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U d C) C) O CC 0 ''I 0 RECEIVED • STATE OF ALASKA S IA N 1 9 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil Gas❑ SPLUG❑ Other ❑ Abandoned ❑ Suspended❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 • Exploratory ❑ GINJ ❑ WINJ❑ WAG❑ WDSPL❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Susp., or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: %11go I%S LL 215-194/315-498 • 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 12/18/2015 0 50-029-21836-62-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 724 FNL, 1842 FWL,Sec 22,T13N, R9E, UM 12/19/2015 KRU 30-01AL3 Top of Productive Interval: 9. Ref Elevations: KB: 59 17. Field/Pool(s): 738 FNL, 1050 FEL,Sec. 16,T13N, R9E, UM GL: 24 BF:25 Kuparuk River Field/Kuparuk River Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 5160 FNL,2224FEL, Sec 9,T13N, R9E, UM 10985/6640 ADL 25513 .. 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 525478 y- 6022095 Zone- 4 11,001/6640 2554 TPI: x- 522558 y- 6027351 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 521380 y- 6028205 Zone- 4 n/a 1967/1840 5. Directional or Inclination Survey: Yes 0 (attached) No ❑ 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) 9492/6635 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 GR/Res 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 16 62.5 H-40 33 115 33 115 24 200 sx ASI I 9 5/8 36 J-55 35 5305 35 4066 12 1/4 1250 sx ASH, 370 sx CI G All cv ASI 7 26 J-55 35 9148 35 6871 8 1/2 200 sx Class G 2 38 4.7 L-80 8730 10985 6544 6640 3 Slotted Liner 24. Open to production or injection? Yes 0 No ❑ 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): 3 1/2 5400 5412 MD,4138 TVD Slotted Liner 8730-10985=MD,6544-6640=TVD 8480 MD, 6350 TVD COMPLETION 8666 MD. 6494 TVD ©AT 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11I1,a IS Was hydraulic fracturing used during completion? Yes❑ No 0 VERIFIED Per 20 AAC 25.283(i)(2)attach electronic and printed information L-• DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 12/29/2015 Gas Lift Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 1/12/2016 8hrs. Test Period -103 264 646 176 484 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 15P nsi 1046 24-Hour Rate -I 310 801 1958 20 API(1/17/2016) Form 10-407 Revised 11/2015 v.R.. l/ /l to CONTINUED ON,PAGE 2 RBDMS LA- JAN L 5 2016 Submit ORIGINIAL oiitr ry� di -lk a,I114Tic • • 28. CORE DATA Conventional Core(s): Yes ❑ No RI Sidewall Cores: Yes ❑ No RI 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 RI Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1967 1840 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 9492 6635 information, including reports, per 20 AAC 25.071. Kuparuk A3 9550 6626 D(Kuparuk A3) Formation at total depth: Kuparuk A3 31. List of Attachments: Operations Summary, Definitive Survey, Schematics Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, Paleontological report, production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Cody Pohler A 265-6435 Email: Cody.J.PohlerAcop.com l 4 00e1 Printed Name: D.Venhaus Title: CTD Engineering Supervisor Signature: q...• ��� �. vim" ?�-1 Z-- Phone: 263-4372 Date: / `/f —7.S % 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 1b: 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 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. Submit ORIGINAL Only KUP OOD 30-01AL3 C nocoPhillips fg' Well Attrib Max Ang.D TD Alolska.nc, Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ft B) Act Btm(ftKB) C.,,,Phitcps : 500292183662 KUPARUK RIVER UNIT PROD 103.95 9,300.69 --- ° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-01AL3,1/19/20168:21:39 AM 140 12/15/2015 Last WO: 34.98 8/5/1988 VedIsdtenla8cjeoWa<). Annotation Depth(ftKB) End Date Annotation Last Mod By End Date x Last Tag: Rev Reason:ADD LATERALS,GLV C/0 lehallf 1/8/2016 HANGER;33.2 ik.,,,!"in, "sing Hogs rr Casing Description 100 tint IID(in) I Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...I Grade Top Thread (pnr_a. "AL3Lateral Slotted 2 3/8 1.992 8,729.8 10,985.0 6,639 5 4.60 L-80 ST-L Liner II al Liner Details CONDUCTOR;33.0115.0 Nominal ID Top(ftKB) Top(ND)(ftKB)I Top Incl(1 Item Des I Com (in) NIPPLE;511.0 8,729.8 6,543 8 39.19 SLEEVE Shorty Deployment Sleeve 1.000 III Perforations&Slots Shot GAS LIFT;2,928.2it Dens Top( Btm(ND) (shots/ NJ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn III 8,730.0 10,985.0 6,543.9 6,639.5 A-1,30-01 12/19/2015 SLOTS GAS LIFT;4,697.1 Notes:General&Safety End Date Annotation 118/2016 NOTE: LATERALS 30-01A,30-01AL2.30-01AL3 ADDED,AL1 NOT DRILLED GAS LIFT;5,287.0 - SURFACE;34.63,305.0 I l NIPPLE;5,334.01111 t SLEEVE;5,368.1 11 LOCATOR;5,377.0 `f`' 111 SEAL ASSY;5,378.3_ SBE;5,381.7 i EMS w It PACKER;5,411.6 fit I PACKER;8,479.6 ra In NIPPLE;8,529.0 II OVERSHOT;8,568.5 III GAS LIFT;8,611.6 PBR;8,652.2 6 PACKER;8,685.9 -• (PERF;8,896.03,898.0I NIPPLE;8,701.4 11 1 1 SOS;8,735.2 L I I IPERF;8,832.0-8,847.0 Ill WHIPSTOCK-ANCHOR TRAY; I II 8,840.0 IPERF;8,8500.8,866.0 . IPERF;8,8900-8,910.0 FISH;9,000.0 . 1 III • PRODUCTION;35.2-9,148.0 --1a . SLOTS;9,180.010,180.0 "A"Lateral Slotted Liner;9,171 8 -11,200.0 SLOTS;8,730.0-10,985 0 "AL3"Lateral Slotted Liner, 8,729.8-10,985.0 • • 0 2 0 2 o Csi 2 io 0N V• O CO p O E , 2 OJa 'Oam -Ts CI _) O O2Mc) OVg T cc _ 0 to 06" WMF-!nJ 0 MC CU•a Q O O CD 1-1 O_ O©.0. " N pO o cv 00._ C M H_JM I-CO tf ' "o �t �t ;1 (D y= 00 ii jig '�I 2'73 ii O M m .yy ,+f 1, ( Y i ;1 N Co N Q' ttc N 0) N II n Y '1'.' � II U N o L0 CK m N y co Y Y s o , C V O CO m 6 .- N N p133 0 't O co YY .7:. (0 CO ONm ( 7�'gg to E 4] ih m o_o'+ ''1 i" d F- oo Y o m n. ol -O N M Q. 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Sp.-` - Nv M I-co 0 ,M horn co 0 7 m Co M <(0(0(0 io2Y ow o)@) 110:t tperations Summary (with Timelog epths) r1► 30-01 ConocOPhnhps II •Rig: NABORS CDR2-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) 12/7/2015 12/7/2015 3.00 MIRU MOVE MOB P Prep for rig move to 30-pad.Load and 0.0 0.0 03:00 06:00 secure tree.Check all tree bolts,found 4 loose bolts between SSV and Master. 1.25 hrs. """Note:Confirmed temp to be minus 33°, Able to keep working as per ConocoPhillips SOP. 12/7/2015 12/7/2015 2.00 MIRU MOVE MOB P Complete RD checklist,Pull pit sub 0.0 0.0 06:00 08:00 away from drilling sub.Prep shop for move.Prep for Sow arrival at 4am and rig move starting at 8:45am. 12/7/2015 12/7/2015 0.75 MIRU MOVE MOB P PJSM,Peak and rig crew, 0.0 0.0 08:00 08:45 continuously monitoring ambient temp as per Conoco SOP,currect temp 32 below zero, install jeeps,ready to move down the road. 12/7/2015 12/7/2015 3.00 MIRU MOVE MOB P Move Rig and Shop to 30-pad, 0.0 0.0 08:45 11:45 """"Note: IA valve stem gas leak, dispatch valve crew to repair stem packing. 12/7/2015 12/7/2015 4.00 MIRU MOVE MOB P Spot rig modules over 30-pad,Well 0.0 11:45 15:45 01.remove jeeps """"Note:No loose tree bolts to report, 0.5 hr. 12/7/2015 12/7/2015 2.75 MIRU MOVE RURD P RU checklist,RU interconnect(Putts), 0.0 0.0 15:45 18:30 connect ground to well head. 12/7/2015 12/7/2015 1.50 MIRU MOVE RURD P Nipple up BOPE stack,intall fusable 0.0 0.0 18:30 20:00 cap,open IA and OA, 12/7/2015 12/8/2015 4.00 MIRU WHDBOP RURD T Replace all BOPE door seals for 0.0 0.0 20:00 00:00 incident prevention in lou of previous o -ring failures. """"Note:Rig Accept at 20:00.... 12/8/2015 12/8/2015 2.00 MIRU WHDBOP RGRP T Continue to change out all door seals 0.0 0.0 00:00 02:00 on BOP 2 Hrs Nabors NPT 12/8/2015 12/8/2015 2.00 MIRU WHDBOP RURD P Continue rig up.swap out riser 0- 0.0 0.0 02:00 04:00 rings,Prep for BOPE test. 12/8/2015 12/8/2015 12.00 SLOT WHDBOP BOPE P Perform initial BOPE test 250/4,500 0.0 0.0 04:00 16:00 psi,annular 250/2,500 psi.Test waived by(AOGCC)Chuck S. 12/8/2015 12/8/2015 4.00 SLOT WELLPR CTOP P PJSM.Prep rig floor to cut coil.Cut 0.0 0.0 16:00 20:00 1,400'coil 12/8/2015 12/8/2015 2.50 MIRU WELLPR PRTS P PJSM,Test TT line,R/U and pull BPV 0.0 0.0 20:00 22:30 12/8/2015 12/9/2015 1.50 SLOT WELLPR MPSP P Rig down BPV lubricator and load out, 0.0 0.0 22:30 00:00 C/0 pack offs,Start filling coil 12/9/2015 12/9/2015 1.00 SLOT WELLPR CTOP P Complete filling coil,Pump slack,PT 0.0 0.0 00:00 01:00 and chart inner reel iron and pack offs 12/9/2015 12/9/2015 1.25 SLOT WELLPR CTOP P Cut 37 feet of CT back to find e-line. 0.0 0.0 01:00 02:15 1400'total 12/9/2015 12/9/2015 0.75 SLOT WELLPR PRTS P Pressure test PDL's.Good test. 0.0 0.0 02:15 03:00 1 Page 1/10 Report Printed: 1/14/2016 ' gperations Summary (with Timelogtpths) 0;:. 30-01 Ccxxxol4litlips Araks Rig: NABORS CDR2-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) 12/9/2015 12/9/2015 2.35 SLOT WELLPR CTOP P Rehead coil connector and pull test to 0.0 0.0 03:00 05:21 37klbs. Rehead UQC and test e-line. Test CC o-rings. 12/9/2015 12/9/2015 1.30 SLOT WELLPR CTOP P PJSM.Stab on,pump lack forward. 