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214-202
Image Project Well History File Cover Page 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. Q1 4 - ,Q 0 a Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: Color Items: E Maps: Grayscale Items: Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: CD Date: al/3 !s /s/ P Project Proofing • BY: Maria Date: 1 3 1J /s/ oft Scanning Preparation x 30 = 1i2 b + = TOTAL PAGES 10 (Count does not include cover sheet) (VI BY: CMariP Date: a 3/1/.5- /s/ Production Scanning Stage 1 Page Count from Scanned File: t9 I (Count does include cove sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: 42, Date: D.113 I 1 S /s/ 6/1,P Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. 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Q c a z E o G E co z m 3 ,-- N O p N O I- N er a- N G• CO w rn U « O E N p a 2 RECEIVED STATE OF ALASKA FEB 4 4 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND &OGCC la.Well Status: Oil ❑• Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development Q • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: • January 14,2015 214-202/ ' 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 •January 6,2015 50-029-20751-60. 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 564'FSL,813'FEL,Sec. 16,T11N,R10E, UM •January 11,2015 KRU 1E-14L1 - Top of Productive Horizon: 8. KB(ft above MSL): 106'RKB 15.Field/Pool(s): 1128'FSL, 2706'FEL,Sec. 16,T11N, R10E,UM GL(ft above MSL): 67'AMSL Kuparuk River Field ' Total Depth: 9.Plug Back Depth(MD+TVD): 1095'FNL, 2103'FEL,Sec.21,T11N, R10E, UM • 6727'MD/6237'TVD Kuparuk River Oil Pool • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-549710 y- 5960150 Zone-4 •9646'MD/6211'TVD ADL 25651 • TPI: x-547813 y- 5960701 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-548436 y- 5958482 Zone-4 no SSSV 469 18.Directional Survey: Yes ❑ Non 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 3148'MD/3134'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res • 6676'MD/6190'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 65# H-40 34' 114' 34' 114' 24" 320 sx AS II 10.75" 45.5# K-55 33' 2333' 33' 2333' 13.5" 1100 sx AS III,250 sx AS II 7" 26# K-55 29' 7169' 29' 6676' 8.75" 775 sx Class G,41 bbls AS II 2.375" 4.6# L-80 6691' 9646' 6205' 6211' 3" slotted liner 24.Open to production or injection? Yes a No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 6767' 6370'MD/5890'TVD and slotted liner from 7197'-9646'MD 6231'-6211'TVD 6437'MD/5955'TVD,6767'MD/6265'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 1 COMPLETION ! Was hydraulic fracturing used during completion? Yes No 0 _II : DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED VIVID 1 none 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on facility hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q • Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407 Revised 10/2012 1/7...7„. Z`G //5"" CO IN D O EREIBD FEB - 4 2015Submit original only 29. GEOLOGIC MARKERS(List all formations and mai .ncountered) 30. FORMATION TESTS NAME MD TVD Well tested? Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results Attach separate sheets to this form,if Permafrost-Bottom 3148' 3134' needed,and submit detailed test information per 20 AAC 25.071 Kuparuk C4 6676' 6190' Top Kuparuk C3 6695' 6209' Top Kuparuk C2 6712' 6225' Top Kuparuk C1 6719' 6230' Top Kuparuk B4 6728' 6238' Top B4/Base C1 7155' 6242' Top C1 /Base C2 7175' 6236' Top C2/Base C3 7199' 6231' Top C3/Base C4 7729' 6211' N/A Formation at total depth' Kuparuk C4 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic,final directional survey 32 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact: EmailJason.Burke• conoco•hilli.s co /P / Printed Name D.Ve us Title CTD Engineering Supervisor Signature Phone 263-4372 Date 7 3-/5 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells. Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29. Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 06 1 in O tD i Z __ d rzi r U :e- CO C rt co a pp ( I - //�����- c_7 r .O O p V, E M N ,— as M - N N (U6 'a CO a1 N coMLL N � �'O ��,`` ��N CO I I c‘i ca C U V 3 06 N a cu 7 N f6 2 O M U co �y lf) I p '--(5 _ O coco as ��M11 O� co3MCaa` �m I _ Cfl N C E V CO Cfl ,_ t0 co N V V Co 3 T CO N Ill l Z �(0� ©© m I p @gy m 4 I—W (a a) co Y�0 0 I Q� p D N U,fl- U T as CV a N a `- W U Q0aE © a8 .a E \ rn •c = � co N �p�J�W J V C ,� a co-2 c aco Nm20m = O \\\ \ ai U co d o cn ° ui @� o�`O c a C0 m 0 CO Y Y Y E Y Y Y (6 p \ Y C O N N N N N f6 C6 C6 f6 N OL E 1 N N co 6) p V CU 61 CO MCO mmmOm mmcn d a� O'x CN to I as _ 7 U m -C3 U Wo E c 2 m I J coo v) E 0 YY Y Y _____A 0 f6 N f6 N 7 O m CO CO CO M M a Ic // Y iLl 0 D r — — — Fill ' C) III-1 WIT T W I p19 Co °� in 2 M co- u) O oN Co Y MLL N Nt pco M tp No.� co 0Y bo O N O-� "O -Co 4t co _ — 6 CNas N. 03CON � @ C? O N (a i CD Q i f"--Ca N c) c 0 c O iot N 1E-14L1 WELL WORK SUMMARY DATE SUMMARY PRE-RIG WELL WORK 12/23/2014 GAUGED TBG TO 2.74"; TAGGED @ 6751' SLM. DRIFTED TBG WITH 2-5/8"WHIPSTOCK DUMMY TO 6759' RKB. MIT-IA 2000 PSI, GOOD. READY FOR E-LINE. 12/29/2014 (AC EVAL): TREE VALVE TEST- MV PPT (PASSED), MV DDT (PASSED), SSV PPT (PASSED), SSV DDT (PASSED), SV PPT (PASSED), SV DDT (PASSED). ConocoPhillips Time Log & Summary We//view Web Reporting Report Well Name: 1E-14 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 1/3/2015 5:00:00 PM Rig Release: 1/14/2015 3:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/02/2015 24 hr Summary Complete R/D from 1H 18:00 23:30 5.50 0 0 MIRU MOVE MOB P Prep to move from 1H to 1E-14 23:30 00:00 0.50 0 MIRU MOVE MOB P Peak Trucks on location @ 1H 31/03/2015 MIRU, Start BOPE Test Witnessed by Lou Grimaldi,AOGCC 00:00 09:00 9.00 0 0 MIRU MOVE MOB P PJSM, Pull off 1H-04, M/Ujeeps, Move to 1E 09:00 14:00 5.00 0 0 MIRU MOVE MOB P Arrive on location, inspect wellhead, remove jeeps, spot modules over 1E-14, berm cellar, containment, R/U putz,steam, interconnect. 14:00 17:00 3.00 0 0 MIRU MOVE MOB P Rig move checklist, load pits. *"*"Note: Rig Accept 1700hrs 17:00 18:30 1.50 0 0 MIRU WHDBO RURD P N/U stack, change riser, intall TT hardline 18:30 19:15 0.75 0 0 MIRU WHDBO RURD P ****Check tree bolts 19:15 19:45 0.50 0 0 MIRU WHDBO RURD P Grease tree, stack, manifold valves. 19:45 20:30 0.75 0 0 MIRU WHDBO RURD P Fluid pack surface lines, perform Shell Test. 20:30 00:00 3.50 0 0 MIRU WHDBO BOPE P Start Full BOPE test.Test witnessed by Lou Grimaldi,AOGCC 01/04/2015 Complete BOPE test with valve replacement, Perform slack mgmt,Trip in hole to set whipstock 00:00 05:00 5.00 0 0 MIRU WHDBO BOPE P Continue full initial BOPE test Witnessed by Lou Grimaldi,AOGCC ****Note: 3 failed valves B4,B7,and B8 05:00 10:30 5.50 0 0 MIRU WHDBO RGRP T Swap out failed valves B4,B7, B8. ****Note: 5.5 hrs Nabors Downtime 10:30 11:00 0.50 0 0 MIRU WHDBO BOPE T Shell test, Retest failed BOP valves on the choke line HCR valves B8,B4 and Manual choke line Valve B7 ****Note: 0.5 hr Nabors Downtime 11:00 11:30 0.50 0 0 MIRU WHDBO PRTS P Pressure test tiger tank line to 1500psi. 11:30 14:30 3.00 0 0 MIRU WHDBO MPSP P PJSM, Load/RU BPV lubricator, P/T lubricator to 3000psi pull BPV,WHP 1000, RD and load out the FMC lubricator. Page 1 of 9 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 14:30 17:06 2.60 0 0 SLOT WELLPF CTOP P PJSM, remove CTC and BHI UQ, dress a-line, line up to break circulation, perform slackmangement, R/U hydraulic CT cutter,cut 56ft of coil to find wire. 17:06 18:06 1.00 0 0 SLOT WELLPF CTOP P PJSM install CTC, Pull test to 35K 18:06 19:18 1.20 0 0 SLOT WELLPF CTOP P Test E-line, Head up E-line to Upper guick connect and retest wire, PT connector to 4000PSI 19:18 20:48 1.50 0 0 SLOT WELLPF CTOP P Circulate coil volume forward @ 1.6 BPM, PT PDL's 20:48 21:30 0.70 0 0 SLOT WELLPF OWFF P Bleed off WHP and monitor for 30 min. Good no flow test 21:30 22:42 1.20 0 73 PROD1 RPEQP1 PULD P PJSM, P/U BHA#1 with 3 1/3 Gen 2 whipstock on hydraulic setting tool. M/U to coil and surface test. 22:42 00:00 1.30 73 5,680 PROD1 RPEQP1TRIP P RIH with BHA#1, Setting whipstock, EDC open 01/05/2015 Set whipstock, Mill 3.5"exit 00:00 00:18 0.30 5,680 6,600 PROD1 RPEQP1TRIP P Continue tripping in hole with whipstock 00:18 00:30 0.20 6,600 6,625 PROD1 RPEQP1TRIP P Log K1 for-7' 00:30 00:42 0.20 6,625 6,685 PROD1 RPEQP1WPST P RIH to set depth of 6685.41,TOWS @ 6675, oriented to 10° LOHS, Close EDC, Kick pumps on, see tool shift @ 3100 PSI, Set down 6K 00:42 02:00 1.30 6,685 6,685 PROD1 RPEQP1TRIP P Trip out of well 02:00 04:18 2.30 6,685 6,685 PROD1 WHPST OWFF P At surface,well not passing no flow, Go to PUD BHA#1 04:18 04:48 0.50 6,685 6,685 PROD1 WHPST