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215-161
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Q 0 o a) 1/"'"_..... 0 a z E 0 o E U m Z 3 c,Lo ' 0 1'' m 0 F v 3 N N w D r W 0 .o, ,- 0 16 U m t7 Q E E 0 0 0 RECEIVED • STATE OF ALASKA • NOV 2 5 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG: la.Well Status: Oil 0 • Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development 0- Exploratory ❑ G❑J 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.: • 10/28/2015 215-161 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 •10/16/2015 50-029-21600-60-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 1434' FSL,318'FWL,Sec 35,T13N, R9E, UM °10/25/2015 KRU 3K-01L1/3K-01L1 PB1/3K-01L1 PB2 Top of Productive Interval: 9. Ref Elevations: KB:69 17. Field/Pool(s): 148T, FSL,776 FEL, Sec.27,T13N, R9E, UM GL: 28 BF: Kuparuk River Field/Kuparuk Oil Pool' Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1212'FNL,2416'FWL, Sec.34,T13N, R9E, UM n/a ADL 25519,25520 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 529306 y- 6008428 Zone-4 •12715/6534 2555/2556 TPI: x- 528183 y- 6013756 Zone-4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 526111 y- 6011050 Zone-4 no SSSV 1500'MD/1441'TVD 5. Directional or Inclination Survey: Yes Dattached) 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)I • 8753/6594 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 CASINGFT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 38 115 38 115 24 1540 Poleset 9 5/8 36 J-55 37 4919 37 3852 12 1/4 1400 sx ASLII,350 sx CI G 7 26 J-55 25.4 9140 25.4 6871 8 1/2 270 sx Class G, 175 sx AS I 2 3/8 4.6 L-80 8757 10316 6597 6592 3 Slotted Liner Open Hole 10316 11606 6592 6591 3 Open Hole 2 3/8 4.6 L-80 11606 12714 6591 6534 3 Slotted Liner 24. Open to production or injection? Yes 2 No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation Size SIZE DEPTH SET(MD) PACKER SET(MD/TVD) and Number): 3.5 8768 6954/5293 Slotted Liner from 8757'-10316'MD/6597'-6592'TVD Open Hole from 10316'-11606'MD/6592'-6591'TVD 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. Slotted Liner from 11606'-12714"MD/6591'-6534'TVD Was hydraulic fracturing used during completion? Yes❑ No El Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift, etc.): 11/3/2015 Gas Lift Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 11/6/2015 19 Test Period -kr- Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press.242 1386 24-Hour Rate - 370 203 1777 1777_ /Z6M.0 RBDM 1t Form 10-407 Revised 11/2015 2� CONTINUED UE1D�ONII7 GE 2 ���►� OV 3 0 201 l Submit ORIGINIAL on I / 0 • • • 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 7 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 El Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1500' 1441' Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 8842 6646 information, including reports, per 20 AAC 25.071. (Kuparuk A Sand) Total Depth 12715 6534 (Kuparuk A Sand) 3K-01L1 PB1 9889 6509 Total Depth(Kuparuk A3) 3K-01L1PB2 12173 6474 Total Depth(Kuparuk A2) Formation at total depth: Kuparuk A4 12571 31. List of Attachments: Summary of Daily Operations,Wellbore Schematic, Directional Survey 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: Mike Winfree p 263-4404 Email: Michael.A.WinfreeAcop.com % 2$4(1C— Printed Name: Kai Starck CTD Specialist ,� • '/ / Signature: ! ��r� Phone: 263-4093 Date: lI/Z 11 / L 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. Form 10-407 Revised 11/2015 Submit ORIGINAL Only ing "' . l li • Daily Operations Summary • Welifs 3K-01 Conoc®Phillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Daily Operations Start Date Last 24hr Sum 10/13/2015 Prep for move to 3K-01.Complete post RD checklist. Hold three year no LTI's presentation. Move rig module from 1G-05. Move CDR2 to 3K-Pad. 10/14/2015 Complete rig move to 3K-Pad. MIRU CDR2. Perform initial BOPE test,test waived by AOGCC(Bob Noble). 10/15/2015 Test PDL's, Pull BPV. MU coil connector and test.Test inner reel iron and pack-offs. Install UQC checks. MU BHA#1, RIH w/Milling assembly,tag whipstock @ 8,760.Swap well over to used mud system. Mill window exit from 8,759'to 8,766',calling bottom of window 8,764',milling in progress. 10/16/2015 Finish milling window exit to 8,767'. Drill ahead rathole to 8,780'. Back ream window as per well plan,dry drift clean, POOH for build assembly. Drill build section from 8,780'to 8,932'. POOH for higher bend motor. LD BHA#2, MU BHA#3, RIH w/2.3 AKO motor assembly.Start drilling build section,in progress. 10/17/2015 Continue drilling build section to end of build @ 9,150'. POOH for RSM assembly. LD BHA#3, MU BHA#4. RIH w/RSM drilling assembly,drill ahead L1 lateral from 9,150'to 9,529',drilling in progress. 10/18/2015 Drill ahead L1 lateral from 9,529'to 9,889'. PUH, pulled heavy from 9,768'to 9,370,bit stuck @ 8,810',worked free.Continue OOH, packing off in 3.5"tbg,getting stuck in big tail pipe crossover. RBIH,jet BTP,stacking ©8,810',work area. PUH,cleaner through 8,810', continue OOH,packing off at choke,jog at surface. PUD BHA#4, make choke repairs. PD BHA#5. RIH w/OH anchored billet. Develop leak at reel @ 8,397',lock-out reel,start repairs. 10/19/2015 Make inner reel iron repairs. Set OH anchored billet @ 9,110'180 degree LOHS. POOH for KO drilling assembly. RIH w/BHA#6,dry tag billet, pumps up,another leak at reel. Make repairs to inner reel iron and test. Had to repair wires at shaker motor. Kick-off billet @ 9,112',dry drift clean. Drill ahead to EOB @ 9,300'. POOH for RSM assembly. PUD BHA#6. 10/20/2015 RIH w/RSM drilling assembly.Drill ahead L1 lateral from 9,300'to 10,032',new mud swap @ 9,470',drilling in progress. 10/21/2015 Drill ahead L1 lateral from 10,032'to 11,410'.Pumped new mud system at bit 11,145',drilling in progress. 10/22/2015 Drill ahead L1 lateral from 11,410'to 12,174'.Several BHA wipers below 11,800',difficulty getting started drilling, low surface weight, low WOB. Had to reduce pump rate through 11,970'.At 12,174'town decide to POOH for agitator. POOH,jet 5.5"BTP, bottoms up, nothing unusual across shaker. PUD BHA#7. 10/23/2015 Function test BOP.PD BHA#8 agitator assembly, made several attempts to drill ahead @ 11,980',got stuck several times. Perform wiper,town decided to POOH for anchored billet. MADD pass from 10,092'to 9,620', perform SBHP @ window. POOH. PUD BHA#8, PD BHA#9. RIH w/ anchored billet @ 2,900'lost communication with MWD. POOH to troubleshhot MWD. Found broken wires in pigtail from collector to MWD, make repairs and test. 10/24/2015 RIH w/anchored billet to set depth @ 11,765', release from billet. POOH. PUD BHA#11. PD BHA#12, RIH w/agitator drilling assembly. Kick-off billet @ 11,767',dry drift clean.Pumped new mud system,new mud at bit 11,885'. Drill ahead lateral to 12,047',drilling in progress. 10/25/2015 Drill ahead lateral to called TD @ 12,715', pump 10 X10 sweeps,chase to swab,jet 5.5"BTP.Continue wiper to swab,at surface,choke plugging off, RBIH to 500',circulate till clean. POOH.Tag up reset depth. RBIH for corrected TD,tie-in for correction. Had to start working pipe at 12,100', cut pump rate to minunum,work to 12,490',getting some crude/gas to surface, in progress. 10/26/2015 RIH for corrected TD,work pipe down to 12,550', POOH laying beaded liner pill, paint EOP flag. LD BA#12. MU lower liner assembly, RIH w/BHA #13,release from liner @ 12,715',TOL @ 11,606'. POOH for second segment. LD BHA#13.MU upper liner assembly, MU BHA#13. 10/27/2015 RIH w/BHA#14 upper liner assembly,stack out off bottom at 10310 ft,release from OH Anchored billet off bottom at 8811 ft, POOH MU,single jt with three pups, RIH and set on bottom,TOL at 8757.3 ft.decision was made to RDMO,displaced well to SW and freeze protected well from 2500 ft, 10/28/2015 Closed Orbit valve, LD BHA#15, Flush coil and surface lines,set BPV, ND BOPE,RDMO CDR2 Page 1/1 Report Printed: 11/24/2015 KUP PROD • 3K-01 ConocoPhillips % *1,...,41 Well Attributes Max Angle&MD TD Alaska 1nCWellbore API/UWI Field Name Wellbore Statue nel(°) MD(IIKB) Act Btm(ftKB) fr4w'tv'taglpC 2 500292160000 KUPARUK RIVER UNIT PROD 47.53 3,800.00 9,150.0 •• Comment 9(25(ppm) Date Annotation End Date KB-0rd(k) Rig Release Date 3K-01.11/2420159'.02:20 AM. SSSV:NONE 90 5/5/2015 Last WO: 10/28/2015 40.78 8/27/1986 verdcsl schematic(actuay Annotation Depth(11KB) End Date Annotation Last Mod By End Date - --- -- Last Tag:SLM 8,836.0 8/20/2015 Rev Reason:ADD LATERAL,ADD NOTES lehallf 11/17/2015 HANGER;35.0 VA:, Casing Strings I . Caning Description OD(In) ID(In) Top(kKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(In) Top(kKB) Set Depth(ftKB) Set Depth(TVD)...WNLen(I...Grade Top Thread dA,i,�:m,,'e:uer,,,.e;e'ro;,n,aa,n,�n,,a, ” -. ...,..SURFACE 95/8 8.921 37.0 4,919.2 3852.4 36.00 J-55 BTC Casing Description '0D(In) ID(In) Top(ftKB) Set Depth(ftKB) Sat Depth(TVD)...WULen(I...Grade Top Thread ''°"�" ' PRODUCTION 7 6.276 25.4 9,139.7 6,870.9 26.00 J-55 BTC _ Tubing Strings CONDUCTOR,38.0-115.0 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft_.Set Depth(TVD)(...Wt(Ib1lt) Grade Top Connection I TUBING-WO 2015 3 1/2 2.992 35.0 8,768.0 6,605.3 9.30 L-80 EUE 8rd Mod GAS LIFT;2,962.5 Completion Details Nominal ID II Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 35.0 35.0 0.09 HANGER CAMERON CXS TUBING HANGER 2.950 ra BARRIER VLV;4,020.5 4,020.5 3,236.5 47.29 BARRIER VLV BAKER ORBIT BARRIER VALVE W/2 CONTROL LINES 2.890 II iv 8,559.8 6,453.9 42.85 LOCATOR BAKER GBH-22 LOCATOR SUB 2.980 li 8,560.8 6,454.7 42.85 SEAL ASSY BAKER 80-40 GBH-22 SEAL ASSEMBLY 2.980 GAS LIFT,4,766.9 lir 8,566.4 6,458.8 42.85 PBR BAKER 80-40 PBR 4.000 8,589.5 6,475.7 42.84 PACKER BAKER 4762 FHL RETRIEVABLE PACKER 2.920 5,642.9 6,514.8 43.27 NIPPLE HALLIBURTON X NIPPLE 2.813 8,684.6 6,545.0 43.69 XO Enlarging Ported Crossover,3-1/2"EUE 8rd Mod Box x 5-1/2"STC 2.992 SURFACE;37.0-4,919.2 Pin 8,685.6 6,545.7 43.70 WEARSOX 6"OD Wearsox,5-1/2".149.J-55,STC Box x Pin 5.012 GAS LIFT;6,175.6 Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (kKB) 1°) Des Com Run Date ID(In) 8,753.0 6,594.4 43.79 WHIPSTOCK BAKER GEN II:RA TAG AT 8757' 9/5/2015 GAS LIFT.7,229.4 I 8.977.0 6,755.1 44.60 FISH DMY 1 1/2"DMY