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180-155
r • • RECEIVED STATE OF ALASKA AUG 15 7Q17 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AAVECKV 1a.Well Status: Oil❑ Gas❑ SPLUG❑ Other ❑ Abandoned CI Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development El Exploratory❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No.of Completions: r,. Service ❑ Stratigraphic Test❑ 2.Operator Name: 6. Date Comp.,Susp.,or 11510. 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska,Inc. Aband.: -/612647- • 180-155/317-196 3.Address: 7.Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 1/1/1981 50-029-20547-00 . 4a.Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 1515'FNL, 1066'FWL Sec 12,T11N, R10E, UM 2/1/1981 KRU 1C-04 . Top of Productive Interval: 9. Ref Elevations: KB:94 17.Field/Pool(s): 1716'FNL, 1414'FEL,Sec 11,T11N, R10E, UM GL:Got BF: Kuparuk River Field/Kuparuk River Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1693'FNL, 1430'FEL,Sec 11,T11N,R10E, UM 7456/6777 , ADL 25649 • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 562073 y- 5968722 Zone- 4 7575/6896 ' ALK 467 TPI: x- 559595 y- 5968501 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 559579 y- 5968524 Zone- 4 N/A 1834/1788 5.Directional or Inclination Survey: Yes ❑ (attached) No E 13.Water Depth,if Offshore: 21.Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary N/A SCOW SEP 2 7 2.011 23. CASING,LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 94 H-40 34 80 34 80 32 245 sx AS II cmt 13 3/8 72 N-80 33 2910 33 2708 17 1/2 1800 sx Fondu&300 sx AS II 9 5/8 47 L-80 30 6936 30 6258 12 1/4 800 sx Class G 7 26 K-55 6612 7545 5935 6866 8 1/2 210 sx Class G 24.Open to production or injection? Yes ❑ No I 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number; Date Perfd): 3 1/2 6986 6799/6122 ALL PERFS PLUGGED OFF 6945/6268 AIMNOoJ4ii-D 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No 0 ',iv I'E- Per 20 AAC 25.283(i)(2)attach electronic and printed information / /17 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LA- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): . N/A PLUGGED BACK Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate �► Form 10-4075/ /T--- /5/2017 V� �9 z `7 CONTINUED ON PAGE 2 RBDMS 1.6.. AUG 1 7 2017 Submit ORIGINIAL only ; • 28.CORE DATA Conventional Core(s): Yes ❑ No 2 Sidewall Cores: Yes ❑ No 2 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. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 2 Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1834 1788 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval N/A N/A information, including reports,per 20 AAC 25.071. Formation @ TPI- Formation at total depth: N/A 31. List of Attachments: Daily Operations Summary,Schematic Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, oaleontoloaical report.production or well test results.per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: J.Ohlinger Contact Name: Keith Herring // Authorized Title: Staff CTD Engineer Contact Email: Keith.E.Herring(cD_cop.com Authorized Contact Phone: 263-4321 Signature: ���- Date: e /. 7 INSTRUCTIONS General: 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. Item la: 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 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: 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. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: 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. Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. 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. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: 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. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • • 10-04 DTTMST JOBTYP SUMMARYOPS 7/2/17 DRILLING PT CTC 4,000 psi, Test PDL's and tiger tank line, wait on valve crew, phone service down, SIDETRACK Pull BPV, 0 psi WHP, PU/MU milling BHA# 1, RIH, log HRZ and K1 for depth control, tag and mill cement from 6,974' to TD 7,210', ream transition area clean, log for tie in, perform CCL, confirm TD 7,210', POOH 7/3/17 DRILLING POOH, LD pilot hole milling BHA# 1, PU/MU/RIH with HAL caliper, logged 7,205' up to 6,600', SIDETRACK POOH, LD Caliper, uploaded data, PU/MU/RIH set TOWS at 7,150', POOH, LD setting tools BHA#2, PU/MU/RIH, dry tag and mill window 7,150' TOW, BOW 7,158', drill rate hole down to 7,162'. 7/4/17 DRILLING Mill rat hole to 7171', back ream window area, dry drift clean. POOH, PUD BHA#4, PU & PD SIDETRACK BHA#5. RIH and attempt to drill build section, suspect whipstock fell down hole. POOH, LD BA#5 over a dead well, PU and run BHA#6, memory caliper indexed to BHI coil track tools. RIH w caliper, unable to get to target depth before MIT fingers opened, POOH, LD BHA#6. Reprogram tool, PU and RIH W BHA#7, memory caliper indexed to BHI coil track tool. 7/5/17 DRILLING Log cement pilot hole with MIT from 7193-7188'. POOH, LD over a dead well. PU BHA#8, SIDETRACK monobore XL whipstock, RIH and set TOW@ 7126 &245 °ROHS. POOH and LD BHA. PU BHA#9,window milling assembly, RIH and mill exit window in 7" casing. Perform reaming/dressing passes, dry drift window—clean, chase sweeps out of hole. S 1C-04 Final CTD Schematic e iI (Mtodrfled by NLti 07/3,741, I 4-12"x 3-12"9.3#L-80 EUE 8rd to surface 20"94#H-40 shoe u 80'MD "'' 3-12"Camco MMG gas Id mandrel @ 2631',3920',4982', IIM 5678',6347' 13-3/8"72#N-40 EM Baker Tie Back Sleeve @ 6612'RKB shoe @ 2910'MD <- . Baker Seal Nipple @ 6618'RKB MIN Baker Liner Hanger @ 6622'RKB i 3-1/2"Camco MMG gas lift mandrel @ 6712'RKB Baker 80-40 Seal Assy @ 6770'RKB eimin Baker PBR©6776'RKB 9-5/8"47#L-80 shoe Ma Baker FHL Packer @6799'RKB @ 6936'MDof 3-1/7'Camco DS Nipple @ 6849'RKB w/2.813"ID Midi Baker Poor Boy Overshot @ 6902'RKB Baker 3-1/2"PBR @ 6919'RKB(3.0"ID) fir_ Baker FHL packer @ 6945'RKB(3.0"ID) 3-12"Cameo D landing nipple @ 6984'RKB(6980'PDC) Milled to 2 80"ILS ---- 3-12"tubing tail @ 6986'RKB(6982'PDC) IKOP @ 7126'MD 1G0aAL1 TO=10008'MD C-sand perp 2-se-6ner ettseamare deployment sleeve 7088'-7148'MD TOL=6955'MO,BDL=10000'MD Top of slotted liner=7649'MD C-sand peds -' _ __ 7208'-7218'MD - - -c- Milled off 3-1/2"XL Tray w/OH I ,__. ---------o---f' --__c a ___c__ _c__ ___ anchor and whipstock fell down - --'-c„ hole IONTOm 1067sM0 TOWS=7198'MD 2-3/r Maned seers aluminum Iwllet BOWS=7211'MD TOL.0146'MO BOL.106301 MD 7"26#K-55 shoe @ 7545'MD • • Operations Summary (with Timelog Depths) H 1C-04 Cortoco'hiilips r Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/30/2017 6/30/2017 4.00 MIRU MOVE MOB P Continue check list,prep for Rig Move 0.0 0.0 14:00 18:00 6/30/2017 6/30/2017 2.50 MIRU MOVE MOB P Begin rig move to 1C-pad 0.0 0.0 18:00 20:30 6/30/2017 6/30/2017 2.00 MIRU MOVE MOB P Arrive on location,prep well for rig. 0.0 0.0 20:30 22:30 6/30/2017 7/1/2017 1.50 MIRU MOVE MOB P Spot sub module over well,and lay 0.0 0.0 22:30 00:00 RM 7/1/2017 7/1/2017 2.50 MIRU MOVE RURD P PJSM,follow post move check list, 0.0 0.0 00:00 02:30 secure cellar,landings,and walkways, spot shop and Halfway house. 7/1/2017 7/1/2017 2.50 MIRU MOVE RURD P MU PUTTS,nipple up stack,energize 0.0 0.0 02:30 05:00 Komey unit,get RKB's 7/1/2017 7/1/2017 0.00 MIRU WHDBOP NUND P RIG ACCEPT 0.0 0.0 05:00 05:00 7/1/2017 7/1/2017 1.30 MIRU WHDBOP RURD P Check all surface lines,perform valve 0.0 0.0 05:00 06:18 checklist. 7/1/2017 7/1/2017 2.40 MIRU WHDBOP RURD P Change out deployment line spool on 0.0 0.0 06:18 08:42 BOP 7/1/2017 7/1/2017 7.30 MIRU WHDBOP BOPE P Perform Initial BOPE test,test waivied 0.0 0.0 08:42 16:00 by Matt Herrera,250 psi Low/4,000 psi High/2,500 psi annular.Test gas alarms,Test PVT system.No Failures 7/1/2017 7/1/2017 2.50 MIRU WELLPR CTOP P PJSM,Stab coil,circulate,Test inner 0.0 0.0 16:00 18:30 reel iron 7/1/2017 7/1/2017 4.00 MIRU WELLPR CTOP P RU and trim 2,000'ft of coiled tubing 0.0 0.0 18:30 22:30 from reel#51196.length 14,956' 7/1/2017 7/1/2017 1.00 MIRU WELLPR CTOP P Test a-line,<550 m-ohms,65 ohms, 0.0 0.0 22:30 23:30 dress and ream end of coiled tubing, install CTC,pull test CTC 35 k 7/1/2017 7/2/2017 0.50 MIRU WELLPR CTOP P Rehead BHI Upper Quick,test e-line 0.0 0.0 23:30 00:00 7/2/2017 7/2/2017 1.50 MIRU WELLPR CTOP P FIll surface lines,MU/test PDL's and 0.0 0.0 00:00 01:30 tiger tank line,250 psi Low/1,500 psi High 7/2/2017 7/2/2017 0.80 MIRU WELLPR MPSP T Phone service out,paging system 0.0 0.0 01:30 02:18 working,no response call valve shop supervisor,unable to find valve crew, found crew out at 2L,wait on equipment to arrive. 7/2/2017 7/2/2017 0.50 MIRU WHDBOP MPSP P Valve shop truck on location,load/MU 0.0 0.0 02:18 02:48 lubricator and extentions,PJSM 7/2/2017 7/2/2017 0.70 MIRU WHDBOP MPSP P Stab Lubricator,PT 500 psi,pull BPV, 0.0 0.0 02:48 03:30 WHP 0 psi,RD equipment. 7/2/2017 7/2/2017 1.40 PROD1 RPEQPT PULD P PJSM,M/U BHA#1,Cement pilot 0.0 62.5 03:30 04:54 hol.e milling BHA with.9°AKO motor, D331 slick gauge mill,M/U to coil and surface test tools 7/2/2017 7/2/2017 1.70 PROD1 RPEQPT TRIP P Trip in hole,EDC open pumping 1.5 62.5 6,970.0 04:54 06:36 BPM,post slack mgmt 7/2/2017 7/2/2017 0.50 PROD1 RPEQPT DLOG P 6970 Tie in,Tag TOC @ 6984 6,970.0 6,984.0 06:36 07:06 uncorrected,P/U and close EDC, RBIH mill cement 7/2/2017 7/2/2017 0.50 PROD1 RPEQPT MILL P 6984 Mill Cement, 1.8 BPM @ 2714 6,984.0 6,995.0 07:06 07:36 PSI FS,BHP=3068,ROP=20 FPH. with 1.8K DHWOB. Page 1/20 Report Printed: 7/17/2017 III • Operations Summary (with Timelog Depths) x . :: 1C-04 1 ConocaPhi[liips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/2/2017 7/2/2017 0.10 PROD1 RPEQPT MILL P Stall at 6985,PUH.Stall again @ 6,995.0 6,975.0 07:36 07:42 6995 Possible 7"contact,PUH to tie in 7/2/2017 7/2/2017 0.20 PROD1 RPEQPT DLOG P Log K1 for-4'correction 6,975.0 6,994.0 07:42 07:54 7/2/2017 7/2/2017 0.10 PROD1 RPEQPT TRIP P PUH,RBIH to mill 6,994.0 6,990.0 07:54 08:00 7/2/2017 7/2/2017 2.50 PROD1 RPEQPT MILL P 6990,Tag and stall,PUH,Roll TF to 6,990.0 7,034.0 08:00 10:30 105R,RBIH and mill.5',then roll TF back to 285 ROHS,1.77 BPM @ 2519 PSI FS 7/2/2017 7/2/2017 0.10 PROD1 RPEQPT WPRT P Observed posible gamma spikes 7,034.0' 6,975.0 10:30 10:36 match K1 when milling by,PUH to tie in,PUW=36K 7/2/2017 7/2/2017 0.20 PROD1 RPEQPT DLOG P Log K1 for-10'correction(total 6,975.0 7,002.0 10:36 10:48 correction-14') 7/2/2017 7/2/2017 0.10 PROD1 RPEQPT WPRT P Trip in to mill 7,002.0 7,024.0 10:48 10:54 7/2/2017 7/2/2017 3.80 PROD1 RPEQPT MILL P 7024',Mill, 1.81 BPM @ 2671 PSI FS, 7,024.0 7,125.0 10:54 14:42 BHP=3119,ROP=25 with 1.7K WOB 7/2/2017 7/2/2017 2.85 PROD1 RPEQPT MILL P 7125-7155 ROP up to 39FPH slowed 7,125.0 7,210.0 14:42 17:33 back down to 30-34 FPH all with 1.7K WOB,Possibly from perf interval,TD cement Pilot Hole 7/2/2017 7/2/2017 4.30 PROD1 RPEQPT REAM P PU at 10 fpm,dry drift pilot hole, 7,210.0 6,975.0 17:33 21:51 weight bobble at 6,989',ream transition area 5 times @ 60 fph,initial wieght bobble 1 k,ream clean to 05 k, 7/2/2017 7/2/2017 1.00 PROD1 RPEQPT DLOG P Log the K1 correction of plus 1.5', 6,975.0 6,994.0 21:51 22:51 PUH Log the HRZ @ 6,810',don't correct(minus 1.25'?), log the K1 correction of plus 0.5', 7/2/2017 7/2/2017 0.25 PROD1 RPEQPT TRIP P PUH to log CCL,PUW 34 k 6,994.0 6,730.0 22:51 23:06 7/2/2017 7/2/2017 0.40 PROD1 RPEQPT DLOG P Log CCL 16 fpm,continue IH tag TD 6,730.0 7,210.0 23:06 23:30 on depth 7/2/2017 7/3/2017 0.50 PROD1 'RPEQPT TRIP P POOH,puming 1.78 bpm at 1999 psi, 7,210.0 6,810.0 23:30 00:00 open choke,performing FC @ 7,099', no-flow 7/3/2017 7/3/2017 1.00 PROD1 RPEQPT TRIP P Continue POOH 6,810.0 62.5 00:00 01:00 7/3/2017 7/3/2017 0.25 PROD1 RPEQPT OWFF P Perform flow check,(no-flow),PJSM 62.5 62.5 01:00 01:15 7/3/2017 7/3/2017 0.75 PROD1 RPEQPT PULD P LD,Milling BHA#1 62.5 0.0 01:15 02:00 7/3/2017 7/3/2017 0.50 PROD1 RPEQPT PULD P PJSM,load/MU Haliburton caliper on 0.0 0.0 02:00 02:30 skate.program tools,mark highside 7/3/2017 7/3/2017 0.50 PROD1 RPEQPT PULD 'P MU BHI Coiltrak tools,hang off in 0.0 70.3 02:30 03:00 stump,MU INJH,surface test tools, (good test) 7/3/2017 7/3/2017 1.25 PROD1 RPEQPT TRIP P RIH w/HAL caliper, filling trip sheet 70.3 6,975.0 03:00 04:15 every 1,000' 7/3/2017 7/3/2017 0.28 PROD1 RPEQPT DLOG P Log the K1 marker correction of minus 6,975.0 7,300.0 04:15 04:31 13.5' 7/3/2017 7/3/2017 0.25 PROD1 RPEQPT TRIP P Continue RIH 7,300.0 7,205.0 04:31 04:46 Page 2/20 Report Printed: 7/17/2017 • • = a Operations Summary (with Timelog Depths) , .g.� 4 1C-04 ConocoPhiilips >'_ ✓.A.a Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log • Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/3/2017 7/3/2017 0.25 PROD1 RPEQPT DLOG P Heisitate for caliper arms. 7,205.0 7,205.0 04:46 05:01 7/3/2017 7/3/2017 0.20 PROD1 RPEQPT DLOG 'P Log up at 50 fpm 7,205.0 6,598.0 05:01 05:13 7/3/2017 7/3/2017 1.30 PROD1 RPEQPT TRIP P 6598 Stop and let caliper arms close, 6,598.0 58.0 05:13 06:31 POOH 7/3/2017 7/3/2017 2.00 PROD1 RPEQPT PULD P At surface,Flow Check,Lay down 58.0 0.0 06:31 08:31 BHA#2 from dead well,Stab on and jet BOP stack 7/3/2017 7/3/2017 0.70 PROD1 WHPST PULD 'P M/U BHA#3 3 1/2"monobore XL 0.0 72.4 08:31 09:13 whipstock with OH anchor,M/U to coil and surface test 7/3/2017 7/3/2017 1.50 PROD1 WHPST TRIP P trip in hole with whipstock,EDC open 72.4 6,985.0 09:13 10:43 7/3/2017 7/3/2017 0.20 PROD1 WHPST DLOG P Log K1 for-13.5' 6,985.0 7,017.0 10:43 10:55 7/3/2017 7/3/2017 0.20 PROD1 WHPST TRIP P Continue in to setting depth 7060.75, 7,017.0 7,060.0 10:55 11:07 Close EDC.Get P/U Weight @ 38K, RBIH to set depth,Oriented to 90° LOHS,Pumps on,See tool shift @ 3993.Set down 3K-Looks good 7/3/2017 7/3/2017 1.30 PROD1 WHPST TRIP P POOH,Stop at 6966 open EDC, 7,060.0 60.0 11:07 12:25 Continue OOH 7/3/2017 7/3/2017 0.60 PROD1 WHPST PULD P Tag up at surface,Flow check well, 60.0 0.0 12:25 13:01 PJSM,Lay down BHA#3 7/3/2017 7/3/2017 1.00 PROD1 WHPST PULD P M/U BHA#4 Window milling BHA 0.0 72.0 13:01 14:01 with.6°Motor,2.80 window mill,2.79 String reamer,M/U to coil and surface test coil 7/3/2017 7/3/2017 1.40 PROD1 WHPST TRIP P Trip in hole,EDC open. 72.0 6,985.0 14:01 15:25 7/3/2017 7/3/2017 0.20 PROD1 WHPST DLOG P Log K1 for-13.5',Close EDC, 6,985.0 7,020.0 15:25 15:37 7/3/2017 7/3/2017 0.20 PROD1 WHPST TRIP P Continue trip in,Dry tag top of 7,020.0 7,150.0 15:37 15:49 whipstock @ 7150.4,Roll hole to window milling fluid 7/3/2017 7/4/2017 8.17 PROD1 WHPST MILL P PUH,Bring pumps online 1.8 BPM @ 7,150.0 7,162.0 15:49 00:00 3237 PSI FS.Make contact @ 7150.3, Start milling window.No stalls getting on tray 7/4/2017 7/4/2017 1.00 PROD1 WHPST MILL P Mill/Drill rathole, 1.8 bpm at 3,874'psi, 7,162.0 7,171.0 00:00 01:00 BHP 3,806,WHP 402,IA 0,OA 696 7/4/2017 7/4/2017 2.00 PROD1 WHPST REAM P Backream window area, 1.8 bpm at 7,171.0 7,151.0 01:00 03:00 3,664 psi,BHP 3,792,WHP 396,IA 0, OA 698,As milled,180°TF,30°R and L,dry drift clean. 7/4/2017 7/4/2017 1.00 PROD1 WHPST TRIP P POOH 7,151.0 74.3 03:00 04:00 7/4/2017 7/4/2017 1.75 PROD1 WHPST PULD P PJSM,PUD milling BHA#4,Crew 74.3 0.0 04:00 05:45 Change 7/4/2017 7/4/2017 1.50 PROD1 DRILL PULD P PJSM,PD Build BHA#5 0.0 72.3 05:45 07:15 7/4/2017 7/4/2017 1.75 PROD1 DRILL TRIP P RIH,w/build section BHA,2.5°ako 72.3 6,985.0 07:15 09:00 motor and RB HCC bi-center bit 7/4/2017 7/4/2017 0.30 PROD1 -DRILL DLOG P Log the K1 correction of minus 15'. 6,985.0 7,006.0 09:00 09:18 PUW 35 k 7/4/2017 7/4/2017 0.25 PROD1 DRILL TRIP P Continue RIH thru window 7,006.0 7,171.0 09:18 09:33 Page 3/20 Report Printed: 7/17/2017 • • fr " j Operations Summary (with Timelog Depths) 1 - " 46 ,, 1C-04 i ConocoPhitliprs Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/4/2017 7/4/2017 2.50 PROD1 DRILL DRLG P Working on TF,(a lot of interference) 7,171.0 7,211.0 09:33 12:03 OBD, 1.8 bpm at 3,700'psi,BHP 3,825. 7/4/2017 7/4/2017 0.25 PROD1 DRILL DRLG T PUH,perform check survey from top 7,211.0 7,198.6 12:03 12:18 of WS down to 7,193',no change in INC 7/4/2017 7/4/2017 0.25 PROD1 DRILL DRLG T Attempt to reach bottom, 1.6 bpm at 7,198.6 7,198.6 12:18 12:33 3,400 psi,High vibrations level 3-4. stalling motor at 7,198.6 7/4/2017 7/4/2017 0.25 PROD1 DRILL DLOG T Log the for the RA,couldn't see RA, 7,198.6 6,964.0 12:33 12:48 WS might of went down hole,PUH above WS 7/4/2017 7/4/2017 0.50 PROD1 DRILL WAIT T Wait on orders 6,964.0 6,964.0 12:48 13:18 7/4/2017 7/4/2017 1.25 PROD1 RPEQPT TRIP T POOH,for caliper run 6,964.0 72.3 13:18 14:33 7/4/2017 7/4/2017 0.50 PROD1 RPEQPT OWFF T Check well for flow,PJSM 72.3 72.3 14:33 15:03 7/4/2017 7/4/2017 0.75 PROD1 RPEQPT PULD T LD Build BHA#5 72.3 0.0 15:03 15:48 7/4/2017 7/4/2017 0.50 PROD1 RPEQPT SVRG T Service choke A and B,and Out MM 0.0 0.0 15:48 16:18 7/4/2017 7/4/2017 0.80 PROD1 RPEQPT WAIT T WOH 0.0 0.0 16:18 17:06 7/4/2017 7/4/2017 1.00 PROD1 RPEQPT PULD T PU BHA#6,HES,'Sondex MIT', 0.0 70.0 17:06 18:06 indexed to BHI coiltrack. 7/4/2017 7/4/2017 1.10 PROD1 RPEQPT TRIP T RIH,adjust RIH speed to 115 fUmin 70.0 6,990.0 18:06 19:12 and did not slow for jewelry due to memory tool program setting 7/4/2017 7/4/2017 0.20 PROD1 RPEQPT DLOG T Attempt toTie into the K1,ran out of 6,990.0 7,008.0 19:12 19:24 time,fingers opening 19:17,stop RIH/ logging. 7/4/2017 7/4/2017 1.40 PROD1 RPEQPT TRIP T POOH,PU Wt 32 k lbs. 7,008.0 70.0 19:24 20:48 7/4/2017 7/4/2017 0.60 PROD1 RPEQPT TRIP T Flow check-good,PJSM,LD BHA 70.0 0.0 20:48 21:24 #6,memory caliper,over a dead well. 7/4/2017 7/4/2017 0.70 PROD1 RPEQPT TRIP T Reconfigure MIT for 145 min, 135 min 0.0 70.0 21:24 22:06 from HES to Nabors hand off. Function test in shed,PU BHA#7 and run over a dead well,stab on,bump up,set counters. 7/4/2017 7/4/2017 1.10 PROD1 RPEQPT TRIP T RIH, 70.0 6,985.0 22:06 23:12 7/4/2017 7/4/2017 0.20 PROD1 RPEQPT DLOG T Tie into the K1 for a-15.5'correction. 6,985.0 7,017.0 23:12 23:24 7/4/2017 7/5/2017 0.60 PROD1 RPEQPT TRIP T Continue to RIH to logging dept, 7,017.0 7,193.0 23:24 00:00 bottom of tool,7193,fingers @ 7188'. Wait for 26 min for fingers to open up. 7/5/2017 7/5/2017 0.20 PROD1 RPEQPT TRIP T Continue to RIH to logging dept, 7,017.0 7,193.0 00:00 00:12 bottom of tool,7193,fingers @ 7188'. Wait for 26 min for fingers to open up. 7/5/2017 7/5/2017 0.30 PROD1 RPEQPT DLOG T POOH @ 50 ft/min,logging w MIT, 7,193.0 6,600.0 00:12 00:30 park for 2 min. 7/5/2017 7/5/2017 1.00 PROD1 RPEQPT TRIP T Continue to POOH. 6,600.0 70.0 00:30 01:30 Page 4120 Report Printed: 7/17/2017 f • • 111 �' Operations Summary (with Timelog Depths) Air a, , 1C-04 CoocoPhi ips i.. et Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/5/2017 7/5/2017 0.50 PROD1 RPEQPT PULD T @ surface,flow check,PJSM,LD 70.0 0.0 01:30 02:00 BHA#7. Clean floor 7/5/2017 7/5/2017 1.00 PROD1 RPEQPT PULD T PJSM,PU BHA#8,BOT 3.5" 0.0 73.0 02:00 03:00 Monobore Whipstock XL W OH anchors,stab on,open EDC. 7/5/2017 7/5/2017 0.20 PROD1 RPEQPT CTOP T Reset BHI database 73.0 73.0 03:00 03:12 7/5/2017 7/5/2017 1.70 PROD1 RPEQPT TRIP T RIH W whipstock. 73.0 6,952.0 03:12 04:54 7/5/2017 7/5/2017 PROD1 RPEQPT WAIT T Wait for memory data processing 6,952.0 6,990.0 04:54 04:54 7/5/2017 7/5/2017 0.20 PROD1 RPEQPT TRIP T Tie into the K1 for minus 13.5' 6,990.0 7,006.0 04:54 05:06 7/5/2017 7/5/2017 0.30 PROD1 RPEQPT WPST T Contin to RIH wwhipstock, 7,006.0 7,136.8 05:06 05:24 7/5/2017 7/5/2017 0.25 PROD1 RPEQPT WPST T PUW 35 k,Close EDC,bring pump on 7,136.8 7,126.0 05:24 05:39 -line,shear at 5,200 psi,5 k DHWOB, set down additional 2 k DHWOB 7/5/2017 7/5/2017 1.00 PROD1 RPEQPT TRIP T PUW 35k,POOH,w/tripsheet and 7,126.0 60.3 05:39 06:39 manual straps 7/5/2017 7/5/2017 0.50 PROD1 RPEQPT OWFF T At surface,check well for flow,PJSM 60.3 60.3 06:39 07:09 laying done BHA 7/5/2017 7/5/2017 0.50 PROD1 RPEQPT PULD T LD BHA#8 60.3 0.0 07:09 07:39 7/5/2017 7/5/2017 0.50 PROD1 WHPST PULD T PU/MU window milling BHA#9,move 0.0 74.3 07:39 08:09 INJH over MU to Coiltrak tools, surface test was good,MU lubricator, tag up,reset counters 7/5/2017 7/5/2017 1.20 PROD1 WHPST TRIP T RIH,with Milling BHA#9 second 74.3 6,990.0 08:09 09:21 attempt to make casing exit 7/5/2017 7/5/2017 0.25 PROD1 WHPST DLOG T Log the K1 marker correction of minus 6,990.0 7,008.0 09:21 09:36 14.5',PUW 33 k 7/5/2017 7/5/2017 0.25 PROD1 WHPST TRIP T Continue IH 7,008.0 7,126.0 09:36 09:51 7/5/2017 7/5/2017 3.75 PROD1 WHPST MILL T Dry tag TOWS,PUH,bring pump up 7,126.0 7,128.0 09:51 13:36 to 1.8 bpm at 3,375 psi,BHP 3468, WHP O,IA O,OA 476 7/5/2017 7/5/2017 5.20 PROD1 WHPST MILL T OB Milling window 1.8 bpm at 3505 7,128.0 7,146.5 13:36 18:48 psi,BHP 3,452,WHP 0, IA 0,OA 611. Bottoms up sample confirmed sand and dark dirt,no evidence of cement. Last 4 sample collected had increasing percentages of dirt vs metal. 7/5/2017 7/5/2017 1.60 PROD1 WHPST REAM T Start reaming passes as milled(245° 7,128.0 7,146.5 18:48 20:24 ROHS)plus lx @ 180&+/-30 from as milled. Low WOB as well as minimal mnotor work,time out and send 5x5 sweeps. Dry drift-25 ft/min -Clean. 7/5/2017 7/5/2017 1.20 PROD1 WHPST TRIP T POOH chasing sweeps to surface 7,146.0 55.0 20:24 21:36 7/5/2017 7/6/2017 2.40 PROD1 WHPST PULD T Bump up,space out,PJSM,PUD&LD 55.0 0.0 21:36 00:00 BHA#9, 7/6/2017 7/6/2017 1.00 PROD1 WHPST PULD T Continue to PUD and LD BHA#9. 0.0 0.0 00:00 01:00 Speed mill 2.80 go,2.79 no go,string reamer 2.80 no go. Good whorl pattern on bottom of speed mill. Page 5/20 Report Printed: 7/17/2017 • • Operations Summary (with Timelog Depths) - ` X 1C-04 r ConocoPhsitlips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Tittle Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/6/2017 7/6/2017 1.20 PROD1 DRILL PULD T PU&PD BHA#10,build drilling BHA, 0.0 70.0 01:00 02:12 2.5°AKO,Break open return micromotion,snake,flush,and blow down.inspoect pack offs,stab on, bump up,reset counters 7/6/2017 7/6/2017 1.60 PROD1 DRILL TRIP T RIH 70.0 6,980.0 02:12 03:48 7/6/2017 7/6/2017 0.20 PROD1 DRILL DLOG T Tie into the K1 for-15'correction 6,980.0 7,000.0 03:48 04:00 7/6/2017 7/6/2017 0.20 PROD1 DRILL TRIP T Wt Ck29 k lbs,Close EDC,Continue 7,000.0 7,146.5 04:00 04:12 to RIH. 7/6/2017 7/6/2017 1.00 PROD1 DRILL DRLG P Set rate 1.73 bpm in, 1.73 bpm out, 7,147.0 7,200.0 04:12 05:12 Free spin diff 524 psi CT 4073 OBD,CTWt15.5klbs,WOB 1.35k lbs,ROP 40 ft/hr. Pick up and restart,Pu Wt=31 k lbs, set rate 1.8 bpm,CT 4032 psi,free spin 511 psi. OBD,CT 3940 psi,CT Wt 13 k lbs, WOB 1.2 k lbs,ROP 35 ft/hr 7/6/2017 7/6/2017 0.20 PROD1 DRILL TRIP P PU 30 k lbs PUH to K1 7,200.0 6,975.0 05:12 05:24 7/6/2017 7/6/2017 0.30 PROD1 DRILL DLOG P Log K1 fora correction plus 1.5',Log 6,975.0 7,164.0 05:24 05:42 the RA @ 7132.5' Offical Window Depths TOW 7125.5' BOW 7130.5' RA 7132.5' 7/6/2017 7/6/2017 0.25 PROD1 DRILL TRIP P RIH 7,164.0 7,200.0 05:42 05:57 7/6/2017 7/6/2017 2.50 PROD1 DRILL DRLG P BOBD 1.8 bpm at 3850 psi,BHP 7,200.0 7,322.0 05:57 08:27 3970,WHP 436,IA 0,OA 675 7/6/2017 7/6/2017 0.20 PROD1 DRILL WPRT P Geo Wiper 7,322.0 7,322.0 08:27 08:39 7/6/2017 7/6/2017 0.20 PROD1 DRILL DRLG P BOBD 1.8 bpm at 4,106 psi,BHP 7,322.0 7,330.0 08:39 08:51 4,372,WHP 328,IA 0,OA 673 7/6/2017 7/6/2017 1.25 PROD1 DRILL TRIP P TD Build section,pump 10x10 sweep, 7,330.0 72.2 08:51 10:06 POOH,open ECD @ 6,960' 7/6/2017 7/6/2017 0.25 PROD1 DRILL SFTY P At surface,space out,PJSM 72.2 72.2 10:06 10:21 7/6/2017 7/6/2017 1.00 PROD1 DRILL PULD P PUD,Build Section BHA#10 72.2 0.0 10:21 11:21 7/6/2017 7/6/2017 1.25 PROD1 DRILL PULD P PD lateral BHA#11,surface test tools, 0.0 78.2 11:21 12:36 good test 7/6/2017 7/6/2017 1.25 PROD1 DRILL TRIP P Tag up reset counters,RIH 78.2 6,985.0 12:36 13:51 7/6/2017 7/6/2017 0.25 PROD1 DRILL DLOG P Log the K1 marker correction of minus 6,985.0 7,008.0 13:51 14:06 16.5',PUW32k 7/6/2017 7/6/2017 0.25 PROD1 DRILL TRIP P Continue IH 7,008.0 7,330.0 14:06 14:21 7/6/2017 7/6/2017 1.90 PROD1 DRILL DRLG P BOBD 1.8 bpm at 3650 psi,BHP 7,330.0 7,458.0 14:21 16:15 3896,WHP 294,IA 0,OA 639 7/6/2017 7/6/2017 0.25 PROD1 DRILL WPRT T PUH,BHI computer locked up,reboot 7,458.0 7,458.0 16:15 16:30 system computers. 7/6/2017 7/6/2017 1.00 PROD1 DRILL DRLG P BOBD, 1.76 bpm,CT Wt 9.6 k lbs, 7,458.0 7,523.0 16:30 17:30 WOB 2.57 k lbs,ROP 96 ft/hr. Taking influx,pinched in choke. Page 6/20 Report Printed: 7/17/2017 # ` '* Operations Summary (with Timelog Depths) .a�4 rryr > . k4 1C-04 CanocaPhi[i9ps r'?� Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/6/2017 7/6/2017 4.00 PROD1 DRILL DRLG P Drilling ahead,Well worc still showing 7,523.0 7,704.0 17:30 21:30 pit gains,pit sensors showing stable to slight loss,shaker losses?,continue to monitor and adjust choke. Hard stall @ 7557'35k lbs PU,worked through and ROP increased to 140 ft/hr,sailed 5x5 sweep,Drill ahead to hard stall @ 7571'PU Wt 35 k lbs.multiple hard spots,near stalls to 7580'.Pull short BHA wiper(100')as sweeps exit,PU 37 k lbs. 6 stalls total,clean drilling with lower ROPs's-40-30ft/hr. Pump 5x5,Short(100')BHA wiper as sweeps transits the open hole,PU Wt 32k lbs, BOBD,ROP over interval on bottom 45 ft/hr 7/6/2017 7/7/2017 2.50 PROD1 DRILL DRLG P OBD,free spin diff 1155 psi,CT Wt, 7,704.0 7,860.0 21:30 00:00 12.45k lbs,WOB 2.17 k lbs,ROP 70 k lbs,annular 4410 psi,Continue to monitor return rate,suspect MM out may be reading 0.2 bpm high, Stall@ 22:10-7729'appears to have surged MM out and cleared up flow issue. Another stall 7779',PU 36 k lbs.looks like it took a drink,7822',losses start @-0.25 bpm. healed in minutes by 7833'. ROP over interval 62 ft/hr 7/7/2017 7/7/2017 1.70 PROD1 DRILL DRLG P OBD,Drilling break at 7898',ROP 7,860.0 8,006.0 00:00 01:42 -150-120 ft/hr. CT Wt 9.73 k lbs, WOB 1.8k lbs,Annular 4498,returns 1 for 1. Sent 5x5 sweeps,losses started at 7944'climbed to 0.75 bpm @ 7977' Multiple stalls @ 7979',PU Wt 33 k lbs.sweeps out the bit. Losses healed slightly to.5-.6 bpm. ROP over interval 85 fUmin 7/7/2017 7/7/2017 0.60 PROD1 DRILL WPRT P Wiper-850'. PU slowly to allow 8,006.0 7,170.0 01:42 02:18 sweeps to exit the well.PU Wt 27 k lbs,slow for missed log data,7473- 7422'. continue up hole,slow to 5 ft/min to calibrate annular friction loss. attempt to target 11.4 ppm at window, taking 0.25 bpm influx,pinch in choke for 1-1. Pump rate 1.81 bpm in,1.77 bpm out, 8.74 ppg in 8.79 ppg out, annular 4050 psi,choke pressure 550 psi. 7/7/2017 7/7/2017 0.40 PROD1 DRILL WPRT P RBIH,following new tripping schedule 7,170.0 8,006.0 02:18 02:42 for 12.3 ppg 7/7/2017 7/7/2017 2.80 PROD1 DRILL DRLG P Rate 1.80 bpm in, 1.80 bpm out,Free 8,006.0 8,262.0 02:42 05:30 spin diff 1150 psi,CT 5200 psi OBD,CT Wt 9.36 k lbs,WOB 2.30 k lbs,ROP 104 ft/hr.stall 8066,PU 32 k lbs,stall 8197,32k lbs. 7/7/2017 7/7/2017 0.65 PROD1 DRILL WPRT P 100'wiper up hole 8,262.0 8,262.0 05:30 06:09 7/7/2017 7/7/2017 3.36 PROD1 DRILL DRLG P BOBD 1.8 bpm at 5,258 psi,BHP 8,262.0 8,400.0 06:09 09:30 4303,WHP 477,IA 0,OA 814 Page 7/20 Report Printed: 7/17/2017 i i t4 Operations Summary (with Timelog Depths) • ,'',',.w. , 1C-04 ConocoPhilips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/7/2017 7/7/2017 0.50 PROD1 DRILL WPRT P Wiper up hole for tie in and pressure 8,400.0 7,150.0 09:30 10:00 check,PUW 30 k 7,180'Choke Calibration Pump rate=1.8 bpm Return rate=1.79 bpm MW IN=8.78 ppg MW Out=8.84 ppg Annular Press.