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Home My WebLink About203-0751a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _0 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): North Cook Inlet Unit GL: N/A BF: N/A Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22. Logs Obtained: 23. BOTTOM 30"366' 16" H-40 631' 10-3/4" J-55 1,839' 7-5/8" L-80 2,718' 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, 1039 sx9-1/2" TUBING RECORD N/A SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 737 sx Surface Driven Surface 631' 610 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 7/5/2022 1306' FNL, 1026' FWL, Sec 6, T11N, R9W, SM, AK 2462' FSL, 612' FEL, Sec 31 T12N R9W SM AK 203-075 / 322-129 / 322-185 Tertiary System Gas Pool 126.6' 3,042' MD / 2,718' TVD HOLE SIZE AMOUNT PULLED 50-883-20030-01-00 NCIU A-10A 332044 2586673 N/A CEMENTING RECORDSETTING DEPTH TVD 2590398 BOTTOM TOP 15" Surface 22"Surface CASING WT. PER FT.GRADE 29.7# 335470 TOP SETTING DEPTH MD Surface Per 20 AAC 25.283 (i)(2) attach electronic information 40.5 / 45# 3,042' Surface Surface DEPTH SET (MD) PACKER SET (MD/TVD) 65# 366' Surface 1,911' Gas-Oil Ratio:Choke Size:Water-Bbl: PRODUCTION TEST N/A Date of Test: Flow Tubing 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 Flowing N/A Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: August 16, 2003 August 2, 2003 ADL 17589 N/A N/A 3,042' MD / 2,718' TVD101 N/A 8,840' MD / 6,882' TVD WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment RECEIVED by James Brooks at 7:50 am, 9/9/2022 Abandoned 7/5/2022 JSB RBDMS JSB 091622 xG This prep for ST is like NCIU A-09, in that they were thoroughly get cement through the tubing and into the IA. So, they performed the same contingency as with A-10A, in that they pulled the tubing and then placed a CIBP w/25' of cement inside the 7-5/8". -WCB DSR-9/19/22 (TOW) NCIU A-10A SFD 11/14/2022 203-075 / 322-129 / 322-185 RECEIVED by James Brooks at 7:50 am, 9/9/2022 Abandoned SFD WCB 4/27/2023 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A Top of Productive Interval N/A Beluga 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Contact Email:cdinger@hilcorp.com Authorized Contact Phone: 777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: 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. 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): 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 Formation at total depth: P&A Reports, P&A Schematic Signature w/Date: 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). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). No NoSidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 9.8.2022Digitally 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: 2022.09.08 15:53:17 -08'00' Monty M Myers _____________________________________________________________________________________ Updated by CJD 09-8-22 P&A SCHEMATIC Tyonek Platform Well: A-10A P&A’d: 7/5/22 PTD: 203-075 API: 50-883-20030-01-00 CASING DETAIL Size Wt Grade Conn ID Top Btm 30”120.0 H-40 WELDED 27”Surf 366’ 16”62.5 H-40 WELDED 15.062”Surf 631’ 10-3/4”40.5 J-55 BTC 10.050”Surf 1,695’ 10-3/4”45.5 J-55 BTC 9.950”1,695’1,911’ 7-5/8”29.7 L-80 BTC 6.875”Surf 3,042’ (TOW) TUBING DETAIL 4-1/2”12.6 L-80 IBT-mod 3.958”4,250’7,764’ 3-1/2”9.3 L-80 IBT-mod 7,765’7,972’ GRAVEL PACK 4”9.5 L-80 IBT-mod 3.548”4,694’7,564’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item A 3,042’2718’Whipstock B 3,065’2,738’CIBP C 4,226’3,487’6.059 CIBP w/ 27’ of cement (tag @ 4,199’) 1 4,277’3,555’3.958 5.563 PBR 80-47, 15’ seal travel 2 4,295’3,531’3.958 Cement Retainer w/ 22ft of cement 6 4,307’3,575’3.875 6.500 Packer, Baker Premier 7 4,310’3,540’3.958 CIBP 8 4,665’3,817’3.813 5.500 Sleeve, Baker CMU Sliding, CLOSED, 9 4,708’3,845’3.280 4.218 Anchor Latch, Baker S-22 10 4,709’3,846’4.000 6.490 Packer, Baker SC-2 4,799’3,906’3.548 4.590 Screen, Bakerweld, .012 ga. 11 5,017’4,049’3.250 6.490 Packer, Baker SC-1L Multizone 12 5,611’4,436’3.250 6.490 Packer, Baker SC-1L Multizone 5,672’4,436’3.548 4.590 Screen, Bakerweld, .012 ga. 13 6,208’4,854’3.280 4.218 Snap Latch, Baker S-22 14 6,209’4,854’4.000 6.490 Packer, Baker SC-2 6,293’4,915’3.548 4.590 Screen, Bakerweld, .012 ga 15 6,716’5,230’3.250 6.490 Packer, Baker SC-1L Multizone 6,748’5,255’Magna Range Plug (12/2/21) 6,814’5,304’3.548 4.590 Screen, Bakerweld, .012 ga 16 7,181’5,581’3.250 6.490 Packer, Baker SC-1L Multizone 7,264’5,643’3.548 4.590 Screen, Bakerweld, .012 ga 17 7,564’5,866’3.280 4.218 Snap Latch, Baker S-22B 18 7,565’5,866’4.000 6.500 Packer, Baker FB-1 Sump Packer 19 7,764’6,019’3.940 5.375 XO, 4.5 X 3.5 20 7,797’6,044’2.813 4.250 Nipple, X 21 7,830’6,070’3.548 5.020 Screen, SLHT Excluder 22 7,938’6,153’2.813 4.250 Nipple, X 23 7,970’6,178’2.992 3.800 Wireline Entry Guide Note: 9/3/2003 Three Radioactive (RA) 7-5/8” casing couplings @ 4366’, 5879’ & 7450’ Note: 9/3/2003 Radioactive (RA) collars @ 581’, 6011’, 6396’, 6907’ & 7377’ Note: 07/02/21 –RIH w/ 2-1/8” nozzle for dry tag to 7,970’ RKB Activity Date Ops Summary 3/21/2022 AKEL crew assembles and attends morning safety meeting. Obtain permits and hold PJSM. Rig up eline equipment. Arm and RIH with 4.5" CIBP (3.5" running OD) and correlate to tubing tally. Set plug at 4310' and POOH. Lay down and inspect tools.,Arm and RIH with 3' of 2" OD tubing puncher. Correlate to tubing tally and punch from 4300-4303'. POOH, lay down and inspect tools.,Arm and RIH with 4.5" composite cement retainer (3.57" running OD). Correlate to tubing tally and attempt to set at 4295'. Setting tool igniter went off but tool did not seem to stroke or shear off. Pull out of rope socket and POOH. Rig down off A-10 and move to A-09.,Fish left in hole: 4.5" composite cement retainer: 1.8' x 3.57" OD, setting sleeve: 1.4' x 3.60" OD, #10 setting tool: 5' x 2.75" OD, QC: 0.75' x 2.75" OD, CCL: 1.5' x 3-1/8" OD, 5' weight bars 10' x 1.69" , rope socket: 1' x 1-7/16". OAL: 21.5'. 3/22/2022 Pollard slickine crew arrives at facility. Obtains permit and hold JSA. Spot in slickline equipment with enough lubricator to recover eline tools. Pressure test lubricator to 250 psi low and 1500 psi high.,RIH with 1-3/8" JDC fishing assembly. Tag 4193' and fall to 4245'. Unable to get good bite on eline fishing neck, POOH. RIH with 4.5" GS with 3.73" overshot and bait tools. POOH. RIH with 4.5" GS and latch up to tools. Pull 20 jar licks @ 1800 pounds no movement. Shear off and POOH.,Call for .160 sheave wheels from beach. Build .160 rope socket and stand by for sheaves. Once tools arrive rig up .160 wire and RIH with 4.5" GS fishing assembly. Latch into tools and start jarring up from 2000 pounds up to 3900 pounds in 200 pound increments. Tools free after 3 3900 pound jar licks. POOH with tools, overpull at SSSV nipple. All eline tools recovered, cement retainer sheared off and left downhole.,Secure well, rig down and SDFN. 3/23/2022 Spot equipment over from A-09 and rig up eline. Mix and load 3.5" cement bailer with 17.5 gallons of cement. RIH tie in to tubing tally. Dump cement at 4270' and POOH.,Mix and load 3.5" dump bailer with 17.5 gallons of cement. RIH and tie in to tubing tally. Dump cement at 4250' and POOH. Lay down baler assembly and nightcap well. Rig down eline and move to A-12. Come online with triplex down tubing taking returns from the IA. Pressure up to 700 psi and see break over to 300 psi. Take 50 gallons of returns from IA and shut in tubing and IA with 70 psi trapped on tubing. 3/24/2022 KEL crew assembles and attends morning safety meeting. Obtain permits and hold PJSM. Warm up eline equipment and rig up.,RIH with 1-11/16" CBL tool and correlate to tubing tally. Log from PBTD @ 4295 up to 3800'. Appears to be cement on VDL log at first reading of tool. POOH and lay down tools. Pressure test IA to 1500 psi for 15 minutes, pass. Tubing will not pressure up. Mix 15 gallons of cement and load in 40' of 3.5" dump bailer. RIH, tie in to tubing tally and dump cement at 4275'. Estimated TOC: 4271' .POOH and lay down tools.,Arm and RIH with 4.5" jet cutter (3-5/8" running OD). Correlate to tubing tally and cut tubing at 4250'. POOH, lay down and inspect tools. Secure well and RDMO eline. 4/19/2022 R/U and Circ A-10 well w/ 8.4ppg drill water. First psi up to 900psi to get circulation at 1.25 bpm 8.5ppg. Psi started trending down to 300psi @ 1.25bpm. Increase flow rate to 2 bpm 400psi. Increased flow rate to 2.2bpm FCP 350psi 207bbls pumped till returns 8.4ppg 4/20/2022 R/d down off A-09,Removed well cover, Set the BPV, Skid 404 over well center. Clamped and R/d jacks,Removed flowline and N/d Tree, had issues removing paint from studs.,Removed A-10 Tree. Cleaned the hanger threads the threads looked good. Installed blanking sub into the hanger. pulled the BOPE stack off of A-09 and installed it on the A-10 well. Torqued all the flanges and installed choke and kill lines. M/U koomy lines to the stack. Installed circ head to the top of the annular.,Skid racking beam into place. Raised and scoped mast. Tightened all necessary guy wires for mast. Installed rig floor and cont RU the floor.,M/U 4.5'' Test JT w/ TIW and Dart valve. Installed 4.5'' test JT and M/U to Blanking sub. Filled up Stack and flooded lines for testing getting all the air out of the system. 4/21/2022 Cont R/u test eq. M/u 4 1/2" test joint, flooded eq. working air out and shell tested BOP's all good,Tested BOPE per sundry as following; Annular 250-2500psi, Rams 250-3000psi, Valves 250-3000psi, Calibrate and test gas detection and preformed Koomey drawdown, Annular closing time 21sec, 1 F/P recorded on choke manifold, C4 and C10 stem packing leak during test #2, Repacked and the sequential test was good. Tested with 4 1/2" TJ. Witness waived by Jim Regg 4/20/22 @ 7:42am.,Blow down lines, R/d testing eq. Pull banking sub and L/d TJ, Pulled the BPV well was static,M/u 4 1/2" Landing joint, BOLDS, Pulled hanger off seat 50k cont pulling into string to 30k over w/1.75' of stretch, Tbg appears not to be fully cut, continue work string up to 50k over and tbg came free, string wt fell back to 50k, pulled hanger to rig floor, De-complete and L/d hanger.,POOH L/d 4-1/2" GL Completion f/4,250' T/ Surface, tubing cut was flared out and possibly cut in green cement, cut JT was 12.20'. Clear floor and beaver slide of remaining tubing and GLM.,R/U AK E-line and set unit in place. M/U CIBP to setting tool,AK E-line RIH with 7 5/8'' CIBP model #CPS000-6090-002 and CBL tool. 4/22/2022 Cont RIH w/7-5/8" CIBP tagged cut joint @ 4,230'md, Picked up and set plug 4,226'RKB, PU and tagged plug to confirm set, POOH L/d setting tool.,Mix and load 5" dump bailer with 25 gallons of 17ppg cement. dumped cement on top of CIBP @ 4,226'RKB, POOH. Mix and load 5" bailer w/25gals cement, RIH and dumped on plug. POOH.,M/u solid bottom on the 5" dump bailer, RIH and tagged TOC 4,199'RKB, putting TOC 27' on top of CIBP. POOH L/d tools,R/u testing eq. MIT-IA t/2,500psi and charted for 30mins- good test. R/d test eq. AGOCC Witness was waived by Jim Regg 4/22/22 @ 10:06am.,Armed and RIH w/7-5/8" CIBP, correlated on depth with CLB dated 09/03/03. Set plug @ 3,036', picked up and tagged plug to verify set. POOH, L/d and inspect tools. R/d AK EL and released crew.,See A-11 report,Removed BOPE stack and installed Dry hole tree on A-10A n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: A-10A Decomplete North Cook Inlet Unit Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:A-10A Decomplete Spud Date: Tubing pulled. Had been cut in green cement. -WCB Rig up eline equipment. Arm and RIH with 4.5" CIBP (3.5" running gy g OD) and correlate to tubing tally. Set plug at 4310' and POOH. Tubing will not pressure up. Mix 15 gallons of cement and load in 40' of 3.5" dump bailer. RIH, tie in to tubing tally and dump g cement at 4275'. Estimated TOC: 4271' ,Armed and RIH w/7-5/8" CIBP, correlated on depth with CLB dated 09/03/03. Set plug @ 3,036', PU and tagged plug to confirm set, POOH pg g pulled hanger to rig floor, De-complete and L/d hanger.,POOH L/d 4-1/2" GL Completion f/4,250' T/ Surface, tubing cut was flared out and pg possibly cut in green cement, EL dumped cmt above punched tbg holes. Triplex -cmt into IA. WCB Cont RIH w/7-5/8" CIBP tagged cut joint @ 4,230'md, Picked up and set plug 4,226'RKB, yy Come online with triplex down tubing taking returns from the IA. Pressure up to 700 psi and see break over toELggddtbhdpptbhlppTi l t it IAgp g 300 psi. Take 50 gallons of returns from IA rig up eline. Mix and load 3.5" cement bailer with 17.5 gallons of cement. RIH tie in to tubing tally. Dump cement at 4270' and pqp gp g g POOH.,Mix and load 3.5" dump bailer with 17.5 gallons of cement. RIH and tie in to tubing tally. Dump cement at 4250' and POOH. g gy p gp Tools free after 3 3900 pound jar licks.gy jgp ppp p POOH with tools, overpull at SSSV nipple. All eline tools recovered, cement retainer sheared off and left downhole., ppqpgp Appears to be cement on VDL log at first reading of tool. POOH and lay down tools. Pressure test IA pp g g y to 1500 psi for 15 minutes, pass. pp ,R/U AK E-line and set unit in place. M/U CIBP to g setting tool,AK E-line RIH with 7 5/8'' CIBP model #CPS000-6090-002 and CBL tool. py g Extra cement dumped in tubing. Est TOC 4271'. Tbg cut @4250'. -WCB gj Tbg appears not to be fully cut, continue work string up to 50k over and tbg came free, gpp y gp g MIT-IA t/2,500psi and charted for 30mins- good test. y p ,Arm and RIH with 4.5" composite cement retainer (3.57" running OD). Correlate to tubing tally and attempt to set at 4295'. ,Arm and RIH with 3' of 2" OD tubing puncher. Correlate to tubing tally gp qp (g g pg and punch from 4300-4303'. POOH, )gy p EL set 7-5/8" CIBP @4226' and dump bailed cement atop it. TOC tagged at 4199' (27' of cement atop CIBP). Passing MIT-IA. 7-5/8" CIBP set @3036' for whipstock. -WCB ,RIH with 1-11/16" CBL tool andgy g correlate to tubing tally. Log from PBTD @ 4295 up to 3800'. @p Agyg SL recovered EL tools, but cement retainer left downhole. -WCB 4-1/2" CIBP set in tubing, in packer. Tubing punched @4300'. -WCB .POOH and lay down tools.,Arm and RIH with 4.5" jet cutter (3-5/8" running OD). Correlate to tubing tally and cut tubing at ppg p gy p 4250'. POOH, ,Fish left in hole: 4 ,Mix and loadg 5" dump bailer with 25 gallons of 17ppg cement. dumped cement on top of CIBP @ 4,226'RKB, POOH. Mix and load 5" bailer w/25gals cement, RIH and dumped gg p gggj@ p pg pp g ppg p p @ on plug. POOH.,M/u solid bottom on the 5" dump bailer, RIH and tagged TOC 4,199'RKB, putting TOC 27' on top of CIBP. POOH pg Spot in slickline equipment with enough lubricator to recover eline tools. Activity Date Ops Summary 7/3/2022 Secure drill package to sub structure. Rig welder working on stairs, handrails to safe out the rig. (note: Tested A-09A tree w/Vault rep. against TWC to 5k psi f/5min. on chart-good).;Drill holes in skid rails and secure sub structure t/deck. Remove dry hole tree from A-10B and cut grating to fit tbg spool LDS. Work boat.;N/U 9" x 11" 5k tbg spool, 13-5/8" 5m riser and DSA, 13-5/8" 5m BOP's and bell nipple. Install TT fill up line, bleed off line and pollution pan and torque same. Cont. t/work boat.;Measure flow line for fitting to shaker tank and fit same. Pressure up Koomey unit and function test BOP's.;P/u 4.5 test jt and m/u lower test plug, R/U test pump, floor valve and dart. Fill stack with h2o. Pressure test w/lower test plug in 11" 3m x 9" 3m Csg spool t/250-3k psi f/5min. -charted. Cont. test BOP's.;Inlet Water Used Today (bbl): 0 Inlet Water Used Cumulative (bbl): 0 Discharge Today (bbl): 0 Discharge Cumulative (bbl): 0 Daily down hole loss (bbl): 0 Total down hole loss (bbl): 0 7/4/2022 Grease choke manifold, fill annulus w/h2o. Flush through choke/kill lines and manifold w/same. Attempt t/test 11-3m x 9-3m csg head t/250-3k psi numerous times, no success. R/D test line, B/O test jt f/test plug and Top drive.;Pull test jt to the floor and observe leak on connection, re-tighten same. RIH and screw into test plug and re-test w/annular t/250-3k psi f/5min. on chart-good.;Cont. t/test 13-5/8" 5m BOP, choke manifold and floor valves w/4" and 4.5" test jts 250low/3000 psi high f/5min. -charted as per AOGCC/Hilcorp policy. Perform Accumulator draw down and function test f/drillers emergency remote panel.;R/D test equipment, install MWD transducer in derrick on stand pipe goose neck.;Pick up clean out assy w/Wellbore Integrity Rep. and RIH t/3000’, attempt t/Kelly up-top drive die retainer not holding-die pushing up.;Pull damaged die retainer plates and fabricate new. inspect grabber blocks and dies.;Inlet Water Used Today (bbl): 78 (Used for rinse of RCRA-empty tank) Inlet Water Used Cumulative (bbl): 78 Discharge Today (bbl): 78 (Rinse volume from RCRA-empty tank) Discharge Cumulative (bbl): 78 Daily down hole loss (bbl): 0 Total down hole loss (bbl): 0 7/5/2022 Kelly up top drive and tag CIBP at 3059' with 10K down.;Displace well to 9.2 ppg LSND 4 bpm, 300 psi while reciprocating string. Flush choke lines, choke manifold and kill line.;Close annular and pressure test 7-5/8" casing to 2500 psi for 30 charted min. Good test.;Pump dry job and pull out of the hole, racking back DP and HWDP. Lay out mills and casing scraper - look good.;Hold PJSM with rig crew, WIS rep, MWD and DD for picking up whipstock assembly. Make up mills and MWD and shallow test - good. Make up slide to mills and and run in the hole. Tag tight spot at 145'.;Discuss options and review 7-5/8" casing run information. Pull out of the hole with whipstock. When pulling whipstock shear bolt pin, observed that the pin was not fully in the groove pushing mills 1/8" further out from slide. Lay out slide assembly and remove shear bolt and replace with new.;Make up whipstock with new shear pin and TIH, tag top of CIBP @3065'. Orient whipstock @84deg ROHS w/Haliburton DD. Set whipstock @3063'DPM As per WIS Rep.. P/O wt-92k, S/O wt-87k.;Mill window f/3042' TOW t/3043' as per WIS @250gpm, 750psi, 100rpm, 4-5k trq, 2-3k wob, P/U wt-92k, S/O wt-87k, rot wt-90k.;Cont. mill window f/3043' t/3052' BOW and 20ft new hole 3074'md as per WIS @265gpm, 805psi, 109rpm, 6k trq, 2-3k wob, P/U wt-92k, S/O wt-87k, rot wt-90k.;Circulate and condition mud 9.1ppg in/out.;Perform FIT t/930psi for a 15.7ppg, 1.5bbls pumped w/1.5bbls returned.;Annulus pressure: OA=0, IA=50psi, @2330hrs.;Inlet Water Used Today (bbl): 0 Inlet Water Used Cumulative (bbl): 78 Discharge Today (bbl): 0 Discharge Cumulative (bbl): 78 Daily down hole loss (bbl): 0 Total down hole loss (bbl): 0 n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: NCIU A-10A PreDrill North Cook Inlet Unit Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:A-10A P&A Spud Date: Whipstock set @3063'. Milled window 3042'-3052' and drilled 20' of new hole. -WCB p ;Cont. mill window f/3043' t/3052' BOW and 20ft new hole 3074'md ;Mill window f/3042' TOW t/3043' pygpg ;Make up whipstock with new shear pin and TIH, tag top of CIBP @3065'. Orientgp@yy p whipstock @84deg ROHS w/Haliburton DD. Set whipstock @3063'DPM A Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 4/20/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NCI A-10A (PTD 203-075) CIBP Punch Cement 3/24/2022 Please include current contact information if different from above. PTD:203-075 T36587 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.11 11:40:06 -08'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 5/09/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NCI A-10A (PTD 203-075) Plug Cement 04/22/2022 Please include current contact information if different from above. PTD:203-075 T36567 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.10 10:06:01 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:Wade Hudgens - (C) Cc:Brooks, Phoebe L (OGC) Subject:RE: HAK 404/NCIU A-10A/BOPE Test Report 4-21-22 Date:Saturday, April 23, 2022 1:09:00 PM Changed our copy of the report to show 2 failures to be consistent with remarks. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Wade Hudgens - (C) <whudgens@hilcorp.com> Sent: Friday, April 22, 2022 9:51 AM To: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com>; 'AAO Offshore' <offshore@allamericanoilfield.com> Subject: RE: HAK 404/NCIU A-10A/BOPE Test Report 4-21-22 Please see attached BOPE Test Report for NCIU A-10A. Thank You, Wade Hudgens WSM, Rig 404 Hilcorp Alaska C: 903-331-6711 O:907-776-6754 whudgens@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1&,8$$ 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:404 DATE: 4/21/22 Rig Rep.: Rig Phone: 907-776-6754 Operator: Op. Phone:907-776-6754 Rep.: E-Mail Well Name: PTD #22030750 Sundry #322185 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250-3000 Annular:250-2500 Valves:250-3000 MASP:1815 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 13-5/8 5m P Pit Level Indicators PP #1 Rams 1 2 7/8 x 5 1/2 vbr's P Flow Indicator NA NA #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 2-1/16 5m P Inside Reel valves 0NA HCR Valves 2 2-1/16 5m P Kill Line Valves 2 2-1/16 5m P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0NA Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)1850 P Quantity Test Result 200 psi Attained (sec)19 P No. Valves 11 FP Full Pressure Attained (sec)80 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 4 x 2175 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:2 Test Time:4.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 4-19-22/08:48 am Waived By Test Start Date/Time:4/21/2022 7:30 (date) (time)Witness Test Finish Date/Time:4/21/2022 11:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp 1 F/P on choke manifold, vavle stem leak on C4 and C10, repaired and the sequential Test was good. Test was preformed w/ 4 1/2" TJ, Annular close 21 sec Chad Johnson / Brad Whitten Hilcrop AK Wade Hudgens / Luke Moore NCIU A-10A Test Pressure (psi): whudgens@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0421_BOP_Hilcorp404_NCIU_A-10A 9 9 9 9999 9 9 9 9 FKDQJHGWR)3RQFKRNHPDQLIROG YDOYHVQRWHGMEU 9 9 -5HJJ 1 F/P on choke manifold, FP FKDQJHGWR)3RQFKRNHPDQLIROGJ YDOYHVQRWHGMEU Annular close 21 sec 2 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,840'N/A Casing Collapse Structural Conductor Surface 1,580 psi Intermediate Production 4,790 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Chad Helgeson, Operations Engineer Contact Email:chelgeson@hilcorp.com Contact Phone: 907-777-8405 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 6,882'6,748'5,255'~1,815 6,748' 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Dan Marlowe, Operations Manager, 907-283-1329 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 203-075 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 50-883-20030-01-00 Hilcorp Alaska LLC North Cook Inlet Unit / Tertiary System Gas Pool N/A N Cook Inlet Unit A-10A Length Size 366'366' 12.6 / L-80 & 9.3 / L-80 TVD Burst 7,764' & 7,972' 6,890 psi MD 3,130 psi 631' 1,839' 631' 1,911' 6,874'7-5/8" 366'30" 16" 10-3/4" 631' 1,911' 8,830' Perforation Depth MD (ft): See Attached Schematic 8,830' See Attached Schematic April 12, 2022 4-1/2" & 3-1/2" See Schematic See Schematic P t _ s 66 Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 3:58 pm, Apr 01, 2022 322-185 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2022.04.01 15:52:31 -08'00' Dan Marlowe (1267) BJM 4/8/22 Variance to 20AAC25.112(c)(1)(E) approved. Plug to be set +/-165' above perfs. X SFD 4/4/2022 CIBP or cement top in step #9 must be pressure tested and tagged per 20 AAC 25.112(g)(2). Provide 48 hrs notice for AOGCC witness. X 10-407 DSR-4/4/22 BOP test to 3000 psi/ Annular test to 2500 psi for both rig 404 and Spartan 151. dts 4/8/2022 Jeremy Price Digitally signed by Jeremy Price Date: 2022.04.08 14:12:10 -08'00' RBDMS SJC 041222 Change of Well Work Well: North Cook Inlet A-10A Date: 3/31/2022 Well Name: NCIU A-10A (Rev 3) API Number: 50-883-20030-01-00 Current Status: SI Producer Leg: Leg #2 SW Corner Estimated Start Date: 4/12/2022 Rig: Rig 404 & Spartan 151 Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: 3/18/2022 Regulatory Contact: Donna Ambruz (8305) Permit to Drill Number: 203-075 First Call Engineer: Chad Helgeson (907)-777-8405 (O) (907) 229-4824 (M) Second Call Engineer: Sean Mclaughlin (907) 223-6784 (M) This change of program replaces step 12 to the final step of approved sundry #322-129. Purpose: Steps 1-11 of the original sundry were completed, however the 25ft of cement outside the tubing was not accomplished. The purpose of these changes is to use rig 404 to pull tubing and set a CIBP with 25ft of cement as deep as reasonable. The remaining procedure is for setting the whipstock when the Spartan 151 rig is on the well for the sidetrack. The previous approved variance to 20 AAC 25.112 (c)(1)(E) for placing cement within 50ft of the top perf will still be required as the new plug installed will be set 165’ above top perfs. Current well status: - Plug set at 4,310’ (plug not tested) - Tubing punched at 4,300’-4,303’ - Composite retainer set at 4,295’ - 35 gal of cement pushed through retainer, 50 gal of water bled from casing - 15 gal (22ft) of cement placed on top of the retainer - Tubing was cut at 4,250’ Continue from step 12 in original sundry. Rig 404 Procedure: 1. MIRU Rig 404 2. Install BPV, ND tree, NU BOP 3. Test BOPE ¾ Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. (Notify AOGCC 48 hours in advance of test to allow them to witness test). ¾ If the BOP is used to shut in on the well in a well control situation or if BOP equipment could be compromised, ALL BOP components utilized for well control or compromised must be tested prior to the next trip into the wellbore. ¾ BOPs will be closed as needed to circulate the well during this workover. 4. Pull BPV 5. Circulate well with water (8.4 ppg) 6. Pull hanger and seals 7. POOH with 4-1/2” IBT-M tubing 8. Lay down GL Valves and SSSV (Send in to be redressed) 9. RU Eline RIH and set 7” CIBP at ~4,245’ and dump 25ft of cement (49 gal) on plug 10. Pressure test casing to 2,500 psi and chart for 30 min 11. RIH and set 7” CIBP at ~ 3,030’ (10’ above collar) CIBP or TOC must be tagged to verify depth - bjm Variance approved CIBP is for 7-5/8" csg, not 7" - bjm Change of Well Work Well: North Cook Inlet A-10A Date: 3/31/2022 12. RD Eline 13. ND BOPs, NU dry hole tree & test 14. RDMO Hilcorp Rig 404 Spartan 151 Rig Procedure: 15. MIRU Spartan 151 16. ND tree, NU BOP 17. Test BOPE ¾ Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. (Notify AOGCC 48 hours in advance of test to allow them to witness test) ¾ Ensure to leave “A” section side outlet valves open during BOP testing so pressure does not build up beneath the TWC. Confirm the correct valves are opened!!! ¾ Test VBRs on 4.5” test joint (3000 test on largest and smallest DP), ¾ Ensure gas monitors are calibrated and tested in conjunction w/ BOPE ¾ If the BOP is used to shut in on the well in a well control situation or if BOP equipment could be compromised, ALL BOP components utilized for well control or compromised must be tested prior to the next trip into the wellbore. 18. Set wear bushing in wellhead. Ensure ID of wear bushing > 6-3/4” 19. Make up the WIS 7” whipstock 20. TIH with DP to the whipstock setting depth. Exercise caution when RIH / setting slips with whipstock assembly ¾ Fill the drill pipe a minimum of every 20 stands on the trip in the hole with the whipstock assembly. With FIW. ¾ Avoid sudden starts and stops while running the whipstock. ¾ Recommend running in the hole at a maximum of 90-120 seconds per stand taking care not to spud or catch the slips. Ensure running string is stationary prior to insertion of the slips and that slips are removed slowly when releasing the work string to RIH. These precautions are required to avoid any weakening of the whipstock shear mechanisms and / or to avoid part / preset on the packer. 21. Orient whipstock as directed by the directional driller. The directional plan specifies 80 deg ROHS 22. Set the top of the whipstock at ~3,010’ MD 23. Circulate out drill water (8.4 ppg fresh water) from well with LSND mud ***Remaining Procedure to be included on the Permit to Drill for the redrill starting at section 13.7*** Attachments: 1. Well Schematic Current (updated from steps 1-11 of original sundry) 2. Well Schematic Proposed 3. BOP Drawing - Rig 404 4. Fluid/Flow Diagrams – Rig 404 5. BOP Drawing – Spartan Rig 151 _____________________________________________________________________________________ Updated By CAH 3/31/22 SCHEMATIC Tyonek Platform Well: A-10A Last Completed: 9/5/2003 PTD: 203-075 API: 50-883-20030-01-00 CASING DETAIL Size Wt Grade Conn ID Top Btm 30”120.0 H-40 WELDED 27”41’366’ 16”62.5 H-40 WELDED 15.062”41’631’ 10-3/4”40.5 J-55 BTC 10.050”41’ 1,695’ 10-3/4”45.5 J-55 BTC 9.950” 1,695’ 1,911’ 7-5/8”29.7 L-80 BTC 6.875”44’ 8,830' TUBING DETAIL 4-1/2”12.6 L-80 IBT-mod 3.958” 43.8’7,764’ 3-1/2”9.3 L-80 IBT-mod 7,765’7,972’ GRAVEL PACK 4”9.5 L-80 IBT-mod 3.548”4,694’7,564’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 414’414’3.813 6.000 Safety Valve, Camco 4-1/2” TRM-4PE CF TRSSSV 2A 1,356’1,336’3.865 6.059 GLM#, 1 Camco KBG-2, BK latch 2B 2,398’2,268’3.865 6.059 GLM#2 Camco KBG-2, BK latch 2C 3,386’2,951’3.865 6.059 GLM#3 Camco KBG-2, BK latch 2D 4,221’3.865 6.059 GLM#4, Camco KBG-2, BK latch 3 4,250’Tubing cut 4 4,277’3,555’3.958 5.563 PBR 80-47, 15’ seal travel 5 4,295 3.958 Composite cement retainer w/ 23ft of cement 6 4,307’3,575’3.875 6.500 Packer, Baker Premier 7 4,310’3.958 CIBP 8 4,665’3,817’3.813 5.500 Sleeve, Baker CMU Sliding, CLOSED 9 4,708’3,845’3.280 4.218 Anchor Latch, Baker S-22 10 4,709’3,846’4.000 6.490 Packer, Baker SC-2 4,799’3,906’3.548 4.590 Screen, Bakerweld, .012 ga. 11 5,017’4,049’3.250 6.490 Packer, Baker SC-1L Multizone 12 5,611’4,436’3.250 6.490 Packer, Baker SC-1L Multizone 5,672’4,436’3.548 4.590 Screen, Bakerweld, .012 ga. 13 6,208’4,854’3.280 4.218 Snap Latch, Baker S-22 14 6,209’4,854’4.000 6.490 Packer, Baker SC-2 6,293’4,915’3.548 4.590 Screen, Bakerweld, .012 ga 15 6,716’5,230’3.250 6.490 Packer, Baker SC-1L Multizone 6,748’5,255’Magna Range Plug (12/2/21) 6,814’5,304’3.548 4.590 Screen, Bakerweld, .012 ga 16 7,181’5,581’3.250 6.490 Packer, Baker SC-1L Multizone 7,264’5,643’3.548 4.590 Screen, Bakerweld, .012 ga 17 7,564’5,866’3.280 4.218 Snap Latch, Baker S-22B 18 7,565’5,866’4.000 6.500 Packer, Baker FB-1 Sump Packer 19 7,764’6,019’3.940 5.375 XO, 4.5 X 3.5 20 7,797’6,044’2.813 4.250 Nipple, X 21 7,830’6,070’3.548 5.020 Screen, SLHT Excluder 22 7,938’6,153’2.813 4.250 Nipple, X 23 7,970’6,178’2.992 3.800 Wireline Entry Guide Note: 9/3/2003 Three Radioactive (RA) 7-5/8” casing couplings @ 4366’, 5879’ & 7450’ Note: 9/3/2003 Radioactive (RA) collars @ 581’, 6011’, 6396’, 6907’ & 7377’ Note: 07/02/21 – RIH w/ 2-1/8” nozzle for dry tag to 7,970’ RKB Top of good cement @ 2616' MD CBL 7-5/8" csg, 3-Sep-2003 - bjm SCHEMATIC Updated By DMA 02-02-22 Tyonek Platform Well: A-10A Last Completed: 9/5/2003 PTD: 203-075 API: 50-883-20030-01-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf Comments Sterling 4,415’ 4,428’ 3,648’ 3,656’ 13’ 9/15/2003 TCP Guns CI-A 4,454’ 4,487’ 3,674’ 3,697’ 33’ 9/15/2003 TCP Guns CI-1 4,805’ 4,905’ 3,910’ 3,976’ 100’ 9/5/2003 Gravel Packed Slots CI-2 4,920’ 5,005’ 3,985’ 4,041’ 85’ 9/5/2003 Gravel Packed Slots CI-10 5,685’ 5,700’ 4,486’ 4,496’ 15’ 9/5/2003 Gravel Packed Slots Beluga A 5,894’ 5,914’ 4,629’ 4,643’ 20’ 9/5/2003 Gravel Packed Slots Beluga B 6,090’ 6,105’ 4,769’ 4,779’ 15’ 9/5/2003 Gravel Packed Slots Beluga C 6,185’ 6,195’ 4,837’ 4,844’ 10’ 9/5/2003 Gravel Packed Slots Beluga D 6,300’ 6,310’ 4,921’ 4,928’ 10’ 9/5/2003 Gravel Packed Slots Beluga D 6,450’ 6,525’ 5,031’ 5,086’ 75’ 9/5/2003 Gravel Packed Slots Beluga E 6,646’ 6,665’ 5,177’ 5,191’ 19’ 9/5/2003 Gravel Packed Slots Beluga F 6,685’ 6,710’ 5,207’ 5,226’ 25’ 9/5/2003 Gravel Packed Slots Beluga G 6,825’ 6,865’ 5,313’ 5,343’ 40’ 9/5/2003 Gravel Packed Slots Beluga H 7,010’ 7,028’ 5,452’ 5,466’ 18’ 9/5/2003 Gravel Packed Slots Beluga I 7,165’ 7,175’ 5,569’ 5,577’ 10’ 9/5/2003 Gravel Packed Slots Beluga J 7,270’ 7,280’ 5,647’ 5,655’ 10’ 9/5/2003 Gravel Packed Slots Beluga L 7,425’ 7,450’ 5,762’ 5,781’ 25’ 9/5/2003 Gravel Packed Slots Beluga M 7,515’ 7,555’ 5,829’ 5,859’ 40’ 9/5/2003 Gravel Packed Slots Beluga P 7,830’ 7,905’ 6,070’ 6,128’ 75’ 9/5/2003 Gravel Packed Slots _____________________________________________________________________________________ Updated By CAH 03-31-22 PROPOSED Tyonek Platform Well: A-10A Last Completed: 9/5/2003 PTD: 203-075 API: 50-883-20030-01-00 CASING DETAIL Size Wt Grade Conn ID Top Btm 30”120.0 H-40 WELDED 27”41’366’ 16”62.5 H-40 WELDED 15.062”41’631’ 10-3/4”40.5 J-55 BTC 10.050”41’ 1,695’ 10-3/4”45.5 J-55 BTC 9.950” 1,695’ 1,911’ 7-5/8”29.7 L-80 BTC 6.875”44’ 8,830' TUBING DETAIL 4-1/2”12.6 L-80 IBT-mod 3.958”±4,250’7,764’ 3-1/2”9.3 L-80 IBT-mod 7,765’7,972’ GRAVEL PACK 4”9.5 L-80 IBT-mod 3.548”4,694’7,564’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item A ±3,010’±2,693’Whipstock B ±3,030’±2,714’CIBP C ±4,245’6.059 CIBP w/ 25’ of cement 1 4,277’3,555’3.958 5.563 PBR 80-47, 15’ seal travel 2 ±4,295’3.958 Cement Retainer w/ 22ft of cement 6 4,307’3,575’3.875 6.500 Packer, Baker Premier 7 ±4,310’3.958 CIBP 8 4,665’3,817’3.813 5.500 Sleeve, Baker CMU Sliding, CLOSED, 9 4,708’3,845’3.280 4.218 Anchor Latch, Baker S-22 10 4,709’3,846’4.000 6.490 Packer, Baker SC-2 4,799’3,906’3.548 4.590 Screen, Bakerweld, .012 ga. 11 5,017’4,049’3.250 6.490 Packer, Baker SC-1L Multizone 12 5,611’4,436’3.250 6.490 Packer, Baker SC-1L Multizone 5,672’4,436’3.548 4.590 Screen, Bakerweld, .012 ga. 13 6,208’4,854’3.280 4.218 Snap Latch, Baker S-22 14 6,209’4,854’4.000 6.490 Packer, Baker SC-2 6,293’4,915’3.548 4.590 Screen, Bakerweld, .012 ga 15 6,716’5,230’3.250 6.490 Packer, Baker SC-1L Multizone 6,748’5,255’Magna Range Plug (12/2/21) 6,814’5,304’3.548 4.590 Screen, Bakerweld, .012 ga 16 7,181’5,581’3.250 6.490 Packer, Baker SC-1L Multizone 7,264’5,643’3.548 4.590 Screen, Bakerweld, .012 ga 17 7,564’5,866’3.280 4.218 Snap Latch, Baker S-22B 18 7,565’5,866’4.000 6.500 Packer, Baker FB-1 Sump Packer 19 7,764’6,019’3.940 5.375 XO, 4.5 X 3.5 20 7,797’6,044’2.813 4.250 Nipple, X 21 7,830’6,070’3.548 5.020 Screen, SLHT Excluder 22 7,938’6,153’2.813 4.250 Nipple, X 23 7,970’6,178’2.992 3.800 Wireline Entry Guide Note: 9/3/2003 Three Radioactive (RA) 7-5/8” casing couplings @ 4366’, 5879’ & 7450’ Note: 9/3/2003 Radioactive (RA) collars @ 581’, 6011’, 6396’, 6907’ & 7377’ Note: 07/02/21 – RIH w/ 2-1/8” nozzle for dry tag to 7,970’ RKB PROPOSED Updated By CAH 03-13-22 Tyonek Platform Well: A-10A Last Completed: 9/5/2003 PTD: 203-075 API: 50-883-20030-01-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf Comments Sterling 4,415’ 4,428’ 3,648’ 3,656’ 13’ 9/15/2003 TCP Guns CI-A 4,454’ 4,487’ 3,674’ 3,697’ 33’ 9/15/2003 TCP Guns CI-1 4,805’ 4,905’ 3,910’ 3,976’ 100’ 9/5/2003 Gravel Packed Slots CI-2 4,920’ 5,005’ 3,985’ 4,041’ 85’ 9/5/2003 Gravel Packed Slots CI-10 5,685’ 5,700’ 4,486’ 4,496’ 15’ 9/5/2003 Gravel Packed Slots Beluga A 5,894’ 5,914’ 4,629’ 4,643’ 20’ 9/5/2003 Gravel Packed Slots Beluga B 6,090’ 6,105’ 4,769’ 4,779’ 15’ 9/5/2003 Gravel Packed Slots Beluga C 6,185’ 6,195’ 4,837’ 4,844’ 10’ 9/5/2003 Gravel Packed Slots Beluga D 6,300’ 6,310’ 4,921’ 4,928’ 10’ 9/5/2003 Gravel Packed Slots Beluga D 6,450’ 6,525’ 5,031’ 5,086’ 75’ 9/5/2003 Gravel Packed Slots Beluga E 6,646’ 6,665’ 5,177’ 5,191’ 19’ 9/5/2003 Gravel Packed Slots Beluga F 6,685’ 6,710’ 5,207’ 5,226’ 25’ 9/5/2003 Gravel Packed Slots Beluga G 6,825’ 6,865’ 5,313’ 5,343’ 40’ 9/5/2003 Gravel Packed Slots Beluga H 7,010’ 7,028’ 5,452’ 5,466’ 18’ 9/5/2003 Gravel Packed Slots Beluga I 7,165’ 7,175’ 5,569’ 5,577’ 10’ 9/5/2003 Gravel Packed Slots Beluga J 7,270’ 7,280’ 5,647’ 5,655’ 10’ 9/5/2003 Gravel Packed Slots Beluga L 7,425’ 7,450’ 5,762’ 5,781’ 25’ 9/5/2003 Gravel Packed Slots Beluga M 7,515’ 7,555’ 5,829’ 5,859’ 40’ 9/5/2003 Gravel Packed Slots Beluga P 7,830’ 7,905’ 6,070’ 6,128’ 75’ 9/5/2003 Gravel Packed Slots BOP Stack Rig 404 Shaffer SL 13 5/8 5M 2 7/8-5.5 variables Blinds 2.26' Riser 13 5/8 5M FE X 13 5/8 5M FE Spacer spool 13 5/8 5M FE X 11 5M 4.54' 2.83' Choke and Kill valves 2 1/16 5M Mud Cross 4 1/16 5M EFO 4.30' Hydril GK 13 5/8-5000 DSA 4 X 2DSA 4 X 2Spacer spool 13 5/8 5M X 13 5/8 5M HILCORP ALASKA, LLC SwacoSuperchokeBlooey LineTo Gas BusterInlet E/Ͳϭϭ ϬϭͲϮϴͲϮϮ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1$1&RRN,QOHW8QLW$$ 7XELQJ*UDGH7XELQJ0'IW3HUIRUDWLRQ'HSWK79'IW7XELQJ6L]H ,KHUHE\FHUWLI\WKDWWKHIRUHJRLQJLVWUXHDQGWKHSURFHGXUHDSSURYHGKHUHLQZLOOQRWEHGHYLDWHGIURPZLWKRXWSULRUZULWWHQDSSURYDO $XWKRUL]HG1DPHDQG 'LJLWDO6LJQDWXUHZLWK'DWH $2*&&86(21/< 'DQ0DUORZH2SHUDWLRQV0DQDJHU a 3 W B V )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Samantha Carlisle at 8:01 am, Mar 14, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH BOP test to 3000 psi, Annular test to 2500 psi. BJM 3/18/22 DSR-3/14/22 X Send CBL to AOGCC for review and approval before placing cement inside tubing. Minimum 25' of cement in annulus above PBR. X Variance to 20 AAC 25.112 (c)(1)(E) approved. Plug will be set ~145' above top perfs. 