Dropped In Rathole 10/17/1986 10/17/1986 0.000 SI Perforations&Slots Shot Dene GAS LIFT,8,005.6 ITop)TVD) Bim(TVD) (shotsR Top(kKB) Btm(kKB) (kKB) (111413) Zone Date 1) Type Com 8.8100 8,850.0 6,641.4 6,664.4 A-4,A-3,3K- 6/6/1990 6.0 RPERF 21/8"Dyna Strip;Odeg. 01 ph GAS LIFT,8.503.2 1 8,824.0 8,844.0 6,645.7 6,660.1 A-4,A-3,3K- 5/18/1996 4.0 RPERF 21/8"EJ;180 deg ph; 01 Orient H-90 deg F/ owside 8,830.0 8,831.0 6,650.0 6,650.7 A-3,3K-01 8/25/1986 1.0 IPERF 4"Csg Gun;120 deg.ph LOCATOR:8.559.8 irsi SEAL ASSY;8,560.8 8,834.0 8,835.0 6,652.9 6,653.6 A-3,3K-01 8/25/1986 1.0 IPERF 4"Csg Gun;120 deg.ph PBR,8,586.4 PACKER.8,589.5 8,836.0 8,837.0 6,654.3 6,655.0 A-3,3K-01 8/25/1986 1.0 IPERF 4"Csg Gun;120 deg.ph 8,850.0 8,896.0 6,664.4 6,697.3 A-3,A-2,3K- 6/6/1990 6.0 RPERF 2 1/8"DynaSeip;O deg ph 01 NIPPLE;8,642.9 8.865.0 8,866.0 6,675.2 6,675.9 A-2,3K-01 8/25/1986 1.0 IPERF 4"Csg Gun;120 deg.ph 1 8,869.0 8,870.0 6,678.0 6,678.7 A-2,3K-01 8/25/1986 1.0 IPERF 4"Csg Gun;120 deg.ph XO Enlarging,8.684.5 I WEARS0X:8,685 s 8873.0 8,874.0 6,680.9 6,681.6 A-2,3K-01 8/25/1986 1.0 IPERF 4"Csg Gun;120 deg.ph 1r 8.876.0 8,877.0 6,683.0 6,683.8-A-2,3K-01 8/25/1986 1.0 IPERF 4"Csg Gun;120 deg.ph " WHIPSTOCK;8,753.0 i., EI 1, 8,881.0 8,893.0 6,686.6 6,695.2 A-2,3K-01 8/25/1986 4.0 IPERF 4"Csg Gun;120 deg.ph SLOTS:8,757.0-10,316.0 I I Mandrel inserts L1 LINER;8,756.3-12,715.0 NI - 9t atl on Top(TVD) Valve Latch Pon Size TRO Run N Top(kKB) (ROB) Make Model 00(In) Sere Type Type (in) (pei) Run Date Com 1 2,962.5 2,508.7 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,320.0 11/2/2015 2 4,766.9 3,746.1 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,306.0 11/2/2015 IPERF,8,830.0-8,831.0- 3 6,175.6 4,740.1 CAMCO MMG 11/2 GAS LIF T GLV RK 0.188 1,293.0 11/1/2015 RPERF:8 824.04 844 0 RPERF.8.818.0-8850.0 4 7,229.4 5,491.9 CAMCO MMG 11/2 GAS LIFT OV RK 0.250 0.0 11/1/2015 IPERF:8.834.0-81535.0 - 5 8,005.6 6,052.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 7/12/2015 6 8,503.2 6,412.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0000 0.0 7/12/2015 IPERF'8 636 0-8,637.0 Notes:General&Safety _ End Date Annotation 8/30/2004 NOTE:WAIVERED WELL:IA x OA COMMUNICATION IPERF;8,885.0-8.866.0 11/2/2010 NOTE:View Schematic w/Alaska SchemaBc9.0-BAD PROD CSG RKB _ 7/12/2015 NOTE:Orbit Valve Is NOT a safety valve,it does not fail to closed position. IPERF'.8.889.0-8,870.0-/ 7/12/2015 NOTE:Orbit Valve Control lines/system at Wellhead marked Open/Close. RPERF;8,850.0-8.896.0 L. IPERF:6873 0-8.674.0-,. . IPERF'.8,878.0-8,877.0 IPERF;8,881.0.8.853.0- FISH,8.977.0 4 PRODUCTION,25.4-9.139.7 es 4t • , 4Ik KUP PROD • 3K-01 L1 Cono+CO (Hips Well Attributes Max Angle&MD TD H].,k ,1\_y Wellbore API/UWI Field Name Wellbore Status Intl(°) MD(RKB) .TD Btrn(ftKB) t- mm 500292160060 KUPARUK RIVER UNIT PROD 103.66 12125.56 12,715.0 ••• Comment H25(ppm) Date Annotation End Date KB•Grd(ft) Rig Release Date 36011.1,11,24,2015 9 58 45 A:•. SSSV:NONE 90 5/5/2015 Last WO: 10/28/2015 40.78 8/27/1986 VefOcal5c11em ( t.,). Annotation Depth(11KB) End Date Annotation IJ Last Mod By End Date ---- Last Tag: Rev Reason:ADD LATERAL,ADD NOTES lehallf 11/17/2015 HANGEN:3S.0 CooingCasing DeaerlptlonStrings 00(In) ID(In) Top(ftKB) Set Depth ICES) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ,t L1 LINER 23/8 1.992 8,756.3 12,715.0 4.60 L-80 SL-T C I Liner Details ,/, Nominal ID Top(CEO) Top(TVD)(RKB) Top Irlel(°) Item DeeCom (In) • CONDUCTOR,38.0-115.0 6,756.3 6,596.8 44.32 DEPLOY Shorty Deployment Sleeve 1.920 8,810.0 6,631.2 57.83 BILLET OH Anchored Aluminum Billet 1.920 GAS LIFT:2,962.5 a 10,316.5 6,591.7 93.13 Open Hole Open Hole 3.000 11,606.5 6,591.3 87.49 DEPLOY Shorty Deployment Sleeve 1.920 Perforations&Slots BARRIER VLV,4,020.5 ^'.4 Shot Dens 11 Top(TVm(TVD) (shotsif Top(10551) Btm(ftKB) (RKB)D) Bi(RKB) Zone Dale 1) Type Com GAS LIFT,4.766.9 I 8.757.0 10,316.0 6,597.3 6,591.7 A-2,3K-01 10/27/2015 SLOTS Slotted Liner 10.317.0 11,606.0 6,591.6 6,591.3'A-2,3K-01 10/27/2015 1.0 SLOTS Open Hole 3" 11,607.0 12,714.0 6,591.3 6,533.7•A-2,3K-01 10/27/2015 SLOTS Slotted Liner SURFACE,37.0-4,919.2 R° Notes:General&Safety GAS LIFT:6.175.6 K. End Date Annotation it 7/177015 NOTE:Orbit Valve is NOT a safety valve,it does not fail to closed position. ii 7/12/2015 NOTE:Orbit Valve Control lines/system at Wellhead marked Open/Close. GAS LIFT.7,229.4 , It GAS LIFT,8,005.6 it GAS LIFT:8,503.2 I LOCATOR',8.559.8 SEAL ASSY;8.560,8 000,0.566 4 PACKER:8.589.5 III NIPPLE;8,642.9 me 111 SO Enlarging,8,884.5 W FARSOX;8,685.5 1I, 1 WHIPSTOCK;8,753.0 1�= tf I I . iiii i s (PERF;8,830.0.0.831.0—. a s = RPERF'.8.818.0-8.650.0 RPERF',8624.0.8.844.0 I PERF',8,834.0-8.8350 IPERF',8,0380-8.637.0— 1 i • a ■■ a - IPERF 8.865.0-8 866.0 ! IN IE IPERF'8 869.0-8,870.0 RPERF;8.850.0.8,898.0 , IPERF'.8:873.0.8,674.0 1 IPERF 8.876.0-8,877.0— II E * 1 IPERF,8,881.0-8.893.0— a FISH',8,977.0 1 , al PRODUCTION.25.4-9.139.7 1111 I SLOTS;8,757.0.10,316.0-- SLOTS;10,317.0-11,606.0 SLOTS.11.607.0.12.714.0 L1 LINER:8.758.3-12,715.0 I i '. IVED iterations Summary (with TimelogWpths) 0; DEC 182015 3K-01 AOGCC C000coPhillps 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) 10/13/2015 10/13/2015 2.50 MIRU MOVE MOB P Prep to move rig to 3K-01.Pull pit 0.0 0.0 15:00 17:30 module. 10/13/2015 10/13/2015 1.50 MIRU MOVE SFTY P Hold three year no LTI's presentation 0.0 0.0 17:30 19:00 with Dan Venhaus and crew.PJSM Peak&night crew. 10/13/2015 10/13/2015 1.00 MIRU MOVE MOB P Pull rig module off of 1G-05.Ready for 0.0 0.0 19:00 20:00 move to 3K-Pad. 10/13/2015 10/14/2015 4.00 MIRU MOVE MOB P Move CDR2 to 3K-Pad. 0.0 0.0 20:00 00:00 10/14/2015 10/14/2015 0.50 MIRU MOVE MOB P Complete rig move to 3K-Pad. 0.0 0.0 00:00 00:30 10/14/2015 10/14/2015 3.50 MIRU MOVE MOB P Spot rig module on 3K-01.Retrieve 0.0 0.0 00:30 04:00 shop from to 1G-Pad.Spot on 3K- Pad.Release Peak. 10/14/2015 10/14/2015 2.00 MIRU MOVE RURD P PJSM.MIRU CDR2.Start post rig 0.0 0.0 04:00 06:00 move checklist. 10/14/2015 10/14/2015 3.00 MIRU MOVE RURD P Continue rig up,Work post rig move 0.0 0.0 06:00 09:00 check list,Test E-Line all good,Pump 3 BBIs methonal into coil from LRS 10/14/2015 10/14/2015 1.00 MIRU MOVE RURD P Test torque on tree found loose bolts 0.0 0.0 09:00 10:00 on tree 10/14/2015 10/14/2015 12.00 MIRU WHDBOP BOPE P Nipple up BOP equipment,Change 0.0 0.0 10:00 22:00 out riser Test BOPE's.Test waived by AOGCC(Bob Noble). Rig Accept 10:00AM 10/14/2015 10/14/2015 1.50 MIRU WHDBOP BOPE T Had leak at 2 3/8"door seal.Replaced 0.0 0.0 22:00 23:30 door seal,finish remaining two test. Note: 1.5 HRS Billable 10/14/2015 10/15/2015 0.50 MIRU WHDBOP PRTS P LD BOP test equipment.Prep to test 0.0 0.0 23:30 00:00 PDL's. 10/15/2015 10/15/2015 1.25 MIRU WHDBOP PRTS P PJSM.Test PDL's. 0.0 0.0 00:00 01:15 10/15/2015 10/15/2015 1.50 MIRU WHDBOP MPSP P PJSM.RU FMC equipment,Pull BPV, 0.0 0.0 01:15 02:45 LD FMC lubricator. 10/15/2015 10/15/2015 3.20 SLOT WELLPR CTOP P PJSM. Install pack-offs.Boot E-line, 0.0 0.0 02:45 05:57 Stab on and fill coil pumping forward, Install counters 10/15/2015 10/15/2015 1.60 SLOT WELLPR CTOP P Prep CT and install CTC, Pull test to 0.0 0.0 05:57 07:33 35K 10/15/2015 10/15/2015 1.60 SLOT WELLPR CTOP P Head up a-line,PT CTC to 4500 PSI, 0.0 0.0 07:33 09:09 10/15/2015 10/15/2015 0.90 MIRU WHDBOP BOPE P Test and chart Inner reel iron and 0.0 0.0 09:09 10:03 stripper 10/15/2015 10/15/2015 1.00 PROD1 WHPST PULD P PJSM,P/U BHA#1,Window milling 0.0 74.3 10:03 11:03 BHA with.6°motor,2.80 window mill, and 2.79 string reamer.M/U to coil and surface test,tag up and set counters 10/15/2015 10/15/2015 2.70 PROD1 WHPST TRIP P RIH,EDC closed,on seawater, 74.3 8,375.0 11:03 13:45 returns to TT 10/15/2015 10/15/2015 0.20 PROD1 WHPST DLOG P Log K1 for+3.5',PUW=42K 8,375.0 8,403.0 13:45 13:57 10/15/2015 10/15/2015 1.10 PROD1 WHPST TRIP P Continue in well,Roll hole to used 8.9 8,403.0 8,752.5 13:57 15:03 PPG flo pro Page 1/11 Report Printed: 12/18/2015 it 0 Summary (with Timelogtpths) +a rr 3K-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) 10/15/2015 10/15/2015 0.30 PROD1 WHPST TRIP P Initial tag whipstock pinch point @ 8,752.5 8,760.0 15:03 15:21 8752.2,Didn't look right,Maybe degradeable plug material?.PUH and make second run.Call pinch point @ 8760. 10/15/2015 10/16/2015 8.65 PROD1 WHPST WPST P Start milling window,call pinch point 8,760.0 8,766.0 15:21 00:00 @ 8759, 1.48 BPM @ 3048PS1 FS, BHP=3768.Call bottom of window 8,764'.Milling in progress. 10/16/2015 10/16/2015 0.75 PROD1 WHPST WPST P Continue milling window exit 8,766.0 8,767.0 00:00 00:45 10/16/2015 10/16/2015 3.15 PROD1 WHPST WPST P Drill ahead rathole: 1.48 BPM @ 3,140 8,767.0 8,780.0 00:45 03:54 PSI,BHP=3,760 PSI,CTW=9.5K, WOB=1.6K,ROP=4 10/16/2015 10/16/2015 1.25 PROD1 WHPST REAM P Back ream window as per well plan, 8,780.0 8,755.0 03:54 05:09 dry drift window,window clean. 10/16/2015 10/16/2015 2.40 PROD1 WHPST TRIP P Trip out of hole 8,755.0 80.0 05:09 07:33 10/16/2015 10/16/2015 1.00 PROD1 WHPST PULD P 30 Min flow check,PJSM,Lay down 80.0 0.0 07:33 08:33 BHA#1 2.79 No Go on mill 10/16/2015 10/16/2015 1.10 PROD1 DRILL PULD P Service injector and reel,P/U BHA#2 0.0 72.2 08:33 09:39 2°motor and RR bi center bit,M/U to coil and surface test 10/16/2015 10/16/2015 1.90 PROD1 DRILL TRIP P RIH,EDC open,Pumping min rate 72.2 8,367.0 09:39 11:33 10/16/2015 10/16/2015 0.20 PROD1 DRILL DLOG P Tie into K1 for+2.5'correction 8,367.0 8,387.0 11:33 11:45 10/16/2015 10/16/2015 0.50 PROD1 DRILL RGRP T Swap out injector motor control 8,387.0 8,387.0 11:45 12:15 encoder,Motors seem to be out of sync with each other 10/16/2015 10/16/2015 0.20 PROD1 DRILL TRIP P Continue in well,close EDC,Clean 8,387.0 8,780.0 12:15 12:27 pass through window,Tag up @ 8780 10/16/2015 10/16/2015 3.60 PROD1 DRILL DRLG P 8780',Drill, 1.5 BPM @ 3260 PSI FS, 8,780.0 8,932.0 12:27 16:03 BHP=3771,Started taking minor fluid losses at-8840 10-12 BPH.Not getting anticipated DLS.First survey -30°second survey @ 34°.Confir with town.POOH for increase motor angle 10/16/2015 10/16/2015 2.95 PROD1 DRILL TRIP T Not getting anticipated DL's.Trip out 8,932.0 72.5 16:03 19:00 for higher bend motor 10/16/2015 10/16/2015 2.50 PROD1 DRILL PULD T Close Baker Orbit valve,bleed 72.5 72.5 19:00 21:30 wellhead to zero.PJSM.Reconfigure BHA,change motors.MU BHA#3. 