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216-007
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Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2538' FNL,4985' FEL, Sec 24, T12N, R8E, UM 3/3/2016 KRU 3G-04AL1 • Top of Productive Interval: 9. Ref Elevations: KB: 90' 17. Field/Pool(s): 2132' FNL,4789' FEL, Sec 25, T12N, R8E, UM GL:54' BF: Kupurak River Field/Kuparuk Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 100' FNL, 998 FEL, Sec 26,T12N, R8E, UM N/A ADL 25548,ADL 25547 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: . 19. Land Use Permit: Surface: x- 498675 y- 5988561 Zone- 4 11003' MD/5894'TVD ' AK 2662 TPI: x- 498873 y- 5983687 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 497383 y- 5985719 Zone- 4 1812' MD/1654'TVD 1732' MD/1574'TVD 5. Directional or Inclination Survey: Yes • ❑✓ (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) 8300' MD/5851'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 RECEIVED APR 0 4 20162 23. CASING, LINER AND CEMENTING RECORD AOGCC WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16" 62.5# H-40 36' 115' 36' 115' 18" ±200 Cu. Ft. 9 5/8" 36# J-55 35' 3795' 35' 3018' 11 5/8" 1685 Cu. Ft.AS III, 570 Cu. Ft. Class G 7" 26# J-55 35' 8062' 35' 6106' 9" 200 Cu. Ft. Class G 2 3/8" 4.6# L-80 7543' 11003' 5714' 5894' 3" Uncemented Slotted Liner 24. Open to production or injection? Yes 0 No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3 1/2" 7557' 7521' MD/5697'TVD SLOTTED LINER MD TVD 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. 7544'- 11003' 5714'-5894' COMPLETION Was hydraulic fracturing used during completion? Yes [1] No 0 - D.AT � � � Per 20 AAC 25.283(i)(2)attach electronic and printed information VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LA-- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 3/16/2016 Gas Lift Date of Test: Hours Tested: 1,`'Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 3/17/2016 1/154E40 Test Period 416 373 2057 176 1050 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 190 1340 24-Hour Rate -4 599 629 3184 27 Form 10-407 Revised 11/2015 1/7L 471 Z`I,, CONTINUED ON PAGE 2 Submit ORIGINIAL only `1�2 f,6 1'114' j/iS7& RBDMS 1,�' APR 0 5 2016 G 28. CORE DATA Conventional ) Yes ❑ No E Sidewall Core es ❑ No ❑✓ If Yes, list formations and intervals cored(MD rom/To),and summarize lithology and presence o ,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. None 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1732' 1594' Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 8300' 5851' information, including reports,per 20 AAC 25.071. A2 8510' 5874' None TD 11003' 5894' Formation at total depth: Kuparuk A2 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematics Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Cody Pohler @ 265-6435 Email: Cody.J.Pohler@cop.com C,.)? Printed Name: J. Ohlinger Title: Staff CTD Engineer Signature: / Phone: 265-6097 Date: y !q/G INSTRUCTIONS / General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs, and all subsequent laboratory analytical results, including,but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to:core analysis,paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only KUP PROD • 3G-04AL1 • ConocoPhillips Ora Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status Ind(1) MD(ftKB) Act Wm(ftKB) - atm i 501032014360 KUPARUK RIVER UNIT PROD 101.03 7,935.50 11,003.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3G-04AL1,3/21/20169:08.24 AM SSSV:TRDP 115 10/16/2014 Last WO: 36.39 11/5/1990 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:ADDDED LATERALS,GLV C/O lehallf 3/18/2016 7, HANGER;308 iJ � i ! Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WBLen(I...Grade Top Thread LinerAL1 Lateral 23/8 1.992 7,5428 11,0030 460 L-80 ST-L Liner Details Nomial ID ,. Top(ftKB) Top(TVD)(ttKB) Top Incl C) Item Des Com (in,, L,IW 7,542.8 5,713.5 41.22 DEPLOY Shorty Deployment Sleeve 1.900 IPerforations&Slots I■1Shot Dens CONDUCTOR;36.0-115.0 A. Top(TVD) Btm(TVD) (shots/t Top(ftKB) Btm(ttKB) (ftKB) (ft68) Zone Date t) Type Com 7,543.0 11,002.0 5,713.7 5,894.3 A-2,3G-04 3/4/2016 SLOTS Notes:General&Safety End Date Annotation SAFETY VLV;1,812.0 r-".. NOTE. GAS LIFT;2,822.1 ii trn SURFACE;35.0-3,7946— GAS LIFT;5,4664 r A; GAS LIFT;7.452.1 ( MR;7,507.9 PACKER;7.521.4 Cli(1.11-i- NIPPLE;7.544.8 ilSOS;7,556.4 APERF;7,640.0.7,660.0 — ._I APERTFIGW10.0-7,734.0 _ PRODUCTION;35.0-8,062.2 SLOTS;7,543.0-11,002.0 i Liner AL1 Lateral;7,542.8- I 11,003.0 pi. KUP PROD • 3G-04 COIIOGOr 111IIIp5 v Well Attributes Max Angle&MD TD A4iSk8 hie s, Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) .-.,r,o,01,.Phiairs10. 501032014300 KUPARUK RIVER UNIT PROD 52.39 2,100.00 8,089.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3G-0432120169.11:31 AM SSSV:TRDP 115 10/16/2014 Last WO: 36.39 11/5/1990 Vertical schematic(actual) 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,838.0 5/27/2015 Rev Reason:SIDETRACKED TO'A',GLV C/O lehallf 3/18/2016 HANGER;30.8-.1/12.1111 I , jl Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread � if SURFACEes9 5/8 8.921 35.0 3,794.6 3,017.6 36.00 J-55 BTC CasingDcriptionOD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread IWeu PRODUCTION 7 6.276 35.0 8,062.2 6,106.4 26.00 J-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection �^TUBING 3 1/2 2.992 30.8 7,557.2 5,724.4 9.30 J-55 EUE8rdABMOD CONDUCTOR',36.0-1150 i Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inel(') Item Des Com (in) 30.8 30.8 0.17 HANGER MCEVOY GEN IV HANGER 3.500 mai SAFETY VLV;1 012.0 : 1,812.0 1,654.4 43.64 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.812 ' 7,507.9 5,687.3 41.33 PBR CAMCO OEJ PBR w/10'STROKE 2.938 7,521.4 5,697.4 41.28 PACKER CAMCO HRP-1-SP PACKER 2.859 7,544.8 5,715.1 41.21 NIPPLE CAMCO D NIPPLE NO GO 2.800 7,556.4 5,723.8 41.18 SOS CAMCO PE-500 SHEAR OUT SUB 2.984 GAS LIFT;2822.1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(NO) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 7,718.0 5,845.6 41.08 WHIPSTOCK 3/2/2016 7,890.0 5,975.6 40.59 FISH 43'GeoService Tool Several Unsuccessful FISH 2/19/1994 attempts;See WSR's from 1/27/94 to 2/24/94 Perforations&Slots Shot SURFACE;35.0-3,794.6-° . Dens Top(ND) Btm(ND) (shots/I Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,640.0 7,660.0 5,786.8 5,801.9 C-4,UNIT B, 7/16/2002 4.0 APERF 2.5"PJ,120 deg phase GAS LIFT;5,466.4 3G-04 7,710.0 7,734.0 5,839.6 5,857.7 A-3,3G-04 7/16/2002 4.0 APERF 2.5"PJ,120 deg phase 7,754.0 7,774.0 5,872.7 5,887.8 A-2,3G-04 1/6/1994 4.0'RPERF 2.5"Titan;180 deg. phasing 7,754.0 7,784.0 5,872.7 5,895.4 A-2,3G-04 1/14/1991 4.0 IPERF 4.5"Expendable Csg GAS LIFT;7,452.1 Gun;180 deg.phasing Mandrel Inserts St ati onTop(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,822.1 2,313.2 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,290.0 3/12/2016 3:00 2 5,466.4 4,2)0.8 MERLA TMPD 1 GAS LIFT OV BK 0.250 0.0 3/12/2016 5:00 3 7,452.1 5,645.5 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0'5/30/2015 1:00 PBR,7,507.9 Notes:General&Safety PACKER;7,521.4 End Date Annotation 5/12/2010 NOTE:CSG Sleeve from bottom Surf Csg hanger to top of 1st collar(54'),10"X.500 wall X65 pipe 8/27/2010 NOTE:View Schematic w/Alaska Schematic9.0 1/21/2016 NOTE:Milled out D-nipple©7,544'to 2.8"OD NIPPLE;7.5448 1/21/2016 NOTE:Cement from TD to 7531 NOTE:View Schematic w/Alaska Schematic9.0 SOS;7.556.4 ` APERF;7,640.0-7,660.0=- APERF;7,710.0-7,734.0 WHIPSTOCK 7,7180 RPER F;7.7540-7,7740 (PERF;7,754.0-7,784.0 FISH;7,890.0 1 PRODUCTION',35.0-6.0622 r • KUP PROD 3G-04A Conoc hillipsi ° Well Attributes Max Angle&MD TD Alaska,Inc. • Wellbore API/UWI Field Name Wellbore Status ncl(') MD(ftKB) Act Btm(ftKB) c,sccovtialpc 501032014301 KUPARUK RIVER UNIT PROD 101.03 7,935.50 10,780.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3G-04A.321120169:09.47 AM SSSV:TRDP 115 10/16/2014 Last WO: 36.39 11/5/1990 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:ADDED LATERALS,GLV C/O lehallf 3/18/2016 HANGER;30.8 gill Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread Liner A lateral 2 3/8 1.992 8,300.6 10,780.0 5,848.5 4.60 L-80 ST-L Liner Details uuu _i'''' Nominal ID yy�� Top(RKB) Top(ND)(RKB) Top Incl(') Item Des Com (in) 8,300.6 5,850.5 93.79 BILLET Anchored Aluminum Liner Top Billet 1.000 nein.�, 8,398.5 5,847.0 90.61 DEPLOY Shorty deployment sleeve 1.900 CONDUCTOR;36.0-115.0-41 Perforations&Slots Shot Den Top(ND) Btm(ND) (shotslf Top(ftKel Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com SAFETY VLV;1,812.0 8,311.0 10,779.0 5,849.8 5,848.6 A-2,3G-04 3/1/2016 SLOTS Notes:General&Safety End Date Annotation NOTE: GAS LIFT;2,822.1 C_ SURFACE;35.0.3,794.6-A GAS LIFT;5,466.4 i 4-71 GAS LIFT;7,452.1 PBR;7,507.9 11 PACKER;7.521.4 i I NIPPLE;7,544.8 ) SOS,7.5564 Iii' APERF,7,6400-7,6600-� I APERF;7710.0-T734.0-N_, PRODUCTION;35.041,062.2 SLOTS;7543.0-11.002.0 Liner AL1 Lateral;7,542.8- 11,003.0 s , i SLOTS;8,311.0-10.779.0 Liner A lateral;8300.6-10,780.0 • • 1 - Operations Summary (with Timelog Depths)ring •.:. &Wells 3G-04 Cbriocoehillips 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) 2/3/2016 2/3/2016 4.00 MIRU MOVE MOB P 14:30, Demob off 3N 0.0 0.0 14:30 18:30 2/3/2016 2/3/2016 3.00 MIRU MOVE MOB P 18:30 leave 3N,Arrive at 3G pad @ 0.0 0.0 18:30 21:30 21:30 2/3/2016 2/4/2016 2.50 MIRU MOVE MOB P DeJeep and spot modules, MIRU,Get 0.0 0.0 21:30 00:00 steam up,walkways,and stairways 2/4/2016 2/4/2016 9.50 MIRU MOVE RURD P Finish post-rig move checklist.Thaw 0.0 0.0 00:00 09:30 R7 valve. 2/4/2016 2/4/2016 1.00 MIRU WHDBOP NUND P NU BOP RIG ACCEPT 0.0 0.0 09:30 10:30 2/4/2016 2/4/2016 1.00 MIRU WHDBOP RURD P Put koomey on line,rig down BOP 0.0 0.0 10:30 11:30 hanging lines and put on elevators. Grease crew on location.Grease swabs,master,Tangos and R valves. 2/4/2016 2/4/2016 10.00 MIRU WHDBOP BOPE P Start BOP test,Test Witness waived 0.0 0.0 11:30 21:30 by Guy Cook,AOGCC 2/4/2016 2/4/2016 2.00 MIRU WHDBOP CIRC P BOPE test complete,Fill coil,test 0.0 0.0 21:30 23:30 inner reel iron and packoffs 2/4/2016 2/5/2016 0.50 SLOT WHDBOP CTOP P Crew change Valve checklist 0.0 0.0 23:30 00:00 2/5/2016 2/5/2016 1.30 SLOT WHDBOP CTOP P Complete valve check list,remove 0.0 0.0 00:00 01:18 nozzle and install floats,Test E-Line, had to change out flow sub 2/5/2016 2/5/2016 1.00 SLOT WHDBOP CTOP P PJSM,PT PDL and TT line,three 0.0 0.0 01:18 02:18 loose connections on TT line 2/5/2016 2/5/2016 1.50 SLOT WHDBOP CTOP P PJSM,P/U TWC Lubricator,Pull 0.0 0.0 02:18 03:48 TWC, R/D and load out lubricator 2/5/2016 2/5/2016 0.70 SLOT WHDBOP CTOP P PJSM,PT DS PDL 0.0 0.0 03:48 04:30 2/5/2016 2/5/2016 3.00 SLOT WHDBOP CTOP P Finish rigging up. 0.0 0.0 04:30 07:30 2/5/2016 2/5/2016 1.00 PROD1 RPEQPT PULD P PJSM.MU milling BHA#1 with 2.80" 62.0 62.0 07:30 08:30 D331 mill and 0.9°AKO motor. 2/5/2016 2/5/2016 2.50 PROD1 RPEQPT TRIP P RIH with BHA#1.Tie in to HRZ for a- 62.0 7,539.0 08:30 11:00 2 ft correction.Continue in the hole and tag up at 7539 ft with 5klbs. 2/5/2016 2/5/2016 1.50 PROD1 RPEQPT TRIP T PUH,PUW=33klbs. RBIH and 7,539.0 7,600.0 11:00 12:30 attempt to retag cement.Saw very little motor work and low WOB. Continue washing down seeing occasional cement stringers(7592', 7597',7598'). Made decsion to stop at 7,600 ft after not seeing any firm cement. Green cement observed over the shakers at bottoms up. 2/5/2016 2/5/2016 0.50 PROD1 RPEQPT TRIP T Discuss with town. Made decsion to 7,600.0 7,600.0 12:30 13:00 POOH. Mobilized Weatherford Reaves Underreamer and associated equipment. 2/5/2016 2/5/2016 0.90 PROD1 RPEQPT TRIP T POOH with BHA#1. 7,600.0 62.0 13:00 13:54 2/5/2016 2/5/2016 1.20 PROD1 RPEQPT PULD T On Surface, PJSM,Flow check well, 62.0 0.0 13:54 15:06 Lay down BHA#1 2/5/2016 2/5/2016 1.20 PROD1 RPEQPT WAIT T Wait on Weatherford under reamer 0.0 0.0 15:06 16:18 Page 1/14 Report Printed: 3/16/2016 !perations Summary (with Timelog Depths) Drilling :_; 3G-04 ConocoPhithps 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) 2/5/2016 2/5/2016 1.00 PROD1 RPEQPT PULD T PJSM,P/U BHA#2 Weatherford 2- 0.0 74.1 16:18 17:18 3/8"Motor and Under reamer dressed with 6"blades for 7"26ppf casing ID. 2/5/2016 2/5/2016 1.80 PROD1 RPEQPT TRIP T Trip in hole, BHA#2 74.1 7,393.0 17:18 19:06 2/5/2016 2/5/2016 0.40 PROD1 RPEQPT DLOG T 7393, PUH to 7360,Log HRZ for no 7,393.0 7,441.0 19:06 19:30 correction, PUW=46K 2/5/2016 2/5/2016 0.20 PROD1 RPEQPT DLOG T Log CCL,Corrected TT @ 7550 7,441.0 7,553.0 19:30 19:42 2/5/2016 2/6/2016 4.30 PROD1 RPEQPT UREM T PUH to 7500 and shut EDC,Trip in to 7,553.0 7,600.0 19:42 00:00 7560 and bring on pumps, 1.7 BPM @ 3107 PSI FS. Multiple stalls getting going.Extremly ratty. Pumped sweeps. 2/6/2016 2/6/2016 5.50 PROD1 RPEQPT UREM T Continue under reaming cement, 7,600.0 7,615.0 00:00 05:30 Multiple stalls,ratty milling,Low ROP, Pump sweeps 2/6/2016 2/6/2016 2.00 PROD1 RPEQPT TRIP T Confer with town,Trip out to inspect 7,615.0 0.0 05:30 07:30 underreamer BHA. 2/6/2016 2/6/2016 0.50 PROD1 RPEQPT OWFF T At surface.Flow check well.Static. 74.0 74.0 07:30 08:00 PJSM for inspecting BHA. 2/6/2016 2/6/2016 0.50 PROD1 RPEQPT PULD T PUH.Stand back BHI BHA. Pull 74.0 0.0 08:00 08:30 Weatherfod compnents above the rotary table for inspection. Reamer blades are in good condition. Some wear observed on the edges. No chipped cutters or other damage. Made decsion to swap out blades for a new set,and pick up a new weatherford 2-3/8"motor. 2/6/2016 2/6/2016 1.00 PROD1 RPEQPT PULD T Lay down weatherford motor and 0.0 74.0 08:30 09:30 redress the Rives underreamer with new 6"blades. MU underreaming BHA #3 with new weatherford motor and redressed underreamer. 