down. The well was then de pressured to 0 psi and observed for 15 min. with no build up. A"~'~'l:'was pressure(~ up from 500 psi to 1100 psi and held for 30 min with no.bleed down. The well was then de pressured to 0 psi and observed for 15 min. with no build up. ~' was pressurecl up from 420 psi to 2200 psi and held for 30 min. with no bleed down. The well was then de pressured to 0 psi and observed for 15 min. with no build up. ~2was pressured up from 500 psi to .2400 psi and held for 30 min. with no bleed down. The well was then de pressured to o psi and observed for 15 min. with no build up. SUMMARy: twitnessed 4'.suc. ~ssful plug .and abandonment, pressure tests. Att~.,chments: None P&A's Tyonek Plat 10-11-02jS.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_X Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _X Time extension _ Stimulate _ Change approved program _ Pull tubing _ Vadance _ Perforate _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 · 4. Location of well at surface ~ ,~ ~ 1301' FNL, 1020' FWL, Sec. 6, T11N, R9W, SM At top of productive interval 645' FSL, 937' FWL, Sec. 31, T12N, R9W, SM At effective depth At total depth 1773' FNL, 928' FWL, Sec. 31, T12N, R9W, SM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service__ 6. Datum elevation (DF or KB feet) RKB 116 feet 7. Unit or Property name North Cook Inlet Unit 8. Well number A-11 9. Permit numbxe~ / approval number 69-89 10. APl number 50-883-20031 11. Field / Pool Cook Inlet/Beluga 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing Structural Conductor Surface Production measured true vertical Length 8212 feet Plugs (measured) bridge plug @ 7125' 6297 feet ~ 7958 feet Junk (measured) 6123 feet Size Cemented Measured Depth 30" Driven 380' 16" 605 sx Class G 621' 10-3/4" 735 sx Class G 2745' 7" 1231 sx Class G 8003' True vertical Depth 380' 621' 2393' 6154' Perforation depth: measured 4254' - 7277' true vertical 3570' - 5662' Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 4.5", 12.6#, J-55 Mod BT&C @ 333', 4.5", 12.75#, J-55 Mod-EUE @ 4083', 3.5", 9.2#, N-80 BT&C @ 6498' Otis "VST" pkr @ 4083' MD, Otis "RH" @ 4182', Baker F-1 pkr @ 4617', 4937', 5211', 5726' and 6115' Halliburton Series "10" Type "FXE" WLRSV @ 298' 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 15. Status of well classification as: 14. Estimated date for commencing operation August 1, 2002 16. If proposal was verbally approved Name of approver Date approved Oil _X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true end__the best of my knowledge. Questions? Call Aras Worthington (907)265-6802 Signed ~.~ ~'//'~"~ Title: Wells Engineer Date ~:f/~"~,//~ Aras Worthington ~" w w .~ Prepared by Sharon AIIsup-Drake 263-4612 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so represen, tative may witness '~I~,~ t'~\~,~w,.~,.~'~t~::':~-~'~ Approval no. Plug integrity _~ BOP Test~ Location clearancd' ~ -c~ Z '*~ 5~ Mechanical Integrity Test_ ~ Subse~nt form req-'~ired 10- '~t {~ ~ -- Onglnal S~gne(I By ~ ,, Approved by order of the Commission ~;ilm~¥ Oechsli Taylor' Commissioner Date ORIgiNAL Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE NCIU A-Il Intended P&A Procedure for rig Sidetrack Objective: Permanent Plug and Abandonment of all zones that are currently perforated for rig sidetrack next Spring. Intended Procedure: 1. Clean-out sand to top of CIBP @.7125'. X2,-,~\,~,~ ~,\,~%~ 2. Shift all sliding sleeves open. 3. Set Cement Retainer near packer @ 5726'. 4. Pump cement through CT & cement retainer to P&A all perfs below. Lay 10' of cement on top of retainer. ~ ~k,~ '~ fo -~'~ ~ ~,'~ ~\ * ~\ 5. Set Cement Retainer near packer @ 4617'. 6. Pump cement through CT & cement retainer to P&A all perfs below. Lay 10', ~ XgXo \ of cement on top of retainer. ~-~,(o'qq~' 3 ~b\5 Set Cement Retainer in packer @ 4083'. Pump cement through CT & cement retainer to P&A all perfs below. Lay 10' of cement on top of retainer. ~ ~ '~ ~,~ ~6b\ ~ Tag TOC with slickline & Pressure-Test to 2000 psi WHP. . 9, NCIU A-11 WELL COMPLETION DIAGRAM FMC OCT 380 4 ~/2" 8rd X 4 1/~" BT&C WATER D]i~TI-I: 120' Total Depth 8212' 621 2745 Howco 'VST' packer @ 4083' Cook Inlet Sands Otis "RH' packer @ 4182' 4225-26 (sqz) 4254 - 4284 stray 4306-07 (sqz) Packer @ 4617 4624-25 (sqz) 4657-4702C1-1.0 4715-4805CI-2.0 4816-4846CI-3.0 4852- 4867 CI-3.1 Packer @ 4937 4977 - 4987 01-5.0 5039 - 5089 CI-5.1&6.0 5107 - 5137 CI-6.2 Packer@5211 5248-5262CI-8.0 5280 - 5285 CI-8.2 5289- 5307 CI-8.2 5358- 5368 CI-9.0 5399- 5419 C1-10.0 5450- 5460 C1-11.0 5468- 5498 C1-11.0 5538-39 (sqz) Packer@5726 luga Sands 5845-5859 b-7 5871 -5877 b-8 5930- 5950 c-1 5962- 5974 c-2 Packer@6115 6182-6197 d-3 6212-6218 d-3.5 6246-6266 d-4 6272-6278 d-5 7176 -7196 i-7 7267-7277 j-2 7" @ 8OO3' 1540 3350 4660 4080 4660 66OO 4730 4730 PRODUCTION TUBING OCT 6" 3M 41/2" ~ x 4 3/2" BT&C 4 ~J2" 12.6 ]~/fl 3-55 ModBT&C Tub~g 4.5 ' $C~'VLandi~g Niplie;Fall~d ~-"V l~/5/Ol 4 1/2" 12.6 lb/ff 1-55 ModBT&C Tubin~ X-Over 4 1/2" ModBUB 8rd x 4 1/2" ModBT&C 4 1/2" 12.6 ib/ff ~-55 Mod ]~0=E 8~d Tubing X-Ove~ 4 1/2" BT&C x 4 1/2" ( 1(~ overall) Otis "VSR" Hy&~ulic Set RetdrwblcPacker 3 1/2" 9.2 lb/ff 1-55 Buttress Tubing; & X-Over 3 1/2" 9.2 lb/ff ~-55 Butlzess Tubin~ & X-Over 3 1/2" 9.2 ~b/ff 1-55 Buaress Tubing & X-Over Set Rettievab]ePacker 3 I/2" X-Over. Otis 3 1/2" 'XA" $1kllng Sleeve- closed 12/5/01 3 1/2" 9.2 lb/fl N-80 Buttress Tubing & X-Ov~ Baker Seal Unit Baker Model "F' Permanent ~'acker 3 1/2" 9.2 ]b/ff Tub[ns, Bhst/oint~, X-Ova. Ofiz 2 7/8" "XA" Slidi~ Sleeve 3 1/2" 9.21b/fl N-80 Buttress Tubln[~ &X-Ov~ Baker SealUnit Baker Model '~F' Perra~ent Packer 1/2" 9.2 lb/fl X-Over. Otb 2 7/8" "XA" Slidln~ Sleeve 1/2" 9.2 lb/fl N-80 Buttress Tubing & X-Over Baker Seal Unit Baker Model "F' Peauanent Packer 31/2" 9.2 lb/fl Tubint, Bhstloints,X-Ov~. Otis 2 7~8" '9iA" Slldhtg Sleeve 9.2 ]b/ff N-80 Buttfc,~ Tubing & X-Over Baker Seal Unlt Baker Model "F' Permaaent Packer 3 1/2" X-Over. Otis 2 7/8" '9iA" Slidln~: Sleeve 3 1/2" 9,2 ro/fl N-80 Buttxess Tubing & X-Ov~ Baker Seal Unit Baker Model "F' Pexmanent Packex 3 1/2" 9.2 lb/fl Tubing, Bhst loints, X-Ove~. o~ -x~', Lana~ Nyp]e 3 1/2" 9.2 lb/fl N-80 Buttress Tubing & X-Over Wkel~e Re-l~-ttry Guide Notes - Well History 4/70 - Fi~t Production from Cook Inlet A, 1-3, 5-11 7/75 - CI A, 1-3, 5-11, Beluga (Add Beluga) 7/83 - Run 3 1/2 inch tubing with multiple packers and sliding sleeves 10/90 - Beluga well oniy 5/94 - Rmt 4-1/2 inch tubing, well not reperfor~ted due to multiple packers, Beluga well 6/93 - Top ofF'ill 6505' 1#95 - Top of Fill 6363' (Lower Sleeve coverM). 5/96 - Top of Fill 6366' (Lowe~ Sleeve covered). 1/97 - Open CI 1-3 Sleeve at 4917' 9/99 - Test 5.5 MlVICt~ & 13.5 BWPHr to fla~e 400 psi (ri. CI Md Beluga sleeves opea) ~0/99 - Could not get 2" gaugefing below 5987' 11/99 - Closed Upper CI sleeve, Test 300-350 BWPD from Beluga (to flare) 150 psi FYP 1/00 - Tag fill at 5843', bail soft to hard sand. Found indications Lower Cook Inlet sleeve open, closed all sleeves. Open Lower Cook Inlet Sleeve at 5536', no flow. FL 1800', pressure up with gas. Open Upper Cook Inlet sleeve, well would not flow. Check for fill TD 5101 ', ball to 5106'. Nov 11,2001 - Pull SCSSV Nov 28, 2001 - FCO 5497' -5910', SL Tag 5720' RKB Nov 29, 2001 - Calpler log, found 3 holes @ 4988'-4989' I~KB Dec 1-5, 2001 - Set 2.187" Bridge Plug @ 4966. Confirm XA sleeves @ 4896 & 4318' open, Set SCSSV. Attempt to flow well; well died. 12/5/01 - pulled SCSSV. Close 3.5' XA sleeve @ 4318'. Tag fine sand @ 4318' Updatedby: ]mO 1/6/02 [ . PBTD: 7,125' Is~p~. ]Tog Wt 4 1/2 "- i2.6 & 12.75 lb/fi: 3 1/2" 9.2 lb/ff w~ North Cook Inlet Unit No. A-11 I Aug. 05,1994 Location: T~tonak Phfform, Cook Inlet, Alaska l~ield: North Cook Inlet Unit PRD STATE OF ALASKA AL . , ~.\ OIL AND GAS CONSERVATION COMMIS ,; REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown __ Pull Tubing X 2. Name of Operator: Phillips Petroleum Co. 3. Address: P.O. Box 1967 Houston, Texas 77251-1967 Stimulate Alter Casing Plugging __ Repair Well 5. Type of Well Development X Exploratory Stratigraphic Service 4. Location of well at surface: Leg 2, Slot 7 PPCo. Tyonek Platform Perforate Other 6. Datum elevation (DF or RKB) RKB 116 7. Unit or Property Name North Cook Inlet Unit 8. Well Number 1,301' FNL & 1,020' FWL At top of productive interval: 645' FSL & 937' FWL At effective depth: 645' FSL & 937' FWL At total depth: 8,212' MD; 1,773' FNL & 928' FWL 12. Present well condition summary: Total Depth: Sec 6-T11N-R9W 4,254' MD; 3,570' TVD Sec 31-T12N-R9W 4,254' MD; 3,570' TVD Sec 31-T12N-R9W 6,297' TVD Sec 31-T12N-R9W measured 8,212 feet Plugs (measured) Feet A-II 9. Permit Number / Approval Number 69-89 10. APl Number 50-883-20031 11. Field / Pool Cook Inlet / Beluga true vertical 6,297 feet PBTD 7,125' Effective Depth: measured true vertical 4,254 feet Junk (measured) 3,570 feet ORIGINAL Casing: Structural Conductor Surface Intermediate Production Liner Length Size Cemented Measured Depth True Vertical Depth 30" Driven 380 380 16" 605 sx 621' 621' 10 3/4" 735 sx 2,745' 2,393' 7" 1,231 sx 8,003' 6,154' Perforation Depth: measured 4,254' - 7,277' true vertical 3,570' - 5,662' Tubing (size, grade and measured depth) Packers and SSSV ( type and measured depth) 13. Stimulation or cement squeeze summary: Intervals treated (measured): 4 1/2" 12.60 Ib/ft J-55 Mod BT&C Tubing Surface to 333'. 4 1/2" 12.75 Ib/ft J-55 Mod EUE 8rd Tubing 333' to 4,083'. 3 1/2" 9.2 Ib/ft N-80 BT&C Tubing 4,083' to 6,498'. Halliburton "VST" Retrievable Packer @ 4,083'; Otis "RH" @ 4,182; Baker F-1 permanent packers @ 4,617', 4,937', 5,211', 5,726' and 6,115'. Halliburton Series "10" Type "FXE" WLRSV @ 297.89'. Treatment description including volumes used and final pressure: RE.dElVED jAN 2 7 1995 .Oil & Gas Cons. Commission 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Prior to well operation: 0 7800 Subsequent to operation Water-Bbl Casing Pressure Tubing Pressure 0.52 20 885 0 4400 0.38 315 924 05/21/94 07/07/94 15. Attachments: Copies of Logs and Surveys Run__ Daily Report of Well Operations 16. Status of Well Classification as: X Oil Gas X Suspended Service 15. I hereby certify that the foregoing is true and correct to the best of my knowledge: Form 10-404 Rev. 06/15/88 Date 19-Jan-95, SUBMIT IN DUPLICATE PHILLIPS PETROLE~~'~ DAILY REPORT SUMMARY WELL:North Cook Inlet Unit No. FIELD:North Cook Inlet CNTY/STATE:TYONEK OFFSHORE/ALASKA PAGE:i DATE DEPTH RPT NO ~ A-11 RIG:Pool Arctic Alaska/Pool Arctic Alaska AFE#:P-V188 AUTH COST:$552,000 OPERAT ZONS SUI414ARY DAILY COST CUM COST EVENT TYPE:Workover 05/Z1/94 7,125 1 8.5 05/22/94 7,125 Z 8.5 05/?.3/94 7,125 3 8.5 0~/24/94 7,125 4 8.5 NOVE RIG OVER NCZU A'11. KILL 1,,'ELL. CLOSE SCSSV, SET BPV. ND TREE, gU BOPS AT REPORT TI#E. TEST BOPS,14ADE THREE ATEMPS TO PULL SCSSV ON LAST TRY COULD NC~SHEAR OFF, PICKED UP STACK NADE UP CONTROL LINE NU STACK SCSSV klCXJLD NOT OPEN, MORKED gIRE LINE, SCSSV CANE FREE POH 14ADE CUT AT 4160 TBG gOULD CIRC BUT NOT CO#E FREE. NADE CUT #2 AT 41~. TBG FREE CIRCULATE BTN UP. RIH g/ 6"GUAGE RING TO 4120. RIH glTH PACK OFF AND OTIS VSR PKR. SET g4082' RUN AND LAND 4"1/2 TBG. TEST TO 1000 psi OK, NIPPLE DOUN BOPS, NIPPLE UP TREE AND TEST.RIG UP TEST LINES. $30,936 $30,936 $30,857 $61,793 $48,407 $110,200 $35,478 S145,'678 05/25/94 7,125 5 8.5 RIG UP TO JET A-11, PULL SCSSV RIG UP CT JET WELL A-11 IN ~ITH N2 t~ELL TESTED TO 11.6 14MCU RECOVERD 118 bbLs WATER RIG DOh'N CT, SET SCCSV. $132,836 $278,514 05/26/94 7,125 6 8.5 SET SCSSV IN LNDG NIPPLE AT 297 FT. POOH RD WL. LOAD OUT BOAT IN PREPARTION TO SKID RIG. ***FINAL REPORT*** RELEASE RIG AT 1100 HRS 5/25/94. PREPARE TO SKID TO NCIU A'8 $83,285 S361,798 DAYSUH.RP1 06/13/94 RECEIVED dAN 2 ? 1995, ~as!;a~.Oil ,& Gas Cons. ...... : ~ch0m,,,,~ SSSV CIBP ~ 7125 · . PBTD 7958' Total Depth 8212' 380 621 2745 Howco "VST" packet 4083' Ot~ *RH"packet @ 4182' 4225-26 (sqzl 4254-4284 S~ay 4306-07 (sqz) Packet ~ 4617 4024-25 (sqz) C~k In~t Sa~s 4657-4702 4715-4805 CV2 4816-4846 C1-3 4852-4867 a-3 Packet ~ 4937 4977-4987 CV5 5039-5089 C~-6 5107-5137 CV7 P~ck~ ~ 5211 5248-5262 cvs 5280-5285 cvs 5289-5307 5358-5368 a-9 5399-5419 CVlO 5450-5460 c~-11 5468-5498 evil 5538-39 {sqz) Packet @ 5726 Beluga Sands 5845-5859 5871-5877 5899- 5909 593O-595O 5962-5974 Packet @ 6115 6182 - 6197 8212 - 6218 6246- 6266 6272-6278 6449- 6464 7176-7196 7267- 7277 7" @ 8003' FINAL WELL C(: ?LETION DIAGRAM 8PV(~ke,T~,~,om FMC o~ ~g.~r.~e,Ty~) ~C 4 1~" 8~ X 4 112" BT&C ~m ~d: 8.5 lb/gal KCL Compi~ion ~d ~h 30 % M~ol [~L: 116.