PULD P Lay down tools, Inspect EDC and floats 04:48 05:48 1.00 6,685 6,685 PROD1 WHPST PULD P PJSM, M/U BHA#2 with 2.80 Window mill,2.79 String reamer, and .6°AKO motor 05:48 07:33 1.75 6,685 6,685 PROD1 WHPST TRIP P RIH window milling BHA#2 w/0.6° AKO motor, 2.80od string mill, and 2.80od window mill. 07:33 07:48 0.25 6,685 6,685 PROD1 WHPST TRIP P 6605ft,Tie into the K1 marker correction of minus 9.5ft. 07:48 08:03 0.25 6,685 6,685 PROD1 WHPST CIRC P Displace well to 9.6ppg Flo-pro milling fluid, close EDC, PUW 28k, RIH,dry tag TOWS at 6676.5ft. 08:03 16:03 8.00 6,685 6,685 PROD1 WHPST WPST P Start time milling as per plan. 1.48bpm at 3695psi, BHP 3584, WHP 18, IA 102, OA 176 16:03 19:33 3.50 6,685 6,685 PROD1 WHPST WPST P 6679ft, PUH,to check FS, begin time milling again, 1.48bpm at 3594psi, BHP 3583,WHP 18, IA 105, OA 181 ****Note: IA 1000, OA 845 19:33 20:33 1.00 6,685 6,685 PROD1 WHPST TRIP P At 6'down from pinch point, POOH, PUW=27K 20:33 21:09 0.60 6,685 6,685 PROD1 WHPST OWFF P At surface, 30 Min flow check, PJSM to lay down BHA#2 Page 2 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T .Comment 21:09 22:03 0.90 6,685 6,685 PROD1 WHPST PULD P Lay down BHA#2,3.5"window run #1 exit, Mill and reamer out at 2.79 No go 22:03 22:51 0.80 6,685 6,685 PROD1 WHPST PULD P M/U BHA#3 with 2°fixed bend Weatherford motor and fat radius 2.80°mill, M/U to coil and surface test 22:51 00:00 1.15 6,685 6,685 PROD1 WHPST TRIP P RIH, EDC open 01/06/2015 Complete Dual string window exit, Drill build section 6700 to 6905.Tie in RA @ 6683, TOWS=6676, BOW=6683 00:00 00:18 0.30 6,685 6,685 PROD1 WHPST TRIP P Log K1 for-9.5', Close EDC 00:18 00:30 0.20 6,685 6,685 PROD1 WHPST TRIP P RIH and dry tag window @ 6681.2 00:30 07:15 6.75 6,685 6,686 PROD1 WHPST WPST P Pumps on at 1.5 BPM @ 3630 PSI FS, Start milling 7"exit 07:15 09:00 1.75 6,686 6,700 PROD1 WHPST WPST P Start milling rat hole. 09:00 10:30 1.50 6,700 6,700 PROD1 WHPST REAM P 6700ft, back ream window area. 15 right, 15 left. dry drift clean 10:30 12:00 1.50 6,700 0 PROD1 WHPST TRIP P PUH to cased hole, open EDC. POOH following tripping schedule. 12:00 15:30 3.50 0 0 PROD1 WHPST PULD P Tag up. Conduct pre-job. PUD tools. 15:30 16:45 1.25 0 72 PROD1 DRILL PULD P Conduct pre-job. PD build BHA. BHA #4, Build section BHA W/2.3°AKO motor and rebuild bi center, Surface test 16:45 17:45 1.00 72 6,595 PROD1 DRILL TRIP P RIH with BHA#4, EDC Open 17:45 18:03 0.30 6,595 6,615 PROD1 DRILL DLOG P Log K1 for-7.5'correction, Close edc 18:03 18:27 0.40 6,615 6,700 PROD1 DRILL TRIP P Continue in well to drill,Window looks good hard to get started in rathole @ 6690 18:27 22:51 4.40 6,700 6,890 PROD1 DRILL DRLG P 6700 Drill, 1.47 BPM @ 3530 PSI FS, BHP=3694 22:51 23:09 0.30 6,890 6,600 PROD1 DRILL WPRT P 6890',Wiper to Window,Tie in K1 and log RA, PUW=28K 23:09 23:15 0.10 6,600 6,695 PROD1 DRILL DLOG P Log K1 for+.5'correction 23:15 23:21 0.10 6,695 6,720 PROD1 DRILL DLOG P Log RA marker @ 6683, TOWS=6676, BOW 6683 23:21 23:27 0.10 6,720 6,890 PROD1 DRILL WPRT P Continue wiper trip back to bottom 23:27 00:00 0.55 6,890 6,905 PROD1 DRILL DRLG P 6890', Drill, 1.47 BPM @ 3570PS1 FS, BHP=3769 Midnight Depth 6905 01/07/2015 TD Build section @ 7217,Trip out for RibSteer,drill ahead to 7570 00:00 00:48 0.80 6,905 6,937 PROD1 DRILL DRLG P Drilling, 1.47 BPM @ 3576 PSI FS, BHP=3726, Start Mud Swap 9.5 PPG PWR PRO, New mud @ bit 6930' New mud all around @ 6937 00:48 04:18 3.50 6,937 7,090 PROD1 DRILL DRLG P Pull off bottom for new pressures, 1.47 BPM @ 3550 PSI FS, BHP=3690 04:18 04:54 0.60 7,090 7,090 PROD1 DRILL WPRT P Wiper to window, PUW=28K Page 3 of 9 TTime Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:54 09:00 4.10 7,090 7,217 PROD1 DRILL DRLG P 7090Drill, 1.46 BPM @ 3420PS1 FS, BHP=3711 Pulled a couple BHA wipers. 09:00 11:30 2.50 7,217 72 PROD1 DRILL TRIP P Pumped a sweep,stop drilling build section @ 7217'.TOOH open EDC once in the tbg. 11:30 14:15 2.75 68 PROD1 DRILL PULD P Tag up, space out. Conduct PUD pre-job. PUD BHA#4. PD BHA#5. 14:15 15:30 1.25 68 6,595 PROD1 DRILL TRIP P RIH w/BHA#5. 15:30 15:45 0.25 6,595 6,622 PROD1 DRILL DLOG P Log K-1 from 6595 to 6622'. Close EDC. 15:45 16:15 0.50 6,622 7,217 PROD1 DRILL TRIP P Continue in hole. 16:15 19:45 3.50 7,217 7,390 PROD1 DRILL TRIP P Drilling, 1.47 BPM @ 3537 PSI FS, BHP=3788, 19:45 20:33 0.80 7,390 7,390 PROD1 DRILL WPRT P Wiper to 6715, PUW=25K 20:33 21:39 1.10 7,390 7,437 PROD1 DRILL DRLG P 7390', Drill, 1.48 BPM @ 3475PS1 FS, BHP=3711 21:39 21:45 0.10 7,437 7,437 PROD1 DRILL WPRT P BHA Wiper, Stacking 21:45 00:00 2.25 7,437 7,570 PROD1 DRILL DRLG P 7437 Drill, 1.47 BPM @ 3490 PSI FS, BHP=3730, Stalling in 7437 to 7463 area, Midnight depth 7570 01/08/2015 Drill 7570 to 8253 00:00 00:12 0.20 7,570 7,590 PROD1 DRILL DRLG P 7570', Drill, 1.46 BPM @ 3490 PSI FS, BHP=3765, Bleed IA and OA to 200 PSI 00:12 01:00 0.80 7,590 7,590 PROD1 DRILL WPRT P Wiper trip to 6790', PUW=26K, Good trip up and down 01:00 03:24 2.40 7,590 7,790 PROD1 DRILL DRLG P 7590', Drill, 1.47 BPM @ 3720 PSI FS, BHP=3785 03:24 03:54 0.50 7,790 6,700 PROD1 DRILL WPRT P Wiper trip to window with tie in, Pumped 5 X 5 sweeps, PUW=25K 03:54 04:00 0.10 6,700 6,716 PROD1 DRILL DLOG P Log RA Marker, +1.5'correction 04:00 04:36 0.60 6,716 7,790 PROD1 DRILL WPRT P Continue wiper trip back to bottom 04:36 14:06 9.50 7,790 7,791 PROD1 DRILL DRLG P 7790', Drill ahead, 1.46 BPM @ 3720 PSI FS, BHP=3780 tough spots of drilling, had to drill awhile without ribs engaged to get moving at times. Drill 7990' 14:06 14:36 0.50 7,991 7,100 PROD1 DRILL WPRT P Wiper to to 7100' 14:36 15:12 0.60 7,100 7,791 PROD1 DRILL WPRT P 7100' RBIH to btm. 15:12 18:00 2.80 7,791 8,045 PROD1 DRILL DRLG P 7791', Drill ahead. 1.46 BPM @ 3756 FS. BHP @ 3790 18:00 18:06 0.10 8,045 8,045 PROD1 DRILL WPRT P Mini wiper, PUW=30K, 18:06 21:24 3.30 8,045 8,190 PROD1 DRILL DRLG P 8045', Drill, 1.47 BPM @ 3850PS1 FS, BHP=3803 21:24 22:18 0.90 8,190 8,190 PROD1 DRILL WPRT P Wiper trip to 7000', PIW=29K 22:18 00:00 1.70 8,190 8,253 PROD1 DRILL DRLG P 8190', Drill, 1.45 BPM @ 3820PSI FS, BHP=3840, Midnight Depth=8253 01/09/2015 Drill 8253 to 8869 Page 4 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:54 2.90 8,253 8,390 PROD1 DRILL DRLG P 8253', Drill ahead, 1.44 BPM @ 3800 PSI FS, BHP=3820 02:54 03:36 0.70 8,390 6,690 PROD1 DRILL WPRT P Wiper to window with tie in, Pump 5 X 5 sweeps, PUW=28K 03:36 03:48 0.20 6,690 6,717 PROD1 DRILL DLOG P Log RA Marker for+1' 03:48 04:36 0.80 6,717 8,390 PROD1 DRILL WPRT P Continue wiper back to bottom 04:36 13:00 8.40 8,390 8,590 PROD1 DRILL DRLG P 8390', Drill Ahead, 1.45 BPM @ 3890 PSI FS, BHP=3896 13:00 14:00 1.00 8,590 8,590 PROD1 DRILL WPRT P 850'Wiper trip, Planning mud swap. 14:00 14:45 0.75 8,590 8,614 PROD1 DRILL DRLG P back on BTM, new mud going down, drill ahead 1.41 BPM @ 3880'psi, 3939 BHP. 14:45 19:51 5.10 8,614 8,790 PROD1 DRILL DRLG P Have new mud all around. Pump pressure down some, 3758 psi while drilling. 19:51 20:57 1.10 8,790 8,790 PROD1 DRILL WPRT P Wiper to 7790', PUW=23K 20:57 00:00 3.05 8,790 8,869 PROD1 DRILL DRLG P 8790', Drill Ahead, 1.44 BPM @ 3750 PSi FS, BHP=3871 01/10/2015 Drill to 8970'with rib steer BHA. POOH to pick-up conventional motor&agitator. Function tested BOP. RIH with BHA#6 Drill to 9170 00:00 00:12 0.20 8,869 8,869 PROD1 DRILL WPRT P MiniWiper-stacking 00:12 02:30 2.30 8,869 8,920 PROD1 DRILL DRLG P 8869', Drill, 1.44 BPM @ 3785 PSI FS, BHP=3890 02:30 02:36 0.10 8,920 8,920 PROD1 DRILL WPRT P P/U and restart, PUW=25K 02:36 07:00 4.40 8,920 8,958 PROD1 DRILL DRLG P 8920', Drill, 1.43 BPM @ 3840 PSi FS, BHP=3890 07:00 08:15 1.25 8,958 8,958 PROD1 DRILL DRLG P ROP continuing to drop, average under 10. Call town.decide to pull for an agitator. Continue drilling until a sweep is out the bit. 08:15 10:30 2.25 8,970 60 PROD1 DRILL TRIP P 8970'sweep out of the bit, POOH for BHA change. 