=4146 psi Choke Pressure=585 psi WHP=545 psi 7/7/2017 7/7/2017 0.15 PROD1 DRILL DLOG P Log the RA correction of plus 2.0' 7,150.0 7,169.0 10:00 10:09 7/7/2017 7/7/2017 0.15 PROD1 DRILL WPRT P PUH above window,open ECD 7,169.0 6,978.0 10:09 10:18 7/7/2017 7/7/2017 0.45 PROD1 DRILL CIRC P Pumping 2.02 bpm at 5000 psi,circ 6,978.0 6,978.0 10:18 10:45 bottoms up, 7/7/2017 7/7/2017 0.60 PROD1 DRILL WPRT P Shut down pump,close choke,after 6,978.0 6,978.0 10:45 11:21 pressure check still trending down on pressure,go back to holding 11.4 ppg at the window. 3792 psi=11.43 3868 psi=11.67 3849 psi=11.61 3820 psi=11.55 7/7/2017 7/7/2017 3.25 PROD1 DRILL TRIP P Close EDC,RIH to bottom 6,978.0 8,400.0 11:21 14:36 7/7/2017 7/7/2017 0.25 PROD1 DRILL DRLG P BOBD 1.8 bpm at 5,000 psi,BHP 8,400.0 8,558.0 14:36 14:51 4032,WHP 257, IA 0,OA 768 7/7/2017 7/7/2017 0.25 PROD1 DRILL WPRT P Wiper up hole,PUW 34 k 8,558.0 8,058.0 14:51 15:06 7/7/2017 7/7/2017 0.25 PROD1 DRILL WPRT P Wiper back in hole RIW 14 8,058.0 8,558.0 15:06 15:21 7/7/2017 7/7/2017 1.90 PROD1 DRILL DRLG P BOBD, 1.8 bpm at 5050 psi,BHP 8,558.0 8,763.0 15:21 17:15 3992,WHP 191, IA 0,OA 832 7/7/2017 7/7/2017 5.60 PROD1 DRILL DRLG P Quick pick up to get restarted,PU Wt 8,763.0 8,982.0 17:15 22:51 39 k lbs. RBIH,OBD,pump 5x5 sweep. CT Wt 9 k lbs,WOB 1.36 k lbs,ROP 139 ft/hr. Encountered 0.35 bpm losses @ 8792',ROP dropped to -20 ft/hr. Losses fluctuating between 0.3-0.6 bpm. Losses healed to-0.1 bpm.Pumped another 5x5 and regained string weight,neutral to+6 k lbs. WOB 1.52 K ROP 90 ft/hr. PU to restart 3x,PU Wt's 37 k lbs,Pumped 5x5,Allow sweep to exit the bit. CT Wt-2.0 klbs,WOB 2.3 k lbs,ROP 30 ft/hr,CT 4911 psi,@ 1.75 bpm in, 1.68 bpm out.CT Wt 8.8 k lbs,as high vis exits, ROP over interval drilled 39 ft/hr 7/7/2017 7/7/2017 0.30 PROD1 DRILL WPRT P Wiper trip 850',PU Wt 34k lbs. Saw 8,982.0 8,150.0 22:51 23:09 slight pulls at 8700 and 8650'. 7/7/2017 7/7/2017 0.30 PROD1 DRILL WPRT P RBIH,CT RIH Wt 12.2 k lbs,clean trip 8,150.0 8,982.0 23:09 23:27 Page 8/20 Report Printed: 7/17/2017 • • 1 06 Operations Summary (with Timelog Depths) lis 1 1 1C-04 conochiilips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/7/2017 7/8/2017 0.54 PROD1 DRILL DRLG P 1.78 bpm in, 1.70 bpm out,CT 4872 8,982.0 9,031.0 23:27 00:00 psi, free spin diff 956 psi. OBD,CT Wt 7.5 k lbs,WOB 1.64 k lbs,ROP 85 ft/min. CT weight dropped to-3 k lbs,w 2.3 k lbs WOB after drilling 70 feet. Organized mud swap.ROP over interval drilled 89 ft/hr 7/8/2017 7/8/2017 2.50 PROD1 DRILL DRLG P Drilling ahead, 9,031.0 9,147.0 00:00 02:30 CT Wt 0 k lbs,WOB 1.67 k lbs,ROP 35 fUhr,conver to 2 pit system,start exporting mud outside. Multiple PU's to restart,PU Wt 32-38 k lbs. new' mud down the coil @ 1:39. New mud @ the bit 9119'. ROP over interval on bottom 46 ft/hr 7/8/2017 7/8/2017 2.00 PROD1 DRILL DRLG P New mud all the way around,off 9,147.0 9,230.0 02:30 04:30 bottom CT 4580 psi,free spin diff 1070 psi CT Wt 0.52,WOB 1.99 k lbs,ROP 150-20 ft/hr Ct 4866 psi,Annular 3877 psi,WH 127 psi. ROP over interval 41 ft/hr 7/8/2017 7/8/2017 3.00 PROD1 DRILL DRLG P OBD,CT 5044 psi,CT Wt 6 k lbs, 9,230.0 9,350.0 04:30 07:30 WOB 1.7 k lbs, ROP 81 ft/hr 7/8/2017 7/8/2017 0.75 PROD1 DRILL WPRT P Wiper up hole,PUW 34 k,perform jog 9,350.0 7,150.0 07:30 08:15 back in hole 100'from EOB 7/8/2017 7/8/2017 0.25 PROD1 DRILL DLOG P Log the RA marker correction of plus 7,150.0 7,168.0 08:15 08:30 3.5', 7/8/2017 7/8/2017 0.85 PROD1 DRILL WPRT P Wiper back in hole,RIW 15 k 7,168.0 9,350.0 08:30 09:21 7/8/2017 7/8/2017 1.00 PROD1 DRILL DRLG P BOBD, 1.8 bpm at 4,931 psi,Diff=880 9,350.0 9,395.0 09:21 10:21 psi,BHP 4,103,WHP 323, IA 0,OA 814,CTSW=4k,DHWOB=2.5 k,ROP 48 mph, 7/8/2017 7/8/2017 0.25 PROD1 DRILL WPRT P "**100%losses"*,PUW 50 k,PUH 9,395.0 9,295.0 10:21 10:36 100' 7/8/2017 7/8/2017 0.25 PROD1 DRILL WPRT P RBIH 9,295.0 9,395.0 10:36 10:51 • 7/8/2017 7/8/2017 2.50 PROD1 DRILL DRLG P BOBD, 1.8 bpm at 3840 psi,BHP 9,395.0 9,625.0 10:51 13:21 2916,WHP 0, IA 0,OA 820, CTSW=15 k,DHWOB=1.2 k, ROP=100 fph 7/8/2017 7/8/2017 1.10 PROD1 DRILL DRLG P OBD,1.77 bpm at 4,248 psi,BHP 9,625.0 9,701.0 13:21 14:27 3,301,WHP 101,IA 0,OA 757, CTSW=0,DHWOB=1.8 k,ROP=83 fph 7/8/2017 7/8/2017 0.75 PROD1 DRILL WPRT P Wiper up hole, PUW 50 k 9,701.0 8,400.0 14:27 15:12 7/8/2017 7/8/2017 0.50 PROD1 DRILL WPRT P Wiper back in hole RIW 15 k 8,400.0 9,701.0 15:12 15:42 7/8/2017 7/8/2017 1.00 PROD1 DRILL DRLG P BOBD, 1.8 bpm at 4,594 psi,BHP 9,701.0 9,782.0 15:42 16:42 3,597,WHP 342,IA 0,OA 767, CTSW=6.2 k,DHWOB=1.8 k, ROP=77 fph 7/8/2017 7/8/2017 2.30 PROD1 DRILL DRLG P OBD, 1.8 bpm at 4318 psi,BHP 9,782.0 9,870.0 16:42 19:00 3,569,WHP 435,IA 0,OA 748, CTSW=minus 2 k,DHWOB=1.7 k, ROP=69 fph,pick ups to get restarted, 55k increasing to 59k lbs. Page 9/20 Report Printed: 7/17/2017 • • �g Operations Summary (with Timelog Depths) /,, id i°. ''`:'^) 1C-04 Con°C°'hiiiips s Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/8/2017 7/8/2017 2.20 PROD1 DRILL WPRT P PU Wt 53 k lbs,pull wiper to window, 9,870.0 6,960.0 19:00 21:12 2750'trip. Saw some negative WOB spikes from 9539 to 7992 and agian in the build at 7155'as well as slight coil weight overpulls from 9492-9136 around the loss zone. 7/8/2017 7/8/2017 0.30 PROD1 DRILL WPRT P Line up down the back side and pump 6,960.0 6,900.0 21:12 21:30 40 bbls stock power pro flush and 48 bbls lubed(1.5%)beaded(2 ppb) stock power pro 7/8/2017 7/8/2017 0.40 PROD1 DRILL DLOG P RBIH,attempt to log the K1,some 6,960.0 7,078.0 21:30 21:54 confusion with possibly a large correction,RIH to log RA tag for a+9 'correction. 7/8/2017 7/8/2017 1.00 PROD1 DRILL TRIP P RBIH, carried 16-13 k CT weight until 7,078.0 9,870.0 21:54 22:54 , —9100'where there's a sharp turn uphill. RIH Wt 8 kl bs, 7/8/2017 7/9/2017 1.10 PROD1 DRILL DRLG P Off bottom,1.80 bpm in,closed choke, 9,870.0 9,906.0 22:54 00:00 free spin diff 1000 psi,CT 4440 psi, annular 3910 psi. OBD,CT Wt 0 k lbs,WOB 2 k lbs, ROP 90 ft/hr. Drill 10 feet,PU Wt 52 k lbs. Seeing some 4's on vibration @ 9888'. PU's 52 climbing to 62 k lbs,five to ten minutes OBD,for each PU. ROP over interval 33 ft/hr 7/9/2017 7/9/2017 2.00 PROD1 DRILL DRLG P At 9907'PU 75k x2,cycled pipe to 9,906.0 9,951.0 00:00 02:00 80k pulled free. Drill ahead pumping 5 bbl tubed sweeps for every—60 bbls of power pro lite pumped. Able to stay on bottom while lubes are coming out and for—10-20 min after. Lube up active system to 1%. ROP over interval 22 ft/hr. 7/9/2017 7/9/2017 0.80 PROD1 DRILL DRLG P Drilled into something hard @ 9951'. 9,951.0 9,960.0 02:00 02:48 WOB 3.5 k CT Wt 0, 1300 psi diff. ROP over interval 11 ft/hr. 7/9/2017 7/9/2017 1.20 PROD1 DRILL DRLG P Drilling break @ 9960, 1.80 bpm, CT 9,960.0 10,024.0 02:48 04:00 Wt 5.2 k lbs,WOB 2.3 k lbs,ROP 110 ft/hr,CT 4846 psi,annular 3797 psi. Resistivity climbed significantly after 9940'.Sending 5 bbls beaded pills as necisary. Weight transfer vastly improved. ROP over interval 53 ft/hr 7/9/2017 7/9/2017 1.80 PROD1 DRILL DRLG P ' OBD,CT Wt 0 klbs,WOB 2.7 k lbs, 10,024.0 10,090.0 04:00 05:48 ROP 60 ft/hr,CT 4885 psi,WH 750 psi. ROP over interval 38t/hr 7/9/2017 7/9/2017 0.25 PROD1 DRILL WPRT P Geo wiper up hole,PUW 41 k 10,090.0 8,975.0 05:48 06:03 7/9/2017 7/9/2017 0.25 PROD1 DRILL WPRT P Geo wiper back in hole,RIW 13 k 8,975.0 10,090.0 06:03 06:18 7/9/2017 7/9/2017 4.70 PROD1 DRILL DRLG P BOBD, 1.8 bpm at 4,500 psi, 10,090.0 10,400.0 06:18 11:00 DIFF=820 psi,BHP 3748,WHP 720, IA 0,OA 817,CTSW=minus 2 k, DHWOB=1.4 k,ROP 92 fph DHD,here bleed down OA from 817 psi-298 psi. 7/9/2017 7/9/2017 0.50 PROD1 DRILL WPRT P Wiper up hole,PUW 38 k,Pulled 10,400.0 9,400.0 11:00 11:30 heavy at fault/loss zone 9,400 Page 10/20 Report Printed: 7/17/2017 • • sOf Operations Summary (with Timelog Depths) a. 1C-04 -,,...- ConoccettiHips Al.xk+b Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (5KB) End Depth(ftKB) 7/9/2017 7/9/2017 0.50 PROD1 DRILL WPRT P Wiper back in hole,RIW 8 k • 9,400.0 10,400.0 11:30 12:00 7/9/2017 7/9/2017 2.00 PROD1 DRILL DRLG P BOBD, 1.8 bpm at 4,100 psi,BHP 10,400.0 10,595.0 12:00 14:00 3615,WHP 744,IA 0,OA 330, CTSW=minus 4 k,DHWOB=1 k,ROP 30 fph Pumping 10 bbl beaded pills frequently 7/9/2017 7/9/2017 0.75 PROD1 DRILL DRLG P OBD, 1.5 bpm at 3,486 psi,BHP 10,595.0 10,602.0 14:00 14:45 3637,WHP 690, IA 0,OA 331, CTSW=3.3 k,DHWOB=2.1 k, ROP=38 fph 7/9/2017 7/9/2017 2.60 PROD1 DRILL DRLG P OBD,1.8 bpm at 4,079 psi,BHP 10,602.0 10,675.0 14:45 17:21 3,815,WHP 720, IA 0,OA 331, CTSW=3.3 k,DHWOB=1.9 k, ROP=16 fph Drilled into hot gamma, 169 API. Called TD 7/9/2017 7/9/2017 1.30 PROD1 DRILL WPRT P PUH wiping to window,PU 42 k lbs. 10,675.0 7,142.0 17:21 18:39 Pull heavy at 9455',CT weight up to 55k lbs,clean running is 35k lbs,RBIH to 9470'PU Wt 58 k pull clean until 9415,then 44k lbs,continue to POOH. 7333',motor work and annular fluctuations, 7/9/2017 7/9/2017 0.20 PROD1 DRILL DLOG P Tie into the RA tag for a+15.5' 7,142.0 7,155.0 18:39 18:51 correction. 7/9/2017 7/9/2017 0.40 PROD1 DRILL 'DISP P Pump 15 bbls clean mud down the 7,155.0 6,947.0 18:51 19:15 back side, 7/9/2017 7/9/2017 1.70 PROD1 DRILL TRIP P RBIH 6,947.0 10,630.0 19:15 20:57 stack CT weight_/-3k lbs @ 9108'& 9148' continue in hole stack CT weight_/-6k lbs plus WOB spike to 1.2k lbs @ 9397' continue in hole stack CT weight_/-3k lbs @ 9399'& 9410' PU and RBIH to clean up 3 'times Continue to RIH clean passage through the loss zone 9400'. stack CT weight_/-3k1 lbs @ 10,000' PU and continue in hole,appears to be clean simply pushing BHA up hill. CT RIH Wt fell of steadily from 145 k lbs,to 10 k lbs @ 10,000 then fell off more quickly as we pushed up hill to 10,630'and 5 k lbs CT Wt. 7/9/2017 7/9/2017 1.40 PROD1 DRILL DISP P 'PUH slowly while completing 10,630.0 9,180.0 20:57 22:21 construction of liner running pill. start pumping @ 21:17,lay in 20 bbls of beaded lubed liner running pill from...10630 to above the loss zone @ 9400'. Pulled 43 k from 9435- 9415'clean was 38 k lbs. Painting Yellow TD flag @ 9388.25' Page 11/20 Report Printed: 7/17/2017 • • O'd Operations Summary (with Timelog Depths) 1C-04 Conocitlips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/9/2017 7/10/2017 1.65 PROD1 DRILL TRIP P POOH pumping PowerPro lite. 9,180.0 2,828.0 22:21 00:00 Pressure check at the window,parked 7,170'bit depth,annular pressure 3176 psi while pumping 8.8 ppg @ 0.5 bpm.sensor depth 6472 TVD,9.4 ppg EMW. Paint WhiteWindow flag @ 5778.21'continue to POOH 7/10/2017 7/10/2017 0.50 PROD1 DRILL TRIP P Contiue to POOH. 2,828.0 78.0 00:00 00:30 7/10/2017 7/10/2017 1.60 PROD1 DRILL DISP P Complete dilution of stock KW fluid.@ 78.0 78.0 00:30 02:06 1:09 start bullhead 90 bbls 10.0 ppg KW(NaCl/NaBr)@ 1.63 bpm and WH of 862 psi. PJSM 7/10/2017 7/10/2017 1.20 PROD1 DRILL PULD P Flow check,Well on a vac,LD BHA 11 78.0 0.0 02:06 03:18 over a dead well.lost 5 bbls in first 5 min.continue to fill hole. Examine pipe for flat spots-good. 7/10/2017 7/10/2017 0.40 PROD1 DRILL BOPE P Perform BOPE function test. 0.0 0.0 03:18 03:42 7/10/2017 7/10/2017 0.50 COMPZ1 CASING PUTB P Prep floor for running liner,PJSM, . 0.0 0.0 03:42 04:12 total hole fill 35 bbls in last two hours. 7/10/2017 7/10/2017 1.40 COMPZ1 CASING PUTB P Make up liner 32 joints,(1266.87')2- 0.0 633.3 04:12 05:36 3/8"4.6#/ft L-80 slotted liner. Perform safety joint drill,time 2:55 min-AAR comments-good job,smooth, efficient. 7/10/2017 7/10/2017 0.40 COMPZ1 CASING PUTB P Clean up rig floor for crew change 633.3 633.3 05:36 06:00 7/10/2017 7/10/2017 1.00 COMPZ1 CASING PUTB P PJSM,continue PU lower liner 633.3 1,267.0 06:00 07:00 assembly 12 jts,close 2-3/8"combi's 7/10/2017 7/10/2017 0.75 COMPZ1 CASING PULD P PJSM,MU Coiltrak tools,surface test, 1,267.0 1,312.3 07:00 07:45 strip down and stab INJH,open 2-3/8" combi's 7/10/2017 7/10/2017 1.25 COMPZ1 CASING RUNL P Tag up,reset counters,RIH wtih 1,312.3 7,037.0 07:45 09:00 BHA#12,32 jts of slotted liner ported bull nose and shorty deployment sleeve. 7/10/2017 7/10/2017 0.15 COMPZ1 CASING RUNL P Stop and correct to the 6,000'EOP 7,037.0 7,012.3 09:00 09:09 flag,minus 24.78',PUW 35 k 7/10/2017 7/10/2017 0.40 COMPZ1 CASING RUNL P Continue RIH 7,012.3 8,225.0 09:09 09:33 7/10/2017 7/10/2017 0.25 COMPZ1 CASING DLOG P Log the K1 marker correction of plus 8,225.0 8,245.1 09:33 09:48 8.0' 7/10/2017 7/10/2017 0.90 COMPZ1 CASING RUNL P Continue RIH 8,245.1 10,630.0 09:48 10:42 • 7/10/2017 7/10/2017 0.25 COMPZ1 CASING RUNL P PUW 44 k,bring pump up to 1.8 bpm 10,630.0 10,630.0 10:42 10:57 at 4,500 psi,open choke 1.0 bpm returns,PUW 33 7/10/2017 7/10/2017 2.25 COMPZ1 CASING TRIP P Remove BHA from Counters,POOH, 10,630.0 44.2 10:57 13:12 pumping.72 bpm 7/10/2017 7/10/2017 0.50 COMPZ1 CASING OWFF P At surface,PJSM,Check well for flow 44.2' 44.2 13:12 13:42 7/10/2017 7/10/2017 0.75 COMPZ1 CASING PULD P LD setting tools 44.2 0.0 13:42 14:27 Page 12/20 Report Printed: 7/17/2017 • �" • • ' � Operations Summary (with Timelog Depths) 1' = ' 1C-04 ConocoPhifiips-Te` rt,), Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/10/2017 7/10/2017 1.50 COMPZ1 CASING PUTB P PJSM,MU upper liner section with 30 0.0 1,189.3 14:27 15:57 jts of slotted liner.close 2-3/8"combi's 7/10/2017 7/10/2017 0.50 COMPZ1 CASING PULD P PJSM,MU CoilTrak tools,surface test 1,189.3 1,234.7 15:57 16:27 tools(good test),open 2-3/8"combi's 7/10/2017 7/10/2017 1.10 COMPZ1 CASING RUNL P Tag up,reset counters,RIH with 1,234.7 7,058.0 16:27 17:33 second liner assembly.BHA#13 7/10/2017 7/10/2017 0.15 COMPZ1 CASING RUNL P Corrected to the EOP flag 5,800', 7,058.0 7,058.0 17:33 17:42 minus 18.5',PUW 35 k 7/10/2017 7/10/2017 0.30 COMPZI CASING RUNL P Continue RIH 7,058.0 8,145.0 17:42 18:00 7/10/2017 7/10/2017 0.25 COMPZ1 CASING DLOG P Log the K1 marker correction of plus 8,145.0 8,163.0 18:00 18:15 4.0' 7/10/2017 7/10/2017 0.40 COMPZ1 CASING RUNL P Continue RIH,work pipe from 8,414' 8,163.0 9,362.0 18:15 18:39 to 8,450'. 7/10/2017 7/10/2017 0.20 COMPZ1 CASING RUNL P Tag bottom at 9362',PUW 45 k,set 9,362.0 8,149.6 18:39 18:51 back down,bring pump up to 1.7 bpm, open choke, 1.0 bpm returns,PUW 35 k 7/10/2017 7/10/2017 1.50 COMPZ1 CASING TRIP P POOH,pumping 0.8 bpm at 1128 psi, 8,149.6 44.2 18:51 20:21 following MP 10.0 ppg schedule 7/10/2017 7/10/2017 0.50 COMPZ1 CASING OWFF P At surface,fill the hole,shut down 44.2 44.2 20:21 20:51 monitor well for flow,PJSM 7/10/2017 7/10/2017 0.25 COMPZ1 CASING PULD P LD setting tools 44.2 0.0 20:51 21:06 7/10/2017 7/10/2017 0.50 COMPZ1 CASING PUTB P PU/MU Open Hole Anchored Billet 0.0 22.1 21:06 21:36 and 10'perforated pup joint. 7/10/2017 7/10/2017 0.25 COMPZ1 CASING PULD P PU/MU CoilTrak tools,stab INJH, 22.1 84.0 21:36 21:51 surface test tools(good test).check pac-offs 7/10/2017 7/10/2017 0.60 COMPZI CASING SVRG P Tighten levelwind CTES counter 84.0 84.0 21:51 22:27 housing and encoder 7/10/2017 7/11/2017 1.55 COMPZ1 CASING RUNL P Tag up,reset counters,RIH with OH 84.0 6,370.0 22:27 00:00 Anchored Billet. Park @ 6925',PU Wt 33 k lbs. S/D pumps,close EDC. continue to RIH. 7/11/2017 7/11/2017 0.20 COMPZ1 CASING RUNL P Continue to RIH 6,370.0 6,690.0 00:00 00:12 7/11/2017 7/11/2017 0.20 COMPZ1 CASING DLOG P Log the K1 for-14.5'correction 6,690.0 7,028.0 00:12 00:24 7/11/2017 7/11/2017 0.60 COMPZI CASING RUNL P Continue to RIH 7,028.0 8,170.9 00:24 01:00 7/11/2017 7/11/2017 0.10 COMPZ1 CASING RUNL P Tag up TOL„PU Wt 38 k,RBIH,tag 8,171.0 8,171.0 01:00 01:06 up S/D 3 k lbs WOB,PU 35k to neutral,orient to 180°ROHS. sheared at 3400 psi,WOB climbed from.9 k to 5k lbs.PU slightly RBIH, S/D 5.8 k 7/11/2017 7/11/2017 1.60 COMPZ1 CASING TRIP P POOH,park @ 6636,open EDC, 8,171.0 81.0 01:06 02:42 continue to POOH holding 10.0 ppg pressure schedule. 7/11/2017 7/11/2017 1.00 COMPZ1 CASING PULD P PJSM,bump up,flow check,on vac, 81.0 0.0 02:42 03:42 LD BHA#14 Billet setting assembly over a dead well. 7/11/2017 7/11/2017 1.20 PROD2 STK PULD P PU BHA#15,AL1 lat build drilling 0.0 72.0 03:42 04:54 assembly,stab injector,check stipper- good,tag up,set counters.test tools Open EDC. Page 13/20 Report Printed: 7/17/2017 • S Operations Summary (with Timelog Depths) 1C-04 ConocoPhitlips 4 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/11/2017 7/11/2017 1.40 PROD2 STK TRIP P RIH holding 10.0 ppg EMW schedule 72.0 6,970.0 04:54 06:18 while turning coil over to PowerProw light drilling system. 7/11/2017 7/11/2017 0.20 PROD2 STK DLOG P Tie into the K1 for a-13'correction. 6,970.0 6,990.0 06:18 06:30 7/11/2017 7/11/2017 0.60 PROD2 STK TRIP P PU Wt 34k lbs,park,down on pumps, 6,990.0 8,150.0 06:30 07:06 close EDC.continue to RIH. 7/11/2017 7/11/2017 2.30 PROD2 STK KOST P Dry tag TOB @ 8150'. PU,set rate, 8,150.0 8,150.5 07:06 09:24 1.80 bpm,CT 4130 psi,annular 4079 psi,WH 748 psi,free spin diff 425 psi, RIH Wt 13 k lbs,OBD,Stall 7 times, pump 10 bbl beaded pill,stall 3 more times,fan pump to get started,beads all going down the A lat,no benifit seen with weight transfer. A lat bridging off with aluminum billet cuttings,annular pressure up to 4400 psi,WH 1100 psi. Crack choke to maintain 11.4 ppg EMW at the window. 1 bpm return rate. Unloading 10.0 ppg KW fluid off the back side,divert returns to the tiger tank. Retuns built to 100%as cuttings were generated. Converting Power Pro light to full system,viscing up fluid. 7/11/2017 7/11/2017 0.30 PROD2 STK KOST P Time drill ahead for 3 feet at-0.9 k 8,150.5 8,151.5 09:24 09:42 lbs WOB and 1 ft/hr. 7/11/2017 7/11/2017 0.80 PROD2 STK KOST P Time drill ahead at 3.6 ft/hr. 8.8 ppg 8,151.5 8,163.8 09:42 10:30 Power Pro light returns,brought fluid back inside. Increase WOB to 2 k lbs, ROP 18 ft/hr. 7/11/2017 7/11/2017 0.20 PROD2 STK KOST P PU,Wt 33 k lbs,dry drift billet clean. 8,163.0 8,163.0 . 10:30 10:42 7/11/2017 7/11/2017 2.00 PROD2 DRILL DRLG P Set rate, 1.78 bpm in, 1.73 bpm out, 8,163.0 8,239.0 10:42 12:42 CT 4199 psi,free spin diff 425 psi..Ct wt 7.32k lbs,WOB 2.69 k lbs,ROP 14 -140 ft/hr. 7/11/2017 7/11/2017 1.20 PROD2 DRILL DRLG P Having a difficult time dropping. Time 8,239.0 8,249.0 12:42 13:54 drill in an effort to drop. 7/11/2017 7/11/2017 1.00 PROD2 DRILL DRLG P Drilled ahead w good weight transfer 8,249.0 8,392.0 13:54 14:54 at-129 ft/hr. 7/11/2017 7/11/2017 0.80 PROD2 DRILL DRLG P Encountered losses of 0.2-0.3 bpm @ 8,392.0 8,453.0 14:54 15:42 8392-TD build section. 7/11/2017 7/11/2017 0.80 PROD2 DRILL WPRT P PU Wt 35 k lbs. PUH,sweep exited 8,453.0 7,095.0 15:42 16:30 the bit @ 8042'. Chase sweeps through build 7/11/2017 7/11/2017 0.30 PROD2 DRILL CIRC P Park,Open EDC,pump 1.7 bpm 8,453.0 7,095.0 16:30 16:48 through pilot hole,2.0 bpm once above the cement pilot hole. 7/11/2017 7/11/2017 0.30 PROD2 DRILL DLOG P Park a the window,6448'TVD, 8,453.0 7,100.0 16:48 17:06 measure BHP @ 3918 psi,bleed the well to 11.4 EMW and observe pressure climb and stabilize at 3885 psi-11.6 ppg EMW. 7/11/2017 7/11/2017 1.30 PROD2 DRILL TRIP P Continue to POOH holding one for 7,100.0 72.0 17:06 18:24 one returns,tag up,space out. 7/11/2017 7/11/2017 1.50 PROD2 DRILL PULD P PJSM,PUD BHA#15,checks not 72.0 0.0 18:24 19:54 holding,close EDC,continue to PUD with EDC closed. Page 14/20 Report Printed: 7/17/2017 x . • Operations Summary (with Timelog Depths) i 1C-04 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/11/2017 7/11/2017 1.60 PROD2 DRILL CTOP P Slide in cart,remove checks,install 0.0 0.0 19:54 21:30 nozzle,stab cart on WH,pump backwards,BO nozzle,changeout• UQC,pump forward 7/11/2017 7/11/2017 2.10 PROD2 DRILL PULD P PJSM,PD BHA#16(agtitator,.5° 0.0 78.0 21:30 23:36 AKO X-Treme motor,HYC C1-3D bit), tag-up,test MWD,check packoffs 7/11/2017 7/12/2017 0.40 PROD2 DRILL TRIP P Begin RIH,surface test agitator,good, 78.0 3,960.0 23:36 00:00 open EDC 7/12/2017 7/12/2017 0.50 PROD2 DRILL TRIP P Continue RIH,holding increased 3,960.0 6,968.0 00:00 00:30 choke to maintain 1-for-1 7/12/2017 7/12/2017 0.30 PROD2 DRILL DLOG P Tie-in for a-15'correction 6,968.0 7,007.0 00:30 00:48 7/12/2017 7/12/2017 0.70 PROD2 DRILL TRIP P Continue RIH 7,007.0 8,453.0 00:48 01:30 7/12/2017 7/12/2017 2.20 PROD2 DRILL DRLG P OBD AL2 lateral,rate in=1.75 bpm, 8,453.0 8,883.0 01:30 03:42 rate out=1.78 bpm,BHP=4165, CWT=10K,WOB=1.4K,PU at 8684',PUW=47K,average ROP -130 fph 7/12/2017 7/12/2017 2.50 PROD2 DRILL WPRT P Wiper up-hole,PUW=35K(geo 8,883.0 7,575.0 03:42 06:12 wiper to discuss pulling for a higher bend) 7/12/2017 7/12/2017 0.60 PROD2 DRILL WPRT P Wiper in-hole,RIW=13 k lbs (geo 7,575.0 8,883.0 06:12 06:48 wiper to discuss pulling for a higher bend) 7/12/2017 7/12/2017 1.70 PROD2 DRILL DRLG P OBD AL1 lateral,rate in=1.80 bpm, 8,883.0 9,001.0 06:48 08:30 rate out=1.60-1.80 bpm,BHP= 4057,CWT=4K,WOB=3.5k,PU's 48k to 35k average ROP-69 fph 7/12/2017 7/12/2017 1.50 PROD2 DRILL DRLG P Broke through ROP up to 150 ft/hr. 9,001.0 9,138.0 08:30 10:00 OBD,CT 5713,WH 330 psi, 1.80 bpm 1 for 1 returns,Annular 4090 psi CT Wt 4.6 k lbs,WOB 1.5 k lbs,ROP 20 to 200 ft/hr PU's 43 k-51 k Drilling stringers average ROP-91 fph 7/12/2017 7/12/2017 0.70 PROD2 DRILL DRLG P ***Lost all returns @ 9138' 9,138.0 9,180.0 10:00 10:42 PU,36k lbs,PUH 100 feet,RBIH losses healed to 0.5 bpm OBD,CT 5009 psi,WH 330 psi, 1.80 bpm,returns 0.3-1.0 bpm Pump 20 bbl 7/12/2017 7/12/2017 0.20 PROD2 DRILL WPRT P PU,46 k lbs,wipe up hole above 9,180.0 9,180.0 10:42 10:54 innitial losses,RBIH,stack of @ 9100',modulate pump,RBIH. 7/12/2017 7/12/2017 0.60 PROD2 DRILL DRLG P BOBD,Losses worsened, 1.8 in 0.5 9,180.0 9,252.0 10:54 11:30 bpm out. Drilled ahead with little healing of losses. Consult W town engineering,decide to close choke. average ROP-120 fph 7/12/2017 7/12/2017 0.90 PROD2 DRILL WPRT P PU,38k lbs. to window 33k lbs while 9,252.0 6,949.0 11:30 12:24 PUH. While pulling through the window and @ min rate WH 310, Annular 3000 psi,rate in 0.3 rate out 0. Page 15/20 Report Printed: 7/17/2017 i • Operations Summary (with Timelog Depths) p 1C-04 Conor hiHips Rig: NABORS CDR3-AC Joli: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/12/2017 7/12/2017 0.80 PROD2 DRILL DISP P S/I choke,Line up to he back side, 9,649.0 9,959.0 12:24 13:12 bullhead 49 bbls bbls liner running pill, increaded rate from 1 bpm to drilling rate of 1.8 bpm,WH climbed to 1773 psi,annular climbed to 3934 psi. 7/12/2017 7/12/2017 0.20 PROD2 DRILL DLOG P Log K1 for+6'correction 9,959.0 7,008.0 13:12 13:24 7/12/2017 7/12/2017 0.80 PROD2 DRILL TRIP P RBIH pumping min rate through the 7,008.0 9,252.0 13:24 14:12 build,window clean,WOB spike @ 7330',slight bobble at 7512,no motor work or TF change, S/D 9141, pushed through. 7/12/2017 7/12/2017 2.00 PROD2 DRILL DRLG P Set rate 1.80 bpm against a closed 9,252.0 9,450.0 14:12 16:12 choke,Free spin diff 1400 psi,CT 5600 psi OBD,CT Wt 5 k lbs,WOB 2.6 k lbs, ROP 130,WH 1169,Annular 4232 psi Average ROP=97.5 ft/min • 7/12/2017 7/12/2017 0.10 PROD2 DRILL WPRT P PU 39k lbs, wipe to above the loss 9,450.0 9,000.0 . 16:12 16:18 zone @ 9138'. String weight fell off above the loss zone. 7/12/2017 7/12/2017 0.10 PROD2 DRILL WPRT P RBIH,RIH Wt 10-11k lbs 9,000.0 9,450.0 • 16:18 16:24 7/12/2017 7/12/2017 1.10 PROD2 DRILL DRLG P Set Rate @ 1.78 bpm,CT 5050 psi, 9,450.0 9,522.0 16:24 17:30 WH 920 psi,free spin 1261 psi OBD,CT Wt 5 k lbs,WOB 2.4 k lbs, ROP 120 ft/hr. in stringers again 65 ft/hr over interval 7/12/2017 7/12/2017 2.60 PROD2 DRILL DRLG P Continue drilling ahead,CWT=7K, 9,522.0 9,701.0 17:30 20:06 WOB=1K,BHP=3748 psi,WHP= 663 psi,ROP—72 fph over interval. 7/12/2017 7/12/2017 0.30 PROD2 DRILL WPRT P Wiper up-hole,PUW=38K 9,701.0 8,992.0 20:06 20:24 7/12/2017 7/12/2017 0.30 PROD2 DRILL WPRT P Wiper in-hole,RIW=11.5K at 9650' 8,992.0 9,701.0 20:24 20:42 7/12/2017 7/12/2017 2.80 PROD2 DRILL DRLG P BOBD,pumping 1.8 bpm,free spin= 9,701.0 10,045.0 20:42 23:30 1170 psi,CWT=4K,WOB=2.7K,dp =1410 psi,BHP=3650 psi,WHP= 570 psi,PUW check at 10,000'=38K, continue drilling waiting for sweep to exit the bit,ROP—123 fph over interval 7/12/2017 7/13/2017 0.50 PROD2 DRILL WPRT P Begin wiper up-hole,PUW=40K 10,045.0 8,534.0 23:30 • 00:00 7/13/2017 7/13/2017 0.60 PROD2 DRILL WPRT P Continue WT to window 8,534.0 6,960.0 00:00 00:36 7/13/2017 7/13/2017 0.20 PROD2 DRILL DLOG P Log K1 for+6'correction 6,960.0 6,960.0 00:36 00:48 • 7/13/2017 7/13/2017 0.80 PROD2 DRILL SVRG T Remain in cased hole,replace leaking 6,960.0 6,900.0 00:48 01:36 seal on mud pump#1,maintaining ECD 7/13/2017 7/13/2017 1.20 PROD2 DRILL WPRT P Wiper in-hole to continue drilling,slight 6,900.0 10,045.0 01:36 02:48 weight bobble through window&at 7467',clean past thief zone at 9138', slight bobble at 8,150'(billet),RIW= 9K at 10,025' Page 16/20 Report Printed: 7/17/2017 • • Operations Summary (with Timelog Depths) � Ar2t ` , 1C-04 to- ConocoPhitlip'S i> Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/13/2017 7/13/2017 1.80 PROD2 DRILL DRLG P BOBD,free spin=1150 psi, pumping 10,045.0 10,208.0 02:48 04:36 1.78 bpm,closed choke,BHP=3826 psi,WHP=728 psi,difficutly dropping inclination,continue to get bounced up from—85°to 87°-88°,PUW=50K, perform BHA wiper,ROP over interval =90 fph 7/13/2017 7/13/2017 1.30 PROD2 DRILL DRLG P Continue drilling ahead attempting to 10,208.0 10,303.0 04:36 05:54 get to&hold 85°inclination,FS= 1141 psi,CWT=6K,WOB=1.5K, BHP=3600 psi,WHP=490 psi,ROP over interval=95 fph 7/13/2017" 7/13/2017 0.60 PROD2 DRILL WPRT P PU Wt 43 k lbs,Pulling weight 38k to 10,300.0 8,980.0 05:54 06:30 36 k lbs above the loss zone,wiper- 1320' 7/13/2017 7/13/2017 0.50 PROD2 DRILL WPRT P RBIH,Wt 15 k lbs,saw theif zone at 8,980.0 10,303.0 06:30 07:00 9100,oriented wrond,most likely BHA geometry. 