2/6/2016 2/6/2016 1.50 PROD1 RPEQPT TRIP T RIH with BHA#3 with EDC open.Tie 74.0 7,616.0 09:30 11:00 into the HRZ for a-1.5'correction. Continue in the hole and dry tag at 7616 ft. 2/6/2016 2/6/2016 9.40 PROD1 RPEQPT UREM T PUH. PUW=57klbs.Close EDC and 7,616.0 7,644.0 11:00 20:24 RIH.Continue underreaming cement from 7616 ft to 7644 ft. 2/6/2016 2/6/2016 0.30 PROD1 RPEQPT WPRT T Back ream uo tp 7605,PUW=60K, 7,644.0 7,644.0 20:24 20:42 2/6/2016 2/7/2016 3.30 PROD1 RPEQPT UREM T Continue Under reaming, 1.6 BPM @ 7,644.0 7,657.0 20:42 00:00 3400 PSI FS,BHP=2976 2/7/2016 2/7/2016 3.40 PROD1 DRILL UREM T Continue under reaming cement in 7" 7,657.0 7,672.0 00:00 03:24 casing, 1.56 BPM @ 3400 PSI FS, BHP=3077 2/7/2016 2/7/2016 0.60 PROD1 DRILL WPRT T Pull wiper to TT with sweeps, 7,672.0 7,672.0 03:24 04:00 PUW=68K 2/7/2016 2/7/2016 4.90 PROD1 DRILL UREM T Continue Under reaming, 1.55 BPM© 7,672.0 7,691.0 04:00 08:54 3400 PSI FS, BHP=3173 2/7/2016 2/7/2016 0.30 PROD1 DRILL WPRT T Mini Wiper, PUW=69K 7,691.0 7,691.0 08:54 09:12 2/7/2016 2/7/2016 8.20 PROD1 DRILL UREM T Continue Under reaming, 1.58 BPM @ 7,691.0 7,712.0 09:12 17:24 3455 PSI FS, BHP=2960 Page 2/14 Report Printed: 3/16/2016 - Operations Summary (with Timelog•pths) h1., Drilling 3G-04 chiIIp Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/7/2016 2/7/2016 0.50 PROD1 DRILL WPRT T Wiper with sweep, PUW=64K 7,712.0 7,712.0 17:24 17:54 2/7/2016 2/8/2016 6.10 PROD1 DRILL UREM T 7712'Ream, 1.58 BPM @ 3550 PSI 7,712.0 7,723.0 17:54 00:00 FS,BHP=2980 2/8/2016 2/8/2016 0.10 PROD1 DRILL UREM T Under ream, 1.58 BPM @ 3550 PSI 7,723.0 7,723.0 00:00 00:06 FS 2/8/2016 2/8/2016 0.30 PROD1 DRILL WPRT T Wiper to 7571, PUW=62K,Blow down 7,723.0 7,723.0 00:06 00:24 choke B 2/8/2016 2/8/2016 6.00 PROD1 DRILL UREM T Continue to under ream. 1.57 BPM @ 7,723.0 7,732.0 00:24 06:24 3730 PSI FS,BHP=3062 Stall at 7732 ft. PU to 7630 ft. PUW 67 klbs. 2/8/2016 2/8/2016 3.60 PROD1 DRILL UREM T Continue to under ream. 1.57 BPM @ 7,732.0 7,740.0 06:24 10:00 3715 PSI FS, BHP=3050. Discuss with town.Call underream TD early at 7740 ft. 2/8/2016 2/8/2016 3.50 DEMOB MOVE TRIP T PUH pumping Hi Vis Sweep.OPen 7,740.0 68.0 10:00 13:30 EDC,continue POOH rolling the hole over to seawater. Meanwhile, RU LRS and pump diesel freeze protect from 2500 ft. 2/8/2016 2/8/2016 0.50 DEMOB MOVE OWFF T Flow check well.Static. 68.0 68.0 13:30 14:00 2/8/2016 2/8/2016 0.50 DEMOB MOVE PULD T LD Weatherford Underreaming BHA. 68.0 0.0 14:00 14:30 No damage 2/8/2016 2/8/2016 3.00 DEMOB WHDBOP PULD T PJSM,R/U to set BPV,Get mis set. 0.0 0.0 14:30 17:30 Debrie in profile.R/U to jet profile and stack 2/8/2016 2/8/2016 3.00 DEMOB WHDBOP CTOP T Start jetting stack and hanger profile, 0.0 0.0 17:30 20:30 TT line frozen,work to thaw, 2/8/2016 2/8/2016 0.70 DEMOB WHDBOP CTOP T PJSM,Jet stack in preperation to set 0.0 0.0 20:30 21:12 BPV 2/8/2016 2/8/2016 1.30 DEMOB WHDBOP CTOP T PJSM,Set BPV, Run profile brush 0.0 0.0 21:12 22:30 with BPV lubricator, Pressure up well to 500PSI.Set BPV, Bleed off tree to 100PSI.Good BPV PT,Rig down BPV crew and load out equipment 2/8/2016 2/9/2016 1.50 DEMOB WHDBOP CTOP T Install test joint and cycle BOPE to 0.0 0.0 22:30 00:00 remove cement debrie, M/U nozzle and jet stack,flush rig 2/9/2016 2/9/2016 1.50 DEMOB MOVE CTOP T Complete flushing rig, Blow down coil 0.0 0.0 00:00 01:30 and rig.Rig down cellar 2/9/2016 2/9/2016 1.50 DEMOB MOVE NUND T Nipple down stack,All fluids off rig. 0.0 0.0 01:30 03:00 RIG RELEASE 03:00 2/19/2016 2/19/2016 4.50 MIRU MOVE RURD T PJSM with PEAK and crew at 06:30 0.0 0.0 06:00 10:30 load Shop on trailer. Pull off 1G-11B. MU jeeps to subs, 2/19/2016 2/19/2016 4.00 MIRU MOVE MOB T PJSM-Mobilize 2 subs and shop to 0.0 0.0 10:30 14:30 3G pad 2/19/2016 2/19/2016 3.25 MIRU MOVE MOB T Remove jeeps, prep well, remove tree 0.0 0.0 14:30 17:45 caps,spot Sub and Pits over well. Send truck back to retrieve shop from pervious location. 2/19/2016 2/19/2016 4.25 MIRU MOVE RURD T MIRU,Get steam up,walkways,and 0.0 0.0 17:45 22:00 stairways,complete post rig move check list. Page 3/14 Report Printed: 3/16/2016 • • Drifting Operations Summary (with Timelog Depths) s Wells 3G-04 COnoicoMilips 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)', 2/19/2016 2/20/2016 2.00 MIRU WHDBOP NUND T Nipple up BOPE stack,and secure 0.0 0.0 22:00 00:00 cellar,Check all tree bolts,40 minutes,none found loose. Rig Accept at 22:00 2/20/2016 2/20/2016 3.00 MIRU WHDBOP RURD T Put koomey on line, rig down BOP 0.0 0.0 00:00 03:00 hanging lines and put on elevators. Grease crew on location.Grease swabs,master,Tangos and R valves. Load stack. Lines from test pump froze up.Troubleshooting boiler, steam lines. 2/20/2016 2/20/2016 7.00 MIRU WHDBOP BOPE T Begin initial BOPE test 250/4,500 0.0 0.0 03:00 10:00 psi,Annular 2,500 psi.Test witness waived by AOGCC rep.Guy Cook. 2/20/2016 2/20/2016 1.00 MIRU WHDBOP RURD T RD testing equipment,freeze protect 0.0 10:00 11:00 test pump and lines. 2/20/2016 2/20/2016 3.00 MIRU WHDBOP RURD T PJSM,with rig and valve crews, RU 0.0 0.0 11:00 14:00 lubricator and BPV equipment,test tiger tank line and valve shop lubricator,pull TWC, RD and load out valve shop equipment, 2/20/2016 2/20/2016 0.50 SLOT WELLPR SFTY T Pre-spud with rig crew and personnel. 0.0 0.0 14:00 14:30 2/20/2016 2/20/2016 4.00 SLOT WELLPR CTOP T PJSM, RU,and perform pipe 0.0 0.0 14:30 18:30 management cut 1393'of coiled tubing 2/20/2016 2/20/2016 3.00 SLOT WELLPR CTOP T Perform slack management,good air 0.0 0.0 18:30 21:30 flow thru coil,load coil 35 bbls, large amount of rust in returns,pump slack back 2.2 bpm. 2/20/2016 2/20/2016 1.00 SLOT WELLPR PRTS T Test inner reel iron and pack-offs, 0.0 0.0 21:30 22:30 good. RD test pump and equipment, freeze protect lines. 2/20/2016 2/21/2016 1.50 SLOT WELLPR CTOP T PJSM-cut 2 ft back to find wire, 0.0 0.0 22:30 00:00 reinstall boot,stab back on,pump slack back 2.2 bpm for 15 minutes,un -stab,cut 25 ft pipe to find wire,cut another 105 ft for total of 1,500 ft cut for pipe management. 2/21/2016 2/21/2016 0.50 SLOT WELLPR CTOP T RD pipe cutting equipment,off load 0.0 0.0 00:00 00:30 cut pipe. 2/21/2016 2/21/2016 3.30 SLOT WELLPR CTOP T PJSM-Prep end of coil and MU CTC, 0.0 0.0 00:30 03:48 pull test 36k,Test wire good,MU UQC, re-test line,good.P/T 3,750 psi, good.Skid injector. 2/21/2016 2/21/2016 0.85 SLOT WELLPR PRTS T PJSM-Pressure test PDL's 1,500 psi. 0.0 0.0 03:48 04:39 2/21/2016 2/21/2016 0.50 SLOT WELLPR OWFF T Bleed well to 0 psi,Monitor well for 0.0 0.0 04:39 05:09 flow. PJSM-MU BHA 2/21/2016 2/21/2016 1.25 SLOT WELLPR PULD T MU BHA#1,0.0°motor and RB HYC 0.0 51.5 05:09 06:24 2.98"bi-center bit. 2/21/2016 2/21/2016 1.70 SLOT WELLPR TRIP T RIH,with cement milling BHA#4 51.5 7,050.0 06:24 08:06 2/21/2016 2/21/2016 0.25 SLOT WELLPR DLOG T 7050 ft,Tie into gamma marker 7,050.0 7,112.0 08:06 08:21 correction of minus 1.0 ft. 2/21/2016 2/21/2016 0.50 SLOT WELLPR TRIP T 7112 ft,Continue RIH to TOC. 7,112.0 7,396.0 08:21 08:51 2/21/2016 2/21/2016 0.25 SLOT WELLPR TRIP T 7396 ft,Dry tag TOC,PUW 38 k, bring 7,396.0 7,396.0 08:51 09:06 pump up 1.6 bpm at 2300 psi Page 4/14 Report Printed: 3/16/2016 Drilling !perations Summary (with Timelog Depths) -__{ &Wells 3G-04 ConocoPhil ps 3� Ec5,k,a 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 (EKE) End Depth(ftKB) 2/21/2016 2/21/2016 8.90 SLOT WELLPR MILL T 7395 ft,start milling cement, 1 k 7,396.0 7,465.0 09:06 18:00 DHWOB,29 fph,getting PUW 50k, every 25 ft pump 5x5 Lo/Hi sweeps 2/21/2016 2/22/2016 6.00 SLOT WELLPR MILL T 7,465 ft. OBM 1.7 bpm at 2,526 psi 7,465.0 7,502.0 18:00 00:00 FS, DHWOB.65k,ROP-10 fph, PUW 55k,pump 5x5 Lo/Hi sweeps, 4 stalls at 7,500 ft(2.938"ID PBR) 2/22/2016 2/22/2016 4.75 SLOT WELLPR MILL T 7,502 ft. OBM 1.7 bpm at 2,526 psi, 7,502.0 7,538.0 00:00 04:45 DHWOB.6k,ROP-10 fph,stall at 7,500 ft(2.938"ID PBR)PUW 54k, mill past,stall at 7,513 ft(2.859"ID Packer)high vibration 4's and 5's and slow milling to 7,528 ft.smoothed out to 7,538 ft.pump sweeps. 2/22/2016 2/22/2016 2.25 SLOT WELLPR TRIP T POOH for pilot hole assembly 7,538.0 51.5 04:45 07:00 2/22/2016 2/22/2016 1.25 SLOT WELLPR OWFF T Check well for flow,PJSM, LD milling 51.5 0.0 07:00 08:15 BHA#4 2/22/2016 2/22/2016 0.75 PROD1 RPEQPT PULD T MU,second milling BHA#5 w/D331 0.0 62.5 08:15 09:00 and 0.9°ako motor. 2/22/2016 2/22/2016 1.25 PROD1 RPEQPT TRIP T RIH,with BHA#5 62.5 7,105.0 09:00 10:15 2/22/2016 2/22/2016 0.25 PROD1 RPEQPT 'DLOG T 7105 ft,Tie into the gamma marker 7,105.0 7,122.0 10:15 10:30 correction of minus 1.5'ft.PUW 49 k. 2/22/2016 2/22/2016 1.00 PROD1 RPEQPT TRIP T 7122 ft, PUW are high, PUH slowly, 7,122.0 7,122.0 10:30 11:30 pumping 10x10 sweep,PUW 38k. lost 12k by pumping sweep,cuttings across shaker, 2/22/2016 2/22/2016 0.50 PROD1 RPEQPT TRIP T 7122 ft,continue RIH 7,122.0 7,445.0 11:30 12:00 2/22/2016 2/22/2016 0.25 PROD1 RPEQPT TRIP T 7445 ft,tag GLM,9k DHWOB, 7,445.0 7,445.0 12:00 12:15 temporarily detained at the bit,worked pipe three times,pipe is free,minus 13k.60k CSW. 2/22/2016 2/22/2016 0.50 PROD1 RPEQPT TRIP T 7445 ft,RIH to 7538 ft. 7,445.0 7,538.0 12:15 12:45 2/22/2016 2/22/2016 1.75 PROD1 RPEQPT MILL P 7538 ft,begin to mill cement, 1.63bpm 7,538.0 7,550.0 12:45 14:30 at 2600psi,20°ROHS, 1.5 k WOB, 10 fph 2/22/2016 2/22/2016 4.15 PROD1 RPEQPT MILL P 7550 ft,Stalling motor,PUW 47k, 7,550.0 7,557.5 14:30 18:39 pump 5x5 sweep,mill ahead at 1.64 bpm at 2600 psi, IA 14,OA 0,Stalling at 7,553 ft and 7,557 ft. 2/22/2016 2/22/2016 0.10 PROD1 RPEQPT MILL P 7,557 ft. Stall,no ROP,call town, 7,557.5 7,558.5 18:39 18:45 PUH and roll TF to 200°ROHS,mill from 7,557.73 ft to 7,578.51 ft with 1k WOB roll TF back to 20°ROHS 2/22/2016 2/22/2016 3.65 PROD1 RPEQPT MILL P 7,558.5 ft. Milling cement 1.64 bpm at 7,558.5 7,600.0 18:45 22:24 2,850 psi,ROP 12 fph,WOB 1.4k, pump 5x5, 2/22/2016 2/22/2016 0.75 PROD1 RPEQPT WPRT P Wiper up hole to 7,350,PUW 38k, 7,600.0 7,600.0 22:24 23:09 RBIH 2/22/2016 2/23/2016 0.85 PROD1 RPEQPT MILL P 7,600 ft. Milling cement 1.65 bpm at 7,600.0 7,613.0 23:09 00:00 2,869 psi FS,ROP 16 fph,WOB 1.4k, 2/23/2016 2/23/2016 1.85 PROD1 RPEQPT MILL P 7,613 ft. Milling cement 1.65 bpm at 7,613.0 7,644.0 00:00 01:51 2,797 psi FS, ROP 16 fph,WOB 1.4k, pump 5x5 Page 5/14 Report Printed: 3/16/2016 !perations Summary (with Timelog Depths) :_K &Chilling 3G-04 ConocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/23/2016 2/23/2016 0.80 PROD1 RPEQPT WPRT P Wiper up hole to 7,350 ft, PUW 46k, 7,644.0 7,644.0 01:51 02:39 RBIH 2/23/2016 2/23/2016 4.00 PROD1 RPEQPT MILL P 7,644 ft. Milling cement 1.65 bpm at 7,644.0 7,706.0 02:39 06:39 2,850 psi FS, ROP 16 fph,WOB 1.4k 2/23/2016 2/23/2016 0.50 PROD1 RPEQPT WPRT P 7706 ft,Wiper up to 7560 ft, PUW 50k 7,706.0 7,706.0 06:39 07:09 2/23/2016 2/23/2016 0.25 PROD1 RPEQPT MILL P 7706 ft, BOBM 1.65 at 2700 psi,ROP 7,706.0 7,750.0 07:09 07:24 4 fph,work pipe. IA 0,OA 0 2/23/2016 2/23/2016 6.00 PROD1 RPEQPT MILL P 7750 ft,TD cement pilot hole. PUH 7,750.0 7,570.0 07:24 13:24 thru pilot hole to 7530 ft. PUW 46k 2/23/2016 2/23/2016 0.25 PROD1 RPEQPT DLOG P 7570 ft,Tie into the K1 marker 7,570.0 7,588.0 13:24 13:39 correction of plus 1.5 ft. 2/23/2016 2/23/2016 1.40 PROD1 RPEQPT MILL P 7588 ft,continue PUH to 7558 ft, 7,588.0 7,545.0 13:39 15:03 backream transition area up to 7545 ft. Dry drift transition,slight stacking 7560 to 7571 2/23/2016 2/23/2016 0.20 PROD1 RPEQPT WPRT P Continue trip in hole,tag TD @ 7751 7,545.0 7,751.0 15:03 15:15 2/23/2016 2/23/2016 2.20 PROD1 RPEQPT TRIP P Pump sweeps and chase to surface. 7,751.0 62.0 15:15 17:27 2/23/2016 2/23/2016 0.50 PROD1 RPEQPT PULD P At surface,30 min no flow test, 62.0 62.0 17:27 17:57 2/23/2016 2/23/2016 1.30 PROD1 RPEQPT SFTY P Hold 2015 year review with both crews 62.0 62.0 17:57 19:15 2/23/2016 2/23/2016 1.00 PROD1 RPEQPT PULD P Lay down BHA#5,Pilot hole mill 62.0 0.0 19:15 20:15 2/23/2016 2/23/2016 0.50 PROD1 RPEQPT WWWH P M/U nozzle and jet BOPE and tree 0.0 0.0 20:15 20:45 2/23/2016 2/23/2016 0.90 PROD1 RPEQPT PULD P PJSM, M/U HES Multi finger imaging 0.0 21.8 20:45 21:39 tool, M/U to coil and surface test.Stab on injector 2/23/2016 2/23/2016 1.90 PROD1 RPEQPT TRIP P RIH BHA#6 HES Caliper 21.8 7,610.0 21:39 23:33 2/23/2016 2/23/2016 0.10 PROD1 RPEQPT DLOG P Correct depth @ K1 for-3.52' 7,610.0 7,607.0 23:33 23:39 2/23/2016 2/23/2016 0.10 PROD1 RPEQPT TRIP P continue in to 7742 7,607.0 7,742.0 23:39 23:45 2/23/2016 2/24/2016 0.25 PROD1 RPEQPT DLOG P 7742,Open caliper fingers,start 7,742.0 7,515.0 23:45 00:00 logging up @ 40 fpm 2/24/2016 2/24/2016 0.20 PROD1 RPEQPT TRIP P RBIH for second logging pass 7,515.0 7,742.0 00:00 00:12 2/24/2016 2/24/2016 0.50 PROD1 RPEQPT DLOG P Log 7742 to 7184, PUW=52K 7,742.0 7,184.0 00:12 00:42 2/24/2016 2/24/2016 1.90 PROD1 RPEQPT TRIP P Continue out of well with caliper 7,184.0 25.0 00:42 02:36 2/24/2016 2/24/2016 1.00 PROD1 RPEQPT PULD P At surface,PJSM, Flow check well. 25.0 0.0 02:36 03:36 Lay down BHA#6 2/24/2016 2/24/2016 1.50 PROD1 WHPST PULD P PJSM, P/U Whipstock,BHA#7. Make 0.0 72.6 03:36 05:06 up to coil track and surface test 2/24/2016 2/24/2016 2.50 PROD1 WHPST TRIP P Trip in with whipstock,EDC open 72.6 7,578.0 05:06 07:36 2/24/2016 2/24/2016 1.00 PROD1 WHPST TRIP P 7578 ft,PUW 45k @ TOC,Continue 7,578.0 7,728.5 07:36 08:36 RIH log K1 marker for tie in correction of minus 2.5 ft. 2/24/2016 2/24/2016 1.50 PROD1 WHPST TRIP P 7728.5 ft. PUW 55k,set TOWS 7,728.5 72.6 08:36 10:06 highside at 7718 ft,PUW 55k,POOH Page 6/14 Report Printed: 3/16/2016 Iterations Summary (with Timelog Depths) :: Wells 3G-04 ConocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/24/2016 2/24/2016 0.50 PROD1 WHPST OWFF P At surface,check well for flow 72.6 72.6 10:06 10:36 2/24/2016 2/24/2016 0.75 PROD1 WHPST PULD P LD WS setting BHA#7 72.6 0.0 10:36 11:21 2/24/2016 2/24/2016 1.00 PROD1 WHPST PULD P Swap out risers to a shorter one for 0.0 0.0 11:21 12:21 future BHA's. Perform shell test,up to 4500 psi. 2/24/2016 2/24/2016 1.00 PROD1 WHPST PULD P MU window milling BHA#8 0.0 0.0 12:21 13:21 2/24/2016 2/24/2016 2.50 PROD1 WHPST TRIP P RIH,with WS milling BHA with 0.6° 0.0 7,580.0 13:21 15:51 ako motor,String Reamer and Diamond Window Mill 2/24/2016 2/24/2016 0.55 PROD1 WHPST DLOG P 7580 ft,Log the K1 correction of 7,580.0 7,589.0 15:51 16:24 minus 1.5 ft.PUW 50k,swap well over to 8.5 ppg drilling fluid, PUW 34k 2/24/2016 2/24/2016 0.10 PROD1 WHPST WPST P Continue RIH,dry tagged TOWS at 7,589.0 7,718.0 16:24 16:30 7718', PUH,bring pump up, 1.5 bpm at 3040 psi, BHP 3172,WHP 3, IA 0, OA 0 2/24/2016 2/25/2016 7.50 PROD1 WHPST MILL P 7717.3',Call pinch point, 1.5 BPM @ 7,718.0 7,721.4 16:30 00:00 3000PS1 FS,DHWOB=1.2K to 2.4K. Mill window per RP and BOT Rep 2/25/2016 2/25/2016 5.50 PROD1 WHPST MILL P Continue to mill window exit, 1.5 BPM 7,721.4 7,740.0 00:00 05:30 @ 2900 PSI FS, DHWOB=2.1K, BOT calls BOW @ 7722.7,@ 3:07 2/25/2016 2/25/2016 1.50 PROD1 WHPST MILL P 7740 ft. back ream window area, 7,740.0 7,719.0 05:30 07:00 seems to be clean, 2/25/2016 2/25/2016 2.00 PROD1 WHPST TRIP P 7719 ft. POOH,Check well for flow at 7,719.0 74.3 07:00 09:00 7350 ft.400 psi WHP. 2/25/2016 2/25/2016 0.25 PROD1 WHPST PULD P At surface,PJSM, Undeploy window 74.3 74.3 09:00 09:15 milling BHA 2/25/2016 2/25/2016 1.25 PROD1 WHPST PULD P LD Window milling BHA. 74.3 0.0 09:15 10:30 ""Note: Mills were in gauge,2.79 no -go. 2/25/2016 2/25/2016 1.00 PROD1 DRILL PULD P PJSM, MU/PD build section BHA 0.0 72.2 10:30 11:30 2/25/2016 2/25/2016 1.85 PROD1 DRILL TRIP P RIH,with build section BHA#9,2.3° 72.2 7,570.0 11:30 13:21 ako motor,USR,and rebuilt bi-center bit. 2/25/2016 2/25/2016 0.25 PROD1 DRILL DLOG P 7570 ft.correction of minus 2.0 ft. 7,570.0 7,590.0 13:21 13:36 PUW 32k 2/25/2016 2/25/2016 0.40 PROD1 DRILL TRIP P 