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D ID D O D o m o m 0 o m o 0 a 2 w w w w _J Z U a C) 0 0 Ce 0 0 RECEIVED • • DEC 18 2015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND�(; G la.Well Status: Oil 0- Gas 0 SPLUG 0 Other 0 Abandoned Suspended 0 1 b.Well Class: 20AAC 25.105 20MC 25.110 Development Q , Exploratory❑ GINJ 0 WINJ 0 WAGE WDSPL❑ No.of Completions: Service 2 Stratigraphic Test 0 2.Operator Name: 6.Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. , Aband.: 11/19/2015 ' 215-144 3.Address: 7.Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 11/18/2015 • 50-029-21206-63 , 4a. Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 905'FSL, 160'FWL,Sec.36,T11N, R9E, UM 11/18/2015 • 2E-15L1-03 Top of Productive Interval: 9. Ref Elevations: KB: 142' 17. Field/Pool(s): 1498'FSL,3631'FWL,Sec 35,T11N,R9E,UM GL: 100' BF: 102' . Kuparuk River Field/Oil Pool • Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: .?/0 2323'FSL,3948'FWL,Sec 35,T11N,R9E,UM 7872'MD/6088'TVD • ADL 25658,26665- 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 529971 y- 5944547 Zone- 4 7945'MD/6,080'TVD ' 2584,2586 TPI: x- 528159 y- 5945134 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 528472 y- 5945959 Zone- 4 N/A 1495'MD/1495'TVD 5.Directional or Inclination Survey: Yes , Q(attached) No ❑ 13.Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 7044'MD/6176'TVD 22.Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/RES 23. CASING, LINER AND CEMENTING RECORD • WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 16" 6- 2.5 H-40 38 115 38 115 18 1975#Poleset 10-3/4" 4- 5.5 K-55 37 2607 37 2607 13.5 950 sx PF E,400 sx CI G 7" 26 J-55 34 7009 34 6183 8.5 225 sx CI G,250 sx PF C 2-3/8" 4.6 L-80 6708' 7872' 6120' 6088' 3 Slotted Liner 24.Open to production or injection? Yes Ei No ❑ 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5"x 5.5" 6737' 6539'MD/5997'TVD Slotted Liner from 6708'-7872'MD/6120'-6088'TVD COMPLETION 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. DATE Was hydraulic fracturing used during completion? Yes 0 No 0 il/ta Per 20 AAC 25.283(i)(2)attach electronic and printed information VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED I.' 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 12/1/2015 Gas lift Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 12/5/2015 14.9 Test Period -322 812 85 100 Bean 2260 scf/STB Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 460 psi 1200 psi 24-Hour Rate -► 511 1347 128 Not Measured Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 1'1.1,15 i/l t lic, Submit ORIGINIAL only vT` //41/.6RBDMS LADEC 312015 1 1 . • 28.CORE DATA Conventional Core(s): Yes ❑ No 11 Sidewall Cores: Yes ❑ No Q 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 Q Permafrost-Top surface surface If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1495' 1495' Attach separate pages to this form,if needed,and submit detailed test information,including reports, per 20 AAC 25.071. Top of Productive Interval 7044' 6175' (Kuparuk A Sand) Formation at total depth: 7945' 6080' (Kuparuk A6 Sand) . 31. List of Attachments: Summary of daily operations,schematic and final directional surveys. 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. n Contact: Ron Phillips @ 265-6312 Email: Ron.L.Phillips(c�cop.com i2 Printed Name: D.Venhaus Title: CTD Engineering Supervisor \ Signature: ----y c. . \k. � � Phone: 263-4372 Date: .1[' — — `Z\\)4 �J INSTRUCTIONS General: This form d the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 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. 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N w I;: VI Op M CO Q CO CO N N NUa Mo o N16 (0 o.c F O n t A- 0 Operations Summary (with Timelog Depths) 2E-15 Com:x(4 lHips Yekn 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 {ftK8) End Depth(ftKE) 10/28/2015 10/28/2015 2.00 MIRU MOVE MOB P Prep to move Rig to 2E-15,pull pit 0.0 0.0 13:00 15:00 module away from drilling sub.Send s 1�hop to 2E-15. 10/28/2015 10/28/2015 1.50 MIRU MOVE ` MOB P 'PJSM,Peak and rig crew,Pull rig 0.0 0.0 15:00 16:30 module off of 3K-01,install jeeps, ready for move to 2E-15 10/28/2015 10/28/2015 5.50 MIRU MOVE MOB P Start moving rig to 2E-15 0.0 0.0 16:30 22:00 10/28/2015 10/29/2015 2.00 MIRU MOVE MOB P Rig on location,Prep well for Rig,Spot 0.0 0.0 22:00 00:00 drillir J sub. 10/29/2015 10/29/2015 2.00 MIRU MOVE MOB P Spot oit module to drilling sub. 0.0 0.0 00:00 02:00 Release Peak 10/29/2015 10/29/2015 4.00 MIRU MOVE RURD P PJSM MIRU CDR2,Start post rig 0.0 0.0 02:00 06:00 move checklist,DTH-reinstall scaffolding in cellar,removed for gravel work around well head. 10/29/2015 10/29/2015 2.75 MIRU WHDBOP RURD P Nipple up BOP stack,MP lines, 0.0 0.0 06:00 08:45 service tree valves,check torque on tree flanges(1 hr)8 at tubing head, 1 top of master,2 top of SSV, 1 bottom of SSV, 1 bottom of swab1 and 2 between swab 1 &2. Rig Accept 06:OOAM 10/29/2015 10/29/2015 10.00 MIRU WHDBOP BOPE P Test BOPE 250/4500,Annular 2,500 0.0 0.0 08:45 18:45 psi.Test waived by AOGCC(Johnnie Hill) Note: Door seal on lower DS blind/shear ram leak,replace seal(2.5 hrs) 10/29/2015 10/29/2015 3.00 MIRU WHDBOP RGRP T Change out all BOPE door seals,after 0.0 0.0 18:45 21:45 further discussion with team. ****Note:Found 6 o-rings with delamination damage. 10/29/2015 10/29/2015 0.50 MIRU WHDBOP PULD P LD BOP test Equipment. 0.0 21:45 22:15 10/29/2015 10/29/2015 1.50 SLOT WELLPR CTOP P Load coil,Test and Chart,shell test, 0.0 0.0 22:15 23:45 inner reel valve and stripper, 10/29/2015 10/30/2015 0.25 MIRU WHDBOP MPSP P PJSM,Load FMC lubricator and tools. 0.0 0.0 23:45 00:00 10/30/2015 10/30/2015 1.00 MIRU WHDBOP MPSP P Crew change,PJSM,RU FMC 0.0 0.0 00:00 01:00 equipment,pull TWC,LD FMC lubricator,230 psi WHP. 10/30/2015 10/30/2015 3.00 MIRU WHDBOP PRTS P PJSM,test PDL's and tiger tank line, 0.0 0.0 01:00 04:00 install BHI checks into the upper quick. 10/30/2015 10/30/2015 0.50 MIRU WHDBOP SFTY P Prespud with crew and third party. 0.0 0.0 04:00 04:30 10/30/2015 10/30/2015 2.50 PROD1 WHPST PULD P PJSM,P/U and Deploy BHA#1, 0.0 74.3 04:30 07:00 Window milling BHA with 0.6°motor, 2.80 window mill,and 2.80 string reamer,M/U to coil and surface test, tag up and set counters. 10/30/2015 10/30/2015 2.00 PROD1 WHPST TRIP P RIH with BHA#1.Tie in to K1 for 74.3 6,695.0 07:00 09:00 plus.5 ft correction,continue in hloe, PUW 28.5k. Page 1/15 Report Printed: 12/15/2015 • • Operations Summary (with Timelog Depths) .110,01 2E-15 +Cc nocoPhitiips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/30/2015 10/30/2015 6.75 PROD1 WHPST DISP P Displace well to 9.3 ppg PwrPro 6,695.0 6,718.0 09:00 15:45 milling fluid,hole taking.25 bp at 11.8 ECD,mix and pump 20 bbl pill of 100k LSRV 11.8 ppg NaBr,slow pumping.1 bpm at max annular pressure of 3,733 psi.Dry tag pinch point at 6,718.3 ft, PUW 28k. 10/30/2015 10/31/2015 8.25 PROD1 WHPST WPST P 6,718 ft Mill window per recomended 6,718.0 6,723.1 15:45 00:00 practice 4°LOHS, 1.53 bpm at 3,033 psi FS,BHP 3,700 psi,IA 0,OA 0 10/31/2015 10/31/2015 0.75 PROD1 WHPST WPST P 6723 ft,OBM 1.52 bpm at 3251 psi, 6,723.1 6,723.6 00:00 00:45 BHP 3690,WHP 236,IA 431,OA 0 10/31/2015 10/31/2015 1.00 PROD1 WHPST WPST P 6723.6 ft,looks like the mill has exited 6,723.6 6,725.0 00:45 01:45 the casing.Continue milling ahead to 6725.1 ft, 10/31/2015 10/31/2015 2.00 PROD1 WHPST WPST P 6725 ft,drill rat hole, 1.52 bpm at 3278 6,725.0 6,738.0 01:45 03:45 psi,BHP 3710,WHP 237, IA 466,OA 0 10/31/2015 10/31/2015 1.50 PROD1 WHPST REAM P 6738 ft,TD rate hole, PUH,back ream 6,738.0 6,738.0 03:45 05:15 window area at 60 fph,dry drift clean. 10/31/2015 10/31/2015 1.60 PROD1 WHPST TRIP P POOH for drilling BHA 6,738.0 74.3 05:15 06:51 10/31/2015 10/31/2015 1.50 PROD1 WHPST PULD P PJSM-Un-depoly BHA#1,2.79"no- 74.3 0.0 06:51 08:21 go mill and string reamer 10/31/2015 10/31/2015 0.50 PROD1 DRILL BOPE P PJSM-RU test equipment,function 0.0 0.0 08:21 08:51 test BOPE,LD test equipment. 10/31/2015 10/31/2015 1.80 PROD1 DRILL PULD P PJSM-MU/PD BHA#2,2.3°+AKO 0.0 72.2 08:51 10:39 motor and RR 1-1,HCC bi-center bit, MU to CoilTrak,surface test. 10/31/2015 10/31/2015 1.80 PROD1 DRILL TRIP P RIH with build drilling BHA#2,tie in at 72.2 6,738.0 10:39 12:27 K1 for plus 2.5 ft correction,close EDC,PUW 27k at window. 10/31/2015 10/31/2015 4.50 PROD1 DRILL DRLG P 6,738 ft, OBD 1.56 bpm at 3,387 psi, 6,738.0 6,900.0 12:27 16:57 BHP 3,672 psi, IA 164,OA 0 10/31/2015 10/31/2015 1.00 PROD1 DRILL DRLG P 6900 ft,trouble drilling ahead,MU and 6,900.0 6,915.0 16:57 17:57 pump 20 bbls screen clean pill 10/31/2015 11/1/2015 6.05 PROD1 DRILL DRLG P 6915 ft,pill was unsuccessful in 6,915.0 7,002.6 17:57 00:00 cleaning bit,continue drilling ahead at 10-15 fph,samples showing clay, 1.5 bpm at 3745 psi,WHP 176, IA 642, OA 0 11/1/2015 11/1/2015 0.50 PROD1 DRILL DRLG P 7003 ft,OBD build section,TD build 7,002.6 7,013.0 00:00 00:30 section at 7013 ft, BHP 3700,WHP 198,IA 678,OA 0 11/1/2015 11/1/2015 0.25 PROD1 DRILL WPRT P 7013 ft,Pump 5x5 sweep,wiper up to 7,013.0 6,700.0 00:30 00:45 the window,PUW 26k 11/1/2015 11/1/2015 0.25 PROD1 DRILL TRIP P 6700 ft, POOH 6,700.0 72.2 00:45 01:00 ****Note: 1 Hr fall back on clocks. 