10/16/2015 10/16/2015 2.25 PROD1 DRILL TRIP T RIH w/BHA#3,equalize wellhead 72.5 8,932.0 21:30 23:45 pressure,open Orbit have.RIH,tie-in to K1 for+1'correction,continue in hole. 10/16/2015 10/17/2015 0.25 PROD1 DRILL DRLG P Drill ahead: 1.50 BPM @ 3,650 PSI, 8,932.0 8,949.0 23:45 00:00 BHP=4,030 PSI,CTW=10K, WOB=1.5K,ROP=70 10/17/2015 10/17/2015 3.35 PROD1 DRILL DRLG P Continue drilling build section: 1.50 8,949.0 9,150.0 00:00 03:21 BPM @ 3,725 PSI,BHP=4,090 PSI, CTW=9.5K,WOB=1.2K,ROP=80. Called EOB @ 9,150'.. 10/17/2015 10/17/2015 1.80 PROD1 DRILL TRIP P POOH for RSM assembly,open EDC 9,150.0 85.5 03:21 05:09 @ 8718' Page 2/11 Report Printed: 12/18/2015 0. aerations Summary (with Timelogitpths) 6, r 3K-01 conocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth', StartTime` End Time Dur(hr)( Phase Op Code Activity Code Time P-T-X Operation [. (ftKB) - End Depth(ftKB) 10/17/2015 10/17/2015 0.90 PROD1 DRILL PULD P At surface close orbit valve,High bend 85.5 0.0 05:09 06:03 motor.Bleed off well,Lay down BHA #3 10/17/2015 10/17/2015 0.70 PROD1 DRILL PULD P PJSM,P/U BHA#4 New Bi center 0.0 69.2 06:03 06:45 with rib steer motor 10/17/2015 10/17/2015 1.00 PROD1 DRILL SVRG P Service reel and injector,Inspect pack 69.2 69.2 06:45 07:45 offs and checks in UQC,Stab coil on BHA and surface test 10/17/2015 10/17/2015 2.00 PROD1 DRILL TRIP P Pressure up well,open orbit valve, 69.2 8,370.0 07:45 09:45 RIH BHA#4 10/17/2015 10/17/2015 0.10 PROD1 DRILL DLOG P Log K1 for+2', 8,370.0 8,388.0 09:45 09:51 10/17/2015 10/17/2015 0.40 PROD1 DRILL TRIP P Continue in well,Stop and close EDC 8,388.0 9,150.0 09:51 10:15 @ 8659',PUW=32K,clean trip past window,Had to shove a bit in build with RSM 10/17/2015 10/17/2015 12.35 PROD1 DRILL DRLG P 9150',Drill ahead, 1.5 BPM @ 3430 9,150.0 9,510.0 10:15 22:36 PSi FS,BHP=4722,MUD SWAP new mud @ bit 9180' 10/17/2015 10/17/2015 0.70 PROD1 DRILL WPRT P Wiper to window,PUW=31K,RBIH. 9,510.0 9,510.0 22:36 23:18 10/17/2015 10/18/2015 0.70 PROD1 DRILL DRLG P Drill ahead: 1.50 BPM @ 3,670 PSI, 9,510.0 9,529.0 23:18 00:00 BHP=4,155 PSI,CTW=8.5K, WOB=1.8K,ROP=25. 10/18/2015 10/18/2015 2.20 PROD1 DRILL DRLG P Drill ahead: 1.50 BPM @ 3,670 PSI, 9,529.0 9,574.0 00:00 02:12 BHP=4,155 PSI,CTW=8.5K, WOB=1.8K,ROP=25.High differential pressure @ 9,570',pull BHA wiper, small over pull @ 9,535'(35K).RBIH, stacking @ 9,540'.PUH.RBIH at reduce pump rate,no issue,continue drilling. 10/18/2015 10/18/2015 0.50 PROD1 DRILL WPRT P BHA Wiper,200', PUW=32K 9,574.0 9,574.0 02:12 02:42 10/18/2015 10/18/2015 4.10 PROD1 DRILL DRLG P 9574',Drill, 1.52 BPM @ 3490 PSi FS, 9,574.0 9,703.0 02:42 06:48 BHP=4165 10/18/2015 10/18/2015 0.10 PROD1 DRILL WPRT P BHA Wiper,PUW=29K 9,703.0 9,703.0 06:48 06:54 10/18/2015 10/18/2015 4.40 PROD1 DRILL DRLG P 9703',Drill, 1.49 BPM @ 3481 PSI 9,703.0 9,889.0 06:54 11:18 FS,BHP=4150 10/18/2015 10/18/2015 5.00 PROD1 DRILL TRIP T Pump 5 X 5 sweeps.POOH for Billet, 9,889.0 68.6 11:18 16:18 PUW=30K,Poor hole conditions with overpulls and packing off 9768 to 9370,Stall @ 8816 with overpull,Hard to RBIH,Get free,stalling and overpull in 5 1/2.Work clear,circ bottoms up. RBIH to 9150,Slight stacking @ 8815, Trip out.Well unloaded small shales and clays @ 1100'.Plugged off choke B.RBIH while swapping to choke A. Perform jog at surface 10/18/2015 10/18/2015 2.60 PROD1 DRILL PULD T PJSM,PUD BHA#4,LD BHA.Crew 68.6 0.0 16:18 18:54 change,flush out surface lines. 10/18/2015 10/18/2015 2.50 PROD1 DRILL PULD T PJSM.MU/PD BHA#5.Work on 0.0 72.5 18:54 21:24 choke. 10/18/2015 10/18/2015 2.10 PROD1 DRILL TRIP T RIH W/OH anchored billet,tie-in to 72.5 8,397.0 21:24 23:30 K1for+1.5'correction,test HOT. Continue in hole. Page 3/11 Report Printed: 12/18/2015 ........ !Iterations Summary (with Timelog•pths) O. . .. ...._ 3K-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) 10/18/2015 10/19/2015 0.50 PROD1 DRILL TRIP T Develop leak at reel,inspect reel, 8,397.0 8,397.0 23:30 00:00 found connection on inner reel iron leaking,shut down pump,locked-out reel. 10/19/2015 10/19/2015 1.50 PROD1 DRILL TRIP T Continue inner reel iron repair and 8,397.0 8,397.0 00:00 01:30 clean-up.Repairs/clean-up complete. Note:2 HRS Billable down time 10/19/2015 10/19/2015 0.75 PROD1 DRILL TRIP T Weight check 29K,close EDC.TIH to 8,397.0 9,121.8 01:30 02:15 set depth @ 9,122',some stacking @ 8,810'.Bring pump online,set billet, KO orientation 150 deg LOHS,TOB @ 9,110',stack 4K down on billet. 10/19/2015 10/19/2015 1.75 PROD1 DRILL TRIP T POOH for drilling assembly 9,121.8 73.5 02:15 04:00 10/19/2015 10/19/2015 2.00 PROD1 DRILL PULD T PJSM.PUD BHA#5 73.5 0.0 04:00 06:00 10/19/2015 10/19/2015 1.00 PROD1 DRILL SVRG T Reconf BHA-Service reel and injector 0.0 0.0 06:00 07:00 10/19/2015 10/19/2015 1.00 PROD1 STK PULD T PD BHA#6, M/U to coil and surface 0.0 72.2 07:00 08:00 test,Tag up and set counters 10/19/2015 10/19/2015 1.90 PROD1 STK TRIP T RIH,EDC Open 72.2 8,367.0 08:00 09:54 10/19/2015 10/19/2015 0.10 PROD1 STK DLOG T Log K1 for+2.5 8,367.0 8,384.0 09:54 10:00 10/19/2015 10/19/2015 0.40 PROD1 STK TRIP T Continue in well.Close EDC above 8,384.0 9,112.0 10:00 10:24 window,Clean pass through window. Slight bobble at 8814 continue in.Dry tag TOB @9112 10/19/2015 10/19/2015 0.40 PROD1 STK TRIP T Bring pumps on to mill off billet,Inner 9,112.0 9,112.0 10:24 10:48 reel iron connection failed,Shut down pumps line up accross top to maintain BHP.Pull to caseing 10/19/2015 10/19/2015 3.00 PROD1 STK RGRP T In cased hole,re configure inner reel 8,650.0 8,650.0 10:48 13:48 hardline,Replace damaged hardline rubber,Secure iron.PT to 3500PSI Nabors 3 hours NPT 10/19/2015 10/19/2015 3.20 PROD1 STK RGRP T Electrical problem with shaker motor 8,650.0 8,650.0 13:48 17:00 electrical supply wiring NABORS 3 Hrs NPT 10/19/2015 10/19/2015 0.40 PROD1 STK TRIP T RIH to KO billet 8,650.0 9,110.7 17:00 17:24 10/19/2015 10/19/2015 1.50 PROD1 STK KOST T Time mill off billet as per well plan. 9,110.7 9,120.0 17:24 18:54 10/19/2015 10/19/2015 1.95 PROD1 DRILL DRLG T Drill ahead: 1.50 BPM @ 3,675 PSI, 9,120.0 9,300.0 18:54 20:51 BHP=4,090 PSI,CTW=10.5K, WOB=2K,ROP=90.Dry drift billet, clean.Called EOB @ 9,300'. 10/19/2015 10/19/2015 2.05 PROD1 DRILL TRIP T POOH for RSM assembly 9,300.0 78.5 20:51 22:54 10/19/2015 10/20/2015 1.10 PROD1 DRILL PULD T PJSM.PUD BHA#6,LD BHA. 78.5 0.0 22:54 00:00 10/20/2015 10/20/2015 1.10 PROD1 DRILL PULD T PJSM.MU/PD BHA#7 0.0 69.5 00:00 01:06 10/20/2015 10/20/2015 2.45 PROD1 DRILL TRIP T RIH w/BHA#7,tie-in for+1.5' 69.5 9,300.0 01:06 03:33 correction,continue in hole. Page 4/11 Report Printed: 12/18/2015 ,.., ,,,,,, 0 erations Summary (with Timelogitpths) 3K-01 ConocoPhiaps 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). 10/20/2015 10/20/2015 7.30 PROD1 DRILL DRLG T Drill ahead: 1.48 BPM @ 3,765 PSI, 9,300.0 9,510.0 03:33 10:51 BHP=4,095 PSI,CTW=8.5K, WOB=2.2K,ROP=35. "Note:Mud swap performed,new mud at bit 9,471 ft.System 1 finished with.75%DS, 1060 ft drilled. 10/20/2015 10/20/2015 0.80 PROD1 DRILL WPRT T Wiper trip to 8,820 ft.PUW 29k,RBIH 9,510.0 9,510.0 10:51 11:39 10/20/2015 10/20/2015 4.00 PROD1 DRILL DRLG T 9,510 ft.OBD 1.7 bpm at 3,890 psi, 9,510.0 9,710.0 11:39 15:39 BHP 4,130 psi,CWT 10.4k,WOB 1.7k,ROP 50 10/20/2015 10/20/2015 0.95 PROD1 DRILL WPRT T Wiper to window,PUW 29k,saw a 9,710.0 8,690.0 15:39 16:36 little motor work at 8,800 ft.Jet/jog 5 1/2"BTP at 1.7 bpm,motor stall at 8,696 ft(BTP XO at 8,686 ft) jog BTP, jet BTP,clean to 8,690 ft,jog BTP 10/20/2015 10/20/2015 0.15 PROD1 DRILL DLOG T Log RA for plus.5 ft correction,slack 8,690.0 8,790.0 16:36 16:45 off 3k at 8,810 ft,PU and run thru no problem. 10/20/2015 10/20/2015 0.50 PROD1 DRILL WPRT T Wiper back in hole,RIW12k. 8,790.0 9,710.0 16:45 17:15 10/20/2015 10/20/2015 3.75 PROD1 DRILL DRLG T 9,710 ft.OBD 1.7 bpm at 3,900 psi, 9,710.0 9,910.0 17:15 21:00 BHP 4,140 psi,CWT 9.4k,WOB 1.7k, ROP 50.Couple stalls @ 9,720',work through.Continue drilling, 10/20/2015 10/20/2015 0.50 PROD1 DRILL WPRT P Wiper to 9,150',PUW=29.5K,RBIH. 9,910.0 9,910.0 21:00 21:30 10/20/2015 10/21/2015 2.50 PROD1 DRILL DRLG P Drill ahead: 1.69 BPM @ 3,850 PSI, 9,910.0 10,032.0 21:30 00:00 BHP=4,195 PSI,CTW=9K, WOB=2.2K,ROP=50. 10/21/2015 10/21/2015 0.90 PROD1 DRILL DRLG P Drill ahead: 1.70 BPM @ 3,925 PSI, 10,032.0 10,110.0 00:00 00:54 BHP=4,175 PSI,CTW=8K,WOB=2K, ROP=85. 10/21/2015 10/21/2015 1.80 PROD1 DRILL WPRT P Wiper to window,PUW=30K,jet 5.5" 10,110.0 10,110.0 00:54 02:42 BTP,tie-in RA for+1.5'correction, RBIH. 10/21/2015 10/21/2015 2.60 PROD1 DRILL DRLG P Drill ahead: 1.67 BPM @ 4,030 PSI, 10,110.0 10,310.0 02:42 05:18 BHP=4,185 PSI,CTW=9K, WOB=1.5K,ROP=85. 10/21/2015 10/21/2015 0.85 PROD1 DRILL WPRT P Wiper up hole to 9,200 ft,PUW 29.5k, 10,310.0 10,310.0 05:18 06:09 RBIH 10/21/2015 10/21/2015 2.25 PROD1 DRILL DRLG P 10,310 ft.OBD 1.67 bpm at 4,050 psi, 10,310.0 10,510.0 06:09 08:24 BHP 4,180 psi,CWT 8.2k,WOB 2.0k, ROP 95. 10/21/2015 10/21/2015 1.85 PROD1 DRILL WPRT P Wiper to window,PUW 29.5k,jet 5 10,510.0 10,510.0 08:24 10:15 1/2"BTP,RA tie in for+2 ft correction, RBIH,smooth and clean in and out. 10/21/2015 10/21/2015 3.15 PROD1 DRILL DRLG P 10,510 ft.OBD 1.67 bpm at 4,005 psi, 10,510.0 10,810.0 10:15 13:24 BHP 4,190 psi,CWT 7.8k,WOB 1.5k, ROP 95 10/21/2015 10/21/2015 0.80 PROD1 DRILL WPRT P Wiper up hole to 9,800 ft,PUW 29k, 10,810.0 10,810.0 13:24 14:12 RBIH 10/21/2015 10/21/2015 3.00 PROD1 DRILL DRLG P 10,810 ft.OBD 1.67 bpm at 4,200 psi, 10,810.0 11,110.0 14:12 17:12 BHP 4,249 psi,CWT 6.6k,WOB 2.0k, ROP 80 Page 5/11 Report Printed: 12/18/2015 •perations Summary (with TimelogIpths) 0 3K-01 ConocoPhillips hfv1- 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) 10/21/2015 10/21/2015 2.35 PROD1 DRILL WPRT P Wiper to window,PUW 31k,pump 11,110.0 11,110.0 17:12 19:33 5x5, jet 5 1/2"BTP,tie-in RA tag for +2'correction.RBIH. 10/21/2015 10/21/2015 4.05 PROD1 DRILL DRLG P Drill ahead: 1.69 BPM @ 3,920 PSI, 11,110.0 11,410.0 19:33 23:36 BHP=4,275 PSI,CTW=4K, WOB=1.5K,ROP=75.Start pumping new mud,mud at bit 11,145'. 