7590 ft.continue RIH thru pilot hole, 7,590.0 7,740.0 13:36 14:00 RIW 8k 2/25/2016 2/25/2016 1.75 PROD1 DRILL DRLG P 7740 ft,OBD 1.55 bpm at 3480 psi, 7,740.0 7,821.0 14:00 15:45 BHP 3646,WHP 311, IA 2,OA 0 2/25/2016 2/25/2016 0.25 PROD1 DRILL WPRT P 7821 ft.wiper up hole to 7740 ft,PUW 7,821.0 7,740.0 15:45 16:00 38k 2/25/2016 2/25/2016 0.25 PROD1 DRILL WPRT P 7740 ft, Log RA marker no correction, 7,740.0 7,821.0 16:00 16:15 RBIH 2/25/2016 2/25/2016 0.60 PROD1 DRILL DRLG P 7821 ft, BOBD 1.55 bpm at 3440 psi, 7,821.0 7,871.0 16:15 16:51 BHP 3650,WHP 312, IA 1,OA 0 2/25/2016 2/25/2016 1.20 PROD1 DRILL WPRT P PUH to check surveys,Surveys not 7,871.0 7,871.0 16:51 18:03 clean,Confer with town 2/25/2016 2/25/2016 0.40 PROD1 DRILL DRLG P 7871', Drill, 1.5 BPM @ 3440 PSI FS, 7,871.0 7,893.0 18:03 18:27 BHP=3650 Page 7/14 Report Printed: 3/16/2016 !perations Summary (with Timelogepths) -{ We 3G-04 Conocophi€lips i; 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 (f',KB) End Depth(ftKB) 2/25/2016 2/25/2016 0.40 PROD1 DRILL WPRT P Pull off bottom to discuss,confer with 7,893.0 7,893.0 18:27 18:51 town.Have 50'seperation from main well bore.surveys still not usable. Confer with town. Drill 15 more feet to see if surveys will clear up 2/25/2016 2/25/2016 0.20 PROD1 DRILL DRLG P 7893', Drill, 1.50 BPM @ 3490 PSI 7,893.0 7,909.0 18:51 19:03 FS, BHP=3670 2/25/2016 2/25/2016 2.30 PROD1 DRILL TRIP T 7909 Surveys still not usable, 104' 7,909.0 70.9 19:03 21:21 from parent well,Trip out for tool Begin BHI NPT 2/25/2016 2/25/2016 2.10 PROD1 DRILL PULD T Tag up and space out, PJSM, PUD 70.9 72.2 21:21 23:27 BHA#9, PD BHA#10.PDL Pre loaded, Make up to coil and surface test 2/25/2016 2/26/2016 0.55 PROD1 DRILL TRIP T RIH 72.2 2,462.0 23:27 00:00 2/26/2016 2/26/2016 1.50 PROD1 DRILL TRIP T Continue in well 2,462.0 7,570.0 00:00 01:30 2/26/2016 2/26/2016 0.10 PROD1 DRILL DLOG T Log K1 for-2'correction 7,570.0 7,595.0 01:30 01:36 2/26/2016 2/26/2016 0.40 PROD1 DRILL TRIP T Continue in well,close EDC,Clean 7,595.0 7,909.0 01:36 02:00 trip through window, Re take surveys 2/26/2016 2/26/2016 1.50 PROD1 DRILL DRLG P 7909', Drill, 1.48 BPM @ 3394 PSI 7,909.0 8,002.0 02:00 03:30 FS, BHP=3636 END BHI NPT TIME,2 Hrs. 2/26/2016 2/26/2016 2.00 PROD1 DRILL TRIP P Call FOB, POOH for lateral BHA, 8,002.0 72.2 03:30 05:30 PUW=36K 2/26/2016 2/26/2016 1.00 PROD1 DRILL PULD P At surface, PJSM,undeploy BHA#10 72.2 0.0 05:30 06:30 2/26/2016 2/26/2016 1.25 PROD1 DRILL PULD P PU/MU/deploy,change UQS check 0.0 72.2 06:30 07:45 valves,inspect Pac-off,Stab on with coil,tag up,space out, 2/26/2016 2/26/2016 2.00 PROD1 DRILL TRIP P RIH with lateral section, BHA#11 72.2 7,570.0 07:45 09:45 2/26/2016 2/26/2016 0.25 PROD1 DRILL DLOG P 7570 ft,log the K1 marker correction 7,570.0 7,589.0 09:45 10:00 of plus 3.0 ft. 2/26/2016 2/26/2016 0.75 PROD1 DRILL TRIP P 7589 ft.Continue IH to bottom. 7,589.0 8,002.0 10:00 10:45 2/26/2016 2/26/2016 5.00 PROD1 DRILL DRLG P 8002 ft,OBD 1.5 bpm at 3700 psi, 8,002.0 8,225.0 10:45 15:45 BHP 3661,WHP 270, IA 0,OA 0 2/26/2016 2/26/2016 0.25 PROD1 DRILL WPRT P 8225 ft,Wiper up hole to EOB 8002 ft. 8,225.0 8,000.0 15:45 16:00 RBIH 2/26/2016 2/26/2016 0.25 PROD1 DRILL WPRT P 8000 ft,wiper back in hole RIW 8k 8,000.0 8,225.0 16:00 16:15 2/26/2016 2/26/2016 2.00 PROD1 DRILL DRLG P 8225 ft,BOBD 1.5 bpm at 3700 psi, 8,225.0 8,229.0 16:15 18:15 BHP 3620,WHP 265, IA 11,OA 0, Continue to try to get drilling,Fluid losses close to bottom @.5 BPM 2/26/2016 2/26/2016 1.10 PROD1 DRILL DRLG P 8229 Drilling break, ROP 70 FPH, 8,229.0 8,310.0 18:15 19:21 Returns back to 95% 2/26/2016 2/26/2016 0.60 PROD1 DRILL WPRT P 8310',wiper to 7775, PUW=37K, 8,310.0' 8,310.0 19:21 19:57 Clean trip up and down 2/26/2016 2/27/2016 4.05 PROD1 DRILL DRLG P 8310', Drill, 1.5 BPM @ 3660 PSI FS, 8,310.0 8,667.0 19:57 00:00 BHP=3675,Swap mud, New mud at bit @ 8636 2/27/2016 2/27/2016 0.60 PROD1 DRILL DRLG P Drill, 1.5 BPM @ 3450 PSI FS, 8,667.0 8,710.0 00:00 00:36 BHP=3664 Page 8/14 Report Printed: 3/16/2016 • • Mining Operations Summary (with Timelog Depths) { &Welts 3G-04 CcxX:coPhitiips 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) 2/27/2016 2/27/2016 0.80 PROD1 DRILL WPRT P Wiper to 7800', PUW=38K,Clean trip 8,710.0 8,710.0 00:36 01:24 up and down 2/27/2016 2/27/2016 4.00 PROD1 DRILL DRLG P 8710', Drill, 1.48 BPM @ 3550 PSI 8,710.0 9,110.0 01:24 05:24 FS, BHP=3678,WHP=421 2/27/2016 2/27/2016 0.50 PROD1 DRILL WPRT P 9110 ft,wiper up hole to 7735 ft. PUW 9,110.0 7,735.0 05:24 05:54 37k 2/27/2016 2/27/2016 0.25 PROD1 DRILL DLOG P 7735 ft,log RA marker correction of 7,735.0 7,753.0 05:54 06:09 plus 6.0 ft. 2/27/2016 2/27/2016 0.50 PROD1 DRILL WPRT P 7753 ft.continue RBIH 7,753.0 9,114.0 06:09 06:39 2/27/2016 2/27/2016 5.00 PROD1 DRILL DRLG P 9114 ft.ODD 1.5 bpm at 3520 psi, 9,114.0 9,471.0 06:39 11:39 BHP 3693,WHP 382, IA 0,OA 0 2/27/2016 2/27/2016 0.50 PROD1 DRILL WPRT P 9471 ft,Wiper up hole to 8470 ft. PUW 9,471.0 8,470.0 11:39 12:09 43k 2/27/2016 2/27/2016 0.50 PROD1 DRILL WPRT P 8470 ft.Wiper back in hole RIW 6k 8,470.0 9,471.0 12:09 12:39 2/27/2016 2/27/2016 2.00 PROD1 DRILL DRLG P 9471 ft. BOBD 1.5 bpm at 3720 psi, 9,471.0 9,620.0 12:39 14:39 BHP 3669,WHP 323, IA 12,OA 0 2/27/2016 2/27/2016 0.50 PROD1 DRILL WPRT P 9620 ft, Pump 5x5 sweep,300 ft wiper 9,620.0 9,320.0 14:39 15:09 up to 9320 ft. PUW 38 k 2/27/2016 2/27/2016 0.50 PROD1 DRILL WPRT P 9320 ft,Wiper back in hole RIW 7 k. 9,320.0 9,620.0 15:09 15:39 2/27/2016 2/27/2016 0.50 PROD1 DRILL DRLG P 9620 ft,BOBD 1.6 bpm at 3730 psi, 9,620.0 9,663.0 15:39 16:09 BHP 3700,WHP 300, IA 48,OA 0 2/27/2016 2/27/2016 0.75 PROD1 DRILL WPRT P 9663 ft,Wiper up hole to 7735 ft. 9,663.0 7,770.0 16:09 16:54 2/27/2016 2/27/2016 0.25 PROD1 DRILL DLOG P 7770 ft,Log the RA marker correction 7,770.0 7,756.0 16:54 17:09 of plus 6.0 ft. 2/27/2016 2/27/2016 0.90 PROD1 DRILL WPRT P 7756 ft.Wiper back in hole, RIW 8 k 7,756.0 9,664.0 17:09 18:03 2/27/2016 2/27/2016 0.70 PROD1 DRILL DRLG P 9664',Drill, 1.5 BPM @ 3630 PSI FS, 9,664.0 9,772.0 18:03 18:45 BHP=3740 2/27/2016 2/27/2016 0.60 PROD1 DRILL WPRT P Run out of push, Pump 5X5 sweeps, 9,772.0 9,772.0 18:45 19:21 pull 350'wiper, PUW=41K 2/27/2016 2/27/2016 0.70 PROD1 DRILL DRLG P 9772', Drill, 1.5 BPM @ 3560 PSI FS, 9,772.0 9,831.0 19:21 20:03 BHP=3700, RIW=6K,ROP=-100 FPH 2/27/2016 2/27/2016 0.40 PROD1 DRILL WPRT P Run out of push,Pull mini wiper. 9,831.0 9,831.0 20:03 20:27 Unable to get drilling, Pump sweeps and pull 350 wiper 2/27/2016 2/27/2016 2.00 PROD1 DRILL DRLG P 9831'Drill, 1.5 BPM @ 3576 PSI FS, 9,831.0 9,944.0 20:27 22:27 BHP=3750, RIW=4.4K, DHWOB=1.2K 2/27/2016 2/27/2016 1.10 PROD1 DRILL WPRT P 9944, pump 5 X 5 sweeps pull 1000' 9,944.0 9,944.0 22:27 23:33 wiper, PUW=46K 2/27/2016 2/28/2016 0.45 PROD1 DRILL DRLG P 9944', Drill, 1.5 BPM @ 3690 PSI FS, 9,944.0 9,990.0 23:33 00:00 BHP=3770 2/28/2016 2/28/2016 0.60 PROD1 DRILL DRLG P 9990',Drill, 1.5 BPM @3690 PSI FS, 9,990.0 10,025.0 00:00 00:36 BHP=3763 2/28/2016 2/28/2016 0.40 PROD1 DRILL WPRT P Pump 5X5 Sweeps, Mini wiper, 10,025.0 10,025.0 00:36 01:00 PUW=45K 2/28/2016 2/28/2016 0.60 PROD1 DRILL DRLG P 10025', Drill, 1.49 BPM @ 3605 PSI 10,025.0 10,063.0 01:00 01:36 FS, BHP=3710 2/28/2016 2/28/2016 0.70 PROD1 DRILL WPRT P P/U,Stacking,Start new mud down 10,063.0 10,063.0 01:36 02:18 coil, New mud at bit @ 10064 2/28/2016 2/28/2016 0.90 PROD1 DRILL DRLG P 10063',Drill, 1.5 BPM @ 3350 PSI 10,063.0 10,106.0 02:18 03:12 FS, BHP=3730,WHP=520 Page 9/14 Report Printed: 3/16/2016 • • Drilling Operations Summary (with Timelog Depths) o4 &Webs 3G-04 CtocoPttitlips 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) 2/28/2016 2/28/2016 0.50 PROD1 DRILL WPRT P Pull 850'wiper, PUW=44K 10,106.0 10,106.0 03:12 03:42 2/28/2016 2/28/2016 0.70 PROD1 DRILL DRLG P 10106', Drill, 1.5 BPM @ 3350 PSI 10,106.0 10,158.0 03:42 04:24 FS, BHP=3719 2/28/2016 2/28/2016 0.50 PROD1 DRILL WPRT P Mini Wiper,PUW=39K,Tought time 10,158.0 10,158.0 04:24 04:54 getting back to drilling,Wipe up to 9850 2/28/2016 2/28/2016 2.00 PROD1 DRILL DRLG P 10158', Drill, 1.5 BPM @ 3350 PSI 10,158.0 10,207.0 04:54 06:54 FS, BHP=3760,WHP=520, RIW=-2K with DHWOB=1.3K 2/28/2016 2/28/2016 0.75 PROD1 DRILL WPRT P 10207 ft,wiper up hole to 7733 ft, 10,207.0 7,729.0 06:54 07:39 PUW 45 k. 2/28/2016 2/28/2016 0.25 PROD1 DRILL DLOG P 7729 ft,log the RA correction of plus 7,729.0 7,753.0 07:39 07:54 9.5 ft. 2/28/2016 2/28/2016 1.00 PROD1 DRILL WPRT P 7753 ft,wiper back in hole, RIW 8 k 7,753.0 10,207.0 07:54 08:54 2/28/2016 2/28/2016 1.50 PROD1 DRILL DRLG P 10270 ft. BOBD 1.6 bpm at 3350 psi, 10,207.0 10,307.0 08:54 10:24 BHP 3668,WHP 330, IA 107,OA 0 2/28/2016 2/28/2016 0.25 PROD1 DRILL WPRT P 10307 ft,Short BHA wiper,line up to 10,307.0 10,307.0 10:24 10:39 pump a 30 bbl 1 bpb alpine beaded pill. 2/28/2016 2/28/2016 3.00 PROD1 DRILL DRLG P 10307 ft, BOBD 1.5 bpm at 3630 psi, 10,307.0 10,512.0 10:39 13:39 BHP 3681,WHP 341, IA 111,OA 0 Pumping 25 bbl beaded pills every 50 bbls pump out of active pits. 2/28/2016 2/28/2016 1.00 PROD1 DRILL WPRT P 10512 ft,Wiper up hole. PUW 51 10,512.0 9,270.0 13:39 14:39 2/28/2016 2/28/2016 0.65 PROD1 DRILL WPRT P 9270 ft,Wiper in hole, RIW 7 k 9,270.0 10,512.0 14:39 15:18 2/28/2016 2/28/2016 1.70 PROD1 DRILL DRLG P 10512 ft, BOBD 1.51 bpm at 3730 psi, 10,512.0 10,617.0 15:18 17:00 BHP 3825,WHP 352, IA 130,OA 0 2/28/2016 2/28/2016 0.50 PROD1 DRILL WPRT P 10617,500'wiper, PUW=43K 10,617.0 10,617.0 17:00 17:30 2/28/2016 2/28/2016 1.40 PROD1 DRILL DRLG P 10,617',Drill, 1.5 BPM @ 3670 PSI 10,617.0 10,704.0 17:30 18:54 FS,BHP=3820 2/28/2016 2/28/2016 0.30 PROD1 DRILL WPRT P 10,704'350'wiper, PUW=49K 10,704.0 10,704.0 18:54 19:12 2/28/2016 2/28/2016 0.90 PROD1 DRILL DRLG P 10,704 Drill, 1.5 BPM @ 3740 PSI FS, 10,704.0 10,762.0 19:12 20:06 BHP=3815 2/28/2016 2/28/2016 0.20 PROD1 DRILL WPRT P BHA Wiper,PUW=44K 10,762.0 10,762.0 20:06 20:18 2/28/2016 2/28/2016 1.00 PROD1 DRILL DRLG P 10762', Drill, 1.5 BPM @3850 PSI FS, 10,762.0 10,780.0 20:18 21:18 BHP=3789 2/28/2016 2/28/2016 1.60 PROD1 DRILL WPRT P 10780',Call TD, PUH pumping 10,780.0 7,730.0 21:18 22:54 sweeps 2/28/2016 2/28/2016 0.60 PROD1 DRILL DLOG P 7730', Log into RA marker for+8', Mad 7,730.0 7,730.0 22:54 23:30 pass 7900'to window 7730 2/28/2016 2/29/2016 0.50 PROD1 DRILL WPRT P Chase sweeps to swab 7,730.0 5,974.0 23:30 00:00 2/29/2016 2/29/2016 1.20 PROD1 DRILL WPRT P Wiper trip to swab,(cont.) 5,974.0 68.0 00:00 01:12 2/29/2016 2/29/2016 1.70 PROD1 DRILL TRIP P Set counters,Trip in 68.0 7,570.0 01:12 02:54 2/29/2016 2/29/2016 0.20 PROD1 DRILL DLOG P Tie into K1 for-3'correction 7,570.0 7,592.0 02:54 03:06 2/29/2016 2/29/2016 1.30 PROD1 DRILL TRIP P Wt check, PUW=36K,Continue in to 7,592.0 10,785.0 03:06 04:24 confirm TD Page 10/14 Report Printed: 3/16/2016 ng Operations Summary (with Timelog•pths) lefts 3G-04 ConocoPtaitttps 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) 2/29/2016 2/29/2016 2.75 PROD1 DRILL TRIP P Trip out pumping 11.8 Beaded liner 10,785.0 72.2 04:24 07:09 running pill, Paint EOP flags @ 8349.28,&5200 2/29/2016 2/29/2016 0.50 PROD1 DRILL OWFF P At surface,check well for flow,inspect 72.2 72.2 07:09 07:39 choke"B",PJSM,simops work on INJH cooling problem. 2/29/2016 2/29/2016 1.00 PROD1 DRILL PULD P LD drilling BHA 72.2 0.0 07:39 08:39 2/29/2016 2/29/2016 0.60 PROD1 DRILL PULD P Function tested BOPE 0.0 0.0 08:39 09:15 2/29/2016 2/29/2016 0.50 COMPZ1 CASING PUTB P PJSM, Prep rig floor for liner, 0.0 0.0 09:15 09:45 2/29/2016 2/29/2016 4.00 COMPZ1 CASING PUTB P MU 82 jts of slotted liner. 0.0 2,381.5 09:45 13:45 2/29/2016 2/29/2016 0.75 COMPZ1 CASING PUTB P MU Coiltrak tools,change out Checks 2,381.5 2,425.7 13:45 14:30 in the upper stab INJH,surface test tools. 2/29/2016 2/29/2016 1.50 COMPZ1 CASING RUNL P RIH,w/"A"lateral liner asssembly 82 2,425.7 7,625.0 14:30 16:00 jts of slotted liner,shorty deployment sleeve,and non-ported bull nose. 2/29/2016 2/29/2016 0.10 COMPZ1 CASING RUNL P 7625 ft.correct to the EOP flag at 7,625.0 7,625.0 16:00 16:06 5200 ft.correction of minus 8.6 ft. PUW 47k 2/29/2016 2/29/2016 1.00 COMPZ1 CASING RUNL P 7625 ft,continue RIH with"A"liner 7,625.0 10,780.0 16:06 17:06 assembly.Tie into the K1 correction of plus 6.0 ft. 2/29/2016 2/29/2016 0.35 COMPZ1 CASING RUNL P 10780 ft, PUW 50 k, RBIH to 10780 ft. 10,780.0 10,780.0 1706 17:27 release from liner off bottom at 10780 ft.PUW 35 k. 2/29/2016 2/29/2016 1.25 COMPZ1 CASING TRIP P POOH 10,780.0 44.2 17:27 18:42 2/29/2016 2/29/2016 1.50 COMPZ1 CASING OWFF P Check well for flow,PJSM LD BOT 44.2 0.0 18:42 20:12 setting tools and flush coiltrak tools. 2/29/2016 2/29/2016 1.00 COMPZ1 CASING RGRP P Replace broken bolt on saddle clamp 0.0 0.0 20:12 21:12 on reel, 2/29/2016 2/29/2016 1.80'COMPZ1 CASING PUTB P PJSM, MU 3 jts of slotted liner with 0.0 159.1 21:12 23:00 ported bull nose and Open Hole Anchored billet.Coiltrak tools.Surface test. 2/29/2016 3/1/2016 1.00 COMPZ1 CASING RUNL P RIH,with"A"lateral upper section with 159.1 5,240.0 23:00 00:00 3 jts of slotted liner,and open hole anchored billet. 3/1/2016 3/1/2016 0.70 COMPZ1 CASING TRIP P Continue in with A lateral upper 5,240.0 7,623.0 00:00 00:42 segment with Anchored Billit,close EDC @ 7345' 3/1/2016 3/1/2016 0.10 COMPZ1 CASING DLOG P At flag,+36'5'correction,did not make 7,623.0 7,623.0 00:42 00:48 correction 3/1/2016 3/1/2016 0.40 COMPZ1 CASING TRIP P continue in hole 7,623.0 7,625.0 00:48 01:12 3/1/2016 3/1/2016 0.20 COMPZ1 CASING DLOG P Log K1 for+36.5,missed marker first 7,625.0 7,703.0 01:12 01:24 time. 3/1/2016 3/1/2016 0.40 COMPZ1 CASING TRIP P RIH 7,703.0 8,697.0 01:24 01:48 3/1/2016 3/1/2016 0.10 COMPZ1 CASING TRIP P At set depth,oriented to 180°,Pumps 8,697.0 8,697.0 01:48 01:54 on,see tool shift at 3650 PSI.Set down 4.4K 3/1/2016 3/1/2016 1.60 COMPZ1 CASING TRIP P PUH,reset counters,Trip out 8,697.0 114.0 01:54 03:30 Page 11/14 Report Printed: 3/16/2016 ,, Driiiiiing operations Summary (with TimelogDepths) Mme# W 3G-04 C.onoccehillips 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) 3/1/2016 3/1/2016 1.00 COMPZ1 CASING PULD P At surface,30 min flow check, PJSM 114.0 0.0 03:30 04:30 lay down Billet running tools 3/1/2016 3/1/2016 1.70 PROD2 DRILL PULD P M/U BHA#14,Drill by-AL1 Lateral 0.0 72.1 04:30 06:12 with .5°AKO motor and RR Bicenter, M/U to coil and surface test, 3/1/2016 3/1/2016 1.70 PROD2 DRILL TRIP P RIH 72.1 7,570.0 06:12 07:54 3/1/2016 3/1/2016 0.20 PROD2 DRILL DLOG P Log K1 for-2.5' 7,570.0 7,587.0 07:54 08:06 3/1/2016 3/1/2016 1.30 PROD2 DRILL CIRC P RIH to 7700'and displace well to 7,587.0 7,700.0 08:06 09:24 8.6PPG drilling mud 3/1/2016 3/1/2016 0.50 PROD2 DRILL TRIP P Close EDC, PUW=38K,Trip In 7,700.0 8,300.0 09:24 09:54 3/1/2016 3/1/2016 1.10 PROD2 DRILL KOST P Dry tag billit @ 8300',PUW=37K, 8,300.0 8,301.0 09:54 11:00 Orient to 150ROHS,bring pumps online @ 1.5 BPM©3837 PSI FS, BHP=3720,Get on billit, No stalls,. Goto 1 FPH auto drilling 3/1/2016 3/1/2016 0.50 PROD2 DRILL KOST P Go to 2 FPH for 1 foot 8,301.0 8,302.0 11:00 11:30 3/1/2016 3/1/2016 0.30 PROD2 DRILL KOST P Go to 3 FPH, 1.5 BPM @ 3840 PSI 8,302.0 8,303.0 11:30 11:48 FS 3/1/2016 3/1/2016 0.30 PROD2 DRILL DRLG P 8303 Control drill with 1K DHWOB 8,303.0 8,313.0 11:48 12:06 3/1/2016 3/1/2016 0.30 PROD2 DRILL DRLG P Drill ahead, 1.5 BPM @ 3588 PSI FS, 8,313.0 8,340.0 12:06 12:24 BHP=3607 3/1/2016 3/1/2016 0.10 PROD2 DRILL WPRT P PUH to drift billit area, PUW=37K 8,340.0 8,340.0 12:24 12:30 3/1/2016 3/1/2016 4.60 PROD2 DRILL DRLG P 8340', Drill, 1.5 BPM @ 3770 PSI FS, 8,340.0 8,690.0 12:30 17:06 BHP=3644 3/1/2016 3/1/2016 1.20 PROD2 DRILL WPRT P Wiper trip,PUW=44K, RBIH @ 17:45. 