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200-033
1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: 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): Cannery Loop Unit GL:20.7' BF:20.7' 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 9-5/8" P-110 91' 7" L-80 2,320' 4-1/2" L-80 5,148' 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 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, TUBING RECORD N/A SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 547 sx Cond Surface 2,983' 307 sx Driven STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 1/8/2021 114' FSL, 463' FEL, Sec 7, T5N, R11W, SM, AK 3716' FSL, 4180' FWL, Sec 8, T5N, R11W, SM, AK 200-033 / 320-512 Sterling Undef Gas Pool 37.7' 1,743' MD / 1,634' TVD HOLE SIZE AMOUNT PULLED 50-133-20492-00-00 CLU-06 272506 2388566 N/A CEMENTING RECORDSETTING DEPTH TVD 2392187 BOTTOM TOP 6-1/8" Surface 8-1/2"Surface CASING WT. PER FT.GRADE 277157 TOP SETTING DEPTH MD Surface Per 20 AAC 25.283 (i)(2) attach electronic information 12.6# 1,685' DEPTH SET (MD) PACKER SET (MD/TVD) 53.5# 23/26# 91' 1,813' 8,124' Gas-Oil Ratio:Choke Size:Water-Bbl: PRODUCTION TEST N/A Date of Test: N/A N/A N/A Flow Tubing N/A N/A 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/AN/A N/A N/A N/A Sr Res EngSr Pet GeoSr Pet Eng N/A N/A Oil-Bbl: Water-Bbl: N/A N/AN/A September 18, 2000 September 9, 2000 Fee ADL60569, ADL324602, FEE-TR 73 N/A N/A 1,743' MD / 1,634' TVDN/A N/A 8,320' MD / 5,277' TVD WINJ SPLUG Other Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Meredith Guhl at 11:44 am, Apr 12, 2021 RBDMS HEW 4/12/2021 Abandonment Date 1/8/2021 HEW xGDLB 04/14/2021 DSR-4/12/21 SFD 4/19/2021 BJM 8/4/21 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A Top of Productive Interval Sterling 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: 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, P&A reports. Signature w/Date: If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): Formation at total depth: 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 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). 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. No NoSidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 4.12.2021Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.04.12 10:29:39 -08'00' Monty M Myers _____________________________________________________________________________________ Updated by CJD 4-12-21 P&A SCHEMATIC Cook Inlet Basin, Alaska Middle Ground Shoal Last Completed: 02-28-1992 Oil Well ->Water injector -> Gas producer for Platform Kenai CLU Well: Cannery Loop Unit 06 Sidetracked: 1/8/2021 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 9-5/8" Conductor 53.5 / P-110 / Unknown 8.525” Surf 91' 7" Surface 23 & 26 / L-80 / Unknown 6.151” Surf 2,964' 4-1/2" Production 12.6# / L-80 / Hydril 521 3.958” Surf 8,124' JEWELRY DETAIL No Depth ID Item 1 1,760’ CIBP 1A 1,812’ CIBP w ~31’ cement (TOC ~1,781’) 1B 4,710’ CIBP w ~25’ cement (TOC ~4,682’) 1C 4,947’ CIBP 9-14-17 2 5,850’ CIBP w/ 10’ of Cement 09-09-17 3 6,040’ CIBP 7-28-17 4 6,049’ xxxx X-Nipple 5 6,300’ CIBP 7-24-17 6 6,387’ Patch 6,387’-6,409’ 7 6,855’ CIBP w/ 34’ cement (TOC 6,821’) 07-24-13 8 6,910’ RCBP 9 7,796' Cement Retainer (See Detail Box) PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT (MD) SPF Date Status A2 4,752’ 4,757’ 3,202’ 3,204’ 5’ 6 9/16/17 Open A-4 5,418’ 5,423’ 3,531’ 3,534’ 5’ 6 9/13/17 Isolated A4-2_C 5,659’ 5,665’ 3,649’ 3,652’ 6 6 9/12/17 Isolated A-5 5,881’ 5,901’ 3,762’ 3,772’ 20’ 6 7/29/2017 Isolated A-6 6,080’ 6,100’ 3,866’ 3,877’ 11’ 6 7/27/2017 Isolated A-9 6,395’ 6,409’ 4,029’ 4,037’ 14’ 6 7/30/2013 Isolated/squeezed A-11 6,740’ 6,760’ 4,224’ 4,236’ 12’ 5 7/15/2017 Isolated B-1 6,865’ 6,880’ 4,302’ 4,312’ 15’ 6 3/15/2012 Isolated B-2 6,919' 6,932' 4,337’ 4,346’ 13' 6 3/31/2012 Isolated C-1 7,846' 7,860' 4,961' 4,970' 14' 6 10/23/2000 Squeezed C-1 C-2 7,883' 7,945' 4,986' 5,028' 62' 6 6/10/2004 Squeezed 7,962' 7,986' 5,039' 5,055' 24' 6 6/9/2004 Squeezed C-2 8,014' 8,024' 5,074' 5,081' 10' 6 10/23/2000 Squeezed C-2 8,024' 8,062' 5,081' 5,106' 38' 6 6/8/2004 Squeezed INCLINATION DETAIL Inclination approx. 60 deg, 2,300-5,800 ft MD Inclination 61º dropping to 40º, 5,800 ft MD to TD Cement retainer set at 7,796’ MD, Sterling C1 and C2 intervals squeezed with approx. 6bbls Class G cement. CT un-stung and 3bbls cmt, 131’, placed on top of cement retainer, leaving TOC at approx. 7,665’ MD Note: Tagged TOC was 7,505' kb witnessed and pressure tested to 1,600psi 2-29-12. 6 1 Activity Date Ops Summary 12/19/2020 Travel to location, Contact DSO, inspect location, get permit signed, PJSM,MIRU, Re-head 5/2, Make up GR/CCL, test wire, good test. Make up Legacy 3.50" Bridge plug. ( 4.5" tubing ) OAL of plug 1.25'. Stab on well, PT wireline bop and lubricator low/high 250/3000,Open well, swab 25, T/I/O=175/0/0, RIH, @ 4730'. Log up, 40 fpm to 4500', download log. Send data to town. Got okay to set plug ( Ben Siks), Set plug @ 4710' RKB. Log up 100'. RBIH reconfirm plug set depth. Tag plug at 4710. POOH,Log from 2000'-1500', Send log to Engineer for evaluation. POOH. Tagged up, swab shut, bleed down, pop off well.,Setting tool looked good. Break down setting tool and gamma. Make up CCL, 30' 3" Bailer with A96L explosive with glass bottom. Mix up 10 gal 17ppg cement. Dump 10 gal into bailer, stab on well, open up swab,,RIH, Tag Plug lightly @ 4680' CCL depth + 30' bailer= Plug depth @ 4710'. Dump bail 10 gal 17 PPG Cmt, seen a 50 lb decrees in wt. POOH,Tagged up, swab shut, bleed down, pop off well. Glass broke all cement gone. Make up new glass and A96L explosive. Batch up 10 gal. 17ppg cement. Dump cement into bailer. Stab on well, open swab. T/I/O= 0/0/0,RIH w/CCL, 30' X 3" bailer and 10 gal of 17ppg cement. @ 4662' CCL + 30= 4692' Bailer bottom. Fire explosive. Dump 10 Gal. 17ppg cement. CMT top= 4682' +/-. POOH,Tagged up, swab closed, bleed down, pop off well. Glass is broke and all cement gone.,RDMO, Job complete, ready for rig to pt. 12/26/2020 Safety meeting with crew, emphasis on rigging up, overhead lifts, cold weather, slippery conditions with ice and snow.,MIRU on CLU-006. Lay herculite, stage in equipment, raise derrick. Significant difficulty removing old tree. Clean flange area, NU BOP stack. Place herculite around tree and keep warm so that overnight crew can continue torqueing bolts on tree, hooking up Accumulator lines.,Continue with RU and getting prepped for BOP test in morning. 12/27/2020 Safety meeting with crew, emphasis on installing stairs. Check fuel levels on equipment, stage in stairs, install. Fill pits, charge accumulator lines, confirm fluid line-up.,Fluid pack BOP, conduct Shell test to 3000 psi, good test. Test all audible and visual alarms. Test with 2-7/8" and 4-1/2" test joints to 250 psi low / 3000 psi high (Sundry permitted 2500 psi test on Annular but we tested to 3000 psi for ease of testing). Witness waived by AOGCC on 12-26-2020.,Cannot get upper variable rams to seal on pipe during test 3. Function 10 times, no progress. Call BOP provider, suggest continued functions while rep is on road to location. Troubleshoot, function, finally getting good results.,Continue with BOP test 3. Complete remainder of test with good results.,Pressure test to 2500 psi against cement plug set at ~4700 for 30 minutes on chart. Stage in E-line for RU.,RU E-Line unit. MU BHA, stab on well. RIH with BHA, tag plug at 4673' (calculated top at 4685'). Pick up and log CCL. Make cut with Spectra Jet Cutter on 4-1/2" tubing at 1800' wireline depth, good indication of fire. POH with E-Line.,RU Spear BHA. Stab into tubing, make attempts to pull. Max overpull 115k, no gain. Disengage spear, LD BHA, secure well.,Nightwatch crew blow down lines, fuel equipment. 12/28/2020 Safety meeting with crew, emphasis on BHA MU, working with Wireline crew.,RU E-Line, RIH, make cut with Spectra Jet Cutter at 1620'. POH, set E-line to side.,Stab with Spear, pick up easily. PUW 23k. RD E-Line while mobilizing tongs to floor and rigging up to circulate.,Circulate full volume around at 3.5 bpm, 400-500 psi. Caught returns with 2 bbls away, returns initially clean but turned very dirty as bottoms up approached. Cleaned back up with fluid all the way around. RD circulating equipment, blow down.,POH with 4-1/2" 12.6# Hyd 521 tubing from 1620'. Cut tubing has flare to ~5" OD.,Rig Up for running Spear / Scraper / Jars / Drill Collar BHA #2. MU BHA.,RIH with Spear BHA #2 on 2-7/8" workstring. PUW 19k, SOW 17k with BHA above top of tubing. Tag top of tubing at 1620', try to sting in without success. Set down while rotating slowly, sting in. Latched.,Attempt to pull / jar tubing out. Start with 20k over, no go. Move to 30k over, good jar lick, PU to 80k over no movement. PU to 50k over, good jar lick, PU to 80k over and no movement. Continue cycling with varying PUW and overpull. Make 18 attempts, no movement.,RU to circulate, stack down and circulate at 3 bpm, 400 psi, demonstrates that we have good flow path through cut. Very dirty, cement contaminated returns. Down on pumps, conduct 8 more jar attempts, no movement. Turn over to Nightwatch crew with instructions to break circulation every hour, monitor returns until day crew arrives. 12/29/2020 Safety meeting with crew, emphasis on jarring operations and laying down BHA. Take over from Nightwatch, inspect equipment. Break circulation with string in tension at 100k up weight. Dirty, cement contaminated returns.,Resume jarring ops in attempt to free pipe. Getting strong licks, no movement.,POH with BHA #2 standing back workstring and drill collars. SIMOPS: Stage in E-Line unit for cutter run.,Complete RU of E-Line unit. RIH with Spectra Jet Cutter tool on centralized BHA. Confirm cut at 1800', pick back up to 1710', make cut. POH logging GR to 1000'. POH, LD tools, RD E-Line.,MU Spear BHA #3 with jars and scraper. RIH on 2-7/8" workstring. Tag and enter into tubing with no issues. Break circulation with pipe in tension after first jar lick, clean bottoms up returns and good pump pressure of 400 psi at 3.5 bpm. Begin jarring ops, no movement. Consult with ODE, POH while developing plan forward.,RD circulation equipment, blow down. Receive plan forward from Town. POH with BHA #3 to stage in BOP, secure well.,RU, pressure test 7" casing by cement plug at 4673' to 2500 psi on test chart for 30 minutes. Crew staging in and setting up lay down machine. Blow down lines.,Turn over operations to Nightwatch crew. 12/30/2020 PJSM, Cut & slip 60' drill line,POOH stood back 11 stands 2 7/8" PH6 wk string, cont. POOH l/d remaining 22 jts,, break down BHA.,RIH w/486' 2 7/8" 8.7# P110, PH6 kill string, P/U 7" VS1X Packer assy. w/ 10k glass shear sub. cont in hole w/ running tool on 2 7/8" wk string t/702.21',R/U pressure up t/3500psi as per Tripoint hand, pressure dropped, attempt to p/u off but appeared to be dragging up hole, pulled to next jt, & l/d placing tail @ 670.83', pressured up t/3500psi pressure dropped x2 to 2250psi & built back then dropped off t/200psi, checked running string & appeared packer had set & sheared off, POOH l/d running tool good. packer set @ 175' top of assy @171',R/U test packer t/2800 f/30 min good,R/D floor & handling tools, N/D BOPE, n/u Dry hole tree.,Cont. RDMO rig 401, load trucks & mobe eq. t/SRU 32A-33, turn well over to Rig 169 12/31/2020 Trucks on locations @ 06:00 hrs / R/dn camp and move same f/ SCU 43-5 pad t/ CLU Pad 1 and R/up same / Scratch and level pad for rig foot print / set up heater to thaw productions flow line and elect service stubs so they can recess below grade / haul in sand to finish grade / Continue R/dn rig and haul f/ SCU pad 43-5 t/ CLU pad #1 as per permits and stage same / Assist production w/ recess of stub ups,Grade and shoot pad for rig foot print / laid felt/ liner and set rig mats/ set pony subs & iron roughneck HPU / installed metal plate shims on ODS pony subs / started & freeing rig mats of ice & snow / cleared out area and started building warm up/ safety meeting shack w/ mats & conexs,Put up handrails & lights on doghouse & choke house / cont. cleaning up felt & liner at pad SCU 43-5 / Cont. hauling misc. equip from Swanson.,Crew change, held PTSM. Cont. freeing rig mats of ice & snow / finished setting up warm up/safety meeting shack / tied up cables on camps / sanded walk areas around camps / cont. cleaning up liner & felt at Swanson River pad 43-5,Storing & treating 300 bbls of 11.4 ppg 6% KCL PHPA mud at G&I. Peak rig mover will be on location @ 05:00 hrs. to set rig. Contractor AFE #: AFE $: Job Name:201-04185P CLU-06RD PreDrill Spud Date: Well Name: Field: County/State: CLU 006RD Cannery Loop Hilcorp Energy Company Composite Report , Alaska n (LAT/LONG): evation (RKB): 50-133-20492-01-00API #: g Test with 2-7/8" and 4-1/2" test joints to 250 psi low / 3000 g Spectra Jet Cutter on 4-1/2" tubing at 1800' wireline depth, good indication of fire Mix up 10 gal 17ppg cement. g g ,Fluid pack BOP, conduct Shell test to 3000 psi, good tes Dump 10 Gal. 17ppg cement. g Set plug @ 4710' RKB CMT top= 4682' +/-. Dump bail 10 gal 17 PPG Cmt, g g cut with Spectra Jet Cutter at 1620'. ,Pressure test to 2500 psi againstyg gg cement plug set at ~4700 for 30 minutes g pick back up to 1710', m Abandonment plug tested on 12/29/20 to 2500 psi. g Confirm cut at 1800', yyy ,POH with 4-1/2" 12.6# Hyd 521 tubing from 1620'. g r and 10 gal of 17ppg cement. g pressure test 7" casing by cement plug at 4673' to 2500 psi on test chart for 30 minutes 1/1/2021 Continue set and center sub over CLU-06 / Set DWK skid / set pin derrick / set all pit modules / crane in Iron rough neck / set cat walk / raised and pin v-door / set centrifuge / set HPU module / set both pump modules / set choke house / raise pit roofs and hung wind walls and rig up modules,Preform derrick inspection / finish setting rest modules / cont. r/ up modules / raise dog house / warm gen set and fire same / Continue police SCU 43-05 pad and continue haul load from Swanson / raise derrick 1/2 mast / set iron roughneck / hung bopes on trolley,Continue pad organization / replaced bad section on steam line in rig water tank / changed out fuel pump on boiler #1.,filled boiler #1 w/ water and started staging up to pressure / installed tarps on sub & pits / erected centrifuge hooch / installed roof light around rig / cont. working on interconnects between modules / cont. hauling misc. trailers of tools& equip. from KGF staging pad, off loading and setting up location.,Set gen #3 /R/U fuel lines around rig / removed shipping blocks from shakers & centrifuge / trouble shooting rig loader -low battery light coming on and locking up brakes, changed out battery (no luck) / installed turn buckles on upper section of TQ tube / hooked up koomey lines from sub to koomey room.,Crew change, held PTSM. completed air & steam loops and energized same / R/U camera system / R/U Pason cables / spooled on drill line / prepped to scope mast / P/U & pinned lower section on TQ tube / scoped mast / installed T-bar & unbridled blocks / staged TDS on catwalk & R/U to P/U TDS,Cont. R/U electrical & prepping pits to hydro test / started taking on water in rig tank / P/U TDS to floor & pinned to blocks.,Storing & treating 300 bbls of 11.4 ppg 6% KCL PHPA mud at G&I. 1/2/2021 Continue r/up TSD, service loop and Kelly hose and function test same (ok) / Make up saver sub / finish r/up of gas buster / R/up shock hose f/ mud pumps to sub / Quadco r/up and tested all gas alarms (ok) also working on annual certification of calibration of all rig gauges,Chk well for pressures (zero) / nip/dn pull tree/ set test plug / stab bope and nip/up same, changed out HCR choke due to leaking HYD fluid from seals / chg plug on boiler #2 and fire same and stage up pressure / take on water to pits and chk for water tight / continue warm rig / continue pad organization / work on rig acceptance chk list.,Cont. R/U & working through rig acceptance check list. R/U tongs & DP elevators, pressured up koomey system & checked for leaks, R/U Pason depth tracker, brought TIW & dart valve to floor & functioned tested, function tested TDS, R/U iron roughneck. Brought on 300 bbls of 11.4 ppg 6% KCL PHPA used mud from G&I.,Crew change, held PTSM. Cont. working on rig acceptance check list, trouble shoot IR, R/U test pump HYD, R/U test equip. Grease & function new HCR choke & choke manifold, attempt to fill stack, found both flanges on HCR choke leaking, tightened flanges (ok), troubleshoot Gen sync issues, completed flooding stack & choke,,changed out bad sensator bladder on test chart, purged out air, cleaned & organized conexs, calibrated flow sensor. Started centrifuging used mud from 11.4 ppg.,Started weekly BOP test, 250 Low 3000 High 5/5 min on 4.5" & 2-7/8" test jts. as per AOGCC regulations, witness waved by Jim Regg. Currently working on testing 4.5", had F/P on electric choke, functioned & serviced Passed.,Hauled: 0 bbls solids to KGF G&I Cumulative: 0 bbls Hauled: 0 bbls fluid to KGF G&I Cumulative: 0 bbls Hauled: 0 bbls cement to KGF G&I Cumulative: 0 bbls Daily downhole losses: 0 bbls Cumulative: 0 bbls Daily metals: 0 lbs. Cumulative: 0 lbs. 1/3/2021 Continued test bopes 250 Low 3000 High 5/5 min on 4.5" & 2-7/8" test jts. as per AOGCC regulations, witness waved by Jim Regg. H ad F/P one electric choke, functioned & serviced Passed. 2nd annular on 2-7/8" Bled air and functioned retest good,Blow dn lines / test surface line t/ 250-3000 psi chase leaks chg out low torque on mud manifold & re test good /,Blow dn lines / bring handling equipment and XO to rig floor,Test torque on IR, Tongs and TDS against each other ok and commission same and accept rig @ @ 15:30 hrs,M/up Tri point storm prk retrieving tool / P/up 4-1/2" CDS-40 dp rih @ tag storm prk @ 202' RKB DPM / space out m/up XO for slick line lubricator,R/up slick line lubricator & test 250L/3000H psi ( Good),Rih w/ 1.25" X 3' Prong on 1-1/2" tool string and set dn on Disc @ 215' wlm hand spang tools t/ 228' and work tools tell clean monitoring for flow / rih t/ 315' wlm and pooh w/ no issue / r/dn slick line,Release tripoint storm prk & circ STS @ 4bpm @ zero psi / flow chk static,Pooh rack back dp & l/dn tri-point running tool and storm prk F/697'-T/495',L/D Tri-Point packer, M/U XO and circ. string volume X3 to clean up work string. Blew down TDS.,R/U Weatherford handling equip. L/D 16 jts of 2-7/8" PH-6 work string F/495'-T/surface. Hole fill Cal=2.2 bbls Act=1.4 bbls Diff=.8 bbls,R/D & L/D Weatherford handling equip. Cont. centrifuging used 6% KCL PHPA mud down from 11.4 ppg . Finished building 300 bbl batch of new 6% KCL PHPA mud.,Staged BHA #2 on catwalk-Yellow Jacket wash pipe, bumper sub, jars, 4.5" HWDP. P/U test jt., test plug, & wear rig, went to install 9" wear rig and noticed HCR choke actuator was leaking HYD fluid from the top, bled off HCR choke pressure, attempted to tighten studs on actuator w/ no luck.,Crew change, held PTSM and weekly safety meeting. Strapped & tally 4.5" HWDP while expeditor ran to BA yard to retrieve back up HCR choke. Once HCR choke arrived on location, removed bad HCR choke and replaced same. Serviced & functioned HCR choke.,Set test plug, R/U testing equip. Flooded stack & choke manifold, purged out air. Tested HCR and back side break to 250 Low & 3000 high 5/5 min as per AGOCC regulations (ok). Cont. centrifuging mud down from 11.4 ppg.,R/D testing equip, blow down lines & choke manifold, set 9" wear ring & RILD's.,P/U BHA #2- 6-1/8" flat bottom shoe, 3 jts. of wash pipe, bumper sub, oil jars, & 16 jts. of 4.5" HWDP. Set TDS drill TQ to 10K. P/U & singled in the hole w/ 4.5" DP. Current depth at report time 675'.,Hauled: 35 bbls solids to KGF G&I Cumulative: 35 bbls Hauled: 35 bbls fluid to KGF G&I Cumulative: 35 bbls Hauled: 0 bbls cement to KGF G&I Cumulative: 0 bbls Daily downhole losses: 0 bbls Cumulative: 0 bbls Daily metals: 0 lbs. Cumulative: 0 lbs. 1/4/2021 Continue singling in the hole w/ 4.5" DP t/ 1590',Brk circ and establish parameters / up/dn / rot @ 40k @ 60 rpm @ 3.7k TQ w/ 210 gpm @ 55 psi / wash over f/ 1590' t/ 1717' / dn did not see TOF @ 1620' w/ max swallow to top sub w/ little mill work Max TQ seen 5.2k @ 1680' and circ Clean,Blow dn lines / flow chk static / Pooh racking back DP and HWDP f/ 1717' to bha / l/dn jars & bumper sub / verify Top sub mark / l/dn first jt wash pipe & rack back rest & inspected burning shoe w/ 5-10% used,P/up Bha #3 / ITCO flush type spear w/ extention dressed w/ 3.947" nom catch grapple + BS & jars / load cat walk w/ dp / crew change / strap and tally same,Rih w/ HWDP out derrick p/up single in rabbiting CDS-40 dp off walk t/ 1597' /w/ calc. and actual disp. @ 9.7 bbls / Brk circ and establish parameters up/dn 43k 3bpm @ zero psi /,Wash dn and engage TOF @ 1615' and no-go out on XO @ 1620' / dn pump / bleed jars @ 20k over and set grapple w 50k over,Commence jarring operations stage jar licks t/ 90k over (135k) and straight pulls t/ 196k (236k) fired jars 71 times w/ no movement ( was able to get one time +1600 psi on DP w/ dn weight),Performed post jarring Inspect- derrick, dwk, brkes & TDS tighten bolts on "T" bar of torque tube and discuss options w/ town,Resume jarring operations firing jars @ 95k over (138k) w/ straight pulls t/ 220 over (263k) and worked in some right hand torque fired jars 16 more times w/ no movement and release spear.,Performed post jarring Inspect- inspected derrick, TDS, brakes, & DWKS. While POOH and racking back HWDP in derrick, derrick hand went to rack back a std in the fingers and strained his back. Notified the proper personal, hand cont. to work remainder of his tour.,POOH w/ BHA #3 (Spearing assy) F/1615'-T/surface, L/D spear, bumper sub, oil jars. P/U-44K S/O-43K Cal hole fill=12.6 bbls Act=11.5 bbls Diff=1.1 bbls,P/U BHA #4, M/U new 6- 1/8" shoe, 6 jts of wash pipe, bumper sub, oil jars, & 16 jts of HWDP. P/U & singled in the hole w/ 4.5" DP F/715'-T/1168'.,Crew change, held PTSM. Resumed P/U & singled in the hole w/ 4.5" DP F/1168'-T/1590', established washing parameters, P/U-44K S/O-43K GPM-210 SPP-73 psi RPM-60 Off bottom TQ- 4.3K,Washed & reamed F/1590'-T/1748'w/ no issues, GPM-210 SPP-125 psi RPM-60 On bottom TQ-3.2K. At 1748' started taking weight. Cont. washing & reaming F/1748'-T/1756', WOB-2/4K GPM-219 SPP-155 psi RPM-60 On bottom TQ-5.5/7.3K. At 1756' started stacking weight and wouldn't drill off, changed up washing parameters,,slowed down rotary & pump, increased WOB, GPM-189 SPP-99 psi RPM-35 WOB-7-9K On bottom TQ-5-9.5K, attempted to wash & ream, ahead w/ no luck (torqued up & stalled out). Called town and made decision to POOH and inspect wash pipe shoe. Flow checked, pulled 2 stds. Blew down TDS.,POOH F/1691'-T/surface, L/D bumper sub && oil jars, racked back wash pipe, removed & inspected wash pipe shoe, wore down shoe a little more than an 1" w/ no carbides left.,Currently Service rig, Greased & inspected -DWKS, TDS, brake linkage, IR, crown, blocks, and drive shaft bolts.,Hauled: 18 bbls solids to KGF G&I Cumulative: 53 bbls Hauled: 42 bbls fluid to KGF G&I Cumulative: 77 bbls Hauled: 0 bbls cement to KGF G&I Cumulative: 0 bbls Daily downhole losses: 0 bbls Cumulative: 0 bbls Daily metals: 5 lbs. Cumulative: 5 lbs. 1/5/2021 Load strap and tally pipe / clean and organize / repair v-door hand rail / remove choke house door for repair / install cmt stand pipe on beaver slide and weld repair on hatch in mud pits,Strap and tally PH-6 tubing and cutter assy. / r/up weatherford power tongs / P/up Bha # 5 yellow jackets 3-5/8" mechanical inside cutter set up for 4-1/2" csg,Rih w/ Bha#5 on Hwdp from derrick / Single in w/ 34 more jts of 4-1/2" CDS-40 DP off walk t/ 1676',Crew chg / continue rih singling in w/ 4-1/2" Dp f/ 1676' t/ 1749',Space out and preform inside cut on 4-1/2" @ 1746' DPM as per yellow jacket / establish rotation @ 60 rpm Idle pump through stand pipe choke and stage up pressure f/ 350 psi t/ 920 psi w/ choke w/ pressure drop indicating full extension of blades w/ 3.4-4k torque,Pooh Racking back dp and HWDP l/dn inspect 6 jts 2-7/8" PH-6 and cutter assy. (All blades broken but stubs appears to have marks of complete cut) also set up and tried rigs IR on m/up and brk/out of 2-7/8" PH-6 work string),P/up Bha #6 RR spear assy, RIH tag up on stop sub @ 1623' w/ pumps 55 psi pump pressure increase, P/U 10k over pull came free, POOH w/ fish L/D 129' of 4.5'' Tubing, Top of new fish 1746',Service rig and top drive,M/U wash pipe BHA #7, L/D remaining wash pipe from derrick, RIH t/ 1716' establish parameters wash and ream down to 1754' no issues, mill t/ 1759' 4.5k -7k tq on bottom 7-10k WOB 8lbs of metal back on magnets not washing over, POOH Inspect shoe.,POOH inspect mill shoe, carbides worn down inside and out, discuss options with town, wait on tools from yellow jacket,Rig Service, service top drive and draworks,Hauled: 0 bbls solids to KGF G&I Cumulative: 53 bbls Hauled: 0 bbls fluid to KGF G&I Cumulative: 77 bbls Hauled: 0 bbls cement to KGF G&I Cumulative: 0 bbls Daily downhole losses: 0 bbls Cumulative: 0 bbls Daily metals: 5 lbs. Cumulative: 10 lbs. 1/6/2021 Inspect leak on TDS compensators & chg out both cylinders and leaking fitting / preform PM on Iron rough neck, TDS, DW K, / load strap and tally last 38 jt of dp / rig and pad cleaning & organization / while waiting on fishing tools,Stage fishing tools to rig floor / M/up stub dressing Bha #8 6-1/8" SOD Piranha mill and 6" SOD string mill + Bit sub + BS + OJ + XO + 16 jts HWDP / RIH out of derrick t/ 1734' / establish Parameters / tag TOF @ 1744',Mill and dress TOF f/ 1744' t/ 1746.5' up/dn/rot 46/43/44k w/ 210 gpm @ 75 psi SPP @ 72 rpm w/ off btm TQ @ 4.5k / crew chg,Blow dn lines / pooh racking back in derrick t/ Bha,L/dn and inspect Bha #8 Mill had good wear pattern of low side engagement and +- 3% wear,R/up weatherford handling equipment f/ 2-7/8",M/up Bha #9 4-1/2" ID dressing mill and inside cutter, RIH t/ 1720' rotate down through top of fish t/ 1758' taking weight had to work through, rotate in the hole t/ 1813' fill pipe and begin cutting w/ 300 psi work pump pressure up t/ 990 psi 4k tq observe tq spike and pump pressure dump, Blow down, POOH All cutters Broken,M/U BHA # 10 spear Assembly Change out worn Jars, RIH t/ 1720' Establish circulation 0 psi , observe psi increase t/ 50 psi when engaging fish @ 1744' slack off t/ 1753' set down 2 times 10k seen 3-5k over pull when picking up, pump pressure remained 50 psi, POOH,L/D Fish 65.8',seen slight bulge in pipe from attempted Eline cut, R/D Weatherford and P/U and break down spear BHA, L/D Wash Pipe stand from derrick,Service rig and top drive, inspect breaks and check oil on floor motor,M/U BHA # 11 Clean Out Assembly RIH P/U DP off Racks t/ 1812' tag up on tubing stub, started taking weight @ 1760' 5k drag with clean pick ups and breaking free when working down, Establish circulation220 gpm 245 psi CBU cement chips on bottoms up, circulate hole clean, POOH t/ Surface L/D BHA,Hauled: 1.5 bbls solids to KGF G&I Cumulative: 54.5 bbls Hauled: 28.5 bbls fluid to KGF G&I Cumulative: 105.5 bbls Hauled: 0 bbls cement to KGF G&I Cumulative: 0 bbls Daily downhole losses: 0 bbls Cumulative: 0 bbls Daily metals: 5 lbs. Cumulative: 10 lbs. y Top of new fish 1746', / 1812' tag up on tubing stub, POOH,L/D Fish 65.8 g) POOH w/ fish L/D 129' of 4.5'' Tubing, 1/7/2021 Finish l/dn Bha and prep for E-line operations,R/up Pollard E-line hang shives and p/up tools t/ run Legacy CIBP,E-line Rih #1 w/ 5.61" Legacy CIBP and tag stub @ 1813' wlm / Pull high resolution GR/CCL f/ 1798' t/ 1500' WLM / rih and set CIBP w/ top@ 1811.5' wlm (7' above a collar and .5' above stub ) w/ good indication of fire / log off t/ 1737' rih and tag and verify depth / pooh inspect setting tool good,Run #2 P/up 30' X 5" dump bailer Mix and fill w/ 25gal neo super slurry cmt w/ accelerator verified full rih and dump same pooh verified empty/ Run #3 Mix and fill w/ 20 gal neo super slurry cmt w/ accelerator verified volume rih and dump same pooh verified empty / total 45 gal dumped / Cal TOC @ 1781.5',Shut blinds line up and attempted 1500 psi csg test/ could only achieve +- 850 psi before leaking off after pumping calc. volume of 14 gals / Chk surface equipment (ok) and bled back re-test w/ same results w/ 18 gals pumped and bled back 7 gals w/ both attempts pressure bled off would slow @ 500 psi,R/dn E-line and blow dn r/dn test equipment / WOC and wait on test prk / Replace dies in IR and Pump part inventory while waiting,M/up HES 7" RTTS w/ bypass bha # 11 / rih slow and set RTTS element @ 1733' / Shut UPR and test above dn annulus / Test #1 w/ 12.65 gal pumped t/ 1550 psi and hold for 10 min good test w/ 11.5 gal bled back / release prk / Rih and set prk w/ element @ 1762' / shut UPR and test above dn annulus test #2 w/ pump 8 gal t/ 800 psi dn pump @ 600 psi and in 10 min @ 480 psi / bled back 4.6 gals / No test,Release prk Pull up hole and set prk w/ element @ 1749' / shut annular and test above dn annulus test #3 w/ pump 10.3 gal t/ 960 psi dn pump @ 550 psi and in 10 min @ 480 psi / No test / bled back 4.6 gals / Release prk / Circ STS & fluid pack lines / reset prk @ 1751' / Test # 4 test below dn DP w/ 7.6 gal t/ 800 psi dn pump w/ 600psi in 10 min 360 psi Bled back 5.3 gals / no test,Release prk Rih / brk circ / set prk w/ element @ 1762' test below dn DP w/ 11.5 gal t/ 1500 psi / air bump up X3 10 min of flat line / ok test /,R/U and Test above Packer element perform LOT, 550 psi formation started taking fluid 14.8 ppg EMW, R/U and test Below test packer t/ 1500 psi f/ 30 min on chart good test, Blow Down Top Drive,POOH L/D test packer BHA,R/U Pollard E-Line RIH w/ Baker CIBP make correlation passes, set plug @ 1760', good indication of plug set, tag plug, Will put top of window @ 1744' POOH R/D Pollard E-Line,Drain stack, Pull wear ring, set test plug R/U t/ Test BOP's w/ 4.5'' and 2 7/8'' Test jts,Test BOP's w/ 4.5'' and 2 7/8'' test joints, t/ 250/3000 psi f/ 5 min, Test CMV 1-15, TIW and Dart, Auto and Man IBOP, HCR and man choke and kill valves, outside kill valve, Upper lower blinds and annular, Accumulator drawdown test,Hauled: 00 bbls solids to KGF G&I Cumulative: 54.5 bbls Hauled: 0 bbls fluid to KGF G&I Cumulative: 105.5 bbls Hauled: 0 bbls cement to KGF G&I Cumulative: 0 bbls Daily downhole losses: 0 bbls Cumulative: 0 bbls Daily metals: 6lbs. Cumulative: 34 lbs. 1/8/2021 Continue and finish Bope test as per regulations 250L / 3000H 5/5 w/ no issues / witness waived w/ stipulations by Mr. Jim Regg / attempt set wear ring 4 times unable lock in place leave wear ring out,P/up Bha #12 / P/up DM/TM collar per and build dn to starter mill / scribe DM/TM collar as per DD, MWD and BOT rep P/up BOT Gen II whip stock assy. and pin w/ 25k shear pin / rih w/ one std HWDP / test tools (ok) continue rih slow t/ 1704' / fill pipe and begin orientation of whip stock Per sperry Swap t/ drilling AFE @ noon element @ 1733' / y / Cal TOC @ 1781.5' @ / element @ 1762' test below dn DP @ HES 7" RTTS w/ g EMW, R/U and test Below test packer t/ 1500 psi f/ 30gg min on chart good test, Blow Down Top Drive,POOH L/D test packer BHA,R/U Pollard E-Line RIH w/ Baker CIBP make correlation passes, set plug @ 1760', g good indication of plug gy / rih and set CIBP w/ top@ 1811.5' g y ,Shut blinds line up and attempted 1500 psi csg test/ could only achieve +- Activity Date Ops Summary 1/8/2021 No activity swap to drilling AFE @ noon.;Continue easing in hole orientating tool face t/ 63R / Dn pumps / Tag @ 1760' w/ 15k dn seen good indication of anchor trip over pull 15k and verified same / set dn and sheared off w/ 25k / p/up w/ no over pull / Top of slide @ 1743'.;Dis place well t/ 6% KCL mud @ 9.1 ppg and over board water to cutting box.;Establish Parameters / SPR / Mill window f/ 1743' t/ 1757' Time drilling 6 fph on ramp, 9k WOB 80 rpm Drill t/ 1777' in formation' Top of window 1743' Bottom of window 1757' Work mills across window clean up ramp x3 smooth no issues, work through with no rotary pulled smooth.;Rack back 2 stands perform FIT t/ 14.02 ppg EMW 422 psi, pumped 9.7 gal bled back 6.9 gal, Blow down all lines.;POOH on elevators, L/D BHA mills in gauge.;Service rig, change oil in floor motor, grease crown, blocks and top drive, inspect breaks and drive shaft.;P/U stack washer and flush stack, set wear ring.;P/U Drilling BHA as per DD/MWD, upload MWD, shallow test tools, Load sources RIH w/ BHA f/derrick t/ 1727'.;Slip and cut drilling line.;Hauled: 13 bbls solids to KGF G&I Cumulative: 67.5 bbls Hauled: 157 bbls fluid to KGF G&I Cumulative: 262.5 bbls Hauled: 0 bbls cement to KGF G&I Cumulative: 0 bbls Daily downhole losses: 0 bbls Cumulative: 0 bbls Daily metals: 152lbs. Cumulative: 186 lbs. Contractor AFE #: AFE $: Job Name:201-04185D CLU-06RD Drilling Spud Date: Well Name: Field: County/State: CLU 006RD Cannery Loop Hilcorp Energy Company Composite Report , Alaska 18 n (LAT/LONG): evation (RKB): 50-133-20492-01-00API #: pp p / Mill window f/ 1743' t/ 1757 pp perform FIT t/ 14.02 ppg EMW 422 psi, pumped 9.7 gal bled back 6.9 gal, pp g@ / Top of slide @ 1743'.; 1.Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD): 4947'; 6040'; Junk (MD): 8,320'6,031' (fill) Casing Collapse Structural Conductor 7,950psi Surface 3,830psi Intermediate Production 7,500psi 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 Taylor Wellman 777-8449 Contact Name: Ted Kramer Operations Manager Contact Email: Contact Phone: 777-8420 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 tkramer@hilcorp.com 5,277'4,947'3,229'1,401'6,300'; 6,821'; 6,910'; 7,505' N/A; N/A N/A; N/A Perforation Depth TVD (ft):Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0060569|ADL0324602|FEE-TR73 200-033 50-133-20492-00-00 Cannery Loop Unit (CLU) 06 KENAI C.L.U. / Sterling Undefined Gas Length Size CO 231A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 12.6# / L-80 TVD Burst 8,124' 8,430psi MD 10,900psi 6,340psi 91' 2,322' 91' 2,964' 5,148'4-1/2" 9-5/8" 7" 91' 2,964' 8,124' Perforation Depth MD (ft): See Attached Schematic 8,124' 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. Authorized Signature: December 21, 2020 4-1/2" m n P 66 t _ Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:21 am, Dec 07, 2020 320-512 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.12.04 16:28:40 -09'00' Taylor Wellman DLB 12/07/2020gls 12/8/20 10-407 *3000psi BOPE test *2500 psi Annular test rig 401 X DSR-12/7/2020 X Suspended q Yes C 12/8/2020 dts 12/8/2020 JLC 12/8/2020 RBDMS HEW 12/9/2020 Well Prognosis Well: CLU 06 Date: 12/03/2020 Well Name: CLU 06 API Number: 50-133-20492-00 Current Status: SI Gas Producer Leg: Estimated Start Date: 11/5/2020 Rig: Eline Reg. Approval Req’d? 10-403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 200-033 First Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (M) Second Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (M) AFE Number: Current Bottom Hole Pressure: ~1,401psi Calculated from 0.437 psi/ft gradient Maximum Expected BHP: ~1,401psi @ 3,204’ TVD Calculated from 0.437 psi/ft gradient Max. Potential Surface Pressure: ~1,261psi Calculated from max BHP minus 0.1 psi/ft Brief Well Summary CLU-06 was drilled in 2000 as the first Sterling producer in Cannery Loop Unit (CLU). Drilled on the highest point on the structure from CLU-01 pad this well produced ~23 BCF until early 2012 when the C-1 and C-2 sands were sold to CINGSA for a storage reservoir. In early 2012, after the original C-1 and C-2 had been plugged back for CINGSA, the B-2 sand directly above the C-1 sand were perforated. The B-2 sand flowed at 1,500 BWPD and 2.5 MMSCFD until it loaded up and died. The B-1 sands were perforated on 3/16/2013 and only a small amount of water flowed until the well loaded up and died. In 2017, the Sterling sand was tested by perforating the A11, A9, A6, A5, A4-2C, A4 and A2. All of the Sterling sands proved to be uneconomic. This purpose of this Sundry is to prepare the well to be side tracked to a new bottom-hole location. E-line Procedure 1. RU E-line and test lubricator to 250psi low/ 3,000psi high. 2. PU CIBP. RIH and set bridge plug at ±4,710’ to isolate the open perfs. 3. Dump bail 25’ of cement on top of plug. WOC 24 hours. Pressure test to 2,500 psi. 4. RIH and tag TOC (est. TOC @ at ±4,685’). POOH W/ Eline. 5. RDMO E-line. Rig 401 Procedure 6. MIRU Rig 401. 7. ND wellhead, NU BOP and test to 250 psi low & 3,000 psi high, annular to 250 psi low & 1,500 psi high. Record accumulator pre-charge pressures and chart tests. a. Perform Test. b. Test rams on 2-7/8” and 4-1/2” test joint. c. Submit completed form 10-424 to AOGCC within 5 days of BOPE test. 8. Load well with produced water from lease. Insure well is dead. 9. Screw in 4-1/2” Landing joint. Latch onto landing joint. Tested reservoir barrier. This purpose of this Sundry is to prepare the well to be side tracked to a new bottom-hole location. 2500 / Rig 401 (Chart 30 min ) I concur, DSR - 12/7/2020 (equalize fluids IA X tubing) Well Prognosis Well: CLU 06 Date: 12/03/2020 10. RU E-line and Pressure test lubricator to 250psi low and 3,000 psi high. 11. RIH W/ Jet cutter 100’. Cut 4-1/2” Casing. POOH With E-line standing back. 12. POOH W/hanger and casing piece racking back pipe. (Note: No open perfs in the well.) 13. PU RIH with OS on 4-1/2” pipe. Latch on to 4-1/2” casing and pick up tension. 14. Rig up E-line. Pressure test Lubricator to 250psi low and 3,000 psi high. 15. PU and RIH W/ free point tool. 16. PU on 4-1/2” production tubing and use the stretch to identify where the 4-1/2” Production Tubing / Casing is free of Cement on the backside. (Note: Notify Ops Engineer of depth). POOH. 17. PU Jet cutter. RIH W/ Same and log into the same free pipe position. PU on 4-1/2” With Rig 401 and fire cutter. Tension should slack off of the pipe after pipe is cut (if free). POOH W/ Cutter. Stand E-line back. If cut is less than 1,700’, go to step 18. Otherwise, go to Step 21. 18. POOH laying down 4-1/2” pipe and lay down same. 19. RU Power swivel. PU Shoe and Wash Pipe or pilot mill and mud motor on WS, RIH W/ Same. Wash over or mill 4-1/2” pipe down past plug back depth. POOH. (Note: Weather Step 19 utilizes a shoe and PS or mud motor will be determined by how much additional pipe needs to be recovered to get to KOP (Kick Off Point). 20. Circulate bottoms up (CBU). 21. RU E-line and test lubricator to 250psi low/ 3,000psi high. 22. PU 7” CIBP on e-line and RIH to KOP +50’. Set Plug. POOH and PU dump bailer. 23. RIH and Dump bail 45’ of cement on top of plug. (Note: 30’, 5” Bailer, Three bailer runs is equal to 45’ of Cement (+/-)). 24. ND BOP. NU Dry Tree. RDMO Rig 401. Attachments: Well Schematic Proposed Well Schematic BOP Schematic Wellhead Schematic Proposed Well head Schematic RWO Procedure Change Form Circu 2nd jet cut Cut 4.5" @100 ft fish pipe contingency washover If cut is less than 1,700’, go to step 18. _____________________________________________________________________________________ Updated by DMA 09-12-17 SCHEMATIC Cook Inlet Basin, Alaska Middle Ground Shoal Last Completed: 02-28-1992 Oil Well ->Water injector -> Gas producer for Platform Kenai CLU Well: Cannery Loop Unit 06 Last Completed: 10/23/2000 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 9-5/8" Conductor 53.5 / P-110 / Unknown 9.95” Surf 91' 7" Surface 23 & 26 / L-80 / Unknown 6.151” Surf 2,964' 4-1/2" Production 12.6# / L-80 / Hydril 521 3.958” Surf 8,124' JEWELRY DETAIL No Depth ID Item 1 4,947’ CIBP 9-14-17 2 5,850’ CIBP w/ 10’ of Cement 09-09-17 3 6,040’ CIBP 7-28-17 4 6,049’ xxxx X-Nipple 5 6,300’ CIBP 7-24-17 6 6,387’ Patch 6,387’-6,409’ 7 6,855’ CIBP w/ 34’ cement (TOC 6,821’) 07-24-13 8 6,910’ RCBP 9 7,796' Cement Retainer (See Detail Box) PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT (MD) SPF Date Status A2 4,752’ 4,757’ 3,202’ 3,204’ 5’ 6 9/16/17 Open A-4 5,418’ 5,423’ 3,531’ 3,534’ 5’ 6 9/13/17 Isolated A4-2_C 5,659’ 5,665’ 3,649’ 3,652’ 6 6 9/12/17 Isolated A-5 5,881’ 5,901’ 3,762’ 3,772’ 20’ 6 7/29/2017 Isolated A-6 6,080’ 6,100’ 3,866’ 3,877’ 11’ 6 7/27/2017 Isolated A-9 6,395’ 6,409’ 4,029’ 4,037’ 14’ 6 7/30/2013 Isolated/squeezed A-11 6,740’ 6,760’ 4,224’ 4,236’ 12’ 5 7/15/2017 Isolated B-1 6,865’ 6,880’ 4,302’ 4,312’ 15’ 6 3/15/2012 Isolated B-2 6,919' 6,932' 4,337’ 4,346’ 13' 6 3/31/2012 Isolated C-1 7,846' 7,860' 4,961' 4,970' 14' 6 10/23/2000 Squeezed C-1 C-2 7,883' 7,945' 4,986' 5,028' 62' 6 6/10/2004 Squeezed 7,962' 7,986' 5,039' 5,055' 24' 6 6/9/2004 Squeezed C-2 8,014' 8,024' 5,074' 5,081' 10' 6 10/23/2000 Squeezed C-2 8,024' 8,062' 5,081' 5,106' 38' 6 6/8/2004 Squeezed INCLINATION DETAIL Inclination approx. 60 deg, 2,300-5,800 ft MD Inclination 61º dropping to 40º, 5,800 ft MD to TD Cement retainer set at 7,796’ MD, Sterling C1 and C2 intervals squeezed with approx. 6bbls Class G cement. CT un-stung and 3bbls cmt, 131’, placed on top of cement retainer, leaving TOC at approx. 7,665’ MD Note: Tagged TOC was 7,505' kb witnessed and pressure tested to 1,600psi 2-29-12. 6 Sterling Gas Pool 2964ft _____________________________________________________________________________________ Updated by DMA 12-02-20 PROPOSED SCHEMATIC Cook Inlet Basin, Alaska Middle Ground Shoal Last Completed: 02-28-1992 Oil Well ->Water injector -> Gas producer for Platform Kenai CLU Well: Cannery Loop Unit 06 Last Completed: 10/23/2000 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 9-5/8" Conductor 53.5 / P-110 / Unknown 9.95” Surf 91' 7" Surface 23 & 26 / L-80 / Unknown 6.151” Surf 2,964' 4-1/2" Production 12.6# / L-80 / Hydril 521 3.958” Surf 8,124' JEWELRY DETAIL No Depth ID Item 1A ±1,950’ CIBP w ~45’ cement (TOC ~1,905’) 1B ±4,710’ CIBP w ~25’ cement (TOC ~4,685’) 1C 4,947’ CIBP 9-14-17 2 5,850’ CIBP w/ 10’ of Cement 09-09-17 3 6,040’ CIBP 7-28-17 4 6,049’ xxxx X-Nipple 5 6,300’ CIBP 7-24-17 6 6,387’ Patch 6,387’-6,409’ 7 6,855’ CIBP w/ 34’ cement (TOC 6,821’) 07-24-13 8 6,910’ RCBP 9 7,796' Cement Retainer (See Detail Box) PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT (MD) SPF Date Status A2 4,752’ 4,757’ 3,202’ 3,204’ 5’ 6 9/16/17 Open A-4 5,418’ 5,423’ 3,531’ 3,534’ 5’ 6 9/13/17 Isolated A4-2_C 5,659’ 5,665’ 3,649’ 3,652’ 6 6 9/12/17 Isolated A-5 5,881’ 5,901’ 3,762’ 3,772’ 20’ 6 7/29/2017 Isolated A-6 6,080’ 6,100’ 3,866’ 3,877’ 11’ 6 7/27/2017 Isolated A-9 6,395’ 6,409’ 4,029’ 4,037’ 14’ 6 7/30/2013 Isolated/squeezed A-11 6,740’ 6,760’ 4,224’ 4,236’ 12’ 5 7/15/2017 Isolated B-1 6,865’ 6,880’ 4,302’ 4,312’ 15’ 6 3/15/2012 Isolated B-2 6,919' 6,932' 4,337’ 4,346’ 13' 6 3/31/2012 Isolated C-1 7,846' 7,860' 4,961' 4,970' 14' 6 10/23/2000 Squeezed C-1 C-2 7,883' 7,945' 4,986' 5,028' 62' 6 6/10/2004 Squeezed 7,962' 7,986' 5,039' 5,055' 24' 6 6/9/2004 Squeezed C-2 8,014' 8,024' 5,074' 5,081' 10' 6 10/23/2000 Squeezed C-2 8,024' 8,062' 5,081' 5,106' 38' 6 6/8/2004 Squeezed INCLINATION DETAIL Inclination approx. 60 deg, 2,300-5,800 ft MD Inclination 61º dropping to 40º, 5,800 ft MD to TD Cement retainer set at 7,796’ MD, Sterling C1 and C2 intervals squeezed with approx. 6bbls Class G cement. CT un-stung and 3bbls cmt, 131’, placed on top of cement retainer, leaving TOC at approx. 7,665’ MD Note: Tagged TOC was 7,505' kb witnessed and pressure tested to 1,600psi 2-29-12. 6 Kick off depth The picture can't be displayed.The picture can't be displayed.The picture can't be displayed.The picture can't be displayed. 13-5/8"Spherical Annular Height: 46" Weight: 12,806 13-5/8"LWS Double BOP Height: 37" Width: 93" Weight 9,900 lbs. TOP RAMS 2-7/8" TO 5-1/2" MULTI- RAMS BOTTOM RAMS BLIND RAMS 13-5/8"Mud Cross W/ 4- 1/16" outlets Height:28.5" Width 31" Dual 4-1/16" Manual Gate valves W/ DSA to 2-1/16" 4-1/16" Manual Gate valve & 4-1/16" HCR W/ DSA to 2-1/16" Full Mud Cross Assy. width w/ valves installed Width: 98.5" Weight: 2200 lbs. Kill side Choke side Height Addition for Ring Gaskets: 0" BOP Total Height: 111.5" BOP Total weight: 24,906 lbs. 13-5/8" 5m BOP Package W/ 4-1/16" Valves VBR Blinds Cannery Loop Unit CLU #6 10/08/2020 Valve, Master, VG-200, 4 1/16 5M FE, HWO, EE trim Valve, Upper master, VG-200, 4 1/16 5M FE, HWO, EE trim Valve, Swab, VG-200 4 1/16 5M FE, HWO, EE trim Valve, Wing, VG-200, 3 1/8 5M FE, HWO, EE trim BHTA, Otis, 4 1/16 5M FE x 6.5 Otis quick union top Starting head, Vetco-Custom- C22BP, 11 5M x 7'’ SOW, w/ 2- 2 1/16 5M SSO Cannery Loop Unit CLU #6 9 5/8 x 7 x 4 ½ Tubing hanger, Vetco Gray- custom, 11 x 4 ½ BTC box btm x 4 ½ BTC box top, w/ 5 1/2 od neck, 4'’ type H BPV profile, DD-NL material Valve, Wing, SSV, VG-200, 3 1/8 5M FE, w/ 15'’ operator 7'’ 4 ½’’ Only 2 lockpins on wellhead Not enough for conventional tubing hanger 18'’ Grade level Cannery Loop Unit CLU #6—Temp abandonment 12/02/2020 Valve, Master, VG-200, 4 1/16 5M FE, HWO, EE trim BHTA, Otis, 4 1/16 5M FE x 6.5 Otis quick union top Starting head, Vetco-Custom- C22BP, 11 5M x 7'’ SOW, w/ 2- 2 1/16 5M SSO Cannery Loop Unit CLU #6 9 5/8 x 7 7'’ Only 2 lockpins on wellhead Not enough for conventional tubing hanger 18'’ Grade level 4 ½ IF test plug left in place for Rig Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well CLU-06 (PTD 200-033) Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC 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 403 Required? Y / N HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Asset Team Operations Manager Date Prepared: First Call Operations Engineer Date 200-033 5 Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 RECEIVED � `_ IVE ele: 90 Anchorage, A77 99503 ICS Tele: 907 777-8308 DATA LOGGv Hilrnrp th, ka,LIA: Fax: 907 777-8510 E-mail: snolan@hilcorp.com K. sEtvDc OCT 1 7 2017 DATE 10/02/2017 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL CLU 6 Prints and Digital data SCANNED FEB 2 8 2018 Prints: PLUG SETTING RECORD PERFORATION RECORD LEAK DETECT LOG CD1: LDL PLUG_2431.1L17 9/19/20171:04 PM File folder PERF 263UL17 9/19/20171:04 PM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: m././..,,-,44) O ,,„,eat. riCtOCIVtu ' STATE OF ALASKA ALTA OIL AND GAS CONSERVATION COM.SION OCT 1 1 2017 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon UPlu9 Perforations U Fracture Stimulate Li Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate Q Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ 3rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ 200-033 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-133-20492-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0060569/FEE-TR73/ADL0324602 Cannery Loop Unit(CLU)06 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kenai C.L.U.Field/Sterling Undefined Gas 11.Present Well Condition Summary: 4,947';6,040';6,300';6,821'; Total Depth measured 8,320 feet Plugs measured 6,910';7,505' feet true vertical 5,277 feet Junk measured 6,031 (fill) feet Effective Depth measured 4,947 feet Packer measured N/A feet true vertical 3,229 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 91' 9-5/8" 91' 91' 10,900psi 7,950psi Surface 2,964' 7" 2,964' 2,320' 6,340psi 3,830psi Intermediate Production 8,124' 4-1/2" 8,124' 5,148' 8,430psi 7,500psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 8,124' 5,148' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 81 Subsequent to operation: 0 0 0 0 133 14.Attachments(required per 20 AAc 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2 Exploratory Development❑., Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas Q WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-399 Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: OperationsOp� Manager Contact Email: tkram (cerhilcorp.com Authorized Signature: l .‘,/,,://4.. ,�i ,/,:/�_ /'_ Date: Co/1 f/17 Contact Phone: 777-8420 IA, it.11erForm 10-404 Revised 4/2017 J /� RBDMS 1V VU1.I 1 2 2017 Submit Original Only 1179/7 • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date CLU-06 E-Line 50-133-20492-00 200-033 9/9/17 9/17/17 Dail O eratiions 09/09/2017-Saturday Sign in. Mobe to location and spot equipment. Rig up lubricator. PT to 250 psi low and 3,000 psi high.TP- 1,502 psi. RIH w/2.74" GR/JB and GPT tool and tie into CBL log. Run correlation log from 6,000' (did not tag) to 5,400'. Found fluid level at 5,900' (open perfs from 5,881'to 5,901'). POOH.TP- 1,501 psi. RIH w/3-1/2" OD CIBP and tie into CBL log. Run correlation log. Spot top of plug at 5,850' . Attempted to set plug. Ignitor went off but plug did not set. POOH. Setting tool had not stroked due to power charge did not go off. Secondary and ignitor went off but did not set off powder charge. Plug had unscrewed from setting sleeve and was left in hole. RIH with new plug and tie into CBL log. Run correlation log. Spot top of plug at 5,850' and set plug with 1,501 psi on tubing. Lost 70 lbs when plug set. Pick up 30' and went back down and tag plug. POOH. Good set. RIH w/3" x 20' bailer and tag plug at 5,850'. Pick up and dumped 10' (4 gals) of 16.9 ppg cement on top of plug.TP- 1,500 psi. POOH. Good dump. Rig down lubricator and WOC. Scheduled to perf Tuesday the 12th. 09/12/2017-Tuesday Sign in. Mobe to location. PTW and JSA. Spot equip and rig up lubricator. PT to 250 psi low and 3,000 psi high. RIH w/GPT and tie into CBL log.Tag TOC at 5,840.5'.Tubing is dry- no fluid.TP- 1,004.5 psi. POOH. Send log to town. RIH w/2-7/8" x 5' HC Razar, 6 spf, 60 deg phase and tie into CBL log dated 6-29-12. Run correlation log and send to town. Adjust the correlation log up 2'. Spot gun from 5,659'to 5,664' and fire gun with 1,002.4 psi on tubing. After 5 min pressure was 1,002.9 psi. POOH. All shots fired and gun was dry. Rig down lubricator and turn well over to field.TP- 998.5 psi. 09/13/2017 Wednesday PTW and JSA. Rig up lubricator, PT to 250 psi low and 3,500 psi high.TP-230 psi. RIH w/GPT tool, tie into Peri log dated 9-12-17 and tag at 5,840'. Found fluid level at 5,800'. Send log to town and POOH. Pressure tubing up to 800 psi with field gas from CLU-05RD. RIH with 2-7/8" x 5' Razor HC and tie into Perf log dated 9-12-17. Run correlation log and send to town. Get ok to perf the A4 sand from 5,418' to 5,423'. Fired gun with 810 psi on tubing. Went to 822 psi right away, 880 psi after 1 min, 958 psi after 2-1/2 min and 1,019 psi in 5 min. POOH. Out of hole. All shots fired. Gun was dry but had sand in it.TP- 1,121.9 psi. Rig down lubricator and turn well over to field. 09/14/2017-Thursday Sign in and mobe to location. PTW and JSA. PT to 250 psi low and 3,500 psi high. RIH w/GPT tool and correlate to CBL log dated 6-28-12.Tag fill at 4,963'. Found fluid level at 2,010'.TP- 773 psi. POOH. RIH with 3-1/2" OD CIBP and tie into CBL log. Found FL at 1,995' and tag fill at 4,950'. Gained that much by just opening swab to go in hole with plug. Set plug at 4,947' and lost 50 lbs line tension when set. Picked up 30' and went back and tag plug. Good set.TP-750 psi. POOH. Setting tool looked good. Rig down lubricator and turn well over to field. Will swab well tomorrow. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date CLU-06 E-Line 50-133-20492-00 200-033 9/9/17 9/17/17 Daily Operations 09/15/2017 Friday Sign in. Mobe to location. PTW and JSA. Spot and rig up lubricator. PT to 250 psi low and 3000 high. Rig up gas buster tank. Bleed tubing from 745 psi to 0 psi. RIH w/swab cup assy and swab fluid out of tubing from 1950' KB to 4920' KB. Tagged fill at 4943' wlm KB. Got out approx. 48 bbls of fluid. Got fluid sample and gave it to Mike. Rig down slickline lubricator and turn well over to field. Will pressure well up to 800 psi for the perf job in the morning. 09/16/2017-Saturday Sign in. Mobe to location. Rig up lubricator and GPT tool. PT to 250 psi low and 3500 psi high.TP-811 psi. Field pressured up tubing this am. RIH w/GPT tool and tie into Pollard perf correlation log dated 9-13-17. Found fluid level at 4860' and tagged at 4947'. Send log to town. POOH. TP -809.4 psi. RIH with 2-7/8"x5' Razor HC and tie into Perf log dated CBL. Run correlation log and send to town. Told to shift log up 1' and good to perf the A2_4C sand from 4752'to 4757'.Spotted and fired gun from 4752' to 4757' with 804.7 psi on tubing. After 5 min pressure was 804.8 psi. We lost 100 lb of line tension when we fired gun. POOH. Gun was dry and no sand in it. Rig down lubricator and turn well over to field.TP -802.9 psi 09/17/2017-Sunday Sign in. Mobe to location. Rig up lubricator and GPT tool. PT to 250 psi low and 3500 psi high.TP -74.4 psi. RIH w/GPT tool, correlate to Perf Log dated 9-16-17 and tag at 4946'. Found fluid level at 4615' with TP at 74 psi. POOH. Rig down lubricator and turn well over to field. • Kenai CLU 11 • SCHEMATIC Well: Cannery Loop Unit 06 Last Completed: 10/23/2000 Hileorp Alaska,LLC CASING DETAIL RKB=21'MSL Size Type Wt/Grade/Conn ID Top Btm w,' t; 9-5/8" Conductor 53.5/P-110/Unknown 9.95" Surf 91' LL; 7" Surface 23&26/L-80/Unknown 6.151" Surf 2,964' 4-1/2" Production 12.64/L-80/Hydril 521 3.958" Surf 8,124' tt ,,,,,4 .4 JEWELRY DETAIL 9-5/8" aint � fi' No ' Depth ID Item 44)" erOf 1 4,947' CIBP 9-14-17 „ t ti 2 5,850' CIBP w/10'of Cement 09-09-17 4 " 3 6,040' CIBP 7-28-17 4 .. 6,049' xxxx X-Nipple r 5 6,300' CIBP 7-24-17 /T 6 6,387' Patch 6,387'-6,409' if � *; A t 7 6,855' CIBP w/34'cement(TOC 6,821')07-24-13 �' w 8 6,910' RCBP t. w' 9 7,796' Cement Retainer(See Detail Box) • 7 0 *f i. PERFORATION DETAIL Top Btm Top Btm FT Zone (MD) (MD) (TVD) (TVD) (MD) SPF Date Status vi A2 4,752' 4,757' 3,202' 3,204' 5' 6 9/16/17 Open litil Sterling� 1A-4 5,418' 5,423' 3,531' 3,534' 5' 6 9/13/17 Isolated liti:„ A4 2_C 5,659' 5,665' 3,649' 3,652' 6 6 9/12/17 Isolated ?: A-5 5,881' 5,901' 3,762' 3,772' 20' 6 7/29/2017 Isolated " Ll r. StelingA-4 / A-6 6,080' 6,100' 3,866' 3,877' 11' 6 7/27/2017 Isolated Toc@5,84d A-9 6,395' 6,409' 4,029' 4,037' 14' 6 7/30/2013 Isolated/squeezed 09/09/17 `°' y SterlingA4-2_C ✓ A-11 6,740' 6,760' 4,224' 4,236' 12' 5 7/15/2017 Isolated .1., 2 B-1 6,865' 6,880' 4,302' 4,312' 15' 6 3/15/2012 Isolated SteriingA-5 B-2 6,919' 6,932' 4,337' 4,346' 13' 6 3/31/2012 Isolated 3 C 1 7,846' 7,860' 4,961' 4,970' 14' 6 10/23/2000 Squeezed t C-1 7,883' 7,945' 4,986' 5,028' 62' 6 6/10/2004 Squeezed Sterling A-6 C-2 7,962' 7,986' 5,039' 5,055' 24' 6 6/9/2004 Squeezed 4': 4 C-2 8,014' 8,024' 5,074' 5,081' 10' 6 10/23/2000 Squeezed ,;1 5 6 C-2 8,024' 8,062' 5,081' 5,106' 38' 6 ' 6/8/2004 Squeezed 1„/1 '* ry.A-9 TOC@6,821' -;:iii Sterling A-11 07/24/13 k" 3s'Y, 7 - B-1 8 k B-2 '' Cement retainer set at 7,796'MD, -,. 9 Sterling Cl and C2 intervals squeezed ' iwith approx.6bbls Class G cement. ;�� C-1&2 CT un-stung and 3bbls cmt,131', 1 -I placed on top of cement retainer, 4-1/2" leaving TOC at approx.7,665'MD t`....,,Nie Note:Tagged TOC was 7,505'kb TD=8,320' PBTD=4,94T witnessed and pressure tested to MAX HOLE ANGLE=64°@1,790' 1,600psi 2-29-12. INCLINATION DETAIL Inclination approx.60 deg,2,300-5,800 ft MD Inclination 612 dropping to 402,5,800 ft MD to TD Updated by DMA 09-12-17 • • V• OF T, y ��\�y/,��� THE STATE Alaska Oil and Gas •F "t Of/\ LAS Conservation Commission KA Witt=___ 333 West Seventh Avenue 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 lierir\ Main: 907.279.1433 GP ALAS Fax: 907.276.7542 www.aogcc.alaska.gov SCOHED SEP () l (L(Ir Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai CLU Field, Sterling Undefined Gas Pool, CLU 06 Permit to Drill Number: 200-033 Sundry Number: 317-399 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Commissioner DATED this 2_4 ay of August, 2017. RBDMS t,v A*1 5 2017 • • • RECEIVED STATE OF ALASKA AUG 2 1,007 ALASKA OIL AND GAS CONSERVATION COMMISSION P75 a, G-2/ 1? APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon 0 Plug Perforations Q • Fracture Stimulate ❑ Repair Well 0 Operations shutdown 0 Suspend ❑ Perforate 0 ' Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other: 0 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC Exploratory 0 Development 0• 200-033 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 0 Service 0 6.API Number: Anchorage Alaska 99503 50-133-20492-00 • 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055(a)(4) Cannery Loop Unit(CLU)06 • Will planned perforations require a spacing exception? Yes ID No No 0 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL0060569IADL0324602IFEE-TR73 KENAI C.L.U./Sterling Undefined Gas • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD):6,040'; Junk(MD): 8,320' . 5,277' • 6,040' 3,845' -1,253 psi 3,300';6,821';6,910';7,50E 6,031'(fill) Casing Length Size MD Burst Collapse Structural Conductor 91' 9-5/8" 91' 91' 10,900psi 7,950psi Surface 2,964' 7" 2,964' 2,322' 6,340psi 3,830psi Intermediate Production 8,124' 4-1/2" 8,124' 5,148' 8,430psi 7,500psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6#/L-80 8,124' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A; N/A N/A;N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: • Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic ❑ Development Q Service 0 14. Estimated Date for 15.Well Status after proposed work: September 5,2017 CommencingOperations: OIL 0 WINJ 0 WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS Q . WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcoro.com / Contact Phone: 777-8420 Authorized Signature: 11;e6Date: M `/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 ' 7- 3 9 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No ❑ RDDM$ �/ AUGpacing Exception Required? Yes ❑ No Subsequent Form Required: r .-40A l/ AU(j 3 0 2017 APPROVED BY Approved by:ate,P iep...„tvd_.t._____ COMMISSIONER THE COMMISSION Date:0--- 2--I7 - 3ibf Ain ® Fife Submn Form ane Form 10-403 Revised 4/2017 iptitAiLalid for 12 months from the date of approval. achments in Duplicate 1,AW7/<6 g"Z-3,/7 • • 14 Well Prognosis Well: CLU#6 Hilcorp Alaska,LLQ Date:8/18/2017 Well Name: Cannery Loop Unit(CLU) API Number: 50-133-20492-00 #6 Current Status: SI Gas Well Leg: N/A Estimated Start Date: September 5th, 2017 Rig: E-line Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 200-033 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 227-5293 (M) AFE Number: Current Bottom Hole Pressure: 1,628 psi @ 4,752' (3,762'TVD) (Based on .433 psi/ft gradient) Max. Potential Surface Pressure: 1,253 psi @ 5,881' (3,762'TVD) (Deepest perf minus .1 psi/ft.grad.) Brief Well Summary: i Cannery Loop Unit#6 is a shut-in gas producer. Recent perf adds in the Sterling have watered up the well and are proven non-productive. The work covered under this Sundry application is to perforate new Sterling intervals. " The intervals(listed below in Step#6) will be shot and tested working up hole until economic quantities of gas - are found. (Note: Non-productive intervals that produce water will be isolated prior to moving up hole.) The well will then be placed on production and flowed. Notes Regarding Wellbore Condition • The well is currently SI. • Cement has excellent bond above and below all intervals to be perfed. Procedure: 1. MIRU E-line Unit. 2. RU and Pressure test Lubricator to 3,000 psi. 3. Pressure up on the well with natural gas to push away water into the open perforations, 5,881 to 5,901'. PU pressure/temperature tool and verify that water has been pushed below the new perforation interval. 4. PU CIBP, RIH and Set at 5,860'. POOH W/E-line. 5. PU Guns and RIH to perforate the A4-2_C Zone. Log guns on depth. Pressure up well to the pressure recommended by Hilcorp reservoir engineer. Fire guns. Record Pressure at 5 min., 10 min. intervals. 6. Bleed down well checking for inflow. Place well in test. If interval is uneconomic, set a plug over perforated interval (See E-line Contingency plan below), move up hole to the next interval. Intervals to be shot and tested: Zone Sands Top (MD) Btm (MD) FT Sterling X2 (+/-)4,012' (+/-)4,024' 12' Sterling A2 (+/-)4,752' (+/-)4,763' 11' . Sterling A2-4_C (+/-) 5,085' (+/-) 5,104' 19' Sterling A4-2_C (+/-) 5,655' (+/-) 5,705' 50' • • Well Prognosis Well: CLU#6 Hilcorp Alaska,LLQ Date:8/18/2017 Sterling A-4 (+/-) 5,415' (+/-) 5,730' 15' a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using a Correlation Log provided by the assigned geologist. d. Use Gamma/CCL/to correlate. e. Send correlation pass Operations Engineer, Reservoir Engineer, and Geologist for Confirmation. f. Record tubing pressures before and after each perforating run. g. All perforations in table above are located in the Sterling"undefined" Pool. Therefore, regular state wide spacing rules apply. 7. RD E-line. 8. Turn well over to production. 9. Test SSV with-in 5 days of stable production (Notify AOGCC 24 hours before testing to give opportunity to witness). E-line Contingency Plan If any zone produces sand and/or excessive water and needs to be isolated: 1. MIRU E-line. Pressure Test Lubricator to 2,500 psi high/250 psi low. 2. RIH and Set 4-1/2" CIBP at depth above zone (place 25' of cement if required) if zone is at bottom of perf interval. 3. If zone is in the middle of perf interval, RIH and set 4-1/2" casing patch to isolate interval. 4. RDMO E-line unit. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Wellhead drawing • • Kenai CLU SCHEMATIC Well: Cannery Loop Unit 06 Last Completed: 10/23/2000 11ilcorp Alaska,LLC CASING DETAIL RKB=21'MSL Size Type Wt/Grade/Conn ID Top Btm 9-5/8" Conductor 53.5/P-110/Unknown 9.95" Surf 91' 7" Surface 23&26/L-80/Unknown 6.151" Surf 2,964' 4-1/2" Production 12.6#/L-80/Hydril 521 3.958" Surf 8,124' 95/8JEWELRY DETAIL No Depth ID Item 1 6,040' CIBP 07-28-17 2 6,049' X-Nipple 3 6,300' CIBP 07-24-17 4 6,387' Patch 6,387'-6,409' 5 6,855' CIBP w/34'cement(TOC 6,821')07-24-13 6 6,910' RCBP 7 7,796' Cement Retainer(See Detail Box) 7„L ,,. PERFORATION DETAIL Zone Top Btm Top Btm SPF Date Status (MD) (MD) (TVD) (ND) (MD) A-5 5,881' 5,901' 3,762' 3,772' 20' 6 7/29/2017 Active A-6 6,080' 6,100' 3,866' 3,877' 11' 6 7/27/2017 Isolated A-9 6,395' 6,409' 4,029' 4,037' 14' 6 7/30/2013 Isolated/squeezed A-11 6,740' 6,760' 4,224' 4,236' 12' _ 5 7/15/2017 Isolated B-1 6,865' 6,880' 4,302' 4,312' 15' 6 3/15/2012 Isolated B-2 6,919' 6,932' 4,337' 4,346' 13' 6 3/31/2012 Isolated C-1 7,846' 7,860' 4,961' 4,970' 14' 6 10/23/2000 Squeezed C-1 7,883' 7,945' 4,986' 5,028' 62' 6 6/10/2004 Squeezed SterlingA-5 C-2 7,962' 7,986' 5,039' 5,055' 24' 6 6/9/2004 Squeezed 1 j C-2 8,014' 8,024' 5,074' 5,081' 10' 6 10/23/2000 Squeezed Sterling A-6 C-2 8,024' 8,062' 5,081' 5,106' 38' 6 6/8/2004 Squeezed ■ 2 3 4 Fr9 Sterling A-11 i is , 5 *- x r B-1 ' 6 2-2 Cement retainer set at 7,796'MD, 7 Sterling Cl and C2 intervals squeezed A with approx.6bbls Class G cement. _c-1&2 CT un-stung and 3bbls cmt,131', placed on top of cement retainer, 4-V2" I 1 leaving TOC at approx.7,665'MD (, Note:Tagged TOC was 7,505'kb TD=8,320' PBTD=6,040' witnessed and pressure tested to 1,600psi 2-29-12. MAX HOLE ANGLE=640 @ 1,790' p INCLINATION DETAIL Inclination approx.60 deg,2,300-5,800 ft MD Inclination 61°dropping to 40°,5,800 ft MD to TD Updated by DMA 08-17-17 1110 • Kenai CLU PROPOSED SCHEMATIC Well: Cannery Loop Unit 06 Last Completed: 10/23/2000 i-Iilcurp Alaska,LLC CASING DETAIL RKB=21'MSL Size Type Wt/Grade/Conn ID Top Btm `d; •1 9-5/8" Conductor 53.5/P-110/Unknown 9.95" Surf 91' 7Surface 23&26/L-80/Unknown 6.151" Surf 2,964' 4_712 1/2" Production 12.6#/L-80/Hydril 521 3.958" Surf 8,124' 9-5/8" JEWELRY DETAIL No Depth ID Item 1 ±5,800' CIBP �`' 2 6,040' CIBP 7-28-17 3 6,049' X-Nipple '. 4 6,300' CIBP 7-24-17 5 6,387' Patch 6,387'-6,409' 6 6,855' CIBP w/34'cement(TOC 6,821')07-24-13 rip_ 7 6,910' RCBP ''' 8 7,796' Cement Retainer(See Detail Box) i 7 74 44`h^..'„ 441 Top Btm TopPERFORATION DETAIL Btm FT I Zone (MD) (MD) (TVD) (TVD) (MD) SPF Date Status Staling X2 y ' X2 ±4,012' ±4,024' ±3,202' ±3,207' ±12' 6 Future Proposed StelingA-2 A-2 ±4,752' ±4,763' ±3,202' ±3,207' ±11' 6 Future Proposed A2-4_C ±5,085' ±5,104' ±3,202' ±3,207' ±19' 6 Future Proposed Sterling A2-4 C A4-2_C ±5,655' ±5,705' ±3,202' ±3,207' ±50' 6 Future Proposed = Sterling A4-2_C A-4 ±5,415 ±5,430 ±3,530' ±3,483' ±15' 6 Future Proposed A-5 5,881' 5,901' 3,762' 3,772' 20' 6 7/29/2017 Active ' • Sterling A-4 A-6 6,080' 6,100' 3,866' 3,877' 11' 6 7/27/2017 Isolated ' 1 A-9 6,395' 6,409' 4,029' 4,037' 14' 6 7/30/2013 Isolated/squeezed ? y Sterling A-11 6,740' 6,760' 4,224' 4,236' 12' 5 7/15/2017 Isolated t 2 B-1 6,865' 6,880' 4,302' 4,312' 15' 6 3/15/2012 Isolated `y - '' B-2 6,919' 6,932' 4,337' 4,346' 13' 6 3/31/2012 Isolated Sterling A-6 C-1 7,846' 7,860' 4,961' 4,970' 14' 6 10/23/2000 Squeezed },..p II ', 3 C-1 7,883' 7,945' 4,986' 5,028' 62' 6 6/10/2004 Squeezed him s' 4 5 C-2 7,962' 7,986' 5,039' 5,055' 24' 6 6/9/2004 Squeezed '1 Emit A-9 C-2 8,014' 8,024' 5,074' 5,081' 10' 6 10/23/2000 Squeezed ` ��� . C-2 8,024' 8,062' 5,081' 5,106' 38' 6 6/8/2004 Squeezed ' Sterling A-11 a" &2 �,* " Cement retainer set at 7,796'MD, *,,,,r '''.,4'•4' 8 Sterling Cl and C2 intervals squeezed = k4C 18,2 CT un-stung and 3bbls cmt,131', 1/4 placed on top of cement retainer, ¢1/2„ , ;+`.1 leaving TOC at approx.7,665'MD Note:Tagged TOC was 7,505'kb TD=8,320' PBTD=6,040' witnessed and pressure tested to 1,600psi 2-29-12. MAX HOLE ANGLE=64°@ 1,790' INCLINATION DETAIL Inclination approx.60 deg,2,300-5,800 ft MD Inclination 61°dropping to 402,5,800 ft MD to TD Updated by TEK 08-18-17 • s • Cannery Loop Unit CLU #6 04/03/2017 H corp \ln.h.+.LI.0 Cannery Loop Unit Tubing hanger,Vetco Gray, CLU#6 11x4%IBTbox btmx4 Y. 9 5/8 x 7x 4% IBT box top,w/6 1/2 od neck,4"type H BPV profile, DD-NL material BHTA,Otis,4 1/16 5M FE x 6.5 Otis quick union top H Valve,Swab,WKM-M -'—'^��I 4 1/16 5M FE,HWO, ' " EE trim / i `0 Valve,Wing,WKM-M, �-- - 3 1/8 SM FE,HWO, Valve,Wing,SSV,WKM-M, LL_Ll) 1_LLa' EE trim 3 1/S 5M FE,w/15"operator 3 I i 0 Valve,Upper master, ,--%-'774-..4.\ WKM-M, '`. Q\ 4 1/16 SM FE,HWO,EE trim J 1131'71 Valve,Master,WKM-M, � 4 1/16 5M FE,HWO, � }�� EE trim Pi? i PI I- 0. .-,laq • Starting head,Vetco,11 5M x I . 7"SOW,w/2-21/165M ' SSOi 1(3) n 1 jV 1 I I�� LI { fr\ I 7„ 4/„ • X33 Seth Nolan Hilcorp Alaska, LLC �� 2,GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 HAlaska,LII. Fax: 907 777-8510 e12s E-mail: snolan@hilcorp.com DATE 08/24/2017 To: Alaska Oil &Gas Conservation Commission Meredith Guhl Petroleum Geology Assistant II 333 W 7th Ave Ste 100 �������� Anchorage, AK 99501 AUG 242017 DATA TRANSMITTAL AOGCC CLU 6 Electronic File: 1 L 50133204920000 CLU-6 PE?C 09182000.las 8/24/2017 9:28 AM LAS File 2,478 KB Please include current contact information if different from above. SCANNED AUG 3 02°17 Please acknowledge receipt bv„si9ning and returning one copy of this transmittal or FAX to 907 777.8337 �" Received 8y: Date: RECEIVED STATE OF ALASKA AL KA OIL AND GAS CONSERVATION COMOSION AUG 2 1 2017 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon Lf Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate El Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: CT/CO W/N2 ❑., 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑✓ Exploratory ❑ 200-033 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-133-20492-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0060569/FEE-TR73/ADL0324602 Cannery Loop Unit(CLU)06 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kenai C.L.U.Field/Sterling Undefined Gas 11.Present Well Condition Summary: 6,040';6,300';6,821'; Total Depth measured 8,320 feet Plugs measured 6,910';7,505' feet true vertical 5,277 feet Junk measured 6,031 (fill) feet Effective Depth measured 6,040 feet Packer measured N/A feet true vertical 3,845 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 91' 9-5/8" 91' 91' 10,900psi 7,950psi Surface 2,964' 7" 2,964' 2,320' 6,020psi 3,400psi Intermediate Production 8,124' 4-1/2" 8,124' 5,148' 8,430psi 7,500psi Liner Perforation depth Measured depth See Attached Schematic NtiED by LL I True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 8,124' 5,148' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 30 Subsequent to operation: 0 0 0 0 81 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory Development❑., Service ❑ Stratigraphic El Copies of Logs and Surveys Run El 16.Well Status after work: Oil ❑ Gas Q WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP El SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-136 " Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcoro.com Authorized Signature: i� Date: ?