~ TOC: 3~' ~r CBL ~ ~2/13/~ WA~ D~: 120 Production 26 lb/ft 23 lb/ft 26 lb/ft 12.60 lb/ft 12.75 lb/ft 9.2 lb/ft PRODUCTION TUBING STRING Elevation FMC / OCT 6' 3M 4 1/2' 8rd x 4 1/2" BT&C Tu 4 1/2" 12.6 lb/ft J-55 Mod BT&C Halliburton 4 1/2" SCSSV 4 1/2" 12.6 lb/ft 1-55 Mod BT&C Tubing X-Over 4 1/2" Mod EUE 8rd x 4 1/2" Mod BT ;4 1/2" 12.6 lb/ft 1-55 Mod EUE 8rd Tubing X-Over 4 1/2' BT&C x 4 1/2' EUE Straight Slot Locator and Seal Units ( 10' overall) Otis 'VSR' Hydraulic Set Retrievable Packer Tubing Adapter and X-Over 3 1/2' 9.2 lb/ft J-55 Buo, xess Tubing & X-Over Otis "X" Landing Nipple 3 1/2' 9.2 lbll~ $-55 Buttress Tubin[g & X-Over Pressure Pack-Off Overshot 3 1/2' 9.2 lb/R $-55 Buttre~ Tubing & X-Over Otis "RH" Hydraulic Set Retrievable Packer 3 1/2' 9.2 lb/ft Tubing, Blast Joints, X-Over. Otis 4 1/2' 'XA' Sliding Sleeve 3 1/2' 9.2 lb/ft N-80 Buttre~ Tubing & X-Over Baker Seal Unit Baker Model "F' Permanent Packer 3 1/2' 9.2 Ib/ft Tubing, Blast Joints, X-OVer. Otis 4 1/2' "XA' Slidin8 Sleeve 3 1/2' 9.2 lb/ft N-80 Buttress Tubi~ Baker Seal Unit Baker Model "F" Permanent Packer 3 1/2' 9.2 lb/ft Tubing, Blast Joints, X-Over. Offs 4 1/2" 'XA" Slidin8 Sleeve 3 1/2" 9.2 lb/ft N-80 Buttress Tubing & X-OVer Baker Seal Unit Baker Model 'F" Permanent Packer 3 1/2" 9.2 lb/ft Tubing, Blast Joint~, X-Over. Otis 4 1/2' 'XA' Sliding Sleeve 3 1/2' 9.2 lb/ft N-80 Buttress Tubing & X-Over Baker Seal Unit Baker Model 'F' Permanent Packer 3 1/2' 9.2 lb/ft Tubing, Blast Joints, X-OVer. Otis 4 1/2' 'XA' Sliding Sleeve 3 1/2' 9.2 lb/ff N-80 Buttress Tubing & X-OVer Baker Seal Unit Baker Model "F' Permanent Packer 3 1/2' 9.2 lb/ft Tubing, Blast Joints, X-Over. Otis "XN' Landing Nipple 3 1/2' 9.2 lb/ft N-80 Buttress Tubing & X-OVer Wireline Re-Entry Guide End of Tubing PRODUCTION PERFORATION INTERVALS COOK INLET SANDS BELUGA SANDS "Upper" ' 4225 - 42 (sqz'd) 5845 - 5859 Stray 4254 - 4284 5871 - 5877 ' 4306 - 43 (sqz'd) 5899 - 5909 C1-1 4657 - 4702 5930 - 5950 Cl-2 4715 - 4805 "Middle" CI-3 4816 - 4846 5962 - 5974 4852 - 4867 6182 - 6197 CI-5 4977 - 4987 6212 - 6218 CI-6 5039 - 5069 6246 - 6266 CI-7 5107 - 5137 6272 - 6278 CI-8 5248- 5262 6449 - 6464 5280 - 5285 "Lower" (Shut Off Below CIBP) 5289 - 5307 7176 - 7196 CI-9 5358- 5368 7267 - 7277 C1-10 5399 - 5419 C1-11 5450 - 5460 5468- 5498 ' 5538 - 55 (sqz'd) PBTD: 7,125' Isupv: ITb~ Wt: 4 1/2 ' - 12.6 & 12.75 lb/R: 3 1/2' 9.2 Ib/ft WeU: North Cook Inlet Unit No. A-1 1 I Aug. 05. 1994 Location: U Cook Inlet, Alaska Field: Cook Inlet Unit PRD ALAS¢,,,-~ OIL AND GAS CONSERVATION COM~r,,.-.SION APPL,CAT,ON FOR SUNDRY A .OV^ S Abandon Suspend ~: Operation Shutdown [ ~ Re-enter suspended well ~ Alter casing Plugging ~ Stimulate ;~ Pull tubing . Amend order [. Perforate [; Other 1. Type of Request: Time extension Change approved program Name of Operator Phillips Petroleum Company Address 6330 W. Loop South, Bellaire, TX 77401 4. Location of well at surface Platform A, Leg 2, Slot 7 1301 FNL, 1020 YWL Sec. 6 T11N-RgW At top of productive interval 645' FSL, 937' FWL Sec 31-T12N-R9W @4254' lyE), 3570' TVD At effectivedepth 645' FSL, 937' FWL Sec 31-T12N-RgW @4254' lv~, 3570' TVD At totaldepth 1773' FNg, 928' FW"L Sec 31-T12N-R9W 11."~resent welJ' condition summary Total depth: measured 8212 feet Plugs (measured) true vertical 6297 feet Effective depth: measured feet Junk (measured) true vertical feet 5. Datum elevation (DF or KB) 116 6. Unit or Property name North Cook Inlet 7. Well number A-11 8. Permit number 9. APl number 50--883-2OO31 10. Pool Cook Inlet/Beluga 7125' Casing Length Size Cemented Structural 323 30" Driven Conductor 584 16" 605 Sacks Surface 2708 10-3/4" 735 Sacks Intermediate 7966 7" 1231 Sacks Production Liner Perforation depth: measured 4254'-7277' Measured depth 36O 621 2745 8003 True Vertical depth 36O 621 2393 6154 RECEIVED NOV 1 5 199, true vertical 3570' -5.662 ' Alaska 0il & Gas Cons. Commission Anchorage Tubing (size, grade and measured depth) 4" 10.9 ppf K-55 @68', 3-1/2 9.2 ppf N-80 @2342', 3-1/2" 9.2 ppf J-55 @4612', 3-1/2" 9.2 ppf N-80 @6498' Packers and $$$¥ (type and measured depth) Otis RH pkr. @4181', Baker F pkrs. @4617', 4937', 12.Attachments Description summary of proposal ~-~ Detailed operations program [~ BOP sketch ~ 13. Estimated date for commencing operation November 25. 1993 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the,foregoin, g.is true and correct to the best of mF'knowledge Signed B. C. Cill ~. TitleD&p Engineering Manager Commission Use Only Conditions of approval Notify commissions/representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI -For,,,.,. Io- o'--t Date Original Signed By Approved by David W. Johnston Form 10-403 Rev 12-1-85 Commissioner Approved Copy Returned by order of ._(' !.- the commission Date Submit ~n triplicate WORKOVER OBJECTIVES: A restriction in the tubing above the SCSSV has made servicing the SCSSV difficult. Efforts to alleviate this problem by replacing the valve have been unsuccessful confirming that the restriction is in the tubing. This restriction has resulted in the safety valve sticking on various occassions. While it has always been possible to jar the valve loose and continue with the desired operation the problem with the valve is indicative of a problem that needs to be repaired. This workover will cut and pull the tubing above the top packer in the well so that the tubing and the safety valve nipple can be replaced. WELL HISTORY AND CURRENT CONDITION: The well was drilled in 1969 and completed as a Cook Inlet formation monitoring well in 1970. The well was worked over ih 1975 during which time the Beluga sands were perforated and the well completed as a commingled Cook Inlet and Beluga producer. The top joint of 7" casing in the well collapsed during the 1975 workover. The joint was successfully backed off and replaced with a new joint of casing. The well began producing a significant volume of water in 1982. A workover was performed in 1983 to identify and isolate the water producing interval. Seven drillstems tests were conducted in an unsuccessful attempt to locate the source of the water. Although the water source was not identified a bridge plug was set to shut off the Lower Beluga and the well recompleted with 5 permanent packers and a retrievable packer. The 5 permanent packers were set on wireline, then the retrievable packer run with a long tailpipe including seals spaced out to seal in each of the permanent packers. A schematic drawing and detailed description of the current completion is attached. This workover apparently shut off the water production. The well is equipped with an FMC-OCT wellhead and X-mas tree. A drawing of the tree is attached. Back pressure valves, test plugs, wear bushings and any required wellhead service will be supplied by FMC. Eleven of the 14 Cook Inlet sands and 10 intervals in the Upper and Middle Beluga are perforated. In 1990 all of the sliding sleeves in the well were closed to permit evaluation of the Middle Beluga formation. The Middle Beluga is the only interval currently open to produce. The well is currently producing 10 MMCFD and has shut in pressure of approximately 1110 psi. R£C£1'V[D At~,SV,~ u~ & Gas Cons. ~omm~sston Anchorage PROCEDURE This well is a category three well. & variance to Phillips Well Control Manual has been requested to permit nippling down the X-mas tree with 1 tested barrier and 2 untested barriers. lo Fill tubing with workover fluid as needed to kill well. See attached workover fluid program. · Bleed off pressure from tubing x casing annulus and fill annulus. 3. Monitor well for at least 30 minutes. 4. Close SCSSV. 5. Install BPV 6. ND tree. Note: Tree should be sent to FMC for inspection, repair, and addition of a second master valve. · NU and test riser and BOP to 3000 psi. See the well control section of this procedure for additional details concerning BOP tests and well control requirements. 8. Retrieve BPV and SCSSV. · Screw DP into tubing hanger. Pick up on DP to lift tubing hanger off seat, limit pull to 45000 lbs. (approximately 10000 lbs. over string weight above RH packer) to minimize risk of releasing the RH packer. 10. RU Western Atlas electric line unit and lubricator 11. RIH w/ CCL and chemical cutter. Run a CCL strip to identify the RH packer set at 4182' then cut tubing at 4162' This cut point was selected so that the XO sleeve at 4147' will be recovered without disturbing the RH packer and its tailpipe. The tailpipe includes the 5 seal assemblies that are stabbed into the 5 permanent packers. 12. Establish circulation to verify tubing has been cut. Circulate at least one full hole volume before POOH. 13. Pick up on pipe, limit pull to 45000 lbs (approximately 10000 lbs. over string weight) to minimize risk of unseating RH packer if pipe has not been completely cut. If necessary rerun cutter to cut tubing. 14. POOH and LD tubing. Note: Tubing is to be checked for NORM contamination Note: A detailed description of the completion equipment presently in this well is attached. The tubing in the well includes 4" and 3 1/2" and other tools. Have handling tools available to cover all sizes of tubing in the well. 15. Inspect cut at end of tubing to determine if a trip should be made to dress off the tubing stub before running the overshot seal assembly. Dress off stub if required. 16. RIH w/ overshot seal assembly with OTIS VSR retrievable packer assembly on 3 1/2" drillpipe. Latch onto tubing stub with overshot assembly and pull 5000 lbs over string weight to insure overshot is latched and stub is properly aligned. 17. Pressure up to set VSR packer. 18. POOH Note: Leave drillpipe standing in the derrick if the rig is to be skidded to wellroom 3 to continue workovers. Lay down the drillpipe if the well is to be skidded to Sunfish 3 to begin drilling. 19. RIH w/ ratch latch, seal divider, 4 1/2" tubing and related tools per attached schematic. 20. Latch into packer with ratch latch. Pick up to shear seal divider. 21. RU wireline and make a gage ring run to insure pipe stub above RH packer is properly aligned with new completion. 22. Space out with pup joints as needed to land tubing hanger. 23. Reverse circulate to fill annulus w/ packer fluid mixture of 70% glycol 30% water containing 5 gallons Betz Enchem 1312 corrosion inhibitor. 24. Land tubing hanger 25. Install DHSV and BPV 26, ND BOP and NU X-mas tree 27. 28. 29. Retrieve BPV and DHSV. RU coiled tubing and jet well in. Turn well over to production. ~as ~ons. oommms%o~ Anchorage ~ell Control This well is a category 3 well, as defined in Phillips Completion Workover and Well Control Policy. For all operations two barriers, e.g. the BOP's, fluid column, etc. must be in place in order to conduct simultaneous operations. The BOP equipment is 10000 psi WP Class 4 as per Phillips Well Control manual. The bottom set of rams should be 3 1/2" pipe rams, the middle set will be blind rams and the top set should be variable rams. Although the BOP is rated to 10000 psi, the riser and the wellhead are rated to 3000 psi. The BOP and choke manifold should be stump tested to 3000 psi. The BOP should be tested to 3000 psi upon nipple up and to 1500 psi on a weekly basis. The Alaska Oil and Gas Conservation Commission (AOGCC) should be notified prior to conducting BOP tests. The notification to AOGCC should be made early enough for them to witness the test if they desire. Well control drills are to be conducted with each crew as per Phillips well control manual. Drills should be reported on the IADC daily drilling report and on Phillips Daily Drilling Report. This well produces from a series of very permeable sands. A small decrease in pressure at the perforations can result in very large flowrates. A detailed trip book comparing measured fill up requirements to the calculated requirements should be maintained for each trip. The cause for any discrepency between the actual and required fill up volume must be determined before continuing with the trip. MAINTAINING CONTROL OF THE WELL IS OF THE UPMOST IMPORTANCE, TRIP SPEED IS SECONDARY. There is a possibility that the partially depleted sands will not support a fluid column without addition of a bridging agent to the workover fluid. A premixed pill designed to bridge off the lower pressured zones should be maintained in one of the mud pits. If the well cannot be made to stand full, then well control can be maintained by constantly pumping workover fluid. Ail of the zones presently perforated in this well can be killed with water. As a precautionary measure, a line should be ran from the annulus valves on the tubing head to supply workover fluid, drillwater, or seawater. This line can be used to supply workover fluid as discussed above or as a last resort can be used to kill the well with drillwater or seawater. Pumping drillwater or seawater through the annulus valves should be considered only in an emergency situation as these fluids could result in formation damage. NOV 1 5 199~ A~gska O~l & Gas Cons. gommmslon Anchorage NClU A-11 RISER AND BOP ARRANGEMENT I I 6M ANNULAR PREVENTER 1OM VARIABLE BORE PIPE RAMS 1OM BLIND RAM8 DRILLING SPOOL 3 1/2' 1OM PIPE RAM$ RI$ER 13 6/8' 1OM X 13 6/8' {~M ADAPTER 13 6/8' SM X 16 3/4' 6M CLAMP RISER 16 3/4' 6M X 16 3/4' 6M I ADAPTER 16 3/4" 6M CLAMP X 9' 3M TUBING HEAD 9' 3M X 11' 3M North Cook Inlet Unit Wellhead Arrangement CURRENT 1. Hammer Union 2. 4' 3M Orbit Ball Valve 3. 4' 3M Studded Tee 4. 4' 3M FE Gate Valve with 'Fail Close' Pneumatic Actuator 5. 4' 3M Gate Valve 4' 3M x 8' 3M Studded Tubing Head Adapter, bored for Otis TSV Line 8' 3M x 10' 3M Tubing Head, equipped with OCT Type TC-1A-EN Tubing Hanger bored for Otis TSV Erie (4-1/2' EU 8rd Hanger Lift Thread) 8. 2' 3M FE Gate Valves 9. 10' 3M x 16' 3M Casing Spool 10. 16' 3M x 16' SOW Casing Head RECEIVED NOV 1 5 199,~ Alaska 011 & Gas Cons. Commission Anchorage Workover Fluid Program The base fluid for the workover is a 2% KCL brine. Fluid density will be 8.4 ppg. Fluid Properties: Weight: 8.4 ppg Total hardness: less than 100 ppm KCl concentration: 7 ppb For additional fluid loss control use pills of workover fluid containing 3 ppb Xanvis (XC polymer). The polymer should be hydrated and sheared properly to obtain the maximum low shear rheology. If additional fluid loss is required LCM pills of Litesal XCP pill will be used, The volume of the pill and the amount of bridgeing agent to be used will be determined based on the rate of loss. Saturate the system with LiteSal (borate salts) and add 2 - 3 ppb Liteplug fine to the circulating system. Then spot the LCM pill across the thief zone. Should additonal fluid loss control be needed for seepage control while working with the thief zones open, add 15 ppb LiteSal XCP and 5 ppb pH-6. This will viscosify the system to suspend additional bridging agent. Then add 5 - 10 ppb Liteplug if needed. RECEIVED NOV 1 5 1993 Alaska 011 & Gas Cons. Commission Anchorage ] L_. EXISTING CONDITION SCHEMATIC NCIU A- 11 MAGNIFIED TO SHOW AREA ABOVE PLANNED CUT _ SCSSV _ BPV(Make,Type,OD): RKB-.'