8,690.0 8,690.0 17:06 18:18 3/1/2016 3/1/2016 4.25 PROD2 DRILL DRLG P Drill ahead, 1.5 BPM @ 4080 PSI FS, 8,690.0 9,110.0 18:18 22:33 BHP=3689,CTW=7K,WOB=1.7K, ROP=100. 3/1/2016 3/1/2016 0.85 PROD2 DRILL WPRT P Wiper to 8,350', PUW=44K, RBIH @ 9,110.0 9,110.0 22:33 23:24 23:05 3/1/2016 3/2/2016 0.60 PROD2 DRILL DRLG P Drill ahead, 1.49 BPM @ 3940 PSI 9,110.0 9,170.0 23:24 00:00 FS,BHP=3710,CTW=6.5K, WOB=1.4K,ROP=95. 3/2/2016 3/2/2016 2.80 PROD2 DRILL DRLG P Drill ahead, 1.49 BPM @ 4020 PSI 9,170.0 9,510.0 00:00 02:48 FS, BHP=3735,CTW=3.5K, WOB=1.5K, ROP=95. Pumped 5 x 5 sweep. 3/2/2016 3/2/2016 1.50 PROD2 DRILL WPRT P Wiper trip for tie-in,tie-in to RA for+5' 9,510.0 9,510.0 02:48 04:18 correction,RBIH,sat down 8,305'. PUH,try again, no issue,continue in hole. 3/2/2016 3/2/2016 1.40 PROD2 DRILL DRLG P Drill ahead, 1.49 BPM @ 3940 PSI 9,510.0 9,698.0 04:18 05:42 FS,BHP=3755,CTW=5.5K, WOB=1.4K,ROP=150.Start pumping new mud system. New mud @ bit 9591' 3/2/2016 3/2/2016 0.20 PROD2 DRILL WPRT P Mini Wiper, PUW=52K, Dragging 47- 9,698.0 9,698.0 05:42 05:54 48K 3/2/2016 3/2/2016 2.60 PROD2 DRILL DRLG P Drill, 1.51 BPM @3400 PSI FS, 9,698.0 9,767.0 05:54 08:30 BHP=3730 Page 12/14 Report Printed: 3/16/2016 Iterations Summary (with Timelog Depths) Drilling 3G-04 ConocoPhiilips i �k k.ro 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)` 3/2/2016 3/2/2016 1.70 PROD2 DRILL WPRT P 9767 wiper to 7750 with sweeps, 9,767.0 9,767.0 08:30 10:12 PUW=52K,Clean trip up set down in billit area 8304 with pump off.PUH and run past billet clean 3/2/2016 3/2/2016 4.00 PROD2 DRILL DRLG P 9767',Drill, 1.5BPM @ 3592 PSI FS, 9,767.0 9,970.0 10:12 14:12 BHP=3756,RIW=6.4K,DHWOB=1 K 3/2/2016 3/2/2016 0.20 PROD2 DRILL WPRT P Mini Wiper,Stacking, PUW=54K 9,970.0 9,970.0 14:12 14:24 3/2/2016 3/2/2016 1.00 PROD2 DRILL DRLG P 9970', Drill, 1.51 BPM @ 3595 PSI 9,970.0 9,983.0 14:24 15:24 FS, BHP=3765, RIW=4.5K, DHWOB=1K 3/2/2016 3/2/2016 0.40 PROD2 DRILL WPRT P Low weight transfer-low ROP, Mix up 9,983.0 9,983.0 15:24 15:48 50 BBI beaded pill-send first 25 down hole,Wipe uphole 3/2/2016 3/2/2016 0.10 PROD2 DRILL DRLG P Drill, 1.5 BPM @ 3711 PSI FS, 9,983.0 9,989.0 15:48 15:54 BHP=3800, RIW=6K, DHWOB=1.2K, Beatles around BHA,ROP=40FPH 3/2/2016 3/2/2016 2.70 PROD2 DRILL DRLG P Pump 20 BBI bead pill,Alternate 9,989.0 10,160.0 15:54 18:36 3OBBIs Mud-20 BBIs beads. Continue drilling 1.50 BPM,@ 3,860 psi,CTW=4.5K,WOB=1.4K,ROP=80. 3/2/2016 3/2/2016 1.35 PROD2 DRILL WPRT P Wiper trip to 8,400'.PUW=48K,RBIH 10,160.0 10,160.0 18:36 19:57 @ 19:18. Flush choke. 3/2/2016 3/2/2016 2.30 PROD2 DRILL DRLG P Drill ahead: 1.53 BPM @ 3,860 psi, 10,160.0 10,360.0 19:57 22:15 BHP=3,760 psi,CTW=2.5K, WOB=1.4K, ROP=80-90.Started losing weight transfer,pump another 20 bbl beaded pill,regained surface weight. 3/2/2016 3/3/2016 1.75 PROD2 DRILL WPRT P Wiper for tie-in,PUW=45K,log RA for 10,360.0 10,360.0 22:15 00:00 +11 5'correction,start back in hole. 3/3/2016 3/3/2016 0.25 PROD2 DRILL WPRT P Continue back in hole 10,360.0 10,360.0 00:00 00:15 3/3/2016 3/3/2016 2.10 PROD2 DRILL DRLG P BOBD:Pumping 1.49 BPM @ 3,925 10,360.0 10,560.0 00:15 02:21 BPM, BHP=3,780 PSI,CTW=2.5K, WOB=1.2K,ROP=100.Continue to pump 20 bbl beaded pills as needed to maintain string weight. 3/3/2016 3/3/2016 0.75 PROD2 DRILL WPRT P Wiper trip to 8,400', PUW=43K,RBIH 10,560.0 10,560.0 02:21 03:06 @ 02:40. 3/3/2016 3/3/2016 1.95 PROD2 DRILL DRLG P Drill ahead: 1.49 BPM @ 3,975 BPM, 10,560.0 10,760.0 03:06 05:03 BHP=3,850 PSI,CTW=2K, WOB=1.1K,ROP=90. 3/3/2016 3/3/2016 0.60 PROD2 DRILL WPRT P Wiper trip to 9760',PUW=44K,RBIH. 10,760.0 10,760.0 05.03 05:39 3/3/2016 3/3/2016 1.10 PROD2 DRILL DRLG P 10760',Drill, 1.48 BPM @ 3805 PSI 10,760.0 10,817.0 05:39 06:45 FS,BHP=3842 3/3/2016 3/3/2016 2.70 PROD2 DRILL WPRT P Wiper#3 to window with tie in for+7' 10,817.0 10,820.0 06:45 09:27 correction, PUW=41 K,Clean trip up and down 3/3/2016 3/3/2016 3.00 PROD2 DRILL DRLG P 10,820', Drill, 1.43 BPM @ 3896 PSI 10,820.0 10,966.0 09:27 12:27 FS,BHP=3820 3/3/2016 3/3/2016 0.50 PROD2 DRILL WPRT P Mini Wiper, PUW=50K 10,966.0 10,966.0 12:27 12:57 3/3/2016 3/3/2016 0.90 PROD2 DRILL DRLG P 10966,Drill to TD @ 11,000', Pump 10,966.0 11,000.0 12:57 13:51 10 X 10 Sweeps Page 13/14 Report Printed: 3/16/2016 „, Drilling! operations Summary (with Timelog•pths) &W 3G-04 ronacoPhilli•ps 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) 3/3/2016 3/3/2016 1.00 PROD2 DRILL WPRT P Wiper trip to swab 11,000.0 8,350.0 13:51 14:51 3/3/2016 3/3/2016 1.10 PROD2 DRILL DLOG P MADD Pass 8,350.0 7,860.0 14:51 15:57 3/3/2016 3/3/2016 1.90 PROD2 DRILL WPRT P Continue wiper to swab 7,860.0 72.5 15:57 17:51 3/3/2016 3/3/2016 1.00 PROD2 DRILL RGRP P Change out encoder on injector, 72.5 72.5 17:51 18:51 chage out hydraulic,reset depth. 3/3/2016 3/4/2016 5.15 PROD2 DRILL TRIP P RBIH for corrected TD,tie-in to K1 for 72.5 11,003.0 18:51 00:00 +1'correction,continue in hole,start pumping beads,tag bottom,corrected TD @ 11,003'. 3/4/2016 3/4/2016 2.05 PROD2 DRILL CIRC P POOH laying beaded liner 11,003.0 65.5 00:00 02:03 pill/completion fluid. Paint EOP flags @ 7,490'&4,172',continue OOH. 3/4/2016 3/4/2016 0.50 PROD2 DRILL OWFF P Flow check,no flow. 65.5 65.5 02:03 02:33 3/4/2016 3/4/2016 2.20 PROD2 DRILL PULD P LD BHA#14,prep floor to run liner, 65.5 0.0 02:33 04:45 maintenance,change-out UQC,check pack-off. 3/4/2016 3/4/2016 4.50 COMPZ2 CASING PUTB P MU AL1 liner assembly: Bull nose, 0.0 3,460.2 04:45 09:15 119 jts slotted,shorty deployment sleeve. 3/4/2016 3/4/2016 1.20 COMPZ2 CASING PULD P Liner in hole, PJSM P/U coil track, 3,460.2 3,504.4 09:15 10:27 M/U to liner and surface test 3/4/2016 3/4/2016 1.20 COMPZ2 CASING TRIP P Trip in hole 3,504.4 7,612.7 10:27 11:39 3/4/2016 3/4/2016 0.10 COMPZ2 CASING DLOG P Correct at flag-8.3' 7,612.7 7,604.4 11:39 11:45 3/4/2016 3/4/2016 1.20 COMPZ2 CASING TRIP P Continue in hole 7,604.4 11,003.0 11:45 12:57 3/4/2016 3/4/2016 0.90 COMPZ2 CASING CIRC P 11003,tag up, Pumps on 1.4 @ 4300 11,003.0 7,528.0 12:57 13:51 PSI, PUW=36K, Roll hole to seawater, correct counters to 7528 3/4/2016 3/4/2016 3.75 COMPZ2 CASING TRIP P Trip out on seawater, F/P tubing at 7,528.0 34.8 13:51 17:36 2500'to surface,at surface.Switch to generator power. 3/4/2016 3/4/2016 1.00 COMPZ2 CASING RGRP T Troubleshoot generator issues 34.8 34.8 17:36 18:36 3/4/2016 3/4/2016 2.25 COMPZ2 CASING PULD P PJSM. PUD BHA#15,remove UQC 34.8 0.0 18:36 20:51 checks, LD tools. 3/4/2016 3/4/2016 1.65 DEMOB WHDBOP MPSP P PJSM. RU and set BPV,WHP below 0.0 0.0 20:51 22:30 BPV is 1150 psi,LD lubricator. 3/4/2016 3/5/2016 1.50 DEMOB WHDBOP RURD P PJSM. Flush lines,blow down coil,jet 0.0 0.0 22:30 00:00 BOP stack. 3/5/2016 3/5/2016 2.00 DEMOB WHDBOP RURD P Finish flushing stack. Perform RD 0.0 0.0 00:00 02:00 checklist. 3/5/2016 3/5/2016 1.00 DEMOB WHDBOP NUND P PJSM. ND BOP stack and secure 0.0 0.0 02:00 03:00 stack.Check tree flange bolts,total of eight bolts found loose,two at SSSV flange,three at between swabs,and three at master.45 mins to tighten. Load and secure tree. Rig release:03:00 on 3/5/16 Page 14/14 Report Printed: 3/16/2016 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3G Pad 3G-04AL1 50-103-20143-60 Baker Hughes 1 NTEQ i Definitive Survey Report HUGHES 04 March,2016 • . ConocoPhillips VAIN ConocoPhillips Definitive Survey Report BHUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3G-04 Protect: Kuparuk River Unit TVD Reference: 3G-04 @ 90.00usft(3G-04) 1. Site: Kuparuk 3G Pad MD Reference: 3G-04 @ 90.00usft(3G-04) Well: 30-04 North Reference: True s Wellbore: 3G-04A Survey Calculation Method: Minimum Curvature If Design: 3G-04A Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level til Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor .„,, Well 3G-04 Well Position +N/-S 0.00 usft Northing: 5,988,560.55usft Latitude: 70°22'47.926 N +E/-W 0.00 usft Fasting: 498,675.12usft Longitude: 150°0'38.779 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft I Wedbora 3G-04AL1 F ;' Maw " Model Naafe Satttple Date Declination gip"Aligle s Field Strength I C) "€"" (nT) I BGGM2015 3/1/2016 1842 80.98 57488 Design 3G-04AL1 '' Audit Notes: I Version: 1.0 Phase: ACTUAL Tie On Depth: 8,290.72 i Vertical Section: Depth From(TVD) (usft) (usft) (usft) te) 90.00 0.00 0.00 330.00 i Survey Program Date 3/4/2016 From To $prytly[.: Survey (usft) (usft) Survey(Wellbore) Tool Name Desctipgon Sten Date End Oats 100.00 7,700.00 3G-04(3G-04) Copy of GYD-CT-CMS Gyrodata cont ca m/s 1/12/2001 7,718.00 8,290.72 3G-04A(3G-04A) MWD MWD-Standard 2/20/2018 2/29/2016 . 1 830000 1097216 3G04AL1(3G-04AL1) MWD MWD-Standard 3/1/2016 3/4/2018 3/4/2016 4:01:O04,6l,4 Page 2 COMPASS 5000 l Build 74 . • ConocoPhillips Kill ConocoPhillips Definitive Survey Report BlUCjq/�E$ ;Company:n ' ConocoPhillips y: Con ocoPhillips(Alaska)Inc.-Ku p2 Local Co-ordinate Reference: Well 30-04 Project. Kuparuk River Unit TVD Reference: 3G-04 @ 90.00usft(30-04) y:, Site: ',',Kuparuk 3G Pad MD Reference: 30-04 @ 90.00usft(3G-04) Welt 30-04 North Reference: True €Wellbore: '3G-04A Survey Calculation Method: Minimum Curvature Design: 3G-04A Database: EDM Alaska NSK Sandbox Survey....... ?. Map Map Vertical £. 1 MD Inc Azi ND TVDSS 1-N(S +E1-W DLS Northing Fasting Section Survey Tool Name Annotation 3 (usft) 11 (°) Watt). (usiti (usft) (usto (ft). ot) mow) Ih) 1y 8,290.72 94.12 282.00 5,851.16 5,761 16 -4,87623 208.10 5,983,684.77 498,882.34 5.84 -4,326.99 MWD(2) TIP 8,300.00 93.81 281.66 5,850.52 5,76052 -4,874.33 199.04 5,983,686.67 498,873.28 4.95 -4,320.82 MWD(3) KOP 3 8,331.06 88.86 284.00 5,849.79 5,759.79 -4,867.44 168.78 5,983,693.57 498,843.02 17.63 -4,299.72 MWD(3) 3 8,359.98 86.71 285.00 5,850.91 5,760.91 4,860.20 140.80 5,983,700.81 498,815.05 8.20 -4,279.46 MWD(3) 3 8,390.11 83.66 286.00 5,853.44 5,763.44 -4,852.18 111.87 5,983,708.83 498,786.12 10.65 -4,258.05 MWD(3) 8,420.32 80.99 286.40 5,857.47 5,767.47 -4,843.83 83.13 5,983,717.19 498,757.38 8.93 -4,236.44 MWD(3) 8,450.28 79.03 285.30 5,862.67 5,772.67 4,835.77 54.75 5,983,725.25 498,729.00 7.47 -4,215.27 MWD(3) 8,480.26 79.60 282.83 , 5,868.23 5,778.23 -4,828.61 26.17 5,983,732.41 498,700.43 8.32 4,184.79 MWD(3) 8,511.24 79.97 282.24 5,873.72 5,783.72 4,822.00 -3.59 5,983,739.04 498,670.68 2.22 -4,174.18 MWD(3) 33 8,540.32 81.03 284.74 5,878.52 5,788.52 4,815.31 -31.48 5,983,745.73 498,642.79 9.23 -4,154.44 MWD(3) 33 • 8,570.28 82.61 285.93 5,882.79 5,792.79 -4,807.46 -60.08 5,983,753.58 498,614.20 6.58 4,133.35 MWD(3) 3 8,600.26 85.24 287.48 5,885.96 5,795.96 -4,798.89 -88.63 5,983,762.15 498,585.65 10.17 -4,111.65 MWD(3) 8,630.32 87.45 288.50 5,887.88 5,797.88 -4,789.63 -117.16 5,983,771.42 498,557.13 8.09 4,089.36 MWD(3) 8,660.28 88.80 290.50 5,888.86 5,798.86 -4,779.63 -145.38 5,983,781.42 498,528.91 8.05 -4,066.59 MWD(3) 3 8,690.49 88.43 293.79 5,889.59 5,799.59 -4,768.25 -173.35 5,983,792.81 498,500.94 10.96 -4,042.75 MWD(3) 1 8,720.35 87.27 296.63 5,890.71 5,800.71 -4,755.54 -200.34 5,983,805.52 498,473.95 10.27 -4,018.25 MWD(3) 3 8,750.46 86.50 298.68 5,892.34 5,802.34 -4,741.59 -226.97 5,983,819.47 498,447.33 7.26 -3,992.85 MWD(3) j3 8,780.32 87.20 302.15 5,893.98 5,803.98 -4,726.50 -252.68 5,983,834.57 498,421.63 11.84 -3,966.93 MWD(3) d 8,810.39 87,57 300.94 5,895.36 5,805.36 -4,710.78 -278.28 5,983,850.29 498,396.03 4.20 -3,940.52 MWD(3) dd 8,840.51 87.45 298.71 5,896.67 5,806.67 -4,695.82 -304.38 5,983,865.26 498,369.94 7.41 -3,914.51 MWD(3) 8,870.46 88.71 301.97 5,897.67 5,807.67 4,680.70 -330.21 5,983,880.38 498,344.11 11.66 -3,868.50 MWD(3) 8,900.36 88.34 304.21 5,898.44 5,808.44 -4,664.38 -355.25 5,983,896.70 498,319.08 7.59 -3,861.85 MWD(3) 8,930.44 89.69 306.23 5,898.96 5,808.96 -4,647.04 -379.82 5,983,914.04 498,294.51 8.08 -3,834.54 MWD(3) 8,960.52 91.51 308.87 5,898.64 5,808.64 4,628.71 -403.67 5,983,932.37 498,270.68 10.66 -3,806.75 MWD(3) 8,990.44 92.98 312.00 5,897.47 5,807.47 -4,609.32 -426.42 5,983,951.76 498,247.93 11.55 -3,778.58 MWD(3) 9,020.29 94.06 314.77 5,895.64 5,805.64 -4,586.86 448.07 5,983,972.23 498,226.28 994 -3,750.03 MWD(3) 3 J 9,050.53 94.31 317.09 5,893.43 5,803.43 -4,567.19 469.04 5,983,993.90 498,205.31 7.70 -3,720.78 MWD(3) 9,080.52 94.46 320.39 5,891.13 5,801.13 -4,544.72 -488.76 5,984,016.37 498,185.60 10.98 -3,691.46 MWD(3) 9,110.36 93.50 323.51 5,889.06 5,799.06 -4,521.28 -507.11 5,984,039.81 498,167.26 10.92 -3,661.99 MWD(3) 3 9,140.33 90.77 325.67 5,887.95 5,797.95 -4,496.87 -524.46 5,984,064.22 498,149.92 11.61 -3,632.18 MWD(3) 3/4/2016 4..o11)oPM Page 3 COMPASS 5000.1 Build 74 0 • ConocoPhillips Vail ConocoPhillips Definitive Survey Report BAKE Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 30-04 Project Kuparuk River Unit TVD Reference: 30-04 l j 90.00usft(30-04) Site: Kuparuk 3G Pad MD Reference: 30-04(4190.00usft(30-04) , Well: '.3G-04 North Reference: True Wellbore:.. 