/Z6//, Contact Phone: 777-8420 Form 10-404 Revised 4/2017 5,1 l'. t ° i 7 RBDMS Or AUG 1 5 2017 Submit Original Only At f7di7 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date CLU-06 CTU 50-133-20492-00 200-033 5/30/17 8/1/17 Daily Operations: 05/30/2017 -Tuesday MIRU SLB CTU 13 with 2.375" CT. (Hilcorp pipe). 24 hr AOGCC BOPE test witness notifications submitted 5/29/17 @ 17:09. Witness waived by Jim Regg 5/29/17 @ 2304 hrs. Start BOPE test. Test all rams and valves to 250/4,000 psi. BOPE test complete. Location secure. Crews off location. 05/31/2017 -Wednesday Obtain PTW. Hold safety meeting. Discuss job procedure and review JSA. Pick injector head. Make up 50' of lubricator. Due to 2.375" CT memory each stick of lubricator had to be pulled with come-alongs. Make up BHA. Install dimple connector. Pull test 50K. Re dimple. Dimple connector 2.875" OD, 2.88" OD MHA (DFCV, HYD disco), 2.88" OD slinger, 2.88" OD weight bar, 2.88" OD weight bar, 2.88" OD maximus dual acting oil jars, 2.88" OD HYD disco 3/4" ball, 3.25" hydraulic overshot. Total tool length 26.97' ( pressure test tool string to 250/3,500 psi. Stab on well. Pt stack 250/4,000 psi. Bleed down. Open master swab 23.5 turns. RIH. Returns at surface from 0'. 0 psi initial WHP. Perform weight checks as needed. 5,784' WT chk 13K. RIH WT-5,300 lbs. Stacked to -16K @ 6,212' CTMD. PU stack )-- at same. Online 3 bbls/min down CT 4,100 circ, 3 bbls return micro motion. Weight slowly breaking back. No increase in CT circ pressure. Continue to RIH. Bottoms up complete of 60.5 bbls. RIH stack weight at 6,337' CTMD. �t Started loosing returns. 3 bbls in 2 bbls out. Continue to RIH and stack 13K down at 6,503' CTMD. PU wt 13K, slack off and RIH past stack depth at 45 ft/min. Stack 15K down at 6,704' CTMD. Fist time we stacked weight and saw circulation pressure increase indicating we have fishing neck in overshot profile. Circ pressure climbed from 4,100 psi to 4,356 psi. Weight break back. RIH 33 ft/min slack of 10K at 6,718' CTMD. Bottoms up complete from 6,704' CTMD. Shut down pump. Stack 20K down on fishing neck. PU 25K over pull or 38K. Saw small jar lick. Slack off and cock jars. 4 times up jar. PU to 68,000 lbs. Jars fired. CT POOH at 18-22K bobbles. Looks like we have fish. RIH and stack 20K down at 6,718' CTMD. PU clean at 18-20K. POOH to surface and check for fish. Tagged up. Close master and swab. Pop off. Gun string recovered. All shots confirmed fired. Fish description from top to bottom. 1.0', 1.375" OD rope socket, 1.5', 3.125" OD firing head, 7' 3.125" OD GR/CCI, 15' 3.375" perf guns. Brea<�down fish and tool string. Set injector on back deck. Install BOPE night cap. Location secure. Crews off location. 06/01/2017 -Thursday Obtain PTW. Hold safety meeting. Pick injector head. Make up 10' lubricator. Install BHA dimple connector, 2.125" DFCV, 2.125" stinger x2, 2.125" ball drop jet swirl nozzle. BHA length 10.2' Stab on well. PT stack 250/4,000 psi. RIH. 220 bbls in supply tank 3 % KCL. Tag @ 6,738' CTMD. RIH wt-2K, PU WT 23K. Online 3 bbls/min down CT 4,100 circ pressure. Pump bottoms up. Small 20 bbls of dark grey fluid. Continue pumping until returns clean up. 120 bbls pumped. Shut down fluid pump. Park CT at 6,415'. Mix up polymer pil 22.5 lbs per bbl. 13 bbls total. Pill at nozzle. Let 1 bbl turn the corner. Lay in pill 1:1 pumping at 1 bbl/min and POOH at 65 ft/min. 5,789' gel out of nozzle. Shut down and pick up to 5,600'. Line up down back side, close choke and inject 10 bbls at 1 bpm. WHP 125 starting. After 10 bbls pumped. WHP was 245 psi. POOH to surface. Tagged up. Pop off well. Stack back injector head. • • I 11 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date CLU-06 CTU 50-133-20492-00 200-033 5/30/17 8/1/17 Dally Operations 06/02/2017- Friday PTW. Hold safety meeting discuss JSA and job procedure. Online bull heading 3% KCL down well to pt poly plug. Pressure up to 500 psi and shut down. WHP dropping. Pressure up to 1,000 psi and shut down. WHP dropping 1 psi per second. Call town to discuss. Conference call with chemical manufacturer. Stab on well. PT stack. RIH. Pull on water to displacement tanks. Mix up 18 bbls of 22.5 lb per bbl poly ultra seal. Mix in ultra seal plus (saw dust),first 9 bbl batch mixed with 3 bags of ultra seal plus. 2nd 9 bbl batch mixed with 6 bags of ultra seal plus. On depth 6,415' CTMD. Continue circulating tanks and mixing ultra seal plus. Mix complete. Zero in and out micro motion. Circulated displacement tanks at 5 bbls/min to shear. Total bbls pumped for circulation 500 bbls. Online with pill down CT. 41.8 bbl CT volume. 3.3 bbls/min 4,100 psi. Pill at nozzle. Let .5 bbls/turn corner. POOH at 65 ft/min and pump rate of 1 bbl/min. Lay in from 6,415' to 5,758' CTMD. Shut down and pick up to 5,600' CTMD. Line up down back side and inject 10 bbls down backside. WHP climbed to 2,750 psi and broke over on last bbl of pill. Shut down. WHP bleeding down. Stay parked at 5,600' CTMD. Clean up displacement tanks. POOH to surface. Keeping well full. Tagged up close master swab. Pop off well. Stack back inj head. Wellsite secure. 06/03/201 a urday Waiting o poly plug to set 06/04/201 -Su Obtain PTW. Hold safety meeting. Review and discuss JSA. Online down back side to PT poly plug to 3,000 psi. Pumped 1.7 bbls pressure 1,000 psi. Shut down. WHP bleeding down 1 psi per second. Online 1 bbl/min to 2,000 psi. Shut down to monitor WHP. Still bleeding down. Online to see what pressure will break over at 2,164 psi. Call town to discuss plan forward. PU inj head. Stab 10' lub. Make up BHA. Stab on well. PT stack 250/4,000 psi. Bleed down. Open master swab. RIH. 22 pails of heavier 27 lb per bucket and 11 sacks of poly seal plus. Start pulling on fluid to displacement tanks. On depth 6,415' CTMD. Mix up 1 bucket per bbl of the 27 lb per bucket of poly seal. 19 bbls mixed up. The 27 lb bucket is making thicker gel and seems to shear better. Attempt to mix in poly ultra seal plus. Gel is getting too thick. Mixed 1.5 bags of poly seal plus and decided to send it down hole. Lay in pill from 6,415'- 5,758' CTMD. Shut down and PU to 5,600'. Injected down backside. 10 bbls. WHP broke over after 3 bbls injected and stayed at 1,236 psi. Clean up displacement tanks. POOH to surface keeping well full. Tagged up. Rig back injector head. SDFN. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date CLU-06 CTU 50-133-20492-00 200-033 5/30/17 8/1/17 Daily Operations: 06/05/2017- Monday Obtain PTW. Hold safety meeting. Discuss JSA. Line up down back side for 300 psi PT. 300 psi on WHP. Shut down and monitor for 15 minutes end pressure 289 psi. PU injector head. Stab 10' lub. Make up BHA. 2.5' CC, 2.375" DFCV, 2.375" stingerx2, 2.375" ball drop/jet swirl nozzle. Stab on well. PT stack 250/4,500 psi. RIH. Start seeing light weight stack at 6,200' CTMD. Stopped coil and weight broke back. Could be poly gel. PU to 6,100' CTMD. Online with 3% KCL down CT. 3 bbls/min returning same. Wash down to PBTD found at 6,828' CTMD. Bottoms up from PBTD compete. Pick up and wash across perfs and RIH back to PBTD. Pump bottoms up. Returns of thick liquid/ poly gel and thick clumps of poly clear. Returns are the same consistency as samples taken during all 3 plug attempts. Park CT at 6,828' CTMD. Close choke and PT again to confirm first PT was at formation vs. plugged tubing. 300 psi. Watch for 15 minutes end 297 psi. N2 cooled down. PT 250/4,500 psi. Plan is to lift above perfs to unload hydrostatic pressure. RIH to PBTD and continue to lift. Expecting 107 bbls tubing volume. 1,000 scf/min 1587 circ, returned 160 bbls and shut down. Circ pressure with CT at PBTD not bleeding down past 1,300 psi indicating column of fluid on back side of CT. 200 total bbls returned from wellbore. We have formation influx. Called town to disc. Plan is to POOH to surface and establish injection rate and record pressure to determine plan for cement squeeze. CT displacement to PBTD is 37 bbls. Tagged up at surface. Close swab. Bull head down tubing to fill well from CT displacement. Caught fluid after 7.8 bbls pumped. 1.5 hrs well influxed 29 bbls of fluid. 1 bbl/min bullhead and pressure started breaking over gradually 1,289 psi. Increased to 2 bbls/min pressure broke over at 1,500 psi injection pressure. Swab master closed. Blow down stack. Pop off well. Stack down inj head. RDMO CTU 13. 06/07/2017 -Wednesday PTW and JSA. Mobe to location. Spot equipment. Wing valve leaking out of stem and grease zerk.Talked to Clint and he is on his way out to replace packing. Keep rigging up lubricator. PT 250 psi low and 3,000 psi high. Packing replaced in wing valve. RIH w/ Halliburton PLT tool with roller stem and E-line knuckle joint above PLT tool to 5,550' could not get past this spot. It was not sticky. Started pressuring up well from jumper line from CL-05RD well. FL was at 120'. Pressured up tubing to 1,400 psi but still couldn't get down. Spinner was packing off too. POOH. TP was 1,310 psi. FL was 1,150'. Added roller stem for wt. Clean spinner(not too bad looked like E-line grease). RIH w/ PLT(TP- 1,100 psi). Started pressuring up well back up. Found FL at 1,450'. Tools set down at 5,576'. Worked tools to 5,660' (1,760 psi), 6,136' (1,850 psi), 6,373' (1,950 psi), lost hole to 6,340' (2,100 psi) and 6,345' (2,150 psi). It got real sticky here and couldn't go any deeper. Called town and decision was made to blow well down while trying to get past perfs from 6,395'to 6,409' (A-9 sand). Pulled up hole and found FL at 2,770' (2,150 psi). Started blowing well down and dropped to 2,814' at 1,300 psi and started back up to 2,812' at 800 psi. Ran back down to 6,306' and saw flow at 750 psi.Tried to run by perfs but sat down at 6,345' again. Spinners would lock up past 6,306'. Kept trying to get past but could not. Log out of hole and found fluid level at 1,138' with 100 psi on well. POOH and well has 0 psi on it. NOTE: All depths are correlated to Pollard CBL dated 6-29-12. Rig down lubricator and turn well back over to field. 06/08/2017 -Thursday • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date CLU-06 CTU 50-133-20492-00 200-033 5/30/17 8/1/17 Daily Operations: Obtain PTW. Hold safety meeting. Review and discuss job procedure and JSA. Spot equipment. Rig up SLB CTU 13 with 2.375" CT. Start BOPE test. 24 hr BOPE test witness notification sent 6/7/17 @ 16:12. Witness waived by Jim Regg on 6/7/17 @ 16:39. Test all rams and valves to 250/4,000 psi. BOPE test complete. Make up 2.375" dimple connector. Pull test 25K. SDFN location secure. 06/09/2017 - Friday Obtain PTW. Hold safety meeting. Discuss JSA and job procedure. Fire equipment. Pick inj head. Make up 10' lubricator. Make up BHA: CC 2.375" x .580', x over 2.375" x .698', checks 2.170"x 1.160', stinger 2.170"x 4.0'x nozzle ball drop 2.5"x.5'. BHA length 6.938'. Stab on well. PT stack 250/4,000 psi. Correct depth to RKB. 8.5' corrected depth at coil zero. Online for coil volume check. Micro motions not working. Swap out cables. Open master swab. RIH. Fluid volume on location 310 bbls of produced water. 3,211' CTMD SLB hydraulic power pack started grinding. Lock in traction and set brake. Called out mechanic. SLB NPT. Diagnose SLB power pack. POOH to surface. Tagged up. SLB dialed out power pack. Start injectivity test down 4.5" production tubing. 1 bbl/min pressure increased to 2,800 psi and broke over to 1,770 psi and started climbing. Pressure increased to 3,000 psi. Shut down pump. Pressure slowly falling off/bleeding off. Online with pump 1.5 bbls/min pressure would climb and break back, then climb to 3,000 psi after shutting down pump it would slowly bleed down. Tubing plugged with poly seal liquid. SLB tractor shut down. PTO finally gave out. SLB bringing out auxiliary power circuit. Make fittings. Pop off well and trolley to back deck. Stack down inj head. SLB moving coil unit back to shop. Auxiliary equipment to remain on location. 06/19/2017 - Monday Permit to work. Hold safety meeting. Wait on CTU unit 13. Unit on location at 10:00 hrs. Still on NPT. Existing CTU pump, iron, choke, tanks rigged up upon arrival. Move in CTU 13. Make up BOP's on well. Start BOPE test. 24 hr test witness notification sent 6/18/17 @ 14:28. Test witness waived by Jim Regg via phone call on 6/19/17 at 10:30. Test all rams and valves to 250/4.000 psi. BOPE test complete. Pick inj. Stab 10' lubricator. Make up BHA. CC 2.375" ODx .580'. x over 2.0" OD x .698', DFCV 2.170" OD x 1.160', stinger 2.170" OD x 4.0', nozzle 2.5" OD x .5'. BHA length 6.938'. Stab on well. Correct depth tho 8.5' from coil zero. RKB correction. PT stack to 250/4.000 psi. Open well. RIH. 360 bbls in supply tank, 20 bbls solids IOT tank, 0 bbls OOT. Fluid pack CT. Park at 6.000'. CT and well fluid packed. Close choke and inject at 1 bpm 178i psi, 2 bbls/min 2020 psi. Open choke TIH pumping 3 bbls/min 2500 circ, 40 whp. Wash across perfs 2 times from 6,350'-6,450'. CIH to PBTD. Pump bottoms up. PU and wash across perfs two more times. pump bottoms up. POOH to surface.Tagged up at surface. Close master swab. Pop off well. Break down tools and lubricator. In] head on deck. Night cap installed on BOPE. Location secure. SDFN. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date CLU-06 CTU 50-133-20492-00 200-033 5/30/17 8/1/17 Daly Operatrons �� _ fir . -17,MALL ' 06/21/2017-Wednesday Hold safety meeting. Discuss job procedure and review SLB JSA. Pick inj head. Stab 10' lubricator. Make up BHA. 2.375" CC, 2.375" DFCV, 2x 2.375" stinger, 2.6" ball drop/jet swirl nozzle. BHA length 9.62'. Stab on well. PT stack 250/4,000 psi. Correct CTMD to RKB. +8.5'. Bleed down PT to zero. Open master and swab 29.5 turns. Initial WHP 0 psi. RIH. Well is full. Returns at surface. SLB cement crew on location. Hold safety meeting. Spot pump and ABT. Rig up cement equip. 6,000' CTMD weight check 17.8K. RIH and tag PBTD 6,821' CTMD. Pick up off bottom 24K. Stop CT at 6,800'. Close choke and perform pre cement injection test. Pump 1 bbl/min pressure broke over and flat lined at 1,500 psi WHP. Pick up coil tension at 6,821'to 24K. Park and set inj brake. Blending cement. Cement wet at 11:28 am. Online with class G cement. Zero in hole micro motion when density increaed to 16.3 ppg. Swap to water density dropped back to 8.6 ppg. .8 bbls of cement loaded in CT. Close in CT reel. Clear cement line down backside iron to open top tank. 5 gallons of contaminant added to return tank. Line up fresh water with CT pump. Online down CT increase rate to 2.5 bbls/min to spot .8-1 bbl cement pill. CT reel volume 41.8 bbls. slow rate to 1 bbl/min at 39 bbls away. 41.8 shut down pump and pick up OOH to 6,429' CTMD. Mix water loaded in cement pump. CT parked at 6,429'CTMD. Online with cement down CT zero in hole MM when density increases 15.7 ppg. mixing cement on the fly. 16 bbls pumped swapped to post flush with 5 bbls of fresh water. Close in choke with 3 bbls of fresh out of 5 pumped to keep heavier cement from falling out and U-tubing. Shut down cement clear pump line. CT pump online 2.5 bbls/min crack choke for 1:1. 42 bbls pumped pick up and lay in cement at 1 bbl/min 65 ft/min from 6,429' to 6,375' RKB. 6,375" CTMD .63 bbls cement pumped and layed in 1:1 close choke. Start squeeze 1.5 bbls/min pressure increased to 2,375 psi. Shut down pump for hesitation squeeze. Pressure rapidly broke over to 1,883 psi. Online cont squeeze. @ 1.5 bbls/min. consistent 1,840 psi flat line for remainder of squeeze. 57 bbls on MM. Cement out. PU to 6,260'. Stop coil and monitor static well bore conditions to see what WHP drops to. WHP bleed down slowly from 1,883 to 1,243 psi. Previous injection test with water WHP bleed down to 160 psi. Good indication of proper cement squeeze when WHP flat line at 1,243 psi. Crack choke and online with CT pump @ 2 bbls/min. POOH at 120 ft/min. Maintain 1,200-1,250 psi on choke while POOH to surface. Tagged up close master swab 29.5 turns. SITP 1,230 psi.Total fresh water pumped 203 bbls/ 1st stage cement at 6,821' CTMD .8 bbls. 2nd cement stage 16 bbls of cement pumped. 15.4 bbls injected into formation. .6 bbls of cement in tubing from 6,429'-6,375'. Cement starts to setup atfer 6 hrs from wet time. Pop off well. Rack back injector head. Night cap installed. Well secure. CTU unit walk around complete. Crews off location. PT cement and mill Friday. • 4110 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date CLU-06 CTU 50-133-20492-00 200-033 5/30/17 8/1/17 Daily Operations: 06/23/2017- Friday Obtain PTW. Hold safety meeting. Discuss job procedure and review SLB JSA. Line up down 4.5" tubing. 50 psi initial WHP. Bled down from previous SITP of 1,200 psi. Pressure test tubing to cement plug to 2,000 psi. 2,171 psi. Start 5 minute test. Test complete end pressure 2,136 psi, loss of 35 psi over 5 minutes. Bleed down WHP. Close master and swab. Pick inj head. Stab 20' lubricator. Make up Weatherford motor mill assembly as follows: 2.875" dimple connector, 2.875" HD MHA 7/8" ball disco, 2.875" circ sub 5/8" ball. 2.87" CTD motor, 3.8" excalibur mill. Total BHA length 14.21'. PT MHA 250/3,500 psi. Stab on well. Correct coil zero to RKB. Add 8.5' to depth at coil zero. Pressure test lubricator 250/4,000 psi. Open master swab. RIH. 6,140' CTMD. RIH WT-300 lbs. PU wt 17.8K. Coil stacked 5K at 6,200' CTMD and then broke back to RIH WT of-300 lbs. Pick up and come online down CT at 2.3 bbls/min 3,200 psi circ pressure. RIH 20 ft/min slow down pump rate to 1.5 bbls/min. Stack solid at 6,323' CTMD. Good motor work. 3,800 psi. Mill to 6,430' and weight started breaking back. Look to be through main cement plug 6,443'. Perform weight check and back ream to top of perfs. Picked up to 6,300'. Turn around and RIH past 6,430' at 35 ft/min. Start stacking weight at 6,760' CTMD. Bottom of A-11 is 6,764'. Milling from 6,760'to 6,775' CTMD. Pick up 3' and start bottoms up. Chase bottoms up OOH to 6,200' CTMD while back reaming. Run back in to 6,775'. Bottoms up complete. 345 bbls pumped for mill job, close choke. Attempt to PT tubing. Increase pressure to 2,000 psi. Shut down 2,165 psi. Pressure fallling 15-20 psi per second. Onine at .5 bbls/min to check injection rate. .5 bbls/min flat line pressure at 1,750 psi. Called town to discuss. Attempt injection rate at 1 bbl/min 2,100 psi. Pre-cement injection rate at 1 bbl/min was 1,500 psi. Looks like cement did some damage. LO rate 20-30 psi/sec. POOH to surface. Tagged up. Close master swab. Pop off well. Current TOC 6,775' RKB. Plan forward is to cement same zone in the AM. Rack back injector head. Location secure. 365 total bbls pumped. 410 bbls returned. • • P-IN Hilcorp Alaska, LLC g Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date CLU-06 CTU 50-133-20492-00 200-033 5/30/17 8/1/17 Daily Operations: 06/24/2017-Saturday Obtain PTW. Hold safety meeting. Discuss job procedure and review JSA. Pick inj head. Stab 10' lubricator. make up BHA. 2.375" dimple connector, 2.375" DFCV, 2x 2.375" stinger, 2.375" ball drop nozzle with jet swirls. 9.87' BHA length. Stab on well. PT stack 250/4,500 psi. Correct depth to RKB. Input depth on CCAT to 8.5'. Open master swab 29.5 turns. Initial WHP 0 psi. Rig up cement equipment. WT chk 24K @ 6,771' CTMD. Hold safety meeting with cement crew and discuss job procedure. Plan is to lay in cement from PBTD (6,821') to above the A-9 perfs tO 6,770' CTMD. Tagged PBTD. Pick up 25K. Set injector brake. Pulling on fresh water for cement job. Perform inj test with CT pump. 1 bbl/min 1,935 psi. Online with cement. Zero in hole MM when density reaches 16 ppg. Pumping cement down CT at 2.8 bbls/min. 2,137 psi circ pressure. 28 bbls pumped followed by 5 bbls of fresh water. Pinch in and close choke with 2 bbls of fresh water left to go. (Keep cement from falling out of CT and U-tubing.) Cement at nozzle. 41.8 bbl CT volume. Let .5 bbls turn corner. Lay in 1:1 from 6,770'-6,335' at 1 bbl/min 65 ft/min. 5.78 bbls of cement layed in 4.5" tubing. CT @ 6,335' close choke and attempt to inject. WHP steadily increasing at .8 bbls/min 2,275 psi shut down and hold squeeze pressure for 5 minutes. Pressured up to 3,327 psi. Called town, got the ok to pressure up to 4K. 4,200 psi holding rock solid. Didn't get any cement pushed away. Pressure just increased. Bleed pressure down to zero. Ramp up to 4K twice. No break over. Mix up 20 bbls of cement retarder/contaminent. Circulate remaining cement to surface. Drop .5", call to plug ball drop on CT nozzle. Better side jetting for clearing cement from tubing wall. Dump 5 gallons of retarder in return tank. Circulated two bottoms up or until returns cleaned up. 380 bbls pumped. POOH to surface. SITP 1,400 psi. Master swab closed. Let cement setup for 24 hours. Crews off location. 06/25/2017-Sunday Hold safety meeting. Discuss JSA and job procedure. Pick inj head. Stab 20' lubricator. Make up BHA, dimple connector, DFCV, CIRC sub, motor and 3.8" parabolic mill. PT stack 250/4,000 psi. Bleed down. Open master swab 1,386 psi on WHP. Pressure held for 24 hrs. Did not bleed down. Pressure test cement to 4,000 psi. Held solid. Bleed down and open choke to take returns. RIH. Tag TOC @ 6,403' CTMD. Milling 1-2' per minute. @ 6478' PT perfs to 2000 psi. Held solid. continue to milling. Milled to 6611' CTMD. Loosing ROP. Mixed 20 bbl gel sweep. Pumped around and returned to surface. Attempt to mill. No increase in ROP. POOH to surface to swap bits. Swapped from 3.8" parabolic mill to 3.8" 5 bladed junk mill (more aggressive teeth and deeper blades). Stab on well PT stack. 250/4,000 psi. Open well, RIH. Start milling at 6,611' CTMD. ROP increasing to 2-3' per minute. Stopped milling at 6,780' CTMD. Circulate bottoms up. Wiper trip 500' up hole. Close choke and attempt to PT cement squeeze to 2,000 psi. Pressure dropped below 2,000 psi. Online to pressure up. 2,378 pressure broke over. Shut down pump. Pressure bleed down to 0 psi. Looks like we broke through our cement plug. Called town to discuss. POOH to surface.At surface. SITP 0 psi. Close master swab 29.5 turns. Break down tools. Install night cap. Well secure. Crews off location. Will attempt to locate CT mulit set test packer. • • HilcorpAlaska LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date CLU-06 CTU 50-133-20492-00 200-033 5/30/17 8/1/17 Daily Operations: 06/26/2017- Monday Sign in. Mobe to location. PTW,JSA and SIMOPS w/Halliburton and SLB pumping. Rig up lubricator and pressure test SLB and HLB to 250 psi low and 4,000 psi high. RIH w/ HLB P/T/2 spinners/CCL-GR to 6,300'. Start pumping fluid at 1 bpm at 2,080 psi and log thru perfs (6,395' - 6,409') down to 6,740'. Logged back up to 6,370'. Went back down to 6,415' and did a stop there. Tools were stuck due to hydrostatic. The wt was in the perfs. Bleed tubing pressure off and tools came free. Performed stops below and above perfs. Determined fluid was injecting into perfs and no injection below perfs. While injecting pressure built to 2,200 psi and broke over to 2,080 psi and would build again. Had pressure up to 2,600 psi and let it bleed off to 2,000 psi one time before it broke over. Final pressure that fluid was injecting was 1,300 psi at 1 bpm. Injected 80 bbls of fluid total. Rig down lubricator and turn well back over to field. We tagged TOC at 6,778' correlated to Pollard CBL. Coil tubing milled cement to 6,780'. 07/09/2017 -Sunday Sign in. Mobe to location. PTW and JSA. Spot equipment. Rig up lubricator and pressure test to 250 psi low and 4,000 psi high.TP-0 psi. RIH w/3.73" GR/JB and tie into OHL. Tool set down at 4,600' and pick up and chase something down to 5,650' and it went away. Tag bottom at 6,766'. POOH.JB had a little bit of Beluga mud in it. MU CCL/GR, 3.6" x 25' Owens tubing patch. RIH and tie into OHL. Patch set down at 6,409' (bottom of perf).Tried several times to get deeper but could not. Had 400 lb over pulls. Call town and discussed. POOH and take 5' of the patch off. The perfs are 14' from 6,395' to 6,409'. MU CCL/GR, 3.6" x 20' Owens tubing patch. RIH and tie into OHL. Patch sat down at 6,407'. Tried several times at different speeds and didn't make any footage. Call town and discussed. Will talk with slickline and get some tools and plan together to figure out what is stopping patch. Lay patch down and rig lubricator off tree. Secure well and SDFN. 07/10/2017- Monday Sign in. Mobe to location. PTW and JSA. Rig up lubricator and PT 250 psi low and 3,000 psi high. TP -0 psi. RIH w/3- 3/8" x 15' spent guns as dummy (3-1/2" OD) and sat down at 6,444' KB SLM.Tried to go thru but no success. POOH. RIH w/3-3/8" x 20' spent guns as dummy (3-1/2" OD) and sat down at 6,444'KB SLM.Tried to go thru but no success. POOH. RIH w/3.85" GR and sat down on X nipple at 6,074' KB SLM (35' deeper than E-Line correlated to OHL). The nipple depth is at 6,049' correlated.That would put slick line tag depth the same as E-line tag depth yesterday at 6,409'. POOH.This GR run was to compare slick line KB depth to E-line correlated depth. Called town and discussed. RIH w/3-3/8 x 20' spent DG with a 3.80" broach on the end of gun. Set down at 6,444' KB SLM (6,409' correlated to OHL). Tried to broach down but could not. POOH. Call town and discuss. If we can set plug at 6,404' correlated to OHL then we will set 20' patch. We got down to 6,409' yesterday with patch. Rig down lubricator and secure well. Well have E-line out in the AM to set patch. S Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date CLU-06 CTU 50-133-20492-00 200-033 5/30/17 8/1/17 ate fl q a .; ru ,, , 07/11/2017-Tuesday Sign in. Mobe to location. PTW and JSA. Rig up lubricator and PT 250 psi low and 3,000 psi high.TP-0 psi. Slick line saw FL at 2,620' WLM yesterday. RIH w/CCL/GR, 3.60" x 22' (2.99" ID) Owens Patch plus sealing elements, tie into Pollard CCL/GR/3.73" GR Log dated 7-9-17 and patch set down at 6,409'. Get ok to set patch from 6,409'to 6,387' (22' from element to element). Lost 200 lbs when patch set. POOH and setting tool looks good. It is possible that the perfs are covered by patch. RIH with 2.50" x8' DG and tie into Pollard CCL/GR/3.73" GR Log dated 7-9-17.Tag bottom at 6,766'. Logged up to 4,500'. POOH. Had no problem going thru patch. Send log to town. (Had to shift the log 2' down which made the patch from 6,409' to 6,387' which I have already corrected patch depth above). RIH with 2.50" x 20' DG and tie into Pollard CCL/GR Post Patch Rev 1 Log dated 7-11-17.Tag bottom at 6,766'. POOH. Went thru patch ok. POOH. Rig down lubricator and secure well. NOTE: All depths for PBTD and patch on this report are corrected back to Pollard C LU -6 GR/CCL Post Patch R1 dated 7-11-17 approved by Benjamin Siks. 07/12/2017 Wednesday Obtain PTW. Hold safety meeting. Discuss JSA and job procedure. RU CTU 13 and associated equipment. 24 BOPE test witness notification sent 7/11/17 @ 13:35. Witness waived by Jim Regg 7/11/17 @ 13:44.Test all rams and valves to 250/4,000 psi. Accumulator draw down test. BOPE test complete. No failures. Line up fluid pump down tubing. Online to fill well. Well pressured up after 1.3 bbls pumped. Pressure up to 515 psi for 30 minutes.Test end 103 psi. Open choke and let well bleed down. No flow at return tank. Close choke and pressure up to 525 psi. 30 minute test end pressure 109 psi.Tubing patch not holding surface pressure test. Report results to town engineer. Close master swab. Location secure. Crews off location. 0700 hrs start to blow well dry with N2. 07/13/2017-Thursday Hold safety meeting. Discuss JSA and review job procedure. Pick injector head. Make up CC, DFCV, Stinger,Jet swirl nozzle. BHA OD 1.75".Total length 6.3'. Stab on well. PT stack 250/4,000 psi. Bleed down. Open master swab 23.5 turns. RIH. Initial WHP 0 psi. Well is static not flowing.Transfer and cool down N2. Weight checks as needed. Online with N2 1,500 scf/min.Tag PBTD 6,767' CTMD. Solid tag. 5K slacked off.Strap return tank. 22 bbls returned from coil displacement. PU OOH until returns increase at surface. 6,046' CTMD fluid returns at surface. 1,500 Circ, 57 psi WHP. 38 bbls returned. Start pinching in choke. 1,593 CIRC 75 WHP. Choke pinched in one 1.5 turns from closed. 235 WHP 1,524 circ, 65 bbls returned. 378 WHP 1,527 circ. Start seeing surges of N2 at surface. WHP 680 psi 87 bbls returned to surface.WHP 707 psi, Circ 1,522 psi. Mostly N2 at surface with surges of fluid. 96 bbls returned. Solid N2 at surface. WHP is starting to fall along with circ pressure indicating hydrostatic column of fluid unloaded. 687 WHP, 1,276 CIRC. POOH to surface. Isolate CT reel and Line up to pump N2 down CTxTubing annuli. 1,500 scf/min. POOH at 125 ft/min. Shut choke to pressure up well. 550 WHP, 1,112 circ pressure.Total bbls returned from N2 lift 96 bbls. At surface. Continue pumping N2 until BHP is reached. Shut down N2. 1,956 SITP on wellhead. Close master swab. Bleed down stack. RDMO CTU 13. 196,000 scf pumped or 2104 gallons of N2. Mobilize coil package to KU 11-07 X. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date CLU-06 CTU 50-133-20492-00 200-033 5/30/17 8/1/17 Daily Operations: 07/14/2017- Friday Sign in. Mobe to location. PTW and JSA. Spot equipment. Rig up lubricator. Wireline unit stopped running. Tried to boost it but wouldn't start. Bring another one from town. Pressure test to 250 psi low and 4,000 psi high. TP - 1,607 psi. RIH w/1=11/16" GPT tool and tie into Pollard CCL/GR Post Patch Rev 1 Log dated 7-11-17.Tag at 6,770'. FL- 6,040' on down pass and 6,046' up pass. Send to town and had to correct GPT log up 2'. POOH. RIH w/2-2/8" GEO HC, 5 spf, 60 deg phase and tie into Pollard GPT Up Pass Before Perf Corrected 2', dated 7-14-17. Run correlation log and send to town. Get ok to perf. Spotted and fired gun from 6,740' to 6,760' with 1,573.9 psi on well. After 5 min TP was 1,572.4. POOH. All shots fired. RIH w/GPT tool and found fluid level at 6,070'. Sat above perfs and operators started bleeding well down slowly from 1,572.4 psi down to 900 psi. Pollard did station logs and making passes. At 974 psi fluid level was 5,280'. Pollard will annotate the surface tubing pressures w/BHP. Log back down from 5,200' to 6,744' and tool set down. Tried to go deeper but couldn't. POOH.Tubing pressure climbed to 924 psi. FL 4,650'. Showed some cooling at A-11 and some water at A-9. Rig down lubricator and turn well over to field. Pollard will send logs tonight. 07/15/2017-Saturday Sign in. Mobe to location. PTW and JSA. Spot equipment. Rig up lubricator. Pressure test to 250 psi low and 4,000 psi high. TP - 974 psi. RIH w/2-1/2" X 10' DD bailer and tag at 6,732' (Per log). Bail to 6,738' . POOH. Bailer had about 4 cups of beach sand in it. RIH w/3.80" fluted centralizer and tagged nipple at 6,049' per log (6,043 WLM KB). Fluid level was 4,326' w/969 psi on tubing. This run was to correlate depth from SLM to log. All depths are perf log depths. Called town and discussed. Rig down lubricator and turn well back over to field. 07/19/2017 -Wednesday Permit, travel to location. Move in and spot equipment. Review JSA. Rig up .125" slickline. Pressure test to 300/2,500. RIH w/ 10' 2.50" DD bailer. Tag fill @ 6,736' KB. Bail to 6,738' KB. Sticky. POOH. Hang up on patch @ 6,428' KB, 1' sticky sand. RIH w/ 10' 2.50" DD bailer. Tag fill @ 6,736' KB. Bail to 6,738' KB. Sticky, POOH. 4" of fill. Gummy. Add 5' wt bar. RIH w/ 10' 2.50" DD bailer, tag fill @ 6,376' KB. Bail to 6,738' KB. POOH 18" fill. No metal marks. RIH w/ 10' 2.50" DD bailer. Tag fill @ 6,738' KB. Drive bailer to 6,740' KB. Have to jar out for over an hour. 1,900# licks and comes free. Bled tubing down to750psi from 925psi. 6" of fill. Cut 100' wire. RIH w/ 10' 2.50" DD bailer. Tag fill @ 6,737' KB. POOH. RDMO.Travel to 11-07X. 07/20/2017 -Thursday Permit, travel to location. Move in and spot equipment. Review JSA. Rig up .160" slickline. Pressure test to 300/2,500. TP -750 psi. RIH w/3.70 B box. Tag fluid @ 4,080' KB. POOH. RIH w/ 10' 2.50 DD bailer. Tag fill @ 6,738' KB. Drive bailer to 6,740' KB 4" fill. RIH w/ 10' 2.50 DD bailer. Tag fill @ 6,738 to 6,742' KB. Sandier material in bailer. Add more weight bar. RIH w/ 10' 2.50 DD bail. Tag fill @ 6,741' KB. Bail to 6,746' KB. 5' sand back. RIH w/ 10' 2.50" DD bailer. Unable to make it through patch @ 6,761' WLM. POOH. Bail bottom damaged. RIH w/3.50" LIB . Tag top of patch @ 6,362' WLM. Lay down lubricator. Secure wellhead. ��� ��� ��� ���y ^i|~ .rr Alaska, LLC Well Operations S~ ~ry Well Name Rig API Number Well Permit Number Start Date End Date CLU'06 CTU 50'133'20492-00 200'033 5/30/17 8/1/17 07/21/2017-Friday Permit,travel to location. Move in and spot equipment. Review]SA. Rig up .160" diok|ine. Pressure test tu3UO/Z,SOO. TP 8O0psi. RIH w/3' 1.87S"' 2.68Cent, 1O' 2.SO" DDbailer. Tag fill @6'741' KB. Drive bailer to6,74S' KB. 3' hard packed sand, S' ofthick sandy slurry. RIH w/3' 1.O7S", 2.68Cent, 10' 2.5O" DDbailer. Tag fill @6,743' KB. Drive bailer to 6,748' KB.Two feet of sand. RIH w/3' 1.875", 2.68 Cent, 10' 2.50" DD bailer.Tag fill @ 6'745' KB. Drive bailer to 6,751' KB. Full bailer. RIH w/3' 1.875", 2.68 Cent, 10' 2.50" DD bailer.Tag fill @ 6,749' KB. Drive bailer to 6,754' KB. Full bailer. RIH w/3' 1.875", 2.68 Cent, 10' 2.50" DD bailer.Tag fill @ 6,754' KB. Drive bailer to 6,759' KB. Full bailer. RIH w/3' 1.875", 2.68Cent, 10' I58" DDbailer.Tag fill @6,7S3' KB. Drive bailer to6,77S' KB. Full bailer. RIH w/3' 1.875", 2.68 Cent, 1Y2.S0" DDbailer.Tag fill @6,77U' KB. Drive bailer to6'756' KB. Bailer has shale and perforating gun debris. 1.5' of sand. Rig down lubricator and secure well. FL ~3,950', TP 750 psi. 07/24/2017 Monday PTVVand]SA. Spot equipment and rig up lubricator. MU P/T/Spinner tool. PT to 250 psi low and 3,000 psi high.TP 775 psi. RIH w/PT with spinner tool and stop at 40'. Could not go deeper and line shorted out. Pull out of hole and find mashed place in line. Cut off—75' of E-line and rehead line. RIH w/ 1-11/16" P/T tool with spinner and tie into HLB Leak Detect Log dated 6'26'17. Make up and down static pass from 6,700'to 6,300' FL 3,727' Start pressuring well up from CLU-O5RD. Started moving fluid at 1,400 psi surface pressure. Made several passes thrupatch at6,38S' to6,408' and made stops above and below patch.Also made stops above pedsat6,7O0' (Open perfs6'740'to6'7G0'). Tagged depth was 6,760' Log showed no fluid entering behind patch. All fluid entering A-il perfs .. Called town and discussed. Decision was made topush fluid away below 6,380' and set C|BPat6,300' Pushed fluid past 6,300' and pulled out of hole while maintaining pressure. Wait on CIBP to come from HLB shop. Plug arrived. MU 3-1/2" CIBP. RIH with 374" OD plug and tie into CBL log dated 6'29'12. Ran correlation log.Spotted plug at 6'300' Set plug with ~1,680 psi on tubing. Lost 100 lb line weight. Picked up 30' and went back and tagged plug. POOH. Good set. Rig down lubricator and turn well back over to field. 07/26/2017 Wednesday PTW and JSA. Rig up lubricator and PT 250 psi low and 3,000 psi high. RIH w/1-11/16" Press/Temp tool and tie into CBL log dated 6-2y-12. Tagged at6'300' (p|ug). Found fluid level at6'2A9' w/l'310psi ontubing. POOH. RIH w/l'7/8" x 5', 1 spf, 60 deg phase and tie into CBL log dated 6-29-12. Ran correlation log and send to town. Get ok to perf from 6'080'to6,085' Spotted and fired gun with 1,306.9 psi. After 5 min TP was 1,323.7 psi and building. POOH.TP 1'4O3.3psi.Tools were falling slow due toangle and probably grease from 1,9OO'to4,9U0'. Fired gun at1408hrs. Put 2.5gals ofdiesel inlubricator. RIH w/3-3/O" (3'l/O" charges) Razor HC, 6spf, 6Odeg phase and tie into CBL log dated G-29-12. Run correlation log and send totown. Get oktoperffrom 6,OO8' to6'l0U' Fired gun w/ 1,430.7 psi. After 5 min pressure was 1,438.1. Fired gun at 1630 hrs. POOH. Gun was dry.TP 1,433.1. Rig down lubricator and turn well over to field. Pack up equipment for the Kalotsa job in the AM. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date CLU-06 CTU 50-133-20492-00 200-033 5/30/17 8/1/17 Daily Operations: 07/28/2017- Friday PTW and JSA. Spot equipment. Rig up lubricator and GPT tool. PT to 250 psi low and 3,000 psi high. RIH with 1-11/16" GPT tool to 4,500'.Tool shorted out. POOH. Check tools and determined GPT tool was shorted. Pollard took tool back to shop to fix. Got tool fixed. RIH w/ 1-11/16" GPT tool and tie into Pollard CBL dated 6-29-12. Found fluid level at 6,020'.TP- 1,511 psi. Ran log to use as correlation log for plug and perf. Sent to town and got ok to use it. POOH. RIH with 3.50" CIBP OD plug to 71'.Tried to go deeper but couldn't. POOH. RIH w/3.61" GR/JB to 71'. Spud on obstruction but did no good. POOH. Had ice inside of GR. TP 1,480 psi. Take GR offJB (2.77" OD) and run in hole to 71' while waiting on methanol. Could not run past this depth. POOH. Dump 3 to 4 gals methanol and open well. Let methanol fall on plug. Wait 15 min and go in hole with 3.61" GR/JB. Found plug at 41'. POOH. Dump 3-4 gals of methanol and wait 15 min. RIH and chase plug from 51' to 71'. Dump 3 to 4 gals more methanol. Started pressuring up well from 1,480 psi and well broke over and started pushing plug down hole at 1,535 psi. Followed ice plug with GR/JB and at 1,200' plug went away. Kept gas to well until we reached 6,100'. Shut gas off and POOH.TP - 1,535 psi. RIH with 3.50" CIBP OD plug and tie into GPT log dated 7-28-17. Spot plug at 6,040'. Set plug with 1,531.4 psi. Lost 100 lbs of line wt when plug set. Picked up 30' and went back down and tagged plug. Looks like good set. POOH. RIH w/ 1-11/16" GPT tool and tie into Pollard GPT Tool log, dated 7-28-17. Found no fluid level. TP- 1,513.2 psi. RIH w/3-3/8" (3-1/8" charges) Razor HC, 6 spf, 60 deg phase and tie into CBL log dated 6-29-12. Bleed tubing down to 1,312.4 psi. Spot gun from 5,881' to 5,901'. Fired gun with 1,312.4 psi and after 5 min 1,336.2.Tools were stuck after shot. Called town and discussed. Worked our way up from 1,250 lbs to 3,000 lbs at 200 lb increments and pulled out of rope socket at 3,000 lbs. Get to 170' and line gets tight. Push on line and line jumped up hole. Had to clamp and cut line. 07/29/2017 -Saturday Continue to strip wire from well (170' total). Got all wire out of hole. Wire end showed that it pulled out of rope socket. Should only be tools in well. Rig down lubricator and turn well over to field to fish E-line tool string. TP- 1,400.7 psi. Arrive on location, TGSM, sign permits talk w/company rep. Begin rig up. RIH w/ 1-3/8 JDS w/core nut w/ 3.75 bell guide to 1,800' KB, fall slow to 3,800' KB, can't fall any further, POOH. R/U 3-1/2 roller boogies, RIH w/same lib to 3,800' KB, fall slow, (begin pumping diesel and methanol mix) begins falling faster get better spang action. Set down @ 5,897' KB, can't locate, POOH. RIH w/3" lib to same, have good spang action now. POOH. OOH w/ picture of top of rope socket. RIH w/ 1-3/8 JDS w/ bell guide to 5,897' KB, latch tool string,jar 10 times, come free, POOH, do not have enough lubricator to cover E-line tool string. RIH to 5,987' KB. Attempt to shear tool, can't shear, can't pull free, continue to beat both ways. Drop cutter bar, does not cut, work tools in attempt to cut, w/I tool string comes free of E- line tool string, POOH, while coming through tree cutter bar, cuts wire dropping the tool string. Rig down for the night. Secure well. • • Hilcorp Alaska, LLC k Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date CLU-06 CTU 50-133-20492-00 200-033 5/30/17 8/1/17 Daily Operations: 07/30/2017 -Sunday Arrive on location. Begin rigging up .160" wire. Pressure test 2,500 psi, good. RIH w/2-1/2" JDC w/2.64" bell guide to 5,964' KB, latch cutter bar, POOH. OOH w/ bar. RIH w/same to 5,965' KB, latch tool string, POOH. OOH w/tool string. Reconfigure tool string w/2" stem and 3-1/2" roller boogies. Rig w/4-1/2" GU, bait sub, overshot, plant overshot at 5,984' KB, shear off, POOH. 17:05. RIH w/4-1/2" GS to 5,985' KB, latch overshot, begin jarring.Jar for 1-1/2 hrs, tool string comes free, POOH. OOH w/ E- line tool string and perf guns. Begin rig down. Head back to Pollard shop. 08/01/2017-Tuesday Obtain PTW. Hold safety meeting. MIRU Pollard E-line. Discuss job procedure. Make up Gamma/CCL, pressure temp logging tools. Stab on well. PT stack 250/3,500 psi. Open master swab RIH. Initial WHP 515 psi. Found fluid level at 1,265' RKB. Tagged fill at 6,031' RKB. POOH to surface. Make up sample balier. RIH to 1,400'. POOH with produced water sample. Sample given to Pete Iverson. RDMO PESI. Kenai CLU SCHEMATIC Well: Cannery Loop Unit 06 Last Completed: 10/23/2000 Hilcorp Alaska,LLC CASING DETAIL RKB=21'MSL Size Type Wt/Grade/Conn ID Top Btm r 9-5/8" Conductor 53.5/P-110/Unknown 9.95" Surf 91' eA' 7" Surface 23&26/L-80/Unknown 6.151" Surf 2,964' 4-1/2" Production 12.6#/L-80/Hydril 521 3.958" Surf 8,124' i;. 4.* , JEWELRY DETAIL 9-5/8" A 16 No Depth ID Item 1 6,040' CIBP 07-28-17 2 6,049' X-Nipple 3 6,300' CIBP 07-24-17 `' 4 6,387' Patch 6,387'-6,409' 5 6,855' CIBP w/34'cement(TOC 6,821')07-24-13 6 6,910' RCBP 7 7,796' Cement Retainer(See Detail Box) 7 L S.:• PERFORATION DETAIL Zone Top Btm Top Btm FT SPF Date Status (MD) (MD) (TVD) (TVD) (MD) A-5 5,881' 5,901' 3,762' 3,772' 20' 6 7/29/2017 Active A-6 6,080' 6,100' 3,866' 3,877' 11' 6 7/27/2017 Isolated A-9 6,395' 6,409' 4,029' 4,037' 14' 6 7/30/2013 Isolated/squeezed ,* A-11 6,740' 6,760' 4,224' 4,236' 12' 5 7/15/2017 Isolated 4,0,„.,*. ••. B-1 6,865' 6,880' 4,302' 4,312' 15' 6 3/15/2012 Isolated )5 B-2 6,919' 6,932' 4,337' 4,346' 13' 6 3/31/2012 Isolated ' , C-1 7,846' 7,860' 4,961' 4,970' 14' 6 10/23/2000 Squeezed t C-1 7,883' 7,945' 4,986' 5,028' 62' 6 6/10/2004 Squeezed SterlingA-5 C-2 7,962' 7,986' 5,039' 5,055' 24' 6 6/9/2004 Squeezed ( ' 1 i C-2 8,014' 8,024' 5,074' 5,081' 10' 6 10/23/2000 Squeezed Sterling C-2 8,024' 8,062' 5,081' 5,106' 38' 6 6/8/2004 Squeezed ' ■" •q 2 s 4 A-9 '' Sterling A-11 _se 5 &1 7 6 gM''. `'.::•• 6-2 '}' Cement retainer set at 7,796'MD, il 7 Sterling Cl and C2 intervals squeezed with approx.6bbls Class G cement. ',4 .yC-1&2 CT un-stung and 3bbls cmt,131', Al -1 placed on top of cement retainer, 41/2' : 1 leaving TOC at approx.7,665'MD `-�'S. Note:Tagged TOC was 7,505'kb TD 43,320' PBTD=6,040' witnessed and pressure tested to MAX HOLE ANGLE=64°@ 1,790' 1,600psi 2-29-12. INCLINATION DETAIL Inclination approx.60 deg,2,300-5,800 ft MD Inclination 61°dropping to 40°,5,800 ft MD to TD Updated by DMA 08-17-17 2,00-40S3 Seth Nolan Hilcorp Alaska, LLC GeoTech �/ 3800 Centerpoint Drive, Suite 100 RECEIVED Anchorage, AK 99503 `/G Tele: 907 777-8308 Hilm,rp Atawku,I.VA Fax: 907 777-8510 AUG 0 9 2017 E-mail: snolan@hilcorp.com DalA LOGGED M. K. BENDER DATE 08/09/2017 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL CLU 6 SCANNED A[;r, 2 7 , Prints: Leak Detect Log CD: 1 1'r CLU 06 LDL 26JUN 17.pdf 7/13/2317 2:20 PM PDF Document 932 KB CLU 06LDL263UN17 img.tiff 7/13/2017 2:20 PM TIFF File 2,610 KB CLU 06_1DL263UN 17 MainPass-dn.las 7/13/2017 2:20 PM LAS File 289 KB CLU 06_LDL263UN 17 MainPass-up.las 7/1312317 2:20 PM LAS File 301 KB Li CLU 06 LDL 263UN 17 Stop-6350ft.las 7/13/2017 2:20 PM LAS File 374 KB CLU 06_LDL 263UN 17 Stop-6417ft.las 7/13/2017 2:20 PM LAS File 758 KB CLU 06 LDL 263UN 17 Stop-6450ft.las 7/13/2017 2:20 PM LAS file 1,542 KB CLU 06 1..131_ 263UN 17 Sbop-i714ft.las 7/13/2017 2:20 PM LAS file 469 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: ✓�� Date: G V • Quick, Michael J (DOA) From: Quick, Michael J (DOA) Sent: Wednesday,July 05, 2017 3:58 PM To: Ted Kramer 03 Cc: Schwartz, Guy L (DOA); Donna Ambruz Subject: RE: CLU #6 - PTD #200-033, Sundry# 317-136 Ted— The procedure change to run the tubing patch for isolation per your procedure below is approved. Michael Quick Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1231(phone) SCANNED AUG 0 9 2017 (907)276-7542(fax) mike.quick@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,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 Mike Quick at 907-793-1231 or mike.auick@alaska.gov. From:Ted Kramer [mailto:tkramer@hilcorp.com] Sent: Wednesday,July 05, 2017 2:36 PM To: Quick, Michael J (DOA) <michael.quick@alaska.gov> Cc:Schwartz, Guy L(DOA) <guy.schwartz@alaska.gov>; Donna Ambruz<dambruz@hilcorp.com> Subject: CLU#6- PTD#200-033, Sundry#317-136 Mike, Hilcorp is requesting a procedure change on the above well. We have attempted to squeeze off the A-9 perforations five times without success(3 with Polymer and 2 with cement). Rather than continue down this path,Hilcorp requests a change to set a permanent tubing patch across the A-9 interval to isolate the existing perforations. We will then pressure test to 2,000 psi, and then blow the well dry with Nitrogen as planned and perforate the well below the tubing patch. The sundry will be modified as follows: 7.) RU E-line and pressure test lubricator to 2,000 PSI. 8.) PU tubing patch. RIH w/same and straddle the A-9 perforations and set the patch. 9.) Pressure test patch to 2,000 psi. for 5 minutes. 10.) If good test, go to step# 12. Otherwise, consult with town. From Step# 12,the work plan follows the sundry. Please let me know if the AOGCC is in agreement with this plan. I will then list it on the Change form for this well. Sincerely, 1 OF Tif • • yjyt�� THE STATE Alaska Oil and Gas OAT KA Conservation Commission 333 West Seventh Avenue T, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS-1°' Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC %AHMED APR 19 2017, 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai CLU Field, Sterling Undefined Gas Pool, Cannery Loop Unit 06 Permit to Drill Number: 200-033 Sundry Number: 317-136 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, o' Cathy '. Foerster Chair DATED this l 3 day of April, 2017. RBDMS LL APR 1 7 2017 • • RECEIVED STATE OF ALASKA APR 0 3 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION D-S 4•L`V/7 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 2- Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend 0 Perforate 2, Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing El Other: CT/CO W/N2 Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development Q 200-033• 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ElService ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20492-00• 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055(a)(4) Cannery Loop Unit 06, Will planned perforations require a spacing exception? Yes ❑ No Q 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0060569IADL03246021FEE-TR73 KENAI C.L.U./Sterling Undefined Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,320' • 5,277's 6,241' 3,950' —1,448psi 6,821';6,910';7,505' 6,212'(fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 91' 9-5/8" 91' 91' 10,900psi 7,950psi Surface 2,964' 7-5/8" 2,964' 2,322' 6,340psi 3,830psi Intermediate Production 8,124' 4-1/2" 8,124' 5,148' 8,430psi 7,500psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6#/L-80 8,124' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A;N/A N/A;N/A 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development❑✓ Service El 14.Estimated Date for 15.Well Status after proposed work: April 17,2017 Commencing Operations: OIL 0 WINJ 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS Q WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved x Q_3 /?- herein will not be deviated from without prior written approval. Contact Ted Kramer-777-8420 Email tkramer(a�hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature (::'/T177 Phone 907-777-8405 Date qJ.//7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: c.....--- ..... 317-- 13 4 Plug Integrity 0 BOP Test/M Mechanical Integrity Test ❑ Location Clearance 0 Other: -1 41000 �5Z P le--; f C C___ j Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes 0 No d Subsequent Form Required: /0_' 4/t 'r DMS � - ,;R P 1 7 ZO,t7 APPROVED BY Approved by:al / ...2.e,.. .____,4_ COMMISSIONER THE COMMISSION RBDate: _ '3 GRIGDIA s roll-t Submit Form and Form 10-403 Revised 11/2015 for 1 months from the date of appro Attachments in Duplicate • • • Well Prognosis Well: CLU#6 Hilcorp Alaska,LLQ Date:4/03/2017 Well Name: Cannery Loop Unit (CLU) API Number: 50-133-20492-00 #6 Current Status: SI Gas Well Leg: N/A Estimated Start Date: April 17, 2017 Rig: CTU, E-line Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 200-033 First Call Engineer: Ted Kramer (907) 777-8420(0) (985)867-0665 (M) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 227-5293 (M) AFE Number: Current Bottom Hole Pressure: —1,386 psi @ 4,755' (3,202'TVD) (Based on .433 psi/ft gradient) Max. Potential Surface Pressure: — 1,448 psi @ 6,848' (4,292'TVD) (Deepest perf minus .1 psi/ft.grad.) Brief Well Summary: Cannery Loop Unit#6 has been SI since August, 2013 when the well sanded up after perforating the Sterling A- 9 interval. The work covered under this Sundry application is to Mill out the X nipple at 6,049' and clean out the well using coil (with Nitrogen) looking for a fish that was left in the hole. Once located,the fish is to be recovered, and a polymer plug is to be spotted and squeezed into the A-9 perforations, effectively shutting them off. The well will then be cleaned out and jetted dry. New intervals(listed below in Step#16)will then be shot and tested working up hole until economic quantities of gas are found. ( Note: Non-productive intervals that produce water will be isolated prior to moving up hole.) • The well will then be placed on production and flowed. Notes Regarding Wellbore Condition • The well is currently SI. • Cement has excellent bond above and below all intervals to be perfed. Nitrogen Safety Concerns • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people • could enter. • Consider tank placement based on wind direction and current weather forecast(venting Nitrogen . during this job). • Ensure all crews are aware of stop job authority. ' Procedure: Coil Tubing Operations 1. MIRU Coil Tubing Unit. 2. Pressure test coil BOP to 4,000 psi Hi 250 Low(Notify AOGCC 24 hours in advance to give them an opportunity to witness). 3. PU/RIH with a motor and mill out the X-nipple at 6,049'. 4. Continue in hole washing sand until contact is made with the fish left in hole. (Note: Nitrogen may be necessary to clean out fill). POH with Coil. • • • Well Prognosis Well: CLU#6 Ililcorp Alaska,LLQ Date:4/03/2017 5. PU and RIH with fishing tools to wash over/latch fish and remove same (Note: If fishing with coil is unsuccessful, then a Slick line unit may be used to fish tool string). 6. PU jet nozzle or mill on motor and wash down to TOC at 6,821' (Note: Nitrogen may be needed to lift sand). Circulate well clean. 7. PU to 6,415'. Open backside, spot a balanced polymer pill from 6,415 to 5,758' (11 Bbls.). 8. PU to 5,600'. Close tubing and pump 10 bbls down the back side squeezing polymer into A-9 perforations (6,395—6,409'). POOH with Coil, SDFN to allow Polymer to set up. 9. PU jet nozzle. RIH with Jet Nozzle to 6,821' washing out excess Polymer. 10. PU to 6,300'. Pressure up on well to 3,000 psi and conduct a pressure test for 15 min. on chart. 11. If good test,go to step#12. Otherwise, return to step#7. 12. RIH to bottom,jet well dry with Nitrogen. Pressure up to 2,000 psi. SI. POOH with coil. E-line Operations 13. MIRU E-line Unit. 14. RU and Pressure test Lubricator to 3,000 psi. 15. PU Guns and RIH to perforate the A-11 Zone. Log guns on depth. Pressure up well to the pressure recommended by Hilcorp reservoir engineer. Fire guns. Record Pressure at 5 min., 10 min. intervals. 16. Bleed down well checking for LEL levels. Place well in test. If interval is uneconomic, set a plug over perforated interval (See E-line Contingency plan below), move up hole to the next interval. Intervals to be shot and tested: Zone Sands Top (MD) Btm (MD) FT Sterling A-2 (+/-)4,752' (+/-)4,763' 11' Sterling A-5 (+/-) 5,885' (+/-) 5,928' 43' Sterling A-6 • (+/-) 6,017' (+/-) 6,027' 10' (+/-) 6,080' (+/-) 6,121' 41' Sterling A-8 (+/-)6,394' (+/-) 6,409' 15' Sterling A 10 (+/-)6,596' (+/-)6,626' 30' Sterling A 11 (+/-)6,725' (+/-)6,764' 39' arc a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using a Correlation Log provided by the assigned geologist. d. Use Gamma/CCL/to correlate. e. Send correlation pass Operations Engineer, Reservoir Engineer, and Geologist for Confirmation. f. Record tubing pressures before and after each perforating run. g. All perforations in table above are located in the Sterling "undefined" Pool. Therefore, regular state wide spacing rules apply. 17. RD E-line. 18. Turn well over to production. 19. Test SSV with-in 5 days of stable production (Notify AOGCC 24 hours before testing to give opportunity to witness). 0 • Well Prognosis Well: CLU#6 Hilcorp Alaska,LLQ Date:4/03/2017 E-line Contingency Plan If any zone produces sand and/or excessive water and needs to be isolated: 1. MIRU E-line. Pressure Test Lubricator to 2,500 psi high/250 psi low. - 2. RIH and Set 4-1/2" CIBP at depth above zone (place 25'of cement if required) if zone is at bottom of perf interval. 3. If zone is in the middle of perf interval, RIH and set 4-1/2" casing patch to isolate interval. 4. RDMO E-line unit. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Schematic 4. Wellhead drawing 5. Coil Tubing Flow Diagrams(forward and reverse) 6. Blank RWO Change Form 7. Standard Well Procedure—Nitrogen Operations • Kenai CLU • H • SCHEMATIC well: Cannery Loop Unit 06 Last Completed: 10/23/2000 Ililcorp Alaska,LLC CASING DETAIL RKB=21'MSL Size Type Wt/Grade/Conn ID Top Btm AT y 9-5/8" Conductor 53.5/P-110/Unknown 9.95" Surf 91' k."4,': $"',..* ,± 7" Surface 23&26/L-80/Unknown 6.151" Surf 2,964' 4-1/2" Production 12.6#/L-80/Hydril 521 3.958" Surf 8,124' ' t,a 9-5/8" *.". W1•44 5 '4` JEWELRY DETAIL No Depth ID Item �w # 1 6,049' 3.813" 4-1/2""X"Nipple * ,, 2 6,855' CIBP w/34'cement(TOC 6,821')07-24-13 P P 3 6,910' RCBP ,;;" ilt 4 7,796' Cement Retainer(See Detail Box) »!I r *rt ' ',,ie1,,,,,,, PERFORATION DETAIL F ." Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Date Status 7" , A-9 6,395' 6,409' 4,029' 4,037' 14' 6 7/30/2013 Covered 11 B-1 6,865' 6,880' 4,302' 4,312' 6' 6 3/15/2012 Isolated >' A B-2 6,919' 6,932' 4,337' 4,346' 13' 6 3/31/2012 Isolated `1,.,- Vii4 7,846' 7,860' 4,961' 4,970' 14' 6 10/23/2000 Squeezed erg IX ', ; C 1 7,883' 7,945' 4,986' 5,028' 62' 6 6/10/2004 Squeezed 1. 4 7,962' 7,986' 5,039' 5,055' 24' 6 6/9/2004 Squeezed '' `4' C-2 8,014' 8,024' 5,074' 5,081' 10' 6 10/23/2000 Squeezed V4 5s. 8,024' 8,062' 5,081' 5,106' 38' 6 6/8/2004 Squeezed 4 INCLINATION DETAIL r I Inclination approx.60 deg,2,300-5,800 ft MD 141,, w;;a Inclination 61°dropping to 40°,5,800 ft MD to TD ': ,fit it4v 4, 1,,t' l« i, r, Slickline tag of fill at 6,212'in March 2017 O'i `ik'' t 14;04 TOF below X Nipple-Not tagged ✓ ? ',+ 1 Consists of 15'pert gun+gamma ray tool-August 2013 1 1 ,SI Sterling Undefined Gas 2` ^`1 F }� Ia = a2 Cement retainer set at 7,796'MD, flt� sis- ky Sterling Cl and C2 intervals squeezed �'4 . :A'4 with approx.6bbls Class G cement. tsi'" *IA'. 4 CT un-stung and 3bbls cmt,131', ya'�: C-1&2 placed on top of cement retainer, f' 54- leaving TOC at approx.7,665'MD '. �9- C �N Note:Tagged TOC was 7,505'kb 4-112" 4 ' witnessed and pressure tested to i `.. 1,600psi 2-29-12. TD x,320' PBTD=6,821' MAX HOLE ANGLE=64°@1,790' Updated by DMA 04-03-17 • . • Kenai CLU 14 PROPOSED SCHEMATIC Well: Cannery Loop Unit 06 Last Completed: 10/23/2000 Ililcorp Alaska,LLC CASING DETAIL RKB=21'MSL Size Type Wt/Grade/Conn ID Top Btm "ij04 9-5/8" Conductor 53.5/P-110/Unknown 9.95" Surf 91' V4' '^� 7" Surface 23&26/L-80/Unknown 6.151" Surf 2,964' 4-1/2" Production 12.64/L-80/Hydril 521 3.958" Surf 8,124' It '1�' JEWELRY DETAIL 9-5/8" dA. 6 No Depth ID Item wl , at 1 6,855' CIBP w/34'cement(TOC 6,821')07-24-13 2 6,910' RCBP ', i 3 7,796' Cement Retainer(See Detail Box) r �li ; y , " , PERFORATION DETAIL ai a t..' xr Zone Top Btm(MD) Top Btm FT SPF Date Status its (MD) (TVD) (TVD) (MD) ' 4V A-2 ±4,752' ±4,763' ±3,202' ±3,207' ±11' 6 Future Proposed - A-5 ±5,886' ±5,929' ±3,722' ±3,745' ±43' 6 Future Proposed ' 7, If, ,19' A-6 ±6,018' ±6,027' ±3,834' ±3,838' ±9' 6 Future Proposed A� ani A-6 ±6,081' ±6,121' ±3,824' ±3,846' ±40' 6 Future Proposed i.,< , A-9 6,395' 6,409' 4,029' 4,037' 14' 6 7/30/2013 Squeeze ' A-10 ±6,596' ±6,626' ±4,096' ±4,113' ±30 6 Future Proposed ild 1 A-11 ±6,726' ±6,764' ±4,173' ±4,197' ±38 6 Future Proposed • . B-1 6,865' 6,880' 4,302' 4,312' 15' 6 3/15/2012 Isolated �± B-2 6,919' 6,932' 4,337' 4,346' 13' 6 3/31/2012 Isolated } C-1 7,846' 7,860' 4,961' 4,970' 14' 6 10/23/2000 Squeezed iC t : C-1 7,883' 7,945' 4,986' 5,028' 62' 6 6/10/2004 Squeezed a C-2 7,962' 7,986' 5,039' 5,055' 24' 6 6/9/2004 Squeezed W' C-2 8,014' 8,024' 5,074' 5,081' 10' 6 10/23/2000 Squeezed -`F Sterling -2 C-2 8,024' 8,062' 5,081' 5,106' 38' 6 6/8/2004 Squeezed A Sterling A-5 1:71 IP Sterling A-6 4 4 Idi t...., , ,r; Milled X Nipple @ 6,049'-TBD A-9 4,••:,,:c; ?' Sterling A-b 0 1 Sterling A-I l t 14-# �' ,,�, LCL. p x 2 ,4 "= B-2 Cement retainer set at 7,796'MD, , ' -'tr►`+�r��• Sterling Cl and C2 intervals squeezed , with approx.6bbls Class G cement. ., '.Y iii ,„� ;a3 3 CT un-stung and 3bbls cmt,131', ,., C-1&2 placed on top of cement retainer, S"r -'' leaving TOC at approx.7,665'MD / Note:Tagged TOC was 7,505'kb 41/T, ,.7¢ t I V witnessed and pressure tested to 1,600psi 2-29-12. TD=8,320' PBTD=6,821' MAX HOLE ANGLE=64°®1,790' INCLINATION DETAIL Inclination approx.60 deg,2,300-5,800 ft MD Inclination 612 dropping to 402,5,800 ft MD to TD Updated by DMA 04-03-17 4110 • 11 Cannery Loop Unit CLU-06 03/23/2017 no.,..fp r1144 0.t.tU: is144014,,i4\. t t Q. _ _ MUS : 1 U limb-_1.�i-_.1Rmi �`!II 1i Coiled Tubing HR580 Injector Head&Gooseneck Ii•_.a.� ni�_� Weight=12,850 lbs I � > El I0 0 00 • 1 4-1/16"10K Conventional Stripper Ih.I l 16.1.111 Mind 4 5K C062 Lubricator WH PSI 2"1502 x 2-1/16 10K Flanged Valve 1 5K CO62 x 4-1/16"10K Flange (Manual) 2-1/16 10K x 2-1/16 = 4-1/16"10K Combi BOP 10K Ranged Vdve Top Set:Blind/Shear (Manual) i "". 'r' Second Set:Pipe/Slip :17:2 4-1/16"10K Flow Cross Manual 2x2 Valve 1:T 1502 x 2-1/16"10K Flange 010/1`I1041.1g0114011! 4 Manual 2x2 Valve 2:2-1/16"10K x2-1/16"10K Flange Manual 2x2 Valve 3:2-1/16"10K x2-1/16"10K Mange Manual 2x2 Valve 4:2"1502 x 2-1/16"10K Range U 4 4-1/16"10K x Welhead Adapter Flange 11IICIOI!I0II40Ile %'tel -4 Wellhead k11 • • • • II Cannery Loop Unit CLU#6 04/03/2017 Hik.rp Va.ka. Tubing hanger,Vetco Gray, Cannery Loop Unit CLU#6 11x 4'''A IBT boxbtmx4 9 5/8 x 7 x 4% IBT box top,w/6 1/2 od neck,4"type H BPV profile, DD-NL material BHTA,Otis,4 1/16 5M FE x 6.5 Otis quick union top ®sI Valve,Swab,WKM-M 4 1/16 5M FE,HWO, 1?-'1X-., EE trim Valve,Wing,WKM-M, 3 1/8 5M FE,HWO, Valve,Wing,SSV,WKM-M, ilLL! ! . 3 1/8 5M FE,w/15"operator EE trim arta! 0 a) Valve,Upper master, itj,:14. WKM-M, Olt 4 1/16 5M FE,HWO,EE trim 1 I IINI:343 Valve,Master,WKM-M, 4 1/16 SM FE,HWO, EE trim _ � hD ■ ■ Starting head,Vetco,11 5M x 7"SOW,w/2-2 1/16 5M C ) SSO i \ 1 , n , 11 7" 4%„ • 0 g ; 81 : .3 D F3E G Q ?S y 0ln 113 Z 0 moi , ] o z ' ==a5 N v E X43 CD Fi E 3 CNcu = z 0 0 o C U 7 O 1 a O H Q 1_ lie .,„ I..11.1111 0 uII.II.I11.'.1.11.'11'.'14i •- m1 nn Inu m1 - 0 it I , l o ag V•U A Z c v a 0 I c v • O 21 It V • A II, k O / e t2 E �/ tt itti 8 acn of U N 0Z o q wti 0 M a i • • g i 8j 1 V 1— m g oz No i= 1 . ] 1-- ' 7 ] moi , ] cu Lwz p 1 O q w w C.) Aikt 10414r ecce 0_ n -aaa E. D 0 s Itt - 0 L • y cy V A • C -+—, N Z N o C ^, V V/ •Z p • o II tmildlll 0 1111111.11I.IIIIII.41.4 II' 45 It IMIMI ml MI ! w dl ' I l I l �of o ii c v o_ 0 1— I c • II a O A V A SI, r k r Y 110 , o IIII 0 i 8 It . it a c.c r 0 E V N 0 p 0 ¢§ Wb 0 V tiA k i • • a) F0 / � W2 Q — � 2& e . s 0 2 m os 0 / / 2 k0. R « � E - • 0f ) / § I k� f CI« = o / SD X � >' > = ICS / /\ a / / % •w- el -0a a)2 \ � � 2 CI CI $ %2 �>- co 2C 0 o co k2 a) CI 2 § 0 / a L. co o % � � Q » — C a) §00 & 2/ § J \< .c I E § % > c = a) 2 -o � / 2 a) Z' \ / E C) C »\ § 2 § \ / . Cl) G0 2 L > \ � C @ 2 § � % § 0 0. U3 � % ' « � 0 0 0. cip U) x ea 2 _� Q ■ x 3 » R e 0)Ct X § � a 0 Q sz• W o x /0 a .. \ 0 % ) 1 o Q ■ > 2 >.0 ® 0_ / Cl) Cl) \ 9cs. • • • STANDARD WELL PROCEDURE Hilcorp Alaska,LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets(formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure),whichever is higher.Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 • • Davies, Stephen F (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Monday, April 10, 2017 2:34 PM To: Davies, Stephen F (DOA) Cc: Trudi Hallett Subject: RE:Cannery Loop Unit 6 (PTD 200-033; Sundry 317-136) - Request Stephen, After discussing this with Hoilcorp's Geologist (Ben Siks) I can respond to your questions. Please see answers below in Red: I hope this helps clear it up for you. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 From: Davies,Stephen F(DOA) [mailto:steve.davies@alaska.gov] Sent: Monday,April 10, 2017 1:31 PM To:Ted Kramer<tkramer@hilcorp.com> Subject: RE:Cannery Loop Unit 6(PTD 200-033;Sundry 317-136)-Request Ted, I haven't received a reply addressing my questions regarding this sundry application. I'd like to get it moving again through the AOGCC's review process, if possible. Thank you, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies,Stephen F(DOA) Sent:Tuesday,April 4, 2017 4:02 PM 1 • • ' To:tkramer2hilcorp.corn Subject: Cannery Loop Unit 6(PTD 200-033; Sundry 317-136)- Request Ted, Could Hilcorp please confirm that the proposed Sterling perforations in CLU 6 will conform to the requirements of 20 AAC 25.055(a)(4)? CLU#6 will be the only well in the CLU perforated in the Sterling A sand. Therefore it is our belief that it does conform with 20 AAC 25.05- 71T.— Is 5.054 .Is CLU 10 the only other well with the CLU that is perforated within the Sterling Formation? CLU#10 was perforated in the Sterling C sands. Due to the agreement with Cingsa, a CIBP was set above those perforations to prevent producing from that interval. The CLU #3 in the past, tested the Sterling Sands also in the C interval. That well was squeezed off without any production. The CLU#6 did produce in the C sands of the Sterling. Once the agreement with Cingsa was finalized,the C sand was isolated in this well. Hilcorp thernfn attempted to produce the Sterling B sands in the CLU #6 and had a small amount of Gas recovery from that interval. The B-1 Sand in CLU#6 is now under a CIBP. (The current target in this well is the Sterling A sands. The A sands have not been tested in the CLU and are not in 1/ communication with the Sterling C sands (the C sands are where the Cingsa gas storage project is located). How will these proposed perforations be situated with respect to the gas storage pool? ?1 Thank you, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 2 WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. /(/0 t?33 Well History File # Digital Data Added to LaserFiche File CD's - # Yes No DVD's - # Yes No Diskettes - # Yes No Oversized Material Added to LaserFiche File Other # Yes No Yes No Yes No Maps # Mud Logs # General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file, or if you have any questions or infonnation requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-1433, or email us at: AOGCC_Librarian@admin.state.ak.us '.. . . IVEL) STATE OF ALASKA 2.013 ALA.OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS ,G , 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other kJ isolate Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 200-033 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99504 50-133-20492-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0060569/FEE-TR73/ADL0324602 Cannery Loop Unit 06 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kenai C.L.U.Field/Sterling Undefined Gas • 11.Present Well Condition Summary: Total Depth measured 8,320 feet Plugs measured 6,910/7,505 feet true vertical 5,277 feet Junk measured 6,241 (Sand) feet Effective Depth measured 6,241 feet Packer measured N/A feet true vertical 3,950 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 91' 9-5/8" 91' 91' 10,900psi 7,950psi Surface 2,983' 7-5/8" 2,983' 2,320' 6,020psi 3,400psi Intermediate Production 8,124' 4-1/2" 8,124' 5,148' 8,430psi 7,500psi Liner r F Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 8,124' 5,148' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A 0 0 0 0 Subsequent to operation: N/A 0 0 87 17 14,Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory Development El• Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas 0• WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry umber or N/A if C.O.Exempt: '&1143 5- PS—3104 Contact Jeremy Mardambek Email jmardambekt�hilcorp.com Printed Name Jeremy Mardambek Title Reservoir Engineer Signature �,� Phone 907-777-8398 Date 9/9/2013 Form -404 Revised 10/2012 10.1q.��/ inePY1 2 1 7& • • Kenai CLU SCHEMATIC WeII: Cannery Loop Unit-06 Ililcorp Alaska,LLC Last CorDieted:10/23/2000 CASING DETAIL RKB=21'MSL Size Type Wt/Grade/Conn ID Top Btm 9-5/8" Conductor 53.5/P-110/Unknown 9.95 Surf 91' ,,, 7-5/8" Surface 23&26/L-80/Unknown 6.875 Surf 2,966' 4-1/2" Production 12.64/L-80/Hydril 521 3.958 Surf 8,320' JEWELRY DETAIL 9-5/8" A No Depth ID Item P. , ) 1 6,049' 3.813 4-1/2""X"Nipple -'S CS 2 6,910' RCBP 3 7,796' Cement Retainer(See Detail Box) PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Date Status A-9 6,395' 6,409' 4,029' 4,037' 14' 6 7/30/2013 Covered B-1 6,865' 6,880' 4,302' 4,312' 6' 6 3/15/2012 Covered 1 B-2 6,919' 6,932' 4,337' 4,346' 13' 6 3/31/2012 Isolated 7,846' 7,860' 4,961' 4,970' 14' 6 10/23/2000 Squeezed C-1 7,883' 7,945' 4,986' 5,028' 62' 6 6/10/2004 Squeezed 7" .S.- 7,962' 7,986' 5,039' 5,055' 24' 6 6/9/2004 Squeezed C-2 8,014' 8,024' 5,074' 5,081' 10' 6 10/23/2000 Squeezed 8,024' 8,062' 5,081' 5,106' 38' 6 6/8/2004 Squeezed }., =°r INCLINATION DETAIL e Inclination approx.60 deg,2,300-5,800 ft MD Inclination 61°dropping to 40°,5,800 ft MD to TD '',T. S d -r i r ti 4 F F.. Run 2.25"Dump Bailer ' ' i''.. to 6,241'8/7/2013 `1, 1 Sterling Undefined Gas B-1 . - 2 6-2 Cement retainer set at 7,796'MD,Sterling Cl and C2 intervals squeezed with approx.6bbls Class G cement. CT *III un-stung and 3bbls cmt,131',placed on top of cement a '=3 retainer,leaving TOC at approx.7,665'MD c-1&2 Note:Tagged TOC was 7,505'kb witnessed and pressure tested to 1,600psi 2-29-12. 4-1/2' TD 43,320' PBTD=8,058' MAX HOLE ANGLE=64°a 1,790' Revised By:TDF 8-7-2013 • . Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date CLU-06 50-133-20492-00 199-024 5/9/13 Daily Operations: 7/17/2013-Wednesday No operations to report. 7/18/2013-Thursday No operations to report. 7/19/2013-Friday No operations to report. 7/20/2013-Saturday RU Eline unit and crane. Note submitted 24 hr notification for CIBP install to AOGCC who waived witness. RIH and set 4-1/2" CIBP at 6,855'. Make two runs dumping 9 gals of cement each trip for a total of 25' of cement. RD Eline unit. Secure well and leave location. 7/21/2013-Sunday No operations to report. 7/22/2013-Monday No operations to report. 7/23/2013 -Tuesday No operations to report. • S Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date CLU-6 50-133-20492-00 199-024 5/9/13 7/24/ 013 Wednesday RU Pollard Eline unit. RIH w/3-1/8"gamma ray/CCLRun correlation pass to get on depth.Tag TOC at 6,821'. POOH RD Eline unit. Fill wellbore with approx 5 bbls of produced water. 7/25/2013-Thursday Pressure casing/cement plug to 1,600psi: 12:20pm - 1,620psi; 12:30pm - 1,600psi; 12:40pm - 1,600psi; 12:50pm - 1,600psi; 1:00pm - 1,600psi. Test charted. 7/26/2013- Friday No operations to report. 7/27/2013-Saturday No operations to report. 7/28/2013-Sunday No operations to report. 7/29/2013- Monday No operations to report. 7/30/2013-Tuesday, RU Pollard Eline. 1,000' of water hydrostatic, 725 psi gas pressure from CLU 9 for underbalance. Approx 1,300psi. Perforate Sterling A9 sand 6,395'-6,409'. 3-3/8" guns 6 SPF, 60 degree phased guns blown uphole. stuck. Worked tools pulled free, left 15' of guns, 7' 3-1/8" gamma/CCL, 1-1/2', 3-1/8'firing head, and 1' of 1-3/8" rope socket. RU slickline. RIH w/3-1/2" LIB below 3.75"wire finderPOOH LIB shows sand but no guns or braided line. RD. Will bail fill in the morning. • Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date CLU-6 50-133-20492-00 199-024 5/9/13 [ .a perations: Emw-4- 7/31/2013 -Wednesday RU slickline. RIH w/3" DD Bailer to 5,523'KB. Fluid level approx. 