.~.RILL DECK: 24.5' 'rbg. Hgr.(Make,Type): OCTTC-1A-EN RKB-THF: 38.9' Annulus Fluid: RKB-SL - 116 TOC: RKB-ML: 30' SURFACE 36O 16' SURFACE 621 65.01~ H-40 10 3/4' SURFACE 2745 45.50 J-55 7' SURFACE 77 23.00 J-55 8RD 4980 3270 281000 7' 77 6,991 23.00 J-55 BUTT 4980 3270 366000 7' 6,991 8,003 26.00 J-55 BUTT 5690 4330 415000 4' 37 68 10.90 J- 55 BUTF 7210 6590 169200 3 1/2' 68 2342 9.20 N-80 BUTT 11610 12120 207200 3 1/2' 2342 4612 9.20 J-55 BUTT 7980 7400 142500 3 1/2' 4612 6498 9.20 N-80 BUTT SC 11610 12120 207200 :::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::: ....... .::::::::::: .... 35.97 1.6 TUBING HANGER 37.57 30.44 4" 10.9 PPF J-55 BUTTRESS TUBING 8.476 4.000 68.01 0.4 X-OVER 4" BUTT BOX X 3 1/2" 8RD PIN 68.41 205.13 3 1/2" 9.2 PPF N-80 BUTTRESS TUBING 2.992 3.500 X-OVER 3 1/2" BUTT BOX X 3 1/2" 8RD PIN 273.54 4.19 OTIS SAFETY VALVE NIPPLE 2.760 X-OVER 3 1/2" 8RD BOX X 3 1/2" BUTT PIN 277.73 1526.93 3 1/2" 9.2 PPF N-80 BUTTRESS TUBING 2.992 3.500 1804.66 2342.48 3 1/2" 9.2 PPF J-55 BUTTRESS TUBING XO 4147.14 3.93 OTIS XO SMDING SLEEVE (CLOSED) 2.750 4151.07 30.12 3 1/2" 9.2 PPF J-55 BUTTRESS TUBING (1 J'r) 2.992 3.500 4181.19 1.13 X-OVER 3 1/2" BUTT BOX X 3 1/2" 8RD PIN · · 4182.32 4.52 OTIS TYPE RH RETRIEVABLE PACKER 2.900 6.000 4186.84 0.95 X-OVER 3 1/2" 8RD BOX X 3 1/2" BUTT PIN RECEIVED NOV 1 5 199~ Alaska O~l & Gas Cons. Commission Anchorage __l L_ PLANNED COMPLETION SCHEMATIC NCIU A-11 MAGNIFIED TO SHOW NEW COMPLETION ABOVE TUBING STUB _ SCSSV _ BPV(Make,Type,OD): RKB-DRILL DECK: 24.5' i Tbg.Hgr.(Make,Type): OCT TC-1A-EN RKB-THF: 38.9' Annulus Fluid: RKB-SL: 116 TOC: .RK~.-~M.L.!... 30, SURFACE 3601 16' SURFACE 6211 65.0e H-40 10 314' SURFACE 274~ 5.50 J-55 7' SURFACE 77~ 23.00 J-55 8RD 4980 3270 281000 7' 7'/ 6,991 23.00 J-55 BUTT 4980 3270 366000 7' 6,991 8,003 26.00 J-55 BUI-F 5690 4330 415000 4 1/2' 37 +/- 330' 12.60 J-55 BUTT 6620 5730 198000 4 1/2' +/- 330 416~ 12.75 J-55 EUE 8RD 6620 5730 198000 3 1/2' 4162 461E 9.20 J-55 BUTT 7980 7400 142500 3 1/2' 4612 6498' 9.20 N-80 Bun' SC 11610 12120 207200 TUBING HANGER 4 1/2" 12.6 PPF J-55 BUTTRESS MODIFIED TUBING +/- 300 OTIS SCSSV NIPPLE 4 1/2' 12.6 PPF J-55 BUTTRESS MODIFIED TUBING (1JT) X-OVER 4 1/2" MODIFIED BUTT BOX X 4 1/2" 8RD PIN 4 1/2" 12.75 PPF J-55 8RD MODIFIED TUBING ~ ~ OTIS TUBING SEAL DIVIDER i OTIS RATCH LATCH I_1 I_ I +/- 4130 OTIS VSR RETRIEVABLE PACKER OTIS X NIPPLE 3 1/2'9.2 PPF J-55 BUTTRESS TUBING (1 JT) il I TRISTATE OVERSHOT SEAL ASSEMBLY 5.750 4162.00 +/-20.0( 3 112' 9.2 PPF J-55 Bu'n'RESS TUBING STUB 2.992 3.500 i 4181.19 1.13 X-OVER 3 1/2# BUTT BOXX 3 1/2' 8RD PIN ~ ~ ~ 4182.32 4.52 OTIS TYPE RH RETRIEVABLE PACKER 2.900 6.000 4186.84 0.95 X-OVER 3 1/2" 8RD BOX X 3 1/2" BUTT PIN RECEIVED NOV ] 5 199~ Alaska Oil & Gas Cons. Commission Anchorage [] [] PLANNED COMPLETION SCHEMATIC NGIU A- 11 : OCT TC-IA-EN INHIBmED WAI~:I WIIH ~LYCOL F~ FREEZE PRO1ECTION Ol18 'IUB~IG ~ DNE)ER OTI~ RATCH I. ATCH OT~ ~ FE1RL=VABLE PAO~ER OTI~ X 1RISTATE OVEI:~HOT ~,L ASSEMBLY J-~6 BUT~rlE8~ lUdWiG OTIS TY~E RH REIRIEVAELE PACKER X-OVER $ lt~'MID BOX X a I/Z' BUTT I~1 BAKER MOOEL F ~ PACKER BI.A~T ; 8PECLM. Q.E,'IRANCE ~ BAKER ~0-40 VITON TOP ~=M. 31 BNCER MOOE]. F Pt~M~4ENT PACICER ~ ~i~ECL~. Q.F.~RANCE i B.KST J01NT~ $1/2' PUP Jl' WI ~CLN. C~=)RANCE BLAST JOINTS :~ 1/2' 1USIN(~ WI 6PECIAL CL.F.)/Vd~:E X-OVER $1/2' BUTT BOX X 2 7/8' eRD OTI~ )CA ~LIDI~G SLEEVE X-OVER 2 7/8 ~ i31, BAKER '80-40 VITON TOP BF.)L. 31/2' BUTI' X 31/2' ACJ~'E B,M~J~R ~ F ~ PACY~ER BAKEFI BOI~'OM SUB 3 t/2' ~ X 31~2' BUTT BLAST JOIN~ f 8P~CLM.~, ELA,ST JOINTS SP~ClM. CI.F.~RANC~ BLAST JOINTS f 8PECI,M. CLE)/LN'4CE B.MCEfl ~0-40 VITON TOP ~L. 31 BM(ER M00i~ F ~ PACKER B~.ER BOTT(~I SUB 3 1 BI.A~T J01NT8 BLAST J01NT8 BLAST J01NT8 31~ '/~" eRD BLAST dOINT~ 'SPeCIaL ~ BLAST J01%lT~ 31/2' ltJBl~l W/~PECLM.. ~ BLAST JOINTS 31 ~v' 1UBI~I W/~P~CL, M. CI.E.M:IANC~ 31/2' 1UBI'4G W/SF~CI~L ~ ED 99;5 Commission ~%.~_~M.k..T~.~: OCT TC-~^-~N , ~',' ' ~<B-~H~: I -~ ":'Lin I=ldd.: INHIBITED WAIER WI~H ~LYCOL FOR FFIEE2~ PROIECTi0N ~:, ~oc: ~-~: .... I~ ~A~ ~ ~1 H-~ 4 ~ ~I 10.~ ~ ~ ~0 ~ 3~ ~ ~ ~.~ N-~ ~ ' 11~0' 1~ , , , ..m 0.4 x-o~~xx3~.~ i ..... ~ , ' ".4~ ~.~3 3~.~N-m~~e A~'" I x-o~3~xx3~.~ ; . , ; x-0~31~xx31~ P~ 4H7.~ ~ 3.~ omxo ~ ~{~o~} , ~, .... : 41~.!~ l 1.13 X-0~31~ ~XX31~ ~ P~ I ' ~.~: 3.. om~~[~o~) ........ , . ~ 1.~ ~'~LO~TORW/I~ . . 4.~ ~3.~ s.~ ~'~'WON ~ ~ 4.~ ~e.~ o.~i ~ ~OM ~ ' ~.~: . '~ ~,.~ ~~ ......... m ~ ~- ~: i ........ c~' '4n~ i ' c~3 ' .~.-~! ..... ' ~ ~.~ o.~ x-o~31~ ~xx ET/~ ~ I , : ~ ~.. o.. x-o~tT~x3~ , ~ ~.3 0.~ ~~OM~31~A~X31~ C~e .... ~-~ ~ ~.e ~T~ ...... 3.~ r m~,t~ o.~ X=~~XX~ ~ , : .?4.M ~.~ =~=~,mw/~c~~(3.~co~m ' :, ~,7 ~.~ W~ '~V~ON,TOp ~ 3 ~ ~ X 3 t~ A~ 4.~ ~1.~ ~~F ~PA~ I 4.~ .... ,~z~, ~.~.i 3~W/~c~~(3.~~; ~ ~.M~ e.14 31~ ~W/~C~~' (3.~ ~ ~ 3.~ Cia ~ ~.~ ~.~ ~T~ , 3.w Cle ~-~ J ' ~o.~{ ~.~ 3~w/~c~~(3.~~, , ,~ ,' Cl~ ~-~ ~.aT~ 1~.~ ~T~ ~' 3.~ : ~.12~ ~,~ 31~ WI ~C~~ (~ ~ ~ 3.~ c~. , , ~-~ ~.~j , ~.M ~T~ ,, , 3.w . ~ ~.74 0.e? X-O~3t~ BOXX27~ ~ ~ ~.~ ~M OT~~(~O~) " '.' ,," ' , ~' . ' .~ .... ~-~ ~.~ OM x-0~27~xp1~ , J ~l,~ 1,70 ~~oN~Q~31~X~1~ ~ : 4.~ : ~.~ ~ ~ F ~ PA~ 4.~ ~ I ~_~ , i .... ~4.m , ~m 3~w/~c~~{3.~~ ~ 3.~ M~ ~-~4 ' ' ~4.~ ~.~ X-O~31~XXET~ ~ ~a.~o o.~ x-~7~x3~ · ~ ~:~1' 1.~' ~ ~ON TO~31~ ~ X 31~ A~ 4.~ ~1o.~ 7.~ W~ ~V~ON ~ (e~ m17.~ ~.~ 31~ WI ~C~ ~ (3.~ ~ ~ 3.~1 m~.~ ~o.47 3~ w/~c~~ (3.~ co~ ,~ 3.~ ~.t7 1M.m 31~ ~ W/~C~~ (3.~ CO~ 2~' ~.~ o.~ x-o~3~ ~xx.;7~ ~ ~ 3.~ ~.~ o.~ o~ ~ N~ , ~.~ 0.~ X-O~27~X 31~ ~ ..... ~, . ~. 3~W/~C~~(3.~~ , ~1 3.~ I%Ft . , , .,.-.- NOV ~ ~ Alaska;UP & ~; ED )93 Commission PHILLIPS PETROLEUM COMPANY ANCHORAGE, ALASKA 99503 2525 C ST., CIRI BLDG., SUITE 508 PHONE: 907 279-0606 TELEX: 090 26555 EXPLORATION AND PRODUCTION GROUP Anchorage Area August 5, 1983 File: A-JFS-251'83 CERTIFIED #P 200 299 267 RETURN RECEIPT REQUESTED Mr. C. V. Chatterton, Director Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: NORTH COOK INLET UNIT WELL A-11 Attached is final Sundry Notice (Form 10-403) reflecting .completion of workover operations on the subject well. J' aFAre 'MaSneta;le; JFS/NEP: kd At tach cc: NCIU A-Ii well file w/attach~ AUG Oi~ & Gas Cons~ Commissior~ .Anchorage :- ~ STATE OF ALASKA ALASKA(~''' AND GAS CONSERVATION C . ,vllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATION 1. Drilling well [] ~-~o-~er operation~- ------ 2. Name of operator -- ~.~~o. Phillips Petroleum Company .~ 3. Address 8. APl Number 2525 C Street, Suite 508, Anchorage, Alaska 99503 50- 883-20031-00 4. Location of Well 9. Unit or Lease Name atsurface Platform 'A', Leg 2, Slot 7 - 1301' FNL & 1020 FWL North Cook Inlet Sec 6 - llN-9W, SM 10. WellNo. A-II 11. Field and Pool North Coot< T~let 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Desiqnation and Serial No. RKB is +100' MSLI ADL 1V589 For the Month of July ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks PBTD 7125' RKB. On 7/1/83 set permanent br~.e plug '~ 7125' a4~a~doning Beluga perfs 7176-7277' over all. Ran DST (.s/ee below) ./From ,7/2-6/83 completing well. Set Baker Model F-1 packers at 6115; 5726, 5211, 4937'and 461~' RKB. Ran 3~ tubing with accessories. Set tubing at 6498' RKB. Otis retrievable ~ydraulic packer at 4182' RKB. Complete as commingle (in tubing) Cook Inlet/Beluga well. Nipple down BOPE and nipple up tree and test to 3000 psi - OK. Workover complete 0730 hours, 7/6/83. 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run 16. DST data, perforating data, shows of H2S, miscellaneous data ~l}Ci~O~-~ :DST #7 ?erfs 4624-4867 MD I~B. Flowed 20._5 hours at_ ]:ate of 9.9 mmcfd and 0,2 BW?D at. FT? of 819 ps±, 17. I hereby certify,~t the foregoing is true and correct to the best of my knowledge. s~ J.F. Settle TITLE Area Manager DATE 8/5/83 ~m ' NOTE--Report on this is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservatioh Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 SUNDRY NOTICES AND REPORTS' ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator Phillips Petroleum Company 3. Address 8. APl Number 2525 C Street, Suite 508, A~chorage, Alaska 99503 50-883-20031-00 4. Location of Well THL - Platform 'A', Leg 2, Slot 7, -1301' FNL & 1020' FWL Sec 6-11N-9W, SM OTHER 7. Permit No. 9. Unit or Lease Name North Cook Inlet 5. Elevation in feet (indicate KB, DF, etc.) RKB IS +100' MSL 6. Lease Designation and Serial No. ADL 17589 10. Well Number A-11 11. Field and Pool North Cook Inlet 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] AbandOn [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). From 6/1-11/83, rigged up. From 6/11/83 to 7/6/83, worked over well. PBTD 7125' RKB. Ran 6 DSTs looking for water entry source. Unable to find. Ran. 3½ ~completion string with accessories using 5 permanent packers and 1 retrievable packer~ to separate the pa] so that wireline tools can be employed to ~is°late water entry point(s) which we expect to manifest itSelf during longer flow test period. Tubing was set at 6498' RKBo Packers are at 6115, 5726, 5211, 4'937, 4617 and 4182' RKB. SS are at 6015, 5'535, 5171, 4895 and 4317. SSSV at 273' RKB. Workover complete 0730 hrs, '7/6/83. Final report. 14. I her~ that the for~ing is true and correct to the best of my knowledge. T~spa~'e ~el ow for Com..~sion use ' Conditions of ApproVal, if any: Alaska Oil & Gas Cons. ommissiot~ Anchorage C, ' Date 8/5/83 Approved by COMMISSIONER By Order of the Commission Date Form 10403 Rev. 7-1-80 Submit "Intentions" ir~ Triplicate and "Subsequent Reports" in Duplicate PHILLIPS PETROLEUM COMPANY ANCHORAGE, ALASKA 99503 2525 C ST., CIRI BLDG., SUITE 508 PHONE: 907 279-0606 TELEX: 090 26555 EXPLORATION AND PRODUCTION GROUP Anchorage Area July 22, 1983 File: A-JFS-235-83 CERTIFIED #P13 1753596 RETURN RECEIPT REQUESTED Mr. C. V. Chatterton, Director Alaska Oil and Gas_Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: SUBSEQUENT SUNDRY NOTICE - NCIU WELL A-11 Attached is Form 10-403 setting forth actions taken following verbal approval granted 7/1/83 to set bridge p~lug and complete subject well. U Area Manager JFS/NEP: kd Attachments (duplicate) cc: NCIU A-Il well file w/attach REC IVEI} JUL 2 5 Alaska Oil & Gas Cons, Commission Anchorage STATE OF ALASKA ALASK/~f '_ AND GAS CONSERVATION (~f /IMISSION SUNDRY OTICES AND REPORT ON WELLS · 2. Name of Operator DRILLING WELL [] COMPLETED WELL [] OTHER 4. Phillips Petroleum Company Address 2525 C Street, Suite 508, Anchorage, Alaska 99503 Location of Well THL - Platform 'A' Leg 2 Slot 7 1301' , , , FNL & 1020' FWL Sec 6 - liN - 9W, SM BHL - 1242' FNL & 1067' FWL Sec 31 - 12 N - 9W, SM 5. Elevation in feet (indicate KB, DF, etc.) RKS ±s + 100' MS[ 12. 6. Lease Designation and Serial No. ADL 17589 7. Permit No. 8. APl Number 50- 883-20031-00 9. Unit or Lease Name North Cook Inlet · 10. Well Number A-11 11. Field and Pool North Cook Tnlet Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Set Baker Model N cast iron bridge plug at 7125' RKB using Schlumberger. Set Baker Model F-1 permanent packers at 6115, 5726, 5211, 4937 & 4617' RKB. 3~ production tubing and accessories and Otis Model RH retrievable packer. tubing at 6498' RKB. Set retrievable packer at 4182. SSSV set at 273. Ran Set J U L 2 5 !983 Alaska 0it & Gas Cons. Commission Anchorage 14. I h correct to the best of my knowledge. Signed ~~?~ .~/~ 3.. F. Settle Title Area Map_ager Th ,..,~. e below for Commission use I ions of Approval if any: Date 7/22/8.3 .. By Order of Approved by. COMMISSIONER the Commission Form 10-403 Date Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate PHILLIPS PETROLEUM COMPANY ANCHORAGE, ALASKA 99503 2525 C ST., ClRI BLDG., SUITE 508 PHONE: 907 279-0606 TELEX: 090 26555 EXPLORATION AND PRODUCTION GROUP Anchorage Area July 1, 1983 File: A-JFS-216-83 CERTIFIED #P13-1753592~ RETURN RECEIPT REQUESTED C. V. Chatterton, Director Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: NORTH COOK INLET UNIT WELL NO. A-ii Dear sir: Attached is Form 10-403 (Sundry Notice...) confirming verbal request to .isOlate the two lower most sets of perforations in.' this producing well by setting'a ~ drillable bridge plug above. Verbal approval was given by your Mr. Trimble on 6/30/83. JFS'/NEP: kd Attach in triplicate cc: NCIU A-11 Well file w/attach JUL 5 Oil & Gas Gons. Oommi~sio~ Anchorage STATE OF ALASKA ALASK( k AND GAS CONSERVATION(' ~IMISSION SUNDRY IOTICES AND REPOR't$ ON WELLS 1. DRILLING WELL [] coMPLETED WE L L :~5~:: OTHER [] ~-~ 2. Name of Operator Ph-illips Petroleum Company 3. Address 2525 C Street, Suite 508, Anchorage, Alaska 99503 4. Location of Well THL Platform 'A' Leg 2, Slot 7, 1301' FNL & 1020' FWL, Sec 6 - i W- 9 W, SM BHL - 1242' FNL & 1067 FWL Sec 31 - 12 N - 9 W, SM 5. Elevation in feet (indicate KB, DF, etc.) RKB is.+ 100' MSL 12. 6. Lease Designation and Serial No. ADL 17589 7. Permit No. 8. APl Number 50-883-20031-0 9. Unit o'r Lease Name North Cook Inlet 10. Well Number A-ii 11. Field and Pool North Cook Inlet Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing r-J Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] 'Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-40'7 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170}. Propose to set cast iron bridge plug in 7" casing at 7125' RKB, to isolate the perforations at 7176-7196 and 7267-7277' RKB from those above. Plan to set production tubing about 6500' RKB to produce the remaining open perfs (4254-6464' over all). This confirms.conversation betweenMr. Jim.Trimble and Neai Porter on 6/30/83 wherein approval was granted to proceed as outlined. RE£EtVEI JUL 5 1983 Alaska 0il & Gas Cons, Commissi0~ Subsequent Work Reported Anchorage on Form X°./¢"///)? Dated 7-~'-/~? Signed ~~"?