10:30 10:45 0.25 60 60 PROD1 DRILL SFTY P Pre-job for un-deploying BHA. 10:45 12:30 1.75 60 0 PROD1 DRILL PULD P PUD Rib steer BHA. Perform BOPE function test. 12:30 14:45 2.25 0 78 PROD1 DRILL PULD P Conduct pre-job for deploying. PD BHA#6 14:45 16:09 1.40 78 6,600 PROD1 DRILL TRIP P RIH, stop @ 200', close EDC Test agitator,good vibration. Re-open EDC, continue in the hole. 16:09 16:21 0.20 6,600 6,630 PROD1 DRILL DLOG P Tie into K1 marker for-8'correction, PUW=25K 16:21 17:33 1.20 6,630 8,970 PROD1 DRILL TRIP P Continue in to drill, Clean pass through window 17:33 19:57 2.40 8,970 9,052 PROD1 DRILL DRLG P 8970', Drill ahead, 1.35 BPM @ 3920 PSI FS, BHP=3915 19:57 20:09 0.20 9,052 9,052 PROD1 DRILL WPRT P Stacking, BHA Wiper, PUW=30K 20:09 23:03 2.90 9,052 9,170 PROD1 DRILL DRLG P Drill, 1.34 BPM @ 3875 PSI FS, BHP=3823 23:03 00:00 0.95 9,170 8,758 PROD1 DRILL WPRT P Wiper to 8000', PUW=27K, Midnight depth RIH @ 8758 Page 5 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/11/2015 24hrSummary Drill 9170 to early TD @ 9648, Drilled into thief zone, Lost 293 BBIs/24Hrs 00:00 00:18 0.30 8,758 9,170 PROD1 DRILL WPRT P Continue inhole on wiper from 9170, Clean trip up and down 00:18 02:06 1.80 9,170 9,220 PROD1 DRILL DRLG P 9170', Drill, 1.35 BPM @ 3902 PSI FS, BHP=3851 02:06 06:06 4.00 9,220 9,223 PROD1 DRILL DRLG P 9220, Hard spot, 46K pull off bottom with additional fluid loss, Pull BHA Wiper. Very hard to get drilling with stalls. Pull sample for Geo, sand. Get drill ROP<5FPH 06:06 08:15 2.15 9,223 9,370 PROD1 DRILL DRLG P 9223', finall broke out, get coil weight back& ROP increase to-50 08:15 09:30 1.25 9,370 9,370 PROD1 DRILL WPRT P 9370',Wiper 29k off BTm, Pull up past troubled spot at 9220 with no issues 09:30 14:00 4.50 9,370 9,500 PROD1 DRILL DRLG P 9370', Drill ahead 1.34 BPM 4051 psi drilling. BHP 3899 psi. 14:00 14:45 0.75 9,500 9,520 PROD1 DRILL DRLG P 9500'stacking out a lot, performed some BHA wipers. Send down 40 bbls of new mud coil, Check to see if drilling improves once the new mud pill is around BHA. 14:45 16:30 1.75 9,520 9,534 PROD1 DRILL DRLG P After getting new mud around BHA& Open hole, no noticeable differance. 1.37 BPM @ 4087 drilling, 10 ROP 16:30 17:24 0.90 9,534 9,574 PROD1 DRILL DRLG P 9534', ROP rapidly increased to over 100. Start taking losses rate in 1.35, rate out.98. Continue drilling to wiper at 9574 17:24 18:54 1.50 9,574 6,710 PROD1 DRILL WPRT P Tie in wiper PUW=31K 18:54 19:00 0.10 6,710 6,722 PROD1 DRILL DLOG P Log RA marker for+6'correction 19:00 20:24 1.40 6,722 9,578 PROD1 DRILL WPRT P Continue wiper back to bottom 20:24 21:54 1.50 9,578 9,648 PROD1 DRILL DRLG P 9578', Drill, 1.36 BPM @ 3870 PSI FS, BHP=3823, Fluild losses at 30-40 BPH, RIW=5.5K 21:54 22:24 0.50 9,648 9,648 PROD1 DRILL WPRT P P/U, unable to run in hole after pick up, Perform 300'mini wiper 22:24 22:48 0.40 9,648 9,648 PROD1 DRILL DRLG P 9648', Drill, 1.35 BPM @ 3950 PSI FS, BHP=3779. Very hard to get WOB or Diff Pressure. Will not drill with-7K surface weight 22:48 23:42 0.90 9,648 9,600 PROD1 DRILL DRLG P Call TD, Start 10 X 10BBI sweeps 23:42 00:00 0.30 9,600 9,086 PROD1 DRILL WPRT P Sweeps out, Chase sweeps to swab 01/12/2015 Condition hole Run AL1 lower liner section 9646 to 8339 00:00 03:18 3.30 9,086 70 PROD1 DRILL WPRT P Continue swab wiper trip 03:18 04:54 1.60 70 6,598 PROD1 DRILL WPRT P Tag up at surface, reset counters, trip in to confirm TD 04:54 05:06 0.20 6,598 6,630 PROD1 DRILL DLOG P Log K1 for-9'correction 05:06 07:30 2.40 9,646 9,646 PROD1 DRILL WPRT P Continue in hole to confirm TD @ 9646'. Page 6 of 9 1 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 07:30 10:15 2.75 9,646 78 PROD1 DRILL DISP P Start laying in 11.4 liner beaded running pill(100 bbls)lay in 11.4 to surface. 10:15 10:45 0.50 78 78 PROD1 DRILL OWFF P Tag up,watch well for 30 minutes, flow check. Conduct pre-job for laying down tools. 10:45 12:15 1.50 78 0 PROD1 DRILL PULD P Lay down drilling BHA. Bit had some hair line cracks on some of the cutters. Port had some trash in them but not clogged off. 12:15 15:45 3.50 0 1,351 COMPZ CASING PUTB P Conduct pre-job. Pick up first section of L1 liner,41 jts. Pick up BHI tools. Move cart back over, MU tools to CT connector. 15:45 17:27 1.70 1,351 5,962 COMPZ CASING RUNL P RIH w/Ll liner(lower section)EDC Closed 17:27 17:33 0.10 5,962 5,951 COMPZ CASING DLOG P Tie into EOP Flag-11.2 17:33 19:03 1.50 5,951 9,645 COMPZ CASING RUNL P Continue in hole with liner, Clean pass through window, Stack out @ 7865. Pass through after three cycles. Set down @ 8084', pull 55K to get moving up. Pass through at 4 cycles. Tag up @ 9646' PUW=34K. Release from liner at PUW=25K TOL at 8339' Unable to tie in with liner 19:03 20:03 1.00 9,645 6,700 COMPZ CASING TRIP P Liner released, remove liner length left in hole from counters, 1306.84, trip out 20:03 22:27 2.40 6,700 8,300 COMPZ CASING TRIP P Consult with town, RBIH to pump more beads for second liner run. Problem areas not covered up with first run. Mix 50 BBL pill start down coil 22:27 22:57 0.50 8,300 6,670 COMPZ CASING TRIP P POOH pumping beaded liner running pill 22:57 23:15 0.30 6,670 6,694 COMPZ CASING DLOG P Log RA for+5' 23:15 00:00 0.75 6,694 4,800 COMPZ CASING TRIP P Continue trip out of well, Paint EOP flags @ 6500'and 4900' 31/13/2015 Set upper section of Al liner,top at 6690', 7'below bottom of whipstock.TIH with BHA#9,wash tray face and overpull 5k at 6,676.5 ft, TOOH. 00:00 00:48 0.80 4,800 41 COMPZ CASING TRIP P Continue trip out of well 00:48 01:42 0.90 41 0 COMPZ CASING OWFF P At surface, perform 30 Min No Flo test, Good test PJSM Lay down BHA#7 Liner running tools 01:42 05:15 3.55 0 1,695 COMPZ CASING PUTB P M/U BHA#8 with ported bullnose, 36 Jts slotted liner, 16 Jts blank liner, and sorty deployment sleeve, M/U to coil and surface test. 05:15 08:15 3.00 1,695 8,342 COMPZ CASING RUNL P RIH with L1 liner, (upper section)See flag at-3, had to work liner @ 8020', 8050'&8280'. Set liner @ 8342. 08:15 08:45 0.50 6,575 6,533 COMPZ CASING DLOG P PUH log into K-1 for a-3. Correct the btm of liner @ 8339'-1648.8 puts top of the liner @ 6690.2. —7'below whipstock. Page 7 of 9 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:45 10:06 1.35 6,533 6,533 COMPZ CASING CIRC P Change of plans for mud swap. Send truck after 290 bbls of 9.5 mud. Circulate,wait on mud. 10:06 13:42 3.60 6,533 6,400 COMPZ CASING DISP P Begin pumping 9 bbl spacer pill and then 9.5 ppg Flo-Pro to displace 11.4 kill weight mud. Slowly reciprocate pipe while displacing. 13:42 14:06 0.40 6,400 6,400 COMPZ CASING OWFF P 11.4 ppg mud has been displaced. Start No-Flow Test.Test good. 14:06 15:06 1.00 6,400 44 COMPZ CASING TRIP P Begin POOH while pumping 9.5 ppg Flo-Pro @.6 bpm. 15:06 15:48 0.70 44 44 COMPZ CASING OWFF P At surface. Begin No-Flow Test. (hold BHA PJSM while waiting on test). Test good. 15:48 16:30 0.70 44 0 COMPZ CASING PULD P L/D BHA#8 16:30 17:24 0.90 0 64 COMPZ RPEQP1 PULL P P/U BHA#9 to fish whipstock. 17:24 19:00 1.60 64 6,600 COMPZ RPEQP1 PULL P RIH with BHA#9 19:00 19:12 0.20 6,600 6,620 COMPZ RPEQP1 PULL P Log K1,-9 ft correction, PUW 28k 19:12 19:30 0.30 6,620 6,648 COMPZ RPEQPI PULL P Continue in hole, RIW 11k,discuss pulling procedure 19:30 19:57 0.45 6,648 6,684 COMPZ RPEQP1 PULL P Pumps up 1.2 bpm at 3680 psi, wash tray face to 6,684 ft,TF 170R up,down/up at 170L and 150R, PUW 25k 19:57 20:09 0.20 6,684 6,677 COMPZ RPEQP1 PULL P Pumps down,TF 10L, RBIH,overpull 5k at 6,676.5, broke over, PUW 27k, orient TF 180 20:09 00:00 3.85 6,677 64 COMPZ RPEQP1 PULL P TOOH with BHA#9 01/14/2015 Lay down BHA#9 and 10.41-ft Baker whipstock. RIH with BHA#10,swap well to seawater from 6,675-ft. Freeze protect from 2,500-ft. RDMO 00:00 00:36 0.60 64 64 COMPZ RPEQP1 PULL P Monitor well for flow. PJSM for laying down fish. 00:36 01:45 1.15 64 0 COMPZ RPEQP1 PULL P Lay down BHA#9 and 10.41-ft X 2.65"OD Baker Mono Bore XL whipstock. 01:45 02:21 0.60 0 15 DEMOB WHDBO PULD P PJSM-MU BHA#10, nozzle and 10 ft extension. 02:21 03:45 1.40 15 6,675 DEMOB WHDBO TRIP P RIH with BHA#10 03:45 05:21 1.60 6,675 2,500 DEMOB WHDBO DISP P Displace well to seawater, PJSM- MIRU LRS, pressure test lines. TOOH, LRS pump 30 bbl diesel, RDMO LRS 05:21 06:09 0.80 2,500 15 DEMOB WHDBO FRZP P freeze protect well to surface. 06:09 07:09 1.00 15 0 DEMOB WHDBO PULD P PJSM-LD BHA#10. 07:09 08:57 1.80 0 0 DEMOB WHDBO MPSP P PJSM-Load FMC equipment, lubricate in BPV, off load FMC equipment. 08:57 11:30 2.55 0 0 DEMOB WHDBO DISP P Pump corrosion inhibitor to displace coil and piping to the tiger tank. Blow down coil and piping to tiger tank afterwards. Page 8 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 13:30 2.00 0 0 DEMOB WHDBO NUND P Nipple down BOPE. 13:30 15:00 1.50 0 0 DEMOB WHDBO NUND P Torque all tree flange bolts(1 1/2 hours) All studs loose on flange joining#1 swab valve and#2 swab valves. 2 stud bolts loose on wellhead adapter flange to master valve and 3 stud bolts loose on flange joining the IA and OA spool pieces. NOTE: Rig released at 15:00 Page 9 of 9 1E-14L1 WELL WORK SUMMARY DATE SUMMARY POST-RIG WELL WORK 1/18/2015 TAG LINER TOP @ 6738' SLM & MEASURED BHP @ 6759' RKB: MAX PSI 2978. IN PROGRESS. 1/19/2015 RAN MADE 2 MAGNET RUNS TO LINER TOP @ 6738' SLM; SET 2.72" CATCHER @ 6738' SLM; PULLED DV'S @ 6253', 5759', &4925' RKB; SET OV© 6253' & GLV @ 5759' RKB. IN PROGRESS. 1/20/2015 PULLED DVs © 3784' &2517' RKB. SET GLVs @ 4925', 3784' & 2517' RKB. BLED IA, CONFIRMED VALVES SET. PULLED CATCHER. COMPLETE. • U MO i lame hogs sz T" 0. 