180'. Recover half bailer packed sand. Bail to 5,524' KB. Switch to 3" pump bailer. Bail sand from 5,524'to 5,539'. RIH to 5,550'. Fall to 5,618' KB. Work tools. Fall to 6,000'. POOH to PU wire finder and LIB. RIH w/3" LIB and 3-3/4" wire finder to X nipple at 6,049' KB. Can't work thru. Momentarily stuck in profile. Jar free. POOH. RD slickline unit. 8/1/2013 -Thursday No operations to report. 8/2/2013- Friday No operations to report. 8/3/2013-Saturday 4'„ No operations to report. 8/4/2013-Sunday No operations to report. 8/5/2013- Monday No operations to report. 8/6/2013 Tuesday No operations to report. VD STATE OF ALASKA � ALA* OIL AND GAS CONSERVATION COMMI�J6ION "1:" `'r,3 REPORT OF SUNDRY WELL OPERATIONS , C 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Isolate Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac 0 Waiver ❑ Time Extension ❑ Change Approved Program 1] Operat. Shutdown ❑ Stimulate Other El Suspended Well ❑ �. Operator Name: Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Development el Exploratory ❑ ■ 200 -033 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, Alaska 99504 • 50- 133 - 20492 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0060569/ FEE -TR73/ ADL0324602 ` Cannery Loop Unit 06 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s):: r N/A Kenai C.L.U. Field/ Sterling Undefined Gas 11 Present Well Condition Summary: Total Depth measured 8,320 feet Plugs measured 6,910 / 7,505 feet true vertical 5,277 feet Junk measured N/A feet Effective Depth measured 6,910 feet Packer measured N/A feet true vertical 4,331 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural e Conductor 91' 9 -5/8" 91' 91' 10,900psi 7,950psi Surface 2,983' 7 -5/8" 2,983' 2,320' 6,020psi 3,400psi Intermediate Production 8,124' 4 -1/2" 8,124' 5,148' 8,430psi 7,500psi (, Liner Perforation depth Measured depth See Attached Schematic SCANNED MAR 2 7 2013 i True Vertical depth See Attached Schematic 'Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6 # /L -80 8,124' 5,148' Packers and SSSV (type, measured and true vertical depth) N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A 0 1,000+ N/A 1,230 Subsequent to operation: N/A 0 1,000+ N/A 1,360 1. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development Q . Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ r Gas WDSPL ❑ 1 GSTOR ❑ WINJ ❑ WAG El GINJ ❑ SUSP ❑ SPLUG ❑ 117. 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: I 313 -125 { 1 Contact Shane Bennett Email sbennettp(�hilcorp.com Printed Name Jeremy Mardambek Title Reservoir Engineer Signature ! Phone 907 - 777 -8398 Date 3/22/2013 R D S MAR 2 2 2013 & e 3 °/3 Submit Original Only . Form 10 -404 Revised 10/201 7 II • • Kenai CLU SCHEMATIC Well: Cannery Loop Unit -06 Hilcorp Alaska. LLC Last Comoleted:10 /23/2000 CASING DETAIL RKB =21' MSL Size Type Wt/ Grade/ Conn ID Top Btm { ." 9 -5/8" Conductor 53.5 / P -110 / Unknown 9.95 Surf 91' F" ' t , 7 -5/8" Surface 23 & 26 / L -80 / Unknown 6.875 Surf 2,966' ,, .it 4 -1/2" Production 12.6# / L-80 / Hydril 521 3.958 Surf 8,320' y 'r' 4 .? 9-5/8" . JEWELRY DETAIL )i.7 : No Depth ID Item iz 1 1 6,049' 3.813 4 -1/2" "X" Nipple V t"I 2 6,910' RCBP ' �' 3 7,796' Cement Retainer (See Detail Box) PERFORATION DETAIL ' �' Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Date Status <{ AJ B -1 6,865' 6,880' 4,302' 4,312' 6' 6 3/15/2013 Future 3 ' i ' B -2 6,919' 6,932' 4,337' 4,346' 13' 6 3/31/2012 Isolated ? ;i, i . A 7,846' 7,860' 4,961' 4,970' 14' 6 10/23/2000 Squeezed ii 6' 14 r C -1 7,883' 7,945' 4,986' 5,028' 62' 6 6/10/2004 Squeezed 4 1►, 7,962' 7,986' 5,039' 5,055' 24' 6 6/9/2004 Squeezed M' C -2 8,014' 8,024' 5,074' 5,081' 10' 6 10/23/2000 Squeezed I. 8,024' 8,062' 5,081' 5,106' 38' 6 6/8/2004 Squeezed t s INCLINATION DETAIL Inclination approx. 60 deg, 2,300 -5,800 ft MD a Inclination 61 dropping to 40 5,800 ft MD to TD ' 0 1 ,,.. : :i:: t fi ' :` t,,,s j s T ' ti 1 9.'. °:: B s ;17, 2 ` * "' B-2 Cement retainer set at 7,796' MD, Sterling C1 and C2 intervals squeezed with approx. 6bbls Class G cement. CT t t un -stung and 3bbls cmt, 131', placed on top of cement f.11 ' retainer, leaving TOC at approx. 7,665' MD 't* C -182 Note: Tagged TOC was 7,505' kb witnessed and pressure 'is , tested to 1,600psi 2- 29 -12. 4-1 /Y' a1 TD = 8,320' PBTD = 8,058' MAX HOLE ANGLE = 64 (ta 1,790' Revised By: TDF 3 -21 -2013 • • iptx Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date CLU 06 50- 133 - 20492 -00 -00 200 -033 3/15/13 3/15/13 Daily €7perations: 3/13/2013 - Wednesday i6 l No operations to report. 3/14/2013 - Thursday ����',��.�, 'I r ,111111 No operations to report. 3/15/2013 - Friday III1IIINI!l, 1i PTW and JSA. Cut line and put new rope socket on. Rig up lubricator. Pressure test to 250 psi low and 2,500 psi high. Tubing pressure is 1380 psi. RIH with a 3.70" gauge ring w /roller boogies and tag fill at 7,614' KB wlm. Did not have any problem. RIH with 3.50 "x10' dummy gun at 150 FPM down to 7,030' KB wlm (did not tag). POOH. RIH with press /temp down to 7,600'. Sit on bottom for 45 min and POOH at 60 -120 fpm. Sit at tubing hanger for 5 min. Good data. Rig dowwn lubricator. JSA and PTW. Rig up lubricator. Pressure test lubricator to 250 psi low and 2,500 psi high. RIH with 3.50" OD CIBP, tie into Open Hole GR log dated 2/15/13 and set plug at 6,910'. Good set. POOH. RIH with 2 -3/4 "x15' HC, 6 spf, 60 deg phase perf gun and tied into Open Hole GR log dated 2/15/13. Spot perf gun from 6865' to 6,880' per Final Approved Perf Request Form dated 3/13/13 by Jeremy Mardambek. Tubing pressure 1,380 psi. Fired perf gun. Pressure came up slow. Got out of hole and psi was 1,390. Rig down lubricator and turn well over to production. 3/16/2013 - Saturday No operations to report. 3/17/2013 - Sunday No operations to report. 3/18/2013 - Monday No operations to report. 3/19/2013 - Tuesday No operations to report. • y w \� �W/j, , THE STATE Alaska Oil and Gas A LAsKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue pF Y . ' Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1 433 Fax: 907.276.7542 Jeremy Mardambek GAt *EU LIAR ��� Reservoir Engineer j 6 © 0 33 Hilcorp Alaska, LLC 3800 Centerpoint Drive Anchorage, AK 99503 Re: Kenai C.L.U. Field, Sterling Undefined Gas Pool, Cannery Loop Unit 06 Sundry Number: 313 -125 Dear Mr. Mardambek: 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. Sincerely, Cathy P. ' oerster Chair DATED this �day of March, 2013. Encl. $ STATE OF ALASKA a � � MAR 1. 1 Zt i l . ALASKA OIL AND GAS CONSERVATION COMMISSION J OT 3( APPLICATION FOR SUNDRY APPROVALS ;AOG 20 MC 25.280 r. Type of Request: Abandon El -, /,, Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ � I Suspend ❑ Plug Perforations { ( 7'3.1/•13 Perforate Q . Pit II Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well El Stimulate ❑ Alter Casing ❑ Other. 1�91ate- 2. Operator Name: 4. Current Well Glass: 5. Permit to Drill Number: ! t;!corp Alaska, LLC Exploratory ❑ Development 200 -033 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number. 3600 Centerpoint Drive, Anchorage AK, 99503 50-133-20492-00-00 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 231, Rules 3 &4 Will planned perforations require a spacing exception? Yes ❑ No is Cannery Loop Unit 06 • 9. Property Designation (Lease Number): 10. Field /Pool(s): rADL0060569/ FEE -TR73/ ADL0324602 Kenai C.L.U. Field/ Sterling Undefined Gas I' ' PRESENT WELL CONDITION SUMMARY r0ta1 Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8,320 5,277 + 7,505 4,732 7,505' N/A Casing Length j Size MD TVD Burst Collapse Structural , Conductor 91' 1 9 -5/8" 91' 91' 10,900psi 7,950psi 1 Surface 2,983' 7 -5/8" 2,983' 2,320' 6,020psi 3,400psi Intermediate I . Production 8,124' 1' 4 -1/2" 8,124' 5,148' 8,430psi 7,500psi Liner i Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): i - See Attached Schematic See Attached Schematic 4 -1/2" 12.6#/ L -80 8,124 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): NIA N/A 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 ' Service ❑ i 4. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/15/2013 Oil ❑ Gas IO• WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ s.eemmission Representative: N/A GSTOR ❑ SPLUG ❑ '. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shane Bennett I Email s.bennettahilcorp.com I • r;inted Name Jeremy Mardambek Title Reservoir Engineer • I -.. I fIgnature Phone 907 - 777 -8398 Date 3/11/2013 c COMMISSION USE ONLY e. r - . Honditions of ap v . Notify Commission s'i that a representative may witness Sundry Number: 1 _ / iT ` 1 . F tl:lug Integrity ❑ BOP Test 0 Mechanical Integrity Test ❑ Location Clearance ❑ Other: • I RBDMS MAR 15 2013 _r I Spacing Exception Required? Yes ❑ No Subsequent Form Required: / U - / o '/ n 77-4'---- TPEROVED Y Approved by: / COMMISSIONER THE COMMISSION Date: Z — / q- - Submit Form and r v e N2A Approved application is valid for 12 months from the ate of approval. Attachments Duplicate �� ` \1 • • • Well Prognosis Well: CLU 06 Hilcorp Alaska, LL) Date: 3/5/2013 Well Name: CLU - 06 API Number: 50- 133 - 205- 31 -00 -00 Current Status: Gas Producer Leg: Estimated Start Date: 3/17/2013 Rig: Eline Reg. Approval Req'd? 10 -403 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: First Call Engineer: Shane Bennett (907) 777 -8425 (0) (325) 203 -7487 (M) Second Call Engineer: Jeremy Mardambek (907) 777 -8388 (0) (561) 512 -8690 (M) AFE Number: Current Bottom Hole Pressure: –2000 psi Calculated from SITP Maximum Expected BHP: –1800 psi @ 4400' TVD Calculated from 0.433 psi /ft gradient Max. Anticipated Surface Pressure: –1600 psi Corrected from Max BHP Brief Well Summary CLU -06 was drilled in 2000 as the first Sterling producer in Cannery Loop Unit (CLU). Drilled on the highest point on the structure from CLU -01 pad this well produced – 23 BCF until early 2012 when the C -1 and C -2 sands were sold to CINGSA for a storage reservoir. In early 2012, after the original C -1 and C -2 had been plugged back for CINGSA, the B -2 sand directly above the C -1 sand were perforated. The B -2 sand flowed 1500 BWPD and 2.5 MMSCFD until it loads up and dies. Intermittent production is not possible due to inability to handle this volume of water at CLU -01 pad. The pressure gradient in the B -1 sands is expected to be between 0.3 psi /ft and 0.433 psi /ft based on the B -2 perfs. Justification: CLU -06 will not produce on its own because of excessive water production. New pay identified in this well will justify further perforations in the Sterling sands higher in this well and in wells further down dip. Recommendation: Temporarily abandon the B -2 perfs and perf higher in the Sterling with a CI BP.Perforate additional pay identified in the B -1 sand. y C1 MP Risks: Pressure is higher or lower than expected. Summary Procedure 1. RU Slick line. 2. RIH with dual pressure gauges. 3. Record 30 minute SBHP at deepest tag depth possible. 4. Pull up 100' TVD and record 15 minute gradient stop. 5. POOH. 6. RU Eline. ? 7. Use tie -in provided to set bridge plug bottom at ±6910' MD. — �� • 8. RIH with perforating guns and perforate from ±6874' to ±6880' MD using tie in log provided. 9. RDMO and turn well over to operation. 81 Attachments: As -built & Proposed Well Schematic and Well Spacing Map 14 • • Kena SCHEMATIC Well: Can nery Loop Unit -06 Ililcarp Alaska, LLC Last Completed:10 /23/2000 i- CASING DETAIL RKB =21' MSL Size Type Wt/ Grade/ Conn ID Top Btm 9 -5/8" Conductor 53.5 / P -110 / Unknown 9.95 Surf 91' 7 -5/8" Surface 23 & 26/ L -80 / Unknown 6.875 Surf 2,966' ;' 4 -1/2" Production 12.6# / L -80 / Hydril 521 3.958 Surf 8,320' t` . JEWELRY DETAIL 9 -5/8 4 ,`! '. No Depth ID Item , t , , 1 6,049' 3.813 4 -1/2" "X" Nipple ". 2 7,796' Cement Retainer (See Detail Box) Q PERFORATION DETAIL P" r i Zone Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Date Status B -2 6,919' 6,932' 4,337' 4,346' 13' 6 3/31/2012 Open 4 7,846' 7,860' 4,961' 4,970' 14' 6 10/23/2000 Squeezed I:* r�'41 . C 1 7,883' 7,945' 4,986' 5,028' 62' 6 6/10/2004 Squeezed A R �� 7,962' 7,986' 5,039' 5,055' 24' 6 6/9/2004 Squeezed a C -2 8,014' 8,024' 5,074' 5,081' 10' 6 10/23/2000 Squeezed _' 6 444' ' 5fri, 8,024' 8,062' 5,081' 5,106' 38' 6 6/8/2004 Squeezed r INCLINATION DETAIL Inclination approx. 60 deg, 2,300 -5,800 ft MD ,; Inclination 612 dropping to 40 5,800 ft MD to TD ri 1 4. '�I t l' 4Y ',..t 1 L "4 s . < , t , 4 . I V 'f +4 :4: 1 b � ivy„ P 1 " . Cement retainer set at 7,796 ft MD, Sterling C1 and C2 . intervals squeezed with approx. 6 bbls Class G cement. t: CT un -stung and 3 bbls cmt, 131 ft, placed on top of cement retainer, leaving TOC at approx 7665 ft MD Note: Tagged TOC was 7,505' kb witnessed and pressure t; t , tested to 1,600psi 2- 29 -12. 4-112: M. TD 43,320' PBTD = 8,058' MAX HOLE ANGLE = 64 A1,790' Revised By: TDF 1 -24 -2013 • Kenai CLU ‘• PROPOSED Well: Cannery Loop Unit -06 Hilcor, Alaska, LLC Last Comoleted:10 /23/2000 CASING DETAIL RKB=21' MSL Size Type Wt/ Grade/ Conn ID Top Btm 9 -5/8" Conductor 53.5 / P -110 / Unknown 9.95 Surf 91' ' 7 -5/8" Surface 23 & 26 / L -80 / Unknown 6.875 Surf 2,966' 4 -1/2" Production 12.6# / L -80 / Hydril 521 3.958 Surf 8,320' JEWELRY DETAIL 9 -5 /8" No Depth ID Item 1 6,049' 3.813 4 -1/2" "X" Nipple 2 ±6,910' CIBP 3 7,796' Cement Retainer (See Detail Box) PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Date Status B -1 ±6,874' ±6,880' ±4,308' ±4,312' 6' 6 Future Future B -2 6,919' 6,932' 4,337' 4,346' 13' 6 3/31/2012 Isolated 7,846' 7,860' 4,961' 4,970' 14' 6 10/23/2000 Squeezed C -1 7,883' 7,945' 4,986' 5,028' 62' 6 6/10/2004 Squeezed 7L 7,962' 7,986' 5,039' 5,055' 24' 6 6/9/2004 Squeezed C -2 8,014' 8,024' 5,074' 5,081' 10' 6 10/23/2000 Squeezed 8,024' 8,062' 5,081' 5,106' 38' 6 6/8/2004 Squeezed INCLINATION DETAIL Inclination approx. 60 deg, 2,300 -5,800 ft MD Inclination 619 dropping to 409, 5,800 ft MD to TD fl [ 1 &1 7 1 2 9 Cement retainer set at 7,796' MD, Sterling C1 and C2 intervals squeezed with approx. 6bbls Class G cement. CT un -stung and 3bbls cmt, 131', placed on top of cement 3 retainer, leaving TOC at approx. 7,665' MD Note: Tagged TOC was 7,505' kb witnessed and pressure tested to 1,600psi 2- 29 -12. 4-1/2" -1 TD 4,320' PBTD = 8,058' MAX HOLE ANGLE = 64 A1,790' Revised By: TDF 3 -11 -2013 • • + ___ ._______ . _ I I N I l 1 IC 1 1 N 01 CL 01RD — - FW 06 I , ,0„ I I t l I. +�s rs I I as i .. 1 4s I y t _. . CL oa _r i KU 13• I ,," -. 1 U04 I 1 i 1 1 I 1 I I I r . � I otO i 1 t 1 I a `. cLU 1 10 I X04 F EET The CLU -06 is the only well producing in the Sterling Sands, all others are either producing from the Beluga or Tyonek sands. 1 Marathon Alaska Production LLC f \\ /j Alaska Asset Team Marathon Oil P.O. Box 1949 Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1350 RECEIVED April 10, 2012 APR 1 12012 Cathy Foerster Alaska Oil & Gas Conservation Commission AOGCC 333 W 7 Ave Anchorage, Alaska 99501 Reference: 10 -407 Well Completion Report and Log ADO -Q Field: Cannery Loop Unit Well: Cannery Loop Unit #6 Dear Ms Foerster, ANEE) JUN 2 9 ` t - Submitted for your records is the Well Completion Report and Log for CLU -6 well. A 2 -7/8" tubing was installed to a setting depth of 3,130' MD. The ABA -1 well was then completed into the Sterling formation. Efforts to produce the Sterling formation were unsuccessful. ABA -1 is presently shut -in awaiting further evaluation of the utility of the Sterling formation at the Abalone location. Please contact me at (907) 283 -1371 if you have any questions or require additional information. Sincerely, •I‹ S. • N.5 4P Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -407 Well Completion Report & Log cc: Houston Well File Well Schematic Kenai Well File Operations Summary (2) KJS STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM SION WELL COMPLETION OR RECOMPLETION R EPORT AND LOG la. Well Status: Oil ❑ Gas SPLUG ❑ Other Abandoned ❑ Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ❑ WINJ ❑ WAG WDSPL ❑ No. of Completions: 0 Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill #: 200 - 033 Marathon Alaska Production LLC Aband.: 3/31/2012 Sundry #: 312 - 103 ,✓ 3. Address: PO Box 1949 6. Date Spudded: 13. API Number: Kenai Alaska, 99611 - 1949 9/9/2000 50 133 - 20492 - 00 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 113' FSL, 465' FEL, Sec. 7, T5N, R11W, SM 9/18/2000 Cannery Loop Unit #6 Top of Productive Horizon: 8. KB (ft above MSL): 21' 15. Field /Pool(s): 3,080' FSL, 3,360' FWL, Sec. 8, T5N, R11W, SM GL (ft above MSL): 22' Cannery Loop Field /Sterling Total Depth: 9. Plug Back Depth(MD +TVD): 3,716' FSL, 4,180' FWL, Sec. 8, T5N, R11W, SM 7,505' 4,732' Undefined Gas Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 272,505.00 y - 2,388,566.00 Zone- 4 8,320' 5,277' ADL - 60568 & ADL - 60569 TPI: x- 276,862.37 y- 2,391,951.60 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 277,157.90 y - 2,392,187.01 Zone- 4 NA NA NA 18. Directional Survey: Yes ❑ No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) NA (ft MSL) NA 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re- drill /Lateral Top Window MD/TVD: NA 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE HOLE SIZE CEMENTING RECORD FT TOP BOTTOM TOP BOTTOM PULLED 9 -5/8" 53.5 P -110 0' 91' 0' 91' Driven 7" 23 & 26 L -80 0' 2,983' 0' 2,320' 8 -1/2" 307 sks 4-1/2" 12.6 L -80 0' 8,124' 0' 5,148' 6 -1/8" 547 sks 24. Open to production or injection? Yes ❑ No El If Yes, list each 25. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) MD TVD Perf Size Number 0 0 6,919' - 6,932' 4,437' - 4,346' 0.37" 6 spf RECEIVED DEPTH INTERV CIID AND KIND OF MATERIAL USED APR 1 12012 AOGCC 27. PRODUCTION TEST Date First Production: 3/31/2012 Method of Operation (Flowing, gas lift, etc.): Flowing Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: NA Test Period 0 - - 64/64 100% gas Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate 0 - - NA 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No El Sidewall Cores Acquired? Yes ❑ No El If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. R%DMS APR 12 2012 4 Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE �� /� Submit (Original only G (A.., 29, GEOLOGIC MARKERS (List all formations and mak encountered): 30. FOR N TESTS NAME MD TVD Well tested? Yes U No U , list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, Permafrost - Top and submit detailed test information per 20 AAC 25.071. Permafrost - Base Sterling 84 6,912' 4,332' Sterling C1 7,846' 4,961' Sterling C2 8,014' 5,074' Formation at total depth: 31. List of Attachments: Operational Summary & Wellbore Schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kevin Skiba (907) 283 -1371 Printed Name: Kevin J. Skiba Title: Regulatory Compliance Representative • Signature: ��j�/1,� • Phon (907) 283 -1371 Date: April 10, 2012 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. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole Item 1 b: Classification of Service wells: Gas Injection, Water Injection, Water- Altemating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with prod Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level 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. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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 24: 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 in Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: 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. Form 10 -407 Revised 12/2009 O perations Summary Report by J Marathon Oil • Well Name: CANNERY LOOP UNIT 6 Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6007005N011W01 CANNERY LOOP UNIT ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 6.40 12.80 6.40 5/1/2000 9/24/2000 Daily Operations Report Date: 3/16/2012 Job Category: R &M MAINTENANCE 24 Hr Summary MIRI Baker coil to jet well dry and BOP Test. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 08:00 08:30 0.50 SAFETY MTG Arrive location, sign in, receive safe work permit, hold PJSM - topics discussed - reviewed JSA, assigned jobs, slips, trips, falls, eye wash station, high pressure, emergency numbers, emergency vehicles, muster area, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, stop the job authority, and keeping the focus on the job. Emphasize that we are in no hurry today. Notified Mr Jim Regg of todays BOP test 2/15/2012 at 9:35 am. HE sent Bob Noble to witness setting of cement retainer and wants Bob to witness cement tag and pressure test. But waived witness of BOP test. 08:30 14:30 6.00 RURD COIL Start equipment. Lay out drip liners. MEOH tank, and flowback tank are already rigged up. Move choke into berm. Spot BJ CoilTech equipment. Hammer up 2" hard lines from choke to flowback tank. ND tree cap. NU DSA. NU 4- 1/16" Dual combi BOP's. MU hard lines to flowa tee. United Rentals delivers second light plant. 14:30 18:00 3.50 TEST BOPE Perform visual function test Dual Combi BOP's. Test surface lines and inside reel valve to 4500 psi. Install test bar. Test pipe rams /slips- 250 psi low /4500 psi high. Test good. Close blinds. Test blind /shear rams. 250 psi low. Test good. Test pipes /slips to 4500 psi. Equilizer ports leaking. Dissassemble ports. Needles appear to be damaged. Re- install and re -test. Still leaking. Shut down and wait for new parts to come from shop. New parts arrive. Pressure test pipe /slip rams to 4500 psi high. Test good. Release pressure. Test accummulator unit. 18:00 18:30 0.50 SECURE WELL Install night cap in BOP's. Secure well and location for the night. Sign out and leave loc. Report Date: 3/17/2012 Job Category: R &M MAINTENANCE 24 Hr Summary RIH w/ coil and jet casing dry. Recover 118 bbls of KCL water. Leave 2045 psi on wellhead for under balanced perforating. Ops - Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status ' Code Com 08:00 08:30 0.50 SAFETY MTG Arrive location, sign in, receive safe work permit, hold PJSM - topics discussed - reviewed JSA, assigned jobs, slips, trips, falls, eye wash station, high pressure, emergency numbers, emergency vehicles, muster area, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, stop the job authority, and keeping the focus on the job. Emphasize that we are in no hurry today. Notified Mr Jim Regg of todays BOP test 2/15/2012 at 9:35 am. HE sent Bob Noble to witness setting of cement retainer and wants Bob to witness cement tag and pressure test. But waived witness of BOP test. 08:30 10:21 1.85 RURD COIL Start equipment. MU BHA on dimple -on connection -3' straight bar and 2" jet nozzle. Dimple -on has been pull tested. PU injector assembly and carry to wellhead. NU injector. 10:21 13:51 3.50 JET N2 RIH w/ coil tubing nozzle to 7425' ctm. At 500 ' start pumping N2 at 500 scf /min. Increase N2 to 1000 scf /min at 7425'. Recover 118 bbls of fluid. POOH. Increase well pressure to 2045 psi. Close in swab, upper, and lower master valves. 13:51 15:51 2.00 RURD COIL OOH. ND coil injector from WH. ND BOP's. Install tree cap. Pressure test tree cap. Test good. RD 2" hard lines. RD pump and coil units. PU drip liners. RD some of the Arctic Iron. Will finish the remaining Monday as well as release the Rainfor Rent tank. 15:51 16:21 0.50 SECURE WELL Secure well and location for the night. Sign out and leave loc. Report Date: 4/1/2012 Job Category: R &M MAINTENANCE 24 Hr Summary RU eline, make a GRJB run, perforate Sterling B2 interval, 13 ft OA, 6919 -6932 ft MD. RD eline. Flow well. Ops - Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 08:00 08:45 0.75 SAFETY MTG Arrive KGF, hold PJSM, review hazards, aspects of the job that we need to keep in mind. Assign roles, cover JSEA, obtain safe work permit. 08:45 10:15 1.50 RURD ELEC Travel to CLU pad 1. Spot equipment, RU Eline unit, crane. 10:15 10:30 0.25 TEST BOPE MU lubricator, PU tool string: RS, 5 ft wt bar, 3 -1/8" GR/CCL, 4 ft wt bar, JB/3.75" GR. PU lub, tools, stab. Pressure test lub to 250/3000 psi. Good test. Recover 50/50 McOH test fluid. www.peloton.com Page 1/2 Report Printed: 4/5/2012 ill Dperations Summary Report by J Marathon Oil Well Name: CANNERY LOOP UNIT 6 Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6007005N011 W01 CANNERY LOOP UNIT ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 6.40 12.80 6.40 5/1/2000 9/24/2000 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 10:30 16:45 6.25 RUNPUL ELEC RIH w/ GRJB, set down repeatedly, suspect N2 has dried out asphaltines? coating inside of monobore, or possibly the friction from the newly changed out grease tubes. Get to 6200 ft, POOH to make changes. 16:45 17:45 1.00 RURD ELEC Change out grease head tubes from new to old, rehead. PU lubricator, tools to wellhead. 17:45 18:00 0.25 TEST BOPE Pressure test lubricator with diesel, drop diesel to help the tool string to drop. Good test. 18:00 19:00 1.00 RUNPUL ELEC RIH w/ GRJB, tag TOC (still at the same depth), POOH. 19:00 20:00 1.00 PULD PGUN LD GRJB, PU 13 ft of pert guns: RS gamma gun, 3 -3/8" pert gun barrel (15 OA, 13 ft loaded), loaded w/ 3 -1/8" Owen Hero charges (for shooting in dry pipe), RIH. 20:00 20:15 0.25 CORL FORM Pull correlation pass, 7000 to 6700 ft. 20:15 21:00 0.75 PERF CSG Lower well pressure, bleed off N2 pressure to shoot at balance. Bled down to 1610 psi surface pressure (procedure stipulated 1750 psi to balance to 2000 psi BHP estimated). Pulled on depth, perforated 6919 -6932 ft MD, correlated to Sep 18 2000 SL 09. s o s ire , goo Ion. Note: Following perforating, surface pressure bled off to formation to 1300 psi N2 surface pressure. 21:00 21:45 0.75 RUNPUL ELEC POOH w/ guns. LD gun assembly. 21:45 22:45 1.00 RURD ELEC RD Eline, release unit. 22:45 01:45 3.00 FLOW BACK Flowback/vent N2 until LEL indicated gas, then put into HP sales. Initial rate rate 5 MMCFD, 0 indicated water, 1200 -1300 psi FTP at 01:45 AM. Operations continued to flow through the night, attempting to stay above unload. As of —10:00 AM Sunday, FTP at —1100 psi, rate at —4MM, but making significant water, —180+ BWPD rate. Note water metering not working in SCADA. www.peloton.com Page 2/2 Report Printed: 4/5/2012 J t. • • Cannery Loop Unit #6 �, Pad CLU -1 FINAL Schematic] ,� jl 113' FSL, 465' FEL, Sec. 7, Post Sterling B2 RCP arathon 011 T5N, R11W, S.M. 1 1 Permit #: 200 -033 API #: 50- 133 - 20492 -00 -00 Prop. Des: ADL- 60568 & Conductor Pipe ADL- 60569 9 -518" P -110 53.5 ppf KB elevation: 42.5' (21' AGL) MD Surf B 91 m Latitude: TVD Surf 91' Longitude: Spud: 9/9/2000 TD: 9/18/2000 Rig Released: Surface Casing 7" L -80 23 & 26 ppf Top Bottom MD 0' 2,966' TVD 0' 2,311' 8 -1/2" hole Cmt w/ 280 sks LITECRETE, + 27 sxs LITECRETE top job, cement to surface Production Casing 4 -1/2" L -80 12.6 ppf Hydril 521 Inclination approx 60 deg, 2300 -5800 ft MD Top Bottom MD 0' 8,320' TVD 0' 5,277' RA tags: 6760, 7284, 7737 ft MD 6 -1/8" hole, cemented with: lead: 161 sxs 12.9 ppg class G, 2.08 yld, 59.6 bbl tail: 386 sxs 15.8 ppg class G,1.18 yld, 82.8 bbls Note: caliper determine 28% overage, calc'd TOC at 1675 ft MD, but TOC could be below surface shoe - uncertainty is depicted with lighter cement shading. 4 -1/2" 'X' Nipple, 3.813" ID, 6,049' KB Inclination 61° dropping to 40° , 5800 ft MD to TD Sterling B2 Interval 1 1 Perforated 6919 -6932 ft (3/31/2012) 1 3.375" guns loaded with 6 SPF 60 degree - phased with Owen Super Hero 3 -1/8" charge, SDP3125- , 311NT4 charges (for dry pipe). /( Cement retainer set at 7796 ft MD, Sterling C1 and C2 intervals squeezed with approx. 6 bbls Class G cement. CT unstung and 3 bbls cmt , 131 ft, placed on top of cement retainer, leaving TOC at approx 7665 ft Sterling C1 & C2 Sands MD (note: Tagged TOC was 7505'kb witnessed and Perforations k -+1 011C+ pressure tested to 1600 psi (2- 29 -12) MD Net Ft TVD Gun Date Sterling - C-1: 7,846' 7,8 86' 7,860' 14' 4,961' - 4,970' 6 spf 10/23/00 7,883' - 7,945' 62' 4,986' - 5,028' 6 spf 6/10/04 Sterling C -2. PBTD: 8,058' MD, 5,104' TVD 7,962' - 7,986' 24' 5,039' - 5,055' 6 spf 619/04 TD: 8,320' MD, 5,277' TVD 8,014' - 8,024' 10' 5,074' - 5,081' 6 spf 10/23/00 8,024' - 8,062' 38' 5,081' - 5,106' 6 spf 6/8/04 Well Name & Number: Cannery Loop Unit 6 Lease: Cannery Loop Unit County or Parish: Kenai Peninsula Borough State: Alaska 1 Country:I USA Perforations (MD): 7,846' - 8,062' Perf (TVD): 4,961' - 5,106' Angle @KOP and Depth: 1 .33° @ 400' MD Angle @ Perfs: 40° -- 61° KOP TVD: 400' Date Completed: 10/23/2000 RKB: 21' Revised By: M ike Ellis Last Revision Date: April 1, 2012 • • I {2 'FP 1 I, ( J , y 6 i 1 1' f r i ` �' b i � g �" 4 i j � � g � g SEAN PARNELL, GOVERNOR ALASK / r � S+ AVENUE SUITE 100 OIL AND GAS 333 W. 7th , CONSERVATION COMMISSION 1 ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Kevin J. Skiba Regulatory Compliance Representative ao 0 3 3 Marathon Alaska Production, LLC P.O. Box 1949 Kenai, AK 99611 -1949 Re: Cannery Loop Field, Sterling Undefined Gas Pool, Cannery Loop Unit #6 Sundry Number: 312 -103 Dear Mr. Skiba: 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. Sincerely, Cathy P. Foerster Chair DATED this6.1--day of March, 2012. Encl. • • • t' / Marathon Alaska Production L• Ir�".t,/ Alaska Asset Team Marathon Oil P.O. Box 1949 Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1350 March 16, 2012 Cathy Foerster Alaska Oil & Gas Conservation Commission 333 W 7 Ave Anchorage, Alaska 99501 , ! 4,; f G cr.rs Reference: 10 -403 Application for Sundry Approvals Field: Cannery Loop Field Well: Cannery Loop Unit #6 Dear Ms Foerster, Submitted for your approval is the10 -403 Application for Sundry Approvals for CLU -6 well. CLU -6 Sterling C1 and C2 sands were recently plugged back in preparation for the CINGSA gas storage project. Marathon proposes to move up -hole and recomplete CLU -6 into the B2 sands. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, la 1:12 Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -403 Application for Sundry Approvals cc: AOGCC Proposed Well Schematic Houston Well File Detailed Operations Program Kenai Well File (2) KJS STATE OF ALASKA 3 «LZ"- • AL* OIL AND GAS CONSERVATION COMMI ON APPLICATION FOR SUNDRY APPROVAL ' 2012 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool Ei . Repair well ❑ "!r `'?iohange etAt 'e ';Bf 95;iiiii Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Spp¢rfyrTirme Extension ❑ Operational shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter casing ❑ Other: Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Alaska Production LLC Development 0 Exploratory ❑ 200 -033 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 50- 133 - 20492 -00 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes El No 0 Cannery Loop Unit #6 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL - 60568 & ADL - 60569 ' Cannery Loop Field / Sterling Undefined Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8,320' . 5,277" 7,505' 4,732' 7,505' NA Casing Length Size MD TVD Burst Collapse Structural Conductor 91' 9 -5/8" 91' 91' 10,900 psi 7,950 psi Surface 2,945' 7" 2,983' 2,320' 7,240 psi 5,410 psi Intermediate Production 8,103' 4 - 1/2" 8,124' 5,148' 8,440 psi 7,500 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NA NA - - - Packers and SSSV Type: SSSV: NA Packers and SSSV MD (ft) and TVD (ft): MD TVD Cement Retainer Baker 7,796' 4,928' 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program la BOP Sketch ❑ Exploratory ❑ Development igl • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: March 29, 2012 ' Commencing Operations: Oil ❑ Gas El ' WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature . 6 Php (907) 283 -1371 Date March 15, 2012 ,QAhyv (9... . COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .• 2 1 D3 ' Plug Integrity ❑ BOP T est Mechanical Integrity Test ❑ Location Clearance ❑ Other: if goo „ire.: g lest , Subsequent Form Required: J� _ L/r1 "7 ` V 7 V T APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date: 3 - 2. 2 --I? 47 4 3 - 2.1• /a �, 31 . �s ORIGINAL1/Z h ,_>, t, -5,-/- 10 -403 Revised 1/2010 Submit in Duplicate + • i►'X /J Marathon Oil CLU 6 Cannery Loop 1 Pad Sterling Recompletion Procedure APPROVALS: Mike Marini 1 -23 -2012 Program Writer No deviation from this procedure to occur without prior approval from supervisor. Well Status: Marathon has abandoned the Sterling C1 and C2 sands in this well in agreement with the CINGSA Sterling C Sand gas storage project. Marathon will go forward with the Sterling B Sand development as part of this follow up procedure. This procedure is to cleanout fluid in the wellbore and perforate the B2 Sand. CINGSA notification and approval are required: Notifying CINGSA of wellwork at Cannery Loop, and gaining CINGSA's approval, is required per the CINGSA agreement . prior to commencing wellwork. Coordinate CINGSA notification with Chick Underwood. Objective: Rig up coil tubing and pump N2 to reverse circulate fluid from wellbore (no perf's, BOP has shear rams, plug and wellbore have been tested, fluid is 6 %KCL water), pump N2 to pressurize wellbore for under balance while perforating, rig up eline and perforate, flow back well. Note: Previous wellwork on this well will have provided a PBTD and gauge ring run sufficient to ensure that there are not restrictions that would prevent the coil or perf guns from being able to be run. (Pollard ran 3.70" gauge ring 9/20/2011 and on 2/29/2012 tagged TOC at 7505'KB). Resources: MIRU 1 -3/4" Coil Unit w/ BOP's, N2 Unit MI WO unit, 4- 1/16" BOP's and accumulator, MI crane. MIRU flow back tank, choke, and 2" iron Paperwork: Sundry Approval, Procedure, WBD, Work Permit, Well Ops transfer sheet, BOP test form and Perforating QA/QC check list, CINGSA notification CAPACITIES bbls /ft. Collapse Burst 4 -1/2" 12.6# L -80 0.01522 7,500 8,430 1 • • Procedure: CT and N2: 1. Hold PJSM prior to rigging up equipment. MIRU flow back tank, gas buster, choke and 2" iron. 2. MIRU BJ coiled tubing unit. Verify 24 hour notification has been made to AOGCC for BOP test. Rig up fluid and N2 pumps. RU pumping iron (BJ) and Arctic flow back iron (MOC). 3. Nipple up BJ CT wellhead assembly (WHA). Current WHA is 4 -1/16" 5M swab /cap. WHA to include 4- 1/16" - 5M X 4- 1/16" - 10M DSA, 4- 1/16" - 10M X 5' Flanged Riser, 4- 1/16" — 10M flow cross and 4- 1/16" - 10M Dual -Combi BOP (dressed for 1 -3/4" CT). Function test BOP. Stab 1 -3/4" CT into injector. Have BJ prep coil end off location prior to RU. Nipple up injector to WHA. 4. Perform complete BOP test with 50:50 MEOH and the test bar. Complete AOGCC BOP Test Report (Correct form dated 01/25/2010). Pressure test pump iron (200 low /4500 high psi). Pressure test WHA and flow back iron to choke manifold (200/4500 psi). Pressure test BOP rams (200/4500 psi). Test inside reel valve to (200/4500 psi). Note BOP test witness or waiver in WellView, including details. 5. (- OPTIONAL -) Pig CT. Run end of CT with pig catcher onto Well head. Open valves on flow cross to flow back tank. Pump 5 bbls water, cleaning pig, and coil displacement +10% behind pig. Record displacement volume of coil. 6. MU CT BHA. Nipple injector off WH. PU 10' of 4- 1/16" CQ lubricator as needed to cover BHA. Install dimple on connector. Pull test to 18K. Pressure test coil to 3200 psi. Install reverse circulation assembly for cleanout with no check valves. 7. Nipple up injector to WHA. Pressure test WHA using CT kill line (200/1500 psi). Bleed WHP to flow back tank. Caution: Coil subject to collapse above 1500 psi. 8. Open well and RIH CT to 7300' MD, reverse jetting well dry with nitrogen. POOH trapping +- 2050 psi surface nitrogen pressure (2000psi bottom hole pressure at 6932'MD 4255'TVD plus 300psi additional incase bleed off before perf work) in 4- 1 /2" monobore to prepare for perforation work on the Sterling B2 sands. 9. RD BJ Services coil tubing and nitrogen units and release equipment. E -Line: 1. MIRU E -Line. Pressure test lubricator to 250/4000 psi with McOH /water to minimize hydrate formation. Recover test fluid prior to opening swab valve. 2 • 2. PU 3 -1/8" gamma ray /CCL and roller boogies. Note that the X Nipple at 6049'KB has a 3.813" ID — mic tools prior to picking up to ensure tools will pass 3.81". Correlate MD to Sep 18 -2000 SLB Density, NP, GR, Caliper Platform Express Log. Correlate depth of B2 perforations 6919' -6932' MD to Gams /CCL 3. Prepare to perforate the proposed Sterling interval. Test quicktest sub to 4000psi. PU and RIH w/ CCL,and 3.375" guns loaded 6 SPF 60 degree - phased with Connex charges. Maintain 1750 psi nitrogen surface pressure on tubing while RIH to perforate at balance (2000psi at pelf's). 4. Contact Mike Ellis / Bell Sennour if perfs appear to have poor response. Backup Perf's of 6952' to 6960' will be shot at later date if needed. 5. RDMO E -Line Flow Back: 1. Prepare for flowback at 25% Draw Down or 1500psi FTP through gas buster until N2 dissipates, then turn well on -line to system. Reservoir team has indicated concern for high solids production on this well. Flow test well per Subsurface /Reservoir guidance. 3 , 4 • Cannery Loop Unit #6 p fift4 Pad CLU -1 Proposed Schematic ', 113' FSL, 465' FEL, Sec. 7, Sterling B2 RCP Marathon O i l T5N, R11W, S.M. 1 1 Permit #: 200 -033 API #: 50- 133 - 20492 -00 -00 Prop. Des: ADL- 60568 & Conductor Pipe ADL- 60569 9 -5/8" P -110 53.5 ppf KB elevation: 42.5' (21' AGL) MD Surf Bottom 91' Latitude: TVD Surf 91' Longitude: Spud: 9/9/2000 TD: 9/18/2000 Rig Released: Surface Casing 7" L -80 23 & 26 ppf Top Bottom MD 0' 2,966' TVD 0' 2,311' 8 -1/2" hole Cmt w/ 280 sks LITECRETE, + 27 sxs LITECRETE top job, cement to surface Production Casing 4 -1/2" L -80 12.6 ppf Hydril 521 Botto Inclination approx 60 deg, 2300 -5800 ft MD MD Top 8,320' m TVD 0' 5,277' RA tags: 6760, 7284, 7737 ft MD 6 -1/8" hole, cemented with: lead: 161 sxs 12.9 ppg class G, 2.08 yld, 59.6 bbl tail: 386 sxs 15.8 ppg class G, 1.18 yld, 82.8 bbls Note: caliper determine 28% overage, calc'd TOC at 1675 ft MD, but TOC could be below surface shoe - uncertainty is depicted with lighter cement shading. 4 -1/2" 'X' Nipple, 3.813" ID, 6,049' KB Inclination 61° dropping to 40° , 5800 ft MD to TD Sterling B2 Interval -6919 -6932 ft MD final depths per Reservoir. i (Note that CINGSA notification req'd.) Backup Perf adds: 6952 -6960 ft MD Cement retainer set at 7796 ft MD, Sterling C1 and C2 intervals squeezed with approx. 3.5+ bbls Class G cement. CT unstung and min. 2 bbls cmt ,TOC at approx 7505'KB (2/29/2012 verified by slickline) Sterling C1 & C2 Sands ��,` �� Perforations MD Net Ft TVD Gun Date Sterling -1: 7,,58466 ' - 7,860' 14' 4,961' - 4,970' 6 spf 10/23/00 7,883' - 7,945' 62' 4,986' - 5,028' 6 spf 6/10/04 PBTD: 8,058' MD, 5,104' TVD Sterling C -2: TD: 8,320' MD, 5,277' TVD 7,962' - 7,986' 24' 5,039' - 5,055' 6 spf 6/9/04 8,014' - 8,024' 10' 5,074' - 5,081' 6 spf 10/23/00 8,024' - 8,062' 38' 5,081' - 5,106' 6 spf 6/8/04 Well Name & Number: Cannery Loop Unit 6 Lease: Cannery Loop Unit County or Parish: Kenai Peninsula Borough State: Alaska 1 Country:' USA Perforations (MD): 7,846' - 8,062' Perf (TVD): 4,961' - 5,106' Angle @KOP and Depth: 1.33° @ 400' MD Angle @ Perfs: 40° -> 61° KOP TVD: 400' Date Completed: 3/23/2000 RKB: 21' Revised By: Mike Marini/ Mike Ellis Last Revision Date: March 12, 2012 ,fir +�. Marathon Alaska Production LL itts Alaska Asset Team • P.O. Box 1949 Marathon O Oil Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1350 March 15, 2012 Cathy Foerster Alaska Oil & Gas Conservation Commission 333 W 7 Ave-- •°"� - "' • Anchorage, Alaska 99501 1 gECL � �:: Reference: 10 -407 Well Completion Report and Log • ii ; �;' Field: Cannery Loop Field Well: Cannery Loop Unit #6 a -,33 Dear Ms Foerster, Submitted for your records is the Well Completion Report and Log for CLU -6 well. The Sterling C1 & C2 sands were isolated to facilitate the development of the CINGSA gas storage project. A cement retainer was placed at 7,796' MD. Six barrels of cement were placed below the retainer with remaining three barrels dumped on top. Please contact me at (907) 283 -1371 if you have any questions or require additional information. Sincerely, Kg/117/ lila- Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -407 Well Completion Report & Log cc: Houston Well File Well Schematic Kenai Well File Operations Summary (2) KJS STATE OF ALASKA , ALA. OIL AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 0 lb. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: 0 • Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., 0., or 12. Permit to Drill #: 200 - 033 Marathon Alaska Production LLC Aband.: 2/22/2012 Sundry #: 312 - 041 3. Address: PO Box 1949 6. Date Spudded: 13. API Number: Kenai Alaska, 99611 -1949 9/9/2000 50- 133 - 20492 -00 -00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 113' FSL, 465' FEL, Sec. 7, T5N, R11W, SM 9/18/2000 Cannery Loop Unit #6 Top of Productive Horizon: 8. KB (ft above MSL): 21' 15. Field /Pool(s): 3,080' FSL, 3,360' FWL, Sec. 8, T5N, R11W, SM GL (ft above MSL): 2T Cannery Loop Field /Sterling Total Depth: 9. Plug Back Depth(MD +TVD): 3,716' FSL, 4,180' FWL, Sec. 8, T5N, R11W, SM 7,505' 4,732' Undefined Gas Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 272,505.00 y - 2,388,566.00 Zone- 4 8,320' 5,277' ADL - 60568 & ADL - 60569 TPI: x- 276,862.37 y- 2,391,951.60 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 277,157.90 y - 2,392,187.01 Zone- 4 NA NA NA 18. Directional Survey: Yes ❑ No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) NA (ft MSL) NA 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re- drill /Lateral Top Window MD/TVD: NA 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE HOLE SIZE CEMENTING RECORD FT TOP BOTTOM TOP BOTTOM PULLED 9 -5/8" 53.5 P -110 0' 91' 0' 91' Driven 7" 23 & 26 L -80 0' 2,983' 0' 2,320' 8 -1/2" 307 sks 4-1/2" 12.6 L -80 0' 8,124' 0' 5,148' 6 -1/8" 547 sks 24. Open to production or injection? Y j � VIZI If Yes, list each 25. TUBING RECORD interval open (MD +TVD of Top & Bottpifi; Perforatior}'Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) MD TVD Perf Size �� , Number 0 0 "c" 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. -' €tp, . 4 � ° DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. ,- " . PR ODUCTION TEST Date First Production:' a Method of Operation (Flowing, gas lift, etc.): �'^' Flowing Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: NA Test Period --` 0 0 0 64/64 100% gas Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate --O 0 0 0 NA 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No U If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. R BDMS MAR 1 91012 Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE ./ Lo S i Origin only / / 5 29. GEOLOGIC MARKERS (List all formations and m encountered): 30. FORD N TESTS NAME MD TVD Well tested? Yes No , list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, Permafrost - Top and submit detailed test information per 20 AAC 25.071. Permafrost - Base Sterling B4 6,912' 4,332' Sterling C1 7,846' 4,961' Sterling C2 8,014' 5,074' Formation at total depth: 31. List of Attachments: Operational Summary & Wellbore Schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kevin Skiba (907) 283 -1371 Printed Name: Kevin J. Skiba Title: Regulatory Compliance Representative Signature: e#i *_ Phone: (907) 283 - 1371 Date: March 15, 2012 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. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole Item 1 b: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with prod Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level 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. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. 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 24: 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 in Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: 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. Form 10 -407 Revised 12/2009 i1 \JJ fipperations Summary Report by J , rah n it Well Name: CANNERY LOOP UNIT Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6007005N011W01 CANNERY LOOP UNIT ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 6.40 12.80 6.40 5/1/2000 9/24/2000 Daily Operations Report Date: 2/15/2012 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Baker pump truck to load casing with 6% KCL water and establish injection. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 12:30 13:30 1.00 RUNPUL EQIP MIRU Baker pump truck. RU 2" hard lines to well. 13:30 14:00 0.50 TEST EQIP Pressure test lines to 2090 psi. Tesst good. 14:00 14:00 PUMP WTR Open swab valve and begin loading casing. Casing volume is 106 bbls. Pump 116 bbls at 65 psi. @ 2 bpm. Pump total of 160 bbls at 80 psi. Shut well in. 14:00 14:00 SECURE WELL Re- install tree cap. Secure well and location for the night. Sign out and leave loc. Report Date: 2/16/2012 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Pollard E Line to run 3.70" GR and set Baker cement retainer,' Mr Bob Noble AOGCC witnessed the setting of the cement retainer @ 7796'. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Corn 08:00 08:30 0.50 SAFETY MTG Arrive location, sign in, receive safe work permit, hold PJSM - topics discussed - reviewed JSA, assigned jobs, slips, trips, falls, eye wash station, high pressure, emergency numbers, emergency vehicles, muster area, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, stop the job authority, and keeping the focus on the job. Emphasize that we are in no hurry today. 08:30 09:00 0.50 PREP ' LOC Pick well house and set aside. Well house was disconnected earlier. 09:00 10:00 1.00 RURD ELEC Spot E line unit. PU lubricator. MU tool string -Gamma ray /CCL and 3.70" GR. Carry luricator to wellhead 10:00 10:15 0.25 TEST EQIP PTest lubricatot too 1000 psi. Test good. 10:15 12:00 1.75 LOG CSG RIH (1) w/ 3.70" GR. Make two logging passes to get on depth. POOH. Call Mr Jim Regg to notify of pending BOP test. He said he would like to ;have an inspector witness the setting of ther retainer. So he made arrangement for Mr Bob Noble to come watch that operation. 12:00 12:45 0.75 SAFETY MTG OOH. Hold Explossives safety meeting to the armong of theBaker cement retainer. Post signage. Turn off cell phones and send guard to the entry gate. Arm tool. 12:45 14:45 2.00 RUNPUL ELEC RIH (2) with Baker cement retainer. Run logging passa to get on depth with Expro pert log. (Tool lenth from CCL to top of retainer is 11'). Set top of retainer @ 7796'. (50' above top pet) Definitely saw retainer set. Rocked the truck at 53 seconds.) Lost 200 lbs of string weight. PUH several hundred feet. RIH and set tool string down on retainer. Tagged @ 7796' and it held string weight. POOH. 14:45 15:45 1.00 RURD ELEC - OOH. RD E line unit and equipment. Re- install tree cap and PTest to 220 psi. 15:45 16:00 0.25 SECURE WELL Secure well and location. Turn in permit. Sign out and leave loc. Report Date: 2/17/2012 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Baker Coil tubing. Test BOP's. Pig coil. Ops Trouble Start Time End Time Our (hr) Ops Code Activity Code Status Code Corn 07:00 08:00 1.00 SAFETY MTG Arrive location, sign in, receive safe work permit, hold PJSM - topics discussed - reviewed JSA, assigned jobs, slips, trips, falls, eye wash station, high pressure, emergency numbers, emergency vehicles, muster area, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, stop the job authority, and keeping the focus on the job. Emphasize that we are in no hurry today. Notified Mr Jim Regg of todays BOP test 2/15/2012 at 9:35 am. HE sent Bob Noble to witness setting of cement retainer and wants Bob to witness cement tag and pressure test. But waived witness of BOP test. 08:00 14:00 6.00 RURD COIL Start equipment. Start light plant. Lay out drip liners. MEOH tank, fluid tank, and flowback tank are already rigged up. Move choke into berm. Spot BJ CoilTech equipment. Hammer up 2" hard lines from choke to flowback tank. Have problem with four studs while removing the tree cap flange. Have to cut one stud. Three are very tough for remove. ND tree cap. NU DSA. NU 4- 1/16" Dual combi BOP's. MU hard lines to flowa tee. United Rentals delivers second light plant. www.peloton.com Page 1/5 Report Printed: 3/9/2012 fn a •perations Summary Report by J� Marathon Oil Well Name: CANNERY LOOP UNIT Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6007005N011W01 CANNERY LOOP UNIT ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 6.40 12.80 6.40 5/1/2000 9/24/2000 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 14:00 15:30 1.50 TEST BOPE Perform visual function test Dual Combi BOP's. Test surface lines and inside reel valve to 6000 psi. Close blinds. Test blind /shear rams. 250 psi low /4500 psi high. Test good. Install test bar. Test pipe rams /slips- 250 psi low /4500 psi high. Test good. Test accummulator unit. Remove test bar. 15:30 16:30 1.00 PUMP TRET Remove BOP cap. PU injector assembly. Install pig catcher. Carry injector to wellhead. Start puming MEOH to pig. Displace coil. 16:30 17:45 1.25 TEST CSG Fill casing with fresh water to perform a pressure test. Pump 98 bbls to load and presssure up casing. test casing to 1000 psi. Hold pressure for 15 minutes. Test good. Release pressure. 17:45 18:30 0.75 RURD COIL Remove injector from wellhead. Inspect pig catcher. no pig. Pump another 20 bbls and check pig catcher for pig. No pig. RD for the night. Install night cap on BOP's. 18:30 18:45 0.25 SECURE WELL Secure well and location for the night. Sign out and leave loc. Report Date: 2/18/2012 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU cement truck and batchmixer to squeeze perfs. Job aborted. Electrical failure on ops cab. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 07:00 07:30 0.50 SAFETY MTG Arrive location, sign in, receive safe work permit, hold PJSM - topics discussed - reviewed JSA, assigned jobs, slips, trips, falls, eye wash station, high pressure, emergency numbers, emergency vehicles, muster area, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, stop the job authority, and keeping the focus on the job. Emphasize that we are in no hurry today. 07:30 08:30 1.00 RURD COIL Start equipment. Start light plant. Lay out drip liners. NU injector assembly on wellhead. 08:30 09:30 1.00 PUMP TRET Carry injector to wellhead. NU injector. Start purring MEOH at 2 BPM 5000 psi to complete pigging of coil. Displace coil. w/ 30 bbls MEOH. 09:30 10:00 0.50 RURD COIL ND injector. Pig is captured in catcher. MU Baker grapple pull test. Pressure test coil to 3500 psi. Informed that the data acquisition system in not working. Spot cement van and batch mixer. 10:00 12:30 2.50 WAITON EQIP Wait on replacement OPS cab. 12:30 14:30 2.00 RURD COIL RU OPS cab. Restring cables. Re- install hydraulic lines to BOP's. Function test OP's. Test good. 14:30 15:00 0.50 SECURE WELL Shut down job for the night. Will resume in the morning. Secure location and sign out. Report Date: 2/19/2012 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU cement truck and batchmixer to squeeze perfs. Job aborted. Continue to have electrical issues with ops cab. Inverter and altermator failure. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 07:00 07:36 0.60 SAFETY MTG Arrive location, sign in, receive safe work permit, hold PJSM - topics discussed - reviewed JSA, assigned jobs, slips, trips, falls, eye wash station, high pressure, emergency numbers, emergency vehicles, muster area, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, stop the job authority, and keeping the focus on the job. Emphasize that we are in no hurry today. 07:36 08:36 1.00 RURD COIL Start equipment. Start light plant. PU injector assembly. PU 20' of 4- 1/16" lubricator. MU tool string - 13/4" coil connector, DFCV, hydraulic disconnect (5/8" ball), 3.65" centralizer, 2.12" weight bar, 3.65" centralizer, 3.06" stringer assembly. PUH in lubricator. 08:36 09:36 1.00 PUMP TRET Carry injector to wellhead. NU injector. Start displacing MEOH out of coil. Pump 30 bbls fresh water. 09:36 10:06 0.50 RURD COIL ND injector. Informed that the data acquisition system in not working. Spot cement van and batch mixer. 10:06 13:06 3.00 WAITON EQIP Wait on electrical repairs and diagnostics 13:06 14:06 1.00 RURD COIL Displace coil w/ MEOH to freeze protect coil. RIH 10 ft and inject MEOH in tree. LD tools and Lubricator. 14:06 14:36 0.50 SECURE WELL Install night cap. Secure well, equipment, and location for the night. Report Date: 2/20/2012 Job Category: R &M MAINTENANCE 24 Hr Summary High wind today. Wind gusts 30 -40 mph. No crane or man -lift work. Watch weater until 10 am. Make the call to shut down today. www.peloton.com Page 2/5 Report Printed: 3/9/2012 /tA/J •perations Summary Report by J Marathon Oil Well Name: CANNERY LOOP UNIT Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6007005N011W01 CANNERY LOOP UNIT ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 6.40 12.80 6.40 5/1/2000 9/24/2000 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com Report Date: 2/22/2012 Job Category: R &M MAINTENANCE 24 Hr Summary RU Baker coil and pump truck to squeeze perfs. RIH w/ coil. Unable to sting into retainer. Make a dozen attempts trying different things but no success. POOH to change centralizer spacing. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 07:00 07:36 0.60 SAFETY MTG Arrive location, sign in, receive safe work permit, hold PJSM - topics discussed - reviewed JSA, assigned jobs, slips, trips, falls, eye wash station, high pressure, emergency numbers, emergency vehicles, muster area, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, stop the job authority, and keeping the focus on the job. Emphasize that we are in no hurry today. 07:36 08:36 1.00 RURD COIL Start equipment. Start light plant. PU injector assembly. PU 20' of 4- 1/16" lubricator. MU tool string - 13/4" coil connector, DFCV, hydraulic disconnect (5/8" ball), 3.65" centralizer, 2.12" weight bar, 3.65" centralizer, 3.06" stringer assembly. PUH in lubricator. 08:36 09:36 1.00 PUMP TRET Carry injector to wellhead. NU injector. Displace coil. w/ 30 bbls fresh water. Shell test to 2000 psi. Test good.. 09:36 12:06 2.50 RUNPUL COIL Run in hole w/ stinger BHA to 7795' ctm. Weight check @ 7700' ctm 16K. 12:06 14:06 2.00 RUNPUL COIL Make first attempt to sting into retainer. RIH pumping .25 bpm to 7795.5 set 3K down on retainer. Increase rate to .5 bpm. No loss of returns. PUH to 7780'- see no over pull. SHould see about 10K RIH(2) to 7795.8 set -2K on retainer. No loss of returns. PUH. No over pull. RIH(3) to 7795.5. Set -2.5K. No loss of returns. RIH(4) to 7795.5. Set down -4K. Pump © 1/2 bpm. Get returns, no over pull. Shut down and make phone calls. PUH 300'. RIH(5) tag. Slowly increase wt to -4K. Bring pump on line. Get returns. No overpull. Continue making repeated attempts to sting in. 14:06 14:36 0.50 WAITON ORDR Call MR Rich Gentses to discuss inablility to get stung into retainer. Wait on return call. Deccission make to POOH and change centralizer setup. 14:36 16:36 2.00 RUNPUL COIL POOH to change centralizer spacing. 16:36 18:36 2.00 RURD COIL OOH. Break down tool string. Examine stinger. No marks on the end of stinger. It still appears brand new. LD 20' of 4- 1/16" lubricator. Displace coil with 30 bbls of MEOH. 18:36 18:51 0.25 SECURE WELL Install night cap on BOP's to secure well for the night. Steam on wheels coming to heat tank. Report Date: 2/23/2012 Job Category: R &M MAINTENANCE 24 Hr Summary RD ops cab. Pull unit forward to accommodate more lubricator. RU OPS cab. PU 32' of lubricator. Call MR. Regg to advise of progress and notify of possible BOP test tomorrow. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 07:30 08:00 0.50 SAFETY MTG Arrive location, sign in, receive safe work permit, hold PJSM - topics discussed - reviewed JSA, assigned jobs, slips, trips, falls, eye wash station, high pressure, emergency numbers, emergency vehicles, muster area, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, stop the job authority, and keeping the focus on the job. Emphasize that we are in no hurry today. 08:00 09:30 1.50 RURD COIL Start equipment. RD OPS cab. Switch tractors to pull unit forward 10 in order to accommodate 12" more lubricator. RU OPS cab. 09:30 10:30 1.00 RURD COIL Start equipment. PU injector assembly. PU 16' of 4- 1/16" lubricator. PU 14' of 5- 1/16" lubricator. MU tool string- 1 -3/4" coil connector,DFCV, hydraulic disconnect(5 /8" ball), 3.65" centralizer, 2.12" weight bar, 3.65" centralizer,XO,XO, 10' x 3 -1/8" wt bar, XO, 3.06" stringer assembly. PUH in lubricator. 10:30 11:36 1.10 PUMP CMT Carry injector to wellhead. NU injector. Displace coil. w/ 30 bbls fresh water. Test iron and shell to 2500 psi. Test good. Open wellhead. 0 psi WHP www.peioton.com Page 3/5 Report Printed: 3/9/2012 irkil operations Summary Report by J Marathon Well Name: CANNERY LOOP UNIT 6 Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6007005N011W01 CANNERY LOOP UNIT ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 6.40 12.80 6.40 5/1/2000 9/24/2000 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Corn 11:36 14:36 3.00 RUNPUL COIL Run in hole w/ stinger BHA to 7795' ctm. Weight check @ 7700' ctm 16K. RIH(1) at 30 fpm pumping .6 bpm. Tag retainer @ 7801'. Set weight down - 4K. Set returns at surface. PUH no overpull. RIH(2) tag retainer @ 7801'. Set -5K on retainer. Bring pump on line @ .6 bpm. Returns at surface. PUH No overpull. RIH(3) tag retainer @ 7802.1. Set -5K down. Weight falls to 900 lbs. Set more weight down. See weight fall off again. Set more weight down. Bring pump on @ .6 bpm. No returns. Pumping .6 bpm into perfs © 150 psi. Increase rate to 1 BPM @ 470 psi. Pump 10 bbls with no returns. Continue down weight -5K. Must be latched into retainder. Call out cementers. 14:36 15:06 0.50 SAFETY MTG Cement crew arrives. Hold PJSM. Discuss JSEA. Discuss alarms, muster area, and emergency response actions. Discuss cement job execution 15:06 18:36 3.50 PUMP CMT Batch mix 12 -1/2 bbls cement: Slurry weight 15.8 ppg Slurry yield 1.15 cu ft /sk Water requirement 5.0 gals /sk Free water zero @ 45 degree angle Fluid loss 42 cc/30 min API Rheology: @ 118 degree F 600 300 200 100 6 3 166 100 72 41 5 4 Prime up cement. Pump 9 bbls. Clear pump and lines. Displace with 28 bbl ( coil capacity) fresh water. Placed approx 6 bbls of cement below the retainer (©7796') and dumped 3 bbls on top of retainer. 18:36 20:36 2.00 RUNPUL COIL Circulate coil clean and POOH. 20:36 21:36 1.00 RURD COIL LD tool string and lubricator. 21:36 22:06 0.50 SECURE WELL Install night cap on BOP's and secure well for the night. Report Date: 2/24/2012 Job Category: R &M MAINTENANCE 24 Hr Summary Rig down coil tubing. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Corn 10:30 11:00 0.50 SAFETY MTG Arrive location, sign in, receive safe work permit, hold PJSM - topics discussed - reviewed JSA, assigned jobs, slips, trips, falls, eye wash station, high pressure, emergency numbers, emergency vehicles, muster area, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, stop the job authority, and keeping the focus on the job. Emphasize that we are in no hurry today. 11:00 19:00 8.00 RURD COIL Start equipment. RD 2" iron. ND BOP's. Vac out fluid, flowback, and slop tanks. NU tree cap flange. RD equipment. PU drip liners. Clean up location. 19:00 19:15 0.25 SECURE WELL Secure wellhead and location. Turn in permit and sign out. lock gate on way out. Report Date: 3/1/2012 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Pollard slick line to tag top of cement. Tag TOC @ 7505' kb. Cement retainer was set at 7796' kb. Three bbls of cement was placed on top of retainer. Y RU pump truck to pressure test casing to 1600 psi for 30 min. Test good. Tag and test witnessed by Mr Matt Herrera with the AOGCC. , Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Corn 07:30 08:00 0.50 SAFETY MTG Arrive location, sign in, receive safe work permit, hold PJSM - topics discussed - reviewed JSEA, assigned jobs, slips, trips, falls, eye wash station, high pressure, emergency numbers, emergency vehicles, muster area, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, stop the job authority, and keeping the focus on the job. Emphasize that we are in no hurry today. 08:00 08:30 0.50 PREP LOC Shovel snow around wellhead in order to be able to work safely. www.peloton.com Page 4/5 Report Printed: 3/9/2012 in. // Operations Summary Report by J t'c�, t on Oil Well Name: CANNERY LOOP UNIT Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6007005N011W01 CANNERY LOOP UNIT ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB Casing Flange Distance (m) KB Ground Distance (m) Spud Date Rig Release Date 0.00 6.40 12.80 6.40 5/1/2000 9/24/2000 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com I 08:30 10:30 2.00 RURD EQIP Spot equipment. MU lubricator. MU tool string- RS, 1 -3/4" x 8' stem, RB, KJ, RB, OJ, SSSJ, 3.72" blind box. Zero tool string to the grating. Carry lub to wellhead. 10:30 10:30 RUNPUL SLIK RIH (1) tag ice plug at tubing hanger. POOH. Slushy ice on tools. 10:30 10:30 RUNPUL SLIK RIH (2) w/ 2.75" GR. Tag up at 1'. Work tools. Don't make any hole. POOH. . 10:30 10:30 TEST EQIP Pump 50/50 MEOH. See plug moving down hole. Pressure up on casing to 1500 psi. 10:30 10:30 RUNPUL SLIK RIH (3) w/ 2.75" GR. Line jumps scheve at 6823' wlm. Clamp line at packoff. Slack off and run line back up over scheve. POOH to rezero. 10:30 10:30 RUNPUL SLIK Rezerp at grating. RIH (4) w 2.75" GR. tag TOC @ 7505 kb. POOH. 10:30 10:30 RURD SLIK RD lubricator and tool string. Re- install tree cap. RU test pump. 10:30 10:30 TEST CSG Pressure test casing and cement to 1610 psi. Pretest Initial P 15 min 30 min Tubing NA NA NA 0 Casing 0 1610 1600 1590 Note: Took 32 gals to pressure up. Recovered 26 gals. Tag and pressure test witnessed by Mr Matt Herrera with the AOGCC. 10:30 10:30 RURD SLIK Move to CLU 9 for MIT Test. www.peloton.com Page 5/5 Report Printed: 3/9/2012 7 • ` • • t C L U - 6 Permit #: 200 -033 /fiV API #: 50- 133 - 20492 -00 -00 Pad CLU -1 Prop. Des: ADL- 60568 & Marathon Oil 113' FSL, 465' FEL, Sec. 7, ADL- 60569 Alaska Production LLC- T5N, R11 W, S.M. KB elevation: 42.5' (21' AGL) _ —_ Latitude: _.._...._.........__ Longitude: Spud: 9/9/2000 TD: 9/18/2000 Conductor Pipe Al — I 9 -5/8" P -110 53.5 ppf Rig Released: Top Bot MD Surf 91' - - - -- TVD Surf 91' Surface Casing 7" L -80 23 & 26 ppf Top Bottom MD 0' 2,966' TVD 0' 2,311' 8 -1/2" hole Cmt w/ 307 sks Production Casing 4 -1/2" L -80 12.6 ppf Hydril 521 Top Bottom MD 0' 8,320' TVD 0' 5,277' 6 -1/8" hole Cmt wl 547 sks Capillary Tubing 61.52 Degree Incl. 3 /8" OD 2205 Stainless Steal Top Bottom MD 0' 0' TVD 0' 0' (Installed 06/27/2008) Inspected 08/02/10 Removed 09/06/2011 4- 1/2 "'X' Nipple w/ 3.813" ID @ 6,049' KB Baker Cement Retainer @ 7,796' MD Top of Cement @ 7,505' MD 11 ink Perforations • N, N. MD Net Ft TVD Gun Date Plugged 4 Sterling B -2: 4 Sterling C -1: + 7 -846'- 7,860' -14' 4,951- 10123/00 2/22/12 11, r • . 7-883 - -- 7945' _ 62'- 4,986' 5,028' 6 spf 6/40/04 2/22/12 Sterling C -2: Y •- ' 7,962' 7,086' -2 - 2/22/12 , Sterling 01 & C2 Sands . 8,014' 8,024' 10' 5 2/22/12 a• , ..\ • . .. 2,22„ Z � 61° to 40° Incl. TD PBTD 8,320' MD 8,058' MD 5,277' TVD 5,104' TVD Well Name & Number: Cannery Loop Unit 6 Lease: Cannery Loop Unit County or Parish: Kenai Penisula Borough State: Alaska 1 Country: USA Perforations (MD): Plugged Perf (TVD): Plugged Angle @KOP and Depth: 1.33° @ 400' MD Angle @ Perfs: 40° — 61° KOP TVD. 400' Date Completed: October 23, 2000 RKB: 21' Revised By: Kevin Skiba Last Revision Date: March 9, 2012 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg C 3 DATE: 02/29/12 P.I. Supervisor SUBJECT: Plug Verification FROM: Petroleum Inspector CLU #6 Matt Herrera Marathon Oil & Gas Cannery Loop Unit PTD 2000330 Summary: Witnessed tag and passing test of CLU #6 plug isolating the Sterling C1 and C2 sands as required in Storage Injection Order 9, Rule 5; work done under Sundry #312 -041 Section: 7 Township: 5N Range: 11W Meridian: Seward Lease No.: ADL 0324602 @TD Drilling Rig: Inlet Glacier 1 - Rig Elevation: 21.5 ft Total Depth: 8058 ft MD (5104 ft TVD) Operator Rep.: Mike Sulley � SZ, ®�� � MA I 2 are. Casinq/Tubinq Data: Casing Removal: Conductor: 9 -5/8" - O.D. Shoe@ 91 ft MD _ Casing Cut@ Feet Surface: 7" - O.D. Shoe@ 2945 ft MD • Casing Cut@ Feet Intermediate: O.D. Shoe@ Casing Cut@ Feet Production: 4 -1/2" O.D. Shoe@ 8124 ft MD - Casing Cut@ Feet Liner: O.D. Shoe@ Casing Cut@ Feet Tubing: N/A O.D. Tail@ Casing Cut@ Feet Plugging Data: Type Plug Bottom of T.O.C. Mud Weight Pressure (bottom up) Founded on Cement (M.D.) T.O.C. Depth Verified? above plug Test Casing Retainer 7796 7505 Wireline Tag 1600 psi 15 min - 1600 30 min - 1590 Charted - Type PIuq Founded on: Verified? Open Hole Bottom Drillpipe tag Perforation Bridge plug Wireline tag Annulus Balanced C.T. Tag Casing Stub Retainer No Surface Distribution: Attachments: AJoNc -Well File (original) -Read File -DNR/DOG Rev.:5 /28/00 by L.R.G. 2012- 0229_Plug_CLU -06_mh 3/7/2012 • • A [E tata/(A If 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 Kevin J. Skiba Regulatory Compliance Representative Marathon Alaska Production, LLC a©© 033 P.O. Box 1949 Kenai, AK 99611 -1949 Re: Cannery Loop Field, Sterling Undefined Gas Pool, Cannery Loop Unit #6 Sundry Number: 312 -041 Dear Mr. Skiba: StANNEI) JAN = ZOIZ 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. Sincere , air Co •. ' sioner DATED this3/ day of January, 2012. Encl. • • Marathon Alaska Production LLC ���,� „� Alaska Asset Team Marathon Oil P.O. Box 1949 Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1350 January 24, 2012 RECEIVED Mr. Daniel Seamount JAN 2 $ 2012 Alaska Oil & Gas Conservation Commission 333 W 7 Ave Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Commission g Anchorage Reference: 10 -403 Application for Sundry Approvals Field: Cannery Loop Field Well: Cannery Loop Unit #6 Dear Mr. Seamount, Submitted for your approval is the10 -403 Application for Sundry Approvals for CLU -6 well. Marathon proposes to isolate the Sterling C1 and C2 intervals in the CLU -6 well to t' comply with Storage Injection Order No. 9, for the purpose of developing the CINGSA gas storage project, as discussed in the Injection Order in Finding #14. The plugging procedure complies with 20 AAC 25.112, (c), (1), (D), by the down - squeeze method using a cement retainer. Marathon has a potential recomplete in this well. Plans are to submit a subsequent sundry request to perform the recomplete. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, a. Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -403 Application for Sundry Approvals cc: AOGCC Current Well Schematic Houston Well File Proposed Well Schematic Kenai Well File Detailed Operations Program (2) KJS • v STATE OF ALASKA • ` " ALAS•IL AND GAS CONSERVATION COMMISSII RECEIVED APPLICATION FOR SUNDRY APPROVALS 1 1/ 20 AAC 25.280 !AN 2* 2012 1. Type of Request: Abandon ❑ ,t Plug for Redrill ❑ Perforate New Pool ❑ Repair well El Change approved program Ill Suspend [ Plug Perforations gi . Perforate ❑ Pull Tubing ❑ $pec,if :Time Extension ❑ Operational shutdown ❑ Re -enter Susp. Well 111 Stimulate ❑ Alter casing ❑ Alaska a Oil & Other: I:OnS. COmmiSSl Anrllprarie 2. Operator Name: 4. Current Well Class: 5 Permit tp Drill Number: Marathon Alaska Production LLC Development 0 Exploratory ❑ 200 -033 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 50- 133 - 20492 -00 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No iti Cannery Loop Unit #6 9. Property Designation (Lease Number): 10. Field / Pool(s): 11,4, LISQ ADL - 60568 & ADL - 60569 ' Cannery Loop Field / Sterling Pool �L 0 t 2 / 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8,320' . 5,277' . 8,058' 5,104' NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor 91' 9 -5/8" 91' 91' 10,900 psi 7,950 psi Surface 2,945' 7" 2,983' 2,320' 7,240 psi 5,410 psi Intermediate Production 8,103' 4 - 1/2" 8,124' 5,148' 8,440 psi 7,500 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7,846' - 8,062' 4,961' - 5,106' NA NA NA Packers and SSSV Type: SSSV: NA Packers and SSSV MD (ft) and TVD (ft): NA NA Packers: NA NA NA 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: / 3 Commencing Operations: February 7 , 2012 Oil 111 Gas r WDSPL ❑ Suspended LYJ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature 11. Phone (907) 283 -1371 Date January 24, 2012 �/l7tM. . COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 2 ) I 2 ' 0141 Plug Integrity [l� BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: N // —�— p / n qs66 e5,.