0.0 0.0 05:21 06:39 12/9/2015 12/9/2015 0.50 MIRU WHDBOP OWFF P Perform flow check,found leak on 0.0 0.0 06:39 07:09 BOP stack at 2 3/8"D.ram door seal. 12/9/2015 12/9/2015 1.00 MIRU WHDBOP RGRP T Troubleshoot BOP stack repair.Add 0.0 0.0 07:09 08:09 more torque to 2 3/8"door seal. NPT:1 Hour 12/9/2015 12/9/2015 1.00 MIRU WHDBOP BOPE P Function test BOPE,good test. 0.0 0.0 08:09 09:09 12/9/2015 12/9/2015 0.85 PROD1 RPEQPT PULD P PJSM.PU/MU BHA#1 with.9°AKO 0.0 62.5 09:09 10:00 motor and D331 mill with slick guage 12/9/2015 12/9/2015 2.50 PROD1 RPEQPT TRIP P RIH w/cement milling assembly while 62.5 8,110.0 10:00 12:30 pumping SW @ 1 bpm. 12/9/2015 12/9/2015 0.50 PROD1 RPEQPT DLOG P Start logging tie-in pass,log HRZ. 8,110.0 8,174.0 12:30 13:00 PUH to relog,wits problem. 12/9/2015 12/9/2015 2.50 PROD1 RPEQPT DLOG T Relog HRZ several times,having 8,174.0 8,500.0 13:00 15:30 MWD software problems,continue troubleshooting logging issues. 12/9/2015 12/9/2015 0.25 PROD1 RPEQPT DLOG P Log K1 for a+2.5 foot correction 8,500.0 8,605.0 15:30 15:45 12/9/2015 12/9/2015 0.50 PROD1 RPEQPT TRIP P RIH and tag cement at 8691' 8,605.0 8,691.0 15:45 16:15 12/9/2015 12/10/2015 7.75 PROD1 RPEQPT MILL P PUH and displace well over to 8,691.0 8,845.0 16:15 00:00 Seawater milling fluid.Begin milling cement pilot hole.Stall at 8834'. Continue milling. 12/10/2015 12/10/2015 1.25 PROD1 RPEQPT MILL P 8845'.Continue milling pilot hole to 8,845.0 8,860.0 00:00 01:15 planned depth of 8860'.ROP 20-25 FPH.20 FPH-20'above whipstock setting depth©8840 12/10/2015 12/10/2015 0.25 PROD1 RPEQPT MILL P Pull up hole and dry drfit transition 8,860.0 8,860.0 01:15 01:30 area.Clean drift. 12/10/2015 12/10/2015 1.70 PROD1 RPEQPT TRIP P Pull out of hole and LD BHA#1 8,860.0 72.0 01:30 03:12 12/10/2015 12/10/2015 1.30 PROD1 RPEQPT PULD P At surface,Flo check well 30 Min-Lay 72.0 0.0 03:12 04:30 down BHA#1,D331 out at 2.79"No- Go 12/10/2015 12/10/2015 1.50 PROD1 RPEQPT PULD P PJSM with HES caliper-Stab on well 0.0 0.0 04:30 06:00 to jet stack,shell test BOP stack, lower 2 3/8"door seal leaking. 12/10/2015 12/10/2015 4.00 PROD1 RPEQPT PULD T Troubleshoot door seal leak,change 0.0 0.0 06:00 10:00 door seal and retest as per town. Good test.Town decide to wait on new door seal.LD Halliburton caliper assembly in mousehole,release crew. Begin NAD NPT Time @ 06:00 End NAD NPT Time @ 16:15 12/10/2015 12/11/2015 14.00 PROD1 RPEQPT WAIT T Secure wellhead.Wait on new door 0.0 0.0 10:00 00:00 seal arrival.Prep stack for new seals. New door seals on location at 22:10. Page 2/10 Report Printed: 1/14/2016 o erations Summary (with Timelog Depths) 30-01 conocoPhiihps A1,,,ks Rig: NABORS CDR2-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) 12/11/2015 12/11/2015 2.50 PROD1 RPEQPT RGRP T Completed installation of new style 0.0 0.0 00:00 02:30 BOP door seals. Function test rams. Shell test BOP to 4,500 psi. End NAD NPT Time 12/11/2015 12/11/2015 1.50 PROD1 RPEQPT DLOG P Run Valve check list,PJSM with HES 0.0 22.0 02:30 04:00 to M/U caliper,M/U to end of coil and surface test caliper 12/11/2015 12/11/2015 2.25 PROD1 RPEQPT DLOG P RIH with caliper,tie-in log-6.5' 22.0 8,855.0 04:00 06:15 correction,RIH to 8,855'. 12/11/2015 12/11/2015 0.75 PROD1 RPEQPT DLOG P Caliber arms deployed,log up hole @ 8,855.0 8,150.0 06:15 07:00 40 FPM. 12/11/2015 12/11/2015 1.50 PROD1 RPEQPT DLOG P POOH w/caliper assembly 8,150.0 0.0 07:00 08:30 12/11/2015 12/11/2015 3.15 PROD1 RPEQPT DLOG P LD Halliburton BHA,set down on 0.0 0.0 08:30 11:39 master during pick-up,bent bow spring centralizer.Wait on caliper data to be downloaded&processed. 12/11/2015 12/11/2015 1.05 PROD1 RPEQPT PULD P PJSM.MU BHA#3 0.0 72.5 11:39 12:42 12/11/2015 12/11/2015 2.75 PROD1 RPEQPT WPST P RIH w/Baker XL WS tray,tie-in K1 72.5 8,851.0 12:42 15:27 marker for-13'correction,PUW @ 8,560'40K,continue in hole to set depth @ 8,851'.Close EDC,pressure up to 3,200 psi,release from WS, stack 3K down.TOWS @ 8,840', orientation 12 deg LOHS. 12/11/2015 12/11/2015 1.45 PROD1 RPEQPT TRIP P POOH for WS milling assembly 8,851.0 57.5 15:27 16:54 12/11/2015 12/11/2015 0.80 PROD1 RPEQPT PULD P Tag up,30 Min flow check,Lay down 57.5 0.0 16:54 17:42 BHA#3,Whipstock setting tools 12/11/2015 12/11/2015 1.20 PROD1 WHPST PULD P M/U BHA#4 Window milling with.6° 0.0 74.3 17:42 18:54 motor,2.79"string mill and 2.80" window mill.M/U to coil and surface test tool 12/11/2015 12/11/2015 1.50 PROD1 WHPST TRIP P RIH,EDC closed,Pump min rate 74.3 8,540.0 18:54 20:24 12/11/2015 12/11/2015 0.30 PROD1 WHPST DLOG P Log K1 for-13'correction,Get rates 8,540.0 8,619.0 20:24 20:42 above cement top, 1.6 BPM @ 2500PSI FS,PUW=39K 12/11/2015 12/11/2015 0.30 PROD1 WHPST TRIP P Continue in well,dry tag whipstock @ 8,619.0 8,841.0 20:42 21:00 8841,PUW=39K 12/11/2015 12/12/2015 3.00 PROD1 WHPST WPST P Bring pumps on 1.6BPM @ 2500 PSI 8,841.0 8,842.0 21:00 00:00 FS,RIH to mill.Begin milling window per procedure.Observed some motor stalls while establishing the window. Started milling from pinch point at 8840.3 ft. 12/12/2015 12/12/2015 5.50 PROD1 WHPST WPST P 8842 ft.Continue milling window per 8,842.0 8,846.0 00:00 05:30 drilling procedure.WOB 1.7klbs pumping 1.6 BPM at 2500 psi pump pressure. 12/12/2015 12/12/2015 2.00 PROD1 WHPST WPST P Continue milling window @ 2 fph as 8,846.0 8,850.5 05:30 07:30 per well plan. 1.6 BPm @ 2,450 psi. Minimal formation sand in returns. 12/12/2015 12/12/2015 1.00 PROD1 WHPST WPST P Drill rathole: 1.60 BPM @ 2,415 PSI, 8,850.5 8,862.0 07:30 08:30 BHP=3,405 PSI,CTW=10.5K, WOB=2K,ROP=10.0.Still not seeing much formation sand in returns,did get some crude. Page 3/10 Report Printed: 1/14/2016 0,,, operations Summary (with Timelogipths) tz 30-01 CocoP €►ohillips Rig: NABORS CDR2-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) 12/12/2015 12/12/2015 3.25 PROD1 WHPST 'REAM T Make back reaming passes to the 8,862.0 8,862.0 08:30 11:45 right,PUH,shut down pump,dry drift. Stack-out four times above window. PUH,call town for input,try it with pump up.Bring pump online,RBIH,no issues through WS.PUH for pump issues. 12/12/2015 12/12/2015 1.50 PROD1 WHPST REAM T Make three more back reaming 8,862.0 8,862.0 11:45 13:15 passes,PUH.Shut down pump,dry drift twice,clean. 12/12/2015 12/12/2015 2.00 PROD1 WHPST TRIP P POOH for build drilling assembly 8,862.0 63.5 13:15 15:15 12/12/2015 12/12/2015 0.25 PROD1 WHPST OWFF P Flow check,wellhead preesure 63.5 63.5 15:15 15:30 coming. 12/12/2015 12/12/2015 1.75 PROD1 WHPST PULD P PJSM.PUD BHA#4 63.5 0.0 15:30 17:15 12/12/2015 12/12/2015 2.25 PROD1 DRILL PULD P PJSM.MU/PD BHA#5,0.6°AKO 0.0 0.0 17:15 19:30 motor and rebuilt HCC bi-center bit. 12/12/2015 12/12/2015 3.25 PROD1 DRILL TRIP P RIH with BHA#5. 0.0 8,862.0 19:30 22:45 12/12/2015 12/12/2015 1.00 PROD1 DRILL SVRG P Service rig,prepare to drill ahead. 8,862.0 8,862.0 22:45 23:45 12/12/2015 12/13/2015 0.25 PROD1 DRILL DRLG P 8862 ft.After clean trip through 8,862.0 8,870.0 23:45 00:00 window,tag bottom at 8862 ft.Begin drilling build section.Displace viscosified seawater with 8.9 ppg flo- pro while drilling. 12/13/2015 12/13/2015 5.25 PROD1 DRILL DRLG P 8870 ft.Continue drilling build section. 8,870.0 9,005.0 00:00 05:15 New mud at bit at 8875 ft.End of build called at 9005 ft.Ankerite @ 8,909' broke free @ 8,914'. 12/13/2015 12/13/2015 1.75 PROD1 DRILL TRIP P POOH for lateral drilling assembly,tag 9,005.0 65.5 05:15 07:00 up,space-out. 12/13/2015 12/13/2015 2.50 PROD1 DRILL PULD P PJSM.PUD BHA#5,LD BHA. 65.5 0.0 07:00 09:30 Maintenance injector&BOP,pump slack,change-out UQC,test E-Line. 12/13/2015 12/13/2015 2.50 PROD1 DRILL PULD P PJSM.MU/PD BHA#6,service choke 0.0 72.5 09:30 12:00 as well. 12/13/2015 12/13/2015 1.50 PROD1 DRILL TRIP P RIH w/lateral drilling assembly,0.5°+ 72.5 8,535.0 12:00 13:30 AKO motor,new Hycalog bit. 12/13/2015 12/13/2015 0.25 PROD1 DRILL DLOG P Tie-in to K1 marker at 8521 ft for a- 8,535.0 8,571.0 13:30 13:45 12.5 ft correction. 12/13/2015 12/13/2015 0.50 PROD1 DRILL TRIP P Continue to RIH to EOB at 9005 ft. 8,571.0 9,006.0 13:45 14:15 12/13/2015 12/13/2015 0.50 PROD1 DRILL DLOG P Tag bottom ay 9005 ft.MAD pass up 9,006.0 8,865.0 14:15 14:45 through build section for resistivity data. 12/13/2015 12/13/2015 5.25 PROD1 DRILL DRLG P RBIH and continue drilling the lateral. 9,005.0 9,410.0 14:45 20:00 1.59 BPM @ 3,590 PSI FSI, BHP=4,110 PSI,CTW=10.5K, WOB=2K,ROP=70-120 FPH. 12/13/2015 12/13/2015 0.50 PROD1 DRILL WPRT P Wiper trip#1 to the window.PUW= 9,410.0 9,410.0 20:00 20:30 33 Klbs. 12/13/2015 12/14/2015 3.50 PROD1 DRILL DRLG P BOBD.1.6 BPM at 3822 PSI FS. 9,410.0 9,713.0 20:30 00:00 BHP=4154 PSI.WOB= 1.8 Klbs. ROP 70 FPH. Page 4/10 Report Printed: 1/14/2016 I • oil Operations Summary (with Timelog Depths) rE3 30-01 ConocoPhiliips Akrks Rig: NABORS CDR2-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) 12/14/2015 12/14/2015 1.00 PROD1 DRILL DRLG P Continue drilling lateral from 9713 ft to 9,713.0 9,810.0 00:00 01:00 9810 ft. 12/14/2015 12/14/2015 0.50 PROD1 DRILL WPRT P PUH for wiper trip to 9,000 ft.RBIH 9,810.0 9,810.0 01:00 01:30 and continue drilling. 