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Home My WebLink About219-118DATA SUBMITTAL COMPLIANCE REPORT 1/14/2020 Permit to Drill 2191180 Well Name/No. KUPARUK RIV UNIT 1C-061-1-01 Operator ConocoPhillips Alaska, Inc. API No. 50-029-20564-61-00 MD 13822 TVD 6562 Completion Date REQUIRED INFORMATION / Mud Log No �/ 10/1/2019 Completion Status 1WINJ / Samples No ✓ Current Status 1WINJ UIC Yes Directional Survey Yes/ DATA INFORMATION List of Logs Obtained: GR/Res (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 31333 Digital Data 10/21/2019 Electronic File: 1C-061-1-01 EOW-NAD83.pdf ED C 31333 Digital Data 10/21/2019 Electronic File: 1C-061-1-01 EOW NAD27.pdf ED C 31333 Digital Data 10/21/2019 Electronic File: 'IC -061-1-01 EOW NAD27.txt ED C 31333 Digital Data 10/21/2019 Electronic File: 1C-061-1-01 MD NAD83.txt Log 31333 Log Header Scans 0 0 2191180 KUPARUK RIV UNIT 1C-061-1-01 LOG HEADERS ED C 31369 Digital Data 9178 13822 10/23/2019 Electronic Data Set, Filename: 1C-061-1-01 GAMMA RES.Ias ED C 31369 Digital Data 10/23/2019 Electronic File: 1C-061-1-01 2MD Final Log.cgm ED C 31369 Digital Data 10/23/2019 Electronic File: 1C-061-1-01 5MD Final Log.cgm ED C 31369 Digital Data 10/23/2019 Electronic File: 1C-061-1-01 STVDSS Final Log.cgm ED C 31369 Digital Data 10/23/2019 Electronic File: 1C-061-1-01 2MD Final Log.pdf ED C 31369 Digital Data 10/23/2019 Electronic File: 1C-061-1-01 5MD Final Log.pdf ED C 31369 Digital Data 10/23/2019 Electronic File: 1C-061-1-01 5TVDSS Final Log.pdf ED C 31369 Digital Data 10/23/2019 Electronic File: 1C-061-1-01 EOW NA027.pdf ED C 31369 Digital Data 10/23/2019 Electronic File: 1C-061-1-01 EOW NAD27.txt ED C 31369 Digital Data 10/23/2019 Electronic File: 1C-061-1-01 Final Surveys TO 13822.csv ED C 31369 Digital Data 10/23/2019 Electronic File: 1C-061-1-01 Final Surveys TO 13822.xtsx ED C 31369 Digital Data 10/23/2019 Electronic File: 1C-061-1-01 Survey Listing.txt AOGCC Page 1 of 3 Tuesday, January 14, 2020 DATA SUBMITTAL COMPLIANCE REPORT 1/14/2020 Permit to Drill 2191180 Well Name1No. KUPARUK RIV UNIT 1C-061-1-01 Operator ConocoPhillips Alaska, Inc. API No. 50-029-20564-61-00 MD 13822 TVD 6562 Completion Date 10/1/2019 Completion Status 1WINJ Current Status 1WINJ UIC Yes ED C 31369 Digital Data 10/23/2019 Electronic File: 1C-061-1-01 Surveys.txt ED C 31369 Digital Data 10/23/2019 Electronic File: 1C-061-1- Ot_25_tapescan_BHI _CTK.tM ED C 31369 Digital Data 10/23/2019 Electronic File: 1C -06L1- 01_5_tapescan_BHI_CTK.txt ED C 31369 Digital Data 10/23/2019 Electronic File: 1C-061-1-01_output.tap ED C 31369 Digital Data 10/23/2019 Electronic File: 1C-061-1-01 21VID Final Log.tif ED C 31369 Digital Data 10/23/2019 Electronic File: 1C-061-1-01 51VID Final Log.tif ED C 31369 Digital Data 10/23/2019 Electronic File: 1C-061-1-01 5TVDSS Final Log.tif Log 31369 Log Header Scans 0 0 2191180 KUPARUK RIV UNIT 1C-061-1-01 LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments IKruKMAI Ium Kcucivcu Completion Report Y Production Test Information Y / NA Geologic Markers/Tops Y COMPLIANCE HISTORY Completion Date: 10/1/2019 Release Date: 9/10/2019 Description Comments: Directional / Inclination Data Y Mud Logs, Image Files, Digital Data Y / NA Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files Y Daily Operations Summary Y Cuttings Samples Y / NA Date Comments Core Chips Y / NA Core Photographs Y / NA Laboratory Analyses Y / NA AOGCC Page 2 of 3 Tuesday, January 14, 2020 DATA SUBMITTAL COMPLIANCE REPORT 1/14/2020 Permit to Drill 2191180 Well Name/No. KUPARUK RIV UNIT 1C -06L1-01 Operator ConocoPhillips Alaska, Inc. MD 13822 TVD 6562 Completion Date 10/1/2019 Completion Status 1WINJ Compliance Reviewed By: Current Status 1WINJ API No. 50-029-20564-61-00 UIC Yes Date: '/I7 1 (D ZC) A06CC Page 3 of 3 Tuesday. January 14. 2020 Winston, Hugh E (CED) From: Winston, Hugh E (CED) Sent: Friday, January 17, 2020 10:49 AM To: Winston, Hugh E (CED) Subject: RE: KRU 1C-06 Sundry Issues From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, January 15, 2020 9:50 AM To: Winston, Hugh E (CED) <hugh.winston@alaska.gov> Cc: Brooks, Phoebe L (CED) <phoebe. brooks @alaska.gov> Subject: KRU 1C-06 Sundry Issues Hugh, Could you please hand make these changes on the forms, put a copy of this list in each of the well files and correct in RBDMS? Let me know if you have any questions. Thanx, Victoria From: Germann, Shane <Shane.Germann@conocophillips.com> Sent: Wednesday, January 15, 2020 8:57 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.sov> Cc: Brooks, Phoebe L (CED) <phoebe.brooks@alaska.aov>; Winston, Hugh E (CED) <hugh.winston@alaska.aov> Subject: RE: [EXTERNAL]KRU 1C-06 Sundry Issues Victoria, Below are the forms that have WIND checked instead of WAG along with the corresponding well names and PTD *Vs. Let me know if you need anything else. I apologize for the inconvenience this has caused. Well Name PTD # Form KRU 1C-06 181-025 10-403 (Sundry # 319-380) KRU 1C-06 181-025 10-404 (Sundry # 319-380) KRU 1C-061-1 219-117 10-401 KRU 1C-061-1-01 219-118 10-401 KRU 1C-061-1-02 219-119 10-401 KRU 1C -06L1 219-117 10-407 KRU 1C-061-1-01 219-118 10-407 KRU 1C-061-1-02 219-119 10-407 Shane Germann Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.¢ov> Sent: Wednesday, January 15, 2020 8:37 AM To: Germann, Shane <Shane.Germann@conocophillips.com> Cc: Brooks, Phoebe L (CED) <phoebe. brooks Pala ska.ftov>; Winston, Hugh E (CED) <hutth.winston@alaska.aov> Subject: [EXTERNAL]KRU 1C-06 Sundry Issues Shane, Please list the wells, PTD #s, Sundry #s and the forms where WI instead of WAG is checked. We will take a look at it. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeoorrD alaska. g ov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria Loeoo@alaska.gov From: Germann, Shane <Shane.Germann@conocophillips.com> Sent: Tuesday, January 14, 2020 3:12 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.eov> Cc: Brooks, Phoebe L (CED) <phoebe.brooks@alaska.aov>; Ohlinger, James J <James.J.Ohli neer@conocophil lips.com> Subject: KRU 1C-06 Sundry Issues Victoria, It has been brought to my attention that the KRU 1C-06 Sundry (319-380) and CTD sidetrack PTD's (219-217, 219-118, 219-119) have a mistake on them. The 1C-06 is a WAG injector and has been on WAG since 2007. The 1C-06 CTD laterals were always planned to be on WAG injection, but I inadvertently checked the "WIND" box instead of "WAG" on the 10-401's, 10-403, 10-404, and 10-407's. The well status for the 1C-06 motherbore as well as the three CTD laterals (Ll, 1-1-01, and L1-02) should be WAG. Please advise if any formal documentation is required. I've attached the email chain that brought this up and the 10-404 for KRU 1C-06. Feel free to call or reply with any questions. Shane Germann Coiled Tubing Drilling Engineer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ /till 20AAC 25.105 20nnc 25.110 WINJC WAGO WDSPL❑ No. of Completions: 1b. Well Class: Development❑ Exploratory ElGINJ❑ Service❑ • Stratigraphic Test F1 2. Operator Name ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 10/112019 14. Permit to Drill Number/ Sundry: 219-118 ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 9/17/2019 15. API Number: 50-029-20564-61-00' 4a. Location of Well (Governmental Section): Surface: 1375' FNL, 658' FWL, Sec 12, T11N, R10E, UM ' Top of Productive Interval: 1307' FNL, 1244' FEL, Sec 1, T11N, r10e, um Total Depth: 2427' FNL, 1823' FEL, Sec 36, T12N, R10E, UM 8. Date TD Reached: 9124/2019 16. Well Name and Number: KRU 'IC -061-1.01 ' 9. Ref Elevations: KB:94 • GL: 55 . BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk River Oil Poo 10. Plug Back Depth MD/TVD: NIA 18. Property Designation: • ADL 25649, ADL 25638 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 561864 • y- 5968860 • Zone- 4 TPI: x- 564994 y- 5974234 Zone- 4 Total Depth: x- 564378 y- 5978388 Zone- 4 11. Total Depth MDRVD: ' 13822/6562 • 19. DNR Approval Number: LONS 79-016 12. SSSV Depth MDfTVD: 2238/2021 20. Thickness of Permafrost MD/TVD: 1931/1785 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: • 946716551 - 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 RECEIVED LVED GR/Res OCT 3 0 2019 23. CASING, LINER AND CEMENTING RECORD D SETTING DEH TVD AMOUNT WT. PER SETTING DEPTH MPT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 65 H40 32 65 32 65 36 425sx Permafrost 10 314 45.5 K-55 31 3287 31 2685 13314 3400 sx AS II 7 26 K-55 30 10226 30 7090 63/4 535 sx Class G 2318 4.6 L-80 11339 13822 6562 6562 3 Slotted Liner 24. Open to production or injection? Yes ❑� No ❑ If Yes, list each interval open (MD/TVD of Tap and Bottom; Perforation Size and Number; Date Perfd): SLOTTED LINER @: 11339-13822 MD and 6562-6562 TVD ... 9126119 COMPLETION D,a,TE ID Zol f V iii, ,FLED 25. TUBING RECORD SIZE DEPTH SET (MD) IPACKER SET (MD(TVD) 31/2 9387 9151/6326 928116423 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑� Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): INJECTION ONLY -- NOT PRE -PRODUCED Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casino Press: Calculated 24 -Hour Rate Gil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10407 Revised 5/2017 1- /�/s/� 9 _ //,/CONTINUED ON PAGE 2 RBDMSL0_' OCT 3 0 2019 Submit RIGI�AL only` 28. CORE DATA Conventional Core(s): Yes ❑ No I] - Sidewall Cores: Yes ❑ No E If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize I'ithology 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 ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1931 1785 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 9467 6551 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk C TD 13822 6562 Formation at total depth: Ku aruk C 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloaical reoort. product on or well test results. per 20 AAC 25,070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: Shane Germann Authorized Title: SW CTD Engineer Contact Email: Shane. ermann & co.com Authorized 7Contact Phone: 263-4597 Signature: Date: .t 9 9 INSTRUCTIONS General: This fo4 and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10407 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 ta: 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 tb: Well Class - Service wells: Gas Injection, Water Injection, Water-Altemating-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 forth for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only 1C46 Final CTD Schema0c uwaanamsmvo 3 W'TRM 4E SSSV®MOV MD 3-112" &NL40 EUE BM Tubing le surface 18'95e Hd shoe �95'MD 3-112" Camc9 MMG gas lin mandrel ® 9045' 10JI4. 4861-55 shoe ®328T MD Baker 1llr PBR ® 9102' MD (3.0" ID) Baker FHL pancer® 9115' MD (3A" ID) X -Nipple Q 9159' MD (2.913" 10) Baker EL -t SBR ® 9222' MO (4.3]5" ID) Baker FHL Parker ® 924T MD (3.0" ID) landing nipple ® 9288" MD (Milled to 2.80' ID) O-aand peRa 9410'- 9495' MD 10,226'MD TO=11. 1D=I1 _ 884' MD TOL=848]' MD BOL=11 MD SOL=13,822' MO Conoco`Phillips Alaska. Inc. WELL -NAME 1C-06 WELLBORE 1C-06 ,cm lDvm,e,zm r#PM Last Tag vaMalsnm (Nubua AnnoAnon Depe1M(B) End care wellbore Las, Mau av __............ _._...... HANGER, las .�..�. coNcue... aoas.D WEI.1. z.D16 suRFAcs: al.asaaTb- M. LIFT %.2 RBRg1a59 PALNER; P.151S xmxe, g]34x OVER9ROT e2Ae sefl;11.2 in PRCI(Efl: 9. 15 N FELE sa184 Part 0a10o9,aa5D� FM: 10pM0 PRODUCTIMl'19..10 ZG5.9� :HTop IH Tub ........_..._ _ i Last Tag: RKB 9,658.0 I 'RA,u. I I C -DU Isona, 1 Last Rev Reason Annotation I End bare wellbore last MW av Rev Reason: Atltl LinBr CTD lever by I 101612019 1G06 1,Ergpsp Casing Strings eaaliq besenp,bn OO Un) l0O TOPIRKB) sM pupil 11x8) seebepm (rvO1... wuIn p_Grade Top Ter. CONDUCTOR 16 15.06 320 65.0 65.0 62.58 H-40 WELDED GPNp CeseXplbn OD(a, IOpn) Tap m(BI Sal pe, INIB) SN-M(NO)....Len p...Grade TOPTnrea] $DRPADE 10 Y4 995 31.3 3,28]0 2,685.1 45.50 K-55 BUTT GaMP MseXpbn OO gni ID (in) Top gMBl SH OepN 11KB) InTan (ND)... WtlLen D... G- TOP T.. PRODUCTION 7 fi28 29.6 10,2258 7.090.1 26.00 K-55 BTC Tubing Strings Tumne Oeacnpnon seine Ma... lb 11n, Top 11x81 set pub. (E.] sal pevrl lrvbl 6.. wr pbnl Grade TOpeonmmhon TUBING 2007 WO 3112 2.99 26.9 9,232.9 6,38].5 930 L�0 8 rd Completion Details lip N`/O) Tov mut Nominal Top(MB) mxa) , tum Dee con mini 2-0 a 9 0.00 HANGER FMC Tubing HANGER 3.500 2,23].8 2,0210 43.75 ISAFRETY VLV 85" TRMAX(LE Safely Valve (Serial # HYS-703) 2.812 9,135.5 6,3134 39.06 PER Baker PER seal assembly gannpA 40M#)Wl. 9'spaceopt 3.000 9,151.5 8,325A 39.54 PA KE ft Baker FHL Packer(pinrreE 60M# shiner) 3.000 9,1 2 Q3576 4079 INIPPLE 2.81Y X Nipple 2.813 9,231.9 6,386.7 4ldUIUVLKbNUI Baker Tubing Sw6 Overshot ♦i'space ow 3.610 N TVm 1... WtpNR) Grade Tap Lonnecxon Tubing Dead anion Sninp Ma... lO bad Tappaid" Sel0ep. 1ft. 5e1DeP'"." TUBING 1993 WO 5314 4.3] 9,232.2 9,281.5 6.4234 Completion Details Ip 11K0) iovlrvpl Top mel (RKBI Nominal hes Com IDlin) 9,255.2 6,404.0 42.38 SBR BAKER EL -1 58R (no penjoinl. TBG suing showing SBR ODIID) 4.375 Tubing Manlptbn beer M., 110onl Topuruip SN Dep. In., bet Oep. INDI I.. WIIIpnQ Grade Top Connw,Wn TUBING Original 3112 2.99 9,281.5 9.3872 6,4987 9.20 K-55 BTC Completion Details p(N01 iap lriGl Nominal Top mKBl ToM1NBI PI Ibem Oea Com IO 1111 92815 6,423.4 43.W PACKER HERFHL PAOKER 3.000 93493 6,472.1 44.90 NIPPLE AM PLEN G MI2,WON 91711 Nipple 2.800 behin8 Dice: 10-06 L14P8 CTD liner. 938091 6.494.3 4593150S 2992 Other In Hole (Wholine retrievable plugs, valves, pumps, fish, etc.) Tap IflKB) Top (TVD) IRKS) I Top Ina (°I Oea Cam Run Oak ID p.)9,274. 6,4179 41 dEi Liner 100 Liner up 'a'. moDcer bore: CTD I " - L1-02 Liner W302019 1.992 ap. 10.026016,9454 1 4400 jHsh IVann Gun Left from original cerf. 101- long 15125119pil Perforations & Slots Top InK81 Bbn 11KB1 ToMal IMBI elm llVpl gtl(BI IJnked IDne Mfr a - Dens (abotLll ) Type Com 94100 9,485.0 6,51446,5659 UNIT D, - 3, 1C*6 3/3111 81 12.0 Mandrel Inserts at n HTopnV01 Top(N(BI (1KB) Make MWaI 00 gin,saiv Type II Lztc1 Taid PoXStre TRO Run (in) Ipsil Run Dek Com 1 9,0/9.2 6.2692 Camco MMG I 1112 GABLIFT DMY BK I 0000 I 00 11111200, Notes: General & Safety End bad, I Annoraken 112M993 NOTE: WORK VER 4272004 NOTE: WANEREO WELL: T KIACOMMONICATION 1 8x010 INUTE: VIEW SCHEMATIC w/Alaska 5chemauc9.0 KUP SVC WELLNAME 1C.06 WELLBORE 1C -06L7-01 ConocoPhillips Alaska. lnc. ic.U.AI,1W 19120LffiPM Casing Strings VNYelat e0e lacavl CaampO—ptb Li -01 LINER OO lin) 2J18 IOlinl 1.99 Top MB) Set Dept. InNO) s" DepN IN01... WVLen p... G1aEe 11,JJ8.9 158220 6.562.1 4.60 L-80 Top TM1 aE STL _........ _....................... Liner Details .......... u m1na11D Top lnRal Top rv01(m19) rop loci l9 Ikm Dea com (nl XANGER1 al. 11, JJS9 6,561.9 895] uminum Bivat Alumipim U.AIIop Billet 1920 12]28] 6,5624 88.89 UeployMent Stony Deployment Sleeve 1.920 Sleeve coxDDmoa, 92oes.o MFEW N.V; 3,. eVRFF E; 3133,m].0� GPe LIFT, 90]92 Ms. O,1R5 Ig KER. 0,1515 xIPPLE 9183.2 OVER T. 9%318 WR;92X] 0 MKER; 9,2815 .PPLE93193 tire, Tcp 9T4 0 PM, B.N90B,aX� PRODCIIO A 10.M: II Ill LlL' 11Nas,, 11.599.413,9?]. OJ Uperations Summary (with Timelog Depths) 1C-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten oeptn Sten Time EM Time Dur (hr) Phase Op Code Amity Code Time P-T-X Operabon (WB) End Depth (RKB) 9/11/2019 9/11/2019 2.75 MIRU MOVE MOB P movefr5m1G-113to1G-103 0.0 0.0 00:00 02:45 9/11/2019 9/11/2019 2.00 MIRU MOVE MOB P On location, remove jeeps, hook up 0.0 0.0 02:45 04:45 truck to drilling sub module, spot over well 9111/2019 9/11/2019 2.00 MIRU MOVE MOB P Spot in rig mats, spot pit module next 0.0 0.0 04:45 06:45 to drilling sub, pusher headed to retrieve shop from 1 G-pad. 9/1112019 9/1112019 3.25 MIRU MOVE MOB P Work on Rig Move check list, secure 0.0 0.0 06:45 10:00 all landings, walking surfaces, and cellar floor, hook up PUTZ (inler- conned).Rig up steam lines / heaters, tool house on location, rig up tiger tank line placing tiger tank off drillers side along well row. 9/11/2019 9/11/2019 2.00 MIRU WHDBOP NUND P Nipple up BOP stack, tighten tree 0.0 0.0 10:00 12:00 bolts, valve crew service tree. Service rig valves in preparation4 for BOPe test, •** Note: Rig Accept 10:00 9/11/2019 9/11/2019 1.00 MIRU WHDBOP NUND P Complete prepping for BOPe test. 0.0 0.0 1200 13:00 Line up and fluid pack rig. Obtaint shell test 9/11/2019 9/11/2019 7.00 MIRU WHDBOP BOPE P Start BOP testing, 250 psi Low/3,500 0.0 0.0 13:00 20:00 psi High/2,500 psi annular witness was waived by Adam Earl (AOGCC). Fail / Replace on C-4, Test complete 9/11/2019 9/11/2019 1.80 MIRU RIGMNT PRTS P Test PDL's and TT line 0.0 0.0 20:00 21:48 9/11/2019 9/11/2019 1.60 MIRU RIGMNT CTOP P Skid injelor to rig loor. Prep CT and 0.0 0.0 21:48 23:24 install coil tubing connecor, Pull test to 35K 9/11/2019 9/12/2019 0.60 MIRU RIGMNT CTOP P Test wire -good, Head up E-line 0.0 0.0 23:24 00:00 9/12/2019 9/12/2019 0.75 MIRU RIGMNT CTOP P Continue heading up E line and 0.0 0.0 00:00 00:45 testing. 9/1212019 9/12/2019 2.00 MIRU RIGMNT CTOP P Fill CT with seawater, PT inner reel 0.0 0.0 00:45 02:45 iron, CTC, and upper quick connect to 4000 PSI 9/12/2019 9/12/2019 1.00 MIRU RIGMNT CTOP P Check pack offs. Install floats in UQC 0.0 0.0 02:45 03:45 9/12/2019 9/12/2019 1.00 SLOT WELLPR PULD P P/U BHA#1. FCO with straight motor 0.0 0.0 03:45 04:45 and 2.80" D-331 mill. Load into PDL. Hang motor in well 9/12/2019 9/1212019 1.75 SLOT WELLPR PULD P PJSM. PD BHA#1, surface test tools 0.0 0.0 04:45 06:30 (good), stab INJH, tag up reset counters. 9/12/2019 9/12/2019 3.00 SLOT WELLPR TRIP P RIH to 2,000', adjust gooseneck, 0.0 2,837.0 06:30 09:30 inspect gooseneck rollers (good), continue IH, park @ 2,837', re-adjust gooseneck, make back-up cable for PCL cabinet (ethernet), repair fiberoptic calble in putz 9/1212019 9/12/2019 1.50 SLOT WELLPR TRIP P Continue IH, RIW 15k 2,837.0 9,180.0 09:30 11:00 9/12/2019 9/12/2019 0.30 SLOT WELLPR DLOG P Log K1 marker (+9.6), PUW 46 k, 9,180.0 9,213.7 11:00 11:18 close EDC, 9/12/2019 9/12/2019 0.30 SLOT WELLPR TRIP P PUH 9,213.7 9,280.0 11:18 11:36 9!12/2019 9/12/2019 0.70 SLOT WELLPR DLOG P Log CCL 9,280' to 9,450' C� 20 fpm, 9,280.0 9,450.0 11:36 12:18 pumping 1.9 bpm/3,688 psi Page 1122 ReportPrinted: 10/1/2019 operations Summary (with Timelog Depths) 1c-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Depth Sten Time End Time du (hr) Phew Op Code Anvity Coe Tlme P -T4 Opemtipn MKB) End DOW (Wa) 9/12/2019 9/12/2019 1.40 SLOT WELLPR TRIP P POOH, chasing milling fluid to surface, 9,450.0 500.0 12:18 13:42 @ 746' notice scale and sand on shaker 9/12/2019 9/12/2019 0.30 SLOT WELLPR TRIP P Perform jog back in hole, to 1000', 500.0 51.3 13:42 14:00 PBOH 9/12/2019 9/1212019 1.60 SLOT WELLPR PULD P PUD CO BHA #1 51.3 0.0 14:00 15:36 9/12/2019 9112/2019 0.50 PROD1 RPEQPT PULD P P/U NS HEW BHA 0.0 0.0 15:36 16:06 9/12/2019 9/12/2019 0.30 PRODt RPEQPT PULD P PD, BHA #2 NS/HEW 0.0 73.5 16:06 16:24 9/12/2019 9/12/2019 1.00 PROD1 RPEQPT PULD T Tool tagging up shallow in PDL. Lay 73.5 0.0 16:24 17:24 down tool to inspect. HEW hanging up on no go plate. Modify HEW 9/12/2019 9/12/2019 1.30 PROD1 RPEQPT PULD P PD BHA#2 Northern SoultionsHEW 0.0 73.5 1724 18:42 whipstock. Make up to coil and surface test tool. 9/12/2019 9/12/2019 2.00 PROD1 RPEQPT TRIP P RIH, BHA #2 Whipstock, EDC open 73.5 9,210.0 18:42 20:42 9/12/2019 9/12/2019 0.20 PROD1 RPEQPT DLOG P Log K1 for + 1.5' correction. 9,210.0 9,242.0 20:42 20:54 PUW=39K 9/12/2019 9/12/2019 0.30 PROD1 RPEQPT TRIP P Continue into set depth @ 9438.78'. 9,242.0 9,438.0 20:54 21:12 Oriented to high side. Close EDC. Pressure up setting tool. See tool shift @ 3900 PSI. Set down 4K. Good 9/12/2019 9/12/2019 1.80 PR0D1 RPEQPT TRIP P Trip out after seting whipstock, EDC 9,438.0 80.0 21:12 23:00 open 9/12/2019 9/1212019 0.60 PROD? RPEQPT PULD P Tag up and space out. PJSM PUD 80.0 0.0 23:00 23:36 BHA#2 9/12/2019 9/13/2019 0.40 PROD1 RPEQPT PULD P P/U NS setting tool. M/U mill motor, 0.0 0.0 23:36 00:00 pup, 2.80 NS window mill and 2.79 String reamer 9/13/2019 9113/2019 1.30 PROD1 WHPST PULD P Pressure deploy BHA #3 with WFT V 0.0 76.6 00:00 01:18 fixed bend motor, NS 2.80 window mill, NS 2.79 string reamer and 10' pup. Make up to coil and surface test. 9/13/2019 9/13/2019 1.60 PROD1 WHPST TRIP P RIH BHA#3 76.6 9,210.0 01:18 02:54 9/13/2019 9/13/2019 0.10 PROD1 WHPST DLOG P Log K1 for +.5' 9,210.0 9,238.0 02:54 03:00 9/13/2019 9/13/2019 0.40 PROD1 WHPST TRIP P Continue in well. Dry tag whipstock @ 9,238.0 9,433.0 03:00 03:24 9433'. PUH, PUW=40K 9/13/2019 9/13/2019 5.25 PRODi WHPST WPST P Bring pumps on 1.79 BPM @ 3631 9,433.0 9,435.3 03:24 08:39 PSI FS, BHP=3927. Call milling pinch point @ 9432.4 9/13/2019 9/13/2019 3.20 PRODt WHPST WPST P Mill exited the casing, continue time 9,435.3 9,459.0 08:39 11:51 milling with string reamer at exit. 9/13/2019 9/13/2019 0.85 PROD1 WHPST REAM P Ream rasing exit @ 60 fph/1.0' fpm, 9,459.0 9,459.0 11:51 12:42 w/sweep, perform dry drift (clean) 9/13/2019 9/13/2019 1.50 PRODi WHPST TRIP P POOH, chasing sweep to 9,459.0 73.5 12:42 141: j 1 surface.PJSM 9/13/2019 9/13/2019 1.20 PROD1 WHPST PULD P Tag up at surface, PUD milling BHA 73.5 0.0 14:12 15:24 "` Note: Mills within gauge 2.80"ori no -go 9/132019 9/13/2019 0.30 PROD1 DRILL CTOP P Slide cart forward and install nozzle, 0.0 0.0 15:24 15:42 stab INJH, get stack and surface lines, unstab INJH, brake n=le off, 9/13/2019 9/13/2019 1.30 PROD? DRILL PULD P PD pre -loaded build BHA #4 w/2.4° 0.0 72.2 15:42 17:00 ako motor Page 2122 ReportPrinted: 1 01112 01 9 Operations Summary (with Timelog Depths) 1c-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Start Time End Time our (hr) Phese Op Cade Activity Cade Time P -T -X Operation (10(13) End Depth (WE) 9/13/2019 9/1312019 1.80 PRODI DRILL TRIP P Tag up, reset counters, RIH wtih BHA 72.2 9,200.0 17:00 18:48 #4 Build assembly with 2.4" ako motor, and new HHC bit 9/13/2019 9/13/2019 0.10 PRODI DRILL DLOG P Log Kt for +3.5' correction, lose EDC, 9,200.0 9,228.0 18:48 18:54 PUW=40K, RIW=16.9 9/13/2019 9113/2019 0.20 PROD1 DRILL TRIP P Continue in hole. good pass through 9,228.0 9,460.0 18:54 19:06 window. Bobble at BOW 9/13/2019 9/13/2019 0.60 PROD1 DRILL DRLG P 9460', Drill, 1.8 BPM @ 3742 PSI FS, 9,460.0 9,495.0 19:06 19:42 BHP=3841 9/13/2019 9/13/2019 0.40 PROD1 DRILL WPRT P Stall, PUW=40K. PUH through 9,495.0 9,200.0 19:42 20:06 window. tie into K1 9/13/2019 9/13/2019 0.30 PROD1 DRILL DLOG P Log Ki for+1'. RBIH through window. 