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217-087
DATA SUBMITTAL COMPLIANCE REPORT 111712017 Permit to Drill 2170870 Well NamelNo. KUPARUK RIV UNIT 31-1-261-1 MD 8773 TVD 5901 Completion Date 8/5/2017 REQUIRED INFORMATION Mud Log Nov Operator CONOCOPHILLIPS ALASKA, INC. API No. 50.103-20208-60-00 Completion Status 1-0I1 Samples No \ DATA INFORMATION Types Electric or Other Logs Run: GR/Res Well Log Information: Log/ 2170870 KUPARUK RIV UNIT 31-1-261-1 LOG Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No ED C 28509 Digital Data ED C 28509 Digital Data Log C 28509 Log Header Scans ED C 28545 Digital Data ED C 28545 Digital Data ED C 28545 Digital Data ED C 28545 Digital Data ED C 28545 Digital Data ED C 28545 Digital Data ED C 28545 Digital Data ED C 28545 Digital Data ED C 28545 Digital Data ED C 28545 Digital Data ED C 28545 Digital Data ED C 28545 Digital Data ED C 28545 Digital Data ED C 28545 Digital Data ED C 28545 Digital Data Interval OH/ Start Stop CH 0 0 6219 8773 Current Status 1 -OIL UIC No Directional Survey Yes f (data taken from Logs Portion of Master Well Data Maint) Received Comments 8/21/2017 Electronic File: 31-1-261-1 EOW - NA027.pdf . 8/21/2017 Electronic File: 31-1-261-1 EOW - NAD27.txt - 2170870 KUPARUK RIV UNIT 31-1-261-1 LOG HEADERS 8/28/2017 Electronic Data Set, Filename: 31-1-261-1 GAMMA RES.las 8/28/2017 Electronic File: 31-1-261-1 2MD Final Log.cgm 8/28/2017 Electronic File: 31-1-261-1 5MD Final Log.cgm 8/28/2017 Electronic File: 31-1-261-1 5TVDSS Final Log.cgm - 8/28/2017 Electronic File: 31-1-261-1 2MD Final.pdf . 8/28/2017 Electronic File: 31-1-261-1 5MD Final.pdf ' 8/28/2017 Electronic File: 31-1-261-1 5TVDSS Final.pdf ' 8/28/2017 Electronic File: 3H-261-1 EOW - NAD27.pdf . 8/28/2017 Electronic File: 31-1-261-1 EOW - NAD27.txt - 8/28/2017 Electronic File: 31-1-261-1 Survey Listing.txt 8/28/2017 Electronic File: 31-1-261-1 Surveys.txt. 8/28/2017 Electronic File: 31-1-261-1_Confirmed TO 8773.csv. 8/28/2017 Electronic File: 31-1-261-1_Confinned TO 8773.xlsx , 8/28/2017 Electronic File: 31-1- 26L1_25_tapescan_BHI_CTK.txt 8/28/2017 Electronic File: 31-1- 26L1_5_tapescan_BHI_CTK.txt ' AOGCC Page I of 2 Tuesday, November 7, 2017 DATA SUBMITTAL COMPLIANCE REPORT 11/7/2017 Permit to Drill 2170870 Well Name/No. KUPARUK RIV UNIT 3H -26L7 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20208-60-00 MD 8773 TVD 5901 Completion Date 8/5/2017 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 28545 Digital Data 8/28/2017 Electronic File: 31-1-261-1_output.tap' ED C 28545 Digital Data 8/28/2017 Electronic File: 3H-261-1 2MD Final Log.tif ED C 28545 Digital Data 8/28/2017 Electronic File: 31-1-261-1 5MO Final Log.tif ED C 28545 Digital Data 8/28/2017 Electronic File: 3H -26L1 5TVDSS Final Log.tif Log C 28545 Log Header Scans 0 0 2170870 KUPARUK RIV UNIT 31-1-261-1 LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report � Directional / Inclination Data Mud Logs, Image Files, Digital Data Y NA Core Chips Y /c Production Test InformatioOY ' NA Mechanical Integrity Test Information Y Composite Logs, Image, Data Files Core Photographs Y / Geologic Markers/Tops Daily Operations Summary s Cuttings Samples Y ti.'l Laboratory Analyses YN COMPLIANCE HISTORY Completion Date: Release Date: Description Comments: Compliance Reviewed By: 8/5/2017 6/26/2017 Date Comments Date:... /-I-/( AOGCC Page 2 of 2 Tuesday, November 7, 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED AUG 3 11201 WELL COMPLETION OR RECOMPLETION REPORT A 1a. Well Status: Oil ❑� ' Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended[] tb. Well Cla s: 20AAC 25.105 20AAC 25.110 Development R] - Exploratory El GINJ ❑ WINJ ❑ WAG[-] WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or gIs I Abend.: 84Qeff �„ 14. Permit to Drill Number/ Sundry: 217-087 • 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 7t24P2M-7 4123111 . 16. API Number: 50-103-20208-60-00 4a. Location of Well (Governmental Section): Surface: 1384' FNL, 281' FWL, Sec 12, T12N, R8E, UM Top of Productive Interval: 2616' FNL, 36' FEL, Sec 11, T12N, R8E, UM Total Depth: 4950' FNL, 5268' FEL, Sec 12, T12N, R8E,UM 8. Date TO Reached: N2B/40t1-' 71V' -1r?- 16. Well Name and Number: KRU 3H -26L7 - 9. Ref Elevations: KB:80 GL:41 BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk Oil Pool ' 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25531 41b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 498655 y- 6000273 Zone- 4 TPI: x- 498339 y- 5999041 Zone- 4 Total Depth: x- 498388 y- 5996707 Zone- 4 11. Total Depth MD/TVD: 8773/5901 19. DNR Approval Number: ALK 2657 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD1TVD: 1639/1638 5. Directional or Inclination Survey: Yes M (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD[TVD: 6230/5892 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH NHOLE SIZE CEMENTING RECORD D AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H40 Surface 121 Surface 121 24 200 sx CMT 7.625 29.7 L-80 Surface 3142 Surface 3140 9.875 550 sx ASIII, 300 sx Class G CMT 5 x 5 1/2 17 L-80 39 6643 39 5973 6.75 210 sx Class G CMT 2318 4.6 L-80 6771 8773 5954 5901 3 Slotted Liner 24. Open to production or injection? Yes ❑� No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Slotted Liner @ 6780 -8743 MD and 5953 - 5901 TVD --, --- ... 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3 1/2 6127 6117/6785 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑a Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 8/8/2017 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 8112/2017 Hours Tested: 3.33 Production for Test Period Oil -Bbl: 32.68 Gas -MCF: 126.93 Water -Bbl: 1198.9 Choke Size: 176 bean Gas -Oil Ratio: 1273 Flow Tubing Press. 250 Casinq Press: 1 1380 Calculated 24 -Hour Rate Oil -Bbl: 760 Gas -MCF: 967 Water -Bbl: Oil Gravity-API(corr): Form 1,0 107 R111 542017 0e ',/y �' CONTINUED ON PAGE 2 RBDMS LL �i. _ 5 Z0��Submit ORIGINIAL o %,O II .h- � l/ 28. CORE DATA Conventional Core(s): Yes ❑ No 21 Sidewall Cores: Yes ❑ No (] If Yes, list formations and intervals cored (MDITVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No D If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1639 1638 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 6229.65 5892 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk C TO 8773 5901 Formation at total depth: Ku aruk C 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, product on or well test results,r 20 AAC 25,070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: Mike Callahan "SIL Authorized Title: Staff CTD Engineer Contact Email: mike.callahan a co .com Authorized Contact Phone: 263-4180 Signature: Date: 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 Is: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. 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 10407 Revised 5/2017 Submit ORIGINAL Only 3H-26 Final CTD Schematic 16" 62# H-40 shoe ® 121' MD 7518" 29.7# L-80 shoe ® 3143' MD &12" 9.3# LA0 shoe a %X%X' MD 5-12' 170 L-80 0 133' MD Csand ports 250'-6280' MD X d pens 8306'-8336' MD 5' 18# LA0 shoe 6643' MD 312" Cemm Landing Nippla@ 504' MD (2.875" min ID) 3-12" 9.3# 1-4i0 EUE 8ml Tubing to surtace &i2" Camco gas lift mandrels @ 2766', 4124', 4988', 5631', 8055' 3-12" Camw DS nipple 0 6106 MD (2.812' min ID) Baker 3-12" GBH -22 seal assembly @ 6114' MD (2.98" ID) 3H-261-142 TD =10168' MD 2-3/8" slotted liner w] deployment sleeve TOL = 6113' MD, BOL =10188' MD 31-2611 TD = 8773' MD 2-W slotted linerw/ aluminum billet TOL =6]72 MD, BOL :8]73' MD 3H -26L1-01 T2 =8890' MD 2-3/8" slottad linarw/ aluminum bigot TOL-7 408' MD, BOL= 8890' MO KUP PROD COnocoP fillipswe115 ti u. Alaska 1m wmllmrenp _ HMGER: SBRFACE NIPPLE, 6.106 RPERF.&i5JD8.mo. - IPERF, 6.3W.88.MOl 3H-26 AnnohXon DepN I'Mig Entl Dae AI,roblon Last Matl By Entl Bah Last Tag: RKB 6,299.D 7060209 Rev R6asdn: CTD SIDETRACK jenlmH BQM17 Casing zParhings Lazing B escepl.— M,nl IBllnl Top IXKm $el Bepm lttKBj $et rpm lNB)... WIILen 11... Greee Tap TX,eze CONDUCTOR 16 15.062 d0.9 121.0 6250 HAO WELDED 'aui, eescripnon OD (in) Nlnl Top IXNBI $et Bepm lM(m Set BepN (NDL.. WUlen30.1"mtle Tneeatl SURFACE 1518 6.875 409 3,1428 LT 3,1403 29]0 L-80 LTC Casing Desc,iplion OD pn) ID pn) Top glKBl Se[Bepin im(BI $ef DepN DVO)... WHIM, g... G,atla Tep Tn,cae PRODUCTION 5112 4.276 38> Q6431 6,2909 17.00 L-80 LTC 5 5x5"@6552' Tubing Strings Tuning Desenpoon ening Ma... ID (1n) TOP MXMI sM hom he sN DePin IND) L.. wtpMll rage rop C.,,-,,.nTUBING WO 3112 2.992 3].8 6,126.0 5,>93.1 930 L-80 IST 1 Completion Details Noll JD Top IXKBI I Top MO) MIKE) I Top Intl (•1 I Hem Due C. Lin) 37.8 HANGER FMC TUBING HANGER 3,500 5042 NIPPLE CANDO BP -61 LANDING NIPPLE 2875 6,1062 5,774.6 21.13 1 NIPPLE CANCO'DS' NIPPLE 2.812 6,1132 5,781,11 20.99 1 LOCATOR BAKER GBH22LOCATOR 2.850 6,113.5 578141 20.98 IDEAL ASSY BAKER BOT GBH- 22 SEAL ASSY 285' DRIFT 2980 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) TOPITVDI TOP Ine, Top MIM Me) M Des Com Run Dae ID (in) 8,229.0 5,890.1 18.84 WHIPSTOCK B IeHWHIPSTOCK.OAL=4T,OAW330LBS, 7/12/2017 0.000 MAX TOOL OD = 2.70, SET WHIPSTOCK 294° I I LEFT OF HIGH -SIDE, TOP OF WHIPSTOCK SET 6229' (2 RA TAGS) Perforations & Slots .he, Don To, IND) Dun (Tv"1:now Top IXKID Bum (WB) MIKE) LMB) zone Dart m Type coni 6,250.0 6,280.0 5,9111.0 5,9386 C4, C-3, 3H- 611511998 4.0 RPERF 2118" EnerJet, 0 deg ph 26 8,250.0 8280.0 5,910.0 5,9386 CA, C-3, 314- 4911997 4.0 IPERF 111116" PIVOTS, 180 26 deg. ph 8,306.0 8,338.0 5,963.4 5,992.2 A -3,A -$3H- 62411994 4.0 IPERF 21/8- EnerJet, W deg. 26 ph Mandrel Inserts s< ri N Top ToMBe IHKB) Mar MaEel Tape True Pmi Bve TRO flan OD (in) Sery type Typo Hn) IKA flan Dab Co. 1 2,765.7 2,763.5 CANDO KBG2- 1 GAS LIFT GLV BTM 0.188 1,253.0 8012017 9 2 4,124.4 4,0962 CAMCO KBG-2- 1 GAS LIFT OV BTM 0.250 0.0 W2017 9 3 4,9676 4,8367 CAMCO KBG2- 1 GAS LIFT DMY BTM 0.000 0.0 11312016 9 4 5,6309 5.351.9 CAMCO KBG2- 1 GAS LIFT DMY DK -1 0.000 0.0 6GW2005 9 5 60551 5.727.0 CAMCO KBG-2- 1 GAS LIFT DMY DK -1 0.000 00 69012005 9 Notes: General 8 Safety Ene wh i Ann.". 42902005 NOTE: TREE: FMC 3.1AE'/GEN N/SOOD psi opium 1112612009 NOTE: View SChamanc w/ Alaska Smema0D9.0 `, KUP PROD COIIOCOPiIIlfip$Wen Attr be, Alesk&Im welleore nrvuwl T 121d2016 IIASTWO: 3H -26L1 Oepth (XNBI End BdLL Annotation Last Mon By End DaR ._................................._..........._..........._......_... .......... ...... I-aMT.on LaM TaB' Rev ReazG¢CTD SIDETRACK lennalt 812920 1) XRXGFA:3]e casing Wage Using Deacnpdnn OD In) 10 (tnI T,MKB) Se[Deplh (ttK9I Set Oeplh MD) ...WULen II...GIM Top Thread L1 LINER 231 1992 6,]]0.] 8,T)30 4.60 L-80 STL Liner Details mpuD In lttND) I Tap "V) (nxe) Top loci l'1 nem De: eom 0n) 67]0] 5.9543 9].31 ALUMINUM Liner TGB Billet 1.920 BILLET I Notes: General & Safety End We An.... NOTE CONDUCTOR Qn-121 o NiWlE:sw.z G Uu ;ZM7 WBR E 31d2e— GnsurT'.4.1m4 GrsuFT.4:. 6 G0.4 uF�; 66v a WLIFT6=1 NIPPLE, stfK.2 SFALPSSy; 8,11]5 WXIPSTGCK6,TID.0 NFEftF:6]91.=O IYcftF,jA08,]&10B� IPERF', B.YJ5.G8.339.0-I PROWCTION S. SS'®6a6Z:� a9.TS,fif3,1 1n` H II Lt LINER; 6TNIi M0� ` KU—P— PROD ConoaoPhillips Well Att'. Ala:.ke. IIIC. ��jj��„ WeIIW1e PPYlIWI Fiek 3H -26L1-01 120001fi IIASTWO1 1 40.991 31611994 An".. DdRE (6) Entl De@ Mnotatian -11 m—" En00— .... .......... ...,,,.. Last Tag: Rev Reason: CTD SIDETRACK Iennall 09QD17 XRNOEft 3]B ngs C-Inasing OeseeiPtpn OD 11n1 roP(DKDI sel0epm lNxe sn Degn Dvq... `1 wnsn 0... cede mraze 111"' L1-01 LINER 2318 Ll -01 1992 7,4063 8,890.0 4.60 L80 ST STL Notes: General & Safety End Om A—Idl..n NOTE: CONDUCTOR: W&121.0 NIPPLE: 501.2 OPS LIFT; 2.]05] WNFACE,AOOI,102a— . Un'r: 1.125.5 G49 UR: 4,W6 G44 LIl. E.L. CNS UPr, 50s51 NIPPLE; 9,1052 6EALAa6Y:9,1195 WHIPSTOCK E, 0 6,2W.0 MO PPENF: PENF, 6,L50.OQMO IPEAP,49NOB,3Y0� PRODUCTION 5 SSaGb` T: LE 3&]E.ai9.1 11411 LINER: ],405]A. KUP PROD 3H -26L1-02 ConQCQPhillips Well Attribu Max Angle 7 TD Md"'kN, Inc. .11L.Po it I 501012020662 FieK Name W¢IlporeStyus nel l') Z%RUK RIVER UNIT PROD 106.54 MDIXheI 6,889.60 Ae101m mine) 10,1680 eommenl Ht6lppm) Date 190 1Z4I2016 MnoleEon Ell Dalo IAST WO: KB mm) RIBR¢I¢ase V¢le 40.99 3Ifi11994 3H-IDlta].4319oIT11454PM Annolallon GepIp MIKE) plat. MnafaCon Laa[Motl eY Entl Gale ................................................................. ....... ......... ..... Last Tag: Rev Reason: CTO SIDETRACK jennalt Brz912D1] mmGER;31A Casing Strings 0—mg DesmipHDn DD lin) IG RnI Top IWell Se1CepM ptK91 Set Oeplp (N )... WYLen (I... Gude L1-02 LINER 2318 1992 6,1136 10,168.0 5,9]1.8 4.60 L-80 STTpleatl STL Liner Details op Nominal ID Top IRKS) Top(TVD)Inept Top 1.11') 1—On Com (in) 6,113.619.8] DEPLOYMENT Shorty Oepbyment Sleeve 1.920 SLEEVE 8,1112 5,6995 89.10 DEPLOYMENT Shorty Deployment Sleeve 1.000 SLEEVE Notes: General & Safety End DaleAnMwlon NOTE: CGNDUCT0R: 4n4R10 NIPPLE. 504.8 GAS OFT; Z785.7— III 4Ge3,td36— GAS UFT: 4,1N.4 ame LIFT;4We WS Di 3,890. QiS LIFT. Eppel NIPPLE; 1.1.2 PRGODLTICN 535'®635'!` 39Te,W41 t) ) Ll -0 LMN I6,1136-10.166.----� Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Tune End T,. Our (hr) Phase Op Coda ActMty Coda Time P -TX Operation (Win EM Depth (ttKS) 7/21/2017 7/21/2017 2.00 MIRU MOVE RURD P Trucks arrive at 1C -Pad atl0:00 hm, 0.0 0.0 10:00 12:00 PJSM with NES, rig sows up to modules 7/21/2017 7/21/2017 5.50 MIRU MOVE MOB P Move to 311 -Pad 0.0 0.0 12:00 17:30 7/21/2017 7/21/2017 4.50 MIRU MOVE MOB P Sub spotted over 311-26, service 0.0 0.0 17:30 22:00 module spotted 7/21/2017 7/22/2017 2.00 MIRU WHDBOP RURD P Halfway house & shop spotted 0.0 0.0 22:00 00:00 7/22/2017 7/22/2017 5.00 MIRU WHDBOP NUND P reconfigure well sraffoldiing, reinstall 0.0 0.0 00:00 05:00 mouse holes, TT line air tested, nipple up BOPE, fuseable link install, depressureize SSV, BOP shell test to 4200 psi, work post rig move checklist ••' Rig Accept 5:00 hrs 7/22/17 7/22/2017 7/22/2017 5.00 SLOT WELLPR OTHR P Install CTC & pull lest, various injector 05:00 10:00 tests, COMMS up, prep for BOPE test 7/22/2017 7/22/2017 0.80 MIRU WHDBOP BOPE T Begin BOPE test, witnessed by Brian 0.0 0.0 10:00 10:48 Bixby of AOGCC. Test #1, Swab 2 test, grease R1 & fluid pack above, fail/pass 7/22/2017 7/22/2017 2.20 MIRU WHDBOP BOPE P Continue with BOPE test 0.0 0.0 10:48 13:00 7/22/2017 7/22/2017 2.20 MIRU WHDBOP BOPS T Change out seals on both Lower 2- 0.0 0.0 13:00 15:12 3/8" ram doors due to leak, Test #6 fail/pass 7/22/2017 7/22/2017 0.70 MIRU WHDBOP BOPE P Continue with BOPE test 0.0 0.0 15:12 15:54 7/22/2017 7/22/2017 0.60 MIRU WHDBOP BOPE T Fail/Pass Test #9 0.0 0.0 15:54 16:30 7/22/2017 7/22/2017 2.50 MIRU WHDBOP BOPE P Continue with BOPE test 0.0 0.0 16:30 19:00 7/22/2017 7/22/2017 0.80 MIRU WHDBOP BOPE T Fail Pass test #15 Lower 2" pipe slips, 0.0 0.0 19:00 19:48 Function twice and pass 7/22/2017 7/22/2017 1.00 MIRU WELLPR BOPE T Fail pass test # 16 Upper 2 inch pipe 0.0 0.0 19:48 20:48 1 slips. Function. Relocate test joint 7/22/2017 7/22/2017 0.20 MIRU WHDBOP BOPE T Perform draw down test - good End 0.0 0.0 20:48 21:00 ROPE test NAD 1 Hr NPT for 11 Hbur test 7/22/2017 7/22/2017 1.90 MIRU RIGMNT CTOP P Skid injector to floor, Head up E -line to 0.0 0.0 21:00 22:54 BHI upper quick connect, Good test on E -line 7/22/2017 7/23/2017 1.10 MIRU RIGMNT CTOP P Fill coil string. PT CTC to 4500 PSI 0.0 0.0 22:54 00:00 7/23/2017 7/23/2017 1.50 MIRU RIGMNT PRTS P Complete filling CT string, Test and 0.0 0.0 00:00 01:30 chart inner reel iron and packoffs, 4000 PSI 7/23/2017 7/23/2017 1.50 MIRU RIGMNT PRTS P Prep and pressure test PDL and tiger 0.0 0.0 01:30 03:00 tank line 7/23/2017 7/23/2017 1.50 MIRU WHDBOP OTHR P PJSM with valve crew, Rig up BPV 0.0 0.0 03:00 04:30 lubricator and pull BPV, RID BPV equipment. WHP after BPV removeal 2304 PSI Page 1113 Report Printed: 8/8/2017 ' . Operations Summary (with Timelog Depths) MEMOkP-S 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Tme End Time Our (hr) Pheae Op code Activity Code Tm,P-T-X Operabon htK8) End Depth(ftKB) 7/23/2017 7/23/2017 0.40 PROD1 WELLPR KLWL P Consult with town, PJSM Bull head 0.0 0.0 0430 04:54 80 BBIs seawater downhole to reduce pressure, Initial pressures @ 3 BPM WHP=2304, IA=2225, 30 BBIs away, WHP= 1770 PSI, IA 2495 7/23/2017 7/23/2017 0.20 PROD1 WELLPR KLWL P 40 BBIs away, 3 BPM, WHP=1600, 0.0 0.0 04:54 05:06 IA=2500 , All gas will not bleed off, 60 BBIs away WHP=1440, @ 3.5 BPM, IA=2370 7/23/2017 7/23/2017 0.30 PROD1 WELLPR KLWL P 80 BBIs away, Shut down pump, 0.0 0.0 05:06 05:24 WHP=1100 PSI, monitor well 7/23/2017 7/23/2017 3.00 PROD1 WHPST PULD P PJSM, crew change, another PJSM, 0.0 74.0 05:24 08:24 PU & PD BHA #1 Window Milling Assembly, WHIP climbs to 1459 psi 7/23/2017 7/232017 1.40 PROD1 WHPST EQRP T Begin RIH to -214', Baker & Nabors 74.0 74.0 08:24 09:48 depth counters not in agreement, troubleshoot depth counters, change out encoder, PUH & tag up, 7/23/2017 7/23/2017 2.20 PROD1 WHPST EQRP T RIH with BHA #1, slop at 2086 to 74.0 3,189.0 09:48 12:00 check gooseneck alignment, continue to RIH, reel counter again does not agree with Baker depth counter after gooseneck alignment, trouble-shoot issue, observe that RIH speeds are not the same, swap back to old counter 7/23/2017 7/23/2017 0.60 PROD1 WHPST TRIP P Continue RIH 3,189.0 6,160.0 12:00 12:36 7/23/2017 7/23/2017 0.40 PROD1 WHPST DLOG P Unable to tie into K1 , gamma is 6,160.0 6,213.0 12:36 13:00 reading coninuous -230 API, slop at TOWS 723/2017 7232017 0.20 PROD1 WHPST TRIP P Confer with town, PUH to 6085'to 6,213.0 6,080.0 13:00 13:12 perform CCL, PUW = 32K 7/23/2017 7/23/2017 1.00 PROD1 WHPST CLOG P RIH to perfrom CCL from GLV #5 to 6,080.0 6,080.0 13:12 14:12 TOWS, correlate +20' correction to. CCL, swap to milling fluid, close EDC Note: Tagged WS pinch point at 6233', putting TOWS at 6230' (RA tag should be at 6237.35') 7/23/2017 7/232017 0.20 PROD1 WHPST TRIP P RIH, dry lag WS pinch point 6233', 6,080.0 6,233.0 14:12 14:24 PUH, PUW = 33K, RBIH to mill window 7/23/2017 7/23/2017 1.90 PROD1 WHPST WPST P Begin milling window as per procedure 6,233.0 6,234.0 14:24 16:18 at 330° ROHS 7/23/2017 7/23/2017 5.40 PROD1 WHPST WPST P Milling @ 1FPH, 1.83 BPM @ 3090 6,234.0 6,237.5 16:18 21:42 PSI FS, BHP=3515 7/23/2017 7/23/2017 0.10 PROD1 WHPST WPST P 6237.5 Stall, PUH RBIH and stall 6,237.5 6,237.5 21:42 21:48 again. Get back on borttom and appear to have exit. 7/23/2017 7/24/2017 2.20 PROD1 WHPST WPST P Milling rathole, 1.8 BPM @ 3090 PSI 6,237.5 6,255.0 21:48 00:00 FS, BHP=3553 Page 2113 Report Printed: 8/812017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time Dur (ht) Phase cip catle Ad" Code Time P -T -X Cyerat' n rMS) end Depth (@K8) 7/24/2017 7/24/2017 2.50 PRODt WHPST WPST P 6255 @ rathole TD, Start reaming 6,255.0 6,255.0 00:00 02:30 passes, as drilled, 330°ROHS, 30L of as drilled 300°, 30R of as drilled 0°, 180° from as drilled 150° ROHS. Maintained -100 PSI motorwork toward bottom of window. Repeat this pass and one more as drilled. Get clean dry drift 7/24/2017 7/24/2017 1.50 PROD1 WHPST TRIP P Trip out for lateral BHA#2, PUW=30K. 6,255.0 78.0 02:30 04:00 7124/2017 7/24/2017 3.00 PROD1 WHPST PULD P On surface, PJSM, PUD BHA#1 78.0 0.0 04:00 07:00 window milling BHA, Mills out @ 2.79 No Go 7/24/2017 7/24/2017 2.00 PROD1 DRILL PULD P PJSM, M/U & PD BHA#2 Build 0.0 72.0 07:00 09:00 Drilling Assembly (2.45° motor and rebuilt Hughes bi center) 7/24/2017 7/24/2017 0.50 PRODII DRILL EQRP T Begin RIH, observed depth counter 72.0 72.0 09:00 09:30 issues, PUH to surface, resolve 7124/2017 1712412017 1.20 PROD1 DRILL TRIP P RIH 72.0 6,000.0 09:30 10:42 7124/2017 7/2412017 1.90 PRODt DRILL EQRP P CCL from 5940'to TOWS (6000'- 6,000.0 6,200.0 10:42 12:36 6200 bit depth) @16 fpm, tie from CCL for +11' correction, allow Peter O'Brian time to install final software updates, upload caused circ pump reading issue, upload new update, close EDC 7/24/2017 7/24/2017 0.20 PRODt DRILL TRIP P Continue to RIH 6,200.0 6,255.0 12:36 12:48 7124/2017 7/24/2017 2.70 PROD1 DRILL DRLG P OBD pumping 1.6 bpm, CWT = 15K, 6,255.0 6,334.0 12:48 15:30 WOB = 2.4K, annular = 3690 psi, WHIP = 493 psi, IA = 1430 psi, FS = 379 psi, multiple PU's required drilling BHA length past window, observed Siderite over shakers, PUW's = -36K 7124/2017 7/24/2017 1.50 PRODt DRILL DRLG P Continue drilling build, pumping 1.6 6,334.0 6,386.0 15:30 17:00 bpm, rate out = 1.5 bpm, CWT = 15K, WOB = 2.5K, annular = 3680 psi. called EOB at 6386' 7/2412017 7/24/2017 2.00 PROD1 DRILL TRIP P Pump sweeps, POOH, MAD pass 6,386.0 72.0 17:00 19:00 6300'-6200' for geology to determine suitable fie -in point, notice black mud and dark cutting coming over the shakers when close to surface, test mud, very little trace amounts of oil, suspect mud black due to fines observed over shakers., EOB Avg DLS=51° 7/24/2017 7/24/2017 2.20 PROD1 DRILL PULD P PJSM, PUD BHA #2, dififcully pulling 72.0 0.0 19:00 21:12 BHA into PDL through tree, work wire -line, get through, tag up, motor was packed off with same black cuttings coming over the shakers. Bit out @ 2- 2 with chipped cutters on reamer tape 7/24/2017 7/24/2017 1.10 PROD1 DRILL PULD P PSJM, PD BHA#3 1_1 Lateral Drilling 0.0 78.0 21:12 22:18 Assembly (.5° AKO X-Treme motor, agitator, RB HYC B8 Edge), check' pack -offs, slide in cart, stab on WH, tag up Page 3113 Report Printed: 81812017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan oepth Stan Tana End T ne Dir (hr) Phase Op Code ActivityCode Titre P -T-% Operation fftKa) Erb Depth (RKa) 7/24/2017 7/24/2017 1.30 PROM DRILL TRIP P RIH 78.0 6,000.0 22:18 23:36 7/24/2017 7/25/2017 0.40 PROM DRILL DLOG P Perform CCL, tie-in for ... 