% Oe f 7 - Subsequent Form Required: /6 — L,/ U ", APPROVED BY Approved by: ' OMMISSIONER THE COMMISSION Date: /.3/ / j - REIC S JAN 312012' oR1G 1NAL 7 z/.30. /L # :47( / 3 1,1 \' 77 ir? Form 10 -403 Revised 1/2010 Submit in Duplicate • • i1 )/, Marathon Oil CLU 6 Cannery Loop 1 Pad Sterling Abandonment Procedure WBS: BL.11.25566.EXP.001 APPROVALS: Mike Sulley 1 -23 -2012 Program Writer Mike Ellis 01/24/2012 Mike Ellis No deviation from this procedure to occur without prior approval from supervisor. Well Status: Honoring Marathon's agreement with CINGSA's Sterling C Sand gas storage project, we have agreed to abandon the Sterling C1 and C2 sands in this well. Marathon will go forward with the Sterling B Sand development in this well, as part of a follow up procedure. This procedure is to isolate /abandon the Sterling interval and perform an AOGCC witnessed pressure test of the plug. CINGSA notification and approval are required: Notifying CINGSA of wellwork at Cannery Loop, and gaining CINGSA's approval, is required per the CINGSA agreement prior to commencing wellwork. Coordinate CINGSA notification with Chick Underwood. Objective: Methodology is to load the hole with 6% KCL and establish injection rates 'A ter 2 bpm. RU E -line, set a Baker coil tubing cement retainer at 7796 ft MD (must be 50 ft ✓ above top perf). MIRU coil tubing and squeeze 4 -6 bbls of cement thru the retainer, then place balance (min. 2 bbls) of cement on top of the retainer. WOC, then pressure test the plug per AOGCC abandonment requirements. Note: Previous wellwork on this well will have provided a PBTD and gauge ring run sufficient to ensure that there are not restrictions that would prevent the cement retainer from being able to be run. (Pollard ran 3.70" gauge ring 9/20/2011 and tagged fill @ 8046'). Resources: MIRU 1 -3/4" Coil Unit w/ BOP's, Cement pump truck, and batch mixer, N2 Unit MI WO unit, 4- 1/16" BOP's and accumulator, MI crane. MIRU flow back tanks, choke, and 2" iron Paperwork: Sundry Approval, Procedure, WBD, Work Permit, Well Ops transfer sheet. CAPACITIES bbls /ft. Collapse Burst 4 -1/2" 12.6# L -80 0.01522 7,500 8,430 7" 23 # L -80 0.0758 3,830 6,340 MASITP 1 • Procedure: 1. MIRU GE Vetco to inspect and perform wellhead maintenance. Grease valves. . Verify pressure isolation between all annuli. 2. Hold Pre -Work meeting a week before work begins with all contractors involved with the CLU 6 plug back. 3. Hold PJSM prior to rigging up equipment. MIRU flow back and fluid tanks, gas buster, choke and 2" iron. 4. MIRU Baker pump unit. Load hole with 6% KCL water. Establish pump in rates at 1 /2, 1, 1-1/2, and 2 bpm. Note injection pressures. 5. MIRU Pollard E -line. RU lubricator. Pressure test lubricator to 250/2500 psi. Make a gauge ring run using a 3.70" gauge ring to PBTD (Minimum ID "X" nipple- 3.813" ID @ 6049') Attempt to locate X nipple at 6049 ft MD. Note well has max deviation of 61.4 degrees, bring roller stem. 6. PU GR/CCL, setting tool and cement retainer. Ensure setting tool has been rebuilt and o -rings replaced prior to running. RIH with Baker cement retainer. Get on depth using X nipple and perforations, and use RA tags denoted on schematic: at 6760, 7284, and 7737 ft MD. Confirm depths, correct to MD per Expro GR -CCL Correlation Log dated August 10, 2004 or Schlumberger HSD Perforation log dated October 23, 2000 (Short joint 7574'- 7612'). 7. Pull cement retainer up to set depth of 7796 ft MD (pulling tool up hole will pull E- line tight, given deviation). Confirm wile Ma a on wellwork supervisor that set depth is accurate. With confirmation, set cement retainer at 7796 ft MD (top pert is 7846 ft MD). Do not set retainer in a collar. (Closest collar @ 7818'). POOH. RD E- line. ;3 4- t - ;#..s c, 8. MIRU BJ coiled tubing unit. Verify 24 hour notification has been made to AOGCC for BOP test. Rig up fluid and N2 pumps. RU pumping iron (BJ) and Arctic flow back iron (MOC). 9. Nipple up BJ CT wellhead assembly (WHA). Current WHA is 4- 1/16" 5M / swab /cap. WHA to include 4- 1/16" - 5M X 4- 1/16" - 10M DSA, 4- 1/16" - 10M X 5' ✓ Flanged Riser, 4- 1/16" — 10M flow cross and 4- 1/16" - 10M Dual -Combi BOP (dressed for 1 -3/4" CT). Function test BOP. Stab 1 -3/4" CT into injector. Have BJ prep coil end off location prior to RU. Nipple up injector to WHA. 10. Perform complete BOP test with 50:50 MEOH and the test bar. Complete AOGCC BOP Test Report (Correct form dated 01/25/2010). Pressure test pump iron (200 2 • • low /4500 high psi). Pressure test WHA and flow back iron to choke manifold (200/2500 psi). Pressure test BOP rams (200/4500 psi). Test inside reel valve to (200/4500 psi). Note BOP test witness or waiver in WellView, including details. 11. Pig CT. Run end of CT with pig catcher onto Well head. Open valves on flow cross to flow back tank. Pump 5 bbls water, cleaning pig, and coil displacement +10% behind pig. Record displacement volume of coil. 12. MU CT BHA. Nipple injector off WH. PU 10' of 4- 1/16" CQ lubricator as needed to cover BHA. Install dimple on connector. Pull test to 18K. Pressure test coil to 3200 psi. Install 1 -3/4" x 3' straight bar and Baker "sting in" nozzle for cement retainer. 13. Nipple up injector to WHA. Pressure test WHA using CT kill line (200/1500 psi). Bleed WHP to flow back tank. Caution: Coil subject to collapse above 1500 psi. 14. RIH with coil tubing to cement retainer pumping 6% KCL water at min. rate to load hole. Fill wellbore, taking returns to the tank. Continue to circulate to ensure wellbore is cleaned up and fluid is uniform. With well full, pressure test cement retainer to 1200_01 psi (note differential applied to cement retainer as Sterling interval is depleted). o 15. Prepare 12 bbls cement (10 bbls pumpable) of Class G cement mixed per BJ cementing proposal. Ensure cement properties match lab design. 16. Pump cement down CT to 1000 ft above EOCT. Do not pump cement to end of coil. Note: Minimize number of times stinging into retainer to prevent seal degradation 17. Sting into cement retainer. Set down on retainer 10,000 to 15,000 Ibs to ensure CT will not be pumped out during squeeze work. Note Sterling interval is depleted. 18. Pump 4 -6 bbls of cement to squeeze Sterling perfs (4.0 bbls is the volume from top of fill (8046') to retainer). Continue to squeeze perforations while monitoring o� pressure and volume of cement under the retainer. Achieve 2000 psi squeeze pressure. Record squeeze pressure and volume of cement pumped through retainer and note in daily wellwork report. Contact Mike Ellis if squeezed cement volume or squeeze pressure deviates from design, may need to quickly notify SL z AOGCC. 44#L ,or $dt fp 19. With successful Sterling squeeze, PU CT and un -sting from cement retainer. Place remaining cement on top of retainer (design calls for minimum 2 bbls, but subject to result of squeeze volumes, could be as much as 6 or more bbls), pumping cement while being mindful of keeping CT nozzle submerged and below circulating top of cement, by picking up CT at an appropriate rate. Once all cement is pumped out the end of CT, PU CT 50 ft above placed TOC and circulate CT clean, taking returns to the tank (handling cement returns to avoid setting up in tank). Note 3 • • cement volume placed on top of cement retainer and record in daily wellwork report. Contact Mike Ellis if cement volume placed differs than design. Circulate wellbore clean. POOH w/ CT. 20. WOC. 21. MIRU Pollard on top of BOP's. RIH to tag TOC. Call AOGCC to witness. 22. Pressure test the cement/retainer to 1500 psi. AOGCC to witness. Can test higher, this is the requirement for the abandonment. 23. PU BHA for coil to jet out 4 -1/2" casing. Subsequent procedure to perform uphole recomplete. History: CLU 06: 08/02/10: Capstring pull test, set 8020' (tag 8025'). FCV =2700 psi. 10/23/09: PBU: 369 psi final SI. 06/28/08: Capstring to 8020'. 06/02/08: PT to 8050'. 06/02/08: GR 2.30" to 8058'. 05/11/05: PT - BHP = 1016 psi. 02/22/05: PT. 02/22/05: GR 2.30" to 8112'. 06/08/04: Perforate 8042 -62, 7962 -86, 8014 -42, 7846 -60, 7883 -7945. CCL. 06/05/04: GR 3.49 ", 5 gal diesel in tree, more weight stem tag 8136'. 06/05/04: GR 3.49" to 3300', work, work but does not fall. 06/18/03: PLT. 09/28/00: Drill Well. Note: No Togs across the C1 &C2 Considerations Instructions and Planning: It is very important to use a low fluid loss cement to lay in this plug. Fluid loss should be 40 -45 cc /30 min. using API test specification (1000 psi, 325 mesh screen). It is also important to simulate surface batch mix time, coil transit time to temperature, and required pump time for job placement plus required safety factor in determining T:T. 4 • 4 w ' r / Cannery Loop Unit #6 Pad CLU -1 Proposed Schematic I ...1 113' FSL, 465' FEL, Sec. 7, Marathon Oil T5N, R11W, S.M. 1 1 Permit #: 200 -033 API #: 50- 133 - 20492 -00 -00 Prop. Des: ADL- 60568 & Conductor Pipe ADL- 60569 9 -5/8" P -110 53.5 ppf KB elevation: 42.5' (21' AGL) MD Surrff B 9 1 ' Latitude: TVD Surf 91' Longitude: Spud: 9/9/2000 TD: 9/18/2000 Rig Released: Surface Casing 7" L -80 23 & 26 ppf Top Bottom MD 0' 2,966' TVD 0' 2,311' 8 -1/2" hole Cmt wl 280 sks LITECRETE, + 27 sxs LITECRETE top job, cement to surface Production Casing 4 -1/2" L -80 12.6 ppf Hydril 521 Inclination approx 60 deg, 2300 -5800 ft MD Top Bottom MD 0' 8,320' TVD 0' 5,277' RA tags: 6760, 7284, 7737 ft MD 6 -1 /8" hole, cemented with: lead: 161 sxs 12.9 ppg class G, 2.08 yld, 59.6 bbl tail: 386 sxs 15.8 ppg class G, 1.18 yld, 82.8 bbls Note: caliper determine 28% overage, calc'd TOC at 1675 ft MD, but TOC could be below surface shoe - uncertainty is depicted with lighter cement shading. 4- 1 /2 "'X' Nipple, 3.813" ID, 6,049' KB Inclination 61° dropping to 40° , 5800 ft MD to TD 1 Potential RCP zone: Sterling B2 Interval approx 6910 -6970 ft MD. Note that CINGSA notification req'd. Cement retainer set at 7796 ft MD, Sterling C1 and C2 intervals squeezed with approx. 3.5+ bbls Class G cement. CT unstung and min. 2 bbls cmt , 131 ft, placed on top of cement retainer, leaving TOC at Sterling C1 & C2 Sands approx 7665 ft MD (note: TOC will depend on sqz'd Perforations ►�� volume - minimum 100 ft will be placed on cement MD Net Ft TVD Gun Date retainer. Sterling C -1: 7,846' - 7,860' 14' 4,961' - 4,970' 6 spf 10/23/00 7,883' - 7,945' 62' 4,986' - 5,028' 6 spf 6/10104 Sterling C -2: r PBTD: 8,058' MD, 5,104' TVD 7,962' - 7,986' 24' 5,039' - 5,055' 6 spf 6/9/04 TD: 8,320' MD, 5,277' TVD 8,014' - 8,024' 10' 5,074' - 5,081' 6 spf 10/23/00 8,024' - 8,062' 38' 5,081' - 5,106' 6 spf 6/8/04 Well Name & Number: Cannery Loop Unit 6 Lease: Cannery Loop Unit County or Parish: Kenai Peninsula Borough State: Alaska 1 Country:I USA Perforations (MD): 7,846' - 8,062' Perf (TVD): 4,961' - 5,106' Angle @KOP and Depth: 1.33 eq 400' MD Angle @ Perfs: 40° -> 61° KOP TVD. 400' Date Completed: 10/23/2000 RKB: 21' Revised By: Mike Ellis Last Revision Date: September 2, 2011 • Cannery Loop Unit #6 Pad CLU -1 Current Schematic 113' FSL, 465' FEL, Sec. 7, Marathon Oil T5N, R11W, S.M. 1 1 Permit #: 200 -033 API #: 50- 133 - 20492 -00 -00 Prop. Des: ADL- 60568 & Conductor Pipe ADL- 60569 9 -5/8" P -110 53.5 ppf KB elevation: 42.5 (21' AGL) MD Sur B 91' Latitude: TVD Surf 91' Longitude: Spud: 9/9/2000 TD: 9/18/2000 Rig Released: Surface Casing 7" L -80 23 & 26 ppf Top Bottom MD 0' 2,966' TVD 0' 2,311' 8 -1/2" hole Cmt w/ 280 sks LITECRETE, + 27 sxs LITECRETE top job, cement to surface Production Casing 4 -1/2" L -80 12.6 ppf Hydril 521 Inclination approx 60 deg, 2300 -5800 ft MD Top Bottom MD 0' 8,320' TVD 0' 5,277' RA tags: 6760, 7284, 7737 ft MD 6 -1/8" hole, cemented with: lead: 161 sxs 12.9 ppg class G, 2.08 yld, 59.6 bbl tail: 386 sxs 15.8 ppg class G, 1.18 yld, 82.8 bbls Note: caliper determine 28% overage, calc'd TOC at 1675 ft MD, but TOC could be below surface shoe - uncertainty is depicted with lighter cement shading. 4- 1/2 " 'X' Nipple, 3.813" ID, 6,049' KB Inclination 61° dropping to 40° , 5800 ft MD to TD I_ Sterling C1 & C2 Sands Perforations MD Net Ft TVD Gun Date Sterling C -1: 7,846' - 7,860' 14' 4,961' - 4,970' 6 spf 10/23/00 7,883' - 7,945' 62' 4,986' - 5,028' 6 spf 6/10/04 Sterling C -2: PBTD: 8,058' MD, 5,104' TVD 7,962' - 7,986' 24' 5,039' - 5,055' 6 spf 6/9/04 TD: 8,320' MD, 5,277' TVD 8,014' - 8,024' 10' 5,074' - 5,081' 6 spf 10/23/00 8,024' - 8,062' 38' 5,081' - 5,106' 6 spf 6/8/04 Well Name & Number: Cannery Loop Unit 6 Lease: Cannery Loop Unit County or Parish: Kenai Peninsula Borough State: Alaska 1 Country:/ USA Perforations (MD): 7,846' - 8,062' Pert (TVD): 4,961' - 5,106' Angle @KOP and Depth: 1.33° @ 400' MD Angle @ Perfs: 40° -> 61° KOP TVD: 400' Date Completed: 10/23/2000 RKB: 21' Revised By: Mike Ellis Last Revision Date: September 2, 2011 Marathon Alaska Production LLC Alaska Asset Team Marathon Oil P.O. Box 1949 Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1350 January 19, 2012 Mr. Daniel Seamount JAN 2 3 2017 Alaska Oil & Gas Conservation Commission 333 W 7 Ave , ske Ud & tis s (AM. ;.,ornmtssion Anchorage, Alaska 99501 A 0r3 F' p o -O33 Reference: 10 -403 Application for Sundry Approvals Field: Cannery Loop Field Well: Cannery Loop Unit #06 Dear Mr. Seamount, tANNE D FEB L 4L' 1112' Submitted for your approval is the10 -403 Application for Sundry Approvals for CLU -06 well. Marathon proposes to perform a Mechanical Integrity Test of the wellbore to comply with the Storage Injection Order No. 9, Rule 5: Demonstration of Mechanical Integrity. Please find attached the Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Mechanical Test Plan which provides a summary and background for the test, the details that relate to the subject well, and a current wellbore schematic, depicting the Sterling C1 interval depths. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, kJ- Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -403 Application for Sundry Approvals cc: AOGCC CINGSA SIO 9 Mechanical Integrity Test Plan Houston Well File Current Well Schematic Kenai Well File (2) KJS • • STATE OF ALASKA IV F D • ALASKWL AND GAS CONSERVATION COMMISSI' APPLICATION FOR SUNDRY APPROVALS AN 3 2012 20 AAC 25.280 0135. �;011YY11ssIO0 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair well ❑ ' (>` ti8il g e a rog ram ❑ Suspend ❑ Plug Perforations El Perforate ❑ Pull Tubing ❑ Spetify`1fr�i� x tension ❑ Operational shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter casing ❑ Other: Perform MIT Test El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Alaska Production LLC Development 0 • Exploratory ❑ 200 -033 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 50- 133 -204' -00 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes III No Cannery Loop U It #6 9. Property Designation (Lease Number): r37 L 32 - V4, 10. Field /Pool(s): ;,( k C li 1.46J 1_<1 ADL ADI6056 7 , z3 /2- Cannery Loop Field / Sterlin • • ool f / . 2 - 3 7 Z, 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measure. . Junk (measured): 8,320' • 5,277' • 8,058' 5,104' NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor 91' 9 -5/8" 91' 91' 10,900 psi 7,950 psi Surface 2,945' 7" 2,983' 2,3 - 7,240 psi 5,410 psi Intermediate Production 8,103' 4 - 1/2" 8,124' 5,148' 8,440 psi 7,500 psi Liner 1 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: t ° ubi e r e:, Tubing MD (ft): 7,846' - 8,062' 4,961' - 5,106' , NA NA Packers and SSSV Type: SSSV: NA • - e y nd V D ft ) and TVD (ft): NA NA Packers: NA NA NA 12. Attachments: Description Summary of Proposal ❑ t ell Class a proposed work: Detailed Operations Program 0 BOP Sketch ❑ \ xplo . , ❑ Development 0 Service ❑ 14. Estimated Date for 15 • - Statu =fter proposed work: Commencing Operations: February 1 , 2012 Oil IN Gas IO WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WIN ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the . -st of my knowledge. Contact Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature ( 907) 283 -1371 Date January 19, 2012 V COMMISSION USE ONLY Conditions of approval: Notify Commission so at a representative may witness Sundry Number: '3l 2' 02:1 Plug Integrity ❑ BOP Test • Mechanical Integrity Test ❑ Location Clearance ❑ Other: . Subsequent Form Requi d: /0 APPROVED BY Approved by COMMISSIONER THE COMMISSION Date: RSDMS FEB 14201 Q RIG INAL Form 10 -403 Revised 1/2010 11 V L. Submit in Duplicate • • • Cook Inlet Natural Gas Storage Alaska, LLC Proposed Mechanical Integrity Test Plan Cannery Loop Sterling C Gas Storage Pool Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) requested by application dated July 27, 2010, a storage injection order from the Alaska Oil and Gas Conservation Commission (AOGCC) authorizing injection for the underground storage of natural gas in the Sterling C Gas Storage Pool of the Cannery Loop Unit. The AOGCC held a public hearing on October 19 -20, 2010 during which CINGSA presented oral and written testimony concerning the project. By Order, the AOGCC issued Storage Injection Order No. 9 (SIO 9) dated November 19, 2010, granting CINGSA the authority to commence the injection of gas for underground storage subject to certain Conclusions and Rules, all as more fully outlined in SIO 9. Two of the key requirements imposed on CINGSA as a condition of SIO 9 are that CINGSA 1) demonstrate the mechanical integrity of all storage injection wells and existing pool wells before injection commences (Rule 5 Demonstration of Mechanical Integrity), and 2) maintain surveillance of operating parameters for storage and offset wells to provide continued assurance that gas remains confined to the Sterling C Gas Storage Pool (Conclusion 8). Following, is the methodology CINGSA proposes to employ to demonstrate the mechanical integrity of all existing pool wells and maintain continued surveillance of the Pool to assure that gas remains confined to the Sterling C Pool. All new gas storage wells will be tested in accordance with 20 AAC 25.412 (c)(d). CINGSA proposes to satisfy the requirements of Conclusion 8 and Rule 5 of SIO 9 through routine monitoring of the annulus pressure of existing wells, and via pressure testing the annulus of certain wells to demonstrate their mechanical integrity, plus the tubing string of certain other wells. Table 1 provides a summary of the scope of CINGSA's proposed measures to satisfy the requirements of Conclusion 8 and Rule 5. The rationale for monitoring pressure of certain annuli and performing a mechanical integrity test is more fully summarized for each individual well below. Table 2 provides a depth reference to the Sterling C1 interval, from Sterling C1 Top to U. Beluga Top, by well. Routine monitoring and recording of annulus pressure will help identify whether any gas may be leaking from the Sterling C Pool or other formations. CINGSA proposes a monthly monitoring and reporting frequency to satisfy the requirements of Conclusion 8. CINGSA proposes to conduct a mechanical integrity pressure tests on the annulus of the wells listed in Table 1 to satisfy the requirements of Rule 5. CINGSA proposes a maximum test pressure of 500 psi for 30 minutes since most of the wells are not completed with tubing set on a packer, and thus, are not in the same configuration contemplated in 20 AAC 252. d • • • 1 Table 1 Proposed Routine Monitoring and Mechanical Integrity Test Plan Cook Inlet Natural Gas Storage Alaska, LLC Well Name Current Status Annulus for MIT Routine Monitor Annulus CLU 1RD Producing 4 1/2 x 7 4 1/2 x 7 and 7 x 9 5/8 CLU 3 Inactive 3 1/2 x 9 5/8 3 1/2 x 9 5/8 CLU 4 Inactive 3 1/2 x 13 5/8 3 1/2 Tbg, 3 1/2 x 13 5/8, and 13 5/8 x 20 CLU 5 Inactive 3 1/2 Tbg x 9 5/8 3 1/2 Tbg, 3 1/2 x 9 5/8, and 9 5/8 x 1/8 CLU 6 P& A Sterlin: C 4 1 2 Tb: 41 2 tb: and 41 2 x 7 CLU 7 Producing 3 1/2 x 9 5/8 3 1/2 x 9 5/8 and 9 5/8 x 13 3/8 CLU 8 Producing 3 1/2 x 9 5/8 3 1/2 x 9 5/8 and 9 5/8 x 13 3/8 CLU 9 Producing 3 1/2 x 9 5/8 3 1/2 x 9 5/8 and 9 5/8 x 13 3/8 CLU 10 Planned P & A 3 1/2 Tbg and 3 1/2 x 9 5/8 3 1/2 x 9 5/8 and 9 5/8 x 13 3/8 CLU 11 Producing 3 1/2 x 9 5/8 3 1/2 x 9 5/8 and 9 5/8 x 13 3/8 CLU 12 P & A'd Sterling C None 9 5/8 Csg Table 2 Cannery Loop Wells, Sterling C interval, Sterling Cl Top to U. Beluga Top Well Name Sterling C depth interval. MD Sterling C depth interval, TVDSS CLU 1RD 5815 -6155 -4927 to -5155 CLU 3 5313 -5574 -4963 to -5205 CLU 4 5171 -5409 -4971 to -5198 CLU 5 6063 -6300 -4856 to -5081 Cl ll 6 7782 -8114 -4876 to -5099 CLU 7 7700 -7965 -4858 to -5095 CLU 8 6690 -6945 -4871 to -5101 CLU 9 5942 -6195 -4860 to -5102 CLU 10 5372 -5614 -4883 to -5125 CLU 11 6281 -6537 -4876 to -5113 CLU 12 7264 -7522 -4920 to -5158 • • CLU 6 CLU 6 is currently completed to the Sterling C1 and C2 interval via a 4 -1/2" monobore tubing string set and cemented at a depth of 8320 ft MD. The Sterling C interval is to be isolated /squeezed prior to commencement of gas storage operations. A string of 7" casing was set and cemented at a depth of 2966 ft MD. The Sterling interval extends from 7782 -8114 ft MD. A sundry will be submitted to abandon /isolate the Sterling C subsequent to this submittal. The work will have two components: 1) the isolation of the Sterling and the pressure testing of the abandonment; and 2) a recomplete to the Sterling B2 sand. Proposed Annuli to configure for routine pressure monitoring: • Need to monitor pressure of the isolated /squeezed 4 -1/2" tubing string • 4- 1/2 "x7" tubing head Proposed Mechanical Integrity Test Procedure: • Perform a 500 psi pressure test of the 4 1/2" tubing after squeezing /isolating the Sterling C interval. CINGSA proposes a 30 minute test duration with no more than a 10 percent change in pressure during that time interval being required for a valid test. • The proposed pressure test will apply an approximate differential of 2106 psi at 7700 ft MD/4863 ft TVD, per the following assumptions: an approximate 500 psi formation pressure at TVD; a fresh water hydrostatic gradient in the tubing, and the 500 psi of applied surface pressure. • A test of the 4 %2 x 7" annulus is not recommended since it would possibly serve as a leak off test of the surface casing shoe at 2966 ft MD, which was previously performed successfully during drilling (2284 psi @ 2311 ft MD). • A test of the 7" x 9 5/8" annulus is not possible because a landing base is installed on 9 -5/8 ". • • • Cannery Loop Unit #6 Current schematic f Pad CLU -1 113' FSL, 465' FEL, Sec. 7, Marathon Oil 1 Permit #: 200 -033 API #: 50- 133 - 20492 -00 -00 Prop. Des: ADL- 60568 & Conductor Pipe ADL- 60569 9 -5/8" P -110 53.5 ppf KB elevation: 42.5' (21' AGL) MD surrff Bottom 91' Latitude: TVD Surf 91' Longitude: Spud: 9/9/2000 TD: 9/18/2000 Rig Released: Surface Casing 7" L -80 23 & 26 ppf Top Bottom MD 0' 2,966' TVD 0' 2,311' 8 -1/2" hole Cmt w/ 280 sks LITECRETE, + 27 sxs LITECRETE top job, cement to surface Production Casing 4 -1/2" L -80 12.6 ppf Hydril 521 Inclination approx 60 deg, 2300 -5800 ft MD MD Top 8 320' TVD 0' 5,277' RA tags: 6760, 7284, 7737 ft MD 6 -1/8" hole, cemented with: lead: 161 sxs 12.9 ppg class G, 2.08 yld, 59.6 bbl tail: 386 sxs 15.8 ppg class G, 1.18 yld, 82.8 bbls Note: caliper determine 28% overage, calc'd TOC at 1675 ft MD, but TOC could be below surface shoe - uncertainty is depicted with lighter cement shading. 4- 1/2 " 'X' Nipple, 3.813" ID, 6,049' KB Inclination 61° dropping to 40° , 5800 ft MD to TD Sterling C1 & C2 Sands Sterling C1 Perforations Interval: MD Net Ft TVD Gun Date 77$2 -8114 ft MD Sterling C -1: 7,846' - 7,860' 14' 4,961' - 4,970' 6 spf 10/23/00 7,883' - 7,945' 62' 4,986' - 5,028' 6 spf 6/10/04 PBTD: 8,058' MD, 5,104' TVD Sterling 7,962' - 7,986' 24' 5,039' - 5,055' 6 spf 6/9/04 TD: 8,320' MD, 5,277' TVD 8,014' - 8,024' 10' 5,074' - 5,081' 6 spf 10/23/00 8,024' - 8,062' 38' 5,081' - 5,106' 6 spf 6/8/04 Well Name & Number: Cannery Loop Unit 6 Lease: Cannery Loop Unit County or Parish: Kenai Peninsula Borough State: Alaska country:/ USA Perforations (MD): 7,846' - 8,062' Perf (TVD): 4,961' - 5,106' Angle @KOP and Depth: 1.33° @ 400' M D Angle @ Perfs: 40° -+ 61° KOP TVD: 400' Date Completed: 10/23/2000 RKB: 21' Revised By: Mike Ellis Last Revision Date: September 2, 2011 • • • Page 1 of 3 Schwartz, Guy L DOA v (DOA) From: Schwartz, Guy L (DOA) pro e_oa _0 3 3 Sent: Friday, February 10, 2012 4:11 PM ( i) Z Os OG To: 'Skiba, Kevin J. (MRO)' �i Z 0G Cc: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Subject: RE: CLU MITs for CINGSA Kevin, I reviewed all the sundry applications for the MIT 's on CLU wells. Three wells: CLU 6, CLU 10 and CLU 12 MIT will not need to be retested following the P & A work that is ongoing (these sundries will be returned as not needed) . I believe CLU 12 is already done and has been tested to 1500 psi. . The other wells are approved as written with the 500 psi MIT as proposed. This is adequate pressure to ensure we have a monitor -able annulus. The Commission will want to witness each and every one of the MIT's on the list. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Maunder, Thomas E (DOA) Sent: Friday, January 27, 2012 7:18 AM To: Skiba, Kevin J. (MRO) Cc: Schwartz, Guy L (DOA); Regg, James B (DOA) Subject: RE: CLU MITs for CINGSA Kevin, Were the work plans submitted designed by Marathon or was it a collaborative effort between yourselves and CINGSA? Why is the proposed applied pressure for testing only 500 psi? Even assuming that the inside BHP at the liner tops or packers is 500 psi, the tubulars all have published burst pressures well in excess of the hydrostatic plus greater applied pressure. Thanks in advance. Please "reply all" with the response. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Thursday, January 26, 2012 2:37 PM To: 'Skiba, Kevin J. (MRO)' Subject: RE: CLU MITs for CINGSA Thanks Kevin. That answers the question I had. Tom From: Skiba, Kevin J. (MRO) [mailto:kskiba ©marathonoil.com] Sent: Thursday, January 26, 2012 2:01 PM To: Maunder, Thomas E (DOA) Cc: Ellis, Michael (MRO); Skiba, Kevin J. (MRO) 2/10/2012 . Page2of3 Subject: RE: CLU MITs for CINGSA Tom, It was discussed during a CINGSA / Marathon meeting that Marathon would provide Cannery Loop casing pressures to CINGSA on a monthly basis. Any anomalies would be provided immediately. Both parties have plans to further discuss the data collection and sharing issue. 1 hope that helps. Sorry it took so long to get back with you. Thanks again, Kevin Skiba Regulatory Compliance Representative Marathon Alaska Production LLC kskiba@marathonoil.com Office (907) 283 -1 371 Cell (907) 394 -3674 Fax (907) 283 -1350 1 Safe, Clean, & Responsible From Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, January 24, 2012 2:05 PM To: Skiba, Kevin J. (MRO) Subject: RE: CLU MITs for CINGSA Thanks. Regarding the pressure monitoring when CINGSA is operating, will the IA and OA values be shared with them or will they be obtaining pressure readings themselves. Working with two parties here is a little confusing. Tom From: Skiba, Kevin J. (MRO) [mailto:kskiba @marathonoil.com] Sent: Tuesday, January 24, 2012 12:39 PM To: Maunder, Thomas E (DOA) Subject: RE: CLU MITs for CINGSA Tom, The tubing pressures are collected daily, from the SCADA system, and entered on to round sheets and into our TOW database. The O.A. and I.A. pressures are gathered weekly and entered on to region wide round sheets and into TOW. Let me know if you have any other questions. Thanks again, Kevin Skiba Regulatory Compliance Representative Marathon Alaska Production LLC 2/10/2012 • Page 3 of 3 1 111 • kskiba@marathonoil.com marathonoil.com Office (907) 283 -1371 Cell (907) 394 -3674 Fax (907) 283 -1350 i Safe, Clean, & Responsible From: Maunder, Thomas E (DOA) [mailto:tom.maunder ©alaska.gov] Sent: Tuesday, January 24, 2012 9:48 AM To: Skiba, Kevin J. (MRO) Subject: CLU MITs for CINGSA Kevin, I am looking at the 403s for the proposed MITs. What sort of pressure monitoring does Marathon presently do on the wells? I presume there is a daily check by the operator of the tubing pressures and maybe the tubing x casing annulus pressure. Is that correct? Thanks in advance, Tom Maunder, PE AOGCC 2/10/2012 • Marathon Alaska Production LLC WA" Alaska Asset Team Marathon Oil P.O. Box 1949 Kenai,AK 99611 Telephone(907)283-1371 Fax(907)283-1350 SCANNED MAR 0 621)t8 November 4, 2011 Z00 O33 Mr. Daniel Seamount Alaska Oil & Gas Conservation Commission RECEIVED 333 W 7th Ave Anchorage, Alaska 99501 NOV 0 7 2011 Alaska Oil&Gas Cans.Commission Allai01 113 Reference: 10-404 Report of Sundry Well Operations Field: Cannery Loop Field Well: Cannery Loop Unit#6 Dear Mr. Seamount: Attached for your records is the10-404 Report of Sundry Well Operations for CLU-6 well. This report covers the work performed to remove the capillary string. The capillary string was removed in preparation for the isolation of the Sterling Cl and C2 sands. These intervals have been targeted for the CINGSA gas storage reservoir. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, K21J1/� Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Operations Summary (2) KJS STATE OF ALASKA ..4 ALASKA OIL AND GAS CONSERVATION COMMISSION 1/-#.'// REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon H Repair Well Li Plug Perforations U Stimulate H Other U Removed Capillary Performed: Alter Casing 0 Pull Tubing❑ Perforate New Pool El Waiver❑ Time Extension❑ String Change Approved Program ❑ Operat.Shutdown❑ Perforate ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Marathon Alaska Production LLC Name: Development Exploratory El 3.Address: PO Box 1949 Stratigraphic❑ Service❑ 6.API Number: Kenai Alaska, 99611-1949 " 50-133-20492-00-00 7.Pro Designation(Lease Number): nip.Well Name and Number: .K1,3 Db6956$ & ADL-60569.(V4,,3.2 Lt(p0 Cannery Loop Unit#6 9.Field/Pool(s): Cannery Loop Field/Sterling Pool 10.Present Well Condition Summary: Total Depth measured 8,320' feet Plugs measured NA feet true vertical 5,277' feet Junk measured NA feet Effective Depth measured 8,058' feet Packer measured NA feet true vertical 5,104' feet true vertical NA feet Casing Length Size MD TVD Burst Collapse Structural Conductor 91' 9-5/8" 91' 91' 10,900 psi 7,950 psi Surface 2,945' 7" 2,983' 2,320' 7,240 psi 5,410 psi Intermediate Production 8,103' 4-1/2" 8,124' 5,148' 8,440 psi 7,500 psi Liner RECEIVED' Perforation depth: Measured depth: 7,846'-8,062' feet 0 7 2O1 True Vertical depth: 4,961'-5,106' feet NOVv C ,Alaska Oil&Gas Cons.Commission Tubing(size,grade,MD&ND): Capillary String NA NA NA r' ncoarar NA TVD SSSV: NA NA MD NA TVD Packers and SSSV(type,MD&TVD): Packers: NA NA MD NA TVD 11.Stimulation or cement squeeze summary: Intervals treated(measured): The capillary string was remove in preparation for plug-back operations as required by the Enstar Cingsa gas storage agreement. Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1,400 7 9 120 Subsequent to operation: 0 0 0 9 528 13.Attachments: 14.Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15.Well Status after work: Oil ❑ Gas U' WDSPL❑ GSTOR❑ WINJ❑ WAG ❑ GINJ ❑ SUSP ❑ 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: NA Contact Kevin Skiba (907)283-1371 Printed Name Kevin J.Skiba Title Regulatory Compliance Representative Signature 'K +,AL,�4 - . v killit's Phone (907)283-1371 Date November 4,2011 DMS NOV 092011q \m s Form 10-404 Revised 10/2010 Submit Original Only • 1%,\W Operations Summary Report by Job MarathonOil Well Name: CANNERY LOOP UNIT 06 Qtr/Qtr,Block,Sec,Town,Range Field Name License d State/Province Country 6007005N011W01 CANNERY LOOP UNIT ALASKA USA Casing Flange Elevation(m) Ground Elevation(m) KB-Casing Flange Distance(m) KB-Ground Distance(m) Spud Date Rig Release Date 0.00 6.40 12.80 6.40 5/1/2000 9/24/2000 Daily Operations Report Date: 9/7/2011 Job Category: R&M MAINTENANCE 24 Hr Summary Pull cap string from well,to prepare well to run PT survey for CINGSA and abandon Sterling Cl &C2 sands. Well was NOT flowed or opened to production during this operation. Well remained shut in per CINGSA agreement. Ops Trouble Start Time End Time Dur(hr) Ops Code Activity Code Status Code Com 07:30 08:00 0.50 SAFETY MTG Hold PJSM. Discuss emergency response,alarms-red flashing strobe for fire alarm,blue flashing strobe for gas alarm,muster area,wind direction,and specific job hazards. Obtain SW Permit. 08:00 10:24 2.40 RURD COIL Spot DynaCoil unit. Lay liners and drip pans. RU DynaCoil Unit. Disconnect foamer line. PU spool onto unit. Thread coil thru side of injector assembly. Carry injector to WH while"walking" injector down string.Release Ratigun. Release mechanical slips. Reduce packoff pressure. 10:24 11:45 1.35 RUNPUL COIL Pull to 4400 lbs. Cap string won't pull free. Work cap string. Stretch indicates capstring stuck downhole. Pull load and hold. Still won't come free. Begin injecting MEOH down cap string while holding 4000 lbs pull on string. String weight 1560 lbs. Load drops off. Pull 10'from well. Resume pumping while holding a load on string. Weight falls to 1500 lbs. POOH. Foamer displaced from cap string with 26 gals MEOH. 11:45 14:00 2.25 RUNPUL COIL POOH from 8020'. Inspected the last 200'of string(area thru the perfs). 14:00 15:48 1.80 RURD COIL OOH. Close swab valve.Close Upper master valve. Remove cap string pack off assembly and adapter bushing. Install tree cap and gauge valve. 15:48 16:03 0.25 SECURE WELL Secure well head. Wing valve remains locked out. Install LOTO on swab valve. Turn in permit and leave loc. www.peloton.com Page 1/1 Report Printed: 11/4/2011 • CLU-6 Permit#: 200-033 API#: 50-133-20492-00-00 �•``•=rI Pad CLU-1 Prop. Des: ADL-60568 & Marathon Oil 113' FSL, 465' FEL, Sec. 7, ADL-60569 Alaska Production LLC.. T5N, R11 W, S.M. KB elevation: 42.5' (21'AGL) Latitude: Longitude: Spud: 9/9/2000 TD: 9/18/2000 Conductor Pipe 9-5/8" P-110 53.5 ppf Rig Released: Top Bottom MD Surf 91' TVD Surf 91' Surface Casing 7" L-80 23&26 ppf Top Bottom MD 0' 2,966' TVD 0' 2,311' 8-1/2"hole Cmt w/307 sks Production Casing 4-1/2" L-80 12.6 ppf Hydril 521 Top Bottom MD 0' 8,320' TVD 0' 5,277' 6-1/8"hole Cmt w/547 sks Capillary 2 lTubing 61.52 Degree Incl. 3/8"OD 2205 Stainless Steal Top Bottom MD 0' 0' ND 0' 0' (Installed 06/27/2008) Inspected 08/02/10 Removed 09/06/2011 4-1/2"'X'Nipple w/3.813"ID @ 6,049'KB Perforations MD Net Ft ND Gun Date * r+ Sterlina C-1: ." L- ''° 7,846'-7,860' 14' 4,961'-4,970' 6spf 10/23/00 Sterling Cl &C2 Sands 7,883'-7,945' 62' 4,986'-5,028' 6 spf 6/10/04 * ., Sterlina C-2: ;, . 7,962'-7,986' 24' 5,039'- 5,055' 6 spf 6/9/04 .+ '.- }n * .` ` ...tic. „. 8,014'-8,024' 10' 5,074'-5,081' 6 spf 10/23/00 ,, 8,024'-8,062' 38' 5,081'•5,106' 6spf 6/8/04 irts"' ' !, �+ 4. 61°to 40° Incl. TD PBTD 8,320'MD 8,058'MD 5,277'TVD 5,104'TVD Well Name&Number: Cannery Loop Unit 6 Lease: Cannery Loop Unit County or Parish: Kenai Penisula Borough State: Alaska Country: USA Perforations(MD): 7,846'-8,062' Perf(ND): 4,961'-5,106' Angle @KOP and Depth: 1.33° @ 400'MD Angle @ Perfs: 40°-.61° KOP TVD: 400' Date Completed: October 23,2000 RKB: 21' Revised By: Kevin Skiba Last Revision Date: November 4,2011 • M Marathon MARATHON Oil Company July 28, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: Report of Sundry Well Operations Field: Cannery Loop Unit Well: Cannery Loop Unit #6 • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 r ~' a ~ ' . ,U~.. R 200 ~', ~ _ _ , ~~~~~~~~ AUG ~ 2DOD Dear Mr. Maunder: Attached for your records is the 10-404 Report of Sundry Well Operations for CLU-6 well. This report covers the capillary string installation performed under Sundry #308- 210. The capillary string was installed on 6/28/2008 and set at the target depth of 8,020' MD. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, r `\~ ..~~,,(fjtic...~ Kevin J. Skiba Engineering Technician Enclosures: 10-404 Report of Sundry Well Operations Well Schematic Operations Summary cc: Houston Well File Kenai Well File KJS DMD ~' O~~ ~'"" /~~ STATE OF ALASKA ~~~~ ~, ~ 2Q08 ~~.p~ ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OP~~~I~S ~'°'- ~:4c~n 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Install Capillary i Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ String Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Marathon Oil Company Na 4. Well Class Before Work: 5. Permit to Drill Number: me; Development ^~ Exploratory^ 200-033 3. Address: PO Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20492-00-00 7. KB Elevation (ft): 9. Well Name and Number: 42.5'• '21' AGL ~ Canne Loo Unit #6 "~ 8. Property Designation: 10. Field/Pool(s): ADL-6068 8~ ADL-60569 Cannery Loop Field /Sterling Pool 11. Present Well Condition St~n7i'nary: r= Total Depth measured 8,320' - feet Plugs (measured) NA true vertical 5,277 , feet Junk (measured) NA Effective Depth measured 8,058' feet true vertical 5,104' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 91' 9-5/8" 91' 91' 10,900 psi 7,950 psi Surface 2,945' 7" 2,983' 2,320' 7,240 psi 5,410 psi Intermediate Production 8,103' 4-1/2" 8,124' 5,148' 8,440 psi 7,500 psi Liner Pertoration depth: Measured depth: 7,846'-8,062' gross True Vertical depth: 4,961'-5,106' gross 2205 Tubing: (size, grade, and MD) 3/8" OD Stainless Steal 8,020' Packers and SSSV (type and measured depth) NA NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 2,725 3 10 277 Subsequent to operation: 0 3,575 1.4 10 288 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development Q Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 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: 308-210 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician ~,,, ~ ~ Signature • ~ Phone (907) 283-1371 Date July 28, 2008 V Form 10-404 Revised 04/2006 ^ R I G I ~I A L ~ ~ ~u~ ~ ~~Qa Submit Original Only • • Clperations Surnm~ty Repprt VM/e1i Karnes CAt+ihtEFtY L,40P t11V1T os ort Mta: 612412,008 .bb C#tagory; R8M MAINTElL4d~1CE ~ _.... ___ .... ~,__ _.._ _..._._ __ a!t urnnary kMRU BJ Dyne coil unit, IAU vee cap to crow over, Found truss rnrgr was xabn4lhresds. SId opeeretl0rt. Machine stx~ to bold 4,5' EUE 8Rt) X ~ 7!8' EUE BRD. Move unp b Sterli~p Pad, .91~r1 ThM_. - Q11d 71rio Ulf CCEO ,..- Lb6e $LV3n .. COd~ - ~-._L`d1YT10fliw'eFt Oi3;D4 02:00 1.OD SAFETY A ~qF r+~d J r.y ~ted dFSCUSSed openriort. 12it14 3.00 Rl~fiF'" OTFdi AF -- ---- .~ ~kerRU co(I un t aTrau~_~ 1 73-04 ® ~~ jiURD ___ OTHR _ ,4~ ~ Aikl kae connecY<on to Iree. PT irrc oorrreclTon~~ psig~pa, Pulled tree cep. t 14.'40 1,00 _ THk` "~ lfrwck oft• tree mnnecdp n. Sk4 on 4 1f7 X 2 718" tree omgr. thn~ds in tree cep would net make up b 4 112' standard BF~t5lhreasla. Shut do1.n opertion. 14 15:tM0 1 URt] O'f'HR ' M StrsrQ ovm, secured wd. klach:re ahoD pg ~ rxeass aver8. np _ ?G~MfS fltlllld be -GCllletl. RD move equiprrrent to whgre smap iubi~! henper is Wt:ated, 15,00 16:Q0 1.00'RU D MSOT Issas. ^T~~ Re rt Oats: B1281'2D06 Job C~~ RSM AAAlt+l'rENAIFCE Nr InIMf Y MIRU Dyne coil unit, PU Injector. RMi hang off 3!$' ropily strtnq, Pump cap String rv±ll pi Foame~. R4 coll. a . ~; r ..;... ~: . , saunnmr ty+atr+r . Lar om. ~ • : ~ cod.. abysi, cosy ;~~ ,: cc*tm.r,r ~c ~ e~ ~:~"_ 08aDD 07:40 1A4 ShFETY 1ATi~ _. Held PJ 's+3uasetl Weraaortel tscuefi. R COIL - - MI U ual. PU irjeclor. li) pa o to top of tree. Secured pump s Ett end al sap string. Set to open et 3400 pstg. Pull test b 800 Ibs. Reedy _ ~ aldrrg to run in xell. Set in)eWut mandrel presaua mt 340() paig. :00 14:94 2.00 W t. _t.. Open wal.'k1R-xtih~6'~ cepgarY nlrirg end hang ~ 0` ~ .Lan $ secrued strYyg. '1 __. ~_~~1 R~. ~_ Cam. k injocaor toto remove m ta~f Citwe~ea~~. et die extra tuUing pry m grouts need ip wail heed, 11:00 12:0 1x44 RU~iD ` ~''~ R coil un vp arouid rre# ham, ,~ ~ toil left lease. Pimped 2-3 ge0on5 in Krell taus®d excess foam in saparalor wtdle urdoading water. ~ _ _ WHP = 290 pskU, 3.4 MAeCFPD Tale. ,_._ www.t~+eleton.pptn Cannery Loop Unit #6 Pad CLU-1 113' FSL, 465' FEL, Sec. 7, T5N, R11 W, S.M. 50-133-20492-00-00 ~s: ADL- 60568 & ADL- 60569 ttion: 42.5' (21' AGL) 9/9/2000 9/18/2000 ~ 61.52 Degree Incl. i i M MARATNOM Conductor Pioe 9-5/S" P-110 53.5 ppf Top Bottom MD Surf 91' TVD Surf 91' Surface Casing 7" L-80 23 8 26 ppf Top Bottom MD 0' 2,966' ND 0' 2,311' 8-112" hole Cmt wl 307 sks Production Casing 4-112" L-80 12.6 ppf Hydril 521 Top Bottom MD 0' 8,320' ND 0' 5,277' 6-1/8" hole Cmt w/ 547 sks Caoillarv Tubing 3/8" OD 2205 Stainless Steal Top Bottom MD 0' 8,020' ND 0' 8,020' 4-1/2" 'X' Nipple wl 3.813" ID 6,049' KB Perforations MD Sterling C-1: 7,846' - 7,860' 7,883' - 7,945' Sterling C-2: 7,962' - 7,986' 8,014' - 8,024' 8,024' - 8,062' Net Ft ND Gun Date 14' 4,961' - 4,970' 6 spf 10/23/00 62' 4,986' - 5,028' 6 spf 6/10/04 24' 5,039' - 5,055' 6 spf 6/9/04 10' 5,074' - 5,081' 6 spf 10/23/00 38' 5,081' - 5,106' 6 spf 6/8/04 C1 ~ C2 Sands ; .:~ , ~ 61° to 40° Incl. ; TD PBTD 8,320' MD 8,058' MD 5,277' ND 5,104' ND Well Name & Number: Cannery Loop Unit 6 Lease: Cannery Loop Unit County or Parish: Kenai Penisula Borough State: Alaska Country: USA Perforations (MD): 7,846' - 8,062' Perf (ND): 4,961' - 5,106' Angle @KOP and Depth: 1.33° @ 400' MD Angle @ Perfs: 40° -~ 81° KOP ND: 400' Date Completed: October 23, 2000 RKB: 21' Prepared By: Kevin Skiba Last Revision Date: July 28, 2008 • • o SARAH PALIN, GOVERNOR ~~ Ou ~ ~ 333 W. 7th AVENUE, SUITE 100 COI~TSERQATIOI~T CO11~jIS5IOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dennis Donovan Production Engineer Marathon'Oil Company PO Box 1949 ~~~NEE~ JUN '), 9 2008 Kenai AK 99611-1949 a d~~ ~ 3 3 Re: Cannery Loop Unit, Sterling Undefined Gas Pool, Cannery Loop Unit #6 Sundry Number: 308-210 '` -- - - Dear Mr. Donovan: 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. 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 iri 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 ff 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, Daniel• T. Seamount, Jr. Chair DATED this J8` day of June, 2008 Encl. • M Marathon MARATHON Oil Company June 12, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 R~~~ ~u~ ~ ~ zoo$ Anchorage, Alaska 99501 Alaska Oii & Gas Cons. Commission ~rci soy age Reference: 10-403 Sundry Notice Field: Cannery Loop Unit, Pad 1 Well: Cannery Loop Unit 6 (PTD 200-033) Dear Mr. Maunder: We propose to run a 3/8" capillary string in CLU 6. With the availability of a capillary injection unit on the Peninsula starting the week of June 23~d 2008; we are able to mitigate water loading by running a capillary string and pumping foamers. Setting depth of the capillary string should be around 8020' MD. The past capillary string installation into KTU 24-6H (PTD 199-073) has yielded an approximate incremental gain of 475 MCFD over the past 3 months. We would like to continue to install capillary strings in other wells like CLU 6 and be able to realize longer and more stable production. Please find attached a 10-403, current wellbore diagram, and detailed operations program. If you have any questions or need further information please call me at (907) 398-1362. Sincerely, ~9~iz. Dennis Donovan Production Engineer Enclosures: 10-403 Sundry Notice Current Well Schematic Detailed Operations Program cc: AOGCC Houston Well File Kenai Well Fife DMD KJS ~ ~ R~ o ~~tF1 ~i STATE OF ALASKA ~ U N ~ ~ ~ ~ ~ f~ ALASKA OIL AND GAS CONSERVATION COMMISSION `,~ APPLICATION FOR SUNDRY APPRQ~~ii ~ Gas Cafes. ~~mmission 20 AAC 25.280 w ,,,,~ ,.. ~. _ .. 1. Type of Request Abandon^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver OtherO Alter gsing ^ Repair wetl ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Install Capillary Change approved program ^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well ^ String z. Operator Name: Marathon Oil Com an p y 4. Current Well Class: 5. Permit to Drill Number: Development O Exploratory ^ 200-033 - 3. Address: p0 BOX 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20492-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Wetl Name and Number: property line where ownership or landownership changes: S i R E i ~ ^ Cannery Loop Unit #6 pac xception equ ng red? Yes No 9. Property Designation: 10. KB Elevation (ft): 11. FieldtPoo~s): ADL-60568 & ADL-60569 ~ ~"~ 42.5" Cannery Loop Field /Sterling Pooi 12. ~,{;~-~~~~ ,~ tL+tL~~~~4 ~t. "1 -- ~ ~ PRESENT WELL CONDITION SUMMARY Total Depih MD ~ ` Total Depth TVD (ft}: Effective Depth MD (ft}: Effectlve Depth TVD ft): Plugs (measured): Junk (measured): > = Casing Length Size MD TVD Burst Collapse Structural Conductor 91' 9-5/8" 91' 91' 10,900 psi 7,950 psi Surface 2,g45' 7" ~° ~~ '' ~~'~ 7,240 psi 5,410 psi Intermediate Production 8 41/2" 0' ~ ~, ' S ~ ~ 8,440 psi 7,500 psi Liner Perforation Depth Mt) (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7,846'-8,062' gross 4,961'-5,106' gross NA NA NA Packers and SSSV Type: Packers and SSSV MD (ft): NA NA 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. WeN Status after proposed work: Commencing Operations: June 24, 2008 Oil ^ Gas 0 Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Dennis M Donovan Title Production Engineer Signature Phone (907) 283.1333 Date June 12, 2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ $ ~ ~ I Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other. Subsequent Form Required: 1 ~ " j fj APPROVED BY Approved by: ~ COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/3006 R ~ ~ ~ ~ A ~ ~ ~~~ JUG ~ ~ ~~~8 Submit in Duplicate 'M Marathon MARATHON Oil Company Cannery Loop #1 Pad 1.5 Miles South of Kenai. Alaska 11/9!2000 I AFFINITO I clu-6wbd.xls KB-42.5 feet GL=21.5 feet CLU #6 Sterling Gas Producer 2008 Capillary String Installation Page 1 2008 Capillary String Installation Program CLU, SU, BC, KGF and NGF WBS#s SD#3 - W0.08.18049.CAP.001 KBU 11-8Y, 33-6X, 41-7 - W0.08.18053.CAP.001 BC 13 - W0.08.18054.CAP.001 ~ CLU 6 - W0.08.18056.CAP.001 ~°'" SU 32-9 - W0.08.18117.CAP.001 GO 6 - W0.08.18196.CA1P.001 Objective - Install a 3/8" Capillary String into these wells to alleviate liquid loading. We intend to treat the producing fluid level in each of these 8 wellbores with foamer. Install and Complete CICM (injection. skids) to utilize on wellheads. We have seen an incremental increase on KTU 24-6H capillary string installation of approximately 475MCFD. Procedure Companies Evolved: UOSS, BJDC, BJCS, BigG Installation Order ell Maximum Setting Depth Maximum String Len th Minimum String Needed at Surface trin Size and T e lan a Connection Est'd Producing Fluid Level a De th Gauge Ring ID run Recommended Setting Depth From PT+Ta 1 CLU 6 8042' 8200' 45' 2205 3/8" X 0.049" WT 4-1/16 5M RX39 7880' 8058' 2.300" 8020' 2 SU 32-9 6200' 6250' 45' 2205 3/8" X 0.049" WT 3-1l8" 5M RX35 TBD TBD TBD TBD 3 BC 13 8590' 8750' 45' 2205 318" X 0.049" WT 3-1/16" 10M BX154 7900' 10055' 2.300" 8580' 4 GO 6 10120' 10300' 45' 2205 3/8" X 0.049" WT 4-1/16 5M RX39 TBD TBD TBD TBD 5 SD 3 9290' 9450' 45' 2205 3/8" X 0.049" WT 4-1/16 5M RX39 TBD TBD TBD TBD 6 KBU 41-7 6910' 7050' 45' 2205 3/8" X 0.049" WT 3-118" 5M RX35 TBD TBD TBD TBD 7 KBU 11-8Y 8145' 8300' 45' 2205 3l8" X 0.049" WT 3-1/16" 10M BX154 TBD TBD TBD TBD 8 KBU 33-6X 8200' 8350' 45' 2205 3/8" X 0.049" WT 3-1/16" 10M BX154 TBD TBD TBD TBD • 2008 Capillary String Installation Page 2 Installation Procedure: l.) BJCS: (Hold PJSM and JSA) a) Complete placement of 3 new CICM skids on wells CLU 6, SD 3, and KBU 41-7, all other wells have units placed. They will complete Installation of items that are pertinent to operation of CICM. b) Move NS#3 CICM to GO#6 well 2.) DOSS: (Hold PJSM and JSA) a) Removal of all well houses to setup for BJ Dynacoil Unit b) Replacement of CICM roof on (3) new skids, after tanks are set inside containment. 3.) Big G: (Hold PJSM and JSA) a) Complete explosion proof electrical end fittings for CICM b) Complete tubing for hookup of Dynacoil - if needed. - Placement of an open conduit under the well house wall for easy routing of 3/8" id tubing for skid hookup. This will prevent multiple tubing disconnects when well work is needed, thus reducing exposure to trapped pressure. 4.) BJDC: 1. Hold PJSM and Complete JSA/JHA 2. Move in rig up BJ Dynacoil unit. 3. Replace tree-cap flange with specified internally threaded flange listed above in the matrix. 4. MU BHA and secure to 3/8" string. 5. MU WHA to internally threaded flange 6. MU Trailer Haskell Pump to WHA with 1" male NPT tie back assembly 7. Pressure test flange assembly against a closed valve to 1.5 times SITP with Trailer Haskell Pump. 8. "SHUT IN WELL AT WING VALVE" -This will prevent BHA from traveling down flowline. BHA is small and capable of flowing into flow-Tee 9. RIH with capillary below "Est'd Producing Fluid Level". All strings must be set into the producing fluid level to prove the most effective. 10. Set Rattiguns and Leave 1.5 times SITP or greater as requested by BJDC on hydraulic pack off. 11. "OPEN WELL TO PRODUCTION" 12. Leave remaining spool of tubing outside of well for soap injection skid hookup. 13. Cap the tubing with a Swagelok cap, Swagelok valve, and pressure gauge. 14. Lockout/Tagout Swab, Upper Master and Lower Master. (Install BJ Dynacoil signs on all valves stating "Do Not Operate BJ Dynacoil in wellhead". Proceed to Lockout valves with production lack and cable.) 15. Hookup injection line to CICM, and set specified rate for each well. 16. RDMO, Cleanup site, Sign-out • F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ( ~ M Marathon MARATHON Oil Company Alaska Asset Team Northern Business Unit P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1326 Fax 907/283-6175 ~OD~ 033 June 29, 2004 [) Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W ¡th Ave Anchorage, Alaska 99501 ~~ ~¡i~"í' DOl uU!~ 't, Jt 2 t Reference: CLU 6 Dear Mr. Aubert: Enclosed is a 10-404 REPORT OF SUNDRY WELL OPERATIONS for Marathon Cannery Loop Field, well CLU 6. I have attached an updated wellbore diagram as well as daily activities reports during the perforating event. This work was completed June 10, 2004. If you need any additional information, I can be reached at 907-283-1333 or bye-mail at d mtitus@marathonoil.com. S.,'I..,.n.,. ce"., reIY'..¥Í:,. n ~. l ! ~ ,A tr- ,~ lV"" ? Denise M. Titus Production Engineer Enclosures ORIGINAL , STATE OF ALASKA I ALA~. A OIL AND GAS CONSERVATION COM!\,I,vSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator Marathon Oil Company Name: 3. Address: PO Box 196168, Anchorage, AK 99519-6068 Plug Perforations U Perforate New Pool 0 Perforate 0 4. Current Well Class: Development 0 Stratigraphic 0 Stimulate U Other U Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0 200-033 Service 0 6. API Number: 50-133-20492-00 9. Well Name and Number: Cannery Loop Unit #6 10. Field/Pool(s): Cannery Loop Field, Sterling Pool 7. KB Elevation (ft): 42.5' KB above MSL: GL=21.5 8. Property Designation: ADL-60568 & 60569 11. Present Well Condition Summary: Total Depth measured 8320 true vertical 5278 feet feet Plugs (measured) N/A Junk (measured) N/A Effective Depth measured 8223 true vertical 5241 feet feet Casing Structural Conductor 91' Surface 2983' Intermediate Production 8308' Liner Length Size MD TVD Burst Collapse 91' 10900 7930 2320' 7240 5410 5266' 8431 7500 9-5/8" 7" 91' 2983' 4-1/2" 8308' Perforation depth: Measured depth: 7846-7860'; 7883'-7945'; 7962'-7986'; 8014-8024'; 8024'-8062' True Vertical depth: 4961-4970'; 4986'-5028'; 5039'-5055'; 5074-5106' Tubing: (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. BFl jUl 0 6 10U4 Prior to well operation: 0 Subsequent to operation: 0 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 10300 0.6 10600 0.6 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: OilD Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl Tubing Pressure 840 1000 Service 0 x Contact Denise Titus GINJ 0 WINJ 0 WDSPL 0 SUndry Number or N/A if C.O. Exempt: Printed Name De¡iS M. Titus , .,... Signature '1&~ ytØ' I'" . ç:.~ . Title Production Engineer Phone 907-283-1333 Date 6/29/2004 Form 10-404 Revised 04/2004 nq\G\NÞ\l Submit Original Only I KB=42.5 feet I GL=21.5 feet {, I CLU #6 Sterling Gas Producer J Sterling C-1 Perfs 6 SPF "\::;::", 7846-7860' (4961-4970 TVD) 10/23/00 "\::::, ::::::!::::::::::::::::::::::::::::::::: í¡~¡;i¡;~; ~~!:::~ ND) 10/23/00 ::::!::::::::::::!:;::::::::::::: 1 ::I:;!;:':;':'~::,\ 8024'-8062' 6/8/04 ~ I ~.::::, I::::::....:::.:.: ....::::'::::::::,.,:':, ,."":"",:,:.:':'.:::""',,, ,'",:,::,:,:,""':'::':' ,.::::: .:::::.:....¡: ¡¡ ,¡ ,¡:! ~ !¡:::.:.:.:: .::: ¡. ;:"""" IDOD = 8223' MD I~\' Ii /7" 261bmlft L-BO @ 2966' MD (2310 1VD) 4-1/2" 12.61bmlft L-80 Hydril 521 @ 8308' MD cmt'd 6- 1/8" Hole [61.52 Degrees Incl. 4-1/2" 'X' Nipple w/3.813" 10 @ 6049' KB 18,320' MD /5,278' TVD M Marathon MARATHON' Oil Company CLU #6 Cannery Loop #1 Pad 1.5 Miles South of Kenai, Alaska Q8IS; ORIGINATOR: IE!.!.£;, 11/9/2000 AFFINITO clu-6wbd.xls WELL NAME CANNERY LOOP UNIT 6 SUPERVISOR Denise Titus FIELD NAME CANNERY LOOP UNIT ST A TElPROV Alaska CURRENT STATUS @ 6AM One of nine runs completed. OPERATION COMMENTS RU Expro. Completed dummylGR/CCL run after pumping diesel to alleviate hanging up around KOP. 8042'-8062' . , MARATHON OIL COMPANY Daily Recompletion Report Increase Production Page 1 of 1 KB \GL 21.00 124 HR PROG TMD TVD AUTH MD WBS I DFS I DOL I RPT # DATE 0 0 3 08-Jun-2004 SAPIWBS COST 21.0 RIG NAME & NO. RIG PHONE W00410055EXP \ MOC WI NRI I DAILY WELL COST \ CUM WELL COST , ~ \ LAST CASING I NEXT CASING I LEAKOFF (Q¿ 0 (in) (Q¿ 0 (ft) \24 HR FORECAST Return to perforate additional zones. Flow well overnight. COUNTY/OTHER Completed perforating run from SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I BOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? 0.00 None N ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM TO 07:45 08:00 08:00 10:15 10:15 10:30 10:30 10:40 10:40 12:20 12:20 13:00 13:00 13:40 \ LAST RIG INSPECTION HRS 0.25 2.25 0.25 0.17 1.67 0.67 0.67 OPERATIONS SUMMARY FROM TO SUB PHASE OP SUBOP TRBL DESCRIPTION AF CMPPRF SAFETY MTG- Arrive, sign in, discuss job, safety meeting. AF CMPPRFRURD- ELEC RU equipment. Run to Expro shop to PU 3-3/8" dummy gun. AF CMPPRF PULD- PGUN MU 20' dummy gun wI gamma raylCCL AF CMPPRF NUND BOPE NU lubricator to tree and preapare lines for P test AF CMPPRF TEST - BOPE Pressure test lubricator to 3200psi using MOC methanol trailer. AF CMPPRF~UNPUL ELEC RIH wI gamma gun & dummy (3-3/8" x 20') 4,400 TA CMPPRFWORK- ELEC MDPF Gun hanging up around 2200' to 2700' Work down to 4400'. Decide to pump diesel to slick up wellbore. TA CMPPRF~UNPUL ELEC MDPF POOH. TA CMPPRFPUMP - DESL At surface, bleed down lubricator and find diesel to pump down wellbore. RIH to 8100' wlo hanging up. Complete correlation logging passes. POOH from 8100'. Pick up 20' 3-3/8" perforating gun #1. RIH wI gun. Correlate on depth. Perforate. POOH. Rig back equpment for night leaving night cap on the well. 13:40 14:15 0.58 4,400 14:15 15:20 1.08 LAST BOP TEST: SIZE I ID I SHOE TEST 15:20 16:25 1.08 16:25 17:15 17:15 17:45 17:45 18:30 18:30 18:45 18:45 19:45 19:45 21 :00 8,100 AF CMPPRFLOG- CSG- 0.83 8,100 0.50 0.75 0.25 8,100 1.00 8,100 1.25 AF CMPPRF~UNPUL ELEC AF CMPPRF PULD- PGUN 8,100 AF CMPPRF~UNPUL ELEC 7,500 AF CMPPRF PERF - TBG- AF CMPPRF~UNPULELEC AF CMPPRFRURD- ELEC CASING SUMMARY LAST CASING TEST: MAX SICP I MD I TVD NEXT BOP TEST: WT I GRADE BURST Printed: 6/29/2004 3:55:04 PM Page 1 of 1 MARATHON OIL COMPANY Daily Recompletion Report Increase Production IKB 21.0 RIG NAME & NO. [GL 21.00 124 HR PROG TMD TVD AUTH MD WBS I DFS I DOL I RPT # DATE 0 0 4 09-Jun-2004 SAPIWBS COST WELL NAME CANNERY LOOP UNIT 6 SUPERVISOR Denise Titus FIELD NAME CANNERY LOOP UNIT ST A TElPROV Alaska CURRENT STATUS @ 6AM completed 5 of 9 total runs OPERATION COMMENTS Completed four perforating runs wI 3-3/8" guns. RIG PHONE COUNTY/OTHER W00410055EXP MOC WI NRI I DAILY WELL COST I CUM WELL COST J U' I LAST CASING I NEXT CASING I LEAKOFF ~ 0 (in) ~ 0 (ft) 124 HR FORECAST Return to perforate additional zones. Flow well overnight. Perforated 7962'-7986' & 8014'-8042'. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG IBOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? 0.00 None N ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: I LAST RIG INSPECTION OPERATIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP SUBOP TRBL 07:35 08:15 0.67 AF CMPPRFSAFETY MTG- 08: 15 09:00 09:00 09:20 09:20 10:00 10:00 10:40 10:4011:20 11 :20 11 :45 11 :45 12:45 12:45 13:00 13:00 13:50 13:50 14:10 14:10 14:45 14:45 15:15 AF CMPPRFPULD- PGUN AF CMPPRF TEST - BOPE 8,100 AF CMPPRF ~UNPUL ELEC 8,100 AF CMPPRFLOG- CSG- AF CMPPRF~UNPULELEC AF CMPPRF PULD- PGUN 8,100 AF CMPPRF ~UNPUL ELEC 8,100 7,600 AF CMPPRFLOG- CSG- 7,600 AF CMPPRF~UNPUL ELEC AF CMPPRF PULD- PGUN 8,100 AF CMPPRF~UNPUL ELEC 8,100 7,600 AF CMPPRFLOG- CSG- 0.75 0.33 0.67 0.67 7,600 0.67 8,100 0.42 1.00 0.25 0.83 0.33 0.58 0.50 AF CMPPRF~UNPULELEC 16:20 17:30 1.17 15:15 16:20 1.08 7,600 TA CMPPRFRURD- ELEC 17:30 17:45 17:45 18:45 18:45 19:05 19:05 20:20 20:20 20:45 0.25 1.00 0.33 8,100 1.25 7,600 0.42 AF CMPPRF PULD- PGUN 8,100 AF CMPPRF~UNPUL ELEC 7,600 AF CMPPRF LOG- CSG- AF CMPPRF~UNPULELEC AF CMPPRFSECURE WELL DESCRIPTION Arrive, sign in, meet to discuss job, PJSM. Specific safety meeting topic regarding arming guns. Discuss radio silence and notify adjacent operations. Arm guns, PU lubricator and tools. Slowly open well to equalize lubricator. Ensure BOP secure. RIH wI 20' X 3-3/8" perforating gun #2. Correlate on depth. Perforate 8022'-8042' POOH. LD carrier and PU 10' x 3-3/8" perforating gun #3. RI H wI gun #3. Correlate. Perforate 8' from 8014'-8022'. POOH. WHP dropped from 1170psi to 1125psi. At surface, LD 10' carrier. PU 10' perforating gun #4. RIH wI gun #4. Correlate on depth and perforate 7976'-7986'. Pwh increased from 1125psi to 1180psi. Had to pull 2500lb over to get unstuck after perforating. Appears gun jump kinked line. POOH to surface. Tools tried to stick in lubricator. Able to shake free. Found kink in line at top of tool. LD tools and retie cable head. New cable head ready to go. PU 15' gun #5. RIH wI gun #5 to depth. Correlate on depth. Pull into position and perforate 7962'-7976'. POOH wI with last carrier for day. Lay down lubricator and secure well for night. LAST BOP TEST: SIZE I ID I SHOE TEST CASING SUMMARY LAST CASING TEST: MAX SICP I MD I TVD NEXT BOP TEST: WT I GRADE BURST Printed: 6/29/2004 3:55:36 PM Page 1 of 1 MARATHON OIL COMPANY Daily Recompletion Report Increase Production KB IGL 21.00 124 HR PROG \ TMD TVD AUTH MD WBS I DFS \ DOL \ RPT # DA.TE 0 0 5 10-Jun-2004 SAP/WBS COST WELL NAME CANNERY LOOP UNIT 6 SUPERVISOR Denise Titus FIELD NAME CANNERY LOOP UNIT STATElPROV Alaska CURRENT STATUS@ 6AM Perforating complete OPERATION COMMENTS Completed final day of perforating 7846'-7860' (reperf) & 7883'-7945', 21.0 RIG NAME & NO. RIG PHONE COUNTY/OTHER W00410055EXP MOC WI NRI \ DAILY WELL COST 1 I LAST CASING \ NEXT CASING ~ 0 (in) ~ 0 (ft) \ 24 HR FORECAST Flow well to system and observe CUM WELL COST I LEAKOFF SAFETY SUMMARY MANHRS WORKED \ ACCIDENT TYPE I LAST SAFETY MTG \BOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? \ LAST RIG INSPECTION 0.00 None N. ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: OPERATIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP SUBOP TRBL 07:30 08:00 0.50 CMPPRFSAFETY MTG- 08:00 09:30 1.50 09:30 10:45 1.25 8,100 10:45 10:55 0.17 8,100 7,600 10:55 11 :40 0.75 7,600 11 :40 12:00 12:00 12:50 12:50 13:10 13:10 14:10 14:10 14:35 14:35 15:00 15:00 15:15 15:15 15:55 15:55 16:15 16:15 17:00 17:00 17:45 17:45 19:00 19:00 21 :00 0.33 0.83 8,100 0.33 8,100 7,600 1.00 7,600 0.42 0.42 8,100 0.25 8,100 7,600 0.67 7,600 0.33 0.75 8,100 0.75 8,100 7,600 1.25 7,600 2.00 LAST BOP TEST: SIZE I ID I SHOE TEST CMPPRFRURD- ELEC CMPPRF~UNPULELEC CMPPRF LOG- CSG- CMPPRF~UNPUL ELEC CMPPRF PULD- PGUN CMPPRF~UNPULELEC CMPPRF LOG- CSG- CMPPRF~UNPUL ELEC CMPPRF PULD- PGUN CMPPRF~UNPUL ELEC CMPPRF LOG- CSG- CMPPRF~UNPULELEC CMPPRF PULD- PGUN CMPPRF~UNPULELEC CMPPRF LOG- CSG- CMPPRF~UNPULELEC CMPPRFRURD- ELEC DESCRIPTION SI well (had flowed all night to clean up). Arrive, sign in, obtain work permit, discuss job, PJSM Fill grease injector, replace pack off rubbers, PU 20' 3-3/8" gun #6. RIH to logging interval. Correlate on depth. Perforate 7925'-7945'. POOH. Pwh increased from 1160psi to 1180psi. Scada trend indicates gradual BU, not necessarily related to perforating. lay down carrier and PU 20' gun #7. RIH to logging interval. Correlate on depth. Perforate 7905'-7925' POOH wI spent carrier LD carrier and MU 20' gun #8. RIH to near depth with gun #8. Pull CCL log to correlate depth. Perforate 7883'-7903' POOH with spent carrier. Pick up final 15' gun. RIH wI gun #9. Log to correlate. Get on depth and perforate 7846'-7860'. POOH wI spent carrier. RD equipment, turn in permit, and sign out. CASING SUMMARY LAST CASING TEST: MAX SICP I MD I TVD NEXT BOP TEST: WT I GRADE BURST Printed: 6/29/2004 3:56:08 PM Alaska Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 March 2, 2004 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Reference: Sundry Application Field: Cannery Loop Unit Well: CLU # 6 Permit No: 200-033 Dear Mr. Aubert, Enclosed please find the APPLICATION FOR SUNDRY APPROVAL, along with the associated attachments. Plans are to perforate additional intervals in the Sterling as soon as wireline is available, pending your approval. If you require further information, I can be reached at 907-283-1337 or bye-mail at DE Eynon@MarathonOil.com. Sincerely, ~~ Donald Eynon Operations Engineer Enclosures MAR 0 3 2004 ~~1~'1;. r" "c;'''\i'¡~I'1:;~¡,nn ~J-Ii;.Æ' L"" . ~C;f~¡~\!m~E[) ~~l~r« 1 5 2D04 nDIr./Nl\L N Gà ~i '~I Z.oo 4- f)J S .J( 3 I 1- STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 1. Type of Request: AbandonD Suspend wellD Operation ShutdownD perforate\Ð varianceD Alter Casing D Repair wellD Plug perforationsD StimulateD Time ExtensionD Change Approved programD 2. Operator Name: Marathon Oil Company Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 3. Address: 4. Current Well Class: DevelopmentE] EXP,oratory8 StratigraPhiCD Service 5. Permit to Drill Number: 200-033 /,- 6. API Number: ,/ 50- 133-20492-00 PO Box 196168, Anchorage, AK 99519-6168 7. KB Elevation (ft): 42.5' KB above MSL GL=21.5' 8. Property Designation: , ADL-60568 & 60569 11. Total Depth MD (ft.) 8110 MD Casing Structural Conductor Surface Intermediate Production Liner 9. Well name and number: Cannery Loop # 6 /' 10. Field/Pools(s): Cannery Loop Field, Sterling Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 6321' MD 5814' Plug (measured): 6378' MD Total Depth TVD (ft): 7410 TVD Length Size MD TVD Burst 95/8" 91 91 N/A 7" 2966 2,311' 7,240 psi 4.5" 8,320' 5,278' 8,440 psi 91' 2966' 8320' Perforation' Depth MD (ft): See attached Diagram Packers and SSSV Type: N/A Tubing Size: Tubing Grade: 4.5" Casing L-80 Packers and SSSV MD (ft): N/A Perforation Depth TVD (ft): See attached Diagram 12. Attachments: Description Summary of proposal~ Detailed Operations Program EI BOP Sketch -0 13. Well Class after proposed work: Exploratory D Development EI 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil D Gas~ PluggedD 5-Mar-2004 / Date: WAG D GINJD WINJD 16. Verbal Approval Commission Representative 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Donald Eynon Title Operations Engineer Signature ~~, "......, " , "~";~)?;)""- ,::"./;.,(t /:-50', ':,4? "i~~'~:'~):'-"-. !,ß~",!:I" Phone 283-1337 Commission Use Only Annular Disposal D OtherD Junk (measured): N/A Collapse 5,410 psi 7,500 psi Tubing MD (ft.): 8,320' Service D Abandoned 0 WDSPL D Date March 1 2004 Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D Mechanical Integrity Test 0 Location Clearance D Other: R \ G\ N~bDEROF COMMISSIONER THE COMMISSION L. MAR \J ,¡;' l8!~I% " ;" ~, .-, MAR 0 3 2004 Marathon Oil Company Alaska Region CLU6 Cannery Loop Field Add Perforations Procedure WBS # WO.04.1 0055.EXP History: CLU 6 is a cemented 4-1/2" Sterling mono-bore completion. Well has been perforated with out use of tractor in past. Last PLT required tractor for wheels to roll in hole, tractor mechanism was not needed. Objective: Perforate additional pay. Additional pay has been identified in the wellbore from log analysis of CLU 7 open hole log data. /' Procedure: 1. Ensure location and tree are prepped for wire line including liner installation and house removal if necessary. 2. MIRU wire line unit. 3. Perforate the following zones with 3-3/8" 6SPF loaded with 3 1/8" charges PN SDP- 3125-311NT3, retrievable guns with a max swell of 3.635" OD in air: CLU 6 Top Bottom Footage Comment \, 7846 7860 14 15' 7846' - 60' (Re-perf.) 7883 7945 62 3-20'" 7883' - 7945' (New interval) / 7962 7986 24 10&15 / 7962' - 86' (New interval) 2-20' 1-10' 8014 8062 48 (8014' - 24' is Re-perf, the bottom section is New interval 8014' - 62') 4. Clean up location. RDMO eline, and return well to system per instruction of production engIneer. NOTE: Gun Perfonnance Data: Ave.. EH. of .36" and 40.250" PEN. The concrete compressive strength was 5344PSI. // I CLU #6 Sterling Gas Producer 9-5/8" 53.5Ibm/ft P-110 driven to 91' : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : ( S~~~I;~~ B~2 . . . . : I: : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : ''¿ : ~: :..::., ::::::::::::::::::::::::::::::::::::::::::::::::::::::: . :::::::::::::::::::::::::::::::::: ~ : 1::::':\. ~: ~: ~: ~: ~: ~: ~: ~: ~: ~: ~ :1 Sterling C-1 Perfs 7846-7860'6 SPF 10/23/00 (4961-4970 TVD) I~: ~: ~: ~: ~: ~ ~ ~~: ~: ~: :"'-::. .:.:.:.:.:.:.:.:.:.: .:.:.:.:.:.:.:.:.:.:.: .:.:.:.:.:.:.:.:.:.:.:.:.:.:. :.:. :.:.:.:.:.:.:.:.:.:.:.:.: .:.:.: 0 .~.:.:., :. '.' ~ I :::. ~: ~: ~: ~: ~: ~: ~: ~: ~: ~: ~: ~: [Sterling C-2 Perfs 8014-8024'6 SPF 10/23/00 (5074-5081' TVD) ~: ~: ~: ~: ~: ;: ~ ~~: ~: ~: ~: ~: ~ :'\ . : . : . : . : . : . : . : . : . : . : . : . : . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . : . : . : . : . : .....'£>.._.4. : . : . : . : . : . : . . "" I , IDOD = 8223' MD : 17" 26 Ibm/ft L-80 @ 2966' MD (2310 TVD) ~/ Ë~~~~~:2g~~~~1 1/8" Hole ~ --,.-----.-------.--- 1~~-.;2~~~~~~~~~~~~=J 4-1/2" 'X' Nipple w/3.813" ID @ 6049' KB 18,320' MD 1 5,278' TVD Marathon Oil Company CLU #6 Cannery Loop #1 Pad 1.5 Miles South of Kenai, Alaska ~ Ell&;. AFFINITO clu-6wbd.xls MŒ. 11/9/2000 Alaska~[' ness Unit Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 November 13, 2002 Mr. Howard Oakland Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Marathon Oil Company Cannery Loop Unit #6 Enclosed is a CD containing the digital well data listed below. Cannery Loop Unit #6 :rqa~e.:;. ~:):: :~..:.: i~: ~: i..: :i~ .::. i: :. i: .:. :: .: :'.:: ~: :: .:::'! !' ::. :.!.:::" ? 5ize~. ~icannery_loop_u-6_mu.d.!.0..'.g..,.!..a..~..i~" .......................................................................... : 5j322 KB ~';;';'~;;'~'~)'"i';';'l~""~l"-'~'"'~'; ~ t r o n, la s 268 KB ~ canneryJoop_u-B_run 1,1as 2, 675 KB ~ canner¥_loop_u-6_sonic, las 195 KB ~ canneryJoop_u-6_tYd,las 5 KB ~ clu6_mudlog_remarks,dab 25 KB LA5 File LA5 File LA5 File LA5 File LA5 File DAT File VIA CERTIFIED MAIL Please confirm receipt of this data by signing and returning one copy of this transmittal to my attention at the letterhead address. Sincerely, Kaynell Zeman Technical Assistant Received by: Date: /~ CD enclosed Certified Mail Receipt: 7001 0320 0005 1579 5155 Environmentally aware for the long run. Permit to Drill 2000330 DATA SUBMITTAL COMPLIANCE REPORT 3/1212003 Well Name/No. CANNERY LOOP UNIT 6 Operator MARATHON OIL CO APl No. 50-133-20492-00-00 MD 8320 --' TVD 5278 -// Completion Dat 10/23/2000 ~ Completion Statu 1-GAS Current Status 1-GAS UIC N REQUIRED INFORMATION Mud Log N._9o Sample N._9o Directional Sur~ey No DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Interval Data Digital Digital Log Log Run OH I Dataset Type/M_edia .... Fmt Name .... Scale Media No Start Stop CH Received Number Comments ' '- ~'g TVD/' 2 2983 5280 CH 1/5/2001 2983-5280 Color Print, ~'" Sepia L./' ,-E-" ~ud Log MD 2 2983 8320 CH 1/5/2001 2983-8320 Color Print, Sepia L L PEX/Array 2/5 ~,~)~ 2967 7810 CH 1/5/2001 2967-7810 Color Print, · Induct/MCFL/GPJCCL ,~~ Sepia ~ '~' ~m Sonic 5 5500 8070 CH 1/5/2001 5500-8070 Color Print, / Sepia ~ e~n/Neu/GPJCaI/PEX 5 2967 7810 CH 1/5/2001 2967-7810 Color Print, Sepia ~ .