7/13/2017 7/13/2017 6.10 PROD2 DRILL DRLG P 1.77 bpm,CT 4163 psi,free spin diff 10,303.0 10,644.0 07:00 13:06 1146 psi,WH 447 psi,annular 2544 psi. OBD,CT Wt 4-1 k WOB 3-1 k lbs, ROP 160-20 ft/hr.PU's 41k last two 56 and 59 k lbs,call wiper ROP over interval=56 fph 7/13/2017 7/13/2017 0.60 PROD2 DRILL WPRT P PU wt 59 k lbs,wiper(1644') 10,644.0 9,000.0 13:06 13:42 7/13/2017 7/13/2017 0.50 PROD2 DRILL WPRT P RBIH,RIH Wt 14 k to 12k lbs 9,000.0 10,644.0 13:42 14:12 7/13/2017 7/13/2017 3.30 PROD2 DRILL DRLG P 1.84 bpm,CT 4408 psi,free spin diff 10,644.0 10,800.0 14:12 17:30 1230 psi,WH 447 psi,annular 3609 psi. OBD,CT Wt3 k lbs k WOB 2.8 k lbs, ROP 60-140 ft/hr.Grabby,looks to be differential sticking,PU 58k lbs, ROP over interval=47 fph 7/13/2017 7/13/2017 1.60 PROD2 DRILL WPRT P PU Wt 45 k lbs,POOH to window for 10,800.0 • 7,100.0 17:30 19:06 tie in and SBHP 7/13/2017 7/13/2017 0.20 PROD2 DRILL DLOG P Obtain SBHP,Bit Depth=7100', 7,100.0 7,132.0 19:06 • 19:18 sensor depth=7051',TVD sensor= 6373',EMW of 10 ppg=3314 psi, shut down pumps,closed choke,allow annular pressure to drop below 3314 psi as per procedure,pressure drops below 10 ppg EMW,10 ppg kills well Log RA tag for+14.5'correction 7/13/2017 7/13/2017 1.00 PROD2 DRILL WPRT P RBIH,slight set down at—8440', 7,132.0 10,808.0 19:18 20:18 cleaned up area at 9145'&9514',TD confirmed at 10,808",begin sending 25 bbl liner running pill 7/13/2017 7/13/2017 3.50 PROD2 DRILL DISP P POOH,lay in liner running pill(25 bbl) 10,808.0 78.0 20:18 23:48 from TD to thief zone at 9138',switch to drilling fluid to surface,painted EOP flag(5278.28),tag up,space out 7/13/2017 7/14/2017 0.20 PROD2 DRILL DISP P At surface,open EDC, begin to 78.0 78.0 23:48 00:00 bullhead 90 bbl KWF down to thief zone. Page 17/20 Report Printed: 7/17/2017 III III '` Operations Summary (with Timelog Depths) Cono ,ieaip I.xA- Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/14/2017 7/14/2017 1.20 PROD2 DRILL DISP P Continue to bullhead KWF to thief 78.0 78.0 00:00 01:12 zone at 9138',PJSM during bullhead for LD BHA#16, flow-check(-5 min), on a vac,-18 bbl/hr losses,close EDC 7/14/2017 7/14/2017 1.00 PROD2 DRILL PULD P LD BHA#16 over a dead well,bit 78.0 0.0 01:12 02:12 came out a 2-2 7/14/2017 7/14/2017 2.80 COMPZ2 CASING PUTB P PJSM,PU Liner Run#1 (ported bull- 0.0 1,770.0 02:12 05:00 nose,44 jnts slotted liner) 7/14/2017 7/14/2017 0.70 COMPZ2 CASING PULD P PJSM(new driller on tour),PU BHA 1,770.0 10,810.9 05:00 05:42 #17 Liner Running Assembly Run#1 (shorty deployment,GS,&BHA),slide in cart,stab on,bump up set counters, inspect pack offs. 7/14/2017 7/14/2017 1.70 COMPZ2 CASING RUNL P RIH with BHA#17,line up down the 1,814.0 8,710.0 05:42 07:24 back side and start pumping liner running pill down the back side. Tie into window flag and correct-21.08'. PU Wt 36 k lbs. 7/14/2017 7/14/2017 0.10 COMPZ2 CASING DLOG P Tie into K1 for+6'corrrection. 8,710.0 8,744.0 07:24 07:30 7/14/2017 7/14/2017 0.90 COMPZ2 CASING RUNL P Continue to run lowwer completion to 8,744.0 10,808.0 07:30 08:24 bottom. SD 10807.5'.4.7k WOB PU Wt 43 k lbs,-4,RBIH S/D 5 kWOB, PU to slack CT Wt,Swap from pumping down the back side to the coil,increase rate to 1.45 bpm PU 33k lbs string weight,WOB 0 lbs **Set bottom linersection,top @ 9038.5', bottom 10808' 7/14/2017 7/14/2017 1.00 COMPZ2 CASING TRIP P POOH,paint yellow window flag @ 10,808.0 6,939.0 08:24 09:24 6954'. Continue to PUH,park at 6939' bit depth,6263'TVD,Inteq pressure 3291 psi,S/D pumps trapping pressure, Pressure trended down to 3259 psi in ten minutes. calculated out at 10.00 ppg EMW. 7/14/2017 7/14/2017 0.20 COMPZ2 CASING TRIP P Continue to POOH,pumping 0.53 6,939.0 6,145.0 09:24 09:36 bpm and pulling 100 ft/min,WH climbed from 0 to 600 psi and annular to 3,970 psi. Parked coil,came down on the pump. Allowed presures to, relax,BHP fell to-10 ppg EMW, verified no flow at surface,well on a vac. 7/14/2017 7/14/2017 1.50 COMPZ2 CASING TRIP P Weight up KW from 10 ppg to 1.2 ppg. 6,939.0 6,145.0 09:36 11:06 Open EDC 7/14/2017 7/14/2017 0.40 COMPZ2 CASING TRIP P RBIH,turning coil over to 8.92 ppg 6,145.0 7,120.0 11:06 11:30 liner running pill, 17 bbls total, 7/14/2017 7/14/2017 0.10 COMPZ2 CASING TRIP P Tie int othe RA tag for a+7' 7,120.0 7,146.0 11:30 11:36 7/14/2017 7/14/2017 0.80 COMPZ2 CASING TRIP P Continue to RIH. chase the liner 7,146.0 9,029.0 11:36 12:24 running pill w 10.2 ppg, 1.33 bpm in, 1.27 bpm out,annular 3774 psi,choke wide open,increase rate to 1.6 bpm chasing pill to bottom,returns fell off damaticaly. 7/14/2017 7/14/2017 0.60 COMPZ2 CASING TRIP P PUH,laying in 17 bbl beaded liner 9,029.0 7,125.0 12:24 13:00 running pill,pumping 0.49 bpm in 0.11 bpm out, 7/14/2017 7/14/2017 1.80 COMPZ2 CASING TRIP P Contiune to POOH,paint white flag @ 7,125.0 45.0 13:00 14:48 4944',continue to POOH Page 18/20 Report Printed: 7/17/2017 • • ' Operations Summary (with Timelog Depths) 1C-04 ConocoPhillips,-L Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/14/2017 7/14/2017 1.00 COMPZ2 CASING PULD P Bump up,open the stack at the floor, 45.0 0.0 14:48 15:48 flood up to the half drum,ovserve flow,-none,cycle EDC closed, opened and closed again after pumping beads through it.-good. PJSM,LD BHA#17 over a dead well. 7/14/2017 7/14/2017 0.40 COMPZ2 CASING PUTB P Prep floor to run liner,buck up ported 0.0 22.2 15:48 16:12 bullnose and three pups(21.82'), • 7/14/2017 7/14/2017 3.40 COMPZ2 CASING PUTB P PU upper AL1 Lateral,37 joints of 22.2 2,077.3 16:12 19:36 slotted&19 joints of blank pipe,filling hole, 4 bbls/hr hole fill 7/14/2017 7/14/2017 1.90 COMPZ2 CASING PULD P PJSM,Kick while running liner drill, 2,077.3 2,128.0 19:36 21:30 PU safety joint,monitor well,well is on a vac, PU PBR,GS,&BHA#17, inspect counter,loose chain,slide cart back,stab on, 7/14/2017 7/14/2017 2.00 COMPZ2 CASING RUNL P RIH with liner,pumping 8.7 ppg liner 2,128.0 6,955.0 21:30 23:30 pill down back side as per town request(not to exceed 750 psi WHP, 12.4 ppg EMW with 10.2 ppg in the hole),tie into EOP pipe flag for a-23' correction,PUW=35K at window, reached setting depth,PUW=40K at set depth,RBIH,bring up pumps, release off liner putting TOL at -6955' MD(BOL at 9038.5'),PUW=30K 7/14/2017 7/14/2017 0.30 COMPZ2 CASING DLOG P Obtain SBHP at 6945'MD,TVD 6,955.0 6,945.0 23:30 23:48 sensor=6245',Annular stabalizes at -2938 psi,EWM=-9 ppg 7/14/2017 7/15/2017 0.20 COMPZ2 CASING TRIP P POOH,pumping KWF down backside 6,995.0 5,000.0 23:48 00:00 7/15/2017 7/15/2017 1.60 COMPZ2 CASING TRIP P Continue POOH,stop at 720'&clean 5,000.0 44.0 00:00 01:36 carUinjector for summer maintenance replacement. • 7/15/2017 7/15/2017 0.60 COMPZ2 CASING PULD P PJSM,flow check,LD BHA#18 over 44.0 0.0 01:36 02:12 dead well 7/15/2017 7/15/2017 0.90 DEMOB WHDBOP FRZP P Slide in cart,stab on,PJSM,bullhead 0.0 0.0 02:12 03:06 30 bbl diesel at.8 bpm 7/15/2017 7/15/2017 0.60 DEMOB WHDBOP CIRC P Jet stack,displace coil to seawater 0.0 0.0 03:06 03:42 7/15/2017 7/15/2017 1.50 DEMOB WHDBOP MPSP P PJSM,RU,lubricate in BPV,RD 0.0 0.0 03:42 05:12 7/15/2017 7/15/2017 2.10 DEMOB WHDBOP CIRC P Slide in cart,stab on,blow down reel, 0.0 0.0 05:12 07:18 PUTZ,&surface lines w/N2(SLB) 7/15/2017 7/15/2017 6.00 DEMOB WHDBOP CIRC P Secure reel,remove inner reel 0.0 0.0 07:18 13:18 iron,pressure bulkhead,un stab, secure pipe. 7/15/2017 7/15/2017 3.70 DEMOB WHDBOP CIRC P Drop stripper off injector,swap bag 0.0 0.0 13:18 17:00 (annular).blow down steam, disconnect at the PUTZ.Start ram swaps.Start motors,swap off high line power to generators-4:00 pm Page 19/20 Report Printed: 7/17/2017 . • • 'ol0 Operations Summary (with Timelog Depths) 1C-04 ConocoPh'Hips .,..r.kn Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/15/2017 7/15/2017 4.30 DEMOB WHDBOP RURD P Breakdown TT hard lines,break down 0.0 0.0 17:00 21:18 scaffolding,NES trucks arrive at —19:30 hours,PJSM,plan moving to edge of 1C-Pad,raise/roll pits,work RDMO check list,RU&spot service module to pad edge,regain COMMS. 7/15/2017 7/16/2017 2.70 DEMOB WHDBOP NUND P ND BOPE,break tree at flow-cross, 0.0 0.0 21:18 00:00 install Otis quick union on tree,RU, move,&spot sub module(witnessed by DSO),begin working to pick reel out of sub module,begin work on PDL (summer maintenance). "Rig Released 24:00 hours 7/15/2017 Page 20/20 Report Printed: 7/17/2017 .%ot KUP PROD • IC-04 ConocoPhillips 1 g Well Attributes Max Angle&MD TD Aaska r1Q Wellbore API/UWI Field Name Wellbore Status Ind 7) MD(ftKB) Act Blm(ftKB) ,,,,,,....„,,rat., 500292054700 KUPARUK RIVER UNIT PROD 1 37.98 4,300.00 7,575.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-04,8/15/2017 9:53:59 AM SSSV:NONE 40 9/10/2016 Last WO: 1/24/2015 39.01 2/7/1981 Vertical schematic tactual).>................ Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag SLM 7,246.0 12/7/2016 Rev Reason:CEMENT PLUG,TAG(CEMENT), pproven 6/6/2017 HANGER;276- It'''l-„1 MILLED CEMENT to 6.974' -Casing Strings • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread CONDUCTOR Insulated 20 18.940 34.0 80.0 80.0 94.00 H-40 WELDED I1 it 32" I. I Casing Description SOD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread C SURFACE 133/8 12.347 33.0 2,910.0 2,707.8 72.00 N-40 ETC 1111 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 95/8 8.661 30.1 6,935.6 6,258.1 47.00 L-BO BTC Casing Description OD(in) ID(in) -Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR Ins uleNd3r;� LINER 7 6.276, 6,612.1 7,545.0 6,866.3 26.00 K-55 BTC 34.0.80.0 I Liner Details Nominal ID rit Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;2,831.1 6,612.1 5,935.6 5.65 TIE BACK BAKER TIE BACK SLEEVE 6.151 4 6,618.2' 5,941.7 5.60 NIPPLE BAKER SEAL NIPPLE 6.151 6,621.5' 5,945.0 5.58 HANGER BAKER LINER HANGER 6.151 I 6,631.6 5,955.0 5.50 XO BUSHING BAKER XO CENTRALIZER BUSHING 6.151 SURFACE;33.0-2,910.0 Tubing Strings Tubing Description Strang Ma...ID(in) Top(ftKB) Set Depth(ft..J Set Depth(ND)(...Wt(Iblft) 0 I GL -80 TopEUE ConneBrdMctionod TUBING-WO-2015 31/2 2.992 27.8 6,910.0 6,232.5 9.3 GAS LIFT;3,920.4 E -4 1/2 x 3 1/2 @62.8 in Completion Details Nominal ID Top(ftKB) Top(TVD)(kKB) Top Incl(°) gem Des Com (in) 27.8 27.8 0.06 HANGER FMC GEN 3 HANGER WITH LH ACME LIFT THREAD 3.958 62.8 62.8 0.13 XO Reducing Crossover Pup 4 1/2"IBTM x 3 1/2"EUE Brd 2.992 GAS LIFT,4,982.1 g 6,769.3 6,092.2 4.38 LOCATOR GBH LOCATOR SUB 2.980 6,770.2 6,093.2 4.38 SEAL ASSY 80-40 SEAL ASSEMBLY 2.990 al II 6,775.7 6,098.6 4.33 PBR BAKER 80-40 PER(20') 4.000 GAS LIFT;5,678.0 16,798.8 6,121.7 4.14 PACKER BAKER 4782 FHL RETRIEVABLE PACKER 2.960 6,849.3 6,172.0 4.10 NIPPLE CAMCO DS NIPPLE 2.813 6,901.7 6,224.3 4.07 OVERSHOT BAKER POOR BOY OVERSHOT 3.590 GAS LIFT;8,348.7 Tubing Description I Strang Ma...I ID(in) I Top(ftKB) 'Set Depth(ft..�Set Depth(ND)(...'Wt(Ib/ft) Grade I Top Connection TUBING-ORIGINAL 3 1/2 2.992 6,904 0 6,986 4 6,308.8 9.201K-55 BTC Completion Details .tzt. ,� Nominal ID -.1; Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn • (in) Ia 6,919.2 6,241.7 4.06 SBR w/EXT BAKER KB4 SBR 3.000 a _ 6,945.3 6,267.8 4.04 PACKER BAKER FHL PACKER 3.000 • 6,983.5 6,305.9 4.02 NIPPLE CAMCO D NIPPLE NO GO(1.81"NIPPLE REDUCER 2.750 ri SET 9/17/14-PULLED 2/6/2015) GAS LIFT;6,712.4 6,984.4 6,306.8 4.02 SOS BAKER SHEAR OUT SUB 2.992 lit Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl LOCATOR;6.769.3 Is Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) SEAL ASSY,6.770.2 7,126.0 6,448.0 3.80 Whipstock#2 BOT Monobore XL Whipstock 7/5/2017 0.000 PBR;6.775.7 �._ 7,150.0 6,472.0 3.90 Whipstock#1 BOT Monobore XL Whipstock 7/3/2017 0.000 PACKER;6,798.8 Niff17,272.0 6,593.7 3.50 FISH E-LINE SPINNER 2"Long x 1/4"Wide 8/20/2014 T Perforations&Slots NIPPLE;6,849.3 I Shot Dens Top(ND) Btm(ND) (shots /f I Tap(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 6,964.0 6,966.0 6,286.4 6,288.4 C-1,UNIT B, 5/23/2017 3.0 APERF 2"HES BIG HOLE 1C-04 CHARGES(3 SPF @ 111 120"PHASE) % OVERSHOT;8,901.7 7,088.0 7,148.0 6,410.1' 6,470.0 C-4,C-3,C-2, 2/7/1981 1C-04 4.0 (PERF 7,208.0 7,218.0 6,529.9 6,539.8 C-1,UNIT B, 2/7/1981 4.0 IPERF ' SBR w/EXT:8,919.2 1C-04 PRODUCTION;30.1-8,935.6- Cement Squeezes PACKER;6,945.3 Top(ND) Btm(ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn 6,960.0 7,268.0 6,282.4 6,589.7 Cement Plug 5/28/2017 MILLED W/BAKER MOTOR AND TURNED DOWN 2.98"BI-CENTER HYCALOG MILL.MILL CEMENT TO 6,974'RKB Mandrel Inserts APERF;8,964.0-69fifi.0 St ati on Top(ND) Valve Latch Port Size TRO Run NIPPLE;6,983.5 N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn SOS;6,984.4A' 1 2,631.1 2,466.5 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188 1,178.0 5/22/2017 1` 2 3,920.4 3,551.9 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 5/22/2017 IPERF;7,08a.0-7,148.0 3 4,982.2 4,397.7 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 5/21/2017 AL1 LINER;8,954.7-10,606.0 Whipstock#2,7,126.0 .. 4 5,678.0 5,018.9 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 1/31/2015 5 6,346.7 5,671.8 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/31/2015 6 6,7124 6,035.5 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 5/22/2017 Whipstock#1;7,150.0 Notes:General&Safety End Date Annotation 12/25/2002 NOTE:WAIVERED WELL:IA X OA COMMUNICATION (PERF;7,208.0-7,218.0 8/10/2010 NOTE:View Schematic w/Alaska Schematic9.0 8/16/2014 NOTE:LEAK AT 5763';3"SPINNER STILL IN HOLE. Cement Plug;0.900,00900 1/24/2015 NOTE:WORKOVER i LINER;6,612.1-7,545.0 1 KUP PROD • 1C-04A ConocoPhillips Oi Well Attributes Max Angle&MD TD Alaska,inc. Wellbore APIIUWI Field Name Wellbore Status Incl CI MD(ftKB) Act Btm(ftKB) C3n41o441nps 500292054701 KUPARUK RIVER UNIT PROD 102.64 7,845.05 10,675.0 ... Comment 025(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-04A.8/15/20179;51 53 AM SSSV:NONE 40 9/10/2016 Last WO: 39.01 2/7/1981 Vertical schematic(acWaQ Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,27.e Last Tag: Rev Reason:SIDETRACK jennalt 8/14/2017 11 Casing Strings Casing Description OD(in) ID(in) Top(51(13) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread A LINER 2 3/8 1.992 8,149.3 10,630.0 6,402.4 4.60 L-80 STL III Liner Details ■ Nominal ID I 11Il .;u„, Sep (kKB) Top(ND)(ft KB) Top In971.115 cl(°) Item Des Com (in) 8,148.3 6,436.3 97.15 ALUMINUM OH Anchor B Aluminum Billet 1.920 T BILLET CONDUCTOR Insulated 32•; I d 8,171.4 6,433.4 97.57 CASING Shorty Deployment Sleeve 1.920 34.0-80.0 HANGER M� 9,361.9 6,414.8 91.89 CASING Shorty Deployment Sleeve 1.920 HANGER GAS LIFT:2.631.1 — Notes:General&Safety End Date Annotation NOTE SURFACE;33.0-2,910.0* l GAS LIFT;3,920A MI I GAS LIFT;4,982.1 - 11 I GAS LIFT;5,678.0 1111 II GAS LIFT;6,346.7 AVYl a b GAS LIFT;6,712.4 I IF LOCATOR;6,769.3 SEAL ASSY;8,770.2 PBR;8,775.7 = PACKER;6,798.8 . It It NIPPLE;6,849.3 F OVERSHOT;6,901.7 I vdE .z PRODUCTIOSBRN;30DT;.1-8,935.86,919 —in PACKER;6,945.3 - S APERF;6,964.0-6,966.0 ti 4 NIPPLE;6,983.5 SOS;6,984.4 i (PERF;7,088.0-7,148.0 1 Cement Plug:6,960.01MB\ LINER;6,612.1-7,545.0\\\ .t.. AL1 LINER;6,954.7-10,808.0 A LINER;8,149.3-10,630.0 KUP PROD III 1C-04AL1 o,...,g Conoc©Phddhhps 5 &YYeYs? Well Attributes Max Angle&MD TD A/aska Inc Wellbore API/UWI Fold Name Wellbore Status:, ncl(°) MD(ftKB) Act Btm(ftKB) ,_ gt� 500292054760 KUPARUK RIVER UNIT PROD l 102.64 7,845.05 10,808.0 ... Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-04A0.1,8/15/2017 9 52'.36 AM 40 9/10/2016 Last WO: 39.01 2/7/1981 Vertical echematp(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date - HANGER:27.8 ',....,,r ,. Last Tag: Rev Reason:SIDETRACK jennalt 8/15/2017 II Casing Strings I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread AL1 LINER 2 3/8 1.992 6,954.7 10,808.0 6,428.6 4.70 L-80 ST L 1- : Liner Details Nominal ID /eygm nu„)..e n,,,,s,,,,s a, nnn.uwx a ,y Top(ftKB) Top(TVD)(ftKB) Top Teel 7) Item Des Com (in) 6,954.7 6,277.2 4.04 SEAL BORE Deployment Sleeve w/6'Sealbore Receptical(PBR) 1.920 lir EXTENSION CONDUCTOR Insulated 32-;� 9,038.5° 6,420.6 95.79 CASING Shorty Deployment Sleeve 1.920 34.0-80.0 HANGER II Notes:General&Safety IREnd Date Annotation 111 NOTE'Blank liner 6955'to 7549'MD GAS LIFT:2,631.1 It SURFACE;33.0-2,910.0 4, GAS LIFT;3,920A I GAS LIFT;4,982.1 GAS LIFT;5,678.0 IE 7 GAS LIFT;6,346.7 ce '3 II GAS LIFT;6,712.4 IF tt LOCATOR;6,769.3 ME SEAL ASSY;6,770.2 PBR;6,775.7 PACKER;6,798.8 al NIPPLE;6,849.3 _j I OVERSHOT;6,901.7 1 SBR w/EXT;6,919.2 PRODUCTION;30.1-8,935.6 - I PACKER;6,945.3 :.:I APERF;6,964.0-6,966.0 NIPPLE:6,983.5 SOS;6,984.4 IPERF;7,088.0-7,148.0 Cement Plug;6,960.0(MB LINER;6,612.1-7,545.0"CGCG(( W A LINER;8,149.3-10,630.0 II AL1 LINER;6,954.7-10,808.0 I I • • Bettis, Patricia K (DOA) � I$O — E From: Herring, Keith E <Keith.E.Herring@conocophillips.com> 2/zut- kci Sent: Thursday, May 25, 2017 3:37 PM To: Bettis, Patricia K (DOA) Subject: RE: [EXTERNAL]KRU 1C-04A (PTD 217-078): Permit to Drill Application Attachments: 1C Pad As-Built-Revl3.pdf Good afternoon Patricia, Attached is the as built from 8/21/15. When placed into the CPAI Coordinate Converter I get the following for the surface location of well 1C-04. 1509.93' FNL,4221.83' FEL, Section 12, T11N, R10E, UM So going off the most recent as built the numbers provided on the permit to drill would be correct. If you need further information please let me know. Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO—664 SCANNED MAY 3 12017, Keith.E.Herring@conocophillips.com ConocoPhillips From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Thursday, May 25, 2017 3:11 PM To: Herring, Keith E<Keith.E.Herring@conocophillips.com> Subject: [EXTERNAL]KRU 1C-04A (PIE) 217-078): Permit to Drill Application Good afternoon Keith, On Form 10-403, Box 4A, it states the surface location of the well to be 1509 FNL,4221' FEL, Section 12,T11N, R10E, U.M. On the Well Completion or Recompletion Report and Log Form 10-407, Box 4,the surface location for the well is 1515' FNL, 1066' FWL, etc. Please verify which footage is correct. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist 1 • • Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 12 7/17/15 JAH SZ Rev. Per K150013ACS 13 8/21/15 NRB JAH Rev. Per K150013ACS LEGEND \KIC'� 2 4: • EXISTING CONDUCTOR K .ARUK plRs= PROECT 1 Q AS BUILT CONDUCTOR THIS SURVEY SWPT ._;1.B 4 GRAPHIC SCALE CPF1 C 0 100 200 400 110 9 SA • 12 PIT /4/ 11 1 inch = 200 ft. 2-�1 V , 11 12 0� O 1. 1615 14 13 11D N • o • o co o • ... o • O (C • • " O • •�� • • •^ IS ') O 00 • '� • • W • ® • O N^ O V. h • • .`� h • do • 0 • •ryN. o ' ;��� • .v. •� • N...'• .' ••r, to .Y� ��ti 83' 30' SEE SHEETS 2 & 3 FOR NOTES AND 04,/44 LOCATION INFORMATION. 1/4%/jz, '0 -*•- -..2-.. ...... e �'?:`� �'• % SURVEYOR'S CERTIFICATE N .V./'� 9th * • I HEREBY CERTIFY THAT I AM PROPERLY REGISTERD AND LICENSED j ,.• ••• • TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND 0 •0 THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER �,'-JEREMIAH F. CORNELL=,oma MY DIRECT SUPERVISION AND THAT ALL NEW DIMENSIONS AND .1 'Co=. LS-12663 •��'e OTHER DETAILS PER THIS REVISION .�'F�,•••.,, :'c04: ARE CORRECT AS OF JULY 16, 2015. LOUNSBURY •• Fop -4./‘4,>•''''�,o .• & ASSOCIATES, INC. ..,*eh SURVEYORS ENGINEERS PLANNERS `i AREA:1C MODULE: XXXX UNIT: D1 ConocoPhillips DS1C WELL CONDUCTORS Alaska, Inc. ASBUILT LOCATIONS CADD FILE NO. DRAWING NO. PART: REV: LK6103d31 6/30/01 CEA-D1 CX-6103D31 1 OF 3 13 • I REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 12 7/17/15 JAH SZ Rev. Per K150013ACS 13 8/21/15 NRB JAH Rev. Per K150013ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 12, T11N, R1OE NAD27 NAD27 Section WELL ASP Coordinates Geographic Coordinates Offset Elev. No. 'Y' 'X' LATITUDE LONGITUDE F.N.L F.W.L PAD O.G. 1 5,968,523.00 562,372.00 N 70'19'28.291" W 14929'39.295" 1,717' 1,363' N/A N/A 2 5,968,590.00 562,271.00 N 70'19'28.958" W 14929'42.227" 1,649' 1,263' N/A N/A 3 5,968,656.00 562,172.00 N 7019'29.615" W 149'29'45.100" 1,582' 1,164' N/A N/A 4 5,968,727.00 562,065.00 N 70'19'30.322" W 149'29'48.207" 1,510' 1,058' N/A N/A 5 5,968,793.00 561,965.00 N 70'19'30.979" W 149'29'51.110" 1,442' 958' N/A N/A 6 5,968,860.00 561,864.00 N 7019'31.647" W 149'29'54.042" 1,375' 859' N/A N/A 7 5,968,926.00 561,765.00 N 7019'32.304" W 149'29'56.916" 1,308' 760' N/A N/A 8 5,968,993.00 561,664.00 N 70'19'32.971" W 149'29'59.848" 1,240' 660' N/A N/A 9 5,968,851.99 561,548.05 N 70'19'31.593" W 149'30'03.267" 1,381' 542' N/A N/A 10 5,968,763.33 561,680.92 N 70'19'30.711" W 149'29'59.409" 1,471' 674' N/A N/A 11 5,969,008.74 561,641.06 N 70'19'33.128" W 149'30'00.514" 1,225' 637' 60.4' 55.0' 12 5,969,000.20 561,653.40 N 7019'33.043" W 149'30'00.156" 1,234' 649' 60.4' 55.1' 13 5,968,842.13 561,891.29 N 70'19'31.469" W 149'29'53.250" 1,394' 885' 60.4' 55.0' 14 5,968,672.21 562,146.39 N 7019'29.777" W 14929'45.844" 1,566' 1,139' 60.4' 55.0' 15 5,968,605.15 562,247.15 N 70'19'29.109" W 14929'42.919" 1,634' 1239' 60.3' 55.0' 16 5,968,825.37 561,916.31 N 70'19'31.302" W 149'29'52.523" 1,411' 910' 60.3' 55.0' 17 5,968,838.00 561,568.78 N 70'19'31.454" W 149'30'02.665" 1,395' 563' 60.5' 56.2' 18 5,968,758.80 562,016.22 N 70'19'30.639" W 14929'49.623" 1,478' 1,010' 60.4' 55.0' 19 5,968,624.28 562,368.18 N 70'19'29.287" W 149'29'39.382" 1,616' 1,360' 59.1' 52.3' 20 5,968,622.03 562,222.10 N 7019'29.277" W 149'29'43.646" 1,601' 1,191' 60.3' 55.0' 21 5,968,637.75 562,198.12 N 70'19'29.434" W 14929'44.342" 1,617' 1,214' 60.6' 55.0' 22 5,968,646.48 562,334.93 N 70'19'29.508" W 149'29'40.347" 1,593' 1,327' 59.1' 51.6' 23 5,968,579.61 562,285.45 N 70'19'28.855" W 149'29'41.807" 1,660' 1,277' 60.3' 55.2' 24 5,968,571.44 562,297.94 N 7019'28.773" W 149'29'41.445" 1,668' 1,290' 60.3' 55.2' 25 5,968,546.47 562,335.47 N 70'19'28.525" W 149'29'40.355" 1,693' 1,327' 60.2' 55.0' 26 5,968,538.05 562,347.93 N 70'19'28.441" W 149'29'39.994" 1,702' 1,339' 60.2' 55.0' 27 5,968,529.79 562,360.58 N 70'19'28.358" W 14929'39.626" 1,710' 1,352' 60.2' 55.0' 28 5,968,689.43 562,121.21 N 70'19'29.948" W 14929'46.575" 1,548' 1,114' 60.6' 55.0' 101 5,968,821.46 561,593.72 N 70'19'31.289" W 149'30'01.941" 1,412' 588' 60.6' 56.7' NOTES: 1. BASIS OF LOCATION AND ELEVATION IS DS1C MONUMENTATION LOUNSBURY PER LOUNSBURY & ASSOCIATES. & ASSOCIATES, INC. 2. COORDINATES SHOWN ARE ASP, ZONE 4, NAD27 SURVEYORS ENGINEERS PLANNERS 3. ELEVATIONS ARE BPMSL AREA:1C MODULE: XXXX UNIT: D1 ConocoPhillips DS1C WELL CONDUCTORS Alaska, Inc. ASBUILT LOCATIONS CA D FILE NO.LK6103d31 6/30/01 DRAWING NO. CEA-D1 CX-6103D31 PART: REV: 2 OF 3 13 • • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 12 7/17/15 JAH SZ Rev. Per K150013ACS 13 8/21/15 NRB JAH Rev. Per K150013ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 12, T11 N, R1 OE NAD27 NAD27 Section WELL ASP Coordinates Geographic Coordinates Offset Elev. No. 'Y' 'X' LATITUDE LONGITUDE F.N.L F.W.L PAD O.G. 102 5,968,813.50 561,606.18 N 70'19'31.210" W 149'30'01.579" 1,420' 600' 60.6' 56.7' 104 5,968,796.65 561,631.04 N 70'19'31.042" W 149'30'00.857" 1,437' 625' 60.6' 56.7' 106 5,968,779.74 561,656.61 N 7019'30.874" W 149'30'00.115" 1,454' 650' 60.7' 56.7' 109 5,968,746.59 561,706.13 N 7019'30.544" W 149'29'58.678" 1,487' 699' 60.7' 56.6' 111 5,968,730.13 561,731.01 N 70'19'30.380" W 149'29'57.955" 1,504' 724' 60.7' 56.5' 113 5,968,713.56 561,755.87 N 70'19'30.215" W 149'29'57.234" 1,521' 749' 60.7' 56.5' 115 5,968,696.96 561,780.86 N 70'19'30.050" W 149'29'56.508" 1,538' 774' 60.7' 56.4' 117 5,968,680.39 561,805.95 N 70'19'29.885" W 149'29'55.780" 1,555' 799' 60.8' 56.3' 119 5,968,664.02 561,830.61 N 70'19'29.722" W 149'29'55.064" 1,571' 823' 60.8' 56.2' 121 5,968,646.80 561,856.20 N 70'19'29.550" W 149'29'54.321" 1,589' 849' 60.8' 56.1' 123 5,968,630.35 561,880.54 N 70'19'29.387" W 149'29'53.614" 1,605' 873' 60.8' 55.9' 125 5,968,613.75 561,905.78 N 70'19'29.221" W 14929'52.882" 1,622' 898' 60.8' 55.8' 127 5,968,597.14 561,930.71 N 70'19'29.056" W 14929'52.158" 1,639' 923' 60.8' 55.7' 129 5,968,580.60 561,955.57 N 70'19'28.891" W 14929'51.436" 1,656' 947' 60.8' 55.6' 131 5,968,563.88 561,980.83 N 70'19'28.725" W 149'29'50.703" 1,673' 973' 60.8' 55.5' 133 5,968,547.28 562,005.48 N 70'19'28.559" W 149'29'49.987" 1,690' 997' 60.8' 55.4' 135 5,968,530.55 562,030.50 N 70'19'28.393" W 149'29'49.261" 1,707' 1,022' 60.8' 55.5' 150 5,968,712.22 562,235.32 N 7019'30.163" W 149'29'43.239" 1,527' 1,228' 58.2' 52.5 151 5,968,922.96 561,919.46 N 7019'32.261" W 149'29'52.408" 1,313' 914' 58.4' 55.0' *152* 5,968,956.10 561,869.93 N 7019'32.591" W 149'29'53.846" 1,279' 865' 57.6' 55.0' *153* 5,968,939.48 561,894.98 N 70'19'32.426" W 14929'53.118" 1,296' 890' 57.6' 55.0' *154* 5,968,757.31 562,168.40 N 70'19'30.612" W 149'29'45.181" 1,481' 1,162' 57.6' 53.2' *155* 5,968,690.68 562,268.34 N 70'19'29.948" W 149'29'42.280" 1,548' 1,261' 57.6' 52.2' 170 5,968,823.66 562,068.55 N 70'19'31.273" W 14929'48.080" 1,414' 1,063' 59.1' 54.1' 172 5,968,801.43 562,101.96 N 70'19'31.051" W 149'29'47.110" 1,436' 1,096' 59.1' 53.8' 174 5,968,779.41 562,135.06 N 70'19'30.832" W 149'29'46.149" 1,458' 1,129' 59.2' 53.5' 178 5,968,735.16 562,201.72 N 70'19'30.391" W 149'29'44.214" 1,503' 1,195' 59.2' 52.9' 184 5,968,668.66 562,301.70 N 70'19'29.729" W 149'29'41.311" 1,571' 1,294' 59.1' 51.8' 190 5,968,602.07 562,401.26 N 70'19'29.066" W 149'29'38.421" 1,638' 1,393' 59.1' 51.5' ** ASBUILT CONDUCTOR THIS SURVEY LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS TtO `.i AREA:1C MODULE: XXXX UNIT: D1 ConocoPhillips DS1C WELL CONDUCTORS Alaska, Inc. ASBUILT LOCATIONS CA D FILE NO.LK6103d31 6/30/01 DRAWING NO. CEA-D1 CX-6103D31 PART: REV: 3 OF 3 13 • • Bettis, Patricia K (DOA) ?i+� / Q — From: Bettis, Patricia K(DOA) Sent: Thursday, May 25, 2017 3:50 PM To: Herring, Keith E Subject: RE: [EXTERNAL)KRU 1C-04A(PTD 217-078): Permit to Drill Application Thanks Keith, I'll update the original footage for the KRU 1C-04 well so that I can proceed to put the KRU 1C-04A wellbore trajectory into the AOGCC database. Patricia From: Herring, Keith E [mailto:Keith.E.Herring@conocophillips.com] Sent:Thursday, May 25,2017 3:37 PM To: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: RE: [EXTERNAL]KRU 1C-04A(PTD 217-078): Permit to Drill Application Good afternoon Patricia, Attached is the as built from 8/21/15. When placed into the CPAI Coordinate Converter I get the following for the surface location of well 1C-04. 