11/1/2015 11/1/2015 0.25 PROD1 DRILL SFTY P At surface,PJSM for PUD build BHA, 72.2' 72.2 01:00 01:15 BHA#2 11/1/2015 11/1/2015 1.25 PROD1 DRILL PULD P PJSM,PUD,build section BHA 72.2 0.0 01:15 02:30 11/1/2015 11/1/2015 1.25 PROD1 DRILL PULD P PJSM,PD lateral BHA,BHA#3 0.0 69.2 02:30 03:45 11/1/2015 11/1/2015 1.30 PROD1 DRILL TRIP P Tag up and reset counters to zero, 69.2 6,520.0 03:45 05:03 RIH with lateral BHA,w/RSM Page 2/15 Report Printed: 12/15/2015 k • • ... Operations Summary (with Timelog Depths) 2E-15 ConocoPhili ps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity.Code; Ttme P-T-X Operation (ftKB) End Depth(ftKS): 11/1/2015 11/1/2015 0.50 PROD1 DRILL DLOG P Tie into the K1 marker correction of 6,520.0 6,985.0 05:03 05:33 plus 1.0 ft,continue in hole to log RA, PUW above window 26k,start stacking at bottom of window,pick up to 25 fpm to get through build area,no problem,no RA log, 11/1/2015 11/1/2015 0.70 PROD1 DRILL TRIP T 6,988 ft, attempt to bring pumps on, 6,958.0 6,694.0 05:33 06:15 motor stalled immediately,attempts to pump failed, PU into BTP,pumping .1 bpm with 800 psi differential,confer with town. 11/1/2015 11/1/2015 1.75 PROD1 DRILL TRIP T Open EDC,POOH to inspect bit and 6,694.0 69.2 06:15 08:00 tools,stop at 1,100 ft to check that EDC functioning,POOH. 11/1/2015 11/1/2015 1.40 PROD1 DRILL PULD T PJSM-PUD BHA#3,bit balled up but 69.2 0.0 08:00 09:24 not plugged,RSM motor chuncked, LD BHA#3 11/1/2015 11/1/2015 1.60 PROD1 DRILL PULD T 2nd RSM being delivered from KCS, 0.0 0.0 09:24 11:00 move top end over to DS PDL.truck on pad with RSM, MU RSM high side and test. 11/1/2015 11/1/2015 1.35 PROD1 DRILL PULD T PJSM-MU/PD RSM lateral drilling 0.0 69.2 11:00 12:21 BHA#4,MU to CoilTrak,surface test. 11/1/2015 11/1/2015 1.50 PROD1 DRILL TRIP T RIH with RSM lateral drilling BHA#4. 69.2 6,520.0 12:21 13:51 11/1/2015 11/1/2015 0.50 PROD1 DRILL DLOG T Tie in to K1 for 0 ft correction,RIH, 6,520.0 7,013.0 13:51 14:21 PUW above window 26.5k,RBIH and log RA at 6 fpm,RA at 6,720 ft. continue in hole no problems. 11/1/2015 11/1/2015 8.00 PROD1 DRILL DRLG P 7,013 ft,OBD 1.45 bpm at 3,464 psi, 7,013.0 7,410.0 14:21 22:21 BHP 3,702 psi,WH 156, IA 183,OA 0 11/1/2015 11/1/2015 0.50 PROD1 DRILL WPRT P 7410 ft,Wiper up hole to 7050 ft,PUW 7,410.0 7,050.0 22:21 22:51 26k ***Note:7381 ft,New mud at the bit @ 21:30 11/1/2015 11/1/2015 0.25 PROD1 DRILL WPRT P 7050 ft,Wiper back in hole.RIW 14 k 7,050.0 7,410.0 22:51 23:06 11/1/2015 11/2/2015 0.90 PROD1 DRILL DRLG P 7410 ft,BOBD 1.64 bpm at 3600 psi, 7,410.0 7,423.0 23:06 00:00 BHP 3770,WHP 181, IA 178,OA 0 11/2/2015 11/2/2015 3.00 PROD1 DRILL DRLG P 7423 ft,OBD 1.64 bpm at 3600 FS, 7,423.0 7,436.0 00:00 03:00 BHP 3751,WHP 184,IA 180,OA 0 11/2/2015 11/2/2015 6.00 PROD1 DRILL DRLG P 7436 ft,OBD in ankerite at 4-8 fph, 7,436.0 7,462.0 03:00 09:00 1.64 bpm at 4025 psi,BHP 3784, WHP 176,IA 258,OA 0 11/2/2015 11/2/2015 7.00 PROD1 DRILL DRLG P 7,465 ft, OBD in ankerite at 4-8 fph, 7,462.0 7,630.0 09:00 16:00 1.64 bpm at 3,964 psi,BHP 3,787 psi, WHP 166,IA 365,OA 0,broke out of ankerite brifly at 7,470 ft,drilled through stringers to 7,550 ft. 11/2/2015 11/2/2015 3.25 PROD1 DRILL DRLG P 7,630 ft, OBD 1.65 bpm at 4,083 psi, 7,630.0 7,710.0 16:00 19:15 BHP 3,825 psi,WHP 159, IA 496,OA 0,ROP 90 11/2/2015 11/2/2015 0.50 PROD1 DRILL WPRT P 7710 ft,perform early wiper up hole to 7,710.0 7,050.0 19:15 19:45 7050 ft,do to dificultty drilling ahead. PUW 26 11/2/2015 11/2/2015 0.25 PROD1 DRILL WPRT P 7050 ft,Wiper back in hole,RIW 14 k 7,050.0 7,710.0 19:45 20:00 Page 3/15 Report Printed: 12/15/2015 10 • Operations Summary (with Timelog Depths) Orr f 2E-15 ConocoPhiilips ; Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T•X Operation (MKS);' End Depth(ftKB) 11/2/2015 11/2/2015 3.00 PROD1 DRILL DRLG P 7710 ft,BOBD 1.55 bpm at 3590 psi 7,710.0 7,769.7 20:00 23:00 FS,BHP 3775,WHP 130,IA 517,OA 0 11/2/2015 11/3/2015 1.00 PROD1 DRILL WPRT P 7770 ft,Wiper up hole,chasing 5x5 7,769.7 6,749.0 23:00 00:00 sweep,PUW 26 k ****Note:Noticed some dragging thru the build section minus 1-3 k. 11/3/2015 11/3/2015 0.50 PROD1 DRILL WPRT P Continue wiper up hole thru window to 6,749.0 6,740.0 00:00 00:30 6600 ft,jetting BTP,RIH to tie in depth. 11/3/2015 11/3/2015 0.25 PROD1 DRILL DLOG P 6735 ft,Tie into the RA marker 6,740.0 6,770.0 00:30 00:45 correction of plus 0.5 ft. 11/3/2015 11/3/2015 0.50 PROD1 DRILL WPRT P 6770 ft,continue wiper back in hole, 6,770.0 7,770.0 00:45 01:15 RIW 15k 11/3/2015 11/3/2015 10.10 PROD1 DRILL DRLG P 7770 ft,BOBD 1.5 bpm at 3850 psi, 7,770.0 8,170.0 01:15 11:21 BHP 3811,WHP 130,IA 556,OA 0 11/3/2015 11/3/2015 1.10 PROD1 DRILL WPRT P Wiper trip to window,6800', 8,170.0 8,170.0 11:21 12:27 PUW=29K,With sweeps,Clean trip up and down 11/3/2015 11/3/2015 5.50 PROD1 DRILL DRLG P 8170',Drill Ahead, 1.6 BPM @ 3800 8,170.0 8,470.0 12:27 17:57 PSI FS,BHP=3825 11/3/2015 11/3/2015 3.00 PROD1 DRILL DRLG P 8470 ft,OBD 1.6 bpm @ 3800 psi, 8,470.0 8,570.0 17:57 20:57 BHP 11/3/2015 11/3/2015 1.00 PROD1 DRILL WPRT P 8570 ft,Wiper up hole to 7060 ft 8,570.0 7,060.0 20:57 21:57 chasing 5x5 sweep,PUW 30 k 11/3/2015 11/3/2015 0.50 PROD1 DRILL WPRT P 7060 ft,Wiper back in hole RIW 14 k 7,060.0 8,570.0 21:57 22:27 11/3/2015 11/4/2015 1.55 PROD1 DRILL DRLG P 8570 ft,BOBD 1.6 bpm at 4094,BHP 8,570.0 8,625.0 22:27 00:00 3853,WHP 71, IA 384,OA 0 11/4/2015 11/4/2015 3.00 PROD1 DRILL DRLG P 8625 ft,OBD 1.6 bpm at 4000 psi, 8,625.0 8,727.0 00:00 03:00 BHP 3859,WHP 73,IA 387,OA 0 11/4/2015 11/4/2015 2.50 PROD1 DRILL DRLG P 8727 ft,OBD,28 fph,2 k DHWOB,6 8,727.0 8,790.0 03:00 05:30 k CTSW, 1.6 bpm at 4030 psi,BHP 3892,WHP 70,IA 426,OA 0 11/4/2015 11/4/2015 2.70 PROD1 DRILL WPRT P Pull wiper with sweeps up to 5 1/2 X 3 8,790.0 8,790.0 05:30 08:12 1/2 XO @ 6602'.PUW=30K,Tie in for +2'correction.Clean trip up and down. Observed out density spike at sweeps 11/4/2015 11/4/2015 6.20 PROD1 DRILL DRLG P Drill, 1.6 BPM @ 3810 PSI FS, 8,790.0 9,024.0 08:12 14:24 BHP=3890,New mud out @ 8835' 11/4/2015 11/4/2015 0.60 PROD1 DRILL WPRT P 6024'wiper to 8000'with sweeps. 9,024.0 9,024.0 14:24 15:00 PUW=26K,Observed 9.7PPG out when sweeps got to surface 11/4/2015 11/4/2015 3.86 PROD1 DRILL DRLG P 9024',Drill, 1.67 BPM @ 3970 PSI 9,024.0 9,172.0 15:00 18:51 FS,BHP=3920 11/4/2015 11/4/2015 0.25 PROD1 DRILL WPRT P 9172 ft,short wiper up hole to 9026 ft. 9,172.0 9,172.0 18:51 19:06 11/4/2015 11/4/2015 1.25 PROD1 DRILL DRLG P 9172 ft,BOBD 1.57 bpm at 3810 psi, 9,172.0 9,195.0 19:06 20:21 BHP 3900,WHP 148, IA 320,OA 0 11/4/2015 11/4/2015 1.25 PROD1 DRILL WPRT P 9195 ft,wiper up hole to 6800 ft,PUW 9,195.0 6,800.0 20:21 21:36 25 k ****Note:8797 ft motor spike on wiper Page 4/15 Report Printed: 12/15/2015 • Operations Summary (with Timelog Depths) 2E-15 ConocdPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) ` Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB); 11/4/2015 11/4/2015 1.25 PROD1 DRILL WPRT P 6800 ft,wiper back in hole.RIW 7 k, 6,800.0 9,195.0 21:36 22:51 min rate thru the build section,7013 ft, bring pump up to full rate. 1.5 bpm. """'Note:2 bobbles at 8843 ft and 8906 ft on wiper back in hole.Lower pump rate and speed to pass thru area. 11/4/2015 11/5/2015 1.14 PROD1 DRILL DRLG P 9195 ft,BOBD 1.6 bpm at 3740 psi, 9,195.0 9,216.0 22:51 00:00 BHP 3916,WHP 140,IA 328,OA 0 11/5/2015 11/5/2015 3.00 PROD1 DRILL DRLG P 9216 ft,OBD 1.6 bpm at 4081 psi, 9,216.0 9,342.0 00:00 03:00 BHP 3903,WHP 147,IA 329,OA 0 11/5/2015 11/5/2015 3.50 PROD1 DRILL DRLG P 9342 ft,OBD 1.5 bpm at 3997, BHP 9,342.0 9,495.0 03:00 06:30 3945,WHP 130, IA 362,OA 0 11/5/2015 11/5/2015 2.30 PROD1 DRILL WPRT P Wiper trip#3 to window with 5 X 5 9,495.0 6,745.0 06:30 08:48 swweps. PUW=25 and jet 5 1/2". Overpulls and packing off from 8990 up to 8700.Pack off up in 5 1/2 @ 5639 and 5619.Jog through 5 1/2 and get cleaned up.Shales on shaker from 5 1/2 tubing. 11/5/2015 11/5/2015 0.10 PROD1 DRILL DLOG P Log RA for+2' 6,745.0 6,750.0 08:48 08:54 11/5/2015 11/5/2015 1.20 PROD1 DRILL WPRT P Continue wiper trip to bottom,Stack 6,750.0 9,496.0 08:54 10:06 out @ 8810 and 8960,Get through with reduced rate.Had to work 9400 down to bottom 11/5/2015 11/5/2015 3.90 PROD1 DRILL DRLG P 9464',Drill, 1.58 BPM @ 3985 PSI 9,496.0 9,618.0 10:06 14:00 FS,BHP=3995 11/5/2015 11/5/2015 1.50 PROD1 DRILL DRLG T 9618,Build hard for Top of the A5 9,618.0 9,963.0 14:00 15:30 location 11/5/2015 11/5/2015 3.00 PROD1 DRILL TRIP T 9963,Trip out for billet,Pump sweeps, 9,963.0 69.0 15:30 18:30 PUW=25K 11/5/2015 11/5/2015 0.50 PROD1 DRILL SFTY T PJSM,Undeploy lateral BHA,BHA#4 69.0 69.0 18:30 19:00 11/5/2015 11/5/2015 1.50 PROD1 DRILL PULD T Undeploy BHA 69.0 0.0 19:00 20:30 11/5/2015 11/5/2015 1.50 PROD1 STK PULD T M/U and Deploy anchored billet BHA. 0.0 72.9 20:30 22:00 .*'*Note:P/T UQC to 4200 psi. 11/5/2015 11/5/2015 1.50 PROD1 STK TRIP T Stab INJH,surface test tools,Tag up, 72.9 6,525.0 22:00 23:30 reset counters, RIH with Open Hole Anchored Billet. 11/5/2015 11/5/2015 0.25 PROD1 STK DLOG T 6525 ft,Tie into the K1 marker 6,525.0 6,548.0 23:30 23:45 correction of plus 1.0 ft.Close EDC. 11/5/2015 11/6/2015 0.25 PROD1 STK TRIP T 6548 ft,continue RIH,close EDC,RIH 6,548.0 6,764.0 23:45 00:00 at 25 fpm set down 6762 ft, PUH and RIH 35 fpm set down 6764 ft,5 k, PUH,PUW 27 k,DHWOB-1.5 k, confer with town,decisoin was made to POOH for a cleanout run. 11/6/2015 11/6/2015 1.50 PROD1 STK TRIP T 6764 ft,Continue POOH to surface. 6,764.0 72.9 00:00 01:30 11/6/2015 11/6/2015 0.25 PROD1 STK SFTY T PJSM,for PUD Open Hole Anchored 72.9 72.9 01:30 01:45 Billet. 11/6/2015 11/6/2015 1.00 PROD1 STK PULD T PUD Billet BHA#5 72.9 0.0 01:45 02:45 Page 5/15 Report Printed: 12/15/2015 i ¢k v�� •• • 4 Operations Summary (with Timelog Depths) 2E-15 iir'o 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(ftK8) 11/6/2015 11/6/2015 1.25 PROD1 STK PULD T PJSM,PD cleanout BHA,Make up to 0.0 62.0 02:45 04:00 coil and surface test 11/6/2015 11/6/2015 1.60 PROD1 STK TRIP T Trip in hole,EDC open 62.0 6,520.0 04:00 05:36 11/6/2015 11/6/2015 0.10 PROD1 STK DLOG T Log K1 for+1'correction 6,520.0 6,540.0 05:36 05:42 11/6/2015 11/6/2015 1.40 PROD1 STK WPRT T Continue in well,Close EDC @ 6699', 6,540.0 6,758.0 05:42 07:06 Clean pass through window,slight motor work in area where setdown with anchor occured.Lost weight @ 6778.Clear down to EOB @ 7010. PUH with sweeps coming out 11/6/2015 11/6/2015 1.10 PROD1 STK WPRT T Confir with town,Run clean out BHA 6,758.0 8,307.0 07:06 08:12 to below anchor setting depth. 