30-04A Survey Calculation Method: - Minimum Curvature Design: "30-04A Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W DLS Northing basting Section Survey Tool Name Annotation Wait)I 1°) (1 (usft) (usft) (ustt) (usft) !hl Iftl (°n0011 {ft) 617046 91.38 327.57 5,887.38 5,797.38 -4,471.72 -541.03 5,984,089 37 498,133.35 6.62 -3,602.11 MWD(3) 9,200.40 91.41 331.28 5,886.65 5,796.65 -4,44595 -556.25 5,984,115.14 498,118.14 12.39 -3,572.18 MWD(3) 9,230.77 90.61 334.63 5,886.12 5,796.12 -4,418.91 -570.06 5,984,142 18 498,104.34 11.34 -3,541.86 MWD(3) 9,260.53 90.64 337.53 5,885.79 5,795.79 -4,391.71 -582.12 5,984,169.38 498,092.28 9.74 -3,512.27 MWD(3) 9,29068 90.83 336.19 5,885.41 5,795.41 4,363.99 -593.97 5,984,197.10 498,080.44 4.49 -3,482.34 MWD(3) 9,32076 91.W 334.49 5,884.90 5,794.90 4,336.66 -606.52 5,984,224.43 498,067.90 5.71 -3,45240 MWD(3) 9,350.51 91.63 333.32 5,884.20 5,794.20 -4,309.95 -619.60 5,984,251 14 498,054.82 4.34 -3,422.73 MWD(3) 9,380.60 90.89 332.43 5,883.54 5,793.54 4,283.18 -633.31 5,984,277 91 498,041.11 3.85 -3,392.68 MWD(3) 9,410.54 89.91 331.56 5,883.33 5,793.33 4,256.74 -647.37 5,984,304.35 498,02706 4.38 -3,362.76 MWD(3) l 9,440.75 89.26 329.25 5,883.55 5,793.55 -4,230.48 -662.29 5,984,330.61 498,012.15 7.94 -3,332.56 MWD(3) ) 9,470.33 89.66 327.90 5,883.83 5,793.83 -4,205.24 -677.71 5,984,355.85 497,996.73 4.76 -3,302.99 MWD(3) , f 9,500.74 90.71 328.16 5,883.73 5,793.73 -4,179.44 -693.81 5,984,381.65 497,980.64 3.56 -3,272.60 MWD(3) 9,530.74 89.51 327.70 5,883.67 5,793.67 -4,154.02 -709.74 5,984,407.07 497,964.72 4.28 -3,242.62 MWD(3) , 9,560.85 90.28 326.69 5,883.73 5,793.73 -4,128.71 -726.05 5,984,432.38 497,948.41 4.22 -3,212.54 MWD(3) 9,590.66 91.17 326.47 5,883.35 5,793.35 -4,103.83 -742.47 5,984,457.26 497,932.00 308 -3,182.79 MWD(3) I f 9,620.55 89.60 329.51 5,883.15 5,793.15 -4,078.49 -758.31 5,984,482.60 497,916.16 11.45 -3,152.92 MWD(3) 9,650.74 90.58 334.24 5,883.10 5,793.10 4,051.87 -772.54 5,984,509.22 497,901.94 16.00 -3,122.76 MWD(3) • 9,680.56 90.65 338.04 5,882.78 5,792.78 -4,024.61 -784.60 5,984,536.48 497,889.89 12.74 -3,093.11 MWD(3) 9,710.43 90.65 341.71 5,882.44 5,792.44 -3,996.57 -794.87 5,984,564.52 497,879.62 12.29 -3,063.69 MWD(3) 9,737.30 90.25 345.93 5,882.23 5,792.23 -3,970.77 -802.36 5,984,590.32 497,872.14 15.78 -3,037.61 MWD(3) 9,770.82 8923 349.37 5,882.38 5,792.38 -3,938.03 -809.53 5,984,623.05 497,864.98 10.70 -3,00567 MWD(3) 9,800.71 89.14 35211 5,882.81 5,792.81 -3,908.54 -814.34 5,984,652.55 497,860.17 9.17 -2,977.72 MWD(3) 9,830.70 88.71 354.09 5,883.37 5,793.37 -3,878.77 -817.94 5,984,682.31 497,856.58 6.75 -2,950.15 MWD(3) 9,860.94 88.62 356.63 5,884.08 5,794.08 -3,848.64 -820.38 5,984,712.44 497,854.14 8.40 -2,922.83 MWD(3) 9,890.72 87.79 359.48 5,885.01 5,795.01 -3,818.90 -821.39 5,984,742.18 497,853.13 9.96 -2896.56 MWD(3) 9,920.61 89.20 359.86 5,885.79 5,795.79 -3,789.02 -821.57 5,984,772.06 497,852.97 4.89 -2,870.60 MWD(3) 9,952.68 91.14 358.46 5,885.70 5,795.70 -3,756.95 -822.04 5,984,804.12 497,852.50 7.46 -2,842.60 MWD(3) 9,980.72 88.77 358.09 5,885.72 5,795.72 -3,728.93 -822.88 5,984,832.14 497,851.66 8.55 -2,817.91 MWD(3) 10,010.75 87.21 355.75 5,886.77 5,796.77 -3,698.96 -824.49 5,984,862.10 497,850.06 9.36 -2,791.15 MWD(3) 10,040.84 87.45 353.55 5,888.18 5,798.18 -3,669.04 -827.29 5,984,892.02 497,847.26 7.35 -2,763.83 MWD(3) 10,070.78 87.51 351.19 5,889.49 5,799.49 -3,639.39 -831.27 5,984,921.67 497,843.29 7.88- -2,736.18 MWD(3) 5/412016 4.731:OOPhf Page 4 COMPASS 5000.1 Build 74 • • ConocoPhillips ConocoPhillips Definitive Survey Report HBIkKER UGHES Company:, ConocoPhillips(Alaska)Inc.-Ku p2 Local Co-ordinate Reference: Well 3G-04 Project: Kuparuk River Unit TVD Reference: 3G-04 @ 90.0ousft(3G-04) 'Site: Kuparuk 3G Pad MD Reference: 3G-04©90.00usft(3G-04) '-=Well: 3G-04 North Reference: True Wellbore: 3G-04A Survey Calculation Method: '-Minimum Curvature Design: 3G-04A Database: EDM Alaska NSK Sandbox "Survey .... , y,. Map Map Vertical . MD MA - AM „ND- TVDSS +NiS +EI-W DLS Northing Easting Section SurveyTool Norm : Annotation tush}' (') (7 .. � (us") (usft) (usft) O Ifq (°1100) (ft) 10,100.50 88.50 348.72 5,890.53 5,800.53 -3,610.15 -836.45 5,984950 91 497,838.12 8.95 -2,708.26 MWD(3) 333 10,130.28 90.03 346.32 5,890.91 5,800.91 -3,581.08 -842.88 5,984,979.98 497,831.69 9.56 -2,67987 MWD(3) 10,160.60 91.72 344.06 5,890.45 5,800.45 -3,551.77 -550.63 5,985,009.28 497,823.95 9.31 -2,650.61 MWD(3) 10,190.51 83.59 343.01 5,889.06 5,79906 -3,523.12 -859.10 5,985,037.93 497,815.49 7.17 -2,621.57 MWD(3) I 10,220.52 92.58 340.46 5,887.45 5,797.45 -3,494.67 -868.49 5,985,066.38 497,806.10 9.13 -2,592.23 MWD(3) 10,250.47 92.73 338.97 5,886.06 5,796.06 -3,466.61 -878.86 5,985,094.45 497,795.74 499 -2562.74 MWD(3) 10,280.55 92.61 336.39 5,88466 5,794.66 -3,438.81 -890.27 5,985,122.24 497,784.33 8.58 -2,53296 MWD(3) 10,310.71 92.85 334.02 5,883.22 5,793.22 -3,411.47 -902.90 5,985,149.58 497,771.70 7.89 -2,50297 MWD(3) 10,340.89 93.25 333.17 5,881.61 5,791.61 -3,38447 -916.30 5,985,176.58 497,758.31 3.11 -2,47289 MWD(3) I 10,370.17 90.55 330.54 5,880.64 5,790.64 -3,358.67 -930.11 5,985,202.38 497,74451 1287 -2,443.64 MWD(3) 10,400.60 92.96 329.06 5,879.71 5,789.71 -3,33239 -945.40 5,985,228.66 497,72922 9.35 -2413.23 MWD(3) 10,430.63 90.92 329.54 5,878,68 5,788.68 -3,306.59 -960.73 5,985,254.47 497,713.90 7.04 -2,383.22 MWD(3) 10,462.62 90.25 327.96 5,878.36 5,788.36 -3,279.24 -977.32 5,985,281.81 497,697.32 5.36 -2,351.24 MWD(3) 10,490.66 88.83 324.30 5,878.58 5,788.58 -3,255.96 -992.94 5,985,305.09 497,681.70 14.00 -2,323.27 MWD(3) 10,520.55 8911 322.77 5,879.12 5,789.12 -3,231.93 -1,010.70 5,985,329.12 497,663.94 5.20 -2,293.58 MWD(3) I 10,550.64 90.80 322.91 5,879.14 5,789.14 -3,207.95 -1,028.88 5,985,353.10 497,645.78 5.64 -2,26373 MWD(3) i 10,580.72 88.96 320.57 5,879.21 5,78921 -3,184.33 -1,047.50 5,985,376.72 497,627.16 9.90 -2,233.96 MWD(3) 10,610.65 8966 320.30 5,879.57 5,78957 -3,161.26 -1,066.57 5,985,399.79 497,608.10 251 -2,204.45 MWD(3) • 10,640.66 88.90 319.19 5,879.94 5,789.94 -3,138.36 -1,085.96 5,985,422.69 497,588.72 4.48 -2,174.92 MWD(3) 10,670.57 88.62 321.69 5,880.59 5,790.59 -3,115.31 -1,105.00 5,985,445.75 497,569.68 8.41 -2145.44 MWD(3) 10,700.73 88.56 322.80 5,881.33 5,791.33 -3,091.47 -1,123.46 5,985,46a 59 497,551.22 3.68 -2115.56 MWD(3) 10,730.59 8979 326.56 5,881.76 5,791.76 -3,067.11 -1,140.72 5,985,493.94 497,533.97 13.25 -2,085.84 MWD(3) ( 10,760.58 89.02 328.60 5,882.08 5,792.08 -3,041.80 -1,156.80 5,985,519.26 497,517.90 7.27 -2,055.88 MWD(3) 10,789.94 89.85 330.67 5,882.36 5,79236 -3,016.47 -1,171.64 5,985,544.59 497,503.07 7.60 -2,026.52 MWD(3) 10,820.30 88.65 330.52 5,882.76 5,792.76 -2,990.03 -1,186.54 5,985,571.03 497,488.17 3.98 -1,996.17 MWD(3) 3 10,850.33 86.01 328.79 5,884.16 5,794.16 -2,964.14 -1,201.69 5,985,596.92 497,473.02 10.51 -1,966.18 MWD(3) I 10,880.20 86.07 327.17 5,886.22 5,796.22 -2,938.88 -1,21749 5,985,622.18 497,45723 5.41 -1,936.40 MWD(3) 10,910.25 86.38 32450 5,888.20 5,798.20 -2,914.07 -1,234.33 5,985,646.99 497,440.40 8.93 -1,906.49 MWD(3) 10,940.28 86.31 32203 5,890.12 5,800.12 -2890.05 -1,252.25 5,985,671.01 497,422.48 8.21 -1,876.73 MWD(3) 10,97216 86.04 319.79 5,892.24 5,802.24 -2865.37 -1,272.31 5,985,695 70 497,40243 7.06 -1,845.33 MWD(3) 11,003.00 86.04 319.79 5,894.37 5,80437 -2,841.87 -1,292.17 5,985,71a 19 497,38258 0.00 -1,815.05 PROJECTED to TD $ 9!412016 4:01:OOPM Page 5 COMPASS 5000.1 Build 74 RECEIVED• • 21 6 0 0 7 26957 w6111111MAR 21 2016 PRINT DISTRIBUTION LIST BAKER MASHIES AOGCC Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Alaska,Inc. ConocoPhillips Alaska, Inc. Ricky Elgarico.ATO 3-334. DATA LOGGED /22/201() WELL NAME 3G-04AL1 700 G Street. M K.GENDER Anchorage,Alaska 99510 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska --- LOG DATE March 4,2016 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider@bakerhughes.com TODAYS DATE March 17,2016 Revision STATUS Final Replacement: No Details: Requested by: COMPANY FIELD FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #ur rrtiN I5 #OF COPIES #OF COPIES #OF COPIES 1 BP North Slope 0 0 I 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 0 Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska I 0 I 0 I 0 I I Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 1 1 I 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 I 1 I Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 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 • • O t ® 11) LO Cn Lo ■ W cNi WI.W SM to ,,-ea U (.) v 4 N O. 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K.BENDER HUGHES _____._______________ To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 3G-04A 21 6 0 6 2 6 9 0 1 3G-04AL1 21 6007 26902 (2) 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 • • O CV O O LO t0 N NI SIN all z `IY; sz N Ul 1 WI c= C ( L Cr ct O 0. cn _as V W Na) LCL Q I- >1 — 11. ' 73 u o L a� a r O v M 72 ._ C 0 _ J N 45 c .- O . = = Q ' .- ^L ^L "ZrM tip cL o cu V O ca. a. 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(0 co O O (O 0 CO CD 0 0 O 0 CO (O (O cO CO co co O CO CO c0 co CO co CO (O O CO CO , CI E V J J J J J J C C -4 J C V V V C J V V C v v J J J J J V J J J W A A A A A A (n (n (n In (n U) 0) 0) C) 0) CO O - J V V V V C CD CO 03 03 CO 7-0 MK -I W w N O N A Cn C O) O V W n D OD O NV (An W D O W N A O A UO p n N S'o' 0 0 - C 0 Cco D 0 A F n A A A N 0 — O co CO N 0V V CO V Co co N n Co V Co C 1 A CO D -3 3 co OWN V V 0 -4 N co N O 0) co A O N O N O co A co O n CO N m 3 nnI O c () co 6 A O V 03 m Cn O Co V V CO- Co CO A N CO (n Cn A (n V (D N W V CO A cO J (O V7 Co O y (n O) O O = O O co A CO O) NN O) A A in O CO N O co O W W co N CO ..... —' co nn CO C C 0 WN3 W in CO 0 V UW CO 0 A O O 0) A W J —' CO CO CO W -4 0) 0 T C CD N CD 0 w w N N N N N N N N N N N N N) N N N N N N N) N N N N n p. O 00 CO CO 0) CO CO CO CO O O O —' -' N N N N W co W -A A A U) N U) n W W C) V 3x - A V O W W CO N) n W -' A J pp Co W O N 0 Co A J O Co Co 30 N) 0 J O OC) C N Cn W 0) Cr) OCD UU U) N A A Co W W Co Co Co Co N N N N N O W co N O W J A A ( Co Co Cn A cD A t0 J UN N N N 0) O CO O V N N 0) D N 0 co W CO 0 Co -4 N Co A C) A N) Ot 0) W Co J A N W a 0 -4 0) A co -4 -3 V 0) S3 -0 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 0) - m w co w co co co co co co co co co co co co co co co Cu CO Co Cu Co Co Co Co Co CO Co Co Co : N< .; m O pl 0 0 g Z NI' DC o 3 m IiIgI 1 n = n 01 cn to yb��p�1r1 einem _ 4rUo t , Z" S PyoF r , • hw\��\� THE STATE Alaska Oil and Gas ,�1:attk� of A Conservation Commission } _ x _,� 333 West Seventh Avenue f GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 of ALAS " Fax: 907.276.7542 www.aogcc.alaska.gov Dan Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3G-04AL1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-007 Surface Location: 2538' FNL, 4985' FEL, SEC. 24, T12N, R8E, UM Bottomhole Location: 265' FNL, 926' FEL, SEC. 26, T12N, R8E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 216-006, API No. 50-103- 20143-01-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy . Foerster Chair DATED this !amu day of January, 2016. 0 STATE OF ALASKA0 RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 1 1 2016 PERMIT TO DRILL 20 PAC 25.005 AOGCC la.Type of Work: lb.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp az lc.Specify if well is proposed for: Drill CI Lateral.C1 Stratigraphic Test ❑ Development-Oil 0. Service- Winj ❑ Single Zone Coalbed Gas ❑ Gas Hydrates ❑ Redril❑ Reentry ❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone L' Geothermal ❑ Shale Gas El 2.Operator Name: 5. Bond: Blanket 0 Single Well❑ 11.Well Name and Number: ConocoPhillips Alaska,Inc. • Bond No. UC30610• 595.Z1 g0 KRU 3G-04AL1 / 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 10900 k TVD: * 5890 Kuparuk River Field 4a. Location of Well(Governmental Section): .Q 7.Property Designation(Lease Number): ii5 Kuparuk River Oil Pool Surface: 2538'FNL,/4985'FEL,Sec.24,T12N,R8E,UM • `". ADL 255481 o?5S4'- Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1966'FNL,4395'FEL,Sec.25,T12N,R8E,UM ALK 2662 2/18/2016 Total Depth: A6 9.Acres in Property: �4 14.Distance to Nearest Property: 265'FNL,926'FEL,Sec T12N,R8E,UM SaS0 -2666.7000' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): . 90 15. Distance to Nearest Well Open Surface: x-498675 y- 5988561 Zone-y • GL Elevation above MSL(ft): 4 54 to Same Pool: 3G-14A, 1600' 16. Deviated wells: Kickoff depth: , 8200 feet 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) v fL Maximum Hole Angle: • 94 degrees Downhole: 4667 Surface:Surface: 35-05— , s,`u 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 2600 8200 5858 10900 5890 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): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 8089 6127 None 7854 5948 7890 Casing Length Size Cement Volume MD TVD Conductor/Structural 115' 16" ±200 Cu.Ft. 115' 115' Surface 3703' 9-5/8" 1685 Cu.Ft.AS III,570 Cu.Ft CI G 3793' 3018' Intermediate Production 7972' 7" 200 Cu.Ft.Class G 8062' 5724' Liner Perforation Depth MD(ft): 7640-7660,7710-7734,7754-7784 Perforation Depth ND(ft): 5786-5802,5839-5858,5873-5895 20. Attachments: Property Plat El BOP Sketch❑ Drilling Program El Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 MC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date 22.I hereby certify that the foregoing is true and the procedure approved herein will not Cody Pohler @ 265-6435 be deviated from without prior written approval. Contact Email Cody.J.Pohlerancop.com Printed Name Da Venhaus Title CTD Engineering Supervisor Ci P Signature *I-�� Phone 263-4372 Date I — II - /4 . Commission Use Only Permit to Drill API Number: y-�1 1,/ Permit Approval See cover letter for other Number: p21(a —QQ� 50- )W— 4,V1 {3—60"00 Date: k'a$ 4C.O requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane as hydrates,or gas contained in shales: d Other: Sop 71-e-5± to 4 5-00 p 5 ic1 Samples req'd: Yes❑ No 1 J Mud log req'd:Yes❑ No[rr 4,�h v/a r p rr t/rvu 1--/-0-- ti's t P-0Z SD b r 5 9-IzS measures: Yes© No L { Directional svy req'd:Yes[ 'No Spacing exception req'd: Yes❑ No Inclination-only svy req'd:Yes❑ No Post initial injection MIT req'd:Yes❑ No❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: l/ 1/ //2(//& P/4 l/IN1' e Submit Form and Form 10-401(Revised 11/ 015) This permit is valid for 24 months from the date of ap royal(20 AAC 25.005(g)) Attachments in Duplicate ORG1NAL • • s ConocoPhilli p Alaska P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 January 5, 2016 Commissioner-State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill a dual-lateral out of the Kuparuk Well 3G-04 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin as early as January 22,2016. The CTD objective will be to drill two laterals(3G- 04A, 3G-04AL1), targeting the A2 and A3 sand intervals. Attached to this application are the following documents: — Permit to drill application form 10-401 for 3G-04a&3G-04AL1 — detailed summary of operations — directional plans — proposed schematic The application for sundry approval(10-403)for 3G-04 was submitted on 12/30/15. If you have any questions or require additional information please contact me at 907-265-6435. Sincerely, C72(,)7?o&x., Cody Pohier Coiled Tubing Drilling Engineer • • Kuparuk CTD Laterals NAAOAS ALASKA Den*w 3G-04A & 3G-04AL1 Application for Permit to Drill Document 2RC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(1)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 MC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 MC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 MC 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 MC 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 5 (Requirements of 20 AAC 25.005(c)(13)) 5 Summary of Operations 5 Pressure Deployment of BHA 6 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(b)) 6 16. Attachments 7 Attachment 1: Directional Plans for 3G-04A&AL1 7 Attachment 2: Current Well Schematic for 3G-04 7 Attachment 3: Proposed Well Schematic for 3G-04A&AL1 7 Page 1 of 7 1/11/2016 • • PTD Application: 3G-04A & 3G-04AL1 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 3G-04A and 3G-04AL1. Both laterals will be classified as "Development—Oil"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 3G-04A and 3G-04AL1. 