~Den~Neu/GP,/Cal/TVD 5 2967 7810 CH 1/5/2001 2967-7810 Color Print, Sepia L L RST/rSigma 5500 8221 1/9/2001 5500-8221 Print L L Perf 7350 8024 1/9/2001 7350-8024 Print Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments Cuttings 5500 8320 / G..~ .... ] ADDITIONAL INFORMATION Well Cored? Y/~ Chips Received? . ¥; ;.' -- Analysis ~ R ~.c~.iv~.d ? Daily History Received? (~N Formation Tops ¢/N Permit to Drill 2000330 MD 8320 TVD DATA SUBMITTAL COMPLIANCE REPORT 311212003 Well Name/No. CANNERY LOOP UNIT 6 Operator MARATHON OIL CO 5278 Completion Dat 10/23/2000 Completion Statu 1-GAS Current Status 1-GAS APl No. 50-133-20492-00-00 UIC N Compliance Reviewed By: Alaska I~' ~ess Unit Marathon Oil Company April 15, 2002 P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 Ms. Lisa M. Weepie Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 VIA CERTIFIED MAIL RE: Marathon Oil Company: Cannery Loop Unit #6 Dear Lisa: As requested in your letter dated April 4, 2002 to John Barnes, Marathon is transmitting the attached information on the Cannery Loop Unit #6. Below is a description of the data being transmitted. · Copy of Approved AOGCC Drilling Permit w/attachments · Daily Drilling Reports · Daily Well Operations Report · Mud Log Summary Report · CoilcadeTM Report · Schlumberger Coiled Tubing Service Report · Casing and Cementing Record · Schlumberger Cementing Service Report · Casing Integrity Test · Test Results - 10/29/00 · Test Results- 1/10-12/01 · Well Completion Report · Copy of Transmittal Letter for CLU #6 Well Samples Transmitted 10/18/01 · Copy of Transmittal Letter for CLU #6 Logs Transmitted 10/31/01 · Copy of Transmittal Letter for CLU #6 Logs Transmitted 12/13/01 · Petroleum Information/Dwights Production Report for CLU #6 Please sign and return one copy of this transmittal to me at the letterhead address confirming your receipt of the data. Thanks, Kay~;'e l~Zem~(~'~ Technical Assistant Certified Receipt 7001 1140 0000 8289 0317 Environmentally aware for the long run. Receivedb'~~, ' ~ Date: t I ? 2002 AIBMmOil&GasCon6. n Allell INTERVAL SUMMARY CANNERY LOOP UNIT WELL CLU 0.6 SURFACE INTERVAL: 8 ½" Hole ( 0 - 2983' MD) On WedneSday, September 6, 2000, Glacier Rig 1 was spotted on Marathon;s CLU~6 Well and rigged up. It was accepted on Friday, September 8 at 06:00 and finished rigging up. The 8 ½" surface hole was spudded September 9 at 01:30. Spud mud started with. 15 ppb M-I Gel. Gelex was used for higher viscosity as needed. The thought process for this spud was to spud with this mud until the gravel formation was drilled through. Aider which, the additions of M-I Gel would be allowed to decrease while drilling through the clay formation of the surface hole. During the accrual drilling, no gravel formations were encotmtered. Only sand and silt was drilled.during the .surface interval before the clays were encountered. Drilling continued to 1827' where torque began to build, and ROP decreased considerably while sliding. A high viscosity sweep was pumped. It brought up a slight increase in solids, but it did not improve sliding. A 13-stand wiper trip was performed back to 1027'. The trip was smooth, and sliding .did improve considerably. When drilling continued, torque and ROP were'back to normal. Drilling continued to the 7" casing point of 2983' MD. A high viscosity sweep was pumped with good results, and a short trip to the conductor pipe was made. The well was swept again with fair results, and the drill string was POOH to run casing. The surface casing (7" X 26 ppfL-80) was nm to 2964' and circulated. Dowell mixed their, cemem mud push in the pill pit, and the cemem job started with 11.5-ppg cement. Two hundred and eighty sacks of cemem were mixed and chased. The plug bumped before full cemem returns came to surface. The plug was chased with pretreated mud for drilling out. A Cemem top job cgmpleted the surface interval. The rig nippled.down and rigged up for the next interval. There were no mud related problems while drilling ,this section of well. High viscosity sweeps were pumped as needed. Some viscosity was needed in the mud in the cuttings box to carry cuttings in the vae trucks hauling off cuttings. Total product cost for this interwa c~o to $ 3789. Engineering costs were $125.0. CLU-6 Well Recap PRODUCTION INTERVAL: 6 %" Hole (2964'- 8320' MD) .. After the top job, the diverter was nipp!ed down and the BOP stack was nippled up and tested. All the 4" drill pipe needed to drill this interval was picked up and stood back in the derrick. Shale shaker screens were change to 180 mesh to begin the production interval. Two pyramids shaker screens with a flat screen at the end were installed on each shaker. As the FloPro mud was being built, each batch was circulated over the shakers to removing any slag or clots in the fluid. The BHA was picked up with a 6 1/8" STC-S75BPX PDC bit and R!H. Cemem was tagged at 2871'. The eemem and 10' of new formation were drilled, and a FIT test was performed to an EMW of 19.1 ppg. To start the displacement, a 15 bbl water cushion was pumped, followed by a 30 bbl Safekleen sweep, and finally ,the new FloPro mud was displaced into the hole. Since the fluid was already sent through the 180 mesh screens, the .mud pumps did not have to slow down. Drilling Continued. A 6 1/8" hole was directionally drilled bom 3003' to 5069', where a short trip. was made with back reaming from 5089'-2970'. Directional drilling at 60 degrees continued to 5228' when signals bom the MWD tool became weak. A LoWate dry job was pumped, and the pipe was pulled out of the hole. The next bit to be RIH was a STC-XR button bit. Directional drilling cominued to 6560', where the drag made it difficult to slide. Twelve drams of LubeTex were added to the mud system resulting in a gradual 35% drag reduction. :Directional drilling continued to 6885', Where a short trip of 25 stands was made. There were some ledges encountered on the trip in the hole, but no fill was on bottom. Directional drilling cominued.to the easing point, of 8320' MD. The M-I solids van was. released and rigged down. After circulating the hole clean, a short trip .to the 'shoe was made with back reaming all.the way. The trip.in the hole encountered no ledges, and there was no fill Solids began to build up in the mud causing the gels to increase. The weight increased from 9.3 to 9.55 ppg; some from the dry job. The back reaming during the short trip caused this build up of solids after TD was reached. ' ' Schlumberger was rigged up, and logging operations began after a PJSM. The tools would not go below 7800', so a wiper trip was made. At 7795', a ledge was reamed out. At 8320', the hole was circulated clean, with 1.5" of cuttings coming across the shakers at one point. A dry job was pumped, and a wiper trip to 7784' was made without any hole problems. The hole was circulated clean, and the drill pipe was pulled.out of the hole for another attempt at logging. Schlumberger was again rigged up. for E-Line logging. The logging tool was RIH, and tagged a bridge at 7795'. After attempts to work through it failed, the tool was POOH. Schlumberger was rigged down, and drill pipe was picked up and RIH. Drill pipe conveyed logs were rigged up and RIH. 'Logging was still unsuccessful past 7790'. So the drill pipe and logging tools were POOH. Schlumberger was rigged do.wii, and the drill string was picked up and RIH. The ledge at 7793' was tagged and reamed through. There was a little increase in gas (397-945 units) while circulating through CLU.6 Well Recap I I I I this ledge. At~er reaming to bottom and CBU, the drill string was POOH and laid down to mn 4 lA" casing. The 4 ~" X 12.6 ppf casing was picked up and RIH. At 6899', there were signs of differemial sticking. The mud weight was reduced from 9.9 to 9.5 ppg, and'the trip in the hole was cominued. At 8124', signs of sticking were again present. The trip was stopped to condition the mud m 9.0 ppg. During the conditioning, the casing became differentially stuck. It wasn't until the mud weight reached 9.0 ppg that the casing came free. After the casing pulled free, a concentrations of 3% LubeTex was added to the mud system The trip in the hole was continued to the casing point of 8308' without any more problems. Dowell was rigged up to cemem. The 4 lA" casing was cemented into place with 15.8 cemem. The plug was chased with 6% KCI Brine, but it did not bump. Pressure was held on the plug, and the casing was successfully tested. The rig nippled down the BOPE and nippled up the production tree. During the drilling of this interval, sweeps were used to assist hole cleaning as needed. Total product cost for this interval came to $ 62,834. Engineering costs were $ 8,750. Re~om.mendations For Future Wells: -. The problems of differential sticking while running the production casing were a result of excess drill solid, which in turn increased the mud weight too high and may have thickened the wallcake, The M-I solids cOntrol van was released after TD was drilled. If every operation after TD would have went as planned (smooth trips and logging), .tliere would not have been any problems 'with excess solids. But due to'the reaming that was done several times after.drilling ..TD,.the solids control.van should have been back On'line. .'. ,.. For future wells, if any. problems are encountered after TD and the solids control van is released, putting the van back on line (no matter what it's status) should be considered. This action could~! have possibly saved $10,000 to $14,000 in conditioning. CLU-6 Well Recap i I i ''1 i i ! ! ! 1 I ! I I 1 I I I I I I I ! M-I L.L.C. MUDTRAX DRILLING FLUIDS DATA MANAGEMENT SYSTEM comments: ,. iii i , I . I . [ .... I. I I . i I I ,. I ~1 .I . . , I i , . I . I Typo Size Depth TVD Hole MaxMW Mud I Mud 2 Drilling Problem Days Cost in it it in lb/sal $ Casing 13.375 123 123 N/A N/A Casing 7 2967 2789 8.5 9.50 Water-based None Casing 4.5 8308 5278 6.125 9.90 FLO-PRO None 5038.57 Il 71584.24 I Operator' Well Name- Contractor' PRODUCT SUMMARY MARATHON OIL COMPANY CLU-6 INLET DRILLING Field/Ama' Description- Location · CANNERY LOOP UNIT SEC 7, T5N, R11W, SM KENAI, ALASKA SUMMARY OF PRODUCT USAGE FOR INTERVAL'*' · 0910912000 - 09124/2000, 1847 - 8320 f WATER-BASED MUD SIZE AMOUNT UNIT COST PROD COST ($) ($) I - GREENClDE 55 GAL 55 GA DM 1 1641.20 1641.20 2 - M-I BAR 100 LB BG '156 11.91 1857.96 3 - M-I GEL 100 LB BG 138 12.96 1788.48 4 - LUBE TEX 55 GA DM 18 734.00 13212.00 5 - DESCO CF 25 LB BG I 46.90 46.90 ... 6- FLOVlS 25 LB BG. 82 197~00 16154.00 7- DUALFLO " 50 LB BG 100 .":82.,00 8200.00 8. LO-WATE 50 LB BG 780' '9.75 7605.00 9 - DEFOAM-X 5 GA CN 7 88.1'7 617.19 10 - CAUSTIC SODA 50 LB BG 5 28.65 1'43.25 11 - POTASS'M CHLORIDE 50 LB BG 1042 12.{~8 13108.36 12 - GELEX 2 LB BG 10 11.90 119:00 13 - POLYPAC SUPREME UL 50 LB BG 6 156.70 940.20 14 - SAFEKLEEN 55 GA DM I 443.27 443.27 15 - GREEN-ClDE 5 GA CN 5 149.20 746.00 16 - ENGINEERING 1.00 16 625.00 ~ 0000.00 SUB TOTAL: 76622.81 TA~ . 0.00 WATER-BASED MUD TOTAL COST: 76622.81 TOTAL MUD COST FOR INTERVAL: 76622.81 MudTrax Operator: MARATHON OIL COMPANY Well Name: CLIJ-6 Fie~Ama: CANNERY LOOP UNIT Description: SEC 7, TSN, R11W, SM Location: KENAI, ALASKA BREAKDOWN OF COST BY. PRODUCT GROUP 09/09/2000 - 09/24/2000, -. Water-Based Mud Products 1-Brine Products 2-Common Chemicals $ 13108.36 17.1 3590.91 4.7 9462.96 12.4 3-Dispersants 46.90 0.1 4-Engineering 10000.00 13.1 5-Flbid Loss Agents 9140.20 11.9 6-Lubricant 13212.00 17.2 7-Vbcosifyers ·18061.48 23.6 8-Weight Material Water-Based Mud Total Cost: $ 76622.81 I00.0 21000 14000 7 0.0 0.~ Cost Analysis 0 - 8320 ft 1 2 3 4 5 6 7 8 Water-Based Mud M-I ~..~..c. D~ZLLING FLUIDS DATA Id~ SZSTEM October 02, 2000 . · . DRILLING FLUIDS SUMMA Operator: MARATHON OIL COMPANY Field/Area: CANNERY LOOP UNIT Well Name: CLU-6 Description · SEC 7, T5N, R11W, SM Contractor: INLET DRILLING Location · KENAI, ALASKA Dcpth/TVD ~ it 1847/1738 2983/2504 2983/2804 2983/2804 3747/2702 5227/3435 ~ ~~~~~SPUD SPUD SPUD SPUD FIX)PRO Circ Volume bbl 520 653 328 488 649 734 'CtrcPressu~e m~ 1400 1610 0 0 1000' 1100 Sam~lc From/ ,. ~ , ~~lll[~ , P1TS~ PIT PIT FIX) PIT PITS Mud Wcit lb/ ?¥ e.~ 12 15 8 9 i R600/l~00/I~00 42130125 55/40/34 / / ! / 32/24/22 44/3,5/28 9130/35 13/33/37 // /t 8/11113 13116/18 aTaP mi.a,...,Los rain $olid~ ........ %.Vol ' ' ' 8.4 8.3 7.0 7.0 9.2 9.0' Pt~Mf 0.05/0.4 '0/0,4 / / 0.05/0:4 0,05/0.6 Hardness ca 40 60 200 200 Daitv ' ' PAC./,~2 GELX / 4 DUAL / 10 FLOV / 20 GCID / 1 : DFX/4 SKLN / 1 · REMARKS - , 09/09/2000: Spud Well @ 01:30. Drl tt 1827. Sw~p and Short Trip t/1027. Cont Drlg t/1847. 09/10/2000: Drl t/CSG Pt 2983. Sweep Hole and Short Trip t/150'. Sweep and POOH. RU gr C. sg. 09/11/2000: Run 7" csg tO btm and cmt. Do topjob. 09/12/2000: Building new FloPro mud. 09/13/2000: Displace FloPro mud into w~ll behind 30 bbi Safekle~n sweep. M-i .solids van on line 9:00 PM. 09/14/2000: Dir drlg to 5069', short trip. Adding KCI with water additions. 1 DRILLING FLUIDS Operator: MARATHON OIL COMPANY Field/Area: CANNERY LOOP UNIT Well Name: CLU-6 Description: SEC 7, T5N, R11W, SM Contractor: INLET DRILLING Location: KENAI, ALASKA · I Circ Vol== bbl[ 818 [ 865 I 862 8320/5278 FLOPRO 866 8320/5278 FLOPRO 823 823 I ' PV GCID / I GCID /.1 REMARKS 09115/2000: Use Lowate for dry job, l~ave M-I Solids van remove it aflcr trip. 09/16/2000: Gels begiflning to climb due to clays. Running pH a little low to minimize vise from. clays. 09/17/2000: Calcium rising.due to Lowate for dvf jobs. Solids van removing clays, keeping gels in tine. 09/18/2000: Rig dn solids van at'TI). Solids in mud rising due to backreaming. Gels incr. 09/19/2000: E-logs hit bridge at 7800. Wiper trip ream ledge at 7795', ream to .b~n, circ. 09/20/2000: Attemp 2 Logging Runs. POOH. RD Loggers. RIH w/DP. 2 -':' .... ' '{ ~ ..... I~ .... rl DRILLING FLUIDS SUMMA 'Y Operator: MARATHON OIL COMPANY Field/Area · CANNERY LOOP UNIT Well Name: CLU-6 Description: SEC 7, T5N, RllW, SM Contractor: INLET DRILLING Location · KENAI, ALASKA ~TVD , · fi 8320/5278 8320/5278 8320/5278 8320/5278 Mud Type .~ FLOPRO FLOPRO FLOPRO FLOPRO Ciro Volume bbl 859 835 544 Ci~c Pressure psi 1850 1850 1850 ' ' ~ ~ Prrs BRI~ PV cP 12 14 R600/R300/R200 / / _ _ ~ 65/51/45 30/24/21 Solids ' , .__"6 Vol I0 8.1 i Pi~Vlf _ ' ~ 0/0.3 520 480 100 · DaiZY Mud Cost ' _ $~~~~~~ - . ~ BAR / 21 ' [~[~[~[li~~ BAR / 29 KCI / 12 DUAL / 29 .. ' '- ' ., REMARKS o9/21/200o: RIH AND ATTEMPT TO RUN LOGS THRu'DP. LOGS IHT LEDGE AT 7800' AND WOULD NOT GO FURTHER. POH. TEST BOPS. 09/22/2000: RIH TO 7800'. REAM TO BOTTOM. CBU. PUMP OUT '1~0 7200'. POH LD DP. 09/23/2000: RU/RIH w/TBG t/7000. CiredCondit/on Mud. Cont RIH w/TBG t/8124, Stuck. CiredConditon Mud t/9.0. Add 2% LubeTex. ' 09/24/2000: Cont CiredCondition Mud w/Working CSG. RIH t/8320. Cited RU t/CMT CSG. CMT and Displace w/6% KC! Brine. · , .... ., · .......... ~ .. ., ...... ,. ~ . .,- .~, ....... ~. ~ ,, MudScan ¢~1996; 99 M-tL.L.C, -All Rights Reserved operator: MARATHON OIL COMPANY Well Name: CLU-6 Well Location: KENAI, ALASKA comment: CANNERY LOOP UNIT Depth Casing ft Program 4-1/2" Mud Well]hi lb/gal PV; YP, LSYP Dell0s, Gell0m, Gel30rr' 'AP! FL,- HTHP FL lb/100 fff lb/-100 fff cc/30m Solids, Solids Vol% MBT pH Pm, Pr, Mf Chlorides -Ib/bbl mg/I Depth lO o 25 50 0 I ' ! ' I [ I i i . , i I 1 2o · 4o o -I I' I' I ! ! I i0 20 0 ,' I I 1 1 I. I i lO 2o o ! ! 20 0 5 10 0 0.5 1.0 0 20000 40000 ... . " HYDRAULICS SUMMARY I Operator: MARATHON OIL COMPANY Field/Area: CANNERY LOOP UNIT I I Well Name: CLU-6 DescripUon: SEC 7, TSN, R11W, SM I Con,actor: INLET DRILLING Location: KENAI, ALASKA [~ . '. ' ' '[0~0~2000 0~10~000 0~11~000 0~1~2000 0~13~000 0~14/2000 0~15~000 39/16~00C ~ -- - [ 1847 2983 2983 2983 3747 5227 6083 70~ ~1 2 3 4 5 6 7 8 ...... ' '~ 1 9.1 9.5 8.34 8.34 8.75 8.95 9.0 9.2 -- I 12 ]5 I 1 8 9 11 11 - {18 25 0 0 16 26 24 30 ~1 545 545 '' 0 0 262 206 286 286 1400 1610 0 ,0 1000 1100 1888 1900 445 512 * * 153 132 315 317 670 431 361' ' 688" 725 1052 '* 23~ 149 492 '503 44 '92' * * 151 300 378 594 1473 1814 * * 818 809 ~558 1822 ~l 2x14 ~14 3x12 3x12 2x12 2x12 ~l 16 16 ~10 2x10 14 14 ~~ i 1 * * 1 '1 1 1 320 335' * * 36' 18 82 84 ~ 1 * * 1 1 1 1 352 352 * * 1'73 136 247 247 903 '943 * * ' 206 130 329 337 ~ 485 , . , 485 * * 429' 338 469 469 368 425 * * 3'81 447 ~5' 523 4387 3429 '* * 3274 ' 1626 2942 21'68 ~ 2805 " 2841 ''* * 290i. 3018 2930' 3000 ~1 237 237 * * 254 235 326 326 [ 330 385 * * 350 425 423 '490 I 1485 1132 * * 1504 928 1680 1286 ~ '2805 ' 2841 * ~ 2901 3018 2930 3000 - I 1 i * * 1 1 '" 1 ..... 1 ~ , 236 236 * * 25'3 234 325 325 /lllll~ll~lllill 1 t * * 1 1 1 1 , , 1.0 1.0 * * 1.0 1.0 1.0 1.0 ~ i61 207 ....... ~ 0 0 117' 84 48' 71 · · * 9.99HO 1'1,86 I. 9.58 10.13 * ' * 9.89 10.67 "~ "11.85 10.24 '~ * 10.01 10.791~ Il II I i il i. ! i i HYDRAULICS SUMMARY Operator: MARATHON OIL COMPANY Field/Area: CANNERY LOOP UNIT Well Name · CLU-6 Description: SEC 7, TSN, R11W, SM Contractor- INLET DRILLING Location: KENAI, ALASKA /~ll~llll~]09/17/2000 09/18/2000 09/19/2000 09/20/2000 09/21/2000' 09/22/2000 09/23/2000 391241200£ ~' ~'_ - '~-'- ~ ~.] 8320 8320 8320' 8320 8320 8320 8320 8320 ~ .... ' ....... ]~,~ 9 ~,,~1 . 10, 11 12 13 14 15 16 :' ~.~,i: ~ . ~ ..~,~it~.~',~. ~':~-"" ' '~'.' ' " 'i~.~! ..... ~i.:,~ ~ ...... ~' ' ~'~"~ ~a~',~-.~..~ - "'.'"'-- ~ ~_-- .... ..-_ii] 9.4 9.55 9.6 9.6 9.7 9.8+ 9.05 8.'/ , , 12 12 12 7 12 14 6 1 27 38. 39 48 44 37 18 0 12 14 14 19 21 17 7 : - I .387 .3103 .3049 .1728 .2801 .3499 .3219 1. ~~~~~~~9'6269 9.7539 '14.3391 16.4!41 12.7947 4.9431 .0021 ~lilllll/lll/ll '286 286 '238 235 238 ~-'38 238 238 , 2200 2200 1850 1850 1850 1850 1850 0 ~67 * 25;7 257 257 2fi7' 257 877 * 711 691 755 731 1:59 102 ~l 514 * 363 363 60 60 56 · 760 842 849 759 " 548 237 · 1834 1'896 '1663 1'550 763 339 ~1. 2X12 2x12 2X12 2x12 3x20 3x20 3x20 Illllllllllll[ 14 i4 14 14 ' ' ' ~1 1 * I i 1 1 I 1 ~1 86' * 50 50 8 8 8' , 247 * 206 206 83 83 83 ~1 344 * 243 243 99 100 92 469' * 390 390 390 '390 338 338' , , 473 * 539 560 555 522 358 10 2595 * ' i492 1405 . 1435 1589 2378 73879 - [ 2940 '* 3052 3233 3096 2991 3029 2100 ~l 326 * 271 271 271 271 338 "~3'38."' 446 * 505 532 530 496 358 10 , ~1 1520 * 888 804 807 911 2378' 73879 2940 '* 3052 3233 3086 2991 3029 2100 'i * 1 1 I I 1 1 '325 * 270 '270 270 270 3'37 337 I * 1 1 1 1 1 1 1.0 * 1.0 1.0 1.0 1.0 1.0 1.0 0 0 0 0 '0 ' 0 0 .. [ 11.57 * 1'2;23 12.52 12.65' 12.43 10.87 9.41 ' - [ 11.69 * 12.34 1.2.64 12.76 12.54 10.99 933 ' --- .......... ~ ..... . - ' . 11.69 * 12.37 12.67 12.79 12.56 11.05 9.56 Z~i' ._..~ __' .............. [. i1.,~, * =,' 12.4~ 12.78 12.9 12.67 11.17 9.69 mt I I. I I I I I i i i I I .. ii I i Well Name CLU-6 Description SEC 7, T5N, R11W, Discussion Contractor INLET DRILLING Location KENAI, ALASKA M-I Well: CLU.S 09/09/2000 lTD = 847 it Day 1 Build Spud Mud. RU and Spud Well (01'.30). Continue Drilling t/1827. Sweep Hole t/Assist Sliding. Short Trip t/1027. Continue Drilling t/ 1847. .. Control Vis w/M-I Gel and Gelex. Lower API Fluid Loss w/PolyPac UL. Spud Well ~ 01'.30. Drl t/1827. Sweep and Short Trip t/1027. Cont Drlg t/1847. I i II I . I I I I I i I I ~9/10/2000 ' ITD 2983 it '" I 2 ' ' ' ....... ' Continue Drilling tl 1847 t/2983. Pump HiVis Sweep to Clean Hole w/Good Results. Short Trip t/150'. Pump HiVis Sweep w/Fair Results... POOH and RU t/Run CSG. Control Rheology w/M-I Gel and Gelex. Lower APl Fluid Loss w/PloyPac Supreme UL. Drl t/CSG Pt 2983. Sweep Hole and Short Trip t/150'. Sweep and POOH. RU ii Csg, " I 1I. . I. . I I I I I I I I lilt I , . . i I i i i i i i r 09/il/2~00 "IT D= 2983 fl:' ' ' [ Day 3 .......... '1 ...... RIH w/7" CSG. Cir~tlated and Condition Mud t/YP <20. CMT CSG. Perform top job (cement) on cag, Nipple dn diverter. Pmtreat Mud to Left in Hole ii CMT w/Desto and BiCarb..Bar used for Dowell mud push. NOTE: Cleaning pits-no mud to ~eck in pits. Run 7" csg to btm and ont. Do top job. II I It I . I ~. I . I iii I I . I i .i ~ Iii . .I I I I I , ' ] i i . I I ..... IT~ '" 2'~83 t~' ' I D'ay" 4...................... 09/12/2000 Nipple dn diverter, N/u BOPE. Test BOPE. Building new FloPro mud in rig pits. Will use water in Pill pit to drill out ~ment. Building new FloPro mud. II . . I I I .11 I .[ . I[I.I I I I I I I I . · · I . i I .. I . I 'og/ a0oo "' ' I ................... ' ' ' ' Test cs& RIH w/BHA #3. Tag at 2871'. Drill cant, FC, shoe, formation to 3003'. Circ clean, run leak-offtest. Serv top drive. Displ Safekleen Sweep, FloPro mud into well, Dir drlg.3003'-3469' at mid. Fi~aish building FloPro mud. Displace FloPro mud into Well behind 30 bbl Safeldeen sweep. M.I solids van on line 9.'00 PM. · I I . I '1 I II ' [ . I , i I I. I i I. ....... ' ~ .... Day ' " ' 09/14/2000 ITI)= 5069 it ' ' ' ........ 6 ' ' i i i I '.1 i ii i , I Dir drlg 3471' (shut dn #1 mud pump for repairs) to 5069'. Short trip, cite and baclcream 5089'-.2960'. CBU at shoe, RIH at mid. Lose 31 bbl mud over shakers pump'g fast to unball the bit at 00'20. Dir drlg to 5069', short trip. Adding KCI with wator additions. I I II TD ii . .I I ,i I t II J I '2 I I 09/1 a000' I - 5s95 I ' I i .,. I.. i.. I I I . I I I I . . III II I I II I . ' .'11 Ii iiDayll., i 7 i,.i i i . , i, .i . . i . jl i . i · i i i DDrlg 5071'-5228'. MWD tooi sick, Pump dry job, POH, Service rig. RIH w/button bit. Test motor, MWD, Cut/Slip line, RIH. DDrlg 5228'-5895' at mid. Use Lowate for dry job, having Solids van remove it from mud after trip. Use Lowate for dry job, have M-I Solids van remove it after trip. , . ; I [ I i , I I ,, I I I ii I : , I , ii I I h ,.I , .[ '09/i6/9000 ' ITl)' "6~8S it ..... I Day'S ................ Dir Drlg 5895'-6560'. Add 12 dr Lubetex..Gradual 35% reduction in drag, Dir Drlgto 6885'. CBU, Pump dry job, short trip 25 stds. RIH. Add 12 drs Lubetex for drag reduction. Clays beginning to affect vis, gels. Gels beginning to climb due to clays. Running pHa little low to minimize visc from clays.. , ' ', ;11 I I . ~ ' II,. .... I II I I I . i .... I I ~,' I. I . I . I i I I I ! ~9/17J2000 I'TD= 83i'0f~ [ Day9 I I . i ' i I I Operator: MARATHON OIL CC Field/Ama: CANNERY LOOP Well Name: CLU-6 Description: SEC 7, T5N, R11W, Contractor: INLET DRILLING Location: KENAI, ALASKA I I I I I . i ii Dir Drlg 6885:8320'. CBU, short trip to shoe. Calcium rising due to Lowate for dry jobs. Solids van removing clays, keeping gels in line. ti 09/18/2000 i I I I ii I I I I I TD = 8320 ft I Day 10 . I i Il i , , i, Daily Discussion M-I Well' CLU4 POH, baekrcmn'g to 2965'. CBU, Scrv rig. RIH-no fill Circ hole dean. POH 10 stds, baelcreaming. Pump dry job, POH for logs. Run E-logs.' Rig dn solids van at 'ID. Solids in mud rising due to dry jobs, baekreaming on trips. Build 200 bbl KCI brine in remote tank. Will charge for this KCI on completion section. Rig dn solids van at TI). Solids in mud rising due to backhmming. Gels incr. i i Jl l i I I _. I , , .I . I i I . i, i i i . I I ii I 09/19/~)0 ......... TI) = 8320 ft I' Day 11 ....... ' ' ...... E-logs hit ledge at 7800'. R/D Schl, RIH w/bit and drillpipe, hit ledge at 7795'. Ream 7795'-8230'. Circ. Pump dry job, short trip to 7784', no problems, no fill. Pump dry job, poh for logging, Added dualflo to keep fluid loss in specs. E-logs hit bridge at 7800. Wiper trip ream ledge at 7795', r~am to btm, circ. . I II I I ..II i , i ii I II - .I, . . I . i i i . . . I . I I i , &//2o/2ooo '{/'b ' ' ' l'Da~' .... ' ' .......... " .... .... , . [ ! .Il I... = 8320 R 12 RIH w/Logs t/7800'. POOH. RIH w/Logs {oouldn~ get past 7800'). POOH and'RD Loggers. PU 26 Joints DP and RIH w/4" DP. Control Bacteria w/Greencide. Attemp 2 Logging Runs. POOH. RD Loggers. RIH w/DP. ".' I , I.II I I I o9'/2'1/20~6-, · I Illl· I . I 8356"~i' '' .... I Day' 13 . I i Ill I. I I j I ,I [ ,11 I I I I I . . [ I . iJ [ R]H W/DP. ATTEMPT TO LOG THRU DP. NO CO. POH. TEST. BOP'S. RH-I AND ATTEMPT TO RUN LOGS THRU DP. LOGS HIT LEDGE AT 7800' AND WOULD NOT GO FURTHER, POH. TEST BOP'S. II I I , . I i I ., I J, t . .,I i i , Il I I . I I .................. _PdH. Ream L~dge ~ 7793. Continue RIH. CBU and Baekream t/8320 t/6674. CBU. POOH. RD and RU Floor t/RIIt w/TBG. Control Rheology w/Water and FloVis. R1H TO 7800'2 REAM TO BOTTOM. CBU. PUMP OUT TO 7200'. POH LD DP. I II I . , I..I I I Ll_ , -I . ii Ill . I [ I II. I .I. ~ 0~/23/20(~6' ' ;ID" 8'320R "' ] Day ................... 15 ii I Il 11 I I.. ' I , I I. I I , . I I1. . )l I . I Il RU and RIH w/4 1/2" Production Tubing ff 6899'. Circulate and Condition Mud. Continue RIH t/8124, Differential Stuck. Circ and Condition Mud ff 9.0 ppg. Add LubeTex tt Lower Drag. Came Free. Add Water f/Rheology and Dehydration. ' Control API Fluid Loss w/DualFlo. Build Up Chlorides and Potassium w/KCI. Lower Mud Weight to Help Differential Sticking While RNt. Add LubeTex for Lubricity. (Oil in Mud f/LubeTex). RU/RIH w/TBG t/7000. Cite/Condition Mud. Cont RIH w/TBG t/8124, Stuck. CircffConditon Mud t/9.0. Add 2% LubeTex. 1' I i i. I [ Il ~ ,I I t I ' I I I .... i I I I . I I I . . I III I .I , I ii i . iii I 109/~4/2000' lTD= 8320 R I Day 16 ' '" "'" : ' Continue Circulating and Conditioning Mud While Working 4 1/2" CSG. RIH t/8320. Circulate While RU t/CMT. CMT CSG, Bump Plug w/ 8.7 ppg 6% KCI Brine. RD and ND BOPE..Mud Engineer Released 12:00. Control 6% KC1 while Conditioning Mud. ' ' .. '' 2 i i i i~ ' I Operator: MARATHON OIL CC Field/Area: CANNERY LOOP U~I Well Name: CLU-6 Description: SEC 7, T5N, R11W, Contractor: INLET DRILLING Location: KENAI, ALASKA 'Bar USed ~] Mud Push. ' ' ' Dispose of Old Mud. · ICont Circ/Condition Mud w/Working CSG. R]H t/8320. Circ/RU t/CMT CSG. CMT and Displace w/6% KCI Brine. I; Daily Discussion M-I W~I' CLU..$ " 3 09/08/00 FRI 14:06 FAX 19075646489 ~[arathonOll Co **~ Craig Young Marathon ( .t: DATE: 09/06/00 LOCATION ~: SPUD DAYS: Oil Company AFE#: 970f000 GL: . KB: MOC WI: WELL:.Cannery Loop # 6 .. RIG: GlaclerDr#11ng Rig f FTG:_ DEPTH: (MD). 0 (TVD) 0 CSG SIZE: CSG MD: CSG TVD: SHOE TEST: MAX. SI 0 LINER TOP: PRESENT OP',Rigging Up :::;:;:;:;:;:;:~:;:::::;:::;:;:;:;: Rig up Qlacler Drilling # f on Cannery Loop # 6 EXECUTIVE SUMMARY :,*:::;:::,,:::::::;:::::.,::;::,.;::.,;:.,. (MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE I I I I ~ I I I ,i ] I ~ I I ! PPB_ PPB_ PPB ([OIL WTR pH Pm Pf IVlf CL CA LIME MUD LOSSES (bblflt) BKGD CONN TRIP MAX .................................. !([ BIT# SIZE TYPE OFF FIG HRS FTIHR RPM WOB IOD LB G OT R CPF COMMENTS ([ B!T # SERIAL # PRESS. GPM JET8 TFA ANNULAR VELOCITY BIT HP,) I I I I BHA: Length: DRILL PIPE DESCRIPTION: MAX PULL: ( JARS " MwD MOTOR TORQUE WEIGHT (1.000) I iBHA. pU Rot So Eft (MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. NIS EJW DOG LEG ( OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION ?:00 20:00 ~ ~.00 MIRU GDf~i. Spot pump mom, pits, sub, mudboaf, and carrier. Spot doghouses and scope up sub. RU rig electrical. RD camp and prep for move. ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :~:~:~:~:~:..:~:::~:~:::~:~:~:~ :~:::~:~:~:~:~:~:~:::~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:¢~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:::~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~ AFE: DH TST/CSG COMP TOT LAST PiT DRILL DATE: 00/00/00 I liiiiiiiiiiiiiiiiiiiiiiiiiiiil MUD COSTS ACTUAL,:;:;=;:;;; ............................................ ........... :,:,:,:,=,,,:,:,:,:,.,:,=,:,,,si COSTS ACTUAL li!iii!i!iiiii!ii LAST BOP TEST DATE: 00/00/00 WELL DAILY: 0 CUM: 0 DAILY: f4,272 CUM: f4,272 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: ~]001 09/08/00 FRI 14:05 FAX 19075646489 ltlarathonOll Co *** Craig Young ,. . Marathon [ ,t: DATE: 09/07/00 LOCATION [ .;: : SPUD DAYS: Oil Company AFE#: 970'1000 GL: . KB: . MDC WI: WELL: CanneryLoop#6 RIG: GlaclerDr#1ingRig f _FTG:_ 0 _ DEPTH: (MD). 0 (TVD) 0 ,-- CSG SIZE: CSG MD: . CSG TVD: SHOE TEST: MAX. SI 0 LINER TOP: PRESENT OP~igging Up Continue to rig up on Cannery Loop # 6 EXECUTIVE SUMMARY :;~.~::~.~;~;:;:;~:~;;:~:~::~.:~.:::::~:.~:::;:;~:~:;:;:~:;.~:::~:t:::;:~:::;~:;~;.~:;~.~:::: (MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE I I I I / I I I / I I (OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES (bbl/It) BKGD CONN TRIP MAX '( BIT # SIZE TYPE OFF FTG HRS FT/HR RPM WOB I O D L B G OT R CPF COMMENTS I I I I ( BIT # SERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY , BIT HP) I ::::::::::::::::::::::::::::::::: :;;;;;~;;;;:1:;:;: ;;;;:;;:; ~ ;I ....... :. ,=..:.:.: BHA: Length: DRILL PIPE DESCRIPTION: MAX PULL: ( ,~ARS MWD MOTOR TORC~UE WEmT (1~00) - I IB.A' Pu .or so ,, ......... ,L ............ .I ....... ,J ...... ! .,,,,...., ......... ,,! ........... : ( DEPTH ANGLE DIRECTION TVD VERT. SEC. N/S E/W DOG .LEG MEA. ( OPERAT,ONS ~N SEC~UENCE START END HOURS DESCRIPTION 6:00 ~:00 24.00 Continue to rig up. Erect derrick and rig out floor. Install topdrive rail. Spot beaver slide and catwalk. Continue work on DWKS chain guard. Move In camp and start plumbing In. Start 24 hr operation ~ 06:00 on 9/6/00 :::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::=:~:~:~:~-:t: ..,' ::~:,:~: ~.' ..:..:~:~:., :~:~:,:~:,,'~:~: t :~:~:; :~: ~:~,' ~ :;: ..,'~:~,'~: ~:.,:~:=:~:~ L':~ :~:~:~ ~: :t ~:~:~ :~:~;~ h:t:::::::::::::::::::::::::::::::::::::::::::::::::::: AFE: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 00/00/00 i~i~ili~iilllilli~iiiiiiili~' MUD [iiiiiiiiiiiiiiiiiiiii i[i iiiiiiii iiiiiiiiii WELL COSTS ACTUAL [iiiiiiiiiiiiiii LAST BOP TEST DATE: 00/00/00 ::::::::::::::::::::::::::::: COSTS ACTUAL ................................................ DAILY: 0 CUM: 0 DAILY: f9,456 CUM: 33,728 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: I~001 09/08/00 FRI 14:04 FAX 19075545489 ~larathon0i! Co ~ Cral~ Youn~ Marathon ~ #: DATE: 09/08/00 LOCATION [ $: SPUD DAYS: Oil Company AFE#: 970f000 GL: . KB: MDC WI: . WELL: Cannery Loop # 6 RIG: Glacier Drilling Rig I FTG: 0 DEPTH: (MD) 0 (TVD) 0 CSG SIZE: CSG MD: . CSG TVD: SHOE TEST: MAX. SI 0 LINER TOP: PRESENT OPdnstell Service loop on top drive. Continue to rig up. EXECUTIVE SUMMARY ::::~::!:;:;:;:;:::;:;~;~.*:~!:.~:;:~.~;~::;~;:.~::~.~:;:;:::..::::;:~::::::::;::::::::~:;:::~::::!:~::~!:;:;~:~.~;;:;:;;:~:::~:?:~:~:~:~::5::.~::::;::::::~::::::::;::::~::~:::~:;:;::::~:?:!:!:;:!:~:~`:~:~::~:~;:~::;!~:;:::~:;:!:!~:~:~:~:~?:::::~:;~.:~:.~:~:!::~:~:~:::::::;:;~.~::~::.~;:;:~:h~;::~::::~`:;~:::~:;:;:~.;::::;:; (MVV VIS PVYP GELS WL T 7.5 30 Hr FC CEC SAND SLD BENT SALT DRILLED BARITE I I I I / I I I / I I /a2 I I / PPB PPB PPB COIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES {bbl/tt) BKGD CONN TRIP MAX ........................................................................... dally cum [ BIT# SIZE TYPE OFF FTG HAS FTIHR RPM WOB IOD LB O OT R CPF COMMENTS ( BIT # SERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP] 3HA: Length: DRILL PIPE DESCRIPTION: MAX PULL: ( JARS MWD MOTOR TORQUE WEIGHT (1~00) - I IBHA' Pu Rot So 'Eft (ME.A. DEPTH ANGLE DIRECTION TVD VERT. SEC. ::::::::::::::::::::::::::::::::::::::::::: ~:;:;:::!::;~;~;:;;;~;~;;;;:;:;;5::;:~;~ ;;:;;:;t;!;;;l;.';;;!;l:'.:!:;:;~;;~:;:;;:: ',~;l;::.';::::l;:;!;'-;~:;;!;;;:;;;~;:;".;t ~'~;:~t:;::~;;~5;:;~:;~;~;:~.:::~;~t:5;::;~:~:~;:~!~;;~;:;!;!;!;5~; ( OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 6:00 24.00 Continue to rig ,up on CLU~, Complete repairs on DWKS clutch/chain guard. PU top drive. Complete camp Installation. NU diverter and function test, Fill pits. ,, :ili:~:~:,:~:,::li:ili:l:l;ililili:lll:l:i:l:l:ili:lllll:l:i:ih:i:;:i:l:i:i:;:~:,:,:~:,':,:~:,:~:,:~:~:l:i:i:;:;:;:i :~:~:~: ~:~: ~:,:~: ~:,:~:,:,:t: ::~:~:,:~:~:,:,:~:~:::::¢::~::: ~:~:,:~:'-:::::'-:::::;:~:::,:~:::~: a. FE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 00/00/00 DALLY: 0 CUM: 0 DAILY: 20,093 CUM: 53,82~ NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: JAR/DMT ~001 09/09/00 SAT 06'58 FAX 190756.46489 l~arathon011 Co *~* Craig Young ~,- Marathon ii.' ii: : DATE: 09/09/00 LOCATION [ $: SPUD DAYS: f Oil Company AFE#: 970f000 GL: . KB: . MDC WI: WELL: Cannery Loop # 6 RIG: Glacier Drilling Rig 1 ._FTG: 440 PBTD_ 440 (TVD) 439 CSG SIZE: CSG MD: . CSG TVD: SHOE TEST'~" MAX. SI 0 LINER TOP: . PRESENT OP:Slide Drilling ~ 440 ft. Complete rig move. Drill to 440 ft. EXECUTIVE SUMMARY ;~ :~ ;;;., ~::;: :::~ ::;; :,.: ;;;;;:~: :: ,..; :~:,.: ,. :~: ::.,::: :; :;;: :: ::::: :~::: .,:; :~: :: ::::;: ::;: ;:,.: :::: ;::: ::: ~ :::::: ::;:;: :::::: ,,: ~:::!::::: ~:::::: ~,.: ,. ::; :;~::: :::: ::.,:;::: .,::::: ::.,:: :: ::;:; ::;:::: :~:~:~: !:~; w.: ~:~:::=: ~:: :;: ::: :.'::; .';:::;:; :;:: .' ::: :::: ~:~:~::: ::~:~;;; :::: ::.*:;:!: :: ~;~:~:! :?; ;:! :~; :;: :::: ;; ;;:;; ;: ::;: ::;:;:~:;: .'; :;: :: {MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLO BENT SALT DRILLED BARITE (~OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES {bbl/lt) BKGD CONN TRIP MAX .................................... dally cum [ C BIT# SIZE TYPE OFF FTG HRS FT/HR RPM WOB IOD LB O OT R CPF COMMENTS ...) BHA: 1 Bit, Downhole Motor, Stab, MWD, Pulser, XO Sub, 3.hwdp, Jars, 23.hwdp, XO Sub, Length: 904.58 DRILL PIPE DESCRIPTION: MAX PULL: 35 · (' JARS MWD MOTOR TORQUE WEIGHT (1'~00) - ,., ' 60 t5f61013 60 ew804063 60 m2058 ]BHA' Pu 35 Rot 30 So 25 Eft ,.,....-..,...I.., ........... I .... :... !,, . ! ..... ;.. .... !..,., ...... !: :, (.MEA. DEPTH ANGLE DIRECTION TV" VERT. SEC. NIS E/W DOG LEG ,( OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 13:00 7.00 Rig accepted ~ 06.ff]O 9/8/00. Finish rigging up top drive service loop. Inspect top drive motor. Load rig floor with tools. Hang tongs, Install mousehole. 13:00 17:30 4.50 Pick up 74 Jta dp and 24its hwdp. Stand back in denfck. 17:30 t8:30 1.00 MU conductor bha. Test mud. pumps. 18:30 21:00 2.50 Mix mud. Install last Joint of diverter line. 21:00 22:30 . 1.50 Clean out conductor w/12 I/4 blt to 91 ft. 22:30 23:00 0.50 POOH and LD t2 t/4 blt and subs. 23:00 0:00 1.00 Adjust brakes. 0:00 1:00 1.00 I~U 8 t/2 blt and BHA. 1:00 1:30 0.50 Orient and test mwd. 1:30 5.~0 3.50 RDRL 91 ft. 350 ft. , 5:00 6:00 1.00 SDRL 350 ft- 440 Fuel used last 24 hrs. [] 200 Fuel on loc= 2500 AFE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 00/00/00 DALLY: 0 CUM: 0 DAILY: 80,644 CUM: 134,4~5 HO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: JAR/DMT ~001 09/10/00 SUN 07:58 FAX 19075646489 MarathonOll Co *** Cralg Young Marathon ~.. #: DATE: 09/10/00 LOCATION . ~: SPUD DAYS: 2 Oil Company AFE#: 970f000 GL: . KB: . MDC WI: o WELL: Cannery Loop # 6 RIG: Glacier Drilling Rig 1 _FTG:_ 2,101 DEPTH: (MD).. 2,541 (TVD) 2,101 CSG SIZE: CSG MD: . CSG TVD: SHOE TES~ MAX. SI 0 LINER TOP: . PRESENT OP:Dr/g ~ 2541 ft Drill 440 to 2541 ft EXECUTIVE SUMMARY ::::::: ::;:;: ::~:: :;: ::: ::;:::: :::::. :;: :~: ::,.;:; ::;:::: :: ~ :;; ::: :: .,::::::::;:;:::~: ~:: ..::::; ::;::: :::;:;: ~.,; .,: ,,; ,,;::.,: ,, ::: t: ;:!::: .': ;:',; ', ::: ;:: :::; :~::: :: .':: :~: ;::: .':::: :.': :: .':: ::;:; ::: :: :;:: :~:; :::::: ::: ?: ;:;: :;~: .':::~::: :;~ :~: ::::!:: :~: ~: :: :::::: :: :::: :::: ::~ :~:~: .' :~:;::::: !::: ;;:: ::::'.: :: :: ;:!: ?:: :~::: .' :.':;:.': :::::: :mR: !: :::; ~MW VIS PV YP GELS WL ; 7.5 30 Hr FC CEC SAND SLD BENT SALT DRILLED BARITE 0.1 148112 I'1 = 1 3o I10.01 I ./ I I2 132 2.0 ] 5.5 I / PPB 2,065.4PPB_ PPB lOlL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES Ibbl/It) BKGD CONN TRiP MAX · .... o..! ...... I ( BIT# SIZE TYPE OFF FTG HRS FT/HR RPM WOB IOD LB O OT R CPF COMMENTS * I '°° I I I I I :[. BIT # SERIAL # PRESS. GPM. JETS IFA ANNULAR VELOCITY BIT HP] I I13f82 1510 445 J 14 f4 t6 I 0.500 I 174.2 I I I ::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::: ...... ;..;.;.;.;.;. ;:;: ;;:;; :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::: BHA: t Blt, Downhole Motor, Stab, MWD, Pulser, XO Sub, 3.hwdp, Jars, 23.hwdp, XO Sub, Length: 904.58 DRILL PIPE DESCRIPTION: MAX PULL: 70 (~ JARS MWr~ MOTOR TORC~UE WEIGHT (~000) 30.0 1151~1013130.0 1ew~040~31 30,0 Im2058 I I BHA= Pu ~3 Rot 57 So 53 ~ ,,, , · i ........ I ...... l' ' '1 ' '1 ........... I I i I · · I ..... I .................... : ~ MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. NIS E/W DOG LEG 1,844.00 46.800 55.10 t,706.57 529.62 318.11 423,49 4.08 t,906.00 48.220 54A0 1,748.45 575.30 344.50 460.83 2.44 2,000.00 49.870 54.00 1,810.06 646.25 386.03 . 518.40 1.78 ( O;,ERAT~ONS ;N SECmENCE START END HOURS DESCRIPTION 6:00 10:30 4.50 Rotary and slide dri 440 o 900. 10:30 11:00 0.50 Circ clean. f ~ :00 f2:00 f .O0 Change top drive saver sub. 12:00 f 6:30 4.50 Rotary and slide dH 900-1455 16:30 17':00 0.50 Change top drive grabber dies. 17:00 f7:30 0.50 Rotary ands#de dr11455.15f6. 17:30 f8:00 0.50 Change out damaged saver sub. 18:00 21:30 3.50 Rotary ands#de dri 15t6-1827. 2f:30 23:00 f.50 f3 stand short trip. 23:00 23:30 0.50 Rotary and slide dH 1827- f847. 23:30 0:00 0.50 Repair MWD. 0:00 6:00 6.00 Rotary and slide dr11847- 2541. fuel used last 24hfs = 1100 gal fuel on loc = 4200 gal :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: AFE: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 00/00/00 DALLY: 2,461 CUM: 2,461 DAILY: 52,278 CUM: 186,743 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: JAR I~001 09/11/00 I/0N 06:46 FAX 19075646489 l~arathonOil Co **~ Craig Young ¢ ~arathon , . #: DATE: 09?t't/00 LOCATION ~: SPUD DAYS: 3 Oil Corn@any ArE#: 970~000 GL: . ~B: MOC WI: . WELL: Cannery Loop # 6 RIG: Glacier Drilling Rig f FTG: 442 DEPTH: (MD). 2,983 (TVD) 2,319 CSG SIZE: CSG MD: . CSG TVD: SHOE TEST: MAX. SI 0 LINER TOP: . PRESENT OP'J;unning 7' casing Drill to 2983. Run 7' casing. EXECUTIVE SUMMARY :.,:;;;;.,;:;~;:::;~;~:;;;;:;;;;;:;::; ~;::::::~;:~:~:~:~:~?:::::::::|:|:|:~:~:::::;~::;:.~:::~:.~:~:;:~:::;:::~:::::;:~:::;:;:;:~:!:::::::!:~:::;:!:::~:;:.~:::~:;:~:::::::::;:=:;:;:~:~:;:::;:;:;:::::::::.~:~.:;:;:~:~:~;::.~:~;~:~:.~:::::::~:;:~:::::~:.~:;:~.:;:::~:~:~:~::~.~:~::::;::;:::~:;:::~:.~:~:;:::::;:::~:~:::.~:;::::;;~;:::;:;:::::: (MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE 9.S 1,591 '/51251 ~3 I 33 IW0.41 I I I I 2 132 2.5 ] 8.5 I I PPB 2,033.5 PPB .PPB (~OIL WTR pH Pm Pt= Mf CL CA LIME MUD LOSSES {bbltlt) BKGD CONN TRIP MAX ................ ~ .... ,o,,o, .... 0.0. ..... 0~ ..... .~0...!...,.°.... I~-',, ...~.= ....... I .............................. I .......................... ! ! :-.. !.: .... :...! ....... I .................... 1 ...................................................... 1 ....................................... [ BIT # SERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP) f lw3f82 fSO0 I 445I f4f4f6 I 0.500 I I 174.2 ::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::: ' ....................... = ................................................................................................. i'i'i'| ..... ~,~,~,~ ............................................... BHA: 1 Bit, Downhole Motor, Stab, IVlWD, Pulser, XO Sub, 3ohwdp, Jars, 23-hwdp, XO Sub, Length: 904.58 DRILL PIPE DESCRIPTION: MAX PULL: (~ JARS MwD MOTOR TORQUE WEIGHT (1~)00) 46.5 f5f6fOf3 46.5 ew804063 46.5 Im2058 I I BHA: Pu Rot 'So Eft (MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. NIS E/W DOG LEG 2,7f0.00 60.370 52.10 2,f84.90 f,248.07 746.87 f,500.f2 fAO 2,77f.00 60.480 53.00 2,2rS. Of f,3Of.f2 779.f3 f,042o23 f .30 2,939.00 60.650 52.20 2,297.57 f,447.43 858.00 f,f58.4§ 0.43 ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ;~;5;~;;~;!;5!~!~;;!;~;;~;!;?;~;5~;5;~;;;!;;~!;~;;;~;;~:;~;~!~;~;~;!;;;;;!;?~;!;!;5~;~!;!~!~!;!~!;!~!~!;!~;!~!~;~;~!;~!;!;!~!;!~!~!~!~!;, ~ OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 f0:30 4.50 Rotary and slide dri 254f o 2983 ft. 10:30 f2:00 f.50 Clrc sweep and condMon. Slug DP. f2:00 f 6.-00 4.00 Short trip into conductor. f 6.~0 f8:00 2.00 CIrc sweep and condition hole for casing. Slug DP. rS:00 2f:30 3.50 TOOH laying down 5' HWDP. 21:30 22:30 f.50 LD directional BHA. 22:30 f:30 3.00 Clear floor and PU casing tools. Change baeles. Safety Mtg. f :30 6:00 4.50 Run 7' casing. fuel used last 24 hfs = 900 fuel on loc = 3300 :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~,FE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 00/00/00 DAILY: 2,577 CUM: 5,038 DAILY~ 28,437 CUM: 215,180 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: JAR ~00'1 09/12/00 T~E 07'10 FAX 19075646489 MarathonOll Co..,~',:'~, ~'' ."~. ......... -~-~ Craig Young Marathon ( '#: ..' DATE: 09/'i2/00 LOCATIO S: ~ SPUD DAYS: 4 Oil Company AFE#: 970'/000 GL: . KB: . MOC Wh WELL: Cannery Loop # 6 RIG: Qlasler Drilling Rig '/ FTG: DEPTH: (MD). 2,983 (TVD) 2,3'/ csGS,,E: 7.000 CSGM~ 2j9C,4. CSG~VD: 2,3~£ S,OETES'~" MAX. SI 0 LINER TOP: . PRESENT OP:Welding on Bradenhead Finish running and cementing 7' casing. Nipple down diverter and Install starting head. EXECUTNE SUMI~RY (MW VIS PVYP GELS WL T 7.5 30 HT FC CEC SAND I I. I I ~ I I { .! I I ~= { I I PPB PPB PPB, (O{L WTR pH Pm Pf Mf CL CA LIME MUD LOSSES ..' ......................................... d,~.. .=um { I I . . 1. I. ! .... 1 ........ { ............ !..~..~ ! ...... ! .................................................... ! ................................... ~. ..................... ( BIT# SIZE TYPE OFF FTG HRS FT/HR RPM WOB IOD LB O OT R CPF COMMENTS { II { { { { BHA: Length: DRILL P{PE DESCRIPTION: _MAX PULL: _ ( JARS MWD MOTOR TORQUE WEIGHT (1000) · ..... } {BHA: Pu -Rot So E~ ...,..,.,.,...J~. ......... ,..,.I.,.,.,..~ ,,!, ............. 1,,. ....... ,! (ME~ DEPTH ANGLE DIRECTION TVD VERT. SEC. MIS E/W DOG LEG 2,7f0.00 60.370 52.f0 2,184.90 '/,248.07 746.07 '/,000.f2 1.40 2,77'fo00 60.480 53.00 2,2tS. Of f,30f.f2 779.'/3 f,042.23 ''/.30 , 2,939.00 60.650 52.20 2,297.57 f,447.43 868.00 f,f58.4§ 0,43 ::::::::::::::::::::::::::::::::::::::::::: ;:;:;;;:;;;:;;;:;::~;:;;;:;;;;~:::~:;;;;:t;:~;;:;t;:~t~T;:~:~:;~;~;;;;;~;~;; ;:;,*;;;;;~;;;;:;:;;;::::;..;:::::;:;.,:t:~ (. OPERATIONS IN SEQUENCE START END HOURS, DESCRiPTiON , 6:00 6:30 0.50 Finish running 73its 7' 23 & 26 ppf casing 6:30 8:00 1o50 Clrc and condition hole for cmt. 8:00 9:30 1.50 Cement 7' csg w/ 25 bbis spacer followed by' 2~10 ~x Iltecreta mixed ~, 1t.5 ppg. Maintain good returns ~hroughout Job. No positive Indication of cement in returns. PH Increase to 10.2. land plug ~ 09:25 and test csg to 500 psi for 10 min. RIS pressure and test float equip. 9:30 17:30 I~.O0 WOC. Wash down and RD cmt equip. Clean pits. Prep for top Job. Recleve and strap 4' DP and 3 '//2 HWDP. Run 105'of. 1' line pipe into conductor. Change pump #2 Dennison and test. Pre Job 17:30 18:30 1.00 Pump top Job of 27 sx litecrete mixed at 11.5 ppg. Job witnessed by AOGCC rep Jeff Jones. 18:30 19:00 0.50 Wash down and RD cmt equip. f9:00 6:00 f 1.00 Slack off on casing. Rough cut 7' and ND diverter. Final cut 7' and 13 ~/8' conductor. , .weld on f 1' 5M x 7' SOW b.radenhead. Change baeles and load out handling tools. Fuel used last 24 hr~ = 400 Fuel on location = 2900 :::~:::..:i:,~:~:~:::::::=::::.=:~:=:::::::~:~: ~:::~:=:::::~:i:::::::~:~:~:~:~:::::~:~:~:=:~::::~::;::!~:~:::=:::~:~:~:.`:::~:`.:~:::::::::::::::":::~:=:::.`:~:::::":::::~:::=:~:~:=:::::~ AFE: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 00/00/00 .iiiii ~ i i i i ~ i !ii~i~ 1 MUD COSTS ACTUAL I ~ ~ ~ ~ ~i~: ~ ~ii!i!!~l COSTS DAILY: 946 CUM: 5,984 DALLY: 123,585 CUM: 338,765 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: JAR ~]00! 09/13/00 Wt~D 06:10 FAX 19'075646489 Marathon011 Co ~....~i.~'"'~, ./..~.~ -,*-, Peter Berga r~a~at~o~ ~ ~: ~ ~^,~: o~3~o ~OCA~ON~. ~: · S~D DA~: ~ Oil Company AFE#: 970f000 GL: . KB: . MOL WI: . WELL: CanneryLoop#6 RIG: QlaclerDr#11ngRIg f FIG: 0 DEPTH: (MD).. 2,983 (TVD) 2,3f9 CSG SIZE:* 7.000 CSG MD: 2,964. CSG TVD: 2,322. ~HOE TES'~": MAX. SI 0 LINER TOP: . ,,, PRESENT OP~ICK UP NEW DRILLING ASSEMBLY INSTALL WELL HEAD COOL AS NEEDED o NIPPLE UP BOP o TEST BOP AND RELATED EQUIPMENT- TEST 7' EXECUTIVE CASING AT 1500 PSI. o PICK UP 4' DRILL PIPE AND STAND IN MAST- PICK UP NEW BHA SUMMARY (-MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD SENT SALT DRILLED BARITE 0.5 1591151251 t3 / 33110,41 I / I I2 132 2.5 J 8.5 I I PPB 2,033.5 PPB PPB COIL WTR pH Pm Pf W CL CA LIME MUD LOSSES (bbltlt) BKGD CONN TRIP MAX ~ BIT # SlUr; TYPE OFF FIG HRS FI/HR RPM WeB I O D L B O eT R CPF COMMENTS I 18.500 IMI=ISTODCPI2,98312,892128.00.1103.31 35120 12,2,Wr~E,O, NO, r~ ] Irerunable (- BIT # SERIAL # PRESS. GPM JETS IFA ANNULAR VELOCITY .BIT HP~ f /W3t112, oo I,!1414't6 10.500 181.9 :l:l;;:l:t;I;l:~;l::;:;:;::l;I;:; :;J;I;:;I;J;I;:;I;;;I;:;I;J;I;IJJ;, I o,' 'l'l'l'l'l'l'l I'1' ' 'l'l'l'l'l'l; 'l I J J ' J J; I · . · ; ;. ; ; '; ; ~;~;~;~;~;~;~~:;~~~;~;~;~;~;~;~;~;~;~~~;'~~j;~;~;~;~;~;~~~;;~;;~~~~~:~;~~;;~;~;~~~;~~~;~;~;;~~;~~~;~ BHA: Length: DRILL PIPE DESCRIPTION: MAX PULL: ( JAR8 MWI:~ MOTOR, TORQUE WEIGHT (t'~100) I I I I "i I I BHA: P. Rot So er ~ MEA. DEPTH 'ANGLE DIRECTION TVD VERT. SEC. N/S E/W DOG LEG 2,710.00 60.370 52.10 2,184.90 1,248.07 746.87 f,000.12 fAO. 2,771.00 60AIIO '53.00 2,215o0f 1,30f..12 T[9.f3 1,042.23 t.30 ~,~3~.00, ~0.~50 52.20 2,2;;'.~ 1,447.,~ ~..00 1,f..4e 0.,~ :::,.:!:::::::.,;.,::~:~:;:;!:::::::::::;;:;:; ,;::!:!:!::;:;;::;:;:;:;:;:;:;!;!;:;:;:; ~:;:~!;:~:;:;:~:;:;:;~';:~;;.';:;:;:;:;:~:;~;:;~;~;:~::::;~;!~;~;!:!~!;!:!:!:!;!;~ ',; ...o ........ .~ ........ .,.,.,.o.!.:.!.:.,.:.,.:.!...:-.-:.... ..... :;:;~:.,~:~.,~.,;:;:;:;:~.,:::::~:~:::!::::; :.,:,.:?:::~:::!:::::!:!:!;.,:::::.,:::~:::!:: (~ OPERATION8 IN SEQUENCE START END HOURS DESCRIPTION 6:00 7:30 1o50 WELD ON 7' X ~1' WEL.L HEAD 7:30 I 1:30 4~00 COOL WELDS ON WELL HEAD - PICK UP 4' DRILL PIPE AND STAND BACK t 1:30 12:00 0.50 TEST WELDS ON WELL HEAD AT 2000 PSI. (TESTED OK) 12:00 20:30 8°50 NIPPLE UP BOP AND RELATED EQUIPMENT- CHANGE 4 t/2' RAMS IN TOP QATE TO4' 20:30 0:00 3.50 TEST BOP AT 250 PS! LOW AND 3000 PSI HIGH- TEST AND RECALJBRATE GAS DETECTORS o:0o o:3o 0.50 PuLL TEST PLU; AND INSTALL WEAR ;~NO 0:30 t:30 1.00 RIG UP AND TEST 7' CASING AT 1500 PS!- HOLD FOR 30 MIN. (TESTED OKAY) 1:30 4.30 3.00 CONTINUE To PICK UP 4" DRILL PIPE 4:30 6:00 1.50 LOAD STRAP AND TALLEY 3 ~/2" HWDP AND BHA. MAKE UP NEW DRILLING ASSEMBLY :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: AFE: DH TST/CSG COMP TOT LAST PiT DRILL DATE: 09/12/00 ;~;;; ;;;:; ;:::~:;:: .:. ; ::::: :~:::::: :;::: . I~;~;~. ~...~ .; ~;~;~;~;~,;~. ,t MU D COST8 ACTUAL]. ......................... ~ ; :.' ~: ~.*'..' :;~.*.' ~; I WELL COSTS ACTUAL li!i!ili!i!ilili LAST. BOP TEST DATE: 09/12/00 DAILY: 5,722 CUM: 11~,706 DAILY: 27,845 CUM: 366,610 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: DARRELL GREEN I~O01 09/14/00 THU 06-32 FAX 19075646489 ~[arathonOll Co ~~L ~ Peter Berga Marathon ( #: DATE: 09//4/00 LOCATION( S: SPUD DAYS: 6 Oil Company AFE#: 970f000 GL: . KB: . MDC WI: . WELL: Cannery Loop # 6 RIG: Glacier Drilling Rig I FTG: 1,117 .. DEPTH: (MD). 4,100 (TVD) 3,096 CSG SE:E: 7.oD0 CSG MO: 2,964. CSG TVO: 2,32:~: ~HOE TEST: 19.01 MAX. SI 1,245 LINER TOP: PRESENT OP.~RILL AHEAD :::~:::~:::;:::~::::..~::::::.~::::~:::::::~;:~..;~:~::~:..~:;:~:~:;:~:::::;:~;~;~::~::~:~:~:;~:~:::::~:~:~:~:~:~:~;:~:~;~:~:~:::::;:::;~::~:~:~:~:~::~:~:~..;~:~=;~:;:~;;~:~:~::~;:~::~:::~:~:::~::::~:~:;:;:;~:;:::;:~:::::;~:~:~.~ PICK UP DRILL PIPE TO DRILL AHEAD - PICH UP BHA AND RIH- PREFORM LEAK OFF TEST- DISPLACE WITH EXECUTIVE PLO PRO MUD- DRILL AHEAD FROM 2,983' TO 4,100' SUMMARY :~.:~:::::~::;~:;~;:~:.~;~.;~.~;::~::.~:~;:;:;~.~;:;=:::::~;:~;~:.~;!~.;;~;:.~:;:;~:;`~;:~::;:::;:;:;:~.::~:::;::;:~::;::~;;;~;;~:;:;~|;~;~.;;~:;.~::~;~.~;::.~:;:~:~:~:;:;~::~.~::;:;:::::;~;;;;~:~;;:~:;;~;:;~:~::::~:;;:::::::`~:;~.~::;::.~::::~:;:~.~:;:;;~:~:~::::;:::;:: (MW VIS PV YP GELS WL r 7.5 30 Hr FC CEC SAND SLD BENT SALT DRILLED BARITE e.z I~1 e I,~1 = / - I&ol I / I II /32 0.3 I 2.8 I / 9,4 PPB 48.7 PPa PPB (OIL WTR pH Pm F'f Mf CL CA LIME MUD LOSSES (bbl/tt} BKGD CONN TRIP MAX o.o I=~.;I =.~ I o., o., ] o~, 128'°°°1 ~oo I Idaily cum I 4 ] :~:~:::::;:::::;:::::::::~:~:~:;:::;:::~:::::::~:~:::~::..~:::::~:~:::::;:::::~:::~:::::~::~.~:~:..;:~;~::;:;:;.~;~:::~:~:;:;:~::=;;;:~:;:~;?;:;:;~;:~:~;:;:::;:~:;:;:;:;:~:;~;;~:~:~;~:;:;:~.~..;:;:;:;:~:::;:;~:;;..;;:;~.~::;~;~:~::~.~::~:::;:~;~:;`~;:r~:;:::~:::::::~;:::~::;:::;:;~;::~:;..;:~:;::::::~:::~..:..;:;:;:;:~..::::;~ ( BIT # SO'I= TyPE OFF FTG HAS FTIHR RPM WOB I 0 D L B G OT R CPF COMMENTS (: BIT # SERIAL # PRESS. GPM JETS IFA ANNULAR VELOCITY BIT HP~ BHA: 3 6 I/8' BIT, MACH IXL AKO .80 DEG, STRING STAB, MWD, PULSER SUB, 4.3 I/2' HWDP, 4 3/4' DAILY JARS, 26.3 Length: f/2" HWDP, XO .SUB, 1,020.54 DRILL PIPE DESCmPT~ON: 26O J=- 4' DRILL PIPE, MAX PULL: ( JARS MWO MOTOR TORQUE WeGHT 0000) - t0.0 114,~0051 t0.0 F.O_07 I' t0.0 IMf-O~ '1 IBHA: 28 Pu Rot So i' '1'1'1'1' 'l' 'l~.' '~' '-'~=1'! .... ;I;I.~;' ! · · I t i I I · I · ~;; 212;;; ;:;;;;;;;;;;;; ·;;;;;;; (M~ DEPTH A, NGLE DmECT,ON, ?VD V=RT. SEC. NIS 2.710.006O.37O b'2.t02.184.OO 1,~. 8.0~ 746.67 1,000.12 1.40 2,,~.OO 6O.650 52.20 ;,.~97.~ 1,447.,=6..CO 1,156.4~ . O~ :.,:l:::.,:;:;:,,:t::;t;;;::::::t;:;:;!:::;::: =;t:;:.';:;::-*;e;-';:;;:!:'-::;;;:;:;'.;'.;:: ;:;;;t;;;t:e;.'::;e;::::;:l-:;;!;:;;;'.;.l;.';.'::;!:t;:;:;:;;;t;''q;'t;t;:;t;t:~:;;t:!;~ e;;;:;;;~.;:;~.;:;.~;:;:;;~=;:;:;.~;:;~.::~.~;;.~;.~;:;:~;.~;~.~;~::;!~!~t;!~e;=;~;~;t;! ;";";:;;;:;";";;;";;;=;;::;!;!;":;;;;~:":~ ( OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION , 6:00 8:30 2~50 PICK UP AND MAKE UP NEW 61/8" DRILLING ASSEMBLY 8:30 fO:CO f.50 STRAP 26 JO!NT~ OF 4' DRILL PIPE- PICK UP AND STAND BACK IN MAST fO:O0 f0:30 0.50 ADJUST TORQE ON TOP DRIVE SET AT t7,000, FT. POUNDS t0:30 12.'oo t.50 RfH (SLM) TAG CEMENT AT 2,6?I' I2.~0 t3:30 1.50 FINISH BUfLOING MUD VOLUME- CLEAN PILL PIT 13:30 15:30 2.00 DRILL CEMENT FROM 2,671' TO TOP OF FLOAT COLLAR AT 2,881'- DRILL FLOAT COLLAR AND CEMENT TO FLOAT SHOE AT 2,g83'- WASH AND REAM 8 1/2' OLO HOLE TO , 2,983'o DRILL NEW 61/8' HOLE TO 3,003' 15:30 16:00 0.50 CIRCULATE HOLE CLEAN 16:00 I 7:00 1.00 PREFORM LEAK OFF TEST WITH 8.8 PPG MUD- EMILY AT f. 9.01 PPG f?:O0 18:00 1.00 SERVICE RIG AND TOP DRIVE f8:00 t9:00 1.00 WORK ON TOP DRIVE COUNTER BALENCE SYSTEM f9.'00 20:00 !.00 DISPLACE WELL WITH 50 BBI- SPACER AND FLO PRO MUD 20:00 6:00 10.00 DRILL AHEAD WITH BIT# 3 FROM 3,003' TO 4,100'- ADT 6.3 HOURS AFE:.DH TSTICSG COMP TOT LAST PIT DRILL DATE: 09//2/00 . :1 a; ;;: :;;; ....... · ;=;' ~'~';~ ':'; ACTUAL ..,, ' ....................... I WELL LAST BOP TEST DATE: 09/12/00 :;=I=A=;,~==. -I.lll=l:;,=, = I;;; I; I; ;: · · '1'1' = =: ';' · · = ............................ ]MUD COSTS I .......... ... ................... COSTS ACTUAL : l:=:~:l:.': :=:~:: :::1: DAILY: 9,476 CUM: 21,182 DAILY: 57,952 CUM: 424,562 NO ACCIDENTS REPORTED TODAY i DRILLING SUPERVISOR: DARRELL GREEN ~001 09/15/00 FRI 06:09 FAX 19075646489 . .. Marathon011 Co '.." .' ~ Peter Berga " ~, Marathon (' '#' ~0 DATE: 09/15/00 LOCATIO 'S: '~ SPUD DAYS: 7 Oil Company AFE#: 970'1000 GL: . KB: . MDC WI: o ,, WELL: CanneryLoop#6 RIG: Glacler Drilling Rig f FTG: 1,128 DEPTH: (MD)_ 5,228 (TVD) 3,438 CSG SEE: 7.000 CSG MI~: 2,964. CSG TVD: .2,322. SHOE TEST: 19.0'1 MAX. SI 1,215 LINER TOP: . PRESENT OP'.POH DRILL AHEAD TO 5,059'° POH TO 7' CASING SHOE, PUMPING OUT OF THE HOLE, CIRCULATE BOTTOMS UP- EXECUTNE RIH TO BOT'rOM- DRILL AHEAD TO 5,228% MWD SIGNAL FAILURE. POH SUMMARY . :;;!:.,;,.;:;.,;:;;;,.;;;::::;;;:,,;:;;;,, .,,;;:;; ,,; ;; ,,: = ;; ;;; ,,; ,,:,,;:;; ;;:.,; :;: ;:: ~,:;;;;:;:: :;;; .,;;;f .'; ;;; ::: :,~ :.,;.,; ;: .-:.'; .'; ;.': ;.,: ;;.* ;:;:: :: .':: ;.':: ::; .';:; :; I; .'; :;.';;::;;; ~: ;;., ;; :.'; .' ;; :.': .';.' ;.' ;.';., :.'::; ~;:; ~; :; ~ ;;; .'; .';: :; ;;: ~; .':: ;~ ;., :: :., :: ;.,;.,;., ::; .~:;: ~;~; ~;~; ~ :;:;: f ;~;; ~ ,,; ;;., ;: ;: :;:: :.*:: :!: .,:: ;~,;.,; .,: .,; :;., ;:: t: .':;; !;.*;: ;:; .':.,: ;:., ;:;; ;.':: (wv v= pvyp GELS W,..T ?.5 30 HT ,:C CRC SA, D SLD "E,T SALT DRILLED eAmTE (OIL WTR pH Pm Pf m CL CA LIME MUD LOSSES {bbte) BKGD CONN TRIP MAX ..°....°.. .... ~.~.~ ...... ~.o,.. .... ~.,.. ...... ~..!,.,,... o....~ ..... ?. 0.°.. I...~.~. °... ......... !.~ ...: ..... ~? ..... ! ............................................. ,.,..,,. ................... ,., .......... , ..: .... ! ...... :....!...: ..... !...: ............ .-. .... ! ..... : ..... ! ........................... I .................................................................................. I ..................... ! ..................... [ ..................... ~ BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB I OD LB G OT R CPF COMMENTS (' BIT # SERIAL # PRESS. GPM JETS TFA, ANNULAR VELOCITY BIT I~P~ 3 JSOO74 f100 I 204 121212t010 I 0A85I I 17.4 ' , ' . ;j:l;;:.';Z;Z:t;.';l;~;l;;;:;t:t;! ~::,;i:i;l;,;,;*;:~l;~:U;:~;:;~; .:l'Z'l;z'.'.'~'r '*:1'1'*, :,'*;:";I;U ::::;l:':; ; I; ; I ILl; ! ! ! ; ! BHA: 3 6 f/8" B/T,/IMCH fXL AKO .80 DEG, STRING STAB, Afl/VD, PULSER SUB, 4.3 f~2' HWDP, 4 3/4' DAILY JARS, 26.3 Length: f/2" HWDP, XO SUB, f,020.54 DRILL PIPE DE81CRIPT!ON: 260 Jts. 4' DRILL PIPE, MAX PULL: ( JAI~S IVlWI~ ' MOTOR TORQUE WEIGHT (1~]00) ,,~ I?~1 ~'~ ~.o.o., I~ IM,-O4,, I ' I'H',=" ,,u ,,, .ot ~ ~o ~, ~ " (MEA. DEPTH ANGLE DIRECTION 'IYD VERT. SEC. N; F-/W DOG L,EG ) 4,886.00 59.620 5t.70' 3,2.68.59 3,133.89 1,934.00 2,465.39 1.23 ,,. 5,014.00 60.120 51.50 3,332.84 3,244.59 2,003.66 2,552.t5 OAf 5,142.00 60.820 49.30 3,395.93 3,355.88 2,074.65 2,637.05 1.59 ( OPERATIONS IN SEQUENCE 8TART END HOURS,. DESCR!PTION ~:00 t~.~0 13.00 ORI,LL AHEAD FROM4,!00' TO 5.059'-4.75 ROTATING HOURS-4.25 SUDING HOURS 19:00 22:00 3.00 POH CIRCULATE AND BACK REAM TO ?' CASING SHOE 22:00 ~2. :~0 0.59 'CIRCULATE BOTTOMS UP AT SHOE 22:30 0.~0 1.50 RIH TO BOTTOM 0.~0 1:30 1.50 I .DRILL AHEAD FROM 5,069'T0 5,228'..5 HOURS ,ROTATING HOURS..5 SUD. ING HOURS 1:30 2:30 1.00 WORK WITH MWD Too.L- MWD TOOL FAILURE WEAK PULSES- MiX DRY JOB i i i i 2:30 6:00 3.50 PUMP DRY JOB AND. POH. i. i ,, , , ,, .... ..::::::i:i:::~:t:t:::l':::~:. :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~,FE: DH TSTlCSG COMP TOT LAST PiT DRILL DATE: 09/I2/00 ',;;;;.*;;;I;;;; il; :l;: :T :l;I;;;;;I;I;$;I;,l~;;,;i;il;li;;;;.l:;'-';;I;i;:;I;;;-ii; ; i~;~:~i~!;.i.~,i.;el,;~i,i:.~.l MUD COSTS ACTUAL I .................................................... I WELL COSTS ACTUAL I.~u.,~:!~i~i= LAST BOP TEST DATE: 09/12/00 DAILY: 6,423 CUM: 27,~05 DALLY: 5f,085 CUM: 475,647 NO ACCIDENT~ REPORTED TODAY DRILLING SUPERVISOR: DARRELL GREEN 1~001 09/16/00 SAT 06'11 FAX 19075646489 MarathonOll Co **~ Peter Berga ., Marathon #: i DATE: 09/16/00 LOCATION 3: SPUD DAYS: 6 Oil Company AFE#: 970f000 GL: KB: . MDC WI: o WELL: Cannery Loop fi 6 RIG: Glacier Drilling Rig f FTG: f,f07 DEPTH: (MD). 6,335 (TVD) 3,996 CSG SIZE: 7.000 CSG MD: 2,964. CSG TVD: 2,322, SHOE TEST: 19,0f MAX. SI 1,209 LINER TOP: PRESENT OP'J)RILL AHEAD POH WORK BHA - LAY DOWN MWD TOOL o SERVICE RIG o CHANGE BIT, MAKE UP BHA AND RIH. CUT DRILL EXECUTNE LINE AT SHOE- CONTINUE TO RIH o DIRECTIONAL DRILL AHEAD FROM 5,226' TO 6,335' SUMMARY ¢~ ws PVYP GELS WL T ?.5 30 HT FC CEC SAND SLD BENT SALT DRILLED RAR~TE 9.01481.1241.11817o01881 I I 11~2 0.3 ]3.61 I 10.5 PPB ~8 PPB ppJ ~OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES Ibbl/It} BKGD -CON-N TRIP MAX ( BIT# SIZE TYPE OFF FTG HRS FT/HR RPM WOB IOD LB O OT R CPF COMMENTS 3 6.~25 IS75BPX 15,228 2,245 16.30 137.7 60 2,2,LT,,,I,BT',DTF MWDFAILURE (. BIT # SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY SIT HP 4 LYlt61 I 2048 285 J 12 14 12 0.370 3 ~s0974 I 1100 2o4 I t2 t2121010 0~5 . 17,4 BHA: 4 6 f/8" BIT, MACH fXL AKO .80 DEG, STRING STAB, MWD, PULSER SUB, 4.3 1/2' HWDP, 4 3/4" DAILY JARS, 26.3 Length: f/2' HWDP, XO SUB, 1,020.64 DRILL PIPE DESCRIPTION: 260 Jts-4"DRILL PIPE, MAX PULL: ( JARS MWD MOTOR TORQUE WEIGHT (1'000) - I 4t5 1t471-0005J 415 ~77 J 415 IM1-048 I 6,20Oft~lbs BHA' 26 Pu 100 Rot 68 So 50 Eft .... .*..,.,.., ..... .... :; ..... . .......... *. ...................... . ..... ..., ................. . ....... : ...... ~ MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. NIS E/W DOG LEG 5,335.00 60.330 5f.80 3,490.76 3,523.88 2,181.46 2,767.74 f.f6 5,643.00 6f.270 53.00 3,643.95 3,797.97 2,348.68 2,984.90 0,45 5,838.00 58.040 5f.60 3,739.42 3,961.05 2,448.38 3,ff3.95 t.82 , ( OPERATIONS ~N SEQUENCE START END HOURS DESCRiPTiON 6'00 7,00 f.O0 POH WORK BHA- LAY DOWN MWD TOOL AND BREAK OFF BIT 7:00 6:00 f.O0 CLEAN UP RIG FLOOR - SERVICE RIG AND TOP DRIVE 8:00 9:30 fo50 MAKE UP N~. 6 f/8" BIT .AND MWD TOOL- ORIENT WITH DOWN HOLE MOTOR- RIH WITH BHA 9:30 f0,00 0.50 SURFACE TEST MWD TOOL AND MOTOR 10:00 10:30 0.50 CONTINUE TO RIH WITH 4" DRILL PIPE TO 7' CASING SHOE AT 2,964' 10:30 12:00 1.50 SLIP AND CUT 1 t/8" DRILL LINE f2,00 f2:30 0.50 CONTINUE TO RIH WITH 4" DRILL PIPE TO 5,t35' 12:30 13:00 0.50 WASH AND REAM TO BOTTOM FROM 5,135' TO 5,228' (NO FILL) 13:00 6:00 f 7.00 DRILL AHEAD FROM 5,226' TO 6,335'- 9.3 ROTATING HOURS- 2.4 SLIDE HOURS AFE: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 09/15/00 DAILY: 7,025 CUM: 34,630 DAILY: 44,477 CUM: 520,f24 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: DARRELL GREEN ~001 09/18/00 MON 08-09 FAX 19075545489 MarathonOll Co **~ Peter Berga Oil Company AFE#: 970f000 GL: . KB: . MDC WI: . WELL: CanneryLoop#6 RIG: GlaclerDr#11ngRigf FTG: f,025 DEPTH: (MD).. 7,360 (TVD) 4,634 CSG SIZE: 7.000 CSG MD: 2,964. CSG TVD: 2,322. SHOE TEST': 19.01 MAX. SI f,f60 - LINER TOP: . PRESENT OP'.DRILI. AHEAD AT 7,360' ~::~:::~;~:;.~:~:::::::~::::~::~::::~;:~:~:~:~:~:;~:~;~:~:~;;;~:::;.~:::;;:::::~;;:~:~:~:~:::::~::::~:;:~:::~:~:;:~:;~.~;;:~:~;~:~:;:~;~:~;~:~:;:~:;:;~.~;:~..~:~:~:~::~:~:~:~:;:~:;:~:~:;..;:;~;;;:;;~:~:;:;..;..;:;~;~:~:~..~:~;..~:~:;;;:~..;;;;~:~:~:~:~;~:~:~::~:~;;:;:~;~;~;~:~:~:~:~:;:~:~:~:::::~:;:;:~ WORK ON RIG # 2 GENERATOR AND MUD PUMP CONTROL o DRILL AHEAD FROM 6,335' TO 6,885'° CIRCULATE EXECUTNE BOTTOMS UP- SHORT TRIP POH 25 STANDS MONITOR WELL AND RIH WORK THROUGH BRIDGES TO BOTTOM !SUMMARY . DRILL AHEAD FROM 6,885'T0 7,360' (~MW VI;PVYP GELS WL T 7.5 30 HT FC CEC SAND SL= BENT SALT DRILLED BARITE 9.4 1471 '/21271 14 / 1717-61"1 I I I '/. 132 0o3 J 6.7 I I 9.8 PPB 77.4 PPB PPB (OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES tbbl/fl:) BKGD CONN TRIP MAX .. .o.o j,,.~,! :.~o i:.o...o. .... .o...o...!..0~ .... ~.o.:o..o..o...!.~.o.~ .1~ ~.~' I... ~o ...... I .:0~. ..[ .... ,.o., :.. ~: ..: : ...... : ............... ! ....................... I ......................................................... I ...................................................... (~ BIT# SIZE TYPE OFF FTG HRS FT/HR RPM WOB 'ODLB GOT R CPF COMMENTS ( BIT # 8ERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP~) 4 . LYf16f12f00275 12f41210.370 DP293.6 !'76.t ::::::::::::::::::::::::::::::::: ;;:;;;;;:~:::=::::;:;;:;:~:;:;:~:;:=:;;~;;:;:==;:;:;:fi;:~:l ::~:;:r;l:t;l=;:;:;;;:;:~;: ~:~:~=:~:~;~:t:~;t~:~:~=;:~:~;:;;~;~:~=~;~=~t~t~;~;:=~;:::~:::= ~;;~:~;~;~=;;a;=~=~=~;~=:~n;~:~;;~.;;~=~=~;:=:;~;=;;;~t;:~r:~=~; ='~'~':::'.'='~'.'~:,;:': BHA: 4 6 fAl' BIT, MACH fXL AKO .80 DEG, STRING STAB, MWD, PULSER SUB, 4.31/2" HWDP, 4 3/4' DAILY JARS, 26.3 Length: I/2' I. IWDP, XO SUB, 1,020.64 DRILL PIPE DESCRIPTION :' 260 Jts o 4' DRILL PIPE, MAX PULL: (: JARS · MWD MOTOR TORQUE. WEIGHT (1000) - 55.5 t47t-0005 55.5 '0.07 ~5.5 IMf.048 ! 5,70Oft~lbs 'BHA: 28' Pu f00 Rot 72 So 50 Elf 27 ( MEA. DEPTH A,NGLE DIRECTION TVD VERT. BEC. NIS .F-A'V DOG LEG' ~,663.00 53.9oo ce.30 4,175.22 4,661.17 2,879.23 3,ee5.82 6,893.00 48.100 54.20 4,319o91. 4,839.59 2,980.95 3,8t2.69 2.62 , 7,141.00 47.59O 55.60 4,486.35 5,023.25 3,086.67 3,963.09 0.47 ;;;;;:;~;t:~:;;;;;;;;;;|;;~|;|;,,;|;;;;;;;_,: ;:|::;:;;;.,;e;:;:;:;!;::;;:;:;;:E;::;::;~ ~:;:~;;~;!;;;;;:;;~;;;~:~;~;~!~:;:;:;;;:;~:~!~;!~!~!;!;!;!;!;!;!;!;~;!;!;!;!~!~!~!~!;e~e~!;~t;~;~;~!~!;~;~:!;!~!~!;!;!:~;~e~;~E~!~!~e~e~: .:;!:!;!:;;!;!;:;:;;;!;:;:;.*;?;:;:;!;!;!;e , (~ ' OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 11:00 5.00 REPAIR FUSE ON NUMBER 2 GENERATOR o TROUBLE SHOOT MUD PUMP CONTROL AT DRILLERS cONSOLE- TOP DRIVE ACCUATOR CLOSED D, UE TO LOSS OF AC POWER 11:00 19.'00 8,00 DRILL AHEAD FROM 6,335'T0 6,885'. 2.75 ROTATING HOURS.. 2.75 SLIDE HOURS t9:00 20.-00 f.00 CIRCULATE BOTTOMS UP o PUMP. DRY JOB 20.00 2f:30 f.50 POH 25 STANDS TO 5,263' .. 21:30 0:00 2.50 RIH WASH AND REAM AS NEEDED TO WORK THRU TIGHT SPOTS. MAX GAS AT BOTTOMS UP ,AFl'ER TRIP 106 UNITS 0:00 6.00 6.00 DRILL AHEAD FROM 6~885' TO 7,360'. 2.5 ROTATING HOURS..75 SLIDE HOURS AFE: DH TSTICSG COMP TOT LAST PiT DRILL DATE: 09/'15/00 :::::::::::::::::::::::::::: ;;; ~ ~;;; ;;.,:::;;;:;;;;;;; !;; ~ ;.;.;,;,;.;.;.; ............................ ~ I;UD COSTS ....... ACTUAL I.... ............................. ....: ....: :,: ._: ...............:.... '~1 WELL COSTS ACTUAL li~i~i;i~i~!~i~i*;:;";*;";" LAST BOP TEST DATE: 09/'12/00 DAILY: t2,57'0 CUM: 47,200 DAILY: 57,116 CUM: .577',240 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: DARRELL GREEN [~001 09/18/00 MON 06:44 FA][ 19075646489 MarathonOll Co .. ,-. · ~*~ Peter Berga Marathon t ..: , DATE: 09/18/00 LOCATION ,: _ __ SPUD DAYS: 10 Oil Company AFE#: 970f000 GL: KB: , MDC WI: , WELL: Cannery Loop # 8 RIG: GlaclerDrilling Rig, FTG: 880 DEPTH: (MD) 8,320 (TVD) 5,278 CSG SIZE: 7.000 CSG MD: 2,964. CSG TVD: 2,322. SHOE TEST: ,9.0, MAX. SI f,f84 LINER TOP: PRESENT DP:CLEAN RIG FLOOR AN RIH DRILl. AHEAD TO 8,320'- CIRCULATE BOTTOMS UP- PUMP OUT OF THE HOLE TO 7' CASING SHOE EXECUTIVE CIRCULATE BOTTOMS UP SUMIt~.RY ::~:::~:::::::::~:::~:~:~:::~:::::~.~:::~::::::::=:~:~.~.;::.~:::~.:::;:~.:::~.~:::~;;~!:;:;:~:~:~:;:;:~:t~::::~;::~.:~:;~::;:~.~;.~;:~:::~::.~::~::;::~:~:~:~:::~:~:~:;::~:~.~:;:~!;;~;;~;;:~:~;~:~ ([MVV VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE 9.2 15,1. jR01,6 / 2, 16.41881 I ] I ' /32 0.3 j 4.7 1 / ,0.2 PPB_ 50.4 PPB .PPB (OIL VV'I'R pH Pm Pf Mf CL CA LIME MUD LOSSES [bbl/ft) BKGD CONN TRIP MAX ..0..,0. .... 95./.3. ..... 8..6....!.0.0.. .... 0.0. ..... O.A.. .... 30:5..00I.'80 Ida"Y -cum 1 4s I ! 525 ( BIT# SIZE TYPE OFF FIG HRS FT/HR RPM WOB IOD LB O OT R CPF COMMENTS ( BIT # SERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP~ 4 ILW,6,12528 285I 12,412 0.370 DP304.2 184.7 ;:;l:;:;:l:;:;:;:;:;:;:;:;:;:::;. :i:i:::;:i:;:;;:;l:::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::~:~~:~:;~:::::::::::::::::::::::::::::: ::::::::::::::::::::::::::: BHA: 4 8 fi8' BIT, MACH ,X£ AKO .80 DEG, STRING STAB, MWD, PULSER SUB, 4.3 ,/2' HWDP, 4 3/4' DAILY JARS, 26.3 Length: ,/2" HWDP, XO SUB, DRILL PIPE DESCRIPTION: 280 Jts. 4' DRILL PIPE, MAX PULL: ( JARS MWD MOTOR TORQUE WEIGHT ('1~)00) '- 7~ 51,47,-00051 7, 5~007I 7, 5 IM,-048 J 5.700 ft/Ibs I ellA. 28 Pu' ,00 Rot 72 So 50 Elf 27 .. .... ........... ., ..... ........... ,,, ..... ..:,..,, ,. ..... ..'; .............................................................. (-MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. N/S 8,038o00 47.2= 50.60 5,090.3' 5,686.2' 3,49'.76 4,4~7.89 0.37 ( OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 22:00 f 6.00 DRILL AHEAD TO 8,320'- 8.5 ROTATING HOURS - 2.25 SLIDE HOURS 22.00 22:30 0.50 CIRCULATE BOTTOMS UP 22:30 5:30 7.00 PUMP AND ROTATE OUT OF THE HOLE TO THE 7" CASING SHOE 5:30 6:00 0.50 CIRCULATE BOTTOMS UP- WASH AND CLEAN RIG FLOOR · ~:::=:::::":~:::=:~:~:~:~:":=:::~:~:::~:::::=:::=:~:~:~:~:~:::::.~:~:=:::~:~:~:::~:::=:=:~:::::::=::~:~:::::~:: ~.FE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 09/15/00 i;i~i:i~:i=!=!~i;i:i;i=i:i:i MUD COSTS liiii iiiiiiii!iiiii,i i !ii !iiiiii!i!iiiiiii!!iiii! WELL COSTS ACTUAL liiiii{iiiiiiiiii LAST BOP TEST DATE: 00/12/00 =,ii~i~i*i~i~;~i~i~il;~i~;il ACTUAL ~:~:~:~:~:~'~:~:~:~i::~"~:~:::~:';:~:~:;':~:~:~:~=::::I DNLY: 0 CUM: 47,200 DAILY: '9,677 CUM: 598,9'7 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: DARRELL GREEN {~001 09/19/00 TU~ 06:49 FAX 19075646489 MarathonOll Co *** Peter Berga Well': Cannery Loop # 6 [ Operations Cont (d) Date: 19-Sep-00 SEQUENTIAL OPERATIONS (REPORT TIGHT SPOTS, LOC. TORQUING UP PROBLEMS, ETC.: 112 HOUR MINIMUM [~002 START END HOURS DESCRIPTION 4:30 6:00 f.50 RIH WITH 4" DRILL PIPE TO 7" CASING SHOE- FILL DRILL STRING 09/19/00 TUE 06:49 FAX 19075646489 ~farathonOll Co (,,,.~t..,},'()t.,/ ..,..,_, Peter Berga ~q;~r;~hon : DATE: 09/f9/00 LOCATION . SPUD DAYS: f'/ Oil Company AFE#: 970f000 GL: KB: . MDC WI: WELL: Cannery Loop # 6 RIG: Glacier Drilling Rig '/ FTG: DEPTH: (MD) 8,320 (TVD) 5,278 CSG SIZE: 7.000 CSG MD: 2,964. CSG 'rVD: 2,32~ SHOE TEST~ '/9.0'/ MAX. SI '///48 LINER TOP: PRESENT OP'.RIH "WIPER RUN" CIRCULATE BOTTOMS UP AT 7" CASING SHOE- RIH TO 8,320'- CIRCULATE. BACK REAM OUT OF THE HOLE EXECUTIVE TO 7,593'- CIRCULATE BOTTOMS UP- PUMP DRY JOB AND POH- LAY DOWN BHA- RIG UP SCHLUMBERGER SUMMARY WIRE LINE LOG RUN # '/STOPPED AT 7,800' LOG OUT OF THE HOLE. CHANGE TOOLS - RUN # 2 STOPPED AT 7,800'° RIG DOWN SCHLUMBERGER - RIH FOR WIPERRUN 74:::!:;:;:~::;;:!:~:::::~:?:~:!:~:~.::: (MW VIS PVYP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE 9.5 I~1 '/~138l '/7 1 2817.81881 I I I '/ /32 0.3 I 7.7 I I 9.7 PPB 90.7 PPB PPB i(OIL VVTR pH Pm PI' Mf CL CA LIME MUD LOSSES (bbl/ft) BKGD CONN TRIP MAX oo 0.0 ..... ( BIT # SERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP) 4 LYff6f125281285 '/2 f4 f2 Io.= ol DP304.2 182.9 I I; I ii ................ I I ::::::::::::::::::::::::::::::::: , ...... BHA: 4 6 fi8" BIT, MACH fXL AKO .80 DEE, STRING STAB, MWD, PULSER SUB, 4.3 fi2' HWDP, 4 3/4' DAILY JARS, 26-3 Length: f/2' HWDP, XO SUB, f,020.64 DRILL PIPE DESCRIPTION: 260 Jts. 4" DRILL PIPE, MAX PULL: ( JAR8 MWD MOTOR TORQUE WEIGHT (1000) 7'/.5I-7'/-0005[ 7'/.5 _0.07 I7'/.5 lM'/'°48 I 5,?ooft/Ibs I.B, HA: 28 Pu '/O5 Rot 72 So 55 Eft 27 .. ' .... ~ ' ' 'l'l'l' · '1'1 .... I'"1 ........... I''l' ' ' (MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. NIS E/W DOG LEG 7,697.00 48.400 5'/.30 4,86'/.39 5,433.56 3,332.55 4,29'/.62 0.63 8,038.00 47.260 50.60 5,090.3'/ 5,686.2'/ 3,49'/.76 4,487.89 0.37 8,265.00 48.740 52.70 5,242.2'/ 5,854.87 3,596.39 4,620.'/9 0.95 :::::'.;p'.:;;:;;;:;t;:;;;.';::.':;:t::;e;!;!: ;~;~;:;~:t:t:~:;;:~:~:~;t;:;:;.~:~;:::::~:::;:p:;:;:;;::~;:~::::;:~:;::::t~:;:~;;~;~::;~:::!:!:e:!~e;~e;~:;!~;;; ~:e:t:e;:;l;t:::t:t:.':t:;:;:t:::t:.'::::;;:e :t:e:!;!:!;!;!:::!;;;;;!;.*;;;!;:;;;!:;::;~ ;t;:~!::~::!:e:!:!~!:!~;~!:~:!:::!~!;!;:;:~;!;!~:;!;!;t~!;:~:;.~;;:!~:;:;!;!;~;~e ( OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 6:30 0.50 CIRCULATE BOTTOMS UP 6:30 7:00 0.50 SERVICE RIG AND TOP DRIVE. MONITOR WELL 7:00 '/0:00 3.00 RIH FROM 2,965' TO 8,320'- NO PROBLEMS OR FILL . , '/0:00 '/'/:00 '/.00 CIRCULATE BOTTOMS UP '/'/:00 '/2:30 '/.50 BACK REAM- ROTATE AND CIRCULATE- FROM 8,320' TO 7,693' 12:30 '/3:30 '/.00 CIRCULATE BOTTOMS UP- PUMP DRY JOB '/3:30 '/7:00 3.50 POH WITH 4" DRILL PIPE MONITOR WELL AT SHOE "NO FLOW'- CONTINUE TO POH '/7:00 '/8.00 '/.00 STAND BACK BHA- LAY DOWN PULSER SUB, MWD TOOL, MWD MOTOR, 6 '//8" BIT '/8:00 '/8:30 0.50 WASH AND CLEAN RIG FLOOR '/8:30 20:00 '/.50 HOLD PRE JOB SAFETY MEETING WITH SCHLUMBERGER o RIG UP TO WIRE LINE 20:00 0:00 4.00 RIH WITH LOGGING TOOLS RUN NUMBER '/* PLATFORM EXPRESS, NETRON DENSITY, RESISTIVITY- TOOLS STOPPED AT 7,800'* LOG OUT OF THE HOLE 0:00 3:30 3.50 CHANGE TOOLS- REMOVE KNUCKLE JOINT- RIH WITH LOGGING TOOLS RUN NUMBER 2- PLATFORM EXPRESS TO 7,800'- TOOLS STOPPED POH WITH TOOLS - RIG DOWN SCHLUMBERGER- CLEAR RIG FLOOR 3:30 4:30 '/.00 MAKE UP BHA AND RIH WITH HWDP :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: AFE: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 59/'/6/00 ':';';';';':P ';';';':':'; S iisi !ii iiiiii! iiiili MUD COST ACTUAL I~iiiiiiii......;; ;:...:,,~,~,~ ~ ~,,,,,~,,,,ili iii iiiiiiiiiiiiil WELL COSTS ACTUAL Iiiiiiiiiiiiii!i! LAST BOP TEST DATE: 09/f2/00 DAILY: 625 CUM: 47,825 DAILY: 27,340 CUM: 637,757 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: DARRELL GREEN ~001 09/20/00 WED 06:15 FAX 19075646489 Marathon01! Co .... .?,/t.,' **~ Peter Berga Marathon #: DATE: 09~0/00 LOCATION $: SPUD DAY8: '/~} Oil Coffi~all~/' AFF~t: 970~000 GL: KB: . MOC ~q: . WELL: Cannery Loop # 6 RIG: Glacier Drilling Rig f FTG: DEPTH: (MD) 8,320 (TVD) 5,276 CSG SIZE: 7.000 CSG MD~ 2,964. CSG TVD: 2,322'~ ~;HOE TES'~: 19.0t - MAX. SI ~,136 LINER TOP: PRESENT OP'.POH WITH EoLINE :~:~;:~::::~::~::::~:::::~::~::~::~:~:~.~::~:~:;~::~;~::;:;~;~;:;:~;:~:~:~::~::~::~::~:~::~:..:~::~:~::~..:~:~::..:~:~.~:~.~;~:~:::.~:~:~;:;:;:;:~::~::~:~;:~:::;:::;:;:~;:::;:;:;:;~;:;:~:;~:~:~::::::::::::;~:~:~:~:~:::;:~::~:::::::::::::~::::..