1.2 BPM @ 35 FPM.weight bobble @ 8236&8269'.Pump additional sweeps 11/6/2015 11/6/2015 2.40 PROD1 STK TRIP T 8307,sweeps out,trip out of hole, 8,307.0 65.0 08:12 10:36 PUW=26K,recip 5 1/2 and below window 11/6/2015 11/6/2015 1.40 PROD1 STK PULD T At surface, PJSM,PUD BHA#6 65.0 0.0 10:36 12:00 11/6/2015 11/6/2015 1.10 PROD1 STK PULD T PJSM,M/U and PD BHA#7 0.0 73.0 12:00 13:06 Anchored billet,Make up to coil and surface test 11/6/2015 11/6/2015 1.50 PROD1 STK PULD T RIH BHA#7,Anchored Billet,EDC 73.0 6,520.0 13:06 14:36 Open 11/6/2015 11/6/2015 0.10 PROD1 STK DLOG T Log K1 for+.5'correction 6,520.0 6,553.0 14:36 14:42 11/6/2015 11/6/2015 1.40 PROD1 STK TRIP T Continue in well,Stop and close EDC 6,553.0 8,261.8 14:42 16:06 @ 6690'.Clean pass through window. Stacking at 6747 and 6756.Did not have to pick up.Contine into set depth @ 8261.75 11/6/2015 11/6/2015 2.25 PROD1 STK WPST T Set anchored billet @ 8261.75,Top of 8,261.8 72.9 16:06 18:21 billet @ 8250,oriented to 350°, 10° LOHS,See tool shift @ 4200 PSI, DHWOB to 2K.Trip out 11/6/2015 11/6/2015 1.25 PROD1 STK PULD T PJSM,PUD and LD BHA#7 billet 72.9 0.0 18:21 19:36 setting tools, 11/6/2015 11/6/2015 0.75 PROD1 STK PULD T P/U and M/U tools into PDL,motor 0.0 0.0 19:36 20:21 and bit,and scribe,Drilling BHA#8, 11/6/2015 11/6/2015 1.25 PROD1 STK PULD T PD,Kickoff/Drilling BHA#8 0.0 72.1 20:21 21:36 11/6/2015 11/6/2015 1.20 PROD1 STK TRIP T RIH,with drilling BHA#8 w/low bend 72.1 6,525.0 21:36 22:48 motor and new bit 11/6/2015 11/6/2015 0.25 PROD1 STK DLOG T 6525 ft,Tie into the K1 marker 6,525.0 6,545.0 22:48 23:03 correction of plus 5.5 ft, PUW 26 k 11/6/2015 11/6/2015 0.65 PROD1 STK TRIP T 6545 ft,Continue RIH,RIW 13 k 6,545.0 8,250.0 23:03 23:42 11/6/2015 11/7/2015 0.30 PROD1 STK KOST T 8250 ft,dry tag TOB,PUH,bring 8,250.0 8,250.0 23:42 00:00 pump up, PUW 26 k 11/7/2015 11/7/2015 2.00 PROD1 STK KOST T 8250 ft,attemp to kick off of billet. 1.5 8,250.0 8,250.0 00:00 02:00 bpm at 3710 psi,BHP 3873,WHP 174, IA 19,OA 0,working pipe,pump rates,and TF. 11/7/2015 11/7/2015 0.50 PROD1 STK KOST T Unable to get kicked off,mix up max 8,250.0 8,250.0 02:00 02:30 lube pill with 2%lo-torque/2%Lube 776, Page 6/15 Report Printed: 12/15/2015 �ee 4 • • =' . :F • Operations Summary (with Timelog Depths) "111--4'; ;' ff' ,, 2E-15 ConocaPhitiips 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) 11/7/2015 11/7/2015 4.00 PROD1 STK KOST T 8250 ft,attemp again to kick off of 8,250.0 8,250.0 02:30 06:30 billet, 1.4 bpm at 3557 psi,BHP 3850, IA 40,Work to get started while lube pill is around tool,Unable to get started. 11/7/2015 11/7/2015 0.70 PROD1 STK WPRT T Perform wiper trip to window 6802, 3,250.0 8,250.0 06:30 07:12 PUW=27K 11/7/2015 11/7/2015 1.00 PROD1 STK KOST T Attempt to get started on billet, 8,250.0 8,250.0 07:12 08:12 multiple heavy stalls.Tool is stick slipping. Run at billet at multiple speeds and pump rates.Try different TF's 11/7/2015 11/7/2015 0.50 PROD1 STK WPRT T 8250,Back ream off top of billet to 8,250.0 8,250.0 08:12 08:42 8230,wiper to 8175,RBIH to get kicked off 11/7/2015 11/7/2015 1.00 PROD1 STK KOST T 8250,try to get on billet,multiple 8,250.0 8,250.0 08:42 09:42 stalls,again try multiple pump rates, RIH speeds,and TF's.Start taking returns to TT for mud swap 11/7/2015 11/7/2015 0.80 PROD1 STK WPRT T Back ream hole on low side @ 2FPM, 8,250.0 8,250.0 09:42 10:30 New mud going down coil 11/7/2015 11/7/2015 1.00 PROD1 STK KOST T Get on billet @ HS-20L, 1.44 BPM @ 8,250.0 8,253.0 10:30 11:30 3270 PSI FS. .8K DHWOB with slight motor work.Start time milling.New mud @ BIT 8252 10:35 11/7/2015 11/7/2015 0.60 PROD1 STK KOST T 8253 goto 5 FPH,goto 10FPH after 2 8,253.0 8,257.0 11:30 12:06 feet,Goto 20FPH 11/7/2015 11/7/2015 0.40 PROD1 DRILL DRLG T '8257',Drilling, 1.44 BPM @ 3294 PSI 8,257.0 8,276.0 12:06 12:30 FS,BHP=3812 11/7/2015 11/7/2015 0.30 PROD1 DRILL WPRT T 8276',PU to drift billet area, 8,276.0 8,276.0 12:30 12:48 PUW=29K,Billet dry drift clean 11/7/2015 11/7/2015 5.75 PROD1 DRILL DRLG T 8276', 1.4 BPM @ 3269 PSI FS, 8,276.0 8,640.0 12:48 18:33 BHP=3833 11/7/2015 11/7/2015 1.00 PROD1 DRILL WPRT T 8640 ft,Wiper up hole to 6800 ft,PUW 8,640.0 6,800.0 18:33 19:33 27 k 11/7/2015 11/7/2015 0.50 PROD1 DRILL WPRT T 6800 ft,Wiper back in hole,RIW 14.5 6,800.0 8,640.0 19:33 20:03 k 11/7/2015 11/8/2015 3.95 PROD1 DRILL DRLG T 8640 ft,BOBD 1.5 bpm at 3720 psi, 8,640.0 8,842.0 20:03 00:00 BHP 3855,WHP 171,IA 120,OA 0 11/8/2015 11/8/2015 1.50 PROD1 DRILL DRLG T 8842 ft,OBD 1.5 bpm at 3963 psi, 8,842.0 8,940.0 00:00 01:30 BHP 3891,WHP 152,IA 209,OA 0 11/8/2015 11/8/2015 1.00 PROD1 DRILL WPRT T 8940 ft,Wiper up hole to 6600 ft.PUH 8,940.0 6,600.0 01:30 02:30 27 k Jet the BTP area from 6600 ft to 6700 ft with sweeps. 11/8/2015 11/8/2015 0.50 PROD1 DRILL DLOG T RIH,tie into the RA marker correction 6,600.0 6,740.0 02:30 03:00 of plus 2.0 ft. 11/8/2015 11/8/2015 1.00 PROD1 DRILL WPRT T 6740 ft,continue wiper back in hole. 6,740.0 8,940.0 03:00 04:00 RIW 13 k 11/8/2015 11/8/2015 3.40 PROD1 DRILL DRLG T 8940 ft,BOBD 1.5 bpm at 3330 psi, 8,940.0 9,058.0 04:00 07:24 BHP 3893,WHP 186, IA 145,OA 0 11/8/2015 11/8/2015 0.90 PROD1 DRILL DRLG T 9058,P/U,Drill ahead, 1.52 BPM @ 9,058.0 9,096.0 07:24 08:18 3880 PSI FS,BHP=3950 11/8/2015 11/8/2015 4.50 PROD1 DRILL DRLG T 9096 Encounter low ROP<10 FPH 9,096.0 9,142.0 08:18 12:48 11/8/2015 11/8/2015 1.50 PROD1 DRILL DRLG T 9142',Drilling break,ROP 60-80 FPH 9,142.0 9,240.0 12:48 14:18 11/8/2015 11/8/2015 1.10 PROD1 DRILL WPRT T 9240,Wiper trip#1 to 8380'with 9,240.0 9,240.0 14:18 15:24 sweeps,PUW=28K Page 7/15 Report Printed: 12/15/2015 • • g., Y Operations Summary (with Timelog Depths) X 'VAtaif.V. 2E-15 ConocoPhillips IP Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftK8) 11/8/2015 11/8/2015 4.00 PROD1 DRILL DRLG T 9240',Drill Ahead, 1.52 BPM @ 3880 9,240.0 9,540.0 15:24 19:24 PSI FS,BHP=3920,WHP=121, IA=368,0A=0 11/8/2015 11/8/2015 1.50 PROD1 DRILL WPRT T 9540 ft,Wiper up hole for a tie in, 9,540.0 6,610.0 19:24 20:54 pump 5x5 sweep,PUW 26 k 11/8/2015 11/8/2015 0.25 PROD1 DRILL WPRT T 6610 ft,perform jog in BTP area 6,610.0 6,525.0 20:54 21:09 6610ft-6700 ft,chasing sweep. 11/8/2015 11/8/2015 0.25 PROD1 DRILL DLOG T 6525 ft,Tie into the RA marker 6,525.0 6,545.0 21:09 21:24 correction of plus 1.2 ft. 11/8/2015 11/8/2015 1.00 PROD1 DRILL WPRT T 6545 ft,Wiper back in hole RIW 13k 6,545.0 9,540.0 21:24 22:24 11/8/2015 11/8/2015 1.00 PROD1 DRILL DRLG T 9540 ft,BOBD 1.5 bpm at 3800 psi, 9,540.0 9,618.0 22:24 23:24 BHP 3935,WHP 62, IA 305,OA 0 11/8/2015 11/9/2015 0.60 PROD1 DRILL DRLG P 9618,OBD 1.5 bpm at 3800 psi FS, 9,618.0 9,674.0 23:24 00:00 BHP 3986,WHP 108,IA 413,OA 0 11/9/2015 11/9/2015 2.25 PROD1 DRILL DRLG P 9674 ft,OBD 1.55 bpm at 4249 psi, 9,674.0 9,870.0 00:00 02:15 BHP 3955,WHP 82,IA 448,OA 0 11/9/2015 11/9/2015 0.75 PROD1 DRILL WPRT P 9870 ft,Wiper up hole up to 8320 ft, 9,870.0 8,325.0 02:15 03:00 PUW 27 k 11/9/2015 11/9/2015 0.50 PROD1 DRILL WPRT P 8325 ft,Wiper back in hole.RIW 12 k 8,325.0 9,870.0 03:00 03:30 11/9/2015 11/9/2015 5.60 PROD1 DRILL DRLG P 9870 ft,BOBD 1.5 bpm at 3766 PSI 9,870.0 10,200.0 03:30 09:06 FS,BHP=4001 11/9/2015 11/9/2015 3.60 PROD1 DRILL WPRT P 10,200'reach plan TD, Pump 10 X 10 10,200.0 71.0 09:06 12:42 sweeps chase to swab,PUW=25K 11/9/2015 11/9/2015 1.40 PROD1 DRILL WPRT P Tag up at surface,reset counters and 71.0 6,525.0 12:42 14:06 RIH 11/9/2015 11/9/2015 0.20 PROD1 DRILL DLOG P Tie into K1 for+1.5' 6,525.0 6,551.0 14:06 14:18 11/9/2015 11/9/2015 1.90 PROD1 DRILL TRIP P Continue in hole,Clean trip down to 6,551.0 10,202.0 14:18 16:12 corrected TD @ 10202' 11/9/2015 11/9/2015 3.00 PROD1 DRILL TRIP P Circiulate 11.8 Beaded liner pill to bit, 10,202.0 72.2 16:12 19:12 POOH pumping beaded pill followed with 11.8 PPG completion fluid to surface.Paint EOP flags @ 9000'and 5500' 11/9/2015 11/9/2015 0.50 PROD1 DRILL OWFF P At surface,check well for flow,PJSM 72.2 72.2 19:12 19:42 for LD drilling BHA,BHA#8 11/9/2015 11/9/2015 0.75 PROD1 DRILL PULD P LD Driling BHA,fill hole. 72.2 0.0 19:42 20:27 11/9/2015 11/9/2015 0.25 COMPZ1 CASING PUTB P Prep rig floor for liner,inspect Top 0.0 0.0 20:27 20:42 Drive 11/9/2015 11/9/2015 1.50 COMPZ1 CASING PUTB P MU lower L1 liner section with 33 jts of 0.0 1,028.9 20:42 22:12 slotted liner,shorty deployment sleeve,and non-ported bull nose. 11/9/2015 11/9/2015 0.75 COMPZ1 CASING PUTB P MU Coiltrak tools and test,tag up, 1,028.9 1,028.9 22:12 22:57 reset counters,clean up rig floor after MU liner assembly. 11/9/2015 11/10/2015 1.05 COMPZ1 CASING RUNL P 1029 ft,RIH with L1 liner assembly 1,028.9 6,474.4 22:57 00:00 11/10/2015 11/10/2015 1.50 COMPZ1 CASING RUNL P 6474 ft,Continue RIH with lower liner 6,474.4 10,202.0 00:00 01:30 section,correct to the EOP flag at 5500 EOP,minus 1.0 ft. 11/10/2015 11/10/2015 0.25 COMPZ1 CASING RUNL P 10202 ft,Tag bottom,PUW 32 k,bring 10,202.0 10,202.0 01:30 01:45 pump up to 1.53 bpm release from liner, PUW 24 k. Page 8/15 Report Printed: 12/15/2015 * ,x Operations Summary (with Timelog Depths) r Oa 2E-15 Coricicillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr); Phase Op Code Activity Code Time P-T-X Operation (5KFB), End Depth(ftKE); 11/10/2015 11/10/2015 2.00 COMPZ1 CASING RUNL P 10202ft, PUH,remove liner from BHA, 10,202.0 44.2 01:45 03:45 liner up across the top,POOH,Tie into the K1 marker correction of plus 2.0 ft. 11/10/2015 11/10/2015 0.50 COMPZI CASING RUNL P At surface,check well for flow,PJSM 44.2 44.2 03:45 04:15 for LD liner setting tools 11/10/2015 11/10/2015 0.50 COMPZI 'CASING PULD P Lay down BHA#9 44.2 0.0 04:15 04:45 11/10/2015 11/10/2015 5.00 COMPZ1 CASING PUTB P PJSM, M/U L1 upper liner segment, 0.0 2,015.0 04:45 09:45 Ported bull nose, 10'pup,63 Jts 2 3/8" slotted liner,and liner top billet. 