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Home My WebLink About217-078Originated: Delivered to:17-Jan-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1A-26 50-029-22115-00 909678321 Kuparuk River Packer Setting Record Field- Final 14-Nov-24 0 12 1A-26 50-029-22115-00 909619342 Kuparuk River Packer Setting Record Field- Final 21-Oct-24 0 13 1A-27 50-029-22124-00 909781603 Kuparuk River Multi Finger Caliper Field & Processed 25-Dec-24 0 14 1B-19 50-029-22475-00 909619036 Kuparuk River Packer Setting Record Field- Final 17-Oct-24 0 15 1B-20 50-029-23164-00 909619415 Kuparuk River Plug Setting Record Field- Final 8-Oct-24 0 16 1B-20 50-029-23164-00 909678322 Kuparuk River Plug Setting Record Field- Final 13-Nov-24 0 17 1C-04A 50-029-20547-01 909677469 Kuparuk River Packer Setting Record Field- Final 23-Nov-24 0 18 1C-158 50-029-23761-00 909810535 Kuparuk River Injection Profile Field & Processed 11-Jan-25 0 19 1D-05 50-029-20417-00 909607635 Kuparuk River Correlation Record Field- Final 9-Oct-24 0 110 1D-14 50-029-22950-00 909677466 Kuparuk River Packer Setting Record Field- Final 26-Nov-24 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T39991T39991T39992T39993T39994T39994T39995T39996T39997T39998190-166190-180194-064203-115217-078223-056179-095199-0891/23/202571C-04A50-029-20547-01909677469Kuparuk RiverPacker Setting RecordField- Final23-Nov-2401203 115217-078223 056Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.01.23 15:06:40 -09'00' DATA SUBMITTAL COMPLIANCE REPORT 10/24/2017 Permit to Drill 2170780 Well Name/No. KUPARUK RIV UNIT 1C -04A Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-20547-01-00 MD 10675 TVD 6399 Completion Date 7/15/2017 Completion Status 1-0I1 Current Status 1 -OIL UIC No REQUIRED INFORMATION Mud Log No / \/ Samples No Directional Survey Yes✓ DATA INFORMATION Types Electric or Other Logs Run: GR/Res (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH I Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 28448 Digital Data 7/31/2017 Electronic File: 1C -04A EOW - NAD27.pdf ED C 28448 Digital Data 7/31/2017 Electronic File: 1C -04A EOW - NAD27.txt Log C 28448 Log Header Scans 0 0 2170780 KUPARUK RIV UNIT 1C -04A LOG HEADERS I ED C 28489 Digital Data 6930 10675 8/11/2017 Electronic Data Set, Filename: 1C -04A GAMMA RE3.las ED C 28489 Digital Data 8/11/2017 Electronic File: 1C -04A 2MD Final Log.cgm, i ED C 28489 Digital Data 8/11/2017 Electronic File: 1C -04A 5MD Final Log.cgm ED C 28489 Digital Data 8/11/2017 Electronic File: 1C -04A 5TVDSS Final Log.cgm ED C 28489 Digital Data 0 8/11/2017 Electronic File: 1C -04A 21VID Final.pdf , ED C 28489 Digital Data p 8/11/2017 Electronic File: 1C -04A SMD Final.pdf - ED C 28489 Digital Data 0/11/2017 Electronic File: 1C -04A 5TVDSS Final.pdf . ED C 28489 Digital Data 8/11/2017 Electronic File: 1C -04A EOW -NAD27.pdf. ED C 28489 Digital Data 8/11/2017 Electronic File: 1C -04A EOW - NAD27.txt' ED C 28489 Digital Data 8/11/2017 Electronic File: 1C -04A Final TO 10675.csv ' ED C 28489 Digital Data 8/11/2017 Electronic File: 1C -04A Final TO 10675.xlsx ED C 28489 Digital Data 8/11/2017 Electronic File: 1C -04A Survey Listing.txt , ED C 28489 Digital Data 8/11/2017 Electronic File: 1C -04A Surveys.txt ED C 28489 Digital Data 8/11/2017 Electronic File: 1C- 04A_25_tapescan_BHI_CTK.txt ED C 28489 Digital Data 8/11/2017 Electronic File: 1C -04A_5_ tapescan_SHI_CTK.txt ED C 28489 Digital Data 8/11/2017 Electronic File: 1C-04A_output.tap , AOGCC Page 1 of 3 Tuesday, October 24, 2017 DATA SUBMITTAL COMPLIANCE REPORT 10/24/2017 Permit to Drill 2170780 Well Name/No. KUPARUK RIV UNIT 1C -04A Operator CONOCOPHILLIPS ALASKA, INC. API No. 50.029-20547-01-00 MD 10675 TVD 6399 Completion Date 7/15/2017 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 28489 Digital Data 8/11/2017 Electronic File: 1C -04A 2MD Final.tif ED C 28489 Digital Data 8/11/2017 Electronic File: 1C -04A 5MD Final.tif - ED C 28489 Digital Data 8/11/2017 Electronic File: 1C -04A 5TVDSS Final.tif - Log C 28489 Log Header Scans 0 0 2170780 KUPARUK RIV UNIT 1C -04A LOG HEADERS ED C 28637 Digital Data Q 9/29/2017 Electronic File: 1C-04A_MFC24_03JUL17.pdf - ED C 28637 Digital Data 9/29/2017 Electronic File: 1C- 04A_MFC24_03JUL17_LAS.zip . ED C 28637 Digital Data 9/29/2017 Electronic File: 1C- 04A_MFC24_03JUL17_Report.pdf< ED C 28637 Digital Data 9/29/2017 Electronic File: 1C-04A_MFC24_03JUL17_img.tif ED C 28637 Digital Data 9/29/2017 Electronic File: 1C- 04_MFC24_03JUL17CENTERED.cmi• ED C 28637 Digital Data 9/29/2017 Electronic File: 1C- 04_MFC24_03JUL17_CENTERED.md ED C 28637 Digital Data 929/2017 Electronic File: 1C- 04_MFC24_03JUL17_CENTERED.mp ED C 28637 Digital Data R 9/29/2017 Electronic File: 1C-04A_MFC24_05JUL17.pdf - ED C 28637 Digital Data 9/29/2017 Electronic File: 1C- 04A_MFC24_05JUL17_LAS.zip ED C 28637 Digital Data 9/29/2017 Electronic File: 1C- 04A_MFC24_05JUL17_Report.pdf , ED C 28637 Digital Data 9/29/2017 Electronic File: 1C-04A_MFC24_05JUL17_img.tif- ED C 28637 Digital Data 9/29/2017 Electronic File: 1C- 04_MFC24_05JUL17_CENTERED.cmh ED C 28637 Digital Data 9/29/2017 Electronic File: 1C- 04_MFC24_05JUL17_CENTERED.Wvd. ED C 28637 Digital Data 9/29/2017 Electronic File: 1C- 04_MFC24_05JUL17_CENTERED.mp` Log C 28637 Log Header Scans 0 0 2170780 KUPARUK RIV UNIT 1C -04A LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments AOGCC Page 2 of 3 Tuesday, October 24, 2017 DATA SUBMITTAL COMPLIANCE REPORT 10/24/2017 Permit to Drill 2170780 Well Name/No. KUPARUK RIV UNIT 1C -04A Operator CONOCOPHILLIPS ALASKA, INC. MD 10675 TVD 6399 Completion Date 7/15/2017 Completion Status 1 -OIL Current Status 1-011- INFORMATION -OIL INFORMATION RECEIVED Completion Report L./ Production Test InformatiotoNA Geologic Markers/Tops 0 COMPLIANCE HISTORY Completion Date: 7/15/2017 Release Date: 6/7/2017 Description Comments: Compliance Re Rev API No. 50-029.20547-01-00 UIC No Directional / Inclination Data Mud Logs, Image Files, Digital Data Y /1A Core Chips Y Mechanical Integrity Test Information Y �N�. Composite Logs, Image, Data FilesO Core Photographs Y Daily Operations Summary 0Cuttings Samples Y / I® Laboratory Analyses Y NA Date Comments By: Date: A06CC Page 3 of 3 Tuesday, October 24.2017 RECEIVE® 21 7 0 7 8 28637 SEP 2 9 2017 WELL LOG TRANSMITTAL #904142991 AOGCC To: Alaska Oil and Gas Conservation Comm. August 10, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 w0/ BENOEP RE: Multi Finger Caliper: 1C -04A -- 2 runs Run Date: 7/3/2017 & 7/5/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 1C -04A -- 2 runs Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20547-01 Multi Finger Caliper (Field Log) I color log, ea. 50-029-20547-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS—ANC@halliburton.com Date: Signed-MA--S-m~---,'A- —e -,rt % STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED Nur 15 2017 WELL COMPLETION OR RECOMPLETION REPORT AND L" 1a. Well Status: Oil ❑� , Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25 .10.5 20AAC 25.1'10 GINJ ❑ WI NJ ❑ WAGE] WDSPL❑ No. of Completions: 1b. Well Class: Development ❑� Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 7/15/2017 14. Permit to Drill Number / Sundry: 217-078 3. Address: P.O. Box 100360 Anchorage, AK 99510.0360 7. Date Spudded: &' g; Mq+7- ?/5 11-4 15. API Number: 50-029-20547-01-00 4a. Location of Well (Governmental Section): Surface: 1509' FNL, 4221' FEL, Sec 12, T11 N, R1 OE, UM Top of Productive Interval: 1708' FNL, 1425' FEL, Sec 11, T11 N, R1 OE, UM Total Depth: 5232' FNL, 3435' FEL, Sec 2, T11 N, R1 OE, UM 8. Date TD Reached: 7/9/2017 16. Well Name and Number: KRU 1C -04A 9. Ref Elevations: KB:94 GL: 61 BF: 17. Field / Pool(s): Kuparuk River FieldlKuparuk River Oil Pool 10. Plug Back Depth MD/TVD: 10630/6402 • 18. Property Designation: ADL 25649 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 562065 y- 5968727 Zone- 4 TPI: x- 559584 y- 5968509 Zone- 4 Total Depth: x- 557559 y- 5970249 Zone- 4 11. Total Depth MD/TVD: 10675/6399 19. DNR Approval Number: ALK 467 12. SSSV Depth MD/rVD: 1 N/A 20. Thickness of Permafrost MD/TVD: 1834/1788 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 1 N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 7125/6448 . 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 TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 94 H-40 34 80 34 80 32 245 sx AS II cmt 133/8 72 N-80 33 2910 33 2708 171/2 1800 sx Fondu & 300 sx AS II 95/8 47 L-80 30 6936 30 6258 121/4 800 sx Class G 23/8 4.7 L-80 8148 10630 6436 6402 3 Slotted Liner 24. Open to production or injection? Yes ❑Q No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SLOTTED LINER @ 8148 -10630 MD and 6436 - 6402 ND COMPLETION DATE �I-rei IIIDEPTH VERIFIED �c 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 31/2 1 6986 1 6799/6122 1 16945/6268 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No R] Per 20 AAC 25.283 (i)(2) attach electronic and printed information INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 7/18/207 Method of Operation (Flowing, gas lift, etc.): FLOWING Date of Test: 7/24/2017 Hours Tested: 12hrs Production for Test Period Oil -Bbl: 371 Gas -MCF: 865 mscf Water -Bbl: 1498 Choke Size: 28/176 Gas -Oil Ratio: 2,325 Flow Tubing Press. 372 sl Casing Press: 1 1220 psi Calculated 24 -Hour Rate Oil -Bbl: 742 Gas -MCF: 1725mcsf Water -Bbl: 2995 Oil Gravity- API (corr): 22. Form 10-407 RG vise /5/.L2J017 k4TLQ CONTINUED ON PAGE 2 RBDMS U,AUG 1 7 2017 Submit ORIGINIAL on s llpp 11/ 7 O /� 28. CORE DATA Conventional Corals): Yes ❑ No 21 Sidewall Cores: Yes ❑ No D If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑Q If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1834 1788 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 7126 6448 information, including reports, per 20 AAC 25.071. Formation @ TPI - Kuparuk C Kuparuk B 7227 6541 Kuparuk C 7549 6544 TO 10675 6399 Formation at total depth: Kuparuk 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, paleontolouiral report. Droduction orwell test results. per 20 AAC 25,070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge.g Authorized Name: J. Ohlin er Contact Name: Keith Herrin Authorized Title: Staff CTD Engineer Contact Email: Keith.E.Herrin co .com Authorized Contact Phone: 263-4321 Signature: Date: .511;7 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 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 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 \ KUP PROD 1C-04 ConoeoPhlllipsMIM _QWall Ino• ributes Max Angle &NO TD WeIIWreRPIx1W1 FIeIE Hann WallEore Slalus In. , MD(NKN Act Ron (MB) SOD292054700 NUPARUKftNERUNR i 37.98 4,300.00 ],5]5.0 Comment HRB (ppm) Oab ESBV: NONE PO &10.2018 AnnWalionEnB pad xBGNIN Rip ReIm90Me LaM WO: 12412015 3901 N11w1 ¢o,, N+mon 9sss9Am mauclxbal Ann -Ion Oe h pi.0 Enp Dale Tag: SLIM 7,246.0 12/112016 AnrwMion 'Pru.p By FnE Bite Rev Reaso¢CEMEM PLUG, TAG(CEMENT), ppmven 6181201] MILLED CEMEM to 6,974' .Ad.PN 21a- --'Last LOxppLiGR lmuacea 3Y: 3a Capn GAsurr; 2,0m.t t waFACE;aaw,a,o➢ cM1RUFrp.920A GAsun;a➢624 GASUFT:6fi76➢ GAILIFT6307 G0.4LI1; B.r13I LOGTOR;AIRI3 BFALASBv: e.npa PER: 9.96] PALKER:E,79BH NIPPLE6."93 DeBRsxDT; 6ROv 9827 w£AT; B,91fl2 pRWI1CnOX; 30,tb,935.fi- PPCRER; 6.9153 APMR6X4.DMa6➢- XIPRE: 6.98]5 KS:%584.a /PERF 7,�EA],ARO ALuwEa;MaN.7-mAoeoL WXad'I..%2:7.1i6➢ WNPAAAA +:],+50➢ IPERF:7gpe➢-7.810➢- cerampxpsP6p.OrMe LINER: G Al2.1-7,NS.0- � asNg ngs CazM80emrlplbn BG llnl CONDUCTOR Insula[etl 20 32" IDIIn) Top BtKN Sat DepN (11x81 Sat DepIM1 RVN... WtlLan 11... Grata Top TnreaE 18.940 34.0 80.0 80.0 9400 H40 WELDED C., bPeri%IOn OD (I.) SURFACE 13818 IDrm) Tap MIS) Set DNDI SIM Set DAPA RVD)... WVLen(I GT Top IDra4 12.34] 33.0 2,910.0 2,]0].0 2700 NA0 BTC Laing odualpxon OD (N) PRODUCTION 998 R(In) Top 1ANB) Sx BAPln(ROB) BN Depxr(NDI... Pull -6... Grace Top. 0.051 30.1 6,935.6 6,258.1 47.00 LA0 BTC Lal^g Daanlpidn OD Qn) LINER ID(In) Top(XKBI Bet Da"(flxN fiat DepN )�� W+It^n (L..GMe Top' op TM1roa4 7 6.276 6,612.1 7,5450 6,866.3 2600 K-55 BTG Liner Details Top InKN TOP nvD)IN1e) rop lniT Am pee Co. xomID On)d 6,612.1 5,835.8 5.65 TIE BBACK BAKER TIE BALK SLEEVE S 8.151 6,fi152 5,941.] 5.0 NIPPLE BAKER SEAL NIPPLE 6.151 6,621.5 5,9450 5.58 HANGER BAKER LINER HANGER bis, 6,631fi 5,955.0 550 XO BUSHING BAKER XO CENTRALIZER BUSHING 6.151 Tubing Strings TUN, CeaviIn- s ono Ma... TUBING -WO -2015 3127 -4112x3112@62.8 10 (In)TaP 2.992 lllll8l sx 2).8 DapIh IN.. 6,910.0 sat poon "D) t.. fi,2325 Wt (mml 930 GntY L-80 Top LnnMGlon EUE BN Motl Completion Detalls xolmnalm Top(1r1(B) T.POVD)(HKBj Topinal l') em Des Lom Bn) 276 27.8 0.66 HANGER FMC GEN 3 HANGER WITH LH ACME LIFT THREAD 62.8 62.8 0.13 XO Retludng Cm96Gver Pup 4112"/BTM x 3112"EVE Ertl 6,769.3 6,092.2 4,38 LOCATOR GBH LOCATOR SUB 6.770.2 6,0932 438 SEAL ASSY B040 SEAL ASSEMBLY N2.M 6,7/51 6,0986 4.33 PER BAKER 80-00 PER(29) 67988 6,121.7 4.14 PACKER BAKER4]02FHLRETRIEVASLEPACKER 6 UBS 6,172.0 PAID NIPPLE CAMCD DS NIPPLE 6,901.] 6224.3 4.07 OVERSHOT BAKER POOR BOY OVERSHOT G-wipYalln) .99Top(RKN VBINRIGon $ongM(11p 2s.+Dapu (IL. 4+Depm (TVo1 n.. WtyeNt) Gratle Top LonneRion 6,904.0 6.9864 Q308.8 9.20 K-55 BTG Completion Details Too (ON.) To, (1VD)((MN Top lnd(') Ron We Com • No1aI1D 6.9192 6.2 406 SBR BAKER KB45BR 3.000 -6 9453 6267678 .8 4.4 ER7 PAG ER BAKER FHL PACKER 3.000 6,983.5 6,3059 4.02 IPP E CAMCO D NIPPLE NO GO U.01"NIPPLE REDUCER 2.750 SETW17114-PULLED 2162015) 6,984.4 6.306.8 402 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, eta.) iop(TYp) Top (flIB) (ftRB ITop °) Oas Co. Run Dad /Olin) 7,12G.0 fi4430 3.60 Whipstock N2 BOT Mono6ore %L WTlpatock ]/5201] 0.000 7,150.0 6.4720 3.90 Whipstock#1 BOT Mo... %L.,,. ]131209 0000 7,92.0 6,5931 350 FISH E -LINE SPINNER TLolgxil4°Wide 812012014 perforations & Slots Top("" Bou MIRK Top DVB) MPKB) ..DVD/ (flKN IDne Dad snot (ano.n 6 Type Com 6,964.0 6,966.0 6,286.4 6,2BS4 Oc, 1CA4 UNITS, 42312017 3.0 APERF T HES BIG HOLE CHARGES IS SPF@ 120° PHASE) 7,006.0 7,148.0 6410.1 6.470.0 C-0, 1LA4 ,02, V71961 4.0 PERE 7,208.0 7,2180 6,529.9 6,539.8 C4. IC_N UNIT B, L711981 4.0 PERE Cement SQaM2PS Tap.9NKB I(T0IN9 a) ) Ron [HID) MR.) 09s SbM1DaY Com 6 600 8 1,20 8.282.4 6,509.7 Cernenl PW9 5Y1&201] MILLED W/BAKER MOTORANO TURNED DOWN 2Brr916ENTERHYCALOG MILL. MILL CEMENT TO 6,974'RKB Mandrel Inserts St AU On x Top (PoIB) To(NtB)) MAb u^mv TYpa �� Parl^la TRD Run YOn ( ) (W) Run DAR Co. 2,631.1 2,466.5 CAMCO AS LIFT GLV RK 01188 1,98.0 5@2209 2 3,9200 3,551.9 CAMCO MINEGAS LIR OV RH 0.25 0.0 522201] t 3 49822 4,397.7 CANDO GAS LIFT DMY RK ODOD 0.0 521201] 4 5,6]50 5.018.9 CANDO No GAS LIFT DMY RK 8000 0.0 1/312D15 5 6.346] 5,6718 CANDO MrGAS LIFT DMY RK 0.000 0.0 1/3121115 fi fi,i124 6,0355 CAMCO GASLIR DMY RK 0000 00 5222017 Notes: General 8 Safety EnP mrn Ann^d0on 12/25Y1002NOTE: WAVERED WELL :NX OA COMMUNICATION fl/102010 NOTE: View Schema0ewl Alaska SchBmetic9.0 Bl1&2014 NOTE: LEPK AT 5787'; 3'SPINNERSTILL IN HO(E. 1I2M2015 NOTE WORKOVER 0 \ KUP PROD 1C -04A ConocoPhillipS & Well AttributesMae Angle&MD TD Alaska, Inc. Welbge APIRM'1 pAN Name 500292054701 KUPAIII RIVER UNr- WNNOry$iMY9 PROD Ai°I 102.fi0 MG(M1KBI 7,005.05 AD (MB) 10.675.0 Lommenl SSSV: NONE Nx3(ppm) Oele 40 91102016 MnalYla I......KRGe4 (IB Lea m 39.01 RiB Relaee Deb Y]". tCAMAM1SROna.61s3Ay Annolblon On (Me) End 0abMnWtlon .Mo4By End Oaf. fuuceR afi - Last Tag: Rev Ream¢ SIDETRACK jennalt 01142017 Cas" rings casing o..=4gmo wMl 1G IInl rovfMel sx cevm (Mat st cevm (rvDl... WUfen6-God. TaP T9ma ALINER 2318 1982 8.1493 10,630.0 84026 4.60 LA0 STL Liner Details xaminal f0 Top 18,14 Top(M1t(XKe Tap 19714•) Ibm Ou Cam (tri) 8,109.3 6,036.3 97.15 OH MMOrBAIUnYDUm Biilel 1.920 BILLETALWINUM BILLET CONDucTOR waMMe 3x': 8,1]1.4 6,433.4 9].5] C ING SnoNy DVII,nbnt Sleeve 1.920 3aASaA HANGER 9,361.9 6,414.0 91.89 CASING SM1oey NployfreMSbeva 1.920 HANGER GA3LIFT x$31.1 Notes: General B Safety End Oale Annotmion NOTE: SURFACE: 3LOp.910.0 GAS LIR; 3.920A GASLI1;91621 GAS LIR; 56)6.0 GASLIR:6.N6] GTS LIR�e,]1xA LOCATOR;B]6a.] SEK ASID, p.7..- .7 0SPop: pop,6.]15.1 PACKER: 6.180, NIPREl.dI OVERSMM;fi.9m.] SBpw r..6.019x PRODUCTION: 301A.035.6- PACKER: E 0e 5.3 I PPERF;6p69A6.066.0- i I Norte 6.063.5 SO6; fi.0NA 1 (PERF;1.000D].N p CY9eNFL&6,Sfi0.ONIB LINER; 6.fi1x.1-]$95A 1 AL1 LINER: 6.043.10,8118.0 --- A LINER; 6.191)3 10.530 0 Ar \ KUP PROD 1 C-O4AL1 LonocomdupS Well Atlrlbutes Max Angie&MD TD make, Im. wan00n1PYUwl Fla Kama walbon smlm na Pl NOfnKR) Ielake(RKB) 500292054]60 KUPARUK RNER UNIT PRGo 102.fi0 ],845.05 10,808.0 Commml 1 (paea Dab 40 W162O16 MnOWKn EnE Usle Last WO: KBTua(X 99.01 nagna wOeb W711981 fooeul, mlmevas2Je Ax etlprlNec lec Wal Mndtn CapN lfll(Bf Ena Osb Annaaen. L¢il Noa By Ena Gale -- ANG.1E -- NPNGER 3]A--- Led Tag'. Rev Reamn: SIDETRACK janlolt &15201] e5e1Q trR10E Caelna Deecnplion OOIin) IOIin) Tap (XKB) RI GepN (N(0.) $N pcpIN jNOf... WULen (1_. Gnae Top]Trtaa AL I LINER 23/8 1992 6,954] 11],8118.0 6,6286 4.]0 L-80 STL Liner Detais x m Ip Top (KKB) Top nVO)(XI(B) TeD incl rf INm Des Com (III (I 6.95'_1 4.04 SEAL BORE Deployment Sleeve wf6' Saseore Raceptial(PfiR) 1.920 EIRENSION Y. 9030..5 6420.6 95.]9 CASING SNORy Deployment Sleeve9.0Notes: jSUR...,3U1L.1.. General & Safety NOTE: blank Ifnar 8855 to 2549' MD 110< 3ABU1.4.1a GA9 LIFT: Sb]fiD GPH YFT:6.M6.] GM;6.]EA LGCATOR:6.7693 sEALA55Y.8.n0] PBR:B,AA PMKM:6.]W.0 NIPPLE; 6.N9 J 04ERSNOT8,901.1 SaR wEXP.8.91H3 PROGYLTOH; 30.I d,9J5.6� PACKER; 6.0,53 PPFRF: 0.604➢ga86➢� NIPPLE;B.Po]5 SQS:fiPO4A IPERF:]p6 PA 980a.01M6 - CmnNP4A6aeara" LRIFR:0b12.1-],N60 AUNIan ,1463-105Ja➢---------- I ILf LINER; 8,950_]-1e Ba0➢� 1C Final CTO Schematic A 80'MD I 9AR47e LAOekm Q 6936' MO CaanB peels ]M -]14V MD Cn6pe n0B'-nlWMD r pee wfifi enpe ®]sas' um aIa'z 112'9,M LAO EUE M m wnam 3IZ Camm MMG pas In maMrH ® 2531, 392P, 49@. 56]5'. Ear Baker Tie Back Sleeve®5612RKB Bakal Seal Nipge QW16'RKB Baker Liner Hanger ® 6522 RKB &I M' Cameo MMG ges IiM1 m anMel ® 6712- RKB Baker WAO Snl Amy ®6]]V RKB Baker PBR®6]]6'RKB Baker FHLPacker®6]9g RKB 31? Cameo M Napa ® 6949' RKB W 2.613" ID Baker Poor Boy OvsMM®69OYRM Baker 31? PM ® 6919' RKB (3. V' ID) Baker FHL peke,® 6945' RKB (3.0" ID) Ma'Cameo D MMing ripple ® 6984' RKB (E93V PDC) Milers Ic 2 BI D 3-1? WEIW MN ® 6986' RKB (8802 POC) ssWu.0>•.��L�4i Waren .. Operations Summary (with Timelog Depths) 1C-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SWA Depth Start Tune Er Time Dur (hr) Phase op C.tl AIX ty Code ➢me P -T -X opemti n (ftKB) EM Depth (fIKB) 6/30/2017 6/30/2017 4.00 MIRU MOVE MOB P Continue check list, prep for Rig Move 0.0 0.0 14:00 18:00 6/30/2017 6/30/2017 2.50 MIRU MOVE MOB P Begin rig move to 1C -pad 0.0 0.0 18:00 20:30 6/30/2017 6/30/2017 2.00 MIRU MOVE MOB P Arrive on location, prep well for rig . 0.0 0.0 20:30 22:30 6/30/2017 7/1/2017 1.50 MIRU MOVE MOB P Spot sub module over well, and lay 0.0 0.0 22:30 00:00 RM 7/1/2017 7/1/2017 2.50 MIRU MOVE RURD P PJSM, fallow post move check list, 0.0 0.0 00:00 02:30 secure cellar, landings, and walkways, spot shop and Halfway house. 7/1/2017 7/1/2017 2.50 MIRU MOVE RURD P MU PUTTS, nipple up stack, energize 0.0 0.0 02:30 05:00 Komey unit, get RKB's 7/1/2017 7/1/2017 0.00 MIRU WHDBOP NUND P RIG ACCEPT 0.0 0.0 05:00 05:00 7/1/2017 7/1/2017 1.30 MIRU WHDBOP RURD P Check all surface lines, perform valve 0.0 0.0 05:00 06:18 checklist. 7/1/2017 7/1/2017 2.40 MIRU WHDBOP RURD P Change out deployment line spool on 0.0 0.0 06:18 08:42 BOP 7/1/2017 7/1/2017 7.30 MIRU WHDBOP BOPE P Perform Initial ROPE test, test waivied 0.0 0.0 08:42 16:00 by Matt Herrera, 250 psi Law/4,000 psi High/2,500 psi annular. Test gas alarms, Test PVT system. No Failures 7/1/2017 7/1/2017 2.50 MIRU WELLPR CTOP P PJSM, Stab coil, circulate, Test inner 0.0 0.0 16:00 18:30 reel iron 7/1/2017 711/2017 4.00 MIRU WELLPR CTOP P RU and trim 2,000' fl of coiled tubing 0.0 0.0 18:30 22:30 j from reel #51196. length 14,956' 7/1/2017 7/1/2017 1.00 MIRU WELLPR CTOP P Test a -line, < 550 m -ohms, 65 ohms, 0.0 0.0 22:30 23:30 dress and ream end of coiled tubing, install CTC, pull test CTC 35 k ' 7/1/2017 7/2/2017 0.50 MIRU WELLPR CTOP P Rehead BHI Upper Quick, test a -line 0.0 0.0 23:30 00:00 7/2/2017 7/2/2017 1.50 MIRU WELLPR CTOP P FIII surface lines, MU/test PDL's and 0.0 0.0 00:00 01:30 tiger tank line, 250 psi Low/1,500 psi High 7/2/2017 7/2/2017 0.80 MIRU WELLPR MPSP T Phone service out, paging system 0.0 0.0 01:30 02:18 working, no response call valve shop supervisor, unable to find valve crew, found crew out at 2L, wait on equipment to arrive. 7/2/2017 7/2/2017 0.50 MIRU WHDBOP MPSP P Valve shop truck on location, load/MU 0.0 0.0 02:18 02:48 lubricator and extentions, PJSM 7/2/2017 7/2/2017 0.70 MIRU WHDBOP MPSP P Stab Lubricator, PT 500 psi, pull BPV, 0.0 0.0 02:48 03:30 WHIP 0 psi, RD equipment. 7/2/2017 7/2/2017 1.40 PRODt RPEQPT PULD P PJSM, M/U BHA#1, Cement pilot 0.0 62.5 03:30 04:54 hol.e milling BHA with .9° AKO motor, D331 slick gauge mill, M/U to coil and surface test tools 7/2/2017 7/2/2017 1.70 PROD1 RPEQPT TRIP P Trip in hole, EDC open pumping 1.5 62.5 6,970.0 04:54 06:36 BPM, post slack mgmt 7/2/2017 7/2/2017 0.50 PROD1 RPEQPT DLOG P 6970 Tie in, Tag TOC @ 6984 6,970.0 6,984.0 06:36 07:06 uncorrected, P/U and close EDC, RBIH mill cement 7/2/2017 7/2/2017 0.50 PROD1 RPEQPT MILL P 6984 Mill Cement, 1.8 BPM @ 2714 6,984.0 6,995.0 07:06 07:36 PSI FS, BHP=3068, ROP:20 FPH. with 1.8K DHWOB. Page 1/20 Report Printed: 711712017 Operations Summary (with Timelog Depths) 1C-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log $left Time End Time Dur (hr) Phase op Code A ctrnty Coda Time P -T -X Operetiaf eteft DepN (fs(a) End Depth (ftKB) 7/2/2017 7/2/2017 0.10 PROD1 RPEQPT MILL P Stall at 6985, PUH. Stall again @ 6,995.0 6,975.0 07:36 07:42 6995 Possible 7" contact, PUH to tie in 7/2/2017 7/2/2017 0.20 PROD1 RPEQPT DLOG P Log K1 for -4' correction 6,975.0 6,994.0 07:42 07:54 7/2/2017 71212017 0.10 PROD1 RPEQPT TRIP P PUH, RBIH to mill 6,994.0 6,990.0 0754 08:00 7/2/2017 71212017 2.50 PROD1 RPEQPT MILL P 6990, Tag and stall, PUH, Roll TF to 6,990.0 7,034.0 08:00 10:30 105R, RBIH and mill .5', then roll TF back to 285 ROHS, 1.77 BPM @ 2519 PSI FS 7/2/2017 7/2/2017 0.10 PROW RPEQPT WPRT P Observed posible gamma spikes 7,034.0 6,975.0 10:30 10:36 match K1 when milling by, PUH to tie in, PUW=36K 71212017 7/2/2017 0.20 PROD1 RPEQPT CLOG P Log K1 for -10' correction (total 6,975.0 7,002.0 10:36 10:48 correction -14') 7/2/2017 7/2/2017 0.10 PROW RPEQPT WPRT P Trip in to mill 7,002.0 7,024.0 10:48 10:54 7/2/2017 7/2/2017 3.80 PROW RPEQPT MILL P 7024', Mill, 1.81 BPM @ 2671 PSI FS, 7,024.0 7,125.0 10:54 14:42 BHP=3119, ROP=25 with 1.7K WOB 7/212017 7/2/2017 2.85 PROD1 RPEQPT MILL P 7125 - 7155 ROP up to 39FPH slowed 7,125.0 7,210.0 14:42 17:33 back down to 30-34 FPH all with 1.7K WOB, Possibly from pert interval, TD cement Pilot Hole 7/2/2017 7/2/2017 4.30 PROD1 RPEQPT REAM P PU at 10 fpm, dry drift pilot hole, 7,210.0 6,975.0 17:33 21:51 weight bobble at 6,989', ream transition area 5 times @ 60 fph, initial wieght bobble 1 k, ream clean to 05 k, 7/2/2017 7/2/2017 1.00 PROW RPEQPT DLOG P Log the K1 correction of plus 1.5', 6,975.0 6,994.0 21:51 22:51 PUH Log the HRZ @ 6,810', don't correct (minus 1.25'?), log the K1 Correction of plus 0.5', 7/2/2017 7/2/2017 0.25 PROD1 RPEQPT TRIP P PUH to log CCL, PUW 34 k 6,994.0 6,730.0 22:51 23:06 7/2/2017 7/212017 0.40 PROD1 RPEQPT DLOG P Log CCL 16 fpm, continue IH tag TD 6,730.0 7,210.0 23:06 23:30 on depth 7/2/2017 7/3/2017 0.50 PROC1 RPEQPT TRIP P POOH, purring 1.78 bpm at 1999 psi, 7,210.0 6,810.0 23:30 00:00 open choke, performing FC (03 7,099', no -flow 7/3/2017 7/3/2017 1.00 PROD1 RPEQPT TRIP P Continue POOH 6,810.0 62.5 00:00 01:00 7/3/2017 7/3/2017 0.25 PROD1 RPEQPT OWFF P Perform flow check, (no -flow), PJSM 62.5 62.5 01:00 01:15 7/3/2017 7/3/2017 0.75 PROD1 RPEQPT PULD P LD, Milling BHA# 1 62.5 0.0 01:15 02:00 7/3/2017 7/3/2017 0.50 PROW RPEQPT PULD P PJSM, load/MU Haliburton caliper on 0.0 0.0 02:00 02:30 skate. program tools, mark highside 713/2017 7/3/2017 0.50 PROD1 RPEQPT PULD P MU BHI Coiltrak tools, hang off in 0.0 70.3 02:30 03:00 stump, MU INJH, surface lest tools, (good test) 7/312017 7/3/2017 1.25 PRODi RPEQPT TRIP P RIH wl HAL caliper, filling trip sheet 70.3 6,975.0 03:00 04:15 every 1,000' 7/3/2017 7/3/2017 0.28 PROD1 RPEQPT DLOG P Log the K1 marker correction of minus 6,975.0 7,300.0 04:15 04:31 13.5' 7/3/2017 7/3/2017 0.25 PROD1 RPEQPT TRIP P Continue RIH 7,300.0 7,205.0 04:31 04:46 Page 2120 Report Printed: 711712017 Operations Summary (with Timelog Depths) 1C-04 t. Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time log StaDepth Sten Time End Time Dur (hr) Phase Op Code Activity Code Time PJA Opeation (WS) End Depth rtKB) 7/3/2017 7/3/2017 0.25 PROD1 RPEQPT DLOG P Heisitale for caliper arms. 7,205.0 7,205.0 04:46 05:01 7/3/2017 7/3/2017 0.20 PRODt RPEQPT DLOG P Log up at 50 fpm 7,205.0 6,598.0 05:01 05:13 7/3/2017 7/3/2017 1.30 PROD1 RPEQPT TRIP P 6598 Stop and let caliper arms close, 6,598.0 58.0 05:13 06:31 POOH 7/3/2017 7/3/2017 2.00 PROD1 RPEQPT PULD P At surface, Flow Check, Lay down 58.0 0.0 06:31 08:31 BHA #2 from dead well, Stab on and jet BOP stack 7/3/2017 7/3/2017 0.70 PROD1 WHPST PULD P M/U BHA #3 3 1/2" monobore XL 0.0 72.4 08:31 09:13 whipstock with OH anchor, WU to coil and surface test 7/3/2017 7/3/2017 1.50 PROD1 WHPST TRIP P trip in hole with whipstock, EDC open 72.4 6,985.0 09:13 10:43 7/3/2017 7/3/2017 0.20 PRODi WHPST DLOG P Log Ki for -13.5' 6,985.0 7,017.0 10:43 10:55 7/3/2017 7/3/2017 0.20 PROD1 WHPST TRIP P Continue in to setting depth 7060.75, 7,017.0 7,060.0 10:55 11:07 Close EDC. Gel P/U Weight @ 38K, RBIH to set depth, Oriented to 90° LOHS, Pumps on, See tool shift @ 3993. Set down 3K - Looks good 7/3/2017 7/3/2017 1.30 PROD1 WHPST TRIP P POOH, Stop at 6966 open EDC, 7,060.0 60.0 11:07 12:25 Continue OOH 7/3/2017 7/3/2017 0.60 PRODi WHPST PULD P Tag up at surface, Flow check well, 60.0 0.0 12:25 13:01 PJSM, Lay down BHA #3 7/3/2017 7/3/2017 1.00 PRODt WHPST PULD P M/U BHA #4 Window milling BHA 0.0 72.0 13:01 14:01 with .6° Motor, 2.80 window mill, 2.79 String reamer, M/U to coil and surface test coil 7/3/2017 7/3/2017 1.40 PROD1 WHPST TRIP P Trip in hole, EDC open. 72.0 6,985.0 14:01 15:25 7/3/2017 7/3/2017 0.20 PROD1 WHPST DLOG P Log Kt for -13.5', Close EDC, 6,985.0 7,020.0 15:25 15:37 7/3/2017 7/3/2017 0.20 PROD1 WHPST TRIP P Continue trip in, Dry tag top of 7,020.0 7,150.0 15:37 15:49 whipstock @ 7150.4, Roll hole to window milling Fluid 7/3/2017 7/4/2017 8.17 PROD1 WHPST MILL P PUH, Bring pumps online 1.8 BPM @ 7,150.0 7,162.0 15:49 00:00 3237 PSI FS. Make contact @ 7150.3, Start milling window. No stalls getting on tray 7/4/2017 7/4/2017 1.00 PROW WHPST MILL P Mill/Drill rathole, 1.8 bpm at 3,874' psi, 7162.0 7,171.0 00:00 01:00 BHP 3,806, WHP 402, IA 0, OA 696 7/4/2017 7/4/2017 2.00 PROD1 WHPST REAM P Backream window area, 1.8 bpm at 7,171.0 7,151.0 01:00 03:00 3,664 psi, BHP 3,792, WHIP 396, IA 0, OA 698, As milled, 180° TF, 30° R and L, dry drift clean. 7/4/2017 7/4/2017 1.00 PRODi WHPST TRIP P POOH 7,151.0 74.3 03:00 04:00 7/4/2017 7/4/2017 1.75 PROD1 WHPST PULD P PJSM, PUD milling BHA# 4, Crew 74.3 0.0 04:00 05:45 Change 7/4/2017 7/4/2017 1.50 PROD1 DRILL PULD P PJSM, PD Build BHA# 5 0.0 72.3 05:45 07:15 7/4/2017 714/2017 1.75 PROD1 DRILL TRIP P RIH, w/build section BHA, 2.5° ako 72.3 6,985.0 07:15 09:00 motor and RB HCC bi-center bit 7/4/2017 7/4/2017 0.30 PROW DRILL OLOG P Log the K1 correction of minus 15'. 6,985.0 7,006.0 09:00 09:18 PUW 35 k 7/4/2017 7/4/2017 0.25 PROD1 DRILL TRIP P Continue RIH thru window 7,006.0 7,171.0 09:18 09:33 Page 3120 Report Printed: 711712017 - Operations Summary (with Timelog Depths) 1C-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time 5nd Time Our (hr) Phase op Cade Aa A C.de b Lme P -T -x o pereUon S�atl B) (fixe) EM 00ptli (WB) 7/4/2017 7/4/2017 2.50 PROD1 DRILL DRLG P Working on TF, (a lot of interference) 7,171.0 7,211.0 09:33 12:03 OBD, 1.8 bpm at 3,700' psi, BHP 3,825. 7/4/2017 7/4/2017 0.25 PROD1 DRILL DRLG T PUH, perform check survey from top 7,211.0 7,198.6 12:03 12:18 of WS down to 7,193', no change in INC 7/4/2017 7/412017 0.25 PROD1 DRILL DRLG T Attempt to reach bottom, 1.6 bpm at 7,198.6 7,198.6 12:18 12:33 3,400 psi, High vibrations level 34. stalling motor at 7,198.6 7/4/2017 7/4/2017 0.25 PRODi DRILL DLOG T Log the for the RA, couldn't see RA, 7,198.6 6,964.0 12:33 12:48 WS might of went down hole, PUH above WS 7/4/2017 7/4/2017 0.50 PROD! DRILL WAIT T Wait on orders 6,964.0 6,964.0 12:48 13:18 7/4/2017 7/4/2017 1.25 PROD1 RPEQPT TRIP T POOH, for caliper run 6,964.0 72.3 13:18 14:33 7/4/2017 7/4/2017 0.50 PROD? RPEQPT OWFF T Check well for Bow, PJSM 72.3 72.3 14:33 15:03 7/4/2017 7/4/2017 0.75 PROD1 RPEQPT PULD T LD Build BHA# 5 72.3 0.0 15:03 15:48 7/4/2017 7/4/2017 0.50 PROD1 RPEQPT SVRG T Service choke A and B, and Out MM 0.0 0.0 15:48 16:18 7/4/2017 7/4/2017 0.80 PRODt RPEQPT WAIT T WOH 0.0 0.0 16:18 17:06 7/4/2017 7/4/2017 1.00 PROD1 RPEQPT PULD T PU BHA #6, HES,'Sondex MIT, 0.0 70.0 17:06 18:06 indexed to BHI coiltrack. 7/4/2017 714/2017 1.10 PROD1 RPEQPT TRIP T RIH, adjust RIH speed to 115 Nmin 70.0 6,990.0 18:06 19:12 and did not slow for jewelry due to memory tool program setting 7/4/2017 7/4/2017 0.20 PRODt RPEQPT DLOG T Attempt toTie into the K1, ran out of 6,990.0 7,008.0 19:12 19:24 time, fingers opening 19:17, stop RIH/ logging. 7/4/2017 7/4/2017 1.40 PROD1 RPEQPT TRIP T POOH, PU Wt 32 k lbs. 7,008.0 70.0 19:24 20:48 7/4/2017 714/2017 0.60 PROD1 RPEQPT TRIP T Flow check- good, PJSM, LD BHA 70.0 0.0 20:48 21:24 #6, memory caliper, over a dead well. 7/412017 7/4/2017 0.70 PROD1 RPEQPT TRIP T Reconfigure MIT for 145 min, 135 min 0.0 70.0 21:24 22:06 from HES to Nabors hand off. Function test in shed, PU BHA # 7 and run over a dead well, stab on, bump up, set counters. 7/4/2017 7/4/2017 1.10 PROD1 RPEQPT TRIP T RIH, 70.0 6,985.0 22:06 23:12 7/4/2017 7/4/2017 0.20 PROD1 RPEQPT DLOG T Tie into the K1 for a -15.5' correction. 6,985.0 7,017.0 23:12 23:24 7/4/2017 7/5/2017 0.60 PRODt RPEQPT TRIP T Continue to RIH to logging dept, 7,017.0 7,193.0 23:24 00:00 bottom of tool, 7193, fingers @ 7188'. Wait for 26 min for fingers to open up. 7/5/2017 715/2017 0.20 PROD1 RPEQPT TRIP T Continue to RIH to logging dept, 7,017.0 7,193.0 00:00 00:12 bottom of tool, 7193, fingers @ 7188'. Wait for 26 min for fingers to open up. 7/512017 715/2017 0.30 PROD1 RPEQPT DLOG T POOH @ 50 ft/min, logging w MIT, 7,193.0 6,600.0 00:12 00:30 1 park for 2 min. 7/5/2017 7/5/2017 1.00 PROW RPEQPT TRIP T Continue to POOH. 6,600.0 70.0 00:30 01:30 1 Page 4120 Report Printed: 711712017 ,- Operations Summary (with Timelog Depths) 1 C-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sa(ft<13) Star) Time End Time Dur (hr) Phase op C,otle Activity Code T,. P -T -X opwason EntlDeP N W ( ) 7/5/2017 7/5/2017 0.50 PROD1 RPEQPT PULD T @ surface, flow check, PJSM, LD 70.0 0.0 01:30 02:00 BHA V. Clean floor 7/5/2017 7/5/2017 1.00 PRODi RPEQPT PULD T PJSM, PU BHA #8, BOT 3.5" 0.0 73.0 02:00 03:00 Monobore Whipstock XL W OH anchors, stab on, open EDC. 7/5/2017 7/5/2017 0.20 PROD1 RPEQPT CTOP T Reset BHI database 73.0 73.0 03:00 03:12 7/5/2017 7/5/2017 1.70 PROD? RPEQPT TRIP T RIH W whipstock. 73.0 6,952.0 03:12 04:54 7/5/2017 7/5/2017 PROD1 RPEQPT WAIT T Wait for memory data processing 6,952.0 6,990.0 04:54 04:54 7/5/2017 7/5/2017 0.20 PROD1 RPEQPT TRIP T Tie into the Ki for minus 13.5' 6,990.0 7,006.0 04:54 05:06 7/5/2017 7/5/2017 0.30 PROD1 RPEQPT WPST T Contin to RIH w whipstock, 7,006.0 7,136.8 05:06 05:24 7/5/2017 7/5/2017 0.25 PROD1 RPEQPT WPST T PUW 35 k, Close EDC, bring pump on 7,136.8 7,126.0 05:24 05:39 -line, shear at 5,200 psi, 5 k DHWOB, set down additional 2 k DHWOB 7/5/2017 7/5/2017 1.00 PROD1 RPEQPT TRIP T PUW 35k, POOH, w/tripsheet and 7,126.0 60.3 05:39 06:39 manual straps 7/5/2017 7/5/2017 0.50 PRODi RPEQPT OWFF T At surface, check well for flow, PJSM 60.3 60.3 06:39 07:09 laying done BHA 7/5/2017 7/5/2017 0.50 PROD1 RPEOPT PULD T LD BHA# 8 60.3 0.0 07:09 07:39 7/5/2017 7/5/2017 0.50 PROD1 WHPST PULD T PU/MU window milling BHA# 9, move 0.0 74.3 07:39 08:09 INJH over MU to Coiltrak tools, surface lest was good, MU lubdcator, tag up, reset counters 7/5/2017 7/5/2017 1.20 PROD1 WHPST TRIP T RIH, with Milling BHA# 9 second 74.3 6,990.0 08:09 09:21 attempt to make casing exit 7/5/2017 7/5/2017 0.25 PRODt WHPST DLOG T Log the K1 marker correction of minus 6,990.0 7,008.0 09:21 09:36 14.5', PUW 33 k 7/5/2017 7/5/2017 0.25 PROD1 WHPST TRIP T Continue IH 7,008.0 7,126.0 09:36 09:51 7/5/2017 7/5/2017 3.75 PROD? WHPST MILL T Dry tag TOWS, PUH, bring pump up 7,126.0 7,128.0 09:51 13:36 to 1.8 bpm at 3,375 psi, BHP 3468, WHP 0, IA 0, OA 476 7/5/2017 7/5/2017 5.20 PROD1 WHPST MILL T OB Milling window 1.8 bpm at 3505 7,128.0 7,146.5 13:36 18:48 psi, BHP 3,452, WHP 0, IA 0, OA 611. Bottoms up sample confirmed sand and dark dirt, no evidence of cement. Last 4 sample collected had increasing percentages of dirt vs metal. 7/5/2017 7/5/2017 1.60 PROD1 WHPST REAM T Start reaming passes as milled (245* 7,128.0 7,146.5 18:48 20:24 ROHS) plus 1x @ 180 & +/- 30 from as milled. Low WOB as well as minimal mnotor work, time out and send 5x5 sweeps. Dry drift - 25 ft/min Clean. 7/5/2017 7/5/2017 1.20 PROD1 WHPST TRIP T POOH chasing sweeps to surface 7,146.0 55.0 20:24 21:36 7/5/2017 7/6/2017 2.40 PROD1 WHPST PULD T Bump up, space out, PJSM, PUD&LD 55.0 0.0 21:36 00:00 BHA#9, 7/6/2017 7/6/2017 1.00 PRODi WHPST PULD T Continue to PUD and LD BHA #9. 0.0 0.0 00:00 01:00 Speed mill 2.80 go, 2.79 no go, string reamer 2.80 no go. Good whorl pattern on bottom of speed mill. Page 5120 Report Printed: 7/17/2017 Operations Summary (with Timelog Depths) 1C-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Depth Start Time End Time Our (hr) Phase Op code Actrvrty Code Time P -T -X Operation (MB) End Depth t4KB) 7/6/2017 7/6/2017 1.20 FROM DRILL PULD T PU & PD BHA #10, build drilling BHA, 0.0 70.0 01:00 02:12 2.5 °AKO, Break open return micromotion, snake, flush, and blow down. inspoect pack offs, stab on, bump up, reset counters 7/6/2017 7/6/2017 1.60 PROD1 DRILL TRIP T RIH 70.0 6,980.0 02:12 03:48 7/6/2017 7/6/2017 0.20 PROD1 DRILL DLOG T Tie into the K1 for -15' correction 6,980.0 7,000.0 03:48 04:00 7/6/2017 7/6/2017 0.20 PROD1 DRILL TRIP T Wt Ck29 k lbs, Close EDC, Continue 7,000.0 7,146.5 04:00 04:12 to RIH. 7/6/2017 7/6/2017 1.00 PROD1 DRILL DRLG P Set rate 1.73 bpm in, 1.73 bpm out, 7,147.0 7,200.0 04:12 05:12 Free spin diff 524 psi CT 4073 OBD, CT Wt 15.5 k lbs, WOB 1.35 k lbs, ROP 40 ft/hr. Pick up and restart, Pu Wt=31 k lbs, set rate 1.8 bpm, CT 4032 psi, free spin 511 psi. OBD, CT 3940 psi, CT Wt 13 k lbs, WOB 1.2 k lbs, ROP 35 fl/ hr 7/6/2017 7/6/2017 0.20 PROD1 DRILL TRIP P PU 30 k lbs PUH to K1 7,200.0 6,975.0 05:12 05:24 7/6/2017 7/6/2017 0.30 PROD1 DRILL DLOG P Log K1 for a correction plus 1.5', Log 6,975.0 7,164.0 05:24 05:42 the R4 @ 7132.5' Ofcal Window Depths TOW 7125.5' BOW 7130.5' RA 7132.5' 7/6/2017 7/6/2017 0.25 PROD1 DRILL TRIP P RIH 7,164.0 7,200.0 05:42 05:57 7/6/2017 7/6/2017 2.50 PROM DRILL DRLG P BOBD 1.8 bpm at 3850 psi, BHP 7,200.0 7,322.0 05:57 08:27 3970, WHP 436, IA 0, OA 675 7/6/2017 7/6/2017 0.20 PROD1 DRILL WPRT P Geo Wiper 7,322.0 7,322.0 08:27 08:39 7/6/2017 7/6/2017 0.20 PROD1 DRILL DRLG P BOBD 1.8 bpm at 4,106 psi, BHP 7,322.0 7,330.0 08:39 08:51 4,372, WHP 328, IA 0, OA 673 7/6/2017 7/6/2017 1.25 PROM DRILL TRIP P TO Build section, pump 10x10 sweep, 7,330.0 72.2 08:51 10:06 POOH, open ECD @ 6,960' 7/6/2017 7/6/2017 0.25 PROM DRILL SFTY P At surface, space out, PJSM 72.2 72.2 10:06 10:21 7/6/2017 7/6/2017 1.00 PROD1 DRILL PULD P PUD, Build Section BHA# 10 72.2 0.0 10:21 11:21 7/6/2017 7/6/2017 1.25 PRODi DRILL PULD P PD lateral BHA# 11, surface test tools, 0.0 78.2 11:21 12:36 good test 7/6/2017 7/6/2017 1.25 PROD1 DRILL TRIP P Tag up reset counters, RIH 78.2 6,985.0 12:36 13:51 7/6/2017 7/6/2017 0.25 PROD1 DRILL DLOG P Log the K1 marker correction of minus 6,985.0 7,008.0 13:51 14:06 16.5', PUW 32 k 7/6/2017 7/6/2017 0.25 PROD1 DRILL TRIP P Continue IH 7,008.0 7,330.0 14:06 14:21 7/6/2017 7/6/2017 1.90 FROM DRILL DRLG P BOBD 1.8 bpm at 3650 psi, BHP 7,330.0 7,458.0 14:21 16:15 3896, WHP 294, IA 0, OA 639 7/6/2017 7/6/2017 0.25 PROD1 DRILL WPRT T PUH, BHI computer locked up, reboot 7,458.0 7,458.0 16:15 16:30 system computers. 7/6/2017 7/6/2017 1.00 PROD1 DRILL DRLG P BOBO, 1.76 bpm, CT Wt 9.6 k lbs, 7,458.0 7,523.0 16:30 17:30 WOB 2.57 k lbs, ROP 96 ft/hr. Taking influx, pinched in choke. Page 6120 ReportPrinted: 7/1 712 01 7 '•- Operations Summary (with Timelog Depths) 1C-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log slaty Depth Start Torre End Time our (hr) Phase Op Code A*vity Code Time P -T -X Operabon (flKe) End Depth(RKB) 7/6/2017 7/6/2017 4.00 PROD1 DRILL DRLG P Drilling ahead, Well worc still showing 7,523.0 7,704.0 17:30 21:30 pit gains, pit sensors showing stable to slight loss, shaker losses?, continue to monitor and adjust choke. Hard stall @ 7557'35k lbs PU, worked through and ROP increased to 140 ft/hr, sailed 5x5 sweep, Drill ahead to hard stall 7571' PU Wt 35 k lbs. multiple hard spots, near stalls to 7580'. Pull short BHA wiper (100) as sweeps exit, PU 37 k lbs. 6 stalls total, clean drilling with lower ROPs's-40-30ff/hr. Pump 5x5, Short (100') BHA wiper as sweeps transits the open hole, PU Wt 32k lbs, BOBD, ROP over interval on bottom 45 ft/hr 7/6/2017 7/7/2017 2.50 PROD? DRILL DRLG P OBD, free spin diff 1155 psi, CT Wt, 7,704.0 7,860.0 21:30 00:00 12.45k lbs, WOB 2.17 k lbs, ROP 70 k lbs, annular 4410 psi, Continue to monitor return rate, suspect MM out may be reading 0.2 bpm high, Stall@ 22:10 - 7729' appears to have surged MM out and cleared up flow issue. Another stall 7779', PU 36 k lbs. looks like it took a drink, 7822', lasses start -0.25 bpm. healed in minutes by 7833'. ROP over interval 62 Whir 7/7/2017 7/7/2017 1.70 PROD1 DRILL DRLG P OBD, Drilling break at 7898', ROP 7,860.0 8,006.0 00:00 01:42 -150 -120 ft/hr. CT Wt 9.73 k lbs, WOB 1.8k lbs, Annular 4498, returns 1 for 1. Sent 5x5 sweeps, losses started at 7944' climbed to 0.75 bpm 7977' Multiple stalls @ 7979', PU Wt 33 k lbs. sweeps out the bit. Losses healed slightly to .5-.6 bpm. ROP over interval 85 fl/min 7/7/2017 7/7/2017 0.60 PROD1 DRILL WPRT P Wiper -850'. PU slowly to allow 8,006.0 7,170.0 01:42 02:18 sweeps to exit the well. PU Wt 27 k lbs, slow for missed log data, 7473- 7422'. continue up hole, slow to 5 ft/min to calibrate annular friction loss. attempt to target 11.4 ppm at window, taking 0.25 bpm influx, pinch in choke for 1-1. Pump rate 1.81 bpm in, 1.77 bpm out, 8.74 ppg in 8.79 ppg out, annular 4050 psi, choke pressure 550 psi. 7/7/2017 7/7/2017 0.40 PROD? DRILL WPRT P RBIH, following new tripping schedule 7,170.0 8,006.0 02:18 0242 for 12.3 ppg 7/7/2017 7/7/2017 2.80 PRODt DRILL DRLG P Rate 1.80 bpm in, 1.80 bpm out, Free 8,006.0 8,262.0 02:42 05:30 spin diff 1150 psi, CT 5200 psi OBD, CT Wt 9.36 k lbs, WOB 2.30 It lbs, ROP 104 R/hr. stall 8066, PU 32 k lbs, stall 8197, 32k lbs. 7!7/2017 7/7/2017 0.65 PROD1 DRILL WPRT P 100'wiper up hole 8,262.0 8,262.0 05:30 06:09 7!7/2017 7/7/2017 3.36 PROD1 DRILL DRLG P BOBD 1.8 bpm at 5,258 psi, BHP 8,262.0 8,400.0 06:09 09:30 4303, WHIP 477, IA 0, OA 814 Page 7120 Report Printed: 7/1 712 01 7 Operations Summary (with Timelog Depths) 1 C-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operabon (MEn End Depth (ttKB) 7/7/2017 7/7/2017 0.50 PROD1 DRILL WPRT P Wiper up hole for tie in and pressure 8,400.0 7,150.0 09:30 10:00 check, PUW 30 k 7,180' Choke Calibration Pump rate=1.8 bpm Return rate=1.79 bpm MW IN=8.78 ppg MW Out=8.84 ppg Annular Press.=4146 psi Choke Pressure=585 psi WHP=545 psi 7/7/2017 7/7/2017 0.15 PROD1 DRILL DLOG P Log the RA correction of plus 2.0' 7,150.0 7,169.0 10:00 10:09 7/7/2017 7/7/2017 0.15 PROM DRILL WPRT P PUH above window, open ECD 7,169.0 6,978.0 10:09 10:18 7/7/2017 7/7/2017 0.45 PROM DRILL CIRC P Pumping 2.02 bpm at 5000 psi, circ 6,978.0 6,978.0 10:18 10:45 bottoms up, 7/7/2017 7/7/2017 0.60 PROD1 DRILL WPRT P Shut down pump, Gose choke, after 6,978.0 6,978.0 10:45 11:21 pressure check still trending down on pressure, go back to holding 11.4 ppg at the window. 3792 psi=11.43 3868 psi=11.67 3849 psi= 11.61 3820 psi=11.55 7/7/2017 7/7/2017 3.25 PROD1 DRILL TRIP P Close EDC, RIH to bottom 6,978.0 8,400.0 11:21 14:36 7/7/2017 7/7/2017 0.25 PROD1 DRILL DRLG P BOBD 1.8 bpm at 5,000 psi, BHP 8,400.0 8,558.0 14:36 14:51 4032, WHP 257, IA 0, OA 768 7/7/2017 7/7/2017 0.25 PROD1 DRILL WPRT P Wiper up hole, PUW 34 k 6,558.0 8,058.0 14:51 15:06 7/7/2017 7/7/2017 0.25 PROD1 DRILL WPRT P Wiper back in hole RIW 14 8,058.0 8,558.0 15:06 15:21 7/7/2017 7/7/2017 1.90 PROD1 DRILL DRLG P BOBD, 1.8 bpm at 5050 psi, BHP 8,558.0 8,763.0 15:21 17:15 3992, WHP 191, IA 0, OA 832 7/7/2017 7/7/2017 5.60 PROD1 DRILL DRLG P Quick pick up to get restarted, PU Wt 8,763.0 8,982.0 17:15 22:51 39 k lbs. RBIH, OBD, pump 5x5 sweep. CT Wt 9 k lbs, WOB 1.36 k lbs, ROP 139 ft/hr. Encountered 0.35 bpm losses @ 8792', ROP dropped to -20 fUhr. Losses fluctuating between 0.3-0.6 bpm. Losses healed to -0.1 bpm. Pumped another 5x5 and regained string weight, neutral to +-6 k lbs. WOB 1.52 K ROP 90 fV hr. PU to restart 3x, PU Wt's 37 k lbs, Pumped 5x5, Allow sweep to exit the bit. CT Wt -2.0 klbs, WOB 2.3 k lbs, ROP 30 ft/hr, CT 4911 psi, @ 1.75 bpm in, 1.68 bpm out. CT Wt 8.8 k lbs, as high vis exits, ROP over interval drilled 39 ft/hr 7/7/2017 7/7/2017 0.30 PROD1 - DRILL WPRT P Wiper trip 850', PU Wt 34k lbs. Saw 8,982.0 8,150.0 22:51 23:09 1 I slight pulls at 8700 and 8650'. 7/7/2017 7/7/2017 0.30 PROD? DRILL WPRT P RBIH, CT RIH Wt 12.2 k lbs, clean trip 8,150.0 8,982.0 23:09 23:27 1 Page 8/20 Report Printed: 7/17/2017 Operations Summary (with Timelog Depths) 1C-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stag Time End Time Our (hr)Phase Op Code Actmity Code Time P -T -X Operation SUR Blprh End Dept (flB) 717/2017 7/8/2017 0.54 PROD1 DRILL DRLG P 1.78 bpm in, 1.70 bpm out, CT 4872 8,982.0 9,031.0 23:27 00:00 psi, free spin diff 956 psi. OBD, CT Wt 7.5 k lbs, WOB 1.64 k lbs, ROP 85 ft/min. CT weight dropped to - 3 k lbs, w 2.3 k lbs WOB after drilling 70 feet. Organized mud swap. ROP over interval drilled 89 R/hr 7/8/2017 7/8/2017 2.50 PROD1 DRILL DRLG P Drilling ahead, 9,031.0 9,147.0 00:00 02:30 CT Wt 0 k lbs, WOB 1.67 k lbs, ROP 35 R/hr, conver to 2 pit system, start exporting mud outside. Multiple PU's to restart, PU Wt 32-38 k lbs. new' mud down the coil @ 1:39. New mud @ the bit 9119'. ROP over interval on bottom 46 R/hr 7/8/2017 7/8/2017 2.00 PROD1 DRILL DRLG P New mud all the way around, off 9,147.0 9,230.0 02:30 04:30 bottom CT 4580 psi, free spin diff 1070 psi CT Wt 0.52, WOB 1.99 k lbs, ROP 150-20 R/hr Ct 4866 psi, Annular 3877 psi, WH 127 psi. ROP over interval 41 R/hr 7/8/2017 7/8/2017 3.00 PRODt DRILL DRLG P OBD, CT 5044 psi, CT Wt 6 k lbs, 9,230.0 9,350.0 04:30 07:30 WOB 1.7 k lbs, ROP 81 it/ hr 7/8/2017 7/8/2017 0.75 PROD1 DRILL WPRT P Wiper up hole, PUW 34 k, perform jog 9,350.0 7,150.0 07:30 08:15 back in hole 100' from EOB 7/8/2017 7/8/2017 0.25 PROD1 DRILL DLOG P Log the RA marker correction of plus 7,150.0 7,168.0 08:15 08:30 3.5', 7/8/2017 7/8/2017 0.85 PRODt DRILL WPRT P Wiper back in hole, RIW 15 k 7,168.0 9,350.0 08:30 09:21 7/8/2017 7/8/2017 1.00 PROD1 DRILL DRLG P BOBD, 1.8 bpm at 4,931 psi, Diff --880 9,350.0 9,395.0 09:21 10:21 psi, BHP 4,103, WHIP 323, IA 0, OA 814, CTSW=4k, DHWOB=2.5 k, ROP 48 mph, 7/8/2017 7/8/2017 0.25 PRODt DRILL WPRT P ••* 100% losses "", PUW 50 k, PUH 9,395.0 9,295.0 10:21 10:36 100' 7/8/2017 7/8/2017 0.25 PROD1 DRILL WPRT P RBIH 9,295.0 9,395.0 10:36 10:51 7/812017 7/8/2017 2.50 PROD1 DRILL DRLG P BOBD, 1.8 bpm at 3840 psi, BHP 9,395.0 9,625.0 10:51 13:21 2916, WHIP 0, IA 0, OA 820, CTSW=15 k, DHWOB=1.2 k, ROP=100 fph 7/8/2017 7/8/2017 1.10 PROD1 DRILL DRLG P OBD, 1.77 bpm at 4,248 psi, BHP 9,625.0 9,701.0 13:21 14:27 3,301, WHIP 101, IA 0, OA 757, CTSW=O, DHWOB=1.8 k, ROP=83 fph 7/8/2017 7/8/2017 0.75 PROD1 DRILL WPRT P Wiper up hole, PUW 50 k 9,701.0 8,400.0 14:27 15:12 7/8/2017 7/812017 0.50 PROD1 DRILL WPRT P Wiper back in hole RIW 15 k 8,400.0 9,701.0 15:12 15:42 7/8/2017 7/8/2017 1.00 PROD1 DRILL DRLG P BOBO, 1.8 bpm at 4,594 psi, BHP 9,701.0 9,782.0 15:42 16:42 3,597, WHIP 342, IA 0, OA 767, CTSW=6.2 k, DHWOB=1.8 k, ROP=77 fph 7/8/2017 7/8/2017 2.30 PROD1 DRILL DRLG P OBD, 1.8 bpm at 4318 psi, BHP 9,782.0 9,870.0 16:42 19:00 3,569, WHIP 435, IA 0, OA 748, CTSW=minus 2 k, DHWOB=1.7 k, ROP=69 fph, pick ups to get restarted, 55k increasing to 59k lbs. Page 9120 Report Printed: 7117/2017 . , Operations Summary (with Timelog Depths) IC -04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sten Time EM Time Do -W) Phase Op Cone Activity Code Time P -T -X O peration copift 9tafti(S) ft Ka) End DepN lttKe) 7/8/2017 7/8/2017 2.20 PROD1 DRILL WPRT P PU Wt 53 k lbs, pull wiper to window, 9,870.0 6,960.0 19:00 21:12 2750' trip. Saw some negative WOB spikes from 9539 to 7992 and agian in the build at 7155' as well as slight coil weight overpulls from 9492-9136 around the loss zone. 7/8/2017 7/8/2017 0.30 PROD1 DRILL WPRT P Line up down the back side and pump 6,960.0 6,900.0 21:12 21:30 40 bbls stock power pro flush and 48 Wits lubed(1.5%) beaded (2 ppb) stock power pro 7/8/2017 7/8/2017 0.40 PROD1 DRILL DLOG P RBIH, attempt to log the Kt, some 6,960.0 7,078.0 21:30 21:54 confusion with possibly a large correction, RIH to log RA tag for a + 9 ' correction. 7/8/2017 7/8/2017 1.00 PRODi DRILL TRIP P RBIH, carried 16-13 k CT weight until 7,078.0 9,870.0 21:54 22:54 - 9100' where there's a sharp tum uphill. RIH Wt 8 kl bs, 7/8/2017 7/9/2017 1.10 PROM DRILL DRLG P Off bottom, 1.80 bpm in, closed choke, 9,870.0 9,906.0 22:54 00:00 free spin diff 1000 psi, CT 4440 psi, annular 3910 psi. OBD, CT Wt k lbs, WOB 2 k lbs, ROP 90 ft/hr. Drill 10 feet, PU Wt 52 k lbs. Seeing some 4's on vibration @ 9888'. PU's 52 climbing to 62 k lbs, five to ten minutes OBD, for each PU. ROP over interval 33 Whir 7/9/2017 7/9/2017 2.00 PROM DRILL DRLG P At 9907' PU 75k x2, cycled pipe to 9,906.0 9,951.0 00:00 02:00 80k pulled free. Drill ahead pumping 5 bbl tubed sweeps for every - 60 bbls of power pro lite pumped. Able to stay on bottom while lubes are coming out and for - 10-20 min after. Lube up active system to 1%. ROP over interval 22 fl/hr. 7/9/2017 7/9/2017 0.80 PROD1 DRILL DRLG P Drilled into something hard @ 9951'. 9,951.0 9,960.0 02:00 02:48 WOB 3.5 k CT Wt 0, 1300 psi diff. ROP over interval 11 ff/hr. 7/9/2017 7/9/2017 1.20 PROD1 DRILL DRLG P Drilling break @ 9960, 1.80 bpm, CT 9,960.0 10,024.0 02:48 04:00 Wt 5.2 k lbs, WOB 2.3 k lbs, ROP 110 f 1hr, CT 4846 psi, annular 3797 psi. Resistivity climbed significantly after 9940'. Sending 5 bbls beaded pills as necisary. Weight transfer vastly improved. ROP over interval 53 tt/hr 7/9/2017 7/9/2017 1.80 PROD1 DRILL DRLG P OBD, CT Wt 0 klbs, WOB 2.7 k lbs, 10,024.0 10,090.0 04:00 05:48 ROP 60 Whir, CT 4885 psi, WH 750 psi. ROP over interval 38t/hr 7/9/2017 7/9/2017 0.25 PRODi DRILL WPRT P Geo wiper up hole, PUW 41 k 10,090.0 8,975.0 05:48 06:03 7/9/2017 7/9/2017 0.25 PRODi DRILL WPRT P Geo wiper back in hole, RM 13 k 8,975.0 10,090.0 06:03 06:18 7/9/2017 7/9/2017 4.70 PROM DRILL DRLG P BOBD, 1.8 bpm at 4,500 psi, 10,090.0 10,400.0 06:18 11:00 DIFF=820 psi, BHP 3748, WHP 720, A0, OA 817, CTSW=minus 2 k, DHW0B=1.4 k, ROP 92 fph DHD, here bleed down OA from 817 psi - 298 psi. 7/9/2017 7/9/2017 0.50 PROD1 DRILL WPRT P Wiper up hole, PUW 38 k, Pulled 10,400.0 9,400.0 1100 1130 heavy at faultAoss zone 9,400 Page 10120 Report Printed: 7117/2017 Operations Summary (with Timelog Depths) IC -04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sud Time End Tune OW (hr) Phase Op Co AcWty Code Time P -T -X Operation start oepm (9K13) End OepM (f1K13) 7/9/2017 7/9/2017 0.50 PROM DRILL WPRT P Wiper back in hole, RIW 8 k 9,400.0 10,400.0 11:30 12:00 7/9/2017 7/9/2017 2.00 PROD1 DRILL DRLG P BOBO, 1.8 bpm at 4,100 psi, BHP 10,400.0 10,595.0 12:00 14:00 3615, WHP 744, IA 0, OA 330, CTSW=minus 4 k, DHWOB= 1 k, ROP 30 fph Pumping 10 bbl beaded pills Sequently 7/9/2017 7/9/2017 0.75 PRODt DRILL DRLG P OBD, 1.5 bpm at 3,486 psi, BHP 10,595.0 10,602.0 14:00 14:45 3637, WHP 690, IA 0, OA 331, CTSW=3.3 k, DHWOB=2.1 k, ROP=38 fph 7/9/2017 7/9/2017 2.60 PROM DRILL DRLG P OBD, 1.8 bpm at 4,079 psi, BHP 10,602.0 10,675.0 14:45 17:21 3,815, WHP 720, IA 0, OA 331, CTSW=3.3 k, DHWOB=1.9 k, ROP=16 fph Drilled into hot gamma, 169 API. Called TO 7/9/2017 7/9/2017 1.30 PROD1 DRILL WPRT P PUH wiping to window, PU 42 k lbs. 10,675.0 7,142.0 17:21 18:39 Pull heavy at 9455', CT weight up to 55k lbs, clean running is 35k lbs, RBIH to 9470' PU Wt 58 k pull clean until 9415, then 44k lbs, continue to POOH. 7333', motor work and annular Fluctuations, 7/9/2017 7/9/2017 0.20 PROD1 DRILL DLOG P Tie into the RA tag for a + 15.5' 7,142.0 7,155.0 18:39 18:51 correction. 7/9/2017 7/9/2017 0.40 PROM DRILL DISP P Pump 15 blots clean mud down the 7,155.0 6,947.0 18:51 19:15 back side, 7/9/2017 7/9/2017 1.70 PROM DRILL TRIP P RBIH 6,947.0 10,630.0 19:15 20:57 stack CT weight—/ -3k lbs @ 9108'& 9148' continue in hole stack CT weight /-6k lbs plus WOB spike to 1.2k lbs @ 9397' continue in hole stack CT weight_/ -3k lbs @ 9399'& 9410' PU and RBIH to clean up 3 times Continue to RIH clean passage through the loss zone 9400'. stack CT weight_/-3kl lbs @ 10,000' PU and continue in hole, appears to be clean simply pushing BHA up hill. CT RIH Wt fell of steadily from 145 k lbs, to 10 k lbs @ 10,000 then felt off more quickly as we pushed up hill to 10,630' and 5 k lbs CT Wt. 7/9/2017 7/9/2017 1.40 PROD1 DRILL DISP P PUH slowly while completing 10,630.0 9,180.0 20:57 22:21 construction of liner running pill. start pumping @ 21:17, lay in 20 bbls of beaded tubed liner running pill from ... 10630 to above the loss zone @ 9400'. Pulled 43 k from 9435 - 9415' clean was 38 k lbs. Painting Yellow TO flag @ 9388.25' Page 11120 Report Printed: 7/17120171 Operations Summary (with Timelog Depths) 1C-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Tore our (hr) Phase Op co A Miry Code Time P -T -X Operation (HKB) EM Depth J KS) 7/9/2017 7/10/2017 1.65 PROD1 DRILL TRIP P POOH pumping PowerPro lite. 9,180.0 2,828.0 22:21 00:00 Pressure check at the window, parked 7,170' bit depth, annular pressure 3176 psi while pumping 8.8 ppg @ 0.5 bpm. sensor depth 6472 TVD, 9.4 ppg EMW. Paint WhiteWmdow flag @ 5778.21' continue to POOH 7/10/2017 7/10/2017 0.50 PROD1 DRILL TRIP P Conliue to POOH. 2,828.0 78.0 00:00 00:30 7/1012017 7/10/2017 1.60 PROD1 DRILL DISP P Complete dilution of stock KW fluid. @ 78.0 78.0 00:30 02:06 1:09 start bullhead 90 bbls 10.0 ppg KW (NaCI/NaBf) @ 1.63 bpm and WH of 862 psi. PJSM 7/10/2017 7/10/2017 1.20 PROD1 DRILL PULD P Flow check, Well on a vac, LD BHA 11 78.0 0.0 02:06 03:18 over a dead well. lost 5 bbls in first 5 min. continue to fill hole. Examine pipe for flat spots - good. 7/10/2017 7/10/2017 0.40 PROD1 DRILL BOPE P Perform BOPE function test. 0.0 0.0 03:18 03:42 7/10/2017 7/10/2017 0.50 COMPZ1 CASING PUTS P Prep floor for running liner, PJSM, . 0.0 0.0 03:42 04:12 total hole fill 35 bbls in last two hours. 7/10/2017 7/10/2017 1.40 COMPZI CASING PUTB P Make up liner 32 joints, (1266.87') 2- 0.0 633.3 04:12 05:36 3/8" 4.6 #/fl L-80 slotted liner. Perform safety joint drill, time 2:55 min - AAR comments- good job, smooth, efficient. 7/10/2017 7110/2017 0.40 C0MPZ1 CASING PUTS P Clean up rig floor for crew change 633.3 633.3 05:36 06:00 7/10/2017 7/10/2017 1.00 COMPZI CASING PUTS P PJSM, continue PU lower liner 633.3 1,267.0 06:00 07:00 assembly 12 Its, close 2-3/8" combi's 7110/2017 7/10/2017 0.75 COMPZI CASING PULD P PJSM, MU Coikrak tools, surface test, 1,267.0 1,312.3 07:00 07:45 strip down and stab INJH, open 2-318" combi's 7/10/2017 7/10/2017 1.25 COMPZI CASING RUNL P Tag up, reset counters, RIH with 1,312.3 7,037.0 07:45 09:00 BHA# 12, 32 its of slotted liner ported bull nose and shorty deployment sleeve. 7/10/2017 7/10/2017 0.15 COMPZt CASING RUNL P Stop and correct to the 6,000' EOP 7,037.0 7,012.3 09:00 09:09 flag, minus 24.78', PUW 35 k 7/10/2017 7/10/2017 0.40 COMPZI CASING RUNL P Continue RIH 7,012.3 8,225.0 09:09 09:33 7/1012017 7/10/2017 0.25 COMPZI CASING DLOG P Log the K1 marker correction of plus 8,225.0 8,245.1 09:33 09:48 8.0' 7/10/2017 7/10/2017 0.90 COMPZ1 CASING RUNL P Continue RIH 8,245.1 10,630.0 09:48 10:42 ' 7/10/2017 7/10/2017 0.25 COMPZI CASING RUNL P PUW 44 k, bring pump up to 1.8 bpm 10,630.0 10,630.0 10:42 10:57 at 4,500 psi, open choke 1.0 bpm returns, PUW 33 7/10/2017 7/10/2017 2.25 COMPZI CASING TRIP P Remove BHA from Counters, POOH, 10,630.0 44.2 10:57 13:12 pumping .72 bpm 7/10/2017 7/10/2017 0.50 COMPZI CASING OWFF P Al surface, PJSM, Check well for flow 44.2 44.2 13:12 13:42 7/10/2017 7/10/2017 0.75 COMPZI CASING PULD P LD setting tools 44.2 0.0 13:42 14:27 Page 12120 Report Printed: 7117/2017 4 Operations Summary (with Timelog Depths) 1C-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our (m) Phase op Code A ity Code Time PT -X Operation start Depth (WB) End Depth(flKB) 7/10/2017 7/10/2017 1.50 COMPZ1 CASING PUTS P PJSM, MU upper liner section with 30 0.0 1,189.3 14:27 15:57 its of slotted liner, close 2-3/8" combi's 7/10/2017 7/10/2017 0.50 COMPZI CASING PULD P PJSM, MU CoilTrak tools, surface test 1,189.3 1,234.7 15:57 16:27 tools (good test), open 2-3/8" oombi's 7/10/2017 7/10/2017 1.10 COMPZ1 CASING RUNL P Tag up, reset counters, RIH with 1,234.7 7,058.0 16:27 17:33 second liner assembly. BHA# 13 7/10/2017 7/10/2017 0.15 COMPZ1 CASING RUNL P Corrected to the EDP flag 5,800', 7,058.0 7,058.0 17:33 17:42 minus 18.5', PUW 35 k 7/10/2017 7/1012017 0.30 COMPZI CASING RUNL P Continue RIH 7,058.0 8,145.0 17:42 18:00 7/10/2017 7/10/2017 0.25 COMPZI CASING DLOG P Log the K1 marker correction of plus 8,145.0 8,163.0 18:00 18:15 4.0' 7/10/2017 7/10/2017 0.40 COMPZI CASING RUNL P Continue RIH, work pipe from 8,414' 8,163.0 9,362.0 18:15 18:39 to 8,450'. 7/10/2017 7/10/2017 0.20 COMPZI CASING RUNL P Tag bottom at 9362', PUW 45 k, set 9,362.0 8,149.6 18:39 18:51 back down, bring pump up to 1.7 bpm, open choke, 1.0 bpm returns, PUW 35 k 7/10/2017 7/10/2017 1.50 COMPZ1 CASING TRIP P POOH, pumping 0.8 bpm at 1128 psi, 8,149.6 44.2 18:51 20:21 following MP 10.0 ppg schedule 7/10/2017 7/10/2017 0.50 COMPZI CASING OWFF P At surface, fill the hole, shut down 44.2 44.2 20:21 20:51 monitor well for flow, PJSM 7/10/2017 7/10/2017 0.25 COMPZ1 CASING PULD P LD setting tools 44.2 0.0 20:51 21:06 7/10/2017 7/10/2017 0.50 COMPZI CASING PUTB P PU/MU Open Hole Anchored Billet 0.0 22.1 21:06 21:36 and 10' perforated pup joint. 7/10/2017 7/10/2017 0.25 COMPZI CASING PULD P PU/MU CoilTrak tools, stab INJH, 22.1 84.0 21:36 21:51 surface test tools (good lest). check pac-offs 7/10/2017 7/10/2017 0.60 COMPZ1 CASING SVRG P Tighten levelwind CTES counter 84.0 84.0 21:51 22:27 housing and encoder 7/10/2017 7/11/2017 1.55 COMPZI CASING RUNL P Tag up, reset counters, RIH with OH 84.0 6,370.0 22:27 00:00 Anchored Billet. Park @ 6925', PU Wt 33 k lbs. SID pumps, close EDC. continue to RIH. 7/11/2017 7/11/2017 0.20 COMPZI CASING RUNL P Continue to RIH 6,370.0 6,690.0 00:00 00:12 7/11/2017 7/11/2017 0.20 COMPZI CASING DLOG P Log the Kt for -14.5' correction 6,690.0 7,028.0 00:12 00:24 7/11/2017 7/11/2017 0.60 COMM CASING RUNL P Continue to RIH 7,028.0 8,170.9 00:24 01:00 7/11/2017 7/11/2017 0.10 COMM CASING RUNL P Tag up TOL„ PU Wt 38 k, RBIH, tag 8,171.0 8,171.0 01:00 01:06 up SID 3 k Itis WOB, PU 35k to neutral, orient to 180° ROHS. sheared at 3400 psi, WOB climbed from .9 k to 5k lbs. PU slightly RBIH, SID 5.8 k 7/11/2017 7/11/2017 1.60 COMPZI CASING TRIP P POOH, park @ 6636, open EDC, 8,171.0 81.0 01:06 02:42 continue to POOH holding 10.0 ppg pressure schedule. 7/11/2017 7/11/2017 1.00 COMPZI CASING PULD P PJSM, bump up, flow check, on vac, 81.0 0.0 02:42 03:42 LD BHA#14 Billet setting assembly over a dead well. 7/11/2017 7/11/2017 1.20 PROD2 STK PULD P PU BHA #15, AL1 let build drilling 0.0 72.0 03:42 04:54 assembly, stab injector, check stipper- good, tag up, set counters. test tools Open EDC. Page 13120 Report Printed: 7/17/2017 Operations Summary (with Timelog Depths) 1C-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Sart Time EM Time Our (hr) Phase Op Code Aavq Code Time P -T -X Opereuon (MB) EM Depth (WS) 7/11/2017 7/11/2017 1.40 PROD2 STK TRIP P RIH holding 10.0 ppg EMW schedule 72.0 6,970.0 04:54 06:18 while turning coil over to PowerProw light drilling system. 7/11/2017 7/11/2017 0.20 PROD2 STK DLOG P Tie into the K1 for a -13' correction. 6,970.0 6,990.0 06:18 06:30 7/11/2017 7/11/2017 0.60 PROD2 STK TRIP P PU Wt 34k lbs, park, down on pumps, 6,990.0 8,150.0 06:30 07:06 close EDC. continue to RIH. 7/11/2017 7/11/2017 2.30 PROD2 STK KOST P Dry tag TOB @ 8150'. PU, set rate, 8,150.0 8,150.5 07:06 09:24 1.80 bpm, CT 4130 psi, annular 4079 psi, WH 748 psi, free spin diff 425 psi, RIH Wt 13 k lbs, OBD, Stall 7 times, pump 10 bbl beaded pill, stall 3 more times, fan pump to get started, beads all going down the A let, no benifit seen with weight transfer. A let bridging off with aluminum billet cuttings, annular pressure up to 4400 psi, WH 1100 psi. Crack choke to maintain 11.4 ppg EMW at the window. 1 bpm return rate. Unloading 10.0 ppg KW fluid off the back side, divert returns to the tiger tank. Retuns built to 100% as cuttings were generated. Converting Power Pro light to full system, viscing up fluid. 7/11/2017 7/11/2017 0.30 PROD2 STK KOST P Time drill ahead for 3 feet at - 0.9 k 8,150.5 8,151.5 09:24 09:42 lbs WOB and 1 Whir. 7/11/2017 7/11/2017 0.80 PROD2 STK KOST P Time drill ahead at 3.6 fl/hr. 8.8 ppg 8,151.5 8,163.8 09:42 10:30 Power Pro light returns, brought fluid back inside. Increase WOB to 2 k lbs, ROP 18 ft/hr. 7/11/2017 7/11/2017 0.20 PROD2 STK KOST P PU, W133 k lbs, dry drift billet clean. 8,163.0 8,163.0 10:30 10:42 7/11/2017 7/11/2017 2.00 PROD2 DRILL DRLG P Set rate, 1.78 bpm in, 1.73 bpm out, 8,163.0 8,239.0 10:42 12:42 CT 4199 psi, free spin diff 425 psi..Cl wt 7.32k lbs, WOB 2.69 k lbs, ROP 14 140 fithr. 7/11/2017 7/11/2017 1.20 PROM DRILL DRLG P Having a dificult time dropping. Time 8,239.0 8,249.0 12:42 13:54 drill in an effort to drop. 7/11/2017 7/11/2017 1.00 PROD2 DRILL DRLG P Drilled ahead w good weight transfer 8,249.0 8,392.0 13:54 14:54 at - 129 fl/hr. 7/11/2017 7/11/2017 0.80 PROD2 DRILL DRLG P Encountered losses of 0.2-0.3 bpm @ 8,392.0 8,453.0 14:54 15:42 8392 - TD build section. 7/11/2017 7/11/2017 0.80 PROD2 DRILL WPRT P PU Wt 35 k lbs. PUH, sweep exited 8,453.0 7,095.0 15:42 16:30 the bit @ 8042'. Chase sweeps through build 7/11/2017 7/11/2017 0.30 PROD2 DRILL CIRC P Park, Open EDC, pump 1.7 bpm 8,453.0 7,095.0 16:30 16:48 through pilot hole, 2.0 bpm once above the cement pilot hole. 7/11/2017 7/11/2017 0.30 PROD2 DRILL DLOG P Park a the window, 6448' TVD, 8,453.0 7,100.0 16:48 17:06 measure BHP @ 3918 psi, bleed the well to 11.4 EMW and observe pressure climb and stabilize at 3885 psi - 11.6 ppg EMW. 7/11/2017 7/112017 1.30 PROD2 DRILL TRIP P Continue to POOH holding one for 7,100.0 72.0 17:06 18:24 one returns, tag up, space out. 7/11/2017 7/112017 1.50 PROD2 DRILL PULD P PJSM, PUD BHA #15, checks not 72.0 0.0 18:24 19:54 holding, close EDC, continue to PUD with EDC closed. Page 14120 Report Printed: 7/1 712 01 7 Operations Summary (with Timelog Depths) IC -04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time Eno Time Our (hr)Phase Op Code Activity Code Time P -T -X Opembon Stan Depth (MB) End Depth (aKB) 7/11/2017 7/11/2017 1.60 PROM DRILL CTOP P Slide in cart, remove checks, install 0.0 0.0 19:54 21:30 nozzle, stab cart on WH, pump backwards, BO nozzle, changeout - UQC, pump forward 7/11/2017 7/11/2017 2.10 PROD2 DRILL PULD P PJSM, PD BHA#16 (agtitator, .5' 0.0 78.0 21:30 23:36 AKO X-Treme motor, HYC C1 -3D bit), tag -up, test MWD, check packoffs 7/11/2017 7/12/2017 0.40 PROD2 DRILL TRIP P Begin RIH, surface test agitator, good, 78.0 3,960.0 23:36 101 open EDC 7/1212017 7/12/2017 0.50 PROM DRILL TRIP P Continue RIH, holding increased 3,960.0 6,968.0 00:00 00:30 choke to maintain 1 -for -1 7/12/2017 7/12/2017 0.30 PROM DRILL DLOG P Tie-in for a -15' correction 6,968.0 7,007.0 00:30 00:48 7/12/2017 7/12/2017 0.70 PROD2 DRILL TRIP P Continue RIH 7,007.0 8,453.0 00:48 01:30 7/12/2017 7/12/2017 2.20 PROD2 DRILL DRLG P OBD AL2 lateral, rate in = 1.75 bpm, 8,453.0 8,883.0 01:30 03:42 rate out = 1.78 bpm, BHP = 4165, CWT = 1OK, WOB = 1.4K, PU at 8684', PUW = 47K, average ROP -130 fph 7/12/2017 7/12/2017 2.50 PROD2 DRILL WPRT P Wiper up -hole, PUW = 35K (geo 8,883.0 7,575.0 03:42 06:12 wiper to discuss pulling for a higher bend) 7112/2017 7/12/2017 0.60 PROD2 DRILL WPRT P Wiper in-hole, RIW = 13 k lbs (geo 7,575.0 8,883.0 06:12 06:48 wiper to discuss pulling for a higher bend) 7/12/2017 7/12/2017 1.70 PROD2 DRILL DRLG P OBD AL1 lateral, rate in = 1.80 bpm, 8,883.0 9,001.0 06:48 08:30 rale out = 1.60-1.80 bpm, BHP = 4057, CWT = 4K, WOB = 3.5k, PU's 48k to 35k average ROP -69 fph 7/12/2017 7/12/2017 1.50 PROD2 DRILL DRLG P Broke through ROP up to 150 Whir. 9,001.0 9,138.0 08:30 10:00 OBD, CT 5713, WH 330 psi, 1.80 bpm 1 for 1 returns, Annular 4090 psi CT Wt 4.6 k lbs, WOB 1.5 k Ibs, ROP 20 to 200 Whir PU's 43 k - 51 k Drilling stringers average ROP -91 fph 7/12/2017 7/12/2017 0.70 PROD2 DRILL DRLG P '•• Lost all returns @ 9138' 9,138.0 9,180.0 10:00 10:42 PU, 36k lbs, PUH 100 feet, RBIH losses healed to 0.5 bpm OBD, CT 5009 psi, WH 330 psi, 1.80 bpm, returns 0.3 - 1.0 bpm Pump 20 bbl 7/12/2017 7/12/2017 0.20 PROD2 DRILL WPRT P PU, 46 k lbs, wipe up hole above 9,180.0 9,180.0 10:42 10:54 innitial losses, RBIH, stack of @ 9100', modulate pump, RBIH. 7/12/2017 7/12/2017 0.60 PROD2 DRILL DRLG P BOBD, Losses worsened, 1.8 in 0.5 9,180.0 9,252.0 10:54 11:30 bpm out. Drilled ahead with little healing of losses. Consult W town engineering, decide to close choke. average ROP -120 fph 7/12/2017 7/12/2017 0.90 PROD2 DRILL WPRT P PU, 38k Ibs. to window 33k Ibs while 9,252.0 6,949.0 11:30 12:24 PUH. While pulling through the window and @ min rate WH 310, Annular 3000 psi, rate in 0.3 rate o4t 0. Page 15120 ReportPrinted: 7117/2017 Operations Summary (with Timelog Depths) 1C-04 Rig: NABORS CDR3-AC Jod: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dw(hn Phase Op Code AMetty Code Tme P -T -X Operation MB) End DepM(W13) 7/12/2017 7/12/2017 0.80 PROD2 DRILL DISP P S/I choke, Line up to he back side, 9,649.0 9,959.0 12:24 13:12 bullhead 49 bbls bbls liner running pill, increaded rate from 1 bpm to drilling rate of 1.8 bpm, WH climbed to 1773 psi, annular climbed to 3934 psi. 7/12/2017 7/12/2017 0.20 PROD2 DRILL DLOG P Log K1 for+6' correction 9,959.0 7,008.0 13:12 13:24 7/12/2017 7/12/2017 0.80 PROD2 DRILL TRIP P RBIH pumping min rate through the 7,008.0 9,252.0 13:24 14:12 build, window dean, WOB spike @ 7330', slight bobble at 7512, no motor work or TF change, SID 9141, pushed through. 7/12/2017 7/12/2017 2.00 PROD2 DRILL DRLG P Set rate 1.80 bpm against a closed 9,252.0 9,450.0 14:12 16:12 choke, Free spin diff 1400 psi, CT 5600 psi OBD, CT Wt 5 k lbs, WOB 2.6 k lbs, ROP 130, WH 1169, Annular 4232 psi Average ROP = 97.5 ft/min 7/12/2017 7/12/2017 0.10 PROD2 DRILL WPRT P PU 39k lbs, wipe to above the loss 9,450.0 9,000.0 16:12 16:18 zone @ 9138'. String weight fell off above the loss zone. 7/12/2017 7/12/2017 0.10 PROD2 DRILL WPRT P RBIH, RIH Wt 10-11k lbs 9,000.0 9,450.0 16:18 16:24 7/12/2017 7/12/2017 1.10 PROD2 DRILL DRLG P Set Rate @ 1.78 bpm, CT 5050 psi, 9,450.0 9,522.0 16:24 17:30 WH 920 psi, free spin 1261 psi OBD, CT Wt 5 k lbs, WOB 2.4 k lbs, ROP 120 ft/hr. in stringers again 65 ft/hr over interval 7/12/2017 7/12/2017 2.60 PROD2 DRILL DRLG P Continue drilling ahead, CWT = 7K, 9,522.0 9,701.0 17:30 20:06 WOB =1 K, SHIP =3748 psi, WHP= 663 psi, ROP -72 fph over interval. 7/12/2017 7/12/2017 0.30 PROD2 DRILL WPRT P Wiper up -hole, PUW =38K 9,701.0 8,992.0 20:06 20:24 7/12/2017 7/12/2017 0.30 PROD2 DRILL WPRT P Wiper in-hole, RIW = 11.51K at 9650' 8,992.0 9,701.0 20:24 20:42 7/12/2017 7/12/2017 2.80 PROD2 DRILL DRLG P SOBD, pumping 1.8 bpm, free spin = 9,701.0 10,045.0 20:42 23:30 1170 psi, CWT = 4K, WOB = 2.71K, dp = 1410 psi, BHP = 3650 psi, WHP = 570 psi, PUW check at 10,000'= 38K, continue drilling waiting for sweep to exit the bit, ROP -123 fph over interval 7112/2017 7/13/2017 0.50 PROD2 DRILL WPRT P Begin wiper up -hole, PUW = 40K 10,045.0 8,534.0 23:30 00:00 7/13/2017 7/13/2017 0.60 PROM DRILL WPRT P Continue WT to window 8,534.0 6,960.0 00:00 00:36 7/13/2017 7/13/2017 0.20 PROD2 DRILL DLOG P Log K1 for+6' correction 6,960.0 6,960.0 00:36 00:48 , 7/13/2017 7/13/2017 0.80 PROD2 DRILL SVRG T Remain in cased hole, replace leaking 6,960.0 6,900.0 00:48 01:36 seal on mud pump #1, maintaining ECD 7/13/2017 7/13/2017 1.20 PROD2 DRILL WPRT P Wiper in-hole to continue drilling, slight 6,900.0 10,045.0 01:36 02:48 weight bobble through window & at 7467', clean past thief zone at 9138', slight bobble at 8,150' (billet), RIW = 9K at 10,025' Page 16120 Report Printed: 7/17/2017 Operations Summary (with Timelog Depths) 1C-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log S Slart Tiere End Time Oar (hr) Phase op Ca a A.Wty Cotle Time P -T -X QpeMW (WS) End Depth (ff1C8) 7/13/2017 7/13/2017 1.80 PROD2 DRILL DRLG P BOBO, free spin= 1150 psi, pumping 10,045.0 10,208.0 02:48 04:36 1.78 bpm, dosed choke, BHP = 3826 psi, WHIP = 728 psi, difficutly dropping inclination, continue to get bounced up from -85° to 87°- 88°, PUW = 50K, perform BHA wiper, ROP over interval = 90 fph 7/13/2017 7/13/2017 1.30 PROD2 DRILL DRLG P Continue drilling ahead attempting to 10,208.0 10,303.0 04:36 05:54 get to & hold 85° inclination, FS = 1141 psi, CWT = 6K, WOB = 1.51K, BHP = 3600 psi, WHIP = 490 psi, ROP over interval = 95 fph 7/13/2017 7/13/2017 0.60 PROD2 DRILL WPRT P PU Wt 43 k lbs, Pulling weight 38k to 10,300.0 8,980.0 05:54 06:30 36 k Ibs above the loss zone, wiper - 1320' 7/1312017 7/13/2017 0.50 PROD2 DRILL WPRT P RBIH, Wt 15 k lbs, saw theif zone at 8,980.0 10,303.0 06:30 07:00 9100, oriented wrond, most likely BHA geometry. 7/13/2017 7/13/2017 6.10 PROD2 DRILL DRLG P 1.77 bpm, CT 4163 psi, free spin diff 10,303.0 10,644.0 07:00 13:06 1146 psi, WH 447 psi, annular 2544 psi. OBD, CT Wt 4- 1 k WOB 3 - 1 k lbs, ROP 160 - 20 R/hr. PU's 41 k last two 56 and 59 k Ibs, call wiper ROP over interval = 56 fph 7/13/2017 7/13/2017 0.60 PROM DRILL WPRT P PU wt 59 k lbs, wiper ( 1644') 10,644.0 9,000.0 13:06 13:42 7/132017 7/13/2017 0.50 PROD2 DRILL WPRT P RBIH, RIH Wt 14 k to 12k Ibs 9,000.0 10,644.0 13:42 14:12 7/13/2017 7/13/2017 3.30 PROD2 DRILL DRLG P 1.84 bpm, CT 4408 psi, free spin diff 10,644.0 10,800.0 14:12 17:30 1230 psi, WH 447 psi, annular 3609 psi. OBD, CT Wt3 k Ibs k WOB 2.8 k Ibs, ROP 60-140 R/hr. Grabby, looks to be differential sticking, PU 58k lbs, ROP over interval = 47 fph 7/13/2017 7/13/2017 1.60 PROD2 DRILL WPRT P PU Wt 45 k Ibs, POOH to window for 10,800.0 7,100.0 17:30 19:06 tie in and SBHP 7/13/2017 7/132017 0.20 PROD2 DRILL DLOG P Obtain SBHP, Bit Depth = 7100', 7,100.0 7,132.0 19:06 19:18 sensor depth = 7051', TVD sensor= 6373', EMW of 10 ppg = 3314 psi, shut down pumps, closed choke, allow annular pressure to drop below 3314 psi as per procedure, pressure drops below 10 ppg EMW, 10 ppg kills "It Log RA tag for +14.5' correction 7/1312017 7/13/2017 1.00 PROD2 DRILL WPRT P RBIH, slight set down at -8440', 7,132.0 10,608.0 19:18 20:18 cleaned up area at 9145'& 9514', TD confirmed at 10,808", begin sending 25 bbl liner running pill 7/13/2017 7/13/2017 3.50 PROD2 DRILL DISP P POOH, lay in liner running pill (25 bbl) 10,808.0 78.0 20:18 23:48 from TO to thief zone at 9138', switch to drilling fluid to surface, painted EDP flag(5278.28), tag up, space out 7/13/2017 7/14/2017 0.20 PROD2 DRILL DISP P Al surface, open EDC, begin to 78.0 78.0 23:48 00:00 bullhead 90 bbl KWF down to thief zone. Page 17/20 Report Printed: 711712017 Operations Summary (with Timelog Depths) IC -04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Mme Our (hr) Phase Op Code AcrWy Code Time P -T -X Operation (f KB) EM Depth (re(a) 7/14/2017 7/14/2017 1.20 PROD2 DRILL DISP P Continue to bullhead KWF to thief 78.0 78.0 00:00 01:12 zone at 9138', PJSM during bullhead for LD BHA #16, flow -check (-5 min), on a vac, -18 bbl/hr losses, close EDC 7/14/2017 7/14/2017 1.00 PROD2 DRILL PULD P LD BHA #16 over a dead well, bit 78.0 0.0 01:12 02:12 came out a 2-2 7/14/2017 7/14/2017 2.80 COMM CASING PUTB P PJSM, PU Liner Run #1 (ported bull- 0.0 1,770.0 02:12 05:00 nose, 44 jnts slotted liner) 7/14/2017 7114/2017 0.70 COMPZ2 CASING PULD P PJSM (new driller on tour), PU BHA 1,770.0 10,810.9 05:00 05:42 #17 Liner Running Assembly Run #1 (shorty deployment, GS, & BHA), slide in cart, stab on, bump up set counters, inspect pack offs. 7/14/2017 7/14/2017 1.70 COMPZ2 CASING RUNL P RIH with BHA #17, lineup down the 1,814.0 8,710.0 05:42 07:24 back side and start pumping liner running pill down the back side. Tie into window flag and correct -21.08'. PU W136 k lbs. 7/142017 7114/2017 0.10 COMPZ2 CASING DLOG P Tie into K1 for +6' correction. 8,710.0 8,744.0 07:24 07:30 7/14/2017 7/14/2017 0.90 COMPZ2 CASING RUNL P Continue to run lowwer completion to 8,744.0 10,808.0 07:30 08:24 bottom. SO 10807.5'. 4.7k WOB PU Wt 43 k lbs, -4, RBIH S/D 5 MOB, PU to slack CT Wt, Swap from pumping down the back side to the coil, increase rate to 1.45 bpm PU 33k lbs string weight, WOB 0lbs " Set bottom linersection, top @ 9038.5', bottom 10808' 7/14/2017 7/14/2017 1.00 COMPZ2 CASING TRIP P POOH, paint yellow window flag@ 10,808.0 6,939.0 08:24 09:24 6954'. Continue to PUH, park at 6939' bit depth, 6263' TVD, Inteq pressure 3291 psi, SID pumps trapping pressure, Pressure trended down to 3259 psi in ten minutes. calculated out at 10.00 ppg EMW. 7/14/2017 7/14/2017 0.20 COMM CASING TRIP P Continue to POOH, pumping 0.53 6,939.0 6,145.0 09:24 09:36 bpm and pulling 100 ft/min, WH climbed from 0 to 600 psi and annular to 3,970 psi. Parked coil, came down on the pump. Allowed presures to, relax, BHP fell to - 10 ppg EMW, verified no flow at surface, well on a vac. 7/14/2017 7/14/2017 1.50 COMPZ2 CASING TRIP P Weight up KW from 10 ppg to 1.2 ppg. 6,939.0 6,145.0 09:36 11:06 1 Open EDC 7/142017 7/142017 0.40 COMM CASING TRIP P RBIH, turning coil over to 8.92 ppg 6,145.0 7,120.0 11:06 11:30 liner running pill, 17 bbls total, 7/14/2017 7/14/2017 0.10 COMM CASING TRIP P Tie int olhe RA tag for a +7' 7,120.0 7,146.0 11:30 11:36 7/14/2017 7/14/2017 0.80 COMM CASING TRIP P Continue to RIH. chase the liner 7,146.0 9,029.0 11:36 12:24 running pill w 10.2 ppg, 1.33 bpm in, 1.27 bpm out, annular 3774 psi, choke wide open, increase rate to 1.6 bpm chasing pill to bottom, returns fell off damaticaly. 7/14/2017 7/14/2017 0.60 COMM CASING TRIP P PUH, laying in 17 bbl beaded liner 9,029.0 7,125.0 12:24 13:00 running pill, pumping 0.49 bpm in 0.11 j bpm out, 7/142017 7/14/2017 1.80 COMPZ2 CASING TRIP P Contiune to POOH, paint white flag @ 7,125.0 45.0 13:00 14:48 4944', continue to POOH 1 Page 18120 Report Printed: 711 712 01 7 Operations Summary (with Timelog Depths) 1 C-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Our (hr) Phaea Op God. AOvity Code Time P -T -x Operabon Start Depth (ftKB) End Depth (MS) 7/14/2017 7/14/2017 1.00 COMPZ2 CASING PULD P Bump up, open the stack at the floor, 45.0 0.0 1448 15:48 flood up to the half drum, ovserve flow, - none, cycle EDC closed, opened and closed again after pumping beads through it. - good. PJSM, LD BHA #17 over a dead well. 7/14/2017 7/14/2017 0.40 COMP72 CASING PUTB P Prep floor to run liner, buck up ported 0.0 22.2 15:48 16:12 bullnose and three pups (21.82'), 7/14/2017 7/14/2017 3.40 COMPZ2 CASING PUTB P PU upper AU Lateral, 37 joints of 22.2 2,077.3 16:12 19:36 slotted & 19 joints of blank pipe, filling hole, 4 bbls/hr hole fill 7/14/2017 7/14/2017 1.90 COMPZ2 CASING PULD P PJSM, Kick while running liner drill, 2,077.3 2,128.0 19:36 21:30 PU safety joint, monitor well, well is on a vac, PU PBR, GS, & BHA #17, inspect counter, loose chain, slide cart back, stab on, 7/14/2017 7/14/2017 2.00 COMPZ2 CASING RUNL P RIH with liner, pumping 8.7 ppg liner 2,128.0 6,955.0 21:30 23:30 pill down back side as per town request (not to exceed 750 psi WHP, 12.4 ppg EMW with 10.2 ppg in the hole), tie into EOP pipe flag for a -23' correction, PUW = 35K at window, reached setting depth, PUW = 40K at set depth, RBIH, bring up pumps, release off liner putting TOL at -6955' MD (BOL at 9038.5), PUW = 30K 7/14/2017 7/14/2017 0.30 COMPZ2 CASING DLOG P Obtain SBHP at 6945' MD, TVD 6,955.0 6,945.0 23:30 23:48 sensor= 6245', Annular stabalizes at - 2938 psi, EW M = -9 ppg 7/14/2017 7/15/2017 0.20 COMM CASING TRIP P POOH, pumping KWF down backside 6,995.0 5,000.0 23:48 00:00 7/15/2017 7/15/2017 1.60 COMPZ2 CASING TRIP P Continue POOH, slop at 720'& clean 5,000.0 44.0 00:00 01:36 cartlinjector for summer maintenance replacement. 7/15/2017 7/15/2017 0.60 COMM CASING PULD P PJSM, flow check, LD BHA #18 over 44.0 0.0 01:36 02:12 dead well 7/15/2017 7/15/2017 0.90 DEMOB WHDBOP FRZP P Slide in cart, stab on, PJSM, bullhead 0.0 0.0 02:12 03:06 30 bbl diesel at .8 bpm 7/15/2017 7115/2017 0.60 DEMOB WHDBOP CIRC P Jet stack, displace coil to seawater 0.0 0.0 03:06 03:42 7/15/2017 7/15/2017 1.50 DEMOB WHDBOP MPSP P PJSM, RU, lubricate in BPV, RD 0.0 0.0 03:42 0512 7/15/2017 7/15/2017 2.10 DEMOB WHDBOP CIRC P Slide in cart, stab on, blow down reel, 0.0 0.0 05:12 07:18 PUTZ, & surface lines w/ N2 (SLB) 7/15/2017 7/15/2017 6.00 DEMOB WHDBOP CIRC P Secure reel, remove inner reel 0.0 0.0 07:18 13:18 iron,pressure bulkhead, un stab, secure pipe. 7/15/2017 7/15/2017 3.70 DEMOB WHDBOP CIRC P Drop stripper off injector, swap bag 0.0 0.0 13:18 17:00 ( annular). blow down steam, disconnect at the PUTZ. Start ram swaps. Start motors, swap off high line power to generators - 4:00 pm Page 19/20 Report Printed: 7117/2017 Operations Summary (with Timelog Depths) 7 C-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Emil Depth start Time End Time Our hr) Phase Op Code Adrviy Cade Time P -T -X Operehon (WS) End Depth(RKa) 7/15/2017 7/15/2017 4.30 DEMOB WHDBOP RURD P Breakdown TT hard lines, break down 0.0 0.0 1700 21:18 scaffolding, NES trucks arrive at —19:30 hours, PJSM, plan moving to edge of 1C -Pad, raise/roll pits, work RDMO check list, RU & spot service module to pad edge, regain COMMS. 7/15/2017 7/16/2017 2.70 DEMOB WHDBOP NUND P ND ROPE, break tree at flow -cross, 0.0 0.0 21:18 0000 install Otis quick union on tree, RU, move, & spot sub module (witnessed by DSO), begin working to pick reel out of sub module, begin work on PDL (summer maintenance). " Rig Released 24:00 hours 7/15/2017 Page 20/20 Report Printed: 7/17/2017 1. ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1 C Pad 1C -04A 50-029-20547-01 Baker Hughes INTEQ Definitive Survey Report 27 July, 2017 BA ER F�UGHES GE.m,, r. ConocoPhilli'°° ConocoPhillips Definitive Survey Report a Up 0 Company: ConodPhllllps(Alaska) Inc .-Kupl Local Coordinate Reference: Well 1C-04 Proles: Kupamk River Unit WO Reference: 1C-04(@ 94.00usft(1C-04) Sib: Kupamk IC Pad MDReMrence: 1"4 Q 94.01(1G04) Well: 1PO4 North Reference: Tme WellSme: 1C-04 Survey Calculation Method: Minimum Curvature Design: 1C-04 Damon.: EDT Alaska Sandbox Project Kupamk River Unit Ni Slope Alaska, United Stabs Map System: US State Plane 1927 (End solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zen. 04 Well 1"4 70.19'30.322IN Well Position +NIS 000 usft Northing: usft +EI -W 000 usft Eastin9: Position Uncertainty 0.00 usft Wellhead Elevation: Williams, 1C -04A ron Magnetics Model Name Sample Deals BGGM2016 8/1/2017 Design 1C -04A Audit Notes Mean Sea Level 10 Phase: ACTUAL Using Well Reference Point Using geodetic awb Mason Vertical section: 5,988,72700usft Latitude: 70.19'30.322IN 552 065 Langitede: 149°29'48.207IN usft Ground Level: 0.00 usft Decimation DIp Ao91e Field Strength E) (1) ron 1755 80.95 57,542.28 Version: 10 Phase: ACTUAL The On Depth; 7,12200 Vertical section: Depth From MWD) +Npi +Em ouecdon lush) (.sit) (usft) III 3350 0 00 000 32000 Survey Program Dab 71132017 From To Survey Survey (usft) toelll 5urveytWe110orei Tool Name Desalptlon start Dab End Data 10000 7,122.00 1C-04(16-04) BOSSGYRO Sperry -Sun BOSS gym nuldshot 812512000 7,12550 7,175.87 1C44A MWD -INC (1C -04A) MWD-INC_ONLY MWD -INC ONLY FILLER 712/2017 71W2017 7,20586 10,839.78 1C-04AMWD(iC-04A) MWO Ml Sterol 71312017 7)9)2017 7,272017 1:40:51FM Page 2 COMPASS 5000.14 Bond 65 v ConocoPhillips Bi 4 ConocoPhilli s Definitive Survey Report Company, ConomPhilh,(Alaska) Inc.-Kup1 Project: Kupamk River Unit Sire: Kupamk IC Pad well IC -04 Wellbore: 1C -D4 Design: 'C -D4 Wcal Co-0Polnabi Reference: Wee 1D-04 I TVD Reference: 1C,M ® 9400unt (10-04) MD Reference: 1041 @ 94.01(1"4) North Reference: True Survey Calculation Mei Minimum Curvature cabinet.. EDTAINka Sandbox Annotation TIP KOP Interpolated Azimuth Interyolated Aumuth find Good Survey COMPASS 500014 Sudd 0 Map Map MD Inc Azi ND TVDSS HUS .0-W NOOft) EanlnB DLS Sent. Sectlan &ury Tool Name � (usRl (1) 11I lush) lush IuaR1 luskl (RI In) (.rtpy) ltt) 7,12200 400 319W 6,944.1 630.1 -19821 -2,482.95 5950.06.26 559,584.01 5.00 1,44447 MW0.1NC ONLY (2) 7.125W 383 3190 6,417.55 6,353.55 -INN 3,493.10 5,968,50 .46 559,503.86 406 1.444.41 kIhai ONLY (2) - 7,146.72 473 234.32 6.468.73 6.374.73 -198.01 -2484.20 590,50.47 %a,wW 27% 1,445.10 MVVNNC_ONLY (2) 7.17507 10.16 219.32 6,497.24 6403 24 -2N.25 -2,439.15 590,SN.20 55aiN 46.89 1,444.43 MW41NC-ONLY (2) 7,20.86 33.24 215.16 6,52A.10 6,430.10 -21285 34%80 5.80.4074 559.571.10 0.55 1,4144 MWD (3) 7,236.11 4748 21891 6,547.10 84W18 -y,2&10 -ZW774 5.960.470.11 559,55947 4774 1,437.15 MIND (3) 7.06.01 61.41 4116 6.564.52 6,47052 -N6.73 $52338 5,91.43 559.WW 46.0 1AMW MIND (3) 7.2%74 75.50 2X.77 6,57540 6,81.40 -X7.23 -2,54184 5,958438.78 559,52570 47.0 1.429.15 MND13) 7,32627 91.07 223.82 6,57&93 6,484.93 .2N 23 -2.552.57 5,960.416 81 559,50.15 5085 1,4250 Nei 7,3MM 0 41 9200 6,577.24 6,40.1 41007 -2.502.93 5,aMnN.81 559,41 .91 1501 1,2218 MWD(3) 7,31.15 I&M 9070 65Y3.40 6479.40 N 260.1 5,90,372.43 55940.21 1441 1,417.94 MWD131 7,418.26 100.07 9510 6W801 6.474.01 -35&26 -262444 5,90,19 .0 558.44385 13.51 1,41405 MWD (3) 74122 1000 23090 6,56152 5,46752 -37980 4WW72 5.96&325.26 559,41776 16.16 1,1283 MWD (3) 7,4&5.87 10.02 21.97 "%at 6.48181 -39&62 -2,6751 5,96&30.31 559,3N.i0 12.M 1,41445 MWD (3) 7,51499 1N.31 239.19 6550.27 645627 41447 -2,699.57 5.96&293.56 559.399.21 1.M 1,4170 MWD (3) 7.54529 10.1 1376 6,54179 6,4W.79 428.40 -2,70.74 5,588,276.12 5$91315 1.85 1,423W MF9(31 7,57741 100.0 19.23 8,538.79 6441.70 140.0 -2,75487 5,M.Na32 55914.1 1678 1.4VW MINI 7,604.52 10063 252.92 6533.70 6.4%.70 J4961 -2779.85 5,91,21.46 559.28923 1343 1,44243 MWD(3) 7,04.83 10059 2&W 6,5X.12 641.12 AWN -2,808 72 590.245.09 559,2W.43 10.42 1,455.37 Miii 761.91 101.0 26251 6,522.46 5.42346 An 79 2037.85 5,90,24180 559,231.33 120 147039 MIND (3) 7,69510 10147 267.10 6,1&56 6,422.56 4N47 -2087.33 5966.2360 55180 1497 ',487.20 MIND (3) 77200 10195 9D.97 6,51053 6,416.53 11.98 .20%43 5.91230.15 559,17279 12M 150.61 MIND (3) 7,75.12 10148 27502 651.30 BAD 38 -06341 -2948.0559%235 .45 09,14317 13.16 1,5XAM MAD (3) 7784A8 10097 27919 64%50 6404 58 45980 -29%00 5.080242.02 59,114.18 13.M 1,1721 MWD (3) 7815.17 101.95 950 6492.0 6.398.W 455.89 3,9143 5,561.48 590173 11.06 1,50.12 MWD (3) 7.845U3 1021 9291 6,4020 6,N2.20 45385 -3,013.51 5,961 58.05563 10.12 1,539.53 MWD (3) 7.87517 10141 X&59 6,47991 650.91 AN 01 3.01 5.90,248.89 59,026.16 1140 1,6097 MWO(3) 79155 10157 20.69 &47405 6,30.05 45394 -3.071,75 5.90,247]1 5%,997.40 90 1,62674 MWD (3) 79514 10065 %319 &450.10 637440 1559 -3,1010 5.%624182 58,%7.55 1147 1,1393 MWD(3) 7,965.33 10059 2600 6,462.49 6,20.49 AW 70 -3,13101 5,90240.46 55693881 763 1,65.5 Mini 7/172017 1A0:51PM Pa0&3 Annotation TIP KOP Interpolated Azimuth Interyolated Aumuth find Good Survey COMPASS 500014 Sudd 0 V,- ConocoPhillips 622 ConocclPhllll UGKES � Definitive Survey Report 1Map Compow. ConamPhillipa(PLeka) Inc-Kupt Local COUMInata Raerance: Rkll 1C-04 Proles: Kupamk R'Mer Unit NO Rerennce: 1 G0494.DOusp(1004) Etta: Kupamk lC Pad MD Refrenw: 1C-04 ®9400uaR(1C4)q Wap: 1604 honk Relafen.¢: T1ue milleara; 70-04 Surve, Calculatlan Method: Minimum Covakee Deaipn: _._.• 10-04 _`__ _.._ _ Database: _�. EDT Alaska Sandbox Surveey IN) 333,3 _- 1Map Map Whose) MD IM Atl ND TSS 12D rWS 4E - W Northing Eastn9 OLS SectianSurvey Tool Name AnnotaUm (tum (1 11 loam (oat) (hart) coat) IN) (cal Moel In) 7,995.13 98.85 25636 645745 6,363.45 -056.00 -3,159.09 5.95a. 4.93 53.900.37 10.12 1,674.16 NAND (3) 8,02531 98.12 25&99 8.453.00 6,359.00 471.86 -3,189.16 5,026228@ 556013.15 318 1,68849 MWD(3) 8,05507 98.26 26515 6.440.]6 6,3".,76 475.92 3,210.32 s,969,224.52 558,85103 20.49 1,]04.12 MND(3) 8,035.37 WD7 210.14 6,44445 6350.45 47716 3,248.28 553223.04 558,82109 16.31 1,722.43 MAI 8.115.15 97.20 V515 6,44049 6,34349 47579 3.27135 593,224.16 55699151 18.93 1,74242 MWD(3) &145.51 9708 280.01 6.438.7,1 8.34272 47152 -330761 5,958,23789 558,]6102 1509 1,76465 MWD(3) 0.17515 9764 264.05 6,432.91 6,338.92 48570 d,3Y.35 5,968,233P 558]32.93 1365 1.7682 MMM (3) 01219,05 96.83 23.3 6.429.02 6.33502 457,09 -3.33.76 5968,24213 559,703.45 1471 1,813.32 NMA)(3) ' 8,235.01 95.57 293.00 6,425.90 6,33190 446.86 -3.392.67 5.9118.252.11 559,678.47 1&11 1,830.45 MNO(3) 8,265.63 91.81 29702 6423.92 6.329.92 433.92 -3.42034 5,908.264.84 558.648.70 17.77 1,86514 MJN(3) 8,295.49 91 fly W219 &422.97 8,328.97 41919 ,7,446.28 5,586279.37 55662264 17.31 1891.11 MNO(3) 8,32470 9175 3%12 6491.05 8.328.05 40200 3,470.43 5,93,29.3 558,56635 1345 l.m 19 MM(3) ( 8,3MO Old 31055 6420.78 63970 384.13 3494.04 5,93,314.02 55657459 1539 1,95168 MWD(3) 8.3&.75 93.65 31485 6,41901 6,325.01 36380 4,51590 5.93,334.09 558.55249 1443 1,98128 MW➢(3) &41496 90.81 316.78 6,417.89 6,323.89 34223 3,53702 5.960,35516 558,53127 11.92 2D11.39 MND(3) F 0.4".99 9021 31681 6,41767 8,323.67 ,719.99 ,7,557.19 5,910,377.63 558,51092 680 2041.39 MAD (3) 0,47445 0089 32000 6.417.39 15,323.39 -297,52 3,57624 5,960,39994 55&49168 649 2.07085 MWD(3) 8,,S " 9 5 93." 32431 6,0624 6.322.24 -27335 3.59480 5,98642396 558,472.93 1491 '{10129 440s) (3) 8535.54 93.93 328.8 6,414.28 632028 -'027,8 -3,611.57 5,968,"9.31 558,455.95 15.05 213161) MWD(3) 0.585.8 92.8 334.19 6,41249 6,318.49 -22125 -3.62591 5.969.475.02 556,"133 17.58 216124 MD (3) 8,5ffv.09 9157 33939 641136 6.317.29 -19441 -3,63748 5,958,502.53 55642950 18,32 210920 MIND (3) 8,625.41 W06 34208 6,410.93 6.316.93 465.80 3,64748 5,968,53106 559,41937 10.17 221755 MD (3) 8,65502 93.12 34992 641036 6,31636 -13710 -3,85483 593655920 550411.97 2737 22".13 MM (3) 8,885.03 ON 35383 64[8.78 6,31578 -10143 -3,850.7 5,9&39.33 55047.49 14ry 226959 MWD(3) 6,71539 91" 048 6400.38 6,31538 -77.10 -366038 5,%9,619.64 558,405.74 22.33 2,293.79 MWD(3) 8,74521 3.52 461 6400.39 6,315.39 47.32 3,wam 5969149.43 3640081 169 2315.75 Naval 8,775.12 09.17 442 6,40999 6,31599 -17.51 34855]0 5,93,79.35 550408.92 2.26 2,3377 MWD(3) 6,805" 9.96 240 6,409.95 6,31585 12.36 3.654.82 5,93,?W.13 550.41045 908 2,33.80 MWD(3) 8,634.72 3.71 359.52 641D55 6,316.55 4202 3651.42 593.73879 558,410.70 17.35 2,38121 MWD(3) 8,34.69 8401 35570 8,41277 6,31677 71.07 3,655.57 5,93,7369 558,409.21 1420 2404.3 MND(3) 6895.65 65.11 35077 &41549 632149 10249 -365930 5"5,79921 556,40533 153 2430.66 MWD(3) 7872017 1:40:51PM Page 4 COMPASS 500014 Bu11d 65 ConocoPhillips ConocoPhlllips Definitive Survey Repon Co.,.,: ConocoPhillips(Alaska) Inc . -Kup1 Well Co,eminde Reference: Mil 1004 Peeled: Ku,.k River Unit NO Relevance: 1C-0494,00usN(1G04) Site: Koparek IC Ped MD Refemnce: IC-04®"'Nusft(IC-04j Well: 1044 North Rebalance: True Weems. 1C SurveYCalculaOon Method: Minimum Curvature Design: 1Cf14 Database: EDTAI36ke Sandbox Survey Y/iiUlL�]F� Babes 1� 0 MnDlation COMPASS 5000.14 Build e5 Map Map Wm.1 MD Inc idol ND NOSS +NIS +E1 -W Novel Easing DLS Smile" (usnl N (•) (Mm) Joel 0-a t) (.aft) (•MW I Survey Tool Name (N) IN) Ind 0,92517 08.31 35105 6,49.10 632318 131.59 -3,663.95 5,960,82&27 558,40043 1080 2.45595 MWD (3) 0,95491 9100 U733 6417,45 632345 160.79 3,66953 5,968,857.42 558,394.52 14.81 2,48100 "D (3) 6985.17 88.40 34546 6,41769 6.323.69 19020 3.87665 5,950,885.]] 558,38].26 972 2509.00 Nell 9.0140 61.39 M&47 6418.]] 8,324]] 21873 3,683.25 5,960,915M 55630042 10.83 2535.11 Mill 9,04321 8770 35251 8,421.09 6,35 .09 24900 -3668.32 5,968,90.5.0 559,37609 13.17 2561.56 Ball 9,0740 915 354.55 645.17 6,35.17 270.55 3,091.67 5,989,97499 559,37150 1589 25534 MWD(3) 9,104.57 84.09 now 8.41661 6,32461 MOM J3693.57 5,989,004.0 5'6309.5 13M 261017 MWD(3) 9,134.83 94.92 390 6,41625 6,35126 35.01 -3.693.05 5,959.04.42 550.36963 1946. 263270 NINE) (3) 9.165.13 9240 &24 6,414.5 63530 35.5 -3.609.04 6969.064.70 55637200 16.43 2653.89 MAD (3) 9,194.61 8963 9.50 6,413.78 6,31878 57.37 -3,68622 5,955,450.84 550.376.97 ion 2.63.22 all (3) 9,225.03 in" 75 6414.02 6,3502 427.43 -3,68089 5,959,15.81 558,3815 1314 2.68333 NAME) (3) 9,254.53 WAS 369 6418.21 8.32221 45675 -3,BP88 5,9591535 50,383.84 1373 271397 NWD(3) 9.28197 69.5 359.55 6441691 8,322.91 40717 3,67.00 5.959,183.89 58,384,45 14.02 275.8 MKD(3) 9,31623 00.83 355.8D 6416.91 timed 5205 3367635 5,969,21690 556302.03 125 216379 hill 9,344.78 94.46 35428 6,41570 6,321.70 54681 3,66364 5.96'9.243.30 558,383.32 1489 2784.75 all 9,375.11 M91 35051 6414.54 635.54 68.114 3,684.65 5,589,27329 59,376.06 1945 2810.33 M00(3) 9,405@ 8797 34681 6.41510 6,321.10 60615 -,600.53 5,58953.55 59,369.94 136 285.57 MA11)(3) 9.434.93 3800 34272 841590 632190 M1 99 3.093.5 5,969,331.32 565184 135 285.71 eVoO(3) 9,464.93 5.90 33842 6.41665 6,352.85 66327 -3,708W 5.96am 51 58,35164 14.34 289178 MJ4D(3) 9,494.92 6.30 3M," 6,41767 6,323.6 69078 -,721.24 5868,3416.92 558,33953 126 29549 aRND(3) 9,579.01 0727 5117 6.41908 632508 71730 -3,73379 5.9601,413.41 50,3577 125 2,94950 all (3) 954.80 07.55 MTN 6,4544 easel" 143.24 -3.14902 59W.439 16 558,310.32 11.04 39795 Mom (3) 9,504.08 90.03 35.26 6,421.08 0,32708 ]04.27 -3.766.54 5,969,484.03 556293.00 11.91 3,009.97 MAD (3) 9.61482 00.71 321.83 64M0ao 6,35.90 792.52 y78113 6.9%45.13 558.275.01 8.45 3,05.5 MWD(3) 9,64504 93.60 35.02 645.5 6355 816.14 -,80197 5,96951159 558,25.78 9.31 3069.00 ill 9,67523 90.52 31672 64527 6.3527 85.70 3,82E 02 5.999,53399 58.2554 1093 3039.23 MWDl3) 9.70504 93.5 313.94 5,42006 6,326.06 new 3.842.97 5,98955501 55,215.41 95 3,12694 MWD(3) 9,734.84 90.5 31060 6.41992 6,35.92 879.96 -/Pant 5,999,57488 5619322 1094 3,158.47 NNiti 9)64]5 91.00 3691 6.419" 6X5,41 890.90 3,698.15 5,569,5930 5,i6e92 10.30 316.85 MAD(3) 9.78501 91.5 Win 6,41650 6,32450 91660 3.9125 5669.611.13 58,145.5 13W 3,217.17 Rill 9.821.84 94.21 30244 6,41720 6,323.5 93124 393511 5,969,625.57 50,121.70 1042 3,24201 hill Y/iiUlL�]F� Babes 1� 0 MnDlation COMPASS 5000.14 Build e5 Annotation 7WR ff 1:40:51PM Platte COMPASS 500 f4 Bulki 65 ConocoPhillips COnocoPhilllps Definitive Survey Report Company: ConocePb011ps(Alaska) Ina-Kupt Local CoarOinale Reference: M11 lC-04 Project: Kup9mk River Unit WO Reference: 1C434@ 94.00usft(1604) Sea Kuparek lC Paid MO Reference: 1C-04®9400usft(1004) Well: 1C-04 North Reference: True Wellbore: 1C-04 Survey Calculation Method: Minimum Curvature Design: 1C-04 Database: EDT Alaska Sandbox Survey Map Nap Vertlaal MD Inc Poi WD TVDSS +WS +Bun NorOling Fa(to OLS Se(0) (usft) n) (°) (°I (.aft) (usft IDatl luanl (.1100) Sarney TaglWme IRI � (0) all'it 6 95.72 30126 6,41400 6320.00 9,15.86 -3,958.65 5,959,caa oa 550,09904 688 3.269.'4 Mosel (3) 9,87961 94.21 388.26 6,41220 6,31820 9244 -3,98345 5.959.6% 37 550,07411 17M 3,29778 MMR) (3) 9,9[9.51 94.52 30.39 8,409.93 6,315.9 90.31 4,007,31 5,959.67401 558.050.'0 391 3,326.81 Well (3) 9,939.75 9,76 31151 6,49 .95 63129 M42 <.03054 5,9l96 558,02672 1545 3,39.38 nova) (3) 9,97036 0.38 31623 6,403 19 639.19 1,021.41 -005238 S99)1377 558.00t 71 15.40 3,39.50 M (3) 9.99 .26 94.43 31910 6,400.17 63W 17 1,0429 4,OY2.09 5,959,73534 557,926,82 13.W 3,41575 MWD(3) 0,0300 92.50 Nate 6,398 31 6,30431 1,tt6.80 4,091.1] 5�,75a a 55],9554 13.78 3,446.05 MWD(3) 10,0599 9.44 32714 6.39.74 6,3@.]4 1,9001 4,'06,26 5,99.]82.69 55],94836 1461 3.4]5]3 MWD(31 ' 10,089.9 078 329.95 6,394,85 6303.85 1,115.57 4.1239 5.99,80 .32 97,932.,11 941 3,505.37 MM (3) 10,120.01 94.71 32676 6,392.62 6.2962 1.14108 4,1390 5959,033.59 9],91640 11.9 3535.01 MAR) (31 '0.150M i 59.31 321.57 63910 6,29783 1,16554 4,157.29 5959,65001 97,6981 2).2] 3,559.11 MWD(3) 10.18014 8]5] 31384 6392.9 6,29.90 1,18051 4,178.@ 59a'atio 2 97,0926 945 3,59.00 INA(3) 10,21022 0.94 31321 6,394.81 6300.61 1,21011 4,197.26 5,99,50.24 W7,8WV 1946 3624.9 MWO(3) t0,N051 89.0 311.33 6,39.8 6,301.72 1,230,47 4,219.9 599.922.41 9],835.]1 1432 365a 94 MWO(3) 10,2]026 9.9 316 t3 639.9 6,302.06 1,2510 4,241.15 5,989942.79 97,0149 1647 3,68450 MW0(3l 10,3100 Nil MIN 6,39.9 6302 58 1,27342 4,2&1.]4 5,969,984.0 54],]94.26 1612 3.71425 Minors) 10,3325] 07.85 32700 6,39745 6,3945 1,29965 4,27989 5.939991,28 97.]7512 170 3.]46.0 MrnD(3) 10.380.9 88.37 33175 639,35 6.304.35 1.323.51 4,29,6i 5970,014,63 97,7998 1661 3,]73.]6 MrYD(3) lo'nom 8603 3951 639,30 6.306 30 1300 430.38 "7004184 9],]4760 1501 3,80.99 Menial 10,420.45 99 33303 6,3965 8,3085 13700 4,31948 5,9]D.09.15 9].]00,68 12.47 383218 MMD(3) 10,450M 07.91 328.34 5.40002 8.3903 1.40,10 43350.9 5,970,099 557M0 an 3,85137 Mineola) 10480.36 San 324.28 5.46090 6,3(189 1429,15 4350.56 5.970,11999 9],791] 1377 3,89139 Media) ( 10,5'0.19 0770 319.23 6,40182 8,30]82 1,452.9 -435903 5,00,143.N 55],68452 17.30 3,9109 MNo(3) 10,540.9 87M 31361 64030 0,3090 1,4]4.1] 4,359.59 5,00,164.66 55T.653 78 1681 3.90.9 Mvorn 10,99.71 940 309.69 6426,11 6,310.11 1,4939 4411.]3 5,970,181.18 557,64149 13M 3,98) 17 Monti t0,6D3.R 91II 310.57 6,40408 6,3100 1,513.57 4,435.11 5.970.20359 557,61795 1123 401029 MMC) 1062613 94.61 30.25 6,40245 6,308.45 1532.23 4457.82 5,00,22216 557,5909 12.M 4,03 l8 MWo(3) 10.639.76 94.9 W752 0,40162 630762 1,538.30 4,464.72 5,970,22835 557,587.14 732 4,08.9 MM (3) 10,050 94 BB 3052 8,39.83 630962 1,559]5 4,4955 5.970$49.39 557,559.13 OW 4,063.24 PRWECTED IOTO Annotation 7WR ff 1:40:51PM Platte COMPASS 500 f4 Bulki 65 UGHES a GE company COMPANY ConocoPhillipsAlaska, IQE CI\ E WELL NAME 1C -04A AUP 1 2017 FIELD Greater Kuoaruk Area COUNTY North Slope Borough AOGCC BHI DISTRICT Alaska se sign and return one copy of this transmittal form to: DcoPhillips Alaska, Inc. V Elgarico. ATO 3-334. DATA LOGGED G Street. %11612017 M. K. BENDER ioraee. Alaska 99510 LOG TYPE GR - RES LOG DATE July 13, 2017 AUTHORIZED BY Patrick Rider EMAIL Patrick.Riderna bakerhuohes.corn TODAYS DATE August 8, 2017 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION IG FIELD 21 7078 FINAL BAER PRINT DISTRIBUTION LIST 2 1 4 8 9 UGHES a GE company COMPANY ConocoPhillipsAlaska, IQE CI\ E WELL NAME 1C -04A AUP 1 2017 FIELD Greater Kuoaruk Area COUNTY North Slope Borough AOGCC BHI DISTRICT Alaska se sign and return one copy of this transmittal form to: DcoPhillips Alaska, Inc. V Elgarico. ATO 3-334. DATA LOGGED G Street. %11612017 M. K. BENDER ioraee. Alaska 99510 LOG TYPE GR - RES LOG DATE July 13, 2017 AUTHORIZED BY Patrick Rider EMAIL Patrick.Riderna bakerhuohes.corn TODAYS DATE August 8, 2017 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION IG FIELD FINAL CD/DVD FINAL PRELIM (las, dlks, PDF, META, SURVEY I REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTSOr PRIN # OF COPIES # OF COPIES # OF COPIES 0 BP North Slope. Q Q Q Q Q EOA, PBOC, PRB-20 (Office 109) 1�D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. !Anchorage. Alaska 99508 2 !ConocoPhillips Alaska Inc. Atm: Ricky Elgarico ATO 3-344 700 G Street Anchorage, AK 99510 3 Exxon Mobil, Alaska Attn: Lynda M. Vaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 0 0 0 0 0 0 1 0 1 0 1 0 1 0 4 State of Alaska - AOGCC 0 1 1 1 0 Attn: Maisons Bender 333 W. 7th Ave, Alaska 10 — — Anchorage, Alaska 995011 5 DNR - Division ofOil & Gas -- 0 0 1 1 0 Ann: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 L.. Stamp "confidential" on all material deliver if, DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd Anchorage, Alaska 99508 0 1 1 1 1 1 1 10 TOTALS FOR THIS PAGE: 0 2 3 3 0 ConocoPhillips RECEIVED AUG 1 1 2017 AOGCC ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1C Pad 1 C -04A 50-029-20547-01 Baker Hughes INTEQ Definitive Survey Report 27 July, 2017 21 7078 28489 BA ER F�UGHES a GE Company ConocoPhillips �ycuE"G1fFs w. ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc.-Kupl Local Coordinate Reference: Well 1C-04 Project: Kupamk River Unit TVD Reference: 1C-04 Q 94,00usft (1C-04) Site: Kupamk 1C Pad MD Reference: IC -04 @ 94.00usft (IC -04) Well: 1C-04 North Reference: True Wellbore: 1 C-04 Survey Calculation Method: Minimum Curvature Design: 1 C-04 Database: EDT Alaska Sandbox project Kupamk 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 1C-04 Well Position +N/ -S 0.00 usft Northing: 5.968,727.00usft Latitude: 70° 19' 30.322 N +E1 -W 0.00 usft Easting: 562,065.00usft Longitude: 149' 29'48.207 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wallbore iC-04A Magnetics Model Name Sample Date Declination Dip Angle Field Strength f) P) lnT) BGGM2016 8/1/2017 17.55 80.95 57.542.29 Design 1C -04A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,122.00 Vertical Section: Depth From (TVD) -NIS +EI -W Direction (usft) (usft) (usft) (1) 33.50 0.00 0.00 320.00 Survey Program Date 7/13/2017 Survey Survey From (usft) To (usft) Survey (Wellbore) Toot Name Description Start Date End Date 100.00 7,122.00 1C-04 (1C-04) BOSS -GYRO Sperry -Sun BOSS gyro multishot 8/25/2000 7,125.50 7,175.87 1C -04A MWD -INC (1 C -04A) MWD-INC—ONLY MWD-INC—ONLY—FILLER 7/2/2017 7/3/2017 7,205.86 10,639.78 1C -04A MWD (1 C -04A) MWD MWD -Standard 7/3/2017 7/9/2017 Page 2 COMPASS 5000.14 Buid 85 7/27/2017 1:40:51PM ConocoPhillips 8A) ER ConocoPhilli S p jUGHES Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Coordinate Reference: Well 1C-04 Project: Kuparuk River Unit TVD Reference: 1604 @ 94.00usft (1C-04) Site: Kuparuk 1C Pad MD Reference: 1C-04 @ 94.00usft (1C-04) Well: 1C-04 North Reference: True Wellbore: 1C-04 Survey Calculation Method: Minimum Curvature Design: 1C-04 Database: EDT Alaska Sandbox Survey Map Map Vertical MD Inc An TVD ND55 +WS +EbW (usft) (°) (°) (usR) (usk) (asR) (usk) Northing Ending1705 01100') Seckon Surve Tool Name Y .Annotation (ft) (k) (ft) - 7,122.00 4.00 319.00 6,444.06 6,350.06 -198.21 -2,482.95 5,968,508.28 559,584.01 5.00 1,444.17 MW -INC _ONLY (2) TIP 7,125.50 3.83 319.00 6,447.55 6,353.55 -198.03 -2,483.10 5,968,508.46 559.583.86 4.86 1,444.41 MWD4NC ONLY (2) KOP 7,146]2 4.73 234.32 6,46873 6.374.73 -198.01 -2.484.28 5,968,508.47 559,582.68 27.34 1,445.18 MM -INC -ONLY (2) Interpolated Azimuth 7,175.87 18.18 219.32 6,497.24 6,403.24 -202.25 -2,488.16 5,968,504.20 559,578.84 46.88 1,444.43 MWD-INC_ONLV(2) Interpolated Azimuth 7.205.86 33.24 215.16 6,524.18 6,430.18 -212.65 -2,495.90 5,968,493.74 559,571.18 50.55 1,441 44 MWD (3) First Good Survey 7,236.11 4].48 218.91 6,547.18 6,453.18 -228.18 -2,507.74 5,968,478.11 559,559.47 47.74 1.437.15 MWD (3) 7,266.01 61.41 221.16 6,564.52 6,470.52 -246.73 -2,523.38 5,968,459.43 559,543.99 46.98 1,432.99 MIND (3) 7,29574 75.58 22277 6,575.40 6,481.40 -267.23 -2,541.84 5,968,43878 559.525.70 47.93 1429.15 MWD (3) 7,326.27 91.07 223.82 6,578.93 6,484.93 - -289.23 -2,562.57 5,968,416.61 559,505.15 50.85 1425.63 MWD (3) 7,356.08 95.44 222.86 6,577.24 6,483.24 -310.87 -2,582.99 5.968,394.81 559,484.91 15.01 1,422.18 MM (3) 7,386.15 99.25 22078 6,573.40 6,479.40 433.09 -2,602.88 5,968372.43 559,465.21 14.41 1,417.94 MWD (3) 7,418.26 100.07 225.10 6,568.01 6,474.01 J56.26 -2.624.44 5,968,349.08 559,443.85 13.51 1,414.05 MWO(3) 7,454.22 100.69 230.98 6,561.52 6,467.52 379.90 -2,65072 5,968,325.23 559,417.76 1618 1,412.83 MM (3) 7,485.87 100.82 234.97 6.555.61 6,461.61 -398.62 -2,675.54 5,968.306.31 559,393.10 12.39 1,414.45 MWO(3) - 7,514.99 100.31 239.19 6,550.27 6,456.27 414.17 -2,699.57 5,968,290.56 559,369.21 14.35 1,417.98 MWD (3) 7,545.29 100.54 243.76 6,544.79 6,450.79 428.40 -2,725.74 5,968,276.12 559,343.15 14.85 1,423.90 MWD 13) 7,577.41 10698 249.23 6,538.79 6,444.79 440.98 -2,754.67 5,968,263.30 559,314.34 16.79 1432.86 MWD (3) 7,604.52 100.63 252.92 6,533.70 6,439.70 -449.61 -2,779.85 5,968,254.46 559,289.23 13.43 1,442.43 MWD (3) 7,634.83 100.59 258.60 6,528.12 6,434.12 456.94 -2,808.72 5,968,246.89 559,260.43 18.42 1,455.37 MWD (3) - 7,664.91 101.06 262.51 6,522.46 6,428.46 461.79 -2,837.85 5,968,241.80 559231.33 12.86 1,470.39 MM (3) 7,695.10 101.47 267.10 6,516.56 6,422.56 464.47 -2,857.33 5,968,238.88 559,201.88 14.97 1,487.28 MM (3) 7,724.83 101.95 270.97 6,510.53 6,416.53 464.96 -2,896.43 5,968,238.15 559,172.79 12.85 1,505.61 MWD (3) 7,755.12 101.48 275.02 6.504.38 6,410.38 463.41 -2,926.05 5,968,239.45 559,143.17 13.18 1,525.83 MM (3) 7,784.88 1W.97 279.19 6.498.58 6,404.58 459.80 -2,955.00 5,968,242.82 559,114.18 13.85 1,547.21 MWD (3) 7,815.17 101.95 275.92 6,492.56 6,398.55 455.89 -2,984.43 5,968,246.48 559,084.73 11.06 1,569.12 MWD (3) 7,845.03 102.64 272.91 6,486.20 6,392.20 453.65 $,013.51 5,968,248.49 559,055.63 10.12 1,589.53 MM (3) 7,875.17 101.44 269.59 6,479.91 6,365.91 453.01 J.042.98 5,968,248.89 559,026.16 11.48 1,608.97 MM (3) 7,904.55 101.57 266.69 6.474.05 6,380.05 453.94 -3,071.75 5,968,247.71 558,997.40 9.68 1,626.74 MWD (3) 7,935.14 100.85 263.19 6468.10 6,374.10 456.59 -3,101.63 5,968,244.82 558,967.55 11.47 1,643.93 MWD (3) 7,965.33 100.59 260.86 6,462.49 6,368.49 460.70 -3,131.01 5,968,240.46 558,938.21 7.63 1,659.65 MWD (3) 7/272017 1:40:51PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips Bq* ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1C-04 Project: Kuparuk River Unit TVD Reference: 1 C-04 @ 94.00usft (1 C-04) Site: Kuparuk 1C Pad MD Reference: 1 C-04 @ 94.00usft (1C-04) Well: 1C-04 North Reference: True Wellbore: 1C-04 Survey Calculation Method: Minimum Curvature Design: 1C-04 Database: EDT Alaska Sandbox Survey 7/2712017 1:40:51PM Page 4 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/ -W Northing Easting DLS Section Survey Toot Name Annotation (usrt) P) V) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) 7,995.13 98.85 258.36 6457.45 6,363.45 466.00 -3,159.89 5,968,234.93 558,909.37 10.12 1,674.16 MM (3) 8,025.31 98.12 25B.99 6,453.00 6,359.00 471.86 -3,189.16 5,968,228.82 558,880.15 3.18 1,688.49 MWD (3) 8,055.07 98.26 265.15 6,44876 6,354.76 -475.92 -3,218.32 5,968,224.52 558,851.03 20.49 1,704.12 MWD (3) 80B5.37 98.07 270.14 6,444.45 6,350.45 477.16 -3,248.28 5,968,223.04 558.821.09 16.31 1,722.43 MWD(3) 8,115.15 97.20 275.15 6,490.49 6,346.49 475.79 -3,277.75 5,968,224.16 558,791.61 16.93 1,742.42 MWD (3) 8145.51 97.08 280.01 6,436.72 6,342.72 471.82 -3,307.61 5,968,227.89 558,761.72 15.89 1,764.65 MWD (3) 8,175.15 97.64 284.05 6,432.92 6,338.92 -465.70 -3,336.35 5,968.233.77 558,732.93 13.65 1,787.82 MWD (3) 8,206.05 96.83 288.56 6,429.02 6,335.02 457.09 -3,365.76 5,968,242.13 558,703.45 14.71 1,813.32 MM (3) 8,235.01 95.57 293.08 6,425.90 6,331.90 446.86 3,392.67 5,968,252.14 558,676.47 16.11 1,838.45 MM (3) 8,265.63 91.81 297.02 6,423.92 6,329.92 433.92 41,420.34 5,968,264.89 558,648.70 17.77 1,866.14 MAID (3) 8,295.49 91.85 302.19 6,422.97 6,328.97 419.19 -3,446.28 5,968,279.37 558,622.64 17.31 1,894.11 MWD (3) 8,324.70 91.75 306.12 6,422.05 6,328.05 402.80 -3,470.43 5,968,295.55 558,598.35 13.45 1,922.19 MWD(3) 8,354.83 93.10 310.56 6420.78 6,326.78 -384.13 -3.494.04 5,968,314.02 558,574.59 15.39 1,951.66 MWD(3) 8,384.75 93.65 314.85 6,419.01 6,325.01 -363.88 -3,515.98 5,968,334.09 558,552.49 14.43 1,981.28 MM (3) 8414.96 90.61 316.78 6,417.89 6,323.89 -342.23 -3,537.02 5,968,355.56 558,531.27 11.92 2,011.39 MWD(3) 8,444.99 90.22 318.81 6,417.67 6,323.67 -319.99 3,557.19 5,968,377.63 558,510.92 6.88 2,041.39 MWD (3) 8,474.45 90.89 320.60 6,417.39 6,323.39 -297.52 -3,576.24 5,968,399.94 558491.68 6.49 2.070.85 MWD(3) 8,504.95 93.44 324.37 6,416.24 6,322.24 -273.35 -3,594.80 5,968,423.95 558,472.93 14.91 2,101.29 MWD (3) 8,535.54 93.90 328.96 6,414.28 6,320.28 -247.86 -3611.57 5,968,449.31 558.455.95 15.05 2,131.60 MM (3) 8,565.86 92.86 334.19 6,412.49 6,318.49 -221.25 -3,625.97 5,968,475.79 558,441.33 17.56 2,161.24 MM (3) 8,595.09 91.57 339.39 6,411.36 6,317.36 -199.41 -3,637.48 5,968,502.53 558,429.60 18.32 2.189.20 MWD(3) 8625.41 90.06 342.08 6,410.93 6,316.93 -165.80 -3,697.48 5,968.531.05 55B,419.37 10.17 2,217.55 MWD (3) 8,655.02 92.12 349.92 6410.36 6,316.36 -137.10 -3,654.63 5,968,559.70 558,411.97 27.37 2,249.13 MM (3) 8,685.00 90.09 353.83 6,409.78 6,315.78 -107.43 -3,658.87 5,968,589.33 558.407.49 14.69 2,269.58 MWD(3) 8,715.39 91.44 0.48 6,409.38 6,315.38 -77.10 -3,660.38 5,968,619.64 558,405.74 22.33 2,293.79 MWD (3) 8,745.21 88.52 4.61 6,409.39 6,315.39 47.32 -3659.05 5,968,649.43 558,406.81 16.96 2,315.75 MAID (3) 8,775.12 89.17 4.42 6,409.99 6,315.99 -17.51 -3,656.70 5,968.679.26 558,408.92 - 2.26 2,337.07 MWD(3) 8,805.04 90.98 2.40 6,409.95 6,315.95 12.36 -3,654.92 5,968,709.13 558410.45 9.06 2,358.80 MWD(3) 8,834.72 86.71 359.52 6,410.55 6,316.55 42.02 41,654.42 5,968,738.79 558,410.70 17.35 2,381.21 MWD(3) 8,864.69 84.81 355.70 6,41277 6318.77 71.87 3.655.67 5,968,768.63 558,409.21 14.20 2,404.88 MWD(3) 8,895.65 85.11 350.77 6,415.49 6,32149 10249 -3.659.30 5,968,799.21 55840533 15.89 2,430.66 MM (3) 7/2712017 1:40:51PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillipsR �i`WE ConocoPhillips p s Definitive Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1C-04 Project: Kuparuk River Unit TVD Reference: 1C-04 Q 94.00usft (1C-04) Site: Kuparuk 1C Pad MD Reference: 1C-04 Q 94.00usft (1C-04) Well: 1C-04 North Reference: True Wellbore: 1C-04 Survey Calculation Method: Minimum Curvature Design: 1C-04 Database: EDT Alaska Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S -Ef-Vv DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (=1100' ) Section Survey Tool Name Annotation (ft) (ft) (ft) 8,925.17 88.31 351.05 6,417.18 6,323.18 131.59 -3,663.95 5,968,828.27 558,400.43 10.88 2.455.95 MWD (3) 8,954.91 90.67 347.33 6,41245 6,323.45 160.79 -3,669.53 5,968,857.42 558,394.62 14.81 2,481.90 MWD (3) 8.985.17 88.40 345.46 6,417.69 6,323.69 190.20 -3,676.65 5,968,886.77 558,387.26 9.72 2,509.00 MWD (3) 9,014.48 87.39 348.47 6,418.77 6,324.77 218.73 -3,683.25 5,968,915.24 558,380.42 10.83 2,535.11 MIND (3) 9,095.21 87.70 352.51 6,420.09 6,326.09 249.00 -3,688.32 5,968,945.47 558,375.09 13.17 2,561.56 MWD (3) 9,074.95 91.96 354.55 6.420.17 6,326.17 278.55 3,691.67 5,968,974.98 558,371.50 15.88 2,586.34 MWD(3) 9,104.57 94.09 358.09 6,418.61 6,324.61 308.06 -3,693.57 5,969,004.47 558,369.36 13.93 2,610.17 MM (3) 9,134.63 94.92 3.90 6,416.25 6,322.25 338.01 -3,693.05 5,969,034.42 558,369.63 19.46 2,632.78 MWD (3) 9,165.13 92.40 8.24 6.414.30 6,320.30 368.26 -3,689.84 5,969,064.70 558,372.60 16.43 2,653.89 MM (3) 9,194.61 89.63 9.77 6,413.78 6,319.78 397.37 -3,685.22 5,969,093.84 558,376.97 10.73 2,673.22 MWD (3) - 9,225.03 86.44 7.36 6.414.82 6,320.82 427.43 -3,680.69 5,969,123.93 558,381.25 13.14 2,693.33 MM (3) 9,254.53 88.16 3.69 6,416.21 6,322.21 456.75 -3,677.86 5,969,153.28 558,383.84 13.73 2,713.97 MWD (3) 9,284.97 89.20 359.55 6,416.91 6.322.91 487.17 -3,677.00 5,969,1 B3.69 558,384.45 14.02 2,736.72 MM (3) $318.23 90.80 355.80 6,416.91 6,322.91 520.39 3,678.35 5,969,216.90 558,382.83 12.26 2,763.04 MWD (3) 9,344]8 94.45 354.28 6,415.70 6,321.70 546.81 3,680.64 5,969,243.30 558,380.32 14.89 2,784.75 MWD (3) 9,375.11 89.91 350.51 6,414.54 6,320.54 576.84 3,684.65 5,969,273.29 558,376.06 19.45 2,810.33 MM (3) 9,405.02 87.97 346.81 6,415.10 6,321.10 606.15 3,690.53 5,969,302.55 558,369.94 13.97 2,836.57 MM (3) _ 9,434.93 88.65 342.72 6,415.98 6,321.98 634.99 -3,698.38 5,969,331.32 558,361.84 13.86 2,863.71 MM (3) 9,464.93 88.80 338.42 6.416.65 6,322.65 663.27 -3,708.38 5.969,359.51 558,351.64 14.34 2,891.78 MWD (3) 9,494.92 87.30 334.86 6,417.67 6,323.67 690.78 x720.24 5,969,386.92 558,339.53 12.87 2,920.49 MWD (3) 9,524.81 87.27 331.17 6,419.08 6,325.08 717.38 3,733.79 5,969,413.41 558,325.77 12.33 2.949.58 MWD (3) 9,554.68 87.55 327.86 6,420.49 6,326.44 743.26 -3,749.02 5,969,439.16 558,310.32 11.04 2,979.20 MWD (3) 9,584.86 90.00 325.26 6.421.08 6,327.08 768.27 -3,765.54 5,969,464.03 558,293.60 11.91 3,008.97 MWD (3) 9,614.82 90.71 322.83 6,420.90 6,326.90 792.52 -3,783.13 5,969,488.13 558,275.81 8.45 3,038.85 MWD(3) 9,645.04 90.58 320.02 6,420.56 6,326.56 816.14 -3,801.97 5,969,511.59 558,256.78 9.31 3,069.06 MWD (3) 9,675.23 90.52 316.72 6,420.27 6,326.27 838.70 -3,822.02 5,969,533.99 558,236.54 10.93 3,099.23 MWD (3) 9.705.04 90.28 313.94 6,420.06 6,326.06 859.90 -3,842.97 5,969,555.01 558,215.41 9.36 3,128.94 MM (3) 9,734.84 90.25 310.68 6,419.92 6,325.92 879.96 -3,865.01 5,969,574.88 558,193.22 10.94 3,158.47 MWD (3) 9,764.75 91.60 307.91 6,419.44 6,325.44 898.90 3,888.15 5.969,593.62 558,169.92 10.30 3,187.85 MWD l3) _ 9,795,01 91.66 303.77 6,41858 6,324.58 916.60 3,912.66 5,969,611.13 558,145.26 13.68 3,217.17 MIND (3) 9,821.84 94.21 30244 6,417.20 632320 931.24 -3,935.11 5,969,625.57 558,122.70 10.72 3,242.81 MV (3) 7727/2017 1:40'S1 PM Page 5 COMPASS 5000.14 Build 85 Survey ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConowPhillips(Alaska) Inc.-Kupl Local Co-ordinate Reference: Well 1C-04 Project: Kuparuk River Unit TVD Reference: 1C-04 @ 94.00usft (1C-04) Site: Kuparuk 1C Pad MD Reference: 1C-04 @ 94.00usft (1C-04) Well: 1C-04 North Reference: True Wetlbore: 1C-04 Survey Calculation Method: Minimum Curvature Design: 1C-04 Database: EDT Alaska Sandbox Survey Annotation BA ER I�WHES 7/2712017 1:40:51PM Page 6 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD NDSS iN/S -E/-W Northing Easting DLS Section Survey Tool Name (usft) V) (°I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) 9849.66 95.72 301.26 6.414.80 6,320.80 945.86 -3,958.65 5,939,640.00 558,099.04 6.88 3,269.14 MWD (3) 9,879.61 94.21 306.26 6,412.20 6,318.20 962.44 3,983.45 5,969,655.37 558,074.11 17.38 3,297.78 MND (3) 9,909.51 94.52 307.39 6,409.93 6,315.93 980.31 4,007.31 5.969,674.04 558,050.10 3.91 3,326.81 MWD (3) 9,939.75 96.76 311.51 6,406.95 6,312.95 999.42 -0,030.54 5,969,692.96 558,026.72 15.45 3,356.38 MWD(3) 9,970.28 97.38 316.23 6,403.19 6.309.19 1,020.41 4.052.38 5,969,713.77 558,004.71 15.48 3,386.50 MM (3) 9,999.72 94.43 319.10 6,400.17 6,306.17 1,042.06 4,072.09 5,969,735.24 557,984.82 13.94 3,415.75 MWD (3) 10,030.09 92.58 322.86 6.398.31 6,30431 1,065.60 4,091.17 5,969,758.63 557,965.54 13.78 3,446.05 MND (3) 10,059.93 93.44 327.14 6,396.74 6,302.74 1,090.01 4,108.26 5,969,782.89 557,948.26 14.61 3,475.73 MM (3) 10,089.96 93.78 329.95 6,394.85 6,300.85 1,115.57 4,123.90 5,969,808.32 557,932.41 9.41 3.505.37 MWD (3) 10,120.01 94.71 326.76 6,392.62 6,298.62 1,141.08 4,139.62 5,969,833.69 557,916.48 11.03 3,535.01 MWD(3) 10,150.22 88.31 321.57 6,391.83 6,297.83 1,165.54 4,157.29 5,969,858.01 557898.61 27.27 3.565.11 MWD (3) 10,180.14 87.57 31 B.84 6,392.90 6,298.90 1,188.51 4,176.42 5,969,880.82 557879.29 9.45 3,595.00 MWD (3) 10,210.22 85.94 313.21 6,394.61 6,300.61 1,210.11 4,197.26 5,969,902.24 557,858.27 19.46 3,624.95 MWD (3) 10,240.51 89,85 311.33 6,395.72 6,301.72 1,230.47 4,219.66 5,969,922.41 557,835.71 14.32 3,654.94 MND (3) 10,270.26 Sees 316.13 6,396.06 6,302.06 1,251.03 4,241.15 5,969,942.79 557814.06 16.47 3,684.50 MWD (3) 10,300.03 89.11 321.52 6,396.58 6,302.58 1,273.42 4,260.74 5,969,955.02 557,794.28 18.12 3,714.25 MND (3) 10,332.57 87.85 327.21 6,397.45 6,303.45 1,299.85 4,279.68 5,969,991.28 557,775.12 17.90 3,746.67 MWD (3) 10.360.06 88.37 331.75 6,398.35 6,304.35 1323.51 4,293.63 5,970,014.83 557,760.98 16.61 3,773.76 MWD (3) 10,390.23 88.03 336al 6,393.30 6,305.30 1,350.63 4,30678 5,970,041.84 557,747.60 15.81 3,802.99 MWD (3) 10,420.45 90.65 333.80 6,399.65 6,305.65 1,378.05 4,319.48 5,970,069.15 557,734.68 12.47 3,832.16 MWD (3) 10,450.23 87.91 328.34 6,400.02 6,306.03 1,404.10 4,333.88 5.970,095.08 557,720.07 20.51 3,861.37 MWD 13) 10,480.36 88.77 324.28 6,400.90 6,306.90 1,429.15 4,350.58 5,970,119.99 557,703.17 13.77 3,891.29 MND (3) 10,510.19 87.70 319.23 6,401.82 6,307.82 1,452.56 4,359.03 5,970,143.24 557,684.52 17.30 3.921.09 MWD (3) 10,540.06 87.54 313.61 6,403.06 6,309.06 1,474.17 4,389.59 5,970,164.68 557,663.78 18.81 3,950.86 MWD(3) 10,569.71 88.40 309.69 6,404.11 6,310.11 1,493.86 4,411.73 5,970.184.18 557,641.49 13.53 3,980.17 MM (3) 10,600.29 91.72 310.57 6,404.08 6,310.08 1,513.57 4435.11 5,970,203.69 557617.95 11.23 4,010.29 MWD (3) 10,629.73 94.61 308.25 6,402.45 6,308.45 1,532.23 4,457.82 5,970,222.16 557,595.09 12.58 4,039.18 MWD (3) 10,639.78 94.88 307.52 6,401.62 6,307.62 1,538.38 4,465.72 5,970,228.25 557,587.14 7.72 4,048.98 MND (3) 10,675.00 94.88 307.52 6,398.62 6,304.62 1559.75 4,493.55 5,970,249.39 557,559.13 0.00 4,083.24 PROJECTEDto TD Annotation BA ER I�WHES 7/2712017 1:40:51PM Page 6 COMPASS 5000.14 Build 85 Letter of Transmittal BAER V.'PGS" Date' DATA LOGGED UGHES C'J�F July 28, 2017 m K BENDER JUL 31 2017 a GE company A nr rf% To: Makana Bender AOGCC 333 West 711 Ave, Suite 100 Anchorage, Alaska 99501 From: Yosha Ragbirsingh / Michael Soper Baker Hughes, a GE Company 795 East 9411 Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 1G-15AP131 2 1 7 0 6 5 28 4 5 1 1G -15A 2 1 7 0 65 2 8 4 5 0 1G-15AL1 2 1 70 70 2 8 4 5 2 1G-15AL2 2 1 70 7 1 28 4 5 3 IC -04A 2 1 70 78 28 4 4 8 1C -04A L1 2 1 7 0 8 3 28 4 4 9 (6) Total prints CD in 217-078 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 ConocoPhillips RECEIVED JUL 31 29V A®GCC ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1C Pad IC -04A 50-029-20547-01 Baker Hughes INTEQ Definitive Survey Report 27 July, 2017 BAER UGHES a GE company 21 7078 28448 \\§a3 666 \0 \00 el ;\! ;12 (0||+[ } \° \� A� �` _5 _ , m0v ! |`� \ } , 2\ }[ \ \�|f } _ ;\! ;12 \ \ � (0||+[ } \° \� A� �` _5 _ , \ } , 2\ }[ \ } _ ) ` tE{ \ \ � (0||+[ } \° \� A� �` _5 \ } 2\ . \ \ � � e (0||+[ } \° \� �` � e ConocoPhillips ConocoPhillip5 Definitive Survey Report f u NEs Company: ConowPhilhps (Alaska) Inc. -Kupt Project: Kuparuk River Unit Site: Kuparuk 1C Pad Well: 1C-04 Wellbore: 1C-04 Design: 1C-04 -2,482.95 5,968,508.28 559,584.01 5.00 p3 Survey Y 5,968,50846 MD Inc Azl TVD TVDSS +W -S (usft) 7,122.00 7,125.50 7,146.72 7,175.87 7,205.86 7,236.11 7,266.01 7,295.74 7,326.27 7,356.08 7,386.15 7,418.26 7,454.22 7,485.87 7,514.99 7,545.29 7,577.41 7,604.52 7,634.83 7.664.91 7,695.10 7,72483 7,755.12 7,784.88 7,815.17 7,845.03 7,875.17 7,90455 7,935.14 7,965.33 V) 4W 3.83 4.73 18.18 33.24 4748 61.41 75.58 91.07 95.44 99.25 100.07 100 69 100.82 100.31 100.54 100.98 100.63 100.59 101.06 101.47 101.95 101.48 100.97 10195 102.64 101.44 101.57 100.85 100.59 (1) 319.00 319.00 234.32 219.32 215.16 218.91 221.16 222.77 223.82 222.85 220.78 225.10 230.98 234.97 239.19 243.76 249.23 252.92 25860 262.51 267.10 270.97 275.02 279.19 275.92 272.91 26959 266.69 263.19 260.86 (usft) 6,444.06 6,447.55 6,468.73 6,497.24 6,524.18 6,547.18 6,564.52 6,575.40 6,578.93 6,57].24 6,573.40 6,568.01 6,561.52 6,55561 6,55027 6,544.79 6,538.79 6,533.70 6,528.12 ,52246 6,516.56 6,510.53 6,504.38 6,498.58 6,492.56 6,48620 6,479.91 6,474.05 6,468.10 6,46249 (usft) 6,350.06 6,353.55 6,374]3 6,403.24 6,430.18 6,453.18 6,470.52 6,48140 6,484.93 6,483.24 6,479.40 6,474.01 6,467.52 6,461,61 6,456.27 6,450.79 6,444.79 6,439.70 6,434.12 6,428.46 6,422.56 6,416.53 6,410.38 6,404.58 6,398.56 6,392.20 6,385.91 6,3.05 6,374.10 6,36849 (usft) -198.21 -198.03 -198.01 -202.25 -212.65 -228.18 -246.73 -267.23 -289.23 -310.87 -333.09 -356.26 -379.90 .398.62 -014.17 -428.40 -440.98 -049.61 456.94 -461.79 -064.47 464.96 -463.41 459.80 455.89 453.65 453.01 453.94 456.59 460.70 Local Co-ordinate Reference: Well 1C-04 ^+ TVD Reference: 1C-04 @ 94.00usft(1C-04) MO Reference: 1C-04 @ 94.00usft (1C-04) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT Alaska Sandbox Vertical Section Survey Tool Nam, (ft) 1,444.17 MWD-INC-ONLY(2) 1,444.41 MWD.INC_ONLY (2) 1,445.18 MWD-INC_ONLY (2) 1,444.43 MWD-INC_ONLY (2) 1,441.44 Ill (3) 1,437.15 MM (3) 1,432.99 MM (3) 1,429.15 MM (3) 1,425.53 MWD (3) 1,422.18 MWD (3) 1,417.94 MWD(3) 1,414.05 MWO(3) 1,412.83 Ml (3) 1,414.45 MM (3) 1,417.98 MM (3) 1,423.90 Ml (3) 1,432.86 MWD(3) 1,44243 MWD(3) 1,455.37 MWD(3) 1,470.39 MWD (3) 1,487,28 MM (3) 150561 MWD(3) 1,525.83 MWD(3) 1,547.21 MWD (3) 1,559.12 MWD(3) 1,58953 MWD (3) 1,608.97 MWD (3) 1,626.74 MWO(3) 1,643.93 MWD(3) 165965 MWD (3) Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth i First Good Survey 7/2712017 1:40:51 PM Page 3 COMPASS 5000.14 Build 85 Map Map +E/ -W Northing Easting DLS (usft) (ft) (ft) (°/100') -2,482.95 5,968,508.28 559,584.01 5.00 -2,483.10 5,968,50846 559,583.86 4.86 .2,484.28 5,968.50847 559,582.68 27.34 .2,488.16 5,968,50420 559,578.64 46.88 -2,495.90 5,968,49374 559,571.18 50.55 -2,507.74 5,966,478.11 559,559.47 47.74 -2,523.38 5,968,459.43 559,543.99 46.98 -2,541.84 5,968,43878 559,525.70 47.93 -2,562.57 5,96,416.61 559,505.15 50.85 -2,582.99 5,968.394.81 559,484.91 15.01 -2,602.88 5,968,372.43 559,465.21 14.41 -2,624.44 5,968,349.08 559,443.85 13.51 -2,650.72 5,968,325.23 559,417.76 16.18 -2,675.54 5,968,306.31 559,393.10 12.39 -2,699.57 5,968,290.56 559,369.21 14.35 -2,725.74 5,968,276.12 559,343.15 14.85 -2,754.67 5,968,263.30 559,314.34 16.79 -2,779.85 5,968,254.46 559,289.23 13.43 -2,808.72 5,968,246.89 559,260.43 18.42 -2,837.85 5,968,241.80 559,23133 12.86 -2,867.33 5,968,238.88 559,201.88 14.97 -2,896.43 5,968,238.15 559,172.79 12.85 -2,926.05 5,968,239.45 559,143.17 13.18 -2,955.00 5,968,242.82 559,114.18 13.85 -2,984.43 5,96,246.48 559,064.73 11.06 -3,013.51 5,968.248.49 559,055.63 10.12 -3,042.98 5,968,248.89 559,026.16 11.48 -3,071.75 5,968,247.71 558,997.40 9.68 -3,101.63 5,968,244.82 558,967.55 11.47 -3,131.01 5,968,240.46 558,93821 7.63 Vertical Section Survey Tool Nam, (ft) 1,444.17 MWD-INC-ONLY(2) 1,444.41 MWD.INC_ONLY (2) 1,445.18 MWD-INC_ONLY (2) 1,444.43 MWD-INC_ONLY (2) 1,441.44 Ill (3) 1,437.15 MM (3) 1,432.99 MM (3) 1,429.15 MM (3) 1,425.53 MWD (3) 1,422.18 MWD (3) 1,417.94 MWD(3) 1,414.05 MWO(3) 1,412.83 Ml (3) 1,414.45 MM (3) 1,417.98 MM (3) 1,423.90 Ml (3) 1,432.86 MWD(3) 1,44243 MWD(3) 1,455.37 MWD(3) 1,470.39 MWD (3) 1,487,28 MM (3) 150561 MWD(3) 1,525.83 MWD(3) 1,547.21 MWD (3) 1,559.12 MWD(3) 1,58953 MWD (3) 1,608.97 MWD (3) 1,626.74 MWO(3) 1,643.93 MWD(3) 165965 MWD (3) Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth i First Good Survey 7/2712017 1:40:51 PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips 13 ER ConocoPhilli S OGRES p Definitive Survey Report sE�, hM Company: ConocoPhillips (Alaska) Inc. -Kupl Project Kuparuk River Unit Site: Kuparuk 1 C Pad Well: 1C-04 Wellbore: 1C-04 Design: 1C-04 Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1C-04 1C-04 @ 94.00usR (1C-04) 1C-04 @ 94.00usft (1C-04) True Minimum Curvature EDT Alaska Sandbox 72712017 1:40:51PM Page 4 COMPASS 5000.14 Build 86 Map Map Vertical - MD Inc Azi TVD TVDSS +Ni -S -E/.W DLS (usft) (1 (1) (usft) (usft) (usft) (usft) Northing Easting (°1100') Section Surve Tool Name ' y Annotation (ft) (ft) (ft) 7,995.13 98.85 258.36 6,45745 6,363.45 -46660 -3,159.89 5,968,234.93 558,909.37 10.12 1,674.16 MWD (3) 8,025.31 98.12 25899 6,453.00 6,359.00 471.86 -3,189.16 5,968,228.82 558,880.15 3.18 168849 MWD(3) , 8,055.07 98.26 265.15 6,448.76 6.354.76 475.92 -3,218.32 5,968,224.52 558,851.03 20.49 1,704.12 MAD (3) 8,085.37 98.07 270.14 6,444.45 6,350.45 477.16 -3,248.28 5,968,223.04 558,821.09 16.31 1,722.43 MM (3) 8,115.15 97.20 275.15 6,440.49 6,346.49 475.79 -3,277.75 5,968,224.16 558,79161 16.93 1,74242 MWD(3) 8,145.51 97.08 280.01 6,43672 6,342.72 471.82 -3,30]61 5,968,227.89 558,761.72 15.89 176465 MWD (3) 8,175.15 97.64 284.05 6,432.92 6,338.92 165.70 -3,336.35 5,968,233.77 558,732.93 13.65 1787.82 MM (3) 8,206.05 96.83 288.56 6,429.02 6,335.02 457.09 3,365.76 5,968,242.13 558,703.45 14.71 1,813.32 MWD (3l 8,235.01 95.57 293.08 6,425.90 6,331.90 446.86 -3,392.67 5,968,252.14 558,676.47 16.11 1,83845 MWD (3) i 8,265.63 91.81 297.02 6,423.92 6,329.92 -433.92 -3,420.34 5,968,264.84 558,64870 17.77 1,865.14 MWD (3l 8,295.49 91 85 302.19 6,422.97 6,328.97 419.19 -3,446.28 5,968,279.37 558,622.64 17.31 1,894.11 MWD (3) 8,324.70 9175 306.12 6,422.05 6,328.05 402.80 -3,470.43 5,968,295.55 558,598.35 13.45 1,922.19 MWD (3) 8,354.83 93.10 310.56 6,420.78 6,326.76 -384.13 -3,494.04 5,968,314.02 558,574.59 15.39 1,951.66 MWD(3) 8,38475 93.65 314.85 6,419.01 6,325.01 -363.88 -3,515.98 5,968,334.09 558,552.49 14.43 1,98L28 MM (3) 8,414.96 90.61 316.78 6,417.89 6,323.89 -342.23 -3,537.02 5,968,355.56 558,531.27 11.92 2,011.39 MWD (3) 8,444.99 90.22 318.81 6,417.67 6,323.67 319.99 -3,557.19 5,968,37763 558,510.92 6.88 2,041.39 MM (3) 8,474.45 90.89 32060 6,41739 6,323.39 -297.52 -3,576.24 5,968,399.94 558,491.68 6.49 2,070.85 MWD (3) 8,504.95 9344 324.37 6,416.24 6,322.24 -273.35 -3,594.80 5,968,423.95 558,47293 14.91 2,101.29 MM (3) 8,535.54 93.90 328.96 6,414.28 6,320.28 -247.86 -3,611.57 5,968,449.31 558,455.95 15.05 2,131.60 MWD(3) 8,565.86 92.86 334.19 6,412.49 6,318.49 -221.25 -3,625.97 5,968,47579 558,441.33 17.56 2,161.24 MWD (3) 8,595.09 91.57 339.39 6,411.36 6,317.36 -19441 -3,637.48 5,968,502.53 558,42960 18.32 2,189.20 MM (3) 8,625.41 90.06 342.08 6,410.93 6,316.93 -165.80 -3,647.48 5,968,53106 558,419.37 10.17 2,217.55 MWD (3) f 8,655.02 92.12 349.92 6,410.36 6,316.36 -137.10 -3,654.63 5,96555970 558,411.97 27.37 2,244.13 MWD (3) 8,685.00 90.09 353.83 6,409.78 6,315.78 -107.43 -3,658.87 5,968,589.33 558,40.49 1469 2,269.58 MWD (3) 8,715.39 9144 0.48 6,409.38 6,315.38 -T.10 -3,66038 5,965619.64 558,405.74 22.33 2,293.79 MM (3) 8,745.21 88.52 4.61 6,409.39 6,31539 4732 -3,659.05 5,966,649.43 558,406.81 16.96 2,315.75 MWD(3) 8,775.12 89.17 4.42 6,409.99 6,315.99 -1751 -3,656.70 5,968,679.26 558,408.92 2.26 2,337.07 MM (3) 8,805.04 90.98 2.40 6,409,95 6,315.95 12.36 -3,654.92 5,968,709.13 558,41045 9.06 2,358.80 MWD (3) 8,83472 86.71 359.52 6,410.55 6,316.55 42.02 -3,654.42 5,968,738,79 558,410.70 17.35 2,381.21 MWD (3) 8,86469 84.81 355.70 6,412.77 6,31877 71.87 -3,655.67 5.9M,768 63 558,409.21 14.20 2,404.88 MWD(3) 8,895.65 85.11 350.77 6,41549 6,32149 10249 -3,659.30 5,968,799.21 558,405.33 15.89 2,430.66 MWD (3) 72712017 1:40:51PM Page 4 COMPASS 5000.14 Build 86 ConoccPhillipsER s " ConocoPhilli p Definitive Survey Report e Company: ConowPhillips(Alaska) Inc.-Kupl Local Co-ordinate Reference: Well 1C-04 Project: Kuparuk River Unit TVD Reference: 1 C-04 @ 94.00usft (1G-04) Site: Kuparuk 1C Pad MD Reference: 1 C-04 @ 94.00usft (1C-04) , Well: 1C-04 North Reference: True Wellbore: 1C-04 Survey Calculation Method: Minimum Curvature Design: 1C-04 Database: EDT Alaska Sandbox Survey Annotation 72712017 1:40.51PM Page 5 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S -El-W DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°1100') Section Surve Tool Name Y (ft) (ft) (ft) 8,925.17 88.31 351.05 6,417.18 6,323.18 131.59 -3,663.95 5,968,828.27 558,400.43 10.88 2,455.95 MWD (3) 8,954.91 90.67 347.33 6,417.45 6,323.45 160.79 3,669.53 5,968,857,42 558,394.62 14.81 2,481.90 MWD (3) 8,985.17 88.40 345.46 6,417.69 6,323.69 190.20 3,676.65 5,968,886.77 558,387.26 9.72 2,509.00 MAD (3) 9,014.48 87.39 348.47 6,418.77 6,324.77 218.73 -3,683.25 5,968,915.24 558,380.42 10.83 2,535.11 MWD(3) 9,045.21 87.70 352.51 6,420.09 6,326.09 249.00 3,688.32 5,968,945.47 558,375.09 13.17 2,561.56 MM (3) 9,074.95 91.96 354.55 6,420.17 6,326.17 278.55 -3,691.67 5,968,97498 558,371.50 15.88 2,586.34 MWD (3) 9,104.57 94.09 358.09 6,418.61 6,324.61 308.06 3,693.57 5,969,00447 558,369.36 13.93 2,610.17 MVM (3) 9,13463 94.92 3.90 6,416.25 6,322.25 338.01 -3,693.05 5,969,034.42 558,369.63 19.46 2,632.78 MWD(3) 9,165.13 92.40 8.24 6,414.30 6,320.30 368.26 -3,689.84 5,969,064.70 558,372.60 16.43 2,653.89 MM (3) 9,19461 89.63 9.77 6,413.78 6,319.78 397.37 -3,685.22 5,969,093.84 558,376.97 10.73 2,673.22 MM (3) 9,22503 86.44 7.36 6,414.82 6,320.82 427.43 -3,680.69 5,969,12393 558,38125 13.14 2693.33 MWD (3) 9,254.53 88.16 3.69 6,416.21 6,322.21 456.75 -3,677.86 5,969,15328 558,383.84 13.73 2,713.97 MWD (3) 9,289.7 89.20 359.55 6,41691 6,322.91 487.17 -3,677.00 5,969,183.69 558,389.45 14.02 2,736.72 MWD (3) 9,31623 90.80 355.80 6,416.91 6,322.91 520.39 -3,678.35 5,969,216.90 558,362.83 12.25 2,763.04 MWD (3) 9,344.78 94,5 354.28 6,41570 6,321.70 546.81 3,68064 5,969,24330 558,380.32 14.89 2,784.75 MWD(3) 9,375.11 89.91 350.51 6,414.54 6,320.54 57684 3,684.65 5,969,273.29 558,376,06 19.45 2,810.33 MM (3) 9,405.02 87.7 346.81 6,415.10 6,321.10 606.15 -3,690.53 5,969,302.55 558,369.94 13.97 2,836.57 MM (3) 9,434.93 88.65 342.72 6,415.98 6,321.98 634.99 3,698.38 5,969,331.32 558,361,84 13.66 2,863.71 MM (3) 9,464.93 88.80 338.42 6,416.65 6,322.65 663.27 -3,708.36 5,969,359.51 558,351.69 14.34 2,891.78 MWD (3) 9,494.92 87.30 334.66 6,417.67 6,323.67 690.78 3,720.24 5,969,386.92 556,339.53 12.87 2,920.49 MWD (3) 9,524.81 87.27 331.17 6,419.08 6,325.08 71738 3,733.79 5,969,413.41 558,32577 12.33 2,949.58 MWD(3) 9,554.88 87.55 327.86 6,420.44 6,326.44 743.26 -3,749.02 5,969,439.16 558,310.32 11.04 2,979.20 MWD (3) 9,584.86 90.00 32526 6,421.08 6,327.08 768.27 3,765.54 5,969,464.03 558,293.60 1191 3,008.97 MWD (3) 9,614.82 90.71 322.83 6,420.90 6,326.90 792.52 3,783.13 5,969,488.13 558,275.81 8.45 3,038.85 MWD (3) 9,645.04 90.58 32002 6,420.56 6,326.56 816.14 -3,801.97 5,969,511.59 558,256.78 9.31 3,069.06 MWD (3) 9,675.23 90.52 316.72 6,420.27 6,326.27 838.70 -3,822.02 5,969,53399 558,235.54 10.93 3,099.23 MM (3) 9,705.04 9028 313.94 6,42006 6,32606 859.90 -3,842.97 5,969,55501 558,21541 9.36 3,128.94 MWD (3) 9,734.84 9025 31068 6,419.92 6,325.92 879.96 -3,865.01 5,969.574.88 558,193.22 10.94 3,158.47 MWD (3) 9,764.75 91.60 307.91 6,419.44 6,325.44 898.90 -3,888.15 5,969,59362 558,169.92 10.30 3,187.85 MWD (3) 9,795.01 91.66 303.77 6,418.58 6,324.58 91660 -3,912.66 5,969,611.13 558,145.26 13.66 3,217.17 MWD (3) 9821.84 94.21 30244 6417.20 6,323.20 931.24 -3,935.11 5,969,625.57 558,122.70 10.72 3,24281 MWD(3) Annotation 72712017 1:40.51PM Page 5 COMPASS 5000.14 Build 85 7/27/2017 1:40:51PM Page 6 Annotation T! %HES COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc Kupl Local Coordinate Reference: Well 1C 04 Project: Kuparuk River Unit TVD Reference: 1C-04 @ 94.00usft (1C-04) Site: Kuparuk 1C Pad MD Reference: 1C-04 @ 94,00usft (1C-04) Well: 1C-04 North Reference: True Wellborn: 1C-04 Survey Calculation Method: Minimum Curvature Design: 1C-04 Database: EDT Alaska Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/ -W OLS (usft) (°) (1 (usft usft ( ) (us@) (usft) Northing Easting (./1 00.) Section Survey Tool Name (ft) (ft) (ft) 9,849.66 95.72 301.26 6,414.80 6,320.80 945.86 -3,958.65 5,%9,640.00 558,09904 6.88 3,269.14 MWD (3) 9,879.61 94.21 306.26 6,412.20 6,318.20 962.44 -3,983.45 5,969,656.37 558,074.11 17.38 3,297.78 MWD(3) 9,909.51 94.52 307.39 6,409.93 6,315.93 980.31 4,007.31 5,969,67404 558,050.10 3.91 3,326.81 MWD (3) 9,939.75 %76 311.51 6,406.95 6,312.95 999.42 4,030.54 5,969,692.96 558,026.72 1545 3,356.38 MWD (3) 9,970.28 97.38 316.23 6,403.19 6,309.19 1,020.41 -4,052.38 5,969,71377 558,00471 1548 3,386.50 MWD (3) 9,999.72 94.43 319.10 6,400.17 6,3W.17 1,042.06 4,072.09 5,969,735.24 557,984.82 13.94 3,415.75 1(3) 10=09 92.58 322.86 6,396.31 6,309.31 1,055.60 4,091.17 5,969,75863 557,965.54 13.78 3,446,05 MM (3) 10,059.93 93.4 327.14 6,396.74 6,30274 1,090.01 -0,108.26 5,969,782.89 557,94826 14.61 3,475.73 MWD (3) 10,089.95 93.78 32995 6,39485 6,300.85 1,115.57 4,123.90 5,969,808.32 557,932.41 9.41 3,505.37 MWD(3) 10,12001 94.71 326.76 6,39262 6,298.62 1,141.08 4,13962 5,969,83369 557,916.48 11.03 3,535.01 MWD (3) 10,150.22 88.31 321.57 6,391.83 6,297.83 1,165.54 -0,15729 5,969,858.01 557,898.61 27.27 3,565.11 MWD (3) 10,180.14 87.57 318,84 6,392.90 6,298.90 1,188.51 1.17642 5,969,880.82 557,879.29 9.45 3,595.00 MVD (3) 10,210.22 85.94 313.21 6,394.61 6,300.61 1,210.11 4,197.26 5,969,902.24 557,858.27 19.46 3,624.95 MWD (3) 10,240.51 89.85 311.33 6,395.72 6,301.72 1,230.47 4,21966 5,%9,92241 557,835.71 14.32 3,654.94 MVV (3) 10,270.26 88.86 316.13 6,395.05 6,302.06 1,251.03 4,241,15 5,%9,942.79 557,814.06 16.47 3,684.50 MAD (3) 10,300.03 89.11 321,52 6,396.58 6,302.58 1,273.42 4,260.74 5,969,965.02 557,794.28 18.12 3,71425 MWD (3) 10,332.57 87.85 327.21 6,397.45 6,305.45 1,299.85 4,279.68 5,969,991.28 557,775.12 17.90 3,796.67 MWD (3) 10,050.06 88.37 331.75 6,398.35 6,304.35 1,323.51 4,293.63 5,970,014.83 557,760.98 16.61 3,773.76 MM (3) 10,390.23 88.03 336.51 6,399.30 6,305.30 1,350.63 4,306.78 5,970,041.84 557,747.60 15.81 3,802.99 MWD (3) 10,420.45 90.65 333.80 6,399.65 6,305.65 1378.05 4,319.48 5,970,059.15 557,734.68 12.47 3,832.16 MWD (3) 10,450.23 87.91 328.34 6,400.02 6,306.03 1,404.10 4,333.88 5,970,095.08 557,720.07 20.51 3,861.37 MWD (3) 10,480.36 88.77 324.28 6,400.90 6,306.90 1,429.15 4,350.58 5,970,119.99 557,703.17 13.77 3,891.29 MWD(3) 10,510.19 87.70 319.23 6,401.82 6,307.82 1452.56 4,369.03 5,970,143.24 557,684.52 17.30 3,921.09 MM (3) 10,540.% 87.54 31361 6,403.06 6,309.06 1,474.17 4,389.59 5,970,16468 557,663.78 18.81 3,950.86 MWD (3) 10,569.71 8640 30969 6,404.11 6,310.11 1,493.86 4,41173 5,970,184.18 557,641.49 13.53 3,980.17 MWD (3) 10,600.29 91.72 31057 6,404.08 6,310.08 1,513.57 4,435.11 5,970,20369 557,617.95 11.23 4,010.29 MWD(3) 10,629.73 9461 308.25 6,402.45 6,3WA5 1,532.23 4,457.82 5,970,222.16 557,595.09 12.58 4,039.18 MWD (3) 10,63978 94.88 307.52 6,40162 6,307.62 1,538.38 4,465.72 5,970,22825 557,587.14 772 4,048.98 MWD (3) 10,675.00 94.88 307.52 6,398.62 6,304.62 1,559.75 4,493.55 5,970,249.39 557,559.13 0.00 4,083.24 PROJECTED to TD 7/27/2017 1:40:51PM Page 6 Annotation T! %HES COMPASS 5000.14 Build 85 THE STATE °f11. - - - GOVERNOR BILL WALKER K. Starck CTD Director ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.cogcc.claska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 C -04A ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-078 Surface Location: 1509' FNL, 4221' FEL, SEC. 12, TI IN, R10E, UM Bottomhole Location: 5188' FNL, 3481' FEL, SEC. 2, TI IN, R10E, UM Dear Mr. Starck: Enclosed is the approved application for permit to re -drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. Foerster Chair DATED this -/ *day of June, 2017. STATE OF ALASKA ALA A OIL AND GAS CONSERVATION COMMIL .ON PERMIT TO DRILL 20 AAC 25.005 RECEIVED MAY 2 4 2017 AQr2r.r 1a. Type of Work: Drill ❑ Lateral ❑ Redrill Q I Reentry ❑ 1b. 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 ❑ 1c. Specify if well is proposed 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 1C -04A , 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 10800' TVD: 6412' 12. Field/Pool(s): Kuparuk River Pool/ , Kuparuk River Oil Pool ' 4a. Location of Well (Governmental Section): Surface: 1509' FNL, 4221' FEL, Sec 12, T11 IN, R1 OE, UM Top of Productive Horizon: 1707' FNL, 1426' FEL, Sec 11, T11 N, R1 OE, UM Total Depth: 5188' FNL, 3481' FEL, Sec 2, T11 N, R10E, UM 7. Property Designation: ADL 25649 8. DNR Approval Number: ALK 467 13. Approximate Spud Date: 6/6/2017 9. Acres in Property: 2560 14. Distance to Nearest Property: 9000' 41h. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 562065 y- 5968727 Zone- 4 10. KB Elevation above MSL (ft): 94' GL / BF Elevation above MSL (ft): 61' 15. Distance to Nearest Well Open to Same Pool: 303', 1C -03A 16. Deviated wells: Kickoff depth: 7150 feet , Maximum Hole Angle: 104 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 3841 - '� Surface: 3194 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# L-80 ST -L 2300' 8500' 6438' 10800' 6412' Slotted 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): 7575' 6896' N/A 7456' 6777' 7258' Casing Length Size Cement Volume MD TVD Conductor/Structural 46' 20" 245 sx AS II 80' 80' Surface 2877' 13-3/8" 1800 sx Fondu & 300 sx AS II 2910' 2708' Production 6906' 9-5/8" 800 sx Class G 6936' 6258' Liner 933' 7.. 210 sx Class G 7545' 6866' Perforation Depth MD (ft): 7 088' - 7148' Perforation Depth TVD (11): 6410'- 6470' 7208'-7218 ' 6530'- 6540' Hydraulic Fracture planned? Yes ❑ No ❑✓ 20. Attachments: Property Plat ❑ BOP Sketch Diverter Sketch e Drilling Program 8 20 Time v. Depth Plot B Shallow Hazard AnalysisB Seabed Report Drilling Fluid Program ✓ AAC 25.050 requirements ✓ 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Keith Herring Authorized Name: K. Starck Contact Email: Keith. E.Herrin CO .Com Authorized Title: CTD Dire cto Contact Phone: 263-4321 Authorized Signature: Date: Of Commission Use Only Permit to Drill 7,3 Number: — 0 API Number: n 50- Q _ 0 _0() Permit—Approval Date: ' 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: '00P r-3;_ YL ho 4O DD P� Samples req'd: Yes Q, No � Mud log req'd: YesNov ,irr�r�vbr�rwG'^7t�7-r5 fo 7—,500 fni H,Smeasures: Yes R] No Directional svyreq'd:Yes No Spacing exception req'd: Yes ❑ NOM Inclination -only svy req'd: Yes[] NoR Post initial injection MIT req'd: Yes❑ No Lrl APPROVED BY Approved by:iw4COMMISSIONER THE COMMISSION Date: d L b b/l t Submit Form and ,��/`ed s/tot` t a orHW onths from the date of approval per 20 AAC 25.005(8) gnachments in Duplicate % (2 �Z ✓(3i ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 23, 2017 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: RECEIVE® MAY 2 4 2017 AOGCC ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill two laterals out of the KRU 1 C-04 (PTD# 180-155) using the coiled tubing drilling rig, Nabors CDR3-AC./ CTD operations are scheduled to begin in June 2017. The objective will be to drill the 2 laterals KRU 1 C -04A and 1C-04AL1 targeting the Kuparuk C -sands. I 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. Attached to this application are the following documents: - Permit to Drill Application Forms (10-401) for 1C -04A & 1C-04AL1 - Detailed Summary of Operations - Directional Plans for 1C -04A & 1C-04AL1 - Current wellbore schematic - Proposed CTD schematic The application for sundry approval (10-403) for 1 C-04 was approved on 5/17/2017. If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely,4— Keith Herring Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 1C -04A & 1C-04AL1 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))...................................................................................................................2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2))..................................................................................................................................................2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5))..................................................................................................................................................2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6))............................_......._........................................_...................................................................3 7. Diverter System Information..........................................................................................................3 (Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8))................. ......... --- ..... ............................................................................................................ 3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c) (10)) ................................................................................................................................................4 11. Seabed Condition Analysis............................................................................................................4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................4 13. Proposed Drilling Program.............................................................................................................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....................................................................... 6 (Requirements of 20 AAC 25.050(b))......................................................................................................................................................6 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 1C -04A & 1 C-04AL1...............................................................................................6 Attachment 2: Current Well Schematic for 1 C-04............................................................................................................6 Attachment 3: Proposed Well Schematic for 1 C -04A & 1 C-04ALl.................................................................................6 Page 1 of 6 May 23, 2016 PTD Application: 1C -04A & 1C-04ALl 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1C -04A & 1 C-04AL1. All laterals will be classified as "Development -Oil" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the C sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1C -04A & 1 C-04AL1. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors 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 ano to 4,000 psi. Using the maximum formation pressure in the area of 3,841 psi in 1C-02 (i.e. 11.4 ppg EMW), the maximum potential surface pressure in 1 C-04, assuming a gas gradient of 0.1 psi/ft, would be 3,194 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 1 C-04 was measured to be 3,087 psi (9.2 ppg EMW) on 12/7/2016. The maximum downhole pressure in the 1C-04 vicinity is to the southeast in the 1C-02 at 3,841 psi (11.4 ppg EMW) from January of 2016. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) Offset injection wells to 1 C-04 have injected gas, so there is a chance of encountering free gas while drilling the 1C-04 laterals. If 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 1C-04 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1C-04 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 6 May 23, 2016 PTD Application: 1C -04A & 1C-04ALl 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 1C -04A 8500' 10800' 6438' 6412' 2-3/8", 4.7#, L-80, ST -L slotted liner; 0' 80' 1530 520 Surface aluminum billet on to 1 C-04AL1 6970' 10800' 6292' 6437' 2-3/8", 4.7#, L-80, ST -L slotted liner; 1730 770 Production 9-5/8" up into 3-1/2" tubing Existing Casing/Liner Information Category OD Weight (pp Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 20" 94.0 qN-40 Welded 0' 80' 0' 80' 1530 520 Surface 13-3/8" 72.0 BTC 0'2910' 0'2708' 1730 770 Production 9-5/8" 47.0 BTC 0'6936' 0'6258' 6870 4760 Liner 7" 26.0 BTC 6612' 7545' 5936' 6866' 4980 4320 Tubing 3-1/2" 9.3 L-80 EUE 8rd MOD 0' 6986' 0' 6309' 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: Chloride -based FloVis mud (8.6 ppg) — Drilling operations: Chloride -based FloVis 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: The well will be loaded with 11.4 ppg NaBr completion fluid in order to provide formation over -balance and 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 5,000 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 1C-04 laterals we will target a constant BHP of 11.4 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be 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 6 May 23, 2016 PTD Application: 1C -04A & 1C-04AL1 Pressure at the 1C-04 Window (7150' MD. 6472' TVD) Usina 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 Well KRU 1 C-04 is a Kuparuk C -sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the C sands to the northwest of the 1C-04 parent wellbore. The laterals will add new resources and improve existing recovery. Prior to CTD operations, E -line will punch 2' of holes in the 3-1/2" tubing tail and the D nipple at 6984' MD will be milled out to a 2.80" ID. The existing C -sand perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing. Following the cement squeeze Nabors CDR3-AC will mill a pilot hole to 7180' MD and set a mechanical whipstock in the 2.80" pilot hole to kick off at 7150' MD. A window will be milled in the 7" casing at 7150' MD to drill and complete the 1C-04 laterals. The 1C -04A sidetrack will exit the cement pilot hole at 7150' MD and TD at 10800' MD, targeting the C4 sand to the northwest. It will be completed with 2-3/8" slotted liner from TD up to 8500'MD with an aluminum billet for kicking off the 1C-04AL1 lateral. The 1C-04AL1 lateral will drill to the northwest to a TD of 10800' MD targeting the C4 sand. It will be completed with 2-3/8" slotted liner from TD up to 6970' MD with a deployment sleeve inside the 3-1/2" tubing. Page 4 of 6 May 23, 2016 Pumps On 1.5 bpm) Pumps Off C -sand Formation Pressure 9.2 3096 psi 3096 psi Mud Hydrostatic 8.6 2894 psi 2894 psi Annular friction i.e. ECD, 0.08psi/ft) 572 psi 0 psi Mud + ECD Combined no chokepressure) 3466 psi overbalanced -370psi) 2894 psi underbalanced -202psi) Target BHP at Window 11.4 3837psi' 3837 psi Choke Pressure Required to Maintain Target BHP 371 psi 943 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 Well KRU 1 C-04 is a Kuparuk C -sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the C sands to the northwest of the 1C-04 parent wellbore. The laterals will add new resources and improve existing recovery. Prior to CTD operations, E -line will punch 2' of holes in the 3-1/2" tubing tail and the D nipple at 6984' MD will be milled out to a 2.80" ID. The existing C -sand perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing. Following the cement squeeze Nabors CDR3-AC will mill a pilot hole to 7180' MD and set a mechanical whipstock in the 2.80" pilot hole to kick off at 7150' MD. A window will be milled in the 7" casing at 7150' MD to drill and complete the 1C-04 laterals. The 1C -04A sidetrack will exit the cement pilot hole at 7150' MD and TD at 10800' MD, targeting the C4 sand to the northwest. It will be completed with 2-3/8" slotted liner from TD up to 8500'MD with an aluminum billet for kicking off the 1C-04AL1 lateral. The 1C-04AL1 lateral will drill to the northwest to a TD of 10800' MD targeting the C4 sand. It will be completed with 2-3/8" slotted liner from TD up to 6970' MD with a deployment sleeve inside the 3-1/2" tubing. Page 4 of 6 May 23, 2016 PTD Application: 1C -04A & 1C-04AL1 Pre -CTD Work 1. RU Slickline: Obtain SBHP, change our GLV's, and pressure test. 2. RU E -line: Punch 2' of holes in the 3-1/2" tubing tail at 6964' MD. 3. RU Pumping Unit: Perform injectivity test down the tubing. 4. RU Service Coil: Mill out "D" nipple and cement squeeze the C -sand perforations up to the holes in the tubing tail. 5. RU Slickline: Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR3-AC rig and set BPV. Ria Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. IC -04A Sidetrack (C4 sand -northwest) r a. Mill 2.80" pilot hole through the cement to 7180' MD. b. Caliper pilot hole. c. Set top of whipstock at 7150' MD. d. Mill 2.80" window at 7150' MD. e. Drill 3" bi-center lateral to TD of 10800' MD. f. Run 2-3/8" slotted liner with an aluminum billet from TD up to 8500' MD. 1 C-04ALI Lateral (C4 sand - northwest) a. Kickoff of the aluminum billet at 8500' MD. b. Drill 3" bi-center lateral to TD of 10800' MD. c. Run 2-3/8" slotted liner with a deployment sleeve from TD up to 6970' MD. 4. Obtain SBHP, freeze protect, set BPV, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 1. Pull BPV. 2. Return to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Page 5 of 6 May 23, 2016 PTD Application: 1C -04A & 1C-04AL1 Liner Running - The 1 C-04 laterals will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids" section for more details. - While running 2-3/8" slotted liner, a joint of 2-3/8" 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 2-3/8" rams will provide secondary well control while running 2-3/8" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. / • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (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). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AA 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 IDistance 1C -04A 9000' 1 C-04AL1 9800' - Distance to Nearest Well within Pool 16. Attachments Attachment 1: Directional Plans for IC -04A & 1 C-04AL11aterals Attachment 2: Current Well Schematic for IC -04 Attachment 3: Proposed Well Schematic for 1C -04A & 1C-04AL1 laterals Page 6 of 6 May 23, 2016 Lateral Name Distance Well 1 C -04A 303' 1 C -03A 1C-04AL1 303' 1C -03A 16. Attachments Attachment 1: Directional Plans for IC -04A & 1 C-04AL11aterals Attachment 2: Current Well Schematic for IC -04 Attachment 3: Proposed Well Schematic for 1C -04A & 1C-04AL1 laterals Page 6 of 6 May 23, 2016 ConocoPhillips ,C 04@ Project. Kuparuk River Unit Site: Kuparuk IC Pad Aamwnm Tm°Nenn M.�. Noon: nss FI"° WELLBORE DETAILS: 1C -04A REFERENCE INFORMATION Parent Wellbore: 1C -D4 CoolRna@iN@I Relemce: WeM 1COC,Trve NnVl Well: 1C-04 Gu. �ox�ssns.°T Te on MD: 7100.00 venrallN0l Rekrmre: 1CL @9a.muw jl0 Wellbore: IC -04A -11 el°: 00.95' a_,_ IVSi Relererce' SkV-IY.WN,O WEI Plan; tC-04A_w o5 (IC- P ( 114/1D-t14A) °"°-�i01T MWN: aGGMiMB Mmsun4 own Releecr lcM 09CDOWf lcC ) CaI vfirn Mebod Mimmm curvaure It-I>'JI C- 15' IC- 151/IL-11i 1r-IInt�Clbl5lt-15I Ir-Islnc-Is West( -)/East(+) (750 usft/in) Ff BAKER HUGHES EMM pi 00 West( -)/East(+) (750 usft/in) Ff BAKER HUGHES ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1C Pad 1 C-04 1 C -04A Plan: 1C -04A wpO5 Standard Planning Report 22 May, 2017 FIA kI BAKER HUGHES ConocoPhillips ,&Akv ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kupi Project: Kupamk River Unit Site: Kupamk IC Pad Well: 1C-04 Wellbore: 1C -04A Design: 1C-04A_wp05 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 C-04 Mean Sea Level 1C-04 @ 94.00usft(1 C-04) 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 1C Pad Phase: PLAN Well Position +N/ -S 0.00 usft Site Position: Northing: 5,968,522.46 usft Latitude; 70° 19' 28.285 N From: Map Easting: 562,372.05 usft Longitude: 149° 29'39.293 W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0,48 " Well 1C-04 Phase: PLAN Well Position +N/ -S 0.00 usft Northing: 5,968,727.00 usft +E/ -W 0.00 usft Easting: 562,065.00 usft Position Uncertainty 0.00 usft Wellhead Elevation: usft L-60.50 — —(usft) 0.00 0.00 Wellbore 1C -04A Magnetics Model Name Sample Date Declination BGGM2016 8/1/2017 17.55 Design 1C-04A_wp05 Audit Notes: Latitude: 70" 19'30.322 N Longitude: 149° 29'48.207 W Ground Level: 0.00usft Dip Angle (°) Version: Phase: PLAN Tie On Depth: Vertical Section: Depth From (ND) +N/ -S +E/ -W (usft) (usft) L-60.50 — —(usft) 0.00 0.00 80.95 Field Strength (nT) 57,541 7,100.00 Direction (°) 320.00 &22/2017 11:44:33AM Page 2 COMPASS 5000.1 Build 74 Plan Sections Measured ConocoPhillips Far fig ConocoPhillips Planning Report Dogleg BAKER Turn Depth HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1C-04 +E/ -W Company: ConocoPhillips (Alaska) Inc. -Kupi TVD Reference: Mean Sea Level TFO Project: Kuparuk River Unit MD Reference: IC -04 @ 94.00usH (1C-04) (usft) Site: Kuparuk IC Pad North Reference: True (o1100ft) Well: 1C-04 Survey Calculation Method: Minimum Curvature 3.60 Wellbore: 1 C -04A 6,328.11 -199.32 -2,481.96 Design: 1 C-04A_wp05 0.00 0.00 0.00 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) (o/100ft) (o1100ft) (o1100@) Target 7,100.00 3.60 318.60 6,328.11 -199.32 -2,481.96 0.00 0.00 0.00 0.00 7,150.00 3.90 320.15 6,378.00 -196.83 -2,484.08 0.63 0.60 3.10 19.45 7,171.00 2.45 240.90 6,398.98 -196.50 -2,484.93 20.00 -6.90 -377.36 215.00 7,241.00 33.95 240.90 6,464.64 -207.00 -2,503.80 45.00 45.00 0.00 0.00 7,394.44 103.00 240.90 6,517.60 -272.29 -2,621.12 45.00 45.00 0.00 0.00 7,550.00 103.05 224.93 6,482.32 -363.34 -2,741.60 10.00 0.03 -10.27 272.00 8,000.00 102.69 271.16 6,376.58 -522.32 -3,136.37 10.00 -0.08 10.27 85.00 8,200.00 92.27 288.40 6,350.37 -488.46 -3,330.69 10.00 -5.21 8.62 120.00 8,400.00 90.77 308.35 6,345.01 -393.91 -3,505.70 10.00 -0.75 9.98 94.00 8,600.00 90.38 328.35 6,342.99 -245.22 -3,637.93 10.00 -0.19 10.00 91.00 8,850.00 90.34 353.35 6,341.38 -10.93 -3,719.28 10.00 -0.01 10.00 90.00 9,100.00 91.58 18.33 6,337.12 235.77 -3,694.06 10.00 0.49 9.99 87.00 9,300.00 91.48 358.32 6,331.71 432.59 -3,665.28 10.00 -0.05 -10.00 270.00 9,550.00 93.46 333.37 6,320.77 672.86 -3,725.83 10.00 0.79 -9.98 275.00 9,800.00 93.13 308.33 6,306.16 864.86 -3,882.15 10.00 -0.13 -10.02 270.00 10,000.00 92.94 328.36 6,295.46 1,013.32 -4,014.21 10.00 -0.09 10.01 90.00 10,200.00 89.37 308.67 6,291.38 1,162.34 -4,146.01 10.00 -1.79 -9.84 260.00 10,450.00 87.31 333.60 6,298.74 1,355.37 -4,301.59 10.00 -0.82 9.97 95.00 10,800.00 86.65 298.56 6,317.75 1,603.22 -4,540.22 10.00 -0.19 -10.01 268.00 5222017 11:44:33AM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1C-04 Company: ConocoPhillips (Alaska) Inc. -Kupt TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1C-04 @ 94.00usft (1C-04) Site: Kuparuk 1C Pad North Reference: True Well: 1C-04 Survey Calculation Method: Minimum Curvature Wellbore: 1C -04A Depth Inclination Design: IC-04A_wp05 +NIS +E/ -W Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NIS +E/ -W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°n00ft) (°) (use) (usft) 7,100.00 3.60 318.60 6,328.11 -199.32 -2,481.96 1,442.69 0.00 0.00 5,968,507.18 559,585.01 TIP 7,150.00 3.90 320.15 6,378.00 -19683 -2,484.08 1,445.96 0.63 19.45 5,968,509.65 559,582.87 KOP 7,171.00 2.45 240.90 6,398.98 -196.50 -2,484.93 1,446.75 20.00 -145.00 5,968,509.97 559,582.01 End 20 dls, Start 45 dls 7,200.00 15.50 240.90 6,427.56 -196.70 -2,488.88 1,447.61 45.00 0.00 5,968,507.74 559,578.09 7,241.00 33.95 240.90 6,464.64 -207.00 -2,503.60 1,450.84 45.00 0.00 5,968,499.32 559,563.24 4 7,300.00 60.50 240.90 6,504.35 -227.87 -2,541.30 1,458.96 45.00 0.00 5,968,478.14 559,525.91 7,394.44 103.00 240.90 6,517.60 -272.29 -2,621.12 1,476.24 45.00 0.00 5,968,433.07 559,446.48 End 46 dls, Start 10 dls 7,400.00 103.02 240.33 6,516.35 -274.95 -2,625.83 1,477.23 10.00 -88.00 5,968,430.37 559,441.78 7,500.00 103.14 230.07 6,493.66 -330.45 -2,705.70 1,486.05 10.00 -88.13 5,968,374.22 559,362.38 7,550.00 103.05 224.93 6,482.32 -363.34 -2,741.60 1,463.93 10.00 -90.46 5,968,341.03 559,326.76 6 7,600.00 103.44 230.06 6,470.86 -396.21 -2,777.46 1,481.80 10.00 85.00 5,968,307.87 559,291.18 7,700.00 103.89 240.34 6,447.17 451.60 -2,857.12 1,490.58 10.00 88.17 5,968,251.63 559,211.98 7,800.00 103.92 250.64 6,423.08 491.81 -2,945.31 1,516.46 10.00 88.61 5,968,210.90 559,124.14 7,900.00 103.51 260.93 6,399.30 -515.63 -3,039.34 1,558.66 10.00 91.09 5,968,186.30 559,030.31 8,000.00 102.69 271.16 6,376.58 -522.32 -3,136.37 1,615.90 10.00 93.54 5,968,178.81 556,933.36 7 8,100.00 97.57 279.88 6,358.96 -512.80 -3,234.21 1,686.08 10.00 120.00 5,968,187.51 558,835.45 8,200.00 92.27 288.40 6,350.37 488.46 -3,330.69 1,766.75 10.00 121.54 5,968,211.06 558,738.78 8 8,300.00 91.54 298.38 6,347.04 -448.83 -3,422.30 1,855.99 10.00 94.00 5,968,249.92 558,646.85 8,400.00 90.77 308.35 6,345.01 -393.91 -3,505.70 1,951.67 10.00 94.33 5,968,304.15 558,563.01 9 8,500.00 90.58 318.35 6,343.83 -325.35 -3,578.31 2,050.86 10.00 91.00 5,968,372.10 558,489.84 8,600.00 90.38 328.35 6,342.99 -245.22 -3,637.93 2,150.56 10.00 91.12 5,968,451.72 558,429.57 10 8,700.00 90.37 338.35 6,342.33 -155.96 -3,682.72 2,247.73 10.00 90.00 5,968,540.60 558,384.05 8,800.00 90.36 348.35 6,341.69 -60.28 -3,711.33 2,339.42 10.00 90.07 5,968,636.03 558,354.65 8,850.00 90.34 353.35 6,341.38 -10.93 -3,719.28 2,382.34 10.00 90.13 5,968,685.31 558,346.29 11 8,900.00 90.60 358.34 6,340.97 38.92 -3,722.90 2,422.85 10.00 87.00 5,968,735.12 558,342.26 9,000.00 91.11 8.33 6,339.47 138.61 -3,717.08 2,495.48 10.00 87.04 5,968,834.85 558,347.25 9,100.00 91.58 18.33 6,337.12 235.77 -3,694.06 2,555.11 10.00 87.19 5,968,932.19 558,369.47 12 9,200.00 91.56 8.32 6,334.37 332.92 -3,671.06 2,614.74 10.00 -90.00 5,969,029.51 558,391.66 9,300.00 91.48 358.32 6,331.71 432.59 -3,665.28 2,687.38 10.00 -90.27 5,969,129.22 558,396.62 13 9,400.00 92.33 348.35 6,328.38 531.73 -3,676.86 2,770.77 10.00 -85.00 5,969,228.25 558,384.22 9,500.00 93.10 338.37 6,323.63 627.31 -3,705.43 2,862.35 10.00 -85.33 5,969,323.58 558,354.86 9,550.00 93.46 333.37 6,320.77 672.86 -3,725.83 2,910.36 10.00 -85.81 5,969,368.95 558,334.09 14 9,600.00 93.44 328.36 6,317.75 716.43 -3,750.12 2,959.35 10.00 -90.00 5,969,412.33 558,309.44 9,700.00 93.34 318.35 6,311.82 796.42 -3,809.63 3,058.88 10.00 -90.30 5,969,491.81 558,249.28 9,600.00 93.13 308.33 6,306.16 864.86 -3,882.15 3,157.92 10.00 -90.90 5,969,559.64 558,176.20 i6 9,900.00 93.09 318.35 6,300.73 933.30 -3,954.68 3,256.97 10.00 90.00 5,969,627.47 558,103.11 10,000.00 92.94 328.36 6,295.46 1,013.32 -0014.21 3,356.53 10.00 90.54 5,969,706.99 558,042.93 522201711:44:33AM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips Planning Report Database: EDM Alaska NSK Sandbox Map Local Co-ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kupl Easting TVD Reference: Project: Kuparuk River Unit (usft) 10.00 MD Reference: 5,969,786.65 Site: Kuparuk 1C Pad -100.35 5,969,854.91 North Reference: Well: 1C-04 5,969,923.23 557,837.11 Survey Calculation Method: Wellbore: iC-04A 557,777.25 10.00 94.48 5,970,046.61 Design: 1C-04A_wp05 -92.00 5,970,090.12 557,728.28 10.00 Planned Survey 5,970,169.89 557,668.43 10.00 -91.24 5,970,238.02 Measured TVD Below Vertical Depth Inclination Azimuth System +Nl-S +EbW Section (usft) (1) (1) (usft) (usft) (usft) (usft) 16 10,100.00 91.17 318.51 6,291.86 1,093.48 -4,073.67 3,456.16 10,200.00 89.37 308.67 6,291.38 1,162.34 -4,146.01 3,555.41 17 10,300.00 88.51 318.64 6,293.24 1,231.28 -4,218.25 3,654.65 10,400.00 87.70 328.61 6,296.56 1,311.64 -4,277.46 3,754.27 10,450.00 87.31 333.60 6,298.74 1,355.37 -4,301.59 3,803.28 18 10,500.00 87.15 328.60 6,301.16 1,399.07 -4,325.71 3,852.26 10,600.00 86.89 318.59 6,306.37 1,479.34 -4,384.91 3,951.81 10,700.00 86.72 308.57 6,311.96 1,548.09 -4,457.14 4,050.90 10,800.00 86.65 298.56 6,317.75 1,603.22 4,540.22 4,146.53 Planned TD at 10800.00 01ild BAKER HUGHES Well iC-04 Mean Sea Level 1C-04 @ 94.00usft (1C-04) True Minimum Curvature Dogleg Toolface Map Map Rate Azimuth Northing Easting (11100ft) (1) (usft) (usft) 10.00 -10000 5,969,786.65 557,982.81 10.00 -100.35 5,969,854.91 557,909.91 10.00 95.00 5,969,923.23 557,837.11 10.00 94.81 5,970,003.10 557,777.25 10.00 94.48 5,970,046.61 557,752.76 10.00 -92.00 5,970,090.12 557,728.28 10.00 -91.76 5,970,169.89 557,668.43 10.00 -91.24 5,970,238.02 557,595.64 10.00 -90.68 5,970,292.46 557,512.11 5222017 11:44:33AM Page 5 COMPASS 5000.1 Build 74 Targets ConocoPhillips 70°4'5.485N 140'22'11.491 W .S1. ConocoPhillips Planning Report Target Name BAKER 1C-04A_Faultl 0.00 0.00 6,312.00 -8,962.111,136,349.41 5,969,164.00 1,698,341.00 HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1C-04 Northing Company: ConocoPhillips (Alaska) Inc. -Kupi TVD Reference: Mean Sea Level (°) (°) (usft) Project: Kuparuk River Unit MD Reference: IC -04 @ 94.00usft (1C -D4) Latitude Longitude Site: Kupamk 1C Pad North Reference: True 5,968,139.00 Well: 1C-04 Survey Calculation Method: Minimum Curvature Wellbore: 1C -04A - Point 1,699,505.00 70° 3'51.933 N 140° 21'37,930 W Design: 1C-04A_wp05 1C -04A T02 Targets 1,698,136.00 70°4'5.485N 140'22'11.491 W - plan misses target center by 1138660.20usft at 7100.00usft MD (6328.11 TVD, -199.32 N, -2481.96 E) Target Name 1C-04A_Faultl 0.00 0.00 6,312.00 -8,962.111,136,349.41 5,969,164.00 1,698,341.00 70°4'3.083N 140°22'6.639W -hit(miss target Dip Angle Dip Dir. TVD +N/ -S -EI-W Northing Easing -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 1C -04A T04 0.00 0.00 6,344.00 -9,988.561,136,508.94 5,968,139.00 1,698,509.00 70° 3' 52.883 N 140° 22'6 512 W - plan misses target center by 1139032.96usft at 7100.00usft MD (6328.11 TVD, -199.32 N, -2481.96 E) - Point 1,699,505.00 70° 3'51.933 N 140° 21'37,930 W - plan misses target center by 1140029.06usft at 7100.00usft MD (6328.11 TVD, -199.32 N, -2481.96 E) 1C -04A T02 0.00 0.00 6,459.00 -10,103.981,137,284.09 5,968,030.00 1,699,285.00 70° 3' 50.625 N 140° 21'44.953 W - plan misses target center by 1139809.09usft at 7100.00usft MD (6328.11 TVD, -199.32 N, -2481.96 E) - Point 1C-04A_T05 0.00 0.00 6,331.00 -9,228.831,136,433.21 5,968,898.00 1,698,427.00 70° 4'0.370 N 140° 22'5.401 W 1C-04A_T07 0.00 0.00 6,292.00 -8,503.661,135,940.15 5,969,619.00 1,697,928.00 70° 4'8.134 N 140° 22' 16.315 W - plan misses target center by 1138452.39usft at 7100.00usft MD (6328.11 TVD, -199.32 N, -2481.96 E) - Point 1C -04A T03 0.00 0.00 6,365.00 -10,196.851,136,904.27 5,967,934.00 1,698,906.00 70" 3'50.281 N 140° 21'56.159 W - plan misses target center by 1139430.09usft at 7100.00usft MD (6328.11 TVD, -199.32 N, -2481.96 E) - Point 1C-04 CTD Polygon 0.00 0.00 0.00 -7,842.341,135,065.50 5,970,273.00 1,697,048.00 70° 4'15.837 N 140° 22'38.367 W - plan misses target center by 1137590.74usft at 7100.00usft MD (6328.11 TVD, -199.32 N, -2481.96 E) - Polygon Point 0.00 0.00 0.00 5,970,273.00 1,697,048.00 Point 0.00 164.15 349.39 5,970,440.02 1,697,395.99 Point 0.00 -961.81 1,421.28 5,969,323.07 1,698,477.05 Point4 0.00 -1,501.16 1,577.87 5,968,765.08 1,698,638.08 Points 0.00 -1,807.94 2,519.47 5,968,486.13 1,699,582.10 Point 0.00 -2,455.27 2,671.17 5,967,840.14 1,699,739.13 Point 0.00 -2,632.12 2,162.65 5,967,659.11 1,699,232.14 Point 8 0.00 -2,607.34 1,703.79 5,967,680.09 1,698,773.13 Point 0.00 -2,353.45 1,233.82 5,967,930.06 1,698,301.12 Point 10 0.00 -1,862.37 1,110.84 5,968,420.06 1,698,174.10 Point 11 0.00 -1,408.81 1,171.57 5,968,874.06 1,698,231.07 Point 12 0.00 -722.29 632.15 5,969,556.03 1,697,686.04 Point 13 0.00 0.00 0.00 5,970,273.00 1,697,048.00 1C-04A_TO6 0.00 0.00 6,301.00 -8,745.401,136,146.18 5,969,379.00 1,698,136.00 70°4'5.485N 140'22'11.491 W - plan misses target center by 1138660.20usft at 7100.00usft MD (6328.11 TVD, -199.32 N, -2481.96 E) - Point 1C-04A_Faultl 0.00 0.00 6,312.00 -8,962.111,136,349.41 5,969,164.00 1,698,341.00 70°4'3.083N 140°22'6.639W - plan misses target center by 1138865.08usft at 7100.00usft MD (6328.11 TVD, -199.32 N, -2481.96 E) - Polygon Point 6,312.00 0.00 0.00 5,969,164.00 1,698,341.00 Point 6,312.00 1.00 1.00 5,969,165.01 1,698,341.99 1C-04A_Feulti_M 0.00 0.00 0.00 -6,962.111,136,349.41 5,969,164.00 1,698,341.00 70° 4'3.083 N 140` 22'&639 W - plan misses target center by 1138882.66usft at 7100.00usft MD (6328.11 TVD, -199.32 N, -2481.96 E) - Rectangle (sides W1.00 1-11,000.00 DO.00) 1C-04A_T01 0.00 0.00 6,521.00 -9,935.791,137,505.51 5,968,200.00 1,699,505.00 70° 3'51.933 N 140° 21'37,930 W - plan misses target center by 1140029.06usft at 7100.00usft MD (6328.11 TVD, -199.32 N, -2481.96 E) - Point 1C-04A_TO8 0.00 0.00 6,341.00 -7,758.911,135,256.22 5,970,358.00 1,697,238.00 70"4' 16.368 N 140" 22'32.580 W - plan misses target center by 1137763.29usft at 7100.00usft MD (6328.11 TVD, -199.32 N, -2481.96 E) - Point 1C-04A_T05 0.00 0.00 6,331.00 -9,228.831,136,433.21 5,968,898.00 1,698,427.00 70° 4'0.370 N 140° 22'5.401 W - plan misses target center by 1138950.96usft at 7100.00usft MD (6328.11 TVD, -199.32 N, -2481.96 E) - Point 5222017 11:44:33AM Page 6 COMPASS 5000.1 Build 74 ConocoPhillips FlIe.. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1C Pad Well: 1C-04 Wellborn: 1C -04A Design: 1C-04A_wp05 Casing Points Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1C-04 Mean Sea Level 1C-04 @ 94.00usft(iC-04) True Minimum Curvature Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 10,800.00 6,317.75 2 3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +EI -W (usft) (usft) (usft) (usft) Comment 7,100.00 6,328.11 -199.32 -2.481.96 TIP 7,150.00 6,378.00 -196.83 -2,484.08 KOP 7,171.00 6,398.98 -196.50 -2,484.93 End 20 dis, Start 45 dis 7,241.00 6,464.64 -207.00 -2,503.80 4 7,394.44 6,517.60 -272.29 -2,621.12 End 45 dis, Start 10 dis 7,550.00 6,482.32 -363.34 -2,741.60 6 8,000.00 6,376.58 -522.32 -3,136.37 7 8,200.00 6,350.37 -488.46 -3,330.69 8 8,400.00 6,345.01 -393.91 -3,505.70 9 8,600.00 6,342.99 -245.22 -3,637.93 10 8,850.00 6,341.38 -10.93 -3,719.28 11 9,100.00 6,337.12 235.77 -3,694.06 12 9,300.00 6,331.71 432.59 -3,665.28 13 9,550.00 6,320.77 672.86 3,725.83 14 9,800.00 6,306.16 864.86 -3,882.15 15 10,000.00 6,295.46 1,013.32 -4,014.21 16 10,200.00 6,291.38 1,162.34 -4,146.01 17 10,450.00 6,298.74 1,355.37 4,301.59 18 10,800.00 6,317.75 1,603.22 4,540.22 Planned TD at 10800.00 52212017 11:44:33AM Page 7 COMPASS 5000.1 Build 74 Baker Hughes INTEQ RAN ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1C Pad Site Error: 0.00 usft Reference Well: 1C-04 Well Error: 0.00 usft Reference Wellbore 1C -04A Reference Design: 1C-04A_wp05 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1C-04 1C-04 @ 94.00usft (1(}04) 1C-04 Q 94.00usft (1C-04) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum Reference 1C-04A_wp05 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,100.00 to 10,800.00usft Scan Method; Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,276.65 usft Error Surface: Elliptical Conic Summary Survey Tool Program Date 5/19/2017 From To Centre to No -Go (usft) (usft) Survey (Wellbore) Tool Name Description 100.00 7,100.00 1C-04 (1C-04) BOSS -GYRO Sperry -Sun BOSS gyro multahm 7,100.00 10,800.00 1C-04A_wp05(I C -04A) MWD MWD - Standard Casing PointsMeasured (usft) from Plan Vertical (usft) Casing Hole (usft) Depth Depth (usft) Diameter Diameter Kuparuk 1 C Pad (usft) (usft) Name 10,800 00 6,41175 2 3/8" 2-318 3 Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 1 C Pad 1C-02 - 1 C-02 - 1C-02 Out of range 1C-03 - 1C-03 - 1C-03 Out of range 1C -03 -1C -03A -1C -03A 8,074.65 12,455.00 303.34 256.49 63.89 Pass - Major Risk 1C -04 -1C -04-1C-04 7,150.00 7,150.00 0.08 1.12 -1.03 FAIL - Major Risk 1C-04-1C-D4AL1-1C-D4AL1 wp02 8,524.99 8,525.00 0.54 0.93 -0.32 FAIL -Minor 1/10 1C-05 - 1C-05 - 1C-05 Out of range 1 C-06 - 1 C-06 - 1 C-06 Out of range 1C -08 -1C -08-1C-08 10,800.00 7,525.00 1,076.78 262.36 927.88 Pass - Major Risk 1C -08 -1C -08L1 -1C-081_1 10,800.00 7,525.00 1,076.78 262.36 927.88 Pass - Major Risk 1C-08-1C-08LI-01-1C-081_1-01 10,800.00 7,525.00 1,076.78 262.36 927.88 Pass - Major Risk 1C -08-1C-081_1 PBI -1C-081_1 P81 10,800.00 7,525.00 1,07678 262.36 927.88 Pass - Major Risk 1 C-09 - 1 C-09 - 1 C-09 Out of range 1 C-10 - 1 C-10 - 1 C-10 Out of range 1C-121 - 1C-121 - 1C-121 Out of range 1C-123 - 1C-123 - 1 C-123 Out of range 1 C-125 -1C-125 - 1 C-125 Out of range 1 C-127 - 1 C-127 - 1 C-127 Out of range 1 C-13 - 1 CA 3 - 1C-13 Out of range 1 C-135 - 1 C-135 - 1 C-135 Out of range 1C-135 - 1C-135PB1 - 1C-135PB1 Out of range 1 C-14 - 1 C-14 - 1 C-14 Out of range 1 CA 5 - 1 C-15 - 1 C-15 Out of range 1 C-15 - 1 C-15LI - 1 C-151_1 Out of range 1 C-150 - 1C-150 - 1 C-150 Out of range 1 C-154 - 1 C-154 - 1 C-154 Out of range 1 C-154 - 1 C-154 - 1 C-154wp08 Out of range 1 C-155 - 1C-155 - 1 CA 55 Out of range 1 C-16 - 1 C-16 - 1 C-16 Out of range 1C -170 -1C -170-1C-170 Out of range w -min cadre to center distance or covergent point, br -min separation factor, is -min ellipse separation &192017 12*54:03PM Page 2 COMPASS 5000.1 Build 74 Baker Hughes INTEQ SPAR■ ConocoPhiilips Travelling Cylinder Report BAKER HUGHES Company: ConomPhillips (Alaska) Inc. -Kupi Project: Kuparuk River Unit Reference Site: Kuparuk 1C Pad Site Error: 0.00 usft Reference Well: 1C-04 Well Error: 0.00 usft Reference Wellbore 1C -04A Reference Design: 1C-04A_wp05 Summary Site Name Offset Well - Wellbore - Design Kuparuk 1C Pad 1C-170- 1C-170PB1 - 1C-170PB1 1C-172- 1C-172 - 1C-172 1 CA 72 - 1 C-1 72A - 1 C -1 72A 1 C-172 - 1 C-172ALl - 1 C-172ALl 1 C-172 - 1 C-172AL2 - 1C-172AL2 1C-172-1C-172AL2PB7-1CA72AL2PB1 1C-172-1C-172AL2PB2-1C-172AL2PB2 1 C-174 - 1 CA 74 - 1 C-174 1 CA 74 - Plan: 1 C-1 74a - 1 C-174a(wp01) 1 CA 74 - Plan: 1 C-1 74a L7 (wp01) - 10174a L1 (w 1C-178 - 1 C-178 - 1 C-178 1C -178 -1C -1781_1-1C-1781-1 1C-178-1CA78L1 Pat -1C -178L7 PB1 1 C-178 - 1C-17811 PB2 - 1 C-1781_1 PB2 1C -18 -1C -18 -1C -1B Plan: 1 C-156 - Plan: 1 C-156 - 1 C-156wp06 Plan: 1 C-157 - Plan: 1 C-157 - 1 C-157wp05 Plan: IC -29- Plan IC -29- 1 C-29 wp04 Plan: IC -29 - Plan 1C-29PB1 - 1C-29PB1 wp04 Kupamk 1 D Pad 1 D-143 - 1 D-143 - 1 D-143 1D-143 - 1 D-1431_2 - 1 D-1431_2 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1C-04 1C-04 @ 94,00usft (1C-04) 1 C-04 @ 94.00usft (1 C-04) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (usft) from Plan (usft) (usft) (usft) Rule (usft) Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Offset Design Kuparuk I Pad- 1C -03 -1C -03A -1C -03A onsst baa Error: 060.01 Survey Program: 100-GYO-CT-CMS. 9131 -MWD Rule Asaigned: Major Risk Unset Well Enron 0.00 oc8 graver. Onaet semi Major Axle Measured Vertical Measuretl Vertical Reference Mset Taoirace+ Offset Wellbore Centre Casing- Centre to No Go Allooeble Wareing Depth Gepm Depth Depth Azimuth +N13 +El -W Hole size Centre penance Deviation (usft) (usal )usft) loan) (une) lueH) PI (usft) (usft) f9 )usft) (ien) loan) 8,07465 6.456.59 12.45500 6,52635 32.69 54.00 17463 -808.04 -3.259.50 2 11116 303.34 256.49 6389 Pass- Maier Risk. CC, ES, SF 8.07466 6,458.59 12.450.00 6,523.56 32.69 5405 17498 -812.95 -3,260.05 2-11/16 307.97 25644 8823 Pass - Major Risk 8,07471 8,458.58 12.425.00 6,51961 32.89 53.92 176.60 -03748 -3.262.82 2-11116 33130 25RM 90.28 Pass - Major Risk 8,07480 6,456.57 12,400.00 8,515.66 32.70 53.81 17501 -082.01) -3,265.66 2-11116 354.86 256.02 112.81 Pass -Map, Risk 8,075.79 845841 12,375.00 6,51166 32.70 53.71 179.30 38632 -3.269.93 2-11116 37580 255.91 135.69 Pass - Map, Risk 8,078.11 6,456.06 12,350.00 8,50780 3271 53.61 -179.48 -910.18 -3.276.16 2-11116 402.41 255.12 15904 Pass - Major RE:k 8,081.35 6,455.57 12325.00 6.5040D 32,73 5349 -178.32 -93357 -3,204.11 2-11/16 426.13 25485 18260 Pass - Major Risk 8,085.71 6,454.94 12,300.00 6,500.15 32.76 53.36 -177.18 -956.18 -3.294.06 2-11/16 449.50 254.01 206.09 Pass - Major Risk 8,100.00 6.452.96 12,22500 8,499.10 32.84 52.87 -174.28 1,017.92 -3,334.86 2-11116 516.31 251.62 27421 Pa. - Major Risk 0.10000 6,452.90 12,250.00 6492.71 32.84 5304 -17470 -99841 3,319.56 2-11116 494.67 251.03 252.58 Pass -Major Risk 0.100.00 645296 12.27501) 6,496.36 32.84 5321 -175.20 -977.00 3,30801 2-11116 472.50 252.00 230.52 Pass - Major Risk 8.11185 6,451.46 12.200.00 6,486.113 3291 52.69 -172.83 -1,038.44 -3,351.39 2-11116 53]36 24877 296.78 Pass - Major Risk 8,119.911 6,450.51 12,175.00 6,484.13 32.96 52.49 -171,85 -1,053.69 -3,369,36 2-11/18 55174 248.34 31834 Pass Major Risk 8.128.70 6.449.56 12,15000 8,482.98 3301 5228 -170.99 -1,069.34 3,388.81 2-11/16 577.09 24675 33908 Pass - Major Risk 8,138.10 6,44860 12,12500 aaa2.34 3307 52.08 -170.12 -1,083.12 -3.409.64 2-11116 595.16 24501 358.72 Pass - Major Risk 8,150.00 6,44152 12,07500 6,480.27 33.14 51.61 -168.98 -1,104.62 -3,454.66 2-11/15 627,05 242.28 393.03 Pass - Major Risk 8,15000 8,447.52 12,100.00 8.48155 33.14 5184 -16801 -1,094.91 -3,43166 2-11116 611.82 242.79 377.38 Paas -Major Risk 8,16974 6,445.00 12.050.00 6,478.94 3328 5137 -167.12 -1,111.95 -3.470.51 2-11116 540.34 238.72 408.44 Pass -Major Risk 8,181.28 6.44528 12,025,00 647187 33.33 51.14 -16805 -1,116.76 -350301 241116 651.85 236.30 42307 Pass - Major Risk 8.20000 8,444.37 11975.00 6,475.36 33.44 50,69 -164.29 -1.119.27 -355260 2-11116 669.49 23205 444.50 Pass - Major Risk CC - Min centre to center distance or covergenl point, SF - min separation factor, ES - min ellipse separation 5719/2017 12:54:03PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips Project. Kuparuk River Unit MmuNab➢ue HOM Mepm&Mnh nss W7_LLBORE DETAILS: 1C -04A REFERENCE INFORMRION Site: Kuparuk 1C Pad EN■■ M.e,.a=e.0 Parent Wellbore: 1C-04 c�d'reeINA3 Relennae: wer moa, Tme NOM Well: 1C-04 Northing sa.rpin s�s•t sm Tie on MD: 7100.00 vw i RD) R W-: Mem sr I Wellbore: IC -04A 0.00 Db wee: mss• 5968727 8edkn a nelemve: SMW Plan: 1C-04A_wp06(1C-04/10-D4A) 19'30.322 � i Sec vemu.D,lt Raluerce: lcoal@aa'o6pmnn OCda) Inc Azi TOSS +N/ -S +E/ -W C4Waron tANOC: m-. carve. C Mean I 2250 200[ 1750 1500 1250 c lobo 0 ]50 so0 250 0 0 t ❑ -zsa 0 -soo -750 000 -1250 FIC .I BAER HUGHES WELL DETAILS: EN■■ 1C-04 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 5968727 562065 70° 19'30.322 N 149' 29'48.207 W Sec MD Inc Azi TOSS +N/ -S +E/ -W Dleg TFace VSect Annotation 1 7100.00 3.60 318.60 6328.11 -199.32 -2481,96 0.00 0.00 1442.69 TIP 2 7150.00 3.90 320.15 6378.00 -196.83 -2484.08 0.63 19.45 1445.96 KOP 3 7171.00 2.45 240.90 6398.98 -196.50 -2484.93 20.00 215.00 1446.75 End 20 cls, Start 45 dls 4 7241.00 33.95 240.90 6464.64 -207.00 -2503.80 45.00 0.00 1450.84 4 5 7394.44 103.00 240.90 6517.60 -272.29 -2621.12 45.00 0.00 1476.24 End 45 cls, Start 10 dls 6 7550.00 103.05 224.93 6482.32 -363.34 -2741.60 10.00 272.00 1463.93 6 7 8000.00 102.69 271.16 6376.58 -522.32 -3136.37 10.00 85.00 1615.90 7 8 8200.00 92.27 288.40 6350.37 -488.46 -3330.69 10,00 120.00 1766.75 8 9 8400.00 90.77 308.35 6345.01 -393.91 -3505.70 10.00 94.00 1951.67 9 10 8600.00 90.38 328.35 6342.99 -245.22 -3637.93 10.00 91.00 2150.56 10 11 8850.00 90.34 353.35 6341.36 -10.93 -3719.28 10.00 90.00 2382.34 11 12 9100.00 91.58 18.33 6337.12 235.77 -3694.06 10.00 87.00 2555.11 12 13 9300.00 91.48 358.32 6331.71 432.59 -3665.28 10.00 270.00 2687.38 13 14 9550.00 93.46 333.37 6320.77 672.86 -3725.83 10.00 275.00 2910.36 14 15 9800.00 93.13 308.33 6306.16 864.86 -3882.15 10.00 270.00 3157.92 15 16. 10000.00 92.94 328.36 6295.46 1013.32 -0014.21 10.00 90.00 3356.53 16 17 10200.00 89.37 308.67 6291.38 1162.34 -4146.01 10.00 260.00 3555.41 17 18 10450.00 87.31 333.60 6298.74 1355.37 -4301.59 10.00 95.00 3603.26 18 19 10800.00 86.65 296.56 6317.75 1603.22 -4540.22 10.00 268.00 4146.53 Planned TD at 10800.00 C Mean I 2250 200[ 1750 1500 1250 c lobo 0 ]50 so0 250 0 0 t ❑ -zsa 0 -soo -750 000 -1250 FIC .I BAER HUGHES West( -)/East(+) (250 usft/in) 5795 EN■■ mmm1 'II■■■■.■■m1:1 5890 E■■■■■■■1 ■��►\®MIN■t■t■■■■1 of 1l�IM� t■■■■M■1 1■■■ ~I \\� �ENE sio■ 5985 F < Q $ 0■1 ~I ~I U tj U 6080 - U _ ~I _ PTz n U 6175 IC4 11C.04 Em ME 0 TIP U ' Ile OVIC BA PAP IN 62]0 West( -)/East(+) (250 usft/in) 5795 5890 of ~I 5985 F < Q $ ~I ~I U tj U 6080 - U _ ~I _ PTz n U 6175 IC4 11C.04 TIP U ' Ile OVIC BA 62]0 KO 6365 1.d 2O Is, Eta 45 dl - - ''I'' ; 5 16 17 18 6460 8 9 I 11 2 13 4.. _. IC- /IC ALI 6556 d45 1s.Sre IOdI 6 6650 IC- u IC -0 /IC - IC 3/IG 3 _Pao ea L N o �., o ,.� o u o .., g ,., o u o u „� o u 8 0 ,.� o ,�.� a �., o ,.• S N o .., o ,., �, ,.. ver[Icat section at :SZu.Vu" (95 usi111n) A. KUP PROD 1C-04 c onocornnups Well Attributes - - Max Angle $ M17 TD Alaska III AP 7"T Fied NYna Welbor..latua 500292054]00 KUPARUN RIVER UNn PROD nI MO(XKBI A<I film (M1Ke) 37.98 4,300.00 ],575.0 Cdnmanl N23(ppm) 0.b Annolal'wn Ena Bab KBGN IN Rig xel[oee Dale SSSV: NONE 40 9/1012016 LEI 1I2N2015 39.01 2/]11981 100a,aneT2Pv1153S3AM 4 IeaMmaa[e[Eu - HANGER 218- CO NOD CTOR InuY4p 3T; 34.0.BpY Gas OFT: 25311 SDRFACE336?8100 .UFTSAI casun: a9621 GASUFT:5.678n cAe uFr:fipae.l GIS LIFT, a'.n2a LOCATOR;6.16R3 SEALA hu:,7702 PER e 157 PACxER6r9e5 NIPPLE6M93 ovERSHOT.6981] SEPRoAPT:6II1225(2002 PRohucnON: 3O.law56� PALKER:6.ws0 NIPRE B.WJS 60E:69HA FISH; 6990D ]PERE', 70ee➢]. on, IPERR].M867.21e➢� LINER: 6612.1-),5150 - AnngLLbn 1. FK JE Oale Lest Tag: SLM 12460 121112016 A.. -"n Leat MOEgy Rev Reason: CORRECTED reducer vas pPmven p..... 2.612015' En -Bab 4/15/2017 raising r ngs cion. Daoarlphon 00 um 10(m) TOP lit") SetDepth Ix881 sm Repm(1VR)... wvL.n 11 cr.a. Top Tmaae CONDUCTOR Insulated 20 18940 34.0 LOS 800 94.00 Hd0 WELDED 32' ...... 0a"ID in ID lin) Top III GM Depth(MB) Bal Oapth Boni).. wPL n(I GraftTop Thnaa SURFACE 13310 12.347 330 2,910.0 2,]0].0 72.00 N-40 BTC ..ams ineadn'ten ODllnl ID(In) Top (XKBI $¢l0.pih IXKB1 9e1 DepIX DVD)... WYL¢n 11... 6,eaa TOPTh-d PRODUCTION 9518 8.861 30.1 6935.6 6,258.1 4].00 L-60 BTC Lasing Bp[,iptlon OD (in) 10(11) TOP "ME) Bel Oepb (flKal sx O.pin Dv01... widen 6... one. Tap Thrtaa IT IT ] 6216 8,612.1 ],5650 6866.3 2800 K55 BTC ilei Datall5 moral lD 1vin6e) mvlrvD)IOKfi) 1011-11-1 1trm Rea Co. On) 6,612.1 5,935.6 5.65 TIEBACK BAKER TIE BACK SLEEVE 6.151 6.618.2 5.941] 5.60 NIPPL BAKER SEAL NIPPLE 6.151 6,621.5 5.945.0 5 h HANGER BAKER LINER HANGER 6.151 6,631.6 5,9550 550 XOBUSHING BAKER XO CENTRALIZER BUSHING 5.151 Tubing Strings mhmng Rlenbnln smog TUBING -WO -2015 -4112x3112@62.6 Na... 3112 ID On 2.992 Top RKaI 2].8 Set Repo Itt_ 69100 set Depth HV 1... 6.232.5 w111hn0 9.30 craea L-80 T0P clnnamin EUE Bb Mod Completion Details TIPTimn) TOP NVD)I11K81 TOP mal l°) mum Dea con Nominal 10 21.8 216 006 HANGER FMC GEN 3 HANGER WITH LH ACME LIFT THREAD 3958 62.8 62.11 0.13 XO Reducing Cmssover Pup 4112°IUM x 3112"EUE 80 2.992 6.769.3 6,092.2 038 LOCATOR GBH LOCATOR SUB 2.900 6.770.2 6,093.2 438 SEAL ABBY 8D 40 SEAL ASSEMBLY 2.990 6,775.7 6,0988 433 PER BAKER 8040 PER (W) 4.000 6.7988 6,121.7 4.14 PACKER BAKER 4782 FHL RETRIEVABLE PACKER 2.960 6.8493 6,1720 4.10 NIPPLE CANSO DS NIPPLE 2,813 8,901.] 6224.3 4.07 OVERSHOT BAKER POOR BOY OVERSHOT 3.590 T.h'7.ixrlption Slang Me...l0lmnl '.-(r op (RKS) Sal.Mh(E SH OepiM1 (TVB)I,. on III Gnae Top Conaval II)BING-ORIGINAL 31.2 2.992 69040 6.986.4 6,308.8 920K-55 BTG Completion Details rov (x881 7oPIrvD101x81 Top 11[1(°] IS. Be. con x I nm 1D 6.9192 6241.] 406 BBR wIEXT BAKER KB4 SBR 3. 3.000 8,945.3 6,26].8 4.04 PW HL R BAKER FPACKER 3.000 B, .5 6.305.9 4.02 NIPPLE uAa in O NIPPLE NO GU H.01'NIPPLE REWCER 1.BiD SET 9111.14 - PULLED 2]612015) 6,984.4 63068 4.02 SOB OAKER SHEAR OWSUB 2992 Other In Hole (Wirellne retrievable plugs, vanes, pumps, fish, etc.) Top ITVRI Top PIKE) (.K. Top /net I°) Re Com Ren Date I01n 6,9900 63129 4.02 FISH E -LINE SPINNER 2"Longxil4"Wide 820.2014 Perforations & Slots Ic IXKB) BM M.) Top DV01 PIKE) BM (iV0) B) 2Om Bale Shot h.pof d Type Com ],088.0 ],1480 8,410.1 5,470.0 Cd,Ca, G2, 1G04 2/]/191 4.0 ]PERF 7.2080 7,218.0 8,5299,539.8 C-1, UNIT B. 1C4M 2]7]1981 4.0 ]PERF Mandrel Inserts IS NI N TOP DVD) Valve Loch PMSiee TRO Run Top (XNB) MKS) Make Noael O06n) Sery Type Type (in) (Pap) Run Btln Co. 1 2,631.1 2,466.5 CAMCO MMG 1112 GAS LIFT OV RK 0.250 0.0 2IW2017 2 3,9206 3,551.9 CAMCO MMG 1112 GASLIFT GLV RK 0.188 1 199 21512015 3 4.9822 4,397.7 CANSO MMG 1112 GAS LIFT OV RK 0.188 00 214/2015 4 5,6780 5,0189 CAMCO MMG 1112 GAS LIFT DMY RK 0,000 0.0 113112015 5 63467 5,6718 CAMCO MMG 11.2 GAS LIFT DMY RK 0.000 00 113112015 6 67124 6,035.5 CAMCO MMG 1 12 GAS LIFT DMY RK 9000 00 113112015 Notes: General& Safety .no Bao Ammo mn NOTE'. WAIVERED WELL IA X OA COMMUNICATION fl/1N20ID NOTE: 7;7-__ iew SCM1ematicwl Plaska SMema11c90 8/1612014 NOTE: LEAK AT 5763°; T SPINNER STILL IN HOLE. 112412015 NOTE: WORKOVER 1C-04 Proposed CTD Schematic 20" 94# H-40 shoe cm 80, MD 113-3/8"72#N-40 shoe @ 2910' MD 9-5/8" 47# L-80 shoe @ 8936' MD IKOP 9D 7150'MD I C -sand parts 7088' - 7148' MD C -sand perfs 7208'- 7218' MD T'26# K-55 shoe @ 7545' MD 4-1/2" x 3-1/2" 9.3# L-80 EUE 8rd to surface 3-1/2" Cameo MMG gas lift mandrel @ 2631', 3920', 4982', 5678',6347- Baker 678',6347'Baker Tie Back Sleeve 6612' IRKS Baker Seal Nipple @ 6618' RKB Baker Liner Hanger @ 6622' RKB 3-1/2" Carrico MMG gas lift mandrel @ 6712' RKB Baker 8040 Seal Assy @ 6770' RKB Baker PBR@ 6776' RKB Baker FHL Packer @ 6799' RKB 3-1/2" Cameo DS Nipple @ 6849' RKB w/ 2.813' ID Baker Poor Boy Overshot @ 6902' RKB Baker 3-1/2" PBR @ 6919' MD (3.0" ID) Baker FHL packer @ 6945' MD (3.0" ID) 3-1/7' Cameo D landing nipple @ 6984' MD (2.75" min ID, No - Go; 1.81" nipple reducer) Mill to 2.80" ID 3-1/2" tubing tail @ 6986' MD 1CG04ALi "02 TO 9 10600' MD Liner Top @ 6970' MD 1G04Awp05 TO @ 10600' MD Liner Billet @ 8`A0' MD REVI DATE I BY I CK I APP i DESCRIPTION REV DATE BY I CK I APP I DESCRIPTION 12 17/17/151 JAH I SZ I IRev. Per K150013ACS 13 8/21/1 NRB I JAH I IRev. Per K150013ACS LEGEND KIC 2 • EXISTING CONDUCTOR Mq 1 IRs��3 :K ARUK LR ATIDJEC& Q AS—BUILT CONDUCTOR THIS SURVEY SmC200 GRAPHIC SCALE 400 012 jCPF1 1 inch = 200 ft. +12 _ f'09 11 p ': 1615 14 13 \ �T ^^ o^ Ory o< • i ^� ^^O ti • . h^ .°` ^h by •; � � •i: ••^^ry^ryy� ��ry 40' ry^OO • ^ • N p i ^ti rv° ti 83' SEE SHEETS 2 & 3 FOR NOTES AND LOCATION INFORMATION. SN' 70 . lov'�aoatIKN OF 'ALl SURVEYOR'S CERTIFICATE AV 9th :: I HEREBY CERTIFY THAT I AM PROPERLY REGISTERD AND LICENSED %•••••.• . ..... ••. / TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND i THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER ..................I. JEREMIAH F. CORNELL;'•0 MY DIRECT SUPERVISION AND THAT ALL NEW DIMENSIONS AND �♦ J`j, '. LS-12663 Ar OTHER DETAILS PER THIS REVISION ''..ARE ♦ F� CORRECT AS OF JULY 16, 2015. LOUNSBURY ��♦Fo •6'f//„��®�� A& ASSOCIATES. INC. 4,SS�CNAL 5u ORS ENGINEERS PUNNfaa QQ b AREA: 1C MODULE: XXXX UNIT: D1 C®n®c oPhilli s WELL CONDUCTORS Alaska, Inc. ASBUILT LOCATIONS CADD FILE NO. DRAWING NO. PART: REV: LK6103d31 6/30/01 CEA—D1 CX-6103D31 1 1 OF 3 1 13 12 17/17/11 JAH I SZ I IRev. Per K150013ACS 1 13 8/21/1 NRB I JAH I IRev. Per K150013ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 12, T11N, R10E WELL NAD27 ASP Coordinates NA Geographic Coordinates Section Offset Elev. No. 'Y' 'X' LATITUDE LONGITUDE F.N.L F.W.L PAD O.G. 1 5,968,523.00 562,372.00 N 70'19'28.291" W 149'29'39.295" 1,717' 1,363' N/A N/A 2 5,968,590.00 562,271.00 N 70'19'28.958" W 149'29'42.227" 1,649' 1,263' N/A N/A 3 5,968,656.00 562,172.00 N 7019'29.615" W 149'29'45.100" 1,582' 1,164' N/A N/A 4 5,968,727.00 562,065.00 N 70'19'30.322" W 149'29'48.207" 1,510' 1,058' N/A N/A 5 5,968,793.00 561,965.00 N 70'19'30.979" W 149'29'51.110" 1,442' 958' N/A N/A 6 5,968,860.00 561,864.00 N 70'19'31.647" W 149'29'54.042" 1,375' 859' N/A N/A 7 5,968,926.00 561,765.00 N 70'19'32.304" W 149'29'56.916" 1,308' 760' N/A N/A 8 5,968,993.00 561,664.00 N 70'19'32.971" W 14929'59.848" 1,240' 660' N/A N/A 9 5,968,851.99 561,548.05 N 70'19'31.593" W 149'30'03.267" 1,381' 542' N/A N/A 10 5,968,763.33 561,680.92 N 70'19'30.711" W 149'29'59.409" 1,471' 674' N/A N/A 11 5,969,008.74 561,641.06 N 70'19'33.128" W 149'30'00.514" 1,225' 637' 60.4' 55.0' 12 5,969,000.20 561,653.40 N 70'19'33.043" W 149'30'00.156" 1,234' 649' 60.4' 55.1' 13 5,968,842.13 561,891.29 N 70'19'31.469" W 149'29'53.250" 1,394' 885' 60.4' 55.0' 14 5,968,672.21 562,146.39 N 70'19'29.777" W 149'29'45.844" 1,566' 1,139' 60.4' 55.0' 15 5,968,605.15 562,247.15 N 70'19'29.109" W 149'29'42.919" 1,634' 1239' 60.3' 55.0' 16 5,968,825.37 561,916.31 N 70'19'31.302" W 14929'52.523" 1,411' 910' 60.3' 55.0' 17 5,968,838.00 561,568.78 N 70'19'31.454" W 149'30'02.665" 1,395' 563' 60.5' 56.2' 18 5,968,758.80 562,016.22 N 7019'30.639" W 14929'49.623" 1,478' 1,010' 60.4' 55.0' 19 5,968,624.28 562,368.18 N 70'19'29.287" W 149'29'39.382" 1,616' 1,360' 59.1' 52.3' 20 5,968,622.03 562,222.10 N 7019'29.277" W 149'29'43.646" 1,601' 1,191' 60.3' 55.0' 21 5,968,637.75 562,198.12 N 70"79'29.434" W 149'29'44.342" 1,617' 1,214' 60.6' 55.0' 22 5,968,646.48 562,334.93 N 70'19'29.508" W 149'29'40.347" 1,593' 1,327' 59.1' 51.6' 23 5,968,579.61 562,285.45 N 70'19'28.855" W 149'29'41.807" 1,660' 1,277' 60.3' 55.2' 24 5,968,571.44 562,297.94 N 70'19'28.773" W 14929'41.445" 1,668' 1,290' 60.3' 55.2' 25 5,968,546.47 562,335.47 N 7079'28.525" W 14929'40.355" 1,693' 1,327' 60.2' 55.0' 26 5,968,538.05 562,347.93 N 70'19'28.441" W 149'29'39.994" 1,702' 1,339' 60.2' 55.0' 27 5,968,529.79 562,360.58 N 70'19'28.358" W 149'29'39.626" 1,710' 1,352' 60.2' 55.0' 28 5,968,689.43 562,121.21 N 70'19'29.948" W 149'29'46.575" 1,548' 1,114' 60.6' 55.0' 101 5,968,821.46 561,593.72 N 70'19'31.289" W 149'30'01.941" 1,412' 588' 60.6' 56.7' NOTES: 1. BASIS OF LOCATION AND ELEVATION IS DS1C MONUMENTATION LOUNSBURY PER LOUNSBURY & ASSOCIATES. pS30CfATS3, qC 2. COORDINATES SHOWN ARE ASP, ZONE 4, NAD27 ups eNceceas ruxNeRs 3. ELEVATIONS ARE BPMSL 10-11 AREA: IC MODULE: )XXX UNIT: 61 ConocoPhillips DS1C WELL CONDUCTORS Alaska, Inc. ASBUILT LOCATIONS Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, May 25, 2017 3:50 PM To: Herring, Keith E Subject: RE: [EXTERNAL]KRU 1C -04A (PTD 217-078): Permit to Drill Application Thanks Keith, I'll update the original footage for the KRU 1C-04 well so that I can proceed to put the KRU 1C -04A wellbore trajectory into the AOGCC database. Patricia From: Herring, Keith E [ma ilto: Keith. E.Herring@conocophillips.com] Sent: Thursday, May 25, 2017 3:37 PM To: Bettis, Patricia K (DOA) <patricia.bettis@alaska.gov> Subject: RE: [EXTERNAL]KRU 1C -04A (PTD 217-078): Permit to Drill Application Good afternoon Patricia, Attached is the as built from 8/21/15. When placed into the CPAI Coordinate Converter I get the following for the surface location of well 1C-04. 1509.93' FNL, 4221.83' FEL, Section 12, T11N, R10E, UM So going off the most recent as built the numbers provided on the permit to drill would be correct. If you need further information please let me know. Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO — 664 Keith.E.Herring@conocophillips.com ConocoPhillips AkaSka From: Bettis, Patricia K (DOA) [ma iIto: patricia.bettis@alaska.sov] Sent: Thursday, May 25, 2017 3:11 PM To: Herring, Keith E <Keith.E.Herring@conocophillips.com> Subject: [EXTERNAL]KRU 1C -04A (PTD 217-078): Permit to Drill Application Good afternoon Keith, On Form 10-403, Box 4A, it states the surface location of the well to be 1509 FNL, 4221' FEL, Section 12, TIM, R10E, U. M. On the Well Completion or Recompletion Report and Log Form 10-407, Box 4, the surface location for the well is 1515' FNL, 1066' FWL, etc. Please verify which footage is correct. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at (907) 793-1238 or patricia.bettisPalaska.¢ov. Bettis, Patricia K (DOA) �� al — a�Y From: Herring, Keith E <Keith.E.Herring@conocophillips.com> Sent: Thursday, May 25, 2017 3:37 PM To: Bettis, Patricia K (DOA) Subject: RE: [EXTERNAL]KRU 1 C -04A (PTD 217-078): Permit to Drill Application Attachments: 1C Pad As-Built-Revl3.pdf Good afternoon Patricia, Attached is the as built from 8/21/15. When placed into the CPAI Coordinate Converter I get the following for the surface location of well 1C-04. 1509.93' FNL, 4221.83' FEL, Section 12, T11N, R10E, UM So going off the most recent as built the numbers provided on the permit to drill would be correct. If you need further information please let me know. Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO — 664 Keith. E. Herrir1gP)conocophilIips.com ConocoPhillips Alaska From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, May 25, 2017 3:11 PM To: Herring, Keith E <Keith. E. Herring@conocophillips.com> Subject: [EXTERNAL]KRU 1C -04A (PTD 217-078): Permit to Drill Application Good afternoon Keith, On Form 10-403, Box 4A, it states the surface location of the well to be 1509 FNL, 4221' FEL, Section 12, T11N, R10E, U. M. On the Well Completion or Recompletion Report and Log Form 10-407, Box 4, the surface location for the well is 1515' FNL, 1066' FWL, etc. Please verify which footage is correct. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 71" Ave., Ste 100 Anchorage, AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE., This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at (907) 793-1238 or patricia.bettisRDalaska.aov. Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, May 25, 2017 3:11 PM To: keith.e.herring@conocophillips.com Subject: KRU 1C -04A (PTD 217-078): Permit to Drill Application Good afternoon Keith, On Form 10-403, Box 4A, it states the surface location of the well to be 1509 FNL, 4221' FEL, Section 12, T11N, R10E, U.M. On the Well Completion or Recompletion Report and Log Form 10-407, Box 4, the surface location for the well is 1515' FNL, 1066' FWL, etc. Please verify which footage is correct. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage, AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE., This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at (907) 793-1238 or patricia.bettis@alaska.gov. TRANSMITTAL LETTER CHECKLIST WELL NAME: Mb, IC -64.4 PTD: 07J/ —G7 - Development _ Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: o%C �i�/�f POOL: I{tA Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MLILTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50 -- (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50-_- from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where sam les arefirst 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 PERfi PTD#. 2170780 Appr Date PKB 5/26/2017 Engineering Appr Date VTL 6/5/2017 Com[ 17 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 KUPARUK RIVER, KUPARUK RIV OIL -490100 Well Name: KUPARUK _RIV _UNIT 1C -04A - Program DEV. Well bore seg El -- -- ALASKA INC _ Initial Class/Tvoe DEV / PEND. - _GeoArea UO Unit 11160 On/Off Shore On Annular Disoosal n Nonconven. gas conforms to AS31.05.0300.1.A),Q.2.A-D) NA Engineering Public Permit fee attached NA Date: 6 Lease number appropriate Yes ADL0025649, entire wellbore. - Unique well. name and number Yes KRU 1C -04A - Well located in a. defined pool Yes KUPARUK RIVER,. KUPARUK RIV OIL.- 490100,. governed. by Conservation Order No. 432D. Well located proper distance from drilling unit. boundary Yes CO 432D contains no spacing restrictions with respect to drilling unit boundaries.. Well located proper distance from other wells - - - - - - Yes - CO 432D has no interwell spacing restrictions.. Sufficient acreage available in drilling unit Yes - - If deviated, is. wellbore plat. included - Yes - - - - - Operator only affected party Yes Wellbore. will be. more than 500' from an external property. line where ownership or landownership changes. Operator has. appropriate bond in force Yes - Permit can be issued without conservation order. - Yes Permit can be issued without administrative. approval Yes Can permit be approved before 15 -day wait..... Yes Well located within area and. strata authorized by Injection Order# (put. 10# in comments) (For NA All wells within 1/4 mile area of review identified (For service well only).. - - - - - NA. Pre -produced injector; duration of pre -production less than 3 months (For service well only) NA - - - - - Conductor string provided ..NA Conductor set in KRU 1 C-04 Surface casing. protects all known USDWs NA Surface casing set in KRU 1C-04 CMT vol adequate to circulate on conductor & surf csg NA.. Surface casing set and fully cemented CMT vol adequate to tie-in long string to. surf csg NA - CMT. will cover all knownproductivehorizons No. Productive. interval will be completed with uncemented slotted liner Casing designs adequate for C, T, B & permafrost Yes Adequate tankage or reserve pit Yes Rig has steel tanks; all waste -to approved disposal wells If a. re -drill, has a 10-403 for abandonment been approved Yes PTD 180-155,. Sundry 317-196 - Adequate wellbore separation proposed Yes Anti -collision analysis complete; no major risk failures If diverter required, does it meet regulations NA - Drilling Fluid program schematic & equip list. adequate Yes Max formation. pressure is 3841 psig(11..4 ppg EMW ); will drill w/ 8,6 ppg EMW & maintain overbal w/ MPD BOPEs, do they meet regulation Yes BOPE press rating appropriate; test to (put psig in comments). Yes MPSP is 3194 psig; will test BOPS to 4000 psig _ Choke. manifold complies w/API. RP -53 (May 84) Yes - Work will occur without operation shutdown Yes Is presence. of H2S gas probable Yes H2S measures required.. Mechanical. condition of wells within AOR verified (For service well only) NA - - 35 Permit can be issued w/o hydrogen sulfide measures No Wells on 1C -Pad are H2S-bearing. H2S measures required. Geology 36 Data presented on potential overpressure zones Yes Maximum potential reservoir pressure is 11.4 ppg EMW;. will be drilled using 8.6 ppg mud and MPD technique. Appr Date 37 Seismic analysis of shallow gas. zones. NA PKB 5/26/2017 38 Seabed condition survey (if off -shore) - NA - - I39 Contact namelphone for weeklyprogress reports [exploratory only] NA Onshore development sidetrack to be drilled, - - - Geologic Engineering Public Commissioner: bts Date: 6 Commission r: ate Commissioner �R Dajje 6 I� �[