1509.93' FNL,4221.83' FEL,Section 12,T11N, R10E, UM So going off the most recent as built the numbers provided on the permit to drill would be correct. If you need further • information please let me know. "" Thanks, Keith Herring CTD Engineer 907.263.4321(Office) SCANNED !� . INt� 907.570.2410(Mobile) 700 G Street,ATO—664 Keith.E.Herring@conocophillips.com ConocoPhillips Alaska From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Thursday, May 25, 2017 3:11 PM To: Herring, Keith E<Keith.E.Herring@conocophillips.com> Subject: [EXTERNAL]KRU 1C-04A(PTD 217-078): Permit to Drill Application Good afternoon Keith, 1 i • On Form 10-403, Box 4A, it states the surface location of the well to be 1509 FNL,4221' FEL,Section 12,T11N, R10E, U.M. On the Well Completion or Recompletion Report and Log Form 10-407, Box 4,the surface location for the well is 1515' FNL, 1066' FWL,etc. Please verify which footage is correct. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.Bov. 2 • • OF TALI, (%%y �9 THE STATE Alaska Oil and Gas n ufAL LA sKA Conservation Commission ! 333 West Seventh Avenue rti GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ,.,;"' e, Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Keith Herring WOO (1 CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 C-04 Permit to Drill Number: 180-155 Sundry Number: 317-196 Dear Mr. Herring: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ,;AG:474. Cathy P Foerster Chair DATED this //71y of May, 2017. RBDMS MAY 1 9 2017 0 • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 11 2017 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations Q Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill Q• Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development Q • 180-155 . 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: PO Box 100360,Anchorage AK 99510 50-029-20547-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No Q / KRU 1C-04 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25649 ' Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7575'• 6896' • 7456' . 6777' • 3194 psi N/A 7258' Casing Length Size MD TVD Burst Collapse Conductor 46' 20" 80' 80' 1530 psi 520 psi Surface 2877' 13-3/8" 2910' 2708' 5380 psi 2670 psi Production 6906' 9-5/8" 6936' 6258' 5750 psi 3090 psi Liner 933' 7" 7545' 6866' 4980 psi 4320 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7088'-7148'• 6410'-6470' 7208'-7218' , 6530'-6540' 3-1/2" L-80/K-55 6986' Packers and SSSV Type: Baker FHL Retrievable Packer Packers and SSSV MD(ft)and TVD(ft): / 6799'MD/6122'TVD Baker FHL Packer , 6945'MD/6268'TVD 12.Attachments: Proposal Summary ❑✓ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q , Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 5/24/2017 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑., ' 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Keith Herring Contact Name: Keith Herring Authorized Title: CTD Engineer Contact Email: Keith.E.Herringta7.conocophillips.Corn //// Contact Phone: 263-4321 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 t—r- kc., Plug Integrity ❑ BOP Test Er Mechanical Integrity Test ❑ Location Clearance ❑ W f 9 ),11‘'q Other: /30 p tf 5,1-- /-o pc)� I�5f �0 2Sov t fi -Invlai' pvc'VC 7 e 5 i lvq p[ctCt z�tv Ap19e' r v'," St vrrc, � 1Z � Post Initial Injection MIT Req'd? Yes ❑ No Er p ✓ ,70/4t-A-6 2 5-. L ) Spacing Exception Required? Yes ❑ No LJ Subsequent Form Required: I 0 ' 1 °- RBDMS w MAY 1 9 2017 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:s/ 7—l 7 PeZ 3�� �- Submit Form and 0RrivGlpNiAsLidForm 10-403 Revise 4/2017 for 12 months from the date of approval. Attachments in Duplicate • • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 MAY 1 1 2017 May 11, 2017 ADCC Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications to plug the KRU 1C-04 (PTD#180-155) by cementing up the perforation to allow CTD operations to drill a dual-lateral out of the KRU 1 C-04 using the coiled tubing drilling rig, Nabors CDR3-AC. A sundry application is attached to plug the KRU 1C-04 perforations to allow these laterals to be drilled. As detailed in the attachments, ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the C-sand perforations in this manner. Attached to this application are the following documents: — 10-403 Sundry Application for KRU 1C-04 — Operations Summary in support of the 10-403 sundry application — Proposed CTD Schematic — Current Well Bore Schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, .7)((ort Keith Herring ConocoPhillips Alaska Coiled Tubing Drilling Engineer • . KRU 1C-04 CTD Summary for Plugging Sundry (10-403) Summary of Operations: KRU well 1 C-04 is a Kuparuk C-sand producer equipped with 3-1/2" tubing and 7" production liner. The CTD sidetrack will utilize two laterals to target the C3 and C4 sands to the northwest of 1 C-04. The laterals will increase C-sand resource recovery and throughput. Prior to CTD operations, E-Line will punch 2' of holes in the 3-1/2" tubing tail at 6964' RKB and the "D" nipple at 6984' RKB will be milled out to a 2.80" ID. The existing C-sand perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A-sand and C-sand perforations in this manner. Following the cement squeeze Nabors CDR3-AC will drill a pilot hole to 7180' MD and set a mechanical whipstock in the 2.80" pilot hole to kick off at 7150' MD. The two laterals will be completed with 2-3/8" slotted liner from TD with the final liner top located inside the 3-1/2" tubing tail. Using the maximum formation pressure in the area of 3,841 psi in 1 C-02, the maximum potential surface pressure in 1C-04, assuming a gas gradient of 0.1 psi/ft, would be 3,194 psi. CTD Drill and Complete 1C-04 Laterals: Early June 2017 Pre-CTD Work 1. RU Slickline: Obtain SBHP, change out GLV's, and pressure test. 2. RU E-line: Punch 2' of holes in the 3%" tubing tail at 6964' RKB. 3. RU Pumping Unit: perform injectivity test down the tubing. 4. RU Service Coil: Mill out "D" nipple and cement C-sand perforations up to the holes in the tubing tail. 5. RU Slickline: Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR3-AC and set BPV. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1C-04A Sidetrack (C3/C4 sand - Northwest) a. Drill 2.80" pilot hole through cement to 7180' MD b. Caliper pilot hole c. Set top of whipstock at 7150' MD d. Mill 2.80" window at 7150' MD. e. Drill 3" bi-center lateral to TD of 11200' MD. f. Run 2%" slotted liner with an aluminum billet from TD up to 7950' MD. 3. 1 C-04AL1 Lateral (C3/C4 sand - Northwest) a. Kick off of the aluminum billet at 7950' MD. b. Drill 3" bi-center lateral to TD of 11200' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 6970' MD. Page 1 of 2 5/11/2017 • 4. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CRD3-AC. Post-Rig Work 1. Pull BPV 2. Obtain SBHP 3. Return to production /effect& w s'f' yr lei`CA'f ©f 1„ Z&4' iervn rheaid coM�v= 1.4„,1-4 .1/.>ret/ fi t7 t 44k 41-6 /►,oriferbre prod 74vs W" le 9J/e To I CO.ee- 4� . /cMv.;4 re f Ct too ative car de Cu//P/1, /OCrili Uh J4//7 Page Page 2 of 2 5/11/2017 • • 1C-04 Proposed CTD Schematic IIII 4-1/2"x 3-1/2"9.3#L-80 EUE 8rd to surface 20"94#H-40 shoe 3-1/2"Camco MMG gas lift mandrel @ 2631',3920',4982', @ 80'MD 5678',6347' 13-3/8"72#N-40 Baker Tie Back Sleeve @ 6612'RKB shoe @ 2910'MD Baker Seal Nipple @ 6618'RKB Baker Liner Hanger @ 6622'RKB 3-1/2"Camco MMG gas lift mandrel @ 6712' Baker 80-40 Seal Assy @ 6770'RKB Baker PBR@ 6776'RKB Baker FHL Packer @ 6799'RKB 9-5/8"47#L-80 shoe 11111 @ 6936'MD 3-1/2"Camco DS Nipple @ 6849'RKB w/2.813'ID Baker Poor Boy Overshot @ 6902'RKB _ Baker 3-1/2"PBR @ 6919'MD(3.0"ID) Baker FHL packer @ 6945'MD(3.0"ID) 3-1/2"Camco D landing nipple @ 6984'MD(2.75"min ID,No- Go;1.81"nipple reducer)Mill to 2.80"ID 3-1/2"tubing tail @ 6986'MD KOP @ 7150'MD II C-sand perfs 7088'-7148'MD 1C-04AL1 wp00 TD @ 11,200'MD Liner Top 4 6970'MD A-sand perfs _ _______ --- 7208'-7218'MD 1C-04A wp01 TD @ 11200'MD Liner Billet 47950'MD 7"26#K-55 shoe @ 7545'MD . ' KUP PROD • 1C-04 • CO1�«�ohlIIIp$ • Well Attributes Max Angle&MD TD Alaska,Inc a«PvnWellbore API/UWI Field Name Wellbore Status 17) MD(ftKB) Act Bim(ftKB) , ,,, lps 500292054700 KUPARUK RIVER UNIT PROD Ind 37.98 4,300.00 7,575.0 ..- Comment H2S(ppm) Date Annotation End(Date KB-Grd(ft) 'Rig Release Date 1C-04,4/15/201711:53:52 AM SSSV:NONE 40 9/10/2016 Last WO: 1/24/2015 39.01 2/7/1981 Vertical schemah (actual) - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date __... _.__.... _.. - Last Tag:SLM 7,246.0 12/7/2016 Rev Reason:CORRECTED"nipple reducer was pproven 4/15/2017 HANGER;27.8- IJ"(ISi pulled 2/6/2015" Casing Strings _ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(NO)...Wt/Len(I...Grade Top Thread CONDUCTOR Insulated 20 18.940 34.0 80.0 80.0 94.00 H-40 WELDED I f32" Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WULen(I...Grade Top Thread ' _ _ SURFACE 133/8 12.347 33.0 2,910.0 2,707.8 72.00 N-40 BTC ,,,,,,Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread PRODUCTION 95/8 8.861 30.1 6,935.6 6,258.1 47.00 L-60 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 1 t LINER 7 6.276 6,612.1 7,545.0 6,866.3 26.00 K-55 BTC CONDUCTOR Insulated 32°, '' Liner Details 34.0-80.0 Nominal ID I Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) • 6,612.1 5,935.6 5.65 TIE BACK BAKER TIE BACK SLEEVE 6.151 In 6,618.2 5,941.7 5.60 NIPPLE BAKER SEAL NIPPLE 6.151 GAS LIFT;2,631.1 t 6,621.5 5,945.0 5.58 HANGER BAKER LINER HANGER 6.151 IN 6,631.6 5,955.0 5.50 XO BUSHING BAKER XO CENTRALIZER BUSHING 6.151 i Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-WO-2015 31/2 2.992 27.8 6,910.0 6,232.5 9.30 L-80 EUE Srd Mod SURFACE;33.D-2,910.0--4, -41/2x31/2@62.8 Completion Details Nominal ID GAS LIFT;3,920.4 E Top(ftKB) Tap(NG)(ftKB) Top Incl(°) Item Des Com (in) 27.8 27.8 0.06 HANGER FMC GEN 3 HANGER WITH LH ACME LIFT THREAD 3.958 62.8 62.8 0.13 XO Reducing Crossover Pup 4 1/2"IBTM 0 3 1/2"EUE Bid 2.992 6,769.3 6,092.2 4.38 LOCATOR GBH LOCATOR SUB 2.980 6,770.2 6,093.2 4.38 SEAL ASSY 80-40 SEAL ASSEMBLY 2.990 1.1 6,775.7 6,098.6 4.33 PBR BAKER 80-40 PBR(20') 4.000 GAS LIFT;4,982.1 6,798.8 6,121.7 4.14 PACKER BAKER 4782 FHL RETRIEVABLE PACKER 2.960 U 6,849.3 6,172.0 4.10 NIPPLE CAMCO DS NIPPLE 2.813 ■ 6,901.7 6,224.3 4.07 OVERSHOT BAKER POOR BOY OVERSHOT 3.590 GAS LIFT;5,878.0 a Tubing Description (String Ma...'ID(in) 'Top(ftKB) 'Set Depth(ft..f Set Depth(ND)(...I Wt(15/ft) 'Grade 'Top Connection ElTUBING-ORIGINAL 31/2 2.992 6,9040 6,986.41 6,308.6 9.20 K-55 BTC • Completion Details Nominal ID GAS LIFT;6,3461 Top(ftKB) Top(ND)(ftKB) Top Incl 7) Item Des Com (in) II 6,919.2 6,241.7 4.06 SBR w/EXT BAKER KB4 SBR 3.000 6,945.3 6,267.8 4.04 PACKER BAKER FHL PACKER 3.000 Me MI 6,983.5 6,305.9 4.02 NIPPLE CAMCO D NIPPLE NO GO(1.81"NIPPLE REDUCER 1.810 _ = SET 9/17/14-PULLED 2/6/2015) `a ra 6,984.4 6,306.8 4.02 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl sII Top(ftKB) (960) (°) Des Com Run Date ID(i n) 6,990.0 6,312.3 4.02 FISH E-LINE SPINNER 2"Lang x 1/4"Wide 8/20/2014 GAS LIFT;6,712.4 II • Perforations&Slots a - Shot IN Dens Top(ND) Btm(ND) (sh s/f LOCATOR;6,769.3 .. Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com SEAL ASSY;6,770.2 -iii,' 7,088.0 7,148.0 6,410.1 6,470.0 C-4,C-3,C-2, 2/7/1981 4.0 IPERF 1C-04 PBR;6,775.7 PACKER;6,798.8 7,208.0 7,218.0 6,529.9 6,539.8 C-1,UNIT B, 2/7/1981 4.0 (PERF 1C-04 Mandrel Inserts St aB NIPPLE;8,849.3 on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,631.1 2,466.5 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 2/6/2017 2 3,920.4 3,551.9 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,199.0 2/5/2015 3 4,982.2 4,397.7 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.188 0.0 2/4/2015 4 5,678.0 5,018.9 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/31/2015 5 6,346.7 5,671.8 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/31/2015 OVERSHOT;6,901.7 6 6,712.4 6,035.5 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 1/31/2015 Notes:General&Safety End Date Annotation SBR w/EcT;6,919.2 12/25/2002 NOTE:WAIVERED WELL:IA X OA COMMUNICATION PRODUCTION;30.1-6,935.6Ili 8/10/2010 NOTE:View Schematic w/Alaska Schematic9.0 PACKER;6,945.3 8/16/2014 NOTE:LEAK AT 5763';3"SPINNER STILL IN HOLE. 1/24/2015 NOTE:WORKOVER NIPPLE;6,983.5 SOS;6,984.4 FISH;6,990.0 IPERF;7,088.0-7,148.0 IPERF;7,208.0-7,218.0- 4-- LINER;6,612.1-7,545.0 ,208.0-7,218.0LINER;8612.1-7,545.0 + a- • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon"or "Suspend"boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon"box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial / then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD"into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill"code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill"comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. LOU • • 011 I CD 1 r-r > wry Q 0 0 N 00 . CD 0N td -tO C rC CT > �1 O Ea V w r0 .` fa +JO v,C a u a a c C .� 0 La @ a C � '_' - .,� -0 CO 0 _ _6 W H oL O t o a, Q 00 ". ;; r r r r r r r a, Oa 0 m s.O . E t -0 0 (/) ts CD ck '.0 i..".O Q Q Q Q Q Q Q S @ vNi G N f- O 0 0 N N N N O coC U - O N Z Q U -0 fo 0 .,.- Z < 0 a) > E aJ T. 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O Q) O O) .:3) O) y n NNNNNN 01 0 0 0 0 0 0 (a 0 0 0 0 0 0 +, O u O u) 1.0 u) 10 10 a u }, r E o y .O v a _ T E L To N N In CU cu d r4 dz ++ OA �� O N m 0 +' ++CLI i- 1q Lf) jys�;'I �_ C = a Q O U M M M ( y T .= r t n co c z H H aL a Q • • Kett t(•C 4- 1)1 (maccgo Regg, James B (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Wednesday,July 27, 2016 5:04 PM To: Regg, James B (DOA) 1-2 ‘ 71 it / Cc: Cook, Guy D (DOA); Brooks, Phoebe L(DOA) Subject: RE: KRU 1C-04 Missing Well Sign Attachments: 2016-0718_Deficiency_KRU_1C-04 07-27-16.pdf Deficiency corrected: Bob Christensen/ Darrell Humphrey NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7535 Kuparuk Pager: 659.7000;#924 CPAI Internal Mail: NSK-69 From: Regg,James B (DOA) mailto•iim.regg@ala ka.gov Sent: Monday,July 25, 2016 3:44 PM To: NSK Prod Engr Specialist<n1139@conocophillips.com> Cc: Cook, Guy D (DOA)<guv.cook@alaska.gov> Subject: [EXTERNAL]KRU 1C-04 Missing Well Sign KRU 1C-04 PTD 1801550 Attached deficiency report was inadvertently forgotten during the Inspection but is documented on the Inspector's SVS Test Report (also attached). This is provided for your records and to ensure the deficiency is corrected. Please provide photo evidence of the well sign after installation when you return the completed deficiency report(date corrected). Thank you. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave,Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907-793-1236 or jim.regg@alaska.gov<mailto:iim.regg@alaska.gov>. 1 ^ ���V ������ �� ~ 7����g Y4c'y4 .\ _`t4« ( / State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: KRU1C-V4 . Date: 7/18/2016 PTD: 1801550 ^ ' Operator: CPAI ' Type Inspection: SVS Operator Rep: Lou Laubenstein - Inspector: Guy Cook ' Position: Op.Phone: 907-659-7229 ^ Correct by(date): 8/15/2016 Op.Email: n2062VmconocophUUps.com Follow Up Reqd: Yes Detailed Description of Deficiencies Date Corrected Missing well sign;refer to 20 AAC 25.040 ' ~ 7/27/16 „,G�nins�Ued . 1 1 |� � ^/ Attachments: Well sign photo /~ � \�' ` Operator '-`\`c- - -~��•+~~��c.°-�~~� Rep Signatures: \ \ ' AOGCC Inspecto *After signing,a copy of this form is to be left with the operato Follow-up Instructions ReturnacmpvofN`|sor0demynepo�*oAosCc��enoo*|�pccunos°pcnx,o�wuh�7d�oof�ce�� Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,Include the date and name of Inspector. Extensions for corrective actions taking longer than the'correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of deU;ienccs that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 • 4 M lost I,-M #: # ' to Imam WI!R OW RIULU.illa MIL SI ,. .. T ' mill I . 1,...,___. _. P I „.. . „. , ,,,,. ..,,, r., ,. .,...... .,.., .. ..., I s • 5 I , . . . _ . , . . , _.,. . . ' , ,.. .. . , , , . . . ,, . . . a '1 ♦ v . .�. '►. .r t . •. • .. a x;, fi y"•' �. r4 w 1 w , • - wiTOCO1�1i111ip AI is1't Ind'LIri „ •i x ~ ' �� �,{y 7 1i,. } � • nl,, l 5-- iii hltcl.P r1 In il1ie i t k4rnc ., w. tr, ,,meq STATE OF ALASKA AL1. A OIL AND GAS CONSERVATION COMN..,,SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed. Abandon r Repair w ell r Rug Perforations r Perforate r Other r Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 180-155 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-20547-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25649 KRU 1C-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: ' Total Depth measured 7575 feet Plugs(measured) none true vertical 6896 feet Junk(measured) 6990 Effective Depth measured 7456 feet Packer(measured) 6799,6945 true vertical 6777 feet (true vertical) 6122,6268 Casing Length Size MD TVD Burst Collapse CONDUCTOR 46 20 80 80 SURFACE 2877 13.375 2910 2708 PRODUCTION 6906 9.625 6936 6258 LINER 933 7 7545 6866 �o 5 701,-- RECEIVED Perforation depth: Measured depth: 7088-7148, 7208-7218 FEB 2 0 2015 True Vertical Depth: 6410-6470,6530-6540 AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80/K-55,6986 MD,6306 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER 4762 FHL RETRIEVABLE PACKER @ 6799 MD and 6122 ND PACKER-BAKER FHL PACKER @ 6945 MD and 6268 ND no SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development F Service r Stratigraphic r 16.Well Status after work: Oil r' Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt. none Contact Jonathan Coberly Cad 265-1013 Email Jonathan.Coberlyaconocophillips.com Printed Name Jonathan Coberl ' Title Sr. Wells Engineer Signature Z Phone:265-1013 Date Z/f?/2076 curl✓ z/23// 5— RBDMS - FEB Z 3 2015 .27/2„///3- Form 10-404 Revised 10/2012 Submit Original Only KUP PROD 1C-04 Conoc P fillips ' Well Attributes [Max An &MD rD t"" .,T Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Alaska.Inc. = -4. r...rr,wL, ''` 500292054700 KUPARUK RIVER UNIT PROD 37.98 4,300.00 7,575.0 a °.- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-04,21020159:58.04 AM SSSV:LOCKED OUT 75 12/16/2013 Last WO: 2/1/2015 39.01 2/7/1981 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .... ......... ____..Last Tag: SLM 7,251.0 2/6/2015 Rev Reason:GLV C/O,PULL NIPPLE hipshkf 2/8/2015 Hanger,27.8 ..' REDUCER,TAG,PULL PLUG Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR Insulated 20 18.940 34.0 80.0 80.0 94.00 1-1-40 WELDED C2 { Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread SURFACE 133/8 12347 33.0 2,910.0 2,707.8 72.00 N-40 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(L..Grade Top Thread ImL PRODUCTION 95/8 8.861 30.1 6,935.6 6,258.1 47.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade 'Top Thread Ti LINER 7 6276 6,612.1 7.545.0 6,866.3 26.00 K-55 BTC CONDUCTOR Insulated32",J & Liner Details Nominal ID a Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 11 6,612.1 5,935.6 5.65 TIE BACK BAKER TIE BACK SLEEVE 6.151 1 6,618.2 5,941.7 5.60 NIPPLE BAKER SEAL NIPPLE 6.151 Mandrel,2,631,1 t 6,621.5 5,945.0 5,58 HANGER BAKER LINER HANGER 6.151 ® 6,631.6 5,955,0 5.50 XO BUSHING BAKER XO CENTRALIZER BUSHING 6.151 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection Tubing-RWO 2015 312 2,992 27.8 6,910.0 6,232.5 930 L-80 EUE 8rd Mod SURFACE:33 0-2,910.0. 4k Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) Mandrel;3,920.4 g- 27.8 27.8 0.06 Hanger FMC GEN 3 Tubing Hanger with 53/4"LH ACME Lift 3.958 Threads 6,769.3 6,0922 4.38 Locator GBH-22 Locator Sub(bottom of locator spaced out 6.13') 2.980 6,770.2 6,093.2 4.38 Seal Assembly 80-40 Seal Assembly(total seal assembly=21.66') 2.990 II Mandrel,4982.1 . 6,775.7 6,098.6 4.33 PBR Baker 80-40 PBR(20') 4.000 1i 6,798.8 6,121.7 4.14 Packer Baker 47B2 FHL Retrievable Packer 2.960 is6,849.3 6,172.0 4.10 Nipple Camco 2.813"'DS'Nipple SN:T091421 2.813 a 6,901.7 6,224.3 4.07 Poor Boy Baker Poor Boy Overshot(7.64'swallow;spaced out 1') 3.590 Mandrel,5,6780 I Overshot ii Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(tt..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection a Original TUBING- 3 1/2 2.992 6,904.0 6,986.4 6,308.8 920 K-55 BTC Remaining RWO 1 2015 Mandrel;6,346.7 VCompletion Details a Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 6,919.2 6,241.7 4.06 SBR w/EXT BAKER K84 SBR 3.000 6,945.3 6,267.8 4.04 PACKER BAKER FHL PACKER 3.000 4'. ,r. 6,983.5 6,305.9 4.02 NIPPLE CAMCO D NIPPLE NO GO(1.81"NIPPLE REDUCER 1.810 SET 9/17/14) 6,984.4 6,306.8 4 02 SOS BAKER SHEAR OUT SUB 2.992 Other in Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) , Mandrel.6,712.4 II Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) 6,990.0 6,312.3 4.02 FISH -E-LINE SPINNER 2"Long x 1/4"Wide 8/20/2014 I Perforations&Slots Locator;6,769.3 0 Shot Seal Assembly,6,770.2 Dens Top(TVD) Btm(TVD) )shotstt PER 6,775.7 = Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn Packer,6,798.8 '' 7,088.0 7,148.0 6,410.1 6,470.0 C-4,C-3,C-2, 2/7/1981 4.0 IPERF a 1C-04 a 7,208.0 7,218.0 6,529.9 6,539.8 C-1,UNIT B, 2/7/1981 4.0 IPERF 1C-04 Nipple,6,849 3 Mandrel Inserts I St ati N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn -1' 2,631.1 2,466.5 Camco MMG 11/2 GLV RK 0.188 1,193.0 2/5/2015 I 2 3,920.4 3,551.9 Camco MMG 11/2 GLV RK 0.188 1,199.0 2/5/2015 3- 4,982.2 4,397.7 Camco MMG 11/2 OV RK 0.188- 2/4/2015 Poor Boy Overshot,6,901.7 4 5.678.0 5,018.9 Camco MMG DMY RK 1/31/2015 5 6,346.7 5,671.8 Camco MMG DMY RK 1/31/2015 6 6,712.4 6,035.5 Camco MMG DMY RK 1/31/2015 SBR w/EXT;6,919.2 Notes:General&Safety PRODUCTION;30.1-6,935.6- End Date Annotation 12/25/2002 NOTE:WAIVERED WELL:IA X OA COMMUNICATION PACKER;6,945.3 -' Ill 8/10/2010 NOTE:View Schematic w/Alaska Schematic9.0 -- NIPPLE,6,983.5 8/16/2014 NOTE:LEAK AT 5763';3"SPINNER STILL IN HOLE. SOS 6,984.4 FISH,6,990 0 (PERF;7,088.0.7,148.0 IPERF;7.208 0-. LINER,6,612.1-7.545.0 1C-04 WELL WORK SUMMARY DATE SUMMARY PRE-RIG WELL WORK 10/4/2014 (Pre-RWO): FT LDS (ALL FUNCTIONED PROPERLY), T POT PASSED. T PPPOT PASSED. IC POT PASSED. IC PPPOT PASSED. 11/26/2014 PULLED CA-2 @ 6983' RKB. PULLED DV @ 6882' RKB. SET 2.72 x 29"AVA CATCHER @ 5753" RKB. PULLED OV© 4583' RKB. IN PROGRESS. 11/27/2014 SET DV©4583' RKB. PULLED GLV SET DV© 2198' RKB. PULLED CATCHER @ 5753' RKB. READY FOR E/L TBG CUT. 11/29/2014 RUN 1: FIRE 160 GR/FT STRING SHOT FROM 6901.5'TO 6906.5'. RUN 2: CUT TUBING AT 6904' USING RCT 2000 200 SP. LOGS CORRELATED TO TUBING DETAIL RECORD DATED 06 FEB 1981. WHILE CLEANING TOOLS POST JOB, NOTICED THREE BROKEN BOWSPRINGS FROM THE BOTTOM CENTRALIZER. TWO PIECES WERE LEFT IN THE HOLE, DIMENSIONS: 5.5"x0.5"x.0625"AND 0.5"x0.5"x.0625". READY TO SET BPV. ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 1C-04 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 1/26/2015 5:00:00 AM Rig Release: 2/1/2015 8:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 31/24/2015 24 hr Summary Rig down and prepare for move to 1C-04. Move satellite camp, shop and pits complex to 1C pad. Move sub off 2H-14, lay down the derrick, and move sub to the entrance of 2H pad. 14:00 19:30 5.50 0 0 MIRU MOVE RURD P Secure top drive in rotary table. Bridle up the blocks. Lower cattle shoot. Break Kelly hose connection. Remove berming around pits,cutting tank,and sub. 19:30 00:00 4.50 0 0 MIRU MOVE MOB P Hook up trucks to the satellite camp. Jack up the pits and move cuttings tanks. Pull pits out and install Jeep. Jack up rig sub and remove mats. Move off 2H-14, lay down the derrick, and move sub down to the entrance of 2H pad.. 01/25/2015 Move rig from 2H pad to 1C pad. Raise the derrick, spot rig over well 1C-04, move pits into place. 00:00 06:00 6.00 0 0 MIRU MOVE MOB P Clean up pad and around cellar. Move rig from 2H pad to CPF-2 and wait for field change out. Satellite camp, shop, and pits arrived on 1C pad at 01:00 hours 06:00 15:00 9.00 0 0 MIRU MOVE MOB P After field change out, move rig from CPF-2 to 1C-pad. 15:00 00:00 9.00 0 0 MIRU MOVE MOB P Raise the derrick, hang tree in the cellar, level matting boards around cellar,and lay herculite. Spot and level rig over well 1C-04. Move pit into place, lay herculite,set cuttings tank, level and set pit. 01/26/2015 Berm pits,cutting tank,fuel tank, and cellar. Go through rig acceptance checklist and accept the rig at 05:00 hours. Load the pits with 9.5 ppg brine. Lubricate out the BPV. Unable to get lubricator off the tree due to leaking swab and master valve; called out the grease crew to service the tree and lay down lubricator. Begin well kill operation. Reverse diesel cap out of the tubing then start circulating conventionally at 2 BPM= 1300 psi(ICP)getting gas with some fluid at surface. Shut down. Strap and empty the kill tank. Load the pits with additional 9.8 ppg brine, mix, and water back to 9.5 ppg brine. 