~:~:::~:;~:::~:~:~::::~:::~:~:~:;:;~;~;~;:~:::::: RIH WIPER RUN FOR LOGS- TAG LEDGE AT 7,795'- WASH AND REAM TO 8,320'- CIRCULATE BOTTOMS UP- EXECUTIVE SHORT TRIP TO 7,700' RIH NO PROBLEMS- CIRCULATE BOTTOMS UP- PUMP OUT OF THE HOLE TO PREVENT SUMMARY SWABING TO 7,266'- POH- RIG UP SCHLUMBERGER- RIH WITH LOGGING TOOLS TAG BRIDGE AT 7,600' POH- CHANGE TOOLS- RIH TAG BRIDGE AT 7,795'- WORK TO GET THRU- NO GO (:MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE ~.= 1~1,2139119 / 2917.21.1 ./ I I I /32 0.3 I 7.7 1 / 9.9 PPB 62.5 PPB PPB (: OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES <bbl/fl) BKGD 'CON-N TRIP MAX oo 19231 00 loo oo/ 0313°,5°°I ,440I IdM~Y cum 1 . 19 .....................I ! ............ p. 125 ,. ...: ........ : ....... : ....... : ....... .... :...,: .................... , ...................................................... , (: BIT# SIZE TYPE OFF FTG HRS FT/HR RPM WOB IOD LB G OT R CPF COMMENTS ( BIT # SERIAL # PRESS. GPM JETS 'TFA ANNULAR VELOCITY BIT HP) ;l;l;l;l:l;lll;l;lll;l;lll;l;I;l; 511151;I;I;111;I;11111;I;11111111 I"'l""'""'"" ""'""""""' ""1l'' """"l"""'l"""'"'" ........ I .............. I'I ......... I' "1 ........ I .... I' '1 ..... ' ~ I I BHA: 5 6 I/8" BIT, BIT SUB, STRING STAB, 2-DC, 4-3 1/2" HWDP, 4 3/4' DAILY JARS, 26-3 t/2" HWDP, XO SUB, Length: 1,020.99 DRILL PIPE DESCRIPTION: 260 Jts - 4" DRILL PIPE, MAX PULL: (: JARS MWD MOTOR TORQUE WEIGHT (1~)00) 760 147f.0005 I I I BHA- 28 Pu 105 Rot 72 So 55 Eft' 27 (MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. N/S E/W DOG LEG 7,697.00 48.400 51.30 4,861.39 5,433.56 3,332.55 4,29t.62 0.63 8,038.00 47.260 50.60 5,090.31 5,686.2t 3,491.76 4,487.89 0.37 8,265.00 48.740 52.70 5,242.21 5,854.87 3,596.39 4,620.19 0.95 ( OPERATIONS IN SEQUENCE START END ,.HOURS DESCRIPTION 6:00 9:00 3.00 RIH WITH 4' DRILL PIPE TAG BRIDGE AT 7,795' 9.'00 f3:30 4.50 WASH AND REAM TO 8,320'- 560 UNITS OF GAS AT BOTTOMS UP f3:30 f4:30 1.00 CIRCULATE BOTTOMS UP- PUMP 20 BARREL DRY JOB 14:30 15:30 f.00 SHORT TRIP POH TO 7,752'- RIH ' SLOW' TO BOTTOM AT 8,320' 15:30 I6:30 1.00 CIRCULATE BOTTOMS UP t 6:30 18:00 1.50 PUMP OUT OF THE HOLE TO 7,226' 16:00 19:00 1.00 CIRCULATE BOTTOMS UP- PUMP DRY,JOB 19.00 22:30 3.50 CONTINue TO Poll 22:30 0:00 1.50 HOLD PRE JOB SAFETY MEETING- RIG UP SCHLUMBERGER 0:00 2:00 2.00 RIH WITH LOGGING TOOLS TAG BRIDGE AT 7,800'- POH 2:00 4:00 2.00 CHANGE TOOLS- INSTALL HOLE FINDER AND CENTRlliZER ON NOSE OF TOOLS 4:00 6:00 2.00 RIH WITH LOGGING TOOLS - TAG BRIDGE AT 7,795'. ATTEMPT TO WORK THRU "NO GO" POH WITH E-liNE AFE: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 09/16/00 :::::::::::::::::::::::::::::::::::::::::::::::::::: i!iiiiiiiii!i!!;!;ii!!!i!iii] MUD COSTS ACTUAL I~;~'~'~i~'~'~'~m'~'~'~' WELL ;,;..,..;=;,,..;=;,;.;,;=;,;,;=;=;=;=;..;..;=;,;,;,;,;=;J COSTS ACTUAL l i!i !i!ii!! ii! LAST BOP TEST DATE: 09/12/00 DAILY: 7,094 CUM: 54,919 DAILY: 24,581 CUM: 662,338 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: DARRELL GREEN [~001 09/22/00 FRI 06:35 FAX 19075646489 MarathonOi! Co Well: Cannery Loop # 6 ~ Peter Berga Operations Cont (d) Date: 22-Sep-00 SEQUENTIAL OPERATIONS (REPORT TIGHT SPOTS, LOC. TORQUING UP PROBLEMS, ETC.: 112 HOUR MINIMUM START END HOURS DESCRIPTION ~002 CONTINUE TO RIH TAG LEDGE AT 7,793' 2:00 5:00 3.00 BREAK CIRCULATION- WASH AND REAM FROM ?,793' TO 8,320'- 397 UNITS OF BOTTOMS UP GAS AT 7,793'-945 UNITS OF OAS AT 8,030' 5:00 6:00 1.00 CIRCULATE BOTTOMS UP ,, 09/22/00 FRI 06-35 FAX 19075646489 MarathonOll Co J(~/b~(~ *** Peter Berga ' Marathon {. ,-#: r DATE: 09/22/O0 LOCA?~O~. ,S: .~ SPUD DAYS: Oil Company AFE#: 970f000 GL: . KB: . MDC WI: WELL~ Cannery Loop # 6 RIG: Glacier Dril#ng Rig f FTG: 0 DEPTH: (MD).. 8,320 (TVD) 5,278 CSG SI-ZE: 7.000 CSG MD: 2,964. CSG TVD: 2,32~ SHOE TEST: fg.0f MAX. SI f, f36 .. LINER TOP: . PRESENT OP:POH FI CASING ~:~:;:;::~:;;:::::::~:~:::::~:;~;;;;~;~;.~:~:~:;:;:;:;~:~:~:~:;:~:;~:~:~:~:~:~:~:~:;t~;;:~:;:;:;:~:;:;:;:~:;~;:~:~..~;:~:;:;:~:~;:~:::~:;~:;~:;:~:~:;;;:;::~:~:::~:~:~:::~:~:~:::::::::;::~::;~;::~::~;~;: ;=;:;:;:;:;:;:;:;:;:::;;;:;:;:;:;::'';:;'';''::;:::;:;~;~ ;~ ;~;:;'' ;~;:;~;:;~ :~;:::;:: ~;-';:;? ;?;~;:;:::;: ~: ATTEMPT TO WORK DRILL PIPE CONVEYED LOGS PAST 7,787' "NO GOOD"- POH WITH E-LINE AND LOGGING EXECUTIVE TOOLS, TEST BOP AND RELATED EQUIPMENT.. RIH WITH BHA AND 4" DRILL PIPE- TAG LEDGE AT 7,793' SUMMARY WASH AND REAM TO 8,320' ,~MW VlS PVYP ;;LB WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARliI: 9.6 I ~1 7 I~1,9 1 2919~1 ~1 ./ I I f 132 0.3 I 7.7 1 / 9.7 PPB 82.7 PPB PPB '{OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES <bbl/It} BKGD CONN TRIP MAX ~ o o 92.3 8'/ o o o o 03 30,000 520 I daiW cum f5 ' I I ; - I ..... I;;; ..... I;..:...;.=.;.;.;.;. .... J.=...:. J ............... { .......... ! ................ =. ................................................................ ! .................................................................... ~ BIT# 8!;1:: TYPE OFF FTG HRS FTIHR RPM WOB IOD LB G OT R CPF COMMENTS ( BIT # SERIAL # PRESS. GPM JETS ¥~A ANNULAR VELOciTY I~1 I 5RRILYffSe f85012361f2f4f21. O.37f DP25f.9 48.~i BHA: 5 6 fi8' BIT, BIT SUB, STRINQ STAB, 2-DC, 4,3 fi2" HWDP, 4 3/4" DAILY JARS, 26-3 '//2" HWDP, XO SUB, Length: 1,020.99 DRILL PIPE DESCRIPTION: 260 Jts. 4' DRILL PIPE, MAX PULL: _ < JARS ~n~O MOTOR TO;(~UE WaGHT, (~00) 70.0 I,~4-/"~..00051 I I I I 6,200f~ I BHA: 28 Pu '~08 Rot. 78 So ~0 ~ 27 !: t i z :~;h:;; Ii:;;;;; ;; :. : ................... ~ ..... · (M~~. DEPTH ANGLE DIRECTION TVD VERT. SEC. N/S E/W DOG LEG '7,597.00 ~A00 5f,30 4,86f.39 5,433.56 3,332.55 4,29f.62 0.83 8,038.00 47.260 50.60 5,090.3'l 5,686.2~ 3,48~.76 4,487.89 0.37 8,265.00 48,740 ' 52.70 5,242.2f 5,854.87 3,596.39 4,620.119 0;95 O.P~TIONS ~N SE~U.£~CE START END I.lOU~S DESCRIPTION 6:00 6:30 0.50 CON'nNUE WORKiNg, LODGING TOOLS- eK C~S. set DOWN WEIGH'r. CRINGE ~ ?,7g0' DRILL PIPE MEASUREMENT ,. 6:30 8:30 2.00 ;~OH WITH DRILL PIPE AND LOGGING TOOLS TO 7,467'- UNLATCH WET CONNECT- POH WITH E.LINE- RIG DOWN sIDE Door SUB 8:30 9:30 f. O0 PUMP DRY JOB - POH W .IT~f LOGGING TOOLS TO 7, f 6f'- HOLE SWABiNG o RIH TO 7,4~/' 9:30 fO:O0 0.50 OIR(~ULATE BOTTOMS UP fO:O0 f2:00 2.00 PUMP OUT OF THE HOLE TO 6,296' ~2.'00 ~2:30 0.50 PUMP DRY JOB 112:30 f 6:00 3.50 POH WITH 4' DRILL PIPE f 6:00 f6:30 0.50 RIG DOWN SHEAVE IN MAST CLEAR RIG FLOOR , ,- - f 6:30 f7:30 f.00 LAYDOWN 26 JOINTS 0F4" DRILL PIPE AND SCHLUMBERGER LOGGING TOOLS f 7:30 2f :00 3.50 PULL WEAR RING - INSTALL TEST PLUG - TEST BOP AND RELAT-ff.D EQUIPMENT- 250 PSI. LOW AND 3000 PSI. HIGH- PREFORM ACCUMULATOR ~-~.$T. PULL ~ t:$T PLUG. Ii~ ~-ALL WEAR RING 2~i :00 22:00 ~.00 RIH WITH BI-IA AND 3 ~ /2" HWDP 22:00 2:00 4.00 RIH WITH 4" DRILL PIPE FROM MAST. FILL DRILL STRING AT 3,2f4'AND 6,327'- ~.FE: DH TSTICSG COMP TOT LAST PiT DRILL DATE: 09//8/00 I I I I ; ]; °*' · .;.l:;.;.l.l'l';' :illil;i;i;;;;il]i;;][iii;t MUD COSTS ACTUAL .~ ~ ..'~.. ... .; .... '.-.. ::.....:..:..~. ......... I WELL COSTS ACTUAL [;,;,;,!,......... LAST BOP TEST DATE: 09/2f/00 DAILY: 2,266 CUM: 50,45f DNLY: f09,3f2 CUM: 793,833 NO ACCIDENTS REPORTED TODAY -DRILLING SUPERVISOR: DARRELL GREEN ~]001 09/23/00 SAT 05:19 FA~ 19075646489 ]~[arathonOll Co *** Peter Berga .* . Marathon [#: . J DATE: 00~3/00 LOCATIO , S: .~ SPUD DAYS: 15 Oil Company A~E#: ~70~00O GL: . ~E: . MOC m: WELL: Cannery Loop # 6 RIG.'. Glacier Drilling Rig f FTG: 0 DEPTH: (MD).. 8,320 (7'VD) 5,278 CSG SIZE: 7.000 CSG Ml~: 2,964. CSG TVD: 2,322. SHOE TEST: fg.01 MAX. SI f,ff2 LINER TOP: . PRESENT OP~UN 4 112' HYDRIL 521 CASING PER PROGRAM PUMP OUT OF THE HOLE DUE TO SWABING TO 6,674'. CIRCULATE BOTTOMS UP- PUMP DRY JOB AND POH EXECUTIVE LAYING DOWN 4' DRILL PIPE- RIH WITH PIPE FROM MAST AND CONTINUE TO POH LAYING DOWN PIPE AND SUMMARY BNA o CHANGE BOP RAMS TO 4 f/2' AND TEST. RIG UP TO RUN CASING - RUN 4 f/2'CASING (MW VIS PVYP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE 0.8 1501.13211712518.81721 I I 12~ 0.1 lul i 0.5 PPa lo..sPP., (OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES.Ibbl/ffI BKGD CONN TRIP MAX · ..°..~ ..... g..o..~ ....... ~..o. .... .o...0 ....... g...o......Lg..~ ...... g.0.:..00.°..!..~g.°...i ..... ? ................ ~.~ ............ ! ................................................. ! ............................................... ..'. !....'..!. :.. !.: .... .'. .......... :..! ............................... I ......................................................................... I ................ ( BIT# SIZE TYPE OFF FTG, HRS FTIHR RPM WOB IOD LB G OT R ,CPF COMMENTS 5RR I 6'1251XR15TDGPSI S'3201 I 4.50 I 0'0 I 90 I 5 I I' IWIPERRUNF/CSQ' ( ' BIT # SERIAL # pRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP) BHA: 5 6 I/8" BIT, BIT SUB, STRING STAB, 2.DC, 4.3 I/2" .HWDP, 4 3/4" DAILY JARS, 26.31/2" HWDP, XO SUB, Length: f,020.09 DRILL PIPE DESCRIPTION: 260 Jts - 4" DRILL PIPE, MAX PULL: ,. ~ JARS MWD MoToR TORQUE WEIGHT (1000) 790 1471-0005 ' I . J BHA' ;8 Pu 108 'Rot 78-So' 60 Eff ;? · .I I I I , , ,), , , · ' ' !~!z:;;;;;;i;~;:;:;~;;~;:;;;~;~;=;:;~'~;~;~;~;~:;z;=;~;~;:;~;;:~r~~;;:~:~:;~l~ ;l:l:l:l;I;l;I;l;l;I;I;I;I;l: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~ DEPTH ANGLE DIRECTION TVD VERT. SEC. NIS F./W DOG LEG 7,697.00 48.400 51.30 4,86t.30 5,433.56 3,332.55 4,291.62 0.63 e,038.00 47'.2~0 50.~0 5,000.31 5,6e6.21 3,401.70 4,487.80 0,37 8,265.00 48.740 52.70 5,242.21 5,854.87 3,596.39 4,620.19 0.95 ,. _'_ ;-..!.. !.. ;;;%;! ....;.-!-;.;! .... -.-.;.*;...;-.-.;.;.;.;.;;.!;.;!;;..;.*'.;.l.'.:;-.' '.;.;.;.: ',' '*' :.!l.,: .. - ;.:!;; ...... .'; '. ..... '; ~;!;;;!:;l!;;;!;~!;;;!;!;;;!;;;!;;;!;!;~;;!;~;;;!;!;~;t;!:!~!;!;~;~;t;~;T;f;!~!; ;;!;;;!;;;!;!;;;!;t;!;!;!;;;!;;;!;!;!;!;~ :::::::::::::::::::::::::::::::::::::::::: , ,, ,, ( OPERATIONS IN SEQUENCE START ' END HOURS DESCRIPTION 6:00 9:30 3..50 PUMP OUT OF THE HOLE TO PREVENT SWABING AND TO KEEP WELL BORE CLEAN ..... 0~30 ~0:30 f.O~.. CIRCULATE BOTTOMS UP- PUMP DRY JOB t0:30 15:00 4.50 POH .I A. YING DOWN 4" DRILL PIPE , 15:0.0 16.'00 1.00 SERVICE RIG , 16:00 17:30 1.50 CONTINUE TO P..OH LAYING DOWN DRILL PIPE 17:30 18:30 f..O0 R!H WITH 20 STANDS 0F4" DRILL. PIPE [:ROM MAST 18:30 20:30 2.00 .POH LAY DOWN 58 JOINTS OF 4" DRLL PIPE 20:30 22.'00 1.50 POH LA Y'DOWN BHA 22.'00 22:30 0.50 CLEAR RIG FLOOR 22:30 0:30 2.00 PULL WEAR RING. INSTALL TEST PLUG. CHANGE BOP RAMS IN TOP GATE TO 4 1/2'. TEST DOORS SEALS AT 2000 PSL - PULL. TEST PLUg- LAY DOWN TEST JOINT 0:30 3:00 2.50 HOLD PRE,JOB SAFETY MEETING. RIG UP TO RUN 4 1/2" CASING 3:00 6:00 3.00 RUN4 1/2" CASING , l iii I i I '.:; Il:'. I; :; ;il; ltl ;il :; :il ;Il: ~ :;Ii !ill Ii:: :lllll: ::~. :i;~; I:1 :'. :~: .':, :~: '. l; :;Il: I l '.Ii !:: .': .' l;l: :., l.' lilt l: :Il; ! Il I l l: I: ::;:I l il; l iii I ill:: :Il ill!l l ill :l l il i:; !lll:l:il ;: ill.:'. ! ill !!!l l lit!l** i:~ *el l; l~l ,.Itl ,.'l lilt l l ,~!l~:lll** ;:;: I l II il ! l !lilt I t :tl IL'l;: .': ! Il l ! Ill; lilt|il ,' :; Ill: ;!: ;: :;Il I: I Itl l Il l I Illi l; l: ~FE: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 00//8/80 l~:l:;;;; :':: :~: :;: :;:: :;::: O :::::::::::::::::::::::::;; :::::::::::::::::::::: iiiil;ii;fil;~i;;'..;~;~i~i:~] MU COSTS.Ac'rUAL I. _ ~;~i,i=i,i~;~i,i=i:i~i'!i:;~;ui,;,;~;~.,~,~,!~!,i~l WELL COSTS ACTUAL li:i~;ii~i~i~i~":':':':::':':' LAST BOP TEST DATE: 09/2f,O0 DAILY: f,419 CUM: 60,870 DAILY: f9,303 CUM: 813,136 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: DARRELL GREEN [~001 09/24/00 SUN 08:28 FAX 19075646489 ]/arathonOll Co ~** Peter Berga Marathon . .~: .. DATE: 09/24/00 LOCATION i: m__ SPUD DAYS: Oil Company AFE#: 970f000 GL: . KB: . MOL WI: WELL: Cannery Loop # 6 RIG.'_Glacier Drilling Rig .1 FTG: 0 _ DEPTH: (MD). 8,320 (TVD) 5,278 _ CSG SIZE: 7.000 CSG MD: 2,964. CSG TVD: 2,322. SHOE TEST: f9.0.1 MAX. SI f,209 LINER TOP: PRESENT OP'~ISPLACE CASING WITH 6% KCL RIH WITH 4 .1/2' HYDRIL 52f .12.6 PPF CASING - REDUCE MUD WEIGHT TO 9.5 PPQ AT 6,699'- CONTINUE TO Rill EXEC UTNE TO 8, .124'- PIPE DIFFERENTIALY STUCK - REDUCE MUD wEIGHT TO 9.0 PPG - CONTINUE TO RIH MAKE UP SUMMARY HANGER AND LAND IN VETCO GRAY WELLHEAD- RIG UP SURFACE LINES. CIRCULATE BOTTOMS UP. CEMENT- DISPLACE W/TH 6% KCL WATER (MW VIS PVYP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE 0.0 I,=1 6 I'1 0 / .1016.21641 / I I .1/32 0.3 I3.61 / .1o.= .r, PB._ 4.1.4 PPB PPB (OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES <bbl/ft) BKGD CONN TRIP MAX -~..o..~ ~.L.[..O...~. ....... .0...! ......... O~ ,~,OOol. !00...I ....... ~,!~ ...... ' .... ~.~ ......... ! ............................... ! ............. ! ............. [ BIT# SIZE TYPE OFF FTG HRS FT/HR RPM WOB I ODLB O OT R CPi: COMMENTS ( BIT # SERIAL # PRESS. GPM, JETS TFA ANNULAR VELOCITY BIT HP] I I I BHA: Length: . DRILL PIPE DESCRIPTION: MAX PULL: (: JARS I~'VD MOTOR TORQUE ' WEIGHT (1~}00) - ' I' ' ' ........ I I BHA: eu Rot So Eft (MF.A. DEPTH ANGLE DIRECTION TVO VERT. sEc. N/S E/W DOG LEG 7,697.00 48.400 5'1.30 4,86f.39 5,433.5§ 3,332.55 . 4,29.1.62 0.63 8,038.00 47.260 50.60 5,090.3f 5,6~8.2f 3,4,gf.76 4,4e7.80 0.37 8,265.00 48.740 52.70 5,2.~.2f 5,854.87 3,596.39 4,620.f0 0.95 C OPE~TIONS m SEQUENCE START END HOURS DESCRIPTION i i 8..O0 .14.'00 8.00 PICK UP AND MAKE UP 4 f/2' HYDRIL 52.1 CASING AND Rill TO 6,899w .14.'00 .17.'00 3.00 R!$ UP ANO CIRCULATE- REDUCE MUD WEIGHT TO 9.6 PPG ~7.'O0 .1~:30 .1..50 CON~/NUE TO RIH WITH 4 f/2' I'IYDRIL 62f .12.6 PPF CASING TO 8,.124' ~8:30 ?1:00 6.50 PIPE DIFFERENTIAL STUCK AT 8,~24'- REOUCE MUD WEIGHT TO 9.f PPG - PULL ON , CASING- SCREW INTO TOP DRAfE AND WORK f2,000 FOOT POUNDS OF TORQUE , OOWNI-IOLE- PIPE FREE Ar 22:55 HOURS. CONT/NUE TO CIRCULATE ANO REDUCE MUD i WEIGHT rD 9.,0 PPG- ADO CUBe rex AT 3% rD sYsTEM .1:00 2:00 .1.00 RUN 4 .1/2' CASING PICK UP LANDING JOINT AND LAND IN VETGO GRAY WELLHEAD 2:00 3:00 LO0 RIG UP CEMENT HEAD AND SURFACE LINES. TEST HANGER AT5000 PSI. 3:00 4.'00 ~.00 MIX 25 BARRELS MUD PUSH- CIRCULATE BOTTOMS UP THRU TWO OUTLET PORTS BELOW HANGER 4:00 6:00 2.00 HOLD PRE JOB SAFETY ME.EI?NG . PUMP 5 BARRELS MUD PUSH- TEST SURFACE LINES A7 3000 PSI.. pUMP ~5 BARRELS MUD PUSH. DROP BOTTOM PLUG. PUMP 2 BARRELS WATER. RELOAD HEAD WITH TOP PLUG - PUMP FIVE BARRELS OF WATER. PUMP .12.9 PPG. LEAD CEMENT.16.1 SACKS. PUMP ~5.0 PPG. TAIL CEMENT 394 SACKS. DROP TOP i PLUG- DISPLACE WiTH .125.2 BARRELS ~ KCL WATER i AFE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: :;i=;=;;i~; i;~ i;; is: ~. T :.:,:.:.:.h;.;.:;:.: :.*' h:;,. ,;:;; h;; ;;,. ...................... · :;: MUD I.:::: ............ ; ..... ... ......... WELL ACTUAL I~;~;~ LAST BOP TEST DATE: 09/2~/00 I; ~!i~ i~!~i~!~!~!~;~;~;~l COSTS AC UAL .; ..... ,,: .................... I COSTS DAILY: ~3,5.10 CUM: 74,380 DAILY: 8.1,087 CUM: 894,223 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: DARRELL GREEN ~001 - ~]oo2 09/25/00 lION 08:43 FAX 19075.~646489 MarathonOil Co ~ Peter Berga Well: Cannery Loop # 6 ~'[' ~'I~'' Operations Cont (d) % Date: 25-Sep-00 SEQUENTIAL OPERATIONS (REPORT TIGHT SPOTS, LOC. TORQUING UP PROBLEMS, ETC.: 1/2 HOUR MINIMUM START END HOURS DESCRIPTION 3:00 4:00 l.O0 TEST4 ~/2" CASING AT 3000 PS1. 'TESTED GOOD' 4:00 6:00 2.00 CONTINUE TO FLUSH AND CLEAN MUD SYSTEM RIG RELEASED FROM CANNERY LOOP # 6 AT 0600 HRS ON 9/25/00 , 09/2~/00 MON 08:42 FAX 19075646489 MarathonOll Co ~ Peter Berga I~larathon ~: DATE: 09/25/00 LOCATION .~: SPUD DAYS: '/7 Oil Company AFE#: 970'/000 GL: KB: . MDC WI: WELL: Cannery Loop # 6 RIG: glacier Drilling Rig '/ FTG: 0 DEPTH: (MD) 8,320 (TVD) 5,270 CSG SIZE: 4.500 CSG MD: 8,307.84 CSG TVD: 5,27~. SHOE TEST: ' MAX. $1 0 LINER TOP: PRESENT OP~IG DOWN STAIRS AND WIND WALLS ON BACK OF RIG FLOOR CONTINUE TO DISPLACE CEMENT WITH 6% KCL WATER. RIG DOWN CEMENT EQUIPMENT. CLEAR RIG EXECUTIVE FLOOR- NIPPLE DOWN BOP AND RELATED EQUIPMENT-NIPPLE UP VETCO GRAY TREE. EMPTY OUT MUD SUMMARY SYSTEM AND CLEAN- TEST CASING AT 5000 PSI. ~:~:;:.~::~;:;:~;~:;~;;;;~:~:;~;:~::.::;:::.~::;::::::::;:;:::::::;:~.:::;:::~:.~:;:::~:~::::~::~:::~:~;~;:;;~:;;~:~;:;;;~;;;~.:~;::~:::~:;:;:::::::~:~;~;;;;;:~:~;~;;;~;~:~:::::~;:::::~:::~::;~::::il;:~;::~:~:::~:::::~::::.~:::~::;:::;:;:~:~:::~::::::~:;:::;:~;~;~.::;:::~:::~::!:;:?;~:;.~::;~;:::;:::;::;;;~;:;~;a~:::;:;~;~; 0VIW VIS PV YP GEL8 WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE I I I / I I I ,/ I I ]I / PPB PPB PPB :COIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES Ibbl/It) BKGD CONN TRIP MAX { BIT # SIZE TYPE OFF FTG HRS FT/HR RPM WOB I O O L B G OT R CPF COMMENTS II I)lllll ( BIT # SERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP) I BHA: Length: DRILL PIPE DESCRIPTION: MAX PULL: ( JARS MWD MOTOR TORQUE WEIGHT (1~)00~ '- [ IBHA· Pu Rot So Eft (MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. NIS E/W DOG LEG 7,697.00 48.400 5'/.30 4,86'/.39 5~. 3.56 3,332.55 4,29'/.62 0.63 8,030.00 47.260 50.60 5,090.3'/ 5,686.2'/ 3,49'/.76 4,487.89 0.37 8,265.00 48.740 52.70 5,242.2f 5,854.87 3,596.39 4,620.f9 0°95 ( OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION ' 6:00 7.'00 '/.00 CONTINUE TO DISPLACE CEMENT WITH ~,4 KCL WATER USING RIG PUMP- PUMPED 3,320 STROKES- 'PLUG DID NOT BUMP'- BLEED DOWN PRESSURE AND TEST FLOATS- FLOATS HELD - CEMENT IN PLACE AT 0~:40 HOURS , 7:00 ~:00 '/.00 FLUSH AND BLOW DOWN CEMENT LINES. TEST HANGER AT 5000 PSI. 'TESTED GOOD' 8:00 9.'00 '/.00 RIg DOWN CEMENT HEAD AND BACK OUT LANDING JOINT- SET BACK PRESSURE VALVE. Rig DOWN CASING ELEVATORS AND CLEAR RIG FLOOR 9:00 '/4:30 5.50 NIPPle DOWN BOP AND RELATED EQUIPMENT- PLACE BOP STACK ON CARRIER AND LAY , OVER - REMOVE SECOND ANNULUS VALVE FROM WELL HEAD - INSTALL VR PLUg AND COMPANION FLANge. , ,. '/4:30 '/6:00 '/.50 NIPPle UP VETCO GRAY TUBING HEAD ADAPTOR SPOOL AND TREE '/6:00 '/9:30 3.50 TEST PACK OFF AT 5000 PSI. 'NO GOOD' PULL BPV- INSTALL TWC- ENERGIZE PACK OFF TEST ~ 5000 PSI. Fl'~5 MIN- ATTEMPT TO TEST TREE, TIGHTEN UP CAP FLANGE- TWC c~,~Ng, PuLL m~c AND REDRESS AND CC~,U~. INSTALL m~C TESt TREE ~ 250 PSI. AND 5000 PSI. '/9:30 3:00 7.50 EMPTY OUT MUD TANKS AND CLEAN MUD SYSTEM- DRAIN UP MUD PUMPS- RIG DOWN TOP DRIVE ::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~.FE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 09/'/8/00 DAILY: 2,242 CUM: 76,622 DAILY: '/80,874 CUM: '/,075,097 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: DARRELL GREEN .. [~001 09/2.6/00 TUE 06-37 FAX 19075646489 Marathon011 Co //f~'.,/. / , .... Li,~........., Peter Berga Marathon ( t: DATE: 0§~6/00 LOCATION & ~: ., SPUD DAYS: fa Oil Company AFE#: 9~f000 GL: . KB: . MOCWI: WELL: Cannery Loop # 6 RIG: Glacier Drilling Rig I FTG: DEPTH: (MD) 8,320 (TVD) 5,2'[8 CSG SIZE: 4.500 CSG MD~' 8,307.84 CSG TVD: 5,278: ~HOE TES'~': MAX. SI 0 LINER TOP: PRESENT OP:SET MATTING BOARDS AT KD `/4-32 - WAIT FOR DAY LIGHT TO MOVE SUB BASE AND CARRIER RIG DOWN FROM CLU fi 6- SET MATTING BOARDS AT KU EXECUTIVE SUMMARY (MW VlS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE I I I I I I I { .i I } 1~2 {} I.. PPB_ PPB PPB ¢o,. w~. ,, ,. ,, ~ c. c^ .,~; ,,u~,oss;slb~.~ ~ co.. m. :~:~:::;:;1;:~:::~:;:~:;:;~:;:;'~;~:~;.-~;:;?::~:::::;:~:::::::~:~:~:~:~:;?;~;:~:~::::~;~::~::;:;:;:;:;:~;~:::~:::;:;:;:;~:~:~;:;:;~:~:::~:;..;:;::~:~::::::~;:~::::;:::~:::;:::::::~::~::;:~:~:~:;:;:;:;:~:;:;:;~;::~;:;~;:;:;:;:::;:~:;:;~:::::~:~:;:;:;:;~;:;~:~:;:;::~;~;:; ~ B.{T# SIZE TYPE OFF FTG HRS FT/HR RPM WOB IOD LB GOT R CPF COMMENTS ( BIT # SERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP~ ' I BHA: Length: DRILL P{PE DESCR{PT{ON: MAX PULL: ,. ( JARS MWD MOTOR TORQUE WBGHT (m O00) { { I I I I IBHA' PU Rot So Eft .......... , ......... ,...,.,, ......... ,., ............ , ..................... , ..... , .............. .., ...... . (MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. N/S E/W DOG LEG '[,687,00 48.400 5`/.30 4,e6`/.39 5,433.56 3,332.55 4,29`/.62 0.63 8,038.00 47.260 50.60 5,000.3`/ 5,686.2,/ 3,4.9`/..'[6 4,487.89 0.37 8,268.00 48.740 52.'[0 5,242.2'/ 5,e54.87 3,596.39 4,620.~9 0.95 ~'~'~;;~;~;;`~:;:;;;;;;:~;~H;:;~t:;~;~;;t;`~t~t~t~::;;t;!:`~;~t~!:!:~;t~t~t~t~t:~:;:;:;t;:;~;~;~;:;Ft;t~t;~;~;~;~H::~;o'''''o'''''''''''''''o'''''''o'''o ~;~;~'~'~'~`'~`!~'~'~`;~'~1~t:~;t;t;t~;~H:;t;~;;;~;;:;t;t~;~t~;~ ,,:t:!;t;t:;;;:t;;;~;~:;:i:i;~;t;;:;;i;,; |:,';;;~;~;|;;:;;:;,';;;;:;;;;;;t;'~:~:~:;;~ START END HOURS DESCRIPTION 6.~)0 6:00 24.00 RIG DOWN TOP DRIVE AND RAIL, REMOVE FROM RIG FLOOR - REMOVE WIND WALLS' FROM AROUND BACK OF RIG FLOOR - REMOVE THREE SETS OF STAIRS AND LANDINGS - PULL WIRES FROM SUB, PITS, AND MOTOR ROOM- PREP DERRICK, scOpE DOWN AND LAY OVER REMOVE FLOW LINE- SEPERATE PITS FROM PUMP ROOM- MOVE THE FOLLOWING TO NEW LOCATION- MUD PITS, PUMP ROOM., BOILER HOUSE, FUEL TANK, GENERATOR BUILDING, MATTING BOARDS- REMOVE CARRIER FROM MUD BOAT- .. REMOVE MUD BOAT SCOPE DOWN SUB BASE AND REMOVE OUT RIGGERS - 'INSTALL GOOSENECK ON SUB - REMOVE DOGHOUSES FOLD DOWN UPPER WIND WALLS - PULL SU~ · BASE OFF OF WELL - PICK UP MATTING BOARDS- PICK UP HERCULITE- SET MATTING BOARDS AT NEW LOCATION FOR SUB BASE AND SUPPORT COMPLEXES - PREP CAMP FOR MOVE- SHUT DOWN TELEPHONES, ELECTRICAL, REMOVE WATER AND SEWER LINES SET BACK PRESSURE VALVE IN WELL CLU fi 6 PRIOR TO LAYING OVER MAST ~kFE: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 09/18/00 iiiiiiiiiiiiiiiiiiiiiiiiilill MUD COSTS ACTUAL ii!iiiii!iiiiiiiiiiiiiiiiiiiliiiiii!i}ii!iiii!iii i WELL COSTS ACTUAL }iili{ iiiiiii LAST BOP TEST DATE= DALLY: 0 CUM: 76,622 DAILY: 2f,95`/ CUM: f,097,048 NO ACCIDENTS REPORTED TODAY D;iLUNG SUPERVISOR: DARRELL GREEN ~001 4* MARATHON OIL COMPAN'( DALLY WELL OPERATIONS R~" PAGE 1 OF 1 DATE: 9/27/00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: TUBING: New well Tag fill, get sample Complete Wire test - 20 turns Kenai Gas Field WELL #: CLU~6 0 CASING: 0 TREE CONDITION: New BENCHES OPEN: None WlRELINE CREW: VanDenberg/Russell Hrs. 8 SUMMARY OF OPERATIONS Check in MOC, meet w/Ralph, get permits Rig down equipment and move from KTU 32-7 Spot equipment, TGSM, test wire, M/U tool string, Roller Stem, rig up W/L RIH w/3.65" GR to 8089'KB, work taols, no hole made, POOH] RIH w! 2.50" DD Bailer w/2.75" OD BTM to 8089'KB, work to 8090'KB, POOH w/sample of mud hard packed Rig down W/L equipment, clean area and tools Move equipment back to KTU 32-7 Complete report Depart field SUMMARY: Ran 3.65" GR to 8089'KB Ran 2.50" DD Bailer to 8090'KB, return w/mud TOOL COST: 3.65" Gauge Ring 50.00 2.50" DD Bailer 150.00 Roller Stem 100.00 Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. W/L unit w/2 man crew $1,150.00 $1,150.00 Pollard Wireline Inc. Tools $300.00 $300.00 Pollard Wireline Inc. Fuel $52.00 $52.00 DALLY COST: $1,502.00 CUM: $1 ~502.00 REPORTED BY: Earl McKibben MARATHON OIL COMPAI(' DALLY WELL OPERATIONS DATE: 10/17/00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Cannery Loop Unit 1 TUBING: CASING: 9/27/00 TREE CONDITION: Drill out cement, Jet to 4000' BENCHES OPEN: Complete CREW: PAGE I OF 1 WELL #: CLU-6 New None Key/Howell/Payment 15 SUMMARY OF OPERATIONS Ardve on location Begin RU. Crane problems. Wait to repair Crane fixed BOP Test to 4000 psi, P-Test to 3000 psi RU Schlumberger RIH w/CT. Dry fag cement at 8005'. Begin milling. Plublng -2900 psi, pump 1.7 bbl/m 125 bbl fluid pumped. Milling cement at 8104' Milling at 8172' Milling at 8215'. Pumped 303 bbl total Milling at 8236'. Milling at 8243'. Pumped 356 bbl total Tag solid at 8243'. Motor stall indicates solid stop. Likely float collar. Circulate. Begin mixing KCI Pump KCI at 1.8 bpm while POOH. Drop ball to circulate nitrogen PU to 4000'. Spill from return tank. Call operator. Wait on vac truck Circulate N2, lifting fluids. PU to surface. RD SLB for night. Vendor Equipment Daily Cost Cumulative Cost Schlumberger Equip. + Crew $37,031.62 $37,031.62 R & K Hauling $2,956.00 $39,987.62 Doyle's Fuel $412.94 $40,400.56 DALLY COST: $40,400.56 CUM: REPORTED BY: Earl McKibben MARATHON OIL COMPAN( .... DALLY WELL OPERATIONS R( .. PAGE 1 OF 1 DATE: 10/23/2000 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Cannery Loop Unit WELL #: TUBING: 4-1/2" 12.6 ppf L-80 CASING: 9/27/2000 TREE CONDITION: New Perforate the Sterling C-1 and C-2 BENCHES OPEN: None Complete CREW: Hrs. 12 CLU-6 SUMMARY OF OPERATIONS Arrive on location Held safety meeting. RU Schlumberger wireline service w/full lubricator, flow tubes, and pump in sub. Pressure test lubricator to 2700 psig using methanol. Held fine. Prepare to perforate the Sterling C-1 and C-2 sands. Initially have an 838 psig underbalance. Run #1 Perforate the C-1 sand from 7846-7860' using 3-3/8" HSD gUns loaded 6 SPF, 60 degree 3hased w/P J3406 HMX 22.7 gram charges. APl target (5713 psi) data shows 0.45" OD EH 3nd 38.6" penetration. Correlated depth to Schlumberger RST-Sigma log dated 19 October, 2000. Pressure climbed to 250 psig in 1 minute. Then to 500 psig after 1 hour. Run #2 Perforate the C-2 sand from 8014-8024' using 3-3/8" HSD guns loaded 6 SPF, 60 degree 3hased w/P J3406 HMX 22.7 gram charges. APl target (5713 psi) data shows 0.45" OD EH 3nd 38.6" penetration. Correlated depth to Schlumberger RST-Sigma log dated 19 October, 2000. Pressure prior to perforating was 1100 psig. Pressure after firing had climbed to 1350 psig. RD Schlumberger WL service and prepare to unload well. Unload well as per attached sheet. Vendor Equipment Daily Cost Cumulative Cost Schlumberger Equip. + Crew $17~328.00 $17,328.00 Toloff Crane $1,600.00 $18,928.00 R&K Light Plant $150.00 $19,078.00 Total $19,078.00 DAILY COST: $19,078.00 CUM: REPORTED BY: Affinito / McKibben MARATHON OIL COMPAN'('" DALLY WELL OPERATIONS R~' ,T PAGE 1 OF 1 DATE: 10/28/00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: TUBING: Flow Gradient/Build Up Survey In progress FIELD: Kenai Gas Field WELL #: CLU-6 1780 Flowing CASING: TREE CONDITION: BENCHES OPEN: WIRELINE CREW: VanDenberg/Doherty Hrs. 8 SUMMARY OF OPERATIONS Travel to KGF Sign in, check & warm up equipment, discuss job, get permit Move equipment to location, TGSM Test wire, 20 & 22 turns, make up tool string: (1 1/2") RS, K J, Anti-blowup, X-over, 10' Tungston Stem, K J, 5' Tungston Stem, O J, K J, SA rig up W/L program gauges, Total time, 55 hours 50 minutes Interval: 1. 10 hrs. @ 1 sec. rate time on: Upper # 2081 12:51:48 2.42 hrs. @ 12 sec. rate Lower # 2110 12:50:11 3. 3 hrs. 50 min. @ 1 sec. rate estimated time off bottom 10/30/00 17:00 P.T. Lub w/methanol to 2000 # -- passed Opened Swab, 10 minute Lub stop RIH w/Tandem Electronic Memory Tools, stops @ 7000', 7700', and 7800'KB, 10 minutes each, RIH to 7853'KB, 10 minute Flowing stop Shut in well, secure equipment Depart field SUMMARY: Ran Flowing Gradient Survey, Left Gauges "hanging" on wire @ 7853'KB, TOOLS: Tungston Stem 150.00 Anti-blowup Tool 50.00 Shock Absorber 50.00 Tandem Electronic Gauges 800.00 Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. W/L Unit & crew $1,150.00 $1 ~150.00 Pollard Wireline Inc. Tools $1,050.00 $1,050.00 DALLY COST: $2,200.00 CUM: $2,200.00 REPORTED BY: Denise Titus MARATHON OIL COMPANy' DALLY WELL OPERATIONS R~" .,.T PAGE 1 OF I DATE: 10/30/00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: TUBING: 1 O/28/OO Survey Complete Kenai Gas Field WELL #: CLU-6 CASING: TREE CONDITION: BENCHES OPEN: WlRELINE CREW: VanDenberg/Doherty Hrs. 8 SUMMARY OF OPERATIONS Sign in, get permit, travel to location TGSM, check & warm up equipment Begin pulling OOH w/Tandem Gauges, making Gradient stops @ 7800', 7700', & 7000'KB, final stop in Lub. OOH w/tools, download - good data Rig down W/L Depart location, move equipment to MOC Pad Complete report Depart field SUMMARY: Completed Static Survey TOOLS: ALL 2 DAY RENTALS 10/29-30/00 Anti-blowup 100.00 Shock Absorber 100.00 Tandem Gauges 1600.00 Tungston Stem 300.00 Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. Unit & crew $1,150.00 $1,150.00 Pollard Wireline Inc. Tool $2,100.00 $2,100.00 Pollard Wireline Inc. Fuel $50.00 $50.00 ,,, DAILY COST: $3,300.00 CUM: $3,300.00 REPORTED BY: MARATHON OIL COMPAN'~" DALLY WELL OPERATIONS R~' .'T DATE: 1/9/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: TUBING: Drift and hang Gauges In progress Wire test: 20 1/2, & 24 Kenai Gas Field 1850# CASING: TREE CONDITION: BENCHES OPEN: WlRELINE CREW: PAGE l OF 1~1~/t~~ WELL#: CLU-6 ~ New VanDenberg/Doherty 12 SUMMARY OF OPERATIONS Depart shop Sign in, get permit, discuss job w/Wayne Cissell, check equipment, move to location Pressure test BOP in Marathon's shop area, test to 3900 #, passed TGSM: Snow, rig up Spot equipment, test wire, make up tool string, pump in sub, rig up W/L Pressure test Lub w/well pressure to 1650 #, passed Shut in well RIH w/Bomb Hanger & 3.75" GR to 8101' KB, pull up to 7850' KB, test set hanger, OK, reset @ 7800' KB, OK, test twice more, OK, POOH aaH w/tools, removed OJ's, make up next BHA Started Memory Gauges RIH w/soft set, Bomb Hanger, shock Absorber, Tandem Gauges w/Centralizer, stop in Lub 10 mtn, RIH to 7853' KB, attempt to set hanger, could not, RIH to lower pens to trip tool, set down 8057' KB, picked up lite, pull up to 7853' KB, (still lite), attempt to set tool, could not, POOH RIH w/2" JDC to 8058' KB, could not latch tools, POOH RIH w/Bell Skirt, 2" JDC (2.37" OD Bell), to 8058' KB, latch and pull tools, POOH aaH w/tools, break down BHA, lay Lub down for the night, secure well Depart location SUMMARY: Drifted to 8101' KB, w/3.75" GR, attempt to set Memory Gauges TOOLS: 3.75" GR $50.00 Soft Set $150.00 N/C Bomb Hanger $175.00 N/C Shock Absorber $50.00 N/C Bowspring Central $50.00 N/C Tandem Memory Gauges $800.00 N/C 2" Skirted JDC $75.00 N/C Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. Unit & crew $1,500.00 $1,500.00 Pollard Wireline Inc. Add hours $400.00 $1,900.00 Pollard Wireline Inc. Tool cost $50.00 $1,950.00 DAILY COST: $1,950.00 CUM: $1,950.00 REPORTED BY: Wayne Cissell MARATHON OIL COMPAN(' DATE: 1/10/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: DALLY WELL OPERATIONS R~.. PAGE 1 OF 1 Hrs. FIELD: Kenai Gas Field WELL#: CLU-6 ~ TUBING: 1850 # CASING: TREE CONDITION: Hang Gauges BENCHES OPEN: In progress WIRELINE CREW: VanDenberg/Doherty 11 SUMMARY OF OPERATIONS travel to location Sign in, permits, move to well site TGSM: Extra Lub, snow, slick Rig up W/E program gauges, make up tools Started Gauges RIH w/soft set, hanger, shock, gauge, cent, gauge stop in Lub 10 min, RIH to 6089' KB, set down, could not work deep, soft set released, POOH RIH w! skirted 2" JDC to 6088' KB, latch and pull gauges, POOH, reprogram and restart gauges, added KJ below Centralizer between gauges RIH w/same stop at surface 10 min, RIH to 5596' KB, could not fall past, POOH w/tools OOH w/tools, reprogram, change tool string Stop in Hanger 10 min RIH w/anti blow-up, shock, tandem gauges to 7853' KB, hang gauges on wire Begin Flow test steps as per procedures, monitor tools and equipment SUMMARY: Attempt to set Gauges on Hanger, begin Four Point Test Hanging Gauges w/ W/L in well Tool Cost: ;oft set $150.00 N/C ~omb Hanger $100.00 N/C ;hock Absorber $50.00 ~owspring Cent. $50.00 N/C Tandem Gauges $800.00 2" Skirted JDC $50.00 N/C Anti Blow-up Tool $50.00 Leaded Stem $150.00 Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. Unit & crew $1,500.00 $1,500.00 Pollard Wireline Inc. Add hours $300.00 $1,800.00 Pollard Wireline Inc. Tool Cost $1,050.00 $2,850.00 Pollard Wireline Inc. Fuel $46.00 $2,896.00 DAILY COST: $2,896.00 CUM: $2,896.00 REPORTED BY: Wayne Cissell MARATHON OIL COMPAN~Ii~I DALLY WELL OPERATIONS RIE(" .T PAGE I OF 1 DATE: 1/11/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: TUBING: 4 Point Flow Test In progress Kenai Gas Field WELL #: CLU-6 CASING: TREE CONDITION: BENCHES OPEN: WIRELINE CREW: VanDenberg/Doherty Hrs. 24 SUMMARY OF OPERATIONS Monitor W/L Equipment while wire in hanging in well w/Gauges ;UMMARY: Continued Flow Test Survey, see Data Sheet for rates & time TOOL COST: Anti blow-up $50.00 Leaded Stem $150.00 Shock Absorber $50.00 Tandem Gauges $800.00 Roller Stem $100.00 *Special Rate for Crew Charges $50.00 per hr Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. Crew * $1,200.00 $1,200.00 Pollard Wireline Inc. Tools $1,150.00 $2,350.00 DALLY COST: $2,350.00 CUM: $2,350.00 REPORTED BY: Wayne Cisse~ll MARATHON OIL COMPANY( DALLY WELL OPERATIONS RL~. .T PAGE 1 OF 1 DATE: 1/12/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: TUBING: Flow test Survey Complete Kenai Gas Field WELL #: CLU-6 CASING: TREE CONDITION: BENCHES OPEN: WIRELINE CREW: VanDenberg/Doherty Hrs. 18 SUMMARY OF OPERATIONS Monitor W/L Equipment while wire is hanging Gauges in well POOH, stop @ 7800', 7700' & 7000' KB, 10 rain gradient stops, continue aaH, stop in Lub 10 rain aaH, had to lay Lub down to get tools ( stuffing box froze) Turn off Gauges, begin download - data good, rig down W/L equipment, secure tree, return well on Production, move equipment off location, fuel and return to Mac Office Pad SUMMARY: Completed Survey Max BHP 2130# BHT 102.6 degrees TOOL COST: Anti blow-up $50.00 Leaded Stem $150.00 Roller Stem $100.00 Shock Absorber $50.00 Tandem Gauges $800.00 * Add hrs special rate $50.00 hr Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. Unit & crew $1,500.00 $1,500.00 Pollard Wireline' Inc. 6 add hrs * $300.00 $1,800.00 Pollard Wireline Inc. Tool Cost $1,150.00 $2,950.00 Pollard Wireline Inc. Fuel $95.00 $3,045.00 DAILY COST: $3,045.00 CUM: $3,045.00 REPORTED BY: Wayne Cissell CoilCADETM CUSTOMER REPORT Operator : Marathon Oil Company Country · United States State · Alaska County · Kenai Prepared for · J. Gary Eller Proposal No. · 1 Date Prepared' 09-29-2000 Well : CLU #6 Field · Cannery Loop Unit Formation · Location : Service Point : Kenai Business Phone : 1-907-274-0713 FAX No. :1-907-776-8158 Prepared by · Phone - E-Mail Address ' James Franks 1-907-273-1739 franks(~prudhoe-bay.dowell.slb.com ,, Disclaimer Not,ce: This information is presented in good faith, but no warranty is given by and Dowell assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the wall, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Dowell's best estimate of the actual results that may be achieved and should be used for comparison pu~posas rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Dowell can assist in selecting. The Operator has superior knowledge of the well, the resewoir, the field and oonditions affecting them. if the Operator is aware of any conditior~ whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Dowell or others is not to be infarmd. Dowell Client · (' . ..~on Oil Company Well : CLU #6 Formation: District : Kenai Country : United States Loadcase: Untitled Section 1: Wellbore Configuration Deviated Hole ...................... YES Treat Down .......................... TUBING Flush Volume to Open Hole Configuration No Tubing. Casing Data OD Weight ID Depth (in) (lb/fi) (in) (ft) 4.500 11.6 4.000 8320.0 Section 2: Wellbore Simulator Input-CT Drilling Initial Wellbore Conditions Initial CT Liquid Initial Wellbore Liquid Fluid Column Top in Wellbore CT Standoff (100% is centered) ........... Slick 2% KCL Water 0.0ft 100.0 % Rock Properties DHII From 8120.0 ft Cuffings Size 0.010 in Specific Gravity 1.90 Liquid Pump Schedule Stage CT Final CT Stage Liq Liq Pump Stage Name Speed MD Duration No Rate Volume (ft/min) (fi) (min) ( ) (bbl/min) (bbl) dh 3 8319.0 106.3 2 1.50 159.5 pooh -3 8000.0 106.3 2 1.50 159.5 rih 3 8319.0 106.3 2 1.50 159.5 pooh -5 8000.0 63.8 2 1.50 95.7 Pumping sequence from stage number I to stage number 2 is performed I time(s). Section 3: Wellbore Simulator Results- CT Drilling Percentage of Total Cuttings Removed from Well ...... 96.8 % First Cuttings at Surface at .................................... 125.7 rain Liquid Pumped ................................................... 188.5 bbl Last Cuttings at Surface at .................................... 382.8 rain Liquid Pumped 574.2 bbl Dowell Client · ..ton Oil Company Well : CLU #6 Formation: District : Kenai Country : United States Loadcase: Untitled Pressures Maximum At MD * At Time Minimum At MD * At Time (psi) (fi) (min) (psi) (fi) (min) CT Internal 3309 8309.0 106.3 1828 0.0 382.8 Pressure Top of Form 2304 8280.0 275.5 2285 8280.0 382.8 Pressure Pressure 2315 8320.0 275.5 2239 8120.0 382.8 Below Bit CT Burst 2356 -4821.5 275.5 Pressure (+) CT Collapse 0 8014.5 4.8 Pressure (+) Velocities I Maximum At MD At Time Minimum At MD At Time (IVmin) (fi) (min) (ft/min) (fi) (min) Ann Mixture 124 6596.0 91.8 98 3414.0 106.3 Velocity Ann Cuffings 123 6596.0 91.8 98 3542.0 106.3 Velocity Cuttings Transport Minimum ** At MD At Time (fi) (min) Transport 0.98 395.0 159.5 Ratio * Negative depths indicate the length of coiled tubing from the wellhead to the reel,. ** Transport Ratio = Solid Velocity / Mixture velocity. Section 4: Treatment Fluid Data Fluid Surface Temperature is at 80 degF. Fluid 1- 2% KCL Water Rheology Data: (Power Law) Temperature: 80 degF Base Fluid Specific Gravity: 1.00 Shear Rate: 170 lis Viscosity: 0.934 cP n-prime: 1.00 K-prime: 1.95E-5 Ibf. s^n/ff2 Only in case of Herschel Bulkley'. Yield Point: 0.00 Ibf/100ff2 Friction Data: Rate Low: 1.0 bbl/min Pressure Low: 330.0 psi/1000ff / [ Dowell Client ' .,non Oil Company Well : CLU #6 Formation: District : Kenai Country : United States Loadcase: Untitled Rate Pivot: 1.5 bbl/min Rate High: 1.8 bbl/min Pressure Pivot: Pressure High: Fluid 2- Slick Rheology Data: (Power Law) Temperature: 80 degF Base Fluid Specific Gravity: 1.00 Shear Rate: 170 lis Viscosity: 0.974 cP n-pdme: 0.43 K-pdme: 3.80E-4 Ibf. s^n/ft2 Only in case of Herschel Bulkley: Yield Point: 0.00 Ibf/100ff2 Friction Data: Rate Low: 2.3 bbl/min Rate Pivot: 3.3 bbl/min Rate High: 4.7 bbl/min Pressure Low: Pressure Pivot: Pressure High: Section 5: Tubing Forces Input 700.0 psi/1000ff 1000.0 psi/1000ff 100.0 psi/10001t 200.0 psill000ft 400.0 psi/1000ft Coiled Tubing Data Stripper Friction Load .............................. 1000.00 Ibf Pickup Reel Back Tension ...................... 1000.00 Ibf Slackoff Reel Back Tension .................... 500.00 Ibf Fluid Data Internal Fluid Density .............................. 8.40 lb/gal External Fluid Density ............................. 8.40 lb/gal Fluid Level .............................................. 0.0 ff Well Head Pressure ................................ 500 psi CT Circulating Pressure .......................... 3600 psi Analysis Information Maximum Tool Depth .............................. 8320.0 ff Analysis Tool Depth ................................ 8320.0 ff Compressive Load on Tool ..................... 1800.00 Ibf Tensile Load on Tool .............................. 0.00 Ibf Friction Data Friction Coefficient RIH .......................... 0.40 Friction Coefficient POH ......................... 0.18 Section 6: Tubing Forces Results Dowell Client · ..,ton Oil Company Well : CLU #6 Formation: District : Kenai Country : United States Loadcase: Untitled Did Lockup occur?. ........................................... NO Maximum Pickup Tension ................................... 9755.74 Ibf Minimum Slackoff Tension .................................. -2383.57 Ibf Maximum Von Mises Stress POH ....................... 24311 psi Maximum Von Mises Stress RIH .............27709 psi Maximum Percent Yield Stress ............................ 34.6 % Maximum Percent Helical Buckling Load ............. 140.9 % Tool string will travel to total depth unhindered. Lm.~,m~.m~ Dowell CoilCADE* Coiled Tubing Weight Indicator Load Marathon Oil Company CLU #6 Untitled 09-29-2000 10000 ~ Pickup 8000- ~.- --- Si.ackoff / 6000 / 4000' / 2000: - - .... - ..... I O ~ ~..~- Stripper Friction Load - 1000 Ibf ......-~ Well Head Pressure - 500 psi ...---: Coiled Tubing Circ. Pressure- 3600 psi Tensile Load on Tool at Max Depth - 0 Ibf _,.-*'""~" Compressive Load on Tool at MaxDepth - 1800 Ibf -2000: ~- · -4000 · · · , ..... 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 Measured Depth of Tool String - ff *Mark of 8ehlumber~ler Dowell Client Well Formation District Country Loadcase Marathon 0il Company CLU #6 Kenai United States Untitled CoilCADE* Weilbore Simulator - Percent Solids to Surface Marathon Oil Company CLU fl6 Untitled 09-29~2000 100 ., . Percent Solids to Surface --- Return Fluid Quality , .. . . . 90' 80- 70' 60' 50, 40' 30. 20. 10 0 0 100 200 300 400 Treatment Tim e - rain *Mark of Sohlumberger Dowell Client : Well : Formation: Distri~ : Country : Loadcase: Marathon OII Company CLU #6 Kenai United States Untitled CoilCADE* Maximum Stress During Pickup Marathon Oil Company CLU #6 Untitled 09-29-2000 40¸ , , Stripper Friction Load - 1000 Ibf Well Head Pressure - 500 psi Coiled Tubing Cim. Pressure- 3600 psi Tensile Load on Tool at Max Depth - 0 Ibf Compressive Load on Tool at MaxDepth - 1800 Ibf , , , ~ 30 a. 20. × 10. ,, 1000 2000 3000 4000 5000 6000 7000 8000 9000 Measured Depth of Tool Stdng- ft *Mark of 8=hlumber~ler Schlumberger Well CANNERY'LOOP 6 Coiled Tubing Service Report I!~!:~i!!.'.;~i!~!!~!~i~!..';!~!~!i!i!:!:~!.-.'~!~ ~~~ '"'~ ""~ ~ ~'~ ~ ~' ':' '''¥''' '''''':! ............... ':"" ~i~~~ii~i1~i~i~ii~ii!i~!i~~!iii~==================================================================================== :'"~::"?':::'"::'" ~::' ":'"::~"':'""~":'%"~'~" Location (legal) Dowell Location Job Start Kenai, AK 10/16/00 Field County CANNERY LOOP Formation Name/Type Clean-Sandstone Deviation Rig Name Slata~rovince AK Drilled For i Service Via Gas I Land o,d C)ffshom Zone Well Class Well Type Development Primary Treating Fluid Fluid Viscssity I Fluid Density 3%KCl 0 cpI lb/gal CT Reel ID I CT String iD I CT b ~ Thickness 15Dg436 I 5053 I 1.5 in 0.11 in Service Line I Job Type Coiled Tubing I CT Well Clean-Out Service Max. Allowed Tubing Pressure , Max. Allowed Ann. Pressure I WellHead Connection 3500 psi 0 psiI RX39 5K service Instructions 0 o BHP 0 psi .:.:.':.::.:::~.':::::::.:-:.:.:.':.:.....:.:.:.:.:.: 0 0 0 0 0 0 ~~~~~'~ - .~., ~-.;~- . ;1~1;~ ,-~ ~-~;,-,-.--~ ~..-~- .~... BitSize: Well MD Well TVD I oin oft I oft o 'FI O'F I o ~;~;*..~:~;~;!~ ~:~"-'~-'~'"~."-~-'"-"%::!~.i ~!::~'"~r"~;!~:~-'"':~::~:~ ::::::::::::::::::::::::::::::::::: ::::~~:,,:::.~ ::::::::::::::::::::::::::::::::::::::::::::::::: Size, In Welg~ I~ Grade I Thmed I 0 0 0 0 Sl~, in Weigh, in Grade I Thmed 0 0 N~ ~Sh~ I T~I I~1 I 0 0 0 0 in Provide 1.5" Coiled Tubing Unit and support equipment for milling cement as I Treat Oow. per customer's request. I Coiled Tubing I Tubing Vol. , 0 bbl Job Scheduled For. Arrived on location: Leave Location: I Fill Type I ) 10/16/00 I:00:00PMI 10/18/001:00:00PMI Cement CasingVoI.Dlsplacement00 bblbbl I' PecknrTypeNone Packnr Depth Off AnnulazVol, OpenHoleVol 0 bbl 0 bbl Fill Depth Minimum RssMcflon 8400 tt 3.813 in 0 0 1200 2350 275O 4500 OCt 20,2000 WRS3 v3.0-SR Safety Meeting Rig Up CTU Off Location Safety Meeting ~onl Rig up Generator problem Crane Rig up ~IU BHA BOP Testing Load Coil w/KCL Pressure test MU BHA Go to well Pressure test Safety Meeting Open well/RIH Check Check Page 1 of 2 CANNERY LOOP ~6 CANNERY LOOP - · MARATHON OIL CO D3583~''''''I -. ~!~...[::-~:~,::..[ ~- ~:. ~::.~L~:~:/.~.~~}~:I:~.:~~':::~::~':~?.:2.'~-~:~'"~.~:'~~.:::~ · ~;~.".~':._'" ~:~:.~ '." '~':'~." · ?' .. ~ ~ ~~.'. ~,: L.~'~ ~ .~,~-..[~i,~"~(~ ':.:~ :.. ~' ..~'. · ~ ~t ~.. · .. .....~ ................... .~...- ..... ~ . J ~ ....· . . ..: ~.. s..~¥..: :~ . :: ..... : ~ ~. : ..... :.. ? .... . . .: ..... '.~k'..~: ~"~::~.:".~.~: ~ ::'.~.: ..':': '"~.~:::.?::'~?..~'.-..: ~.'~:~:'~ ': :~'.' :: "~l' :'.' .L'?: ~ ~ ~'~ :~:"? ::? ?:'~: :.: · .'-.'". ..... ~'::~' · .' - ~ ¥ :.~:~.'~,'::~ ....... , .... '.' ....... · ...... ' ...... '-':*: '.:' ..... ~:~1~'. ..... · ..... I.. · ' 1 ................... '--~ .......... ... .... .:.:-...-: ....... ::.~:: .~ 15:31 ~ ~ ~ 0 0.7 0 0 ' 951 0 ~. Ch~k · '~g:~': ~sS- "~-" o o.s o- ' o ': s~2 o W~.Ch~k ............... , ...................................................... 15:57 ' 5~ 9~ 0 0.8 0 0 ~4 0 Wt. Ch~k ~ .. -~F~ ~so ~ o o.~ o o Bm 5' ~. Che~k '~:~ ....'f~ ~2~ 0 ....... 6.~ 0 " 0 S~' ........ ~ 'Wi:'E~ec~ ............... ~S:~': S~" '~0 .... ~ 0 ' d-" 0 .... 0 ' 0 D~'~O~' ' ........... · . ........ ; .................. , .................................... 16:35 : 80~ 13~0 0 1.7 0 0 2~ 0 PUH 10' ~ . ~ ............. : ....... lS:~' ~ -~ 0 1.7 0 0 3~ 6 ~i~i ~eme~ '-1~:1~' ;---81~ 2~ 0 ' '1.~-' 0 0 ' 3223 0 Mill ~me~t .................... ... ............................. 17:~ i 8~ 1~0 0 1.8 0 0 ~ 3~7 ' 0 Mill ~me~ 19:~ 82~ --' ~0' 0 1.8 0 0 - 3~0 · 0 Milling ~me~ ......... : ........... 19:10 i 82~ 1~' .... 0 1.8 ...... ~ ........-~---"~ 3~ ...... ~---'~t de~h ............... __ 19:11 ~' 82~ 13~ 0 1.8 .... 0 0 : 3'~ ...... 0 PUH~ ........................... 19:~ ~ 81~ I 3~0 0 1.8. 0 . 75 ~ 0 S~d 3% KCL o -,- o o o ~'6:-~'- '~4~ ...... ~~' o , ~.2~' '~' ~' o ~H~o~ .......... ~:3o ~ .... '. ~m 0 ................ ~ ................. ; . lStop and cimul~e 2~'~-"~ ~ ~m ~ ~ o ":' 5 ...... o-" ~ . o ~l~'~,d&~ .... ~:~~ ,.~ ~ ....... ~ ...... ~ ..... ~--~ ....... ~-~ ~;~~ ................... ~:oo . ' ....................... .-'~ ...................... F ....... ~-g'H~ .............................. =~:~s, .................................. ~ ...... ~ ................ ~ -~ ~'~,j.'~k .... 2~:~i "' I. ' " ~ .................... ~G'~ ................ .... ~ ........ . .............................................. ~ ............................. 9:~ ! 0 lRig D~n CT UnR "'I .............. ' ......... .......... A~mge Inj~ion Rat~. bpm Volume of Fluid Inj~, bbl FlUid N2 ~ m~lmum ~ Fluid ~ld N2 ~.~ I ~ I o I ~.~ ~ I o I o I o I o ., Tr~ P~re Sure. W, ~ B~kd~ Fluid B~n Maximum Final A~mge ISIP ~ Volume Dens~ o I o o I oI o I I o ~' Lo,~,., Cummer or A~ofl~ ReprOve I ~11 Su~w~r ~ P~um ~p~ ~ Cimul~onL~ Den~ T~us Tab ~ Unde~lanc~ ~ Job Compl~ Oct 20,2000 WRS3 v3.0-SR Page 2 of 2 09/24/00 SUN 20:54 FAX 1907564~9 (" ~arathonOll Co ~ MARATHON OIL COMPANY - GULF COAST REGION CASING AND CEMENTING RECORD Craig Young Page 1 of 2 ~001 Field: Kenai Gas Field Rig: Glacier Drilling Rig #1 Date Run: 9/23/00 Well: CLU # 6 Cement Contractor: Dowell RKB - MWL: 21 AFE: 9701000 Shoe Depth (MD): 8307.84 MWL. ML: 0 Lease: Shoe Depth (TVD): 5271 RKB. ML: 21 Settln~ Depth NO. Jts I Description I Size I TopThreadl Grade I Weloht I Cenoth From ! TO I RKB to: i Han~ier Buttress Casin~l Box 19.66 0.00 19.66 1 I Hanger with X/O pup 4.5" Butt Casing LB0 12.6 # 5.20 19.66 24.86 148 Joints 4.5" Casing 4.5" Hydri1521 L80 12.6 # 6018.35 24.86 6043.21 2 I Pup Joint 4.5" Hydri1521 LB0 12.6 # 5.47 6043.21 6048.68 1 X- Nipple 4.5" Hydri1521 LB0 12.6 # 0.89 6048.68 6049.57' 3 Pup Joint 4.5" Hydri1521 LB0 12.6 # 23.24 6049.57 6072.81 53 Joints 4.5" Casing 4.5" Hydri1521 LB0 12.6 # 2150.64 6072.81 8223.45 1 Float Collar 4.5" Hydri1521 LB0 12.6 # 1,68 8223.45 8225.13 2 Joints 4.5" Casing 4.5" Hydri1521 LB0 12.6 # 80.99 8225.13 8306.12 1 Float Shoe 4.5" Hydri1521 L80 12.6 # 1.72 8306.12 8307.84 1 R-A Ta~l Placed At 6760' 1 R-A Tag Placed At 7244' 1 R-A Tag Placed At 7737' Amount I Type I Spacing I From I To 55 W.elded Bow Spring [Middle Of Joints I Thru 55 With Stop Collars 8279.00 6094.00 I Welded Bow Spring IAround X-Nipple 6050.00 6049.00 I 2 Welded Bow Spring Middle Of Joints 56 Thru 57 With Stop Collars 6025.00 5985.00 I Lead Cement I Other Cement I Other Cement I Tall Cement Cement Type (Class) "G" Mud Push Pre Flush "G" Cement Amount (sx) 161 20 Barrel 386 Additive (gps/dry%)/(Type) 0.20% D046 0.20% D046 Additive (gps/d~%)/IType); 0.15% D065 0.25% D085 Additive (gps/dry%)~Type)' 4.00% S001 0.30% D 167 Additive Igps/dry%)l(Type) 4.00% D020 0.20% D800 Additive (gps/dry%)/( Type ) Mix Water (gps)/Type 11.044 FW 5.089 FW Sluny Weight (ppg) 12.9 15.8 Slurry Yield ICuFt/sx) 2.08 1.18 0 Open Hole Excess (%) 28 · Caliper Log + 25% 28% Caliper Log + 25% Planned Top of Cement Imd) 2500' I 5800' MARATHON OILCOMPANY-GULFCOASTREGION CASING AND CEMENTING RECORD , ~ Cral~ Youn~ ~002 09/24/00 SUN 20:55 FAX 1907564t~489 Marathon01! Co . Page 2 of 2 Field: Kensi Gas Field Well: CLU # 6 Casing Size: 4.5" Circulate Time Prior to Pre-Flush (hrs) 3 Bump Wiper Plug To (psi) 0 Reciprocate Pipe (Yes/No) Yes Cement In Place Time (hrknin) 6:40 Wiper Plug Prior To Pre-Flush (Yes/No) No Floats Held (Yes/No) Y Pre-Flush (Spacer) Type MP XL Mud Lost While Running Casing (bbls) 0 Pre-Flush Volume (bbls) 20 Mud Lost While Circulating (bbls) 0 Pre-Flush Weight (ppg) 10.5 Mud Lost While Pump and Displace Cement (bbls) 0 Wiper Plug Prior To Cement (Yes/No) Yes Total Mud Lost (bbls) 0 Begin Cement Mix Time (hr/rain) 5:25 Inner String Used (Yes/No) No End Cement Mix Time (hr/rain) 6:15 Cement Retums to Surface (CUR)' No Displace With (Cement Unit/Rig Pump) RP Estimated Top of Cement (MD) 2500' Displacement Fluid Type 6%KCL Open Hole Excess Cement Used (%) 53 Displacement Fluid Weight (ppg) 8.70 Open Hole Diameter (in) 6 1/8" Displacement Volume (bbls) 125.2 Landing Weight on Slips/Hanger (1000 lbs) 55 Displacement Rate (bpm) 4.5 Casing Landed On (slips, hanger, liner hanger)l Hanger Final Displacement Pressure (psi) 1250 Sub-Sea Hanger Lockring Installed (yes/No/NA)l N/A Dowell pumped 161 sacks of lead cement, I was told that 200 sacks were in silo. I suggest that some type of measuring device.be used other than what is in place now. Maybe when they order it they are not getting all that they are asking for" I Don't Know". We made up the difference on tail cement. The casing was displaced with 8,7 PPG 6 % KCL water. The plug did not bump. No. Joints I Weight I Grade I Thread I Length No Joints I Weight Grade I Thread I Length 208 12.6 L-80 Hydri1521 8408.61 4 12.6 L-80 Hydri1521 158.63 .............................................................................................................................. Total 8408.61~.......~...................-....................~...............~..............~....................... ........................................................................................................ Total 158.63 Motor Vessel:I Tommy Coursen Motor Vessel:I, Tommy Coursen Manifest No.:l Manifest No.:l Signed: Darrell Green Approved;' Date: 9/24/00 Date: 09/24/00 · SUN 18:54 FAX 19075646~t~9 ( MarathonOll Co ~ Cralg Young ~ 001 ,I Casing Data :Weight 12.60 Grade L-80 Thrd I-lyclri1521 ID 3.958 DdR 3.833 Thds par Inch 3.360 Coupling OD 4.729 Coupling Length MU Loss 3.620 Burst 8,431 Collapse 7,500 Tensile (1,000 lbs) 121 Min Toque 3,900 MU Toque 4,465 Max Torque 12,800 Disp (dry) 0.01967 Disp (full) 0.00445 Capacity 0.01522 Marathon Oil Company Cannery Loop Field CLU ~ 6 4 112" Casing Job Well Data Drilled Depth 8,320 4 1/2" Shoe Depth 8,308 Mud Weight 9.1 Load Shoulder Depth 20.58 Planned Shoe Depth 8,307.84 Planned FC Depth 8,223.45 JL No. Leng~ Cum Box Total Cum Cummulative DIsp Remarks LenOth Depth Jnts Wt Dry Full Float Shoe 1.72 1.72 8,306.12 18 0.03 0.01 Bakerlock 1 41.57 43.29 8,264.55 1 470 0.85 0.19 Bakerlock-Centrilizer W'dh Stop Collar Middle Of Joint 2 39.42 82.7t 6,225.13 2 697 1.63 0.37 Bakedock-Centrilizer W'dh Stop Collar Middle Of Joint Float Collar 1.68 84.39 8,223A5 916 1.66 0.38 Bakedock 3 39.28 123.67 8,184.17 3 1,342 2.43 0.55 Bakedock Pin End- Centrilizer Middle Of Joint 4 39A7 163.14 8,144.70 4 1p770 3.21 0.73 Centrilizer With Stop Collar Middle Of Joint 6 36.66 201.79 8,106.05 5 2,189 3.97 0.g0 Centrilizer With 8top Collar Middle Of Joint 6 40.00 241.79 8,066.05 6 2,623 4.76 1.08 Centrilizer With Stop Collar Middle Of Joint 7 40A9 262.26 8p025.56 7 3,063 5.55 1.26 Centrilizer VV'dh Stop Collar Middle Of Joint 8 41.00 323.28 7,984.56 8 3,507 6.36 1.44 Centrilizer W'dh Stop Collar Middle Of Joint 9 40.99 354.27 7,943.57 9 3,952 7.17 1.62 Centrilizer W'db Stop Collar Middle Of Joint 10 40.87 405.14 7,902.70 10 4,396 7.97 1.60 Centrilizer With Stop Collar Middle Of Joint 11 40.97 446.11 7,86t .73 11 4,640 6.77 1.99 Cenbilizer W'dh Stop Collar Middle Of Joint 12 41 A9 487.60 7~820.24 12 5,290 9.59 2.17 Centrilizer With Stop Collar Middle Of Joint 13 41.50 529.10 7,778.74 13 5,740 10Al 2.35 Centdlizer With Stop Collar Middle Of Joint 14 41 A8 570.58 7,737.26 14 6,190 11.22 2.54 ' Centrilizer With Stop Collar Middle Of Joint 1S 41 AS 612.07 7,895.77 15 6,541 12.04 2.72 16 41.14. 653.21 7,654.63 16 7,067 t 2.85 2.91 Centrilizar With Stop Collar Middle Of Joint 17 41.05 694.26 7,613.56 17 7,532 13.66 3.09 Centrilizer With Stop Collar Middle Of Joint 18 39.32 733.58 7,574.26 18 7,959 14.43 3.26 Centrilizer With Stop Collar Middle Of Joint 19 4t .54 775.12 7,532.72 t9 8,410 15.26 3A5 Centrilizer W'dfl Stop Collar Middle Of Joint 20 41.56 616.68 7,491.16 20 8,861 16.06 3.63 Centrilizer With Stop Collar Middle Of Joint 21 41.55 858.23 7,449.61 2! 9~311 16.88 3.82 Centrilizar W'dh Stop Collar Middle Of Joint 22 41.56 899.79 7,408.05 22 9,762 17.70 4.00 Centrilizer With Stop Collar Middle Of Joint 23 39A3 939.22 7,368.62 23 10,190 18A7 4.16 Centrilizer With Stop Collar Middle Of Joint 24 4t .57 980.79 7,327.05 24 10,541 19.29 4.36 Cantrilizer With Stop Collar Middle Of Joint 25 41.58 1,022.37 7,266A7 25 11,092 20.11 4.55 Centrilizer With Stop Collar Middle Of Joint 26 41.57 1,063.94 7,243.90 26 11,543 20.93 4.73 ICenl~ilizar. With Stop Collar Middle Of Joint 27 39A9 1,103.43 7,204.41 27 11,972 21.70 4.91 ~(~q~..~ 28 39.54 1,142.97 7,154.87 28 12,401 22A8 5.09 !Centrilizer With Stop Cellar Middle Of Joint 29 40Ag 1, t 63.46 7,124.38 29 12,840 23.28 5.27 Centrilizer With Stop Collar Middle Of Joint 30 41.57 1,225.03 7,082.81 30 t 3,291 24.10 5A5 Ce ,ntrilizer With Stop Collar Middle Of Joint 31 41.56 1,266.59 7,041.25 31 13,742 24.91 5.54 Cenbilizer With Stop Collar Middle Of Joint 32 41.56 1,308.1 5 6,999.69 32 14~ 193 25.73 5.82 Centrilizer With Stop Collar Middle Of Joint 33 38.80 1,346.95 6,960.89 33 14,614 26.49 5.99 Centrilizer With Stop Collar Middle Of Joint 34 40.89 1,387.84 6,920.00 34 15,067 27.30 6.18 Centrilizer With Stop Collar Middle Of Joint 35 41.57 1,429.41 6,878A3 35 15,508 28.12 6.36 Centrilizer With Stop Collar Middle Of Joint 36 41.57 1,470.98 6,836.86 36 15,959 28.93 6.55 Centrilizer With Stop Collar Middle Of Joint 37 36.48 1,507A6 6,600.36 37 16,355 29.65 6.71 Centdlizer With Stop Collar Middle Of Joint 38 39.60 1,547.06 6,760.78 38 16,765 30.43 6.88 Centrilizer With Stop Collar Middle Qf Joint 39 39A0 1,586A6 6,721.3a 39 17,212 31.21 7.06 40 39.39 1,625.85 6,681.99 40 17,640 31.98 7.24 Centrilizer With Stop Collar Middle Of Joint 41 41.17 1,667.02 6,640.82 41 18,086 32.79 7.42 Centrilizer With Stop Collar Middle Of Joint 42 41.02 1,708.04 6,599.80 42 18,531 33.60 7.60 Centrilizer With Stop Collar Middle Of Joint 43 39.08 1,747.12 6,560.72 43 16,955 34.37 7.77 Centrilizer With Stop Collar Middle Of Joint . 09/24/00 SUN 18:54 FAX 19075646489 Marathon011 Co Young 002 44 40A6 1,767.58 6,520.26 44 19,394 35.16 7.95 Centrilizer With Stop Collar Middle Of Joint 45 41.55 1,829.13 6,478.71 45 19,845 35.98 8.14 Centrilizer With Stop Collar Middle Of Joint 46 41.47 1,870.60 6,437.24 46 20,295 36.79 8.32 Centrilizer W'dfl Stop Collar Middle Of Joint 47 40.27 1,910.87 6,396.97 47 20,732 37.59 8.50 Centrilizer With Stop Collar Middle Of Joint 48 41.48 1,952.35 6,355A9 48 21,182 38.40 8.69 Centrilizer W'dfl Stop Collar Middle Of Joint 49 41.47 1,993.82 6,314.02 49 21,632 39.22 8.87 Cenlfilizer W'dfl Stop Collar Middle Of Joint 50 39.96 2,033.78 6,274.06 50 22,065 40.00 9.05 Centrilizer W'dh Stop Collar Middle Of Joint 51 41.57 2,075.35 6,232.49 51 22,516 40.82 9.24 Cenl;ilizer With Stop Collar Middle Of Joint 52 38.65 2,114.00 6,193.94 52 22,936 41.58 9.41 Centrilizer With Stop Collar Middle Of Joint 53 39.99 2,153.99 6,153.85 53 23,370 42.37 9.59 Centrilizer With Stop Collar Middle Of Joint 54 39.48 2,193A7 6,114.37 54 23,798 43.15 9.76 Centrilizar W'dfl Stop Collar Middle Of Joint 55 41.56 2,235.03 6,072.81 55 24,249 43.96 9.95 Centrilizer With Stop Collar Middle Of Joint Pup Joint 9.76 2,244.79 6,063.05 Pup 24,355 44.16 9.99 Pup Joint 9.76 2,254.55 6,053.29 Pup 24,461 44.35 10.03 Pup Joint 3.72 2,258.27 6,049.57 Pup 24,501 44.42 10.05 X- Nipple 0.89 2,259.16 6,048.68 X-Nip 24,511 44.44 10.05 Centrilizer Around X-Nipple Pup Joint 3.71 2,262.87 6,044.97 Pup 24,551 44.51 10.07 Pup Joint 1.76 2,294.63 6,043.21 Pup 24,570 44.55 10.08 56 39.25 2,303.88 6,003.96 56 24,996 45.32 10.25 Centrilizer With Stop Collar Middle Of Joint 57 40.10 2,343.98 5,963.86 57 25,431 46.11 10A3 58 39.61 2,383.59 5,924.25 58 25,861 46.89 10.61 59 39.60 2,423.19 5,884.65 59 26,290 47.66 10.78 60 39.56 2,462.75 5,945.09 60 26,720 48/14 10.96 61 40A3 2,503.18 5,804.66 61 27, t 58 49.24 11.14 62 40.73 2,543.91 5,763.93 62 27,600 50.04 11.32 63 41.55 2,585A6 5,722.38 63 28,051 50.86 11.51 64 41A5 2,626.9t 5,680.93 64 28,501 51.67 11.69 65 41.56 2,668A7 5,639.37 65 28,951 52A9 1 t.87 66 41.55 2,710.02 5,597.82 66 29,402 53.31 12.06 67 41.55 2,751.57 5,556.27 67 29,853 54.12 12.24 68 41.46 2,793.03 5,514.81 69 30,303 54.94 12A3 69 4t .55 2,934.59 5,473.26 69 30,754 55.76 12.6t 70 41.57 2,876.t5 5,431.69 70 31,205 56.57 12.80 71 39.31 2,915A6 5,392.38 71 31,631 57.35 12.97 72 38.00 2,953A6 5,354.38 72 32,043 58.09 13.14 73 37.50 2,990.96 5,316.89 73 32,450 58.93 13.31 74 41 AB 3,032A4 5,275A0 74 32,900 59.65 t3A9 75 41 AB 3,073.92 5,233.92 75 33,350 60A6 13.68 . 76 41.57 3,115A9 5,192.35 76 33,801 61.28 13.86 77 41A8 3,156.97 5,150.87 77 34,251 62.10 14.05 78 41.56 3,198.53 5,109.31 76 34,702 62.92 t4.23 79 39.09 3,237.62 5,070.22 79 35,126 63.68 14A1 80 39.92 3,277.54 5,030.30 80 35,560 64A7 14.59 81 39.18 3,316.72 4,991.12 81 35,985 65.24 14.76 82 4t .49 3,358.21 4,949.63 82 36,435 66.06 14.94 83 41A6 3,399.67 4,908.17 83 36,885 66.87 15.13 94 41.47 3,441.14 4,866.70 94 37,335 67.69 15.31 85 41A7 3,482.61 4,825.23 85 37,784 68.50 15.50 86 40.48 3,523.09 4,784.75 86 38,224 69.30 15.68 87 41 A8 3,594.57 4,743.27 87 38,674 70.12 15.86 88 41.56 3,606.13 4,701.71 88 39,125 70.93 16.05 89 41.55 3,547.68 4,660.16 89 39,575 71.75 16.23 90 41.54 3,689.22 4,618.62 90 40,026 72.57 16.42 91 41.56 3,730.78 4,577.06 91 40,477 73.38 t6.60 92 41.02 3,771.80 4,536.04 92 .., 40,922 74.19 16.78 93 41.05 3,812.85 4,494.99 93 41,367 75.00 16.97 94 41.05 3,853.90 4,453.94 94 41,813 75.81 17.15 95 41.48 3,895.38 4,412A6 95 42,263 76.62 17.33 96 41.47 3,936.85 4,370.99 96 42,713 77.44 17.52 97 41.57 3,978A2 4,329A2 97 43,194 78.26 17.70 98 41.56 4,019.98 4,287.86 98 43,615 79.07 17.89 99 40.91 4,060.89 4,246.95 99 44,058 79.88 18.07 100 37.75 4,098.94 4,209.20 100 44,468 80.62 18.24 101 41.56 4,140.20 4,167.94 101 44,919 81.44 18.42 102 41.55 4, t81.75 4,126.09 102 45,370 82.26 18.61 103 41 A6 4,223.21 4,084.63 103 45,820 83.07 18.79 104 37.57 4,260.78 4,047.06 104 46,227 83.81 18.96 t05 41.48 4,302.26 4,005.58 105 46,677 84.63 19.15 106 41.42 4,343.68 3,964.16 106 47,127 85.44 19.33 107 41.48 4,395.16 3,922.68 107 47,577 86.26 19.51 108 41.55 4,426.71 3,881.13 108 48,027 87.07 19.70 ' - 09/24/00 SUN 18-55 FAX 190756.46,t89 ~arathon011 Co *** Cralg Young ~003 1o9 41.55 4,466.26 3,839.59 lO9 48,478 87.89 19.98 11o 41.48 4,509.74 3,798.1o 1 lO 48,928 86.71 2o.o7 111 41.57 4,551.31 3,756.53 111 49,379 89.52 20.25 112 41.56 4,592.87 3,714.97 112 49,830 90.34 20.44 113 40.34 4,633.21 3,674.63 113 50,268 91.14 20.62 114 41.57 4,674.78 3,633.o6 114 5o,71g 91.95 20.60 115 41.55 4,716.33 3,591.51 115 51,17o 92.77 20.99 116 41.54 4,757.87 3,549.97 116 51,620 93.59 21.17 117 41.49 4,799.36 3,508.48 117 52,070 94.40 21.36 118 41.49 4,840.85 3,466.99 118 52,521 95.22 21.54 119 41.48 4,882.33 3,425.51 119 52,971 96.04 21.73 120 41.51 4,923.84 3,384.00 120 53,421 96.85 21.91 121 41.48 4,965.32 3,342.52 121 53,871 97.67 22.10 122 41.48 5,006.80 3,301.04 122 54,321 98.48 22.28 123 41.57 5,048.37 3,259.47 123 54,772 99.30 22.47 124 38.50 5,086.87 3,220.97 124 55,190 100.06 22.64 125 39.20 5,126.07 3,181.77 125 55,615 100.83 22.81 126 41.49 5,167.56 3,140.26 126 56,065 101.65 23.00 127 41.02 5,208.58 3,099.26 127 56,510 102.45 23.18 128 39.48 5,248.06 3,05g.78 128 56,939 103.23 23.35 129 41.95 5,290.01 3,017.83 129 57,394 1 04.05 23.54 130 41.05 5,331.06 2,976.78 130 57,839 104.86 23.72 131 41.88 5,372.94 2.934.90 131 59,294 105.69 23.91 132 41 A7 5,414.41 2,893.43 132 58~743 106.50 24.09 133 41.55 5,455.96 2,851.88 133 59,194 107.32 24.28 134 41.57 5,497.53 2,810.31 134 59,645 108.14 24.46 135 41.56 5,539.09 2,768.75 135 60,096 108.95 24.65 136 40.36 5,579.45 2,728.39 136 60,534 109.75 24.83 137 4t .56 5,621.01 2,686.83 137 60,985 110.57 25.01 138 41.60 5,662.61 2,645.23 138 61,436 111.38 25.20 139 41.56 5,704.17 2,603.67 139 61,887 112.20 25.38 140 41.57 5,745.74 2,562.10 t40 62,338 113.02 25.57 t41 41.46 5,787.20 2,520.64 141 62,788 113.83 25.75 t42 41.57 5,828.77 2,479.07 142 63,239 114.65 25.94 143 41.34 5,870.11 2,437.73 143 63~686 115.47 26.12 144 41.54 5,911.65 2,396.19 144 64,138 116.28 26.31 145 41.55 5,953.20 2,354.04 145 64,589 117.10 26.49 146 39.51 5,992.71 2,315.13 t46 65,018 117.88 26.67 147 35~70 6,028.41 2,279.43 147 65,405 118.58 26.83 148 40.11 6,068.52 2,239.32 148 65,840 119.37 27.00 149 36A9 6,105.01 2,202.83 149 66,236 120.09 27.17 150 39.71 6,144.72 2,163.12 150 66,667 120.67 27.34 151 36.09 6, t82.81 2,125.03 151 67,080 121.62 27.51 152 37A5 6,220.26 2,087.58 152 67,486 122.35 27.68 153 39.52 6,259.78 2,048.06 153 67,915 123.13 27.86 1 54 39.69 6,299A7 2,008.37 1 54 68,346 123.91 28.03 155 40.26 6,339.73 1,968.11 155 68,783 124.70 28.21 156 41.55 6,381.28 1,926.56 156 69,233 125.52 28.40 157 40.14 6,421.42 1,886.42 157 69,669 126.31 28.58 158 39.97 6,461.39 1,846.45 158 70,103 127.10 28.75 159 40.06 6,501.45 1,806.39 159 70,537 127.88 28.93 160 40.17 6,541.62 1,766.22 160 70,973 128.67 29.11 161 39.89 6,58'i .51 1,726.33 161 71,406 129.46 29.29 162 41.57 6,623.08 1,664.76 162 71,857 130.28 29.47 163 39.96 6,663.04 1,644.80 163 72,290 131.06 29.65 1 64 36.44 6,699.48 1,608.36 164 72,686 131.78 29.81 165 41.01 6,740.49 1,567.35 165 73,131 132.59 30.00 166 38.53 6,779.02 1~528.82 166 73,549 133.34 30.17 167 39.29 6,818.31 1,4,89.53 167 73,975 134.12 30.34 168 39.38 6,857.69 1,450.15 168 74,402 134.89 30.52 ! 69 40.36 6,888.05 1,409.79 169 74,840 135.68 30.70 170 40.25 6,938.30 1,369.54 170 75,277 136A8 30.88 171 38.12 6,976A2 1,331.42 171 75,690 137.23 31.05 172 40.39 7,016.81 1,291.03 172 76,129 138.02 31.22 173 41.57 7,058.38 1,249.46 173 76,580 138.64 31.41 174 41.56 7,099.94 1,207.90 174 77,031 t39.66 31.59 175 38.27 7,138.21 1,169.63 175 77,446 140.41 31.77 176 39.91 7,178.12 1,129.72 176 77,879 141.19 31.94 177 39.85 7,217.97 1,089.87 177 78,311 141.98 32.12 178 40.09 7,258.06 1,049.78 178 78,746 142.77 32.30 179 39.87 7,297.93 1,009.91 179 79,179 143.55 32.48 ' 09/24/00 SUN 18:56 FAX 19075646&89 Marathon01! Co .. Craig Young 004 180 39.94 7,337.87 969.97 180 79,612 144.34 32.65 181 39.88 7,377.75 930.09 181 80,945 145.12 32.83 182 39.07 7,416.82 891.02 182 80,469 145.89 33.00 183 38.56 7,455.38 852.46 183 80,887 146.65 33.18 184 39.54 7,494.92 812.92 164 81,316 147.43 33.35 185 39.35 7,534.27 773.57 185 81,743 148.20 33.53 186 40.26 7,574.53 733.31 186 82,180 148.99 33.71 187 39.76 7,614.29 693.55 187 82,611 149.77 33.88 188 39.92 7,654.21 653.63 188 83,044 150.56 34.06 189 38.47 7,692.68 615.16 189 83,461 151.32 34.23 190 39.65 7,732.33 575.51 190 83,892 152.09 34.41 191 38.59 7,770.92 536.92 191 84,310 152.85 34.58 192 38.26 7,809.18 498.66 192 84,725 153.61 34.75 193 39.66 7,648.84 459.00 193 85,156 1 54.39 34.93 1 94 38.14 7,686.96 420.86 194 65,570 155.14 35.10 196 38.44 7,925A2 382.42 195 85,987 155.69 35.27 196 40.09 7,965.51 342.33 196 86,422 156.68 36.45 197 39.89 8,005A0 302A4 197 86,854 157A7 35.62 196 38.59 8,043.99 263.85 198 87,273 158.23 35.80 169 39.67 6,083.66 224.16 199 87,703 159.01 36.97 200 39.22 8,122.88 164.96 200 68,129 159.78 36.15 201 39.85 8,162.73 145.11 201 88,561 160.56 36.32 202 40.27 8,203.00 1 04.84 202 88,998 161.35 36.50 203 40.15 8,243.t5 64.69 203 89,434 162.14 36.68 204 39.83 8,282.98 24.86 204 89,666 162.93 36.86 Pup Joint 3.46 8,286.44 21 A0 Pup 69,903 162.99 36.87 Hanger 0.82 8,287.26 20.58 Hanger 89,912 163.01 36.88 Above Hang 0.92 8,288.18 19.66 Above 69,922 163.03 36.66 X/O Pup 3.83 6,292.01 16.83 X/O 89,964 163.10 36.90 Land Joint 19.69 6,31t.70 -3.86 Land Jt 90,176 163A9 36.99 ' Above ET -3.86 6,307.94 0.00 Above 90,136 ** 3.66 Above Rotar~ Table** Joint Cum Total Number Length Length Joints 205 41.56 41.56 1 206 37.08 78.64 2 207 39.98 t 18.62 3 208 40.01 158.63 4 JOINT 205 HAS BAD BOX MARATHON OIL; COMPANY- ALASKA REGION CASING AND CEMENTING RECORD Field: Kenai Gas Field , Rig: ,Giacier Driilin9 Rig #1 Date Run: · Well: CLU - 6 · Cement Contractor. Doweli ' RKB - MWL: Al=E: 9701000 Shoe .Depth (MD): 2966 MWL - ML: Lease: CANNERY LOOP Shoe Depth (TVD): 2322 RKB - ML: Page I1 of 2 I · 911J0 . . 21.6I ol I · ~J~ I . I..."I'~ I TopTh.~dI 6. rode ! w~htl .L~gth I..From i .i i .... ' ,.. O.oo !o.oo i 1 LANDING JT 7' : 'E~TC L-e0 23.0 24.70 -3.2S I 21.46 i i i ....... I CIO 7' : BTC L-80 23.0 14.67 21.45 I 36.02 6 CASING .... 7" ! BTC . L-e0 23.0 239.76 , 36:.02 27'5.7,7 64 CASING 7" ;BTC MOD L..80 26.0 2604,46 275,77 12660.23 i i 111 , i i · , 1 FC 7' eTC 1.30 2660.23 12681 II i ii i i I 2 SI':1..O..E, JT~ . 7" ?~TC MOD 't~'~ 26.0 83.16 28.81.53 i2064.68 1 FS · . . 7' ... BTC , , , 1..60 2064.66 12666.16 ' I ii il i i ii i i " i i i i i i i iiii i j i i i i i i i ' i mil ii i i i . , .... ' i -- ; I i libi ii ii ii ii · i i ..... ; I iiiii ii i ! i i i i i' i i i~1 Amo..t I Tvse _. I L' [ SPaCiOR I From II To 1 Welded Bow Spring ,. 4 5 Welded Bow Sprin. ...... MIDDLE OF BTM 5 ,JTS ...... i .. i I iii 11, ill i , , , , i ... iii · , i i i i ii i i i i i iii i I ' , ' I . ,. I Leal~Cement .I ! Other C,....* I ~h~...__-_ "i +.,'¢;~ ..... , , Content Typo (clase)J M,'TECRETE ..... Cemen~ Amount (.x) l 280. ; I · ~ , , , , i , 1 ,,i Addmve (.pWrv%)/('TypeY 34% D124 ; I i i i i iii i iii ^ddmve <~pr~dry%)/CTVpe);. 0..,..S..% D65 ' . ...... I AdceUve (,pe/dry~)/('rw,eY 0.10% D46 : I · , · Additive (gpe/dry%)/(Typ~} I :0.30°/. D7~9 .... : ~. I Add~ (gps/d~_)I(Type) i f Mix 4/Vster (Ops)/l'~e 8.097 FW : i i · ·. Slurry Weight (ppg) 11.5 I ... .............. Stu,yY~eld (CuFt~) 2.28 ' i. . l, . .. i i Open H,ole .~,~ (%) 50 : I i il i iii ii ii ii I Planned Top of Cement (re.d) . O .......... . i TO0~ - iI CA~ING AND CEMENTING RECORD .. Field: Kenai Gas Field Well: i KBU 33-6 , . Casing Size: I Page [2 of 2 * 13 3/8' Circulate Time..P. dor to Pre-Rush (hm) 2 h~ .. . Bump. Wiper plug To Reciprocate PIpe ~,erJNoi ¥ : C..ement In Place Time.~hrlmin) Wipe;Plug Pdgr T° Pre-Flush (Yes/No) Y ' Flbat~ Held (Yes/~. o)1 I Yes Pre-Flush (Spacer).?y~e MP XI. " ...... , Mud LostWh,e Rurumm ~ (bble} I o ! I i i ii I , , Pre-Flush Volume (bbb) 20 : Mud'Lost WMe Cir~!.ting (bbb) i 0 , Pre-Flu~ Waipht (p~) 8.3 ; Mud Lost While Pump and pi~lace Cement (bbb) J 5 V~iper Plug Pdor To Ceme~ (Yes/No) Y ; '" '. ' Total Mud Ldst (bbb) .I, ' 5 ,, B~in Cement Mix'lime (l~lmin) 8:55 = , , Inner G.~lng Used (Y. as/No) I NO End Cement Mix Time (hr/mM) ,9:1.7 i .. Cement R. elums to Surface (CUR.) Disp, iaca WRh (Cement Un,,.it~p,Pump) RIGPMP, :,, Estimated Top 9f Cement (MD) i 30 , i .... Displacement Fluid T~e Mud , ,, , , Open Hole, F_xcess Cement Used (%} I 50 Dbplacemant ,Fiji, dWeight ~p~ ,9.50 : Open Hole Diameter ('m) I 8.5 , Dleplaoament V~lume, (bbb:} 110 , : Lan.ding Welgl~ on Slips/Hanger (1000 lbs} I 0 , . Dbplucement Rate ~pm:} ., 4 : Casing Landad On (slil~, hanger, iinar hanger) INA , Final Displacement Pressure (l~i} ,.5.00 , ;, ,. Sub-Sea Hanger Locking Installed (Ye~/NelNA...) ' I -Il J ''T ............ 1'1 ..................... I I IIr'"N~ ............................. Couldr~'t get density up past 11.8 ppg. Most of the"tin~e it was mixed at 11.5. Target density Was 12.00 Pp~'. I~o cmt returns to su~ace but the PH incr~s~l at the end ind:i~ting that ~nt was close to sufl~ace. A top job of 27 .