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V V (r) (n N 0 r O Y • `A N N N N N N N ,z60 U — 0 CO 0 0 0 0 0 0 C y N N , CO OC) U) CO0CO CO m OM) Q C Oi V O co oi (V M oi co W Q y 0 0 co N- n r N- N a cc a N L [Z 0 0 Y Y ii U O J J 0 (0 (00. V V V M 81 (00 N m M ,� U Y Y LLL W W C• � W W W rn m oo m 0) a b 0 u oCMM 0- 0 0 0 0 (ri co r; til C13 V. LO O 2 o � 2 , m � � � � � a � o y .0 01cu E0 0 a+ d d N ✓ a in o in 214202 25303 Letter of Transmittal rpu BAKER Date: DATA LOGGED January 21, 2015 M`K D5 HUGHES To: From: State of Alaska, AOGCC Jesse Salyer 333 West 7th Ave, Suite 100 Baker Hughes INTEQ Anchorage, Alaska 99501 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the final well data for the following well(s): ell: 1E-14L1 « Enclosed for each well(s): 1 hardcopy print of final logs • 2MD, 5MD & TVDSS 1 compact disk containing final field data • CGM • PDF • SURVEY • TIFF • LAS RECEIVED • TAPESCAN `L015 JAN 22 AOGGC N in Nt r , 0 H > N U ► W ammo wII a= CC m a. C t CU O a. 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C rK m N • O O O O _ i W W I ; Letter of Transmittal FIRMr _._ _ RECEIVED BAKER Date: DATA LOGGED 15, 2015 JAN 16 2015 /16/2016 HUGHES I- AOGCC M.K.BENDER To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 1H-04L1 2\2k-VS 2-52:13 1H-04L1-01 2'4''x\ 1-52:114 1E-14L1 2'.4 2 02 25271 Cj (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@BakerHughes.com CIF Tye THE STATE Alaska Oil and Gas A, .-s���, foALASI�:A Conservation Commission 333 West Seventh Avenue Anchorage Alaska 99501-3572 � GOVERNOR BILL WALKER 9 Main 907 279.1433 OFLA`*P.- Fax 907.276 7542 www aogcc.alaska goy D. Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1E-14L1 ConocoPhillips Alaska, Inc. Permit No: 214-202 Surface Location: 564' FSL, 813' FEL, SEC. 16, T11N, R10E, UM Bottomhole Location: 1369' FNL, 2043' FEL, SEC. 21, T11N, R10E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 182-079, API No. 50-029- 20751-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, David J. ayberry Commissioner DATED this l614"day of December, 2014. i STATE OF ALASKA - ALASKA OIL AND GAS CONSERVATION COMMISSION 117 S) 9 2014 PERMIT TO DRILL AC GC 20 AAC 25.005 1a Type of Work 1 b Proposed Well Class' Development-Oil Q• Service-Winj ❑ Single Zone Q• 1c Specify if well is proposed for. Drill ❑ 'Lateral Q Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2 Operator Name 5 Bond U Blanket• u Single Well 11.Well Name and Number ConocoPhillips Alaska, Inc. Bond No. 59-52-180 , KRU 1E-14L1 , 3 Address 6 Proposed Depth 12.Field/Pool(s)' P.O. Box 100360 Anchorage,AK 99510-0360 MD:9900'• TVD: 6222'- Kuparuk River Field 4a Location of Well(Governmental Section) 7 Property Designation(Lease Number): Surface:564'FSL,813'FEL,Sec. 16,T11N, R10E, UM ' ADL 25651 • Kuparuk River Oil Pool r Top of Productive Horizon: 8.Land Use Permit. 13 Approximate Spud Date 1172'FSL,2433'FEL,Sec. 16,T11N, R10E,UM 469 1/5/2015 Total Depth: 9 Acres in Property 14 Distance to 1369'FNL,2043'FEL,Sec.21,T11N, R10E,UM 2560 - Nearest Property 24700 4b Location of Well(State Base Plane Coordinates-NAD 27) 10 KB Elevation above MSL. 106 feet• 15.Distance to Nearest Well Open Surface:x- 549710 y- 5960150 Zone- 4• GL Elevation above MSL: 67 feet - to Same Pool 1E-06,197 16.Deviated wells Kickoff depth: , 6675 ft.• 17.Maximum Anticipated Pressures in psig(see 20 MC 25 035) Maximum Hole Angle J 105° deg Downhole:4005 psig • Surface'3391 psig - 18.Casing Program Specifications Top - Setting Depth -Bottom Cement Quantity,c f or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 3225' 6675' 6190' 9900' 6222' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft) Effective Depth TVD(ft) Junk(measured) 7190 6697 6633',6795' 7076 6584 none Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 330 sxASll 114' 114' Surface 2300' 10.75" 1100 sx ASIII,250 sx ASII 2333' 2333' Production 7140' 7" 775 sx Class G,41 bbls ASII 7168' 6676' Perforation Depth MD(ft): Perforation Depth TVD(ft): 6660-6724,6747-6749,6853-6859,6871-6888 6175-6238,6260-6262,6365-6371,6383-6399 20.Attachments. Property Plal❑ BOP Sketch❑ Drilling Prograrr ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25 050 requirements Q 21 Verbal Approval Commission Representative. Date: 22 I hereby certify that the foregoing is true and correct. Contact Jason B r @ 231-4568 Email Jason.Burkecop.com Printed Name D. enhaus Title CTD Engineering Supervisor Signature /jt_ _ Phone:263-4372 Date /2 ' 8- /4 Commission Use Only Permit to Drill API Number / ermit Approval See cover letter Number: ail.'—c20').._ 50- OM—�O 7E1—GO—COoDate: ku`(47,_cA ` for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed mgfhane,gashydrates,or gas contained in shales: d Other:aoP trotI`. gvvC ,. 5'- Samples req'd: Yes ❑ No Lre1f Mud log req'd: Yes❑ No Il r�✓7 v. r ft-- to �aO S t H2S measures: Yes [r No ❑ Directional svy req'd: Yes Er No 4. Spacing exception req'd: Yes ❑ No L Inclination-only svy req'd: Yes❑ No zi APPROVED BY THE a/ I Approved by' ago COMMISSIONER COMMISSION Date:I?.I Form 10-401(Re sed 10/2012) is permit is valid for 24 months from a. . a,p • : '` -.005(g)) ' I h 4 /I, VT`/u/2-//4- ( /' ,moi R ` , 1iie D ConocoPhillips =1ET ° 9 2014 Alaska AOGC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 December 4, 2014 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 an application for a permit to drill a lateral from the existing well bore on KRU 1E-14 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin on January 5, 2015. The CTD objective will be to drill a lateral (1E-14L1), targeting the C sand. This well will be classified as a development well. Attached to this application are the following documents: — Permit to Drill Application Form 10-401 for 1E-14L1 — Detailed Summary of Operations — Directional Plans — Current Schematic — Proposed Schematic If you have any questions or require additional information please contact me at 907-265-6097. Sincerely, Al Ilr. 111"" Jason Burke Coiled Tubing Drilling Engineer 907-231-4568 Kuparuk CTD Laterals NABONS ALASKA 1E-14L1 cpci AIFISApplication for Permit to Drill Document 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 5 Pressure Deployment of BHA 5 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(b)) 6 16. Attachments 6 Attachment 1: Directional Plans for 1E-14L1 6 Attachment 2: Current Well Schematic for 1E-14 6 Attachment 3: Proposed Well Schematic for 1E-14L1 6 Page 1 of 6 12/3/2014 i-6GNAL PTD Application: 1E-14L1 1. Well Name and Classification (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) The proposed lateral described in this document is 1E-14L1. This lateral will be classified as "Development- Oif'well. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This lateral will target the C sand package in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 1E-14L1. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036, for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. Using the maximum formation pressure in the area of 4005 psi in the 1E-11, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 3391 psi. See the"Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 6,1'v° Two 12.5 r'g� 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) A static bottom hole pressure of 1E-14 in September 2014 indicated a reservoir pressure of 2938 psi or 9.2 ppg equivalent mud weight. The maximum down hole pressure in the 1E-14 pattern is at 1E-11 with 4005 psi. It is not expected that reservoir pressure as high as 1E-11 will be encountered while drilling the 1E-14L1 because we are drilling away from the 1E-11 and the two wells are separated by a fault. Using the 1E-11 pressure as the maximum possible, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3391 psi. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; gas injection has been performed on the 1 E pad, but we will be drilling away from that area. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The largest, expected risk of hole problems in the 1E-14 lateral will be drilling into the B shale, which could prove to be unstable. Managed pressure drilling will be used to reduce this risk. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(f), thru-tubing drilling operations need not perform additional formation integrity tests. Page 2 of 60 R I G I L 12/3/2014 PTD Application: 1E-14L1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS 2%", 4.7#, L-80, ST-L slotted liner; 1E-14L1 6,675' 9,900' 6,189' 6,222' with a shorty deployment sleeve on top. Existing Casing/Liner Information Category OD Weight Grade Conn. Top MD Btm Top Btm Burst Collapse (ppf) MD TVD TVD psi psi Conductor 16" 65.0 H-40 Welded 34' 114' 0' 114' 1640 630 Surface 10-3/4" 45.5 K-55 BTC 34' 2,333' 0' 2,333' 3580 2090 Casing 7" 26 K-55 BTC 34' 7,168' 0' 6,675' 4980 4330 Liner 3 %" 9.2 J-55 BTC 6,428' 6,808' 5,920' 6,320' 6990 7400 Tubing 3 '/" 9.3 L-80 EUE 30' 6,428' 0' 5,920' 10160 10540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System - Window milling operations: Chloride-based Flo-Pro mud (9.7 ppg) - Drilling operations: Chloride-based Flo-Pro mud (9.3 ppg): This mud weight will hydrostatically overbalance the reservoir pressure. - Completion operations: BHA's will be deployed using standard pressure deployments and the well will be loaded with 11.5 ppg NaBr completion fluid in order to provide formation over-balance while running completions. - Emergency Kill Weight fluid: Two well bore volumes(-172 bbl)of at least 12.2 ppg emergency kill weight fluid will be within a short drive to the rig during drilling operations. N Page 3 of 6 12/3/2014 ORIGINAL PTD Application: 1E-14L1 Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing an overbalance on the reservoir. Through experience with drilling CTD laterals in the Kuparuk sands, 11.8 ppg has been identified as the minimum EMW to ensure stability of shale sections. Since this well is proposed as an infield development candidate in an actively water flooded field, expected reservoir pressures can be difficult to estimate. In this case, however, a constant BHP of the minimum of 11.4 ppg will be initially targeted at the window based on the recent static bottom-hole pressure and the propensity of the C sand to have losses. The constant BHP target will be adjusted to maintain overbalanced conditions if increased reservoir pressure is encountered during drilling. The constant BHP target will be maintained utilizing the surface choke. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 1E-14 Window(6,675' MD, 6,189' TVD Using MPD Pumps On (1.5 bpm) Pumps Off C-sand Formation Pressure(9.2 ppg) 2961 psi 2961 psi Mud Hydrostatic(9.3 ppg) 2993 psi 2993 psi Annular friction (i.e. ECD, 0.090 psi/ft) 601 psi 0 psi Mud + ECD Combined 3594 psi 2993 psi (no choke pressure) (overbalanced (overbalanced —633 psi) —32 psi) Tzrn�+ RHP at Window(11.4 ppg) 3669 psi 3669 psi Choke Pressure Required to Maintain 75 psi 676 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Page 4 of 6 12/3/2014 ORIGINAL PTD Application: 1E-14L1 Summary of Operations Background Well 1E-14 is a Kuparuk C-sand development well equipped with 3'/2"tubing and a 3 ''/2"liner. A single lateral will be drilled from well 1E-14 to the south. This lateral will be through the C-sand. A mechanical whip-stock will be placed in the 3 'A" liner at the planned kickoff point of 6675' MD. The 1E-14L1 lateral will exit through the 3 'A"liner and 7"casing;drilling to a TD of 9900'. The lateral will be completed with 2-%" slotted liner;the whip-stock will then be pulled out of the hole to allow access to the well below. Pre-CTD Work 1. RU slickline—Drift dummy whip-stock 2. RU E-line—Obtain SBHP and set whip-stock 3. Prep site for Nabors CDR2-AC,including setting BPV Rig Work 1. M1RU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 1E-14L1 Lateral(C sand-South) i. Mill 2.80"window at 6675' MD ii. Drill 2.74"x 3.00"bi-center lateral to TD of 9900' MD iii. Run 2%"slotted liner with a shorty deployment sleeve from TD up to 6670' MD iv. 3. Freeze protect the well. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV. 3. Turn over to production Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree, so we will use the standard pressure deployment process. A system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick-line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate Page 5 of 6 12/3/2014 URtGINAL PTD Application: 1 E-14L1 reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment,the steps listed above are observed, only in reverse. Liner Running — All the laterals will be displaced to an overbalancing fluid (11.5 ppg NaBr) prior to running liner. See the "Drilling Fluids" section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to Nearest Property Line(measured to KPA boundary at closest point) Lateral Name Distance 1E-14L1 24700' — Distance to Nearest Well within Pool(measured to offset well) — 1E-06 currently secured with a bridge plug set at 6563', has been shut in since 9/30/14 Lateral Name Distance Well 1E-14L1 197' 1E-06 16. Attachments Attachment 1: Directional Plans for 1E-14L1 Attachment 2: Current Well Schematic for 1E-14 Attachment 3: Proposed Well Schematic for 1E-14L1 Page 6 of 6 12/3/2014 URLGINAL 2 M CD F.(6 C3 % O Eo I a p z co 3m-" 0 V D J 0 3 p r r 1 e o� a, 7 W 0 c C_ � N M co• C I r F J 3 r-C U co c`l as oi as N - 2 O 7 N o I V CO r o I b o C M M D - M N CO •t C b '- 3 c E (o co a v co r, p — m ~ m ?Y 2 Qw0 . w o O7 f0 p 2 N r p_N 2 `� w U 173 Q. U \ rn •'c C m _0 o Q of o co w kii U (o CO g co N > N `m m CV = Y- �a N a (n N N i 1 N fU6(11) CL�� U6 In c0 r 11J p E o _1 mu) E U 2 i d I N N N N N N O Y Y Y il 3 CO CO f6 (6 r r o a_ m mmm ri c+)Eo• = I CV ii.Tr: cc c;3m / iii i ... I co il r IT Q. a r .: x.. ai ' f ...1.,...' 11111111 1 .- 111 al 0 I 1 1111 V I—a m13 v U o I CI 0 U) E cco m (0 O �g En - mO.O YMcf) � c0 co2 I- ** co ���pp'�� m_ co o� o_ Y ao � N V 01_> ,_ C N C COMCO (O I ,- 40 d �rn n ° " COTr °° N r W tAl kLflv M p 1-- co o U . Q . � � w (q N O L - O N b L r N ORNkL KUP PROD 1E-14 ConocoPhillips w Well Attributes JMax Angle&MD TD Al:. +i.IS I''. Wellbore APIIUWI Field Name WeIl bore Status not("I MD(5661 Act Bite(RKB) Con00.;oaippa 500292075100 KUPARUK RIVER UNIT PROD 38.78 4,000.00 7,190.0 • Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-14.1013612014 10 1 4 51 AM SSSV:TRDP Last WO. 5/6/1983 40.71 7/21/1982 Vert.'schematic(actual) " 'Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag:RKB 6,633.0 10/16/2014 Rev Reason Lock-Out SSSV,Set Catcher,GLV hipshkf 10/30/2014 HANGER 113.4.-- "7 C/O,Cut TBG Casing Strings Casing Description OD(In) ID(In) Top(168) Set Depth(RKB) Set Depth)TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.060 34.0 114.0 114.0 65.00 H-40 WELDED Casing Description 00(In) ID(In) Top(ttK8) Set Depth(ttK8) Set Depth)ND)...Wt/Len p...Grade Top Thread SURFACE 103/4 9.950 332 2.333.0 2.332.9 45.50 K-55 BTC Casing Description OD(In) ID(in) Top(RKB) Set Depth(RKB) Set Depth)ND)...WtILen(I...Grade Top Thread 1PRODUCTION 7 6276 28.9 7.168.5 6.675.6 26.00 K-55 BIC Tubing Strings !� Tubing Description Suing Ma...ID(In) Top(R(B) Set Depth(ft..Set Depth IND)(...WI(Ib/ft) Grade Top Connection TUBING WO 3 1/2 2.992 18.4 6,767.2 6,280.2 9.20 J-55 BTC Completion Details nth /J' .A �a To RKB To ND RKB TopIncl Rem Des Com Nominal ID CONDUCTOR,340-1140 a ,�� P) ) P( )( 1 r) Iln 18A 18.4 0.18 HANGER FMC TUBING HANGER 3 500 SAFETY VLV(LOCKED OUT 1,916.5 1,916.4 0.50 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE(LOCKED OUT 2.813 1025%4);1,918.5 --- ''e' (LOCKED 1028/14) OUT 10128/14) 6,430.3 5,948.5 11.88 PACKER BAKER FHL PACKER 2.891 6,760.8 6,273.9 9.74 LOCATOR BAKER LOCATOR SUB 2.970 6,762.2 6,2753 9.75 SEAL ASSY 12'OF SEALS BELOW LOCATOR SUB STABBED INTO 2.970 FBI PACKER SURFACE:33.2-2.7330- Tubing Description String Ma...ID(In) Top(RKB) Set Depth(R..Set Depth(TVD)(. Wt(14/11) Grade Top Connection TUBING Original 31/21 2.992' 6,767.2 6,808.31 6,320.7 9.201 J-55 I BTC Completion Details Nominal ID Top 19KB) Top(TVD)(RKB) Top Incl 0 item Des Com (In) 6,767.2 6,280.2 9.76 PACKER BAKER FB-1 PERMANENT PACKER 4.000 GAS LIFT,6.389 4 E[ 6,769.7 6,282.7 9.76 SBE SEAL BORE EXTENSION 4.000 6,779.1 6,291.9 9.78 MILL MILL OUT EXTENSION 2.992 TUBING CUT:6,3510 -. 