10-407 SFD 3/16/2022 Pressure test 7" casing to 2200 psi and chart for 30 minutes after pulling tubing and swapping to mud. Provide 48 hrs notice to AOGCC. JLC 3/18/2022 Jeremy Price Digitally signed by Jeremy Price Date: 2022.03.18 15:12:51 -08'00' RBDMS SJC 032322 tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůů͗EŽƌƚŚŽŽŬ/ŶůĞƚͲϭϬ ĂƚĞ͗ϯͬϭϯͬϮϬϮϮ tĞůůEĂŵĞ͗E/hͲϭϬ;ZĞǀϭͿ W/EƵŵďĞƌ͗ ϱϬͲϴϴϯͲϮϬϬϯϬͲϬϭͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^/WƌŽĚƵĐĞƌ >ĞŐ͗>ĞŐηϮ^tŽƌŶĞƌ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ϬϯͬϭϳͬϮϮ;Ͳ>ŝŶĞͿ ZŝŐ͗Spartan 151 ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍ϰϬϯ ĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ŽŶŶĂŵďƌƵǌ;ϴϯϬϱͿ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϬϯͲϬϳϱ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ŚĂĚ,ĞůŐĞƐŽŶ ;ϵϬϳͿͲϳϳϳͲϴϰϬϱ;KͿ ;ϵϬϳͿϮϮϵͲϰϴϮϰ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗^ĞĂŶDĐůĂƵŐŚůŝŶ ;ϵϬϳͿϮϮϯͲϲϳϴϰ;DͿ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗Ϯ͕ϰϬϭƉƐŝΛϱ͕ϴϱϱ͛ds ;Wd^ƵƌǀĞǇƌƵŶϭϭͬϭϵͬϮϭͿ DĂǆŝŵƵŵǆƉĞĐƚĞĚ,W͗Ϯ͕ϰϬϭƉƐŝΛϱ͕ϴϱϱ͛ds ;WůƵŐŐŝŶŐǁĞůůͿ DĂǆŝŵƵŵWŽƚĞŶƚŝĂů^ƵƌĨĂĐĞWƌĞƐƐƵƌĞ͗ϭ͕ϴϭϱƉƐŝ ĂƐĞĚŽŶϬ͘ϭƉƐŝͬĨƚŐĂƐŐƌĂĚŝĞŶƚ DĂǆ/ŶĐůŝŶĂƚŝŽŶ ϰϵ͘ϵΣΛϱ͕ϬϰϬ͛D ƌŝĞĨtĞůů^ƵŵŵĂƌǇ dŚĞͲϭϬtĞůůǁĂƐƐŝĚĞƚƌĂĐŬĞĚŝŶϮϬϬϯǁŝƚŚƚŚĞ<ƵƵŬƉŝŬηϱZŝŐƚŽƚŚĞͲϭϬĂŶĚĐŽŵƉůĞƚĞĚŝŶ^ĞƉƚĞŵďĞƌ ϮϬϬϯĂƐĂŐĂƐǁĞůů͘dŚĞǁĞůůǁĂƐĐůĞĂŶĞĚŽƵƚǁŝƚŚĐŽŝůŝŶϮϬϬϰ͕ϮϬϭϬ͕ĂŶĚϮϬϮϭ͘/Ŷ:ƵŶĞŽĨϮϬϮϭĐŽŝůǁĂƐ ĂďůĞƚŽƌĞŵŽǀĞůŽƐƚƐůŝĐŬůŝŶĞƚŽŽůƐĂŶĚĐůĞĂŶƚŚĞǁĞůůŽƵƚĂŶĚƉĞƌĨŽƌŵĞĚĂĐĂůŝƉĞƌƐƵƌǀĞǇƚŽϳ͕ϵϬϯ͛͘dŚĞǁĞůů ǁĂƐďƌŽƵŐŚƚŽŶůŝŶĞ͕ďƵƚǁĂƐŵĂŬŝŶŐϭ͕ϱϬϬͲϮ͕ϬϬϬďďůƐŽĨǁĂƚĞƌƉĞƌĚĂǇǁŝƚŚŶŽŐĂƐĂŶĚƚŚĞǁĞůůŚĂƐďĞĞŶ ƐŚƵƚͲŝŶ͘ dŚĞƉƵƌƉŽƐĞŽĨƚŚŝƐƐƵŶĚƌǇŝƐƚŽƉůƵŐďĂĐŬƚŚĞĐƵƌƌĞŶƚǁĞůůďŽƌĞĂŶĚƐĞƚƵƉƚŚĞǁĞůůĨŽƌĂƐŝĚĞƚƌĂĐŬĨŽƌĂ ƌĞĚƌŝůů͘ ,ŝůĐŽƌƉƌĞƋƵĞƐƚƐĂǀĂƌŝĂŶĐĞƚŽϮϬϮϱ͘ϭϭϮ;ĐͿ;ϭͿ;ͿĨŽƌƉůĂĐŝŶŐĐĞŵĞŶƚǁŝƚŚŝŶϱϬĨƚŽĨƚŚĞƚŽƉƉĞƌĨ͘dŚĞ ĐŽŶƚŝŶŐĞŶĐǇƉƌŽĐĞĚƵƌĞŝŶĐůƵĚĞƐƚŚĞƐƚĞƉƐƚŽƉůĂĐĞĐĞŵĞŶƚĂƐĚĞĞƉĂƐƌĞĂƐŽŶĂďůĞŝŶƚŚĞƚƵďŝŶŐĂŶĚ ĐĂƐŝŶŐƚŽŵĞĞƚϮϬϮϱ͘ϭϭϮ;ĐͿ;ϭͿǁŚĞƌĞƚŚĞŚǇĚƌŽĐĂƌďŽŶƐĂƌĞĐŽŶĨŝŶĞĚƚŽƚŚĞŝƌŝŶĚŝŐĞŶŽƵƐƐƚƌĂƚĂ ĂŶĚǁŝůůŶŽƚŵŝŐƌĂƚĞƚŽƐƵƌĨĂĐĞ͕ďƵƚƚŚĞǇǁŝůůŶŽƚďĞǁŝƚŚŝŶϱϬĨƚŽĨƚŚĞƚŽƉŽĨƉĞƌĨŽƌĂƚŝŽŶƐ͕ĂƐ ƌĞƋƵŝƌĞĚŝŶƚŚĞƌĞŐƵůĂƚŝŽŶƐ͘ tĞůůďŽƌĞEŽƚĞƐ͗ x DĂŐŶĂƌĂŶŐĞďƌŝĚŐĞƉůƵŐƐĞƚŝŶƚƵďŝŶŐĂƚϲ͕ϳϰϴ͛ x ƵƌƌĞŶƚdͬ/ͬKͬKKʹϴϬͬϲϴϬͬϰϴͬϬƉƐŝ x dŽƉŽĨWŽŽůƉĞƌKϲϴʹϯ͕ϴϴϵ͛ x WƌŽƉŽƐĞĚǁŚŝƉƐƚŽĐŬĚĞǀŝĂƚŝŽŶʹϰϱĚĞŐ WƌĞͲƌŝŐǁŽƌŬ͗ ϭ͘ D/ZhůŝŶĞ͗Z/,ĂŶĚƐĞƚϰͲϭͬϮ͟/WĂƚΕϰ͕ϯϬϳ͛;ŝŶƉĂĐŬĞƌͿ Ϯ͘ &ůƵŝĚƉĂĐŬǁĞůůƚƵďŝŶŐĂŶĚ/ǁŝƚŚǁĂƚĞƌ ϯ͘ D/dͲĐĂƐŝŶŐƚŽϮ͕ϱϬϬƉƐŝĂŶĚĐŚĂƌƚĨŽƌϯϬŵŝŶƵƚĞƐ ϰ͘ WhƚƵďŝŶŐƉƵŶĐŚ͕Z/,ĂŶĚƉƵŶĐŚƚƵďŝŶŐΕϰ͕ϯϬϬ͛;ĂďŽǀĞƉĂĐŬĞƌͿ ϱ͘ WƵŵƉǁĂƚĞƌĚŽǁŶƚƵďŝŶŐƚĂŬŝŶŐƌĞƚƵƌŶƐŝŶĂŶŶƵůƵƐƚŽĞƐƚĂďůŝƐŚ ĐŽŵŵƵŶŝĐĂƚŝŽŶ ϲ͘ Z/,ǁŝƚŚƉŽƉƉĞƚƐƚǇůĞĐĞŵĞŶƚƌĞƚĂŝŶĞƌĂŶĚƐĞƚΕϰ͕Ϯϵϳ͛;ϯ͛ĂďŽǀĞƚƵďŝŶŐƉƵŶĐŚĞƐͿ ϳ͘ WƵŵƉǁĂƚĞƌĚŽǁŶƚƵďŝŶŐ;ĞŶƐƵƌĞŐŽŽĚĨůŽǁͿĂŶĚƉƌĞƐƐƵƌĞƵƉĂŶŶ ƵůƵƐƚŽĞŶƐƵƌĞƌĞƚĂŝŶĞƌŝƐ ǁŽƌŬŝŶŐƉƌŽƉĞƌůǇ ϴ͘ Z/,ǁŝƚŚĐĞŵĞŶƚĚƵŵƉďĂŝůĞƌĂŶĚĚƵŵƉϲϵŐĂůŽĨĐĞŵĞŶƚ; ¾ŶŶƵůƵƐǀŽůƵŵĞͲϬ͘ϬϮϲϮďďůͬĨƚǆϲϬĨƚсϲϲŐĂůŽĨĐĞŵĞŶƚ ¾dƵďŝŶŐǀŽůƵŵĞͲϬ͘ϬϭϱϮďďůͬĨƚǆϱĨƚсϯŐĂůŽĨĐĞŵĞŶƚ ϵ͘ WƵŵƉŝŶƚŽƚƵďŝŶŐǁŝƚŚǁĂƚĞƌ;ϭ͘ϱyĐĞŵĞŶƚǀŽůƵŵĞͿ͕ƚĂŬŝŶŐƌĞƚƵƌŶƐŽƵƚĂŶŶƵůƵƐ;ĚŝƐƉůĂĐŝŶŐ ĐĞŵĞŶƚƚŚƌŽƵŐŚƌĞƚĂŝŶĞƌĂŶĚŝŶƚŽĂŶŶƵůƵƐͿ This is across PBR Must have enough cement to have minimum 25 ft of cement above PBR, logged with CBL. - bjm Approved. Plug will be set ~145' above top perf per base plan. - bjm tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůů͗EŽƌƚŚŽŽŬ/ŶůĞƚͲϭϬ ĂƚĞ͗ϯͬϭϯͬϮϬϮϮ ϭϬ͘ tK͕Z/,ĂŶĚƚĂŐĐĞŵĞŶƚͬƌĞƚĂŝŶĞƌ͘>ŽŐĐĞŵĞŶƚŽƵƚƐŝĚĞƚƵďŝŶŐǁŝƚŚĐĞŵĞŶƚďŽŶĚůŽŐĂŶĚ ƚĞŵƉƚŽŽů͘dŽƉŽĨĐĞŵĞŶƚŽŶĂŶŶƵůƵƐƐŚŽƵůĚďĞΕϰ͕Ϯϯϳ͛͘ ϭϭ͘ WƌŽǀŝĚĞ>ƚŽK'ƚŽĐŽŶĨŝƌŵϮϱ͛ĐĞŵĞŶƚŽŶŽƵƚƐŝĚĞŽĨƚƵďŝŶŐ ŽŶƚŝŶŐĞŶĐǇ;ŝĨĐĂŶŶŽƚƐŚŽǁϮϱĨƚŽĨĐĞŵĞŶƚŽƵƚƐŝĚĞƚƵďŝŶŐͿ͘^ĞĞĐŽŶƚŝŶŐĞŶĐǇƉƌŽĐĞĚƵƌĞ ϭϮ͘ WůĂĐĞϮϱĨƚŽĨĐĞŵĞŶƚŝŶƐŝĚĞƚƵďŝŶŐĂĐƌŽƐƐƚŚĞƐĂŵĞŝŶƚĞƌǀĂůĐĞŵĞŶƚůŽŐŐĞĚǁŝƚŚ>͘ĚĚ ĂĚĚŝƚŝŽŶĂůĐĞŵĞŶƚĂƐŶĞĞĚĞĚƚŽĞŶƐƵƌĞƚŚĞƌĞŝƐϮϱĨƚŽĨĐĞŵĞŶƚŝŶƚŚĞƐĂŵĞŝŶƚĞƌǀĂůŝŶƐŝĚĞ ƚƵďŝŶŐĂƐŝŶĂŶŶƵůƵƐ͘ ϭϯ͘ D/dͲdĂŶĚD/dͲ/ƚŽϭ͕ϱϬϬƉƐŝ͘;WƌŽǀŝĚĞϰϴŚƌƐŶŽƚŝĐĞĨŽƌK'ǁŝƚŶĞƐƐͲD/d͛ƐͿ ϭϰ͘ Z/,ǁůŝŶĞĂŶĚƚĂŐdKŝŶƚƵďŝŶŐ;ĐŽƌƌĞůĂƚĞĚƚŽ>Ϳ ϭϱ͘ Z/,ĂŶĚĐƵƚƚƵďŝŶŐΕϰ͕ϭϬϬ͛;ǀĞƌŝĨǇĚĞƉƚŚǁŝƚŚĞŶŐŝŶĞĞƌďĞĨŽƌĞĐƵƚƚŝŶŐƉĞŶĚŝŶŐŚŽǁŵƵĐŚ ĐĞŵĞŶƚǁĂƐƵƐĞĚƚŽƉůƵŐďĂĐŬĂŶĚǁŚŝƉƐƚŽĐŬǁŝůůďĞƐĞƚŽŶƚƵďŝŶŐƐƚƵď͘Ϳ ZŝŐWƌŽĐĞĚƵƌĞ͗ ϭϲ͘ D/Zh^ƉĂƌƚĂŶϭϱϭ ϭϳ͘ /ŶƐƚĂůůdt͕EƚƌĞĞ͕EhKW ϭϴ͘ dĞƐƚKW ¾dĞƐƚKWƚŽ ϮϱϬͬϯϬϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘dĞƐƚĂŶŶƵůĂƌƚŽϮϱϬͬϮϱϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘ ;EŽƚŝĨǇK'ϰϴŚŽƵƌƐŝŶĂĚǀĂŶĐĞŽĨƚĞƐƚƚŽĂůůŽǁƚŚĞŵƚŽǁŝƚŶĞƐƐƚĞƐƚͿ͘ ¾ŶƐƵƌĞƚŽůĞĂǀĞ͟͞ƐĞĐƚŝŽŶƐŝĚĞŽƵƚůĞƚǀĂůǀĞƐŽƉĞŶĚƵƌŝŶŐKWƚĞƐƚŝŶŐƐŽƉƌĞƐƐƵƌĞ ĚŽĞƐŶŽƚďƵŝůĚƵƉďĞŶĞĂƚŚƚŚĞdt͘ŽŶĨŝƌŵƚŚĞĐŽƌƌĞĐƚǀĂůǀĞƐĂƌĞŽƉĞŶĞĚ͊͊͊ ¾dĞƐƚsZƐŽŶϰ͘ϱ͟ƚĞƐƚũŽŝŶƚ;ϯϬϬϬƚĞƐƚŽŶůĂƌŐĞƐƚĂŶĚƐŵĂůůĞƐƚWͿ͕ ¾ŶƐƵƌĞŐĂƐŵŽŶŝƚŽƌƐĂƌĞĐĂůŝďƌĂƚĞĚĂŶĚƚĞƐƚĞĚŝŶĐŽŶũƵŶĐƚŝŽŶǁͬKW͘ ¾/ĨƚŚĞKWŝƐƵƐĞĚƚŽƐŚƵƚŝŶŽŶƚŚĞǁĞůůŝŶĂǁĞůůĐŽŶƚƌŽůƐŝƚƵĂƚŝŽŶŽƌŝĨKW ĞƋƵŝƉŵĞŶƚĐŽƵůĚďĞĐŽŵƉƌŽŵŝƐĞĚ͕>>KWĐŽŵƉŽŶĞŶƚƐƵƚŝůŝǌĞĚĨŽƌǁĞůůĐŽŶƚƌŽůŽƌ ĐŽŵƉƌŽŵŝƐĞĚŵƵƐƚďĞƚĞƐƚĞĚƉƌŝŽƌƚŽƚŚĞŶĞǆƚƚƌŝƉŝŶƚŽƚŚĞǁĞůůďŽƌĞ͘ ϭϵ͘ WƵůůdt ϮϬ͘ WƵůůŚĂŶŐĞƌĂŶĚ>Εϰ͕ϭϬϬ͛ŽĨϰͲϭͬϮ͟ƚƵďŝŶŐ ¾ϰͲϭͬϮ͟hŚĂŶŐĞƌƚŚƌĞĂĚƐ ¾ϰϭϰĨƚŽĨϰͲϭͬϮ͟/dͲDƚƵďŝŶŐ ¾ĂŵĐŽϰͲϭͬϮ͟dZDͲϰWdZ^^^sΛϰϭϰ͛;ƌĞĐŽǀĞƌĂŶĚƐĞŶĚŝŶĨŽƌŝŶƐƉĞĐƚŝŽŶͿ ¾ϯĞĂϰͲϭͬϮ͟ĂŵĐŽ'>DŵĂŶĚƌĞůƐ ¾Εϯ͕ϲϴϲĨƚŽĨϰͲϭͬϮ͟/dͲDƚƵďŝŶŐ Ϯϭ͘ ^ĞƚǁĞĂƌďƵƐŚŝŶŐŝŶǁĞůůŚĞĂĚ͘ŶƐƵƌĞ/ŽĨǁĞĂƌďƵƐŚŝŶŐхϲͲϯͬϰ͟ ϮϮ͘ WhĐůĞĂŶŽƵƚĂƐƐĞŵďůǇ͕ďŝƚĂŶĚƐĐƌĂƉĞƌĂŶĚWƚŽцϯ͕ϭϬϬ͛ Ϯϯ͘ Whϳ͟/WĂŶĚZ/,ƚŽΕϯ͕ϬϯϬ͛ǁŝƚŚW Ϯϰ͘ DĂŬĞƵƉƚŚĞt/^ϳ͟ǁŚŝƉƐƚŽĐŬ Ϯϱ͘ d/,ǁŝƚŚWƚŽƚŚĞǁŚŝƉƐƚŽĐŬƐĞƚƚŝŶŐĚĞƉƚŚ͘ǆĞƌĐŝƐĞĐĂƵƚŝŽ ŶǁŚĞŶZ/,ͬƐĞƚƚŝŶŐƐůŝƉƐǁŝƚŚ ǁŚŝƉƐƚŽĐŬĂƐƐĞŵďůǇ CBL must show at least 25' of cement above PBR. - bjm tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůů͗EŽƌƚŚŽŽŬ/ŶůĞƚͲϭϬ ĂƚĞ͗ϯͬϭϯͬϮϬϮϮ ¾&ŝůůƚŚĞĚƌŝůůƉŝƉĞĂŵŝŶŝŵƵŵŽĨĞǀĞƌǇϮϬƐƚĂŶĚƐŽŶƚŚĞƚƌŝƉŝŶƚŚĞŚŽůĞǁŝƚŚƚŚĞ ǁŚŝƉƐƚŽĐŬĂƐƐĞŵďůǇ͘tŝƚŚ&/t͘ ¾ǀŽŝĚƐƵĚĚĞŶƐƚĂƌƚƐĂŶĚƐƚŽƉƐǁŚŝůĞƌƵŶŶŝŶŐƚŚĞǁŚŝƉƐƚŽĐŬ͘ ¾ZĞĐŽŵŵĞŶĚƌƵŶŶŝŶŐŝŶƚŚĞŚŽůĞĂƚĂ ŵĂǆŝŵƵŵŽĨϵϬͲϭϮϬƐĞĐŽŶĚƐƉĞƌƐƚĂŶĚ ƚĂŬŝŶŐ ĐĂƌĞŶŽƚƚŽƐƉƵĚŽƌĐĂƚĐŚƚŚĞƐůŝƉƐ͘ŶƐƵƌĞƌƵŶŶŝŶŐƐƚƌŝŶŐŝƐƐƚĂƚŝŽŶĂƌǇƉƌŝŽƌƚŽ ŝŶƐĞƌƚŝŽŶŽĨƚŚĞƐůŝƉƐĂŶĚƚŚĂƚƐůŝƉƐĂƌĞƌĞŵŽǀĞĚƐůŽǁůǇǁŚĞŶƌ ĞůĞĂƐŝŶŐƚŚĞǁŽƌŬ ƐƚƌŝŶŐƚŽZ/,͘dŚĞƐĞƉƌĞĐĂƵƚŝŽŶƐĂƌĞƌĞƋƵŝƌĞĚƚŽĂǀŽŝĚĂŶǇǁĞĂŬĞŶŝŶŐŽĨƚŚĞ ǁŚŝƉƐƚŽĐŬƐŚĞĂƌŵĞĐŚĂŶŝƐŵƐĂŶĚͬŽƌƚŽĂǀŽŝĚƉĂƌƚͬƉƌĞƐĞƚŽŶƚŚĞƉĂĐŬĞƌ͘ Ϯϲ͘KƌŝĞŶƚǁŚŝƉƐƚŽĐŬĂƐĚŝƌĞĐƚĞĚďǇƚŚĞĚŝƌĞĐƚŝŽŶĂůĚƌŝůůĞƌ͘dŚĞĚŝƌĞĐƚŝŽŶĂůƉůĂŶƐƉĞĐŝĨŝĞƐ ϴϬĚĞŐ ZK,^ Ϯϳ͘ ^ĞƚƚŚĞƚŽƉŽĨƚŚĞǁŚŝƉƐƚŽĐŬĂƚΕϯ͕ϬϭϬ͛D Ϯϴ͘ ŝƌĐƵůĂƚĞŽƵƚ&/tǁĞůůǁŝƚŚ>^EŵƵĚ ΎΎΎZĞŵĂŝŶŝŶŐWƌŽĐĞĚƵƌĞƚŽďĞŝŶĐůƵĚĞĚŽŶƚŚĞWĞƌŵŝƚƚŽƌŝůůĨŽƌƚŚĞƌĞĚƌŝůůƐƚĂƌƚŝŶŐĂƚƐĞĐƚŝŽŶϭϯ͘ϳΎΎΎ ŽŶƚŝŶŐĞŶĐǇWƌŽĐĞĚƵƌĞ&ƌŽŵƐƚĞƉϭϭ͘ ĂͿ Wh/W͕Z/,ĂŶĚƐĞƚĂƚΕϰ͕ϮϮϬ͛;ĂďŽǀĞ'>DηϰͿ ďͿ WhƚƵďŝŶŐƉƵŶĐŚ͕Z/,ĂŶĚƚĂŐ/W͕WhĂŶĚƉƵŶĐŚƚƵďŝŶŐĂƚΕϰ͕Ϯϭϳ͛Ͳϰ͕Ϯϭϰ͛ ĐͿ WƵŵƉǁĂƚĞƌĚŽǁŶƚƵďŝŶŐƚĂŬŝŶŐƌĞƚƵƌŶƐŝŶĂŶŶƵůƵƐƚŽĞƐƚĂďůŝƐŚ ĐŽŵŵƵŶŝĐĂƚŝŽŶ ĚͿ Z/,ĂŶĚƐĞƚĞŵĞŶƚƌĞƚĂŝŶĞƌĂƚϰ͕ϭϭϬ͛͘ ĞͿ dĞƐƚƌĞƚĂŝŶĞƌ͕ƉƵŵƉďŽƚŚĚŝƌĞĐƚŝŽŶƐ ĨͿ ZhĐĞŵĞŶƚŚŽƉƉĞƌĂŶĚŵŝǆϰďďůƐŽĨĐĞŵĞŶƚ ŐͿ WƵŵƉĐĞŵĞŶƚĚŽǁŶƚƵďŝŶŐƚĂŬŝŶŐƌĞƚƵƌŶƐƵƉƚŚĞϰͲϭͬϮǆϳͲϱͬϴ͟/ ŚͿ WůĂŶŶĞĚdKŝŶ/ŝƐϰ͕Ϭϲϳ͛;ϭϱϬĨƚĂďŽǀĞƉƵŶĐŚĞƐͿ ŝͿ ŝƐƉůĂĐĞƉĞƌK ũͿ ^/DĂƐƚĞƌǀĂůǀĞĂŶĚ/ĂŶĚƚƌĂƉƉƌĞƐƐƵƌĞŽŶƚŚĞƚƵďŝŶŐ͕tK ŬͿ Z/,ĂŶĚƚĂŐĐĞŵĞŶƚŝŶƚƵďŝŶŐ͘>ŽŐĐĞŵĞŶƚŽƵƚƐŝĚĞƚƵďŝŶŐǁŝƚŚ ĐĞŵĞŶƚďŽŶĚůŽŐĂŶĚƚĞŵƉƚŽŽů͘ dŽƉŽĨĐĞŵĞŶƚŽŶĂŶŶƵůƵƐƐŚŽƵůĚďĞΕϰ͕Ϭϲϳ͛ ůͿ WƌŽǀŝĚĞ>ƚŽK'ƚŽĐŽŶĨŝƌŵĐĞŵĞŶƚŽŶŽƵƚƐŝĚĞŽĨƚƵďŝŶŐ ŵͿ WůĂĐĞϮϱĨƚŽĨĐĞŵĞŶƚŝŶƐŝĚĞƚƵďŝŶŐĂĐƌŽƐƐƚŚĞĐĞŵĞŶƚŝŶƚŚĞĂŶŶƵůƵƐ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ tĞůů^ĐŚĞŵĂƚŝĐƵƌƌĞŶƚ Ϯ͘ tĞůů^ĐŚĞŵĂƚŝĐWƌŽƉŽƐĞĚ ϯ͘ tĞůůŚĞĂĚ^ĐŚĞŵĂƚŝĐ ϰ͘ KWƌĂǁŝŶŐʹ^ƉĂƌƚĂŶZŝŐϭϱϭ ϱ͘ ZtK^ƵŶĚƌǇŚĂŶŐĞ&Žƌŵ ϲ͘ tĞůů^ĐŚĞŵĂƚŝĐWƌŽƉŽƐĞĚ;ŽŶƚŝŶŐĞŶĐǇͿ 23. Pressure test 7" casing to 2200 psi and chart for 30 minutes. - bjm Contingency A is not approved. - bjm Follow steps 13-15 in base plan, with tubing cut depth above new TOC in annulus. BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇDϬϮͲϬϮͲϮϮ ^,Dd/ dǇŽŶĞŬWůĂƚĨŽƌŵ tĞůů͗ͲϭϬ >ĂƐƚŽŵƉůĞƚĞĚ͗ϵͬϱͬϮϬϬϯ Wd͗ϮϬϯͲϬϳϱ W/͗ ϱϬͲϴϴϯͲϮϬϬϯϬͲϬϭͲϬϬ Wd͗ϲ͕ϳϰϴ͛;DͿ d͗ϴ͕ϴϰϬ͛;DͿ ´ Z<ƚŽd',ĞĂĚʹϰϯ͘ϴ͛ ´ ´ ͟ ϭϴ ´ ZLQGRZ# ¶ ϭϲ ; ; ^/E'd/> ^ŝǌĞ tƚ 'ƌĂĚĞ ŽŶŶ / dŽƉ ƚŵ ϯϬ͟ ϭϮϬ͘Ϭ ,ͲϰϬ t> Ϯϳ͟ ϰϭ͛ ϯϲϲ͛ ϭϲ͟ ϲϮ͘ϱ ,ͲϰϬ t> ϭϱ͘ϬϲϮ͟ ϰϭ͛ ϲϯϭ͛ ϭϬͲϯͬϰ͟ ϰϬ͘ϱ :Ͳϱϱ d ϭϬ͘ϬϱϬ͟ ϰϭ͛ ϭ͕ϲϵϱ͛ ϭϬͲϯͬϰ͟ ϰϱ͘ϱ :Ͳϱϱ d ϵ͘ϵϱϬ͟ ϭ͕ϲϵϱ͛ ϭ͕ϵϭϭ͛ ϳͲϱͬϴ͟ Ϯϵ͘ϳ >ͲϴϬ d ϲ͘ϴϳϱ͟ ϰϰ͛ ϴ͕ϴϯϬΖ dh/E'd/> ϰͲϭͬϮ͟ ϭϮ͘ϲ >ͲϴϬ /dͲŵŽĚ ϯ͘ϵϱϴ͟ ϰϯ͘ϴ͛ ϳ͕ϳϲϰ͛ ϯͲϭͬϮ͟ ϵ͘ϯ >ͲϴϬ /dͲŵŽĚ ϳ͕ϳϲϱ͛ ϳ͕ϵϳϮ͛ 'Zs>W< ϰ͟ ϵ͘ϱ >ͲϴϬ /dͲŵŽĚ ϯ͘ϱϰϴ͟ ϰ͕ϲϵϰ͛ ϳ͕ϱϲϰ͛ :t>Zzd/> EŽ ĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ / K /ƚĞŵ ϭ ϰϭϰ͛ ϰϭϰ͛ ϯ͘ϴϭϯ ϲ͘ϬϬϬ ^ĂĨĞƚǇsĂůǀĞ͕ĂŵĐŽϰͲϭͬϮ͟dZDͲϰW&dZ^^^s Ϯ ϭ͕ϯϱϲ͛ ϭ͕ϯϯϲ͛ ϯ͘ϴϲϱ ϲ͘Ϭϱϵ '>Dη͕ϭĂŵĐŽ<'ͲϮ͕<ůĂƚĐŚ͕WŽƌƚсϬ͘ϭϴϴ͕͟ dZKсϭϯϳϱƉƐŝ ϯ Ϯ͕ϯϵϴ͛ Ϯ͕Ϯϲϴ͛ ϯ͘ϴϲϱ ϲ͘Ϭϱϵ '>DηϮĂŵĐŽ<'ͲϮ͕<ůĂƚĐŚ͕WŽƌƚсϬ͘ϭϴϴ͕͟ dZKсϭϯϳϱƉƐŝ ϰ ϯ͕ϯϴϲ͛ Ϯ͕ϵϱϭ͛ ϯ͘ϴϲϱ ϲ͘Ϭϱϵ '>DηϯĂŵĐŽ<'ͲϮ͕<ůĂƚĐŚ͕WŽƌƚсϬ͘ϭϴϴ͕͟ dZKсϭϯϳϱƉƐŝ ϱ ϰ͕ϮϮϭ͛ ϯ͘ϴϲϱ ϲ͘Ϭϱϵ '>Dηϰ͕ĂŵĐŽ<'ͲϮ͕<ůĂƚĐŚ ϲ ϰ͕Ϯϳϳ͛ ϯ͕ϱϱϱ͛ ϯ͘ϵϱϴ ϱ͘ϱϲϯ WZϴϬͲϰϳ͕ϭϱ͛ƐĞĂůƚƌĂǀĞů ϳ ϰ͕ϯϬϳ͛ ϯ͕ϱϳϱ͛ ϯ͘ϴϳϱ ϲ͘ϱϬϬ WĂĐŬĞƌ͕ĂŬĞƌWƌĞŵŝĞƌ ϴ ϰ͕ϲϲϱ͛ ϯ͕ϴϭϳ͛ ϯ͘ϴϭϯ ϱ͘ϱϬϬ ^ůĞĞǀĞ͕ĂŬĞƌDh^ůŝĚŝŶŐ͕>K^ ϵ ϰ͕ϳϬϴ͛ ϯ͕ϴϰϱ͛ ϯ͘ϮϴϬ ϰ͘Ϯϭϴ ŶĐŚŽƌ>ĂƚĐŚ͕ĂŬĞƌ^ͲϮϮ ϭϬ ϰ͕ϳϬϵ͛ ϯ͕ϴϰϲ͛ ϰ͘ϬϬϬ ϲ͘ϰϵϬ WĂĐŬĞƌ͕ĂŬĞƌ^ͲϮ ϰ͕ϳϵϵ͛ ϯ͕ϵϬϲ͛ ϯ͘ϱϰϴ ϰ͘ϱϵϬ ^ĐƌĞĞŶ͕ĂŬĞƌǁĞůĚ͕͘ϬϭϮŐĂ͘ ϭϭ ϱ͕Ϭϭϳ͛ ϰ͕Ϭϰϵ͛ ϯ͘ϮϱϬ ϲ͘ϰϵϬ WĂĐŬĞƌ͕ĂŬĞƌ^Ͳϭ>DƵůƚŝǌŽŶĞ ϭϮ ϱ͕ϲϭϭ͛ ϰ͕ϰϯϲ͛ ϯ͘ϮϱϬ ϲ͘ϰϵϬ WĂĐŬĞƌ͕ĂŬĞƌ^Ͳϭ>DƵůƚŝǌŽŶĞ ϱ͕ϲϳϮ͛ ϰ͕ϰϯϲ͛ ϯ͘ϱϰϴ ϰ͘ϱϵϬ ^ĐƌĞĞŶ͕ĂŬĞƌǁĞůĚ͕͘ϬϭϮŐĂ͘ ϭϯ ϲ͕ϮϬϴ͛ ϰ͕ϴϱϰ͛ ϯ͘ϮϴϬ ϰ͘Ϯϭϴ ^ŶĂƉ>ĂƚĐŚ͕ĂŬĞƌ^ͲϮϮ ϭϰ ϲ͕ϮϬϵ͛ ϰ͕ϴϱϰ͛ ϰ͘ϬϬϬ ϲ͘ϰϵϬ WĂĐŬĞƌ͕ĂŬĞƌ^ͲϮ ϲ͕Ϯϵϯ͛ ϰ͕ϵϭϱ͛ ϯ͘ϱϰϴ ϰ͘ϱϵϬ ^ĐƌĞĞŶ͕ĂŬĞƌǁĞůĚ͕͘ϬϭϮŐĂ ϭϱ ϲ͕ϳϭϲ͛ ϱ͕ϮϯϬ͛ ϯ͘ϮϱϬ ϲ͘ϰϵϬ WĂĐŬĞƌ͕ĂŬĞƌ^Ͳϭ>DƵůƚŝǌŽŶĞ ϲ͕ϳϰϴ͛ ϱ͕Ϯϱϱ͛ DĂŐŶĂZĂŶŐĞWůƵŐ;ϭϮͬϮͬϮϭͿ ϲ͕ϴϭϰ͛ ϱ͕ϯϬϰ͛ ϯ͘ϱϰϴ ϰ͘ϱϵϬ ^ĐƌĞĞŶ͕ĂŬĞƌǁĞůĚ͕͘ϬϭϮŐĂ ϭϲ ϳ͕ϭϴϭ͛ ϱ͕ϱϴϭ͛ ϯ͘ϮϱϬ ϲ͘ϰϵϬ WĂĐŬĞƌ͕ĂŬĞƌ^Ͳϭ>DƵůƚŝǌŽŶĞ ϳ͕Ϯϲϰ͛ ϱ͕ϲϰϯ͛ ϯ͘ϱϰϴ ϰ͘ϱϵϬ ^ĐƌĞĞŶ͕ĂŬĞƌǁĞůĚ͕͘ϬϭϮŐĂ ϭϳ ϳ͕ϱϲϰ͛ ϱ͕ϴϲϲ͛ ϯ͘ϮϴϬ ϰ͘Ϯϭϴ ^ŶĂƉ>ĂƚĐŚ͕ĂŬĞƌ^ͲϮϮ ϭϴ ϳ͕ϱϲϱ͛ ϱ͕ϴϲϲ͛ ϰ͘ϬϬϬ ϲ͘ϱϬϬ WĂĐŬĞƌ͕ĂŬĞƌ&Ͳϭ^ƵŵƉWĂĐŬĞƌ ϭϵ ϳ͕ϳϲϰ͛ ϲ͕Ϭϭϵ͛ ϯ͘ϵϰϬ ϱ͘ϯϳϱ yK͕ϰ͘ϱyϯ͘ϱ ϮϬ ϳ͕ϳϵϳ͛ ϲ͕Ϭϰϰ͛ Ϯ͘ϴϭϯ ϰ͘ϮϱϬ EŝƉƉůĞ͕y Ϯϭ ϳ͕ϴϯϬ͛ ϲ͕ϬϳϬ͛ ϯ͘ϱϰϴ ϱ͘ϬϮϬ ^ĐƌĞĞŶ͕^>,dǆĐůƵĚĞƌ ϮϮ ϳ͕ϵϯϴ͛ ϲ͕ϭϱϯ͛ Ϯ͘ϴϭϯ ϰ͘ϮϱϬ EŝƉƉůĞ͕y Ϯϯ ϳ͕ϵϳϬ͛ ϲ͕ϭϳϴ͛ Ϯ͘ϵϵϮ ϯ͘ϴϬϬ tŝƌĞůŝŶĞŶƚƌǇ'ƵŝĚĞ EŽƚĞ͗ϵͬϯͬϮϬϬϯdŚƌĞĞZĂĚŝŽĂĐƚŝǀĞ;ZͿϳͲϱͬϴ͟ĐĂƐŝŶŐĐŽƵƉůŝŶŐƐΛϰϯϲϲ͕͛ϱϴϳϵ͛ΘϳϰϱϬ͛ EŽƚĞ͗ϵͬϯͬϮϬϬϯZĂĚŝŽĂĐƚŝǀĞ;ZͿĐŽůůĂƌƐΛϱϴϭ͕͛ϲϬϭϭ͕͛ϲϯϵϲ͕͛ϲϵϬϳ͛Θϳϯϳϳ͛ EŽƚĞ͗ϬϳͬϬϮͬϮϭʹZ/,ǁͬϮͲϭͬϴ͟ŶŽǌǌůĞĨŽƌĚƌǇƚĂŐƚŽϳ͕ϵϳϬ͛Z< ^,Dd/ hƉĚĂƚĞĚǇDϬϮͲϬϮͲϮϮ dǇŽŶĞŬWůĂƚĨŽƌŵ tĞůů͗ͲϭϬ >ĂƐƚŽŵƉůĞƚĞĚ͗ϵͬϱͬϮϬϬϯ Wd͗ϮϬϯͲϬϳϱ W/͗ϱϬͲϴϴϯͲϮϬϬϯϬͲϬϭͲϬϬ WZ&KZd/KEd/> ŽŶĞ dŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ ŵƚ ƐƉĨ ŽŵŵĞŶƚƐ ^ƚĞƌůŝŶŐ ϰ͕ϰϭϱ͛ ϰ͕ϰϮϴ͛ ϯ͕ϲϰϴ͛ ϯ͕ϲϱϲ͛ ϭϯ͛ ϵͬϭϱͬϮϬϬϯdW'ƵŶƐ /Ͳϰ͕ϰϱϰ͛ ϰ͕ϰϴϳ͛ ϯ͕ϲϳϰ͛ ϯ͕ϲϵϳ͛ ϯϯ͛ ϵͬϭϱͬϮϬϬϯdW'ƵŶƐ /Ͳϭ ϰ͕ϴϬϱ͛ ϰ͕ϵϬϱ͛ ϯ͕ϵϭϬ͛ ϯ͕ϵϳϲ͛ ϭϬϬ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ /ͲϮ ϰ͕ϵϮϬ͛ ϱ͕ϬϬϱ͛ ϯ͕ϵϴϱ͛ ϰ͕Ϭϰϭ͛ ϴϱ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ /ͲϭϬ ϱ͕ϲϴϱ͛ ϱ͕ϳϬϬ͛ ϰ͕ϰϴϲ͛ ϰ͕ϰϵϲ͛ ϭϱ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ ϱ͕ϴϵϰ͛ ϱ͕ϵϭϰ͛ ϰ͕ϲϮϵ͛ ϰ͕ϲϰϯ͛ ϮϬ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ ϲ͕ϬϵϬ͛ ϲ͕ϭϬϱ͛ ϰ͕ϳϲϵ͛ ϰ͕ϳϳϵ͛ ϭϱ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ ϲ͕ϭϴϱ͛ ϲ͕ϭϵϱ͛ ϰ͕ϴϯϳ͛ ϰ͕ϴϰϰ͛ ϭϬ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ ϲ͕ϯϬϬ͛ ϲ͕ϯϭϬ͛ ϰ͕ϵϮϭ͛ ϰ͕ϵϮϴ͛ ϭϬ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ ϲ͕ϰϱϬ͛ ϲ͕ϱϮϱ͛ ϱ͕Ϭϯϭ͛ ϱ͕Ϭϴϲ͛ ϳϱ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ ϲ͕ϲϰϲ͛ ϲ͕ϲϲϱ͛ ϱ͕ϭϳϳ͛ ϱ͕ϭϵϭ͛ ϭϵ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ& ϲ͕ϲϴϱ͛ ϲ͕ϳϭϬ͛ ϱ͕ϮϬϳ͛ ϱ͕ϮϮϲ͛ Ϯϱ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ' ϲ͕ϴϮϱ͛ ϲ͕ϴϲϱ͛ ϱ͕ϯϭϯ͛ ϱ͕ϯϰϯ͛ ϰϬ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ, ϳ͕ϬϭϬ͛ ϳ͕ϬϮϴ͛ ϱ͕ϰϱϮ͛ ϱ͕ϰϲϲ͛ ϭϴ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ/ ϳ͕ϭϲϱ͛ ϳ͕ϭϳϱ͛ ϱ͕ϱϲϵ͛ ϱ͕ϱϳϳ͛ ϭϬ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ: ϳ͕ϮϳϬ͛ ϳ͕ϮϴϬ͛ ϱ͕ϲϰϳ͛ ϱ͕ϲϱϱ͛ ϭϬ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ>ϳ͕ϰϮϱ͛ ϳ͕ϰϱϬ͛ ϱ͕ϳϲϮ͛ ϱ͕ϳϴϭ͛ Ϯϱ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂD ϳ͕ϱϭϱ͛ ϳ͕ϱϱϱ͛ ϱ͕ϴϮϵ͛ ϱ͕ϴϱϵ͛ ϰϬ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂW ϳ͕ϴϯϬ͛ ϳ͕ϵϬϱ͛ ϲ͕ϬϳϬ͛ ϲ͕ϭϮϴ͛ ϳϱ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ,ϬϯͲϭϯͲϮϮ WZKWK^ dǇŽŶĞŬWůĂƚĨŽƌŵ tĞůů͗ͲϭϬ >ĂƐƚŽŵƉůĞƚĞĚ͗ϵͬϱͬϮϬϬϯ Wd͗ϮϬϯͲϬϳϱ W/͗ ϱϬͲϴϴϯͲϮϬϬϯϬͲϬϭͲϬϬ Wd͗ϲ͕ϳϰϴ͛;DͿ d͗ϴ͕ϴϰϬ͛;DͿ ´ Z<ƚŽd',ĞĂĚʹϰϯ͘ϴ͛ ´ % ' & ´ ͟ $ ϭϴ ´ ZLQGRZ# ¶ ϭϲ 72&¶ *RRGFPW #¶ ĞŵĞŶƚ ZĞƚĂŝŶĞƌΘ dƵďŝŶŐWƵŶĐŚ ' ; ; ^/E'd/> ^ŝǌĞ tƚ 'ƌĂĚĞ ŽŶŶ / dŽƉ ƚŵ ϯϬ͟ ϭϮϬ͘Ϭ ,ͲϰϬ t> Ϯϳ͟ ϰϭ͛ϯϲϲ͛ ϭϲ͟ ϲϮ͘ϱ ,ͲϰϬ t> ϭϱ͘ϬϲϮ͟ ϰϭ͛ ϲϯϭ͛ ϭϬͲϯͬϰ͟ ϰϬ͘ϱ :Ͳϱϱ d ϭϬ͘ϬϱϬ͟ ϰϭ͛ ϭ͕ϲϵϱ͛ ϭϬͲϯͬϰ͟ ϰϱ͘ϱ :Ͳϱϱ d ϵ͘ϵϱϬ͟ ϭ͕ϲϵϱ͛ ϭ͕ϵϭϭ͛ ϳͲϱͬϴ͟ Ϯϵ͘ϳ >ͲϴϬ d ϲ͘ϴϳϱ͟ ϰϰ͛ ϴ͕ϴϯϬΖ dh/E'd/> ϰͲϭͬϮ͟ ϭϮ͘ϲ >ͲϴϬ /dͲŵŽĚ ϯ͘ϵϱϴ͟цϰ͕ϭϬϬ͛ϳ͕ϳϲϰ͛ ϯͲϭͬϮ͟ ϵ͘ϯ >ͲϴϬ /dͲŵŽĚ ϳ͕ϳϲϱ͛ ϳ͕ϵϳϮ͛ 'Zs>W< ϰ͟ ϵ͘ϱ >ͲϴϬ /dͲŵŽĚ ϯ͘ϱϰϴ͟ ϰ͕ϲϵϰ͛ ϳ͕ϱϲϰ͛ :t>Zzd/> EŽ ĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ / K /ƚĞŵ цϯ͕ϬϭϬ͛ цϮ͕ϲϵϯ͛ tŚŝƉƐƚŽĐŬ цϯ͕ϬϯϬ͛ цϮ͕ϳϭϰ͛ /W ϱ ϰ͕ϮϮϭ͛ ϯ͘ϴϲϱ ϲ͘Ϭϱϵ '>DĂŵĐŽ<'ͲϮ͕<>ĂƚĐŚ ϲ ϰ͕Ϯϳϳ͛ ϯ͕ϱϱϱ͛ ϯ͘ϵϱϴ ϱ͘ϱϲϯ WZϴϬͲϰϳ͕ϭϱ͛ƐĞĂůƚƌĂǀĞů цϰ͕Ϯϵϳ͛ ϯ͘ϵϱϴ ĞŵĞŶƚZĞƚĂŝŶĞƌ цϰ͕ϯϬϬ͛ цϯ͕ϱϳϬ͛ ϯ͘ϵϱϴ /W ϳ ϰ͕ϯϬϳ͛ ϯ͕ϱϳϱ͛ ϯ͘ϴϳϱ ϲ͘ϱϬϬ WĂĐŬĞƌ͕ĂŬĞƌWƌĞŵŝĞƌ ϴ ϰ͕ϲϲϱ͛ ϯ͕ϴϭϳ͛ ϯ͘ϴϭϯ ϱ͘ϱϬϬ ^ůĞĞǀĞ͕ĂŬĞƌDh^ůŝĚŝŶŐ͕>K^͕ ϵ ϰ͕ϳϬϴ͛ ϯ͕ϴϰϱ͛ ϯ͘ϮϴϬ ϰ͘Ϯϭϴ ŶĐŚŽƌ>ĂƚĐŚ͕ĂŬĞƌ^ͲϮϮ ϭϬ ϰ͕ϳϬϵ͛ ϯ͕ϴϰϲ͛ ϰ͘ϬϬϬ ϲ͘ϰϵϬ WĂĐŬĞƌ͕ĂŬĞƌ^ͲϮ ϰ͕ϳϵϵ͛ ϯ͕ϵϬϲ͛ ϯ͘ϱϰϴ ϰ͘ϱϵϬ ^ĐƌĞĞŶ͕ĂŬĞƌǁĞůĚ͕͘ϬϭϮŐĂ͘ ϭϭ ϱ͕Ϭϭϳ͛ ϰ͕Ϭϰϵ͛ ϯ͘ϮϱϬ ϲ͘ϰϵϬ WĂĐŬĞƌ͕ĂŬĞƌ^Ͳϭ>DƵůƚŝǌŽŶĞ ϭϮ ϱ͕ϲϭϭ͛ ϰ͕ϰϯϲ͛ ϯ͘ϮϱϬ ϲ͘ϰϵϬ WĂĐŬĞƌ͕ĂŬĞƌ^Ͳϭ>DƵůƚŝǌŽŶĞ ϱ͕ϲϳϮ͛ ϰ͕ϰϯϲ͛ ϯ͘ϱϰϴ ϰ͘ϱϵϬ ^ĐƌĞĞŶ͕ĂŬĞƌǁĞůĚ͕͘ϬϭϮŐĂ͘ ϭϯ ϲ͕ϮϬϴ͛ ϰ͕ϴϱϰ͛ ϯ͘ϮϴϬ ϰ͘Ϯϭϴ ^ŶĂƉ>ĂƚĐŚ͕ĂŬĞƌ^ͲϮϮ ϭϰ ϲ͕ϮϬϵ͛ ϰ͕ϴϱϰ͛ ϰ͘ϬϬϬ ϲ͘ϰϵϬ WĂĐŬĞƌ͕ĂŬĞƌ^ͲϮ ϲ͕Ϯϵϯ͛ ϰ͕ϵϭϱ͛ ϯ͘ϱϰϴ ϰ͘ϱϵϬ ^ĐƌĞĞŶ͕ĂŬĞƌǁĞůĚ͕͘ϬϭϮŐĂ ϭϱ ϲ͕ϳϭϲ͛ ϱ͕ϮϯϬ͛ ϯ͘ϮϱϬ ϲ͘ϰϵϬ WĂĐŬĞƌ͕ĂŬĞƌ^Ͳϭ>DƵůƚŝǌŽŶĞ ϲ͕ϳϰϴ͛ ϱ͕Ϯϱϱ͛ DĂŐŶĂZĂŶŐĞWůƵŐ;ϭϮͬϮͬϮϭͿ ϲ͕ϴϭϰ͛ ϱ͕ϯϬϰ͛ ϯ͘ϱϰϴ ϰ͘ϱϵϬ ^ĐƌĞĞŶ͕ĂŬĞƌǁĞůĚ͕͘ϬϭϮŐĂ ϭϲ ϳ͕ϭϴϭ͛ ϱ͕ϱϴϭ͛ ϯ͘ϮϱϬ ϲ͘ϰϵϬ WĂĐŬĞƌ͕ĂŬĞƌ^Ͳϭ>DƵůƚŝǌŽŶĞ ϳ͕Ϯϲϰ͛ ϱ͕ϲϰϯ͛ ϯ͘ϱϰϴ ϰ͘ϱϵϬ ^ĐƌĞĞŶ͕ĂŬĞƌǁĞůĚ͕͘ϬϭϮŐĂ ϭϳ ϳ͕ϱϲϰ͛ ϱ͕ϴϲϲ͛ ϯ͘ϮϴϬ ϰ͘Ϯϭϴ ^ŶĂƉ>ĂƚĐŚ͕ĂŬĞƌ^ͲϮϮ ϭϴ ϳ͕ϱϲϱ͛ ϱ͕ϴϲϲ͛ ϰ͘ϬϬϬ ϲ͘ϱϬϬ WĂĐŬĞƌ͕ĂŬĞƌ&Ͳϭ^ƵŵƉWĂĐŬĞƌ ϭϵ ϳ͕ϳϲϰ͛ ϲ͕Ϭϭϵ͛ ϯ͘ϵϰϬ ϱ͘ϯϳϱ yK͕ϰ͘ϱyϯ͘ϱ ϮϬ ϳ͕ϳϵϳ͛ ϲ͕Ϭϰϰ͛ Ϯ͘ϴϭϯ ϰ͘ϮϱϬ EŝƉƉůĞ͕y Ϯϭ ϳ͕ϴϯϬ͛ ϲ͕ϬϳϬ͛ ϯ͘ϱϰϴ ϱ͘ϬϮϬ ^ĐƌĞĞŶ͕^>,dǆĐůƵĚĞƌ ϮϮ ϳ͕ϵϯϴ͛ ϲ͕ϭϱϯ͛ Ϯ͘ϴϭϯ ϰ͘ϮϱϬ EŝƉƉůĞ͕y Ϯϯ ϳ͕ϵϳϬ͛ ϲ͕ϭϳϴ͛ Ϯ͘ϵϵϮ ϯ͘ϴϬϬ tŝƌĞůŝŶĞŶƚƌǇ'ƵŝĚĞ EŽƚĞ͗ϵͬϯͬϮϬϬϯdŚƌĞĞZĂĚŝŽĂĐƚŝǀĞ;ZͿϳͲϱͬϴ͟ĐĂƐŝŶŐĐŽƵƉůŝŶŐƐΛϰϯϲϲ͕͛ϱϴϳϵ͛ΘϳϰϱϬ͛ EŽƚĞ͗ϵͬϯͬϮϬϬϯZĂĚŝŽĂĐƚŝǀĞ;ZͿĐŽůůĂƌƐΛϱϴϭ͕͛ϲϬϭϭ͕͛ϲϯϵϲ͕͛ϲϵϬϳ͛Θϳϯϳϳ͛ EŽƚĞ͗ϬϳͬϬϮͬϮϭʹZ/,ǁͬϮͲϭͬϴ͟ŶŽǌǌůĞĨŽƌĚƌǇƚĂŐƚŽϳ͕ϵϳϬ͛Z< Verified TOC outside 7-5/8" csg at 2618' MD, CBL 3Sep03. - bjm WZKWK^ hƉĚĂƚĞĚǇ,ϬϯͲϭϯͲϮϮ dǇŽŶĞŬWůĂƚĨŽƌŵ tĞůů͗ͲϭϬ >ĂƐƚŽŵƉůĞƚĞĚ͗ϵͬϱͬϮϬϬϯ Wd͗ϮϬϯͲϬϳϱ W/͗ϱϬͲϴϴϯͲϮϬϬϯϬͲϬϭͲϬϬ WZ&KZd/KEd/> ŽŶĞ dŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ ŵƚ ƐƉĨ ŽŵŵĞŶƚƐ ^ƚĞƌůŝŶŐ ϰ͕ϰϭϱ͛ ϰ͕ϰϮϴ͛ ϯ͕ϲϰϴ͛ ϯ͕ϲϱϲ͛ ϭϯ͛ ϵͬϭϱͬϮϬϬϯdW'ƵŶƐ /Ͳϰ͕ϰϱϰ͛ ϰ͕ϰϴϳ͛ ϯ͕ϲϳϰ͛ ϯ͕ϲϵϳ͛ ϯϯ͛ ϵͬϭϱͬϮϬϬϯdW'ƵŶƐ /Ͳϭ ϰ͕ϴϬϱ͛ ϰ͕ϵϬϱ͛ ϯ͕ϵϭϬ͛ ϯ͕ϵϳϲ͛ ϭϬϬ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ /ͲϮ ϰ͕ϵϮϬ͛ ϱ͕ϬϬϱ͛ ϯ͕ϵϴϱ͛ ϰ͕Ϭϰϭ͛ ϴϱ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ /ͲϭϬ ϱ͕ϲϴϱ͛ ϱ͕ϳϬϬ͛ ϰ͕ϰϴϲ͛ ϰ͕ϰϵϲ͛ ϭϱ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ ϱ͕ϴϵϰ͛ ϱ͕ϵϭϰ͛ ϰ͕ϲϮϵ͛ ϰ͕ϲϰϯ͛ ϮϬ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ ϲ͕ϬϵϬ͛ ϲ͕ϭϬϱ͛ ϰ͕ϳϲϵ͛ ϰ͕ϳϳϵ͛ ϭϱ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ ϲ͕ϭϴϱ͛ ϲ͕ϭϵϱ͛ ϰ͕ϴϯϳ͛ ϰ͕ϴϰϰ͛ ϭϬ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ ϲ͕ϯϬϬ͛ ϲ͕ϯϭϬ͛ ϰ͕ϵϮϭ͛ ϰ͕ϵϮϴ͛ ϭϬ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ ϲ͕ϰϱϬ͛ ϲ͕ϱϮϱ͛ ϱ͕Ϭϯϭ͛ ϱ͕Ϭϴϲ͛ ϳϱ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ ϲ͕ϲϰϲ͛ ϲ͕ϲϲϱ͛ ϱ͕ϭϳϳ͛ ϱ͕ϭϵϭ͛ ϭϵ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ& ϲ͕ϲϴϱ͛ ϲ͕ϳϭϬ͛ ϱ͕ϮϬϳ͛ ϱ͕ϮϮϲ͛ Ϯϱ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ' ϲ͕ϴϮϱ͛ ϲ͕ϴϲϱ͛ ϱ͕ϯϭϯ͛ ϱ͕ϯϰϯ͛ ϰϬ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ, ϳ͕ϬϭϬ͛ ϳ͕ϬϮϴ͛ ϱ͕ϰϱϮ͛ ϱ͕ϰϲϲ͛ ϭϴ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ/ ϳ͕ϭϲϱ͛ ϳ͕ϭϳϱ͛ ϱ͕ϱϲϵ͛ ϱ͕ϱϳϳ͛ ϭϬ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ: ϳ͕ϮϳϬ͛ ϳ͕ϮϴϬ͛ ϱ͕ϲϰϳ͛ ϱ͕ϲϱϱ͛ ϭϬ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂ> ϳ͕ϰϮϱ͛ ϳ͕ϰϱϬ͛ ϱ͕ϳϲϮ͛ ϱ͕ϳϴϭ͛ Ϯϱ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂD ϳ͕ϱϭϱ͛ ϳ͕ϱϱϱ͛ ϱ͕ϴϮϵ͛ ϱ͕ϴϱϵ͛ ϰϬ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ ĞůƵŐĂW ϳ͕ϴϯϬ͛ ϳ͕ϵϬϱ͛ ϲ͕ϬϳϬ͛ ϲ͕ϭϮϴ͛ ϳϱ͛ ϵͬϱͬϮϬϬϯ'ƌĂǀĞůWĂĐŬĞĚ^ůŽƚƐ 7\RQHN3ODWIRUP $$&XUUHQW dƵďŝŶŐŚĞĂĚ͕&DͲdͲKK͕ ϭϭϯDǆϵϯD͕ǁͬϮͲ ϮϭͬϭϲϱD^^K sĂůǀĞ͕DĂƐƚĞƌ͕&DͲϭϮϬ͕ ϰϭͬϭϲϯD&͕,tK͕ ƚƌŝŵ sĂůǀĞ͕hƉƉĞƌŵĂƐƚĞƌ͕^^s &DͲϭϮϬ͕ϰϭͬϭϲϯD&͕ǁͬ &DWŽƉĞƌĂƚŽƌ͕ƚƌŝŵ sĂůǀĞ͕^ǁĂď͕&DͲϭϮϬ ϰϭͬϭϲϯD&͕,tK͕ ƚƌŝŵ ,d͕KƚŝƐ͕ϰϭͬϭϲϯD&ǆ ϳ͘ϱΖ͛KƚŝƐƋƵŝĐŬƵŶŝŽŶƚŽƉ ϭϲΖ͛ ϳϱͬϴΖ͛ ^ƚĂƌƚŝŶŐŚĞĂĚ͕KdͲϮϵͲ>͕ ϭϲΖ͛ϯDǆϭϲΖ͛^Kt͕ǁͬϮͲϮ ϭͬϭϲϱD&K ĂƐŝŶŐƐƉŽŽů͕KdͲͲϮϵ>ͲKK ϭϲΖ͛ϯDǆϭϭϯD͕ǁͬ ϮͲϮϭͬϭϲϱD&K dǇŽŶĞŬWůĂƚĨŽƌŵ ͲϭϬ ϭϲǆϭϬвǆϳϱͬϴǆϰЪ sĂůǀĞ͕tŝŶŐ͕^^s͕&DͲϭϮϬ͕ ϰϭͬϭϲϯD&͕ǁͬϭϱΖ͛ǆĞůƐŽŶ D,ŽƉĞƌĂƚŽƌ͕ƚƌŝŵ dƵďŝŶŐŚĂŶŐĞƌ͕&DͲdͲEͲ >͕ϵǆϰЪhϴƌĚůŝĨƚĂŶĚ ϰЪ/dƐƵƐƉ͕ǁͬϰΖ͛ƚǇƉĞ/^Ͳ WsƉƌŽĨŝůĞ͕ϭͲЬŶƉƚĐŽŶƚƌŽů ůŝŶĞƉŽƌƚ ĚĂƉƚĞƌ͕&DͲϱWͲ>͕ ϵΖ͛ϯD&ǆϰϭͬϭϲϯD ϰЪ͛͛ ϭϬв͛͛ E/Ͳϭϭ ϬϭͲϮϴͲϮϮ KW +LOFRUS$ODVND//&+LOFRUS$ODVND//&Changes to Approved Rig Work Over Sundry Procedure6XEMHFW &KDQJHVWR$SSURYHG 6XQGU\3URFHGXUHIRU :HOO 1&RRN,QOHW8QLW $$ 37' 6XQGU\ ;;;;;;$Q\PRGLILFDWLRQVWR DQ DSSURYHGVXQGU\ ZLOOEHGRFXPHQWHGDQG DSSURYHGEHORZ&KDQJHVWRDQDSSURYHG VXQGU\ ZLOOEHFRPPXQLFDWHGWRWKH$2*&& E\WKHULJZRUNRYHU5:2³ILUVWFDOO´HQJLQHHU $2*&&ZULWWHQDSSURYDORIWKHFKDQJHLVUHTXLUHGEHIRUHLPSOHPHQWLQJWKHFKDQJH6HF3DJH'DWH3URFHGXUH&KDQJH1HZ5HTXLUHG"<1+$.3UHSDUHG%\,QLWLDOV+$.$SSURYHG%\,QLWLDOV$2*&&:ULWWHQ$SSURYDO5HFHLYHG3HUVRQDQG'DWH$SSURYDO$VVHW7HDP2SHUDWLRQV0DQDJHU 'DWH3UHSDUHG)LUVW&DOO 2SHUDWLRQV (QJLQHHU 'DWH BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ,ϬϯͲϭϯͲϮϮ WZKWK^ ŽŶƚŝŶŐĞŶĐǇ dǇŽŶĞŬWůĂƚĨŽƌŵ tĞůů͗ͲϭϬ >ĂƐƚŽŵƉůĞƚĞĚ͗ϵͬϱͬϮϬϬϯ Wd͗ϮϬϯͲϬϳϱ W/͗ ϱϬͲϴϴϯͲϮϬϬϯϬͲϬϭͲϬϬ Wd͗ϲ͕ϳϰϴ͛;DͿ d͗ϴ͕ϴϰϬ͛;DͿ ´ Z<ƚŽd',ĞĂĚʹϰϯ͘ϴ͛ ´ % ' & ´ ͟ $ ϭϴ ´ ZLQGRZ# ¶ ϭϲ 72&¶ *RRGFPW #¶ ĞŵĞŶƚ ZĞƚĂŝŶĞƌΘ dƵďŝŶŐWƵŶĐŚ) ( ; ; ^/E'd/> ^ŝǌĞ tƚ 'ƌĂĚĞ ŽŶŶ / dŽƉ ƚŵ ϯϬ͟ ϭϮϬ͘Ϭ ,ͲϰϬ t> Ϯϳ͟ ϰϭ͛ϯϲϲ͛ ϭϲ͟ ϲϮ͘ϱ ,ͲϰϬ t> ϭϱ͘ϬϲϮ͟ ϰϭ͛ ϲϯϭ͛ ϭϬͲϯͬϰ͟ ϰϬ͘ϱ :Ͳϱϱ d ϭϬ͘ϬϱϬ͟ ϰϭ͛ ϭ͕ϲϵϱ͛ ϭϬͲϯͬϰ͟ ϰϱ͘ϱ :Ͳϱϱ d ϵ͘ϵϱϬ͟ ϭ͕ϲϵϱ͛ ϭ͕ϵϭϭ͛ ϳͲϱͬϴ͟ Ϯϵ͘ϳ >ͲϴϬ d ϲ͘ϴϳϱ͟ ϰϰ͛ ϴ͕ϴϯϬΖ dh/E'd/> ϰͲϭͬϮ͟ ϭϮ͘ϲ >ͲϴϬ /dͲŵŽĚ ϯ͘ϵϱϴ͟цϰ͕ϭϬϬ͛ϳ͕ϳϲϰ͛ ϯͲϭͬϮ͟ ϵ͘ϯ >ͲϴϬ /dͲŵŽĚ ϳ͕ϳϲϱ͛ ϳ͕ϵϳϮ͛ 'Zs>W< ϰ͟ ϵ͘ϱ >ͲϴϬ /dͲŵŽĚ ϯ͘ϱϰϴ͟ ϰ͕ϲϵϰ͛ ϳ͕ϱϲϰ͛ :t>Zzd/> EŽ ĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ / K /ƚĞŵ цϯ͕ϬϭϬ͛ цϮ͕ϲϵϯ͛ tŚŝƉƐƚŽĐŬ цϯ͕ϬϯϬ͛ цϮ͕ϳϭϰ͛ /W цϰ͕ϮϭϬ͛ ϯ͘ϵϱϴ ĞŵĞŶƚZĞƚĂŝŶĞƌ цϰ͕ϮϮϬ͛ ϯ͘ϵϱϴ /W ϱ ϰ͕ϮϮϭ͛ ϯ͘ϴϲϱ ϲ͘Ϭϱϵ '>DĂŵĐŽ<'ͲϮ͕<>ĂƚĐŚ ϲ ϰ͕Ϯϳϳ͛ ϯ͕ϱϱϱ͛ ϯ͘ϵϱϴ ϱ͘ϱϲϯ WZϴϬͲϰϳ͕ϭϱ͛ƐĞĂůƚƌĂǀĞů цϰ͕Ϯϵϳ͛ ϯ͘ϵϱϴ ĞŵĞŶƚZĞƚĂŝŶĞƌ & цϰ͕ϯϬϬ͛ цϯ͕ϱϳϬ͛ ϯ͘ϵϱϴ /W ϳ ϰ͕ϯϬϳ͛ ϯ͕ϱϳϱ͛ ϯ͘ϴϳϱ ϲ͘ϱϬϬ WĂĐŬĞƌ͕ĂŬĞƌWƌĞŵŝĞƌ ϴ ϰ͕ϲϲϱ͛ ϯ͕ϴϭϳ͛ ϯ͘ϴϭϯ ϱ͘ϱϬϬ ^ůĞĞǀĞ͕ĂŬĞƌDh^ůŝĚŝŶŐ͕>K^͕ ϵ ϰ͕ϳϬϴ͛ ϯ͕ϴϰϱ͛ ϯ͘ϮϴϬ ϰ͘Ϯϭϴ ŶĐŚŽƌ>ĂƚĐŚ͕ĂŬĞƌ^ͲϮϮ ϭϬ ϰ͕ϳϬϵ͛ ϯ͕ϴϰϲ͛ ϰ͘ϬϬϬ ϲ͘ϰϵϬ WĂĐŬĞƌ͕ĂŬĞƌ^ͲϮ ϰ͕ϳϵϵ͛ ϯ͕ϵϬϲ͛ ϯ͘ϱϰϴ ϰ͘ϱϵϬ ^ĐƌĞĞŶ͕ĂŬĞƌǁĞůĚ͕͘ϬϭϮŐĂ͘ ϭϭ ϱ͕Ϭϭϳ͛ ϰ͕Ϭϰϵ͛ ϯ͘ϮϱϬ ϲ͘ϰϵϬ WĂĐŬĞƌ͕ĂŬĞƌ^Ͳϭ>DƵůƚŝǌŽŶĞ ϭϮ ϱ͕ϲϭϭ͛ ϰ͕ϰϯϲ͛ ϯ͘ϮϱϬ ϲ͘ϰϵϬ WĂĐŬĞƌ͕ĂŬĞƌ^Ͳϭ>DƵůƚŝǌŽŶĞ ϱ͕ϲϳϮ͛ ϰ͕ϰϯϲ͛ ϯ͘ϱϰϴ ϰ͘ϱϵϬ ^ĐƌĞĞŶ͕ĂŬĞƌǁĞůĚ͕͘ϬϭϮŐĂ͘ ϭϯ ϲ͕ϮϬϴ͛ ϰ͕ϴϱϰ͛ ϯ͘ϮϴϬ ϰ͘Ϯϭϴ ^ŶĂƉ>ĂƚĐŚ͕ĂŬĞƌ^ͲϮϮ ϭϰ ϲ͕ϮϬϵ͛ ϰ͕ϴϱϰ͛ ϰ͘ϬϬϬ ϲ͘ϰϵϬ WĂĐŬĞƌ͕ĂŬĞƌ^ͲϮ ϲ͕Ϯϵϯ͛ ϰ͕ϵϭϱ͛ 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from above. eceived By: 01/20/2022 37' (6HW By Abby Bell at 10:30 am, Jan 20, 2022 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 12/28/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NCI A-10A (PTD 203-075) Plug 12/02/2021 Please include current contact information if different from above. 37' (6HW Received By: 12/29/2021 By Abby Bell at 8:58 am, Dec 29, 2021 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 8,840'4,462' Casing Collapse Structural Conductor Surface 1,580 psi Intermediate Production 4,790 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Chad Helgeson Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE AOGCC Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 6,882'3,938'3,326'1,004 psi N/A 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Dan Marlowe, Operations Manager chelgeson@hilcorp.com (907) 777-8405 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: See schematic See schematic 4,415 - 7,905 3,648 - 6,128 11/25/2021 4-1/2" & 3-1/2" PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 203-075 50-883-20030-01-00 N Cook Inlet Unit A-10A North Cook Inlet Unit / Tertiary System Gas Pool CO 68A 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Hilcorp Alaska, LLC Length Size 366' 366' 12.6 / L-80 & 9.3 / L-80 TVD Burst 7,764' & 7,972' 6,890 psi MD 3,130 psi 631' 1,839' 631' 1,911' 6,874'7-5/8" 366'30" 16" 10-3/4" 631' 1,911' 8,830' Perforation Depth MD (ft): 8,830' ry Statu Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. 321-581 By Meredith Guhl at 7:33 am, Nov 12, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.11.11 14:56:26 -09'00' Dan Marlowe (1267) DSR-11/12/21 10-404 DLB 11/12/2021 BJM 11/15/21 Install and test SSSV within 5 days of return to production. X dts 11/15/2021 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.11.15 13:49:07 -09'00'11/15/21 RBDMS HEW 11/17/2021 Well Work Prognosis Well: A-10A Date: 11/11/2021 Well Name:NCIU A-10A API Number: 50-883-20030-01-00 Current Status:SI Gas Producer Leg:2 Estimated Start Date:11/25/2021 Rig:E-Line Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Donna Ambruz Permit to Drill Number:203-075 First Call Engineer:Chad Helgeson Office: 907-777-8405 Cell: 907-229-4824 Second Call Engineer:Katherine O’Connor Office: 907-777-8376 Cell: 214-684-7400 Current Bottom Hole Pressure:1,729 psi @ 7,270’ TVD Maximum Expected BHP:1,729 psi @ 7,270’ TVD (New Perfs being added lower pressure) Maximum Potential Surface Pressure:1004 psi Based on 0.1 psi/ft gas gradient Max Inclination 49.9° @ 5,040’ MD Brief Well Summary: The A-10 Well was sidetracked in 2003 with the Kuukpik #5 Rig to the A-10A and completed in September 2003 as a gas well. The well was cleaned out with coil in 2004, 2010, and 2021. In June of 2021 coil was able to remove lost slickline tools and clean the well out, and performed a caliper survey to 7,903’. The well was brought online, but was making 1,500-2,000 bbls of water and the well has been shut-in. Notes Regarding Wellbore Condition x Current Conditions: SI Well T/I/O - 1004/739/48 Objective: The objective of this program is to find current zone that has high water influx, plug back water producing zone and add perforations in Beluga sands. Pre-Sundry Work Procedure: 1. Slickline MIRU, PT lubricator (250L/2500H) 2. RIH and pull SSSV from nipple at 348ft 3. RIH w 3.1” gauge ring, tag bottom. (Have bailer on hand if fill is tagged above proposed perfs. 4. RDMO slickline 5. MIRU E-line, PT lubricator (250L/2500H). 6. Operations start flowing the well into test separator. Note: Obtain steady flowing conditions, (estimated water production of ~1,500 bbls of water/day) 7. Run Spinner survey following separate procedure from engineer. Note: If water rate is too high for spinner to get to bottom, cut back rate and start logging from the bottom of the well. 8. RDMO E-Line Well Work Prognosis Well: A-10A Date: 11/11/2021 Sundry E-Line Work Procedure: 1. MIRU E-line, PT lubricator (250L/2500H) 2. PU plug and RIH to set above water producing zone below the gravel pack packer, that is above the wet zone. 3. PU guns, RIH and perforate the following Beluga sands with the well shut in. Gross Proposed Perforated Intervals Pool Sands Top (MD) Btm (MD) Total Top (TVD) Bottom (TVD) Tertiary Gas System Beluga A ±5,796’ ±5,805’ ±9’ ±4,562‘±4,568‘ Tertiary Gas System Beluga A ±5,820’ ±5,831’ ±11’ ±4,578 ‘±4,586’ Tertiary Gas System Beluga A ±5,876’ ±5,885’ ±9’ ±4,617’±4,623’ Tertiary Gas System Beluga B ±5,935’ ±5,941’ ±6’ ±4,658’±4,662’ Tertiary Gas System Beluga B ±5,971’ ±5,981’ ±10’ ±4,683’±4,690’ Tertiary Gas System Beluga B ±6,003’ ±6,006’ ±3’ ±4,706’±4,708’ Tertiary Gas System Beluga B ±6,035’ ±6,052’ ±17’ ±4,729’±4,741’ Tertiary Gas System Beluga B ±6,137’ ±6,144’ ±7’ ±4,802’±4,807’ Tertiary Gas System Beluga C ±6,175’ ±6,180’ ±5’ ±4,830’±4,833’ Tertiary Gas System Beluga C ±6,201’ ±6,207’ ±6’ ±4,848’±4,853’ Tertiary Gas System Beluga C ±6,233’ ±6,238’ ±5’ ±4,872’±4,875’ Tertiary Gas System Beluga D ±6,597’ ±6,603’ ±6’ ±5,140’±5,145’ a. Send the correlation pass to the Reservoir Engineer (Chris Kanyer), and Geologist (Daniel Yancy) for confirmation. b. Verify PTs are open to SCADA before perforating. Record tubing pressures and well flow rate at 0, 5, 10 and 15 minutes after each perforating run. 4. RDMO E-line. 5. Turn over to operations. 6. Monitor production for up to 2 weeks to evaluate any significant water production. Contingency (If water production from new perfs impacts gas rate): 1. MIRU E-line, PT lubricator (250L/1500H). 2. MU & Run spinner survey to find zone making water. Install SSSV - bjm Well Work Prognosis Well: A-10A Date: 11/11/2021 3. SI Production. 4. PU plug, RIH and set in blank pipe above zone making water. 5. RD E-Line 6. Turn well over to Production Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic _____________________________________________________________________________________ Updated By: JLL 07/29/21 SCHEMATIC Tyonek Platform Well: A-10A Last Completed: 9/5/2003 PTD: 203-075 API: 50-883-20030-01 PBTD: 8,749’ (MD) TD: 8,840’ (MD) 22 30” RKB to TBG Head – 43.8’ 7-5/8” 13 2 3 4 8 5 7 17 9 10 11 6 16” 10-3/4” 1 15 18 12 13 14 14 19 23 10-3/4” window @ 1,911’ 16 21 20 13 X X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” 120.0 H-40 WELDED 27” 41’ 366’ 16” 62.5 H-40 WELDED 15.062” 41’ 631’ 10-3/4” 40.5 J-55 BTC 10.050” 41’ 1,695’ 10-3/4” 45.5 J-55 BTC 9.950” 1,695’ 1,911’ 7-5/8” 29.7 L-80 BTC 6.875” 44’ 8,830' TUBING DETAIL 4-1/2” 12.6 L-80 IBT-mod 3.958” 43.8’ 7,764’ 3-1/2” 9.3 L-80 IBT-mod 7,765’ 7,972’ GRAVEL PACK 4” 9.5 L-80 IBT-mod 3.548” 4,694’ 7,564’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 414’ 414’ 3.813 6.000 Safety Valve, Camco 4-1/2” TRM-4PE CF TRSSSV 2 1,356’1,336’ 3.865 6.059 GLM#, 1 Camco KBG-2, BK latch, Port = 0.188”, TRO = 1375 psi 3 2,398’2,268’ 3.865 6.059 GLM#2 Camco KBG-2, BK latch, Port = 0.188”, TRO = 1375 psi 4 3,386’2,951’ 3.865 6.059 GLM#3 Camco KBG-2, BK latch, Port = 0.188”, TRO = 1375 psi 5 4,221’ 3.865 6.059 GLM#4, Camco KBG-2, BK latch 6 4,277’ 3,555’ 3.958 5.563 PBR 80-47, 15’ seal travel 7 4,307’ 3,575’ 3.875 6.500 Packer, Baker Premier 8 4,665’ 3,817’ 3.813 5.500 Sleeve, Baker CMU Sliding, OPEN 9 4,708’ 3,845’ 3.280 4.218 Anchor Latch, Baker S-22 10 4,709’ 3,846’ 4.000 6.490 Packer, Baker SC-2 4,799’ 3,906’ 3.548 4.590 Screen, Bakerweld, .012 ga. 11 5,017’ 4,049’ 3.250 6.490 Packer, Baker SC-1L Multizone 12 5,611’ 4,436’ 3.250 6.490 Packer, Baker SC-1L Multizone 5,672’ 4,436’ 3.548 4.590 Screen, Bakerweld, .012 ga. 13 6,208’ 4,854’ 3.280 4.218 Snap Latch, Baker S-22 14 6,209’ 4,854’ 4.000 6.490 Packer, Baker SC-2 6,293’ 4,915’ 3.548 4.590 Screen, Bakerweld, .012 ga 15 6,716’ 5,230’ 3.250 6.490 Packer, Baker SC-1L Multizone 6,814’ 5,304’ 3.548 4.590 Screen, Bakerweld, .012 ga 16 7,181’ 5,581’ 3.250 6.490 Packer, Baker SC-1L Multizone 7,264’ 5,643’ 3.548 4.590 Screen, Bakerweld, .012 ga 17 7,564’ 5,866’ 3.280 4.218 Snap Latch, Baker S-22B 18 7,565’ 5,866’ 4.000 6.500 Packer, Baker FB-1 Sump Packer 19 7,764’ 6,019’ 3.940 5.375 XO, 4.5 X 3.5 20 7,797’ 6,044’ 2.813 4.250 Nipple, X 21 7,830’ 6,070’ 3.548 5.020 Screen, SLHT Excluder 22 7,938’ 6,153’ 2.813 4.250 Nipple, X 23 7,970’ 6,178’ 2.992 3.800 Wireline Entry Guide Note: 9/3/2003 Three Radioactive (RA) 7-5/8” casing couplings @ 4366’, 5879’ & 7450’ Note: 9/3/2003 Radioactive (RA) collars @ 581’, 6011’, 6396’, 6907’ & 7377’ Note: 07/02/21 – RIH w/ 2-1/8” nozzle for dry tag to 7,970’ RKB -00 DLB SCHEMATIC Updated By: JLL 07/29/21 Tyonek Platform Well: A-10A Last Completed: 9/5/2003 PTD: 203-075 API: 50773-20030-01 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf Comments Sterling 4,415’ 4,428’ 3,648’ 3,656’ 13’ 9/15/2003 TCP Guns CI-A 4,454’ 4,487’ 3,674’ 3,697’ 33’ 9/15/2003 TCP Guns CI-1 4,805’ 4,905’ 3,910’ 3,976’ 100’ 9/5/2003 Gravel Packed Slots CI-2 4,920’ 5,005’ 3,985’ 4,041’ 85’ 9/5/2003 Gravel Packed Slots CI-10 5,685’ 5,700’ 4,486’ 4,496’ 15’ 9/5/2003 Gravel Packed Slots Beluga A 5,894’ 5,914’ 4,629’ 4,643’ 20’ 9/5/2003 Gravel Packed Slots Beluga B 6,090’ 6,105’ 4,769’ 4,779’ 15’ 9/5/2003 Gravel Packed Slots Beluga C 6,185’ 6,195’ 4,837’ 4,844’ 10’ 9/5/2003 Gravel Packed Slots Beluga D 6,300’ 6,310’ 4,921’ 4,928’ 10’ 9/5/2003 Gravel Packed Slots Beluga D 6,450’ 6,525’ 5,031’ 5,086’ 75’ 9/5/2003 Gravel Packed Slots Beluga E 6,646’ 6,665’ 5,177’ 5,191’ 19’ 9/5/2003 Gravel Packed Slots Beluga F 6,685’ 6,710’ 5,207’ 5,226’ 25’ 9/5/2003 Gravel Packed Slots Beluga G 6,825’ 6,865’ 5,313’ 5,343’ 40’ 9/5/2003 Gravel Packed Slots Beluga H 7,010’ 7,028’ 5,452’ 5,466’ 18’ 9/5/2003 Gravel Packed Slots Beluga I 7,165’ 7,175’ 5,569’ 5,577’ 10’ 9/5/2003 Gravel Packed Slots Beluga J 7,270’ 7,280’ 5,647’ 5,655’ 10’ 9/5/2003 Gravel Packed Slots Beluga L 7,425’ 7,450’ 5,762’ 5,781’ 25’ 9/5/2003 Gravel Packed Slots Beluga M 7,515’ 7,555’ 5,829’ 5,859’ 40’ 9/5/2003 Gravel Packed Slots Beluga P 7,830’ 7,905’ 6,070’ 6,128’ 75’ 9/5/2003 Gravel Packed Slots -00 DLB _____________________________________________________________________________________ Updated By: CAH 11/11/21 PROPOSED Tyonek Platform Well: A-10A Last Completed: 9/5/2003 PTD: 203-075 API: 50-883-20030-01 PBTD: 8,749’ (MD) TD: 8,840’ (MD) 22 30” RKB to TBG Head – 43.8’ 7-5/8” 13 2 3 4 8 5 7 17 9 10 11 6 16” 10-3/4” 1 15 18 12 13 14 14 19 23 10-3/4” window @ 1,911’ 16 21 20X X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” 120.0 H-40 WELDED 27” 41’ 366’ 16” 62.5 H-40 WELDED 15.062” 41’ 631’ 10-3/4” 40.5 J-55 BTC 10.050” 41’ 1,695’ 10-3/4” 45.5 J-55 BTC 9.950” 1,695’ 1,911’ 7-5/8” 29.7 L-80 BTC 6.875” 44’ 8,830' TUBING DETAIL 4-1/2” 12.6 L-80 IBT-mod 3.958” 43.8’ 7,764’ 3-1/2” 9.3 L-80 IBT-mod 7,765’ 7,972’ GRAVEL PACK 4” 9.5 L-80 IBT-mod 3.548” 4,694’ 7,564’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 414’ 414’ 3.813 6.000 Safety Valve, Camco 4-1/2” TRM-4PE CF TRSSSV 2 1,356’1,336’ 3.865 6.059 GLM#, 1 Camco KBG-2, BK latch, Port = 0.188”, TRO = 1375 psi 3 2,398’2,268’ 3.865 6.059 GLM#2 Camco KBG-2, BK latch, Port = 0.188”, TRO = 1375 psi 4 3,386’2,951’ 3.865 6.059 GLM#3 Camco KBG-2, BK latch, Port = 0.188”, TRO = 1375 psi 5 4,221’ 3.865 6.059 GLM#4, Camco KBG-2, BK latch 6 4,277’ 3,555’ 3.958 5.563 PBR 80-47, 15’ seal travel 7 4,307’ 3,575’ 3.875 6.500 Packer, Baker Premier 8 4,665’ 3,817’ 3.813 5.500 Sleeve, Baker CMU Sliding, OPEN 9 4,708’ 3,845’ 3.280 4.218 Anchor Latch, Baker S-22 10 4,709’ 3,846’ 4.000 6.490 Packer, Baker SC-2 4,799’ 3,906’ 3.548 4.590 Screen, Bakerweld, .012 ga. 11 5,017’ 4,049’ 3.250 6.490 Packer, Baker SC-1L Multizone 12 5,611’ 4,436’ 3.250 6.490 Packer, Baker SC-1L Multizone 5,672’ 4,436’ 3.548 4.590 Screen, Bakerweld, .012 ga. 13 6,208’ 4,854’ 3.280 4.218 Snap Latch, Baker S-22 14 6,209’ 4,854’ 4.000 6.490 Packer, Baker SC-2 6,293’ 4,915’ 3.548 4.590 Screen, Bakerweld, .012 ga 15 6,716’ 5,230’ 3.250 6.490 Packer, Baker SC-1L Multizone 6,814’ 5,304’ 3.548 4.590 Screen, Bakerweld, .012 ga 16 7,181’ 5,581’ 3.250 6.490 Packer, Baker SC-1L Multizone 7,264’ 5,643’ 3.548 4.590 Screen, Bakerweld, .012 ga 17 7,564’ 5,866’ 3.280 4.218 Snap Latch, Baker S-22B 18 7,565’ 5,866’ 4.000 6.500 Packer, Baker FB-1 Sump Packer 19 7,764’ 6,019’ 3.940 5.375 XO, 4.5 X 3.5 20 7,797’ 6,044’ 2.813 4.250 Nipple, X 21 7,830’ 6,070’ 3.548 5.020 Screen, SLHT Excluder 22 7,938’ 6,153’ 2.813 4.250 Nipple, X 23 7,970’ 6,178’ 2.992 3.800 Wireline Entry Guide Note: 9/3/2003 Three Radioactive (RA) 7-5/8” casing couplings @ 4366’, 5879’ & 7450’ Note: 9/3/2003 Radioactive (RA) collars @ 581’, 6011’, 6396’, 6907’ & 7377’ Note: 07/02/21 – RIH w/ 2-1/8” nozzle for dry tag to 7,970’ RKB -00 DLB PROPOSED Updated By: CAH 11/11/21 Tyonek Platform Well: A-10A Last Completed: 9/5/2003 PTD: 203-075 API: 50773-20030-01 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf Comments Sterling 4,415’ 4,428’ 3,648’ 3,656’ 13’ 9/15/2003 TCP Guns CI-A 4,454’ 4,487’ 3,674’ 3,697’ 33’ 9/15/2003 TCP Guns CI-1 4,805’ 4,905’ 3,910’ 3,976’ 100’ 9/5/2003 Gravel Packed Slots CI-2 4,920’ 5,005’ 3,985’ 4,041’ 85’ 9/5/2003 Gravel Packed Slots CI-10 5,685’ 5,700’ 4,486’ 4,496’ 15’ 9/5/2003 Gravel Packed Slots Beluga A ±5,796 ±5,805’ ±4,562‘ ±4,568‘ ±9’ Proposed Beluga A ±5,820 ±5,831’ ±4,578‘ ±4,586’ ±11’ Proposed Beluga A ±5,876 ±5,885’ ±4,617’ ±4,623’ ±9’ Proposed Beluga A 5,894’ 5,914’ 4,629’ 4,643’ 20’ 9/5/2003 Gravel Packed Slots Beluga B ±5,935 ±5,941’ ±4,658’ ±4,662’ ±6’ Proposed Beluga B ±5,971 ±5,981’ ±4,683’ ±4,690’ ±10’ Proposed Beluga B ±6,003 ±6,006’ ±4,706’ ±4,708’ ±3’ Proposed Beluga B ±6,035 ±6,052’ ±4,729’ ±4,741’ ±17’ Proposed Beluga B 6,090’ 6,105’ 4,769’ 4,779’ 15’ 9/5/2003 Gravel Packed Slots Beluga B ±6,137 ±6,144’ ±4,802’ ±4,807’ ±7’ Proposed Beluga C ±6,175 ±6,180’ ±4,830’ ±4,833’ ±5’ Proposed Beluga C 6,185’ 6,195’ 4,837’ 4,844’ 10’ 9/5/2003 Gravel Packed Slots Beluga C ±6,201 ±6,207’ ±4,848’ ±4,853’ ±6’ Proposed Beluga C ±6,233 ±6,238’ ±4,872’ ±4,875’ ±5’ Proposed Beluga D 6,300’ 6,310’ 4,921’ 4,928’ 10’ 9/5/2003 Gravel Packed Slots Beluga D 6,450’ 6,525’ 5,031’ 5,086’ 75’ 9/5/2003 Gravel Packed Slots Beluga E ±6,597 ±6,603’ ±5,140’ ±5,145’ ±6’ Proposed Beluga E 6,646’ 6,665’ 5,177’ 5,191’ 19’ 9/5/2003 Gravel Packed Slots Beluga F 6,685’ 6,710’ 5,207’ 5,226’ 25’ 9/5/2003 Gravel Packed Slots Beluga G 6,825’ 6,865’ 5,313’ 5,343’ 40’ 9/5/2003 Gravel Packed Slots Beluga H 7,010’ 7,028’ 5,452’ 5,466’ 18’ 9/5/2003 Gravel Packed Slots Beluga I 7,165’ 7,175’ 5,569’ 5,577’ 10’ 9/5/2003 Gravel Packed Slots Beluga J 7,270’ 7,280’ 5,647’ 5,655’ 10’ 9/5/2003 Gravel Packed Slots Beluga L 7,425’ 7,450’ 5,762’ 5,781’ 25’ 9/5/2003 Gravel Packed Slots Beluga M 7,515’ 7,555’ 5,829’ 5,859’ 40’ 9/5/2003 Gravel Packed Slots Beluga P 7,830’ 7,905’ 6,070’ 6,128’ 75’ 9/5/2003 Gravel Packed Slots -00 DLB 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: CTCO Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,840 feet N/A feet true vertical 6,882 feet N/A feet Effective Depth measured 7,970 feet See schematic feet true vertical 6,178 feet See schematic feet Perforation depth Measured depth 4,415 - 7,905 feet True Vertical depth 3,648 - 6,128 feet 4-1/2" 12.6 / L-80 7,764 MD 6,019 TVD Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3 / L-80 7,972 MD 6,180 TVD Packers and SSSV (type, measured and true vertical depth)See Schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: TVD 366 measured true vertical Packer 7-5/8" 30" 8,830 MD 366 631 1,911 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 2500 Casing Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-075 50-883-20030-01-00 Plugs ADL0017589 N Cook Inlet Unit A-10A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-233 587 Authorized Signature with date: Authorized Name: 0 WINJ WAG 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 667 N/A Oil-Bbl 0 Water-Bbl Intermediate N/A Junk 5. Permit to Drill Number: 0 North Cook Inlet / Tertiary System Gas PoolN/A measured 8,830 Size 707 Production Casing Structural Liner Length 366 631 1,911 Conductor Surface 4,790psi 16" 10-3/4" 907 777-8376 6,890psi 631 1,839 6,874 Collapse Katherine O'Connor Katherine.oconnor@hilcorp.com Tubing Pressure 1,580psi3,130psi Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: Daniel E. Marlowe Operations Manager Burst PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 3:34 pm, Jul 29, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.07.29 15:29:47 -08'00' Dan Marlowe (1267) SFD 7/30/2021DSR-7/29/21 RBDMS HEW 8/2/2021 BJM 10/12/21 _____________________________________________________________________________________ Updated By: JLL 07/29/21 SCHEMATIC Tyonek Platform Well: A-10A Last Completed: 9/5/2003 PTD: 203-075 API: 50-883-20030-01 PBTD: 8,749’ (MD) TD: 8,840’ (MD) 22 30” RKB to TBG Head – 43.8’ 7-5/8” 13 2 3 4 8 5 7 17 9 10 11 6 16” 10-3/4” 1 15 18 12 13 14 14 19 23 10-3/4” window @ 1,911’ 16 21 20 13 X X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” 120.0 H-40 WELDED 27” 41’ 366’ 16” 62.5 H-40 WELDED 15.062” 41’ 631’ 10-3/4” 40.5 J-55 BTC 10.050” 41’ 1,695’ 10-3/4” 45.5 J-55 BTC 9.950” 1,695’ 1,911’ 7-5/8” 29.7 L-80 BTC 6.875” 44’ 8,830' TUBING DETAIL 4-1/2” 12.6 L-80 IBT-mod 3.958” 43.8’ 7,764’ 3-1/2” 9.3 L-80 IBT-mod 7,765’ 7,972’ GRAVEL PACK 4” 9.5 L-80 IBT-mod 3.548” 4,694’ 7,564’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 414’ 414’ 3.813 6.000 Safety Valve, Camco 4-1/2” TRM-4PE CF TRSSSV 2 1,356’1,336’ 3.865 6.059 GLM#, 1 Camco KBG-2, BK latch, Port = 0.188”, TRO = 1375 psi 3 2,398’2,268’ 3.865 6.059 GLM#2 Camco KBG-2, BK latch, Port = 0.188”, TRO = 1375 psi 4 3,386’2,951’ 3.865 6.059 GLM#3 Camco KBG-2, BK latch, Port = 0.188”, TRO = 1375 psi 5 4,221’ 3.865 6.059 GLM#4, Camco KBG-2, BK latch 6 4,277’ 3,555’ 3.958 5.563 PBR 80-47, 15’ seal travel 7 4,307’ 3,575’ 3.875 6.500 Packer, Baker Premier 8 4,665’ 3,817’ 3.813 5.500 Sleeve, Baker CMU Sliding, OPEN 9 4,708’ 3,845’ 3.280 4.218 Anchor Latch, Baker S-22 10 4,709’ 3,846’ 4.000 6.490 Packer, Baker SC-2 4,799’ 3,906’ 3.548 4.590 Screen, Bakerweld, .012 ga. 11 5,017’ 4,049’ 3.250 6.490 Packer, Baker SC-1L Multizone 12 5,611’ 4,436’ 3.250 6.490 Packer, Baker SC-1L Multizone 5,672’ 4,436’ 3.548 4.590 Screen, Bakerweld, .012 ga. 13 6,208’ 4,854’ 3.280 4.218 Snap Latch, Baker S-22 14 6,209’ 4,854’ 4.000 6.490 Packer, Baker SC-2 6,293’ 4,915’ 3.548 4.590 Screen, Bakerweld, .012 ga 15 6,716’ 5,230’ 3.250 6.490 Packer, Baker SC-1L Multizone 6,814’ 5,304’ 3.548 4.590 Screen, Bakerweld, .012 ga 16 7,181’ 5,581’ 3.250 6.490 Packer, Baker SC-1L Multizone 7,264’ 5,643’ 3.548 4.590 Screen, Bakerweld, .012 ga 17 7,564’ 5,866’ 3.280 4.218 Snap Latch, Baker S-22B 18 7,565’ 5,866’ 4.000 6.500 Packer, Baker FB-1 Sump Packer 19 7,764’ 6,019’ 3.940 5.375 XO, 4.5 X 3.5 20 7,797’ 6,044’ 2.813 4.250 Nipple, X 21 7,830’ 6,070’ 3.548 5.020 Screen, SLHT Excluder 22 7,938’ 6,153’ 2.813 4.250 Nipple, X 23 7,970’ 6,178’ 2.992 3.800 Wireline Entry Guide Note: 9/3/2003 Three Radioactive (RA) 7-5/8” casing couplings @ 4366’, 5879’ & 7450’ Note: 9/3/2003 Radioactive (RA) collars @ 581’, 6011’, 6396’, 6907’ & 7377’ Note: 07/02/21 – RIH w/ 2-1/8” nozzle for dry tag to 7,970’ RKB SCHEMATIC Updated By: JLL 07/29/21 Tyonek Platform Well: A-10A Last Completed: 9/5/2003 PTD: 203-075 API: 50773-20030-01 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf Comments Sterling 4,415’ 4,428’ 3,648’ 3,656’ 13’ 9/15/2003 TCP Guns CI-A 4,454’ 4,487’ 3,674’ 3,697’ 33’ 9/15/2003 TCP Guns CI-1 4,805’ 4,905’ 3,910’ 3,976’ 100’ 9/5/2003 Gravel Packed Slots CI-2 4,920’ 5,005’ 3,985’ 4,041’ 85’ 9/5/2003 Gravel Packed Slots CI-10 5,685’ 5,700’ 4,486’ 4,496’ 15’ 9/5/2003 Gravel Packed Slots Beluga A 5,894’ 5,914’ 4,629’ 4,643’ 20’ 9/5/2003 Gravel Packed Slots Beluga B 6,090’ 6,105’ 4,769’ 4,779’ 15’ 9/5/2003 Gravel Packed Slots Beluga C 6,185’ 6,195’ 4,837’ 4,844’ 10’ 9/5/2003 Gravel Packed Slots Beluga D 6,300’ 6,310’ 4,921’ 4,928’ 10’ 9/5/2003 Gravel Packed Slots Beluga D 6,450’ 6,525’ 5,031’ 5,086’ 75’ 9/5/2003 Gravel Packed Slots Beluga E 6,646’ 6,665’ 5,177’ 5,191’ 19’ 9/5/2003 Gravel Packed Slots Beluga F 6,685’ 6,710’ 5,207’ 5,226’ 25’ 9/5/2003 Gravel Packed Slots Beluga G 6,825’ 6,865’ 5,313’ 5,343’ 40’ 9/5/2003 Gravel Packed Slots Beluga H 7,010’ 7,028’ 5,452’ 5,466’ 18’ 9/5/2003 Gravel Packed Slots Beluga I 7,165’ 7,175’ 5,569’ 5,577’ 10’ 9/5/2003 Gravel Packed Slots Beluga J 7,270’ 7,280’ 5,647’ 5,655’ 10’ 9/5/2003 Gravel Packed Slots Beluga L 7,425’ 7,450’ 5,762’ 5,781’ 25’ 9/5/2003 Gravel Packed Slots Beluga M 7,515’ 7,555’ 5,829’ 5,859’ 40’ 9/5/2003 Gravel Packed Slots Beluga P 7,830’ 7,905’ 6,070’ 6,128’ 75’ 9/5/2003 Gravel Packed Slots Rig Start Date End Date CTU 6/14/21 7/2/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name N Cook Inlet Unit A-10A 50-883-20030-01-00 203-075 Simops mtg w/ production. PJSM & permits. Fire up CTU equipment package. Blend 50 bbl of 6% KCl in batchmixer. Stab 1-3/4" CT thru injector chains. Move to well. Pump & displace 1.188" OD ball thru 1-3/4" CT w/ 30 bbl 6% KCl water. Stand back from well. Ball retrieved. MU CT connector. Pull test CTC = 22K. MU BHA1. Press Test BHA1 = 3200. Move to well. PT Lubricator & WLV = 300/3000. BHA1 = CTC(2.87"x0.70'), DFCV(2.88"x1.25'), X-over(2.55"x0.44'), Stinger(2.25'x4'), Stinger(1.125"x4'), Power Clean Nozzle (2.14"x0.79') OAL = 11.18'. Open swab. T/IA/OA = 141/0/50. RIH for dry tag w/ choke shut in. 1800', WHP = 660, bleed down to 300 psi thru choke & continue RIH holding 300 psi @ choke. 2900' WT CHK = 6K. Dry tag @ 3740', PUH & line out fluid pump to circulate well. Attempts to bring on water @ fluid pump from batchmixer keep plugging off pump suction line @ the rock catcher. Unable to pump fluid. Empty rock catcher, find rust & sediment. Multiple attempts made to clear line w/ repeat of plugged rock catcher after each attempt. POOH. Close swab. Secure well & CTU. Ship fluid from batchmixer to flowback tank. Pressure wash batchmixer tanks shipping fluid & sediments to flowback tank. Use vacuum unit to suck up residual sediment remaining in batch. SDFN. Resume cleaning tank in the morning to remove remaining solids contamination. Job in Progress. Simops mtg w/ production. PJSM & permit. MV Endeavor arrives platform. Offload MV Endeavor. Offload & spot on drill deck 2 flowback tanks, filter skid & hose basket. Offload 4 N2 tanks & spot same on liner laid on drill deck. Offload & spot 10 pallets KCL on the pipe deck. MV Endeavor away from platform. Run flowback lines from choke manifold to 2 flowback tanks. Run 3" camlock drain lines from flowback tanks to filter skid & platform production wqter manifold. Wait on helicopter green deck. Rig up WH riser, flow tee & BOP. Run flowback iron from flow tee to choke. Run supply line from production drill water manifold to batchmixer. Run supply line from batchmixer to fluid pump. BOPE test per AOGCC & Hilcorp standards 250/2500 psi. Witnessed waived by Jim Regg (6/11/21). SDFN. Job in Progress. 06/15/2021 - Tuesday 06/14/2021 - Monday Dry tag @ 3740', BOPE test per AOGCC & Hilcorp standards 250/2500 psi. Witnessed waived by Jim Regg (6/11/21). S Rig Start Date End Date CTU 6/14/21 7/2/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name N Cook Inlet Unit A-10A 50-883-20030-01-00 203-075 06/16/2021 - Wednesday Simops mtg w/ production. PJSM & permits. Resume batchmixer tank cleaning. Remove solids from bottom of tank w/ vacuum unit while washing w/ pressure washer & digging out sump w/ extended handle shovel. Unable to get rear batchmixer pod clean enough to blend clean fluid. Able to mix clean fluid in batchmixer front pod. Windwall 3 sides of injector. Move 380 bbl upright tank & spot tank on rig beams. Run fill line from batchmixer to 380 bbl upright tank and supply line from 380 bbl upright tank to fluid pump. Blend 100 bbl of 6% KCl in batchmixer front pod & ship to 380 bbl upright. PU injector & lubricator. MU Power Clean nozzle BHA (BHA1). Move to well. PT WH/BOP & lubricator = 250/4200. Ship 100 bbl of returned fluid in flowback tank to production header/tank. Open swab. T/IA/OA = 44/0/50. RIH w/ BHA1, hold 300 psi @ choke, dry tag @ 3740'. Bring fluid pump online @ 1.40 BPM pump 6% KCl water holding 75 psi WHP @ choke w/ 1:1 returns. Continue to mix 6% KCl in batchmixer front pod & ship to 380 bbl upright. RIH washing, take 75' bites w/ wiper trips back to 3700', pump 6% KCl & 5 bbl Flovis gel pills. Wash to 4052' w/ 1:1 returns w/ black/grey, fine, flour sand in returns. PUH chasing gel sweep to 3200'. RBIH to 4052' & continue washing, w. / 75 - 80' bites & 200' - 300' wiper trips, to tag @ 4319' pumping 6% KCl & 5 bbl gel pills. PUH 20', RBIH & wash past obstruction. Wash to 4375', wiper trip chasing 5 bbl gel sweep to 4200'. 1:1 returns w/black/grey fine, flour sand in returns. RBIH to 4375'. Wash to 4475', pumping 6% KCl & 5 bbl gel pill to 4497'. Wiper trip to 4190' chasing 5 bbl gel sweep. RBIH & wash to 4503' RKB tag depth. PUH 10', RBIH washing. Unable to wash past 4503' RKB, TOP OF AD-2 STOP FISH. Circulate 10 bbl gel pill to end of coil while washing at top of AD-2 stop. 1:1 returns w/black/grey, fine, flour sand in returns. 4503' RKB, POOH @ 50 FPM to 3700' chasing 10 bbl gel sweep w/ 6% KCl @ 1.40 BPM pump rate. Hold 75 psi WHP @ choke Continue POOH to surface @ 65 FPM continuing to pump 1.40 BPM 6% KCl & hold 75 psi WHP @ choke. Return to surface & pull into lubricator. Stop Fluid pump & trap 75 psi WHP @ choke. Close Swab. Secure well & CTU. SDFN. Job in Progress. Final T/IA/OA = 75/0/50. Zero losses to well. Pumped 440 BBL 6% KCL + 60 bbl Flovis gel. Shipped 700 bbl total fluid to production. Sand Volume in Flow Back Tank = 10 - 11 bbl of solids. wash past 4503' RKB, TOP OF AD-2 STOP FISH. Unable to Rig Start Date End Date CTU 6/14/21 7/2/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name N Cook Inlet Unit A-10A 50-883-20030-01-00 203-075 06/17/2021 - Thursday Simops mtg w/ production. PJSM & permits. Rig up. PT BOP & Lub = 4000. Open swab. T/IA/OA = 0/0/50. RIH w/ Power Clean nozzle BHA (BHA1). Dry tag sand top @ 4468' RKB, 35' high. Cleanout to top of AD-2 stop @ 4503' RKB pumping 140 bbl 6% KCl water & 10 bbl Flovis gel pill. 1:1 returns. Chase gel pill OOH to surface. Sand slug in the fluid returns to as CT pulls into lubricator. Close swab, trap250 psi on well. Bleed off surface pressure & stand back from well. LD nozzle BHA. MU GS spear fishing BHA. BHA2 = CTC(2.87"x0.70'), DFCV(2.88"x1.25'), Bi-DI Jar(2.90"x6.60'), Disco(2.88"x2.13'), 4" GS Spear(3.625"x1.9') OAL = 12.63' Disco Ball = 3/4". PT BHA = 3000. Open swab. WHP = 0. RIH to 4400' WT CHK = 10.5K. Dry tag sand top @ 4474' RKB, 29' HIGH. Pump 10 bbl gel pill & displace to end of CT w/ 6% KCL. pumping 1.40 BPM @ 3250 psi CTP. Hold 75 psi @ choke. Wash down to top of AD-2 Stop @ 4503' RKB. Circulate gel to end of CT and then continue circulating 10 bbl gel sweep OOH @ 1.40 BPM w/ 6% KCl water. 1:1 returns, fine sand in gel sweep when returned to surface. Stop pump & stack down to -7K @ 4503' RKB to latch AD-2 Stop. PUH to 25K, FISH ON. 13 jar licks @ 30K followed by 40K straight pulls, release & pull AD-2 Stop free. POOH. to check tools. OOH w/ FISH ON. Lay down AD-2 stop & fishing BHA. MU Power Clean Nozzle BHA. Move to well. Pressure test = FAIL. There are 2 Pinholes in 1-3/4" CT. Lay down nozzle BHA & cut off coil connector. Rig up hydraulic cutting tool to bottom of lubricator. Cut 1-3/4" CT in 15' lengths. Pinhole #1 @ 690'. Continue to cut back 1-3/4" CT. Total Cut Length = 2185'. Pinhole #2 @ ~ 2600''. Will resume cutting back ~ 900' of 1-3/4" CT in morning. SDFN. Job in Progress. Pump Total 260 BBl & shipped same to production. 240 BBL 6% KCL water. 20 BBL Flovis gel 0 losses to well. 06/18/2021 - Friday Simops w/production & PJSM. Continue to cut back 1-3/4" CT in 15' lengths. Total Cut Length = 3100'.Located Pinhole #2 @ ~ 2823', M/U ext. coil connector as per Yellow jacket rep., pull test 20k good. M/U BHA- 1 1/2" power nozzle, 2-4' stinger, xo,dual flapper check valve, EXT CTC = 11.19', Stab injector on, PT 300/4000 good. RIH t/4454', tag fill, up wt 11k, dn wt 1800. Wash down f/4454'CTM t/4715', CTM, PUMP 1.5bpm, 2750PSI, pump 5 bbl gel sweep every 20 min. Attempt to wash past 4715', w/no joy, cont. circulate BU. POOH t/4613', S/d pump wait 30 min, RIH t/tag @4698', P/U t/4600', RIH tag @ 4680'. Wash down t/4715', pump out of hole @ 1.5 BPM , 2515 psi, hold ~400 psi back pressure, CBU clean, s/d pump, cont. hold 400 psi back pressure, RIH tag 4714',POOH, t/surface, holding 400psi back pressure. R/U production to hold 400 psi on wellhead, shut in swab break off coil, break down BHA. R/U w/l. RIH w/shifting tool, t/4288', tag up, work down t/4624' stopped making headway. POOH, L/D shifting tool, P/U Brush. RIH t/4300'wlm, wk down t/ 4715'WLM, P/U work several times f/4600'-4715', POOH. C/O t/shifting tool, RIH t/4629' tag, wk down t/ 4715', cont. work f/ 4640'-4700' unable to locate, inconclusive if sleeve shifted while working down. POOH. Pressure up t/480 psi, R/d & secure well. Production will monitor WHP for night. Pump Total 369 BBl & shipped same to production 344 BBL 6% KCL water. 25 BBL Flo-vis gel. 0 losses to well. Rest crews. , FISH ON. OOH w/ FISH ON. Lay down AD-2 stop /shifting tool, RIH RIH tag 4714',POOH, t/surface, Pressure test = FAIL. There are 2 Pinholes in 1-3/4" CT. RIH w/ Power Clean nozzle BHA (BHA1). Dry tag sand top @ 4468' RKB, 35' high. Continue to cut back 1-3/4" CT in 15' lengths. Total Cut Length = 3100' Cleanout to top of AD-2 stop @ 4503' RKB Located0'.L Pinhole #2 @ ~ 2823', M wk down t/ 4715', cont. work f/ 4640'-4700' unable to locate, inconclusive if sleeve shif release & pull AD-2 Stop free. Cut 1-3/4" CT in 15' lengths. Pinhole #1 @ 690'. Continue to cut back 1-3/4" CT. Total Cut Length = 2185'. Pinhole #2 @ ~ 2600''. W Rig Start Date End Date CTU 6/14/21 7/2/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name N Cook Inlet Unit A-10A 50-883-20030-01-00 203-075 06/27/2021 - Sunday No operations to report. No operations to report. 06/25/2021 - Friday No operations to report. 06/26/2021 - Saturday No operations to report. 06/22/2021 - Tuesday No operations to report 06/23/2021 - Wednesday No operations to report. 06/24/2021 - Thursday Simops meeting with Production. PJSM with w/l. R/U rih w/ brush t/ 4725' wlm, work across sliding sleeve area, w/no significant change in pressure. RIH w/ shifting tool t/ 4715'wlm, unable to locate sleeve @ 4665' (could be closed) POOH. R/D wireline, R/U coil, m/u ext CTC, pull test 20k & pressure test 4k good, M/U Milling BHA -3.2" rev clutch junk mill, 2 7/8" mud mtr, circ sub, (5k burst, 5/8" ball) Ty disconnect sub (3/4" Ball), Jars, dual flapper chack valve, ext CTC =24.48', stab injector t/lubricator, test 300/4k good. Production bleed well down t/80 psi, RIH t/4280', tag up p/u & pump through no issue, cont. rih tag @ 4693', p/u pump through made 2 runs then dropped through. Cont. wash down f/4710' pump 1.3 BPM, 2650 psi, increase t/1.6 bpm, 3220 psi, wash down t/4802' pressure increase appeared to stall, s/d pump, p/u off bottom, start pump 1.6 bpm 3610 psi, rih tag btm adjust parameters, not making headway, & no pressure increase when stacking weight, P/u off bottom try different flow rates troubleshoot motor, could not get over 1.6bpm with pump through motor. POOH to inspect BHA, call out for 2 1/8" assembly for option. @ 900' found hole in coil, cont. POOH secure well & break off injector. L/D BHA. Rig up hydraulic cutting tool to bottom of lubricator. Cut 1-3/4" CT in 15' lengths to hole in pipe @912', m/t batch mix tanks into upright & flush, send well returns to production. Pump Total 190 BBl & shipped same to production. 185 BBL 6% KCL water. 5 BBL Flo-vis gel. 10 bbl losses to well. 06/20/2021 - Sunday Simops meeting with production, PJSM, line up & blow down coil. N/D BOPE & install well cap. Disconnect lines & prep eq. to back load boat (needed on beach to spool new coil). Call boat in, backload boat, Suspend work until new coil is mobed out, demobe crew to beach. 06/21/2021 - Monday No operations to report 06/19/2021 - Saturday RIH w/ shifting tool t/ 4715'wlm, unable to locate sleeve @ 4665' (could be closed) Cut 1-3/4" CT in 15' lengths to hole in pipe @912', @ 900' found hole in coil, Rig up hydraulic cutting tool to bottom of lubricator. blow down coil. Rig Start Date End Date CTU 6/14/21 7/2/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name N Cook Inlet Unit A-10A 50-883-20030-01-00 203-075 Simops mtg w/ production. PJSM & permits. MU BHA: CTC(2.25'x 0.85'), DFCV(2.13" x 0.98'), BI-DI Jar(2.15" x 6.20'), Disco(2.13" x 1.58'), Circ Sub(2.13" x1.08'), Motor(2.13" x10.45'), Tapered Mill(2.70" x 0.88') OAL = 22.02' Disco ball = 5/8". Circ Sub ball = 1/2" w/ 5K burst disc. Pull test CTC = 20K. Press test BHA = 3500 psi. Move to well. PT WHA/BOP & lubricator = 4180 psi. Open swab (35T). T/IA = 0/0. RIH w/ 2.70" taper mill & motor to 4640' dry tag depth (150' above 6/20 report date final depth). PUW =10K. Mill ahead. PR = 1.25 bpm pumping 6% KCl water & 5 bbl Flovis gel sweeps, free spin = 2700 psi, WHP =13 psi w/ 1:1 retrurns. 