00:00 05:00 5.00 0 0 MIRU MOVE RURD P Berm pits,cuttings tank, fuel tank, and cellar. Hook up interconnect to the pits, check pumps, and all fluid connections. Go through rig acceptance checklist. **RIG ACCEPTED AT 05:00 HOURS** Page 1 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 06:00 1.00 0 0 MIRU MOVE RURD P Bridle Down Blocks. Hook Up Top Drive Hydraulics. SIMOPS: Start loading the pits with 9.5 ppg NaCI brine. 06:00 10:00 4.00 10 0 MIRU MOVE RURD P Continue to bridle down. Secure Rig Floor. Hook up steam to the Cutting Bin. Continue to take on 9.5 lb/gal Brine in the Pits. Rig up Kill Lines. 10:00 11:00 1.00 0 0 MIRU WELCTL MPSP P Pick-up Lubricator and pressure test to 2,000 psi. No surface leaks. Good. Pull the BPV. Tubing pressure= 1,700 psi, Inner Annulus pressure= 1,650 psi. Outer Annulus =940 psi. Unable to get Lubricator off of the Tree. Both the Swab Valve and the Master Valve leaking bad. Call out the Grease Crew to service the Tree. Tree Serviced,Well secured. Lay down Lubricator and BPV. 11:00 13:30 2.50 0 MIRU WELCTL MPSP T Unable to get Lubricator off of the Tree. Both the Swab Valve and the Master Valve leaking bad. Call out the Grease Crew to service the Tree. Tree Serviced,Well secured. Lay down Lubricator and BPV. 13:30 16:30 3.00 0 0 MIRU WELCTL RURD P Rig up kill line to the Tree. Thaw out hard line to the Kill Tank. 16:30 19:30 3.00 0 0 MIRU WELCTL KLWL P PJSM. Notify security and 1C DSO that we will be venting gas. Vent gas to the kill tank. Reverse circulate diesel out of the tubing at 2 BPM= 1640 psi(ICP)after 65 bbls pumped small trace of diesel. Circulate conventionally at 2 BPM= 1300 psi (ICP)getting gas with some fluid at surface. 19:30 21:00 1.50 0 0 MIRU WELCTL KLWL P Shut down. Strap and empty the kill tank. 21:00 22:00 1.00 0 0 MIRU WELCTL WAIT T Waiting on truck with 9.8 ppg brine to arrive. 22:00 00:00 2.00 0 0 MIRU WELCTL COND P Load pits with 9.8 ppg brine, mix, and water back to 9.5 ppg brine. 01/27/2015 Attempt to kill the well with 9.5 ppg NaCI brine,once both the IA and tubing were fluid packed, shut down, and monitored the tubing/IA pressures(tubing=75 psi; IA=50 psi). Bring fluid weight in the pits from 9.5 ppg up to 9.8 ppg brine. Start circulating 9.8 ppg brine and after two hole volumes pumped getting back 9.7 ppg brine. 00:00 06:00 6.00 0 0 MIRU WELCTL KLWL P Resume well kill operation(Tbg= 380 psi; IA= 1090 psi)circulating conventionally at 2 BPM =415 psi (ICP)with 9.5 ppg brine. Had issues getting clean fluid due to multiple holes in the tubing string. Got 9.5 ppg brine to surface(FCP= 175 psi) with some gas. Shut down. Tubing = 100 psi and IA= 100 psi. Page 2 of 9 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 07:00 1.00 0 0 MIRU WELCTL COND P Load pits with 9.8 ppg brine, mix, and water back to 9.5 ppg brine. 07:00 12:30 5.50 0 0 MIRU WELCTL KLWL P Resume circulating 100 bbls at 3 BPM=305 psi(ICP)psi getting 9.5 ppg in/out(FCP=330 psi). Shut down check pressures,tubing and IA at 90 psi. Circulate 100 bbls at 2 BPM=204(ICP)psi getting 9.5 ppg in/out(FCP=220 psi). Shut down check pressures IA at 60 psi. Tubing is fluid packed but still gas in the IA. Circulate 100 bbls at 2 BPM =200(ICP)psi getting 9.5 ppg in/out (FCP=205 psi). Shut down check pressures IA at 45 psi(gas and some fluid)and tubing in fluid packed. Circulate 172 bbls at 2 BPM= 195(ICP)psi getting 9.5 ppg in/out(FCP=200 psi). Tubing and IA fluid packed 12:30 13:00 0.50 0 0 MIRU WELCTL OWFF P Monitor tubing/IA pressures for 30 minutes,tubing= 100 psi,and IA= 60 psi 13:00 13:30 0.50 0 0 MIRU WELCTL KLWL P Bleed IA back to the gas buster and got 15 bbls back in 15 minutes. Bleed the tubing off and got 10 bbls back in 10 minutes. 13:30 14:00 0.50 0 0 MIRU WELCTL OWFF P Monitor tubing/IA pressures for 30 minutes,tubing=75 psi, and IA=50 psi 14:00 16:00 2.00 0 0 MIRU WELCTL COND T Weight up the pits from 9.5 ppg to 9.8 ppg NaCI brine. 16:00 00:00 8.00 0 0 MIRU WELCTL KLWL T Start circulating 9.8 ppg brine at 2 BPM= 153 psi(ICP)and after two hole volumes pumped getting back 9.7 ppg brine. 01/28/2015 Continue to circulate 9.8 ppg brine until clean 9.8 ppg brine at surface. Monitor the well for flow for 30 minutes,well static. Install BPV. ND tree and tubing head adaptor. Install blanking plug and NU BOPE. Test BOPE to 250/3000 psi with 3-1/2"test joint. Perform Koomet test. Observed initial 200 PSI increase obtained in 17 Secs, and full 300 PSI obtained in 93 Secs. 5 Nitrogen Bottles with an avg PSI of 1990.The state's right to witness the BOPE test was waived by AOGCC field inspector M. Herrera. Hold safety stand down with day and night crews. Pull BPV. Spear tubing below hanger, BOLDS, and pull hanger to the rig floor. Unable to get spear to release therefore lay down hanger and 1 joint of 3-1/2"tubing with spear. RU to circulate. 00:00 01:00 1.00 0 0 MIRU WELCTL KLWL T Continue circulating 9.8 ppg brine at 2 BPM = 153 psi until 9.8 ppg brine at surface(FCP= 142 psi). 01:00 01:45 0.75 0 0 MIRU WELCTL OWFF T Tubing on a slight vac; IA sputtered a little gas and fluid then went dead. Monitor the well for flow for 30 minutes,well static 01:45 02:15 0.50 0 0 MIRU WELCTL RURD P Blow down and RD circulating equipment. 02:15 02:30 0.25 0 0 MIRU WHDBOMPSP P Install FMC'IS-A' BPV. Page 3 of 9 , Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:45 1.25 0 0 MIRU WHDBO NUND P PJSM. ND tree and tubing head adaptor. Tubing hanger has IBT lift threads and a welded hanger neck.Not in very good shape. 03:45 04:00 0.25 0 0 MIRU WHDBO MPSP P Install IBT blanking plug. 04:00 08:00 4.00 0 0 MIRU WHDBO NUND P NU 13-5/8"BOPE with 2-7/8"x 5" VBR's in the upper and lower ram cavity. 08:00 09:00 1.00 0 0 MIRU WHDBO RURD P RU test equipment. Fill the stack and choke with water. RU test pump. 09:00 10:00 1.00 0 0 MIRU WHDBO OWFF P Line up and fill IA with 9.8 ppg brine. IA took 30 bbls to fill. Observed gas and fluid swap. Bleed gas through degasser until dead. Monitor well, static fluid losses less than 20 bbl per hour. 10:00 11:00 1.00 0 0 MIRU WHDBO BOPE P Chase leaks and continue retesting to obtain a shell test on the BOPE to 250/3000 psi(good test) 11:00 16:00 5.00 0 0 MIRU WHDBO BOPE P Test BOPE to 250/3000 psi with 3-1/2"test joint. The state's right to witness the BOPE test was waived by AOGCC field inspector M. Herrera. 1) Blind rams, outer test spool valve, hydraulic IBOP,2" Demco at manifold, chokes 1,2, 3, 16(passed) 2) Blind rams, HCR kill, inner test spool valve, manual IBOP, chokes 4, 5, 6(passed) 3) Blind rams, manual kill, inner test spool valve, HT-38 dart, chokes, 7, 8, 9(passed) 4) Super choke and manual adjustable choke(passed) 5) Blind rams, manual kill, inner test spool valve, HT-38 TIW,chokes 10, 11 (passed) 6) Blind rams, manual kill, chokes 12, 13, 15(passed) 7) Annular with 3-1/2"test joint, manual kill, 8rd TIW,choke 14 (passed) 8) Upper pipe rams with 3-1/2"test joint,choke HCR, manual kill, 8rd TIW(passed) 9) Upper pipe rams with 3-1/2"test joint, manual choke, manual kill, 8rd TIW(passed) 10)Lower pipe rams with 3-1/2"test joint, 8rd TIW(passed) Perform Koomey test,with initial 200 PSI obtained in 17 seconds, full 3000 PSI obtained in 93 seconds and 5 nitrogen bottles with a 1990 psi average. Page 4 of 9 l Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 16:30 0.50 0 0 MIRU WHDBO RURD P Blow down and RD test equipment 16:30 17:30 1.00 0 0 COMPZ RPCOM SFTY P Safety stand down with day crew to discuss recent field incidents. 17:30 18:00 0.50 0 0 COMPZ RPCOM BHAH P PU and MU spear assembly. SIMOPS: Safety stand down with night crew. 18:00 18:30 0.50 0 0 COMPZ RPCOM SFTY P Safety stand down with night crew to discuss recent field incidents. 18:30 21:00 2.50 0 0 COMPZ RPCOM MPSP P Prior to pulling BPV check for pressure and there was some gas below the BPV. Bleed some gas off the IA to the bleed tank then bleed off the gas under the BPV. Pulled BPV and filled the stack. SIMOPS: RU SLB control line spooler and GBR tubing pulling equipment. 21:00 21:45 0.75 0 6,904 COMPZ RPCOM PULL P RIH with spear and spear the tubing below the tubing hanger. BOLDS, PU to unseat hanger, pull completion free at 95K, and pull hanger to the rig floor. PU =85K. 21:45 23:30 1.75 6,904 6,904 COMPZ RPCOM BHAH T Unable to get the spear to release. Lay down DP joint and MU DP pup joint. PU and break out hanger with pup and full joint below hanger and lay down. 23:30 23:45 0.25 6,904 6,904 COMPZ RPCOM SFTY P Well Control Drill. D-1 Drill.Well shut in 31 sec, all hands in position 78 sec.AAR with all crew members. 23:45 00:00 0.25 6,904 6,904 COMPZ RPCOM RURD P RU circulating equipment. 01/29/2015 Reverse circulated two tubing volumes and got clean 9.8 ppg brine back but did not see any sand come over the shakers. POOH laying down 3-1/2"tubing(recovered all 62 stainless steel bands; holes in the tubing at 5173'and 5205'). RIH with 3-1/2"stacked packer gas lift completion per running order(depth at midnight= 5213') 00:00 00:30 0.50 6,904 6,904 COMPZ RPCOM RURD P Continue to RU circulating equipment. 00:30 01:30 1.00 6,904 6,904 COMPZ RPCOM CIRC P Reverse circulate at 2 BPM=80 psi two tubing volumes(120 bbls). Returns are clean 9.8 ppg brine but did not see any sand. 01:30 02:00 0.50 6,904 6,904 COMPZ RPCOM RURD P RD circulating equipment and blown _down lines. 02:00 05:30 3.50 6,904 5,010 COMPZ RPCOM PULL P PJSM. POOH laying down 3-1/2" tubing spooling control and removing stainless steel bands to SCSSSV. Lay down SCSSSV. Recovered all 62 stainless steel bands. 05:30 06:00 0.50 5,010 5,010 COMPZ RPCOM SVRG P Daily tour top drive inspection. SIMOPS: RD SLB control line spooler Page 5 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 13:00 7.00 5,010 620 COMPZ RPCOM PULL P Continue POOH laying down 3-1/2" tubing from 5010'to 620'. Note: Holes in tubing at 5173'and 5205'. Light external corrosion at 5140'. 13:00 13:30 0.50 620 620 COMPZ RPCOM SFTY P Well control drill: Shut in=49 seconds and CRT=97 seconds 13:30 14:00 0.50 620 620 COMPZ RPCOM SFTY P Secure well. Safety appreciation meal for rig team for 1 year without a LTA. 14:00 15:30 1.50 620 0 COMPZ RPCOM PULL P Continue POOH laying down 3-1/2" tubing from 620'to surface. Recovered all 6 GLMs,tubing patch, and cut joint= 14.89'. 15:30 16:00 0.50 0 0 COMPZ RPCOM SVRG P Daily tour top drive inspection. 16:00 17:30 1.50 0 0 COMPZ RPCOM RURD P RU to run 3-1/2"tubing completion. Arrange jewelry in pipe shed per running order. 17:30 00:00 6.50 0 5,213 COMPZ RPCOM PUTB P PU and MU poor boy overshot, nipple assembly, FHL/PBR assembly and single in the hole with stacked packer GL completion on 3-1/2"9.3# EUE 8rd Mod L-80 tubing per running order(depth at midnight=5213'). 01/30/2015 Continue to single in the hole with 3-1/2"tubing to the top of the cut tubing stub,engage with poor boy overshot and PU to circulate. Reverse circulate 1%CRW 9.7 ppg corrosion inhibited brine. Relocate tubing stub, space out 1'and drop ball&rod. Attempt to set FHL packer but unable to pressure up. Call out slickline. RU slickline, chase ball&rod to seat, pressure up,set the FHL packer and PT the IA to 1000 psi for 5 minutes(good test). RD slickline. Pressure up and shear the PBR and space out. 00:00 01:00 1.00 5,213 5,213 COMPZ RPCOM SFTY P Secure well. Safety appreciation meal for rig team for 1 year without a LTA. 01:00 04:00 3.00 5,213 6,904 COMPZ RPCOM PUTB P Continue to single in the hole with 3-1/2"tubing to the top of the cut tubing stub at 6904'. 04:00 04:45 0.75 6,904 6,904 COMPZ RPCOM PUTB P Attempt to engage poor boy overshot. 04:45 05:15 0.50 6,904 6,904 COMPZ RPCOM RURD P RU circulate circulating. 05:15 06:00 0.75 6,904 6,904 COMPZ RPCOM PUTB P Work poor boy overshot onto tubing stub. Saw shear screw shear at 15K, no-go with 20K down, and PU to circulate. 06:00 06:30 0.50 6,904 6,904 COMPZ RPCOM SFTY P PJSM with rig crew and third party hands. 06:30 09:15 2.75 6,904 6,904 COMPZ RPCOM CRIH P Reverse circulate 407 bbl at 3-4 BPM =245-350 psi 1%CRW 9.7 ppg corrosion inhibited brine. 09:15 10:00 0.75 6,904 6,911 COMPZ RPCOM PUTB P Relocate tubing stub with 20K down and PU 1'. Drop ball&rod and let it fall. 10:00 11:00 1.00 6,911 6,911 COMPZ RPCOM PACK T Attempt to pressure up to set FHL packer but unable to get ball&rod to seat. Attempt to pump ball&rod on seat with no luck. Page 6 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:30 1.50 6,911 6,911 COMPZ RPCOM WAIT T Wait for HES slickline to arrive. SIMOPS: Clean and service the rig while monitoring the well. 12:30 18:00 5.50 6,911 6,911 COMPZ RPCOM SLKL T RU HES slickline and PT lubricator to 3000 psi. 18:00 18:30 0.50 6,911 6,911 COMPZ RPCOM SLKL T RIH with slickline and chase ball& rod to seat. 18:30 19:00 0.50 6,911 6,911 COMPZ RPCOM PACK P Pressure up to 2600 psi to set FHL packer and hold for 5 minutes. Bring the pressure up to 3000 psi and hold for 5 minutes. Bleed the tubing to 500 psi and pressure on the IA to 1000 psi for 5 minutes to ensure packer is set. 19:00 19:30 0.50 6,911 6,911 COMPZ RPCOM SLKL T POOH with slickline tools and ball& rod 19:30 20:15 0.75 6,911 6,911 COMPZ RPCOM SLKL T PJSM. Disconnect slickline lubricator, reconfigure tool string, reconnect slickline lubricator and PT to 1500 psi. 20:15 20:45 0.50 6,911 6,911 COMPZ RPCOM SLKL T RIH with ball&rod. Seat ball&rod. Release running tool and PT tubing to 1000 psi to ensure ball&rod is on seat. 20:45 21:15 0.50 6,911 6,911 COMPZ RPCOM SLKL T POOH with slickline tools. 21:15 22:30 1.25 6,911 6,911 COMPZ RPCOM SLKL T RD HES slickline 22:30 23:00 0.50 6,911 6,911 COMPZ RPCOM RURD P RU circulating equipment to the tubing in order to pressure up and shear the PBR. 23:00 23:15 0.25 6,911 6,911 COMPZ RPCOM HOSO P Pressure up to 1800 psi, PU,shear PBR and space out. 23:15 23:30 0.25 6,911 6,911 COMPZ RPCOM RURD P RD circulating equipment. 23:30 00:00 0.50 6,911 6,677 COMPZ RPCOM HOSO P Pull four joints of 3-1/2"tubing for space out(joints 218,217,216, and 215). 01/31/2015 Space out, MU tubing hanger, land tubing hanger, and RILDS. Attempt to PT tubing to 3000 psi but tubing leaked off slowly. BOLDS and pulled tubing hanger to the rig floor. Attempt CMIT but hanger lift thread leaking. Tighten lift thread and CMIT to 2500 psi(good test). Land tubing hanger and RILDS. PT the tubing to 3000 psi for 15 minutes(good test), bleed the tubing down to 1500 psi and PT the IA to 2500 psi for 30 minutes(good test). Shear the SOV and pump through SOV each was to ensure good flow path. Install 4" 'IS-A' BPV. Pressure up on the IA to 1000 psi for 5 minutes to test the BPV from below(good test). ND BOPE, NU tree, pull BPV, install tree test plug, and PT tree to 250/5000 psi(good test). Pull tree test plug and RU Little Red Services to freeze protect the well. 00:00 01:00 1.00 6,677 6,764 COMPZ RPCOM HOSO P PU/MU 8.18', 10.21',and 3-1/2" tubing joint(joint 215). MU 4-1/2"x 3-1/2"crossover and 1 joint of 4-1/2" tubing. 01:00 03:15 2.25 6,764 6,793 COMPZ RPCOM THGR P MU landing joint and MU tubing hanger. Land tubing hanger and RILDS Page7of9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:15 05:00 1.75 0 0 COMPZ RPCOM PRTS T Attempt to PT the tubing to 3000 psi but tubing is leaking off about 350 psi every 5 minutes. Check for leaks and isolate surface equipment but tubing leak signature remains the same. Pressure up on the tubing to 3000 psi and pressure up the IA to 2000 psi. Tubing leak signature the same and the IA dropped about 50 psi in 20 minutes. 05:00 05:45 0.75 0 0 COMPZ RPCOM WAIT T Call town engineer and discuss options. 05:45 06:15 0.50 0 0 COMPZ RPCOM THGR T BOLDS, pull seals from the PBR, and pull hanger to the rig floor. 06:15 08:30 2.25 0 0 COMPZ RPCOM PRTS T CMIT-TxIA to 2500 psi to test combination packer and ball&rod seated on RHC plug body. Tubing hanger lift thread connection leaking, tighten,and CMIT TxIA to 2500 psi for 15 minutes(good test). 08:30 09:30 1.00 0 0 COMPZ RPCOM THGR T Suck out BOP stack, land the tubing hanger, and RILDS 09:30 12:00 2.50 0 0 COMPZ RPCOM PRTS P PT the tubing to 3000 psi for 15 minutes(good test), bleed the tubing down to 1500 psi and PT the IA to 2500 psi for 30 minutes(good test). Shear the SOV and pump through SOV each was to ensure good flow path. Recorded on test chart. 12:00 12:30 0.50 0 0 COMPZ RPCOM OWFF P Observe the well for flow for 30 minutes,well static. 12:30 13:00 0.50 0 0 COMPZ WHDBO MPSP P Install 4"'IS-A' BPV. Pressure up on the IA to 1000 psi for 5 minutes to test the BPV from below(good test) 13:00 16:00 3.00 0 0 COMPZ WHDBO OTHR P Blow down choke manifold, mud manifold, and kill/choke. Clean under rotary table,steam tables,and draw works with super sucker 16:00 18:00 2.00 0 0 COMPZ WHDBO NUND P Pull riser, ND BOPE,and set back on stump. 18:00 20:00 2.00 0 0 COMPZ WHDBO NUND P NU 4-1/16"tree. 20:00 20:30 0.50 0 0 COMPZ WHDBO PRTS P PT the void/tubing hanger pack-off to 250/5000 psi for 10 minutes(good test). 20:30 21:00 0.50 0 0 COMPZ WHDBO MPSP P Pull BPV and install tree test plug. 21:00 21:30 0.50 0 0 COMPZ WHDBO PRTS P RU tree testing equipment and fill the tree with diesel. 21:30 22:45 1.25 0 0 COMPZ WHDBO PRTS P PT the tree to 250/5000 psi(good test). 22:45 23:00 0.25 0 0 COMPZ WHDBO MPSP P Pull tree test plug. 23:00 00:00 1.00 0 0 COMPZ WHDBO FRZP P Rig up Little Red Services to freeze protect the well. Page 8 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/01/2015 24 hr Summary Freeze protect well with LRS pumping 129 BBLS.Allow to U-Tube. Rig up lubricator and install BPV. Secure tree and cellar. Complete cleaning of pits. Prepare rig and outside equipment for move. RDMO "'Rig Released at 0800 HRS 2-1-2015" 00:00 00:15 0.25 0 0 COMPZ WHDBO FRZP P Continue to RU Little Red Services. 00:15 00:30 0.25 0 0 COMPZ WHDBO SFTY P PJSM with crew and Little Red Services. 00:30 04:00 3.50 0 0 COMPZ WHDBO FRZP P PT lines to 2500 psi and pump 129 bbls of diesel down the IA taking returns out the tubing at 2 BPM. Allow the well to u-tube and diesel to equalize between the IA and the tubing to freeze protect the well down to 1848'MD. Release Little Red Services. 04:00 05:15 1.25 0 0 COMPZ WHDBO FRZP P Blow down lines and RD u-tube equipment. RU lubricator to set BPV. PT lubricator to 1000 psi. 05:15 05:30 0.25 0 0 COMPZ WHDBO MPSP P Install BPV. 05:30 06:00 0.50 0 0 COMPZ WHDBO MPSP P RD lubricator. 06:00 08:00 2.00 0 0 DEMOB MOVE RURD P Secure tree and cellar. Install valves and gauges. Completed pit cleaning. Prepare for rig release and move. Final well pressues: tubing=250 psi, IA=250 psi, and OA=750 psi. "Rig Released at 08:00 HRS** Page 9 of 9 1C-04 WELL WORK SUMMARY DATE SUMMARY POST RIG WELL WORK 2/4/2015 SET 3" BAIT SUB & PULLING TOOL (CATCHER ASSEMBLY) ON BALL & ROD @ 6826' SLM; PULLED SOV& SET OV©4982' RKB. IN PROGRESS. 2/5/2015 PULLED DV's @ 3918' &2615' RKB, SET NEW GAS LIFT GLV'S @ SAME. PULLED CATCHER/ BALL & ROD @ 6826' SLM; PULLED RHC PLUG BODY @ 6849' RKB. IN PROGRESS. 2/6/2015 PULLED NIPPLE REDUCER @ 6984' RKB; TAG @ 7251' SLM (EST. 56' RAT HOLE; , MEASURED BHP © 7130' SLM (BHP 3220 PSI). JOB COMPLETE. Ima~°roject Well History File Cove~ XHVZE ' This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. /~)-/~_~Well History File Identifier Organizing RESCAN El'""~ Color items: ~;~/~/~ [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA [] Diskettes, No. [] Other, No/Type ~Rescan Needed BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) .D ~various kinds ~Other Project Proofing BY: .~OBIN VINCENT SHERYL MARIA WINDY DATE /SI Scanning Preparation x 30 = ' BEVERLY ROBIN(~SHERYL MARIA WINDY Production Scanning /2/ Stage 1 PAGE COUNT FROM SCANNED FILE: - .v/,~ TOTAL PAGES BY: Stage 2 BY~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: , YES NO III Illlllllll Illll RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: lsl General Notes or Comments about this file: Quality Checked 12/lO102Rev3NOTScanned.wpd UNSCANNED, OVERSI7Ell MATERIALS AVAILABLE: S~ FILE # To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ~ 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 -Tax (907) 27fi-7542 • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16th, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: • ~~~@ V ~~~~ uia fit GBt C9tt~. CE~('RfiT~iSSft7E ~t~cFi~ra~~± ~go_~ss r c- ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRL)). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped November 25th 2007 & March 21 2009, the corrosion inhibitor/sealant was pumped July 6th, 7~', 8th 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klem ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (1004) Kuparuk Field Date 7116110 1A.1 C.1 E PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-11 50029206850000 1811730 10" n/a 10" n/a 3.4 7/8/2010 1A-12 50029206880000 1811780 2" n/a 2" Na 1.7 7/8/2010 1A-13 50029207000000 1811950 11" Na 11" n/a 3.4 7/8/2010 1A-14 50029207060000 1820100 4" Na 4" Na 2.1 7/8/2010 1 C-01 50029205260000 1801280 SF Na 24" Na 4.3 7/6/2010 1 C-02 50029205320000 1801350 24" Na 24" Na 8.5 7/6/2010 1C-03A 50029205350100 2070630 SF n/a 16" Na 7,7 7/6/2010 1C-04 50029205470000 1801550 SF Na 5" Na 2.6 7/68010 1C-06 50029205640000 1810250 76 17.70 32" 3/21/2009 9.4 7/6/2010 1 C-09 50029208590000 1821850 38' 8.00 6" 11858007 6.8 7/6/2010 1 C-10 50029208650000 1821930 37'6" 8.00 8" 11858007 6.8 7/6/2010 1E-02 50029204720000 1800500 21" n/a 21" Na 1.7 7/7/2010 1 E-03 50029204770000 1800560 4" n/a 4" n/a 2.4 7/7/2010 1 E-06 50029204930000 1800780 12" n/a 12" n/a 13.6 7/7/2010 1 E-07 50029204950000 1800800 5" n/a 5" n/a 2.6 7/7/2010 1 E-08 50029204960000 1800810 5" n/a 5" Na 2.6 7/78010 1 E-10 50029207250000 1820360 2" Na 2" Na 1.7 7/7/2010 1 E-13 50029207500000 1820780 5" n/a 5" Na 2.6 7/78010 1E-19 50029209050000 1830170 1" Na 1" Na 1.7 7/78010 1 E-21 50029208920000 1830020 3" Na 3" Na 2.6 7/78010 1 E-24A 50029208570100 1971870 2" n/a 2" Na 1.7 7/78010 1E-25 50029208440000 1821700 3" n/a 3" n/a 1.7 7f1/2010 1 E-28 50029208320000 1821580 4" n/a 4" n/a 2.5 7/88010 1 E-29 50029208280000 1821540 7" Na 7" n/a 2.5 7/88010 1C-04 (PTD 180-155) failed a TI~ • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, August 04, 2008 10:15 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 1C-04 (PTD 180-155) failed a TIFL Attachments: 1C-04.pdf; 1C-04 TIO.jpg Tom/Jim, Kuparuk gas lifted producer 1C-04 (PTD 180-155) failed; a TIFL on 08/03/08 and has been added to the Weekly SCP report. The TIO prior to the TIFL was 190/1010/850. A leaking GLV is suspected so slickline will troubleshoot the leak and repair if possible. The well is currently online and will be repaired before 8/31/08 or SI. Attached is a 90 day TIO plot and schematic. «1 C-04. pdf» «1 C-04 TIO.jpg» ./ Please contact me at your convenience if you have questions or comments. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 12/10/2009 KRU 1C-04 PTD 180-155 8/4/2008 TIO Pressures T11fQ Plot - 7 C-04 1200 1000 400 a 600 400 200 D ................................................................................................................... IL '' 1 l ~~III 1+r' k• ' ~ ~ ................~. ......i........................................,`.;~.................................................. ................I~. ..i ............................................................................................ ,f ~,, ihi' '~ . rte. t- ~' - - ti~ - 1' 01-Jun-08 01-Jul-08 Date 200 150 • a I. d 100 ~ 0 t v 50 0 01-Aug-08 -- ~ 1 C 04 ,~ y. - - ` ' ConocoPhilGps ~ " - .. ~ - - - - _ - .. - a ':+~ i i ~~ %./LUVJI _ Held Name -Well Status _ M . mum I tl natmu O Tu Wl Depth (ftKe) .':12054700 KUPAR K RI VER UNIT PROD 37.98 7 57 .0 Comment H2S (ppm) Date Annotation End Date KB-G d (ft) Rig Release Date wan coin - tc-oa sizafzooe ~:oe:aa PM SSSV: "LOCKED Last WO: 39.01 2J7/1981 _ Schematic-Actual ,, ~,ot.,t~o~, Depth (RKB) End Date u Annotation Entl Date l „-. ~ 7.285.0 5/18/2008 Rev Reason: TAG SLM. NEW GLV DESIGN 5/24/2006 ~T t L~,:ti~_i i{. r ~D ~. I ~ I ,[I'C, :.~ C,, HI-! S t :~:li iT,. l'Gi V:t II ~; r.,J~ T~,-~i ,I ITUI- i ~ - ~ r C- I~.~ I Too dw6, , G utiotion ~ Comment I Run Date I ID (in 3 --- -. `. -- ~------------ ~ -- shoe-caicu. Top (ND) Btm (TVD) Dens Shot op (RKB) Btm (RKB) (RKB) (RKB) Type Zone (shot... Tafal 7,088.0 7,148.0 6,410.1 6,470.0 IPERF C-4, C-3, 4.0 24i C-2, 1C-04 7,208.0 7,218.0 6,529.9 6,539.8 IPERF C-1, UNIT 4.0 4i End Gate -- , B, 1C-04 An114 laUOr1 GAS LIFT, 6,883 7 . BR 6 1 ,9 S , 9 @ C ` CT N ~ PRODU IO f ~I 7 ', 1 r ~ PACKER, 6,945 q ~-''" ~ i NIPPLE 6 984 , , SOS 6 985 ~ ~ 1~ , , TTL, 6,986 LINER TD, 7,575 ARCO Alaska, Inc. Date: January 30, 1989 Transmittal #: 7417 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1 B- 0 8 Kuparuk Well Pressure Report 1 2- 0 4 - 8 8 Both Sands 1 B - 0 2 Kuparuk Well Pressure Report 1 0- 2 8 - 8 8 Amerada 1 H- 0 3 Kuparuk Well Pressure Report 1 1 - 2 2 - 8 8 Amerada 1 D- 0 8 Kuparuk Well Pressure Report 1 1 - 2 5 - 8 8 Both Sands 1 C- 0 4 Kuparuk Well Pressure Report 1-27-89 Amerada Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: D&M State of Alaska Unocal Chevron Mobil SAPC ARCO Alaska, In Post Officed~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: November 5, 1987 Transmittal # 7006 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. and return one sigqed copy of this transmittal. Please acknowledge receipt x"-3 lB-2 "'J IC-4 ~ 1H-4 "J 1H-4 ~ '"'-/1H-3 ----o 2F-5 """~ 2C-9 ~ 2F-6 '"-33C-13 ~"J3A-13 ~ 1L-5 '-"' IL-7. ~"-~. 