6,795.9 6,308,5 9.81 NIPPLE CAMCO D NIPPLE NO GO 2.750 6,807.4 6.319.8 9.82 SOS BAKER SHEAR OUT SUB 2.992 1 Other In Hole(Wlrellne retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl PACKER;6,430 3 Top MKS) (RKB) (°) Des Corn Run Date ID lin) 6,391.0 5,910.1 12.47+TUBING CUT-CUT TUBING(CHEM CUT) 102912014 I 6,785.0 6,297.8 9.79 SAND DUMP BAILED 10'SILICA SAND ON CA-2 PLUG 2/3/2014 PRODUCTION e eaz z rl 6,785.0 6.297.8' 9.79 CATCHER 2.72"JUNK CATCHER(OAL=96") 10/29/2014 0.000 6,795.0 6,307.6- 9.81 PLUG 2.75 CA-2 PLUG 2/3/2014 0.000 PRODUCTION.6,629.61 14 Perforations&Slots Shot Dens Top(ND) Btm(TVD) (shots/1 (PERF;6.660.06.724.0-- kTop(560) Btm(RKB) (RKB) (RKB) Zone Date t) Type Com APERF;6.700.0-6.7100 A ti 6,660.0 6,724.0 6,174.5 6,237.6 C-4,C-3,C-2, "7/18/1982 4.0 IPERF R 4 C-1,1E-14 n ti 6,700.0 6,710.0 6.214.0 6,223.8 A-4.1E-14 5/82014 3.0 APERF 2"HSC BH GUNS,120 DEG PHASING ti 6,747.0 6,749.0 6.260.3 6,262.3 A-4.1E-14 3/29/2014 3.0 APERF 120 DEGREE PHASING APERF;6,747,06,7490- t 6.853.0 6.859.0 6,364.8 6,370.7 A-5.1E-14 8/8/1982 8.0 IPERF 6.871.0 6.888.0 6,382.5 6,399.2 A-4,1E-14 8/8/1982 8.0 IPERF LOCATOR;6.7601 • g�, Cement Squeezes SEAL ASSY;6,762.2 -M Top(568) Elm KB) To (pRK(HB)D) Btm(RK(NB)D) Dec Start Date Corn PACKER;8,767.2 ` (R 6,633.0 6.790.01 6,147.9 6,302.7 Cement Plug 10/13/201 15BBLS OF 15.8 PPG UNISLURRY. MILLED TO Il 4 6790 10-24-2014 SEE:6,769.7 . . Mandrel Inserts X //JJ1 at n /''� n MILL 6,779.1 it I/ti o Top(TVD) Valve Latch Port Size TRO Run k / 4 el 'top(RKB) (RKB) Make Model OD(In) Sery Type Type (In) (psi) Run Date Corn 1 6,369.4 5,889.1 CAMCO KBUG 0.0 GAS LIFT OPEN 0.000 0.0 10/29/2014 5:30 ''ll1l:j CATCHER;6765.0 -2 6,5322 6.046.5 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 3/28/2014 11:30 SAND;6,7850 t-r 3 6,629.8 6.144.7 CAMCO KBUG 1 PROD OPEN BK 0.000 0.0 5/20/2014 2:00 Notes:General&Safety PLUG.6,795071 End Date Annotation 314/2011 NOTE.View Schematic w/Alaska Schematic9.0 NIPPLE:6.795 9 2/3.2013 'NOTE.DUMP BAILED 10'SILICA SAND ON CA-2 PLUG AT 6795'RKB SOS;6.807.4 i- (PERF,6,853.06.859.0 (PERF;6.871.0-6.888 0 PRODUCTION:28.9.7,168.5 flP1R11\101 iii M 1 `gtm i - - - i►-. f■■pi f ,ry -iF Wilii-•iiIiIW.:9Urra��iiii�irrii4'�iirrr7.�■iiii■mi �. �7T.�^...M.'nti^2c iZ B _ to m Z i. t!.� �r t `$. if.' +l• ~ '1641 _ _ }. 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U (a1/}41sn OSI) +)qliolsI/(-)44nos w ur\ i61NAL ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1E Pad 1E-14 1E-14L1 Plan: 1 E-14L1_wp05 Standard Planning Report 04 November, 2014 BAKER HUGHES ORIGINAL ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1 E-14 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-14 @ 105.70usft(1E-14) Site: Kuparuk 1 E Pad North Reference: True Well: 1E-14 Survey Calculation Method: Minimum Curvature Wellbore: 1E-14L1 Design: 1 E-14L1_wp05 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1 E Pad Site Position: Northing: 5,959,760.24 usft Latitude: 70°18'3.022 N From: Map Easting: 549,889.51 usft Longitude: 149°35'45.358 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.38 ° Well 1E-14 Well Position +N/-S 0.00 usft Northing: 5,960,150.10 usft Latitude: 70°18'6.868 N +E/-W 0.00 usft Easting: 549,710.48 usft Longitude: 149°35'50.502 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1E-14L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (') (°) (nT) BGG M2014 1/1/2015 19.11 80.92 57,573 Design 1E-14L1_wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 6,600.00 Vertical Section: Depth From(TVD) +NI-S +EI-W Direction (usft) (usft) (usft) (0) 0.00 0.00 0.00 160.00 11/4/2014 3:47:29PM Page 2 COMPASS 5000.1 Build 61 QRIGINM- Fri- ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1 E-14 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-14 @ 105.70usft(1E-14) Site: Kuparuk 1 E Pad North Reference: True Well: 1E-14 Survey Calculation Method: Minimum Curvature Wellbore: 1E-14L1 Design: 1 E-14L1_wp05 f Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100ft) 0100ft) (°/100ft) (°) Target 6,600.00 9.35 348.50 6,009.67 595.83 -1,619.27 0.00 0.00 0.00 0.00 6,675.00 9.56 346.32 6,083.65 607.85 -1,621.96 0.55 0.28 -2.91 -60.69 6,700.00 13.87 339.89 6,108.12 612.68 -1,623.48 18.00 17.25 -25.70 340.00 6,770.00 45.22 332.55 6,168.28 643.39 -1,638.19 45.00 44.78 -10.49 350.00 6,934.05 104.00 283.24 6,212.50 724.88 -1,759.81 45.00 35.83 -30.06 310.00 7,034.05 104.05 236.78 6,186.94 708.58 -1,852.42 45.00 0.05 -46.46 276.00 7,134.05 104.09 190.31 6,161.30 630.22 -1,904.38 45.00 0.03 -46.47 276.00 7,204.05 96.86 159.09 6,148.27 562.65 -1,897.88 45.00 -10.32 -44.60 260.00 7,404.05 94.08 151.56 6,129.18 381.90 -1,814.81 4.00 -1.39 -3.77 250.00 7,504.05 90.92 149.10 6,124.82 295.11 -1,765.36 4.00 -3.15 -2.46 218.00 7,804.05 90.90 137.09 6,120.03 55.69 -1,585.57 4.00 -0.01 -4.00 270.00 8,204.05 94.96 152.60 6,099.46 -269.79 -1,356.22 4.00 1.01 3.88 75.00 8,354.05 93.69 158.48 6,088.14 -405.88 -1,294.32 4.00 -0.85 3.92 102.00 8,754.05 90.13 174.09 6,074.73 -793.00 -1,199.87 4.00 -0.89 3.90 102.50 9,024.05 86.28 184.18 6,083.20 -1,062.43 -1,195.78 4.00 -1.43 3.74 111.00 9,124.05 89.75 182.18 6,086.67 -1,162.20 -1,201.32 4.00 3.47 -2.00 330.00 9,324.05 89.75 174.18 6,087.56 -1,361.93 -1,194.99 4.00 0.00 -4.00 270.00 9,624.05 89.75 186.18 6,088.87 -1,661.38 -1,195.95 4.00 0.00 4.00 90.00 9,900.00 78.72 186.18 6,116.55 -1,933.92 -1,225.48 4.00 -4.00 0.00 180.00 11/4/2014 3:47:29PM Page 3 COMPASS 5000.1 Build 61 ORIGINAL ri- ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1 E-14 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-14 @ 105.70usft(1E-14) Site: Kuparuk 1 E Pad North Reference: True Well: 1 E-14 Survey Calculation Method: Minimum Curvature Wellbore: 1E-14L1 Design: 1 E-14L1_wp05 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (') (') (usft) (usft) (usft) (usft) 0100ft) (°) (usft) (usft) 6,600.00 9.35 348.50 6,009.67 595.83 -1,619.27 -1,113.72 0.00 0.00 5,960,735.14 548,087.46 TIP 6,675.00 9.56 346.32 6,083.65 607.85 -1,621.96 -1,125.93 0.55 -60.69 5,960,747.14 548,084.69 KOP 6,700.00 13.87 339.89 6,108.12 612.68 -1,623.48 -1,131.00 18.00 -20.00 5,960,751.97 548,083.14 End 18 dls,Start 45 dls 6,770.00 45.22 332.55 6,168.28 643.39 -1,638.19 -1,164.88 45.00 -10.00 5,960,782.57 548,068.23 4 6,800.00 54.66 319.89 6,187.61 662.28 -1,651.04 -1,187.03 45.00 -50.00 5,960,801.38 548,055.25 6,900.00 91.20 291.76 6,217.01 714.73 -1,727.73 -1,262.54 45.00 -41.80 5,960,853.31 547,978.22 6,934.05 104.00 283.24 6,212.50 724.88 -1,759.81 -1,283.06 45.00 -32.95 5,960,863.25 547,946.08 5 7,000.00 105.09 252.58 6,195.56 722.63 -1,822.75 -1,302.46 45.00 -84.00 5,960,860.58 547,883.17 7,034.05 104.05 236.78 6,186.94 708.58 -1,852.42 -1,299.41 45.00 -91.88 5,960,846.34 547,853.59 6 7,100.00 105.14 206.11 6,169.94 661.41 -1,894.13 -1,269.35 45.00 -84.00 5,960,798.90 547,812.20 7,134.05 104.09 190.31 6,161.30 630.22 -1,904.38 -1,243.55 45.00 -91.91 5,960,767.64 547,802.16 7 7,200.00 97.36 160.86 6,148.77 566.42 -1,899.26 -1,181.85 45.00 -100.00 5,960,703.89 547,807.70 7,204.05 96.86 159.09 6,148.27 562.65 -1,897.88 -1,177.83 45.00 -105.61 5,960,700.12 547,809.10 End 45 dls,Start 4 dls 7,300.00 95.54 155.47 6,137.90 474.68 -1,861.05 -1,082.56 4.00 -110.00 5,960,612.41 547,846.52 7,400.00 94.13 151.71 6,129.47 385.45 -1,816.73 -983.56 4.00 -110.39 5,960,523.49 547,891.42 7,404.05 94.08 151.56 6,129.18 381.90 -1,814.81 -979.57 4.00 -110.71 5,960,519.95 547,893.36 9 7,500.00 91.05 149.20 6,124.89 298.59 -1,767.44 -885.08 4.00 -142.00 5,960,436.96 547,941.28 7,504.05 90.92 149.10 6,124.82 295.11 -1,765.36 -881.11 4.00 -142.11 5,960,433.50 547,943.38 10 7,600.00 90.92 145.26 6,123.28 214.51 -1,713.37 -787.58 4.00 -90.00 5,960,353.25 547,995.90 7,700.00 90.91 141.26 6,121.68 134.40 -1,653.56 -691.85 4.00 -90.06 5,960,273.54 548,056.22 7,800.00 90.90 137.26 6,120.09 58.66 -1,588.32 -598.36 4.00 -90.13 5,960,198.25 548,121.96 7,804.05 90.90 137.09 6,120.03 55.69 -1,585.57 -594.63 4.00 -90.19 5,960,195.30 548,124.73 11 7,900.00 91.89 140.80 6,117.69 -16.63 -1,522.58 -505.12 4.00 75.00 5,960,123.40 548,188.19 8,000.00 92.92 144.67 6,113.49 -96.13 -1,462.10 -409.73 4.00 75.09 5,960,044.30 548,249.19 8,100.00 93.93 148.55 6,107.52 -179.46 -1,407.18 -312.64 4.00 75.25 5,959,961.35 548,304.65 8,200.00 94.92 152.44 6,099.81 -266.22 -1,358.08 -214.33 4.00 75.48 5,959,874.93 548,354.32 8,204.05 94.96 152.60 6,099.46 -269.79 -1,356.22 -210.33 4.00 75.78 5,959,871.37 548,356.20 12 8,300.00 94.15 156.36 6,091.84 -356.09 -1,315.02 -115.15 4.00 102.00 5,959,785.35 548,397.97 8,354.05 93.69 158.48 6,088.14 -405.88 -1,294.32 -61.28 4.00 102.30 5,959,735.71 548,419.00 13 8,400.00 93.29 160.27 6,085.34 -448.80 -1,278.16 -15.42 4.00 102.50 5,959,692.89 548,435.44 8,500.00 92.41 164.18 6,080.37 -543.89 -1,247.68 84.36 4.00 102.61 5,959,598.02 548,466.55 8,600.00 91.52 168.08 6,076.95 -640.90 -1,223.73 183.71 4.00 102.80 5,959,501.18 548,491.14 8,700.00 90.62 171.98 6,075.08 -739.35 -1,206.42 282.14 4.00 102.94 5,959,402.85 548,509.09 8,754.05 90.13 174.09 6,074.73 -793.00 -1,199.87 334.79 4.00 103.01 5,959,349.26 548,516.00 14 8,800.00 89.47 175.80 6,074.89 -838.77 -1,195.82 379.19 4.00 111.00 5,959,303.52 548,520.35 8,900.00 88.04 179.54 6,077.05 -938.64 -1,191.76 474.43 4.00 110.99 5,959,203.68 548,525.07 9,000.00 86.62 183.28 6,081.71 -1,038.48 -1,194.21 567.41 4.00 110.91 5,959,103.84 548,523.28 9,024.05 86.28 184.18 6,083.20 -1,062.43 -1,195.78 589.38 4.00 110.74 5,959,079.88 548,521.88 11/4/2014 3:47:29PM Page 4 COMPASS 5000.1 Build 61 11 p, I INAL ConocoPhiIIips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1E-14 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-14 @ 105.70usft(1E-14) Site: Kuparuk 1E Pad North Reference: True Well: 1E-14 Survey