10/21/2015 10/22/2015 0.40 PROD1 DRILL WPRT P Wiper trip,PUW=32K. 11,410.0 11,410.0 23:36 00:00 10/22/2015 10/22/2015 1.35 PROD1 DRILL WPRT P Continue short wiper trip,RBIH.PUH 11,410.0 11,410.0 00:00 01:21 for GEO wiper. 10/22/2015 10/22/2015 4.70 PROD1 DRILL DRLG P Drill ahead: 1.69 BPM @ 3,975 PSI, 11,410.0 11,710.0 01:21 06:03 BHP=4,290 PSI,CTW=5K, WOB=1.8K,ROP=60. 10/22/2015 10/22/2015 2.75 PROD1 DRILL WPRT P Wiper to window, PUW 28k,RA tie in 11,710.0 11,710.0 06:03 08:48 for+6 ft correction,RBIH. 10/22/2015 10/22/2015 5.75 PROD1 DRILL DRLG 'P 11,710 ft.OBD 1.68 bpm at 4,059 psi, 11,710.0 12,030.0 08:48 14:33 BHP 4,285 psi,CWT 6.2k,WOB 1.5k, ROP 60 10/22/2015 10/22/2015 1.10 PROD1 DRILL WPRT P Wiper up hole to 10,800 ft,PUW 28k, 12,030.0 12,030.0 14:33 15:39 RBIH,stacking at 11,972 ft,PUW 29k, reduce rate to 1 bpm,RBIH,same results at 11,974',PUW 29k,reduce rate to.7 bpm,RBIH no problems. 10/22/2015 10/22/2015 1.50 PROD1 DRILL DRLG P 12,030 ft.OBD 1.58 bpm at 4,089 psi, 12,030.0 12,174.0 15:39 17:09 BHP 4,284 psi,CWT 6k,WOB 1.9k, ROP 80.Losing WOB&surface weight,trouble getting going. 10/22/2015 10/22/2015 0.45 PROD1 DRILL WPRT P Wiper to 11,950',drag @ 11,974'. 12,174.0 12,174.0 17:09 17:36 RBIH,OK through it,stacking 12,030'. Work down to 12,174'. 10/22/2015 10/22/2015 0.50 PROD1 DRILL DRLG P BOBD: 1.60 BPM @ 4,060 PSI, 12,174.0 12,174.0 17:36 18:06 BHP=4,330 PSI,low coil weight,low WOB.Make wiper to window.Town decided to POOH for agitator.Pump 5 X5 sweep. 10/22/2015 10/22/2015 3.85 PROD1 DRILL TRIP P POOH for agitator assembly,jet 5.5" 12,174.0 75.5 18:06 21:57 BTP max rate,bottoms up,nothing unusual across shaker.Continue OOH. 10/22/2015 10/23/2015 2.05 PROD1 DRILL PULD P PJSM.PUD BHA#7,LD BHA,crew 75.5 0.0 21:57 00:00 change. 10/23/2015 10/23/2015 1.10 PROD1 DRILL BOPE P Perform BOP function test. 0.0 0.0 00:00 01:06 10/23/2015 10/23/2015 1.65 PROD1 DRILL PULD P PJSM.PD BHA#8,check UQC and 0.0 78.5 01:06 02:45 pack-offs. 10/23/2015 10/23/2015 3.85 PROD1 DRILL TRIP P RIH w/agitator drilling assembly. 78.5 11,982.0 02:45 06:36 close EDC,surface test agitator,test HOT.Continue in hole,tie-in for+3.5' correction,continue in hole,circulate out crude,take 70 bbls outside for clean up.Stacking at 11,980 ft, pulled free with 40k,pumps down,try again different rates,speeds,TF-HS,90R, 180,stuck each time,47k max pull to free up BHA, 10/23/2015 10/23/2015 1.95 PROD1 DRILL WPRT T Wiper up hole per town,waiting on 11,982.0 11,200.0 06:36 08:33 instruction.swab on pump 1 out,use pump2 while pump 1 repaired. Page 6/11 Report Printed: 12/18/2015 iterations Summary (with Timelog•pths) 0 iii 3K-01 Conotoihillaps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time P. End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/23/2015 10/23/2015 0.50 PROD1 DRILL TRIP T POOH for OH Anchored billet. 11,200.0 10,100.0 08:33 09:03 10/23/2015 10/23/2015 0.80 PROD1 DRILL DLOG T MAD pass 10,992 ft to 9,622 ft at 10 10,992.0 9,622.0 09:03 09:51 fpm. 10/23/2015 10/23/2015 0.65 PROD1 DRILL TRIP T PUH into 5 1/2"BTP. 9,622.0 8,745.0 09:51 10:30 10/23/2015 10/23/2015 0.25 PROD1 DRILL DLOG T Static BHP at window,initial BHP 8,745.0 8,745.0 10:30 10:45 4,044 psi,WH 680.15 minutes BHP 4,051,WH 764,EMW 11.9 ppg 10/23/2015 10/23/2015 1.60 PROD1 DRILL TRIP T POOH for anchored billet assembly. 8,745.0 78.5 10:45 12:21 PJSM for un-deploying BHA 10/23/2015 10/23/2015 1.80 PROD1 DRILL PULD T On surface,un-deploy BHA#8, 78.5 0.0 12:21 14:09 service injector. 10/23/2015 10/23/2015 1.35 PROD1 DRILL PULD T PJSM-bring in and MU OH anchored 0.0 72.9 14:09 15:30 billet assembly and deploy BHA#9. 10/23/2015 10/23/2015 1.00 PROD1 DRILL RGRP T Injector pipe brake will not release, 72.9 72.9 15:30 16:30 troubleshoot and repair,loose wire. Note:Nabors down time,non chargable. 10/23/2015 10/23/2015 0.50 PROD1 DRILL PULL T PJSM-MU BHA#9 to Cioltrak tools, 72.9 72.9 16:30 17:00 surface test. 10/23/2015 10/23/2015 1.50 PROD1 DRILL TRIP T RIH with BHA#9,EDC open,continue 72.9 2,900.0 17:00 18:30 in hole @ 2,900'lost communication BHI tools,troubleshoot E-Line.Unable to resolve issues. 10/23/2015 10/23/2015 1.50 PROD1 DRILL TRIP T POOH to further troubleshoot 2,900.0 78.0 18:30 20:00 communication issues.Test junction box in reel and collector. 10/23/2015 10/24/2015 4.00 PROD1 DRILL CTOP T PJSM. Break-off injector,test E-Line. 78.0 78.0 20:00 00:00 Wait on rig electrician to return,test MWD tools,no issues.Rig electrician found crossover pigtail line from collector to MWD to have several broken wires.Make repairs and test. 10/24/2015 10/24/2015 1.50 PROD1 DRILL TRIP T MU injector,RIH w/BHA#10.Open 78.0 1,550.0 00:00 01:30 orbit valve,test HOT,test good. Continue in hole,lost communication again.Troubleshoot. 10/24/2015 10/24/2015 1.00 PROD1 DRILL TRIP T POOH to troubleshoot MWD.Close 1,550.0 78.5 01:30 02:30 orbit valve.bleed off wellhead.Skid injector.Test E-Line,test good. 10/24/2015 10/24/2015 1.75 PROD1 DRILL PULD 'T PJSM.MU all new BHA#11 0.0 72.5 02:30 04:15 10/24/2015 10/24/2015 3.85 PROD1 DRILL TRIP T RIH w/BHA#11 anchored billet,open 72.5 11,776.8 04:15 08:06 orbit valve,K1 tie in for plus 1.5 ft correction,RIH to 8,740 ft,close EDC, continue in hole pumps off,slight bobble thru 8,810 ft.on depth at 11,776.75 ft, 150°ROHS single slip, pick up neutral,release off OH anchored billet at 4,400 psi,set down 4k,PUW 30k,TOB at 11,765 ft. 10/24/2015 10/24/2015 3.00 PROD1 DRILL TRIP T POOH for drilling BHA,circulate 80 11,765.0 72.9 08:06 11:06 bbls gas/crude cut mud outside.PJSM -Pressure un-deploy. Page 7/11 Report Printed: 12/18/2015 111 o Ipo erations Summary (with Timelog•pths) 3K-01 Conon i!bps 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) 10/24/2015 10/24/2015 1.60 PROD1 DRILL PULD T On surface,un-deploy and lay down 72.9 0.0 11:06 12:42 BHA#11,remove HOT from BHA#11 for BHA#12 10/24/2015 10/24/2015 1.60 PROD1 STK PULD T PJSM-make up BHA#12,agitator, 0.0 78.3 12:42 14:18 0.7-°AKO motor and RR 1-1 HYC bit, MU to CoilTrak,surface test. 10/24/2015 10/24/2015 3.00 PROD1 STK TRIP T RIH with BHA#12,surface test 78.3 11,767.0 14:18 17:18 agitator at 180 ft,good,continue in hole,tie in at K1 for plus 1.5 ft correction,PUW at window 28k, bobble thru bottom of window at 8,762 ft,clean thru 8,710 ft.Dry tag top of billet at 11,767'ft,PUW 30k dry. 10/24/2015 10/24/2015 2.40 PROD1 STK KOST T 11,765.8 ft,Time mill off billet per 11,767.0 11,775.0 17:18 19:42 plan, 1.22 bpm at 3,401 psi FS,BHP. Off billet @ 11,769'.Drill ahead @ 10 to 20 fph. 10/24/2015 10/25/2015 4.30 PROD1 DRILL DRLG T Drill ahead: 1.43 BPM @ 4,195 PSI, 11,775.0 12,047.0 19:42 00:00 BHP=4,410 PSI,CTW=4K, WOB=1.5K,ROP=65.Dry drift billet @ 11,767',clean.Start pumping new system,new mud @ bit 11,885'. 10/25/2015 10/25/2015 0.45 PROD1 DRILL DRLG T Drill ahead: 1.43 BPM @ 4,095 PSI, 12,047.0 12,060.0 00:00 00:27 BHP=4,410 PSI,CTW=3K, WOB=1.1K,ROP=35. 10/25/2015 10/25/2015 0.80 PROD1 DRILL WPRT T Wiper trip,sticky off bottom, 12,060.0 12,060.0 00:27 01:15 PUW=39K,RBIH. 10/25/2015 10/25/2015 2.50 PROD1 DRILL DRLG T Drill ahead: 1.40 BPM @ 4,045 PSI, 12,060.0 12,175.0 01:15 03:45 BHP=4,385 PSI,CTW=3K, WOB=1.1K,ROP=45.Off trouble time. 10/25/2015 10/25/2015 3.05 PROD1 DRILL DRLG P Drill ahead: 1.40 BPM @ 4,015 PSI, 12,175.0 12,360.0 03:45 06:48 BHP=4,415 PSI,CTW=3K, WOB=1.1K,ROP=55. 10/25/2015 10/25/2015 3.45 PROD1 DRILL WPRT P Wiper to window,PUW 30k,jet/jog 12,360.0 12,360.0 06:48 10:15 BTP,RA tie in for plus 2 ft correction, RBIH,circulate outside 105 bbl crude/gas cut mud to TT 10/25/2015 10/25/2015 2.25 PROD1 DRILL DRLG P .12,360 ft, OBD 1.37 bpm at 4,087 psi, 12,360.0 12,560.0 10:15 12:30 BHP 4,404 psi,CWT 2.6k,WOB 1.4k, ROP 85 10/25/2015 10/25/2015 1.00 PROD1 DRILL WPRT P Wiper up hole to 11,780 ft,PUW 31k, 12,560.0 12,560.0 12:30 13:30 clean,RBIH 10/25/2015 10/25/2015 2.35 PROD1 DRILL DRLG P 12,560 ft,OBD 1.37 bpm at 4,084 psi, 12,560.0 12,715.0 13:30 15:51 BHP 4,422 psi,CWT 3.0k,WOB 1.2k, ROP 70 10/25/2015 10/25/2015 6.30 PROD1 DRILL TRIP P 12,715 ft,TD called,pump 10x10 12,715.0 78.3 15:51 22:09 sweep,wiper to BTP,jet/jog BTP, continue wiper to swab.At surface, choke plugging off,jog back in hole, circulate to clean,blow down choke. 10/25/2015 10/26/2015 1.85 PROD1 DRILL TRIP P RBIH for corrected TD,tie-in Kt for 78.3 12,490.0 22:09 00:00 +2'correction,continue in hole,at 12,060'had to cut pump rate to mininum to make hole,start working pipe,made to 12,490'.Still getting some crude/gas to surface,after adjusting EMW to 12.3. Page 8/11 Report Printed: 12/18/2015 w iterations Summary (with Timelog IIepths) OS 3K-01 CorooY ilhps AknA. 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) 10/26/2015 10/26/2015 2.50 PROD1 DRILL TRIP P Continue to work pipe,dealing with 12,490.0 12,550.0 00:00 02:30 crude issues,increase EMW to 12.3, circulate out crude/gas to tiger tank. Town decided to lay in liner pill from here. 10/26/2015 10/26/2015 3.50 PROD1 DRILL DISP P POOH laying in 50 bbl beaded liner 12,550.0 78.5 02:30 06:00 pill,paint EOP flags,continue OOH. 10/26/2015 10/26/2015 1.50 PROD1 DRILL PULD P On surface,close Orbit valve(1,250 78.5 0.0 06:00 07:30 psi surface pressure)LD BHA#12, Bit condition 1-1-BU-G-X-I-WT-TD, agitator#0041 in good shape with 89 total hours. 10/26/2015 10/26/2015 3.25 COMPZI CASING PUTB P PJSM-Pre floors for liner,MU 0.0 1,108.5 07:30 10:45 bullnose,36 joints slotted,shorty deployment sleeve,stand back liner running equipment. 10/26/2015 10/26/2015 0.95 COMPZ1 CASING PULD P PJSM-MU lower liner assembly to 1,108.5 1,152.7 10:45 11:42 BHA#13,MU to CoilTrak,surface test. 10/26/2015 10/26/2015 3.50 COMPZ1 CASING RUNL P RIH w/BHA#13,Open Orbit valve, 1,152.7 12,715.0 11:42 15:12 contine in hole holding 12.5 ppg EMW, minus 1.1 ft correction at 7,500 ft EOP flag,continue in hole,slight bobble at 10,000 ft,clear to TD. 10/26/2015 10/26/2015 0.20 COMPZ1 CASING RUNL P 12,715 ft,On depth,stack 4k,release 12,715.0 11,606.0 15:12 15:24 off liner 1.4 bpm,PUW 28k,reset depth,top of liner at 11,606 ft.,line up pump. 10/26/2015 10/26/2015 3.85 COMPZ1 CASING TRIP P POOH pumping over the top,paint 11,606.0 44.2 15:24 19:15 EOP flags at 9,900 ft and 7,100 ft.At surface,close orbit valve,bleed off,no flow. 10/26/2015 10/26/2015 0.90 COMPZ1 CASING PULD P LD BHA#13.Prep to pick-up second 44.2 0.0 19:15 20:09 segment. 