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217-116
DATA SUBMITTAL COMPLIANCE REPORT 1/10/2018 Permit to Drill 2171160 Well Name/No. KUPARUK RIV UNIT 2A-22AL1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50.103-20221-60-00 MD 17619 TVD 5946 Completion Date Completion Status 1-0I1- Current Status 1-0I1 UIC No REQUIRED INFORMATION Mud Log No I Samples No ./ Directional Survey Yes DATA INFORMATION List of Logs Obtained: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No ED C 28687 Digital Data ED C 28687 Digital Data ED C 28687 Digital Data ED C 28687 Digital Data Log C 28687 Log Header Scans ED C 28770 Digital Data ED C 28770 Digital Data ED C 28770 Digital Data ED C 28770 Digital Data ED C 28770 Digital Data ED C 28770 Digital Data ED C 28770 Digital Data ED C 28770 Digital Data ED C 28770 Digital Data ED C 28770 Digital Data ED C 28770 Digital Data ED C 28770 Digital Data ED C 28770 Digital Data Interval OH/ Start Stop CH Received Comments 10/16/2017 Electronic File: 2A-22AL1 EOW - NAD27.pdf 10/16/2017 Electronic File: 2A-22AL1 EOW - NAD27.txt 2171160 KUPARUK RIV UNIT 2A-22AL1 LOG HEADERS 11/2/2017 Electronic Data Set, Filename: 2A-22AL1 GAMMA RES.Ias 11/2/2017 Electronic File: 2A-22AL1 2MD Final.cgm, 11/2/2017 Electronic File: 2A-22AL1 5MD Final.cgm' 11/2/2017 Electronic File: 2A-22AL1 5TVDSS Final.cgm- P 11/2/2017 Electronic File: 2A-22AL1 2MD Final.pdf ' P 11/2/2017 Electronic File: 2A-22AL1 5MD Final.pdf 11/2/2017 Electronic File: 2A-22AL1 5TVDSS Final.pdf• 11/2/2017 Electronic File: 2A-22AL1 EOW - NAD27.pdf . 11/2/2017 Electronic File: 2A-22AL1 EOW - NAD27.txt " 11/2/2017 Electronic File: 2A-22AL1 Survey Listing.txt 11/2/2017 Electronic File: 2A-22AL1 Surveys.txt 11/2/2017 Electronic File: 2A-22AL1_Final Surveys TD 17619.csv 11/2/2017 Electronic File: 2A-22AL1_Final Surveys TD 17619.xlsx 0 0 14109 17619 (from Master Well Data/Logs) AOGCC' Page l of Wednesday, January 10, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1/10/2018 Permit to Drill 2171160 Well Name/No. KUPARUK RIV UNIT 2A-22AL1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20221-60.00 MD 17619 TVD 5946 Completion Date ED C 28770 Digital Data ED C 28770 Digital Data ED C 28770 Digital Data ED C 28770 Digital Data ED C 28770 Digital Data ED C 28770 Digital Data Log C 28770 Log Header Scans Well Cores/Samples Information Name INFORMATION RECEIVED Completion Report Y Production Test Information Y / NA Geologic Markers/Tops Y COMPLIANCE HISTORY Completion Date: Release Date: 9/6/2017 Description Comments: Interval Start Stop Completion Status 1-0I1 Current Status 1-0I1 UIC No 11/2/2017 Electronic File: 2A- 22AL1 _25_tapescan_BH I_CTK.txt 11/2/2017 Electronic File: 2A- 22AL1_5_tapescan_BHI_CTK.txt - 11/2/2017 Electronic File: 2A-22AL1_output.tap 11/2/2017 Electronic File: 2A-22AL1 2MD Final.tif 11/2/2017 Electronic File: 2A-22AL1 5MD Final.tif 11/2/2017 Electronic File: 2A-22AL1 5TVDSS Final.tif 0 0 2171160 KUPARUK RIV UNIT 2A-22AL1 LOG HEADERS Directional / Inclination Data Y Mechanical Integrity Test Information Y / NA Daily Operations Summary Y Date Comments Sample Set Sent Received Number Comments Mud Logs, Image Files, Digital Data Y / NA Core Chips Y / NA Composite Logs, Image, Data Files Y Core Photographs Y / NA Cuttings Samples Y / NA Laboratory Analyses Y / NA AOGC(C Page 2 of 3 Wednesday, January 10, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1/10/2018 Permit to Drill 2171160 Well Name/No. KUPARUK RIV UNIT 2A-22AL1 MD 17619 TVD 5946 C pI tion Date Compliance Reviewed By�/ _ �/`�---- Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20221-60-00 Completion Status 1-0I1 Current Status 1-011 r UIC No Date: AOGCC Page 3 of 3 Wednesday, January 10, 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION I IIS-VGI V GLJ NOV 0 6 2017 WELL COMPLETION OR RECOMPLETION REPORT AN0k9Mk; 1a. Well Status: Oil ❑Q + Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.1 m GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No. of Completions: 1b. Well Class: Development ❑+ • Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 10/7/2017 14. Permit to Drill Number / Sundry: 217-116 ' 3. Address: P.O. Box 100360 Anchorage, AK 99510.0360 7. Date Spudded: 10/3/2017 15. API Number: 50-103-20221-60-00 4a. Location of Well (Governmental Section): Surface: 766' FSL, 227' FWL, Sec 13, T11N, R8E, UM Top of Productive Interval: 1540' FNL, 1679' FEL, Sec 16, T11 N, R8E, UM Total Depth: 1108' FNL, 4129' FEL, Sec 16, T11 N, R8E, UM 8. Date TO Reached: « 1-0!4!2947 16. Well Name and Number: KRU 2A-22AL1 9. Ref Elevations: KB:135 GL:94 BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk Oil Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25570, ADL 25571 , 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 498620 y- 5960177 Zone- 4 TPI: x- 6736g4 ut041SS y-39%6677 91454110 Zone- 4 Total Depth: x- 483705 y- 5963610 Zone- 4 11. Total Depth MD/TVD: 17619/5946 , 19. DNR Approval Number: 9318991000,931892000 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/fVD: 1543/1497 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/ND: S 6q i 5x85 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 ND HOLE SIZE CEMENTING RECORD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 16 62.6 H-40 41 121 41 121 24 250 sx AS 1 95/8 40 L-80 41 4928 41 2937 12.25 820 sx AS III Lead 890 sx Class G 7 26 L-80 38 14787 38 6137 8.5 260 sx Class G 23/8 4.7 L-80 14182 14434 5762 5874 3 N/A Solid Liner 2 3/38 4.7 L-80 14434 17619 5874 5946 3 Slotted Liner 24. Open to production or injection? Yes ❑� No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Slotted Liner at 14434 - 17619 MD and 5874 - 5946 COfdPLET ION nATEI _ IC> h? 1_:� VERIFIED - 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3 1/2 14265 14103/5716 27/5789 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑� Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) 1AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 10/22/2017 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 10124/2017 Hours Tested: 15 Production for ITest Period Oil -Bbl: 357 Gas -MCF: 1 226 Water -Bbl: 2708 Choke Size: 176 Gas -Oil Ratio: 634 MMCFIbbI Flow Tubing Press. 226 JCasinq Press: 1 1330 Calculated 24 -Hour Rae Oil -Bbl: 571 Gas -MCF: 1 362 Water -Bbl: 4 4 Oil Gravity- API (corr): 2 Form 10-407 Revised 5/2017 1/iL 11 /15-J/Y CONTINUED ON PAGE 2 RBD,%!S LV 1,0V1 7 2G17 Submit ORIGINIAL onl -fM fit' ul11,117 28. CORE DATA Conventional Corals): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No I] If Yes, list formations and intervals cored (MD/TVD, Fronri 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 1543 1497 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 15047 5886 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk C TD 17619 5946 Formation at total depth: Ku aruk D 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematics Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, naleontoloaical report. nroduction orwellr20 AAC 25,070 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Kai Starck Contact Name: Mike Callahan %nG Authorized Title: CTD Team Lead Contact Email: Mike.Callahan ro.com Authorizedq Contact Phone: g07-263-4180 Signature: Date: -- 91 �/ 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 10404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item ta: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 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 10-007 Revised 5!2017 Submit ORIGINAL Only 2A -22A and 2A-22AL1 Completed Wellbore Schematic 16" 62# H-40 shoe @ 121' MD 9-5/8" 40# L-80 shoe @ 4928' MD ILiner Top @ 14,181' MD with Northern Solutions LTP 14,242' MD KOP @ 14,308' MD 3-1/2" XL Monobore WS set in cement pilot hole C/A -sand parts 14,302'- 14,317' MD 14,330' - 14,348' MD 14,352' - 14,378' MD 3-1/2" DS Nipple (min ID 2.812") @ 532.6' MD 3-1/2" 9.3# L-80 ELIE 8rd Tubing to surface 3-1/2" Camco MMG gas lift mandrel @ 3342', 7554', 10,757', 12,955', and 14,018' Baker 3-1/2" PBR @ 14,080' MD (2.98" ID) Baker FHL packer @ 14,103' MD (2.93" ID) 3-1/2" Carrico DS landing nipple @ 14,153' MD (2.812" min ID, No -Go) Poor Boy Overshot @ 14,205' Baker KBH-22 Anchor SA @ 14,226' MD Baker SAB -3 Packer @ 14,227 3-1/2" Camco D landing nipple @ 14,242' MD (milled out to 2.80" min ID, No -Go) 3-1/2" WLEG @ 14,263' MD 14,239' MD it squeze 14,434' MD Slotted 7" 26#14, 87' shoe��l� @ 15,047' 1 o Ported Bull Nose @ 14,787' MD KOP for AL1 off LT Billet /Deployment Sleeve 2A -22A TD @ 17,092' 016.015' MD 1 12-3/8" Slotted Liner Corxx hillips Well KUP PROD Attrit AlaR-well Wee avuuwl FINt 2A-22 12/512016 11-8si W12 1 912912014 1 45.901 611111995 Annotation - III End BNa AnnWNon Lass Moa By En4eand ---------------------- INNGERI a5.a -.----- La51Taa RKB 14,399.0 &SQ017 Rev Reason'. TAG, LINER TOP PACKER, GLV G0, SET 3 PATCHES(1-Leak2-Pmacdvel Carole, 101311201] u mg ngs Tubing 0 -caption Shng ma... ID (in) Depin In.. s« Depin Irvoj 1... w<pNXI Graae Tnp to nnvction TUBING Original 3112 29921'"'(711 14,264.6 5811.9 930'-80 ABM-EUE Completion Details Nominal lD Top @KS) Top LVD) (nKB) Top Incl l°1 linin Co. Co. (in) CONww]OR:a C -al 14225.8 5,788.0 52.60 SEAL ASSY BAKER KBH-22 ANCHOR SEAL ASSY 3.000 142261 5,788.6 52.58 PACKER BAKER SAB -3 PERMANENT PACKER 3.250 NIPPLE: a32e 14,2420 5,797.9 52.22 NIPPLE CAMCO D LANDING NIPPLE NO GO 2,750 14,262.7 5,8106 5173 WLEG WIRELINE ENTRY GUIDE, ELMD@14258 ON SAE 2.992 PERF 811712001 ki axl5 Perforations & Slots sn« xns Top lrvD) atm (M)/ snow op(XKBI BmIKKBI KKBj Na)Zone Dh N TVT Co. P 14,3020 14,317.0 5,835.1 5,844.4 C-0, 2A-22 &282000 4.0 APERF 212"1 DP, 180 ON 1 I 1 1 ph SURFACE.Q911I Stimulations & Treatments Peoppam Designee lml Peopw« In Foem«bn0bl Dale Mwka:1S539I Ed 121911002 Stimulations & Treatments YOlckan Pump PATCX:&3850 $tgx -E4 atm 2' Date Stign—t Eli /bbl) VOI 51urry(b011 1 -e) 14,302 0 14,3)8.0 12/912002 PATCH/ 8.6150 Notes: General & Safety End Dam I Annolatmn PATCH 6/1/2008 NOTETUBING PUNCH BETWEEN SAB -3 PACKER CA -2 PLUG IN TUBING STUB, 9 SHOTS w1ENTRANCE HOLE OF 0.19 PATCH: 91 - 11811008 NOTE: View Schematic wl Alaska Scnen ic9.0 PATCR 9x20 11152014 NOTE: 2 81'DS N P. @14152' RKP MAY BE DAMAGED FROM PULLING PLUG ON 11514 PATCH: 9 Con PATCH;9MO MawM:lor,].4 MwpeN', 199.0 MaMie1; 10.01] B LOCATOR: R.073 SEALASSY:I4N]3 PSR: 100]95 PACKER: 14 1.11 MPPIE: 14, 1528 PACYER: ta,kdo OYERSHOTa0ID5.• SEAL ASSY: I4,22a.6 PACKER: 14.226.7 NIPPUI.14220 WLEG: 14, 2827 APERF:N,A3.6143U0 t AHPP ', 4307 0 PRODOCT*B WU 4hg0 P.:143M.a AL Lnui 14,101 &17.619D �.�__♦�„KUP PROD CoroccIP"IIIIp$ len!' Well Attrit Na", IfiC. WeIIWreaPVUWI T 2A -22A NIPPLE 1 1201 12/512016 ILASTWO'. 9/2912014 1 45901 6/1111995 annoGllon Depen ) Ene Dxh Mnpplbn Lx:lmmay no """"""""""""""SIDIRR __- HANGER, 30 Last Tag. RKB 14,3990 99201] Rev Reason: Side Track lennaa 112/201] asmg Strings Casing Deapipt on OD(Im IOhn) Top(MB) act Di lnleB) Rl Dalai RVD1.. WVLen O._GrWa Top Th. CONDUCTOR 16 15.062 41.0 121.0 121.0 6258 H40 WELDED Con, DempipHo, OD (in) In (IN Top (MIN Sol Depth mrce) Set Depth MDL- MLen(L-10Ms TopTgread SURFACE 9018 8835 409 4,928.0 2,9363 40.00 LA0 BTC Cuing Deaalptlon OD(N) ID 9n) Tep RRUR Sat Dap'1XKB) SN DepeM1 FIND)... WIM1an 6.,. G,pM Top Thmmd CONDUCTOR, 41 nRT 0 PRODUCTION ] 6.276 38.3 14,)8).0 5,886,6 26-00 L-80 BTC -MOO e Depehl'B) Sm...5-in W11Len(I Gnoe Top TMead OaNlp Desnipeion ODFin) IDpn) Top IXU" S".."n"' NPWM sus ALaleral 2318 1992 15,0480 1),091.5 5,9434 460 L-80 STL Tubing Strings Tieing DescNphan string Nom an'ropinxa) set Depth ln.. set DBP' (ND) F... gaHileaa G,Me Top Domlaclion TUBING WO 2014 3112 2992 364 142125 5,)80.0 930 LA0 EUE8Rd Ma.: 3.34Is Completion Details Nominal ID Top (MIN Top RVOT tnxe) Top Ind Pl @m Can Com lin) 36.4 364 000 HANGER FMC TUBING HANGER 2992 532.6 5326 164 NIPPLE DS NIPPLE 2.812 SURFACE,N)IFI ID.0-. 14,0722 5,6983 56.28 LOCATOR LOCATOR SUB 2.970 14,0732 5,699.2 5626 SEALASSY SEAL ASSY.. STICK-UP =7-O. SWALLOW =14.6-6 3.000 Me,pM: ]39.9 14,0795 5.]02] 56.10 PBR BAKER POLISH BORE RECEPTACLE 2.980 14,102.6 5,]15] 55.54 PACKER BAKER FHL RETRIEVABLE PACKER 2.930 Party: A-' 14,152.9 5.744.6 54.31 NIPPLE CAMCO DS NIPPLE 2.812 Parc N: rep 142054 57757 5308 OVERSHOT POOR BOY OVERSHOT._ SWALLOW = SS -ft . 3.620 PATCN', 8.90 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) To Top Incl RATCN s.a4a Top.585 N..) F3,98 Oei Lom Run Dale ID lin) 8.585.0 3,9634 )3.60 3 PATCH UPPER AS16"SPA2"PIIP(SN: 101151200 1600 vanx:11,aza 35119)PATCH LATCH EA2525'x21/16"SPACERPIPE8 LATCH SEAL (SN: CPAL35068) DAL = SORT 1 vamx: sem.0 MID ID =160' varcx: g,ss0.o 8,6150 3.9919 ]3.53 PATCH LOWER 23Y PIIP PACKER (SN. CPP35132) DAL =4.01 I MIN ID =1.625 1W14I2017 1.620 9,399.0 4,2200 7278 PATCH UPPER 2.72" PIIP( SN: CPP35127) 11.6a OF 2 101142017 1.820 M.,p.I:1o.]sa4 1/16" SPACER PIPE 8 LATCH SEAL ASSEMBLY (SN: CPAL350059 )17.0]' GAL I MIN ID = 1.62" Q 15 MID ELEMENT TO BTM )) 9414.0 4,224.5 72.76 PATCH 3.5" PER (SN; CPBR35004) 301 x 21/16"SPACER lWlWO17 1.62) Room, 12a3D PIPE & LATCH SEALASSY ( SN: CPAL35050 ) DAL= M,75'11.62" ID 9,447.0 4,234.2 72.]2 PATCH 2.72" PIP PACKER( N: CPP3511714.01"GAL / 19132017 1.620 1.62"ID) Ma,o,et 14.01 96200 4,2859 7262 PATCH 2.72"PIIP (SN:CPP35108) 25.5' SPACER PIPE& 1 011 2/2 0 1] 1625 LATCH SEAL ASSEMBLY( SN: CPAL35056 I DAL = 30.86') LCDATDRi 14,0211 SEALAssY',14,022 9,650.0 4,294.8 ]2.8] PATCH 232" PIIP PACKER (SN:CPP35131/1.625'IDI OAL 4.10' ) 19122017 1e25 PBM: 140711.5 14,1800 5)606 5368 PACKER CATCHERON LINER TOP PACKER WI1.781 R 10/101201] pacxERi 1 VMa�4 NIPPLE (01 14,307.0 5,838.2 51.62[Whipstock 92fi201] 1.000 Perforations & Slots xlvvLEi 14,lug snore Oen Top aR. Mnt Top FNNBI BMFDKB) F 1X5,81 M.81 Zone Oah n) TmumERF Lom PACIaER:1umD 14,330.0 14,348.0 5. 5.8516 5,860.5 C-0, 2A-22 &V/2001 4.0 APERF 2.5"H, mating 1,80 BHIIP 180 deg he. 14,352.0 14,3)8.0 5,8522 5,869.8 A-3, 2A-22 0112/1995 6 0 IPEHF SINS TCP Type BH UP; 180 deg Oh: oriented 90 CCW f1hughslde OVERSHOT: 1429.4 Stimulations & Treatments SENAM1;14 6.e PACKER:1aZa67 P,oppmm DeslinM Do) Pmpwnt In Fo,mamn pe) Dare 12192002 Mandrel Inserts s 'FPLE: 14,z4zs tlI H raP(iVDI Tap,2K1 Iwo) Mab almeBMG N.Iae torah P (N) OD (in) Sary TVpe Type mo ) (313 Bt Conl 3,341.5 2,5032 CAMCO KBMG 0.1 1 GAB LIFT GLV BK 0.188 1,313.0 UP 1W1&20V WLEG, 14,331] 2 7,5539 3,707.5 CANDO KBMG 1 GAS LIFT OV BK 0.188 Be 19192017 3 10,]5]4 4,606.1 RAMBO KBMG 1 GA LIFT DMY BK 0000 0.0 19282014 FX -TE APERF: 149DZa1aa1>O NDE wngsmek 14.3].0 D FRAC; 1a,3uD 4 12,9550 5,2518 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 9/3l MR4 tae AL ae{ 141 10 5 14.017,9 5,6690 CANDO KBMG 1 GAS LIFT DMY BK 0.000 OD 10/11112017 APERF: 14,99].a14,3N 0 Notes: General & Safety PERF: 140 iPil,s/BD End DAR nnolanun NOTE. W092e. PRODUCTION', 38.314,Ta].O A... 15W 1] W15J �, UP PROD K Conoa;Phlllips „'' walaaFit NaSka.inC. waloore nPVDwI Flea 2A-22AL1 12/512018 i 1 1 45,901 &1111995 AnnoWl .e IM(B) EMD& Annul . Lu1MM By Fn00eb ............. XANGER, 38.0 Rev ReBSOn: Side Track µ00a8 1112/201] astng rings Casm9 0escrlpdon o0 (n IO IIN iap(aKB) set Dept MKB) sM Degn IIVD1... wvLen O-. Ga0e M AL Lateral 2318 7992 14,181.8 1],6190 4.60 LA0 5Tp"" Stimulations & Treatments Proppant DcslgnM X161 P,ppanl In 1—,ton 1161 Oale 2/90002 M LONOOCTOR; 41,p1210 NIPPLE: 02.6 YerN#, 3.9115 SURFACE, 40.8-0,9$8.0 1 YWN: 7559.9 PATCH; B,SB5.0 PATCH: 9,8150 PATCH, 9,3990 PATCH, 94190 PATCH; 9,44]0 PATCH; 9,6M.0 PATCH; 9.8 .0 M�r]41; 10.]5)4 NaMN', 128580 YvgrM 14,0119 LOCATOR: 14083 SEALA88Y: 14.082 ASK 14.M.5— PACKER: 14,1@e NIPPLE, 14, 1529 PAGHE 8.14180,0 r ovERSHm;14,$as4 sEPl Assv; w,Y6.e PACKER. NIPPLE: 14&9.0 ..G,1426[] APERF, 14,90 4,9170 M1 k: 14,99]0 PROO=nON: W;14.i O FRAC; 14,720 I I{I AL , 14,181a11,6190--------1 . .jperations Summary (with Tirnelog uepths) 2A-22 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log StartTana End 7me Dur (tat ( ) Phase OP code Activity Cetla Time P-T-% Operation Start Depth (WS) De Entl Depth (N(e) 9/23/2017 9/24/2017 8.00 MIRU MOVE MOB P Trucks to move rig on location - PJSM 0.0 0.0 16:00 00:00 with Peak. Broke drive shaft yoke pulling sub off well @ 18:30. Replacement on location @ 20:30. Off 3M with both modules @ 21:30 enroute to 2A 9/24/2017 9/24/2017 3.50 MIRU MOVE MOB P Continue travels to 2A 0.0 0.0 00:00 03:30 9/24/2017 9/24/2017 1.70 MIRU MOVE MOB P Arrive on 2A pad, de-jeep modules. 0.0 0.0 03:30 05:12 Prep cellar with herculite and plywood 9/24/2017 9/24/2017 1.00 MIRU MOVE MOB P Go to spot sub. Pad soft where gravel 0.0 0.0 05:12 06:12 added to level up. Became stuck. Sow breaks radiator hose. 1 cup spill to pad. Call for Mats - plywood to spot. Wail on Peak mechanic 9/24/2017 9/24/2017 3.30 MIRU MOVE MOB P Leave 2A with one Sow to get shop 0.0 0.0 06:12 09:30 and halfway house. Sow on 3M drive line repaired. Setting mats for spotting rig. Leave 3M with shop and halfway house. At CPF 3 trailer hauling shop looses wheel bearing. Peak mechanic to CPF3 to repair trailer. More mats on 2A. Lay out 9/24/2017 9/24/2017 1,50 MIRU MOVE MOB P Leave CPF 3 with halfway house to 0.0 0.0 09:30 11:00 2A. Arrive on 2A @10:30. Swap out sow on sub 9/24/2017 9/24/2017 2.00 MIRU MOVE MOB P Mats all positioned. Spot sub on well 0.0 0.0 11:00 13:00 22 9/24/2017 9/24/2017 2.00 MIRU MOVE MOB P Back up pits and spot more mats. 0.0 0.0 13:00 15:00 Spot in Pits 9/24/2017 9/24/2017 2.50 MIRU MOVE RURD P Start working rig up checklist, R/U 0.0 0.0 15:00 17:30 PUTZ, lower stairs 9/24/2017 9/24/2017 4.50 MIRU WHDBOP NUND P Change out stack, grease tree, NU 0.0 0.0 17:30 22:00 BOPE " Rig accept: 22:00 hrs 9/24/2017 9125/2017 2.00 MIRU WHDBOP BOPE P Fluid pack, begin BOPE test at 22:15 0.0 0.0 22:00 00:00 ms 9/2512017 9/25/2017 5.00 MIRU WHDBOP BOPE P Continue BOPE test. ROPE test 0.0 0.0 00:00 05:00 completed at 5:00 bra 9/25/2017 9/25/2017 2.10 MIRU WHDBOP PRTS P PT PDL's & TT line - test gas alarms 0.0 0.0 05:00 07:06 9/25/2017 9/25/2017 1.40 PROD1 RPEQPT PULD P PJSM, M/U BHA #1 to mill cement 0.0 68.5 07:06 08:30 pilot hole, Check pack offs, Install checks in UQC, Make up to coil and surface test 9/25/2017 9/25/2017 2.80 PROD1 RPEQPT TRIP P RIH, Surface test agitator@ 700' - 68.5 14,130.0 08:30 11:18 good 9/25/2017 9/25/2017 0.30 PROD1 RPEQPT DLOG P Log Kt for+7 foot correction, 14,130.0 14,155.0 11:18 11:36 PUW=39K 9/25/2017 9/25/2017 0.30 PROD1 RPEQPT TRIP P Continue in well, Encountered cement 14,155.0 14,217.0 11:36 11:54 stringer @ 14205. Set down, PUH kicked on pump didn'tsee anything. Continue in to dry tag TOC @ 14217 Page 1121 ReportPrinted: 10/1712017 . operations Summary (with Timelog uepths) 2A-22 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stan Time End Time Due (he) Phase Op Code Activity Code Time P -T-% Operation (ftKB) End Depth(fd(B) 9/25/2017 9/25/2017 4.30 PROD1 RPEQPT MILL P 14217 Tag cement, PUH Pumps on @ 14,217.0 14,340.0 11:54 16:12 1.79 BPM Q 3515 PSI FS, BHP=3335, RIW=8.6K @ 1.1K DHWOB. Cement ROP down to 25-30 ROP @ 14225 and down to TO 9/25/2017 9/25/2017 0.70 PROD1 RPEQPT WPRT P Wiper up hole, PUW=40K, Back ream 14,340.0 14,260.0 16:12 16:54 14285 to 14260 9/25/2017 9/25/2017 2.00 PROD1 RPEQPT REAM P Make reaming passes per procedure 14,260.0 14,290.0 16:54 18:54 160L, LS, 20R, LS. Dry drift transition area good 9/25/2017 9/25/2017 0.20 PROD1 RPEQPT OWFF P Shut down and monitor well for 14,229.0 14,229.0 18:54 19:06 pressure build up - No flow 9/25/2017 9/25/2017 2.30 PRODi RPEQPT TRIP P Trip out, EDC open 14,229.0 80.0 19:06 21:24 9/25/2017 9/25/2017 0.60 PRODt RPEQPT PULD P At surface, Flow check well, PJSM, 80.0 0.0 21:24 22:00 Lay down BHA #1 on dead well, Mill out @ 2.80 NoGo 9/25/2017 9/25/2017 0.70 PROD1 RPEQPT CTOP P Stab on well with nozzle. Jet stack to 0.0 0.0 22:00 22:42 remove cement debrie. Unstab inject and rack back 9/25/2017 9/25/2017 0.60 PROD1 RPEQPT PULD P PJSM, M/U BHA #2 HES caliper, 0.0 23.1 22:42 23:18 Surface test, cycle fingers. Tag up and set counters 9/25/2017 9/26/2017 0.70 PROD1 RPEQPT TRIP P Trip in with caliper 23.1 3,000.0 23:18 00:00 9/26/2017 9/26/2017 1.80 PRODi RPEQPT TRIP P Continue RIW with BHA #2 (caliper), 3,000.0 14,050.0 00:00 01:48 9/26/2017 9/26/2017 0.20 PROD1 RPEQPT DLOG P tie in for +4.1'correction 14,050.0 14,231.8 01:48 02:00 