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 operp ions. 4cfl" P — Pipe rams, blind rams and the CT pack off will be pr re tested to 250 psi and to 4500 psi. Using the maximum formation pressure in the area of 4 psi in 3G-12, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 3 psi/ See the"Drilling Hazards Information and Reservoir Pressure" section for more de ils. 3565Lt 0 kti — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Expected Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) Well 3G-04 has a formation pressure of 9 ppg EMW as of 5/31/2015 (2670 psi at 5714' TVD). The maximum potential formation pressure in the area is to the north, well 3G-12 with a 13.8 ppg EMW as of 1/2/2016 (4167 psi at 5816' TVD). Along the well path we drill near wells 3G-14A and 3G-19A, both have been LTSI. Well 3G-14A is a rock producer and has a WRP plug installed, it should not pose any pressure risk and well 3G-19A had a formation pressure of 7.9 ppg EMW as of 7/25/2014 (2299 psi at 5585' TVD). Near the toes of the laterals wells 3G-23 and 3G-12 could influence the pressure we encounter. Well 3G-23 has a formation pressure of 12.8 ppg EMW as of 4/21/2015 (3893 psi at 5859' TVD) however is 3970' away and has baffling faults in between the laterals. Well 3G-12 is 3050 feet away from the 3G-04 laterals at the closest point. The maximum reservoir pressure we expect to see while drilling along the well path is 11.8 ppg EMW. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) Well 3G-12 to the north has been injecting lean gas (2015) and has a clear communication with 3G-04. Both planned laterals are to the northwest; gas zones could be encountered while drilling. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The largest, expected risk of hole problems in the 3G-04 laterals will be shale instability across the faults, managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossing. Along with shale instability as mentioned above the higher pressure risk will also be taken into consideration for potential hole problems. Again MPD will be used to mitigate the high pressure risk. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) Page 2 of 7 1/11/2016 • • Loepp, Victoria T (DOA) From: Pohler, Cody J <Cody.J.Pohler@conocophillips.com> Sent: Monday,January 25, 2016 8:57 AM To: Loepp,Victoria T(DOA) Subject: RE: KRU 3G-04A(PTD 216-006) Max Reservoir Pressure Victoria, I apologize for the late response,4578 psi is a typo from an older pressure in the well.The most up to date 3G-12 formation pressure is 4167 psi.This would result in the maximum potential surface pressure assuming a gas gradient of 0.1 psi/ft,would be 3585 psi. Thank you, Cody From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@)alaska.gov] Sent: Wednesday, January 20, 2016 2:57 PM To: Pohler, Cody 3 Subject: [EXTERNAL]KRU 3G-04A(PTD 216-006) Max Reservoir Pressure Cody, Two different formation pressures are quoted for 3G-12: 4578 psi and 4167 psi. Please clarify. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCa?alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.LoeQO@alaska.gov 1 • • PTD Application: 3G-04A & 3G-04AL1 N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(f), thru-tubing drilling operations need not perform additional formation integrity tests. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS 3G-04A 8,200' 10,800' 5,768' 5,757' 2g/ , 4.7#, L-80, ST-L slotted liner; aluminum billet on top 2%", 4.7#, L-80, ST-L slotted liner; 3G-04AL1 7,552' 10,900' 5,630' 5,800' shorty deployment sleeve in 3-1/2" tubing tail Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (PO MD MD TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 36' 115' 36' 115' 1,640 630 Surface 9-5/8" 36 J-55 BTC 35' 3,794' 35' 3,018' 3,520 2,020 Production 7" 26.0 J-55 BTC 35' 8,062' 35' 6,106' 4,980 4330 Tubing 3-1/2" 9.3 L-80 EUE 31' 7,557' 31' 5,724' 10,160 10,530 7. Diverter System Information (Requirements of 20 AA C 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AA C 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-weighted FloVis water-based mud (8.9 ppg) — Drilling operations: Chloride-weighted FloVis water-based mud (8.9 ppg). This mud weight does not hydrostatically overbalances the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: BHA's will be deployed using standard pressure deployments and the well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over-balance and maintain wellbore stability while running completions- Page 3 of 7 1/11/2016 • • PTD Application: 3G-04A & 3G-04AL1 Managed Pressure Drilling Practice Managed pressure drilling (MPD)techniques will be employed to maintain a constant overbalanced pressure on the openhole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". The targeted MPD BHP will be 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 3G-04 Window(7,718' MD, 5,845' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation 2670 psi 2670 psi Pressure(9 ppg) Mud Hydrostatic(8.9 ppg) 2705 psi 2705 psi Annular friction (i.e. ECD, 695 psi 0 psi 0.090 psi/ft) Mud + ECD Combined 3400 psi 2705 psi (no choke pressure) (overbalanced —730 (underbalanced —36 psi) psi) Target BHP at Window 3588 psi 3588 psi (11.8 ppg) Choke Pressure Required 188 psi 883 psi to Maintain Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is for land-based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Page 4 of 7 1/11/2016 • • PTD Application: 3G-04A & 3G-04AL1 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 3G-04 is a Kuparuk A-sand producer well equipped with 3'/2"tubing and 7"production casing. Two laterals will be drilled to the north west of the parent well bore with the laterals targeting the different A2 and A3 sand lobes. These laterals will improve the sweep in the producer pattern where 3G-14A and 3G-19A have been long term shut in. Prior to CTD operations,the 3-1/2"tubing tail will be perforated and the D nipple at 7,545' MD will be milled out to a 2.80"ID.The existing A-sand and C-sand perfs will be squeezed with cement to provide a means to kick out of the 7"casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A-sand and C-sand perfs in this manner. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 7,748' MD and set a mechanical whipstock in the 2.80"pilot hole to kick off at 7,718' MD. Both laterals will be completed with 2-3/8" slotted liner from TD with the second lateral liner top located inside the 3-1/2"tubing tail. Pre-CTD Work 1. RU Slickline: dummy off gas lift mandrels. 2. RU E-line: Shoot 2' of holes in the 31/2"tubing tail at 7541' MD. 3. RU Pumping Unit: perform injectivity test down the tubing. 4. RU Service Coil: Mill out D nipple and cement squeeze the A& C sand perforations up to the perforations in the tubing tail. 5. RU Slickline: Tag top of cement and log. 6. Prep site for Nabors CDR2-AC, including setting BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 3G-04A Lateral(A3 sand to north west) a. Drill 2.80"high-side pilot hole through cement to 7,748' MD b. Caliper pilot hole c. Set whipstock at 7,718' MD d. Mill 2.80"window at 7,718' MD. e. Drill 3"bi-center lateral to TD of 10,800' MD. f. Run 2%"slotted liner with an aluminum billet from TD up to 8,200' MD. 3. 3G-04AL1 Lateral(A2 sand) a. Kick off of the aluminum billet at 8,200' MD. b. Drill 3"bi-center lateral to TD of 10,900' MD. c. Run 23/8"slotted liner from TD up to 7,552' MD, above the whipstock and in the 3-1/2"tubing. 4. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV. 2. Install GLV's. 3. Return to production. Page 5 of 7 1/11/2016 ! • PTD Application: 3G-04A & 3G-04AL1 Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick-line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 3G-04 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%". rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1B disposal facilities)or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. Page 6 of 7 1/11/2016 • • PTD Application: 3G-04A & 3G-04AL1 - Distance to Nearest Property Line(measured to KPA boundary at closest point) 3G-04A 6990' 3G-04AL1 7000' - Distance to Nearest Well within Pool yam . y 3G-04A 1610' 3G-14A 3G-04AL1 1600' 3G-14A 16. Attachments Attachment 1: Directional Plans for 3G-04A &AL1 Attachment 2: Current Well Schematic for 3G-04 Attachment 3: Proposed Well Schematic for 3G-04A &AL1 Page 7 of 7 1/11/2016 : gi_ • • • M Io N ( v , I I 0 N 0 4 4 • • eco 1 0 A'y y o = 2 v = 0 0 F, a9L91 .0 - _ m o z __1 i t- ,LI.. o .o v a I -m A g P 0 >v o I v 1 Q 1 I. >. 0 0 1 M 0 0 0 0 —c E C G • o l r + km ��• • r Iy _ 0 czt �v ��o�a I ' W F, i E• m ` ( O L,,, . I ___.__ .. / ,_ . , , , , ., ,rH. _____:_______ _...... , ____ _ , = T . , O ,..,=. _ .... _ , , . , __ ,_ ..„, 1, .2 0 Q W K M M .. ..... dhyr . _. • _. - - N >> Q 9 I O 0 CI.C.7,G .. _. r{ :- ___ _-. . _-, ,.. 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Conocomiftlps Planning Report BAKER HUGHES d , n,...„a -;,,- „,,,,,,,,,"'''"7:- = ,-- - .vst ",..arano�li' _ 1 001,--,1,,,, 0I� -, ,*-�-. war marmEmm n ii nr .., ® .F , • EDM Alaska ANC Prod Well 3G-04 'a,. 1, NADConversion =' f eance Mean Sea Level ��it,'7� ''' 3G-04 90.00usfti �- �� Kuparuk River Unit �ii � @ (3G-04) tte , 111fI Kuparuk 3G Pad ; tlill True 16I� 3G-04 f` + od ? �Minimum Curvature t a ,il, 3G-04A (L l' _�)9�L5 = l�riE, l e =_ 3G-04A wp04 ; .: , tlitt:P---' iiil@eIeib,-,--d iii!Y,h, . .. ,,'4,4 (NII6( f P'lllxo_' Kuparuk River Unit North Slope Alaska,United States _�,!.„_ ��� ,„,„umi i ; .-. .,.. �mn wuwuwwb ., 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 E i� ,��3 i" Kuparuk 3G'Pad 1, '' 11 i _ w^we ii „i i _ - ----....1,409m,,,„„„, Site Position: Northing: 5,988,559.95 usft Latitude: 70°22'47.920 N From: Map Easting: 498,724.97 usft Longitude: 150°0'37.320 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: -0.01 ° 16.t.:7'2=------- .5:'-- ''.-'-'"-,1.4-4 rimom 04i E w o,ma cr aw __ r7• oiiw , Well Position +N/-S 0.00 usft Northing: 5,988,560.55 usft Latitude: 70°22'47.926 N +El-W 0.00 usft Easting: 498,675.12 usft Longitude: 150°0'38.779 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft ((,EW, phi i ? ithJU Enn _ ^y,v::.ae�„ '� -w a a.na.iunmmnunanwraa --w.�' �uinnrm '' ��!'1111 3G 04A�. -,. ,' 'n w'+ �>viPi I:UII IIIUIIUI6MWK"�iW6iC6 ,> -�?9JN§�bH464NiMJYi ii i _ .,-17,-1----1-1,1110;122 r h ' li IFI �14 Iih91P �i t,(w' d , y { 4 1y ra l 11.1,111°1p �l ', I � F , 0 I I i . ;i iikit,,..• -7,4,,,,,,11,111,1,„_,...„....:,,z, , a I,fid,x... - _ � dsr_,,,._.80._98 57,487 4/1/2016 18.37 3G 04A wp04 1 a-,,,,°inNi Rwwmi Imwm 11�- ....,- --AnnpAiNflif,�fn r _w-r= Audit Notes: Version: Phase: PLAN Tie On Depth: 7,700.00 i --"';',1=1-'.47� N: # _ f' ' -llml I,.�I( s d "!;� ° F `*^ a� '�i` � ',7- rH. 9iPii' 611-�' t ` ' a . r t1a$I' i.' f ' P'` "04. $5� - = Vta)i;Iiit xnadwa e: r z . will Iih� ,1 ddu . + 0.00 0.00 0.00 330.00 r„ LLwrewiaaamEw,v:u w ,swrw x= w ung rtr+,.>,_ - ,. Ptah Seetf Tari5 r= i r E � NN I 1;GGi 't#F r rihai� 7 l __ ,-'-'--='!!'',,..,, I )111:;'';',;•-•-•,;X:___: PI ry '-Iq 1�'V,,,,,'',,',„,,„:,,,,'::'''.',!,..-z' � �ip � iali:!!!,- i,a 4a.�haa d"1 b1� 't (' ,,0,0, ®.,6 , II E 'L utrt _ [111101111*,-;* � 16 p I`'II(,I 1'z - II ,-...',,,-,',!'mi !IW wd_ G �t I) " a yt.,. AT ,dili�rrll�l i° 4i#I'ti�. � 6 "' q ' "'Illy Ili '� �.__, - ! I,IaiWiE! -- E,.ri3 ii Viii I • t� ti 11 !11ii!Ii�� '2-'4:- ��1Oil1� �I , mjai _,,1>rptu. a r�IP), Ii, !'I ,� � l �_, � '�14 r � '� � -- i i,� 111'11,11.,:k.� � 19',0,4r -5:-..,-.,':::',. -4.- m u, ?. � 111,,A.,-m-4.4-,k__- � �� � ,r)� 7,700.00 41.10 172.16 5,742.03 -4,696.74 591.04 0.00 0.00 0.00 0.00 7,718.00 41.08 172.07 5,755.59 -4,708.46 592.66 0.35 -0.11 -0.50 -108.71 7,739.00 45.28 172.07 5,770.90 -4,722.69 594.64 20.00 20.00 0.00 0.00 7,838.38 90.00 172.07 5,807.76 -4,811.42 607.00 45.00 45.00 0.00 0.00 8,070.00 97.75 276.43 5,785.68 -4,955.33 468.45 45.00 3.35 45.06 82.00 8,110.00 98.02 279.65 5,780.19 -4,949.79 429.23 8.00 0.67 8.05 85.00 8,210.00 95.44 282.73 5,768.47 -4,930.51 331.83 4.00 -2.58 3.08 130.00 8,330.00 91.20 284.98 5,761.53 -4,901.82 215.55 4.00 -3.53 1.88 152.00 8,430.00 89.51 288.61 5,760.91 -4,872.94 119.83 4.00 -1.69 3.62 115.00 9,330.00 90.19 324.60 5,763.41 -4,345.08 -590.84 4.00 0.08 4.00 89.00 9,630.00 91.22 336.56 5,759.71 -4,084.27 -737.93 4.00 0.34 3.99 85.00 9,930.00 90.99 348.56 5,753.90 -3,798.64 -827.68 4.00 -0.08 4.00 91.00 10,130.00 89.59 340.68 5,752.89 -3,605.97 -880.69 4.00 -0.70 -3.94 260.00 10,500.00 89.61 325.88 5,755.49 -3,276.41 -1,046.60 4.00 0.00 -4.00 270.00 10,800.00 89.62 313.88 5,757.53 -3,047.43 -1,239.57 4.00 0.00 -4.00 270.00 1/5/2016 10.13:41AM Page 2 COMPASS 5000.1 Build 74 • ConocoPhillips • i i ConocoPhillips Planning Report BAKER HUGHES "t EDM Alaska ANC Prod Cp*d i 2p . nt Well 3G-04 S4 NADConversion ;,,!,*1113p Mean Sea Level Pro Kuparuk River Unit tk R$ td j5 30-04L7o 90.00usft(30-04) Kuparuk 3G Pad Ior True 30-04 A 5luSunrerlpl+ Lpili) �p� ih Minimum Cur vature P1A' 3G-04A -04'1' 1o 04304,,,Trwr_ .77,7WAd777 M777 - ,s. �IIt7411h. En1111' 2 . °s°��1�����I (I��II _ II}�� D) ) I„(( eIDUfir �iI�,�l it�€ sA ry 7777-77-777 ,7 7,700.00 41.10 172.16 5,742.03 -4,696.74 591.04 -4,363.01 0.00 0.00 5,983,864.18 499,265.26 TIP 7,718.00 41.08 172.07 5,755.59 -4,708.46 592.66 -4,373.97 0.35 -108.71 5,983,852.46 499,266.89 KOP 7,739.00 45.28 172.07 5,770.90 -4,722.69 594.64 -4,387.29 20.00 0.00 5,983,838.23 499,268.86 End 20 dls,Start 45 dls 7,800.00 72.73 172.07 5,802.02 -4,773.98 601.79 -4,435.28 45.00 0.00 5,983,786.94 499,276.00 7,838.38 90.00 172.07 5,807.76 -4,811.42 607.00 -4,470.31 45.00 0.00 5,983,749.50 499,281.21 4 7,900.00 93.71 199.57 5,805.72 -4,872.10 600.83 -4,519.78 45.00 82.00 5,983,688.83 499,275.03 8,000.00 97.64 244.64 5,795.30 -4,944.07 535.97 -4,549.68 45.00 82.91 5,983,616.88 499,210.16 8,070.00 97.75 276.43 5,785.68 -4,955.33 468.45 -4,525.67 45.00 87.61 5,983,605.63 499,142.65 End 45 dls,Start RSM 8,100.00 97.96 278.85 5,781.58 -4,951.38 439.00 -4,507.52 8.00 85.00 5,983,609.59 499,113.20 8,110.00 98.02 279.65 5,780 19 -4,949.79 429.23 -4,501.25 8.00 85.33 5,983,611.18 499,103.43 