11/10/2015 11/10/2015 1.00 COMPZ1 CASING SVRG P Service injector and reel 2,015.0 2,015.0 09:45 10:45 11/10/2015 11/10/2015 0.40 COMPZ1 CASING PULD P M/U coil to coil track and surface test, 2,015.0 2,015.0 10:45 11:09 Tag up and set counters 11/10/2015 11/10/2015 1.20 COMPZ1 CASING RUNL P Trip in well,EDC closed,pumping min 2,015.0 6,615.0 11:09 12:21 rate 11/10/2015 11/10/2015 0.10 COMPZ1 CASING DLOG P Correct to 5500'EOP flag @-.46 6,615.0 6,614.0 12:21 12:27 11/10/2015 11/10/2015 1.10 COMPZ1 CASING RUNL P Continue in well,Clean trip through 6,614.0 8,465.0 12:27 13:33 window,setdown and start working pipe 7645 to 8340 11/10/2015 11/10/2015 0.20 COMPZ1 CASING DLOG P Log K1 for no correction 8,465.0 8,497.0 13:33 13:45 11/10/2015 11/10/2015 0.80 COMPZ1 CASING RUNL P Continue in well,have to start working 8,497.0 9,181.0 13:45 14:33 pipe @ 8534 to 8747 with multiple setdowns.Smoothed out after 8747, Lower EOP flag came in within(foot, Setdown should have been @ 9173.1 11/10/2015 11/10/2015 0.50 COMPZI CASING TRIP P 9181,Pump off liner,PUH and 9,181.0 6,500.0 14:33 15:03 subtract liner length left in hole, 1970.73 11/10/2015 11/10/2015 0.10 COMPZ1 CASING DLOG P Tie into RA for+1 foot, 6,500.0 6,520.0 15:03 15:09 11/10/2015 11/10/2015 1.30 COMPZ1 CASING TRIP P Trip out on 11.8 PPG completion fluid 6,520.0 57.6 15:09 16:27 11/10/2015 11/10/2015 0.60 COMPZ1 CASING OWFF P At surface,perform 30 Min no flow 57.6 57.6 16:27 17:03 check,PJSM.Check coil above connector,break out QC. 11/10/2015 11/10/2015 0.50 COMPZ1 CASING PULD P Lay down L1 upper segment running 57.6 0.0 17:03 17:33 tools,BHA#10. 11/10/2015 11/10/2015 1.45 PROD2 WHDBOP RURD P Skid cart,install nozzle,stab on 0.0 0.0 17:33 19:00 wellhead.Circulate coil to water, flushing stack,unstab,inspect coil. 11/10/2015 11/10/2015 4.00 PROD2 WHDBOP RGRP T PJSM.Change out all twelve BOP 0.0 0.0 19:00 23:00 door seals 11/10/2015 11/11/2015 1.00 PROD2 WHDBOP RURD P PJSM.Grease choke manifold,BOP 0.0 0.0 23:00 00:00 stack,swabs,and tangos. 11/11/2015 11/11/2015 1.50 PROD2 WHDBOP RGRP T During initial shell test found leak at 0.0 0.0 00:00 01:30 Driller's side upper blind/shear door seal,replaced cut seal,retest was good. .75 Hrs downtime to replace BOP door seal 11/11/2015 11/11/2015 13.00 PROD2 WHDBOP BOPE P Perform bi-weekly BOP test,250/ 0.0 0.0 01:30 14:30 4,000 psi,annular 2,500 psi.Test waived by AOGCC(Jeff Jones). Hydraulic actuator leak on upper DS 2"pipe slips 2 Hrs NPT Page 9/15 Report Printed: 12/15/2015 • • Operations Summary (with Timelog Depths) 2E-15 03ir,acc ehiitll ss Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation {MKS)< End Depth MftKS), 11/11/2015 11/11/2015 0.50 PROD2 STK CTOP P BOPE test complete,Displace coil 0.0 0.0 14:30 15:00 back to 11.8PPG fluid,Fill out MM with water 11/11/2015 11/11/2015 1.25 PROD2 STK RGRP T Unable to calibrate new micro motion 0.0 0.0 15:00 16:15 installed during BOPE test,Remove new MM and re install old micro motion, 1.25 Hrs NPT 11/11/2015 11/11/2015 0.90 PROD2 STK CIRC P Continue circulating coil to 11.8 PPG 0.0 0.0 16:15 17:09 completion fluid,install floats in UQC, test. 11/11/2015 11/11/2015 1.70 PROD2 STK PULD P PJSM.PU/MU BHA#11.Shallow hole 0.0 72.5 17:09 18:51 test with 11.8 ppg fluid. 11/11/2015 11/11/2015 1.25 PROD2 STK TRIP P RIH w/drilling assembly,tie-in to K1 72.5 6,550.0 18:51 20:06 for+1.5'correction,continue in hole. 11/11/2015 11/11/2015 1.25 PROD2 STK CIRC P Circulate hole to 9.1 ppg used drilling 6,550.0 7,210.0 20:06 21:21 mud,continue in hole,dry tag billet @ 7,210'. 11/11/2015 11/11/2015 1.90 PROD2 STK KOST P Time mill off billet,2-3 initial stalls, 7,210.0 7,212.0 21:21 23:15 1.40 bpm @ 3,920 psi,CTW=14K, WOB=1K, 1=FPH. 11/11/2015 11/12/2015 0.75 PROD2 DRILL DRLG P Drill ahead L1-01 lateral: 1.40 BPM @ 7,212.0 7,217.0 23:15 00:00 3,880 psi,BHP=3,775 psi,CTW=14K, WOB-.6K,ROP=20. 11/12/2015 11/12/2015 0.90 PROD2 DRILL DRLG P Drill ahead L1-01 lateral: 1.40 BPM @ 7,217.0 7,245.0 00:00 00:54 3,780 psi, BHP=3,825 psi,CTW=14K, WOB-.8K,ROP=35.At 7,230',dry drift billet,billet clean.Start pumping new mud 11/12/2015 11/12/2015 6.30 PROD2 DRILL DRLG P New mud at bit 7,245'.Drill ahead L1- 7,245.0 7,610.0 00:54 07:12 01 lateral: 1.43 BPM @ 3,410 psi, BHP=3,750 psi,CTW=13K,WOB -.2.3K,ROP=4.Ankerite?Broke free @ 7,252' 11/12/2015 11/12/2015 0.70 PROD2 DRILL WPRT P Wiper trip to 7275',PUW=27K 7,610.0 7,610.0 07:12 07:54 11/12/2015 11/12/2015 5.00 PROD2 DRILL DRLG P 7610',Drill, 1.5 BPM @ 3508 PSI FS, 7,610.0 8,010.0 07:54 12:54 BHP=3804 11/12/2015 11/12/2015 1.90 PROD2 DRILL WPRT P 8010 Wiper to window with sweeps 8,010.0 8,010.0 12:54 14:48 and jetting BTP,PUW=27K,Tie into RA for no correction.Smooth trip.No additional cuttings observed 11/12/2015 11/12/2015 4.75 PROD2 DRILL DRLG P 8010',drill 1.5 BPM @ 3620 PSI FS, 8,010.0 8,410.0 14:48 19:33 BHP=3794 11/12/2015 11/12/2015 1.00 PROD2 DRILL WPRT P Wiper to 7,300',PUW=25K,RBIH. 8,410.0 8,410.0 19:33 20:33 11/12/2015 11/13/2015 3.45 PROD2 DRILL DRLG P Drill ahead: 1.50 BPM @ 3,775 PSI, 8,410.0 8,573.0 20:33 00:00 BHP=3,870 PSI,CTW=10.5, WOB=1.3K,ROP=50.BHA wiper @ 8,490'. 11/13/2015 11/13/2015 1.95 PROD2 DRILL DRLG P Drill ahead to TD: 1.50 BPM @ 3,775 8,573.0 8,700.0 00:00 01:57 PSI,BHP=3,890 PSI,CTW=9.5, WOB=1.3K,ROP=65.BHA wiper @ 8,573',PUW=25K.Pumped 10X10 sweeps. 11/13/2015 11/13/2015 2.15 PROD2 DRILL WPRT P Chase sweeps to swab,jet 5.5"BTP, 8,700.0 72.5 01:57 04:06 continue OOH. 11/13/2015 11/13/2015 1.20 PROD2 DRILL TRIP P Tag-up,reset depth,RBIH for 72.5 6,625.0 04:06 05:18 corrected TD. 11/13/2015 11/13/2015 0.10 PROD2 DRILL DLOG P Log K1 for+.5' 6,625.0 6,553.0 05:18 05:24 Page 10/15 Report Printed: 12/15/2015 • , Operations Summary (with Timelog Depths)2E-15 cortocoPhililps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Actively Code Time P-T-X Operation (ftKB) End Depth(ftKB)' 11/13/2015 11/13/2015 1.70 PROD2 DRILL TRIP P Continue in,set down in window,PUH 6,553.0 8,270.0 05:24 07:06 and roll pump,S/D pump and run through window,Clean trip to corrected TD @ 8700. 11/13/2015 11/13/2015 1.80 PROD2 DRILL TRIP P POOH pumping beaded liner pill 8,270.0 87.0 07:06 08:54 followed by 11.8 PPG completion fluid, Paint EOP flags 6600 and 4700' 11/13/2015 11/13/2015 0.50 PROD2 DRILL OWFF P Perform 30 min no flow check,PJSM 87.0 87.0 08:54 09:24 to lay down drilling BHA @ 11 11/13/2015 11/13/2015 0.90 PROD2 DRILL PULD P Lay down BHA#11 87.0 0.0 09:24 10:18 11/13/2015 11/13/2015 0.20 COMPZ2 CASING PULD P PJSM,Rig up floor to run L1-01 liner 0.0 0.0 10:18 10:30 11/13/2015 11/13/2015 3.60 COMPZ2 CASING PUTB P M/U BHA#12,L1-01 liner with non 0.0 1,937.4 10:30 14:06 ported bullnose,61 jts slotted liner, and liner top billet.M/U to coil and surface test 11/13/2015 11/13/2015 1.10 COMPZ2 CASING TRIP P RIH EDC shut 1,937.4 6,638.3 14:06 15:12 11/13/2015 11/13/2015 0.10 COMPZ2 CASING DLOG P Correct to 4700'EOP flag-1', 6,638.3 6,637.0 15:12 15:18 PUW=29K 11/13/2015 11/13/2015 0.80 COMPZ2 CASING TRIP P Continue in hole,Clean trip past 6,637.0 8,691.0 15:18 16:06 window,set down with liner @ 7654, 7992,8640,and 8684.Hard setdown ©8691,Repeat three times.Pump off liner to tie in 11/13/2015 11/13/2015 0.10 COMPZ2 CASING TRIP P Trip up to tie into RA 8,691.0 8,600.0 16:06 16:12 11/13/2015 11/13/2015 0.20 COMPZ2 CASING DLOG P Log RA for+1',Confer with town, 8,600.0 8,625.0 16:12 16:24 BOL=8692,T0L=6799, 11/13/2015 11/13/2015 1.15 COMPZ2 CASING TRIP P Remove liner length left in hole from 6,732.0 62.5 16:24 17:33 counters,POOH on 11.8PPG fluid 11/13/2015 11/13/2015 0.50 COMPZ2 CASING OWFF P At surface,flow check,no flow. 62.5 62.5 17:33 18:03 11/13/2015 11/13/2015 0.75 COMPZ2 CASING PULD P PJSM.LD BHA#12 62.5 0.0 18:03 18:48 11/13/2015 11/13/2015 2.90 COMPZ2 STK CTOP P Inspection of coil found flat above coil 0.0 0.0 18:48 21:42 connector,cut 23'coil,rehead CC and pull test 35K.Rehead UQC,meg test. PT to 4,000 psi. 11/13/2015 11/13/2015 1.00 PROD3 STK PULD P PJSM.MU BHA#13 0.0 72.5 21:42 22:42 11/13/2015 11/14/2015 1.30 PROD3 STK TRIP P RIH w/KO drilling assembly,2.30 72.5 6,525.0 22:42 00:00 AKO motor,RB Hughes bit. 11/14/2015 11/14/2015 0.25 PROD3 STK TRIP P Continue in hole,tie-in K1 for+1.5' 6,525.0 6,700.0 00:00 00:15 correction, RIH to TOW @ 6,700'. 11/14/2015 11/14/2015 1.00 PROD3 STK DISP P Swap hole back to used drilling mud, 6,700.0 6,797.0 00:15 01:15 RIH.Dry billet @ 6,797' 11/14/2015 11/14/2015 1.75 PROD3 STK KOST P Time mill off billet: 1.44 BPM @ 6,797.0 6,799.0 01:15 03:00 3,750',BHP=3,720 PSI,CTW=13K, WOB=.3K 11/14/2015 11/14/2015 1.00 PROD3 DRILL DRLG P Drill ahead L1-02: 1.45 BPM @ 3,725 6,799.0 6,825.0 03:00 04:00 PSI,BHP=3,725 PSI,CTW=13K, WOB=1.7K,ROP=25. 11/14/2015 11/14/2015 0.15 PROD3 DRILL DRLG P PUH,dry drift billet,billet clean. 6,825.0 6,825.0 04:00 04:09 11/14/2015 11/14/2015 2.00 PROD3 DRILL DRLG P Drill ahead: 1.45 BPM @ 3,825 PSI, 6,825.0 6,950.0 04:09 06:09 BHP=3,730 PSI,CTW=12.5K, WOB=1.7K, ROP=80. Page 11/15 Report Printed: 12/15/2015 ; Operations Summary (with Timelog Depths) sss 4'rr. R JR 0,0 M 4 , 2E-15 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 (ft(En End',Depth MKS) 11/14/2015 11/14/2015 1.50 PROD3 DRILL TRIP P 6950 call EOB,Trip out for AKO 6,950.0 75.0 06:09 07:39 change,PUW=27K,Jog BTP on way out Avg DLS 50.7° 11/14/2015 11/14/2015 2.00 PROD3 DRILL PULD P At surface,PJSM PUD BHA#13 75.0 0.0 07:39 09:39 11/14/2015 11/14/2015 0.90 PROD3 DRILL PULD P PJSM,PD BHA#14.5°motor with RR 0.0 72.0 09:39 10:33 Hughes bicenter for 11-02 lateral section,M/U to coil and surface test tool 11/14/2015 11/14/2015 1.20 PROD3 DRILL TRIP P Trip in hole with BHA#14,EDC open 72.0 6,525.0 10:33 11:45 11/14/2015 11/14/2015 0.20 PROD3 DRILL DLOG P Log K1 for+1',PUW=26K,Close EDC 6,525.0 6,546.0 11:45 11:57 11/14/2015 11/14/2015 0.30 PROD3 DRILL TRIP P Clean trip through window and past 6,546.0 6,950.0 11:57 12:15 billet 11/14/2015 11/14/2015 3.20 PROD3 DRILL DRLG P 6950',Drill ahead, 1.50 BPM @ 3699 6,950.0 7,360.0 12:15 15:27 PSI FS,BHP=3720,New mud heading down @ 12:45,New mud all around @ 7075', 13:26 11/14/2015 11/14/2015 0.60 PROD3 DRILL WPRT P 7360'Wiper to 6750',PUW=26K, 7,360.0 7,360.0 15:27 16:03 Clean trip up and down 11/14/2015 11/14/2015 5.50 PROD3 DRILL DRLG P 7360',Drill, 1.55 BPM @ 3630 PSI 7,360.0 7,690.0 16:03 21:33 FS,BHP=3725,WHP=101 11/14/2015 11/14/2015 1.85 PROD3 DRILL WPRT P Wiper to TT,PUW=28K,jet 5.5"BTP, 7,690.0 7,690.0 21:33 23:24 tie-in to RA for+.5'correction,RBIH. 11/14/2015 11/15/2015 0.60 PROD3 DRILL DRLG T Drill ahead: 1.50 BPM @ 3,720 PSI, 7,690.0 7,717.0 23:24 00:00 BHP=3,775 PSI,CTW=12K, WOB=1.2K,ROP=45.Crossed fault, off target,drilling of data, 11/15/2015 11/15/2015 5.00 PROD3 DRILL DRLG T Drill ahead: 1.50 BPM @ 3,735 PSI, 7,717.0 7,970.0 00:00 05:00 BHP=3,798 PSI,CTW=10.5K,WOB= 2K,ROP=45.Off target,drilling for data. 11/15/2015 11/15/2015 2.30 PROD3 DRILL TRIP T TD Lateral, POOH for Billet,Jet BTP 7,970.0 72.0 05:00 07:18 6700-6618,Open EDC in 3 1/2 11/15/2015 11/15/2015 1.50 PROD3 DRILL PULD T At surface,PJSM,PUD BHA#14 L1- 72.0 0.0 07:18 08:48 02 lateral BHA 11/15/2015 11/15/2015 1.80 PROD3 STK PULD T M/U BHA#15 Anchored open hole 0.0 72.8 08:48 10:36 billet and deploy.M/U to coil,strip on and surface test. 11/15/2015 11/15/2015 1.60 PROD3 STK TRIP T RIH with BHA#15 Anchor Billet,EDC 72.8 6,525.0 10:36 12:12 open 11/15/2015 11/15/2015 0.10 PROD3 STK DLOG T Log K1 for+1' 6,525.0 6,551.0 12:12 12:18 11/15/2015 11/15/2015 0.60 PROD3 STK WPST T Continue in well,close EDC @ 6695, 6,551.0 7,261.8 12:18 12:54 PUW=25K,clean pass through window down to set depth @ 7261.75',Orient to HS,Pumps on see tool shift @ 4200PSI,DHWOB=6K, TOB=7250 11/15/2015 11/15/2015 1.30 PROD3 STK TRIP T Trip out of hole 7,261.8 79.0 12:54 14:12 11/15/2015 11/15/2015 1.80 PROD3 STK PULD T At surface,PJSM,PUD BHA#15 79.0 0.0 14:12 16:00 Anchor running tools.Lay down BOT tools and MWD tools Page 12/15 Report Printed: 12/15/2015 Operations Summary (with Timelog Depths) 4.1 kl4r 2E-15 PhiEr Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr)', Phase Op Code Activity Code Time P-T-X Operation (ftKB)I End Depth MKS) 11/15/2015 11/15/2015 6.75 PROD3 WHDBOP RGRP T Swap out BOPE Shear seal rubbers. 