~t ¢ ~ the same slurry was placed from the conductor shoe to surface. ... , · · ; ; , , ,. i I ' 1/oo ' ' · Il - Dt,.se~in:[ ~/9~- I Ne.'Joints I' Weight I Gl~dl~ . !. Thread i' "'L.,~.. Il' "o Jo~,, i W;i.ht '1 m,.d. I Thread I I Length , I ..... , , , . . · , I ; I , , in i il' ' i ii i i ...... ' ., '" i , ':' T _'.,, Signed: CLU6CMT. xls oD ~TO~Oq~e~e~ Approved: Date: Rev: 9-: 68tg~9E£O6T I¥& 0~:90 ~0-98 i 00/ST'/60 Cementing Service Report ~ ~_~. %," ~_~ w ] Customer Job Number ] MARATHON OIL CO D35834 20176867 Well ) Location (legal) Dowell Location Job Start CANNERY LOOP 6I Kenai, AK 9/1 Field Formation Name/Type D~'laUoo I ,itS~ I Wel, MD WeliTV~ CANNERY LOOP 0 ° 0 in 2,983 It 2,983 It County State/Province BHP I BHST BHCT Pore Press. Gradient AK 0 psiI 105 OF 90 OF 0 psi/fi: Rig Name Drilled For I Set.ce ~ra Casing/Liner GsaI Lsnd Depth, It Size, in Weight, lb/It Grade Thread Offshore Zone Well Class I Well T~e 2968 7 26 N80 BUTT OldI Development ' 0 0 0 oduing Fluid Type Ma~ Density masUc Viscosity Tubing/Drill Pipe Bentonite 10 lb/gal 0 cp Depth, Size, In Weight, ib/ft Grade Thread Service Line Job Type 0 0 0 Cementing Cern Surface Casing 0 0 0 Max. Allowed Tubing Pre, sure Max, Nlowed Ann. Pr~sure I WellHead Concectlan Perforations/Open Hole 2000 psi 0 PsiI Double cement hea Tu~ it Bottom, ft sp~ ~ o~s~ota Tumi int~val s~vic~ Insm~'uons 0 0 0 0 0 Fumish Equipment, Personnel, and Materials for 7" surface. Per customer 0 0 0 0 request. 0 0 0 0 0 in Treat Down Displacement Packer Type Packer Depth Casing 110.8 bbl 0 It Tubing Vol. casing VoL Annular Vel. OpenHole Vol 0 bbl 110.8 bbl 0 bbl 0 bbl Caaln~Tubing SeCured [] 1 Ho~ Velum Circu,a~d mot to Demen~ng[-] Casing Tools Squeeze Job uft Pre,sum: psi shoe T~: Guide Squ~ze Ty~ Pipe Ro=tad ~ Pip, R~pro=t,dF--I Shoe Dep~: 3000 tt Too, No. Centralizers: 0 Top ~lu;.: I .otto= P~s: I Stage Tool Type: Tool Depth: 0 it Cement Head Type: Double stage Tool Depth: 0 It Tall Pipe Size: 0 in Job Schedu~,d Foc. I a,T~ed oo LooSen: Le~e CocaUoo: ColOr Type: Diff-Fill Tail Pipe Depth: 0 it 9/11/00 5:30I 9111/00 5:30 9/1 !/00 11:30, cel~.r Dep~: 2885 ff Sqz Tut~ v~: 0 bbl Time ' c.mv~ oen. ity Ire. Suture Tut~k~wrata ' ' 'Message ' ' 24 hr rJock bM ppg psi bpm 8:40 0 0 0 0 0 0 O START ACQUISmON 8:40 0.' 5. -3750 o. 0 "0 0 8:41. 0. 8.16 -132.8 0. 0 ' 0 0 ' ' 8:~2 0. 8.13 -169.4 0. O O 0 8:43 0. 8.13 -169.4 0. 0 0 0 Start Pumping Spocer '8:43 ~.102 ' ?.63 -91.58 0.56:4 0 0 0 8:44 2.63' 7.66 -9.16 3.48 0 0 8:45 5.5§ '8.11 -114.5 0. 0 ' 0 0 , 8:46 5.59 ?.77 512.8 0. 0 0 0 8:47 5.59 ?.7~ '512.8 0. 0 0 0 Pressure Test Lines 8:4~ 5.6 8.1 2995' 0. "0 0 ' 0 8:48 5.6 8.16 -18.32 0. 0 0 0 8:49 5.6 8.16 -141.9 o. o o o 81~0 9.04 7.66 50.37 3.91 0 0 0 8:51 9.04 7.66 50.37 3.91 0 0 0 Start Pumping Specer . 8:51 13.05 7.7 82.42 4.55 0 0 0 '8:52 17.67 7.68 68.68 4.65 0 0' 0 8:53 22.28 ~.? 10~.9 4.6~3 0 0 0 8:54 22.28 7.7 109.9 4.63 0 0 0 ShUtdown 8:54 . 25.62 8.13 -141.9 0. 0 0 0 · 8:54 25.62 8.13 -141.9 o. 0 0 0 [CumVol]=25.62 bbl Sep 11,2000 WRS3 v3.0-SR Page I of 2 Well I Field Sewice Date Custon~ek t JobNumber CANNERY LOOP #6 CANNERY LOOP MARATHON OIL CO D358 20176867 Time CumVol Density Pressure Ul TotFIowrate Message 24 hr clock bbl ppg psi bpm 8:54 25.62 8.13 -141.9 0. 0 0 0 ResetVolume 8:55 25.62 8.1 ~ -141.9 O. 0 0 O Stert Pumping Water 8:55 1.1 8.13 -114.5 1.63 0 0 0 8:55 1.1 8.13 -114.5 1.63 0 0 0 Reset Volume 8:56 1.1 8.13 -114.5 1.63 0 0 0 [CumVol]=4.216 I~bl 8:56 1.1 8.13 -114.5 1.63 0 0 0 Start Cement Slurry 8:55 0.568 10.44 196.9 5.64 0 0 8:57 6.25 11.73 306.8 5.66 0 0 0 8:58 12.05 11 .'6 389.2 6.94 0 0 0 8:59 18.57 11.45 430.4 5.66 0 0 0 9:00 24.23 10.83 91.58 5.62 0 0 0 9:01 29.84 11.1 5 164.8 5.44 0 0 0 9:02 35.44 11.31 361.7 5.56 0 0 0 9:03 41. 11.3 283.9 5.58 0 0 0 9:04 46~51 11.27 265.6 5.31 0 0 0 9:05 51.96 11.32 228.9 5.3 0 0 0 9:06 57.99 11.26 380. 6. 0 0 0 I i i 9:07 64.02 11.36 334.2 5.98 0 0 0 , 9:08 69.3 11.35 132.8 4.72 0 0 0 9:09 74.1 11.42 375.5 5.98 0 0 0 9:i 0 80.12 11.5 302.2 5:98 0 0 0 9:11 85.01 11.56 91.58 4.12 0' ' 0 0 , , 9:12 89.53 11.59 297.6 5.99 0 0 0 9:13 95155 11.62 315.9 6. 0 0 0 9:14 101.5 11.44 393.8 ~. 0 0 0 9:1S 107.7 li.57 549.5 6155 0 0 0 9:16 114.3 11.6 499.1 6.57 0 0 0 9:17 119.2 11.92 288.5 6.55 0 0 0 9:18 124.4 9.18 -164.8 0. 0 0 i 9:19 ' 124.4 9.4 -169.4 0. 0 0 0 9:20 '124.4 9.06 -151.1' 0. 0 0 0 9:21 124.~ 9.0~' -151.1 O. O' .. 0, 0 S, tartPu, mpingWater 9:21 126.1 8.38 274.7 3.93 0 0 0 9:22 1;~1.1 8.33 -174. O. 0 0 ' 0 , 9:23 131.1 8.37 -174. O. 0 0 0 9:24 131.t 8.37 ' -174. 0. 0 0 0 Rig Pumps To Displace 9:24 131.1 8.34 -174. 0. 0 0 0 , , ~ ,, , Post'job SungnarY ..... Average Pump Rates, bpmI Volume of Fluid Injected, bbl Slurry N2 Mud Maximum Rate Total Slurry Mud Spacer N2 6 I o I o I, I o I I o Treating Pressure Summary, psi Breakdown Fluid Maximum Final Average Bump Plug to Breakdown Type Volume Density I I oo I o I o I o bb,I01b/ga, Customer or Authorized Representative Dowell 8uperviser Darrel Green Albin HaleI [] CirculationLost [] Job Completed Sep 11,2000 WRS3 v3.0-SR Page 2 of 2 Cementing Job Administration Data Client Client Rep. Well Name Field Name Rig Name Rig Contractor Contractor Rep. Serv. Location Dowell Engineer Dowell Phone Acq. Front End Start Date End Date SIR Number Description MARATHON OIL CO. JIM ROSE CANNERY LOOP #6 CANNERY LOOP KEN.A1, ALASKA ALBIN HALE (907) 26~-7800 1 JAB/Hybrid RDA - 1 Cement Unit 09/11/2000 08:40:24 09/11/2000 09:25:15 20176867 7 SURFACE Channels Description .................... n t , u,, , i , ,,~ i , ,, Ji, Channel Description Minimum '[ Maximum' unit Acquisition Time Acquisition time 09/11/200~) 08:40:28" '("i)9~11/:~61)'0'0~i25i10 CumVol Cumulative Volume 0 131.1 bbl Density DS Digital Demitumeter Panel w/Ronan Source & Detector 5 11.97 ppg Pressure U1 Viatran 500 Pressure Transdtmer 4-20mA 0-15 kpsi -3750 3031 psi TotFlowrate Total Flowrate .... 0 7.601 bpn},, Acquisition Data Ae, q~isifion Time 09/11/2000 08:40:24 09/11/2000 08:40:28 09/11/2000 08:40:58 09/11/2000 08:41:28 09/11/2000 08:41:59 09/11/2000 08:42:29 09/11/2000 08:42:59 09/11/2000 08:43:20 09/11/2000 08:43:29 09/11/2000 08:43:59 09/11/2000 08:44:30 09/11/2000 08:45:00 09/I 1/2000 08:45:30 09/11/2000 08:46:00 09/11/2000 08:46:30 09/11/2000 08:47:01 09/11/2000 08:47:13 09/11/2000 08:47:31 09/11/2000 08:48:01 09/11/2000 08:48:31 CumVol 0. 0. 0. 0. 0. 0. - 0.102 0.894 2.632 4.594 5.587 5.587 5.593 5.603 . 5.604 5.604 5.604 D, ,~.si.ty . 5. 8.145 8.165 8.145 8.126 8.165 . 7.628 7.608 7.657 7.696 8.106 8.126 7.774 7.701 . 8.101 8.145 8.165 Pressure UI -3750 -128.2 -132.8 -164.8 -169.4 -174. . -91.58 -77.84 -9.158 32.05 -114.5 -109.9 512.8 3031 . 2995 2981 -18.32 TotFlowra~e 0.564 1.769 3.48 3.966 0. 0. 0. 0.117 START ACQUISITION Start Pumpi~ Spsoer Pressure Test Lines © Schlumberger 1994.-1998 .k',h 'mo. ecl~ sm' Cementing , .Aeqeisition Time 09/11/2000 08:49:01 09/11/2000 08:49:32 09/11/2000 08:50:02 09/11/2000 08:50:32 09/11/2000 08:51:02 09/11/2000 08:51:19 09/11/2000 08:51:32 09/11/2000 08:52:03 09/11/2000 08:52:33 09/11/2000 08:53:03 09/11/2000 08:53:33 09/11/2000 08:54:03 09/11/2000 08:54:31 09/11/2000 08:54:34 09/11/2000 08:54:55 09/11/2000 08:54:55 09/11/2000 08:55:01 09/11/2000 08:55:04 09/11/2000 08:55:34 09/11/2000 08:56:04 09/11/2000 08:56:27 09/11/2000 08:56:27 09/11/2000 08:56:34 09/11/2000 08:56:34 09/I 1/2000 08:57:05 09/11/2000 08:57:35 09/11/2000 08:58:05 09/11/2000 08:58:35 09/11/2000 08:59:05 09/11/2000 08:59:36 09/11/2000 09:00:06 09/11/2000 09:00:36 09/11/2000 09:01:06 09/11/2000 09:01:36 09/11/2000 09:02:07 09/11/2000 09:02:37 09/I 1/2000 09:03:07 09/11/2000 09:03:37 09/11/2000 09:04:07 09/11/2000 09:04:37 09/11/2000 09:05:08 09/11/2000 09:05:38 09/11/2000 09:06:08 09/I 1/2000 09:06:38 09/11/2000 09:07:08 09/11/2000 09:07:39 09/11/2000 09:08:09 09/11/2000 09:08:39 09/11/2000 09:09:09 09/11/2000 09:09:39 09/11/2000 09:10:10 09/11/2000 09:10:40 09/11/2000 09:11:10 09/11/2000 09:11:40 09/11/2000 09:12:10 09/11/2000 09:12:40 09/11/2000 09:13:11 09/11/2000 09:13:41 09/11/2000 09:14:11 09/11/2000 09:14:41 09/11/2000 09:15:11 09/11/2000 09:15:42 09/11/2000 09:16:12 CumVol 5.604 5.604 7.078 9.038 11.01 . 13.05 15.35 17.67 19.96 22.28 24.57 . 25.62 . . 0.196 1.097 2.116 . - . 0.568 3.41 6.248 9.08 12.05 15.58 18.57 21.4 24.23 27.05 29.84 32.65 35.44 38.23 41. 43.77 46.51 49.24 51.96 54.97 57.99 61.01 64.02 66.91 69.3 71.67 74.1 77.1 80.12 82.92 85.01 87.07 89.53 92.54 95.55 98.56 101.5 104.5 107.7 111. Densit~, 8.179 8.165 Pressure UI -132.8 -141.9 O. 50.37 27.47 82.42 137.4 68.68 123.6 109.9 54.95 - -141.9 -68.68 -114.5 54.95 196.9 206. 306.8 480.8 389.2 522. 430.4 96.15 91.58 174. 164.8 215.2 361.7 293. 283.9 274.7 265.6 302.2 228.9 348. 380. 343.4 334.2 119. 132.8 137.4 375.5 283.9 302.2 91.58 91.58 100.7 297.6 389.2 315.9 210.6 393.8 389.2 549.5 293. TotFlowrate O. O. 3.907 3.907 3.927 ' . 4.549 4.588 4.646 4.568 4.627 4.568 . O. . 1.886 1.633 4.141 5.638 5.657 5.657 5.599 6.941 7.444 5.657 5.599 5.618 5.56 5.443 5.56 · 5.56 5.579 5.579 5.521 5.307 6.52 5.296 6.023 6.003 5.975 5.975 4.74 4.72 4.72 5.975 5.975 5.975 4.204 4.117 4.079 5.995 5.995 6.003 5.984 6.003 5.975 6.551 6.59 Start Pumping Spacer Shutdown [CumVol]=25.62 bbl Reset Volume Start Pumping Water [CumVol]=4.216 bbl Reset Volume Start Cement Slurry © Sclflm~l',erger 1994.-I ~)98 Jab: m(.>cc!6 :';'~.,' ( ( Cementin Aequb~on T~me 09/11/2000 09:16:42 09/11/2000 09/11/2000 09/11/2000 09/11/2000 09/11/2000 09/11/2000 09111/2OOO 09/11/2000 09/11/2000 09/11/2000 09/11/2000 09/11/2000 09/11/2000 09/11/2000 09/11/2000 09:23:45 09/11/2000 09:24:11 09/11/2000 09:24:15 09/I 1/2000 09:24:45 09/11/2000 09:25:15 CumVol 114.3 09:17:12 116.8 09:17:42 119.2 09:18:13 122.4 09:18:43 124.4 09:19:13 124.4 09:19:43 124.4 09:20:13 124.4 09:20:43 124.4 09:21:14 124.5 09:21:16 - 09:21:44 126.1 09:22:14 129.1 09:22:44 131.1 09:23:14 131.1 131.1 . 131.1 131.1 Demit~ 11.6 11.52 11.92 10.93 9.181 9.283 9.396 9.303 9.059 9.02 . 8.38 8.189 8.326 8.326 8.37 ~1.37 8.341 Pressure UI 499.1 567.8 288.5 123.6 -164.8 -169.4 -169.4 -169.4 -151.1 22.89 274.7 141.9 -174. -174. -174. - -174. -174. TotFlowrate 6.571 3.258 6.551 6.238 0. 0. 0. 0. 0. 0.175 3.925 7.452 0. 0. 0. 0. 0. Messages Start Pumping Water Pumps To Displace STOP ACQUISITION. (4¢ Scl'~}ambcrge, r t994-1998 ,lc~b: m,:>oc:16 s'tu' PRISM* V2.23 Well CANNERY LOOP ~ Client MARATHON OIL CO. Field CANNERY LOOP SIR No. 20176867 Country USA Job Date 9/11/2000 8:40:24 AM Time 09111/00 08:40:24 ..... TolFIowrate Messages CmlV~ ~ Density FYessa'e Ul .... *START ACQUISITION *Pressure Test Unes I 08:55:(X) , 09:t5:00 ~'-'-'-"- ...... ~ ~ *st~ Pun-eln; W~ter ............ '.'22.7.222 'Rig Ptraps To Displace 09:25:00 . *STOP ACQUISITION ~ i ~ i , i, i~J'l, i ,~1 ~ i · i, '& I. i ~ i~ i.I ~ i, i, i ~ i· ~ i'. i'~ i ~ i ~ i ; i, I, ~, I, , , hh:mm:ss o '" 0 ..... ~ B 09111/00 09:25:15 * Mark of ,~hlumberge~ Marathon Oil Company Casing Integrity Test Block & Wall CLU-6 Casing Size 7" Lease CANNERY LOOP Casing Weight 23 & 29 Rig Name GLACIER RIG 1 Casln.q Grade & Thread L-80 Buttress !Riff T~(pe LAND 8hoe Depth, MD 2,965 RKB to MWL Shoe Depth, TVD 2,322 ff Water Depth Date Tested 12-Sap-00 RKB to Mud Line Co. Rep. Darrell Green Test Pump Rater bpm I 0.5 bpm Mud Type WATER BASE Mud YP 10 lb/100 sf Mud Volume Pumped, bblsI 2.5 bbls Mud Wt 8.8 ppg HPHT WL 2.5 cc/30 min Max Pressure Observed, psig 1,500 pslg Mud Vis 40 s/qt Mud Gel 10 sec 8 lb/100 sf Mud PV 10 cps Mud Gel 10 min 29 Ibll00 sf Injection Profile Pressure Fall Off Volume Pressure Comments Time Pressure Pressure Fall Off Plot bbls psi Minutes pslg 0.0 0 0 1,520 1,520 ~, 0.5 360 5 t,505 1;515 1.0 582 10 1,505 t.5 757 15 t,505 _m 1,516 2.0 1,208 20 1 r505 ~ 1,514 , i 2.5 t,520 25 t r505=E 1.5t2 3.0 30 1,505 i 1 3.5 e. 1.508 I 4.0 4.5 1,605 5.0 ~.~}0,~ 5.5 0 5 10 16 20 26 30 6.0 Time, rain 6.5 7.0 7.5 8.0 8.5 9.0 9.5 10.0 10.5 11.0 Casing Integrity Test 1.600 1/,00 t ,200 1,000 800 0.0 1.0 2.0 3.0 4.0 Volume Pumped, bbls 6.0 $.0 7.0 Page 1 File No. ~ Marathon Oil Company Leak Off Test (Actually Taken To Leak Ofl~ Block & Well CLU 6 Casing Size 7 In I 7 In Lease Canne~ Loop Casing Weight 26 lb/fi 23 lb/ti Rig Name Glacier Rig 1 Casing Grade & Thread L80 Butt I LB0 Butt Rig Type LAND Shoe Depth~ MD 2,965 fl RKB to MWL Shoe Depth, TVD 2,322 fl Water Depth Test Depth, TVD 2,329 ff RKB to Mud Line Tested EMW at shoe 19.01 ppg Co. Rep. Darrell Green Date Tested 13-8ep-00 Test Pump Rate, bpm 0.5 bpm Mud Type Water Base Mud YP 10 lb/100 sf Mud Volume Pumped, bbls 3 bbls Mud Wt 8.8 ppg HPHT WL 2.5 cc/30 mln Max Pre-~re Observed, psig t ,255 psig Mud Vis 40 s/qt Mud Gel t 0 sec 8 Ib/t 00 sf Departure Pressure, psig 1233 psig Mud PV 10 cps Mud Gel 10 mln 29 lb/100 st' Volume bbls 0.0 0.5 '!.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 5.5 6.0 6.5 7.0 Injection Pressure psi 0 835 1,146 I r255 1,233 1,230 Test Comments Pressure Fall Off Time Minutes 0 1 2 3 1 A0o 1,200 1.000 800 600 400 2OO 0 Pressure Fall Off Plot 0 2 4 6 8 t0 Time, mln Leak Off Test 1,400 O4 1,200 1,000 8O0 60O 400 200 0.0 1.0 2.0 3.0 4.0 Volume Pumped, bbls 5.0 6.0 7,0 Page 1 Alaska _1~~ .... ~ Domestil~ ,duction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 December 13, 2000 Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 LETTER OF TRANSMITTAL VIA CERTIFIED MAIL The following well logs are enclosed: Print O~'u -~-'~'~O''~t~arath°n Oil Comnanv CLU-6 /RST-SIGMA - 1b/1~3/00 ............................................................................................................. 1 · ~3-3/8" HSD Perforation - 10/23/00 ............................................................................................. 1 Marathon Oil Company KTU 32-7 v~U 32-7 - 3.75" Gauge Ring/4.5" Plug, GR-CCL - Perforating Record - 11/12/00 ................... 1 ~KU 32-7 - SLIM Sonic Logging DT Combined Mode - 9/9/00 ................................................. 1 ~KU 32-7 - SLIM Sonic Logging CBL-VDL - 9/9/00 ................................................................. 1 ,~U 32-7 - Depth Determination, 4.5" Bridge Plug, GR-CCL, Perforating Record - 9/9/00 ...... 1 Marathon Oil Comoanv KBU 33-6L0ng ~, Cement Mappin~ L~g, SCMT-PSP - 9/14/00 ............................................................................. I Marathon Oil Company SU 41-t5 t~Oompletion Record, 2-1/8" Enerjets - 8/4/00 .......................................................................... 1 Please sign and return confirming you have received this data. Thank you, MARATHON OIL COMPANY Enclosures Certified Receipt No. 70000520002487427729 Received Date: A subsidiary of USX Corporation Environmentally aware for the long run. Alaska ~ 3n Domestic ,-'roduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 November 15, 2000 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: CLU 6 Dear Mr. Wondzell: Enclosed are the following documents for well CLU 6: · Well Completion Report · Well History · Wellbore Schematic · Directional Survey Please contact me if any additional information is needed. I can be reached at 907-564-6303 or rjaffinito@marathonoil,com. Sincerely, Ralph Affinito Production Engineer Enclosure A subsidiary of USX Corporation Environmentally aware for the long run. A(~. STATE OF ALASKA J'i AL ..A OIL AND GAS CONSERVATION CO . JSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OILN GAs~l SUSPENDEDE'~ ABANDONED~ SERVICEF'~ Classification of Service Well 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 113' FSL & 465' FEL, Sec. 7, T5N, R11W, SM At top of Producing Interval 3080' FSL& 3360' FWL, Sec. 8, TSN, RllW, SM At Total Depth 3716' FSL& 4180' FWL, Sec. 8, T5N, R11W, SM 7. Permit Number 200-033 8. APl Number 50-133-20492-00 9. Unit or Lease Name Canney Loop Unit 10. Well Number CLU 6 1. Field and Pool Cannery Loop Field Sterling Pool 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KB=42', GL = 21' I ADL 60568 & 60569 17. Total Depth (MD+TVD)8320, MD, 5278' TVD 18. Plug Back Depth (MD+'rVD)8223, 5241'TVD 19. DirectionalSurVeYyes~_~No ~ I I 22. Type Electic or Other Logs Run AIT-MCFL-PEX-TVD-FDL-CNL-SPHI-DTCO-RST-SIGMA-GR 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 9-5/8" 5305 P- 110 0 91' Driven Driven N/A 7" 23-26 L-80 0 2983' 8-1/2" 307 sks N/A 4-1/2" N/A 12.6 L-80 0 , 8308' 6-1/8" 547 sks N/A N/A N/A N/A N/A N/A N/A N/A 24. Perforalions open to Production (MD+TVD of Top and Bottom and interval, size and number) C-1 7846-7860' MD (4961-4970' TVD) 6 SPF C-2 8014-8024' MD (5074-5081' TVD) 6 SPF I~, ~) ~:,, .~j ~ ~ r.,'~ ': :' ';: ........ ~:'"'~'~' 27. Date First Production 26-Oct-00 Date of Test Hours Tested 11/1/2000 24 Flow Tubing Pres. Casing Pressure 1710 N/A 28. 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A N/A PRODUCTION TEST I~(~'6'f'Operation (Flowing, gas lift, etc.) flowing OIL-BBL GAS-MCF WATER-BBL 0 5374 0 OIL-BBL 0 IPRODUCTION FOR TEST PERIOD CALCULATED 24-HOUR RATE GAS-MCF 5374 WATER-BBL 0 ICHOKE SIZE IGAS-OIL I N/A OIL GRAVITY-APl (corr) N/A RATIO Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Sterling Sandstone - Interbedded sandstone, silt and shale. Sandstone is porous and gas and/or water bearing. No cores were taken. Form 10-407 Rev. 7-1-80 N:\drlg\kgt~wells\KBUS$-6V~OG COMPL. xls '~ &~,,..'.~ CONTINUED ON REVERSE SIDE ORIGINAL Submit in Triplicate (, 29. 30. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered NAME MEAS. DEPTH TRUE VERT. DEPTH and gravity, GOR, and time of each phase. Steding B4 6912 4332 Combined production test from the Cl (7846') and C2 (8014') flowed 5374 MMCFGPD/0 BWPD. Sterling Cl 7846 4961 Sterling C2 8014 5074 ,' ..~ ,,I,~,~ ,,... 31. LIST OF A~ s ACHMENT$ Daily operations summary, wellbore schematic, directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ Ralph Affinito Title Production Engineer Date 11/9/2000 . 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 othenNise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage 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 N:\.drlg~sterling~s uS2-9~AOGCOMPL, xls APl: KB: GL: SURFACE LOC: BOT HOLE LOC: SPUD: COND CSG: SURFACE CSG: PROD CSG: TD: MARATHON OIL COMPANY ALASKA REGION Cannery Loop #6 Well History 50-133-20492-00 42 feet 21 feet 113' FSL 465' FEL Sec 07, T5N, R11W, S. M. 3716' FSL 4180' FWL Sec 08, T5N, RllW, S. M. September 09, 2000 9-5/8" 53.5 ppf P-110 driven to 70 feet 7" 23-26 ppf L-80 to 2983' cemented w/280 sks plus a 27 sk top job 4-1/2" 12.6 ppf, L-80 to 8308' cemented w/547 sks 8320' MD/5278' TVD Sep 09, 2000 Sep 27, 2000 O~17,2000 Om19,2000 om 23,2ooo om26,20o0 Spud Well. Drill w/8-1/2" bit to 2983'. Ran 7" 23-26 ppf L-80 BTC csg to 2966' MD. Cemented csgw/280sksofLITECRETE plus 27 sks LITECRETE top job. MU new BHA of 6-1/8" bit and drill out shoe. Perform leak off test to 19.01 ppg EMW. Directionally drill to 8320' MD / 5278' TVD. RU Schlumberger logging service and attempt to run Platform Express open hole logs on WL. Stacked out at 7800'. POH and remove knuckle joint and make second logging attempt to no avail stacking out at 7800'. RIH w/DP and tag bridge at 7800'. Work through and condition hole. TOH and run logging tools on drill pipe stacking out at 7795'. Unable to work past bridge. Have Platform Express open hole logs from 7800' to above hydrocarbon bearing sands. Run 4-1/2" Hydri1521 12.6 ppf L-80 tubing from 8308' to surface with 58 centralizers. Cement tubing in place with 161 sacks of 12.9 ppg lead and 394 sacks of 15.8 ppg tail cement. Cement was displaced with 6% KCl water. Total cement pumped was 547 sacks of Class G cement. Calculated top of cement 2500'. Pressure tested hanger. Installed BPV and tested tree - all fine. Released Glacier Drilling Rig #1 on September 26th, 2000. Remove BPV. RU Schlumberger logging service to run cased hole logs but unable to get deep enough. RU slickline unit. RIH w/3.65" GR to 8089' tagging solid. RIH w/2.5" bailer and bail 1 foot of solid cement. RD Slickline unit. RU DS coil tubing unit. Pressure test BOP and all lines. RIH w/1.5" OD coil and down hole motor. Mill cement to float collar at 8223' but did not drill float collar. Pull up hole to 4000' and unload fluid from wellbore. RD CT. RU Schlumberger logging service. Pressure test. Run RST-SIGMA cased hole logging suite from 8223' to 5500'. Load hole with 25 bbls of 3% KCl water. RU Schlumberger logging service. Have an 823 psig underbalance. Perforate the Sterling C-1 sand from 7846' - 7860' MD (4961-4970' TVD), and the Sterling C-2 sand from 8014' - 8024' MD (5074-5081' TVD) using 3-3/8" HSD guns loaded 6 SPF 60 degree phased. Open well to tank to unload completion fluid. SI well once predominantly gas flow. Turn well to sales at 5,374 MCFGPD / 0 BWPD w/1710 psig FTP. ILIA 9:24 AM 11/15/00 IKB=42.5feet I GL=21.5 feet I I ICLU #6 Sterling Gas Producer 9-5/8" 53.5 Ibmlft P-110 driven to 91' I J7" 26 Ibm/It L-80 ~ 2966' MD I 4-1/2" 12.6 Ibm/It L-80 Hydri1521 ~ 8308' MD cmt'd 6-1/8" Hole 61.52 Degrees Incl. 4-1/2" 'X' Nipple wl3.813" ID ~ 6049' KB ................... !: !: i ilSt_e~li_~g_ C_-:I peffs 7846-7860,6 SPF 10/23/00 :::: i :i: i:i:i:i:i:i:i' Sterling C-2 P,~ 8014-8024' 6 SPF 10/23/00 18,320' MD 15,278' TVD I Marathon Oil Company CLU #6 Cannery Loop ~1 Pad 1.5 Miles South of Kenai, Alaska DATE; ~ORIGINATOR: 1119/2000 I AFFINITO clu.6~,,, bd~xls I~RA~ON 0~ Conpany Cr.O-6 Cazmez'y v.oop Un:Lk Cook 'rn3.et:, Ataaka S U RV in ~' L 'r S .~ Z N G Bakez' R'ughea ZN'Z~Q You.~z'o£ : ~:'l~B <0 - 8320> Ou~ z*o~ : a'wj'6388 L:L~onBo : Da~e 9~n~ed : Lg~Hep-2000 Da~e c,~ea~ed. = LL-Sep-2000 'FleZd £s cen~z'ed on n60 31 5&.076,w'J.51 L5 37.735 8~z-'uc~uz-e La aen~=ed cmn6O 31 54.076,w151 15 37.735 Hlob lo, akron La n60 31 55.268,w't_51 15 47.263 Blob G~ld cooz'd~nabes an N 2388566.360, R 272504.570 Hlob local ~ooz*d~na~oa an 121.05'N .476.76 W p=o~e~b$on t~pe: alaska - Zone 4,.Sphoz'o~d: CLarke - 1866 Re£oz-ence Mo~h $s TFue No=~h MARATHON Oil Con~an.y Pad #1, CLU-6 Canner], Loop Unit,Cook 'mist:, Alaska Measured inclin. Azimuth TFue VezOt Depth 0.00 195.00 305.00 395.00 465.00 525.00 588.00 675.00 736.00 796,00 827.00 919.00 1014.00 1104.00 1227.00 1288.00 1411.00 1544.00 1660.00 1721.00 1844.00 1906.00 2000.00 2091,00 2185~00 2340.00 2464.00 2626.00 2648.00 2710.00 2771.00 2939.00 3033.00 3157,00 3286.00 3414.00 3542.00 3670.00 3798.00 3924.00 4051.00 4180.00 4308.00 4501.00 4757.00 4886.00 5014.00 5142.00 5335.00 5649.00 Degrees Degrees Depth 0.00 0,00 0.00 0.87 7.60 194.99 0.72 20.40 304.98 1.33 26.10 394.97 2.22 27.00 464.93 3.35 39.40 524.86 5.13 53.60 587.69 9.06 49.30 674.01 12.17 50.90 733.95 12.78 51.60 792.54 13.31 53,90 822.74 16.02 57.20 911.73 17.86 56.90 1002.61 21,39 55.40. 1087.37 24.80 54.00 1200.49 RECTANGULAR COORD INATR S SURVEY LISTING Page 1 Your ref : PMSS <0 - 8320> Last revised : 19-Sep-2000 Dogleg Dsg/1004:t Vezot Sect 0.00 N 0.00 E 0.00 0.00 1.47 N 0.20 E 0.45 1.05 2.94 N 0.55 R 0.21 2.23 4.41 N 1.20 Z 0.69 3.65 6.35 N 2.18 R 1.27 5.60 8.74 N 3.82 E 2.12 8.36 11.83 N 7.25 E 3.26 12.97 18.61 N 15.58 R 4.56 23.70 25.80 N 24,21 E 5.12 34.93 33.91 N 34,32 R 1,05 47.89 38.14 N 39,89 B 2,39 54.88 51.26 N 59.12 E 3.08 78.12 66.32 N 82.35 E 1.94 105.71 83.18 N 107.&3 E 3.96 135,87 111.09 N 146.77 R 2.81 184.07 26.10 53.10 1255.57 126,67 N 167.85 E 2.22 210.27 28.92 52.00 1364.66 161.23 N 212.93 E 2.33 267.08 33.68 5~90 1478.27 203.30 N 267,72 R 3.60 336.15 38.44 52.70 1572.01 244.57 N 322.09 R 4.10 404.41 41.88 53,70 1618.63 268.13 N 353.59 R 5.74 443.74 46.80 55.10 1706.57 318.11 N &23.&9 E 4.08 529.62 48.22 54.40 1748.45 344.50 N 460.83 R 2.&4 575,30 49,87 54;00 1810.06 386,03 N 518,40 E 1.78 646.25 53.60 53.00 1866.41 428.53 N 575,81 E 4.19 717.67 '57.29 52.50 1919,72 475.39 N 637.42 R 3.95 795.07 60,31. 53.50 2000,00 555.15 N 743.30 R 2.02 927,63 60,02 53.40 2061.69 819.21 N 829.71 R 0.24 1035,17 59.73 53.60 2092,81 651,11 N 872,82 R 0.54 1088,79 59.99 53.00 2154.07 714.16 N 957.41 R 0.48 1194.28 60.37 52.10 2184,90 746.87 N 1000.12 R 1.40 1248.07 60.48 53.00 2215.01 779.13 N 1042.23 R 1.30 1301.12 60.65 52.20 2297.57 868,00 N 1158.46 R 0,43 1447.43 59.&8 53,20 2344.48 917.36 N 1223.26 R 1.55 1528,88 59.76 52.&0 2407.19 982.04 N 1308.&6 R 0.60 1635.85 58.55 50.20 2473.33 1051.27 N 1394.90 R 1.74 1746.58 58.95 50.80 2539.74 1120.87 N 1479.34 R 0,51 1855.95 60.87 50.10 2603.91 1191.39 N 1564.72 R 1.57 1966.63 60.86 50.10 2666.23 1263.11 N 1650.50 R 0.01 2078.35 61.10 50.80 2728.32 1334.38 N 1738.80 E 0.51 2190.21 61.18 49.80 2789.14 1404.87 N 1821.70 R 0.70 2300.49 61.04 48.60 2850.50 1477.52 N 1905.88 E 0.83 2411.51 59.26 51.10 2914.71 1549.67 N 1991.37 R 2.17 2523.27 60,18 48.90 2979.26 1620.72 N 2078.03 R i,65 2633,70 59.31 52.&9 3076.53 1726.32 N 2204.98 R 1.67 2800,30 60.74 50.40 3204.44 1864.54 N 2378.36 E 0.90 3022.01 59.62 51.70 3268.59 1934.90 N 2465.39 E 1.23 3133.89 60.12 51.50 3332.84 2003.66 N 2552.15 ~ 0.41 3244.59 60.82 49.30 3395.93 207~,65 N 2637.95 E 1.59 3355.88 60.33 51.80 3490.76 2181.46 N 2767.74 E 1.16 3523.88 61.27 53.00 3643.95 2348.68 N 2984.90 R 0.45 3797.97 211 ~ata is in feet unless o~herwise stated. Coordinates from CLU-6 and TVD fro~Rstimated RKB (42.50 Fb above mean sea level). Bott~mhole distance is 5896.35 on azimuth 52.11 ~egroes frmawellhead. Vertical section is frcm wellhea~ on azimuth 52.36 degrees. Calculatlon uses the minimum curvature method. Presented byBakerHughes ZNTEQ .' & MARATHON 0il Con,any Pad #i,CLU-6 Cannsz~ Loop Unit,Cook Inlet, Alaska Measured Inclin. Azimuth True Vort Depth Degrees Degrees Depth 5838.00 58.04 51.60 3739.42 6155.00 58.85 51.60 3905.31 6462.00 58.91 51.20 4063.98 6663.00 53.90 56.30 4175.22 6893.00 48.10 54.20 4319.91 7141.00 47.59 55.60 4486.35 7449.00 47.22 52.70 4694.84 7697.00 48.40 51.30 4861.39 8038.00 47.26 50.60 5090.31 8265.00 48.74 52.70 5242.21 8320.00 &9.O0 52.70 5278.39 RECTANGULAR COORDINATES SURVEY LISTING Page 2 Your ref : PMSS <0 - 8320> ~ast revised : 19-Sep-2000 Dogleg Deg/100ft 2448.38 N 3113.95 E 1.82 2616.17 N 3325.65 E 0.26 2780.14 N 3531.05 E 0.~1 2879.23 N 3665.82 g 3.27 2980.95 N 3812.69 B 2.62 3086.67 N 3963.'09 E 0.47 3219.42 N 4146.84 E 0.70 3332.55 N 4291.62 E 0.63 3491.76 N 4487.89 E 0.37 3596.39 N 4620.19 E 0.95 3621.49 N 4653.15 R 0.47 Vert Sect 3961.05 4231.15 4493.93 4661.17 4839.59 5023.25 5249,83 5433.56 5686,21 5854.87 5896.30 Prodection to~D All data is in feet unless otherwise stated. Coordinates £ro~CLU-6 and TVD £rmaEstimatod RKB (42.50 Ft above mean sea level). Bottonhole distance is 5896.35 on az~nuth 52.11 degrees from wollhead. vertical section is £ramwellhead on azimuth 52.36 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON 0~1 ~on~any Pad ~annery Loop Unit,Cook Inlet, Alaska MD TVD Rec~angu2ar Coords. SURVEY LISTING Page 3 Your ref : PM~S <0 - 8320> Last revised : 19-SED-2000 Cc~nents in wellpath Ccmm~ent 8320.00 5278.39 Target name 3621.49 N 4653.15 E Projection to TD Targets associated with thiswellpath mmmmm m mmmmmmmmmm m mmm m Geographic Location T.V.D. Rectangular Coordinates Sterl~n~ B2 TGT - 2- 276397.137,2391451.164,0.0000 4312.50 2958.95N 3836.76E 8-Feb-2000 Top o£ Buluga 9-&ug- 5225.00 3575.80N 4631.90E 10-Aug-2000 #'~" AItPBU · Main Results Company Marathon Field Cannery Loop Well CLU 6 Test Initial PBU Date Gauge Depth Formation interval Perforated interval 10/29/00 C1&2 7846-60' & 8014-24' TEST TYPE Porosity Phi (%) Well Radius rw Pay Zone h Standard 25 O.2552 ft 14ff FLUID TYPE Gas Gravity Pseudo-Critical P Pseudo-Critical T Reservoir T Reservoir P Properties Total Compr. ct Viscosity Gas 0,556 682.851 psia 340.646 °R 100 °F 2200 psia @ Reservoir T&P 0.000333424 psi-1 0.0157721 cp Flow Period # Rate Rate Change P at dt=0 Pi Time Match Pressure Match ,2 0 MSCF/day 5000 MSCF/day 2045.84 psia 2206.29 psia 1210 (hr)-1 9E-7 (psi2/cp)-I RESERVOIR BOUNDARY WELL Storage C Skin factor Delta P Skin kh k Mobility k/mu Investig. R Tested Volume L sealing at Homogeneous 1 Fault Storage & Skin 0.0552 STB/psi 37.2 126.856 psia 3580 md.ft 256 md 16200 2790 ft 1.52386E7 Barrels 1210 ft H = Perforated Interval Only Saphir Level 3 V2.30T - 10-2000 Company Field Well Test AItPBU: Simulation Marathon Cannery Loop CLU 6 Initial PBU 2200 - -- -- -- -- 2100 - 5000 0 10 20 30 40 50 60 70 80 90 100 110 P [psia] & Q [MSCFIday] versus T [hr] Flow Period# 2 RESERVOIR Homogeneous Rate 0 MSCF/day BOUNDARY 1 Fault Rate Change 5000 MSCF/day WELL Storage & Skin P at dt=0 2045.84 psia Storage C 0.0552 STB/psi Pi 2206.29 psia Skin factor 37.2 Delta P Skin 126.856 psia Time Match Pressure Match 1210 (hr)-1 9E-7 (psi2/cp)-I kh 3580 md.ft k 256 md Mobility k/mu 16200 Investig. R 2790 ft Tested Volume 1.52386E7 Barrels L sealing at 1210 ft H = Perforated Interval Only Saphir Level 3 V2.30T - 10-2000 AItPBU · Semi-Log Company Marathon Field Cannery Loop Well CLU 6 Test Initial PBU 4E8 - -- -- 3.9E8 -- -- 3.8E8 - -- -- 3.7E8 -- -- 3.6E8 -- -- -5 -4 -3 -2 -1 m(P) [psi21cp] versus Superposition t ,.. Flow Period # 2 Rate 0 MSCF/day Rate Change 5000 MSCF/day P at dt=0 2045.84 psia Pi 2206.29 psia Time Match 1210 (hr)-1 'Pressure Match 9E-7 (psi2/cp)-I RESERVOIR Homogeneous BOUNDARY 1 Fault WELL Storage & Skin Storage C 0.0552 STB/psi Skin factor 37.2 Delta P Skin 126.856 psia kh 3580 md.ft k 256 md Mobility k/mu 16200 Investig. R 2790 ft Tested Volume 1.52386E7 Barrels Lsealing at 1210 ft H = Perforated Interval Only Saphir Level 3 V2.30T - 10-2000 Company Field Well Test Marathon Cannery Loop CLU 6 Initial PBU AItPBU · Log-Log _ ~- ~+ ............. ~~ ~ ~~--~----.-=~__r ~ [] r-1 -F I I I I I II I I I I lill i I I i iiii i I I I i iii, i I I I I III I I I 10 7_ 10 6 10 5 0 -4 10 -3 0.01 0.1 1 10 dm(P) [psi21cp] versus dt [hr] Flow Period # 2 RESERVOIR Homogeneous Rate 0 MSCF/day BOUNDARY 1 Fault Rate Change 5000 MSCF/day WELL Storage & Skin P,at dt=0 2045.84 psia Storage C 0.0552 STBIpsi Smoothing 0.1 Skinfactor 37.2 Pi 2206.29 psia Delta P Skin 126.856 psia Time Match Pressure Match 1210 (hr)-1 9E-7 (psi2/cp)-I kh 3580 md.ft k 256 md Mobility k/mu 16200 Investig. R 2790 ft Tested Volume 1.52386E7 Barrels Lsealing at 1210 ft H = Perforated Interval Only Saphir Level 3 V2.30T - 10-2000 ,, Company Field Well Test AItPBU · History Listings~ Marathon Cannery Loop CLU 6 Initial PBU Rate Duration Date Time FP # MSCF/day hr 31/10/2000 00:00:00 1 5000.00 68.8350 02/11/2000 20:50:06 2 0,00 49.7553 H = Perforated Interval Only Saphir Level 3 V2.30T - 10-2000 Company MOC Field CLU Well CLU 6 Test 4 Pt Test CLU6Low' Main Results Date Gauge Depth Formation interval Perforated interval 1/10-12/01 7853' MD Sterling C-1 & C-2 7846-60' & 8014'24' TEST TYPE Porosity Phi (%) Well Radius rw Pay Zone h Standard 25 0.2552 ft 41.5 ft FLUID TYPE Gas Gravity Pseudo-Critical P Pseudo-Critical T Reservoir T Reservoir P Properties Total Compr. ct Viscosity Gas 0.565 681.636 psia 343.045 °R 105 OF 2205 psia @ Reservoir T&P 0.000308765 psi-1 0.015824 cp Flow Period # Rate Rate Change P at dt=0 Pi Time Match Pressure Match 12 0 MSCF/day 8600 MSCF/day 1881.47 psia 2143.53 psia 1210 (hr)-1 5.32E-7 (psi2/cp)-I RESERVOIR BOUNDARY WELL Storage C Skin factor Delta P Skin Homogeneous Infinite Storage & Skin 0.0568 STB/psi 33.6 200.337 psia kh 3680 md.ft k 88.6 md Mobility k/mu 5600 Investig. R 857 ft Tested Volume 4.26457E6 Barrels January 10-12 4 PT Test; Simple Reservoir Description Saphir Level 3 V2.30T - 01-2001 Compa,,y' MOC Field CLU Well CLU 6 Test 4 Pt Test CLU6Low · Simulation 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 lOOO 8600 1800 1810 1820 1830 1840 P [psia] & Q [MSCFIday] versus T [hr] Flow Period # 12 Rate 0 MSCF/day Rate Change 8600 MSCF/day P at dt=0 1881.47 psia Pi 2143.53 psia Time Match 1210(hr)-1 Pressure Match. 5.32E-7 (psi2/cp)-I RESERVOIR Homogeneous BOUNDARY Infinite WELL Storage & Skin Storage C 0.0568 STB/psi Skin factor 33.6 Delta P Skin 200.337 psia kh 3680 md.ft k 88.6 md Mobility k/mu 5600 Investig. R 857 ft Tested Volume 4.26457E6 Barrels January 10-12 4 PT Test; Simple Reservoir Description Saphir Level 3 V2,30T - 01-2001 ( Company MOC Field CLU Well CLU 6 Test 4 Pt Test CLU6Low · Semi-Log 3.8E8 -- 3.7E8 3.6E8 .._ 3.5E8 -- -- -- 3.4E8 -- -- 3.3E8 -- 3.2E8 3.1E8 -- -5 ~ -3 -2 -1 m(P) [psi21cp] versus Superposition t Flow Period # '12 Rate 0 MSCF/day Rate Change 8600 MSCFIday P at dt=0 1881.47 psia Pi 2143.53 psia Time Match 1210(hr)-1 Pressure Match 5.32E-7 (psi21cp)-I RESERVOIR Homogeneous BOUNDARY Infinite WELL Storage & Skin Storage C 0.0568 STB/psi Skin factor 33.6 Delta P Skin 200.337 psia kh 3680 md.ft k 88.6 md Mobility k/mu 5600 Investig. R 857 ft Tested Volume 4.26457E6 Barrels January 10-12 4 PT Test; Simple Reservoir Description Saphir Level 3 V2.30T - 01-2001 Company MOC Field CLU Well CLU 6 Test 4 Pt Test CLU6Low 'Log-Log (" [] D [] I I I i iiii I I I I I III I i I I ~ iii I I ~ I I ~1 I I I I i iii 107 106_ 105 10 -3 0.01 0.1 1 10 dm(P) [psi21cp] versus dt [hr] Flow Period # 12 RESERVOIR Homogeneous Rate 0 MSCF/day BOUNDARY Infinite Rate Change 8600 MSCF/day WELL Storage & Skin P at dt=0 1881.47 psia Storage C 0.0568 STB/psi Smoothing 0.1 Skin factor 33.6 Pi 2143.53 psia Delta P Skin 200.337 psia Time Match Pressure Match 1210 (hr)-1 5.32E-7 (psi2/cp)-I kh 3680 md.ft k 88.6 md Mobility k/mu 5600 Investig. R 857 ft Tested Volume 4.26457E6 Barrels January 10-12 4 PT Test; Simple Reservoir Description Saphir Level 3 V2.30T - 01-2001 Company MOC Field CLU Well CLU 6 Test 4 Pt Test 2100 - -- -- -- -- -- 2000 -- -- -- -- -- -- 0 1 2 3 4 5 Horner: P versus Log(tp + dt) - Log(dt) Flow Period # 12 Rate 0 MSCF/day Rate Change 8600 MSCF/day P at dt=0 1881.47 Psia Pi 2143.53 psia Flexible line # 1 P vs Log(dt), BU Slope -5.8478 Intemept 2142.87 kh 4350 md.ft k 105 md Skin factor 41.1 January 10-12 4 PT Test; Simple Reservoir Description Saphir Level 3 V2,30T - 01-2001 Company Field Well Test MOC CLU CLU 6 4 Pt Test CLU6Low · History Listing~~' Rate Duration Date Time FP # MSCF/day hr 12/01/2001 00:19:00 1 7226.70 1800.00 28/03/2001 00:19:00 2 0.00~ 1.86278 02:10:46 3 2700.00 2.16000 04:20:22 4 0.00 2.21944 06:33:32 5 5100.00 2.01667 08:34:32 6 0.00 1.91944 10:29:41 7 6300.00 1.95000 12:26:41 8 0.00 2.16667 14:36:42 9 8600.00 1.27222 15:53:01 10 0.00 0.38334 16:16:02 11 8600.00 13.1197 29/03/2001 05:23:13 12 0,00 14.5106 January 10-12 4 PT Test; Simple Reservoir Description Saphi~ Level 3 V2.30T - 01-2001 Cop)fright 2002. All rights reserved. P(' .- 'eum Information/Dwights LLC d/b/a IHS En~' ", Group. KENAI AK CANNERY LOOP UNIT 6 MARATHON OIL COMPANY ACTIVE Detailed Production Report Lease Name: Lease Number: Operator Name: State: County: Field: Sec Twn Rng: Latitude/Longitude: Regulatory #: API: Production ID: Reservoir Name: Prod Zone: Prod Zone Code: Basin Name: Gas Gatherer: Liquid Gatherer: Status: CANNERY LOOP UNIT 10320 MARATHON OIL COMPANY ALASKA KENAI KENAI 7 5N llW 10320 50133204920000 25000113320492000578 CLU STERLING UNDEFINED STERLING 654SRLG COOK INLET BASIN ACTIVE GAS Well Number: Cum Oil: Cum Gas: Cum Water: First Production Date: Last Production Date: Spot: Lat/Long Source: Completion Date: Total Depth: Upper Perforation: Lower Perforation: Gas Gravity: Oil Gravity: Temp Gradient: N Factor: GOR: 6 3,001,227 109 OCT 2000 JAN 2002 0.0 Annual Production Year Oil Gas Water BBLS MCF BBLS Beginning Cum: 2000 2001 2002 Totals: 452,833 2,128,370 420,024 109 3,001,227 109 Monthly Production Date Oil Gas Water Cond Yld % Water # of Days MO/YR BBLS MCF BBLS BBLS/MCF Wells on llllllllllllllllllllll Illllllllllll I I llllllllllllll illlllllllllllllllllllllllllllll illlllllllllllllll OCT 2000 22,624 109 NOV 2000 201,639 0 DEC 2000 228,570 0 Totals: 2000 452,833 109 1 5 1 30 1 31 JAN 2001 162,935 FEB 2001 193,271 1 of 2 1 24 1 27 Copyright 2002. All rights reserved. P~r'" 'eum Information/Dwights LLC clPo/a IHS En~r "Group. ,,' MAP. '2001 132,702 APR 2001 35,343 MAY 2001 26,937 JUN 2001 142,677 JUL 2001 46,844 AUG 2001 25,661 SEP 2001 137,656 OCT 2001 366,333 NOV 2001 393,501 DEC 2001 464,510 Totals: 2001 2,128,370 JAN 2002 420,024 Totals: 2002 420,024 17 7 4 19 7 4 16 29 30 31 31 2 of 2 ~RATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/CLU-6 23-Sep-00 24-Sep-00 25-Sep-00 26-Sep-00 POOH LID drill pipe. Changed rams and tested. Started running 4 1/2" casing. Ran 4 1/2" casing to 8124: Pipe stuck. Circulated and reduced mud weight from 9.5 to 9.0 ppg. Worked pipe free. Ran casing to 8308'. CBU. Started cementing. Finished cementing 4 1/2" casing. N/D BOPE. N/U tree mud and tested, Cleaned mud pits. Rig released from CLU-6 at 0600 hours 9/25/00. Demob rig for move to KU 14-32 workover. MARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai PeninsulalCLU-6 6-Sep-00 Rig up Glacier Drilling #1 on CLU #6. Worked daylight hours only. 7-Sep-00 Rig up Glacier Drilling #1 on CLU #6. Started 24 hour operations at 0600, 09/06/00. 8-Sep-00 Rig up Glacier Drilling #1 on CLU #6. PU top drive. Complete camp installation. NU diverter and function test. Fill pits. ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai PeninsulalCLU-6 16-Sep-00 POH. BHA. RIH. Drilled from 5228' to 6335'. 17-Sep-00 Repaired generator and PLC. Drilled from 6335' to 6885'. CBU. Made 25 STD wiper trip. Drilled to 7360'. 18-Sep-00 Drilled from 7360' to 8320'. CBU. Made wiper to casing shoe. 19-Sep-00 Finished wiper trip. CBU at 8320'. POOH. Logged out of the hole from 7800'. RIH for wiper trip. 20-Sep-00 Made wiper trip. RIH with logging tools and could not get past 7,800'. POOH with logging tools. 21-Sep-00 POOH with logging tools. Make up and RIH with logging tools on drill pipe. Could not work past 7790'. 22-Sep-00 Attempted to work drill pipe. Conveyed logging tools past 7790'. POOH. Tested BOPE. RIH with bit. Tagged ledge at 7793'~ Washed and reamed to 8320'. CBU. MARATHON OIL COMPANY {' ~ (~(~ - ~ ~ ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai PeninsulalCLU-6 - PTD 200-033 9-Sep-00 Completed rig mob. Accepted rig at 0600 hours 9/8/00. Spudded well at 2100 hours 9/8/00. Drilled to 440'. 10-Sep-00 Drilled from 440' to 2541' 11-Sep-00 Drilled from 2541' to 2983'. CBU. Made wiper trip. CBU. POOH. Started running 7" casing. 12-Sep-00 Finished running and cementing 7" casing. Performed top job. Nippled down diverter and installed starting head. 13-Sep-00 Installed well head. Nippled up BOPE. Tested BOPE. Tested 7" casing at 1500 psi. Picked up 4" drill pipe. Picked up new BHA. 14-Sep-00 P/U drill pipe and BHA. RIH. Tag cement at 2871'. Drilled out to 3003'. Tested shoe. Drilled from 3003' to 4100'. 15-Sep-00 Drilled from 4100' to 5069'. Made wiper trip to shoe. Drilled to 5228'. POOH for MWD. Alaska [~'" n Domestt ,~duction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 October 31, 2000 Alaska Oil & Gas Conservation Commission Attn: Loft Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 LETTER OF TRANSMITTAL VIA AIRBORNE The following well data are enclosed: ,, Marathon Oil Company CLU 6 Prin~/ Reoroducit~le CLU 6 - SLIM Sonic Logging, Delta Compressional - 9/26/00 ................................................. 1 ........... -1 (film) ~ . CLU 6 Array Induction, MCFL Gamma Ray, Caliper, Platform Express - 9/18/00 ................ 1 ../. ........ 1 (film) / CLU 6 - Density, Neutron Porosity, Gamma Ray, Caliper, Platform Express - 9/18/00 ............ 1 .~ ....... I (film) / CLU 6 - Density, Neutron Porosity, Gamma Ray, Caliper, TVD - 9/18/00 ............................... 1 ...~.. ...... 1 (film) i' CLU 6 Array Induction, MCFL, Gamma Ray, Caliper, TVD - 9/18/00 ................................... 1 ' 1 (film) / CLU 6 - Formation Log - TVD - 9/13-17/00 .............................................................................. 1 ..,(.. ..... 1 (vellum) ,, CLU 6 - Formation Log - MD - 9/13-17/00 ................................................................................ I ..'f~ ...... 1 (vellum) ,/ Marathon Oil Company KTU #32-7 - Final Well Report .............................................................. 1/'' / ~l~-*~l Marathon Oil Company KBU #33-6 - Final Well Report ..............................................................1 / Please sign and return confirming you have received this data. Thank you, MARATHON OIL COMPANY Kaynell Zeman Enclosures Via Airborne A subsidiary of USX Corporation Environmentally aware for the long run. October 18, 2000 Alaska Oil & Gas Conservation Commission Atto: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 Well Cuttings Samples Disposition KTU 32-7 and CLU 6, Cook Inlet, AK Sample Inventory Marathon Oil Company CLU 6 Box I Depths One set of 20' samples from 5500-8320' (TD) 1 5500' - 6100' 2 6100' - 6700' 3 6700' - 7260' 4 7260' - 7660' 5 7660' - 8000' 6 8000' - 8320' Sample Inventory Marathon Oil Company KTU 32-7 Box I Depths One set ofl0'samplesfr0m5700-9121'(TD) 1 5700' - 6040' 2 6040' - 6300' 3 6300' - 6580' 4 6580' - 6860' 5 6860' - 7220' 6 7220' - 7500' 7 7500' - 7840' 8 7840' - 8120' 9 8120' - 8470' 10 8470' - 8730' 11 8730' - 8920' 12 8920' - 9121' 13 Core Chips Please sign and return confirming you have received this data. Thank you, MARATHON OIL COMPANY Kaynell Zeman Enclosures Hand Delivered Received Date: BY"~~~~~ Re: Drilling Out Cement PTD 200-033 Subject: Re: Drilling Out Cement PTD 200-033 Date: Thu, 05 Oct 2000 10:15:21 -0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Ralph J Affinito <rjaffinito~marathonoil.com> Ralph, I agree, this is part of the completion and no additional paper work is needed. The operation can be reported on the completion Report - 10-407. Thanks, Blair Ralph J Affinito wrote: > Blair, > > Marathon intends to utilize CT (on approximately 10/12/00) to remove approximately 100 feet of cement from the bottom'of the recently drilled Cannery Loop #6 well prior to commencing completion operations. The cement displacement was slightly inadequate to place the wiper plug below the lowest zone of interest in the 4-1/2" csg/tbg. > > We will not be drilling the landing or float collars. > > It is my understanding that a sundry is not necessary for this project. However, we will call to offer witness of the BOP test. Please advise if I am incorrect. > > Thanks, > Ralph Affinito > Marathon Oil Company > 907-564-6303 1 ofl 10/5/00 10:15 AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount Commissioner Blair Wondzell, P. I. Supervisor ~(~ FROM: Jeff Jones ,/,~ ~. SUBJECT: Petroleum Inspector DATE: Sept. 11, 2000 Cement Top Job Inlet Drlg. Glacier #1 CLU / Sterling Field Well CLU-6 Permit # 200-033 September 11, 2000: I traveled to Marathon Oil Company's Cannery Loop Unit, Sterling Field to inspect well CLU-6, where personnel on Inlet Drilling Glacier Rig #1 were preparing to do a cement top job, because cement had failed to reach the surface during the previous cementing operation. On arrival at the location I spoke with the operator representative, Jim Rose, regarding the casing strings particulars and a plan of action. He indicated that 13 3/8"/#60 conductor pipe was set @ 91' RKB and the 7"/#26 - #23 inverted taper casing string was set @ 2964.7' RKB. It was decided to RIH with 1" schedule 40 pipe until cement was tagged or green cement could be verified. When the 1" pipe reached a depth of 63' it was POH and a fluid sample was evaluated. The sample, tested with Litmus paper indicated an approximate pH of 12 and the smell and consistency of green cement was evident. The 1" pipe was then RIH to a depth of 105' RKB and circulation with water begun. Sampled returns at the cellar also indicated green cement. After circulating approx. 10 bbls. of water, 12 bbls. of 11.4 p.p.g, cement was pumped at a rate of 1.2 bbl/min. I witnessed good cement returns in the cellar, verified by weight, pH, smell and consistency. A casing leak off test may provide further verification. SUMMARY: I witnessed a successful cement top job on Marathon Oil Company's Cannery Loop Unit well #6, in the Sterling Field. Aff. achments: none CONFIDENTIAL Cement Top Job CLU-6 Sterling 9-11-00 JJ.doc MEMORANDUM TO: Dan Seamount Commissioner THRU: Blair Wondzell _~r2'0~. P.I. Supervisor FROM: Lou Grimaldi J, a6r Co- Petroleum Inspector ( State ot Alaska Alaska Oil and Gas Conservation Commission DATE: September 7, 2000 SUBJECT: Diverter Function Test Inlet Drilling CC1 Marathon Oil Co. CLU 6 200-033 Cannery Loop Unit NON CONFIDENTIAL fly I Operator Rep.: Jim Rose Op. phone: 283-2883 Op. E-Mail: Contractor Rep.: Geor,qe Brewster. Rig phone: Rig E-Mail: MISC. INSPECTIONS: ACCUMULATOR SYSTEM: PIF Location Gen.: P Well Sign:. P Systems Pressure: 3000 psig P Housekeeping: P (Gen.) Drlg: Rig: P Pressure After Closure: 1700 psig P Reserve Pit: NIA Flare Pit: NIA 200 psi Recharge Time: :31 mb:sec P FullRecharge Time: 2:41 min:sec P .. Nitrogen Bottles: 4 (~ 2500 MUD SYSTEM INSPECTION: DIVERTER SYSTEM INSPECTION: Light Alarm Diverter Size: 21 114 in. Trip Tank: P P Divert Valve(s) Full Opening: P Mud Pits: P P Valve(s) Auto & Simultaneous: P Flow Monitor: P P Vent Line(s) Size: ...... 16.". in. Vent Line(s) Length: .... '.. '..'75 ..... '~'ft. GAS DETECTORS: Line(s) Bifurcated: NIA Light Alarm " Line(s) Down Wind: P Methane P F Line(s) Anchored: P H2S: p p Turns Targeted I Long Radius: NIA Salt Flats / North W~nd---~---~ Test's Details I arrived to find the rig still assembling the vent line. I had some concerns with the direction the vent line was facing as it would cut off escape for the residence down the road, it also faced in the general direction of a populated area. I brought this up to Jim Rose (Marathon rep.), Jim explained that in case of a problem Marathon would evacuate the trapped people with a helicopter. I requested that he bring my concerns up to Pete Berga (Drilling Supervisor). Pete explained that as surface gas had not been experienced on this pad before and felt they could do it safely. Pete did allow that by the next well the rig would be setup to have the vent line exit from either side. The function test went well with the vent line valve opening promptly and the 21 114" annular preventer closing within 1 minute. The gas detectors were not warmed up yet and would be calibrated this morning. The rig appeared to be in good · shape and is ready to drill surface hole on this well. The situation with the vent line direction is simply poor planning on rig layout. The rig could have been brought in from the opposite direction and the vent line would have been directed at the vacant salt fiats. Total Test Time: 3_ NUmber'of;failures: .......1_. Attatchments: None, .cc: Bill Barton (Marathon Oil Co.,}. Diverter OD1 9-7-00 LG RBDMS Markup.xls OFFICE OF THE GOVERNOR OFFICE OF MANAGEMENT AND BUDGET DIVISION OF GOVERNMENTAL COORDINATION +9165646489 / SOUT'HCENTRAL REE#ONAL OFFICE 550 W. XTH AVENUE, SUt'l'E 1660 ANGHORAGIE, ALASKA 99.501 Pi, h (907) 269.$gaO/FAX: (907) 269-398 CENTRAl. OFFICE R O. BOX 710030 JUNEAU, ALASKA ~811-0030 PH= (907) 46§.$$62/FAX: (907) 455-3075 T-317 P.02/06 F-041 TONY KNOW~8, GOVERNOR J~ PIPELINE COORDINATOITS OFFICE 411 WEffF 4TH AVENUE, SUITE 2C ANC, HORA~iE, ALASKA 9~$01-2343 PH; (90?) 271-4317~FAX: (907) 272.0890 May 4, 2000 B. Schoffmann Adv. Sr. Reservoir Engineer Mantthon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Dear Mr. Sohoffmann: SUBJECT: Cannery Loop Unit Pad 1; CLU Well 6 Gas Development Project ID No. AK 0003-01G Final Consistency Determination The Division of Governmental Coordination has completed coordinating the state's review of your proposed project for consistency with the Alaska Coastal Management Program (ACMP) and has developed this Final Consistency Determination based on reviewers' comments. Project Description Marathon plans to drill one gas well near Kenai, Alaska as early as May 2000, that .targets the potential gas reserves in the Sterling reservoirs. A water-based mud will be utilized and the existing water well will furnish watm to produce the drilling mud. Approximately 25 days will be required to th-ill CLU 6. The location is T. 5N., IL 11W., Section 7 Seward Meridian. Authorizations The following state and federal authorizations arc needed for ~tis project. Alaska Department of Environmental Conservation (DEC) Temporary Storage of Drilling Wastes C~ printod o~ moycled, paper 01*A3$LH , · F-041 Ma¥-24-00 08:15am From-MARATHON O( Cannery Loop Unit Pad l; CLU 6 +0156646489 T-317 P.03/05 ,, ~,,~}:~:t ( Ylay 4, 2000 Alaska Depanmcnt of Natural Resources (DNK) Temporary Water Use Permit Alaska Oil & Gas Conservation Commission (A.O.G.C.C.) Permit to Ddll Consistency Determination Based on the review of your project by the Alaska Departments of Environmental Conservation, Fish and Game, and Natural Resources; the Kenai Peninsula Borough coastal district, and the Alaska Oil & Gas Conservation Commission, the state concurs with your certification that the project is consistent with the ACMP with thc following modifications which will appear as stipulations on the state permit as noted. The following stipulation will be placed on the DEC Temporary Storage of Solid Waste authorization. A) A person may not store accumulated solid waste in a manner that causes: 1) a litter violation under 15 AAC (;4.015 2) the attraction or access of domestic animals, wildlife, or disease vectors 3) a health hazard; or 4) Polluted nm-offwater [lg AAC60.010(a)] B) A drilling waste containment structure must be sized to contain all the waste and any anticipated precipitation that may accumulate in the storage area, Pursuant to Marathon's waiver request under 18 AAC 60.900 a minimum of one foot of freeboard must be maintained in tanks that are used for drilling waste storage. Additionally, tanks used for drilling waste storage must also have secondary containment consisting of a flexible membrane liner that maintains at least six (6) inches of freeboard. [18 AAC 50.430(a)(2)] C) A drilling waste containment structure must be leak-proof and the liner material must bc compatible with petroleum hydrocarbons, drilling waste and any other material that might be deposited into the temporary storage facility. [18 AAC 60.430(a)(2)] D) After removal ofltte &illing waste from the storage facility Marathon Oil Company shall: 1) Conduct a visual site inspection to confirm thc removal o£ all drilling waste from the site; and 2) Within seven (7) days of decommissioning the storage facility provide photographs, and a written notification to the Department documenting fltat the ,, May-24-O0 08:15am From-MARATHON 0~"'" +9155646489.,.,~. (' T-317 P.04/06 Mr. Schoffraann ",:'i'~' 3 "~;i) .vIay 4, 2000 Cannery Loop Unit Pad l; CLU 6 final site inspection has occun'ed, and information describing the volume o'C drilling waste stored and its final disposal location. [18 AAC 60.430(a)(3)] F-041 E) Drilling mud, cuttings, and completion fluids shall be transported to the Kenai Fields for re-injection or storage certainly within 2 weeks of £mal demobilization of the drilling fig. Rationale: These stipulations are necessary to meet the Air, Land and Water Quality standard [6/.AC 80.140J. Stipulation E) is necessary to maintain the esthetic characteristic of the Cannery Road residential area and to minimize the risk of contaminating the soil, ground water, the Kenai River, Cook Inlet and sensitive wetland habitat in the project vicinity (KPBCMP 2.6 Mitigatior~ 5.2 a. Water Resources, 13.2 b S. torage o_f petroleum and Petrol.eum._ Products).. F) Petroleura products and hazardous materials shall be stored in double-walled tanks or impermeable berms and basins capable of retaining 1 l0 percent of storage capacity plus 12-inches of freeboard. Hazardous materials shall be stored in such a manner as to ensure they are not able to reach wetlands or water sources. Rationale: To prevent spills of toxic substances from contaminating sensitive surface waters and wetlands (KPI~CMP 23.2 c Storage of Petroleum Products and Other _Substanc..es, 5.2 a .Water Resources_). G) Spill response equipment shall be available onsite to handle accidental leaks or spills of fuel or other toxic materials. Rationale: .ds a precaution to prevent hazardous substance runoff into surrounding sensitive areas (5,2 a _Water Resources,, 6AAC 80.130. a, b, c$ Habitats Standard, 6AAC80.140 Air Land and Water Quality Standard). The following stipulation will be placed on the DNR Temporary Water Use authorization. During the constructional or operational phases'of this project, any discharge to state waters made subsequent to this appropriation shall comply with Alaska Water Quality Standards. Rationale: This stipulation is necessary to meet the Air, Land and Water Quality standard [6 AAC 80.140]. . May-24-O0 OS:lSam From-MARATHON +{115554548{l T-31T P.05/06 F-041 Mr. Schoffm~ 4 '~.'? ay 4, 2000 C~e~ Loop Unit Pad 1; CLU 6 ~s fret consistency detem.ation represents a consensus reached be~een you as ~he project applic~t md ~e re~ew~g agencies listed above, reggd~g ~e conditions neoess~ to ensue ~e proposed project is consistem wi~ ~e ACMP. Federal au~ofizafion of yo~ project will be made wi~ ~e ~11 ~derst~ding ~at yom origfltal project ~oposfl has been mottled subject to the conditions described above. Advisories Please be advised that although the state has found the project consistent with'the ACMP, based on your project description and any modifications that appear as stipulations contained herein, you are still required to meet all applicable state ~ind federal laws and regulations. Your consistency determination may include reference to specific laws and regulations, but this in no way precludes your responsibility to comply with other applicable laws and regulations. If changes to the approved project arc proposed prior to or during its siting, construction, or operation, you are required to contact this office immediately to determine if fm~er review and approval of the revised project is necessary. If the actual use differs from the approved use contained in the project description, the state may amend the state approvals listed in this consistency determination. If drilling is planned between April 1 and August 30, Marathon is advised to contact the Dept. of Fish & Game to establish potential impacts to migratory and nesting birds from drilling noise. If is determined that noise levels will adversely impact birds during sensitive life phases, drilling operations may be curtailed or mitigated during this brief time. Should cultural or paleontological resources be discovered as a result of this activity, we request that work, which would disturb such resources be stopped, and that you contact the State Historic Preservation Office (269-8720). Please contact me at 271-4317, or by email at Klebm~jpo.doi-goy if you have arty questions. Project Review Coordinator Glenda Landau, Kenai Peninsula Borough Buz Kuby, DNR, Anchorage o Ma~,'-24-O0 08:16am From-MARATHON .0~~' Mr. Schoffmann "~;~ 5 Caunery Loop Unit Pad 1; CLU 5 (~ary Liepitz, DFO, AnchoraSe and Soldoma Paul McLamon, DBC, Anchora§¢ Ol~nn Gray, DC~, ~unesu +9155646489 T-31T P.06/06 May 4, 2000 F-041 TONY KNOWLE$, GOVERNOR ALASICA OIL AND GAS CONSERVATION CO~ISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 17, 2000 Mr. David Brimberry Senior Geologist Marathon Oil Company P O Box 196168 Anchorage, AK 99519-6168 RE: Denial of Shallow Logging Exemption Request Marathon Cannery Loop Unit #6 Kenai Peninsula Borough, Alaskp-~-'------~ AOGCC Drilling Permit Numb r~....0_?..-.0_3..,3..,___... Dear Mr. Brimberry: Alaska Regulation 20 AAC 25.071 (a), states that an operator shall log the portion of each well below the conductor pipe by either a complete electrical log, a complete radioactivity log, or other log(s) specified by the Alaska Oil and Gas Conservation Commission (Commission). The Commission hereby denies Marathon Oil Company's (Marathon's) request for exemption for logging thc CanneD' Loop Unit #6 well (CLU #6) between surface and 3800 feet TVD. In CLU. #6, the Commission requires Marathon to acquire: 1. a cased hole gamma ray log from base of conductor to surface casing shoe, 2. cased hole gamma ray and neutron porosity logs from surface casing shoe to intermediate casing shoe, and 3. a standard, open hole wireline logging suite from intemacdiatc casing shoe to total depth of the well. These logs will allow Marathon mad the Commission to adequately evaluate geologic and reservoir conditions within this sparsely drilled area. We appreciate 3'our cooperation. If you have any questions or require additional information, please contact the undersigned at (907) 279-1433. avies Petroleum Geologist CC: Robert Crandall Well File ALASKA OIL AND GAS CONSERVATION CO~ISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 P. K. Berga Drilling Superintendent Marathon Oil Company P O Box 196168 Anchorage, AK 99519-6168 Re: Cannery Loop CLU 6 Marathon Oil Company Permit No: 200-033 Sur Loc: 113'FSL, 465'FEL, Sec. 7, T5N, R11W, SM Btmhole Loc. 3716'FSL, 4180'FWL, Sec. 8, T5N, R11W, SM Dear Mr. Berga: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission at 279-1433. Robert N. Christenson, P.E. Chair BY ORDER OF TH~ COMMISSION DATED thisI~o~ day of April, 2000 dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Depamncnt of Enviromnental Conservation w/o encl. Marathon OilCompany Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 9071561-5311 Fax 9071564-6489 April 3, 2000 Mr. Robert Crandall Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage AK 99501-3192 RE: SHALLOW LOGGING EXEMPTION REQUEST MARATHON CLU #6 PTD 8247' (5147' TVD) Marathon requests an exemption for logging the above well in the interval from the surface to 3800' TVD because of the risk and expense of logging in the highly deviated hole that will be drilled (above 60 degrees of devia~on) to reach the deeper objective targets. The closest two wells (Cannery Loop #1 & #5) have logged the interval requested to be exempt. The wells are 200' to 1500' feet east then west (a result of deviated wellbores) of the proposed well in the interval that is under question (map attached). The data for these wells is listed below and is sufficient to evaluate the reservoir fluids (water) and the reservoir quality of the sandstone beds from the base of the conductor pipe (approximately 300') through the non-prospective interval above the gas objective of the Marathon well. The proposed well will be in a similar sffuctural position to the two wells listed below through the non-logging interval. Marathon will acquire logging data over if any prospective reservoir is encountered during drilling. The first possible gas I~'earing sandstone is expected below 4000' TVD. Unocal Cannery Loop #1 Lo.q Data, Sec. 7-T5N-R11W, 1979, TD 11,985' M_n Dual Induction - SFL w/SP, 90' to TD Borehole Compensated Sonic Log, - 90'to TD Compensated Neutron / Formation Density Log w/GR, 3494' to TD High Resolution Continuous Dipmeter, 3540' to 11,960' Proximity Log - Microlog, 9050-TD Mudlog, 1000' to TD Marathon Cannery Loop ~5 Lo.q Data, Sec. 7-T5N-R11W, 1995, TD 11,424' MD Array Induction w/GR & SP, 2968' to TD Dipole Sonic Imager, 2968' to TD Stratigraphic High Resolution Dipmeter, 8500' to TD Natural Gamma Ray Spectrometrylog, 2968' to TD Litho-Density/Neutro, 2968' to TD. Mudlog, 3000' to TD Thank you for your consideration. If you have questions, please contact me at 564-6402. R~.~egards,,.,' David L. Brimberry Senior Geologist Attachment- map RECEIVED 0 5 2000 AJaflm Oil & Gas Cons. Commi~mn And~orage i UNIT BOUNDARY 6 ~, !* 5 ' ; 4 3 ~.,. /.,~,{~ . ,,,,'~,,u.~~~Y/ , '' ,, ,, ~-1 , I !, , , R11W , I i I I i AREA SHOWN RECEIVED APR 0 5 STERLING B2 STRUCTURE 0 1/2 I I MIL£ MARATHON OIL COMPANY ALASKA REGION CANNERY LOOP FIELD KENAI, ALASKA CLU 6 Location February 2000 i _ .o:\freehand/clu61°c. fh 7 X. POTENTIAL HAZARDS Well CLU-6 To comply with state regulations the Potential Hazards section and the well shut-in procedures must be posted in the drillers dog house. The man on the brake(driller or relief driller) is responsible for shutting the well in(BOPE or diverter as applicable) as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC or BLM inspector. This well's primary objective is gas and no oil sands are expected to be encountered. No H2S is anticipated. Gas sands will be encountered from +/-3500'tvd/5266'md to total depth of the well. These sands should be normally pressured and no lost circulation or differential sticking hazards are anticipated. Minor well interference hazards exists from surface to 2580' md. page 1 n:drlg\clu\clu-6\Clu6prog.xls · Re: 'Sor~e Queslions -Reply Subject: Re: Some Questions -Reply Date: Thu, 16 Mar 2000 14:13:57 -0900 From: Tom Maunder <tom maunder@admin.state.ak, us> To: John GEller <jgelle~'@marathonoil.com> CC: Blair Wondzell <blair_wondzell@admin.state.ak. us> Gary, Just a further note regarding what I know of the status of approvals for the proposed work. KU 43-6a ....Sundry approved 399-196, coastal zone not needed KBU 33-6 ....PTD approved 99-24, coastal zone completed KTU 24-6h--PTD approved 99-73, coastal zone completed KTU 32-7 ....approval pending PTD 200-023, coastal zone waived KBU 42-7 ....PTD approved 99-25, coastal zone completed KDU 5 ........ to date, no sundry application received, coastal zone not needed CLU-6 ........ approval pending PTD 200-033, coastal zone underway GO #1 ........ to date, no P'iD application received, coastal zone in preparation I will move the,42=?' and CLU-6 PTD applications on through. We can issue the 42-7 without delay since CZ is not necessary. CLU-6 and ultimately GO #1 can be issued when the respective CZ is received. Thanks again for the info. Tom John GEller wrote: > Tom - I sent you a message a day or two ago that I believe addresses items #3 (i.e. formation test) and #5 (Le. BOP test pressure). I'll tryto address the other concerns you brought up. > > #1 & #2 - We do have a rig schedule prepared, and we're planning on doing all our drilling and workover work this year using the same rig. I'll try to get a GANTT chart to you in the near future, but in the mean time here is our best-estimate for the rig schedule: > 1) Well KU 43-6a workover, start March 23 > 2) Well KBU 33-6 drill & complete, start April 8. > 3) Well KTU 24-6h drill & complete, start May 10. > 4) Well KTU 32-7 drill & complete, start June 26. > 5) Well KBU 42-7 drill & complete, start July 28. > 6) Well KDU 5 workover, start August 29. > 7) Well > 8] Well CLU 6 drill & complete, start September 15. Grossim Oskolkoff #1 drill & complete, start October 15. > The order of these jobs is Only rock-solid for wells 1-3. The order in which we do jobs 4-8 in very much in flux. That is the reason we gave you identical start dates for CLU 6 and KTU 32-7: we want to be able to move to the next well that makes sense without having to wait on permits. But the above schedule is the plan we currently are working under. > > ~1 - There is a typographical error on page 5 of the drilling programthat was sent you for we//KTU 32-7. Including the 50% excess, the top of Cement from the second stage will at 2000'. This adequately covers the Sterling Sands, the top of which is at 3567' TVD. My apologies for the error. > > P/ease/et me know if you have any other questions. > >>> Tom Maunder <torn_maunder~admin. state, ak. us> 03/14/00 02:58pm >>> > Gary, > Following up with my call of a little bit ago, I hate some additional 1 of 3 3fl 7/00 9:41 AM . Some ~ueslions -Reply Tom Maunder AOGCC Subject: Some Questions Date: Tue, 14 Mar 2000 14:58:22-0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: Gary Eller <jgeller@marathonoil.com> Gary, Following up with my call of a little bit ago, I have some additional questions and requests. These may be items for Pete. Please forward on if you would, I don't have Pete's eddress. 1. At this morning's meeting, it is apparent that Marathon is planning to be busy. We like that. Could you please send us an anticipated schedule for the activities of your rig or rigs. 2. I am looking at the CLU-6 and KTU 32-7...will they be drilled with the same rig? The same spud date is on each permit application. 3. When drilling out of a casing, our regulations require 20' to 50' of new hole. The programs specify 10' or 5-10'. 4. By the numbers given in the program, it appears that the planned cement height on the 2nd stage of the 9-5~8" casing in KTU 32-7 will not cover the shallowest Sterling sand. 5. BOP test pressures...on each rig 13-5/8" 5000' psi stacks are planned. For CLU-6, the estimated MASP is 1815 psi. Absent Marathon's need for a higher pressure, we would plan to require a 3000 psi BOP test pressure. On KTU 32-7, with the higher MASP, a 5000 psi test would be the requirement. Thanks for the help. Tom Maunder ^OGCC ~tom maunder.vd Name: tom_maunder, vd .................................... Type: Plain Text (text/plain) 2 of 2 3/16/00 12:02 PM ..Permit;{o-Ddll, Well CLU-6 Subject: Permit-to. Drill, V~ll CLU-6 Date: Tue, 14 Mar 2000 17:57:32-0600 From: "John GEller" <JGEIler@MarathonOil.com> To: Tom_Maunder@admin.state.ak. us CC: CEYoung@MarathonOil.com, JGr=ller@MarathonOil.com, PKBerga@MarathonOil.com Tom - Thanks for calling concerning the permit-to-drill application for well CLU-6 in the Cannery Loop Unit. In response to your questions: 1) After running and cementing casing, Marathon will drill 20' to 50' of new formation before conducting a formation integrity test in accordance with 20 AAC 25.030(0. 2) Since the surface pressure during drilling ofwell CLU-6 is not expected to exceed 1,815 psi, Marathon requests that the BOPE be tested to a maximum of 3,000 psig. Please let me know if I can be of further assistance. 1 of 1 3716/00 1:37 PM Alaska R~,gion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 March 10, 2000 Mr. Steve Davies State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Reference: Revised CLU-6 Permit to Drill Dear Mr. Davies: Please find attached three (3) signed originals of the revised CLU-6 Permit to Drill. They have been changed as per our discussion and my fax dated March 10, 2000. If you have any other questions or concerns, please call me at 564-6319 Sincerely, P.K. Berga Drilling Superintendent Attachment A subsidiary of USX Corporation Environmentally aware for the long run. Cannery Loop Gas Well #6 (Marathon): Marathon Oil Company plans to drill one gas well near Kenai, Alaska in May 2000 that targets the potential gas reserves in the Sterling reservoir. A water-based mud will be used, and the existing water well will furnish water to produce the drilling mud. Approximately 25 days will be required to drill CLU 6. The location is T. 5N., R. 1 lW., Section 7 Seward Meridian. Review Status: Request for Information: April 3, 2000 Comment Deadline: April 12, 2000 Proposed Consistency Determination: April 24, 2000 (on or before) Final Consistency Determination: April 28, 2000 (on or before) S('i~ STATE OF ALASKA ~' g:\cmn\drlg~terllng~su44-10~AOOCOPTD'xls~/~~ '~ ALA A OIL AND GAS CONSERVATION COM ., .SION ~'~--. PERMIT TO DRILL ~, 210 AAC 25.005 ~ la. Type of Work DrillL~ Re-Drill~J lb. Type of well. ExploratoryU Stratigraphic TestU Development OilU Re-EntrYr--~ Deepen~ Servicer~ Development Gas~-'~ Single Zone~'~ MullJple Zone~-~ 2. Name of Operator s. Datum Elevation (DF or KB) 10. Field and Pool MARATHON OIL COMPANY 87' KB feet Cannery Loop Unit/Sterling 3. Address 6. Property Designation P. O. Box 196168, Anchorage, AK 99519-6168 ADL-60568 4. Location of Well at Surface 7. Unit or Property Name 11. Type Bond (see 20 AAC 25.025) 113'FSL, 465'FEL, Sec. 7, T5N, R11W, S.M. Cannery Loop Blanket Surety At top of Productive Interval 8. Well Number Number 3080'FSL, 3360'FWL, Sec. 8, T5N, R11W, S.M. CLU 6 5194234 At Total Depth 9. Approximate Spud Date Amount 3716'FSL, 4180'FWL, Sec. 8, T5N, R11W, S.M. 05/01/00 $200,000 12. Distance to Nearest 13. Distance to Nearest Well 14. Number of Acres in Property 15. Proposed Deplh (MD andTVD) Property Line(unit boundary) 3500 feet 1800 feet 2640 8400' MD/5272' TVD feet 16. To be Completed for Deviated Wells 17. Anticipated Pressure (see 20 AAC 25.035 (e) (2)) Kickoff Depth 550 feet Maximum Hole Angle 61.5 o Maximum Surface 1815 psig at Total Depth (TVD) 5140' 18. Casing Program Set'dng Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 9 5/8" 53.5 P-110 PE +/-150' 0' 0' 150' 150' 8-1/2" 7" 26 L-80 BTC 2600' 0' 0' 2600' 2279' 330 sx 6 1/8" 4 1/2" 12.6 L-80 Hydd1521 8400' 0' O' 8400' 5272' 250 ?!'"'!'., ,~. ~,j ~ ~ ~ ! ..~ :.. ~. i! V" !!i.,~' ii'.;:!' Cannery Loop Unit #6 well will be directionally drilled to an estimated total depth of 8400' MD, 5272' TVD from the existing Cannery Loop Unit pad 1 .The production interval will be cased with 4 1/2" casing cemented in place and run to surface. Marathon's drilling rig will be used to drill and complete this well. The following documents are attached: Drilling Program, Area Maps, Location Map, Structure Map, Surface use plan, Directional Maps, Mud pit .r.w,n.....,owou,.reven,,on..u,.men,...w,n... ORI$1NAL 20. Attachments Filing FeeL~.J Property PlatL~ BOP SketchL~j Diverter SketchL.