~W~~~ '~' J. F. Settle Title Area Manager Date' 7/1/83 Th~below for Commission use I o~d~tions of Approval, if anY: OlllGINALSIGNED' '" ': ,, ~ By Order of Approved by. COMMISSIONER the Commission ApprOved Copy Returned Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate PHILLIPS PETROLEUM COMPANY ANCHORAGE, ALASKA 99503 2525 C ST., CIRI BLDG., SUITE 508 PHONE: 907 279-0606 TELEX: 090 26555 EXPLORATION AND PRODUCTION GROUP Anchorage Area July 1, 1983 File: A-JFS-215-83 CERTIFIED #P13-1753593 RETURN RECEIPT REQUESTED C. V. Chatterton, Director Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: NCIU WELL A-ii Attached, in duplicate, is Form 10-404 (Monthly 'Report...Workover Operations) setting out activities during June, 1983. JFS/NEP:kd Attach 2 cc: w/attach - NCIU A-Il Well file RECEIV£O J U L - 5 1§~3 Alaska 0il & Gas Cons. Commission Anchorage ' ~ STATE OF ALASKA .... ' ALASKJ~ . AND GAS CONSERVATION MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation 2. Name of operator 7. Permit No. Phillips Petroleum Company 3. Address 8. APl Number 2525 C Street, Suite: 508, Anchorage, Alaska 99503 50- 883-20031-0 4. Location of Well at surface Leg 2, Slot 7, Platform A- 1301 FNL & 1020 FWL, Sec 6 - 11 N - 9 W, SM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB is + 100 MSL ADL 17589 9. Unit or Lease Name North Cook Inlet 10. Well No. A-11 11. Field and Pool North Cook Inlet For the Month of. June ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks PTD 7936. test same. to bottom. From 6/1-11/83, rig up. From 6/11-20/83, kill well. Install BOP riser, Pull tubing. Clean out to 7958' RKB. Lost retrievable BP in hole. Push From 6/20-30/83, running 6 DST's trying to locate source of water entry. 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run 1 6. DST data, perforating data, shows of H2S, miscellaneous data See back of form. 17. I he~~t, to the best of my knowledge. SiGNE~'~w'~~~F. Settle TITLE Area Manager DATE 7/1/83 NOT/~port on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oi~[~as Conservation Commission by the 15th~of the succeeding month, unless otherwise directed. FoY~ 10-404 Rev. 7-1-80 Submit in duplicate 4254-4284 4977-5137 5248-5539 5845-5974 6182-6464 7176-7277 12 10 17 12 15 21.5 8700 767 20 7274 1012 5 8760 895 1 9824 835 2 9211 980 2 7028 365 .5 Mud & Mud Filtrate,SW? Mud & Mud Filtrate, SW? Mud & Mud Filtrate, SW? Mud & Mud Filtrate, SW? Mud & Mud Filtrate, SW? Mud & Mud Filtrates PHILLIPS PETROLEUM COMPANY ANCHORAGE, ALASKA 99503 2525 C ST., CIRI BLDG., SUITE 508 PHONE: 907 279-0606 TELEX: 090 26555 EXPLORATION AND PRODUCTION GROUP Anchorage Area April 12, 1983 File: A-JFS-138-83 CERTIFIED P13 1753584 RETURN RECEIPT REQUESTED Alaska Oil & Gas Conservation Commission 3001 Porcbpine Drive Anchorage, Alaska 99501 RE: Form 10-403 for NCIU Wells No. A-8 & A-ii Attached. in triplicate are "Sundry Notices" indicating our proposed plans to workover the subject wells to improve their deliverability. If you have any questions, please call Neal Porter or myself at 279-0606. JFS/NEP:mm A t t a chmen t s STATE OF ALASKA cOUSE.V^ o co u ss ou SUNDRY IIII D i/ ES A#D REPORTS ON WELLS 1. DRILLING WELL Alaska, Oil & (~as C,~n~ ,', 2. Name of Operator Anchorage Phillips Petroleum Company COMPLETED WELL 7. Permit No. 3. Address 8. APl Number 2525 'C' Street, Suite 508, Anchorage, Alaska 99503 50-883-20031-00 OTHER [] 4. Location of Well THL - Platform 'A' Leg 2, Slot 7, 1301' FNL & 1020' FWL, 9. Unit or Lease Name North Cook Inlet Sec 6-TllN-R9w, SM BHL - 1242' FNL & 1067' FWL, Sec 31-T12N-R9W, SM 5. Elevation in feet (indicate KB, DF, etc.) RKB is + 100' MSL 6. Lease Designation and Serial No. ADL 17589 10. Well Number A-11 11. Field and Pool North Cook Inlet 12. (Submit in Triplicate) Perforate [] Alter Casing r-I, ~ Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Propose to perform the following operations~l~$e startSng~$tv ~~/('ab°ut~p Ju. ne)~¢ ~l~p/l" 198.3.A]~*/' F~¢'~ _~_~ _¢z¢~/~' t ~/~ 1. Rig up. Kill well with 8.8-9.0 pPg fluid.f~ Remove tree.-~I~s~alI riser an~ BOP stack (Hydril, 1 doublegate & 1 singlegate). All components 2M WP or better and arranged per API RP53. Test BOP, choke and kill lines and riser to 2M psi. 2.. Pull combination 4" &' 3~" tubing string and retrievable packer. 3. GIH w/DP and. condition mud and clean out to 7948' RKB. PBTD. 4. GIH w/Retrievable BP and RTTS tool and test existing perforated intervals from 4254' - 7278' RKB for water entry. 5. Squeeze cement perforations found to he wet. Following squeeze work, PU bit and CO to PBTD. 6. Run permanent packers on WL and set according to results of testing. .Then run 3½" tubing string w/sliding sleeves, retrievable hydraulic top packer, and SSSV' Set tubing at lowermost set of perfs open to wellbore. Set top packer about 4200' RKB. Set SSSV about 300' RKB. 7. Clean up well and conduct 4 point BPT. 8. Return to production as a commingled producer in Cook Inlet and Beluga formations. Signed Title Area Manager _. ' ..~.._.~ ~ ~ .r. J. F. settle · ne spa~~ ,or ~omm,ss,on use Condi~,~of Approval, if any: ~ubsequent Work Date 4/12/83 ORIGINAL SIGNED Approved Copy' Returned UEPAR~NT OF ~%TURAL P~SOURCES Division of Oil and Gas Cc~se_r~aticn O' K. Gi!breth, Jr~ ~ Director ~ : Hoyle H. Hanti~tcn . ~/~/~' June 1, 1978 Pswitr~ss subsurface safety valve (SSSV) and surface safety valves (SSV) plus high and low pilots, Phillips Platfonm North Cook Inlet ' ~y_,'May 19, 1978 - I left ~nchorage to ¥~nai at 8:00 AM by AAI, arriving ~n KeD2~i at 8-:30 AM. I ~ralked to Kenai air service where I ~s to get a c~ ride to Phillips Platfon~ Purpose of trip to r~vitness safety valves that failed last test c~ 4/20/78. I arrived on the platform at 12:10 I~4. I met Bob Gamble, the supervisor for Phillips platfc~m. Belc~ are the results of the tests: .,Well No. Fi~ PSI Test PSI 14'00 900 1375 875 · 1500 1000 A-5 ',. 1400 900 Pilot S~SSV ' sS~_ ___ ,_.Hi_' g~_ inw OK OK CK OK OK CK OK OK OK CK OK OK in_. ~_Um~ary3 I rewitnessed the ~ indicated safety valves plus high -and low pilots that failed in previous tests c~ the Phillips platform. Retests were satisfactory. Attachment "Form 20-403 ( Submlt"lntentions" in Triplicate *" REV. 1-10-3'3 & "Subsequent Reports" in. Duplicate STATE OF ALASKA 5. AP, NUMER,CAL CODE OIL AND GAS CONSERVATION COMMITTEE 50-283--20031. AND REPORTS ON WELLS ~ SUNDRY(Do not NOTICESu. this form for proposals to drill or to d~pen u~ "~..L,C~T,ON FO..~.M,T~' ~o~ ~c~ ~ro.o~,~ WELL~ WELL~ OTHER [ NAME OF OPERATOR ~8. UNIT, FARMER LEASE ~ ADDR~5 OF OPERATOR ~9. WELL NO. 4. LOCATION OF WELL [0. FIELD AND POOL, OR ~,~..c~ ~e~ 2~ Slo~ ~ 1301' ~ 1020.3' ~ 12h2~ ~ 1067' ~ Sec. 31~ ?12~ ~M See Item ~ B~ 13. ELEVA~lONS (Show whether DF, RT, GR, etc.) 12. PERMIT NO. ~ 116' ~om ~LW 14. CheCk Appropriate Box To Indicate Nature of Notice, Re )orr, or Other Data NOTICE OF INTENTION TO; SUBSEQUENT REPORT OF: FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT L.~ ALTERING CASING SHOOT OR ACIDIZE ABANDON* SHOOTING OR ACIDIZING L.__J ABANDONMENT* REPAIR WELL CHANGE PLANS (Other) Clea~ out (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PRoPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work, SEE ATTACHED "DAILY REPORT DETAILED" NOV ? 197,5 16. I hereby certify ~ha~~going is trUe and correct TITLE St, Pebrulcum ~in~r ,,, DATE (This space for State office use) APPROVED BY. CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side . .. BZCS. 7286. ~ES. R~' S~SV in place. .u~mded*~ tbsp. ... ...... . ,. ....., · . ~n.. Pressured ,~p 4~ ~d set:.Ot!s ~{...pkr~at..4i98 with 1200 'psi. .~..~" -'.. '::~ .s~ With ,1.800 psi. g~7.nulus ~ressure 'held. ok. ~sConnec-ted lines'. ~u~g: 26~"'Z975' ~ "'~.tl ho~s f~Sshed nSppZe up BOP.- 2 ho~s 'cZ°se ~~ p~essu~e up on . BOP S~aek 2~5~ PSI fo~ ~5 m~uges OK. 2 ho~s pSek up on gub~g~ ;. gub~g ~ ~agched f~om paeke~ pull fo~ sg~ds go ~emove b~l ~a~e ~d ~/~" sgeel l~e~ go ~ ho~e~ g~ go ~ageh ~Ss s~ee~o dS~de~ back ~go ' paeke~. ~ hours seg do~ on paeke~ ~gh s~ee~e dS~de~ " -: - ~e :i~e ~d t~ to close s~e ~to packer would not close, pick up off packer~ go ~ hole ~th w~e l~e to Cheek Sleeve di~der, set back do~ on paeke~ ~ ~e i~e ~d g~ go e~ose se~ dS~de~ se~ dS~de~ ~ouid nog eiose. ~' ho~s come oug og hole ~Sgh ~,, gUb~g ~efg paeke~ ~ ho~e. ~ulF 27~ 1~75 ~ ho~s come oug of ho~e ~Sgh ~,, gub~g~ found Iageh~g gFpe "S" ~e ~e s~e~F 3o~g ~n ioeked posSgSOn. ~n~k ~d go hole~ ~ ~o geg ~ s~egF jo~g~ c~euiage~ ~ogage ege. eome oUg o~ hole~ pSek up 5" Bogen Spe~ go ~'hole~ eouid o~F .... _ -. Form 911 1-69 Printed in U.S.A. DAILY REPORT DETAILED LEASE TOTAL DATE DEPTH NATURE OF WORK ~ERFORMED WELL NO. A-11 SHEET NO. ~ Ju3.v 28, 1975 Jul~ 31, 1975 Present Operation: OIH with tbg. ~ Going in hole with production string. Come out of hole chan~e 5" spear to 2 7/8", go in hole with 5' extansion and fish for top of packer mandrel. Pull packer loose, c~ulate out come out of hole. Lay down Otis packer and safety Joint and fishing tools, finish comAng out of hole. Change out Otis shear sub. Note: La~ing down three ~last Joints excessive san~ cut well produced 1 hr. Operation: Wire line work Finished UIH with tbg, land tbg, remove BOP NU Christmas tree, displace mud with sea water, pump 180 bbls. caustic water down casing. Drop ball and set packer, shear out at 1250 psi, open XA sleeve above packer at ~162, pressure up on tbg, to 1260 psi with annulUS open push water out of tbg to 3500 ft. Close XA sleeve, now bleeding down tbg, prepare to open camco mandrel, Present Operation: Preparing to flow well WTH with Camco retrieving tool, pulled ~ dummy out of camco mandrel at 325, let fluid fall out of easing into tubing (for spottinK alcohol around the top part of casing) Reran~dumm~ valve back into m_andrel. Bleed the pressure off casing, with 720 lbs back to zero pressure tbg 1250 lbs with casing holding steady at zero pressure. Rig up and ran. Otis, -opened XO sleeve at 2236 with 900 lbs pressure on tbg. Rigged down Otis prepare to open yell 1/2" choke. Flowed well for ~ hours. Rigged up Otis, closed XO sleeve at ~2~6 replaced ball valve, opened ~ell on 1/W' choke flowing throuE, h bottom of tbg. Tubin~ loaded up with water and well d/ed. Pulled ball valve, opened XO sleeve at 4236. Now. flowing well. Present Operation: Test operation Finished Flowing water out of tubing and througJ% XO ~'sliding sleeve at ~236. Close sleeve and tr3r to flow through bottom~O~f tUbing, well died. Opened XO sleeve (sliding) at 68,872 flow well through XO ~Valve, closed XO sleeve at ~236, dropped Howco soap sticks (3) and let well sit for three hours. Blow .water out of tbg at 6,872, let Well clean up and closed XO sliding sleeve at. 6,872. Dropped one soap stick and run ball valve opened at 1/4" choke. Blow ~ater out of tbg pu~ well on test at 2:15 a.m. Ail sleeves closed, flowing from bottom of tbg. Note: Ball valves in place during each flow. Will test until B:00 pm if everything O.K. will move to well A-10. Form 911 1-69 Printed in U.S.A. STATE OF ALASKA Form No. G-1 ~EWS~O .. ,~,~,. s, IS6S OIL AND GAS CONSERVATION CO/V~ITTEE GAS WELL OPEN FLOW POTENTIAL TEST REPORT , .~,... 4-POL~T. TEST · '" '-"/ i Test ~ Init lal L~J Annual D Special Oper~'~ ~ . -- I Lease ~ . ' , I Pr;}lueln. Thru [ R,..olr I 'WellheJd I C~0. Size I %Vt/Ft. TB . CSG. Temperature Temperature ,, .'..' / ~~~ :'::,.".? )) i ,~lultiple Completion (Dual or Triple) , t ' ' *" :'" ''~ '~': ....:~,,'"L,,",: J T,y..pe produ~tio[t fron}, each zone OBSERVED DkTA Flow Data :,, · Timer ',' ,'" ~),, ' (~!~e).~o.i. J ' '""Press ...... : , ...' Diff, , ~ Tubing Casing Flowing ~' N0. of Flow; ' (Line) (Orifice),, : .',. :,;i,: ..~ h Press. Press. " Temp. ~":' Hours . Size Size "' pslg W ' pslg psi~ 'F s, I0o/ ' ~ , , , , , ' " ~' /~ " I ' .... - g! FLOXV CALCULATIONS ' , !' Flow Temp." Gravity Compress. .' __~/hw : ' ' .' 'F tor. ,.. Factor . Factor RateofFlow Coeffi- 1~Io, clent ' , .. . p :'...,. Pressure .i.(., a~c .. , . F · F ,. (24 Hr.) m psla t g pv Q MCF/D ~. ,45 t~:F., . ',.,~t.~ ~ l~..t~ ,,~' . ~,~,:~ t,o~ 2: " 2B~,~ ' /2,~o /,oo~ " " /~, I1~ , , ,, . · , .... . ,. ,,. ' axz. o ,z.o:. ,,,,o. '" '' ,.o~e t,,lal )i: L,!' ' PRESSURE CALCULATIONI Potential n ,, , ~- '"----~ ~ · · CERTIFICATE: I, ~e undersized, state ~at I am the ~* (~: ~ of ~e ~ ~1 ~.~ (comply), ~d ~at I am au~or~ed by said comply to make t~s report; and ~a~eport was pre- p~ =der my ,u.~ion ~d d~ecUon and that the'fac~st~ ~ere~ are~~rect~d complete to ...//~.>, ~_..,... '.... ~.,~: .. .,:., ,. ~ ~ ! ! 1975 :1 I '2'I ,, i .. ; i 3 4 5 b 7 8 9 10 100 EForm 10-403 ' Submit "1 ntentions" in Triplicate ,~ RE~;~i.10.Y3 ( & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 50-283-:~0031 6. LEASE DESIGNATION AND SERIAL NO. ADL- 17589 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. O,L r-I GAs WELLL.J WELL ~ OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Phillips Petroleum Company NCIU 3. ADDRESS OF OPERATOR 9. WELL NO. P. 0. Drawer 66 / Kenai, Alaska 99611 A-11 10. FIELD AND POOL, OR WILDCAT 4, LOCATION OF WELL Atsurface Leg 2, Slot 7, 1301' FNL, 1020.3' FWL, Sec. 6, TllN, Rgw, S.M. BHL 1242' FNL, 1(}67' FWL, Sec. 31, T12N, RgW, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RKB 116 ' From M~LW CheCk Appropriate Box To Indicate Nature of Notice, Re 14. 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) See Item 4 BHL 12. PERMIT NO. )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) ~'[eR.T~ nl]~ & Pe. rf (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimateM date of starting any proposed work. SEE ATTACHED "DAILY REPORT DETAILED" JUL Sr. l°e±,rol~_~TM lq.n~ineer ('~l~s space for State office use) DIYI,SiON OF t DATE. APPROVED BY. CONDITIONS OF APPROVAL, IF ANY.' TITLE DATE See Instructions On Reverse Side ' .. ~LEASE DailY REPORT, DETA : WELL'NO. SHEET NO. 