6,000.0 6,220.0 23:36 00:00 7/25/2017 7/25/2017 0.30 PROD1 DRILL DLOG P Continue to review logs for tie in, Call 6,220.0 6,220.0 00:00 00:18 a +5' correction 7/25/2017 7/25/2017 0.10 PROM DRILL TRIP P Close EDC, PUW=28K, trip in 6,220.0 6,260.0 00:18 00:24 7/25/2017 7/25/2017 0.20 PROD1 DRILL DLOG P Log Ra marker, Stacked out, Unable 6,260.0 6,280.0 00:24 00:36 to work through build at logging speed 7/25/2017 7/25/2017 0.20 PROD1 DRILL TRIP P Trip in to drill 6,280.0 6,387.0 00:36 00:48 7/25/2017 7/25/2017 4.60 PROD1 DRILL DRLG P 6387', Drill, 1.8 BPM @ 4924 PSI FS, 6,387.0 6,810.0 00:48 05:24 BHP=3825 7/25/2017 7/25/2017 0.40 PROD1 DRILL WPRT P Wiper trip to 6390', PUW=27K 6,810.0 6,810.0 05:24 05:48 7/25/2017 7/25/2017 5.60 PROD1 DRILL DRLG P 6810', Drill, 1.78 BPM @ 4924 PSI 6,810.0 7,125.0 05:48 11:24 FS, BHP=3760 7/25/2017 7/25/2017 0.50 PROD1 DRILL WPRT T PUH to cased hole, depth discrepancy 7,125.0 6,203.0 11:24 11:54 between BHI and Nabors, PUW=34K, Open EDC in cased hole 7/2512017 7/25/2017 1.00 PROD1 DRILL RGRP T Change out Baker encoder, Shut • 6,203.0 6,000.0 11:54 12:54 EDC, Pull up hole to log CCL j 7/25/2017 7/25/2017 0.30 PROD1 DRILL DLOG P Log CCL for -3 foot correction 6,000.0 6,205.0 12:54 13:12 7/25/2017 7/25/2017 0.10 PROM DRILL WPRT P Continue in hole 6,205.0 6,250.0 13:12 13:18 7/25/2017 7/25/2017 0.30 PROM DRILL DLOG P Log gamma points for future tie in - No 6,250.0 6,280.0 13:18 13:36 correction 7/2512017 7/25/2017 2.50 PROM DRILL WPRT T Baker computer depth tracking side of 6,280.0 7,020.0 13:36 16:06 program became corrupt, Call Jeff and CDR2, Remove erronious data from data base generated by bad encoder, 2.5 Him BHI NPT 7/2512017 7/25/2017 0.30 PROD1 DRILL WPRT P Continue in hole to drill 7,020.0 7,123.0 16:06 16:24 7/25/2017 7/25/2017 4.00 PROM DRILL DRLG P 7123', Drill, 1.76 BPM @ 4822 PSI 7,123.0 7,525.0 16:24 20:24 FS, BHP=3740 7/25/2017 7/25/2017 0.50 PROD1 DRILL WPRT P Wiper up hole PUW38 k 7,525.0 6,500.0 20:24 20:54 j 7/25/2017 7/25/2017 0.50 PROD1 DRILL WPRT P Wiper back in hole RIW 14 k 6,500.0 7,525.0 20:54 21:24 7/25/2017 7/2612017 2.60 PROD1 DRILL DRLG P BOBO, 1.8 bpm at 4,870 psi FS, BHP 7,525.0 7,830.0 21:24 00:00 3,908, WHIP 384, IA 1,290. OA 23 7/26/2017 7/26/2017 0.75 PROM DRILL DRLG P OBD, 1.8 bpm at 5,028 psi, BHP 7,830.0 7,861.0 00:00 00:45 3768, WHIP 306, IA 1297, OA 24 7/26/2017 7/26/2017 1.50 PRODt DRILL TRIP T POOH, to inspect BHA, (lost 650psi 7,861.0 78.0 00:45 02:15 diff), leaving EDC closed 7/26/2017 7/26/2017 2.00 PROM DRILL PULD T PJSM, PUD Drilling BHA# 3, following 78.0 0.0 02:15 04:15 checklist w/closed EDC 7/26/2017 7/2612017 2.60 PROD1 DRILL PULD T PJSM, PU/MU/PD Drilling BHA# 4 0.0 78.0 04:15 06:51 7/26/2017 7/26/2017 1.40 PROD1 DRILL TRIP T Trip in hole, BHA #4 with .5° motor 78.0 6,001.0 06:51 08:15 and RB HYC bit with agitator, Test agitator @900' Page 4/13 Report Printed: 8/8/2017 .Aawftiil Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log swn Dam Stan Time EMTime Eur(hr) Phase CP Loft Acbmy Co4e Time P-T4 opa2uon (MB) EMOeWOKB) 7/26/2017 7/26/2017 0.40 PRODt DRILL DLOG T Set tool to CCL mode. Log CCL tie in 6,001.0 6,215.0 08:15 08:39 for+7' 7/26/2017 7/26/2017 0.70 PRODt DRILL TRIP T Close EDC and trip in to drill. Clean 6,215.0 7,857.0 08:39 09:21 pass through window. Slight stacking at bottom of build - 6370', 7 HRS BHI NPT 7/26/2017 7/26/2017 3.40 PROD1 DRILL DRLG P 7857', Drill, 1.8 BPM @ 5133 PSI FS, 7,857.0 8,250.0 09:21 12:45 BHP=3834, RIW=8K. DHWOB=l.1K 7/26/2017 7/26/2017 0.60 PROD1 DRILL WPRT P 8250, Wiper trip to 7395', PUW=33K 8,250.0 8,250.0 12:45 13:21 7126/2017 7/26/2017 4.50 PROD1 DRILL DRLG P 8250', Drill, 1.78 BPM @ 4940 PSI 8,250.0 8,628.0 13:21 17:51 FS, BHP=3839 7/26/2017 7/26/2017 0.15 PROD1 DRILL WPRT P Wiper up to the window, PUW 35 k 8,628.0 7,535.0 17:51 18:00 7/26/2017 7126/2017 0.50 PROD1 DRILL DLOG P Perform MADD PASS 7,535.0 7,325.0 18:00 18:30 7/26/2017 712612017 0.50 PROD1 DRILL WPRT P Continue wiper to the window 7,325.0 6,200.0 18:30 19:00 1 1 ' 7/26/2017 7/2612017 0.25 PROD1 DRILL WPRT P Perform Static Pressure Survey 6,200.0 6,200.0 19:00 19:15 Sensor Depth=6,160' Annular Press =3,571 (11.74 ppg) MWI=8.7 ppg MWO=8.9 ppg TVD (RKB)=5,847' WHP=813 7/26/2017 7/26/2017 1.25 PROD1 DRILL WPRT P Wiper back in hole, RM 11.3 k 6,200.0 8,628.0 19:15 20:30 7/26/2017 7/2612017 3.00 PROM DRILL DRLG P BOBD, 1.8 bpm at 5,155 psi FS, BHP 8,628.0 8,762.0 20:30 23:30 3,850, WHIP 364, IA 1,278, OA 26 8,629' rough drilling with stalls. 7/26/2017 7/2712017 0.50 PROM DRILL WPRT P TD L1 lateral, PUW 35 k, send 10x10 8,762.0 8,762.0 23:30 00:00 sweep down hole 7/27/2017 712712017 2.50 PROD1 DRILL WPRT P POOH, chasing 10x10 sweep, 6,187' 8,762.0 78.2 00:00 02:30 open EDC 7/27/2017 7/2712017 0.25 PRODt DRILL WPRT P Tag up at surface, reset counters, lube 78.2 78.2 02:30 02:45 CTES counters on horses head 7/27/2017 7/2712017 1.00 PROM DRILL TRIP P RIH 78.2 6,000.0 02:45 03:45 7/27/2017 712712017 0.25 PROD1 DRILL DLOG P Set tool to CCL mode. Log CCL tie in 6,000.0 6,199.0 03:45 04:00 1 for plus 6.0' 7/27/2017 7/27/2017 0.90 PROD1 DRILL TRIP P Continue RIH, confine TD 6,199.0 8,773.0 04:00 04:54 7/27/2017 7/27/2017 1.10 PRODt DRILL TRIP P POOH, laying in liner running pill with 8,773.0 6,926.0 04:54 06:00 beads. 7/27/2017 7/27/2017 0.50 PROD1 DRILL TRIP T 6926', Dragging weight 26K. 6K over 6,926.0 6,926.0 06:00 06:30 pull. Run back in hole. PUH overpull 10K - RBIH. PUH over pull 15K unable to run back in hole. Work pipe down. Unable to move. Orient freely. No weight changes on DHWOB. Start working pipe up. Pull free at 70K continue out 7/27/2017 7/27/2017 1.80 PROD1 DRILL TRIP P Continue up to 6202 above window. I 6,926.0 6,202.0 06:30 08:18 Circ out small bubble and perform Sow check - good Page 5113 Report Printed: 8/812017 Operations Summary (with Timelog Uepths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Burt Depth start Tena End none Dur (hr) Phase Op Code Activity Cade Time P -T -X operation (ftKB) End Depth (RKB) 7/27/2017 7/27/2017 1.10 PROW DRILL TRIP P Continue out of well, Paint EOP flag 6,202.0 90.0 08:18 09:24 @ 4800' 7/27/2017 7/27/2017 2.20 PROD1 DRILL PULD P At surface, Flow check well, Lay down 90.0 0.0 09:24 11:36 BHA #4 7/27/2017 7/27/2017 1.00 PROD1 DRILL RURD P Rig up floor to run liner - inspect top 0.0 0.0 11:36 12:36 drive. Adjust wrapping on service loop 7/27/2017 7/27/2017 3.00 COMPZI CASING PUTB P PJSM, P/U BHA #5 L1 completion 0.0 1,993.3 12:36 15:36 with non ported bullnose, one joint solid liner, 49 joints slotted and anchor top billet. Perform safety joint drill at joint 15 - Good drill 7/27/2017 7/27/2017 1.20 COMPZI CASING PULD P PJSM, Make up coil trek to liner, 1,993.3 2,046.5 15:36 16:48 Secure coikrak in slips. Change out floats in UQC. Make up to coil and surface lest. Strip on well. Change packoffs 7/27/2017 7/27/2017 1.50 COMP21 CASING RUNL P Trip in well with liner, Wt Chit at 6176' 2,046.5 6,842.0 16:48 18:18 34 k 7/27/2017 7/27/2017 0.00 COMPZI CASING RUNL P Saw flag on driveby @ 6842' plus 4.5', 6,842.0 7,507.0 18:18 18:18 didn't correct. continue IH 7/27/2017 7/27/2017 2.50 COMPZ1 CASING RUNL P Work pipe and attempt to run to 7,507.0 8,116.0 18:18 20:48 bottom, PUW's 40-45 k, 7/27/2017 7/28/2017 3.20 COMPZ1 CASING RUNL T PUW 59 k, Weight cell faulted to 171 8,116.0 8,116.0 20:48 00:00 k. call electrician/mechanic, trouble shoot weight cell, service crew showed up at 21:15 7/28/2017 7/28/2017 0.50 COMPZ1 CASING RUNL T Install new weight cell, cleanup work 8,116.0 8,116.0 00:00 00:30 area Nabors NPT 3.5 hr; 7/28/2017 7/28/2017 0.20 COMPZ1 CASING RUNL P RIH 8,116.0 8,303.0 00:30 00:42 7/28/2017 7/28/2017 1.10 COMPZI CASING RUNL P Work pipe to bottom 8,303.0 8,773.0 00:42 01:48 7/28/2017 7/28/2017 0.30 COMPZI CASING RUNL P Liner on bottom, PUW 43 k, bring 8,773.0 8,773.0 01:48 02:06 pump up 1.6 bpm, 0.70 bpm returns, PUW 29 k, liner released, TOL (-6,771) 7/28/2017 7/28/2017 1.30 COMPZI CASING TRIP P POOH, pumping pipe displacement, 8,773.0 58.2 02:06 03:24 following trip sheet 7/28/2017 7/28/2017 0.50 COMPZI CASING OWFF P At surface, PJSM, Check well for flow 58.2 58.2 03:24 03:54 7/28/2017 7/28/2017 0.50 COMPZI CASING PULD P LD setting tools. on dead well 58.2 0.0 03:54 04:24 7/28/2017 7/28/2017 0.70 PROD2 STK PULD P PU1MU kickoff/drilling BHA# 6, surface 0.0 78.2 04:24 05:06 test CoilTrack tools, good test 7/28/2017 7/28/2017 1.20 PROD2 STK TRIP P Tag up, reset counters, RIH, 700' 78.2 6,060.0 05:06 06:18 shallow test agitator, 1.8 BPM @ 6200, Thinking this was due to 12PPG fluid. Same agitator as last run, Continue in well 7/28/2017 7/28/2017 0.20 PROD2 STK DLOG P Log CCL r+5.5 correction 6,060.0 6,228.0 06:18 06:30 7/28/2017 7/28/2017 1.00 PROD2 STK CIRC P Displace well to 8.7PPG PwrPro from 6,228.0 6,234.0 06:30 07:30 12.OPPG NaBr 7/28/2017 7/28/2017 0.50 PROD2 STK TRIP P Close EDC, PUW=28K, Trip in hole, 6,234.0 6,772.0 07:30 08:00 Dry tag billit @ 6772 Page 6/13 Report Printed: 8/8/2017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Deco, Sten T,me EM Tdre Dur(hr) Pheee DD Code AcdNty Code Time P -T -X operation W15) End DepN(nKB) 7/28/2017 7/28/2017 1.10 PROD2 STK MILL P Bring pumps on 1.8 BPM @ 5680 PSI 6,772.0 6,773.5 08:00 09:06 FS, BHP=3769, Call inital contact @ 6772.05, time mill @ 1 FPH 7/28/2017 7/28/2017 0.70 PROD2 STK MILL P Mill @ 2 FPH, 1.8 BPM @ 5680 PSI 6,773.5 6,774.0 09:06 09:48 FS, BHP=3769 7/28/2017 7/28/2017 0.30 PROD2 STK MILL P Stall, PUH Go to 3 FPH, 1.8 BPM @ 6,774.0 6,775.0 09:48 10:06 1 1 15303 PSI FS 7/28/2017 7/28/2017 0.90 PROD2 DRILL DRLG P Time drill 2-4 FPH for 1 foot, Go to 6,775.0 6,782.0 10:06 11:00 control drilling 5-15 FPH, 1.8 BPM @ 5300 PSI FS, BHP=3768 7/28/2017 7/28/2017 0.40 PROD2 DRILL DRLG P Go to normal drilling ops, 1.8 BPM @ 6,782.0 6,825.0 11:00 11:24 5303 PSI FS, BHP=3768, On bottom pressure 6080 with fluctuations all through billit kick off 7/2812017 7/28/2017 0.10 PROD2 DRILL WPRT P PUH to drift billit area, PUW=30K. 6,825.0 6,825.0 11:24 11:30 Looks good j 7/28/2017 7/28/2017 0.50 PROD2 DRILL DRLG P 6825', Drill, 1.8 BPM @ 5330 PSI FS, 6,825.0 6,874.0 11:30 12:00 BHP=3796 7/28/2017 7/28/2017 1.50 PROD2 DRILL TRIP T 6874, Pressures high and fluctuating. 6,874.0 84.0 12:00 13:30 Cannot drill on diff pressure. Trip out for agitator replacement 7/28/2017 7/28/2017 2.00 PROD2 DRILL PULD T Tag up and space out, PJSM PUD 84.0 0.0 13:30 15:30 BHA #6, Checks not holding. Close EDC. Continue PUD 7/2812017 7/28/2017 1.50 PROD2 DRILL PULD T PD BHA #7 with .5° motor, agitator 0.0 78.2 15:30 17:00 and RR Hyc bit, surface test CoilTrak tools. 7/28/2017 7/28/2017 1.25 PROD2 DRILL TRIP T Tag up reset counters 78.2 6,060.0 17:00 18:15 7/28/2017 7/28/2017 0.25 PROD2 DRILL DLOG T Log CCL for +5.5'correction 6,060.0 6,149.0 18:15 18:30 7/28/2017 7/28/2017 0.75 PROD2 DRILL TRIP T Continue RIH, work pipe to bottom. 6,149.0 6,875.0 18:30 19:15 from 6835' to 6875' 7/28/2017 7/28/2017 3.88 PROD2 DRILL DRLG P BOBD, 1.8 bpm at 5,100 psi, BHP 6,875.0 7,275.0 19:15 23:07 3748, WHP 241, IA 1206, OA 17 7/28/2017 7/28/2017 0.50 PROD2 DRILL WPRT P Wiper up hole PUW 36 k 7,275.0 6,300.0 23:07 23:37 7/28/2017 7/29/2017 0.38 PROD2 DRILL WPRT P Wiper back in hole, RIW, gouge on 6,300.0 6,907.0 23:37 00:00 coil at (6382' f/EOP) 7/29/2017 7/29/2017 0.10 PROD2 DRILL WPRT P Continue wiper in hole 6,907.0 7,275.0 00:00 00:06 7/29/2017 7/2912017 3.20 PROD2 DRILL DRLG P BOBD, 1.8 bpm at 4,650 psi, BHP 7,275.0 7,675.0 00:06 03:18 1 1 3675, WHP 187, IA 1220, OA 20 7/29/2017 7/2912017 0.50 PROD2 DRILL WPRT P Wiper up hole PUW 34 k 7,675.0 6,825.0 03:18 03:48 7/29/2017 7/29/2017 0.50 PROD2 DRILL WPRT P Wiper back in hole, RIW 14 k 6,825.0 7,675.0 03:48 04:18 7/2912017 7/29/2017 2.10 PROD2 DRILL DRLG P BOBD, 1.8 bpm at 5,074 psi, BHP 71675.0 7,929.0 04:18 06:24 3,739, WHP 239, IA 1,235, OA 23 7/2912017 7/29/2017 0.10 PROD2 DRILL WPRT P BHA Wiper, PUW=36K 7,929.0 7,929.0 06:24 06:30 7/29/2017 7/29/2017 2.50 PROD2 DRILL DRLG P 7929', Drill, 1.78 BPM @ 4605 PSI 7,929.0 8,075.0 06:30 09:00 1 FS, BHP=3790 7/29/2017 7/29/2017 1.20 PROD2 DRILL WPRT P 8075', Wiper to window with tie in, 8,075.0 6,060.0 09:00 10:12 7/29/2017 7/29/2017 0.40 PROD2 DRILL DLOG P Run CCL logging pass for+2' 6,060.0 6,203.0 10:12 10:36 Page 7113 Report Printed: 816/2077 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth I Start Time End Tune Dur (hr) Phase op Code Activity code Time P -T -X Operation (ftKB) Eed Depth 1*08) 7/29/2017 7/29/2017 0.40 PROD2 DRILL RGRP P Tighten right angle drive coupler on 6,203.0 6,203.0 10:36 11:00 injector drive ' 7/29/2017 7/2912017 0.75 PROD2 DRILL WPRT P Continue wiper back in hole 6,203.0 8,077.6- 11:00 11:45 7/29/2017 7/29/2017 2.90 PROD2 DRILL DRLG P 8077', Drill, 1.78 BPM @ 5020 PSI 8,077.0 8,490.0 11:45 14:39 FS, BHP=3814 7/29/2017 7/29/2017 0.75 PROD2 DRILL WPRT P Wiper trip, 1000', PUW=36K, Clean 8,490.0 8,490.0 14:39 15:24 1 1 1 trip up and down 7/29/2017 7/29/2017 2.87 PROD2 DRILL DRLG P 8490', Drill, 1.78 BPM @ 5030 PSI 8,490.0 8,629.0 15:24 18:16 FS, BHP=3856, RIW=10.2K, WHP=288 7/29/2017 7/29/2017 0.89 PROD2 DRILL WPRT P Wiper trip up hole, PUW 35 k 8,629.0 8,300.0 18:16 19:09 7/29/2017 7/29/2017 0.85 PROD2 DRILL WPRT P Wiper back in hole, RIW 6 k 8,300.0 8,629.0 19:09 20:00 7/29/2017 7129/2017 3.50 PROD2 DRILL DRLG P BOBD, 1.8 bpm at 5,400 psi, BHP 8,629.0 8,894.0 20:00 23:30 3,891, WHP 286, IA 1,267, OA 38 7/29/2017 7/30/2017 0.50 PROD2 DRILL WPRT P TD well, pump 10x10 sweep, perform 8,894.0 7,711.0 23:30 00:00 1 swab wiper. PUW 33 k 7/30/2017 7/30/2017 1.90 PROD2 DRILL WPRT P Continue Swab Wlper 7,711.0 78.2 00:00 01:54 7/30/2017 7/30/2017 1.10 PROD2 DRILL TRIP P Tag up reset counters, RIH 78.2 6,060.0 01:54 03:00 7/30/2017 7/30/2017 0.20 PROD2 DRILL DLOG P Log CCL correction of plus 5.5', PUW 6,060.0 6,225.0 03:00 03:12 31 k 7/30/2017 7/30/2017 0.90 PROD2 DRILL TRIP P Continue in hole, RIW 18 k 6,225.0 8,890.0 03:12 04:06 7/30/2017 7/3012017 1.30 PROD2 DRILL DISP P Pump 12 PPG pill 8,890.0 8,890.0 04:06 05:24 7/30/2017 7/30/2017 1.70 PROD2 DRILL TRIP P POOH laying in 12 PPG liner running 8,890.0 101.0 05:24 07:06 pill followed by 12PPG completion fluid, Paint EDP flags @ 7300 and 4700. 7/30/2017 7/30/2017 1.30 PROD2 DRILL PULD P Tag up, Flow check well. Lay down 101.0 0.0 07:06 08:24 BHA # 7 on dead well 7/30/2017 7/3012017 0.50 PROD2 DRILL BOPE P Perform Bi Weekly BOPE function lest 0.0 0.0 08:24 08:54 7/30/2017 7/30/2017 3.10 COMPZ2 CASING PUTS P Prep floor and pick up Li -01 0.0 1,424.4 08:54 1200 completion with non ported bullnose, 1 Jt blank liner, 35 As slotted liner, and liner top billet 7/30/2017 7/30/2017 0.90 COMPZ2 CASING PULD P Make up coil track to liner, set in 1,424.4 1,477.7 12:00 12:54 deployment rams. Check pack offs, C/O UQC checks, M/U to coil and surface test. Strip on well 7/30/2017 7/30/2017 1.00 COMPZ2 CASING PULD T Change of liner configuration, Tag up 1,477.7 1,477.7 12:54 13:54 and space out. Strip off and lay down coil track 7/3012017 7/30/2017 0.10 COMPZ2 CASING PUTB T PIU one joint slotted, Add 8'solid pup 1,477.7 1,473.9 13:54 14:00 7/30/2017 7130/2017 0.80 COMPZ2 CASING PULD T P/U coil trek and make up to liner, Set 1,473.9 1,527.5 14:00 14:48 in slips and strip on well. Surface test tool. Tag up and set depths 7/30/2017 7130/2017 0.90 COMPZ2 CASING RUNL P RIH, BHA #8 1,527.5 6,220.1 14:48 15:42 7/30/2017 7/30/2017 0.10 COMPZ2 CASING DLOG P Correct+7.38'at flag 6,220.1 6,227.5 15:42 15:48 7/30/2017 7/30/2017 1.75 COMPZ2 CASING RUNL P Continue in well. Set down and start 6,227.5 8,890.0 15:48 17:33 1 1 working pipe from - 8400 to bottom Page 8113 Report Printed: 81812017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sten Depth Stan Time EM Time Our (hr) Phase Op Code Adivoy Code T. P -T -X Opetalion (ftKa) Erd DepN (MG) 7/30/2017 7/30/2017 0.25 COMPZ2 CASING RUNL P Liner on bottom, bring pump up to 1.5 8,890.0 7,406.7 17:33 17:48 bpm, 0.7 bpm returns, PUW 29 k, subtract liner BHA from counter 7/30/2017 7/30/2017 1.00 COMPZ2 CASING TRIP P POOH, following trip sheet, pumping 7,406.7 44.3 1748 18:48 pipe displacement 7/30/2017 7/30/2017 0.50 COMPZ2 CASING OWFF P Check well for flow, PJSM 44.3 0.0 18:48 19:18 7/30/2017 7/302017 0.50 COMPZ2 CASING PULD P LD setting tools, inspect coil and CTC, 0.0 0.0 19:18 19:48 visually inspect setting tools, everything looks normal 7130/2017 7/30/2017 1.00 PROD3 STK CTOP P Gap and marks noticed above CTC, 0.0 0.0 19:48 20:48 perform pipe maintenance, cut off connector and marks, prep and install New CTC, Pull test CTC 35 k, PT 4000 psi, "' Trim 16' of coil "" 7/30/2017 7130/2017 0.75 PROD3 STK CTOP P Meg a -line, > 2000 mohms / 87 ohms 0.0 0.0 20:48 21:33 Rehead UQ sub, 7/30/2017 7/30/2017 1.00 PROD3 STK PULD P PJSM, PU/MU Build section BHA# 9, 0.0 72.2 21:33 22:33 I surface lest tools (good test) 7/30/2017 7/30/2017 1.25 PRODS STK TRIP P Tag up, reset counters, RIH w/ build 72.2 6,060.0 22:33 23:48 section BHA# 9 ' 7/302017 7/31/2017 0.20 PROD3 STK CLOG P Log CCL connection of plus 8.0', 6,060.0 6,199.0 23:48 00:00 PUW 7/31/2017 7/31/2017 0.50 PROD3 STK TRIP P PUW 31 k, continue RIH 6,199.0 7,409.0 00:00 00:30 7/312017 7/31/2017 1.00 PROD3 STK DISP P Dry tag TOB, PUW 31 k, bring pump 7,409.0 7,409.0 00:30 01:30 on to displace well to drilling fluid. 7/31/2017 7/31/2017 1.20 PROD3 STK KOST P Kickoff billet at 7,409', 1.8 bpm at 7,409.0 7,437.0 01:30 02:42 4,300 psi, BHP 3,807, WHIP 259, IA 1250, OA 8, dry drift billet area clean. 