9/26/2017 9/26/2017 0.10 PROD1 RPEQPT TRIP P Continue RIH 14,231.8 14,330.0 02:00 02:06 9/26/2017 9/26/2017 0.20 PROD1 RPEQPT DLOG P Caliper log run #1, PUW = 42K, 50 14,330.0 14,000.0 02:06 02:18 fpm 9/26/2017 9/26/2017 0.20 PROD1 RPEQPT TRIP P Close caliper arms, RBIH 14,000.0 14,330.0 02:18 02:30 9/26/2017 9/26/2017 0.20 PROD1 RPEQPT DLOG P Open caliper arms, caliper log run #2, 14,330.0 14,000.0 02:30 02:42 50 fpm 9/26/2017 9/26/2017 2.20 PROD1 RPEQPT TRIP P POOH, tag up, flow check well 14,000.0 20.0 02:42 04:54 9/26/2017 9/26/2017 0.50 PROD1 RPEQPT PULD P PJSM, LD BHA #2 20.0 0.0 04:54 05:24 9/26/2017 9/26/2017 0.70 PROD1 RPEQPT PULD P PJSM, PU BHA#3 WS Setting 0.0 73.0 05:24 06:06 Assembly, tag up, open EDC 9/26/2017 9/26/2017 2.80 PROD1 RPEQPT TRIP P RIH with BHA #3 73.0 14,136.0 06:06 08:54 9/26/2017 9/26/2017 0.20 PROD1 RPEQPT DLOG P Log K1 for+3' correction 14,136.0 14,162.0 08:54 09:06 9/26/2017 9/26/2017 0.20 PROD1 RPEQPT TRIP P Continue RIH, weight check = 43K, 14,162.0 14,317.8 09:06 09:18 arrive at setting depth, close EDC, bring up pumps, release off WS, set down 4.3K WOB, leaving TOWS = 14,307', oriented 10" ROHS 9/26/2017 9/26/2017 2.50 PROD1 RPEQPT TRIP P POOH, PUW = 44K, check well for 14,317.8 73.0 09:18 11:48 flow, PJSM for LD R PU, tag up 9/26/2017 9/26/2017 0.50 PROD1 RPEQPT PULD P LD BHA #3 over a dead well 73.0 0.0 11:48 12:18 1 I Page 2121 Report Printed: 10/17/2017 operations Summary (with Timelog uepths) Am 2A-22 1W Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time I End Time our (hr) Phase Op Code Acdviy Cade Time P -T -X Operation Start Depth (WB) End Depth (111(13) 9/26/2017 9/26/2017 0.60 PROD1 WHPST PULD P Reconfigure & PU BHA #4, Window 0.0 74.0 12:18 12:54 Milling Assembly (10' pup, 0.6° AKO motor, string reamer, window mill), slide in cart, MU to coil 9/26/2017 9/26/2017 2.50 PROD1 WHPST TRIP P RIH with BHA #4, begin swapping to 74.0 14,135.0 12:54 15:24 used Power Pro 9/26/2017 9/26/2017 0.20 PROD1 WHPST DLOG P Tie into K1 for a +4' correction 14,135.0 14,170.0 15:24 15:36 9/26/2017 9/26/2017 0.40 PROD1 WHPST TRIP P Continue RIH, weight check =44K, 14,170.0 14,307.0 15:36 16:00 dry tag TOWS right on depth at 14,307', PUW = 44K, bring up pump, RBIH 9/26/2017 9/26/2017 2.00 PROD1 WHPST WPST P Begin milling wiindow in 7" casing as 14,307.0 14,308.8 16:00 18:00 per procedure (tagged TOWS at 14,306.08' pumping 1.8 bpm), FS = 431 psi, CWT = 6.6K, 9/26/2017 9/26/2017 4.00 PROD1 WHPST WPST P 1.77 bpm, CT 4196 psi, CT Wt 3.66 k 14,308.8 14,327.0 18:00 22:00 lbs, WOB 1.33 k Ibs. Saw mill off @ 14,311.6'- BOW. Bottoms up sample from 14,325' formation sand + glauconile per Geo. CT 3.9 k lbs, WOB 2.7 k lbs, ROP 10 ft/hr 9/26/2017 9/26/2017 1.00 PROD1 WHPST REAM _ P Perform back reamin/dressing passes, 14,308.8 14,327.0 22:00 23:00 14300 - 14,315', as drilled, 10 *ROHS, 40 ` ROHS, & 340 'ROHS. Little motor work -15-20 psi over free spin. Send 5x5 sweeps. Dry drift clean, PU 30k Ibs 9/26/2017 9/26/2017 0.50 PROD1 WHPST OWFF P SBHP/ flow check, park@ 14191'- 14,327.0 14,191.0 23:00 23:30 5741' TVD. IA pressured up from tubing hole at 9426'. Bleed IA to 143 psi observe it slowly build to 173 psi while monitoring. Baker Coil track BHP stabilized at 2506 psi for 8.39 ppg EMW. Flow check at stack - Good. Mud weight in and out tested w pressurized mud balance 8.8 heavy Ppg- 9/26/2017 9/26/2017 0.30 PROD? WHPST CIRC P Establish circulation rate of 1.80 bpm 14,191.0 14,175.0 23:30 23:48 while slowly PUH. CT 4192 psi, Annular 3778 psi, Bore 4198 psi, Expro WH 140, (upstream of micro motion), CTES transducer #6, 17 psi, (downstream of the micro motion). Note, micro motion making more noise than usual and we suspect has impeded flow from some sort of blockage. 9/26/2017 9/27/2017 0.20 PROD1 WHPST TRIP P Park, Open EDC, rate to 2.0 bpm, 14,175.0 13,260.0 23:48 00:00 1 1 POOH chasing sweep to surface. 9/27/2017 9/27/2017 2.10 PROD1 WHPST TRIP P Continue to POOH, @ -700' out MM 13,260.0 100.0 00:00 02:06 rate and density reading became erottic. Monitored returns, rate and density at the shaker, 8.8 ppg heavy, all looks good. Contiune out of hole. 9/27/2017 9/27/2017 1.00 PROD1 WHPST PULD P PJSM, Bleed IA from 589 psi to 209 100.0 0.0 02:06 03:06 psi in 3 min, built back to 390 once S/I. Flow Check - Good, LD BHA #4, Bit 2.79 no go, Mill 2.78 no go, decent whorl pattern in center of window mill. Page 3/21 Report Printed: 10/17/2017 - uperations Summary (with Timelog Depths) 2A-22 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur(hr) Phase Op Corte Actn iq Corte Time P -T -X Operation Start Depth (MB) End Depth(MB) 9/27/2017 912712017 1.20 PROD'i DRILL CIRC P Jet Stack, snake and flush out MM, 0.0 0.0 03:06 04:18 retrieved 3 quarter sized pieces of flattened aluminum (billet) from the MM. Blew down choke. Changed out upper Quick conned 9/27/2017 9/27/2017 0.90 PROM DRILL PULD P PU BHA#5 (agitator, 2.3°+AKO 0.0 78.0 04:18 05:12 motor, & RR Hughes bit) 9/27/2017 9/2712017 2.80 PROD1 DRILL TRIP P RIH, surface test agitator, good 78.0 14,135.0 05:12 08:00 9/27/2017 9/27/2017 0.20 PROM DRILL DLOG P Tie into K1 for+3' correction, close 14,135.0 14,163.0 08:00 08:12 EDC, weight check = 38K 9/27/2017 912712017 0.30 PRODt DRILL TRIP P Continue RIH, pumps off - clean 14,163.0 14,327.0 08:12 08:30 through window, RIW = 9.2K off bottom, PUH to adjust TF per DD, RBIH 9/27/2017 9/27/2017 0.30 PROD1 DRILL DRLG P OBD, pumping 1.8 bpm, FS = 850 psi, 14,327.0 14,351.0 08:30 08:48 CWT = 7K, WOB = 1.6K, circ pressure = 4753 psi, annular = 3754 psi, WHIP = 0 psi, dip = 1151 psi. WOB up to -4.5 K, PU at 14,345', PUW = 38K, RBIH & continue drilling, again at 14,352, rate out dropped to 1 bpm 9/27/2017 9/27/2017 0.50 PRODt DRILL DRLG P BOBO, pumping 1.8 bpm, rate out = 14,351.0 14,367.0 08:48 09:18 1.09 bpm, FS = 762 psi, PU at 14,355', PUW = 40K, pulling negative WOB up to 4K (possibly hanging up in window), PU at 14,362', PUW = 38 K, 9/27/2017 9/27/2017 0.70 PROD1 DRILL DRLG P Go to near total losses at 14,357' (.25 14,367.0 14,390.0 09:18 10:00 bpm returns), returns begin to heal with drilling, improving to .98 bpm returns by 14,387', pump 5 x5 sweeps at 14,387', continue to pull heavy on PU's (negative WOB up to -6K), call EOB at 14,390', returns at -59% 9/27/2017 9/27/2017 0.20 PROM DRILL TRIP P Begin POOH, PUW =42K 14,390.0 14,135.0 10:00 10:12 9/27/2017 9127/2017 0.50 PROD1 DRILL DLOG P RIH to tie into K1 for+0.5' correction, 14,135.0 14,135.0 10:12 10:42 log RA at 14,315', (putting TOW at 14,308'& BOW at 14,314), continue POOH, close EDC above TOC. 9/27/2017 9/27/2017 2.40 PROD1 DRILL TRIP P Continue POOH, holding 11.4 ppg 14,135.0 _78-0- 8010:42 10:42 13:06 schedule, tagged up, space out, WHP at 790 psi 9/27/2017 9/27/2017 1.40 PROD1 DRILL PULD P PJSM for PD & PUD, PUD BHA #5, bit 78.0 0.0 13:06 14:30 came out a 1-1, pumping manage pressure losing -12 bph, observe marks on motor, possibly from window 9/27/2017 9/27/2017 1.10 PRODt DRILL PULD P Reconfigure & PD BHA #6 Lateral 0.0 78.0 14:30 15:36 Drilling Assembly (agitator, 0.5° AKO motor, RR 0-0 HYC B8 Edge), slide in coil, MU to coil 9/27/2017 9/27/2017 2.50 PROD1 DRILL TRIP P RIH with BHA #6, close EDC, surface 78.0 14,141.0 15:36 18:06 test agitator, good 9127/2017 9/27/2017 0.20 PRODi DRILL DLOG P Tie into the Kl marker for a+2.5' 14,141.0 14,169.0 18:06 18:18 I correction Page 4121 ReportPrinted: 10117/2017 operations Summary (with Tirnelog Lfepths) 2A-22 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-% Operation (i1Ke) End Depth (110) 9/27/2017 9127/2017 0.30 PROD1 DRILL TRIP P Wt check, 33k lbs, continue to RIH 14,169.0 14,390.0 18:18 18:36 9/27/2017 9/27/2017 1.10 PROD1 DRILL DRLG P Rate 1.80 in, 1.10 out, CT 4600 psi, 14,390.0 14,534.0 18:36 19:42 free spin diff 1040 psi, Annular 3622 psi w choke wide open. CT RIH Wt 8.7 k lbs. OBD, CT wt, 6 k lbs, WOB 2.5 k Ibs, ROP 160 fUhr - 0.63 bpm losses - 38 bbl/hr Losses quickly healed in 15 min of drilling from 40% stabilizing @ 27%- 30 bbl/hr Average ROP over interval drilled - 131 if/hr average 9/27/2017 9/27/2017 1.80 PROD1 DRILL DRLG P PU @ 14,534' for missed survey, 33k 14,534.0 14,777.0 19:42 21:30 lbs, zero WOB, RBIH, BOBD stall @ 14553, PU Wt 37k, returns fell from 1.3 to .7 bpm, second stall 14,556, PU 38 k lbs 1.77 in 1.12 out, CT Wt 3.66 k lbs, WOB 2.7 k lbs, ROP 160 ft/hr IA 1016, OA 280 psi. Mud weight out started falling off@ — 14,613'- 20:27 - not cleaning the hole... 14,731', stacked weigh, ROP dropped, losses increased to - 1 bpm, Average ROP over interval drilled - 135 ff/hr average 9/27/2017 9/27/2017 0.90 PROD1 DRILL DRLG P PU to rotate HOT, BHA wiper 100', PU 14,777.0 14,855.0 21:30 22:24 Wt 38 k. RBIH 1.80 bpm in, 0.78 k bpm out, CT 4600 psi, RIH Wt 6 k lbs, free spin 1140 psi OBD, CT Wt 4 k, WOB 2.5 k lbs, ROP 60-160 iVhr 14,811', 1.80 bpmin , 0.48 bpm out Average ROP over interval drilled - 87 ft/hr average 9/27/2017 9/27/2017 0.20 PRODt DRILL WPRT P Wiper to window-500', PU40klbs 14,855.0 14,365.0 22:24 22:36 send 25 bbl ultra hi vis pill— 150k LSRV Losses healed slightly, then dropped again as we drug past 14,457' 9/27/2017 9/27/2017 0.20 PROD1 DRILL WPRT P RBIH RIH Wt 7 k lbs 14,365.0 14,855.0 22:36 22:48 Page 5121 ReportPrinted: 10117/2017 Uperations Summary (with'Timelog Depths) 2A-22 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Stan Depth (RKB) End Depth(fiKB) 9/27/2017 9/27/2017 1.00 PROD1 DRILL DRLG P 1.78 bpm in, 0.66 bpm out, CT 4967 14,855.0 15,014.0 22:48 23:48 psi, free spin 1033 psi, 6 It lbs RIH Wt OBD, CT wt 4k lbs, WOB 2 k lbs, ROP 150 ft/hr Stall @ 14,890 +/- 6 bbls high vis out the bit, PU Wt 40 k Rate out dropped from 0.7 bpm to 0.40 bpm as Hi vis was on the back side. Drilling break, up to 360 R/hr, PU to roll hot, PU Wt 41 k, RBIH RIHWt 5 k Ibs, 1.8 in 0.40 out, diff 1164 psi OBD, - 380 R/hr, friction pressure from high vis pill on back side exacerbating losses. Pill moving @ 60 ft/min with current returns Average ROP over interval drilled - 160 R/hr average 9/27/2017 9/28/2017 0.20 PROD1 DRILL WPRT P PU Wt 38 k lbs 15,014.0 14,462.0 23:48 00:00 CT weight slowly increased from -36 It to 39 k near the bottom of the window RBIH to jog solids 9/28/2017 9/28/2017 1.20 PROM DRILL WPRT P Continue to PUH, order power pro 14,462.0 9,979.0 00:00 01:12 light system(s) in preperation for closed choke drilling. 9/28/2017 9/28/2017 1.10 PRODt DRILL DISP P Park, down on the pumps, finish 9,979.0 8,179.0 01:12 02:18 preping high vis pill, line up down the back side with power pro, establishing injection, 1 bpm @ 1400 psi WH. Pump 10 x 10 low/hi vis pill down the back side. 9/28/2017 9/28/2017 1.00 PRODI DRILL TRIP P RBIH, 100 ft/min, lined up down the 8,179.0 14,140.0 02:18 03:18 coil @ 0.6 bpm, pushing sweeps in front, pipe displacement .5 bpm. CT 2198 psi, WH 221 psi 9/28/2017 9/28/2017 0.20 PROW DRILL TRIP P Tie into K1 for + 6' correction 14,140.0 14,156.0 03:18 03:30 9/28/2017 9/28/2017 0.30 PROD1 DRILL TRIP P Continue to RIH, window Clean, WOB 14,156.0 15,014.0 03:30 03:48 spike as well as Ct weigh stack out in the build @ 14,386'. 9/28/2017 9/28/2017 1.10 PROD1 DRILL DRLG P 1.65 bpm, CT 4347 psi, WH 473 psi, 15,014.0 15,165.0 03:48 04:54 annular 3714 psi. off bottom diff 1124 psi CT Wt 4.2 k lbs, WOB 2.1 k lbs, ROP 200 R/hr PU, 35 k lbs, increase rate to 1.80 bpm, Ct 4800 psi, diff 1150 psi, annular 3799 psi BOBD CT Wt 5 k lbs, WOB 1.08 k lbs, ROP 150 Whir Stall 15,093', PU 39 k lbs, spuded and restarted, new diff 1,337 psi, plugged nozzle? Average ROP over interval drilled - 137 R/hr average 9/28/2017 9/28/2017 0.10 PROD1 DRILL WPRT P PU 38 k lbs - DD wiper- 30' 15,165.0 15,165.0 04:54 0500 Page 6121 ReportPrinted: 10/17/2017 Operations Summary (with Timelog Depths) 2A-22 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation 1tKB) End DeM (MB) 9/28/2017 9/28/2017 1.80 PROD1 DRILL DRLG P 1.83 bpm, CT 5007 psi, 1,380 psi diff 15,165.0 15,310.0 05:00 06:48 RIH Wt 6k lbs, WH 836 psi, annular 3775 psi OBD, CT Wt Ok lbs, WOB 2.5 k lbs, ROP 180 Whir stall @ 15,195', annular fell off from 3,850 to 3,350 psi at -15,185' 9/28/2017 9/28/2017 0.40 PROM DRILL WPRT P Wiper up-hole, PUW = 40K 15,310.0 14,333.0 06:48 07:12 9/28/2017 9/28/2017 1.30 PROD1 DRILL WPRT P Wiper in-hole, , lied in for a+3' 14,333.0 15,310.0 07:12 08:30 correction, difficulty RIH past 14,375'- 14,380' in the build, PU & attempt various TF's, get by stacking -8K WOB, back ream up through trouble area up to 14,350', RBIH and slide right by 14,375' Stack weight at 14,409', PUW = 38K, attempt multiple TF's, no success, attempt with pumps off, no success, creep in with pumps at 1.4 bpm and get by (likely fill) Stack weight at 15,125', PUW = 42K, vary TF, no success, creep in at 10 fpm & get by, back-ream up to 15,116' through trouble spot 9/28/2017 9/28/2017 3.60 PROD1 DRILL DRLG P BOBD, FS = 1230 psi at 1.8 bpm, 15,310.0 15,610.0 08:30 12:06 CWT = 8K, WOB = 1.71K, annular = 3440 psi, WHP = 346 psi, circ pressure = 4793 psi, began pumping PowerPro lite at 15,385', ROP over interval = -83 fph 9/28/2017 9/28/2017 0.40 PROD1 DRILL WPRT P Wiper up-hole, PUW =41K 15,610.0 14,609.0 12:06 12:30 9/28/2017 9/28/2017 0.40 PROM DRILL WPRT P Wiper in-hole, RIW=6.5K 14,609.0 15,610.0 12:30 12:54 9/28/2017 9128/2017 3.20 PROM DRILL DRLG P BOBD, FS = 1250 psi pumping 1.8 15,610.0 15,910.0 12:54 16:06 bpm, CWT = 5K, WOB = 2K, annular = 3692 psi, circ pressure = 5245 psi, average ROP over interval = 94 fph Note: CWT, among other values, was not receiving data in WellLiink from 13:00 hrs - 13:53 his ( MWD resolved issue) 9/2812017 9/28/2017 0.40 PROD1 DRILL WPRT P Wiper up-hole, PUW =41K 15,910.0 14,895.0 16:06 16:30 9/28/2017 9/28/2017 0.50 PROD1 DRILL WPRT P wiper in-hole, send 5x5, stack weight 14,895.0 15,910.0 16:30 17:00 1 I I at 15,816', bring up rate, RBIH & creep through, RIW = 5.2K Page 71211 ReportPrinted: 10/1712017 Operations Summary (with Time9og Depths) a+i 2A-22 601 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Tim Dur (hr) Phase Op Code Activity Corte rme P -T -X Operation (ftl(B) End Depth (WS) 9/28/2017 9/28/2017 4.80 PROM DRILL DRLG P 801313, FS = 1194 psi pumping 1.77 15,910.0 16,087.0 17:00 21:48 bpm, CWT =2K, WOB =2.2 klbs Pumped 10x10 sweep, exited Cot 16,038 bit depth, snub limit set to -3 k CT wt, WOB in creased from 1 k to 2.81k plus, lubes /solids movement is helping weight transfer. Top off pill 1 with new mud 1% lubes to be used for sweeps. PU Wt 41 k lbs BHA wiper struggle to get restarted 4 times. Average ROP over interval drilled - 37 ft/hr average 9/28/2017 9/28/2017 0.60 PROD1 DRILL WPRT P PU Wt 41 k lbs, pull 3rd long wiper to 16,087.0 14,145.0 21:48 22:24 window for tie in. - 1,757' drug low side on the way out. 9128/2017 9/28/2017 0.20 PROD1 DRILL DLOG P Tie into K1 tag for+ 9' correction, 14,145.0 14,206.0 22:24 22:36 bypass high pressure screens 9/28/2017 9/28/2017 0.80 PROD1 DRILL DISP P Line up down the back side, bullhead 14,206.0 14,198.0 22:36 23:24 45 bbls new mud W 2 ppb Alpine drill beads down the backside @ 1.6 bpm bpm, WH 758 psi initial, WH 1940 psi final Pre IA 1333 psi, OA 305 psi, Post Is 1706 psi, OA 305 psi PU Wt 39 k Ibs 9/28/2017 9/29/2017 0.60 PROD1 DRILL TRIP P RIH, Window clean, small WOB spike 14,198.0 15,625.0 23:24 00:00 at 14,386' near the end of the build, no CT Wt change. small WOB spike 14,915 9/29/2017 9/29/2017 0.20 PROD1 DRILL TRIP P Continue to RIH 15,625.0 16,087.0 00:00 00:12 9/29/2017 9/29/2017 3.70 PROD1 DRILL DRLG P RIHWl 6.8 k lbs, 1.80 bpm, CT 5171 16,087.0 16,332.0 00:12 03:54 psi, Wh 464 psi, annular 3732 psi, diff 1143 psi OBD, WOB 2.5 k Ibs, CT Wt - 3 k lbs, ROP 54 ft/hr 16,178' PU Wt 38 k lbs, Pumping 10 bbls sweeps of new mud. Struggling to get restarted Average ROP over interval drilled -66 ft/hr average 9/29/2017 9/29/2017 0.60 PROD1 DRILL WPRT P Wiper trip #1 - PU Wt 38 k lbs - 1812' 16,332.0 14,520.0 03:54 04:30 9/29/2017 9/29/2017 1.40 PROD1 DRILL WPRT P RBIH, spudded in @ 15,144', TF 14,520.0 16,332.0 04:30 05:54 orientation issue, continue in hole. Started stacking out CWT at 16,088' (though not showing in WOB). difficulty working to bottom attempting various pump rates, tagged bottom —9' higher than expected, plan to inspect injector counter Page 8121 ReportPrinted: 10117/2017 Operations Summary (with Timelog Depths) 2A-22 I& Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Tana our (hr) Phase Op Code Activity Code Time PJ -x Operation Stan Depth (MB) End Depth (MB) 9/29/2017 9/29/2017 3.20 PROD1 DRILL DRLG P BOBD, FS = 1,250 psi pumping 1.7 16,332.0 16,419.0 05:54 09:06 bpm, CWT= -6K, WOB =1.8K, annular = 3834 psi, circ pressure 5,065 psi, WHIP = 778 psi PU from 16,360', difficulty RBIH past 16,344', stacking CWT to -8K on multiple attempts, no WOB indication, PUH slow waiting for beaded pill to exit bit, slide right by with beads Stall at 16,419, stack 8K WOB,PUW = 45K 9129/2017 9/29/2017 3.90 PROD1 DRILL DRLG P Stall a second time attempting to get 16,419.0 16,580.0 09:06 13:00 started 16,419', PUW =42K, annular dropped by —500 psi & CWT increased from -5K to +10K after stalls at 16,419' Drilling ahead pumping 1.8 bpm, CWT = 8K, WOB = 2K, annular = 3,432 psi, circ pressure = 4,796psi 9/29/2017 9129/2017 1.40 PROM DRILL DRLG P Continue drilling ahead at 16,580', 16,580.0 16,631.0 13:00 14:24 CWT = 4K, WOB = 2.6K, annular = 3511 psi, circ pressure = 4966 psi, WHP = 539 psi 9/29/2017 9129/2017 1.00 PROM DRILL WPRT P Wiper up -hole, PUW=38K 16,631.0 14,314.0 14:24 15:24 9/2912017 9/29/2017 1.10 PROD1 DRILL WPRT P Wiper in-hole, clean off injector 14,314.0 16,646.0 15:24 16:30 counter, tie into RA tag for +16.5' correction, RIW diminished beginning at 16,545' 9/29/2017 9/29/2017 2.00 PROM DRILL DRLG P BOBD, FS = 1284 psi pumping 1.8 16,646.0 16,722.0 16:30 18:30 bpm, CWT = -5K, WOB = 2.5K, annular = 3543 psi, circ pressure = 5118 psi, WHIP = 361 psi, lost —10 CWT from immediately before WT. Immediately send 5x5 sweeps (5bbl DuoVis w/ 1%776, 5 bbl DuoVis w/beads) Drilled w neutral to slightly neg surface weight w/ -2.4k lbs WOB. CT wt slowly climbed to -5-7k lbs as the effects of the pill wore off. Proactively pumped another 5x5 with B 200 bbls out the bit from the first pill Average ROP over interval drilled -38 R/hr average Page 9121 Report Printed: 1 0/1712 01 7 (- Operations Summary (with Timelog Depths) 2A-22 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log StartTune End Time our (hr) Phase Op Code Activity Code Time P -T -X O p eraton Start Depth ((t KB) End Depth (ftKB) 9/29/2017 9/2912017 3.70 PROD1 DRILL DRLG P CT Wt A.5 k IDS, WOB 2.0 k lbs, 16,722.0 16,806.0 18:30 22:12 Annular 3571 psi, WH 477 psi, IA 1128, OA 306 psi PU as sweeps exit the bit, PU Wt 41 k lbs, steady 37 to 39 k Wt while moving. WH climbed to 1020 psi, RBIH 1.80 bpm, RH Wt 5 k lbs, CT 4966 psi, FS 1352 psi, OBD, CT Wt 2 k lbs, WOB 2.2 k lbs, ROP 38 ft/hr CT Wt fell to -8 k lbs, WOB falling off to 1.6 k IDS, little motor work Send 10x10 sweeps to time our for wiper Average ROP over interval drilled - 22.7 R/hr average 9/29/2017 9/29/2017 0.30 PROD1 DRILL DRLG P PU Wt 42 k lbs, 1000' wiper 16,806.0 15,809.0 22:12 22:30 Motor work at 16,447', 16,234', 16,124', and 16,044' 9/29/2017 9/292017 0.40 PROD1 DRILL DRLG P RBIH as sweeps exit the bit 15,809.0 16,806.0 22:30 22:54 9/29/2017 9/3012017 1.10 PROD1 DRILL DRLG P RIH Wt 5.8 k IDS, Annular 3600 psi, 16,806.0 16,834.0 22:54 00:00 WH 400 psi, IA 1066, OA 306 psi 1.5 bpm, CT 4105 psi, FS 912 psi OBD, CT Wt 2 k lbs, WOB 2.4 k lbs, ROP 35 fft Ct Wt diminished to -4.9 k lbs , pumped 5x5 WH to 505 psi Average ROP over interval drilled -25 ft/hr average 9/30/2017 9/30/2017 1.40 PROD1 DRILL DRLG P OBD, CT Wt -4 k lbs, WOB 2 k lbs, 16,834.0 16,865.0 00:00 01:24 ROP 24 ft/hr Average ROP over interval drilled -22 R/hr average 9/30/2017 9/30/2017 1.20 PROD1 DRILL DRLG P PU 48 k lbs, started out as a BHA 16,865.0 14,T2-0-0- 01:24 02:36 wiper, attempt to tum around 16,669' failed. Snubbing, PUH at 16,840', PU 46 k lbs. while 2 ppb bead/1% lubel2%LVF pill is completed. Pull heavy Ct Wt from 36 k to 46 k lbs starting at 15,811' POOH for tie in wiper. lots of motor work started at 15,243' fell off at 14,961'. 