2 stalls @ 4640'. 3 stalls @ 4660'. Milll to 4750' @ 6 FPM. Continue milling ahead. 4890' milling @ 10FPM, 1.25 bpm 6% KCl water & 5 bbl gel sweeps @ 2900 psi, whp = 15 w/ 1:1 returns containing fine sand. Mill ahead to 5300' stall. 2 stalls, mill ahead w/ motor work, 5365' milling ahead @ 17 FPM, 1.25 bpm 6 % KCl & gel sweeps @ 2775 psi. 1:1 returns w/ heavier concentration of coarse sand mixed w/ coal in returns. Mill to 5475'. Wiper trip, PUW = 14K. PR = 1.25 bpm, WHP = 25 psi. PUH @ 4700' pumping 1.40 bpm @ 3300 psi, leak @ 1502 iron x CT connection. SD pump, check leak. Failed 1502 connection gasket. Bring pump online @ 0.4 bpm @ 565 psi, no leak. Continuous sand in returns. POOH @ 60 FPM while continuing to circulate 6% KCl water at 0.4 bpm & 550 psi. OOH. Close swab. Bleed pressures. Replace failed 1502 gasket. PT = 4000 psi - PASS SDFN. Job in Progress. Total Pump Volume = 275 bbl. 245 bbl 6% KCl water + 30 bbl Flovis gel. Shipped 175 bbl 6% KCl to production. 06/28/2021 - Monday Simops mtg w/ production. PJSM & permits. Continue RD & move off of B-02. Unstab pipe from injector. Break down hyd. lines to injector & reel. Break down power line from generator to console. Move injector & BOP skids, power pack, lubricator box & basket to Leg 2. Spin CT reel 180 degrees & spot on deck for Well A-10A. Spot console behind reel. RU equipment & prep for BOP test. Test BOPE as per Hilcorp & AOGCC requirements, witness waived By AOGCC inspector Jim Regg @ 10:01 am 6-26-21, Perform drawdown test good, tested 250 low 4000 high all tests good. Run hoses from batchmixer to drill water supply & upright supply tank. Blend & ship 100 bbl 6% KCl water to supply tank. Drift 1.75" CT w/ 1.125" OD ball displacing ball w/ 30 bbl 6% KCl. MU CT connector. Secure injector, well & drill deck. SDFN. Job in Progress. 06/29/2021 - Tuesday 1:1 returns w/ heavier concentration of coarse sand mixed w/ coal in returns. M Continuous sand in returns. Milll to 4750' @ / motor work, 5365' milling ahead @ Rig Start Date End Date CTU 6/14/21 7/2/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name N Cook Inlet Unit A-10A 50-883-20030-01-00 203-075 06/30/2021 - Wednesday Simops mtg w/ production. PJSM & permits. RU CTU. MU BHA: CTC(2.25'x 0.85'), DFCV(2.13" x 0.98'), BI-DI Jar(2.15" x 6.20'), Disco(2.13" x 1.58'), Circ Sub(2.13" x1.08'), Motor(2.13" x10.45'), Tapered Mill(2.70" x 0.88') OAL = 22.02'. Disco ball = 5/8", Circ Sub ball = 1/2" w/ 5K burst disc. Move to well. PT WHA/BOP & Lub = 4100 psi. Open swab & RIH to 5090' dry tag. PU, bring fluid pump online w/ 6% KCl water @ 1.20 bpm w/ 3150 psi free spin. 1:1 returns @ 16 psi WHP. RBIH & wash clean past obstruction. Continue cleanout milling ahead @ 13 FPM pumping 6% KCl water & 5 bbl Flovis gel sweeps. Take 125' bites w/ 250' wiper trips to 6329'. 1:1 returns, WHP = 15 psi, w/ coarse sand in fluid returns. 6329' continue cleanout milling ahead @ 10 FPM. 1.20 bpm 6% KCl water & 5 bbl gel sweeps taking 125' bites & 300' wiper trips. WHP = 20 w/ 1:1 returns. Coarse sand & small amount of coal/shale in fluid returns. Motor work @ 6546' & 6636'. 6840' lose returns, WHP = 3. PUH while continuing to pump 6% KCl @ 1.40 bpm. PUH 200' & regain 1:1 returns @ surface. WHP = 15 psi. RBIH & continue cleanout @ 6840' milling ahead @ 6 FPM pumping 6% KCl & 5 bbl gel sweeps. Take 125' bites & 300' wiper trips. 7582' WHP = 20 psi. Mill ahead to 7750', PUH for 250' wiper trip. 1:1 returns contain sand & solids. RBIH & take final bite to 7970' RKB end of tubing. POOH pumping 1.30 bpm 6% KCl water chasing 5 bbl gel sweep to surface @ 80 FPM. Shut down pump & pull into lubricator. Close swab & bleed surface pressures. LD motor & mill. Secure injector, well & drill deck. SDFN. Job in Progress. Total Volume Pumped = 834 bbl. 734 bbl 6% KCl water + 100 bbl Flovis gel. Shipped 650 bbl total fluid volume shipped to production. 0 bbl losses to formation. 07/01/2021 - Thursday Simops mtg w/ production. PJSM & permit. MU nozzle BHA for drift run. BHA: CTC(2.25'x 0.80'), DFCV(2.13" x 0.98'), Stinger (2.13" x 4.0') Stinger (2.25" x 4.0'), Disco(2.13" x 1.58'),JSN(2.13" x 0.80') OAL = 12.16'. Disco ball = 5/8". Move to well. PT = 4100 psi. Ship 120 bbls of 6% KCl returned fluid to production header. Open swab. T/IA = 0/0 psi. RIH w/ 2-1/8" nozzle for dry tag to 7970' RKB. Paint flag @ 7923' RKB & POOH pumping for CT displacement. OOH. Close swab & bleed off all surface pressures. Stand back from well & LD nozzle BHA. MU Caliper Log Tool Suite. BHA: CTC(2.25'x 0.80'), DFCV(2.13" x 0.98'), Stinger (2.13" x 4.0'), Disco(2.13" x 1.58'), Read Memory Caliper Tool(1.69'" x 14.70') OAL = 22.73'. Disco ball = 5/8". Move to well. PT = 4100 psi. Open swab & RIH to 7933' RKB flag depth & park coil. 7933' RKB waiting on caliper tool suite timer to initiate memory data recorder @ 14:47. Log up w/ caliper tool suite @ 50 FPM to 4100'. Park & wait for memory data recorder to time out while circulating 6% KCl water & 10 bbl Flovis gel. 4100' POOH. Close swab & bleed surface pressures. Stand back from well. LD memory caliper tool. Down load memory data - GOOD DATA. Start CTU rig down. Blow CT reel dry w/ N2. RD all pumping iron & flowback iron. Ship 230 bbl of well return fluids to production header. RD supply and suction lines to upright tank. RD N2 supply lines.Secure injector, well & drill deck. SDFN. Continue RD in morning & prep for backload to boat. Pump 197 BBL fluid. 0 losses to well. Shipped 350 bbl fluid to production. 340 of 6% KCl water + 10 bbl Flovis gel. RBIH & take final bite to 7970' RKB end of tubing. Read Memory Caliper Tool( r dry tag to 7970' RKB. Paint flag @ 7923' RKB & MU Caliper Log Tool Suite. Rig Start Date End Date CTU 6/14/21 7/2/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name N Cook Inlet Unit A-10A 50-883-20030-01-00 203-075 07/02/2021 - Friday Simops mtg w/ production. PJSM & permits. Continue CTU RDMO prepping for backload to boat. Unstab pipe from injector. RD BOP & riser, normal up tree. Roll up all hydraulic lines from reel & injector. SD generator & roll up power line from console. Remove Injector gooseneck. Backload CTU equipment to M/V Masco Endeavor. Backload Fluid pump, console, reel, batch mixer, N2 pump, (2) N2 tanks, power pack, toolbox/doghouse, gooseneck basket & iron rack. M/V Endeavor away from platform & waiting for tide change. Waiting on tide change. M/V Endeavor returns to platform. Backload Injector. M/V Endeavor pulls away from platform due to high wind & seas. Release M/V Endeavor to return w/ load to OSK Dock. Wait on helicopter. Fly CTU crew to the beach. Job Complete. e CTU RDMO David Dempsey Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 07/15/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Please include current contact information if different from above. Received By: 07/16/2021 37' (6HW By Abby Bell at 9:07 am, Jul 16, 2021 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): North Cook Inlet Unit / Tertiary Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 8,840'4,462' Casing Collapse Structural Conductor Surface 1,580 psi Intermediate Production 4,790 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: CTCO N/A Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size N/A 366' COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 203-075 50-883-20030-01-00Anchorage, AK 99503 Hilcorp Alaska, LLC N Cook Inlet Unit A-10A 12.6 / L-80 & 9.3 / L-80 TVD Burst 7,764' & 7,972' 6,890 psi Tubing Size: MD 3,130 psi 631' 1,839' 631' 1,911' 366'366' 30" 16" 10-3/4" 631' 1,911' 8,830' Perforation Depth MD (ft): 4,415 - 7,905 8,830' See Schematic Tubing Grade:Tubing MD (ft): 3,648 - 6,128 Perforation Depth TVD (ft): Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 6/1/2021 4-1/2" & 3-1/2" Daniel E. Marlowe See Schematic 6,882'3,938'3,326'656 psi 6,874'7-5/8" Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 9:20 am, May 07, 2021 321-233 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.05.06 17:32:58 -08'00' Dan Marlowe (1267) Tertiary System Gas Pool BOP test to 2500 psi. BJM 5/14/21 10-404 DSR-5/10/21 X SFD 5/7/2021 SFD 5/7/2021 dts 5/17/2021 JLC 5/17/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.05.17 11:20:06 -08'00' RBDMS HEW 5/19/2021 Well Work Prognosis Well: A-10A Date: 04/28/2021 Well Name:Tyonek A-10A API Number: 50-883-20030-01-00 Current Status:Gas Producer (Gas Lifted)Leg:2 Estimated Start Date:06/01/2021 Rig:Coil Tubing Reg. Approval Req’d? Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett 777-8332 Permit to Drill Number:203-075 First Call Engineer:Katherine O’Connor (907) 777-8376 (O) (214) 684-7400 (M) Second Call Engineer:Karson Kozub (907) 777-8434 (O) (907) 570-1801 (M) Current Bottom Hole Pressure: 728 psi @ 5379’ TVD Maximum Expected BHP: 728 psi @ 5379’ TVD) Maximum Potential Surface Pressure:656 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary In April 2012 an AD-2 Stop was set as a catcher sub @ 4,462’ prior to performing a GLV change out of GLV# 1-4. SLU attempts to retrieve the AD were unsuccessful due to high sand tag. Sand top tagged at 3,938’ on 1/24/15 prior to SBHP survey. This procedure will utilize a coil tubing clean out tubing to AD-2 stop, fish the AD-2 Stop with slickline, continue cleanout to TD and run a caliper to determine if there are any damaged screens that may need to be patched to prevent sand production. Procedure: 1. MIRU Coil Tubing 2. NU BOP and test to 250psi low / 2,500psi High. (Note: Notify AOGCC 48 hours in advance of test) 3. RIH cleaning out fill to ± 4,462’ (top of AD-2 Stop) using 6% KCl and N2 as needed. 4. POOH with coil. 5. MIRU slickline P/T lubricator to 250 low/ 1500psi High. 6. Fish AD-2 stop with SLU. 7. RIH with CT cleaning to ± TD. Circulate bottoms up using N2 assist as needed. 8. POOH with coil. 9. MIRU slickline P/T lubricator to 250 low/ 1500psi High. 10. Run caliper from ±7780’ MD to surface a. If caliper shows damaged screen or tubing attempt to set straddle patch across screen 11. Turn well over to Operations for flow back. Attachments: 1. Well Schematic Current / Proposed (Same) 2. Coil Tubing BOP Drawing 3. Standard Well Procedure – Nitrogen Operations 4. Flow Diagrams 5. RWO Sundry Revision Change Form _____________________________________________________________________________________ Updated By: PJR 06/29/17 SCHEMATIC Tyonek Platform Well: A-10A Last Completed: 9/5/2003 PTD: 203-075 API: 50773-20030-01 PBTD: 8,749’ (MD) TD: 8,840’ (MD) 23 30” RKB to TBG Head – 43.8’ 7-5/8” 1 4 2 3 4 9 5 7 8 18 10 11 12 6 16” 10-3/4” 1 16 Sand tagged 3,938 1/24/15 19 13 13 14 15 20 24 10-3/4” window @ 1,911’ 17 22 21 4 X X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” 120.0 H-40 WELDED 27” 41’ 366’ 16” 62.5 H-40 WELDED 15.062” 41’ 631’ 10-3/4” 40.5 J-55 BTC 10.050” 41’ 1,695’ 10-3/4” 45.5 J-55 BTC 9.950” 1,695’ 1,911’ 7-5/8” 29.7 L-80 BTC 6.875” 44’ 8,830' TUBING DETAIL 4-1/2” 12.6 L-80 IBT-mod 3.958” 43.8’ 7,764’ 3-1/2” 9.3 L-80 IBT-mod 7,765’ 7,972’ GRAVEL PACK 4” 9.5 L-80 IBT-mod 3.548” 4,694’ 7,564’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 414’ 414’ 3.813 6.000 Safety Valve, Camco 4-1/2” TRM-4PE CF TRSSSV 2 1,356’1,336’ 3.865 6.059 GLM#, 1 Camco KBG-2, BK latch, Port = 0.188”, TRO = 1375 psi 3 2,398’2,268’ 3.865 6.059 GLM#2 Camco KBG-2, BK latch, Port = 0.188”, TRO = 1375 psi 4 3,386’2,951’ 3.865 6.059 GLM#3 Camco KBG-2, BK latch, Port = 0.188”, TRO = 1375 psi 5 4,221’ 3.865 6.059 GLM#4, Camco KBG-2, BK latch 6 4,277’ 3,555’ 3.958 5.563 PBR 80-47, 15’ seal travel 7 4,307’ 3,575’ 3.875 6.500 Packer, Baker Premier 8 4,462’ 3,680’ 0.000 Fish, AD-2 Stop(4/6/12) 9 4,665’ 3,817’ 3.813 5.500 Sleeve, Baker CMU Sliding, OPEN 10 4,708’ 3,845’ 3.280 4.218 Anchor Latch, Baker S-22 11 4,709’ 3,846’ 4.000 6.490 Packer, Baker SC-2 4,799’ 3,906’ 3.548 4.590 Screen, Bakerweld, .012 ga. 12 5,017’ 4,049’ 3.250 6.490 Packer, Baker SC-1L Multizone 13 5,611’ 4,436’ 3.250 6.490 Packer, Baker SC-1L Multizone 5,672’ 4,436’ 3.548 4.590 Screen, Bakerweld, .012 ga. 14 6,208’ 4,854’ 3.280 4.218 Snap Latch, Baker S-22 15 6,209’ 4,854’ 4.000 6.490 Packer, Baker SC-2 6,293’ 4,915’ 3.548 4.590 Screen, Bakerweld, .012 ga 16 6,716’ 5,230’ 3.250 6.490 Packer, Baker SC-1L Multizone 6,814’ 5,304’ 3.548 4.590 Screen, Bakerweld, .012 ga 17 7,181’ 5,581’ 3.250 6.490 Packer, Baker SC-1L Multizone 7,264’ 5,643’ 3.548 4.590 Screen, Bakerweld, .012 ga 18 7,564’ 5,866’ 3.280 4.218 Snap Latch, Baker S-22B 19 7,565’ 5,866’ 4.000 6.500 Packer, Baker FB-1 Sump Packer 20 7,764’ 6,019’ 3.940 5.375 XO, 4.5 X 3.5 21 7,797’ 6,044’ 2.813 4.250 Nipple, X 22 7,830’ 6,070’ 3.548 5.020 Screen, SLHT Excluder 23 7,938’ 6,153’ 2.813 4.250 Nipple, X 24 7,970’ 6,178’ 2.992 3.800 Wireline Entry Guide Note: 9/3/2003 Three Radioactive (RA) 7-5/8” casing couplings @ 4366’, 5879’ & 7450’ Note: 9/3/2003 Radioactive (RA) collars @ 581’, 6011’, 6396’, 6907’ & 7377’ SCHEMATIC A-10A Schematic Page 2 of 2 06/29/2017 PJR Tyonek Platform Well: A-10A Last Completed: 9/5/2003 PTD: 203-075 API: 50773-20030-01 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf Comments Sterling 4,415’ 4,428’ 3,648’ 3,656’ 13’ 9/15/2003 TCP Guns CI-A 4,454’ 4,487’ 3,674’ 3,697’ 33’ 9/15/2003 TCP Guns CI-1 4,805’ 4,905’ 3,910’ 3,976’ 100’ 9/5/2003 Gravel Packed Slots CI-2 4,920’ 5,005’ 3,985’ 4,041’ 85’ 9/5/2003 Gravel Packed Slots CI-10 5,685’ 5,700’ 4,486’ 4,496’ 15’ 9/5/2003 Gravel Packed Slots Beluga A 5,894’ 5,914’ 4,629’ 4,643’ 20’ 9/5/2003 Gravel Packed Slots Beluga B 6,090’ 6,105’ 4,769’ 4,779’ 15’ 9/5/2003 Gravel Packed Slots Beluga C 6,185’ 6,195’ 4,837’ 4,844’ 10’ 9/5/2003 Gravel Packed Slots Beluga D 6,300’ 6,310’ 4,921’ 4,928’ 10’ 9/5/2003 Gravel Packed Slots Beluga D 6,450’ 6,525’ 5,031’ 5,086’ 75’ 9/5/2003 Gravel Packed Slots Beluga E 6,646’ 6,665’ 5,177’ 5,191’ 19’ 9/5/2003 Gravel Packed Slots Beluga F 6,685’ 6,710’ 5,207’ 5,226’ 25’ 9/5/2003 Gravel Packed Slots Beluga G 6,825’ 6,865’ 5,313’ 5,343’ 40’ 9/5/2003 Gravel Packed Slots Beluga H 7,010’ 7,028’ 5,452’ 5,466’ 18’ 9/5/2003 Gravel Packed Slots Beluga I 7,165’ 7,175’ 5,569’ 5,577’ 10’ 9/5/2003 Gravel Packed Slots Beluga J 7,270’ 7,280’ 5,647’ 5,655’ 10’ 9/5/2003 Gravel Packed Slots Beluga L 7,425’ 7,450’ 5,762’ 5,781’ 25’ 9/5/2003 Gravel Packed Slots Beluga M 7,515’ 7,555’ 5,829’ 5,859’ 40’ 9/5/2003 Gravel Packed Slots Beluga P 7,830’ 7,905’ 6,070’ 6,128’ 75’ 9/5/2003 Gravel Packed Slots Coiled Tubing BOP SWAB VALVE MASTER VALVE HilcorpMonopod Rig 56Flow Diagram Fluids Pumped Fluids ReturnedValve Open Valve ClosedGate Valve Ball ValveButterfly Valve Lo Torq ValveAutomatic Choke Manual ChokePressure Gauge Knife ValveChoke LineP PIT SYSTEM SucƟon SHAKER SHAKER CHOKE MANIFOLDGAS BUSTER Panic LineC12 C13 C15 C14 C16 A B C4 C5 C6 C7 C2 C10 C9 C11 C8 C3 P C1 C STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review 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 Nitrogen Tank. 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/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 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 Tank. Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: N Cook Inlet Unit A-10A (PTD 203-075)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date Well Name Pre 2008 Survey Location NAD27 ASP 4 Northing Easting Post 2008 Survey Location NAD27 ASP4 Northing Easting Distance Moved NCI A-01 2,586,726.69 332,100.19 2,586,726.40 __ 332,102.26 _ 2.09 _ NCI A-02 _ __ 2,586,722.85 332,108.29 _ _ 2,586,721.16 332,111.27 3.43 NCI A-03 - 2,586,728.60 -- 332,106.22 2,586,728.31 332,109.43 3.22 NCIA-04 2,586,719.62 332,105.09 2,586,718.58 _ 332,108.09 _ 3.18 __ ___ NCI A-05 2,586,725.55 332,110.17 2,586,725.14 332,111.79 1.67 NCI A-06 2,586,719.66 332,102.09 2,586,719.22 332,104.19 2.15 NCI A-07 2,586,727.79 332,103.73 2,586,728.78 332,105.40 1.94 NCI A-08 2,586,720.56 332,098.31 2,586,722.44 332,101.65 3.83 NCI A-09 2,586,666.58 332,039.08 2,586,667.35 332,040.44 1.56 NCI A-10 2,586,670.21 332,040.91 2,586,673.71 _332,044.17 _ __ 4.78 NCI A-10A _ 2,586,670.21 332,040.91 __ 2,586,673.71 332,044.17 ___ 4.78 NCI A-11 __ 2,586,670.23 332,039.14 : 2,586,677.01 332,041.75 7.27 NCI A-12 --- 2,586,722.73 _ 331,947.80 - --- 2,586,723.59 331,994.15 46.36 NCI A-13 2,586,734.88 331,993.50 2,586,733.15 331,995.48 2.63 NCI B-01 2,586,730.03 331,999.80 2,586,723.04 331,998.16 7.18 NCI B-01A 2,586,730.03 331,999.80 . 2,586,723.04 331,998.16 7.18 NCI B-02 2,586,731.14 331,999.29 2,586,729.60 332,001.86 3.00 NCI B-03 2,586,731.69 331,986.37 2,586,726.81 331,991.70 7.23 NCI B-03PB1 2,586,731.69 331,986.37 2,586,726.81 331,991.70 7.23 • • 2aos REV DATE BY CK APP SCRIPTION REV DATE BY CK DESCRIPTION I 2/29/08 SAS K W,[a MOOIFY WELL HOUSE SCHEMA TIC, SHT.2 AOD MUD LINE ELEV., SHT.3 ~~r ~ ~ 36 31 T 12 IV 31 32 9p; ¢ Y ~"a ~ 1 6 T II N 6 5 N rw xa N ~./-~ S. 19'15' ~ ' / SE . 6 IC L/ v ' SCALE: I"-1320' ----6- ~ ~ ~ o ~ ~ 1 6 6 5 12 7 ~ g GENERAL NOTES: ~~ OF ~~ EE .......... ~,q !~ .• 1. SEE SHEET 3 FOR COORDINATE TABLE P • s ~ . ~ ~ '~ ••%1~ ~ '••• 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND i • ~ i ~ • • ~ VERTICAL SURVEY DATA r ; 49th : ~~ r ' ..... 3. SECTION LINES AND TIES ARE BASED ON PROTRACTED ~ """""""""""""""""""""' VALUES. ....................... ........ . ... . ' ~ c ~ ~ ~ ~' •% KENNETH W. AYERS moo; . • • ~~ J' ',• LS-8535 •.• ~~: • J ~ ~`~ • SURVEYOR'S CERTIFICATE '~FO ''••.•, •.••'• 1 o~ i A .......... N / I HEREBY CERTIFY THAT 1 AM PROPERLY REGISTERED AND ,~~~~;~ ~=~~~~~~ LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DONE BY LOUNSBURY DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF & assoc[n'rES, INC. SURVEYORS ENGINEERS PWNNERS FEBRUARY 28, 2008. ~ ~ PHONE: (907/ 272-5451 AREA: MODULE: UNIT: ConocoPhilli s NORTH COOK INLET p TYONEK PLATFORM Alaska, Inc. WELL CONDUCTOR AS BUNT CADD FILE N0. 08-005 AS BUILT 02/27/08 DRAWING N0: 08-005 AS BUILT PART: 1 of 3 REV: 1 REV DATE BY CK APP SCRIPTION REV DATE BY CK DESCRIPTION 1 2/29/08 SAS KWA MODIFY WELL HOUSE SCHEMATIC, SHT.2 ADD MUD LINE ELEV., SHT.3 x v ~ ~r W ~ ~S ~ A~ 9 z~3 s` Aa9 riN R0 SO s. ro•u. uv, scc e ~ ~ ~~ so .`rs SCALE: 1"=30' a9 kp. O SD 600 -50 E ESD 600-51 8 A13 7 I p •92 AI A• A8 • B3•• •p5 • A3• A6 A12 BI :••AS A4 A2 WELL HOUSE 2 Op• 2p A1O0 LEGEND: p• 3 A9 • WELL p WELL CONDUCTOR 0 ESD (EMERGENCY SHUT OFF VALVE) GENERAL NOTES: 1. SEE SHEET 3 FOR COORDINATE TABLE 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND VERTICAL SURVEY DATA LOUNSBURY 3. NO WELLS EXIST IN WELL HOUSE N0. 4, AND IT WAS NOT & ASSOCIATES, INC. AS BUILT SURVEYORS ENGINEERS PLANNERS D PHONE: (9071 272-5451 AREA: MODULE: UNIT: ConocoPhilli s NORTH COOK INLET p TYONEK PLATFORM Alaska, Inc. WELL CONDUCTOR AS BUILT CADD FILE N0. DRAWING N0: PART: REV: 08-005 AS BUILT 02/27/08 ~g-~~5 AS BUNT 2 of 3 1 REV DATE BY CK APP DESCRIPTION I 2/29/08 SAS KWA MODIFY WELL HOUSE SCHEMATIC, SH T.2 ADD MUD LINE ELEV., SHT.3 ASP ZONE4, NAD83, FEET NAD133 GE OGRAPHIC MLLW DESCRIPTION (POINT NO.) NORTHING FASTING LATITUDE LONGITUDE ELEVATION NCIU W ELL TAG NO. WELL HOUSE NO. 1 1001 2586492 1472018 61 04 34.38 150 57 03.71 72.0 Conductor 1 1002 2586489 1472017 61 04 34.34 150 57 03.72 73.9 B3 1003 2586485 1472019 61 04 34.31 150 57 03.67 74.1 A12 1004 2586485 1472023 61 04 34.31 150 57 03.59 73.8 B1 1005 2586487 1472027 61 04 34.33 150 57 03.52 72.0 Conductor 5 1006 2586491 1472027 61 04 34.37 150 57 03.52 73.7 B2 1007 2586495 1472025 61 04 34.41 150 57 03.57 72.1 Conductor 7 1008 2586495 1472021 61 04 34.41 150 57 03.65 73.7 A13 WELL HOUSE N0.2 2001 2586437 1472060 61 04 33.84 150 57 02.83 71.9 Conductor 1 2002 2586433 1472059 61 04 03.38 150 57 02.84 71.9 Conductor 2 2003 2586430 1472062 61 04 33.77 150 57 02.79 71.8 Conductor 3 2004 2586429 1472066 61 04 33.77 150 57 02.71 73.4 A9 2005 2586431 1472069 61 04 33.79 150 57 02.65 71.9 Conductor 5 2006 2586435 1472069 61 04 33.83 150 57 02.64 73.3 A10 2007 2586439 1472067 61 04 33.86 150 57 02.69 73.3 A11 2008 2586439 1472063 61 04 33.87 i 50 57 02.77 71.9 Conductor 8 WELL HOUSE N0.3 3001 2586488 1472128 61 04 34.36 150 57 01.47 73.0 Al 3002 2586484 1472127 61 04 34.32 150 57 01.48 73.1 A8 3003 2586481 1472130 61 04 34.29 150 57 01.43 73.1 A6 3004 2586480 1472133 61 04 34.28 150 57 01.35 73.0 A4 3005 2586483 1472137 61 04 34.31 150 57 01.29 73.0 A2 3006 2586487 1472137 61 04 34.34 150 57 01.28 73.0 A5 3007 2586490 1472135 61 04 34.38 150 57 01.33 73.0 A3 3008 2586490 1472131 61 04 34.38 150 57 01.41 73.3 A7 50 2586540 1472069 61 04 34.86 150 57 02.69 72.7 ESD Valve 600-50 51 2586501 1472011 61 04 34.46 150 57 03.86 72.6 ESD Valve 600-51 100 2586572 1472123 61 04 35.18 150 57 01.58 115.3 Top center helipad -101' MUD LINE SURVEY NOTES: 1. ALL COORDINATES ARE ASP ZONE 4, NAD83, US SURVEY FEET. GEOGRAPHIC COORDINATES ARE NAD83. 2. ELEVATIONS ARE IN FEET, BASED ON MLLW, REFERENCED TO DRAWING N0. MPD- TY04-2021, SHEET 1 OF I, REV. 2 3. ALL AS BUIL TS ARE TO THE CENTER OF EXISTING STRUCTURE. 4. WELL CONDUCTOR ARE VERTICALLY AS BUILT TO THE TOP OF A 1/4" STEEL LID, TACK WELDED TO THE TOP OF THE CONDUCTOR. 5. WELLS ARE VERTICALLY AS BUILT TO THE TOP OF THE LOUNSBURY LOWEST HORIZONTAL FLANGE ON THE WELL. & nssoclnTES, irrc. SURVEYORS ENGINEERS PLANNERS ~ ~ PHONE: f907J 272-5451 `..~ AREA: MODULE: UNIT: ConocoPhillips NORTH COOK INLET TYONEK PLATFORM Alaska, Inc. WELL CONDUCTOR AS BUILT CADD FILE N0. DRAWING N0: PART: REV: 08-005 AS BUILT 02/27/08 08-005 AS BUILT 3 of 3 1 • • --~,~ ~- -~, 1l ~ • t 03101 /2008 DO NOT PLACE ., _; .~~' ~a> ~' ~; .,_ ANY NEW MATERIAL UNDER THIS PAGE F: ~LaserFiche\CvrPgs_Inserts\Microfilm_Marker. doc Åì ÒJ\ DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2030750 Well Name/No. N COOK INLET UNIT A-10A Operator CONOCOPHILLlPS ALASKA INC J.,t'VL. ~ L ~)- API No. 50-883-20030~q-OO MD 8840 /" TVD 6882 /" Completion Date 9/28/2003 /' Completion Status 1-GAS Current Status 1-GAS UIC N ---_.,~_._--~._---_._- REQUIRED INFORMATION Mud Log No Samples No .....- . ~ Direction~§1.~· .........;..~. ~..... ~- DATA INFORMATION Types Electric or Other Logs Run: GR/Res/Dens-Neutrön, CBL Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No Interval OH / Start Stop CH . Received Comments Rpt Report: Final Well R 0 0 9/18/2003 In Well History File ~ Mud Log M(;)I1"v.Þ t"~."'11 2 Col 1910 8840 Open 9/18/2003 Formation Log - in Well History File w/End of Well Report (Óg' Induction/Resistivity 1 2 Col 1910 8840 Open 9/18/2003 DML - MWD Combo Log - In Well History File w/End M fJ!ìtlD of Well Report ~g Lithology 2 Col 1910 8840 Open 9/18/2003 DML - MWD Combo Log - I 'r-Wt:. t.v.) t In Well History File w/End ~Og of Well Report Rate of Penetration 2 Col 1910 8840 Open 9/18/2003 DML - MWD Combo Log - ~ in Well History File w/End ¿ of the Well Report Mud Log 2 Myl 1910 8840 Open 9/18/2003 MD . '-'d5 C Pds 4fñ Report: Final Well R 0 0 10/28/2003 ~D C Pds -r2167 Formation Micro Ima 1850 8128 Open 10/28/2003 ED C Asc 12171 LIS Verification 1806 6770 Open 10/28/2003 ED C Pds 12171 Density 1593 8802 Open 10/28/2003 MWD - Also a Field I=D ~171 Density on CD #12170 C Pds Sonic 1593 8802 Open 1 0/28/2003 MWD ED C Pds 12171 Induction/Resistivity 1593 8802 Open 10/28/2003 MWD - Also a Field Resistivity on CD #12170 ED C Pds 12171 See Notes 1593 8802 Open 1 0/28/2003 MWD - Vision Service - Also a Field Service on CD #12170 ..£0 C Pds /12169 Cement Evaluation 1593 8734 Case 1 0/28/2003 Cement Bond Log DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2030750 Well Name/No. N COOK INLET UNIT A-10A Operator CONOCOPHILLlPS ALASKA INC API No. 50-883-20030-01-00 2 8840 2':.D 6882 Completion Date 9/28/2003 Completion Status 1-GAS Current Status 1-GAS UIC N ",. "____0'. ____._._______".____.._~"_.___.,_____.~____n.."'_·~'_~·_.~~,..____~_"____._~_~_ C Pds 12169 Formation Micro Ima 1593 8734 Open 10/28/2003 Modular Formation Imager ....eD C Pds ~68 Sonic 1850 8128 Open 1 0/28/2003 Dipole Shear Sonic Tool ED D Exc Directional Survey 378 88400 11/6/2003 Also a text file on disk ~ Cement Evaluation 5 Blu 1600 8747 Case 11/6/2003 Cement Bond Log - .~ Gamma Ray Sonic tit I) ITV b 25 Blu 1894 8117 Open 11/6/2003 Dipole Shear Sonic Tool, Upper & Lower Dipole, P&S . oIGg Induction/Resistivity M t:> )'111 ~ 25 Blu 2-4 1900 8840 Open 11/6/2003 Vision Resistivity ;;¡ Density ""-D rv D 25 Blu 1900 8840 Open 11/6/2003 See Vision Service TCB Log, individual Density Neutron Log culled. .; Log Neutron 25 Blu 1900 8840 Open 11/6/2003 See Vision Service TCB Log, individual Density Neutron Log culled. ED C eøs&.U 12419 Production 4238 7646 Case 2/24/2004 Production Profile w/PressurefT emp/Spinner ED C ..f'dS 1,P/12419 Production 4238 7646 Case 2/24/2004 Production Profile ~ w/PressurefT emp/Spin ner PInrl~....LU.J1 r 4238 7646 Case 2/24/2004 Production Profile ('1 w/PressurefT emp/Spin ner '_og Production 5 BS 4238 7646 Case 2/24/2004 Production Profile I w/Pressu refT emp/Spin ner ,/-Og Pressu re 5 BS 4238 7646 Case 2/24/2004 Production Profile BS/ w/Pressu refT emp/Spi nner . Log Temperature 5 4238 7646 Case 2/24/2004 Production Profile w/Pressu refT emp/Spinner Log Spinner 5 B~ 4238 7646 Case 2/24/2004 Production Profile w/PressurefT em p/Spinner ------'-- Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2030750 Well Name/No. N COOK INLET UNIT A-10A Operator CONOCOPHILLlPS ALASKA INC MD 8840 Completion Status 1-GAS TVD 6882 Completion Date 9/28/2003 ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? .J Chips Received? Y I N Formation Tops Analysis Received? ~:IJ ----.--"----- Comments: Compliance Reviewed By: _._----_._._._~---- API No. 50-883-20030-01-00 Current Status 1-GAS (öN ~/N Date: UIC N /K-DÅ~~{ - . . It ConocóP'hillips e Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 May 10, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for NCI A-10A (203-075) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforating operations on the North Cook Inlet well A-1 OA. The perforations listed in this report are below the P A and were considered "exploratory" in nature. A verbal agreement had been reached in 2003 between AOGCC and ConocoPhillips to perforate the interval in order to evaluate its commercial productivity. If the interval was found productive, steps would then be taken to allow commingled production. The interval was found to be non-productive, as verified with prior and subsequent well tests and production logs. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, ;.{J- !{~ M. Mooney Wells Group Team Leader CPAI Drilling MM/DV/skad RECE\\JEO M~'1 1 '2 '2.ßt)~ . CotnmìsslOI\ .\ &. Gas eal\S. Mas\(a 0\ ~l\t\\Ofa\\e OR\G\NAL STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS o Repair well 0 Plug Perforations 0 Stimulate 0 o Pull Tubing 0 Perforate New Pool 0 Waiver 0 o Opera\. Shutdown 0 Perforate 0 e 1. Operations Performed: Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska, 99510-0360 7. KB Elevation (ft): 116' RKB 4. Current Well Class: Development 0 Stratigraphic 0 8. Property Designation: ADL 17589/ ALK 2916 11. Present Well Condition Summary: Total Depth measured 8840' feet true vertical 6882' feet Effective Depth measured 8749' feet true vertical 6804' feet Casing Length Size MD Structural 366' 3D" 366' Conductor 631' 16" 631' Surface 10-3/4" 1911' Intermediate Production 7-5/8" 8830' Liner Perforation depth: Measured depth: 4415'-7555',8487'-8517' True Vertical depth: 3648' - 5859', 6585'-6609' e Other 0 Time Extension 0 Re-enter Suspended Well 0 Exploratory 0 Service 0 5. Permit to Drill Number: 203-075 6. API Number: 50-883-20030-01 9. We!l Name and Number: NCIU A-1OA 10. Field/Pool(s): N. Cook Inlet Field I Beluga Pool .Plugs (measured) Junk (measured) TVD 366' 631' 1839' Burst Collapse RECE\VED MAY 122004 Alaska Oi\ & Gas Cons. Commíssíon Anchorage 6874' Packers and SSSV (type and measured depth) 4.5", L-80 @ 4708',3.5", L-80, @ 7972' Tubing: (size, grade, and measured depth) Baker pkr's @ 4307', 4694', 6209', 7565', Cameo SSSV @ 414' Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure Tubing Pressure 9.7 mmscf/d 15 270 9.7 mmscffd 15 270 15. Well Class after proposed work: Exploratory 0 Development 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. nla Oíl-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: n/a .. n/a Copies of Logs and Surveys Run Service 0 Daily Report of WeU Operations X 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 WINJD 17. I hereby certify that the foregoing is true and correct to the best of my knowfedge. Sundry Number or N/A if C.O. Exempt Contact Dan Venhaus @ 263-4372 Printed Name Signature WDSPO Phone 263·4574 Title Wells Group Team Leader ¡¡¡on".y .Jtt ~ Date f:5 /;, /õ 1- MAY ~~mÆ~9i~inal Only Form 10-404 Revised 04/2004 OR'G\NA~8fl - NCIU A-10a ACTUAL WELLBORE DIAGRAM, 9/29/03 BPV(Mab;lype.OD) .,..,...". Typo H .... ...... Ths-....._Ty...) mc 41/1"EUE tupX 41/J;" IBl'btm RXB-TIIJi': .ø.78' ........ ...... 5% KCLwÞhœrrodonblblbltor JUœ.SL: 366 TOe, ..... CBL WATERDEPl'H: no' RXB-ML: ProdadIou. CadDa: 631 30' 41 366 16' 41 631 10 3/4 ø 41 L695 "'''',. 1-55 BT&C 3130 1530 629 10 3/4 ø .1695' 1911'KOP 4S.5N/tt; '·55 BT&C 3580 """ 11S 103l4-wIndow @ 1911' 7-S/1" (y ..... 19.71b/ft L·80 BT&C 6390 .,.., 683 Jooc .,."..,. .....' 4112" (y 4,708 12.61b1ft L·80 111 Mod .... 1500 238 3-112" 7165' 1.m 9.31b1ft L·80 111Mod 10160 10530 1JJ1 .J J.;. 15' PBR on top 01 pkr PRODUCTION TUBING STRING 28a Baker Premier Packer 0 4307' 39 0.00 43.78 Elevation fromKuukpik Rig#5 toLDSootb:tbead ~ 2' T CP perfs, not gravel packed 38 43.78 0.66 FMC/11'x4-1I2'lbghgl. 41/2" EUElopand IBTblm 3.958 11.000 4415'·4428' 31 44.44 369.68 4112" 1261b1ft L-BO Mod IBT Tubing 3.958 5.563 4454'·4487' 36 414.12 6.65 Camoo4-1I2''IRM-4PECF'IRSSSVwfRow<:pJp 3.813 6.000 35 4W.77 935.53 4112- 12.61b1ft L-BO Mod.:mT~ 3.958 5.563 34 1356.30 1.31 4-112" x 1- CamooKBG-2GLMwitbGLV,9m¡œ 3.865 6.059 ~ 33 1363.61 1034.53 4112· 12.61bfft L-BO Mod.:œTTubing 3.958 5.563 SC-2 pkr ðS3'f @ 4694' 32 1398.14 7.34 4-112"]1, lit CamooKBCJ..2GLMwitbGLV,9J21103 3.865 6.059 wlthKOIV 31 2A05." 980.17 4112" 1261b1ft L-BO ModIBTTubing 3.958 5.563 .. 30a ..8M' 7,32 4-112" x t"CamooKBG-2GLMwhbGLV,9n:T¡œ 3.865 6.059 23 ... 3392.91 8'l7.73 4112" 12.61b1ft L-W ModIBTT~ 3.958 5.563 22 30c -.,. 7.33 4-111!' x 1~ CamcoKBG-2GLM wid!. GLV. 9mffß 3.865 6.059 4805'-4905' 29 4228... 49.21 4112~ 12.61bJft L-W Mod mT TuttDg 3.958 5.563 4920'-5005' 29b 4277.24 29.95 &0-47 PRR wid!. 15' seal travel 21 28a 4307.19 7.06 Baker Premierpacker 3.&75 6.500 281> 4314.25 350.39 4l12~ 12.61bJft L-W Mod mT 1't11::ùl$t 3.958 5.563 - - SC-1l pkr 8SSf@ 5017' 28 ........ 4.74 Baker 4-lI2~ CMU slidinp; sleeve wi1b.3.813~ "X~ profite 3.813 5.500 V 4669.38 38.11 4l12~ 12.61b1ft L-W Mod mT TutUIg 3.958 5.563 20 26 4707.49 0.98 Baker4-lI2~S-22Aochorlalcbsealassy 3.280 4.218 25 "'0''''' 37.85 BakerSC-2PackerAssembIy(tbgtaUy) 4.000 6.490 DepCbs above tbís point are tbg 1ally ~1bs Depttas beloWUlis poiDt are oorreJated to CilL 913Jœ 20. 25 ......1 37.85 ,Baker SC-2 Packer Assembly (carelated to CBL) 4.000 6.490 - ~ SC-1l pkrassy@5611' 14 4731.86 2.52 Baker Model C withKOIV w/ Protector sleeve 3.375 5.630 KOlV puncbed out with inner s:tJiIW; 00 9120103 23 4J34.38 64.42 4~ 9.5#SUIT blank tbg 3.548 4.000 I 5685'-5700' 12 4798.10 217.84 4" Bakerweld screen. .012' gauge 3.548 4.590 I 190_ 5894'-5915' 21 5016.64 24.18 BakerSC-1LMulli1mepackerassy 3.250 6.490 I 6090'-6105' 1J) 5040.82 569.83 4"9.5#SUITblanktbg 3.548 4.000 I 6185'-6195' 20a 5610.65 24.18 BakerSC-ILMUllizonepackerassy 3.250 6.490 I I I 1. 5634.83 37.55 4"9.5#SUITblaDktbg 3.548 4.000 I I 190 5672.38 535.53 4~ Bakerweld screen. .012' ~Iijte 3.548 4.590 ~ S-22B Snap latch (plus two x 9':Brao:Ien blank joints at 5813..56'-5822.86' and 601053'-6019.56,\ SC-2 f'to" 8SSf @ 6209' 18 6207.91 0.S7 BakerS·22B snap latch 3.280 4.21' 17 .....,. 35.95 Baker SC- 2 Packer Assembly 4.000 6.490 ,. 6244.13 2.52 BakerModelCKOIV Protector sleeve (miSSÙl$tKOlV) 3.500 5.630 15 16 6247.25 45.73 4~9.5#SUITblank~ 3.548 4.000 6300'-6310' IS 6292.98 423.'l7 4~ Balœrweld screen. .012' gauge 3.548 4.590 6450'-6525' (plus two x 9' Brao:Ien blank joints at 6396.13'-6405.16 and 6592.53'-6601.56' 6646'·6665' 14 671.... 24.18 BakerSC-ILMullizone packerassy 3.250 6.490 6685'-6710' 13 6740.43 73.12 4~9.5#Surrblanktbg 3.548 4.000 - 1. 12 6813.55 367.15 4~ Bakerweld screen. .012' gatIJI;e 3.548 4.590 - SC-1l pkr8SSf@671ft (plus ooe 9'Brao:Ien blank ;oint at 6906.85'-6915.88) 11 1uo.10 24.18 Baker SC-1L Multi7Øle: packer assy 3.250 6.490 10 120U. 58.82 4~ 9.5#SUIT blank IbIt 3.548 4.000 13 . 71fß.70 300.43 4~ Bakerweld screen. .012' ~Ute 3.548 4.590 6825'-6865' (plus ooe 9' Braden blankjOOltat 7366.77'-m5.8O') 7010'-7028- 8 1564.13 0.87 BakerS·22B snap IaICb 3.280 4.218 12 7165'-7175~ 1 1565.00 13.30 Baker A·lSUmp packer assywith4-1I2" buttress pin doWn 4.000 6.500 11 6 7578.30 185.63 4·1I212.6#buttressttg.Six joints 3.958 5.563 - ~ SC-1l pkrassy@7181' 5 7163.93 1.684-112" x3--1I2~<:rossover 3..... 5.375 4 7765.61 3O.983-1I29.3#buttressttg.1jt 2992 4.250 10 3 7196.59 1.02 3-1I2"Xøippk:.2.813~ID 2813 4.250 7270'-7280' 2 7797.61 30.93 3-V29.3#tutressttg.1jt 2992 4.250 7425'·7450' 1 7828.54 1.43 3--112" bunressx 4~ SUITxover 2992 4.500 7515'-7555' A 78'19.'17 75.13 4~ SUIT exclooer screen. two jts. 3.548 5.0W B 7905.10 1.43 3·vrtJutlressx4~SUITxover 299' 4.500 V' S·22B Snap latch C 7906.53 31.00 3.lI293#btmress1tlg.1jt 2992 ~25O FB-1 Su~ PIer @ 7565' D 7937.~ 1.01 3-1I2"XDippte.2.813~ID 2.813 4.250 . 793&.54 31.76 3-ln9.3#buttressttg.l it 2992 ~25O F 7970.30 1.31 End of Tubing, 3-lI2~ WLEO 299' 3.800 ---121!.&. .X' 3 2,1 A B.C D E 'X' 7972' TD =8840' MDJ6882' TVD 3-11.l-Xnlpple Two Its 01 4" Excluder screen. fine Six Braden blank Joints are 9' long wfth Radioactive Collar at top 01 Joint at 581'4',6011', ro96', 6593', 6907' and 7377' 3-1/T X nlpþle Three Radioactive 7·5/8" casing cplgsat 4366',5879' and 7450' elm (CBl9ß1D3) ~ 7-5/8- @ 8830' Updated b. ,~SISI04 PBTD: 18743' 1suPv: Well: NCØ1b CookIolet UDltNo. A·1Øa Locatioo: Tyooek PlatfooD, COOk IIlIet, AIasb. IThg Wt 4-112~ 12.6lbfft 1- Rekl: NorttI. CookIDletUllif e NCI A-10A Well Events Summary e Date Summary 02/11/04 DRIFT AND TAG FOR UPCOMING COIL WORK @ 7764' WLM (7780' CORRECTED) - CORRELATE DEPTH TO 3.5" X-OVER @ 7748' WLM (7764' RKB). CHECKED CMU SLEEVE@ 4665' RKB (4646' WLM) TO ASSURE IT WAS CLOSEDD [Tag] 02/13/04 RIG UP BJ AND PTS - BOP FUNCTION AND PRESSURE TEST TO 4000 PSI- PREP AND BUILD ALL FLUIDS - RIH TO 2362' CTM - COULDN'T GET BY GLM - CHANGED BHA - SAT DOWN @ SAME - CHANGE BHA AGAIN - MADE IT TO FILL LEVEL @ 7742' CTM - START CLEANOUT @ 1000 SCFM NITROGEN AND 1.4 BPM KCL WATER WITH 5 BBL GEL SWEEPS - LIFT GAS ON. 02/14/04 CONTINUED FROM 2/13/04 - NITROFIED FILL CLEANOUT FROM 7742' CTM TO 8040' CTM USING SLICK 3% KCL WATER @ 1.4 BPM WITH GEL SWEEPS AND 1000 SCFM NITROGEN - LIFT GAS ON FOR ASSIST - PUMPED 359 BBLS WATER & 30 BBLS GEL WITH 371 BBLS RETURNED - PUMPED 4000 GAL. N2. 02/15/04 COMPLETE MEMORY LOG PASS AND FLAGGED PIPE @ 8550' CTM - RIG UP GUNS- HAD TO RIG DOWN FOR BOAT LOAD (N2) - SHOT 20' GUN 2.5",6 SPF, 60 DEGREE PHASED, POWER JETS WITH WELL FLOWING - ALL SHOTS FIRED FROM 8517'- 8497' - RIG UP SECOND 20' GUN - SET GUNS ON DEPTH. PUMPED BALL AND SHOT FROM 8507'-8487'. 02/16/04 SPINNER/PRESSUREfTEMP SURVEY TO DETERMINE WATER INFLUX AREA IN WELLBORE. Ws ~ 10· wit LOG TRANSMITTAL . 8ð3 -()?-5 ProActive Diagnostic SelVices, Inc. To: State of Alaska AOGCC 333 W. 7'" Street Suite # 700 Anchorage, Alaska 99501 RE: Dìstrìbution - Fìnal Ptìnt(s] The technical data listed below is being submitted herewìth. Please acknowledge receipt by returnìng a signed copy of thìs transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 WELL DATE loG TYPE DIGITAL OR CD-ROM MYLAR / SEPIA FILM BLUE LINE PRINT[S) REPORT OR CoLOR Open Hole A-10a 1-15-04 Res. Eva!. CH 1 1 1 JA) Y 19 Mech. CH 1 Caliper Survey 1 Signed: \:~')'--~i ~:~~. ~~.~~~'" RECEIVED Date : Print Name: r· 1""1' 2' ?004 ...".J ..... \iaska Oi! & Gas Coos. Commission ""'''¡''M~ k):.{~~;,t!~\1I~'¥ PRoACTivE DÌAGNOSTic SERvicES, INC., PO Box 1 ~69 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Websitc: www.memorvlog.com ~~~ . ~'L)bIY\~ . Conoc~illips . Paul Mazzolini Exploration Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4603 November 5, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for NCI A-10A (203-075) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the North Cook Inlet well A-10A. If you have any questions regarding this matter, please contact me at 263-4603 or Tim Billingsley at 265-6531. Sincerely, ?JfJ1~ P. Mazzolini Exploration Team Leader CPAI Drilling PM/skad 7 I STATE OF ALASKA - ALAS OIL AND GAS CONSERVATION COM~ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 GINJ 0 2. Operator Name: WINJ 0 Gas ~ Plugged U Abandoned 0 20AAC 25.105 No. of Completions _ WDSPL 0 ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 1304' FNL, 1023' FWL, Sec. 6, T11N, R9W, SM At Top Productive Horizon: 277' FSL, 2400' FWL, Sec. 31, T12N, R9W, SM Total Depth: 2462' FSL, 612' FEL, Sec. 31, T12N, R9W, SM 4b. Location of Well (State Base Plane Coordinates): Surface: x-332041 TPI: x- 333441 Total Depth: x- 335477 18. Directional Survey: Yes 0 21. Logs Run: GRlRes/Dens-Neutron, CBL 22. CASING SIZE WT. PER FT. 30" 16' 65# 10-3/4" 40.5#/45# 7 5/8" 29.7# CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 366' Surface 631' Surface 1911' Surface 8830' y- y- y- 2586670 2588237 2590393 Zone-4 Zone- 4 Zone- 4 NOU GRADE H-40 J-55 L-80 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4415'-4428' MD 3648'-3656' TVD, 4454'-4487' MD 3674'-3697' TVD 4805'-4905' MD 3911 '-3976' TVD 4920'-5005' MD 3986'-4041' TVD 5685'-5700' MD 4486'-4496' TVD 5894'-5915' MD 4629'-4644' TVD 6090'-6105' MD 4768'-4779' TVD 6185'-6195' MD 4837'-4844' TVD 6300'-6310' MD 4920'-4928' TVD 26. Date First Production October 10, 2003 Date of Test Hours Tested 10/10/2003 24 hours Flow Tubing Casing Pressure press. 260 psi 255 27. Test Period --> Calculated OIL-BBL Suspended U WAG 0 20AAC 25.110 Other 5. Date Comp., Susp., .:$ jI) or Aband.: .9).2!f!2Ó03 6. Date Spudded: August 2, 2003 7. Date TD Reached: August 16, 2003 8. KB Elevation (ft): RKB 116' 9. Plug Back Depth (MD + TVD): 8749' MD 16804' TVD 10. Total Depth (MD + TVD): 8840' MD I 6882' TVD 11. Depth where SSSV set: 414' feet MD 19. Water Depth, if Offshore: 130' feet MSL HOLE SIZE 1b. Well Class: Development 0 Exploratory 0 Service 0 Stratigraphic Test 0 12. Permit to Drill Number: 203-075 / 13. API Number: 50-883-20030-01 14. Well Name and Number: NCIU A-10A 15. FieldlPool(s): Beluga Pool Cook Inlet Oil Pool 16. Property Designation: ADL 17589 17. Land Use Permit: ALK 2916 20. Thickness of Permafrost: N/A Driven CEMENTING RECORD AMOUNT PULLED 22" 15' 91/2" 610 sx Class G 737 sx Class G 1039 sx 12.8 ppg "Gas Tight" TUBING RECORD DEPTH SET (MD) 4708' 7972' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 24. SIZE 4.5" 3.5" 25. WATER-BBL 89 WATER-BBL 89 ORIGINAL CONTINUED ON REVERSE SIDE PACKER SET (MD) 4307',4694',6209',7565' CHOKE SIZE IGAS-OIL RATIO 69 -- OIL GRAVITY - API (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". 6450'-6525' MD 5030'-5086' TVD 6646'-6665' MD 5177'-5191' TVD 6685'-6710' MD 5207'-5226' TVD 6825'-6865' MD 5313'-5343' TVD 7010'-7028' MD 5452'-5466' TVD 7165'-7175' MD 5569'-5576' TVD 7270'-7280' MD 5647'-5655' TVD 7425'-7450' MD 5762'-5781' TVD 7515'-7555' MD 5829'-5859' TVD PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Producer Production for OIL-BBL GAS-MCF 5726 GAS-MCF 5726 CORE DATA 24-Hour Rate -> RBDMs 8FL NOV 12 ,28(f3 NONE 7 r --?':Æ~¡ ; v:nJ~:(j.· I. ¡--:AD ¡ ~Yn.._... .>......,.,. ,._........"._=:..;,. l,V Submit in duplicate Form 10-407 Revised 2/2003 28. GEOLOGIC MARKERS. 29. . FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state 'None". Top open hole log Top Cook Inlet Sand Top Beluga Formation Total Depth 1889' 4449' 5787' 8840' 1830' 3682' 4567' 6882' N/A 7 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Logs, Schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Billingsley @ 265-6531 Printed N~ Paul Mazzoli!1i , Signature ~ f71~~ Title: Phone Cook Inlet Drilling Team Leader II/os '6''"2 Date (, <-.) Prepared by Tim Billingsley 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 1a: 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 production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. 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: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state 'None'. Form 1 0-407 Revised 2/2003 ORIGINAL . . North Cook Inlet Unit No. A-lOa Daily Summary (A-1O Abandonment Daily Summary, 6/22/03 to 7/29/03, Submitted with 407 Report, 8/12/03) Start of A-lOa Sidetrack Drilling 7/30/03 Perform Weekly BOPE test, set WB. PU scraper BHA, RIH w/ 10-314" 45.5# scraper, RIH to 1936 DPM to tag CIBP. Circ/sweep, POOH, UD BHA, Clean pits. 7/31/03 PU 4 1/2" 16.6 #/ft SS-95 DP, mix new drilling mud, reverse circ hole from milling fluid to drilling mud @ 1934'. Continue PU 4-1/2' drill pipe. 8/1/03 Continue PU 4-1/2" drill pipe. 8/2/03 MU 10-314" Whipstock, orient to MWD, RIH w/ whipstock, orient whipstock 42 deg rt of high side, set anchor, shear bolt, (top of whipstock @ 1910', bottom of whipstock @ 1931 ') mill casing and open hole f/ 1911'- 1963', circ, perform FIT to 10.7, POOH with mills. 8/3/03 RIH with 9 1/2" bit & motor assembly, slide drill from 1963' to 2391 " CBU to clean hole, slide 2391' to 2710'. 8/4/03 Directional drill 2710' to 2956', Circ hole clean, short trip to 1910, drill f/ 2956' to 3940', circ & cond mud, wiper trip f/ 3940' to 3202' @ midnight. 8/5/03 Continue wiper trip f/ 3202' to 2520', RIH to 3858', ream f/ 3858' to 3940', Drill f/ 3940' to 4922', CBU, POOH to 4050' making wiper trip. 8/6/03 Continue wiper trip to 3800', RIH to 4738', ream to 4922', Drill f/ 4922' to 5912'. 8/7/03 Wiper trip from 5912' to 4804', RIH to 5846', ream to 5912', Drill f/ 5912' to 6524'. 8/8/03 Drill f/ 6524' to 6770'. Circulated and reamed tight hole, POOH pumping to 3266'. 8/9/03 POOH from 3266', Laid down BHA, Tested Bop. Made up BHA and RIH RIH to 2232' and displace mud system. 8/10/03 RIH to 5893' and washed to 5950'. RIH to 6770'. Drilled from 6770' to 7190'. A-lOa daily summary 9-29-03 final AOGCC.doc 1 . . 8/11/03 Drilled from 7190' to 7520'. Circulated. Made wiper trip to 6601' and Rill. Drilled from 7520' to 7755'. 8/12/03 Drilled from 7755' to 7966'. Circulated. Made wiper trip to 7400' and Rill. Drilled from 7966' to 8143', top drive motor failure, CBU. 8/13/03 POOH with pump to 6590', Circulated out gas cut mud. Rill to bottom and circulated out gas. POOH (With pump to 3900') to 1889'. Put well on trip tank and cleaned floor to work on top drive. 8/14/03 Work on TD, POOH and change BHA, Rill to 1873' and build mud volume. 8/15/03 Rill to 5000', CBU, Rill to 7000', CBU, Rill to 8143' and CBU. Drilled from 8143' to 8438'. 8/16/03 Drilled to 8501'. CBU, Made wiper trip to 7400'. Circulated and worked on pump. Drilled and circulated to 8840' TD. CBU, Made wiper trip to 8210'. Circulated for logs. 8/17/03 POOH and laid down BHA. RU Schlumberger, Rill on E-line with FMI/Dipole Sonic/SP. Set down at 8117', log up from 8117'. 8/18/03 Logged from 8117' to 1894', POOH with FMI logging tools. Tested BOP. Rill and cut DL. Rill to 4828'. 