7/31/2017 7/31/2017 2.30 PROD3 DRILL DRLG P Drill ahead, 1.8 bpm at 4,294 psi, BHP 7,437.0 7,546.0 02:42 05:00 3,753, WHIP 247, IA 1,257, OA 10 7/31/2017 7/31/2017 0.60 PROD3 DRILL WPRT P Wiper trip, PUW=35K 7,546.0 7,546.0 05:00 05:36 j 7/31/2017 7/31/2017 4.60 PROD3 DRILL DRLG P 7546', Drill, 1.81 BPM @ 4210 PSI 7,546.0 7,708.0 05:36 10:12 FS, BHP=3760, Several pick ups - Ratty drilling 7131/2017 7/31/2017 0.50 PROD3 DRILL WPRT P 7708', Wiper to billet, 7000', 7,708.0 7,708.0 10:12 10:42 PUW=39K 7/31/2017 7/31/2017 1.10 PROD3 DRILL DRLG P 7708', drill, 1.78 BPM @ 4238 PSI FS, 7,708.0 7,728.0 10:42 11:48 BHP=3802 7/31/2017 7/31/2017 1.90 PROD3 DRILL TRIP P Call end of tum / build, trip out, AVG 7,728.0 84.3 11:48 13:42 DLS=39.7°, Perform 200' jog at surface 7/31/2017 7/31/2017 1.80 PROD3 DRILL PULD P Tag up and space out. PJSM, PUD 84.3 0.0 13:42 15:30 BHA #9, Floats not holding, Power up tool and close EDC. Follow procedure for PUD with EDC shut 7/31/2017 7/31/2017 1.70 PROD3 DRILL PULD P PD BHA # 10 with .6° motor, agitator, 0.0 78.2 15:30 17:12 and RB Hyc bit, Make up to coil and surface test. Strip on well. Tag up and set counters 7/31/2017 7/31/2017 1.20 PROD3 DRILL TRIP P Trip in well, EDC open, shut EDC 78.2 6,060.0 17:12 18:24 shallow test agitator - Good Continue I 1 in well Page 9113 Report Printed: 8/812017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Siert Depth Stan Tune End Tae Dur (hr) Phase Op Code Activity Code fine P -T-% Opeation (flKB) Ertl Depth (i1KB) 7/31/2017 7/31/2017 0.20 PRODS DRILL DLOG P Log CCL for +5' correction, PUW=29K 6,060.0 6,214.0 18:24 18:36 7/3112017 7131/2017 1.00 PROD3 DRILL TRIP P Continue in well, Stack at 7710 PIU 6,214.0 7,723.0 18:36 19:36 continue in 7/31/2017 8/1/2017 4.40 PRODS DRILL DRLG P 7723', drill, 1.79 BPM @ 5050 PSI FS, 7,723.0 8,041.0 19:36 00:00 BHP=3745, RIW=9.6K 8/1/2017 8/1/2017 1.25 PRODS DRILL DRLG P OBD, 1.5 bpm at 3,960 psi, BHP 8,041.0 8,120.0 00:00 01:15 3,736, WHP 327, IA 1,343, OA 24, CTSW=2k, DHWOB=2 k, ROP 48 fph 8/1/2017 8/1/2017 0.50 PRODS DRILL WPRT P 400' wiper up hole, PUW 33 k 8,120.0 8,120.0 01:15 01:45 8/1/2017 8/1/2017 5.75 PRODS DRILL DRLG P OBD, 1.8 bpm at 5,108 psi, BHP 8,120.0 8,520.0 01:45 07:30 3,783, WHP 299, IA 1,343, OA 25, ROP ranging from 20FPH to 115 FPH. 8/1/2017 8/1/2017 1.00 PRODS DRILL WPRT P 400' wiper up hole to 7515'. PUW 36K, 8,520.0 8,520.0 07:30 08:30 8/1/2017 8/1/2017 4.50 PRODS DRILL DRLG P OBD, 1.8 bpm at 5314 psi, 1360 psi 8,520.0 8,715.0 08:30 13:00 DP, ROP from 20 to 115 FPM, pump hi vis sweeps w/ 2.5% Mone w/ limited improvement, try 5x5 sweeps. 8/1/2017 8/1/2017 0.20 PRODS DRILL WPRT P 100' wiper up hole, 42K PUW, had to 8,715.0 8,715.0 13:00 13:12 work to gel RIH 8/1/2017 8/1/2017 2.50 PRODS DRILL DRLG P OBD, 1.8 bpm, 5134 psi, 3912 psi 8,715.0 8,920.0 13:12 15:42 BHP, 1220 psi dp, 6K CW, 1k WOB, 135 FPH, ROP improved, pumped 5x5 sweep w/ 2.5% DZone 8/1/2017 811/2017 1.10 PRODS DRILL WPRT P Wiper trip to window, 34K PUW, 8,920.0 6,060.0 15:42 16:48 8/1/2017 8/1/2017 0.20 PRODS DRILL DLOG P Tie-in to CCL, 1.5' correction 6,060.0 6,195.0 16:48 17:00 8/1/2017 8/1/2017 0.20 PRODS DRILL SVRG P Injector maintenance, tighten Love 6,195.0 6,195.0 17:00 17:12 Joys 8/12017 811/2017 0.25 PRODS DRILL TRIP P Trip in, pressure cal, 6,195.0 6,197.0 17:12 17:27 ""• Pressure Survey MD 6,225', TVD 5,850', Ann 3,600 psi, 11.83ppg 8/1/2017 8/1/2017 1.50 PRODS DRILL WPRT P Wiper back in hole, RIW 0 k 6,197.0 8,920.0 17:27 18:57 8/1/2017 8/1/2017 3.50 PRODS DRILL DRLG P BOBD, 1.77 bpm at 4,933 psi FS, 8,920.0 9,158.0 18:57 22:27 BHP 3,889, WHP 257, IA 1,321, OA 30 811/2017 8/2/2017 1.55 PRODS DRILL DRLG P By pass high pressure screens, pump 9,158.0 9,191.5 22:27 00:00 20 bbl beaded pill, continue drill ahead, 1.77 bpm at 5,233 psi, BHP 3,884, WHP 277, IA 1,321, OW 30 8/2/2017 8/2/2017 1.00 PROD3 DRILL DRLG P OBD, 1.78 bpm at 5,242 psi, BHP 9,191.5 9,255.0 00:00 01:00 3,880, IA 1,342, OA 30, CTWS= minus 4 k, DHWOB=1.5 k, ROP 35 fph 8/2/2017 8/2/2017 2.50 PROD3 DRILL DRLG P Pump 20 bbl beaded pill, continue 9,255.0 9,319.0 01:00 03:30 drilling ahead, 1.77 bpm at 5,372 psi, BHP 3,889, WHP 266, IA 1,330, OA 30 8/2/2017 8/2/2017 0.50 PRODS DRILL WPRT P Wiper up hole, PUW 33 k 9,319.0 8,300.0 03:30 04:00 Page 10113 Report Printed: 8/812017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Sten Time End Time Ow (hr) phece Op Code Aa ty Cade Time P -T -X Opeteeon (ftKB) End Depth (ftKB) 8/2/2017 8/2/2017 0.40 PRODS DRILL WPRT P Wiper back in hole, TIW 4 k, lowering 8,300.0 9,319.0 04:00 04:24 pump rate to 0.9 bpm to get back to bottom. 8/2/2017 8/2/2017 1.90 PRODS DRILL DRLG P BOBO, 1.8 bpm at 5,400 psi, BHP 9,319.0 9,372.0 04:24 06:18 3,969, WHP 258, IA 1,323, OA 28, CTSW= 0 k, DHWOB=1.5 k, ROP= 55 fph 8/2/2017 8/212017 0.20 PROD3 DRILL WPRT P Wiper up hole, PUW 34K 9,372.0 9,372.0 06:18 06:30 8/2/2017 812/2017 3.50 PRODS DRILL DRLG P OBD, 1.8 bpm at 5420 psi, BHP 3976 9,372.0 9,505.0 06:30 10:00 psi, WHP 268 psi, -3K CTW, WOB=1.6K, Pump 20 bbl beaded pill, swap to new mud at 9486'. 8/2/2017 8/2/2017 3.10 PRODS DRILL DRLG P OBD, new mud at bit, 1.8 bpm, 5121 9,505.0 9,590.0 10:00 13:06 psi, BHP 3983, WHP 279, CTW= -.2K, WOB=1.2K, ROP 15 to 30 FPH 8/2/2017 8/2/2017 1.40 PRODS DRILL WPRT P Wiper to window, PUW 40K, jet 5-1/2" 9,590.0 6,060.0 13:06 14:30 8/2/2017 8/2/2017 0.30 PRODS DRILL DLOG P Tie-in to CCL, +1.5' correction, 31 K 6,060.0 6,206.0 14:30 14:48 PUW 8/2/2017 8/212017 1.30 PRODS DRILL WPRT P Wiper in hole, weight swings at 8710' 6,206.0 9,590.0 14:48 16:06 and 8900' to 9000', -2 to +SK. 8/2/2017 8/212017 2.75 PRODS DRILL DRLG P BOBD, 1.8 bpm at 5433 psi, BHP 9,590.0 9,681.0 16:06 18:51 3981, WHP 333, CTW= 4K to -1.2K, WOB= 0.8K, ROP 25 to 45 FPH. 8/2/2017 8/212017 2.00 PRODS DRILL WPRT P BHA wiper up hole, PUW 35 k 9,681.0 9,681.0 18:51 20:51 8/2/2017 8/3/2017 3.15 PROD3 DRILL DRLG P BOBO, 1.52 bpm at 4,297 psi, BHP 9,681.0 9,819.0 20:51 00:00 3,942, WHP 596, IA 1,455 psi, OA 22 psi, pumping 10 bbl mud x 10 bbl beads x 10 bbl mud 8/3/2017 813/2017 0.50 PROD3 DRILL WPRT P Wiper up hole, PUW 50 k, 9,819.0 8,819.0 00:00 00:30 8/3/2017 8/3/2017 0.50 PRODS DRILL WPRT P Wiper back in hole, RIW minus 4 k 8,819.0 9,819.0 00:30 01:00 8/3/2017 8/3/2017 3.25 PRODS DRILL DRLG P BOBD, 1.82 bpm at 5,100 psi, BHP 9,819.0 9,925.0 01:00 04:15 4,034, WHP 363, IA 1,398, OA 21,• CTWS=O k, DHWOB=1.4 k, ROP30- 60 fph, pumping low -vis and high -vis beaded sweeps 813/2017 8/312017 0.50 PRODS DRILL WPRT P 200' Wiper up hole, PUW 32 k 9,925.0 9,925.0 04:15 04:45 8/3/2017 8/3/2017 5.00 PRODS DRILL DRLG P BOBO, 1.8 bpm at 5,100 psi, BHP 9,925.0 10,065.0 04:45 09:45 3,890, WHP 598, IA 1437, OA 22 8/312017 8/3/2017 1.10 PRODS DRILL WPRT P Wiper up hole 500', PUW= 38K 10,065.0 10,065.0 09:45 1051 8/3/2017 8/3/2017 3.30 PRODS DRILL DRLG P BOBD, 1.8 bpm at 5500 psi, BHP 10,065.0 10,168.0 10:51 1409 4081, WHP 500, IA 1426, OA 19. 8/3/2017 813/2017 2.80 PRODS DRILL WPRT P TO called, pump 10 x 10 sweep, 10,168.0 78.2 14:09 16:57 perform swab wiper 8/3/2017 813/2017 1.25 PRODS DRILL TRIP P Tag up, reset counters, RIH 78.2 6,060.0 16:57 18:12 8/3/2017 813/2017 0.25 PRODS DRILL DLOG P Log CCL correction of plus 6.0' 6,060.0 6,190.0 18:12 18:27 8/3/2017 813/2017 1.50 PRODS DRILL TRIP P Continue IH 6,190.0 10,168.0 18:27 19:57 8/3/2017 8/3/2017 0.50 PRODS DRILL TRIP P Confirm TO 10,168', PUW 40 k, line 10,168.0 10,168.0 19:57 20:27 up to liner running pill Page 11113 Report Printed: 6/8/2017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SGrrt DapN Start Time End Thee Our (hr) Phase Op Cade AWvar Cede Time P-T-X Cperabon (Po(a) EM Deem (1tKa) 8/3/2017 8/3/2017 1.50 PROD3 DRILL DISP P POOH, laying liner running pill 10,168.0 6.230.0 20:27 21:57 8/3/2017 8/3/2017 1.25 PRODS DRILL DISP P At the window, displace well to 6,230.0 78.2 21:57 23:12 competion fluid while POOH, filling trip sheet. 8/3/2017 8/412017 0.81 PROD3 DRILL OWFF P Check well for flow, flow seen at 1" 78.2 78.2 23:12 00:00 haliburton valve, shut in and monitor well, WHP 28 psi, open choke bleed off pressure to the pits, continue to monitor well, observed flow, close 1 pressure build of 27 psi 8/4/2017 8/4/2017 0.25 PROD3 DRILL OWFF P Check well for flow, flow seen at 1" 78.2 78.2 00:00 00:15 haliburton valve, shut in and monitor well, WHIP 28 psi, open choke bleed off pressure to the pits, continue to monitor well, observed flow, dose 1 pressure build to 27 psi, Discuss with DE, reset counters. 8/4/2017 8/4/2017 1.20 PRODS DRILL TRIP T RIH, pumping 0.3 bpm at 319 psi, 78.2 6,060.0 00:15 01:27 WHP=44 psi 8/4/2017 8/4/2017 0.50 PRODS DRILL DLOG T Log CCL correction of plus 6.0' 6,060.0 6,208.0 01:27 01:57 8/4/2017 8/4/2017 1.25 PROD3 DRILL DISP T Continue RIH to 6200', displace well to 6,208.0 6,208.0 01:57 03:12 12.2 ppg completion fluid. 130 bbls returned 8/4/2017 81412017 0.75 PRODS DRILL OWFF T Check well for flow, Gas Cut fliud at 6,208.0 6,208.0 03:12 03:57 surface 8/4/2017 8/4/2017 1.00 PRODS DRILL CIRC T Circulate bottoms up 6,208.0 6,208.0 03:57 04:57 8/4/2017 8/4/2017 0.50 PROD3 DRILL OWFF T Check well for flow, no flow observed 6,208.0 6,208.0 04:57 05:27 8/4/2017 8/4/2017 0.90 PROD3 DRILL TRIP T POOH pumping pipe displacement: 6,208.0 78.2 05:27 06:21 1 1 with 40% returns 8/4/2017 8/4/2017 1.40 PROD3 DRILL PULD T Flow check well, no flow observed. 78.2 0.0 06:21 07:45 Laydown BHA #10 over dead well. 8/4/2017 8/4/2017 2.70 COMPZ3 CASING PUTB P Prep rig floor, PJSM, pick-up Lt-02 0.0 0.0 07:45 10:27 lower liner segment; non-ported bullnose, 50 Its of 2-3/8" slotted liner, and shorty deployment sleeve. Fill hole every 10 jnts. 8/4/2017 814/2017 0.60 COMPZ3 CASING PULD P Make up coil track BHA, set in 2,041.1 2,041.1 10:27 11:03 deployment rams, Change checks in UQC, MU to coil, surface test, strip on well, set counters 8/4/2017 8/4/2017 5.00 COMPZ3 CASING RUNL P RIH w/ BHA#11, 0.8' correction at 2,041.1 10,168.0 11:03 16:03 window flag, continue in well, sat down at 7904', begin working liner to 9600', gain 6K wieght back, able to RIH 30 to 40 FPM. 8/4/2017 8/4/2017 0.40 COMPZ3 CASING RUNL P Liner on bottom, bring pump to 1.5 10,168.0 8,171.2 16:03 16:27 bpm, 4800 psi, PUW 31 K, subtract liner BHA from counter 8/4/2017 8/4/2017 1.50 COMPZ3 CASING TRIP P POOH, slow while making beaded 8,171.2 8,171.0 16:27 17:57 liner pill. 8/4/2017 8142017 1.70 COMPZ3 CASING TRIP P POOH, laying in 12.2 ppg beaded liner 8,171.0 6,009.0 17:57 19:39 1 running pill. 8/4/2017 814/2017 0.25 COMPZ3 CASING OWFF P Check well for flow 6,009.0 6,009.0 19:39 19:54 814/2017 8/4/2017 1.15 COMPZ3 CASING TRIP P POOH 6,009.0 44.3 19:54 21:03 Page 12/13 Report Printed: 8/812017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log • Star/ Depth Start Time End Time Our (hr) Phase Op Code A Vdy Code Time P -T -X Operabon (flKB) EM Depth (ftKB) 8/4/2017 8/4/2017 0.50 COMPZ3 CASING OWFF P At surface, check well for Flow, PJSM 44.3 44.3 21:03 21:33 8/4/2017 8/4/2017 0.50 COMM CASING PULD P LD settling tools 44.3 0.0 21:33 22:03 8/4/2017 8/4/2017 0.35 COMPZ3 CASING PUTB P Prep rig floor for liner ops, PJSM 0.0 0.0 22:03 22:24 8/4/2017 8/5/2017 1.60 COMPZ3 CASING PUTB P PU/MU upper liner segment with 51 its 0.0 1,161.8 22:24 00:00 of slotted liner 8/5/2017 8/5/2017 1.25 COMPM CASING PUTS P Continue PILI upper liner segment 1,161.8 2,058.0 00:00 01:15 8/5/2017 8/5/2017 0.75 COMPZ3 CASING PULD P PJSM, PU/MU CoilTrak tools, surface 2,058.0 2,107.8 01:15 02:00 test, (good test), strip down onto stump 8/5/2017 8/5/2017 1.25 COMPZ3 CASING RUNL P RIH, pumping min rate 0.3 bpm 2,107.8 6,093.0 02:00 03:15 8/5/2017 8/5/2017 0.75 COMPZ3 CASING RUNL P Correct to the 4,000' EOP flag plus 6,093.0 7,808.0 03:15 04:00 8.3', puw 30 K, continue IH 8/5/2017 8/5/2017 0.70 COMPZ3 CASING RUNL P Tag up at 7808, work pipe down to 7,808.0 8,177.0 04:00 04:42 bottom 8/5/2017 8/5/2017 0.20 COMPZ3 CASING RUNL P Release from liner, bring pump to 1.5 8,177.0 6,110.0 04:42 04:54 bpm, 4350 psi, 30K PU, reset counter 8/5/2017 8/5/2017 1.10 COMPZ3 CASING DISP P Displace out KWF, roll well over to SW 6,110.0 6,110.0 04:54 06:00 8/5/2017 8/5/2017 2.20 COMM CASING TRIP P PUH to 2500', LRS pushed 30 bbl& 6,110.0 44.2 06:00 08:12 diesel to coil, continue OOH, lay in diesel FP. 8/5/2017 8/5/2017 1.80 COMPZ3 CASING PULD P PUD and laydown BHA#12. 44.2 0.0 08:12 10:00 8/5/2017 8/5/2017 1.70 DEMOB WHDBOP MPSP P PJSM, RU, lubricate and set BPV, 0.0 0.0 10:00 11:42 perform negative test, RD valve crew 8/5/2017 8/5/2017 1.30 DEMOB WHDBOP NUND P MU 2" nozzle, slide injector cart over, 0.0 0.0 11:42 13:00 stab on, jet BOP stack, move injector off 8/5/2017 8/5/2017 0.50 DEMOB WHDBOP NUND P Borescope inspection on BOP stack 0.0 0.0 13:00 13:30 8/5/2017 8/5/2017 2.50 DEMOB WHDBOP NUND P Blowdown lines, suck out stack, pour 0.0 0.0 13:30 16:00 in MEOH on top swab, disconnect Putz, off high line power, 15:00 8/5/2017 8/5/2017 2.00 DEMOB WHDBOP NUND P ND BOPE 0.0 0.0 16:00 18:00 Rig Released 18:00 hours 8/5/2017 Page 13/13 Report Printed: 818/2017 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H -26L1 50-103-20208-60 Baker Hughes INTEQ Definitive Survey Report 11 August, 2017 BA ER F�UGHES E ttnnpa, ConocoPhillips no�pucHEs 0 ConocoPhillips Definitive Survey Report 9 Comfort, C0u0C0PindlIpa Alasua)IOC.-Kup2 Loral Coafdinms Reference: VtleII 3H-26 protect: Kuparuk River Unit NO Reference: 3H -26@O 80.00uah ZH-26) Site: Kuparuk 3H Pad MO Reference: 3H-25 @6000uaft(3H-2fi) Well: 311-26 North Reference: True Wellbore: 31 Survey Calculation Method Minimum Curvature Design: 3H -25L1 Dadards, EDT Alaska Sandb0x Protect Kuparuk River Unit North Slope Alaska, United States Map Stood.: US State Plane 1927 (Exact solution) System Damm: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Welt 3H26 Well Poaltlon ♦NI -S 000 an Nodding: 5000,27270 ueN Latitude: ]0'24'43.124N +EI -W 000 usfl Eading: 49865481 usft Longitude: 150. 0'39435W Position uncertainty 000 usfl Wellhead Elevation: usfl Ground Level: 0.00 usfl Wellbore 31-1-261.1 Magnetic. Model Name Sample Dust Dediru0on DIP Angle Field Strength (°) (11 Inn BGGM2017 9/1/2017 1742 8095 57487.12 Design 3H-2611 Audit Nates: Version: 10 Phase: ACTUAL ne On Depth: 5,974.70 '.. Vertical Section: Depth From I7VO) .1i +EI.W Direction lu.ft) (elft) (usft) f) 8000 0 00 000 180.00 Survey Program Date 711 From To Survey Survey Wsft) (waft) Survey Mallbure) Tool Name Description Stanoele End Date 121.00 5,974.70 3H -26(3H-16) MWD MWD - Standard 111212001 6,229.65 632045 31 MWD-INC(3H-26L1) MWD -INC ONLY MWD-INC_ONLY _FILLER 712312017 712412017 6.350.41 8,724.12 31 MWD(311-261.1) MAID MWD -Standard 712412017 712712017 8/112017 428: 15PM Page 2 COMPASS 5000.14 Build 85 �- ConocoPhillips %^ 0 ConocoPhillips Definitive Survey Report COmpaOY: ConocoPhillips(Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kuparuk 3H Pad Well: 3H-26 Wellbore: 3H-26Lt Oe51gn: 3H-26LI Survey Local Co-ordinate Reference: Well 3H-26 WO Reference: 311-26 @ 80.00usn (3H-26) MO Reference: 31136 @ 8000usfl (311-26) NOnb ReMrence: True Survey Calculation Method: Minimum CunaMre Database: EDT Alaska Santlbox MD 8/11200 4 28 15P Papa 3 COMRISS 500014 Bui1r1 a5 MD Inc Aal ND WOSS ANIS �V M NOMUIp Easting OLS 8ecrdtlun (uenl (9 (°) (tsn) (-an) loan) (4m) (n) RU pnowl lid Survey Tool Wake Annotation 5,97470 2380 18270 5,65342 5,57302 -1,144.12 -Mass 5,999,12895 498,]45.]8 366 1,144.12 MW41NC_ONLY (2) TIP 6229.65 1656 180.57 5,892.16 5,81216 -1.23176 -315.45 5999,"1.12 498.3E.P 200 1,231.76 M INC ONLY 9) KOP 6,200.30 23.16 178.00 592105 5,"1.05 -1,24316 31553 !U19iM 496339.09 1432 1,242.16 M INC ONLY (2) IOt.wlatetl ASimm 6.290.26 3743 16500 5.946.81 6,8%.81 -1.2%88 31276 5.999.016.00 49631186 5106 1,256.00 M INCONLY(2). IntemDlatetl Azimuth 6.32045 %.29 163.60 5.961.97 500797 -1 an 309.95 5.996995.41 490,34766 52.33 1277.48 MN0.1NC_ONLY(2) Intetpolieud Aaimuth 6,350.41 60.04 16368 5,992.61 5,90263 -1,302.46 -299.63 5,993.87042 49635497 49W 1,302.46 M40 (3) First Clean Survey 6,37910 0174 16203 5,M,N 5,910.24 -1,mm -MI 45 5,990,94343 498,38345 46.14 1,329.40 MNO (3) 6,41062 0742 18262 5.947.16 5,913.16 -1,356.02 -282.26 5,996914.0 498,372.33 10.37 1,3%82 MWD (3) 6,43978 0,12 162.96 5.003.79 5,91379 -1.3%.67 -273M 5.998,893 22 498,300.95 9.30 1.36667 MWD (3) 6,46981 003 16349 5,59:1.23 5,91323 -1,41541 -20497 5,996.85740 496389.61 660 1,41541 MWD(3) 6,502.51 94.92 164.42 5,99124 5,911N -1,448.70 35595 5,996029.1.1 490,3&9.67 920 1,446.78 MWD(JI 6,52901 97.37 184.97 5,980.32 5,908.22 -1,472.96 -24879 5,996794.94 490,405.78 920 1,472.96 MWD(3) 6.559.83 sew Meet 5,50424 59(X.24 -1,50180 -24153 5,006771.10 49641303 876 1,501.80 MWD(3) 6,589.91 98.11 IW75 59n% 5,099.96 -1530.90 -23523 5.998,74200 490.41932 6.40 1,53].90 avi 66"964 87.80 1611.87 597584 5.09594 -1.559.78 -22952 5998.713.12 498,425.03 1.12 1,cNi evi 6,650]0 97.70 IN87 5,97184 509164 -0,590.1.1. -II383 5,9'4,882]9 498,4]072 320 1,590 11 1400a) 6,69.03 98.32 17142 5,96759 5,867.59 4,61848 219.15 5,900654.41 498,435.39 570 1618A9 MND (3) 6.T09W 96.50 175.50 5953.15 5.081.15 -1,840.02 215.77 5.990,82 .89 498,43877 1348 1,E4802 MND (3) 6,740.07 M75 1756 5.958 6 5.68 .57 4,67776 31352 5.995.595.14 498,44101 123 1,6716 MRD (3) 676Q74 633 176.94 5.984.42 56442 -170706 -211,M 5.900,5656 496,44284 597 1,70700 Ni (3) 6,700.03 90.% 178W 5,95024 5,6024 -1.714.80 -21054 5,900,535.06 49644390 718 1,736.65 MND (3) s ecn,5 00.94 101.32 5,94545 5,4545 -1,760.09 -21053 5,990,5%02 498,44398 986 1,766.09 MND (3) 6859.71 101.69 183.6 5,939]7 5.05977 -1,795]0 -211.79 595647714 498,44271 9.32 17078 MRD (3) 6690.03 102.44 185" 5933.43 5053.43 -1,62533 314.23 5990,44700 498,44020 7.Y3 1,82533 MWD (3) 6,924.91 IM23 1691 592596 5."598 4,859.15 -218.30 5.980.41377 498,43619 5.83 186915 MWD (3) 6,9',4.10 102.09 10732 5,920.% 5,"0% -1083." -221% 5,990,30929 498,432.92 235 1,063" MWD (3) 669.63 00.at 184.92 5,91521 !UIM2 -1,91241 -YM .% 5,998,N052 498,42.83 12% 1,91241 ME 7.000.80 94.92 17984 5,91"49 5.03149 -1,942.31 -225.90 5.99633].63 496428.59 21.50 1,94231 MWo (3) 7,039.62 Ato 17931 5.908.96 5.820.08 1.972.02 -225.60 5.996329392 498.428.80 1.80 1.972.02 MWD (3) 7.069.60 94.14 17475 5,906.58 5.6'$% -ZwlN -2412 5,89627100 48643035 1525 200194 MWD (3) 8/11200 4 28 15P Papa 3 COMRISS 500014 Bui1r1 a5 ConocoPhillips CorvocoPhllllps Definitive Survey Report Company: ConomPhillips(AWska) Inc.-Kup2 Local Coordinate Reference: Project: Kupamk River Und WD Reference: Site: Kuparuk 311 Pad MO Reference: Well: 3W26 North Reference: Wellbore: 3H -26L1 6u1ey Calculaflon MMhod: Deslgn'. 3H26L1 Database: Survey Nkll 3H-26 3H-26 @ 8000usn (31+26) 344-26 @ 80.00usfi (31+26) True Minimum CurveW. EDT Alaska Sandbox -� ER �I.i�mS Map Map Vadical MD Inc Aa WD Wass +WS +Ef-W NoMin 0 Eastin 9 DLS Section Wsnl (1I I°I Wan) laanl Wanl luanl 1°n99•) Survey Tool Nama Annotation Inl tnl (n) ],101.% 91.1] 1]1.04 590507 582507 -2033.63 -220.17 5990,239.32 498.431.29 15.05 3,073.63 MWD(3) 1,130.08 5031 166.50 5.904.10 5824]0 -205151 -21171 5.998.2110 498,439.75 1522 2%161 NAND (3) 1160.65 %55 184.]5 6,904.4] 5824,47 -2.09115 -21720 5.9%181.50 498,44726 675 209115 MAO(3) 7,19110 003 164.C5 5,903.]9 582.1.]8 -2,1.20.46 -19902 5,99a152.49 48545043 536 2128.43 MWO(3) ],272.00 92.0] 163.48 s9W 70 56n70 -215011 -1039 5,999,122& 480,46406 188 216011 Nal)(3) ],250]1 92.37 161.14 507161 5,82161 -2,177.44 10167 5,9%,0%.51 48548.]] 625 297.44 MD 7,201.23 9330 16022 5,933.% 5,820.00 3,205 20 -171.56 5,9950%.]5 488.40285 047 2286.20 MWD(3) 7,311.02 93.07 15615 5,899.24 581624 -2,233.99 -161.02 5,9%,IX ie 490.4%40 ].01 2233.99 MfA(31 ].3412] 93% 1%at 5.8%.22 5.81622 -226187 -14946 5,%501180 490.50.% 451 226187 MAVD(3) j ],3]000 9351 15561 5.8&.33 5.81490 -2288.84 -13]5] 5907984.4 498.51684 4,33 220681 MAD(3) 7.40102 8940 149]5 51M4 n 5,813.]9 -2,31586 -02372 5,90],95).29 495530.69 25.72 231550 MWO(3) ],43088 87.91 149]3 5,89475 5814.]5 -2,34144 -10860 5,907,931.51 49554572 1.64 234144 MWD(3) ],460.]] east 147.19 5.895.52 5815.52 .2370.31 -%.95 5,907,90264 498,553.44 8.% 2370.31 UMD(3) ],4904] 90.09 14506 5,895.61 5.81561 -239165 -3663 5.997,88130 4%,577_]6 659 2,39165 MR111)(3) 7,520.68 0.0 148.80 5,894.78 5.81478 -241695 6018 5.997,856.00 498.594.22 1518 2,416% MWD(3) 7,551.18 91.14 14983 6,893.87 5,81367 -2443.16 44.60 5,907,68]9 498,817.]] 708 2,44316 MND(3) ],58050 910 15143 5,89311 5,013.11 Z468 70 -30.23 5,997,6014.25 498,624.14 546 240910 MIND (3) 7,611,02 93.47 15396 5.89191 5,811.91 -2.4%.50 -1624 5,997,M.15 498,630.4 1147 2,495.80 MIND (3) 707 17 9175 166.00 5.89040 5,01040 -2.525.80 -223 5.997.74715 4%,652.12 60 2525.80 MWD(3) 76]1 28 92.