9/30/2017 9/30/2017 0.20 PROD1 DRILL DLOG P Tie into RA tag for +1 1'correction 14,320.0 14,55-0- 02:36 02:48 9/3012017 9/30/2017 1.80 PROD1 DRILL WPRT P RBIH, Stack out coil weight briefly at 14,349.0 16,865.0 02:48 04:36 15,903', more significantly @ 16,460' atemept to work coil to bottom, snubbing. Send 5x5 pills, chase to bit while we slowly PUH, PU Wt 36 k IDS. 9/30/2017 9/30/2017 0.60 PROD1 DRILL DRLG P Three false starts, S/D WOB to 2.5 k, 16,865.0 16,865.0 04:36 05:12 @ 16,852, PU 43 k lbs, again at 16,844', PU 38 k lbs, and again at 16,833 PU 45 k lbs. RIH at min rate and dial up the pump as we saw WOB. BOBD, 1.78 bpm, WH 714 psi, CT Wt -2 k k lbs, WOB 2 k lbs, ROP 24 R/hr Page 10/21 ReportPrinted: 10/1712017 Operations Summary (with Timelog Depths) 2A-22 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Tana our (hr) Phase Op Code AcOvlty Code Time P -T -X Operation Stan Depth (WB) End Depth (flKB) 9/302017 9/30/2017 1.20 PROD1 DRILL WPRT P PU 44k lbs, PUH, annular pressuring 16,865.0 14,175.0 05:12 06:24 up, 13.8 ppg ECD at the window. Confer with town. Plan forward is to pull above TOC, open choke & try to establish returns. 9/30/2017 9/30/2017 1.30 PROM DRILL CIRC P PUH slowly from 14,175', open choke, 14,175.0 14,120.0 06:24 07:42 pumping 1.8 bpm, rate out stablized at 1.08 bpm, -60% returns, circulate bottoms up, annular at 3459 psi, begin pumping 5x5 sweeps 9/30/2017 9/30/2017 0.10 PROD1 DRILL DLOG P Begin RBIH, tie-in for +4' correction 14,120.0 14,163.0 07:42 07:48 9/302017 9/30/2017 1.60 PROD1 DRILL WPRT P Continue RIH, attempting to hold 14,163.0 16,885.0 07:48 09:24 between 11.4 ppg - 12.2 ppg, unable to maintain returns and pressure schedule, close choke & continue to RIH Work to pass 16,792', stack 3.5K WOB at 16,854', PUW of 59K from 16,823' with -6K WOB 9/30/2017 9/30/2017 1.50 PROD1 DRILL DRLG P OBD, CWT= -7.7K, WOB =1.9K, 16,885.0 16,919.0 09:24 10:54 annular = 3740 psi, WHP = 717 psi, circ pressure = 5039 psi Began sending 5x5 sweep at 16,907', annular to 3800 psi, ROP avg = 23 fph 9/30/2017 9/30/2017 2.10 PROD1 DRILL DRLG P PU from 16,919', PUW =47K, OBD, 16,919.0 16,980.0 10:54 13:00 FS = 1400 psi pumping 1.8 bpm, CWT = -6K, WOB = 1.7K, annular = 3790 psi, WHP = 832 psi, ROP avg = 29 fph 9/30/2017 9/3012017 3.60 PROD? DRILL DRLG P PU from 16,980', PUW = 48K, FS = 16,980.0 17,053.0 13:00 16:36 900 psi pumping 1.5 bpm, OBD, CWT = -7.7K, WOB = 1.2K, annular = 3786 psi, WHP = 844 psi, pumping sweeps as required, bring rate back up to 1.8 bpm PUW = 46K from 17,022', 10 bbl beaded pill coming around, drilling at 17,025 wtih -9.4K CWT, WOB = 1.4K, PUW= 47K from 17,053', RO avg = 20.3 fph 9/3012017 9/30/2017 2.80 PROD1 DRILL DRLG P OBD, CWT= -10K, WOB =1K, 17,053.0 17,086.0 16:36 19:24 annular= 3861 psi, WHP 899 psi, pumping pillls as required, gained -5K CWT with beads coming around. 9130/2017 9/30/2017 0.30 PROD1 DRILL WPRT P PU Wt 44k lbs, planned 500' wiper. 17,086.0 16,380.0 19:24 19:42 Faierly clean, one spike to 55k. Pumped pill timed out for turnaround. 9/30/2017 9/30/2017 3.10 PROD1 DRILL WPRT P RBIH, RIH Wt- 3k lbs, WH 62 psi, 17,086.0 17,090.0 19:42 22:48 Annular 3804 psi RIH wl fell of to as low as -10 k lbs, as we ran out of seeep, pump more. WOB spikes 16,778 and 16,788, cleaned up around 16,828 and deeper 9/30/2017 10/1/2017 1.20 PRODt DRILL WPRT P OBD, CT Wt -10 to 0, WOB 2 - 3.5 k 17,086.0 17,090.0 22:48 00:00 lbs, low differential pressure. ROP -5 Page 11121 ReportPrinted: 1011712017 Operations Summary (with Tirnelog Depths) 2A-22 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time Ehd Time our (hr) Phase Op cede Activity Code Time P -T -X Operation (RKB) EM Depth(W) 10/1/2017 10/1/2017 0.60 PROD1 DRILL DRLG P OBD, CT Wt -10 to 0, WOB 2 - 3.5 k 17,090.0 17,090.0 00:00 00:36 His, low differential pressure. ROP -5 Start pumping 90 bbl beaded sweep to bit, Paint white TD flag at horses head 10/1/2017 10/1/2017 1.10 PROD1 DRILL WPRT P PU Wt 48 k lbs, Pulled 60 k (20 overo 17,090.0 14,140.0 00:36 01:42 @ 16,910 and 16,292' up to -1 k WOB. 10/1/2017 10/1/2017 0.20 PROD1 DRILL DLOG P Tie into the Kt for+9' correction 14,140.0 14,168.0 01:42 01:54 10/1/2017 10/1/2017 0.90 PROD1 DRILL CTOP P Bleed IA from 1466 psi, to 950 psi, 14,168.0 14,168.0 01:54 02:48 S/D pumps, observe pressure while parked w sensor at 5725' TVD. Coil track pressure fell from 3496 to 3446 psi in 36 min 11.57 ppg EMW 10/112017 10/1/2017 1.50 PROM DRILL CTOP P Online w pumps, creep up hole while 14,168.0 13,957.0 02:48 04:18 slowly working choke open. Establish returns, 1.2 bpm in 0.86 bpm out. Build weighted liner running pill and KW while circulating bottoms up in the cased hole. Load coil with 47 bbl beaded pill to aid RIH, TO conformation 10/1/2017 10/1/2017 1.40 PROD1 DRILL TRIP P RIH to confirm TD, enter open hole as 13,957.0 17,092.0 04:18 05:42 pill started exiting the bit, confirm TO at 17,092' 10/1/2017 10/1/2017 4.20 PROD1 DRILL DISP P POOH laying 11.9 ppg liner running 17,902.0 78.0 05:42 09:54 pill at KWF to surface, painted EDP flags at 16,038'& 13,178', not getting KWF out on surface, at 175' form surface, rate out began to drop at -4500', well is laking -1.25 bpm in and 0 bpm out, unable to fill hole 10/1/2017 10/1/2017 2.10 PROM DRILL WAIT T Confer with town, well is taking 1.25 78.0 78.0 09:54 12:00 bpm with no 11.9 ppg fluid back to surface, decision made to bull -head 8.5 ppg DuoVis to window, if well is dead, carry on, if there is flow at surface, RBIH and obtain SBHP. Shut pumps down with 15 bbl bull- headed (1725' MD, 1679' TVD), choke closed, hole stablized, confer with town, decison made to RIH to 2000' and circulate 11.2 ppg KWF, displacing 15 bbl of 8.5 ppg DuoVis to surface. BHP= 23 psi WHP+,052(8.5 ppg) (1679) +.052(11.9 ppg)(5838' - 1679) = 3339 psi, or 11.0 ppg EMW 10/1/2017 10/1/2017 1.70 PROD1 DRILL DISP P RIH, water down KWF, & circulate in 78.0 2,500.0 12:00 13:42 11.2+ KWF from 2500', includes rolling coil to 11.2 ppg at 1.25 bpm, MW out climbs 10/1/2017 10/1/2017 0.80 PROD1 DRILL DISP P Begin POOH pumping 11.2 ppg KWF 2,500.0 78.0 13:42 14:30 to surface, MW out climbs to 11.9 ppg with bit at 2100', all 8.5 ppg out of the hole and begining to get some original KWF out of the hole, IA = 959 psi Page 12/21 ReportPrinted: 10117/2017 I Operations Summary (with Timelog Depths) 2A-22 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time Dur(hr) Phase op Code AcWity Code Time P -T -X Operation Stan Depen (MB) End Depth (WB) 10/1/2017 10/1/2017 1.70 PROM DRILL PULD P Check well for flow, good (on a vac), 78.0 0.0 14:30 16:12 gel loss rate, PJSM, LD BHA #6, loss rate at-14bbl/hr, loss rate dropped to 7.5 bbl/hr, bit came out a 4-2 10/112017 1011/2017 2.00 COMPZ1 CASING PUTB P PJSM, PU liner (ported bull -nose, 27 0.0 1,125.0 16:12 18:12 jnts slottted, liner top billet), loss rate at 7.5 bbl/hr 10/1/2017 10/1/2017 0.80 COMPZI CASING PULD P Pick up BHA, checked pack offs- 0.0 1,075.0 18:12 19:00 good, tagged up set counters, 10/112017 10/1/2017 3.20 COMPZ1 CASING RUNL P RIH, Returns fell off. Confirmed coil 11,215.0 14,231.0 19:00 22:12 marks (3 minor indentions, not from slipped blocks) at 1347' from EDP. - Continue to RIH, 80 fUmin, pumping 0.34 bpm in 0.24 bpm out, loosing - 0.33-0.4 bpm. Lost all returns @ 8031', partial retuns as coil speed slowed for GLM @ 10,723', fell off. 10/1/2017 10/1/2017 1.30 COMPZ1 CASING RUNL P stop, PU Wt 33 k lbs, Tie into White 14,213.0 17,062.0 22:12 23:30 window flag in tension for -10.5' correction. "Coil track pressure parked, pumps down, 3136 psi, bit depth 14221' TVD sensor 5306' calculated BHP 11.37 ppb EMW Contiue to RIH Start picking up WOB @ 14,700' SID 17,086' drive by on flag was - + 2' correction PU, Wt 40 k lbs, RBIH S/D 17,0885, squat neutral coil, 4 K WOB, Pumps online 1.5 bpm, CT 3900 psi, PU, 35 k lbs, - 0.95 WOB. Lost - 50 bbls while RIH 10/1/2017 0.50 COMPZ1 CASING TRIP P Stop to reset depth, line up pump 17,062.0 15,044.0 23:30 00:00 accros the top, 110/2/2017 POOH, paint yellow flag @ 15044.19' 10/2/2017 10/2/2017 0.30 COMM CASING TRIP P Continue to POOH 15,044.0 14,100.0 00:00 00:18 10/2/2017 10/2/2017 0.20 COMPZ1 CASING DLOG P Tie into the K1 for a +14.5' correction 14,100.0 14,137.0 00:18 00:30 Lost 12 bbls while POOH. 10/22017 10/2/2017 0.50 COMPZ1 CASING DLOG P Park @ 14,137 bit depth, 5727.6 TVD 14,137.0 14,137.0 100:30 01:00 monitor bottom hole pressure. Innitial 3365 psi - 11.29 ppg Open up bleed on the floor, fill hole till fluid at the stack, SID well on a vac 5 min coil track 3362 psi - 11.28 ppg Verify MW at inlet 11.23 ppg with scale. 10 min coil track 3362 psi - 11.28 ppg - took 1.6 bbls to refill hole. 30 min coil track 3358 psi - 11.27 ppg Readding BHP of killweight fluid less the slow leak off. 10/22017 102/2017 2.70 COMPZ1 CASING TRIP P Continue to POOH purring across the 14,137.0 110.0 01:00 03:42 1 top - Lost 89 bbls of KW Page 13121 ReportPrinted: 10/17/2017 . Operations Summary (with Timeiog Depths) 2A-22 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Shit Tme End Tuna our (hr) Phase Op Code AcWty Cade Time P -T -X Operation StanDepth (MKB) End Depth (MB) 10/2/2017 10/2/2017 0.80 COMPZ1 CASING TRIP P At surface, WH 0 psi, open at stack, 110.0 0.0 03:42 04:30 well on a vac, flood up to the half drum, SID. Well on a vac. Fill well after ten min 1.9 bbl fill up. PJSM. LD BHA #7 over a dead well. hole fill 2 bbls in 30 min. Flat spot on pipe - 8' back from CC. Plan to UT prior to RIH w BHA #9. 10/2/2017 10/2/2017 0.60 COMM CASING BOPE P PJSM, PU safety joint, perform weekly 0.0 0.0 04:30 05:06 BOP function test Hole fill 1 bbl 10/2/2017 10/2/2017 2.00 COMPZI CASING PUTS P Clear dean floor ,prep to run liner. 0.0 966.0 05:06 07:06 PJSM, PU upper liner run #2 (ported bull -nose, 24 jnts slotted liner, & liner top billet), keeping the hole full 10/2/2017 10/2/2017 0.60 COMM CASING PULD P PU BHA #8 liner running tools, slide in 966.0 1,011.0 07:06 07:42 cart, MU coil, tag up, EDC closed 10/2/2017 10/2/2017 4.00 COMPZI CASING RUNL P RIH with Upper Liner Assemlby, no 1,011.0 16,014.0 07:42 11:42 returns to surface pumping .37 bpm, begin to see small returns at -2100', stop at 2177' to establish returns to surface & ensure the hole is full (pumping across the top), continue RIH with no returns to surface Tied into window flag for a +0.31' correction, weight check at window = 35K, clean through window, began taking weight at -14,800' (WOB spikes to 5K), cleaned up by -15,600, arrive at set depth, PUW = 40K, RBIH, release off liner on depth, PUW = 36K, TOB -15,050' 10/2/2017 10/2/2017 2.80 COMPZI CASING TRIP P POOH, flow check well, PJSM, losses 16,014.0 44.0 11:42 14:30 at -9 bbl/hr 10/2/2017 10/2/2017 1.00 COMM CASING PULD P LD BHA #8, UT flat spot on coil (-8' 44.0 0.0 14:30 15:30 up from EOP), minimum value at .150" wall thickness, within spec to not cut coil, checked pack -offs 10/2/2017 10/2/2017 2.00 PROD2 STK PULD P PJSM, PU BHA #9 AL1 KO/Drilling 0.0 -T8.0- 8.015:30 16:30 17:30 Assembly (agitator, 0.5°- AKO motor, RB Hughes bit), tag up, set counters, EDC dosed 10/2/2017 10/2/2017 2.00 PROM STK TRIP P RIH with BHA #9, surface test agitator, 78.0 14,140.0 17:30 19:30 good 10/2/2017 10/2/2017 0.20 PROD2 STK DLOG P Log K1 for +31' correction, inspect 14,140.0 14,140.0 19:30 19:42 and clean BHI counter, dirty, 10/2/2017 10/2/2017 1.20 PROD2 STK DISP P Line up to pump across the top. bull- 14,140.0 14,140.0 19:42 20:54 head 68 bbl DuoVis down the backside, pumping to 11.5 ppg at the window, annular= 3427 psi, WHP 1270 psi, pumped away 68 bbl, lined up on coil. Change out injector counter, re -tie in for a 0' correction 10/2/2017 10/2/2017 0.80 PROD2 STK TRIP P Continue RIH, dry tagged TOB at 14,140.0 15,048.0 20:54 21:42 1 I 15,048', PUW = 32K, RBIH Page 14121 ReportPrinted: 10/17/2017 . Operations Summary (with Timeiog Depths) 2A-22 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Slaty Time End Time Dur hr Dur(hr) phase Op Code Activity Code Time P -T-% Operation (ftKa) EM Depth (ftKB) 10/2/2017 10/3/2017 2.30 PROD2 STK KOST P Begin milling off billet (15,046' 15,047.0 15,058.0 21:42 0000 pumping), pumping 1.43 bpm, rate out = .63 bpm, annular = 3503 psi, CWT = 12K, WOB =.7K, circ pressure = 3892 psi, milling on an open choke with -49% returns, climbs to -58% returns, off billet at 15,052' 10/3/2017 10/3/2017 0.40 PROD2 DRILL DRLG P Drilling ahead on AL1 lateral 15,058.0 15,095.0 00:00 00:24 10/3/2017 10/3/2017 0.40 PROD2 DRILL WPRT P PU Wt 35 k lbs, min rate see -1k lbs 15,095.0 15,095.0 00:24 00:48 WOB whilepulling up past the billet. Returns check with open choke Rate in Rate out % retuns 1.3 0.9 70 1.5 0.79 53 1.6 0.79 50 RBIH, down on the pumps, 400 lb WOB spike as we passed the billet 10/3/2017 10/3/2017 1.30 PROD2 DRILL DRLG P 1.42 bpm in, 0.76 bpm out, Ct 3842, 15,095.0 15,230.0 00:48 02:06 diff 760 psi OBD, CT Wt 8.7 k lbs, WOB 1.6 k lbs, ROP 100 ft/hr retums less than 60% After 20 min drilling returns healed to 0.80 bpm -57 % Stall 15163, PU 41 k Ibs Pump 5x5 sweep, returns increased from 0.8 to 0.87 bpm as the low vis exited the bit Average ROP over interval drilled - 104 fl/hr 10/3/2017 10/3/2017 2.10 PROD2 DRILL DRLG P Returns fell to 0.70, suspect we 15,230.0 15,383.0 02:06 04:12 crossed fault B, PU @ 15,241'36 k lbs OBD, 1.42 bpm in, 0.70 bpm out, Ct 4131, CT Wt 5.0 k lbs, WOB 1.0 k IDS, ROP 90 ft/hr Returns slowly healed to 0.75 bpm ! 53% Pull 100' BHA wiper @ 15,364' PU Wt 36k lbs, Returns 0.78 bpm W PUH, 0.66 W RIH BOBD 1.42 bpm in, 0.73 bpm out, CT 3877 psi, FS 770 psi CT Wt 0, WOB 1.02, ROP 35 ft/hr Average ROP over interval drilled - 73 ft/hr 10/3/2017 10/3/2017 0.50 PROD2 DRILL WPRT P Pu Wt 36 k lbs, Wiper trip - 1058', 15,383.0 14,325.0 04:12 04:42 slight neg WOB at the billet. 10/3/2017 10/3/2017 0.20 PROD2 DRILL DLOG P RBIH, Tie into the RA lag for+5' 15,383.0 14,T5-4-0- 04:42 04:64 correction. 10/3/2017 10/3/2017 1.70 PROD2 DRILL CIRC P PUH above cement pilot hole, open 14,354.0 14,204.0 04:54 06:36 EDC, pump 5x5 sweep all the way around. S/D close EDC, Gose choke. 10/312017 10/312017 0.60 PROD2 DRILL TRIP P RIH 14,204.0 15,383.0 06:36 07:12 Page 15121 Report Printed: 10117/2017 Operations Summary (with Timelog depths) �I. 2A-22 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Adlvity Code Time P-T.X Operation (NKB) End Depth (N(e) 10/3/2017 10/3/2017 3.70 PROD2 DRILL TRIP P 1.77 bpm, CT 5411 psi, FS 1075 psi 15,383.0 15,800.0 07:12 10:54 OBD, CT Wt 5.4 k lbs, WOB 1.9 k lbs, ROP 128 15,390, PU 38 k lbs CT Wt 0.6 k lbs, WOB 2.4 k lbs, ROP 170 It/hr 15,525', PU 39k lbs 15,654', PU 39k lbs 15,758', PU 39k lbs CT Wt -5 k, WOB 1.4 k lbs, ROP fell off to less than 100 Average ROP over interval drilled - 113 fUhr 10/3/2017 10/3/2017 0.30 PROM DRILL WPRT P Pu Wt 39 k Ibs - wiper to above the 15,800.0 14,947.0 10:54 11:12 billet - 853' 10/3/2017 10/3/2017 0.30 PROD2 DRILL WPRT P RBIH, RIH Wt 2.6 k lbs 14,947.0 15,800.0 11:12 11:30 10/3/2017 10/3/2017 3.90 PROD2 DRILL TRIP P 1.78 bpm, FS 1042 psi 15,800.0 16,202.0 11:30 15:24 OBD, CT Wt 3 k lbs, WOB 1.4 k lbs, ROP 153 15,933' PU 43 k CT Wt -5 k, WOB 0.9 k lbs, ROP dropping off to 50 ft/hr Pump 5x5 sweep 1 % Low torque and 776 Pre CT Wt -3k, WOB 0.9 K ROP 55 ff/hr Post CT Wt -1 k lbs, WOB 1.8 k lbs, ROP 126 ft/hr Average ROP over interval drilled - 103 ft/hr 10/3/2017 10/3/2017 0.40 PROD2 DRILL TRIP P Pu Wt 39 k, wiper 250 16,202.0 16,202.0 15:24 15:48 1 turn around @ 15,950 RBIH 10/3/2017 10/3/2017 2.00 PROD2 DRILL DRLG P 1.78 bpm, CT 5058 FS 1012 psi WH 16,201.0 16,385.0 15:48 17:48 911 psi, IA 1450 psi, OA 300 psi OBD, CT Wt 2 k lbs, WOB 1.0 k lbs, ROP 100 Average ROP over interval drilled - ft/hr 10/3/2017 10/3/2017 0.45 PROD2 DRILL WPRT P Wiper up hole, PUW 40 k 16,385.0 15,767.0 17:48 18:15 10/3/2017 10/3/2017 0.35 PROD2 DRILL WPRT P RBIH, pumping 5x5 sweep 15,767.0 16,363.0 16:15 18:36 1 10/3/2017 10/3/2017 0.25 PROD2 DRILL WPRT P Wiper up hole, PUW 46 k 16,363.0 16,216.0 18:36 18:51 10/3/2017 10/3/2017 0.25 PROD2 DRILL WPRT P RBIH, pumping 5x5 sweep 16,216.0 16,380A 18:51 19:06 10/3/2017 10/3/2017 0.75 PROM DRILL WPRT P Wiper to the window, PUW 46 k 16,380.0 14,110.0 19:06 19:51 10/3/2017 10/3/2017 0.25 PROM DRILL DLOG P Log the K1 marker correction of plus 14,110.0 14,168.0 19:51 20:06 18.5' 10/3/2017 10/3/2017 1.50 PROD2 DRILL CIRC P PUH, bullheading 50 bbl bead/lube pill 14,168.0 13,900.0 20:06 21:36 down the back side, 0.5 bpm at 1,736 psi 10/3/2017 10/3/2017 1.00 PROD2 DRILL WPRT P Wiper back in hole„ cloised choke, 13,900.0 16,380.0 21:36 22:36 pumping 0.28 bpm at 2,125 psi, Page 16/21 Report Printed: 10/17/2017 a Operations Summary (with Timeiog Depths) 2A-22 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth rte Stat Time Endrime_ Dur r m) Phase Op Code Activit' Code Time P -T-% OperaOon End Depth (fiKB) 10/3/2017 10/4/2017 1.40 PROD2 DRILL DREG T7 BOBD, 1.76 bpm at 4,600 psi FS, 16,380.0 16,498.0 22:36 00:00 BHP 4000 psi, closed choke, IA 1,426, OA 307, CTWS= 2 k, DHWOB= 1.8 k, ROP=83 fph "` Pump 2 - 5x5 sweeps 10/4/2017 10/4/2017 0.70 PROD2 DRILL DRLG P OBD, 1.76 bpm at 5,100 psi, BHP 16,498.0 16,547.0 00:00 00:42 4,002, Closed choke, IA 1,375, OA 308, CTSW= 4 k, DHWOB= 1 k 10/4/2017 10/4/2017 3.75 PROD2 DRILL DRLG P OBD, 1.76 bpm at 4,743 psi, Closed 16,547.0 16,790.0 00:42 04:27 choke, BHP dropped 400 psi, to 3,684, IA 1,374 psi, OA 308, CTSW= 8.0 k, DHWOB=2.8 k, ROP 166 fph 10/4/2017 10/4/2017 0.50 PROD2 DRILL WPRT P Wiper up hole, PUW 41 it 16,790.0 15,090.0 04:27 04:57 10/4/2017 10/4/2017 0.70 PROD2 DRILL WPRT P Wiper back in hole, RIW 15,090.0 16,790.0 04:57 05:39 10/4/2017 10/4/2017 5.60 PROD2 DRILL DRLG P RIH Wt 4.4 k lbs, 1.79 bpm, CT 4860 16,790.0 16,957.0 05:39 11:15 psi, FS 1096 psi, WH 500 psi, IA 1198 psi, OA 312 psi OBD, Ct Wt 2-0 k lbs, WOB 2-3 k lbs, ROP 80-10 ft/hr @ 16,955', differential pressure dropped to - 1000 psi while OBD and -2k WOB PU, 48 k Ibs, free spin diff returned to 1090 psi RBIH diff increased to 1200 psi then fell off rapidly to less than 1000 psi while OBD w WOB. Motor still appears to be working, WOB drilling off. ROP 30 it/hr average over interval drilled 10/4/2017 10/4/2017 1.30 PROD2 DRILL WPRT T PU wt 40 k Ibs, Wiper up hole, 16,957.0 14,189.0 11:15 12:33 Diferential pressure varying from as high as 1500 psi to as low as 1000 psi while POOH at 1.8 bpm. Once above the cement pilot hole, parked, Open EDC, 10/4/2017 10/4/2017 2.30 PROD2 DRILL WPRT T Continue to POOH replacing pipe 14,189.0 -75-0- 5012:33 12:33 14:51 voidage. 