'AL. E P ,T H ERFORMED ~Ad:" 10.5 Vis: ~2, - .. ' GOON w/ 3 1/3 DP, :PU BOP aud riser. ND tbg head.. 'Hung off and riser. Lowered mud level in 7" csg. Visual inspection showed ~arted at. 26' below csg head.. Speared csg and LD 26.' piece. Csg ruptured and parted in body of gauge Jt of 26~ K-55 Which was immediately above 23# K-55 csg... No evidence of DP wear or corrosion in'"area' of ruptUre,was apparent.: S ~peared fish a~ 61' R~.'~:,.' Stretch in 'fi~h,~hoWed 7"x 10 3/~" annulus ". cmtd up within hS0' of RT; Rlf GO Yn~ i. BaCked out thread in Tri orate spear when attempting back ~orque. Screwed' spear back together. Released same. Pulled .and welded spear. Respeared fish. RU GO. When applying back off torque 7" broke and released'at'mill connection on bottom of 7" gauge Jr'. LD 10' piece 7" ,csg 26#:K-55. Now off loading 7"csg from ~'Ork"boat. l,' '/~i 'i':.:.:WIN' '." bridge 7542. Drilled dry. hole' 75h2'; 7895. C&C~ 8 hours. POOH. ,'Now RU :Schlumberger. ,, · J_uly .~,,. !9.75 Tstd lubricator to 1000 psi ok..'Perf as follOWs With ~" hyperJet with 4" holesyer f~. ~. 7267- 77 1ES.. Mud:lO. 5 'Vis: 25 ':~ ',:' Screwed into 7" fish at 77' .~ old'RKB with new~ 7". 2R#'K-~ Hung 7 &. csg head'w/80,O00 lb,.-~NU tbg~head, Tstd to B000 #. NU BOP. Repaired blind'rams ~ hrs, '. Tstd 7" to 2000'Psi:;~' o.k. Tstd pipe and blind rams, choke manifold and kill line to 3000 Psi. ,Tstd Hydril 2500 .psi..l~IH'w/ 6 1/8 bit. Tagged emt. at B2~0. Filled emt to 35~0. NOW finishing GiH pushing cmt plug ahead of bit. RD Schlumberger. WIN w/3 1/2 tbg. TStd~4" rmu 2500 Finished test plug. Now GIH 6272 6212' ' 6182 ' 5962 ,'' . 500 ~Psi g mud SD Pump~'~ attempte ~ei1 · flowed press ~built up ,si in 2 hrs. ~ gas t° h00"psi and lubricated 32 bbl .mUd into tbg. 11 'cont lubri c g p % .~ . : Wi ating' in mud until tb .ress,,~ stabilizes, near will then ho°t.'circ'ulati°n per~o~ati°ns intbg and . , ~ killing well.~ Finished lubricating mud into tbg : could be bled'~o zero. Gas was'still working out of'tbg, ger perf ~" tbg at H092.5/: to 4093.5 with 4 circ holes'. 3' indication of commUniCation with ~"~x 7" anulus When..gun fired. ~ .preSSed up '.%'.' csg to establish cftc throug~ holes.~. 7" csgi~ruptured at llO0 psi - ok. a No communication thru~ cite PerfS in tbg. Bled g s head off ,::~bg and pressured up to 1200 pSi. pumped into formation ~t 1200 psi without communication through holes, in ~" tbg~ Perf' ~052 to 2053 in 4" tbg with heavier charges. GoOd. circ established. circ. water ' out of 7" and C&OM. Installed BPV. ND XT. NU~BOP. Tstd pipe-rams, kill .line and'choke manifold to 3000 psi. Tstd psi. Pulled pkr~?looSe' Now COOH and Laying down . ',Pkr hung from B2' to2h', belOW'.tbg head;, ,Pk~ dragged WOC. rc out. Now. WOC~'~ c 7 hrS.~ 3336~ to ,'-,.:PO0 to' 000# overpull . 6f. being ,sed.csg, ,:'Ran 5 ~ thrm bad L6", Circ out, 5'hfs w~ting on li, 3hfs erie" ~p~r, R~ cmt from sx Ci~s G ~t~/~:Po~" to ~800".~ Rearsod n°~'s'~ ~. ~PU'to ~BB6. C~ci~ ~loride,~ Job ~'a woc 6 h°~, werehar~.. PU PU %~ 2976, Circ , ~:~:PU'%0 Rev out, t,~ Co~d p~.o~ · - - !y~':3OQ.:-..:' from ,':~n'e~':-fi tting,~?',.. ' rsn GR" tbg.'"'""'~'Of'- bg cbr~lat'ed 'at '"' ;0~:~:: NU ~,:.~ .~s~'eo';~ 't0. 300 pai:~'.:".:f~essu~"..~/~. e~:~'01 l~e ~o" ~." .. . ,..... .... ,.. . .?.....,:?.'~ P : :~=.....'::. ,: T ~~ ~/ · ,~'. ~°~ed 1 !/4"' 8~eei'-~'~l,.:~:~.~g,.- T~e~ o~ b~l~ ~o~ ~0 ~ss'~red 4" x 7 ~n~ to gOO PSi ou~ ball ~d cat'er ~OJ psi:, ';~mulus::o~ss Ok.. ~s'~onnected'lines ~"rePort~.~'......~..:.~.. ?~... ~:' ......:~'~'~ ..~'~.' '-~ ~'...~:-...-~: .~.~:. ~':~.. '~' ..e~'~' '~ ,'~ '.~.. · ':' .:3 ':,'. ' ?.:., :'L~ - .:. . :' '. · ' 3~.. -? %~:'.: ' ~ . ~ .." , '.~.V~-~:..,.: , .. ' '.', . .' ~'.-'~': ~' ? .: ~ "-: .'. ,. ~:"~ ': . : · ' :"-7"3..::~' /,~ "..' ".'"'~ : .~3' '. ~ . '~'::~4' :,~'('??",. :~.'~'. ' '-: ' ~ ...,: ,._- ~ ~{" . . ~.: (Do not use this form for proposals to drill or to deepen or plug back to a difflerent reservoir. 1. OIL [~ GA8 WELL WELL 2. NAAIE OF OPEP,~TOR Form P--3 REV. 9-30-6~ (' Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate. STATE ,OF 'ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS Use ".'U'PL~CA~m~ FO, ~'~-t~',nT--" ~or such p,'opo,.~.) ] ADL'- 17589 19.~o. - - [ .zu. ~-,,:,.,, .q.~D ~OOL, OR WILt [ North Cook Inlet ! ,l. s~c.. T.. ~i.. ~'.. [] OTHER 99611 ~A.N. A. LLO~ OR TRIBE Phillips Petroleum Company. 3. ADDP,~'SS OF OPEP~TOR 8. UNIT, FAP~Wl OR LEASE NAME NCIU P. O. Drawer 66, Ken&i, Alaska 4. LOCA.TION OF mAr~.,L Atsur~acel-eg 2, Slot 7, .1301' FNL, 1020.3' FWL, Sec. 6, TllN~ R 9W, S.M. BHL 1242' FNL, 1067' FWL~ Sec. 31, T 12N~ R 13. ELEVATIONS (Show whether DF, RT, GR, etc. 10. Frk-rr.r~ ANT) POOL, OR WILDCAT 11. SEC., T., R.. M., (BOTTOM HOL~ RKB ll6' F~om MLLW -. ,~ i~~ :. 14. Check Appropriate-Box-To [mi}cate Niature of N~t~Ce, Report, or Other 'Data .-. ,_ details, and give pertinent dates, including estimated date of st~r~ln~ an}- .: NOTIC~ OF INTmNTZON TO: TEST WATER'SRUT-0FF ~'~ 'PULL OR ALTER CA,IN0 FRACTUR, TREAT {__{ MULTIPL, COMPLETE REPAIR W~LL ' ~ CHANO~ PLANS D~SCm~ v~oPOS~o ~~ · proposed wor~ · PLaTeD OP~ATION~ (Clearly state all p~rtlnent 1. Rig up. Kill well with 10.5 ppg mud. Remove tree; Install 12"--'3000~ WP riser and 12" 3000~ WP double gate prevenbor and Hydril. Test BOP and riser. 2. Pull 4" tbg and retrievable packer. 3'. Perforate Beluga P~v 5869 - 7277, MD RKB overall Run combination ~', X 3~~'' tubing string with Otis subsurface safety Valve set about 286' RKB and Otis retrievable packer set about 4218, MD RKB~ and tubing set 7283' ND RKB. 5. Install tree and displace mud with water. Set hydraulic packer,. Test packoff. : 6. Clean up well and .conduct ~ point BPT. 7. Utilize as a producer commingled in Cook Inlet an~ Be!Ui2 :ipay~ ~ Estimated start of Oper~ations is 6/27/75 . _~', i .... : .. .. :i ,. ~: DI',/:S!ON OF OiL (This space for State o~ie use) CONDITION80~F'A~p~¥AL, 1~ .~': ' See Instructions On Reverse Side ' ,~:~m',foej Cop y Date Size of C,~stlng 5-3-70 7". 11 !1 11 1t II 11 II I1 II II II II I1 ~I 11 11 II II II II II II tl IES &702, &805' &846' &867' t~987, 5089' 5137' 5262' 5285' 5307' 5368' 5~19' 5~60' 5~98" THE FOLIZ Per{orating:: Perforated_ : oles :-.': -;;. -Holes ::-.; : }--:Dbmeter:>~-:.: I' _:-:~--:-.:-Type-.,:::::!:;--:.- ?.':,'.-: COmpany _ _ . : :' _ .:,- ..: . :' -~ ,...'~ . .?" ::_-.::: ~_ ..-_/ _ ,.,:-: : .- . . ; _1.--- _, ';:-.: ::.- -,. - 90 - -: 360 i 120 ·" 15 :. -: 60 10 /,O-' 50 200: 3o _: 120. '.' -;~ .----' ' 56 '~- 5 '-: 20. 18'- .-:.:. /:' 72": 10'' 20' "/- :~ 80: :- lO' . '. -&O-..": 30 .' -:: '--120 :_: :' . rlONS : .' ::'~- '_ .: ~ - ._ - ~ .. - _~..- PHILLIPS PETROLEUM COMPANY ANCHORAGE, ALASKA 99501 ~ 515"D' STREET EXPLORATION AND PRODUCTION DEPARTMENT August 31, 1970 FILE: - ,. , Division of Mines & Minerals Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 9950~ Attention: Mr. T. R. Marshall, Jr. Gentlemen: Attached, please find Form P-7, Well Completion or Recompletion Report and Log, Chronological Well History from date of re-entry to suspension, Perforating and Squeeze Record and Sample Description for NCIU Well ~,~A-11. Yours truly, JBG: jo Attachments P/~LLIPS PETROLEUM COMPANY District Office Manager SUBMIT IN DUPLI~I~. $?A?E OF A£ASKA (See other in- structions on 5. APl[ N~.~C./~ CODE OIL AND GAS CONSERVATION COMMITTEE ~,,~,r~e A?I 50-283-20031 J I I ~11 I T WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TY~E OF WELL: 0ILwzLL ~ GAS ~ DRY - - W~LL ~ Other b. TYPE 0F COMPLE~ON: NEW ~ wonK OVER ~ DEEP- WELL BACK 'EE~VR. . . z ~i~ or o~=.~roa No~h Cook Znle~ UnE~ ~. ADDRESS OF OPERATO~ A-~ 515 "D" Street, Anchorage, Alaska ~950Y ~t,,,~ ~ 2, S/o~ 7, Z3OZ.~~ F~, Z020.3~ ~ Sec. ~, TZ~, u.s~c..r..~..~..c~ao~ At top prod. lazervaz reported betow ~00~ Z~20~ F~ & ~ ~, Sec. 31, TZ2~, RgW, S.~. ...... ., , ,~?-e? 8-2~-69 } 10-13-69 . [ 5-3w70 [ ~B 116' From ~W ,. 73' From ~,LW 18, T~ D~H, .~ & TVD $9. PLUG .~CK MD & '~'v~$, ~ ~LT~LE ~L,, ' [ 21, ' 'INTERVALS 'DRILLED BY ' . _ '[ DE~ _ ] ~OW~Y' ~ ROTARY TOOLS ......... I ' ' CABLE TOOLS m~0, ~; ,~9~'Tm[795S, m~ e~7' T~ - ' I ~ota~ Cook Inlet Sands ~251' - 5a98' ~ ..~ _ ~a-~a ] Yes Sec. 31, T12N, Rgw, S,M. 12. PEP, lVlIT 1~O. IES, FDC SNP & CBL CASCO ~' (Re~ all strips set ~ well) ANCI~O~AO~ -~6U 0.a. , [ 65~ ,' [H-~0 ",1' ~2Z.~01 I 22It [" 605 Sx 'O' cmt ? 0.D. [23~ &26~ ']' J'55[ ~03.06' ] 9-5/8,1.12~1 SX 'O' cmt '26. LINER ~CO~ ' SIZE ' TOP (~) BO~O~ (MD) 28. PE~O~TIONS OPEN TO PRODUCl~ON (Inte~al, size ~d number) i A.MOUI',TT PULLED None NOne None II 27. [TUBING i~EOOI:~D SCREEN CMl)) SIZE DEPTH SET (MD) PACKER SET (MD) 4147 ',' · I Il Il I 29. ACID, SHOT, Fx'~A,C~I'URE,' CEAIE~T SQUEEZE, ETC. SEE ATTACHED PERFORATING & SQUEEZE RECORD · I I I 3O. PRODUCTION DICC~-I. INT~V~ (MD) 5538'-39' " ~62~'-2~' 2~06'-07' A,MO/,,)-N'.I' .,'-..ND KIND O,F MATE.~.IAI~ USS ,'].S. qzd 12.5 Sx 'G' cmt Sczd 125 sx "G' cmt . Sqzd /+75 sx 'G' cmt Sqzd 1}O sx 'G, cmt DATE FIRST PI%ODUCTION '[ PRODUCTION METHO'D (Flowh~g, gas lift, pumping~size and type of pump) [WELL STATUS (Producing or aleut-in) , . NOT PRODUCED ,, ' ' -' DATE OF TEST, p~oUas TE~TED [PaO~)'N FOa ~m--B~L. ' -8~--~CF. WAT~--BEU. lO*S-Om FLOW TUBING ~*.SING PRESSU12E [CALCUI.~TED OIL--BBL, ' TEST WITNESSED BY '~7 1. Pe;fora~ing i Squeeze Record. 2. ~ronoloaical We~ , '/ / }. ~fle Description 3~. I hereby cert~ ~at the fore~oin~nd attached ln~rmation Is complete and correct as determined from all;availa~le records *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well complet!on report and log on all-types of lands and leases in:'~aska .... Item: 16: Indicate which eleva~ion' is usec~ ~ - ~ ~ ments given ;in ather:~sPaces on,this form and in any attachments. "~ ~ms 20, an~ .... 2~:~;If this well is .completed fo~ separat~ production from'[~ more thah one interval zon~ (multiple co~l~ti~n),'~ so~state~ in item 20, and in item 22 show the prcducing ih~erval, o~. intervals~ to~), :~tt~(s). and name (s) (if any) ~or only the interval reported in item 30. SUb~it a separate re~rt. (pa~) ~ thJg fbr~,'?~d~uatelyjdentified, for each additional inte~al to ing the a~ij~o~al .~afa'.~ine~ to such-~rval. ~26: "~c~ Cement": Atta~ supple~-ntaJ ~ords for this well should show the ~etails of any mul- , tiple stage ~entjng and the loCation Ibm 28: ~bmit a serrate com~etion r~rt on this form for each interval to . (~ instru~ion for imms 20 and 22 a~e~. ' :,,' /'~34. SUMI~ARY OF FOII.M:~TION TE~/'S INCLt~OIN~.-JN'~RVAL TESTED. ~URE DATA ~ ~It. ECOVERIES OF OIL. .~- '~ : . 9 '3. ') -" ;;' >"~-~ ' :~' _': . . :. ;:-~. 'J . , -: .... ~. : · , q .. ~ . : . ~ ' . ~ '1 5 ' .: . ~ . ..... t '-. ~. . 3~_.. i~ : ~..: CO~ 'DATA. A~ACll nm~ D~Pmo~ or LI~O~GY. ~ROSITY. -~RA~. APP~T Ol~ ' ' -~ ~ -' ~ ~ -I - · ; .- .-.. -s . , .. ---. ~ { ': ~ . ~;..~J. .. - · '::~ -- . ..... NCIU WELL ~A-1! /,-22-'70 ~-23./29-?0 &-9o/5-1-7o 5-2 ./3 -7o CHRONOLOGICAL ?~LL HISTORY ?gH. Drld cmt & DC 5586' - 5596'. i.~H to top of float collar. Tstd csg. Ran CBL. Perf csg 5538' - 5539' w/L ½" shots. Sqzd 125 sx T~rpe 'G' cmt into formation thru perfs. ~ax. holding press., 3OO~~. Perf csg 462~' - 4625' w/g ½" shots. Sqzd 125 sx ~Type 'G' cmt into formation thru perfs. Max. holding press., 3000~~-. Perf 4306' - lA307' w/& ½" shots. Sqzd 135 sx Type 'G' cmt into formation thru perfs. ~ax. holding press., 3000~. Perf &225' -4226' w/4 ½" shots. Sqzd 130 sx Type 'G' cmt into formation thru perfs. Max. holding press., 300~4. Drld out cmt. Tstd perfs 4506' - ~307'; would not hold. Sqzd perfs ~306' - ~30?' w/lO0 sx ,Type 'G' cmt; did not hold. Sqzd 240 sx Type 'G' cmt into formation thru perfs. M~x. holding press., 3100~. Drid out cmt to 7955'. Tstd csg to 2000# for 15 mins, held O.K. Ran ~" OD tbg string. Set at ~1~7'. Ball valve set at 287' & tstd control line to 5000~/-, 0.K. Released rig. Pulled Otis ball valve dummy. Perf as follows in Cook Inlet Sands 4-.~6" shots/ft thru tbg w/No Plug jets in 2" Scallop. IES Measurements RKB: ~25~' - 428~', ~657' - 4702', ~715' - 4805', 4816' - 48~6', L852' - 4867', 4977' -4987', 5039' - 5089', 5107' - 5157', 52g8' - 5262', 5280' - 5285', 5289' - 5307', 5358' - 5368', 5399' - ~419', 5450' - 5g'60', 5g68' - 5498'. SNP Measurements RKB: g253' - 42S3', ~657' - g702', ~?15' - 4805', ~816' - g446', 4S52' -4S67', g977' -49S7', 50~9' - 50~9', 5107' - 51~7', 5250' - 526J~', 5281' - 5286', 5290' - ~308', 5559' - 5569', 5400' - 5g20', 5450' - 5460', 5468' - 5498' · Temporarily Suspended. 0 - 3100 3100- 397O 397O- 4180 4180 - 4545 4545 - 4610 4610 - 5515 5515 - 5845 5845 - 5970 5970 - 6175 6175 - 6480 648O - 6675 6675 - 67OO 6700 - 7175 7175 - 729O 7290 - 7595 7595 - 8210 PHILLIPS PETROLEUM COMPANY #A-il N.C.I. Unit North Cook Inlet Field Cook Inlet, Alaska SAMPLE DESCRIPTION Sand & gravel. Sand- Lt gy, f-mg, SA. Mudst - Gy, soft. Sand- Lt gy, f-mg, SA. Mudst - Gy & tan, soft, carb. Sand- Lt gy, f-mg, SA-SR; w/interbedded mudst, sltst, and coal. Mudst- Tan, soft; w/interbedded sltst, coal & sand. Sand - Lt gy, f-mg, SA; w/interbedded sltst and mudst. Mudst - Tan, carb; w/interbedded sltst, coal & sand. Sand - Lt gy, fg, SA-SR. Mudst - Gy, soft. Sand- Lt gy, fg, SA. Clyst - Gy and tan, soft; w/interbedded sltst and ss. Sand- Lt gy, vf-fg, SA, pt. calc; w/interbedded sltst. Interbedded clyst and ss. Clyst - Lt tan, soft; w/interbedded coal and sltst. SYMGOL OF SERVICE REPORT of SUB-SURFACE DIRECTIONAL SURVEY PHILLIPS PETROLEUM COMPANY COMPANY PLATFORM "A" A--II WELL NAME NORTH COOK INLET ALASKA ~'LOCATION JOB NUMBER AM9-3169 TYPE OF SURVEY SINGLE SHOT DATE SEPT- OCT 1969 SURVEY BY anchorage OFFICE fORM ID-gO~' I~ ~. LITHO BY EASTCO IN U. S. A. N E L L' C~'O M~P L E T~I'O'N R _F p 0 R T PH!'I l_)P_g PFTR~ll FIlM C6)MPANY ': A"II ',~ PREPARED BY /S£S 10/t3/69 FOR EASTMAN TANGENTIAL MEASURFr)_ 0 F V ! A T:'! 