% 158.50 5,88928 5,809.28 -2,560.78 824 5.997.712.17 495662.59 1022 255010 M iD(3) 7,]00.]7 91.20 159.64 5,888.22 5,&@YI -2,5]0.31 18.P 5,997,694ffi 498,6/3.11 ].OB 253`8.31 MAT) (3) ],]30.98 W12 16514 assist 5,Basal -2,607.20 27.89 5,997,5650 4956@.23 20.81 2607.04 MND(3) 7.76153 93.89 10791 5884.73 580413 -2,63563 35.25 599],636.33 498.689.58 595 263683 MWO(3) ],]9082 9117 170.11 5.88349 5801.49 -268530 4108 5.997.60766 490.69541 1390 266030 MWD(3) 7,820.31) 9160 171.56 5,882.]] 5802.7/ -2,894.80 45.65 5,9075]8.06 498,70017 505 2694.89 MWO(3) 7.85090 9144 17426 5,881.% 5.00156 -2]24.84 49.50 590].540.13 498,70,89 8.95 272484 WMA) (3) f7.8"179 68.22 17479 5862.06 5,802.06 -2,75778 W74 593751519 498,707 04 9.% 215718 MWD(3) ],913]9 870 9755 5,891.14 5,803.14 -2,78739 54.]2 5,907,48558 498,709.02 950 2,78739 MND(3) ],9412] 88.90 1]932 5,894.16 5804 16 -281484 55.47 5,90],458.13 498,]09.]] 665 2.81404 MWD(3) ].9]141 8730 18223 5,6%.% 6.805.38 -2020.95 55.% 5,907428.02 498109.35 10.07 2844.95 MWD(3) 8.001.16 8742 19519 5,896.]5 5,805.75 -2874.80 53.14 6,997,398.38 498,]0].42 9.0 2,87460 MWD (3) 8/112017 4 2815PM Papa 4 COMPASS 500014 Build 65 %. CormoPhilli P' ConocoPhillipsER Definitive Survey Report 1 � " Company CenomPh66ps(Maska) Inc.-Kup2 Local CuorJinate Rate.... We83H-26 Map Project: Kupamk River Unit WO Reference: 3H26 @ 80.00ustt (3H-26) MD Site: Kupanuk 3H Pad MU Reference: 311-26@8000us6(311-26) WDSS Well: 3H-26 Noah Reference: True Setting Meec, 3H -26L1 Survey Calculation Method: Minimum Curvalwe M ne5ign: 3H25L1OeMbaee: (uaRl EDTAlaske Sandbox (.eft) Survey 6118011 428:15944 Page 5 COMPASS 5000.14 Sold 65 Map Map Vertical MD Inc Aai WD WDSS *N/S +S.W Nanning hin Setting Surrey Tool Nance Mn0ldhOn (uaNl M V) (uaRl Juan) (.eft) (-am (M (R) (.Mw,) 8,03137 M25 18900 508769 5,60L09 -2.90.55 4941 5.991.YS.43 496,70369 12N 2,9".55 awet(3) ecomm 89.75 194.05 5,8191 58".41 -2933.]] 4345 5,991,33912 488,69]]3 1799 2,9331] VIWD(3) noonda 88.77 197.35 5,88 19 5,8[8.79 -296.29 3544 5,997,310.70 498,689.71 1162 296229 101iD(3) B, 124.31 07.82 20105 544.79 5,00.19 -2.99380 N.43 5,997,279.11 498618.10 Ma 299388 M S) 8,15110 an 25 204.0 5,01 .18 5811.18 .3,01868 14.14 5,591,254.74 498,09 ,40 120 3,01865 MWD(3) 8,18102 9931 205.71 Said 12 5.813.12 3.0,1555 136 5,997,Y xI5 490.655.62 9.B 3"5.55 MWD (3) 821125 Be 21t 20916 5,M 07 5,01507 3,08.19 -12.79 5,991,20.01 498,641,47 1.0 3.02.19 MWO(3) 8140.69 8742 24445 6,81 5.81669 4.027 17 -20.21 5,01,17505 498,825.98 1835 3.01.17 M (3) 8,27107 0.31 22045 6,09129 5.81729 3,1219 -4613 5.01,151.15 498,607.52 21.92 3,77437 MIND (3) 0,30.0 0.37 219.74 5891.11 5,811.11 3,14499 65.0 5,991,128.0 498,508.32 239 3,14407 MWD(3) 8,331.32 "04 211.51 5,89154 5,811.54 3.161.85 -84.0 5,997,10.19 49850.32 lo.0 3,16.85 MWD(3) 8,30'155 91.51 21753 5.89165 5817.96 3191.82 -10334 5.997.0121 40.599.91 11.46 319102 MWD(3) 8,39136 0.0 21608 5,89725 5,01725 -3,21568 -12119 5,90,0636 490,533.05 695 321560 MJ nn 8,415.33 0.12 21250 5,80.0 581886 -3,235.46 -134.0 51991,07.59 49851955 22.0 3,235.46 hlWi B.445.11 ItSm 2942 5,900.27 5,874.21 -3,260.92 -149.0 5,991,02.13 490,0416 10.75 32600 MADS) 8481.15 89.0 0160 5902.35 5.022.35 -3.292.52 -167.17 508,950.54 498.46." a84 3,20.52 MND(3) eatitm 0717 20100 6.90.55 5823.55 -3.31791 -180.36 59981965 10 490.47308 366 3.317.97 MND(3) 6.543.2 0.0 444." 5.9".40 5,82448 y348.0 -10.01 5,MM,07 498,4022 9.02 3348.0 MWD(3) 869.05 91.0 742.08 5.9".05 5Wxl05 -3,30.01 -2092 5,60,8922 40pN.0 985 3,30.01 MD (3) 861132 0.0 199.58 500.40 5.82340 3.41096 -M0.74 590,66.12 40,433.48 BN 3,410.56 MWO(3) 8640.0 89.48 19740 5,6037 5,823.37 3,4390 -23012 5,90,87405 40,424.0 834 3499107 ani (3) 864.19 0.56 197.13 5,02.49 5,822.49 3,470.13 -24016 5996.802 36 40,41405 1233 3470.13 MWD (3) 0,10441 9233 195.73 5,90.93 5.820.93 34063 -24884 5.90,713.46 49840.36 776 3,4WW MWO(3) , 8,72412 69.63 19401 5,90.0 Smain 351664 -254.03 5,99154.45 40,40.11 1047 3,518.64 MWD(3) 8,11300 090 19401 5.5100 91 5,820.91 3556.90 -2'66.53 5.doISo 49836.6 0.0 a565.90 PROJECTEDto TO 6118011 428:15944 Page 5 COMPASS 5000.14 Sold 65 21 7087 BA ER PRINT DISTRIBUTION LIST 28 5 4 5 F UGHES a GE company COMPANY ConocoPhillips Alaska, R E C E I V E WELL NAME 3H -26L1 8 2011 FIELD Greater Kuparuk Area COUNTY North Slope Borough CC BHI DISTRICT ie sign and return one copy of this transmittal form to: 3coPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) G Street. DATA LOGGED forage, Alaska 99510 MSK/ -SENDER of this data. LOG TYPE GR - RES LOG DATE August 4, 2017 AUTHORIZED BY Patrick Rider EMAIL Patrick.Ridera@bakerhuohes.com TODAYS DATE August 24, 2017 STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION 4 1 BP North Slope. LOA, PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 Conoco Phillips Alaska Inc. Attn: Tom Osterkamp ATO 3-344 700 G Street Anchorage, AK 99510 3 Exxon Mobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division ofOil & Gas *** Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 �* Stamp "confidential" on all material deliver to DNI 6IBP Exploration (Alaska) Inc. Petrotechnical Data Center, 1R2-1 900 E. Benson Blvd Anchorage, Alaska 99508 Revision No Details: Rev. Requested by: -- FIELD/ FINALCD/DVD FINAL PRELIM (las, dlis, PDF, META, SURVEY REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTS9 Ur MIN # OF COPIES 1# OF COPIES # OF COPIES V V V 0 0 0 0 0 0 0 0 0 0 0 1 1 1 1 1 1 1 0 TOTALS FOR THIS PAGE: 0 2 3 3 0 ConocoPhillips RECEIVED AUG 2 8 2017 AOGCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H -26L1 60-103-20208-60 Baker Hughes INTEQ Definitive Survey Report 11 August, 2017 21 7087 BAT UGHES a GE company 28545 ConocoPhillips lggc'(HES 0 y. ConocoPhillips Definitive Survey Report Company: ConowPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 3H-26 Project: Kuparuk River Unit TVD Reference: 3H-26 @ 80.00usft (3H-26) Site: Kuparuk 3H Pad MD Reference: 3H-26 @ 80.00usft (31-1-26) Well: 3H-26 North Reference: True Wellbore: 31-1-2611 Survey Calculation Method: Minimum Curvature Design: 3H-2611 Database: EDT Alaska Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 3H-26 Well Position +N/S 0.00 usft Northing: 6,000,272.70usft Latitude: 70" 24'43.124 N •E/ -W 0.00 usft Easting: 498,654.81 usft Longitude: 150'0'39A35 W Position Uncertainty 0.00 usft Wellhead Elevation: uslt Ground Level: 0.00 usft Wellbore 31-1-2611 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (1) (nT) BGGM2017 9/1/2017 17.42 80.95 57,487.12 Design 31-1-261-1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 5.574.70 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) just) (1) 8000 0.00 0.00 180,00 Survey Program Date 7/28/2017 Survey Survey From To (usft) (usft) Survey (Wellborn) Tool Name Description Start Date End Date 121.00 5,974.70 3H-26 (31-1-26) MWD MWD -Standard 1/12/2001 6,229.65 6,320.45 31-1-261-1 MWD -INC (3H-261-1) MWD-INC—ONLY MWD-INC_ONLY_FILLER 7/23/2017 7/24/2017 6,350.41 8,724.12 3H-261-1 MWD(21H-2611)MWD MWD - Standard 7/24/2017 7/27/2017 Page 2 COMPASS 5000.14 Build 85 81112017 4:28'15PM 8/112017 4:28:15PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips 6acER p ConocoPhilli s I� UG ES Definitive Survey Report Company: ConomPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 311-26 Project: Kuparuk River Unit TVD Reference: 31-1-26 @ 80.00usR (3H-26) Site: Kuparuk 3H Pad MD Reference: 3H-26 @ 80.00usR (3H-26) Well: 3H-26 North Reference: True Wellbore: 311-261-1 Survey Calculation Method: Minimum Curvature Design: 31H-2611 Database: EDT Alaska Sandbox Survey Map Map Vertical ' MD Inc AN TVD TVDSS +N/S +E/ -W DLS Northing Easting Section Survey Tool Name AOOOt8fi0D (usR) Q) 1 Will) (usR) (usR) (usR) IR) IR) ('1100') (it) 5,974.70 23.80 182.70 5,653.02 5,573.02 -1,144.12 308.86 5,999,128.75 498.345.78 3.66 1,144.12 MWD -INC _ONLY (2) TIP 6,229.65 16.58 186.57 5,892.16 5,812.16 -1,231.76 -315.45 5,999,041.12 498,339.17 2.88 1,231.76 MWD-INC_ONLY (2) KOP 6,260.38 23.16 176.00 5,921.05 5,841.05 -1,242.16 -315.53 5,999,030.72 498.339.09 24.32 1,242.16 MWD -INC ONLY(2) Interpolated Azimuth 6,290.26 37.43 165.00 5,946.81 5,866.81 -1,256.88 312.76 5,939,016.00 498,341.86 51.06 1,256.88 MW9-INC_ONLY (2) Interp0lated Azimuth 6,320.45 53.20 163.68 5,967.97 5,887.97 -1,277.48 -306.95 5,998,995.41 498,347.66 52.33 1,277.48 MWD -INC ONLY (2) Interpolated Azimuth 6,350.41 68.04 163.68 5,982.63 5.902.63 -1,302.46 -299.63 5,998,970.42 498,354.97 49.53 1,302.46 MWD (3) First Clean Survey j 6,379.70 81.74 162.63 5,990.24 5,910.24 -1,329.46 -291.45 5,998,943.43 498,363.15 46.90 1,329.46 1 (3) 6,410.62 87.42 162.62 5,993.16 5,913.16 -1,358.82 -282.26 5,998,914.06 498,372.33 18.37 1,358.82 MWD(3) 6,439.78 90.12 162.96 5,993.79 5,913.79 -1,386.67 -273.64 5,998,886.22 498,380.95 9.33 1,386.67 1 (3) 6,469.81 92.03 163.49 5,993.23 5,913.23 -1,415.41 -264.97 5,998,857.48 498,389.61 6.60 1,415.41 MWD (3) ` 6,502.51 94.92 164.42 5,991.24 5,911.24 -1,446.78 -255.95 5,998,826.11 498,398.63 9.28 1,446.78 MWD(3) ( 6,529.81 97.37 164.97 5.988.32 5.908.32 -1,472.96 -248.79 5,998.799.94 498,405.78 9.20 1,472.96 MWD (3) 6,559.83 98.26 166.81 5,984.24 5,904.24 -1,501.80 -241.53 5,998,771.10 498,413.03 6.76 1,501.80 1(3) 6.589.91 %.11 168.75 5,979.96 5.899.96 -1,530.90 -235.23 5,998,742.00 498,419.32 6.40 1,530.90 MWD(3) 6,619.64 97.80 168.87 5,975.84 5,895.84 -1,559.78 -229.52 5,998,713.12 498,425.03 1.12 1,559.78 1 (3) 6,65038 97.70 169.87 5,971.64 5,891.64 -1,590.11 -223.83 5.998,682.79 498,430.72 3.20 1,590.11 1(3) 6,679.83 98.32 171.42 5,967.59 5,887.59 -1,618.49 -219.15 5,998,654.41 498,435.39 5.70 1,618.49 MWD(3) -. 6,709.89 98.69 175.50 5,963.15 5,883.15 -1,648.02 -215.77 5,998,624.89 498,438.77 13.48 1,648.02 1 (3) 6,740.07 98.75 175.87 5,958.57 5,878.57 -1,677.76 -213.52 5.998,595.14 498.441.01 1.23 1,677.76 MWD (3) 6,769.74 97.33 176.94 5,954.42 5,874.42 -1,707.08 -211.68 5,998,565.82 498,442.84 5.97 1,707.08 MWD (3) ' 6,799.83 98.66 178.66 5,950.24 5,870.24 -1,736.86 -210.54 5,998,536.05 498,443.98 7.18 1,736.86 MWD (3) 6,829.46 99.94 181.32 5,945.45 5,865.45 -1,766.09 -210.53 5,998,606.82 498,443.98 9.86 1,766.09 MWD (3) 6,859.71 101.69 183.57 5,939.77 5,859.77 -1,795.78 -211.79 5,998,477.14 498,442.71 9.32 1,795.78 MWD(3) 6,890.03 102.44 185.84 5,933.43 5,853.43 -1,825.33 -214.23 5.998,447.60 498,440.28 7.73 1,825.33 MWD (3) 6,924.91 102.23 187.91 5,925.98 5,845.98 -1,859.15 -218.30 5,998.413.77 498,436.19 5.83 1,859.15 MWD (3) 6,950.18 102.09 187.32 5,920.66 5,840.66 -1.883.64 -221.58 5,998,389.29 498,432.92 2.35 1,883.64 1 (3) 6,979.63 99.23 184.92 5,915.21 5,835.21 -1,912.41 -224.66 5,998,360.52 498,429.83 12.59 1,912.41 MWD (3) 7,009.80 94.92 179.84 5,911.49 5,831.49 -1,942.31 -225.90 5,998,330.63 498,428.59 21.98 1 942.31 MWD (3) 7,039.62 94.83 179.31 5,908.96 5.828.96 -1,972.02 -225.68 5,998,300.92 498,428.80 1.80 1.972.02 MWD(3) [ 7,069.68 94.24 17475 5,906.58 5826.58 -2,001.94 -224.12 5,998.27100 498.43035 15.25 2,001.94 MW (3) 8/112017 4:28:15PM Page 3 COMPASS 5000.14 Build 85 Survey Well 3H-26 3H-26 @ 80.00usit (3H-26) 311-26 @ 80.00usR(3H-26) True Minimum Curvature EDT Alaska Sandbox ConocoPhillips r ConocoPhillips Definitive Survey Report Company: ConocoPhilips(Alaska) Inc.-Kup2 Local Coordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kupamk 3H Pad MD Reference: Well: 3H-26 North Reference: Wellbore: 31-1-2611 Survey Calculation Method: Design: 3H-2611 Database: Survey Well 3H-26 3H-26 @ 80.00usit (3H-26) 311-26 @ 80.00usR(3H-26) True Minimum Curvature EDT Alaska Sandbox 8117/2017 4:28:15PM Page 4 BAER W UGH Annotation COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Ai TVD TVDSS -NI-S +E/ -W Northing Easting DLS Section Survey Tool Name lusR) (°) (°) luskl luskl just) (usft) (R) IRI (°/100') lftl 7,101.66 91.17 17104 5,905.07 5,825.07 -2,033.63 -220.17 5,996,239.32 498,434.29 15.05 2,033.63 MWVD(3) 7,130.08 90.31 166.80 5,904.70 5,824.70 -2,061.51 -21471 5,998,211.44 498.439.75 15.22 2,061.51 MM (3) 7,160.66 90.55 164.75 5,904.47 5,824.47 -2,091.15 -207.20 5,998,181.80 498.447.26 6.75 2,091.15 MWD (3) 7,191.10 92.03 164.06 5,903.79 5,823.79 -2,120.46 -199.02 5,998,152.49 498,455.43 5.36 2,120.46 MWD (3) 7,222.00 92.00 163.48 5,902.70 5,822.70 -2,150.11 -190.39 5.998,122.89 498,454.06 188 2,150.11 MWD(3) 7,250.71 92.37 161.14 5,901.61 5,821.61 -2,177.44 -181.67 5,998,095.51 498,472.77 8.25 2,177.44 MWD(3) 7,281.23 93.38 160.22 5,900.08 5,820.08 -2,206.20 -171.58 5,998,066.75 498,482.85 447 2,206.20 MM (3) 7,311.02 93.69 158.15 5,898.24 5,818.24 -2,233.99 -161.02 5,998,038.96 498,493.40 7.01 2,233.99 MWD (3) 7,341.27 93.% 156.81 5,896.22 5,816.22 -2,261.87 -149.46 5,998,011.08 498,504.96 4.51 2,261.87 MWD(3) 7370.80 93.51 155.61 5,894.30 5,814.30 -2,288.84 -137.57 5,997,984.12 498,516.84 4.33 2,288.84 MWD (3) 7,401.02 88.40 149.75 5,893.79 5,813.79 -2,315.66 -123.72 5,997,957.29 498,530.69 25.72 2,315.66 MWD (3) 7,430.88 8191 149.73 5,894.75 5,814.75 -2,341.44 -108.68 5,997,931.51 498,54532 1.64 2,391.44 MM (3) 7,464.77 89.51 147.19 5,895.52 5,815.52 -2,370.31 -90.95 5,997,902.64 498,563.44 8.86 2,370.31 MWD(3) 7,490.47 90,03 145.06 5,895.61 5,815.61 -2,391.65 -76.63 5,997,881.30 498,5]7.76 8.59 2,391.65 MWD(3) 7,520.68 93.04 148.80 5,899.78 5,814.78 -2,416.95 G0.16 5,997,856.00 498,599.22 15.76 2,416.95 MM (3) 7,551.18 91.14 149.83 5,893.67 5.813.67 -2,443.16 44.60 5,997,829.79 498,609.77 7.08 2,443.16 MWD (3) 7,580.50 91.05 151.43 5,893.11 5,813.11 -2,468.70 -30.23 5,!Kr(aN.25 498,624.14 5.46 2,468.70 MWD (3) 7,611.02 93.47 153.96 5,891.91 5,811.91 -2,495.80 -16.24 5,997,777.15 498,638.12 1147 2,495.80 MWD(3) 7,644.17 91.75 156.00 5,890.40 5,810.40 -2,525.80 -2.23 5,997,747.15 498,652.12 8.04 2,525.80 MWD (3) 7,671.28 92.95 158.50 5,889.28 5,809.28 -2,550.78 8.24 5,997,722.17 498,662.59 10.22 2,550.78 MWD (3) 7.700.77 91.20 159.64 5,888.22 5,808.22 -2,578.31 18.77 5,997,694.65 498,673.11 7.08 2.578.31 MWD (3) 7,730.96 94.12 165.14 5,886.81 5,806.81 -2,607.04 27.89 5.997,665.92 498,682.23 20.61 2,607.04 MWD (3) 7,761.53 93.69 166.91 5,884.73 5,804.73 -2,636.63 35.25 5,997,636.33 498,689.58 5.95 2,636.63 MWD (3) 7,790.82 91.17 170.11 5,883.49 5,803.49 -2,665.30 41.08 5,997,607.66 498,695.41 - 13.90 2,655.30 MWD (3) 7,820.79 91.60 171.56 5,88277 5,802.77 -2,694.88 45.85 5,997,578.08 498,700.17 5.05 2694.88 MWD(3) 7,850.99 91.44 174.26 5,88196 5,801.96 -2,724.84 49.58 5,997,546.13 498,703.89 8.95 2,724.84 MWD (3) 7,884.09 88.22 174.79 5,882.06 5,802.06 -2,757.78 52.74 5997,515.19 498,707.04 9.86 2,757.78 MWD(3) 7,913.79 87.63 177.55 5,883.14 5,803.14 -2,787.39 54.72 5,997,485.58 498,709.02 9.50 2,767.39 MWD(3) 7,941.27 68.09 179.32 5,884.16 5,809.16 -2,814.89 55.47 5.997,458.13 498,709.77 6.65 2,814.84 MWD (3) 7,971.41 87.30 182.23 5,885.38 5,805.38 -2,84495 55.06 5,997.428.02 498709.35 1000 2,844.95 MM (3) 8,001.16 87.42 185.19 5,886.75 5,806]5 -2,874.60 53.14 5991398.38 498,70742 9.95 2,874.60 MWD(3) 8117/2017 4:28:15PM Page 4 BAER W UGH Annotation COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 3H-26 Project: Kuparuk River Unit ND Reference: 3H-26 @ 80.00usft (3H-26) Site: Kuparuk 3H Pad MD Reference: 3H-26 @ 80.00usft (31-1-26) Well: 31-1-26 North Reference: True Wellbore: 31H-2611 Survey Calculation Method: Minimum Curvature Design: 3H-2611 Database: EDT Alaska Sandbox Survey Annotation 8H (ER UGHES 8711/2017 4: 28.15PM Page 5 COMPASS 5000.14 Build 85 Map Map Vertical. MD Inc Azi TVD TVDSS +N1S +E/ -W DILS (usft) C) (I (usft) (usft) (usft) (usft) Northing Easting (-MOO-) ') Section Survey Tool Name (ft) (ft) (ft) 8,031.37 86.25 189.00 5,887.89 5,807.89 -2,904.55 49.41 5,997,368.43 498,703.69 12.90 2,904.55 MWO(3) -. 8,06120 89.75 194.05 5,888.41 5,808.41 -2,933.77 43.45 5,997,339.22 498,697]3 17.66 2,933.77 MWD(3) 8,090.83 88.77 197.35 5,888.79 5,808.79 -2,96229 35.44 5,997,310.70 498,689.71 11.62 2,962.29 MWD (3) 8.124.31 87.82 201.06 5,889.79 5,809.79 -2,993.88 24.43 5,997,279.11 498,678.70 11.43 2,993.88 MWD (3) 8,151.18 86.25 204.06 5.891.18 5,811.18 -3,018.66 14.14 5,997,254.34 498,668.40 12.59 3,018.66 MWD (3) 8,181.02 86.31 206.77 5,893.12 5,813.12 -3,045.55 1.36 5.997,227.45 498,655.62 9.06 3,045.55 MWD (3) 8,211.25 86.28 209.16 5,895.07 5,815.07 -3,072.19 -12.79 5,997,200.81 498,641.47 7.89 3,072.19 MWD (3) 8,240.69 87.42 214.45 5,896.69 5,816.69 -3,097.17 -28.27 5,997,175.85 498,625.98 18.35 3,097.17 MWD (3) 8,271.07 90.31 220.45 5,897.29 5,817.29 -3,121.27 -06.73 5,937,151.75 498,607.52 21.92 3,121.27 MM (3) 8,300.88 90.37 219.74 5.897.11 5,817.11 -3,144.07 65.93 5.997.128.96 498,588.32 2.39 3,144.07 MWD (3) 8,331.32 88.04 217.51 5,897.54 5.817.54 -3,167.85 64.93 5,997,105.19 498.569.32 10.59 3,167.85 MWD (3) 8,361.55 91.51 217.53 5,897.66 5,817.66 -3,191.82 -103.34 5,937,081.22 498,550.91 11.48 3,191.82 MWD (3) 8,391.36 90.03 216.08 5,897.25 5,817.25 -3,215.68 -121.19 5,997,057.35 498,533.05 6.95 3,215.68 MWO(3) 8,415.33 86.12 212.54 5,898.06 5,818,6 -3,235.46 -134.69 5,997,037.58 498,519.55 22.00 3,235.46 MWD (3) 8,415.11 85.36 209.42 5.900.27 5,820.27 -3,26D.92 -149.98 5,997.012.13 498,504.26 10.75 3,260.92 MWD (3) 8,481.15 88.03 207.68 5,902.35 5,822.35 .3,292.52 -167.17 5,996,980.54 498,487.06 8.84 3,292.52 MWD (3) 8,509.83 87.17 207.08 5,903.55 5,823.55 -3,317.97 -180.35 5,996,955.10 498,473.88 3.66 3.317.97 MM (3) 8,543.27 89.66 204.94 5.904.48 5,824.48 41,348.00 -195.01 5,996,925.07 498,459.22 9.82 3,348.00 MWD(3) 8,579.05 91.69 202.06 5,904.05 5,824.05 -3,380.81 -209.27 5,995892.27 498,444.95 9.85 3,380.81 MWD (3) 8,611.32 90.64 199.58 5,903.40 5,623.40 -3,410.96 -220.74 5,995862.12 498,433.48 8.34 3,410.96 MWD (3) 8,640.92 89.48 197.40 5,903.37 5,823.37 -3,439.03 -230.12 5,9%,834.05 498,424.09 8.34 3,439.03 MM (3) 8,674.19 93.56 197.73 5,902.49 5,822.49 -3,470.73 -240.16 5,996802.36 498,414.05 12.30 3,470.73 MWD (3) 8,704.41 92.33 195.73 5,900.93 5,620.93 -3,499.63 -248.84 5,996.773.46 498,405.36 7.76 3,499.63 MWD (3) 8,724.12 89.63 194.81 5,900.60 5,820.60 -3,518.64 -254.03 5,996,754.45 498,400.17 14.47 3,518,64 MWD (3) 8,773.00 89.63 194.81 5,900.91 5,820.91 -3,555.90 -266.53 5,996707.20 498,387.67 0.00 3,565.90 PROJECTED to TD Annotation 8H (ER UGHES 8711/2017 4: 28.15PM Page 5 COMPASS 5000.14 Build 85 RECEIVE') AUG 2 1 2017 AOGCC BA ER F�UGHES aGEcompany To: Letter of Transmittal Date: DATA LOGGED August 18, 2017 .1 BENDER Makana Bender AOGCC 333 West 71h Ave, Suite 100 Anchorage, Alaska 99501 From: Yosha Ragbirsingh / Michael Soper Baker Hughes, a GE Company 795 East 94t1 Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following welI(s): 3H -26L1 3H -26L1-01 3H -26L1-02 (3) Total prints n 21 7088 1 21 7690 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@BHGE.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.RaRbirsinRh@BHGE.com ConocoPhillips RECEIVED AUG 2 1 2017 AOGCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H -26L1 60-103-20208-60 Baker Hughes INTEQ Definitive Survey Report 11 August, 2017 BA, ICER UGHES a GE company 21 7087 28509 )011 ConocoPhillips C011000Phillip5 Definitive Survey Report Company: ConocePhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 3H Pad MD Reference: Well: 31-1-26 North Reference: Wellborn: 31-1-2617 Survey Calculation Method: Design: 31-1-261-1 Database: Project Kuparuk River Unit, North Slope Alaska, United Stales Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) MWD-INC—ONLY—FILLER Map Zone: Alaska Zone 04 Survey(Wellbore) Well 3H-26 3H-26 (3H-26) Well Position +N/ -S 0.00 usft Northing: 6,350.41 +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 3H -26L1 Magnetics Model Name Sample Date BGGM2017 9/1/2017 Design 3H-2611 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 80.00 Survey Program Description Date 7/28/2017 From To MWD-INC—ONLY—FILLER (usft) (usft) Survey(Wellbore) 121.00 5,974.70 3H-26 (3H-26) 6,229.65 6,320.45 311-261-7 MWD -INC (31H-2611) 6,350.41 8,724.12 31-1-2611 MWD(3H-261-1) Well 3H-26 311-26 @ 80.00usft (3H-26) 31-1-26 @ 80.00usft (3H-26) True Minimum Curvature EDT Alaska Sandbox Mean Sea Level Using Well Reference Point Using geodetic scale factor 6,000,272.70usft 498,654.81 usft usft BAKER E7 HUGHES Latitude: 70° 24'43.124 N Longitude: 150° 0' 39.435 W ='.. Ground Level: 0.00 usft Declination Dip Angle Field Strength (nT) 1742 80.95 57,487.12 Tie On Depth: 5,974.70 +N/ -S +E/ -W Direction (usft) (usft) C) 0.00 0.00 180.00 Tool Name Description MWD MWD - Standard MWD-INC—ONLY MWD-INC—ONLY—FILLER MWD MWD - Standard Survey Survey Start Date End Date 1/12Y20011 7/23/2017 7/24/2017 7/24/2017 7/27/2017 611112017 4:28:15PM Page 2 COMPASS 5000.14 Build 85 Annotation 8A cER UGHES TIP KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth First Clean Survey 8/112017 4.28: 15PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 3H-26 Project: Kuparuk River Unit TVD Reference: 3H-26 @ 80.00usft (311-26) Site: Kuparuk 3H Pad MD Reference: 3H-26 @ 80.00usft(3H-26) Well: 3111-26 North Reference: True Wellbore: 311-2611 Survey Calculation Method: Minimum Curvature Design: 311-2611 Database: EDT Alaska Sandbox Survey (1 (1) Annotation 8A cER UGHES TIP KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth First Clean Survey 8/112017 4.28: 15PM Page 3 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +NlS +El -W D1S (usft) (1 (1) Wait) Wait) (usft) (usft) Northing Easting (°/108•) Section Survey Tool Namr (ft) (ft) (ft) 5,97470 23.80 182.70 5,653.02 5,573.02 -1,144.12 -308.96 5,999,128.75 498,345.78 3.66 1,144.12 MM -INC _ONLY (2) 6,22965 16.58 186.57 5,892.16 5,812.16 -1,231.76 -315.45 5,999,041.12 498,339.17 2.88 1,231.76 MWD-INC_ONLy(2) 6,260.38 23.16 176.00 5,921.05 5,841.05 -1242.16 -315.53 5,999,03072 498,339.09 24.32 1,242.16 MM -INC -ONLY (2) 6,290.26 3743 165.00 5,946.81 5,866.81 -1,256.88 -312.76 5,999,016.00 498,341.86 51.06 1,256.88 MWD -INC -ONLY (2) 6,32045 53.20 163.68 5,967.97 5,887.97 -1,277.48 -306.95 5,998,99541 498,34]66 52.33 1,277.48 MWD -INC _ONLY (2) 6,350.41 68.04 163.68 5,982.63 5,902.63 -1,302.46 -299.63 5,998,97042 498,354.97 49.53 1,302.46 MWD (3) 6,379.70 81.74 162.63 5,990.24 5,910.24 -1,329.46 -291.45 5,998,943.43 498,363.15 46.90 1,329.46 MWD (3) 6,410.62 8142 162.62 5,993.16 5,913.16 -1,358.82 -282.26 5,998,914.06 498,372.33 18.37 1;358.82 MM (3) 6,439.78 90.12 162.96 5,993.79 5,913.79 -1,386.67 -273.64 5,998,886.22 498,380.95 9.33 1,386.67 MWD (3) 6,469.81 92.03 163.49 5,993.23 5,913.23 -1,41541 -264.97 5,99B,857.48 498,389.61 6.60 1,415.41 MWO(3) 6,502.51 94.92 164.42 5,991.24 5,911.24 -1,446.78 -255.95 5,998,826.11 498,398.63 9.28 1,446.78 M6 (3) 6,529.81 97.37 164.97 5,988.32 5,908.32 -1472.96 -248.79 5,998,799.94 498,405.78 9.20 1,472.96 MWD (3) 6,559.83 9626 166.81 5,984.24 5,904.24 -1,501.80 -241.53 5,998,771.10 498,41303 6.76 1,501.80 MWO(3) 6,589.91 98.11 168.75 5,979.96 5,899.96 -1,530.90 -235.23 5,998,742.00 498,419.32 6.40 1,530.90 MM (3) 6,619.64 97.80 168.87 5,975.84 5.895.84 -0,559.78 -229.52 5,998,713.12 498,425.03 1.12 1,559.78 MM (3) 6,650.78 97.70 169.87 5,971.64 5,891.64 -1,590.11 -223.83 5,998,682.79 498,430.72 3:20 1,590.11 MNeD (3) 6,679.83 98.32 171.42 5,967.59 5,887.59 -1,618.49 -219.15 5,998,654.41 498,435.39 5.70 1,618.49 MWD(3) 6,709.89 98.69 175.50 5,963.15 5,883.15 -1,648.02 -215.77 5,998,624.89 498,438.77 13.48 1,648.02 MWD (3) 6,740.07 98.75 175.87 5,958.57 5,878.57 -1,677.76 -213.52 5,998,595.14 498,441.01 1.23 1,677.76 MWO(3) 6,769.74 97.33 176.94 5,954.42 5,874.42 -1,707.08 -211.68 5,998,565.82 498,442.84 5.97 1,707.08 MWD (3) 6,79983 98.66 17666 5,950.24 5,870.24 -1,736.86 -210.54 5,998,53605 498,443.98 7.18 1736.86 MWD(3) 6,82946 99.94 181.32 5,945.45 5,865,45 -1,766.09 -210.53 5,998,506.82 498,443.98 9.86 1,766.09 MWD(3) 6,859.71 101.69 183.57 5,939.77 5,859.77 -1,795.78 -21179 5,998,477.14 498,442.71 9.32 1,795]8 MWD (3) 6,890.03 102.4 185.84 5,933.43 5,853.43 -1,825.33 -214.23 5,998,44160 498,44028 7.73 1,825.33 MWD (3) 6,924.91 102.23 18291 5,925,98 5,645.98 -1,859.15 -218.30 5,998,413.77 498,436.19 583 1,859.15 MWD (3) 6,950.18 102.09 187.32 5,920.66 5,84066 -1,883.64 -221.58 5,998,38929 498,432.92 2.35 1,883.64 MM (3) 6,97963 99.23 184.92 5.915.21 5,835.21 -1,91241 -224.66 5,938,360.52 498,429.83 12.59 1,912.41 MWD (3) 7,009.80 9492 179.84 5,911.49 5,831.49 -1,942.31 -225.90 5,998,33063 498,428.59 21.98 1,94231 MWD (3) 7,03962 94.83 179.31 5,908.96 5,828.96 -1,97202 -225.68 5,998,300.92 498,428.80 1.80 1,972.02 MM (3) 7,069.68 94.24 17475 5,906.58 5,82658 -2,001.94 -224.12 5,998,271.00 498,430.35 15.25 2,00194 MWD(3) Annotation 8A cER UGHES TIP KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth First Clean Survey 8/112017 4.28: 15PM Page 3 COMPASS 5000.14 Build 85 Survey ConocoPhillips BA ER ConocoPhillips Definitive Survey Report t U tES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 31-1-26 Pro}ect: Kupamk River Unit TVD Reference: 31-1-26 @ 80.00usft (31-1-26) Site: Kupamk 3H Pad MD Reference: 31-1-26 @ 60.00usft (31-1-26) Well: 3H-26 North Reference: True Wellbore: 3H-2611 Survey Calculation Method: Minimum Curvature Design: 3H-2611 Database: EDT Alaska Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S -1 DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (oltoo' ) Section Survey Tool Name Annotation (ft) (ft) (ft) 7,101.66 91.17 171.04 5,90507 5,825.07 -2,033.63 -220.17 5,998,239.32 498434.29 15.05 2,03363 MM (3) 7,130.08 90.31 165.80 5,904.70 5,824.70 -2,061.51 -214.71 5,998,21144 498,439.75 15.22 2,061.51 MWD (3) 7,160.66 90.55 164.75 5,904.47 5,824.47 -2,091.15 -207.20 5,998,181.80 498,447.26 6.75 2,091.15 MM (3) i7,191.10 92.03 164.03 5,903.79 5,823.79 -2,120.46 -199.02 5,998,152.49 498,455.43 5,36 2,12046 MWD (3) 7,222.00 92.00 163.48 5,902.70 5,822.70 -2,150.11 -190.39 5,998,122.84 498,464.06 1.88 2,150.11 MWD(3) 7,250.71 92.37 161.14 5,901.61 5,821.61 -2,177.44 -181.67 5,998,095.51 498,472.77 8.25 2,177,44 MWD (3) i ],281.23 93.38 160.22 5,900.08 5,820.08 -2,203.20 -171.58 5,998,066.75 498,482.85 4.47 2,206.20 MWD (3) 7,311.02 93.69 158.15 5,896.24 5,818.24 .2,233.99 -161.02 5,998,038.96 498,493.40 7.01 2.233.99 MAD (3) _ 7,341.27 93.96 156.81 5,896.22 5,816.22 -2,261.87 -149.46 5,998,011.08 498,504.96 4.51 2,261.87 MWD (3) � 7,370.80 93.51 155.61 5,894.30 5,814.30 -2,288.84 .137.57 5,997,984.12 498,516.84 4.33 2,286.84 MWD (3) ` 7,401.02 88.40 14975 5,893.79 5,813.79 -2,31565 -123.72 5,997,957.29 498,53069 25.72 2,315.66 MWD (3) 7,430.88 87.91 14973 5,894.75 5,814.75 -2,34144 -108.68 5,997,931.51 498,59572 1.64 2.341.44 MM (3) 7,464.77 89.51 147.19 5,895.52 5,815.52 -2,370.31 -90.95 5,997,90264 498,56344 8.86 2,370.31 MWD (3) 7,490.47 90.09 145.06 5,895.61 5,815.61 -2,391.65 -76.63 5,997,881.30 498,577.76 8.59 2,391.65 MWD (3) 7,52068 93.04 14680 5,894.78 5,814.78 -2,416.95 -60.16 5,997,856.00 496,594.22 1576 2,416.95 MM (3) € 7,551.18 91.14 149.83 5,893.67 5,813.67 -2,443.16 -44.60 5,997,829.79 498,609.77 108 2,443.16 MWD (3) 7,580.50 91.05 151.43 5,893.11 5,813.11 .2,468.70 30.23 5,997,80425 498,624.14 5.46 2,46870 MWD (3) ` -� 7,611.02 93.47 153.96 5,891.91 5,811.91 -2,495.80 -16.24 5,997,777.15 498,638.12 11.47 2,495.80 MWD (3) I 7,644.17 91.75 156.00 5,890.40 5,810.40 -2,525.80 -2.23 5,997,747.15 498,652.12 8.04 2,525.60 MWD (3) f` 7,671.28 92.95 158.50 5,889.28 5,809.28 -2,55078 8.24 5,997,722.17 498,662.59 10.22 2,550.78 MM (3) 7,700.77 91.20 159.64 5,888.22 5,808.22 -2,578.31 18.77 5,99],694.65 498,673.11 7.08 2,578.31 MM (3) I 7,730.95 94.12 165.14 5,886.81 5,606.81 -2,607.04 27.89 5,997,665.92 498,682.23 20.61 2,607.04 MWD (3) i 7,761.53 9369 166.91 5,88473 5,80473 -2.636.63 3525 5,997,635.33 498,689.58 5.95 1 2,63663 MWD (3) y Ipl 7790.82 91.17 170.11 5,88349 5,803.49 -2,665.30 41.08 5,997,6066 498,695.41 13.90 2,66530 MWD (3) 7,820.79 91.60 171.56 5,882.77 5,802.]] -2,694.88 45.85 5,997,578.08 498,700.17 5.05 2,694.88 MWD (3) 3 7,850.99 91.44 174.26 5,881.96 5,801.96 -2,724.84 49.58 5,997,548.13 498,703.89 8.95 2,724.84 MVD (3) 4 I 7,884.09 W22 174.79 5,882,6 5,802.06 -2,757.78 5274 5,997,515.19 498,707.04 9.86 2,75778 MWD (3) i 7,91379 87.63 177.55 5,883.14 5,803.14 -2,787.39 54.72 5,997,485.58 498,709.02 9.50 2,787.39 MM (3) fi 7,941.27 88.09 179.32 5,884.16 5,804.16 -2,814.84 55.47 5,997,458.13 498,709.77 6.65 2,814.84 MWD(3) 7,971.41 87.30 182.23 5,885.38 5,805.38 -2,844.95 55.06 5,997,428.02 498,709.35 10.00 2,8*195 MWD(3) 8,001.16 87.42 185.19 58W75 5,80675 -2,87460 53.14 5,997,398.38 498,70742 995 2,874.60 MAD (3) 811112017 4:28:15PM Page 4 COMPASS 5000.14 Build 85 Annotation HAFUGHFS 81112017 4:28: 15PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 local Co-ordinate Reference: Well 31-1-26 Project: Kuparuk River Unit TVD Reference: 3H-26 @ 80.00usft (3H-26) Site: Kuparuk 3H Pad MD Reference: 3W26 @ 80.00usft (3H-26) Well: 3H-26 North Reference: True Wellbore: 3H-261-1 Survey Calculation Method: Minimum Curvature Design: 31-1-2611 Database: EDT Alaska Sandbox Survey..... (1 (1) Annotation HAFUGHFS 81112017 4:28: 15PM Page 5 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W D1 -S (usft) (1 (1) (usft) (usft) (usft) (usft) Northing Easting (°1100') Section Survey Tool Name (ft) (ft) (ft) 8,031,37 88.25 189.00 5,88789 5,807.89 -2,904.55 49.41 5,997,35843 498,70369 12.90 2,904.55 MWD (3) 8,061.20 89.75 194.05 5,88841 5,80841 -2,933.77 43.45 5,997,33922 498,697.73 17.66 2,933.77 MWD (3) 8,090.83 88.77 197.35 5,888.79 5,808.79 -2,962.29 35.44 5,997,310.70 498689.71 11.62 2,962.29 MWD (3) 8,124.31 87.82 20106 5,889.79 5,809.79 -2,993.88 24.43 5,997,279.11 498,67870 11.43 2,993.88 MWD (3) 8,151.18 86.25 204.06 5,891.18 5,811.18 3,018.66 14.14 5,997,254.34 498,66840 12.59 3,018.66 MWD(3) 8,181.02 86.31 206.77 5,893.12 5,813.12 -3,045.55 1.36 5,997,227.45 498,65562 9.06 3,045.55 MWD (3) 8,211.25 86.28 209.16 5,895.07 5,815.07 3,072.19 -12.79 5,997,200.81 498,64147 7.89 3,072.19 MWD (3) 8,24069 87.42 214.45 5,896.69 5,816.69 3,097.17 -28.27 5,997,175.85 498,625.98 18.35 3,097.17 MWD (3) 8,271.07 90.31 22045 5,897.29 5,817.29 3,121.27 46.73 5,997,151.75 498,607.52 21.92 3,121.27 MM (3) 8300.88 90.3] 219.74 5,897.11 5,817.11 3,144.07 -65.93 5,997,12896 498,588.32 2.39 3,144.07 MWD(3) 8,331,32 88.04 217.51 5,897.54 5,817.54 3,167.85 -84.93 5,997,105.19 498,569.32 10.59 3,167.85 MWD (3) 8,361.55 91.51 217.53 5,897.66 5,817.66 -3,191.82 -103.34 5,997,08122 498,550.91 1148 3,191.82 MWD (3) 8,391.36 90.03 216.08 5,897.25 5,817.25 3,215.68 -121.19 5,997,057.36 498,533.05 6.95 3,215.68 MWD (3) 8,415.33 86.12 212.54 5,898.06 5,818.06 -3,235.46 -134.69 .5,997,037.58 498,519.55 22.00 3,235.46 MWD (3) 8,445.11 85.36 20942 5,900.27 5,820.27 -3,260.92 -149.98 5,997,012.13 498,504.26 1075 3,260.92 MWD (3) 8,481.15 88.03 207.68 5,902.35 5,822.35 -3,292.52 -167.17 5,996,98054 498,48TW 8.84 3,292.52 MWD(3) 8,509.83 87.17 207.08 5,903.55 5,823.55 -3,317.97 -180.35 5,996,955.10 498,473.88 3.66 3,317.97 MM (3) 8,543.27 89.66 204.94 5,904.48 5,824.48 -3,348.00 -195.01 5,99892507 498,459.22 9.82 3,348.00 MWD (3) 8,579.05 91.69 202.06 5,904.05 5,824.05 -3,380.81 -209.27 5,996,892.27 498,444.95 9.85 3,380.81 MWD (3) 8,611.32 90.64 199.58 5,903.40 5,82340 -3,410.96 -22074 5,996,862.12 498,433.48 8.34 3,410.96 MM (3) 8,640.92 89.48 197.40 5,903.37 5,823.37 -3,43903 -230.12 5,998834.05 498,424.09 8.34 3,439.03 MWD (3) 8,674.19 9355 197.73 5,902.49 5,822.49 -3,470.73 -240.16 5,996,602.36 498,414.05 12.30 3,470.73 MWD (3) 8,704.41 92.33 195.73 5,900.93 5,820.93 -3,499.63 -248.84 5,996,77346 498,405.36 T76 3,499.63 MWD (3) 8,724.12 89.63 194.81 5,900.60 5,820.60 -3,518.64 -254.03 5,99875445 498,400.17 1447 3,518.64 MWD(3) 8,773.00 89.63 194.81 5,900.91 5,820.91 -3,565.90 -26653 5,996,707.20 498,387,67 0.00 3,565.90 PROJECTED to TD Annotation HAFUGHFS 81112017 4:28: 15PM Page 5 COMPASS 5000.14 Build 85 THE STATE °fALASKA GOVERNOR BILL WALKER James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3H -26L1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-087 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Surface Location: 1384' FNL, 281' FWL, Sec. 12, T12N, R8E, UM Bottomhole Location: 5019' FNL, 5218' FEL, Sec. 12, T12N, R8E, UM Dear Mr. Ohlinger: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 194-029, API No. 50-103- 20208-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, O�p� Daniel T. Seamount, Jr. Commissioner DATED this ZG day of June, 2017. STATE OF ALASKA ALh.,nA OIL AND GAS CONSERVATION COMMI",ON PERMIT TO DRILL 20 AAC 25.005 RECEIVED JUN 12 2017 A Pi/-% r%,f% 1 a. Type of Work: Drill ❑ Lateral • 0 Redrill ❑ Reentry ❑ 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ Stratigraphic Test ❑ Development - Oil ❑✓ . Service - Winj ❑ Single Zone ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑� 1 c. S I r sed for: Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska Inc 5. Bond: Blanket ❑' - Single Well ❑ Bond No. 5952180 11. Well Name and Number: KRU 3H -26L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 8900 TVD: sS 5823 12. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool 4a. Location of Well (Governmental Section): Surface: 1384' FNL, 281' FWL, Sec. 12, T12N, R8E, UM Top of Productive Horizon: 2635' FNL, 38' FEL, Sec 11, T12N, R8E, UM Total Depth: 5019' FNL, 5218' FEL, Sec 12, T12N, R8E, UM 7. Property Designation: ADL 25531 i 8. DNR Approval Number: ALK 2657 13. Approximate Spud Date: 6/21/2017 9. Acres in Property: 2560 • 14. Distance to Nearest Property: 5215' 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 498655 y- 6000273 Zone- 4 10. KB Elevation above MSL (ft): 80, GL / BF Elevation above MSL (ft): 41 15. Distance to Nearest Well Open to Same Pool: 1328' (3H-09) 16. Deviated wells: Kickoff depth: 6277 feet Maximum Hole Angle: 103 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 3990 r � Surface: 3405 ' '1 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" 2-3/8" 4.7 ppf L-80 ST -L 1400' 7500' 5815' 8900' 5823' N/A 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): 6660' 6306' N/A 6643' 6291' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 121' 16" 200 sx CMT 121' 121' Surface 3143' 7-5/8" 550 sx ASIII, 300 sx Class G 3143' 3140' Intermediate Production 6643' 5" x 5-1/2" 210 sx Class G 6643' 6291' Liner Perforation Depth MD (ft): 6250-6280, 6306-6336 Perforation Depth TVD (ft): 5910-5939, 5963-5992 Hydraulic Fracture planned? Yes ❑ No ❑✓ 20. Attachments: Property Plat ❑ BOP Divertter Sketch 8 DSleabed lling Program Report e ysis Drilling eFluid Program e 20 AAC 25.050 requirev. Depth Plot Shallow Hazard ments B 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be rr�� deviated from without prior written approval. Contact Name: Mike Callahan / ��- Authorized Name: James Ohlinger Contact Email: mike.callahan@conocophillips.com Authorized Title: Staff CTD Engineer Contact Phone: 263-4180 Authorized Signature: Date: Commission Use Only Permit to Drill Number: - a JAPI Number: 50-I'os- m o$ - (p(7 -Q13 Permit Approval 1 Date: (.t- Z(.c- See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane gas hydrates, or gas contained in shales: Other: �Op fC$t �"Sb 5-'I.Samples req'd: Yes ❑ No 7z Mud log req'd: Yes[] No[e /4-" r1(/ I a ✓ YC VC ✓1 �- r"3 t� Z 5-00 p s f�}izS measures: Yes d No,❑,( Directional svy req'd: Yes [v� No❑ svy req'd: Yes ❑ Nov �G r- Spacingvexception req'd: Yes ❑ No LCI Inclination -only injection Past initial injection MIT req'd: Yes ❑ No[� —��l L'Kd bC96vYf Ll til r/J nO1 vl, J aGl rrinG pe$r ,-f `a,'t-�•S' l APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: V7 /0 22 Submit Form and Norm 1 401 I viss15� 7 if %i14t R Ali fob 24 months f��� date of approval per 20 AAC 25.005(g) Attachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 9, 2017 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: RECEIVED JUN 12 7.017 ,A®GCG ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill three laterals out of the Kuparuk well 31-1-26 using the coiled tubing drilling rig, Nabors CDR3-AC. "' To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. The work is scheduled to begin June 21st, 2017. The objective will be to drill laterals KRU 3H-261-1, 31-1-261-1-01, and 3H -26L1-02 targeting the Kuparuk C -sands. Attached to this application are the following documents: - 10-401 Applications for 31-1-26L1, 31-1-261-1-01, and 3H-261-1-02 - Detailed Summary of Operations - Directional Plans for 3H-261-1, 31-1-261-1-01, and 3H-261-1-02 - Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4180. Sincerely, Mike Callahan ConocoPhillips Alaska Coiled Tubing Drilling Engineer Kuparuk CTD Laterals 3H-26L1,3H-26L1-01,& 3H -26L1-02 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(o and 20 AAC 25.005(b))...................................................................................................................2 2. Location Summary .......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2))..................................................................................................................................................2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5))..................................................................................................................................................2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................4 11. Seabed Condition Analysis............................................................................................................4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4 12. Evidence of Bonding......................................................................................................................4 (Requirements of 20 AAC 25.005(c)(12)).................................................................................................................................................4 13. Proposed Drilling Program............................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................6 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 7 (Requirements of 20 AAC 25.050(b))......................................................................................................................................................7 16. Attachments....................................................................................................................................7 Attachment 1: Directional Plans for 3H-261-1, 31-1-261-1-01 and 3H -26L1-02 laterals......................................................7 Attachment 2: Current Well Schematic for 3H-26............................................................................................................7 Attachment 3: Proposed Well Schematic for 31-1-261-1, 3H-261-1-01 and 3H-261-1-02 laterals........................................7 Page 1 of 7 June 9, 2017 PTD Application: 3H-261-1. 3H -26L1-01. & 3H -26L1-02 Well Name and Classification (Requirements of 20 AAC 25.005(o and 20 AAC 25.005(b)) The proposed laterals described in this document are 3H -26L1, 3H-261-1-01, and 31-1-261-1-02. All laterals will be classified as "Development -Oil' wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will tarnet the C sand packaoe in the Kuparuk reservoir. See attached 10-401 forms for surface and subsurface coordinates of each of the laterals. 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 CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,750 psi. Using the maximum formation pressure in the area of 3990 psi in 3H-09 (i.e. 12.7 ppg EMW), the maximum potential surface pressure in 31-1-26, assuming a gas gradient of 0.1 psi/ft, would be 3,405 psi., See the "Drilling Hazards Information and Reservoir Pressure" section for more details. - The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 3H-26 was measured to be 3472 psi (11.4 ppg EMW) on 5/20/2017. The maximum downhole pressure in the 3H-26 vicinity is the 3H-09 at 3990 psi or 12.7 ppg EMW. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled; gas injection has been performed in this area, so there is a chance of encountering gas while drilling the 31-1-26 laterals. If significant gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 3H-26 laterals will be shale stability. MPD will be used to maintain a constant BHP on the shales for hole stability, in addition to stability additives in the drilling mud. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 31-1-26 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 June 9, 2017 PTD Application: 3H -26L1, 31-1-261-1-01, & 31-1-261-1-02 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 3H -26L1 7,500' 8,900' 5,815' 5,823' 2%", 4.7#, L-80, ST -L slotted liner; 0' 121' 1640 670 Surface aluminum billet on to 3H -26L1-01 7,400' 8,900' 5,827' 5,812' 2W, 4.7#, L-80, ST -L slotted liner; 3140' 6890 4790 Production 5-1/2" aluminum billet on to 31-1-261-1-02 6,100' 9,725' 5,768' 5,838' 2W, 4.7#, L-80, ST -L slotted liner; 7740 6290 Production 5" 18 Liner top packer Existing Casing/Liner Information Category OD Weight (ppf) Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded 0' 121' 0' 121' 1640 670 Surface 7-5/8"" 29.7 L-80 LTC 0' 3143' 0' 3140' 6890 4790 Production 5-1/2" 17 L-80 LTC 0' 6151' 0' 5816' 7740 6290 Production 5" 18 L-80 LTC 6151' 6643' 5816' 6291' 10140 10490 Tubing 3-1/2" 9.3 L-80 EUE IBT 0' 6126' 0' 5793' 10160 10540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Water based Power -Vis milling flu (8.6 ppg) — Drilling operations: Water based Flo -Pro drilling mud (8.6 ppg). This mud weight will not hydrostatically overbalance 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 13.0 ppg potassium formate completion fluid in order to provide formation over -balance and maintain wellbore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information'. In the 31-1-26 laterals we will use MPD to maintain formation overbalance. We will target an EMW at the window of whatever formation pressure we see while drilling, with 12.7 ppg as the maximum expected. 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. Page 3 of 7 June 9, 2017 PTD Application: 31-1-261-1, 31-1-261-1-01, & 3H -26L1-02 Pressure at the 31-1-26 Window (6277'M 5856' TVD Using MPD 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 a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background The 3H-26 CTD producer project targets the C4 and C3 sands to increase throughput and recovery in the parent well pattern and regain production from the long-term shut-in (LTSI) 3H-05 producer. Three laterals will be drilled from the 3H-26 parent well in the C -sand, two to the south and one to the north. The 314-26 CTD well will be supported by the offset 3H-07 and 3H-06 injectors to the west. Nabors CDR3 will mill a 2.80" window off of a whipstock at 6,277'. Three laterals will be drilled targeting the Kuparuk C sands. All laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner top located inside the 3-1/2" tubing tail. Page 4 of 7 June 9, 2017 Pumps On 1.5 bpm) Pumps Off C -sand Formation Pressure 11.4 3472 psi 3472 psi Mud Hydrostatic 8.6 ✓ 2619 psi 2619 psi Annular friction i.e. ECD, 0.080psi/ft) 502 psi 0 psi Mud + ECD Combined no chokepressure) 3121 psi underbalanced -350psi) 2619 psi underbalanced -850psi) Tar et BHP at Window 12.7 3870 psi 3870 psi Choke Pressure Required to Maintain Target BHP 750 psi 1250 psi 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 a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background The 3H-26 CTD producer project targets the C4 and C3 sands to increase throughput and recovery in the parent well pattern and regain production from the long-term shut-in (LTSI) 3H-05 producer. Three laterals will be drilled from the 3H-26 parent well in the C -sand, two to the south and one to the north. The 314-26 CTD well will be supported by the offset 3H-07 and 3H-06 injectors to the west. Nabors CDR3 will mill a 2.80" window off of a whipstock at 6,277'. Three laterals will be drilled targeting the Kuparuk C sands. All laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner top located inside the 3-1/2" tubing tail. Page 4 of 7 June 9, 2017 PTD Application: 311-261-1, 31-1-261-1-01, & 3H -26L1-02 Pre -CTD Work 1. Set whipstock in 5" production casing at 6277'. 2. Prep site for Nabors CDR3-AC. Rill Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3H -26L1 Lateral (C3/C4 sand - South) a. Mill 2.80" window at 6277' MD. b. Drill 3" bi-center lateral to TD of 8900' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 7500' MD. 3. 3H -26L1-01 Lateral (C3/C4 sand- South) a. Kickoff of the aluminum billet at 7500' MD. b. Drill 3" bi-center lateral to TD of 8900' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 7400' MD. 4. 3H -26L1-02 Lateral (C3/C4 sand -North) a. Kick off of the aluminum billet at 7400' MD. b. Drill 3" bi-center lateral to TD of 9725' MD. c. Run 2%" slotted liner with seal bore from TD up to 6100' MD. 5. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post -Rig Work 1. Run KB liner top packer 2. Obtain SBHP. 3. Install GLV's . 4. Return to production. Page 5 of 7 June 9, 2017 PTD Application: 3H -26L1, 3H-261-1-01, & 3H -26L1-02 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 slick -line. - 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 - 3H-26 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 DS4 Prudhoe Bay for disposal. � • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B 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. (6704200). Page 6 of 7 June 9, 2017 PTD Application: 31H-261-1, 3H -26L1-01, & 3H-261-1-02 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 Plans - 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 open hole section. Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 3H-261-1 5215' 3H-261-1-01 5340' 3H -26L1-02 5470' Distance to Nearest Well within Pool Lateral Name Distance Well 3H-261-1 1328' 3H-09 3H-261-1-01 1350' 3H-09 311-1-261-1-02 1050' 3H-09 16. Attachments Attachment 1: Directional Plans for 3H -26L1, 3H -26L1-01 and 3H -26L 1-02 laterals. Attachment 2: Current Well Schematic for 3H-26 Attachment 3: Proposed Well Schematic for 3H -26L1, 3H -26L1-01 and 3H -26L 1-02 laterals. Page 7 of 7 June 9, 2017 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-26 3H -26L1 Plan: 3H-26L1_wp02 Standard Planning Report 01 June, 2017 riFag BAKER HUGHES ConocoPhillips HA.. ConocoPhillips Planning Report BAKER HUG## :S Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kupamk 3H Pad Well: 31-1-26 Wellbore: 31-1-2611 Design: 31-1-261-1_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3H-26 Mean Sea Level 31-1-26 @ 80.00usft (3H-26) True Minimum Curvature 'roject Kuparuk River Unit, North Slope Alaska, United States dap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level deo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point dap Zone: Alaska Zone 04 Using geodetic scale factor site Kupamk 3H Pad 3H-26 Well Position +N/ -S 91te Position: Northing: 6,000,110.73 usft Latitude: 70° 24'41.531 P -rom: Map Easting: 498,655.44 usft Longitude: 150° 0'39.416 N Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.01 ° Well 3H-26 Well Position +N/ -S 0.00 usft +E/ -W Position Uncertainty Wellbore 3H-2611 Magnetics Model Name 0.00 usft Northing: 0.00 usft Easting: 0.00 usft Wellhead Elevation: BGGM2016 Sample Data 9/1/2017 Design 3H-2611_wp02 Audit Notes: 70" 24'43.124 N Version: Phase: Vertical Section: Depth From (TVD) (usft) Ground Level: 0.00 6,000,272.70 usft Latitude: 70" 24'43.124 N 498,654.81 usft Longitude: 150° 0'39A35 W usft Ground Level: O.00 usft TVD Below Dogleg Build Turn Declination Depth Dip Angle Field Strength System +N/ -S +E/ -W (nT) 17.39 Rate 80.96 57,536 PLAN Tie On Depth: +NbS +E/ -W (usft) (usft) 0.00 0.00 5,974 70 Direction (°) 180.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) 1°) (°) (usft) (usft) (usft) f-matift) (°/100ft) (°/100ft) (°) 5,974.70 23.80 182.70 5,573.02 -1,144.12 -308.86 0.00 0.00 0.00 0.00 6,277.00 17.52 187.55 5,855.76 -1,250.27 -317.72 2.15 -2.08 1.60 167.01 6,302.00 21.02 187.55 5,879.36 -1,258.45 -318.80 14.00 14.00 0.00 0.00 6,455.29 90.00 187.55 5,961.01 -1,376.27 -334.42 45.00 45.00 0.00 0.00 6,525.00 90.00 182.67 5,961.01 -1,445.68 -340.63 7.00 0.00 -7.00 270.00 6,700.00 102.06 180.51 5,942.66 -1,619.32 -345.48 7.00 6.89 -1.23 350.00 6,800.00 103.18 173.43 5,920.78 -1,716.89 -340.34 7.00 1.12 -7.08 280.00 6,900.00 103.08 166.24 5,898.03 -1,812.48 -323.17 7.00 -0.10 -7.19 270.00 7,175.00 95.96 148.09 5,852.18 -2,061.00 -218.05 7.00 -2.59 -6.60 250.00 7,325.00 96.77 137.56 5,835.49 -2,179.62 -128.12 7.00 0.54 -7.02 275.00 7,550.00 96.52 153.41 5,809.28 -2,363.18 -1.91 7.00 -0.11 7.05 90.00 7,975.00 89.29 182.33 5,787.28 -2,773.55 85.91 7.00 -1.70 6.80 103.00 8,450.00 87.22 215.53 5,802.17 -3,216.38 -65.90 7.00 -0.44 6.99 94.00 8,900.00 87.63 184.00 5,822.94 -3,634.09 -216.01 7.00 0.09 -7.01 270.00 Target 6/1/2017 3:54:59PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips IGFAI ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupawk River Unit 14 rile, Start 45 dis Site: Kuparuk 3H Pad 65.12 Well: 3H-26 90.00 Wellbore: 3H-2611 46 dls, Start 7 dls Design: 31-1-261-1_wp02 90.00 Planned Survey 6,525.00 90.00 Measured 5 TVD Below Depth Inclination Azimuth System (usft) (°) (°) lust[) 5,974.70 23.80 182.70 5,573.02 TIP 6,800.00 103.18 6,000.00 23.27 183.01 5,596.22 6,100.00 21.18 184.38 5,688.78 6,200.00 1911 186.03 5,782.66 6,277.00 17.52 187.55 5,855.76 M 6,300.00 20.74 187.55 6,302.00 21.02 187.55 End 14 rile, Start 45 dis 5,879.36 6,400.00 65.12 187.55 6,455.29 90.00 187.55 End 46 dls, Start 7 dls Rate 6,500.00 90.00 184.42 6,525.00 90.00 182.67 5 (°) (usft) 6,600.00 95.17 181.76 6,700.00 102.06 180.51 6 498,345.78 -1,154.21 6,800.00 103.18 173.43 7 5,999, 11 B.66 498,345.27 6,900.00 103.08 166.24 8 166.73 5,999,080.92 7,000.00 100.61 159.55 7,100.00 97.99 152.97 7,175.00 95.96 148.09 9 1,250.27 2.15 7,200.00 96.11 146.34 7,300.00 96.65 139.32 7,325.00 96.77 137.56 10 5,998,556.24 498,314.19 7,400.00 96.75 142.85 7,500.00 96.62 149.89 7,550.00 96.52 153.41 11 52.63 2,502.00 7,600.00 95.72 156.84 7,700.00 94.07 163.67 7,800.00 92.35 170.47 7,900.00 90.61 177.25 7,975.00 89.29 182.33 12 7.00 104.33 8,000.00 89.17 184.08 8,100.00 88.69 191.06 8,200.00 88.23 198.05 8,300.00 87.80 205.04 8,400.00 87.40 212.04 8,450.00 87.22 215.53 13 -2,897.56 71.35 8,500.00 67.22 212.03 8,600.00 87.26 205.02 8,700.00 87.35 198.01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3H-26 Mean Sea Level 3H-26 Q0 80.00usft (31-1-26) True Minimum Curvature 5,877.49 -1,257.74 -318.71 1,257.74 14.00 0.00 5,999,015.14 498,335.91 5,879.36 Vertical Dogleg Toolface Map Map +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) -1,144.12 -308.86 1,144.12 0.00 0.00 5,999,128.75 498,345.78 -1,154.21 -309.36 1,154.21 2.15 167.01 5,999, 11 B.66 498,345.27 -1,191.96 -311.78 1,191.96 2.15 166.73 5,999,080.92 498,342.85 -1,226.25 -314.87 1,226.25 2.15 165.47 5,999,046.63 498,339.75 -1,250.27 -317.72 1,250.27 2.15 163.92 5,999,022.61 498,336.90 5,877.49 -1,257.74 -318.71 1,257.74 14.00 0.00 5,999,015.14 498,335.91 5,879.36 -1,258.45 -318.80 1,258.45 14.00 0.00 5,999,014.43 498,335.81 5,949.19 -1,323.17 -327.38 1,323.17 45.00 0.00 5,998,949.72 498,327.22 5,961.01 -1,376.27 -334.42 1,376.27 45.00 0.00 5,998,896.63 498,320.18 5,961.01 -1,420.73 -339.08 1,420.73 7.00 -90.00 5,998,852.17 498,315.51 5,961.01 -1,445.68 -340.63 1,445.68 7.00 -90.00 5,998,827.22 498,313.96 5,957.63 -1,520.53 -343.52 1,520.53 7.00 -10.00 5,998,752.39 498,311.05 5,942.66 -1,619.32 -345.48 1,619.32 7.00 -10.04 5,998,653.61 498,309.07 5,920.78 -1,716.69 -340.34 1,716.69 7.00 -80.00 5,998,556.24 498,314.19 5,898.03 -1,812.48 -323.17 1,812.48 7.00 -90.00 5,998,460.46 498,331.34 5,877.48 -1,905.95 -294.38 1,905.95 7.00 -110.00 5,998,366.99 498,360.11 5,861.30 -1,996.22 -254.66 1,996.22 7.00 -111.38 5,998,276.73 498,399.81 5,852.18 -2,061.00 -218.05 2,061.00 7.00 -112.44 5,998,211.94 498,436.41 5,849.55 -2,081.90 -204.59 2,081.90 7.00 -85.00 5,998,191.04 498,449.87 5,838.42 -2,161.04 -144.59 2,161.04 7.00 -85.18 5,998,111.90 498,509.85 5,835.49 -2,179.62 -128.12 2,179.62 7.00 -85.97 5,998,093.32 498,526.31 5,826.66 -2,236.82 -80.46 2,236.82 7.00 90.00 5,998,036.11 498,573.95 5,815.01 -2,319.47 -25.49 2,319.47 7.00 90.62 5,997,953.47 498,628.90 5,809.28 -2,363.18 -1.91 2,363.18 7.00 91.44 5,997,909.76 498,652.47 5,803.95 -2,408.27 18.99 2,408.27 7.00 103.00 5,997,864.66 498,673.37 5,795.41 -2,502.00 52.63 2,502.00 7.00 103.37 5,997,770.94 498,706.98 5,789.81 -2,599.25 74.95 2,599.25 7.00 103.95 5,997,673.70 498,729.29 5,787.22 -2,698.58 85.64 2,698.58 7.00 104.33 5,997,574.38 498,739.95 5,787.28 -2,773.55 85.91 2,773.55 7.00 104.51 5,997,499.41 498,740.21 5,787.62 -2,798.51 84.52 2,798.51 7.00 94.00 5,997,474.46 498,738.81 5,789.49 -2,897.56 71.35 2,897.56 7.00 93.98 5,997,375.42 498,725.63 5,792.17 -2,994.25 46.25 2,994.25 7.00 93.85 5,997,278.74 498,700.51 5,795.63 -3,087.15 9.57 3,087.15 7.00 93.66 5,997,185.85 498,663.82 5,799.82 -3,174.87 -38.13 3,174.87 7.00 93.42 5,997,098.15 498,616.11 5,802.17 -3,216.38 -65.90 3,216.38 7.00 93.12 5,997,056.66 498,588.34 5,804.59 -3,257.88 -93.67 3,257.68 7.00 -90.00 5,997,015.16 498,560.57 5,809.41 -3,345.58 -141.34 3,345.58 7.00 -89.83 5,996,927.48 498,512.88 5,814.12 -3,438.45 -177.95 3,438.45 7.00 -89.49 5,996,834.62 498,476.26 5,818.65 -3,535.10 -202.97 3,535.10 7.00 -89.16 5,996,737.99 498,451.22 6/12017 3:54:59PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips IGaI ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 31-1-26 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kupamk River Unit MD Reference: 31-1-26 @ 80.00usft (31-1-26) Site: Kuparuk 3H Pad North Reference: True Well: 31-1-26 Survey Calculation Method: Minimum Curvature Wellbore: 31-1-261-1 0.00 -1,278.06 Design: 3H-26L7_wp02 Point 0.00 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +Nf-S +E/.W Section Rate Azimuth Northing Easting I (usft) 1°) (') (usft) (usft) (usft) (usft) (°1100ft) (') (usft) (usft) 8,900.00 87.63 184.00 5,822.94 -3,634.09 -216.01 3,634.09 7.00 -88.84 5,996,639.01 498,438.17 ] Planned TD at 8900.00 J Targets Target Name ] -hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Basting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 3H -26L7 T03 0.00 0.00 5,823.00 -3,677.761,139,929.86 5,996,390.00 1,638,470.00 70'9'57.835 N 140'48'32.529 40°48'32.529 W - plan misses target center by 1139844.31 usft at 7975.00usft MD (5787.28 TVD, -2773.55 N, 85.91 E) Point 311-26 CTD Polygon Sot 0.00 0.00 0.00 -1,126.551,139,681.38 5,998,941.00 - plan misses target center by 1139611.35usft at 7975.00usft MD (5787.28 TVD, -2773.55 N, 85.91 E) - Polygon Measured Vertical Point 1 0.00 0.00 0.00 5,998,941.00 Point 0.00 -813.08 -6.81 5,998,128.00 Point 0.00 -1,278.06 277.32 5,997,663.02 Point 0.00 -1,674.08 396.43 5,997,267.02 Point 0.00 -3,028.34 -145.31 5,995,912.99 Point 0.00 -3,148.27 201.75 5,995,795.01 Point 0.00 -1,813.00 764.50 5,997,128.04 Point 0.00 -1,353.98 687.38 5,997,587.03 Point 0.00 -785.00 340,22 5,998,156.02 Point 10 0.00 14.07 291.03 5,998,955.02 Point 11 0.00 0.00 0.00 5,998,941.00 3H-2611_701 0.00 0.00 5,961.00 -1,419.551,139,811.44 5,998,648.00 - plan misses target center by 1139726.35usft at 7975.00usft MD (5787.28 TVD, -2773.55 N. 85.91 E) - Point 31-1-26 CTD Polygon Nor 0.00 0.00 0.00 -2,008.561,140,063.57 5,998,059.00 - plan misses target center by 1139992.61 usft at 7975.00usft MD (5787.28 TVD, -2773.55 N, 85.91 E) - Polygon Measured Vertical Point 0.00 0.00 0.00 5,998,059.00 Point 0.00 -173.96 236.06 5,997,885.01 Point 0.00 2,007.38 769.61 6,000,066.04 Point 0.00 1,944.45 1,096.66 6,000,003.06 Point 0.00 -367.90 597.14 5,997,691.03 Point 0.00 -617.99 312.17 5,997,441.02 Point 0.00 -424.07 -138.92 5,997,635.00 Point 0.00 -174.07 -242.98 5,997,884.99 Point 0.00 0.00 0.00 5,998,059.00 1,638,222.00 70° 10'22,971 N 140° 48'28.517 W 1,638,222.00 1,638,215.04 1,638,499.06 1,638,618.09 1,638,076.16 1,638,423.16 1,638,986.10 1,638,909.07 1,638,562.04 1,638,513.00 1,638,222.00 1,638,352.00 70° 10' 19.934 N 140'48'26.074W 1,638,604.00 70° 10' 13.842 N 140° 48'21.431 W 1,638,604.00 1,638,840.01 1,639,373.89 1,639,700.90 1,639,201.01 1,638,916.03 1,638,465.02 1,638,361.01 1,638,604.00 3H -26L1 T02 0.00 0.00 5,787.00 -2,793.611,140,232.73 5,997,274.00 - plan misses target center by 1140146.82usft at 7975.00usft MD (5787.28 TVD, -2773.55 N, 85.91 E) Point 1,638,773.00 70° 10' 5.970 N 140° 48' 20.016 W Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 8,900 GO 5,822.94 2 3/8" 2.375 3.000 6/12017 3:54:59PM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips ,fAFA. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3H Pad Well: 311-26 Wellbore: 3H-2611 Design: 31-1-261-1_wp02 Plan Annotations Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 5,974.70 5,573.02 -1,144.12 -308.86 TIP 6,277.00 5,855.76 -1,250.27 -317.72 KOP 6,302.00 5,879.36 -1,258.45 -318.80 End 14 dls, Start 45 cis 6,455.29 5,961.01 -1,376.27 -334.42 End 45 die, Start 7 dls 6,525.00 5,961.01 -1,445.68 -340.63 5 6,700.00 5,942.66 -1,619.32 -345.48 6 6,800.00 5,920.78 -1,716.69 -340.34 7 6,900.00 5,898.03 -1,812.48 -323.17 8 7,175.00 5,852.18 -2,061.00 -218.05 9 7,325.00 5,835.49 -2,179.62 -128.12 10 7,550.00 5,809.28 -2,363.18 -1.91 11 7,975.00 5,787.28 -2,773.55 65.91 12 8,450.00 5,802.17 -3,216.38 -65.90 13 8,900.00 5,822.94 -3,634.09 -216.01 Planned TD at 8900.00 Well 3H-26 Mean Sea Level 31-1-26 @ 80.00usft (3H-26) True Minimum Curvature 61112017 3:54:59PM Page 5 COMPASS 5000.1 Build 74 Baker Hughes INTEQ ,O.. ConocoPhillips Travelling Cylinder Report BAKER HUGFIEs Company: ConowPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 3H Pad Site Error: 0.00 usft Reference Well: 31-1-26 Well Error: 0.00 usft Reference Wellbore 31-1-261-1 Reference Design: 31-1-2611_Ap02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3H-26 3H-26 @ 80.00usft (31-1-26) 31-1-26 @ 80.00usft (3H-26) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum Reference 31-1-261.1_wp02 =ilter type: GLOBAL FILTER APPLIED: All welipaths within 200'+ 100/1000 of reference nterpolation Method: MD Interval 25.00usft Error Model: ISCWSA 3epth Range: 5,974.70 to 8,900.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,082.00 usft Error Surface: Elliptical Conic Survey Tool Program Date 5/242017 From To (usft) (usft) Survey (Wellbore) Tool Name Description 121.00 5,974.70 3H-26(3H-26)MWD MWD -Standard 5,974.70 8,900.00 3H-2611_wp02(3H-26L1) MWD MWD - Standard Casing Points Kuparuk 3H Pad - 3H-26 - 3H-26 - 31-1-26 Measured Vertical Casing Hole Depth Depth Allowable Diameter Diameter (usft) (usft) Name Distance Deviation 121.00 121.00 16" 16 26 3,142.80 3,140.36 75/8" 7-5/8 9-7/8 8,900.00 5,902.94 23/8" 2-3/8 3 Summary Kuparuk 3H Pad - 3H-26 - 3H-26 - 31-1-26 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) vertical (usft) Toolface+ Kuparuk 3H Pad Centre Casing- Caravan, No Go Allesends Warning Depth Depth 3H-01 - 31-1-01 - 31-1-01 Depth Azimuth +N/S +E/ -W Out of range 3H-02 - 31-1-02 - 31-1-02 Distance Devlarl. Wsm Waft) (usft) (daft) Out of range 31-1-03 - 31-1-03 - 31-1-03 (usft) (ean) ("1 hurl (usft) Out of range 31-1-04 - 31-1-04 - 31-1-04 5,97500 5.653.30 0.00 000 -177.30 -1,144.24 Out of range 31-1-05 - 31-1-05 - 31-1-05 0.00 0.87 -045 FAIL - Major Risk, CC 6000.00 5.67622 6.000.00 Out of range 31-1-06 - 31-1-06 - 31-1-06 -175.95 -1,154.21 -30835 4-1/4 0.00 Out of range 31-1-07 - 31-1-07 - 31-1-07 6,025.00 5,699.23 6,025.00 5,699.23 021 0.17 -176.07 Out of range 31-1-09 - 31-1-09 - 31-1-09 4-1/4 000 236 -1.18 FAIL - Major Risk Out of range 31-1-10 - SHAD - 31-1-10 Out of range 31-1-10 - 3H -10C - 3H -10C Out of range 3H-10 - 3H -10C1-1 - 3H-10CL1 Out of range 31-1-11 - 31-1-11 - 31-1-11 Out of range 3H -26 -3H -26-3H-26 6,275.00 6,275.00 0.01 9.38 -4.75 FAIL - Major Risk 31-1-26-31-1-261-1-01-31-1-261-1-01_wp01 7,524.99 7,525.00 0.40 1.24 -0.51 FAIL - Minor 1/10 3H-26-31-1-261-7-02-31-1-261-1-02_wp01 7,400.00 7400.00 0.00 0.29 -0.22 FAIL - Minor 1110 Offset Design Kuparuk 3H Pad - 3H-26 - 3H-26 - 31-1-26 oeaet age Emor. 0.0050 Survey Program: 121 -MWD Rule Assigned: Major Risk onset Well Error: 0.00 suit Reference West Semi Miio,Atis Measured Vertical Measured vertical Reference Grand Toolface+ Onset Wellbore Centre Casing- Caravan, No Go Allesends Warning Depth Depth Depth Depth Azimuth +N/S +E/ -W done size Centre Distance Devlarl. Wsm Waft) (usft) (daft) (saa) (am) CI (usft) (ean) ("1 hurl (usft) Wns) 5,975.00 5.65330 5,97500 5.653.30 0.00 000 -177.30 -1,144.24 308.86 4-1/4 0.00 0.87 -045 FAIL - Major Risk, CC 6000.00 5.67622 6.000.00 5,676.22 0.12 009 -175.95 -1,154.21 -30835 4-1/4 0.00 165 -0,83 FAIL -Major Risk 6,025.00 5,699.23 6,025.00 5,699.23 021 0.17 -176.07 -1,163.97 40990 4-1/4 000 236 -1.18 FAIL - Major Risk CC - Min centre to Center distance or covergent point, SF - min separation factor, ES - min ellipse separation 124/2017 10:53:27AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips Project: Kuparuk River Unit Site: Kuparuk 311 Pad almmm�o n,. ram ..1.Hmm: 11 a ...1. r.N WELLBORE DETAILS' 311-2611 REFERENOE INFOIiN4nary Parent Wellbore: 311-26 _ O-We(NaE Remmnm, WN 34.26, Tme era Well: 3H-26 mmpnsTm.sm] Teon MD: 5974.70 Vertu RD)RrM- Nem See -e Wellbore: 3H-261-1 o0ar4u: ones- +E/ -W Semon (VS) Reaen<e: Sbl-0.0044, o WE) Plan: 314-261-1_wp02(311-261311-261-1) raal ebn�arzM7 Latitude Noah Depn Rnererce: 3H46Reommn(3H.2s) 0.00 0.00 6000272.70 Cekulem Wool Mn4 m Ouvace 5355 5440 G 5525 610 cO 5695 t 6 5]BC 5865 U 1= 595c ` 6035 6126 6205 Mean Sea I //.11\ BAKER HUGHES 0 WELL DETAILS: 311-26 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 6000272.70 498654.81 70° 24'43.124 N 150° 0'39.435 W Sec MD Inc Azi TOSS +N/ -S +EAW Dleg TFace VSect Annotation 1 5974.70 23.80 182.70 5573.02 -1144,12 -308.86 0.00 0.00 1144.12 TIP 2 6277.00 17.52 187.55 5855.76 -1250.27 -317.72 2.15 167.01 1250.27 -]00 KOP 3 6302.00 21.02 187.55 5879.36 -1258.45 -318.80 14.00 0.00 1258.45 End 14 d1s, Start 45 dls 4 6455.29 90.00 187.55 5961.01 -1376.27 -334.42 45.00 0.00 1376.27 End 45 d1s, Start 7 dls 5 6525.00 90.00 182.67 5961.01 -1445.68 -340.63 7.00 270.00 1445.68 5 6 6700.00 102.06 180.51 5942.66 -1619.32 -345.48 7.00 350.00 1619.32 6 7 6800.00 103.18 173.43 5920.78 -1716.69 .940.34 7.00 280.00 1716.69 7 8 6900.00 103.08 166.24 5898.03 -1812.48 -323.17 7.00 270.00 1812.48 8 9 7175.00 95.96 148.09 5852.18 -2061.00 -218.05 7.00 250.00 2061.00 OP 9 10 7325.00 96.77 137.56 5835.49 -2179.62 -128.12 7.00 275.00 2179.62 10 11 7550.00 96.52 153.41 5809.28 -2363.18 -1.91 7.00 90.00 2363.18 ' = 11 12 7975.00 89.29 182.33 5787.28 -2773.55 85.91 7.00 103.00 2773.55 .1400 12 13 8450.00 87.22 215.53 5802.17 -3216.38 -65.90 7.00 94.00 3216.38 13 14 6900.00 87.63 184.00 5822.94 -3634.09 -216.01 7.00 270.00 3634.09 8 Planned TD at 8900.00 5355 5440 G 5525 610 cO 5695 t 6 5]BC 5865 U 1= 595c ` 6035 6126 6205 Mean Sea I //.11\ BAKER HUGHES 0 aso FI IP 3 -26/3 1-2fiL -02 -]00 Z H-2 -26 OP ' d 14 i SIass31126 t"� 314-2(1314-2 LI-01 3H-2 3H36 1.02 Z OP 1 T01 %� � tlOSd Slav 11 ' = 5- P armed Mat 00000 .1400 Eni 14 dIs Sue 5 & 6 8 3H-' ISH -2 Lt -1]50 7 8 -2100 E Is,Sta -7-&- aaH-26/ 1 -2450 H-26 H-2&'H-26 3H-2 Ll_ 2,___,_. -2800 .3150 -3500 - _ :"--------3F-26131 2611 -3850 -4200 311- 6/311. 611-0 -4550 .4900 0 0 0 8 0 0 0 0 0 0 0 0 0 0 0 0 West( -)/East(+) (350 usfttin) N Vertical Section at 180.000 (85 usft/in) FI IP J Z I 314-2(1314-2 LI-01 3H-2 3H36 1.02 Z OP 11 18 P armed Mat 00000 Eni 14 dIs Sue 5 & 8 3H-' ISH -2 Lt 7 E Is,Sta -7-&- aaH-26/ H-26 H-2&'H-26 N Vertical Section at 180.000 (85 usft/in) ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-26 31-1-261-1-01 Plan: 31-1-261-1-01_wp01 Standard Planning Report 01 June, 2017 rias BAKER HUGHES ConocoPhillips Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuperuk River Unit Site: Kuparuk 3H Pad Well: 31-1-26 Wellbore: 3H-261-1-01 Design: 311-261-1-01_wp01 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3H-26 Mean Sea Level 3H-26 @ 80.00usft (3H-26) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor BIN BAKEHUGHESR Site Kuparuk 3H Pad 3H-26 Tie On Depth: 7,500.00 Site Position: Northing: 6,000, 110.73 usft Latitude: 70'24'41.531N From: Map Easting: 498,655.44 usft Longitude: 150° 0'39.416 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.01 ° Well 3H-26 Tie On Depth: 7,500.00 Depth From (TVD) +N/ -S +E/ -W Well Position +N/ -S 0.00 usft Northing: 6,000,272.70 usft Latitude: 70° 24'43.124 N 0.00 +E/ -W 0.00 usft Easting: 498,654.81 usft Longitude: 150° 0'39A35 W Position Uncertainty Azimuth 0,00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore Magnetics Design Audit Notes: Version: Vertical Section: 3H-261-1-01 Model Name Sample Date BGGM2016 _ _ 9/1!2017 311-261-1-01_wp01 Declination V) 17 39 Dip Angle 1°) 80.96 ----7 Field Strength (nT) 57,536 --- Phase: PLAN Tie On Depth: 7,500.00 Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 180.00 Plan Sections Measured TVD Below Dogleg Build Tum Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) (I (°) (usft) (usft) (usft) (°1100ft) (°/100ft) (°1100ft) (°) 7,500.00 96.62 149.89 5,815.01 -2,319.47 -2549 0.00 0.00 0.00 0.00 7,675.00 85.51 155.05 5,811.76 -2,474.34 55.21 7.00 -6.35 2.95 155.00 7,850.00 67.72 167.12 5,822.15 -2,639.30 111.70 7.00 1.26 6.90 80.00 8,000.00 89.57 177.46 5,825.72 -2,787.69 131.77 7.00 1.23 6.89 80.00 8,200.00 93.87 190.80 5,819.70 -2,986.59 117.44 7.00 2.15 6.67 72.00 8,600.00 93.41 218.85 5,793.80 -3,345.25 48.49 7.00 -0.11 7.01 90.00 8,900.00 93.19 197.82 5,776.34 -3,607.39 -189.83 7.00 -0.08 -7.01 270.00 Target 61112017 3:57:55PM Page 2 COMPASS 50001 Build 74 I ConocoPhillips .��. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 3H-26 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H-26 Q 80.00usft (311-26) Site: Kuparuk 3H Pad North Reference: True Well: 3H-26 Survey Calculation Method: Minimum Curvature Wellbore: 3H -26L1-01 Depth Inclination Azimuth Design: 3H-260-01_wp01 +EI -W Section Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map I Depth Inclination Azimuth System +N/•S +EI -W Section Rate Azimuth Northing Easting (usft) V) 1`) (usft) (usft) (usft) (usft) (°1100ft) (') (usft) (usft) 7,500.00 96.62 149.89 5,815.01 -2,319.47 -25.49 2,319.47 0.00 0.00 5,997,953.47 498,628.90 TIP/KOP 7,600.00 90.27 152.85 5,809.00 -2,407.03 22.30 2,407.03 7.00 155.00 5,997,865.90 498,676.68 7,675.00 85.51 155.05 5,811.76 -2,474.34 55.21 2,474.34 7.00 155.18 5,997,798.59 498,709.57 Start 7 dls 7,700.00 85.81 156.78 5,813.66 -2,497.10 65.38 2,497.10 7.00 80.00 5,997,775.84 498,719.73 7,800.00 87.07 163.68 5,819.87 -2,590.97 99.11 2,590.97 7.00 79.87 5,997,681.97 498,753.44 7,850.00 87.72 167.12 5,822.15 -2,639.30 111.70 2,639.30 7.00 79.44 5,997,633.65 498,766.02 3 7,900.00 88.33 170.57 5,823.88 -2,688.31 121.36 2,688.31 7.00 80.00 5,997,584.63 498,775.67 8,000.00 8957 177.46 5,825.72 -2,787.69 131.77 2,787.69 7.00 79.88 5,997,485.26 498,786.07 4 8,100.00 91.73 184.12 5,824.58 -2,887.61 130.39 2,887.61 7.00 72.00 5,997,385.35 498,784.67 8,200.00 93.87 190.80 5,819.70 -2,986.59 117.44 2,986.59 7.00 72.08 5,997,286.39 498,771.70 6 8,300.00 93.84 197.81 5,812.98 -3,083.21 92.80 3,083.21 7.00 90.00 5,997,189.78 498,747.05 8,400.00 93.75 204.83 5,806.35 -3,176.10 56.54 3,176.10 7.00 90A7 5,997,096.90 498,710.78 8,500.00 93.61 211.84 5,799.93 -3,263.89 9.21 3,263.89 7.00 90.94 5,997,009.14 498,663.43 8,600.00 93.41 218A5 5,793.80 -3,345.25 48A9 3,345.25 7.00 91.39 5,996,927.79 498,605.72 6 8,700.00 93.39 211.84 5,787.86 -3,426.62 -106.20 3,426.62 7.00 -90.00 5,996,846.44 498,548.00 8,800,00 93.31 204.83 5,782.01 -3,514.44 -153.55 3,514.44 7.00 -90.42 5,996,758.64 498,500.64 8,900.00 93.19 197.82 5,776.34 -3,607.39 -189.63 3,607.39 7.00 -90.83 5,996,665.71 498,464.35 Planned TD at 8900.00 6112017 3:57:55PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips ryR. ConocoPhillips Planning Report BAKER NUMES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kupamk 3H Pad Well: 311-26 Wellbore: 3H-2611-01 Design: 3H-26L1-o1_wp01 Targets Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3H-26 Mean Sea Level 311-26 @ 80.00usft(3H-26) True Minimum Curvature Target Name -hit/miss target Dip Angie Dip Dir. TVD -NIS +E/ -W Northing Easting -Shape (1) (1) (usft) (usft) (usft) (usft) (usft) LaftWtle Longitude 3H-26 CTD Polygon Sot 0.00 0.00 0.00 -1,126.551,139,681.38 5,998,941.00 - plan misses target center by 1139565.71 usft at 8000.00usft MD (5825.72 TVD, -2787.69 N, 131.77 E) - Polygon Diameter (usft) (usft) Name (in) Point 0.00 0.00 0.00 5,998,941.00 Point 0.00 -813.08 -6.81 5,998,128.00 Point 0.00 -1,278.06 277.32 5,997,663.02 Point 0.00 -1,674.08 396.43 5,997,267.02 Point 5 0.00 -3,028.34 -145.31 5,995,912.99 Point 0.00 -3,146.27 201.75 5,995,795.01 Point 0.00 -1,813.00 764.50 5,997,128.04 Point 0.00 -1,353.98 687.38 5,997,587.03 Point 0.00 -785.00 340.22 5,998,156.02 Point 10 0.00 14.07 291.03 5,998,955.02 Point 11 0.00 0.00 0.00 5,998,941.00 1,638,222.00 70'10'22.971N 1,638,222.00 1,638,215.04 1,638,499.06 1,638,618.09 1,638,076.16 1,638,423.16 1,638,986.10 1,638,909.07 1,638,562.04 1,638,513.00 1,638,222.00 3H-2611-01_702 0.00 0.00 5,776.00 -3,650.751,139,955.86 5,996,417.00 1,638,496.00 - plan misses target center by 1139824.42usft at 8000.00usft MD (5825.72 TVD, -2787.69 N, 131.77 E) - Point 3H -261-1-01_T01 0.00 0.00 5,825.00 -2,808.611,140,275.74 5,997,259.00 1,638,816.00 - plan misses target center by 1140143.97usft at 8000.00usft MD (5825.72 TVD, -2787.69 N, 131.77 E) - Point 3H-26 CTD Polygon Nor 0.00 0.00 0.00 -2,008.561,140,063.57 5,998,059.00 - plan misses target center by 1139946.96usft at 8000.00usft MD (5825.72 TVD, -2787.69 N, 131.77 E) - Polygon Diameter (usft) (usft) Name (in) Point 0.00 0.00 0.00 5,998,059.00 Point 0.00 -173.96 236.06 5,997,885.01 Point 3 0.00 2,007.38 769.61 6,000,066.04 Point 0.00 1,944.45 1,096.66 6,000,003.06 Points 0.00 -367.90 597.14 5,997,691.03 Point 0.00 -617.99 312.17 5,997,441.02 Point 0.00 424.07 -138.92 5,997,635.00 Point 0.00 -174.07 -242.98 5,997,884.99 Point 0.00 0.00 0.00 5,998,059.00 Casing Points Plan Annotations 140° 48' 28.517 N 70" 9'58.058 N 140° 48'31a68 W 70° 10'5.761 N 140° 48' 1,638,604.00 70" 10' 13.842 N 140° 48'21 .431 W 1,638,604.00 1,638,840.01 1,639,373.89 1,639,700.90 1,639,201.01 1,638,916.03 1,638,465.02 1,638,361.01 1,638,604.00 Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 8,900.00 5,776.34 23/8" 2.375 3.000 Measured Vertical Local Coordinates Depth Depth +NIS +E/ -W (usft) (usft) (usft) (usft) Comment 7,500.00 5,815.01 -2,319.47 -25.49 TIP/KOP 7,675.00 5,811.76 -2,474.34 55.21 Start 7 dls 7,850.00 5,822.15 -2,639.30 111.70 3 8,000.00 5,825.72 -2,787.69 131.77 4 8,200.00 5,819.70 -2,986.59 117.44 5 8,600.00 5,793.80 -3,345.25 48.49 6 8,900.00 5,776.34 -3,607.39 -189.83 Planned TD at 8900.00 6/12017 3:57'55PM Page 4 COMPASS 5000 1 Build 74 Baker Hughes INTEQ rias ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 3H Pad Site Error: 0.00 usft Reference Well: 3H-26 Well Error: 0.00 daft Reference Wellbore 311-261_1-01 Reference Design: 3H-26L1-01_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3H-26 3H-261@ 80.00usft (311-26) 311-26 ® 80.00usft (311-26) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum Reference 3H-261_1-01_wp01 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,500.00 to 8,900.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,082.00 usft Error Surface: Elliptical Conic Survey Tool Program Date 5/24/2017 From To (usft) (usft) Survey (Wellbore) 121.00 5,974.70 311-26 (311-26) 5,974.70 7,500.00 3H-26L1_wp02(3H-261_1) 7,500.00 8,900.00 311-261-1-01_wp01(3H-2611-01) Casing Points Measured Vertical MWD Depth Depth MWD - Standard (usft) (usft) 7-5/8 121.00 121.00 16" 3,142.80 3,140.36 7 5/8" 8,900.00 5,856.34 23/8" Tool Name Description MWD MWD -Standard MWD MWD - Standard MWD MWD - Standard Casing Hole Diameter Diameter Name 16 26 7-5/8 9-7/8 2-3/8 3 Summary Kuparuk 3H Pad -3H-26-3H-261_1-3H-26L1wp02 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 3H Pad vertical Measured Vertical Refen.nce Green 3H-01 - 311-01 - 311-01 we., Wellbore Centre Caused- Centre to No Go Out of range 311-02 - 311-02 - 311-02 trends Ceptin earth Out of range 3H-03 - 3H-03 - 3H-03 +NIS +FJ -W Holistas Cents Out of range 3H-04 - 3H-04 - 311-04 roan) lean) loan) lural Out of range 3H-05 - 3H-05 - 3H-05 M loam (ush) 111 Out of range 3H-09 - 311-09 - 311-09 tuaal ],50000 5,89501 7,500.00 Out of range 311-26 - 31-1-2611 - 3H-26L1_wp02 7,524.99 7,525.00 0.40 1.25 -0.48 FAIL- Minor 1110 3H-26-311-261-1-02-311-261-1-02_wp01 7,518.19 7,525.00 33.54 1.34 33.25 Pass - Minor 1110 Offset Design Kuparuk 3H Pad -3H-26-3H-261_1-3H-26L1wp02 West site error: 0,00 uan survey Program: 121 -MWD, 5975 -MWD Rule Assigned Minor 1/10 Offset Well Error. O.DOasa Ridenour. West semi Major Asia Measured vertical Measured Vertical Refen.nce Green TaaHan♦ we., Wellbore Centre Caused- Centre to No Go Agowable Warning Ce1n, trends Ceptin earth Azimuth +NIS +FJ -W Holistas Cents Clarence Deviation roan) lean) loan) lural last lurri M loam (ush) 111 loan) (deft) tuaal ],50000 5,89501 7,500.00 5.895.01 000 000 149.09 -2.31947 35.49 2-11116 000 029 -0.22 FAIL -Minor 1110, CC 7,524.99 5.892.47 7.525.00 5,892.13 0A9 063 -17606 -2,341.14 1337 2.11116 040 1.25 -048 FAIL- Minor 1110, ES, SF 7.549.95 5,89062 7,550.00 5.88928 0.97 1.27 -175.23 -2,383.18 -181 2-11116 161 1.37 0.39 Paas-Mliwel/10 7,57683 5.889.47 7.575.00 5.805.53 1.40 1.76 -17387 -2,38556 8.98 2-11116 355 138 2.24 Pass-Mlnorl/10 71599.62 5.809.00 7.600.00 5883.95 1.83 225 -17236 -2.40827 18.99 2-11118 6.15 1.38 5.13 Pass-Minm1/10 7.62429 5,88921 7,62500 5.881.55 2.23 2.67 -170.97 -2,431.30 2844 2-11116 9.41 137 9.19 Pass-Minari/10 7,64881 589009 7,65000 5,879.32 2.62 3.09 -16970 -2,45460 37.20 2-11/16 13.33 1,32 13.10 Pass - Minor 1110 7,673.17 5.891.62 7.67500 5,07728 299 3,45 -168.53 -2,470.10 4526 2-11118 17.89 1.36 17,67 Pass - Minor 1110 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 5/242017 11:03:24AM Page 2 COMPASS 50001 Build 74 ConocoPhillips Project: Nuparuk River Unit Site: Kuparuk 3H Pad Mun ;b°sy. M.pi rw WELLBORE DETAILS: 3H-2611-01 avaaexcfi wroRM4TI0N Parent Welltere: 3H-2611 Coag le(N£) Reerenre: WeII3H-2i WRi Well: 3H•26 i�v su°ipn_sisaa., The on MD: 7500.00 Verteinn D)Rel'i Mean See LeW Wellbore: 3H•261-1.01 Plan: SH-26L1-01_vii 1314-26/SH-261.1411) Dip Am%. a4.er eyae'e�sumii +E/ -W sanoo(vsl Retaerce. sloe-loaorv,6mR7 Mmeu�m 0,m Rekrerce: 3tn@waoumldn2sl Easting Latitude CAWAa n MCIM1M: Hnimum Cur Mean 8 riusI HUGHES 0 v-3500 WELL DETAILS: 3H-26 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 6000272.70 498654.81 70° 24'43.124 N 150° 0'39.435 W See MD Inc Azi TOSS +NAS +E/ -W Dleg TFace VSect Annotation 1 7500.00 96.62 149.89 5815.01 -2319.47 -25.49 0.00 0.00 2319.47 - TIP/KOP 2 7675.00 85.51 155.05 5811.76 -2474.34 55.21 7.00 155.00 2474.34 Start? dls 3 7850.00 87.72 167.12 5822.15 -2639.30 111.70 7.00 80.00 2639.30 3 4 8000.00 89.57 177.46 5825.72 -2787.69 131.77 7.00 80.00 2787.69 4 5 8200.00 93.87 190.80 5619.70 -2986.59 117.44 7.00 72.00 2986.59 5 6 8600.00 93.41 218.85 5793.80 -3345.25 48.49 7.00 90.00 3345.25 6 7 8900.00 93.19 197.62 5776.34 -3607.39 -189.83 7.00 270.00 3607.39 Planned TD at 8900.00 Mean 8 riusI HUGHES 0 v-3500 -350 5440 - ........3 -26/3 -26L -02 ao0 FI 5525 H-26 -26 -1050 J 5610 -1400 ti -1'150 -2100 2 5695 TIP/ P P nMd et80D.00 3H-2 3H.0 in. -2950 '', 711-2 /314-2 Ll .1 ... _.Smn MO 314- 611-0 T01 4 -2800 3150 i, 314 ZGLM 1 T02 Phn d.1Du 4 5 6 5950 /l 2611 -3850 -4200 314-2 14.2 LI 6035 JH- 6/3H- 61,1-0 -0550 6120 -0900 0 8 0 0 0 0 0 o e o 0 0 0 0 0 0 0 West( -)/East(+) (350 usft/in) 5355 5440 FI 5525 J 5610 ti 2 5695 P nMd et80D.00 3H-2 3H.0 102 '', 711-2 /314-2 Ll .1 MO ... i, TIP/ OP Start dls 3 4 5 6 5950 314-2 14.2 LI 6035 6120 6205 H-26/ H-26 Vertical Section at 180.000 (85 usft/in) ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-26 3H -26L1-02 Plan: 31-1-261L1-02_wp01 Standard Planning Report 01 June, 2017 WEaI BAKER HUGHES ConocoPhillips red AI ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3H Pad Well: 31-1-26 Wellbore: 31-1-261-1-02 Design: 3H-26Ll-02_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3H-26 Mean Sea Level 311-26 @ 80.00usft (311-26) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3H Pad 311-2611-02_wp01 Audit Notes: Site Position: Northing: 6,000,110.73usft Latitude: 70°24'41.531N From: Map Easting: 498,655.44usft Longitude: 150° 0'39.416 W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: -0.01 ° Well 3H-26 Well Position +N/S +E/ -W Position Uncertainty 0.00 usft Northing: 0.00 usft Easting: 0.00 usft Wellhead Elevation: Wellbore 3H-2611-02 Magnetics Model Name BGGM2016 Sample Date 9/1/2017 6,000,272.70 usft Latitude: 498,654.81 usft Longitude: usft Ground Level: Declination Dip Angle (1 (°) 17.39 80.96 70" 24'43.124 N 150° 0'39A35 W 0.00 usft Field Strength (n T) 57,536 Design 311-2611-02_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,400 OD Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction Dogleg (usft) (usft) (usft) (°) Depth 0.00 0.00 0.00 000 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100ft) (°1100ft) (°/100ft) (°) Target i 7,400.00 96.75 142.85 5,826.66 -2,236.82 -80.46 0.00 0.00 0.00 0.00 7,470.00 82.38 132.83 5,827.19 -2,268.51 -33.66 25.00 -20.52 -14.32 215.00 7,540.00 94.84 120.50 5,828.89 -2,330.12 22.27 25.00 17.79 -17.60 315.00 7,800.00 92.04 55.43 5,611.39 -2,321.17 267.76 25.00 -1.07 -25.03 270.00 7,900.00 91.85 30.41 5,607.93 -2,248.56 335.28 25.00 -0.19 -25.01 270.00 8,050.00 91.82 19.91 5,803.12 -2,113.05 398.92 7.00 -0.02 -7.00 270.00 8,250.00 81.94 9.96 5,814.02 -1,920.59 450.33 7.00 -4.94 4.97 225.00 8,375.00 82.04 1.12 5,831.47 -1,797.51 462.27 7.00 0.08 -7.07 270.00 8,750.00 90.64 26.00 5,855.79 -1,437.01 549.62 7.00 2.29 6.63 72.00 9,125.00 91.01 359.75 5,850.30 -1,074.67 632.44 7.00 0.10 -7.00 271.00 9,375.00 91.27 17.25 5,845.29 -828.42 669.23 7.00 0.10 7.00 89.00 9,725.00 91.15 352.74 5,837.78 -482.49 699.48 7.00 -0.03 -7.00 270.00 6/12077 3'58 35PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Coordinate Reference: Well 311-26 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H-26 @ 80.00usft (3H-26) Site: Kuparuk 3H Pad North Reference: True Well: 3H-26 Survey Calculation Method: Minimum Curvature Wetlbore: 311-261-1-02 Depth Inclination Azimuth Design: 3H -26L1-02 wp01 +E/ -W Section Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (e) (e) (usft) (usft) (usft) (usft) (-Mooft) (1) (usft) (usft) 7,400.00 96.75 142.85 5,826.66 -2,236.82 -80.46 -2,236.82 0.00 0.00 5,998,036.11 498,573.95 TIP/KOP 7,470.00 82.38 132.83 5,827.19 -2,288.51 -33.66 -2,288.51 25.00 -145.00 5,997,984.42 498,620.74 Start 26 dls 7,500.00 87.71 127.53 5,829.78 -2,307.77 -10.84 -2,307.77 25.00 -45.00 5,997,965.16 498,643.56 7,540.00 94.84 120.50 5,828.89 -2,330.12 22.27 -2,330.12 25.00 -44.54 5,997,942.81 498,676.65 3 7,600.00 94.67 105.45 5,823.89 -2,353.39 77.16 -2,353.39 25.00 -90.00 5,997,919.53 498,731.53 7,700.00 93.70 80.40 5,616.48 -2,358.43 175.96 -2,358.43 25.00 -91.25 5,997,914.47 498,830.33 7,800.00 92.04 55.43 5,811.39 -2,321.17 267.76 -2,321.17 25.00 -93.11 5,997,951.72 498,922.13 4 7,900.00 91.85 30.41 5,807.93 -2,248.56 335.28 -2,248.56 25.00 -90.00 5,998,024.31 498,989.65 End 26 dls, Start 7 dls 8,000.00 91.84 23.41 5,804.71 -2,159.49 380.48 -2,159.49 7.00 -90.00 5,998,113.36 499,034.87 8,050.00 91.82 19.91 5,803.12 -2,113.05 398.92 -2,113.05 7.00 -90.23 5,998,159.79 499,053.31 6 8,100.00 89.34 17.43 5,802.61 -2,065.69 414.93 -2,065.69 7.00 -135.00 5,998,207.14 499,069.32 8,200.00 84.40 12.47 5,808.07 -1,969.28 440.68 -1,969.28 7.00 -135.03 5,998,303.54 499,095.09 8,250.00 81.94 9.96 5,814.02 -1,920.59 450.33 -1,920.59 7.00 -134.75 5,998,352.22 499,104.75 7 8,300.00 81.96 6.42 5,821.02 -1,871.60 457.36 -1,871.60 7.00 -90.00 5,998,401.21 499,111.81 8,375.00 82.04 1.12 5,831.47 -1,797.51 462.27 -1,797.51 7.00 -89.50 5,998,475.28 499,116.71 8 8,400.00 82.58 2.80 5,834.82 -1,772.75 463.12 -1,772.75 7.00 72.00 5,998,500.04 499,117.56 8,500.00 84.81 9.47 5,845.80 -1,673.99 473.75 -1,673.99 7.00 71.78 5,998,598.79 499,128.21 8,600.00 87.12 16.10 5,852.85 -1,576.78 495.82 -1,576.78 7.00 71.04 5,998,695.99 499,150.30 8,700.00 89.46 22.70 5,855.83 -1,482.56 529.01 -1,482.56 7.00 70.57 5,998,790.19 499,183.50 8,750.00 90.64 26.00 5,855.79 -1,437.01 549.62 -1,437.01 7.00 70.38 5,998,835.73 499,204.12 9 8,800.00 90.70 22.50 5,855.21 -1,391.44 570.15 -1,391.44 7.00 -89.00 5,998,881.30 499,224.65 8,900.00 90.81 15.50 5,853.90 -1,296.95 602.58 -1,296.95 7.00 -89.04 5,998,975.77 499,257.20 9,000.00 90.91 8.50 5,852.40 -1,199.21 623.46 -1,199.21 7.00 -89.13 5,999,073.50 499,277.99 9,100.00 90.99 1.50 5,850.74 -1,099.66 632.16 -1,099.66 7.00 -89.24 5,999,173.03 499,286.71 9,125.00 91.01 359.75 5,850.30 -1,074.67 632.44 -1,074.67 7.00 -89.35 5,999,198.02 499,286.99 10 9,200.00 91.10 5.00 5,848.92 -999.77 635.54 -999.77 7.00 69.00 5,999,272.91 499,290.11 9,300.00 91.20 12.00 5,846.90 -900.95 650.31 -900.95 7.00 89.10 5,999,371.72 499,304.89 9,375.00 91.27 17.25 5,845.29 -828.42 669.23 -828.42 7.00 89.24 5,999,444.24 499,323.83 11 9,400.00 91.27 15.50 5,844.73 -804.45 676.28 -804.45 7.00 -90.00 5,999,468.21 499,330.88 9,500.00 91.25 8.50 5,842.54 -706.71 697.05 -706.71 7.00 -90.04 5,999,565.93 499,351.66 9,600.00 91.22 1.50 5,840.38 -607.18 705.75 -607.18 7.00 -90.19 5,999,665.45 499,360.38 9,700.00 91.17 354.49 5,838.29 -507.32 702.26 -507.32 7.00 -90.34 5,999,765.30 499,356.91 9,725.00 91.15 352.74 5,837.78 -482.49 699.48 482.49 7.00 -90.49 5,999,790.14 499,354.13 Planned TD at 9726.00 6112017 3:58:35PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips Planning Report Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Project: Kupawk River Unit MD Reference: Site: Kuparuk 3H Pad North Reference: Well: 31-1-26 Survey Calculation Method: Wellbore: 3H-2611-02 0.00 Design: 31-1-261-1-02_wp01 5,998,128.00 Targets 0.00 -1,278.08 Target Name 5,997,663.02 Po1nt4 -hillmiss target Dip Angle Dip Dir. TVD +NlS -E/-W Northing -Shape (1 V) (usft) (usft) (usft) (usft) 31-1-26 CTD Polygon SOL 0.00 0.00 0.00 -1,126.551,139,681.38 5,998,941.00 - plan misses target center by 1138990.72usft at 9600.00usft MD (5840.38 TVD, -607,18 N, 705.75 E) - Polygon N, 705.75 E) Point Point 0.00 0.00 0.00 5,998,941.00 Point 0.00 -813.06 -6.81 5,998,128.00 Point 0.00 -1,278.08 277.32 5,997,663.02 Po1nt4 0.00 -1,674.08 396.43 5,997,267.02 Points 0.00 -3,028.34 -145.31 5,995,912.99 Point6 0.00 -3,146.27 201.75 5,995,795.01 Point 0.00 -1,813.00 764.50 5,997,128.04 Pointe 0.00 -1,353.98 687.38 5,997,587.03 Point 0.00 -785.00 340.22 5,998,156.02 Point 10 0.00 14.07 291.03 5,998,955.02 Point 11 0.00 0.00 0.00 5,998,941.00 I/.is BAKER HUGHES Well 3H-26 Mean Sea Level 3H-26 @ 80.00usft (31-1-26) True Minimum Curvature Easting (usft) Latitude Longitude 1,638,222.00 70° 10'22.971 N 140° 48'2&517 W 1,638,222.00 1,638,215.04 1,638,499.06 1,638,618.09 1,638,076.16 1,638,423.16 1,638,986.10 1,638,909.07 1,638,562.04 1,638,513.00 1,638,222.00 3H -261-1-02_T01 0.00 0.00 5,803.00 -2,108.491,140,560.64 5,997,959.00 1,639,101.00 70° 10' 12.136 N 140° 48'7.652 W - plan misses target center by 1139855.88usft at 9600.00usft MD (5840.38 TVD, -607.18 N, 705.75 E) Point 31-1-2611-02_702 0.00 0.00 5,856.00 -1,535.411,140,671.55 5,998,532.00 1,639,212.00 70° 10' 17.536 N 140" 48' 1.981 W - plan misses target center by 1139966.18usft at 9600.00usft MD (5840.38 TVD, -607.18 N, 705.75 E) - Point 3H-2611-02_703 0.00 0.00 5,838.00 -526.281,140,845.39 5,999,541.00 1,639,386.00 70° 10'27,075 N 140° 47'52S06 W - plan misses target center by 1140139.64usft at 9600.00usft MD (5840.38 TVD, -607.18 N, 705.75 E) - Point 3H-26 CTD Polygon Nor 0.00 0.00 0.00 -2,008.561,140,063.57 5,998,059.00 1,638,604.00 70° 10' 13.842 N 1400 48'21.431 W - plan misses target center by 1139373.65usft at 9600.00usft MD (5840.38 TVD, -607.18 N, 705.75 E) - Polygon Point 0.00 0.00 0.00 5,998,059.00 1,638,604.00 Point 0.00 -173.96 236.06 5,997,885.01 1,638,840.01 Point 0.00 2,007.38 769.61 6,000,066.04 1,639,373.69 Point4 0.00 1,944.45 1,096.66 6,000,003.06 1,639,700.90 Points 0.00 -367.90 597.14 5,997,691.03 1,639,201.01 Point 0.00 -617.99 312.17 5,997,441.02 1,638,916.03 Point 0.00 -424.07 -138.92 5,997,635.00 1,638,465.02 Point 0.00 -174.07 -242.98 5,997,884.99 1,638,361.01 Point 0.00 0.00 0.00 5,998,059.00 1,638,604.00 Casing Points _ Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 9725.00 5,837.78 2318" 2.375 3.000 6112017 3:58:35PM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips wift. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupawk River Unit Site: Kuparuk 3H Pad Well: 31-1-26 Wellbore: 3H-261-1-02 Design: 31-1-2611-02_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3H-26 Mean Sea Level 311-26 @ 80.00usft (3H-26) True Minimum Curvature Plan Annotations Measured Vertical Local Coordinates Depth Depth -NIS +E/ -W (usft) (usft) (usft) (usft) Comment 7,400.00 5,826.66 -2,236.82 -80.46 TIP/KOP 7,470.00 5,827.19 -2,288.51 -33.66 Start 25 dls 7,540.00 5,828.89 -2,330.12 22.27 3 7,800.00 5,811.39 -2,321.17 267.76 4 7,900.00 5,807.93 -2,248.56 335.28 End 25 dls, Start 7 dis 8,050.00 5,803.12 -2,113.05 398.92 6 8,250.00 5,814.02 -1,920.59 450.33 7 8,375.00 5,831.47 -1,797.51 462.27 8 8,750.00 5,855.79 -1,437.01 549.62 9 9,125.00 5,850.30 -1,074.67 632.44 10 9,375.00 5,845.29 -628.42 669.23 11 9,725.00 5,837.78 -482.49 699.48 Planned TD at 9725.00 61112017 3:58:35PM Page 5 COMPASS 5000.1 Build 74 Baker Hughes INTEQ RAN ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 3H Pad Site Error. 0.00 usft Reference Well: 3H-26 Well Error: 0.00 usft Reference Wellbore 31-1-261.1-02 Reference Design: 3H-26L1-02_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3H-26 31-1-26 @ 80.00usft(31-1-26) 3H-261@ 80.00usft (31-1-26) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum Reference 3H-26L1-02_wp01 Filter type: GLOBAL FILTER APPLI ED: All welipaths within 200'+100/1000 of reference Depth Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,400.00 to 9,725.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,164.50 usft Error Surface: Elliptical Conic Survey Tool Program Date 5/24/2017 From To (usft) (usft) Survey (Wellbore) Tool Name Description 121.00 5,974.70 3H-26 (3H-26) MWD MWD - Standard 5,974.70 7,400.00 31-1-261-1_Wp02(3H-261_7) MWD MWD -Standard 7,400.00 9,725.00 31-1-2611-02_wp01 (31-1-2611-02) MWD MWD -Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 121.00 121.00 16" 16 26 3,142.80 3,140.36 75/8" 7-5/8 9-7/8 9,725.00 5,917.78 2 318" 2-3/8 3 (usft) (usft) Vii (usft) Offset Toolface+ Summary Kuparuk 3H Pad -3H -09 -3H -09-3H-09 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore- Design (usft) (usft) (usft) Vii (usft) Offset Toolface+ Kuparuk 3H Pad Casing- Centre to No 09, Allowable Warning Depth Depth 0i 31-1-01 - 3H-01 - 3H-01 Azimuth -Ni +V -W Out of range 3H-02 - 3H-02 - 3H-02 Distance Doi (oaa) )usn) (usft) (usm Out of range 3H-03 - 3H-03 - 3H-03 r) (usft) (usm fi jus") Out of range 3H-04 - 3H-04 - 314-04 9,059.55 5.882.85 7200.00 6.273.67 27,61 35.96 Out of range 3H-05 - 3H-05 - 3H-05 143637 2.11116 1,162.53 18143 990.89 Pass - Major Risk Out of range 3H-07 - 3H-07 - 311-07 6,24&77 27.61 3583 128.14 -2.45818 Out of range 3H -09 -3H -09-3H-09 8,067.07 6,675.00 1,050.35 180.20 871.62 Pass - Major Risk 3H-10 - 31-1-10C - 3H -10C 3579 126.96 -2.457.24 1,43252 2-11116 Out of range 3H-10 - 3H-10CL1 - 3HA DCL1 969,46 Pass - Major Risk 8,0810 5.882.82 7.12500 6,198.95 27.0 Out of range 3H -26 -3H -26-3H-26 8,650.00 6,325.00 873.25 63.59 809.80 Pass - Major Risk 3H-26 - 3H-261_1 - 3H -26L1 wpO2 7,400.00 7,400.00 0.00 0.29 -0.22 FAIL- Minor 1110 31-1-26-3H-261-1-01-31-1-261-7-01_wp01 7,400.00 7,400.00 0.00 0.29 -0.22 FAIL - Minor 1110 Offset Design Kuparuk 3H Pad -3H -09 -3H -09-3H-09 Was'sae Error: 0o0 usn survey Program: 100 BOSS -GYRO Ruk Assigned: Major Risk Dent Well Error: 000 on Nehrence Offset semi Major As. Maaaured venlcal Measured Vii Reference Offset Toolface+ ORaet WelOora Centre Casing- Centre to No 09, Allowable Warning Depth Depth 0i Derain Azimuth -Ni +V -W HOW Sim centre Distance Doi (oaa) )usn) (usft) (usm lush) lural r) (usft) (usm fi jus") (usftj (daft) 9,059.55 5.882.85 7200.00 6.273.67 27,61 35.96 12929 -2459.12 143637 2.11116 1,162.53 18143 990.89 Pass - Major Risk 8.060.96 5,982.84 7,175.00 6,24&77 27.61 3583 128.14 -2.45818 143445 2-11116 1.152.35 18138 979,93 Pass -Major Risk 8060.56 5.882.83 7,150.00 8.22386 27.60 3579 126.96 -2.457.24 1,43252 2-11116 1,142.56 1a132 969,46 Pass - Major Risk 8,0810 5.882.82 7.12500 6,198.95 27.0 35.75 125.Tr -2,456.31 1,430.58 2-11116 1,133.24 161.27 95947 Pass - Major Risk 8,08148 5,982.81 7.100.00 6,17405 2759 35.72 1211.55 -2,45541 1,428,60 2-11116 1.12637 181.21 94996 Pass -Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 5x242017 11:09:44AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips Project: Ku ruk River Unfit 1 Pe Site: Kuparuk 3H Pad awuremnu Nunn e+m xrm: ,- tee. sda WELLBORE DETAILS: 3H.2621-02 RERERENCE INFOWMTION Parent Wellbore 3H-26LI Doaanate(N )Refnerce: M3H28,T�ae NwN Well: 311-26 snerpn srsw.mr Tie on MD: ]400.00 ve,erei IND) Revere: Mrm See L� Wellbore: 3(-2626102 O.n atl.:mas. +E/ -W Se nlVSlRele,eae:8b1-pnay9mE1 Plan: 311.261-7-02 wP0713H36q(-2621-D2) vat c%wiT Meawmt Evan R 3xx(9oawnlJn-3s1 Longitude 0.00 0.00 Mallotlmt(hal CelwkOon '. Mnimam Curvnlure 5355 544D = 5525 5610 3 pip 5695 L 6 5780 5865 V 5950 7 N 6035 F 6120 6205 Mean Sea L Vertical Section at 0.00° (85 usft/in) M c ri.s BAKER HUGHES 0 WELL DETAILS: 31-1-26 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 6000272.70 498654.81 $ 70° 24'43.124 N 150° 0'39.435 W Sec MD Inc Azi TVDSS +N/ -S +E/ -W Dleg TFace VSect Annotation 1 7400.00 96.75 142.85 5826.66 -2236.82 -80.46 0.00 0.00 -2236.82 TIP/KOP 2 7470.00 82.38 132.83 5827.19 -2288.51 -33.66 25.00 215.00 -2288.51 Start 25 ills 3 7540.00 94.84 120.50 5828.89 -2330.12 22.27 25.00 315.00 -2330.12 3 4 7800.00 92.04 55.43 5811.39 -2321.17 267.76 25.00 270.00 -2321.17 .I 6 4 4 5 7900.00 91.85 30.41 5807.93 -2248.56 335.28 25.00 270.00 -2248.56 -26 End 25 dls, Start 7 dls 6 8050.00 91.82 19.91 5803.12 -2113.05 398.92 7.00 270.00 -2113.05 6 7 8250.00 81.94 9.96 5814.02 -1920.59 450.33 7.00 225.00 -1920.59 7 8 8375.00 82.04 1.12 5831.47 -1797.51 462.27 7.00 270.00 -1797.51 10 8 9 8750.00 90.64 26.00 5855.79 -1437.01 549.62 7.00 72.00 -1437.01 9 10 9125.00 91.01 359.75 5850.30 -1074.67 632.44 7.00 271.00 -1074.67 10 11 9375.00 91.27 17.25 5845.29 -828.42 669.23 7.00 89.00 -828.42 11 12 9725.00 91.15 352.74 5837.78 482.49 699.48 7.00 270.00 -482.49 Planned TD at 9725.00 5355 544D = 5525 5610 3 pip 5695 L 6 5780 5865 V 5950 7 N 6035 F 6120 6205 Mean Sea L Vertical Section at 0.00° (85 usft/in) M c ri.s BAKER HUGHES 0 $ PI natal I D at 25 00 -350 s a j 11-26/ H-26 End 2 dls,Son 7 al m -.-3 4 -2N3 -261. .02 Boo Y 3 '26/3 -26LI 1 .I 6 4 7 H-26/ -26 3 -261.1 02 TO -1050 12nn TD at 9725. -1400 P/KO 10 11 .1750 Su 25 dl 8 3H-2 1-02 M2 n o0 .......___ Son 25 ala.. ,_ '311- -zaso 6 TIF -- 1-261, -02 T 11 - ata 25 Is, Stai 7 dls 2800 -3150 -3500 .t .:...............3 .2N3 -26LI -3850 -0200 3H- W31r. 6L1-0 .4550 -4900 e o 0 8 0 0 8 0 0 0 0 o e o 0 0 0 West( -)/East(+) (350 usf /in) 1 $ s a j 11-26/ H-26 End 2 dls,Son 7 al m Y 3 '26/3 -26LI 1 .I 6 4 7 y 12nn TD at 9725. P/KO 10 11 Su 25 dl '311- 6I3H- 6 1 ConocoPhillips Project. Kuperuk River Unit Site:MpMie KMparuk SH Pad PiMWrcwilue xaM xem�:na� M.xMx�r1.M WELLBORE DETAILS: 3H-2611 REFERENCE INFORMATION Parent Wellbore: 314-26 C.=.W MI7 Rekrerue'. We03 3, TrueN h OW Well: 314-26 slwlMm srs0e.xo Tie on MD: 6974.70 vxursl frwl 6Meferce'. 31+-26 @ Wendt 13x461 Wellbore: 314-2611 114 �eM.��, 6lod iV6)Rvererce', slm-(@M.M Plan: 314-2811 vp02)3H-2MI4.261-1) mw wvmn Mo4e1'. e00Mm1 Meewretl DepN ReMrem'. 3N26@B].WYEn 13w261 t( CabiMlnn MepIW M,nxmm ClrvSure 111.1'Jll l-12 a166n11,1 111 -91011 -SMA 316I'll, M In 111-L'011.lyftnl ,111 IiyltlllA191 111-1411,1-I I'll2 1pgNiu-10011 II IR911 I6A lll-I'_I,II LISA II-2Wyy y `l1-IffilI I'A Jltdx/!1414x1.1 11111/111 -IIA 1116.III�AP01 Ip IypII l2U i42A111k1�IRl6 11WIH14131 ,C"1rld 1n14WA 11111911-11x.1 ) '1140 111. 11 uMiu-laum 111-I{AII.IIAI. I.N 31116111! -fid lulxHlllx (1i 164'12.._.] 1. .1xFn .ldAa311'L. 311.1211, 1.1111 11 200 — hlizlllv A ,]11h .i-IAY+IYH� _ i T xI i 1111 1 ;- l nnlh 11(11!1 - �-- o 11 -TI, -400 11AK Ilan: I �� a ' � o ' •i I .. IIIY j � y_- i111�1 -400 -600 0 -800 -- 1 - - I -1000 I 1 I -1200 r T -1400 31600 C I p-1800 - o NI -2200 - r - -- �- 2400 — — - 2600 W - -- .2800 - 141 \\ -3000 -3200 -3400 -3600- - 1800 II moll Sol 1 11� �: -4000 4200 Ly. 4400 -32W -3000 -2800 -2600 -2400 -2200 -2000 -1800 -1600 -1400 -1200 -IWO -800 -600 -400 -200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 West( -)/East(+) (200 us8/in) 3H-26 @ 80.00usft (311-26) MAN BAKER HUGHES /�-����� KUP PROD 3H-26 4.A/11�iffi� $ Well Attributes Max Angie&MD TD Alap1ar41D WellO32AF-He 000' FIaMNwna WellEoreblAus ncll°) MV (fltt0) 61m IN66 Sm 032020800 KUPARUK RIVER UNIT PROD 39.20 514990 ec 6,fifi00 Comment K]S(ppm) Dab MneMtinn En40ab KaGeE 1N RiB R¢Ieau G@ 3nz45nSn0189AeD8 AM SASV: NIPPLE 120 tO1201fi Leel WO: U29I2005 40.99 31611994 anbemaan e MnMNiOn Deplll (M1KBj Eno Gb AnnoWlbn Iaal Moo ar End Dale Lest Tag: ALM 6,323.0 3/z42015 Rev Reeson: H25, GLVC10 pproven 5/252016 �AFFFR.ms asmg rags caamg Lesnlpron oDlinj mlinj Tnp (NK¢) S¢I DePIn InKe) Gn Depth lrvo)....1-s. p... Grade Top Tbeaa CONDUCTOR i6 15062 409 1210 121.0 62.50 H-40 WELDED Laing DeuFlpllOn OO llnj ID(inj TOp IM1Ka) SMDep.IXK.)-,uepu1 DVD)... WVLan (1... 4nEe Top Tne¢na SURFACE )SIB 58)5 40.9 3.1428 3.140.3 2970 LAO LTC Lasln, GscrlplionW'in) 1u Fn) Tnp.7B] SN Dep101XKa) Se1Dep`IND'... --n--n11... Gni. Tep Tnrua 1 PRODUCTION 51/2 42]fi 36,643.6,2909 17,(061L-80LTC 5.5x5'@6552' Tubing Strings Tobin aa["I" Slrmy Ma._ ID lin) TnPlflKB sel D¢Pm IN_ sel DaPP (ID) 6.. wil Al Gna¢ TOPCnnn¢mmL TUBING WO 31/2 1 3]0 6.1260 5,]93.1 9.301.80 EUE IST Completion Details Nominal l0 CONDUCTOR mR4 ', D.o-utD Top (FKDj Top ND IIKB TO Incl •) didDes Co. 3 37B 3]8 009 HANGER FMC TUBING HANGER 35pp 5042 5042 1.16 NIPPLE CAMOO BP-61 LANDING NIPPLE 2075 6,106.2 5J]4.fi 21.13 NIPPLE CAM IDS' NIPPLE 2.812 uu=FLe seas 6113.2 5]81.1 2098 LOCATOR BAKER GBW22 LOCATOR 2850 6.113.5 5.)814 2090 SEALASSY BAKER NOT GBH-22 SEAL ASSY 2.05"DRIFT 2900 Perforations & Slots snot Gna ToppK2 don "OR (Mho Toe (NK¢) eM (xxel Ixxel zone vaM II TrpeLdegph cam cqs urr ns5r fi.250.0 ,28 . 6,280.0 5,9100 5,9358 G4, 03.314 &191998 4.0 RPERF rided, O deg ph 26 6.250.0 6.2800 5,91DO 5,938.60-0, CA, 3H- 41911997 -40 PERE PIVOTS, 180 26 6,30fi0 53360 5,9634 5,9922 A-3.A-2.3H- 612411994 4.0 (PERF ner3e1900¢926 Mandrel Inserts ev n SDRFgCE'. 1O.11.1aRe- H Top INO) To2,76S (2,76 said MOEN OD (in) Valve Type /diel/ Pn(ISIu TRO Run Tree lin' (psi) Run Gb Lam 2y85] 2,]835 GAMCO KBG-2- O f LIF GAS LIFT GLV BTM O.iBB 1,2420 52412016 9 2 4,124A 4.0982 CAMCO KBG-2- 1 GASLIFT OV BTM 0,250 0.0 5242016 GASLIFTI4,124A 9 3 4,987,6 4,836.7 CAMCO KBG-2- 1 GAS LIFT DMS BTM 0,000 e0 1132D16 9 4 5,6309 5,3519 CAMCO KBG2- 1 GAS LIFT DMY DK-1 -7070-0 0.0 613012005 9 5 5055.1 5)2]0 CAMCO KBG2- 1 GAS LIFT DMY DK-1 0.000 00 6/30/2005 9 GAS UFT: I.sers Notes: General & Safety An Eoa Dal¢ nnlmlon 4/292005 NOTE. TREE FMC&1/8 '/ GEN IV 15000 psi aletl 111262009 NOTE: VIew Sglemedi w/ A,AnSd SLSemel.0 GAS LIFT: 6.055.1 IIIFFLE: 8.106 z SEALASLY:611]5 OP.,',6]SD 05,]90-0 IPERF',6p5006R90A IPERF,6d08A-8.3380 FRGGUCTLON 5AS®6535. 3S)-08 3.1 3H-26 Proposed CTD Schematic 16"62# H-40 shoe @ 121' MD 7-5/8" 29.7# L-80 shoe @ 3143' MD 3-1/2" 9.3# L-80 shoe @ XXXX' MD 5-1/2" 17# L-80 @ 6133' MD C -sand pens 6250' - 6280' MD IKOP @ 6277' MD A -sand perfs 6306' - 6336' MD 5" 18# 1.-60 shoe 6643' MD 3-1/2" Cameo Landing Nipple@ 504' MD (2.875" min ID) 3-1/2" 9.34 L-80 ELIE 8rd Tubing to surface 3-1/2" Cameo gas lift mandrels @ 2766', 4124', 4988', 5631', 6055' 3-1/2" Cameo DS nipple @ 6106' MD (2.812" min ID) Baker 3-1/2" GBH -22 seal assembly @ 6114' MD (2.98" ID) 31-1-261.1-02 wp01 TD @ 9725' MD Top of Liner @ 6272' MD 3H -26L1 wp02 TD @ 8900' MD Billet @ 7500' MD 31-1-261-1-01 wp01 TD @ 8900' MD Billet @ 7400' MD TRANSMITTAL LETTER CHECKLIST WELL NAME: K FZ (k. 3 H- — cz( L PTD: 02l 7 —O$7 - ✓Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: 1`wx,O�wI�1L �i�/�J POOL: XIt11G ',R 46d- K40W(tk 14V4F Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK 7 OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. API No. 50-105 -_ ZO-_ 0 - 00. (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 hi 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 sam les 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 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL -490100 _ Well Name: KUPARUK RIV UNIT 3H_2r _Program DEV Well bore seg PTD#:2170870 Company CONOCOPHIL_LIPS ALASKA, INC,__ Initial Class/Type DEV/PEND GeoArea 890 _ Unit 11160 On/Off Shore On Annular Disnosal F Administration 1 r Nonconven. gas contorms to A831.05.030(j 1.A).0.2.A-D) _ NA 1 Permit fee attached_ _ _ _ ... _ NA 2 Lease number appropriate _ _ _ _ _ _ Yes 3 Unique well name and number _ _ _ _ _ _ Yes 4 Well located in a defined _pool _ _ Yes 5 Well located proper distance. from drilling unit. boundary.. Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit.. _ Yes 18 If. deviated, is wellbore plat. included _ Yes �9 Operator only affected party. Yes If diverter required, does it meet regulations 10 Operator has appropriate bond in force _ Yes Appr Date 11 Permit can be issued without conservation order. Yes PKB 6/14/2017 12 Permit. can be issued without administrative approval Yes BOPE press rating appropriate: test to (put psig in. comments) 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order# (put. 10# in. comments) (For NA 15 All wells within 114. mite area of review identified (For service well only). _ NA 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA 18 Conductor string provided NA Engineering 19 Surface casing_ protects all known USDWs NA 20 CMT vol adequate to circulate on conductor & surf csg NA. 21 CMT vol. adequate to tie-in long string to surf csg NA 22 CMT. will cover. all known productive horizons No 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes 25 If a re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation. proposed Yes 27 If diverter required, does it meet regulations NA. Appr Date 28 Drilling fluid. program schematic & equip list adequate Yes VTL 6/22/2017 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate: test to (put psig in. comments) Yes 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown_ Yes 33 Is presence of H2S gas probable Yes 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Geology 36 Data presented on potential overpressure zones _ Yes Appr Date 37 Seismic analysis of shallow gas zones NA PKB 6/14/2017 38 Seabed condition survey (if off -shore) _ _ NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Commissioner: Dale: Commissioner: Date Co issioner Date i.l16Iu. ADL0025531, entire wellbore, KRU 3H-261.1_ KUPARUK RIVER, KUPARUK RIV OIL.- 490100, governed. by Conservation Order No. 432D CO 432D contains no spacing restrictions with respect to drilling unit boundaries..... CO 432D has no intenvell spacing restrictions. Wellbore. will be more than 500' from an external property line where ownership or landownership changes. Conductor set in KRU 3H-26 Surface casing set in KRU 3H-26 Surface casing set and fully_ cemented Productive interval will be completed with. slotted liner _ Rig has steel tanks; all waste to approved disposal wells Anti -collision analysis complete; no major risk failures Max formation pressure is 3990 psig(12.7 ppg EMW); will drill w/ 8.6 ppg EMW and maintain overbal w/ MPD MPSP is 3405 psig; will test BOPS to 3750 psig H2S measures required Wells on 3H -Pad are H2S-bearing. 112S measures. required.. _ Max. potential reservoir pressure is 12.7 ppg EMW; will be drilled using 8.6. ppg mud and MPD technique.. Onshore development lateral to be drilled.