6 8,200.00 95.70 282.42 5,769.44 -4,932.68 341.54 -4,442.59 4.00 130.00 5,983,628.31 499,015.75 8,210.00 95.44 282.73 5,768.47 -4,930.51 331.83 -4,435.86 4.00 130.33 5,983,630.47 499,006.04 7 8,300.00 92.26 284.42 5,762.43 -4,909.43 244.55 -4,373.97 4.00 152.00 5,983,651.56 498,918.78 8,330.00 91.20 284.98 5,761.53 -4,901.82 215.55 -4,352.88 4.00 152.11 5,983,659.18 498,889.78 8 8,400.00 90.01 287.52 5,760.79 -4,882.24 148.35 -4,302.32 4.00 115.00 5,983,678.77 498,822.59 8,430.00 89.51 288.61 5,760.91 -4,872.94 119.83 -4,280.00 4.00 115.03 5,983,688.08 498,794.08 9 8,500.00 89.55 291.41 5,761.49 -4,848.99 54.06 -4,226.38 4.00 89.00 5,983,712.03 498,728.32 8,600.00 89.63 295.41 5,762.20 -4,809.28 -37.69 -4,146.11 4.00 88.98 5,983,751.76 498,636.59 8,700.00 89.70 299.40 5,762.79 -4,763.26 -126.44 -4,061.88 4.00 88.95 5,983,797.79 498,547.85 8,800.00 89.78 303.40 5,763.24 -4,711.16 -211.78 -3,974.10 4.00 88.93 5,983,849.90 498,462.53 8,900.00 89.85 307.40 5,763.57 -4,653.24 -293.27 -3,883.19 4.00 88.91 5,983,907.83 498,381.06 9,000.00 89.93 311.40 5,763.75 -4,589.78 -370.52 -3,789.60 4.00 88.89 5,983,971.30 498,303.82 9,100.00 90.01 315.40 5,763.81 -4,521.08 -443.16 -3,693.79 4.00 88.89 5,984,040.00 498,231.20 9,200.00 90.09 319.40 5,763.72 -4,447.48 -510.84 -3,596.22 4.00 88.88 5,984,113.60 498,163.55 9,300.00 90.16 323.40 5,763.50 -4,369.35 -573.21 -3,497.36 4.00 88.89 5,984,191.74 498,101.19 9,330.00 90.19 324.60 5,763.41 -4,345.08 -590.84 -3,467.53 4.00 88.90 5,984,216.01 498,083.57 10 9,400.00 90.43 327.39 5,763.03 -4,287.05 -629.99 -3,397.70 4.00 85.00 5,984,274.04 498,044.44 9,500.00 90.78 331.37 5,761.98 -4,201.02 -680.90 -3,297.74 4.00 85.02 5,984,360.07 497,993.54 9,600.00 91.12 335.36 5,760.32 -4,111.66 -725.72 -3,197.94 4.00 85.06 5,984,449.43 497,948.75 9,630.00 91.22 336.56 5,759.71 -4,084.27 -737.93 -3,168.11 4.00 85.12 5,984,476.82 497,936.54 11 9,700.00 91.17 339.36 5,758.24 -4,019.41 -764.20 -3,098.81 4.00 91.00 5,984,541.68 497,910.29 9,800.00 91.09 343.36 5,756.27 -3,924.69 -796.15 -3,000.80 4.00 91.06 5,984,636.39 497,878.35 9,900.00 91.01 347.36 5,754.43 -3,827.97 -821.42 -2,904.41 4.00 91.14 5,984,733.10 497,853.10 9,930.00 90.99 348.56 5,753.90 -3,798.64 -827.68 -2,875.88 4.00 91.21 5,984,762.43 497,846.85 12 10,000.00 90.50 345.80 5,752.99 -3,730.40 -843.21 -2,809.01 4.00 -100.00 5,984,830.67 497,831.33 10,100.00 89.80 341.86 5,752.73 -3,634.37 -871.06 -2,711.93 4.00 -100.04 5,984,926.69 497,803.51 10,130.00 89.59 340.68 5,752.89 -3,605.97 -880.69 -2,682.51 4,00 -100.05 5,984,955.10 497,793.88 13 10,200.00 89.59 337.88 5,753.39 -3,540.50 -905.46 -2,613.43 4.00 -90.00 5,985,020.56 497,769.13 10,300.00 89.60 333.88 5,754.09 -3,449.25 -946.31 -2,513.98 4.00 -89.98 5,985,111.81 497,728.29 1/5/2016 10:13:41AM Page 3 COMPASS 5000.1 Build 74 �,, • ConocoPhillips .��. C4t10C0�11��t�?5 Planning Report BAKER HUGHES „ - ,yi n�i rPai rc = ji 8Ai X40 ,Ir, (�[ !�( - -, w... ., .;v. ,. - _ ,y,n ra,p ` ` EDM Alaska ANC Prod ��1tl 21; �[� t! �(i „Il ;meU 3G-04 Y NADConversion l�h�I�''�� � �� � i, l'U�� �� Mean Sea level IIII t b .r Kuparuk River Unit . )�� �, 3G-04 @ 90.00usft(3G-04) Kuparuk 3G Pad " ort efere> �� True �� 3G-04' uwey atd+�ft 4 t1� Minimum Curvature Ub ra 3G-04A m 1 � 3G-04A wp04, 104 �� , im �'I�ic"� ra„i ,ii s��muHUH,.=u � ma, � m _� �� ��� r � ..��r,w s,�.��,��..,.,w iniM�..�wi,_....�.�_ �.._, _._ s,.rrr.__� dHrc I'FI ta e ix. " � 9 r-';-t Ji 1 P19i119i IIID �llili' �°, qp -,' r _ Itilifligiliij 11T ti! ��41��,�� �r .' �ueR} .iiiIMPit ' � � �.444444444414'444""4`` 9i� iL�II>fi�h ,d'Illli,�l�t �,��� 10,400.00 89.60 329.88 5,754.80 3,361.08 993.44 2,414.06 4.00 89.95 5,985,199.98 497,681.19 10,500.00 89.61 325.88 5,755.49 -3,276.41 1,046.60 -2,314.15 4.00 -89.92 5,985,284.66 497,628.05 14 10,600.00 89.61 321.88 5,756.17 3,195.65 1,105.54 2,214.74 4.00 -90.00 5,985,365.42 497,569.13 10,700.00 89.61 317.88 5,756.86 3,119.20 1,169.96 -2,116.32 4.00 -89.97 5,985,441.87 497,504.72 10,800.00 89.62 313.88 5,757.53 3,047.43 1,239.57 2,019.37 4.00 -89.95 5,985,513.64 497,435.14 Planned TD at 10800.00 inn 4-4-44.----44.7.4441.401"4�9�l�tti�741�ij --��- tUl���IiP ,101001P1111 y JGa Jjli (�;)�� - _--�=,� a. �i"l�y hug�VH.�444,4444,44.411"44144:04:4:111114014 , t-asHa� ---(�id--- ,,,r,„ i.,�.c .. ya (�� i(�i��� i Yy;'N`a. '. r,�"'' S' a���dlNp Iyj 44 a r ( J 1 4i '' ( Ip� air;.' �,ly{ � �� :_ 'F� ' Y Iii,: ��• ate' > > 3 ¢'^ t : �-1A011110,1144:110.114()(10,11i�14 4"4"44. li ii - i4 a y a-,.-.4-74-141"4"49_' a 0 ;� �e '`�=.t j r J t r • ' III (a ub y .' of �#�t;31 0., ""- 0" 9 I li i)�� iii"rlr'Ili Hi0g9�t;�11 e a .lidp a _ WJ '8 r 1 �� "--444 ."0"41.11,444. il, >�,�,,- :a`=,F 1"ac�' ak _:. ,.'"IIH Spuf,<.>, HieH.r3ili FC: _ .4".......4411044444==4."-- 3 � ir�q y:.h,4= .,. ,. 7l����"471 __e� -61,,,,A.'''.�r 10,800.00 5,757.53 2 3/8" 2-3/8 3 N�� Y I ao11114 = 444 I) a. (h�4 'ii .z,.„ 4 III iry 1 .: .. ,,. 04 "4-4 ? �J4r i ( iiq a ` rl4 0,�4� t4� 7 G44}� 444 yr g li44444444414114414441441114 ia F J�G�i 44441 11444ilii"��15NII441114 ]''�� � ® � "aw #} 4�i it 4 -4 Qi', " d +; F�IF .�d I"441" ,„7 rc i ti r F#. I B 64.14411"" Y4e r 1 j��4I';11"g� 4 4t 6180 ® d l � 744-14.44444444.41e444.14:44.4„4_,_4444.. % _ _ _ iii p Edi ����� " a t4%4 4441i ` 18`"TM lthi1,�, ."hr,Hrr�li. .. =� _- .,. -T - _ k Ii iliiiG ,�I r= .= - _ = ' 7,700.00 5,742.03 4,696.74 591.04 TIP 7,718.00 5,755.59 -4,708.46 592.66 KOP 7,739.00 5,770.90 -4,722.69 594.64 End 20 dls,Start 45 dls 7,838.38 5,807.76 -4,811.42 607.00 4 8,070.00 5,785.68 -4,955.33 468.45 End 45 dls,Start RSM 8,110.00 5,780.19 -4,949.79 429.23 6 8,210.00 5,768.47 -4,930.51 331.83 7 8,330.00 5,761.53 -4,901.82 215.55 8 8,430.00 5,760.91 -4,872.94 119.83 9 9,330.00 5,763.41 -4,345.08 -590.84 10 9,630.00 5,759.71 -4,084.27 -737.93 11 9,930.00 5,753.90 -3,798.64 -827.68 12 10,130.00 5,752.89 -3,605.97 -880.69 13 10,500.00 5,755.49 -3,276.41 -1,046.60 14 10,800.00 5,757.53 -3,047.43 -1,239.57 Planned TD at 10800.00 COMPASS 5000.1 Build 74 1/5/2016 10:13:41AM Page 4 III W a • • p c • • O g ,r ......-..... 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CO V Ct V CT CT C D C C CO CO CO CD CO co OO W -p � W 0 o 0 o Co O 0000 0 0 0 000 - - 0 0 0 M O 0 0 0 0 0 0 0 0 0 0 0 0 0 o O o O o o Jam' 0 CO CO CO CO CO CO CO CO 000000 CO CO�M M N-r-,-C)00 M 0/M M CO O h m0 O 8 b C NNNN 9 NVU N- t-co CO A-NM V co 00)y- CO r `N-N-x000 CO CO CO CO CO CO OOO CO C Cz O ,_N co CO C0 N-CO CO COA-N M At CO + (" (UI/8sn 08)to.doa IrognA on.z,I V • • • • h l�, itn x. ConocoPhillips z 01,1111b ConocoPhillips (Alaska) Inc. In I?IP -Ku p2 ,Glr-, li��rti Kuparuk River Unit Kuparuk 3G Pad 3G-04 3G-04A ^A 3G-04A_wp04 Iti H Illi la Travelling Cylinder Report ,$ 0 W il ku 04 January, 2016 14 tialiOl r ,,,,,,,,,,,,,,,,,,,,,,,,,,!„41,,,,„ i F' i9, 'I'1I00 II 1 gh it �1'1 it 1 irrAiiiii '_-----t.:_=-Aso BAKER HUGHES • • Baker Hughes INTEQ vrilI ConocoPhillips Travelling Cylinder Report BAKER _ HUGHES " sA:S, in n �' 1'� 4.` :,1.,144 Ny 4N.4- H ';z- CoBtlpatyy� ConocoPhillips(Alaska)Inc.-Kup2aa� It- �ix Well3G-04 s � �- Kuparuk River Unit 4 II`' � 30 -04 @ 90-O0usft(3G-04) ,,,:i.,.7.-__ tea. Kuparuk 3G Pad li. X119! 3G-04 @ 90.Oousft(3G 04) _ c, 0.00 usft " �l�il� ml I�d908 i i T ----004, , bp8 �j1 True 91 �� 3G-04 uJ k q ' Minimum Curvature 11"-'7,:g." III Crry` - p , 0.00 usft `',,'.:&4i-,;!1,119111,.:!. �' h, 1.00 sigma lIhor a 3G-04A -Data J:" �L� '� ( OAKEDMP2 �� ���p�+jF1rTIl'e is �yr 3G-04A_wp04 � m "1:''''4�C1t - "'� Offset Datum _ ,,,,,,rr-, ... F7=-' nc.9i61n r_ 3G 04A_wp04 ,.:; . .: Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,700.00 to 10,800.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,271.00 usft Error Surface: Elliptical Conic W -------_-_,--T'' _ l'1 iG�t ;�EI BGaU IiPrm i lily g'�ihih5 �� ill ri' -,m i.i III,0r� i ( , ( a I ..1it,' 1 n ': 1 From C 1 b'I 1M- +.g +-. aI)6D 1' �� - U �! 4 r� " 7 - 14jhli 1 i'9^' ? 1 ami 4 ` i j a � $t7le = _ $G` _ +ryl 1� ,_ 4 saus ,iiiilbi) , a ° "'. , il��l -r:.v.a - € 6171��Ji �.. � ri@�r -,_ �", ... `�iii 100.00 7,700.00 3G-04(3G-04) Copy of GYD-CT-CMS Gyrodata cont.casing m/s 7,700.00 10,800.00 3G-04A_wp04(3G-04A) MWD MWD-Standard i �� ihi _ 3 F 3 i Sir ,�' 1 I,ult .1' r1 II � yai III lli 111110:44,�ger n ly _ 1 r AHI ii iiN 1-,-;71,-:'1..,'",1 ® z+rl Ii dl ., 11,4. 1 r 141,010'1; 0�i',, ��I " ollij,1 ( . ,,ii lh„ (� hh ' g� m y . IIIIIIII9th_ �ll�� 10,800.00 5,847.53 2 3/8" 2-3/8 3 iliiiii,{i yNll(Arai - z F� illi! - ,w. "Till 1 01,11(i�111` . our, " I(IIII Q ) ;, r 1,�� `�. ( 114F' R e' 1, r Gt qt - - rte, r ('ill- = r 1 a ) -, �h, iriH Tri ih 111i,p,rw _ ie- (1111 ji !j 7 �� � eY $ r ! F1ai +�(I Ii n��1 i�+� H �11� ii a till '''''''''''''''''''0''''' i iz 9i W; i 1` r '_, .. r1� ! :3 ®1 `-ri 'I a ,qiwogl, 414 _ - i. e �- a�° I- 1 --- (i , ,g, t I I--7!:A4301,, ri ii j �4�� _, t, I Et 1,e, { �' - illi ." ,Y ( (i a;, �� ^i4b1 7 ti .. �1 n =�"'�_ �-.,,. ,'teak a�� e--. ... ..ti�11 �',.-.- �=`, fi 1���'1,10,14.„1,---40,------- "ml�j� a '�� Kuparuk 3G Pad 3G-03-3G-03-3G-03 Out of range 7,725.00 7,725.00 0.09 0.91 -0.73 FAIL-Major Risk 3G-04-3G-04-3G-04 3G-04-3G-04AL1-3G-04AL1_wp03 8,200.00 8,200.00 0.00 0.31 -0.22 FAIL-Minor 1/10 3G-05-3G-05-3G-05 Out of range 3G-06-3G-06-3G-06 Out of range 3G-08-3G-08-3G-08 Out of range 3G-09-3G-09-3G-09 Out of range 3G-12-3G-12-3G-12 Out of range 3G-16-3G-16-3G-16 7,940.00 7,825.00 1,175.10 171.54 1,021.14 Pass-Major Risk 3G-19-3G-19A-3G-19A 3G-19-3G-19-3G-19 9,840.89 7,250.00 1,031.31 217.79 822.64 Pass-Major Risk 3G-19-3G-19-3G-19A WP01 9,900.00 7,100.00 1,030.85 217.35 829.29 Pass-Major Risk 9,848.32 7,225.00 1,030.58 217.80 822.63 Pass-Major Risk 3G-19-3G-19A-3G-19a WP01 9,848.32 7,225.00 1,030.58 217.89 822.54 Pass-Major Risk pn • + 9(ti;';i a Kuparuk 3G Pad 3G-04 3G-04 3G 04 Yi oyoo t� III' , ®a - ;Of"4u G ad -gi ll '® r i jtir'j 'p�� - , 1 1 i ? :1 _ �c, rl-�i _`_-,..--,-,mics,, •,r I'IIn of 1f�IP"'''- `I�eti�' ..... d",.. .1 plgiillliill' I r I - 4fk $- _ hIIIIIII .I ,F 11 j�il 9 b d'' II -_ E �Y"1 1 r ; '4 r� Ilii@i .�I IIIA) hqP li�a_ 1 1 (I h 1llhilh`�i fiI�i� uretl 1P1 it 1 _. v 1oo 4� y 1160' = 1 i� IIigiI)�"_. I Ftl�i1'M li"i rri i p µIl r r 11 - 9 0' ;, -,II Distance Ili;'®I 1' wa:::,-, i�-, h frit IIII: GiIlilll)i 41 9� H (tihli al 6 (. I) � i tia - 1 I BI�IIII y 4� } - :,,Ilii Ililll lI9I4€o 4 T j -_ k filllhlll 140?- €,rinr _ € Ilj t""'1, r 0. 1, €� € , a1 7,725.00 5,850.81 7,725.00 5,850.87 0.09 0.12 -6.78 -4,713.01 593.29 2-11/16 0.09 0.91 -0.73 FAIL-Major Risk,CC,ES,SF 7,749.77 5,868.15 7,750.00 5,869.72 0.10 0.23 -7.07 -4,729.27 595.59 2-11/16 2.05 1.68 0.45 Pass-Major Risk 7,773.08 5,881.38 7,775.00 5,888.58 0.11 0.35 -7.26 -4,745.52 597.92 2-11/16 8.27 2.59 5.77 Pass-Major Risk 7,793.72 5,890.01 7,800.00 5,907.45 0.12 0.47 -7.32 -4,761.75 600.28 2-11/16 18.57 3.40 15.32 Pass-Major Risk 7,811.24 5,894.87 7,825.00 5,926.33 0.12 0.58 -7.35 -4,777.95 602.67 2-11/16 32.19 4.09 28.34 Pass-Major Risk 7,825.75 5,897.13 7,850.00 5,945.25 0.13 0.70 -7.39 -4,794.12 605.05 2-11/16 48.36 4.67 44. - j 7,838.38 5,897.76 7,875.00 5,964.20 0.13 0.82 -7.41 -4,810.25 607.45 2-11/16 66.46 5.18 61.7805 PassPass-MMaajoror Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/4/2016 3:41:50PM Page 2 COMPASS 5000.1 Build 74 MI ma • • �We gi , //// J: , O • r O O ^ ^ N • o o - ,-o c L,',' o°�$ 0 1 11 xo LTz ami ami m``Gt _. 6 , -- ¢ doh S.J I Z O o L':" o o Q N Q • v K W • a2 N Yt p r, m o N O O I 1 0 N ,.. 7 IO o O a 4 0 Y Yana _}_. ,..f . ( ®' ;m3a¢ 1 o rv� c O C r a , 11\4\ J • I p cO ry 4— o N7 (ui si OSi)(+)gIiotvi/(-)ulnos M i • Conoconi1 S-43'' G I NADConversion Kuparuk River Unit Kuparuk 3G Pad �°°°40111 3G-04 3G-04ALI Plan: 3G-04AL1 wp03 _ E.:',:'—::::: : � a;_ Standard Planning Report ,1,�T 05 January, 2016 dA'14 4;l41-411-444- 111k(tiq al " ' 11iq FrAPAI , i , h ii .,, , h BAKER Tr �'Pi, HUGHES 'dip;�g ;�, r•- ConocoPhillips Fait'ConocoPhulhfps Planning Report BAKER HUGHES ii�,� "�� �),i 8 i`.xr,ii iil iiiiiiiiilii iii 11114Ai tiM. i YOX"i"ii.I i �-.X11Ji I .1 `t ' _.81111 III1111IIIIitl0XiiiM i t ",=Ji 1"tl Liary1,) 0 '11'111'0 EDM Alaska ANC Prod 1 x nate R §t e: Well 3G-04 It ' y1�'1L�I 'li"1 NADConversion ' P�iM�IMOl ll'�)'Mean Sea Level Firxject Kuparuk River Unit 1 (,p 30-04 @ 90.00usft(3G-04) il Ih t1R 6h 7q. ,, `Kuparuk 3G Pad # ' Pi1i1 ] 1(y1 True It h� Minimum Curvature 1 3G-04 � (1= s, Wellbore '3G-04AL1 9y9 Y 3G-04AL1 wp03 '' 1' '''''''475' 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 ',Iii,tiil'p _ = Kuparuk Pad MM t , ,kr, _ _ _ „,,.4-,+- ,h9MMBM11 i' .._. _ __— , ---q,,1 I S I M,11M11,MtffniMVIItMIEI iii .=,,,,,, .. Site Position: Northing: 5,988,559.95 usft Latitude: 70°22'47.920 N From: Map Easting: 498,724.97 usft Longitude: 150°0'37.320 W Position Uncertainty: 0.00 usft Slot Radius: 0” Grid Convergence: -0.01 ° Im, ,Jnhh i a z� 3 „ Ta i vu«w,p a s = ,ux�alw„em oau�ai "r tV.113G04 Well Position +N/-S 0.00 usft Northing: 5,988,560.55 usft Latitude: 70°22'47.926 N +E/-W 0.00 usft Easting: 498,675.12 usft Longitude: 150°0'38.779 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft g x�. �:i( � �- He .. ,� �=6 PA4AiiMMiihhhhhNtt Al '- - sus.:?.XM�iMi➢iiiltttQttWGtNhiiilAit((ttiittttt ttttt[.'�' .�. �vt. 11 i. , ,10,a5.' - 3G04AL1 ,,,h,eMmhueohmiulillyu111111111111 w11 I,1,1101r3=",ia , ma : xsLHUHir ," =,,,n _ ,J-n",Ns1-°,`= �I u � — v -. �Rp8116iiiM P ,t �.. yiiliq ie�,,,,;II 11 111,111 It, 101,1e,, op. L - ti ® "' h rti;1,"11, !i1 .i� lI J . ) (�r,i�i�d� I1,llli�i �11:,,,,,,4„,,,,,, Cf#t 1r ,. , " 1 i ,r1di ,,,4',,,,,, ,-.:3,-::_-..:[,-..-;1:,-,,,,,, fiii h4�l-dhP�6 iiiiGlj=� wi�� = ,li � „ 601/ 47-ti q��IINill . s ,-;-,:::11',1,,,''..---;:,. ,r aT} F_ :iii�BG�G��I�7Ei G M` BGGM2015 4/1/2016 18.37 80.98 57,487 .>� ,H 3G 04AL1 wpO3 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,200.00 VertrcatSes i 11 1' 1 1 €l rF r 6 i il001I€"'' w w a ®1 i. NiyiiiilFt_iii ,A i, J Irl '1 II _ 9ft� �� � ��tiL �.-: (" � >�v�>=�_ Cl�i iL ,: ��� 0.00 0.00 0.00 330.00 1/5/2016 10:14:55AM Page 2 COMPASS 5000.1 Build 74 • 1,. ConocoPhillips Va�. ConocoPhillips Planning Report BAKER HUGHES � , �p ,.; r.�, - .,�nsom„n, ,i s.s,n ,� % --lir.. ,� 1 file! ,.,... 3G-04 r.�mamas° uw� f ,....f',.. �" "- EDM Alaska ASIC Prod ,Lo-a -o _,fl : U1lek oma NADConversion `_1" R , ',...,,,L7,,...,;,::=74-7:::717,17,Mean Sea Level 111 r., ,n�, 1> �� 1�rim 0'1r - '' Kuparuk River Unit �iIC# 3G-04 @ 90.00usft(3G 04) Kuparuk 3G Pad t q,r i4 �1 �) True 30-04 eY at lu• a--,. Minimum Curvature Weftboe 3G04AL1 'aG H b�I� 1,1 "1� ���T� i1,:ii �� 3G-04AL1_wp03 ��� � ',���(�� � 6� * .��a�umor.,�,a�ara�a�tavaca��aa�s�u .m�. �ii���t��'�� - u a,uuununum .,a- ,= � ��� �� � ri i�4 i iii (�e ,L..,-.,--7---,.,... ,,,T1-51,4,v? (ili, ,Iir H,ri � 71: _ � " � e' ,14:,6.71-....-!'271.1.