12/14/2015 12/14/2015 2.00 PROD1 DRILL DRLG P Continue drilling lateral from 9810 ft to 9,810.0 10,031.0 01:30 03:30 10031 ft. 1.56 BPM,3700 psi FS.BHP=4200 psi.ROP 100-150 FPH. 12/14/2015 12/14/2015 0.50 PROD1 'DRILL DRLG T Observed pump pressure increase of 10,031.0 10,038.0 03:30 04:00 300 psi. PUH and pump sweeps. Attempt to drill additional footage. Stalled out.PUH with motor still in stalled condition. Shut off pumps. Brought pumps back up to minimum rate.Pump pressure high and erratic. Pump pressure 3500 psi FS at 0.25 BPM. 12/14/2015 12/14/2015 1.00 PROD1 DRILL CIRC T Begin pumping out of the hole at 0.7 10,038.0 10,038.0 04:00 05:00 BPM and 2650 psi FS. Differential pressure is 630 psi. 12/14/2015 12/14/2015 2.50 PROD1 DRILL TRIP T POOH to check motor,open EDC. 10,038.0 72.5 05:00 07:30 Tag-up 12/14/2015 12/14/2015 1.00 PROD1 DRILL PULD T PJSM.PUD BHA#6,LD motor,bit 72.5 0.0 07:30 08:30 nozzle plug with motor rubber,able to use air to blow free. 12/14/2015 12/14/2015 0.50 PROD1 DRILL BOPE T Function test BOP 0.0 0.0 08:30 09:00 12/14/2015 12/14/2015 3.00 PROD1 DRILL 'PULD T PJSM.MU/PU BHA#7 with new 0.0 72.5 09:00 12:00 motor and new bit. 12/14/2015 12/14/2015 1.00 PROD1 DRILL TRIP T RIH w/drilling assembly,tie-in to K1 72.5 10,040.0 12:00 13:00 for-12.5'correction,continue in hole, tag up @ 10,040'.PUW=31K. 12/14/2015 12/14/2015 5.00 PROD1 DRILL DRLG P BOBD: 1.59 BPM @ 3,850 PSI, 10,040.0 10,440.0 13:00 18:00 BHP=4,195 PSI,CTW=10.5K, WOB=2K,ROP=90. 12/14/2015 12/14/2015 1.50 PROD1 DRILL WPRT P Wiper trip to window. RIH and tie in to 10,440.0 10,440.0 18:00 19:30 whipstock RA for+1.5 ft correction. 12/14/2015 12/14/2015 4.00 PROD1 DRILL DRLG P Continue drilling ahead from 10,440 ft 10,440.0 10,840.0 19:30 23:30 to 10,840 ft. Mud swap. New mud at bit at 10,636 ft. 1.6 bpm at 3880psi FS.BHP=4241 psi.WOB=1.6klbs ROP 80-140 FPH 12/14/2015 12/15/2015 0.50 PROD1 DRILL WPRT P Wiper trip from 10840 ft to 9900 ft. 10,840.0 10,840.0 23:30 00:00 PUW=30klbs. 12/15/2015 12/15/2015 0.25 PROD1 DRILL WPRT P Finish short wiper.Hole appears to be 10,840.0 10,840.0 00:00 00:15 in good shape. 12/15/2015 12/15/2015 3.75 PROD1 DRILL DRLG P Continue drilling ahead from 10,840 ft 10,840.0 10,965.0 00:15 04:00 to 10965 ft. ROP 80-120 FPH with occasional ankerite drilled at 3-5 FPH. Pumping 1.6 BPM at 3,711 psi FS. BHP=4300 psi.WOB 1.7klbs. Page 5/10 Report Printed: 1/14/2016 0. 0 Operations Summary (with Timelog Depths) 30-01 Conoco Phillips ALv.k.. Rig: NABORS CDR2-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) 12/15/2015 12/15/2015 4.90 PROD1 DRILL DRLG P Continue drilling drill ahead: 1.59 BPM 10,965.0 11,200.0 04:00 08:54 @ 4,150 PSI,BHP=4,285 PSI, CTW=4.5K,WOB=1.7K,ROP=60. Extended TD to 11,200',last 50'or so showed CTW at-1K.TD depth @ 11,200'. 12/15/2015 12/15/2015 4.50 PROD1 DRILL WPRT P Pump 10 bbl to/hi vis sweeps,chase 11,200.0 65.5 08:54 13:24 to swab,did jog back in hole @ 500', choke loading up,circulate to till clean, POOH. 12/15/2015 12/15/2015 1.75 PROD1 DRILL TRIP P RBIH for corrected TD,tie-in K1 65.5 11,201.0 13:24 15:09 marker for-12.5'correction,tag corrected TD @ 11.201'. 12/15/2015 12/15/2015 3.25 PROD1 DRILL DISP P POOH laying in 40 bbl beaded liner/ 11,201.0 72.2 15:09 18:24 completion fluid.Paint EOP flags @ 6,772'and 9,195'.Continue OOH. 12/15/2015 12/15/2015 0.50 PROD1 DRILL OWFF P Monitor well for flow. PJSM-LD BHA 72.2 72.2 18:24 18:54 12/15/2015 12/15/2015 0.80 PROD1 DRILL PULD P LD BHA#7,bit condition 1-1-CT-N-X-I 72.2 0.0 18:54 19:42 -BU-TD 12/15/2015 12/15/2015 0.60 COMPZ1 CASING PUTB P Prep floor to run liner,PJSM-pick up 0.0 0.0 19:42 20:18 liner 12/15/2015 12/15/2015 2.70 COMPZ1 CASING PUTB P MU"A"lateral liner assembly,non- 0.0 2,028.2 20:18 23:00 ported bullnose-2 pups,65 jts slotted, aluminum billet. 12/15/2015 12/16/2015 1.00 COMPZ1 CASING PULD P MU"A"lateral liner assembly to BHA 2,028.2 2,072.5 23:00 00:00 #8,change out checks,MU to CoilTrak,surface test. 12/16/2015 12/16/2015 0.75 COMPZ1 CASING PUTB T Surface testing BHA#8,surface 2,072.5 2,072.5 00:00 00:45 equipment,software.Wrong telemetry file,troubleshooting MWD computers. 12/16/2015 12/16/2015 2.75 COMPZ1 CASING RUNL P RIH with BHA#8 and liner assembly, 2,072.5 11,200.0 00:45 03:30 tie-in to first flag for-16 ft correction, PUW 34k,continue in hole,CWT 13k on bottom. 12/16/2015 12/16/2015 0.15 COMPZ1 CASING RUNL P 11,200 ft, Tag up,PUW 37k,stack 5k, 11,200.0 9,171.0 03:30 03:39 release off liner 1.3 bpm at 3,874 psi, PUW 30k,WOB lost 4k,reset counters. 12/16/2015 12/16/2015 1.70'COMPZ1 CASING TRIP P POOH for drilling assembly. 9,171.0 44.2 03:39 05:21 12/16/2015 12/16/2015 0.50 COMPZ1 CASING OWFF P Monitor well for flow. 44.2 44.2 05:21 05:51 12/16/2015 12/16/2015 1.35 COMPZ1 CASING PULD P PJSM.LD BHA#8 44.2 0.0 05:51 07:12 12/16/2015 12/16/2015 0.70 PROD2 STK PULD P PJSM.MU BHA#9 0.0 72.2 07:12 07:54 12/16/2015 12/16/2015 2.25 PROD2 STK TRIP P RIH w/KO drilling assembly,0.7 AKO 72.2 9,171.0 07:54 10:09 motor,RR HYC bit.Tie-in to K1 marker for-13'correction,dry tag billet @ 9,171'. 12/16/2015 12/16/2015 1.60 PROD2 STK DISP P Circulate hole back to 8.9 ppg drilling 9,171.0 9,171.0 10:09 11:45 mud. 12/16/2015 12/16/2015 0.40 PROD2 STK TRIP P PUH to just below window @ 8,860', 9,171.0 9,171.0 11:45 12:09 get pressure reading at drilling parameters,choke pressure 275 psi. RBIH. Page 6/10 Report Printed: 1/14/2016 i • 0,',i,.;. Operations Summary (with Timelog Depths) Amt 30-01 ConocoPhiiiips PoL•eks Rig: NABORS CDR2-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) 12/16/2015 12/16/2015 1.10 PROD2 STK KOST P Time mill off billet,1.59 BPM @ 3,920 9,171.0 9,175.0 12:09 13:15 psi,BHP=4,100 psi,CTW=11.5K, WOB=1 K,ROP=5.Off billet,lots of aluminum across shaker. 12/16/2015 12/16/2015 0.50 PROD2 DRILL DRLG P Drill ahead: 1.59 BPM @ 3,920 psi, 9,175.0 9,200.0 13:15 13:45 BHP=4,105 psi,CTW=11.2K, WOB=1 K,ROP=25.Dry drift billet, clean. 12/16/2015 12/16/2015 3.25 PROD2 DRILL DRLG P Drill ahead: 1.65 BPM @ 4,125 psi, 9,200.0 9,570.0 13:45 17:00 BHP=4,125 psi,CTW=10.8K, WOB=1.4K,ROP=125. 12/16/2015 12/16/2015 0.45 PROD2 DRILL WPRT P Short wiper trip to 8,875 ft,PUW 31k 9,570.0 8,875.0 17:00 17:27 12/16/2015 12/16/2015 0.40 PROD2 DRILL WPRT P Wiper trip back in hole, RIW 11k 8,875.0 9,570.0 17:27 17:51 12/16/2015 12/16/2015 3.10 PROD2 DRILL DRLG P 9,570 ft, OBD 1.62 bpm at 3,840 psi 9,570.0 9,970.0 17:51 20:57 FS,BHP 4,120 psi,CWT 9k,WOB 1.0k,ROP 160,WHP 244,IA 200,OA 260 12/16/2015 12/16/2015 0.50 PROD2 DRILL WPRT P Wiper to window for tie in,PUW 30k 9,970.0 8,860.0 20:57 21:27 12/16/2015 12/16/2015 0.15 PROD2 DRILL DLOG P Tie in to RA for plus 1.5 ft correction. 8,860.0 8,890.0 21:27 21:36 12/16/2015 12/16/2015 0.35 PROD2 DRILL WPRT P Wiper back in hole,RIW 9k 8,890.0 9,970.0 21:36 21:57 12/16/2015 12/17/2015 2.05 PROD2 DRILL DRLG P 9,970 ft, OBD 1.60 bpm at 3,860 psi 9,970.0 10,140.0 21:57 00:00 FS,BHP 4,170 psi,CWT 9.5k,WOB 1.2k,ROP 90,WHP 220, IA 236,OA 266 12/17/2015 12/17/2015 2.00 PROD2 DRILL DRLG P 10,140 ft, OBD 1.58 bpm at 3,979 psi, 10,140.0 10,380.0 00:00 02:00 BHP 4,180 psi,CWT 9.2k,WOB 1.9k, ROP 120,WHP 224, IA 326,OA 269 Note:Begin mud swap. 12/17/2015 12/17/2015 0.40 PROD2 DRILL WPRT P Wiper trip to 9,300 ft,PUW 31k 10,380.0 9,300.0 02:00 02:24 12/17/2015 12/17/2015 0.40 PROD2 DRILL WPRT 'P Wiper trip in hole,RIW 10.2k. 9,300.0 10,380.0 02:24 02:48 12/17/2015 12/17/2015 2.50 PROD2 DRILL DRLG P 10,380 ft, OBD 1.60 bpm at 3,955 psi, 10,380.0 10,790.0 02:48 05:18 BHP 4,212 psi,CWT 9.0k,WOB 1.0k, ROP 160,WHP 242, IA 368,OA 270 Note:New 8.9 ppg mud at bit at 10,445 ft. 12/17/2015 12/17/2015 1.00 PROD2 DRILL WPRT P Wiper,short trip,PUW 31k,RBIH. 10,790.0 10,790.0 05:18 06:18 12/17/2015 12/17/2015 2.25 PROD2 DRILL DRLG P BOBD:1.64 BPM @ 4,265 PSI, 10,790.0 11,200.0 06:18 08:33 BHP=4,275 PSI,CTW=4.5K, WOB=1.2K,ROP=182.Called TD @ 11,200'. 12/17/2015 12/17/2015 2.50 PROD2 DRILL WPRT P Pump 10 bbl to/hi vis sweeps,chase 11,200.0 65.5 08:33 11:03 to swab.Had to jog back @ 300',clear choke,POOH,reset depth. 12/17/2015 12/17/2015 3.50 PROD2 DRILL TRIP P RBIH for corrected TD.Tie-in to K1 65.5 11,201.0 11:03 14:33 marker for-13.5'correction,continue in hole,tag corrected TD @ 11,201. Wait for liner pill. Page 7/10 Report Printed: 1/14/2016 0t Operations Summary (with Timelog Depths) 30-01 Co€ocol hillips A(.,.ks Rig: NABORS CDR2-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) 12/17/2015 12/17/2015 2.40 PROD2 DRILL DISP P POOH laying in liner pill/completion 11,201.0 72.2 14:33 16:57 fluid.Paint EOP flags @ 7,000'& 9,451',continue OOH. 12/17/2015 12/17/2015 0.50 PROD2 DRILL OWFF P Flow check,PJSM-LD BHA 72.2 72.2 16:57 17:27 12/17/2015 12/17/2015 0.80 PROD2 DRILL PULD P LD BHA#9,Bit condition 1-1-ER-N-X-I 72.2 0.0 17:27 18:15 -N-TD 12/17/2015 12/17/2015 0.50 COMPZ2 CASING PUTB P Prep floor to run liner,PJSM-picking 0.0 0.0 18:15 18:45 up liner. 12/17/2015 12/17/2015 2.00 COMPZ2 CASING PUTB P MU"AL2"lateral liner assembly,non- 0.0 1,708.4 18:45 20:45 ported bullnose,55 jts slotted, aluminum billet. 12/17/2015 12/17/2015 0.70 COMPZ2 CASING PULD P MU"AL2"lateral liner assembly to 1,708.4 1,752.6 20:45 21:27 BHA#10,change out checks,MU to CoilTrak,surface test. 12/17/2015 12/17/2015 2.25 COMPZ2 CASING RUNL P RIH with BHA#10 and liner assembly, 1,752.6 11,200.0 21:27 23:42 tie-in to first flag for minus 17 ft. correction,PUW 34k,continue in hole. 12/17/2015 12/17/2015 0.15 COMPZ2 CASING RUNL P 11,200 ft, Tag up,PUW 34k,stack 5k, 11,200.0 9,491.0 23:42 23:51 release off liner 1.4 bpm at 4,000 psi, PUW 31k,WOB lost 3.2k,reset counters. 