9,200.0 9,470.0 20:06 20:24 1 Log RA @ 9437.5. TOWS=9430.5, TOW=9432.5, BOW=9435.5 9/13/2019 9/13/2019 0.10 PROD1 DRILL TRIP P Trip in to Drill 9,470.0 9,495.0 20:24 20:30 9/13/2019 9/14/2019 3.50 PROD1 DRILL DRLG P 9495', Drill, 1.8 BPM @3676 PSI FS, 9,495.0 9,709.0 20:30 00:00 BHP=3888. Hard time getting past 9495. Low differential with High DHWOB. Drilling break @ 9500 ROP+ 60-80 FPH 9/14/2019 9/14/2019 0.40 PROD1 DRILL DRLG P Continue drilling build section, 1.8 9,709.0 9,745.0 00:00 00:24 1 BPM @ 3676 PSI FS, BHP=3906 9/14/2019 9/14/2019 2.20 PROD1 DRILL TRIP P Call end of build, Pump sweeps, 9,745.0 72.0 00:24 02:36 PUW=42k. recip twice through 7" casing. AVG DLS=47.25` 9/14/2019 9/14/2019 0.70 PROD1 DRILL PULD P At surface, Tag up and space out. 72.0 72.0 02:36 03:18 PUD BHA#4. 9/14/2019 9/14/2019 1.70 PROD1 DRILL PULD T Pull BHA into lubricator assembley 72.0 72.0 03:18 05:00 hung @ 10 out of -18 turns of slickline winch. Try closing master to move BHA around. No good. Try both swabs them Aannular bag in tum. Try pumping across the top. try pumping into tangos. No good. Pressure up surface safely valve, No good. Dump SSSV, unable to bleed off well. Try pressuring up WH. No good. Consult town. Shift fluid around to line up 12PPG fluid down well for kill. 9/14/2019 9/14/2019 1.00 PROD1 DRILL PULD T Line up and bullhead 110 BBIs 12.0 72.0 72.0 05:00 06:00 PPG down tubing @ 3 BPM, j WHP=1175 9/14/2019 9114/2019 1.10 PRODI DRILL PULD T Monitor WHIP 749 psi, pressure 72.0 72.0 06:00 07:06 dropping,continue to monitor WHIP 81 psi WHP, open choke bleed pressure to 70 psi, shut choke back in, and continue to monitor WHPWHP 10 psi, open whiney on PDL, well is dead, PJSM 9/14/2019 9/14/2019 0.50 PROD1 DRILL PULD P LD, build assembly over a dead well 72.0 0.0 07:06 07:36 9/14/2019 9114/2019 0.75 PROD1 DRILL PULD P PU lateral assembly over a dead well, 0.0 80.3 07:36 08:21 inspect pac-off 9/14/2019 9/14/2019 1.00 PRODI DRILL DISP T Displace coil to 12.0 ppg KWF wtih 80.3 488.0 08:21 09:21 open EDC 9/14/2019 9/14/2019 1.50 PROD1 DRILL TRIP P RIH, surface lest agitator @ 488', 488.0 9,280.0 09:21 10:51 attempt to obtain screen shot 9/14/2019 9/14/2019 0.25 PROD? DRILL DLOG P Log formation for depth control (0.0') 9,280.0 9,393.0 10:51 11:06 9114/2019 9114/2019 0.60 PRODI DRILL TRIP P Continue IH 9,393.0 9,730.0 11:06 11:42 Page 3122 Report Printed: 101112019 Operations Summary (with Timelog Depths) 1c-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log smn oepm Start Time End Time Our(hr) Phase Op Code Ac9Nty Cafe Time P -T -X Operatlon Me) End CepM(flKB) 9/14/2019 9/14/2019 1.75 PROD1 DRILL DISP T Displace well to new drilling fluid, 9,730.0 9,730.0 11:42 13:27 System #1,PUH slowly. 9/14/2019 9/14/2019 1.30 PROD1 DRILL DRLG P OBD, 1.9 bpm at 4,555 psi, F5=1,442 9,730.0 9,953.0 13:27 14:45 psi, WHP=256, BHP=3,953, IA=2, OA=64 " Note: Re -head drillers side Slickline Unit. 9/14/2019 9/14/2019 1.25 PROM DRILL DRLG P OBD, 1.6 bpm at 3,914 psi, 9,953.0 10,150.0 14:45 16:00 Diff=1,240, WHP=219, BHP=3,912, IA=7, OA=70, increase pump back up to full drilling rate 1.9 bpm at 4,555 psi, Diff --1,264 psi. 9/14/2019 9/14/2019 0.30 PROD1 DRILL WPRT P Short wiper up hole to the EOB 9,745', 10,150.0 9,745.0 16:00 16:18 PUW=45 k 9/14/2019 9/14/2019 0.25 PROD1 DRILL WPRT P Wiper back in hole, RIW 14 k 9,745.0 10,150.0 16:18 16:33 9/14/2019 9/14/2019 0.60 PROD1 DRILL DRLG P BOBD, 1.9 bpm at 4,550 psi, 10,150.0 10,270.0 16:33 17:09 Diff --1,280 psi, WHP=239, BHP=3,939, IA=8. OA=71 9114/2019 9/14/2019 0.10 PROD1 DRILL WPRT P Pull BHA wipe, grab survey, 10,270.0 10,270.0 17:09 17:15 PUW=45K 9/14/2019 9/14/2019 1.85 PROD? DRILL DRLG P 10„270', Drill, 1.8 BPM @ 4425 PSI 10,270.0 10,428.0 17:15 19:06 FS, BHP=3943 9/14/2019 9/14/2019 0.10 PROD1 DRILL WPRT P 10428, BHA Wiper, PUW=57K 10,428.0 10,428.0 19:06 19:12 9/1412019 9/14/2019 2.20 PRODt DRILL DRLG P 10,428', Drill, 1.8 BPM @ 4219 PSI 10,428.0 10,554.0 19:12 2124 FS, BHP=3920, 10,513' faulted out of zone. Gamma 160+, ROP 30FPH 9/1412019 9/14/2019 1.00 PROD1 DRILL WPRT P 10554 wiper to window with sweeps, 10,554.0 9,300.0 21:24 22:24 PUW=50K, Jet 7" up to 9300' with sweeps, High gamma area good on this wiper 9/14/2019 9/14/2019 0.10 PROM DRILL WPRT P Wiper back through window 9,300.0 9,445.0 22:24 22:30 9/14/2019 9/14/2019 0.10 PROM DRILL DLOG P Log RA marker for+4' correction 9,445.0 9,480.0 22:30 22:36 9/14/2019 9/14/2019 0.50 PROM DRILL WPRT P RBIH to drill, No poor hole conditions 9,480.0 10,556.0 22:36 23:06 9/14/2019 9/15/2019 0.90 PROW DRILL DRLG P 10556', Drill, 1.8 BPM @ 4361 PSI 10,556.0 10,586.0 23:06 00:00 FS, BHP=3925 9/15/2019 9115/2019 0.80 PROM DRILL DRLG P 1586', Drill 1.8 BPM @ 4361 PSI FS, 10,586.0 10,638.0 00:00 00:48 BHP=3951 9/15/2019 9115/2019 0.10 PROD1 DRILL WPRT P BHA wiper, PUW=50K 10,638.0 10,638.0 00:48 00:54 9/15/2019 9/15/2019 2.40 PROD1 DRILL DRLG P 10638', Drill, 1.81 BPM @ 4360 PSI 10,638.0 10,810.0 00:54 03:18 FS, BHP=3945 9/15/2019 9/15/2019 0.20 PROD1 DRILL WPRT P Pull mini wiper. Get surveys off bottom 10,810.0 10,810.0 03:18 03:30 due to high vibration levels, PUW=47K 9/15/2019 9/15/2019 2.30 PROD1 DRILL DRLG P 1081', Drill 1.80 @ 4360 PSi FS, 10,810.0 10,954.0 03:30 05:48 BHP=3955 9/15/2019 9/15/2019 0.30 PROD1 DRILL WPRT P Wipe up hole, PUW 45 k 10,954.0 9,980.0 05:48 06:06 9/15/2019 9/15/2019 0.30 PROD1 DRILL WPRT P Wiper back in hole, RIW 12 k 9,980.0 10,954.0 06:06 06:24 9/15/2019 9/15/2019 1.00 PROM DRILL DRLG P BOBD, 1.88 bpm at 4,882 psi, 10,954.0 11,095.0 06:24 07:24 Diff -1,252 psi, WHP=218, BHP=3,995, IA=22, OA=87 9/15/2019 9/15/2019 0.50 PROD1 DRILL WPRT P Lost returns (0.4 bpm), PUH PUW 45 11,095.0 11,095.0 07:24 07:54 k, 10690'. RBIH, slowly healing up. Page 4122 Report Printed: 1011/2019 Operations Summary (with Timelog Depths) IC-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time our (hr) Phase Op Cade Activity Coda Time P-T-X Operation Me) End Depth (ftKa) 9/15/2019 9/15/2019 1.90 PROM DRILL DRLG P BOBO, 1.88 bpm at 4,885 psi, 11,095.0 11,264.0 07:54 09:48 Diff-1,250, WHP=234, BHP=3,995, IA=22, OA=87 9/15/2019 9/15/2019 0.85 PROD1 DRILL WPRT P Lost all returns, pull wiper to the 11,264.0 9,180.0 09:48 10:39 window, PUW 52 k 9/15/2019 9/15/2019 0.20 FROM DRILL DLOG P Log K1 marker (+3.0) 9,180.0 9,233.6 10:39 10:51 9/15/2019 9/15/2019 0.60 PROD1 DRILL WPRT P Wiper back in hole, RIW 17 k, no 9,233.6 11,264.0 10:51 11:27 returns, Gose choke, continue RIH 630 psi WHIP. 11.7ppg ECD 9115/2019 9115/2019 0.85 PRODi DRILL DRLG P BOBD, 1.88 bpm at 4,435 psi, 11,264.0 11,350.0 1127 12:18 Diff=1,250, WHP=234, BHP=3,995, IA=22, OA=87 9/15/2019 9/1512019 1.00 PROD1 DRILL DRLG P BOBD, snubbing -5 k CTSW, 11,350.0 11,376.0 12:18 13:18 DHWOB=0.4-1.3 k 1.63 bpm at 4,060 psi, Diff--970, WHP=251, BHP=4,050, IA=8, OA=84 9/15/2019 9115/2019 3.25 PROD1 DRILL DRLG P BOBO, 1.58 bpm at 4,430 psi, 11,376.0 11,664.0 13:18 16:33 Diff=970, WHP=251, BHP=4,050, IA=8, OA=84 9/15/2019 9/15/2019 0.50 PROD1 DRILL WPRT P Wiper up hole, PUW 52 k 11,664.0 10,664.0 16:33 17:03 9/15/2019 9/15/2019 0.30 PRODt DRILL WPRT P Wiper back in hole, RIW 6 k 10,664.0 11,664.0 17:03 17:21 9/1512019 9115/2019 1.40 PRODi DRILL DRLG P BOBO, 1.81 BPM @ 4865 PSI FS, 11,664.0 11,808.0 17:21 16:45 BHP=4093, Choke shut 9/15/2019 9/15/2019 0.10 PROD1 DRILL WPRT P BHA wiper, PUW=49K 11,808.0 11,808.0 18:45 18:51 9/15/2019 9/1512019 3.15 PROD1 DRILL DRLG P 11,808', Drill, 1.8 BPM @ 5005 PSI 11,808.0 11,962.0 18:51 22:00 1 1 FS, BHP=4112, Choke shut 911512019 9116/2019 2.00 PROD1 DRILLWPRT P 11962, Call TO @ X-Y coordinate. 11,962.0 9,420.0 22:00 00:00 Pump 10 X 10 Sweeps. Open choke at 7 inch. Pumping 1.8 Returns @ 1.2 BPM 9/16/2019 9/16/2019 1.90 PROD1 DRILL WPRT P On wiper trip to swab. Unloaded 9,420.0 70.0 00:00 01:54 cuttings @ - 500'. Jog back in hole to 1000'. Continue out of well. 9116/2019 9116/2019 1.70 PROD1 DRILL DRLG P At surface, Tag up, reset counters, 70.0 9,200.0 01:54 03:36 Trip back in well 9/16/2019 9/16/2019 0.10 PROM DRILL HOG P Log K1 for-1' correction 9,200.0 9,280.0 03:36 03:42 9/16/2019 9/16/2019 0.40 PROD1 DRILL TRIP P RIH to 9401. Get static pressure. 9,280.0 9,401.0 03:42 04:06 sensor depth TVD 6473.6, Start test a 3843 annular, Bled down to 3731 PSI Fri 10 minutes. Down to 11.1 PPG MW 9/16/2019 9/16/2019 1.00 PROD1 DRILL TRIP P Continue in hole to confirm TO 9,401.0 11,964.0 04:06 05:06 @11,964, RIW=14.3, PUW=45K, Trip out pumping 8.5 Beaded liner pill 9/16/2019 9/16/2019 0.90 PROD1 DRILL TRIP P POOH, pumping 8.5 ppg beaded liner 11,964.0 9,539.0 05:06 0600 pill 9/1612019 9/16/2019 2.00 PROD1 DRILL TRIP P Continue POOH pumping 11.4 ppg 9,539.0 80.3 06:00 08:00 completion fluid 9/1612019 9/16/2019 0.50 PROD1 DRILL OWFF P At surface, check well for flow, PJSM 80.3 80.3 08:00 08:30 `• Note: Static loss rate 9 bbl/hr 9/16/2019 9/1612019 1.00 PROD1 DRILL PULD P LD drilling assembly#5 80.3 0.0 08:30 09:30 9/1612019 9116/2019 0.35 COMPZ1 CASING PUTB P Prep RF for liner operations 0.0 0.0 09:30 09:51 9/16/2019 9/16/2019 3.20 COMPZ1 CASING PUTB P Start PU Lt slotted liner completion 0.0 2,101.3 09:51 13:03 w/53 joints and Liner top billet Page 5122 ReportPrinted: 10/112019 Operations Summary (with Timelog Depths) 1 C-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log stars Depm start Tme End Time Phew Op Code Activity Code Time P -T -X Operation M13) End Depen (WS) 6/2019 9/16/2019 COMPZ1 CASING PULD P PJSM, PU CoilTrak tools.2,101.3 2,145.5 13:03 13:57 9/16/2019 9/1612019 rDur(hr) COMPZ7 CASING RUNL P Tag up, reset counters, RIH with BHA 2,145.5 10,374.0 13:57 15:42 Note: Hanging weight 20 k surface weight 9/16/2019 9/16/2019 0. COMPZ1 CASING RUNL P Initial set down 10,374', PUW 38 k 10,374.0 10,376.0 15:42 15:54 with a little drag, work pipe for a short period, continue in hole 9/16/2019 9/16/2019 1.30 COMM CASING RUNL P Continue IH, set down @ 11,568', 10,376.0 11,568.0 15:54 17:12 TOL=9,466.7', CTC=9422.7', work pipe unable to move up or down per the weak point (billet 24k), GS rated 49k 9/16/2019 9116/2019 0.30 COMPZ1 CASING RUNL T Dicuss with town team, bring pump 11,568.0 11,568.0 17:12 17:30 online, release liner, PUW 35 k, build 50 bbl beaded 11.4 ppg liner running pill, RBIH latch up to liner, PUW 44 k, seems we are re -latched into liner, standby for liner pill 9/16/2019 9/1612019 0.70 COMPZ1 CASING RUNL T Standby for beaded liner running pill 11,568.0 11,566.0 17:30 18:12 9/16/2019 9/16/2019 3.00 COMM CASING RUNL T Pump 50 BBI beaded liner running pill 11,568.0 18:12 21:12 down backside. CT in compression. Pump 70 BBIs -20 BBIs pill past window. Work pipe +65K to -9K. No go. Pump 5 more bbls. CT in tension. Work pipe no good. Go to neutral weight pump 5 bbls down CT Work pipe No good. Pump down back side 1.5 BPM while working pipe. No movement. Consult town. Trip for agitator 9116/2019 1.70 COMPZ1 CASING TRIP T Line up down CT, Pump 1.5 BPM. 11,568.0 70.0 22:54 Release off fish. PUW=40K, TOF=9469, Remove liner length left in hole from counters F22:54 9116/2019 1.00 COMPZt CASING PULD T At surface, PJSM lay down BHA on 70.0 50.3 23:54 dead well. No Flow test good. Unstab injector. Inspect CT for flat spots. Back off GS. M/U agitator and GS spear. M/U to coil and surface test. Check pack offs 911712019 0.10 C0MPZ1 CASING TRIP T Trip in hole BHA #7 50.3 480.0 00:009/17/2019 1.60 COMPZI CASING TRIP T Stop at 480', Shallow test agitator. 4800 9,185.0 01:36 Continue in well9/17/2019 r23:54 0.30 COMPZ1 CASING DLOG T Log K1 for+1.5' 9,185.0 9,221.0 01:54 9/1712019 0.10 COMPZt CASING TRIP T Continuein well. Clean pass through 9,221.0 9,467.0 02:00 window. Tag up @ 9467. Work pipe two cycles PUW=58, DHWOB=10K 9117/2019 9/17/2019 0.70 COMPZ1 CASING CIRC T Put CT in light tension PUW=45K. 9,467.0 9,467.0 02:00 02:42 Bring pump on. Agitating. Roll CT to 6.5 PPG recovering 11.4 9/17/2019 911712019 0.10 COMM CASING CIRC T Coil swapped to 8.5 PPG Duo vis 9,467.0 9,467.0 02:42 02:48 Iight.Been agolaling in light tension. Shut down pump. Work pipe. Pull out of billet @ 62K DHWOB=-16.8. Try to relatch. No good. 9/1712019 9/17/2019 0.50 COMPZ1 CASING CIRC T at down on fish. 19K. Continue to 9,467.0 9,467.0 02:48 03:18 agitate down. 1.7 BPM, Recovering KWF from well DHWOB-3.5K, Page 6122 Report Printed: 101112019 Operations Summary (with Timelog Depths) 1C-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Tne End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (Val I End Depth (fe(B) 9/17/2019 9/17/2019 0.50 COMPZ1 CASING CIRC T Bring DHWOB up to 4.7K, Continue 9,467.0 9,467.0 03:18 03:48 agitating down 9/17/2019 9/17/2019 0.40 COMPZI CASING CIRC T Work pipe down, 8.5 PPG all around. 9,467.0 9,467.0 03:48 04:12 Bring annular down from 3650 to 3650PSI. Work pipe down 9/17/2019 9/17/2019 0.80 COMPZ1 CASING CIRC T Line up down backside, 50 BBI 9,467.0 9,467.0 04:12 05:00 beaded liner running pill in 11.4, displace bill around BHA 9/17/2019 9/17/2019 2.25 COMPZ1 CASING CIRC T Continue agitating with 8-9k CTSW 9,467.0 9,467.0 05:00 07:15 stacked out 8 k 9/17/2019 9/17/2019 1.25 COMPZ1 CASING CIRC T Continue agitating with 8-9k CTSW 9,467.0 9,467.0 07:15 08:30 stacked out 8 k, build 50 bbl 8.5 ppg beaded tubed pill 9/17/2019 9/17/2019 1.75 COMPZ1 CASING CIRC T Diplace 50 bbl pill down the back side 9,467.0 9,467.0 08:30 10:15 9/17/2019 9/17/2019 1.30 COMPZ1 CASING CIRC T Pill displaced, work pipe, PUW 35 k, 9,467.0 9,467.0 10:15 11:33 RIW 14 k, no movemen, line back down coil, stack out 13.9k, no movement, stackout again 2.5k agitate some more. 9/17/2019 9/17/2019 1.40 COMPZ1 CASING TRIP T Unable to move liner assembly, POOH 9,467.0 45.3 11:33 12:57 9/17/2019 9/17/2019 1.20 COMPZI CASING PULD T At surface, space out, PUD BHA#7 45.3 0.0 12:57 14:09 BOT GS Spear, and NOV Agitator 9/17/2019 9/17/2019 1.00 PROD2 STK PULD P PU/MU/PD Drilling/Build LI -01 lateral 0.0 62.6 14:09 j 1509 9/17/2019 9/17/2019 1.50 PROD2 STK TRIP P Tag up, reset counters, RIH 62.6 9,205.0 15:09 16:39 9/17/2019 9/17/2019 0.25 PROD2 STK DLOG P Log K1 for depth control 9,205.0 9,226.0 16:39 16:54 9/17/2019 9/17/2019 0.30 PROD2 STK TRIP P Continued IH tagged TOB at 9,467', 9,228.0 9,467.0 16:51 17:12 stacked out 1.6 k 9/17/2019 9/17/2019 0.20 PROD2 STK KOST P PUH, PUW 38 k, obtain 9,467.0 9,467.0 17:12 1724 parameters1.80 bpm 4,132 psi, Diff=428 psi, WHP=354, BHP=3,861, IA=17, OA=81 9/17/2019 9/17/2019 2.10 PROD2 STK KOST P Kickoff billet as per RP, time mill 1', 2', 9,467.0 9,470.0 17:24 19:30 and 3' 9/17/2019 9/17/2019 0.30 PROD2 STK KOST P Push on it to 9,472', seem to be 9,470.0 9,472.0 19:30 19:48 stacking weight, PU to PUW 35 k, continue kicking off with controled WOB 9/17/2019 9/17/2019 1.10 PROD2 DRILL DRLG P Drill ahead, 1.78 bpm at 4,234 psi, 9,472.0 9,557.0 19:48 20:54 Diff=709, WHP=354, BHP=3,863, IA=17, OA=81 9/17/2019 9/17/2019 0.30 PROW DRILL WPRT P Stall motor, PUW 41 k, continue up 9,557.0 9,250.0 20:54 21:12 hole to dry drift kickoff point, slight bobble pulling across billet 9/17/2019 9/17/2019 0.20 PROD2 DRILL WPRT P Dry drift kickoff point (clean), Continue 9,250.0 9,557.0 21:12 21:24 IH 9/17/2019 9/17/2019 1.60 PROM DRILL DRLG P BOBD, 1.79 bpm at 4,400 psi, 9,557.0 9,720.0 21:24 23:00 Diff --532, WHP=351, BHP=3,895, IA=22, OA=88 9/17/2019 9/1712019 0.30 PROD2 DRILL WPRT P TD, build section, wiper to the window, 9,720.0 9,400.0 23:00 23:18 PUW 37 k, Jog 7inch, open EDC 9/17/2019 9/18/2019 0.70 PROD2 DRILL TRIP P POOH, At 5841' al midnight 9,400.0 5,841.0 23:18 00:00 9/18/2019 1911812019 1.10 PROM DRILL TRIP P Continue out of well 5,841.0 62.0 00:00 01:06 9/18/2019 9118/2019 1.10 PROD2 DRILL PULD P At surface, Tag up and space out, 62.0 0.0 01:06 02:12 PJSM PUD BHA #8. Page 7122 ReportPrinted: 10/112019 operations Summary (with Timelog Depths) IC -06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Depth Stan Time End Time Phase Op Code Mvay Corte Time P -T -X Operation (flKa) End Depth (WEI) 9/18/2019 9/18/2019PROD2 DRILL BOPE P Pick up BOPE test joint perform Bi- 0.0 0.0 02:12 02:42 weekly BOPE function test 9118/2019 971612019 r PROD2 DRILL PULD P PD BHA#9 from pre loaded PDL..7° 0.0 78.3 02:42 03:30 AKO motor, Hyc A3 bi center. Make upto coil and surface test. Check pack offs. Tag up and reset counters. 9118/019 9/18/2019 PROD2 DRILL TRIP P RIH BHA #9, Shallow test agitator@ 78.3 9,205.0 03:30 05:24 500' 9/1812019 9/18/2019 0.10 PROD2 DRILL DLOG P Log K1 for -.5' 9,205.0 9,231.0 05:24 05:30 9/18/2019 9/18/2019 0.40 PROD2 DRILL TRIP P Continue in well, Set down in bottom 9,231.0 9,720.0 05:30 05:54 of window 9437'. PUH roll pump then go through window clean. Clean past billet 911812019 9118/2019 2.80 PROD2 DRILL DRLG P 9720', Drill 1.81 BPM @ 5458 PSI FS, 9,720.0 10,020.0 05:54 08:42 BHP=3977 9/18/2019 9/18/2019 0.60 PROD2 DRILL WPRT P 10020', Wiper trip to window, perform 10,020.0 9,451.0 08:42 09:18 MAD pass 9725 to 9451 9/18/2019 9/18/2019 0.10 PROD2 DRILL DLOG P 9451 Log RA marker Tor +2'correction 9,451.0 9,476.0 09:18 09:24 9/18/2019 9/18/2019 0.20 PROD2 DRILL WPRT P 9476 RBIH to drill 9,476.0 10,020.0 09:24 09:36 9/18/2019 9/18/2019 2.20 PROD2 DRILL DRLG P 10020', Drill. 1.8 BPM @ 5595 PSI 10,020.0 10,420.0 09:36 11:48 FS, BHP=4006 9/18/2019 9/18/2019 0.70 PROD2 DRILL WPRT P 10420', Wiper trip, 1000', PUW=35K 10,420.0 10,420.0 11:48 12:30 9/18/2019 9/18/2019 2.10 PROD2 DRILL DRLG P 10420', Drill, 1.8 BPM @ 5773 PSI 10,420.0 10,559.0 12:30 14:36 FS, BHP=4104 9/18/2019 9/18/2019 0.10 PROD2 DRILL WPRT P BHA wiper, PUW=34K 10,559.0 10,559.0 14:36 14:42 9/18/2019 9/18/2019 1.40 PROD2 DRILL DRLG P 10559', Drill, 1.8 BPM @ 5844 PSI 10,559.0 10,759.0 14:42 16:06 FS, BHP=4032. LSRV up to 57K. Consult mud eng. Get LSRV back to plan 9/18/2019 9/18/2019 0.10 PROD2 DRILL WPRT P 10759', Pick up to get new pressures, 10,759.0 10,759.0 16:06 16:12 PUW=37K 9/18/2019 9/18/2019 0.50 PROD2 DRILL DRLG P 10759', Drill, 1.8 BPM @5690 PSI FS, 10,759.0 10,820.0 16:12 16:42 DHWOB=3.1 K 9/18/2019 9/18/2019 0.90 PROD2 DRILL WPRT P 10,820'. Wiper to window, Jet 7" 10,820.0 9,196.0 16:42 17:36 casing. Tie in for depth control 9/18/2019 9/18/2019 0.10 PROD2 DRILL DLOG P Log K1 for+3' correction 9,196.0 9,232.0 17:36 17:42 1 9/18/2019 9/18/2019 0.80 PROD2 DRILL WPRT P Wiper in-hole, RIW = 13K, set -down 9,232.0 10,820.0 17:42 18:30 6.51K WOB at BOW, got through on second attempt 9/18/2019 9/18/2019 4.10 PROD2 DRILL DRLG P Drilling, FS = 1300 psi @ 1.8 bpm, 10,820.0 11,218.0 18:30 22:36 CWT = 12.8 @ 1 K WOB, annular - 3982 psi, WHIP = 122 psi, 11.4 ppg @ widnow, pump = 5870 psi, dip = 1442 psi drilling, IA= 39 psi, OA= 104 psi, 97% returns, PUW = 38K @ 11,144' Lower ROP 11,178'- 11,190'(-60 fph) 9/18/2019 1911812019 0.40 PROD2 DRILL WPRT P Wiper up -hole, PUW=40K 11,218.0 10,270.0 22:36 23:00 9/18/2019 9/18/2019 0.40 PROD2 DRILL WPRT P Wiper in-hole, RIW = 11.9K 10,270.0 11,218.0 23:00 23:24 9/18/2019 9/19/2019 0.60 PROD2 DRILL DRLG Drilling, FS = 1300 psi @ 1.8 bpm, 11,218.0 11,268.0 23:24 00:00 CWT = 7.41K @ 2K WOB, annular = IP 4039 psi, WHP = 101 psi, pump = I 6118 psi Page 8122 Report Printed: 10/112019 Uperations Summary (with Timelog Depths) 1C-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log 5(art Depth Stant Time EM Time our (hr) Phase ActivityCode Time P -T -X Opem6on MM) End Depth (MB) 9/19/2019 9/19/2019 2.50 PROD2 DRLG P Drilling, FS = 1300 psi @ 1.8 bpm, 11,268.0 11,544.0 00:00 02:30 CWT = 6.7K @ 1.9K WOB, pump = 6024 psi, annular = 4048 psi, WHIP = rDRILL 70 psi, swap to system #3, new mud hits bit at 11,479' 9/19/2019 9/19/2019 0.90 PROM DRLG 15 Drilling, new mud all the way around, 11,544.0 11,620.0 02:30 03:24 FS = 1284 psi @ 1.8 bpm, CWT = 4K @ 1.71K WOB, annular = 3995 psi, WHIP = 368 psi, pump = 5757 psi 9/19/2019 9/19/2019 0.30 PROD2 DRILL WPRT P Wiper up -hole, PUW=44K 11,620.0 10,620.0 03:24 03:42 9/19/2019 9/19/2019 0.40 PROM DRILL WPRT P Wiper in-hole, RIW = 8K, WOB bobble 10,620.0 11,620.0 03:42 04:06 I a1-11,554'(1.1 K) 9/19/2019 9/19/2019 2.80 PROD2 DRILL DRLG P Drilling, FS = 1290 psi @ 1.8 bpm, 11,620.0 11,753.0 04:06 06:54 CWT = 8.71K @ 1.2K WOB, annular = 4000 psi, WHIP = 343 psi, pump = 5710 psi, harder drilling beginning at ^11,625' (PUW's - 47K) 9/19/2019 9/19/2019F2.20 PROD2 DRILL WPRT P Running low on surface weight. Hard 11,753.0 9,205.0 06:54 08:18 to maintain steady state drilling. Pull wiper to tubing tail. PUW=53K. recip 7" X2. 