~ Drilling ProgramLX..j Drilling Fluid ProgramF'q Time vs Depth PlotN Refraction AnalysisN Seabed ReportN 20 AAC 25.050 RequirementsN 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed P.K. B erga ~j~~ Title Drilling Superintendent Date 3/10/2000 ~/' Commission Use Only Permit Number lap, Number iSee Cover Letter ~ "-'~-'~ 50--/..~'5~.- ,,~(~...~) iFor Other Requirements Conditions of Approval Samples Required ~.JYes ~No Mud Log Required ~Yes [~No Hydrogen Sulfide Measures DYes ~"~No Direclional Survey Required ~;~Yes DNo Required Wolking Pressure for BOPE D2M ~3M J--"~5M D10M D15M Other: Approved by Robert N. (~hrJstensoll Commissioner the Commission Date Form 10-401 Rev. 12-1-85 Submit in Triplicate DRILLING AND COMPLETION PROGRAM MARATHON OIL COMPANY ALASKA REGION WELL: CLU 6 FIELD: Cannery Loop Unit PAD: CLU 1 AFE No.: 9701000 SLOT: NA TYPE: Development. REVISION NO.: 0 DATE: 3/1/00 SURFACE LOCATION: TARGETS:' Sterling 113' FSL, 465' FEL, Sec. 7, T5N, R11W, S.M. 3080' FSL, 4290' FWL, Sec. 8, T5N, R11W, S.M. BOTTOMHOLE LOCATION:. 3697' FSL, 4155' FWL, Sec. 8, T5N, R11W, S.M. KB ELEVATION: 42 ft. mean S.L. (est.) GL ELEVATION: 21 ft. mean S.L. I. IMPORTANT GEOLOGIC HORIZONS: FORMATION DEPTH(MD) DEPTH(TVD) Sterling B2 6971 4312 Sterling B4 7446 4572 Sterling C2 8104 5033 Upper Beluga 8204 5110 II. ESTIMATED FORMATION TOPS AND CONTENT: FORMATION DEPTH(MD) DEPTH(TVD) Sterling B2 6971 4312 Sterling B4 7446 4572 Sterling C2 8104 5033 Upper Beluga 8204 5110 TD 8400 5272 RECEIVED POTENTIAL CONTENT gas/water gas/water gas/water gas/water gas/water page 1 n:drlg\clu\clu-6\Clu6prog.xls III. WELL CONTROL EQUIPMENT DIVERTER SYSTEMS The diverter system will consist of a 13 5/8" X 3000 psi annular preventer and a 10" O.D. nonbifurcated vent line. The vent line valve will be full opening and integrated with the annular in the fail safe design as stipulated in 20AAC 25.035. The vent line will be a minimum of 75' from any source of ignition. BLOWOUT PREVENTERS The blowout preventer stack will consist of a 13-5/8" x 5000 psi annular preventer, a 13-5/8" x 5000 psi double gate ram type preventer with blind rams in the bottom and pipe rams in the top, a 13-5/8" x 5000 psi drilling spool (mud cross) with 3-1/8" x 5000 psi outlets, and a 13-5/8" x 5000 psi single gate ram type preventer with pipe rams. The choke manifold will be rated 3-1/8" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor- boy gas buster and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mudpits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. WELLHEAD SYSTEM STARTING HEAD: 13 5/8" 5M x 9 5/8" SOW bottom for N/U diverter system. CASING HEAD: None RECEIVED CASING HEAD: None TUBING HEAD: 11 "-5000 psi top x 7" SOW with base plate for 9 5/8". CHRISTMAS TREE: 4 1/16" - 5000 psi dual christmas tree including two master valves, one flow tee, one wing valve and one swab valve. page 2 n:drlg\clu\clu-6\Clu6prog.xls IV. CASING PROGRAM: TYPE SIZE CASING DESCRIPTION WT. GRADE CONDUCTOR: 9 5/8" 53.5 ppf P-110 SURFACE: 7" PRODUCTION: 4 1/2" 26 ppf L-80 12.6 ppf L-80 SET SET THREAD FROM TO (md/Nd) (md/tvd) PE Surf +/-150 BTC Surf 2600'/2279' Hydril 521 Surf 8400'/5272' HOLE SIZE Driven 81/2" 61/8" CASING DESIGN SIZE WEIGHT GRADE 7" 26 ppf L-80 4 1/2" 12.6 ppf L-80 SETTING DEPTH,TVD 2279' FRAC GRD FORM PRSS DESIGN FACTORS @ SHOE @ SHOE MASP TENS COLL BURST 11.5 702 763 11.84 3.30 6.06 5272' 14.0 2480 3524 4.04 9.23 2.39 All tubulars are new. page 3 n:drlg\clu\clu-6\Clu6prog.xls V. CEMENTING PROGRAM SURFACE: 7" 2600'md/2279' tvd LEAD SLURRY: Class "G"+ required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: SURFACE 12.8 ppg. 2 cu. ft./sk gal/sk hrs:min 50 % in open hole. 150 sks. TAIL SLURRY: Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: 1263 ft. 15.8 ppg. 1.15 cu. ft./sk gal/sk hrs:min 50 % in open hole. 180 sks. RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED ! 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe and 2 shoe joint. Check float. Fill pipe until circulating. 3. M/U float collar. (Baker-lok all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing and centralizers. M/U circulating head. Test lines. 6. Circulate until no gain in circulating efficiency is made. 7. Pump spacer as follows: To be designed. 8. Drop top bottom plug. 9. Mix and pump lead slurry. 10. Mix and pump tail slurry. 11. Drop top plug and displace cement. 12. Check floats. 13. WOC. 14. N/D diverter. Weld on tubing head and N/U blowout preventers. 15. Test BOPE. Run wear bushing. page 4 n:drlg\clu\clu-6\Clu6prog.xls ' V. CEMENTING PROGRAM (continued) ntermediate None .EAD SLURRY: Class "G" + required additives. TOP OF CEMENT: ft. WEIGHT: ppg. YIELD: 2.00 cu. ft./sk WATER REQ.: gal/sk PUMPING TIME: hrs:min EXCESS (%): 25 % over caliper log. ESTIMATED VOLUME: 0 sks. TAIL SLURRY: Class "G" + required additives. TOP OF CEMENT: ft. WEIGHT: 15.8 ppg. YIELD: 1.15 cu. ft./sk WATER REQ.: gal/sk PUMPING TIME: hrs:min EXCESS (%): 25 % over caliper log. ESTIMATED VOLUME sks. RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1.Remove thread protectors and visually inspect connections. 2.Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. 3.M/U float collar. (Baker-lok all connections to top of float collar) 4.Fill pipe until circulating. 5.Run remaining casing. M/U cementing head and test all lines. 6.Circulate and reciprocate until no gains in circulating efficiency is made. 7.Drop bottom plug and begin pumping spacer. 8. Pump spacer as follows: To be designed. 9. Drop bottom plug. 10. Mix and pump tail slurry. Drop top plug. 11. Displace cement with water or brine. 12. Bump plug w/500 psi over final circulating pressure. Check floats. 13. WOC 14. P/U BOP stack. Set slips. N/U casing spool and test. N/U BOP stack. 15. Test BOPE. page 5 n:drlg\clu\clu-6\Clu6prog.xls (, V. CEMENTING PROGRAM (continued) PRODUCTION 4 1/2" @ 8400'md/5272' tvd LEAD SLURRY: Class "G"+ required additives. TOP OF CEMENT: ft. WEIGHT: ppg. YIELD: cu. ft./sk WATER REQ.: gal/sk PUMPING TIME: hrs:min EXCESS (%): %(use 25% over caliper log.) ESTIMATED VOLUME: sks. TAIL SLURRY: Class "G" + required additives. TOP OF CEMENT: 6400 ft. WEIGHT: 15.8 ppg. YIELD: 1.15 cu. ft./sk WATER REQ.: gal/sk PUMPING TIME: hrs:min EXCESS (%): 25 % over caliper log. ESTIMATED VOLUME 250 sks. RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. 3. M/U float collar. (Baker-lok all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing and centralizers. M/U cementing head and test all lines. 6. Circulate until no gains in circulating efficiency is made. 7. Drop bottom plug and begin pumping spacer. 8. Pump spacer as follows: To be designed 9. Mix and pump tail slurry. Drop top plug. 10. Displace cement. 11. Bump plug with 500 psi. over displacement pressure Check floats. 12. WOC. page 6 n:drlg\clu\clu-6\Clu6prog.xls VI. MUD PROGRAM MUD PROPERTIES DEPTH DEPTH WEIGHT VISCOSITY WATER MUD FROM TO TVD ppg sec/qt LOSS TYPE 0' 2279' 8.6-9.0 80-250 15-30 Freshwater gel 2279' 5272' 9.0-10 50-70 <5 FLO PRO/KCL MUD EQUIPMENT The solids control equipment will consist of two flowline cleaners and the MI centrifuge van. Included will be equipment to dewater the underflow from the mud processing equipment to allow for disposal of the cuttings and solids by slurrification and injection into the disposal well at the KGF. VII. LOGGING, TESTING, AND CORING PROGRAMS LOGGING PROGRAM CONDUCTOR: No logging is planned for this interval. SURFACE: No logging is planned for this interval. PRODUCTION: RUN #1: AIT/DSI/LDT/CNL/GR. RUN #2: CMR/AIT/MSFL/LDT/CNL/NGT. RUN #3: RFT/GR. RUN #4: MSCT/GR. COMPLETION: Gammaray/CCL. MUD LOGGING The well will be mud logged from 2600' md(casing point) to TD at 8400' md. CORING PROGRAM No coring planned. TESTING PROGRAM No open hole tests are planned for this well. page 7 n:drlg\clu\clu-6\Clu6prog.xls VIII. BOTTOMHOLE PRESSURES AND POTENTIAL HAZARDS All sands are normally pressured. Hydrogen sulfide gas has not been encountered in any well in the Cannery Loop Unit. IX. OTHER INFORMATION DIRECTIONAL PLAN NORTH DESC MD TVD INCL AZIM COORD EAST COORD VERT SECTION RKB 0 0 0 0 0 KICKOFF 550 550 0.0 52.2 0 build @ 3.0deg/100ft HOLD 2600 2229 61.5 52.2. 612 0 790 0 999 DROP 6971 4313 61.5 52.2 2967 3825 4841 END of DROP 8400 5272 34.0 52.2 3603 4645 5879 Total Depth 8400 5272 34.0 52.2 3603 4645 5879 POTENTIAL INTERFERENCE: WELL DISTANCE (ft.) DEPTH (MD) CLU-1 85.7' 1261' CLU-5 95.9' 2575' page 8 n:drlg\clu\clu-6\Clu6prog.xls Xl DRILLING PROGRAM CONDUCTOR: Drive 9 5/8" conductor to +-150 ft. RKB. Weld starting head to drive pipe. Move in and rig up rotary drilling rig. Nipple up 13 5/8" diverter, diverter valve, and 10" diverter line. Function test diverter and diverter valve. SURFACE: Drill a 8 1/2" hole to 2600' md/2279' tvd per the directional plan. Run and cement 7" casing. WOC. Cutoff 7" and 9 5/8". Weld on 7" SOW by 11" 5M wellhead and test. N/U 13 5/8" 5M BOP'S. Test BOP'S and choke manifold to 250/3000 psi. Set Wear bushing. Test surface casing to 1500 psi. INTERMEDIATE PRODUCTION: Drill float equipment and 10' of new formation w/6 1/8" bit. CBU. Test shoe to leak off. Estimated EMW 11.5 ppg. Drill a 6 1/8" directional hole from 2600'md/2279' tvd to 8400' md/5272' tvd' per the directional program. Log. Pull wear bushing. Run and cement 4 1/2" casing. Test casing to 3000 psi. COMPLETION: Complete well as per comletion program. page 9 n:drlg\clu\clu-6\Clu6prog.xls NOTES: MASP CALCULATIONS: Surface casing: 7" MASP = Injection pressure at shoe + S.F. - Hydrostatic pressure of gas column. MASP = (11.5 ppg + 1.0 ppg) x .052 x 2279' - (.115 x 2279') MASP = 1481 psi - 262 psi MASP = 1219 psi. Intermediate casing: None. MASP = Injection pressure at shoe + S.F. - Hydrostatic pressure of gas column. MASP = MASP = MASP = Production casing: 4 1/2". MASP = Formation pressure(producing zone) - Hydrostatic pressure of gas column. MASP = 9.0 ppg x .052 x 5140' - (.115 x 5140') MASP = 2406 psi - 591 psi MASP = 1815 psi. Cementing The 7" casing must be cemented to surface. Contact AOGCC in advance to see if they want to witness the cement job. BOP/Diverter Tests. Contact AOGCC a minimum of 24 hrs prior to tests to see if they wish to witness. Tubulars All tubulars are new. page 10 n:drlg\clu\clu-6\Clu6prog.xls I I I ,~ I 5U ~JL. ~$d/ I:JL.., il i .~ . ! . ,~ !'~ ~ ~ PT ill.-~ PT. ' I '" '. ! " I~- " I " ' ' ' ' ' I ,......,...., .... ,. ..... ~'~'1 '- - .' 61.5 615 6 X5 & ~ ' '1 .... . .. :'. .... ~. ,. ~.11 ~.~2 .... ~ . ..~, ". . ~1~:~,~.,~-,~ 1 ~'~ ,. ~' ~ ! . '. .'.'... . ." .'i ~...... ~?' ~, ...... ~-- .., ~ , , . .~ .... .., . , .... ,,, ,_u . . .... '"" ','] ,,, i..~~ i ~ i.. ~' , ~ . I'.'_~.' "': ~.'. ,. "., '~ ', ' ~ ' . .'?' ... , ~ '~ . . .. . ~ . ~ ~ ~ , ~. ~ ..'. ~ .,,, ~ ~ ~ ~ ~ . ~ ~ ~ . , . .. i. . .., . ' . '.. ~' ; ' '" ..' I ~, - .... __ . ..... . ~ . ':~ ' . . , ,- ~ . ,. . . .. ~ .~ . . . ,, ~ ,~ ,,~ .. ~' ,. ,,, , : . . ... -'. , .' '. .. .... ~ , ., ,', '. , ~ , : , ~ ~ ~ _~ P~,,, ,, ~_ ,. . . . .. . . = · ,, ~ i _ .. .~ ~' . . . . ,'~ ~ .~ ., i , , ~ i~ ~ --, , . . . · . . ".. .. . .. T' ~ ~ ' ' "." .'. .... . . .....'. .... '' ... . ... . . .. . . _~.. ~. .. '" ::_ ~ , ~ ... . . Marathon Oil Well CLU-6 Diverter Flow line · 113 5/8" 3M Diverter IDiverte; Spool I I10" Diverter Line RECEIVED :~.~ 0 2 ~000 Marathon 0il Well CLU-6 BOP Stack JFIowNipple J JFIow Line JI 13 5/8" 5M Annular Preventer J13 5/8" 5M Double Ram Preventer 3 1/8" 5M Manually Operated Valves I I~ 5/8,, SM Cross I J135/8" 5M Single Ram Preventer J ~ ~' I IPipe Ram J JBlind Ram J J3 1/8" 5M Hydraulically (~ JOperated Valve t 13 1/8" 5M Manually I I Pipe Ram I I I Operated Valve ii Marathon Oil Well CLU-6 Choke Manifold Gas Buster ITo Blooey Line ii iI IBleed off Line to Shakers I 2 9/16" 1 OM Swaco Hydraulically Operated I From BOP Stack Choke 3 1/8" 5M Manually Adjustable Choke ECENE ) f, T 5 N UNIT BOUNDARY 6 5 I 4 3 f- ' · CLU 3 -4419' I . / / / Y q.~J /~.-. ~"~ I .... i I .... RIIW i I I iiiii ~ AREA SHOWN i i i i iii i STERLING B2 STRUCTURE C.I. =50' 0 1/2 I I MILE i i MARATHON OIL COMPANY ALAS~, REGION CANNERY LOOP FIELD KENAI, ALASKA CLU 6 Location February 2000 o :\freeha ndlclu61oc.fh7 CL['C---~-~6 Sterling Gas Producer 9-518" 5305 Ibm/It P-110 driven to 150' J IPROPOSED WELLBORE 17" 26 Ibm/It L-80 ~ 2600' I MD and 2279' TVD cmt'd to 4-1/2" 12.6 Ibm/It L-80 Hydri1521 ~} 8400' MD I 5272' TVD cmt'd wi 250 sks in 6-118" Hole 18,400' MD 15,272' TVD I M. arathon Odd.ny ii CLU #6 Cannery Loop #1 Pacl 1.5 Miles South of Kenai, Alaska [~T.C IOR~,TOR: IFII,~; 2/2~oooI ^FF~.:TO ?u, ,-~wbd.x~s MARATHON Oil Company Structure: Pad #1 Well: CLU-5 Field: Cannery Loop Unit Location : Cook Inlet, Alaska WELL PROFILE DATA KOP ~qO.O0 nOD 5Z.~O~O.O0 O. O0 O. O0 0.00 0.00 End oF Build 2600.51 61~2 52.202228,80612.4~ 78~.57ggg.2~ rqlk Sliding BZ TOT DB71.10 51.02 52.204312.10206%00 3825.(20 4840.84 rap M' 8il~a 8342.81 3&,On S2.20q'2'J~ O0 3683,96d~20.37 .5847.44 ~.00 F.D.. E~ o~ ~q~ ~o.00 3~.gs o,~o ~TZ, W ~mA3q 444~3~,87~0~ 400 800 1200 · +'- 1600 0.1 2000 ~ 2400 2800 -4,-, 5200 5600 I V 4000 4400 4800 5200 5600 0.00 KOP 5.00 6.00 9.00 DLS: 5.00 deg per 100 ft 12.00 15.00 1B.O0 21.00 24.00 27.00 30.00 35.00 59.00 45.00 51.00 57.00 End of Build Tangent Angle 61.52 Deg. East (feet) -> 0 800 1600 2400 5200 4000 4800 I I I I I I · I I I I I I I I Top of Bel.~ 4000 5200 A I 2400 Z 0 1600 ~-~ 800 ~'~ Sterlrng 52 TGT - DLS: 2.00 deg per 100 ft 60.00 56.00 52.00 48.00 44.00 40.00 36.00 Top of Belugo I I I I I I I I I I ! I I I I I I I I I I II I I I I I I I I I 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 VerticalSection'(feet)-> Azimuth 52.20 with reference 0.00 N, 0.00 E from CLU-6 MARATHON Oil Company Pad #1 CLU-6 CLU-6 Cannery Loop Unit Cook Inl et, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : CLU-6 Ver #4 Our ref : prop3879 License: Date printed : 25-Feb-2000 Date created : 8-Feb-2000 Last revised : 18-Feb-2000 Field is centred on n60 31 54.076,w151 15 37.735 Structure is centred on n60 31 54.076,w151 15 37.735 Slot location is n60 31 55.189,w151 15 47.028 Slot Grid coordinates are N 2388558.088, E 272516.172 Slot local coordinates are 113.00 N 465.00 W Projection type:'alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECE VE ) MARATHON Oil Company Pad #1,CLU-6 Cannery Loop Unit,Cook Inlet, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 1 Your ref : CLU-6 Ver~4 Last revised : 18-Feb-2000 Dogleg Vert Deg/lOOft Sect 0,00 0.00 0,00 0,00 0,00 N 0,00 E 0,00 0,00 100,00 0,00 52,20 100.00 0,00 N 0,00 E 0,00 0.00 200,00 0,00 52,20 200,00 0,00 N 0,00 E 0,00 0,00 300,00 0,00 52,20 300,00 0,00 N 0,00 E 0,00 0,00 400,00 0,00 52,20 400,00 0,00 N 0,00 E 0,00 0,00 500,00 0,00 52.20 500,00 0,00 N 0,00 E 0,00 0,00 550,00 0.00 52,20 550,00 0,00 N 0,00 E 0,00 0,00 650,00 3,00 52,20 649,95 1,60 N 2,07 E 3,00 2,62 750.00 6,00 52.20 749.63 6.41 N 8,27 E 3.00 10.46 850,00 9,00 52,20 848.77 14,41 N 18,58 E 3,00 23,51 950,00 12,00 52,20 947,08 25,58 N 32,98 E 3,00 41,74 1050,00 15,00 52,20 1044.31 39.89 N 51,42 E 3,00 65,08 1150,00 18.00 52,20 1140,18 57.29 N 73.86 E 3,00 93.48 1250,00 21,00 52,20 1234,43 77,75 N 100,23 E 3,00 126,85 1350,00 24,00 52,20 1326,81 101.20 N 130.47 E 3,00 165,12 1450.00 27.00 52.20 1417.06 127.58 N 164.48 E 3.00 208.16 1550.00 30.00 52.20 1504.93 156.83 N 202.18 E 3.00 255.87 1650.00 33.00 52.20 1590.18 188.85 N 243.46 E 3.00 308.12 1750.00 36.00 52.20 1672.59 223.56 N 288.21 E 3.00 364..75 1850.00 39.00 52.20 1751.91 260.87 N 336.30 E 3.00 425.62 1950,00 42,00 52.20 1827.95 300.67 N 387.62 E 3,00 490.56 2050,00 45,00 52,20 1900,47 342,85 N 442,00 E 3,00 559,38 2150,00 48,00 52,20 1969,30 387,31 N 499.31 E 3.00 631,91 2250.00 51,00 52,20 2034,24 433,91 N 559,39 E 3.00 707,95. 2350,00 54,00 52,20 2095,11 482,53 N 622,07 E 3,00 787,27 2450,00 57,00 52,20 2151,74 533,03 N 687,18 E 3,00 '869,68 2550,00 60,00 52.20 2203,99 585,29 N 754.54 E 3,00 954.93 2600,81 61,52 52,20 2228,80 612,46 N 789,57 E 3,00 999,26 3000,00 61,52 52,20 2419,13 827,53 N 1066,83 E 0,00 1350,16 3500,00 61,52 52,20 2657,52 1096,91 N 1414,11 E 0,00 1789,67 4000,00 61,52 52,20 2895,92 1366,29 N 1761,39 E 0,00 2229,18 4500,00 61,52. 52,20 3134,31 1635,67 N 2108,67 E 0,00 2668,69 5000,00 61,52 52.20 3372,70 1905,05 N 2455,95 E 0.00 3108,20 5500,00 61.52 52.20 3611,10 2174,43 N 2803.23 E 0.00 3547,71 6000.00 61.52 52.20 3849.49 2443.81 N 3150.51 E 0.00 3987.22 6500.00 61.52 52.20 4087.88 2713.19 N 3497.79 E 0.00 4426.73 6971.10 61.52 52.20 4312.50 2967.00 N 3825.00 E 0.00 4840.84 7047.32 60.00 52.20 4349.72 3007.76 N 3877.55 E 2.00 4907.34 7147.32 58.00 52.20 4401.23 3060.29 N 3945.27 E 2.00 4993.05 7247.32 56.00 52.20 4455.69 3111.69 N 4011.54 E 2.00 5076.92 7347.32 54.00 52.20 4513.04 3161.90 N 4076.26 E 2.00 5158.83 7447.32 52.00 52.20 4573.22 3210.84 N 4139.36 E 2.00 5238.69 7547.32 50.00 52.20 4636.15 3258.47 N 4200.76 E 2.00 5316.40 7647.32 48.00 52.20 4701.75 3304.73 N 4260.39 E 2.00 ' 5391.86 7747.32 46.00 52.20 4769.95 3349.55 N 4318.18 E 2.00 5465.00 7847,32 44,00 52,20 4840,65 3392,89 N 4374.05 E 2,00 5535,70 7947,32 42.00 52.20 4913,79 3434,69 N 4427,93 E 2.00 5603,90 8047,32 40,00 52,20 4989,25 3474,90 N 4479,77 E 2,00 5669,50 8147,32 38,00 52,20 5066,96 3513,47 N 4529,49 E 2,00 5732,43 8247,32 36,00 52.20 5146,82 3550,35 N 4577,04 E 2.00 5792,61 Sterling B2 TGT - 2-8-00 All data is in feet unless otherwise stated. Coordinates from CLU-6 and TVD from Estimated RKB (42.50 Ft above mean sea level). Bottom hole distance is 5879.02 on azimuth 52.20 degrees from wellhead. Total Dogleg for wellpath is 90.10 degrees. Vertical section is from wellhead on azimuth 52.20 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ,i, MARATHON Oil Company Pad#1,CLU-6 Cannery Loop Unit,Cook Inlet, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page Your ref : CLU-6 Ver Last revised : 18-Feb-2000 Dogleg Vert Deg/lOOft Sect 8342.81 34.09 52.20 5225.00 3583.96 N 4620.37 E 2.00 5847.44Top of Beluga 8347.32 34.00 52.20 5228.73 3585.50 N 4622.36 E 2.00 584g.g6 8400.00 32.95 52.20 5272.68 3603.31 N 4645.32 E 2.00 5879.02 All data is in feet unless otherwise stated. Coordinates from CLU-6 and TVD from Estimated RKB (42.50 Ft above mean sea level). Bottom hole distance is 587g.02 on azimuth 52.20 degrees from wellhead. Total Dogleg for wellpath is 90.10 degrees. Vertical section is from wellhead on azimuth 52.20 degrees. Calculation uses the minimum curvature method. Presented byBaker Hughes INTEQ MARATHON Oil Company Pad #1.CLU-6 Cannery Loop Unit.Cook Inlet, Alaska PROPOSAL LISTING Page 3' Your ref : CLU-6 Ver~4 Last revised : 18-Feb-2000 Comments i n wel 1 path MD TVD Rectangul ar Coords. Comment '~]~"~]~ .... ~]~'~ .... ~]~'~"~ii~'~'~'~'~ ...................................... 8342.81 5225.00 3583.g6 N 4620.37 E Top of Beluga Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised Sterling B2 TGT - 2- 276397.137,2391451.164,0.0000 4312.50 2967.00N 3825.00E 8-Feb-2000 MARATHON Oil Company Pad #1 CLU-6 CLU-6 Cannery Loop Unit Cook Inlet, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : CLU-6 Ver~4 Our ref : prop3879 License : Date printed : 25-Feb-2000 Date created: 8-Feb-2000 Last revised : 18-Feb-2000 Field is centred on n60 31 54.076,w151 15 37.735 Structure is centred on n60 31 54.076,w151 15 37.735 Slot location is n60 31 55.189,w151 15 47.028 Slot Grid coordinates are N 2388558.088, E 272516.172 Slot local coordinates are 113.00 N 465.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Presented by Baker Hughes INTEQ MARATHON Oil Company Pad #1,CLU- 6 Cannery Loop Unit,Cook Inlet. Alaska PROPOSAL LISTING Page 2 Your ref : CLU-6 Ver~4 Last revised : 18-Feb-2000 Measured Inclin Azimuth True Vert R E C TAN G U LAR Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 8342.81 34.09 52.20 5225.00 3696.96N 4155.37E 2.00 5847.44 8347.32 34.00 52.20 5228.73 3698.50N 4157.36E 2.00 5849.96 8400.00 32.95 52.20 5272.68 3716.31N 4180.32E ' 2.00 5879.02 277204.14 2392052.75 277206.17 2392054.26 277229.46 2392071.62 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from SE Corner of Sec. 7, TSN, RllW, SM and TVD from Estimated RKB (42.50 Ft above mean sea level). Bottom hole distance is 5879.02 on azimuth 52.20 degrees from wellhead. Total Dogleg for wellpath is 90.10 degrees. Vertical section is from wellhead on azimuth 52.20 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ MARATHON Oil Company Pad #1, CLU- 6 Cannery Loop Unit,Cook Inlet, Alaska PROPOSAL LISTING Page 3 Your ref : CLU-6 Ver#4 Last revised : 18-Feb-200D Comments i n wel 1 path MD TVD Rectangul ar Coords. Comment 8342.81 5225.00 3696.g6N 4155.37E Top of Beluga Targets associated with this wellpath Target name Geographic Locati on T.V.D. Rectangul ar Coordi nates Revised '~;:;;.ii,¥,i~'~¥':'~:'~;i~;~i,i~i;i~,i;,~;,~,~,~",i~i~;~ ...... ~i~;~,~ ..... ~,~;~"',i:~;,;:~,~,~ ....... Created by Suthedond For: P. Berga~ Da~ plo~ted: 25-Feb-2000 / PI~ R~emn~e |{ ~LU-E Vet ~ m Coon:l)nahm nm in ~ mf~nmc~ CLU-S. I /~ 2400 I 1600 e' -.I.-- 0 Z 1200 MARATHON Oil Company Structure: Pad #1 Well: CLU-6 field : Cannery Loop Unit Location : Cook Inlet, Alask( East (feet) -> 1 00 0 1 O0 200 500 ,I.00 500 600 700 I I I I I I I I I I I I I I I I I m soo 2ooo/" %. ~0~' r soo 19oo,/ "a ye o," .,~ m 400 1850./' z ;3',~ / _/- ~, I- ,too 1800./' ~0,,~ v ~ /' ~ ~0~ m A 17002 ,,.,., ~'n,"' .,/v',,~,'ao,.,"o F A i 3o0 16oo ~,' 500 ~- 15ooI ~/~.o-°o :,~ x~_ '"o_ ~ z ,' ,,os/. '%~o;,' ./,,....o / -,° · +.. 200 1500] /,t ~',, '- .~- ~e_ ~ I- 200 ~o0/ ~," ,,%. %.,--0 r ~"= ,00 .~.o/' ..~,,,, ~ %.,-"o L ,oo ,,,-" z ]- 100 ' 100 East (feet) -> ................... 0 ~00 2oo 300 4o0 5oo s00 7o0 East (feet) 4O0 0 4.00 800 1200 1600 2000 24O0 2800 3200 3600 4000 ~4O0 4800 5200 4000 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 4000 3600 5600 ~,~ reOo ~' 28O0 00.//* 2800 / 2.4.o0 ,,,o 2OO0 2OO0 1600 1200 800 800 4-00 4-O0 0 0 4.00 , , u u ~ ~ ~ ~ ~ ~ ~ , ~ ~ ~ u ~ ~ ~ ~ ~ ~ ~ , ~ m ~ 4.00 400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 East (feet) -> Cr~ot.d by Suthedond For: P. l]ergaI Dote plotted: 25-Feb-20~ I P~t ~Fe~Ge ;I C~-5 ~r ~ I I ~ I MARATHON Oil Company Structure: Pad #1 Well: CLU-6 Field : Cannery Loop Unit Location : Cook Inlet, Alaska TRUE NORTH 350 0 10 340 20 33O 30 520 40 310 50 500 60 7O 280 80 270 9O 260 1 O0 250 110 240 120 230 130 220 140 210 150 190 180 170 160 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well HARATHON Oil Company Pad #1 CLU-6 CLU-6 Cannery Loop Unit Cook Inlet, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT by Baker Hughes INTEQ Your ref: CLU-6 Ver~/4 Our ref: prop3879 License: Date printed: 25-Feb-2000 Date created : 8-Feb-2000 Last revised : 18-Feb-2000 Field is centred on n60 31 54.076,w151 15 37.735 Structure is centred on n60 31 54.076,w151 15 37.735 Slot location is n60 31 55.189,w151 15 47.028 Slot Grid coordinates are N 2388558.088, E 272516.172 Slot local coordinates are 113.00 N 465.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 200 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath GMS <O-16500'>,,CLU-4,Pad # 3 / 4 GMS <0-11125'>,,CLU-3,Pad # 3 / 4 GMS <O-10731'>,,CLU-2,Pad#2 GMS <O-12010'>,,CLU-1,Pad#1 Dipmeter <8600-11420'>,,CLU.5,Pad #I Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 6-May-1995 4373.7 8400.0 8400.0 6-May-1995 5071.3 8400.0 8400.0 5-May-lgg5 1700g.5 8400.0 8400.0 5-May-1995 85.7 1275.D 1275.0 19-Mar-lg97 gs.g 2580.5 2580.5 M.D. 0.0 25.0 50.0 75.0 100.0 125.0 150.0 175.0 200.0 225.0 250.0 275.0 300.0 325.0 350.0 375. 400. 425. 450. 475. 500.0 525.0 550.0 561.1 572.2 575.0 583.3 594.4 600.0 605.6 616.7 625.0 627.8 638.9 650.0 661.1 672.2 675.0 683.3 694.4 700.0 705.6 716.7 725.0 727.8 738.9 750.0 761.1 772.2 775.0 783.3 MARATHON Oil Company CLEARANCE LISTING Page 1 Pad #1,CLU-6 Your ref : CLU-6 Ver #4 Cannery Loop Unit,Cook Inlet, Alaska Last revised : 18-Feb-2000 Reference wel 1 path Object wel 1 path : GMS <0-12010'>,,CLU- 1, Pad #1 Horiz Min'm TCyl T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 O.ON O.OE 1.5 0.0 82.4N 77.3E 43.2 113.0 113.0 25.0 O.ON O.OE 26.5 25.0 82.4N 77.3E 43.2 113.0 113.0 50.0 O.ON O.OE 51.5 50.0 82.4N 77.3E 43.2 113.0 113.0 75.0 O.ON O.OE 76.5 75.0 82.4N 77.3E 43.2 113.0 113.0 100.0 O.ON O.OE 101.5 100.0 82.4N 77.3E 43.2 113.0 113.0 125.0 O.ON D.OE 126.5 125.0 82.4N 77.3E 43.2 113.0 113.0 150.0 O.ON O.OE 151.5 150.0 82.4N 77.3E 43.2 113.0 113.0 175.0 O.ON O.OE 176.5 175,0 82.4N 77.3E 43.2 113.0 113.0 200.0 O.ON O.OE 201.5 200.0 82.4N 77.3E 43.2 113.0 113.0 225.0 O.ON O.OE 226.5 225.0 82.4N 77.3E 43.2 113.0 113.0 250.0 O.ON O.OE 251.5 250.0 82.4N 77.3E 43.2 113.0 113.0 275.0 O.ON O.OE 276.5 275.0 82.4N 77.3E 43.2 113.0 113.0 300.0 O.ON O.OE 301.5 300.0 82.4N 77.3E 43.2 113.0 113.0 325.0 O.ON O.OE 326.5 325.0 82.4N 77.3E 43.2 113.0 113.0 350.0 O.ON O.OE 351.5 350.0 82.4N 77.3E 43.2 113.0 113.0 375.0 O.ON O.OE 376.5 375.0' 82.4N 77.3E 43.2 113.0 113.0 400.0 O.ON O.OE 401.5 400.0 82.4N 77.3E 43.2 113.0 113.0 425.0 O.ON O.OE 426.5 425.0 82.4N 77.3E 43.2 113.0 113.0 450.0 D.ON O.OE 451.5 450.0 82.4N 77.3E 43.2 113.0 113.0 475.0 O.ON O.OE 476.5 475.0 82.4N 77.3E 43.2 113.0 113.0 500.0 O.ON O.OE 501.7 500.2 82.4N 77.3E 43.2 113.0 113.0' 525.0 O.ON O.OE 526.7 525.2 82.4N 77.3E 43.2 112.9' 112.9' 550.0 O.ON O.OE 552.1 550,6 82.3N 77.3E 43,2 112.9' 112.9' 561.1 O.ON O.OE 563.2 561.7 82.2N 77.3E 43.2 112.8' 112.8' 572.2 0.1N 0.1E 574,3 572.8 82,2N 77,2E 43.2 112.7' 112,7' 575.0 0.1N 0.1E 577.1 575.6 82.2N 77.2E 43.2 112.6' 112.6' 583.3 0.2N 0.2E 585.4 583.9 82.1N 77.2E 43.2 112.4' 112.5' 594.4 0.3N 0.4E 596.5 595.0 82.0N 77.2E 43.2 112.1' 112.2' 600.0 0.4N O.5E 601.8 600.3 82.0N 77.2E 43.2 112.0' 112.0' 605.5 0.5N 0.6E 607.4 605.9 81.9N 77.2E 43.2 111.8' 111.8' 616.7 O.TN 0.gE 618.5 617.0 81.9N 77.2E 43.2 111.4' 111.5' 625.0 O.9N 1,2E 626,8 625,3 81,9N 77,2E 43.2 111.1' 111.2' 627.8 1.ON 1.3E 629.6 628,1 81.9N 77,2E 43.2 111,0' 111.1' 638.9 1.3N 1.6E 639.8 638.3 81.9N 77.2E 43,2 110,5' 110.6' 650.0 1.6N 2.1E 650.9 649.4 81.9N 77.2E 43.1 110.0' 110.1' 661.0 2.ON 2.6E 662.0 660.5 82.0N 77.2E 43.0 109.5' 109.6' 672.1 2.4N 3.1E 672,2 670.7 82,1N 77.2E 42.9 108,9' 109.1' 674.9 2.5N 3.2E 675.0 673.5 82.2N 77.2E 42.9 108.8' 108.9' 683.2 2.9N 3.7E 683.3 681.8 82,3N 77.2E 42.8 108.3' 108.5' 694.3 3.3N 4.3E 694.4 692.9 82.5N 77.3E 42.7 107.7' 107.9' 699.8 3.6N 4.7E 698.6 697.1 82.6N 77.3E 42.6 107.3' 107.5' 705.4 3.9N 5.0E 704,2 702,7 82,7N 77.3E 42.5 107.0' 107,2' 716.5 4.5N 5,7E 715.3 713.8 83.0N 77.3E 42.3 106.3' 106.5' 724.8 4.gN 6,3E 723.6 722.1 83,3N 77.4E 42.2 105.8' 106.0' 727.5 5.1N 6.5E 726.4 724.8 83.4N 77.4E 42.2 105.6' 105.8' 738.6 5.7N 7.4E 735.8 734.2 83.7N 77.5E 42.0 104.9' 105.2' 749.6 6.4N 8.3E 746.9 745,3 84.1N 77.6E 41.7 104.2' 104.5' 760.7 7.1N 9.2E 757.9 756.4 84,6N 77.8E 41.5 103.5' 103.8' 771,7 7,9N 10.2E 767,4 765.8 85.1N 77.9E 41.3 102.8' 103.1' 774.5 8.1N 10.5E 770,1 768.6 85.2N 78.0E 41.2 102,7' 102.9' 782.8 8.7N 11.2E 778.4 776.9 85.7N 78.1E 41.0 102.1' 102.3' All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from CLU-6 and TVD from Estimated RKB (42.50 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 52.20 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ M,D, 794.4 800.0 805.6 816.7 825.0 827.8 838.9 850.0 861.1 872.2 875.0 883.3 894.4 900.0 905.6 916.7 925.0 927.8 938.9 950.0 961.1 972.2 975.0 983.3 994.4 1000.0 1005.6 1016.7 1025.0 1027.8 1038.9 1050.0 1061.1 1072.2 1075.0 1083.3 1094.4 1100.0 1105.6 1116.7 1125.0 1127.8 1138.9 1150.0 1161.1 1172.2 1175.0 1183.3 1194.4 1200.0 1205.6 ... MARATHON Oil Company CLEARANCE LISTING Page 2 Pad #1,CLU-6 Your ref :'CLU-6 Vert~4 Cannery Loop Unit,Cook Inlet, Alaska Last revised : 18-Feb-2000 Reference wellpath Object wellpath : GMS <O-12010'>,,CLU-1,Pad#1 Horiz Min'm TCyl T.V.D. Rect Coordinates M.D.T.V.D. Rect Coordinates Bearing Dist Dist 793.8 9.6N 12.3E 789.5 787.9 86.3N 78.4E 40.7 101.4' 799.3 lO.ON 12.9E 795.1 793.5 86.7N 78.5E 40.6 101.0' 804.8 10.5N 13.5E 798.8 797.2 86.9N 78.6E 40.4 100.7' 815.8 11.4N 14.7E 809.8 808.2 87.7N 78.9E 40.1 100.0' 824.1 12.1N 15.6E 818.1 816.5 88.3N 79.1E 39.8 99.5* 101.6' 101.3' 100.9' 100.2' 99.7* 826.8 12.4N 15.9E 820.9 819.2 88.5N 79.2E 39.7 99.3* 837.8 13.4N 17.2E 830.0 828.2 89.3N 79.5E 39.3 98.7* 848.8 14.4N 18.6E 841.0 839.3 90.3N 79.9E 38.9 98.0* 859.7 15.5N 20.OE 850.1 848.3 91.3N 80.2E 38.5 97.5* 870.7 16.6N 21.4E 861.2 859.3 92.5N 80.7E 38.0 96.9* 99.5* 98,8* 98,2* 97,6* 97.1' 873.4 16.9N 21.8E 863.9 862.0 92.8N 80.8E 37.8 96.8* 881.6 17.8N 22.9E 872.2 870.2 93.8N 81.1E 37.4 96.4* 892.6 19.0N 24.5E 881.3 879.2 95.0N 81.6E 36.9 96.0* 898.0 19.6N 25.3E 886.8 884.'7 95.7N 81.8E 36.6 95.8* 903.5 20.2N 26.1E 892.4 890.2 96.5N 82.1E 36.3 95.6* 96.9* 96,5* 96.1' 95.8* 95,6* 914.4 21.5N 27.7E 901.7 899.4 97.9N 82.6E 35.7 95.2* 922.6 22.5N 29.0E 910.0 907.6 99.1N 83.0E 35.2 94.9* 925.3 22.8N 29.4E 912.7 910.3 99.5N 83.2E 35.0 94.8* 936.2 24.2N 31.2E 923.8 921.2 101.2N 83.8E 34.3 94.5* 947.1 25.6N 33.0E 933.4 930.7 102.7N 84.4E 33.7 94.2* 95.3* 95.0* 94.9* 94.5* 94.2* 957,9 27,0N 34,8E 944.5 941,5 104.5N 85.1E 33,0 93,8* 968,8 28,5N 36,7E 955,5 952,4 106,3N 85,9E 32.3 93.5* 971,5 28,9N 37,2E 958,3 955,1 106,8N 86,1E 32,1 93,4* 979,6 30,ON 38,7E 965,1 961,9 107,9N 86,5E 31,6 93,2* 990,4 31,6N 40,7E 976,2 972,7 109,8N 87,4E 30,8 92,8* 995,8 32,3N 41,7E. 981,7 978,1 110,8N 87,8E 30,4 92,7* 1001,2 33,1N 42,7E 987,2 983,6 111,8N 88,2E 30,1 92,5* 1012,0 34,8N 44,8E 998,2 994.4 113,7N 89,1E 29,3 92,2* 1020,1 36,0N 46,4E 1005,5 1001,5 115,0N 89,7E 28,7 92,0* 1022,8 36,4N 47,0E 1008,2 1004,2 115,5N 89,9E 28,5 91,9' 1033,6 38,1N 49,2E 1019,3 1015.0 117,6N 90.9E 27.7 91,6' 1044,3 39,9N 51,4E 1030,3 1025,8 119,6N 91,8E 26,8 91,3' 1055,0 41,7N 53,7E 1040,6 1035,9 121,6N 92,7E 26,0 91,0' 1065.7 43.5N 56.1E 1051,6 1046,6 123,7N 93,6E 25,1 90,6* 1068,4 43,9N 56,7E 1054,4 1049,3 124,3N 93,8E 24.8 90,5* 93.9* 93.5* 93.4* 93.2* 92.9* 92.7* 92.6* 92.3* 92.0* 92.0* 91.7' 91.3' 91.0' 90.7* 90.6* 1076,4 45,3N 58,5E 1062,6 1057,4 125,9N 94,5E 24,1 90,3* 90,3* 1087,1 47,2N 60,9E 1072,9 1067,5 127,9N 95,4E 23,1 89,9* 89,9* 1092.4 48,2N 62,1E 1078,4 1072,8 129,0N 95.8E 22.6 89,7* 89,8* 1097,8 49,2N 63,4E 1083,9 1078,2 130,1N 96,3E 22,1 89,5* 89,6* 1108.4 51.1N 65.9E 1094.9 1088.9 132.3N 97.2E 21.1 89.2* 89.2* 1116,4 52,7N 67,9E 1102,5 1096,3 133,9N 97.9E 20,3 88.9* 88,9* 1119,0 53,2N 68,5E 1105,2 1098,9 134,5N 98,1E 20,0 88,8* 88,9* 1129,6 55,2N 71,2E 1116,2 1109,6 136,7N 99,0E 18,8 88,4* 88,5* 1140,2 57,3N 73.9E 1127,1 1120,3 139,1N 99,9E 17,7 88,1' 88,1' 1150,7 59,4N 76,6E 1137,4 1130,3 141,3N 100.8E 16.5 87,8* 87,8* 1161,3 61,6N 79,4E 1148,3 1140,9 143,6N 101,7E 15,2 87,4* 87,5* 1163,9 62.1N 80,1E 1151.1 1143,6 144.2N 101.9E 14.9 87,4* 87,4* 1171.8 63,8N 82,2E 1159,3 1151,6 146,0N 102,6E 13,9 87,1' 87.2* 1182,3 66,0N 85,1E 1169,5 1161.5 148,3N 103.5E 12.6 86,8* 86,9* 1187,5 67,1N 86,6E 1175.0 1166,8 149,5N 103,9E 11,9 86,7* 86.7* 1192,8 68,3N 88,0E 1180,4 1172,1 150,7N 104,4E 11,2 86,6* 86,6* All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from CLU-6 and TVD from Estimated RKB (42.50 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 52,20 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ M.D. 1216.7 1225.0 1227.8 1238.9 1250.0 1261.1 1272.2 1275.0 1283.3 1294.4 1300.0 1305.6 1316.7 1325.0 1327.8 1338.9 1350.0 1361.1 1372.2 1375.0 1383.3 1394.4 1400.0 1405.6 1416.7 1425.0 1427.8 1438.9 1450.0 1461.1 1472.2 1475.0 1483.3 1494.4 1500.0 1505.6 1516.7 1525.0 1527.8 1538.9 1550.0 1561.1 1572.2 1575.0 1583.3 1594.4 1600.0 1605.6 1616.7 1625.0 1627.8 i, MARATHON Oil Company CLEARANCE LISTING Page 3 Pad#1,CLU-6 Your ref: CLU-6 Ver#4 Cannery Loop Unit,Cook Inlet, Alaska Last revised : 18-Feb-2000 Reference wellpath Object wellpath : GMS <O-12010'>..CLU-1,Pad#1 Horiz Min'm TCyl T.V.D. Rect Coordinates M.D.T.V.D. Rect Coordinates Bearing Dist Dist 1203.2 70.6N 91.0E 1191.3 1182.7 153.2N 105.3E 9.8 86.3* 86.4* 1211.0 72.4N 93.3E 1198.8 1189.9 154.9N 105.9E 8.7 86.2* 86.2* 1213.6 72.9N g4,0E 1201.5 1192.6 155.6N 106,1E 8,3 86.1' 86.1' 1224.0 75.3N 97.1E 1212.4 1203.1 158.1N 107.0E 6,8 86.0* 86.0* 1234.4 77.7N 100,2E 1223.3 1213.7 160.7N 107.9E 5.3 85.8* 85.8* 1244.8 80.2N 103,4E 1233.4 1223.5 163.1N 108,8E 3.7 85.7* 85.7* 1255.1 82.7N 106.6E 1244.3 1234.0 165.7N 109.7E 2,1 85.7* 85.7* 1257.7 83.3N 107.4E 1247.0 1236.6 166.3N 109,9E 1.7 85.7* 85.7* 1265.4 85.2N 109.9E 1255.2 1244.5 168.3N 110.5E 0,5 85.7 85.7 1275.7 87.8N 113.2E 1265.3 1254.2 170.8N 111.4E 358.7 85.8 85.8 1280.9 89.1N 114.9E 1270.7 1259.4 172.2N 111.8E 357.9 85.8 85.8 1286.0 90.4N 116.6E 1276.1 1264.7 173.5N 112.2E 357.0 85.9 85.9 1296.2 93.1N 120.0E 1286.9 1275.1 176.2N 113.1E 355.3 86.1 86.1 1303.g gS.1N 122.6E 1295.0 1282.9 178.3N 113.8E 354.0 86.3 86.3 1306.5 95.7N 123,4E 1297.7 1285.5 179.0N 114.0E 353.5 86.3 86.4 1316.6 98.4N 126.gE 1307.7 1295.2 181.5N 114.8E 351.7 86.7 86.7 1326.8 101.2N 130.5E 1318.5 1305.5 184.3N 115.6E 349.9 87.1 87.2 1336.9 104.0N 134.1E 1329.3 1315.9 187.2N 116.5E 348.0 87.6 87.7 1347.1 106.8N 137.7E 1339.2 1325.4 189.8N 117.2E 346.1 88.2 88.3 1349.6 107.5N 138.6E 1341.9 1328.0 190.5N 117.4E 345.7 88.3 88.5 1357.1 . 109.7N 141.4E 1349.9 1335.7 192.7N 118.0E 344.3 88.8 89.0 1367.2 112.6N 145.1E 1360.6 1346.0 I95.6N 118.8E 342.4 89.6 89.8 1372.2 114.0N 147.0E 1365.2 1350.4 196.8N 119.2E 341.4 go.o 90.3 1377.2 115.5N 148.9E 1370.5 1355.5 198.2N 119.6E 340.5 90.4 90.8 1387.2 118.5N 152.7E 1381.2 1365.7 201.2N 120.4E 338.6 91.4 91.8 1394.7 120.7N 155.6E 1389.2 1373.4 203.4N 121.0E 337.3 92.2 92.6 1397.2 121.5N 156.6E 1391.9 1376.0 204.2N 121.1E 336.8 92.4 92.9 1407.1 124.5N 160.5E 1401.7 1385.4 206.9N 121.9E 334.9 93.6 94.2 1417.1 127.6N ' 164.5E 1412.3 1395.5 209.9N 122.6E 333.1 94.9 95.6 1426.9 130.7N 168.5E 1423.0 1405.7 213.0N 123.4E 331.3 96.2 97.1 1436.8 133.8N 172.5E 1432.8 1415.1 215.8N 124.1E 329.4 97.7 98.7 1439.3 134.6N 173.6E 1435.4 1417.6 216.6N 124.3E 329.0 98.1 99.1 1446.6 137.0N 176.6E 1443.4 1425.2 218.9N 124.8E 327.7 99.2 100.4 1456.4 140.2N 180.8E 1453.9 1435.3 222.0N 125.5E 326.0 100.9 102.3 1461.3 141.9N 182.9E 1459.2 1440.3 223.5N 125.9E 325.1 101.8 103.3 1466.2 143.5N 185.0E 1464.5 1445.3 225.1N 126.3E 324.3 102.7 104.3 1475.9 146.8N 189.2E 1474.2 1454.6 228,0N 126.9E 322.5 104.6 106.4 1483.2 149.3N 192.4E 1482.1 1462.1 230.4N 127,5E 321.3 106.0 108.0 1485.6 150.1N 193.5E 1484.8 1464.6 231.2N 127.7E 320.9 106.6 108.6 1495.3 153.4N 197.8E 1495.3 1474.6 234.4N 128.4E 319,4 108.6 110.9 1504.9 156.8N 202.2E 1504.7 1483.6 237.3N 12g. OE 317.7 110.8 113.4 1514.5 160.2N 206.6E 1515.2 1493.5 240,5N 129.7E 316.2 113.1 116.1 1524.1 163.7N 211.0E 1525.6 1503.4 243.8N 130.4E 314.8 115,5 118.8 1526.5 164.6N 212.2E 1528.2 1505.9 244.6N 130.6E 314.4 116,1 119,5 1533.7 167.2N 215.5E 1534.8 1512.1 246,7N 131,0E 313.2 118,0 121.7 1543.2 170.7N 220.1E 1545.3 1521.9 250.1N 131.7E 311.9 120.7 124.7 1547.9 172.5N 222.4E 1550.5 1526.8 251.7N 132.0E 311.3 122.0 126.3 1552.6 174.3N 224.7E 1555.6 1531.7 253.4N 132.4E 310.6 123.4 127.9 1562.1 177.9N 229.3E 1566.0 1541.5 256.9N 133.0E 309.4 126.2 131.1 1569.1 180.6N 232.8E 1572.6 1547.6 259.0N 133.5E 308.3 128.4 133.6 1571.5 181.5N 234.0E 1575.1 1550.1 259.9N 133.6E 308.0 129.1 134.4 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from CLU-6 and TVD from Estimated RKB (42.50 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 52.20 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad ~I,CLU-6 Cannery Loop Unit,Cook Inlet, Alaska Reference wellpath Object wellpath : GMS <O-12010'>,,CLU-1.Pad #1 CLEARANCE LISTING Page 4 Your ref : CLU-6 Ver ~4 Last revised : 18-Feb-2000 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 1638.9 1580.8 185.2N 238.7E 1585.5 1559.8 263.4N 134.3E 306.8 132.1 137.7 1650.0 1590.2 188.8N 243.5E 1595.8 1569.5 266.9N 134.9E 305.7 135.3 140.9 1661.1 1599.5 192.6N 248.3E 1606.7 1579.7 270.7N 135.7E 304.7 138.4 144.0 1672.2 1608.8 196.3N 253.1E 1619.6 1591.8 275.1N 136,7E 304.1 141.6 147.0 1675.0 1611.1 197.3N 254.3E 1622.2 1594,2 276.0N 136.9E 303.8 142.4 147.7 1683.3 1618.0 200.1N 258.0E 1630.0 1601.5 278.7N 137.6E 303.1 144.7 150.0 1694.4 1627.2 203.9N 262.9E 1643.2 1613,8 283,2N 139.0E 302.6 147.7 152.8 1700.0 1631.8 205.9N 265.4E 1648.4 1618.6 284.9N 139.5E 302.1 149.2 154.3 1705.6 1636.3 207.8N 267.9E 1653.6 1623.5 286.7N 140.2E 301.7 150,7 155.7 1716.7 1645.5 211.7N 272.9E 1667,0 1635.9 291.3N 141.9E 301.3 153.6 158.4 1725.0 1652.3 214.6N 276.7E 1674.8 1643.3 293.9N 143.0E 300.7 155.7 160.5 1727.8 1654.5 215.6N 278.0E 1680.4 1648.5 295.9N 143.8E 300.9 156.4 161.1 1738,9 1663.6 219.6N 283.1E 1691.0 1658.3 299.4N 145.4E 300,1 159,2 163.9 1750.0 1672.6 223.6N 288.2E 1703.6 1670.0 303.7N 147.6E 299.7 161,9 166.6 1761.1 1681.6 227.6N 293.4E 1714.2 1679.7 307.3N 149.5E 299.0 164.6 169.4 1772.2 1690.5 231.6N 298.6E 1726.0 1690.5 311.5N 151.7E 298.5 167.2 172.1 1775.0 1692.7 232.6N 299.9E 1728.7 1693.0 312.4N 152.2E 298.4 167.9 172,8 1783.3 1699.4 235,7N 303.9E 1736.6 1700.2 315.2N 153.7E 297.9 169.9 174.9 1794.4 1708.2 239.8N 309.2E 1748.5 1711.1 319.6N 156.1E 297.5 172,6 177.6 1800.0 1712.6 241.9N 311.8E 1753,8 1715,9 321.5N 157.2E 297.3 173.9 178.9 1805.6 1717.1 244.0N 314.5E 1760.5 1721.9 324.0N 158.7E 297.2 175.3 180.3 1816.7 1725.8 248.1N 319.9E 1771.2 1731.5 328.0N 161.0E 296.7 177,9 182.9 1825,0 1732.4 251.3N 324.0E 1780.7 1740.0 331.7N 163,2E 296.6 179.9 184.9 1827.8 1734.6 252,4N 325.3E 1783.4 1742,4 332.7N 163.8E 296.4 180.6 185.5 1838.9 1743.3 256,6N 330.8E 1794.0 1751.9 336.9N 166.3E 296.0 183.2 188.0 1850.0 1751,9 260.9N 336.3E 1806.7 1763.2 341.9N 169.4E 295.9 185.8 190.5 1861.1 1760.5 265.2N 341,8E 1820,0 1774.8 347.2N 172,8E 295.9 188.4 192.9 1872,2 1769.1 269.5N 347.4E 1830,7 17B4.2 351.6N 175.7E 295.5 190.9 195.3 1875.0 1771,2 270.6N 348.8E 1833.4 1786.5 352.6N 176.4E 295,5 191.5 195.9 1883.3 1777.6 273.9N 353.1E 1844.1 1795,8 357.0N 179.4E 295.6 193,4 197.6 1894.4 1786.1 278.3N 358.7E 1854.9 1805.1 361.5N 182.5E 295.3 195.8 199.8 1900.0 1790.4 280.5N 361.6E 1863.0 1812.1 364.9N 184.9E 295,5 197.0 200.9 1905.6 1794.6 282.7N 364.4E 1868.4 1816.7 367.1N 186.6E 295.4 198.1 202,0 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from CLU-6 and TVD from Estimated RKB (42.50 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 52.20 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company CLEARANCE LISTING Page 5 Pad #1,CLU-6 Your ref: CLU-6 Ver~4 Cannery Loop Unit,Cook Inlet, Alaska Last revised : 18-Feb-2000 Reference wellpath Object wellpath : Dipmeter <8600-11420'>..CLU-5.Pad#1 M,D, T.V.D, Rect Coordinates M,D, T,V,D, Horiz Min'm TCyl Rect Coordinates Bearing Dist Dist 1494.4 1456.4 140.2N 180.8E 1437.1 1383.9 185.3N 1500.0 1461.3 141.9N 182.9E 1442.6 1388.9 186.6N 1505.6 1466.2 143.5N 185.0E 1448.1 1394.0 187.9N 1516.7 1475.9 146.8N 189.2E 1456.4 1401.6 189.8N 1525.0 1483.2 149.3N 192.4E 1464.7 1409.3 191.7N 1527,8 1485,6 150,1N 193,5E 1467,5 1411,8 192.4N 1538.9 1495.3 153,4N 197,8E 1478.5 1421,9 195,0N 1550,0 1504,9 156,8N 202,2E 1487,3 1429,9 197,1N 1561,1 1514,5 160,2N 206,6E 1498,4 1440,0 199,8N 1572.2 1524,1 163,7N 211,0E 1509,4 1450,1 202.4N 1575.0 1526,5 164,6N 212,2E 1512,2 1452.6 203,1N 1583,3 1533,7 167,2N 215,5E 1520,5 1460.1 205,1N 1594,4 1543,2 170,7N 220,1E 1529,8 1468,6 207,4N 1600,0 1547.9 172,5N 222.4E 1535.3 1473.6 208,7N 1605,6 1552,6 174,3N 224,7E 1540,9 1478,6 210,1N 1616,7 1562,1 177,9N 229,3E 1551,9 1488.7 212.8N 1625,0 1569,1 180,6N 232,8E 1560,1 1496,1 214.9N 1627,8 1571,5 181,5N 234,0E 1562,9 1498.6 215,5N 1638,9 1580,8 185,2N 238,7E 1573.9 1508.6 218,3N 1650,0 1590,2 188,8N 243,5E 1582.8 1516,6 220,5N 1661,1 1599,5 192,6N 248,3E 1593,8 1526,6 223,3N 1672,2 1608,8 196,3N 253,1E 1604.8 1536,5 226.1N 1675,0 1611,1 197,3N 254,3E 1605,0 1536,7 226.2N 1683,3 1618,0 200,1N 258,0E 1613,3 1544,1 228,3N 1694,4 1627,2 203,9N 262,9E 1624,3 1553,9 231.2N 1700,0 1631.8 205,9N 265,4E 1629,8 1558,9 232.6N 1705,6 1636,3 207,8N 267,9E 1635,3 1563,8 234.1N 1716,7 1645,5 211,7N 272,9E 1643,8 1571,4 236,4N 1725.0 1652,3 214,6N 276,7E 1652,1 1578,7 238,6N 172.7,8 1654,5 215,6N 278,0E 1654,9 1581,1 239,3N 1738,9 1663,6 219,6N 283,1E 1665,9 1590,9 242,3N 1750,0 1672,6 223,6N 288,2E 1674,5 1598,5 244.7N 1761,1 1681,6 227,6N 293,4E 1685,5 1608,2 247,7N 1772,2 1690,5 231,6N 298,6E 1694,2 1615,8 250,2N 1775,0 1692,7 232,6N 299,9E 1696,9 1618,2 250~9N 361.0E 76.0 199,5 200,3 362,8E 76,0 199,0' 199.8' 364,5E 76,1 198.6' 199.3' 367,2E 76,4 197.6' 198.4' 369.9E 76.5 196,9' 197.7' 370.8E 76,6 196,7' 197,5' 374,4E 76,8 195,7' 196.5' 377.3E 77.1 194,7' 195,5' 381,0E 77,2 193,7' 194,6' 384,7E 77.4 192,7' 193,6' 385.6E 77.5 192.4' 193.3' 388.4E 77,6 191,6' 192,6' 391,5E 77,9 190,5' 191,5' 393.4E 78.0 190.0' 191,0' 395,3E 78,1 189,4' 190.5' 3gg,oE 78.4 188.2' 189,3' 401.9E 78,5 187.3' 188,5' 402,8E 78.6 187,0' 188,2' 406,6E 78,8 185,8' 187,0' 409,7E 79,2 184,5' 185,8' 413.5E 79.5 183.2' 184.6' 417.4E 79.7 182.0' 183.3' 417.5E 80.0 181.7' 183.0' 420.5E 80.2 180.7' 182.0' 424.5E 80.4 179.4' 180.7' 426.5E 80.6 178.8' 180.1' 428.5E 80.7 178.2' 179.5' 431.6E 81.2 176.9' 178.2' 434.7E 81.4 175.9' 177.2' 435.7E 81.5 175.6' 176.9' 439.9E 81.7 174.3' 175.6' 443.2E 82.2 173.0' 174.3' 447.4E 82.5 171.8' 173.0' 450.8E 83.1 170.5' 171.7' 451.9E 83.1 170.2' 171.4' 1783,3 1699,4 235,7N 303,9E 1705,2 1625,4 253,3N 1794,4 1708,2 239,8N 309,2E 1713,9 1633,0 255.8N 1800,0 1712,6 241,9N 311,8E 1719,4 1637,8 257,4N 1805,6 1717,1 244.0N 314,5E 1724.9 1642,6 258,9N 1816,7 1725,8 248,1N 319,9E 1733,7 1650,2 261,5N 1825,0 1732,4 251,3N 324,0E 1742.0 1657,3 263,9N 1827,8 1734,6 252,4N 325,3E 1744,7 1659,7 264,7N 1838,9 1743,3 256,6N 330,8E 1755,7 1669,1 268,0N 1850,0 1751,9 260,9N 336,3E 1764,8 1676,9 270,7N 1861,1 1760,5 265,2N 341,8E 1775,8 1686,3 274,0N 455.1E 83.4 169,3' 170.5' 458,6E 83,9 168,1' 169.2' 460,8E 84,1 167,4' 168,6' 463.1E 84.2 166,8' 167.9' 466,7E 84,8 165.6' 166.7' 470,1E 85,1 164,7' 165,8' 471,2E 85,1 164,4' 165,5' 475,8E 85,5 163,3' 164,3' 479,6E 86,1 162,1' 163,1' 484.3E 86,4 160,9' 161,9' 1872.2 1769,1 269,5N 347,4E 1786,8 1695,7 277,4N 1875,0 1771,2 270,6N 348.8E 1787,9 1696.6 277,7N 1883,3 1777,6 273,9N 353,1E 1796,1 1703,6 280,3N 1894,4 1786,1 278,3N 358.7E 1807,1 1712.9 283,7N 1900,0 1790.4 280,5N 361,6E 1812,6 1717,5 285,4N 489,0E 86.8 159,7' 160,7' 489,5E 87,1 159,4' 160,4' 493.0E 87,4 158,5' 159,5' 497,8E 87,8 157,3' 158,3' 500.2E 88,0 156,7' 157,7' 1905,6 1794,6 282,7N 364,4E 1818,1 1722.1 287,1N 502,6E 88,1 156,1' 157,1' All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from CLU-6 and TVD from Estimated RKB (42.50 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 52.20 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company CLEARANCE LISTING Page 6 Pad#1,CLU-6 Your ref: CLU-6 Ver~4 Cannery Loop Unit,Cook Inlet, Alaska Last revised : 18-Feb-2000 Reference wellpath Object wellpath : Dipmeter <8600-11420'>,,CLU-5,Pad#1 M.D. T.V.D. Rect Coordinates M.D. T.V.D. Horiz Min'm TCyl Rect Coordinates Bearing Dist Dist 1916.7 1803.0 287.1N 370.2E 1827.5 1730.0 290.1N 1925.0 1809.3 290.5N 374.5E 1835.8 1737.0 292.8N 1927.8 1811.3 291.6N 375.9E 1838.5 1739.3 293.6N 1938.9 1819.7 296.1N 381.8E 1849.5 1748.5 297.2N 1950.0 1827.9 300.7N 387.6E 1858.9 1756.3 300.2N 506.7E 88.7 154.8' 155.9' 510.3E 89.0 153.9' 154.9' 511.5E 89.1 153.6' 154.6' 516.4E 89.6 152.3' 153.4' 520.6E 90.2 151.1' 152.1' 1961.1 1836.2 305.2N 393.5E 1869.8 1765.4 303.8N 1972.2 1844.4 309.8N 399.4E 1880.8 1774.5 307.4N 1975.0 1846.4 311.0N 400.9E 1881.9 1775.4 307.7N 1983.3 1852.5 314.5N 405.4E 1890,1 1782.2 310.4N 1994.4 1860.6 319.1N 411.4E 1901.1 1791.3 314.1N 2000.0 1864.7 321.5N 414.4E 1906.6 1795.8 315.9N 2005.6 1868.7 323,8N 417.5E 1910.5 1799.0 317.2N 2016.7 1876.7 328.5N 423.5E 1921,4 1808.0 320.8N 2025.0 1882.7 332.1N 428.1E 1929,7 1814.7 323.5N 2027.8 1884.7 333.3N 429.7E 1932.4 1817.0 324.5N 2038.9 1892.6 338.1N 435.8E 1941.5 1824.4 327.5N 2050.0 1900.5 342.9N 442.0E 1952.5 1833.3 331,2N 2061.1 1908.3 347.7N 448.2E 1963.5 1842.2 334.9N 2072.2 1916.1 352.5N 454.5E 1974.4 1851.0 338.6N 2075.0 1918.0 353.8N 456.1E 1975.1 1851.6 338.9N 525.5E 90.6 149.8' 150.9' 530.5E 91.1 148.5' 149.6' 531.0E 91,4 148.2' 149.3' 534.7E 91.8 147.3' 148.3' 539.8E 92.3 146.0' 147.0' 542.3E 92.5 145.3' 146.4' 544.1E 93.0 144.7' 145.7' 549.2E 93.5 143,4' 144.4' 553.0E 93.9 142.5' 143.5' 554.3E 94,0 142.1' 143.2' 558.6E 94.9 140.9' 141.9' 563.8E 95.5 139.6' 140.6' 569.1E 96.0 138.3' 139.3' 574.4E 96.6 137.1' 138.0' 574.7E 97.2 136.8' 137.7' 2083.3 1923.8 357.4N 460.8E 1983.4 1858.2 341.7N 2094.4 1931.5 362.3N 467.1E 1994.3 1867.0 345.5N 2100.0 1935.4 364.8N 470.3E 1999.8 1871.4 347.4N 2105.6 1939.2 367.3N 473.5E 2005.3 1875.7 349.3N 2116.7 1946.8 372.2N 479.9E 2014.3 1882.9 352.5N 578.7E 97.6 135.9' 136.8' 584.1E 98.2 134.7' 135.5' 586.8E 98.5 134.1' 134.9' 589.5E 98.8 133.5' 134.3' 594.0E 99.8 132.3' 133.1' 2125.0 1952.5 376.0N 484.7E 2022.5 1889.4 355.4N 2127.8 1954.3 377.2N 486.3E 2025.3 1891,5 356.3N 2138.9 1961.8 382.3N 492.8E 2034.9 1899.1 359.7N 2150,0 1969.3 387.3N 499.3E 2045.9 1907.7 363.7N 2161.1 1976.7 392.4N 505.8E 2056.8 1916.2 367.6N 598.2E 100.3 131.4' 132.2' 599.5E 100.5 131.1' 131.9' 604.4E 101.4 130.0' 130,7' 610.0E 102.1 128.9' 129.6' 615.6E 102.7 127.7' 128.4' 2172.2 1984.1 397.5N 512.4E 2067.0 1924.2 371.3N 2175.0 1985.9 398.8N 514.1E 2069.8 1926.3 372.3N 2183.3 1991.4 402.6N 519.0E 2078.0 1932.7 375.3N 2194.4 1998.7 407.8N 525.7E 2088.9 1941.1 379.4N 2200.0 2002.3 410.3N 529.0E 2094.4 1945.4 381.4N 620.8E 103.6 126.6' 127.3' 622.2E 103.7 126.3' 127.0' 626.5E 104.2 125.4' 126.2' 632.1E 104.9 124.3' 125.0' 635.0E 105.3 123.7' 124.4' 2205.6 2005.9 412.9N 532.4E 2099.2 1949.0 383.2N 2216.7 2013.0 418.1N 539.1E 2110.,1 1957.5 387.3N 2225.0 2018.4 422.1N 544.1E 2118.4 1963.7 390.4N 2227.8 2020.2 423.4N 545.8E 2121.1 1965.8 391.4N 2238.9 2027.2 428.6N 552.6E 2131.3 1973.6 395.3N 637.4E 105.8 123.1' 123.8' 643.1E 106.5 122.0' 122.7' 647.4E 107.1 121.1' 121.8' 648.8E 107.2 120.8' 121.5' 654.2E 108.2 119.6' 120.3' 2250.0 2034.2 433.9N 559.4E 2142.3 1982.0 399.4N 2261.1 2041,2 439,2N 566.2E 2153.2 1990,2 403.6N 2272.2 2048.1 444.5N 573.1E 2163.4 1998,0 407.6N 2275.0 2049.8 445.9N 574.8E 2166,1 2000.0 408,6N 2283.3 2055.0 449.9N 580.0E 2174.3 2006.2 411.8N 659.9E 108.9 118.4' 119.1' 665.7E 109.7 117.3' 118.0' 671.1E 110,7 116.1' 116.8' 672.5E 110.9 115,8' 116.5' 676.9E 111.5 115.0' 115.6' 2294.4 2061.8 455.3N 586.9E 2185.2 2014.4 416.1N 2300.0 2065.2 458.0N 590.4E 2190.0 2018.0 417.9N 2305.6 2068.6 460.7N 593.9E 2195.5 2022.1 420.1N 2316.7 2075.3 466.1N 600.9E 2206.4 2030.2 424.4N 2325.0 2080.3 470.2N 606.2E 2214.5 2036.3 427.6N 682.7E 112.3 113.8' 114.5' 685.3E 112.9 113.3' 113.9' 688.2E 113,3 112.7' 113.3' 694.0E 114.1 111.6' 112.2' 698.4E 114.8 110,7' 111.3' 2327.8 2081.9 471.6N 607.9E 2217.3 2038.3 428.7N 699.9E 115.0 110.5' 111.0' All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from CLU-6 and TVD from Estimated RKB (42.50 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 52.20 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company CLEARANCE LISTING Page Pad #I,CLU-6 Your ref : CLU-6 Ver Cannery Loop Unit,Cook Inlet, Alaska Last revised: 18-Feb-2000 Reference wellpath Object wellpath : Dipmeter <8600-11420'>,.CLU-5,Pad #1 M.D. T.V.D. Rect Coordinates M.D. T.V.D. Horiz Min'm TCyl Rect Coordinates Bearing Dist Dist 2338.9 2088.6 477.0N 615.0E 2227.4 2045.8 432.7N 2350.0 2095.1 482.5N 622.1E 2238.2 2053.8 437.0N 2361.1 2101.6 488.0N 629.2E 2248.2 2061.1 441.0N 2372.2 2108.1 493.6N 636.3E 2259.1 2069.0 445.5N 2375.0 2109.7 495.0N 638.1E 2261.8 2071.0 446.6N 705.3E 116.1 109.4' 109.9' 711.3E 117.0 108.3' 108.8' 716.7E 118.2 107.3' 107.8' 722.8E 119.1 106.4' 106.8' 724.3E 119.3 106.1' 106.5' 2383.3 2114.5 499.2N 643.5E 2269.1 2076.2 449.5N 2394.4 2120.8 504.7N 650.7E 2280.0 2084.1 454.0N 2400.0 2124.0 507.6N 654.3E 2285.4 2088.0 456.3N 2405.6 2127.1 510.4N 657.9E 2290.1 2091.2 458.2N 2416.7 2133.3 516.0N 665.2E 2301.0 2099.0 462.7N 728.3E 120.3 105.5' 105.8' 734.5E 121.2 104.6' 104.9' 737.6E 121.6 104.2' 104.5' 740.2E 122.4 103.8' 104.1' 746.4E 123.3 103.0' 103.3' 2425.0 2138.0 520.2N 670.7E 2309.1 2104.7 466.2N 2427.8 2139.5 521.7N 672.5E 2311.9 2106.6 467.3N 2438.9 2145.7 527.3N 679.8E 2322.3 2114.0 471.7N 2450.0 2151.7 533.0N 687.2E 2333.2 2121.6 476.3N 2461.1 2157.8 538.8N 694.6E 2344.0 2129.1 480.9N 751.1E 123.9 102.5' 102.7' 752.7E 124.1 102.3' 102.5' 758.7E 125.2 101.6' 101.8' 765.0E 126.1 100.9' 101.1' 771.3E 127.0 100.3' 100.5' 2472.2 2163.7 544.5N 702.0E 2354.9 2136.6 485.5N 2475.0 2165.2 545.9N 703.8E 2357.6 2138.5 486.7N 2483.3 2169.7 550.3N 709.4E 2365.8 2144.2 490.2N 2494.4 2175.5 556.0N 716.8E 2376.6 2151.6 494.8N 2500.0 2178.4 559.0N 720.6E 2382.0 2155.4 497.1N 2505.6 2181.3 561.9N 724.3E 2387.5 2159.1 499.5N 2516.7 2187.1 567.7N 731.8E 2398.3 2166.6 504.2N 2525.0 2191.3 572.1N 737.5E 2406.0 2171.9 507.5N 2527.8 2192.8 573.5N 739.4E 2408.7 2173.7 508.7N 2538.9 2198.4 579.4N 746.9E 2419.6 2181.2 513.3N 777.6E 127.9 99.7* 99.8* 779.2E 128.2 99.5* 99.7* 783.9E 128.9 99.1' 99.2* 790.2E 129.9 98.5* 98.6* 793.4E 130.3 98.2* 98.3* 796.5E 130.8 98.0' 98.1' 802.9E 131.8 97.5* 97.6* 807.4E 132.8 97.1' 97.2* 809.0E 133.0 97.0* 97.1' 815.'3E 134.0 96.6* 96.7* 2550.0 2204.0 585.3N 754.5E 2430.4 2188.5 518.0N 2560.2 2209.0 590.7N 761.5E 2439.5 2194.7 521.9N 2570.3 2214.1 596.1N 768.5E 2449.4 2201.4 526.2N 2575.0 2216.3 598.6N 771.7E 2454.0 2204.5 528.2N 2580.5 2219.0 601.5N 775.5E 2459.3 2208.1 530.5N 821.7E 135.0 96.3* 96.3* 827.1E 136.3 96.1' 96.1' 833.0E 137.3 96.0* 96.0* 835.8E 137.7 95.9* 95.9* 839.0E 138.2 95.9* 95.9* 2590.6 2223.9 607.0N 782.5E 2468.4 2214.2 534.4N 2600.0 2228.4 612.0N 789.0E 2477.5 2220.3 538.3N 2600.8 2228.8 612.5N 789.6E 2478.3 2220.9 538.7N 2625.0 2240.3 625.5N 806.4E 2501.4 2236.2 548.6N 2650.0 2252.3 639.0N 823.7E 2525.7 2252.4 559.0N 844.5E 139.5 95.9 95.9 850.0E 140.4 96.0 96.0 850.4E 140.5 96.0 96.0 864.5E 142.9 96.5 96.6 879.4E 145.2 97.5 97.6 2675.0 2264.2 652.4N 841.1E 2549.8 2268.3 569.3N 2700.0 2276.1 665.9N 858.5E 2574.1 2284.5 579.6N 2725.0 2288.0 679.4N 875.8E 2598.2 2300.5 589.9N 2750.0 2299.9 692.8N 893.2E 2622.5 2316.6 600.2N 2775.0 2311.9 706.3N 910.6E 2646.6 2332.7 610.4N 894.2E 147.4 98.8 98.9 909.1E 149.6 100.4 100.7 924.0E 151.7 102.4 102.8 939.0E 153.7 104.7 105.2 953.8E 155.7 107.3 107.9 2800.0 2323.8 719.8N 927.9E 2671.0 2348.9 620.7N 2825.0 2335.7 733.2N 945.3E 2695.4 2365.2 631.0N 2850.0 2347.6 746.7N 962.6E 2719.7 2381.4 641.2N ,2875.0 2359~5 760.2N 980.0E 2744.6 2397.9 651.8N 2900.0 2371.5 773.7N 997.4E 2768.9 2414.1 662.2N 968.8E 157.6 110.1 110.9 983.8E 159.4 113.2 114.2 998.7E 161.1 116.5 117.5 1013.9E 162.6 119.9' 121.1 1028.8E 164.2 123.4 124.7 2925.0 2383.4 787.1N 1014.7E 2793.1 2430.2 672.6N 2950.0 2395.3 800.6N 1032.1E 2817.4 2446.4 683.0N 2975.0 2407.2 814.1N 1049.5E 2841.0 2462.2 692.9N 3000.0 2419.1 827.5N 1066.8E 2865.2 2478.5 703.2N 3025.0 2431.1 841.0N 1084.2E 2889.4 2494.7 713.3N 1043.6E 165.8 127.1 128.6 1058.5E 167.4 131.0 132.7 1072.9E 169.1 135.1 137.1 1087.7E 170.5 139.4 141.6 1102.4E 171.9 143.8 146.2 3050.0 2443.0 854.5N 1101.6E 2914.2 2511.3 723.8N 1117.6E 173.0 148.3 150.8 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from CLU-6 and TVD from Estimated RKB (42.50 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 52.20 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ M.D. 3075.0 3100.0 3125.0 3150.0 3175.0 3200.0 3225.0 3250.0 3275.0 MARATHON Oil Company CLEARANCE LISTING Page 8 Pad #1,CLU-6 Your ref : CLU-6 Ver~4 Cannery Loop Unit,Cook Inlet, Alaska Last revised : 18-Feb-2000 Reference wellpath Object wellpath : Dipmeter <8600-11420'>,,CLU-5,Pad#1 Horiz Min'm TCyl T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2454.9 867.9N 1118.9E 2938.1 2527.2 733.9N 1132.3E 174.3 152.9 155.6 2466.8 881.4N 1136.3E 2962.4 2543.4 744.2N 1147.1E 175.5 157.5 160.6 2478.7 894.9N 1153.7E 2985.1 2558.7 753.7N 1161.0E 177.0 162.4 165.9 2490.6 gOS.3N 1171.0E 300g.3 2575.1 763.8N 1175.7E 178.1 167.5 171.4 2502.6 921.8N 1188.4E 3031.9 25g0.5 773.1N 1189.3E 179.6 172.7 177.2 2514.5 935.3N 1205.7E 3056.0 2607.1 783.0N 1203.8E 180.7 178.3 182.9 2526.4 948.7N 1223.1E 3079.8 2623.4 792.6N 1218.1E 181.8 183.9 188.5 2538.3 962.2N 1240.5E 3105.2 2640.7 803.0N 1233.5E 182.5 189.4 194.0 2550.2 975.7N 1257.8E 3130.7 2657.9 813.5N 1249.2E 183.1 194.9 199.5 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from CLU-6 and TVD from Estimated RKB (42.50 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 52.20 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ SURFACE USE PLAN FOR WELL CLU -6 Surface Location: SE 1/4 of SE 1/4, Sec. 7, T5N, R11W, S.M. 1. Existing Roads Existing roads that will be used for access to the CLU-6 well are shown on the attached map. Kenai, Alaska, is the nearest town to the site and is also shown on the map. 2. Access Roads to be Constructed or Reconstructed No new roadS will be required to access CLU-6. 3. Location of Existing Wells Well CLU-6 Will be drilled on pad CLU-1 off of Cannery Loop road. A pad drawing is attached that shows existing wells and the proposed location for CLU-6. Location of Existing and/or Proposed Facilities The location bf existing production facilities on the CLU-1 pad are shown on the attached pad [drawing. These facilities will be upgraded to handle the additional gas production. : Location of Water Supply The location 0f the water well is shown on the pad drawing. Water will be used to make and maintain the drilling mud. Construction Materials No road or pad modifications or improvements are planned. i. Method of Handling Waste Disposal a) Mud and Cuttings Cuttings will be dewatered on location. The cuttings and excess mud will be hauled to Pad 41-18 of the Kenai Gas Field for disposal into Well KU 11-17, a Class II disposal well (AOGCC Disposal Injection Order No. 9, Permit #81-176). \~ALARS01\COMMON\D RLG\CLU\CLU-6\SU RFUSE.doc Surface Use Plan ~' Well CLU-6 Surface Use Plan Page 2 b) Garbage All household and approved industrial garbage will be hauled to the Kenai Peninsula Borough Soldotna Landfill. c) Completion Fluids Clear fluids will be hauled to Pad 34-31 of the Kenai Gas Field and injected in Well WD #1, an approved disposal well (AOGCC Permit #7-194). d) Chemicals Unused chemicals will be returned to the vendor who provided them. Efforts will be made to minimize the use of all chemicals. e) Sewage Sewage will be hauled to the Kenai sanitation facility. 8. Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose. Bottled water will be used for human consumption. Potable water will be obtained from the existing water well on the pad. Town & Country will collect and transport sanitary wastes to their ADC approved disposal facility. No additional structures will be necessary. 9. Plans for Reclamation of the Surface Well CLU-6 will be drilled from an existing pad. Reclamation of the pad, if required, will occur after abandonment of CLU-6 and the other existing wells on the pad. 10. Surface Ownership Marathon Oil Company is the surface owner of the land in the Cannery Loop Unit. 11. Operator's Representative and Certification I hereby certify that I, or persons under my direct supervision, have inspected the proposed drill site and access route; that I am familiar with the conditions that Surface Use Plan ( Well CLU-6 Surface Use Plan Page 3 currently exist; that the statements made in this plan are, to the best of my knowledge, true and correct; and that the work associated with operations proposed herein will be performed by Marathon Oil Company and its contractors and subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 18 U.S.C. 1001 for the filing of a false statement. Date: ~'~/////E' ~ ~ ~ Name & Title: /,,~', ],,//,,,, ~,~'/~-,~'-/" Mar{[then Oil Comp~any ~' P. O. Box 196168 Anchorage. Alaska 99519-6168 (907) 561-5311 3.5 ~ I '-~-~---~so~ -. .............. :':> ..~ I '-' ,.. /J~_,~ _-z' -'-":"-"': I.-" ~ .......... ~.). .... , ....- .., .... --..,..- ¢! .... -- ............. '--.. ..." ...~_:-:! -/ I ' '"--- L--, I' | ..... ..._..........--~ ' - ---~-- 2-5 _-_¢;z--__ --~ -'~--'2- I .I I .I · I I I /I / / .... :-'----"'" I / I I I I .I. ....... --6 I! :: ...... "-.:::: .... I-: .... 24 / 2.'9 5' '7_-__-:. / 34 '%! 25 '~, · . .:,.}"'?!:..,...~ >.. /. 3 · '''~' C' "-' 1 I ~-,-'-. 10 I :11 '":..-:".. _~__ .'.. '-.... ~ ; : · =.~, ~,,¢ ~..-%=· ,.--%~':' '_- :... ,-'-,~ -- ~l~ .,_ _-_.~ , . ... -:.'.:'::'~L':'-.... :~ '"'" .'"-... "' ;."-"-':'::, .............. i :'"'... "h "--~- .-' T,.---' ~ '~ .... :'. -"; "' ....... - ' ~¢ __-..,. :'".:. ,. "" - ' '" "' '-B- _ .-. .' · ~. _m,~,L~_ T '~--:..:::"',..'_'_' l-. . ':- '--' 1--. ' . ,:...;. :. ;7~.--=-:_.";.:-::'::' ,~.-~'"- .. · "" .' .-.-' ~ -,- I · . .. , ~~:. .~-".T-.-~..-'' T < .-' "- _r--, ~-- 4¢- -' L~"-'.-"_ ,'- -- I ~- -' ;.,%,'--': :.- j. · I:"!._,oo:::'~' s . -. =-_: ,-.:-.- -2%~.-I: = :?': ............ 7 '"'. ............ '""I """"' '"'" ' ~;' -" - - /-:: 5 '-.i '.:- -'~'"" '-""- '.';----:.. 2 -'-~. ::3,-.::.-.-:-:".. I_-'. _. -_-_ _._ i ;-" / i .... ] II .~.~ ......... ~ ~. /.-" '- -.,I '. ' .~ · '~. . .,~-~....~,. ,~ IF- ~" · ~% ' /~'">"-: ":~':/~'::"' """" -L '"i,/ .../-'10':" '"::i~ ':'.. 6 "11' ' · o// ff.:' ..- ...'/ /.~ ._.' ' t -' ' - -'= ,~" ; ..... .:- / ..... :' .'...':".:.- - - ' ':'" ':'...' '.': :!.":-:~::--i:"'.~ :."'-:.'.,-;-~.:..' :".{: .9:' ?'"-:j-:-.'.'f.:..'. '-] ; "'- ': "-"... . * ..... .,- --:.-:.~."'..' .-:~{:.~.:"-;-7 ':--'.:::-".:-,. --.'{'--~:";..':~'~:-~ :i ....: . .-_' .... _ - .' ..,.: .:.-' .:-': -::.:.'. ;.'.-v 'B' "~".-' ':i i-:.-:'"' :.-'--.:':,'::'-;; ;: '::,:.-'i ' .- ..: - '- .. '. '- · ' -.'. ':-. "_ 5- : :"~ ;-:",.':].~ '"':'-" y"?' '"'.~:::,~-'f.'"i": :' ..- , ' ' · *s.~'.o~'~:'.'-" '.-' ~ '"i ' :. .,. '.' .: - '--:'~ '; '"' .'-..]'_',? :-"':.;:."::' "'~":.::": ": *; 7"',.. ' -' -~ - · - '~.' " ' -.. : ~ -.- :- "' '- - :-. '-:-,' %:-" ~-.-.3" - ' -- ' :',~ - ' .. '::. .. ':'i.-:,.y"; '--..'.-':.?? .//:.:-. ,.:; ' .// '*:'. "-. -" '-i~' :; :-"/.': :-' '-...? -'Y- '--'"-.,t.i:7-~, ':"-'~ ;2'-?:'" :"- '~ '% .... ~ .: .. . - . ?' .- :". ...../'.'/."- . . -,..:},.; ..-. t:.. :.}'."; :.::-' ..-.::-'.i: ::.:':-?'/'- :" "'." .": ..... .? · " · '. ' j .... .... .:/;"'/: -:: ~"'-:-"::;.'"'-""-.....?.--'.::i"--'::..:/:,"'{,:)--,;'.,-'::..:':}~,: t:.--'-.,....::~ . . . . - . .,: _ -~{->-~.~ :...- - .....-..-..... ::--..:.-..-:,...-.'-:.]~..-. ~-.-.::::..,.'::,.:..::';.~. :..:-..:.':::.~ ~.~ .. .&,- . .--.. .. -. . .:...~. . --.,.;. :.:' -. ., -',,- .. -.. · '- ,.:'.,,' . . .'.. ."'......'..". ...... ::}: ":'!::.-'--:..--.!':.:..'.:'::--:::-::..'}i-::.':.': ..~.. I'" ' ;' i '2(7[' i"' (K£N~;-'B~'~ ...... ~ ~ROXIMATE MEAN CLINATION, 1951 SCALE 1:63360 ~ 0 ! ~ ~ 4 NILES I----I ~ ~ I I I I I 3000 0 3000 6000 ~000 12000 15000 18000 21000 :FEET i---i ~ ~ i i i fI i I J i i I I i i I ~ i i I I ~ 1 .5 0 1 2 . 3 4 5 KILOMETERS ~ i--i i-~ t-~ t--i i ' I I I I i CONTOUR INTERVAL 50 FEET Do'ri'ED LINES REPRESENT 25-FOOT CONTOURS DATUM IS MEAN SEA LEVEL DEPTH CURVES IN FEET-DATUM IS MEAN LOWER LOW WATEE SHOREUNE SHOWN I~r. PRESEI,.'tS 1H£ APPROXlNATE UNE OF NF.~N HIGH WATER TH£ ~VEI~,~i [ RM~I~£ OF TIDE I$ .~W~O~II.~T ELY 18 ~ FOR SALE BY U. S. GEOLOGICAL SURVEY FAIRBANKS, AI.~SKA 99701, DENVER, COLORADO 80225, OR WASHINGTON, D.C. 20242 A FOLDER DESCRIBING TOPOGRAPHIC MAPS AND SYMBOLS IS AVAILABLE ON REQUEST QUADRANGLE LOCATION Il, II 602OOOm. E. ! SOLDOTN,4 .2 MI ROAD CLASSIFICATION Medium-duht ...... Light-duty Unimproved dirt ......... e~ogooom. N. PIPELINE 25 60'3(7 151°07'30' 1951 NINOR RE¥1SlONS 1972 'T. ? N. T. 6 ['1. 35' T. 6N. T. 5N. KENAI (C-4), ALASKA N60~0--W15107.5/15X22.5 Emar~t 5' Uti~ REPLAQ3) ~ OFF P.,L,O, B.C. ~ 3 I/4' ~ CAP Tm 6' PM Bev. lO.g~ TRACT A ' KENAI SPIT SUBDI~SION NO. 2 INAO~ R~ PIT ~EC ~O~RE ~908 U~ x I I ~ Y - Il? 3.5X4.EX3 UNE S ~'~' E O iCLU-6 SUI~ry BASELINE 8' HIGH WALL ~I.U N~. 5 '" VE]J. HOUm= Y - 23~t.17 479.--x x , ~ &~l[ X OLD CANNERY ROAD 660.~ GRAVEL PAD ELEV.=21.0' & B~ 572.92' 4'X8' x x Y-~laMO.31 8 Mmument Box l Y-238844~45 i X- 272067.~ , ~M by. 24.6~' ~=60'31'~.1~" N L~g.-151~5'~7~9~ W __ I!}i!i~~:':':':':':':':':':':':" ' ' ~~/~t~4~ -: i:i:?i~:i:¥.'."i:i:i:i:i~:?ii:i::¥.... ~ m ~=============================== .. ~. 1" - 1 I~ ¢LD/BI.M monumont found this ~urvey. Found 1/2" robin- Found surrey monument of record. Po~er Pele Ught P~e ~btbg w~ ~H~mm M~it~ ~11 V~ Piping und~gr~nd Ph~e p~ Septic ~t O.H.,S, OVERHEAD EIZCTRIC O.H. P/W O~E:RI'iEAD PIPE WAY E.M. ELECTRIC UE"~ NOTES 1) Elevations at the top of pipe for monitoring wells were taken with cover off or open. 2) Reference dmtum b mean sea IMI-- 0.00' for elemtlmns shem. 3) All bonringe mm grid unlearn nNed 4) Basis of Coordinates ia U.S.C, & A.S.P. Zone 4. 5) Property boundaries shown hm were derived ~rom Trcgt A, Konal Spit SubdNi~ion No. 2, K.R.D. 5) AUDRY Iocetion: ~: 15196'37,44~"W x-:,.,,.7, Marathon Oil Company CLU-1 AS-BUILT SURVEY Region CANNERY LOOP UNIT NO. 1 Alaska"' jion Domest~ Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 March 2, 2000 Ms. Riki Lebman Project Review Coordinator, Oil & Gas Projects Division of Governmental Coordination 411 W. 4th Avenue, Suite 2C Anchorage, AK 99501 RE: Coastal Project Questionnaire; Cannery Loop Unit Pad _ Dear Riki: Attached is the Coastal Project Questionnaire for Cannery Loop Unit Pad 1 Well CLU 6, Kenai Peninsula Borough. This CPQ supercedes a partial CPQ submitted in March 1999 covering the environmental permits for this project only. Also attached are copies of the relevant permits for drilling and completion of the subject gas well and all necessary pad permits for the work to enable initiation of the consistency review. The questionnaire information is consistent with the discussions we had with DGC and other agencies in the pre-application meeting in JPO's offices on Tuesday, February 22, 2000. Thank you for your assistance in this matter. Please advise if you need any other information in order to complete the consistency review for this project. My phone number is 564-6471. Sincerely, Ben Schoffmarm Adv. Sr. Reservoir Engineer Attachments cc: R.J. Menzie W. C. Barron J. V. Miesse S. E. Tmdell Robert N. Christenson - AOGCC ~ Bryant M. Kuby - ADNR Paul McClarnon - ADEC REcENED A subsidiary of USX Corporation Environmentally aware for the long run. PUBLIC NOTICE Alaska Coastal Management Program (ACMP) Division of Governmental Coordination (DGC) The following proposed project is in the Kenai Peninsula Borough Coastal District is being reviewed for consistency with the ACMP. Your comments, particularly on the proposed project's consistency with the affected local coastal district management program, are requested. To be considered, written comments must be submitted to the DGC (address and fax number below) and must be received on or before 5:00 p.m. April 12, 2000. Comments regarding inconsistency with a Kenai Peninsula Borough Coastal District's enforceable policy or a state standard set out in 6 AAC 80.040-6 AAC 80.150 must identify the enforceable policy or standard and explain how the project is inconsistent. PROJECT NAME: Cannery Loop Unit Pad 1: CLU Well 6 PROPOSED PROJECT & LOCATION: Marathon Oil Company proposes to drill a gas development well near Kenai, Alaska in May 2000, that targets the potential gas reserves in the Sterling reservoirs. A water-based mud system will be utilized and the existing water well will furnish water to produce the drilling mud. Approximately 25 days will be required to drill CLU 6. This project is located at T. 5N., R. 11W., Section 7 Seward Meridian. APPLICANT/AGENT: Marathon Oil Company PROJECT NUMBER: State ID # 0003-010G DEADLINE FOR WRITTEN COMMENTS: .April 12, 2000, 5:00 p.n~ FOR MORE INFORMATION Governmental Coordination, JPO 411 West 4th Ave. Suite 2C Anchorage, AK 99501-2343 OR TO SUBMIT COMMENTS CONTACT: Division of Contact: Riki Lebman Phone: 271-4317 Fax: 272-0690 Email: Rlebman~jpo.doi.gov Individuals with disabilities who may need auxiliary aids, services, or special modifications to participate in this review may contact the number above. Dated at Anchorage, AK on 3/10/00 Published in Anchorage Daily News on 3/10/00 Published in Kenai Peninsula News on 3/10/00 16.{50 and O~ Update (,ru /is, 2000 !", Uv/Uu' Pre-Application Stage Tom Cat Exploration Well (Foreenergy): Forcenergy proposes to drill wells on a "wildcat prospect" located on private land owned by the Salamatof Corporation located on-shore on thc western side of Cook Inlet. DGC will initiate the review when agencies deem the application packet is complete. Redoubt Shoals Production Facility (Forcener£y): DOC is awaiting receipt of thc application packet from ForcenergY for dcwlopmcnt of the Redoubt Shoals reservoir. The project would involve construction of a plp¢line from the proposed Osprey Platform to a land-based processing facility on Salamatof Corporation land in the vicinity of the proposed Tom Cat cxplora6on sit~. If Spring 2000 exploration drilling confirms a comm~ial rvscrvoir, Forcenergy hopes to begin construction of production facilities during summer 2000 and begin production in fall 2001. On Ja~mary 25, Trustees for Alaska submitted a brief to thc Superior Court on their ACMP lawsuit for thc Redoubt Shoals exploration project. Cross Cook Inlet Pipeline (UnocaO: Unocal postponed public meetings on this project until completion of partnership agreements. The proposal involves construction of an oil pipeline across Cook Inlet in conjunction with a phase out ofthe Drift River terminal. Unocal is ~onsidering several routes from the West Side of Cook Inlet to Nikiski, and it will likely propose a route from Granite Poin~ ~o Nikiski. The pipeline would b~ t~n- inches in diameter with a thickness of.7 in~h~s and with a coating of about 2 inches of concrete. Unocal is ourrcntly in negottauo with potenti'al partners and has postponed public meetings associated with this projecx. Pike Prospect- Cross Island (Phillips): On December 7, DOC sponsored a pre- application meeting for Phillips Pctrolvum's Pike Prospect which is located in the Cross Island area of thc Beaufort Sea. The proposal may include a three-year exploration program in addition to a seismic survey. Cleanvater Env. ironmcnt~ agent for Phillips, submitted a report to DEC on modeling protocol for this project on January 27. Cannery Loop #6 (Marathon Oil Compan. v):. This project involves a proposal to drill a gas well at Cannery Loop Unit ~6. It would be drilled from the pad using a water-based mud system. The DEC is waiting for a response to a request for information. DQC will issue a joint public notice ,with DEC w~¢n the revirw begins. Stariski Prospect (Frontier Petroleum): This proposed exploration oil and gas w~ll would be located in the .Ninilchik Dome ar~a of thc Kenai Peninsula. An application is expected to be submitted this fall. Renewal of Material Sales Authorizations (ARCO): DGC expects to start the review of a renewal of material sales aut. horizations this week. This project includes six sites for .o. ~: I, i~ ci i~O00 ci ?~:0 I,,'0 ?,cl cir., Marathon Oil Company P.O. Box 196168 ALASKA 99519-6168 IF REPORTABLE RENTS INDICATE I SERVICES I TY.P.E OF I NON-EMPLOYEE COMP. ! PAYMENT IP.~ZES. AWARDS. OR I ................... Filing---f. ee ..-for-,...Perm.~-- to. dr-ill CLU-6 ........................................................ EECE!.._VED .................................... "'.-',,~. 02 ~000 Alaska Oii&Gas ~S. Com~ti ............................................................................... A, nchoFa~ WELL PERMIT CHECKLIST FIELD & POOL COMPANY /~-~'~ ~z~ WELL NAME ~Z,L.~_- ~ PROGRAM: exp ADMINISTRATION 1. . 3. 4. 5. 6. 7. 8. 9. 10. 11. DATE 12. ~./-,~.CX.~ 13. INIT CLASS ~' LP ~'- ~,-~_~ ENGINEERING Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs. do they meet regulation ................ 26. BOPE press rating appropriate; test to '~j~(~(~ psig. dev c,/redrll serv wellbore seg ann. disposal para req GEOL AREA ~"~~; UNIT# ~_~_~('~ ~---~"~ ON/OFF SHORE N .~"l=J"=~: ~--~-~~'~--~'~-~'~-,~' /~-9"~/ .'J-~/"~.,~'. ~~ , 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued wlo hydrogen sulfide measures .... _. / //(~ N 31. Data presented on potential overpressure zones ..... ~,/;/-j'.. Y N 32.' Seismic analysis of shallow gas zones ........... ,/~,,,/-'~. Y N 33. Seabed condition survey (if off-shore) ........... ,,~/.,/7- Y N ~. ~'-C~::) 34. Contact name/phone for weekly progress reports rexploratory on~,,~. N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLQG,Y; ENGINEERING: UIC/Annular COMMISSION: ,.,/J ~-..) T E ~. -.,,...~ .'~,. ~'/'>0 - Comments/Instructions: O Z O Z -r c:\msoffice\wordian~diana\checklist (rev. 02117/00)