-.;:21' 1 �1 J'i '�)�t, , �, @, 9 ' 3 '1�� � ,ilii � '->�[Li:� ���' ,i� a �r '� + 4 _- I. � a �9 ih 5�0 4,,�4�, E I�� a� 9 ii i ust} 7', r■ s +I'E OOki . s `i J111111 i: ��in x�� 8,200.00 95.70 282.42 5,769.44 4,932.68 341.54 0.00 0.00 0.00 0.00 8,350.00 80.92 279.81 5,773.85 -4,903.83 194.84 10.00 -9.85 -1.74 190.00 8,450.00 81.06 269.69 5,789.55 -4,895.66 96.55 10.00 0.14 -10.12 270.00 8,550.00 89.75 274.67 5,797.55 -4,891.85 -2.93 10.00 8.68 4.98 30.00 8,650.00 89.75 284.67 5,797.99 -4,875.07 -101.39 10.00 0.00 10.00 90.00 8,750.00 90.62 294.63 5,797.67 -4,841.48 195.44 10.00 0.87 9.96 85.00 9,050.00 93.53 324.52 5,786.54 -4,652.72 -423.93 10.00 0.97 9.96 84.00 9,300.00 89.84 349.26 5,779.07 -4,424.69 -521.21 10.00 -1.48 9.90 98.00 9,600.00 87.86 319.31 5,785.23 -4,157.53 649.84 10.00 -0.66 -9.98 266.00 4054.71 -720.33 10.00 -0.13 9,725.00 87.70 331.82 5,790.10 , 10.01 91.00 9,925.00 88.18 351.83 5,797.38 -3,865.78 -782.35 10.00 0.24 10.00 89.00 10,025.00 89.93 341.98 5,799.03 -3,768.52 -804.98 10.00 1.75 -9.85 280.00 10,175.00 91.23 327.04 5,797.51 -3,633.51 -869.34 10.00 0.86 -9.96 275.00 10,350.00 94.16 344.31 5,789.22 -3,474.86 -941.10 10.00 1.68 9.87 80.00 -999.85 10.00 0.96 10,500.00 92.73 329.35 5,780.15 -3,337.61 -9.97 265.00 10,650.00 85.68 316.10 5,782.24 -3,218.59 1,090.42 10.00 4.70 8.83 242.00 10,900.00 86.08 341.17 5,800.49 -3,007.38 -1,219.15 10.00 0.16 10.03 90.00 1/5/2016 10:14:55AM Page 3 COMPASS 5000.1 Build 74 • �,. ConocoPhillips • FARS ConocoPhillips Planning Report BAKER pp dq HUGHES EDM Alaska ANC Prod ¢a1 Gai�:€ Well 3G-04 NADConversion Mean Sea Level Kuparuk River Unit 7 ' 3G-04 @ 90.00usft(3G-04) rt � Kuparuk 3G Pad N t n True �1 pl r i l'1 51 3G-04 itA 001001-0 r Y� ��' Minimum Curvature a r 3G-04AL1 7� I r1rail i l 3G 04AL1 wp03gh� i_ Psi is __ „,,,,,, ,Ar.-tr, aiiniiii, MIA110,4'itallittt 1114111114-- --4, 8,200.00 95.70 282.42 5,769.44 -4,932.68 341.54 -4,442.59 0.00 0.00 5,983,628.31 499,015.75 TIP/KOP 8,300.00 85.85 280.69 5,768.09 -4,912.67 243.70 -4,376.35 10.00 -170.00 5,983,648.33 498,917.92 8,350.00 80.92 279.81 5,773.85 -4,903.83 194.84 -4,344.26 10.00 -170.02 5,983,657.17 498,869.07 Start 10 dls 8,400.00 80.96 274.75 5,781.73 -4,897.57 145.88 -4,314.36 10.00 -90.00 5,983,663.44 498,820.12 8,450.00 81.06 269.69 5,789.55 -4,895.66 96.55 -4,288.04 10.00 -89.20 5,983,665.36 498,770.79 3 8,500.00 85.40 272.20 5,795.44 -4,894.84 46.92 -4,262.51 10.00 30.00 5,983,666.19 498,721.17 8,550.00 89.75 274.67 5,797.55 -4,891.85 -2.93 -4,235.00 10.00 29.70 5,983,669.19 498,671.32 4 8,600.00 89.75 279.67 5,797.78 -4,885.61 -52.53 -4,204.80 10.00 90.00 5,983,675.44 498,621.74 8,650.00 89.75 284.67 5,797.99 -4,875.07 -101.39 -4,171.24 10.00 89.98 5,983,685.99 498,572.88 5 8,700.00 90.19 289.65 5,798.02 -4,860.32 -149.14 -4,134.59 10.00 85.00 5,983,700.74 498,525.13 8,750.00 90.62 294.63 5,797.67 -4,841.48 -195.44 -4,095.12 10.00 85.00 5,983,719.59 498,478.84 6 8,800.00 91.14 299.61 5,796.90 -4,818.70 -239.92 -4,053.15 10.00 84.00 5,983,742.38 498,434.37 8,900.00 92.15 309.56 5,794.02 -4,762.03 -322.12 -3,962.98 10.00 84.08 5,983,799.05 498,352.19 9,000.00 93.10 319.53 5,789.43 -4,692.05 -393.22 -3,866.83 10.00 84.36 5,983,869.03 498,281.10 9,050.00 93.53 324.52 5,786.54 -4,652.72 -423.93 -3,817.41 10.00 84.82 5,983,908.37 498,250.41 7 9,100.00 92.83 329.47 5,783.76 -4,610.87 -451.12 -3,767.57 10.00 98.00 5,983,950.22 498,223.23 9,200.00 91.35• 339.37 5,780.11 -4,520.84 -494.21 -3,668.06 10.00 98.28 5,984,040.25 498,180.16 9,300.00 89.84 349.26 5,779.07 -4,424.69 -521.21 -3,571.29 10.00 98.64 5,984,136.39 498,153.18 8 9,400.00 89.15 339.28 5,779.96 -4,328.57 -548.29 -3,474.50 10.00 -94.00 5,984,232.51 498,126.12 9,500.00 88.48 329.30 5,782.03 -4,238.60 -591.60 -3,374.93 10.00 -93.91 5,984,322.48 498,082.82 9,600.00 87.86 319.31 5,785.23 -4,157.53 -649.84 -3,275.60 10.00 -93.70 5,984,403.55 498,024.60 9 9,700.00 87.72 329.32 5,789.10 -4,076.47 -708.06 -3,176.30 10.00 91.00 5,984,484.61 497,966.41 9,725.00 87.70 331.82 5,790.10 -4,054.71 -720.33 -3,151.32 10.00 90.61 5,984,506.37 497,954.14 10 9,800.00 87.85 339.33 5,793.02 -3,986.53 -751.30 -3,076.78 10.00 89.00 5,984,574.55 497,923.19 9,900.00 88.10 349.33 5,796.57 -3,890.43 -778.26 -2,980.08 10.00 88.71 5,984,670.65 497,896.25 9,925.00 88.18 351.83 5,797.38 -3,865.78 -782.35 -2,956.69 10.00 88.35 5,984,695.30 497,892.16 11 10,000.00 89.49 344.44 5,798.91 -3,792.45 -797.76 -2,885.48 10.00 -80.00 5,984,768.62 497,876.77 10,025.00 89.93 341.98 5,799.03 -3,768.52 -804.98 -2,861.14 10.00 -79.85 5,984,792.55 497,869.56 12 10,100.00 90.58 334.51 5,798.70 -3,698.91 -832.75 -2,786.97 10.00 -85.00 5,984,862.16 497,841.79 10,175.00 91.23 327.04 5,797.51 -3,633.51 -869.34 -2,712.04 10.00 -85.03 5,984,927.56 497,805.22 13 10,200.00 91.66 329.50 5,796.88 -3,612.26 -882.49 -2,687.06 10.00 80.00 5,984,948.81 497,792.08 10,300.00 93.35 339.37 5,792.50 -3,522.25 -925.55 -2,587.58 10.00 80.06 5,985,038.81 497,749.04 10,350.00 94.16 344.31 5,789.22 -3,474.86 -941.10 -2,538.77 10.00 80.49 5,985,086.20 497,733.50 14 10,400.00 93.71 339.32 5,785.79 -3,427.49 -956.66 -2,489.96 10.00 -95.00 5,985,133.58 497,717.95 10,500.00 92.73 329.35 5,780.15 -3,337.61 -999.85 -2,390.53 10.00 -95.34 5,985,223.45 497,674.78 15 10,600.00 88.02 320.53 5,779.50 -3,255.86 -1,057.23 -2,291.05 10.00 -118.00 5,985,305.20 497,617.42 10,650.00 85.68 316.10 5,782.24 -3,218.59 -1,090.42 -2,242.17 10.00 -118.06 5,985,342.47 497,584.24 1/5/2016 10:14:55AM Page 4 COMPASS 5000.1 Build 74 Iv1 ConocoPhillips 11111111ConocoPF1l�IIps Planning Report BAKER HUGHES ��� EDM Alaska A C Prod S Well 3G-04 �°1D @@ NADConversion toilyIlIpt Mean Sea Level Pzpaa Kuparuk River Unit11,kance � � 3G-04 @ 90 OOusft(3G-04) hf ui� kpl,ru,tI,� Kuparuk 3G Pad I4 V� �IIJ i�rence True 3G-04 Sum '� fit#2� � eth Minimum Curvature Wig!LG-04AL1 Fhh�h�� Ie �� ra trlil[;,1!!771777::::::::::777=ra,s,L77_7„ 4A ��J�w,°.wau�l� d�p>'( � � arc��,�,s V_ ,aianrrNxw --`�- i � � = imr '�. ._ iriiiiiiiii i =n ilii r-r i t IP nned!SdrYey 6i7w 9iy� a �� ;lI" ii � i k I ` 4C` r ili��� a hs 4GN0� �IeasurecRIHMEN&PIHiiII�D���fibn,,_-��6l � l� ' d�Ill�� e; i =� -_ x.=12 is '� 011-.711- 1,1L1AfUt31 `�Lra�N�,- d �� a- to 13 = "� _�. II�iii Ili Ti 1t i ,� i��r' x� i . _`: �,- ��il ,,,_ � a�il,-:11,007.,..1:,,:;: � �� i ,a,,. _�� rq� ��u���"k oto 4 r �� �r 44�r�11 M ry(r 8 4 16 10,700.00 85.69 321.12 5,786.01 -3,181.20 1,123.37 2,193.31 10.00 90.00 5,985,379.87 497,551.30 10,800.00 85.83 331.14 5,793.42 -3,098.50 -1,178.88 2,093.94 10.00 89.62 5,985,462.57 497,495.81 10,900.00 86.08 341.17 5,800.49 3,007.38 1,219.15 1,994.89 10.00 88.88 5,985,553.68 497,455.56 Planned TD at 10900.00 god°px�' -' ' r - , �r�!P - x I�I I{{{ � �( iii� - �r Yl i ir4 - 1hOrtlink 11 �W I iia ANG i„ ".,u IA a iii Fa I�i��110 i� ilii o- _ 11 ,= Y st 9 cal kr 1)�it, h� �It t' �i ll - (iii( 0ati 'Cr smg s�"Ia ( i�i��ii - iI �'(r (]�i� M- [ p 4 a' a i -`{ i-� �b p i a i��� ill lr ,[ :�<' JU4., !I'''''''4""°°'-----800.49 i.. � a�, �i IR�� I7W W�' ��Ilia �,E;iit ii ii .-c. ILiiiUi ,a _ (� �� 10,900.00 5,800.49 2 3/8" 2-3/8 3 'Gu " tlli lli aye . :: altihill HP� � li : 0,A,110lA,AlIll11,111,,,,a,l' ., _ ' 1 � (ii� �riD1q° -4 14t; _" r - � � E� fi�� �li�biI ry y� i ' 1,,q��I4���� it m ��!�iH _ r e. , 4oca� j� �i� x llii _ lt1I1Iyjl m ,,,,,,,„&,,x,,,,,,,,,,,, IPKOPIttlIPRONN2k04r,',- 4928o� r341.54 TN [ 5,769.44 8,200.00 Obl hu tat 73.85 -4,903.83 8,350.00 5,7194.84 Start 10 dls 8,450.00 5,789.55 -4,895.66 96.55 3 8,550.00 5,797.55 -4,891.85 -2.93 4 8,650.00 5,797.99 -4,875.07 -101.39 5 • • 8,750.00 5,797.67 -4,841.48 -195.44 6 9,050.00 5,786.54 -4,652.72 -423.93 7 9,300.00 5,779.07 -4,424.69 521.21 8 9,600.00 5,785.23 -4,157.53 -649.84 9 9,725.00 5,790.10 -4,054.71 -720.33 10 9,925.00 5,797.38 -3,865.78 -782.35 11 10,025.00 5,799.03 -3,768.52 -804.98 12 10,175.00 5,797.51 -3,633.51 -869.34 13 10,350.00 555,:777899979."250231 ,789.22 -3,474.86 -941.10 14 10,500.00 5,780.15 -3,337.61 -999.85 15 10,650.00 5,782.24 -3,218.59 -1,090.42 16 10,900.00 5,800.49 -3,007.38 -1,219.15 Planned TD at 10900.00 1/5/2016 10:14:55AM Page 5 COMPASS 5000.1 Build 74 Ny ■ � ^ • W o , . 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M o CD N 00,i V'- R 00 ,-,-1 000 o- ( O O b conN N N N N N M M M CP CP`Cr M M M C)M .... ..............� ( _ - __C7__. ____. h M O Q U O N CO 0000 N M cr CO 0.00 M CO CO M 0000 _. ..._ ............ ...... •� C N 0 O 1�N-CO u)CO 00 P c-0 N c-I-COO ._.. _ V — l ___o _ - r`.2-'.0 r O D O C0O,-000 M01Z 1-000 4 Nu)O 000 C OCC 000003 CO 000000000CO CO L+ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O O m O J O 0 0 0 0 0 0 0 0 0 u)u)C C)u)0 0 C.0 N N V 0 N N p O 00 N N) u)C O N O M C O I-O O c-M C 0 00 0 CO V COCO0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o CO CD -«c-c-c O NDN M V u)CO i 000 O e-N C,,r C0 CO1 0 z 0 (uygsn 08)LI�dou IeoplaA an.J ✓ KUP PROD 3G-04 COnOCOPhiIIips zt ry Wefl Attnittiteo ` Z. . III=masiommounim!!!ift!iimilim NIA)04.094ft4MP4E,TIZMItiMk AIBSka.Inc. * Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) <rm ,tt,nr„ F. 501032014300 KUPARUK RIVER UNIT PROD 52.39 2,100.00 8,089.0 "." Comment H2S(ppm) Date Annotation End Date KB-Grd(R) -Rig Release Date 30-54,6/12015 3:26:02 PM SSSV:TRDP Last WO: 36.39 11/5/1990 Venial schematic(actuaQ Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM y7,838.0 5/27/2015 Rev Reason:TAG,GLV C/O hipshkf 6/1/2015 HANGER:30.8 PIA pati - if.`� .Iiii ::l e.'.. v' x=.."'t I = IPG ii '.., Casing Description 0D(in) ID(int Top(ftKB) Set Depth(ttKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread ,. CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread SURFACE 95/8 8.921 35.0 3,794.6 3,017.6 36.00 J-55 BTC I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 1 nuu.PRODUCTION 7 6.276 350 8,062.2 6,106.3 26.00 J-55 BTC CONDUCTOR;36.0-115.0 Iiii ,Tg a f ) e ' °,' Tubing Description )St I g Ma...ID(I) Top(ftKB) Set Depth(K Set Depth(ND)( Wt(lb/ft) Grade Top Connection TUBING 31/2 2992 308 7,557.2 57244 9.30 J-55 EUE8rdABMOD Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com _ (in) 130.8 30.8 0.17 HANGER MCEVOY GEN IV HANGER 3.500 _ 1,812.0 1,654.4 43.64 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.812 SAFETY VLV;1,012.0 „'' 7,507.9 5,687.3 41.33 PBR CAMCO OEJ PBR w/10'STROKE 2.938 7,521.4 5,697.4 41.28 PACKER CAMCO HRP-1-SP PACKER 2.859 7,544.8 5,715.1 41.21 NIPPLE CAMCO D NIPPLE NO GO 2 750 7,556.4 5,723.8 41 18 SOS CAMCO PE 500 SHEAR OUT SUB 2.984 GAS LIFT;2.922.1 t t., (1M liik rfeliatifiktikitOPtitliti4h8l 41= -' Iu PMM Top(TVD) T p Incl Top(ftKB) (ftKB) (°) _ Des Com Run Date ID(in) 7,890.0 5,975.6 40.59 F1750011,;1,4,2t'enGirse,t7veie\X!isSfz:irisi cl Unsuccessful FISH 2/19/1994 e /27/94 to 2/24/94 ani Ya�erD7i8r � n ri e shot Dens Top(TVD) Btm(THD) Dens Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,640.0 7,660.0 5,786.8 5,801.9 C-4,UNIT B, 7/16/2002 4.0 APERF 2.5"PJ,120 deg phase SURFACE,35.0-3,7946-a 30-04 I 7,710.0 7,734.0 5,839.6 5,857.7 A-3,3G-04 7/16/2002 4.0 APERF 2.5"PJ,120 deg phase GAS LIFT;5,466.4 7,754.0 7,774.0 5,872.7 5,887.8 A-2,30-04 1/6/1994 4.0 RPERF 2.5"Titan;180 deg. phasing 7,754.0 7,784.0 5,872.7 5,895.4 A-2,3G-04 1/14/1991 4.0 IPERF 4.5"Expendable Csg Gun;180 deg.phasing n' Mandrel Inserts St GAS LIFT;7 452.1 o N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make _ Model OD(in) Sery Type Type (in) (psi) Run Date Com 1' 2,822.1 2,313.2 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,276.0 5/28/2015 2 5,466.4 4,210.8 MERLA TMPD 1 GAS LIFT OV BK 0.250 0.0 5/28/2015 3 7,452.1 5,645.5 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/30/2015 a #4,00#11, erat&`_Safet 9TiNI ,,,0 t,0 End Date Annotation • 5/12/2010 NOTE:CSG Sleeve from bottom Surf Csg hanger to top of 1st collar(54"),10"X.500 wall X65 pipe PBR;],507.9 - -_-- 8/27/2010 NOTE:View Schematic w/Alaska Schematic9.0 PACKER;7,521.4 NIPPLE;7.544.8 APERF;7,640.0-7660.0- .. APERF;7,710 0-7,734.0 RPERF;7.754 0-7,774 01-x. _ IPERF;7,7540.7,784.0 FISH',78900 PRODUCTION;35.0-8,062.2 • • Proposed 3G-04 CTD Schematic Modified by 1GE 12/28/15 3-1/2"Camco TRDP-1A SSSV at 1812'RKB(locked out???) 3-1/2"9.3#J-55 EUE 8rd-Mod Tubing to surface 16"62#H-40 — 3-1/2"Merla TMPD gas lift mandrels 2822'&5466'RKB shoe @ 115' MD 3-1/2"Camco MMG-2 gas lift mandrel 7452'RKB 9-5/8"36#J-55 shoe @ 3795'MD Camco 10'PBR at 7508'RKB Camco HRP-1-SP packer at 7521'RKB 3-1/2"Camco D-nipple at 7545"RKB(2.75"min ID) Note:Will be milled out to 2.80"ID 3-1/2"tubing tail at 7557'RKB WOK C-sand perfs(sgz'd) KOP @ 7718°MD 7640'-7660'MD A-sand perfs(sgz'd) 7710'-7734'MD3G-04AwN04 7754'-7784'MD TD @ 10;800'MD Liner Binet @ 8200 MD tiff Lat#1 Lat#2 IMRE 3G-04AL1 wp03 TD @ 10,900'MD Top of Liner @ 7550'MD 7"26#J-55 shoe @ 8062'MD • • Bettis, Patricia K (DOA) From: Pohler, Cody J <Cody.J.Pohler@conocophillips.com> Sent: Thursday,January 14, 2016 11:58 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 3G-04A (PTD 216-006): Permit to Drill Application Good morning Patricia, Apologize about that,the maximum formation pressure in the area is from 3G-12 and is 4578 psi.The maximum potential surface pressure assuming a gas gradient of 0.1 psi/ft,would be 3995 psi. This would qualify for the AL1 lateral as well. Thank you, Cody Pohler I CTD Engineer Office:907-265-6435 I Cell: 281-409-7869 cody.j.pohler@conocophillips.com nacoP"hitli s Alaska From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, January 14, 2016 11:52 AM To: Pohler, Cody J Subject: [EXTERNAL]KRU 3G-04A (PTD 216-006): Permit to Drill Application Good morning Cody, On Form 10-403, Box 17,the information on maximum potential downhole and surface pressures is missing on the application. Please provide this data by email. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 1 • • CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME: K i2 u 3(1--01-11kLI PTD: n2)(v — OC)7- ✓ Development Service Exploratory Stratigraphic Test _Non-Conventional FIELD: /` K . V E�! POOL: l ,11.4& ' 1 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. al() _00(0 , API No. 50-103 - a0 I43 -0I - 40. (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 • • ❑ El U 0, 0 a) 0. (0 w m o a - 0 0, d .r a c a g, o: 3, w r tiE' a N, C N, O, p "0 C o. V c CO Z CO •@, p`o o a a. E, c , a O ° CO C. E O 4) o o , w 0) a 4) d U zL . 4 y 40 F 0, o ao, d' Y, $' _ ots. > v a 3. 3, C .- ai E O ' O) O c, M o4 p E laa � U r ' o a o0 •a N p 1-, o cd a, a co = I co c 2 c o �' o f Co c a a �' �� �� c' (0 �� CQ'1). 0 0 Od a) a) 4 m' .a U N III Y 0, •3,, w C 2, >. v o a in a U, 0 <, d a as, w Y �. E m CO o ai �� Y. �' � o c �'� c. . . m c, 4), 3. ami' �. 'o N U, vi 5. 2, a), 01 a0 t, U, . ami. 1, T, o, . >' a), 15 a `o a) E. 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