9/19/2019 9/19/2019 PROM DRILL DLOG P Log K1 for+5.5' 9,205.0 9,225.0 08:18 08:30 9/19/2019 9/19/2019 PROM DRILL WPRT P Continue wiper back in hole to drill 9,225.0 11,754.0 08:30 09:18 9/19/2019 9/19/2019 PROD2 DRILL DRLG P 11754', Drill, 1.81 BPM @ 5586 PSI 11,754.0 11,880.0 09:18 11:30 FS, BHP=4035, RIW=6.8K, DHWOB=I.3K. ROP=41 FPH 9/19/2019 9/19/2019 0.20 PROD2 DRILL WPRT P 11880% Pull 100' BHA wiper, 11,880.0 1,188.0 11:30 11:42 PUW=43K 9/19/2019 9/19/2019 3.10 PROM DRILL DRLG P 11,880', Drill, 1.81 BPM @ 5580 PSI 1,188.0 12,034.0 11:42 14:48 FS, BHP=4003, RIW=-5K. BDHWOB=3K 9/19/2019 9/19/2019 0.40 PROD2 DRILL WPRT P Pu11250'wiper, PUW=38K 12,034.0 12,034.0 14:48 15:12 9/19/2019 9/19/2019 2.00 PROD2 DRILL DRLG P 12,0341, Drill, 1.80 BPM @ 5780 PSI 12,034.0 12,138.0 15:12 17:12 FS, BHP=4102, RIW=2K, DHWOB=2.2K 9/19/2019 9/19/2019 0.30 PROD2 DRILL DRLG P Drilling, 1.8 bpm, annular = 4150 psi, 12,138.0 12,150.0 17:12 17:30 WHIP = 215 psi, pump = 6040 psi, pumping beads to aid in weight transfer (20 bbl in straight drilling Fluid) 9/19/2019 9/19/2019 0.30 PROD2 DRILL WPRT P Wiper up -hole, PUW = 39K 12,150.0 11,153.0 17:30 17:48 9/19/2019 9/19/2019 0.50 PROD2 DRILL WPRT P Wiper in-hole, RIW=8.8K 11,153.0 12,150.0 17:48 18:18 9/19/2019 9/19/2019 2.80 PROD2 DRILL DRLG P Drilling, FS = 1338 psi @ 1.8 bpm, 12,150.0 12,270.0 18:18 21:06 CWT =8.3K@ 1.31K WOB, annular= 4089 psi, WHIP = 181 psi, pump = 6164 psi, difficult drilling when back on bottom, struggling w/ weight transfer, snubbing to -5K & 0.81K WOB, pumping 25 bbl beaded pills to good effect, avg ROP = 43 fph 9/19/2019 9/20/2019 2.90 PROD2 DRILL DRLG P Drilling, annular =4167 psi, WHIP = 12,270.0 12,379.0 21:06 00:00 136 psi, pump = 5979 psi, struggling w/ weight transfer unless beads are coming around (continue pumping 25 bbl beaded pills built from active), PUW = 43K from 12,373', struggle to get to bottom after BHA wiper w/o beads on back -side Page 9122 ReportPrinted: 101112019 Uperations Summary (with Timelog Depths) 1 C-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Coe Time P-T-X Operation (ftKB) End Depth (8K13) 9/20/2019 9/20/2019 3.00 PROD2 DRILL DRLG P Drilling, annular =4129 psi, WHP = 12,379.0 12,471.0 00:00 03:00 146 psi, pump = 6160', drilling through low ROP interval, WOB = 2.6K @ 17 fph, break out Pump 50 bbl lubed pill (2% 776 / 1% LoTorq), hits bit at 12,417'), limited bennefit 9/20/2019 9/20/2019 2.30 PROD2 DRILL DRLG P Drilling,CWT=-6K,WOB=0.6K, 12,471.0 12,550.0 03:00 05:18 annular= 4137 psi, WHIP = 128 psi, pump = 6103 psi, continue pumping beaded pills 9/2012019 9/20/2019 1.60 PROD2 DRILL WPRT P Wiper to window and jet 7 inch casing 12,550.0 9,205.0 05:18 06:54 X2, PUW=39K 9/20/2019 9/20/2019 0.10 PROD2 DRILL DLOG P Log tie in for +6' 9,205.0 9,224.0 06:54 07:00 9/2012019 9/20!2019 1.90 PROD2 DRILL WPRT P Wiper trip back in hole 9,224.0 12,550.0 07:00 08:54 9/2012019 9/20/2019 3.50 PROD2 DRILL DRLG P 12,550' Drill 12,550.0 12,672.0 08:54 12:24 9120/2019 9/20/2019 0.80 PROD2 DRILL DRLG P Pull off bottom. Free spin has been 12,672.0 12,685.0 12:24 13:12 gradually climbing at 5946 @ 1.8 BPM. Lower flow rate to 1.7. Free spin now 5685. Mud @ 40K LSRV 9/20/2019 9/20/2019 3.10 PROD2 DRILL TRIP T Pressures still high. ROP low for being 12,685.0 73.5 13:12 16:18 in zone. No indications we are not in zone. Trip to inspect BHA 9/2012019 9/20/2019 1.10 PROD2 DRILL PULD T At surface, PJSM. PUD BHA #9, bit 73.5 0.0 16:18 17:24 came out graded a 1-1 9/20/2019 9/20/2019 1.00 PROD2 DRILL PULD T PD BHA #10 Lateral Assembly(NOV 0.0 73.0 17:24 18:24 agitator, new 0.7° AKO motor, RB Baker P104 bit), slide in cart, change out pack-offs, MU to coil, tag up, set counters 9/2012019 9/20/2019 1.80 PROD2 DRILL WPRT T RIH, close EDC 73.0 9,200.0 18:24 20:12 Shallow test agitator: = 546', 1.8 un bpm, FS= 1157 psi, pump = 5928 psi 9/20/2019 9120/2019 0.20 PROD2 DRILL DLOG T Log Kt for +4.5' correction, PUW = 9,200.0 9,234.0 20:12 20:24 35K 9!20/2019 9/20/2019 1.10 PROD2 DRILL WPRT T Continue RIH 9,234.0 12,685.0 20:24 21:30 9/20/2019 9/20/2019 0.80 PROD2 DRILL DRLG P Drilling, FS = 1043 psi @ 1.8 bpm, 12,685.0 12,732.0 21:30 22:18 CWT= 7K @ 1.8K WOB, annular= 4157 psi, WHP = 50 psi, pump = 5150 psi, -96% returns Swap to PowerPro system (system #4), new mud at bit, 12,686' 9/20/2019 9/21/2019 1.70 PROD2 DRILL DRLG P New mud all the way around, PU for 12,732.0 12,800.0 22:18 00:00 new parameters, FS = 1177 @ 1.8 bpm, CWT = 5.3K @ 1 K WOB, annular = 4107 psi, WHP = 247 psi, pump = 5128 psi, quickly begin snubbing at-8K, PUW =42K from 12,766', bore pressure climbs -5600 pis, perform BHA wiper, bore pressure returns to normal (-5300 psi) Blow-down micro motion 9/21/2019 912112019 2.00 PROD2 DRILL DRLG P Drilling, CWT=-5K@0.3K WOB, 12,800.0 12,860.0 00:00 02:00 annular = 4113 psi, pump = 5122 psi Page 10122 ReportPrinted: 101112019 Operations Summary (with Timelog Depths) 1C-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stait7ene End Time Dar(hr) Phase op code Actimry Code Time P -T -X operation (flKB) End Depth(RKB) 9/21/2019 9/21/2019 2.00 PROD2 DRILL DRLG P Drilling, FS = 1072 psi @ 1.8 bpm, 12,860.0 12,908.0 02:00 04:00 CWT =-6.9K @ 1.4K WOB, annular= 4131 psi, WHP = 273 psi, pump = 5127 psi, pumped 20 bbl beaded pill Begin seeing slight increase in rate out at 12,866' (-1.9 bpm out), pinched in choke a to 11.5 ppg at window, drilled ahead, then begin losing fluid holding 11.35 ppg, losses quickly began to heal 9/21/2019 9/21/2019 7.10 PROD2 DRILL DRLG P Drilling, CWT - -4.8K @ 1.4K WOB, 12,908.0 13,043.0 04:00 11:06 annular = 4135 psi, WHP = 262 psi, pump = 5238 psi, returns -97%, pump 10x 10w/ beads 9/21/2019 9/21/2019 0.10 PROD2 DRILL WPRT P Pull BHA wiper, PUW=43 13,043.0 13,043.0 11:06 11:12 9/21/2019 9/21/2019 2.50 PROD2 DRILL DRLG P 13043', Drill, 1.8 BPM @ 5138 PSI 13,043.0 13,142.0 11:12 13:42 FS, BHP=4149. Unable to maintain steady state drilling without beads. Pump multiple 20 BBIs beaded pills. ROP with beads above 40 FPH 9/21/2019 9/21/2019 0.10 PROD2 DRILL WPRT P 13142', Pull BHA wiper 13,142.0 13,142.0 13:42 13:48 9/21/2019 9/21/2019 2.40 PROD2 DRILL DRLG P 13142', Drill, Low ROP. Pump multiple 13,142.0 13,165.0 13:48 16:12 beaded 25 BBI pills. Get to 13165'. Unable to make any ROP. Unable to stall motor. Not getting any Diff pressure or reactive torque. Oscillate, Pump more beads. Try to stall motor with beads. Able to gel 1.9K DHWOB.No change in parameters. Consult towm 9/21/2019 9/21/2019 3.30 PROD2 DRILL TRIP T Trip out to inspect / swap out BHA, 13,165.0 78.0 16:12 19:30 PJSM 9/21/2019 9/21/2019 2.00 PROD2 DRILL PULD T PUD BHA#10, checks not holding, 78.0 0.0 19:30 21:30 change to PUD w/ failed checks (EDC closed), pop off, see residual coil pressue, stab on & bleed pump, good, PT CTC to verify no leak path (4500 psi), good, complete PUD, bit came out a 1-1 *Difficulty turning motor at surface (motor appears to have failed) 9/21/2019 9/22/2019 2.50 PROD2 DRILL PULD T PU & PD BHA#11 Lateral Assembly 0.0 78.0 21:30 00:00 #3 (New MWD tools, NOV agitator, Iron Horse 0.5° AKO motor, RB HYC A3 bit), slide in cart, check pack -offs, change out checks in UQC, MU to coil, tag up, set counters 9/22/2019 9/22/2019 0.40 PROD2 DRILL PULD T Complete PD BHA#11 Lateral 78.0 78.0 00:00 00:24 Assembly #3 (New MWD tools, NOV agitator, Iron Horse 0.5° AKO motor, RB HYC A3 bit) 9/22/2019 9/22/2019 1.70 PROD2 DRILL TRIP T RIH w/ BHA#11 78.0 9,200.0 00:24 02:06 Shallow test agitator: MD = 50301, 1.8 bpm, pump = 5350 psi, dp = 1421 psi 9/22/2019 9/22/2019 0.10 PROD2 DRILL DLOG T Log Kt for +3.5'correction, PUW = 9,200.0 9,232.0 02:06 02:12 1 133K Page 11122 ReportPrinted: 10/1/2019 Operations Summary (with Timelog Depths) 1c-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Shan Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Deph(ftKB) 9/22/2019 9/22/2019 1.80 PROD2 DRILL TRIP T Continue RIH w/ BHA#11, clean 9,232.0 13,165.0 02:12 04:00 through window & past billet, observe drop in MW out, take reduced density returns to tiger-tank, CWT falls off quickly begommomg at —12.875', reduced speed to get to bottom 9/22/2019 9/2212019 2.00 PROD2 DRILL DRLG P Drilling, FS —=1510 @ 1.8 bpm, CWT = 13,165.0 13,213.0 04:00 06:00 -6.7K @ 1 K WOB, annular = 4189 psi, WHIP = 142 psi, pump = 5205 psi, vibrations up to 6 9/22/2019 9/2212019 0.60 PROD2 DRILL WPRT P 13,213, High vibrations, Pick up to get 13,213.0 13,213.0 06:00 06:36 surveys. PUW=45K, Hard time turning around. Work to get to bottom with beads 9/2212019 9/22/2019 1.00 PROD2 DRILL DRLG P 13213', Drill 1.78 BPM @ 5111 PSI 13,213.0 13,230.0 06:36 07:36 FS, BHP=4226, RIW=1.3K, DHWOB=20. Pumping beaded pills 9/22/2019 9122/2019 0.20 PROM DRILL WPRT P 13230, Pick up to get surveys, 13,230.0 13,230.0 07:36 07:48 PUW=50K, Tough to get fumed around 9122/2019 9122/2019 3.80 PROM DRILL DRLG P 13230', Drill, 1.78 BPM @ 5111 PSI 13,230.0 13,359.0 07:48 11:36 FS, BHP=4226, RIW=1 K with DHWOB=.5K, ROP=40 FPH. Pump many beaded pills 50 BBIs 9122/2019 9/22/2019 0.20 PROM DRILL WPRT P Pull 100'wiper, PUW=42K 13,359.0 13,359.0 11:36 11:48 9/22/2019 9122/2019 4.20 PROM DRILL DRLG P 13359', Drill, 1.78 BPM @ 5202 PSI 13,359.0 13,449.0 11:48 16:00 FS, BHP=4249. Pumping beaded pills almost continuiously 50 BBL then spacer while batching up another one 9/2212019 9122/2019 0.10 PROM DRILL WPRT P 13449, BHA Wper, PUW=39K 13,449.0 13,449.0 16:00 16:06 912212019 9/22/2019 2.00 PROM DRILL DRLG P 13449, Drill, 1.8BPM @ 5189PSI FS, 13,449.0 13,494.0 16:06 18:06 BHP=4254. Still pumping beaded pills to maintain drilling 9122/2019 9/22/2019 2.10 PROD2 DRILL DRLG P Drilling, CWT =-2K @ 0.21K WOB, 13,494.0 13,523.0 18:06 20:12 annular = 4267 psi, WHIP = 45 psi, pump = 5509 psi, pumping 40 bbl beaded pills to stay drilling, low ROP & struggling to get weight to bit, avg ROP = 11.5 fph, pump 10 bbl LoVis followed by 40 bbl beaded mud 9/2212019 9/22/2019 0.30 PROD2 DRILL WPRT P Wiper up-hole, PUW = 39K, lay in 13,523.0 12,523.0 20:12 20:30 beads on wiper 9/2212019 9/22/2019 1.30 PROD2 DRILL WPRT P Wiper in-hole, snubbing to bottom (up 12,523.0 13,523.0 20:30 21:48 to -81K), reduced RIH speed down to 6 fpm at times, reduce rate to 1 bpm @ 13,488' to grab missed survey 9/22/2019 9/2312019 2.20 PROD2 DRILL DRLG P Drilling, FS = 1302 psi @ 1.8 bpm, 13,523.0 21:48 00:00 annular =4267 psi, WHIP =77 psi, pump = 5138 psi, pump 15 bbl LoVis followed by 15 bbl beaded pill, notice rate out drops as LoVis exits bit, immedialy comes back as beaded pill exits bit, possibly losing to formation due to low _SRV in LoVis, pump 10 bbl LoVis followed by 40 bbl HiVis beaded pill Difficulty working to bottom after BHA wipers (requires reducing rate & speed) Page 12/22 ReportPrinted: 10/1/2019 Uperations Summary (with Timelog Depths) 1C-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Start Time End Time Dur (hr) Phase Op Cove ACtiviy Catle Time P -T -X Operation (ftKB) End Depth (ftKB) 9/23/2019 9/23/2019 2.00 PROD2 DRILL DRLG P Drilling, snubbing to -8K, struggling w/ 13,567.0 13,606.0 00:00 02:00 weight transfer, annular = 4277 psi, pump = 5636 psi, continue pumping 10 x 40 bbl (LOVIS x Beaded HiVis), avg ROP = -20 fph 9/23/2019 9/23/2019 2.50 PROD2 DRILL DRLG P Drilling, annular =4211 psi, WHP= 13,606.0 13,658.0 02:00 04:30 238 psi, pump = 5583 psi, WOB 0.1 K - 0.3K, continue pumping 40 bbl beaded pills, avg ROP = -21 fph PU, drop rate to grab missed surverys due to vibration, immediatly bring rate back to 1.8 bpm 9/23/2019 9/23/2019 1.70 PROD2 DRILL DRLG P Drilling, annular =4248 psi, WHP= 13,658.0 13,698.0 04:30 06:12 278 psi, pump = 4338 psi, continue pumping 40 bbl beaded pills 9/23/2019 9/23/2019 0.10 PROD2 DRILL WPRT P BHA wiper, Get surveys, PUW=38K 13,698.0 13,698.0 06:12 06:18 9/23/2019 9/23/2019 2.90 PROD2 DRILL DRLG P 13698', Drill, 1.81 BPM @ 5184 PSI 13,698.0 13,726.0 06:18 09:12 FS, BHP=4239, RIW=-1.8K, DHWOB=.3K. Bump 40 BBI beaded pilss 9/23/2019 9/23/2019 0.10 PROD2 DRILL WPRT P 13726, BHA wiper, PUW=47K 13,726.0 09:12 09:18 9/23/2019 9/23/2019 3.90 PROD2 DRILL DRLG P 13726', Drill, 1.72 BPM @ 5043 PSI 13,780.0 09:18 13:12 FS, BHP=4255. Hard time staying on bottom drilling, Pump beaded pills, r13,726.0 frequent pick ups. 9/23/2019 9/23/2019 0.10 PROD2 DRILL WPRT P BHA wiper, PUW=42K 13,780.0 13:12 13:18 9/23/2019 9/23/2019 1.90 PROD2 DRILL DRLG P 13780', Drill, 1.72 BPM @ 5075PSI 13,804.0 13:18 15:12 1 1 FS, BHP=4246 9/23/2019 9/23/2019 0.10 PROD2 DRILL WPRT P BHA pick up, PUW=44K 13,804.0 13,804.0 15:12 15:18 9/23/2019 9/23/2019 1.00 PROD2 DRILL DRLG P 13804', Drill, 1.82 BPM @ 5265 PSI 13,804.0 13,817.0 15:18 16:18 FS, BHP=4276 9/23/2019 9/23/2019 1.70 PROD2 DRILL WPRT T Town call TD, Go to pull off bottom. 13,817.0 13,817.0 16:18 18:00 Made initial pull to 65K and turned around. Unable to move pipe. No change on DHWOB. Able to orient freely. Pull to 80K. Get LVT ready to pump. 40 BBI beaded pill going down coil, relax to 3550 psi and pull to 80K M1 beads around, no good 9/23/2019 9/23/2019 1.50 PROD2 DRILL CIRC T Crew change, complete loading 20 bbl 13,817.0 13,817.0 18:00 19:30 LVT in pill pit, relaxed to 3549 psi annular, attempt to pull free, no good, pump 20 bbl LVT with pipe in tensioin at 55K CWT, WHP is down to 9 psi when pumping at 1.8 bpm (possible partial pack -off), begin taking returns to tiger -tank (density out dropping), W/ 5 bbl LVT out bit, let soak & relax to 3815 psi annular, pull to 80K twice, no luck, can still orient freely, pump additonal 10 bbl out bit (15 bbl LVT in annulus), annular = 4364 psi @ 1.8 bpm in & 1 bpm out (appear to be partially packed off), popped free after soaking in tension at 55K for 5 min Page 13122 ReportPrinted: 10/1/2019 Uperations Summary (with Timelog Depths) 1C-06 ORig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time Dur (hr) Phase Op cone Activitycode Time P -T -x Operation MKB) End Depth ME) 9/23/2019 9/23/2019 1.20 PROD2 DRILL CIRC T Pipe free, 1.8 bpm in & 1 bpm out, pull 13,817.0 13,500.0 19:30 20:42 off bottom at 12 fpm, annular = 4328 psi, continue circulating allowing pack off to erode, rate climbs to 1.8 bpm over 9 minutes (achieve 1 -tor -1 returns), circulate bottoms up, pump 40 bbl beaded pill to aid in RBIH after swab wiper 9/23/2019 9/24/2019 3.30 PROD2 DRILL WPRT P Perform swab wiper, lay in 40 DDF 13,500.0 78.0 20:42 00:00 beaded pill, jog 7" casing 9/24/2019 9/24/2019 1.80 PROD2 DRILL TRIP P RBIH to confirm TD 78.0 9,200.0 00:00 01:48 9124/2019 9/24/2019 0.20 PROD2 DRILL DLOG P Log K1 for+3' correction, RIH to 9,200.0 9,231.0 01:48 02:00 1 window 9/2412019 9/24/2019 0.50 PROD2 DRILL DLOG P RIH to window. Confirm 11.4 ppg kills 9,231.0 9,415.0 02:00 02:30 well, drop pumps, shut in choke MD = 9415.5', TVD -sensor = 6483', annular = 3774 psi, EMW = 11.21 ppg Note: annular was rock solid at 3774 psi 9/24/2019 9124/2019 1.80 PROD2 DRILL TRIP P PUW@window = 34K, continue RIH, 9,415.0 13,822.0 02:30 04:18 clean through window & past billet, clean to bottom, confirm TD at 13822', PUW = 35K 9124/2019 9/24/2019 4.10 PROD2 DRILL TRIP P Lay in LRP & KWF to surface, paint 13,822.0 78.0 04:18 08:24 1 flags, 12760 & 8280 9/2412019 9/24/2019 0.50 PROD2 DRILL PULD P At surface, Flow check well -Good. 78.0 78.0 08:24 06:54 PJSM lay down BHA on dead well. 9/24/2019 9/2412019 0.70 PROD2 DRILL PULD P Unstab injector, Inspect CT for wall 78.0 0.0 08:54 09:36 thickness. Lay down BHA#11. Ironhorse motor bearing end seems to have excessive gap. 9/2412019 9/24/2019 0.80 COMM CASING RURD P Prep floor to run liner 0.0 0.0 09:36 10:24 9/24/2019 9/24/2019 2.00 COMM CASING PUTB P M/U BHA#12, L1-01 lower liner 0.0 1,093.3 10:24 12:24 segment with non ported bullnose, 36 its slotted 2 3/8" liner, and shorty deployment sleeve 9/24/2019 9/24/2019 0.70 COMPZ2 CASING PULD P M/U coil track to liner. M/U to injector 1,093.3 1,137.6 12:24 13:06 and surface test. Tag up and set counters 9/24/2019 9/24/2019 2.30 COMPZ2 CASING TRIP P RIH BHA#12, EDC closed pumping .2 1,137.6 9,337.0 13:06 15:24 BPM 9/24/2019 9/24/2019 0.10 COMPZ2 CASING DLOG P Tie into flag for -6.88' 9,337.0 9,337.0 15:24 15:30 9/24/2019 9/24/2019 0.30 COMPZ2 CASING TRIP P 9337 Continue in. Clean trip through 9,337.0 10,280.0 15:30 15:48 window and past billet 9/24/2019 9/24/2019 0.10 COMPZ2 CASING DLOG P 10280', Log K1 for +7', Stop and reset 10,280.0 10,296.0 15:48 15:54 counters 9/24/2019 9/24/2019 1.20 COMPZ2 CASING TRIP P Continue in hole, 50 FPM. Slick trip to 10,296.0 12,429.0 15:54 17:06 bottom @ 13,822', PUW=50K. Set back down. Bring pumps online, Release from liner. PUW=35K. PUH 13,803. Remove liner length left in hole from counters 9/24/2019 9/24/2019 2.80 COMPZ2 CASING TRIP P Tip out of hole. Paint flag @ 7944.2 12,429.0 57.0 17:06 19:54 9/2412019 9/24/2019 0.50 COMPZ2 CASING PULD P Tag up, Perform flow check. PJSM. 57.0 0.0 19:54 20:24 Lay down liner running tools on dead well 9/24/2019 9/24/2019 0.60 COMP CASING RURD P Rig up floor for liner ops 0.0 0.0 20:24 21:00 Page 14122 Report Printed: 101112019 Operations Summary (with Timelog Depths) 1C-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time log Start Depth start Time End Time Phase Op Code Activity Code Time P-T-% Operation (ftKB) End Depth (MB) 9/24/2019 9/25/2019 COMPZ2 CASING PUTS P Pickup L1-01 upper liner segment 0.0 1,375.0 21:00 00:00 with non-ported bullnose, 45 Jts slotted 2 3/8" liner, 6' pup joint, and aluminum liner lop billet, begin PU r2.90 BHA #13 Liner Tools 9/25/2019 9/25/2019 COMPZ2 CASING PULD P Complete PU BHA #13 Liner Tools, 1,375.0 1,433.0 00:00 00:18 slide in cart, check pack-offs, MU to coil, tag up, set counters 9125/2019 9/25/2019 COMPZ2 CASING RUNL P RIH w/ BHA#13, -6.12' correction to 1,433.0 12,728.0 00:18 03:12 window flag, PUW = 36K, drive by RA for +7.5' correction, arrive at set depth, PUW = 47K, set-down, come up to 1.5 bpm, PUW = 39K, release off liner TOL-11,339' 9/25/2019 9/25/2019 2.30 COMPZ2 CASING TRIP P Reset counlers,POOH 12,728.0 50.0 03:12 05:30 9/25/2019 9/25/2019 0.70 COMPZ2 CASING PULD P Flow check, LD BHA#13, crew 50.0 0.0 05:30 06:12 change, carry on LD tools 9/25/2019 9/25/2019 1.20 PROD3 WHDBOP CTOP P MU nozzle, jet stack, break off nozzle, 0.0 0.0 06:12 07:24 clear rig floor, displace coil to fresh water 9/25/2019 9/25/2019 0.40 PROD3 WHDBOP IFR _TS P PT Test IRV (250 low 13500 high) 0.0 0.0 07:24 07:48 9/25/2019 9/25/2019 1.20 PROD3 WHDBOP CTOP P Grease swabs, master, & tangos, 0.0 0.0 07:48 09:00 bravo's & romeo's, DSO on site to bleed down GI line in cellar, break off nozzle, prep rig floor, install night cap 9/25/2019 9/25/2019 0.30 PROD3 WHDBOP CTOP P Fluid pack lines, line up valves for test, 0.0 0.0 09:00 09:18 put up barriers 9/25/2019 9/25/2019 5.20 PROD3 WHDBOP BOPE P Test BOP's (witness waived by Austin 0.0 0.0 09:18 14:30 McLeod of the AOGCC), PU test jnt, continue w/ test, filling the hole w/ MP line '250 low / 3500 high 9/25/2019 9/25/2019 0.30 PRODS WHDBOP BOPE P Perform draw down test 0.0 0.0 14:30 14:48 9/25/2019 925/2019 0.50 PROD3 WHDBOP PRTS P LD test jnt, Gear dg floor 0.0 0.0 14:48 15:18 9/25/2019 9/252019 1.20 PROD3 STK CTOP P Change out UQC, MU nozzle, stab on, 0.0 0.0 15:18 16:30 open swab 2, flow check, pop off, break off nozzle 9/25/2019 9/25/2019 1.20 PROD3 STK PULD P PU BHA #14 KO Build/furn Assembly 0.0 78.0 16:30 17:42 (1.0° AKO motor, RR Baker bit), slide in cart, check pack-off, MU to coil, tag up, set counters 9/25/2019 925/2019 1.70 PROD3 STK TRIP P RIH 78.0 9,204.0 17:42 19:24 9/252019 9/25/2019 0.20 PRODS STK DLOG P Tie into the K1 for +Y correction 9,204.0 9,220.0 19:24 19:36 9/25/2019 9/25/2019 0.10 PROD3 STK TRIP P RIH to just above the window 9,220.0 9,411.0 19:36 19:42 9/25/2019 9/25/2019 1.20 PRODS STK DISP P Tum well over to drilling fluid ramping 9,411.0 9,401.0 19:42 20:54 up rate targeting 11.4 ppg, 20:47, mud weight out dropping to drilling fluid density, PU W133 klbs, Close EDC Charging gas injection line in cellar @ 1125 psi SSSV 4300 psi 925/2019 9/252019 0.60 PRODS STK TRIP P RIH, 9,401.0 11,316.0 20:54 21:30 "Dry tag TOB @ 11,338' PU Wt 38 k bs. Page 15122 ReportPrinted: 101112019 Operations Summary (with Timelog Depths) 1C-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Tim Our (hr) Phase Op Code Advity Coda Time PJA Operation MKB) End Depth(flKB) 9/25/2019 9/25/2019 0.10 PRODS STK TRIP P Set rate, CT 4211 psi @ 1.80 bpm in 11,316.0 1,336.2 21:30 21:36 and 1.65 bpm out, BHP 4092 psi, 11.5 ppg @ the window, 11.9 ppg @ the toe. WH 18 psi, IA 11 psi, OA 69 psi, free spin diff 894 psi. MW out dropped to 8.0 ppg as open hole bottoms up arrived at surface, export returns to Tiger tank. 9/25/2019 9/25/2019 0.90 PROD3 STK KOST P Time drill off billet @ 60 ° ROHS @ - 1,336.2 11,337.2 21:36 22:30 Brought returns back inside - 10 bbls, 1 ft/hr for 1' - seeing some aluminum back at he shaker from initial milling bottoms up. 9/25/2019 9/26/2019 1.50 PROD3 STK KOST P 2ft/hr for V- WOB 0.65 k lbs, Ct Wt 8 11,337.2 11,338.0 22:30 00:00 klbs. 11337.84 - Stall - PU Wt 36 klbs, RBIH, RIH Wt 12 k lbs, CT 4120 psi, 1.81 bpm in and 1.81 bpm out, BHP 4045 psi, Free spin diff 503 psi, Saw motor work @ 11,335.8' Stall #2 @ 11,337.6' PU 38 k lbs, RBIH 0.10 PROD3 STK KOST P Continue to time drill ahead@ 2 h/hr 11,338.0 11,338.2 00:06 9/26/2019 0.20 PROD3 STK KOST P Increase rate to 3 ff/hr 11,338.2 11,339.2 00:189/26/2019 r/26/2019/26/2019 4.70 PROD3 DRILL DRLG P Drilling ahead, work WOB up to 1.5 k 11,339.2 11,630.0 05:00 lbs, ROP 160 ft/hr. Stacking out @ 11377'. WOB up to 3 k and string weight as low as 6 k lbs with no motor work. Multiple PU's, Pull above billet, tug -1 k WOB @ 11325', other than that, billet clean. RBIH, drilling ahead. 11,476 - PU Wt 43 k lbs CT 4222 psi @ 1.82 bpm in and 1.70 bpm out, BHP 4074 psi, 11.45 ppg EMW @ the window, Free spin diff 564 psi, 12.2 k CT RIH wt, OBD, Ct wt 9 k lbs, WOB 1-0.6 k lbs. 9/26/2019 9/26/2019 2.70 PRODS DRILL TRIP P POOH, PJSM 11,630.0 72.0 05:00 07:42 9/26/2019 9/26/2019 1.30 PROD3 DRILL PULD P PUD BHA#14, blow down tools, clear 72.0 0.0 07:42 09:00 rig floor, inspect injector, bit came out 2-2 w/ 1 plugged nozzle (aluminum in nozzle) 9/26/2019 9/262019 1.00 PROD3 DRILL PULD P PD BHA#15 (NOV agitator, 0.6° AKO 0.0 78.0 09:00 10:00 motor, New Dynamus bit), slide in cart, check pack -offs, MU to coil, tag up, set counters 9/26/2019 9262019r2.20 PROD3 DRILL TRIP P RIH w/ BHA#15, shallowtesl, rip = 78.0 9,200.0 10:00 11:42 940 psi @ 1.8 bpm 9/26/2019 9/26/2019 PROD3 DRILL DLOG P Log K1 for +4' correction, PUW = 36K 9,200.0 9,232.0 11:42 11:48 9/26/2019 9/26/2019 PRODS DRILL TRIP P Continue RIH, weight bobble @ 9,232.0 11,630.0 11:48 12:42 11,383' (2K) 9/26/2019 9/26/2019 PROD3 DRILL DRLG P Drilling, FS = 1060 psi, @ 1.9 bpm, 11,630.0 11,795.0 12:42 14;51 CWT = 12K @ 1.8 WOB, annular = 4085 psi, WHP = 25 psi, pump = 5108 psi, avg ROP = 75 fph Page 16122 ReportPrince l: 101112019 Operations Summary (with Timelog Depths) 1C-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth End Time Our (Inn Phase Op Cod. Acbvdy Code Time P -T -X Operation (aKB) End DePlh MKS) 9/26/2019 1.70 PROD3 DRILL DRLG P Drilling, annular =4105 psi, WHIP=42 11,795.0 11,898.0 16:36 psi, pump = 5030 psi, -97% returns, avg ROP = -61 fph 9/2612019 2.50 PROD3 DRILL DRLG P Drilling, annular= 4106, WHIP = 34 11,898.0 12,030.0 r14:54 19:06 psi, 11.4 ppg at window, lower ROP in hard spots (possibly Siderite as seen on the L1 & L1-01) Start new mud down the coil - Duo vis lite system doctered up w power vis New mud at the bit 18:42 and 12,000'. Average ROP over interval 53- fl/hr 9/26/2019 9/26/2019 0.30 PRODS DRILL WPRT P PU wt 40 k Is, Pull up hole on wiper 12,030.0 11,360.0 19:06 19:24 #1 Saw -1.3 k WOB tug @ 11,380 onn way up hole. 9/26/2019 9/26/2019 0.20 15ROD3 DRILL WPRT P RBIH 11,360.0 12,030.0 19:24 19:36 0.22 bbls of cutting returned on the trip 9/26/2019 9/27/2019 4.40 PROD3 DRILL DRLG P Ct 4740 psi @ 1.90 by in and 1.90 12,030.0 12,348.0 19:36 00:00 bpm out, Free spin diff 1111 psi, BHP 4077, 11.4 ppg EMW at the window. 11.84 ppg @ the bit, WH 347 psi, IA 29 psi, OA 91 psi. OBD, CT Wt 4.4 k lbs, 1.92 k WOB -Average ROP 72 ff/hr 12,171' PU Wt 44 k lbs 12,239' PU Wt 45 k lbs 12,301' PU Wt 44 k lbs 12,326' PU Wt 41 k lbs 9127/2019 9/27/2019 1.70 PRODS DRILL DRLG P Continue to drill ahead 12,348.0 12,480.0 00:00 01:42 12,404' PU Wt 39 k lbs 12,482' PU Wt 46 k lbs CT 5033 psi, 1.89 bpm in and 1.85 bpm out, Free spin 1,248 psi, BHP, RIH Wt 6.5 k lbs, OBD, CT Wt 1.5 k Is, WOB 1.45 k lbs -Average ROP 77.6 ff/hr 9/27/2019 9/27/2019 1.70 PRODS DRILL DRLG P ROP slowed significantly 12,480.0 12,513.0 01:42 03:24 CT Wt -5 k lbs, WOB 1.2 k lbs, ROP - 20 ff/hr 12,496' losses increased to 0.1 bpm Gamma started to wrap @12,475' 178 API gamma @ 12,482' 9/27/2019 9/27/2019 1.20 PRODS DRILL WPRT P PU Wt 40 k lbs, pull into casing 12,513.0 9,420.0 03:24 04:36 9/27/2019 9/27/2019 0.50 PROD3 DRILL WPRT P Jet 7" and chase bottoms up. 9,420.0 9,200.0 04:36 05:06 9/27/2019 9/27/2019 0.20 PROD3 DRILL DLOG P Tie into the Kt for 5' correction. 