8/19/03 Rill f/ 4828' to 8840', reamed tight spot @ 8540', circ, POOH, LID BHA, MU Schlumberger MDT tool string on drill pipe, Rill on 4 1/2" dp to 2130', top drive hydraulic leak, cleanup spill. 8/20/03 Reroute hyd fittings on top drive, Rill w/ dp conveyed logs to 6796' circ, MU side entry sub, Rill w/ WL & connector, Logging f/ 6835' to 8628'. 8/21/03 POOH w/ TLC tools on 4 1/2" dp to side entry sub (6796'), remove clamp on side entry, POOH WL, remove side entry sub, POOH w/4 1/2" dp to 4396', circ, MU side entry, Rill WL, latch up, log 4426'-6196', POOH to 4712'. 8/22/03 Obtain samples with MDT from 4712' to 4512', POOH to 4396', POOH w/ WL, LID SE sub, POOH w/ logging tools on dp, LID Schlum MDT tools. RU Schlumberger sidewall cores, Rill to 8700', shot 11 of 17 (malfunction), POOH, RID Schlum. 8/23/03 Rill for 9 1/2" wiper trip, wash through 4505' and 4700', continue in hole, precautionary ream 8400' to 8840', circ and condition mud and hole, POOH w/ cleanout assembly. A-lOa daily summary 9-29-03 final AOGCC.doc 2 . . 8/24/03 Pull wear bushing, change top rams to 7 5/8", test doors 250/3000 psi, RU fl running 7 5/8" csg, run 7 5/8" csg to 1910', circ, run 7 5/8" csg to 3240', circ while offload cmt equipment from boat. 8/25/03 Run 7 5/8" csg from 3240' to 7640. TESCO casing running tool did not release on jt # 178. RD Tesco casing MU tool. 8/26103 Continued running casing to 8830' with GBR tongs. Circulated and worked pipe 20' stroke. Pump 20 bbl water spacer and 27 bbls of 10.5 ppg weighted spacer, drop bottom plug followed by 333 bbls (1039 sx) of 12.8 ppg BJ "Gas Tight" cmt, dropped top plug. Displaced with drilling mud, unable to continue reciprocation when spacer rounded corner on bottom. Bumped plug, floats held. Lost a total of 87 bbls during entire cement job. Rigged down casing tools. 8/27/03 ND BOPE, PU stack, set slips on 7 5/8" wI 230k on wt indicator, rough cut, final cut, install tubing spool & 2 drilling spools, NU BOPE, RU top drive fl 3 1/2", test BOPE, NU bell nipple. 8/28/03 Laid down 4 1/2" DP, cleaning in pit room. 8/29103 Offloading boat to platform, lay down 4 1/2" dp fl derrick, RIH with 6 3/4" bit, dual scrapers brush and magnet BHA while PU 3 1/2" dp to 5666'. 8/30103 PU/RIH 3 1/2" dp to 8713', RU to take seawater to rig pits, offload boat, fill platform pits wI drill water, MI filter platform pits, cleaning rig pits. 8/31/03 Offloading equip f/boat to platform, Rigging up MI/SW ACO filter unit to pump filtered water (less than 5 NTD's) to horizontal 520 bbl tank on top deck, add KCL concentrate to get 5% in horizontal tank, RU pill mixing tank pump and equip. 9/1/03 Fill pits wI 8.5 ppg seawater, tag bottom @ 8749'dp measurement, pump 842 bbls seawater, clean/rinse pits, build 5% KCL volume in platform pits, fill rig pits w/KCL water, RU MI transfer pump & lines to move KCL fluid. 9/2/03 Pump caustic wash, displace wI 5% KCL, circ checking NTD's, shut down, transfer fluid to rig pits and horizontal 520 bbls tank, Pumped acid pickle in drill pipe and reversed out. Circulated and filtered brine. POOH. 9/3/03 LD BHA. RU loggers and ran CBL/GR, RD loggers. Tested BOP. RU and tested casing to 3000 psi. RU and ran sump packerltail pipe assembly on drill pIpe. 9/4/03 RU E-line and ran GR, place packer on depth. RD E-line. Set packer at 7565.5' and tested packer. POOH. A-lOa daily summary 9-29-03 final AOGCC.doc 3 . . 9/5/03 Laid out and strapped TCP string. Picked up and RIH with TCP guns. Set plug in packer at 7565' and PU to 10' to place guns on depth. Pressure up drill string and perforated well. Monitored losses at 40 bph. 9/6/03 Pump 100 bbls of HEC pills and losses decreased to 15 bph. POOH and laid down TCP string. Picked up and RIH with Cavins bailer. Bailed 7' of fill and attempt to latch plug. Put well on trip tank and monitored losses at 2 bph. 9/7/03 POOH and found overshot plugged with gun debris but no plug. RIH with Cavins bailer. bailed 10' of fill and latched plug. Put well on trip tank and monitored losses, dropped bar and well U-tubed. Reversed out more debris. Circulated. POOH, recovered plug. 9/8/03 RU and ran gravel pack assembly, outer string and two inner strings. 9/9/03 PU and ran gravel pack assembly to 6143'. Waited on BJ. RU BJ. 9/10103 RIH gravel pack assembly to 7690', worked thru tight spots in perfs. Set and tested packer at 6209'. Waited on BJ to solve computer problems. Set isolation packer at 7180'. Pump stage 1 gravel pack. 9/11/03 Finished stage 1 gravel pack. Repositioned inner string. Mixed and filtered brine. Set isolation packer at 6717'. Pumped GP stage 2. Repositioned inner string for 3rd stage and mixed brine. 9/12/03 Mixed and filtered brine. Pumped GP stage 3. Repositioned inner string to close KOIV flapper, did not close, losses at 50 bph. POOH and laid down inner strings. Made up plug on drill pipe. 9/13/04 RIH and set plug in packer. Put sand on plug. POOH. Tested BOP. Waited on Boat. Offloaded Boat. 9/14/03 RU E-line and ran log to check depth of sump packer for GP run #2. RD loggers. PU and RIH TCP gun assembly #2. Put guns on depth, confirmed with E-line log. Attempt to fire guns with drill pipe pressure, slight indication of fired guns on 3rd. try. Monitor well, no losses. 9/15/03 POOH to firing head. Guns did not fire. Found mistake in firing head programming. Reworked firing head. RIH TCP gun assembly. Put guns on depth and fired guns. Reversed out. Monitor well 50 BPH loss. Pumped pill and loss declined to 10 BPH. POOH. 9/16/03 POOH and LD perf guns. All shots fired. RIH wi scraper assembly to top of fill at 6200' (DP). Worked through ledge at 4915'. POOH wlwith scraper A-lOa daily summary 9-29-03 final AOGCC.doc 4 . . assembly. MU Cavins Bailer assembly, RIH to stand 61, pIpe filling (Hydrostatic valve leaking). 9/17/03 POOH and change out hydrostatic control valve. RIH. Clean out fill from 6197' to 6217'. Bailer plugged. POOH. Cleanout debris, re-run in hole wI CAVINS bailer, bail @ 6218', pull plug, monitor losses, pull 15 stands, drop bar, fill pipe, monitor hole, POOH. 9/18/03 POOH wI CAVINS bailing assemby & Baker pkr plug. PU/MU 4" Multi- zone gravel pack assembly wI 2 7/8" and 1.90" inner strings, MU Baker SC-2 packer. 9/19/03 MU stand 3 1/2" dp, pt workstring, did not hold 300 psi, reverse fluid @ 20 psi, ok. RIH wI 4" gp screens on 3 1/2" dp, offload boat, RU BJ, con't RIH to 6245', RU BJ iron to floor, set SC-2 packer @ 4707.78' dpm, test to 3000 psi, retest-leaking, POOH due to leak. 9/20103 POOH wI inner string to pkr setting tool, test fl leaks, LID setting tool. MU x- o to replace leaking setting tool, test to 1000 psi, RIH wI inner string to KOIV @ 4732', break KOIV. RIH, sting into pkr, test to 3500, RU BJ, PJSM, test lines, pump lower stage of gravel pack, rev, POOH to iso pkr, set pkr, POOH fl 2nd stage of gravel pack. 9/21/03 Locate & estab. rev circ rate, locate fl GP, perform GP, rev sand, RID BJ iron on floor, POOH to above pkr, Fluid loss at 60 bph, Wash up BJ over shakers, RID BJ iron on floor, POOH wI inner strings, RU GBR, POOH LID 1.90" & 2 7/8", RID GBR. PU/RIH with packer plug, fluid loss at 23 bph, set pkr plug in pkr at 4708' dpm. 9/22/03 Spot sand on Baker packer plug, POOH wI running tool, test BOPE, run Schlumberger TCP guns on 3 1/2" dp, tag top of packer & put guns on depth, RU & test Schlum equip on floor, fire guns, rev out dp fluid and large amounts of sand, release pkr, POOH 140', mono well. 9/23/03 Circ after perforating, mon well, clean trip tank of large amounts of sand, POOH, LID perf guns, PU CAVINS bailer assy, RIH bail 10' of sand, pull plug @ 4708' dpm wI lOOk over, POOH 6 stands, monitor well at 60 bph losses, POOH LID 6 jts of sand plugged DP with losses at 51 bph. 9/24/03 MU 4-112" compl to Premier packer and PBR wlseals, RIH with packer assy on DP to 557', tag something in hole, POOH, two gouges in side of PBR guide, reduce OD on PBR guide from 6.72" to 6.62" OD, RIH with no problems, snap into SC-2 packer at 4708', pressure up and set Premier pkr at 4306', shear PBR seals, test annulus to 2500 psi, pull seals, re-run seals, POOH with seals and drill pipe, change rams to 4-112". A-lOa daily summary 9-29-03 final AOGCC.doc 5 . . 9/25/03 Test 4-1/2" rams, RIH with 4 1/2" completion assy, space out, pump inhibited fluid into annulus, land 4 1/2" tubing, test annulus to 2500 psi, test tubing to 3500 psi, UD landing jts, set BPV, Pull rotary table fl running tree. 9/26/03 N/D BOP, NU tree, pull BPV, set test plug, test tree to 250 & 3000 psi, RU slickline, test lubricator, RID slickline, re-orient tree, test tree to 250 & 3000 psi, RU slickline, test lubricator, RIH to set AD-2 stop, work to remove dummy valves fl GLM. 9/27/03 Replace dummy valves wI live valves, test tubing and WL lubricator. 9/28/03 Retrieve ball rod, well on strong vacuum, RIH retrieve plug body, RID Pollard slickline, RU & UD 3 1/2" dp fl derrick, load boat with DP. 9/29103 Finish loading boat with DP and drill collars. Rig released fl move from A- lOa to B-3 @ 0600 hrs 9/29/03. End of A-lOa Sidetrack Drilling Reports A-lOa daily summary 9-29-03 final AOGCC.doc 6 . . Conoc~hillips A-10A Survey Report Schlumberger Report Date: 81712003 SUlVey I DlS Computation MethOd: Minimum Curvature I Lubinski Client: ConocoPhillips Vertical SectIon AzImuth: 38.810" Field: North Cook Inlel Unit Vertical SectIon OrIgin: N 0.000 It, E 0.000 ft structure I SIal: Tyonekl A-10 (slot 6 leg 2) TVD Reference Datum: KB Well: A-10 TVD Reference ElevaUon: 119.0 ft relative to MSL Borehole: A-lOA UWIIAPI.: 508332003001 Ml9net1c DecllnaUon: 20.514' SUrvey Name I Date: A-10AI August 7, 2003 Total Field S1rength: 55601.506 nT TortI AHD/DDlI ERD ratio: 159.744' 15081.03 ft/6.0181 0.738 Magnetic Dip: 73.85~ Grid Coordinate System: NAD27 Alaska Stale Planes, Zone 04, US Feel Declination Date: August 19, 2003 locaUon latIlong: N 61 435.796, W 150 56 54.672 Magnetic Declination MOdel: BGGM 2003 locaUon Grid NIE YIX: N 2586670.210 ftUS, E 332040.920 ftUS North Reference: True North Grid Convergence Angle: -0.8302261 ~ Total Corr Mag North -> True North: +20.514' Grid Scale Factor: 0.99993210 local CoordInates Referenced To: Well Head I M~~I Inclination I AzImuth I TVD I su~Sœ TVD I Vertical I NS EW I DLS I Build Rate I Walk Rate I Northing EasIIng latitude longitude SectIon (II) (de9) (dog) (II) (II) (II) (II) (II) ( deWl00 II ) ( deWl00 II ) ( deW100 II) (IIUS) (flUS) 0.00 0.00 0.00 0.00 -119.00 0.00 0.00 0.00 0.00 0.00 0.00 2586670.21 332040.92 N 61 435.796 W 1505654.672 378.00 0.25 336.00 377.98 258.98 5.40 2.41 5.62 0.07 0.07 0.00 2586672.54 332046.57 N 61 435.820 W 15056 54.557 403.00 0.25 302.00 402.98 283.98 5.42 2.49 5.55 0.58 0.00 -136.00 2586672.62 332046.51 N 61 435.821 W 1505654.559 428.00 0.50 319.00 427.98 308.98 5.43 2.60 5.43 1.08 1.00 68.00 2586672.73 332046.39 N 61 435.822 W 1505654.561 453.00 0.50 351.00 452.98 333.98 5.52 2.79 5.35 1.10 0.00 128.00 2586672.92 332046.30 N 61 4 35.824 W 150 56 54.563 478.00 0.25 25.00 477.98 358.98 5.65 2.95 5.35 1.30 -1.00 136.00 2586673.08 332046.31 N 61 4 35.825 W 150 56 54.563 503.00 0.25 332.00 502.98 383.98 5.72 3.04 5.35 0.89 0.00 -212.00 2586673.18 332046.31 N 61 435.826 W 1505654.563 528.00 0.50 337.00 527.98 408.98 5.80 3.19 5.28 1.01 1.00 20.00 2586673.33 332046.25 N 61 435.827 W 1505654.564 553.00 0.50 356.00 552.98 433.98 5.93 3.40 5.23 0.66 0.00 76.00 2586673.54 332046.20 N 61 435.830 W 15056 54.565 578.00 0.75 29.00 577.97 458.97 6.17 3.65 5.30 1.71 1.00 132.00 2586673.79 332046.27 N 61 435.832 W 1505654.564 603.00 0.50 39.00 602.97 483.97 6.44 3.88 5.45 1.09 -1.00 40.00 2586674.01 332046.43 N 61435.834 W 1505654.561 628.00 0.75 37.00 627.97 508.97 6.71 4.10 5.62 1.00 1.00 -8.00 2586674.23 332046.60 N 61 4 35.836 W 15056 54.558 653.00 1.75 53.00 652.97 533.97 7.25 4.46 6.02 4.20 4.00 64.00 2586674.58 332047.00 N 61 435.840 W 1505654.549 678.00 2.75 56.00 677.95 558.95 8.19 5.02 6.82 4.03 4.00 12.00 2586675.13 332047.81 N 61 435.846 W 1505654.533 703.00 3.75 55.00 702.91 583.91 9.55 5.83 7.99 4.01 4.00 -4.00 2586675.92 332048.99 N 61 435.853 W 1505654.509 728.00 5.00 49.00 727.83 608.83 11.41 7.01 9.48 5.32 5.00 -24.00 2586677.08 332050.50 N 61 435.865 W 1505654.479 753.00 6.00 37.00 752.72 633.72 13.78 8.77 11.09 6.08 4.00 -48.00 2586678.82 332052.13 N 61 4 35.882 W 150 56 54.446 778.00 7.00 29.00 777.56 658.56 16.59 11.15 12.61 5.39 4.00 -32.00 2586661.17 332053.69 N 61435.906 W 15056 54.415 803.00 8.25 26.00 802.34 683.34 19.84 14.09 14.14 5.25 5.00 -12.00 2586684.09 332055.26 N 61435.935 W 1505654.384 828.00 9.00 26.00 827.05 708.05 23.50 17.46 15.78 3.00 3.00 0.00 2586687.44 332056.95 N 61435.968 W 1505654.351 853.00 9.25 27.00 851.74 732.74 27.37 21.01 17.55 1.18 1.00 4.00 2586690.96 332058.77 N 61 436.003 W 150 56 54.315 878.00 9.75 32.00 876.39 757.39 31.44 24.59 19.59 3.86 2.00 20.00 2586694.52 332060.86 N 61 436.038 W 1505654.274 903.00 9.75 33.00 901.03 782.03 35.65 28.16 21.86 0.68 0.00 4.00 2586698.05 332063.19 N 61 436.073 W 1505654.227 909.00 9.75 35.00 906.95 787.95 36.66 29.01 22.43 5.64 0.00 33.33 2586698.89 332063.77 N 61 436.082 W 15056 54.216 972.00 11.00 36.00 968.91 849.91 47.99 38.24 29.02 2.00 1.98 1.59 2586708.02 332070.49 N 61 436.173 W 1505654.082 1032.00 13.00 31.00 1027.60 908.60 60.39 48.66 35.86 3.75 3.33 -8.33 2586718.34 332077.48 N 61 436.275 W 150 56 53.943 1094.00 14.75 36.00 1087.79 968.79 75.18 61.02 44.10 3.42 2.82 8.06 2586730.58 332085.89 N 61436.397 W 1505653.775 1158.00 16.25 32.00 1149.47 1030.47 92.22 75.21 53.63 2.88 2.34 -6.25 2586744.63 332095.63 N 61 4 36.537 W 150 56 53.582 1249.00 19.00 32.00 1236.19 1117.19 119.57 98.57 68.23 3.02 3.02 0.00 2586767.78 332110.57 N 61 4 36.767 W 150 56 53.285 1343.00 21.25 30.00 1324.44 1205.44 151.60 126.30 84.86 2.50 2.39 -2.13 2586795.26 332127.59 N 61 437.040 W 150 56 52.947 1435.00 23.75 32.00 1409.43 1290.43 186.48 156.46 103.01 2.84 2.72 2.17 2586825.15 332146.18 N 61 437.337 W 1505652.578 1528.00 26.00 35.00 1493.80 1374.80 225.42 189.04 124.63 2.77 2.42 3.23 2586857.42 332168.27 N61437.658 W 1505652.138 1620.00 26.50 29.00 1576.33 1457.33 265.78 223.52 146.16 2.93 0.54 -6.52 2586891.57 332190.29 N 61 437.997 W 1505651.701 1715.00 26.00 30.00 1661.53 1542.53 307.24 260.09 166.84 0.70 -0.53 1.05 2586927.84 332211.50 N 61 438.357 W 150 56 51.280 1810.00 24.50 32.00 1747.46 1628.46 347.38 294.83 187.69 1.82 -1.58 2.11 2586962.27 332232.85 N 61 438.699 W 1505650.856 1904.00 25.00 32.00 1832.82 1713.82 386.45 328.21 208.55 0.53 0.53 0.00 2586995.34 332254.19 N 61 439.028 W 1505650.432 2089.04 23.75 41.36 2001.43 1882.43 462.91 390.11 253.57 2.19 -0.68 5.06 2587056.58 332300.10 N 61 439.637 W 1505649.517 2149.57 25.55 47.03 2056.45 1937.45 488.01 408.16 271.18 4.91 2.97 9.37 2587074.37 332317.97 N61439.815 W 1505649.159 2211.17 28.22 48.00 2111.38 1992.38 515.54 426.96 291.73 4.39 4.33 1.57 2587092.87 332338.79 N61440.000 W1505648.741 2273.39 30.98 48.37 2165.48 2046.48 545.86 447.45 314.64 4.45 4.44 0.59 2587113.02 332361.98 N 61 440.202 W 1505648.276 2334.09 34.62 49.41 2216.49 2097.49 578.23 469.05 339.42 6.07 6.00 1.71 2587134.26 332387.07 N 61440.415 W 1505647.772 2395.97 37.54 50.01 2266.50 2147.50 614.01 492.61 367.21 4.75 4.72 0.97 2587157.42 332415.21 N 61 440.647 W 15056 47.207 2457.10 40.87 52.12 2313.86 2194.86 651.75 516.87 397.28 5.87 5.45 3.45 2587181.23 332445.62 N 61 4 40.886 W 150 56 46.596 2519.71 44.10 51.85 2360.03 2241.03 692.92 542.91 430.59 5.17 5.16 -0.43 2587206.79 332479.30 N61441.142 W1505645.918 2581.88 47.26 51.62 2403.46 2284.46 736.27 570.46 465.51 5.09 5.08 -0.37 2587233.82 332514.61 N 61 441.413 W 1505645.209 2642.06 49.45 47.96 2443.45 2324.45 780.40 599.50 499.82 5.82 3.64 -6.08 2587262.36 332549.34 N61441.699 W 1505644.511 2703.11 48.82 44.65 2483.40 2364.40 826.16 631.38 533.20 4.23 -1.03 -5.42 2587293.75 332583.17 N 61 442.013 W 1505643.832 2764.33 47.75 40.84 2524.15 2405.15 871.74 664.92 564.21 4.96 -1.75 -6.22 2587326.84 332614.67 N 61 442.343 W 1505643.202 2826.65 47.24 41.44 2566.26 2447.26 917.64 699.52 594.44 1.08 -0.82 0.96 2587360.99 332645.39 N 61 442.684 W 1505642.587 SurveyEdilor Ver 3.1 RT-SP3.03-HFI.2 Bld( d031 rt-546 ) A-10 (slOI 6 leg 2)1A-101A-10AIA-10A Generated 11/612003 10:20 AM Page 1 of 3 . . 2887,89 46,52 41,72 2608,12 2489,12 962.29 732,95 624.10 1,22 -1.18 0.46 2587393,99 332675,53 N61443,013 W1505641.984 2948.96 46.02 41.94 2650,33 2531,33 1006.36 765.84 653,53 0,86 -0.82 0,36 2587426,44 332705,44 N 61443.337 W 1505641,386 3010,80 44,83 41,68 2693.73 2574.73 1050,35 798,67 682,90 1.95 -1.92 -0,42 2587458.85 332735.27 N 61443.660 W 150 56 40.789 3072.19 45.94 42.92 2736.85 2617.85 1093.96 830.99 712.31 2.31 1.81 2.02 2587490.73 332765.15 N 61443.979 W 1505640.191 3134.78 45.84 42.87 2780.41 2661.41 1138.79 863.91 742.90 0.17 -0.16 -0.08 2587523.20 332796.21 N 61 444.303 W 150 56 39.569 3196,70 47.81 40.90 2822.78 2703.78 1183.87 897.53 773.04 3.94 3.18 -3.18 2587556.38 332826.83 N 61 444.634 W 1505638.956 3258.65 47.09 40.54 2864.67 2745.67 1229.49 932.12 802.81 1.24 -1.16 -0.58 2587590.53 332857.09 N 61444.974 W 1505638.351 3319.38 46.18 40.75 2906.37 2787.37 1273.61 965.62 831.57 1.52 -1.50 0.35 2587623.61 332886.33 N 61 4 45.304 W 15056 37.766 3382.61 48.86 41.30 2949.07 2830.07 1320.21 1000.79 862.18 4.29 4.24 0.87 2587658.34 332917.45 N61445.651 W 1505637.144 3440.45 48.08 41.62 2987.42 2868.42 1363.46 1033.24 890.84 1.41 -1.35 0.55 2587690.36 332946.58 N 61 4 45.970 W 150 56 36.561 3503.71 47.45 41.64 3029.94 2910.94 1410.24 1068.25 921.96 1.00 -1.00 0.03 2587724.92 332978.19 N 61446.315 W 150 56 35.929 3565.63 46.73 42.06 3072.10 2953.10 1455.53 1102.03 952.22 1.26 -1.16 0.68 2587758.25 333008.94 N 61446.847 W 1505635.313 3626,98 46.12 42.18 3114.39 2995.39 1499,90 1135.00 982.02 1.00 -0.99 0.20 2587790.78 333039.22 N 61 446.972 W 1505634.707 3688.26 47.88 42.37 3156.18 3037.18 1544.63 1168.16 1012.17 2.88 2.87 0.31 2587823.50 333069.84 N 61 447.299 W 1505634.094 3750.10 47.67 42.01 3197.74 3078.74 1590.35 1202.09 1042.93 0.55 -0.34 -0.58 2587856.98 333101.08 N 61 447.633 W 1505633.469 3811.79 47.35 42.05 3239.41 3120.41 1635.76 1235.88 1073.38 0.52 -0.52 0.06 2587890.32 333132.02 N 61 447.965 W 150 56 32.850 3874,11 46.84 41.95 3281.83 3162.83 1681.34 1269.80 1103.93 0.83 -0.82 -0.16 2587923.80 333163.05 N 61 448.299 W 150 56 32.229 3933.39 46.84 41.66 3322.38 3203.38 1724.52 1302.04 1132.75 0.36 0.00 -0.49 2587955.61 333192.34 N 61 448.617 W 1505631.643 3993.68 48.21 40.56 3363.09 3244.09 1768.95 1335.54 1161.99 2.64 2.27 -1.82 2587988.68 333222.05 N 61 448.947 W 15056 31.048 4056.78 47.86 40.91 3405.29 3286.29 1815.85 1371.09 1192.60 0.69 -0.55 0.55 2588023.78 333253.18 N 61 4 49.297 W 1505630.426 4118.69 47.54 41.15 3446.95 3327.95 1861.60 1405.64 1222.66 0.59 -0.52 0.39 2588057.89 333283.73 N61449.637 W1505629.815 4180.00 47.05 41.39 3488.54 3369.54 1906.61 1439.50 1252.38 0.85 -0.80 0.39 2588091.31 333313.94 N 61 4 49.910 W 150 56 29.210 4241,81 47.02 41.01 3530.66 3411.66 1951.81 1473.53 1282.17 0.45 -0.05 -0.61 2588124.91 333344.22 N 61 4 50.305 W 150 56 28.605 4303,82 47.92 40.77 3572.58 3453.58 1997.47 1508.08 1312.08 1.48 1.45 -0.39 2588159.01 333374.62 N 61 4 50.845 W 150 56 27.996 4364.63 47.53 40.53 3613.49 3494.49 2042.44 1542.21 1341.40 0.70 -0.64 -0.39 2588192.72 333404.43 N 61450.981 W 1505627.400 4427.19 47.11 40.73 3655.90 3536.90 2088.41 1577.12 1371.34 0.71 -0.67 0.32 2588227.18 333434.87 N 61451.325 W 1505626.792 4488.94 46.98 40.46 3697.97 3578.97 2133.58 1611.43 1400.75 0.38 -0.21 -0.44 2588261.07 333464.77 N61451.663 W1505626.194 4550.53 47.23 40.56 3739.89 3620.89 2178.68 1645.74 1430.06 0.42 0.41 0.16 2588294.94 333494.58 N 61 452.001 W 1505625.598 4610.88 48.01 39.18 3780.57 3661.57 2223.25 1679.96 1458.64 2.13 1,29 -2.29 2588328.74 333523.64 N 61452.338 W 1505625.017 4672.84 47.79 40.76 3822.12 3703.12 2269.21 1715.19 1488.16 1.93 -0.36 2.55 2588363.54 333553.68 N 61 452.685 W 1505624.416 4733.65 47.16 41.09 3863.22 3744.22 2314.00 1749.05 1517.52 1.11 -1.04 0.54 2588396.97 333583.52 N 61453.018 W 15056 23.819 4796.30 49.15 38.16 3905.02 3786.02 2360.65 1785.00 1547.26 4.71 3.18 -4.68 2588432.48 333613.78 N 61 453.372 W 1505623.214 4857.59 48.98 38.40 3945.17 3826.17 2406.95 1821.35 1575.95 0.41 -0.28 0.39 2588468.40 333642.98 N 61 453.730 W 1505622.631 4918.40 49.61 37.57 3984.83 3865.83 2453.05 1857.68 1604.32 1.46 1.04 -1.36 2588504.32 333671.87 N 61 4 54.088 W 150 56 22.054 4979,71 49.14 37.81 4024.75 3905.75 2499.57 1894,50 1632.77 0.82 -0.77 0.39 2588540.72 333700.85 N 61 4 54.450 W 150 56 21.476 5040.33 49.96 36.86 4064.08 3945.08 2545.69 1931.18 1660.74 1.80 1.35 -1.57 2588576.99 333729.35 N61454.811 W1505620.907 5102.44 49.92 36.42 4104.05 3985.05 2593.19 1969.32 1689.11 0.55 -0.06 -0.71 2588614.72 333758.27 N 61455.187 W 1505620.330 5163.87 49.88 35.08 4143.62 4024.62 2640.11 2007.46 1716.56 1.67 -0.07 -2.18 2588652.45 333786.27 N61455.562 W 1505619.772 5225.97 49.45 34.79 4183.82 4064.82 2687.34 2046.27 1743.67 0.78 -0.69 -0.47 2588690.85 333813.93 N 61455.944 W 150 5619.220 5287.48 48.99 35.00 4223.99 4104.99 2133.80 2084.47 1770.32 0.79 -0.75 0.34 2588728.66 333841.13 N 61456.320 W 150 5618.679 5349.29 48.48 35.02 4264,76 4145.76 2780,16 2122.52 1796.97 0.83 -0.83 0.03 2588766.32 333868.33 N61456.695 W1505618.137 5409.88 49.85 34.99 4304.38 4185.38 2825.90 2160.07 1823.27 2.26 2,26 -0.05 2588803.48 333895.17 N 61457.065 W 1505617.602 5470.69 49.41 35.42 4343.76 4224.76 2872.14 2197.93 1849.98 0.90 -0.72 0.71 2588840.95 333922.42 N 61457.438 W 1505617.059 5532.67 48.94 35.07 4384.28 4265.28 2918.95 2236.23 1877.04 0.87 -0.76 -0.56 2588878.85 333950.03 N 61457.815 W 1505616.508 5593.99 48.30 35.24 4424.82 4305.82 2964.87 2273.85 1903.54 1.06 -1.04 0.28 2588916.08 333977.07 N61458.185 W1505615.969 5656.19 47.65 35.07 4466.46 4347.46 3010.98 2311.62 1930.14 1.06 -1.05 -0.27 2588953.46 334004.21 N 61458.557 W 1505615.428 5718.38 47.03 34.80 4508.60 4389.60 3056.61 2349.12 1956.33 1.05 -1.00 -0.43 2588990.57 334030.94 N 61458.926 W 1505614.896 5780.02 46.49 35.29 4550.83 4431.83 3101.41 2385.88 1982.11 1.05 -0.88 0.79 2589026.95 334057.26 N 61459.288 W 1505614.371 5839.74 46.53 38.45 4591.94 4472.94 3144.71 2420.53 2008.10 3.84 0.07 5.29 2589061.22 334083.74 N 61459.629 W 150 5613.843 5903.53 46.37 38.23 4635.89 4516.89 3190.94 2456.79 2036.78 0.35 -0.25 -0.34 2589097.06 334112.94 N 61459.986 W 150 5613.260 5965.12 44.79 41.46 4679.00 4560.00 3234.91 2490.57 2064.95 4.54 -2.57 5.24 2589130.43 334141.59 N 61 50,319 W 1505612.687 6026.60 44.23 41.86 4722.84 4603.84 3277,95 2522.77 2093.59 1.02 -0.91 0.65 2589162.20 334170.70 N6150.636 W1505612.104 6087.06 44.12 41,51 4766.20 4647.20 3320.03 2554.23 2121.61 0.44 -0.18 -0.58 2589193.26 334199.17 N 6150.946 W 1505611.534 6146.34 44.02 44.53 4808.80 4689.80 3361.14 2584.37 2149.74 3.55 -0.17 5.09 2589222.98 334227.72 N 6151.242 W 1505610.963 6210.05 43.51 45.07 4854.81 4735.81 3404.97 2615.64 2180.79 0,99 -0.80 0.85 2589253.80 334259.22 N 61 51.550 W 1505610.331 6271.13 43.00 45.49 4899.30 4780.30 3446.56 2645.09 2210.53 0.96 -0.83 0.69 2589282.81 334289.38 N 6151.840 W 150569.726 6332.30 43.14 48.06 4943.99 4824.99 3487.92 2673.70 2240.96 2.88 0.23 4.20 2589310.97 334320.23 N 6152.122 W 150569.107 6394.34 42.63 47.97 4989.44 4870.44 3529.60 2701.94 2272.34 0.83 -0.82 -0.15 2589338.75 334352.01 N 61 5 2.400 W 150 56 8.469 6454.71 42.31 48.14 5033.97 4914.97 3569.83 2729.18 2302.66 0.56 -0.53 0.28 2589365.55 334382.72 N 61 5 2.668 W 15056 7.853 6518.33 41.92 47.84 5081.17 4962.17 3611.95 2757.74 2334.36 0.69 -0.61 -0.47 2589393.64 334414.83 N 61 5 2.949 W 150567.208 6580.09 41.51 47.87 5127.27 5008.27 3652.53 2785.31 2364.83 0.66 -0.66 0.05 2589420.77 334445.70 N 61 5 3.221 W 150 56 6.588 6641.97 40.90 48.00 5173.82 5054.82 3692.78 2812.62 2395.10 1.00 -0.99 0.21 2589447.64 334476.35 N 61 5 3.490 W 150565.973 6703.98 40.30 48.19 5220.91 5101.91 3732.61 2839.58 2425.13 0.99 -0.97 0.31 2589474.15 334506.77 N 61 5 3.755 W 150 56 5.362 6763.53 40.23 49.12 5266.35 5147.35 3770.53 2865.00 2454.02 1.02 -0.12 1.56 2589499.16 334536.02 N 61 5 4.005 W 150564.774 6825.43 40.65 49.27 5313.46 5194.46 3810.02 2891.24 2484.42 0.70 0.68 0.24 2589524.95 334566.79 N 61 5 4.264 W 150564.156 6886.85 41.38 49.70 5359.80 5240.80 3849.63 2917.42 2515.06 1.27 1.19 0.70 2589550.68 334597.81 N 61 5 4.521 W 150 56 3.533 6948.87 41.10 46.55 5406.44 5287.44 3889.96 2944.71 2545.50 3.38 -0.45 -5.08 2589577.52 334628.64 N 6154.790 W 150562.914 7009.58 41.51 45.50 5452.05 5333.05 3929.72 2972.53 2574.33 1.33 0.68 -1.73 2589604.92 334657.87 N 61 5 5.064 W 150 56 2.328 SurveyEdnor Ver 3.1 RT-SP3.03-HF1.2 Bld( d031 rt-546 ) A-10 (slot 6 leg 2)1A-101A-10AIA-10A Generated 11/6/2003 10:20 AM Page 2 of 3 . . 7071.39 41.13 42.95 5496.47 5379.47 3970.34 3001.77 2602.79 2.79 -0.61 -4.13 2569633.74 334666.75 N 61 5 5.352 W 15056 1.749 7126.93 41.06 42.20 5540.33 5421.33 4006.77 3026.65 2627.49 0.90 -0.13 -1.35 2569660.26 334711.63 N 61 55.616 W 150561.247 7194.15 41.47 42.59 5590.66 5471.86 4051.01 3061.39 2657.39 0.72 0.61 0.56 2569692.56 334742.20 N 61 5 5.939 W 150560.639 7256.06 41.95 42.74 5637.07 5516.07 4092.11 3091.68 2665.30 0.79 0.76 0.24 2589722.44 334770.55 N 61 5 6.237 W 150560.071 7317.66 42.28 43.01 5682.78 5563.76 4133.33 3121.97 2713.42 0.61 0.54 0.44 2569752.32 334799.10 N 61 5 6.535 W 150 55 59.499 7379.13 42.66 43.30 5726.10 5609.10 4174.71 3152.24 2741.60 0.72 0.65 0.47 2569762.17 334627.92 N 61 56.633 W 150 55 56.922 7439.58 41.99 45.29 5772.79 5653.79 4215.23 3181.38 2770.23 2.49 -1.14 3.29 2569610.69 334656.76 N6157.120 W1505556.344 7501.94 42.22 45.61 5619.06 5700.06 4256.75 3210.66 2600.06 0.67 0.37 0.63 2569639.74 334667.02 N 61 57.406 W 1505557.737 7563.36 41.06 45.24 5664.97 5745.97 4297.30 3239.26 2829.21 1.96 -1.86 -0.93 2569667.91 334916.57 N 61 57.690 W 1505557.144 7625.26 41.21 45.94 5911.57 5792.57 4337.73 3267.75 2856.30 0.77 0.21 1.13 2569695.96 334946.06 N 61 57.970 W 150 55 56.552 7666.96 39.14 46.44 5956.72 5639.72 4377.22 3295.32 2667.03 3.39 -3.35 0.61 2569923.12 334975.19 N 61 56.242 W 1505555.966 7748.31 39.01 46.75 6006.33 5667.33 4415.52 3321.68 2915.11 0.38 -0.21 0.51 2569949.26 335003.65 N 61 56.503 W 1505555.397 7610.26 39.30 47.43 6054.37 5935.37 4454.23 3346.51 2943.76 0.64 0.47 1.10 2569975.49 335032.68 N 6156.765 W 1505554.814 7671.99 38.91 46.19 6102.28 5963.26 4492.69 3374.66 2972.61 1.00 -0.63 1.23 2590001.21 335061.90 N 61 59.023 W 1505554.226 7931.75 39.44 46.66 6146.60 6029.60 4529.69 3399.66 3000.89 1.13 0.69 1.12 2590025.60 335090.54 N 61 59.269 W 1505553.652 7993.14 39.92 49.12 6195.65 6076.85 4568.47 3425.36 3030.47 0.63 0.76 0.42 2590051.09 335120.49 N 61 59.522 W 150 55 53.051 8055.43 39.70 46.90 6243.70 6124.70 4607.64 3452.06 3060.11 2.31 -0.35 -3.56 2590077.33 335150.51 N 61 59.765 W 1505552.446 8086.67 39.29 47.30 6267.81 6146.81 4627.50 3465.56 3074.67 1.54 -1.31 1.28 2590090.64 335165.26 N6159.918 W 1505552.152 8148.65 40.11 46.38 6315.65 6196.65 4666.63 3492.75 3103.63 1.62 1.32 -1.48 2590117.39 335194.62 N 61510.185 W 1505551.563 8209.52 38.65 46.22 6362.48 6243.46 4705.07 3519.40 3131.52 2.08 -2.08 -0.26 2590143.63 335222.89 N 61510.447 W 150 55 50.995 8271.90 37.23 46.25 6411.60 6292.60 4743.19 3545.99 3159.26 2.60 -2.60 0.05 2590169.81 335251.03 N 61 510.709 W 1505550.431 8332.94 37.60 45.28 6460.09 6341.09 4780.00 3571.86 3185.85 1.14 0.61 -1.59 2590195.29 335277.97 N 61 510.964 W 150 55 49.890 8395.20 36.46 44.71 6509.78 6390.78 4617.26 3596.38 3212.37 1.88 -1.80 -0.92 2590221.42 335304.86 N 61511.225 W 150 55 49.351 6455.54 35.15 44.19 6556.71 6439.71 4652.42 3623.59 3237.10 2.26 -2.20 -0.66 2590246.26 335329.95 N 61511.473 W 15055 48.848 8516.67 34.26 44.07 6608.96 6489.96 4667.06 3646.57 3261.34 1.43 ·1.42 -0.20 2590270.89 335354.55 N 61511.719 W 1505548.355 8577.03 33.63 44.35 6659.03 6540.03 4920.65 3672.74 3264.85 1.11 -1.08 0.46 2590294.71 335378.40 N 61 511.957 W 150 55 47.677 8638.38 32.79 43.89 6710.36 6591.36 4954.10 3696.86 3306.24 1.43 -1.37 -0.75 2590318.49 335402.14 N 61512.194 W 1505547.401 8699.83 31.74 44.39 6762.32 6643.32 4966.77 3720.40 3331.08 1.76 -1.71 0.61 2590341.70 335425.32 N61512.426 W1505546.936 8774.59 30.60 44.36 6826.22 6707.22 5025.39 3746.14 3358.22 1.26 -1.26 -0.04 2590369.04 335452.86 N 61512.699 W 1505546.384 6640.00 30.60 44.36 6862.40 6763.40 5058.72 3772.09 3381.64 0.00 0.00 0.00 2590392.64 335476.62 N 61 512.935 W 150 55 45.906 SurveyEd~or Ver 3.1 RT-SP3.03-HF1.2 Bld( d031 rt-546 ) A-10 (slot 6 leg 2)1A-101A-10AIA-10A Generated 11/612003 10:20 AM Page 3 of 3 . . 38 !!!L 36 J34 366 J 32 ,m J 300 NCIU A-10a ACTUAL WELL BORE DIAGRAM, 9/29/03 BPV(M.aJœ,Type,OD) Cameron Type H 'Ibg.If¡r.<Maket'l'ype.) me 4112"EUEtopX4112"IB'lbCm ADDulusndd: !%KCLwlthc:orTOdoø.lahIbItør TOCI 26ZO' CBL WATER DEPl'H: 120' RKB-DriD Deek: RK8-TID': 43.'1' RKB-SL: RKB-ML; ",. 16" 103/4" 103/4" 7-S/S" Prodacdoa Casql 41 366 41 631 41 1,695 1695' 1911'KOP '" ...,. ................' 0' 4.708 ì76S' 7,972 4O.S#ftt 4S.5#lft 29.7Ib1ft J·55 J·55 L·80 BT&.C BT&C BT&C 31'" 3580 689Q 1580 ""'" 4790 629 715 683 J30c .J 1 29b _288 4112" 3-112" 15' PBR on top of pier Baker Premer Packer @ 4307' PRODUCTION TUBING STRING 39 0.00 43.78 Rlevadon fromKuukpik aiR #5 to LDS on tbg bead ~ 29 TCP p9l1s. not gravel packed 38 43.78 0.66 FMCJ11' x4-1J2"thg hgr, .4 1n- EVE lop and IBT btm 3.958 11.000 4415',4423' 37 44.44 369.68 4112" 12.61b1ft L-BO ModIBTTuhing 3.958 5.563 4454'·4487' 36 414.U 6.65 Cameo 4-112· TRM-4PECF'IRSSSV wlflow cp1gs 3.813 6.000 35 4'1J).77 935.53 4112! 1261b1ft L-80ModmTTubing 3.958 5.563 34 13"'-30 7.31 4-1I21t."lltCamcoKBG-2GLMwitbOLV,9n:lJ03 3.865 6.05. -? 33 1363.61 1034.53 4112" 126lb1ft L-M ModmT Tubing 3.958 5.563 SC-2 pkr aæ¡@ 4694' 32 23.98.14 1.34 4-112" x lit CamooKBG-2OLMwi1bGLV.9n:lm 3.865 6.059 with KOIV 31 2405.48 980.17 41/2" 12.61b1t't L-BO ModmT Tubing 3.958 5.563 24 30, 33..... 7.32 4-112~11wcamooKB(j.2GLMWi1bGLV,9!27J03 3.865 6.0.59 23 3Ot> 3392.97 821.73 4112" 12.61b1ft L·80 ModmT TubiJijt 3.958 5.563 22 30c 4'l2O.70 7.33 4-1I2"11"CamcoKBG-zGLMwitbGLV,9!27J03 3.865 6.059 4805'-4905' 29 4228.03 49.21 41/2" 12.6lb1ft L-80 ModIBT Tubing 3.958 5.563 4920',5005' 29b 4217.24 29.95 8047 PBR with 15' seal travel 21 28a 4301.19 7.06 Baker I'remierpacker 3.875 6.500 28t> 4314.25 350.39 4112" 12.6 IbIft L-80 Mod:IBT Tubing 3.95& 5.563 - - SC-1l pier assy @ 5017' ,. 4664.64 4.74 Baker 4-1/2" CMU sliding sleevewitb 3,8}3" "X" profile 3.813 5.500 ZI 4669.38 38.11 41f2" 12.6lb1ft L-BO ModIBT Tubi~ 3.951 5.563 20 1fi 47CfT.49 0.98 Baker 4-112" S-22Ancbor la1Chseal assy 3.230 4.21. 25 47...47 37.85 BakerSC-Z Packer Assembly {tb¡;t tally) 4.000 6.490 Depths above this point are ~ taUy dpeths Depths beloW Ibis point are COITeIated to CBL 9ßJOO 20a 25 4694.01 37,85 :BakerSC-ZPackerAssembly(oorrelatedtoCBL) 4.000 6.490 ., ~ SC-1lpkrassy@ 5611' 24 4731.86 2.52 :BakerModelCwitbKOIVwfProte<:tŒsleeve 3.375 5.630 KOIV puncbedoutwitbinner string$on 9/W/œ 23 4134.38 64.42 4" 9.S#SUIT blank tbg 3'>48 4.000 5685'-5700' 22 4798.30 217.84 4" Bake1weld SClefÐ, .012' gauge 3.>48 4.590 19a_ 5894'-5915' 21 ..,..... 24.18 Baker SC lLMuJlizme packer assy 3.250 6.490 6090'-6105' '" 5040.32 569.83 4" 9.5#SUfT blank tbg 3.>48 4.000 6185'-6195' "'" 5610.65 24.13 BakerSC-ILMullironepackerassy 3.250 6.490 1. 5634.83 37.55 4~9.5#Surrbtankttg 3.>48 4.000 ,.. 5672.38 535.53 4" Bakerweld screen, .012' ga~ 3.>48 4.590 ..Fïiï. 5-228 Snap IaIch (pI\ß two x 9'Braden Nank joints at5813.56'-5822Só' and 6010.53'-6019.56') SC-2 Pkr assy @ 6209' 18 6207.91 0.87 BakerS·22BsnaplatGb 3.230 4.218 17 .....7. 35.95 Baker SC-2 Packer Assembly 4.000 6.490 1. 6244.73 252 Baker Model CKOIV Protector sleeve (missingKOIV) 3.500 5.630 15 16 6241.25 45.13 4" 9.5#SUIT blank tbg 3.>48 4.000 6300'-ffi10' 15 6292.98 423.27 4"Bake1weklscreeu...012'gauge 3.>48 4.590 6450'-6525' (plus two x 9'Braden blaDkjoints at 6396.13'-6405.16 and 6592.53'-6601.56') 6646'-6665' 14 6716.25 24.18 BakerSCILMu1ti:ronepackerassy 3.250 6.490 , 6685'-6710' 13 6740.43 73.12 4" 9.5#SUff blank tbg 3.>48 4.000 , , - 12 6813.55 367.15 4" Bakerwekl screen, .012' gauge 3.>48 4.590 , - SG-1lpkrassy@ 6716" (ptusone 9'Braden blank joint at 6906.35'-6915.88) 11 7180.70 24.18 Baker SCIL Multizooe packer assy 3.250 6.490 10 120.4.88 58.82 4" 9.S#SUff blank ttg 3.>48 4.000 13 . 7263.70 300.43 4" Baketweld screen, .012' ~ 3.>48 4.590 6825'-6865' (plus one 9'Braden blank joint at 7366.77'-7375.80') 7010'-7028· 7564.13 0.87 Baker S-22:B snap latch 3.280 4.21. 12 7165'-7175" 756!.OO 13.30 Baker FR-! Sump packer assy witb 4-112" buttress pin down 4.000 6.500 , 11 7573.30 135.63 4-1/212.6#buttress~Six;O¡nts 3.958 5.563 11IIII - SC-1lpkrassy@ 7181' 7763.93 1.68 4-1ITx3-1/2'"crossovu 3.940 5.375 7765.61 3O.983-1I29.3#buttresstbt.ljt 2992 ~250 10 7796.59 1.02 3-112" X nipple, 2813" ID 2813 4.250 7270'·72S0' 77tfl.61 30,93 3-1I29.3#buttresstbg.ljt 2992 4.250 7425'·7450' 782&..54 1,43 3-1I2"buttressx4"SUITxover 2992 4.500 7515'-7555' A 7&1!J.97 75,13 4"SUITexcJuderscreen,twojts. 3.>48 5.011J B 7905.10 1.43 3-1f2"buttressx4"SUITxover 2992 4.580 V' S-22B Snap latch C 7906.>3 31.00 3-1/29.3#buttress~ljt 2992 4.250 FB-1 SUß1) Pier @ 7565' D 7937.53 1.01 3·1I2"Xnipp~.2813"ID 2813 4.250 . 7938.54 31.16 3·1129.3#buttress~ Ijt 2992 4.250 F 1970.30 1.31 Endo(~3-1f2"WLEG 2992 3.800 ~ . "X" 3 3-1n-Xnlppte 2.1 A Two Its 01 4" Excluder screen, fine SIX Braden blank Joints are 9' long wfth RadIoactive CüIar allop 01 joinI at B.C 581'4',6011',6396',6593', 6907'and 7371' 'X" D 3-112" X nipple E Three RadIoactIve 7·5/8" casing cplgs at 4366'. 5879' and 7450' elm (CBL 9.G103) 7972' F pns.<\Ihla Future perts S400' ·8510· 7-5/8" @ 8830' TO =8840' MD16882' TVD UpWot<d by ,Billiot: '129/fJ3 TbgWt PBTDo 18743' _, 4-1f2"126Ib1ft Well: North CookIDlet Uo1tNo. A-lOa hroI''''''' Location: Tyonet PIatfonn, CookInlet, Alaska Field: Nottb. Cook InletUnit e ConocJPt.illips . Ðð,3-0'15 TRANSMITTAL FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Steve Davies AOGCC 333 W. ih Ave, Suite 100 Anchorage, Alaska 99501 RE: NCIU A-10A Permit: 203-075 DATE: 11/05/2003 Transmitted: Floppy and hardcopy directional survey report 'v~mberger-MWD directional survey; hardcopy QC report and digital load .txt file MD/INC/AZ; 0-8840'md 81ackline log prints Schlumberger v~ment Bond log, 9/3/03 , ~ole Shear Sonic; P&S 08/17/03 þ ~Ie Shear Sonic; TVD; P&S 08/17/03 t- ~n Resistivity, TVD; 8/16/03 z,.;MSIÕÍÍ·Resistivity, MD; 8/16/03 ¿:.,.c'I1ís·ion Service TCB; TVD; 8/16/03 ¿....vísíón Service TCB; MD; 8/16/03 t ...vísIon De.nsity Neutron; MD; 8/16/03 ¡ ~nsity Netron; TVD; 8/16/03 '4-",. r:~ J \~ ,"\1 H\P;' \'1 v ~;j Q! Please check off each item as received, promptly sign and return the transmittal enclosed to address below. " Receipt: Return receipt to: Date: ConocoPhillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Prepared by: Sandra D. Lemke ConocoPhillips Alaska, Inc. Global Information IT-Tech Data Management 907.265.6947 Sandra.D.Lemke@Conocophillips.com ~~~r\~ . Co~illips . -1 ~',\ '\ ! \l OCT 2 8 TRANSMITTAL ¿y FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Howard Okland AOGCC .~Q3 -oiS 333 W. ih Ave, Suite 100 U' Anchorage, Alaska 99501 RE: NCIU A-10A "'~.~.- Permit: 203-075 DATE: 1 0/27/2003 r Transmitted: J ~ /7CJ - \ ~.;::---, ¡=:'ü l ~ ~~.x. CftROM - Mud LOQ data ~ Epoch - Final Well Report; DML, final well report text, morning reports; LAS files and PDF log image files; accompanies hardcopy report delivered to AOGÇ~ 9/18/~?~ I a /1 d.. ;~A -_ //~Cy~ c;,OROMs - Sch/umber.,oer /o.,oging data~~~V \)/~ ~ Modified LDWG Open hole edit; MWD/DSI/FMI/CET; 1593-8802.5; 8/3 through 9/3/2003; Job 23419 Jd It-I ~ Field MWD DUS and PDS files (MWD/MAD) 1806.5'-8839.5'; Job 23419 ~ Field MDT in DUS/PDS; Field Cement Bond in DUS/PDS 1593'-8734'; Job 2341918-ILo1 ;?FieJd DSJ in DLlS and PDS; 1850'-8128' md; Job23419~- Ie) iß8" . Field FMI main IOQ SUS, Field FMI PDS; Field FMI/DSI Repeat DUS; 1850'-8128'md FG'"GY)~~~~V) Job 23419 ~ J ~ J wr- Please check off each item as received, promptly sign and return the transmittal enclosed to address below. CC: Rick Levinson, Receipt: Return receipt to: """''\.~ Date: /0 .'2ß ,,0 '3 ConocoPhillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Prepared by: Sandra D. Lemke ConocoPhillips Alaska, Inc. Global Information IT-Tech Data Management 907.265.6947 EI\/EO Sandra. D.Lemke@Conocophillips.com OC'1- f) (i , l_ () -~ fZ\~~~~\\\ .~ C(jmm¡~sion /\Jh:tor!tg~) . ConocÓPhillips . ~Oi3--o7S TRANSMITTAL FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Howard Okland AOGCC 333 W. ¡th Ave, Suite 100 Anchorage, Alaska 99501 RE: NCIU A-10A Permit: 203-075 DATE: 9/16/2003 Transmitted: Hardcopy Report and mud /OQ data _ Epoch- Final Well Report -DML Data -Final well Report -Log Prints - Formation Log TVD and MD; DML-MWD Combo TVD and MD -Morning reports reproducible Formation Log 2"=100'; 1910'-8840'md Please check off each item as received, promptly sign and return one of the two transmittals enclosed to address below The other copy is for your records. CC: Rick LevinsoÄil W~I Geologist Receipt: . ~ () W Return receipt to: ConocoPhillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Date: Prepared by: Sa~d~D. Lemke ConocoPhillips Alaska, Inc. Global Information IT-Tech Data Management 907.265.6947 Sandra. D. Lemke@Conocophillips.com ~~·\\\0 . ~ . . NC. ~- ,D \<0<; -Œ;~ ~-\a,"" dD~-O\5'" Variance Request ~c..\ \..) ç.'<L~ ~\\~ ConocoPhillips Alaska Kuupkik Rig 5 North Cook Inlet Platform ConocoPhillips Alaska (CPA) has moved Kuupkik Rig 5 to North Cook Inlet Platform to perform drilling and completion operations on the platform. Inspector John Crisp witnessed the initial BOP test on June 22 and noted 5 discrepancies. Preparatory operations were allowed to continue, however CPA was required to remedy the discrepancies before conducting what would be considered "open hole" activities. As of the afternoon of June 25, 2003, CPA had completely remedied 3 of the discrepancies. The 4th discrepancy was expected to be remedied following arrival of the necessary LEL calibration gas on the evening of June 25. The final discrepancy, distinct audio alarms for H2S and methane, is not expected to be remedied until sometime Friday June 26. CPA has requested a variance to the requirements of 20 AAC 25.066(6) so operations might proceed. In support of their request, CPA stipulates that 1-AII required gas detection sensors are in place and functional. 2--There are functioning, individual, visual indicators for H2S and methane. 3--The 7" casing will not be cut until the LEL detectors have been properly calibrated. 4- The gas on North Cook Inlet does not contain H2S. 5- The recognized risk of H2S lies in cutting the 7" casing and circulating the "fluids" that have been in place for some 35 years. 6-CPA has hand held detectors available. Regulation 20 AAC 25.066(d)(3) allows the Commission to approve a variance from the requirements of this section [.066] if the variance provides at least an equally effective means of gas detection. The ability to detect either gas is not compromised by granting CPA's request. If either H2S or methane were detected, the individual visual indicators would signal appropriately. If high detection limit were exceeded for either gas, the single audio alarm would sound. I recommend approval of CPA's variance request. This approval is only for the time necessary for CPA to obtain the necessary "horn" parts. As noted in CPA's variance request, they expect to remedy the 5th discrepancy on June 26, 2003. ~11~ Tom Maunder, PE Sr. Petroleum Engineer [F"Wd: Kuupik Rig 5 BOP test compliance issue. t . Subject: [Fwd: Kuupik Rig 5 BOP test compliance issues] Date: Wed, 25 Jun 2003 16:54:42 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Randy Ruedrich <randy_ruedrich@admin.state.ak.us>, Dan T Seamount <dan_seamount@admin.state.ak.us>, Sarah Palin <sarahJ)alin@admin.state.ak.us> CC: Jim Regg <jim_regg@admin.state.ak.us>, Winton GAubert <winton_aubert@admin.state.ak.us> All, Enclosed ¡sa response to CPA with regard to a H2S gas alarm variance request. I discussed this matter with Randy and he gave his approval to send the response. The analysis note is attached. Tom Subject: Re: Kuupik Rig 5 BOP test compliance issues Date: Wed, 25 Jun 200316:52:38 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Tim A Billingsley <Tim.A.Billingsley@conocophillips.com> CC: Kuupik 5 Company Man <Kuupik5CompanyMan@conocophillips.com>, Kuupik 5 Tool Pusher <Kuupik5TooIPusher@conocophillips.com>, Larry Ross <Iarry@kuukpik-drlg.com>, Paul Mazzolini <PauI.Mazzolini@conocophillips.com>, AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us> Tim et ai, An evaluation has been made of your request for a variance to the requirements to have separate audio alarms for the H2S and methane detectors on board the Kuupkik 5 rig on NCIU platform. Your request for variance has been approved. This approval is for roughly the next 24 - 30 hours to allow ConocoPhillips to obtain the necessary parts to allow the separate audio alarms. As you indicated in your request, the LEL detectors must be satisfactorily calibrated before any operations to cut the 7" casing may be undertaken. Both the H2S and methane detectors and the associated visual alarms must be operational. You correctly identify the H2S risk as being from the "fluids" in the 10-3/4" x 7" annulus that will be circulated from the wellbore following the cut. You are urged to take prudent precautions when circulating that annulus. Please keep us informed as to the status of finally remedying the audible alarm discrepancy. Tom Maunder, PE Sr. Petroleum Engineer Tim A Billingsley wrote: > Tom, > (See attached file: 1_BOP Kuukpik 5 06-22-03 JC1.xls) > The BOP test of 6/22/03 on Tyonek Well A-1 0 witnessed by John Crisp had the > following 5 failures (see attachment above). > These failures are all corrected or will be corrected before cutting the 7" > casing as shown below except for #5. > > 1) Floor valve - New floor valve has been obtained. > 2) LEL gas detector at shale shakers not working. New detector has been > installed. Calibration gas will be on the platform this evening to verify > detector operates correctly. > 3) Casing pressure gauge not working at choke panel next to driller's > console. This gauge has been repaired. > 4) Wellhead flange leaked. This has been fixed and pressure tested to 1500 > psi after NU the BOPs on the casing head. 1 of 3 6/26/20038:19 AM 1Fwd: Kuupik Rig 5 BOP test compliance ¡55. . 2of3 > 5) Gas detectors did not comply with 20 AAC 25.066(6), H2S and Methane > alarm systems need to be different from each other, both visual and audio > alarms need to be different from one another. This problem has not been > fully corrected yet. There is distinctly different visual alarms (Amber > for H2S and Red for LEL) but there is presently not distinct audio alarms > for H2S and LEL. There is only one alarm sound for both. A new audio > alarm is arriving and should be working by Friday. We do have handheld H2S > monitors which will be present when we circulate up the 7" x 10-3/4" > annulus. None of the wells at Tyonek platform produce H2s but there is a > possibility of H2S being present in the old annulus fluids that will be > circulated up the 7" x 10-3/4" annulus. If there is a release of H2S gas, > all of the detectors have been calibrated and will detect the H2S but the > audio alarm will not be distinguishable between H2S or LEL. > > Therefore, ConocoPhillips proposes: > ConocoPhillips will not cut the 7" casing until the calibration gas has > been transported to the platform and the LEL detectors checked. (item #2 > above). > ConocoPhillips requests permission to proceed with the 7" casing cut > tonight after the LEL detectors have been calibrated but before the > distinct H2S vs LEL audio alarm has been installed which will occur on > Friday. > > Thank you for your consideration. > > Tim Billingsley > 265-6531 > > > > > Name: 1_BOP Kuukpik 5 06-22-03 JC1.xls 1_BOP Kuukpik 5 06-22-03 JC1.xls Type: EXCEL File (application/msexcel) Encoding: base64 Tom Maunder <tom maunder{â>.admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission Name: 030625-gasdetVariance Request.doc D030625-QasdetVariance ReQuest.doc Type: WINWORD File (application/msword) Encoding: base64 Tom Maunder <tom maunder{â>.admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 6/26/20038:19 AM Re: Tyonek A-10 7" ram test . . Subject: Re: Tyonek A·10 7" ram test Date: Tue, 24 Jun 2003 09:25:22 -0800 . ..'