0.0 0.0 16:00 22:45 Updated parts arrived this morning. NAD NPT.Took several attempts to get upper blind ram(high test). Replaced rubber seals twice.LD test equipment. Note:2.75 HRS Non-Billable. 11/15/2015 11/16/2015 1.25 PROD3 STK PULD T PJSM. PU/MU/PD BHA#16 0.0 72.5 22:45 00:00 11/16/2015 11/16/2015 0.35 PROD3 STK PULD T Finish PD BHA#16 72.5 72.5 00:00 00:21 11/16/2015 11/16/2015 2.15 PROD3 STK TRIP T RIH w/drilling assembly,tie-in for+2' 72.5 7,250.3 00:21 02:30 correction,continue in hole,dry tag billet @ 7,250'. 11/16/2015 11/16/2015 1.60 PROD3 STK KOST T Time mill off billet: 1.50 BPM @ 3,480 0.0 7,252.5 02:30 04:06 PSI,BHP=3,740 PSI,CTW=15K, WOB=.4K.Off billet. 11/16/2015 11/16/2015 2.80 PROD3 DRILL DRLG T Drill ahead: 1.50 BPM @ 3,540 PSI, 7,252.5 7,553.0 04:06 06:54 BHP=3,760 PSI,CTW=11.5K, WOB=1.5K,ROP=100.PUH @ 7,275',dry drift clean,continue drilling. 11/16/2015 11/16/2015 0.10 PROD3 DRILL WPRT T 7553,Pull BHA wiper,PUW=26K, 7,553.0 7,553.0 06:54 07:00 ROP down to less then 10FPH from 110FPH 11/16/2015 11/16/2015 8.80 PROD3 DRILL DRLG T 7553 Drill, 1.55 BPM @ 3430 PSI FS, 7,553.0 7,640.0 07:00 15:48 BHP=3760,Low ROP less then 10 FPH,Surface weight=11 K, DHWOB=25K,Broke out @7594 @ 15:10, ROP=90FPH 11/16/2015 11/16/2015 1.00 PROD3 DRILL WPRT T 7640,Wiper to 6830',PUW=26K 7,640.0 7,640.0 15:48 16:48 11/16/2015 11/16/2015 0.50 PROD3 DRILL DRLG T 7640',Drill, 1.55 BPM @ 3430 PSI 7,640.0 7,690.0 16:48 17:18 FS,BHP=3790,Clean wiper up and down 11/16/2015 11/17/2015 6.70 PROD3 DRILL DRLG P 7690',off trouble time, Drilling ahead, 7,690.0 7,817.0 17:18 00:00 1.6 BPM @ 3790 PSI FS.Found ankerite again @ 7,785',ROP=5. 11/17/2015 11/17/2015 2.70 PROD3 DRILL DRLG P Continue drilling L1-02 lateral: 1,59 7,817.0 7,980.0 00:00 02:42 BPM @ 3,840 PSI,BHP=3,810 PSI, CTW=9K,WOB=2.7K, ROP=5.Broke free from ankerite @ 7,820', ROP=100.Pumped 10 X 10 to/hi vis sweeps. 11/17/2015 11/17/2015 2.30 PROD3 DRILL WPRT P Chase sweeps to swab,jet 5.5"BTP, 7,980.0 72.5 02:42 05:00 continue OOH. 11/17/2015 11/17/2015 1.30 PROD3 DRILL TRIP P Tag-up,reset depth.RBIH for 72.5 6,525.0 05:00 06:18 corrected TD. 11/17/2015 11/17/2015 0.20 PROD3 DRILL DLOG P Log K1 for+1.5',PUW=24K 6,525.0 6,549.0 06:18 06:30 11/17/2015 11/17/2015 0.80 PROD3 DRILL TRIP P Continue in well,Clean pass through 6,549.0 7,980.0 06:30 07:18 window,Tag up @ 7980 corrected TD. 11/17/2015 11/17/2015 0.20 PROD3 DRILL CIRC P PUH circulating 11.8 beaded liner 7,980.0 7,980.0 07:18 07:30 running pill to bit 11/17/2015 11/17/2015 1.50 PROD3 DRILL TRIP P Trip out of hole pumping 11.8PPG 7,980.0 72.5 07:30 09:00 beaded liner running pill followed with 11.8 PPG completion fluid.Paint EOP flags @ 6900',and 5700' Page 13/15 Report Printed: 12/15/2015 4 Operations Summary (with Timelog Depths) 4.04:4,t- � �., : r F 2E-15 c occsPhillip 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 MKS) End Depth(ftKS), 11/17/2015 11/17/2015 0.55 PROD3 DRILL OWFF P Monitor well for flow,PJSM-LD BHA 72.5 72.5 09:00 09:33 11/17/2015 11/17/2015 0.80 PROD3 DRILL PULD P LD BHA#16, Bit condition 3-4-BT-T-X 72.5 0.0 09:33 10:21 -I-NO-TD 11/17/2015 11/17/2015 1.10 COMPZ3 CASING PUTB P Prep floor for liner run,PJSM. 0.0 0.0 10:21 11:27 11/17/2015 11/17/2015 1.30 COMPZ3 CASING PUTB P MU bullnose,pup joint,30 joints 2 3/8" 0.0 935.2 11:27 12:45 slotted,liner top billet. 11/17/2015 11/17/2015 0.80 COMPZ3 CASING PULD P PJSM-MU L1-02 liner assembly to 935.2 979.5 12:45 13:33 BHA#17,MU to CoilTrak,surface test. 11/17/2015 11/17/2015 2.00 COMPZ3 CASING RUNL P RIH with L1-02 liner assembly,.26 ft 979.5 7,980.0 13:33 15:33 correction at flag,PUW 27k, RBIH,tag up at 7,980 ft,PUW 31k,stack 4k, release off liner at 1.4 bpm,PUW 26k. 11/17/2015 11/17/2015 1.50 COMPZ3 CASING TRIP P POOH for drilling assembly. 7,980.0 44.2 15:33 17:03 11/17/2015 11/17/2015 0.50 COMPZ3 CASING OWFF P Monitor well for flow, PJSM-LD BHA 44.2 44.2 17:03 17:33 11/17/2015 11/17/2015 0.50 COMPZ3 CASING PULD P LD BHA#16 44.2 0.0 17:33 18:03 11/17/2015 11/17/2015 1.15 PROD4 STK BOPE P PJSM.Function test BOP 0.0 0.0 18:03 19:12 11/17/2015 11/17/2015 1.60 PROD4 STK PULD P PJSM. PU/MU BHA#18,check UQC 0.0 72.5 19:12 20:48 and pack-offs. 11/17/2015 11/17/2015 1.70 PROD4 STK TRIP P RIH w/KO drilling assembly: 1.0 AKO 72.5 7,045.0 20:48 22:30 motor,RR HYC bit,tie-in to K1 for+2' correction,continue in hole,dry tag billet @ 7,045'. 11/17/2015 11/17/2015 0.95 PROD4 STK CIRC P Circulate hole back to used mud 7,045.0 7,045.0 22:30 23:27 system. 11/17/2015 11/18/2015 0.55 PROD4 STK KOST P Time mill off billet: 1.49 BPM @ 3,665 7,045.0 7,045.5 23:27 00:00 PSI,CTW=14K,WOB=.2K, 1.5 FPH. Some stacking. 11/18/2015 11/18/2015 0.90 PROD4 STK KOST P Continue time milling off billet: 1.49 7,045.5 7,047.0 00:00 00:54 BPM @ 3,650 PSI,CTW=13K, WOB=.3K.Off billet,loosing WOB. 11/18/2015 11/18/2015 5.20 PROD4 DRILL DRLG P Drill ahead: 1.60 BPM @ 3,930 PSI, 7,047.0 7,360.0 00:54 06:06 BHP=3,745 PSI,CTW=12K, WOB=1.5,ROP=75.PUH @ 7,072', dry drift billet,clean.Continue in drilling.Start pumping new mud system,out bit at 7,134' 11/18/2015 11/18/2015 0.40 PROD4 DRILL WPRT P Wiper up hole,PUW 27.5k 7,360.0 6,830.0 06:06 06:30 11/18/2015 11/18/2015 0.30 PROD4 DRILL WPRT P Wiper in hole,RIW 12.8k 6,830.0 7,360.0 06:30 06:48 11/18/2015 11/18/2015 3.05 PROD4 DRILL DRLG P 7,360 ft, OBD 1.6 bpm at 4,020 psi, 7,360.0 7,675.0 06:48 09:51 BHP 3,751 psi,CWT 10k,WOB 1.7k, ROP 130 11/18/2015 11/18/2015 1.05 PROD4 DRILL WPRT P Wiper up hole,PUW 27k,jet/jog BTP, 7,675.0 6,710.0 09:51 10:54 RBIH 11/18/2015 11/18/2015 0.20 PROD4 DRILL DLOG P Tie in at RA for plus.5 ft correction. 6,710.0 6,760.0 10:54 11:06 11/18/2015 11/18/2015 0.40 PROD4 DRILL WPRT P Wiper in hole,RIW 13.8k 6,760.0 7,675.0 11:06 11:30 Page 14/15 Report Printed: 12/15/2015 • • Operations Summary (with Timelog Depths) 2E-15 C«acoPt Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(RKE)i 11/18/2015 11/18/2015 3.90 PROD4 DRILL DRLG P 7,675 ft, OBD 1.6 bpm at 4,053 psi, 7,675.0 7,945.0 11:30 15:24 BHP 3,765 psi,CWT 11.3k,WOB 1.5k,ROP 100,TD called at 7,945 ft, pump 10 x10 sweep 11/18/2015 11/18/2015 2.25 PROD4 DRILL WPRT P Chase sweeps to swab,jet/jog 5.5" 7,945.0 72.2 15:24 17:39 BTP,continue OOH. 11/18/2015 11/18/2015 2.65 PROD4 DRILL TRIP P Tag up,reset depth.RBIH,tie-in for 72.2 7,872.0 17:39 20:18 +1.5'correction,continue in hole. 11/18/2015 11/18/2015 1.60 PROD4 DRILL DISP P POOH laying in beaded liner pill/ 7,872.0 72.0 20:18 21:54 completion fluid.Paint EOP flags @ 6,600'&5,400',continue OOH. 11/18/2015 11/18/2015 0.50 PROD4 DRILL OWFF P Flow check,no flow. 72.0 72.0 21:54 22:24 11/18/2015 11/18/2015 0.55 PROD4 DRILL PULD P PJSM. LD BHA#18 72.0 0.0 22:24 22:57 11/18/2015 11/19/2015 1.05 COMPZ4 CASING PUTB P PJSM.MU L1-03 liner assembly:bull 0.0 0.0 22:57 00:00 nose,3 solid pups,37 jts slotted liner, in progress. 11/19/2015 11/19/2015 1.65 COMPZ4 CASING PUTB P Finish MU of L1-03 liner assembly. 0.0 1,208.0 00:00 01:39 MU BHA#19. 11/19/2015 11/19/2015 2.05 COMPZ4 CASING RUNL P RIH w/L1-03 liner assembly,tie-in to 1,208.0 7,872.0 01:39 03:42 EOP flag for+.9'correction,continue on hole to set depth @ 7,872', PUW=31 K,pump ups,release from liner @ 3,950 psi.PUW=26K. 11/19/2015 11/19/2015 1.10 DEMOB CASING DISP P PUH,start pumping seawater, 7,872.0 6,692.0 03:42 04:48 circulate out completion fluid. 11/19/2015 11/19/2015 0.60 DEMOB WHDBOP FRZP P POOH to FP from 2,500'with diesel. 6,692.0 2,550.0 04:48 05:24 11/19/2015 11/19/2015 1.00 DEMOB WHDBOP FRZP T LRS on there way,called out at 02:00 2,550.0 2,550.0 05:24 06:24 11/19/2015 11/19/2015 1.95 DEMOB WELLPR FRZP P LRS on loctaion,rig orientation for 2,550.0 2,550.0 06:24 08:21 new hands,PJSM,RU LRS,P/T lines and equipment,pump 30 bbls diesel down coil,RDMO LRS. 11/19/2015 11/19/2015 0.70 DEMOB WELLPR FRZP P Freeze protect from 2,500 ft. 2,550.0 45.0 08:21 09:03 11/19/2015 11/19/2015 1.45 DEMOB WELLPR PULD P PJSM-Pressure un-deploy,LD BHA 45.0 0.0 09:03 10:30 #19, 11/19/2015 11/19/2015 2.00 DEMOB WELLPR MPSP P PJSM-RU FMC equipment,P/T lines 0.0 0.0 10:30 12:30 and equipment 1500 psi,lubricate in BPV,off load FMC equipment.Final T/I/O= 967/0/0 psi. 11/19/2015 11/19/2015 1.50 DEMOB WELLPR RURD P flush coil,choke inspection and new 0.0 0.0 12:30 14:00 Micro Motion testing. 11/19/2015 11/19/2015 3.00 DEMOB WELLPR RURD P PJSM,Pump Corrosion Inhibitor,post 0.0 0.0 14:00 17:00 flush and jet BOPE,RD MP line and misc.lines in cellar.Begin rig down checklist. 11/19/2015 11/19/2015 1.00 DEMOB WELLPR NUND P Nipple down stack. 