61 N TVD ~t_lR RFA TOTAL'COORDINATES ~ C L :t3 S U R E S m DOG LEG LATITUDE DEPARTURE: DISTANCE AN'GLEE _SEVERITY C ORIG!N LOCaTEO AT 911 6 45' 1006 !0 log9 .. 12 ~ .... 14 0 !2~0 , , 16 r t 22 30' ..... 24 ,!5' 1788 27 !97~ :~ ~34R ~667 46 0 2888 45 0~ 3451 42 30' , 3958 4~nI 4~ 30' 4~ 4~ 0" 5178 44 ZS,,~ 5365 5489 48 0 5613 58A~, ~R 0 ' MD = 840.00? TVD = 848:!~6!e~ LATTTUOF N ~W RTq.46 77q.46 N 2W 910,25 N 3W !003.73 00~.73 40-q2N N 5,F 10q4.70 094~70 N. 3W 1278,80 11,78-80 !lO'~TqN N 4W l~q~.~ 17q~ l~-OqN N. 3W !6~2.95 !522~95 N 2W 21R4.&O 2084'40 640,~gN N 3W ~406=00 N ~W 2&73.58 2373.58' g~7~f;4N N 3W 256!=g7 2461'q7 ]025~g!N N IW ~Rq~.Aq 2732.6g 1283-70N N 3W 33fi!,02 ~25!*02 '!747~82N_ N 3W ~!!2,05 40!2~05 N 3W 4374,00 4276~00 N 3W 4456=97 ~356~97 N ~W 4707.2~ = !7-4'3= DEPARTURE. 3-~8F 20.67 N ' 2-37F 40'g8 N 4.05F 60-]1N . 2,20E !10.81 N 7,~W~ ~].)4~N- !6~6qW ' 407~06 N 20-58W' . 518~29 N 39'e20W 870-39 N 4t.58W 938'-~6 N 46'20W !026.gS~..N 57.42W 1284'.98"N 61'87W 141~.66 N 64'81W 1~80.91.N 83.~7W 1~3.7'~ N 9~.38W 2~07'63 N 101,27W 2277'44 N l!O+26W 24~g-~0 N~ !!7,05W.. 2579.09 N 27!]'8gN !24.15W 2714-73 N 308t,68N 138.88W 3084.80 N 9.42E o.000 7,71E 4'046 3.31,F 3'68:7 3.85E 2.504. 2-5!,F 2.537. t-14~ 2'916' 0.28W i 2,633 )~39W ~'037 t'72W !.549 2.~5W 2.701 : 2.~7W 2.425 .:2.22W: 2.406 2.52W 2'787 2-58W ~ 0.540 ~.53W ~'.079 2.57W 0~:6:01 2.SIW 0.753 2.56W 0,398 2'~IW 0'640 2~34W 0-473 2.4IW 2.4bW 0'088 2'51W 0.198 2.54W . 0-200 2,58W _ 0,000 2.60W 2.62W 1.203 2~6'3W. 1.209 2.6IW 0.599 2.57W OoOOQ. · ~' ' '. i A" I ~ PRFPARF -- W. E L L: C O.:M P L:E: T:!'O:N R IL:_ P O~'R-T !NTERPOLATEO VALUF:_$ FOR 'EV_F::N !OQ'-F~F~T OF $1iB $1::j_A I')~PTH ' PAGE ! PHTII TPR PFTRnlFI1M el']MPA-NY 'A-.ll PRFPAR~D HY .~C.R ]0/]_~/i69 FOR EA~TNAN TANG~.NTIAL {METHOD - MEASURED - DEPTH TOT;Al,:' COORD ir NATES MD-TVD VFRT ! CAI= TVD SUB SEA LAT!TUDE DEPARTU..II_E D! F FERENC. F:_ CORR~CT_'[.ON 90! !!04 !208 1419 .... 15_~? "47 '~ 1864 1983 ~-- 2~70 ~ 2658 o 2800 294! 3353 3~88 3622 .. ..... ~15g ~293 2 4429 4565 900~00 !000=00- !!00=:00 lO00,O0 !2gO=g0 1!00~00 1300=00 !200:00 !400=00 !300=00 !50O~O0 !~O0~O0 1600=00 !500~00 !?00=00 !600~00 !800~00 !700~00 1900=00 1800.00 2000=00 !900,00 2!00~00', ,20no.on 2200~00 2!00:00 2~00=00 2200=.00 2400.00 , 2300.00 25,00=00 2~00=00 . ~600=00 2500=00 ~700~00 . 2AOO~OO 2800~00 ,2700:00 2900=00 2800,00 3000=00 2900.00 3100=00 3000~'00 3200=00 3!00~00 3400=00 3300:00 3500=00 3400=00 3600=00 3500~00 3700=00 3600~00 3800~00 3700,00 22~82N 40=24N !!8:48N !55:02N 240=90N 290=39N ~85=88N 5AT~!~N 2~0E 4~03E !.67E -O~9lW -!0-28W -!~-46W 656=60N -25.98W 759~90N ~-33~2'!W 964=0!N ~70~'34N ITg!=86N -75~g4W !881=77N 13 2T 48 64 107 170 2!4 258_ 00 ~79 88 22 590, 1 1 2 4 5 ___6 8 ~g ~4 42 ~ 38 35 34 35 %6 W 'E' L :L C :0 M:P L::E T!~!'-.O:: N' R E INTERPOLATED VALUES FOR EVEN' !000 'FEET OF MEASURED DEPTH PAGE 1_ : PH!LL!P$ PETROLEIJ~:iCO~PANY "A-l-! PREPAREO BY'"$¢$ 10'/!3!6g FO~.EASTNAN TANgeNTS:A!: HFTNflD ~. MEASURED DEPTH TVD SUB SEA TOTAL COORDINATES LAT!TUDE DEPARTURE. 1000 2000 3000 4000 5000 6000 7000 3'0 997.00 897 !g'!3,00 !~!~=00 42~,!7N --17.23N' 26~2 O0 .~5~2-:00 1!i0~.3'1N 3382.=00 3282=00 !775,89N -?5.!'OW 4!!7~'00 40!7=00 2~52'=39N -1,!'0-=55W 4799=00' 4699=00 . 31-8)i~'0'7N -!40',45W 6!53=00 6053 00' 4653*.::2'5N :-!05'63W 358 618 883 1201 1847 84 318 321} ' ---- W E L:L ~ · C 0 M' P L ~E T ! 0 N R E P 0 R-T INTE.RPOLATED'VALiJES FOR EVEN' 1_00 FEET OF .SUB SEA :DEPTH PAGE 2 PH!LL!P$:PETROLEUMiCOMPANY'A-11 'PREPARED BY SCS !0'/1j3/~q FOR FASTNAN 'TANGFNT/AL NETHGO: , MEASURED DEPTH TVD SUB SEA TOTAI2'COO~D~N~TES LAT!TUDE DEPARTURE D!~FFERENCF CnRRFCT~N 2 1 0 9 ~702 4839 5115 5257 · 5a.O~. 5553 -- 03 6001 .6296 6589 70~6 7!86 7~8 ! 7627 7773 .792 ! 3900-00 3800,00. 4000=00 3900=00 4!00 O0 4000:00 4200,00 4100,00 4300=00 4200=00 !iO0~O0 !300.00 ~600=00 !500 O0 4700~00 4600-00 4800=00 4700,00 4900:00 ~800*00 5000=00 4900-00 5100,00 5000,00 5200;00' 5!00:00' 5300=00 5200=00 5~00=00 5300,00 5500;00 5400=00 56.00:00 5500.00 5700~00 5600~00 5800;00 .5700=00 5900:00 5800,00 6000=00 5900,00 6100.00 ~OOO,O0 6200*00 :6!00.00 23~2=~7N -!04.79W 2435=60N -!09,67N 2532~8N. -!!4.~4W 2634=0!N' 2740=72N 2962,'66N '3073,::65N -1,:38~40N 3293.!6N '36!4=82N 37:25=28N 3836'!7N 4055.17N 4380-90N -!27*T!W 76 915 57 1004 !~:OB 1152 !20! 1~49 I~2 !389 !487 1536 1584 !~8! 1773 ]82! ' 1869 B7 39 42 50 49 49 47 48 ~9 48 '7 i4 LOCATED IN THE APPENDIX UI WFL UI IPR LOG CALIPER SURVEY Cl VOLAN UI CURVE DATA [~ STRATIGRAPHIC HIGH RESOLUTION DIPMETER · [~ OTHER: STATE OF ALASKA Sub~ ' ' "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION ,COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a difflerent reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) OIL ~. GAS ~ WELL WELL OTHER 2. NAME OF OPEP,~TOR Phillips Petroleum 0empamy 3. ,DbmS oF oP~Toa 515 "B" Street, Anchorage, Alaska ~501 4. LOCATION~ O,F WELL At.-ur~ace Leg 2, Slot 7, 1301.9' F~L, 1020.3' FWL, Sec. 6, Tll~, R~, $.M., North 0ook Inlet, Platform "Tyemek" Top of. ?..a.v: .&~M), H~, 3850, ~, 850, FSL, ~, FWL, Sec. 31, ?12~, R~W, 8.M ..... 13. ELEVATIONS (ShoW Whether DF, RT, Gl{, etc. I~B L16' Fr~a NLI.W 14. 5. API NUiVIERICAL CODE API 50-283-20031 6. LEA~E DESIGNATION A.ND SEPJ_A.L NO. , ABL-17589 '/. IF INDIA_Ar, AJ_J.~ OR TRIBE NA.ME 8. UNIT, FA_R1VL OR LEASE NAlVlE 'Ninth Cook Inlet; Unit 9. WIiIL,L NO. 10. FI~"-:LD ~ i~OOL, Gl{ WILDCAT , OBJECTIVE) , See..:31~ ~ R9W~ $.M. 1~. PEP, NIIT NO. Check Appropriate Box To I,ndi'cate Nlature of Nlotice, Report, or'Other 'Data NOTICE OF INTENTION TO: TEST WATEa SHUT-OFF It PULL OR ALTER CASING FRACTURE TREAT -- MULTIPLE COMPI,ETE SHOOT OR ACIDIZE . ABANDON' REPAIR WELL CHANGE PLANS ( Other ) :' SUBSEQUENT a~POaT oF: .. FRACTURE TREATMENT J t ' ALTERING CASING SHOOTINGiOR A'CIDIZING LI Il ABANDONMENTS (Other) ~ ~'l~'J~ (No~: Rep0rt,,~esults 'of multiple completion on Well Completion or Recompletion Report and L~g form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertineut details, and give pertinen[idates, including estimated date of starting any proposed work. ,: -- ~,~,.,~ - Palled O~is Ball Valve dmm~. Perf as follows Ln Ooek~'I~et~.'i;Sands ~-.36" shots/ft ~hra tbg w~o Plag Jets in 2 ,, .. $oa~0:p :,'. I~SA"' A28~.', A657' - ~702', ~715' -~5', ~816' -~', &852' -'~7', ~7' -~9~',J'~39' -5089', 51~7' - 5~7', 52&8' - 5262', 52~' - 5285', ~2~ - 53~7', 5358' - 5368', 5399' - 5&19', 5&50' - 5~', 5~8' - 5&98', ~8 ~a~~s ~. 16. I hereby certify that ~the foregoin~ is true and correct SIGNED TITLE Dist. 0fo. Hgt. DATE ~ay 12, 1970 (This space for State office use) APPROVED BI' CONDITIONS OF APPROVAL, IF ANI': TITLE DATE See 1,nstructions On Reverse Side Appro've~l Copy Returned Form F.~'v. 9-30-67 "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PERiVIIT--" for such proposals.) 0IL WELL ~-~ GAS WELL [] OTHER 2. NAME OF OPERATOR ~ Petreleu~ Co~j~ 3. ADDRESS OF OPERATOR 515 "D" Street: knchora~-e. Al~aka 99501 4. LO'CATIOn. OF W~':~ ,T, - - · - - Atsurface L~ 2, Slot 7, 1301.~' F~L, 1020.3' ?11~ R~, 3.~.~ North Cook Inle%, Platfor~ "Yyonek" ~op of Pa.v~ 1900' MD, 3850' YVD, 850' FSL, 13. ELF. VA etc. Check A~pmpria~e ~ox ?~ l,ndlcate NIs*ure ~ N~fi'¢e, ~e. AP1 ~CAL CODE $. LEA~E DE~IGNATION ~n SEI~IAL NO. Am----17 589 ?, IF INDLA.N', .A-T-J..,Oq-r~ OR TI:J2BE NA.IVEE 8. UNIT, FARM OR LEASE NAME · _---:- _ - --ak · !et Unit 9. WELL NO. A-13 10. FIE4~D AND POOL, OR WILDCAT _- North ~k Inlet. 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) NOTICE OF INTENTION TO: / EUB~EQUENT REPORT OF: TEST WATEE SHUT-OFF PULL 0E ALTER CASING ~ ~ WATER SHUT-OFF ~' REPAIRING WELL (Other) I~ / ....... ~:~Na~i.~epor'{~result~ ~ m~tiple'eompletlon on W~ .... c~e~!on or ~ecomp~euon ~ePort and Log form.) ~5. D~SCR~Z PnOPOSEo OR CO~PLZ~ZV OPZ~O~S (Clearly sra~e ~~~ lncludtng~gstima$~d date of starting an~. all pertinent proposed work. · 5-3-70 ~-22-70 /+-23-70 /~-29-70 WIH. Drld emi & DC 5586' - 5596'. ~ to %ep ,cf float corr. k-3o-7o / 16. I hereby certit~.egolu .-'-s true au5 correct (This space f~// State office use) Tstd csg. Pan CBL. Perf esg 5538' - 5539' w/~ ~. she%s. Sqzd 125 sx Type "~" ~ i~to formation thru perfs. Kw.x. holding press, 3~. Perf esg ~2~, -~25' w/ into formation thru perfs. ~ax. hold~ press. 3~. Perf ~306' - ~307' w/A ~" shots. ~queezed 135 ex Type .,,~,, em~ into formation thru perfs. ~ax. hol~ing press, 3,~. Perf ...~.5, ~226' w/A ~" shots. Squeezed 130 sx Type "O" cement irate fer~atie~ thru perfs. Max. holding press, 3~. ~rld cut cement. TStd perfs k~..~' - ~3~'; would not hold. Squeezed perfs ~3~' -~307' 'w/i00 ax Type .~. cement; did met hold. Squeezed w/150 ax Ty~ ,~. ce~emt; did not. hold. ~eezed ~ $-x Type "0" eemen~ i~to/fern%ion thru perfs. ~h~x. holding press, 3100~. Drld out cement %°'7~55,, Tstd eSE to 2~C~ for 15 sins, held O.K. Ran ~" ~D tbg string. Set at ~1~?'~ Ra~ vat~e ~set a%:287' & tstd control lime to 5,0~, 0.X. Relea~ed,.rig. APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See 1,n:structions O'n Reverse Side Approved Cop~ Returned Per~omfing'-.-?.:',"; '1 ; No.~ 'No . : ". '. -': :.!-'_ Feet:~.::.- %. , ~' - ~ '~s~': .-' '-';4:--:~~ -¥~o-:_. __--.~,,-'~ : ~r :-~ ~,.::.~---,-: ~o~~e-~_.;- s~~:- - - · . Dale Size of Casting 5-3-70 7" 11 tl II II ti t~ ti ti Il tl tl It Il ti ti ti 11 t! ~702'. /*805' ~.8~.6,-' /*867 ' /.987' 5089, 5137' 5262' 5285' 5307' 5368' 5/,i9' 5/*60' /+~23-70 i-2&-70- '- 1-21-70 i-25-70 .~' . IES 360 -- .' :-120 >: 60 -- 2oo 120 56. 20 > ;-:-- /*657' ;- /.715' /.816'. - -- /.852.' /.977' 5039' -. 50 '. 5107' 30 '- .' 52/*8' 5280" 'i'- " ' 5358'" 10 5399' '20' 5/+50' " 10 i -- 5/.68-! "".' ; . . -.- .... . . . ~ -: _ __ _ .. - .. ...... ~ · - . - .~ -y ... .. ;~ .-... . . : -.-.. -. - .... --;. ~ - _- . - .-. - . .._ ..... 5538' '- Form REV. 9-30-6? Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservof~. Use "APPLdCATION FOR PERi. IT--" for such proposals.) 1. WELL WELL 2. NAME OF OPERATOR OTHER Phillios Petroleum Comoanv 3. ADDI:LES~ OF OP]~a, TOR - - ~15 "D" Street, Anchorage. Alaska 99501 4. LOCATION. OF W~:,,T, - - ~ ' At surface L~g 2~ Slot 7, 1301.9' F~, 1020.3' ~FL~ Sec. 6, Tl~2{, R9W, S.M., North Cook inlet, Platform "Tyonek" .Top of Paz: 4900' MD, 3850' TVD, 850' FSL, 900' ~/~, 13'-~T'~V~6N~(~E~Jw~JbF, ~:~R. etc. ~3 116 ~ From ~,~f 8. UNTO, FARIVI OR, LEASE NAME North Cook Inlet Unit 9. W~.,~L NO. A-II 10. _~'i~-~ AND POOL, OR WILDCAT North Cook Inlet 11. SEC., T., R,, M., (BOTTOM HOLE OBJECTIVE) Sec. 31~ T12N~ Rgw, S.M. 12. P~T 69-89 ~ort, or Other I~ta NOTICE OF INTENTION TO; TEST WATER SHUT-OFF ~--] PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONS REPAIR WELL CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENTS (Other) (Other) See Below ] (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. D~:scR~BSproposedPROPOSEDwork. OR COMPLETED OPERATIONS (Clearly state all pertineut details, and give pertinent dates, including estlm~i~ed date of starting an~. Re-enter-Well #A-11, run cement Bond Log, perforate and squeeze any zones'where cement no good, run tubing string, perforate Cook Inlet Sands, 4' shots/ft at the intervals shovm below. Run ~-point test and complete to produce. IES Measurements RKB: A25&' - ~28A' ~657' - 4702', ~715' - 4805' 4816' - Y~8~6' 4852' - ~867' ~977' - ~987' 5039' - 5089', 5107' ' , - 5137' 5248' - 5262' 5280' - 5285' 5289' 5307' 5358' - 5368', 5399' ' ' ' - , - 5~19'~ 5~50' - 5460', 5~68' - 5~98'. SMP Measurements RKB: ~253' - ~283', 4657' - ~702', ~715' - ~805', ~816' - 48~+6', ~852' - ~867', ~977' - ~987', 5039' - 5089', 5107' - 5137' 5250' - 5264', 5281' , - 5286', 5290' - 5308', 5359' - 5369' 5400' - 5420', 5450' - 5~60', 5~68' - 5~98'. ' (This ~for State ~ffice use,) · ITLE District Ofc. Mgr. DATE April 21, 1970 CONDITI~ONS OF APPROVAL, IF ANY: TITLE See 1,nstrucfions On Reverse Side , Approved Copy . : Returned ~ ~,,'~*~,:' ~0~ ~ ..~ ,. · DATE ... Noveltblr 19. 1969 'llk~, A-II, A-IO,, :~..t~e n. retaral~ll ,lfl~ this.' ?leaed om h ~lulea of Fn-~7 o~fhe ~lefl'~ Fa ~7~I. elm ~ ei.ll.a f!a~l'ty~? ~.. fl:I! o~lea dill., PHILLIPS PETROLEUM COMPANY ANCHORAGE, ALASKA 99501 ~ 515"D" STREET EXPLORATION AND PRODUCTION DEPARTMENT November 12, 1969 Division of Mines & Minerals Department of Natural Reso~mrces State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. T. R. MarshaL, Jr. Gentlemen: Attached, please find original and two copies of Form P-3, Sundry Notices and Reports on Wells, Chronological Well History, Sepia and Blue Line 1ES Log for NCIU Well #A-II. Yours truly, P~J._TPS PETRO~UM COMPANY /// John B. Oipson, ' ~/~ District Office Manager JBG: jo Attachments 1969 Form P~3 REV. STATE OF ALASKA Su~mit "Inten{lons" irt Triplicate "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION. COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to ih'ill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) 1. oil oas [] WELL WELL OTHER 5. API N~CAL CODE APr 50-283-20031 ;'8. LEksE DESIGNATION A/hID SElqJJLL NO. ADL-17 89 2. NAME OF OPERATOR Ph~ ] ] Cps Petroleum Compan7 3. ADDRESS OF OPERATOR 515 "D" Street., Anchora~e~ Alaska 4. LOCATION O,F WELL 99501 ?. IF INDIAN, ALLOTTEE OR TRIBE I~IA1VIE 8. UNIT, FAHiV~ OR LEASE NAME North C~k Inlet Unit 9. WELL NO. A-lA 10. Fr~r.~ PuND POOL, OR WILDCAT At-~=~ace Leg 2, Slot 7, 1301.9' FNL, 1020.3' F~L, Sec. 6, TllN, Rgb, S.M., North C~ok Inlet, Platform "Tyonek" TOp of PR.v: &900' MD, 3850' TVD, 850' FSL, ~00' F~L, See. 3i~-T12N~ R~ S.M. 13. ELEVATIONS (Show whether DF, ET, GE, etc. RKB 116' From MLLW Nerth Cook Inlet 11. SEC., T., R.", M., (BiFT'POM HOLE OBJECTIVE) Sec. 31, T12N, Rgb, B.M. 12. PEtLMtT 1~O. 69--89 Check Appropriate Box To Irnd, i,cate Nlature of N~oti'C'e, Re, mrS, or 'Other 'Dat~ NOTICE OP INTENTION TO: TEST WATER eHUT-OFF II PULL OR ALTER CASINO FRACTURE TREAT ~..jj MULTIPLE COMPLETE SHOOT OR ACIDIZE ARANDONs REPAIR WELL CHANGE PLANS WATER 8HUT-OFF ~ REPAIRING WELL J ] 8HOOTING OR ACIDIZINO [___J ABANDONMEN'T* (Other) Suspended Well (NOTE: Report results of multiple completion on Well (Other) , Completion or Recompletion,.Report and Log form ) 15. DESCRmE rROPOSEV OR CO.~tPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates including estimated date of starting any proposed work. This well has been drilled to a TVD of 6296~, MD ef 8210t:. BHL: 1820' FNL, 880, FUL, Sec. 31, T12N, R~W, $.M. The well ~s ~hen legged and ~asing was run (See Chronological Well History attached). The well will net be perferated until some later date when the well is needed. (Est.. ~-~ years) Also attached, please :find Sepia and Blue Line IRS 16. I hereby cer he fore%~ot~/l~ true and correct ('his spa e~or ~t~ tffi~e~) · ITLE ~Dist. Ofc. Manager DA~ November ~, 1969 See 1,nstrucfions On Reverse Side Approved Copy Returned CHRONOL~,,~!,CAL WELL HISTORY NCIU WELL #A-11 8-2/~--69 8-25-69 8-26/31-69 9-1/30-69 o/5/69 o/6-].3/69 6&5' 2765' 8212, 7958' PBTD Spudded 15" hole & drld to 6&5' & rind to 22". Ran 16" csg, set @ 621'. Cmtd w/&35 sx Type "G" cmt mxd in 220 bbls prehydrated &% Gel wtr. Cmt circ. Tailed in w/170 sx Type "G" cmt mxd in 22 bbls FW w/2% cc wtr. WOR. Temporarily suspended. Drld 15" hole to 2765'. Ran lO-3/&" csg. Set @ 27&5'. Cmtd w/610 sx Type "G" cmt mxd in 257 bbls &% prehydrated Gel wtr. Tailed in w/125 sx Type "G" cmt mxd in 15 bbls 2% cc wtr. Drld 9-5/8" hole to 8212'. Ran IES, FDC & SNP Logs. Ran 7" csg. set @ 8003". Cmtd 1st stage w/333 sx Type "G" cmt mxd in 107 bbls 20% Diacel "D" mxd in FW. Cmtd 2nd stage w/898 sx Type "G" cmt mxd in 111 bbls 2% cc FW. Temporarily suspended. This well has been logged and csg run. The tbgwill not be run in this well and the well willnot be perforated until some later date when the well is needed. Form No. P--4 REV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT IN DUPLICATE 1. ~. NAME OF OPERATOR Phtl~ps Petroleum Company 3. ADDRESS OF OPEP,.ATOR 515 "D" Street ~.. Anchorage, Alaska 99501 4.LOCATION OF WELL Surface: Leg 2, Slot 7, 1301.9' FNL, 1020.3' FWL, Sec. 6, TllN, R9W, S.M., North Cook Inlet, Platform "Tyonek" Top of Pay: ~9OO' MD, 3850' TVD, 850' FSL, 900' FWL, Sec. 31, T12N, R9W, S.M. %. API NUA~[ERIcAL ~(~DE T?,...~A. ~A -- ~I 50-283-2~31 6. L~SE DESIG~A~ON AND S~ AD~17589 7. IF I~DIA~, A~T~E OR ~IB~AM~ 8. L~IT,F.~{ O~ LEASE ~.~E ~o~h Cook I~g 9. WELL NO. 10. FT'~.T~I~ A-ND POOL, OR WILDCAT North Cook Inlet 11. SEC., T., R., A~., (BO/'FOM HOLE Sec. 31, T12N, R9W, S.M. 12. PEEA,IIT NO. 69-89 13. REPORT TOTAL DEPTH AT END OF MONTH, CITA_NGES IN HOLE SIZE, CASING AZ~T) CE1V~EN'IUNG JOBS INCLUDING DEPTH SET AN~ VOL~ USED, PERFO.i:~TIONS, TESTS ~ RESULTS. FISHING JOBS, JLrNK IN HOLE A_ND SIDE-TIq~CKED HOLE AND ANY OTHER SIGNIFICANT CI-IAN-~ES IN HOL~ CONDITIONS. 10/31/69 7958' PBTD This well has been logged and csg run. The tbg will not be run in this well and the well will not be perforated until some later date when the we~ is ne eded. 2765' Drld 15" hole to 2765'. Ran lO-3/&" csg. set @ 27&5'. Cmtd w/610 sx Type "G" cmt mxd in 257 bbls h% prehydrated Gel wtr. Tailed in w/125 sx Type "G" cmt mxd in 15 bbls 2% cc wtr. Om% circ. Drld 9-5/8" hole to 8212'. ', o/::U,.-::LS/69 10/16-31/69 Ran IES, FDC & SNP I~gs. Ra~ 7" csg. Set @ 8003'. Cmtd 1st stage w/333 sx Type "G" cmt mxd in 107 bbls 20% Diacel "D" mxd in FW. Cmtd 2nd stage w/898 sx Type "G" cmt mxd in 111 bbls 2% cc FW. Temporarily suspended. 14. ! hereby ce~i~ %h~t the ,o~oinA ~trut and correct with tl~e Division of Mines & Minerals by the 15th of the succeeding month, un ess otherwise directed. PHILLIPS PETROLEUM ANCHORAGE, ALASKA 99501 ~ 515 ~'D" STREET EXPLORATION AND PRODUCTION DEPARTMENT COMPANY October 23, 1969 Mr. T. R. Marshall, Jr. Division of Nines and Minerals Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 9950~ Dear Mr. Marshall: Enclosed, please find two copies each of Report of Sub-Surface Directional Survey, Phillips Petroleum Company, Platform ,,A", Well #A-II, North Cook Inlet, Alaska. Sincerely, , LLIPS PETROLEUM COMPANY District .Office ~hmager JBG: Jo Attachments (2) Fo~ No. REV. S-~ STATE OF ALASKA SUBMrr IN DUPLICATE _ 5. AP1 NUMERICAL CODE HLB - TRM OKG -.-~ _ KLV OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS REL WELL ~'ELL 2. NA/~E OF OP~TOR 8. L~.'IT,FA/RA{ OR LEASE N.~ME Phillips Petroleum Company North Cook Inlet Unit g. WELL NO. 3, ADDRESS OF OPE~q. ATOR 515 "D" Street, ~nchorage, A~ska 99501 4. LOCATION OF WELJ~ Surface: Leg 2, Slot 7, 1301. O' FNL, 1020.3' FWL, Sec. 6, TI/N, RgW, S.M., North Cook Inlet, Platform "Tyenek" Top of P~V: ~900' MD, 3850' TVD, 850' FSL, 9OO' FUL, Sec. 31, T12N, R9W, S.M. ADL-17589 - ?. IF INDIA]~, ALOTTEE O]{ FILE ;., I0. F~ A. ND POOL. OR WILDCAT 1L-SEC., T.,-~.., M., (BOTTOM HOLE OBJF_,CTrV~ , Sec. 31,. T12N, R9W,, S.M. 12. PERMIT NO. 6q-~9 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET ~ VOLLrMF-~ USED, PERFO'~TIONS, TESTS ANT) RESULTS. FISHING JOB~, JU/~K IN HOLE AiWD SIDE-TI:LACKED HOLE A~NT) A/~Y OTHER SIGNIFICA/%IT CI-IA/~ES IN HOL~ CONDITIONS. Temporarily Suspended. ~ !,tI.SION OF OIL AN~ GAS 14. I hereby ~ the fore ~g ' ~~ sm~ , ~ Dist. 0lc. ~r. D~E October 1~ 1969 , , L/, ,~ ' ~ V ~0T[--~eport on this form ~s ~e~u~ed fo~ each ca;e~da~ momb, ~ega~dless of the statu~ of operations, a~ must ~ flied ~ d~]cat w~t~ the D~v~s]o~ of M]~es & M]~e~a!s b~ the 15th o{ t~e succeedi,9 mo,th, u,~ess othe~ise d~ected. lSo~ No. P--4 STATE OF ALASKA SUBM~ n~ D~LZCAr~- OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WOR'KOVER OPERATIONS 1. o,L [2 °" [] NAME OF OPERATOR Phillips Petroleum Company 3. ADDRESS OF OPER.~TOR 515 "D" Street, Anchorage, Alaska, 99501 4. LOCATION OF WF-J~L Surface: Leg 2, Slot 7, 1301.0' FNL, 1020.3' ~L, Sec. 6, TllN, R9W, S.M., North Cook Inlet, Platform "Tyonek" Too of Pay: ~900' MD, 3850' TVD, 850' FSL, 900' ~.~L, Sec. 31, T12N, R9W, S.M. 8. L~I%-'IT,FA3t~i OR LEASE N.~ME NQr~H O0ok ,, Inlet ,Unit 9. %VET.T. NO. 10. FTF. I~r~ AND POOL. OR WILDCA.T North Cook Inlet 11. SEC., T., R., Ai., (BOO-rOM HOLE oamcr~) Sec. 31, T12N, R9W, S.M. 11. PIER.MIT NO. 69-89 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMEN'YiNG JOBS INCLUDING DEPTH SET AI~TD VOLUMES USED, PERFO.I:L~TIONS, TESTS ~ i~ESULTS. FISHING JOB8, JU/~K IAI HOLE A_ND SIDE-TI:L~CKED HOLE AND A/%TY OTPIER SIGNIFICAx%TT ~GF_~ IN HOLIil CONDITIONS. 8-31-69 6 5, WOR. 8-2/+-69 Spudded 15" hole & drld to 6~5' & rind to 22'. 8-25-69 Ran 16" csg, set @ 621', cmtd w/435 sx Type "G" cmt mxd in 220 bbls prehydrated ~% Gel wtr. ~t circ. Tailed in w/170 sx Type. "G" cmt mxd in 22 bbls M~ w/2% cc wtr. 8-26/31--69 6L~5' WOR. 1 1969 DIVISION OF OIL AND GAS ANCHOliAGE , , s.,s~ _--3~z.~-~ ~ /.~', '.~.Z~ ==,.~. District Cfc. ~ager , ~.~, September ~, 1969 ~OTE--Report on this form is required or each calendar month, regardless of the status of operations, and must ~ filed in duplicate with the Division of Mines b Minerals by the 15th of the succeeding month, unless othe~ise directed. September 9, 1969 John B. Gipson District Office Manager Phillips Petroleum Company 515 D Street Anchorage, Alaska 99501 .Re' North Cook Inlet, #A-11 Phillips Petroleum Co., operator Dear Sir' In reference to the subject offshore drill-site the following sti. t)ulations are required to protect fish and game resources' 1. No material foreign to tile environment will be discharged from this platform. This includes garbage, trash, refuse, petroleum and/or its products, drilling mud, and debris. nt~.r~er~ with commercial fishing 2. Drilling operations are not to i ~ '° * 3. This office should be notified prior to abandonment of this location. Statement' The foregoing provisions cio not relieve the lessee and/or his con,~rac~or~ or assignees of any responsibilities or provisions required law or regulation, of the State Of Alaska or the federal gov.~'~n Si ncerely yours, L Habi~a~ Biologis'8 cc' B. Hi!liker H Bt.!rrell P. Denton ~r, lktvielen ~t&te of ~ ~ M. Fifth the ~abJo~t dll ~ ~ on ~tate A.M. ~, X~9. The ea~&ee ~ a bette~ h~le leca%ien Di~mm e~ bi & b~ ~te of Alaaka SUBMIT IN ruct~i~ (Other inst ~ reverse side) .TE 50-283--20031 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLIJ~ BACK DRILL J]J DEEPEN F-] PLUG BACK J-J OIL [] OA~i FI~ SINGLE [~ MULTIPLE ~_~ WELL WELL OTHER ZONE ZONE '8. ~IT~FA~ OR ~E N~ 2. NA~ OF OP~TO~ No~h ~k I~t U~t P~ips P~t~le~ ~~ ~. ~o. .t~u~ 3~t 7, 1301.0' ~, 10~.3' ~, Sec. 6, T~, Ne~h ~k I~et R~, S.N., Ne~h ~k I~et, P~tfe~ "~nek" n, s~c., ~., ~., ~., (~o~o~ T~N, RgW. ~. DICTatE IN MfLES AND D~ECTION F_IOM NEAREST ~WN OR.POST OFFICE~ ~,5 ~s ~st e~,~nek, ~~ 14. BOND INFO~A~ON: H~~ State ~de ~nd ~-1 .' TYPE ~uretyr and/or No. ~o~t 15. DISTANCE F~O~ ~RO'~O~E~~t'" ' ' ~'' il6. ~O. OF ~ IN LEA~E:'~ 1~. NO.,,AO~ A~I~N~ ~CATION TO NEAREST J TO ~iS WELL PROP~TY OR LEASE L~E, FT[ ::, :.-~, . / , . . (*~ to nearest dria. unit, if any) ~0[ ~ ~ ~,. o~s~.~ci ~o~ ~o~os~o ~O~A~O~. 11~. ~o'~os~O~ ' ..... ' ~0. ~o~,~ o~ ~,~ ~oo~ TO NEAREST WE~L D'~ILLING,,COM~LET~, J'J 8150' ~ 2l, ELEVATIONS (Show whether DF, HT, ~R, ere,) '~. APPROX-, DATE WORK WILL Sec. 31, T12N, RgW, S.M. 12. SIZE OF HOLE SIZE OF cAS'lNG ':WEi~HT':~ER';~': '~RAt~E! ~ r"i *;'sETT[N~ DEPTH ' · ~,, ~. &~ '~0 ~00' ctre'~e ~o:s~faoe .... 1. Deviatien reqUi~d:~'~:'rea~eh' BltL<freTM perm~-~Uen% p~tfoxin- 2. There are no"'~ffecte~ eperat0rs;~ .... 3. BOP ~pe¢ification attached. Intervals ef..interes$1~tri~l!:, be perforated and may be striated. * Refer te Stare'Cf ~~;' AlaSka 0il &:Gas °°nSe~atien ~emmlttee, Conservation Order #~0, dated 6-8-67 and #68, dated 12-7-68. NOTE: BHL: 2100' FNL, 70~' FWL, ~ec. 31, T12N, RgW, ~ ABOVE SP~ D~BE ~OPOS~ P~GR~: If ~1 ~ ~ dee~n o.r plug ~, give ~ on present p~u.~ive ~ ~d proposed ~ produ~ive ~e. If pr~ ~ ~ drill or d~n d~e~on~ly, give pe~inent ~ on subsu~a~ ~a.t~ ~d meas~d ~d ~ue ve~¥ dept. Give blo~uL preventer program. 24. I hereby~~~~that lhe Forego~ I .is ~e ~d Corre~. ' (Thissp~ex~teo,~i~u~),__ -- CONDI~ONS OF ~P~V~, IF A~: [ S~L~D CORE cmos RE~U~ [ ~ ~U~TS: u Y~ ~'~o [ See ~ansmittal Letter [ DI~CTION~ SURVEY ~~ [ A.P.I. ~C~ CODE ~<~ ~f..o ~< / //~ / Executive Se-'.}~ConservationAlaska Oil & GaScomitt~A~ Aug, 22~ APPROV~ B ~'//yQ' *See [.~*~., O. ii ROP BHL A-II 36 31 PROP. B.H.L A-IO~ . / ,oo ', TO~OFPAY /. ~ ' 850 ES~-9Op'F.W~. ~ . A'5 " ' ' '',,~ A 8 ~A-I / o 350 F. SL-2550 FW.L PHILLIPS , '- , ', ~,,' . . I 2650 F.S.L:6 ' // ~ -4 PRO~SED B.H.~ A- 9 Sec. I-lIN-lOWS M ~' ~200 ~S.~=~O0 ~.~. ~-/ / X _ ~ ~7~/ A-70 4~Z /7~ / · , / ,, ~ ,, , , 18 _ i i ii] i i i i i i $2 8 l II 4DL /87'.¢/ GRID PHILLIPS PETROLEUM COMPANY 5i5 "D" STREET ANCHORAGE ,ALASKA PLAT OF NORTH COOK INLET UNIT TYONEK PLATFORM , I SCALE' 1"=2000' D~W~' ~: id' ~{'"':1 .... I t:)AT ~: 'S-~ 0 :..6 9 · IL II ~ Leg 4 · North Cook Inlet Unit · N.C.I. Un. A~ · "'c'"u~'~-'~L~' Leg 3 N.C.I. Un.A-8"~~ , (~/ · ,.c.,. ~N.C.I. Un. A-9 iii i i i i i ii PHILLIPS PETROLEUM COMPANY 515 "[~' ,STREET 'NORTH COOK INLET TYONEK PLATFORM COOK INLET, ALASKA NOTE: using' PLA~"F'~DRM' NORTHi"S't'ot'No.! furthest plc~tform North slot in platform Ncrth- west quadrant of any leg; Slots ~re numbcred 1 thru $ in a counter-clock-wise direction. PLATFORM LOCATION; Sac. 6-1.1N-gW' J. DATE: 6-20-~ [DRWN. N.~J:' 'P~w*ll ...... j[ NOT TO SCALE Double Preventers are u,,~d with rbXnged side Outlets for choke ]~mnlfold and fillup 15ne connections.. . . ~ . · . ~ BLO,,,'OU 1 PR ""-' I. '. -;.,'-~ h' I ! f') ,:v ~:,~ In,-,, ,',~-...,,,-,..- (SERIES 1500 FI.A,.,.:.=., 0:~ P.,:-1'I'EF:),: o ; REV. ::,li!/C..,~ SC~'.~O',.,Lr.;. E _ · , 12 7- LEG Ng. I 975" 12 N SCALE I"'= 1,000" LAT. 6t© 04' 36.38" LONG.150° 56' 55.63" Y: 2,586,731 X= 331,995 FROM N.W. COR. 1,250' SOUTH & 975' EAST. 6 5 ,. 6 5 .......~ 7 8 LEG N°-. 4 LEG N°. 2 LAT. 6t° 04' 36.89" LAT. 6t° 04' 35.83" LONG. 150° 56' 54.25" LONG. 150° 56' 54.77" Y= 2¢86~781 Y= 2~586~ 674 X=, 332,063 X= 332,036 FROM N.W. COP. FROM NW. COR. 1,t98' SOUTH & 1~305'SOUTH & 1~045' EAST. ' 1~018' EAST. LEG N-~ 5 LAT. 6t~ 04' 36.34"' LONG. 15CP 56' 53.39" Y= 2., 586,724- X= 332,105 FROM N)N. COR. 1,254.' SOUTH & 1,085' EAST. NOTE: Plat emended 7AUG.68' to show revised leg numbering. CERTIFICATE OF SURVEYOR i hereby certify that I am properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me or under my supervision and that ali dimensions and other details are correct. NOTE The iccation of ,h ~..e platform legs was eccomplished by using tri~n9u;~tion stations BELUGA,TERRACE,and TYONEK which are ,mil U.S.C.&G.S. stations. Aft coordinates are Alaska State Plane, Zone 4. P L NORTN COOK PLA'TFORNi PHILLIPS PE:;~O~_~_~¢M CO ~¢A~ ~_. 21 JUNE I PM. !_I ....... c ....~:.~ A.SSOQ SCALE: F'i I000' FB. i1374 PP. Il-t5 l. Lci~d ~,Surveyors ........... ~ 250Z w ~ORi'~ECNL. iSH~: 8LV3. DRW N. CHKD. t C.C. PROP BH.L A-II Se. i.-~2N- W ~. · 36 31 PROP. B.H.L. A-lO /x Sec, D! - 12 N-9W S. ~ / 2100 RSJ..-- IO00'F. Et % I ' ~'%~, ~' ~ i ' TO.P, OF PAY ,'. "~ \ 850 F.S~.-9OO'F. WJ_. · ~ · 0 i ' ,. ~. A-5 ' ' ~,,. ' ~ ¢6~ ' TOP 0 F PAY , - ' ' "-../A-8 ~.A-I ? , o~50' F.s~.-2550 F.W.L PHILLIPS '* q~-,.. ~ ", t J ~PHILLIPS ~ . · . ~ / / ',.. ~ F.~' ' TOP 9F PAY / ~A- I ~650 F.S.L:S ' / -~,, 4 PROPOSED B.H.~ A-9 Sec !~ Ii N- IOW S M , oo / ~DL . / 12 , ~ 7 . . , 18 ANCI.-IOI~gE 5 A DZ. GRID PHILLIPS PETROLEUM COMPANY 515 "~' STREET ANCHORAGE ~ALASKA , PLAT OF NORTH COOK INLET UNIT TYONEK PLATFORM DRWN.'N. ,,I, Powell J$c ALE:'"'I" = 2000' I ~'A'T"C~'. '~'~' : ...... Company Lease & Well No. /-'//'~{~ --x~'~_// - . ~ .. Ci~ECK LIST FOR NEW WELL PERMITS ~ --,~'i~ ~'..i- ,~- ~..-.i-i ~_-'.' _'i'i;?~.'; yes .o Zs well to be located in a defined pool.''