-J From: Tom Maunder <tom_maunder@admin.state.ak.us> . _ To: Tim A Billingsley <TimABillingsley@conocophillips.com> (dO -:s t) ~ S- cc: AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us> ~ \ CoS -0<2><6 Tim, Thanks for the email, I don't see what other option you will have. Has there been any pressure noted on the 10-3/4" x 7" annulus?? That would be you f' greatest risk. Your proposal to test prior to ND against a BP in the casing was what I was thinking of after listening to your message. By copy of this email, your proposal is accepted. Good luck. Tom Maunder, PE AOGCC Tim A Billingsley wrote: > Tom, > As we discussed on the phone today, 6/24/03, the upcoming cut and pull of > the 7" casing on Tyonek A-10 is presenting difficulties in obtaining a > conventional 3000 psi test of the 7" rams. > Step #4 of the approved Permit to drill says "ND BOPs and ND tubing head. > Tack weld slips to 7" casing. NU BOPE to casing head. Test BOPE to 3000 > psi." > > The problem is that a test plug can not be run in the casinghead with the > slips and 7" stub in the way. Also, the 10-3/4" x 7" annulus will be in > communication with any BOP test pressure so the test pressure can not be > contained. So a BOP test after the BOPs are nippled up to the casinghead > can not be accomplished. > > ConocoPhillips proposes to: > 1) Set a 7" bridge plug at 2100'. > 2) Change the top pipe rams to 7". > 3) Pressure test to 1500 psi, a shell test on the 7" rams against the 7" > bridge plug. > 4) Nipple down the BOPs. > 5) Remove the tbg head. > 6) Tack weld the 7" slips to 7" casing stub. > 7) NU the BOPs to the casing head. > 8) Proceed with the 7" cut at 2100' and pull 7" casing. > 9) After the 7" casing has been pulled, set test plug in the casing head > bowl. > 10) Change 7" rams to 4-1/2" rams. > 11) Pressure test BOPs to 3000 psi. > 12) Proceed with step 7,preparing to sidetrack 10-3/4" casing at 2000'. > > Please let me know if the revised plan above meets with your approval. > > Also, the rig is working on the deficiencies that John Crisp noted. The > gas alarms are being corrected and will be done before the 7" casing is cut > and pulled. > > Tim Billingsley > 265-6531 1 of 2 7/24/2003 11 :46 AM . MEMORANDUM TO: Randy Ruedrich Commissioner THRU: Jim Reg9 P.I. Supervisor FROM: John Crisp Petroleum Inspector Operator Rep.: Mike Winfree Contractor Rep.: Otto/PulliQ/Peters Test Pressures Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve . State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 22, 2003 SUBJECT: Blowout Preventer Test New Contractor 5 Co no co/Phillips Tyonek Pit. A-10 Ptd 169-088 Sundry 302-237 N. Cook InletlBeluga Pool NON· CONFIDENTIAL Op. phone: 907 776-2350 Op. E-Mail: Rig phone: 907 776-2350 Rig E-Mail: Rams: 250/3000 P/F Sign: N/A Rig cond: .....!:..... Hazard: P Size 135/8 4.5 27/8x5.5 135/8 31/8 31/8 31/8 NIA P/F P P P P P P P Annular: 250/3000 Choke: 250/3000 TEST DATA FLOOR VALVES: Quantity P/F Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 F Inside BOP 1 P CHOKE MANIFOLD: No. Valves Man. Chokes Hyd. Chokes Quantity 16 1 ! P/F P P P MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector Visual P P P Tested Tested Alarm P P P F P MISC. INSPECTIONS: P/F Location Gen.: Good Housekeeping: V. Good PTD On Location Yes Standing Order: Yes BOP STACK: Quantity 1 1 1 1 1 1 2 ACCUMULATOR SYSTEM: Time/Psi P/F System Pressure 3000 After Closure 1650 200 psi Attained 18 sec. Full Pressure 2 min. 11 sec. Blind Covers (All Stations): Yes N2 Bottles (avg): 4 @ 2500 psi. Test's Details I traveled to C/P Tyonek PIt. to witness the initial BOP test on the de completion of well A-IO. The application for sundry approval number for de complete is 303-129. The PTD for the sidetrack of A-lOA is 203-075. 5 failures were witnessed on initial BOP test. Flange to W IH would not hold test pressure, this was seen leaking to atmosphere. There was no working gauge @ Drillers console or choke panel to show casing pressure. Floor safety valve leaked @ keyhole. Lighter than air gas detector @ the shale shakers failed to test. Gas detectors did not comply wi AOGCC Regulation 20 AAC 25.066 (6). Withe amount of cased hole work to be performed before wellbore pressure or fluids could be encountered @ surface, & wi the on duty AOGCC Engineer contacted for support, the cased hole operations were allowed to continue wi Rig out of compliance. The Rig must be in full compliance w/ AOGCC regulations before pressure tested 7" casing is cut. Total Test Time: 10 hrs. Number of failures: cc: BOP Test (for inspectors) BFL OS/29/03 § Attatchments: ~ 1_BOP Kuukpik 5 06-22-03 JC1.xls . rñìo -e I~ ~ Ill\ ~ ~~ ~ LW 'J f}1j...=J U U (l!) J~ Lrü . / / / / / FRANK H. MURKOWSKI, GOVERNOR J AI4A.SIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Mazzolini Cook Inlet Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 Re: NCill No. A-lOa ConocoPhillips Alaska, Inc. Pennit No: 203-075 Surface Location: 1304' FNL, 1023' FWL, Sec. 6, TUN, R9W, SM Bottomhole Location: 2794' FSL, 550' FEL, Sec. 31, TI2N, R9W, SM Dear Mr. Mazzolini, Enclosed is the approved application for pennit to redrill the above development well. This pennit to redrill does not exempt you ITom obtaining additional pennits or approvals required by law ITom other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~ Þ &e/-L-- ~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this "l. -,: day of April, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section Hole Casing 30" 22" 16" 15" 1 0-3/4' 9-1/2" 7-5/8" 19 Total Depth MD (ft): 8250' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments: Filing Fee Property Plat . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION . 1- '11, '1 PERMIT TO DRILL 20 MC 25.005 Redrill~ 11 b. Current Well Class: Stratigraphic Test D 1a. Type of Work: Drill D Re-entry D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 1304' FNL, 1023' FWL, Sec. 6, T11N, R9W, SM Top of Productive Horizon: 283' FSL, 2397' FWL, Sec. 31, T12N, R9W, SM Total Depth: 2794' FSL, 550' FEL, Sec. 31, T12N, R9W, SM 4b. Location of Well (State Base Plane Coordinates): 2.5'6~ 76. 2-1 ~/) Surface:x- 332040.92 y- ~ Zone- 4 16. Deviated wells: Kickoff depth: 2000 18. Casing Program Size ft. Maximum Hole Angle: 49° Weight Specifications Grade Coupling Length 65# 40.5&45 29.7 H-40 J-55 L-80 BTC BTC BTC 631' 2000' 7633' PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Plugs (measured) 6240' 4771' Length Size 366' 30" 631' 16" 2782' 10-3/4" 8228' 7" ExploratoryU Development Oil U Multiple Zone 0 Service D Development Gas 0 Single Zone D 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 NCIU No. A-10a 6. Proposed Depth: 12. Field/Pool(s): MD: 9433' TVD: 7266' No. Cook Inlet Field 7. Property Designation: Cook Inlet Pool 17589 ' Beluga Pool 8. Land Use Permit: 13. Approximate Spud Date: 2916 6/1/2003 9. Acres in Property: 14. Distance to 4375 Nearest Property: 5830 10. KB Elevation 15. Distance to Nearest (Height above sea): 116 feet Well within Pool: A-10 300' (twin well) 17. Anticipated Pressure (see 20 MC 25.035) Max. Downhole Pressure: 3146 psig Max. Surface Pressure: 2347 psig Setting Depth Quantity of Cement Bottom c. f. or sacks TVD (including stage data) 366' Driven 631' 610 sx Class G 1919' 737 sx Class G 7266' Proposed 718 sx Class G Top MD Surf Surf Surf 1800' TVD MD 366' 631' 2000' 9433' 1737' (To be com)leted for Redrill and Re-Entry Operations) I Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) 8183' 6194' Cement Volume MD Driven 366' 610sx 631' 737 sx 2782' TVD 366' 631' 2518' 1210sx 8228' 6225' 4890'-7765' o BOP Sketch ~ o Diverter Sketch D perfOration Depth TVD (ft): 3905'-5912' Drilling Program0 Time v. Depth Plot U Seabed Report D Drilling Fluid Program 0 Date: 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name P. Mazzolini Signature ?J rv]~ Commission Use Only Permit to Drill2D3-075' API Number: _ ?~-ð I Permit APPloyal ) Number: 50- ~3~· I Date: 7/ 2.Jjl D-::> Conditions of approval: Samples required D Yes ~ No Mud log required Hydrogen sulfide measures DYes IRI No Directional survey required Other: ~ö::Jt:)\' <>~, ~CJ \> ~ -\- _ tft?yA 'r:~Á ~' . --..-.-- - ) ~ J Approved by: Shallow Hazard Analysis U 20 AAC 25.050 requirements 0 Contact Questions? Call Tim Billingsley 265-6531 Title Cook Inlet Drilling Team Leader Phone Date 'o4-/,S/Zo063 Prepared by Tim Billingsley see cover letter for other requirements U Yes ~ No IX! Yes D No COMMISSIONER BY ORDER OF THE COMMISSION 'I/2-$/DJ Date: ORiGJ¡\JAL Form 10-401 Revised 3/2003 . Submit in duplicate · ... Application for Permit to Drill, Well A-10a ., Revision No.O Saved: 14-Apr-03 Permit - Tyonek Platform, North Cook Inlet Unit Well A-10a Application for Permit to Drill Document Table of Contents 1. Well Name ........................ ..... .......... ........ ............. .......... .... ....................... ....... ......... 2 Requirements of 20 AAC 25.005 (f)... .................. ........................... ................ ................ ...... ............. .....2 2. Location Summary.. ...... ...... ......... ........ ............ ........ ... ....... ....................... ...... ......... 2 Requirements of 20 AAC 25.005(c)(2) ...................................................................................................2 Requirements of 20 AAC 25. 050(b).......... .......... ............ ......... ..... ............... ........... .......... .... .................. 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................ ......... ............ .... ........ .., ................. ...... ............ ....... ..... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) ..................................................................................................3 6. Casing and Cementing Program.............................................................................4 Requirements of 20 AAC 25.005(c)(6) ..... ....... ................. ......... ............... ........... ................. ...... ............ 4 7. Diverter System Information ...................................................................................4 Requirements of 20 AAC 25.005(c)(7) .. ........ ........... .................................. ......... ........ ....... .................... 4 8. Dri II i ng FI uid Program .... ....... ......... ....................... ......... ......... ... .............................. 4 Requirements of 20 AAC 25.005(c)(B) .... ..... .......... .............. ........... ........... ..... ................ ...... ................. 4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis... ..... ..... ........ ......... ....................... ........ .......... ..... ..... ..................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................5 12. Evidence of Bond i ng .. ...... ........... ........ ......... ... .................... ..................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 ORIGliVAL A-10a PERMIT IT P4.DOC Page 1 of 7 Printed: 14-Apr-03 . ¡&Application for Permit to Drill, Well A-10a . Revision No.O Saved: 14-Apr-03 13. Proposed Drilling Program .....................................................................................5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7 15. Attachments ............... ........ ................. ...................... .................. .......... ........... ........ 7 Attachment 1 Property Plat and Directional Plan .................................................................................. 7 Attachment 2 Kuukpik Rig #5 BOP and choke manifold drawings........................................................ 7 Attachment 3 Drilling Hazards........................................................... .................. ................ 7 Attachment 4 Kuukpik Rig #5 Mud System and M-I Drilling Fluids Mud Products and LCM pills.......... 7 Attachment 3 A-10 and Proposed A-10a Well Schematics ...................................................................7 1. Well Name Requirements of 20 AAC 25.005 (f) Erxh well must be identifìed by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 25.040(b). For a well wIth multiple well branches, each branch must simIlarly be identifìed by a unique name and API number by adding a suffìx to the name designated for the well by the operator and to the number assigned to the well by the commission The well for which this application is submitted will be designated as NGU A-lOa. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on fìle with the commission and /dentifìed in the application: (2) a plat identifYing the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the we/I at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the wel/ at the top of each objective formation and at total depth; Location at Surface NGS Coordinates Northings: 2,586,670 11304' FNL, 1023' FWL, Eastings: 332,041 I See 6, T11N, R9W, SM RKB Elevation I RKB to Casing Head 116' MSL 43' Location at Top of Productive Interval (Top Cook Inlet Sands) NGS Coordinates Northings: 2,588,237 Eastings: 333,438 283' FSL, 2397' FWL, See 31, T12N, R9W, SM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 4451' 3673' 3557' Location at Total Depth I 2794' FSL, 550' FEL, NGS Coordinates Northings: 2,590,714 Eastings: 335,807 See 31, T12N, R9W, SM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 9433' 7266' 7150' and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must ORIGI1VAL A-10a PERMIT IT P4.DOC Page 2 of 7 Printed: 14-Apr-03 · _pplication for Permit to Drill, Well A-10a ., Revision No.O Saved: 14-Apr-03 (1) include a plat, drawn to a sUItable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and Property Plat and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. ConocoPhillips Alaska is a 100% owner of the North Cook Inlet Unit and the proposed A-lOa is more than 3000' from any property lines of the North Cook Inlet Unit. The proposed A-lOa replacement well is in compliance with Conservation Order No. 40, 6/8/67, and Conservation Order No. 68, 1217/68 regarding well spacing in the North Cook Inlet Unit and a spacing exemption is not required. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An applIcation for a Permit to Drill must be accompanied by each of the following Items, except for an item already on file wIth the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as requIred by 20 MC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please see Attachment #2: BOP and choke manifold schematics for Kuukpik Rig #5. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following Items, except for an Item already on file with the commission and identified in the application: (4) information on dnlling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; Historical pressure data indicates all intervals to be drilled by the proposed A-lOa will be normal pressure or depleted. The maximum potential surface pressure (MPSP) while drilling A-lOa is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the proposed total depth of 7266' tvd: MPSP =(7266 ft)*(0.433 - 0.11 psi/ft) = 2347 psi (B) data on potential gas zones,' Potential gas pay intervals will be encountered by the proposed A-lOa well bore from 4451' MD/3673' TVD (top of Cook Inlet Sands) all the way to TD which is the base of the Beluga sands. and (C) data concerning potential causes of hole problems such as abnom18lly geo-pressured strata, lost circulation zones, and zones that have a propensity for differential f>ticking; Please see Attachment 3 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a PermIt to Drill must be accompanied by each of tile fo/Jowing Items, except for an item already on file with the commission and identified Ji¡ the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 MC 25. 030(f); ORIGIJVAL A-10a PERMIT IT P4.DOC Page 3 of 7 Printed: 14-Apr-03 . .PPlication for Permit to Drill, Well A-10a Revision No.O Saved: 14-Apr-03 For the proposed A-lOa, the planned formation integrity test below the whipstock kick-off point will be a test to 1.0 ppg over the highest anticipated mud weight used to drill the well which is 9.6 ppg. Therefore the test will be to 10.6 ppg EMW at the 2000' sidetrack point. (see step 6 in the procedure) 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An applìcation for a Permìt to Drìll must be accompanìed by each of the followìng ìtems, except for an item already on file wìth the commlssìon and Identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25.034 and a description of any slotted liner, pre- perforated linel; or screen to be Installed; Casing and Cementing Program Hole Top Btm CsgfTbg Size Weight Length MD/TVD MD/TVD 00 (in) (in) (Ibltt) Grade Connection (tt) (tt) (tt) Cement Program 30" 323 43 366 / 366 Driven 16" 22" 65 H-40 BTC 588' 43'/43' 631'/631' 610 sx Class G (existing) 10-3/4" 15" 40.5 J-55 BTC 1957' 43'/43' 2000'/1918' 737 sx Class G & Prop KOP (existing) 45.5 7-5/8" 9-1/2" 29.7 L-80 BTC 7633' 1800/1737' 9433'/7266' 718 sx Class G Prop Liner (proposed) Estimated cement volume = 9433' -2000' window = 7433' of 9-1/2" x 7-5/8" hole x 1.2 washout = 7433' x .031 x 1.2 = 277 bbls 200' of 7-5/8" x 10-3/4" 45.5# liner lap = 200' x .0397 = 8 bbls 80' of 7-5/8" float track = 80' x .0459 = 4 bbls Total = 289 bbls of 12.4 ppg class G slurry, 3000 psi compressive strength, 2.26 cuft/sx = 718 sx 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following ìtems, except for an ìtem already on file with the commìssion and identified in the application: (7) a dìagram and descriptìon of the diverter system as required by 20 MC 25.035, unless thìs requìrement is waived by the commission under 20 MC 25.035(h)(2); Diverter not needed for sidetrack at 2000' MD/1918' 1VD 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Pem/it to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (8) a drìlling fluid program, including a diagram and description of the drilling fluId system, as required by 20 MC 25. 033; Drilling will be done using mud systems having the following properties: Production Hole mud properties Initia, 2000'1 8.8-9.2 20-30 Density (ppg) Yield Point (cP) Plastic Viscostiy (/b1100 sf) 10 minute Gel Strength (lbl1oo sf) API Filtrate(cc) Solids (%) 6000' 9.0-9.6 15-25 9433'TD 9.0-9.6 15-25 5-10 7-12 10-15 12 12 12 <10 5-6 <5 3 or less 5 or less 5 or less OR"G/AIAL ;'" . . It· . ~ 7 . ._~f > .--~ \: ,---~ r~ ,~·Ij.'~ c A-10a PERMIT IT P4.DOC Page 4 of 7 Printed: 14-Apr-03 · IMPplication for Permit to Drill, Well A-10a .. Revision No.O Saved: 14-Apr-03 See Attachment 4- Diagram of Kuukpik Rig #5 Mud System M-I Drilling Fluids proposed mud products and LCM pills Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f)/ N/A - Application is not for an exploratory or stratigraphic test well. All zones to be penetrated by the proposed A-lOa well will be normally pressured or depleted. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 MC 25.061(a},· N/ A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Dnll must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 MC 25.061(b)/ N/A - Application is for a sidetrack from 2000' MD. 12. Evidence of Bonding Requirements of 20 MC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 MC 25.025 {Bonding}have been met,· Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An applIcatIon for a Permit to Drill must be accompanied by each of the following Items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. ~ -, <..."'? K' ~ ~-i..,~ S~"'\i13. 4. 1. MIRU Kuukpik #5 on the Tyonek platform. 2. Install and test BOPE to 3000 psi. (Note: 5,000 psi BOP equipment will be rigged up on A-lOa but the tubinghead is only rated to 3000 psi so the max test pressure is requested to be only 3000 psi. The maximum anticipated surface pressure is only 2347 psi as noted above in Section 4 so a 3000 psi test is appropriate.) Cut and pull 4-1/2" tbg from 2100'. (Note: tbg plug was tagged at 4771' on 10/9/02 to abandon perfs in A-l0.) Observe that 7" casing and 7" x 10-3/4" annulus is stable. ND BOPs and ND tubing head. Tack weld slips to 7" casing. NU BOPE to casing head. Test BOPE to 3000 psi. (Note: 5,000 psi BOP ORIG/¡VAL A-10a PERMIT IT P4.DOC Page 5 of 7 Printed: 14-Apr-03 ... ...PPlication for Permit to Drill, Well A-10a _ Revision No.O ~.. \ r\t \ \, \\ r;:. \_' L '" Save~ 14-Apr-03 -"'r bç-~~ t> \J '-. 'T '\ ~" at \'-\lLf\ ~ ~\ ~\'''"\s''' <..t. Do..f'è}~~~' \ equipment will bé rigged up on A-lOa but the casinghead is only rated to 3000 psi so the max test pressure is requested to be only 3000 psi. The maximum anticipated surface pressure is only 2347 psi as noted above in Section 4 so a 3000 psi test is appropriate.) 5. RIH with hydraulic casing cutter on drill pipe. Cut 7" casing at 2050'. Circulate up 7" x 10-3/4" annulus via casing cut. POOH with casing cutter. 6. Spear 7" casing, pull and lay down 2050' of 7" casing. 7. RIH with 9-1/2" tri-mill clean out assy to 2050'. Circ hole clean, POOH with mill assy. - 8. RU E-line, set 10-3/4" 45.5# bridge plug at 2000' (KOP). POOH and RD E-line. 9. Pressure test 10-3/4" casing to 1500 psi. 10. RIH with whipstock/mill assy. Orient and set whipstock at 2000'. Mill 9-1/2" window and 20' of ~ new hole while changing hole to 9.0 ppg mud. 11. Perform formation integrity test to 10.6 ppg EMW. POOH with mills. 12. RIH with 9-1/2" bit, drill 9-1/2" hole to proposed TD of 9433' MD/7266' lVD with triple combo LWD logging tools on drill string (Density/Neutron/Resistivity/Gamma Ray). 13. RU E-line, run FMI/Dipole Sonic log over selected intervals from TD to 4451' MD. 14. Run MDT sampler logging tool on drill pipe. Obtain formation samples and pressures at selected intervals from TD to 4451' MD. RD E-line. 15. Make wiper trip with 9-1/2" bit. POOH. 16. Run and cement 7-5/8" 29.7#, L-80 BTC liner from 9433' to 200' above window at 1800'. Mix and pump 12.6 ppg Class G cement up to liner top (718 sx). Set hanger after plug bumps. Release liner running tool. PU and slack-off to weight set ZXP liner top packer. POOH with drill pipe. 17. PU cleanout assy and clean out to landing collar at appx 9350'. Change over well from mud to filtered 3% KCL brine. 18. RU E-line, perf lower intervals (below gravel pack intervals) as per log analysis. Approximate perfs are 8630'-8635' and 8657' - 8672'. RD E-line. 19. RIH with sump packer assy on drill pipe. Correlate packer on depth at 7680' with E-line. POOH with E-line. Set sump packer at 7680'. POOH with drill pipe. 20. RIH with 5-1/8" TCP guns with plug in bottom of guns. Tag sump packer setting plug in sump packer at 7680'. PU and fire guns hydraulically at 5950'-7668' depending on log analysis. Circ and monitor losses. Pump pill if necessary. POOH with spent guns. 21. RIH with bailer and remove perf debris and retrieve plug in sump packer at 7680'. POOH with bailer. 22. Clean out perfs with 7-5/8" mill assy. Pickle casing, POOH with cleanout assy. 23. RIH with lower gravel pack assembly including 4" screen, 2-7/8" and 1.9" concentric inner strings. Stab into sump packer. Set upper packer at 5820'. Pump two-stage gravel pack. POOH with inner strings and drill pipe. 24. RIH with 5-1/8" TCP guns with plug in bottom of guns. Tag sump packer setting plug in sump packer at 5820'. RUN E-line depth correlation log in drill pipe above top shot. POOH with E-line. PU guns as needed to place shots on depth. Fire guns hydraulically at 4452'-5804' depending on log analysis. Circ and monitor losses. Pump pill if necessary. POOH with spent guns. 25. RIH with bailer and remove perf debris and retrieve plug in sump packer at 5820'. POOH with bailer. 26. Clean out perfs with 7-5/8" mill assy. Pickle casing, POOH with cleanout assy. 27. RIH with upper gravel pack assembly including 4" screen, 2-7/8" and 1.9" concentric inner strings. Stab into sump packer at 5820'. Set upper packer at 4400'. Pump three-stage gravel pack. POOH with inner strings and drill pipe. 28. Run 5-1/2" x 4-1/2' tubing, GLMs, and SSSV. Stab into top packer at 4400'. 29. ND BOPE, NU and test tree. 30. Pressure up to break knock-out isolation valve below top packer at 4400'. 31. Release well to production and move rig from A-lOa to B-3. ~ 'W'? ~.~. ~~' f See Attachment #5- A-l0 and Proposed A-lOa wellbore schematics ORIG/¡VAL A-10a PERMIT IT P4.DOC Page 6 of 7 Printed: 14-Apr-03 - .PPlication for Permit to Drill, Well A-10a Revision No.O Saved: 15-Apr-03 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanIed by each of the following item~ except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drIlling mud and cuttings and a statement of whether the operator intends to request authorizatIon under 20 MC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of down a permitted disposal well, A- 12. Waste fluids include wash water collected via deck drains, cement clean-up, other non-hazardous waste fluids associated with the drilling of A-lOa. During the drilling/workover operations on the Tyonek platform, a monthly injection report will be submitted to AOGCC for the A-12 well. All cuttings will be checked for compliance and then discharged overboard as per an approved NPDES permit. 15. Attachments Attachment 1 Property Plat and Directional Plan Attachment 2 Kuukpik Rig #5 BOP and choke manifold drawings Attachment 3 Drilling Hazards Summary Attachment 4 Kuukpik Rig #5 Mud System and M-I Drilling Fluids Mud Products and LCM pills Attachment 5 A-10 and Proposed A-10a Well Schematics. ORIG/¡VAL A-10a PERMIT IT P4.DOC Page 7 of 7 Printed: 15-Apr-03 tJ ,.,.... Well Name: NCIU A-10a Surface Location: 1304' FNL, 1023' FWL, 8ec. 6, T11N, H9W, 8M Target C.I. A: 283' FSL, 2397' FWL, 8ec.31, T12N, H9W, SM TO Location: 2794' FSL, 550' FEL, Sec. 31, T12N, H9W, 8M 36 NC.' 'i\ I !)J!~~!;: «. rKê,~)(; C~1,. ~\ta,ge~//" "'" ... . """". ,loQäíión// __~ .~1?~.~'.~2¡N/' R9W i '_.' '" , '"-.- ,:' -,' Î ,,( ,1 . ,~,: T 11 N '" :;"Rlò'-W.. \1'\11 l/Nl.. R 9 W--_c";' ,\0' ''''~_ "<~J//>/' .~ . ",."..,.' iit!';, Surface //// '~\ \::;:location . ".' '\ : / ./ / \ 1, l / \'j'.>..,J,' 6-.,c",.,_,. ~,."I'-/ , / \\f " ,/ ,x\ ,/'\\ G\ \ "12 ! \ / I ! ,. / /'C~i',;,:/'i,'·"-'·" .) ,} ¡</ ~ // ¡ I 1..$1 ~5 / / -----i¡i '-~o1trml1\Jlf [---- Scale: 1" = 1& mile , . . ~. ConocoPhiUips Alaska, Inc. BOLT,iH. 50 DONKE~, D. 50 11-30+09 - ' 25 North Cook Inlet ··Unit ... ADL390099 ,\ PPCO 100 HBP ------' Ii""."'.. ;.V'-.../-, rê""",} . I \.,.. ""'0, I I I- / / , .:;, r~ .. L:31170 ADL037831,,¡ I I /2 I t31906 .----.----'"._---".--,._---'~'--'- ADL018740 03040803AOO o Y2 IN C MILES PPCO 100 HBP i 30 29 , , PPCO 1do HBPI ',<!(;:-: f\"'-',~ , , i NCI A-1QA BHL LociÎtion - ", 5 " '''~ I .\, \1\r\€- . NG l\--í>~ " \ II\. . C'?O~ PPCO 100 HBP I I , 11 ./'\ ./ 7\ 8 \ I----~ I \ \, . I I I L31907 I ADL018741! --4t_~"__-__.~"-,-,--~"'-:---,-,-,.,."-.N___.""___'''_._,._""+--. ConocriP'hillips A-10A Proposed Well Profile - Geodetic Report SChlldllipuer Report Date: April 11 , 2003 ~ ,,,'" I DLS ,_"...... Minimum Curvature I Lubinski Client: ConocoPhillips Vertical Section Azimuth: 42.130· Field: North Cook Inlet Unit S dY.. Vertical Section Origin: N 0.000 ft, E 0.000 ft structure J Slot: ~~~~ekl A-10 (slot 6 leg 2) - b -llty U TVD Reference Datum: KB Well: TVD Reference Elevation: 116.0 ft relative to MSL Borehole: A-10A Feasl I Sea Bed J Ground level Elevation: 116.000 ft relative to MSL UWlIAPI#: 508832003001 Magnetic Declination: 20.631· e Survey Name J Date: A-10A (P4) / April 11, 2003 Total Field Strength: 55571.696 nT Tort J AHD J DDI J ERD ratio: 97.783· I 5558.57 ft /5.849 I 0.76~ Magnetic Dip: 73.822· Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Declination Date: June 15, 2003 Location Lat/Long: N 61.07661001, W 150.94851992 Magnetic Declination Model: BGGM 2002 Location Grid NIE YIX: N 2586670.210 ftUS, E 332040.920 ftUS North Reference: True North Grid Convergence Angle: -0.83022617· Total Corr Mag North -> True North: +20.631· Grid Scale Factor: 0.99993210 Local Coordinates Referenced To: Well Head '-.) Grid Coordinates Geographic Coordinates ~ ~ID MD I Incl I Azim I TVO TVDss VSec I NJ-S EI-W DLS Northing Easting Latitude I longitude (ft) (.) (.) (ft) (ft) (ft) (ft) (ft) (·'10Off) (ftUS) (ftUS) ~ -' ie-in Survey 1993.00 27.50 32.00 1912.34 1796.34 419.00 361 .40 225.07 0.00 2587028.29 332271.19 N 61.07759854 W150.94724900 ::::'''íOp Whipstock 2000.00 27.67 32.00 1918.54 1802.54 422.19 364.14 226.79 2.41 2587031.00 332272.95 N 61.07760603 W 150.94723929 "",...::sase Whipstock 2020.00 29.27 35.20 1936.13 1820.13 431.62 372.08 232.07 11.06 2587038.86 332278.34 N 61.07762775 W 150.94720948 ~'~.~;J<OP Crv 6/100 2050.00 29.27 35.20 1962.30 1846.30 446.18 384.07 240.52 0.00 2587050.73 332286.96 N 61.07766054 W150.94716176 .-- 2100.00 29.93 41.13 2005.78 1889.78 470.79 403.45 255.78 6.00 2587069.88 332302.50 N 61.07771355 W 150.94707559 2200.00 31.97 52.11 2091.61 1975.61 521.85 438.53 293.11 6.00 2587104.42 332340.33 N 61.07780950 W 150.94686479 2300.00 34.85 61.69 2175.13 2059.13 574.90 468.37 339.21 6.00 2587133.58 332386.86 N 61.07789112 W 150.94660446 e End Crv 2350.00 36.55 65.93 2215.74 2099.74 601.99 481.22 365.39 6.00 2587146.05 332413.22 N 61.07792627 W 150.94645663 Crv 6/100 2450.00 36.55 65.93 2296.08 2180.08 656.47 505.50 419.76 0.00 2587169.54 332467.93 N 61.07799268 W150.94614960 2500.00 37.73 61.37 2335.94 2219.94 684.54 518.91 446.78 6.00 2587182.56 332495.14 N 61.07802935 W 150.94599702 2600.00 40.58 53.00 2413.53 2297.53 745.43 553.18 499.66 6.00 2587216.05 332548.51 N 61.07812309 W150.94569841 2700.00 43.97 45.63 2487.56 2371.56 812.08 597.07 550.50 6.00 2587259.20 332599.97 N 61.07824313 W150.94541131 End Crv 2792.38 47.47 39.62 2552.08 2436.08 878.15 645.75 595.16 6.00 2587307.22 332645.33 N 61.07837628 W 150.94515910 C.!. A Sand I Crv 2/100 4450.54 47.47 39.62 3673.00 3557.00 2098.86 1586.98 1374.33 0.00 2588237.00 333438.00 N 61.08095063 W 150.94075855 4500.00 48.20 38.72 3706.20 3590.20 2135.48 1615.40 1397.48 2.00 2588265.08 333461.56 N 61.08102835 W 150.94062780 End Crv 4584.49 49.47 37.24 3761.82 3645.82 2198.91 1665.54 1436.62 2.00 2588314.64 333501.42 N 61.08116549 W 150.94040672 Beluga A Sand I Crv 5801.99 49.47 37.24 4553.00 4437.00 3120.93 2402.24 1996.63 0.00 2589043.10 334072.01 N 61.08318034 W150.93724339 5900.00 47.84 38.69 4617.74 4501.74 3194.31 2460.25 2041.88 2.00 2589100.45 334118.09 N 61.08333900 W 150.93698777 Schlumberger Private A-10A (P4) report.xls Page 1 of 2 4/11/2003-4:32 PM Grid Coordinates Geographic Coordinates Station ID MD Incl I Azim I TVD TVDss I VSec I N/-S E/-W DLS Northing Eastíng Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (0/100lt) (ftUS) (ftUS) 6000.00 46.20 40.25 4685.92 4569.92 3267.38 2516.73 2088.37 2.00 2589156.24 334165.39 N 61.08349346 W 150.93672515 6100.00 44.57 41.89 4756.15 4640.15 3338.54 2570.40 2135.12 2.00 2589209.23 334212.91 N 61.08364024 W 150.93646106 6200.00 42.98 43.63 4828.36 4712.36 3407.72 2621.20 2182.08 2.00 2589259.34 334260.60 N 61.08377917 W 150.93619578 6300.00 41.41 45.48 4902.45 4786.45 3474.81 2669.06 2229.19 2.00 2589306.51 334308.39 N 61.08391006 W 150.93592966 End Crv 6325.37 41.02 45.97 4921.53 4805.53 3491.50 2680.73 2241.15 2.00 2589318.00 334320.52 N 61.08394197 W 150.93586209 Beluga Q Sand 7954.84 41.02 45.97 6151.00 6035.00 4558.48 3424.00 3010.00 0.00 2590050.00 335100.00 N 61.08597455 W150.93151860 TO 9432.60 41.02 45.97 7266.00 7150.00 5526.12 4098.07 3707.26 0.00 2590713.85 335806.91 N 61.08781777 W150.92757906 Legal Description: e Northing ey) rftUS] Eastin" eX) [ftUS] Surface: 1304 FNL 1023 FWL S6 T11 N R9W SM 2586670.21 332040.92 <::) :J::J -- c;":) ~"".. ~:' ,,-.- e A-10A (P4) report.xls Schlumberger Private Page 2 of 2 4/11/2003-4:32 PM VERTICAL SECTION VIEW ConocoPhillips A~10A (P4) Well: Field: North Cook Inlet Unit Structure: Tyonek Section At: 42.13 deg Date: April 11, 2003 o ---. ...... ::::J () $! (j) 2000 - 0 :E 0 () 0 > N 0 II ..Q c: tI:I Hold ¡¡::: ..- 0 ~o ..c: <Ó 4553 ND ...... Hold Angle Q. ..- () ..- 0 ~ i:I1 (ü ~ (.) ~ t () 61511VD ~ e::: > () ~ 6000 :::¡ LU '- I- TO 9433 MO 7266 TVD 41.02~ 45.97" az 5526 departure -2000 o 4000 6000 Vertical Section Departure at42.13 deg from (0.0,0.0). (1 in = 2000 feet) PLAN VIEW Client: Well: ConocoPhillips A-lOA ^ ^ ^ :r: I- a::: o z :r: I- :J o 1000 C/) V V V -1000 ¡Iii Field: North Cook Inlet Unit Structure: Tyonek Scale: Date: 1 in = 1000 ft ll-Apr-2003 o ! 1000 , 2000 I True North Mag Dee ( E 20 63° 5000 TD 9433 MD 7266 TVO 41<02~ 45.97" az 4098 N 3707 E 4000 - 2000 o o 1000 «< WEST 2000 3000 4000 - , 13.400 c:::> ::0 Kill Line Inlet 3" 5,000 PSI ..........;...,.~"...."" " .. r-- cc ) 1,. 13 5/8" Annular 45" L-J . D= =Q 13 5/8" Double Gate 34" . Choke Line Outlet 3" 5,000 PSI Mud Cross 20" 13 5/8" Single Gate 18" 13 5/8" 5,000 PSI Shaffer BOP Stack Kuukpik Drilling Rig 5 , e 9.800 ... e e - To Shaker 3" Panic To Gasbuster æ 8) 18)1 18)1 8) 8) 8) -,8)1 , 8) Pressure senso$ 8)CÐ 18)1 8)1 8) 18)¡- , D , Manual Choke Automatic Choke Inlet 3" 5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 OR ;f...~.1 A , ¡ .~' .... 'I . t \..1 ¡ þ~,. Upper Building With Solids Equipment .', /' \ '" L faccu~'DiQasser ---"'---11· __n~~~~~1 B~-;----·-L ! () o~~~+ ¿) ;;' ~~--r=;==·-Y:J-~il.,_-,_,---------,---_.J c:'L__~t.~_utt~~s_~-.---..,J r' L .--l-__~__'_ . , I '. ........ ~. 2 Derrick 2000 Shakers 1:;;;::;Ef~±~~ With possem bellies above screens C). .:::t'J ~""''':>... Flow Line ~41!.- """"'-~ o '--~-'--r- 0 0 i þ<J I Þ<I ~!--I _[:><1__.._..,.._.L__.!><1_,=._..R'U Suction Tank '''''--''-'''-.,.. " ~ ;i-- Volume Tank ~I Shaker Tank ¡--T---·--·_-·n_-___n :o~ c __I¡ll_________n___~_, Mud Tanks With Suction Lines Gun Lines in Tanks Trip Tank Pump Trip Tank 30 BBLS Shaker Tank . I Shaker Tank 160 BBLS ---- From Mud Gun Pump To Mud Pumps To Hopper/Guns Rig 5 Mud System with/ Solids Equip/Flow/ Volumes Revised 12/18/02 Mud Tanks With Tank Compartments and Agitators Volume Tank Suction Tank . I Degasser Tank Centrifuge Tank 70 BBLS 130 BBLS Volume Tank 80 BBLS ~ i Suction Tank 80 BBLS --,._,._-~---- _.~_..--_._---- 520 BBLS Active Volume 30 BBLS Trip Tank 30 BBLS Pill Tank Suction Tank Agitators r Pill Tank 30 BBLS e Green = Mud Flow Ditch Blue = Mud Flow w/ risers e Shaker Tank Mud Tanks With Mud Flow e - Attachment #3 NCIU A-lOa Drillinc, Hazards Summartl 9-1/2" Hole / 7-5/8" Casina Interval Event Coal stability, stuck pipe Risk Level Low Solids Build-up due to poor hole cleaning Moderate Depleted Reservoir Pressure High Differential Sticking Moderate Lost Circulation Moderate Mitigation Strategy Reduce stuck pipe risk with proper drilling practices including rotating through coals. Penetrating at relatively low hole angle of 48 degree will help keep coals stable. Maintain mud weight and increase rheology. Coal stability is a larger risk with deeper coals in the lower Tyonek which the proposed A-lOa will not be penetrating. The large 9-1/2" hole size and relatively small 4- 1/2" drill pipe will result in a low annulus velocity with potential for solids build up. Rotary steerable assembly and periodic sweeps and short trips will prevent significant solids build up from becoming a problem. Some zones will be depleted. This will increase risk for differential sticking and lost circulation as discussed in the next two events. Do not leave pipe static for extended period of time. Rotary steerable drilling assembly will reduce the risk for differential sticking due to constant rotation, no sliding. Reduced pump rates, Mud rheology, LCM. See mud section for LCM pill formulas that will be available on the rig. A-10a Drilling Hazards Summary. doc prepared by Tim Billingsley 4/10/2003 O R ~ r:. ~ fI' 'A L . ... ... ¡ \J ¡ rVH~ Page 1 of 1 41 i!E: - IIIII! 37 '!i!f.T j~ g 31 -3:-. ~~ ~ 29:' :&i,; _ ~E..I~ ~:_"!E. ~ELL'PLETlON DIAGRAM ..._ II,I'~..I, I.::...~_ ..__~~::r 1,"'1:11 '1'.;' II 11.1 ~I"""h. 1".10 II·, I . '1\.1 1;¡...;--ii'~1I11II I,.:. 366 i~~~~:~:;~-~ :}i~~'~;:¡!:'~~:: ~~;;:;: :~~~;:j';,!~ I~;'''~'~:::::~~:_:; :,::~~~:~:;,-, .'f ;.~::~:: '·"~~:~·'_.~~i~j~~J~:Jt~~=.'_·:l ~ ....::::~16 (sqz) .",- ·11.,,~I!...:.li:.:~I.¡ï:I"; 'I.I.:..!~{,-:- __no - -- - . Otis ~SR· packer @ 4833' CMT retainer 0 4856'1017/02 Side Cook Inlet Sands 4890 - 4990 CI-1.0 5008 - 5088 CI~2.0 5111 - 5151 01.-3.0 5163 - 5193 CI.-3.1 B~. packer @ 5243 -, 5270 - 5280 CI-4.1 -. 5313 - 5318 CI-5.0 - . 5324 - 5327 01-6.0 5337 - 5343 CI-5.0 5352 - 5355 CI-6.1 5360 - 5365 CI~5, 1 5392 - 5417 CI-6.0 l!!l, .... 5482 - 5483 (sqz) "XD" 0000 24 c;:;;- lW u 5557 - 5558 (sqz) -=-'"' packer@ 5571 s..... ~ 5587 - 5602 01-8.0 "XD" _ 19 5608-5618 CI-8.1 packer @ 5637 packer @ 5737 .. 5744 - 5756 CI-10.0 .. 5800-5810 CI-11,0 .. 5814 - 5615 (sqz) packer @ 5846 . DV collar @ 5&21' Beluga Sands m :>.. 5912-5913 (sqz) F1SH @ 6008' .. 5933 - 5937 a-7 leaking .. 5942 - 5944 a-7 ~ 5949 ~ 5959 a-7 "XA" 0000 .. 6055 - 6088 b..3, b-4, & b-5 6129 - 6139 b-6 6158-6163 b-7 6181 - 6186 b-8 6210 - 6225 c-0.5 6228 - 6234 c-1 .. 6272 ~ 6275 e-2.5 6424 - 6430 d-2 6462 - 6477 d-3 2!!:... 6508 - 6548 d-4 & d-5 PBTD 6619' EZSV 06619" .. .-- " 'I I .--';1'1 I 0.·... "-';'.' r " J,.. 1$- l'< 1 J ",' I.' ." I '. . , , \..1 Ii ot: ¡ ¿_ 6694-6716 e-8 6755 - 6765 f-1.1 6919 - 6926 g-1 7030 - 7050 h-1 7085 - 7090 h-3 7224 - 7234 h-9 7294 . 7296 i-3,1 7329 . 7339 i-7 7361 - 7366 i-8 7463 - 7466 k-1 7541 - 7547 k-4.1 7628·7668 m-1,m-2,m-3,m-4 . * 7762 - 7765 m-11 .. 44 0.00 38.90 Elevation 43 38.90 0.66 FMCIOCT6"3M 41I2"Bfdx41fl'BT&C TublnQHèII1!!1r 3.958 6.000 42 39.56 23953 4 ¡nø 12.61b/ft J-55 ModBT&C Tubin~ 3.958 5.563 41 2:79.09 2A6 otis4112" SCSSVLandin~N:ippk· -pullSSSV9/12102 3.813 5.566 40 281.55 29.21 411r 12.61b1ft J-55 ModBT&C Tubin~ 3.958 5563 3. 310.76 0.75 X-OVer 41n"BT&Cto4I!2"ModEUE8rd 3.953 4.919 38 311.51 4471.96 4112" 12.6JbJft 1~55 Mod EVE 8rd Tubing 3.958 5.563 37 4783.47 1M HaUiburton "X" Landing Nipple 3.813 4.998 36 4784.91 35.Q3 4 In" 12.61blft J-55 Mod EVE 8ni Tubing 3.958 5.563 3S 4819.94 12.26 Halliburton Tubing Seal Divider 3.958 5.969 34 4832.20 1.12: Otis Ratcl1·Latch Seal Unit 3.955 5.627 33 483332 6A8 Otis "VSR" Hydraulic Set Retrievable: Packer 3.880 5.982 32 4839.80 33.07 41/2" 12.61b1ft 1-55 Mod EUE 8rd Tubîn~ 3.958 5563 31 4872.87 1M HaDiburton "X" Landing Nipple: 3.813 4.998 30 487431 333.50 4 112" 12.61b/ft 1·55 Mod EUE 8re1 Tubing 3.958 5.563 2. 5207.81 4.22 Halliburton 4 In" "XO" Sliding Sle:eve: 3.813 5.475 28 5212.Q3 30.12 41n" 12.61b1ft 1·55 ModEUE 8rd Tubing 3.958 5563 27 5242.15 1.12 Halliburton "No-Go" Seal Unit 3.900 4.000 26 5243.27 11.24 Halliburton "A WR" Pc:nnanent Packer & Tbg. Adapter 3.880 5.982 25 525451 279.97 4 1/2" 12.61blft J-55 Mod EUE Srd Tubing 3.958 5563 24 5534.48 4.22 Halliburton 4 112" "XD" Sliding Sic:c:ve: 3.813 5.475 23 5538.70 31.26 4112" 12.61blft J-S5 Mod EUE 8ni Tubing 3.958 5563 22 5569.96 1.12 Halliburton "No-Oo" Seal Unit 3.900 4.000 21 5571.08 12.37 HaUiburton "A WR" Pc:nnanent Packet & Th¡t. Adapter 3.880 5.982 20 5583.45 38.46 4 112" 12.61bJft J-55 Mod EUE 8ni Tubing 3.958 5563 ... . . --.- 16 563651 11.30 HaUiburton "A WR" Pc:nnanent Paclcc:r & Tbg. Adapter 3.880 5.982 15 5647.81 77.26 4 Woo 12.61b/ft J-55 Mod EVE Srd Tubinl!: 3.958 5563 14 5725.07 4.22 Halliburton 4 lIzø "XO" Slidin¡t Sleeve: 3.813 5.475 13 5729.29 6.11 4 W" 12.61b1ft 1-55 Mod EUE Srd Tllbinl!: 3.958 5.563 12 5735.40 1.12 Halliburton "No-Oo" Seal Unit 3.900 4.000 11 573652 11.29 Halliburton "A WR" Pc:nnane:nt Packer & Tbg. Adapler 3.880 5.982 10 5747.81 61.90 411r 12.61b1ft J.55 ModEUE Srd Tubing 3.958 5.563 . 5809.71 4.22 Halliburton 4 tnM "XD" Sliding Sleeve 3.813 5.475 8 5813.93 30.95 4 tn~ 12.61blft J-55 Mod EUE Srd Tubing 3.958 5563 7 5844.88 1.12 HaIliburton ~No_Go" Seal Unit 3.900 4.000 5846.00 11.29 Halliburton "AWR" Pc:nnanent Paclcc:r & Tbg. Adapter 3.880 5.982 5857.29 151.35 4112" 12.6lblft J-55 Mod EUE Srd Tubing 3.958 5.563 6008.64 4.18 Halliburton 4 In" 'XA ~ Sliding Sle:eve: 3.813 5.475 6012.82 537.14 41/Z" 12.61blft J·55 ModEVE8rd Tubing 3.958 5.563 6549.96 l.50 Halliburton 4 In" "XN" Nipple 3.725 5563 6551.46 0.88 Rc:_EnttyGuide 3.99 5.56 655234 End of Tubing Notes - Well History May, 1970 - Original Completion in Beluga a~7 thru m-4. Beluga pressure monitor well July, 1975 - Added CI 14.1. 6.0 & 9.0 May,l994 Workover - Commingled CI 1.0 - 6.0, 8.0 -11.0, & Being. .-71hrn m-1I June, 1994 - Produc1ion Test 13 MMCFD & 62 BWPD. Well died Augus' 1994 Reperforateladd perforations in Beluga, Flow TeslBeluga 5933'-7765': 9.7 MMCFD & 25 BWPD (9500 CI) 255 psi FfP Reperforate/add perforations in Cook Inlet from 4890'-58101 September, 1994 ~ Set BP at 6691 t and abandon Beluga e-8 to m-l1 without testing. sand had cut tubing opposite perforations 7030'-7050' Belug. .-7 to d-5le8l4.8MMCFD & 3000 BWPD October, 1994 - Set PXplug inXD sleeve at 5534' (5514'WLM). Open CI 1-3 XD sleeve at 5207'. Well compleled in CI 1-3, tesl 14.7 MMCFD, FfP900 psi Note: Fish left on top of plug @ 6008': spang jars. knuckle joint., x~line setting tool May,1997 Top ofFill 5342' February. 1998 Well started making 2000 BWPO and died October, 1999 - Set Side Bore Separation Tool with plug on bottom in Sliding Sleeve at 5207' Well would not flow, pressure up with gas, still no flow January 13-15, 2000 - Found fill at 5116' RKB. ball drilling mud and sand from 5116'to 5147' RKB. SO for weekend January 18-20, 2000, Ball drilling mud and sand from 5103' SLM to 5120' SLM Nov. 26, 2001 FCC 5150'- 5212' NoY. 26, 2001 Tag silt@ 5161' - FCC 5150 ~ 5212'-post FCOtag @5158' Nov, 28, 2001 Set SCSSV Sept. 12, 2002· Pull SSSV & Tag fill @ 5150 WLM Oct. 5. 2002 Pull SBST Oct. 6, 2002 Pull PX plug; obstruction noted C 5578' Oct. 7, 2002 Open sleeves at 5534' & 5207', Set 4-112' cmt retainer at 4856'. Oct. 8, 2002 Pump 35 bbl of 15.8 ppg emt thru retainer and lay in 5 bbbl on top of retainer Oct g, 2002 Tag TOO @4771',Pressuretestcmtt02100psi,lost100psi¡n30min. good test ** Squeeze Perforations Original Completion (1970) * Peñorations Added during 1994 Workover .!.:I,..I,I. '11~, _ 0: 1111~~.-;':;'::'Î- , ___..i -. , . e _ 38 NCIU A-10a PROPOSED WELL COMPLETION DIAGRAM SSSY 36 32 \ ~ 30 ~ 28 7786' I I Y2 TD =9433' MD17266' TVD 366 BPV(MaIœ,Type,OD) Tbg.Hgr.