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Home My WebLink About219-021DATA SUBMITTAL COMPLIANCE REPORT 6/17/2019 Permit to Drill 2190210 Well Name/No. KUPARUK RIV UNIT 2G-06AL2 Operator ConocoPhillips Alaska, Inc. API No. 50-029-21121-66-00 MD 10261 TVD 6054 Completion Date 3/15/2019 Completion Status 1-0IL Current Status 1-0I1- UIC No REQUIRED INFORMATION Mud Log No 1/'Samples No V� Directional Survey Yes V/ 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 OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 30605 Digital Data 4/15/2019 Electronic File: 2G-06AL2 EOW NAD27.pdf ED C 30605 Digital Data 4/15/2019 Electronic File: 2G-06AL2 EOW NA027.txt ED C 30605 Digital Data 4/15/2019 Electronic File: 2G-06AL2 EOW NAD83.pdf ED C 30605 Digital Data 4/15/2019 Electronic File: 2G-06AL2 EOW NAD83.txt Log C 30605 Log Header Scans 0 0 2190210 KUPARUK RIV UNIT 2G-06AL2 LOG HEADERS ED C 30609 Digital Data 7981 10261 4/15/2019 Electronic Data Set, Filename: 2G-06AL2 GAMMA RES.Ias ED C 30609 Digital Data 4/15/2019 Electronic File: 2G-06AL2 2MD Final.cgm ED C 30609 Digital Data 4/15/2019 Electronic File: 2G-06AL2 5MD Final.cgm ED C 30609 Digital Data 4/15/2019 Electronic File: 2G-06AL2 5TVD Final.cgm ED C 30609 Digital Data 4/15/2019 Electronic File: 2G-06AL2 2MD Final.pdf ED C 30609 Digital Data 4/15/2019 Electronic File: 2G-06AL2 51VID Final.pdf ED C 30609 Digital Data 4/15/2019 Electronic File: 2G-06AL2 5TVD FinaLpdf ED C 30609 Digital Data 4/15/2019 Electronic File: 2G-06AL2 EOW NAD27.pdf ED C 30609 Digital Data 4/15/2019 Electronic File: 2G-06AL2 EOW NAD27.txt ED C 30609 Digital Data 4/15/2019 Electronic File: 2G-06AL2 Survey Listing.txt ED C 30609 Digital Data 4/15/2019 Electronic File: 2G-06AL2 Surveys.bd ED C 30609 Digital Data 4/15/2019 Electronic File: 2G- 06AL2_25_tapescan_BHI CTK.txt ED C 30609 Digital Data 4/15/2019 Electronic File: 2G- 06AL2_5_tapescan_BHI_CTK.txt AOGCC Page 1 of 2 Monday, June 17, 2019 DATA SUBMITTAL COMPLIANCE REPORT 6/17/2019 Permit to Drill 2190210 Well Name/No. KUPARUK RIV UNIT 2G-06AL2 Operator ConocoPhillips Alaska, Inc. API No. 50.029.21121-66-00 MD 10261 TVD 6054 Completion Date 3/15/2019 Completion Status 1-0I1- Current Status 1 -OIL UIC No ED C 30609 Digital Data 4/15/2019 Electronic File: 2G-06AL2_output.tap ED C 30609 Digital Data 4/15/2019 Electronic File: 2G-06AL2 2MD Final.tif ED C 30609 Digital Data 4/15/2019 Electronic File: 2G-06AL2 5MD Final.tif ED C 30609 Digital Data 4/15/2019 Electronic File: 2G-06AL2 5TVD Final.tif Log C 30609 Log Header Scans 0 0 2190210 KUPARUK RIV UNIT 2G-06AL2 LOG HEADERS Well Cores/Samples Information: Name INFORMATION RECEIVED� Completion Report (Yl Production Test Informatior NA Geologic Markers/Tops Y COMPLIANCE HISTORY Completion Date: 3/15/2019 Release Date: 2/19/2019 Description Comments: Interval Start Stop Directional / Inclination Data I Mechanical Integrity Test Information Y / NA Daily Operations Summary V Compliance Reviewed By: IV _v . `.. Date Comments Sample Set Sent Received Number Comments Mud Logs, Image Files, Digital Data Y l Composite Logs, Image, Data Files 0 Cuttings Samples Y l Core Chips Y _tf Core Photographs Y {' Laboratory Analyses Y /A Date: - - - l —F AOGCC Page 2 of 2 Monday, June 17, 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Y la_G/Vt V `a.0 APR 15 2019 A 'r1%^^v+ WELL COMPLETION OR RECOMPLETION REPORT AN 1a. Well Status: Oil EJ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: 2 C 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: ConocoPhillips Alaska, Inc. Aband.: 3115/2019 219-021 a 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 3/12/2019 15. API Number: 50-029-21121-66-00 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: • Surface: 547' FSL, 239' FWL, Sec 32, TI IN, R9E, UM 3113/2019 KRU 2G-06AL2 Top of Productive Interval: 9. Ref Elevations: KB:140 17. Field / Pool(s): 1227' FNL, 1259' FEL, Sec 32, T11 N, R9E, UM GL: 104 BF: Kuparuk River FieldlKuparuk River Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2830' FNL, 939' FEL, Sec 32, TI I N, R9E, UM 940316057 ADL 25656 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 508930 y- 5944135 Zone- 4 10261/6064 LONS 82-180 TPI: x- 512698 y- 5947646 Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 513026 y- 5946044 Zone- 4 NIA 1500/1470 5. Directional or Inclination Survey: Yes ❑+ (attached) No ❑ 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 834016032 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/RES 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H40 38 110 38 110 24 202 sx Cold Set II 9 618 36 J-55 37 3134 37 2774 12114 1035sx PF E, 250sx PF C 7 26 J-55 36 8449 36 6224 8112 575 Class G, 250sx PF C 2318 4.6 L-80 7999 9402 5665 6057 3 Slotted Liner 24. Open to production or injection? Yes ❑� No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MD/TVD) Size and Number; Date Perfd): 3 112 8044 796815841 SLOTTED LINER: 8252-9402 MD and 6010-6057 TVD COMPLETION DAT f S O1 VERIFIED 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes E] No ❑Q 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: Method of Operation (Flowing, gas lift, etc.): 3121/2019 GAS LIFT Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 3/24/2019 33.2hrs Test Period 199 540 6843 176 1 2712 Flow Tubing Press. 2011411 Casinq Press: Calculated 24 -Hour Rate Oil -Bbl: 144 Gas -MCF: 390 Water -Bbl: 4947 Oil Gravity - API (corr): 24 Form 10-407 Revised 5/2017 l/'JZ -IcI f``7�y/� ONTINUED ON PAGE 2 RBDMS� "'� APR 16 2019 �^ �g �r Submit ORIGINIAL only 1 28. CORE DATA Conventional Core(s): Yes ❑ No El Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored (MD/TVD, Fromlro), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1500 1470 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk Al 8340 6032 TD 10261 6054 Formation at total de the Kuparulk A 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, paleontolooical report. production 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 Ohlinger Contact Name: Keith Herrin Authorized Title: Staff CTD En ineer Contact Email: Keith. E. Herrin co .ce Authorizedy//�� Contact Phone: 263-4321 Signature: Date: INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10A07 Revised 5/2017 Submit ORIGINAL Only 2G-06 Final CTD Schematic 0.89.3BYJ5551Me 3131' MD Partial Wintlaw � 810]'-etOB' MD Faeetl HighEnpansbn Wstlpe Last Tao a 8136' MD High Evpansbn lv Q9 0134' MD Lower Pscker hom OM Campltbn a 8150' MD FA peels s0aeezM letter -Btea'Me A4send Mrh sq"'"n etl 8216'-82K MD r zsg 3.55 M. 8110' MD 3-12" 9.39 LAG EL)E Brd Tubing to surface 3-12" DB landing nipple ® 525' MD (2.875" min ID) 3-12" Camw MMG gas fg mandrel @ 2852, 4946, 6250', 7246', and 7696' MD Beker 3-12" PBR @ 795T MD (2.98" ID) Baker FHL packer @ 7968 MD (3.03" ID) 3-12" DB limiting nipple @ 6011' MD (2.813" inn ID) 3-12" tubing tail @ 8043.6' MD (8048' PDO) 3" Ku"mk Liner Top Packer 0 8000' PDC 2(LB UTED =10281'MD 24118-sblletl / blank finer x80 seBbare depbprmM sleeve TOL a B000' MD. BOL = 8403' MD Top of sbluni Ilner= 8252 MD -_ 2G-0eL1Pe1 TD ® B.33p MD Waslwul. cinch, it Peakaffs Q b1]0' MD KUP PROD WELLNAME 2G-06 WELLBORE 213-06 '"/� +' Well Altribut4 Max Angle TD 'i�s Well Ae WeIIWr¢APYIIWI Wellbore e++lus n[I I°I MDlttr Ac101m IXXB) Alaska, Inic, KUPARUK RIVER UNIT 5002921121M PROD 460 400900 84850 NIPPLE 23HOaxMs'A,Beaimi AM Last Tag tams" MnaY[(a[OWI Anno n I DoWBUB) I End Om I WeRlnre M7. M- ey Last Tag: RKB I8,130.0 "72019 1. ifergai HANGERI3o.+- Last Rev Reason Annotation f End DAW I ofall a Las+MW By Rev Reason'.New OLD 32312019 2G-0fi Jhansen0 Casing Strings eaaina Desenptbn oDlinl ID ljp Top lnKBl set pepin lXKel sN oepin mm... wuL¢n p._erad¢ Top Tmeaa CONDUCTOR 16 15.06 70.0 110.0 110.0 62.58 HAO VArd it Galnp OesnryYion DOgn) Ip pill Top(Itl(B) SN DepIM1 (NISI SN DepN RV01... iWM1en P... Grada Tbp Tneead SURFACE 95]8 9.21 37.2 3,133.9 2,7737 36.00 J-55 BTC Gsq,p Oezcdptlon Dp lln) Ip llnl TOPOtKB) seI DaWM1 MKBI sel DeptM1 (NDI... WbLan 11... Grade Tap To_ conpuc7oB:38D++OoT PRODUCTION J 6.28 35.9 8,449.1 6223.8 26.00 J-55 BTC Tubing Strings Tubi,q oesniplion ailing Mo...lp lln) TopinKW siian lit sN Oep,n I -DI .-116X9 Gna TapeonnecOon xIPP1E:52.7 TUBWG WO 3112 2.99 30.1 ),969.3 50414 9.30 LA0 EUE8rQABM00 Completion Details ToplNol Top mal xominm Topinne) WKS) (°I Ibm Den eom to (m) 30.1 30.1 1 B09 1HANGER VetcolGMy Gen II TUBING HANGER 2938 GAS 111. 2,9 524.] 5246 1.18 NIPPLE 3.5"Camco "DS` Nipple w) 2.875 profile 2.875 5. 6831fi uiw PBR FUH bear Asairri(sheared) wl 2F space out STABBED IWO 2.980 PACKER ASSEMBLY I TUW,q"'W"ipEon WIN Me...1011n1 Toplflltsl Sea IHpM IR. 0e1 oepin(X7711... Wlpoet Gnde Top Connection TUBING PACKER 312 2.99 7,968.3 8,043.6 5899.1 9.30 LA0 6RDEUE ASSY SURFACE: 37. M,+i&a� Completion Details TopINO) Top Incl Nominal Top IflK01 Ma's °) Ihm Dee Com to '.n)_ GAS UFT; a.t 7,968.3 5,840) 39.50 PACKER FHL Packer 3.030 8,011.2 b.616 61 3903 NIPPLE 2813"DSNrpple 2.813 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top BVIS Topinm OWLIFT:Sz d l II,d Maph (') Des com Run DOW IDlin) 8.0060 5,869.8 39.10 PACKER Set " Kuparuk Liner lop packer 5" OAL, .5' Seal 311912019 Assembly 45" OAL, 4 Am Seals, 1,625' Min ID Third DSD Pai Set 3" Slip Stop On top Pecker GAS LIFT:7MBo $095.0 5939.4 3801 WED Eiiii NS High Expansion Wedge WS.Set-3deg ROHS. 2252019 0.000 8,097.5 5,941.4 3798 WINDOW W ailed ell downhole, Iedviag Wndw 102 Ot 2800 exposed in T' casrag 0 6132.0 --5.-99-7 77.54 WEDGE HIS High Expansion Wedge WS TIM= 0000 B COWLIFT, l.asaz N01e: WS slid down-h01e. Likely rop at 0136' MD (1azalle) 8,136.0 5.071.8137.49 WEDGE NS High Expansion Wedge WS WN201 0.000 1 B Pae. 7,551 5,989.313721 FISH PAUKER FROM OLD COMPLETION, PXX 1162008 7W PLUG, 0 REST OF TUBING DOWN TO WIRELINE RE- jLUi ENTRY GUIDE IS IN FILL. TAGGED HARD MUD @ PACKER-. 7 Sea.3 8158 SCM. Perforations & Slots a - Mile Top TWO) I B.fTUDI I (ehoods I I TopMKB) BM(nKB) IRKS) Maa) Unked2ane Dab ) Type Cam NIPPLE;Bo+1$ SUWA 8.198.0 6,0133 6,021.3 A5, 2GM5 9124/1988 4.0IPERF IS asrng; 1 1 19WO Schlumberger Casi 8,216.0 8246.0 6.035) 6059.9 A4.2G-06 92411988 ea IPERF Sua,. tune" u" I I I I Schlumberger Casi 'PL? LATERPl COMPLETION: ZmesG.aoz.o Mandrel Inserts St an WEOGE:aWSo on Top lTvo) vahm latex -S" -0 Run x Top ME) (ME)Mate under OO and Sery PairTyq W) I Q Run Date Com 1 2.9sl 51 2,5550 jCamco MMC 1112 GAS LIFT IGLV RK 0.188 1 1,247.0 32012019 9:30 2 4,945.5 3.851 9 Camco MING t 112 GAS LIFT GLV RK 0.188 1,2460 31202019 1030 6.2503 4,646.2 Camco MMG 1112 GAS LIFT OV RK 0.250 us, 311912019 100 WEDGa:9,+3z.O 4 72460 5310.6 Cam- MMG 1112 GAS LIFT DMI RK 0,000 0.0 2/1812019 5 7,8982 5.786.8 Cam- MMG t tl2 GAS LIFT DMY RK UUwI 00 2/192019 WEDGE, 8,35p Nobs: General & Safety EM Dae I Amwb - 1rz2000 NOTE: WORKOVER 1 102007 NOTE '^ MIT TESTING WILL HAVE USE OS NIPPLE@8000 12]1 007 NOTE: WORKOVER 009 NOTE: 5005' = TIGHT SPOT, UNABLETOWORK 2.6" GAUGE RING PAST 6272009 019 NOTE: View SCOemaercw/Alaska SHlemalrc10.0 FISH: 8.,M.o IPERF:B.+ea.cradso- IpERG&318o$3450----- PRO LOTION', SoSrs B1 KUP PROD WELLNAME 2G-06 WELLBORE 2G-06AL2 ConocoPhillips Naska, Im zcmuz u,srzaeaw.sa AM Last Tag veriM blacnell Anndbon Depth (WS) End DaW Wellbore Lar, MOE ey LAST TAG 1,nn.rt Last Rev Reason -- - ---- RPNDEq., W,__ An... EM oah W 111 Last Mod Br REV REASON. CTO MULTILAT 1jennall Casing Strings CWnB Dawliplbn oD pnl m pnl Too MKBl s rwh iM(e) saL DePM (Not... W""'n ti _ G.d Tap In. "ALP"LATERAL 2318 1.99 ),999.3 9,402.0 6,05)5 460 L-80 BTL COMPLETION Notes: General & Safety End Dab AnnobHon 41912019 NUI E:VIeW SCneMWIC WI Alaaka 6cnemalle10.0 CONOUCTOR: ]8.61100 NIPPLE; BNi Bas urr'.zasl.s BUPGACE, 3I.1J.133.B� G45 LIFT; 0.80.5.1 GP LIFT, 6Z 3 GAS LIFT, 72a 0 WS LIFT, ].I PBR', 7Y 6 PACNER', 7,6 3 NIPPLE, r,011 i PRODUCTICN.W5 ,i I I� 'AL AI FR WMPLETION:�J' I'M .39..rz Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Tens End Time Dur (hr) Phase Op Code Activity Code Imre P-T-% dperatlon Start Depth (ftKB) End Depth (M) 10/14/2018 10/14/2018 3.00 MIRU MOVE MOB P Trucks on location, Load shop on 0.0 0.0 06:00 09:00 flatbed, PJSM with Peak for rig move. Move pits & sub off well 31-01, Jeep up, R/D cellar bene and herculite 10/14/2018 10/14/2018 5.00 MIRU MOVE MOB P Move rig 31 to 2G pad 0.0 0.0 09:00 14:00 10/14/2018 10/14/2018 1.00 MIRU MOVE MOB P On 2 G pad, De jeep rig, Rig up 0.0 0.0 14:00 15:00 herculite in cellar, Scaffolding crew here. 10/14/2018 10/14/2018 2.00 MIRU MOVE MOB P Spot sub and pits 0.0 0.0 15:00 17:00 10114/2018 10/14/2018 1.00 MIRU MOVE MOB P Start pre spud check list, Safe out rig, 0.0 0.0 17:00 18:00 stairs down. Ensure egress routes clear. 10/14/2018 10/14/2018 3.00 MIRU WHDBOP RGRP P Swap out swab #2 on stack, Work rig 0.0 0.0 18:00 21:00 1 up check lists 10/14/2018 10/14/2018 2.00 MIRU WHDBOP NUND P Nipple up stack, change out riser, 0.0 0.0 21:00 23:00 Obtain RKB's, RIG ACCEPT 21:00 10/14/2018 10/15/2018 1.00 MIRU WHDBOP SVRG P Grease stack, R valves, and drilling 0.0- 0.0 23:00 00:00 choke 10/15/2018 10/15/2018 0.50 MIRU WHDBOP SFTY P PJSM to perform full BOPS test, Test 0.0 0.0 00:00 00:30 witness waived by Adam Earl, AOGCC 10/15/2018 10/15/2018 8.00 MIRU WHDBOP BOPE P Start full ROPE test, Test pressure 5K, 0.0 0.0 00:30 08:30 stab INJH, test inner reel iron, inner reel valve, and pac-off. 10/15/2018 10/15/2018 0.50 MIRU WHDBOP CTOP P Valve crew on location load lubricator 0.0 0.0 08:30 09:00 into pipeshed, Unstab INJH, changeout UQV floats. 10/15/2018 10/15/2018 1.50 MIRU WHDBOP PRTS P Perform valve check-list, test PDL's 0.0 0.0 09:00 10:30 and tiger tank line. 10/15/2018 10115/2018 1.20 MIRU WHDBOP PRTS P PJSM, PIT Lube, pull BPV 0.0 0.0 10:30 11:42 10/15/2018 10/15/2018 0.30 MIRU WHDBOP CTOP P Load out Valve crew egiupment 0.0 0.0 11:42 12:00 10/15/2018 10/15/2018 0.30 SLOT WELLPR CTOP P Move INJH forward remove UQC, 0.0 0.0 12:00 12:18 boot a-line, stab INJH 10/15/2018 10/15/2018 0.60 SLOT WELLPR CTOP P Line up and pump slack 0.0 0.0 12:18 12:54 manangement. 10/15/2018 10/15/2018 0.30 SLOT WELLPR CTOP P Unstab INJH, rig up hydraulic CT 0.0 0.0 12:54 13:12 cutter 10/15/2018 10/15/2018 3.80 SLOT WELLPR CTOP P PJSM, start trimming coil, found wire, 0.0 0.0 13:12 17:00 continue trimming coil, RD cutter and dress CT for CTC. * ' Note: Found wire (03 28' 10/15/2018 10/15/2018 1.50 SLOT WELLPR CTOP PJSM, install CTC, pull test to 35 k 0.0 0.0 17:00 18:30 10/15/2018 1011512018 0.60 SLOT WELLPR CTOP Re-head BHI upper quick connect, 0.0 0.0 18:30 19:06 test e-line (good-test), install floats 10/15/2018 10/15/2018 0.40 SLOT WELLPR CTOP ]PPD PT connections and re-head 4,500 psi 0.0 0.0 19:06 19:30 (good test) 10115/2018 10/15/2018 1.00 SLOT WELLPR PULD PJSM, slide cart back, load both 0.0 0.0 19:30 20:30 PDL's 10/15/2018 10/15/2018 1.30 SLOT WELLPR PULD cleanout BHA fl, perform surface 0.0 51.3 20:30 21:48 test (good test) 10/15/2018 10/15/2018 1.90 SLOT WELLPR TRIP P Tag up, reset counters, RIH with 51.3 7,990.0 21:48 23:42 Cleanout BHA, PUW @ 4,0007 24 k 10/15/2018 10/15/2018 0.10 SLOT WELLPR DLOG P Log the Ki marker correction of+2', 7,990.0 8,019.0 23:42 23:48 PUW=38K 10/15/2018 10/16/2018 0.20 SLOT WELLPR PRTS P Start static BHP, TVD 5872, 8,019.0 8,030.0 23:48 00:00 Ann=3778, EMW=12.38 Page 1119 ReportPrinted: 3/19/2019 Operations Summary (with Timelog Depths) 2G-06 is Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log n D men �P� start Time End 7me DurM Plisse Op Code Ad,i, Code ry Time RT -x Operation End NO (11(B) 10/16/2018 10/16/2018 0.20 SLOT WELLPR PRTS P Static BHP, TVD 5872, Ann=3778, 8,030.0 8,030.0 00:00 00:12 EMW=12.38 10/16/2018 10/16/2018 0.30 SLOT WELLPR TRIP P Trip in to 8158 dry. PUH to 8000 for 8,030.0 8,000.0 00:12 00:30 CCL pass 10116/2018 10116/2018 0.20 SLOT WELLPR DLOG P Log CCL down to 6158, Bit to CCL 8,000.0 8,158.0 00:30 00:42 39.5 10/16/2018 10/1612018 0.40 SLOT WELLPR CIRC P recip CT wailing on sweeps 8,158.0 8,158.0 00:42 01:06 10/16/2018 10/16/2018 1.60 SLOT WELLPR TRIP P Sweeps out trip out displacing well to 8,158.0 56.8 01:06 02:42 used PwrPro 10116/2018 10/16/2018 1.10 SLOT WELLPR PULD P Al surface, PJSM PUD BHA #1 56.8 0.0 02:42 03:48 10/16/2018 10/16/2018 1.90 PROD1 RPEQPT PULD P Assemble Northern High Expansion 0.0 73.5 03:48 05:42 Wedge whipstock, M/U to Coil track and deploy. M/U to coil and surface test. Check pack offs. 10/16/2018 10/16/2018 1.60 PROD1 RPEQPT TRIP P RIH BHA #2 NS HEW whip stock 73.5 8,020.0 05:42 07:18 10116/2018 10/16/2018 0.20 PROD1 RPEQPT DLOG P Tie into K1 marker for -1', PUW=37K 8,020.0 8,043.0 07:18 07:30 10116/2018 10/16/2018 0.10 PROD1 RPEQPT TRIP P Continue in hole to setting depth 8,043.0 8,142.8 07:30 07:36 10/16/2018 10/16/2018 0.10 PROD1 RPEQPT TRIP P 8142, at set depth oriented to HS. 8,142.8 8,142.8 07:36 07:42 Close EDC pull slack from CT. Pumps on .5 BPM see tool shift 4200 PSI Set down lightly on whipstock 10/16/2018 10116/2018 1.50 PROD1 RPEQPT TRIP P POOH after setting whip stock 8,142.8 61.0 07:42 09:12 10/16/2018 10/16/2018 0.90 PROD1 RPEQPT PULD P Tag up at surface. Space out. PJSM 61.0 0.0 09:12 10:06 PUD BHA#2 10/16/2018 10/16/2018 1.10 PROD1 WHPST PULD P M/U and PD BHA #3 to mill window. 