0.0 0.0 17:00 18:00 Note:Found four tree flange bolts loose,took 1.25 HRS to complete check. 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COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska --- LOG DATE November 18,2015 AUTHORIZED BY Patrick Rider EMAIL Patrick.Riderapbakerhughes.com TODAYS DATE December 15,2015 215-141 KRU 2E-15L1 26561 Revision 215-141 KRU 2E-15L1PB1 26562 STATUS Final Replacement: No Details: 215-142 KRU 2E-15L1-01 26563 Requested by: 215-143 KRU 2E-15L1-02 26564 215-143 KRU 2E-150-02PB1 26565 215-144 KRU 2E-15L1-03 26566 COMPANY FIELD FINAL ADDRESS(FEDEX WILL NOT DELIVER TO P.O.Box) LOGS LOGS (digital/image)CD Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OF PKIN I S #OF COPIES #OF COPIES #OF COPIES 4 11, 1 BP North Slope 0 0 0 EOA,PBOC,PRB-20(Office 109) iD&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 0 Attn:Ricky Elgaricio ATO 3-344 1700 G Street Anchorage,AK 99510 3 lExxonMobil,Alaska 0 0 0 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 1 1 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 !Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 1 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 • e--to LOLL) `'- l41/ CN •II W gl `W; szN si I V c CtiL O. 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On U E „ .40 %," a, — 0- E '0. ii = — Z o 2 2- 2 0 5) = c (°) N 4 O ft 0 cl en e • • e •RECEIVED • N0V242 t Letter of Transmittal AOGCC BAKER Date: DATA LOGGED November 23,2015 /z-`/201E HUGHES -- _ M K BENDR 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): 2E-15L1PB1 21 5 4 1 2 6 4 7 0 2E-15L1 21 5 1 4 '1 2 6 4 7 1 2E-15L1-01 2 1 5 1 4 2 2 6 4 7 2 2E-15L1-02PB1 2 1 5 1 4 3 2 6 4 7 3 2E-15L1-02 21 51 4 3 2 6 4 7 4 2E-15L1-03 2 1 5 1 4 4 2 6 4 7 5 (6) 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 -.4. • • e-- U? "4 e-n LO CNI CN IP . 311 z ikago isw2 ccz NI Csl •i,„--, -12 I • (4) :ler -Nzt4 i C 4 ' t}grit --.7) -,," ,0••••,, 0 ONE,,. Cf) 03 ow < LLI I:e H >, . z 0 A nom Om OM= (f) 1111111111 • *MN a) m ..... -,, I •_ A a. 73 co r.3) cp in .. 03 = > 41) 1:1- (.0 cm 1 .. > ._ uj 0 1.W CI) W N 2 c`l _ •. 2 0 . (7, 1(3C E Li ‘ii0') (66 co in csi ....e .— w g 0 0- CL ' 9 = = ulj CO a) co i ±- cri 0 Y N in CV I • 0 t • • ,._ 1 co g #. )_ ipiil � ( N � i�( ,r) h E 22 2,224222 1 aOvo y��'��I '` Y�b'bI � N•:::-... 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U) 'S �S 0 to OF TMJ S 1 yw\%j II/7 , THE STATE Alaska Oil and Gas �w "!''��►`-�a O 1 T 6 Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 114F \W Main: 907.279.1433 ALAS 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 2E-15L1-03 ConocoPhillips Alaska, Inc. Permit No: 215-144 Surface Location: 905' FSL, 160' FWL, Sec. 36, Ti 1N,R9E, UM Bottomhole Location: 2366' FSL, 1397' FEL, Sec. 35, Ti 1N, 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. 184-189, API No. 50-029- 21206-00-00. 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. F erster Chair DATED this / day of September, 2015. • W D STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 1 1 2015 PERMIT TO DRILL 20 AAC 25.005 GCC 1 a.Type of Work: lb.Proposed Well Class: Development-Oil O' Service-Winj ❑ Single Zone O ' 1 c.Specify if well is proposed for: Drill ❑ 'Lateral 0 Stratigraphic Test❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: O Blanket ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. " Bond No. 59-52-180 i KRU 2E-15L1-03 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD:7980', TVD: 5971' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:905'FSL, 160'FWL,Sec.36,T11N, R9E, UM - ADL 25658 • Kuparuk River Oil Pool Top of Productive Horizon: 8 Land Use Permit: 13.Approximate Spud Date: 1277'FSL, 1483'FEL,Sec.35,T11N, R9E, UM 2584 11/1/2015 Total Depth: 9.Acres in Property: 14.Distance to 2366'FSL, 1397'FEL,Sec.35,T11N, R9E, UM 2560 ' Nearest Property: 10085 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: , 142 feet 15.Distance to Nearest Well Open Surface:x- 529971 y- 5944547 Zone- 4 - GL Elevation above MSL: ` 38 feet to Same Pool: 2E-16,1645' 16.Deviated wells: Kickoff depth: • 7050 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: '105° deg Downhole:4065 psig • Surface:3496 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 1277' 6703' 5974' 7980' 5971' 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) 7035 6354 none 6926 6275 none Casing Length Size Cement Volume MD TVD Conductor/Structural 77' 16" 1975#Poleset 115' 115' Surface 2570' 10.75" 950 sx PF E,400 sx CI G 2607' 2607' Production 6975' 7" 225 sx CI G,250 sx PF C 7009' 6335' Perforation Depth MD(ft): Perforation Depth TVD(ft): 6713-6735,6762-6794 6124-6139,6159-6182 20.Attachments: Property Plat❑ BOP Sketcr❑ Drilling Program ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketcr❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 MC 25.050 requirements ❑ 21.Verbal Approval: Commission Representative: Date: -b-G 22. I hereby certify that the foregoing is true and correct. Contact J. Gary Eller @ 263-4172 � Email J.Gary.Elleracop.com Printed Name D. V-• •aus Title CTD Engineering Supervisor Signature °( 2 . Phone:263-4372 Date ,F—/O /5 Commission Use Only Permit to Drill API Number: Permit ApprovalSee cover letter Number: p215'" 149 50- 0 2,9- 2.04 -c° -UC) Date: l( l t 5 for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m{thane,gas hydrates,or gas contained in shales: d Other:Bap 7rsf to 4 000 5, $Qr9plles t q'd: Yes No Irl( Mud log req'd: Yes❑ No d fr-h�-t via r p rt✓fv5ftr trSi��2 -12/mg-asures: Yes No ❑ Directional svy req'd: Yes No❑ Spacing exception req'd: Yes ❑ No L Inclination-only svy req'd: Yes❑ No d (/� APPROVED BY THE • _ d Approve Form 10-401 R vise/201�T iT�OMa 901- Is 4-1-14---COMMISSIONER th from the dateCOMMISSION of approval(20 AAC 25.005(g)) DTI's��1.� � .-Z 1/TL- 6/7.8/I -.----- 4pf 174i • • R _E ConocoPhillips AUG 11 2015 Alaska P.O. BOX 100360 /►®(SCC ANCHORAGE,ALASKA 99510-0360 /'� esu June 30, 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 a quad-lateral out of the KRU 2E-15 (184-189) using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin late November 2015. The CTD objective will be to drill four laterals (2E-15L1, 2E-15L1-01, 2E-15L1-02, &2E-15L1-03), targeting the Kuparuk A-sand intervals. Note the current A sand perforations will be open below the whipstock. Attached to this application are the following documents: — Permit to Drill Application Forms (10-401)for 2E-15L1, 2E-15L1-01, 2E-15L1-02, &2E-15L1-03 — Detailed Summary of Operations — Directional Plans for 2E-15L1, 2E-15L1-01, 2E-15L1-02, &2E-15L1-03 — Current wellbore schematic — Proposed wellbore schematic If you have any questions or require additional information please contact me at 907-263-4172. incerely, Gary Eller Coiled Tubin rifling Engineer , . • • Kuparuk CTD Laterals NABOB^5KA s A �� 2E-15L1, 2E-15L1-01, 2E-15L1-02, 2E-15L1-03 'IJ9 Cauca P6llips Application for Permit to Drill Document 24AC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.0050 and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 MC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Pressure Deployment of BHA 6 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Attachments 7 Attachment 1: Directional Plans for 2E-15L1, L1-01, L1-02,and L1-03 7 Attachment 2: Current Well Schematic for 2E-15 7 Attachment 3: Proposed Well Schematic for 2E-15L1, L1-01, L1-02,and L1-03 7 Page 1 of 7 June 30,2015 • • PTD Application: 2E-15L1, L1-01, L1-02, & L1-03 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 2E-15L1, 2E-15L1-01, 2E-15L1-02, &2E-15L1-03. All laterals will be classified as"Development—Oil"wells. 2. Location Summary (Requirements of 20 AA C 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 2E-15L1, 2E-15L1-01, 2E-15L1-02, and 2E-15L1-03. 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 4000 psi. Using the maximum formation pressure in the area of 4065 psi in 2E-14 (i.e. 12.9 ppg EMW), the maximum potential surface pressure in 2E-15, assuming a gas gradient of 0.1 psi/ft, would be 3496 psi.+7See the"Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AA C 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 2E-15 was measured to be 2319 psi (7.2 ppg EMW)on 6/9/2015 following a workover. The maximum downhole pressure in the 2E-15 vicinity is to the northwest in the 2E-14 injector at 4065 psi (12.9 ppg EMW)from June 2013, but due to distance and faulting the maximum formation we expect to encounter is only 10.4 ppg. The southern L1 and L1-01 laterals will cross a major E-W fault that could encounter formation pressure as high as 10.4 ppg, which is what was measured when 2E-04 was drilled in early 2014. The northern L1-02 and L1-03 laterals will be drilled toward 2E-16, which was last measured at 10.2 ppg EMW in June 2015. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) None of the offset injection wells to 2E-15 have ever injected gas, so there is a low probability of encountering free gas while drilling the 2E-15 laterals. There has been some historic gas injection in wells 2D-11 and 2D-14 to the north, but it is not expected that these have communicated to 2E-15. Nevertheless, if significant gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The major expected risk of hole problems in the 2E-15 laterals will be lost circulation due to low formation pressure near the 2E-15 mother bore and shale instability across faults. Well 2E-15 has been shut in for several months now which has already helped to elevate the pressure, and it is hoped that 2E-10 will be converted to water injection in the near future to supplement that rate of pressure build. Managed pressure drilling (MPD)will be used to reduce the risk of shale instability associated with fault crossing. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 2E-15 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 June 30, 2015 • • PTD Application: 2E-15L1, L1-01, L1-02, & L1-03 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS 2%", 4.7#, L-80, ST-L slotted liner; 2E-15L1 7200' 10,200' 6041' 6024' aluminum billet on top 2%'', 4.7#, L-80, ST-L slotted liner; 2E-15L1-01 6808' 9120' 6029' 6012' aluminum billet on top 2%", 4.7#, L-80, ST-L slotted liner; 2E-15L1-02 7050' 7970' 6038' 6006' aluminum billet on top 2%", 4.7#, L-80, ST-L slotted liner; 2E-15L1-03 6703' 7980' 5974' 5971' deployment sleeve on top Existing Casing/Liner Information Weight Grade Connection Top Btm Top Btm Burst Collapse Category OD (ppf) MD MD TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 0' 115' 0' 115' 1,640 630 Surface 10-3/4" 45.5 K-55 BTC 0' 2607' 0' 2607' 3,580 2,090 Production 7" 26.0 J-55 BTC 0' 7009' 0' 6335' 4,980 4330 Tubing 3-1/2" 9.3 L-80 EUE 0' 5980' 0' 6,524' 10,160 10,530 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) 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 A diagram of the Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based FloVis mud (9.0 ppg) — Drilling operations: Chloride-based FloVis mud (9.0 ppg)./ While this mud weight may hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 11.4 ppg NaBr completion fluid in order to provide formation over-balance and well bore stability while running completions. 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". In the 2E-15 laterals we will target a constant BHP of 11.4 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 June 30, 2015 • • PTD Application: 2E-15L1, L1-01, L1-02, & L1-03 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 2E-15 Window(6713' MD, 6124' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (7.2 ppg) 2293 psi 2293 psi Mud Hydrostatic(9.0 ppg) 2866 psi 2866 psi Annular friction (i.e. ECD, 0.080 psi/ft) 537 psi 0 psi Mud + ECD Combined 3403 psi 2866 psi (no choke pressure) (overbalanced (overbalanced 1110 psi) —570 psi) Target BHP at Window(11.4 ppg) 3630 psi 3630 psi Choke Pressure Required to Maintain 227 psi 764 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AA C 25.005(c)(11)) N/A-Application is for a 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. 13. Proposed Drilling Program (Requirements of 20 AA C 25.005(c)(13)) Summary of Operations Background Well 2E-15 is a Kuparuk A-sand production well equipped with 3'/2"tubing and 7"production casing. A rig work-over was recently performed, replacing the existing tubing and packers with new 3'/2"tubing with a 51/2""Big Tail Pipe" completion. Four laterals will be drilled to the south and north of the parent well with the laterals targeting the A4 and A5 sands. A thru-tubing whip-stock has already been set inside the 51/2"tail pipe at the planned kick off point of 6713' MD. The 2E-15L1 southern lateral will exit through the 51/2"tailpipe and 7"casing at 6713'MD and TD at 10,200' MD,targeting the A4 sand. It will be completed with 2%"slotted liner from TD up to 7200' MD with an aluminum billet for kicking off the 2E-15L1-01 lateral. The 2E-15L1-01 will drill south to a TD of 9120' MD targeting the A5 sand. It will be completed with 2%" slotted liner from TD up to 6808' MD with an aluminum billet for kicking off the 2E-15L1-02 lateral. Pana d of 7 June 30, 2015 • • PTD Application: 2E-15L1, L1-01, L1-02, & L1-03 The 2E-15L1-02 will turn north and drill to a TD of 7970' MD targeting the A4 sand. It will be completed with 2%" slotted liner from TD up to 7050' MD with an aluminum billet for kicking off the 2E-15L1-03 lateral. The 2E-15L1-03 will drill north to a TD of 7980' MD targeting the A5 sand. It will be completed with 2%" slotted liner from TD up to 7200'MD with the liner top inside the 7"casing at—6708' MD.. Pre-CTD Work 1. RU Slickline:Dummy all gas lift valves and obtain an A-sand SBHP. 2. RU E-line: Set Baker Hughes 31/2"x 51/2"thru-tubing whipstock at 6713' MD 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. 2E-15L1 Lateral(A4 sand south) a. Mill 2.80"window at 6713' MD. b. Drill 3"bi-center lateral to TD of 10,200' MD. c. Run 2%"slotted liner with an aluminum billet from TD up to 7200' MD. 3. 2E-15L1-01 Lateral(A5 sand south) a. Kick off of the aluminum billet at 7200' MD. b. Drill 3"bi-center lateral to TD of 9120' MD. c. Run 2%" slotted liner from TD up to 6808' MD 4. 2E-15L1-02 Lateral(A4 sand north) a. Kick off of the aluminum billet at 6808' MD. b. Drill 3"bi-center lateral to TD of 7970' MD. c. Run 2%" slotted liner from TD up to 7050' MD 5. 2E-15L1-03 Lateral(A5 sand north) a. Kick off of the aluminum billet at 7050' MD. b. Drill 3"bi-center lateral to TD of 7980' MD. c. Run 2%" slotted liner from TD up to 6708' MD, inside the 7"casing 6. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV. 2. Install GLV's and return to production. June 30, 2015 • • PTD Application: 2E-15L1, 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 down hole 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 Runningrior to running liner. See — The 2E-15 laterals will be displaced to an overbalancing fluid (11.4 ppg Naar) p "Drilling Fluids" section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(C)(14)) ® No annular injection on this well. ® All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. ® Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. he y documented and manifested. ® All wastesand waste Envirs hauled from onmental Coordinator tpad must be for quest ons l regarding waste classification. (670-4200). ® Contact Kuparukk June 30, 2015 • • PTD Application: 2E-15L1, L1-01, L1-02, & L1-03 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plan - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire openhole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 2E-15L1 7079' 2E-15L1-01 8115' 2E-15L1-02 9935' 2E-15L1-03 10,085' - Distance to Nearest Well within Pool Lateral Name Distance Well 2E-15L1 -2000' 2E-04 2E-15L1-01 -2660' 2E-09 2E-15L1-02 1650' 2E-16 2E-15L1-03 1645' 2E-16 16. Attachments Attachment 1: Directional Plans for 2E-15L1, L1-01, L1-02, and L1-03 Attachment 2: Current Well Schematic for 2E-15 Attachment 3: Proposed Well Schematic for 2E-15L1, L1-01, L1-02, and L1-03 . , ! • Q Q Q o: o oQ J=' a,a O Q o Q (yO-- I u m N- rn� o0 LI-I _ Zo o Q UN CNIN. 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(0 (h O O 00 Q co co N r- N N g CO 8U U (Op I` (6 (O 4) C C CO Y N CO O (O L u1 • S ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2E Pad 2E-15 2E-15L1-03 Plan: 2E-15L1-03 wp02 Standard Planning Report 05 June, 2015 Fagg BAKER HUGHES • Nil 0 ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2E-15 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2E-15 @ 142.00usft(2E-15) Site: Kuparuk 2E Pad North Reference: True Well:? 2E-15 Survey Calculation Method: Minimum Curvature Wellbore: 2E-15L1-03 Design: 2E-15 L 1-0 3_w p 02 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 2E Pad Site Position: Northing: 5,944,247.48 usft Latitude: 70°15'31.481 N From: Map Easting: 529,971.75 usft Longitude: 149°45'27.897 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.23 ° Well 2E-15 Well Position +N/-S 0.00 usft Northing: 5,944,547.40 usft Latitude: 70°15'34.431 N +E/-W 0.00 usft Easting: 529,970.59 usft Longitude: 149°45'27.896 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 2E-15L1-03 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 9/1/2015 18.83 80.93 57,499 Design 2E-15L1-03_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,050.00 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction ,,,,,-,,,,,,,,,,,,0' ' (usft) (usft) (usft) (°) 0.00 0.00 0.00 0.00 Plan Sections Measured TVD Below ` Dogleg Build Turn Depth Inclination Azimuth System +Nl-S +EI-W Rate Rate Rate TFO ,o ,l�I'l _ 3 (usft) (°) (°) (usft) (usft) (usft) (°/100ft) (°/100ft) (1100ft) (0) Target 7,050.00 93.37 7.12 6,038.01 584.80 -1,822.27 0.00 0.00 0.00 0.00 7,210.00 104.57 7.12 6,013.11 741.38 -1,802.71 7.00 7.00 0.00 0.00 7,330.00 96.29 8.58 5,991.41 858.19 -1,786.58 7.00 -6.90 1.22 170.00 7,510.00 92.29 20.57 5,977.91 1,031.54 -1,741.46 7.00 -2.22 6.66 108.00 7,675.00 91.24 32.07 5,972.81 1,179.11 -1,668.46 7.00 -0.63 6.97 95.00 7,900.00 89.84 16.38 5,970.68 1,383.64 -1,576.42 7.00 -0.62 -6.97 265.00 7,980.00 89.84 10.78 5,970.90 1,461.37 -1,557.64 7.00 0.00 -7.00 270.00 6/5/2015 3.50:31PM Page 2 COMPASS 5000.1 Build 61 • •• rsas ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2E-15 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2E-15 @ 142.00usft(2E-15) Site: Kuparuk 2E Pad North Reference: True Well: 2E-15 Survey Calculation Method: Minimum Curvature Wellbore: 2E-15L1-03 Design: 2E-15L1-03_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E1-W Section Rate Azimuth Northing Easting (usft) (0) (0) (usft) (usft) (usft) (usft) (°/100ft) (0) (usft) (usft) 7,050.00 93.37 7.12 6,038.01 584.80 -1,822.27 584.80 0.00 0.00 5,945,124.89 528,146.19 TIP/KOP 7,100.00 96.87 7.12 6,033.55 634.21 -1,816.10 634.21 7.00 0.00 5,945,174.32 528,152.17 7,200.00 103.87 7.12 6,015.57 731.76 -1,803.91 731.76 7.00 0.00 5,945,271.91 528,163.96 7,210.00 104.57 7.12 6,013.11 741.38 -1,802.71 741.38 7.00 0.00 5,945,281.53 528,165.12 Start 7 dls 7,300.00 98.36 8.22 5,995.24 828.75 -1,790.93 828.75 7.00 170.00 5,945,368.94 528,176.55 7,330.00 96.29 8.58 5,991.41 858.19 -1,786.58 858.19 7.00 170.22 5,945,398.39 528,180.78 3 7,400.00 94.76 13.26 5,984.67 926.58 -1,773.39 926.58 7.00 108.00 5,945,466.82 528,193.71 7,500.00 92.51 19.90 5,978.33 1,022.17 -1,744.92 1,022.17 7.00 108.45 5,945,562.51 528,221.79 7,510.00 92.29 20.57 5,977.91 1,031.54 -1,741.46 1,031.54 7.00 108.87 5,945,571.90 528,225.21 4 7,600.00 91.73 26.84 5,974.75 1,113.85 -1,705.32 1,113.85 7.00 95.00 5,945,654.35 528,261.02 7,675.00 91.24 32.07 5,972.81 1,179.11 -1,668.46 1,179.11 7.00 95.22 5,945,719.75 528,297.61 5 7,700.00 91.09 30.33 5,972.30 1,200.49 -1,655.51 1,200.49 7.00 -95.00 5,945,741.17 528,310.48 7,800.00 90.47 23.36 5,970.94 1,289.65 -1,610.39 1,289.65 7.00 -95.04 5,945,830.51 528,355.24 7,900.00 89.84 16.38 5,970.68 1,383.64 -1,576.42 1,383.64 7.00 -95.13 5,945,924.62 528,388.83 6 7,980.00 89.84 10.78 5,970.90 1,461.37 -1,557.64 1,461.37 7.00 -90.00 5,946,002.42 528,407.30 Planned TD at 7980.00 6/5/2015 3:50.31PM Page 3 COMPASS 5000.1 