(MaIœ,Type) AmmlusFluid: TOC, Cameron Type H FMC TC-lA SV2"BTCXS1l1:'BTC WATER DEPTII: 126' RKß'Drill Ded<, RKB-TIlF: 39Â' RKB.st: 11" RKß·ML , Produdion Casing: 631 30" 41 366 16" 41 631 103/4" 41 1.695 4O.5#/ft J-55 BT&C 3130 1580 629 7-S/S-line, kip at 1800' 103/4" 1695' 200Y KOP 45.5#fft J·55 BT&C 3580 1IJ9O 715 10 314' window 0 2000' ?5Jf>" 1800' 9433' 29.7Ib/ft Iroo BT&C 6890 4790 683 Tubing String: HiT 41 1,7SO 1551b/ft Iroo BTCMOO 4112" 1.750 4,362 12.6Ib/ft Iroo 18T Mod 8430 7500 288 15' PBR on top of pkr SC-1 R pia as.y 0 4362' with KOIV 4452'-4460' 451&'-4542' 4574'·4794' 4890'·4980' 5009'-5080' 5116-5142' 5166'-5186' 5272'·5276' SC-1L pia assy 0 5283' 5400'-5414' 5456'-5474' 5595'-5599' 5608'-5615' 5678'·5714' 5748'-5751' 5801'-5804' $-22B Snap latch SC-fR Pkrassy C 5811' 5950'-5956' 6129'·6137" 6159'-6164' 6182'·6186' 6212'-6232' 6425'-6430' 6462'-6475' 6510'-6516' 6527'-6536' 6695'-6714' 6756'·6765' SC-1L pkr assy G 6Tr.1 6919'·6923' 7038'-7046' 7086'·7090' SC-1L pkr assy 07093' 7331 '·7339' 7363'·7365' 7630'-7668' $-228 Snap latch Fe-1 Sump Pkr 0: 7673' 3-1/2- X nipple One jt of 4-1/2' Excluder screen ~ 8630'-8635' 865 7'·8672' 7·518" 0 9433' 39 0.00 38 38.90 37 39.90 36 400.00 35 405.00 34 1750.00 33 1756.00 32 3718.00 31 3720.00 30 3750.00 29 3756.00 28 4312.00 "n 4317.00 26 4347.00 25 4362.00 24 4389.20 23 4395.20 22 4441.20 21 5283.00 20 5308.70 19 5393.70 18 5810.00 17 5810.50 5837.70 16 5843.70 15 5939.70 14 '772.20 13 6797.90 12 6'XJ7.9O 11 7092.90 10 7118.60 9 7321.60 8 7673.10 7 "73.'0 6 7683.60 5 7713.60 4 7716.60 3 7746.60 2 7748.60 1 7785.60 7786.60 PRODUCTION TUBING STRING 38.90 Elevatim 1.00 FMC/11'x5-1/2'ttghgr, 51/2' BTOlop and btm 360.10 5 112" 15.5 Ib/ft. L-SO Mod BTC (Casing 'Thread) Tubing 5.00 Camco5-112~ TRM-4E TRSSSV 1345,00 5112" 15.5Ib/ft L·80 ModBTC(Casing 'Thread) Tubing 6,00 5-1(1:' x 1-112" CamcoMMG Gas Lift Mm<hel 1962.00 5112" 15.5lbllt L-SO ModBTC (Casing 'Thread) Tubing 2.00 5-112" BTC mod x 4-112" BTCmod xover 30.00 4 112" 12.6 fu/ft L-SO Mod mT Tubing 6.00 4-112" x 1" Caßl(X)KBMG Gas Lift Mandl:el 556.00 4 112" 12.61b/ft L-SO Mod mT Tubing 5.00 Baker 4-112" CMU sliding sieeve 30.00 4 112" 12.6Ib/ft. L-SO Mod mT Tubing 15.00 Baker 4-112"PBRIS-22Anchor Assy V.20 BåœI: SC-IRPa:::1œr Assembly 6.00 BaIœ[ 5" x 3-112" KOIV 46.00 4" 9.5#SLHI' blank tbg 841.80 4" Bakel:weJd screen. .012' gauge 25.70 Baker SC-ILMultízone pa:::ker asS)' 85.00 4" 9.5#SLIIT blank tbg 416.30 4" Bakel:weJd screen. .012' gauge 0.50 Baker S-22B map latch V.20 Baker SC-IRPa:::k.e[ Assembly 6.00 Baker 5" x 3-112" KOlV 96.00 4" 9.5#SLHI' blank tbg 832.50 4" Bakez:weld SC[een. .012' gauge 25.70 Baker SC-ILMultizone pa:::ker assy 110.00 4" 9.5#SLIIT blank tbg 185.00 4" Bakel::weld screen. .012' gauge 25.70 Baker SC-1LMultízone pa:::1œr assy 203.00 4" 9.5#SLHI'blanktbg 351.50 4" Bakel::weJd screen. .012' gauge 0,50 Baker S-22B map latch 10,00 BaIœ[ liB-I Sump packez: 30.00 3-112 9.3# buttress tbg. 1 jt 3.00 3-1n:' X nipple, 2,813" ID 30.00 3-1f29.3#butt:resstbg.1jt 2.00 3-112" buttress x 4" SIJITxover 37.00 4" SLHI' excluder SC[een, one jt. 1.00 Bull plug. 4" SUIT End of Tubing Updated by, BiIIi'W'l.y 3131/03 I PBID, 9242' Is""", ø~ ..' 'IJoo.'i. .~t.~ il}.. .··~..rl &o.ll2"12..6Ib/ft w.n. No"hCook1nletUnit .A 0 , fa' I ~ IPrcpœed Loca'ioo TyonekPlafionn.Cook I I \,,1 J l ;~, J.. Cook I""t Urn' 5.500 11.M 4.950 6.0SO 4.562 8.226 4.9SO 6.050 4.825 7.937 4.950 6.050 3.958 6.050 3.958 5.563 3.865 6.375 3.958 5.563 3.813 3,958 5.563 3.548 4.000 3.548 4.000 3.548 4.000 3.548 4.000 3.548 4.000 2.813 e e Interval Summary Tyonek Platform A-lOA 2000' - 9334' - MD 7266' TVD 7 5/8" Casing 9 1/2 " Hole -.---....----.-- -..------... -"-_.~.."- -.- ....----.--- Drilling Fluid System 3% KCI Flo Pro NT Key Products M-I Bar / Flo Vis / Soda Ash / Polypac UL/ DD/Nut Plug/SAPP Bicarb / Caustic Soda! KCL / Kia-guard / Solids Control Flow Line Cleaners / Desander / Desilter / Centrifuge Potential Problems Hole Cleaning / Tight Hole / Bit Balling / Hole Enlargement / Gas Kicks / Coal Sloughing Interval Drilling Fluid Properties ! Depth Mud Plastic Yield Gel API Total '" Interval Weight Viscosity Point Strength Fluid Loss DrilledSol- ids (ft) (ppg) (cp.) (lb./100ft2) (lb.l100ft2) (ml/30min) (%) 2000 8.8-9.2 5-10 20 - 30 12 < 10 3 or less 6000 9.0-9.6 7-12 15 - 25 12 5-6 5 or less 9000 9.0-9.6 10-15 15 - 25 12 <5 5 or less .J · Build spud system with 3% KCI and Flo Vis. Add Kla-Gard for solids encapsulation. · Utilize all solids control equipment. · Raise viscosity if gravel sections are encountered. · Pump sweeps if required. · Maintain adequate yP and 3 RPM reading for hole cleaning Lower fluid loss with Polypac UL and Dual Flo. Add 2 - 4 PPB of Soltex if running coal becomes a problem. · Add DD (drilling detergent) ,Nut Plug, and SAPP for possible bit balling. · Potential Problems: Running gravel, bit balling, shallow gas, and swelling clay · Lower fluid loss to below 10 cc's API by end of interval with Polypac additions. · Estimated volume usage -1650 barrels. Note: Mud Weights of 10.0 ppg may be required. M-I. L.L.c. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax ORIG/AIAL e e Interval Summary Tyonek Platform A-lOA 2000' - 9334' MD ~ I Drilling Fluid / OM Seal / SafeCarb Fine, Medium, Coarse / Versa- J HRP -.... ---. ...~._.._.. "-_... ..._-_...._-_._..~.__._- ._..~-. .....----.--.-... . ..--.-.... Lost Circulation Recommended LCM Pill Formulas Problems Key Products Lost Circulation Pill (Slight Losses) Volume Mix II SafeCarb SafeCarb Flo-Vis of Mud Fine Medium (barrels) (ppb) (ppb) (ppb) (ppb) 30 10 10 10 1/4 Lost Circulation Pill (Moderate Losses) I Volume Mix II SafeCarb SafeCarb Flo-Vis of Mud Medium Coarse (barrels) (ppb) (ppb) (ppb) (ppb) 40 15 15 10 1/2 II Lost Circulation Pill (Severe Losses) ~ Volume Mix II SafeCarb SafeCarb Flo- Vis 1 of Mud Medium Coarse (barrels) (ppb) (ppb) (ppb) (ppb) 50 15 20 30 1 ... . LCM should be added to mud system. Flo Vis should only be added if required. . Ifpossible, spot pill across thiefzone. Apply moderate pressure (50 - 100 psi) to squeeze pill into thief zone. M-I. L.L.c. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax ORIGl AL . .. :J I l·; ... COn()C~iUiPS . Post Office Box 100360 Anchorage, Alaska 99510-0360 Paul Mazzolini Phone (907) 263-4603 Fax: (907) 265-1535 Email: pmazzol@conocophillips.com April 15, 2003 RECEIVED APR ? 1 7G03 A\Mt<, 01 &. Gas Cons. Commission AAd1arage Alaska Oil and Gas Conservation Commission 333 West th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, NCIU Well #A-10a Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an offshore gas producing well, NCIU A- 10a, a development well on the Tyonek platform. The original A-10 wellbore became unuseable due to mechanical problems (collapsed tubing). After attempting to correct the mechanical problems, it was determined that the old A-10 well bore could not be economically repaired. The A-10 wellbore was suspended with a coiled tubing operation in October 2002 where cement was pumped through a retainer in the tubing at 4856' and more cement was placed on top of the retainer up to 4771' in preparation for this proposed sidetrack drilling operation. A 10-407 completion report was filed with AOGCC on1 0/24/02 describing the A-1 0 suspension. The proposed A-10a will be a sidetrack of A-10 at approximately 2000'. The proposed directional plan of A-10a will be a twin well to A-10 approximately 300' next to the old well bore. The purpose of A-10a will be to finish draining the Cook Inlet and Beluga sand gas reserves as a replacement well to A-10. The proposed A-10a depth will be s.lightly deeper stratigraphically than the original A-10 well bore to penetrate all of the Beluga sand intervals so some new zones may be encountered. But these new zones will not be abnormally pressured. The proposed A-10a replacement well is in compliance with Conservation Order No. 40, 6/8/67, and Conservation Order No. 68, 12/7/68 regarding well spacing in the North Cook Inlet Unit and a spacing exemption is not required. ConocoPhillips Alaska is a 100% owner of the North Cook Inlet Unit and the proposed A-10a is more than 3000' from any property lines of the North Cook Inlet Unit. The tubing head and casing head on A-10 upon which the BOPs will be installed are only rated to 3000 psi. Therefore, ConocoPhillips Alaska requests permission to test BOPs on A-10a to only 3000 psi, not 5000 psi. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). If you have any questions or require any further information, please contact Tim Billingsley at 265-6531 or myself at 263-4603. Sincerely, j)~ fl1~ Paul Mazzolini Cook Inlet Drilling Team Leader OR G\t~AL , ...... "" .. ~ _::» /--- N . c~ , : &~l.Q* ;?~/··l~ ?tx:-/ . . " ) STATE OF J1.lJ\S¡(,L"; DEPARTf'{1UH OF NATUH¡\L RESOURCES DIVISION OF OIL AND GAS Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 Re: The establishment of permanent rules for pool designation and well spacing in the North Cook Inlet Field. Conservation Order No. 68 December 7, 1968 IT þ,PPEARING THAT: 1. Conservation Order No. 40, dated June 3, 1967, prescribed a special rule for pool designation and a special rule for well spacing for a speci- fied area of the North Cook Inlet Field. 2. Conse¡'vation Oy'der No. 40 V1iJ.S mace pursuant to Section 2061.3 of the Alaska Oil and Gas Conservation Regulati~ns (1964) and continued in force until December 7, 1968. 3. There have beer. no wen conmletions in the NQj~th Cook Inlet Field while Conservation Order No. 40 has been in effect. 4. Notice of the consideration of the Oil and Gas Conservation Connnittee was published on November 7. 1968. in the Anchorage Daily News and there were no protests. AND IT FURTHER APPEARING nun the evi denee presented at the Dub li c hear; ng on Hay 15, 1967, is timely and tne!'e has been no ne\'1 evidence to material1y change the findings of Conservation Order No. 40. ¡~m!, THEREFORE, IT IS ORDERED that the area. affected by thi s order is described as follows: J O\~i~~h.ìB...J.~JiQ.r ttl-"_J3i11.Lg.e____?~J,ie s..!.L S . [,1. Section 33: t'.Ji~l4 Township 11 fJorttl, Ranqe 9 West, S.M~ S·ec rFj¡1--1:;:-~T;2-------- S~'J/4 T O\;JtlS h i iJ 1 ~~ :jor't:h, )(anc¡e 10 lies t, S.)\'1. -----·--·-~---S;?cHõî~-~~5-:-·--s-ËÏ~r------- -; e e < \ . CONSERVATION ORDER NO. 68 " Page 2 . Depember 7, 1968 .~ .. ~;. ,': Township 11 North~~Rânge 10 West, S.M. Section,,2:E/2 Sect ipn; '11 : E/2 Township 12 North, Range 9 West, S.M. Section. 31 : All Section 32: All Township 11 North., Range 9 West, S.M. Section 5: All . Secti on 6: A11 Section 7: All Section· 18: N/2 Township 11 North; Range 10 West, S.M. Section 12: All Section 13: N/2 Township 12 North, Range 9 West, S.M. Section 21: W/2 Section 28: W/2 [' Township 12 North, Range 9 West, S.M. Section 19: SE/4 Section 20: NE/4, S/2 Section 29: All Section 30: All Township 12 North, Range 10 West, S.M. Section 25: SE/4 Section 36: All Township 11 North, Range 10 West, S.M. Section 1: All ..J! IT IS FURTHER ORDERED that the following special rules apply to the aforementioned area: Rule 1. Pool Designation - the pool affected by this order is called the Tertiary System Gas Pool. . Its vertical limits are defined as the interval which will correlate with !the interval 3,500 feet to 6,200, feet in the Pan American Petroleum Cor,poration,North Cook Inlet State 17589 well No.1. I Rule 2. Well Spacing - Ga,s wells may be drilled on a "Cluster" spacing pattern in accordance with the pattern shown in Exhibit "B" of the original application, which is made part of this order. This order is made pursua~tto Section 2009 of the Alaska Oil and Gas Regulations. <, ,. ',' e - . v v, CONSERVATION ORDER #68 Page 3' December 7, 1968 ,DONE at Anchorage, College, and Juneau, Alaska, and dated· December 7,1968 q,./(IØ~J~ .J ~~as R. t-'¡arsha 11, Jr., Ex:J;;t'i ve Secretary Alaska Oil and Gas Conservation Committee Concurrence: ~ JLmes A. Williams, Chairman A"aska Oil and Gas Conservation Committee ~/k Dale Wallington, Member. Alaska Oil and Gas Con ervation Committee .' 1'." /i"f / ~ r.l,,·,f ,;.~~.¡.'~fi.r ,.t:,,~"l. ? -ø-, ;..,/:tl·¡·1;r..,~;.,..,·('-· ·t}·'it '~".""'.¡;?.J 5~~~';'·"'7~<.~~.,,(t.....-~<,~t.r~·,\,' ~, ."..".t . i . Karl L. VonderAhe, Member Alaska Oil and Gas Conservation Committee ~7Ä~/-y ú), kd 5/u Harry W. Kugler, Member 7 Alaska Oil and Gas Conservation Committee ,'-' ... L ; . . CHAK-ADL 17593 CHAK- ADL 18~4:..I ------ r 1 19 I 20, I I I , . e~ ·RIOW R9W ----. 14 18 13 ~ SAS-AOL 18759 23 24 26 PRODUCTIVE LIMIT ~........_--' 3 f-. 36 I 311 J I I I I J 1 14~ I ~ ..... 2 15~ 1 PERMANENT, PLATFORM ~ I I i ¡ *~II I . ¡, ~"A ,*9 2 f ~ -.---*' ~. I 12 ¥ .' 7 I c) - 13 ~-~----------~------~----~ CHAK-ADL 18740 ---.--- 23 CHAK-AOL /7589 24 19, I ! ¡ r') I e- 171 16 21 I i 1 -1-.. 29\ T -12 28 N *, SA AD' /8'55 321 I' SASIADL 17590 I - .--33" I I I I I ..----.... (\ U 41 I I i I I I j I ~ 8 9"' .------_.. I I I I 4-1 T ___J ~ . ~ II \ 171 '61N TERTIARY SYSTEM INITIAL PARTICIPATING AREA CHA)(-ADL /87411' 20 ___" ,.-___.-_0- 21 ----_.- ¡ I' ~r, .., ~ ~ IALAS· O.t:FSH_O".E. 18T66 ,~,_. AL-·[ /8,66-... _" ·SAS ADL 17583 CHAK-ADL /8752 II C L U S T E R II S PAC I N G P LAN FOR THE TERTIARY SYSTEM INITI A L PARTICIPATING AREA OF THE NORTH COOK INL ET UNIT EXHIBIT B o ¡/Z 1 MILE ~~~/'!!'~.mW~ e e PHILLIPS PETROLEUM COMPÁNV DENVER. COLORADO 80202 1230 SECURITY LIFE BUILDING EXPLORATION AND PRODUCTION DEPARTMENT WESTERN REGION August 2, 1967 Subject: Plan of Development and Operation North Cook Inlet Unit, Alaska Mr. Roscoe E. Bell, Director Division of Lands Department of Natural Resources 344 Sixth Avenue Anchorage, Alaska Dear Sir: In accordance with Section 10 of the Unit Agreement for the development and oper- ation of the North Cook Inlet Unit, Alaska, State of Alaska, Phillips Petroleum Company respectfully submits herewith the plan of further development and operation for your consideration and approval. During the last half of 1967 and the first quarter of 1968, an offshore drilling and producing platform. will be built and transported to Alaska for. use at the North Cook Inlet Unit. During the second and third quarters of 1968, the platfoI'.!l1. will be erected and rigged up for drilling. It is planned to locate the platform. in the approximate center of the ~:ff,'¡/4 Section 6, Tl1N, R9W. Drilling to develop the Tertiary System initial participating area will commence when the platform is rigged up. The pattern for the locations of the development wells will be that approved under Alaska Oil and Gas Conservation Committee Conservation Order No. 40. A copy of this Order is attached for your reference. Rule 2 of the Order provides that gas wells may be drilled on a cluster spacing pattern in accordance with the patt~rnshown on Exhibit "B" of the application. A copy of Emibit "B" is attached for your reference. The number of wells to be drilled in the cluster will be that required to supp¡Y the gas market. The cluster shows fifteen wells. Fewer wells may be required. A number has been added to Emibit liB" adjacent to each well. This number indicates the sequence of drilling for the wells. It is requested that the sequence shown be considered tentative at this time. It is expected that the drilling of fifteen wells, if that number is required, will occupy the fourth quarter of 1968 and all of 1969. Your approval of the herein plan of development covering the period through 1969 is respectfully requested. Very truly yours, PHILLIPS PETROLEUM COMPANY H. W. Patterson Unit Representative CNL:rc II~.&. _ _\._ __.&. # . c..' ,:,~_. '~:'-'.'.:": , r..,.,.,:): .,I~j .1 '. · .' · ! 1. .- ~i t .... .t. . .¡ . -: ." , .r . · . ¡ . ~ ;'>:.:' .. . . ! I · . j ! i .. · i ¡ . , : . i ¡ ~ · i ! . i · .' · : · ! t ".' , ~ ." e .-----e . :ï-- . .,.. . .(1 ....___.:;.0 ----- .._- ..--.... .-. , ):): _:!-'C.1 fJ4d.:J o..;¡; c:.,,"_ .- . . " . 'p,". '. , . . . . . ".. ,- '. . " . . -' . ~.. .¡ . '... '.. : '. ..' ."- . ," ". '-.. . .. ,'............ -:--' . .. .' ST.ATE OF ALAS~. DEPA..~TI·2~IT 07 NATúl;'~ RESOi,JRCES . DIVISION' 0:::' HI:iES þ.:7I) HU¡=:?,.ALS ~~SKA OIL ~ID GAS CO~SZ1~:~TION CO}~TTZE - ~.. ". ." "." . . .. . . . . '. '. , '. "..;. -. .' . '. - .. 3001 Porcu~ine D=ive .Anchor~~e~ A!~s~a . . . . ,'" .. ., ; .- '. . . .-:. .. .' .. .. .. .' U: THE APPLICATION 0:' Tffi: P.j~{ A!·2::'!CA~~ } PETROLEŒ:l COR?OlATIO~ for a te~?ora=) spacing ) order allo~Ting "cluste=" s~ê.cing Ü1 the ~:o=th ) Cook Inlet "Field ~.:hich i:l~Jolves c::,.:c·~?t:!.Or:5 -to ) S~tion 2061.2 of tr.~~~aska Oil and Gas Co~- ) servat!on Regu1ations~ Title l~~ &~c 1 Conservation Order :40 June 8~ 1967 . . .. . IT APPEA..IUNG THAT: :. ~.- . .. .'. . 1. The Pan A~erica~ Petrole~ Co=?orê.tio~~ a~~licant in the above entitled ~atter~ on beh~lf of itself~ Philli~s Pet=oleu~ Co~a~~~ Sinclair Oil & Gas CO=JGny a~è Skelly Oil CO~EI,,":1Y sub=itted arequS$t receIve;: April 27, 1967, fer a tt~luster" spacing order covering ê.:1 areG desi~:1ate¿ as t~c TertiGry Syste~ Initial Partici- patinz; Area. of the !~orth Coo!~ Inlet Unit in the ~{orth Cook Inlet Field. 2. Notice of the åearir.g 1;o1as pü¡'li5h~d Ò:l Z.!~y 3, 1967, in the }....""1.chorage Ddly ~e·.d. 3. A hearing was held in th~ City Council Cha=~ers 0= the Z. J. Loussac Library~ Anchorage, Alaska,at 9 :39 a.n., o~ :.t3.y 15 ~ 19ó 7. 4. Test1cony in su~~ort of the a~o1i~ation was given by Pan },~erican ~etrolau= Corporation's duly ~;thcrize¿ re?~~sentatives and there were r~ objections fro~ af~ected ?arties. - A..~ IT FURTEER A??E:ARIXG that: e:<:ce;,tions to Se=.tion 2061.2 of the Ale.s:<:n Oil and Gas Cons~rvatio~ Regulations should oe" gr~nted in a¿¿ition to tåose allo~,e¿ by uniti- za.tion because ope-cating con¿itio~3 necessitatinz; directional drilli:1S from a platfortil in waters of Upper Cook.Inlet '~ould 6~~e the drilling of wells'on a re3ular s?ac~g plan unduly hazardous and eh7cnsiv~. AND IT F~.T~~ AP?zARr~iG that g~olo~ical ~~d reservoir conditions a=esuch that the : . affected area will be adequately ¿r~i~ed by a cluster patter~ of ~ells directio:1- · . ally drilled frOQ a sbgle platfo~ as ir.¿ic2.t~¿ on Zxhibit flBrr of the ~p1icatio:1. t . ~ - -if' '. . ., ~ ....:....... ~àl- . .. -. '0:>\ -~gJ .j' -l:-.-.,a, .----- ·.'?ì .,:.~ ...-.. ._...,........ . .". .- I...· . to~;¡' ..~...- . '. : "... . . . -,;. . ". . . - '.-. .##. " . . - . . " . "~ - - .......; . ..- '. ~". - . . . - . .... .. .' ..... ..... . . " . ". CONSERVATIÔN ORDE~ fl.40 Page 2 J'une 8. 1967 . . . .. .,.... . :. ,'';; ". . .. -. .'. . ~ , . - *-. .- " ; t. ' ¡., . . . , " , . . . .' ..,.- ." ". ", ~~ . .. ..- .4"' t. - ~ ':.: : : ,,'.-" j . I ..., .. ~ f " '." '. - . . . , ...... . r ,. . I ; , Ð,'D IT FURTHER APPEA~rXG that the interv~l in the :?an A:nerican Petroleum Cor~oration State well :fil bet~'7~en the depths of 3500 feet and 6200 feet has been proved productive of ¡as and this interval co~?ris~s the prese~t1y unitized interval in the North Cook Inlet Initial Participating Area Tertiary Syst~. .' . , ~ . : , I , BOW, THEREFORE, IT IS ORDE~ED that the area a=fected .õy this order is described as follows~ . . , .. ¡- - ~ovmshi!> 12 ~ro~ t11 t ~~~2\:! I) ~...:!s t, , Section 33: :fí·! /4 ~ . , ; .. .1ownship 11 North, ?.2~~e 9 ~lest . . " Section 8: :.¡}"2 Stof/ 4 ~Ow"TIS:tiD 12 z.~or!:~. ~an\!e 10 ¡·rest Section:35: SE/4 1o~'mshi!, 11 ~orth, Ran~~ 10 t-rest Section 2: '2./2 Section 11: E/2 "o~'mshiD 12 ~orth, Rõ!.!1~e 9 Hest. Section 31: All Section 32: :All ,. ,. .. .. " · '. . :ro~..nshi~ 11 North. Ra~~~e 9 ¡'Tes t Section 5: All " Section 6: All · . . , : . - Section 7: All t -,. .. Section 18: N/2 . . -. Towns!! in 11 North, Ra:l~~ 10 ¡'Test . " Section 12: All Section 13: N/2 . Townsbi.., 12 North, R2n~e 9 ¡-Tes t Section 21: H/2 Section 23: '11/2 ;'! ~o~ros~i.T) 12 No~th, ~ati.~e 9 l!e s t. . , . . Sec:tbn 19: 5:'/4 ~ '. Section 20': NE/4, 5/2 t Sectio:l 29 : All '"..". , Section 30 : All . · .' . ""." ..... . ...-....',..'- . . ~~.".-~'.: '·'__a_ ~f - . ~- I. " . ----- .0;:): Wtt3XJ . -,-' -.----., . . _·---",-,~~..e ~¡-'- '.>.': . .~.J_x'J . - I...do.; l~~ ~ .. . . .. ,- " -. - . .. . :...--' .. . ..... .. ...... " ...,-. . ., . .. .. ..' .. .' : -.. to::' , ~ .. - ..... .. ., ...... . . . . . - ... . '. ." - . ..' . . , CONSERVATION' raze 3 .June S. 1967 ORDER v40 .- " . '- i' ~'~ . ". . . .. . . : . .' < ' . .. c· -~ ,~ovmship 12 North, Rf!~~e 10 Hest , . _. 'Sectio!\ 25: SE/4 . Section 3ó: All .10wnship 11 ~¡ôrth. Ra:1!2:e 10 ¡-les t Section 1: All . . ... y ~,': . " ~. .. , - . ,. . .' .. .- ,., ... .. . ~ " '. .... . . ,- . . ,:.. .. . - 1" - The followi~g special rules ap?ly to th~ aforê==~tic~ed area: ~ULE 1 Fool Desi~~at!on - The pool ~~fecteà by t~~s order is called the Terti~=y System Gas Pool. Its vertic~l lisits a=e àefi~ed as the interval which will correlate with tbe' interval-'3500 feet to 6200 f~et in the ?an _~erican Petrolel.::l Corporatio:!. . ,- North Cook Inlet Stélte 17589 ...¡ell {fl. . f;. ;. ..,.. '" RULE 2 toTe!1 SDé!cin~ - Gas ...·ells "[:",.::.y b~ drilled on a "Cluster" spaci!'.g pattern i:t accordanc~ with'the pattern s:,o,:.;:1 0:1. E}~hibit t~3" of the application. '. . . this Order is ~~¿e pursuant to S~ct~on 2061.3 of the Alaska Oil and Gas Conserva~ion ~esulations and sh~ll contincc in force fo~ a period of not more than eighteen (13) ~nths provided, however, that wells w~icè have been årilled anG co~pleted an¿ are being p~odu~ed in co~liance ~ith the provisicns 0= t~is Order, or any other Order of the Co=nittce, cay óe pro::!uc~d i:t cO::ï;?lia:-.ce uit!1 the tet'::!.s 0= said Orde=not,::ith- standing the fact that such Cr¿~r p.~y h.i·.re e:;-;? ired or have been te~i!'.ated, or that ~here gay oe pending a request th.::.:: s~id O=de:: b~ r::adified or tert;1inated, u:-.til such ~tme as the Co~ittee s~all~ a~::ern~tice .::.n¿ h~~ri~g, enter an Order esta~lishi~3 different rules, esta~lis~~ents, or ?rovisio~$. The Co~üittee on its o,ro ~otion, or at the request of any interested party, ~ay àt any tL~e during the te=?ora=y pe=icd set this ~atter for further he~=ing for the pU::?OSC of dete~ining vhet~er the present Order should be ~~n¿e1 or ~odified. ThcCo==ittce will, in the a~sence .of a re~uest of an interested party for a èe~rin8 ~t an earlier ¿ate, set this ;:¡atter fo:: hea=i~z for a da.te which shall be not later than 30 daj's p:-::or to thed~te of the e:9it:'ation of this O:-de:-, for the ~)Urpose of de::er::li.ninz the p:=oper spacing ànd. ~~eld rules which should then be ~?plicable to this field. ' '. I, ,. . . 0. . . .~ . . . . . . ... .' . .:i.(,:~;~ \:;-~___.. · .(AoSC:O>. ! 'P~~} . .!'; ,'. . ~"~'~_.~- i .' r.\:~~i i ~ J '. · ,:, ~: ~ ;: j .. ... '..~.¡.: ...... .~.. - :', "':;-. ;' ~ " ..., · J :.~·1 .::.:.:..:~~..~. ., I·' ..... :..= <1- ..', !....\. '!' . ~ ': .. ¡ , . t··:}· ':,:' :.'. L ..' !. i.:I·: ..··~·f:..·~·... ! .'. I . : ..' . . ..... .. . .' . ..., -e'., ., ,. .-..._~.. .'. ,,---...--- . '.. cio:): . ". . .... . .~~jJ . ----... .._.___i....:-__ ;, ---:.-:.-__.._--.:.._ .:)1 .. . '.:' . :. -;;:!!J . .... 't" ~-~ ." to".: ., '. - . (:'-~~I- O~3": .. ...,.....,... ~ ':. ,"': '. . .:: .. '. ... ~..<.:. .: -. ,,.:: . .....::~...........-." .=. ~ ...: ." : :.~'~: ¿.:~_.:".~::._.~ ':..~";l';~':"'." . .. - .. ~ .' .... .. ... ;'.f"·:.~;.:. .'_": ":. ':'~" ,. ,. . ~ ..:" .... ,', .... .. :;"'~~": -; .'~'" ,; ........:. '. .' , . O"lDGR.!J40 CO~SERVATIO~ .P~ge 4 . < : June . S~ -.1.9.67 ., .' " . ........ . - ~i;~~·;:-,::::~.;:~.·.~:·;"·"'- ....- - .".,,: .:.- ':J>-::. ..' , ~.. - ,'. . ,'"..." ..... "...". ...... ':.." :~. .. ..'0 ,,-'.:~~.~~ .." .". ".. · " .".; ·:__~t.' .... ~·.·\~o;f:.:.~~~ ,.' . ..... ~3JJ . . .~. ..:..... ~... . .- '.' '. -..' .... " -.. .... ..... . " .. ... '-.. : . ..:. ..- -.. '. . . '.. ~... . .......... ." -".:.:' ~. . ~ .... .. . "..: ~ f .-,,;.' . ...."'.. - . -' . ' ~::~. ..~!. :. .'. .- .' .-. .. . . ;'.. . -.... - . . .' .. . . .'. ........... . ... ..... .~ . . - . '. ... . ..~' :,.- : . -:. ... . .. .;. . . ..,.J:'. 1967>' '. . - '. , . DONE a~~nchoraze a~¿ Juneau~ Alaska~ and ..:. . .- . .:'.. ........ ...- -....;... ..: i --. J. '. . .~ ..:'.¡'. :~.., .. t '.:'. -:.. .... ..' ~:..: · . i .. '.. .. ~ -'j .' .' .'-' ~... ..' .. ~ " \0/ :""-:::~:..:.: .:~ ~... }.j~:~~'''.:... . .... ~ . -' .. .... . .-.... '. -' '.4· '.. ....= :..>. .. .! :i· ;:. I· j i ~. .~, ; .f!. i ¡ .' .. ........ '. . . :.:"':~;. . · .. '" .. ,..;.....- . . ... .' · . 'f .t' '. " · ~ - .' ., .~ . !. - . . . . tl . , . .: .i '.1' . .., .' t · · ~ ~ ;: ! :. ~ ..~~-:~ 'to .- · . .... .. . ':" -.- . ... ; .....;: "." :....: .. ...1 '..-:' ;,:: . . .' . . · ....- . , . :........... .' . . .. .. -... '.' · '. - . ... ~ ...... .c: . .. .. .~ r ..' . ; .' ..., -.. .~ ;:4J :\~ . : i - r . ! -: . . .. . . . .~. , '. - '. · ...... ! :. ... ~ .. .. ..... . - ~ .. . " . ..' .~. .' · . .. '.-:" . . .: ,,' . '. '" ; t ;. .. ,.. '-: . . ~ ··h ..... ...,. ~ . .' . · . '. .... -. ,,,, ... . .. "; . - ¡"", ~ ... '. ".. . . :t .. .~; .....:., . " .- ... .. . . .' ., .. .. . ' ...!...-..oo , . ..... · · . .'. .:. .. ...' . .... ..~ . ..... .:.' " . .... · . ; ...~~-: ,.... '. .- .1 .....¡,.. ,,:: .... .... -' . . .~.... ~. · '. ~ '. .' · .. . .. . ,., " :.. I . da.:ê¿ JU:lè S ~ ......~: ð{.JUt~ ~ . . . .... ...," ~. .... ." - .-. ~ :....... . .' -.a.'___... _.. ,. Ad(,,' O~3 "- . ., .. ---_-.:. .... ..... ...... f..tl~.J . .. ............ ... O~:JX¡' ......>::.: ,:'..-:-: :.~: :~.;.. ,'-: ~,! .~~: .. _.w....~... ~ .... ...., .. . .~ ... . ..~~. .. . . "'~ - .' .- :...:".. :.. ~ " -:' .' . ..:' '-.-" '. ... :. .~.~~?:: .~.~...~ .;:~.. -:, q .... ~: ;.:~ :;:'--. :.... :~...::. .-. . ....-: ":.. ...... . . :." ...~~~~. ...::. .- ,-!-·"_~··.·i·:":.,, . '. ..... ......!. '.'~.' tJ:~).:;'L; '. .. ~..'.. . , . . ::. .,. ' :'<:.<::~;~;~<.:\:'".'... ..' -:'- Tho~~s ~. X~~shall~ Jr. Executiv~ Sec::etary Al~sk~ Oil ~~¿ Gas Cor.se=vatio~ Co~ittee . . ".: ~'vv.;~~:<t~ ~ ~~u.:,~~~ P. /jé.:h~s ,G.. ¡:illi-c1=:s) Chain:an ~SkS G~l aod Gas eoose"Vstion eo~~ttee "'ÆÆ>¿~?J:í~~ D"'e r.TA1' i-".to- '·"~~be"" //. Wo_ ..c..___.......;I 4.., ..J,,;;.õ.1.* .-v Al~ska oii ~n¿ G3S Cons~rvation Co~ittee '.. .. .- ... ...... -. Concu¡-::e:l':c: .- . .' : " . . . . ., .' ~ . ..- .. '- .' · .. '7:.; .... . - .. .-.'f ':-/1/2 t~---~- . I<.nrl 1'.. V;::.~dc=l~he) He:nber ." Alaska Oil and Gas Conservatio~·Co~ittae .. .. '. ..: : ·~_·-··6 .' ..... . . . . ~. . . ,,~ .. '. . - . . .~...' "... ", '" .. ~:::~.~::~.,.. : ":::.. ~. '.~ '·t~~.; ..;._ ~ :: .. '. .. . . , . ... .'. - . .... --: . .: <~~.~:j~._~~~; ;...:~'" ...:. '. ......::..; . i" ~. ~ . - - ..,- '. '::- ...~ -~:;.- .; . '.. . c. .. ..: ~'~';'-,.~.. .... '. . . :-.:: ~ .. ',-. .::'. '::"-:. .. oo' -.' '. . . . .. . . .. . . . -.' .. .: ~"~.'. .. ." :....:: '. '..-= " .:. .~ . . . .. -'. ...: .-...... -. , . .:. ~.. '. ,," -~. .... ...-. .... .. '. . ',- ,,'.:.' , .' ~ .... , . - ..~ -- :~ '. '-.:., .' ..... .' -::-. :'':~....' -' ~ .. ~~ ';-..' . ...;: - ." ~ .... ..:~.. . ...... ., ;: "~ - -~. .".:.. ,," . '. ." '.~ '." !' '. ':.. ; -.' ~.., - ..' '. .' '" -.. .. ..... _ r -' '. 1r.. '. '. .' ... -. . ",-.:-.-.-- -_... --~- -- ....... ..... .' '... . . .~. -.. . . '- .- ... . ..: .' .. . . . . '. .. . -'.- . . .' .. .... .. .: ~:;~.. · .- :-.;:~ . : ¡.. . .... '.' ., "..... . ., .. .. . . .'. - .. ." . . ......:. . .' - ',. ." ':..' · . .... '.. .. . . '. ." .,,; '.' .. .' .- ; -- : ..,. .... .. , .', · '. .~..:.. .' i .. .. . i: ...; ~ ',. .... ".111: ~ .: . ;.. · . ; :': r · r··· F 'f.~. .' ~ .' f' .. .. . , · · · ,. · : ! i t, .- · ! r' . ' · t' · · . · , · . - . · ". · !..' · .'. ~: , ! . : .. - .: for .~ " ~ f " C¡'¡Ag';'IJOl.17:;!J~. CHAK- AD:" 137491 . ¡!) r/OL~,",~~~'~~~~-~~~ ~ ; . I . . ,...__......__............~ ...... .... .. ~ t. r . I u . PRODUCTIVE: ~ !. 1 - .! I. tJ4ïT. __u::o__.....!) ( ì 26 _ J,¡j ~25~ 50\ 29' I .... ~L . : ~ '. ~~ I ¡ . . !:"v----;..,~j .1 *' I D . ! . . , -r . ,. . i .. II! . I ; !I V· I .~ Aæmø 35r----~... . ~6 ¡.¡; ;;'2 ~ ~ . . I.. ; j ro., II,,) ~ PERMÞ.N::NT --!~,- .... -1'. PLATF?R.M ~~/. I"~)~" f~' ",' ¡.J '., . . , I" . ~ç / ' I~ . ;.1.:.I·A .,!.Io.' ~ ,j~..! "'\ ll' t tü ~,.. "i' " "I ~~ ........... .... 1 ' ':";"'. ..,_.._.,.__', \. ___..__. I .....,... ..... _ _ __ .: ..... II 121 ....... ...-: . , 'f ~ ~·I I " I ~ . '. ~ ~ L ~ L...._.:.._...,~.-...._---_..._._·: ....... .. ,. --;Ä....""'''''.... i7r ..;... ¡i¡ . "'â .13j~. I. ,.18~ ~>. 17. I¡.N r Ii . I~ '\:-,,T£r? T/ARY SYST£ltl¡ . ~" '. . .... '.. ~ ,~NITIAL' PA;-?TICIPATING . ~~----~----~~~~~~~~~~~~~~~. 1 . · (> I AREA .' ! i I· I I I ~\ ;0 tJ ! !~ SAS-If'!)!. 10759 23 ~, 1 , i ì .. , . I. ¡ i I ¡ ¡ j ¡ . I I ! i I I i ! ! I ,I i ¡ 1 I ¡ ¡ , ¡ i ¡ .- . ¡' I, I I I ! ! Î I '.. I·· . . . I' t ¡ ; , CNAI{-AO!. 18740 2::" SAS AD!. '175C3 e- .'- . . 141 ¡ RZï.:'] . ,IOf -'17 Ii' ¡' , I~ .' 'E::J 2.4 21 .. . - ¡ , · · ~ T . -12 . '2a N ~ ;. · " a · · ~ .ft W ~ · SAS,AOL 17590 .¡.~ 33 .. · · · . of' , ·i~·"----'" n ! I; ¡ ~ J-:,. J "'I: i~ ~ 0' ft ~ ',:..... ~...., '. 'R . " '~ . ... ar . '\ ~:'~:' xS" 4 ., \, . . ", ," "t. ' . ~ '. > "':- ~~ :'::. . '. ::..4',. i ! I - . :. ~ ' , .. ~ 2 ~ ~ t-_...._-_·~ . ,", . :' :;;-, ~ ClIh::-.!JDL 175C~ . . I~ èU.l.2/t-/~:.O!../~?";'.t ~ .' ~c,; ! i . .21 '. . .... , C.,!/'I(-AOL I.'ll:;.?: . .. ArL. ADL 18755-':' ¡..1L.4S. OFFSf/O!U: 187531' : r:.~ '.:' r-:, ~ ï:} fi'? R .. .....'to. _~.... r. - UCLUSTERU SPACING PLAN FOR THE 'TERT1ARY S\'STEM 'INITIAL ?ÅRTIC1PAT~NG AREA OF T[-tl; NORTl-t COOK INL ET UNIT 0c-.,.._::-,,=.-::::.,..~l:, : :..¡...: '. '\;' . ,'. ." J . e e ~-_._._""'- S. K. ALLSUP-DRAKE 1035 PHILLIPS PETROLEUM COMPANY DAn At;! (I, ttV3 "'-141311 700G ST. ATO 1530 ... . ANCHORAGE AK 99501 PAVTOTHE §rl/T'6éFlI-urst:/l /J4CJEtCC I $ /00. Oõ "'",'0' L:D cl ~ ./ 0). ~ -- ~ It. t:-. /k-o ,/0 & ~ s.o...ilyF...",~. ~ DOLLARS I ~~.... ~ o CHASE Chas. Manhattan Bank USA. N.A. Valid Up To 5000 Dollars ' g . "'00 /1-/01/ Ncrm~.~_._.m"_~"""-Þ~_14L. ':0 j ~ ~OO ~.....: 2 ~BOOOO" 2 7 è 5 7"· ¡O j 5 ,- WELL PERMIT CHECKLIST COMPANY (!fJJftlt43liil.¡'J WELL NAME øðW /1--/00- PROGRAM: Exp _ D~v ~edrll ¿ Re-Enter _ Serv _ Wellbore seg_ FIELD & POOL 5c..'-/.c:; 70 INITCLASS Ì"\e-V / /- GAS GEOLAREA 820 UNIT# Ol/¥S'O ON/OFFSHoREQiÍC ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. . . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . dll . 7. Sufficient acreage available in drilling unit., , . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N 12. Permit can be issued without administrative approval.. . . , . N 13. Well located w/in area & strata authorized by injection order#--.dA ,,' N-'" 14. All wells wlin ~ mile area of review identified. . . . . . . . .. .All'( Y N 15. Conductor string provided. . . . . . . . . . . . . . . . . . . Y N 16. Surface casing protects all known USDWs. . . . . . . . . . .HI"! - y ~ 17. CMT vol adequate to circulate on conductor & surf csg. . . . . N 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . N 19. CMT will cover all known productive horizons. . . . . . . . . . N 20. Casing designs adequate for C, T, B & permafrost. . . . . . . N 21. Adequatetankageorreservepit................. N V\~c-,.~~c.....~I~~\'Y~,..~~\\\~,:~üc.,,\<è~c\:~~~"~\\'__J- ·11 22. If a re-drill, has a 10-403 for abandonment been approved. . . N ~c:::.d _ d ~ ~ ":""l(d~-~;}~o.\,c~",,~.. ~~ ~tOtU -\t\ ~.:"~~ ..~ 23. Adequate wellbore separation proposed.. . . . . . . . . . . . Y N ¡s;;.~ \'=> "\~ ~~ c\.~'<..,k<.," "..He \ \.. ",\~''-'':> ~x\\ ~\\ \ \o~ ~~ <::. ~~çc 24. If diverter required, does it meet regulations. . . . . . . . . . ~ ~ ~ \. "'- ~ 25. Drilling fluid program schematic & equip list adequate. . . .. NN ~~ Q.'Q ~<S~ \'1 ~\I~G.. '-"01.. ~ ~~ ~ ~. ~. "í(.~a{'\\"Ic') <\ \ ~ ~~ C'~. . . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . r"\. _ '" \. ~ 27. BOPE press rating appropriate; test to Y'ØO psig. Y NN \J'\Þ-.S'? <s:>.\r., \~ù d~""\~\., ~~Ç:,~\.~~~~ ~~1C)Ç¿~\r:~ 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . . - 1- 29. Work will occur without operation shutdown. . . . . . . . . . . Yy ~ 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . \tD (Service Well Only) 31. Mechanical condition of wells within AOR verified. . . . . . . . ~ ~'" GEOLOGY 32. Permit can be issued wlo hydrogen sulfide measures. . . . œ N . / ~ .ð /. / _ -'7 " 17 APPR DATE 33. Data presented on potential overpressure zones. . . . . . . . (j) N ~A'\.4..( err -71'tl....~ ~"'"'rC- ..J!..¥.¡:::'~ . h-. {.2Z.d334. Seismic anal~~is of shalla,:"" gas zones. . . . . . . . . . . .. 1,11* ~ 35. Seabed condition survey (If off-shore). . . . . . . . . . . . . . Jill N (Exploratory Only) 36. Contact namelphone for weekly progress reports. ...... Y N APPR DATE ~lZ2·07 /f2 (Service Well Only) (Service Well Only) ENGINEERING APPR DATE .~ ~~-o> ~kd ~ 1'1/:J.6jJ;. ¿Jd( ù ~..,/¿~- .:3,~-;-~..h. ¿~. 'ðd/'~ £.u(~~ "d«.~r~ -f"" ~r~7; ~~ ~u d ~ ...,..,.;...~..,.-.. ,Ld~. ~ ~<,,(4 ¿/~.-.,~ - .-..~~ ~r~ /1-/0/ I<,..)J(....~ i<J u.....u~~d"-C-~ cc//y~~~' A-/04 þ.Þ-)'/( ~ ~~~~~~:5 ~"ð"'- ~ 4-/ô ~ ~...¡I( ~(..I.A<..k ALw ......~O ~ ~v~. ) e \~O'\.~\¡"o..Cjt..\ ~\\ ~c..-~r;/f d e-~ISj.Þ:5 ~ "\ t--.. t:'."'\. ~ ~'\._ \ ~'t..\' -.. ~?'-() ~'-\o.~,> -\-0 ~~~ C:., \ \ ~~, ~~~~ .~~ ~'\""c.>~~ e GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: RPC_ TEM JDH JBR COT SFD~ DTS WGA MJW Rev: 07/12/02 G:\geology\permits\checklist.doC Comments/lnstructions: e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, infonnation of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ·' . .' /JO ,3 -0-1-6 Conoc~illips NCIU A-10A NORTH COOK INLET UNIT TYONEK PLATFORM KENAI, ALASKA August 2, 2003 - August 16, 2003 John Morris: Senior Logging Geologist Brian Q'Fallon: Senior Logging Geologist Barry Wright: Logging Geologist Charles Isbon: Logging Geologist Habib Mamman: Logging Geologist ~ E?OCH \\~~\\\-~ RECEIVED SEP 18 20Q3 Aia&ka o¡·¡ {{ Ga4 Con$. ÇQmntiMm Aod1or$ge . . . y ConocoPhillips:U A-10A TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT AND CREW............. ............... ............. ... ................ ........... ...2 1.1. EQUIPMENT SUMMARY .............................................................................................2 1.2. PERSONNEL.......... .............. ......................................................................... ........... ...2 2. GENERAL WELL DETAILS ..................................... .......................... ........ ..........................3 2.1. OBJ ECTIVES ............................................................................................................... 3 2.2. WELL RESUME.......... .......... ..... ......................................... ............... ... .......................3 2.3. HOLE DATA............................................... ....... ........................................................... 4 3. GEOLOGICAL DATA........................................................................................................... 5 3.1. LITHOLOGY AND REMARKS ........................... .................... .............. .... ........ .... ......... 5 3.2. SAMPLING PROGRAM AND DISTRIBUTION ...........................................................20 4. DRILLING DATA.................................................................... ............... ........ .................... .21 4.1. DAILY ACTIVITY SUMMARY .....................................................................................21 4.2. SURVEY RECORD................. ..... ... ......... ................................................................. .23 4.3. MUD RECORD.. ................ .............................................................................. ... ........ 30 4.4. BIT RECORD............ ................................................................................................. 31 4.5. DAYS VERSES DEPTH.................................. .............. ............................................. 32 DAILY REPORTS. ......... ............ ..... ...... ............. ....... ..... ...... ........... ...... .................... APPENDIX I FORMATION LOGS................................................................................................ APPENDIX II COMBO LOGS ................... ........ .............. .............................................................. APPENDIX III ~ EPOCH 1 C~illips NICU A-10A . 1 MUDLOGGING EQUIPMENT AND CREW 1.1. EQUIPMENT SUMMARY Parameter Equipment Type And Position Total Comments Downtime Electric QGM Degasser Mounted In Ditch Gas Possum Belly; FID Total Hydrocarbon 0 Analyzer And Chromatograph Rate of Penetration (ROP) Bristol-type hydraulic block height 0 Pump stroke counter Magnetic Proximity Sensor 0 Hookload I Weight on bit (WOB) Hydraulic Pressure Cell Mounted on 0 Drill String Drill string torque NA 0 Top drive rotary (RPM) NA 0 Standpipe Pressure NA 0 Casing Pressure NA 0 Mud flow in lout (MFII MFO) NA 0 Pit volumes NA 0 Driller's work station NA 0 Casing Pressure NA 0 . 1.2. PERSONNEL Unit Number: Mudloggers John Morris Barry Wright Brian O'Fallon ML032 Years 30 3 15 Days 15 7 8 Technician Pete Ramsey Days 2 Sample Catchers Charles Isbon Habib Mamman Days 14 15 . [=I EPOCH 2 . 2.1. OBJECTIVES y ConocoPhillips NICU A-10A 2. GENERAL WELL DETAILS The A-10A is a sidetrack ofthe original A-10 well, drilled August 22, 1969. 2.2. WELL RESUME Operator: Well Name: Field: County: State: Company Representatives: Location: Classification: . API#: Network #: Activity Code: Rig Name / Type: Elevation - Ground: -RKB: Primary Target: Primary Target Depth: Secondary Target: Secondary Target Depth: Milled Out: Total Depth: Total Depth Formation: Total Depth Date: . ConocoPhillips Alaska Inc. NCIU A-10A North Cook Inlet Kenai Alaska Mike Winfree / Granville Rizek / Donnie Lutrick Tyonek Platform, Cook Inlet, Alaska Lat: N61.07661, Long: W150.94852 Development 50-883-20030-01 10029463 K200 Kuukpik #5 / Offshore - Double Sea level 119' Sterling and Beluga Confidential 1910' 8840' Beluga 8/16/2003 [:J EPOCH 3 Cono~illips NICU A-10A . MWD Company: Tools Run: Schlumberger Anadrill Directional, Gamma Ray, Triple Combo Resistivity, Neutron Porosity, Neutron Density, Pressure While Drilling. Directional Drilling: Schlumberger Anadrill Drilling Fluids Company: Mi Drilling Fluids 2.3. HOLE DATA Hole Maximum Depth T.D. Mud Deviation Shoe Depth Section MD TVDSS Formation Weight rinc) Casing MD TVDSS F.I.T. (ppg) NA 1910' 1719' Sterling 8.7 25 10 3/4" 1910' 1719' Pass 9 1/2" 8840' 6763' Beluga 9.6 30.8 . . [1 EPOCH 4 . ¥ ConocoPhillips NICU A-10A 3. GEOLOGICAL DATA 3.1. LITHOLOGY AND REMARKS 1915 Sand = Clear, white, light to medium gray, black, dark. greenish gray; clasts range from very fine upper to medium lower; angular to subround; moderately well sorted; composed of 70% quartz and other siliceous minerals, 300k mafics and metamorphic lithics; no matrix visible; appears loose in samples. 1965 Tuffaceous claystone = Light to medium brownish gray; very soft to occasionally soft; appears as clay with common slightly finnlumps; dominantly pasty and runny, mod to very soluble; matte, earthy luster; smooth with common silty texture; non calc; common very fine sand grains embedded in lumps. 2020 Sand (2032'-2060')= Multicolored, appears med to dark. gray overall; white, clear, light to medium gray, common medium to dark. greenish gray, com reddish orange, black; clasts range from medium upper to very fine upper; moderately sorted in the fine to medium range; angular to rounded, dominantly subangular to subround; composed of 60% quartz and other siliceous minerals, 40% meta and igneous lithics; no matrix in samples; no acid reaction; estimate fair to good porosity and penneability. . 2115 Tuffaceous claystone = Pale yellowish brown to light brownish gray; very soft; appears as clay in samples; scattered small, slightly finnlumps; moderately to very water soluble; dull, earthy luster; smooth to slightly gritty texture; non calcareous; occasionally appears silty. 2160 Sand = Light medium gray to medium gray overall; clear, white, to gray siliceous grains with common reddish orange, black and greenish fragments; medium upper to very fine upper, rare coarse lower; moderately well to moderately sorted; subrounded to subangular, occasional angular; appears unconsolidated in sample; estimate good to fair porosity; generally a coarsening downward sequence through section; 60% quartz and other siliceous material, 40% volcanic and metamorphic fragments, trace ash; non to rare calcareous. 2245 Tuffaceous claystone = Light gray to medium light gray, some medium gray, occasional light brownish gray; very soft to soft, some slightly finn; massive to subtabular cuttings; dull to earthy luster; smooth to silty texture, occasionally grading to and interbedded with tuffaceous siltstone; slightly ashy matrix, rare thin laminations of tuff; common thin streaks of brownish black to black carbonaceous material; moderately to very hydrophilic; non to trace acid reaction. 2320 Sand = Light medium gray to medium gray overall; clear, white, to gray siliceous grains with common reddish orange, black and greenish fragments; medium upper to very fine upper, rare coarse lower; moderately well to moderately sorted; subangular to angular, occasional subrounded; appears unconsolidated in sample; estimate fair to good porosity; fair amount of flaky to slivered metal pieces in sample; 60% quartz and other siliceous material, 40% volcanic and metamorphic fragments, trace ash; non to rare calcareous. . 2405 [~ EPOCH 5 C~illips NICU A-10A . Tuffaceous claystone = Light gray to medium light gray, some medium gray, occasional light brownish gray; very soft to soft, some slightly finn; massive to subtabular cuttings; dull to earthy luster; smooth to silty texture, occasionally grading to and interbedded with tuffaceous siltstone; slightly ashy matrix, rare thin laminations of tuff; common thin streaks of brownish black to black carbonaceous material; moderately to very hydrophilic; non to trace calcareous. 2480 Sand/conglomeratic sand = Light gray to medium gray overall; clear, white, to gray siliceous grains with common reddish orange, black and greenish fragments; dominantly medium upper to very fine upper, common coarse and occasional very coarse; moderately sorted; mostly subangular to angular, some bit impacted subrounded pebbles; moderate sphericity; unconsolidated in sample with no apparent matrix or cementing; 50% quartz and 50% igneous, metamorphic, and carbonaceous fragments; no acid reaction. 2560 Tuffaceous claystone = Light gray to medium light gray, some medium gray, occasional light brownish gray; very soft to soft, some slightly finn; massive to subtabular cuttings; dull to earthy luster; smooth to silty texture, occasionally grading to and interbedded with tuffaceous siltstone; slightly ashy matrix, rare thin laminations of tuff; common thin streaks of brownish black to black carbonaceous material; moderately to very hydrophilic; non to trace calcareous. 2635 Sand/conglomeratic sand = Light gray to medium gray overall; clear, white, to gray siliceous grains with common reddish orange, black and greenish fragments; dominantly medium to very fine upper, common coarse and occasional very coarse; moderately sorted; mostly subangular to angular, some bit impacted subrounded grains; unconsolidated grains show no apparent cementing; 65- 75% quartz and 25-35% volcanic, metamorphic and carbonaceous fragments; no acid reaction. . 2710 Sand = Medium gray to medium light gray, with light olive gray secondary hues; dominantly clear, white, and gray grains, abundant green, yellowish green, and reddish orange grains; dominantly very fine upper to medium, with some coarse lower; noticeably smaller grains than above; moderately to moderately well sorted; subangular to angular; completely unconsolidated in sample; 70% quartz, 30% opaque lithic fragments; non to rare calcareous. 2780 Sand = Medium gray to medium light gray; mostly medium lower to coarse lower, some very fine upper; moderately well sorted; subangular to angular; unconsolidated in sample; estimate fair to good porosity and penneability; 70% clear, white, and gray siliceous fragments and 30% volcanic, metavolcanic, and carbonaceous pieces; non to rare calcareous. 