Calculation Method: Minimum Curvature Wellbore: 1E-14L1 Design: 1 E-14L1_wp05 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 15 9,100.00 88.91 182.66 6,086.39 -1,138.18 -1,200.31 659.01 4.00 -30.00 5,959,004.12 548,517.85 9,124.05 89.75 182.18 6,086.67 -1,162.20 -1,201.32 681.23 4.00 -29.94 5,958,980.09 548,516.99 16 9,200.00 89.75 179.15 6,087.01 -1,238.14 -1,202.20 752.29 4.00 -90.00 5,958,904.16 548,516.61 9,300.00 89.75 175.15 6,087.45 -1,337.99 -1,197.23 847.83 4.00 -89.99 5,958,804.35 548,522.25 9,324.05 89.75 174.18 6,087.56 -1,361.93 -1,194.99 871.09 4.00 -89.97 5,958,780.42 548,524.64 17 9,400.00 89.75 177.22 6,087.89 -1,437.66 -1,189.30 944.20 4.00 90.00 5,958,704.74 548,530.83 9,500.00 89.75 181.22 6,088.33 -1,537.63 -1,187.94 1,038.60 4.00 89.99 5,958,604.79 548,532.85 9,600.00 89.75 185.22 6,088.77 -1,637.45 -1,193.56 1,130.48 4.00 89.97 5,958,504.94 548,527.89 9,624.05 89.75 186.18 6,088.87 -1,661.38 -1,195.95 1,152.15 4.00 89.95 5,958,481.00 548,525.66 18 9,700.00 86.71 186.18 6,091.21 -1,736.85 -1,204.13 1,220.27 4.00 -180.00 5,958,405.49 548,517.98 9,800.00 82.71 186.18 6,100.42 -1,835.82 -1,214.86 1,309.60 4.00 -180.00 5,958,306.46 548,507.91 9,900.00 78.72 186.18 6,116.55 -1,933.92 -1,225.48 1,398.15 4.00 -180.00 5,958,208.31 548,497.94 Planned TD at 9900.00 11/4/2014 3:47:29PM Page 5 COMPASS 5000.1 Build 61 ORIGINAL ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1E-14 Company: ConocoPhillips(Alaska)Inc.-Kupt TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 E-14 @ 105.70usft(1 E-14) Site: Kuparuk 1 E Pad North Reference: True Well: 1E-14 Survey Calculation Method: Minimum Curvature Wellbore: 1E-14L1 Design: 1 E-14L1_wp05 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (0) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 1E-14L1_T07 0.00 0.00 6,117.00 -9,725.671,138,890.80 5,957,960.00 1,688,530.00 70°2'29.523 N 140°27'35.894 W -plan misses target center by 1140108.14usft at 9500.00usft MD(6088.33 TVD,-1537.63 N,-1187.94 E) -Point 1E-14L1_T01 0.00 0.00 6,132.00 -7,380.401,138,286.24 5,960,301.00 1,687,910.00 70°2'53.181 N 140°27'43.000 W -plan misses target center by 1139489.16usft at 9500.00usft MD(6088.33 TVD,-1537.63 N,-1187.94 E) -Point 1 E-14L1_T04 0.00 0.00 6,075.00 -8,630.741,138,920.04 5,959,055.00 1,688,552.00 70°2'40.111 N 140°27'30.356 W -plan misses target center by 1140130.05usft at 9500.00usft MD(6088.33 TVD,-1537.63 N,-1187.94 E) -Point 1E-14 CTD Polygon 0.00 0.00 0.00 -7,239.81 1,138,503.20 5,960,443.00 1,688,126.00 70°2'54.228 N 140°27'36.228 W -plan misses target center by 1139721.67usft at 9500.00usft MD(6088.33 TVD,-1537.63 N,-1187.94 E) -Polygon Point 1 0.00 0.00 0.00 5,960,443.00 1,688,126.00 Point2 0.00 20.53 72.14 5,960,464.00 1,688,198.00 Point 3 0.00 184.15 -19.79 5,960,627.00 1,688,104.99 Point 4 0.00 237.78 -266.47 5,960,678.99 1,687,857.99 Point 5 0.00 144.50 -378.10 5,960,584.98 1,687,746.99 Point 6 0.00 -126.80 -337.87 5,960,313.98 1,687,789.01 Point 7 0.00 -489.60 -69.22 5,959,953.00 1,688,060.03 Point 8 0.00 -705.71 95.38 5,959,738.01 1,688,226.04 Point 9 0.00 -1,203.75 245.13 5,959,241.02 1,688,379.06 Point 10 0.00 -1,522.66 226.03 5,958,922.02 1,688,362.08 Point 11 0.00 -2,022.49 190.75 5,958,422.01 1,688,330.11 Point 12 0.00 -2,612.22 138.87 5,957,832.01 1,688,282.13 Point 13 0.00 -2,694.23 443.37 5,957,752.02 1,688,587.14 Point 14 0.00 -2,389.78 532.38 5,958,057.03 1,688,674.13 Point 15 0.00 -1,691.91 564.96 5,958,755.03 1,688,702.09 Point 16 0.00 -1,031.70 545.29 5,959,415.03 1,688,678.05 Point 17 0.00 -586.23 329.19 5,959,859.02 1,688,459.03 Point 18 0.00 -309.36 49.98 5,960,134.01 1,688,178.02 Point 19 0.00 -124.37 -98.83 5,960,317.99 1,688,028.00 Point 20 0.00 -31.14 -132.22 5,960,410.99 1,687,994.00 Point 21 0.00 0.00 0.00 5,960,443.00 1,688,126.00 1E-14L1_T05 0.00 0.00 6,084.00 -8,871.761,138,919.45 5,958,814.00 1,688,553.00 70°2'37.772 N 140°27'31.409 W -plan misses target center by 1140130.98usft at 9500.00usft MD(6088.33 TVD,-1537.63 N,-1187.94 E) -Point 1 E-14L1_T06 0.00 0.00 6,088.00 -9,304.871,138,927.58 5,958,381.00 1,688,564.00 70°2'33.555 N 140°27'33.040 W -plan misses target center by 1140141.99usft at 9500.00usft MD(6088.33 TVD,-1537.63 N,-1187.94 E) -Point 1 E-14L1_T03 0.00 0.00 6,099.00 -8,072.641,138,764.72 5,959,612.00 1,688,393.00 70°2'45.758 N 140°27'32.373 W -plan misses target center by 1139971.39usft at 9500.00usft MD(6088.33 TVD,-1537.63 N,-1187.94 E) -Point 1E-14L1_T02 0.00 0.00 6,117.00 -7,827.581,138,608.32 5,959,856.00 1,688,235.00 70°2'48.367 N 140°27'35.766 W -plan misses target center by 1139813.62usft at 9500.00usft MD(6088.33 TVD,-1537.63 N,-1187.94 E) -Point 1E-14L1_Faultl 0.00 0.00 0.00 -8,871.761,138,919.45 5,958,814.00 1,688,553.00 70°2'37.772 N 140°27'31.409 W -plan misses target center by 1140147.24usft at 9500.00usft MD(6088.33 TVD,-1537.63 N,-1187.94 E) -Rectangle(sides W345.00 H1.00 D0.00) 11/4/2014 3:47:29PM Page 6 COMPASS 5000.1 Build 61 ORIGINAL ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1E-14 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-14 @ 105.70usft(1E-14) Site: Kuparuk 1 E Pad North Reference: True Well: 1 E-14 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-14L1 Design: 1E-14L1_wp05 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 114.00 8.30 16" 16.000 24.000 2,333.00 2,227.23 10 3/4" 10.750 12.250 9,900.00 6,116.55 2-3/8" 2.375 3.000 Plan Annotations • Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 6,600.00 6,009.67 595.83 -1,619.27 TIP 6,675.00 6,083.65 607.85 -1,621.96 KOP 6,700.00 6,108.12 612.68 -1,623.48 End 18 dls,Start 45 dls 6,770.00 6,168.28 643.39 -1,638.19 4 6,934.05 6,212.50 724.88 -1,759.81 5 7,034.05 6,186.94 708.58 -1,852.42 6 7,134.05 6,161.30 630.22 -1,904.38 7 7,204.05 6,148.27 562.65 -1,897.88 End 45 dls,Start 4 dls 7,404.05 6,129.18 381.90 -1,814.81 9 7,504.05 6,124.82 295.11 -1,765.36 10 7,804.05 6,120.03 55.69 -1,585.57 11 8,204.05 6,099.46 -269.79 -1,356.22 12 8,354.05 6,088.14 -405.88 -1,294.32 13 8,754.05 6,074.73 -793.00 -1,199.87 14 9,024.05 6,083.20 -1,062.43 -1,195.78 15 9,124.05 6,086.67 -1,162.20 -1,201.32 16 9,324.05 6,087.56 -1,361.93 -1,194.99 17 9,624.05 6,088.87 -1,661.38 -1,195.95 18 9,900.00 6,116.55 -1,933.92 -1,225.48 Planned TD at 9900.00 11/4/2014 3:47:29PM Page 7 COMPASS 5000.1 Build 61 ORIGINAL ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1E Pad 1E-14 1E-14L1 1 E-14L1_wp05 Travelling Cylinder Report 04 November, 2014 BAKER HUGHES ORIGINAL Baker Hughes INTEQ Fa" ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1 E-14 Project: Kuparuk River Unit TVD Reference: 1E-14 @ 105.70usft(1E-14) Reference Site: Kuparuk 1 E Pad MD Reference: 1E-14 @ 105.70usft(1E-14) Site Error: 0.00usft North Reference: True Reference Well: 1E-14 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 1E-14L1 Database: OAKEDMP2 Reference Design: 1 E-14L1_wp05 Offset TVD Reference: Offset Datum Reference 1E-14L1_wp05 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 6,600.00 to 9,900.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,179.43usft Error Surface: Elliptical Conic Survey Tool Program Date 11/4/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description 200.00 6,600.00 1 E-14(1 E-14) BOSS-GYRO Sperry-Sun BOSS gyro multishot 6,600.00 9,900.00 1 E-14L1_wp05(1 E-14L1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 9,900.00 6,222.25 2-3/8" 2-3/8 3 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 11/4/2014 1:05:20PM Page 2 of 50 COMPASS 5000.1 Build 65 OB \ G\ N , \ L • Baker Hughes INTEQ Ird" ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1E-14 Project: Kuparuk River Unit TVD Reference: 1E-14 @ 105.70usft(1E-14) Reference Site: Kuparuk 1E Pad MD Reference: 1E-14 @ 105.70usft(1E-14) Site Error: 0.00usft North Reference: True Reference Well: 1E-14 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 1E-14L1 Database: OAKEDMP2 Reference Design: 1 E-14L1_wp05 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) *Kuparuk 1 E Pad 1 E-102-B-Lateral-B-Lat Actual Out of range 1 E-102-D-Lateral-D-Lat Actual Out of range 1E-104-Wellbore#1-Actual Surveys Out of range 1 E-112(D4)-A Lateral-Actual Surveys Out of range 1 E-112(D4)-B Lateral-B Lateral Out of range 1E-112(D4)-D Lateral-D Lateral Out of range 1E-114(C6)-A Lateral-A Lat Survey Out of range 1E-114(C6)-D Lateral-D Lat Survey Out of range 1E-119-Single Injector-Single Injector Out of range 1 E-121-B Lateral-B-Lat Survey Out of range 1E-121-D Lateral-D-Lat Survey Out of range 1E-123(X5)-B Lateral-B-Lat Survey Out of range 1E-123(X5)-D Lateral-D Lateral Survey Out of range 1 E-126(D5)-A Lateral-A Lateral Out of range 1E-126(D5)-B Lateral-B Lateral Out of range 1 E-126(D5)-D Lateral-D