12/17/2015 12/18/2015 0.15 COMPZ2 CASING TRIP P POOH for drilling BHA 9,491.0 9,100.0 23:51 00:00 12/18/2015 12/18/2015 1.50 COMPZ2 CASING TRIP P POOH for drilling BHA 9,100.0 44.2 00:00 01:30 12/18/2015 12/18/2015 0.50 COMPZ2 CASING OWFF P Monitor well for flow.PJSM-LD BHA 44.2 44.2 01:30 02:00 12/18/2015 12/18/2015 0.75 COMPZ2 CASING PULD P LD BHA#10 44.2 0.0 02:00 02:45 12/18/2015 12/18/2015 0.90 PROD3 STK PULD P PJSM-MU BHA#11,0.7 AKO motor 0.0 72.2 02:45 03:39 and RB HCC bi-center bit,MU to CoilTrak,surface test. 12/18/2015 12/18/2015 2.25 PROD3 STK TRIP P RIH with KO drilling assembly,tie in at 72.2 9,493.0 , 03:39 05:54 K1 for minus 12.5 ft.correction, PUW 31k,continue in hole,dry tag billet at 9,493'. 12/18/2015 12/18/2015 1.00 PROD3 STK DISP P PUH.Displace well back to 8.9# 9,493.0 9,493.0 05:54 06:54 drilling mud. 12/18/2015 12/18/2015 3.80 PROD3 STK KOST P Time mill off billet to 9,395', 1.59 BPM 9,493.0 9,495.0 06:54 10:42 @ 3,870',CTW=12K,WOB=.8K, ROP=1.Total of four stalls. 12/18/2015 12/18/2015 3.75 PROD3 DRILL DRLG P Drill ahead: 1.59 BPM @ 4,085,BHP= 9,495.0 9,910.0 10:42 14:27 4,130 PSI,CTW=11K,WOB=1.5K, ROP=110.Dry drift through billet clean. 12/18/2015 12/18/2015 0.90 PROD3 DRILL WPRT P Short wiper trip,PUW=30K,RBIH. 9,910.0 9,910.0 14:27 15:21 12/18/2015 12/18/2015 2.60 PROD3 DRILL DRLG P Drill ahead: 1.60 BPM @ 4,160,BHP= 9,910.0 10,310.0 15:21 17:57 4,190 PSI,CTW=9K,WOB=1.6K, ROP=180. 12/18/2015 12/18/2015 0.85 PROD3 DRILL WPRT P Wiper to window,PUW 30k 10,310.0 8,860.0 17:57 18:48 12/18/2015 12/18/2015 0.10 PROD3 DRILL DLOG P Tie in to RA marker for plus 2 ft. 8,860.0 8,885.0 18:48 18:54 correction. 12/18/2015 12/18/2015 0.70 PROD3 DRILL WPRT P Wiper back in hole.RIW 10.1k 8,885.0 10,310.0 18:54 19:36 Page 8/10 Report Printed: 1/14/2016 .0:', ¶eratuons 1 Summary (with Timelog Depths) e 30-01 ConocoPhillips Rig: NABORS CDR2-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) 12/18/2015 12/18/2015 3.00 PROD3 DRILL DRLG P 10,310 ft. OBD 1.6 bpm at 4,123 psi, 10,310.0 10,710.0 19:36 22:36 BHP 4,196 psi,CWT 9.6k,WOB 1.7k, ROP 180,WHP 222, IA 299,OA 262. Note:Mud swap,new 8.9 ppg mud at bit at 10,460 ft.System 3 finished with 1,724 ft.drilled and.85%solids. 12/18/2015 12/18/2015 0.40 PROD3 DRILL WPRT P Wiper,short trip, PUW 31k 10,710.0 9,600.0 22:36 23:00 12/18/2015 12/18/2015 0.40 PROD3 DRILL WPRT P Wiper back in hole,RIW 9.0k 9,600.0 10,710.0 23:00 23:24 12/18/2015 12/19/2015 0.60 PROD3 DRILL DRLG P 10,710 ft. OBD 1.57 bpm at 4,223 psi, 10,710.0 10,765.0 23:24 00:00 BHP 4,240 psi,CWT 4.2k,WOB 2.1k, ROP 100,WHP 256, IA 212,OA 256. 12/19/2015 12/19/2015 3.25 PROD3 DRILL DRLG P 10,765 ft. OBD 1.57 bpm at 4,223 psi, 10,765.0 11,000.0 00:00 03:15 BHP 4,240 psi,CWT 4.2k,WOB 2.1k, ROP 50,WHP 256,IA 212,OA 256. TD called at 11,000 ft. 12/19/2015 12/19/2015 2.50 PROD3 DRILL WPRT P 11,000 ft.Pump 10 bbl to/hi vis 11,000.0 72.2 03:15 05:45 sweeps,chase to swab.reset counters. 12/19/2015 12/19/2015 3.15 PROD3 DRILL TRIP P RBIH for corrected TD.Tie-in to K1 72.2 11,001.0 05:45 08:54 marker-12.5'correction,tag corrected ©11,001'. 12/19/2015 12/19/2015 2.15 PROD3 DRILL DISP P POOH laying in liner pill/completion 11,001.0 65.5 08:54 11:03 fluid.Paint EOP flags @ 6,400'& • 8,600',continue OOH. 12/19/2015 12/19/2015 0.50 PROD3 DRILL OWFF P Tag-up.Flow check 65.5 65.5 11:03 11:33 12/19/2015 12/19/2015 2.50 PROD3 DRILL PULD P PJSM.LD BHA#11,prep floor to run 65.5 0.0 11:33 14:03 liner. 12/19/2015 12/19/2015 3.60 COMPZ3 CASING PUTB 'P PJSM.MU Liner assembly,bull nose, 0.0 2,299.4 14:03 17:39 73 jts slotted,shorty.MU BHA#12. 12/19/2015 12/19/2015 2.70 COMPZ3 CASING RUNL P RIH w/AL3 liner assembly,tie-in to 2,299.4 10,985.0 17:39 20:21 first flag for minus 16.5 ft.correction, iC PUW 35k,RBIH to 10,985 ft.PUW 37k,RBIH to set depth,release off liner,PUW 32k,-5k WOB,TOL at 8,730 ft.reset counters. 12/19/2015 12/19/2015 2.10 COMPZ3 CASING DISP P Displace well to seawater.PJSM with 8,730.0 2,500.0 20:21 22:27 LRS, MIRU LRS. POOH,P/T Lines and equipment.LRS pump 30 bbl diesel.RDMO LRS. 12/19/2015 12/19/2015 1.00 COMPZ3 CASING FRZP P Freeze protect well from 2,500 ft. 2,500.0 44.2 22:27 23:27 12/19/2015 12/20/2015 0.55 COMPZ3 CASING PULD P PJSM-Pressure un-deploy BHA#11 44.2 44.2 23:27 00:00 12/20/2015 12/20/2015 1.50 COMPZ3 CASING PULD P Pressure un-deploy BHA.LD BHA 44.2 0.0 00:00 01:30 #12. 12/20/2015 12/20/2015 0.75 DEMOB 'WHDBOP RURD P Remove checks,MU nozzle,jet stack 0.0 0.0 01:30 02:15 and profile. 12/20/2015 12/20/2015 2.25 DEMOB WHDBOP MPSP P PJSM-Rig orientation,load to floor 0.0 0.0 02:15 04:30 and MU Valve Shop equipment,P/T 1800 psi,Set BPV,WHP 1,250,rig down load out equipment 12/20/2015 12/20/2015 3.50 DEMOB WHDBOP RURD P Flush all surface lines and coil with 0.0 0.0 04:30 08:00 inhibited water. Page 9/10 Report Printed: 1/14/2016 I,,. • • Operations Summary (with Timelog Depths) 0a 30-01 Conoco Phillips Alaska Rig: NABORS CDR2-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(EKE) 12/20/2015 12/20/2015 2.00 DEMOB WHDBOP RURD T Continue R/D checklist.ND BOP stack 0.0 0.0 08:00 10:00 and secure.Check tree bolts,found none loose,30 minutes. Load tree with methanol and secure wellhead. 12/20/2015 12/20/2015 3.00 DEMOB WHDBOP RURD T Complete RD checklist.Prep rig 0.0 0.0 10:00 13:00 modules for move to 30-06.Prep for Peak equipment. Note:Move original rig release time from 08:00 to 13:00 due to waiting on trucks. Page 10/10 Report Printed: 1/14/2016 • . meq, ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 30 Pad 30-01 AL3 50-029-21836-62 Baker Hughes INTEQ .N Definitive Survey Report HUGHES 22 December,2015 • III ConocoPhillips 11,4%11 ConocoPhillips Definitive Survey Report 'iCEIGH ESR ConocoPhillips(Alaska)Inc-Kup2 Local Co-ordinate Reference:.....,, /";Well 30-01 Project: Kuparuk River Unit TVD Reference: 30-01 @ 59.00usft(30-01) Site: Kuparuk 30 Pad MD Reference: 30-01 @ 59.00usft(30-01) Well: 30-01 North Reference: True Wellbore:. 30-01A Survey Calculation Method: Minimum Curvature Design: 30-01A Database: EDM Alaska NSK Sandbox 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 Well 30-01 Well Position +N/-S 0.00 usft Northing: 6,022,095.27 usft Latitude: 70°28'17.339 N I • +E/-W 0.00 usft Easting: 525,478.27 usft Longitude: 149°47'30.897 W 9 Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft I. '`'.'''?'' jlbote 30-01AL3 ,.,',:a,4,;''' is Mgnetic. Model Name Sample Date ; DipAngle Field#tMength i t`) tett BGGM2015 1/1/2016 18.65 81.05 57,496 z Design ^• 30-01 AL3 '' Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,480 64 Vertical Section: Depth From(TVD) ON/-S +EI-W Direction y (usft) (usft) (usft( ` t+) 59 00 0 00 0 00 315D0 Survey Program Date 12/22/2015 From To ' Survey Survey (usft) (usft) , :Survey(Wellbore) :,'Tool140ImC Description Start Date Elul Data 100.00 8,800.00 30-01(30-01) BOSS-GYRO Sperry-Sun BOSS gyro multishot 1/15/2001 8,841.00 9,140.59 30-01A(30-01A) MWD MWD-Standard 12/11/2015 12/15/2015 9,171.00 9,480.64 30-01AL2(30-01AL2) MWD MWD-Standard 12/16/2015 12/17/2015 9,492.00 10982.53 30-01AL3(30-01AL3) MWD MWD-Standard 12/18/2015 12/19/2015 1 1222/2015 12:46:52PM Page 2 COMPASS 5000.1 Build 74 • ConocoPhillips Ili%II ConocoPhillips Definitive Survey Report BAICIER Company: ConocoPhillips(Alaska)Inc.-Ku p2 Local Co-ordinate Reference: Well 30-01 Project: Kuparuk River Unit TVD Reference: 30-01 @ 59.00usfl(30-01) Site: Kuparuk 30 Pad MD Reference: 30-01 @ 59.00usft(30-01) Well: 30-01 North Reference: True Wellbore: 30-01A Survey Calculation Method: Minimum Curvature Design: 30-01A Database. EDM Alaska NSK Sandbox t. Survey t „t„.401 '' Map Map Vertical. MD Inc Azi ND TVDSS +NIS +E7-W Northing g Eastin OLS Section (usft) (°). (°) (usft) (usft( (usft) (usft) of) (1100') Survey Tool Name Annotation 9,480.64 97.20 315.30 6,636.27 6,577.27 5,258.03 -2,894.33 6,027,342.84 522,566.25 8.36 5,764.59 MWD(3) TIP 9,492.00 96.07 314.21 6,634.96 6,575 96 5,265.98 -2,902.34 6027,350.76 522558 21 13.78 5,775.87 MWD(41 KOP 9,520.25 100.25 313.70 6,630.95 6,571.95 5,285.38 -2,822.47 6,027,370.09 522,538.02 14.90 5,803.82 MWD(4) 9,570.95 97.79 309.73 6,623.00 6,564.00 5,318.69 -2,959.84 6,027,403.27 522,500.54 9.13 5,853.80 MWD(4) 9,600.95 96.49 311.72 6,619.27 6,560.27 5338.11 -2,982.39 6,027,422.61 522477.92 7.88 5,883.48 MWD(4) 9,631.06 93.19 313.57 6,616.73 6,557.73 5,358.43 -3,004.46 6,027,442.85 522455.79 12.55 5,913.46 MWD(4) 2 9,660.65 90.68 314.58 6,615.73 6,556.73 5,379.00 -3,025.70 6,027,463.35 522,434.48 9.14 5,943.02 MWD(4) 9,690.78 87.73 311.20 6,616.15 6557.15 5,399.50 -3,047.77 6,027,483.77 522,412.34 14.89 5,973.12 MWD(4) t 9,720.55 89.17 308.40 6,616.96 6,557.96 5,418.55 -3,070.63 6,027,502.74 522,389.42 10.57 6,002.75 MWD(4) € 9,750.79 88.43 305.63 6,617.59 6,558.59 5,436.75 -3,094.77 6,027,520.85 522,365.22 9.48 6,032.69 MWD(4) i. 9,780.76 88.00 302.08 6,618.52 6,559.52 5,453.43 -3,119.64 6,027,537.45 522,340.29 11.93 6,062.08 MWD(4) 8,810.87 88.80 299.26 6,619.36 6,560.36 5,468.78 -3,145.53 6,027,552.71 522,314.36 9.73 6,091.23 MWD(4) 9,840.58 87.85 300.89 6,620.23 6,561.23 5,483.66 -3,171.22 6,027,567.50 522,288.61 6.35 6,119.93 MWD(4) 