2835 Sand = Medium gray to medium light gray, with light olive gray secondary hues; dominantly clear, white, and gray grains, abundant green, yellowish green, and reddish orange grains; dominantly very fine upper to medium, with some coarse lower; moderately to moderately well sorted; subangular to angular; completely unconsolidated in sample; 70% quartz, 30% opaque lithic fragments; non to trace calcareous. . 2900 Sand = Medium gray to medium light gray, with light olive gray secondary hues; dominantly clear, white, and gray grains, abundant green, yellowish green, and reddish orange grains; dominantly very fine upper to medium, with some coarse lower; moderately to moderately well sorted; subangular to angular; completely unconsolidated in sample; 70% quartz, 30% opaque lithic fragments; trace tuff; non to trace calcareous. MW 9.0 FV 44 PV 9 yP 25 GELS 10/12/15 [~ EPOCH 6 . y ConocoPhillips NICU A-10A FL 5.6 CK 1 SOL 6 SO .75 MBT 2 PH 9.0 PM .1 PFIMF .1/2.6 CL 14000 Ca 40 2985 Tuffaceous claystone = Pale yellowish brown to light brownish gray, occasionally very light gray; very soft; appears as clay in samples; runny to occasionally pasty, smooth to commonly gritty; dries to dull, earthy luster with scattered micro fine sparkles; smooth to silty appearing texture; non calcareous; moderately to very water soluble; scattered very fine grained volcanic glass shards; scattered ashy appearing streaks and blebs; scattered to common black. pinpoint specks. 3065 Sand = Multicolored; dominantly medium to dark gray with abundant white and clear, com light to med greenish gray, com pinkish orange, occasional black; clasts range from very fine upper to medium upper, trace coarse; dominantly fine to medium; moderately sorted in the fine to medium range; 50% quartz and other siliceous minerals, 50% meta and igneous lithics; traces to scattered mica flakes; traces to common carbonaceous matter; no visible matrix; no acid reaction. 3135 Tuffaceous claystone = Pale yellowish brown to light brownish gray, occasional very light gray; very soft to rarely slightly finn; dominantly runny to occasionally pasty, smooth to commonly gritty; dries to dull, earthy luster with scattered microfine sparkles; smooth to siUy appearing texture; non to occasionally slightly calcareous; scattered very fine grained volcanic glass shards; scattered woody material; occasionally very carbonaceous, grading to carbonaceous shale; increasingly indurated with depth. . 3215 Sand = Multicolored with overall light to medium color; common white, clear, light to medium gray, black, light to medium greenish gray, reddish orange and light to moderate brown; clasts range from very fine upper to coarse upper, dominantly fine to medium grain; angular to rounded, dominantly subangular to subround; moderately sorted in the fine to medium range; composed of 50% quartz and other light colored siliceous minerals, 50% greenish gray, black. and reddish orange metamorphic and volcanic lithics; scattered to occasional common mica; no matrix is present in the samples; no acid reaction. 3290 Tuffaceous claystone = Pale yellowish brown, light to medium brownish gray, moderate brown; very soft to rarely slightly finn; dominantly appears as clay, rarely as soft irregularly shaped cuttings; matte, earthy luster; smooth to occasionally very silty texture; non to occasionally slightly calcareous; locally silty, grading in part to very argillaceous siltstone; lighter colored fraction appears more "ashy"; darker fraction appears more carbonaceous; 3350 Sand/conglomerate = Light to med gray overall; dominantly white, clear, light to medium greenish gray, black, light to medium brownish gray, reddish orange and light to moderately brown; clasts range from very fine upper to granule fragments, dominantly fine to medium grain; angular to rounded, dominantly subangular to subround; mod sorted in the fine to medium range; composed of 50% quartz and other light colored siliceous minerals, 50% greenish gray, black and reddish orange metamorphic and volcanic lithics; scattered mica; trace amounts light gray ashy matrix. . 3420 Tuffaceous claystone = Pale yellowish brown, light to medium brownish gray, moderate brown; very soft to rarely slightly finn; com appears as clay, often as soft irregularly shaped cuttings; matte, earthy luster; smooth to occasionally very silty texture; non to occasionally slightly calcareous; locally silty, grading in part to very argillaceous siltstone; lighter colored fraction appears more "ashy"; darker fraction appears more carbonaceous; some cuttings with subblock.y parting showing increasing induraton. U EPOCH 7 . . . y ConocoPhillips NICU A-10A 3490 Sand = Light gray overall with continued multicolored grains as before; clasts range from very fine upper to coarse lower with trace amounts of granule fragments; increase in lithics to 60% with balance quartz or light colored siliceous minerals; traces to scattered mica; trace amounts of free ash fall tuff; continues unconsolidated in the samples. 3545 Carbonaceous shale = Black to dusky yellowish brown; finn to moderately hard; brittle; matte to slightly resinous luster; platy and blocky fracture; scattered to common thin coal laminations; scattered ashy appearing clay laminations. 3580 Tuffaceous claystone = Pale yellowish brown, light to medium brownish gray, moderate brown; very soft to rarely slightly finn; commonly appears as clay, often as soft irregularly shaped cuttings; matte, earthy luster; smooth to occasionally very silty texture; non to occasionally slightly calcareous; locally silty, grading in part to very argillaceous siltstone; lighter colored fraction appears more "ashy"; darker fraction appears more carbonaceous; some cuttings with subblocky parting showing increasing induraton. 3650 Sand = Light gray overall with continued multicolored grains as before; clasts range from very fine upper to coarse lower with trace amounts of granule fragments; increase in lithics to 60% with balance quartz or light colored siliceous minerals; traces to scattered mica; trace amounts of free ash fall tuff; continues unconsolidated in the samples. 3700 Tuffaceous claystone = Pale yellowish brown to light medium gray, some light gray; very soft to soft, with occasional slightly finn subblocky cuttings; mushy to pasty consistency; matte to earthy luster; smooth to occasionally very silty texture, with some interbedded strings of argillaceous siltstone; lighter colored sections appear more ashy; darker cuttings appear more carbonaceous; non to slightly calcareous. 3770 Carbonaceous shale = Brownish gray to brownish black; slightly finn to soft, common finn; subblocky to subplaty cuttings with some incipient fissitlity and parting along subplanar planes; dull to earthy luster; locally containing thin laminations of lignitic to subbituminous coal and tuffaceous claystone; non calcareous. 3820 Sand = Medium gray to medium light gray, with light olive gray secondary hues; dominantly clear, white, and gray grains, abundant green, yellowish green, and reddish orange grains; dominantly very fine upper to medium, with some coarse lower; moderately to moderately wefl sorted; subangufar to angular; completely unconsolidated in sample; 70% quartz, 30% opaque lithic fragments; trace tuff; non to trace calcareous. 3885 Coal = Brownish black to black; finn to slightly finn, some very finn; subblocky to subplaty cuttings with parting along planes; dominantly lignitic to subbituminous; common woody pieces and anhedral to subhedral pyrite crystals; often grading to and interbedded with carbonaceous shale; abundant gas bleeding from surfaces. 3935 Sand = Medium light gray to medium gray overall; dominantly very fine upper to medium lower, occasional medium upper to lower coarse; grains generally finer than above; moderately to moderately well sorted; subangular to subrounded; unconsolidated with no matrix visibfe; 60% ~ EPOCH 8 y ConocoPhillips NICU A-10A · clear, white and gray quartz, 40% multicolored opaque lithic fragments; trace tuff; non to rare calcareous. 3995 Sand = Medium gray to medium light gray overall; mostly medium lower to coarse lower, noticeably coarser than above; moderately to moderately well sorted; subangular to angular; mostly unconsolidated, some very friable cuttings; trace ash fall; 60% quartz, 40% lithic fragments; non to rare acid reaction. 4065 Tuffaceous claystone = Light gray to white, pale yellowish brown, light to medium brownish gray; very soft to occasional firm; amorphous to subblocky habit; mushy to crumbly, occasional slightly brittle; dominantly occurs as pasty clay lumps, occasionally as poorly to moderately indurated lumps or roughly formed cuttings; matte, earthy luster; smooth to gritty texture; slightly calcareous; ashy appearing fraction is lighter in color and mostly grayish; carbonaceous appearing fraction is darker in color and mostly brownish; common ashy blebs and carbonaceous specks and streaks; locally silty, grading in part to siltstone; locally very carbonaceous, grading to carbonaceous shale. 4165 Sand = Light to medium gray overall; dominantly light to medium gray, medium greenish gray, clear, white; com reddish orange, black, moderately brown; size ranges from very fine upper to coarse lower, traces of granule fragments; dominantly fine to medium grain; angular to rounded, dominantly subangular; moderate sorting in the fine to medium range; composed of 60% quartz and other light colored siliceous minerals, 40% meta lithics and volcanic lithics; traces to scattered mica; few grains with thin coating of ashy clay matrix material; no acid reaction. · 4230 Coal = Dusky brown to black; firm to moderately hard; brittle; hackly, blocky and tabular cuttings habit; matte to slight resinous luster; smooth to moderately rough surface texture; commonly very argillaceous, grading to carbonaceous shale; occasionally appears woody; scattered ashy appearing streaks. 4275 Tuffaceous claystone = Pale yellowish brown to light medium gray, some light gray; very soft to soft, with occasional slightly firm subblocky cuttings; mushy to pasty consistency; matte to earthy luster; smooth to occasionally very silty texture, with some interbedded strings of argillaceous siltstone; lighter colored sections appear more ashy; darker cuttings appear more carbonaceous; non to slightly calcareous. 4340 Coal = Dusky brown to black; firm to moderately hard; brittle; hackly, blocky and tabular cuttings habit; matte to slight resinous luster; smooth to moderately rough surface texture; commonly very argillaceous, grading to carbonaceous shale. 4375 Sand = Light gray overall with common salt and pepper appearance; clasts range from very fine lower to medium lower, dominantly very fine to fine grained; angular to subround; moderately sorted; composed of 70% quartz and other siliceous minerals, 30% metamorphic and volcanic lithics; argillaceous; silty; estimate poor to fair porosity and permeability. · 4425 Sand = Light to medium gray overall with slight salt and pepper appearance; dominantly clear, light to medium gray, white; common black, pinkish orange, light to medium greenish gray; clasts range from very fine upper to fine upper, rare grains in the medium range; subangular to round; welf sorted in the very fine to fine range; composed of 70% quartz and other light colored siliceous [=I EPOCH 9 . ../ ConocoPhillips NICU A-10A minerals, 30% volcanic and metamorphic lithics; totally disaggregated in the sample; very slight acid reaction; estimate fair to good porosity and penneability; appears "clean". 4500 Sand = Light to medium gray overall; dominantly light to medium gray, clear to white, light gray, common reddish orange, black, light yellow, moderately brown; size ranges from very fine upper to coarse lower, traces of granule fragments; dominantly fine to medium grain; angular to rounded, dominantly subangular; moderate sorting in the fine to medium range; lower section coarsens with scattered granule fragments and increase in coarse size grains; dominantly fine upper to coarse upper; composed of 600Æ> quartz and other light colored siliceous minerals, 40% meta lithics and volcanic lithics; scattered mica; few grains with thin coating of ashy clay matrix material; very slight acid reaction. 4590 Tuffaceous claystone = Light gray to white, pale yellowish brown, light to medium brownish gray; very soft to occasionally finn; lumpy to subtabular habit; mushy to crumbly, occasionally slightly brittle; dominantly occurs as pasty clay lumps, occasionally as poorly to moderately indurated lumps or roughly fonned cuttings; matte luster; smooth to gritty texture; slightly calcareous; ashy appearing part is lighter in color and mostly grayish; carbonaceous appearing part is darker in cotor and mostly brownish; common ashy blebs and carbonaceous specks and streaks; locally silty, grading in part to siltstone; locally very carbonaceous, grading to carbonaceous shale. 4685 Coal = Dusky yellowish brown, dusky reddish brown, black; finn to moderately hard; brittle; moderately tough; matte to slightly resinous luster; smooth to commonly rough surface texture; variable clay content, occasionally grades to carbonaceous shale; coals in general appear to be cleaner with depth. . 4730 Sand = Light gray overall with common salt and pepper appearance; clasts range from very fine lower to medium lower, dominantly very fine to fine grained; angular to subround; moderately sorted; composed of 70% quartz and other siliceous minerals, 30% metamorphic and volcanic lithics; argillaceous; silty; estimate poor to fair porosity and penneability. 4780 Coal = Dusky yellowish brown to brownish black to common black.; dominantly finn to moderately hard, some slightly finn; brittle; moderately tough; dull to slightly waxy luster; matte texture; subplaty to subtabular cuttings; common amber blebs; occasionally grading to carbonaceous shale; abundant gas bleeding from surfaces. 4830 Tuffaceous claystone = Pale yellowish brown to light medium gray, some light gray; very soft to soft, with occasional slightly finn subblock.y cuttings; mushy to pasty consistency; matte to earthy luster; smooth to occasionally very silty texture, with some interbedded argillaceous siltstone; non to slight calcareous. 4880 Sand = Medium gray to light medium gray overall; dominantly medium lower to medium upper, some very fine upper and coarse lower; scattered bit impacted granules with rounded edges; subangular to angular; moderately to moderately well sorted; 60% quartz, 40% multicolored lithic fragments; none to rare acid reaction. . 4930 Coal = Dusky yellowish brown to brownish black to common black; dominantly finn to moderately hard, some slightly finn; brittle; moderately tough; dull to slightly waxy luster; matte texture; subplaty to [=I EPOCH 10 ../ ConocoPhillips NICU A-10A . subtabular cuttings; common amber blebs; occasionally grading to carbonaceous shale; abundant gas bleeding from surfaces. MW 9.6 FV 47 PV 13 yP 28 GELS 8/11/13 FL 5.2 CK 2 SOL 9 SD .5 MBT 9.3 PH 9.3 PM .2 PFIMF .211.6 CL 12500 Ca 50 5000 Sand = Light gray overall, dominantly clear, white, light to medium gray; common light greenish gray, occasionally reddish orange, black; clasts range from very fine lower to medium upper, dominantly fine range; moderate sorting; angular to rounded, dominantly subangular to subround; composed of 80% quartz and other siliceous minerals, 20% metamorphic and volcanic lithics; appears loose in sample; no acid reaction. 5055 Tuffaceous claystone = Pale yellowish brown, light to medium brownish gray, rarely moderately brown; very soft to soft; dominantly appears as amorphous clay lumps, occasionally as roughly subblocky poorly indurated cuttings; mushy to rarely slightly brittle; earthy luster with scattered microsparkles; smooth to common moderately gritty texture; non to rarely slightly calcareous; brownish fraction is more carbonaceous, pale yellowish brown fraction contains more ash; scattered to common black carbonaceous specks and streaks; scattered very fine grained volcanic glass shards; locally silty, grading rarely to argillaceous siltstone. . 5140 Sand/sandstone = Light gray overall with dominantly clear, light to medium gray, common light to medium greenish gray, scattered reddish orange, scattered black; clasts range from very fine lower to medium lower, dominantly very fine to fine range; subangular to rounded; moderately well sorted; composed of 70% quartz and other light colored minerals, 30% volcanic and meta lithics; scattered mica; common thin coating of clay matrix material on grains; no acid reaction; estimated fair porosity and permeability. 5210 Tuffaceous claystone = Pale yellowish brown, light to medium brownish gray, rarely moderate brown; very soft to soft; dominantly appears as amorphous clay lumps, occasionally as roughly subblocky poorly indurated cuttings; mushy to rarely slightly brittle; earthy luster with scattered microsparkles; smooth to common moderately gritty texture; non to rarely slightly calcareous; brownish fraction is more carbonaceous, pale yellowish brown fraction contains more ash; scattered to common black carbonaceous specks and streaks. 5280 Sand = Light gray overall with salt and pepper appearance; grains range from very fine lower to fine lower; subangular to rounded; well sorted; 70% quartz and other siliceous minerals, 30% metamorphic and volcanic lithics; trace to scattered mica; scattered clay matrix material loose in sample; few grains with thin coating of clay on surfaces; estimated fair porosity and permeability; mostly appears "clean" in samples. 5335 Tuffaceous claystone = Pale yellowish brown, light to medium brownish gray, occasionally moderate brown; dominantly very soft; appears as very small amorphous lumps and roughly formed subblocky cuttings; mushy to pasty, occasionally crumbly to rarely slightly brittle; earthy luster; smooth to moderately gritty texture; dominantly non calcareous, occasionally shows slight acid reaction; ashy appearance; scattered very fine volcanic ash shards; scattered to common very fine to medium size sand grains embedded in lumps. . 5405 [:I EPOCH 11 . Conocri'Phillips NICU A-10A Sand = Light gray to light medium gray overall; dominantly very fine lower to fine lower; very well to well sorted; subangular to subrounded; 75 - 80% quartz and 20 - 25% metamorphic and volcanic lithic fragments; some mica disseminated throughout sample; estimate good to fair porosity and permeability; appears unconsolidated and very "clean" in sample; non to locally slight calcareous. 5465 Tuffaceous claystone = Light gray to white, pale yellowish brown, light to medium brownish gray; very soft to occasionally firm; lumpy to subtabular habit; mushy to crumbly, occ slightly brittle; dominantly occurs as pasty clay lumps, occasionally as poorly to moderately indurated lumps or roughly formed cuttings; matte luster; smooth to gritty texture; non to slightly calcareous; ashy appearing part is lighter in color and mostly grayish; carbonaceous appearing part is darker in color and mostly brownish ; common ashy blebs and carbonaceous specks and streaks; locally silty, grading in part to siltstone. 5550 Coal = Dusky yellowish brown to brownish black to common black; dominantly firm to moderately hard, some slightly firm; brittle; moderately tough; dull to slightly waxy luster; matte texture; subplaty to subtabular cuttings; common amber blebs; occasionally grading to carbonaceous shale; abundant gas bleeding from surfaces. . 5600 Tuffaceous claystone = Light gray to white, pale yellowish brown, light to medium brownish gray; very soft to occasionally firm; lumpy to subtabular habit; mushy to crumbly, occasionally slightly brittle; dominantly occurs as pasty clay lump, some poorly to moderately indurated irregular to subblocky cuttings; dull to earthy luster; smooth to gritty texture; non to slightly calcareous; "ashy" portion appears lighter in color and grayish; carbonaceous portion appears darker in color and mostly brownish; often interbedded with carbonaceous laminations and small stringers of coal; traces air fall tuff. 5690 Carbonaceous shale = Brownish gray to brownish black; slightly firm to soft, common firm; subblocky to subplaty cuttings with some incipient fissillity and parting along subplanar planes; dull to earthy luster; locally containing thin laminations of lignitic to subbituminous coal and tuffaceous claystone; non to locally moderately calcareous. 5745 Tuffaceous claystone = Light gray to white, pale yellowish brown, light to medium brownish gray; very soft to occasionally firm; lumpy to subtabular habit; mushy to crumbly, occasionally slightly brittle; dominantly occurs as pasty clay lump, some poorly to moderately indurated irregular to subblocky cuttings; dull to earthy luster; smooth to gritty texture; non to slightly calcareous; "ashy" portion appears lighter in color and grayish; carbonaceous portion appears darker in color and mostly brownish; scattered blebs of free ash fall tuff. 5830 Tuffaceous siltstone = Light brownish gray to light medium gray; mushy to slightly firm with occasional slightly crunchy cuttings; irregular to subblocky fracture with rare subplanar partings; dull to earthy luster with scattered microsparkles; silty to gritty texture; massive bedding with rare visible thin bedding; often grades to and is interbedded with tuffaceous claystone; generally argillaceous; non to slightly calcareous, increasing in acid reaction from above samples. MW 9.6 FV 52 PV 13 yP 28 GELS 12/20/22 FL 6.0 CK 2 SOL 9 SO .3 MBT 4 PH 9.2 Pm.2 Pf/Mf .1/1.3 CI12500 Ca 50 . 5920 ~ EPOCH 12 . C~illips NICU A-10A Tuffaceous claystone = Pale yellowish brown, light gray, light to medium brownish gray; very soft to occ slightly firm; mushy to crumbly, rarely slightly brittle; dominantly amorphous lumps with common subblocky cuttings; matte luster; smooth to gritty texture; dominantly non calcareous, rarely to slightly calcareous; carbonaceous in part; common ashy appearance; scattered very fine sand grains embedded in lumps; scattered volcanic glass shards. 5980 Coal = Black, dusky brownish black; firm to moderately hard; brittle; crunchy to moderately tough; flaky, tabular, blocky cuttings habit; slightly resinous luster with smooth to slightly rough texture; scattered amber blebs; scattered ashy laminations; variable clay content, occasionally grades to carbonaceous shale; occasional gas bubbles visible on surfaces. 6030 Tuffaceous siltstone = Pale yellowish brown, light to occasionally medium brownish gray, occasionally moderate brown; very soft to occasionally moderately firm; dominantly appears as amorphous lumps, occasionally as poorly indurated subblocky cuttings; matte, earthy luster; variable gritty to slightly smooth texture; dominant non calcareous, rarely with slight acid reaction; scattered volcanic shards; scattered to common carbonaceous specks; argillaceous, grading to and interbedded with tuffaceous claystone. 6090 Tuffaceous claystone = Pale yellowish brown, light gray, mod brown, light to medium brownish gray; very soft to occ slightly firm; mushy to crumbly, rarely slightly brittle; dominantly appears as lumps with common subblocky cuttings; earthy luster; smooth to gritty texture; dominantly non calcareous, rarely slightly calcareous; carbonaceous in part; common ashy appearance; scattered very fine sand grains embedded in lumps; scattered volcanic glass shards; locally silty zones, grades in part to and is interbedded with siltstone. . 6160 Coal = Black, dusky brownish black; firm to moderately hard; moderately brittle; moderately tough; blocky and tabular cuttings habit; slightly resinous luster with smooth to slightly rough surface texture; scattered amber blebs; scattered ashy laminations; variable clay content, occasionally grades to carbonaceous shale; occasional gas bubbles visible on surfaces. 6210 Tuffaceous siltstone = Pale yellowish brown, light to occasionally medium brownish gray, occasionally moderate brown; very soft to occasionally firm; dominantly appears as irregular lumps, occasionally as poorly indurated subblocky cuttings; slightly sparldy luster; variable grainy to gritty texture; dominantly non calcareous, rarely with slight acid reaction; scattered volcanic shards; scattered to com carbonaceous specks; argillaceous, grading to and interbedded with tuffaceous claystone. 6270 Tuffaceous claystone = Pale yellowish brown to light brownish gray, with some olive gray secondary hues; very soft to slightly firm, occasional firm; dominantly appears as amorphous lumps to irregular poorly indurated subblocky cuttings; smooth to slightly gritty texture; often grading to and interbedded with tuffaceous siltstone; variable amounts of carbonaceous matter disseminated throughout sample; scattered microsparkles; slightly to non calcareous. . 6340 Carbonaceous shale = Moderate yellowish brown to dusky brown, some light brownish gray to brownish gray; dominantly slightly firm to firm, some soft; irregular to subblock.yto subplaty cuttings; some with incipient fissillity; commonly grades to and is interbedded with tuffaceous claystone; rare thin laminations of lignite to subbituminous coal; dull to earthy luster; gritty to smooth texture; non calcareous. ~ EPOCH 13 ConocJ'Phillips NICU A-10A · 6405 Coal = Black, dusky brownish black; finn to moderately hard; moderately brittle; moderately tough; blocky and tabular cuttings habit; slightly resinous luster with smooth to slightly rough surface texture; scattered amber blebs; scattered ashy laminations; variable clay content, often grades to carbonaceous shale; abundant gas visible bleeding from surfaces. 6460 Tuffaceous claystone = Pale yellowish brown to light brownish gray, with some olive gray secondary hues; very soft to slightly finn, occasional finn; dominantly appears as amorphous lumps to irregular poorly indurated, subblock.y cuttings; smooth to slightly gritty texture; often grading to and interbedded with tuffaceous siltstone; sample speckled with carbonaceous material; scattered volcanic glass shards and microsparkles; slightly to non carbonaceous. 6530 Tuffaceous siltstone = Pale yellow brown to brownish gray, some light gray to medium gray; mostly slightly finn to slightly soft, occasionally finn; dominantly appears as poorly indurated irregular to subblocky cuttings; gritty to silty texture, some grading to and interbedding with tuffaceous claystone; variable amounts of carbonaceous material; scattered volcanic glass shards; non to slightly calcareous. 6595 Coal = Black, dusky brownish black; finn to moderately hard; moderately brittle; moderately tough; blocky and tabular cuttings habit; slightly resinous luster with smooth to slightly rough surface texture; scattered amber blebs; some grading to carbonaceous shale; occasional woody pieces; some gas bleeding visible on surfaces. · 6645 Sand = Light medium gray to light gray; very fine to medium, some coarse lower; moderately well to moderately sorted; subangufar to angular, occasional subrounded to rounded bit impacted granules; mostly unconsolidated, some friable cuttings; slightly argillaceous/ashy matrix; estimate good to fair porosity and penneability; non to slightly calcareous. MW9.6 FV 49 PV 11 YP 26 GELS 15/26/32 FL 6.2 CK 2 SOL 9 SD.5 MBT 12.5 pH 9.6 PM .3 PFIMF .211.8 CI12000 Ca 60 6725 Coal = Black., dusky brownish black.; finn to moderately hard; moderately brittle; moderately tough; blocky and tabular cuttings habit; slightly resinous luster with smooth to slightly rough surface texture; scattered amber blebs; scattered ashy laminations; variable clay content, often grades to carbonaceous shale; abundant gas visible bleeding from surfaces. MW 9.2 FV 70 PV 18 YP 31 GELS 11/16/17 FL 5.5 CK 1 SOL 6 SD 0 MBT 4 pH 9.1 Pm .2 Pf/Mf .2/.3 C115000 Ca 50 6800 Sand = Light gray overall with common salt and pepper appearance; dominantly clear, frosted white; com light to dark gray, scattered to common reddish orange, light to medium greenish gray; grains range from very fine upper to fine upper with scattered medium lower grains; subangular to rounded; moderately well sorted; composed of 70% quartz and other light colored siliceous minerals, 30% volcanic and metamorphic lithics; scattered mica; appears loose in samples; non calcareous; estimated poor to fair porosity and penneability. · 6870 ~ EPOCH 14 · · · y ConocoPhillips NICU A-10A Tuffaceous siltstone = Pale yellow brown to brownish gray, some light gray to medium gray; mostly slightly finn to soft, occasionally moderately finn; dominantly appears as poorly indurated irregular to subblocky cuttings; gritty to silty texture, some grading to and interbedding with tuffaceous claystone; variable amounts of carbonaceous material; scattered volcanic glass shards; non to slightly calcareous. 6935 Tuffaceous claystone = Pale yellowish brown to light brownish gray, with some olive gray secondary hues; very soft to slightly finn, occasional finn; dominantly appears as amorphous lumps to irregular poorly indurated subblocky cuttings; smooth to slightly gritty texture; often grading to and interbedded with tuffaceous siltstone; sample speckled with carbonaceous material; scattered volcanic glass shards and microsparkles; slightly to non calcareous. 7005 Sand = Light gray to light medium gray; dominantly very fine upper to fine upper, some medium to medium upper; well to moderately well sorted; subangularto rounded; composed of 70% quartz and other light colored siliceous minerals, 30% volcanic and metamorphic lithic fragments; scattered mica; unconsolidated; non to locally slightly calcareous; estimate poor to fair porosity and permeability. 7065 Tuffaceous claystone = Light gray, brown to light brownish gray, with some olive gray secondary hues; very soft to slightly finn, occasional finn; dominantly appears as amorphous lumps to irregular poorly indurated subblocky cuttings; smooth to slightly gritty texture; often grading to and interbedded with tuffaceous siltstone; sample speckled with carbonaceous material; scattered volcanic glass shards and microsparkles; slightly to non calcareous. 7135 Sand = Light gray to light medium gray; dominantly very fine upper to fine upper, some medium to medium upper; moderately to moderately well sorted; subangular to rounded; composed of 70% quartz and other light colored siliceous minerals, 25% volcanic and metamorphic lithic fragments; scattered mica; unconsolidated; non to locally slightly calcareous; estimate poor to fair porosity and permeability. Abundant graphite in samples from mud additive. 7210 Tuffaceous claystone = Light gray, brown to light brownish gray, with some olive gray secondary hues; very soft to slightly finn, occasional finn; dominantly appears as amorphous lumps to irregular poorly indurated subblocky cuttings; smooth to slightly gritty texture; often grading to and interbedded with tuffaceous siltstone; sample speckled with carbonaceous material; scattered volcanic glass shards and microsparkles; non calcareous. 7280 Coal = black, dusky brownish black; finn to moderately hard; moderately brittle; moderately tough; blocky and tabular cuttings habit; slightly resinous luster with smooth to slightly rough surface texture; scattered amber blebs; some grading to carbonaceous shale; occasional woody pieces; some gas bleeding visible on surfaces. MW 9.5 FV 54 PV 16 yP 24GEL 9/18/22 FL 5.4 CK 2/3 SOL 7 SD .25 MBT 5 PH 8.9 PM 0 PFIMF 0/1.1 CI14500 Ca 60 7355 Tuffaceous claystone = light gray to olive gray; usually soft; amorphous habit; scattered volcanic glass shards; vitreous luster; embedded clasts of sandstone and lithic fragments. [~ EPOCH 15 Conoc;pJ,illips NICU A-10A . 7385 Tuffaceous claystone = gray to dark gray I brown; soft to moderately hard, apparent lithification occasionally; notable increase in sandstone clasts; sandstone clasts range from fine to coarse. 7415 Tuffaceous siltstone= light brownish gray; moderately soft to hard; occasionally friable; irregular to subangular; common 'floating' clasts of sandstone and exotic colored lithics. 7445 Sand = color1ess-translucent, light gray, yellow brown; grain size from fine to coarse, dominantly size is medium; grains show moderate sphericity I roundness; fair sorting; 40 - 50% quartz, 40 to 50% volcanic and metamorphic lithics; common thin coating of clay matrix material on grains; no acid reaction; appears to be poor to fair porosity and permeability. 7495 Tuffaceous claystone = pale yellowish brown; very soft to occasionally firm; dominantly mushy to crumbly, occasionally crumbly to moderately brittle; dominantly appears as amorphous clay lumps, occasionally as subblocky or irregular cuttings; matte, earthy luster; smooth to moderately grainy, silty texture; non calcareous; locally common silty zone; occasionally grades to and is interbedded with siltstone; appears ashy; common black pinpoint carbonaceous specks. 7555 Volcanic ash = very light gray; soft and soluble; mostly slightly to moderately silty to sandy grading tuffaceous siltstone and sandstone; commonly with disseminated organic matter and occasional carbonaceous partings. . 7595 Coal = brownish black to dark grayish black; moderately hard and brittle, to slightly firm and crumbly with increase in organic clay content; common visible lamina with dense to platy to flaky fracture; lignite to bituminous; very slight to occasional moderate micropyrite; common bleeding gas. 7640 Sandstone = medium light gray; very fine to medium lower; subangular to subrounded; moderately to poorly sorted in slight to moderate ashy clay matrix; grain supported and friable, to matrix supported and soluble; 50% quartz, and 50% green to black siliceous to clayey lithics and metalithics; estimate poor porosity. 7690 Tuffaceous claystone = medium light gray to some yellowish gray to rare brownish gray; soft and soluble; slightly to moderately silty to slightly gritty texture; grading to tuffaceous siltstone and minor sandstone; some slightly organic with disseminated carbonaceous matter and partings occasionally grading organic claystone. 7740 Sand = light gray; fine to medium; subrounded to subangular; estimate moderately to poor1y sorted in overall slight to moderate ashy slightly organic clay matrix; 80% quartz, and 20% orange brown to brown to minor green to gray to white lithics; estimate some fair porosity; no oil indicators. 7785 Coal = grayish black to brownish black; slightly hard and brittle to slightly firm and crunchy; occasionally malleable grading peat; mostly subbituminous to lignite; common visible lamina, dense to some flaky to platy fracture; bleeding gas. . 7825 U EPOCH 16 · ConocJ'Â,illips NICU A-10A Tuffaceous claystone = medium light gray to yellowish gray to brownish gray to light gray; soft and soluble to slightly firm; slightly to moderately silty/gritty texture often grading to tuffaceous siltstone and sandstone; often slightly organic occasionally grading carbonaceous claystone with interbedded coals; occasionally grading to ash fall tuff. MW 9.5 FV 66 PV 20 yP 36 GELS 12/25/32 FL 5.5 CK 2 SOL 7 OIL 1 SD .5 MBT 5 PH 9.5 PM .3 PF/MF .1/1.3 CI15000 Ca 50 7900 Coal = black, dusky yellowish brown, brownish black; firm; crunchy to brittle to moderately tough; irregular, tabular and platy cuttings; slightly resinous luster with occasionally rough patches; locally high clay content-grades in part to carbonaceous shale; scattered ashy clay laminations; occasionally appears woody; trace amounts of pinpoint gas bubbles on freshly broken surfaces. 7955 Tuffaceous claystone = pale yellowish brown; very soft to occasionally moderately firm; dominantly mushy to crumbly, occasionally crunchy to moderately brittle; dominantly appears as amorphous clay lumps, occasionally as subblocky or pr indurated cuttings; matte, earthy luster; smooth to moderately grainy, common silty texture; non calcareous; common silty zones; occasionally grades to and is interbedded with siltstone; appears "ashy"; scat to common black to brownish black carbonaceous specks. · 8015 Sand = medium light gray; fine to very fine and slightly scattered medium lower grains; subrounded to subangular; estimate moderately to moderately well sorted in probable ashy clay 65% quartz, and 35% gray to green to black mostly siliceous lithics and metalithics and coal and clay fines; some interbedded slightly organic claystone and possible thin coal beds; estimate some fair porosity and permeability with no oil indicators. 8080 Tuffaceous claystone = medium light gray to medium gray to brownish gray to light gray; soft and soluble to moderately soft; slight to moderate fine silty texture; often sandy occasionally grading sandstone especially light gray; often slightly organic to locally grading carbonaceous claystone with common carbonaceous matter and interbedded coal. 8135 Sand = light gray overall; clasts range from fine lower to coarse lower, dominantly fine range; subangular to rounded; moderately sorted; composed of 70% quartz and other siliceous minerals, 30% volcanic and metamorphic lithics; traces of mica; occasionally grains with thin ashy clay matrix material on surfaces; appears disaggregated in sample; estimate fair porosity and permeability. MW 9.5 FV 70 PV 13 yP 26 GELS 10/13/16 FL 5.6 CK 2 SOL 5.5 OIL 0 SD TR MBT 2 PH 8.5 PM .1 PF/MF .05/1 CI 27000 Ca 60 8210 Tuffaceous claystone = medium gray to medium light gray to occasionally yellowish gray; soft and soluble to moderately soft; smooth to fine silty texture grading siltstone; some slight organic matter and locally possible thinly interbedded coal; occasional streaks or debris slightly firm to brittle grayish yellow partially siliceous claystone; non to slightly calcareous. · 8265 Sand = light gray; very fine to medium and slightly scattered coarse; locally conglomeratic associated ash and coal; subangular to subrounded; some matrix supported in ashy clay; 50% quartz, and 50% metalithics, partially siliceous clay and coal, and volcanics; estimate poor porosity. [=I EPOCH 17 y ConocoPhillips NICU A-10A · 8310 Coal = very dark gray to grayish black to dusky brown; finn and brittle to slightly finn and crunchy to slightly malleable; abundant lamina with platy to some flaky fracture; lignite to subbituminous occasionally grading to peat and carbonaceous shale; some bleeding gas. 8355 Sand = medium light gray; fine to coarse lower; subrounded to subangular; moderately well to moderately sorted and estimate mostly grain supported in ashy clay matrix; 40% quartz, and 60% mostly metalithics, and some volcanics and lithics; estimate some fair porosity. 8395 Tuffaceous claystone = medium gray to light gray to brownish gray; soft to moderately soft, and soluble; smooth to silty and slightly gritty texture; often organic with flaky carbonaceous partings and grading carbonaceous shale with interbedded coal. 8435 Coal = grayish black to dark brownish gray; finn and brittle, to slightly finn and crunchy; massive to interiaminated and as partings with tuffaceous to organic claystone; blocky to platy to flaky fracture along visible lamina. 8470 Sand = medium light gray; fine to medium grains; subangular to subrounded; estimate moderately to poorly sorted and mostly grain supported in ashy clay; 50% quartz, and 50% metalithics and volcanics; abundant coal after sweep; estimate poor to fair porosity. · 8510 Sand = light to medium gray overall; dominantly clear, white, light to dark gray; clasts range from very fine upper to medium upper, dominantly fine grain; angular to rounded, dominantly subangular to subround; moderately sorted; composed of 60% quartz, 40% metamorphic and volcanic lithics; appears as loose grains in sample but common chunks of ashy clay matrix material is common; slightly calcareous; estimated poor to fair porosity and penneability. 8575 Coal = black; finn; crunchy to brittle; rarely moderately tough; hackly, tabular and platy cuttings; slight resinous luster; scattered ashy laminations; rare pin point gas bubbles on surfaces. 8605 Tuffaceous siltstone = light brownish gray, pale yellowish brown; very soft to soft; mushy to occasionally crumbly; irregular and subblocky cuttings; matte luster common micro sparkles; gritty texture; non to occasionally slightly calcareous; locally clay rich, grading in part to and interbedded with tuffaceous claystone; common volcanic glass shards; common black pinpoint specks; occasionally lams of very fine lower sand. 8665 Tuffaceous claystone = light gray, pale yellowish brown; very soft to soft, rarely slightly finn; dominantly mushy amorphous cuttings; occasionally poorly indurated roughly subblocky cuttings; smooth to gritty texture; earthy luster; non to locally slightly calcareous; commonly very silty, grading in part to tuffaceous siltstone; scattered to common carbonaceous specks; common ashy appearance. 8725 Tuffaceous claystone = medium gray to medium light gray; soft to soluble; smooth to silty/gritty texture; some coal and carbonaceous matter in samples indicating possible thin zones and partings in clay; possible interbedded matrix supported sand. · 8765 [~ EPOCH 18 · · · Cono~illips NICU A-10A Sand = medium gray to medium light gray; very fine to medium lower grains; subrounded to subangular; estimate moderately to poorly sorted and mostly matrix supported in ashy clay; 60% quartz, and 40% mostly metalíthics and minor líthics and volcanics; estimate poor porosity. 8810 Tuffaceous claystone = medium gray to medium light gray; soft and soluble; smooth to some silty/gritty texture; occasionally grading tuffaceous siltstone and matrix: supported sandstone; non to slightly calcareous. Total Depth of 8840' 19:17hrs. AUQust 16.2003 [=I EPOCH 19 y ConocoPhillips NICU A-10A · 3.2. SAMPLING PROGRAM AND DISTRIBUTION Set Type and Purpose Interval Frequency Distribution Unwashed wet for ConocoPhillips Alaska Inc. A Biostratigraphy KOP to 4200' 50' 619 East Ship Creek Avenue Anchorage, AK 99501 Unwashed wet for ConocoPhillips Alaska Inc. A Biostratigraphy 4200' to T.D. 30' 619 East Ship Creek Avenue Anchorage, AK 99501 A Washed Wet KOP to 4200' 50' On Site Examination A Washed Wet 4200' to T.D. 30' On Site Examination ConocoPhillips Alaska Inc. A Washed and Dried KOP to 4200' 50' 619 East Ship Creek Avenue Anchorage, AK 99501 ConocoPhillips Alaska Inc. A Washed and Dried 4200' to T.D. 30' 619 East Ship Creek Avenue Anchorage, AK 99501 AOGCC B Washed and Dried KOP to 4200' 50' C/O ConocoPhillips Alaska Inc. 619 East Ship Creek Avenue Anchorage, AK 99501 · AOGCC B Washed and Dried 4200' to T.D. 30' C/O ConocoPhillips Alaska Inc. 619 East Ship Creek Avenue Anchorage, AK 99501 Specific Coal ConocoPhillips Alaska Inc. A Washed and Dried 3500' to 8000' 619 East Ship Creek Avenue Zones' Anchorage, AK 99501 Isotech Laboratories, Inc. A Ditch Gas Bags KOP to 4200' 500' 1308 Parkland Court Champaign, IL 61821 Isotech Laboratories, Inc. A Ditch Gas Bags 4200' to T.D. 30' 1308 Parkland Court Champaign, IL 61821 · ~ EPOCH 20 ¡. C~illips NICU A-10A 4. DRILLING DATA 4.1. DAILY ACTIVITY SUMMARY June 26 2003 Epoch arrived on location for rig-up. August 2, 2003 Epoch commenced DML logging. Pick up Whipstock BHA. Run in with BHA. Test MWD. Run in hole and set Whipstock at 1910'. Sheared off and milled window from 1910' to 1963'. Pressure tested window twice. Failed. POOH for new BHA. August 3,2003 Pull out of hole. Lay down HWDP, MWD and mill assembly. Pick up new BHA. Test MWD. Trip in hole with new BHA. Orient tool face, run through whipstock and back. Slide to 1973'. Drill/slide from 1973' to 2391'. Circulate bottoms up - hole loaded up with cuttings. Drill slide from 2391' to a midnight depth of 2709'. August 4,2003 Drill ahead from 2709' to 2956'. Circulate out hole several times. Pull out of hole to shoe for wiper trip. Run in hole. Ream down last stand to 2956'. Drill ahead from 2956' to 3940'. Circulate out hole several times. Pull out of hole for wiper trip. . August 5,2003 Pull out of hole to 2527'. Run in hole to 3858'. Wash and ream down last stand, from 3858' to 3942'. Drill from 3492' to 4740'. Circulate and condition mud, change screens, and service rig. Drill from 4740' to 4924'. Pump sweep, circulate bottoms up, and trip out of hole for wiper trip. Work pipe through tight spot at 4165' and 4060'. August 6,2003 Trip out of hole to 3824'. Trip in hole to bottom. 