Build 61 r • ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2E-15 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2E-15 @ 142.00usft(2E-15) Site: Kuparuk 2E Pad North Reference: True Well: 2E-15 Survey Calculation Method: Minimum Curvature Wellbore: 2E-15L1-03 Design: 2 E-15L1-03_wp02 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +El-W Northing Easting -Shape (°) (0) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 2E-15L1-03_T02 0.00 0.00 5,987.00 -3,949.751,138,380.38 5,945,128.00 1,668,245.00 70°0'55.815 N 140°38'8.676 W -plan misses target center by 1139950.86usft at 7980.00usft MD(5970.90 TVD,1461.37 N,-1557.64 E) -Point 2E-15 CTD Polygon Sot. 0.00 0.00 0.00 -4,232.421,138,540.27 5,944,846.00 1,668,406.00 70°0,52.836 N 140°38'5.348 W -plan misses target center by 1140127.77usft at 7980.00usft MD(5970.90 TVD,1461.37 N,-1557.64 E) -Polygon Point 1 0.00 0.00 0.00 5,944,846.00 1,668,406.00 Point 2 0.00 14.68 -173.96 5,944,859.99 1,668,232.00 Point3 0.00 -47.88 -285.22 5,944,796.99 1,668,121.00 Point4 0.00 -199.57 -368.82 5,944,644.98 1,668,038.01 Point5 0.00 -540.71 -342.16 5,944,303.99 1,668,066.03 Point6 0.00 -895.14 -243.54 5,943,949.99 1,668,166.05 Point7 0.00 -1,094.48 -161.32 5,943,751.00 1,668,249.05 Point8 0.00 -1,291.71 -109.09 5,943,553.99 1,668,302.06 Point 9 0.00 -1,568.95 -55.17 5,943,277.00 1,668,357.08 Point 10 0.00 -2,035.10 -29.00 5,942,811.00 1,668,385.10 Point 11 0.00 -2,375.11 -37.33 5,942,471.00 1,668,378.13 Point 12 0.00 -2,686.64 -163.57 5,942,159.00 1,668,253.14 Point13 0.00 -2,909.28 -261.46 5,941,935.99 1,668,156.14 Point 14 0.00 -3,297.97 -352.99 5,941,546.98 1,668,066.17 Point 15 0.00 -3,526.90 -374.89 5,941,317.99 1,668,045.18 Point 16 0.00 -3,514.13 -62.81 5,941,332.00 1,668,357.18 Point 17 0.00 -3,271.19 -40.85 5,941,575.00 1,668,378.17 Point 18 0.00 -2,861.70 99.77 5,941,985.00 1,668,517.15 Point 19 0.00 -2,411.45 302.56 5,942,436.01 1,668,718.12 Point20 0.00 -1,779.28 278.04 5,943,068.02 1,668,691.09 Point2l 0.00 -1,404.06 230.51 5,943,443.01 1,668,642.07 Point22 0.00 -1,049.59 120.89 5,943,797.00 1,668,531.05 Point23 0.00 -722.34 66.17 5,944,124.00 1,668,475.04 Point24 0.00 -472.07 5.15 5,944,374.00 1,668,413.03 Point25 0.00 -332.59 -112.32 5,944,513.00 1,668,295.02 Point26 0.00 0.00 0.00 5,944,846.00 1,668,406.00 2E-15 CTD Polygon Nor 0.00 0.00 0.00 -4,225.361,138,526.30 5,944,853.00 1,668,392.00 70°0'52.925 N 140°38'5.715 W -plan misses target center by 1140113.76usft at 7980.00usft MD(5970.90 TVD,1461.37 N,-1557.64 E) -Polygon Point 1 0.00 0.00 0.00 5,944,853.00 1,668,392.00 Point2 0.00 56.34 -84.79 5,944,909.00 1,668,306.99 Point3 0.00 354.05 -3.61 5,945,207.00 1,668,386.98 Point 4 0.00 506.77 72.00 5,945,360.00 1,668,461.98 Point 5 0.00 839.39 177.32 5,945,693.01 1,668,565.96 Point6 0.00 1,062.25 219.20 5,945,916.01 1,668,606.95 Point7 0.00 1,097.21 -23.69 5,945,950.00 1,668,363.95 Point8 0.00 882.43 -86.54 5,945,734.99 1,668,301.96 Point 9 0.00 569.71 -164.78 5,945,421.99 1,668,224.97 Point 10 0.00 410.82 -196.41 5,945,262.99 1,668,193.98 Point 11 0.00 175.03 -258.34 5,945,026.98 1,668,132.99 Point 12 0.00 -88.81 -305.38 5,944,762.98 1,668,087.01 Point 13 0.00 -291.37 -168.16 5,944,560.99 1,668,225.02 Point 14 0.00 -325.68 -91.29 5,944,526.99 1,668,302.02 Point 15 0.00 0.00 0.00 5,944,853.00 1,668,392.00 2E-15L1-03_T05 0.00 0.00 5,971.00 -3,323.481,138,578.90 5,945,755.00 1,668,441.00 70°1'1.605 N 140°38'0.357 W -plan misses target center by 1140146.58usft at 7980.00usft MD(5970.90 TVD,1461.37 N,-1557.64 E) -Point 2E-15L1_Fault2 0.00 0.00 0.00 -4,443.341,138,262.41 5,944,634.00 1,668,129.00 70°0'51.195 N 140°38'14.140 W -.lan misses tar.et center b 1139850.98usft at 7980.O0usft MD 5970.90 TVD 1461.37 N -1557.64 E 6/5/2015 3:50:31PM Page 4 COMPASS 5000.1 Build 61 • • ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2E-15 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2E-15 @ 142.00usft(2E-15) Site: Kuparuk 2E Pad North Reference: True Well: 2E-15 Survey Calculation Method: Minimum Curvature Wellbore: 2E-15L1-03 Design: 2E-15L1-03_wp02 -Rectangle(sides W290.00 H1.00 D0.00) 2E-15L1_Faultl 0.00 0.00 0.00 -4,385.741,138,364.65 5,944,692.00 1,668,231.00 70°0'51.604 N 140°38'10.991 W -plan misses target center by 1139952.92usft at 7980.00usft MD(5970.90 TVD,1461.37 N,-1557.64 E) -Rectangle(sides W500.00 H1.00 D0.00) 2E-15L1-03_T04 0.00 0.00 5,971.00 -3,461.321,138,535.34 5,945,617.00 1,668,398.00 70°1'0.331 N 140°38'2.184 W -plan misses target center by 1140103.61 usft at 7980.00usft MD(5970.90 TVD,1461.37 N,-1557.64 E) -Point 2E-15L1-03_T01 0.00 0.00 6,000.00 -4,069.621,138,343.90 5,945,008.00 1,668,209.00 70°0'54.704 N 140°38'10.226 W -plan misses target center by 1139914.96usft at 7980.00usft MD(5970.90 TVD,1461.37 N,-1557.64 E) -Point 2E-15L1-03_T03 0.00 0.00 5,978.00 -3,781.951,138,434.06 5,945,296.00 1,668,298.00 70°0'57.366 N 140°38'6.434 W -plan misses target center by 1140003.75usft at 7980.00usft MD(5970.90 TVD,1461.37 N,-1557.64 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 7,980.00 5,970.90 2 3/8" 2.375 3.000 Plan Annotations i it Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W 1. (usft) (usft) (usft) (usft) Comment 7,050 00 6,038.01 584.80 -1,822.27 TIP/KOP 7,210.00 6,013.11 741.38 -1,802.71 Start 7 dls 7,330.00 5,991.41 858.19 -1,786.58 3 7,510.00 5,977.91 1,031.54 -1,741.46 4 7,675.00 5,972.81 1,179.11 -1,668.46 5 7,900.00 5,970.68 1,383.64 -1,576.42 6 7,980.00 5,970.90 1,461.37 -1,557.64 Planned TD at 7980.00 6/5/2015 3:50:31PM Page 5 COMPASS 5000.1 Build 61 S ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2E Pad 2E-15 2E-15L1-03 2E-15L1-03_wp02 Travelling Cylinder Report 05 June, 2015 Vaalfl BAKER HUGHES •• Baker Hughes INTEQ ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2E-15 Project: Kuparuk River Unit TVD Reference: 2E-15 @ 142.00usft(2E-15) Reference Site: Kuparuk 2E Pad MD Reference: 2E-15©142.00usft(2E-15) Site Error: 0.00usft North Reference: True Reference Well: 2E-15 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at R 1.00 sigma Reference Wellbore 2E-15L1-03 Database: OAKEDMP2 Reference Design: 2E-15L1-03_wp02 Offset TVD Reference: Offset Datum Reference 2E-15L1-03_wp02 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,050.00 to 7,980.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 983.80usft Error Surface: Elliptical Conic Survey Tool Program Date 6/5/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 200.00 6,700.00 2E-15(2E-15) GCT-MS Schlumberger GCT multishot 6,700.00 6,808.00 2E-15L1_wp04(2E-15L1) MWD MWD-Standard 6,808.00 7,050.00 2E-15L1-02_wp03(2E-15L1-02) MWD MWD-Standard 7,050.00 7,980.00 2E-15L1-03_wp02(2E-15L1-03) MWD MWD-Standard Casing-pointe Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (••)' 7,980.00 6,112.90 2 3/8" 2-3/8 3 Summary' Reference Offset Centre to No-Go Allowable Measured Measured Centre ! Distance Deviation Warning Site Name I Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Kuparuk 2E Pad 2E-01-2E-01-2E-01 Out of range 2E-01-2E-01-2E-01wp05 Out of range 2E-02-2E-02-2E-02 Out of range 2E-03-2E-03-2E-03 Out of range 2E-04-2E-04-2E-04 Out of range 2E-04-2E-04PB1-2E-04PB1 Out of range 2E-05-2E-05-2E-05 Out of range 2E-06-2E-06-2E-06 Out of range 2E-06-2E-06L1-2E-06L1 Out of range 2E-06-2E-06L1-01-2E-06L1-01 Out of range 2E-06-2E-06L1 PB1-2E-06L1 PB1 Out of range 2E-07-2E-07-2E-07 Out of range 2E-08-2E-08-2E-08 Out of range 2E-09-2E-09-2E-09 Out of range 2E-10-2E-10-2E-10 Out of range 2E-11-2E11-2E-11 Out of range 2E-12-2E12-2E-12 Out of range 2E-13-2E-13-2E-13 Out of range 2E-14-2E-14-2E-14 Out of range 2E-15-2E-15-2E-15 Out of range 2E-15-2E-15L1-2E-15L1_wp04 Out of range 2E-15-2E-15L1-01-2E-15L1-01_wp02 Out of range 2E-15-2E-15L1-02-2E-15L1-02_wp03 7,050.00 7,050.00 0.00 0.36 -0.22 FAIL-Minor 1/10 2E-16-2E-16-2E-16 Out of range 2E-17-2E-17-2E-17 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 6/5/2015 11:21:35AM Page 2 of 4 COMPASS 5000.1 Build 65 • Baker Hughes INTEQ • � ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2E-15 Project: Kuparuk River Unit TVD Reference: 2E-15 @ 142.00usft(2E-15) Reference Site: Kuparuk 2E Pad MD Reference: 2E-15 @ 142.00usft(2E-15) Site Error: 0.00usft North Reference: True Reference Well: 2E-15 Survey Calculation Method: Minimum Curvature Welt Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 2E-15L1-03 Database: OAKEDMP2 Reference Design: 2E-15L1-03_wp02 Offset TVD Reference: d Offset Datum Reference Depths are relative to 2E-15©142.00usft(2E-15) Coordinates are relative to.2E-15 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:0.23° Ladder Plot 60— I I I I I I I I I I I I I I I J J I I I I I I I I I I I I I I I I 45 g I J J JCL � I � I i I 0 I I 0 I d) I J J J J a) I I U I I 15— - 0 I I 0 1500 3000 4500 6000 7500 9000 Meast.red Depth LEGEND 2E-15,2E-15L1-02,2E-15L1-02 wp03V0 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 6/5/2015 11:21:35AM Page 4 of 4 COMPASS 5000.1 Build 65 • • 0 111 0 R kW pO C M rq N4�] . 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These materials may be found in the original hard file or check the parent folder to view it in digital format. • S TRANSMITTAL LETTER CHECKLIST WELL NAME: PN(J. c9E- 1-5U-03 PTD: pis- Iyy t/ )evelopment Service Exploratory Stratigraphic Test Non-Conventional FIELD: Kt, K r2i\m4r POOL: i yail+�k /R .,'V , XL y &itJ.K P V&- 0') II / 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. 18M Igct , API No. 50-O a531- oLI 16(o -t70 - Oo ✓ (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 S 0 ❑i ❑ Co , co , , , m 0 Cu fl- 0 N 2 m _o , 0) p' a' c CO g Qc)' 0-_.„ 3. C. o. NCI o; c, c, O Z C, 3, a a`r > r O' yr a 0. a cm. c. c. 0) E O a a' w. m w' a' cmc, ..� 3' — 0 • _ c 3 a co o M °� a 3 o c O a o a ,_0, eN m 0) �I v 0 V' v w' a E. 4 W ' c 0 oa°i, ami o a oo rn N J o wm , -0 V o, , CO , Cl. 0 ,c4 2 _� �, -o f- O. U ai' E a N, a °' jl , > o �, a. r, °c, y 0? a. �, c E c >; •0 "o ' a 3, 0. :. y a0 ,. a' , .0 Y CO m w v v, w a o Y o. 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