10/4/2017 10/4/2017 0.90 PROD2 DRILL PULD T Bump up, space out, PUD BHA #9 75.0 0.0 14:51 15:45 10/4/2017 10/4/2017 1.10 PROD2 DRILL PULD T Break off bit, motor and agitator. Bit 1 0.0 75.0 15:45 16:51 rated 2-1. Air blow freely through agitator, motor appears to work with air. Bit of black rubber found in bit. check / replace pack offs. 10/4/2017 10/4/2017 1.50 PROD2 DRILL CTOP T check / replace pack offs. 75.0 75.0 16:51 18:21 10/4/2017 10/4/2017 0.25 PROD2 DRILL PULD T Stab on, complete PD BHA #10 0.0 75-0- 18:21 18:36 10/4/2017 10/4/2017 0.25 PROD2 DRILL TRIP T RIH, close EDC, testes agitator 75.0 600.0 18:36 18:51 10/4/2017 10/4/2017 2.35 PROD2 DRILL TRIP T Continue RIH pumping 0.30 bpm @ 600.0 14,100.0 18:51 21:12 2,062 psi 10/4/2017 10/4/2017 0.25 PROD2 DRILL DLOG T Log K1 marker correction of plus 19.0' 14,100.0 14,130.0 21:12 21:27 10/4/2017 10/4/2017 1.00 PROD2 DRILL TRIP T Continue RIH to bottom 14,130.0 16,958.0 21:27 22:27 10/4/2017 10/5/2017 1.55 PROD2 DRILL DRLG P OBD, 1.80 bpm at 4918 psi, BHP 16,958.0 22:27 00:00 3,785, WHIP 505, IA 1,159, OA 298, Page 17121 ReportPrinted: 10/17/2017 Operations Summary (with Timelog Depths) 2A-22 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log StartTime End Time Dr (hr) Phase op Code Activity CodeTime P -T -X Operation Stan Depth (WB) End Depth (W13) 10/5/2017 10/5/2017 1.30 PROD2 DRILL DRLG P OBD, 1.78 bpm at 5,106 psi, BHP 17,029.0 17,122.0 00:00 01:18 3,906, WHP 788 (closed choke), IA 1,307, OA 302 10/5/2017 10/5/2017 0.30 PROD2 DRILL WPRT T PUH, notice counter not working, PUH 17,122.0 16,818.0 01:18 01:36 to log formation marker @ 16,818' 10/5/2017 10/5/2017 0.25 PROD2 DRILL DLOG T Log formation correction of plus 30.0' 16,818.0 16,911.0 01:36 01:51 10/5/2017 10/5/2017 0.25 PROM DRILL WPRT T RBIH to bottom, RIW 5 k 16,911.0 17,122.0 01:51 02:06 10/5/2017 10/5/2017 2.00 PROD2 DRILL DRLG P BOBD, 1.77 bpm at 4,700 psi FS, 17,122.0 17,190.0 02:06 04:06 BHP 3,913, WHP 813, IA 1,319, OA 302, CTSW=minus 1.3 k, DHWOB=1.3 k, ROP 44 fph 10/5/2017 10/5/2017 1.90 PROD2 DRILL DRLG P OBD, 1.78 bpm at 5,186 psi, BHP 17,190.0 17,251.0 04:06 06:00 3,956, WHP 876, IA 1,389, OA 303, CTSW=minus 4.7 k, DHWOB=1.3 k, ROP 40-60 fph Average ROP over interval drilled 32 ft/sec 10/5/2017 10/5/2017 4.90 PROD2 DRILL DRLG P OBD, 1.78 bpm BHP 3,996, WHP 17,251.0 17,501.0 06:00 10:54 957, IA 1,1546, OA 304, Ct Wt -5 k lbs, WOB 1.6 k lbs, ROP 40 Struggled to build angle, getting thrown down, dove and inverted Average ROP over interval drilled 51 ft/sec 10/5/2017 10/5/2017 0.30 PROD2 DRILL WPRT P Pu Wt 44 k lbs, BHA wiper,struggled 17,501.0 17,096.0 10:54 11:12 to turnaround, turned into 405' wiper 10/5/2017 1015/2017 0.60 PROD2 DRILL WPRT P RBIH, struggle to get below 17,339', 17,096.0 17,501.0 11:12 11:48 1 sweeps on the back side. Once sweeps 5 bbls out continue to RIH. 10/5/2017 10/5/2017 2.00 PROD2 DRILL DRLG P OBD, 1.78 bpm BHP 3,996, WHP 17,501.0 17,569.0 11:48 13:48 957, IA 1, 1546, OA 304, Ct Wt -5 k lbs, WOB 1.6 k lbs, ROP 120-10 Average ROP over interval drilled 34 ft/sec 10/5/2017 10/5/2017 0.80 PROD2 DRILL WPRT P Pu Wt 42 k lbs, wiper, WH increased 17,569.0 15,200.0 13:48 14:36 from 980psi to 1585 psi - 2369' wiper 16,711' pulled heavy, 55 k lbs, -0.6 k WOB CT weight and WOB cleaned up after 16,500' 10/5/2017 10/5/2017 0.80 PROD2 DRILL WPRT P RBIH, struggle to get below 17,339', 15,200.0 17,569.0 14:36 15:24 sweeps on the back side. Once sweeps 5 bbls out continue to RIH. 10/5/2017 10/5/2017 1.50 PROD2 DRILL DRLG P OBD, 1.81 bpm BHP 4078 psi, WHIP 17,569.0 17,591.0 15:24 16:54 980, CT 5060 psi, FS 1020 psi Ct Wt 3 k lbs, WOB 3 k lbs, ROP 20 Average ROP over interval drilled 15 ft/sec 10/5/2017 10/5/2017 0.40 PROD2 DRILL WPRT P Pu Wt 40 k lbs, Geo wiper 17,591.0 17,015.0 16:54 17:18 10/5/2017 10/5/2017 0.40 PROD2 DRILL WPRT P RBIH, RIW 6 k 17,015.0 17,569.0 17:18 17:42 Page 18/21 Report Printed: 10/1712017 . Operations Summary (with Timelog Depths) 2A-22 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Tune End Time Our that Phase Op Code Activity Code Time P -LX Operation Stan Depth We) End Depth (110) 10/5/2017 10/5/2017 0.75 PROD2 DRILL DRLG P BOBD, 1.79 bpm at 5,074 psi FS, 17,569.0 17,601.0 17:42 18:27 BHP 4,110, WHP 920, IA 1,497, OA 303 10/5/2017 10/5/2017 1.25 PROD2 DRILL WPRT P TD called, wiper up hole, PUW 40 k 17,601.0 14,100.0 18:27 19:42 10/5/2017 10/5/2017 0.25 PROD2 DRILL DLOG P Log the K1 marker correction of Plus 14,100.0 14,163.0 19:42 19:57 1 28.0' 10/5/2017 10/5/2017 0.25 PROD2 DRILL TRIP P RIH to window 14,163.0 14,290.0 19:57 20:12 10/5/2017 10/5/2017 3.50 PROD2 DRILL CTOP P Static Pressure Survey: Final ECD 14,290.0 14,290.0 20:12 23:42 11.6 ppg TIME: 20:00 -23:30 WHP: 930 - 761 AP: 3710- 3480 IA: 1497 -1182 10/5/2017 10/6/2017 0.30 PROD2 DRILL TRIP P RIH to confirm TD 14,290.0 15,281.0 23:42 00:00 10/6/2017 10/6/2017 1.15 PROD2 DRILL TRIP P Continue RIH to confirm TD 17,619' 15,281.0 17,619.0 00:00 01:09 10/6/2017 10/6/2017 1.30 PROD2 DRILL TRIP P PUH slowly while mixing liner running 17,619.0 17,210.0 01:09 02:27 pill 10/6/2017 10/6/2017 0.20 PROD2 DRILL TRIP P RBIH while mixing liner running pill 17,210.0 17,549.0 02:27 02:39 10/6/2017 1016/2017 0.50 PROD2 DRILL TRIP P PUH while mixing liner running pill 17,549.0 17,386.0 02:39 03:09 10/6/2017 10/6/2017 0.40 PROD2 DRILL TRIP P Line up to coil and start pumping liner 17,386.0 17,246.0 03:09 03:33 running pill, continue to creep uphole 017 017 0.20 PROD2 DRILL TRIP P RBIH to time out Liner running pill 17,246.0 17,619.0 03:33 03:33 03:45 03:45 10/6/2017 10/6/2017 1.40 PROD2 DRILL DISP P PUH laying in 50 bbl 11.5 ppg liner 17,246.0 14,238.0 03:45 05:09 1 running pill Paint Yellow EDP flag @ 14160' 10/6/2017 10/6/2017 1.10 PROD2 DRILL DISP P PUH slowly while bullheading 11.5 14,238.0 14,127.0 05:09 06:15 ppg KW fluid down the CT by tubing annulus. Stage pums up to 1.5 bopm, WH 850 psi, 10/6/2017 10/6/2017 2.30 PROD2 DRILL DISP P SID, Observe well head pressure. 14,127.0 14,127.0 06:15 08:33 Initial 156 psi, after 10 min WH 96 psi, open choke to shaker, bleed 0.5 bbls S/I WH stabilizes @ 87 psi Bleed another 0.4 bbls to shaker WH stabilized at 80 psi. off load 12.0 ppg NaBr from truck Start building 11.8 ppg KW fluid Monitor pressure WH fell slowly to 18 psi while building KW fluid 10/6/2017 10/6/2017 0.60 PROD2 DRILL TRIP P Start displacing the coil with 11.8 ppg 14,127.0 10,878.0 08:33 09:09 KW fluid while PUH Paint white window flag at 10878.34' KW fluid at the bit 10/6/2017 10/6/2017 2.00 PROD2 DRILL TRIP P At surface, flow check, well on a vac, 10,878.0 102.0 09:09 11:09 lost 138 bls of KW on the trip from the window to surface. 10/6/2017 10/6/2017 1.00 PROD2 DRILL PULD P LD over a dead well, Inspect pipe flat 102.0 0.0 11:09 12:09 spots, 0.10" 8 ft back. Hole fill 8.5 bbls Page 19121 Report Printed: 10/17/2017 Operations Summary (with Timelog Depths) 2A-22 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our fir) Phase op code Activity Code Time P -T -X Operation Start Depth (WB) End Depth(WEI) 10/6/2017 10/6/2017 4.00 COMPZ2 CASING PUTB P Bring in 1 additional R2 slotted joint to 0.0 1,589.4 12:09 16:09 ad to tally for seal bore space out, Prep dg floor for running liner, shelter adjusting roller on CTS counter to 2" pipe from 23/8" pipe. PU, 1st R2 slotted joint, MU 3 blanks to the bottom and cap w non ported bull nose. Run 2nd R2 slotted joint and top w 78 joints of R3, 8 blank joints of R2 and a seal bore deployment sleeve. ( 3437.29') filling the hole every 5 joints. Drift lodged in joint # 18, found joint full of wood shavings. Cleared drift, re drifted joint, - clean, carded on. 10/6/2017 10/6/2017 2.00 COMPZ2 CASING PUTB P Continue PU/MU of AL1 liner 1,589.4 2,624.6 16:09 18:09 assembly 10/6/2017 10/6/2017 0.50 COMPZ2 CASING PUTS P Crew change, PJSM, inspect liner 2,624.6 2,624.6 18:09 18:39 running equipment and safelyjoint. perform valve check list. 10/6/2017 10/6/2017 1.15 COMPZ2 CASING PUTS P Continue PU/MU ALl liner asembly 2,624.6 3,437.2 18:39 19:48 1016/2017 10/612017 1.20 COMPZ2 CASING PULD P PU/MU, Coiltrak tools, and BOT 3.0 3,437.2 3,481.4 19:48 21:00 GS, stab into PBR, Hanging weight 25 k on blocks, surface test MWD tools (good test), stab INJH, open rams 10/6/2017 10/612017 2.00 COMM CASING RUNL P RIH, with AL1 liner assembly, 3,481.4 14,284.2 21:00 23:00 pumping beaded pill min rate down the backside. 10/6/2017 10/6/2017 0.25 COMM CASING RUNL P Correct to the EOP flag 14281.46', 14,284.2 14,284.2 23:00 23:15 plus 7.44' 10/6/2017 10/7/2017 0.75 COMPZ2 CASING RUNL P Continue IH 14,284.2 16,590.0 23:15 00:00 10/7/2017 10/7/2017 2.35 COMPZ2 CASING RUNL P Continue to work liner to bottom 16,590.0 17,235.0 00:00 02:21 10/7/2017 10/7/2017 1.00 COMPZ2 CASING RUNL P Continue to work liner to bottom, IA 17,235.0 17,619.0 02:21 03:21 1024, OA 286 10/7/2017 10/7/2017 0.25 COMPZ2 CASING RUNL P Liner is on bottom, PUW 59 k, set 17,619.0 17,619.0 03:21 03:36 down minus 8 k CTSW, DHWOB 0 k, set back down 8 k CTSW, bring pump online at 1.75 bpm at 4,000 psi, PUW 33 k, 10/72017 10/7/2017 0.25 COMPZ2 CASING TRIP P PUH for a tie in 17,619.0 14,090.0 03:36 03:51 10/7/2017 1017/2017 0.25 COMPZ2 CASING DLOG P Log the Kt correction of plus 17.5' 14,090.0 14,120.0 03:51 04:06 10/7/2017 10/72017 0.25 COMPZ2 CASING DISP P Perform BHSP sensor depth 14,105.6' 14,120.0 14,120.0 04:06 04:21 MD, 5,717' ND BHSP 11.625 ppg, 3,456 psi AP 10/7/2017 10/7/2017 0.60 COMM CASING DISP P Line up SW down the coil,displace CT 14,120.0 13,921.0 04:21 04:57 to seawater. 10/7/2017 10/7/2017 0.60 COMPZ2 CASING TRIP P Attempt to lift KW fluid, stage pumps 14,120.0 13,921.0 04:57 05:33 up slowly, No returns, well on a vac. 1017/2017 10172017 1.70 COMPZ2 CASING TRIP P Line up with seawater down the back 13,921.0 57.0 05:33 07:15 side, displacing well bore to seawater taking returns to the formation while pulling out of hole. 125 bbls pumped. WH climbed from 0 to 902 psi. Page 20/21 Report Printed: 1011 712 01 7 Operations Summary (with Timelog Depths) 2A-22 qW Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sheri Time End Thre Dw pen Phase Op Code AcGvi Code N Time P-T-% O wation p n De start Depth End Depth (PKB) 10/7/2017 10/7/2017 1.50 COMPZ2 CASING PULD P PJSM, bump up, space out, PUD BHA 57.0 0.0 07:15 08:45 #11, LD same. 10/7/2017 10/7/2017 0.70 DEMOB WHDBOP FRZP P PJSM, LRS , PT, 3500 psi, equalize, 0.0 0.0 08:45 09:27 open up and bullhead 30 bbis diesel down the tubing. Final WH pressure 1200 psi. 10/7/2017 10/7/2017 1.50 DEMOB WHDBOP MPSP P PJSM, Pull QTS, Instal ASRC BPV 0.0 0.0 09:27 10:57 lubricator, Set BPV, RD lubricator. Final pressure under the lubricator 1000 psi. 10/7/2017 1017/2017 1.00 DEMOB WHDBOP CIRC P Reinstall QTS, stab on w nozzle, jet 0.0 0.0 10:57 11:57 stack while turning coil over to fresh water for next well BOPE test. 10/7/2017 10/7/2017 3.00 DEMOB WHDBOP CTOP P Cut flat spot out of pipe, 20' 1", 0.0 0.0 11:57 14:57 rehead, pull test to 38 k - good. Rehead a-line, PT to 4,000 psi. Pull QTS, install night cap. Lock out storage reel 10/7/2017 10/7/2017 1.00 DEMOB WHDBOP RURD P Blow down. Pull night cap, vac down 0.0 0.0 14:57 15:57 stack. Bore O scope the stack 1017/2017 10/7/2017 2.05 DEMOB WHDBOP RURD P ND and RD in prep to move off. Move 0.0 0.0 15:57 18:00 shop and halfway house spot on 2K- pad. "« Note: Rig Released 18:00 10/7/2017 10/7/2017 DEMOB Trucks back on location, PJSM, 0.0 18:00 18:00 Page 21121 ReportPrinted: 10/1712017 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2A Pad 2A-22AL1 50-103-20221-60 Baker Hughes INTEQ Definitive Survey Report 11 October, 2017 BAKER JUGHES E company .� ConocoPhillips eye._ S ConocoPlllllps Defingive Survey Report m^�a Company. ComeoPhillips(Naska) Inc.-KuP2 Props: Kupduk River Unit Site: Kup ml,k Pad Well: 2A-22 Wellbore: 2A�ZZAL1 Design: 2A-22AL1 Wo),q Kuparuk River Unit, Nods Slope Maeka, United Slates Map System: US Slate Plane 1927 (EmG solution) assume Datum'. Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone O4 Well ZA,22 Local Coon inatg RMerence: Well 2A-22 NO Reference: 2MZ2 135.00usft MD Reference: 2A-22 ®135 Much North Reference: True Survey Calculation Method: Minimum Curvatwe Decades.: EDT Aknce Sandbox Well Foamed aWS 0.00 usft Northing: .EM 0.00 usft Easdng: Position l ream inty 0.00 usft Wellhead Elevation: Wellbore 2A-22AL1 MagMtics Model Nemo Sample Data BGGMM17 11/1/2017 Design ZA-2241.1 Audit Noti Version: 1.0 Phase: ACTUAL Wrtkal SBHi.. Depth From (NDI (dee) 4070 Mean Seas U a Using Well Reference Point Using geodmlc scale tachor 5,960,177.15.0 498,62078 usft use Declaudern (°) 1728 1M On Depth: 15,031.31 AWS IMsrt) 000 tatlWde: LongKode: Grouts Leval: Dip Angle 0 80.87 D ractlon C) 300,00 TO- 18' 8]58 N 150° 0' 40.217 W 94.30 deft Field Strength Inn $7.475 1041RO17 4:03:48PM Page 2 COMPASS 5 ..14 Build 85 ConocoPhillips eA� • ConocoPhillips Definitive Survey Report Company: ConocoPMlllps (Alaska) Ow. -Kup2 Local C.dmmte Reference: Wal TA -T2 Prided: Kupamk River Unit ND Rafannce: 2A-22 Q 13500usd Site: Kupamk 2A Pad MDRerererlce: 271-n Q 13500usa then: 2.22 North assistance: True WelWon: 2M22AL1 Survey Calculation Method M9dmum Curvature MAIN: 271-T L1 Claude.: EOTAMaka SanEhox Survey Program Den 10.BY2017 Fnm To Survey Survey (ueR) (am) Survey (IWllEom) Tool Name Dncrlpnon stare Data End Dan 469.83 14.288.49 2 MSAM (2A-22) MWD MND -Standard 5/18/1895 5/19/1995 14,308.00 14,33523 ?A -22A MWD-INC(2A-2271) MW61NC ONLY MWD-ING ONLY FILLER 9/2612017 WMM17 14,$]2.3] 15.031.31 TMT2AamRo-22A) MWD All -StandeN 9/2812017 1N1Y1017 15.047.00 15,08,18 2A-2TALl MM INC (24-22AL1) MW INC ONLY MAID -INC _ONLY _FILLER 10/2/2017 10.22017 15,11124 17,587.28 TR22AL1 MWD(2A-22AL1) MWD MWD -Standard 101T/2017 1018/2017 Survey Map Map Veneta. MD Ino Ad TVD rvoss aN/5 aEl'W Dta (ues) 0 1% (deft) (Mm) (um) (um) Northing Eaelleg Section Surrey Tool Name Annotation IRI (n) (.11ar) (R) 16013, 00.58 27189 5.80562 5.75062 2,99340 -12.45.36 5,96311322 405172.22 1065 12219,0 MWD (3) TIP 15.047.00 "80 2720 5.H5]0 5,750.70 2,5414 -12,45.03 5,953,17307 489.15,56 1301 12202.97 MN INC ONLY (4) KOP 15,08016 9323 275.40 sets 12 5)5.12 200542 -1240810 5.963.170.16 4812348 145 123m7,1 MND-INLONLY(4) IMegotaled Admulh 15,11324 081 27001 5,88309 5.748.5 2,98800 -12.63206 5,909,177.04 486.09) 52 12.76 12.3mI3 MWD(51 FIM Clean 6uNey !6,140.32 93.30 27237 5,881.39 5.746.39 2998.84 -1258900 5.983.17559 40506351 5.% 12.V5.N MWD(5) 15,15.96 Sam 2829 S.BM.28 5.74530 3.0004 -12,58867 5,893,99.60 486,03392 930 12.40 13 MAD (5) 15.10.99 8870 MU SAW.O 5.745.09 3.005 -1261089 5.993,18029 480003W 888 12,428.37 MWD(5) 16,230.13 8845 257,83 6.M29 5,74539 2,959.84 -12,6082 Sam 9861 485,07377 5.81 12,454,12 MND (5) 15.259.91 W.W 20 42 5.88) 44 5,745. 2908.80 -12,67558 5.963.178.38 485,914.0 230 12.47827 MND(6) 15.28992 8.02 28550 5,000.09 5,745.8 2.89575 -12.70853 5,6-19,17553 485,914.07 718 12.5038 MM (5) 15.32007 .43 2P8.5 5,881.36 5,740.311 2994.65 -12,73300 5.983.174.44 405,004.01 3.85 12.Scs ] WIND (5) 15,34073 W17 269.94 5,081.99 5,74899 28830 -1276832 5,983,173.25 485,854.39 059 12.554.34 MIM) (5) 15.38,5 BB.n 27189 5882.52 3,70 .52 2.9935 -1279912 5,953.173.43 485,02349 588 12,581.17 MWD (6) 15.41204 87.95 274,31 5863.5 5,740.50 2,09531 -12,03126 5.953,175.11 485,791.35 903 1289.05 MWD (5) 15.1 .09 87.A 275.8 5.144.5 3,74960 2,957.81 -13.859.10 593970 486.78324 5,50 863545 MM (5) 15.471.10 8.95 273.87 gold, 12 5.751.12 3,0[035 -12.88924 6.58,1 00 is 485.733.38 501 1280.5 MND (5) 15,5037 888 27129 5,8834 6.753.24 3,0020 -12,92731 5,963.181.89 405, US 31 579 12.69841 lWD(3) 15.64310 88.93 M73 5,89014 5.75514 3.00207 -125!27 5.903.18180 4.661..4 7.55 12,72502 MWD (5) 15,672.8 87.11 Won Seat 67 5.7587 3.800 -02.990.85 5,983,1803 485,631W 365 12,75.73 MWD (6) 10-1120974:03. S M Page3 COMPASS 3000.14 Suits 85 ConocoPhillips BeH ER ConocoPh(ll(ps Defn4we Survey Report t�EHE g Company: COONOPEIIIIps OAJNM) Ina-Kup2 Local Cootdiame Reference: WOO 2A-22 ProjM: Kuume, Minter Unit ND Reference: M-2213500us3 Sita: Kupamk 2A Ped MD Reference'. M-= 135 Daunt Ml 23-22 North Reference: The. millume: 2A-22AL4 Surrey Calculation Method: Minimum Cu enure Deslgn: 2A-22AL1 pauWae: EDTAMaka San00ox tonal Map Map Nanical MD Inc AM MNDSB +NIS 4177-14 DU (NOR) (1) (°) (am) (da") (and) hard)M) Northing Emitting (.1100•) Section Survey Tod Name (R) M) 1SM76 N. Man 5.892.88 5.75].88 2.9138 -1301862 5,863.179.21 485,60401 641 12.774.14 MW (5) 15,83000 88.51 284.16 5,80314 5,]59.14 Zealand -13.048.55 5.983.17673 486674.W 7.60 12,29862 MM (5) 15,65082 88.95 282.34 589354 5750.54 299335 -13.070.36 6,WO17320 48564018 6.33 1282282 MNEI(5) 15.69084 08.0 211034 5.894.33 5,259.33 2,988.03 -13.100.02 5.983,1681. 485,51462 733 12,848.30 MWD(5) 15,120.94 87.91 25708 5,89539 5,280.39 2982.85 -13,13752 5901081 48548512 10.83 12,868.90 Pad, (5) 15750.81 8291 254.74 5.898.40 5761.48 2,97568 -13166.0 5,983.155.55 Ni 783 12,890.34 WN) (61 15,280Y 8831 25361 5,07M 5,762.48 2,07,59 -13,195.00 5.853,14740 485.42757 3.84 12.911.02 MWD (6) 15.81160 ee.40 253.59 589835 5.783.36 2958.4 -13.M85 5.963 138,72 485,397.80 039 12832.48 MM(5) 15.W" 08.44 25548 5.899.16 5,764.16 295101 -13.25295 5.58313093 485.M020 6.51 12952.63 WAD (6) 15.870.51 8792 258.12 5.814.14 578509 2,&4.28 13,28109 5,983.124.18 481 0.98 12,974.110 MAID (5) 15,88042 8733 28012 5.901.32 5.264.32 2.38.85 -13,31129 5.853,11855 485.311W 7.16 12,99734 MoD (5) 1583093 W. 20161 5,20282 5,76.90 293383 -13.34432 5,053.113.24 48528134 5.55 13,02083 MM (5) 15,86112 89.65 M2 he 5.904.79 5,709.79 282874 -13,371.12 5,9U,iO9w 485,25149 4.00 13044.05 MIND (5) 15.99051 85.85 924.98 5,806.92 5.771.92 2,928.62 -13,40033 5.90 ,106.53 48!YM 33 782 13.928.34 NMI (5) 18.022.78 60.8 250.85 5.91414 5,21409 2,92132 -13.432.43 5,803104.24 405,19023 5.05 13.09WN MM (5) 16,051.34 06.90 We. 5,9100 5,775.95 2.42352 -13,48091 5,983.103.41 485.18175 11.44 13.119.25 MM (6) 18.080.81 0776 27242 5.91235 577735 2.924.13 -13,49034 5.863,104.09 485.1T132 801 13,14504 MM (5) 18,11037 82.51 174.46 5,81352 5778.52 2025.90 -13,51982 5033.105.& 485,103.85 8.95 13.121.46 MIND (5) 16,140.84 .11 2M 10 5.01447 S,T790 292870 -13155015 5,933,10885 485,02253 752 13.199.12 AMID (5) 16.1710 8935 22898 5.914.09 5,22680 293278 -13,58098 530311213 40592189 9.29 13,22707 NAME) (5) 10.210.92 88.14 2812M 5.915.27 5,78027 293798 -13.80855 5,253.117.84 925,013.13 7.89 13.255.15 MND(5) 16,23022 88.83 284.. 5,815.80 5,780.80 294439 -13,638.57 6,143.124.34 484.9&.12 9.22 13,283. MIND (5) 18250.M 8714 205.12 5,01805 5.781.85 2.95141 -13,66.59 5,583131.89 4.,955.10 625 13.312.44 MAID (6) 18,29244 89.14 288.42 5.912.95 5,28295 2,93107 -13,69793 5561,141. 48492470 1177 13,.320 MWD(5) 18,320.75 "C9 29CM 5,91870 5,283.70 2,97047 -13,224.0 5093.150.44 4114,80807 748 13.371.11 Ment (6) 16,350.29 07,40 29069 Sidle. 5.784.84 2,900.82 .1375227 5.93316080 484.970 44 2. 13.4..22 MOOD (5) 16,37822 88.93 200.. 5021.10 5760.10 2980. -13,776.58 5,053,16972 4.,.6.12 4.74 13,42574 MND(5) 1641074 850 M7.16 5.92333 5.788.33 3,00060 13.01421 5,933.18058 481,813.44 7. 13.459.48 MWD(5) 10.440.42 0530 No 23 5.92505 5,700 3.008. -13.83775 5,80"08.59 404.204.05 9.93 13.488.15 MWD(5) 16470.511 05.32 211338 5.02612 5,293.12 3,01577 -13,868.41 5,5113.19576 484,7550 281 13,516.88 MND (5) 16.01 .22 ..90 2007 5.93074 5,79574 3022.21 -13,89878 5,803.202.21 4..792.. 785 13.5411.07 MND(n 10/118017 4:0348PM Pege4 Annotation C0MPASS500014Buad85 v ConocoPhillips �T • Con0coPhillips Defntiive Survey Report Company: CO)o08Ph191ps(AlaSke) Inc.-Kup2 Local C9roMinal6 Reference: Well M-22 Project: Kupamk Feel Unit TVD Reference: M 135 When Site: Kup8mk 2A Pad MD Reference: 2A -m 135.00usfl Well: 2422 North Reference: True Wellbore: 2M22AL1 Survey Calculation Method: Minimum Curvature Design: 2-2241-1 Database: EDTMaska San))ex SUN" Map Map Map Vertical MD Inc Rat TVD NDBS A14 .0-W OLS (Imre) r) PI (IMn) (inn) (and) lean) Easling section gurney Tod Name (rel (n) (°1100') (rel 16,530.50 Baa 281]3 5.932.14 5,]8].14 3.02].9] -13825.45 5,96320707 484697.28 1620 13,5]3.]8 MWD(6) 18.559.88 276.13 21.39 5,271323 5.79823 3,033.31 -13,954.11 5,M.213.M 48456852 14.34 13,6019 MWD(5) 1558102 14.39 274.91 Sm0 5.501.09 3,03].20 -13.98506 5,%321]21 414 637,67 1670 13,.20.02 MND(5) 16,62098 84.99 273.55 5.139.12 5,804.12 3.039.39 -1401479 591 481 N 699 13,85518 MWD (5) 18.650.62 89.54 27545 5,94654 5,805.54 3,0410 -14,04428 3,963221.. W578 45 18.83 13, do 57 MM (5) 15830.5] 8638 278.41 6,.82 5.80582 3.04533 -14,074.02 5.963.22538 484.548.73 9.90 13,71112 MM (5) 1531040 no, 280.55 5.94150 5,11 .50 3.050.0 -14,10351 5.963.233.29 484519.24 854 13.739.13 MYMD(5) 16,745.85 89.45 284.35 5,94228 11,10721 3.03788 -14,13803 5983,23792 484, 4"n 11.48 lam" mm (5) 15])51 89.14 201Q 5.942.65 5.807 65 3,06 .62 -14,187,01 5.963,24450 481455]5 5.5] 13,801.29 MM (6) 1810524 9000 282]0 5,04207 5.807 87 3.01091 -14.19597 6.963 250,95 411M.,01 SO 415 13,829.52 MWD(5) 18,83550 9104 28311 5,942.% 5,807.58 3,077.70 -14,22562 59632576 484.397.15 387 13,858.60 MM (5) 18.896.02 92.96 283.14 5,941.54 5,808.51 3.084.58 -14256.17 5,951,284.85 484.367.61 8.29 13,88783 MWD(n 188275.1 93.75 285.16 5939.10 5,804.81 3.09182 44383.83 5,963.2]1.80 484331.95 7.33 13.91607 Man (5) 18.925.96 95.73 259.01 5,93732 5.802.32 310051 14.31243 5.853.281.87 404,31035 1438 13,845.23 MAD(5) 18,95532 078 29056 5.914.88 5,769.80 3,11061 -1431024 5963,29068 481,212.55 830 13,974.32 MM (6) 16.985.53 8809 280.70 5,933.90 5798.90 3,12125 -14.36949 5.96330132 484254.30 1292 14,004.10 MM (5) 17,01559 1731 2918) 5.934.85 5.78055 313214 -14,396.49 5,963,31222 4".=30 961 14,03350 JU D(5) 17,01558 a 004.39 5.935.]] 