0.0 76.8 10:06 11:12 WFT V fixed bend motor, 2.80 window mill, and 2.79 string reamer. WU to coil and surface test 10/16/2018 10/16/2018 4.20 PROD1 WHPST TRIP P RIH BHA #3 to mill window, close EDC 76.8 8,025.0 11:12 15:24 @ 500' Pumps on @ 1.80 BPM @ 4111 PSI. Take screen shots. Continue in well, Stacked out hard @ 4790'. Nothing in the area. PUH Inspect pipe and injector. Good. Trip in. Stack out. Roll pump @ ,7 BPM and roll TF to HS. Taking weight every -30 feet. Continue in well pumping at reduced speed 10/162018 10/16/2018 0.20 PROD1 WHPST DLOG P Log K1 for -3', PUW=34K 8,025.0 8,049.0 15:24 15:36 10/1612018 10/16/2018 0.50 PROD1 WHPST TRIP P Continue in well, Dry tag pinch point 8,049.0 8,137.0 15:36 16:06 @ 8137.8', PUH 10/16/2018 10/1612018 2.70 PROD1 WHPST MILL P Bring pumps on 1.8 BPM @ 3803 PSI 8,137.4 8,140.0 16:06 18:48 FS, Start milling @ 8137.4 10/16/2018 10/162018 1.50 PRODi WHPST MILL P Continue milling window per 8,140.0 8,142.0 18:48 20:18 procedure, 1.8 bpm, BHP = 3986 psi, WHP = 394 psi, BOW called at 8140.2' (WOB & rip fall off), string reamer through window 10/162018 10/162018 3.20 PROD1 WHPST MILL P Begin pushing, milling rat -hole, CWT= 8,142.0 8,163.0 20:18 23:30 11.8K, WOB=0.7K-3K, BHP =3846 psi, WHP = 406 psi, -5.5 bph losses, pump 5 x 5 sweeps 10/162018 10/17/2018 0.50 PROD1 WHPST REAM P Begin reaming passes per procedure 8,163.0 8,163.0 23:30 00:00 (HS, 30L, & 30R) Page 2119 Report Printed: 3/19/2019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Sbut The EM Time Dur(hr) Phase Op Code AcWdy Coda Tyne P -T -X Operation W13) End DWUi(ItKa) 10/17/2018 10117/2018 0.80 PROD1 WHPST REAM P Complete reaming passes per 8,163.0 8,163.0 00:00 00:48 procedure (HS, 30L & 30R), dry drift window, clean up & down, PUW = 35K 10/17/2018 10/17/2018 2.10 PRODt WHPST TRIP P POOH, slight overpull at 4781', 8,163.0 76.0 00:48 02:54 slowed, close EDC, PJSM 10/17/2018 10/17/2018 1.10 PROD1 WHPST PULD P PUD BHA#3 (1.8'AKO motor, RB 76.0 0.0 02:54 04:00 Hughes bit), mill & string reamer came out 2.79" no-go 10/17/2018 10/17/2018 1.10 PROD1 DRILL PULD P PD BHA#3 Buildf rum Assembly (1.8' 0.0 72.0 04:00 05:06 AKO motor, RB Hughes bit), slide in cart, check pack -offs, MU to coil, tag up, set counters 10/17/2018 10/17/2018 1.70 PROD? DRILL TRIP P RIH w/ BHA #4, Set down @ 5077 72.0 8,031.0 05:06 06:48 10/17/2018 10/17/2018 0.10 PROD1 DRILL DLOG P Log K1 for -1.5', PUW=35K 8,031.0 8,031.0 06:48 06:54 10/17/2018 10/17/2018 0.10 PROD1 DRILL TRIP P Continue in well, clean pass through 8,031.0 8,165.0 06:54 07:00 1 1 1 window, Tag up and drill from 8165 10117/2018 10117/2018 0.50 PROD1 DRILL DRLG P 8165', Drill 1.77 BPM @ 3790 PSI FS, 8,165.0 8,180.0 07:00 07:30 BHP=3810 10/17/2018 10/17/2018 1.20 PROW DRILL DRLG P 8180 stall, Pick up, PUW=40K loosing 8,180.0 8,010.0 07:30 08:42 retums,pulling heavy, DHWOB=-14K, Pull up into casing. Orion shut down. WITTS running very slowly. Restart BHI and orton computers - Gas in returns at surface. Divert to tiger tank. Pump bottoms up. PUH 10/17/2018 10/1712018 0.40 PROD1 DRILL WPRT P PUH to log K1 for+1', trip in and log 8,010.0 8,029.0 08:42 09:06 RA@ 8141, TOWS=8134, TOW=8137, BOW=8140 10/17/2018 10/1712018 0.20 PROD1 DRILL WPRT P RBIH to drill, returns fall off - 8178'. 8,029.0 8,181.0 09:06 09:18 Work to bottom 10/17/2018 10/17/2018 0.20 PRODt DRILL DRLG P 8181', Drill 1.78 BPM @ 4010 PSI FS, 8,181.0 8,195.0 09:18 09:30 BHP=4130, RIW=12.8K 10/17/2018 10/17/2018 0.20 PROD1 DRILL WPRT P 8195 Pick up stacking, Overpulling, 8,195.0 8,175.0 09:30 09:42 DHWOB=-10K, Initial PUW=55K with - 20K DHWOB 10117/2018 10/17/2018 1.70 PROD1 DRILL WPRT T 8175 Stuck, work pipe, Try to orient 8,175.0 8,175.0 09:42 11:24 looks bit stuck. Diminished / no returns. Reduce wail head. Shut down pump to relax. Circulate 8 BBIs LVT down CT. Spot 2 BBIs out, let soak. Work pipe. Spot 3 more bbls out. Let soak. Work pipe and pop free 10/17/2018 10/17/2018 0.10 PROD1 DRILL WPRT P Continue wiper to cased hole 8,175.0 8,122.0 11:24 11:30 10/17/2018 10117/2018 1.80 PRODt DRILL CIRC P Pump 10 X 10 sweeps and circulate 8,122.0 8,013.0 11:30 13:18 bottoms up. Little material coming overshaker 10/17/2018 10/17/2018 0.10 PROD1 DRILL DLOG P 8013 tie into K1 for 1.5' correction 8,013.0 81030.0 13:18 13:24 10/17/2018 10/17/2018 0.50 PRODi DRILL WPRT P RBIH, stop @ 8127 and perfor static 8,030.0 8,127.0 13:24 13:54 pressure test, TVD 5931.4, Annular pressure 3935, EMW=12.7. Holding 12.8 PPG at window 10/17/2018 10/17/2018 0.10 PROD1 DRILL WPRT P RBIH to drill, stack and loose returns 8,127.0 8,195.0 13:54 14:00 @ 8178 work through 10/17/2018 10/1712018 0.30 PROD1 DRILL DRLG P 8195', Drill, 1.77 BPM @ 3860 PSI 8,195.0 8,205.0 14:00 14:18 FS, BHP=3850 10/17/2018 10/17/2018 0.90 PROD1 DRILL WPRT P 8205, PUH into casing. Pressures all 8,205.0 8,111.0 14:16 15:12 over. Circ bootoms up. Sample to geo. Calls it B shale. Blow down micro motion Page 3119 Report Printed: 3/19/2019 . Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sted Tim End Tim our (hr) Phase Op Code Activity Code Tlrne P -T -X Operation n De Start Depth End Depth (N(e) 10/17/2018 10/17/2018 0.20 PRODt DRILL WPRT P RBIH to drill 8,111.0 8,207.0 15:12 15:24 10/17/2018 10/17/2018 0.70 PROD1 DRILL DRLG P 8207', Drill, 1.76 BPM @ 3860 PSI 8,207.0 8,210.0 15:24 16:06 FS, BHP=4250, frequent pick ups. On pick up from 8210 became stuck @ 8190. Work pipe up to 50K, DHWOB=- 16K. Down to zero. DHWOB=6K 10/17/2018 10117/2018 0.60 PROD1 DRILL DRLG T Pipe stuck, Pump 8 BBIs LVF down 8,210.0 8,210.0 16:06 16:42 1 1 CT 10/17/2018 10/17/2018 1.60 PROD1 DRILL WPRT P Get two bbls out CT let soak. Work 8,210.0 8,075.0 16:42 18:18 pipe. Pump 3 more bbls out let soak. Pull free. Trip to cased hole. Pump 10 X 10 sweeps, circulate multiple bottoms up, pump additioal sweep 10/17/2018 10117/2018 1.80 PROD1 DRILL TRIP T Decision mae to POOH for cleanout 8,075.0 72.0 18:18 20:06 assembly, sill/shake over shakers, not sticky, low clay content, fairly benign 10/17/2018 10/17/2018 0.80 PROD1 DRILL PULD T PJSM, PUD BHA #4 72.0 0.0 20:06 20:54 10117/2018 10/17/2018 1.90 PROD1 DRILL PULD T PJSM, make up new tools, PD BHA 0.0 63.0 20:54 22:48 #5 (1.0° AKO motor, string reamer, D331 w/ridge-set, no Res tool), slide in cart, check pack -offs, MU to coil, tag up, set counters, blow down choke & micro -motion 10/17/2018 10/18/2018 1.20 PROD1 DRILL TRIP T RIH w/ BHA#5 63.0 5,500.0 22:48 00:00 10/18/2018 10/18/2018 0.50 PROW DRILL TRIP T RIH w/BHA #5 5,500.0 8,005.0 00:00 00:30 10118/2018 10/18/2018 0.10 PROD1 DRILL DLOG T Log K1 for -1' correction 8,005.0 8,037.0 00:30 00:36 10/18/2018 10/18/2018 0.50 PRODt DRILL DLOG T Continue RIH to 8100, close EDC, 8,037.0 8,137.0 00:36 01:06 PUW = 35K Stop, obtain SBHP (15 min): MD = 8120.6', TVD -senor = 5932.9', BHP = 4050 psi, WHP = 1367 psi, EMW = 13.13 ppg, pressure climbed during test 10/18/2018 10/1812018 2.30 PROD1 DRILL REAM T Work to end of rat -hole in 10' bites, 8,137.0 8,137.0 01:06 03:24 PUW's = 35K, FS = 394 psi @ 1.8 bpm, BHP = 4071 psi Peifrom reaming passes of window & rat -hole (8137' to 8166'): HS down- hole. 30L, 30R, HS, & 2 passes LS all up -hole (1 fpm through window, 5 fpm in rat -hole), pump multiple sweeps 10/18/2018 10/18/2018 1.90 PROD1 DRILL TRIP T POOH, open EDC, pre -loaded DS 8,137.0 59.0 03:24 05:18 PDL 10/18/2018 10/1812018 1.00 PROD1 DRILL PULD T At surface, Tag up and space out. 59.0 0.0 05:18 06:18 PUD BHA#5 10/18/2018 10/18/2018 0.40 PROD1 DRILL PULD T Reconfigure pre loaded tool to remove 0.0 0.0 06:18 06:42 UltraSlimResistivity tool from BHA 10/18/2018 10/18/2018 1.10 PROD1 DRILL PULD T Pressure deploy BHA#6 with 1.8° 0.0 62.6 06:42 07:46 AKO motor, RR HCC bi center. No agitator or USR. Make up to coil and surface test. Check pack offs 10/18/2018 10/18/2018 1.70 PRODt DRILL TRIP T Trip in hole, BHA#6, Test HOT on 62.6 8,010.0 07:48 09:30I stop 10/18/2018 10/18/2018 0.10 PROD? DRILL DLOG T Log K1 for -1/2', Close EDC, 8,010.0 8,030.0 09:30 09:36 PUW=34K Page 4119 ReportPrinted: 311912019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Stan Time End Time our (no phase op Cade Advity Code Time P -T -X Operadon (Po(9) End Depth(WB) 10/1812018 10/18/2018 0.40 FROM DRILL TRIP T Trip in well, initial tag up @ 8176 work 8,030.0 8,210.0 09:36 10:00 down to next tag up @ 8195. Work down to 8209. recip up to 8160. Clear on way up. No overpulls on DHWOB. RBIH stack at 8179. work pipe down to 8210 10/182018 10/18/2018 0.40 FROM DRILL DRLG T 8210', Drill, 1.79 BPM @ 3850 PSI 8,210.0 8,216.0 10:00 10:24 FS, BHP=4075, Hard to maintain differential pressure. Able to get all DHWOB. Tool is hanging up above bit. Mukiple pick ups to get back to bottom with Diff pressure 10/18/2018 10/18/2018 0.60 FROM DRILL WPRT T 8216, stacking out. PUH, PUW=50K. 8,216.0 8,216.0 10:24 11:00 Stuck @ 8190. Work pipe within limits of HOT. Seeing negative weight. Unable to orient. Work free. PUH to 8150. RIH to drill. Have to work 8178 down 10/18/2018 10/18/2018 1.40 FROM DRILL DRLG T 8216', Drill, 1.8 BPM 3995 PSI FS. 8,216.0 8,236.0 11:00 12:24 Returns coming and going. Start get gas in returns. Ship returns to tiger tank, Frequent pickups to get differential pressure. Unable to maintain steady state drilling 10/18/2018 10/18/2018 0.20 FROM DRILL WPRT T One of many pickups over pull and 8,236.0 8,236.0 12:24 12:36 stuck, Not showing any WOB. Able to orient freely. Work pipe. Little returns. Not showing any pull on HOT. Work free @ 70K 10/18/2018 10/18/2018 1.40 FROM DRILL WPRT T After pulled free BHA shorted out. 8,236.0 8,075.0 12:36 14:00 PUH to rased hole. Pump 10 X 10 sweeps. Circulate gas out of well Trouble shoot surface electrical componets. Shorted down hole 10/18/2018 10/18/2018 2.30 FROM DRILL TRIP T Trip out maintain 1 to 1. At 500' well 8,075.0 63.0 14:00 16:18 unloaded heavy shales. Jog back in hole. Pull to surface, Tag up and space out. Swap chokes and lost all . WHIP. Open up tangos. MP line showed zero. Open up whitey valve on riser. No pressure 10/18/2018 10118/2018 1.00 FROM DRILL TRIP T Trip in hole to find pack off / bridge 63.0 63.0 16:18 17:18 holding 1100 PSI WHIP. RIH to 750'.Saw nothing. Blleed off WHIP to 650 PSI. Bridge must be down much lower. POOH 10/18/2018 10/182018 1.30 FROM DRILL PULD T PUD BHA #6, DBV bent (pictures on 63.0 0.0 17:18 18:36 S: drive), bit came out a 1-3 (7 broken reamer cutters 8 1 plugged nozzle) 10/182018 10/18/2018 1.00 PROD1 DRILL PULD T Decision made to PU build assembly, 0.0 63.0 18:36 19:36 PD BHA #7 Build Assembly #3 (1.8" AKO motor, RR Dynamus bit, no RES tool), slide in cart, check pack -offs, MU to coil, tag up, set coutners 10/182018 10/18/2018 2.00 FROM DRILL TRIP T RIH w/ BHA#7, EDC closed, RIH 63.0 8,005.0 19:36 21:36 pumping anticipating bridge -off at unknown depth 10/18/2018 10/16/2018 0.20 PROD1 DRILL DLOG T Log Kt for -0.5' correction, PUW = 8,005.0 8,030.0 21:36 21:48 34K 10/18/2018 10/18/2018 0.50 FROM DRILL TRIP T Continue RIH, clean down to 8120', 8,030.0 8,100.0 21:48 22:18 pump 5x5 sweeps 10/18/2018 10/18/2018 0.40 FROM DRILL TRIP P Begin working through window, stack 8,100.0 8,133.0 22:18 22:42 8K WOB at 8133' (believe found bridge -off at window stopping flow to surface), allow sweeps to exit bit Page 5119 Report Printed: 311912019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log stat Depen Stat Time End Tore cur(hr) Phase Op Code Activity Code Time P -T -X OperaWn (fit®) End Depth (WO) 10/18/2018 10/19/2018 1.30 PROD1 DRILL TRIP T EDC open, POOH for FCO assembly 8,133.0 600.0 22:42 00:00 10/19/2018 10/19/2018 0.50 FROM DRILL TRIP T EDC open, POOH for FCO assembly, 600.0 63.0 00:00 00:30 tag up, PJSM 10/19/2018 10/19/2018 0.80 PROD1 DRILL PULD T PUD BHA#7, bit came out balled up 63.0 0.0 00:30 01:18 with clay from setdown at TOWS, 2 plugged n=les 10/19/2018 10/19/2018 1.20 PROD1 DRILL PULD T PD BHA#8 FCO Assembly (1.0°AKO 0.0 63.0 01:18 02:30 motor, D331 w/ ridge -set), slide in cart, check pack -offs, MU to coil, tag up, set counters 10/19/2018 10/19/2018 1.80 FROM DRILL TRIP T RIH w/ BHA#8, corrupt data on Baker 63.0 8,005.0 02:30 04:18 screen, trouble -shoot & resolve issue 10/19/2018 10/192018 0.10 FROM DRILL DLOG T Log K1 for +4.5' correction, close EDC 8,005.0 8,027.0 04:18 04:24 10/192018 10/192018 0.20 FROM DRILL TRIP T RIH to TOWS, PUW = 35K 8,027.0 8,130.0 04:24 04:36 10/19/2018 10/192018 0.70 PROM DRILL TRIP T FCO from TOWS, 1.8 bpm, FS = 360 8,130.0 8,163.0 04:36 05:18 psi, circ = 3792, BHP = 4080 psi, WHP = 780 psi, 390 Ib motorwork beginning at 8146', PUW = 37K from 8147', pull up through window. Continue in-hole to end of rat -hole (8163'), PUH to BOW, PUW = 37K 10/19/2018 10/19/2018 1.00 PROD1 DRILL TRIP T Continue FCO, 1.77 BPM. Set down 8,163.0 8,150.0 05:18 06:18 @ 8186, Pull heavy 52K, -6K DHWOB. PUH pack off RBIH to 8173. PUH to window. 10/19/2018 10/192018 0.10 FROM DRILL DLOG T Log RA for+1'correction 8,150.0 8,173.0 06:18 06:24 10/19/2018 10/192018 2.80 FROM DRILL WPRT T RBIH, stckout @ 8175 recip up hole to 8,173.0 7,960.0 06:24 09:12 8098. RBIH to 8216. Padkoff with overpull, 70K. PUH to 8150. RBIH to bottom @ 8234, Pumping multiple sweeps. Getting medium amount of shales on shaker. Pull up through window at full rate. PUH through 7" to 7960, 10/19/2018 10/19/2018 0.20 PROD1 DRILL WPRT T RBIH, clean pass through window 7,960.0 8,139.0 09:12 09:24 stack at 8175. PUH stuck at window 8139. 10/192018 10/192018 1.10 PROD1 DRILL WPRT T Work pipe out of window, PUH to 8,139.0 7,960.0 09:24 10:30 8070. RBIH dean through window. Stack out at 8175. Pick up sticky 65K with -17K DHWOB. PUH to TT at full rate with more sweeps 10/19/2018 10/19/2018 2.00 PROD1 DRILL WPRT T 7960 RBIH dean through window. run 7,960.0 8,063.0 10:30 12:30 past 8275 @ 4 FPM with 90% returns. Full returns back @ 8285. Continue to bottom @ 8126. Recipt twice to 8143. Pumping sweeps. Maintaining full returns. Hole looks clean. Not stacking or over pulls. Pump 10 X 10 sweeps 10/192018 10/19/2018 1.80 PROD1 DRILL WPRT T Sweeps out, Chase to swab. Jog @ 8,063.0 60.0 12:30 14:18 729' Hole unloading. Same shales as yesterday 10/19/2018 10/19/2018 1.50 PROD? DRILL WPRT T Tag up at surface, Set counters, RBIH 60.0 8,010.0 14:18 15:48 10/19/2018 10/192018 0.10 PROD1 DRILL DLOG T Log K1 for +11% PUW=32K 8,010.0 8,030.0 15:48 15:54 10/19/2018 10/19/2018 0.10 PROD1 DRILL WPRT T Continue in well. Clean through 8,030.0 8,234.0 15:54 16:00 window and past 8175 to 8185 area with returns Page 6119 Report Printed: 3 /1 912 01 9 Operations Summary (with Timelog Depths) 2G-06 ... Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Depen Steri Time End Time our (hr) Phase Op CMe AnOty C09 Time P -T -x Operation (MB) EM Depth (N(B) 10/19/2018 10/19/2018 0.40 PROD1 DRILL WPRT T PUH to 7", Clean trip through build 8,234.0 8,130.0 16:00 16:24 with no overpulls no packoff events. Start sweeps down CT 10/19/2018 10/19/2018 0.10 PRODt DRILL WPRT T Sweeps Gose to bit. RBIH to 8200. 8,130.0 8,200.0 16:24 16:30 Clean hip to 8200 10/19/2018 10119/2018 1.70 PRODt DRILL WPRT T Sweeps at bit, POOH pumping 1.8 8,200.0 63.0 16:30 18:12 BPM, PUW=33K, open EDC, PJSM 10/19/2018 10119/2018 0.90 PROD1 DRILL PULD T PUD BHA #8, mill came out 2.80" no- 63.0 0.0 18:12 19:06 go 10/19/2018 10/19/2018 1.00 PROD1 DRILL PULD T PD BHA #9(Build Assembly, 1.8'AKO 0.0 63.0 19:06 20:06 motor, RR P104 bit, & no res tool), slide in cart MU to coil, change out pack -offs, tag up, set counters 10/19/2018 10/19/2018 1.60 PROM DRILL TRIP T RIH w/ BHA#9, lost COMMS to BHA 63.0 7,975.0 20:06 21:42 at 4146', stop trouble -shoot, resolved 10119/2018 10/19/2018 0.60 PROM DRILL DLOG T Did not see K1 on first pass, PUH to 7,975.0 8,025.0 21:42 22:18 7975 to re -log, +34.5' correction 10/19/2018 10/19/2018 0.40 PROD1 DRILL TRIP T Continue RIH, PUW =38K, log RA for 8,025.0 8,236.0 22:18 22:42 1 1 +1' correction, bring up rate 10/19/2018 10/19/2018 0.80 PRODt DRILL DRLG P OBD, 1.88 bpm, FS = 525 psi, circ = 8,236.0 8,330.0 22:42 23:30 4313 psi, CWT = 13K, WOS = 1.8K, BHP = 4120 psi, WHP = 710 psi, pump sweeps, Begin packing off at 8330', losing returns 10/19/2018 10/20/2018 0.50 PROW DRILL WPRT P Wiper, PUW = 45K, continue to pull 8,330.0 8,050.0 23:30 00:00 heavy, working up & down to release pack -off, pulling up to 68K, density out drops, clear packoff, pull up through window, begin taking returns to TT, begin circulating bottoms up 10/20/2018 10/20/2018 0.50 PROM DRILL WPRT P Continue circulating bottoms up in 7" 8,050.0 8,050.0 00:00 00:30 casing, sweeps coming to surface, density out climbs to 8.94 ppg, bring returns back inside after 42 bbls Sample to geo: —50% ravings, remaining 50% mixutre of cuttings (shale & sand) 10/20/2018 10/20/2018 0.40 PROD1 DRILL WPRT P RBIH, stack weight at 8164', PUW = 8,050.0 8,175.0 00:30 00:54 38K, stack again at 8169', again at 8170', begin packing off, begin losing returns, pull -1 OK WOB, wiper to bottom of window, tum around 10/20/2018 10/20/2018 0.90 PROM DRILL WPRT P RBIH at 7 fpm, taking bites & PUH, 8,175.0 7,835.0 00:54 01:48 begin packing off at 8205', erratic returns, reciprcate pipe to Gear pack - off, PUW = 45K, pulling heavy up to 66K Pull up to tubing tail & circulate, 8.9 ppg slug over shakers, rate out drops while in 7", circulate bottoms up, pull 500' into tubing tail 10/20/2018 10/20/2018 1.40 PROD1 DRILL WPRT T Circulating, pins/ retaining -stops on 6 7,835.0 7,835.0 01:48 03:12 gripper block plates sheared pff, elastomers worn, circulate awaiting mechanic, 10120/2018 10/20/2018 4.70 PROD1 DRILL TRIP T POOH @ 50 fpm, EDC open 7,835.0 63.0 03:12 07:54 Decision made to POOH, replace failed gripper block plates & elastomers on Nabors rig repair time Page 7/19 Report Printed: 3/19/2019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start'rime End Time DW (hr) Phase Op Corte Aetroty Cede Time P -T -X Operatlon (fixe) End Depth(%KB) 10/20/2018 10/20/2018 1.60 PROD1 DRILL PULD T PJSM, PUD BHA #9, Lay down BHA 63.0 0.0 07:54 09:30 10/202018 10/20/2018 3.00 PROD1 DRILL RGRP T Conmue with repairs to chains, 0.0 0.0 09:30 12:30 Change out all elastomers Confer with town asset, drilling, & rig. Decision made to cleanout down to 7" & set backup " 8 ms; agreed upon for Nabors rig repair time (SIMOPS w/ replanning of second WS) 10/20/2018 10/202018 1.20 PROD1 DRILL PULD T Repairs complete, Start making up 0.0 0.0 12:30 13:42 build section BHA. Plan change going Ito run whipstock 10/20/2018 10/20/2018 0.90 PROD1 DRILL PULD T M/U BHA#10. FCO BHA with V motor 0.0 62.3 13:42 14:36 and D-331. Pressure deploy. Make up • to coil and surface test 10/20/2018 10/20/2018 1.80 PROD1 DRILL TRIP T Trip in hole to clean 7" casing for 62.3 7,995.0 14:36 16:24 whipstock set 10/20/2018 10/202018 0.10 PROD1 DRILL DLOG T 7995', Log K1 for- 1/2', PUW=39K, 7,995.0 6,031.0 16:24 16:30 1 1 Pumping sweeps 10120/2018 10/20/2018 1.80 PROD1 DRILL CIRC T PUH circulating sweeps DH 8,031.0 8,128.0 16:30 18:18 10/20/2018 10/202018 1.60 PROD1 DRILL TRIP T POOH, open EDC 8,128.0 62.0 18:18 19:54 10/20/2018 10/20/2018 1.00 PRODt DRILL PULD T PUD BHA#10 62.0 0.0 19:54 20:54 10/2012018 10/20/2018 1.90 PROD1 RPEQPT PULD T MU & PU HEW, PD BHA#11 (HEW 0.0 74.0 20:54 22:48 Whipstock #2), slide in cart, MU to coil, tag up, set counters 10/20/2018 10/21/2018 1.20 PROD1 RPEQPT TRIP T RIHw1BHA#11 74.0 5,400.0 22:48 00:00 10/212018 1021/2018 0.40 PROD1 RPEQPT TRIP T Continue RIH w/BHA #11, EDC open 5,400.0 8,015.0 00:00 00:24 10/21/2018 10/21/2018 0.10 PROD1 RPEQPT DLOG T Log K1 for -1' correction 8,015.0 8,043.0 00:24 00:30 10/21/2018 10/21/2018 0.40 PROD1 RPEQPT TRIP T Continue RIH, arrive at setting depth 8,043.0 8,103.8 00:30 00:54 (8103.78'), PUW = 38K, RBIH, close EDC, bring up pump, shear off @ 5100 psi, set down 2K on WS, PUW = 37K, TOWS -8095', oriented HS 10/21/2018 10/21/2018 1.40 PROD1 RPEQPT TRIP T POOH, EDC open, PJSM 8,103.8 65.0 00:54 02:18 10/21/2018 10/212018 1.10 PROD1 RPEQPT PULD T PUD BHA#11 65.0 0.0 02:18 03:24 10121/2018 10/21/2018 1.50 PROD1 WHPST PULD T PO BHA#12 Window Assembly (1.0° 0.0 77.0 03:24 04:54 AKO motor, string reamer, window mill), slide in cart, check pack -offs, clean up metal built around brass & pressure wash, MU to coil, tag up, set counters 10/21/2018 1021/2018 1.80 PROD1 WHPST TRIP T RIH w/ BHA#12, Tagged upon collar 77.0 6,025.0 04:54 06:42 @ 4965', Work through, Coninue in 10/2112018 10/212018 0.20 PROD1 WHPST DLOG T Log K1 for -1.5' corretion, PUW=36K, 8,025.0 8,046.0 06:42 06:54 close EDC 10/21/2018 10/21/2018 0.10 PROD1 WHPST TRIP T Continue in well, Dry tag pinch point 8,046.0 8,099.0 06:54 07:00 @ 6099, PUH 10/21/2018 10/21/2018 2.60 PROD1 WHPST MILL T Pumps on 1.8 BPM @ 4530 PSI FS, 8,099.0 8,100.4 07:00 09:36 BHP=4095. Call pinch point 8097.5. Start milling window per procedure Page 8119 Report Printed: 3/1 912 01 9 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log seat Depth Startllma rWTtne our (hr) Phase Op COED Astivay Cade Tena P -T -X Operation (flue) End Depth(Mul) 10/21/2018 10/21/2018 2.40 PROD1 WHPST MILL T Call BOW 8100.4 Time Milling 8,100.4 8,100.3 09:38 12:00 formation 10/21/2018 10/21/2018 1.50 PROD1 WHPST MILL T Milling rathole, Stall @ 8103.19 8,100.3 8,103.3 12:00 13:30 Restart and stall here again 10/21/2018 10/21/2018 4.40 PROD1 WHPST MILL T Continue milling rathole, 1.81 BPM @ 8,103.3 8,122.0 13:30 17:54 4620 PSI FS, BHP=4050 10/21/2018 10/21/2018 2.10 PROD1 WHPST REAM T Perform reaming passes 1 fpm 8,122.0 8,122.0 17:54 20:00 through window, 5fpm in rat -hole (HS, 30L, 30R, LS), dry drift up & down, clean 10/212018 10/21/2018 1.70 PROD1 WHPST TRIP T POOH, EDC open, lost WITS data, 8,122.0 77.0 20:00 21:42 trouble -shoot, reboot Canrig server, up & running. 10/212018 1021/2018 1.20 PROD1 WHPST PULD T PUD & LD BHA#12, mill came out 77.0 0.0 2142 22:54 2.79" no-go, string reamer came out 2.80" no-go 10/21/2018 1022/2018 1.10 PROD1 DRILL CTOP T Clear floor, MU nozzle, stab on & jet 0.0 0.0 22:54 00:00 stacK Sunday Safety Meeting in dog -house (SIMOPS) 10/22/2018 1022/2018 0.50 PROD1 DRILL CTOP T Break off nozzle, clear floor, break 0.0 0.0 00:00 00:30 1 1down & snake MM 10/22/2018 10/22/2018 1.30 PRODt DRILL PULD T PJSM, PD BHA#13 Build Assembly 0.0 62.0 00:30 01:48 (2.4° AKO motor, RR Hughes bit), MU to coil, check pack -offs, tag up, set counters 10/22/2018 10/22/2018 1.60 PROD1 DRILL TRIP T RIH w/ BHA#13 62.0 8,010.0 01:48 03:24 10/2212018 1022/2018 0.20 PROD1 DRILL DLOG T Log K1 for -1' correction, close EDC, 8,010.0 8,030.0 03:24 03:36 PUW = 38K 10/22/2018 10/22/2018 0.40 PROD1 DRILL TRIP T Continue RIH, did not find bottom at 8,030.0 8,136.0 03:36 04:00 8122', found it at 8136', stalled, PUW = 38K 10/2212018 10122/2018 0.80 PROD1 DRILL TRIP T PUH to log RA, did not see it & tag at 8,136.0 8,136.0 04:00 04:48 8134', PUW = 38, RIH to find bottom, stall 1022/2016 10/22/2018 0.30 PROD1 DRILL TRIP T PUH to log K1 & find RA. Log K1 for 0' 8,136.0 8,136.0 04:48 05:06 correction, do not see RA tag, PUW = 38K, PUH 10/222018 10/222018 0.20 PROD1 DRILL TRIP T Confer with town, attempt to find RA 8,136.0 8,136.0 05:06 05:18 an additional time, 10/22/2018 1022/2018 1.60 PROD1 DRILL TRIP T No sign of RA marker, POOH. Open 8,136.0 65.0 05:18 06:54 1 1 1 EDC @ 8024 10/22/2018 1022/2018 1.20 PROD1 DRILL PULD T Tag up / space out, PJSM. PUD BHA 65.0 0.0 06:54 08:06 #13 10/22/2018 10/22/2018 0.30 PROD1 DRILL BOPE P Perform Bi Weeekly BOPE function 0.0 0.0 08:06 08:24 test 10/22/2018 10/22/2018 3.10 PROD1 DRILL WAIT T Stand by for Caliper, Inspect CT .195 0.0 0.0 08:24 11:30 min wall thickness found. Pull all gripper blocks and check elastomers - Allgood 10/222018 1022/2018 1.00 PROD1 DRILL PULD T HES on location, M/U caliper and put 0.0 25.7 11:30 12:30 1 1 1 in well. Rig up HES computer 10/222018 10/22/2018 2.10 PROD1 DRILL TRIP T Trip in with BHA #14 HES caliper 25.7 8,029.0 12:30 14:36 10/22/2018 102212018 0.10 PRODt DRILL DLOG T Log K1 for+20, Continue in 8,029.0 8,050.0 14:36 14:42 10/22/2018 10/22/2018 0.10 PROD1 DRILL TRIP T Continue in well 8,050.0 8,126.0 14:42 14:48 10/22/2018 10/22/2018 0.30 PROD1 DRILL DLOG T 8126. run 2 logging passes up to 8,126.0 8,000.0 14:48 1506 8000' Page 9119 Report Printed: 3119/2019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth start Tme End Time D.(hr) Phase Op coda Actieily Coda Time P -T -x Operalion (N(6) End Depth(W13) 10/22/2018 10/22/2018 1.30 PROD1 DRILL TRIP T POOH with HES caliperr 8,000.0 25.0 15:06 16:24 10/22/2018 10/22/2018 1.50 PROD1 DRILL PULD T At surface, Lay down BHA#14 HES 25.0 0.0 16:24 17:54 caliper 10/22/2018 10/22/2018 0.20 PROD1 DRILLSF P Crew change, PJSM ice rig 0.0 0.0 17:54 18:06 valves 10/22/2018 10/22/2018 0.90 PROD1 DRILL P Servicerig v 0.0 0.0 18:06 19:00 ,00oRG 10/22/2018 1012212018 0.60 PROD1 DRIL PULD P PJ /U nozzle and stinger. Put in .0 16.8 19:00 19:38 rand and hook up coil. M/U injector to up 10/22/2018 10/22/2018 1.90 DEMOB P7VHDBOP DISP P Trip in hole. Seawater here load into 16.8 8,050.0 19:36 21:30 suction pit. Start pumping sewater time to get to nozzle @ 8050 10/22/2018 10/22/2018 1.60 PR WHDBOP FRZP P 10 BBIs seawater out of CT. T' ut. 8,050.0 17.0 21:30 23:06 Freeze protect from 2500' w' ,diesel 10/2212018 10/23/20180.9 RODt WHDBOP P P At surface, Tag up ands swabs. 17.0 0.0 23:06 00:00 Lay down BHA #15 1400 psi WHP 10/23/2018 10/23/2018 1.00 DEMOB WHD CTOP P Complete jedi ack&surface lines 0.0 0.0 00:00 01:00 10/23/2018 10/23/ 8 2.30 DEMOB DBOP CTOP P Await vavErew, crews prepping to 0.0 0.0 01:00 03: move oro -scope stack 10/23/2018 3/2018 1.00 DEMOB WHDBOP RURD P Set V 0.0 0.0 03:18 4:18 10/23/201 10/23/2018 2.70 DE WHDBOP RURD P ear floor, prep for move, await plan 0.0 0.0 04:18e78 07:00 onward 10/23 10/23/2018 2.50 MOB WHDBOP RURD P Freeze protect tree, work RD 0.0 0.0 07:009:30 checklist, ND BOPS " Rig Released: 10/23/18 @ 9:30 AM 3/5/2019 315/2019 4.70 MIRU MOVE MOB P Trucks on location, PJSM Pull off well. 0.0 0.0 13:00 17:42 Sub off @ 16:00, Pits off 16:45. DSO change out on location 17:30. Leave 3M 17:45 3/5/2019 3/6/2019 6.30 MIRU MOVE MOB P Travel to 2G 0.0 0.0 17:42 00:00 3/6/2019 3/6/2019 3.00 MIRU MOVE MOB P Travel to 2G 0.0 0.0 00:00 03:00 3/612019 3/6/2019 1.00 MIRU MOVE MOB P On 2G, De Jeep, Rig up cellar lay 0.0 0.0 03:00 04:00 hercu lite 3/6/2019 3/612019 2.00 MIRU MOVE MOB P Spot sub and pits 0.0 0.0 04:00 06:00 3/6/2019 3/6/2019 1.00 MIRU MOVE RURD P PJSM, Safe out rig. Start working rig 0.0 0.0 06:00 07:00 up check list 3/6/2019 3/6/2019 1.50 MIRU MOVE RURD P PJSM, R/U Putz, R/U Steam. R/U to 0.0 0.0 07:00 08:30 unstab Coil 3/612019 3/6/2019 1.50 MIRU MOVE OTHR P Unstab CT and secure to storage 0.0 0.0 08:30 10:00 spool 3/6/2019 316/2019 1.50 MIRU MOVE OTHR P remove riser from injector, remove 0.0 0.0 10:00 11:30 stuffing box, remove gripper blocks 3/6/2019 316/2019 3.00 MIRU MOVE OTHR P Disconnect Injector electrical service, 0.0 0.0 11:30 14:30 hydraulic lines, and instrumentation 3/6/2019 3/6/2019 1.50 MIRU MOVE OTHR P PJSM, Rig up injector to crane, Pull up 0.0 0.0 14:30 16:00 on injector unbolt cart bolts. Lift injector out of rig to ground 3/6/2019 3/6/2019 1.50 MIRU MOVE OTHR P Prep new injector for lift into dg 0.0 0.0 16:00 17:30 1 I I I 3/6/2019 3/6/2019 1.00 MIRU MOVE OTHR P Pick & set new injector onto rig 0.0 0.0 17:30 16:30 1 I I Page 10119 ReportPrinted: 3/1912019 . Operations Summary (with Timelog Depths) 2G-06 • Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depen Stan Time EM Time Dur(hr) Phase Op Code A Wty Code Time P.T.X Operabon (W) End Depth (RKe) 3/6/2019 3/6/2019 3.00 MIRU MOVE OTHR P Begin connecting electrial & hydraulic 0.0 0.0 18:30 21:30 lines, tighten/adjust goose -neck (Nabors electrician & Peter O'Brian houred out, went back to camp to rest), secure injector to cad 3/6/2019 3/7/2019 2.50 MIRU MOVE OTHR P Clear rig floor, slide injector back, NU 0.0 0.0 21:30 00:00 ROPE, continue connecting hydraulic lines, vis'd up seawater for window milling 3/7/2019 3/7/2019 1.50 MIRU MOVE OTHR P Grease surface valves in prep for BOP 0.0 0.0 00:00 01:30 test, install BOP riser 317/2019 3/7/2019 1.50 MIRU MOVE OTHR P Verify Koomey bottle levels, inspect 0.0 0.0 01:30 03:00 mud pump #1, fill injector fluids, grease master, swabs, & tangos, open up & inspect chokes (both look good) 3/7/2019 3/7/2019 3.00 MIRU MOVE OTHR P Clean up hammer union "ears", 0.0 0.0 03:00 06:00 change out mud -pump #1 worn valve/seat 3/7/2019 3/7/2019 7.00 MIRU MOVE OTHR P Crew change, Continue to hook up 0.0 0.0 06:00 13:00 injector, Complete MP #1 reconditioning 317/2019 3/7/2019 1.00 MIRU WHDBOP OTHR P Move injector // Prep for full BOPE 0.0 0.0 13:00 14:00 test. Test witness waived by Adam Earl, AOGCC 3/7/2019 3/72019 5.00 MIRU WHDBOP BOPE P Start full BOPE test, fail pass on 0.0 0.0 14:00 19:00 Tango 1 (250 psi low 14800 psi high) Working injector in SIMOPS (Nabors/Peter O'Brina/HydraRig rep) 31712019 3/7/2019 4.00 MIRU WHDBOP BOPE P Continue w/ BOP test, continue 0.0 0.0 19:00 23:00 injector tests in SIMOPS, install gripper blocks, perfrom draw -down ' test, laydown testjnt, clearfloor 3/72019 3/7/2019 0.20 MIRU WHDBOP OTHR P PU & install stripper & riser 0.0 0.0 23:00 23:12 3/7/2019 3/8/2019 0.80 MIRU WHDBOP OTHR P Crew change, PJSM, begin stabbing 0.0 0.0 23:12 00:00 coil, pull test crapple to 900 psi, good, remove reel chains, unlock reel, pull pipe through injector 3/82019 318/2019 0.80 MIRU WHDBOP OTHR P Complete stabbing pipe, break down 0.0 0.0 00:00 00:48 grapple, tugger line & snatch block, clear floor, injector error (motor differential detected), confer w/ O'Brein, continue running pipe through injector, break off nozzle 3/8/2019 3/8/2019 0.90 MIRU WHDBOP OTHR P Install UQC, re -head a -line & test, PT 0.0 0.0 00:48 01:42 UQC to 4500 psi 3/8/2019 3/8/2019 1.30 MIRU WHDBOP PRTS P MU nozzle, check pack -offs, stab -on, 0.0 0.0 01:42 03:00 test IRV & stripper Small hydraulic leak from stripper T - fitting (Gall out mechanic to repair) 3182019 3/82019 1.00 MIRU WHDBOP PRTS P PT tiger -lank line & PDUs, adjust 0.0 0.0 03:00 04:00 goose -neck 3/8/2019 3/8/2019 0.60 MIRU WHDBOP OTHR P Continue goose -neck adjustments 0.0 0.0 04:00 04:36 3/8/2019 3/82019 0.40 MIRU WHDBOP OTHR P Open up well, 1280 pdi, bleed off to 0.0 0.0 04:36 05:00 TT, slowly building pressure on MP line, blow down TT line 3/8/2019 3/8/2019 4.50 MIRU WHDBOP OTHR P Install checks, MU nozzle, RIH, 0.0 0.0 05:00 09:30 Pumping seawater returns to tiger tank. Recip while ARP making adjustments / taking readings. Do not run in deeper then 300' Page 11119 Report Printed: 3/19/2019 ; Operations Summary (with Timelog Depths) 1 2G-06 • Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Dam Start Time Erdlme Dur (hr) Phase op Cade Activity Cade Time P -T -X Openalbn ("a) End Depth(ftKB) 3/8/2019 3/8/2019 0.50 MIRU WHDBOP OTHR P Unstab injector. remove nozzle. M/U 0.0 0.0 09:30 10:00 pull plate. Pull test injector to 45K in IOK steps. Hold 45K. Relax coil. End of surface testing 3/8/2019 3/8/2019 1.30 PROD1 WHPST PULD P WU BHA#16 with Weatherford 7 0.0 77.2 10:00 11:18 fixed bend motor, 2.80 Dimond window mill, and RR string reamer 3/8/2019 3/8/2019 1.80 PRODI WHPST TRIP P RIH BHA#16, EDC open pumping 77.2 8,020.0 11:18 13:06 seawater @ .4 BPM. Monitoring injector 3/8/2019 3/8/2019 0.10 PROD1 WHPST DLOG P Log K1 for -2', PUW=30K 8,020.0 8,045.0 13:06 13:12 3/8/2019 318/2019 0.80 PROD1 WHPST CIRC P Displace coil I well to viscosified 8,045.0 8,066.0 13:12 14:00 milling fluid 31812019 318/2019 0.10 PROD1 WHPST TRIP P Continue in, tag lop of cement @ 8,066.0 8,085.0 14:00 14:06 8085, PUH 3/812019 3/8/2019 1.10 PROD1 WHPST MILL P Bring on pumps 1.8 BPM @ 3725 PSI 8,085.0 8,097.9 14:06 15:12 FS, Call TOC @ 8084. Tough to get going. Once going ROP - 20 FPH. Roll toolface to 10° ROHS to handle walking in mini pilot hole 3/8/2019 3/8/2019 2.30 PROD1 WHPST MILL P ROP stopped, Call this pinch point. 8,097.9 8,099.4 15:12 17:30 Roll TF to HS. 1.79 BPM @ 3757 PSI FS. Start time milling window per procedure / Northern soulotions rep (TOW = 8098.3. Hold at least 11.8PPG in rathole (per engineer) 318/2019 3/8/2019 2.30 PROD1 WHPST MILL P Continue milling window, CWT= 8,099.4 8,100.0 17:30 19:48 11.7K, WOB = 2.1K, annular = 3280 psi, pump = 4017 psi, 1 for 1 returns, milling slows down, PU from 8099.9', FS = 610 psi 3/8/2019 3/812019 1.40 PROD? WHPST MILL P Milling window, CWT =10.6K, WOB = 8,100.0 8,100.4 19:48 21:12 3.2K, annular =3281 psi, pump= 4101 psi, 1.8 bpm, bleed down IA, slow milling progress, NS rep requests WOB increase to 4K. " Pre -load ODS PDL 318/2019 3/9/2019 2.80 PROD1 WHPST MILL P Continued slow milling, PU per NS 8,100.4 8,101.5 21:12 00:00 rep, PUW = 27K, FS = 600 psi, begin seeing weight at 8,099.9' (made footage from last PU), call BOW @ 8101' (2.7' window) 3/9/2019 3/9/2019 0.60 PRODI WHPST MILL P Continue milling window from 8101.5', 8,101.5 8,102.3 00:00 00:36 CWT= 12K, WOB =.9K, annular = 3283 psi TOW= 8098.3', BOW= 8101' 3/9/2019 3/9/2019 2.40 PROD! WHPST MILL P String reamer exits window, milling rat- 8,102.3 8,124.0 00:36 03:00 hole, begin pushing on it, CWT = 10K WOB = 3.2K, increase ECD at window to 12.4 ppg, WHP = 549 psi, dirt in samples 3/9/2019 319/2019 1.80 PROW WHPST REAM P PUW = 27K, pump 5x5 sweep, 8,124.0 8,124.0 03:00 04:48 perform reaming passes, 2 HS, 30L, 30R, & LS, dry drift window up & down, clean, confirm rat -hole TD, pump 5x5 sweeps 3/9/2019 3/9/2019 1.60 PRODI WHPST TRIP P POOH, PUW = 28, open EDC 8,124.0 77.0 04:48 06:24 3/9/2019 3/9/2019 1.20 PROD1 WHPST PULD P At surface, tag up and space out. PUD 77.0 0.0 06:24 07:36 BHA#16. Mill out 2.79 No go Page 12/19 Report Printed: 3119/2019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth start Tune EM Time Dor(hr) Phase Op Gods Activity Code Time P -T4 Operation (WB) EM Depth(Uft) 319/2019 3/9/2019 0.90 PRODt DRILL CTOP P Make up nozzle and jet stack 0.0 0.0 07:36 08:30 319/2019 3/9/2019 1.40 PROD1 DRILL PULD P PD BHA#17 with 2.5° AKO motor and 0.0 72.2 08:30 09:54 RB HCC bit with Dynamus cutters. TX25207. PDL was preloaded. Make up to coil and surface test. Check packoffs. 31912019 3/9/2019 2.30 PROD1 DRILL TRIP P Trip in BHA# 17 to drill build / turn 72.2 8,005.0 09:54 12:12 1 1 1 section rolling CT to mud system #1 3/9/2019 3/9/2019 0.10 PRODt DRILL DLOG P Log K1 for -5.5' 8,005.0 8,033.0 12:12 12:18 319/2019 3/9/2019 0.70 PROD1 DRILL TRIP P Continue trip in. Complete fluid swap 8,033.0 8,124.0 12:18 13:00 Clean pass through window, Tag up and drill ahead @ 8124 3/9/2019 3/9/2019 3.10 PRODt DRILL DRLG P 8124', Drill, 1.8 BPM @ 4691 PSI FS, 8,124.0 8,259.0 13:00 16:06 BHP=3771, RIW=9.1K, DHWOB=I.5K 3/9/2019 319/2019 0.10 PRODt DRILL WPRT P 8259, BHA Wiper, PUW=28K 8,259.0 8,259.0 16:06 16:12 3/9/2019 3/912019 1.80 PROD1 DRILL DRLG P 8259', Drill, 1.9 BPM @ 4874 PSI FS, 8,259.0 8,403.0 16:12 18:00 BHP=3940 3/9/2019 3/9/2019 1.00 PRODt DRILL WPRT T PUW = 29K, allow DD to grab survey. 8,403.0 8,080.0 18:00 19:00 Discover bolt walked out on pillow - block, pull into cased hole to install, dragging -4K WOB through 8370' 3/9/2019 3/9/2019 0.50 PRODt DRILL DLOG P Log K1 for +45 correction, log RA at 8,080.0 8,140.0 19:00 19:30 8102' 3/9/2019 3/9/2019 0.20 PRODt DRILL WPRT P RIH to drill, 2.3K WOB spike at 8263', 8,140.0 8,403.0 19:30 19:42 1 RIW = 8.3K 3/9/2019 3/912019 0.30 PRODII DRILL DRLG P Drilling, FS = 600 psi, CWT = 6.6K, 8,403.0 8,450.0 19:42 20:00 WOB = 2.2K, bhp = 3980 psi, pump = 5078 psi, WHP = 522 psi (12.7 ppg @ window), pump 5x5 sweeps 319/2019 3/9/2019 1.70 PROD1 DRILL TRIP P POOH, PUW = 26K, clean through 8,450.0 72.0 20:00 21:42 build & window, open EDC, tag up, PJSM 3/9/2019 3/9/2019 1.30 PROD1 DRILL PULD P PUD BHA#17, once cart slid back, 72.0 0.0 21:42 23:00 lock -out storage reel, check and tighten hub & saddle clamp bolts, blow -down MM, bit came out 1-1, balledup, & 1 plugged nozzle 3/9/2019 3/10/2019 1.00 PROD1 DRILL PULD P Begin PD BHA#18 "A" Lateral 0.0 78.0 23:00 00:00 Assembly (NOV Agitator, 0.5` AKO motor, RB HYC A3 bit), lock -out injector, roll chains, checklinspect gripper blocks Note: Welll-ink moved forward 1 hr for DLS time prior to RIH (@ -23:00 hrs) 3/10/2019 3/10/2019 0.40 PROD1 DRILL PULD P Complete PD BHA#18, slid in cart, 78.0 78.0 00:00 00:24 check pack -offs, MU to coil, set counters 3/1012019 3/10/2019 1.50 PROD1 DRILL TRIP P RIH w/ BHA#18 78.0 8,015.0 00:24 01:54 3/1012019 3/10/2019 1.20 PROD1 DRILL DLOG P Log K1 for -5' correction, close EDC, 8,015.0 8,047.0 01:54 03:06 PUW = 28K (Note: Added 1 hour in this cell to account for daylight saving time) 3"0/2019 3/10/2019 0.30 PROD1 DRILL TRIP P Continue RIH, RIW = 9.5K, captured 8,047.0 8,450.0 03:06 03:24 agitator transducer screens Page 13119 ReportPrinted: 3/1912019 Operations Summary (with Timelog Depths) . 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Stan Time End Time Die(M Phase Dip Code AcWy Code Time P -T -X Operation (ill®) End Depth(Po(B) 3/10/2019 3/10/2019 1.60 PRODI DRILL DRLG P Drilling, FS = 940 psi Q 1.85 bpm, 8,450.0 8,663.0 03:24 05:D0 CWT = 7K, WOB = 1.7K, annular = 4006 psi, WHP = 595 psi, pump = 5382 psi, dp = 1347 psi, 1 for 1 returns, by-pass MM & blow -down again, -1/2"shale pieces from MM blow down 3/10/2019 3/10/2019 1.80 PRODt DRILL DRLG P Drilling, CWT =3.9K, WOB=2K, 8,663.0 8,900.0 05:00 06:48 annular = 4069 psi, pump 5505 psi, WHP = 496 psi, PUW = 28K from 8686' 3/10/2019 3/10/2019 0.60 PROD! DRILL WPRT P 8900', Wiper trip, PUW=29K 8,900.0 8,900.0 06:48 07:24 3/10/2019 3/10/2019 2.60 PROD1 DRILL DRLG P 8900', Drill, 1.9 BPM Q 5254 PSI FS, 8,900.0 9,172.0 07:24 10:00 BHP=4014 3/10/2019 3/10/2019 0.10 PROD1 DRILL WPRT P 9172', BHA wiper, PUW=31K 9,172.0 9,172.0 10:00 10:06 3/10/2019 3/10/2019 0.60 PROD1 DRILL DRLG P 9172', Drill, 1.9 BPM @ 5229 PSI FS, 9,172.0 9,300.0 10:06 10:42 BHP=4061 3/10/2019 3/10/2019 1.00 PRODt DRILL WPRT P 9300', Wiper to jet 7" and tie in, With 9,300.0 8,015.0 10:42 11:42 sweeps off bottom and another set in 7", PUW=30K 3/10/2019 3/10/2019 0.10 PROD1 DRILL DLOG P Log Tie in for+.5' 8,015.0 8,042.0 11:42 11:48 3/10/2019 3/1012019 0.60 PROD1 DRILL WPRT P Continue in well. Set down in build 8,042.0 9,300.0 11:48 12:24 -8124'. Work pipe, reduce rate momentarily to pass. Continue in 3/10/2019 3110/2019 0.50 PROD1 DRILL DRLG P 9300', Drill, 1.9 BPM @ 5240 PSI FS, 9,300.0 9,380.0 12:24 12:54 BHP=4107, RIW=3.2K, DHWOB=.8K 3/10/2019 3/10/2019 4.80 PROD1 DRILL DRLG P 9380', Started encountering Ankorite 9,380.0 9,705.0 12:54 17:42 stringers. ROP 200 FPH to 15' FPH back and forth. Better after 9540', drilled to called TD of 9705' 3/10/2019 3/10/2019 3.90 PROD1 DRILL WPRT P Pump sweeps, wiper to 7550' (500' 9,705.0 78.0 17:42 21:36 into 3-1/2"), RBIH to EOB, pump sweeps, pull into 7" & circulate bottoms up, complete wiper to swab 3/10/2019 3110/2019 1.50 PROD1 DRILL WPRT P RBIH 78.0 8,015.0 21:36 23:06 3/10/2019 3/10/2019 0.10 PROD1 DRILL DLOG P Log K1 for -3' correction 8,015.0 8,037.0 23:06 23:12 3/10/2019 3/10/2019 0.10 PROD1 DRILL TRIP P Continue RIH 8,037.0 8,085.0 23:12 23:18 3/10/2019 3/11/2019 0.70 PROD1 DRILL DLOG P SBHP: Depth_bit =8085', 8,085.0 8,085-0- 23:18 00:00 TVD sensor= 5893.3', annular= 4003, EMW = 13.075 ppg Attempt bleeding down 3 times, well climbs to -13.08 ppg each time Confer with town, drop to 12.7 ppg (3909 psi on annular), well climbs back to 13.13 ppg overtime 3/11/2019 3111/2019 1.50 PROD1 DRILL CIRC T Confer w/ town, begin circulating, 8,085.0 8,085.0 00:00 01:30 working KWF plan forward, working to find avalability of Micronized Barite & ammounts required for current lateral (mix recipe) 3/11/2019 3/11/2019 5.20 PROD1 DRILL CIRC T Identify Micronized Barite available in 8,085.0 8,085.0 01:30 06:42 Alpine, begin hot -shoeing from Alpine to MI plant, offload 12.8 ppg K - Formate from rig in clean truck to MI plant to be weighted up to 13.35 ppg, continue circulating at window Page 14119 Report Printed: 3/19/2019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SMDepth Start Time Ertl Time our (hr) Phase op Code Activdy Code Tune P -T4 operabon Y") End UeW(MB) 3/11/2019 3/11/2019 0.70 PROD1 DRILL CIRC T Shutdown pump. Monitir well, 13.1 8,085.0 8,085.0 06:42 07:24 PPG EMW 3/11/2019 3/11/2019 7.00 PROD1 DRILL CIRC T Continue to circulate waiting on KWF 8,085.0 8,015.0 07:24 14:24 3/11/2019 3/11/2019 0.40 PROD? DRILL DLOG P Log K1 for no correction 8,015.0 8,040.0 14:24 14:48 3/11/2019 3/11/2019 1.10 FROM DRILL TRIP P Trip in hole to condition hole, Get to 8,040.0 9,400.0 14:48 15:54 9408. Circulate 13.1 PPG Beaded liner running pill down CT. No setdowns or stacking. Hole in very good codition 3/11/2019 3/11/2019 0.70 PROD1 DRILL TRIP P 13.1 beaded liner pill at bit. PUH 9,400.0 7,867.0 15:54 16:36 pumping pill 3/11/2019 3/11/2019 1.00 PROM DRILL TRIP P RBIH to pump 13.3 WARP 7,867.0 8,450.0 16:36 17:36 3/11/2019 3/11/2019 1.70 PROD1 DRILL TRIP P Trip out pumping 13.3 K -Formate 8,450.0 65.0 17:36 19:18 W/micronized barite, Paint EOP flags 8304, & 6900 3/11/2019 3/11/2019 1.30 PRODI DRILL PULD P At surfae, Flow check well - Static. 65.0 0.0 19:18 20:36 Unstab injector. Lay down Drilling BHA #18, bit came out 1-2 & balled up 3111/2019 3/11/2019 0.90 COMPZ1 CASING RURD P Rig up floor to run liner, PJSM to run 0.0 0.0 20:36 21:30 liner 3111/2019 3/11/2019 1.70 COMPZ1 CASING PUTS P MIU BHA#19 A lateral completion with 0.0 1,061.0 21:30 23:12 non ported bullnose, 36 Jts slotted liner, and shorty deployment sleeve 3/11/2019 3/12/2019 0.80 COMPZ1 CASING PULD P PJSM, P/U coiltrak and WU to 1,061.0 1,061.0 23:12 00:00 completion 3/12/2019 3/12/2019 0.70 COMPZ1 CASING PULD P Complete PU liner running tools BHA 1,061.0 1,061.0 00:00 00:42 #19 3/12/2019 3/12/2019 2.20 COMPZ1 CASING RUNL P RIH w/BHA#19,-3.9'correction to 1,061.0 9,414.0 00:42 02:54 window flag, PUW = 30K, continue RIH to 9414', PUW = 35K, RBIH, PU slack, bring up pumps, release off liner, PUW = 29K 3/12/2019 3/12/2019 3.10 COMPZ1 CASING DISP P Displace well to drilling fluid, pumping 9,414.0 8,088.0 02:54 06:00 fluid to the bit at 0.25 bpm, 14.5 ppg at window 3/12/2019 3112/2019 2.30 COMPZ1 CASING TRIP P With drilling fluid at bit, begin 8,808.0 45.0 06:00 08:18 increasing rate, POOH 311212019 3/12/2019 1.00 COMPZ1 CASING PULD P PUD BHA #19, WHP = 1400 psi 45.0 0.0 08:18 09:18 3/12/2019 3/12/2019 1.10 COMPZ1 CASING PULD P PD BHA#20 Liner Run #2 (Anchored 0.0 72.0 09:18 10:24 Billet), slide in cart, check pack -offs, MU to coil, tag up, set counters 3/12/2019 3/12/2019 1.90 COMM CASING RUNL P RIH w/BHA #20 72.0 8,010.0 10:24 12:18 3/12/2019 3/12/2019 0.20 COMPZ1 CASING DLOG P Log K1 for -5.5' correction 8,010.0 8,046.0 12:18 12:30 3/12/2019 3/12/2019 0.50 COMPZ1 CASING RUNL P PUW = 24K, close EDC, continue RIH 8,046.0 8,052.0 12:30 13:00 w/ BHA #20, setdown 2K at 8102 twice (possible selling down on slips in bottom of window), orient 90° ROHS, again set down, PU & odent to 180°, get through. Arrive at set depth, PU slack, bring on pumps, shear off at 4900 psi, set down 4K, TOB -8340' 3/12/2019 j 3/12/2019 1.70 COMPZ1 CASING TRIP P POOH, PJSM 8,052.0 78.0 13:00 14:42 1 Page 15/19 ReportPrinted: 311912019 . Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log De slartoegn Stan roe 6s W ren Dw(hr) phase Op code Advity core ri me P-T-x Opeacm (rt End Depth (N(B) 3/12/2019 3/12/2019 1.00 COMPZI CASING PULD P PUD BHA#20 72.0 0.0 14:42 15:42 3/12/2019 3/1212019 1.10 PRODS STK PULD P PD BHA#21 AL2 KO/Turn Assembly 0.0 78.0 15:42 16:48 (2.3° AKO motor, RB Hughes bit) 3/1212019 3/1212019 1.30 PRODS STK TRIP P RIH wl BHA #21 78.0 8,005.0 16:48 18:06 3/12/2019 3/12/2019 0.20 PRODS STK CLOG P Tie into the Kt for a -5.5' con'ection. 8,005.0 8,035.0 18:06 18:18 3/12/2019 3/12/2019 0.20 PRODS STK TRIP P Close EDC 8,035.0 8,339.6 18:18 18:30 PU wt 25 k lbs, pass through the window, clean. ** Tag TOB - 8339.6'- WOB 2.4k 3112/2019 3/12/2019 1.00 PRODS STK KOST P PU Wt 28 k lbs, Set rate and RBIH 8,339.6 8,340.5 18:30 19:30 CT 4913 psi, aQ 1.83 bpm in, 1.83 bpm out, diff 614 psi. WH 660 psi, IA 30 psi, OA 358 psi, BHP 4073 psi holding 13.0 ppg EMW Q the window CT RIH Wt 9 it lbs, see motor work Q 8338.9' engage auto drill, WOB fell off to neg, bummed it up to see a little motor work and WOB, re-engaged auto drill at Vft per hr. 3/12/2019 3/12/2019 0.50 PRODS STK KOST P Increase to 2 it/hr. 8,340.5 8,341.5 19:30 20:00 CT Wt 8.3 it lbs, WOB 0.06 k lbs. 3/12/2019 3/12/2019 0.25 PRODS STK KOST P Increase to 3 Whr. 8,341.5 8,342.5 20:00 20:15 CT Wt 8.3 k lbs, WOB 0.06 k lbs. 3/12/2019 3/12/2019 1.35 PRODS DRILL DRLG P Drill ahead up to 230 R/hr, 8,342.5 8,464.0 20:15 21:36 Gamma Spike to 91 API, @ 8410'. Drilling dropped from 200 R/hr to 100 - R/hr over area then jumped back up. Resistivity pinched in as well. 8460' sudden drop in ROP to 8 ft/hr, resistivity suggests ankerite 3/12/2019 3/12/2019 0.20 PRODS DRILL WPRT P PU Wt 28k lbs, 8,464.0 8,322.0 21:36 21:48 Saw neg WOB to -1.2 it lbs, pulling up past 8410' Billet clean 3/12/2019 3/12/2019 0.10 PRODS DRILL WPRT P RBIH, Billet dry drift clean 8,322.0 8,464.0 21:48 21:54 Saw WOB spike to 1.5 k Ib @ 8410' 3/12/2019 3/12/2019 0.50 PRODS DRILL DRLG P CT 4731 psi Q 1.83 bpm in and 1.83 8,464.0 8,502.0 21:54 22:24 bpm out, diff 546 psi. WH 672 psi, IA 229 OA 400 psi, BHP 4116 psi holding 13 ppg EMW at the window. WOB 2.4 k CT 4.8 it lbs, ROP 13 ft/hr 8,468' break out ROP up to 200 +R/hr 3/12/2019 3/12/2019 1.30 PRODS DRILL DRLG P 8502', WOB stacked out, motor work 8,502.0 8,737.0 22:24 23:42 went away, PU 33k lbs - 8 k lbs over. Losses of 0.3 bpm. RBIH, tried to restart, had to PU again, 33k lbs, Ct wt. RBIH, New mud at the bit @ 8,528', Qa surface 8620'- 23:05 3/1212019 3/13/2019 0.30 PROD3 DRILL DRLG P Pi 35 it IDS, - 100' wipe, RBIH, 8,737.0 8,766.0 23:42 00:00 1 Drill ahead to midnight depth of 8766' 3/13/2019 3/13/2019 1.90 PRODS DRILL TRIP P PU, 28 it lbs, billet and window clean. 8,766.0 66.0 00:00 01:54 1 1 I Open EDC, continue OOH. 3113/2019 3/13/2019 1.30 PRODS DRILL PULD P Bump up, space out, PUD BHA # 21 66.0 0.0 01:54 03:12 3/13/2019 3/13/2019 0.40 PRODS DRILL BOPE P Vac down stack, Perform BOP 0.0 0.0 03:12 03:36 I function lest - good Page 16119 Report Printed: 311912019 Operations Summary (with Timelog Depths) �- 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth n De Start Time End Time Dur (hr) D Phase op Code Aclivky Cotle Time P -T -X Operation End Depth (flXB) 3/13/2019 3/13/2019 1.30 PRODS DRILL PULD P PD BHA# 22, check pack offs - good. 0.0 66.0 03:36 04:54 Bump up, set counters 3/13/2019 3/13/2019 1.50 PRODS DRILL TRIP P RIH, close EDC, shallow test agitator. 66.0 8,010.0 04:54 06:24 3/13/2019 3/13/2019 0.10 PRODS DRILL DLOG P Log K1 for -5' correction, PUW = 25K 8,010.0 8,042.0 06:24 06:30 3113/2019 3/13/2019 0.50 PRODS DRILL TRIP P Coninue RIH, see weight at 8153', 8,042.0 8,766.0 06:30 07:00 1 continue through, RIW = 1 O 3/13/2019 3/13/2019 0.50 PRODS DRILL DRLG P Drilling FS = 1200 psi @ 1.9 bpm, 8,766.0 8,783.0 07:00 07:30 CWT = 7.51K, WOB = 1 K, annular= 4113 psi, pump = 5444 psi, WHP = 691 psi, diff less than FS, PUW = 25K, grab new parameters 3/13/2019 3/13/2019 2.00 PRODS DRILL DRLG P Drilling FS = 1048 psi @ 1.9 bpm, 8,783.0 9,166.0 07:30 09:30 CWT =5.5K, WOB =1K, annular= 4142 psi, WHP = 718 psi, pump = 5300 psi, pump sweeps 3113/2019 3/1312019 0.30 PRODS DRILL WPRT P Wiper up -hole, PUW =28K 9,166.0 8,375.0 09:30 09:48 3/13/2019 3113/2019 0.30 PRODS DRILL WPRT P RBIH, RIW =8K 8,375.0 9,166.0 09:48 10:06 3/13/2019 3/13/2019 2.30 PRODS DRILL DRLG P Drilling, FS = 1060 psi @ 1.9 bpm, 9,166.0 9,566.0 10:06 1224 CWT = 4.81<, WOB = 1.51K, annular = 4169 psi, WHP = 723 psi, pump = 5466 psi, drilling w/ negative CWT shortly after wiper, pump sweeps Drop ECD at window to 12.9 ppg (rate in = 1.9 bpm, rate out = 1.96 bpm), unble to maintain 1 -for -1 returns, pinch back into 13.0 ppg 3/13/2019 3/13/2019 1.00 PRODS DRILL WPRT P Wiper to 7" casing, PUW = 27K, pump 9,566.0 8,010.0 12:24 13:24 additional sweeps time for EOB, (faulty pressure readings from DPS at -8280), clean past fault, slight negative pull through window 3/13/2019 3/13/2019 0.10 PRODS DRILL DLOG P log K1 for+1' correction 8,010.0 8,036.0 13:24 13:30 3/13/2019 3113/2019 0.50 PRODS DRILL WPRT P RBIH, dean through window, stacked 8,036.0 9,566.0 13:30 14:00 5.51K weight at 8223', PU, clean through, clean past billet, clean past fault at 8764', RIW = 5.3K 3/13/2019 3113/2019 2.50 PRODS DRILL DRLG P Drilling, FS = 1060 psi @ 1.88 bpm, 9,566.0 9,894.0 14:00 16:30 CWT = 5K, WOB = 1.5K, annular = - 4183 psi, WHP = 577 psi, pump = 5393 psi, losing -0.03 bpm, ran into low ROP beginning at 9611', breakout by 9644' 3/13/2019 3/13/2019 1.10 PROD3 DRILL DRLG P Drilling, CWT= -6.4K, WOB =1.6K, 9,894.0 10,009.0 16:30 17:36 annular = 4213 psi, WHP = 559 psi, pump = 5521 psi, PUW = 30K from 9914' Pump 10x 10 sweeps in anticipation of TD 3/13/2019 3/13/2019 0.60 PRODS WPRT P Discussion of extending TD, PU Wt 30 10,009.0 9,012.0 17:36 18:12 j j jDRILL j k lbs, pull wiper trip while deciding j path forward, to drill or TD. 3/13/2019 3/13/2019 0.80 PRODS DRILL WPRT P RBIH to drill 9,012.0 10,009.0 16:12 19:00 I I Page 17/19 ReportPrinted: 3/1 912 01 9 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth start Time EM Time Our (hr) Phase Op Cafe Activity Code 71me P -T -X Operetlon (ftKB) EM DepN (KKB) 3/13/2019 3/13/2019 4.10 PRODS DRILL DRLG P CT 5012 psi @ 1.83 bm in and 1.83 10,009.0 10,260.0 19:00 23:06 bpm out. Diff 911 psi. Drilling, CWT = 0 to -4 K, WOB = 1 K, annular = 4219 psi, WHIP = 586 psi Drill ahead with diminishing resistivity until Geo's called TD @10260. 3/1312019 3/14/2019 0.90 PRODS DRILL WPRT P PU Wt 35 k Itis, PUH chasing 10 x 10 10,260.0 8,368.0 23:06 00:00 TD sweeps up hole. 3/14/2019 3/14/2019 0.30 PROD3 DRILL WPRT P PU Wt 35 k Ibs, PUH chasing 10 x 10 8,368.0 7,554.0 00:00 00:18 TD sweeps up hole. 3/14/2019 3/14/2019 0.50 PRODS DRILL WPRT P RBIH to EOB staging 10 x 10 sweep 7,554.0 8,840.0 00:18 00:48 to the bit. 3114/2019 3/14/2019 1.00 PRODS DRILL WPRT P PUH chasing sweeps, Pull though 8,840.0 8,085.0 00:48 01:48 billet and window clean. Once in casing pump a bottoms up. 3/14/2019 3/14/2019 0.30 PROD3 DRILL WPRT P Park @ 8085.05, 5893.5 TVD, trap 8,085.0 8,085.0 01:48 02:06 4037 psi - pressure slowly falling, bleed to 3992 psi observe pressure stabalize @ 3987 psi, bleed to 3960 psi, pressure increased and stabilized 2 3983 psi -13.00 ppg 3/14/2019 3/14/2019 1.40 PRODS DRILL WPRT P Continue out of hole on swab wiper. 8,085.0 67.0 02:06 03:30 3/14/2019 3/14/2019 1.50 PROD3 DRILL TRIP P Bump up, set counters, RBIH 67.0 8,005.0 03:30 05:00 3/14/2019 3/14/2019 0.20 PRODS DRILL DLOG P Tie int the K1 for -5.5' correction, by 8,005.0 8,037.0 05:00 05:12 pass HP screens. 3/14/2019 3/14/2019 0.20 PRODS DRILL DLOG P RIH and park @ 8084.99' CTMD / 8,037.0 8,076.0 05:12 05:24 589345' TVD. Trap 4007 psi - bleed to 3989 psi and observed pressure stabilize at 3989 psi - 13.0 ppg PU Wt 25 k lbs 3/14/2019 3/14/2019 1.00 PRODS DRILL TRIP P RIH, confirm TD @ 10,261', PUW = 8,076.0 10,261.0 05:24 06:24 1 28K 3/14/2019 3/14/2019 2.90 PRODS DRILL DISP P Lay in15 bbl LRP (build from drilling 10,261.0 8,370.0 06:24 09:18 fluid, followed by 5 bbl of 13.1 ppg K- Fonnate spacer), followed by 13.35 ppg WARP to surface, flow check 3/14/2019 3/14/2019 1.20 PRODS DRILL DISP P LD BHA#22, PJSM, check pipe for flat 8,370.0 0.0 09:18 10:30 -spots (good) 3/14/2019 3/14/2019 3.70 COMPZ3 CASING PUTB P PU Liner (NP bullnose, 67 jnts slotted, 0.0 2,245.0 10:30 14:12 8 jnts blank, pup, & sealbore deployment sleeve), loss rate minimal 3/14/2019 3/14/2019 0.60 COMPZ3 CASING PULD P PU liner running tools BHA #23, slide 2,245.0 2,305.0 14:12 14:48 1 in cart, MU to coil, tag up, set counters 3/14/2019 3/14/2019 3.20 COMPZ3 CASING RUNL P RIH w/ BHA#23, slow down to reduce 2,305.0 9,370.0 14:48 18:00 losses (-.2 bpm @ 60 fpm), -4.9' correction to window flag, PUW = 30K, RIH, stack weight at 9618, PUW = 40K, work pipe at -9618', dragging negative WOB, stack at 9606', PUH heavy, losing hole, continue dragging heavy, sete down 9533', continue to work pipe, 3/14/2019 3114/2019 1.00 COMPZ3 CASING RUNL T Continue to work completion to 9,370.0 9,528.0 18:00 19:00 bottom. Snubbing up to -12 k lbs, PU Wts 48-50 k Itis, Neg WOB up to -23k lbs, was -10 k lbs in open hole. Picking up from 9513' PU Wt 60 k lbs, 20 k Itis over normal pick up. 3/14/2019 3/14/2019 1.00 COMPZ3 CASING WAIT T Discuss plan forward with engineering 9,528.0 9,503.0 19:00 20:00 support. Page 18119 Report Printed: 3/19/20191 . Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stan Tlme End Troia Dur (hr) Phase Op Code Fe fty Code TMP-T-X Operation (RKB) End Depih(WS) 3/14/2019 3/14/2019 2.00 COMPZ3 CASING PULL T POOH with AL2 liner and running 9,503.0 2,293.0 20:00 22:00 assembly, repaint white window flag @ 8003.54' Pumped 26 bbls KW to replace pipe voidage - 26 bbl of WARP remaining in pits. 3/14/2019 3/14/2019 0.70 COMPZ3 CASING PULL T LD AL2 liner running assembly -BHA 9,503.0 2,293.0 22:00 22:42 #23 3/14/2019 3/15/2019 1.30 COMPZ3 CASING PULL T LD 8 solid joints and 8 slotted joints 2,293.0 1,767.0 22:42 00:00 1 1 1 fill hole - 1 bbl 3/15/2019 3/15/2019 1.00 COMPZ3 CASING RUNL T LD 20 slotted joints, Fill hole 1 bbl 1,767.0 1,150.0 00:00 01:00 3/15/2019 3/15/2019 0.40 COMPZ3 CASING PUTS T PU 8solid joints 1,150.0 1,402.0 01:00 01:24 3/15/2019 3/15/2019 0.80 COMPZ3 CASING PULD T BHA#23, AL@ liner running assembly 1,150.0 1,447.0 01:24 02:12 - second attempt. 3/15/2019 3/15/2019 1.50 COMPZ3 CASING RUNL T RIH with AL2 completion, 85 ft/min 1,447.0 7,159.0 02:12 03:42 running speed with minimal losses, 0.07 bpm. Tie into the window flag for 6.78' correction. 3/15/2019 3/15/2019 1.20 COMPZ3 CASING RUNL T Continue to RIH, PU Wt 28 k lbs, 7,159.0 9,402.6 03:42 04:54 WOB -9.5 k lbs, RIH, drive by yellow TD flag for +3'correction. PU Wt 32 k lbs, unable to RBIH, PU wt 40 k lbs, RBIH to 9402'. Pump 1.34 bpm, CT 5608 psi, diff 1034 psi, PU Wt 23 k lbs, 3/15/2019 3/15/2019 2.40 COMPZ3 CASING DISP P Park, reset counters, displace well 9,402.8 2,500.0 04:54 07:18 bore to seawater 3/15/2019 3/15/2019 1.80 COMPZ3 CASING FRZP P PJSM, freeze protect from —2500' to 2,500.0 50.0 07:18 09:06 1 1 surface 3/15/2019 3/15/2019 1.00 COMPZ3 CASING PULD P PUD BHA #24 (SITP = 1461 psi) 50.0 0.0 09:06 10:06 3/15/2019 3/1512019 0.90 DEMOB WHDBOP CIRC P M/U nozzle stab on injector and flush 0.0 0.0 10:06 11:00 BOPE and rig surface lines 3/15/2019 3/15/2019 1.00 DEMOB WHDBOP RURD P Break off injector, vac stack, freeze 0.0 0.0 11:00 12:00 protect tree, secure injector, begin RD checklist 3/15/2019 3/15/2019 3.00 DEMOB WHDBOP NUND P Continue RD check list, off-load fluids 0.0 0.0 12:00 15:00 from rig, swap out Tango valves, ND BOP NES trucks arrive at 1400 hrs (to move shop & 112-way house ahead of dg) " Rig Release: 3/15 @ 1500 ms Page 19119 Report Printed: 3/19/2019 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 2G Pad 2G-06AL2 50-029-21121-66 Baker Hughes INTEQ Definitive Survey Report 10 April, 2019 BAKER gUGHES E-,,,, V102019 92623AM Pogo 2 COMPASS 500014 Budd BSD Conocc Phillips b 9 ConocoPhilli iK Definitive Survey Report Compaly: ConamPhilnps Alaska lnc Kuprouk Local Coordinate Reference: Wen2G-06 pro)am Kupamk River Unit TVD Reference: 2G46®140.00usg(ZG-06) SM: Kupamk 2G Pad MO Reference'. 2G46 a 140.00usfl (23-06) Wei 2G06 North Reference: True Weubore: 2G06AL2 Survey calculation Method: Minimum Curvature Design: 2G-06AL2 Database: EDT 14 Alaska Production Profess Kupemk River Und, North Slope Alaska, United Stales Map System: US State Plane 1927 (Exact solution) System Datum: Mean See Level Gen Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaske Zone 04 Using geodetic scabfactor Wen 2G-06 Well Peahen tN1S 0.00 usfi Northing: 5,9b,135.21usR Latlmde: 70° 15'30.911 N .E -W 0.00 usfi basting: 508,929.90usfl Longitude: 149°55'40.165W Position Uncertainty 040 usfi Wellhead Elevation: Usfl Ground Level: 0.00 Usfl Wadbore 2G-06AL2 Magnetise Model Name Sereple Dam Declination Dip Angla Field Strength V) (nn EGGM2018 41112019 16.57 80.80 57,411 Design 2G-06AL2 Audit Notes: Version: 1.0 Phase: ACTUAL Te On Depth: 8,333.18 Vertical Section: Depth From IWO) rWS a m Direction (oaf) (USR) lam) ('1 140.00 0.00 0.00 18000 V102019 92623AM Pogo 2 COMPASS 500014 Budd BSD ConocoPhillips % Conoco II1�IIp5 Definitive Survey Report Company: ConocoPhili,s Alaskalnc_Kupamk Local Coordinate Reference: MR 2G-06 Profen: Kupamk Rear Unit TVD Reference: 2606@140.00usB(2(3) ) SNe: Kupamk 2G Pad MO Reference: 2G-06@ 140.00uae(242-06) Well: 2606 North Reference: Tree Wellbore 2G-WAl3 Survey Calculation Method Minimum Curvature Design: 2GOUi Database: EDT 14 Alaska PmEuclem Survey Pmgmm Date From To Survuy Sunni (uen) (..ft) Suney(Wellbon) Tool Nems Description SmR Dab End Dab 20000 8,000.00 2G-06(26-06) SEEKER MS BHI Seeker muleshot 1/12/2001 8095.00 8,212.80 2G -06A MWD -INC (2G -06A) MW INC_ONLY MV INC ONLY FILLER 3192019 3192019 8242.71 8,333.18 2(3-00.4 MyVO(2G-0BA) MWD MWD -Standard 3/102019 3/1012019 8340.00 8,396.92 2G-06AL2 MM-INC(2G-06AL2) MW INOQONLY MWD-INCONLY FILLER 3/132019 3/132019 842840 10,224.62 2G -OMI -2 MM(2G-06AL2) MWD MWD-StandaM 31142019 3114/2019 Survey Map Map Vertical MD bra 1lN TVD TVO86 0WS ♦E14F Northing Eastin9 DLS Section luslp (9 (1 (UFM (11811) (USM loan) (°1100') Survey Tool Name QfInOt811Do (R) IDI ID) 0.333.'0 75.07 4TSS 6,030.23 5,890.23 3502.15 3.76805 5.96],54148 512.593.42 9959 -3,502.15 umv(3) TIP 0,390.00 75.07 4697 6031.93 5.09180 3,506.63 3,772,09 5,947,60.5.96 512698i25 5.0 41,5411 MANO-114C ONLY (4) KOP 0,311&54 00.53 57.9E 6635.19 5,096.19 3,525.16 3,795.39 5,941,600.52 512,20.73 51.21 41525.16 MWD -INC ONLY (4) Inter olamd Azimuth 039&92 WS7 60.60 6,039.04 5,89004 3,590.56 3019.99 5,917.880.31 512,45.31 44.02 41,540.00 MWDINC ONLY (4) Intep.hited A3lmNh 642890 95.65 8161 6.029.92 500992 3,551.11 3WAS 5.947,61a.53 512772.0.5 28.44 .3554.11 MID 8.45&62 90.10 70.21 6,02830 5,88&30 3,562.67 3,87499 5,90,702.11 512,803.20 40.43 d,552.67 MWD(5) 8487.95 MR7 91.05 6,028]7 5,080.17 3,565.41 3,904.13 594170489 512,02841 40.49 41555.41 MD (5) 851899 00.22 105.10 6,OID]6 5,809.76 3,551.13 3,934.27 5941106.04 512.859.56 45.98 41561.13 MD (5) 8.549.14 119102 117.33 B.M51 5,89051 3,550.116 3.96210 5,941.689.61 51200800 39.90 41.MDOS MWD (5) 8579.16 88,25 129.92 6.wlPm 5.88132 3.533.40 3.90132 5.941,673.06 51291303 42.00 $,Wa" MWO(5) &6%]2 90.12 14167 6.01.84 5.89165 3.51239 4.001,26 5,941,651.90 512.933.59 4091 .151229 MWD (5) 8639.39 9166 15339 6,m1.17 589117 3,4116.43 002065 5,947,628.01 51295001 3189 J,486.43 MWD(6) 5689.II 89.79 100.11 6,030.19 5,8110.79 3,458.67 4035.42 5.947,698.32 512,%082 WS7 -3,458.67 MWD(6) B,6S"S.40 91.75 17592 603038 5000.33 3429.00 404063 5,941568.66 512,966.05 39.47 41429.03 MNO(5) 0,28.M 09.18 View 6,030.07 5893.07 3,3%.12 4,039.63 5,947,539.31 512,955.09 4186 - RN.n MND(5) 0,161.86 88.31 2N 80 6030.69 5,000.89 3,385.95 4,030.811 5,947,508.60 512.958.36 49.47 400&95 MNO(5) 8,760.98 81.70 2IXV6 6,0318 5891.8 334187 4,011.91 5.9,17,481,61 512,w.H 2.00 -3 341.87 MMD(5) 8.821.94 86.04 20091 6,033.41 5,09041 SM328 4,001.15 5,947.952.91 512,932,3 1064 41.313.20 MD 0,85160 07.91 199.01 60M.W 5,09600 3,285.07 3,996.92 5,947,4M69 512,922.52 886 .120507 MIND (5) M02019 926:23AM Papa 3 COMPASS WOO, 14 Build 850 ConoCOPhillips ConocoPhillips Definitive Survey Report BA<ERuCHES 4 Comparry: ConomPhillips Alaska Inc_Kupamk Local Co-ordinate Reference: Wall 2G-06 PmfecL Kupamk RNer Unit TVD Reference: 2G06®140.00usg(2G-06) Site: Kupamk 2G Pad MD Reference: 26-06®140.00usg(2G-O6) Well: 26.06 Noon Reference: True Wellbore: 2G-06At-2 survey calculation Method: Minimum Curvature Design 2G 6At2 Daubase. EDT 14 Alaska Production Survey 4/10¢019 926:23NM Page 4 COMPASS 5000.14 B,dd 85D MD Inc Av ND WDSS sNfS +Elm Noon], Easting 135 Section (use! 1°I I°) (usn) fuse) (usftl (aaR) (n) IR) (°a09) Survey Tool Name Annotation fill 866156 6331 1.. 603599 569599 3256,42 396]62 5.94]3.03 51291346 St13 1.256,42 MWD (5) 8,911.83 82.67 19133 6,03705 5692.05 3,22].20 3,980.14 5.94236680 512.905.23 912 1,222211 "D (5) 8.940.65 86.16 15010 6,03860 569360 3.1004 3,92446 5,942.33364 512,898.92 1299 -3,199.14 "D (5) 8,920.65 86.32 182.14 6.M0.03 5,96003 3169.44 3969.9 4942.30903 512,395.25 1392 J.109.44 MW➢(5) 9,141,43 86.9 IES12 6,040.14 5,900.90 3,137,8T 3.90499 5,942277.48 512.891.2! 308 3,132.02 MND(5) 8.02,12 BB.24 10223 6,04182 5,901.62 3.10321 3,953.96 5,942.242.80 512,809.22 0.02 J.106.21 MtND(5) "Pas" aalst 114.92 8,04239 5,902.39 3.02486 396290 5.942,214,52 92880]5 5. yW4,96 aMo(5) 9.97.02 86.96 129.34 6,043.62 5,903.62 3.04336 3,96263 5,942,18295 5126838 212 -3043.25 MMIt(5) 9,130,32 Kea 128.% 0.04fi-0.5 59%.05 3.01016 3863.44 5,947149.75 512.86932 7.23 4010.16 MMO(5) 9,160.2! 85.20 172.12 6,046.59 5,908.59 2,979.93 3,964.53 5,942,119.54 512,891n 5.67 -0,979.93 IAMD(5) 9.190.71 0294 175.90 605026 5.91036 2,950.05 3,986.36 5,947 MISS 512,89235 849 3,950.05 MM (5) 9,211,18 8985 174.63 6050.84 5910.84 2919.69 3,560.90 5,942,059.32 512894.94 7.97 -2919.09 MD (5) 9,25508 B7.G2 12254 6,051.7 5.911.77 2.0%.03 3,98.24 5,947,M,66 512,090.81 10.86 -2.805.% MD (S) 928530 .59 171.70 6.053.99 5.913.99 2,85610 3,9mm 6945,995.74 51290299 8.14 3.0%.10 MD (5) 931540 8665 1'%2.% 6.055.20 5,.1625 2026.45 39..95 5,946,9%1. 51290210 7.57 -2,82645 MD 9,345.25 0905 124.16 6,057.19 SEVA9 2296.86 3,884.]7 499693651 512,910.55 1186 -2.796.85 MWD (5) 9325.16 89.08 176.82 6.052.42 59P.42 2,267.00 3,986.8 5,9M,9W.% 512.912.84 924 -2.26214 MWD(5) 940513 90.86 12840 6,057.40 591248 2,]3206 3,907.97 5.914,8]8,72 512.91433 794 -2.232.0G MWD(5) 9,435% 93.69 129.66 30:@20 5,91628 2,705,66 3.9NA9 5.946,84633 512.91478 1010 -2.706.65 al D(5) 9,4 tiol 93.90 10262 6.054.33 5.91433 2622.26 2.0280 5,914,816% 512914,23 ions -2,627.28 MPoD(5) _ 9494.98 9350 13527 6,862.39 591239 2642.45 3,93565 5946.78212 512,912.21 8.92 -2.64745 MWD(5) 99532 94.37 18841 6,060.31 5,81031 261239 3,902.32 5946)52.05 512918.8 9.72 -2,617.39 MMD(5) %%7m 14]4 191.31 6M273 5807.23 258552 3.976.82 5946.215.18 92.903.50 9.90 -2.685.52 MND(5) 9.5910$ 94.06 18362 6,045,18 5,905.18 2,55263 3.971.12 5,946.692.49 512.097.60 0.32 -2,%2.03 MhD(5) 961502 9106 106.86 BrW.32 590,1.32 2529.% 3,95322 5,946.%0.8 512894.]2 22II -2.529.05 MMD(5) 9,64537 8314 10406 6,04347 5.90346 2498,02 3,96505 5,94683B.4B 512,89'139 1071 249362 MMD(5) li'mom 92.. 18216 6,04184 5,.164 2463.67 3,%394 5946 3.33 512,814,52 543 -2453.67 MMD(5) 9,211.11 91.8 170.7) 6.04043 5.90043 243321 3,963]2 5,946.572.87 513.89133 11.91 -2,433.21 MND(5) 974072 92.4] 176.62 603902 5,899.87 2403.58 3,964.93 5,946.843.25 512,89130 8.25 -2,143.9 MMD (5) 92698 93.74 174.07 8.039.9 5,899.58 237423 3.95728 5,948.514.41 612.893,% 387 132473 anon (5) 9.0.61 9680 171.52 6039.14 5,599,15 2.344.09 3,97114 6946.48377 512.BW-05 310 -234414 MWD M) 4/10¢019 926:23NM Page 4 COMPASS 5000.14 B,dd 85D ConocoPhillips ER O ConocoPhillips Definitive Survey Report Company: Cenci Alaska lnc Kupamk Pmjacn Kupamk River Unit SM: Kupamk 2G Pad well: 2( 0W Wellbore: 2G-06AL2 Des19n: 2G-0IiAL2 survey Local COordinala Rafara i We112G-06 TVD Intercnce: 2, 0M C 141 (2&M) MD Reference: 2GA6 ®140.01(2605) North Reference: Tme Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Producfian VFOW19 9'26'23AM Page 5 COMPASS 5000.14 BUM 85D Map Map Vertical MD Inc AL TVD TVDSS 4k94 -i Northing Eastin ° DLS Section Survey Tool Name Annotation (usft) 1°I V) lasft) (waft) (-14) (.an) (n) Ift) 1°11001 Ift! 9630]] an 1.57 enol 5a.. 2,314.39 39]6.34 5946454.08 51290309 1087 231439 MWD i5) 9.060.89 91.41 167.W 6,clil]M 5,89579 2285.14 3,86265 594542484 512,90944 8.01 3,205.14 MOD (5) 9,890.63 91.84 164.% 6,037.94 5,09794 2,25513 3,98&98 5.946.395.84 512.916.80 B50 -2256.13 MWD(5) 9,920.23 91.83 162.78 6037.05 5,887.05 222].]4 3,89030 5,946.35]45 512825.16 &as -2.M7.74 Meet (5) 9,950]8 90.61 18136 6036.45 5,88545 2198.69 4,06]]3 5,946,33843 512,934.62 599 3.19&69 am (5) 9,895.10 Who 157.89 6.035.37 5,895.37 2,157.08 4.023.22 5,946,285.85 512,85016 7.92 Q157.08 MND(5) 10,025.21 66.99 154.88 6,036.74 5.80]4 2,129.37 4034.]] 5,946,26914 512,961 346 8.128.46 MWD(5) 10.05544 89.60 1..01 6,037.11 5,897.11 2,10136 4,045.8] 5,946.24103 512,462.87 1055 410126 MWD (5) 100855] 8001 1..56 6,031"73 5,89]]3 2,08.90 4,0%.03 5,946$12]1 512,9&3,06 5.51 3,0]2. MD (5) 10,11466 Who 162.67 6,039.03 569900 2.045.32 4065.19 5,94&185.14 512.99225 8.08 -2.045.32 MWD(5) 10,14478 6545 10.53 6.040.99 5846.89 2,016.56 407392 5,946.15&40 513,00102 5.n -2,1 Mr4D(5) 10.174.65 8328 16508 6,46).93 5,903.93 1Watt 408187 5,940,4]5] 513,003.11 8.90 -1,96i92 MND(6) 10.034.35 6295 168,10 6,047.49 5,90.49 1,9592] 4088,80 5,8450.13 51301587 10.17 -1869.9 mran(5) 10224.62 63.11 1... 6,049,95 5,946.95 1,1 4,09210 59450n940 513019.88 739 -1,939.53 MJvi 10,281.46 8311 16960 605431 5,91431 1904.01 40%22 5.946043.89 513,0m.45 000 -1,804.01 PROJECTED b TD VFOW19 9'26'23AM Page 5 COMPASS 5000.14 BUM 85D BA ER PRINT DISTRIBUTION IL,IST J�U HES a GE company COMPANY ConocoPhiilips Alaska, Inc. WELL NAME 2G-06AL2 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(& akerhughes.com STATUS Final Replacement: COMPANY ADDRESS (FEDE)CVALL NOT DELIVER TO P.O. BOX) PERSON ATTENTION l t BP North Slope. EOA, PBOC, PRB-20 (Office 109) D&G WO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPbillips Alaska Inc. A": Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 F,ssonMobil, Alaska Attn: Lynda M. Vaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska -AOGCC Attn: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alasle 99501 21 9021 30 609 ie sign and return one copy of this transmittal form to: xoPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) G Street. braze, Alaska 99510 LOG TYPE GR - RES LOG DATE March 14, 2019 TODAYS DATE April 12, 2019 Revision No Details: Rev. Requested by: --- FIELD I FINAL CD/DVD FINAL PRELIM (las, dlis, PDF, META, SURVEY REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES # OF COPIES # OF COPIES 9 4 is 4 4 4 AOGUU 5. DNR - Division of Oil & Gas .** Atm: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material deliver in DNR 6� BP Exploration (Alaska) Inc. Petrotechnical Data Center, Lk 900 E Benson Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 BAF IGHES BAT GE company 21 90'2 30605 Letter of Transmittal Date: —------ -- - April 12, 2019 Abby Bell AOGCC 333 West 7" Ave, Suite 100 Anchorage, Alaska 99501 Harvey Finch Baker Hughes, a GE Company 795 East 941" Avenue Anchorage, Alaska 99515 se find enclosed the directional survey data for the following well(s): 2G -06A 2G -AL2 LP (2) Total prints RECEivED APR 15 2019 AOGCC Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Harvey Finch, Baker Hughes, Wellplanner Harvey.Finch@BakerHughes.com ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 2G Pad 2G-06AL2 50-029-21121-66 Baker Hughes INTEQ Definitive Survey Report 10 April, 2019 BA ER I UGHES a GE company 219011 30606 Conocolahillips BA�KER ConocoPhllllps Definitive Survey Report f l4e Company: ConocoPhillips Alaska Inc—Kuparuk Project Kuparuk River Unit Site: Kuparuk 2G Pad Well: 2G-06 Wellbore: 2G-06AL2 Design: 2G-GSAL2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum Geo Datum: NAD 1927 (NAOCON CONUS) Map Zone: Alaska Zone 04 Well 2G -O6 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Position -NI-S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 2G-06AL2 Magnetics Model Name Sample Date BGGM2018 4/1/2019 Design 2G-06AL2 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 140 00 Well 2G-06 2G-06 @ 140.00usft (2G-06) 2G-06 @ 140.O0usft (2G-06) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,944,135.21 usft 508,929.90usft usft Declination (1) 16 57 Tie On Depth: 8.333.16 +N/ -S (usft) 0.00 +E/ -W (usft) 0.00 Latitude: Longitude: Ground Level: Direction (1) 180.00 f 70° 15' 30.911 N 149° 55'40.165 W 0.00 usft Field Strength (nT) 57.411 4/10@019 9:26:23AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips Company: ConocoPhillips Alaska Inc Kuparuk Project: Kuparuk River Unit Site: Kuparuk 2G Pad Well: 213-06 Wellbore: 2G-06AL2 Design: 2G-06AL2 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: Well 2G-06 TVD Reference: 2G-06 @ 140.00usft (2G-06) MD Reference: 2G-06 @ 140.00usft (2G-06) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production 6A�u(IF? 0 Survey Program � Date From TO Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 8,000.00 2G-06 (2G-06) SEEKER MS BHI Seeker multishot 1/12/2001 8,095.00 8,212.80 2G -06A MWD -INC (2G -06A) MWD -INC -ONLY MWD -INC -ONLY -FILLER 3/9/2019 3/9/2019 8,242.71 8,333.18 2G -06A MWD (2G -06A) MWD MWD - Standard 3/10/2019 3/10/2019 8,340.00 8,398.92 2G-06AL2 MWD -INC (2G-OBAL2) MWD -INC -ONLY MWD -INC -ONLY -FILLER 3/13/2019 3/13/2019 8,42940 10,224.62 2G-06AL2 MWD(2G-O6AL2) MWD MWD - Standard 3/14/2019 3/14/2019 ( Survey 6{{i Map Map Vertical MD Inc Azi TVD TVDSS +N/-S+E/-W Easting DLS Section (usR) 1 °I (°) (usft)Northing (usft) (usft) (usft) (°1100') Survey Tool Name Annotation (ft) (ft) (R) I 8,33348 75.07 47.39 6,030.23 5,890.23 3,502.15 3,768.05 5,947,641.48 512,693.42 49.59 -3,502.15 MWD (3) TIP 8,340.00 75.07 46.97 6,031.98 5,891.98 3,506.63 3,772.89 5,947,645.96 512,698.25 595 -3,50663 MWD-INC_ONLY(4) KOP 8,369.54 88.53 53.96 6,036.19 5,896.19 3,525.16 3,795.39 5,947,664.52 512,720.73 51.21 -3,525.16 MWD-INC_ONLY (4) Interpolated Azimuth 11 8,398.92 99.87 60,68 6,034.04 5,894.04 3,540.96 3,819.99 5,947,680.34 512,745.31 44.82 -3,540.96 MWD-INC_ONLY(4) Interpolated Azimuth 8,42940 95.65 67.61 6,029.92 5,889.92 3,554.11 3,847.15 5,947,693.53 512,772.45 26.44 -3,554.11 MWD(5) 8,458.62 90.40 78.21 6,028.38 5,888.38 3,562.67 3,874.93 5,947,702.11 512,800.28 40.43 -3,562.67 MWD (5) 8,487.95 88.07 91.05 6,028.77 5,88877 3,565.41 3,904.13 5,947,704.89 512,829.41 44.49 -3,565.41 MWD (5) 8,518.49 88.22 105.10 6,02976 5,889.76 3,561.13 3,934.27 5,947,700.64 512,859.56 45.98 -3,561.13 MWD(5) $549.14 89.02 117.33 6,030.51 5,890.51 3,550.06 3,962.78 5,947,689.61 512,88808 39.98 -3,550.06 1(5) E 8,579.16 88.25 129.92 6,031.22 5,891.22 3,533.48 3,987.72 5,947,673.06 512,91393 42.00 -3,533.48 1(5) 8,608.72 90.12 141.87 6,031 64 5,891.65 3,512.29 4,008.26 5,947,651.90 512,933.59 40.91 -3,512.29 1(5) 8,639.39 91.66 153.39 6,031.17 5,891.17 3,486.43 4,024.65 5,947,626.07 512,95001 37.89 -3,486.43 1(5) ( 8,669.22 89.79 164.17 6,030.79 5,890.79 3,458.67 4,035.42 5,947,598.32 512,960.82 3667 -3,458.67 1(5) 8,699.40 III; 91.75 175.92 6,030.38 5,890.38 3,429.00 4,040.63 5,947,568.65 512,966.06 39.47 -3,429.00 1(5) 8,728.76 89.48 188.00 6,030.07 5,690.07 3,399.72 4,03963 5,947,539.37 512,96509 41.86 -3,399.72 MWD (5) 8,760.86 88.31 20384 6,030.69 5,890.69 3,368.95 4,030.86 5,947,508.60 512,956.36 49.47 -3,368.95 1(5) 8,790.48 87.70 203.76 6,03172 5,891.72 3,341.87 4,01891 5,947,481.51 512944.44 2.08 -3,341.87 MWD (5) 8,82144 86.04 200.91 6,033.41 5,893.41 3,313.28 4,00716 5,947,452.91 512,932.73 10.64 -3,313.28 MWD (5) 8,851.50 87.91 199.01 6,035.00 5,89500 3,28507 3.996.92 5,947,424.68 512,922.52 8.86 -3,285.07 MWD (5) 4/102019 9:26:23AM Page 3 COMPASS 5000.14 Build 850 ConocoPhillips BA ConocoPhillipsV H( � Definitive Survey Report Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit Site: Kuparuk 2G Pad Well: 2G-06 Wellborn: 2G-06AL2 Design: 2G-06AL2 Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2G-06 2G-06 @ 140.00usfl (2G-06) 2G-06 @ 140.00usfi (2G-06) True Minimum Curvature EDT 14 Alaska Production 4/102019 9:26.23AM Page 4 COMPASS 5000.14 Build 850 Map Map Vertical MD Inc Azl TVD TVDSS -NI-S -i Northing Easting DLS Section (usft) (1) (' (usft) (usft) (usft) (usft) (•1100•) Tool Name ADDO1atI0D (ft) (ft) (it)Survey 8,881.58 88.31 196,23 6,035.99 5,895.99 3,256.42 3,98782 5,947,396.03 512,91346 9.33 -3,256.42 MWD (5) 8,911.83 87.67 193.53 6,037.05 5,897.05 3,227.20 3,98806 5,947,36680 512,905.73 9.17 3,227.20 MWD(5) 8,940.65 86.16 190.10 6,038.60 5,898.60 3,199.04 3,974.16 5,947,338.64 512,899.87 12.99 3,199.04 MWD (5) I i 8,970.65 88.37 187.68 6,040.03 5,900.03 3,169.44 3,969.53 5,947,30903 512,895.28 10.92 3,169.44 MM (5) 9,002.43 88.50 18512 6,040.90 5,900.90 3,137.87 3,96599 5,947,277.46 512,691.77 8.06 -3,137.87 MWD (5) 9,032.17 88.74 18273 6,041.62 5,901.62 3,108.21 3,963.96 5,947,24780 512,889.77 8.07 3,108.21 MWD (5) 9,065.43 88.59 180.92 6,042.39 5,902.39 3,074.98 3,962.90 5,947,214.57 512,888.75 5.46 -3,074.98 MM (5) .9,097.07 86.96 179.34 6,043.62 5,903.62 3,043.36 3,962.83 5,947,182.96 512,888.72 7.17 -3,043.36 MWD (5) 9,130.37 84.68 178.56 6,046.05 5,906.05 3,010.16 3,963.44 5,947,149.76 512,889.37 7.23 3,010.16 MWD (5) 9,160.73 85.70 177.17 6,048.59 5,908.59 2,979.93 3,964.56 5,947,179.54 512,890.53 5.67 -2,979.93 MWD (5) 9,190.71 87.94 175.96 6,050.26 5,910.26 2,950.05 3,966.36 5,947,089.66 512,892.36 849 -2,950.05 MWD(5) 9,221.18 89.85 174.46 6,050.84 5,910.84 2,91969 3,968.90 5,947,059.32 512,894.99 7.97 -2,919.69 MWD (5) 9,255.08 87,02 172.54 6,051.77 5,911.77 2,881 3,972.74 5,947,025.66 512,898.81 10.09 -2,886.03 MWD (5) 9,285.38 84.59 171.70 6,053.99 5,913.99 2,858.10 3,976.88 5,946,995.74 512,902.99 8.48 -2,856.10 MWD (5) 9,315.40 8665 172.66 6,056.28 5,916.28 2,826.45 3,980.95 5,946,966.09 512,907.10 7.57 -2,826.45 MWD (5) 9,345.20 89.85 174.16 6,057.19 5,917.19 2,796.86 3,984.37 5,946,936.51 512,910.55 11.86 -2,796.86 MWD (5) 9,375.16 69.08 176.82 6,057.47 5,917.47 2,767.00 3,986.72 5,946,906.66 512,912.94 9.24 -2,767.00 MWD (5) I 9,405.13 90.86 178.40 6,057.48 5,917.48 2,737.07 3,987.97 5,946,876.72 512,914.23 7.94 -2,737.06 MWD (5) 9,435.56 93.69 179.66 6,056.28 5,916.28 2,70666 3,98849 5,946,846.33 512,914.78 10.18 -2,706,66 MWD (5) 9,465.01 93.90 18262 6,054.33 5,914.33 2,677.28 3,987.90 5,94,816.95 512,914.23 10.05 -2,677.28 MWD(5) 9,494.98 93.50 18527 6,052.39 5,912.39 2,647.45 3,98585 5,946,787.12 512,912.21 8.92 -2,64745 MWD (5) 9,525.32 94.37 188.11 6,050.31 5,910.31 2,617.39 3,982.32 5,946,757.06 512,908.72 9.77 -2,617.39 MM (5) 9,557.76 94.74 191.31 6,047.73 5,907.73 2,585.52 3,976.87 5,946,725.18 512,903.30 9.90 -2,585.52 MWD(5) 9,591.05 94.05 188.62 6,045.18 5,905.18 2,552.83 3,97112 5,946,692.49 512,897.60 8.32 -2,552.83 MWD (5) 9,615.02 90.06 185.09 6,044.32 5,904.32 2,529.06 3,968.27 5,946,66872 512,894.77 22.22 -2,529.06 MWD (5) 9,64.5.37 93.14 184.05 6,043.47 5,903.48 2,496.82 3,965.85 5,946,638.48 512,892.39 10.71 -2,498.82 MWD (5) 9,680.62 92.83 182.16 6,041,64 5,901.64 2,463.67 3,963.94 5,94,603.33 512,890.52 5.43 -2,463.67 MWD(5) 9,711.11 97 72 178.70 6,040.43 5,900.43 2,433.21 3,963.72 5,946,572.87 512,890.33 11.91 -2,433.21 MWD (5) 9,740.77 90.43 176.62 6,039.87 5,899.87 2,403.58 3,964.93 5,946,543.25 512,891.58 8.25 -2,403.58 MWD (5) 9,76972 90.74 174.07 6,039.58 5,899.58 2,374.73 3%7,28 5,946,514.41 512.893.96 8.87 -2,37073 MWD (5) 9,800.61 90.85 17157 6,039.14 5899.15 2,344.09 3,971.14 5,946,48377 512,897.86 8.10 -2,344.09 MWD (5) 4/102019 9:26.23AM Page 4 COMPASS 5000.14 Build 850 41102019 9:26:23AM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips 3%R ConocoPhillips Definitive Survey Report E�S Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 2G-06 Project: Kupamk River Unit TVD Reference: 2G-06 @ 140.00usft (2G-06) _ Site: Kupamk 2G Pad MD Reference: 2G-06 @ 140.00usft (2G-06) Well: 2G-06 North Reference: True Wellbore: 2G-06AL2 Survey Calculation Method: Minimum Curvature Design: 2G-06AL2 Database: EDT 14 Alaska Production i Survey Map Map Vertical MD Inc Azi TVD TVDSS+N/-S +E/.W Northing Easting Section (usft) (°) (°) (usft) (usft) (usft) (usft) (°Doo) Survey Tool Name Annotation (ft) (ft) (ft) - 9,830.77 89.54 168.57 6,039.04 5,899.04 2,314.39 3,976.34 5,946,454.08 512,903.09 10.87 -2,314.39 MWD (5) 9,660.69 9141 167.07 6,038.79 5,898.79 2,285.14 3,982.65 5,946,424.84 512,909.44 8.01 -2,285.14 MWD (5) 9,890.63 91.84 164.56 6,037,94 5,897.94 2,256.13 3,989.98 5,946,395.84 512,916.80 8.50 -2,256113 MWD (5) 9,920.23 9163 162.78 6,037,05 5,897,05 2,227.74 3,998.30 5,946,367.46 512,925.16 6.05 -2,227.74 MWD (5) 9,950.78 9061 161.26 6,036.45 5,896.45 2,198.69 4,007.73 5,946,338.43 512,934.62 5.99 .2,198.69 MWD (5) ' 9,995.18 Oats) 157.89 6,036.37 5,896.37 2,15208 4,023.22 5,946,296.85 512,950.16 7.92 -2,157.08 MWD (5) 10,025.21 88.99 156.88 6,036.74 5,896.74 2,129.37 4,034.77 5,946,269.14 512,961.74 3.93 -2,129.37 MWD(5) 10,055.44 89.60 16061 6,037.11 5,897.11 2,101.26 4,04587 5,946,241.05 512,972.87 10.55 -2,101.26 MM (5) 10,085.57 8604 160.58 6,037.73 5,897.73 2,072.90 4,056.03 5,946,212.71 512,983.06 5.51 -2,072.90 MWD (5) 10,114.66 Was 162.67 6,039.00 5,899.00 2,045.32 4,065.19 5,946,185.14 512,992.25 8.08 .2,045.32 MWD (5) 10,144.78 85.45 163.53 6,040.99 5,900.99 2,01656 4,073.92 5,946,156.40 513,001.02 5.77 -2,016.56 MM (5) 10,174.68 83.28 165.08 6,043.93 5,903.93 1,987.92 4,081.97 5,946,127.77 513,009.11 8.90 -1,987.92 MWD (5) 10,204.35 82.95 168.10 6,047.49 5,907.49 1,959.27 4,088.80 5,946,099.13 513,015.97 10.17 -1,959.27 MWD (5) 10,224.62 83.11 169.60 6,049.95 5,909.95 1,939.53 4,092.70 5,946,079.40 513,019.88 7.39 -1,939.53 MWD(5) { 10,261.00 83.11 16960 6,054.31 5,914.31 1,904.01 4,099.22 5,946,043.89 513,026.45 0.00 -1,904.01 PROJECTED to TD i I 41102019 9:26:23AM Page 5 COMPASS 5000.14 Build 85D Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Friday, March 1, 2019 10:05 AM To: 'Herring, Keith E' Cc: Guhl, Meredith D (DOA); Boyer, David L (DOA); Kair, Michael N (DOA) Subject: RE: Issue with APIs for recent KRU 2G-06 wells Keith, I made a mistake when assigning API numbers to CPAI's planned KRU 2G -06A redrill and its laterals that must be corrected. Please accept my apology. To fix this as painlessly as possible: • For consistency with past practices, the API number for KRU 2G -06A must be changed from 50-029-21121-64-00 (wrong API) to 50-029-21121-01-00 (correct API) on all forms and in all databases. To minimize the paperwork chaos that could ensue for the remaining laterals (2G-06AL1, 2G-06AL2, and 2G- 06AL2-01), I propose leaving the API numbers that I assigned to those laterals unchanged and simply not assigning 50-029-21121-64-00 to any lateral. A copy of this email and an explanatory "Note to File' in CPAI's and AOGCC's well history files for 2G -06A and 2G-06AL1 will adequately explain to future users why API number 50-029-21121-64-00 was never assigned. • Please note that all assigned Permit to Drill numbers will remain unchanged. All production from laterals 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 must be reported against redrilled well KRU 2G -06A, API number SO -029-21121-01-00, Permit to Drill number 219-019. Please forward this email to anyone affected by this change, and please extend my apologies for this mistake. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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 Steve Davies at 907-793-1224 or Steve davies(&a laska.gov. From: Guhl, Meredith D (DOA) Sent: Wednesday, February 27, 2019 2:54 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov>; Boyer, David L (DOA) <davic1boyer2@alaska.gov> Subject: Issue with APIs for recent KRU 2G-06 wells Hi Steve and Dave, We've got an API number issue with recently permitted KRU 25-06 wells. i 50-029-21121-00-00 CONOCOPHILLIPS ALASKA, INC. KUPARUK RIV UNIT 2G-06 1 -OIL 24 -Se - 50-029-21121-60-00 CONOCOPHILLIPS ALASKA, INC. KUPARUK RIV UNIT 2G-061_1 50-029-21121-61-00 W CONOCOPHILLIPS ALASKA, INC. KUPARUK RIV UNIT 2G-061-1.01 CANC 11 -Feb - 50 -029-21121-62-00 CONOCOPHILLIPS ALASKA, INC. KUPARUK RIV UNIT 2G -06L1-02 CANC 11 -Feb - 50 -029-21121-63-00 2190190 No CONOCOPHILLIPS ALASKA, INC. KUPARUK RIV UNIT 2G-061-1-03 CANC 11 -Feb - 50.029 -21121-64-00 CONOCOPHILLIPS ALASKA, INC. KUPARUK RIV UNIT 2G -06A 50-029-21121-65-00 2190200 , No CONOCOPHILLIPS ALASKA, INC. KUPARUK RIV UNIT 2G-06AL1 50-029-21121-66-00 2190210 No CONOCOPHILLIPS ALASKA, INC. KUPARUK RIV UNIT 2G-06AL2 50-029-21121-67-00 2190220 No CONOCOPHILLIPS ALASKA, INC. KUPARUK RIV UNIT 2G-06AL2-01 The highlighted well should have an API of 50-029-21121-01-00 as it is a sidetrack from them a in bore, and then the API needs to be adjusted for the laterals following. Unless we've changed our numbering conventions? Thanks, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.puhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.auhl@alaska.gov. THE STATE OfALASKA GOVERNOR MIKE DUNLEAVY Kai Starck CTD Director ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2G-06AL2 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-021 Surface Location: 547' FSL, 236' FWL, SEC. 32, TI 1N, R9E, UM Bottomhole Location: 2536' FNL, 1065' FEL, SEC. 32, TI IN, R9E, UM Dear Mr. Starck: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.olasko.gov Enclosed is the approved application for the permit to re -drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 219-019, API No. 50-029-21121-64- 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, Daniel T. Seamount, Jr. Chair DATED thisIr day of February, 2019. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS„�JN PERMIT TO DRILL 20 AAC 25.005 E i,: °C=EYED 1 a. Type of Work: Drill ❑ Lateral ❑� Redrill ❑ Reentry ❑ 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG Service - Disp ❑ Stratigraphic Test ❑ Development - Oil ❑� " Service - Winj ❑ Single Zone ❑� . Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ 1c. Specify if well is proposed for: Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: Blanket 0 - Single Well ❑ Bond No. 5952180 • 11. Well Name and Number: KRU 2G-06AL2 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 9900' TVD: 6038' 12. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool ` 4a. Location of Well (Governmental Section): Surface: 547' FSL, 236' FWL, Sec 32, Tl l N, R9E, UM • Top of Productive Horizon: 1312' FNL, 1241' FEL, Sec 32, T11 N, R9E, UM Total Depth: 2536' FNL, 1065' FEL, Sec 32, T11 N, R9E, UM 7. Property Designation: ADL 25656 8. DNR Approval Number: LONS 82-180 13. Approximate Spud Date: 2/26/2019 9. Acres in Property: 2491 14. Distance to Nearest Property: 22200' ' 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 508930 • y- 5944135 Zone- 4 10. KB Elevation above MSL (ft): 140' GL / BF Elevation above MSL (ft): 104' 15. Distance to Nearest Well Open to Same Pool: 1285', 2G-08 ' 16. Deviated wells: Kickoff depth: 8300' • feet Maximum Hole Angle: 98 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 4,908 Surface: 4,320 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 1500' 8400' . 6054' 99001. 6038' Slotted 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 8485' 6253' N/A 8368' 6158' 8136' Casing Length Size Cement Volume MD TVD Conductor/Structural 72' 16" 202 sx Cold Set II 110' 110' Surface 3097' 9-5/8" 1035 sx PF E, 250 sx PF C 3134' 2774' Production 8413' 7" 575 sx Class G, 250 sx PF C 8449' 6224' Perforation Depth MD (ft): 8188'- 8198' Perforation Depth TVD (ft): 6013'- 6021' 8216'- 8246' 6036- 6060' Hydraulic Fracture planned? Yes[] No ❑� ' 20. Attachments: Property Plat ❑ BOP Sketch Divertter Sketch E] Drilling Program Seabed Report v. Depth B Drilling eFluid Program m ot B ard Analysis 20 AAC 25.050 Shallow zrequirements e 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Keith Herring Authorized Name: Kai Starck Contact Email: Keith. E. Herrin CO .Com Authorized Title: CTD Director Contact Phone: 907-263-4321 Authorized Signature: Date: 17— - Commission Use Only Permit to Drill � Number: 2, '7 )0 API Number: / 50- �1-/- �M(Z '" C.F —r-�U Permit Approval Date: Z la 1 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: L5010 fl6f to %Boo YO ff--J Samples req'd: Yes❑ Nov Mud log req'd: Yes❑ No L✓� A nn 11/67 r �� rc ✓e-" from Tf51 fo .2 50C? p5 r l 12S measures: Yes [olNo❑ Directional svy req'd: Yes [1/No❑ g ing exception req'd: Yes ElNol Inclination -only svy req'd: Yes[]No[r Post initial injection MIT req'd: Yes ❑ No is 9rR,� trd i� al/a v fht ky`GeoFf point fo be any pont a long fl'� fJ a-rrnT !ai"r��c l . �APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: I �G Z//�J//9 Submh Form and 10-401 Revised 5/2017 rs ermrt i5 validin Qafo oEapproval per 20 AAC 25.00S,�ttachments i7uplicale AE Z ��' ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 08, 2018 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 sundry application to set a mechanical whipstock and cement squeeze the A -sand perforations in the KRU well 2G-06 (PTD# 184-082). ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill four laterals out of the KRU 2G-06 (PTD #184-082) using the coiled tubing drilling rig, Nabors CDR3-AC. Pre -rig operations are scheduled to begin in late February with CTD operations following in early March 2019. The objective will be to drill four laterals, KRU 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 targeting the Kuparuk A -sand interval. ConocoPhillips requests a variance to the requirements of 20 AAC 25.112(c) for the alternate plugging method to isolate the 2G-06 A -sand perforations utilizing an A -sand cement squeeze via service coil. To account for geologic 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 the sundry application are the following documents: - 10403 Sundry Application for KRU 2G-06 - Operations Summary in support of the 10-403 sundry application - Current Wellbore Schematic - Proposed CTD Schematic Attached to the permit to drill applications are the following documents: - Permit to Drill Application Forms (10401) for 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 - Detailed Summary of Operations - Directional Plans for 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 - Current Wellbore Schematic - Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerer Keith Herring Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b))............ _.......................... _....................... _............................. _................. 2 2. Location Summary .................. ......... ..... ........ .... .... ..... ...... 2 (Requirements of 20 AAC 25.005(c)(2)).. ................. ....... .. ... ,...... __........ . ...... .. ... ....... ... ........ .. .........2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AA C 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 of20AAC25.005(c)(5))...... . ..............- ............... ..._..... .... ................. .............. ............. ...................2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20AAC 25.005(c)(6)).- - ...................... .............. ........ ..........._..._................... _._............. _._..,._...3 7. Diverter System Information ..........................................................................................................3 (Requirements of 20 AAC 25.005(c)(7)) ... .. ........... ................ _...._... .................................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8))... ........ _...................... .... - ...... ...... _..... _...................... ................ .............. 3 9. Abnormally Pressured Formation Information.............................................................................4 .................................. (Requirements of 20 AA C 25.005(c)(9)).. ._....- _.-... ... _....................... ...... .......... _. ... .................4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))... ........__...._. .......... ......... ........__.......... ........._.. .._........................ ..........4 11. Seabed Condition Analysis............................................................................................................ 4 .................... ............. (Requirements of 20 AAC 25.005(c)(11))............... ..... .......... .........._...... ......_._..._. .................4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12)) . .._....._. ....... ........... ................ ........................_. -............... ..............4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13)) .......... .......... ................. ............... ._.............. .............................. .............. ........ ...... ......... 4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................6 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14)) . ............._.. ............... .___.......... ...... _... _....... .. ......._. ............... __..............6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 7 (Requirements of 20 AA C 25.050(b)) ........... ............ _.............. ................. .. ......... _..... ............ ................. ........_.........7 16. Attachments....................................................................................................................................7 Attachment 1: Directional Plans for 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 laterals . .............. .................... 7 Attachment 2: Current Well Schematic for 2G-06...........................................................................................................7 Attachment 3: Proposed Well Schematic for 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 laterals......................7 Page 1 of 7 February 08, 2019 PTD Application: 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 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 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01. All laterals will be classified as "Development -Oil' wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 forms for surface and subsurface coordinates of each of the laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,800 psi. Using the maximum formation pressure in the area of 4,908 psi in 213-05 (i.e. 15.5 ppg EMW), the maximum potential surface pressure in 2G-06, assuming a gas gradient of 0.1 psi/ft, would be 4,320 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 2G-06 was measured to be 3,829 psi (12.4 ppg EMW) on 10/13/2018. The maximum downhole pressure in the 2G-06 vicinity is the 26-05 at 4,908 psi or 15.5 ppg EMW on 7/7/2016. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) ✓ No specific gas zones will be drilled; gas injection has been performed in this area, so there is a chance of encountering gas while drilling the 2G-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 2G-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 2G-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 February 08, 2019 PTD Application: 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 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 2G -06A 8,400' 9,750' 5,912' 51887' 2%", 4.7#, L-80, ST -L slotted liner; Surface 110' 1640 670 Surface aluminum billet on to 2G-06AL1 8,300' 9,750' 5,913' 5,859' 2%", 4.7#, L-80, ST -L slotted liner; 2774' 3520 2020 Production 7" aluminum billet on to 2G-06AL2 8,400' 9,900' 5,914' 5,898' 2%", 4.7#, L-80, ST -L slotted liner; 4980 4320 Tubing 3-1/2" 1 9.3 aluminum billet on to 2G-06AL2-01 8,006' 9,900' 5,730' 5,873' 2'/", 4.7#, L-80, ST -L slotted liner/ 10,540 blank; deployment sleeve on to Existing Casingkiner Information Category OD Weigh t Grade Connection Top MD Btm MD Top TVD BtrnTVD TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded Surface 110' Surface 110' 1640 670 Surface 9-5/8" 36 J-55 BTC Surface 3134' Surface 2774' 3520 2020 Production 7" 26 J-55 BTC Surface 8449' Surface 6224' 4980 4320 Tubing 3-1/2" 1 9.3 L-80 EUE 8rd MOD Surface 8044' Surface 5899' 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 Power -Vis milling fluid (8.6 ppg) - Drilling operations: Water based Power -Pro drilling mud (8.6 ppg). This mud weight may not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: BHA's will be deployed using standard pressure deployments and the well will be loaded with 12.6 ppg potassium formate completion fluid in order to provide formation over -balance ' and maintain wellbore stability while running completions. If higher formation pressures are encountered the completion brine will be weighted up with potassium formate. Page 3 of 7 February 08, 2019 PTD Application: 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 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 2G-06 laterals we will target a constant BHP of 12.4 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. PfeSRure at the 2G-06 Window (8.095' MD. 5.939' TVD) Usino MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU well 2G-06 is a Kuparuk producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize four laterals to target the Kuparuk A -sands to the north and south of the existing 2G-06 wellbore. The laterals will reclaim resource from the long term shut in rock producer 2G-06 and provide additional offtake in a high-pressure area. E -line will set a high expansion wedge in the 7" production casing at the planned kick off point at 8095' MD. Service coil will cement the high expansion wedge in the 7" casing and squeeze cement the A -sand perforations. Page 4 of 7 February 08, 2019 Pumps On 1.8 bpm) Pumps Off Formation Pressure 12.4 3829 psi 3829 psi Mud Hydrostatic 8.6 2655 psi 2655 psi Annular friction i.e. ECD, 0.080psi/ft) 647 psi 0 psi Mud + ECD Combined no chokepressure) 3302 psi underbalanced -527psi) 2655 psi underbalanced -1174psi) Target BHP at Window 12.4 3830 psi 3830 psi Choke Pressure Required to Maintain Target BHP 528 psi 1175 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU well 2G-06 is a Kuparuk producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize four laterals to target the Kuparuk A -sands to the north and south of the existing 2G-06 wellbore. The laterals will reclaim resource from the long term shut in rock producer 2G-06 and provide additional offtake in a high-pressure area. E -line will set a high expansion wedge in the 7" production casing at the planned kick off point at 8095' MD. Service coil will cement the high expansion wedge in the 7" casing and squeeze cement the A -sand perforations. Page 4 of 7 February 08, 2019 PTD Application: 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 CDR3-AC will cut a window in the 2G-06 production casing and drill the 2G -06A sidetrack to a planned TD at 9,750' MD, targeting the A sand to the north. It will be completed with 2-3/8" slotted liner from TD up to 8,400' MD with an aluminum billet for kicking off the 2G-06AL1 lateral. The 2G-06AL 1 lateral will drill to a TD of 9,750' MD targeting the A sand to the north. It will be completed with 2-3/8" slotted liner from TD up to 8,300' MD with an aluminum billet for kicking off the 2G-06AL2 lateral. The 2G-06AL2 lateral will drill to TD of 9,900' MD targeting the A sand to the south. It will be completed with 2-3/8" slotted liner from TD up to 8,400' MD with an aluminum billet for kicking off the 2G-06AL2- 01 lateral. The 2G-06AL2-01 lateral will drill to TD of 9,900' MD targeting the A sand to the south. It will be completed with 2-3/8" slotted/blank liner from TD up into the 3-1/2" tubing at 8,006' MD with a deployment sleeve. Pre -CTD Work 1. RU Slickline: Obtain caliper of 7" casing. 2. RU E -line: Set high expansion wedge in 7" casing. 3. RU Service Coil: Cement high expansion wedge and squeeze cement the A -sand perforations. 4. Prep site for Nabors CDR3-AC. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 2G -06A Sidetrack (A4 sand - North) a. Mill 2.80" window at 8,095' MD. b. Drill 3" bi-center lateral to TD of 9,750' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 8,400' MD. 3. 2G-06AL1 Lateral (A4 sand -North) a. Kickoff of the aluminum billet at 8,400' MD. b. Drill 3" bi-center lateral to TD of 9,750' MD. c. Run 2%" slotted liner with aluminum billet from TD up to 8,300' MD. 4. 2G-06AL2 Lateral (A4 sand - South) a. Kickoff of the aluminum billet at 8,300' MD. b. Drill 3" bi-center lateral to TD of 9,900' MD. ` c. Run 2%" slotted liner with aluminum billet from TD up to 8,400' MD. 5. 2G-06AL2-01 Lateral (A4 sand - South) a. Kick off of the aluminum billet at 8,400' MD. b. Drill 3" bi-center lateral to TD of 9,900' MD. c. Run 2%" slotted/blank liner with deployment sleeve from TD up to 8,006' MD. 6. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post -Rig Work 1. Return to production. Page 5 of 7 February 08, 2019 PTD Application: 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 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 - 2G-06 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. - While running 2W slotted liner, a joint of 2%" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AA 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). Page 6 of 7 February 08, 2019 PTD Application: 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 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 2G -06A 23,075' 2G-06AL1 23,075' 2G-06AL2 22,200'- 2G-06AL2-01 22,200' -- Distance to Nearest Well within Pool Lateral Name Distance Well 2G -06A 525' 2F-20 2G-06AL1 525' 2F-20 2G-06AL2 1285' • 2G-08 2G-06AL2-01 1285' 2G-08 16. Attachments Attachment 1: Directional Plans for 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 laterals. Attachment 2: Current Well Schematic for 2G-06. Attachment 3: Proposed Well Schematic for 2G -06A, 2G-06AL 1, 2G-06AL2, and 2G-06AL2-01 laterals. Page 7 of 7 February 08, 2019 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2G Pad 2G-06 2G-06AL2 Plan: 2G-06AL2_wp03 Standard Planning Report 02 November, 2017 BT�a GHES GE company ConocoPhillips Database. EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project Kuparuk River Unit Site: Kuparuk 2G Pad Well: 2G-06 Wellbore: 2G-06AL2 Design: 2G-06AL2_wp03 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 2G-06 Mean Sea Level 2G-06 Qa 140.00usft (2G-06) True Minimum Curvature ` Project Kupamk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) - Using Well Reference Point Map Zone: Alaska Zone 04 • Using geodetic scale factor BIER UGHES a GEaarpany Site Kuparuk 2G Pad 2G-06 Site Position: Northing: 5,944, 015.12 usft Latitude: 70°15'29.733N From: Map Easting: 508,649.96 usft Longitude: 149'55'48.314W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.07 ° Well 2G-06 Well Position -NIS 0.00 usft Northing: 5,944,135.21 usft Latitude: 70° 15' 30.911 N TVD Below +EAW 0.00 usft Easting: 508,929.90 usft Longitude: 149" 55'40.165 W Position Uncertainty Depth 0.00 usft Wellhead Elevation: usft Ground Level: O, 00 usft Wellbore 2G-06AL2 Magnetics Model Name Sample Data Declination Dip Angle (°) (°) BGGM2017 2/1/2018 17.14 80.85 Design Audit Notes: Version: Vertical Section: 2G-06AL2_wp03 Phase: Depth From (TVD) (usft) 0.00 PLAN +N/ -S (usft) 0.00 Tie On Depth: +E/ -W (usft) 0.00 Field Strength (nT) 57 466 J 8,300.00 Direction (°) 180.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +NIS +EI -W Rate Rate Rate TFO (usft) (°) (I (usft) (usft) (usft) (°1100ft) (°1100ft) (-1100ft) (°) Target 8,300.00 82.31 49.07 5,913.06 3422.25 3,790.98 0.00 0.00 0.00 0.00 8,400.00 96.57 73.23 5,914.05 3,470.00 3,877.71 28.00 14.26 24.16 60.00 8,800.00 87.54 185.10 5,692.33 3,255.07 4,139.34 28.00 -2.26 27.97 90.00 9,000.00 84.26 198.74 5,906.70 3,060.37 4,098.28 7.00 -1.64 6.82 104.00 9,150.00 90.32 207.33 5,913.80 2,922.69 4,039.71 7.00 4.04 5.72 55.00 9,350.00 98.49 195.92 5,898.40 2,737.82 3,966.31 7.00 4.08 -5.71 306.00 9,550.00 89.39 185.23 5,884.63 2,542.15 3,929.89 7.00 4.55 -5.34 230.00 9,900.00 86.14 160.93 5,898.47 2,197.61 3,971.61 7.00 -0.93 -6.94 262.00 1122017 4:56:26PM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips BATER ConocoPhillips Planning Report GHES GE company, Database: EDT Alaska Sandbox Vertical Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupaiuk River Unit +El -W Site: Kuparuk 2G Pad Azimuth Well: 2G-06 (usft) (usft) Wellbore: 2G-06AL2 (') (usft) Design: 2G-06AL2_wp03 3,790.98 Planned Survey 000 0.00 5,947,56161 Measured 3,470.00 3,877.71 TVD Below Depth Inclination Azimuth System (usft) (') (_) (usft) 8,300.00 82.31 49.07 5,913.06 TIP/KOP -3,432.27 28.00 8,400.00 96.57 73.23 5,914.05 Start 28 dls -3,352.90 28.00 8,500.00 95.80 101.39 5,903.05 8,600.00 93.67 129.40 5,894.63 8,700.00 90.69 157.27 5,890.75 8,800.00 87.54 185.10 5,892.33 End 28 dis, Start 7 dls 4,098.28 -3,060.37 8,900.00 85.87 191.91 5,898.08 9,000.00 84.26 198.74 5,906.70 4 5,947,107.38 512,987.52 2,922.69 9,100.00 88.29 204.48 5,913.20 9,150.00 90.32 207.33 5,913.80 5 9,200.00 92.38 204.50 5,912.62 9,300.00 96.47 198.80 5,904.91 9,350.00 98.49 195.92 5,898.40 6 9,400.00 96.23 193.22 5,892.00 9,500.00 91.68 187.89 5,885.10 9,550.00 89.39 185.23 5,884.63 7 9,600.00 88.91 181.77 5,885.37 9,700.00 87.95 174.83 5,888.11 9,800.00 87.02 167.89 5,892.50 9,900.00 86.14 160.93 5,898.47 Planned TO at 9900.00 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 2G -O6 Mean Sea Level 2G-06 @ 140.00usft (2G-06) True Minimum Curvature 2,877.74 4,017.87 Vertical Dogleg Toolface Map Map +NIS +El -W Section Rate Azimuth Northing Easting (usft) (usft) (usft) (°1100ft) (') (usft) (usft) 3,422.25 3,790.98 -3,422.25 000 0.00 5,947,56161 512,716.44 3,470.00 3,877.71 -3,470.00 28.00 60.00 5,947,609.46 512,803.10 3,474.61 3,976.00 -3,474.61 28.00 90.00 5,947,614.18 512,901.38 3,432.27 4,065.10 -3,432.27 28.00 93.10 5,947,571.95 512,990.52 3,352.90 4,124.15 -3,352.90 28.00 95.46 5,947,492.66 513,049.66 3,255.07 4,139.34 -3,255.07 28.00 96.54 5,947,394.86 513,064.96 3,156.40 4,124.59 -3,156.40 7.00 104.00 5,947,296.18 513,050.33 3,060.37 4,098.28 -3,060.37 7.00 103.61 5,947,200.13 513,024.14 2,967.66 4,061.55 -2,967.66 7.00 55.00 5,947,107.38 512,987.52 2,922.69 4,039.71 -2,922.69 7.00 54.63 5,947,062.39 512,965.74 2,877.74 4,017.87 -2,877.74 7.00 -54.00 5,947,017.42 512,943.95 2,785.13 3,981.10 -2,785.13 7.00 -54.07 5,946,924.78 512,907.30 2,737.82 3,966.31 -2,737.82 7.00 -54.51 5,946,877.46 512,892.57 2,689.83 3,953.85 -2,689.83 7.00 -130.00 5,946,829.46 512,880.16 2,591.82 3,935.60 -2,591.82 7.00 -130.35 5,946,731.43 512,862.03 2,542.15 3,929.89 -2,542.15 7.00 -130.71 5,946,681.77 512,856.38 2,492.26 3,926.83 -2,492.26 7.00 -98.00 5,946,631.87 512,853.38 2,392.40 3,929.80 -2,392.40 7.00 -97.95 5,946,532.03 512,856.46 2,293.70 3,944.79 -2,293.70 7.00 -97.76 5,946,433.35 512,871.58 2,197.61 3,971.61 -2,197.61 7.00 -97.45 5,946,337.30 512,898.50 1122017 4:56.26PM Page 3 COMPASS 5000.14 Build 85 Targets Target Name -hit/miss target Dip Angle Dip Dir. ConocoPhillips BA�(ER ConocoPhillips Planning Report UGHES -Shape (°) (°) (usft) a 6Ecompany Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 2G-06 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kupawk River Unit MD Reference: 2G-06 @ 140.00usft (2G-06) Site: Kupamk 2G Pad North Reference: True Well: 2G-06 Survey Calculation Method: Minimum Curvature Wellbore: 2G-06AL2 5,947,456.01 1,652,615.00 Design: 2G-06AL2 wp03 5,897.00 589.371,144,142.91 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD -N/-S +EI -W Northing Easting 70° V40.963 N 140° 45'25.912 W -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 2G-06AL2_T03 0.00 0.00 5,885.00 937.421,144,132.33 5,946,429.00 1,652,946.00 70" V 31.310 N 140° 45' 17.268 W - plan misses target center by 1139995.34usft at 8800.00usft MD (5892.33 TVD, 3255.07 N, 4139.34 E) 5,947,355.00 1,652,500.00 - Point Point 0.00 100.88 115.13 5,947,456.01 1,652,615.00 2G-06AL2 T04 0.00 0.00 5,897.00 589.371,144,142.91 5,946,081.00 1,652,957.00 70°1'27.915N 140'45'18.467W - plan misses target center by 1140006.69usft at 8800.00usft MD (5892.33 TVD, 3255.07 N, 4139.34 E) Point 0.00 - Point 5,947,860.00 1,652,585.97 Point 0.00 2G-06 CTD Polygon Sot 0.00 0.00 0.00 2,064.671,144,019.65 5,947,556.00 1,652,832.00 70° 1'42.421 N 140" 45' 15.609 W - plan misses target center by 1139896.16usft at 8800.00usft MD (5892.33 TVD, 3255.07 N. 4139.34 E) 5,948,263.00 1,652,506.95 - Polygon Point 0.00 1,108.12 -8.74 5,948,463.00 1,652,489.95 Point 1 0.00 0.00 0.00 5,947,556.00 1,652,832.00 1,652,452.94 Point 0.00 -23.24 210.99 5,947,533.01 1,653,043.00 1,652,428.93 Point 3 0.00 -125.51 434.90 5,947,431.02 1,653,267.01 1,652,714.93 Point 0.00 -372.62 510.63 5,947,184.02 1,653,343.02 1,652,946.93 Point 0.00 -592.57 448.37 5,946,964.02 1,653,281.03 1,652,963.94 Point 0.00 -912.56 413.01 5,946,644.02 1,653,246.05 1,652,966.96 Point 0.00 -1,276.52 348.59 5,946,280.02 1,653,182.07 1,653,004.96 Point 0.00 -1,760.61 383.04 5,945,796.02 1,653,217.09 1,653,081.98 Point 0.00 -1,778.06 -107.03 5,945,777.99 1,652,727.09 1,653,081.99 Point 10 0.00 -1,628.01 -133.86 5,945,928.00 1,652,700.08 1,652,986.01 Point 11 0.00 -1,334.96 -153.53 5,946,220.99 1,652,680.07 1,652,892.01 Point 12 0.00 -1,146.96 -136.32 5,946,408.99 1,652,697.05 1,652,759.01 Point 13 0.00 -907.97 -111.04 5,946,647.99 1,652,722.05 1,652,500.00 Point 14 0.00 -699.98 -76.80 5,946,856.00 1,652,756.04 1,652,952.00 Point 15 0.00 -410.04 -0.47 5,947,146.00 1,652,832.02 Point 16 0.00 -303.94 -78.35 5,947,252.00 1,652,754.02 0.00 0.00 5,890.00 Point 17 0.00 9.09 -77.00 5,947,565.00 1,652,755.00 Point 18 0.00 0.00 0.00 5,947,556.00 1,652,832.00 2G-06 CTD Polygon Not 0.00 0.00 0.00 1,864.041,143,687.38 5,947,355.00 1,652,500.00 70° V40.963 N 140° 45'25.912 W - plan misses target center by 1139564.12usft at 8800.00usft MD (5892.33 TVD, 3255.07 N. 4139.34 E) - Polygon Point 1 0.00 0.00 0.00 5,947,355.00 1,652,500.00 Point 0.00 100.88 115.13 5,947,456.01 1,652,615.00 Point 3 0.00 325.88 136.38 5,947,681.01 1,652,635.98 Point 0.00 504.95 86.58 5,947,860.00 1,652,585.97 Point 0.00 703.01 52.80 5,948,058.00 1,652,551.96 Point 0.00 908.08 8.03 5,948,263.00 1,652,506.95 Point 0.00 1,108.12 -8.74 5,948,463.00 1,652,489.95 Point 0.00 1,243.18 -45.59 5,948,598.00 1,652,452.94 Point 0.00 1,441.22 -69.37 5,948,795.99 1,652,428.93 Point 10 0.00 1,336.89 216.54 5,948,692.01 1,652,714.93 Point 11 0.00 1,241.62 448.45 5,948,597.03 1,652,946.93 Point 12 0.00 1,103.58 465.30 5,948,459.02 1,652,963.94 Point 13 0.00 856.56 468.02 5,948,212.03 1,652,966.96 Point 14 0.00 662.49 505.80 5,948,018.02 1,653,004.96 Point 15 0.00 395.38 582.51 5,947,751.03 1,653,081.98 Point 16 0.00 157.36 582.24 5,947,513.03 1,653,081.99 Point 17 0.00 -45.56 486.00 5,947,310.02 1,652,986.01 Point 18 0.00 -186.46 391.83 5,947,169.02 1,652,892.01 Point 19 0.00 -292.32 258.69 5,947,063.02 1,652,759.01 Point 20 0.00 0.00 0.00 5,947,355.00 1,652,500.00 2G-06AL2_T02 0.00 0.00 5,914.00 1,323.451,144,138.78 5,946,815.00 1,652,952.00 70" V35.049 N 140° 45' 15.421 W - plan misses target center by 1140001.08usft at 8800.00usft MD (5892.33 TVD, 3255.07 N. 4139.34 E) - Point 2G-06AL2 T01 0.00 0.00 5,890.00 1,716.381,144,231.26 5,947,208.00 1,653,044.00 70' V 38.728 N 140'45'11.100 W 11/22017 4:56:26PM Page 4 COMPASS 5000.14 Build 85 Plan Annotations Measured Vertical Depth Depth (usft) (usft) 8,300.00 ConocoPhillips Bp(ER 5,914.05 ConocoPhillips Planning Report 9,000.00 UHES 9,150.00 5,913.80 a GEcompary Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 2G-06 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kupawk River Unit MD Reference: 2G-06 ® 140.00usft (2G-06) Site: Kupamk 2G Pad North Reference: True Well: 2G-06 Survey Calculation Method: Minimum Curvature Wellbore: 2G-06AL2 3,929.89 7 Design: 2G-06AL2_wp03 3,971.61 Planned TD at 9900.00 -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 9,90000 5,898.47 2318" 2.375 3.000 Plan Annotations Measured Vertical Depth Depth (usft) (usft) 8,300.00 5,913.06 8,400.00 5,914.05 8,800.00 5,892.33 9,000.00 5,906.70 9,150.00 5,913.80 9,350.00 5,898.40 9,550.00 5,884.63 9,900.00 5,898.47 Local Coordinates -N/-S +EI -W (usft) (usft) Comment 3,422.25 3,790.98 TIP/KOP 3,470.00 3,877.71 Start 28 dls 3,255.07 4,139.34 End 28 dls, Start 7 dls 3,060.37 4,098.28 4 2,922.69 4,039.71 5 2,737.82 3,966.31 6 2,542.15 3,929.89 7 2,197.61 3,971.61 Planned TD at 9900.00 11/2/2017 4: 56: 26PM Page 5 COMPASS 5000.14 Build 85 Baker Hughes lNTEQ BVER CO000PhillipS Travelling Cylinder Report UGH f1ES .GEmmparry Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 2G Pad Site Error: 0.00 usft Reference Well: 2G-06 Well Error: 0.00 usft Reference Wellbore 2G-06AL2 Reference Design: 2G-06AL2_wp03 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 2G-06 2G-06 @ 140.01 (2G-06) 2G-06 ® 140.01 (2G-06) True Minimum Curvature 1.00 sigma OAKEOMP2 Offset Datum reference 2G-06AL2_wpO3 41ter type: GLOBAL FILTER APPLIED: All wellpaths within 2004 100/1000 of reference From nterpolation Method: MD Interval 25.00usft Error Model: ISCWSA )epth Range: 8,300.00 to 9,900.00usft Scan Method: Tray. Cylinder North tesults Limited by: Maximum center -center distance of 1,176.00 usft Error Surface: Pedal Curve Survey Tool Program Date 11/2/2017 From To Reference Offset (usft) (usft) Survey( Wellbore) Tool Name Description 200.00 8,100.0026-06(2G-06) SEEKER MS BH I Seeker mullishot Deviation 8,100.00 8,300.00 2G -06A wp03(2G-06A) MWD MWD - Standard Distance 8,300.00 9,900.00 2G-06AL2_wpO3(2G-0BAL2) MWD MWD - Standard (usft) Casing Points (usft) -- - (usft) wri Measured Vertical offset Togeacea Casing Hole Casing- Centre to Depth Depth Allowable wamlag Diameter Diameter Depth neem (usft) (usft) Name Aaimuth Out of range 2G -O6 -2G -06 -2G -O6 9,900.00 6,038.47 2 3/8" 7,200.00 2-3/8 3 18.75 Summary Kupamk 2G Pad -2G -06 -2G -06-2G-06 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Weighers, - Design (usft) (usft) (usft) Vertcal (usft) wri Kuparuk 2G Pad offset Togeacea Offset wellbore castle Casing- Centre to No Go Allowable wamlag 2G-05 - 2G-05 - 2G-05 Depth neem Depth Aaimuth Out of range 2G -O6 -2G -06 -2G -O6 9,400.00 7,200.00 1,083.63 18.75 1,068.69 Pass - Major Risk 2G -O6 -2G -06A -2G -06A wp03 9,400.00 7,200.00 1,083.63 4.66 1,082.59 Pass - Minor 1/10 2G-06-2G-06AL1-2G-06AL7_wpO5 9,400.00 7,200.00 1,083.63 4.94 1,082.59 Pass - Minor 1/10 2G-06-2G-06AL2-01-2G-06AL2-01_wp03 8,935.69 8,950.00 9.02 0.66 8.43 Pass - Minor 1/10 Offset Design Kupamk 2G Pad -2G -06 -2G -06-2G-06 onset site Error. 0.00 usft Survey Program: 20Q -SEEKER Me Rule Assigned: Major Risk Offset well Enw 0.00 sent Reference offset semi Major Asn Measured Vertcal Measured wri Prof.... offset Togeacea Offset wellbore castle Casing- Centre to No Go Allowable wamlag Depth Depth neem Depth Aaimuth +1,114 .EIM Hak $ize Centre Distance Dedatern (usft) (.an) lean) (usft Wsa) lase 0 (-am 4- 1 11 IaaRl nosh) lose) 8.301.64 6,05328 835000 6,143 B4 0.17 187 -131.11 3,414.91 3.783.80 3 9134 854 84.07 Pass - Major Risk 8,315.27 6,054.82 8375.00 6.164.02 0.18 2.05 -12784 3624.45 3,79506 3 10912 908 102.11 Pass - Major Risk 8.327.88 6.055.84 0,400.00 6,184.20 0.19 2.24 -124.40 3,433.99 3,806.32 3 128.84 9.82 120.73 Pass - Major Risk 8,340.00 6,058.45 0,425.00 6,204.38 0.18 2.42 -120.83 3,443.53 3,817.57 3 14005 10.15 139.87 Pass - Major Risk 8,350.16 s(e6.67 0,450.00 6.224.56 0.19 2.61 -l17.60 3,453.07 3,920.83 3 167.93 10.67 159.52 Pass - Major Risk 8.360.00 6.055.65 0,05.00 6,244.74 0.20 2.79 -l14.37 3,462.61 3,840.09 3 188.23 11.17 179.61 Pas. - Major Risk 8.363.60 6,058.50 8,485.00 8,252.81 0.20 2.87 -113.15 3,466,43 3,044.00 3 1%.47 11.38 187.77 Pass - Major Risk 9,40000 6.032.00 7.200.00 5,278,26 0.91 0.00 -121.00 2,923.40 3211.16 3 1,003.63 18.75 1058.09 Pas.- Major Risk. OC. ES, SF 9.117.40 6.030.23 7,175.00 5,280.70 0,94 0.00 -122.24 2,911.85 3,197.63 3 1,102.43 is" 1.007.26 Pass - Major Risk 9,624.08 6,029.61 7,15000 5,243.19 0.95 0.00 -122.03 2,900.25 3,184.06 3 1.121.0 19.09 1,106.21 Pass -Met Risk 9,430.65 6,029.04 7,125.00 5,225.73 0.96 0.00 -123.40 2,888.81 3.170.47 3 1,140.82 19.19 1,125.28 Pas. - Major Risk 9.437.12 6,028.51 7,100.00 5,208.32 007 0.00 -123.95 2.876.92 3,156.85 3 1,15988 1929 1,144.45 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 1122017 10:24:03AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Project: Kuparuk River Unit Site: Kuparuk 20 Pad Avmn mT^ Nwm u.rr.ue Nwm: n.0 Mea. Flet WELLBORE DETAILS: 2G-06AL2 REFFAENCE INFORM PM Perenl WkllbOre: 2G -06A Gondlnab lNe)Rekmre: v1d2G0*,Tmr Nom Well: 213-06 srcero�naca,nn MD: 6300.00 veeeol Ov0)Rebrew. M Ses Lwd WeljOore: 204SAU eµ areb: Bo.Bs' eon S.A. M)Reb ... S-P.wK000E) Plan: 20.O6AL2_wpM (2G-MG-06AL2) umu�ecaemi. Latitude Meawntl Orom Rdereem: 2Gaa@ MounaaN RGOS) 0.00 HO caWaWn WM Miimum Curnlue Mean 5250 5000 4]50 4500 4250 ,4000 c 3750 0 vc3500 ;'3250 L r 03000 2750 s_ 2500 2250 2000 1750 EAF�MHES a GEmmpmry WELL DETAILS: AL1fPXO1l 2G-06 A +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 HO 5944135.21 508929.90 70° 15' 30.911 N 149° 55' 40.165 W Sec MD Inc Azi TVDSS +N/ -S +E/ -W Dleg TFace VSect Annotation 1 8300.00 82.31 49.07 5913.06 3422.25 3790.98 0.00 0.00 -3422.25 TIP/KOP 2 8400.00 96.57 73.23 5914.05 3470.00 3877.71 28.00 60.00 -3470.00 Start 28 dls 3 8800.00 87.54 185.10 5692.33 3255.07 4139.34 28.00 90.00 -3255.07 End 28 cls, Start 7 dls 4 9000,00 84.26 198.74 5906.70 3060.37 4098.28 7.00 104.00 -3060.37 4 5 9150.00 90.32 207.33 5913.80 2922.69 4039.71 7.00 55.00 -2922.69 5 6 9350.00 98.49 195.92 5898.40 2737.82 3966.31 7.00 306.00 -2737.62 6 7 9550.00 89.39 185.23 5884.63 2542.15 3929.89 7.00 230.00 -2542.15 7 8 9900.00 86.14 160.93 5898.47 2197.61 3971.61 7.00 262.00 -2197.61 Planned TD at 9900.00 Mean 5250 5000 4]50 4500 4250 ,4000 c 3750 0 vc3500 ;'3250 L r 03000 2750 s_ 2500 2250 2000 1750 EAF�MHES a GEmmpmry e West( -)/East(+) (250 usB/in) 5650 213 213 AL1fPXO1l A 6 5700"As� e o I mrt28 ft � �I Q 5750 21 Q � JI 4 AL TM -- V 5 ry 4 5800 2G MA T04- - 2 6aG MAL22 G ALZ-0 1213 G AL2 1 5850 - e West( -)/East(+) (250 usB/in) 5650 5700"As� e o I � �I Q 5750 Q � JI V ry 4 5800 1213 G AL2 1 5850 - 5900 "%dls'Surt b dk 5 2G4 6I2G AL2 [nd - fi000 6050 6100 -0 -06 f�ja5 Vertical Section at 180.00° (50 ustt/in) ConocoPhillips 2"3r]GLl 20402002 20 -0@(i -0I Project: Kupaluk River UnH Sita: Kuparuk 2G Pad V=w Tl_ft. uoy�.u�xmm. n.1a• Mq ,,,:x F.M WELLBORE DETAILS: 2G -DBA REFERENCE INFOWTION Parent Wellbore: 2G-06 ha M:EI Refertrca: WdI zca, ix. Nunn VmfiOa IN0) Rafnmm' 2GO6 Q 14000usfl RGa61 Wall: 2264 so-areln: sr4e4e� Tie on MD: 8100.00 sa<r NG1Remaxe: sla-1DM.'ONEI Wellbore: 2G -06A lei MeasvW DWM Rely .2G06Q 14oC ORGt Plan: 2G-06A_wp06 (MC 6I234eA) MOEM eooMm+ cikum. he : Mlnmam C lia 24' IM.4-04 +I-�riWif'.I SY .p+��yjy�� I`aG�EaoHES J C92F.1p Ji n3�4ii 2G-06 ® 140.00usH (2G-06) \I !mli`b-i ri 00 1800 2100 2400 2100 3000 3300 3600 MO 4200 4500 48 West( -)/East(+) (300 usft/in) I ■ 7 2G-06 Proposed CTD Schematic 16" 62# H-40 shoe 0- 110' MD 9-5/8" 36# J-55 shoe @ 3134' MD High Expansion Wedge @ 8095' M0, 38.01.49.06 Partial Window @8107'-8109'MID Failed High Expansion Wedge Last Tag @ 8136' MD High Expansion Wedge @ 8134' MD Lower Packer from Old Completion @ 81158'M A5 -sand perfs squeezed 8188'-8198'MD A4- sand perfs squeezed 8216' - 8246' MD 7" 26# J-55 shoe @ 8449' MD 3.1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" DS landing nipple @ 525' MD (2.875" min ID) 3-1/2" Camco MMG gas lift mandrel @ 2952', 4946', 6250', 7246', and 7898' MD Baker 3-1/2" PBR @ 7957' MD (2.98" ID) Baker FHL packer @ 7968' MD (3.03" ID) 3-1/2" DS landing nipple @ 8011' MD (2.813" min ID) 3-1/2" tubing tail @ 8043.6' MD (8048' PDC) 2G -06L1 PB1 TD @ 8,330' MD Washout, Cavings, and Packoffs @ —8170' MD 2G-06AL2-01 wp03 TO @ 9,900' MD Liner top at 8006' MD 2G-06AL2 wp03 TD @ 9,900MD Liner Billet @ 8,400' MD 2G-06ALi wp05 TO @ 9,750' MD Liner Billet @ 8,300' MD 2&06A wp06 TO @ 9.750' MD Liner Billet @ 8.400' MD TRANSMITTAL LETTER CHECKLIST WELL NAME: _ Clic OC LZ PTD: /Development _ Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: leu x�c rc4 / ✓W POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for as new wellbore segment of existing well Permit LATERAL No. C-� API No. 50-�- Z//U �. V1 (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company- Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company -Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. hi addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: / ✓ Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL -490100 Well Name: KUPARUK RIV UNIT 2G-06AL2 Program DEV Well bore seg Q PTD#:2190210 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV / —W GeoArea 809 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven.. gas conforms to AS31 <05.030(y1.A),(j,2.A-D) _ _ _ _ _ _ _____ _ _ _ NA _ _ ......... 1 Permit fee attached .. ................ .... ___ NA ........ _.. _. 2 Lease number appropriate---- - - - - - - --- - - - - - - - - - .. - - - - - - - - - Yes _ ... _ Entire Well lies within ADL0025656., _ _ ..... 3 Unique well. name and number_...... . . ...... .................. Yes ......-- 4 Well located in a. defined pool _ _ _ _ _ _ _ _ _ - - . .... . . . . ..... . . Yes - - - - KUPARUK RIVER, KUPARUK RIV OIL - 490100.. - 5 .Well located proper distance from drilling unit. boundary. _ - - - - - _ . _ _ _ Yes _ . _ Kuparuk River Oil POOL governed by Conservation Order No. 432D 6 Well located proper distance from other wells _ _ _ _ _ _ - - - - Yes _ _ _ _ Conservation Order No. 432D has no interwell_spacing _restriclions, Wellbore will be more than 500' 7 Sufficient acreage available in drilling unit. _ _ _ _ . . . .. . . . . ..... Yes _ _ .. from an external property line where ownership orlandownership-changes. As proposed,. well will.. _ 8 If deviated, is. wellbore platincluded_ _ _ _ _ _ _ _ _ _ Yes _ _ .. conform to spacing. requirements.. 9 Operator only affected party- - - .... - - - - - - - - - . - - - - - Yes- 10 Operator has appropriate bond in force .... ..... ........ ............ Yes..-.-------.. Appr Date 11 Permit. can be issued without conservation order--- - - - - - -- - - - - - - ------ - - - - - - Yes _ _ .......... 12 Permit can be issued without administrafive.approva_I __ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ Yes ... SFD 2/11/2019 13 Can permit be approved before 15-day wait _ _ _ _ - -_.... Yes .................... 14 Well located within area and strata authorized by. Injection Order # (put 10# in.comments)_(For. NA _ _ _____ 15 All wells. within 1/4-mile area of review identified (For service well only). _ _ _ _ .. _ _ _ _ NA --- - - - - --- - - - - - 16 Pre-produced injector: duration of pre-production Less then 3 months _(For service well only) .. NA. . . .. . . . . . . ....... . . . . . 18 Conductor string.provided - - - --- - - - - - - -- - - - - - - --- - - - - ----- - - - - - - - NA- - - - .... Conductor set for KRU_ 2G-06 _ Engineering 19 Surface casing protects all*nown USDWs _ _ _ _ _ _ _ _ _____ _ _ _ _ - - - . - ... NA. - _ _ _ _ Surface casing set in KRU 2G-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 rs9- - - - - - - - ----- - - - - - - --- 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 If a, re-drill, has 10-403 for abandonment been approved _ _ _ - - - NA 26 Adequate wellbore separation proposed... _ _ _ _ .. ....... _ _ _ Yes _ _ AntireoUision analysis complete; no major risk failures ........ 27 If diverter required, does it meet regulations _ _ _ __ _ __ _ _ _ _ ___ _ _ _ _ NA_- 28 Drilling fluidprogramschematic & equip list adequate_ _ .. _ _ . _ _ _ .. _ _ _ _ Yes _ _ _ - Max formation_ pressure is 4908 psig(15.5 ppg EMW ); will drill w/ 8.6 ppg EMW and maintain overbalw/ MPD Appr Date VTL 2/19/2019 29 BOPEs, do they meet regulation --- - - - - - - - - - - - ---- - _ Yes 30 BOPE press rating appropriate; test to-(put prig in comments)_ . _ _ _ _ _ _ Yes - - - - MPSP is 4320 psig; will test BOPS to 4800.psig 31 Choke manifold complies w/API_RP-53 (May 84). _ _ _ _ ... - - - _ Yes _ . . . ... . . . ........ . . . . . .. . 32 Work will occur without operation shutdown. . . .. . . . . . ........ . _ _ Yes 33 Is presence of H2$ gas probable _ _ _ _ __ _ _ _ _ __ _ __ _ _ _ _ _ _ _ ... _ _ Yes _ H2S measures required _ _ _ _ ...... - - - _ ... - 34 Mechanicaloondition of wells within AOR verified (Forservice well only) _ _ _ _ _ NA... . . . . . . . ... . . . . . . ...... . . . . . . .... . . . . . . ......... . 35 Permit can be issued w/o hydrogen_ sulfide measures ..... _ _ _ _ .... No _ .. _ _ _ Wells on2G-Pad are H2S-bearing. H2S measures required, Geology 36 Date presented on potential overpressure zones _ _ _ _ ....... _ Yes _ _ ... Max. potential-res. pressure is 15.5 ppg EMW; expected. res. pressure. is 12.4 ppg. EMW.. Well will be 37 Seismic analysis of shallow gas zones _ _ _ _ _ _ _ _ _ ____ _ _ _ _ _ _ _ _ _ NA.... drilled using 8,6-ppg mud,.a coiled-tubing rig, andmanaged.pressure drilling techniqueto control. Appr Date 38 Seabed condition survey (if off-shore) _ _ _ _ _ - _ _ NA _ _ formation pressures and stabilize shale sections with constant BHP of about 12.4 ppg EMW. SFD 2/11/2019 39 _ .. _ Contact name/phone for weekly progress reports [exploratory only] _ _ - NA ... - NOTE: Chance of encountering free gas while drilling due to gas injection performed in-this area. Geologic Engineering Public Commissioner: Date: Commissioner Date Commissioner Date