9,870.91 87.51 304.07 6,621.46 6,562.46 5,499.93 -3,196.78 6,027,583.69 522,263.00 10.54 6,149.51 MWD(4) 1 i 9,910.57 87.51 308.13 6,623.18 6,564.18 5,523.28 -3,228.79 6,027,606.91 522,230.91 10.23 6,188.65 MWD(4) s $ 9,940.65 89.08 312.11 6,624.08 6,565.08 5,542.65 -3,251.78 6,027,626.20 522,207.86 14.22 6,218.60 MWD(4) n 9,970.64 91.29 315.50 6,623.98 6,564.98 5,563.40 -3,273.42 6,027,646.88 522,186.15 13.49 6,248.57 MWD(4) 10,000.62 87.73 314.03 6,624.24 6,565.24 5,584.51 -3,294.70 6,027,667.91 522,164.80 12.85 6,278.55 MWD(4) g 10,030.05 87.42 318.07 6,625.49 6,566.49 5,605.67 -3,315.10 6,027,689.01 522144.33 13.76 6,307.94 MWD(4) 10,060.49 89.45 323.24 6,626.32 6,567.32 5,629.20 -3,334.39 6,027,712.46 522124.97 18.24 6,338.21 MWD(4) 0 ' 10,090.33 89.26 327.86 6,626.65 6,567.65 5,653.79 -3,351.26 6,027,737.00 522,108.01 15.49 6,367.53 MWD(4) ' 10,120.19 88.28 332.25 6,627.29 6,568.29 5,679.66 -3,366.16 6,027,762.81 522093.03 15.06 6,396.36 MWD(4) g 10,150.60 89.57 332.82 6,627.86 6,568.86 5,706.63 -3,380.18 6,027,789.73 522078.91 4.64 6,425.35 MWD(4) 10,180.33 88.68 330.45 6,628.32 6,569.32 5,732.79 -3,394.30 6,027,815.84 522,064.70 8.51 6,453.83 MWD(4) b 10,210.67 89.20 328.52 6,628.88 6,569.88 5,758.92 -3,409.70 6,027,841.91 522,049.21 6.59 6,483.20 MWD(4) i 10,240.61 88.89 325.54 6,629.38 6,570.38 5,784.03 -3,425.99 6,027,866.97 522,032.84 10.01 6,512.47 MWD(4) 10,27032 88.71 322.89 6,630.00 6,571.00 5,808.13 -3,443.36 6,027,891.00 522,015.39 8.94 6,541.79 MWD(4) b 10,300.70 89.60 320.96 6,630.45 6,571.45 5,832.04 -3,462.09 6,027,914.84 521,996.58 7.00 6,571.94 MWD(4) 1 10,330.84 89.20 319.06 6,630.77 6,571.77 5,855.13 -3,481.46 6,027,937.86 521,977.14 6.44 6,601.96 MWD(4) 110,359.92 88.59 317.25 6,63133 6,57233 5,876.78 350086 6,027.959.45 52195767 6.57 663099 MWD(4) 1222/201512:46:52PM Page 3 COMPASS 5000.1 Build 74 • • ConocoPhillips MINI ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Welt 30-01 Project: Kuparuk River Unit TVD Reference: 30-01 c@ 59.00usft(30-01) Site: Kuparuk 30 Pad MD Reference: 30-01 @ 59.00usft(30-01) Well: 30-01 North Reference: True Wellbore: 30-01A Survey Calculation Method: Minimum Curvature Design: 30-01A Database: EDM Alaska NSK Sandbox Survey Map Map Vertical 1 MD Inc AZi TVD TVDSS +Nl-S 081-W D4.S usk usk (soft) (soft) (usft) Northing Easting Section Survey Tool Name Annotation it ( j (°) '' {°) ( Ikl (k) (°1100') (k) S 10,390.06 88.50 315.47 6,632.09 6,573.09 5,898.59 -3,521.65 6,027,981.19 521,936.80 5.91 6,661.11 MWD(4) I 10,420.24 87.45 311.06 6,633.16 6,574.16 5,91926 -3,543.61 6,028,001.77 521,914.78 15.01 6,69125 MWD(4) t 10,450.31 89.48 308.90 6,633.96 6,574.96 5,938.57 -3,566.64 6,028,021.00 521,891.68 9.86 6,721.19 MWD(4) 10,480.46 90.37 305.45 6,634.00 6,575.00 5,956.78 -3,590.66 6,028,039.14 521,867.60 11.82 6,751.06 MWD(4) 10,510.56 89.88 303.21 6,633.94 6,574.94 5,973.76 -3,615.51 6,028,056.02 521,842.69 762 6,780.64 MWD(4) a 10,540.28 89.82 299.34 6,634.02 6,575.02 5,989.18 -3,640.91 6,028,071.36 521,817.25 13.02 6,809.50 MWD(4) 10,570.09 90.06 296.33 6,634.05 6,575.05 6,003.10 -3,667.27 6,028,085.19 521,790.84 10.13 6,837.98 MWD(4) t 10,600.52 91.20 293.15 6,633.71 6,574.71 6,015.83 -3,694.90 6,028,097.82 521,763.17 11.10 6,866.52 MWD(4) 10,630.48 89.32 286.73 6,633.58 6,574.58 6,026.04 -3,723.04 6,028,107.94 521,734.99 2233 6,893.65 MWD(4) 1 10,663.31 91.32 284.98 6,633.39 6,574.39 6,035.01 -3,754.62 6,028,116.80 521,703.39 8.09 6,922.32 MWD(4) 10,690.31 91.20 282.91 6,632.80 6,573.80 6,041.52 -3,780.82 6,028,123.21 521,677.17 768 6,945.44 MWD(4) 10,719.79 90.00 278.90 6,632.49 6,573.49 6,047.09 -3,809.76 6,028,128.69 521,64822 14.20 6,969.85 MWD(4) 10,749.78 90.43 276.73 6,632.38 6,573.38 6,051.17 -3,839.47 6,028,132.66 521,618.50 7.38 6,993.74 MWD(4) 10,779.82 91.29 279.21 6,631.93 6,572.93 6,055.33 -3,869.21 6,028,136.72 521,588.74 8.74 7,017.71 MWD(4) 10,809.76 88.65 280.69 6,631.94 6,572.94 6,060.51 -3,898.70 6,028,141.80 521,559.24 10.11 7,042.22 MWD(4) 10,840.00 88.19 284.69 6,632.78 6,573.78 6,067.15 -3,928.18 6,028,148.33 521,529.74 13.31 7,067.76 MWD(4) 10,870.27 86.99 286.64 6,634.05 6,575.05 6,075.31 -3,957.30 6,028,156.40 521,500.59 7.56 7,094.13 MWD(4) z. 10,900.29 86.56 289.62 6,635.74 6,576.74 6,084.64 -3,985.78 6,028,165.62 521,472.08 10.01 7,120.86 MWD(4) 10,930.08 87.18 292.11 6,637.37 6,578.37 6,095.23 -4,013.57 6,028,176.12 521,44426 8.60 7,148.00 MWD(4) 10,962.53 87.94 295.06 6,638.75 6,579.75 6,108.20 -4,043.28 6,028,188.99 521,414.51 9.38 7,178.18 MWD(4) 11,001.00 87.94 295.06 6,640.13 6,581.13 6,124.48 -4,078.11 6,028,205.15 521,379.63 0.00 7,214.32 PROJECTED to TD 12/22/2015 12:48.52PM Page 4 COMPASS 5000.1 Build 74 RECEIVES 2 1 5 'D 1 2 1 5 1 9 1 5 1 9 4 26 64 6 26 64 7 1 RauJAN 13 2016 BAKER PRINT DISTRIBUTION LIST HUGHES AOGCC Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Alaska,Inc. ConocoPhillips Alaska,Inc. Ricky Elgarico.ATO 3-334. DATA BOGGED 2/Z/201 Cb WELL NAME 30-01A;01AL2;01AL3 700 G Street. M.K.BENDER Anchorage,Alaska 99510 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska --- LOG DATE December 19,2015 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider anbakerhughes.com TODAYS DATE January 11,2016 Revision STATUS Final Replacement: No Details: Requested by: COMPANY FIELD FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #UF-I'NIN I5 #OF COPIES #OF COPIES #OF COPIES 1 BP North Slope 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 0 Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska I 0 0 0 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 41State of Alaska -AOGCC 1 1 I 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 1 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 • • CO LSI 1.0 N1 IP W ig `W; szN Q 0 W U I N 0 ■ W 0 c 0z 0 _ ca L LV 0Y cn co 0 cv Q Ce ^^ Z_ G) — — _c t!) a -cc O CD 0 Lo O a. w a CDD > N M 4W 0 62 cl co Y Y J CV a) 0 c i i Q a1 - ■ U V ©11 a a 9 o �� V elinm a 4 • 0 . 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PT ,215----/ q4- Loepp, t5--114Loepp, Victoria T (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, December 22, 2015 9:03 AM To: Eller, J Gary Cc: Loepp, Victoria T (DOA);Venhaus, Dan E; Pohler, Cody J Subject: RE: Official TD on 30-01L3 (#215-194) Follow Up Flag: Follow up Flag Status: Completed Gary, As we discussed the incident is fairly minor and unintentional. However,to ensure that it doesn't happen again I would suggest that the CT unit either: 1)tie-in just before TD 2) leave a margin of error by stopping a few feet short of 500' or 3)get a revised PTD if drilling conditions warrant additional footage past 500 ft. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). From: Eller, J Gary [mailto:J.Gary.EllerOconocophillips.com] Sent: Monday, December 21, 2015 1:52 PM To: Schwartz, Guy L(DOA) Cc: Loepp, Victoria T(DOA); Venhaus, Dan E; Pohler, Cody 3 Subject: Official TD on 30-01L3 (#215-194) Guy—As I discussed with you today, we drilled and completed 30-01L3 (PTD#215-193)this weekend with Nabors CDR2-AC. The official TD of that lateral is 11,001' MD, which is 501' beyond the permitted TD of 10,500'. 20 AAC 25.015(a)(1) allows us to drill 500' laterally beyond the permitted TD, but in this case we inadvertently drilled 501' beyond permitted TD. Because of the inherit margin of error on coiled tubing depth measurement, CTD's practice has always been to drill to preliminary TD, then tie-in to some marker near the window, and then re-tag at what we call the official TD. In 30-01 L3 we drilled to 11,000' MD, but after tying-in and tagging TD the corrected depth was 11,001' MD. In my discussion with you, your immediate thought was that this 1' depth variance is within the margin of error on coiled tubing depth measurement. I agree with that, but regardless ConocoPhillips has captured this event in our CTD lessons learned and will strive not to repeat this mistake in the future. 7. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 1 • CF E) 23 Letter of Transmittal V I AOG C BAKER Date: DATA LOGGED December 22, 2015 > /12/201G,HUGHES 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): 30-01A 2 1 5 1 9 1 2659`6 30-01AL2 21 51 93 26597 30-01AL3 21 5 1 9 4 2 6 5 9, 8 (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 • M 01 III col CN C91 1.�, u.gl N 0. 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N N N M M M CO Co IA L > 0 a op 3 Q Q o a o 0 o a co. co CO m (0 N C a p- C ^ 0i O h O 0) O O O S o C 0 0 0 C v 00 as m co m as as asZ U Y Y co (+) co a Q. N 7 V N- N N 7 (n M N 0 fV o 0 (f) ui O o vi O j >+ m N (0 O) N V (0 O LO = d 0 0 CO 0 0 0 Co Q t6 V p C T o— r 0 V E o «' Ti, d " 0 U a. N }S S O (I) Ati OF!Tit • .0"%' �j, s THE STATE Alaska Oil and as of A LA ,C)KA Conservation Commission 5� - 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �` h' Main: 907.279.1433 OF+�nm' ' Fax: 907.276.7542 ALAS www.aogcc.alaska.gov Dan Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 30-01 AL3 ConocoPhillips Alaska, Inc. Permit No: 215-194 Surface Location: 724' FNL, 3438' FEL, SEC. 22, T13N, R9E, UM Bottomhole Location: 15' FNL, 1748' FEL, SEC. 16,T13N, R9E, 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. 