5,50077 3.14389 44.42404 5,86332387 484,180.]6 9.74 1406SW MWD(5) 17,076% BS.W 296.55 5p35.e7 5.80167 3.15878 -1445111 5.963,33587 454,1]169 743 14,033.42 MUM) (5) 1],105.14 07.02 30021 5,93796 6.M2.at 3,17093 -14.4]].30 5963.35102 all 51 12.70 14,12317 MM (5) 17,13529 87,03 30274 5,8353] 5, Sea 37 3, IN," -14,501.80 5,583385.0 434.120.02 866 14.153.0 mm (6) 17,185.35 00.05 145.69 5,03888 58".98 320343 -14,52].64 5,963383.53 4",045.18 1270 14.11302 MM (5) 17,19510 67.0 30751 5.910.53 SON 63 SM 21 -14,55151 5,963,40131 401,0]124 960 14,21285 Mi (5) 17,22515 1].8] 3134 5,941.70 5,896.]0 g239.fi6 -14.575.30 5.963,41918 4","753 203 14,24241 MAD (5) 1]255.60 1.61 30724 5,94218 5.807 16 3,25823 44,59830 5.963.43834 NtQC&1 1023 14,272.48 Men) 161 17.28508 86]] 304.43 5,84285 5.81185 3275.96 -1482354 5.933 455.96 483.%9.80 15.71 14,302.60 MND(5) 1].315.0] 871 30152 5.814.24 5,80824 3,28182 -1464820 5.983.471.93 483,974.56 10.52 14,33170 MM(5) 17.34&71 [d.3] 299." 5,94538 5.8107 3.305]] -1487.32 5963,418.80 43,"553 7.58 14,38532 MWD(5) 1],3]5.15 1748 207 70 5,945.34 5,911." 3321.37 -14.700.68 5,963,501.49 481822.20 BM 14,381.83 MIM) (5) 17.41107 0462 297.11 5,"881 5.013.81 3,337.82 -14,]32.38 5.953.517.94 483890.49 8.15 14,42].52 MM (S) 17,43523 83" 29567 5,851.27 5,816.27 3348.1 -14,753.91 5,1352662 483.008.98 ].W 1445151 MND(5) Annotation fO 119017 4:03 48PM PUSS 5 COMPASS 500014 Budd 85 Conocolshillips COnocoPhIIIIPS Definitive Survey Report mM^� Company: ConocoPhilips/Alaska) Ina-Kup2 Local Cogfdirwd Reference: NbII 2x22 Pm1ee: Kupamk Rive, Unit ND Reference: 2A -22 135.00u53 a": Kupanuk 2A Red MD Reference: 2.4-22®13500u53 AND: M -M North Reference: Tme Wetmore: 2M22AL1 Survey Calculation Method: Minimum Curvalure Design: 2A-221-1 Datalmse: EDTAMska Sandbox survey MD Inc Joel ND ND38 eWS Map 4FJW Map Dtb Vertical (auto P) P) lusfl) haft) lues) Nonhin9 lose) fasting Sactlon Survey Taal Name gnnWalion lot Ifl) Pn9v) Ifl) 17465.71 082 295.10 SAN.59 5.819.59 3,36149 1478128 5,953,54162 03,8,11 S. 1.91 14,401.71 Mayo (5) 17.49510 6083 296.89 !"Mwe 5,9x.99 3.374.61 -14,808.19 Saws al 4 03,81089 24.12 14,511.57 May) (5) 17,5250 9311 297,48 5.954.99 5.819.% 3,380.20 -11,834.85 5.9&3.588.33 40,788.23 789 14,541.29 MM (5) 17,555.22 9529 20701 5.95279 5,01779 3.40110 -14,861.03 5,083.581.91 483,70188 7.0 14,57092 MAD (5) 17,50728 9&W 28989 5,94948 5,81448 3,41818 14.88840 5.983.593.32 483.733.41 406 14,602.76 MAID (6) 17,61800 60.55 Moe 5,845.80 S.B10w 3,430.33 -14.81764 5,963.61047 483.705.20 0.00 14,634.22 PROJECTEDto TD IMIA2017 o03:49P00 Rallied COMPASS 5000.14 SUTd S5 BAN( PRINT DISTRIBUTION LIST UGHES a GE company RECEIVE COMPANY ConocoPhillips Alaska, Inc. WELL NAME 2A-22AL1 NOV 0 2 2017 FIELD Greater Kuparuk Area A 0 ^CC COUNTY North Slope Borough IJ�J BHI DISTRICT Alaska 21 71 16 28 770 :e sign and return one copy of this transmittal form to: xoPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) G Street. DATA LOGGED 1,i /'1/201-1 lorage, Alaska 99510 M. K. BENDER LOG TYPE GR - RES LOG DATE October 6, 2017 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider@bakerhughes.com TODAYS DATE October 31, 2017 Revision uD %.ZS 2A'L-\l5 STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY ADDRESS (FERE% WILL WT DELIVER TO P.O. BOX) PERSON ATTENTION V I RP North Slope. EOA, PROC. PRBdO (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 Exxon Mobil, Alaska Attn: Lynda M. Yaskell and/or Lconarem Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 FIELD FINAL CD/DVD FINAL PRELIM las, tills, PDF, META, SURVEY REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES 1901 -COPIES # OF COPIES 0 0 0 0 0 5 DNR - Division ofOil&Gas *** 0 0 1 0 Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2 900 E Benson Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 ConocoPhillips RECEIVED NOV 0 2 2011 A®GCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2A Pad 2A-22AL1 50-103-20221-60 Baker Hughes INTEQ Definitive Survey Report 11 October, 2017 BAT UGHES a GE company 21 71 16 28770 Conocophillips BAIT ER Ci ConocoPhillips Definitive Survey Report Company: ConoccPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2A-22 Project: Kuparuk River Unit TVD Reference: 2A-22 @ 135.00usft Site: Kuparuk 2A Pad MD Reference: 2A-22 @ 135.00usft Well: 2A-22 North Reference: True Wellbore: 2A-22AL1 Survey Calculation Method: Minimum Curvature Design: 2A-22AL1 Database: EDT Alaska Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2A-22 - Well Position +NIS 0.00 usft Northing: 5,960, 177.75usft Latitude: 70° 18'8.756 N +E/ -W 0.00 usft Easting: 498,620 78usft Longitude: 150" 0'40.217 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 94.30 usft Wellbore 2A-22AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength V) V) (nn BGGM2017 11/1/2017 17.28 80.87 57,475 Design 2A-22AL1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 15,031.31 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) lusft) (1) 4070 0.00 0.00 300.00 10/112017 4:03:48PM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips BA�(FR 0 ConocoPi� Definitive Survey Report Phillips UGH LS Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2A Pad Well: 2A-22 Wellbore: 2A-22AL1 Design: 2A-22AL1 Survey Program Date 10/6/2017 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2A-22 2A-22 @i3 135.00usft 2A-22 @ 135.00usft True Minimum Curvature EDT Alaska Sandbox From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name. Description Start Date End Date 469.83 14,266.49 2A-22 MWD(2A-22) MWD MWD - Standard 5/19/1995 5/19/1995 14,308.00 14,335.23 2A -22A MWD-INC(2A-22A) MWD -INC -ONLY MWD -INC -ONLY -FILLER 9/26/2017 9/26/2017 14,372.37 15,031.31 2A -22A MWD(2A-22A) MWD MWD -Standard 9/26/2017 10/1/2017 15047.00 15,080.16 2A-22AL1 MWD-INC(2A-22AL7) MWD -INC -ONLY MWD -INC -ONLY -FILLER 10/2/2017 10/2/2017 15.113.24 17,587.28 2A-22AL1 MWD(2A-22AL1) MWD MWD -Standard 10/2/2017 10/6/2017 Survey Annotation TIP KOP Interpolated Azimuth First Clean Survey 10111/2017 4 03 48PM Page 3 COMPASS 5000 14 Build 85 Map Map Vertical MD Inc TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (° ) (°) (1) (usft) (usft) (usft) (usft) (°)1000 Survey Tool Name (ft) (ft) (ft) 15,031.31 90.58 271.89 5,885.62 5,750.62 2,993.48 -12,450.35 5,963,173.22 486,172.22 14.65 12,279.06 MWD (3) 15,047.00 88.80 272.89 5,885.70 5,750.70 2,994.14 -12,466.03 5,963,173.87 486,156.55 13.01 12.292.97 NIM -INC _ONLY (4) 15,080.16 93.23 275.00 5,885.12 5,750.12 2,996.42 -12,499.10 5,963,176.16 486,123.48 14.80 12,322.74 MWD -INC ONLY (4) 15,113.24 93.81 270.81 5.883.09 5.748.09 2,998.09 -12,532.06 5.963.177.84 486.090.52 12.76 12.352.13 MWD (5) 15,140.32 93.38 272.37 5,881.39 5,746.39 2,998.84 -12,559.08 5,963,178.59 486,063.51 5.96 12375.90 MWD(5) 15,169.96 90.92 272.29 5,880.28 5,745.28 3,000.04 -12,588.67 5,963,179.80 486,033.92 8.30 12,402.13 MWD (5) 15,199.99 89.78 269.55 5,880.09 5,745.09 3,000.53 -12,618.69 5,9433,180.29 486,003.90 9.88 12,428.37 MWD (5) 15,230.13 89.45 267.83 5,880.29 5,745.29 2,999.84 -12,648.82 5,963,179.61 485,973.77 5.81 12,454.12 MWD (5) 15,259.91 90.00 267.42 5,680.44 5,745.44 2,998.60 -12,678.58 5,963,178.38 485,944.02 2.30 12,479.27 1(5) 15,289.92 89.02 265.50 5,880.69 5,745.69 2,996.75 -12,708.53 5,963,176.53 485,914.07 7.18 12,504.28 MWD(5) 15,320.07 88.43 266.50 5881.35 5,746.36 2,994.65 -12,738.60 5,963,174.44 485,884.01 3.85 12,529.27 MWO(5) 15,349.73 89.17 268.94 5,881.99 5,746.99 2,993.47 -12,768.22 5,963,173.26 485,854.38 8.59 12,554.34 MWD(5) 15,380.63 88.86 271.66 5,882.52 5,747.52 2,993.63 -12,799.12 5,963,173.43 485,823.49 8.86 12,581.17 MWD(5) 15,412.84 87.66 274.31 5,883.50 5,748.50 2,995.31 -12,831.26 5,963,175.11 485,791.35 9.03 12,609.85 1(5) 15,441.09 87.54 275.86 5,884.68 5,749.68 2,997.81 -12,859.38 5,963,177.62 485,763.24 5.50 12635.45 1(5) 15471.10 86.95 273.87 5,81 5,751.12 3,000.35 -12,889.24 5,963,180.16 485,733.38 6.91 12,662.59 MWD (5) 15,509.27 86.68 271.29 5,888.24 5,753.24 3,002.07 -12,927.31 5,963,181.89 485,695.31 6.79 12,696.41 MWD (5) 15,543.28 86.93 268.73 5,890.14 5,755.14 3,002.07 -12,961.27 5,953,181.90 485,661.36 7.55 12,725.82 NIM (5) 15,572.72 87.11 26707 5,89167 5,756.67 300099 -12,990.65 5,963,180.83 48563199 566 12,750.73 MWD (5) Annotation TIP KOP Interpolated Azimuth First Clean Survey 10111/2017 4 03 48PM Page 3 COMPASS 5000 14 Build 85 ConocoPhillips BA� �cq ConocoPhillips Definitive Survey Report 9. E..u. Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2A-22 Project: Kuparuk River Unit TVD Reference: 2A-22 @ 135,00usft Site: Kuparuk 2A Pad MD Reference: 2A-22 @ 135.00usR Well: 2A-22 North Reference: True Wellbore: 2A-22AL7 Survey Calculation Method! Minimum Curvature Design: 2A-22AL7 Database: EDT Alaska Sandbox Survey 10111/2017 4: 03 48P Page 4 Annotation COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N15 +E/-WDLS Northing Ea(Rng Section Survey Tool Name (usR) (°) (°) (usR) (usR) (usR) (usR) (R) (R) (°/100') IRI 15,600.76 88.74 266.31 5,892.68 5,757.68 2,999.38 -13,018.62 5,963.179.21 485,604.01 6.41 12,774.14 MWD (5) 15,630.80 89.51 264.16 5,893.14 5,758.14 2,996.88 -13,048.55 5,963,176.73 485,574.09 7.60 12.798.82 MWD (5) 15.680.82 88.96 262.34 5,893.54 5.758.54 2,993.35 -13,078.36 5,963.173.20 485544.28 6.33 12,822.87 MWD (5) 15,690.84 88.04 260.34 5,894.33 5,759.33 2,988.83 -13,108.02 5,963,168.69 485,514.62 7.33 12.846.30 MWD (5) 15,720.94 87.91 257.08 5,895.39 5,760.39 2,982.95 -13,137.52 5,963,162.81 485,485.12 10.83 12,868.90 MM (5) 15,750.81 87.91 254.74 5,896.48 5,761.48 2,975.68 -13,166.47 5,963,155.55 485,456.17 7.83 12,890.34 MWD (5) 15,780.56 88.31 253.67 5,897.46 5,762.46 2,967.59 -13,195.08 5,1163.147.46 485,427.57 3.84 12,911.07 MM l5) 15,811.60 88.40 253.59 5,898.35 5,763.36 2,958.84 -13,224,85 5,963,138.72 485,397.80 0.39 12,932.48 MWD (5) 15,840.77 88.44 255.49 5,899.16 5,764.16 2,951.07 -13,252.95 5,963,130.96 485,369.70 6.51 12,952.93 MWD (5) 15,870.51 87.97 258.12 5,900.09 5,765.09 2,944.28 -13,281.89 5,963,124.18 485,340.76 8.98 12,974.60 MWD (5) 15,900.47 87.33 260.17 5,901.32 5,766.32 2,938.65 -13,311.29 5,963,118.55 485,311.36 7.16 12,997.24 MWD (5) 15,930.93 86.44 261.61 5,902.97 5,767.98 2,933.83 -13,341.32 5,963,113.74 485,281.34 5.55 13,020.83 MWD (5) 15,961.12 86.65 262.80 5,904.79 5,769.79 2,929.74 -13,371.17 5,963,109.66 485,251.48 4.00 13,044.65 MWD(5) 15,990.51 85.85 264.96 5,90672 5,771.72 2,926.62 -13,400.33 5,963,106.53 485,222.33 7.82 13,068.34 MWD (5) 16,022.78 85.72 266.85 5,909.09 5.774.09 2,924.32 -13,432.43 5,963.104.24 485,190.23 5.85 13,094.99 MM (5) 16,051.34 86.80 269.94 5,910.95 5,775.95 2,923.52 -13,460.91 5,963,103.45 485,161.75 11.44 13,119.25 MWD(5) 16,080.81 87.76 272.42 5,912.35 5,777.35 2,924.13 -13,490.34 5,963.104.06 485,132.32 9.01 13,145.04 MM (5) 16,110.37 87.51 274.46 5,913.57 5,778.57 2,925.90 -13,519.82 5,963,105.84 485,102.85 6.95 13,171.46 MWD(5) 16,140.84 89.11 276.10 5,914.47 5,779.47 2,928.70 -13,550.15 5,963,108.65 485.072.53 7.52 13,199.12 MM (5) 16,171.95 89.35 278.98 5,914.89 5,779.89 2,932.78 -13,580.98 5,963,112.73 485,041.69 9.29 13.227.87 MWD (5) 16,200.97 89.14 281.26 5,915.27 5,780.27 2,937.88 -13,609.55 5,963,117.84 485,013.13 7.89 13,255.15 MM (5) 16,230.72 88,83 284.00 5,915.80 5,780.80 2,944.39 -13,638.57 5,963,124.34 484,984.12 9.27 13,283.54 MWD (5) 16,260.72 87.14 285.12 5,916.85 5,781.85 2,951.92 -13,667.59 5,963,131.89 484,955.10 6.76 13,312.44 MWD (5) 16,292.44 88.89 288.42 5,917.95 5,782.95 2,961.07 -13,697.93 5,963,141.04 484,924.76 11.77 13,343.29 MM (5) 16,320.75 86.09 290.38 5,918.70 5,783.70 2,970.47 -13,724.63 5,963,150.44 484,898.07 7.48 13,371.11 MWD (5) 16,350.29 87.48 290.69 5,919.84 5,784.84 2,980.82 -13,752.27 5,963,160,80 484.870.44 2.32 13,400.22 MWD (5) 16,376.22 86.93 289.59 5,921.10 5,786.10 2,989.74 -13,776.58 5,963,169.72 484,846.12 4.74 13,425.74 MWD (5) 16,410.74 85.69 287.16 5,923.33 5,788.33 3,000.60 -13.809.27 5,963,180.58 484,813.44 7.89 13,459.46 MWD (5) 16,440.42 85.30 284.23 5,925.66 5,790.66 3,008.60 -13,837.75 5,963,188.59 484,784.96 9.93 13,488.15 MWD (5) 16,470.56 85.32 28338 5928.12 5,793.12 3,015.77 -13,866.92 5,963,19576 484,755.80 2.81 13,516.99 MWD (5) 16,501.22 84.90 280.97 5,930.74 5,795.74 3,022.21 -13,896.78 5,963,202.21 484,725.94 795 13,546.07 MWD (5) 10111/2017 4: 03 48P Page 4 Annotation COMPASS 5000.14 Build 85 ConocoPhillips BAKED Q Philli s Conocop UG REs Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2A-22 Project: Kuparuk River Unit TVD Reference: 2A-22 @ 135.00usH Site: Kuparuk 2A Pad MD Reference: 2A-22 @ 135.00usft Well: 2A-22 North Reference: True - Wellbore: 2A-22AL7 Survey Calculation Method: Minimum Curvature Design: 2A-22AL1 Database: EDT Alaska Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS -N/-S -E1-W DLS (usft) (usft) (usft) (usft) (usft) Northing Easting (°/100` ) Section Survey Too] Name Annotation , (ft) (ft) (ft) 16,53050 8960 281.]3 5,932.14 5,797.14 3,027.97 -13,925.45 5,963207.97 484,69].28 1626 13,573.78 MM (5) 16,559.68 86.13 279.39 5,933.23 5,798.23 3,033.31 -13,954.11 5,963,213.32 484.668.62 14.34 13,601.27 MM (5) i 16,591.02 83.39 274.91 5,936.09 5,801.09 3,037.20 -13,985.06 5,963,217.21 484.637.67 16.70 13,630.02 MWD (5) , 16,620.98 84.99 273.55 5,939.12 5,804.12 3,039.39 -14,014.79 5,963,219.41 484.607.95 6.99 13,656.86 MWD (5) j 16,650.62 89.54 275.45 5,940.54 5,805.54 3,041.72 -14,044.29 5,963,22174 484,578.45 16.63 13683.57 MWD (5) 16,680.57 89.39 278.41 5,940.82 5,805.82 3,045.33 -14,074.02 5,963,225.36 484,548.73 9:90 13,711.12 MM (5) ' ` 16,710.48 88.01 280.56 5,941.50 5,8%.50 3,050.26 -14,103.51 5,963,230.29 484.519.24 8.54 13,739.13 MM (5) 16,745.85 89.45 284.35 5,942.28 5,807.28 3,057.88 -14,138.03 5,963,237.92 484,484.72 11.46 13,772.84 MWD (5) - 16,775.60 89.14 281.82 5,942.65 5,807.65 3,064.62 -14,167.01 5,%3,244.66 484,455.75 8.57 13,801.29 MWD (5) 16,805.24 90.00 282.70 5,942.87 5,807.87 3,070.91 -14,195.97 5,963.250.96 484,426.80 4.15 13,829.52 MWD (5) 16,835.66 91.04 283.11 5,942.59 5,807.59 3,077.70 -14,225.62 5,%3,257.76 484,397.15 3.67 13,858.60 MWD (5) 16,866.02 92.95 283.14 5,941.54 5,8%.54 3,084.59 -14,255.17 5,963,264.65 484,367.61 6.29 13.887.63 MWD (5) 16,895.63 93.75 285.16 5,939.80 5,804.81 3,091.82 -14,283.83 5,5363,271.88 484,338.95 7.33 13,916.07 MVD(5) I 16,925.66 95.73 289.01 5,937.32 5,802.32 3,100.61 -14,312.43 5,963,280.67 484,310.35 14.38 13,945.23 MWD (5) I 16,955.32 93.78 290.56 5,934.86 5,7%.% 3,110.61 -14,340.24 5,963,20.68 484.282.55 8.39 13,974.32 MM (5) 16,985.53 89.88 290.70 5,933.90 5,798.90 3,121.25 -14.368.49 5,963,301.32 484,254.30 12.92 14,004.10 MWD (5) 17,015.59 87.21 291.80 5,934.66 5,799.66 3,132.14 -14.396.49 5,%3,312.22 484,226.30 9.61 14,033.80 MWD (5) I 17,045.56 88.56 294.39 5,935.77 5,800.77 3,143.89 -14,424.04 5,%3,323.97 484,198.76 9.74 14,063.53 MWO(5) j j 17,075.56 88.00 296.55 5,936.67 5,801.67 3,156.78 -14,451.11 5,963,336.87 484,171.69 7.43 14,093.42 MWD (5) 17,105.36 87.02 300.21 5,937.96 5,802.96 3,170.93 -14,477.30 5,963,351.02 484,145.51 12.70 14,123.17 MWD (5) 1 i 17,135.29 87.60 302.74 5,939.37 5,804.37 3,186.54 -14,502.80 5,%3,366.63 484,120.02 8.66 14,153.06 MWD(5) 17,165.35 90.06 305.69 5,939.98 5,804.98 3,203.43 -14,527.64 5,%3,383.53 484,095.18 12.78 14.183.02 MWD (5) ' 17,195.18 87.85 307.51 5,940.53 5,80.53 3,221.21 -14,551.58 5,963,401.31 484,071.24 9.60 14,212.65 MWD (5) 17,225.25 87.67 308.24 5,941.70 5,8%.70 3,239.66 -14,575.30 5,963,419,76 480,047.53 2.50 14,242.41 MWD (5) 17,255.60 90.61 307.24 5,902.16 5,807.16 3,258.23 -14,599.30 5,963,438.34 484,023.54 10.23 14,272.48 MAID (5) 17,285.89 86.77 304.43 5,942.85 5,807.85 3,275.96 -14,623.84 5,963,456.06 463,999.00 15.71 14,302.60 MWD (5) 17,315.07 87.76 301.52 5,944.24 5,809.24 3,291.82 -14,648.29 5,963,471.93 483,974.56 10.52 14,331.70 MM (5) 17,348.71 68.37 299,04 5,945.38 5,810.38 3,308.77 -14677.32 5,963,488.88 483,945.53 7.59 14,365.32 MWD (5) 17,375.25 87,48 297.70 5,946.34 5,811.34 3,321.37 -14,700.66 5,%3,501.49 483,922.20 6.06 14,391.63 MM (5) ' 17,411.07 84.62 297.11 5,948.81 5,813.81 3,337.82 -14,732.38 5,963,517.94 483,690.49 8.15 14,427.52 MWD (5) 17435.23 83.68 29567 5,951.27 5,816.27 3,348.50 -14,753.91 5,963,528.62 483,868.96 7.09 14,451.51 MWD (5) 10/112017 4:03:48PM Page 5 COMPASS 5000.14 Budd 85 ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map -NI'S •E/ -W ConocoPhillips tusft) (usft) (ft) Company: ConocoPhillips (Alaska) Inc. -Kup2 3,374.61 Project: Kuparuk River Unit 3,388.20 -14,834.65 Site: Kuparuk 2A Pad -14,861.03 5,963,581.91 Well: 2A-22 5.963,596.32 3,430.33 -14,917.64 Wellbore: 2A-22AL1 Design: 2A-22AL1 Survey MD Inc Azi TVD TVDSS ' (usrt) CI Cl (usft) (usft) 17,465.71 83.82 295.10 5,954.59 5,819.59 j 17,495.70 90.83 2%.89 5,955.99 5,82099 17,525.47 93.11 297.46 5,954.96 5,819.96 17,555.22 95.29 297.01 5,952.79 5,817.79 17,687.28 96.55 296.68 5,949.48 5,814.48 17,619.00 96.55 296.68 5,945.86 5,810.86 ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: BAIKER Q r)UGHES Well 2A-22 2A-22 @ 135.00usft 2A-22 @ 135.00usft True I Minimum Curvature i EDT Alaska Sandbox i Map Map -NI'S •E/ -W Northing tusft) (usft) (ft) 3,361.49 -14,781.28 5,963,541.62 3,374.61 -14,808.19 5,963,554.74 3,388.20 -14,834.65 5,963,568.33 3,401.78 -14,861.03 5,963,581.91 3,416.18 44,889.48 5.963,596.32 3,430.33 -14,917.64 5,963,610.47 BAIKER Q r)UGHES Well 2A-22 2A-22 @ 135.00usft 2A-22 @ 135.00usft True I Minimum Curvature i EDT Alaska Sandbox i Map Vertical Easting DLS Section Survey Tool Name Annotation (ft) (°Hoo') (ft) 483,841.60 1.91 14.481 71 MWD (5) 483,814.69 24.12 14,511.57 MM (5) 483,788.23 7.89 14,541.29 MWD (5) 483,761.86 7.48 14,570.92 MWD (5) 483.733.41 4.06 14,602.76 MM (5) 483,70526 0.00 14,634.22 PROJECTED to TD 10/11!2017 4:03:48PM Page 6 COMPASS 5000 14 Build 85 RECEIVED OCT 16 2017 AOGCC BATE 1 a GE company To: 217-116 28687 Letter of Transmittal Date: DATA *v2o 1 kit October 16, 2017 M K BENDER Makana Bender AOGCC 333 West 7t" Ave, Suite 100 Anchorage, Alaska 99501 From: Yosha Ragbirsingh / Michael Soper Baker Hughes, a GE Company 795 East 94" Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 3M -27A 3M-27AL1 3M-27AL2PB1 3M-27AL2 3M-27AL2-01 3M-27AL3 2A -22A 2A-22AL1 (8) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BHGE.com Yosha Ragbirsingh, Baker Hughes, Survey Manager ConocoPhillips RECEIVED OCT 16 2017 A®GCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2A Pad 2A-22AL1 50-103-20221-60 Baker Hughes INTEQ Definitive Survey Report 11 October, 2017 217-116 28687 BA ER F�UGHES a GE company ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2A Pad Well: 2A-22 Wellbore: 2A-22AL1 Design: 2A-22AL1 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US Stale Plane 1927 (Exact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 2A-22 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Position +N/ -S 0.00 usft Northing: Using geodetic scale factor +E/ -W 0.00 usft Easting: Position Uncertainty Longitude: 0.00 usft Wellhead Elevation: Wellbore 2A-22AL1 Magnetics Model Name Sample Date BGGM2017 11/1/2017 Design 2A-22AL1 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 4070 Well 2A-22 2A-22 @ 135.00usfl 2A-22 @ 135.00usfl True Minimum Curvature EDT Alaska Sandbox Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,960,177.75 usft Latitude: 498,620.78usft Longitude: usit Ground Level: Declination Dip Angle 17.28 80.87 Tie On Depth: 15,031.31 +N/ -S (usft) 0.00 +E/ -W (usft) 0.00 Direction (°) 300.00 BITER ES 70° 18' 8.756 N 150° 0' 40.217 W 94.30 usfi Field Strength (nT) 57,475 10/112017 4'03:48PM Page 2 COMPASS 5000.14 Build 85 I Survey ConocoPhillips 6A Eft I UGHES ConocoPhilli s p Map Vertical MD Inc Azi TVD TVDSS Definitive Survey Report +E/ -W Company: ConowPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Well 2A-22 (I (usft) Project: Kuparuk River Ung (usft) TVD Reference: 2A-22 @ 135.00usft (°/100') Section Survey Tool Name Site: Kuparuk 2A Pad MD Reference: 2A-22 @ 135.00usft Well: 2A-22 North Reference: True 90.58 271.89 Wellbore: 2A-22AL7 2,993.48 .Survey Calculation Method: Minimum Curvature 486,172.22 14.65 Design: 2A-22AL7 8880 Database: EDT Alaska Sandbox 5,750.70 2,999.14 Survey Program 5,963,173.87 Date 1016/2017-R^'-^s 13.01 ---PT�-J V• ���-�a`v--�--__--�•' 9323 From To 5,750.12 2,996.42 -12,499.10 Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 469.83 14,266.49 2A-22 MWD (2A-22) MWD MWD -Standard 5/19/1995 5/19/1995 93.38. 