9,200.0 9,230.0 05:06 05:18 9/27/2019 9/27/2019 0.20 PRODS DRILL WPRT P Measure BHP, stabilizes at 11.2 ppg 9,230.0 9,410.0 05:18 05:30 EMW 9/27/2019 9/27/2019 1.10 PR0D3 DRILL WPRT P RBIH to drill & reaquire sand, begin 9,410.0 12,513.0 05:30 06:36 seeing weight & motor -work beginning at 12,479 (1.31K WOB), a bit ratty to bottom 9/27/2019 9/27/2019 1.80 PROD3 DRILL DRLG P Drilling, FS = 1106 psi @ 1.9 bpm, 12,513.0 12,549.0 06:36 08:24 CWT = 1.6K @ 2.21K WOB, annular = 4120 psi, WHIP = 242 psi, pump = 5159 psi, 20 fph to 30 fph, pump 5 x 5 sweeps "Monitor hole stability through high gamma interval Page 17122 Report Printed: 10/1/2019 Operations Summary (with Timelog Depths) 1c-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SW DWh Stent Time EM Time our (hr) Phase Op Cale Activity Cod. Time P -T -X Operation (flKB) End OepM (WB) 9/27/2019 9/27/2019 2.60 PRODS DRILL DRLG P Drilling break al- 12,549', CWT= -2K 12,549.0 12,653.0 08:24 11:00 @ 0.6K WOB, annular = 4133 psi, WHP = 215 psi, pump = 5192 psi, rate out dropped at -12,646'(-.25 bpm), ,avg ROP = 40 fph, PUW = 46 at 12,653' " Wrapping gamma interval: 12,478' to 12,532' 9/27/2019 9/27/2019 1.50 PRODS DRILL DRLG P Drilling, CWT 2K @ 1.51K WOB, 12,653.0 12,693.0 11:00 12:30 annular = 4179 psi, WHP = 290 psi, pump = 5445 psi, PUW = 43K from 12,693', -90% returns, reduce rate & speed to get back to bottom, avg ROP = 27 fph 9/27/2019 9/272019 2.10 PRODS DRILL DRLG P Drilling, CWT = 4K @ 0.5K WOB, 12,693.0 12,753.0 12:30 14:36 pump 5 x 15 beaded (lo/hi) to moderate effect, PUW = 46K @ 12,720', mud foaming up (pump efficiency fluctuating), add defoamer to mud, rate out doom to 1.3 bpm, climbs back to 1.76 bpm out, avg ROP = 29 fph Pump 50 bbl beaded pill 9/27/2019 9/27/2019 1.30 PRODS DRILL DRLG P Beads exiting bit at 12,753', PUW = 12,753.0 12,813.0 14:36 15:54 46K, much improved weight transfer, increase in ROP, up to 90 fph, avg ROP = 46 fph 69K PUW from 12,786 927/2019 9/272019 0.20 PRODS DRILL WPRT P Wiper up -hole, PUW = 39K, 60 fpm, 12,813.0 12,000.0 15:54 16:06 1 clean through high gamma interval 9/272019 9/27/2019 0.40 PR0D3 DRILL WPRT P Wiper in-hole, preemtively reduce rate 12,000.0 12,813.0 16:06 16:30 to 1.25 bpm running through high gamma interval, stack a bit of weight at 12,495' & 12,516', reduce to 0.5 bpm, reduce speed to 30 fpm, get through w/o much trouble, RIW = 0.51K 9/27/2019 927/2019 1.80 PRODS DRILL DRLG P Drilling, FS = 1173 psi @ 1.9 bpm, 12,813.0 12,863.0 16:30 18:18 beads exiting bit, CWT = 4.31K, @1.1K WOB, annular = 4177 psi, WHP = 129 psi, pump = 5536 psi 9/27/2019 9/27/2019 5.40 PRODS DRILL DRLG P Crew change, PU to grab parameters 12,863.0 13,035.0 18:18 23:42 CT 5166 psi @ 1.80 bpm in and 1.64 bpm out, Free spinn 1077 psi, BHP 4208 psi, CT Wt to -6 k lbs, WOB 1.2 k -0.3k lbs. Struggling with weight transfer, 100' BHA wipers seemd giving limited help. 2 ppb beaded sweeps limited help, Reduced pump rate to 1.5 bpm CT inlet pressure reduced to 4466 psi, some weight ransfer benifit but still picking up more than drilling. Average ROP over section 31 ft/hr 9/27/2019 9/28/2019 0.30 PRODS DRILL WPRT P PU Wt 37 k lbs, pull wiper to rasing 13,035.0 12,048.0 2342 00:00 9/28/2019 9/28/2019 1.20 PRODS DRILL WPRT P Continue to PUH, dragging low side, 12,048.0 9,404.0 0000 01:12 chasing sweeps -1.6 k WOB tug @ 11373'- old trouble spot -1.7 k WOB tug @ 11325'- billet -1.7 k WOB tug while Coming through the window Page 18122 Report Printed: 10/1/2019 Operations Summary (with Timelog Depths) 1C-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log $lift oepm Steri Time End Time our (hr) Phase Op Code Aetiviy Code Time P-T-X Operation (IIXB) End Depth (/IX8) 9/28/2019 9/28/2019 0.40 PRODS DRILL WPRT P Jet 7" and chase bottoms up. 9,404.0 9,199.0 01:12 01:36 9/28/2019 9/28/2019 0.20 PRODS DRILL DLOG P Tieintothe Ki marker for+12' 9,199.0 9,242.7 01:36 01:48 correction. 9/28/2019 9/28/2019 1.50 PRODS DRILL WPRT P RBIH 9,242.7 13,035.0 01:48 03:18 WOB spikes to - 1.5 k lbs @ 10,264' and 11,136' WOB spike to 2.9 k lbs 11,338'- billet, slacked out some coil weight too then popped through. Started exporting returns to the tiger tank line and new mud down the coil. " 0.91 bbls of cuttigs returned on the round trip. " New mud at the bit 9/28/2019 9/28/2019 2.90 PRODS DRILL DRLG P CT 4599 psi @ 1.79 bpm in and 1.79 13,035.0 13,103.0 03:18 06:12 bpm out, free spin 1052 psi, BHP 4212 psi, WH 81, IA46, OA 107 psi. OBD, CT Wt 5.2 k lbs, WOB 2.8 k lbs, 13,056'- PU Wt 44 k lbs, Free spin diff 1065 psi w new mud all the way around. 9/28/2019 9/28/2019 3.70 PRODS DRILL DRLG P Drilling, CWT = 3.2 @ 0.2 WOB, 13,103.0 13,181.0 06:12 09:54 annular = 4206 psi, WHP = 211 psi, pump = 4323, pump 10 x 101ow/high beaded sweeps, mud aired up, add defoamer to system, -96% returns, pump 10 low x 40 high beaded 9/28/2019 9/28/2019 0.60 PRODS DRILL DRLG P Drilling, pumping 50 bbl beaded pills, 13,181.0 13,251.0 09:54 10:30 annular = 4355 psi, WHP = 176 psi, pump = 5109 (w/ high vis down coil), BHA wiper from 13,182' Rate out dropped to .38 bpm at 13,211' (80% losses), ECD drops 10.3 ppg, drill ahead in attempt to heal losses, drill to 13,251', returns to -.5 -.8 bpm (fluctuating), pump high vis sweep, wiper to window 9/28/2019 9/28/2019 1.30 PROD3 DRILL WPRT P Wiper to window on losses, PUW= 13,251.0 9,400.0 10:30 11:48 49K, 1.86 bpm in, 0.6 bpm out, rate out climbs to 0.9 = 1.0 bpm at window w/ reduced frictional pressure loss (holding 11.4 ppg at window), reduce to 11.1 ppg for 1.4 bpm returns 9/28/2019 9/28/2019 1.00 PRODS DRILL CIRC P Jog 7" casing, pump sweeps, circulate 9,400.0 5,000.0 11:48 12:48 bottoms up, wiper up-hole to 5000' 9/28/2019 9/28/2019 1.90 PRODS DRILL CIRC P RBIH to window, circulating awaiting 5,000.0 9,400.0 12:48 14:42 fluid to rig, trucks arrive at rig, begin unloading '• Log K1 for +12' correction 9/28/2019 9/28/2019 1.40 PRODS DRILL TRIP P Pump 1.9 bpm, holding 11.4 ppg, 9,400.0 12,762.0 14:42 16:06 returns are 1 for 1, losses at window are much reduced, RBIH, mud trucks stuck behind Parker 272 rig move At 12,763', 1.86 bpm in, 0.97 bpm out, confer w/ town, decison made to POOH & circulate pending rig move 9/28/2019 9/28/2019 1.10 PROD3 DRILL TRIP T POOH to window to circulate pending 12,762.0 9,328.0 16:06 17:12 1 i rig move 9/28/2019 1912812019 4.30 PRODS DRILL WAIT T Circulate waiting on trucks 12,762.0 9,328.0 17:12 21:30 1 Page 19122 ReportPrinted: 101112019 Operations Summary (with Timelog Depths) IC-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth StaM1Time EM Time Our (hr) Phase Op Code Acbvky Code Time P-T-X Operation (NKB) End DePM MIKS) 9/28/2019 9/28/2019 0.40 PRODS DRILL DISP T Shut choke, line up down the coil, 9,328.0 9,335.0 21:30 21:54 stage pump rate up to drilling rate. CT 4800 psi @ 1.80 bpm, 11.81 ECD at the window and slowly climbing, WH 766 psi, IA 21 psi, OA 90 psi. SID 9128/2019 9/28/2019 0.60 PROD3 DRILL DISP T Line up down the back side, Pump 50 9,335.0 9,300.0 21:54 22:30 bbl lube pill down the back side. 9/28/2019 9/29/2019 1.50 PRODS DRILL TRIP T RIH, window clean, stacked WOE on 9,300.0 12,914.0 22:30 00:00 lower billet, again - 11,336' stacked out coil, no WOB 12,579' 9/29/2019 9/29/2019 1.50 PRODS DRILL DRLG T Struggling to get to bottom, CT Wt -7 k 12,914.0 13,249.0 00:00 01:30 lbs, any pumping slicks the coil diferentially. 9/29/2019 9/29/2019 3.10 PRODS DRILL DRLG P CT 4748 psi @ 1.80 bpm, BHP 4300 13,249.0 13,261.0 01:30 04:36 psi, 12.47 ppg EMW, WH 1099 psi, IA 23 psi, OA 97 psi. 13,261' PU 65 k lbs 13,262' PU 65 k be 9/29/2019 9/29/2019 1.00 PRODS DRILL DRLG T Attempt to pick up, stuck. 13,261.0 13,261.0 04:36 05:36 Worked pipe to 75 k, WOB to -11 k lbs. No success. Able to orient freely. Drop pump rate and relax, work pipe with no sucess. 9/29/2019 9/29/2019 0.80 PRODS DRILL CIRC T Pump 7 bbls LVT, with 4 bbl out, 13,261.0 13,261.0 05:36 06:24 9/29/2019 9/29/2019 1.00 PRODS DRILL CTOP T Let soak (choke closed), pumps off, 13,261.0 13,261.0 06:24 07:24 annular = 3852 psi, WHIP = 786 psi, begin working pipe to 80K, no good, let soak in 70K tension 11.2 ppg calculated at window (8.79 ppg out, TVD window = 6528.2', WHIP = 815 psi) Work pipe, no good, pump .45 bpm LVT while working pipe, briefly crack choke while pumping 1.9 bpm, work pipe, no good, all LVT away, shut down pumps, crack bleeder vavle to see if hole is full, with -800 WHIP no flow through WT valve 9/29/2019 9/29/2019 1.30 PRODS DRILL CTOP T Load LVF 16 bbl into pill pit, build 60 13,261.0 13,261.0 07:24 08:42 bbl 1%/1% 776/LoTorq & 1.5 ppb beaded pill 9/29/2019 9/29/2019 1.10 PRODS DRILL CTOP T Bullhead 16 bbl LVT followed by 13,261.0 13,261.0 08:42 09:48 lubed/beaded pill to theif zone, 1.25 bpm, WHIP = 1950 psi, 69 bbl away (down to thief zone), shut down pumps & let soak, pop free holding 77K in tension (5 min soak time) 9/29/2019 9/29/2019 1.40 PRODS DRILL TRIP P Pipe free, pull to window 13,261.0 9,390.0 09:48 11:12 9/29/2019 9/29/2019 0.10 PRODS DRILL CIRC P Pump @ 1.8 bpm, open choke to 9,390.0 9,390.0 11:12 11:18 establish returns holding 3860 psi annular (-11.4 ppg EMW at window), returns -97%, confirm 11.4 ppg kills well (drop to 11.0 ppg) 9/29/2019 9/29/2019 0.30 PRODS DRILL DLOG P PUH, Log K1 for +17'correction 9,390.0 9,180.0 11:18 11:36 9/29/2019 9/29/2019 1.30 PRODS DRILL WPRT P RBIH to 13,150', RIW=8K-1 OK at 9,180.0 13,150.0 11:36 12:54 13,160' Page 20122 ReportPrinted: 10/1/2019 Operations Summary (with Timelog Depths) 1c-06 I& Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Sten Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operadw (N(6) End Depth (WEn 9/29/2019 9/29/2019 2.00 PRODS DRILL WPRT P PUH to 7890', PUW = 46K, clean 13,150.0 7,890.0 12:54 14:54 Log K1 for +6.5' correction, clean counter wheel 9/29/2019 9/29/2019 1.20 PROD3 DRILL DISP P Bull -head 50 bbl LRP to 13,160'(11.4 7,890.0 7,890.0 14:54 16:06 ppg), 1.25 bpmm, WHIP = 1207 psi 9/29/2019 929/2019 2.30 PROD3 DRILL DISP P Layin 11.4 ppg KWF to surface (1 -for- 7,890.0 78.0 16:06 18:24 1), 0.7 bpm @ 80 fpm per trip schedule 9/29/2019 929/2019 0.90 PRODS DRILL PULD P Flow check, LD BHA#15, inspect 78.0 0.0 18:24 19:18 pipe, 0.202, 0.202, 0.196, 0.203" found thinnest spot of 0.14" atypical wear, multiple flat spots radially around the pipe. .. Bit graded out 1-2, observed slight burnishing on leading edge cutters and reamers. 9/29/2019 929/2019 0.90 COMPZ3 CASING CTOP P Found basket ball sized ball of Brillo 0.0 0.0 19:18 20:12 pad in the stack just above swab #2. Attempted unsuccessfully to remove with rig vac and water hose. 9/292019 9/292019 1.40 COMPZ3 CASING CIRC P Make up jet nozzle and stab injector. 0.0 0.0 20:12 21:36 Jet stack @ 1.88 bpm , un stab, vac stack down, debris clean. 9/29/2019 9/29/2019 0.30 COMPZ3 CASING PUTB P Prep floor for running liner 0.0 0.0 21:36 21:54 9/29/2019 9/30/2019 2.10 COMPZ3 CASING PUTS P L1-02 completion -61 joints of 4.6#, L 0.0 300.0 21:54 00:00 -80, ST -L Slotted R2 Liner under a shorty deployment sleeve over a non ported bull nose. ( LOA 1849.97') .• Note, unable to pass 1.94" drift in first two joints, swapped to 1.63" drift Joint #4 box end found exploded - appears to have been made up, over torqued, and broke out. - removed From completion. 9/30/2019 9/30/2019 2.70 COMPZ3 CASING PUTB P Continued to PU lower L1-02 300.0 1,850.0 00:00 02:42 completion - 61 joints of 4.6#, L-80, ST -L Slotted R2 Liner under a shorty deployment sleeve over a non ported bull nose. ( LOA 1849.97') 9/30/2019 9/30/2019 0.10 COMPZ3 CASING PUTB P Clear / clean floor from running liner. 1,850.0 1,850.0 02:42 02:48 9/30/2019 9/302019 0.90 COMPZ3 CASING PULD P PU lower L1-02 completion running 1,850.0 1,894.2 02:48 03:42 BHA, inspect pack offs - good, fill the hole - 67 bbls KW lost while at surface. 9/30/2019 9/30/2019 5.50 COMPZ3 CASING RUNL P RIH with lower L1-02 completion, drive 1,850.0 13,165.0 03:42 09:12 by K1 for +1' (did not stop to correct counters) Stack weight at 11,538', PUW = 50K, work pipe, continue RIH, stacked at 12,108', PU, got by, work to pass 12,933', continue to work pipe to 13,165', bring up rate to 1.5 bpm, dp = 995 psi, PUW = 38K, liner is off TOL - 11,315' 9/30/2019 9/30/2019 2.60 COMPZ3 CASING TRIP P POOH, logged K1 for +10'correction, 13,165.0 44.0 09:12 11:48 1 1 1 1 pait flags at 9269.22'& 7244.22' 9/30/2019 9/30/2019 0.80 COMPZ3 CASING FULL) P PJSM, LD BHA #16, check coil for flat 44.0 0.0 11:48 12:36 I spots, pump managed pressure, KWF I arrives at rig Page 21122 ReportPrinted: 101112019 Operations Summary (with Timelog Depths) 1c-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start oepm Btert Time End Time Dur(hn Phase Op Code Advity Code Time P-T-XOperation (RKB) End Depth(M(B) 9/30/2019 9/30/2019 0.90 COMPZ3 CASING PUTB P PJSM, clear floor, off-load KWF, prep 0.0 0.0 12:36 13:30 to run liner 9/30/2019 9/30/2019 2.90 COMM CASING Tu -TBP- PU Upper Completion (ported BN, 67 0.0 2,039.0 13:30 16:24 jnts slotted liner, & shorty deployment sleeve), 30 bph losses PU liner 9/3012019 9/30/2019 0.60 COMPZ3 CASING PULD 5 PJSM, PU liner running tools, BHA 2,039.0 2,085.0 16:24 17:00 #17 9/30/2019 9/30/2019 2.60 COMM CASING RUNL P RIH W upper L1-02 completion - 67 2,085.0 11,320.0 17:00 19:36 joints of 4.6#, L-80, ST -L Slotted R2 Liner under a shorty deployment sleeve over a ported bull nose. (2040.93- LOA) Tie into Flag for+ 1.8' correction. PU Wt 36 k lbs, WOB -8 k lbs tag TOL @ 11320', WOB spiked from 5.4 to 7.9 klbs Stage pump to 1.5 bpm, Diff 908 psi, PU 36 k lbs, WOB 0 k - liner released - TOL 9274' 9/30/2019 9/30/2019 1.90 COMPZ3 CASING DISP P PUH after releasing liner, reset 11,320.0 43.0 19:36 21:30 counters, line up down the coil with seawater. Attempt to lift KW fluid. Losses to great to circ out an reuse KW Fluid. Bulkhead seawater down the coil turning it over to seawater, line up down the backside and bullhead seawater down the tubing while POOH. " unable to measure BHP. 9/30/2019 9/30/2019 0.50 COMM CASING DISP P LRS lined up to the coil, Load with 30 43.0 43.0 21:30 22:00 bbls diesel, SID, RD LRS, Pump additional 5 bbls seawater to the coil. 9/30/2019 9130/2019 1.00 COMPZ3 CASING PULD P PUD BHA# 17, liner running 43.0 0.0 22:00 23:00 assembly. 9/30/2019 9/30/2019 0.70 DEMOB WHOBOP DISP P Stab injector, bullhead 30 bola of 0.0 0.0 23:00 23:42 diesel to the well - FP. Prior to pumping w column of seawater - 8.55 ppg, WH was 707 psi. Unload coil trak from PDL. final tubing pressure 1120 psi. 9/30/2019 10/1/2019 0.30 DEMOB WHDBOP CIRC P Jet stack W seawater 0.0 0.0 23:42 00:00 10/1/2019 10!1/2019 0.30 DEMOB WHDBOP CIRC P Continue to Jet stack 0.0 0.0 00:00 00:18 1011/2019 10/1/2019 0.20 DEMOB WHDBOP CIRC P Flush, blow down, bleed off, unstab 0.0 0.0 00:18 00:30 injector 10/1/2019 10/1/2019 3.00 DEMOB WHDBOP CTOP P Remove upper quick connect, cut coil, 0.0 0.0 00:30 03:30 cut back 12' of pipe. Rehead, pull test to 35 k lbs- good, rehead test wire - greater than 2000 mega ohms and 64.8 ohms - good Vac down stack, dump meth, Bore -0 - scope stack. 10/112019 101112019 6.00 DEMOB WHDBOP NUND P Work RD checklist, ND BOP'S 0.0 03:30 09:30 I TOO "Rig released at 0600 hrs on 10/1/19 Page 22122 Report Printed: 10/1/2019 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1C Pad 1C-060-01 50-029-20564-61 Baker Hughes INTEQ Definitive Survey Report 17 October, 2019 Baker Hughes S ConocoPhlllips Baker Hughes CODOCOPh11�11J5 Definitive Survey Report Company: ConocoPhlllips Alaska Inc_Kuparuk Local Co.ordlnate Reference: Well 10-06 Protect: Kupamk River Unit TVD Reference: iC-06®94.00us1(iC46) Site: Kupamk IC Pad MO Reference: 1C-06®94AOusd(iC406) Wel: 1C-06 North Reference: True Wellbore: 1C 1.141 Survey Calculation Metlldd: Minimum Curvature Deal 1C 1-141 Damon. EDT 14 Alaska Production Protect Kupamk River Unit, NOM Slope Alaska, United States Map System: US State Plane 1924 (Exact solution) System Datum: Mean Sea Leval Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Ma P Zone: Alaska Zone Using geodetic scale factor Well IC -06 Well Position MOS 0.10 usfl Northing: 5,960,860.00us1 Latdude: 70.19'31.647N .am 0.00 raft Easteng: 561,864.00us1 Longitude: 149'29'$4.042W ' Position Uncertainty 0,00 min Wellhead Elevation Usl Ground Level 0.00 usfl Wellbore 1C46LI41 Magnetics klotlel Name sample Date Decllnatbn Dip Angle FMld steno I9 r) Inn 11113311,12010 101112019 16.44 60.88 57,404 Design 1C-061.1-01 Audit Notes: Version: 1 0 Phase: ACTUAL Tee On Depth: 9461.62 Vertical 5ec0ort Depth From [TVD) aNi ♦Elm phenomena (us"I (oalq Iran) IM 3350 0.00 0.00 0.00 survey Program Date --- From To Survey survey (USM loan) Survey lWegeem) Toed Name Deaelfpgdn BMM Date ErM DSM 100.00 9,400.00 1C -06 (1C ) GYINCTAMS Gymdala conlArseng Ms 0125,2000 9,430.00 9,00.62 1C-0811 MWTI (1C 1-1) Iii _ONLY MWD -INC ONLY_FILLER 9113,2019 91142019 9,467.00 9.496.06 1CAt61141 111TWD-INC(1C-06L1-01) MV4D-INC_ONLY MWD -INC ONLY _FILLER 91172019 911712019 9,527.18 13,780.61 U34)8L1-01 MWD (1C4KL1-01) MWD OWISG OWSG MWD - Standard 9/1812019 91212019 IM7Q 19 1:55:2" Paget COMPASS 5000.14 Bald III Survey ConocoPhillips ConocoPhillips Definitive Surrey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Go-ompote Rlfere6Ce: We111"6 Project: Kupamk River unit TVD ReRrence: 1C-06 @ 94.00ush(1C-06) Site: Kupamk I Pad MO Reference: 1L06 @ IMMi st (1C-06) Well: 10-08 North Reference: Tme Wellhere: 10 1.1-01 Survey DalcuhNon Method: M'eimum Curvature Gas".: 104161-141 DMAInue: EDT 14AIaSka Production Survey Baker Hughes .notation inleryolakd Azimuth - TIP KOP Imeryolated&cmNh 10/17/019 1:SS23PM Page 3 COMPASS 5000.14 Build 5511 Map Map Vertical MD Iz Atl TVD TVDSS -NIS +Hm NG(it) EaNn9 DLS °11929• Section SUNGY Tool Name Was) PI (°) lus) rt I s) u rc uzn 1 ) loan) u n Int I ttl 1 1 Int 9,030.82 54.24 57.64 6.50.65 6453.65 5,34534 3,18971 5,97423060 5..,98924 .82 5.245.24 AW NC_DNLY(2) 9,457.09 57.36 5764 6,551.24 6457,24 5,34808 31]41] 5,974,233.54 SM,W3.67 ON 5.%8.06 MrVP1NC ONLY (3) 9,456. 6511 51.00 55MAY 6.471.0 5436340 a1W42 5,974,249.04 565,014.79 34.10 5.363.40 MND4NC ONLY(3) 9527,18 75.76 44.58 6,575.47 6,481.4] 5,38263 3,216.55 5,974,268.45 565.035.76 36.69 5,30263 MNT)MSG (4) 95%.83 78.32 R55 6.562.14 6,488.14 5,40513 3,234.51 5,974,291.15 565.0.53.53 4046 5,.5.18 MN9MSG (4) q WT.70 8107 PR 6,587.58 6,493.58 5,43230 3,2000 5974,310.37 565.068.. 39.08 5,432.30 MW90WSG(4) 9,61685 8354 1061 6.691.39 649239 Smells 325.00 5,974.34872 565.074.45 35.11 5,41m.09 MND MSG (4) 9,64)58 WM 0.08 8594.02 6,500.02 5,490.54 325.72 5,974,376.. 565,077.04 35.62 5.490.54 MNDO MW (4) 9,67745 0920 30.9.62 659589 6,501.09 6SM.22 3,25.05 5,97440.34 55,07412 35.01 5520.23 WAIDMW (4) 9,70799 93.69 33905 6594.32 6.500.32 5549.5 3,24782 5,97443362 55,065.65 37.5 5,549.5 MWD MSG (4) 973755 96.43 3315 6591.71 6,49771 5,5]8.52 3,236.40 5,974,4620 565.053.61 20.71 5,576.52 aAJD aWSO(4) 976820 97,94 =W 6.587.88 6.49330 5,603A2 3,221.. 5974,480.25 565039.22 9.98 5.63342 MWD OW6G(4) 9]80.. 100.0 3273,4 6,58284 6,488.84 5,629.41 3206.25 5,974,515.11 55,023.43 ISM 5,629A1 MW00 WPW 9820.07 100.70 32426 6,snM 6.483.22 5,65171 3,1.70 5,974.539.20 5.50017.5 B0t 5,65372 MWDO MGG (4) %05985 101.15 32230 6,5]1.35 84]].35 5.,678.10 3,17152 5,97450.51 564,988.33 630 5,678.10 MWD OWS3(4) 9898.57 102. 33216 6,55.39 6,471.39 5,703.31 3.154.31 5,974.58557 54.9]091 5.76 5700.31 MWD MSG (4) 9.91845 10382 321.39 6.55.51 6,464.51 5,]23.15 3,135.32 5,974,85.28 564.95273 4.24 SMAS MWD OW6G(4) 0.94645 103.76 321.16 6,551.36 6,457.36 5.745. 3,118.10 5,974,630.34 Masson 0.71 574580 MND GIVES (4) 9,978.41 10290 3195 6,544.45 5.45045 5,768.34 3.099.51 5,87465.14 564,915.55 5.94 5,768.34 MND OW6G(4) 10,009.51 10317 318.85 6,53.44 6,.344 5,791A5 3.079.91 5.974,676.09 54,896.7! 1.21 5,791,45 MND OWSG(4) 10.039.69 100.35 321A1 6.531E 6,437,29 5,81439 3,05110 5,974,69.]7 564,67635 1DSO 5,81029 MND GwfiO(4) 10.070.13 9716 M.59 6.526.63 6,43263 5.837.99 3.042.66 5,97422.32 WeN14 1D.85 5.83799 MMD ONSG(4) 10,100.01 94.67 323.18 6,523.52 6429.52 551.69 3,01 5.974,745.5 564SWIG 8.89 5,SI69 MWD 0WSG(4) 10,126.37 9IA4 322.97 552.. 642609 584.33 3,007R 5.974,75.317 564,822.62 1247 5,54.33 MND CMG (4) 10,158.75 89@ 32133 6,521.94 642784 5,900.31 2,989.05 5,8]4,]92.19 5..80398 7.82 5,W8.31 MND OMG(4) 10,189.51 69.M 32092 6.522.13 64013 5,93225 2.95971 5,9]4,815.9] 584784.48 1.0 5,932.26 MWD 0%6G(4) 10219.5 N. 321.73 6.57131 6420.21 5,9579 2.95.94 5,974,839.34 564]65.46 269 5.9539 MNOONSG(4) 1020.64 8963 324.96 6.522.33 6,420.33 5.979.45 2933.04 5.97486325 5647475 10. stent 85 MWDOW9G(4) 102..21 0860 379.14 6,52.25 6.428.25 600549 2916.41 5.9]46..]6 564.730.5 14.10 6,005.49 MWD OWSG(4) 10.310.03 08.5 31105 6.521.03 6,427.03 6.03159 2,902W 5,974914.73 54.715. 13.14 6,031.5 MND0 MSG (4) Baker Hughes .notation inleryolakd Azimuth - TIP KOP Imeryolated&cmNh 10/17/019 1:SS23PM Page 3 COMPASS 5000.14 Build 5511 Survey Con000Phillips C0IWC0Ph1llIP5 Baker Hughes Definitive Survey Report Map Company: ConocolhAlips Alaska Inc Kupamk Local Cocrdmate Reference: M11 1C-06 Protect: Kupamk River unit TVD Reference: iC45 @ 94.00ush(iC46) She: Kupamk I Pau MD Reference: 1C @94.00ustt(iC-06) Well: 1C-05 North Reference: True WellEora: 1p 0-01 Survey Calculation Method Minimum Curvature Oesipn: 1C410L141 boneless.. EDT 14 Manse Pmoluctlon Survey Map Map Vertical MD Inc A6 TVD TVDSS -NIS eEl-W No(I Foshan OLS Section Survey Tool Name AOnOt9fiOn (-I 19 1°I (ush) (usnl lusttl (nal") (I pt) 1°1100') Itt) 10,340.25 90.60 335.98 6,52140 642740 6,03.66 2.689.00 5.974.91189 564.702 on 974 6,05896 MWD MSG 14) 1404.17 noun 339.50 6520.94 0,426.94 6,050.25 26]6.16 5,974.97317 506.19.58 1039 6,00.25 MWD MSG (4) 10.399.55 91.8 342.97 652031 6,420.37 6,11427 2,assma 5,914.ne"2 564681.22 tA08 6,114.27 MWD OWBG(4) _ 10.42911 90.43 345.11 6,519.01 6.42501 6,14260 2,059.87 5,975,02546 50,6886 045 6,142.68 MWOMSG (4) 10,458]3 0920 kneuk, 6,51991 642581 61846 2,85277 5975,0.318 564.685.52 10.53 6,M.46 MWD OWED (4) ' j 10.489.34 86.45 348.09 6,521.03 6,427.03 6,201,47 2,04892 5,975.08013 SM 65943 9.65 6.20147 MWCi MI (4) 10.519.32 8&M351.27 6,5M.46.429.0,1 6,23094 2,041.02 5,975.11350 584,65409 7.51 6,230.94 MODOWSG(4) 10.546.39 6680 354.27 6,52492 6.430.92 6,259.71 2,836.17 5,97514230 564650.20 10.53 6259.71 MWDOWSG(4) j 40.50.20 0745 157,20 652656 01 6291,40 2,035.03 5.91 564647.60 979 6,NIAB MJVTJOWBG(4) 1060.53 67.17 076 6,527.06 6,4JJ.96 6.319.60 2835.35 5,975,20224 564645.89 12.28 6,31&68 NWD OWSG(4) 10,0030 8)40 2.25 6529.35 6.435.35 6,351,16 28317.18 5,975,23571 564,647.45 4.02 6,351.16 NWD0 MISS (4) � 10,668.59 80.37 0.69 6530.39 6436.39 6,379.77 283.91 6975262.33 584,647.95 627 637977 MWD O MEG (4) 10,098.11 80.53 tID 6,531.19 6,137.19 6,400.17 2837.42 5.675291.73 564.648.22 211 6,409.17 MW➢OWSO(4) 10,730.57 3.6 240 6533.49 6438.46 6.44159 2830,46 5,975,324.15 330.648.3 6.18 6,441.59 MWD MSG (4) 10)59.5 65.60 2.20 6534.35 6440.3 6.47078 283964 5,975,353.35 564,649.93 342 6,47078 MWOO SG 14) 10.793.69 85.17 1.- 653.99 6,44299 6.504.50 2840.76 5.975,307.0 564,80.77 274 6W.50 MWD MSG (4) I 10,825.13 85.0 359.0 6,539.42 6, a5A2 6,535.84 2,841.16 5,915,41842 564.8091 6.05 0.53564 MWD MSG (4) 16858]7 0.52 0.15 6.541.04 644104 656944 2,841.16 5.975.452.01 W.65ow 7.69 6,3941 MWOMSG (4) 10300.41 87.0 010 654216 644610 6,589.0 2.&I.M 5,975,48t62 34,650.45 4.06 6.599.0 MWOMSG (4) 10928.53 0569 0.20 6,544.71 645071 6619.10 284t3 5,975.52tOS 564.6!1 347 6,09.10 MWO OWSG(4) 109580 0560 015 6.546.95 645295 6,668 48 2,841.42 5,975551.1 56060.0 0.35 606.49 MWD OWuG(4) 10980.41 65.57 OW 6,549.29 6,455.29 6,60 .80 2,84159 5,975.561.3 56060.0 1.15 6.690.30 MWD OWSG(4) 11,01B33 85.11 359.90 65518 6,49)2 6,8662 2.64169 5.975,6111,9 564649.06 252 6,72862 MWD OWSG(4) ' 11,04619 84.48 35945 6.551.46 0,450.40 5.75606 2.841.53 5,975,6301.20 SW fi49.40 260 6,75866 MWD OWED (4) 11,078.19 8053 358]0 6.557.31 6,463.31 6,788n 2,041.05 5975,670.76 5"San 2.56 6,10.22 MWD OWSG(4) H.10TS5 85.0 359.11 6.50.01 6.466.01 6,817.05 2,040.48 5,975,710.3 564647.91 221 6,617.85 Mv4D0WS3(4) 11.tJ13 8601 358.84 6,Sn23 640.35 6,847,76 2039.95 5,915,73026 04647,13 3.32 6,847]6 MPoDOWSG(4) 11,167.51 89.39 357.80 6,56154 0.469.54 6,07.30 2,039.08 5,.7575901 564646.02 Ito 6,877.3 MWOOWSG(4) 11,197.94 9046 357.49 65410 6.469.58 6,90167 2837.83 5,975793.17 564644.52 366 6,907.67 MWD MSG (4) 7122181 9095 3131 6,563.21 6,469.21 6,937.53 283.48 5,97583.0 564.642.92 1]5 6,937.53 MWD MSG (4) 11256.'9 9133 357.42 6,56263 6.40.0 6,967.84 2835.08 5,975,8031 56464127 OH 6,%184 MID MSG (4) 101172019 155:23PM Page 4 COMPASS 5006), 1481uAE 6541 Conoc0PhillipS ConocoPhillips Definitive Survey Report Compan, ConocoPNlk, Alaska Inc Kuparuk LOcal Coordinate Reference: We9 IC46 PTfett Kuparuk River❑nil TVD Reference: 1C-06 @ 94.00us8(1 C-06) SIM: Kupamk lC Pad MO Reference: 1C-05@ 94.ODus11(I C-06) Well: 1C-06 Nodh Reference: True Wellbore: 1D L1-01 Survey Calculallon Method: Minimum Curvature Design: 1C-06Ll 01 Database: EDT 14 Alaska Production Survey Baker Hughes Map Map µSean MD Inc Av TVD TVDSS sNIS +HAM Nont,IN ease" D" Sury yrew ra,au � Annotation (usn) (1) P) (..ft) (uaa) (ua0) (w1N (17 tlN ('/1oa) (m 11.2683] 9104 357 fig 6.562M 6466.04 6996.60 2833.80 5,975.08145 56639.74 1.09 699900 MWOOWSG 14) 64,310.59 90.00 355.50 6.561.76 46 6].]6 1,028.16 3,832.00 5,915,910.60 584.83!] 0 8.02 20 2,0]8 MbD MSG (4) 11. 348.93 0939 359.00 6,561.93 8,481.93 7,958.36 2,830.55 5975,94078 564,636.03 11.27 2,0531 MMD GWSG(4) 11,378.81 90.89 359.18 8.581.88 6.462.82 2,008.34 2.53033 6915.870.15 %4fi35A2 5111 7068.34 M4A MSG (4) ' 11.412.45 9021 04 6.551.54 8.467.54 7,12198 2.830.31 5.926,60439 564635.23 3.03 1,121.66 M4N OWSG(4) 11,438.45 9252 0.41 6560.92 6 wsw 714797 2,930.52 5,976,=37 Go Ion 0.88 7,1292 MWD aN6G(4) j 11,469.37 9209 0.14 6,559.50 aA..5o 1,11913 2,933.82 5,916060.54 564.635.28 1.64 1,120.13 MWD a05G(4) 64.560.7) 8991 352.85 6.550.57 6.464.52 7,21923 2,860.35 5,978.09863 554.83450 1069 7.21823 MND OWS3(4) 11,533.11 92.10 3581 6.550.09 6,464.09 1,24255 2,02.40 5 a 124.93 5646"" 884 7,24255 MWOOWSG(4) 11,56304 89.42 355.78 6551.67 8,46&67 2.2842 2,89.11 5,976,154]9 56463146 1163 1,222.42 MWD GWSG(4) 1159223 9138 35328 6,55746 6463.46 1,30149 202.12 5,916,183.83 564,628 56 951 7.301.49 MWD CWSG(4) 1162311 11 355.46 6,11,11 6461.98 7,33255 2,02220 5,976,214.02 554.625.39 101 2.332.55 MWD0WSG(4) H 661.31 96.00 35693 6.552.14 6,458.14 2,328.13 2,819.32 5,608.258.6 W.02.15 6.0 1,376.13 MWDOWSG(4) H 69853 90.98 35836 8.5124 8.4`1.24 2.407.23 2812.51 5.975,209.49 56.620.98 18.2 1,402.23 MWDGWSG(4) ' 11 nl.2 89.14 356.2 6.550.21 84%.21 1.439.91 2815.39 5.916,3T216 564611.69 5.63 2,439.92 MWDOWSG(4) 11,2598 89.19 35612 6,550.47 6456.41 1,46795 281352 5,916,350.10 564.615.59 235 7,457.95 MND OWSG(4) 11,780.8 07.76 355.43 6,551.11 6451.11 2,492.48 2,811.1 5,976,379.69 564.81342 8.04 7,497.48 MWD OWSG(4) 11,821.59 86.2 355.59 8.552.01 6.458.81 7,52.97 2.809.61 5,91641218 564,61L7 4.66 2,52901 MWD OWSG(4) 11,84945 06.99 356.89 6551.45 8.41.45 7,557.4 2,808.1 5.976.439.91 564,61.36 2.61 7,551.74 MND OWSG(4) 11,682.1 6833 35915 6,5658 6,4Q.35 2,51.23 2,.,. 5,976,4831 564.60712 3.1 1,58023 MWD GWSG(4) 11.9081 852 357.65 6,558.2 6.464.20 7,6171 2,14.1 5,sna,ed 16 564,8145 5.90 2,61703 MND OWSG(4) 11.92.49 80.34 35631 6,559.8 6.418 7,646.40 2,01.1 5,978,520.59 564,811 9.75 1,81649 MND ON5G(4) 11,971.30 Salo 355.11 6,561.39 6467.30 7.679.16 281.1 5,92 8561.25 584.61.93 1.60 7.679.16 MND ONSG(4) 11,990.47 Val 3531 6,562.81 0,4%01 7]116 2,71.1 5, SIM li .22 564,596.11 825 1,206.16 MWD OWSG(4) 1205.49 60.83 353.8 8%311 646817 7.735.86 27WAIS 5916610.01 564.59452 4.83 1735.98 MWD GWSG(4) 12,19.14 91.56 353.66 658366 64166 1,761.1 2,191.11 5,916,649.02 61,590.8 0.01 1,762.02 MwDO w(4) 12,080.68 91.87 353.66 6.562]9 646019 7.795.21 2181.92 5,976.621.74 584.587.2 107 7,71," MWD GWSG(4) 92.92 363.1 6.561.62 646762 7,823.64 278468 5,926,79650 564,563.82 427 1,023.64 MWDOWSG(4) '12,118.15 12,147,N 9285 35&54 6,51.09 6466.09 7,853.87 2781.13 5.976.23510 56.580.02 1.52 1,13.01 MWDOWSG(4) ' 1211711 9347 352.1 6550." 645444 7583.49 2111.62 5,916,26636 56,526.2 281 1,893.49 MWDOWSG(4) 122935 9267 353.17 5556.22 6462.17 7,91446 211386 5,9M,296.8 564,572.25 2.1 7.91446 MWDOWSG(4) 10/112019 15 23PM Pages COMPASS 5000.148ui 05H Conoi:4 Phillips Conmolthillips Definitive Survey Report Baker Hughes Company ConocoPhllllps Alaska Inc_Kupamk Local CaomdNah Ralapnca: Wall 1C-06 Profett: Kuparuk River Unit TVD Reference'. 1C-06®94.00uah(1"e) She: Kupamk IC Pad MD Reference. 1 C-06@ 94.00usR(I C46) Well: 10-06 North Reference: Thus Wellbom: 1C-061-1-01 Survey Calculation Method Minimum Curvature Oeslgn: 1C-0611-01 Database: EDT 14 Alaska Production Survey 101172019 1:5529 Pape 6 COMNSS 50114 shot 6511 Map Map enlcal 1.10 Ino ABI TVD Titters 4105 +sAy No(it EaS) OLS settlon Tool Name (Umo (') P) (Into iuslq (mart) (usi Ol ow) Survey Annotation (it) I I hl IRI 1224655 8].81 35334 6,6%.5] 6,462.57 7,952.38 276931 59]6,839.1.8 564.567.45 1.247 795238 hIW00W5G 141 i 122]6]4 03.94 353.33 6,550.60 6464.88 7.981.79 2M594 5,9]8.8 Sa 554,5E3.78 13.37 ],981.]9 MW lOWSG(4) 12,30244 64]8 35.56 6.561.37 6,46]3] 0.007.73 2,763.41 59MAN 47 51K.Sl 65] B4OJ].M MWD OWSG I4) 1233307 81 35.30 653.76 6,469]6 0,038.18 2,761.25 5,976,91.9.90 W'SM62 &45 8,038.18 MWOOWSG (4) 12%081 89.14 357.31 6,5415 saTJ5 B.OS.W 2,]59]0 6'sn's4].55 564,55.05 9.29 8.055.86 MWD OW63(41 1239233 90.37 35471 6,564.5 6,4]008 &097.30 2.757.51 5.976,9]&90 564.554.40 9.12 8.007.30 MWD OWSG (4) 1242229 91.75 35t.90 656G33 6,470.33 0,127.13 2.754.80 5,9T7IX619 564.551.44 4.5 8.127.13 INAU OWSG (4) 1245235 9212 354'4 6,563.31 6,469.31 6.157.06 2.752.06 5,87],030.69 564.548.48 1.50 11 MWD OWSG (4) 1248234 8205 354.&5 6,56222 645.22 6.103.88 2749.31 59T7.06i 54.545.47 01 8,176.09 mAr, owSG (4) 12513.93 9064 35.5 (1 6,46247 8,218.37 2,70616 5,9TIP]9.95 564.512.65 5.52 8,218.37 MAD OWSG I4) I 125421.34 8912 365.01 6,56130 6467.30 8,246.99 2.744.47 5,972120.54 54.54013 4.36 &246.99 MrY11 OWSG (4) 12,5]30] 89,82 35.03 6,561.60 6467,51 &2]].30 2141'3 5,972150.03 51.537.24 034 8.2]].30 MADOWSGl4) 12WZ35 89.76 35.44 Simi 81 8.305.48 273940 5,062107.99 564.534.57 102 8,306.40 MINDOW0G14) i 12624.828 9.32 35.14 6,51.80 6.467.80 RM8,37 2,]3].55 5,977.210.36 506,532.54 2.33 0,328.87 MADOWSG(4) 1253.48 0&95 Zis' 6,56223 640623 0.35244 2,735.23 59'n,238.90 076,521..99 190 &357.44 k1WDOWSGI4) 126131 90.12 35.30 6,58247 6468A7 8,385.99 2.733.65 51972268.44 51.320.15 10.03 8.388.98 MMDOWS'i 12,71213 9040 0.12 6,56234 6,4hi 8,41804 2.733.25 597).206.48 561 5.31 8.416.04 MADOWIii 1214278 87560 am 6,56207 6,468.07 6446.88 1,73345 5,972320.12 564,5P.46 9.29 0,446.68 MJUDOW6G141 12,76].59 66.83 2.15 6,564.06 6.47006 8.471.45 2.734.05 5,06735289 54.527.86 686 8,471.45 MJUD OWSG 141 1278249 88.74 359.38 6565.2] 6.47123 0,501.32 2,734.45 5,062362]6 561520.01 11.25 6,501.32 MADOWSGI4) 12 ,821.1] i 6 9.48 2D 5]0 6,5 6,4]1.70 &530.992.735.01 SRT7,41243 54.52&.2 11.69 6530.99 MW00WSG14l 1285].]1 8245 361 6,506.51 6,48.51 Simi 2.735.6837 35.68 58.44285 54 ]5 .528 11,05 8.51.06 MAOOWSGI4) ' 1.2118261 86.46 299 6,560.10 6,04.10 8.591.35 2]35.]' 5,977.4'79 56155.21 1112 8,591]5 MWDOWSGI4) 1281251 8516 0.13 6,570.03 6,476.06 8.82117 2,737.19 5,977,502.62 54.5HP '.47 8,621.17 MAD OWSG (4) 1294].25 0644 358.60 6,571.% 6477.85 0,650.85 2136.71 59725322B 561629.04 721 8,50.85 MADOWSi 1297].62 86.74 359.01 657&]5 6,479.]5 0,681.15 2,735.92 5.0675825 ws20.00 3.46 8.51.15 MADOW&G14) 1306&3] 89.54 3520 '1 6,48015 8,77307 2]351] 5,972503.29 564,2200 946 8.71.1.07 MADOW6G14) i 1303824 9227 369.91 6574 6480.26 8,74113 2734.69 5'72623.14 561 1078 8141.73 MAOOWSG(4) i13,069.03 9378 35.82, 6,5'61 6470.61 8.77326 2,73318 5,972854.5 51625.ID 1005 S,T73.26 MADOWSG(4) 1309717 9192 35/.86 6,57054 64]6.54 Sets 49 273252 6,971.69188 51 5.06 8.80U.49 MADDAY'S 1 13129.65 94.83 35602 656779 647370 8832.83 2731.36 5 i 714.20 564,522.19 051 6242.83 MAD OWSG (4) 101172019 1:5529 Pape 6 COMNSS 50114 shot 6511 Survey Cortmolahillips Baker Muglx36$ COnOCOPh1111�J5 Definitive Survey Report Map Company: Con000Polips Alaska ac_Kuparuk Local C.aNnate Refinence: Aell1C-06 Project: Kupamk River Unit TVD Reference: 1046@94.01(i(C-06) am: Kuparuk 1C Pad MD Reference: 1C-06@94.01(iC46) Well: 1C416 North Refereal True Wellbore: 1C-0611-01 Survey Calcupnon McMoO: Minimum Curvtlure Desl9n: 1C -06L1-01 Oatabase: EDT 14 Alaska Production Survey 10/11!2019 1:55:28PM Pape 7 COMPASS 6000.148u9E 651,f Map Map Vertical MO Ix Aad TVD TVD65 ♦NIS -EM Northing Eautin9 DLS Section Survey Tool Name Annotation (-am 1°) (°) Juan) (tuft) (usft) loan) Ifll (X) 1°1100'1 (n1 13.160.91 8437 356.50 6,565.27 64]12] 6,66396 2,]29.90 5 9773931 56452047 9.82 8.663.96 vital MSG (4) 13,194.57 92am 356.40 6,563.14 646414 5,897.49 2.79746 59]],]]882 564510.16 441 6.69249 ar,A)MSG (4) 13.217.44 9157 356 515 6.562.25 6489.25 8,920.30 2,]25.48 5,901.641.62 564,516.59 575 0,920.30 NWMarra (41 13.26325 Ill Mai 6.56189 646269 8,965.96 2,723.20 5,90].84].2] 564.51293 569 8.965.98 NVID MSG (4) 13.280.]0 89.46 353.25 6,562.16 6.468.16 8,991.30 2]20.66 5,9D.621.57 564,51016 7.73 8,0130 MJN Maas (4) 13,31643 09.91 35250 6,562.32 ."'Al 982000 2,716.98 5.9]],902.03 564,56426 364 9.02080 MWDOW6G(4) 1J35355 89.R 35258 6.962.43 6,468.43 9.055.63 271245 5.801.93682 584,501.44 0.75 9,055.63 MUADMi 4) 13,38986 8854 348.46 6,562.67 6,468.6] 9.01 2764.62 5,97..972.80 564,49533 10.53 9,091.46 MWD MSG (4) 13.423.97 9631 30.97 6.552.71 6,468.71 9,124.88 2699.]7 5,978,005.95 564.46420 345 9,124.88 MWD 06466(4) 13"VISA. 9009 346.73 6,Xi2.64 6,64664 9,1a5.49 26015 5,976,026.53 NM.48al Site 9,145.49 MWD MSG (4) 19,03.95 91.35 34255 8.56228 6468.28 9.17362 2,664.73 5,970,054.59 564.4PEM 523 9173.62 MD i 13.506.09 9043 348.26 6,581.)6 6 4673 9,205.04 2,682.00 5,970,005.86 554 k68.71 360 9iIS04 MND MSG (4) 13.634]5 8025 30.33 SSAS1 646].81 9,233.05 2675.94 5,816113.91 S64.463a8 3.31 8.2ia05 NAW MSG (4) 13.5511.05 50.15 341 6 o So 6,467.50 9,261.57 2669.23 5,978,14238 564.456.53 367 9,26157 MND MSG (4) 13,584.45 9006 343.30 6, 561 A5 6,46Ta5 9,290.91 2661.26 5,978,171,M 564.448.32 9.26 9X0.91 MNO 06456 (4) 1362426 Sol 34125 6,56131 6,46].21 9,319.33 2,642.19 5978,199.09 564438.02 7.62 6319.33 MNID MW (4) 13.E80.44 %.92 34081 8,664.65 6,466.85 9,353.53 2,800.47 5,978,134.09 564427,02 0.95 8,363.53 MJul1MSG (4) 1309.51 Saw 30314 6,560.65 6,465.65 9,381.17 2631.50 597626146 564.41].52 695 9,381.17 MNll OM6G(4j ' 13,026.26 07.61 30.3.04 6,56170 8.467.70 9,416.35 26]0.01 5,978.X6.]3 564446.84 393 9,08.35 MND OWSG (41 . 13,]46]1 8665 U4 aal 6,582.42 6.468.42 9,a37,75 2,61425 5.91 584.400.11 498 9.43].]6 MPoolt Car 4) 13700.61 9064 30257 8.552.n 6,169.61 8,46834 2.6Da50 5,978.315.49 6.3041 635 9,46624 givADMIll 13,822.80 9061 312.57 6.51 • 6468.15 8,50].]3 2592.40 5,978.381.46 561.37260 0.00 9,50273 PROTECTED 10 TO 10/11!2019 1:55:28PM Pape 7 COMPASS 6000.148u9E 651,f BA EIS 0PRINT DISTRIBUTION LIST HUGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME IC -06L1-01 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(ftakerhughes.com 219118 31369 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (WNS Petroleum Technician) 700 G Street. Anchorage, Alaska 99510 to acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE September 24, 2019 TODAYS DATE October 22, 2019 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 Revision STATUS Final Replacement: No Details: Rev. Requested by: -- COMPANY FIELD I FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY REPORT ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) LOGS CGM, Final Surveys) (Compass) PERSON ATTENTION # OFnPRINTS4 UrIMIN OF COPIESn # OF CnOPIES # OF V V n V n# V V V nCOPIES V RP North Slope. EOA. PBOC. PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 o 3 Exxon Mobil, Alaska Attn: Lynda M. Yaskeil and/or Leonardo Elias ^ 19 3201 C Street, Suite 505 Anchorage, AK 99503 4State of Alaska -AOGCC 1 1 Attn: Natural Resources Technician If 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division of Oil & Gas *** 1 Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 Baker Hughes SDate` � October 18, 2019 Ifo: Abby Bell AOGCC 333 West 7" Ave, Suite 100 Anchorage, Alaska 99501 I 21 91 18 3 133 3 Letter of Transmittal Harvey Finch Baker Hughes 795 East 94' Avenue Anchorage, Alaska 99515 'Please find enclosed the directional survey data for the following well(! 1C -06L1 1C -06L1-01 1C -06L1-02 RECEIVED OCT 2 1 2019 A.OGCG (3) Total print Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files i Harvey Finch, Baker Hughes, Wellplanner Harvey.Finch@bakerhughes.com ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1C Pad 1C -06L1-01 50-029-20564-61 Baker Hughes INTEQ Definitive Survey Report 17 October. 2019 Baker Hughes 21 91 18 31333 Project Kuparuk River Unit, North Slope Alaska, United States Map System: ConocoPhillips r ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 1C Pad MD Reference: Well: 1C-06 North Reference: Wellbore: 1C-061-1-01 Survey Calculation Method: Design: 1C-061-1-01 Database: Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) Description Map Zone: Alaska Zone 04 Survey (Wellbore) Well 1 C-06 1C-06(1 C-06) Well Position •N/S 0.00 usft Northing: 9,467.00 +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 1C -06L7-01 9/23/2019 Magnetics Model Name Sample Date BGGM2018 10/1/2019 Design 1.C-O6L7-01 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 33 50 Survey Program Date From To Description (usft) (usft) Survey (Wellbore) 100.00 9,400.00 1C-06(1 C-06) 9430.00 9,460.62 1C-0611 MWD4NC(1C-061-1) 9,467.00 9,496.86 1C-0611-01 MWD-INC(IC-061-1-01) 9,527.18 13,780.61 1C -06L1 -OI MWD (1C-061-1-01) Well 1C -O6 1C-06 @ 94.00usft (1C-06) 1C-06 @ 94.00usft (1C-06) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor Baker Hughes 5,968,860.00usft Latitude: 70° 19'31.647 N 561,864.00usft Longitude: 149" 29'54o42 W usft Ground Level: 0.00 usft Declination Dip Angle Field Strength (') (1) K) 16.44 80.86 57,404 Tie On Depth: 9,460.62 +N/ -S •EJ -W Direction (usft) (usft) (1) 0.00 0.00 0.00 1011712019 1:55'23PM Page 2 COMPASS 5000.14 Build 85H Survey Survey Tool Name Description Start Date End Date GYD-CT-CMS Gyrodata contcasing Ms 8/25/2000 MWD-INC—ONLY MWD-INC—ONLY—FILLER 9/13/2019 9/14/2019 MWD -INC ONLY MWD-INC_ONLY FILLER 9/17/2019 9/17/2019 MWD OWSG OWSG MWD- Standard 9/18/2019 9/23/2019 1011712019 1:55'23PM Page 2 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc-Kuparuk Local Co-ordinate Reference: Well 1C-06 Project: Kuparuk River Unit TVD Reference: 1C-06 @ 94.00usft (1 C-06) Site: Kuparuk 1C Pad MD Reference: 1C-06 @ 94.00usft (1C-06) Well: 1C-06 North Reference: True Wellbore: 1"61-1-01 Survey Calculation Method: Minimum Curvature Design: 1C-0611-01 Database: EDT 14 Alaska Production Survey Baker Hughes S Annotation Interpolated Azimuth - TIP KOP Interpolated Azimuth 10/17/2019 1:55:23PM Page 3 COMPASS 5000 14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS +Nf-s +E/ -W Northing Easing(°1100') OLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) Survey Tool Namr (ft) Iftl (R) 9,46062 54.24 5760 6547.65 6,453.65 5.345.24 3.16971 5,974230.68 564,989.24 24.82 5..345.24 MWD -INC _ONLY (2) 9,467.00 57.36 5764 6.551.24 6457.24 5,348.06 3,174.17 5,974,233.54 564.993.67 48.90 5.348.06 MWD -INC _ONLY (3) 9,496.86 6571 5160 6,565.47 6,47147 5.363.40 3,19542 5,974,249.04 565,014.79 34.10 5,36340 MWD -INC ONLY(3) 9.527.18 7576 44.58 6,575.47 6,48147 5,382.63 3,216.55 5,974,26845 565,035.76 38.69 538263 MWD OWSG(4) 9,556.83 7832 32.55 6,582.14 6488.14 5.405.18 3,234.51 5,974,291.15 565053.53 40.46 5,405.18 MWD OWSG(4) 9.58770 8147 2012 6,587.58 6.493.58 5,432.30 3,248.09 5,974,318.37 565,066.89 39.08 5,432.30 MWD OWSG(4) 9,61685 8359 1061 6.591.39 6,497.39 5,460.09 3,25588 5,974,346.22 565.074.45 35.11 5,460.09 MWD OWSG(4) 9,647.59 8668 0.08 6,594.02 6,500.02 5,490.54 3,258.72 5.974,37669 565,07704 35.62 5,490.54 MWD OWSG(4) 9,677.45 8920 34962 6,59509 6,501.09 5,520.22 3,256.05 5,974,406.34 565,07412 Won 5.520.22 MWD OWSG(4) 970799 9369 339.06 6,594.32 6.500.32 5,54956 3.247.82 5.974,435.62 565,065.65 37.56 5.549.56 MWD OWSG(4) 9,737.55 96.43 333.56 6.591.71 6.497.71 5.576.52 3236.00 5974.462.47 565,053.61 20.72 5,57652 MWD OWSG(4) 9,76820 9794 330.88 6,587.88 6,493.88 5.603.42 3,221.83 5,974,489.25 565,039.22 9.98 5,603.42 MWD OWSG(4) 9.798.93 100.93 32724 6,582.84 6,488.84 5,62941 3,206.25 5,974,51511 565023.43 1520 5.629.41 MWD OWSG(4) 9,828.87 100.70 324.26 6,577.22 6,483.22 5,653.72 3.18970 5,974,539.28 565.00668 9.81 5,653.72 MWD OWSG(4) 9,859.85 101.15 322.30 6,57135 6,477.35 5,678.10 3,171.52 5.974,563.51 564.988.30 6.38 5,678.10 MWD OWSG(4) 9.888.57 10280 322.16 6,565.39 6.471.39 5,700.31 3,154.31 5,974,585.57 564,970.91 576 5,700.31 MWD OWSG(4) 9,91845 10382 321.39 6,558.51 6,464.51 5,72315 3,136.32 5,974,608.26 564,952.73 4.24 5.723.15 MWD OWSG(4) 9,94845 10376 321.18 6,551,36 6.457.36 5.745.88 3,118.10 5,974,630.84 564,934.32 071 5.745.88 MWD OWSG(4) 9,97841 10290 31958 6,544.45 6.450.45 5,768.34 3.093.51 5.974.653.14 564,915.55 5.94 5.76834 MWD OWSG(4) 10,009.51 103.17 319.85 6,53744 6,44344 5,791.45 3,079.91 5,974,676.09 564,89577 121 5,791.45 MWD OWSG(4) 10,039.69 100.35 321.41 6,531.29 6.437.29 5,81429 3,061.18 5,974,698.77 564,876.85 1063 5,814.29 MWD OWSG(4) 10,070.13 97.26 322.59 6,526.63 6,432.63 5,83799 3,04266 5,974,722.32 564.858.14 1085 5,837.99 MWD OWSG(4) 10,100.01 9467 323.18 6,523.52 6.429.52 5.861.69 3,024.73 5,974,745.M 564.890.02 8.89 5.86169 MWD OWSG(4) 10,12837 9114 322.97 6,522.09 6428.09 5,884.33 3,007.72 5,974,768.36 564,82282 1247 5,884.33 MWD OWSG(4) 10,15875 89.42 321.33 6,521.94 6,427.94 5,908.31 2,09.08 5,974,792.19 564,803.98 7.82 5,90.31 MWD OWSG(4) 10,189.51 89.85 320.92 6,522.13 6,428.13 5,932.26 2,969.77 5.974,815.97 564,764. t8 193 5.932.26 MWD OWSG(4) 10,21965 89.88 321,73 6,522.21 6,428.21 5,95579 2.95094 5.974,839.34 564,765.46 2.69 5,955.79 MWD OWSG(4) 10.24964 89W 324.96 6,522.33 6,428.33 5,979.85 2,933.04 5.974.863.25 564747.36 10.80 5.979.85 MWD OWSG(4) 10,280.21 90.68 329.14 6,522.25 6,428.25 6,00.49 2,91641 5,974,888.76 564,730.53 14.10 6,005.49 MWD OWSG(4) 1031003 90.95 333. D5 6,521.83 6,427.83 6,031.59 290200 5.97491473 564715.90 13.14 6,031.59 MWD OWSG(4) Baker Hughes S Annotation Interpolated Azimuth - TIP KOP Interpolated Azimuth 10/17/2019 1:55:23PM Page 3 COMPASS 5000 14 Build 85H Survey ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kupamk Local Co-ordinate Reference: Well 1C-06 Project Kuparuk River Unit TVD Reference: 1C-06 @ 94.00usfl (1C-06) Site: Kupamk 1C Pad MD Reference: 1C-06 @ 94.00usft (1C -O6) Well: 1C-06 North Reference: True Wellbore: 1C-061-1-01 Survey Calculation Method: Minimum Curvature Design: 1C-061-1-01 Database: EDT 14 Alaska Production Survey Baker Hughes S Annotation 10/17/2019 1,55 23PM Page 4 COMPASS 5000. 14 Build 85H Map Map Vertical -- MD Inc Azi TVD 7VDSS +WS +E/ -W Northing Eat DLS Section (usft} (°) (°) Waft) (wft) Waft) (usft) (`/100 Survey Tool Name (8 1 (R)) ( (ft) j 10,340.25 90.68 335.98 6,52140 6,427.40 6.058.86 2,88900 5,974,941.89 564.702.68 974 6,058.86 MWD OWSG(4) j 10,374.17 9086 339.50 6,520.99 6.426.94 6,090.25 2.87616 5.974,973 17 564,689.58 1039 6,090.25 MWD OWSG(4) j 10,399.55 91.72 342.97 6,520.37 6.42637 6.114.27 2.86800 5,974,997 12 564,681,22 14.08 6.114.27 MWD OWSG(4) 10.429.11 9043 345.11 6,51981 6,425.81 6,14268 2,85987 5,975,02546 564,672.86 845 6,142.68 MWD OWSG(4) 10,459.73 89.20 348.09 6,519.91 6,425.91 6,17246 2,852.77 6975,055.18 564,665.52 10.53 6,172.46 MWD OWSG(4) 10,48939 8646 349.09 6,521.03 6,42703 6201.47 2,846.92 5975.084.13 564,65943 9.85 6,201.47 MWD OWSG(4) 10,519.32 85.88 351.27 6,523.04 6,429.04 6.230.94 2,841.82 5,975,113.56 564.654:09 7.51 6,230.94 MWD OWSG(4) 10.548.39 86.68 354.27 6,524.92 6430.92 6,25971 2.83817 5,975.14230 564.650.20 low 6,259.71 MWD OWSG(4) ? 10.580.29 8745 357.30 6,526.56 6.432.56 6,29148 2,835.83 5,975,17404 564,647.60 979 6,291.48 MWD OWSG(4) 10,608.53 87.17 0,76 6,527.88 6,433.88 6,31968 2,835.35 5,975,202 24 564,646.89 12.28 6.319.68 MWD OWSG(4) 10,640.05 87.48 2.25 6,529.35 6.435.35 635116 2836.18 5,975,23371 564,697.45 4.82 6,351.16 MWD OWSG(4) 10,668.69 88.37 0.69 6,530.39 6.436.39 6.379.77 2,836.91 5975262.33 564,647.95 6.27 6,379.77 MWD OWSG(4) 10,698.11 8853 129 6,531.19 6,437.19 6409.17 2,837.42 5,975,291.73 564,64822 2.11 6,409.17 MWD OWSG(4) + 10,73057 86.86 240 6,53249 6,438.49 6,441.59 2,83846 5,975,324.15 564,648.99 6.18 6,441.59 MWD OWSG(4) 10,759.85 85.86 2.20 6,534.35 6,440.35 6,470.78 2,839.69 5,975.353.35 564.64993 342 6,470.78 MWD OWSG(4) 10,793.69 85.17 160 6,53699 6,442.99 6.504.50 2,84076 5,975,38708 564,650.77 274 6,504.50 MWD OWSG(4) 10,825.13 85.95 359.86 6,639.42 6,445.42 6,53584 2,84116 5.975,41842 564,650.91 605 6,535.84 MWD OWSG(4) 10,858.77 8852 0.15 6,541.04 6,49709 6,569.44 2,841.16 5,975,452.01 564650.63 7.69 6.569.44 MWD OWSG(4) 10,888.41 87W 0.10 6.542.18 6.448.18 6.599.06 2,841.22 5.975,481 62 569,650.45 4.86 6,599.06 MWD OWSG (4) 10,928.53 85.69 020 6,594.71 6.450.71 6.639.10 2.84133 5.975,521 66 564.650.23 347 6,639.10 MWD OWSG(4) 10.958.00 85.60 0.15 6,546.95 6,452.95 6,668.48 2,841.42 5,975,551.04 569,650.08 0.35 6,668.46 MWD OWSG(4) 10,98841 85.57 0.50 6549.29 6455.29 6,698.60 2,891.59 5975,58136 564.650.00 115 6,698.80 MWD OWSG(4) 1101833 8511 35990 6,551]2 6457.72 6,728.62 2,84169 5,975,611.18 564.649.86 2.52 6,72862 MWD OWSG(4) 11,098.49 84.46 35946 6,554.46 6460.46 6,758.66 2,841.53 5,975,64120 564.64944 260 6,758.66 MWD OWSG(4) 11,078.19 84.53 358.70 6,557.31 6.463.31 6,788.22 2,641.05 5,975,67076 564.648.72 2.56 6,788.22 MWD OWSG(4) 11,107.95 85.05 359.11 6,56081 6,466.01 6,817.85 2,840.48 5,975,700.38 564697.91 2.22 6.81785 MWD OWSG(4) 11.137.96 66.ol 35884 6.562.35 6.46835 6.847.76 2.839.% 5.975,730.28 564,647.13 332 6,84776 MWD OWSG(4) 11.167.54 89.39 357.80 6.563.54 6,469.54 6.877.30 2.83908 5975.759.81 564,646.02 11.95 6,87730 MWD OWSG(4) 11,197.94 90.46 357,49 6.563.58 6,469.58 6,90767 2,83783 5.975.790.17 569,644.52 3.66 6,90767 MWD OWSG(4) 11,227.83 90.95 357.31 6,563.21 6,469.21 693753 2,836.48 5,975,82001 564.692.92 175 6,93753 MWD OWSG(4) 11258.18 9123 35742 5,562.63 6468.63 6.96784 2,835.08 5,975,85031 564641.27 0.99 6,967.84 MWD OWSG(4) Baker Hughes S Annotation 10/17/2019 1,55 23PM Page 4 COMPASS 5000. 14 Build 85H Survey ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 1C-06 Project: Kuparuk River Unit TVD Reference: 1C-06 @ 94.O1 (1C -O6) Ske: Kuparuk 1C Pad MD Reference: 1C-06 @ 94.00usft (1C -O6) Well: 1C-06 North Reference: True Wellbore: 1C-061-1-01 Survey Calculation Method: Minimum Curvature Design: 1C-061-1-01 Database: EDT 14 Alaska Production Survey 10/17/2019 1:55: 23PM Page 5 Baker Hughes Annotation COMPASS 5000 14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS -N/-S +E7 -W Northing Eating DLS Section Survey Tool Name (usft) (°) (°) (usft) (usR) (usR) (usft) (ft) ( (ft) (°/100') (R) 11288.37 91.04 357.69 6,562.04 6468.04 6,998.00 2833.80 5,975,880.45 56463974 109 6,998.00 MWD OWSG(4) 11,31859 9000 355.50 6,561.76 6.467.76 7.028.16 2,83200 5.975,91060 564,637.70 802 7,028.16 MWD OWSG(4) 11,348.83 89.36 359.00 6.561.93 6.467.93 7056.36 2.830.55 5.975,940 78 564,636.00 11.77 7,058.36 MWD OWSG(4) 1137881 90.89 359.76 6,56186 6,467.87 7,088.34 2,83023 5,975,970.75 564,635.42 570 7,088.34 MWD 0WSG(4) 11,41245 90.21 0.52 6,561.54 6,467.54 7,12198 2,830.31 5,976,00439 564.635.23 3.03 7,121.98 MWD OWSG(4) 1143845 92.52 0.41 6,560.92 6466.92 7, 147a7 2.830.52 5,976,030.37 564.635.23 8.89 7,147.97 MWD OWSG(4) 11,468.65 92.89 0.74 6,559.50 6,465.50 7,178.13 2,830.82 5,976,060.54 564.635.28 164 7,178.13 MWD OWSG(4) 11,505.77 89.91 357.85 6,558.57 6,464.57 7,216.23 2.830.35 5.976.098.63 564634.50 1089 7,216.23 MWD OWSG(4) 11,533.11 92.18 358.00 6,558.09 6.464.09 7,242.55 2.82940 5.976,12493 564,633.33 8.64 7,24255 MWD 0WSG(4) 11,563.04 89.42 35578 6,59.67 6,463.67 7,27242 2,827.77 5,976,15479 564.63146 11.83 7,272.42 MWD 0WSG(4) 11,592.23 91.38 35379 6.557.46 6,463.46 730149 2,825.12 5.976,183.83 564,62856 9.57 7,301.49 MWD OWSG(4) 11,62347 94.05 35546 6.555.98 6,461.98 7,332.55 2,822.20 5,976,214.87 564,62539 10.08 7,332.55 MWD OWSG(4) 11,WT31 96.00 356.98 6,552,14 6,458.14 7,376.13 2,619.32 5,976,258.41 564.622.15 563 7,376.13 MWD OWSG(4) 11,698.53 90.98 356.36 6,550.24 6,456.24 7,407.23 2,81751 5,976,289.49 564.620.08 16.20 7,407.23 MWD OWSG(4) 11,731.29 69.14 356.23 6,550.21 6,45621 7439.92 2,815.39 5,976.322.16 564.61769 5.63 7,439.92 MWD OWSG(4) 11,759.39 89.79 356.12 6,550.47 6,456.47 7.467.95 2.813$2 5,976,350.18 564.615.59 235 7467.95 MWD OWSG(4) 11,788.99 8776 305.43 6,551.11 6,457.11 7.49748 2,81160 5,976,37969 054.61342 6.94 7,49748 MWD OWSG (4) 11821.59 8.25 356.59 6,55281 6,458.81 7,529.97 2,80961 5,976,412.16 564,611.17 405 7.529.97 MWD OWSG(4) 11,849.45 8.99 356.89 6,559.45 648.45 7,557.74 2.808.03 5,976,439.91 564.609.36 2.87 7,557.74 MWD OWSG(4) 11,82.05 8.32 356.15 6,556.35 6462.35 7.590.23 2,806.06 5,976,472.37 564,607.12 3.05 7590.23 MWD 0WSG(4) 11,908.96 85.79 35765 6,558.20 6,454.20 7,61703 2,80460 5,976,499.16 564,60545 5.90 7617.03 MWD OWSG(4) 11,938.49 88.34 35.31 6,55972 6,465.72 7,646.18 2,8305 5,976.52859 564,603.65 9.75 7,646.48 MWD OWSG(4) 11,971.30 8.13 355.11 6,561.30 6,467.30 7,679.16 2,8060 5.97605125 054.600.93 7.8 7,679.16 MWD OWSG(4) 11,998.47 8751 35390 6,562.81 6,48.81 7,706.16 2,79800 5,976,58822 564.598.11 6.75 7,78.16 MWD OWSG(4) 12,02849 8.83 353.30 6.563.77 6.46977 7,735.98 2,79466 5,976,61801 564594.52 4.83 7,735.8 MWD OWSG(4) 12,059.74 91.56 35366 6,563.8 6,469.8 7,76702 2.791.11 5,976,649.02 564,590.72 8.81 7.767.02 MWD OWSG(4) 12,088.68 91.87 353.66 656279 6,468.79 ]]95.77 2,787.92 5.976,677.74 564.587 29 107 7,795.77 MWD OWSG(4) 12,116.76 92.92 38.8 656162 6.467.62 7,823.64 2.764.68 5.976 7a5,58 564,58.82 4.27 7,823.64 MWD OWSG(4) 12.147.24 92.8 353.54 6.560.09 6,46.09 7.88.87 2.781.13 5.976.73578 560,580.02 1.52 7,853.87 MWD OWSG(4) 12,17711 9347 352.% 6,558.44 6464.44 7,883.49 2,77762 5,976,765.36 564,576.28 2.84 788349 MWD OWSG (4) 12208.35 92.67 35317 6,55677 6.462.77 791446 2,77386 5,976,796 30 564,57225 265 7,91446 MWD OWSG(4) 10/17/2019 1:55: 23PM Page 5 Baker Hughes Annotation COMPASS 5000 14 Build 85H Survey ConocoPhillips ConocoPhillips Definitive Survey Report Baker Hughes g Company: ConocoPhillips Alaska Inc_Kupamk Local Coordinate Reference: Well 1C-06 Project Kuparuk River Unit TVD Reference: 1P06 @ 94.00usft (11C -O6) Site: Kupamk 1C Pad MD Reference: 1C-06 @ 94.00usft (I C-06) Well: 1C-06 North Reference: True Wellbore: 1C-061-1-01 Survey Calculation Method: Minimum Curvature Design: 1C-061-1-01 Database: EDT 14 Alaska Production Survey 10/17/2019 1:55'23PM Page 6 COMPASS 5000. 14 Build 85H Map Map Vertical MD Inc Az TVD TVDSS +N/-3 +E/-WOLS Easting Section Survey Tool Name AOnOfafi00 (usft) (°) (°) (usft) (usft) (usft) (usft) (R) (R) {ft) (=11000 (ft) 12,246.55 8791 35334 6,556.57 6,46257 7.952.38 2,76937 5976,834.18 564,56746 1247 7,952.38 MWD OWSG (4) 12,276.24 8394 35333 6.558.68 6.464.68 7,981.79 2.76594 5.976,863.56 564,563.78 13.37 7,981.79 MWD OWSG (4) 12,302.44 84.29 355.56 6.56137 6,467.37 8.00773 2,76341 5.976,889.47 564.561.09 857 8,007.73 MWD OWSG (4) 12,333.07 86.77 356.30 6,563.76 6,469.76 8,038.18 2,76125 5,976,91990 564,558.62 845 8.038.18 MWD OWSG J4) 12,360.81 89.14 35731 6,564.75 6,470.75 8,065.86 2,759.70 5,976,947.56 584556.85 929 8,065.86 MWD OWSG (4) 12,392.33 9837 359.71 6,564.88 6,470.88 8,09730 2,757.51 5,976.97898 564.554.40 9.12 8,097.30 MWD OWSG (4) 12,422.29 91.75 354.90 6,564.33 6,470.33 8,127.13 2.754.80 5,977,008.79 564.551.44 4.65 8,127.13 MWD OWSG (4) 12,452.36 92.12 354.64 6,56331 6,469.31 8,157.06 ?]52.06 5,977,03869 564,548.46 150 8,157.05 MWD OWSG (4) 12.48234 92.06 354.85 6,562.22 6,468.22 8,186.89 2,74931 5,977,058.50 564.545.47 0.73 8,186.89 MWD OWSG (4) 12,51393 9064 355.86 6.56147 6,467.47 8,218.37 2.74676 5,977,09995 564.542.65 5.52 8,218.37 MWD OWSG (4) 12,54264 89.72 355.01 6.561.38 6.467.38 8246.99 2744.47 5.977,128.54 564,540.13 4.36 8,296.99 MWD OWSG (4) 12,573.07 89.82 355.03 6,561,50 6,467.51 8.277.30 2,741.83 5.977,15883 564,537.24 0.34 8.277.30 MWD OWSG (4) 12,602.35 89.75 35544 6,561.61 6,457.61 8,306.48 2,73940 5,977,187.99 564,534.57 142 8,306.48 MWD OWSG (4) 12,624.82 89.32 355.14 6,55180 6,467.80 8,328.87 2.73755 5,977.21036 564,532.54 2.33 8,32887 VIM OWSG (4) 12,653.48 88.95 355.57 6,552.23 6,466.23 8,35744 2.735.23 5,977,238.90 564.529.98 1.98 835744 MWD OWSG (4) 12,683.08 90.12 35830 6,56247 6,468.47 8,386.99 2.73365 5,977.26844 564,528.15 10.03 8,386.99 MWD OWSG (4) 12,712.13 90.40 0.12 6,56234 6,468.34 8,416.04 2,733.25 5,977,297.48 564,527.51 6.34 8,416.09 MWD OWSG (4) 12,74278 8760 0.63 6,562.87 6,468.87 8,44668 2,73345 5,977,328.12 564,527.46 9.29 8,446.68 MWD OWSG 14) 12.76759 86.83 2.15 6,564.08 6.470.08 8.471.45 2.734.05 5.9T/,352.89 564,527.86 6.86 8,471.45 MWD OWSG 14) 12.79749 W74 359.38 6.565.23 6.471.23 8,50132 2,734.45 5,977,382 76 MA 52801 11.25 8,50132 MWD OWSG (4) 12,827.17 89.48 2.77 6,55570 6,471.70 8,530.99 2,735.01 5,977,412.43 564,528.32 1169 8,530.99 MWD OWSG (4) 12,857.71 87.45 35977 6,566.51 6,472.51 8,561.50 2,735.68 5,977,44295 564,52875 1185 8,561.50 MWD OWSG (4) 12.88761 8646 2.95 6,568.10 6.474.10 8,59135 2,736.39 5.977,47279 564.529.21 11.12 8,591,35 MWD OWSG (4) 12,917.51 86.16 0.13 6,570.03 6,476.03 8621.17 2,737.19 5,977,50262 564.529.77 9.47 8,621.17 MWD OWSG (4) 12,99725 86.44 358.00 6,571.95 6,477.95 8,650.85 2,73671 5,977,532.28 564,529.04 7.21 8,650.85 MWD OWSG (4) 12,97762 W74 359.01 6,573.75 6,47975 8,681.15 2,735.92 5,977,562% 564.528:00 346 8.681.15 MWD OWSG l4) 13,008.37 89.54 358.20 6,574.75 6,480.75 8,711.87 2.735.17 5.977,593.29 564.527.00 9.48 6711.87 MWD OWSG (4) 13,038.24 92.27 35991 6,574.28 6,480.28 8,74173 2.734.68 5.977.623 14 569,526.26 10.78 8,74173 MWD OWSG (4) 13,06983 9378 356.83 6,572.61 647861 8.773.26 2,73378 5.977,654 66 564,525.10 10.85 8,77326 MWD OWSG (4) 13,09717 94.92 357.88 6.570.54 6,476.54 8,800.49 2,73252 5977,68188 564.523.62 5.66 13,800 49 MWD OWSG (4) 13,12965 9483 35802 6.56778 547378 8.832.83 2,73136 5977.71420 56452219 0.51 8,83283 MWD OWSG (4) 10/17/2019 1:55'23PM Page 6 COMPASS 5000. 14 Build 85H ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska lnc_Kupamk Local Co-ordinate Reference: Well 1C-06 Project Kuparuk River Unit TVD Reference: 1C-06 @ 94.00usft (1C -O6) Site: Kuparuk 1C Pad MD Reference: 1C-06 @ 94.00usft (1C-06) Well: 1C-06 North Reference: True Wellbore: 1C-061.7-01 Survey Calculation Method: Minimum Curvature Design: 1C-061.1-01 Database: EDT 14 Alaska Production Survey Baker Hughes S Annotation 10/17/2019 1:55.'23PM Page 7 COMPASS 5000 14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS *N/S -El-W Northing Eastin 9 DLS Section (usft) (1) (°) (usft) (usft) (waft) (usft) (°1100') Survey Tool Name (ft) (ft) (ft) 13.16091 94.37 35658 6,565.27 6,471.27 8,663.96 2,72990 5,977,745.31 564,520.47 4.82 8,863.96 MWD OWSG(4) 13,194.57 92.89 356.48 6,563.14 6.469.14 889249 2,727.86 5.977,778.82 564.518.16 441 8,89749 MWD OWSG(4) 1321744 91.9 356.56 6.562.25 6.468.25 8,920.30 2,72648 5,977,80162 564,516.59 5.78 8,920.30 MWD OWSG(4) 13,263.25 89.32 355.24 6,56189 6,46789 6,965.98 2,723.20 5,977,847.27 564,512.93 5.69 8,96598 MWD OWSG(4) 13286.70 89.48 353.28 6,562.16 6,468.16 8,991.30 2.720.66 5,977,872.57 564,510.18 773 8,99130 MWD OWSG(4) 13,318.43 89.91 352.50 6,562.32 6,468.32 9,020.80 2,716.98 5,977,902.03 564.506.26 3.00 9,020.80 MWD OWSG(4) 13,353.55 8912 352.68 6,562.43 6,46843 9.055.63 2,71245 5,977,936.82 564.501.44 0.75 9,055.63 MWD OWSG(4) 13389.86 89.54 348.86 6.562.67 6,468.67 9.091.46 2,70662 5,977,97260 564,495.33 10.53 9,091.46 MM OWSG(4) 13.423.97 90.31 34797 6,562.71 6,468.71 9,124.88 2,69977 5,978,00595 564.488.20 3.45 9,124.88 MWD OWSG(4) 13,445.10 90.09 W73 6,56264 6,468.64 9,145.49 2,695.15 5,978,02653 564483.40 5.96 9,145.49 MWD OWSG(4) 13.473.95 91.35 34756 6,562.28 6,468.28 9.173.62 2,688.73 5,978,05459 564.476.76 5.23 9.173.62 MWD OWSG(4) 13,506.09 9043 348.26 6.55178 6.467.78 9.205.04 2,682.00 5.978,085 96 564,469]7 360 9,205.04 MWD OWSG(4) 13,534.75 90.25 347.33 6,561.61 6,467.61 9,233.05 267594 5,978,11391 564,463.48 3.31 9,233.05 MW7D OWSG(4) 13,564.05 90.15 346.20 6,%1.50 6,467.50 9,261.57 2,669.23 5,978,142.38 564456.53 3.87 9,261.57 MWD OW/SG(4) 13,594.45 90.06 343.38 6,%145 6, 167AS 9,290.91 2,661.26 5,978,171.64 564.448.32 9.28 9,290.91 MWD OWSG(4) 13,62429 90.86 341.25 6.%1.21 6,467.21 9,319.33 2,652.19 5,978,199.99 564.439.02 7.62 9,31933 MWD OWSG(4) 13.66044 90.92 340.91 6,%0.65 6,466.65 9,353.53 2.64047 5,978.2U 08 564427.02 0.95 9,353.53 MWD OWSG(4) 13.689,51 89.08 343.14 6,560.65 6,46685 9,381,17 2,631,50 5,978,26165 56441782 9.95 9,381.17 MWD OWSG(4) 13,726.29 87.64 343.04 6.56170 6.467]0 9,416.35 2.620.81 5.978.296 73 564406.84 392 9,41635 MWD OWSG(4) 13,748.71 88.68 342.94 6,562.42 6.466.42 9.437.78 2,614.25 5,978,318.10 564,400.11 4.66 9,437.78 MWD OWSG(4) 13,780.61 9064 342.57 6,562.61 6,468.61 9,468.24 2604.80 5,978,348.49 564.390.41 6.25 9,468.24 MWD OWSG(4) 13,622.00 9064 34257 6,%2.15 6,46815 9,507.73 2,592.40 5,978,387.66 564.377.68 0.00 9,50773 PROJECTED to TO Baker Hughes S Annotation 10/17/2019 1:55.'23PM Page 7 COMPASS 5000 14 Build 85H THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO 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 v .aogcc.aloska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1C -06L1-01 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-118 Surface Location: 1375' FNL, 858' FWL, SEC, 12, TIIN, R1OE, UM Bottomhole Location: 1993' FNL, 1779' FEL, SEC. 36, T12N, R10E, UM Dear Mr. Ohlinger: Enclosed is the approved application for the permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well Permit No. 181-025, API No. 50-029- 20564-00-00. Production should continue to be reported as a function of the original API number stated above. 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. 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, essie L. Chmielowski Commissioner DATED this ) 0 day of September, 2019. Winston, Hugh E (CED) From: Winston, Hugh E (CED) Sent: Friday, January 17, 2020 10:49 AM To: Winston, Hugh E (CED) Subject: RE: KRU 1C-06 Sundry Issues From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, January 15, 2020 9:50 AM To: Winston, Hugh E (CED) <hugh.winston@alaska.gov> Cc: Brooks, Phoebe L (CED) <phoebe. brooks @alaska.gov> Subject: KRU 1C-06 Sundry Issues Hugh, Could you please hand make these changes on the forms, put a copy of this list in each of the well files and correct in RBDMS? Let me know if you have any questions. Thanx, Victoria From: Germann, Shane <Shane.Germann@conocophillips.com> Sent: Wednesday, January 15, 2020 8:57 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Brooks, Phoebe L (CED) <phoebe.brooks@alaska.aov>; Winston, Hugh E (CED) <hugh.winston@alaska.aov> Subject: RE: [EXTERNAL)KRU 1C-06 Sundry Issues Victoria, Below are the forms that have WINJ checked instead of WAG along with the corresponding well names and PTD #'s. Let me know if you need anything else. I apologize for the inconvenience this has caused. Well Name PTD # Form KRU 1C-06 181-025 10-403 (Sundry # 319-380) KRU 1C-06 181-025 10-404 (Sundry # 319-380) KRU 1C-061-1 219-117 10-401 KRU 1C-061-1-01 219-118 10-401 KRU 1C-061-1-02 219-119 10-401 KRU 1C-061-1 219-117 10-407 KRU 1C-061-1-01 219-118 10-407 KRU 1C-061-1-02 219-119 10-407 Shane Germann Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, January 15, 2020 8:37 AM To: Germann, Shane <Shane.Germann@conocophillips.com> Cc: Brooks, Phoebe L (CED) <Phoebe.brooks @alaska.gov>; Winston, Hugh E (CED) <hugh.winstonCa@alaska.gov> Subject: [EXTERNAL]KRU 1C-06 Sundry Issues Shane, Please list the wells, PTD Its, Sundry Its and the forms where WI instead of WAG is checked. We will take a look at it. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 V ictoria. LoeDOrrD alaska. aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria Loeoo@alaska.aov From: Germann, Shane <Shane.Germann@conocophillips.com> Sent: Tuesday, January 14, 2020 3:12 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov>; Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Subject: KRU 1C-06 Sundry Issues Victoria, It has been brought to my attention that the KRU 1C-06 Sundry (319-380) and CTD sidetrack PTD's (219-217, 219-118, 219-119) have a mistake on them. The 1C-06 is a WAG injector and has been on WAG since 2007. The 1C-06 CTD laterals were always planned to be on WAG injection, but I inadvertently checked the "WINJ" box instead of "WAG" on the 10-401's, 10-403, 10-404, and 10-407's. The well status for the 1C-06 motherbore as well as the three CTD laterals (Ll, 1-1-01, and 1-1-02) should be WAG. Please advise if any formal documentation is required. I've attached the email chain that brought this up and the 10-404 for KRU 1C-06. Feel free to call or reply with any questions. Shane Germann Coiled Tubing Drilling Engineer STATE OF ALASKA ;KA OIL AND GAS CONSERVATION COMI, _SION PERMIT TO DRILL 9n nnr. oA nns irN4 SEP 0 ,' 1a. Type of Work: Drill ❑ Lateral ❑' Redrill ❑ Reentry ❑ 11b. Proposed Well Class: Exploratory - Gas [:]Service Stratigraphic Test ❑ Development - Oil ❑ I Exploratory - Oil ❑ Development - Gas ❑ - WAG Service - Disp E]1 Service- Winj Single Zone (] Service -Supply LJ Multiple Zone ❑ c. Specify if well. is proposed for: Coalbed Gas Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: Blanket E] Single Well ❑ Bond No. 5952180 11. Well Name and Number: KRU 1 C-061_1 -01 ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 14,300' TVD: 6499' 12. Field/Pool(s): Kuparuk River Pool Kupamk River Oil Pool , 4a. Location of Well (Governmental Section): Surface: 1375' FNL, 858' FWL, Sec. 12, T! 1N, R10E, UM Top of Productive Horizon: 975' FNL, 1210' FEL, Sec. 01, T11 N, R10E, UM Total Depth: 1993' FNL, 1779' FEL, Sec. 36, T12N, R10E, UM 7. Property Designation: ADL 25649 NOL -2563 8. DNR Approval Number: W. _9 1t9 LONS 79-016 13. Approximate Spud Date: 9/10/2019 9. Acres in Properly: 2560 14. Distance to Nearest Property: 2694' - 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 561864 y- 5968860 1 Zone- 4 10. KB Elevation above MSL (ft): 94 GL / BF Elevation above MSL (ft): 55 15. Distance to Nearest Well Open to Same Pool: - 1139'(1C-111.2-02) 16. Deviated wells: Kickoff depth: 9,900 feet Maximum Hole Angle: 101 degrees 17. Maximum Potential Pressures in prig (see 20 AAC 25.035) Downhole: 3888 Surface: 3235 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST -L 3050' 11,250' 6533' 14,300' 6499' Uncemented Slotted Liner 19, PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): 10,243' 7102' N/A Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 10,127' 7019' 10,026' Casing Length Size Cement Volume MD TVD Conductor 33' 16" 425 sx PF 65' 65' Surface 3255' 10-3/4" 340 sx AS 11 3287' 2685' Production 10,196' 7" 535 sx Class G 10,226' 7090' Perforation Depth MD (ft): 9410-9485 Perforation Depth TVD (ft): 6514-6566 Hydraulic Fracture planned? Yes F1 No 0 20. Attachments: Property Plat ❑ BOPSketch Diverter Sketch Drilling Program e Seabed Report Time v. Depth Plot ® Drilling Fluid Program Shallow Hazard Analysis® 8 20 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: Shane Germann Authorized Name: James Ohlinger Contact Email: Shane. efmann CO .Com Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4597 Authorized Signature: Date: f/-;// f Commission Use Only Permit to Drill Number: API Number: 50- 0 Z Set{ -^6 1 "L)0 Permit Approval Date:a(lotl 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: ✓7500 `d'1 Samples req'd: Yes ❑ NOL6✓Mud log req'd: Yes❑ NOR-*' /�vP fl.� / ' NO,/ Directional svy req'd: Yes Er G d HzS measures: Yes [x] ❑ 1�nnv/a rf Vl✓7. z S spacing exception req'd: Yes ElNo§ Inclination -only svy req'd: Yes ❑ ,NO eW a o,q qG 25 0 /5 L �jc Post initial injection MIT req'd: Yes No❑ V,4,r-ie4ni5 9rao-ttd -la a{low the krck�f��/�� /r N[ �l 4✓x'Nf a y/pol%1�'a��9 � -- APPROVED BY Approved by: �`� COMMISSIONER THE COMMISSION Date: 1 Q i Form 0 01 Revised 512017 V7-1- 01 petrn is valid for �4lfrrpllSh fpin r�teAf �roval per 20 AAC 25�g) Attachments in ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 29, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill three laterals out of the KRU 1 C-06 (PTD# 181-025) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in mid September 2019. The objective will be to drill three laterals, KRU 1C-061-1, 1C -06L1-01, and 1C-061-1-02, targeting the Kuparuk o -sand interval. 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 permit to drill applications are the following documents: - Permit to Drill Application Forms (10-401) for 1C-061-1, 1C-061-1-01, and 1C-061-1-02 - Detailed Summary of Operations - Directional Plans for 1C-061_1, 1C-061-1-01, and 1IC-061-1-02 - Current Wellbore Schematic - Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4597. Sincerely 95.�� jk�' Shane Germann Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 1C-061-1, 1C -06L1-01, & 1C-061-1-02 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b))............................................................... _.................... _. _.. _ _.......... _ _..... 2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)) ................. _......................_............................................................................................-_.. 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3))............................................................. _.................... ....... ....... ......................................... .__.2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)).................................................................................................................................................. 2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)) .......... ...................................................................................................................... ..- .............. 3 7. Diverter System Information ..........................................................................................................3 (Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(0))..................................................................................................................................................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...................................................................................................................................................................5 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. Quarter Mile Injection Review........................................................................................................6 (Requirements of 20 AAC 25.402)..........................................................................................................................................................6 17. Attachments....................................................................................................................................7 Attachment 1: Directional Plans for 1C-061-1, 1C-061-1-01, & 1C-061-1-02 laterals.........................................................7 Attachment 2: Current Well Schematic for 1 C-06............................................................................................................7 Attachment 3: Proposed Well Schematic for 1C-061-1, 1C -06L1-01, & 1C-061-1-02 laterals...........................................7 Page 1 of 7 January 30, 2019 PTD Application: 1C-u6L1, 1C-061-1-01, & 1C-061-1-02 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-061-1, 1C -06L1-01, & 1C-061-1-02. All laterals will be classified as "Development' 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 -06L1, 1C-061-1-01, & 1C-061-1-02. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. Using the maximum formation pressure in the area of 3888 psi in 1C-11 (i.e. 11.9 ppg EMW), the maximum potential surface pressure in 1C-06, assuming a gas gradient of 0.1 psi/ft, would be 3235 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 1C-06 was measured at the datum to be 3585 psi (11 0 ppg EMW) on 7/23/2017. The maximum downhole pressure in the 1C-06 vicinity is to the south in the 1C-11 producer. Pressure was measured to be 3888 psi, at the datum, (11.9 ppg EMW) in May of 2019. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injection wells to 1C-06 have injected gas, so there is a possibility of encountering free gas while drilling the 1C-06 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-06 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-06 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 January 30, 2019 PTD Application: 1C -06L1, 1C -06L1-01, & 1C-061_1-02 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 16" H-40 Welded Surface 2-3/8", 4.7#, L-80, ST -L slotted liner; 1C -06L1 9900' 13,000' 6452' 6404' aluminum billet on to t45.5 BTC Surface 3287' 2-3/8", 4.7#, L-80, ST -L slotted liner; 1 C-061_1-01 11,250' 14,300' 6439' 6405' aluminum billet on to K-55 BTC Surface 10,226' Surface 2-3/8", 4.7#, L-80, ST -L slotted liner; 1C-061_1-02 9320' 13,900' 6357' 6528' deployment sleeve on to Existing Casing/Liner Information Category OD Grade Connection Top MD Btm MD Top TVD TVD TVD Burst si Collapse psi Conductor 16" H-40 Welded Surface 65' Surface 65' 1640 670 Surface 10-3/4"K-55 t45.5 BTC Surface 3287' Surface 2685' 3580 2090 Production 7" K-55 BTC Surface 10,226' Surface 7090' 4980 4320 Tubin 3-1/2" L-80 EUE-8rd Surface 9381' Surface 6494' 10,160 10,540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Water -Based PowerVis milling fluid (8.6 ppg) — Drilling operations: Water-based PowerVis 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 NaCl / NaBr completion fluid in order to provide formation over -balance and well bore stability while running completions. ,/Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 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-06 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 7 August 29, 2019 PTD Application: 1C-061_1, 1C -06L1-01, & 1C-061_1-02 Pressure at the 1C -n6 Window (9430' MD. 6528' TVD) Using MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations KRU well 1C-06 is a Kuparuk C -Sand injector equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize three laterals to target the C -sands to the north and west of 1C-06. The laterals will increase C -sand resource recovery and throughput. Prior to CTD rig up, E -Line will set a mechanical whipstock (High Expansion Wedge) inside the 7" casing at the planned kick off point of 9430' MD. The 1 C -06L1 lateral will exit through the 7" casing at 9430' MD and drill to a planned TD at 13,000' MD, targeting the C sand to the west. The lateral will be completed with 2-3/8" slotted liner from TD up to 9900' MD with an aluminum billet for kicking off. The 1C-061-1-01 lateral will kick off at 9900' MD and drill to a planned TD of 14,300' MD targeting the C sand to the north. It will be completed with 2-3/8" slotted liner from TD up to 11,250' MD with an aluminum billet for kicking off. The 1C-061-1-02 lateral will kick off at 11,250' MD and drill to a planned TD of 13,900' MD targeting the C sand to the north-east. It will be completed with 2-3/8" slotted liner from TD up into the 3-1/2" tubing at 9330' MD with a deployment sleeve and seal bore assembly. Pre -CTD Work 1. RU Slickline: Dummy whipstock drift, C/O GLV's 2. RU E -Line: Caliper 3. RU CTU: Mill out D -Nipple to 2.80" ID, cleanout if fill is encountered. Page 4 of 7 August 29, 2019 Pumps On 1.9 bpm) Pumps Off C -sand Formation Pressure 11.0 3734 psi 3734 psi Mud Hydrostatic 8.6 2919 psi 2919 psi Annular friction i.e. ECD, 0.080psi/ft) 754 psi 0 psi Mud + ECD Combined no chokepressure) 3673 psi underbalanced —61psi) 2919 psi underbalanced —815psi) Target BHP at Window 11.4 3870 psi 3870 psi Choke Pressure Required to Maintain Target BHP 197 psi 951 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 KRU well 1C-06 is a Kuparuk C -Sand injector equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize three laterals to target the C -sands to the north and west of 1C-06. The laterals will increase C -sand resource recovery and throughput. Prior to CTD rig up, E -Line will set a mechanical whipstock (High Expansion Wedge) inside the 7" casing at the planned kick off point of 9430' MD. The 1 C -06L1 lateral will exit through the 7" casing at 9430' MD and drill to a planned TD at 13,000' MD, targeting the C sand to the west. The lateral will be completed with 2-3/8" slotted liner from TD up to 9900' MD with an aluminum billet for kicking off. The 1C-061-1-01 lateral will kick off at 9900' MD and drill to a planned TD of 14,300' MD targeting the C sand to the north. It will be completed with 2-3/8" slotted liner from TD up to 11,250' MD with an aluminum billet for kicking off. The 1C-061-1-02 lateral will kick off at 11,250' MD and drill to a planned TD of 13,900' MD targeting the C sand to the north-east. It will be completed with 2-3/8" slotted liner from TD up into the 3-1/2" tubing at 9330' MD with a deployment sleeve and seal bore assembly. Pre -CTD Work 1. RU Slickline: Dummy whipstock drift, C/O GLV's 2. RU E -Line: Caliper 3. RU CTU: Mill out D -Nipple to 2.80" ID, cleanout if fill is encountered. Page 4 of 7 August 29, 2019 PTD Application: 1C-061_1, 1C-061-1-01, & 1C-061-1-02 4. RU E -Line: Set top of high expansion wedge at 9430' MD 5. Prep site for Nabors CDR3-AC. Ria Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1 C-061_1 Lateral (C sand -West) a. Mill 2.80" window at 9430' MD. b. Drill 3" bi-center lateral to TD of 13,000' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 9900' MD. 3. 1C-061-1-01 Lateral (C sand - North) a. Kickoff the aluminum billet at 9900' MD. b. Drill 3" bi-center lateral to TD of 14,300' MD. c. Run 2V slotted liner with an aluminum billet from TD up to 11,250' MD. 4. 1C-061-1-02 Lateral (C sand -North-East) a. Kick off of the aluminum billet at 11,250' MD. b. Drill 3" bi-center lateral to TD of 13,900' MD. c. Run 2%" slotted liner with deployment sleeve and seal bore from TD up to 9330' MD. 5. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CRD3-AC. Post -Ria Work I. 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 slick -line. - When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. - The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running - The 1C-06 laterals will be displaced to an overbalancing fluid (11.4 ppg NaCl / NaBr) prior to running liner. See "Drilling Fluids" section for more details. Page 5 of 7 August 29, 2019 PTD Application: 1C-061_1, 1C-061_1-01, & 1C-061-1-02 - 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 (1R-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. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1 C-061_1 6830' IC -0611-11-011 2694' 1C -06L1-02 2806' - Distance to Nearest Well within Pool Lateral Name Distance Well 1C -06L1 1079' 1C-19 1C-061-1-01 1139' 1C-111-2-02 1C-061_1-02 1204' 1C-191-1 16.Quarter Mile Injection Review V/ (Requirements of 20 AAC 25.402) The only wells that lie within'% -mile of the proposed 1C-06 laterals are the 1C-06 mother bore, 1C -07A, 1C-19, 1C -19L1, and 1C-111-2-02. The casing and cementing of 1C-06 is described below. Seethe attached schematic for further details. 1C-06 Mother bore Well 1C-06 was drilled and completed in 1981. The 7", 26 ppf, K-55 BTC production casing was set at 10,225' MD in the Miluveach. IC -06 is a service well with a "Normal Well" Ann -Comm status. It is capable of injecting to the Kuparuk C sands but is not open to the A sands. The mother bore will continue to be open to the current C - sand perforations. 1C -07A Well 1C -07A (PTD #209-029) was drilled and completed in 2009. It is a sidetrack from the 1C-07 mother bore (PTD #181-031) which was drilled and completed in 1981. The 1C-07 mother bore had the C sand perforations cement squeezed prior to the CTD project in 2009. The 1 C -07A is a C sand lateral completed with 2-3/8" 4.7 ppf L-80 slotted liner. The 1C-07 is a production well with a "Problem Well" Ann -Comm status open to produce from only the C sand. There was suspected IAxOA communication in 2014. The 7", 26 ppf K-55 BTC production casing was set at 9766' MD in the Miluveach. The 1C-061-1 to IC -07A center to center distance is roughly 1223'. Page 6 of 7 August 29, 2019 PTD Application: 1C-061_1, 1C -06L1-01, & 1C-061_1-02 ✓1C-19 & 1C -19L1 Well 1C-19 (PTD #203-054) was drilled and completed in 2003. The 7", 26 ppf BTC production casing was set at 10,429' MD in the B sand. The 1C-19 is a production well with a "Normal Well" Ann -Comm status open to produce from only the C sand. The 1C-19 is the mother bore for CTD sidetrack lateral 1C -19L1 (PTD #219-086) drilled in 2019 and completed with 2-3/8" 4.7 ppf L-80 slotted liner. 1C -19L1 is located in the C sand to the north of 1C-19. The 1C -06L1 to 1C-19 center to center distance is roughly 1079'. The 1C -06L1-02 to 1C-191_1 center to center distance is roughly 1204'. V 1C-111-2-02 Well 1C -11L2-02 (PTD #219-043) was drilled and completed in 2019. It is a sidetrack from the 1C-11 mother bore (PTD #196-172). The 1C-11 mother bore had the C sand perforations cement squeezed prior to the CTD project in 2019. The 1C-111_2-02 is a C sand lateral completed with 2-3/8" 4.7 ppf L-80 slotted liner. The 1C-11 is a production well with a "Normal Well" Ann -Comm status open to produce from only the C sand. The 7", 26 ppf L-80 BTC production casing was set at 10,427' MD in the Kalubik. The 5", 18 ppf L-80 LTC liner was set at 11.300' MD in the Miluveach. The 1C-061-1-01 to 1C -11L2-02 center to center distance is roughly 1139'. 17.Attachments Attachment 1: Directional Plans for 1C -06L1, 1C -06L1-01, & 1C -06L1-02 laterals Attachment 2: Current Well Schematic for 1C-06 Attachment 3: Proposed Well Schematic for 1C -06L1, 1C -06L1-01, & 1C -06L1-02 laterals Page 7 of 7 August 29, 2019 Well KRU XX•XX Nabors CDR3-AC: 4 -Ram BOP Configuration 2" Date April 2a, 2019 Coiled Tubing and 2-3/8" BHA Quick Test Sub to Of Top of 7" Otis Distances from top o Excluding quick -test Top of Annular CL Annular Bottom Annular Flan CL Blind/Shears CL T Combrs CL 2.318" Combrs CL 2" Combrs CL of Top Top of Swa CL Swab i Flow Tee CL SSV CL Master LDS Ground Tree Size ne ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1C Pad IC -06 1C-061-1-01 Plan: 1 C -06L1-01 _wp02 Standard Planning Report 15 August, 2019 BA UGHES a GE company ConocoPhillipsBA ER ConocoPhillips Planning Report F�UGHES aGEmmpany Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc Kuparuk Project Kuparuk River Unit Site: Kuparuk 1C Pad Well: 1 C-06 Wellbore: 1C-061.1-01 Design: 1C-061.1-01_Wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1C-06 Mean Sea Level 1"6 @J 94.00Usft (1G06) True Minimum Curvature >roject Kuparuk River Unit, North Slope Alaska, United States aap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Nap Zone: Alaska Zone 04 Using geodetic scale factor fsite Kupamk lC Pad 1C-06 Te On Depth: Well Position «NIS 0.00 usft Site Position: Northing: 5,968,522.46 Usti, 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-06 Te On Depth: Well Position «NIS 0.00 usft Northing: -El-W +EI -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 1C-061-1-01 0.00 Magnetics Model Name Sample Date Build BGGM2018 10/1/2019 Depth Design lC-06L1-01_wp02 Audit Notes: Version: Vertical Section: 5,968,860.00 usft Latitude: 70" 19' 31.647 N 561,864.00 usft Longitude: 149° 29'54.042 W Usti Ground Level: 0.00 usft Declination Dip Angle Field Strength (°) l°I (nT) 16.44 80.86 57.404 Phase'. PLAN Te On Depth: 9,900.00 Depth From (TVD) +N/ -S -El-W Direction (usft) (usft) (usft) (°) -60.50 0.00 0.00 0.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System -NIS +E/ -W Rate Rate Rate TFO (usft) V) 1°) (usft) (usft) (usft) (°1100uaft) (°1100usft) (°1100usft) (°) Target 9,900.00 95.16 317.01 6,451.71 5,681.01 3,207.68 0.00 0.00 0.00 0.00 10,000.00 101.20 320.57 6,437.48 5,755.42 3,142.50 7.00 6.05 3.56 30.00 10,300.00 93.18 340.15 6,399.60 6,012.84 2,996.56 7.00 -2.68 6.53 111.00 10,600.00 89.40 0.82 6,392.77 6,306.99 2,947.30 7.00 -1.26 6.89 100.00 10,800.00 81.64 12.51 6,408.43 6,504.54 2,970.29 7.00 -3.88 5.85 124.00 11,200.00 89.53 345.55 6,439.75 6,899.27 2,963.10 7.00 1.97 -6.74 -75.00 11,500.00 95.58 5.69 6,426.24 7,196.40 2,940.21 7.00 2.01 6.71 73.00 11,800.00 89.91 345.44 6,411.74 7,493.47 2,917.03 7.00 -1.89 -6.75 -105.00 12,100.00 85.99 6.09 6,422.58 7,790.78 2,894.92 7.00 -1.31 6.86 101.00 12,400.00 89.82 345.42 6,433.66 8,088.07 2,872.77 7.00 1.28 -6.89 -80.00 12,600.00 87.42 331.62 6,438.50 8,273.67 2,799,75 7.00 -1.20 -6.90 -100.00 13,000.00 90.06 359.51 6,447.47 8,657.11 2,701.09 7.00 0.66 6.97 85.00 13,200.00 98.04 347.96 6,433.31 8,854.93 2,679.47 7.00 3.99 -5.77 -55.00 13,550.00 84.82 8.64 6,424.53 9,202.01 2,669.35 7.00 -3.78 5.91 122.00 13,900.00 90.61 344.81 6,438.69 9,548.49 2,649.36 7.00 1.66 -6.81 -77.00 14,300.00 98.89 11.67 6,404.98 9,942.88 2,636.67 7.00 2.07 6.72 72.00 871512019 9:40.34AM Page 2 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Planning ReportUGHES aGRcompany Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit Site: Kuparuk 1 Pad Well: 1 C-06 Wellbore: IC-06LI-01 Design: 1C-06L1-01_wp02 Planned Survey Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1C-06 Mean Sea Level 1 C-06 0 94.00usft (1 C-06) True Minimum Curvature Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (^) (°) (usft) (usft) (usft) (usft) (°I100usft) (°) (usft) (usft) 9,900.00 95.16 317.01 6,451.71 5,681.01 3,207.68 5,681.01 0.00 0.00 5,974,566.72 56502443 TIP/KOP 10,000.00 101.20 320.57 6,437.48 5,755.42 3,142.50 5,755.42 7.00 30.00 5,974,640.58 564,958.65 Start DLS 7.00 TFO 30.00 10,100.00 98.63 327.18 6,420.24 5,834.95 3,084.49 5,834.95 7.00 111.00 5,974,719.62 564,899.98 10,200.00 95.94 333.70 6,407.55 5,921.18 3,035.60 5,921.18 7.00 112.14 5,974,805.44 564,850.39 10,300.00 93.18 340.15 6,399.60 6,012.84 2,996.56 6,012.84 7.00 112.97 5,974,896.76 564,810.61 Start DLS 7.00 TFO 100.00 10,400.00 91.94 347.05 6,395.13 6,108.61 2,968.38 6,108.61 7.00 100.00 5,974,992.29 564,781.64 10,500.00 90.68 353.94 6,392.84 6,207.15 2,951.88 6,207.15 7.00 100.31 5,975,090.68 564,764.32 10,600.00 89.40 0.82 6,392.77 6,306.99 2,947.30 6,306.99 7.00 100.47 5,975,190.47 564,758.93 Start DLS 7.00 TFO 124.00 10,700.00 85.50 664 6,397.22 6,406.62 2,953.79 6,406.62 7.00 124.00 5,975,290.13 564,764.59 10,800.00 8164 12.51 6,408.43 6,504.54 2,970.29 6,504.54 7.00 123.74 5,975,388.19 564,780.28 Start DLS 7.00 TFO -75.00 10,900.00 83.51 5.71 6,421.36 6,602.39 2,985.97 6,602.39 7.00 -75.00 5,975,486.15 564,795.15 11,000.00 85.46 358.96 6,430.99 6,701.78 2,990.01 6,701.78 7.00 -74.12 5,975,585.56 564,798.37 11,100.00 87.48 352.24 6,437.15 6,801.24 2,982.35 6,801.24 7.00 -73.47 5,975,684.94 564,789.90 11,200.00 89.53 345.55 6,439.75 6,899.27 2,963.10 6,899.27 7.00 -73.06 5,975,782.80 564,769.85 Start DLS 7.00 TFO 73.00 11,300.00 91.58 352.24 6,438.78 6,997.33 2,943.86 6,997.33 7.00 73.00 5,975,880.69 564,749.79 11,400.00 93.60 358.95 6,434.25 7,096.87 2,936.19 7,096.87 7.00 73.07 5,975,980.15 564,741.30 11,500.00 95.58 5.69 6,426.24 7,196.40 2,940.21 7,196.40 7.00 73.37 5,976,079.71 564,744.50 Start DLS 7.00 TFO -106.00 11,600.00 93.73 358.91 6,418.12 7,295.93 2,944.20 7,295.93 7.00 -105.00 5,976,179.26 564,747.67 11,700.00 91.83 352.17 6,413.26 7,395.45 2,936.43 7,395.45 7.00 -105.55 5,976,278.70 564,739.09 11,800.00 89.91 345.44 6,411.74 7,493.47 2,917.03 7,493.47 7.00 -105.88 5,976,376.55 564,718.87 Start DLS 7.00 TFO 101.00 11,900.00 88.56 352.31 6,413.07 7,591.52 2,897.74 7,591.52 7.00 101.00 5,976,474.43 564,698.78 12,000.00 87.27 359.19 6,416.70 7,691.12 2,890.34 7,691.12 7.00 100.91 5,976,573.95 564,690.56 12,100.00 85.99 6.09 6,422.58 7,790.78 2,894.92 7,790.78 7.00 100.66 5,976,673.63 564,694.32 Start DLS 7.00 TFO -80.00 12,200.00 87.24 359.18 6,428.49 7,890.44 2,899.50 7,890.44 7.00 -80.00 5,976,773.32 564,698.08 12,300.00 88.52 352.30 6,432.20 7,990.03 2,892.08 7,990.03 7.00 -79.59 5,976,872.83 564,689.84 12,400.00 89.82 345.42 6,433.66 8,088.07 2,872.77 8,088.07 7.00 -79.34 5,976,970.71 564,669.73 Start DLS 7.00 TFO -100.00 12,500.00 88.61 338.52 6,435.03 8,183.09 2,841.85 8,183.09 7.00 -100.00 5,977,065.46 564,638.02 12,600.00 87.42 331.62 6,438.50 8,273.67 2,799.75 8,273.67 7.00 -99.91 5,977,155.68 564,595.18 Start DLS 7.00 TFO 86.00 12,700.00 88.05 338.60 6,442.47 8,364.25 2,757.73 8,364.25 7.00 85.00 5,977,245.90 564,552.42 12,800.00 88.70 345.57 6,445.31 8,459.31 2,727.00 8,459.31 7.00 84.72 5,977,340.69 564,520.91 12,900.00 89.38 352.54 6,446.99 8,557.41 2,708.03 8,557.41 7.00 84.53 5,977,438.63 564,501.13 13,000.00 90.06 359.51 6,447.47 8,657.11 2,701.09 8,657.11 7.00 84.41 5,977,538.25 564,493.38 Start DLS 7.00 TFO -56.00 13,100.00 94.07 353.76 6,443.87 8,756.81 2,695.24 8,756.81 7.00 -55.00 5,977,637.89 564,486.70 13,200.00 98.04 347.96 6,433.31 8,854.93 2,679.47 8,854.93 7.00 55.21 5,977,735.87 564,470.13 Start DLS 7.00 TFO 122.00 13,300.00 94.29 353.91 6,422.57 8,953.05 2,663.83 6,953.05 7.00 122.00 5,977,833.85 564,453.68 13,400.00 90.50 359.80 6,418.38 9,052.75 2,658.36 9,052.75 7.00 122.64 5,977,933.49 564,447.39 13,500.00 86.70 5.68 6,420.83 9,152.55 2,663.14 9,152.55 7.00 122.89 5,978,033.31 564,451.34 13,550.00 84.82 8.64 6,424.53 9,202.01 2,669.35 9,202.01 7.00 122.74 5,978,082.82 564,457.15 Start DLS 7.00 TFO -77.00 8/152019 9:40.34AM Page 3 COMPASS 5000.14 Build 85H `- ConocoPhillips ConocoPhillips Planning Report UGHES a6Emmpany Database: EDT 14 Alaska Production Dogleg Toolface Company: ConocoPhillips Alaska Inc_Kupamk «El -W Section Project: Kupamk River Unit Northing Easting Site: Kupamk 1C Pad (°/100usft) (1 Well: 1C-06 2,675,36 9,251.47 Wellbore: 1C-061-1-01 5,978,132.32 564,462.75 Design: 1C-061-1-01_WP02 7.00 -76.71 Planned Survey 564,465.07 2,669.79 9,450.66 Measured TVD Below 5,978,331.44 Depth Inclination Azimuth System -NIS (usft) (1 (') (usft) (usft) 13,600.00 85.61 522 6428.70 9,251.47 13,700.00 87.25 358.40 6434.93 9,351.16 13,800.00 88.92 351.60 6,438.28 9,450.66 13,900.00 90.61 344.81 6,438.69 9,548.49 Start DLS 7.00 TFO 72.00 2,636.67 9,942.68 14,000.00 92.77 351.47 6,435.74 9,646.25 14,100.00 94.88 358.16 6,429.06 9,745.55 14,200.00 96.93 4.89 6,418.76 9,844.92 13,000.00 6,447.47 8,657.11 2,701.09 14,300.00 98.89 11.67 6,404.98 Vj 9,942.88 Planned TD at 14300.00 Start DLS 7.00 TFO 122.00 13,550.00 Casing Points Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1C-06 Mean Sea Level 1 C-06 @ 94.00usft 0 C-06) True Minimum Curvature Measured Vertical Dogleg Toolface Map Map «El -W Section Rate Azimuth Northing Easting (usft) (usft) (°/100usft) (1 lush) lush) 2,675,36 9,251.47 7.00 -77.00 5,978,132.32 564,462.75 2,678.50 9,351.16 7.00 -76.71 5,978,232.03 564,465.07 2,669.79 9,450.66 7.00 -76.29 5,978,331.44 564,455.54 2,649.36 9,548.49 7.00 -76.06 5,978,429.09 564,434.30 2,628.82 9,646.25 7.00 72.00 5,978,526.67 564,412.96 2,619.80 9,745.55 7.00 72.20 5,978,625.89 564,403.12 2,622.43 9,844.92 7.00 72.64 5,978,725.26 564,404.93 2,636.67 9,942.68 7.00 73.34 5,978,823.32 564,418.36 Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 14,300.00 6,404.98 2-318' 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +Nl-S -El-W (usft) (usft) (usft) (usft) Comment 9,900.00 6,451.71 5,681.01 3,20768 TIPIKOP 10,000.00 6,437.48 5,755.42 3,142.50 Start DLS 7.00 TFO 30.00 10,300.00 6,399.60 6,012.84 2,996.56 Start DLS 7.00 TFO 100.00 10,600.00 6,392.77 6,306.99 2,947.30 Start DLS 7.00 TFO 124.00 10,800.00 6,408.43 6,504.54 2,970.29 Start DLS 7.00 TFO -75.00 11,200.00 6,439.75 6,899.27 2,963.10 Start DLS 7.00 TFO 73.00 11,500.00 6,426.24 7,196.40 2,940.21 Start DLS 7.00 TFO-105.00 11,800.00 6,411.74 7,493.47 2,917.03 Start DLS 7.00 TFO 101.00 12,100.00 6,422.58 7,790.78 2,894.92 Start DLS 7.00 TFO -80.00 12,400.00 6,433.66 8,088.07 2,872.77 Start DLS 7.00 TFO -100.00 12,600.00 6,438.50 8,273.67 2,799.75 Start DLS 7.00 TFO 85.00 13,000.00 6,447.47 8,657.11 2,701.09 Start DLS 7.00 TFO -55.00 13,200.00 6,433.31 8,854.93 2,679.47 Start DLS 7.00 TFO 122.00 13,550.00 6,424.53 9,202.01 2,669.35 Start DLS 7.00 TFO-77.00 13,900.00 6,438.69 9,548.49 2,649.36 Start DLS 7.00 TFO 72.00 14,300.00 6,404.98 9,942.88 2,636.67 Planned TD at 14300.00 811512019 9: 40: 34AM Page 4 COMPASS 5000.14 Build 85H ConocoPhillips Company: ConocoPhillips Alaska lnc_Kuparuk Project: Kuparuk River Unit _1 Reference Site: Kupanik 1C Pad Site Error: 0.00 usft Reference Well: 1C-06 Well Error: 0.00 usft Reference Wellbore 1C -06L1 -0l Reference Design: 1C-061-1-01_wp02 ConocoPhillips Anticollision Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well IC -06 1 C-06 @ 94.00usft (1 C46) 1 C-06 @ 94.00usft 11 C-06) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Reference IC-0611-01_wp02 Fitter type: GLOBAL FILTER APPLI ED: All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 9,900.00 to 14,300.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum ellipse separation of 3,000.00 usft Error Surface: Combined Pedal Curve Warning Levels Evaluated at: 2.79 Sigma Casing Method: Added to Error Values Survey Tool Program Date 8/14/2019 Out of range From To lust) (usft) Survey (Wellbore) Tool Name Description 100.00 9,400.00 1C-06 (1C-06) GVD-CT-CMS Gyrodata contcasing m/s 9,400.00 9,900.00 1C-061-1_wp02(1C-061-1) MWD OWSG OWSG MWD - Standard 9,900.00 14,300.00 1C-06L1-01_wp02(IC-061-1-01) MWD OWSG OWSG MWD - Standard Summary Site Name Offset Well - Wellbore - Design Kupamk 1C Pad 1 C-04 - 1 C -04A - 1 C -04A 1 C-04 - 1 C -04A - 1 C -04A 1 C-04 - 1 C -04A - 1 C -04A 1 C-04 - 1 C-04ALl - 1 C-04AL1 1 C-04 - 1004AL1 - 1 C-04ALI 1 C-04 - t C-04ALl - 1 C-04ALl 1C-06-1C-0611-1C-061.1_wp02 1C -06 -1C -06L1 -02-1C-061-1-02 wp02 1C-06-1C-061-1-02-1C-061-1-02_wp02 1C-07 - 1 C-07 - 1 C-07 1 C-07 - 1 C-07 -1 C-07 1 C-07 - 1 C -07A- 1 C -07A 1 C-07 - 1 C -07A- 1 C -07A 1 C-07 - 1 C-07ALl - 1 C-07ALI 1 C-07 - 1 C-07ALI - 1 C-07AL1 1 C-07 - 1 C-07ALl PBI-1C-07ALl PBI 1 C-07 - 1 C-07ALl PB1 - 1 C-07ALl PBI 1C-07-1C-07APB1-1C-07APB1 1C-07-IC-07APB1-1C-07APB1 1 C-08 - 1 C-08 - 1 C-08 1 C-08 - 1 C-08 - 1 C-08 1 C-08 - 1 C-0811 - 1 C-081-1 1 C-08 - 1 C-08LI - 1 C-081-1 1 C-08 - 1 C-08LI-01 - 1 C-08LI-01 1 C-08 - 1 C-081-1-01 - 1 C -08L1-01 1 C-08 - 1C -08L1 PBI - 1 GO81-1 PB1 1C -08 -1C -08L1 PBI -1C-081-1 P81 1 C-104 - 1 C-104 - 1C-104 1 C-104 - 1 C-104 - 1G104 1 C-104 - 1 C-1041-1 - 1 C-10411 1 C-104 - 1 C-1041-1 - 1 C-10411 1 C-104 - 1 C-104PB1 - 1 C-104PB1 1C-104 - 1C-104PB1 - 1C-104PB1 Reference Offset Measured Measured Depth Depth (usftl (usft) 10,208.58 10,250.00 11,570.37 11,575.00 11,769.86 11,800.00 Distance Between Between Separation Warning Centres Ellipses Factor (usftl (usft) CC - Min centre to center distance or covergent point, SF- min separation factor, ES - min ellipse separation 8/14/2019 10:33:29AM Page 2 COMPASS 5000.14 Build 85H Out of range Out of range Out of range Out of range Out of range Out of range 120.57 114.30 19.238 CC, ES, SF 45.33 43.45 24.106 CC, ES 116.59 103.94 9.214 SF 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 Out of range Out of range Out of range 134.97 690.45 2.553 Normal Opei CC - Min centre to center distance or covergent point, SF- min separation factor, ES - min ellipse separation 8/14/2019 10:33:29AM Page 2 COMPASS 5000.14 Build 85H Summary ConocoPhillips Antioollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method; Output errors are at Database: Offset TVD Reference: Reference ConocoPhillips Between Company: ConocoPhillips Alaska Inc Kuparuk Project: Kuparuk River Unit i Reference Site: Kuparuk IC Pad Site Error: 0.00 usft Reference Well: 10-06 Well Error: 0.00 usft Reference Wellbore 10-061.1-01 Reference Design: 1C-06L1-01_wp02 Summary ConocoPhillips Antioollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method; Output errors are at Database: Offset TVD Reference: IC -11 - 1C-111.2-02 - IC -111.2-02 IC -11 - 1C-111.2-02 - IC -111.2-02 10-71 - 1C-1112-02 - 10-11 L2-02_wP03(Draft B) 10-71 - 1C-111.2-02 - 1C-111.2-02_wp03(Draft B) 10-711 - 1C-111 - 1C-111 10-711 - 1C-111 - 1C-111 10-711-10-111-1C-111 10 -119 -1C -119-1C-119 1C-119 - 1C -1i9 - 1 C-119 1C-121 - 1C-121 - 1C-121 1C-121 - 1C-121 - 1C-121 1C -121 -1C -121-1C-121 1C -13 -1C -13-1C-13 1C-13 - 1C-13 - 1C-13 1C -13 -1C -13-1C-13 1C-150 - IC -150 - 1C-150 IC -150 - IC -150 - 1C-150 1C-151 - IC -151 - 1C451 IC -152 - IC -152 - 1C-152 IC -152 - IC -152 - 1C-152 IC -153 - 1C-153 - 1C-153 IC -153 - 1C-153 -1 C-153 1C-154 - 1C-154 - 1C-154 IC -154 - 1C-154 - 1C-154 IC -154 - 1C-154 - 1C-154 1C-155 - 1C-155 - 1C-155 IC -155 - 1C-155 - 1C-155 IC -170 - 1C-170- 1 C-170 1C-170 - 1C-170 - 1C-170 1C-170-1C-170PB1-iG170PB1 1C-170-1C-170PB1-iG170PB1 1C-172 - 1C-172- 1C-172 IC -172 - 1C-172- 1C-172 IC -172 - 1C -172A- 1 C -172A 1C-172 - 1 G172AL1 - 1 C-172ALI 1C-172 - 1 C-172AL2 - 1 C-172AL2 IC-172-1C-172AL2PB1-1C-172AL2P81 IC -172 - 1 C-172AL2PB2 - 1 C-172AL2PB2 IC -174 - 1C-174- IC -174 IC -174 - 1C-174- IC -174 iC-18-IC-18-10-18 lC-18-10-18-10-18 1C-19- 1C-191-1 - 1C-191-1 1C-19 - 1C-1911 - 1C -19L1 1C-19 - 1C-1911 - IC -19L1 1C-19 - 1C-1911 - 10-19L1 Plan: 1 C-156 - Plan: 10-156 - 1 C-156wp07 Plan: 1 C-158 - Plan:1 C-158 - iC-158wp02 Plan: 1 C-158 - Plan:1 C-158 - iC-158wp02 Prelim: 1 C-157 - Plan: 1 C-157 - 1 C-157wp06 Prelim: 1 C-157 - Plan: 1 C-157 - 1 C-157wp06 13,400.00 14,350.00 13,421.98 14,375.00 14,200.00 14,975.00 14,250.00 15,075.00 Well 1C-06 1 C-06 Q 94.00usft (10-06) 1 C-06 @ 94.00usft (1G06) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Distance Reference Offset Between Measured Measured Site Name Depth Depth Offset Well - Wellbore - Design (usft) (usft) Kuparuk 1C Pad IC -11 - 1C-111.2-02 - IC -111.2-02 IC -11 - 1C-111.2-02 - IC -111.2-02 10-71 - 1C-1112-02 - 10-11 L2-02_wP03(Draft B) 10-71 - 1C-111.2-02 - 1C-111.2-02_wp03(Draft B) 10-711 - 1C-111 - 1C-111 10-711 - 1C-111 - 1C-111 10-711-10-111-1C-111 10 -119 -1C -119-1C-119 1C-119 - 1C -1i9 - 1 C-119 1C-121 - 1C-121 - 1C-121 1C-121 - 1C-121 - 1C-121 1C -121 -1C -121-1C-121 1C -13 -1C -13-1C-13 1C-13 - 1C-13 - 1C-13 1C -13 -1C -13-1C-13 1C-150 - IC -150 - 1C-150 IC -150 - IC -150 - 1C-150 1C-151 - IC -151 - 1C451 IC -152 - IC -152 - 1C-152 IC -152 - IC -152 - 1C-152 IC -153 - 1C-153 - 1C-153 IC -153 - 1C-153 -1 C-153 1C-154 - 1C-154 - 1C-154 IC -154 - 1C-154 - 1C-154 IC -154 - 1C-154 - 1C-154 1C-155 - 1C-155 - 1C-155 IC -155 - 1C-155 - 1C-155 IC -170 - 1C-170- 1 C-170 1C-170 - 1C-170 - 1C-170 1C-170-1C-170PB1-iG170PB1 1C-170-1C-170PB1-iG170PB1 1C-172 - 1C-172- 1C-172 IC -172 - 1C-172- 1C-172 IC -172 - 1C -172A- 1 C -172A 1C-172 - 1 G172AL1 - 1 C-172ALI 1C-172 - 1 C-172AL2 - 1 C-172AL2 IC-172-1C-172AL2PB1-1C-172AL2P81 IC -172 - 1 C-172AL2PB2 - 1 C-172AL2PB2 IC -174 - 1C-174- IC -174 IC -174 - 1C-174- IC -174 iC-18-IC-18-10-18 lC-18-10-18-10-18 1C-19- 1C-191-1 - 1C-191-1 1C-19 - 1C-1911 - 1C -19L1 1C-19 - 1C-1911 - IC -19L1 1C-19 - 1C-1911 - 10-19L1 Plan: 1 C-156 - Plan: 10-156 - 1 C-156wp07 Plan: 1 C-158 - Plan:1 C-158 - iC-158wp02 Plan: 1 C-158 - Plan:1 C-158 - iC-158wp02 Prelim: 1 C-157 - Plan: 1 C-157 - 1 C-157wp06 Prelim: 1 C-157 - Plan: 1 C-157 - 1 C-157wp06 13,400.00 14,350.00 13,421.98 14,375.00 14,200.00 14,975.00 14,250.00 15,075.00 Well 1C-06 1 C-06 Q 94.00usft (10-06) 1 C-06 @ 94.00usft (1G06) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Distance Between Between Separation Warning Centres Ellipses Factor (usft) (usft) 1,135.14 689.74 2.549 Normal Operations, ES 1,136.51 690.18 2.546 Normal Operations, SF 1,570.19 1,146.03 3.702 CC 1,571.90 1,145.14 3.683 ES, SF 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 Outofrange 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 Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range CC - Min centre to center distance or covergent point, SF- min separation factor, ES - min ellipse separation 81142019 10,33: 29AM Page 3 COMPASS 5000.14 Build 85H ConocoPhillips Pro Site: Kuparuk River Unit Site: KuparOk IC Pad �e.nren m.. xonn MrymticNoonlau- WELLBORE DETAILS' iC-061.1-01 REFERENCE wFC WTICDN Parent Wellbore'. 1C-061.1 covanalalxel Reiaeare� Wel lCue,nel Well: 1C46 zn�u nmi Tie on MD'. 9800.00 vwm Mol Rerererca MraaI vel Wellbore: 1C-0BLi-01 aV! YI✓a]� SecEon(VS)R¢a C N I@0DOO-OR PWn: 1r•a6L1-01 w 02 1G0611C-061_1-01 P ( t MmN. goo p� . 1C Mveww ENahUlat ReMrta ILuan sappurn lwa6l Lakvle0on MCNon. Mmlmum Curvame WELL DETAILS: 1C-06 +N/ -S +E/ -W North@ Easting Latitude Longitude 0.00 0.00 5968860.00 561864.00 70' 19'31.647 N 149° 29' 54.042 W Sec mo Inc Am ett Mace VSi3 Annotation 1 9900.00 95.16 317.01 6451.71 5681.01 3207.68 0.00 0.00 5681. 1 TIPIKOP 2 10000.00 101.21 320.57 6437.48 5755.41 3142.49 7.00 30.00 5755. 1 Start DLS 7.00 TFO NX 3 10300.00 93.18 340.15 6399.57 6012.82 2996.55 7.00 111.00 6012. 2 Start DLS 7.00 TF01 C D.0 4 10600.00 89.41 0.82 6392.72 6306.97 2947.27 7.00 100.00 6306. 7 Start DLS 7.00 TFO 1 .0 5 10800.00 81.65 12.51 6408.36 6504.53 2970.25 7.00 124.00 6504. 3 Start DLS 7.00 TFO -7 .01 6 11200.00 89.54 345.54 6439.66 6899.25 2963.05 7.00 -75.00 6899. 5 Start DLS 7.00 TF0 71010 7 11500.00 95.58 5.69 6426.13 7196.39 2940.14 7.00 73.00 7196. 9 Start DLS 7.00 TFO -1 5. 8 11800.00 89.91 345.43 6411.61 7493.45 2916.94 7.00 -105.00 7493. 5 Start DLS 7.00 TFO I( I.0 9 12100.00 86.00 6.08 6422.43 7790.76 2894.82 7.00 101.00 7790. 6 Start DLS 7.00 TFO -8 .01 10 12400.00 89.82 345.42 6433.49 6088.05 2872.66 7.00 -80.00 8088.5 Start DLS 7.00 TFO -1 0. 11 12600.00 87.42 331.62 6438.33 8273.65 2799.63 7.00 -100.00 8273. Start DLS 7.00 TFO 6 OC 12 13000.00 90.06 359.50 6447.28 8657.08 2700.96 7.00 85.00 8657. Start DLS 7.00 TFO -5 .0 13 13200.00 98.04 347.96 6433.11 8854.90 2679.32 7.00 -55.00 8854. 0 Start DLS 7.00 TFO 1; .0 14 13550.00 84.82 8.64 6424.31 9201.98 2669.19 7.00 122.00 9201. 8 Start DLS 7.00 TFO -7 A 15 13900.00 90.61 344.80 6438.46 9548.46 2649.18 7.00 -77.00 9548. 6 Start DLS 7.00 TFO 7 OC 16 14300.00 98.89 11.67 6404.74 9942.85 2636.47 7.00 72.00 9942. 5 Planned TD at 14300. 0 Mean Sr G I 8400 da O 8050 - wl v + 7]00 z 0 ]350 ]000 t p 6650 - 6300- ` i If 96'1( 0(1 OI mni _. IC -0,11 01 T09 IiC-DG 1( "@I_1 _1 Planned '[D a1 13000.00 IC-06LI-01 IC-06LI-01 T06 W-06LID1 rm IC-U6LI-01 'FOI West( -)/East(+) (350 usft/in) on NNorlbeasl IU at 13%000 O 72 00 7700 122 00 Stan DLS) W 1 P� - _.. SIzn DLS 7.0D TFO IDI. Do Stan DIS 7 00'110 105 00 __ -- Sian DLS]. OO TFC) 7300 Stan DLS 1.00 TFO -75 00 Stan DLS 7 00 1 F0124 DO Vertical Section at 0.00° (200 usft/in) ConocoPhillips Project: Kuparuk River Unit_i Site: Kuparuk IC Pad m.n,=w,m u•eiwi=xmn Iaaa• Mae,w2 R.M WELLBORE DETAILS: iC-06L1 REEEREKE IREORIATIOM Parent Wellbore: 1C-06 Coordwk (NEI Reierewe: WeX ICL6. nue Mmn vaWw(M)Relmence'. IG30�9900usflpC-06) FBnmw. Well: 1C-06 snreu vnaaani Tie on MD Mi i,ciun (vs)"'e. slu.(o WN, OWE) Wellbore: 1C-061-1 °1 %W M- 0°08 Mearvrea Dente Reiue�'. Icu6 @ 9amuaa lICa6I Plan: 1C416L1_wp02(1C4)MC-061-1) xoaipe ooicee CakWalon Mi Minimus caval. BER AHUGHES Emnip ny III-IVa(10-IWL: III-IOI/II1.10uL1 r I ,I IIt Fi lli I I i I C.....� I i_ Iff IiBH I i. t _ 1 �IOn i. j a It +O 9000 j ....._ s I ^ SDOD v A v Ili egll i+'i 7500CA f 700U. t �. . _ —T� • 6000 5500 - 5000 _ 4900 • ¢ 5i.•,lr. I' It}il'HI -po- 4000 +L -w l�:in f Lil ill l 14tlYl�--I'/NL 3^ t 3500 3000:-__..:._�.. -. -5000 4500 4000 .500 -50110 -;500 �OOU -1500 -1000 -500 II 500 1000 1500 2000 '_SOU 3W0 3500 4000 4500 5000 5500 6000 G50(I 7(10(1 ]500 8000 8500 9000 0500 10000 10500 11000 11100 West( -)Bast(+) (500 usft/in) 1C-06 94.00usn (1C-06) s KUP INJ WELLNAME 1C-06 WELLBORE 1C_06 CQn«TPhi"1PS - A43ska. Inc. Atbibutes. Max Angle &MD TD FIeW Name WeNhore 0P1111Vd WNIbwe Status ncl '1 MO amid ACI BIm INKS) KUPARUK RIVER UNIT 500292056400 IN3 800 4,200D0 10,2430 Comment Xg31Wm1 Bate Annotation me.ae NB-0Nlhl Rlg Relxu Dale SSSV:TRDP Lav WO: 1122007 39.01 W31119V IGa3'H.G, dEEa" Last Tag Wr1iWeW-dogrlWl AnmwlbnOepiM1 MKBI End DM I WeRWe I bar Mod By - - - - - - HANGER, S9 con.1 Oft, 11 SAgVNKZda76 SIIgFACE; 3r J.i, ffi7.0� GA811RiaWg.3 pi GIMETO ItE pACR: Rt5f.5 wwLe 9dg3g OVEgeHOT; 9.23¢9 am, grsa EACKEgI A.1.1 in NIPPLE93ae3 Pn1: Anda ilated- FM. Isakep PRockdol IDN, aurnerZ256- -- -- - UM I T71 Lest Tag: RKB 9,488.0 718/2019 I1C-O6 Ildri Last Rev Reason MmMlon 1 EMDeM Wgia", last am By Rev Reason; T.B I7182019 1C-06 fergusp Casing: Strings Casing Description CONDUCTOR GDlin ID(in) Top INKBI Set DeptM1 INK01 SH. 16 15.06 32.0 65.0 65.0 A!K (N➢... WIILen 11....40 Top Thread 62.58 Home -d0 WELDED Lazing pescnplipn SURFACE ODlinl 10 (in) Tap(hK8) Set Depq (nKB) Set 10 get 9.95 31.3 13,287.0 12.1385.1 DeptM1 (iW)... WN.w 11... Gra Ge Top TM1rea] 45.50 K-55 BUTT casing Besctlp,lon PRODUCTION I.. (in) lip (In) Top(nKBI Jam cepat MKB) I Am 7 6.28 29.6 10.2258 7,090.1 MpN IIVal-1WMn 11... Gretla Top TM1mal 2600 K45 BTC Tubing Strings '!M cubing ion ENing Ma.. 1p(int cop INKBI 1.DeptM1 rt -Gel pepm lTVp (--WlpbXn Gratle Top Connection TUBING 200.7 WO 3112 299 26.9 9,232.9 6,38].5 9.30 L-80 8 rd Completion Details Top RVEd Top Incl Nominal I., RR81 (NK.) I°) Imm ens Co. to (in) 26.9 26.9 0.00 HANGER FMC Tubing HANGER 3.500 2,237.6 2,021.0 43.75 SAFE WV 3.5'TRMAXX-5E Safely Velve (Serial A HYS-70i . 12 91355 6,313.4 39.06 PER Bdger PER seal assembly(pined drop) W1.39' space0ul 3.140 9,1515 6,325.8 39.54 PACKER Beker FHL Packer(purned WM®shear) 3.WO 9,193.2 6357.6 40.79 Ni 2.813'%Nipple 2,813 9,231.9 6386.7 THAT VERSHOT Baker Tuhing Stub Overshot a I space out 3.610 plin) Top (IIKB1 EN oepIM1 IX.. 3C oeplh (No)... WI(IhXn Gratle Tap<onnecfim Tuning Description Shing Ma... 110 TUBING 1993 WO 53/4 4.37 9,232.2 9,281.5 6423.4 Completion Details Top LN81 T -"-G) Tap Rm-' Incl (°) Item pv tom Nominal Ip (n1 9,2552 6,4040 42.38SBR OAKEN EL -1 SBR(no lull joint. TBG string showing SBROD/ID) 4.375 Tubing oeicnption String Ma... 10(n Tap (NKB1 SH OepIM1 (M1.. Sel DeptM1 (ND)(... WI IWMI Gratle iopeonneclion TUBING Original 31/2 299 9281.5 93112 6498] 9.20 K-55 BTC Completion Details "1 Top inn Top nlce (nlce p1 Imm Des Com Thamal In (in) ,25 6.4234 43.04 PACKER BAKERFHLPACKER 967 3.000 9.3493 6.4721 44.98 NIPPLE CAri D NIPPLE NO GO 2.750 9,380.9 6,494.3 I 45.93 SOS 2,992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Tapingel *ap(rv01 (ngel mpmd f) GasCom aun Dam mon" 10,Flo .in I 6,946d 4400 FisM1 Vann UT Leh firm original pert. 101 long 625/1981 Perforations & Slots RNHftKB) BtMMKB) "(p nw) NKBI Bun Pri MKB) llnkedlme large SM1OI Dena pM1alsm 1 Typz Co. 9.410.0 9,485.0 6,514A 6,565.8 UNIT O, Com, C- 3,1C-06 Jo5hod81 12.0 Mandrel Inserts 31 on N Top MMEN 1B Top(iWl (NIB) Make MaM 00(in) Sery Valve Type IatN Type Pon41xe gn) TAG ftun (psl) Run Bem Cam 9.079.2 62fi . amw MMG 112 A LIFT DMY BK 000 0.0 111112007 Notes: Cenmal&Safety End Dale I MnOtafion 1/23/1993 NOTE'. WORKOVER 4/92004 NOTE:WAIVEREDWELC TxIACOMMUNICATION 1.281010 NOTE: VIEWSCHEMATICw1Alaska SpllMMIC9.0 Proposed CTD Schematic 16" 65# H-40 shoe @65'MD 10-3/4"46# K-55 shoe @ 3287' MD IKOP @ 9430' MD C -sand parts 9410'- 9485' MD 7" 26# K-55 shoe 10,226' MD 3-1/2" TRMAXX-5E SSSV @ 2238' MD 3-1/2" 9.3#L-80 EDE 3rd Tubing to surface 3-1/2" Camco MMG gas lift mandrel @ 9079' Baker 3-1/2" PBR @ 9136' MD (3.0" ID) Baker FHL packer @ 91 52'MD (3.0" ID) X -Nipple (d1 9193' MD (2.813" ID) Baker EL -1 SBR @ 9255' MD (4.375" ID) Baker FHL Packer @ 9282' MD (3.0" ID) 3-1/2" Camco D landing nipple @ 9349" MD (2.75" min ID, No - Go) 3-1/2" tubing tail @ 9381' MD IC -0611-02 wp02 TD - 13,900' MD Liner top - 9320' MD IC -06L1-01 wp02 TD -14,300' MD Billet/Liner top - 11,250' MD VMD top - 9900' MD Iniection ReNew Casing Top of C Send Topof C-Sand0il Topof Cemem Top W[ement Top of Cement Cement Openshom Well Name Seems She on pool (MO) Pao1(TVD55) (MD) (Ttow) Determined By Ressmolr Stet.. Zonal imladan Summery Mechanical Integrity 1C-06 Injector open to only C -And MMA passed @3000 psi 7/26/19 Mmherlmre Sh t -In T" 94I1' 6421' 5225' 3680' L911 through "donations. Packer st 929T.nd TOC at 5225' 535 sa Gass G cement MMA instead@IWO psi 7/26/19 Producer open only to C -And through mmherlrom, perforations IC -19 & IC- and CID sidetrack mmpk[ed MITIA passed @2750 psi 9/7/I7 191.1 Producing T' 10144' 60.59' 9281' 5800' LOS with sI.0 dtine, Packarat10035'and O at92B1 240.U.Gcament MITOA Walled 5/26/07 1C-1112-02 Pmducar open only to GAnd Motherbore perforations Cemem (1011 IO,229'(topof5" through CUD sidetrack completedseumred. Packer at 10,149' and MITOA passed@IWO psi 2/5/19 Motherim.) Producing 15-Lim 10,656' 6612' limn) 6134' Lot with slotted lines T0C at ID,2T9' (S") 112uC sG MITIApasmd@25OOpsi7/26/09 Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Monday, September 9, 2019 5:19 PM To: Germann, Shane Subject: Re: PTD's for KRU 1 C-06 Laterals They're in process. Not much lead time on these permits Sent from my Phone On Sep 9, 2019, at 2:59 PM, Germann, Shane <Shane.Germann@conocophillips.com> wrote: Victoria, I'm checking in to see what the status is for the PTO's for the KRU 1C-06 laterals (1C -06L1, 1-1-01, & Ll - 02). We should be moving to the IC -06 tomorrow night (9/10). Feel free to give me a call or email if there is any information you need from me. Thanks, Shane Germann Coiled Tubing Drilling Engineer Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 Loepp Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Tuesday, September 10, 2019 7:50 AM To: Germann, Shane Subject- KRU 1C-061-1, -1-1-01,-L1-02(PTD 219-117,219-118, 219-119) 1/4 mile AOR Shane, Please send a well plat showing the % mile review area for each lateral and a table outlining information as shown in the example attached plat and table. Thanx, Victoria r� Section 2 — Plat 20 AAC 25.283 (a)(2) 6L Plat 1: wells within .5 miles �a AA092347 C U C la L AA087M 1� r 10 ,U s i ASRC-A,092744 A5RC-NPR4 ConocoPhillips AUska CDS-98 1 AA081817 1 I Lease Plat a 02 0a 0.8 08 1 Wes 2 • Frac Pow.s \\ Q Man We Frac Pon Bu7lci ASRC-NPRi F—I nan 44k Wen TraU Bue, ' —Nelle wdxn Trach Bu!Rr — N'M Tract �Op"Iroe" ASRC.NPR{ AlpIr1e PA ASRC�IPR3 r.� VV..IB \ \ _ Und Boundary CPA) Lease �a AA092347 C U C la L AA087M 1� r 10 ,U s i ASRC-A,092744 A5RC-NPR4 ConocoPhillips AUska CDS-98 1 AA081817 1 I Lease Plat a 02 0a 0.8 08 1 Wes 2 Q . �y.%.�. ' ■ \ � } 7a - |# - '— —� ---= !■\_ � -�- � , TRANSMITTAL LETTER CHECKLIST WELL NAME: k p U , iC-- 06 L _1-' 0 ,J- PTD: �J 1 + —11S Development /Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: K U t cwa k R I VT- POOL: Ku a UrL < IN 1 ✓e lr 01-1 Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit % LATERAL No. (TI—dZv, API No. 50-OZq-ao56h►- V(If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company- Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Companv 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, V/ composite curves for well logs run must be submitted to the AOGCC V/ within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 PTD#: 2191180 Company ConocoPhillios Alaska. Inc. Initial Classrfype Well Name: KUPARUK RIV UNIT 1C-06L1-01 Program SER Well bore seg SER/PEND GeoArea B2D Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 1 Permit. fee attached..... _ _ I .......... . .................. . NA... _ _ _ _ Date Commissioner Date 2 Lease number appropriate _ ........ .................... Yes 3 Unique well. name and number - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - Yes . .. .. ... . 4 Well located in a. defined pool _ _ _ _ _ _ _ _ _ _ Yes 5 Well located proper distance from drilling unit. boundary ..... . .................. Yes ..... - . ...... - ... _ ............ _ 6 Well located proper distance from other wells .. _ _ _ .... _ ..... Yes ............. ... . . . . . . 7 Sufficient acreage available in drilling unit. _ _ _ _ _ _ _ _ _ _ _ Yes 8 If deviated, is wellbore plat included _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ Directional. plan view & wellbore profile included.. 9 Operator only affected party. _ _ _ _ _ _ _ _ Yes 10 Operator has. appropriate, bond in force _ _ _ _ _ _ Yes _ 11 Permit can be issued without conservation order _ _ _ _ _ _ _ _ Yes Appr Date 12 Permit can be issued without administrative approval _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 13 Can permit be approved before 15-day. Wait. _ Yes DLB 9/5/2019 _ .. ... 14 Well located within area and strata authorized by Injection Order # (put 10# in. comments) (For Yes _ _ _ _ _ Area Injection Order No. 2C-.Kuparuk River Unit. 15 All wells within 1/4 mile area of review identified (For service well only) _ Yes 16 Pre-produced injector: duration of pre-production less than 3 months. (For service well only) _ NA _ _ _ _ Well will not be pre-producedper Conpoo.PhiJlips. 17 Nonconven< gas conforms to AS31,05:030Q.1.A),Q.2.A-D) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ NA .. _ . _ ....... _ _ _ . _ ........... _ .. _ _ 18 Conductor string provided _ _ _ _ _ _ _ _ _ _ _ NA. Conductor set. for.KRU 1C-06 Engineering 19 Surface.casing.. protects all.known_ USDWs _ . _ _ _ _ _ _ _ _ _ NA Surface casing set for KRU 1C-06. _ 20 CMT vol adequate to circulate on conductor & surf csg _ NA .. Surface casing set and fully cemented 21 CMT vol adequate. to tie-in long string to surf csg. _ _ _ _ _ NA.. 22 CMT will cover all known productive horizons_ _ _ _ _ _ _ _ _ _ No _ _ _ _ _ Productive. interval will be completed with uncemented slotted liner 23 Casing designs adequate for C, T, B &. permafrost Yes 24 Adequate tankage or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Rig has steel tanks; all waste to approved disposal wells. 25 Ifa_re-drill, has 10-403 for abandonment been approved .. ........... .. NA.................. 26 Adequate wellbore separation proposed _ _ _ _ _ . .. . ... . . . . .. Yes .... - .. Anti-collision analysis complete; no major risk failures 27 If diverter required, does it meet regulations.... _ _ _ _ _ NA Appr Date 28 Drilling fluid. program schematic & equip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ Max formation pressure is 3880 psig(11.9 ppg EMW); will drill. w/ 8.6_ppg EMW and. maintain overbal w/ MPD VTL 9/10/2019 29 BOPEs,.do they meet regulation _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 30 BOPE.press rating appropriate; test to _(put psig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ Max formation pressure is 3235 psig; will test BOPS to 3500 psig. 31 Choke manifold complies w/API_ RP-53 (May 84). _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 32 Work will occur without operation shutdown ............................... Yes ....... ................... 33 Is presence. Rf H2S gas probable _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _Yes _ . H2,9 measures required 34 35 .Mechanical condition of wells within AOR verified (Forservice well only) ........... _ Permit can be issued w/o hydrogen_ sulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes NO _ .. 1C-07A. 1C-19,.1Cr19L1, 1C-11 L2-02; Rech integrity verified.. . _ _ _ _ Wells-on 1C-Pad are KS-bearing. H2S measures required._ Geology 36 Data presented on potential overpressure zones _ _ _ _ _ _ _ _ Yes Appr Date 37 Seismic analysis of shallow gas. zones. . . . . . . . ........ . .... NA..... DLB 9/5/2019 38 Seabed condition survey (if off-shore) _ .. _ _ _ _ . . . . . . . ......... NA 39 Contact name/phone for weekly.progress reports [exploratory only] .. .......... NA. .... _ _ _ _ ..... . Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date n/3