215-191, API No. 50-029- 21836-01-00. 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 an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cs0.& Cathy P. Foerster 54S Chair DATED this 3 day of November, 2015. • S RECEIVED STATE OF ALASKA0t5 ALASKA OIL AND GAS CONSERVATION COMMISSION DCT 2 3 PERMIT TO DRILL AOG C 20 AAC 25.005 1 a.Type of Work: lb.Proposed Well Class: Development-Oil Q` Service-Winj ❑ Single Zone Q' 1 c.Specify if well is proposed for: Drill ❑ • Lateral 0 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: LJ Blanket l . Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 - KRU 30-01AL3 k 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 10500'` TVD: 6569' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:724'FNL,3438'FEL,Sec.22,T13N, R9E, UM i ADL 25513• Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1196'FNL, 593'FEL,Sec. 16,T13N, R9E,UM 2554 12/1/2015 Total Depth: 9.Acres in Property: 14.Distance to 15'FNL, 1748'FEL, Sec. 16,T13N, R9E, UM 2560 - Nearest Property: 6009 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: , 59 feet 15.Distance to Nearest Well Open Surface:x- 525478 y- 6022095 Zone- 4 • GL Elevation above MSL: , 24 feet to Same Pool: 30-08L1 ,762 16.Deviated wells: Kickoff depth: f 9065 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 99° deg. Downhole:4504 psig• Surface:3841 psig• 18.Casing Proglam: 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 1770' 8730' 6462 10500 6569 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) 9173 6890 none 9065 6805 9000' Casing Length Size Cement Volume MD TVD Conductor 82' 16" 200 sx ASII 115' 115' Surface 5270' 9.625" 1250 sx AS III,370 sx CI G 5305' 4066' 80 sx AS I Production 9113' 7" 200 sx Class G 9248' 6871' Perforation Depth MD(ft): Perforation Depth TVD(ft): 8832-8847,8850-8866,8890-8910 6623-6634,6637-6649,6668-6684 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements ❑ 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Cody Pohler @ 265-6435 Email Cody.J.PohlerCa�cop.com Printed Name Da Venhaus Title CTD Engineering Supervisor OP Signature ‘7Phone:263-4372 Date 7. ..-2/"---/--S- Commission oZ/isCommission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: 415—1 9 y 50-a9- Jg34-(02-pp Date: H I '0 5 for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m thane,gas hydrates,or gas contained in shales: d Other: 8 op 7-1„...5/ to 450 0/25 tai, &mples req'd: Yes No [ Mud log req'd: Yes No d 4hY3vl G v p rtKf�ftV ftt Z H2 )eaares: Yes No Directional svy req'd: Yes d Noll], Spacing exception req'd: Yes ❑ No Inclination only svy req'd: Yes❑ No illg APPROVED BY THE Approved by:( g/-1.-1,7(1."--e0MMISSIONER COMMISSION Date:if- 3- S Form 10-401(nevi d����`� mita", 4�o hs from the fl< o/app�ro&va620 AAC f0/�)//� Llo pj/ 6/ ! • ConocoPhillips RECEIVED Alaska OCT 2 3 2015 P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC October 6,2015 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 permits to drill a quad-lateral out of the Kuparuk Well 30-01 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin end of December 2015. The CTD objective will be to drill four laterals(30-01A, 30-01AL1, 30-01AL2, 30-01AL3), targeting the A sand intervals. Attached to this application are the following documents: — Permit to Drill Application Form 10-401 for 30-01A, 30-01AL1, 30-01AL2, 30-01AL3 — Detailed Summary of Operations — Directional Plans — Proposed Schematic If you have any questions or require additional information please contact me at 907-265-6435. Sincerely, 60/15::?-aje--- Cody Pohler Coiled Tubing Drilling Engineer • • Kuparuk CTD Laterals NABOAS ALASKA 30-01A, 3®®01 AL1, 30-01 AL2 & 3®®01 AL3 i)n °°`°P'"riP= Application for Permit to Drill Document (AC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(1)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 5 (Requirements of 20 AAC 25.005(c)(13)) 5 Summary of Operations 5 Pressure Deployment of BHA 6 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 7 (Requirements of 20 AAC 25.050(b)) 7 16. Attachments 7 Attachment 1: Directional Plans for 30-01A,AL1,AL2,AL3 7 Attachment 2: Current Well Schematic for 30-01 7 Attachment 3: Proposed Well Schematic for 30-01A,AL1,AL2,AL3 7 Page 1 of 7 10/22/2015 • • PTD Application: 30-01A, AL1, AL2 and AL3 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 30-01A, 30-01AL1, 30-01AL2 & 30-01AL3. All laterals will be classified as"Development— Oil"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 30-01A, 30-01AL1, 30-01AL2 & 30-01AL3. 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 4500 psi. Using the maximum formation pressure in the area of 4504 psi in 30-05, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3841 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. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Expected Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) Well 30-01 has a formation pressure of 10.6 ppg EMW as of 2/1/2015 (3679 psi at 6652' TVD). The maximum potential formation pressure in the area is to the east, well 30-05 with a 13.4 ppg EMW as of 7/18/2015 (4504 psi at 6472' TVD). Since we are drilling away from 30-05 we do not expect to see the higher 30-05 pressure while drilling the 30-01 laterals. Well 3R-22 has a formation pressure of 12.7 ppg EMW as of 9/29/2015 (4406 psi at 6668' TVD). We expect 3R-22 pressure to decline to 12.5 ppg by the time we spud. The maximum expected pressure along the proposed well path is less than 12.5 ppg EMW due to the distance and baffling faults in between the laterals and 3R-22. The 3R-22 pressure would be more likely to influence the 30-01 laterals than the 30-05 pressure. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) Well 30-07 to the east injected lean gas (2014) and well 30-05 to the east injected MI (2013) however all planned laterals are to the northwest; no specific gas zones are expected to be drilled. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The largest, expected risk of hole problems in the 30-01 laterals will be shale instability across the faults, managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossing. Along with shale instability as mentioned above the higher pressure risk will also be taken into consideration for potential hole problems. Again MPD will be used to mitigate the high pressure risk. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. Page 2 of 7 10/22/2015 • S PTD Application: 30-01A, AL1, AL2 and AL3 According to 20 AAC 25.030(1), thru-tubing drilling operations need not perform additional formation integrity tests. 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 30-01A 10,400' 11,150' 6,610' 6,665' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 30-01AL1 9,350' 11,200' 6,623' 6,631' 23/8', 4.7#, L 80, ST-L slotted liner; aluminum billet on top 30-01AL2 9,065' 11,200' 6,627' 6,604' 23/8 , 4.7#, L 80, ST-L slotted liner; aluminum billet on top 2%", 4.7#, L-80, ST-L slotted liner; 30-01AL3 8,730' 10,500' 6,462' 6,569' shorty deployment sleeve in 3-1/2" tubing tail Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 33' 115' 33' 115' 1,640 630 Surface 9-5/8" 36 J-55 BTC 35' 5,305' 35' 4,066' 3,520 2,020 Production 7" 26.0 J-55 BTC 35' 9,148' 35' 6,870' 4,980 4330 Tubing 3-1/2" 9.3 L-80 EUE 33' 8,736' 33' 6,754' 10,160 10,530 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-weighted FloVis water-based mud (8.9 ppg) — Drilling operations: Chloride-weighted FloVis water-based mud (8.9 ppg). This mud weight does not hydrostatically overbalances the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: BHA's will be deployed using standard pressure deployments and the well will be loaded with 12 ppg NaBr completion fluid in order to provide formation over-balance and maintain wellbore stability while running completions- Page 3 of 7 10/22/2015 • PTD Application: 30-01A, AL1, AL2 and AL3 Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". The targeted MPD BHP will be 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. 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 30-01 Window(8,840' MD, 6,629' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation 3679 psi 3679 psi Pressure (10.6 ppg) Mud Hydrostatic(8.9 ppg) 3068 psi 3068 psi Annular friction (i.e. ECD, 796 psi 0 psi 0.090 psi/ft) Mud + ECD Combined 3864 psi 3068 psi (no choke pressure) (overbalanced -185 (underbalanced —612 psi) psi) Target BHP at Window 4069 psi 4069 psi (11.8 ppg) Choke Pressure Required 205 psi 1001 psi to Maintain 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 for land-based 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. Page 4 of 7 10/22/2015 • PTD Application: 30-01A, AL1, AL2 and AL3 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 30-01 is a Kuparuk A-sand producer well equipped with 3'/2"tubing and 7"production casing. A rig work-over was completed in 2009 to isolate the production casing leak between 5,551'MD to 5,556' MD. Four laterals will be drilled to the north west of the parent well bore with the laterals targeting the different A sand lobes.These laterals will access reserves in the adjacent fault blocks targeting the Al,A2,and A3 sands. Prior to CTD operations,the 3-1/2"tubing tail will be perforated and the D nipple at 8,701' MD will be milled out to a 2.80"ID. The existing A-sand perfs will be squeezed with cement to provide a means to kick out of the 7"casing. ConocoPhillips has submitted at 10-403 sundry application for a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A-sand perfs in this manner. Sundry has been approved; Sundry#315-498. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 8,840' MD and set a mechanical whipstock in the 2.80"pilot hole to kick off at 8,840' MD.All four 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. Pre-CTD Work 1. RU Slickline: dummy off gas lift mandrels. 2. RU E-line: Shoot 2' of holes in the 3V2"tubing tail at 8696' MD. 3. RU Pumping Unit: perform injectivity test down the tubing. 4. RU Service Coil: Mill out D nipple and cement squeeze the A sand perforations up to the perforations in the tubing tail. 5. RU Slickline: Tag top of cement and log. 6. Prep site for Nabors CDR2-AC, including setting BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 30-01A Lateral(Al sand to north west) a. Drill 2.80"high-side pilot hole through cement to 8,840' MD b. Caliper pilot hole c. Set whipstock at 8,840' MD d. Mill 2.80"window at 8,840' MD. e. Drill 3"bi-center lateral to TD of 11,150' MD. f. Run 2%" slotted liner with an aluminum billet from 1'D up to 10,400' MD. 3. 30-01AL1 Lateral(A2 sand) a. Kick off of the aluminum billet at 10,400' MD. b. Drill 3"bi-center lateral to TD of 11,200' MD. c. Run 2%"slotted liner from TD up to 9,350' MD 4. 30-01AL2 Lateral(A2&A3 sands) a. Kick off of the aluminum billet at 9,350' MD. b. Drill 3"bi-center lateral to TD of 11,200' MD. c. Run 2%"slotted liner from TD up to 9,065'MD 5. 30-01AL3 Lateral(A3 sand) a. Kick off of the aluminum billet at 9,065' MD. Page 5 of 7 10/22/2015 • • PTD Application: 30-01A, AL1, AL2 and AL3 b. Drill 3"bi-center lateral to TD of 10,500' MD. c. Run 2%" slotted liner from TD up to 8,730' MD, above the whipstock and in the 3-1/2"tubing. 6. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV. 2. Install GLV's. 3. Return to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using 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 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 — The 30-01 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. — 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 AA C 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. Page 6 of 7 10/22/2015 • i PTD Application: 30-01A, AL1 AL2 and AL3 • 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 30-01A 5872' 30-01 AL1 7072' 30-01AL2 6210' 30-01 AL3 6009' — Distance to Nearest Well within Pool Lateral Name Distance Well 30-01A 633' 30-08L1 30-01AL1 1827' 30-08L1 30-01AL2 960' 30-08L1 30-01AL3 762' 30-08L1 16. Attachments Attachment 1: Directional Plans for 30-01A, AL1, AL2, AL3 Attachment 2: Current Well Schematic for 30-01 Attachment 3: Proposed Well Schematic for 30-01A, AL1, AL2, AL3 Page 7 of 7 10/22/2015 ...,_...._...n� , KUP 0 30-01 ConocoPhillips f Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Well Status Inc](°) MD(ftKB) Act Btm(ftKB) Cu"n,N dlgps 500292183600 KUPARUK RIVER UNIT PROD 52.62 3700.00 9173.0 Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:NIPPLE 165 11/25/2011 Last WO: 2/26/2009 34.98 8/5/1988 Well Conga:-30-01.3/24/201294024 AM Schematic-Actual Annotation Depth(MB) End Date Annotation Last Mod...End Date Last Tag:SLM 8,951.0 3/29/2009 Rev Reason:GLV C/0 ninam 3/24/2012 Casing Strings Casing Description String 0... St ...Top(ftKB) Oct Depth(f...Set Depth ...String Wt...String...String Top Thrd HANGER,33 CONDUCTOR 16 15.15,066 2 33.0 115.0 115.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 95/8 8.765 34.6 5,395.0 4,066.0 36.00 J-55 BTC Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd ' PRODUCTION 7 6276 35.2 9,148.0 6,870.7 26.00 J-55 BTC Tubing Strings CONDUCTOR, I I + Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 33-115 TUBING 31/2 2.990 33.2 5,399.8 4,129.6 9.30 L80 EUE8RD Completion Details NIPPLE,511 Top Depth 1 (TVD) Top Incl Sarni... ( Top(11(B) (ftKB) (°) Item Description Comment ID(in) GAS LIFT, ( 33.2 33.2 0.55 HANGER C.I.W.TUBING HANGER 2.950 2928Li 511.0 510.8 3.42 NIPPLE CAMCO 2.875"'DS'NIPPLE 2.875 r=li 5,334.0 4,085.5 47.73 NIPPLE CAMCO 2.813"'DS'NIPPLE 2.813 5,377.0 4,114.4 47.86 LOCATOR LOCATOR 2.990 • GAS --C-,- 5,378.31 4,115.21 47,861SEALASSY 'SEAL ASSEMBLY W/2'SPACEOUT 3.000 LIFT, � _ 4,697 Tubing Description String 0... String ID_.Top(ftKB) Set Depth(f_.Set Depth(TVD)...String Wt..String...-String Top Thrd Straddle Packer 3 1/2 2.992 5,368.1 8,575.0 6,423.6 9.30 L-80 EUE 8rd AB Mod Completion Details Top Depth (TVD) Top Incl Nomi... Top(ftKB) (ftKB) (°) Item Description Comment ID(In) 5,368.1 4,108.4 47.83 SLEEVE "HR"LINER SETTING SLEEVE 4.420 GAS UFT, _ 5,381,7 4,117.5 47.87 SBE SEAL BORE EXTENSION 4.000 5,287 5,401.7 4,130.8 47.72 X0-Reducing CROSSOVER SUB 2.990 5,411.6 4,137.5 47.72 PACKER BAKER 4782-7"26#FHL PACKER 2.970 SURFACE, 8,479.6 6,350.2 39.74 PACKER BAKER 4782-T'26#FHL PACKER 2.970 x•305 8,529.0 6,388.2 39.57 NIPPLE OTIS 2.813"'X'NIPPLE 2.813 NIPPLE,6334 8,568.5 6,418.6 39.52 OVERSHOT BAKER 7"x 3.625"POOR BOY OVERSHOT WI 6.10"SWALLOW 3.620 Tubing Description String 0... String ID_.Top(ftKB) Set Depth(f...Set Depth(TVD)_.'String Wt...String...String Top Thrd TUBING Original I 31/2 I 2.992 I 8,570.6 I 8,736.0 I 6,548.1 IStri9.30 I J-55 Completion Details SLEEVE,5,368 r Top Depth LOCATOR. (NftKB)D) Top Ind Noml... 5,377 Top(ftKB) ( (") Item Description Comment ID(in) 8,652.3 6,483.4 39.57 PBR AVA PBR/LOCATOR 3.000 SEAL ASSY. 5,378 $,665.9 6,493.9 39.51 PACKER AVA RMS PACKER 3.000 BBE,5,382 8,701.4 6,521.2 39.34 NIPPLE CAMCO'D'NIPPLE 2.750 8,735.2 6,547.5 39.18 SOS SHEAR OUT SUB 2.992 il:4, Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (ND) Top Teel Top(ftKB) (ftKB) (1 Description Comment Run Date ID(in) 9,000 6,754.3 38.18 FISH PIECE OF 3"JD DOG 1"x 1.5" 8/31/2008 0.000 PACKER,5,412 Perforations&Slots 4Shot Top(ND) Btm(ND) Dens Top(ftKB) Btm(ftKB) (ftKB) (ft613) Zone Date (eh... Type Comment PACKER,8.480 8,832 8,847 6,622.6 6,634.4 A-3,30-01 4/28/1989 12.0 IPERF 21/8"EnerJet;60 deg.ph 8,850 8,866 6,636.7 6,649.2 A-2,30-01 4/28/1989 12.0 IPERF 2 1/8"EnerJet;60 deg.ph - 8,890 8,910 6,668.0 6,683.7 A-1,30-01 10/3/1988 8.0 IPERF 4.5"Csg Gun;45 deg.ph NIPPLE.8,629 i I Notes:General&Safety -1End Date Annotation �I/ 2282009 (NOTE:View Schematic W/Alaska Schematic9.0 OVERSHOT, 8,569 GAS LIFT, -I 8,612 PBR,8,652 - F PACKER,8,666 NIPPLE,8,701 -- - tiO. I SOS,8,735 ---- Mandrel Details Top Depth Top Port ® (ND) Incl OD Valve Latch Size TRO Run 8E132-8,8R47 Stn Top(ftKB) (ftKB) 1°) Make Model (in) Bery Type Type (In) (psi) Run Date Com._ 1 2,928.2 2,504.0 47.95 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,258.0 3/21/2012 (PERF, M ® 2 4,697,1 3,649.5 47.37 Camco MMG 1 12 GAS LIFT GLV RK 0.188 1,259.0 3/21/2012 8,8508,868 3 5,287.0' 4,053.9 47.58 Camco MMG 1 12 GAS LIFT OV RK 0250 0.0 3/21/2012 8,89 08,910 IPERF, S R 4 8,611.6 6,4522 39.77 OTIS LBX 1 12 GAS LIFT OPEN 0.000 0.0 1282009 FISH,9,0001 PRODUCTION, 359,148 . TO 9,173 • 0 o a o� zn 30 a 0 0 N ty� og go <-,,,,,-,_O ¢'-'m O�OF out o©v 3,--m CO O V v T OI-. a) N o LO ~ p N m ao n co M O 3�m m _ moa N- - CO• < o Ma, 1 OD N N D o© i N @ . ii t 1,-- o 0 0� , �, II N N 0 L O 'H' m F- o m - m k I ' Fri a 0 op o a oN ��1 a o .) LU C �C P. o o .'t Cl 'O V O .o '- N of @ O5, f ",'0 coco 7 - .o M I-10.3) o g m p o v as - _ a) r� N- - a o c'E_ Ti. m 2 -. 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"F �4 ��:,,KW-, - ^ i ;r p;.sC.•.wt T3 0u_1t' ]..(� - 71- TT11 - O CL. in LO o I 1 I Ili na O ' LO L r I ar N N a 0 O -- .1,N s L0 M o as a) v �0 0� #- N -U ',o CO 'C rc0O co c0 )O @(D @VCO V O to C)In o 0 aooma) i--am vLO -O - to czo d ammm My- 4tntonor 0 asivoCI o N - g MO F-,so Y NMt06) LOU) E.M Q o7 aD a0 ZO tLO U N Q)'_ • • Conoco P i H i p NADConversion Kuparuk River Unit Kuparuk 30 Pad 30-01 30-01AL3 Plan: 30-01AL3 wp03 Standard Planning Report 14 October, 2015 r'1 BAKER HUGHES • Baker Hughes INTEQ • VAMP ConocoPhillips Planning Report BAKER HUGHES Database: OAKEDMP2 Local Co-ordinate Reference: Well 30-01 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-01 @ 59.00usft(30-01) Site: Kuparuk 30 Pad North Reference: True Well: 30-01 Survey Calculation Method: Minimum Curvature Wellbore: 30-01 AL3 Design: 30-01 AL3_wp03 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 30 Pad Site Position: Northing: 6,022,094.67 usft Latitude: 70°28'17.333 N From: Map Easting: 525,478.25 usft Longitude: 149°47'30.897 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.20° Well 30-01 Well Position +N/-S 0.00 usft Northing: 6,022,095.27 usft Latitude: 70°28'17.339 N +EI-W 0.00 usft Easting: 525,478.27 usft Longitude: 149°47'30.897 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 30-01AL3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 1/1/2016 18.65 81.05 57,496 Design 30-01AL3_wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,065.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 315.