1L-1 ---_o 1L-16 -'-.o 1E-4 "'~ 1F-16 '"-~ 1F-10 ~ 1F-9 -"'~ 1F-4 '"--3 IQ-9 Kuparuk Well Pressure Report(Camco) Kuparuk Well Pressure Report(Camco) Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report(Otis) Sperry-Sun Pressure Build Up Test 'A' Sand Static BHP Survey PBU Well Test Interpretation Plots 'A' Sand Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report)Otis)' KOE Buildup Analysis. 6-10-87 KOE Falloff Analysis 6-13-87 KOE Falloff Analysis 6-14-87 KOE Falloff Analysis 6-17-87 KOE Falloff Analysis 6-18-87 KOE Falloff Analysis 6-14-87 KOE Buildup Analysis 6-11-87 KOE Falloff Analysis 6-10-87 KOE Falloff Analysis 6-17-87 KOE Buildup Analysis 6-12-87 KOE Falloff Analysis 6-9-87 Kuparuk Well Pressure Report 7-8-87 Static 7-7-87 'C' Sand 8-5-87 Static 8-3/5-87 PBU 8-22-87 7-19-87 AK-MS-70043 7-14/17-87 100591H 7-15/19-87 6-10-87 Static 7-28-87 Static 'C' Sand 'C' Sand Both Sands Both Sands Both Sands Both Sands 'C' Sand Both Sands Both Sands 'C' Sand Both Sands 11-3-87 Static 'A' Sand Receipt Acknowledged: · DISTRIBUTION: Anchorage D&M State of Alaska BPAE Chevron Mobil SAPC Unocal ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany ATTACHMENT I I Drill Site lA Well No. 1A-4 1A-5 1A-7 1A-9 1A-11 1A-12 1A-14 1A-15 1A-16A KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Lo9 Date Drill 716/83 10/29/83 2/8/82 5~7~82 1/25/82 3/23/83 1/19/83 3/21/83 3/8/82 4/1/82 6/5/82 5/11/82 6/8/82 lB Si te Wel 1 No. Lo9 Date lB-1 12/26/81 · 1B-2. 6/25/81 lB-3 11/16-18/81 3/12/82 1B-6 11/18/81 9/10/82 1B-7 11/23/81 1B-8 12/28/81 8/4/82 1B-9 6/24/82 8/3~84 Drill Site 1C Wel 1 No. 1C-1 1C-2 1C-3 1C-5 1C-6 1C-7 1C-8 ' .. Lo9 Date 5/9/81. 5/8/81 7/13/81 11/8/81 3/9/81 2/26/81 :: 11/30/81 5/19/81 ' 5/21/81 Drill Site Well No. Lo9 Date 1D 1D-1 · 1/80 5/23/83 1D-3 8/5/80 1D-4 7/30/80 8/13/80 1D-5 6/11/81 1D-6 6/9/81 1D-7 6/8/81 (~ID-8 (WS-8) 5/i0/78 AAska 0//& Gas Co,~ ~ Attach~nt I T Page 2 ") Drill Site 1H Drill Site lQ Wel 1 No. 1H-3 1H-4 1H-6 1H-7 1H-8 Well No. Log Date 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 Log Date Drill Site Well No. 1E 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 Log Date 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 10/21/8! 11/12/82 10/28/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 1G Well No. 1G-1 1G-2 1G-3 1G-4 1G-5 1G-7 1G-8 Lo9 Date Drill Site Well No. 9%7/82 9/25/82 9/28/82 12/8/84 10/13/82 11/12/82 1F 1F-1 1F-2 1F-3 1F-4 1F-5 1F-6 3/12/83 . Alaska Oil 1F-7 Log Date 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 10/28/82 11/19/82 5/7/83 Attach.ment Page Drill Site Well No. Log Date 1Y 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 ~6/18/83 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1Y-9 6/20/83 !lIC~'~, 5110183 )~_ 11/21/83 ~~28y85~ 1Y-125~25~83 1Y-135/27/83 1Y-145/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site Well No. Log Date 2C 2C-4 2/19/85 2/28/85 2C-7 10/15/84 Drill Site Well No. Lo9 Date 2Z' ~ l~2/10 / 83 ~8'~ 2Z-2 " 6/24/83 7/19/83 2Z-3 · 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF'pg'O052 Anchorage Drill Site lA Wel 1 No. ~ 1A-4 ~1A-5 ~1A-7 ~IA-g ~1A-11 ~1A-12 ~IA- 14 ~1A-15 '..1A-16A ATTACHMENT I I KUPARUK RIVER UNIT Prod. uction Logs, Log Date 7/6/83 10/29/83 2/8/82~X 5/7/82/ 1/25/82~. 3/23/83/'~ 1/19/83") 3/21/83/ 3/8/82 4/1/82 6/5/82 5/11/82~ ~ 618182/ Drill Site Well No. Log Date '"lB-1 12/26/81 ~'lB-2 6/25/81 '~1B-3 11/16-18/81'~ ~ 3/12/82 ~1B-6 11/18/81~ '~ 9/10/82/ .... ~lB-7 11/23/81 ~.1B-8 12/28/81~ "~ 8/4/82 ~1B-9 6/24/82 ~ 8/3/84 lB Drill Site lC Wel 1 No. ~1C-2 xlC-3 ~IC-4 "~-~ ~1C-5. "~1C-6 "~1C-7 ~ 1C-8 LO~llDate 519/81 5/8/81 7/13/81 11/8/81'~ 3/9/81/ 2/26/81 11/30/81 5/lg/81 5/21/81 Drill Site Well No. Lq.g Date 1D '%~1D-1 1/80~; ~.... ~ 5/23/83/' ~1D-3 8/5/80 1D-4 ~7/30/80~ ,.., ~ 8/13/80/ '~ "~ ~'1D-5 6/11/81 ~1D-6 6/9/81 ~1D-7 6/8/81 ~1D-8 (ws-8) 5110178 % c.o ~" c:z::,.,~' r RECEIVED FEB ~ 1 1986 Al~kll 011 & Gms Oon~. Gomml~lon Anchorage ARCO Alaska, Inc ')x Post Office. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE:09-05-85 TRANSMITTAL NO: 5331 RETURN TO: ARCO ALASKA, INC. KUPARUK-OPERATIONS ENGINEERING RECOkDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH A~l~ %'HE FOLLOWING I'i'f/~]S. PLEASE ACKNO~LEDGE RECEIPT AND RETUkN ONE SIGNED COPY OF THIS TRANSHITTAL. PRESSURE FINALS/ASSORTED VENDEKS CAMCO 1C-4 / STAT.lC GRAD Ii~N~' 04-25-85 2G-1 ,-'/ PRESSURE BUILD-UP 04-17-85 OTIS3 2X-',.5 / FLO~ING PRESSURE 07-09-85 TOR:2UE TURN 2D-2A'"' 24 HOUR PBU 04-21/22-85 GUAGE #63137 LYNES'/- 2X-4" PRESSURE REPORT 08-12-85 DRESSER ATLAS lA-5/ PRESSURE SUhVEY 08-13-85 lB-2'/ PRESSURE SURVEY 08-05/06-85 1Y-2'''~ PRESSURE SURVEY 08-07-85 2C-8~/ PRESSURE SURVEY 08-16-85 2G-9 PRESSURE SURVEY 08-22-85 2H-1 ~/ PRESSURE SURVEY 08-24-85 2W-7 PkESSURE SURVEY 08-22-85 2X-ll-/ PI{]~SSURi~ bURVI~Y 08-25-85 RECEIPT ACKNOWLEDGED: BPAE* B. CURRIER CHEVRON* D & M* DRILLING L. JOHNSTON HOBIL* NSK CLERK DISTRIBUTION: W. PASHER EXXON PHILLIPS OIL* J. RATHMELL* DATE: Aiask'a O~i & ':0~$ Cor~s. Commission' STATE OF ALASKA* SOHIO* UNION* K . TULIN/VAULT ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, ir~ ~, Post Offic,. ,&ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TRANSMITTAL N(J: 5292 . RE~'URN TO: ARCO aLASKA, INC. KUPARUK OPERATIONS ENGINEERING tiECORDS CLEPd{ ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED k~CEIPT AND K U PARU K --lB-2 ~lB-4. ' - 1C-4 · 1C-6~' - 1D_ 8_~ --1H-3 ~lQ-13/ ~' 1Q_14-~' XlQ_15-,~' ~lQ-16~ ~ 1R_5~-~ , 1R_6/ ~lR-7/ '~2A- 2 ~2W-7-- '~2 V- 3 ~2W-15" 3B-t 3B-27' ' 3B-3"- ~3B-4- ~ 3B-5 ~ ' 3B-6-- ~3B-7- 3B-7~ - 3B-8~ -3B-~ -3B-11 ~ - 3B- ~2 -.~ ' 3B-13- -3B-14 RECEIPT HERE%;IITH ARE; THE liETUKN ONE SIGNED COPY OF THIS TRANSMITTAL. %4ELL PRESSURE REPORT--ENVELQPE FACE DATA '~3B- 15 FOLLOWING ITEMS. PLEASE ACKNOWLEDGE 05-30-~5 CAMCO . 05- 30- 85 CAMCO 05-16-85 CAMCO ~ 3C-11," 07- 24- 8 5 CAHCO 07-25-85 CAMCO 07-30-85 .CAHCO 07- 30- 85 CAMCO 06- 24- 8 5 CAHCO 06- 23- 85 CAMCO 06-21-85 CAMCO 06-21-85 Ct~ICO 07- 05- 85 CAHCO 07-06-85 CAMCO 07- 06- 85 CAMCO 07-08-85 CAMCO 07-04-85 OTIS 07-26-85 DRESSEIt 07-11-85 OTIS 08-04-85 OTIS 06-14-85 ???? 06-14- 85 CAMCO 06-28-~5 OTIS 06-15-85 CAMCO 06-15- 85 CAI~ICO 06-26-85 CAMCO 06- 26- 85 CA[,ICO 06- 28- 85 CAIvlCO 06- 27- 85 CAivlCO 06-28-85 OTIS 07-18 - 85 CAI~ICO 07-20-85 CAMCO 07- 20- 85 CAMCO 07 - 21- 85 CAI~ICO 05-29-85 OTIS 05-29-85 OTIS ACKNO~4LEDGED: 05-28-85 OTIS 05-28-85 OTIS 07-29-85 CAMCO DISTRIBUTION: BPAE* DRILLING W. PASPiER B. CURRIER L. JOHNSTON EXXON CHEVRON* t,L)B I L* PHILLIPS OIL* D & H* NSK CLERK J. RATHMELL* STATE OF ALASKA* $OH I O* UNION* K. TULIN/VAULT ARCO Alaska. Inc. ~s a Subsidiary of AtlanticRichfieldCompany ARCOAlaska, lnc U'~x Post Office 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TRANSMITTAL NO: 529 6 RETURN TO: ARCO ALASKA, INC. KUPARUK 'OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHOtCAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TR~SMITTAL. SEQUENCE OF EVENTS FROM WELL SERVICE REPORTS PRESSURE DATA '~1C-4 ...... 07-23-85 --' 1C-5 '~' 07-29-85 '~ 1C-5 ~ .... 07-30-85 '~1C-6 ~' 07-25-85 ~1C-6 ~ 07-24-85 -~lD-8 ........07-30-85 -" 1H- 3"' 07-30-85 -'--lR-5' 07-05-85 "--11{-6 ..... 07-06-85 '"lR-8 07-U8-85 1Y-10 07-27-85 1Y-1i ....... 07-28-85 2A-2 / 07-04-85 2B-13 07-30-85 2U-14 06-30-85 2U-14~'~ 07-01-85 2U-15~ 07-08-85 2V-2 07-27-85 2V-2, 07-28-85 2W-7 07-26-85 '~ 2W-7 07-27-85 2X-15 07-09-85 2X-15 ~'' 07-04-85 2Z-1 07-05-85 '-2Z-6' 04-08-85 ~3B-7 06-27-85 3B-8~ 06-28-85 3B-8 .... 06-27-85 ~3B-9 / 07-18-85 3B-11 07-20-85 3B-12~ 07-21-85 3C-11 07-29-85 STATIC BHP PBU PBU STATIC BHP STATIC BHP STATIC BHP STATIC BHP I~HP & MISC. BHP & MISC. STATIC Blip & t, lISC. STATIC BHP END OF PBU 'C' SAND STATIC Blip PRESSURE DATA 'A' SAND PBU 'A' SAND PBU PRESSURE TEST & MISC. 'A' SAND PBU 'A' SAND PBU 'A' SAND ONLY PBU 'A' SAND PBU FLOWING Blip & FLUID I.D. CAMCO DRESSER ATLAS DRESSER ATLAS CAMCO CAMCO CAMCO CAMCO 'CAMCO CAMCO CAMCO CAMCO DRESSER ATLAS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS FLOWING BHP & TEMPERATURE OTIS Blip .SURVEY & MISC. STATIC BHP STATIC BHP & MISC. STATIC BHP & MISC. Blip & MISC. STATIC BHP & MISC. BHP SURVEY & MISC. STATIC Blip tx MISC. STATIC Blip ~ MISC. RECEIPT ACKNOWLSDGED: BPAE* B. CURRIER CHEVRON* D & ~* DISTRIBUTION: W. PAStiER EXXON PHILLIPS OIL* J. RATtiM~'.LL* - ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany DRILLING L. JOHNSTON HOBIL* NSK CLEI~K OTIS CAMCO CAMCO OTIS CAMCO CAMCO CAMCO CAMCO c co ~ DAT~sk~- O!! 0_ C~ Cu,s'. ~;ommission SOHIO* UNION* ARCO Al; ~'),''~ Inc. Pos~Office Box 10G360 Anchorage, Alaska 99510-0360 Telephone 907 275 1215 DATE: 06-24-85 TRANSMITTAL NO: 5227 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TF,3,NSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. KU?ARUK WELL PRESSURE REPORT ENVELO lB-3 ~. 04-21-85 PBO BOTH SD. ~ 04-25-85 SBIIP BOTH SD. !Il-3 ~, 03-06'-85 PBU BOTH SD. IQ-l-. 05-26-85 SBHP 'A' SD. lQ-2-, 05-26-85 SBHP.~ 'A' SD. lQ-3-, 05-18-85 SBHP 'A' SD. 1Q-4~ 05-14-85 SBHP BOTiI. SD. lQ-5,, 06-0 6-85 SB[IP 'C ' SD. lQ-6,. 04-23-85 SBHP !Q-7-, 04-17-85 SBHP 'A' SD iQ-8-,. 04-03-85 SBHP 'A' SD. 2A-2\ 05-27-85 SBHP 'C ' SD. 2A-4< 05-11-85 SBIIP 'A' SD. 2C-5 -~ 04-23-85 PBU 'A: SD, 2C-9" 04-06-85 SBHP 'A' SD. 2C-!0\ 04-40-85 SBIIP BOTH SD. 2C-11\ 03-29-85 SBIIP 'A' SD. 2C-12~ 03-2~-85 SBHP 'C' SD. 2C-14'~ 04-23-85 PBU 'A' SD. 2C-!~ 04-29-85 FBItP 'A' SD. 21I-1,, 05-0~-85 2H-!~ 0'-",~-~.~7-85 SBI'iP 'A' SD. 2H-2'- 05'23-85 ???? ???????? 2H-3,. 05-23-85 SB!IP 'A' SD. 2!!-4,~ 05-23-85 SB!IP 'A' SD. 2V-9~ 05-18-85 SBHP 'A' SD. 2V-! 0,. 05-17-85 SBHP 'A' SD. 2V-!! '- 05-12-85 SBIIP 'A' SD 2V-12'- 05-14-85 SBIIP ~' 1 2X-2" 00-_6-85 SBIIP BOTH SD 2X-2-- 06-14-85 SBHP BOTII SD. 2X-5,. 06-12-85 SBIiP BOTII SD. 2Z-6' 04-08-85 SB!iP 2Z-7-- 0,1-23-85 PBU BOTH SD. 2Z-8~. 04-01-85 S~[IP BOTH SD. <ECEIPT ACaNONLEDCED: PE DATA CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO OTIS CAMCO BAKER NORTH SLOPE OTIS OTIS OTiS OTIS OTIS & BAKER CAMCO CAMCO OTIS CAMCO OTIS OTIS OTIS OTIS OTIS OTIS OTIS OT~+S OTIS · . . . BAKER NOTH SLOPE OTIS D'i STIV/E'UT'iON- EXXON PHILLIPS OIL* A~chor:~3 DATE: SOI!IO* UNION* K.~"U.'-LIN/VAULT ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 05-1 5-85 '¥RANSHITTAL N0'5t85 REI'UI~N TO: ARCO ALASKA, IN(::. ATTN: RECOI~:I)S CL. EI';~I( A'I'O-t t t 5B F'.O, BOX t00360 ~~A ANCHORAi;E, AK 99510 ' I'RANSHI'I'TED i"iEREaII'i'-I ARE THE FOi..L. OWING II'[~.HS. CI<NOWLEDGE RECEIF'T At'ID RETURN ONE SI(;NED COPY OF THIS' 'FF<aNSMIT'r. AL. WSt:~/SEQtJENCI?.. OF EV[.!:i'.41'S (ONE COPY OF EACI'I) t A-t I::'BU 04-2t -85 CAMCO t A-I F'BU 04-22-85 CAMCO t A - 2 R O i'4 L Y N E 5' i;: [!: C 0 f~: I) E R S(') 4 - 21 '" 85 C A Iq C 0 ' 'l ' e -" t A--2 END I'"[U/i'<UN WRD 04-'2~ (:}5 CAMCO t A-S S[-:i-IP 04-t 9-'85 CAH[.;O ' I A-4 SBHP 04-t 9-85 CAMCO t A- 5 !::' ii'.' U ' "~ -' 8.5 04-,.t CAHCO t A-5 PUl_l_ F'BU ('~4-'22-85 CALICO 1A-6 I::'BU 04-2t -'85 OTIS IA-6 HAI,IC OFF' LYNES F'i:;;ESSUI:;:E BOHBS FOR PBU 04-2t-8.5 [.)'l'I$' t A - 6 1:" I N I ,."? H F' B tJ 0 ,I - 22 - 85 0 T I S i A-i 0 RLIN LYi',IES RECOI:~:I)Ei"(.~' (')q-21'-85 tA-t0 F'LILL LYNES RECORDERS 04-22/2:5-85 CAHCO i B-;3 F'BU 0'1-2t-8~ CAHCO t B-:3 PBU 04-22-85 CAMCO t C-Zt S BHI:!' 04- 2 O- ['~'.:5 CAHCO t C-4 SBHF' 04-25-85 CAHCO i C-6 RUN LYNES RECOI:;:I)ERS 04-2t-'85 o'rI,S" t C-6 REi'RIFVF.: LYNES I:¢Ii.'COi:(DEI:(S 04--2~--85 OTIS t E.-4 RUN SI::'INNER/'I'EMI::'i::'RA'£UI:~:E .$' O i;: V 1:" Y--- 1_ E A I< DE'i'["{,'[ I ON 0,1-23-85 CAMCO t E-5 RUN I::'BU SIJI:~VEy 04-26-85 CAi'ICO ~ E-i 5 INJECI'IVII'Y 'i'F:~;T 04-~ 9-85 i E-t 6 INJr..~CTIVITY TE,S'I' 0,1-20-85 ARCO iF-27 INJECTION 'I'I:'.ZST/'A'SAND 04-22-85 ARCO i E-27 T EHPERATUR[-'/SP I NME:R-- IF-3 t i::-5 RECEIF'T LEAl( DETIECTION RUN LYNES TA?'II)E:M I:'i:;:FSSIJI:;:E' BOMBS i--OR PBU RETRIEVE LYNi:'-..':; I:([:'C[iRI)ERS RUN LYNES I:::ECOi:(DI:"I:~:S--- 'C' SANI) [INLY RIi-'TRIEVE LYNES RECORDERS hCI(NOWL[--'D[; ED: BF'AE* B. CURRIER. CHEVRON-x- D & M* Dl:ill_i._ I Ng t_. .JOHNSTON * i'i 0 I:': I I... NSI( C L Ei:;:I( 04-2'?-85 OT '-[ S 04-2t -85 [)TIS 04-273-85 OI'IS 04-2t -85 OTIS 04-~2-85. OTIS D I S T I:;; I B U'l' I 0 N: W. F'ASHER EXXON -x. !::' H I L L I I::' S 01 L *J. R¢;Tt'IitFLL DATE: __ ,STATE OF ALA$1<A *SOHIO ,UNION i(, TULI N/VAUL. I' ARCO Alaska, Inc. Post Office ~x 100360 ' Anchorage, ,.d'aska 99510-0360 Telephone 907 276 1215 ,?'T'ATIC BHP DATA ZTA'¥IC ,ql'iF' DATA ,:.7'AT~.F: BHF' I)ATA ,~TAT I C'. E,'I"IF' DATA ,~TAT]:r',.,BHF' DAT'A ,'.-?TATIC BHP DATA ,~OE,;ZTATIC BHF' ~TATIC BHF' DATA ,?OE/,?TAT]:C BI.iF' .~TATIC BHF' I)ATA ~ :..,:_,. ,:. ,~.,TIC BHF' ::TTAT!C E~i.iF:' DATA £OE.,"$TATI~',_. :-.,~'I. IP 2]r'ATIC BHF' DATA .9OE/'A' ,~AND F'BU · '?TATIC BI..IF' DATA ¢' / ~' T"! I ,.¥ gE..- i" .,:',,..' F'BU DATA ~?'FAT]:r'. ,., ..F.;HP DATA ,?'T' A 'F I F'. E, 1": ,- D A T A · .,:'p..m:/~T.'..,Hr.:, 'A' ~.: ~.:..J ! .... .... .... ~ F'BU DATA .5'OE/F'BU 'C' 5'AND DATE:' AF:'R IL FF:nr.!~rl.[ TT~L NO ' ::) ~2 51 4? ^ "! · ^ <', - I1'E'.MS' F' ,.E.~'i~F". ACI<NOWLE:D[;I"': OF TI"I Z 2. 'rF:.:A i,~!,"~l',i .l: T'Er..'.[., · ~,.. ~ :. ~.., .... t/'~ ';' ;o,-" / *~. ,.// t /~ /Ot.-- /~': i / .,' ,.'.....'..,. ~ .,..-' t 2/J J ,' ,::,_;' 2/ft "'~ 2/I 0/85 ;2/i O/o5'" - '--, / ,, ' 2 / 9 / 8 5 · ~./~' I · 2/2 7/""=' ") /"~ I) l ~: T R I B U 1' I ('J N · Pn'A'-- T'.,RII.. I i,HG - I..,1 F'A31-1~'R --' ~ "!: ........... · T.'.., [-: L.'. R F: :[ I-.--_ F: ! ...... .'. 0 !-i i'.! f T C~ !','. E X X 0 i'-,'. ·../~ ,~j 'r I n"E .... "' H.:'.7 B :r. !.. ~ I_I.. z F':? ... ,-, ..... F.,..,.,, F'H~ ... ','r:[..E~'~'' L ~ ~ H H,?:.. .. ,,,,, ...... :., ~: J R;.'.-,THH=:' ;. ARCO Alaska, Inc. i$ a Subsidiary of AllanlicRichfieldCompany ARCO Alaska, Ir~ POst Offic= ~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/23/85 Transmittal No: 4992 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 · ~~Tra. nsmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. · . STATIC' ~H? RE?O~TS & WSW f/24 12/29,'28/84 1H-4 '11/25/84 1C-4 12/05/84 lB-2 12/03/84 1D-8 12/06/84 /cat SEQUENCE OF EVENTS Static BHP 12/29,28/84 · SBHP 11/25/84. Static 11/26/84 Statid BHP 12/05/84 Static BHP 12/03/84 St'atic BHP 12/06/84 Receipt Acknowledged: DISTRIBUTION . . B. Currier Drilling W. Pasher BPAE Geology 'G. Phillips Chevron Mobil Phillips Oil D & M NSK Ops. J. Rathmell Date: Sohio Union Well Files ARCO Aleska. Irtc is as subsiclisry of AllanticqichfieldCompany ARCO Alaska. Inc. , :< ;.~',er,¢ D~,/277 5C37 Return To: ARCO ALAS~, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 10/2_2/84 Transmittal No: 4794 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ... OH LIS TAPE f/61376 · 1C'4 Runs 1, 2 2860 - 7550 Schlumberger 2/28/84* 2/01/81 *Recomputed Date ~'~%f~6V~ J ~,~0.~~ ~p~_-~LL/~4//V~ C~7 lC-~ ** MWD Directional Survey 2A-1 Job f~376-AK 3/30 - 4/07/84 Teleco Oilfield ** Subsurface Directional " A0384D0037 3/30/84 Eastman Whip ** Ref. State of AK Ltr, Dated 10/04/84, RequeSting 2A-1 Directional Survey NOTE: " " " " " Requesting 2V-8 Mag Tape & Logs Have not received or'distributed such info (Well Abandoned) /cat Receipt Acknowledged: DaceA/.aska 0ii & Gas Cons. Commission Anchorage DISTRIBUTION M. Adams D & M W.V. Pasher ' G. Phillips F.G. Baker Drilling Phillips Oil P. Baxter Geology BPAZ Mobil J.J. Rathmell Chevron State of Alaska Sohio Union ~SK Operations R&D Well Miles ARCO Alaska, Ir P:': C.~fi;:.~ 'E:ex 3GC, Anch(:,rage. A~a~ka 99510 Tef,::phone 907 277 5637 Date: 9/11/84 Transmittal No: 4719 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 nsmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. PBU SURVEYS/PRESSURE ANALYSIS 2Z-7 17'/84 Run 1 Lynes 8/18,19/84 2B-7 '"/ 8/17/84 " Lynes 8/17-19/84 ] 2B-9 8/17/84 Lynes 8/17-19/84 ! 1C-9GI ~7/07/84 Camco 7/08/84 ' ~i~: ..... : ........ TZ''~'''~:''', ~,,'"" J?~':~'"' 5i~i'~ J~7/! 2-14 / 84 Camco 7 / 12 / 84 1B-5 "" 3.2/15/84 Otis 12/16/84 SEQUENCE OF EVENTS Falloff Test II Il Static BHP 1C-4 ....~'" 12/17/84 Otis 12/17/84 1C-6 12/29/84 Otis 12/29/84 Il l! 1D_7''"~112/19/84 Otis 12/19/84 II 1D-4~''- 12/18/84 Otis 12/18/84 Il /cat Receipt Acknowledged: B. Adams D & M F.G. Baker Drilling P. Baxter Geology BPAE Mobil · · Chevron DISTRIBUTION W.V. Pasher Da . ~-- Alaska 0il & Gas Cons. ~::cmmissior Ancl~ors. Ca C. R. Smith C. Phillips Phillips Oil Sohio J.J. Rathmell Union NSK Operations R&D Well Files KUPAFLJK EI'E~ I NEERI ~ D. W. Bose/She i by J. Mat thews' ' TranSmitted herewi th are the foi lowing: PLEASE NOTE: BL- BLUELI[~E, S - SEPIA, F- FILM, T- TAPE, ZI PT ~'~ F'~ED: · PLEASE REItJI~ RECEI PT TO: ARCO ALASKA, INC. ATrN: SHELBY J. IVlA77HB.'.~5 - ATO/1115-B: P. O. BOX 100360 ~E, Al(. 99510 At'lantic Ritchfield Company Arco Alaska, Inc. TRAN S}IITTAL To: Wm.-Van Alee.n/Sate . D.ate:' 31 August, 1983 of AK From: EXTENS IoN/EX~LORATI ON' o. Transm/tted herewith are the following: Mud logs From the iA- 5 · 1A-8-{-West Sak 12) lB-5 ~(West Sak 7) 1C-5 / 1C-6~ 1D-4-' 1D-8~West Sak 1F_5j- lO_4~ 1H-3~ 1H-6 / 1Y-14 J 2C-6 j 2C-7,~ 2X-2 ~' 2Z-4- 8) folloving .wells' g-ll-81 7-22-78 11-27-77 1-1-81 2-9-81 3-1r81 12-31-79 4-7-78 8-20-82 10-12-82 7-24-82 5-19-82 2-4'83 7-8-83 6-29-83 7-2-83 6-t0-83 Also-' included is an expanded' core-log from well 2Xz2,'7-2-83. A blueli'ne copy and a Sepia is provided for each well.. . . R./. eipt Acknowledge: . R'~turn recai to: Arco Alaska, Inc. At tn: XM~XM~0~kX E. P.O. Box 100360 ~orage, ~ 9~510 McAllster Prepared by: B.BYI4ne KUPARUK ENGINEERING TRANSMITTAL ~ ~)m'~_o William V'~-n Alen TO: FROM: D.W. DATE: <~---/~-~ WELL NAME- .. Bose/Shelby J. Matthews Transmitted herewith are the' following- . · PLEASE NOTE:...... F - FILM,, T - TAPE, PC - PHOTOCOPY f DATE: "~.--~-.' ARCO AI'ASKA, INC. Alaska 0~ ' A~N' SHELBY J. MATTHEWS- AFA/311 ~Con.~.~, P.O. BOX 360 ANCHORAGE, AK. 99510 T~ansm~tted herewith a~e the ~ollOW~n~: ~ErEIVE3 AUG 1 9 1~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 80-155 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20547 4. Location of well at surface 1515'FNL, 1066'FWL, Sec 12, TllN, R10E, UM 9. Unit or Lease Name Kuparuk 25649 At Top Producing lnterval 1716'FNL, 1414'FEL, Sec 11, TllN, R10E, UM lO. WelINumber 1C-4 At TotaI Depth 1693'FNL,. 1430'FEL, Sec 11, TllN, R10E, UM ~.FieldandPoo~ Kuparuk Rive[' Field , 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 94' RKB ADL 25649 KuDaruk River 0ii Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 1/1/81 2/1/81 2/7/81I __ feet MSL 1 17. Total Depth (MD+TVD)18.Plug Back Depth (MD+TVD)19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafros't 7575' 6896' 7456' 6777' YES J~ NO[]1883' feet MD · . 22. Type Electric or Other Logs Run DIL/SP/GR/BHCS, FDC/CNL/GR/NGT, CBL/VDL/CCL/GR. 6radio/SDinner/HP. 6radio/Temp; Eyre. 23. CASING, LINER AND CEMENTING RECORD RHC.C,/p.R. I')TP/P.R_ FDP/PI, JI /klP. T SETTING DEPTH MD KC Capture Lo,] CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD . AMOUNT PULLED - 20" 94# H-40 Surf 80' ~?" 245 sx A.S II cmt 13 3/8" 72# ..... N-80 Surf 2910' 17 1/2 1800 $× Fond,_, & 30t~ sx A.S II 9 5/8" 47~ 7" 26# K-55 6612' 7545' 8 1/2" 210 . 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. ~ '"' TUBING REC~ORD interval, size and number) ' SIZE' .~*~, ,.,~,~?~¢,S,,ET., (MD) PACKER SET (MD) 7088 '-7148 w/4 -SPF 3 !/2" 6986' 69q5 ' 7208'-7218' w/4 SPF 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. - DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ii I"/1~1 ~nnnn ~,,. "and -..4 h~;nnn ~ ~ ~ .... itc - 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 12/16/81 Flnwlnn Date of Test Hours Tested PRODUCTION FOUR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IG~['S-OILRATIO 11/10/81 14.5 TESTPERIOD I~ 1305 378-- ~,l~l,J ~on OIL-BBL GAS-MCF WATER-BBL O~ I' ~G~ ~V ITY-Ap I'-(~o~r) Flow Tubing Casing Pressure CALCULATED Press320 _- 24-HOUR RATE I~ 1:122 383 -.- 23.9 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or wate¢. Submit core chips. N/A RECEIVED MAR 1 5 1982 j / i~as~ Oil & Gas Cons. Commissio. .n_ !, Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE · , ,, 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME . .. Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. , ,, Top Kuparuk RJ. ve ~' Fo~'m, 7088' 6410' Base Kupa~'uk RJ_ve~' Form. 7446 ' 6767' 31. LIST OF ATTACHMENTS · 32~ I hereby certify that the foregoing is true and correct to the best of my knowledge _ F- Ori?inaJ s,..~ 'MAR 0' 1982 Signed. j ~,j ~1. 5. -n-~-¥T-~I~- , Title Az'ea 0ps. Engr. Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Itpm 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. Post Office Box ~ Anchorage, Alaska' 99310 Telephone 907 277 5637 December 22, 1981 Mr. Hoyle H. Hamilton State of Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Hamilton: Attached find revised Sundry Notice Subsequent Reports for Kuparuk Wells 1C-3 and 1C-4 to correct surface and bottomhole locations. Sincerely, J. S. Dayton EAS/bl Attachments ARCO Alaska, Inc. is a st~bsidiar¥ o~ AtlanticR~chfioldCompany J ECEIVED* DEC? z, JS8] a!aska 0il & 6as Cons. Anchorage O,L) STATE OF ALASKA 0~ ALASKA AND GAS CONSERVATION C ~ ISSiON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] X OTHER [] 2. Name of Operator ARCO Alaska, ]]nc. 3. Address P.0.Box 360, Anchoraqe, AK 99510 4. Location of Well SL 1515' FNL, 1066' BHL 1693' FNL, 1430' 5. Elevation in feet (indicate KB, DF, etc.) 94' KB 12. FWL Sec 12 T11N, RiOE FEL, Sec 11, T11N, RiOE 7. Permit No. 80-155 8. APl Number 50- 029-20547 9. Unit or Lease Name Kuparuk 25649 10. Well Number 1C-4 11. Field and Pool Kuparuk River Field 6. Lease Designation and Serial No. A_nL 25649 Kunaruk River F)il Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation XE] Abandonment [] Repair Well [] Change Plans [] RePairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On Saturday, November 7, 1981, Kuparuk Well 1C-4 was stimulated with a fracture treatment. Gel Sed diesel was used as the pad and the fracturing fluid. The well was propped with 30,000 pounds of sand and 45, 000 pounds of bauxite. All pressure equipment was pressure tested to 5000 psi. All injected and produced fluids were flowed to surface vessels and disposed of. The Kuparuk C-4 test rate increased from a pre-frac test rate of 757 BPD to post-frac rate of 1420 BPD. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed , , ~-~ Title The space~l;w fo; Commission/~ Conditions of Approval if any' ~ EngineerDate By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Bo 0 Anchorage, Ai~ ,~ ~'9510 Telephone 907 277 5637 December 11, 1981 Mr. Hoyle H. Hamilton State of Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Hamilton: Attached please find subsequent report, s Well lB-7, 1C-3, 1C-4, and 1E-3. Sincerely, S. Dayton Area Operations Engineer EA.S/bl Attachment for Kuparuk r., "1 5 1-98! L~ E !~ 0il & d;~,s Cons. STATE OF ALASKA ALASKA AND GAS CONSERVATION CO ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O.Box 360, Anchorage, AK 99510 4. Location of Well.., .. , :,,/0~z.,~/.~-~.~ o~z~.-.~,, /.~z,,~----.~=--~% ,,'06 6./~a BHL 1143' FSL, 649' FWL, Sec 11, TllN, R10E 5. Elevation in feet (indicate KB, DF, etc.) 94' KB 12. 7. Permit No. 80-155 8. APl Number 50- 029-20547 9. Unit or Lease Name Kuparuk 25649 10. Well Number C-4 11. Field and Pool Field 6.ADLLease Desig.atio,25649 a,d Seria~ No. KuparUkKuparuk RiverRiver Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation ~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On Saturday, November 7, 1981, Kuparuk Well 1C-4 was stimulated with a fracture treatment. Gelled diesel was used as the pad and the fracturing fluid. The well was propped with 30,000 pounds of sand and 45,000 pounds of bauxite. All pressure equipment was pressure tested to 5000 psi. All injected and produced fluids were flowed to surface vessels and disposed of. The Kuparuk C-4 test rate increased from a pre-frac test rate of 757 BPD to a post-frac rate of 1420 BPD. DEC1 5 .AJaska 0il & Gas Cons. Co~rnissio~.~ Ar~ch0rag~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~;O; Eommiss~~ Area Operations Signed ~, Title Engineer Date Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~ '~ ~-- t NORTH ~LOPE TRAi!SHITTAL # ¢9'¢ J. J. Pawelek/Ann Simonsen DATE' //-'"2 .~---"~/ WELL NAME' /¢__..,' -~/ Transml ~,_d herewith are the following PL,-.'*..~- HOTE' BL - BLU=L!i.IE, S - SEPIA, . . F- FILM, T - TAPE gt~l c. ~.--,:_: ,',=,uRN RECE~?T TO' NOV 2 5 IS i ARCO ALAS!iA INC , · ,-,..= , Oil & aa,- Con Comm.t~,,~i-''' n,,,, ' ATT~I' ~,-,~ SIMO~iSE~ - AFA/311 P.O. BOX 360 ~ '-~' ~ 9951 O)L STATE OF ALASKA ~M ALASKA AND GAS CONSERVATION CO ISSION · DR, ILLING WELL CO~'VIPLETED WELL [] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address 1). O. Bo× 360, Anchorage, 4. Location of Well Alaska 99510 Surface location' 1515' FNL, 1066' FWL, Sec 12, TllN, R10E 5. Elevation in feet lindicate KB, DF, etc.) KR = 94' 12. 7. Permit No. 80-155 8. APl Number so- 029-20547 9. Unit or Lease Name Kuparuk 25649 10. Well Number C-4 11. Field and Pool Kuparuk River Field 6. LeaseDesignat,onandSerialNo. Kuparuk River Oil Pool ADL 25640 · Chec~ Appropriate Box To' Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well .r-- Change Plans [] Repairs Made [] Other [] Pull Tubing ~ Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each comp4-etion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details an(: give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perform a fracture treatment on the Upper and Middle Kuparuk sands in cased well C-4. Pumping equipment will be tested to 5000 psi. A 3000-psi lubricator will be used for all wire- line work. All circulated and flowed fluids will be diverted to tanks on location. The well w~ll be tested subsequent to the stimulation. The expected starting date is10-20-81. Subsequent WoA~ Be7°:ted on Form No./_&:.Y_Z23 Dated/--~/~~ RECEIVED 0CT 1 6 198I Alaska Oil & 6as Cons. ~ommission Anchorage Fc-.m 10-403 ....... u, url£U 8-27-81 By Order of CON1M, ISSION ER the Corem,ss,on Returned Submit "intentions" ~n Trrpiicate and "Subsequent Repo,'ts" tn Dt~Dl,cate TRA~!S;'iLTTAL" ~d)~ J. J. Pawelek/Ann Simonsen DATE' -//~ ~/ '.'ELL ' .... · Transmi;ted here;.,,i;h are the following' F- FILM, T - TAPE DATE' PLEAS~ ,',EiLF..t ~',L~c,,'T TO' ARCO ALASKA, IUC. ATT;I' A~;;i StF0iISE'! - AFA/311 P.O. BOX 360 ~.: ,,-~.~.~ ~.., aqS10 RECEIVED OCT 1 6 1981 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, InC. B,' ~)3 Post Office o. 60 Anchorage, Alaska 99510 Telephone 907 277 5637 Hand del~.'~red SAMPLE TRANSMITTAL SHIPPED TO: State of Alaska DATE' Octorbcr 2, 1981 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn' Mr. Wm. VanAlan OPERATOR: Arco SAMPLE TYPE: dry ditch and core chips NAME: Kuparuk C-4 NUMBER OF BOXES: seven SAMPLES SENT: drys: core chips: 130 - 2260 3536 - 3556 core #1 2260 - 5140 3566 - 3595 core #2 5170 - 6960 3910 - 3637 core #3 '4134 - 4139. '. core #4 . . 4139.5 4140 - 4144 4159 - 4176 core #5 4210 - 4211.S core #6 ~ 4211.5..- 4212.2 4212 - 4214 4219 - 4237 core #7 (samples are in one foot intervals unless'listed otherwise) SHIPPED BY: ~.=~ '~ ~.~~. Paleo Lab Supervisor UPON RECEIPT OF THESE SAMPLES, .PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO' ARCO ALASKA, INC. P.O. BOX 360 ANHCHORAGE, ALASKA 99510 ATTN: R. L. BROOKS DATE: Alaska Oil & Gas Anohorago ARcO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc Post Offic ~x 360 Anchorage, ,Alaska 99510 Telephone 907 277 5637 April 30, 1981 Mr. Hoyle Hamilton State of Al as'ka Alaska Oil and Gas CQnServati on Commi ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 14-9A DS 16-3 DS 1 6-4 DS 16-8 DS 16-9 DS 16-12 C-4 . C-5 C-6 15-22 Confidential Dear Sir' Enclosed please find: · The Completion Reports & Gyroscopic Surveys for DS 15-22 (T-l), DS 16-3, DS 16-8, DS 16-9, DS 16-12, C-4, C-5, C-6. Please note that DS 15-22 (T-l) is CONFIDENTIAL. 2. The Completion Report and Multishot Survey for DS 14-9A. 3.. The Completion Report for DS 16-4. An updated Completion Report and Gyroscopic Survey will be submitted as soon as data becomes available. Sincerely, P. A. VanDusen District Drilling Engineer PAV/KJG'sp Attachments RECEIVED MAY - 1 1981 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska. Inc. is a Subsidiary of Atlan{icRichfieldCompany WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ,,, 2. Name of Operator 7. Permit Number Atlantic Richfield Company 80-155 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 9950] 50-029-20547 4. Location of well at surface_/,, ..9. Unit or Lease Name 1515'FNL, 1066'FWL, Sec 12, TllN, R10E, UM ,<~.,~.,~' Kuparuk 25649 At Top Producing Interval . ~ ~ ~'/, ~ .,.'~C~ / 10. Well Number 1716'FNL, 1414'F~, Sec ll, TllN, R10E, UM ~.,' C-4 At Total Depth ! , ~" 11. Field and Pool 1693'FNL, 1430'F~. ', Sec ll, TllN, R10E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KBS, DF, etc.) ] 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 94' RKBI ADL 25649 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 1/1/81 2/1/81 2/7/81 -- feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7575MD 6896TVD 7456MD 6777TVD YES~ NO[] 1894 feetMDI 1650' (approx) 22. Type Electric or Other Logs Run DIL'/SP/GR/BHCS, FDC/CNL/GR/NGT, CBL/VDL/CCL/GR, Gradio/Spinner/HP, Gradio/Temp, Gyro, 23. CASING, LINER AND CEMENTING RECORD BHCS/GR, DIP/GR. FDC/CNL/NGT SETTING DEPTH MD KC Capture Log CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED , 20" 94# H-40 surf 80' 32" 245 SX AS II cmt to surface 13-3/8" 72# N-80 surf 2910' 17½" 1800 sx Fondu & 300 sx AS II 9-5/8" 47# L-80 surf 6935' 12¼" 800 sx Class G 7" 26# K-55 6612' 7545' 82" 210 sx Class G 24. Perforatio'ns open to Production (MD+TVD of Top and Bottom an'd 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3~"- ~. 6986' 6952' 7088-7148 w/4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. · " 7208-7218 w/4 spf ~ . DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED n/a ... , . 27. PRODUCTION TEST ,, I Date First Production Method of Operation (Flowing, gas lift, etc.) n/a Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow.Tubing .'Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press... 24-HOUR RATE I~ ' 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil gas or water. Submit core chips. To be ' ' submitted by ARCO Geology Dept. under separate cover. ~b ./ . ' . · ...,. · · Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS ...... NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk 7056' 6378' Top Up Sand 7086' 6408' ~ See Attached Base Up Sand 72] 8' 6540' Top Low Sand 7342' 6664' Base Low Sand 74]0' 673]' Base Kuparuk 7446' 6767' 31~. LIST OF ATTACHMENTS Drilling History, Gyroscopic Su.rvey: Formation Flow Test Report 32. ~ hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and.24: If this well is comple, ted for separate production fromm:more than one interval (multiple completion), so state in item 16, and iq?.i.tem 24 show the producing intervals for only the interval reborted in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). "'Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 C-4 DRILLING HISTORY Spudded well @ 1800 hrs, 1/1/81. Drld 17½" hole to 2925' Ran 72 jts 13-3/8" 72# N-80 BTC csg w/shoe @ 2910'. Cmtd w/1800 sx i2.0 ppg Fondu & 300 sx 15.2 ppg AS II cmt. ND diverter. Set 13-3/8" pkoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 2000 psi f/15 min - ok. Drld cmt, FC, FS & 10' new form to 2935' Tstd form to 12.3 ppg, EMW- ok. Drld 12¼" hole to 3536'. Cut core ~1 f/3536'-3566'; #2 f/3566'-3596'. Drld 12¼" hole f/3596'-3910'. Cut core #3 f/3910'- 3938'. Drld 12¼" hole f/3938'-4134'. Cut core #4 f/4134'-4159'; #5 f/4159'-4194'. Circ hole clean. Cut core #6 f/4210'-4219'; #7 f/4219'- 4239'. Drld 12¼" hole to 6960'. Circ & cond for logs. Ran DIL/SP/GR/ BHCS, FDC/CNL/GR/NGT, CBL/VDL/CCL/GR. Cleaned out to 6960' Ran 176 its 9-5/8" 47# L-80 BTC csg w/shoe @ 6935'. Reciprocated & cmtd csg w/800 sx Class G cmt. Instld 9-5/8" pkoff & tstd to 3000 psi f/30 min - ok. Tstd BOPE to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld cmt, FC, FS + 10' new form to 6970'. Tstd form to 12.5 ppg EMW - ok. Chngd ,to "oil faze" mud Drld 8½" hole to 7042'. Cut core #8 f/7042-7101 Cut Core #9 f/7101-7161'; #10 f/7161-7219'; #11 f/7219-7278'. Circ & cond ~ole. RU surface tstg assy. RIH & set RTTS pkr @ 6850' Tstd ann to 1000 psi - ok. Displ 3½" DP w/diesel to pkr. Ran open hole ~low test #1 on 64/64" choke (see attached Halliburton formation test report). Ran Gradio/Spinner/HP while flowing well. POOH. RIH w/Gradio & temp survey. Flowed well on 22/64" choke for flow test #2. FTP = 390 psi. SI well. SITP: 1000 psi. SIBP: 3190 psi. Bullhead to kill well w/55 bbls oil- faze mud. Unseated RTTS pkr & opened by-pass. Circ & cond mud. POOH w/DP. Tstd BOP to 3000 psi & pulled test plug. Set wear ring. Washed & reamed f/6935-7278'. Cut core #12 f/7278-7236'; #13 f/7336-7338'; #14 f/7338-7398'; #15 f/7398-7457'; #16 f/7457-7516'. Drld 8½" hole to 7575'. Arctic packed 9-5/8" x 13-3/8" ann w/300 bbls H20, 300 sx 15 2 ppg AS II cmt & 116 bbls Arctic Pack. Ran BHCS/GR, DIP/GR, FDC/CNL/NGT, KC capture log. Circ & cond hole. Ran 22 its 7" 26# K-55 BTC csg f/6612- 7545'. Cmt lnr w/210 sx 14.2 ppg Class G cmt. Drld FC, cmt to 7456' PBTD . Tstd lnr lap to 1500 psi - lost 30 psi in 1st 15 min & 10 psi 2nd 15 min. Displaced oilfaze mud w/NaBr. Ran Gyro f/0-7460'. Ran CBL/VDL/GR/CCL f/2000'-7456'. Ran 3½" compl assy w/tail @ 6986 & pkr @ 6952. Tstd tbg hngr to 3000 psi - ok. Displaced NaBr in tbg & ann w/diesel. Dropped ball & set pkr. Tstd tbg to 3000 psi - ok. ND BOP. NU tree & tstd to 5000 psi - ok. Tstd 9-5/8" x 13-3/8" ann to 1000 psi - ok. Prssrd tbg to 3000 psi & 3½" x 9-5/8" ann to 250 psi (w/ diesel). Begin long term tbg tst. Secured well & released rig @ 1100 hrs ' . - a$O. ON$' . ¢~. ) F L U ! D S A M P L E D ' ^ Date 1-27-81 TicketNumber 566241 Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of D.S.T. FLOW TEST Location ANCHORAGE cc. Oil cc. Woter Tester MR. MC MAHAN Witness MR. JONES cc. Mud Drilling Tot. Liquid cc. Contractor ROWAN DRILLING COMPANY #34 bc Gravity ° APl @ °F. EQ U I PM E N T & H O L E DATA Gas/Oil Ratio cu. ft./bbl. Formation Tested KuparuK RESISTIVITY CHLORIDE Elevation Ft. CONTENT Net Productive Interval Ft. Recovery Water (~ --°F. ppm, All Depths Measured FromKal ly Bushing Recovery Mud @ °F. ppm Total Depth7278'Ft. Recovery Mud Filtrate @ °F. ppm Main Hole/Casing Size9 5/8"C§g. to 6935'-8~"~ Hole Mud Pit Sample __ @ °F. ppm Drill Collar Length - I.D Drill Pipe Length. 6843' kD 2. 764" Mud Pit Sample Filtrate @ °F. ppm Packer Depth(s) 68 50 ' lt. Mud Weight 1 0,4 vis' ~ec. Depth Tester Valve. - .Ft. TYPE Dept~ Back Surface ¼n Bottom Cushion Bi esel A~j~T Ft. Pres. Valve Choke Choke 2¼" Recovered Feet of ., Recovered Feet of Recovered Feet of .~. b~9,.~ Recovered Feet of ~&>Ca Cb/,. Remarks Displaced drill pipe with diesel (6.8#) and then set packer. SEE PRODUCTION TEST DATA SHEET. CS = Clock stopped *Time given and time recorded does not agree Gauge No. H-206 Gauge No. H-207 ' Gauge No. TIME TEMPERATURE Depth: 68621 Ft. Depth: 68621 Ft. Depth: , Ft. (00:00-2'4:00 hrs.) 144Hourao~k 120 Hour Clock HourClock Too~ 1-23-81 Est.' ;F~ Blanked Off No Blani~ed Off No Blanked Off Opened 2230 6862' @ 1u~C & Openedl-26-81 Actual 1480 °F. Pressures Pressures Pressures Bypass 2300 Field · Office Field Office Field Office Reported computed ,, Initial Hydrostatic 334Z 3362.0 3336. I Minutes Minutes Initial 3106 2685 3 Zbbb.b ~ Flow ' ~ F~na~ 1685 . 1691,8 1668,7 1605 1592 Closed in 3106 3137,9 3114,8 1065 1069 ~ Initial 2907 2887 9 2871 7 ~,~ FlawFinal 2?02 2199,5 2179,4 870 879 m~ Closed in 3116 3135.7' 3097 8-CS 810 788* ~ Initial - ._~.o_ Flow ~. Final . Closed in _Final Hydrostatic 3386 3362.0 3336.1 FORM 181--R2 -- PKINTSD IH.U.S.A. FORMATION TEST DATA LITTLE'S · ' 566241 Cosing-pearls. Bottom choke Surf. temp 'F Ticket No. Gas gravity Oil gravity GOR Spec. gravity .Chloride,~ ppm Res. @ °F INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED i ~D~te 1-23-81 Choke Surface Gas Liquid T~me a.m. Size Pressure Rate Rate Remarks . p.m. psi MCF BPD 0945 J Started clocks 1025 Made up surface & down hole tools 1030 Ran in hole 1310 On bottom rigged up manifold flow ' ' lines and test 1415 Seated and unseated packer 1500 1280 Diff. Filled drill pipe with diesel 2030 Tested surface equipment again 2044 Ran in hole with wireline tools 2230 16/64" 1200 Opened surface manifold ~., 2300 " 30 Slight blow 1-24-81 0400 32/6R" 200 Changed choke, flowing gas and oil 0630 48/64" 220 Flowing gas and oil '0800 64/64" Turned to separator, tool man released 1-25-81 0115 Shut in for pressure buildup 1900' 16/64" Opened well to flow ?00~? ,-,., 22/64" Changed choke I - ~-U--O I 0930 Shut in for pressure buildup ,. 2300' Ki13ed well 1-27-83 0010 Unseated packer 0600 Circulated hole . 0700 Pul 3 ed out of hole i-' PRODUCTION TEST DATA LITTL1E'¢: 96672 e No. First Flow Period Time Deft. PSIG Temp. .000" Corr. H-206 I Depth First Closed In Pressure Time Defl. .~ .000" Log .2432 2105·1 2042 C .2005 .3242 1892.2. C .2402 1747.8 .2798 .4863 1711.2 .3195 · 1674.5 .3591 · 1657.3 .3988 .7295 1665.9 .4384 .8106 1609.9 .4781 · 8900 1691.8~ .5177 .5574 PSIG T&mZ· 1691.8 2971.9* 304 3.1 3071.1 3084· 0 3096.9 3105.6 3112.0 3116.3 3120.6 3122.8 6862' Second Flow Period Time Defl. .000" .0000 .0280 .0371 .0743 .1114 · 1485 .1857 .2228 .2599 .2971 .3342 PSIG 2887.9 2911.6) 2491.4 2272.5 2261.7 2246.7 2244.6 2233.9 2227.4 2225.3 2223.1 22769 Clock No. Second Closed In Pressure Time Deft. .0000 .0333 .0667 · 1000 .1333 .1667 .2000 .2334 .2667 .3000 .3333 PSIG 2199.5 3025.8 3075.4 3096.9 3107.7 3114.2 3120.6 31 25.0 3127.1 3131.4 3133.6 3127.1 .371 3 2223.1 ..3667 3135.7 3131.4 .4085 2218.8 .4000 3135.7 3133.6 .4456 2203.8 .4333 3135.7 3137.9 .4800 2199.5' ~* .4380 3135.7' 3137.9 I Ticket 566241 [ 44 hour No., Third Flow Period r** Third Closed In Pressure Time Dell. PSIG Time Defl. t-~-~ PS IG Temp. Log Temp. .000' Corr. .000" ~ Corr. Gauge No. H- 207 Depth 6862' Clock No. 21828 1 20 hour o .0000 ~2 .0976 .1953 i(( '2150 .2929 · 3200 il.3906 · 4882 .5859 .6835 7oI .7811 i~ ·8788 12 .9764 ~3 1.0720 15 2666.6 2987.1 2886.7 3065.9 2089.7 2021.3 1871.7- 1726.4 · 0000 .0505 .0983 C .1461 .1940 C .2418 C . 2896 .3374 1690.1 .3852 1653.8 1636.7 .4331 · 4809 1647.4 .5287 1587.6 .5765 1668.7 .6243 .6721 ,Reading Interval 145 REMARKS: · 7200 71 1 668.7 2944.4 *' 3014.8 3044.6 3059.5 3070.2 .0000 .0340 .0458 ·0916 .1374 .1832 2871.7 2891.0 2465.8 2252.1 2241.4 2226.4 3080.3 .2290 2226.4 3087.2 .2748 2213.6 3091.4 . 3206 2209.3 3095.7 .3664 2205.1 3100.0 .4122 2202.9 3104.2 .4580 2202.9 3106.3 .5038 2198.7 3110.6 .5496 2183.7 3114.8 3114.8 .5920 2179.4' 68 tl = 75 minutes .0000 .0404 .0809 .1213 .1617 .2021 .2426 ( .2520 2179.4 3002.1 3053.1 3072.3 3082.9 3091.4 3095.7 3097.8 CLOCK S'FOPPED AI:TER APF IOXIMATE_Y 374 MINIJTES .... LAST IN'FERVAL = 14 min~ es 60 ***Interval : 63 mi nut ' Minutes _ *Interval : 142 minutes **Inter' ;s ****Interval = ~ minutes C = Choke change TIME Each Horizontal Line Equal to 1000 p.s.i. Drill Pipe or Tubing .............. Drill Collars ..................... Reversing Sub .................... Water Cushion Valve .............. . DHII Pipe ....................... Drill Collars ..................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint .................... AP Running Case .................. Hydraulic Jar .................... Circulating valve VR Safety Joint '. ................ Pressure Equalizing Crossover ......... Packer Assembly ................... X over Bundle Carrier Distributor ........................ Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube .......... Blanked-Off B.T. Running Case ....... Drill Collars ...................... Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... FORM I~B?--R2 -- PRINTED INU.S.A. O.D. I.D. NO. LENGTH 566241 DEPTH 3.5" 2.764" 6843' 3.68' 6.48' 1' 7.98' 6850' 6862' 7278' EQU! PMENT DATA LITTLE'S 111036 75C ~ .... Ill ~ COifGt.0~r~AT~ COAt ~ GYP&'ttI& E~ UiAi'.$ I 0)~ .._ SY~'B-OLS .. ! C. AT.CAr~C-O U?' ! · OOt OMI 1'!C.. , Gl.AU CO ~i Ti C ' oou'f~,~ - ~ILJ C~.O U.f, L-- C:l, i~ioo . . II Ill .{ · iill~l I I 11 ~[lllll~III ll. I I I I · .=:j. , l I I[illl I ' I lll[[l[ [ll~l l I Ill · ~ I IIll lllIIIIll,] .. 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I ' ' ' · I lm~ll~mkl"ll' - - mm -~ m mmm j February 24, 1981 Mr. Bob Hines ARCO Alaska, Inc. ?. O. Box 360 Anchorage, Alaska 99510 · Re: Our B~ss Gyroscopic Survey Job No. Boss-16745 Well C-4 (SEC12 TllN R10E) Kuparuk Field North Slope,'Alaska Survey Date: February 5, 1981 Operator: Tom McGuire Dear Mr. Hines: Please find enclosed the "Original" and one (1) copy of our ~Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service.. Yours very truly, SPERRY-SUN, INC. Kirk Afflerbach Senior Survey Engineer KA/kc Enclosures ~ARCO ALA~'KA, WELL NO. C-q SEC12 TllN PlOE NGRTH SLG~E~ SLAGK$ 50SS SURWEL TRUE' SUB M~ASWEgD ............... ~.g.B.LT.g..A..g ..................... SE A DEPTH DE PTH TVD "'JATE OF fURVEY FEL",FUARY [ ~ 19~.1 VERTIC.:~L SECTION PIRECTION SPERRY'SUN~ INC. RECORD OF' SURVEY COURSE COURSF DOG-LEG INCLINATION DIRECTION SEV DEG MIN DEG N].N DIG/lO0 TOTAL RECTANGULAR CCORE'INATES VEP. TIC$L NORTH/SOUTH EAST/WFS T SECTI Or, ............... q:OO ...................... P.:.OO ...... -9~.00 ORIGIN AT SURFACE :~:..'- 100.00 lOO.OO 6.00 0 12 S 60 q2 E i:.i: 200.00 200.00 106.00 0 1 N 56 6 E '-'-::;.:.. ~_o_:_Q...,._O..q .......... ~_o..._P...O.. .... ~ ......... 2 .c_,.¢; ..0 o ....... q 1 o .... N.. 75. 12. E z~O0.O0 400.00 306.00 0 11 N 55 lg E O.O0 N O.O0 E . ~0 .09 ~ - .~ , ,.. .15 E ,]9 .16 S .32 g -.~,~ 1~ ¢' .......... ..~ ...................... ~!_..? ........ .~S E .' .fi7 .02 N ,76 E -,75 ....... 500.00 .................. 500.00 ................... ~05.00 0 11 N 27 5 E l" 506.00 0 10 N ~7 ~B E 600.00 600.00 i: '::::' 7 .00 _0._.0 ......... .~-.(L,.._O....q ........... 7..0.,~.,. o 0 ......... o.. 8. _ s ~ z 5 ~. E ....... 900.00 900.00 gO6.00 0 2 N 1~ 56 E .09 .26 N .07 ~ -.94 · ].2 .66 N 1.17 E -1,13 · 11 .&2 N 1,35 E -1.2C o~ .Ax ~l 1.4K E -1,39 .16 .56 ~: 1.~2.. r,.. -1.~7 .'~'-:.:. 12oo.oo 1~'9-9.~z' ........ ...]1o5.21 8 7 s-sz 1~'~ w [/.'""~;-125oooo 12~8o55.:'z' ......... .. 1.5~.55 lO_.2~ ........ s e.i.$¢..N ........... ]300.00 1297.51 1203.5] 13 1 S 79 6 W 1,15 .63 N .53 f -.4F 3.51 ,02 S q,q3 W A,41 3.50 1.78 S ]5,38 W 15,1.= 4.52 2.99 S 23,33 W 23,01. 5.35 ~.72 S 33.31 W Z. 2,F1 2q W 12 W ~2 W e. W 5.25 7.14 S qS.flq ¥: 44.70 5.12 10,35 S 59,58 W gS.b~'''~ 5.79 la.]l S 75.87 ~, 74.~ 3.14 ]7.82 S 93.98 L' $2,22 3.54 20.97 S 113.30 W 111.22 1.600.00 1578.9~ 1~8q.98 2fl 38 S 84 1. P W " .......................................................... :'-~ ................. 1,,:70.~~'":' ~ ..... .,,69 ' 1~ ~ 8~ 3' W '1700.00 · 1669.29 .... = · 1800.00 : 1758.32 166~,32 27 56 S 83 12 W .. 18~5.82~ 1751.82 29 56 S 81 18 W 2000.00 19;1.59 1737.59 31 56 S 79 5~ W 2.4q 23.35 c 133.62 ~,.; 1-~1,2c 1.59 %, 27.50 S 175.3~ W 173..~'2 1,8~, 32,~5 S 221.59 W 218,22 2,19 38,90 S 26q~.51 W 265.46 2.13 ~+7.31 S 320.21 W 315.30 "?:i?~?.'~2200.00 2099.~7 '' ~005.~7 ~2 ~-~ ' .......................... S aO 12.W 2500.00 2353.98 2259.98 31 13 S 80 18 ~ 1,6.3 ~7.16 e 373,'~'~ W 317,q'~ .79 67,31 S q27.03 ¢ ~20.14 · 56 77,00 S 479.82 W q71.97 · Sfl 86,2fl S 531,9q kI 523.16. · 51 95.08 S 583.35 W 573.71 SPE .... :'.i "REc'oRD COURSE CO INCLINATION TVD DE6 giN DE FA GE ' 2 DATE OF ,cURVEY FEBRUARY 6, 19&l VERTICAL SECTION DIRECTION [:I8~-"20-00--~' · RRY-SUN, INC, SURVEY URSE DOG-LEG TOTAL ECTION SEV RECTANGULAR COORDINATr'S NIN 'DEG/].O0 'N;gRTiLi/S'O'OTH. .... E'A~I'/WFC'T,.. .:, E. OSS-1674b VERTICAL SECTION 2600.00 2q39.70 21.45.70 30 47 S 7 ~7~-2-~'0"":~-~"~" ........ T .... '~' ~'~,-5";=/g'"ii'F '-'"2' 4 ~ l'. 76 30'28 " S 8 ~']'::~:;:2RO0.O0 2612,17 :::;L 2518.17 : 29 59 ; S 8 3000,00 2785,98 2691,98 50 4 S 8 9 5 0 3 0 1 1 2 4 W .48 105.93 ~ 634.11 (.'W .48 ...... 112'56'S G8:4.31 8 N ,50 120,91 S 73~.,,~fl.. 6 U .80 128.90 S 7~2.73 c'"u " 'so ............1~'6;~ .... s .... 831.67 ~ 0 7fi9,~ 817.f~5 ::]:;::;:;:;:3300'00 '. 30q2'7~ 2908.70 32'32 t' ::%3000,00 ..,1.~6,7A 30.2,74 ...... . 33.11 3500,00 3210,07 3116,07 33 57 S 8 S 8 S 8 2 1 2 ,5 q 4'1 4 4 8. U .E. 6 1~$.07 S 881.79 O":U .72' :" :;:;1fi9"~'9:S. ....... 952.92 6 W t.40 156,06 S 985,50 2 b ,65 161.59 S 1039,47 8 W .GA .......... i'a'6"88 .... S ...... 10~4.50 91 02 6'7 . 22 63 87 3600.0'0 32' .r¢.-' 2 · 19 319P... 19 35 57 t ' ::: 3700.00 ~ 337...~3. 3279,33 35 56 ':;: 3360· 7 35 36 J 38o0.00 ,. ~o5~*.47 '.,' ~ : ~.~ ~ ' . I' ..-~900.00 ~u~, 1 ~ :3441,41 36 20 41 O0,00 3695.26 $601.26 ' 4400,00 3932,70 3838,70 .4500.00 ~Cll ,74 3 9i"7'"' 74 ....... S 8 S e S 8 S 8 S 8 5 2 5 4 5 4 6 1 6'4 ,4 W 2 W 2 W 2 W 1,69 ',171,75 · 36 ..... 176~29 ~3 180.67 · 79 1.84.ql ......... . ..................... · 87 188,51 37 7 S 87 12 W 37'32 . S 88 !2 !W . 37 59 : S 8~ lG'W 37 55 S 87 42 W 37'38 S 87 54 W 1151.33 1209.60 1267,88 1325.q7 13R6.17 ,., · 50 191,73 S 1446,45 ,74 .... 194,16' S 1507,04 · 4~ ' 1F:.'6,03 S 156,~, 25 .~ t98,17 S 1629.70 · 30 .... 200; 5'~" -S .... 1690,91 11~ 119 124 130 142 160 166 1.25 8.98 7,03 6,23 7.11~ ~.17 H.99 f1600.O0 40q1.04 3997.0A 37 26 S 88 0 W .22 202.70 S 1751.79 ~6 58 .~ 88" 6. :W .~6 2'0~,7'~''S 1~12.22 t.00 :: 4250.50 :~156,50 37 8 S 'RS 12 W ,17 206,71S 1872,q4 j?~;:!?!'4900'00 ;,;;; q330'76 :i : q2SG.76 $~ 6 $ 88 42 ~ 1.07 208.32 S 1932.06 5000,00 ~,41.2.3A q318.~ .............. 3~ .... 3~ .............S .... ~8 .....6 ~ ...... 1.58 ................. ~'09;'9'~'S ............ 19H9;'86 729 7P. 9 908 966., ,49 o18 5100.00 ~495.6A 4401.64 32 55 S 86 30 W 2.16 21.2.52 S. 20,r'...,,,09 I/., ::. ; 5200~ ,O'O'-"~ ...... ~-'~"~-2'~"~"T"7!"-'i'~87S22 29:'41 S' 85 4~ W 2,92 ' ' 2i5'97 S 209fi,68 W 5300'00" ~&69.17 657S.17 27 8 S 87 2~ U 2.67 218.82 S 21~.1({ U 5500,00 4851,38 ~q757,38 ............. 21"'~'0 ........ S'85 12"'U .... 2.65 .......... ~23,55 ..... S ......... 222(:.'31 U 2021 2072 2119 21.52 2200 ,15 ,25 ,20 .74 lC'-:'"' NORTH SLOPE, /'.LASKA BOSS SURwEL .i.i::?!'i!: :.' TRUE SUB CO DEPTH DEPTH TVD DE PAGE' 3 gAT.Lt. OF SLIRVEY FEI:'RUARY 6, lC:;P1 VERTIC.AL SECT]ON DIRECTION SPERRY-SUN, INC. RECORD OF SURVEY URSE COURSE DOG-LEG INATtON DIRECTION SFV G MIN DEG MIN DEOliOO POSS-l,~74r: TOTAL RECT~,NGULAR COORDI'~AT:'S VEF, TIS~L NORTi4/SOUTH EAST/WEST SECTION 6000.00 5329.65 5235.65 12 10 2.]5 22&.55 g 2261.3~ W 2255.~1 ,. 2.11 229.36 S 2292.86 W 22~6.60 1.65 2~1.90 S 2521.27 W 2294.7~ 1.75 233.76 S 2346.92 %' 2Z20.' 1.94 254.66 S 2369.59 10 2 N 88 ~2 W 8 ~6 N 84 12 ~ 7 31 N 80 30 W 6 49 N 76 36 W 6 9 N 72 12 W 2.19 1.~7 253.71 S 2q05.12 ~ 2~78.13 1.35 231.87 S 2qlg.lq ~ 2392.25 .~fl 229.41 S 2AZ1.$6 ~; 2404.63 .85 226.40 S 2442.23 ~ 2~15.72 :~?:'.7:;::~':6800.00">""" 6122,69., 6028,69 4 ' "'"-'--~?-:/6900.00 6222.q3'"" 6128.q3 4 7000.00 5322.18 6228.18 ~:2P.66 S 2fl~1.88 k' 2425.6c 218,28 S 2450.09 W ~43~.18 ~.~13.90 S 2466.69 ~d 2~41.11 209.5~ S 2472.19 W 24A6.96 :-'204.28 S 2477,09 W 2452.26 710C.00 6q21.96 6327.96 3 36 N 41 24 W .q2 oo.oo s N 7460.00 67S1.52 6687.52 ~ I N 31 2~ W .60 199.31 S 2~8].50 W 2qe7.06 154.65 S 2485.35 )W 2061.'.2~-' 189.48 S 2A88.72 W 184.56 S 24F1.98 W 2468.70 181.95 S 2~93.80 W 2470.72 7575.00,------6£.A96.16 6802.16 3 1 N 31 2A W 0.00 ]76.77 S 2496.95 ! C TIONS ARE ED ON THE MINIMU RADIUS OF CURVATURE MFTHOD ** HORIZONTAL DISPLACEMENT = 2503.20 FEE~ AT SOUTH 85' oE'-G''' ..... 5'~""~-~N' '~'E's'~" (TRUE) 2474.29 ........................................ .$. T A..R.T OF SURVEY WAS 9~,00 feet ABOVE SEA LEVEL ARCO ALA,.K~, I1~',~. WELL,NO. C-4 SECI2 T! tN RiOE NORTH SL. CPE, ALA~Kfio BOSS SURbEL .. FEBRUARY P~'. GF ' 5 6, 1981 TRUE MEASURED VFRTICAL DEPTH DEPTH SPERRY-SUN, INTERPOLATED RECORD SUB SEA TVD INC. OF SURVEY TRUF ................ FECTANGULA ELEV/~ T I Oht NOR Tt'i/SOUT TOTAL R COOR H EA DINATr~ SI/VE,ST 3361. 3094. ~451. 31~ 3726. 3794. 3H49. 3494. 3000. 3100. 3200. 3300. 3~00. . . -3000. -3100. -3200· -3400. 159. 166. 1.72. 177. 183. lOfA. ~ 11,~3. 1225. W 129 ~. W 4351. 3894. 4478. 3994. 3500. 370~. 3800. 3900. -3500. -3500. =700. -3~OOo -3900. 188. 192. 195. 197. 200. 1'~70. 1445. ,.., . 1600. 1C 77· 4978. 439Z~· 4300. 5098.. 4494. 4400. 5546. 4894. 5652. 4~94, 4500· 4600. 4700. 4800. 4900, -4 -4 gOO. 100. 300 · 400. -4500, -4600. -4700. -4200. -4 c ~1 0 · 20~ 205. 208, 210. 212. 21g. 219. 222. 225. 22 ~:: · S S S S S S S' S S S 175fl. 1830. 190~ 1977. 2fi44. 21g4. 2157. 2203. 2243. 2278. 5~60. :':' 519A. 51.00· 5~s3. · 52p~... .................. 52oo. 6066. 5394. 5300· 6167. 5~9~. SAO0. ::::6070. ::: ::' 579..~..': : . . 5700 6570. 5~4. 5soo. ~7 I _ ~qqA . :,q fl -5000~'~, 231 · S -5100, 233. S -5200. 234. S -5'zO0.~, 235. ,.S ¢:4n 9. 2'A4. S -5~.io o. 233. s -5600. 230. S -5700. 227. S -SAO0. 224. S -5~(ln. PP~. S 23 2~ 23 23 24 24 2~ 24 24 24 09. ,:7. .F.. 2 · ?!3 · 00. 15. 2P, o 39. 49. ARCO ALA KA, INC, WELL NO. C-q $EC12 TllN RICE K U P A P, U K _ ["L! .[ LE NORTIt SLGmE-, gL~SK~ BOSS SURWEL gATE OF SURVEY PA6E 4 FE[$RUAI~,t g., ]98! B3SS-t6745 ........... ] ................................................................. SPERRY-gUN, INC. INTERPOLATED RECORD OF SURVFY ......................................................................... !~..uE ................. MEASURED VERTICAL SUB SEA TRUF' DEPTH DFPTH TVD FLEVATI ON T REC T ~.N GULA R NOR l'H/SO JTH OTSL COCRDI~.~TE$ CAST/W:-ST 94. 94. O. . 19q. 1.94. 100. ! ...... ~ 2 · 294, 200 3~4.., ..... ~E~ ............... 300. ~94, ~94, 400, -100, -2UO, -~00. -4RO, O, S O, S O. S O, N O, N O. F 1· F 694. 69~. 794. 79~. 99~, ~9~, 500· 600. 700. 800. ~00, 1400. 1394. 1'.507. 14°A-., · 1000. 1100. 1200· 1300. 1400. -500, -EO0. -700 · -~00, -ciO0. -1 ooo, -1].00. -1230. ~1300. -1400. t'::i .... " i841. . ' ' ' 1956 · 1 .~" 94 . 2074. 1994. 15~0o 1600. 1700. 1800. lcOO, -1500. -1600. -1700· -lbOO. -1900. '2 4, 2q. 1!i9. t, 2ql. w 29 ,fi · W 2193. 2312. 24=0.. 25~7. 2663. D'T] ,~ 4'~. ..... 2 o o o. 219~+. 2100. 229~. 2200, 2494. 24O0. -2000. -2100. -2290. -2~o0.' ........................ -2400. 67. .89. 99. 10:). q2q. W 4 .¢.:;,6 · i J t q- 7 · W F: C 7 · '4 666 · W 3125. 289~. '~ O Z~ o _ 9Gq/4 _ 2500. 2600. 2700. 2800. -2500. -2600. -2700. -2800. -2~on. llq. 128. 137. 1~5. 1~. 724. 780. 836 · p c 5 _ ,,,' · 955 · I '"~ WELL NO. C-,'+ SEC12 Tl lN R. IOE ·'l;.. __K_U_?....._A~E.U._._K .... ~.~_ E L a . .......... : ................. i N ORTH SLOPE, ALASKA BOSS SUR t,!E L ' . ........................................... TRIJE MEASURED VERTICAL SUB SEA DEPTH DEPTH TVD SPERRY-SUN,,, INTERPOLATED RECORD gATE OF SURVEY Fl, ,,SI' FEBF, U4RY 6, P'CSS-16745 I NC. 0 F S UR VE TPUE ELEV41ION r,'ECT ANGULA NOR Tti/SCUT TOT/~L R CCOR H DINSTES ST/WEST 6871. 6194o 6].00. 6972. 6294. 6200 7072. 6.;94 · 6300 7172o 6q-94. 6400, -6000. -6100. -6200. -5300' -6400. 215. 21], 205, 201, 196, 2q71,~ 2/476. 2480, W 2q~,';4. 'w 7272. 6~.,~. 6500. 7373. 6694, 6,600. 7~+73, 6794, 6700, '7573 · 6~94 , 6 ~., 00. 7575. 6896. 68 O 2. INTERPOLATED COORDINATES FOR EVERY FROM`' '0.00 FEET TO -6500. -6600. -6700. -6CO0, .... -6~02. . 100,00 FEET OF SU~-SEA DEPTH 6802.16 F~ET ...................... . 191. 186, 181. 177. 177. 2~97. W 2'137. ' WELL NO. C-4 F, ECI2 T:~.i.N F,:]OL , NORTH SLOPE, t~LASK/~ BOSS SURWEL I NT£.Rf)OLA. TED MEASURED VERTICSL SUB SEa DEl-'" TH DE P TN T VP SPERRY-SUN,, INC. V~.LUES FOR SPECIAL SU TRUE REC TANGLtLA .... /S ELEVATIOn,. NORTH OUT -628,. 20i. -63.1~. 200. -6.~6. 19q. -6570. 187. -66~7, !PA. ;74.56. . 6777. 6683. 6 673. 183. 683, 182, 802, 177, ~ATE OF SURVE'Y RVEY POINTS TOTAL P C30RDINATES H FAgT/WFST S 2~8'0' ~ TOP ? 2~81, W TOP S 2~86, W BASf cZ 2690, W TOP S 2~93. W S 2~9~. W S 2~97, W F E .l::.~R U A R Y h,'~ Sc- 167z,~ KUDARL.IK UPPER SAND UPPER SAND LOWER SAND LOWER SANF BAS'- KUPARUK PLUSDACK TD TOT AlL DFPTH TRUE NORTH 1515 SNL Well No. -C-4 ....................................................... HORIZONTAL PROJECTION .......... ' ....... ~.'J..~_'.J.~"~..'J'~'~_..'_.~'.'~ .... ~../.~.'.~ '~" ~_ Scale' 1'.'=500' '- Surface Location (1515SNL 1066EWL) MD= 7575' ..... TVD= 6896' ~ -- Check Form for timely compliance with our regulations. ~3perator, ,. and Number Reports and Materials to be received by: Completion Report Wel 1 History Samples Mud Log Core Chips Core Description Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports Logs Run Digitized Log Data Required Yes Yes Date Received Remarks Yes NORTH SLOPE ENG~ From: J. J. Pawelek / Leo Lash Transmitted herewith are the following: Please note: BL - Blueline, S - Sepia, F - Film, T - Tape CONFER: FILF: . ARCO Alaska, Inc. Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 RECEIVED 01! & Gas Cons. Commission Anchorage NORTH SLOPE ENG~ From: J. J. Pawelek / Leo Lash Transmitted herewith are the follOwing: Please note: BL - Blueline, S - Sepia, F - Film, T - Tape ,. PIgASE RMilMN ~IPT TO: ARCO Alaska, Inc. Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 Transmitted .herewith are the following: ~..._co~, I-I co~, 'From: J. J. Pawelek / Leo Lash ' ~-OE~ · , note: - , ~-'o=~a, F- Film, T .... Tape ARCO Alaska, Inc. Attn. Leo .Lash / AFA-311 P. 0. Box 360 Anchor~e, AK 99510 RECEIVED DA~: MAR 1 ? 1981 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. ~ Post Office Bt.**.360 Anchorage, Alaska 99510 Telephone 907 277 5637 hand delivered SAMPLE TRANSMITTAL SHIPPED TO: State of Alaska DATE: Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Ak. 99501 Attn: Mr. Wm. VanAllen J ~r 2 EN_G J I_sTA.?-TE~:-- ~_T TEC-- OPERATOR: ARCO SAMPLE TYPE: core chips NAME- ~t,_p_~ruk C-4 /' NUMBER OF BOXES: eight '; ~/ · SAMPLES SENT: 7042 - 7100 7100 - 7158 716i - 7218 7219 - 7277 7278 - 7335 7336 - 7395 7398 - 7457 7457 - 7485 SHIPPED BY: Pnlon ON RECEIPT OF THESE SAMPLES, ,PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ARCO ALASKA, INC. P.0. BOX 360 ANHCHORAGE, ALASKA 99510 ATTN-: R. L. BROOKS DATE: ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany NORTH SLOPEENGINEFR21qG From: J. J. Pawelek / Leo Lash Transmitted herewith are the following: · co E~' G ~ 9(31 I_STA __~ STA' -- CONFER: F.ILF: -- Please note: BL - Blueline, S - Sepia, F - Film, T - Tape ,4(., 8 k/V~)L 14' C~ Y¥~ o.. ,o I~. RETURN RECEIPT TO: ARCO Alaska, Inc. Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 ~- ~ ro ~: 7 ..~ 9 ~1 Alaska Oil & Gas Cons. Commission An~hora~;,, NORTH SLOPE ENGINFTRRING Transmitted herewith are the following: ,. . "I\ 4. ENG From: J. J. Pawelek / Leo Lash i~7~--i OEOi FILF~ Please note: BL- Blueline, S - Sepia, F - Film, T - Tape ARCO Alaska, Inc. Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 NORTH SLOPEENGINMFRING Transmitted herewith are the following- Please note: BL - Blueline, S - Sepia, From: J. J. Pawelek / Leo Lash F - Film, T - Tape iC GEO _/ 3 .c,~0' I ST^TT t STATT ~ FIL,F: ....................... RETURN RECEIPT TO: ARCO Alaska, Inc. Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 FEB 2 5 1981 DA~: .__ rm & Gas Gon9. Alas~ ~" ~chorag~ NORTH SLOPE ENG~ From: J. J. paWelek/ ~ Lash Transmitted herewith are the following: Please note: BL - Blueline, S - Sepia, F - Film, T - Tape /v--- RETURN RECEIFr TO: ARCO Alaska, Inc. Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 FEB ? '~ xuo~ Naska Oit & Gas Cons'. Commission Anchorage NORTH SLOPE ENGINRFRING From: J. J. Pawelek / Leo Lash Transmitted herewith are the following: Please note: BL- Blueline, S- Sepia, F - Film, T - Tape .'-.- 5'" FL)c. 5'" 61J. L~ ~ ,,~" flf- s YASE ~ RECEIPT TO: ARCO Alaska, Inc. Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 RECEIVED FEB 1 8 1981 · . Alaska 0ii & ~?~ Co.s. COrni~i~81o~ ~c.orage i ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilto~ Chairman COmmissioner ~~,, Ben LeNorman Petroleum Inspector Thru: Lonnie C. January 13, 1981 B.O.P.E. Tests on KU PARUK C-4, Sec. 12, TllN, R10E, UM Kuparuk River Undefined _MondaY January__5~ !98_!: I departed my home at 7:40 am for an 8:20 showup and scheduled 9:20 am departure via Wien ftight~..#1 for Deadhorse. However, the flight, which originated in Seattle, was delayed due to fog. We departed Anchorage at 2:20 pm and arrived in Deadhorse at 4:00 pm. Weather: -4CF, low overcast, light wind. Tuesdg¥ January 6, 1981: BOPE t.~ests on Arco's DS 14-9A were completed during the morning, .the subject of a separate report. BOPE tests on KUPARUK C-4 began at 4:00 pm and were_.,i.comp~'leted at 7:30 pm. BOPE Inspection report is attached. Wednes.d..ay January 7, 1981: BOPE tests on Arco's DS 13-12 began at 11:45 pm . . . Thursday January 8,~_!_78_~1: . . . and were completed at 3:00 am, the subject of a separate report. .F.r...i~day~ January 9, 1981: I departed Deadhorse via the ARCO charter at 1:00 pm arriving in Anchorage at 2:45 pm and at my home at 3:15 pm. Monday January 12, 1981: Ken Jones, Drilling Foreman, called to advise the kelly cock was replaced and tested to 5000 psig. In summary, I witnessed successful BOPE tests on ARCO'S KUPARUK C-4. Note: Considerable ~oiling of water in the cellar was noted ~.~ escaping methane ~as around the~ 20" C°nd~ctor pipe, This was particularly pre,lent ~'in the area Opposite the'V'Door. In my opinion this prese~t~ n° prOblem as 10ng. as the heater .blowers are operating to dxssxpate the gas. O~G #4 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator ~-~ ¢.~ Representative Well ~ ~9~ &; ~: ~ V Pe rmi t # ~) · Location: Sec /~. TI/A/R/O~M ~,F~ /~C~asing Set @~.~)~ ft. Drilling Contractor F~O~~ Rig # --~.~ Representativ~(~---~/ ~/~'~ Location, General Well Sign General Housekeeping Reserve pit Rig BOPE Stack Test Pressure Annular Preventer Pipe Rams _ Blind Rams Choke Line Valves ACCUMULATOR SYSTEM Full Charge Pressure ~,.~O psig Pressure After Closure /~O psig 200 psig Above Precharge Attained: Full Charge Pressure Attained: N2 ~O~--~) m ~~ ~ Controls: Master ~) ~ Remote O/~ Blinds switch cover~/~ Kelly and Floor Safety ValVes H.C.R. Valve Kill Line Valves Check Valve Upper Kelly Lower Kelly Ball Type Inside BOP Test Pressure Test Pressure ~/z~ Test Pressure ~)/~ Test Pressure Choke Manifold No. Valves ,/~'- No. flanges Adjustable Chokes / Test Pressure Hydrauical!y ope[ated choke Test Results: Failures ~ Test T~me ~.~9. hrs. Repair or Replacement of failed equipment to be made within ~ days and Inspector/Commission office notified. Distribution. ~~ ~-/~,~, orig. - AO&GCC cc - Operator r~~ cc - Supervisor Inspecto min~) se~ min 'se~ December 26, 19.80 Mr. P. A. VanDusen District Drilling Engineer ARCO Oii and Gas Company P. O. l~ox 360 Anchorage, Alaska 99510 Re= Kuparuk. 25649 C-4 Atlantic Richfield Company Permit No. 80-155 Sur. Loc.= 1'515~FNI~ 1066~FWL, Sec 12, TllN, RIOE, OM. Bottomhole Loc.= 1320~FNL, 1320~FEL, Sec 11, TllN, R10E, OM. Dear Mr. Va~J)usen~ Enclosed is the approved application for permit t° drill the above referenced well. Well samples and a mud log are required. A directional survey is r~uired. If available, .a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys.. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and ~he regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator~s office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. P. A. VanDusen Kuparuk 25649 -2- December.26, 1980 commencing operations you maybe contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department. of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded, we would .also like robe notified so that a repre- sentative of the commission may. be present to witness %eeting of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so ~hat we may have a witness present. Very truly yours, He H. Hamilton Chairman of BY ORDER OF THE COMMISSi0'~' Alaska 0il & Gas Conservation Commission Enclosure cc: Department of .Fish & Game, Habitat Section w/o encl. Department of Envirom~ental Conservation w/o/enO1. Department of Labor~ Supervisor, Labor Law Compliance Division w/o encl. HHH:be ARCO Oil and Gas C ~any North Slope D /ct Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Kuparuk C-4 Dear Sir: Enclosed please find: l) 2) 3) ~) 5) 6) Very truly yours, The Application for Permit to Drill Kuparuk C-4. A $100.00 check for the application fue. Diagrams of the BOP stack & surface diverter system. The as-built drawing. The well-bore proximity map. The horizontal projection drawing. P. A. VanDusen District Drilling Engineer PAV/KJG:sp Enclosures RECEIVED Alaska Oil & G~o Cons, Commission Anchorage ARCO Oil and Gas Company is a Division ol AtlantlcRichfieldCompany Form 10-401 [lEV. 9'1-78 SUBMIT IN TRI' E (Other instruch STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL OR DEEPEN reverse side) la. TYPE OF WORK DRILL r~ b. TYPE OF WELL OIL ~ GAS WELL WELL ~] DEEPEN [] SINGLEf~l MULTIPLE OTHER ZONE I I ZONE I I 2. NAME OF OPERATOR Atlantic Richfield Compan7 3. ADDRESS OF OPERATOR P.0 Box 360, Anchorage Alaska 99510 · ' 4. LOCATION OF WELL At surface 1515'FNL, 1066'FWL, Sec 12, TllN, R10E, At proposed prod. zone 1320'FNL, 1320'FEL, Sec 11, TllN, R10E, 13. DISTANCE IN MILES AND DI~ION FROM NEAREST TO~ OR ~ST OFFICE* 30 miles NW of Deadhorse, Alaska aPI #50-029-20547 6. LEASE DESIGNATION AND SERIAL NO. ADL 25649 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Kuparuk 25649 9. WELL NO. C-4 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay/Kuparuk River Oil 11. SEC., T., R., M., (BOTTOM Pool :ior~ HOLE OBJECTIVE) Sec ll, TllN, RIOE, UM 12. 14. BOND INFORMATION : Oil and Gas Bond T~EStatewide S~etyand/orNo. 8011-38-40 (Federal Insurance Co.) 16. ACRES IN LEASE 15. LOCATION TO NEAREST 3765 (surface) No. OF DISTANCE FROM PROPOSED * ! PROPERTY OR LEASE LINE, FT. 1320' t-rod zon (Also to nearest drig, unit, if any) %~ . e 2 5 6 0 l~. DISTA~C" FROM PROPOSED LOCATION '~.PROPOSED DE~H TO NEAREST WELL DRILLING, COMPLETED, / OR APPLIED FOR, FT. 120' (surface) 3733' (prod. zone) 6849' TVD 21. ELEVATIONS (Show whether DF, RT, CR, etc.) +55 GL, +60 Pad, +94' RKB Amount $500,000 17. NO,ACRES ASSIGNED TO THIS WELL 320 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START 12/30/80 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEffrH Quantity of cement 32" 20 94 H-40 80 Cmt to surf - appr0x 200 ft3 17~" 13-3/8 72 N-80 2893 Cmt to SUrf- approx 36~0 ft3 12~" 9-5/8 47 L-80 . 6948 Cmt with aDDrOX 1000 fto Drimarv 8~'; 7 26 K-55 6648 to 7373 233 ft~ se~bndary-Arctic Pack f~{ 2300 + MD to surface Atlantic Richfield Company proposes to drill a Prudhoe Bay Kuparuk River Oil Pool devel- opment well to approximately +7473'MD, +6~49'TVD. Selected intervals in the upper Cretaceous sands at 3600'MD (73294'TVD)-will be cored. Selected intervals in the West Sak Sands at +4087'MD (+3694'~VD) will be cored. The Kuparuk formation will be cored. Selected inte-~vals will-be 1.o.gged and tested· A 20" x 2000 psi annular diverter will be installed on the 20" conductor while drilling the surface hole· A 13-5/8" 5000 psi RSRRA BOPE stack will be installed on the surface pipe· It will be tested upon instal- lation and weekly thereafter. Test pressure will be 3000 psig. The well will be com- pleted with 3½" 9.2# J-55 buttress tubing. Non-freezing fluids will be left on uncemented annuli thru the permafrost interval· Selected intervals will be perforated within the IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed ( k ) new productive zone. If proposal is ,o drill or deepen di~ectionally, give pertinent data on subsurface locations and measured and true CO n ' t. on bBc vertical depths. Give blowout preventer program. 24. I hereby certiflMhat the Fj[regoing~lFrue and Correct roLE Dist. Drilling Eng. ~ space for State office use) SAMPLES AND CORE CHIPS REQUIRED [] NO DIRECrIONAL SURVEY REQUIRED [] No PERMrr NO. APPROVED BY CONDITIONS OF APPROVAL, IF ANY: [] NO OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE /) <~/ APPROVAL DATE ~ " *See Instruction On Reverse Side · December 26, 1980 DATE 12/26/80 Kuparuk formation and reported on subsequent report. A dow,mole safety valve will be installed and tested upon conclusion of job. INSTRUCTIONS General: A filing fee of $100.00 must accompany application for permit to drill or deepen. Checks shall be made out to State of Alaska Department of Revenue. This form is designed for submitting proposals to perform certain well operations, as indicated, on all types of lands and leases for appropriate action by the State agency, pursuant to applicable State laws and regulations. Any necessary special instructions concerning the use of this form either are shown below or may be obtained from the Alaska Oil and Gas, Conservation Commission. ITEM 1: Use this form, with appropriate nOtations, if the proposal is to redrill to the same reservoir at a different subsurface location or redrill to a new reserVoir. ITEM 13: Attach hereto a neat, accurate plat or map, drawn to scale, showing the site or proposed site for this location, distances from section, distances from section line, lease line, if any, and other information that is pertinent. Refer to Section 11AAC 22.005 of Oil and Gas Regulations. · ITEM 14: Enclose drilling bond on Form 10-402 with this application for permit to drill, or deepen, unless covered by other suitable bond. ITEM 15 and 18: If well is to be, or had been directionally drilled, use subsurface location of hole in any present or objective productive zone. !)~NNUL~R ' 1 PREV9ENTOR~ BL I ND RRHS - 8 -- , ) . ( ) . . PIPE RRHS ? ( ) RILLING SPOOL PIPE RRHS 5 6. Anchorags 8. TBG HD ~ CSG ~ Maximum Bottom Hole Pressure - 3258 psig Haximum Surface Pressure - 2861 psig 1. 16" Bradenhead 2. 16" 2000 PSI x 10" 3000 PSI casing head 3. 10" 3000 PSI tubing head 4. lO" 3000 PSI x 13-5/8" 5000 PSI adapter spool 5. 13-5/8" 5000 PSI pipe rams 6. 13-5/8" 5000 PSI drilling spool .w/choke and kill lines 7. 13-5/8" 5000 PSI pipe rams 8. 13-5/8" 5000 PSI blind rams 9. 13-5/8" 5000 PSI annular ACCU~IULATOR CAPACITY TEST · ;. l. CHECK AND FILL ACCUHULATOR RESERVOIR TO PROPER LEVEL WIT~ HYDRAULIC FLUID. 2. ASSURE THAT ACCUHULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSE~'~' TIME THEN CLOSE ALL UNITS SII.~LTA:;E= OUSLY AND RECORD THE TIME AND PRESSURE RE;qAIN- ING AFTER ALL UNITS ARE CLOSED WITH CHARGii~G PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECO~DS CLOSING TIHE A~D 1200 PSI RENAINI~G PRESSURE. - 13-5/8" BOP STACK TEST l. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY TRACTED. PREDETERHINE DEPTH THAT TEST PLUG WILL SEAT A~;D SEAT IN WELLHEAD. RUN I~t LOCK DOWN SCREWS IN HEAD. CLOSE At;NULAR PREVENTER AND CHOKES AND BYPASS VALVES ON NANIFOLD. TEST ALL COMPONE¢~TS TO 250 PSI AND HOLD FOR l0 MINUTES. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR lO MItlUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVE~&TER AND CLOSE TOP SET OF PIPE R2¢4S. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR lO HINUTES. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOW~iSTREN.I PRESSURE TO ZERO PSI TO TEST VALVES. TEST RDiIAINING UNTESTED HANIFOLD VALVES, IF ANY, ~ITH 3000 PSI UPST~EA'.I OF VALVE AND ZERO PSI DOW~ISTREAM. BLEED SYSTE:.I TO ZERO PSI. 9. OPEN TOP SET OF PIPE RANS AND CLOSE BOTTC-I SET OF PIPE RA,qS. lO. INCREASE PRESSURE TO 3000 PSI AND HOLD FO,~ l0 MIl;UTES. BLEED TO ZERO PSI. ll. OPEi; BOTTC,~.I SET OF PIPE R&HS. BACK OFF ?.U:I- NI¢;G JOI;IT A;ID PULL OUT OF HOLE. CLOSE :.LI~;D RNIS A~ID TEST TO 3000 PSI FOR l0 HI~;UTES. BLEED TO ZERO PSI. 12. OPE:I BLI:;D R~.IS A;;D RECOVER TEST PLUG. ,";AXE SURE HA;~IFGLD A;;D LI;;ES ARE FULL OF ARCTIC DIESEL A:;D ALL VALVES ARE SET I;i CRILLI:,.S POS I T! 13. TEST ST;,;;DPIPE VALVES TO 3000 PSI. ]4. TEST KELLY COCKS A:;D I;;SIDE 8CP TO 3SCO PSI WITH. "~r':EY :.~, PL;'!P. 15. RECCRD TEST I:;FC.-'J"ATIO'~ 0:( BLC;~OUT P~E'~"_-.',TER TEST FG;~'I SiG'~ A~,D SE~,D TO DRILL;:,S VISCR. 16. PE~FC.:~I CC~PLETE :~CPE TEST O.',CE A '~EE~ ;,.',D F~,",CTIC:;ALLY OPE?~TE -COPE CAILY. Surface Div6~ ~er System 1. 16" Bradenhead. 2. 16" x '20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell nipple. -'Maintenance & Operation ~ . 1. Upon initial installation close annular I preventer and verify that bal 1 valves ! have opened properly. '- i 2. Close annular preventer and blow air ~_ ~ through diverter lines every 12 hours. t 3. Close annular preventer in the event that gas or flUid flow to surface is detected. If necessary, manually over- ride and close ball valve to upwind diverter line...Do not shut in'well under an~, circum~ances_ 16" Conductor i x ~. ~- _~ ~'~ ~ ~- ~ '/~'-~' ~~,L~ ' ~' . "' '" · -' ~ · "?" · .> // . ... ~~~-- ~ l[ ' ' ' ~" ~ "'"~7': ' X = · 562,372.05 · · ~--'"~c,~%'~: " ":. LAT = 70°19~28.285'' ~:' ~'~"~ ,.":m" ' X =. ~2,271~78 .... -':' ' ~.%". ' - ."~:'-~' .... . ~u"~ = '~ =~ 7~~. '". . ' . 't .. .' '.- ~.~~ ~ELL'.E~ Y = 5,968,655'~2 i HEREBY CERTIFY THAT ! A~ ' X = 562,172,58 PROPERLY REGISTERED AND LICENS'ED LONG = 1~9°29~q~.08~'' THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS- WELL ~ Y = ~,~68,722.O] BUILT SURVEY HADE BY HE, AND X = 5~2,O72,98 THAT ALL OlHENSlO~S ANO OTHER LAT = 70°19~30,27]'' DETAILS ARE CORRECT, AS WELL Y x = F6i 37~ n0 X = F6],772.8~9 LONG= 149029'50 878" LONG = 149o29~56.6~o'' ~ELL ~6 Y = F,968,855.o9 ~ELL ~8 Y = 5,9~8,987.86 ~':~ X = 561,87~:6~"- X = 561,672.26 LAT = 70°19- 31.598" LAT = 70°19~32.920'' LONG 149°2q~53.'°1'' = ~ ,~ LONG = 149o29~59.608'' i i i i i I I i i i ....... ~-~.~ NORTH AMERICAN PRODUCING DIVISION .;':7'7' - ...... ii - ~ i_1 i i iii ii · '- - .: :.': ..:- ... ...... ,. 'j PAD C:.,; kiEl2[: :NO: : PROPOSED · . . j' i TRRGET :-! i ; TVD,.63'I4 4-.~ TMD.7025 i DEP..E394 1,443 DEP.1675:- OEP. I'tl I 'TVD.6174;THD=682S DEP-2B94 :[TOg KUP SANDS) ~TVD=6374 ..Li...~].~.i._!.~.L~L..:...i..! i!..i.., TOP LONER ,~d:IND~TYD=6$44 TMDL7295 OEP.2394 FO:TVDr6849 I000 N 85 DEG 20 MIN N ] .... E394 FT' (TO TARGET) : .-TT':' ~ .~ l . , I ~ zz 0 rrl 'm ,, CHECK LIST FOR NEW WELL PERMITS Item Approve (1) Fee (2) / (3.) Oompany Date Yes ~-~.-%,~-o 1. Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................ . / 3. Is a registered survey plat attached ................................ I'.. %~.-~ .4 Is well located proper distance frcm property line .................. 5 Is well located ~roper distance frcm other wells .. 6. Is sufficient undedicated acreage available in this pool ............ 7. Is well to be deviated .............................................. / 8. Is operator the only affected party ................................ ./~ 9. Can permit be approved before ten-day wait .......................... / No ~ %/-~-~..-,~0 10. Does operator have a bond in force .................................. 11. Is a conservation order needed ...................................... 12. Is administrative approval needed ................................... .. ~ .... / 13. Is conductor string provided ........................................ ~ . 14. Is enough cement used to circulate on conductor and surface ........ ~ 15. Will cement tie in surface and intermediate or production strings 6. Will cmt cover ali knom prcrtuctive horizons ..................... 17. Wil 1 surface casing protect fresh water zones ...................... ~~ 18. Will all casing give adequate safety in collapse, tension and burst. (5) BOPE ~ ~ .,~/~9 (9919. Does BOPE have sufficient pressure rating - Test to ~ ~ · ~ psig . .d~ __ ~Approval Reccmmended: Additional Requirements: Lease & Well No. /-"-~l~,,-~-_,.,..-~-~/~. Z5%~¢ Remarks Geology: Engineering: HWK LCS BEW ~~ re,r: 03/05/80 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. I *****~**** EOF UNIT TYPE CATE 000 onn ooo 006 o00 000 oo0 ooo 000 000 000 000 0o0 000 606 600 000 000 016 011 007 003 003 002 011 OO6 010 065 065 065 065 065 065 065 065 **************************************************************************************** ************************************************************************************* BOROUGH ******************************************************************************* ****************************** C T F I C,~T IFi~ ~:~r~ ~B[~Vi~C~ .... i)~-~' 'A.P! fi;PI ~PI S!ZE PROCESS SAMPLE PT ¢ 0 o 0 0 0 4 * 0 O fq ~ ,4 7 0 0 0 0 4 0 l 0 ~a~I 7 {~8/~~ 60 ~i2 32 0 0 :~ 0 .AOl 60 31 32 c> n ~ 0 /C 3 42 a 4 n 0 1 I 4 2 ? 8 3 n ~ 4 0 1 42 ~ f 0 0 4 0 1 S.~ ..- I 4 ,,. '~ t 32 C 0 ~ 0 1 PPa 0 ~'~ 0 O~ -0 ~ 0 p p a o 0 0 0 0 4 0 p~" o o 6 6 0 4 o (¢ A.- t 0 e) 0 0 4 O CODE 6R 68 6~ 68 68 6~ 68 6[4 SP N'DNT ~RAT 7550. .,,oao. 250o -999,. ~sn0 (~ 1. 9482 74 0000 11,6953 POT !% 3 . ~ 5 5 !. gG~ D E P T 74:00 NP~I 32 POTA ~, OEPT SP POTh DEPT SP NPHI NPAT DEPT N P!-'! ] NRAT POTA D~PT SP N p U I D EPT NpHI D E P T F !., L~ -qq9,220o Di~q~') n 0462 ~O ! 63, g 375 t07~06~5 1.~,474,1 .... ~LI Su' ,,I -9oo oSnn T~.p ~,3340 ~1.~ Z3OO.nOOa , ,.[ ........... . ................. ,. ~g~.~506 ~ ~ 52,92!9 PT 96;6094 '~ 36.6694 DPH{:i ~,033'1 P ~{:~[~ 2,4626 CALI 1..~677 8GP 62. !.562 ~200 '~gq 1 30 0 /000 999 ? 6900 ,O000 SFt~il -Oc*q, 2500 ILD 3,4R6LI I l...!~ 1~0!, DRH['! 0,0372 RH~[:~ ~,1659 C.~[..,I . .. 42= SC;g~ a2. 593R 0000 Sb'[.,~ -999 2.., ......... 12 5469 5547 D~ 103 ~4688 .360! PR}'J f'~ O, 057f~R } l~ O[ ~ 2,53~2 CALl .7.4~i Ga .... a0.9~38 THOP 6i9~4~ 976& 8G~ 30,664! ~ . .0375 C~ 1_23;3!5945 DT 1.436 npHri -0 2407 P ~.-~ O P. ,!719 SGP 43.1094 6700 -O9O.- -09g · r~ o o 0 . ?500 .2500 .oso7 CAb1 19~,6547 uRAN .9141 !LO 21~,2S06. O~ -09~;2soo 3,61 S 2 I b D !.~9~3~21 PT 1,7549 It9;q375 ,g~72 CAI.,[ · 11~,7207 ILS -qqq,2500 ChLI l 6621 93;250© 8 3859 s: 7os 2,47R5 50.1797 8,3929 0.7513 3,4453 75,0156 8,428~ 1,5906 3,7305 70.6250 10,2e52 3,6973 5156 4 8 5207 0:2761 1,3q06 90.4844 19,!563 ;5i9e 1.7813 t20.6250 8,74~5 1,5764 2 2598 252:0000 -099.2500 -999.2500 2,3438 1i2,4375 -999,2500 -999,2500 POTA -q99. 2500 SGR DEPT 6600.0000 SFI,U SP -39.0000 ~R MPHI -q99.2500 DRI'9 POT~ -q99,2500 SG~ DEPT fi~0O 0000 SFI;U NPBI -999.2500 DG~U POTA -999.~500 DEPT 6400 00OO SFLU SP -34:K000 CR NPHI -999 25oo DRHO POTA -999.2500 SGR DEPT 6~00 0000 SFLU NPHI -999.2500 DRHO NP~T -99~.~5on G~ POTA -099.2500 SGR DEPT 6200.0000 SVLU ~P -I~.7813 GR NPHI -999.2500 DR~O MRAT -~q.~500 GR POTA -q99.2500 SGR DEPT 6100 0000 SFLU NPHI -999 2500 DRHfl NRAT -ogg:~50o ~R POTA -999.2500 SG~ DEPT 6~00 0000 SFI,O NPMI -999 2500 DRHO NR~T -999~2500 ~R POTA -999.2500 SGR DEPT 5900 0000 SFLU SP -1.9!7500 ~ NPH'[ -999 ~500 DRHO NR~T -ggg ~500 GR POT~ -999,2500 SGR -999.2500 -999.2500 ~HO~ -99.9,2500 CALI -999,2500 -~9q'~500 T~'O~ /~:~g-99'~0~6~: A~ < ~--~ ' -: -~99 2500 2 6719 ILD 1.8057 {!,~. 1.9023 -999.2500 RH05 '999'250.0 CA~I -999~2500 99. ~500 ~/0.~' ~'999:;':'~:50:0 [~:~-;: ::: '?~9 :~: ::.~--'- -999.2500 -999.2500 3.5664 I LD 2,.232.4 I h~ 2..7949 I 32. 8750 ' : -': ~:~; : -}~:!::~,:~;:~ C~- ./.: : ~,~:: ::-t' 6J::'''~:':: :::'":': :; : : -~9~.2500 ~HOB -q99..2500 CALI -999.~50~ -~. ~00 ~HO~: : :? :':~99:~5:0.0:~ [:IRA:~ :'~99:.~;~::~ ::'~:~: ':: ::" :: : : -99~.2500 9160 ~ hD 2.. 5117 ! b~ ..... 2, 66~41 3,96~7 DT ,: ': '~: ~:1-0'8.;~.: _~ :~_:: :-1'5::~6 :/:;~' ': :: -' -~99.~500 ~HOB -999.2500 Cab! ~9.99.. 2500 -999.2500 ~?;. : : ::...<::::: ..:,.. :. ::/:,::.::~:~' : : . 3,0820 ISD 2,3828 IL~ 2,412~ 153 ' 4375 DT: ::~ GR" 'i:~: :-:- '. 999.2500 ~0:~ :999..2500 CA[,I - --999-25.00 -~99.2500 ;9219 :~.~.T- :'~:~- -~l:,~':~ :~;I:'8,~ ,::: ,":?'~:?: ~.: .-: - · -999,2500 RMO8 . -999,2500 CALl -999,2500 . 9992~500 T~:6~ ' :::::.::. ~::', ~:~ ':'::':~> ~:.::': :~ ~ -999,2500 ~ - ~::::: ~ .::/. ::~./>:::' .:: :..:.:<. :::::::::::::::::::::::::::::::::::::::::::: : ~ . 1. 7549 ILD 1,57.7.1 !LM ~,5947 ~]5;75o0 o~. ~:'6:74_9.:: 6~: :: --. <..:..-I35 :+ : -999,2500 RHOB ~-999,2500 CASI ~999,2500 -999.2500 ~.2754 I[,~ 2.0313 !L~ . 2,089~ 93.37-56: D~:;': ~-:. i ' ~.~_:~::;,'..?: ::~ :: ;: >;. -. 0~ _,:. ~ ::-: :: - -999. ~500 PHOB--.999,2500 [~ALI--:999.2500 -999.9500 T~OR. ~'~:~ ,,,,, 9~ t '~. ~'99 OO - : POTA DEPT ~P OEPT ~P NPHI POTA D[PT ~P NPH! POTA OEPT SP NPHI NRAT POTA DEPT SP NPHI NRAT POTA DEPT ~P NPHI POTA NPHI SP NPHI NRAT POTA SP N pHI NRAT -0,99. 2500 SGR 5700,n0o9 SFL[t -20.75o0 ~R -999.2500 DRHO -999.7500 SCR 5600 nO00 SFLU -q99.2500 DRHO -q9O.~5no ~R -999.25e0 SGP 5~0~ ~000 SFLU 26~71~8 ~R -999.75e0 ORHO -099.2500 SGR 57.00. 0000 SF~,U -34.2187 GR 999 ?..500 DRHO 5100.0000 SFLU -36.21B7 GR -099.2500 DRHO -099.~5no ~R -q99.2500 S(;R 5000.OHO0 SFI, U -34.2187 GR -999 25n0 DRMO -999:250¢) GR -099.2500 SGR 4900 0000 SFLU -35~7188 GR ggq ~500 DRNO - - >' :-; i';-;/ -999.2500 2 2168 500 RHO: -999,2500 CAGI .999,2500 , -q'gO. 2500 8~.43~6,,. -999,2500 g~,9~'~4~, ILD 2.8398 .I[~ ~,~ 2999 2500 P:~O~ -999.2500 CALl -999~2500 -999,2500 2 632~ ILD 2,4863 IL~ 2,5215 -999.2500 RHOB -999,2500 CALI -999,2500 . -999.2500 : 2.9785 I~.D 3. 0371. !L.~ 3.0293 86' 99~9 ' ~999. 2500 RHO[ -999.~500 CAb! . 999.2500 4,6523 ILD 4,8906 IL~ 4,738~ 3; 606.: :: ::::::::::8::::;::::: -999.2500 R~]O~- 999~500 CAL! 999,2500 -9~9.2500 : 1562 98:8437 DT : : -:: ::~:~'~ :.: GR':_T ::: ':: ::9:8 ,:::-::-:::::~:- :999, ~500 ~HOB -999,2500 CALl -999,2500 999,2500 T~OR: ~- '~? :"9' ~ [jR :." ::: .~:~999:~ 0 0664 !LD 3,6465 IL?~ 3,5332 :~99 ~506 ~,0~ .999.2500 CA.:~!. -999,2500 -999. 2500 ~3:0078 IbD 3.5684 Ib~ 3.5254 -99~; 2500 THOR - ~: -5 99 5 UR'~:N-' .'999 O0 bVP POTA DEPT NPHI POTA NPHI NRAT DKPT NDHI NRAT POTA DEPT SP NPH] DEPT NPH] NRAT POTA DKPT NPH] NRAt POTA -099.2500 SGR 4800,0000 SFLU -3~.91R7 GR -999.2500 ORHU -q99.2500 ~R -999.25n0 SGR 4:00.0000 SFL;~ 3~.21~7 CR -999.2500 DRHO -0~9.~500 CR -999.2500 SGR 4600.0000 SFLU -34.7189 GR -999.2500 DRHO -o90.2500 GR 1.6113 SGR 4500.0000 SFLU -35.21R7 CR :999.~500 DRHO ~9~.25no ~R 1.5015 SGR 4400.0000 SFLU -999.2500 I)RHO 1.5~59 SGR 4300.0000 -46.718~ GR 99:2500 ~..~648 DEPT 4~00 0000 SFLU SP -40:7188 CR NPH] -099.2500 DR[lC POTA 1.4160 SGR DEPT NPMI NRAT POTA DEPT SP NPHI NRIT 4000.O000 SFLU -22.7813 GR -qgq.~500 DRHO -q99.2500 ~R -999.2500 - ':~i. - ..:"_ i::-: ':. 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