10/26/2015 10/27/2015 3.85 COMPZ1 CASING PUTB P PJSM.MU upper liner segment:bull 0.0 1,568.0 20:09 00:00 nose,48 jts slotted,OH anchored billet.MU BHA#14 10/27/2015 10/27/2015 5.50 COMPZ1 CASING RUNL P MU injector,set depth,open orbit 1,568.0 10,310.0 00:00 05:30 valve.RIH w/BHA#14 upper liner assembly,tie-in to EOP flag for-4' correction,PUW=31K,continue in hole,one pick-up @ 9,888',some stacking 10,190',fell free,continue in hole,stacking 10,310',unable to work up or down,pressure up on backside, try to work down,noy joy,pick up 36k (5k over PUW)confer with town, 10/27/2015 10/27/2015 1.30 COMPZ1 CASING RUNL T Stand by,waiting for orders from town. 10,310.0 10,310.0 05:30 06:48 10/27/2015 10/27/2015 0.70 COMPZ1 CASING RUNL T Pull 42k,no movement,slack off,pick 10,310.0 10,310.0 06:48 07:30 up to neutral,able to orientate HOT freely. 10/27/2015 10/27/2015 0.65 COMPZI CASING RUNL T Stand by,waiting for orders from town. 10,310.0 10,310.0 07:30 08:09 10/27/2015 10/27/2015 0.15 COMPZ1 CASING RUNL T Release off billet at 4,200 psi,PUW 10,310.0 10,310.0 08:09 08:18 30k 10/27/2015 10/27/2015 0.20 COMPZ1 CASING DLOG T Log RA up for plus 6 ft correction, 10,310.0 8,745.0 08:18 08:30 reset BHA depth. Page 9/11 Report Printed: 12/18/2015 i orations Summary (with Timelog pths) 00 3K-01 conoc 1hilwps AG+kn 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) 10/27/2015 10/27/2015 1.70 COMPZ1 CASING TRIP T POOH 8,745.0 72.5 08:30 10:12 10/27/2015 10/27/2015 1.25 COMPZ1 CASING PULD T On surface,close Orbit valve,PJSM, 72.5 0.0 10:12 11:27 LD BHA#14,reconfigure BHA for short liner run. 10/27/2015 10/27/2015 0.90 COMPZ1 CASING PUTB T PJSM-MU L1 upper liner ported bull 0.0 53.7 11:27 12:21 nose, 1 jt slotted,3 pup jts,shorty deployment sleeve. 10/27/2015 10/27/2015 0.35'COMPZ1 CASING PULD T MU upper liner assembly to BHA#15, 53.7 97.5 12:21 12:42 MU to Coiltrak,surface test. 10/27/2015 10/27/2015 2.55 COMPZ1 CASING RUNL T RIH with BHA#15,Slick-line GS 97.5 8,810.0 12:42 15:15 pinned very light, open Orbit valve, continue in hole,tie in at K1 for plus 1.5 ft correction,continue in hole, PUW at 8,745',28k,WOB-.44. 10/27/2015 10/27/2015 0.20 COMPZ1 CASING RUNL T 8,810 ft, Tag top of billet,PUH,RBIH 8,810.0 8,745.0 15:15 15:27 50 fpm,stack 9k,repeat 1 time,Top of liner at 8,756 ft.POOH,PUW 28k, WOB 1.26k,liner appears set,reset to BHA depth,RBIH. 10/27/2015 10/27/2015 0.75 COMPZ1 CASING OTHR T Static BHP-initial 4,297 psi,45 8,745.0 8,745.0 15:27 16:12 minutes 4,270 psi,Hold 12.7 ppg EMW at window. 10/27/2015 10/27/2015 0.75 COMPZ1 CASING DISP T Pump 20 bbl of 9.8 ppg FloPro, 100k 8,745.0 8,745.0 16:12 16:57 LSRV pill,displace with 9.8 ppg FloPro, 10/27/2015 10/27/2015 3.75 COMPZ1 CASING DISP T Continue displacing well to 9.8 ppg Flo 8,745.0 8,745.0 16:57 20:42 -Pro,Discuss with town team on plan forward,decision was made to displace well to SW and freeze protect well from 2500 ft.RDMO Initiate calls for LRS,MI swaco Prudhoe,FMC,Wells Planner,Rig prep,Valve Crew,and Drilling Support. 10/27/2015 10/27/2015 1.75 DEMOB WHDBOP DISP P Seawater on location,load pits, 8,745.0 2,550.0 20:42 22:27 displace well to SW while POOH 10/27/2015 10/27/2015 1.25 DEMOB WHDBOP FRZP P 2500 ft,LRS on location,PJSM with 2,550.0 2,550.0 22:27 23:42 LRS,PT lines,load 30 bbls of diesel into CT reel.RD LRS, 10/27/2015 10/28/2015 0.31 DEMOB WHDBOP FRZP P POOH,freeze protecting well from 2,550.0 2,500.0 23:42 00:00 2500 ft. 10/28/2015 10/28/2015 0.50 DEMOB WHDBOP FRZP P Continue POOH while freeze 2,500.0 44.7 00:00 00:30 protecting well. 10/28/2015 10/28/2015 0.25 DEMOB WHDBOP OWFF P At surface function closed Orbit valve, 44.7 44.7 00:30 00:45 1550 psi on WH.PJSM for LD liner running tools. 10/28/2015 10/28/2015 3.00 DEMOB WHDBOP PULD P LD BHA#15,install swizzle stick 44.7 0.0 00:45 03:45 nozzle,jet BOPE,pump corrosion inhibitor and flush surface lines and coil. 10/28/2015 10/28/2015 1.00 DEMOB WHDBOP MPSP P FMC on location,PJSM, PU/RU/PT 0.0 0.0 03:45 04:45 FMC lubricator to 1500 psi,found upper Blind Shear door seal to be leaking. 10/28/2015 10/28/2015 2.25 DEMOB WHDBOP PRTS T RD FMC lubricator,replace door seal, 0.0 0.0 04:45 07:00 chart body test on BOPE 250/4,500 psi,good. Page 10/11 Report Printed: 12/18/2015 01,;:i Operations Summary (with Timelog epths) 014 3K-01 Conon Pttilhps 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) 10/28/2015 10/28/2015 2.00 DEMOB WHDBOP MPSP P PJSM-RU/PT FMC lubricator to 1500 0.0 0.0 07:00 09:00 psi,set BPV,test from below with 1,500 psi well head pressure,RD,off load FMC equipment. 10/28/2015 10/28/2015 2.00 DEMOB WHDBOP RURD P Blow down coil tubing reel and rig 0.0 0.0 09:00 11:00 surface lines to tiger tank.RD MP line and misc.lines in cellar.Perform rig down checklist. 10/28/2015 10/28/2015 1.50 DEMOB WHDBOP NUND P Nipple down stack,check flange bolts 0.0 0.0 11:00 12:30 (45 minutes)9 loose-4 at tubing head, 1 top of master valve,4 between swab 1 &2 10/28/2015 10/28/2015 0.50 DEMOB WHDBOP RURD P Peak trucks on site,PJSM-move 0.0 0.0 12:30 13:00 shop first,finish up rig down check list. 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O 0 0 cl C .. i C o NC CC m W CDO O O N r g Lo o ad CT2 V ( ( C . O% .,1 p O « N N d N 0 0. co 6 (o o 215161 4` �' 11, 2 7026371126 nalll ' U 13 o LL; PRINT DISTRIBUTION LIST 36 7 2 HSS 4�� 'A , ,f Please sign and return one copy of this transmittal form to: COMPANY A ConocoPhillips Alaska,Inc. ConocoPhillips Alaska,Inc. DATA LOGGED Ricky Elgarico.ATO 3-334. yl./3/2015 WELL NAME 3K-01L1;3K-01L1PB1;3K-01L1PB2 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 October 28,2015 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider@bakerhughes.com TODAYS DATE November 23,2015 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 #ur rrtiN i b #OF COPIES #OF COPIES #OF COPIES '4 4 4 4 1 BP North Slope [ 0 0 I 0 EOA,PBOC,PRB-20(Office 109) l D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. I 0 I 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 4 State of Alaska -AOGCC I 1 I 1 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *5* I 0 I 1 I 1 I 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. I 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 r".. 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LO, V V V V' R E## 3 � (O f0 O (O co co co co co co co N \\\ N UO M N- OJ N fO U) M M M c U) U) UO N 7 V M M M n "� S y4�) Up O CO M U) CO- M f0 (O M M U a = VA 0 • N N -0 �� 8 0 0 0 0 0 0 0 0 0 0 co a \\�\�`t`‘Q' N N N N N N N N N NN g CIL ° 2 2 —) J U Y Y M M M �� iim co V M V W V co 0 M M o as a 0 0 0 ii M " vM Ir. r` tg v rn (onf Qc n i ) +`v ro rnm rni mrnomrn a, m O 0 \_‘ . r r OUO r N M NO O M U \ O W M M M f- O O ypMVOo0 (Om 0 co co W O) O 0 L .' = NNoi . • • . . • • 21 51 61 Letter of Transmittal FARM BAKER Date: DATA LOGGED to/30/2015 October 29, 2015 . K.BENDER HUGHES 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): 3K-01L1PB1 4 1 3K-01L1PB2 2 b 4 1 3K-01L1 2 6 4 1 0 RECEIVED OCT 30 2015 AOGCC (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 LO O • • e- e- L1'a _ CG C•1 N 1.1 rill all Z gee `40 gzN 0. I • C .„ .-. C L.L1 C4 E. CC- U) Z CD 111111111. ..111111111 •- IP_ _ )10 ig •- cn . _ d. o o Dop > U, 0. O 2 •I- r O O 0 ri M � 1._ I N V i OXY d L L J ♦/ L^I+ O V Y 1 M CO N f M 0 0 • • co Ei , ., . . 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ON O (") (Li DyNCOCD O ( mN (O W 0) O O O 1 CO• U p E T N N N CV N c ZED- EL il U• a 5 5 o a) ...+.; 0 • 0 • • pro Zee-L61 Loepp, Victoria T (DOA) From: Winfree, Mike A <Michael.A.Winfree@conocophillips.com> Sent: Sunday, October 18, 2015 7:18 PM To: Loepp,Victoria T(DOA) Cc: Venhaus, Dan E; Eller,J Gary;Strumness, Laura A; Krysinski, Marina L Subject: PTD 215-161 3K-01L1PB1 and 3K-01L1 Follow Up Flag: Follow up Flag Status: Flagged Good evening Victoria, This e-mail is to inform you that we will plug back and redrill a portion of the 3K-01L1 CTD lateral (PTD 215-161). After crossing a large fault,a geosteering decision was made to increase inclination to find the pay. Ultimately the lateral was steered out of zone,and a plug back is required to meet the objectives for this lateral. TD of the 3K-01L1PB1 is 9,889' MD and the kick off point for the 3K-01L1 lateral redrill will be 9,110' MD. The top of the whipstock is located at 8,753'MD in the parent well. The hole section from 9,110' MD to 9,889' MD will not be lined and is not likely to produce,so it will be designated 3K- 01L1PB1. The re-drill of this lateral will retain the name 3K-01L1. If you have any questions or need additional information regarding the operations described above, please let me know. Thank you, -Mike Winfree Drilling Engineer j ConocoPhillips Alaska ATO-660 Direct:+1(907)263-4404 Cell:+1(907)202-2887 1 1, of Tye • THE STATE Alaska Oil and Gas - � Conservation Commission o �., f - _�t� 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 rh' Main: 907.279.1433 O ALASY' Fax: 907.276.7542 www.aogcc.alaska.gov D. Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3K-01L1 ConocoPhillips Alaska, Inc. Permit No: 215-161 Surface Location: 1434' FSL, 318' FWL, Sec. 35, T13N, R9E,UM Bottomhole Location: 953' FNL, 2752' FEL, Sec. 34, T13N, R9E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 186-101, API No. 50-029- 21600-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P Foerster Chair DATED this iv day of September, 2015. IIII. OD STATE OF ALASKA RECEIVED S E P 10 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL AOGCC 20 AAC 25.005 1a.Type of Work: I 1 b.Proposed Well Class: Development-Oil ❑- Service-Winj El Single Zone 0_ lc.Specify if well is proposed for: J� Drill ❑ . Lateral I Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry I Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: ` LJ Blanket Li Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. ' Bond No. 59-52-180 i KRU 3K-01L1 - 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 12350' ' TVD: 6455' - Kuparuk River Field ' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1434'FSL,318'FWL,Sec.35,T13N, R9E, UM ADL 25519,25520 . Kuparuk River Oil Pool . Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1273'FSL, 1598'FEL,Sec.27,T13N, R9E, UM 2555,2556 9/24/2015 Total Depth: 9.Acres in Property: T"U 14.Distance to 953'FNL,2752'FEL,Sec.34,T13N, R9E, UM _ -*SI&Q Nearest Property: 3785 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: , 69 feet 15.Distance to Nearest Well Open Surface:x- 529306 y- 6008429 Zone- 4. GL Elevation above MSL: , 28 feet to Same Pool: 3K-06,1815' 16.Deviated wells: Kickoff depth: . 8750 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: , 97° deg, Downhole:4603 psig . Surface:3944 psig ' 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) • 3" 2.375" 4.7# L-80 ST-L 2550' 9800' 6567' 12350' 6454' 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) 9150' 6877' none 9055' 6809' 8977' Casing Length Size Cement Volume MD TVD Conductor/Structural 77' 16" 1540 Poleset 115' 115' Surface 4882' 9.675" 1400 sx ASIII,350 sx CIG 4919' 3852' Production 9114' 7" 270 sx Class G, 175 sx ASI 9140' 6871' Perforation Depth MD(ft): Perforation Depth TVD(ft): 8818'-8896' 6641'-6697' 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 2 21.Verbal Approval: Commission Representative: Date: Ci fsI,c A 22. I hereby certify that the foregoing is true and correct. Contact Mike Winfree @ 263-4404 Email Mike.A.Winfree(@.cop.com Printed Name D enhaus Title CTD Engineering SupervisorGG�� Signature -/-- Phone:263-4372 Date q—/5 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: a�S^ �( .I 50- 0a9 .21000 _40_00 I Date: q(131f6 for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: 12/ Other:eO P tf 5 t f,-, 4 SUc 7,>-/_, Samples req'd: Yes No g Mud log req'd: Yes❑ No El' 4-,-4.7 u 1�—p re.v�14 fes' 5 H2S measures: Yes No Directional svy req'd: Yes 2. No❑ 25'0 p5 t5 Spacing exception req'd: Yes ❑ No Inclination-only svy req'd: Yes❑ No d APPROVED BY THE Q ��� Approved by: COMMISSIONER COMMISSION Date: -/ - Form 10-401 ( evised 10/2012) T 't d f oNm t from the date of approval(20 AAC 25.005(9)) 7 IQ `f sq�)s 7� Vi-- moi/19--1!5— �' �`7 I 1 V _ ,�5'���- i ConocoPhillips RECEIVED Alaska SEP 10 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC August 8th, 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 applications for permits to drill four laterals out of the Kuparuk Well 3K-01 using the coiled tubing drilling rig, Nabors CDR2-AC. CTD operations are scheduled to begin at the end of September, 2015. The objective will be to drill laterals KRU 3K-01L1, L1-01, L1-02, and L1-03 targeting the Kuparuk A2 and A3 sands. Attached to this application are the following documents: — 10-401 Applications for all planned laterals — Detailed Summary of Operations — Directional Details for all planned laterals including anti-collision — Proposed CTD Schematic If you have any questions or require additional information please contact me at 907-263-4404. Sincerely -----"\AA\4\ Mike A. Winf e ConocoPhillips Alaska Coiled Tubing Drilling Engineer • • Kuparuk CTD Laterals NABOAS^ALASKA 3K-01L1, 3K-01L1-01, 3K-01L1-02, 3K-01L1-03 CJ,H °noc° ap= Application for Permit to Drill Document 2AC 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 3 (Requirements of 20 AAC 25.005(c)(5)) 3 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 6 (Requirements of 20 AAC 25.050(b)) 6 16. Attachments 7 Attachment 1: Directional Plans for 3K-01L1, L1-01, L1-02, L1-03 7 Attachment 2: Current Well Schematic for 3K-01 7 Attachment 3: Proposed Well Schematic for 3K-01L1, L1-01, L1-02, L1-03 7 Page 1 of 7 9/9/2015 r • PTD Application: 3K-01L1, L1-01, L1-02, L1-03 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 3K-01L1, 3K-01L1-01, 3K-01L1-02, 3K-01L1-03. 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 packages in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 3K-01L1, 3K-01L1-01, 3K-01L1-02, 3K-01L1-03. 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 4,500 psi. Using the maximum formation pressure in the area of 4,603 p i in 3K-04, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, wouldbe.3,944 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. 1,®3p5 t3 ,��1's 4. DrillingHazards Information and Reservoir Pressure , 4 b 5v (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Expected Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) A static bottom hole pressure of 3K-01 A sand on August 8th 2015 indicated a reservoir pressure of 3003 psi or 8.7 ppg equivalent mud weight. The maximum down hole pressure in the 3K-01 pattern is at 3K-04 with 4603 psi. This higher pressure risk only exists in the first southern lateral, 3K-01L1, which is planned to cross a sealing fault into a block that does not appear to have any offtake. The second lateral to the south, 3K-01L1-01, is planned to stop short of the sealing fault. The northern laterals are drilling towards the producer 30-18 which is currently shut in and the last known BHP was 9.2 ppgemw taken in August 2013. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones are expected to be drilled. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) One potential cause of hole problems in the 3K-01 CTD laterals, could be managing the pressure differential across the faults. An orbit valve has been installed in the 3K-01 completion to help maintain applied surface pressure on the formation when out of the hole in managed pressure mode. The 3K area is also structurally complex, and the potential for multiple unmapped faults increases the likelihood of encountering high gamma ray interfaces. 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. Page 2 of 7 9/9/2015 • PTD Application: 3K-01L1, L1-01, L1-02, L1-03 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(f), thru-tubing drilling operations need not perform additional formation integrity tests. 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 3K-01L1 9,800' 12,350' 6,567' 6,454' 2%', 4.7#, L 80, ST-L slotted liner; aluminum billet on top 3K-01L1-01 9,150' 11,950' 6,567' 6,479' 2% , 4.7#, L 80, ST-L slotted liner; aluminum billet on top 3K-01L1-02 9,585' 11,150' 6,556' 6,560' 2% , 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3K-01L1-03 8,745' 11,150' 6,519' 6,540' 2%", 4.7#, L-80, ST-L slotted liner; shorty deployment sleeve 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 38' 115' 38' 115' 1,640 630 Surface 9-5/8" 36 J-55 BTC 37' 4,919' 37' 3,852' 3,520 2,020 Production 7" 26.0 J-55 BTC 25' 9,139' 25' 9,139' 4,980 4,320 Tubing 3-1/2" 9.3 L-80 EUE 35' 8,768' 35' 6,605' 10,160 10,530 Tubing Tail 5-1/2" 14 J-55 STC 8,684' 8,723' 6,544' 6,572' 4,270 3,120 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 (9.1 ppg) - Drilling operations: Chloride-weighted FloVis water-based mud (9.1ppg):i While this mud weight may not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. - Completion operations: Well 3K-01 contains a downhole deployment valve allowing deployment of tool strings and liner without pumping kill weight fluid. If the valve does not hold, BHA's will be deployed using standard pressure deployments and the well will be loaded with an overbalanced completion fluid in order to provide formation over-balance and maintain wellbore stability while running completions Page 3 of 7 9/9/2015 PTD Application: 3K-01L1, L1-01, L1-02, L1-03 Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole 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 3K-01 Window(8,750 MD, 6,592' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation 2982 psi 2982 psi Pressure (8.7 ppg) Mud Hydrostatic(9.1 ppg) 3120 psi 3120 psi Annular friction (i.e. ECD, 788 psi 0 psi 0.09 psi/ft) Mud + ECD Combined 3908 psi 3120 psi (no choke pressure) (overbalanced—926 psi) (overbalanced—240 psi) Target BHP at Window 4045 psi 4045 psi (11.8 ppg) Choke Pressure Required 137 psi 925 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 9/9/2015 • PTD Application: 3K-01L1, L1-01, L1-02, L1-03 13. Proposed Drilling Program (Requirements of 20 AA C 25.005(c)(13)) Summary of Operations Background Well 3K-01 is a Kuparuk A-sand production well equipped with 3W tubing and 7" production casing. The rig work-over in July 2015 replaced the existing tubing and packers with new 3-1/2" tubing and 5-1/2" "Big Tail Pipe" completion. Four laterals will be drilled from the 3K-01 parent well. 2 laterals will be drilled to the south and 2 laterals will be drilled to the north of the parent well with the laterals targeting the different A sand lobes. A mechanical whip-stock will be set inside the 5 '/2" big tail pipe at the planned kick off point of 8,750' MD. The 3K-01 L1 lateral will exit through the big tail pipe at 8,750'MD and TD at 12,350' MD. The L1 lateral will be completed with 2 3/8" slotted liner from TD up to 9,800' MD with an aluminum billet for kicking off the 3K- 01L1-01 lateral The 3K-01L1-01 will drill to a TD of 11,950' MD, with the slotted liner from TD to 9,150' MD and an aluminum billet to kick off the L1-02 lateral. The 3K-01L1-02 will drill to a TD of 11,150' MD, with slotted liner run from TD to 9,585' MD with an aluminum billet to kick off the L1-03 lateral. The 3K- 01L1-03 will drill to a TD of 11,150' MD, with the liner top above the whipstock at 8,745' MD. Pre-CTD Work 1. RU Slickline: Pull sheared SOV, dummy all gas lift valves, obtain a KRU A-sand SBHP, and conduct a dummy whipstock drift. DONE 2. RU E-line: Set Baker Hughes 3-1/2" x 5-1/2" Thru-Tubing Whipstock. DONE 3. 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. 3K-01L1 Lateral (A2 sand to the South) a. Mill 2.80"window at 8,750 MD. b. Drill 3" bi-center lateral to TD of 12,350' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 9,800' MD. 3. 3K-01L1-01 Lateral (A3 sand to the South) a. Kick off of the aluminum billet at 9,800' MD. b. Drill 3" bi-center lateral to TD of 11,950' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 9,150' MD 4. 3K-01L1-02 Lateral (A2 sand to the North) a. Kick off of the aluminum billet at 9,150' MD. b. Drill 3" bi-center lateral to TD of 11,150' MD. c. Run 2%" slotted liner with aluminum billet from TD up to 9,585' MD 5. 3K-01L1-03 Lateral (A3 sand to the North) a. Kick off of the aluminum billet at 9,585' MD. b. Drill 3" bi-center lateral to TD of 11,150' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 8,745' MD 6. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV. 2. Install GLV's. Page 5 of 7 9/9/2015 • • PTD Application: 3K-01L1, L1-01, L1-02, L1-03 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, so installed in this well is a deployment valve. This valve, when closed using hydraulic control lines from surface, isolates the well pressure and allows long BHA's to be deployed/un-deployed without killing the well. If the deployment valve fails, operations will continue using the standard pressure deployment process. A system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick-line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate 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 3K-01 well has a deployment valve installed. It will serve to deploy liners into the newly drilled laterals. If the valve fails the 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. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AA C 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. / Page 6 of 7 9/9/2015 • ! PTD Application: 3K-01L1, L1-01, L1-02, L1-03 - Distance to Nearest Property Line (measured to KPA boundary at closest point) *aterl.. ; Distance 3K-01L1 3,785' 3K-01L1-01 4,310' 3K-01L1-02 2,865' 3K-01L1-03 2,863' - Distance to Nearest Well within Pool c, .at, E s©istanc ,- TF 3K-01L1 1,815' 3K-06 3K-01L1-01 1,732" 3K-06 3K-01L1-02 1,222' 30-18 3K-01L1-03 1,222' 30-18 16. Attachments Attachment 1: Directional Plans for 3K-01L1, L1-01, L1-02, L1-03 Attachment 2: Current Well Schematic for 3K-01 Attachment 3: Proposed Well Schematic for 3K-01L1, L1-01, L1-02, L1-03 Page 7 of 7 9/9/2015 • • 3K-01 Post-RWO Schematic Modified by JGE 7-30-15 3-1/2"9.3#L-80 EUE 8rd-Mod Tubing to surface Baker Orbit Valve placed at 4021'MD(2.835"min ID) —.1111111L 111 sh"62.5#H-40 shoe@115'MD 3-1/2"Camco MMG gas lift mandrels at 2963',4767', 6176',7229', • 8006', and 8503' MD 9-5/8"36#J-55 Baker GBH-22 Seal assembly at 8561' shoe @ 4919'MD Baker 80-40 PBR at 8566' MD Baker FHL packer at 8590'MD 3-1/2"X-nipple at 8643'MD(2.812"min ID) 5-1/2"Big Tail Pipe with wear-sox at 8686'-8768 • o'o\ 8750'proposed TOWS depth 7"cplgs:8691',8733', Squeeze perfs(8/86) 8772',8793'PDC N 8750-8752' ® ;'� �_ Crl' A-sand perfs 8818-8893' 111111116°- 7"26#J-55 shoe @9140'MD • 0 0§ 0 0 _ oo § 0 Lo ca- us sr) §9 § - IIc co § {a )k C _ \/ 7 lir) - 2W ƒ/ _ Ct �� \\ y • _ ® \\ m e o { cCV _J _ w co co cm E CO a cNi® _ \ – co CI \ § ) ° LO ) _\§§ «& \\ • E } + §. a \ o } )/ .c \ %\ 11 \ j\ • ®®as 0 \ )\ \1.0 §� %j = \ \ k \\ \ \ { d\ w ~ n m m= __= nr ` § % S a @ a3 iiiiii 4E i @ u g y ,, n n m jit .' / . I « § » , D > ° Q — _ y » "0ci) TMT 1 @ 0 a LO; \ gi 2 \\ grg 1 -i 43 0 2 iri !7 = , _� °° I& /\ (.4) a) 2! m2 • • Conoco-Phillips NADConversion Kuparuk River Unit Kuparuk 3K Pad 3K-01 3K-01 L1 Plan: 3K-01 L1 wp10Gi4 Standard Plannin Re ort Ii 12 August, 2015 r _ 8 wolaill g cnE1��c iy I BAKER ilk' HUGHES NTE( 9 • P ConocoPhillips • iii BAKER ConocoPhillips illips Planning Report HUGHES INTEQ Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 3K-01 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3K-01 @ 69.00usft(3K-01) Site: Kuparuk 3K Pad North Reference: True Well: 3K-01 Survey Calculation Method: Minimum Curvature Wellbore: 3K-01L1 Design: 3K-01 L1_wp10 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 3K Pad Site Position: Northing: 6,008,428.74 usft Latitude: 70°26'2.781 N From: Map Easting: 529,306.18 usft Longitude: 149°45 39.930 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.23° Well [ 3K-01 Well Position +N/-S 0.00 usft Northing: 6,008,428 74 usft Latitude: 70°26'2.780 N +El-W 0.00 usft Easting: 529,306.18 usft Longitude: 149°45'39.930 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft I Wellbore 3K-01L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 8/15/2015 18.88 81.03 57,501 Design 3K-01L1_wp10 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,700.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 210.00 8/12/2015 2.14.10PM Page 2 COMPASS 5000.1 Build 74 ,0,,_, ConocoPhillips Waal BAKConocoPhillips Planning Report ONES INTEQ Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 3K-01 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3K-01 @ 69.00usft(3K-01) Site:, Kuparuk 3K Pad North Reference: True Well: 3K-01 Survey Calculation Method: Minimum Curvature Wellbore: 3K-01L1 Design: 3K-01 L1_wp10 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) O (0) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (0) Target u. 8,700.00 43.85 8.72 6,487.18 5,224.97 -1,114.61 0.00 0.00 0.00 0.00 8,750.00 43.79 9.47 6,523.26 5,259.16 -1,109.14 1.05 -0.12 1.50 96.86 8,775.00 47.73 6.43 6,540.70 5,276.89 -1,106.68 18.00 15.76 -12.16 330.00 8,835.00 72.04 352.63 6,570.69 5,328.21 -1,107.88 45.00 40.51 -23.01 330.00 8,908.24 90.00 324.52 6,582.30 5,394.41 -1,134.34 45.00 24.52 -38.38 300.00 9,058.24 96.46 257.17 6,572.72 5,444.91 -1,266.15 45.00 4.31 -44.90 277.00 9,158.24 90.00 254.48 6,567.09 5,420.47 -1,362.89 7.00 -6.47 -2.68 202.60 9,408.24 90.00 244.48 6,567.10 5,332.97 -1,596.73 4.00 0.00 -4.00 270.00 9,858.24 90.00 226.48 6,567.12 5,079.03 -1,966.00 4.00 0.00 -4.00 270.00 9,978.24 84.03 222.44 6,573.37 4,993.57 -2,049.89 6.00 -4.97 -3.37 214.00 10,108.24 90.02 217.44 6,580.11 4,894.10 -2,133.16 6.00 4.61 -3.85 320.00 10,233.24 92.37 221.86 6,577.49 4,797.90 -2,212.88 4.00 1.88 3.53 62.00 10,358.24 92.36 216.85 6,572.33 4,701.36 -2,292.05 4.00 -0.01 -4.00 270.00 10,509.99 92.35 210.78 6,566.10 4,575.45 -2,376.39 4.00 -0.01 -4.00 270.00 10,628.24 93.16 215.44 6,560.41 4,476.54 -2,440.89 4.00 0.69 3.95 80.00 10,889.99 93.11 204.96 6,546.07 4,250.97 -2,572.17 4.00 -0.02 -4.01 270.00 11,178.24 91.06 193.60 6,535.56 3,979.52 -2,667.10 4.00 -0.71 -3.94 260.00 11,378.24 91.05 201.60 6,531.89 3,789.07 -2,727.52 4.00 -0.01 4.00 90.00 11,628.24 93.78 191.97 6,521.35 3,550.25 -2,799.60 4.00 1.09 -3.85 286.00 11,958.24 93.47 215.12 6,500.20 3,250.40 -2,930.27 7.00 -0.09 7.01 90.00 12,108.24 97.45 205.36 6,485.89 3,121.60 -3,005.40 7.00 2.66 -6.51 292.70 12,350.00 97.13 188.30 6,454.98 2,892.94 -3,074.54 7.00 -0.13 -7.06 270.00 8/12/2015 2.14:10PM Page 3 COMPASS 5000.1 Build 74 0 • ~,-, ConocoPhillips 193-AU CUi''1C}Cf}P'11llIct5 Planning Report NUEGGHES INTEQ Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 3K-01 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3K-01 @ 69.00usft(3K-01) Site: Kuparuk 3K Pad North Reference: True Well: 3K-01 Survey Calculation Method: Minimum Curvature Wellbore: 3K-01L1 Design: 3K-01 L1_wp10 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (0) (o) (usft) (usft) (usft) (usft) (°I100usft) (°) (usft) (usft) 8,700.00 43.85 8.72 6,487.18 5,224.97 -1,114.61 -3,967.65 3.33 73.86 6,013,648.78 528,171.16 TIP 8,750.00 43.79 9.47 6,523.26 5,259.16 -1,109.14 -3,999.99 1.05 96.86 6,013,682.98 528,176.50 KOP 8,775.00 47.73 6.43 6,540.70 5,276.89 -1,106.68 -4,016.58 18.00 -30.00 6,013,700.72 528,178.89 End 18 dls,Start 45 dls 8,800.00 57.68 359.80 6,555.84 5,296.71 -1,105.68 -4,034.25 45.00 -30.00 6,013,720.54 528,179.81 8,835.00 72.04 352.63 6,570.69 5,328.21 -1,107.88 -4,060.42 45.00 -25.97 6,013,752.02 528,177.49 4 8,900.00 87.90 327.57 6,582.15 5,387.57 -1,129.74 -4,100.91 45.00 -60.00 6,013,811.30 528,155.40 8,908.24 90.00 324.52 6,582.30 5,394.41 -1,134.34 -4,104.52 45.00 -55.52 6,013,818.12 528,150.77 5 9,000.00 94.61 283.44 6,578.44 5,444.59 -1,208.70 -4,110.80 45.00 -83.00 6,013,868.00 528,076.22 9,058.24 96.46 257.17 6,572.72 5,444.91 -1,266.15 -4,082.36 45.00 -84.73 6,013,868.10 528,018.78 End 45 dls,Start RSM 9,100.00 93.77 256.04 6,569.00 5,435.28 -1,306.60 -4,053.79 7.00 -157.40 6,013,858.30 527,978.36 9,158.24 90.00 254.48 6,567.09 5,420.47 -1,362.89 -4,012.82 7.00 -157.50 6,013,843.28 527,922.14 7 9,200.00 90.00 252.81 6,567.09 5,408.72 -1,402.95 -3,982.61 4.00 -90.00 6,013,831.37 527,882.13 9,300.00 90.00 248.81 6,567.10 5,375.86 -1,497.38 -3,906.94 4.00 -90.00 6,013,798.14 527,787.84 9,400.00 90.00 244.81 6,567.10 5,336.50 -1,589.29 -3,826.90 4.00 -90.00 6,013,758.42 527,696.10 9,408.24 90.00 244.48 6,567.10 5,332.97 -1,596.73 -3,820.12 4.00 -90.00 6,013,754.87 527,688.67 8 9,500.00 90.00 240.81 6,567.10 5,290.82 -1,678.22 -3,742.87 4.00 -90.00 6,013,712.40 527,607.35 9,600.00 90.00 236.81 6,567.11 5,239.05 -1,763.75 -3,655.27 4.00 -90.00 6,013,660.30 527,522.03 9,700.00 90.00 232.81 6,567.11 5,181.44 -1,845.46 -3,564.52 4.00 -90.00 6,013,602.37 527,440.56 9,800.00 90.00 228.81 6,567.12 5,118.27 -1,922.96 -3,471.07 4.00 -90.00 6,013,538.90 527,363.32 9,858.24 90.00 226.48 6,567.12 5,079.03 -1,966.00 -3,415.57 4.00 -90.00 6,013,499.51 527,320.44 9 9,900.00 87.92 225.08 6,567.88 5,049.92 -1,995.92 -3,375.40 6.00 -146.00 6,013,470.28 527,290.63 9,978.24 84.03 222.44 6,573.37 4,993.57 -2,049.89 -3,299.61 6.00 -145.97 6,013,413.72 527,236.89 10 10,000.00 85.03 221.60 6,575.44 4,977.48 -2,064.39 -3,278.43 6.00 -40.00 6,013,397.58 527,222.45 10,100.00 89.64 217.76 6,580.08 4,900.63 -2,128.14 -3,180.00 6.00 -39.92 6,013,320.49 527,159.02 10,108.24 90.02 217.44 6,580.11 4,894.10 -2,133.16 -3,171.83 6.00 -39.74 6,013,313.94 527,154.02 11 10,200.00 91.75 220.68 6,578.69 4,822.87 -2,190.97 -3,081.25 4.00 62.00 6,013,242.49 527,096.50 10,233.24 92.37 221.86 6,577.49 4,797.90 -2,212.88 -3,048.67 4.00 62.05 6,013,217.44 527,074.69 12 10,300.00 92.37 219.18 6,574.74 4,747.20 -2,256.21 -2,983.09 4.00 -90.00 6,013,166.57 527,031.56 10,358.24 92.36 216.85 6,572.33 4,701.36 -2,292.05 -2,925.47 4.00 -90.11 6,013,120.60 526,995.90 13 10,400.00 92.36 215.18 6,570.61 4,667.61 -2,316.58 -2,883.98 4.00 -90.00 6,013,086.76 526,971.51 10,500.00 92.35 211.18 6,566.51 4,584.01 -2,371.25 -2,784.24 4.00 -90.07 6,013,002.94 526,917.17 10,509.99 92.35 210.78 6,566.10 4,575.45 -2,376.39 -2,774.26 4.00 -90.23 6,012,994.36 526,912.07 14 10,600.00 92.97 214.33 6,561.92 4,499.67 -2,424.76 -2,684.45 4.00 80.00 6,012,918.41 526,864.00 10,628.24 93.16 215.44 6,560.41 4,476.54 -2,440.89 -2,656.35 4.00 80.16 6,012,895.21 526,847.97 15 10,700.00 93.16 212.57 6,556.46 4,417.15 -2,480.95 -2,584.88 4.00 -90.00 6,012,835.67 526,808.14 10,800.00 93.14 208.56 6,550.97 4,331.19 -2,531.72 -2,485.06 4.00 -90.16 6,012,749.52 526,757.72 10,889.99 93.11 204.96 6,546.07 4,250.97 -2,572.17 -2,395.36 4.00 -90.38 6,012,669.15 526,717.59 8/12/2015 2:14:10PM Page 4 COMPASS 5000.1 Build 74 lir' 1 Cono • coPhillips VirikU C0110C hillipS Planning Report BAKERHUGHES INTEQ Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 3K-01 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3K-01 @ 69.O0usft(3K-01) Site: Kuparuk 3K Pad North Reference: True Well: 3K-01 Survey Calculation Method: Minimum Curvature Wellbore: 3K-01L1 Design: 3K-01 L1_wp10 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) 16 10,900.00 93.04 204.56 6,545.53 4,241.89 -2,576.35 -2,385.41 4.00 -100.00 6,012,660.06 526,713.44 11,000.00 92.33 200.62 6,540.85 4,149.68 -2,614.72 -2,286.37 4.00 -100.02 6,012,567.71 526,675.44 11,100.00 91.62 196.68 6,537.39 4,055.01 -2,646.67 -2,188.41 4.00 -100.21 6,012,472.92 526,643.86 11,178.24 91.06 193.60 6,535.56 3,979.52 -2,667.10 -2,112.81 4.00 -100.34 6,012,397.35 526,623.73 17 11,200.00 91.06 194.47 6,535.16 3,958.41 -2,672.38 -2,091.90 4.00 90.00 6,012,376.23 526,618.54 11,300.00 91.05 198.47 6,533.32 3,862.55 -2,700.72 -1,994.71 4.00 90.02 6,012,280.27 526,590.57 11,378.24 91.05 201.60 6,531.89 3,789.07 -2,727.52 -1,917.67 4.00 90.09 6,012,206.69 526,564.06 18 11,400.00 91.29 200.77 6,531.45 3,768.78 -2,735.39 -1,896.17 4.00 -74.00 6,012,186.38 526,556.28 11,500.00 92.38 196.92 6,528.24 3,674.21 -2,767.66 -1,798.13 4.00 -74.02 6,012,091.69 526,524.38 11,600.00 93.47 193.06 6,523.13 3,577.76 -2,793.49 -1,701.69 4.00 -74.14 6,011,995.15 526,498.93 11,628.24 93.78 191.97 6,521.35 3,550.25 -2,799.60 -1,674.81 4.00 -74.34 6,011,967.61 526,492.93 19 11,700.00 93.76 197.01 6,516.63 3,480.94 -2,817.51 -1,605.83 7.00 90.00 6,011,898.24 526,475.30 11,800.00 93.69 204.02 6,510.12 3,387.54 -2,852.46 -1,507.47 7.00 90.33 6,011,804.72 526,440.72 11,900.00 93.57 211.03 6,503.78 3,299.10 -2,898.56 -1,407.83 7.00 90.79 6,011,716.10 526,394.97 11,958.24 93.47 215.12 6,500.20 3,250.40 -2,930.27 -1,349.79 7.00 91.23 6,011,667.28 526,363.45 20 12,000.00 94.60 212.41 6,497.27 3,215.77 -2,953.42 -1,308.23 7.00 -67.30 6,011,632.57 526,340.44 12,100.00 97.24 205.90 6,486.94 3,128.97 -3,001.86 -1,208.84 7.00 -67.49 6,011,545.58 526,292.35 12,108.24 97.45 205.36 6,485.89 3,121.60 -3,005.40 -1,200.69 7.00 -68.16 6,011,538.20 526,288.84 21 12,200.00 97.41 198.88 6,474.01 3,037.35 -3,039.64 -1,110.61 7.00 -90.00 6,011,453.83 526,254.93 12,300.00 97.25 191.82 6,461.24 2,941.77 -3,065.88 -1,014.71 7.00 -90.84 6,011,358.15 526,229.07 12,350.00 97.13 188.30 6,454.98 2,892.94 -3,074.54 -968.09 7.00 -91.74 6,011,309.29 526,220.60 Planned TD at 12350.00-2 3/8" Casing Points 1igiiiiipTa, Measured Vertical i ' Casing Hole Depth Depth , _; Diameter Diameter (usft) (usft) Name (••}( "} 12,350.00 6,454.98 2 3/8 2-3/8 3 8/12/2015 2.14:10PM Page 5 COMPASS 5000.1 Build 74 • ConocoPhillips • EMI +�t)t1t,�COPhllllp5 Planning Report HUGHES INTEQ Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 3K-01 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3K-01 @ 69.00usft(3K-01) Site: Kuparuk 3K Pad North Reference: True Well: 3K-01 Survey Calculation Method: Minimum Curvature Wellbore: 3K-01L1 Design: 3K-01 L1_wp10 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W _ lea ' (usft) (usft) (usft) (usft) Comment ''✓ 4,i 8,700.00 6,487.18 5,224.97 -1,114.61 TIP 8,750.00 6,523.26 5,259.16 -1,109.14 KOP 8,775.00 6,540.70 5,276.89 -1,106.68 End 18 dls,Start 45 dls 8,835.00 6,570.69 5,328.21 -1,107.88 4 8,908.24 6,582.30 5,394.41 -1,134.34 5 9,058.24 6,572.72 5,444.91 -1,266.15 End 45 dls,Start RSM 9,158.24 6,567.09 5,420.47 -1,362.89 7 9,408.24 6,567.10 5,332.97 -1,596.73 8 9,858.24 6,567.12 5,079.03 -1,966.00 9 9,978.24 6,573.37 4,993.57 -2,049.89 10 10,108.24 6,580.11 4,894.10 -2,133.16 11 10,233.24 6,577.49 4,797.90 -2,212.88 12 10,358.24 6,572.33 4,701.36 -2,292.05 13 10,509.99 6,566.10 4,575.45 -2,376.39 14 10,628.24 6,560.41 4,476.54 -2,440.89 15 10,889.99 6,546.07 4,250.97 -2,572.17 16 11,178.24 6,535.56 3,979.52 -2,667.10 17 11,378.24 6,531.89 3,789.07 -2,727.52 18 11,628.24 6,521.35 3,550.25 -2,799.60 19 11,958.24 6,500.20 3,250.40 -2,930.27 20 12,108.24 6,485.89 3,121.60 -3,005.40 21 12,350.00 6,454.98 2,892.94 -3,074.54 Planned TD at 12350.00 8/12/2015 2:14.10PM Page 6 COMPASS 5000.1 Build 74 a • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3K Pad 3K-01 3K-01 L1 3K-01 L1_wp1 0 Travelling Cylinder Report 12 August, 2015 BAKER HUGHES INTEQ • I 1.--- ConocoPhillips lidiall BAKER ConocoPhillips Travelling Cylinder Report HUGHES INTEQ Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3K-01 Project: Kuparuk River Unit TVD Reference: Mean Sea Level Reference Site: Kuparuk 3K Pad MD Reference: 3K-01 @ 69.00usft(3K-01) Site Error: 0.00 usft North Reference: True Reference Well: 3K-01 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 3K-01L1 Database: EDM Alaska ANC Prod Reference Design: 3K-01L1_wp10 Offset TVD Reference: Offset Datum Reference 3K-01 L1_wp10 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,700.00 to 90,000.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,428.10 usft Error Surface: Elliptical Conic Survey Tool Program Date 8/6/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 8,700.00 3K-01 (3K-01) GCT-MS Schlumberger GCT multishot 8,700.00 12,350.00 3K-01 L1_wp10(3K-01L1) MWD MWD-Standard i Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name ("1 (•') I 12,350.00 6,454.98 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 3K Pad 3K-01-3K-01-3K-01 8,725.00 8,725.00 0.06 311.33 -306.63 FAIL-Major Risk 3K-01-3K-01-3K-01 8,774.95 8,775.00 1.02 3.04 -1.94 FAIL-Major Risk 3K-01-3K-01L1-3K-01 L1_wp10 12,275.00 12,275.00 0.38 365.69 -363.38 FAIL-Major Risk 3K-01-3K-01L1-01-3K-01L1-01_wp05 8,725.00 8,725.00 0.06 311.11 -306.30 FAIL-Major Risk 3K-01-3K-01L1-01-3K-01L1-01_wp05 11,927.10 11,925.00 36.02 187.48 -119.06 FAIL-Major Risk 3K-01-3K-01L1-02-3K-01 L1-02_wp04 8,725.00 8,725.00 0.06 311.11 -306.30 FAIL-Major Risk 3K-01-3K-01L1-02-3K-01 L1-02_wp04 9,174.98 9,175.00 0.69 0.68 0.02 Pass-Major Risk 3K-01-3K-01L1-03-3K-01 L1-03_wp02 8,725.00 8,725.00 0.06 311.11 -306.30 FAIL-Major Risk 3K-01-3K-01L1-03-3K-01 L1-03_wp02 9,174.98 9,175.00 0.69 0.68 0.02 Pass-Major Risk 3K-02-3K-02-3K-02 11,068.22 8,375.00 1,083.15 303.51 793.54 Pass-Major Risk 3K-05-3K-05-3K-05 Out of range 3K-06-3K-06-3K-06 Out of range 3K-19-3K-19-3K-19 Out of range 3K-20-3K-20-3K-20 Out of range 3K-22-3K-22-3K-22 Out of range 3K-22-3K-22A-3K-22A Out of range 3K-23-3K-23-3K-23 Out of range 3K-24-3K-24-3K-24 Out of range 3K-25-3K-25-3K-25 Out of range Plan 3K 36 3K 36 3K 36(wp01) 12,159.35 7,950.00 404.37 243.43 165.40 Pass-Major Risk Offset Design Kuparuk 3K Pad- 3K 01 3K 01 3K 01 Offset Site Error: 000 usft Survey Program: 100- Rule Assigned:Major Risk 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 1-N1/-S +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (1 (usft) (usft) r9 (usft) (usft) (usft) 8,700.00 6,487.18 8,700.00 6,487.18 52.12 52.13 8.72 5,224.97 -1,114.61 2-11/16 0.00 310.96 -277.29 FAIL-Major Risk,CC CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 8/12/2015 10:25:45AM Page 2 COMPASS 5000.1 Build 74 • • IIM kb iI ®' I i1 : iF , g?i1Fu1!ii �C -h is g 6. . ,7,yl _ C, I .1 s .m O q�Jo�7 E _ ® Y "f�� Lli `\ 1 ` Y }ill I 8 Y : \\ \-1, '• ' YomI'3 m .. 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OOLei.5 copCpD CD CO CO CO co Ci CO OJ T OO CD CO co COO e O O r co s O I O I a l zI rn 2l 3 0 0 0 0 0 Z2 cr r'N c`"v o f ,D 0 0 •R• S� I� n p OD OD co OO aO N O `O U N M IA CO I�CO O 0 N M �D(O 1-CO O N' CV ( OSI) `3 u I A .L O �o � Nui sn da ea��aa mu V • • Bettis, Patricia K (DOA) f 1 J ;/s/c/ From: Winfree, Mike A <Michael.A.Winfree@conocophillips.com> Sent: Monday, September 14, 2015 8:58 AM To: Bettis, Patricia K (DOA) Subject: FW: [EXTERNAL]KRU 3K-01L1: Permit to Drill Application (PTD 215-161) Attachments: 3K-01L1_wpl0 VPO - NAD27.pdf; 3K-01L1-01_wp05 VPO - NAD27.pdf; 3K-01L1-02 _wp04 VPO - NAD27.pdf; 3K-01L1-03_wp02 VPO - NAD27.pdf Good Morning Patricia, Attached are the cross-section and map view wellbore plots for all of the KRU 3K-01 laterals. Sorry for the delay. Please let me know if you need more information to process this permit application. Thank you, -Mike Drilling Engineer I ConocoPhillips Alaska I ATO-660 I Direct:+1(907)263-4404 I Cell:+1(907)202-2887 From: Burke, Jason Sent: Friday, September 11, 2015 8:05 PM To: Winfree, Mike A Cc: Eller, J Gary; Venhaus, Dan E Subject: FW: [EXTERNAL]KRU 3K-01L1: Permit to Drill Application (PTD 215-161) Sent with Good (www.good.com) From: Callahan, Mike S Sent: Friday, September 11, 2015 10:08:42 PM To: Burke,Jason; Pohler, Cody J Subject: Fwd: [EXTERNAL]KRU 3K-01L1: Permit to Drill Application (PTD 215-161) Sent from my iPhone Begin forwarded message: From: "Bettis, Patricia K (DOA)" <patricia.bettis@alaska.gov> Date:September 11, 2015 at 4:17:54 PM AKDT To: "Callahan, Mike S (Mike.Callahan@conocophillips.com)" <Mike.Callahan@conocophillips.com> Subject: [EXTERNAL]KRU 3K-01L1: Permit to Drill Application (PTD 215-161) Good afternoon Mike, 1 • Please submit the cross-sectional and planar wellbore plats for KRU 3K-01L1. Only the spider map was included in the applications. Thank you and have a great weekend. Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • 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. 41110 • TRANSMITTAL LETTER CHECKLIST WELL NAME: {Ru,,, .31( 01 L PTD: ge ) ✓ Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: 11\l 1f2 , �,t Ati POOL: /4tyc.,/t„ tcr r,I � ( K ?1 ©:I 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. 1.810- /d( , API No. 50- 0.9- 1 (, 0C) - OC) - DO. V (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 • • N❑ To a) 0 co ' '°' 2o Ul O @ O, U, QL 1 a w a O L N O y d 3. E o O. O z @ 4 u) a co 0 o. w • L a) a > : p w N C' O. N _ W d C a). O� c O C E O o o' a — m , v. N3. NO W' I . py . oaf oa °. a ° J p a 0) 3 o . O c: co a a @i; rni �' °' o c c ° t o o E.1-0 N. t N' OE w �' a E. o) o_cs 3. 3' m ; moo' Y. co m �o Y' £ o. m, 4 0 Q nQ' y a)' L M, Ce' 9 3' o' - v. 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