229 units wiper gas. Drill ahead from 4924' to 5108'. Power failure on rig. Drill ahead from 5108' to 5293'. Repair #2 pump. Drill ahead from 5293' to a midnight depth of 5909'. August 7, 2003 Pull out of hole, reaming and circulating, to 4835' for wiper trip. Run in hole to bottom. 175 units of wiper gas. Drill/slide ahead from 5909' to 6217'. Repair rig. Drill from 6217' to 6278'. Trip out of hole for short wiper trip (3 stands). Run in hole to bottom. Drill/slide ahead from 6278' to 6525'. August 8, 2003 Drill ahead, sliding and rotating, from 6525' to 6770'. Work stuck pipe free. Circulate mud to clean out hole. Trip out of hole for new bit/BHA, working the pipe through tight spots. August 9, 2003 Trip out of hole for new bit/BHA. Lay down BHA. Test BOPE. Pick up BHA with new bit #2. Run in hole with new BHA. Test MWD tool. Cut and slip drill line. Continue to run in hole. August 10, 2003 Displace mud from hole. Mix, circulate and condition new mud. Run in hole to bottom, washing and reaming through tight spots. 395 units of trip gas. Drill ahead, rotating and sliding, from 6770' to 7090'. Top drive torqued up, added graphite to mud system. Drill ahead, rotating and sliding, from 7090' to 7192'. . August 11, 2003 Drill ahead, rotating and sliding, from 7192' to 7520'. Wipe hole 15 stands, drill from 7520' to 7751'. ~ EPOCH 21 · · · ~ ConocoPhillips NICU A-10A August 12, 2003 Drill from 7751' to 7951', unable to rotate due to high torque, circulate and wiper trip 9 stands, fix pump, work on engine, and drill from 7951' to 8143', top drive malfunction, circulate out high gas, and begin pump out of hole for bit. August 13, 2003 Trip from bottom total 25 stands pumping out of hole, circulate out high gas, maximum 1230 units, trip to bottom and circulate, 2500 units of trip gas, trip out of hole pumping, maximum 275 units decreasing down to 60 units after 15 stands, continue pumping out of hole averaging 60 units of gas, continue tripping out of hole without pumping after 68 stands. August 14. 2003 Continue tripping out of hole to window, work on top drive, pull out of hole, change bit and BHA, trip in hole to window, test MWD and displace mud, 70 units of gas, and build mud volume. August 15, 2003 Finish building mud and trip to bottom, displacing mud twice during trip, displace mud on bottom, 300 units oftrip gas, and drill from 8143' to 8438'. August 16, 2003 Drill from 8438' to 8501', and circulate out, 945 units of gas, wiper trip while waiting on orders to drill ahead after show, trip out 15 stands, repair rig after starting trip in, finish tripping in and circulate bottoms up, maximum 195 units, and drill from 8501' to 8605', wait on orders to drill ahead after MWD confirms show, drill ahead from 8605' to 8840', total depth, circulate and condition hole, wiper trip pumping out 10 stands, circulate and condition hole, 220 units of wiper gas ~ EPOCH 22 Conoc~Phillips NICU A-10A 4.2. SURVEY RECORD Measured Vertical Closure Depth Inclination Azimuth TVD Section NS EW Closure Azimuth DLS (ft) ( deg ) ( deg ) (ft) (ft) ( ft ) (ft) (ft) ( deg ) ( deg/100 ft ) 0 0 0 0 0 0 0 0 0 0 43 0 0 43 0 0 0 0 0 0 75 0.08 122 75 0 -0.01 0.02 0.02 122 0.25 100 0.5 94 100 0.07 -0.03 0.14 0.15 101.38 1.72 125 0.33 28 125 0.21 0.03 0.29 0.29 84.54 1.9 150 0.08 183 150 0.27 0.07 0.32 0.33 77.01 1.62 175 0.42 60 175 0.34 0.1 0.4 0.41 75.6 1.87 200 0.08 128 200 0.43 0.14 0.49 0.51 74.38 1.59 225 0.17 322 225 0.44 0.16 0.48 0.51 72.09 0.99 250 0.17 313 250 0.44 0.21 0.43 0.48 64.02 0.11 275 0.25 21 275 0.5 0.29 0.42 0.51 55.93 0.98 300 0.33 44 300 0.62 0.39 0.49 0.63 51.72 0.56 325 0.58 13 325 0.8 0.56 0.57 0.8 45.36 1.37 349 0.83 1 349 1.04 0.86 0.6 1.05 35.09 1.2 375 0.25 336 374.99 1.2 1.1 0.58 1.24 27.95 2.36 400 0.25 302 399.99 1.22 1.17 0.51 1.28 23.6 0.58 425 0.5 319 424.99 1.22 1.29 0.4 1.35 17.09 1.08 450 0.5 351 449.99 1.3 1.48 0.31 1.51 11.74 1.1 475 0.25 25 474.99 1.42 1.63 0.31 1.66 10.84 1.3 500 0.25 332 499.99 1.49 1.73 0.31 1.76 10.16 0.89 525 0.5 337 524.99 1.56 1.88 0.24 1.89 7.33 1.01 550 0.5 356 549.99 1.68 2.09 0.19 2.1 5.24 0.66 575 0.75 29 574.99 1.91 2.34 0.26 2.36 6.42 1.71 600 0.5 39 599.99 2.18 2.57 0.41 2.6 9.1 1.09 625 0.75 37 624.99 2.45 2.78 0.58 2.84 11.74 1 [~ EPOCH 23 . . . Conoc~illips NICU A-10A Measured Vertical Closure Depth Inclination Azimuth TVD Section NS EW Closure Azimuth DLS (ft) ( deg ) ( deg ) (ft) (ft) (ft) ( ft) (ft) ( deg ) ( deg/100 ft ) 650 1.75 53 649.98 2.99 3.14 0.98 3.29 17.34 4.2 675 2.75 56 674.96 3.95 3.71 1.78 4.12 25.68 4.03 700 3.75 55 699.92 5.33 4.51 2.95 5.39 33.17 4.01 725 5 49 724.85 7.21 5.7 4.44 7.22 37.95 5.32 750 6 37 749.73 9.59 7.46 6.05 9.6 39.06 6.08 775 7 29 774.57 12.37 9.83 7.58 12.41 37.62 5.39 800 8.25 26 799.35 15.58 12.78 9.1 15.69 35.46 5.25 825 9 26 824.07 19.18 16.15 10.74 19.39 33.64 3 850 9.25 27 848.75 23 19.69 12.51 23.33 32.43 1.18 875 9.75 32 873.41 27.02 23.28 14.55 27.45 32 3.86 900 9.75 33 898.05 31.2 26.85 16.82 31.68 32.07 0.68 906 9.75 35 903.96 32.2 27.69 17.39 32.7 32.13 5.64 969 11 36 965.93 43.47 36.93 23.98 44.03 33 2 1029 13 31 1024.62 55.79 47.34 30.83 56.49 33.07 3.75 1091 14.75 36 1084.81 70.48 59.71 39.06 71.35 33.19 3.42 1155 16.25 32 1146.48 87.4 73.89 48.59 88.44 33.33 2.88 1246 19 32 1233.2 114.52 97.26 63.19 115.98 33.01 3.02 1340 21.25 30 1321.46 146.24 124.99 79.82 148.3 32.56 2.5 1432 23.75 32 1406.45 180.78 155.14 97.98 183.49 32.27 2.84 1525 26 35 1490.82 219.45 187.73 119.6 222.59 32.5 2.77 1617 26.5 29 1573.34 259.46 222.21 141.12 263.23 32.42 2.93 1712 26 30 1658.55 300.46 258.78 161.8 305.2 32.02 0.7 1807 24.5 32 1744.47 340.21 293.52 182.66 345.71 31.89 1.82 1901 25 32 1829.83 378.95 326.89 203.51 385.06 31.9 0.53 2089.04 23.75 41.36 2001.17 455.96 389.04 249.61 462.23 32.68 2.16 [=I EPOCH 24 . . . . . . Conoc;pí,illips NICU A-10A Measured Vertical Closure Depth Inclination Azimuth TVD Section NS EW Closure Azimuth DLS (ft) ( deg ) ( deg ) (ft) (ft) (ft) ( ft ) ( ft ) ( deg ) ( deg/100 ft ) 2149.57 25.55 47.03 2056.19 481.16 407.09 267.22 486.95 33.28 4.91 2211.17 28.22 48 2111.13 508.89 425.89 287.76 513.99 34.05 4.39 2273.39 30.98 48.37 2165.23 539.44 446.37 310.67 543.84 34.84 4.45 2334.09 34.62 49.41 2216.24 572.09 467.98 335.45 575.79 35.63 6.07 2395.97 37.54 50.01 2266.25 608.21 491.54 363.25 611.19 36.46 4.75 2457.1 40.87 52.12 2313.61 646.36 515.79 393.31 648.64 37.33 5.87 2519.71 44.1 51.85 2359.78 688.02 541.83 426.62 689.63 38.22 5.17 2581.88 47.26 51.62 2403.21 731.87 569.38 461.54 732.95 39.03 5.09 2642.06 49.45 47.96 2443.2 776.43 598.42 495.85 777.16 39.65 5.82 2703.11 48.82 44.65 2483.15 822.46 630.3 529.23 823.02 40.02 4.23 2764.33 47.75 40.84 2523.9 868.14 663.84 560.25 868.65 40.16 4.96 2826.65 47.24 41.44 2566 914.08 698.44 590.47 914.59 40.21 1.08 2887.89 46.52 41.72 2607.86 958.78 731.88 620.14 959.28 40.28 1.22 2948.96 46.02 41.94 2650.08 1002.9 764.76 649.57 1003.39 40.34 0.86 3010.8 44.83 41.68 2693.48 1046.95 797.59 678.93 1047.43 40.41 1.95 3072.19 45.94 42.92 2736.6 1090.65 829.91 708.35 1091.1 40.48 2.31 3134.78 45.84 42.87 2780.16 1135.59 862.83 738.93 1136 40.58 0.17 3196.7 47.81 40.9 2822.53 1180.74 896.45 769.07 1181.14 40.63 3.94 3258.65 47.09 40.54 2864.42 1226.36 931.04 798.84 1226.78 40.63 1.24 3319.38 46.18 40.75 2906.12 1270.49 964.54 827.6 1270.93 40.63 1.52 3382.61 48.86 41.3 2948.82 1317.11 999.72 858.21 1317.56 40.64 4.29 3440.45 48.08 41.62 2987.17 1360.41 1032.17 886.88 1360.85 40.67 1.41 3503.71 47.45 41.64 3029.69 1407.25 1067.18 917.99 1407.68 40.7 1 3565.63 46.73 42.06 3071.85 1452.6 1100.96 948.25 1453.03 40.74 1.26 3626.98 46.12 42.18 3114.14 1497.04 1133.93 978.06 1497.46 40.78 1 U EPOCH 25 . . . Conoc;p"illips NICU A-10A Measured Vertical Closure Depth Inclination Azimuth TVD Section NS EW Closure Azimuth DLS (ft) ( deg ) ( deg ) (ft) ( ft ) ( ft ) (ft) (ft) ( deg ) ( deg/100 ft ) 3688.26 47.88 42.37 3155.93 1541.86 1167.08 1008.2 1542.26 40.82 2.88 3750.1 47.67 42.01 3197.49 1587.65 1201.01 1038.96 1588.04 40.86 0.55 3811.79 47.35 42.05 3239.16 1633.14 1234.8 1 069.42 1633.52 40.89 0.52 3874.11 46.84 41.95 3281.58 1678.79 1268.73 1099.96 1679.16 40.92 0.83 3933.39 46.84 41.66 3322.13 1722.03 1300.96 1128.79 1722.4 40.95 0.36 3993.68 48.21 40.56 3362.84 1766.49 1334.47 1158.02 1766.86 40.95 2.64 4056.78 47.86 40.91 3405.04 1813.39 1370.02 1188.63 1813.78 40.95 0.69 4118.69 47.54 41.15 3446.7 1859.17 1404.56 1218.69 1859.57 40.95 0.59 4180 47.05 41.39 3488.28 1904.22 1438.42 1248.41 1904.62 40.95 0.85 4241.81 47.02 41.01 3530.41 1949.45 1472.46 1278.2 1949.85 40.96 0.45 4303.82 47.92 40.77 3572.33 1995.13 1507 1308.12 1995.55 40.96 1.48 4364.63 47.53 40.53 3613.23 2040.11 1541.14 1337.43 2040.54 40.95 0.7 4427.19 47.11 40.73 3655.64 2086.09 1576.04 1367.38 2086.53 40.94 0.71 4488.94 46.98 40.46 3697.72 2131.27 1610.36 1396.78 2131.73 40.94 0.38 4550.53 47.23 40.56 3739.64 2176.37 1644.66 1426.09 2176.85 40.93 0.42 4610.88 48.01 39.18 3780.32 2220.91 1678.88 1454.67 2221.42 40.91 2.13 4672.84 47.79 40.76 3821.86 2266.85 1714.11 1484.2 2267.38 40.89 1.93 4733.65 47.16 41.09 3862.97 2311.65 1747.97 1513.55 2312.2 40.89 1.11 4796.3 49.15 38.16 3904.76 2358.27 1783.92 1543.3 2358.84 40.86 4.71 4857.59 48.98 38.4 3944.92 2404.47 1820.27 1571.98 2405.1 40.81 0.41 4918.4 49.61 37.57 3984.58 2450.44 1856.6 1600.35 2451 .14 40.76 1.46 4979.71 49.14 37.81 4024.5 2496.84 1893.43 1628.8 2497.61 40.7 0.82 5040.33 49.96 36.86 4063.83 2542.8 1930.11 1656.78 2543.66 40.64 1.8 5102.44 49.92 36.42 4103.8 2590.12 1968.25 1685.14 2591.08 40.57 0.55 5163.87 49.88 35.08 4143.37 2636.82 2006.38 1712.6 2637.91 40.48 1.67 [~ EPOCH 26 . . . ConocJ'"Phillips NICU A-10A Measured Vertical Closure Depth Inclination Azimuth TVD Section NS EW Closure Azimuth DLS (ft) ( deg ) ( deg ) (ft) (ft) (ft) (ft) ( ft ) ( deg ) ( deg/100 ft ) 5225.97 49.45 34.79 4183.57 2683.78 2045.19 1739.7 2685.03 40.39 0.78 5287,48 48.99 35 4223.74 2729.99 2083.39 1766.35 2731.39 40.29 0.79 5349.29 48.48 35.02 4264.51 2776.09 2121,44 1793 2777.66 40.2 0.83 5409.88 49.85 34.99 4304.13 2821.58 2158.99 1819.3 2823.32 40.12 2.26 5470.69 49.41 35.42 4343.51 2867.57 2196.85 1846.01 2869.48 40.04 0.9 5532.67 48.94 35.07 4384.03 2914.13 2235.15 1873.08 2916.22 39.96 0.87 5593.99 48.3 35.24 4424.57 2959.8 2272.77 1899.57 2962.07 39.89 1.06 5656.19 47.65 35.07 4466.21 3005.66 2310.55 1926.17 3008.12 39.82 1.06 5718.38 47.03 34.8 4508.35 3051.04 2348.04 1952.36 3053.69 39.74 1.05 5780.02 46.49 35.29 4550.58 3095.6 2384.8 1978.15 3098.44 39.68 1.05 5839.74 46.53 38,45 4591.68 3138.73 2419.46 2004.14 3141.71 39.64 3.84 5903.53 46.37 38.23 4635.63 3184.86 2455.72 2032.82 3187.93 39.62 0.35 5965.12 44.79 41 .46 4678.75 3228.81 2489.49 2060.98 3231.91 39.62 4.54 6026.6 44.23 41.86 4722.59 3271.9 2521.69 2089.63 3274.98 39.65 1.02 6087.06 44.12 41.51 4765.95 3314.03 2553.16 2117.65 3317.08 39.67 0.44 6146.34 44.02 44.53 4808.55 3355.25 2583.3 2145.77 3358.24 39.71 3.55 6210.05 43.51 45.07 4854.56 3399.27 2614.57 2176.82 3402.13 39.78 0.99 6271.13 43 45.49 4899.04 3441.06 2644.02 2206.56 3443.8 39.85 0.96 6332.3 43.14 48.06 4943.73 3482.69 2672.62 2236.99 3485.26 39.93 2.88 6394.34 42.63 47.97 4989.19 3524.69 2700.86 2268.38 3527.06 40.03 0.83 6454.71 42.31 48.14 5033.72 3565.23 2728.11 2298.69 3567.43 40.12 0.56 6518.33 41.92 47.84 5080.92 3607.67 2756.66 2330,4 3609.7 40.21 0.69 6580.09 41.51 47.87 5127.02 3648.56 2784.24 2360.87 3650.43 40.3 0.66 6641.97 40.9 48 5173.57 3689.12 2811.55 2391.13 3690.84 40.38 1 6703.98 40.3 48.19 5220.66 3729.25 2838.5 2421.16 3730.83 40.46 0.99 ~ EPOCH 27 . . . ConocJ'Phillips NICU A-10A Measured Vertical Closure Depth Inclination Azimuth TVD Section NS EW Closure Azimuth DLS 6763.53 40.23 49.12 5266.1 3767.49 2863.93 2450.06 3768.93 40.55 1.02 6825.43 40.65 49.27 5313.21 3807.34 2890.16 2480.45 3808.63 40.64 0.7 6886.85 41.38 49.7 5359.55 3847.31 2916.35 2511.09 3848.46 40.73 1.27 6948.87 41.1 46.55 5406.19 3887.96 2943.63 2541.53 3889 40.81 3.38 7009.58 41.51 45.5 5451.8 3927.94 2971.45 2570.36 3928.91 40.86 1.33 7071.39 41.13 42.95 5498.22 3968.72 3000.69 2598.83 3969.64 40.9 2.79 7126.93 41.06 42.2 5540.08 4005.23 3027.58 2623.53 4006.13 40.91 0.9 7194.15 41.47 42.59 5590.61 4049.56 3060.32 2653.42 4050.45 40.93 0.72 7256.06 41.95 42.74 5636.82 4090.75 3090.61 2681.33 4091.63 40.94 0.79 7317.68 42.28 43.01 5682.53 4132.07 3120.89 2709.45 4132.93 40.96 0.61 7379.13 42.68 43.3 5727.85 4173.56 3151.16 2737.84 4174.4 40.99 0.72 7439.58 41.99 45.29 5772.54 4214.24 3180.3 2766.26 4215.03 41.02 2.49 7501.94 42.22 45.81 5818.81 4255.98 3209.58 2796.11 4256.72 41.06 0.67 7563.38 41.08 45.24 5864.72 4296.74 3238.19 2825.24 4297.42 41.1 1.96 7625.26 41.21 45.94 5911.31 4337.38 3266.68 2854.33 4338.02 41.15 0.77 7686.98 39.14 46.44 5958.47 4377.09 3294.24 2883.06 4377.68 41.19 3.39 7748.31 39.01 46.75 6006.08 4415.63 3320.81 2911.14 4416.17 41.24 0.38 7810.26 39.3 47.43 6054.12 4454.6 3347.44 2939.79 4455.08 41.29 0.84 7871.99 38.91 48.19 6102.02 4493.35 3373.59 2968.64 4493.77 41.35 1 7931.75 39.44 48.86 6148.35 4530.86 3398.59 2996.93 4531.22 41.41 1.13 7993.14 39.92 49.12 6195.6 4569.78 3424.31 3026.5 4570.08 41.47 0.83 8055.43 39.7 46.9 6243.45 4609.44 3450.98 3056.14 4609.7 41.53 2.31 8086.67 39.29 47.3 6267.56 4629.24 3464.51 3070.7 4629.47 41.55 1.54 8148.85 40.11 46.38 6315.4 4668.82 3491.68 3099.67 4669.02 41.6 1.62 8209.52 38.85 46.22 6362.23 4707.29 3518.33 3127.56 4707.47 41.63 2.08 [1 EPOCH 28 . . . y ConocoPhillips NICU A-10A Measured Vertical Closure Depth Inclination Azimuth TVD Section NS EW Closure Azimuth DLS 8271.90 37.23 46.25 6411.35 4745.63 3544.92 3155.31 4745.78 41.67 2.60 8332.94 37.60 45.28 6459.84 4782.64 3570.79 3181.89 4782.77 41.70 1.14 8395.20 36.48 44.71 6509.53 4820.10 3597.31 3208.40 4820.21 41.73 1.88 8455.54 35.15 44.19 6558.46 4855.38 3622.51 3233.13 4855.48 41.75 2.26 8516.67 34.28 44.07 6608.71 4890.17 3647.50 3257.37 4890.27 41.77 1.43 8577.03 33.63 44.35 6658.78 4923.86 3671.66 3280.88 4923.95 41.78 1.11 8638.38 32.79 43.89 6710.11 4957.44 3695.78 3304.27 4957.52 41.80 1.43 8699.83 31.74 44.39 6762.07 4990.22 3719.33 3327.11 4990.30 41.81 1.76 8774.59 30.80 44.36 6825.97 5029.00 3747.06 3354.25 5029.07 41.83 1.26 8271.90 37.23 46.25 6411.35 4745.63 3544.92 3155.31 4745.78 41.67 2.60 PROJECTED SURVEY TO TOTAL DEPTH AT 8840' 8840.00 30.80 44.36 6882.15 5062.47 3771.01 3377.67 5062.53 41.85 0 ~ EPOCH 29 . . . y ConocoPhillips NICU A-10A 4.3. MUD RECORD Contractor: MI Drilling Fluids Mud Type: Flo Vis/KCL DATE DEPTH MW VIS PV YP GELS API CAKE SOLIDS SAND OILlWATER pH CL" Ca FL 08/02/03 1963 8.7 41 6 20 8/10/10 6.0 1/na 3 0 0/97 8.6 15500 200 08/03/03 2710 9.0 44 9 25 10/12/15 5.6 1/na 6 .75 0/94 9.0 14000 40 08/04/03 4740 9.4 46 13 27 8/10/13 5.0 2/na 9 .5 0/91 9.6 14500 40 08/05/03 4922 9.6 47 13 28 8/11/13 5.2 2/na 9 .5 0/91 9.3 12500 50 08/06/03 5912 9.6 52 13 28 12/20/22 6.0 2/na 9 .3 0/91 9.2 12500 50 08/07/03 6524 9.6 49 11 26 15/26/32 6.2 2/na 9 .5 0/91 9.6 12000 60 08/08/03 6770 9.7 70 14 32 18/35/40 5.5 1/na 10 .5 0/90 9.6 14500 60 08/09/03 6770 9.2 70 18 31 11/16/17 5.5 1/na 6 0 0/94 9.1 15000 50 08/10/03 7190 9.5 54 16 24 9/18/22 5.4 2/3 7 .25 1/92 8.9 14500 0 08/11/03 7755 9.5 66 20 36 12/25/32 5.5 2/na 7 .5 1/92 9.2 15000 50 08/12/03 8143 9.6 62 21 26 8/20/27 5.2 2/na 8 .5 1/91 10.0 14000 50 08/13/03 8143 9.7 81 20 28 8/21/27 5.4 2/na 8.5 .5 0/92 9.4 13000 60 08/14/03 8143 9.5 70 13 26 10/13/16 5.6 2/na 5.5 TR 0/95 8.5 27000 60 08/15/03 8420 9.6 52 16 20 6/12/15 5.6 2/na 6.5 .5 1/93 9.6 11500 80 08/16/03 8840 9.6 54 17 22 5/11/13 5.5 2/na 7.0 .5 Trc/93 9.4 12000 60 [:I EPOCH 30 . . . ~/ ConocoPhillips NICU A-10A 4.4. BIT RECORD BIT SIZE MAKE TYPE SIN JETSITFA IN OUT FEET HOURS AVE WOB CONDITION NO. ROP 9.5 HTC MXC1 5004780 1X12,3X14 1963 6770 4807 42.3 113.6 13.6 3-2-WT-N-E-16-ER- BHA 2 9.5 HTC MX-09 K87JL 3X18 6770 8143 1373 24.74 55.5 16.5 2-2-WT -A-E-IN-ER-RIG 3 9.5 HTC MXC1 5008902 1X12,3X18 8143 8840 700 15.4 45.5 18.4 1-1-WT-A-E-I-NO-TD [:I EPOCH 31 "'"/ ConocoPhillips NiCU A-10A O' 500' 1000' 1500' 2000' 2500' 3000' 3500' 4000' ¡:::- ~ 4500' :I: 5000' ~ 5500' e 5000' 5500' 7000' 7500' BOOO' 8500' 9000' .'. 9500' 10000' 1 2 3 4 5 5 7 8 9 DAn FROM START 10 11 12 13 14 15 ConocoPhillips Alaska . NCIU A-10A REPORT FOR Granny Rizek DATE July 31, 2003 TIME 12:01 am CASING INFORMATION SURVEY DATA BIT INFORMATION NO. SIZE TYPE DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW VIS FC SOL MWD SUMMARY . INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL DAILY WELLSITE REPORT DEPTH 1950 YESTERDAY 1950 24 Hour Footage 0 DEPTH INCLINATION SIN INTERVAL JETS IN OUT FOOTAGE HIGH LOW @ @ @ @ @ @ @ @ @ @ DEPTH: PV YP SO OIL HIGH LOW @ @ @ @ CHROMATOGRAPHY(ppm) AVERAGE @ @ @ @ @ @ @ @ @ @ LITHOLOGY IREMARKS LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Epoch Personel On Board= John Morris, Barry Wright Daily Cost 2575 Report by: Barry Wright . AZIMUTH HOURS AVERAGE FL MBL g EPOCH PRESENT OPERATION= Cleaning pits VERTICAL DEPTH CONDITION REASON TIBIC PULLED CURRENT AVG fI/hr amps Klbs RPM psi Gels CL- pH Ca+ CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENTBACKGROUND~VG GAS DESCRIPTION ConocoPhillips Alaska . NCIU A-10A REPORT FOR Granny Rizek DATE August 1, 2003 TIME 12:01 am CASING INFORMATION SURVEY DATA BIT INFORMATION NO. SIZE TYPE SIN DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW VIS PV FC SOL SD MWD SUMMARY . INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL DAILY WELLSITE REPORT DEPTH 1950 YESTERDAY 1950 U EPOCH PRESENT OPERATION= Picking up drill pipe 24 Hour Footage 0 DEPTH INCLINATION AZIMUTH INTERVAL JETS IN OUT FOOTAGE HIGH LOW AVERAGE @ @ @ @ @ @ @ @ @ @ DEPTH: YP FL OIL MBL HIGH LOW AVERAGE @ @ @ @ CHROMATOGRAPHY(ppm) @ @ @ 0 @ @ 0 @ @ 0 @ @ 0 @ LlTHOLOGY/REMARKS LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Pick-up drill pipe. Epoch Personel On Board= 2; John Morris, Barry Wright Daily Cost 2200 Report by: Barry Wright . HOURS VERTICAL DEPTH CONDITION REASON TIBIC PULLED CURRENT AVG ft/hr amps Klbs RPM psi Gels CL- pH Ca+ CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENTBACKGROUND~VG GAS DESCRIPTION ConocoPhillips Alaska . Tyonek Platform NCIU A-10A REPORT FOR Granny Rizek DATE August2,2003 TIME 12:01am CASING INFORMATION SURVEY DATA BIT INFORMATION NO. SIZE TYPE DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW VIS FC SOL . MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY DAILY WELLSITE REPORT g EPOCH DEPTH 1950 YESTERDAY 1950 PRESENT OPERATION= Picking up Whipstock BHA 24 Hour Footage 0 DEPTH INCLINATION INTERVAL SIN JETS IN OUT FOOTAGE HIGH LOW @ @ @ @ @ @ @ @ @ @ DEPTH: PV YP SO OIL AZIMUTH VERTICAL DEPTH CONDITION REASON T/B/C PULLED CURRENT AVG ft/h r amps Klbs RPM psi Gels CL- pH Ca+ CCI HOURS AVERAGE FL MBL HIGH LOW AVERAGE @ @ @ @ CHROMATOGRAPHY(ppm) @ @ @ @ @ @ @ @ @ @ TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENTBACKGROUND~VG LITHOLOGY IRE MARKS GAS DESCRIPTION DAILY ACTIVITY Pick up drill pipe. Circulate and condition mud. Pull out of hole, strapping pipe. Pick up pipe (17 stands). Pick up BHA. Test SUMMARY mud pumps. Pick up Whipstock BHA. Epoch Personel On Board= 2, John Morris, Barry Wright Daily Cost 2035 Report by: Barry Wright . ConocoPhillips Alaska . Tyonek Platform NCIU A-10A REPORT FOR Granville Rizek DATE Aug 03, 2003 TIME 12:01am DAILY WELLSITE REPORT g EPOCH DEPTH 1963 YESTERDAY 1911 PRESENT OPERATION= POOH 24 Hour Footage 52 SURVEY DATA CASING INFORMATION 10.75"@1910' DEPTH AZIMUTH BIT INFORMATION NO. SIZE TYPE DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 8.7 VIS FC 1/na SOL . MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL INCLINATION VERTICAL DEPTH INTERVAL CONDITION REASON SIN JETS IN OUT FOOTAGE HOURS T IB/C PULLED HIGH LOW AVERAGE CURRENT AVG 170.0 @ 1934 0.8 @ 1917 52.2 105.9 ft/hr @ @ amps 15 @ 1931 6 @ 1912 11.3 12.0 Klbs @ @ RPM @ @ psi DEPTH: 1936 90 PV 14 YP 28 FL 5.0 Gels 8/10/12 CL- 13.000 3 SO 0 OIL 0/97 MBL 0 pH 8.5 Ca+ 280 eel HIGH LOW AVERAGE 0 @ 1963 0 @ 1922 -0.0 TRIP GAS= na 0 @ 1963 0 @ 1963 0.0 WIPER GAS= na CHROMATOGRAPHY(ppm) SURVEY= na 0 @ 1963 0 @ 1963 0.0 CONNECTION GAS HIGH= na 0 @ 1963 0 @ 1963 0.0 AVG= 0 0 @ 1963 0 @ 1963 0.0 CURRENT 0 0 @ 1963 0 @ 1963 0.0 CURRENT BACKGROUND/AVG 0 0 @ 1963 0 @ 1963 0.0 None LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 90% sand, 10% clay PRESENT LITHOLOGY sand DAILY ACTIVITY SUMMARY Pick up Whipstock BHA. Run in with BHA. Test MWD. Run in hole and set Whipstock at 1910'. Sheared off and milled window from 1911' to 1963'. Pressure test window twice. Failed. POOH for new BHA. Epoch Personel On Board= 2, John Morris, Barry Wright Daily Cost 2035 Report by: Barry Wright . ConocoPhillips Alaska . Tyonek Platform DAILY WELLSITE REPORT U EPOCH NCIU A-10A REPORT FOR Granville Rizek DATE Aug 04, 2003 TIME 12:01am DEPTH 2709 YESTERDAY 1964 PRESENT OPERATION= Drilling/sliding ahead 24 Hour Footage 745 CASING INFORMATION 10.75"@1910' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 9.5 MXC1-HUGHES 5004780 1X12,3X14 1963' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 625.8 @ 2009 15.7 @ 1968 185.7 272.8 fI/hr SURFACE TORQUE @ @ amps WEIGHT ON BIT 30 @ 2233 0 @ 2401 10.2 13.7 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: 1963 MW 8.7 VIS 41 PV 6 YP 20 FL 6.0 Gels 8/10/10 CL- 15500 FC 1/NA SOL 3 SD 0 OIL 0/97 MBL 0 pH 8.6 Ca+ 200 CCI . MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 523 @ 2047 0 @ 2708 11.6 TRIP GAS= 0 CUTTING GAS 0 @ 2709 0 @ 2709 0.0 WIPER GAS= 0 CHROMATOGRAPHY(ppm) SURVEY= 0 METHANE(C-1 ) 103327 @ 2046 40 @ 1966 2204.2 CONNECTION GAS HIGH= 0 ETHANE(C-2) 34 @ 2046 1 @ 2060 0.5 AVG= 1.5 PROPANE(C-3) 0 @ 2709 0 @ 2709 0.0 CURRENT 3 BUTANE(C-4) 0 @ 2709 0 @ 2709 0.0 CURRENT BACKGROUND/AVG 1.5 PENTANE(C-5) 0 @ 2709 0 @ 2709 0.0 HYDROCARBON SHOWS INTERVAL lITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 75% Sand, 25% Clay PRESENT LITHOLOGY Sand DAILY ACTIVITY Pull out of hole. Lay down HWDP, MWD and mill assembly. Pick up new BHA. Test MWD. Trip in hole with new BHA. Orient tool SUMMARY face, run through whipstock and back. Slide to 1973'. Drilllslide from 1973' to 2391'. Circulate bottoms up - hole loaded up with cuttings. Drill slide from 2391' to a midnight depth of 2709'. Epoch Personel On Board= 4 Daily Cost 2350 Report by: Barry Wright . Conoco Phillips Alaska . Tyonek Platform DAILY WELLSITE REPORT g EPOCH NCIU A-10A REPORT FOR Granville Rizek DATE Aug 05. 2003 TIME 12:01AM DEPTH 3940 YESTERDAY 2710 PRESENT OPERATION= Tripping out of hole. 24 Hour Footage 1230 CASING INFORMATION 10.75"@1910' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBIC PULLED 1 9.5 MXC1-HUGHES 5004780 1X12,3X14 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 566.1 @ 3084 28.4 @ 3572 209.3 131.3 ft/hr SURFACE TORQUE @ @ amps WEIGHT ON BIT 33 @ 3672 0 @ 2896 11.3 7.8 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: 2710 MW 9.0 VIS 44 PV 9 YP 25 FL 5.6 Gels 10/12/15 CL- 14000 FC 1/NA SOL 6 SO .75 OIL 0/94 MBL 2 pH 9.0 Ca+ 40 CCI . MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 25 @ 3480 @ 2781 9.7 TRIP GAS= NA CUTTING GAS 0 @ 3940 0 @ 3940 0.0 WIPER GAS= 0 CHROMATOGRAPHY(ppm) SURVEY= 0 METHANE(C-1) 5100 @ 3480 158 @ 2756 1808.8 CONNECTION GAS HIGH= 0 ETHANE(C-2) 0 @ 3940 0 @ 3940 0.0 AVG= 6 PROPANE(C-3) 0 @ 3940 0 @ 3940 0.0 CURRENT 4 BUTANE(C-4) 0 @ 3940 0 @ 3940 0.0 CURRENT BACKGROUND/AVG 4 PENTANE(C-5) 0 @ 3940 0 @ 3940 0.0 HYDROCARBON SHOWS NONE INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 70% SAND, 20% CLAY, 7% SILT, 3% CARBONACEOUS SHALEICOAL PRESENT LITHOLOGY SAND DAILY ACTIVITY Drill ahead from 2709' to 2956'. Circulate out hole several times. Pull out of hole to shoe for wiper trip. Run in hole. Ream down SUMMARY last stand to 2956'. Drill ahead from 2956' to 3940'. Circulate out hole several times. Pull out of hole for wiper trip. Epoch Personel On Board= 4 Daily Cost 2275 Report by: BARRY WRIGHT . ConocoPhillips Alaska . Tyonek Platform DAILY WELLSITE REPORT ~ EPOCH NCIU A-10A REPORT FOR Mike Winfree DATE Aug 06, 2003 TIME 12:01am DEPTH 4924 YESTERDAY 3941 PRESENT OPERA TION= Wiper trip. 24 Hour Footage 983 CASING INFORMATION 10.75"@1910' DEPTH SURVEY DATA INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE 1 9.5 TYPE MXC1 - Hughes INTERVAL CONDITION REASON SIN JETS IN OUT FOOTAGE HOURS T IBIC PULLED 5004780 1X12,3X14 HIGH LOW AVERAGE CURRENT AVG 410.4 @ 4664 25.1 @ 4869 147.4 105.5 fIIhr @ @ amps 41 @ 4750 0 @ 4522 14.1 12.3 Klbs @ @ RPM @ @ psi DEPTH: PV YP FL Gels CL- SO OIL MBL pH Ca+ CCI DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW VIS FC SOL . MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 746 @ 4465 5 @ 4059 122.9 TRIP GAS= na CUTTING GAS 0 @ 4924 0 @ 4924 0.0 WIPER GAS= 18 CHROMATOGRAPHY(ppm) SURVEY= 0 METHANE(C-1) 148247 @ 4465 601 @ 4059 24874.0 CONNECTION GAS HIGH= 0 ETHANE(C-2) 82 @ 4912 1 @ 4388 7.9 AVG= 0 PROPANE(C-3) 0 @ 4924 0 @ 4924 0.0 CURRENT 71 BUTANE(C-4) 0 @ 4924 0 @ 4924 0.0 CURRENT BACKGROUND/AVG 70 PENTANE(C-5) 0 @ 4924 0 @ 4924 0.0 HYDROCARBON SHOWS INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 50% Sand, 30% Clay, 10% Siltstone, 10% Coal PRESENT LITHOLOGY Sand DAILY ACTIVITY Pull out of hole to 2527'. Run in hole to 3858'. Wash and ream down last stand, from 3858' to 3942'. Drill from 3492' to 4740'. SUMMARY Circulate and condition mud, change screens, and service rig. Drill from 4740' to 4924'. Pump sweep, circulate bottoms up, and trip out of hole for wiper trip. Work pipe through tight spot at 4165' and 4060'. Epoch Personel On Board= 4 Daily Cost 2275 Report by: Barry Wright . ConocoPhillips Alaska . Tyonek Platform DAILY WELLSITE REPORT U EPOCH NCIU A-10A REPORT FOR Mike Winfree DATE August7,2003 TIME 12:01am DEPTH 5909 YESTERDAY 4925 PRESENT OPERA TION= Circulate, wiper trip. 24 Hour Footage 984 CASING INFORMATION 10.75"@1910' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBIC PULLED 1 9.5" MXC1 - Hughes 5004780 1X12,3X14 1963' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 410.4 @ 5877 9.1 @ 5723 141.9 119.1 ft/hr SURFACE TORQUE @ @ amps WEIGHT ON BIT 31 @ 5838 0 @ 5342 16.0 21.7 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: 4924 MW 9.6 VIS 47 PV 13 YP 28 FL 5.2 Gels 8/11/13 CL- 12500 FC 2/na SOL 9 SD .5 OIL 0/91 MBL 2 pH 9.3 Ca+ 50 eel . MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 735 @ 5725 46 @ 4993 232.1 CUTTING GAS 0 @ 5909 0 @ 5909 0.0 CHROMATOGRAPHY(ppm) METHANE(C-1) 122137 @ 5725 10029 @ 4993 46119.5 ETHANE(C-2) 103 @ 5725 6 @ 4993 27.8 PROPANE(C-3) 6 @ 5725 1 @ 5770 0.1 BUTANE(C-4) 0 @ 5909 0 @ 5909 0.0 PENTANE(C-5) 0 @ 5909 0 @ 5909 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY IREMARKS TRIP GAS= na WIPER GAS= 229 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 112 CURRENT BACKGROUND/AVG 135 GAS DESCRIPTION LITHOLOGY 40% Sand, 40% Clay, 10% Siltstone, 5% Carbonaceous Shale, 5% Coal PRESENT LITHOLOGY Claystone DAILY ACTIVITY SUMMARY Trip out of hole to 3824'. Trip in hole to bottom. 229 units wiper gas. Drill ahead from 4924' to 5108'. Power failure on rig. Drill ahead from 5108' to 5293'. Repair #2 pump. Drill ahead from 5293' to a midnight depth of 5909'. Epoch Personel On Board= 4 Daily Cost 2275 Report by: Barry Wright . ConocoPhillips Alaska . Tyonek Platform NCIU A-10A REPORT FOR Mike Winfree DATE Aug 08, 2003 TIME 12:01am DAILY WELLSITE REPORT U EPOCH DEPTH 6525 YESTERDAY 5910 PRESENT OPERATION= Drilling ahead. 24 Hour Footage 615 SURVEY DATA CASING INFORMATION 10.75"@1910' DEPTH VERTICAL DEPTH BIT INFORMATION NO. SIZE 1 9.5 TYPE MXC1 - Hughes DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE INCLINATION AZIMUTH INTERVAL CONDITION REASON SIN JETS IN OUT FOOTAGE HOURS TIBIC PULLED 5004780 1X12,3X14 1963' HIGH LOW AVERAGE CURRENT AVG 219.8 @ 6039 12.7 @ 6508 93.0 51.7 ft/h r @ @ amps 35 @ 6132 0 @ 6340 17.7 3.1 Klbs @ @ RPM @ @ psi DRILLING MUD REPORT DEPTH: 5912 MW 9.6 VIS 52 PV 13 YP 28 FL 6.0 Gels 12/20/22 CL- 12500 FC 2/na SOL 9 SD .3 OIL 0/91 MBL 4 pH 9.2 Ca+ 50 CCI . MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 722 @ 6068 35 @ 6286 209.3 TRIP GAS= na CUTTING GAS 0 @ 6525 0 @ 6525 0.0 WIPER GAS= 175 CHROMATOGRAPHY(ppm) SURVEY= 0 METHANE(C-1) 140572 @ 6068 7081 @ 6286 38725.0 CONNECTION GAS HIGH= 50 ETHANE(C-2) 97 @ 6009 5 @ 6222 27.4 AVG= 50 PROPANE(C-3) 16 @ 6067 1 @ 6147 3.1 CURRENT 50 BUTANE(C-4) 7 @ 5954 1 @ 5999 0.3 CURRENT BACKGROUND/AVG 75 PENTANE(C-5) 0 @ 6525 0 @ 6525 0.0 HYDROCARBON SHOWS INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 65% Clay, 15% Sand, 10% Carbonaceous Shale, 10% Sitlstone PRESENT LITHOLOGY Claystone/siltstone DAILY ACTIVITY Pull out of hole, reaming and circulating, to 4835' for wiper trip. Run in hole to bottom. 175 units of wiper gas. Drill/slide ahead SUMMARY from 5909' to 6217'. Repair rig. Drill from 6217' to 6278'. Trip out of hole for short wiper trip (3 stands). Run in hole to bottom. Drill/slide ahead from 6278' to 6525'. Epoch Personel On Board= 4 Daily Cost 2275 Report by: Barry Wright . ConocoPhillips Alaska . Tyonek Platform DAILY WELLSITE REPORT U EPOCH NCIU A-10A REPORT FOR Mike Winfree DATE Aug 09, 2003 TIME 12:01am DEPTH 6770 YESTERDAY 6526 PRESENT OPERA TION= Tripping out of the hole. 24 Hour Footage 244 CASING INFORMATION 10.75"@1910' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T IB/C PULLED 1 9.5 MXC1 - Hughes 5004780 1X12,3X14 1963' 6770' 4807' 42.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 159.8 @ 6558 11.2 @ 6757 52.1 50.2 ft/hr SURFACE TORQUE @ @ amps WEIGHT ON BIT 33 @ 6730 @ 6629 11.1 11.6 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: 6524' MW 9.6 VIS 49 PV 11 YP 26 FL 6.2 Gels 15/26/32 CL- 12000 FC 2/na SOL 9 SO .5 OIL 0/91 MBL 12.5 pH 9.6 Ca+ 60 CCI . MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 404 @ 6592 26 @ 6766 55.8 TRIP GAS= na CUTTING GAS 0 @ 6770 0 @ 6770 0.0 WIPER GAS= na CHROMATOGRAPHY(ppm) SURVEY= 0 METHANE(C-1) 82619 @ 6592 5280 @ 6732 11857.8 CONNECTION GAS HIGH= 35 ETHANE(C-2) 68 @ 6592 6 @ 6587 12.1 AVG= 25 PROPANE(C-3) 0 @ 6770 0 @ 6770 0.0 CURRENT na BUTANE(C-4) 0 @ 6770 0 @ 6770 0.0 CURRENT BACKGROUND/AVG na PENTANE(C-5) 0 @ 6770 0 @ 6770 0.0 HYDROCARBON SHOWS INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 70% Clay, 10% Siltstone, 10% Sand, 5% Carbonaceous shale, 5% Coal PRESENT LITHOLOGY Claystone DAILY ACTIVITY Drill ahead, sliding and rotating, from 6525' to 6770'. Work stuck pipe free. Circulate mud to clean out hole. Trip out of hole SUMMARY for new biVBHA, working the pipe through tight spots. Epoch Personel On Board= 4 Daily Cost 2275 Report by: Barry Wright . ConocoPhillips Alaska . Tyonek Platform NCIU A-10A REPORT FOR Mike Winfree DATE Aug 10,2003 TIME 12:01am CASING INFORMATION 10.75"@1910 SURVEY DATA BIT INFORMATION NO. SIZE 2 9.5 TYPE MX-09 Huhges DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.7 VIS 70 PV FC 1/na SOL 10 SO . MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY Claystone DAILY WELLSITE REPORT U EPOCH DEPTH 6770 YESTERDAY 6770 PRESENT OPERATION= Tripping in hole with new bit #2. 24 Hour Footage 0 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH HOURS CONDITION T/B/C REASON PULLED SIN K87JL INTERVAL IN OUT 6770' FOOTAGE CURRENT AVG ft/hr amps Klbs RPM psi 18/35/40 9.6 CL- 15400 60 CCI JETS 3x18 HIGH LOW AVERAGE @ @ @ @ @ @ @ @ @ @ DEPTH: 6770' 14 YP 32 FL 5.5 Gels .5 OIL 0/90 MBL 12.5 pH HIGH LOW @ @ @ @ CHROMATOGRAPHY(ppm) AVERAGE @ @ @ @ @ @ @ @ @ @ Ca+ TRIP GAS= na WIPER GAS= na SURVEY= na CONNECTION GAS HIGH= na AVG= na CURRENT na CURRENT BACKGROUND/AVG na GAS DESCRIPTION LlTHOLOGY/REMARKS DAILY ACTIVITY SUMMARY Trip out of hole for new biVBHA. Lay down BHA. Test BOPE. Pick up BHA with new bit #2. Run in hole with new BHA. Test MWD tool. Cut and slip drill line. Continue to run in hole. Epoch Personel On Board= 4 Daily Cost 2275 Report by: Barry Wright . Conoco Phillips Alaska · Tyonek Platform NCIU A-10A REPORT FOR Mike Winfree DATE Aug 11,2003 TIME 12:01 a.m. CASING INFORMATION 10.75"@1910' DEPTH SURVEY DATA BIT INFORMATION NO. SIZE 2 9.5" TYPE MX-09Hughes DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.2 VIS 70 PV FC 1/na SOL 6 SO DAILY WELLSITE REPORT g EPOCH DEPTH 7192 YESTERDAY 6771 PRESENT OPERATlON= Drilling 24 Hour Footage 421 INCLINATION VERTICAL DEPTH AZIMUTH INTERVAL CONDITION REASON SIN JETS IN OUT FOOTAGE HOURS T IB/C PULLED K87JL 3x18 6770 HIGH LOW AVERAGE CURRENT AVG 232.7 @ 7174 13.7 @ 7088 82.3 76.5 fI/h r @ @ amps 71 @ 7028 @ 7089 18.7 16.2 Klbs @ @ RPM @ @ psi DEPTH: 18 YP 31 FL 5.5 Gels 11/16/17 CL- 15000 0 OIL 0/94 MBL 4 pH 9.1 Ca+ 50 CCI · MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 162 @ 7164 16 @ 7090 68.1 TRIP GAS= 395 CUTTING GAS 0 @ 7192 0 @ 7192 0.0 WIPER GAS= na CHROMATOGRAPHY(ppm) SURVEY= na METHANE(C-1) 30327 @ 7164 3311 @ 7090 13438.2 CONNECTION GAS HIGH= 15 ETHANE(C-2) 37 @ 7076 5 @ 7121 15.5 AVG= 10 PROPANE(C-3) 15 @ 7131 1 @ 7190 1.4 CURRENT 10 BUTANE(C-4) 5 @ 7192 1 @ 7185 0.1 CURRENT BACKGROUND/AVG 30 PENTANE(C-5) 0 @ 7192 0 @ 7192 0.0 HYDROCARBON SHOWS INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 60% Clay, 20% Sand, 10%Coal, 10%Siltstone PRESENT LITHOLOGY Clay DAILY ACTIVITY Displace mud from hole. Mix, circulate and condition new mud. Run in hole to bottom, washing and reaming through tight spots. SUMMARY 395 units of trip gas. Drill ahead, rotating and sliding, from 6770' to 7090'. Top drive torqued up, added graphite to mud system. Drill ahead, rotating and sliding. from 7090' to 7192'. Epoch Personel On Board= 4 Daily Cost 2275 Report by: C. Isbon · Conoco Phillips Alaska · Tyonek Platform NCIU A-10A REPORT FOR Mike Winfree DATE Aug 12,2003 TIME 00:00:01 DAILY WELLSITE REPORT U EPOCH DEPTH 7751 YESTERDAY 7193 PRESENT OPERATION= Drilling 24 Hour Footage 558' SURVEY DATA CASING INFORMATION 10.75"@1910' DEPTH AZIMUTH BIT INFORMATION NO. SIZE 2 9.5" TYPE MX-09Hughes DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.5 VIS 54 PV FC 2/3 SOL 7 SO · MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL INCLINATION VERTICAL DEPTH INTERVAL CONDITION REASON SIN JETS IN OUT FOOTAGE HOURS T IB/C PULLED K87JL 3x18 6770 HIGH LOW AVERAGE CURRENT AVG 219.8 @ 7338 5.7 @ 7561 62.2 22.0 ftlhr @ @ amps 37 @ 7538 2 @ 7275 16.8 3.0 Klbs @ @ RPM @ @ psi DEPTH: 7190' 16 YP 24 FL 5.4 Gels 9/18/22 CL- 14500 .25 OIL 1/92 MBL 5 pH 8.9 Ca+ 0 CCI HIGH LOW AVERAGE 96.9 0.0 TRIP GAS= na WIPER GAS= 90 SURVEY= na CONNECTION GAS HIGH= 25 AVG= 15 CURRENT 22 CURRENT BACKGROUND/AVG 65 431 o @ 7673 9 @ 7387 @ 7751 0 @ 7751 CHROMATOGRAPHY(ppm) @ 7673 1851 @ 7387 @ 7673 2 @ 7387 @ 7686 1 @ 7515 @ 7193 1 @ 7668 @ 7751 0 @ 7751 19292.9 14.0 3.8 0.3 0.0 88091 52 17 5 o LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 50%Clay, 20% Siltstone, 20% Sand, 10% Coal PRESENT LITHOLOGY 50% Clay, 10% Siltstone, 30% Sand, 10% Coal DAILY ACTIVITY SUMMARY Drill from 7192' to 7520', wiper trip 15 stands, drill from 7520' to 7751'. Epoch Personel On Board= 4 Daily Cost 2275 Report by: C. Isbon · Conoco Phillips Alaska . Tyonek Platform DAILY WELLSITE REPORT U EPOCH NCIU A-10A REPORT FOR Mike Winfree DATE Aug 12,2003 TIME 23:28:45 DEPTH 8143 YESTERDAY 7751 PRESENT OPERATION= trip for bit 24 Hour Footage 392 CASING INFORMATION 10.75"@1910 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBIC PULLED 2 9.5" MX-09 Hughes K87JL 3X18 6770 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 206.9 @ 8025 10.2 @ 7764 9.2 46.9 ftlhr SURFACE TORQUE @ @ amps WEIGHT ON BIT 32 @ 8036 @ 8064 2.5 9.4 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: 7755 MW 9.5 VIS 66 PV 20 YP 36 FL 5.5 Gels 12/25/32 CL- 15000 FC 12 SOL 7 SD .5 OIL 0 MBL 5 pH 9.2 Ca+ 50 CCI . MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 631 @ 8137 36 @ 8117 95 TRIP GAS= CUTTING GAS 0 @ 8143 0 @ 8143 0.0 WIPER GAS= 550 CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-1) 122568 @ 8137 6921 @ 8117 18523 CONNECTION GAS HIGH= 325 ETHANE(C-2) 93 @ 8138 6 @ 8118 15 AVG= 60 PROPANE(C-3) 28 @ 8137 2 @ 8119 6 CURRENT 325 BUTANE(C-4) 15 @ 8138 1 @ 8142 0.2 CURRENT BACKGROUND/AVG 45 PENTANE(C-5) 0 @ 8143 0 @ 8143 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY IRE MARKS GAS DESCRIPTION LITHOLOGY 20% Sand, 5% Coal, 25% Siltstone, 50% Claystone PRESENT LITHOLOGY 70%Sand, 20% Claystone, 10% Siltstone DAILY ACTIVITY Drill from 7751' to 7951', unable to rotate due high torque, circulate and wiper trip 9 stands. fix pump, work on engine, and drill SUMMARY from 7951' to 8143'. top drive malfunction, circulate out high gas, and begin pump out of hole for bit. Epoch Personel On Board= 4 Daily Cost 2275 Report by: Brian O'Fallon . Conoco Phillips Alaska . Tyonek Platform NCIU A-10A REPORT FOR Mike Winfree DATE Aug 14,2003 TIME 00:00:01 DAILY WELLSITE REPORT U EPOCH DEPTH 8143 YESTERDAY 8143 PRESENT OPERATION= tripping for bit 24 Hour Footage 0 SURVEY DATA CASING INFORMATION 10.75" @ 1910' DEPTH AZIMUTH BIT INFORMATION NO. SIZE 2 9.5" TYPE MX-09 Hughes DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.6 VIS 62 PV FC 21 SOL 8 SD . MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY INCLINATION VERTICAL DEPTH SIN K87JL INTERVAL IN OUT 6770 CONDITION T IBIC REASON PULLED JETS 3x18 FOOTAGE HOURS HIGH LOW AVERAGE CURRENT AVG @ @ ft/hr @ @ amps @ @ Klbs @ @ RPM @ @ psi DEPTH: 8143 21 YP 26 FL 5.2 Gels 8/20/27 CL- 14000 .5 OIL 1 MBL 15 pH 10.0 Ca+ 50 CCI HIGH 1230 @ @ LOW 40 @ @ AVERAGE 100 TRIP GAS= 2500 WIPER GAS= na SURVEY= na CONNECTION GAS HIGH= na AVG= na CURRENT 60 CURRENT BACKGROUND/AVG 60 CHROMATOGRAPHY(ppm) @ @ @ @ @ @ @ @ @ @ LITHOLOGY IREMARKS GAS DESCRIPTION DAILY ACTIVITY Trip from bottom 25 stands pumping out of hole, circulate out high gas, maximum 1230 units, trip to bottom and circulate, 2500 SUMMARY units of trip gas. trip out of hole pumping, maximum 275 units decreasing down to 60 units after 15 stands, continue pumping out of hole averaging 60 units, continue tripping out without pumping after 68 stands. Epoch Personel On Board= 4 Daily Cost 2275 Report by: Brian O'Fallon . Conoco Phillips Alaska . Tyonek Platform DAILY WELLSITE REPORT U EPOCH NCIU A-10A REPORT FOR Hill/Lutrick DATE Aug 15,2003 TIME 00:00:01 DEPTH 8143 YESTERDAY 8143 PRESENT OPERATION= tripping in 24 Hour Footage 0 CASING INFORMATION 10.75" @ 1910' DEPTH SURVEY DATA INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE 2 9.5" MX-09 Hughes 3 9.5" MX-C1 Hughes SIN K87JL 5008902 JETS 3x18 1x12,3x18 INTERVAL IN OUT 6770 8143 8143 FOOTAGE 1373 HOURS 30.8 CONDITION T/B/C 2-2-WT -A-E-I-ER-RIG REASON PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ ft/hr SURFACE TORQUE @ @ amps WEIGHT ON BIT @ @ Klbs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ psi DRILLING MUD REPORT DEPTH: 8143 MW 9.7 VIS 81 PV 20 YP 28 FL 5.4 Gels 8/21/27 CL- 13000 FC 21 SOL 8.5 SD .5 OIL 0 MBL 13 pH 9.4 Ca+ 60 CCI . MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 70 @ 3 @ 30 CUTTING GAS @ @ CHROMATOGRAPHY(ppm) METHANE(C-1) @ @ ETHANE(C-2) @ @ PROPANE(C-3) @ @ BUTANE(C-4) @ @ PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LlTHOLOGY/REMARKS TRIP GAS= na WIPER GAS= na SURVEY= na CONNECTION GAS HIGH= na AVG= na CURRENT na CURRENT BACKGROUND/AVG 3 GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Pull out to window and work on top drive, pull out of hole, change bit and BHA, trip in hole to window, test MWD and displaced mud, 70 units of gas, and building mud volume. Epoch Personel On Board= 4 Daily Cost 2275 Report by: Brian O'Fallon . Conoco Phillips Alaska . Tyonek Platform DAILY WELLSITE REPORT [:I EPOCH NCIU A-10A REPORT FOR Hill/Lutrick DATE Aug 16,2003 TIME 00:00:01 DEPTH 8438 YESTERDAY 8143 PRESENT OPERATlON= drilling ahead 24 Hour Footage 295 CASING INFORMATION 10.75" @ 1910' DEPTH SURVEY DATA INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T IBIC PULLED 3 9.5" MX-C1 Hughes 5008902 1X12,3X18 8143 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 160.9 @ 8352 5.7 @ 8264 49.9 23.0 ft/h r SURFACE TORQUE @ @ amps WEIGHT ON BIT 40 @ 8329 2 @ 8374 17.0 12.7 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE 1000 @ 8144 1000 @ 8438 979.6 1000 psi DRILLING MUD REPORT DEPTH: 8143 MW 9.5 VIS 70 PV 13 YP 26 FL 5.6 Gels 10/31/16 CL- 27000 FC 21 SOL 5.5 SD TR OIL 0 MBL 2 pH 8.5 Ca+ 60 CCI . MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 570 @ 8373 28 @ 8147 103.0 TRIP GAS= 300 CUTTING GAS 0 @ 8438 0 @ 8438 0.0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-1 ) 107837 @ 8373 5529 @ 8147 20943.7 CONNECTION GAS HIGH= 60 ETHANE(C-2) 96 @ 8373 4 @ 8147 18.9 AVG= 20 PROPANE(C-3) 26 @ 8373 2 @ 8304 6.4 CURRENT 60 BUTANE(C-4) 12 @ 8373 1 @ 8399 0.4 CURRENT BACKGROUND/AVG 55 PENTANE(C-5) 0 @ 8438 0 @ 8438 0.0 HYDROCARBON SHOWS INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 15% COAL, 30% SAND. 40% CLAYSTONE; 15% SILTSTONE PRESENT LITHOLOGY 40% COAL, 10% ASH FALL TUFF, 10% SAND, 40% CLAYSTONE DAILY ACTIVITY SUMMARY Finish building mud volume and trip to bottom, displace mud, 300 units of trip gas, and drill 8143' to 8438' Epoch Personel On Board= 4 Daily Cost 2275 Report by: BRIAN O'FALLON . Conoco Phillips Alaska . Tyonek Platform DAILY WELLSITE REPORT ~ EPOCH NCIU A-10A REPORT FOR HilllLutrick DATE Aug 17.2003 TIME 00:00:01 DEPTH 8842 YESTERDAY 8438 PRESENT OPERATlON= circulating and conditioning hole 24 Hour Footage 404 CASING INFORMATION 10.75"@1910' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T IBIC PULLED 3 9.5" MX-C1 Hughes 5008902 1x12,3x18 8143 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 251.1 @ 8830 18.4 @ 8451 68.8 83.7 ftlhr SURFACE TORQUE @ @ amps WEIGHT ON BIT 50 @ 8567 3 @ 8802 19.4 21.3 Klbs ROTARY RPM @ @ RPM PUMP PRESSURE 1000 @ 8438 1000 @ 8842 1002.5 1000 psi DRILLING MUD REPORT DEPTH: 8420' MW 9.6 VIS 52 PV 16 YP 20 FL 5.6 Gels 6/12/15 CL- 11500 FC 2/na SOL 6.5 SO .5 OIL MBL 9.5 pH 9.6 Ca+ 80 CCI . MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 944 @ 8497 25 @ 8609 108.4 TRIP GAS= CUTTING GAS 0 @ 8842 0 @ 8842 0.0 WIPER GAS= 220 CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-1) 164009 @ 8495 4888 @ 8609 20984.9 CONNECTION GAS HIGH= 35 ETHANE(C-2) 214 @ 8495 6 @ 8613 21.9 AVG= 20 PROPANE(C-3) 58 @ 8495 2 @ 8760 7.7 CURRENT 15 BUTANE(C-4) 42 @ 8495 1 @ 8532 1.4 CURRENT BACKGROUND/AVG 52 PENTANE(C-5) 0 @ 8842 0 @ 8842 0.0 HYDROCARBON SHOWS INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 10% Coal, 30% Sand. 20% Siltstone, 40% Claystone PRESENT LITHOLOGY 30% Sand, 20% Siltstone, 50% Claystone DAILY ACTIVITY SUMMARY Drill from 8438' to 8501', and circulate out, 945 units of gas, wiper trip while waiting on orders to drill ahead after show, trip out 15 stands, repair rig after starting trip in, finish tripping in and circulate bottoms up, maximum 195 units, and drill from 8501' to 8605', wait on orders to drill ahead after MWD confirms show, drill ahead from 8605' to 8842', total depth, circulate and condition hole, wiper trip pumping out 10 stands, circulate and condition hole, 220 units of wiper gas Epoch Personel On Board= 3 Daily Cost 2275 Report by: Brian O'Fallon .