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +EI-W Rate Rate Rate TFO (usft) (0) (0) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) Target 9,065.00 90.00 306.78 6,627.06 4,981.34 -2,594.17 0.00 0.00 0.00 0.00 9,200.00 99.45 306.78 6,615.96 5,061.80 -2,701.81 7.00 7.00 0.00 0.00 9,355.00 99.45 317.78 6,590.51 5,164.50 -2,814.76 7.00 0.00 7.10 90.00 9,435.00 93.93 316.80 6,581.19 5,222.86 -2,868.63 7.00 -6.89 -1.22 -170.00 9,505.00 95.61 312.18 6,575.37 5,271.73 -2,918.38 7.00 2.39 -6.61 -70.00 9,605.00 96.82 319.11 6,564.54 5,342.77 -2,987.84 7.00 1.22 6.94 80.00 9,750.00 90.30 311.32 6,555.53 5,445.33 -3,089.67 7.00 -4.50 -5.36 -130.00 9,850.00 90.06 318.31 6,555.22 5,515.77 -3,160.56 7.00 -0.24 7.00 92.00 10,000.00 89.14 307.85 6,556.27 5,618.09 -3,269.96 7.00 -0.61 -6.97 -95.00 10,200.00 88.41 321.84 6,560.55 5,758.74 -3,411.37 7.00 -0.37 6.99 93.00 10,300.00 88.41 314.84 6,563.33 5,833.37 -3,477.78 7.00 0.00 -7.00 -90.00 10,500.00 88.41 328.84 .6,568.88 5,990.18 -3,601.00 7.00 0.00 7.00 90.00 10/14/2015 7:39:19AM Page 2 COMPASS 5000.1 Build 74 • Baker Hughes INTEQ • 7717 ' ConocoPhiHips Planning Report BAKER HUGHES Database: OAKEDMP2 Local Co-ordinate Reference: Well 30-01 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-01 @ 59.00usft(30-01) Site: Kuparuk 30 Pad North Reference: True Well: 30-01 Survey Calculation Method: Minimum Curvature Wellbore: 30-01 AL3 Design: 30-01AL3_wp03 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) (°/100usft) (°) (usft) (usft) 9,065.00 90.00 306.78 6,627.06 4,981.34 -2,594.17 5,356.69 0.00 0.00 6,027,067.20 522,867.32 TIP/KOP 9,100.00 92.45 306.78 6,626.32 5,002.29 -2,622.20 5,391.32 7.00 0.00 6,027,088.06 522,839.23 9,200.00 99.45 306.78 6,615.96 5,061.80 -2,701.81 5,489.70 7.00 0.00 6,027,147.29 522,759.42 Start 7 dls 9,300.00 99.45 313.88 6,599.54 5,125.60 -2,776.96 5,587.95 7.00 89.42 6,027,210.82 522,684.06 9,355.00 99.45 317.78 6,590.51 5,164.50 -2,814.76 5,642.19 7.00 89.69 6,027,249.60 522,646.13 3 9,400.00 96.35 317.23 6,584.33 5,197.36 -2,844.87 5,686.72 7.00 -169.96 6,027,282.35 522,615.91 9,435.00 93.93 316.80 6,581.19 5,222.86 -2,868.63 5,721.55 7.00 -169.98 6,027,307.76 522,592.06 4 9,500.00 95.49 312.51 6,575.85 5,268.38 -2,914.70 5,786.31 7.00 -69.82 6,027,353.12 522,545.84 9,505.00 95.61 312.18 6,575.37 5,271.73 -2,918.38 5,791.28 7.00 -70.13 6,027,356.46 522,542.15 5 9,600.00 96.77 318.77 6,565.13 5,339.02 -2,984.58 5,885.67 7.00 79.65 6,027,423.51 522,475.73 9,605.00 96.82 319.11 6,564.54 5,342.77 -2,987.84 5,890.63 7.00 80.18 6,027,427.25 522,472.46 6 9,700.00 92.55 314.00 6,556.78 5,411.47 -3,052.91 5,985.22 7.00 -129.76 6,027,495.72 522,407.15 9,750.00 90.30 311.32 6,555.53 5,445.33 -3,089.67 6,035.16 7.00 -129.96 6,027,529.45 522,370.29 7 9,800.00 90.18 314.82 6,555.32 5,479.47 -3,126.19 6,085.12 7.00 91.99 6,027,563.46 522,333.66 9,850.00 90.06 318.31 6,555.22 5,515.77 -3,160.56 6,135.09 7.00 92.00 6,027,599.64 522,299.16 8 9,900.00 89.75 314.83 6,555.31 5,552.08 -3,194.93 6,185.07 7.00 -95.00 6,027,635.83 522,264.68 10,000.00 89.14 307.85 6,556.27 5,618.09 -3,269.96 6,284.79 7.00 -95.03 6,027,701.57 522,189.43 9 10,100.00 88.77 314.85 6,558.09 5,684.10 -3,344.96 6,384.51 7.00 93.06 6,027,767.32 522,114.20 10,200.00 88.41 321.84 6,560.55 5,758.74 -3,411.37 6,484.25 7.00 93.08 6,027,841.73 522,047.55 10 10,300.00 88.41 314.84 6,563.33 5,833.37 -3,477.78 6,583.98 7.00 -90.10 6,027,916.13 521,980.89 11 10,400.00 88.41 321.84 6,566.11 5,908.01 -3,544.19 6,683.71 7.00 90.10 6,027,990.52 521,914.23 10,500.00 88.41 328.84 6,568.88 5,990.18 -3,601.00 6,781.99 7.00 90.10 6,028,072.49 521,857.15 Planned TD at 10500.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (•') (•.) 10,500.00 6,568.88 2 3/8" 2-3/8 3 10/14/2015 7:39:19AM Page 3 COMPASS 5000.1 Build 74 • Baker Hughes INTEQ • AR11 ConocoPhillips Planning Report BAKER HUGHES Database: OAKEDMP2 Local Co-ordinate Reference: Well 30-01 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-01 @ 59.00usft(30-01) Site: Kuparuk 30 Pad North Reference: True Well: 30-01 Survey Calculation Method: Minimum Curvature Wellbore: 30-01 AL3 Design: 30-01 AL3_wp03 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +El-W (usft) (usft) (usft) (usft) Comment 9,065.00 6,627.06 4,981.34 -2,594.17 TIP/KOP 9,200.00 6,615.96 5,061.80 -2,701.81 Start 7 dls 9,355.00 6,590.51 5,164.50 -2,814.76 3 9,435.00 6,581.19 5,222.86 -2,868.63 4 9,505.00 6,575.37 5,271.73 -2,918.38 5 9,605.00 6,564.54 5,342.77 -2,987.84 6 9,750.00 6,555.53 5,445.33 -3,089.67 7 9,850.00 6,555.22 5,515.77 -3,160.56 8 10,000.00 6,556.27 5,618.09 -3,269.96 9 10,200.00 6,560.55 5,758.74 -3,411.37 10 10,300.00 6,563.33 5,833.37 -3,477.78 11 10,500.00 6,568.88 5,990.18 -3,601.00 Planned TD at 10500.00 10/14/2015 7:39:19AM Page 4 COMPASS 5000.1 Build 74 • • Viill► W g egZ mum = 4 3 g< oFs a gI 'a o = 0:4 3 #a r„, z M qp'AP, `F$�6 qF -g, o - pHg � 1``-O o p r3yRE -C w . 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C O Nc7 V CO r com O�,N z o (tn/gsn OL)IPdaa ieotuaA MULL U • S ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 30 Pad 30-01 30-01AL3 30-01AL3_wp03 Travelling Cylinder Report 13 October, 2015 BAKER HUGHES • • ConocoPhillips .diI ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 30-01 Project: Kuparuk River Unit TVD Reference: 30-01 @ 59.00usft(30-01) Reference Site: Kuparuk 30 Pad MD Reference: 30-01 @ 59.00usft(30-01) Site Error: 0.00 usft North Reference: True Reference Well: 30-01 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 30-01AL3 Database: EDM Alaska ANC Prod Reference Design: 30-01AL3_wp03 Offset TVD Reference: Offset Datum Reference 30-01AL3_wp03 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 9,065.00 to 10,500.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,244.10 usft Error Surface: Elliptical Conic Survey Tool Program Date 9/22/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 8,800.00 30-01 (30-01) BOSS-GYRO Sperry-Sun BOSS gyro multishot 8,800.00 9,065.00 30-01A_wp03(30-01A) MWD MWD-Standard 9,065.00 10,500.00 30-01AL3_wp03(30-01AL3) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 10,500.00 6,627.88 2 3/8" 2-3/8 3 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 30 Pad 30-01-30-01A-30-01A_wp03 9,075.00 9,075.00 0.08 0.36 -0.27 FAIL-Minor 1/10 30-01-30-01AL1-30-01AL1_wp03 9,075.00 9,075.00 0.08 0.36 -0.27 FAIL-Minor 1/10 30-01-30-01AL2-30-01AL2_wp03 9,075.00 9,075.00 0.08 0.36 -0.27 FAIL-Minor 1/10 30-02-30-02-30-02 Out of range 30-02-30-02A-30-02A Out of range 30-02-3O-02AL1-30-02AL1 Out of range 30-02-30-02AL1 PB1-30-02AL1 PB1 Out of range 30-02-30-02AL2-30-02AL2 Out of range 30-02-30-02AL2-01-30-02AL2-01 Out of range 30-04-30-04-30-04 Out of range Offset Design Kuparuk 30 Pad- 30-01-30-01 A-30-01A_wp03 Offset Site Error: 0.00 usft Survey Program: 100-BOSS-GYRO,8800-MWD Rule Assigned:Minor 1/10 Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) 1°) (usft) (usft) II (usft) (usft) (usft) 9,075.00 6,686.00 9,075.00 6,686.06 0.01 0.01 79.79 4,987.37 -2,602.14 2-11/16 0.08 0.36 -0.27 FAIL-Minor 1/10,CC,ES,SF 9,099.97 6,685.32 9,100.00 6,686.01 0.03 0.04 79.76 5,002.68 -2,621.75 2-11/16 1.02 0.51 0.52 Pass-Minor 1/10 9,124.85 6,683.88 9,125.00 6,685.91 0.05 0.07 79.71 5,018.98 -2,640.87 2-11/16 2.99 0.53 2.48 Pass-Minor 1/10 9,149.58 6,681.70 9,150.00 6,685.76 0.07 0.10 79.63 5,035.66 -2,659.50 2-11/16 6.00 0.56 5.46 Pass-Minor 1/10 9,174.09 6,678.80 9,175.00 6,685.55 0.09 0.13 79.52 5,052.90 -2,677.60 2-11/16 10.02 0.61 9.45 Pass-Minor 1/10 9,198.32 6,675.23 9200.00 6,685.29 0.12 0.17 79.40 5,070.68 -2,695.18 2-11/16 15.06 0.66 14.44 Pass-Minor 1/10 9,223.05 6,671.17 9,225.00 6,684.98 0.15 0.21 81.11 5,088.98 -2,712.20 2-11/16 20.64 0.74 19.97 Pass-Minor 1/10 9,247,95 6,667.08 9,250.00 6,684.61 0.18 0.25 82.93 5,107.80 -2,728.65 2-11/16 26.18 0.81 25.47 Pass-Minor 1/10 9,273.00 6,662.97 9,275.00 6,684.20 0.22 0.29 84.90 5,127.03 -2,744.62 2-11/16 31.59 0.69 30.83 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/13/2015 1:15:32PM Page 2 COMPASS 5000.1 Build 74 1 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • TRANSMITTAL LETTER CHECKLIST WELL NAME: /(RL 3O— 9 IA13 PTD: 02�S ' �`['� I/ Development _Service Exploratory _Stratigraphic Test Non-Conventional FIELD: gra gt\ack. POOL: (ti d V 1 to() Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit / LATERAL No. oZ jS'1 T , API No. 50- 0 Qq-v g3 4 -01 - coq (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) 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 Pilot Hole name ( 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 conservation Spacing Exception 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 also required for this well: Well Logging 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 2/2015 0 • a) ° (ry , , 3' , , - - c , , m, , @: , .. a 0 o a L co w cn O': gr: t , , , , , co, c m w, 2 0) • 0 ` W c c: �, — a C, H o: ° 3. W: L of v 3. o 3, 'p: °, a o E: N: .0 a) .c V ' o , ID O. .- ry ,- E a): •o, , a , E of o 1 M. ., Z•, > w o' a , N; �, n c: N: ° ai N' a1' COa of D, o. : °: �, ,°: O a), as a) ai ° �' ai c a' c cc- , E); , D c CO Lo: ; ; , c 0 0' E' , a v m: o. m M: Y v QI rn 3. 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