~. ~ .', '. '..'~. , ,-~-._~i.,,.. ..~'. . .~ '.'~' . ..~- Remarks Well Histow File APPENDIX Information of detailed nature that is not . particularly germane to the Well Permitting Process ... but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this natum is accumulated at the end of the file under APPENDIX~ '-' No special'effort has been made to chronologically organize this category of information. Memory Multi-Finger Caliper Log Results Summaw Company: Phillips (Alaska) Inc. Well: A-11 Log Date: November 30, 2001 Field: Cook Inlet Log No.: 4282 State: Alaska Run No.: I APl No.: N/A Pipe Desc.: 3.5" 9.2 lb. N-80 Top Log Intvl: 4,075 Ft. (MD) Pipe Use: Tubing Bot. Log Intvl: 5,690 Ft. (MD) Inspection Type: Corrosive Damage Inspection COMMENTS: This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate that the tubing is in good to fair condition. The caliper recorded a hole at 4,979 ft. The caliper readings indicate wall penetrations ranging from 20 to 29% wall thickness recorded throughout the rest of the interval logged. The damage appears in the forms of isolated and shallow pitting. No areas of significant cross-sectional metal loss or areas of significant ID restriction are recorded throughout the interval logged. The distribution of corrosive penetrations recorded throughout the tubing string is illustrated in the Body Region Overview sheet of this report. MAXIMUM RECORDED WALL PENETRATIONS: Hole (100%) Jt. 35 @ 4,979' MD Isolated Pitting (29%) Jt. 33.1 @ 4,890' MD Corrosion (28%) Jt. 34 @ 4,913' MD Isolated Pitting (28%) Jt. 46 @ 5,188' MD Isolated Pitting (34%) Jt. 55 @ 5,384' MD MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall-loss (in excess of 8%) are recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS: No areas of significant ID restriction are recorded throughout the interval logged. Field Engineer' S. Adcock Analyst: M. Lawrence Witness: A. Worthington ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Well: Field: Company: Country: Tubing: A-11 Cook Inlet Phillips (Alaska), Inc. USA PDS Report Overview Nom.OD Weight Grade & Thread 3.856 ins 15 ppf BI Jt 3.5 ins 9.2 ppf N-80 Body Region Analysis Survey Date: November 29, 2001 Tool Type: MFC24 No. 99812 Tool Size: 1.69 No. of Fingers: 24 Analyst: M. Lawrence Nom. ID Nom. Upset Upper len. Lower len. 2.992 ins 3.856 ins 6.0 ins 0.0 ins 2.992 ins 3.5 ins 6.0 ins 0.0 ins Penetration and Metal Lo~s (% wall) mm penetration body ~ metal loss body 80 60 40 20 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 74) pene. 0 56 10 7 0 1 loss 9 64 0 1 0 0 20 10 0 Damage Configuration ( body ) isolated general line ring hole / poss pitting corrosioncorrosioncorrosionible hole Number of joints damaged (total = 25) 15 7 2 1 0 Damage Profile (% wall) penetration body ~ metal loss body 0 50 100 0 · £- ? 17 34 53 Bottom of Survey: 69 Analysis Overview page 2 Description · Holes in Tubin~ Blast Joint Blast Joint PDS Multifinger Caliper 3D Gompany' Phillips Alaska Well · A-11 Detail of recordings near Hole recorded @ 4,979' Log Plot Field * North Cook Inlet Unit Date · November 29, 2001 ~ Company * Phillips Alaska Field * North Cook Inlet Unit Well * A-11 Date · November 29, 2001 Description · Detail of Recordings through 3.5" Sliding Sleeve @ 4,318' (Closed) Tu~ng Slidi~ ~lg , ~SmON Page 1 Description · PDS Multifinger Caliper 3D Log Plot Company ' Phillips Alaska Field · North Cook Inlet Unit Well ' A-11 Date · November 29, 2001 Detail of recordings through 2 718" Sliding Sleeve @ 4,896' (Open) Tu~ , S~ in OP~ ~S~ON Sli~ng ~10 ~ , ....... Page 1 :! PDS Muitifinger Caliper 3D Log Plot Company' PhillipsAiaska Field · North Cooklnlet Unit Well · A-11 Date · November 29, 2001 Description · Detail of recordings through 2 718" Sliding Sleeve ~ 5,171' (Closed) Comment Tubing 5182 sIi~ S~ ~W. Page 1 Description · PDS Multifinger Caliper 3D Log Plot Company · Phillips Alaska Field · North Cook Inlet Unit Well · A-11 Date · November 29, 2001 Detail of recordings through 2 718" Sliding Sleeve ~ 5,536' (Closed) C~rnment TuU~ Sli~ng S~ ~. CLOSED ~SmON Slidin~ s~ ~. Tu~ Pa~e 1 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 ins 9.2 ppf N-80 Wall thickness: Body = 0.254 ins Upset = 0.254 ins Nominal ID: 2.992 ins Well: A-11 Field: Cook Inlet Company: Phillips (Alaska), Inc. Country: USA Survey Date: November 29, 2001 penetration body metal loss body Joint Penetration Metal Projection Minimum Damage Profile No. Upset Other Body Loss Cplng Body ID Comments (% wall) inches inches inches % % inches inches inches 3 50 101 .1 0 0 0 0 0 0 0 N/A PACKER 1 0 0 .05 19 4 .12 .04 2.86 Shallow pitting. 1.1 0 0 0 0 0 0 0 N/A X Nipple 2 0 0 .02 9 3 0 .04 2.91 · 2.1 0 0 0 0 0 0 0 N/A OVERSHOT 3 0 0 .02 9 4 0 0 2.97 3.1 0 0 0 0 0 0 0 N/A PACKER 4 0 0 .01 5 3 0 .04 2.96 5 0 0 .03 12 4 0 .04 2.94 6 0 0 .02 5 2 0 .03 2.92 Blast Jr. 7 0 0 .04 9 2 0 .07 2.89 Blast Jt. Shallow pitting. 8 0 0 .03 10 2 0 0 2.93 8.1 0 0 0 0 0 0 0 N/A SLIDING SLEEVE 9 0 .02 .01 5 4 .07 .04 2.90 9.1 0 0 .02 6 4 0 0 2.93 PUP 9.2 0 0 .02 7 4 0 .04 2.93 PUP I 10 0 0 .02 8~ 4 .07 .04 2.87 11 0 0 .02 81 6 0 .04 2.87 Pitting. 12 0 0 .02 9 7 .02 .05 2.89 Line corrosion. Lt. Deposits. 13 0 0 .03 12 4 0 .04 2.90 Shallow pitting. 14 0 0 .02 9 4 0 .04 2.92 15 0 0 .02 9 4 0 .04 2.89 16 0 0 .01 6 3 0 .04 2.90 17 0 0 .02 7 4 0 .04 2.86 17.1 0 0 0 0 0 0 0 N/A PACKER 18 0 0 .03 12 5 .08 .06 2.84 Lt. Deposits. 19 0 0 .03 6 3 0 0 2.88 Blast Jr. 20 0 0 .01 3 2 0 0 2.89 Blast Jt. 21 0 0 .02 4 2 0 0 2.91 Blast Jr. i 22 0 0 .01 3 2 0 0 2.88 Blast Jt. 23 0 0 .02 5 3 .08 .03 2.88 Blast Jt. 24 0 0 .03 6 5 0 .03 2.87 Blast Jt. 25 0 0 .04 9 2 0 .08 2.85 Blast Jr. Shallow pitting. 26 0 0 .03 8 6 0 .04 2.87 Blast JL Shallow corrosion Lt. Deposits 27 0 0 .03 6 3 0 0 2.90 Blast Jr. 28 0 0 .02 4 1 0 .04 2.92 Blast Jr. 29 0 0 .02 5 1 0 .08 2.90 Blast Jr. 30 0 0 .03 7 3 0 0 2.91 Blast Jr. 31 0 0 .01 2 1 0 0 2.91 Blast Jt. 32 0 0 .01 3 1 0 .04 2.89 Blast Jr. 33 0 0 .07 17 2 0 .04 2.91 Blast Jt. Shallow pitting. 33.1 0 0 .07 29 4 0 .05 2.90 PUP Isolated pitting. Lt. Deposits. 33.2 0 0 .03 13 5 0 .10 2.90 PUP Shallow pitting. Lt. Deposits. 33.3 0 0 0 0 0 0 0 N/A SLIDING SLEEVE 34 0 .04 .07 28 9 .11 .11 2.81 Corrosion. Lt. Deposits. 34.1 0 0 0 0 0 0 0 N/A PACKER 35 0 0 .35 100 34 0 .10 2.86 HOLE! 36 0 0 .02 4 1 0 .04 2.89 Blast Jt. 37 0 0 .01 2 2 0 0 2.90 Blast Jt. 37.1 0 .07 .06 24 5 .07 .06 2.91 PUP Isolated pitting. Lt. Deposits. Pipe Tabulations page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 ins 9.2 ppf N-80 Wall thickness: Body = 0.254 ins Upset = 0.254 ins Nominal ID: 2.992 ins Well: A-11 Field: Cook Inlet Company: Phillips (Alaska), Inc. Country: USA Survey Date: November 29, 2001 penetration body metal loss body Joint Penetration Metal Projection Minimum Damage Profile No. Upset Other Bod~ Loss Cplng Body ID Comments (% wall) inches inches inches % % inches inches inches 3 50 10~ 38 .03 0 .06 24 5 .05 .09 2.88 Corrosion. Lt. Deposits. 39 0 0 .02 5 1 0 0 2.91 Blast Jt. ~ 40 0 0 .04 10 8 0 .05 2.87 Blast Jt. Shallow corrosion. ~ 41 0 0 .01 2 1 0 0 2.91 Blast Jt. 42 0 0 .03 7 2 .05 .06 2.91 Blast Jt. · 43 0 0 .01 3 1 0 .06 2.89 Blast Jt. I 44 0 0 .02 4 1 0 .06 2.90 Blast Jr. I 45 0 0 .04 14 6 0 .13 2.85 Shallow pitting. Deposits. ~ I 45.1 0 0 0 0 0 0 0 N/A 'SLIDING SLEEVE 46 0 0 .07 28 7 0 .06 2.86 'Line corrosion. Lt. Deposits. ~ 46.1 0 0 0 0 0 0 0 N/A PACKER 47 0 0 .04 16 6 .07 .06 2.87 Shallow pitting. Lt. Deposits. ~· 48 0 0 .02 5 3 0 .04 2.91 Blast Jt. 49 .03 0 ,05 11 2 .06 .06 2.91 Blast Jt. Shallow pitting. /~ 50 0 0 .03 8 3 0 .04 2.89 Blast Jt. Shallow pitting. [] 51 0 0 .02 4 4 0 .05 2.88 Blast Jt. 52 0 0 .04 10 5 0 .05 2.90 Blast it. Shallow corrosion. I 53 0 0 .04 9 4 0 .05 2.90 Blast Jt. Shallow pitting. I 54 0 0 .03 6 3 0 0 2.87 Blast Jt. I 55 .10 .09 .10 24 4 .07 .07 2.87 Blast it. Corrosion. 56 0 0 .03 6 3 0 .06 2.89 Blast Jt. ~ 57 0 0 .01 2 3 0 .05 2.88 Blast Jt. 58 0 0 .03 8 4 0 .05 2.85 Shallow pitting. ~ 59 0 0 .03 6 4 0 .06 2.89 Blast Jt. I 60 .02 0 .02 5 3 .06 .07 2.87 Blast Jt. 61 0 0 .01 3 2 0 .05 2.90 Blast Jt. 62 0 0 .02 5 2 0 .06 2.91 Blast Jt. ii 63 0 0 .02 6 3 0 0 2.92 Blast Jt. I 64 0 0 .06 24 6 0 .27 2.77 Isolated pittin8. Deposits. ~ 64.1 0 0 0 0 0 0 0 N/A SLIDING SLEEVE 65 0 0 .01 4 3 0 ,04 2.87 I 66 0 0 .04 17 6 .10 .07 2.84 Shallow corrosion. Lt. Deposits. ~ []: 67 0 0 ,02 9 3 .11 .06 2.87 Lt. Deposits. 68 0 0 .01 6 3 0 .04 2.85 ~ 69 0 0 ,02 6 4 0 .19 2.87 Deposits. ~1 Damage classification scheme Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 50% of circumference, but depth range does not exceed 2 * pipe ID Line - damage depth range exceeds 6 * pipe ID, but extends less than 20% of circumference. General - damage depth range exceeds 2 * pipe IDand/or extends more than 20% of circumference. Isolated - damage depth range does not exceed 6 * pipe ID or extend more than 20% of circumference. Damage reporting threshold = 30 thou inches deviation in body, 50 thou in coupling. Modal line length -- 0.550 feet. Pipe Tabulations page 2 Well: A-11 Field: Cook Inlet Company: Phillips (Alaska), Inc. Country: USA Tubing: 3.5 ins 9.2 ppf N-80 PDS Report Cross Sections Survey Date: November 29, 2001 Tool Type: MFC24 No. 99812 Tool Size: 1.69 No. of Fingers: 24 Analyst: M. Lawrence Cross Section for Joint 35 Tool speed: 37 Nominal ID -- 2.992 Nominal OD: 3.500 Remaining wall area = 67 % Tool deviation -- 43 o at depth 4979.44 ft Finger 5 Penetration = 0.346 ins HOLE! HIGH SIDE = UP Cross Sections page 1 PDS REPORT JOINT TALLY SHEET Pipe: 3.5 ins 9.2 ppf N-80 Wall thickness: Body = 0.254 ins Upset = 0.254 ins Nominal ID: 2.992 ins Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches .1 4074.11 22.87 N/A N/A 2.992 3.500 packer 1 4096.98 31.02 3.035 3.029 2.992 3.500 1.1 4128.00 1.59 N/A N/A 2.992 3.500 xn 2 4129.59 30.52 3.045 3.043 2.992 3.500 . .2.1 4160.11 1.29 N/A N/A 2.992 3.500 ovrsht 3 4161.40 19.89 3.030 3.029 2.992 3.500 3.1 4181.29 6.74 N/A N/A 2.992 3.500 [packer 4 4188.03 29.00 3.021 3.018 2.992 3.500 5 4217.03 30.17 3.025 3.025 2.992 3.500 6 4247.20 19.73 3.004 3.007 2.992 3.856 7 4266.93 19.94 3.010 3.007 2.992 3.856 8 4286.87 31.15 3.015 3.010 2.992 3.500 8.1 4318.02 3.82 N/A N/A 2.992 3.500 sldngslv 9 4321.84 29.10 3,012 3.008 2.992 3.500 9.1 4350.94 10.02 3.004 3.006 2.992 3.500 pup ...... 9.2 4360.96 12.11 3.018 3.020 2.992 3.500 pup 10 43 73.07 30.22 3.021 3.016 2.992 3.500 11 4403.29 30.75 3.025 3.022 2.992 3.500 12 4434.04 28.72 2.999 3.005 2.992 3.500 13 4462.76 29.95 3.004 3.003 2.992 3.500 14 4492.71 30.85 3.023 3.018 2.992 3.500 15 4523.56 30.20 2.998 2.995 2.992 3.500 16 4553.76 30.87 3.003 3.000 2.992 3.500 17 4584.63 28.87 2.980 2.976 2.992 3.500 17.1 4613.50 6.99 N/A N/A 2~992 3.500 packer 18 4620.49 30.84 2.999 2.996 2.992 3.500 19 4651.33 9.78 2.949 2.954 2.992 3.856 20 4661.11 9.69 2.957 2.960 2.992 3.856 21 4670.80 9.85 2.968 2.970 2.992 3.856 22 4680.65 19.75 2.957 2.957 2.992 3.856 23 4700.40 19.79 2.957 2.958 2.992 3.856 ,, 24 4720.19 21.33 2.973 2.968 2.992 3.856 25 4741.52 20.02 2.970 2.966 2.992 3.856 26 4761.54 20.14 2.935 2.935 2.992 3.856 27 4781.68 20.27 2.964 2.966 2.992 3.856 2.8 4801.95 9.69 2.972 2.973 2.992 3.856 Well: Field: Company: Country: Survey Date: A-11 Cook Inlet Phillips (Alaska), Inc. USA November 29, 2001 Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 29 4811.64 9.46 2.973 2.975 2.992 3.856 30 4821.10 20.12 2.965 2.965 2.992 3.856 31 4841.22 19.72 2.968 2.969 2.992 3.856 32 4860.94 19.89 2.973 2.972 2.992 3.856 33 4880.83 5.99 2.997 2.997 2.992 3.856 33.1 4886.82 10.10 2.989 2.994 2.992 3.500 pup 33.2 4896.92 9.93 2.995 2.994 2.992 3.500 pup 33.3 4906.85 4.09 N/A N/A 2.992 3.500 sldngslv 34 4910.94 31.29 2.968 2.965 2.992 3.500 34.1 4942.23 7.72 N/A N/A 2.992 3.500 packer 35 4949.95 30.67 2.976 2.972 2.992 3.500 36 4980.62 9.79 2.956 2.955 2.992 3.856 37 4990.41 9.71 2.960 2.964 2.992 3.856 37.1 5000.12 12.22 2.978 2.980 2.992 3.500 pup 38 5012.34 31.03 2.989 2.983 2.992 3.500 39 5043.37 19.80 2.968 2.967 2.992 3.856 40 5063.17 20.20 2.937 2.939 2.992 3.856 41 5083.37 19.86 2.969 2.969 2.992 3.856 42 5103.23 9.82 2.984 2.981 2.992 3.856 43 5113.05 19.88 2.961 2.959 2.992 3.856 44 5132.93 20.04 2.961 2.960 2.992 3.856 45 5152.97 29.42 2.981 2.979 2.992 3.500 45.1 5182.39 4.06 N/A N/A 2.992 3.500 sldngslv 46 5186.45 30.71 2.966 2.965 2.992 3.500 46.1 5217.16 7.59 N/A N/A 2.992 3.500 packer 47 5224.75 28.82 2.967 2.969 2.992 3.500 48 5253.57 22.09 2.990 2.991 2.992 3.856 49 5275.66 6.23 2.990 2.992 2.992 3.856 50 5281.89 20.25 2.969 2.970 2.992 3.856 51 5302.14 20.28 2.984 2.986 2.992 3.856 52 5322.42 9.84 3.037 3.040 2.992 3.856 53 5332.26 30.97 3.023 3.019 2.992 3.856 54 5363.23 19.88 2.984 2.985 2.992 3.856 55 5383.11 10.55 3.024 3.025 2.992 3.856 56 5393.66 11.99 3.025 3.025 2.992 3.856 57 5405.65 9.82 2.990 2.992 2.992 3.856 Joint Tally page 1 PDS REPORT JOINT TALLY SHEET Pipe: 3.5 ins 9.2 ppf N-80 Wall thickness: Body = 0.254 ins Upset = 0.254 ins Nominal ID: 2.992 ins Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 58 5415.47 20.25 2.971 2.974 2.992 3.856 59 5435.72 10.74 3.021 3.020 2.992 3.856 60 5446.46 10.23 3.005 3.006 2.992 3.856 61 5456.69 19.91 2.971 2.971 2.992 3.856 62 5476.60 19.70 2.972 2.972 2.992 3.856 63 5496.30 19.59 2.998 3.001 2.992 3.856 64 5515.89 31.69 2.998 2.997 2.992 3.500 64.1 5547.58 4.07 N/A N/A 2.992 3.500 sldngslv 65 5551.65 29.69 2.999 2.994 2.992 3.500 66 5581.34 30.03 2.956 2.955 2.992 3.500 67 5611.37 29.13 3.000 2.992 2.992 3.500 68 5640.50 30.87 2.986 2.975 2.992 3.500 .... 69 5671.37 N/A 2.969 2.963 2.992 3.500 Well: A-11 Field: Cook Inlet Company: Phillips (Alaska), inc. Country: USA Survey Date: November 29, 2001 Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches , Joint Tally page 2