Lateral Out of range 1 E-166(E2)-A Lateral-A Lat Survey Out of range 1E-166(E2)-B Lateral-B Lat Survey Out of range 1 E-166(E2)-D Lateral-D Lat Survey Out of range 1 E-168-A Lateral-A Lat Survey Out of range 1E-168-B Lateral-B Lat Survey Out of range 1 E-168-D Lateral-D Lat Survey Out of range 1E-170-1E-170-1 E-170 Out of range 1E-170-1 E-170-A-Lat ST(wp05) Out of range 1 E-170-Plan 1E-170 L1-1 E-170 L1 (wp05) Out of range 1 E-170-Plan 1 E-170 L1-1E-170 L1 Rig Out of range 1 E-170-Plan 1E-170 L2-1 E-170 L2(wp05) Out of range 1 E-170-Plan 1 E-170 L2-1 E-170 L2 Rig Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 11/4/2014 1:05:20PM Page 3 of 50 COMPASS 5000.1 Build 65 ORIGINAL • Baker Hughes INTEQ • ✓ r ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinateReference: Well 1E-14 Project: Kuparuk River Unit TVD Reference: 1E-14 @ 105.70usft(1E-14) Reference Site: Kuparuk 1 E Pad MD Reference: 1 E-14 @ 105.70usft(1 E-14) Site Error: 0.00usft North Reference: True Reference Well: 1E-14 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 1E-14L1 Database: OAKEDMP2 Reference Design: 1 E-14L1_wp05 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Kuparuk 1E Pad 1E-01-1E-01-1E-01 Out of range 1E-01-1 E-01 PB1-1 E-01 PB1 Out of range 1 E-02-1 E-02-1 E-02 Out of range 1E-03-1 E-03-1 E-03 Out of range 1 E-04-1 E-04-1 E-04 Out of range 1 E-05-1 E-05-1E-05 Out of range 1E-05-1 E-05A-1 E-05A Out of range 1 E-05-1 E-05AL1-1 E-05AL1 Out of range 1E-05-1 E-05AL1 PB1-1 E-05AL1 PB1 Out of range 1 E-05-1 E-05AL2-1 E-05AL2 Out of range 1E-05-1 E-05AL2-01-1 E-05AL2-01 Out of range 1E-05-1 E-05AL2-02-1 E-05AL2-02 Out of range 1 E-05-1 E-05AL3-1 E-05AL3 Out of range 1E-06-1 E-06-1 E-06 7,792.24 6,700.00 197.06 142.06 54.98 Pass-Major Risk 1 E-06-Plan:1 E-06A-1 E-06A(wp02) 8,349.95 6,650.00 243.69 137.41 106.59 Pass-Major Risk 1E-07-1 E-07-1 E-07 Out of range 1 E-07-1E-07A-1 E-07A Out of range 1E-07-1 E-07AL1-1 E-07AL1 Out of range 1 E-07-1 E-07AL2-1 E-07AL2 Out of range 1 E-07-1 E-07AL2-01-1 E-07AL2-01 Out of range 1E-08-1 E-08-1 E-08 Out of range 1 E-08-1E-08A-1 E-08A Out of range 1E-08-1 E-08AL1-1 E-08AL1 Out of range 1E-08-1 E-08AL1-01-1 E-08AL1-01 Out of range 1E-08-1 E-08AL1-02-1 E-08AL1-02 Out of range 1E-08-1 E-08AL1-03-1 E-08AL1-03 Out of range 1 E-08-1 E-08AL2-1 E-08AL2 Out of range 1E-08-1E-08AL2-01-1 E-08AL2-01 Out of range 1E-10-1E-10-1E-10 Out of range 1E-11-1E-11-1 E-11 Out of range 1E-12-1E-12-1E-12 6,940.00 6,575.00 1,176.55 146.90 1,036.14 Pass-Major Risk 1E-12-1E-12L1-1E-12L1 6,940.00 6,575.00 1,176.55 146.71 1,036.33 Pass-Major Risk 1E-12-1E-12L1-01-1E-12L1-01 6,940.00 6,575.00 1,176.55 146.71 1,036.33 Pass-Major Risk 1 E-12-1 E-12L1 PB1-1 E-12L1 PB1 6,940.00 6,575.00 1,176.55 146.71 1,036.33 Pass-Major Risk 1 1E-12-1 E-12L2-1 E-12L2 6,900.00 8,460.00 982.20 159.48 822.74 Pass-Major Risk 1 E-12-1 E-12L2-01-1 E-12L2-01 6,800.00 9,150.00 632.73 177.23 456.83 Pass-Major Risk 1E-12-1 E-12L2-01 PB1-1 E-12L2-01 PB1 6,940.00 6,575.00 1,176.55 146.71 1,036.33 Pass-Major Risk 1E-12-1 E-12L2PB1-1 E-12L2PB1 6,790.00 9,140.00 664.15 179.05 487.59 Pass-Major Risk 1E-126-1E-126-1E-126 Out of range 1 E-126-1 E-126L1-1E-126L1 Out of range 1 E-126-1 E-126L2-1 E-126L2 Out of range 1E-13-1E-13-1E-13 Out of range 1E-14-1E-14-1E-14 6,675.00 6,675.00 0.00 1.97 -1.71 FAIL-Major Risk 1E-15-1E-15-1 E-15 7,180.00 6,700.00 1,035.72 120.73 926.40 Pass-Major Risk 1 E-15-1 E-15A-1 E-15A 7,180.00 6,700.00 1,035.72 120.53 926.60 Pass-Major Risk 1 E-15-1 E-15AL1-1 E-15AL1 7,180.00 6,700.00 1,035.72 120.53 926.60 Pass-Major Risk 1E-15-1 E-15AL2-1 E-15AL2 9,259.29 10,085.00 980.64 224.60 766.80 Pass-Major Risk 1 E-15-1 E-15AL2-01-1 E-15AL2-01 7,180.00 6,700.00 1,035.72 120.53 926.60 Pass-Major Risk 1E-15-1E-15AL2-PB1-1E-15AL2-PB1 9,124.05 9,836.00 1,118.51 206.68 921.12 Pass-Major Risk 1 E-15-1 E-15AL2-PB2-1 E-15AL2-PB2 9,300.00 10,135.00 1,090.95 220.37 881.11 Pass-Major Risk 1E-15-1 E-15AL2-PB3-1 E-15AL2-PB3 7,659.28 9,200.00 1,055.54 184.92 878.17 Pass-Major Risk 1E-16-1E-16-1E-16 Out of range 1E-17-1E-17-1E-17 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 11/4/2014 1:05:20PM Page 4 of 50, , COMPASS 5000.1 Build 65 U b ( IL , t Baker Hughes INTEQ IN"- ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1E-14 Project: Kuparuk River Unit TVD Reference: 1E-14©105.70usft(1E-14) Reference Site: Kuparuk 1E Pad MD Reference: 1E-14 @ 105.70usft(1E-14) Site Error: 0.00usft North Reference: True Reference Well: 1 E-14 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 1E-14L1 Database: OAKEDMP2 Reference Design: 1 E-14L1_wp05 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Kuparuk 1 E Pad 1 E-24-1 E-24BL2-1 E-24BL2 9,813.79 8,395.00 991.02 174.17 823.72 Pass-Major Risk 1 E-24-1 E-24BL2-02-1 E-24BL2-02 9,751.96 8,486.00 896.02 171.20 731.24 Pass-Major Risk 1 E-27-1E-27-1E-27 8,754.05 6,525.00 816.01 141.44 681.71 Pass-Major Risk 1E-27-1E-27L1-1E-27L1 8,700.00 6,525.00 737.70 140.50 601.31 Pass-Major Risk 1E-27-1E-27L1-01-1E-27L1-01 8,700.00 6,525.00 737.70 140.48 601.31 Pass-Major Risk 1 E-27-1 E-27L1-02-1 E-27L1-02 8,700.00 6,525.00 737.70 140.48 601.31 Pass-Major Risk 1 E-28-1 E-28-1 E-28 Out of range 1 E-28-1 E-28A-1 E-28A Out of range 1 E-28-1 E-28AL1-1 E-28AL1 Out of range 1 E-28-1 E-28AL1-01-1E-28AL1-01 Out of range 1 E-28-1 E-28AL2-1 E-28AL2 Out of range 1 E-28-1 E-28AL2-01-1 E-28AL2-01 Out of range 1E-28-1 E-28AL2PB1-1 E-28AL2PB1 Out of range 1 E-28-1 E-28AL3-1 E-28AL3 Out of range 1E-28-1 E-28APB1-1 E-28APB1 Out of range 1E-29-1E-29-1E-29 9,624.05 6,400.00 722.99 172.90 556.72 Pass-Major Risk 1 E-30-1 E-30-1 E-30 9,900.00 6,575.00 632.58 188.39 453.00 Pass-Major Risk 1E-31-1E-31-1E-31 Out of range 1 E-31-1 E-31 PB1-1 E-31 PB1 Out of range 1 E-32-1 E-32-1 E-32 Out of range 1 E-34-1 E-34-1 E-34 Out of range 1 E-36-1 E-36-1 E-36 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 11/4/2014 1:05:20PM Page 5 of 50 COMPASS 5000.1 Build 65 ow, G\ NAL • Baker Hughes INTEQ ri- ConoCoP'l'Ir ps Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1E-14 Project: Kuparuk River Unit TVD Reference: 1E-14 @ 105.70usft(1E-14) Reference Site: Kuparuk 1E Pad MD Reference: 1E-14 @ 105.70usft(1E-14) Site Error: 0.00usft North Reference: True Reference Well: 1 E-14 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 1 E-14L1 Database: OAKEDMP2 Reference Design: 1 E-14L1_wp05 Offset TVD Reference: Offset Datum Reference Depths are relative to 1 E-14 @ 105.70usft(1 E-14) Coordinates are relative to:1 E-14 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:0.38° Ladder Plot , 1200- - t ' , "IAAk - I I I I I I I a I WO I _ I I I 0 I LPI I I I U) 1 1 1 I f2 r�r� 1 I a) 6W I I I U 0 132 J J J ____J___f>,Th_3 __I C WW N U 0 300-- _ -_ - T v O J J __ 0 P 0 aro 4000 6000 8000 10000 12000 Measued Depth LEGEND -9- 1E-06,1 E-06,1 E-06 V1 -0- 1E-12,1E-12L2PB 1,1E-12L2PB 1 va -6- 1E-15,1E-15AL2-P83,1E-15AL2-PB3 V3 1E-06,Plan:1 E-06A,1 E-06A(wp02)VO $ 1E-14,1E-14,1E-14 V2 -6- 1E-24,1E-24BL2,1 E-24BL2 V0 1E-12,1E-12,1E-12 V 1 - 1E-15,1E-15,1E-15 V2 -34- 1E-24,1E-24BL2-02,1 E-24BL2-02 VO -E- 1E-12,1 E-12L1,1 E-12L1 VO -e- 1E-15,1 E-15A,1 E-15A VO -ati- 1E-27,1E-27,1E-27 V2 1E-12,1E-12L1-01,1E-12L1-01 VO -8- 1E-15,1E-15AL1,1 E-15AL1 VO 1E-27,1 E-27L1,1 E-27L1 V0 -X- 1E-12,1E-12L1PB1,1E-12L1PB1W -I- 1E-15,1E-15AL2,1E-15AL2V0 -e- 1E-27,1E-27L1-01,1E-27L1-01 V0 -B- 1 E-12,1 E-12L2,1 E-12L2 VO -4- 1E-15,1E-15AL2-01,1 E-15AL2-01 VO 1E-27,1 E-27L1-02,1 E-27L1-02 VO - 1E-12,1E-12L2-01,1E-12L2-01 VO -f- 1E-15,1E-15AL2-PB1,1 E-15AL2-PB1 W -8- 1E-29,1E-29,1E-29 V2 SAI- 1E-12.1 E-12L2-01 PB 1.1E-12L2-01PB 1 VO -4- 1 E-15.1 E-15AL2-PB2.1 E-15AL2-PB2\A -I- 1E-30.1E-30.1E-30 V 1 CC-Min centre to center distance orcovergent point,SFi-m' s paration factor,ES-min ellipse separation 11/4/2014 1:05:20PM 0 R I Pa i td COMPASS 5000.1 Build 65 s 1■■■■■■■■■■■■■■■$ I. atom 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TRANSMITTAL LETTER CHECKLIST WELL NAME: k R()., 1E - H1,1 PTD: 0,0) VDevelopment Service Exploratory Stratigraphic Test Non-Conventiona FIELD: Kr,.,\K N‘Ub.r POOL: K1/4. k I4L rV6.4J' Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit / (If last two digits No. / a —O?q , API No. 50- d�� - ao7Sl - 09 - co . in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Logging also required for this well: Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 Iii N m ° a) 0- p 1n N a a) o o m. . 3, N C Q c, co o ° O, C, .O-r m O ° o `s, , , a aM > E O a) a o ,,� ;c oi a, E ,aY 3, 0; •3, O 0, ', a)ca a �, °, °, _ III 6 3 N N o) a o g 3. a2. > y, a �, 7. a a) >, et 3, ° N, p c, a ° w E. 0 ar d' Z > :.+ , o, p Q .co, m W IDi c at ca G <0 yrp, o E os as 0. 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