272.37 5,881.39 5,746.39 2,998.84 -12,559.08 5,963,178.59 14,308.00 14,335.23 2A -22A MWD -INC (2A -22A) MW0.1NC_ONLY MWD -INC _ONLY _FILLER 9/26/2017 9/26/2017 14,372.37 15,031.31 2A -22A MWD (2A -22A) MWD MWD -Standard 9/26/2017 10/1/2017 t I 15,047.00 15,080.16 2A-22AL1 MWD-INC(2A-22AL1) MWD -INC -ONLY MWD -INC -ONLY -FILLER 10/2/2017 10/2/2017 i ( 15,113.24 I 17,587.28 2A-22AL1 MWD(2A-22AL1) MWD MWD - Standard 10/2/2017 10/6/2017 i I Survey 10/11/2017 40348PM Page 3 Annotation TIP KOP Interpolated Azimuth First Clean Survey COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W DLS (usft) (I (I (usft) (usft) Wait) (usft) Northing Easting (°/100') Section Survey Tool Name (ft) (ft) (ft) 15,031.31 90.58 271.89 5,885.62 5,750.62 2,993.48 -12,450.35 5,963,173.22 486,172.22 14.65 12,279.06 MWD(3) 15,047.00 8880 272.89 5,885.70 5,750.70 2,999.14 -12,466.03 5,963,173.87 486,156.55 13.01 12,292.97 MWD -INC _ONLY (4) 15,080.16 9323 27500 5,885.12 5,750.12 2,996.42 -12,499.10 5,953,176.16 486,123.48 14.80 12,32214 MWD -INC -ONLY (4) 15,113.24 93.81 27081 5,883.09 5,748.09 2,996.09 -12,532.06 5,963,177.84 486,090.52 12.76 12,352.13 MWD (5) 15,140.32 93.38. 272.37 5,881.39 5,746.39 2,998.84 -12,559.08 5,963,178.59 486,063.51 5.96 12,375.90 MWD (5) 15,169.96 90.92 27229 5,880.28 5,745.28 3,000.04 -12,588.67 5,963,179.80 486,033.92 8.30 12,402.13 MWD(5) 15,199.99 89.78 269.55 5,880.09 5,745.09 3,000.53 -12,618.69 5,963,180.29 486,003.90 9.88 12,428.37 MWD (5) 15,230.13 89.45 267.83 5,880.29 5,745.29 2,999.84 -12,648.82 5,963,179.61 485,973.77 5.81 12,454.12 MM (5) 15,259.91 90.00 267.42 5,880.44 5,745.44 2,998.60 -12678.58 5,963,178.38 485,944.02 2.30 12,479.27 MM (5) 15,289.92 89.02 26550 5,880.69 5,745.69 2,99615 -12,708.53 5,963,176.53 485,914.07 7.18 12,504.28 MAD (5) 15,320.07 88.43 266.50 5,881.36 5,746.36 2,994.65 -12,738.60 5,963,17444 485,884.01 3.85 12,529.27 MWD (5) 15,349.73 89.17 268.94 5,881.99 5,746.99 2,993.47 -12,768.22 5,963,173.26 485,854.38 8.59 12,554.34 MWD (5) 15,380.63 88.86 271.66 5,88252 5,747.52 2,993.63 -12,799.12 5,963,173.43 485,823.49 8.86 12,581.17 MM (5) 15,412.84 87.66 274.31 5,883.50 5,748.50 2,995.31 -12,83126 5,963,175.11 485,791.35 9.03 12,609.85 MM (5) 15,441.09 87 54 27586 5,884.68 5,749.68 2,997.81 -12,859.38 5,963,177,62 485,763.24 5.50 12,63545 MWD (5) 15,471.10 86.95 273.87 5,886.12 5,751.12 3,000.35 -12,889.24 5,963,180.16 485,733.38 6.91 12A5Z59 MWD(5) 15,509.27 86.68 271.29 5,888.24 5,75324 3,002.07 -12,927.31 5,963,181.89 485,695.31 6.79 12,696.41 MWD (5) 15,543.28 86.93 268.73 5,890.14 5,755.14 3,002.07 -12,961,27 5,963,181.90 485,661.36 7.55 12,725.82 MM (5) 15,572.72 87.11 26707 5,89167 5,756.67 3,000.99 -12,99065 5,963,180.83 485,631.99 566 12750.73 MWD (5) 10/11/2017 40348PM Page 3 Annotation TIP KOP Interpolated Azimuth First Clean Survey COMPASS 5000.14 Build 85 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kuparuk 2A Pad Well: 2A-22 Wellbore: 2A-22AL7 Design: 2A-22AL7 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2A-22 2A-22 (a7 135.00usft 2A-22 @ 135.00usft True Minimum Curvature EDT Alaska Sandbox 10/11/2017 4: 03: 48PM Page 4 BA ER F�DGHES Annotation COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azl TVD TVDSS +N/ -S +E/ -W DLS Northing Easting Section Survey Tool Name (usft) P) (1 (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) 15,600.76 88.74 266.31 5,892.68 5,757.68 2,999.38 -13,01862 5,963,17921 485,604.01 6.41 12,774.14 MWD (5) 15,630.80 89.51 264.16 5,893.14 5,758.14 2,996.88 -13,048.55 5,963,176.73 485,574.09 7.60 12,798.82 MWD (5) 15,660.82 88.96 262.34 5,893.54 5,758.54 2,993.35 -13,078.36 5,963,17320 485,544.28 6.33 12,822.87 MWD (5) 15,690.84 88.04 260.34 5,89433 5,759.33 2,988.83 -13,108.02 5,963,168.69 485,51462 7.33 12,846.30 MWD(5) 15,720.94 87.91 257.08 5,895.39 5,760.39 2,982.95 -13,137.52 5,963,162.81 485,485.12 10.83 12,868.90 MWD (5) 15,750.81 87.91 254.74 5,896.48 5,761.48 2,97568 -13,166.47 5,963,155.55 485,456.17 7.83 12,890.34 MWD (5) 15,78656 88.31 253.67 5,897.46 5,762.46 2,967.59 -13,195.08 5,963,147.46 485,427.57 3.84 12,911.07 MWD (5) 15,81160 88.40 253.59 5,898.35 5,763.36 2,958.84 -13,224.85 5,963,138.72 485,397.80 0.39 12,932.48 MM (5) 15,84077 88.44 255.49 5,899.16 5,764.16 2,951.07 -13,252.95 5,963,130.96 485,369.70 6.51 12,952.93 MWD (5) 15,870.51 87.97 258.12 5,90009 5,76599 2,944.28 -13,281.89 5,963,124.18 485,340.76 8.98 12,974.60 MWD (5) 15,900.47 87.33 260.17 5,901.32 5,76632 2,938.65 -13,311.29 5,963,118.55 485,311.36 7.16 12,99724 MWD (5) 15,930.93 86.44 261.61 5,902.97 5,767.98 2,933.83 -13,341.32 5,963,113.74 485,281.34 5.55 13,020.83 MM (5) 15,961.12 86.65 262.80 5,90479 5,769.79 2,929.74 -13,371.17 5,963,109.66 485,251.48 4.00 13,044.65 MWD (5) 15,990.51 85.85 264.96 5,906.72 5,771.72 2,926.62 -13,400.33 5,963,106.53 485,222.33 7.82 13,068.34 MWD (5) 16,022.78 85.72 266.85 5,909.09 5,77499 2,924.32 -13,432.43 5,963,104.24 485,190.23 5.85 13,094.99 MM (5) 16,051.34 86.60 269.94 5,910.95 5,775.95 2,923.52 -13,460.91 5,963,103.45 485,161.75 11.44 13,119.25 MWD(5) 16,080.81 87.76 272.42 5,912.35 5,777.35 2,924.13 -13,490.34 5,963,104.06 485,132.32 9.01 13,14604 MVJD(5) 16,110.37 87.51 274.46 5,913.57 5,778.57 2,925.90 -13,519.82 5,963,105.84 485,102.85 6.95 13,171.46 MWD (5) 16,140.84 89.11 276A0 5,914.47 5,779.47 2,928.70 -13,550.15 5,963,108.65 485,072.53 7.52 13,199.12 MWD(5) 16,171.95 89.35 27898 5,914.69 5,779.89 2,932.78 -13,560.96 5,963,112.73 485,041.69 9.29 13,227.87 MM (5) 16,200.97 89.14 281.26 5,915.27 5,780.27 2,937.88 -13,609.55 5,963,117.84 485,013.13 7.89 13,255.15 MWD (5) 16,230.72 88.83 28400 5,915.80 5,780.80 2,944.39 -13,638.57 5,963,124.34 484,984.12 9.27 13,283.54 MM (5) 16,260.72 87.14 285.12 5,916.85 5,781.85 2,95192 -13,667.59 5,963,131.89 484,955.10 6.76 13,31244 MWD (5) 16,292.44 88.89 288.42 5,917,95 5,782.95 2,961.07 -13,697.93 5,963,141.04 484,92476 11.77 13,343.29 MWD (5) 16,320.75 8899 290.38 5,91870 5,783.70 2,970.47 -13,724.63 5,963,150.44 484,898.07 7.48 13,371.11 MWD (6) 16,350.29 8748 290.69 5,919.84 5,784.84 2,980.82 -13,752.27 5,963,160.80 484,870.44 2.32 13,400.22 MM (5) 16,376.22 86.93 289.59 5,921,10 5,786.10 2,989.74 -13,776.56 5,963,16932 484,846.12 474 13,425.74 MWD (5) 16,410.74 85.69 287.16 5,923.33 5,788.33 3,000.60 -13,809.27 5,963,180.58 484,813.44 7.89 13,459.48 MWD (5) 16,440.42 85.30 28423 5,925.66 5,790.66 3,008.60 -13,837.75 5,963,188.59 484,784.96 9.93 13,488.15 MWD (5) 16,470.56 85.32 283.38 5,928.12 5,793.12 3,015.77 -13,866.92 5,963,195.76 484,755.80 2.81 13,51699 M4VD(5) 16,501.22 64.90 28097 5,930.74 5.795.74 3,022.21 -13,896.78 5.96320221 484,725.94 7.95 13,546.07 MWD(5) 10/11/2017 4: 03: 48PM Page 4 BA ER F�DGHES Annotation COMPASS 5000.14 Build 85 ConocoPhillips sA ER ConocoPhillips Definitive Survey Report .hR E„S Company: Project: Site: Well: Wellbore: Design: ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2A Pad 2A-22 2A-22AL7 2A-22AL7 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2A-22 2A-22 @ 135.00usft 2A-22 @ 135.00usft True Minimum Curvature EDT Alaska Sandbox Survey Map Map Vertical MD Inc Azi TVD NDSS +N/ -S -E/-W DLS (usft) (') (1) (usft) (usft) (usft) (usft) Northing Easting V/100') Section Survey Tool Name Annotation (ftj (ft) (ft) 16,530.50 8960 281.73 5,932.14 5,797.14 3,027.97 -13,925.45 5,963,207.97 484,697.28 16.26 13,573.78 MAD (5) 16,559.68 86.13 279.39 5,933.23 5,798.23 3,033.31 -13,954.11 5,963,21332 484,668.62 14.34 13,601.27 MWD (5) 16,591.02 83.39 274.91 5,936.09 5,801.09 3,037.20 -13,985.06 5,963217.21 484,637.67 1670 13,630.02 MWD(5) 16,620.98 84.99 273.55 5,939.12 5,804.12 3,039.39 -14,01479 5,96321941 484,607.95 6.99 13,656.85 MWD (5) 16,65062 89.54 275.45 5,940.54 5,805.54 3,091.72 -14,044.29 5,963,22174 484,57845 16.63 13,683.57 MWD (5) 16,680.57 89.39 278.41 5,940.82 5,805.82 3,045.33 -14,074.02 5,963,22536 484,548.73 9.90 13,711.12 MWD (5) 16,710.48 88.01 280.56 5,941.50 5,805.50 3,05026 -14,103.51 5,963,230.29 484,51924 8.54 13,739.13 MWD (5) 16,74585 8945 284.35 5,942.28 5,807.28 3,057.88 -14,138.3 5,963,237.92 484,484.72 1146 13,772.84 MWD (5) 16,775.60 89.14 281.82 5,992.65 5,807.65 3.054.62 -14,167.01 5,963,244.65 484,455.75 8.57 13,801.29 MWD (5) 16,80524 90.00 282.70 5,942.87 5,807.87 3,070.91 -14,195.7 5,963,25096 484,426.80 4.15 13,829.52 MWD (5) 16,83566 91.04 283.11 5,942.59 5,807.59 3,077.70 -14,22562 5,963,257.76 484,397.15 367 13,858.60 MWD(5) 16,866.02 92.95 283.14 5,941.54 5,806.54 3,084.59 -14,255.17 5,963,264.65 484,367.61 6.29 13,887.63 MWD (5) 16,89563 93.75 285.16 5,939.80 5,804.81 3,091.82 -14,283.83 5,963,271.88 484,338.95 7.33 13,916.07 MAD (5) 16,925.66 95.73 289.01 5,937.32 5,802.32 3,100.61 -14,312.43 5,963,280.67 484,310.35 14.38 13945.23 MWD (5) 16,955.32 93.78 290.56 5,934.86 5,799.86 3,11061 -14,340.24 5,963,290.68 484,282.55 8.39 13,974.32 MM 15) 16,985.53 89.88 290.70 5,933.90 5,798.90 3,12125 -14,368.49 5,963,30132 484,254.30 12.92 14,004.10 MWD (5) 17,015.59 87.21 291.80 5,934.66 5,799.66 3,132.14 -16,396.49 5,963,312.22 484,226.30 9.61 14,033.80 MWD (5) 17,045.56 8856 294.39 5,935.77 5,800.77 3,143.89 -14,424.04 5,963,323.97 484,198.76 974 14,063.53 MM (5) 17,075.56 88.0 2%55 5,936.67 5,801.67 3,156.78 -14,451.11 5,963,336.87 484,171.69 7.43 14,093.42 MWD (5) 17,105.36 87.02 300.21 5,937.96 5,802.96 3,170.93 -14,477.30 5,963,351.02 484,145.51 12.70 14,123.17 MWD (6) 17,135.29 87.60 302.74 5,939.37 5,804.37 3,186.54 -14,502.80 5,963366.63 484,120.02 8.66 14,153.06 MM (5) 17,165.35 90.6 305.69 5,939.98 5,804.98 3,203.43 -14,527.64 5,963,383.53 484,095.18 12.78 14,183.02 MWD (5) 17,195.18 87.85 307.51 5,940.53 5,805.53 3,221.21 -14,551.58 5,963401.31 484,071.24 960 14,212.65 MWD (5) 17,225.25 87,67 308.24 5,941.70 5,806.70 3,23966 -14,57530 5,963,419.76 484,047.53 2.50 14,242.41 MWD (5) 17,255.60 90.61 307.24 5,942.16 5,807.16 3,258.23 -14,599.30 5,963,438.34 484,023.54 10.23 14,272.48 MM (5) 17,28589 86.77 304.43 5,942.85 5,807.85 3,275.96 -14,623.84 5,963,456.06 483,999.00 15.71 14,302.60 MWD(5) 17,315.07 87.76 301.52 5,944.24 5,809.24 3,291.82 -14,648.29 5,963,471.93 483,974.56 10.52 14,331.70 MWD(5) 17,348.71 8837 299.04 5,945.38 5,810.38 3,308.77 -14,677.32 5,963,486.88 483,945.53 7.59 14,365.32 MWD (5) 17,37525 87.48 297.70 5,946.34 5,811.34 3,321.37 -14,70866 5,963,501.49 483,922.20 6.06 14,391.83 MAD (5) 17,411.07 84.62 297.11 5,948.81 5,813.81 3,337.82 -14,732.38 5,963,51794 483,890.49 8.15 14,427.52 MWD (5) 17,435.23 83.68 29567 5951.27 5,816.27 3,348.50 -14,753.91 5963,52862 483,868.96 709 14,451.51 MM (5) 1011112017 4r03:48PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips aA EE ConocoPhillips Definitive Survey Report u�t ws Company: ConocoPhillips (Alaska) Inc. -Kup2 project: Kuparuk River Unit Site: Kuparuk 2A Pad Well: 2A-22 Wellbore: 2A-22AL1 Design: 2A-22ALl Survey Well 2A-22 TVD Reference: 2A-22 135.00usft MD Reference: ( MD Inc AN TVD TVDSS (usft) (°I (°) (WIN) Wall 17,465.71 83.82 295.10 5,954.59 5,819.59 17,495.70 90.83 296.89 5,955.99 5,820.99 17,525.47 93.11 29746 5,954.96 5,819.96 17,555.22 95.29 297D1 5,952.79 5,817.79 17,587.28 96.55 296.68 5,949.48 5,814.48 17.619.00 96.55 296.68 5,945.86 5,81086 Local Co-ordinate Reference: Well 2A-22 TVD Reference: 2A-22 135.00usft MD Reference: 2A-22 135.00usft North Reference: True Survey Calculation Method; Minimum Curvature Database: EDT Alaska Sandbox 10/112017 4: 03: 48PM Page 6 COMPASS 5000.14 Build 85 Map Vertical +N/ -S Wait) +E/ -W (uaR) Northing Northing Easting DLS P/100'1 Section Survey Tool Name Annotation IR). (R). (ft) 3,361.49 -14,781.28 5,963,541.62 483,841.60 1.91 14,48171 MWD (5) 3,374.61 -14,808.19 5,963,554.74 483,814.69 24.12 14,51157 MWD (5) 3,388.20 -14,834.65 5,963,568.33 483,788.23 789 14,541.29 MWD (5) 3,401.78 -14,861.03 5,963,581.91 483,761.86 7.48 14,570.92 MWD (5) 3,416.18 -14,889.48 5,953,596.32 483,733.41 4.06 14,602.76 MVVD(5) 3,430.33 -14,917.64 5,963,610.47 483,705.26 0.00 14,634.22 PROJECTEDIo TD 10/112017 4: 03: 48PM Page 6 COMPASS 5000.14 Build 85 THE STATE GOVERNOR BILL WALKER Kai Starck CTD Team Lead ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Clic and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2A-22AL1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-116 Surface Location: 4523' FNL, 5052' FEL, SEC. 13, TI IN, R8E, UM Bottomhole Location: 875' FNL, 4430' FEL, SEC. 16, TI IN, R8E, UM Dear Mr. Starck: Enclosed is the approved application for permit to re -drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit 217-115, API 50-103-20221-01- 00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy . Foerster Commissioner DATED this lP day of September, 2017. STATE OF ALASKA , ALA_..A OIL AND GAS CONSERVATION COMMIb_.JN PERMIT TO DRILL 20 AAC 25.005 EGENUP 4UL 0 7 21017 neE`r 1a. Type of Work: Proposed Well Class: Exploratory - Gas Ll Service- WAG Service - Disp ❑ 1c. Speci i walks proposed for: Drill ❑ Lateral, Q 11b. Stratigraphic Test ❑ Development - Oil • Service - Winj ❑ Single Zone ❑� Coalbed Gas ❑ Gas Hydrates ❑ RednII ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q , Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska Inc Bond No. 5952180 R%,,. 2A-22AL1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 18000 TVD: 5867 . Kuparuk River Field / Kuparuk Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 4523' FNL, 5052' FEL, SEC 13, T 11 N, R 8E, UM ADL025570, ADL025571 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 1563' FNL, 1696' FEL, SEC 16, T 11N, R 8E, UM 9318991000, 931892000 _ 811 17 9/jsI Total Depth: 9. Acres in Property: 14. Distan earest Property: 875' FNL, 4430' FEL, SEC 16, T 11 N, R 8E, UM 26W SJZo 850' 4b. Location of Well (Stale Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 135 15. Distance to Nearest Well Open Surface: x- 498620 y- 5960177 Zone- 4 GL / BF Elevation above MSL (ft): 94 - to Same Pool: 2,059' 16. Deviated wells: Kickoff depth: 15,050 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 94 degrees Downhole: 3832 - Surface: 3245' 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST -L 3,760' 14,240' 5,661' 18,000' 5,867' Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 14,797' 6,144' NA 14,340' 5,864' NA Casing Length Size Cement Volume MD TVD Conductor/Structural 80.00 16 250 sx ASI 121 121 Surface 4,887.00 9.625 820 sx AS III Lead, 890 sx Class G 4928 2937 Intermediate Tail Production 14,749.00 7 260 sx Class G 14787 6138 Liner Perforation Depth MD (ft): 14,302'-14,317', 14,330'-14,348', Perforation Depth TVD (ft): 5,835'-5,844', 5,852'-5,864', 14,352'-14,378' 5,866'-5,882' Hydraulic Fracture planned? Yes❑ No ❑� 20. Attachments: Property Plat ❑ BP Sketch ram✓ DSeanIfirbed Timlot Shallow Hazard Analysis Diverter Sketch e Report Drilling Fluid ProgDepthram B 20 AAC 25.050 requirements B 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: Trevor Hyatt Authorized Name: Kai Starck d Contact Email: trevor.hvattAmnlractor wnmoolilruscom Authorized Title: CTD Team Lead Contact Phone: 907-223-3087 S�rStecclL Authorized Signature: Date: 017 817/2017 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: — 50- 3" Q '0 —�� Date: q I1 requirements. rr 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: 1Z Other: 13op tC5/ 4t7 q& 5 I Samples req'd: Yes ❑ No[V Mud log req'd: Yes © ❑ No" HzS measures: Yes [f Noz Directional svy req'd: Yes [ryrNo❑ / r ✓(h �(/ /} h {� V a /7 / rC o Z SG acing exception req'd: Yes ❑ No[j( Inclination -only svy req'd: Yes ❑ No Q' Ya iJ , i C G 15 /-4 ✓>ft d t-0 Post initial injection MIT req'd: Yes ElNo L'J &I How k)c1<o�; poi,-) t- fo b'c \ atck9 the 1Gvc5t-h o� tj-1cPclr?nt !arts (�ofirrG2S,bt>t APPROVED BY �_ / : — / Approved b COMMISSIONER THE COMMISSION Date: to I A' A Submit Form and F rim 10401 ev' d 5/2017 X d <>)o t'7 d t d months from the,datG of a proval per 20 AAC 25.005(g) Attachments in Duplicate Il ?'/ _ 4l ri I l .W'CrV// ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 3, 2017 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: DECEIVED /pASU GG 00 7/� 22017 �^1OGCC ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a dual -lateral out of the KRU 2A-22 (PTD# 195-068) using the coiled tubing drilling rig, Nabors CDR3-AC. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. The CTD objective will be to drill two laterals (2A -22A & 2A-22AL1), targeting the Kuparuk C -sand intervals. The work is scheduled to begin August 12th, 2017. Attached to this application are the following documents: — Permit to Drill Application Forms (10-401) for 2A -22A & 2A-22AL1 — Detailed Summary of Operations — Directional Plans for 2A -22A & 2A-22AL1 — Current wellbore schematic — Proposed wellbore schematic If you have any questions or require additional information, please contact me at 907-263-4109 (cell 907-223-3087). Sincerely, Tre Hyatt Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 2A-22A & 2A-22AL1 #*U% ALASKA Application for Permit to Drill Document C� J', 1. Well Name and Classification.............................................................................................................2 (Requrements of 20 AAC 25.005(V and 20 AAC 25.005(b)).................................................................................................................... 2 2. Location Summary...............................................................................................................................2 (Requrements of 20 AAC 25.005(c)(2))...................................................................................................................................................2 3. Blowout Prevention Equipment Information....................................................................................2 (Requrements of 20 AAC 25.005(c)(3)).................................................................................................................................................. 2 4. Drilling Hazards Information and Reservoir Pressure....................................................................2 (Requrements of 20 AAC 25.005 (c)(4)) ..................................... _............................. _..... ....................................................................... 2 5. Procedure for Conducting Formation Integrity tests......................................................................2 (Requrements of 20 AAC 25.005(c)(5))................................................................................................................................................... 2 6. Casing and Cementing Program........................................................................................................3 (Requrements of 20 AAC 25.005(c)(6))................................................................................................................................................... 3 7. Diverter System Information..............................................................................................................3 (Requrements of 20 AAC 25.005(c)(7))................................................................................................................................................... 3 8. Drilling Fluids Program.......................................................................................................................3 (Requrements of 20 AAC 25.005(c)(8))................................................................................................................................................... 3 9. Abnormally Pressured Formation Information................................................................................4 (Requrements of 20 AAC 25.005(c)(9))................................................................................................................................................... 4 10. Seismic Analysis..................................................................................................................................4 (Requrements of 20 AAC 25.005(c)(10))................................................................................................................................................. 4 11. Seabed Condition Analysis................................................................................................................4 (Requrements of 20 AAC 25.005(c)(11))................................................................................................................................................. 4 12. Evidence of Bonding...........................................................................................................................4 (Requrements of 20 AAC 25.005(c)(12))................................................................................................................................................. 4 13. Proposed Drilling Program.................................................................................................................4 (Requrements of 20 AAC 25.005(c)(13))............................................................................................................................ 4 Summaryof Operations.....................................................................................................................................................................4 LinerRunning......................................................................................................................................................................................6 14. Disposal of Drilling Mud and Cuttings .................................... (Requrements of 20 AAC 25.005(c)(14))................................................................... 15. Directional Plans for Intentionally Deviated Wells ................, (Requrements of 20 AAC 25.050(b))......................................................................... 16. Attachments............................................................................... Attachment 1: Directional Plans for 2A -22A& 2A-22AL1 laterals ............... Attachment2: Current Well Schematicfor2A-22.......................................... Attachment 3: Proposed Well Schematic for 2A -22A& 2A-22AL1 laterals .................... 6 ........................... 6 ............ I .............. 6 ........................... 6 Page 1 of 6 August 1, 2017 PTD ADDlication: 2A -22A & 2A-22AL1 Well Name and Classification (Requirements of 20 AAC 25.005(o and 20 AAC 25.005(b)) The proposed laterals described in this document are 2A -22A & 2A-22AL1. All laterals will be classified as "Development -011" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A and C sand packages in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 2A -22A & 2A-22AL1. 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 4,000 psi. Using the maximum formation pressure in the area of 3,832 psi in 2A-20 (i.e. 12.46 ppg EMW), the maximum potential surface pressure in 2A -22A, assuming a gas gradient of 0.1 psi/ft, would be 3,245 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 2A-22 was measured to be 2,962 psi (9.76 ppg EMW) on 11/7/2017. The maximum downhole pressure in the 2A-22 vicinity is to the east in the 2A-21 injector at 3,636 psi (11.7 ppg EMW) from 07/07/2007. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injection wells to 2A-22 have historically injected gas to the west and southwest.There is a small probability of encountering free gas while drilling the 2A -22A laterals. If significant gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 2A -22A 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 2A -22A laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 6 August 3, 2017 PTD Application: 2A -22A & 2A-22AL1 6. Casing and Cementing Program (Requirements of 20 AA 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top LinerBtm Liner Details MD MD TVDSS TVDSS 2A -22A 15,050' 18,000' 5,760' 5,867' 2-3/8", 4.7#, L-80, ST -L slotted liner; aluminum billet on to 2A-22AL1 14,240' 18,000' 5,660' 5,867' 2-3/8", 4.7#, L-80, ST -L slotted liner; de to ment sleeve 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 AA 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride -based FloVis mud (8.6 ppg) Drilling operations: Chloride -based FloVis mud (8.6 ppg). This mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions w411 be maintained using MPD practices described below — Completion operations: The well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over -balance and well bore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 2A -22A laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of August 3, 2017 PTD Application: 2A -22A & 2A-22AL1 Pressure atthe 2A -22A Window 14,310 MD and 5,705' TVD Using MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AA 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 AA 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 AA 25.005(c)(13)) Summary of Operations Background Well KRU 2A-22 is a Kuparuk A and C sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the A and C sands to the west of 2A-22. The laterals will increase resource recovery and add new resources. Prior to CTD operations, E -line will punch 2' of holes in the 3-1/2" tubing tail below the packer at 14,227' MD and the D nipple at 14,242' MD will be milled out to a 2.80" ID. The existing A and C sand perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing. Following the cement squeeze, Nabors CDR3 will drill a cement pilot hole to 14,340' MD and set a mechanical whipstock in the 2.80" pilot hole at the planned kick off point of 14,310' MD. The 2A -22A lateral will exit through the 7" at 14,310' MD and TD at 18,000' MD, targeting the A and C sands to the west. It will be completed with 2-3/8" slotted liner from TD up to 15,050' MD with an aluminum billet for kicking off the 2A-22AL 1 lateral. The 2A-22AL] lateral will drill to a TD of 18,000' MD targeting the A and C sands. It will be completed with 2-3/8" slotted liner from TD up inside 3-1/2" tubing tail to 14,240' MD with a deployment sleeve. Page 4 of August 3, 2017 Pumps On 1.5 bpm) Pumps Off A/C -sand Formation Pressure 9.76 2895 psi 2895 psi Mud Hydrostatic 8.6 2551 psi 2551 psi Annular friction i.e. ECD, 0.09psi/ft) 1288 psi 0 psi Mud + ECD Combined no chokepressure) 3839 psi overbalanced -944psi) 2551 psi (underbalanced -344psi) Target BHP at Window 11.8 ) 3500 psi 3500psi Choke Pressure Required to Maintain Target BHP 0 psi 949 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AA 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 AA 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 AA 25.005(c)(13)) Summary of Operations Background Well KRU 2A-22 is a Kuparuk A and C sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the A and C sands to the west of 2A-22. The laterals will increase resource recovery and add new resources. Prior to CTD operations, E -line will punch 2' of holes in the 3-1/2" tubing tail below the packer at 14,227' MD and the D nipple at 14,242' MD will be milled out to a 2.80" ID. The existing A and C sand perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing. Following the cement squeeze, Nabors CDR3 will drill a cement pilot hole to 14,340' MD and set a mechanical whipstock in the 2.80" pilot hole at the planned kick off point of 14,310' MD. The 2A -22A lateral will exit through the 7" at 14,310' MD and TD at 18,000' MD, targeting the A and C sands to the west. It will be completed with 2-3/8" slotted liner from TD up to 15,050' MD with an aluminum billet for kicking off the 2A-22AL 1 lateral. The 2A-22AL] lateral will drill to a TD of 18,000' MD targeting the A and C sands. It will be completed with 2-3/8" slotted liner from TD up inside 3-1/2" tubing tail to 14,240' MD with a deployment sleeve. Page 4 of August 3, 2017 PTD Application: 2A -22A & 2A-22AL1 Pre -CTD Work 1. Slickline (Fullbore assist): a. Dummy GLVs b. Injectivity Test 2. Coil: a. Obtain GR/CCL jewelry log and memory caliper log above tag b. Perftubing tail c. Mill D nipple and tag TD for depth control d. Lay in Cement Plug (7" casing up to tubing tail) 3. Slickline: a. Tag TOC b. Pressure Test Cement Squeeze and Negative Test Rig Work 2. MIRU Nabors Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2A -22A Lateral (A and C sand) a. Drill 2.80" pilot hole through cement to 14,340' MD b. Caliper pilot hole c. Set top of whipstock at 14,310' MD and mill 2.80" window d. Drill 3" bi-center lateral to TD of 18,000' MD. e. Run 2%" slotted liner with an aluminum billet from TD up to 15,050' NO. 4. 2A-22AL1 Lateral (A and C sand) a. Kick off the aluminum billet at 15,050' MD. b. Drill 3" bi-center lateral to TD of 18,000' M. c. Run 23/s" slotted liner with deployment sleeve from TD up into 3-1/2" production tubing to 14,240' MD. 5. Freeze protect, ND BOPE, and RDMO Nabors CDR3- AC rig. Post -Rig Work 1. Obtain SBHP. 2. Install gas lift design. 3. Return to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reserwir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from Page 5 of 6 August 3, 2017 PTD Application: 2A -22A & 2A-22AL1 moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 2A -22A laterals will be displaced to an overbalancing fluid (11.8 ppg NaBr) prior to running liner. See "Drilling Fluids" section for more details. — While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (113-18 or 1B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AA 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plans — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire open hole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 2A -22A 710' 2A-22AL1 850' — Distance to Nearest Well within Pool Lateral Name Distance Well 2A -22A 2048' 2T-36- 2A-22AL1 2059' 2T-36` *1490' West Sak 18 is P&A'd 16. Attachments Attachment 1: Directional Plans for2A-22A & 2A-22AL1 laterals Attachment 2: Current Well Schematic for 2A-22 Attachment 3: Proposed Well Schematic for 2A -22A & 2A-22AL 1 laterals Page 6 of 6 August 3, 2017 KUP PROD 2A-22 eonoeoPhllUp$ Well Attributes MaxAngle&MD TD AlaskalrlC Walbore PPuuw1 F1tltl Name weueol[stgus 501032022100 KUPARUKRNERUNIT PROD riaL MOVMet M161m Ince) ]559 4,18853 14,]9].0 Disappoint H25(pp.)Dah SSSV: NIPPLE 120 12/&2016 MndAlon Ent pale Lest"I 9/202014 KBGN III, RIP R¢Imse Dons 4590 6/11/1995 2x4. erI 4'. 14.1 PM n[alawmeee acMl AnpdAlon Oe Ph MKBI End DYe the-bn LeAMet By EnE Dah _. .... _ Last TRg: RKB 14.348.0 616/201] Rev Reason'H26, TAG pploven 6/712017 NN4..ON 36.4 10 F a8mg nngS Casing Descripn[n oDpn) IDIin T[p lnKe) sel Depin VlKfi) sel ceple IND)... wuLen p... Grade iopmreTl - CONDUCTOR 16 15062 41.0 1210 1210 62.58 w40 AELOED Casing Desetiplion _'o, ID IinI Top(/tl(B) sel DePin IflKBI SeI DePIn INDI... Wlltm l... Glatle Top Tnsytl SURFACE 95/6 8835 40.9 4,928.0 2.938.) 40.00 L80 BTC I1l se Cafing pesnlpfion OD gn) Ip(in) r[p IXN6) SN DepIn IXK8 SN pePq INDIWGLen 11... Glatle TOp Tnrm] PRODUCTION > 6.2]6 38.7 147870 e137.6 2600 L-80 BTC -MOD Tubing Strings eONDwlOR: 41.o -12L Teb,,, Cex'hplinn stm9 ma... ID (n) rop lIn9) sN pePlh In- sel Depth G` L- W41euq Gmae Top ConnMmn TUBING WO -2014 31/2 2.992 364 14,212.5 5]690 9.30 L-60 I EUE 8R0 Completion Details NOmmal ID NIPPLE. oi Top IXKA Top TGG (than TOP ma(') I.. Des Com Iin) 36.4 36.4 0.06 HANGER FMC TUBING HANGER 2992 WEE 532.6 164 NIPPLE DS NIPPLE 2812 14,072.2 5.691 56.28 LOCATOR LOCATOR BUB 2.970 MarvMe43es, 5 14,0733 6,899.2 56.26 BEALASSY SEAN. ASSY. STICK-UP =7-%. SWALLOW =148-n 3.000 14,0795 5.702.7 56.10 PER BAKER POLISH BORE RECEPTACLE Seen 14.1026 5,715.7 55.54 PACKER BAKER FHL RETRIEVABLE PACKER 2,930 14,152.9 5,744.8 54.31 NIPPLE CAMCO DS NIPPLE 2812 14,2054 5..457 5308 OVERSHOT POOR BOT OVEftSHOT...SWALLOW=58X. 3620 SVFFgC E; 40849]60� tubi ng seriwing Ma ID,inj Top (IInB) sel 0ep[h (X. Sef Oepin (NO)(... WI(Ibnu Grade iop Lonnuclion TUBING Original 3t/2 2.992 1420>0 14,2646 5,6119 930 L80 ABM-EUE Completion Details NDminal DTop (XK9 Top Trip Incl (°) Item Des Com (in) .N.I.I:TE539 142250 5,]88.0 52.60 REAL AGSV BAKER KBB-22 ANCHOR SEAL ASSY 3.000 14226.] 5,7886 52.58 PACKERBAKER SAB -3 PERMANENT PACKER 3.250 142420 5797.9 52.22 NIPPLE CAMCO D LANDING NIPPLE NO GO 2.750 Memrzq D..74 142627 56106 51]3 WLEG WIRELINE ENTRY GUIDE. ELMD@ 14256ON SAS 2992 PERE 8/17/2001 Perforations & Slots snot III 12Lso Top(ND) elm(rv01 Dens I,he. T[ptrnej -MM) MKS) Thine) zone D. U Tyce Com 14,302.0 14.3170 5,835.1 5,&AA CA. 2A-22 6/28/2000 40 APERF 2 11 DR. 180 deg ph 14,330.0 143480 5.852.4 5,863.6 C4,2A-22 8/1702001 4.0 APERF 2.5"HSDAI1ema0tg Me.aet 14.oRp BKPJ.180 deg phase 14.352.0 14.3780 5.888.1 5.8823 A -3,2A-22 811211995 40 TP E -RF SM TCP Type BH UP; 180 deg ph', oriented SO GOWN ighside Stimulations & Treatments LOCAL01i rz2 R[ppam Aslgnen lips Pu wm 11 F[lmaron(is) Dam SEAL ASSY. 1<0]3] 12/9/2002 PER, 14,07pS Stimulations & Treatments SIg' "MIKE) 84n MILE) Vol Clean Pump DateSUMTrail Fluh bel) Vol $lum/Ipbg PPCFER: 14,1026 1 14.702.0 14,3]8.0 I 12/9/2002 Mandrel Inserts st NIPPLE . Is 112 ni onioPlrvOl N Top(KKB) IIMB) Melee Where lath Pensive TRO Run Maeel Op (Int Sery Type Type (In) (psi) Run Dah Com 1 3,341.5 2,503.2 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,3490 12/15/2014 2 7,553.9 3.707.5 CAMW KBMG 1 GASLIFT OV BK 0.188 0.0 12/1501014 OVFASNOT. 14..6.4 3 10.757.4 4,606.1 CAMCO KBMG 1 GAS LIFT TINY BK 0.000 0.0 102801014 EXTE INDEED PKG saN.AIKIY 14x56 4 12,955.0 5 251 8 CAMCO KBMG 1 GAS LIFT DMV BK5 0,000 00 91302014 PACKER;14326.7 5 140179 56690 CARGO KONG 1 GAS LIFT DMV BK5 9000 00 9/3012014 Notes: General & Safety End Dane Anml#mn &12008 NOTE: TU81W PUNCH BETI EEN SAB -3 PACKER A CA -2 PLUG IN TERING STUB, 9 SHOTS NIPPLE 14.x2 o W/ENTRANCE HOLE OF 0.19 111&2008 NOT Vier Schement,w/ Nature Schelr.tic90 11/5/2016 NOTE: 2.81'TAS N.P. 014152' WE MAY BE DAMAGED FROM PULLING PLUG ON 11 514 WLEG; 143627 APERF:143034143170 APERF: t4.3i].6143490 FEAC; 143020 IPERF, 1435E,III 378U PROMCDDN.WT 14,767.0 2A-22 Proposed CTD Schematic 16"62# H-40 shoe @ 121' MD 9-5/8" 40# L-80 shoe @ 4928' MD KOP @ 14,310' MD C/A -sand perfs 14,302' - 14,317' MD 14,3301- 14,348' MD 14,352' - 14,378' MD 7" 26# L-80 shoe @ 14,787' MD 3-1/2" DS Nipple (min ID 2.812") @ 532.6' MD 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camoo MMG gas lift mandrel @ 3342', 7554', 10,757', 12,955', and 14,018' Baker 3-1/2" PBR @ 14,080' MD (2.98" ID) Baker FHL packer @ 14,103' MD (2.93" ID) 3-1/2" Camco DS landing nipple @ 14,153' MD (2.812" min ID, No -Go) Poor Boy Overshot @ 14,205' Baker KBH-22 Anchor SA @ 14,226' MD Baker SAB -3 Packer @ 14,227 3-1/2" Camco D landing nipple @ 14,242' MD (2.75" min ID, No -Go) Needs to be milled out to 2.80" ID 3-1/2" WLEG @ 14,263' MD 2A-22AL1 wp02 TD @ 18,000' MD 2A -22A wp03 TD @ 18,000' MD Liner Billet M 15000'MD ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2A Pad 2A-22 2A-22AL1 Plan: 2A-22AL1_wp02 Standard Planning Report 02 August, 2017 BA UGHES a GE company ConocoPhillips BAILER ConocoPhillips Planning Report HUGHES a GEmmpaoy Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2A Pad Well: 2A-22 Wellborn: 2A-22AL7 Design: 2A-22AL1_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 2A-22 Mean Sea Level 2A-22 @ 135.00usft True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 2A Pad 2A-22 TVD Below Magnetics Site Position: Northing: 5,960,138.24 usft Latitude: 70° 18'8.367 N From: Map Easting: 498,621.00usft Longitude: 150° 0'40.211 W Position Uncertainty: 0.00 usft Slot Radius: O.000in Grid Convergence: -0.01 ° Well 2A-22 TVD Below Magnetics Model Name Sample Date Declination Well Position +N/ -S 0.00 usft Northing: 5,960,177.75 usft Latitude: 700 18' 8.756 N +N/ -S +PJ -W 0.00 usft Easting: 498,620.78 usft Longitude: 150° 0'40+217 W Position Uncertainty (°) 0.00 usft Wellhead Elevation: usft Ground Level: 94.30 usft Wellbore 2A-22ALl TVD Below Magnetics Model Name Sample Date Declination Dlp Angle Field Strength Turn Depth (nT) Azimuth BGGM2017 11,1/2017 +N/ -S 17.28 8087 57,475.24 Rate Design 2A-22AL1 wp02 TFO (usft) Audit Notes: (°) (usft) (usft) Version: Phase: PLAN Tie On Depth: 15,050.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 5,759.63 (usft) (usft) (usft) (°) 0.00 -94.30 000 0.00 300.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) (') (°) (usft) (usft) (usft) (-1100ft) (-1100ft) (°/100ft) (I 15,050.00 88.52 285.64 5,759.63 2,970.36 -12,485.15 0.00 0.00 0.00 0.00 15,150.00 94.58 282.13 5,756.92 2,994.34 -12,582.13 7.00 6.06 -3.50 330.00 15,300.00 86.69 274.98 5,755.00 3,016.62 -12,730.24 7.00 -5.13 -4.77 223.00 15,450.00 86.94 264.47 5,763.09 3,015.90 -12,879.81 7.00 0.03 -7.01 270.00 15,675.00 88.14 248.75 5,772.81 2,963.98 -13,097.79 7.00 0.53 -6.99 274.00 15,950.00 89.56 267.95 5,778.38 2,908.73 -13,365.81 7.00 0.52 6.98 86.00 16,175.00 87.14 283.52 5,784.89 2,931.12 -13,588.89 7.00 -1.07 6.92 99.00 16,375.00 87.23 269.50 5,794.76 2,953.72 -13,786.86 7.00 0.04 -7.01 270.00 16,675.00 88.13 290.50 5,807.05 3,005.52 -14,080.39 7.00 0.30 7.00 88.00 16,900.00 88.20 306.26 5,814.30 3,112.08 -14,277.62 7.00 0.03 7.00 90.00 17,150.00 86.78 288.80 5,625.34 3,227.09 -14,498.23 7.00 -0.57 -6.98 265.00 17,375.00 85.54 304.54 5,840.49 3,327.52 -14,698.21 7.00 -0.55 6.99 95.00 17,550.00 86.71 292.32 5,852.36 3,410.46 -14,851.46 7.00 0.66 -6.98 275.00 17,850.00 88.71 313.24 5,864.49 3,571.86 -15,102.06 7.00 0.67 6.97 85.00 18,000.00 88.73 302.73 5,867.84 3,664.03 -15,220.09 7.00 0.01 -7.00 270.00 Target 82/2017 12:19:21PM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips BA ER ConocoPhillips Planning Report BAT a GEmmpeny Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 2A-22 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2A-22 @ 135.00usft Site: Kupamk 2A Pad North Reference: True Well: 2A-22 Survey Calculation Method: Minimum Curvature Wellbore: 2A-22AL7 Design: 2A-22AL1_wp02 f Planned Survey - - -� _--- Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +141-S +El -W Section Rate Azimuth Northing Easting (usft) (°) V) (usft) (usft) (usit) (usft) (°1100ft) (°) (usft) (usft) 15,050.00 88.52 285.64 5,759.63 2,970.36 -12,485.15 12,297.63 0.00 000 5,963 150 10 486,13743 TIP/KOP 15,100.00 91.55 283.89 5,759.60 2,983.10 -12,533.49 12,345.87 7.00 -30.00 5,963,162.85 486,089.09 15,150.00 94.58 282.13 5,756.92 2,994.34 -12,582.13 12,393.61 7.00 -30.00 5,963,174.10 486,040.46 Start 7 dls 15,200.00 92.02 279.75 5,754.04 3,003.81 -12,631.13 12,440.78 7.00 -137.00 5,963,183.57 485,991.47 15,300.00 86.89 274.98 5,755.00 3,016.62 -12,730.24 12,533.02 7.00 -137.14 5,963,196.40 485,892.37 3 15,400.00 86.91 267.97 5,760.41 3,019.19 -12,830.00 12,620.70 7.00 -90.00 5,963,198.99 485,792.62 15,450.00 86.94 264.47 5,763.09 3,015.90 -12,879.81 12,662.19 7.00 -89.62 5,963,195.71 485,742.81 4 15,500.00 87.19 260.97 5,765.65 3,009.57 -12,929.33 12,701.92 7.00 -86.00 5,963,189.39 485,693.29 15,600.00 87.72 253.99 5,770.10 2,987.92 -13,026.80 12,775.50 7.00 -85.82 5,963,167.77 485,595.84 15,675.00 88.14 248.75 5,772.81 2,963.98 -13,097.79 12,825.01 7.00 -85.51 5,963,143.84 485,524.84 6 15,700.00 88.26 250.49 5,773.59 2,955.28 -13,121.22 12,840.95 7.00 86.00 5,963,135.15 485,501.42 15,800.00 88.77 257.48 5,776.19 2,927.73 -13,217.24 12,910.33 7.00 85.95 5,963,107.61 485,405.40 15,900.00 89.29 264.46 5,777.88 2,912.04 -13,315.93 12,987.95 7.00 85.76 5,963,091.94 485,306.72 15,950.00 89.56 267.95 5,778.38 2,908.73 -13,365.81 13,029.50 7.00 85.65 5,963,088.65 485,256.84 6 16,000.00 89.01 271 Al 5,779.00 2,908.45 -13,415.80 13,072.65 7.00 99.00 5,963,088.37 485,206.86 16,100.00 87.93 278.33 5,781.67 2,916.93 -13,515.34 13,163.09 7.00 98.96 5,963,096.87 485,107.33 16,175.00 87.14 283.52 5,784.89 2,931.12 -13,588.89 13,233.88 7.00 98.77 5,963,111.07 485,033.79 7 16,200.00 87.14 281.77 5,786.13 2,936.59 -13,613.25 13,257.71 7.00 -90.00 5,963,116.54 485,009.43 16,300.00 87.18 274.76 5,791.09 2,950.94 -13,712.03 13,350.43 7.00 -89.91 5,963,130.91 484,910.67 16,375.00 87.23 269.50 5,794.76 2,953.72 -13,786.86 13,416.63 7.00 -89.57 5,963,133.71 484,835.84 8 16,400.00 87.29 271.26 5,795.95 2,953.89 -13,811.83 13,438.34 7.00 88.00 5,963,133.88 484,810.88 16,500.00 87.56 278.26 5,800.45 2,962.17 -13,911.32 13,528.64 7.00 87.92 5,963,142.17 484,711.39 16,600.00 87.88 285.26 5,804.43 2,982.51 -14,009.09 13,623.48 7.00 87.60 5,963,162.54 464,613.64 16,675.00 88.13 290.50 5,807.05 3,005.52 -14,080.39 13,696.74 7.00 87.32 5,963,185.55 484,542.35 9 16,700.00 88.13 292.25 5,807.86 3,014.63 -14,103.66 13,721.44 7.00 90.00 5,963,194.66 484,519.08 16,800.00 88.15 299.26 5,811.11 3,058.03 -14,193.62 13,821.05 7.00 89.94 5,963,238.08 484,429.14 16,900.00 88.20 306.26 5,814.30 3,112.08 -14,277.62 13,920.82 7.00 89.72 5,963,292.14 484,345.16 10 17,000.00 87.60 299.28 5,817.97 3,166.14 -14,361.60 14,020.58 7.00 -95.00 5,963,346.21 484,261.20 17,100.00 87.04 292.30 5,822.64 3,209.57 -14,451.48 14,120.14 7.00 -94.74 5,963,389.65 484,171.33 17,150.00 86.78 288.80 5,825.34 3,227.09 -14,498.23 14,169.38 7.00 -94.42 5,963,407.18 484,124.60 11 17,200.00 86.48 292.29 5,828.27 3,244.61 -14,544.96 14,218.61 7.00 95.00 5,963,424.70 484,077.87 17,300.00 85.92 299.29 5,834.91 3,287.99 -14,634.74 14,318.05 7.00 94.79 5,963,468.10 483,988.11 17,375.00 85.54 304.54 5,840.49 3,327.52 -14,698.21 14,392.78 7.00 94.33 5,963,507.63 483,924.65 12 17,400.00 85.70 302.79 5,842.40 3,341.33 -14,718.95 14,417.65 7.00 -85.00 5,963,521.45 483,903.91 17,500.00 86.36 295.80 5,849.33 3,390.12 -14,805.90 14,517.34 7.00 -84.87 5,963,570.24 483,816.98 17,550.00 86.71 292.32 5,852.36 3,410.46 -14,851.46 14,566.98 7.00 -84.38 5,963,590.59 483,771.43 13 17,600.00 87.02 295.81 5,855.10 3,430.81 -14,897.04 14,616.62 7.00 85.00 5,963,610.95 483,725.85 17,700.00 87.67 302.78 5,859.74 3,479.66 -14,984.11 14,716.45 7.00 84.81 5,963,659.81 483,638.81 17,800.00 88.36 309.75 5,863.21 3,538.75 -15064.63 14,815.73 7.00 84.48 5,963,718.91 483,558.30 aWO17 12:19:21PM Page 3 COMPASS 5000.14 Build 65 ConocoPhillips BAICER ConocoPhillips Planning Report HUGHES aGEcompany Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 2A-22 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2A-22 @ 135.00usft Site: Kuparuk 2A Pad North Reference: True Well: 2A-22 Survey Calculation Method: Minimum Curvature Wellbore: 2A-22AL7 Design: 2A-22AL1_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting Inert) V) (v) inert) (usft) (usft) (usft) (°/10oft) (q (usft) (usft) 17,850.00 88.71 31324 5,86449 3,571.86 -15,102.06 14,864.70 7.00 84.24 5,963,752.02 483,520.88 14 17,900.00 88.71 309.74 5,865.61 3,604.97 -15,139.51 14,913.68 7.00 -90.00 5,963,785.14 483,483.45 18,000.00 88.73 302.73 5,867.84 3,664.03 -15,220.09 15,013.00 7.00 -89.92 5,963,844.20 483,402.88 Planned TO at 18000.00 &22017 12.19:21PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2A Pad Well: 2A-22 Wellbore: 2A-22AL1 Design: 2A-22AL1_wp02 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: BA_ ICER BAT a6Emmpany Well 2A-22 Mean Sea Level 2A-22 @ 135.00usft True Minimum Curvature Targets 70° 50,066 N 140° 57'57.895 W - plan misses target center by 1137602.39usft at 15050.00usft Target Name - Point -hitimiss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting -Shape V) V) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 2A-22AL7_T04 0.00 0.00 5,815.00 3,084.221,125,874.26 5,963,055.00 1,624,383.00 70' 4'54.731 N 140° 57'38.184 W - plan misses target center by 1138359.41 usft at 15050.00usft MD (5759.63 TVD, 2970.36 N. -12485.15 E) - Point - Point 2A-22ALi T03 0.00 0.00 5,795.00 2,918.291,126,350.34 5,962,889.00 1,624,859.00 7W 4'52.427 N 140° 57'25.330 W - plan misses target center by 1138835.48usft at 15050.00usft MD (5759.63 TVD, 2970.36 N, -12485.15 E) target center by 1137413.40usft at 15050.00usft MD (5759.63 TVD, 2970.36 N, -12485.15 E) - Paint - Point 2A-22AL1_T02 0.00 0.00 5,779.00 2,874.361,126,780.39 5,962,845.00 1,625,289.00 70" 4'51.375 N 140° 57' 13.267 W - plan misses target center by 1139265.54usft at I5050.00usft MD (5759.63 TVD, 2970.36 N, -12485.15 E) 1,623,960.00 70°4'57.318N - Point - plan misses target center by 1137936.37usft at 15050.00usft MD (5759.63 TVD, 2970.36 N, -12485.15 E) 2A-22 CTD Polygon 0.00 0.00 0.00 3,873.131,124,941.02 5,963,844.00 1,623,450.00 70° 5'3.751 N 140° 58'1.407 W - plan misses target center by 1137441.11usft at 15050.00ush MD (5759.63 TVD, 2970.36 N, -12485.15 E) Casing Points Polygon Point 0.00 0.00 0.00 5,963,844.00 1,623,450.00 Hole Point 0.00 215.91 -462.10 5,964,059.97 1,622,987.99 Diameter Diameter Point 0.00 -70.15 -594.04 5,963,773.97 1,622,856.01 (in) Point 0.00 -174.11 -378.00 5,963,669.98 1,623,072.01 Point 0.00 -334.04 47.93 5,963,510.00 1,623,402.01 COMPASS 5000.14 Build 85 Point 0.00 -713.94 550.22 5,963,130.03 1,624,000.03 Point 0.00 -1,040.82 1,204.36 5,962,803.06 1,624,654.05 Point 0.00 -1,120.68 1,858.45 5,962,723.09 1,625,308.06 Point 0.00 -1,089.63 2,048.46 5,962,754.10 1,625,498.06 Point 10 0.00 -1,011.55 2,366.47 5,962,832.12 1,625,816.05 Point 11 0.00 -1,033.48 2,638.51 5,962,810.14 1,626,088.06 Point 12 0.00 -1,135.39 3,078.57 5,962,708.16 1,626,528.05 Point 13 0.00 -1,218.34 3,352.62 5,962,625.17 1,626,802.06 Paint 14 0.00 -1,041.31 3,381.58 5,962,802.17 1,626,831.05 Point 15 0.00 -895.39 2,974.51 5,962,948.15 1,626,424.05 Point 16 0.00 -732.51 2,380.41 5,963,111.13 1,625,830.04 Point 17 0.00 -423.83 891.19 5,963,420.05 1,624,341.02 Point 18 0.00 -227.92 448.10 5,963,616.02 1,623,898.01 Point 19 0.00 0.00 1.00 5,963,844.00 1,623,451.00 Point 20 0.00 0.00 0.00 5,963,844.00 1,623,450.00 2A-22AL1_TO6 0.00 0.00 5,861.00 3,520.12 1,125,117.10 5,963,491.00 1,623,626.00 70° 50,066 N 140° 57'57.895 W - plan misses target center by 1137602.39usft at 15050.00usft MD (5759.63 TVD, 2970.36 N, -12485.15 E) - Point 2A-22AL1_T01 0.00 0.00 5,763.00 2,976.461,127,269.42 5,962,947.00 1,625,778.00 70° 4' 51.654 N 140" 56'5&90l W - plan misses target center by 1139754.56usft at 15050.00usft MD (5759.63 TVD, 2970.36 N. -12485.15 E) - Point 2A-22AL1_T07 0.00 0.00 5,868.00 3,624.101,124,928.06 5,963,595.00 1,623,437.00 70° 5' 1.351 N 140° 58'2.B38 W - plan misses target center by 1137413.40usft at 15050.00usft MD (5759.63 TVD, 2970.36 N, -12485.15 E) - Point 2A-22AL1 T05 0.00 0.00 5,841.00 3,287.161,125,451.18 5,963,258.00 1,623,960.00 70°4'57.318N 140°57'49.371 W - plan misses target center by 1137936.37usft at 15050.00usft MD (5759.63 TVD, 2970.36 N, -12485.15 E) - Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) L 18,000.00 5,867.84 23/8" 2.375 3.000 &/2/2017 12..19.21PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips BA_ ICER ConocoPhillips Planning Report HUGHES a GE cornpary Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kuparuk 2A Pad Well: 2A-22 Wellborn: 2A-22AL1 Design: 2A-22ALi_wp02 Plan Annotations Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Measured Vertical Local Coordinates Depth Depth «N/ -S -E/-W (usft) (usft) (usft) (usft) Comment 15,050.00 5,759.63 2,970.36 -12,485.15 TIP/KOP 15,150.00 5,756.92 2,994.34 -12,582.13 Start 7 dls 15,300.00 5,755.00 3,016.62 -12730.24 3 15,450.00 5,763.09 3,015.90 -12,879.81 4 15,675.00 5,772.81 2,963.98 -13,097.79 5 15,950.00 5,778.38 2,908.73 -13,365.81 6 16,175.00 5,784.89 2,931.12 -13,588.89 7 16,375.00 5,794.76 2,953.72 -13,786.86 8 16,675.00 5,807.05 3,005.52 -14,080.39 9 16,900.00 5,814.30 3,112.08 -14,277.62 10 17,150.00 5,825.34 3,227.09 -14,498.23 11 17,375.00 5,840.49 3,327.52 -14,698.21 12 17,550.00 5,852.36 3,410.46 -14,851.46 13 17,850.00 5,864.49 3,571.86 -15,102.06 14 18,000.00 5,867.84 3,664.03 -15,220.09 Planned TD at 18000.00 Well 2A-22 Mean Sea Level 2A-22 @ 135.00usft True Minimum Curvature 14/201712:19:21PM Page 6 COMPASS 5000.14 Build 65 ConocoPhillips Project:P Ku aruk River unit Site:�5, Kuparuk 2A Pad �ni4�ry nae xam �.a�.w a�an „�a u.a,.rv�rxe WELLBORE DETAILS: 2A-22AL1 aEFlEreErvcE WfoRM4710N Parent Wellbore: 2A -22A coaemertrVD) Refiace. wdlxwxz, irve rvonh Well: 2A-22 Wall. Wellbore; 2A•22ALi mwiauarn+.lsn !`JIrjV`p uvbgk: erv.ar Te on MD: 15050.00 tl vemm0vnl Refinance lean 0. 'MN, section ryal Relermee sql-lo.rox,9mq Plan: 2A-22AL1wp02(2A.2212A.22ALt) Easting r.ra:med oapmnwana: xry xx @tis amsn Longitude worm etrriami . , Calan n madod mnmwm Lamlua, Mean a BACHE 11 aGEwndon, 5950 "3500 WELL DETAILS: 2A-22 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 . , 5960177.75 498620.78 70e 18' 8.756 N 150° 0'40.217 W Sec MD Inc Azi TVDSS +N/ -S +E/ -W Dleg TFace VSect Annotation 1 15050.00 88.52 285.64 5759.63 2970.36-12485.15 0.00 0.00 12297.63 TIP/KOP 2 15150.00 94.58 282.13 5756.92 2994.34.12582.13 7.00 330.00 12393.61 Start? dls 315300.00 86.89 274.98 5755.00 3016.62-12730.24 7.00 223.00 12533.02 3 415450.00 86.94 264.47 5763.09 3015.90-12879.81 7.00 270.00 12662.19 4900 4 5 15675.00 88.14 248.75 5772.81 2963.98-13097.79 7.00 274.00 12825.01 5 6 15950.00 89.56 267.95 5778.38 2908.73-13365.81 7.00 86.00 13029.50 6 7 16175.00 87.14 283.52 5784.89 2931.12-13588.89 7.00 99.00 13233.88 7 816375.00 87.23 269.50 5794.76 2953.72-13786.86 7.00 270.00 13416.63 A 8 916675.00 88.13 290.50 5807.05 3005.52-14080.39 7.00 88.00 13696.74 9 1016900.00 88.20 306.26 5814.30 3112.08-14277.62 7.00 90.00 13920.82 10 1117150.00 86.78 288.80 5825.34 3227.09-14498.23 7.00 265.00 14169.38 11 12 17375.00 85.54 304.54 5640.49 3327.52.14698.21 7.00 95.00 14392.78 12 13 17550.00 86.71 292.32 5852.36 3410.46-14851.46 7.00 275.00 14566.98 i W e 13 1417850.00 88.71 313.24 5864.49 3571.86-15102.06 7.00 85.00 14864.70 00.. 14 15 18000.00 88.73 302.73 5867.84 3664.03-15220.09 7.00 270.00 15013.00 A-22 Planned TD at 18000.00 LI TI ACOP Mean a BACHE 11 aGEwndon, 5950 "3500 . , 5600 5100 5250 4900 5250 g 4550 2A-2 A-3 A > r " > 4200 > r G < < aso i W e PI in D act 00.. 5550 A-22 A-22 LI TI ACOP a ry 14 iStart 7 dls PnC 150es- 5700 12 II 2800 A-2 A-22 9 8 5 A 3 2450 2A-22 .A-22 5850 SA IBM AKII 3 4 5 2100 ._.._.. led M at 18 .( 1750 8 0 1 ., ....._... 6000 1400 11 3 A --Z2/ A-22 LI 6150 1050 MqA 2A- West( -)/East(+) (350 usftlin) 4950 . , 5100 5250 g 5400 G < < 5550 TI ACOP a ry Sun dls 5700 A-2 A-22 5850 3 4 5 led M at 18 .( 8 0 1 ., ....._... 6000 11 3 A --Z2/ A-22 LI 6150 MqA 2A- 2rzA- 2 6300 6450 ee L Vertical Section at 300.001 (150 usft/in) ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2A Pad 2A-22 2A-22AL1 2A-22AL1_wp02 Travelling Cylinder Report 02 August, 2017 BT�a GHES GE company ConocoPhillips Company: ConocoPhillips(Alaska) Inc.-Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 2A Pad Site Error: 0.00 usft Reference Well: 2A-22 Well Error: 0.00 usft Reference Wellbore 2A-22AL1 Reference Design: 2A-22AL1_wpO2 Baker HugheslNTEQ Travelling Cylinder Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 2A-22 2A-22 @ 135.00usft 2A-22 @ 135.00usft True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum BAT�UGHES A GE company Reference 2A-22AL1_wp02 Casing -ilter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 1 OD/1000 of reference To nterpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 15,050.00 to 18,00atDousft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,995.93 usft Error Surface: Pedal Curve Survey Tool Program Date 8/2/2017 Casing Hole From To Diameter Diameter (usft) (Draft) Survey (Wellbore) Tool Name Description 469.83 14,266.492A-22 MWD (2A-22) MWD MWD -Standard 14,266.49 15,050.00 2A-22A_wpO3(2A-22A) MWD MWD - Standard 15,050.00 18,000.00 2A-22AL1_wp02(2A-22AL1) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (Daft) (usft) Name Centre to No -Go 4,928.00 2,936.74 9 5/8" 9-5/8 12-1/4 18,000.00 6,002.84 2 3/8" 2-3/8 3 Summary Kuparuk 2A Pad- 2A -22 -2A -22A -2A -22A wp03 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Wanting Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 2A Pad Measured Vertical Meaeured Vertmal Reference 2A -22 -2A -22A -2A -22A Wp03 15,360.40 15,375.00 64.58 1.39 64.33 Pass - Minor 1/10 Kuparuk W.Sak Depth Depth Depth Desk W SAK 1B - W SAK 18 - W SAK 18 17,323.92 6,200.00 1,337.46 729.40 611.86 Pass - Major Risk Offset Design Kuparuk 2A Pad- 2A -22 -2A -22A -2A -22A wp03 orteet she Error: 000 osn survey Program: 470 MW0. 14266 -MWD Rule Assigned: Minor 1110 Mae wall Error. 000 on asked rce Offset semi Major Axle Measured Vertical Meaeured Vertmal Reference ONaN Tooll+ Offset Wellbore Cenha Casing- Contra to No Co Allowable warning Depth Depth Depth Desk Atlmuth +W -S ♦Fl -W Hole sue Centre Distance Deviation lust (usft) lush) luso) heft/ lush) (1) lean) (usft/ 1"1 (rare loan lust 15474.98 5,89495 15075.00 5.895.27 0.21 021 4463 297746 -12,509.11 2-11/15 056 081 -0.12 FAIL - Minor 1110 15.099.86 5,89460 15.100.00 5,89591 041 063 4371 2,985.29 -12532.84 2-41116 264 1.12 1.55 Pass -Minor 1110 15,124.53 5,89362 15,12500 589855 0.61 065 42.75 2,99385 12556.32 2-11/16 592 129 464 Pass - Minor 1110 15,140.90 5.892.01 15.150.00 5,897.17 0.81 0.86 4118 3,003.11 12579.53 2-11/16 1049 1.35 9.13 Pau - Minor 1/10 15.173.14 5,89031 15.17500 5,897.80 1.00 Los 3871 3,01308 12602.45 2-11/16 16.14 1.38 1483 Pass -Minor 1110 15,197.08 5,889.15 15,20000 5,898.41 120 1.30 34.02 3,02315 -12,625.05 2-11/16 MA7 1.39 21.64 Pass Minor//10 15.220.92 5,880.50 15,225.00 8899.02 1.39 1.52 29,65 3.034.42 -12,64765 2-11/16 2950 1.39 29.24 Pass-Minor//10 15,244.54 5.88838 15.250.00 5.099,64 1.50 1.74 25.09 3,044.39 -12.670.56 2-11/16 3598 1.39 3513 Pass-Mlnor1/10 15.251123 5.88012 15.275.00 5,900.25 118 1.97 22.38 3.05365 -12.69317 2-11/16 42.12 137 4187 Pass-Mlnorl/10 15,291.86 5.85853 15,300.00 5.900.86 1.97 2.19 10.99 seso21 .12,717,26 2-11/16 47.93 140 4750 Pass - Minor 1/10 15,31498 5.890.81 15,325.00 5.91 2.10 2.41 1544 3500.04 -12,74099 2-11/16 53.50 140 53.25 Pass - Minor 1110 15,33716 5.892.04 15,350.00 5,902.07 235 263 1212 3,077.14 -12,76495 2-11/16 5905 1,40 58.80 Pass - Minor 1110 15.36040 5,89327 15,375.00 5,90267 253 285 9.13 3,083.51 -12789.12 2-11/16 64.58 1.39 64.33 Pass - Minor 1/10, CC, ES, SF CC - Min Centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 8!2/2017 10:57.'218AM Page 2 COMPASS 5000.14 Build 85 Baker Hughes INTEQ BAKER ConocoPhillips Travelling Cylinder Report UGHES a GEcompany Company: ConowPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 2A Pad Site Error: 0.00 usft Reference Well: 2A-22 Well Error: 0 00 usft Reference Wellbore 2A-22AL7 Reference Design: 2A-22AL1 wp02 Local Co-ordinate Reference: ND Reference: MO Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well 2A-22 2A-22 @ 135.00usft 2A-22 @ 135.00usft True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum eference Depths are relative to 2A-22 @ 135.00usft Coordinates are relative to: 2A-22 Inset Depths are relative to Offset Datum Coordinate System is US State Plane 1927, Alaska Zone 4 '.entral Meridian is 150" 0'0.000 W Grid Convergence at Surface is: -0.01 CC -Min centre to center distance or cevergent point, SF -min separation factor, ES - min ellipse separation S/2/2017 1 Ladder Plot { 1 C a) rn T m1 U 0 v c 0 U 0 300D 2000 9000 12000 15ODD 18000 Measured Depth LEGEND CC -Min centre to center distance or cevergent point, SF -min separation factor, ES - min ellipse separation S/2/2017 1 { 0:57.'28AM Page 8 COMPASS 5000.14 Build 85 .- ConocoPhillips Project Kupamk River Unit WELL DETAILS: 2A-22 ANTI -COLLISION SETTINGS -NI-S +E/ COMPANY DETAILS'. Con.Philims (Alaska) Inc 4<up2 Site Well. 2A42 k 2A Pad 0.00 0.00 Interpolation Method, MD. interval: 25.00 150° 0 40217 W Calculation Method Minimum Curvature Wellbore.. 2A-22AL1 TFace VSecl Depth Range From: 15050.00 To 18000.00 88.62 285.64 5694.63 2970.36-12485.15 0.00 Methotl: Design. 2A-22AL1_wp02 94.58 282.13 5891.92 2994.34-12582.13 7.00 Results Limited By, Centre Distance: 1995.93 315300.00 Scan Tra, Cylinder North 223Z01 2533 02 415450.00 Reference: Plan: 2A-22AL7 _wp02 (2A-222A-22AL1) 270.0012662.19 Error toPedal Curve 88.14 248.75 5907.81 2963.98-13097.79 7.00 274.0012825.01 615950.00 89.56 267.95 5913.38 2908.73-13365.81 7.00 Wamin Method : Rules Based Azimuth from North [e] vs Centre to Centre Separation [20 usftlin] BAKER gUGHES z GE company WELL DETAILS: 2A-22 -NI-S +E/ -W Northing EaaMg Latittude Longitude 0.00 0.00 5960177]5 498620 78 70° 18' 8 756 N 150° 0 40217 W Sec MD Inc Azi TVD +N/ -S +E/ -W Dleg TFace VSecl 115050.00 88.62 285.64 5694.63 2970.36-12485.15 0.00 0.001229763 215150.00 94.58 282.13 5891.92 2994.34-12582.13 7.00 330.001239361 315300.00 86.89 274.98 5889.99 3016.62-12730.24 7.00 223Z01 2533 02 415450.00 86.94 264.47 5898.09 3015.9042879.81 7.00 270.0012662.19 515675.00 88.14 248.75 5907.81 2963.98-13097.79 7.00 274.0012825.01 615950.00 89.56 267.95 5913.38 2908.73-13365.81 7.00 86.0013029 50 716175.00 87.14 283.52 5919189 2931.12-13588.89 7.00 99.0013233.88 816375.00 8723 269.50 5929.76 2953.72 -13786.86 7.00 270 0013416.63 916675.00 88.13 290.50 5942.05 3005.52 44080.39 7.00 88.0013696.74 1016900.00 88.20 306.26 5949.30 3112.08 -142T7.62 7.00 90,0013920 82 1117150.00 86.78 288.80 5960.33 3227.09-14498.23 7.00 265.0014169.38 1217375.00 65.54 304.54 5975.49 3327.52-14696.21 7.00 95 0014392.78 1317550.00 86.71 292.32 5987.36 3410.46-14851.46 7.00 2750014566.98 1417850.00 88.71 313.24 5999.49 3571.86 -15102.06 7.00 65.0014864.70.. 1518000.00 88.73 302.73 6002.84 366403-15220.09 7.00 2700015013 SURVEY PROGRAM Date: 2017-08.02T00:00:00 Validated. Yes Version: Depth From Depth To Survey/Plan Tool 469.83 14266.49 2A-22 MWD (2A-22) MWD 14266.49 15050.00 2A -22A wp03 (2A -22A) MWD -' 15050.00 18000.00 2A-22AL7_wp02(2A-22AL1) MWD Color Ran es by Plan MD 2A -AL1 -22 _wp02 From MD Color To MD 15050 18000 TRANSMITTAL LETTER CHECKLIST WELL NAME: 7 kj�/(� `o — 011A G l PTD: 021 Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: 9446,uk, IPtV6tr POOL: Atw'r'. uk 91V r. Kk>Q'jux IJ'v51 Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. .9,17-115- , API No. 50-103- 9 o Z2, ! - 01 - 0 O. (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 onpermit). 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 pro Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 PTD#:2171160 Company CONOCOPHILLIPS ALASKA INC._ Initial Class/Type Well Name: KUPARUK RIV UNIT 2A-22AL1 -_ Program DEV Well bore seg J _DEV / PEND GeoArea 890 Unit 11160. _ On/Off Shore On __ Annular Disposal Administration 17 Nonconven. gas conforms to AS31.05.030Ij.1.A),(j.2.A-D) NA 1 Permit fee attached NA - - 2 Lease. number appropriate. Yes ADL0025570, Surf Loc; ADL0025571, Top Prod Intery & TD. 3 Unique well. name and number Yes KRU 2A-22AL1 4 Well located in a defined pool Yes KUPARUK RIVER,. KUPARUK RIV OIL. -490100, governed. by Conservation. Order No. 432D. 5 Well located proper distance from drilling unit. boundary Yes CO 432D contains no spacing restrictions with respect to drilling unit boundaries - 6 Well located proper distance from other wells Yes CO 432D has no interwell spacing restrictions. _ 7 Sufficient acreage available in drilling unit Yes _ 8 If deviated, is wellbore plat included Yes - 9 Operator only affected party Yes Wellbore will be. more than 500' from an external property line where ownership or landownership changes. 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 administrative. approval Yes PKB 8/8/2017 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 than 3 months (For. service well only) NA _ 18 Conductor string. provided NA _ Conductor set in KRU 2A-22 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in KRU 2A-22 20 CMT vol adequate to circulate. on conductor & surf csg NA. Surface casing set and fully cemented 21 CMT vol. adequate to tie-in long string to surf csg. NA. 22 CMT will cover all known productive horizons No Productive. interval will be completed with. 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 a 10-403 for abandonment been approved No 26 Adequate wellbore separation proposed. Yes Anti -collision analysis complete; no major risk failures 27 If diverter required, does it meet regulations NA 28 Drilling fluid program schematic & equip list. adequate Yes Max formation pressure is 3832 psig(12.45 ppg EMW); will use 8.6 ppf EMW and maintain overbal w/ MPD Appr Date VTL 8/18/2017 29 BOPEs,.do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 3245 psig; will test BOPs to 4000. psig 31 Choke manifold complies w/API RP -53 (May 84) Yes - 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S measures required 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Wells on 2A -Pad are H2S-bearing. H2S measures required. Geology 36 Data presented on potential overpressure zones _ Yes Max potential reservoir pressure is. 12.46.ppg EMW; will be drilled using 8.6 ppg mud and MPD technique. Appr Date 37 Seismic. analysis of shallow gas zones NA PKB 8/8/2017 38 Seabed condition survey (if off -shore) NA - 39 Contact name/phone for weekly progress reports [exploratory only] NA. Onshore development lateral to be drilled. Geologic Engineering Public Commissioner: Date: Commi one Date Commissioner Date P7S �)6�r7 Cly���
