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Home My WebLink About218-156Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700main (907)273-4760fax Delivered to: ri 6' AOGCC w ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision ♦ 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 2 r 156 TRANSMITTALDATF -- TRANSMITTAL N WELL NAME API 4 ORDERSERVICE U FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATELOGGED Prints CD's 1H-114 1H-111 11-1-105 1H-113 1H-116 3M-19 3G -07A 50.029-23584-00 50-029.23581-00 50-029.20727.01 50-029-23588-00 50-029-23594.00 50-029-21737.00 50-103.20127-01 EOSH-00071 EAI8-00022 E118.00075 E118-00076 E716-00077 E116.00078 E118-00079 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL WL WL IPROF [PROF-WFL IPROF-WFL IPROF-WFL IPROF-WFL Caliper PPROF FINAL FIELD FINAL FIELD FINAL FIELD19-Jul-19 FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 15 -Jul -19 17-Ju1-19 20 -Jul -19 21 -Jul -19 22 -Jul -19 23 -Jul -19 1 1 1 1 1 1 1 3G-11 50-103-20133-00 E118-00081 KUPARUK RIVER WL IPROF FINAL FIELD 25-Ju1-19 1 3M-13 1B-16AL1 1A-17 1C-121 3N -14A 3G-08 50-029-21720.00 50.029-22457-60 50-029.22102.00 50-029-23015-00 50-029.21589-01 50-103-20128-00 E118-00084 EDEA -00009 E118-00085 E118.00086 EOSH-00074 EOSH-00075 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL Memory WL WL WL WL Caliper PPROF LDL IPROF LDL,Caliper LDL,Caliper FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD LD LD 28 -Jul -19 28 -Jul -19 29Jul-19 1 -Aug -19 2 -Aug -19 3 -Aug -19 1 1 1 1 1 1 2N-317 50-103-20266-00 EOSH-00076 KUPARUK RIVER WL LDL MFINAL LD 4 -Aug -19 1 4.1 1nin 15 •" """` / ATransmittal Receipt signature confirms that package (box, a wi� envelope, etc.) has been received and the contents of the Ltu package have been verified to match the media noted above. 3me Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this return via courier or sign/scan and emar and CPAI. point. �TSPrintcenter slb.com Tom.Osterkam SLB Auditor- Tt..) Schlumberger -Private SCANNED AU6 0 7 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/29/2019 Permit to Drill 2181560 Well Name/No. KUPARUK RIV UNIT 1 B-16AL1 PBZ , Operator CONOCOPHILLIPS ALASKA, INC. MD 9693 TVD 6681 Completion Date 1/31/2019 Completion Status 1 -OIL Current Status 1 -OIL REQUIRED INFORMATION C Mud Log No ✓ Samples No V DATA INFORMATION 30418 Digital Data List of Logs Obtained: GR/Res C Well Log Information: ED Logi Electr 30418 Digital Data Data Digital Dataset Log Log Run Interval Type Med/Frmt Number Name Scale Media No Start Stop Log C 30405 Log Header Scans 0 0 ED C 30405 Digital Data C ED C 30405 Digital Data ED ED C 30405 Digital Data 30418 Digital Data ED C 30405 Digital Data ED C 30406 Digital Data ED C 30406 Digital Data ED C 30406 Digital Data ED C 30406 Digital Data Log C 30406 Log Header Scans 0 0 ED C 30418 Digital Data 6628 9693 ED C 30418 Digital Data ED C 30418 Digital Data ED C 30418 Digital Data ED C 30418 Digital Data ED C 30418 Digital Data ED C 30418 Digital Data ED C 30418 Digital Data ED C 30418 Digital Data OH/ CH Received API No. 50-029-22457-60-00 UIC No Directional Survey Yesz (from Master Well Data/Logs) 2181560 KUPARUK RIV UNIT 1B-16AL1 LOG HEADERS 2/26/2019 Electronic File: 1B-16AL1 EOW - NAD83.pdf 2/26/2019 Electronic File: 1B-16AL1 EOW - NAD83.txt 2/26/2019 Electronic File: IB-16AL1 EOW NAD27.pdf 2/26/2019 Electronic File: 1B-16AL1 EOW NAD27.txt 2/26/2019 Electronic File:1B-16AL1PBI EOW -NAD83.pdf 2/26/2019 Electronic File: 1B-16AL1 PBI EOW -NAD83.txt 2/26/2019 Electronic File: 1B-16AL1PB1 EOW NAD27.pdf 2/26/2019 Electronic File: IB-16AL1PB1 EOW NA027.txt 2181560 KUPARUK RIV UNIT 1B-16AL1 PB1 LOG HEADERS 2/28/2019 Electronic Data Set, Filename: 1B-16AL1 GAMMA RES.Ias 2/28/2019 Electronic File: 1B-16AL1 21VID Final Log.cgm 2/28/2019 Electronic File: 1B-16AL1 51VID Final Log.cgm 2/28/2019 Electronic File: 1B-16AL1 5TVDSS Final Log.cgm 2/28/2019 Electronic File: 1B-16AL1 2MD Final Log.pdf 2/28/2019 Electronic File: 1 B-16AL1 51VID Final Log.pdf 2/28/2019 Electronic File: 1B-16AL1 5TVDSS Final Log.pdf 2/28/2019 Electronic File: 1B-16AL1 I NAD27.pdf 2/28/2019 Electronic File: 18-16AL1 EOW NAD27.bd AOGCC Page 1 of 4 Monday, April 29, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/29/2019 Permit to Drill 2181560 Well Name/No. KUPARUK RIV UNIT 1B-16AL1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029.22457-60-00 MD 9693 TVD 6681 ED C 30418 Digital Data ED C 30418 Digital Data ED C 30418 Digital Data ED C 30418 Digital Data ED C 30418 Digital Data ED C 30418 Digital Data Completion Date 1/31/2019 Completion Status 1 -OIL ED C 30418 Digital Data ED C 30418 Digital Data ED C 30418 Digital Data ED C 30418 Digital Data Log C 30418 Log Header Scans Log C 30419 Log Header Scans ED C 30419 Digital Data ED C 30419 Digital Data ED C 30419 Digital Data ED C 30419 Digital Data ED C 30419 Digital Data ED C 30419 Digital Data ED C 30419 Digital Data ED C 30419 Digital Data ED C 30419 Digital Data ED C 30419 Digital Data AOGCC Page 2 of 4 0 0 0 0 6628 8886 Current Status 1 -OIL UfC No 2/28/2019 Electronic File: 16-1641-1 Final Surveys 9693.csv 2/28/2019 Electronic File: 1 B-16AL1 Final Surveys 9693.x1sx 2/28/2019 Electronic File: 1B-16AL1 Survey Listing.txt 2/28/2019 Electronic File: 1 B-16ALl Survey.txt 2/28/2019 Electronic File: 1B- 16AL1 _25_tapescan_BH I_CTK.txt 2/28/2019 Electronic File: 16- 16AL t _5_tapescan_BH I_CTK.txt 2/28/2019 Electronic File: 1B-16AL1_output.tap 2/28/2019 Electronic File: 1B-16AL1 2MD Final Log.tif 2/28/2019 Electronic File: 1B-16AL1 5MD Final Log.tif 2/28/2019 Electronic File: 1B-16AL1 5TVDSS Final Log.tif 2181560 KUPARUK RIV UNIT 1B-16AL1 LOG HEADERS 2181560 KUPARUK RIV UNIT 1B-16AL1 1`61 LOG HEADERS 2/28/2019 Electronic Data Set, Filename: 1B-16AL1PB1 GAMMA RES.Ias 2/28/2019 Electronic File: 16-16AL1PB1 2MD Final Log.cgm 2/28/2019 Electronic File: 1B-16AL1PB1 5MD Final Log.cgm 2/28/2019 Electronic File: 1B-16AL1PB1 5TVDSS Final Log.cgm 2/28/2019 Electronic File: 1B-16AL1PB1 2MD Final Log.pdf 2/28/2019 Electronic File: 1B-16AL1PB1 5MD Final Log.pdf 2/28/2019 Electronic File: 1B-16AL1PB1 5TVDSS Final Log.pdf 2/28/2019 Electronic File: 1B-16AL1PB1 EOW NAD27.pdf 2/28/2019 Electronic File: 1B-16AL1PB1 EOW NAD27.bct 2/28/2019 Electronic File: 1B-16AL1PB1 Final Surveys 8886 TD.csv Monday, April 29, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/29/2019 Permit to Drill 2181560 Well Name/No. KUPARUK RIV UNIT 1B-16AL1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-22457.60.00 MD 9693 TVD 6681 Completion Date 1/31/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 30419 Digital Data 2/28/2019 Electronic File: 1B-16AL1 PB1 Final Surveys 8886 TD.xlsx ED C 30419 Digital Data 2/28/2019 Electronic File: 1B-16AL1PB1 Survey Listing.txt ED C 30419 Digital Data 2/28/2019 Electronic File: 1B-16AL1PB1 Survey.txt ED C 30419 Digital Data 2/28/2019 Electronic File: 16- 16AL1 PB1_25_tapescan_BHI_CTK.txt ED C 30419 Digital Data 2/28/2019 Electronic File: 1B - 16A1 -1 PB1_5_tapescan_BH I_CTK.txt ED C 30419 Digital Data 2/28/2019 Electronic File: 1B-16AL1P81_output.tap ED C 30419 Digital Data 2/28/2019 Electronic File: 1B-16AL1PB1 2MD Final Log.lif ED C 30419 Digital Data 2/28/2019 Electronic File: 1B-16AL1PB1 5MD Final Log.tif ED C 30419 Digital Data 228/2019 Electronic File: 1B-16AL1P81 5TVDSS Final Log.tif Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report CY Directional / Inclination Data Gy Mud Logs, Image Files, Digital Data YNA Core Chips Y A Production Test InfonnatioNA Mechanical Integrity Test Informations YY /SNA Composite Logs, Image, Data Files YY Core Photographs Y / A Geologic Markers/Tops O Daily Operations Summary I Y ) Cuttings Samples Y /9 Laboratory Analyses Y NA COMPLIANCE HISTORY Completion Date: 1/31/2019 Release Date: 12/6/2018 Description Date Comments AOGCC Page 3 of 4 Monday, April 29, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/29/2019 Permit to Drill 2181560 Well Name/No. KUPARUK RIV UNIT 1B-16AL1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-22457-60-00 MD 9693 TVD 6681 Completion Date 1/31/2019 Completion Status 1-011- Comments: -OILComments: Compliance Reviewed By: _ Current Status 1-0I1 Date: UIC No AOGCC Page of Monday, April 29. 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑� Gas[] SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAc 25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: 1b. Well Class. Development 21 ° Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 1/31/2019 14. Permit to Drill Number / Sundry: 218-156 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 1/26/2019 15. API Number: 50-029-22457.60.00 4a. Location of Well (Governmental Section): Surface: 501' FNL, 244' FEL, Sec 9, T11N, R10E, UM Top of Productive Interval: 2866' FNL, 1011' FEL, Sec 4, T71 N, R10E, UM Total Depth: 1459' FNL, 432' FEL, Sec 4, T11N, R10E, UM 8. Date TO Reached: 1/29/2019 16. Well Name and Number: , KRU 1B-16AL1/1B-16AL1PB1 9. Ref Elevations: KB:102 GL:61 BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk River Oil Pool ° 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25648 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 550195 y- 5969647 Zone- 4 TPI: x- 549403 y- 5972557 Zone- 4 Total Depth: x- 549969 y- 5973967 Zone- 4 11. Total Depth MD/TVD: 9693/6681 19. DNR Approval Number: LONS 79-016 12. SSSV Depth MD[rVD: 189311825 20. Thickness of Permafrost MD/TVD: 1588/1544 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 8149/6659 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 SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 41 121 41 121 24 200 sx ASI 9.625 40 L-80 41 4424 41 4164 12.25 1000 sx ASIII Lead, 420 sx G Tail 7x5 26 L-80 39 7441 39 6982 8.5 350 sx Class G 23/8 4.6 L-80 6690 9069 6272 6652 3 24. Open to production or injection? Yes E] No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): /^� (,.(.r SLOTTED LINER @: ( / j b I ` `/;;k I 7098-9069 MD and 6649-6652 TVD ((( C PLETION DAT E 3( 2o(4( VEi2, IFIED/ 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDrrVD) 4x 3.5 6704 6666/6250 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑ Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 2/18/2019 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 2123/2019 Hours Tested: 14.4hrs Production for Test Period Oil -Bbl: 689 Gas -MCF: 7431 Water -Bbl: 160 Choke Size: 1 100 Gas -Oil Ratio: 1 1079 Flow Tubing Press. 152 lCasinq Press: 1 808 Calculated 24 -Hour Rate Oil -Bbl: 1128 Gas -MCF: 1 1216 Water -Bbl: 1 262 Oil Gravity - API (corr): 1 18.2 Form 10-407 Revised 5/2017 P'7 - 3�z / /9CONTINUED ON PAGE 2 RBDMS MAR 0 6 2019 Submit ORIGINAL only. 28. CORE DATA Conventional Corals): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored (MD/TVD, Fromlro), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Permafrost - Base 1588 1544 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 7205 6698 information, including reports, per 20 AAC 25.071. Formation @ TPI-Kuparuk A4 1B-16AL1PB1 8886 6648 TD 9693 6681 Formation at total depth: LAI I 31. List of Attachments: Daily Aerations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, oaleontoloalcal report, production or well test results. per 20 AAC 25,070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: V, 1 -j T)9 -e4— Contact Name: William Lon Authorized Title: — Sk0Fef&ftQII1UV1 e 'TJD Sal %Zt -V1X_ Contact Email: William.R.Lon co .com Authorized Contact Phone: 263-4372 Signature: _ Date: INSTKILICTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item tb: Well Class - Service wells: Gas Injection, Water Injection, Water -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 10-407 Revised 5/2017 Submit ORIGINAL Only IB -16 Final CTD 16" 62# H-40 shoe @ 121' MD 9-5/8" 40# L-80 shoe @ 4424' MD C -sand perfs Squeezed 6778'- 6838' M D 6900' - 6908' MD Rol R' - R09R' nen KOP @ 7046' MD 3-1/2" x 5" TTWS A -sand perfs 7124' - 7158' MD 7" x 5" shoe @ 7441' MD 7026' MD x 5" TTWS 3-1/2" Camco TRDP-4A Safety Valve @ 1893' MD Locked Out: 8/2/2017 4" 11#J-55 Tubing 4104' MD to surface Cross-over 4"x3.5" @ 4104' MD 3-1/2" Camco gas lift mandrels @ 2624', 4139', 5204', 5987', & 6620' MD Baker FB -1 packer @ 6666' MD (4.0" ID) Baker SBE @ 6670' MD 3-112" Camco D landing nipple @ 6688' MD (2.80" min ID, Milled Out) 3-1/2" Camco SOS @ 6700' MD 3-1/2" x 2-3/8" Northern Solutions Liner Top Paker @ 6682' MD 1 B-16AL1 PB1 TD @ 8886' MD Billet @ 8149' MD 1 B-16APB1 TD @ 7478' MD 1 B-16AL1 TD @ 969T MD Liner @ 9069' MD Top of Liner 6690' MD 1 B-1 6A TD @ 9243' MD Billet @ 7205' MD KUP PROD WELLNAME 1B -16A WELLBORE 1B-16 s. Well Attributr Max Angle 1 TD CO�IOCOP�'1)ll)p5 F,eIJNaTe We11�reAPWW1 W¢IlWmslatua ncll°I MOIa gclaMlflN81 Alaskajl , KUPARUKRIVER UNIT 500292245]00 PROD 363 2.230.41 ]4500 TRDP 120 181122016 ILasIWO'. 18-16, i2N 1se.:12 PM Last Tag Vveula Ysraec lrNN) Annotation DepM1RK0) End Dah WNIEoretas1 Ma09y ...................................................................._...........-_. _.... Last Tag- RKB(Tagged Fill in 5!r Casing, -16 6,9fi80 11100019 182emhaej Last Rev Reason HANGER; se 9� II Annatatpn EM Care wellEOre La51 Mnd Ry Rev Reason: Installed GLYS B Set Liner Top Packer 2/612019 18-16 2encaej II 1 Casing Strings Casing Ceacnptlon oClln) IC llnl Top ryxcal set xpin lone) ael Oepn lrv0l... WNten 11_.s Top Timaa CONDUCTOR 16 1506 41.0 121.0 1210 62.50 H-00 WELDED CUIng Dearn,rm .D6n) IC(In) Top61KB) SN DepM MM sM dean IrvC)...."" 11 an Tem4 Iron SURFACE 9518 8.83 40.8 4,424.1 4,164.5 40.00 L-80 BTC CONDUCTOR; at Pt210 Galnp Daearlplbn OD gn) IDJUU TopmKB) BH DONE IM(B) SN Depen INUJH.I. en lt.. Grade Tep TN,eW PRODUCTION 7 8.28 38.9 ],441.1 6,982.5 2800 L-80 BTC M00 7"x5" @ 6690' Tubing Strings Tubing Deec,iptmn latrine Ma... ID 1N rop lrcNB) set 0epin lR. set Depin lrv0)1.. WIDdnI Grade ropdor;;M..n TUBING 4"x35" 4 348 38.8 E. 6286.0 11.00 J-55 BTC MOD $AFETVVLV;1Mi1 Completion Details Top (rvDl TripNaminel GnsuFT. 261]5 Tap BU mKel b Hem On com Dan) 38.8 38.8 0.05 HANGER MCEVOY GEN IV HANGER 4000 1,893.1 1,625.3 2323 SAFETYVLV 7TM767ff9X7A FETYVALV 3312 (LOCKED OUT TROP 8-2-201]) 4,104.1 3,866.9 2193 %O REDUCING CROSSOVER 4 x 35, ID 2.992, a9.3, J-55, EUE8RDMOD 3500 GAB urr: usea 6,665.3 6,249.] 21.61 SEALASSY BAKER GBH -22 LOCAT R w710 SEAL ASSEMBLY 3.000 6,666.2 6,2504 21.61 PACKER BAKER FB -1 PERMENANT PACKER 4000 6,669.6 6,253.6 21.60 SBE SEAL BORE EOENSION 4.000 6,6876 6,2]04 21.58 NIPPLE CASCO D NIPPLE NO GO. (MILLED OUT TO A 2.80-) 2.800 suRFAGE;,osa.axl- 6,]036 6,2852 2156 SOS CAMCO PE 500 SHEAR OUT SUB 3.000 Gasun;s.2oas Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top(NC) Tap mI GAs uR; a,Se6g Top (Mdo (IMB) I r;" Das Com Run Mb ID (in) T) 6,882.0 8,285.1 21.58 LINER TOP 2.72" Northern SWUgons Liner lop packerwl l )81" R- 2/612019 1.781 PACKER Profile Ninon, (10' DAL) 7,0260 3SMS 19.2 WHIPSTOCK 6 D R GEN 2 DELTA WHIPSTOCK, 13. 111612019 .000 Gas LIFTI emee OAL, 2 RA TAGS AT 7032.3', 0 DEGREE HIGH SIDE ORIENTATION 7,0450 6,604.7 19.00 WHIPSTOCK 263"OD BAKER GEN 2, 13.0CAL, 9.Z5'TRAY,].35' 12132018 0.000 SE LMS.6eM.3 FROM TOW TO RA TAG, 330° ROHS ORIENTATION PADxER e,eel Perforations 8 SAHs sBE'.6M a.$ - a. G ne TO(Me) B (snotLR LINER MPPACNER; 8,8920 ToptflKB) aM (IIKB) IRnB) eorso ptl(B) Llnked IDne Dah ) Type Cam NIPPLE;6M7.a 6,1]8. ,54.4 ,410. - 110/1990 6.01PERF nerjel,9 Geg LINER ALI COMPLETION 3, 16-16 phasing 45 deg orient CTD;66M.ea.essog 69000 6, O8. 4 8. 647571=1B-1 1(/20011 6.0 APERT D deg random 6,910 .45.1 fiA -1, 1B-16 fi11012008 60 APERF eg random .04;e.Me7.1 4. 7,1580 6,679.6 67119 A-0,18-16 615119N 40 WERE H uns, deg phasing Mandrel Inserts at 0 IPEFNr8"& GMO-L n N ToBtKBI valve INcn Topg23 1249 Make MND OD (in) sery Type Pain) TRO Run Run Dah Cam 1 2,623.5 2,498.0 MERIA TMPD 1 GAS LIFT GLV BK2 LV 0.1 ,311 0.156 1,311.0 215I419 APERF 691806.9a6.0� 2 4,139.3 3,899.5 CAMCO KBUG 1 GAS LIFT GLV STRIP 0.188 1,3050 122811999 ship 0shin APERF; SROO-0 9:B.0� g neck 3 5203.5 4,8901 CASCO KBUG 1 GAS LIFT OV BK 02W 00 2132019 4 59869 56200 CAMCO KBUG 1 GAS LIFT DMY BK 0000 00 W411999 5 6.619.8 62073 CAMCO MMM 112 GAS LIFT DMV RK 0100 00 BN311999 Notes: General & Safety 'no"mnimmon 21272009 NOTE. EST.132' RATHOLE BELOW BOTTOM PERF POST FCO wHlvsrocK zce60 8192010 NOTE. View SCM1emalicwl AWaka Schemalic00 WHIPBTOCK 7.Or5.0 2/202019 NOTE. View Schematic wl Alaska SChemalk100 IPEQF: ].Ib6],IenO PRODUCTION rAm: as R -I nall Operations Summary (with Timelog Depths) IB -16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log $tart Depth Start Time End Time our (hr) Phase Op Cada AcBv'ity Cade Time P -T-% Operation (fIKB) End Deplh(XKB) 12/13/2018 12/13/2018 1.50 MIRU MOVE RURD P Break down TT hard-line, secure BOP, 0.0 0.0 21:00 22:30 continue RD checklist 12/13/2018 12/14/2018 1.50 MIRU MOVE RURD P Disconnect PUTZ lines, chain off reel, 0.0 0.0 22:30 00:00 move mats away from rig, complete RD check list, Peak trucks arrive on pad 12/1412018 12/14/2018 2.00 MIRU MOVE RURD P RU & move shop & half -way house to 0.0 0.0 00:00 02:00 1 1 2A -Pad 12/14/2018 12/1412018 3.00 MIRU MOVE RURD P Truck back on site, rig up to sows, pull 0.0 0.0 02:00 05:00 sub & pits off well 12/14/2018 12/14/2018 6.50 MIRU MOVE MOB P Move from 2T -Pad to 1 B -Pad 0.0 0.0 05:00 11:30 12/14/2018 12/14/2018 1.50 MIRU MOVE MOB P On 1B pad, Remove jeeps from units. 0.0 0.0 11:30 13:00 Check tree status, Rig up cellar herculite 12/14/2018 12/14/2018 1.50 MIRU MOVE MOB P Spot modules 0.0 0.0 13:00 14:30 12/14/2018 12/14/2018 3.00 MIRU MOVE RURD P Crew change, PJSM, Safe out 0.0 0.0 14:30 17:30 location, Build scaffolding in cellar, Start working rig up check lists 12/14/2018 12/14/2018 1.50 MIRU MOVE NUND P MU PUTZ, NU BOPE, continue RU 0.0 0.0 17:30 19:00 checklist '. Rig Accept 19:00 furs 12/14/2018 12/14/2018 2.50 MIRU MOVE RURD P Grease swab & tango valves, 0.0 0.0 19:00 21:30 harmmer up flanges, swap out riser, engergize koomy 12/14/2018 12/14/2018 2.10 MIRU MOVE RURD P Grease HCR's (change out bad 0.0 0.0 21:30 23:36 pump), complete RU checkisit 12114/2018 12/15/2018 0.40 MIRU WHDBOP DISP P Line up valves, begin fluid packing 0.0 0.0 23:36 00:00 lines 12/15/2018 12/15/2018 0.20 MIRU WHDBOP DISP P Complete fluid packing lines, displace 0.0 0.0 00:00 00:12 coil to freshwater 12/15/2018 12/152018 0.30 MIRU WHDBOP PRTS P Shell test, good 0.0 0.0 00:12 00:30 12/15/2018 12/15/2018 1.30 MIRU WHDBOP BOPE P Begin BOP test (witness waive by 0.0 0.0 00:30 01:48 Adam Earl of AOGCC), "Low 250 psi, high 3500 psi 12/15/2018 12/15/2018 1.00 MIRU WHDBOP BOPE T Difficulty holding low test #5 (Charlie 0.0 0.0 01:48 02:48 7), grease valve, good test 12/15/2018 12/15/2018 6.70 MIRU WHDBOP BOPE P Continue BOP test, install test joint, 0.0 0.0 02:48 09:30 continue test, No other failures. Test PVT & gas detectors - all good, 9 hour test 12/15/2018 12/15/2018 1.90 MIRU WHDBOP PRTS P Fluid pack CT and pressure test inner 0.0 0.0 09:30 11:24 reel valve. Unstab injector, PT TT line and PDL's 12/15/2018 12/15/2018 0.60 PROD1 WHPST CTOP P Change out upper quick connect and 0.0 0.0 11:24 12:00 1 1 1 retread E -line 12/15/2018 12/152018 1.50 PROD1 WHPST PULD P PJSM, M/U and deploy BHA#1 0.0 74.2 12:00 13:30 Window milling BHA with 2.81 mill, 2.8 string reamer, and .6° AKO motor 12/15/2018 12/15/2018 1.00 PROD1 WHPST PULD T Unable to accuate master valve, Call 74.2 74.2 13:30 14:30 out valve crew. Valve is pressure locked 12/15/2018 12/15/2018 0.80 PROW WHPST PULD P Master open. WHP=525, Continue 74.2 74.2 14:30 15:18 with deployment, Make up coil to BHA and surface test - Good. Stab on injector. Tag up and set counters 12/15/2018 12/1512018 1.60 PROD1 WHPST TRIP P RIH BHA#1 to mill window. On 74.2 6,655.0 15:18 16:54 1 1 11 seawater returns to Tiger tank Page 1122 Report Printed: 211412019 Operations Summary (with Timelog Depths) lab 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our (hr) Phew Op code Activity Code Time P -T -X Opem n (MB) End Depth (VB) 12/15/2018 12/15/2018 0.10 PROD1 WHPST DLOG P Log Kl for+1.5' correction 6,655.0 61684.0 16:54 17:00 12/15/2018 12/15/2018 1.20 PROD1 WHPST DISP P Continue RIH, flush well w/ seawater, 6,684.0 6,760.0 17:00 18:12 unable to establish returns, bull -head seawater to window (2 bpm, 200 psi WHP) 12/15/2018 12/15/2018 0.40 PROD1 WHPST DISP P Displace coil to DuoVis 6,760.0 6,760.0 18:12 18:36 12/15/2018 12/15/2018 2.30 PROD1 WHPST WAIT P Await building 50 bbl 150K LSRV pill, 6,760.0 6,760.0 18:36 20:54 coordinate trucks & fluids for possibility of no returns should pill not help Obtain SBHP while waiting on pill: MD = 6760', TVD sensor = 6296.9', BHP = 2717 psi, EMW = 8.3 ppg 12/15/2018 12/15/2018 2.00 PROD1 WHPST DISP P Bullhead 50 bbl 150K LSRV pill 6,760.0 6,760.0 20:54 22:54 followed by DuoVis down to parts (pushing away seawater), WHIP climbs from 150 psi to -850 psi at perfs, then begins to drop (100 bola away, 40 bbl squeezed into Paris) 12/15/2018 12/15/2018 0.60 PRODt WHPST TRIP P Pump attempting to get returns, 6,760.0 7,049.3 22:54 23:30 returns start @ 40%, quickly demininish to -21 %, decision made to close choke & mill window, PUW = 41 K, RIH, dry tag WS pinch point @ 7049.8', PUH, bring on pumps 12/15/2018 12/1612018 0.50 PROD1 WHPST WPST P Tag WS pumping @ 70493, FS = 550 7.049.3 7,050.0 23:30 00:00 psi @ 1.9 bpm,, CWT = 24.6K, WOB = 0.3K, BHP = 2866 psi, circ = 3567 psi 12/16/2018 12/16/2018 3.50 PROD1 WHPST WPST P Continue milling window, CWT = 7,050.0 7,052.8 00:00 03:30 21.4K, WOB = 1.8K, BHP = 2906 psi, circ = 3324 psi, closed choke, 1.87 bpm 12/16/2018 12/16/2018 1.50 PROW WHPST WPST P Continue milling window, CWT= 7,052.8 7,054.7 03:30 05:00 22.8K, WOB = 2K, BHP = 2933 psi, circ = 3272 psi Pre -load build BHA 12/16/2018 12/16/2018 2.60 PROD1 WHPST WPST P Milling window, WOB =2.5K, BHP= 7,054.7 7,057.3 05:00 07:36 2952 psi, circ = 3364 psi, WHIP = 12 psi TF=30R 12/16/2018 12/16/2018 2.00 PROD1 WHPST WPST P Called BOW @ 7056.3, Reamer out 7,057.3 7,071.0 07:36 09:36 @ 7057.3. Drill rathole. 1.9 BPM @ 3400 PSI FS, BHP=2993 12/16/2018 12/16/2018 2.00 PRODt WHPST REAM P TD Rathole, start reaming passes. As 7,071.0 7,071.0 09:36 11:36 drilled, 30L, 30R, and 180° out of as drilled tool face. Dry drift window - Good. 12/16/2018 12/16/2018 1.20 PROD1 WHPST TRIP P POOH, PUW=36K 7,071.0 74.0 11:36 12:48 12/16/2018 12/16/2018 1.00 PRODt WHPST PULD P At surface, Tag up and space out. 74.0 0.0 12:48 13:48 Flow check well. PJSM. Well dead. Static losses - 20 BPH. Lay down BHA#1. Mill and string reamer out @ 2.79 No Go 12/16/2018 12/16/2018 1.20 PROD1 DRILL PULD P PIU BHA #2, was pre loaded in PDL. 0.0 72.2 13:48 15:00 Make up to coil and surface test, Check pack offs 12/16/2018 12/16/2018 1.30 PROD1 DRILL TRIP P RIH BHA #2 72.2 6,650.0 1500 1618 Page 2/22 ReportPrinted: 211412019 - Operations Summary (with Timelog Depths) IB-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Depth Stan Time End Time our (hr) phase Op co Activity Cale Time P-T-X Operation M13) End Depth (eKB) 12/16/2018 12/16/2018 0.20 PROM DRILL DLOG P log K1 for+.5', PUW=36K, Close EDC 6,650.0 6,670.0 16:18 16:30 12/16/2018 12/16/2018 0.20 PROM DRILL TRIP P Continue in well. Clean pass through 6,670.0 7,071.0 16:30 16:42 window 12/16/2018 12/16/2018 1.40 PROM DRILL DRLG P 771', Drill, 1.9 BPM @ 3214 PSI FS, 7,071.0 7,160.0 16:42 18:06 BHP=2950, Choke shut, WHP=O, RIW=19.2K, DHWOB=1.5, Bleed IA down from 1070, crew change, PUW = 40K 12/16/2018 12/16/2018 1.20 PROM DRILL DRLG P Drilling, FS = 530 psi @ 1.9 bpm, 7,160.0 7,215.0 18:06 19:18 closed choke, CWT = 21 K, WOB = 1.4K, BHP = 3050 psi, circ = 3404 psi, WHP = 0 psi Difficulty achieving 45° DLS, reduce rate to 1.5 bpm & increase WOB per DO request, geo's confer w/town geology 12/16/2018 12/16/2018 0.30 PROD1 DRILL WAIT P Geo/DD wiper, allow geo's time to 7,215.0 7,215.0 19:18 19:36 discuss deeper build landing, PUW = 40K, decision made to continue drilling 12/16/2018 12116/2018 1.50 PROM DRILL DRLG P Drilling, CWT = 19K, WOB = 3.5K, 7,215.0 7,267.0 19:36 21:06 BHP = 3091 psi, WHP = 33 psi, circ = 2820 psi Continue at 1.5 bpm & increase WOB in attempt to achieve higher DLS, PUW = 38K 12/16/2018 12/17/2018 2.90 PROM DRILL DRLG P Drilling, FS = 550 psi @ 1.9 bpm, 7,267.0 7,378.0 21:06 00:00 CWT = 17.6K, WOB = 4K, BHP = 3134 psi, WHP = 62 psi, varialbe ROP (12 fph - 115 fph), PUW = 40K, begin pulling 46K & -3 WOB 12/17/2018 12/17/2018 0.30 PROD1 DRILL WPRT P Continue wiper to window, pull up past 7,378.0 6,640.0 00:00 00:18 1 1 1 perfs at 6788' 12/17/2018 12/17/2018 0.30 PROD1 DRILL DLOG P Log K1 for+1' correction, continue in- 6,640.0 7,090.0 00:18 00:36 hole, log RA @ 7053' TOWS = 7046', TOW = 7048', BOW = 7056, RA= 7053 12/17/2018 12/17/2018 0.20 PROD1 DRILL WPRT P Wiper in-hole, RIW = 20K, weight 7,090.0 7,378.0 00:36 00:48 bobbles at 7277'& 7355'(-1 K WOB) 12/17/2018 12/17/2018 1.40 PROD? DRILL DRLG P Drilling, FS = 568 psi @ 1.9 bpm, 7,378.0 7,470.0 00:48 02:12 CWT = 19.8K, WOB = 1.8K, BHP = 3229 psi, WHP = 120 psi, circ = 3602 psi, closed choke, drill to called EOB @ 7470 Work PDL's to avoid freeze-up 12/17/2018 12/17/2018 1.80 PROD1 DRILL TRIP P POOH, PUW = 40K, pull heavy 7,470.0 71.0 02:12 0400 through 7365', 7342'& 7242 (up to - 4K WOB), open EDC, tag up, flow check, have flow 12/17/2018 12/17/2018 0.90 PROD1 DRILL PULD P PUD BHA#2, pumping managed 71.0 0.0 04:00 04:54 pressure 12/17/2018 12/17/2018 2.00 PROD1 DRILL PULD P PD BHA#3 "A" Lateral Assembly 0.0 78.0 04:54 06:54 (NOV Agitator, 0.5" AKO motor, RB HYC A2 bit), slide in cart, check pack- offs, MU to coil, tag up 12/17/2018 12/17/2018 1.20 PROD1 DRILL TRIP P Trip in hole, BHA #3A lateral section, 78.0 6,655.0 06:54 08:06 1 1 Shallow test agitator 12/17/2018 12/17/2018 0.20 PROW DRILL DLOG P Log K1 tor +.5', PUW=37K 6,655.0 6,680.0 08:06 08:18 Page 3122 ReportPrinted: 2114/2019 Operations Summary (with Timelog Depths) } 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Titre our (hr) Phase op code Activity Code Time P -T -X Operation (ftKB) End Depth (flKe) 12/17/2018 12/17/2018 0.20 PRODi DRILL TRIP P Continue in well, Clean trip through 6,680.0 7,478.0 08:18 08:30 window. Clear to bottom @ 7478 12/17/2018 12/17/2018 0.50 PRODi DRILL TRIP T 7478 PUH. Tight spots with pack offs 7,478.0 6,608.0 08:30 09:00 and high negative weight on bit. Hole in poor condition. Get up to cased hole. Jet 5 1/2 tubing in preparation for Polyswell pill. 12/17/2018 12/17/2018 2.40 PRODi DRILL CIRC T Poly Swell material coming for 6,608.0 6,608.0 09:00 11:24 Deadhome. recip 5 112 tubing 12/17/2018 12/17/2018 2.00 PRODi DRILL CIRC T Stand by for polly swell 6,608.0 6,655.0 11:24 13:24 12/17/2018 12/1712018 0.10 PRODt DRILL DLOG T Log K1 for+3' correction 6,655.0 6,682.0 13:24 13:30 12/17/2018 12/17/2018 0.10 PRODt DRILL TRIP T Trip in hole 6,682.0 6,700.0 13:30 13:36 12/17/2018 12/17/2018 0.20 PROD1 DRILL CIRC T Line up to pump down back side for 6,700.0 6,700.0 13:36 13:48 baseline pressures for poly swell job, 1 BPM Pump=315 PSI, BHP=2928, 1.5 BPM Pump=475PSI, BHP=3001, WHP=420, 2 BPM Pump=600PSI, BHP=3083, 2.5 BPM, Pump=700PS1, BHP=3137, 3 BPM Pump=800PSI, BHP=3177, 12/17/2018 12/17/2018 1.30 PROM DRILL CIRC T PJSM to mix and pump poly swell 6,700.0 6,715.0 13:48 15:06 12/17/2018 12/17/2018 0.50 PROM DRILL CIRC T Pump 20 BBI poly swell pill down back 6,715.0 6,715.0 15:06 15:36 side, 3 BBI/Min, Pump Pressure 1100 PSI, WHP=25 PSI. 12/17/2018 12/17/2018 0.10 PROM DRILL TRIP T 6715 At 60 BBIs pumped down back 6,715.0 6,096.0 15:36 15:42 side Pull up hole out of pill, PUW=38K 12/17/2018 12/17/2018 1.00 PROD1 DRILL OTHR T 6096, out of pill. Wait for poly swell to 6,096.0 6,096.0 15:42 16:42 activate. 12/17/2018 12/17/2018 0.20 PROD1 DRILL CIRC T Start pumping down back side .5 6,096.0 6,096.0 16:42 16:54 BPM, WHP=23PSI, No change durin pumping, BHP=2745 12/17/2018 12/17/2018 0.80 PRODi DRILL OTHR T Shut down pump. No pressure build 6,096.0 6,096.0 16:54 1742 up, Batch up second 20 BBL pill of poly swell 12/17/2018 12/17/2018 0.40 PROD1 DRILL CIRC T Pump 20 BBI pill of poly swell down 6,096.0 6,714.0 17:42 1806 back side follow with duo vis RIH to below TT 12/17/2018 12/17/2018 2.40 PRODi DRILL OTHR T At 6714. Wait on poly swell to activate, 6,714.0 6,714.0 18:06 20:30 1 1 12 Him 12/17/2018 12/17/2018 1.00 PROM DRILL CIRC T Online with pump down back side .5 6,714.0 6,714.0 20:30 21:30 BPM, BHP=2830, Climbed slowly to 3210 12/17/2018 12/17/2018 0.60 PROM DRILL TRIP T Trip in hole, Start prepping 3rd Poly 6,714.0 6,094.0 21:30 22:06 pill, 30 BBIs 12/1712018 12/17/2018 0.50 PROM DRILL CIRC T Pump 30 BBI poly pill down back side 6,094.0 6,094.0 22:06 22:36 at 2 BPM under displace pill 30 Pill and 20 BBIs duo vis. 2 BPM BHP=3210 12/17/2018 12/18/2018 1.40 PROD1 DRILL WAIT T Pill spatted, PUH out of pill to 4000', 6,094.0 4,000.0 22:36 00:00 1 1 1 lWait 2 hours for swelling action 12/18/2018 12/18/2018 1.20 PROD1 DRILL WAIT T Continue to allow poly swell pill swell 4,000.0 4,000.0 00:00 01:12 1 time, estimate 35 bbl at perfs Page 4/22 Report Printed: 2/14120191 Operations Summary (with Timelog Depths) f I-• = 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth start Time End Time our(hr) Phase Op Code Aatnty Cada Time P -T -X Operation (WB) End Depth(ftKB) 12/18/2018 12/1812018 0.70 PROM DRILL DISP T Pump 0.5 bpm down back -side, bit 4,000.0 4,000.0 01:12 01:54 depth = 4000', (attempting to achieve 1500 psi over stabalized annular pressure of 2750 psi) Annular quickly rises to 2600 psi, 2 bbl away, annular = 2750 psi 5 bbl away, annular = 3000 psi 10 bbl away, annular = 3217 psi 15 bbl away, annular = 3387 psi 17.5 bbl away, annular = 3412 psi (up to 13.7 ppg, and began to flatten) Shutdown pumps, pressure drops to -2600 psi relatively quickly, then began to slow 12/18/2018 12118/2018 1.10 PROM DRILL WAIT T Confer wl town on plan forward 4,000.0 4,000.0 01:54 03:00 12/18/2018 12118/2018 3.20 PROM DRILL DISP T Decision made to pump away 4,000.0 4,000.0 03:00 06:12 remaining 8.5 bbl Poly Swell, maintaining 11.4 ppg at window (2650 psi annular @ bit depth of 4000') Began pumping, annular quickly jumps to 3200 psi, allow to drop to 2650 psi, shut down pumps, continue pumping small ammounts and shutting down pump to maintain 11.4 ppg. (-1100 psi WHIP), swap to managed pressure in attempt to reduce annular fluctuations, rate in began to increase quickly from nominal to hold 11.4 ppg to .45 bpm, difficulty holding 11.4 ppg at window Begin prepping for 4th Poly Swell pill should it be required (30 bbl) 12/18/2018 12/18/2018 1.00 PROD1 DRILL DISP T Begin circulating down coil, unable to 4,000.0 6,715.0 06:12 07:12 hold 11.4 ppg at window, confer w/ town, decision made to build & pump 4th Poly Swell pill (30 bbl) 12/1812018 12/18/2018 0.60 PROD1 DRILL DISP T 50 bbl bullhead away 30 bbl Poly 6,715.0 3,826.0 07:12 07:48 Swell follow by 20 bbl DuoVis, reduce rate & PUH to 3826' pumping pipe displacement, PUW = 38K, (-26 bbl Poly Swell above parts in cased hole) 12/18/2018 12/1812018 2.00 PROD1 DRILL WAIT T Wait on swell time, pumps off (9.0 ppg 3,819.0 3,819.0 07:48 09:48 1 1 1 at window) 12/18/2018 12/18/2018 0.70 PROD1 DRILL DISP T Squeeze 22 bbl away attempting to 3,819.0 3,819.0 09:48 10:30 hold 12.4 ppg at window, begin pumping at 1.8 bpm to build to 11.76 ppg ppg, 10 bbl away, reduce rate to .5 bpm attempting to build to 12.4 ppg, unable to achieve 12.4 ppg, drop to 10.4 ppg 12/18/2018 12/1812018 2.00 PRODi DRILL WAIT T Confer w/ town, MI formulating plan 3,819.0 78.0 10:30 12:30 forward w/ FORM-A-BLOK pill (recipe & volume requirements), perform lab tests w/ product on rig, PUH, tag up in prep for pumping 12/18/2018 12/18/2018 2.20 PRODi DRILL WAIT T Await super sucker to clear pits, super 78.0 78.0 12:30 14:42 sucker arrives on site Coordinate w/ facilites for 3C-08 pre - rig work, begin RDMO paperwork should that become plan forward Page 5122 Report Printed: 211412019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth StartTime End Time our (hr) Phase Op Code Activity Cafe Time P -T -X Opeamon (%KB) End Depth mKB) 12/18/2018 12/18/2018 1.00 PROD1 DRILL CLEN T Suck out pits, wash down & clean of 78.0 78.0 14:42 15:42 all polymer 12/18/2018 12/18/2018 2.80 PROD1 DRILL CIRC T Build 10 bbl KCI spacers & 23 bbl 78.0 78.0 15:42 18:30 FORM-A-BLOK pill (40 ppb product) 12/18/2018 12/18/2018 0.80 PROD1 DRILL CIRC T PJSM, Pump 5 bbl KCL spacer, @ 3 78.0 78.0 18:30 19:18 bpm, Pump 20 bbis Form-A-Blok from 3-0.25 bpm, lots of issues pumping, lost C pump pressure, Triplex jacking off, pum - 1.0 bbl duovis, unable to initially catch prirme with KCL, swap to KCL once pump lined up, Pump 5 bbis KCL @ 3 bpm, Swap to duovis displacement, chase LCM to perfs @ 3 bpm, CT 650 psi, WH 612 psi, 12/18/2018 12/18/2018 0.30 PROD1 DRILL CIRC T At 77 bbis total treatment away, with 78.0 78.0 19:18 19:36 Form-A-Blok at the parts reduce rate to 0.5 bpm, pump 10 bbls of Form-A- Blok to the formation, CT 195 psi, WH fell from 596 psi to 165 psi @ 5 bbis away, then climbed slowly to 179 psi at 10 bbis away 12/18/2018 12/18/2018 3.70 PROD1 DRILL CIRC T SID for 30 min, On line, - 1 bbl away 78.0 78.0 19:36 23:18 to fit hole / catch pressure. Squeeze away 1.8 bbis ( total away 89.8 bbis) well head climbed to 137 psi then broke over, SID for 30 min, WH fell to 0 psi Catch pressure with 1 bbl away, squeeze 1 bbl, WH climbed to 140 psi. SID for 30 min. WH fell to 0 psi Catch pressure imeditly, squeeze 1 bbl away, WH climbed to 183 psi. SID for 30 min. WH fell to 3 psi Catch pressure imeditly, squeeze 1 bbl away, WH climbed to 218 psi. S/D for 30 min. WH fell to 33 psi Catch pressure imeditly, squeeze 1 bbl away, WH climbed to 245 psi. SID for 30 min. WH fell to 50 psi Catch pressure imeditly, squeeze 1 bbl away, WH climbed to 290 psi. SID for 30 min. WH fell to 83 psi 12/18/2018 12/19/2018 0.70 PROD? DRILL CIRC T Move pipe, RIH 100 feet, POOH, 78.0 96.8 23:18 00:00 bump up, space out PJSM, Start batching 50 bbis of Pro V, 40 bbis water, 3 sacks viscosifyer, and Pro V plus LCM pill 12/19/2018 12/19/2018 3.00 PRODt DRILL CIRC T Complete building 52 bbis pill of Pro 96.8 96.8 00:00 03:00 V+ LCM pill, (92 Ib/bbl). 12/19/2018 12119/2018 2.10 PROD1 DRILL CIRC T Lead in with duovis - mud, establish 96.8 96.8 03:00 05:06 injection 1 bpm WH 350 psi, swap to Pro V, pump 9.8 bbls, lock up Pump #1, troubleshoot issues. Swap to pump #2, get 7.6 bbls away lost pump #2. Pull apart pump # 1, LCM packing off and floating the valves. Tear down and clean Pump#1. *`ProV = 9.32 ppg Page 6122 Report Printed: 2/14/2019 Operations Summary (with Timelog Depths) 1 B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depm Start Time End rime Dur (hr) Phew Op Code Activit' Code Time P -T -X Operation (WB) End Depth (RKB) 12/19/2018 12/19/2018 0.80 PROD1 DRILL CIRC T Back on line, estimate 17.4 bbls of 96.8 96.8 05:06 05:54 plug on the backside, meter indicated - 33 bbls on restat due to clearing lines. Ignoring fallout lead of plug at parts with 92.6 bbls away end of plug is 110 bbls away. Displace at 2 bpm, WH 610 pi. WH broke trend @ 76 bbls, cut rate to 1 bpm @ 81 bbs away. WH increased to 720 psi then broke back, reduced rate to 0.5 bpm. WH climbed and started to break over. Shut down trapping 555 psi on the WH 12/19/2018 12/19/2018 1.30 PROD1 DRILL CIRC T Wait on dehydration 96.8 96.8 05:54 07:12 12/19/2018 12/19/2018 0.70 PROD? DRILL CIRC T Discussed w/ Procor rep, decision 96.8 78.0 07:12 07:54 made to squeeze away all 5.75 bbl & attempt again w/ more volume (ie the remaining 45 bbl in pits), Squeeze away bbl 11.4 bbl, WHP climbs to 785 psi, WHP w/ pumps off drops to 69 psi Shut 2-3/8" rams to isolate EDC, trap 105 psi WHP to ensure rams & checks are holding, pump down MP line, DPS is below rams (so will see did, though is not affecting EDC) 12/19/2018 12/19/2018 1.20 PROD1 DRILL CIRC T PJSM, discuss w/ Procor rep method 78.0 78.0 07:54 09:06 of getting LCM in-hole given earlier packed off pump issue, decision made to pump remaing -45 bbl of Pro V, 5 bbl Pro V followed by -2 bb DuoVis (both in-hole), chase 60 bbl "pill' w/ DuoVis 72 bbl away, Pro V @ parts (Note: 132 bbl total pumped will be tail of Pro V pill through the parts) 12/19/2018 12/19/2018 0.30 PROD1 DRILL CIRC T Squeeze away 20 bbl @ 1 bpm (92 78.0 78.0 09:06 09:24 total pumped), WHP climbs to 850 psi 12/19/2018 12/19/2018 1.00 PROD1 DRILL CIRC T Wait, WHP drops to 79 psi @ 1 hr 78.0 78.0 09:24 10:24 12/19/2018 12/19/2018 0.20 PROD1 DRILL CIRC T Squeeze 12 bbl, WHP = 875 psi, 78.0 78.0 10:24 10:36 103.75 bbl total pumped, 28.25 bbl pill remains 12/19/2018 12/19/2018 0.50 PROD1 DRILL CIRC T Wait, WHP drops lot 97 psi 78.0 78.0 10:36 11:06 12/19/2018 12/19/2018 1.50 PROM DRILL CIRC T Pump at.1-.2 bpm until WHP =600 78.0 78.0 11:06 12:36 psi, wait 20 min, WHP drops to 210 psi, (pumped 110 bbl total, 22 bbl remain) 12/19/2018 12/19/2018 0.70 PROM DRILL CIRC T Pump at .1-.2 bpm until WHP = 650 78.0 78.0 12:36 13:18 psi, wait 20 min, WHP drops to 221 psi,(pumped 113.7 bbl total, 19 bbl remain) 12/19/2018 12/19/2018 0.80 PROD1 DRILL CIRC T Pump at -.3 bpm until WHP begins to 78.0 78.0 13:18 14:06 plateaus @ 888 psi, WHP quickly w/ pumps off, (pumped 125.8 bbl total, 6.2 bbl remain) 12/19/2018 12/19/2018 0.50 PROD1 DRILL CIRC T Pump remaining 6.2 bbl at .5 bpm, 78.0 78.0 14:06 14:36 WHP climbs to 962 psi, with tail out perfs WHP drops to 856 psi, then climbs to 990 psi (142 bbl total pumped) Page 7/22 Report Printed: 2114/2019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code AC iry Code Time P -T -X Operation (NCB) End Depth (NCB) 12/19/2018 12/19/2018 1.10 PROD1 DRILL CIRC T Line up down coil, RIH to 2000', 78.0 78.0 14:36 15:42 pumping 1.3 bpm, At 2000' " 1.8 bpm, 1 -for -1 returns at holding 9.7 ppg at window .. 1.8 bpm, 11.2 ppg, 72% returns, WHIP = 818 psi 12/19/2018 12/19/2018 1.00 PROD1 DRILL TRIP T Continue RIH, pumping .75 bpm, 78.0 6,620.0 15:42 16:42 holding 11.2 ppg 12/19/2018 12/19/2018 0.40 PROD1 DRILL DLOG T Difficulty finding K1, PUH to 6620'& re 6,620.0 6,676.0 16:42 17:06 -log, PUW = 34K 12/19/2018 12/19/2018 2.00 PROD1 DRILL CIRC T Continue in-hole, slow through tubing- 6,676.0 6,676.0 17:06 19:06 tail & down to TOWS Make two down passes jeting max rale @ 20 ft/min from 6723' to 7035'. 12/19/2018 12/19/2018 1.50 PRODi DRILL TRIP T POOH 6,676.0 83.0 19:06 20:36 12/19/2018 12/19/2018 1.20 PROD1 DRILL PULD T PJSM, atempt to bleed WH and lay 83.0 0.0 20:36 21:48 down over a dead well, presure built to 8 psi. PUD BHA#3. 12/19/2018 12/19/2018 0.50 DEMOB WHDBOP PULD P Pick up a nozzle, stab back on. 0.0 0.0 21:48 2218 12/19/2018 12/20/2018 1.70 DEMOB WHDBOP DISP P Bullhead 220 bbls seawater 1.9 BPM, 0.0 0.0 22:18 00:00 CT 4047 psi, WH 774 psi. LR on location, PJSM, confirm customer valve clear with air, RU, PT to 4 k psi, good. 12/20/2018 12/20/2018 0.20 DEMOB WHDBOP DISP P Complete bullheading 180 bbls 0.0 0.0 00:00 00:12 seawater 1.9 BPM, CT 4047 psi, WH 774 psi. LR on location, PJSM, confirm customer valve clear with air, RU, PT to 4 k psi, good. 12/20/2018 12/20/2018 1.00 DEMOB WHDBOP DISP P LRS, Bullhead 30 bbls diesel FP 1.0 0.0 0.0 00:12 01:12 BPM, CT 1400 psi, WH 454 psi. "' S/I well with 490 psi on the tubing 12/20/2018 12/20/2018 1.00 DEMOB WHDBOP CIRC P Pop off, install jet nozzle, stab back 0.0 0.0 01:12 02:12 on, Jet slack. 12/20/2018 12/20/2018 1.00 DEMOB WHDBOP CTOP P Pop off, install night cap flush lines, 0.0 0.0 02:12 03:12 blow down. 12/20/2018 12/20/2018 1.00 DEMOB WHDBOP CTOP P Pop off, vac stack, Bore O scope BOP 0.0 0.0 03:12 04:12 stack. 12/20/2018 12/20/2018 4.80 DEMOB WHDBOP RURD P Work ng down checklist, NO BOP 0.0 0.0 04:12 09:00 **Rig Released: 12/20/18 @ 09:00 his 1/19/2019 1/19/2019 3.00 MIRU MOVE RURD P Continu to work RD checklist. 0.0 0.0 00:00 03:00 1/19/2019 1/19/2019 1.00 MIRU MOVE RURD P Peak truck( trackor I trailer for shops) 0.0 0.0 03:00 04:00 broke down in middle of acces pad road just off pad. Crew towing truck to pad so sows can access the rig. PJSM 1/19/2019 1/19/2019 2.00 MIRU MOVE RURD Pull pits & sub off well, pull flow -block, 0.0 0.0 04:00 06:00 gate valve, & adapter flange from tree, Gear pad, perform environmental walk -around 1/19/2019 1/19/2019 2.50 MIRU MOVE RURD P Jeep up, load shop & pull shop mats 0.0 0.0 06:00 08:30 Page 8122 ReportPrinted: 2114/2019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stall Time End Tlme our (hr) Phase Op code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth(IKS) 1/19/2019 1/19/2019 4.50 MIRU MOVE MOB P Move from 3H pad to 1B pad 0.0 0.0 08:30 13:00 1/19/2019 1/19/2019 6.00 MIRU WHDBOP RURD P "' Rig Accept 20:00 0.0 0.0 13:00 19:00 adjust scaffold, and stack riser. Capture RKBs. Grease valves, complet RU check list, flood up 1/19/2019 1/19/2019 2.70 MIRU MOVE MOB P Arrive at 1B -Pad, de -jeep, lay 0.0 0.0 19:00 21:42 herculite, spot sub & pits, lay mats Note: 38 minutes to place mats for sub & pits 1/19/2019 1/20/2019 2.30 MIRU WHDBOP RURD P Begin RU checklist, get COMMS on- 0.0 0.0 21:42 00:00 line, lower stairs & landings, MU PUTZ, bring on steam, began building scaffolding around tree, unlock reel & injector. Shop and 1/2 way house spotted at entrance to the pad. Make up managed pressure line, stab BOP stack. Spot tiger tank, d in same. 1/20/2019 1/20/2019 4.20 MIRU WHDBOP BOPE P "'BOP test start 0:00 0.0 0.0 00:00 04:12 Shell test, 250 low, 3500 psi high good test. AOGCC witness waived by Austin McLeod R1 leaking, replace R1 Got test 5 Test against Rt, with upper swab shut, open a the night cap, fluid apears to be going through the master, dump SSV, same, call valve crew. Contiune to trouble shoot, close lower blinds, held, not going through master, swab2 is leaking, fluid a the nigh cap. 1/20/2019 1/20/2019 2.80 MIRU WHDBOP BOPE P Valve crew sevice swab 2 Nabors 0.0 0.0 04:12 07:00 crew regreased stack valves, continue w/ BOP test 1/20/2019 1/20/2019 1.80 MIRU WHDBOP BOPE T Difficulty w/ high on test 8, trouble- 0.0 0.0 07:00 08:48 shoot, change out test pump bleeder valve, re-teset, continue trouble- shooting, eliminate choke maniford, track to Romeo2, grease R2, test, good 1/20/2019 1/20/2019 0.90 MIRU WHDBOP BOPE T Continue w/ BOP test, difficulty 0.0 0.0 08:48 09:42 holding low on test 9, re -grease Romeo 3, test, pass 1/20/2019 1/20/2019 2.30 MIRU WHDBOP BOPE P Continue w/ BOP test, install test 0.0 0.0 09:42 12:00 joint, draw down test, LD test jnl, test complete 1/20/2019 1/20/2019 1.00 MIRU WHDBOP CIRC P Slide in cart, slab on, line up to 0.0 0.0 12:00 13:00 seawater, pump slack forward (1.5X coil volume @ 2 bpm) 1/20/2019 1/20/2019 1.00 MIRU WHDBOP PRTS P Reverse circulate, test inner reel 0.0 0.0 13:00 14:00 valve. PT tiger -tank line to 2500 psi & blow down 1/20/2019 1/20/2019 0.80 MIRU WHDBOP PRTS P Pop off injector, break off nozzle, 0.0 0.0 14:00 14:48 install pressure plate, PT CTC to 4000 psi, install UQC checks, PT PDL's 1/20/2019 1/20/2019 1.70 SLOT WELLPR OTHR P Valve crew opens grease locked 0.0 0.0 14:48 16:30 master valve (quite difficult to open), pressure up above SSV (588 psi), open SSV, no change in pressure 1/20/2019 1/20/2019 1.40 PROD1 WHPST PULD P PD BHA #4 Window Milling Assembly 0.0 74.0 16:30 17:54 (0.6° AKO motor, 2.79" string reamer, 8 2.80" DSM) Page 9/22 Report Printed: 211412019 Operations Summary (with Timelog Depths) gibe 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth start Time End Tim. Our (hr) Phase Op Code Activity Cade Time P-T.X Operation (W) End Depth (WB) 1/20/2019 1/20/2019 3.30 PROD! WHPST PULD T Test MWD - Short! 0.0 74.0 17:54 21.12 Unstab, break off, test meg 0. Cut lead off & troubleshoot. 9.1 Mega ohm from office to whip, 8.7 Mega Ohm from whip to office. Test surface lines from office to coil - good. Call out electrician, found some water in collector, pulled anchor, cut wire back same issue, cut back coil on whip end -5' same issue. 1/20/2019 1/20/2019 1.80 PROD1 WHPST PULD T Organize new string (# 52795) to be 0.0 74.0 21:12 23:00 loaded and staged @ peak yard for morning move. SLB N2 crews hour'd out will mobilize from deadhorse to rig @ 04:00 Install anchor and rehead CTC, pull test 35 k lbs, good. PT CTC and inner reel iron to 2,500 psi - good. Skid cart back 1/20/2019 1/21/2019 1.00 PROD1 WHPST PULD T Grab lunch, PUD BHA #4, LD tools. 0.0 74.0 23:00 00:00 1/21/2019 1/21/2019 1.50 PROD1 WHPST PULD T Continue to PUD &ILD BHA #4. 0.0 0.0 00:00 01:30 Struggle with frozen tugger line. 1/21/2019 1/21/2019 1.50 PROD1 WHPST CTOP T Skid cart, torque up nozzle, stab 0.0 0.0 01:30 03:00 injector, RIH, POOH to change coil position on reel in preparation to unstab. S/I master with 1000 psi trapped below. 1/21/2019 1/21/2019 4.00 PROD1 WHPST CTOP T Prep for reel blow down and unslabing 0.0 0.0 03:00 07:00 coil while waiting on N2. 1/21/2019 1/21/2019 2.20 PROD1 WHPST CTOP T SLB arrives at rig, PJSM, PT customer 0.0 0.0 07:00 09:12 line to 3500 psi, lock -out reel & MU pressure bulk -head, pump 15,000 SCF N2 (100° F), bleed down coil 1/21/2019 1/21/2019 2.30 PROD1 WHPST CTOP T Unlock reel, pop off, disassemble 0.0 0.0 09:12 11:30 inner -reel iron, install grapple 1/21/2019 1/21/2019 2.00 PROD1 WHPST CTOP T PJSM, Pull test grapple/CTC to 900 0.0 0.0 11:30 13:30 psi, check grapple connection, unstab coil & secure 1/21/2019 1/21/2019 1.00 PROD1 WHPST CTOP T PJSM, lower whip end of pipe w/ 0.0 0.0 13:30 14:30 tugger from goose -neck to rig floor, prep to cut coil at reel end 1/21/2019 1/21/2019 1.70 PROD1 WHPST CTOP T Cut pipe on rig floor, prep reel for 0.0 0.0 14:30 16:12 removal, remove saddle clamps, reel n slings 1/21/2019 1/21/2019 1.30 PRODi WHPST CTOP T Reel arrives on pad, PJSM, pick reel 0.0 0.0 16:12 17:30 from rig, pick & set new reel (# 52795) 1/21/2019 1/21/2019 1.00 PROD1 WHPST CTOP T Safety Stand -down meeting w/ all 0.0 0.0 17:30 18:30 personnel on rig, followed by pre tour for night crew 1/21/2019 1/21/2019 2.50 PROD1 WHPST CTOP T Complete cutting coil & clear pipe from 0.0 0.0 18:30 21:00 rig floor, clear snow from new reel & heat w/ steam, connect TT soft line to rig, begin changing out brass 1/21/2019 1/21/2019 1.50 PROD1 WHPST CTOP T Reel set down in saddle, begin MU 0.0 0.0 21:00 22:30 saddle clamps, re -assemble injector, test wire in reel - Good. 1/21/2019 1/22/2019 1.50 PROD1 WHPST CTOP T String grapple line, MU grapple, prep 0.0 0.0 22:30 0000 1 to stab pipe 1/22/2019 1/22/2019 2.80 PROD1 WHPST CTOP T PJSM, Pull test grapple to 900 psi - 27 0.0 0.6- 00:00 0248 k lbs - good. Pull pipe past horses head, lock out reel, clamp coil in head, unlock reel, stab pipe into gripper blocks. Page 10122 Report Printed: 2/14/2019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log star Depth etam Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (MS) End Depth rBKa) 1/22/2019 1/22/2019 3.20 PROM WHPST CTOP T Skid cart forward, cut pipe install CTC, 0.0 0.0 02:48 06:00 install inner reel iron. 1/22/2019 1/22/2019 4.00 PROM WHPST CTOP T complete inner rell iron, install 0.0 0.0 06:00 10:00 pressure bulkhead 1/22/2019 1/22/2019 0.40 PROD1 WHPST CTOP T Electrical test 68.8 Ohms >2kM 0.0 0.0 10:00 10.24 Ohms, polarity good, Unlock reel LRS on location, PJSM, RU, PT 1/22/2019 1/22/2019 1.10 PROM WHPST CTOP T Pull test to 35 k lbs, MU upper Quick - 0.0 0.0 10:24 11:30 no flaots, Test UQC, 66.2 ohms >2 K M Ohms, make up nozzle, skid cart and stab on 1/22/2019 1/22/2019 2.00 PROD1 WHPST CTOP T Line up to LRS, Pump 5 bbls neat 0.0 0.0 11:30 13:30 MetOH. Check pack offs, Line up to seawater, fluid pack the reel. Find leak in 90' , inner reel iron, SID and lock out rig. Hammer up iron, unlock reel, Circ MethOH to the tiger tank. 1/22/2019 1/22/2019 2.50 PROD? WHPST CTOP T Leak manifest its self again, locked 0.0 0.0 13:30 16:00 out reel, hammered up double wing under HP bulkhead. Pumped slack forward @ 2.2 bpm & 4256 psi. Drip healed as fluid warmed up. Pressure test & chat inner reel valve to 4400 psi - god. PT CTC to 4200 psi good. Test upper quick, install checks, 1/22/2019 1/22/2019 1.30 PROD1 WHPST PULD T PD BHA #5, miling asembly PT tiger 0.0 85.0 16:00 17:18 tank line. test tool - good 1/22/2019 1/22/2019 0.20 PROD1 WHPST PULD P Continue to PD BHA#5 0.0 85.0 17:18 17:30 1/22/2019 1/22/2019 1.35 PROD1 WHPST TRIP P RIH, with window milling BHA #5 85.0 6,625.0 17:30 18:51 1/22/2019 1/22/2019 0.60 PROD1 WHPST DLOG P Logging K1 marker, missed it, PBUH 6,625.0 6,684.3 18:51 19:27 to start logging higher, start logging 6,625', correction of plus 25.5'. PUW 34 k 1/22/2019 1/22/2019 0.25 PROD1 WHPST TRIP P Continue RIH, flushing welll with SW 6,684.3 6,792.0 19:27 19:42 1/22/2019 1/22/2019 1.00 PROD1 WHPST CIRC P Set down 10 k Top of pert section, 6,792.0 6,699.0 19:42 20:42 PUW 41 k, continue circulating SW flush from well, swap to milling fluid 1/22/2019 1/22/2019 0.75 PROW WHPST TRIP P Inspect and torque up Hub Bolts, suck 6,699.0 6,699.0 20:42 21:27 out tiger lank 1/22/2019 1/22/2019 2.00 PROD1 WHPST TRIP P Continue IH, mill past pert intervals, 6,699.0 6,750.0 21:27 23:27 6,790', 6,810', 6,810', and 6,904' with HS TF. PUW's 36-38 k, PUH to above initial set down to 6,750', RBIH 1/22/2019 1/22/2019 0.25 PROD1 WHPST TRIP P Dry tag TOWS @ 7,029', PUH obtain 6,750.0 7,029.0 23:27 23:42 pumping parameters 1/22/2019 1/23/2019 0.31 PRODi WHPST WPST P OB milling window @ 7,029', 1.9 bpm 7,029.0 7,029.3 23:42 00:00 at 4,430 psi, Diff=460 psi, WHP=592, BHP= -0,016, IA=618, OA=2 1/23/2019 1/23/2019 4.50 PROM WHPST WPST P OB milling window exit, 1.87 bpm at 7,029.3 7,033.2 00:00 04:30 4,423 psi, Diff=450 psi, WHP=610, BHP=4,033, IA=630, OA=1 1/23/2019 1/23/2019 4.00 PROM WHPST WPST P OB milling window exit, 1.87 bpm at 7,033.2 7,037.2 04:30 08:30 4,423 psi, Diff -450 psi, WHP=610, BHP= 4,033, IA=630, OA=1 1/23/2019 1/23/2019 2.20 PROD1 WHPST WPST P Drillig ahead, CT Wt 17 k lbs, Ct 4440 7,037.2 7,051.0 08:30 10:42 1 1 I I psi @ 1.88 bpm in 1.88 bpm out, WOB 1.84 6.5 fl/hr. Page 11/22 ReportPrinted: 2/14/2019 Operations Summary (with Timelog Depths) "r IB -16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log seen Depth Stan Tme End Time Our (hr) Phase Op Code AcYlviry Code Time P -T -X Operation (RKB) End Depth(RKB) 1/23/2019 1/23/2019 1.60 PRODt WHPST REAM P TD rat hole @ 7051' PU 38 klbs, 7,051.0 7,051.0 10:42 12:18 perform reaming passes, HIS, 30 L 30 R and LS. Dry drift clean. Tag bottom, pump 5 x 5 TD sweep, 1/23/2019 1/23/2019 0.50 PRODi WHPST CIRC P PUH slowly waiting for sweeps to exit. 7,051.0 6,977.0 12:18 12:48 1/23/2019 1/23/2019 1.60 PROD1 WHPST TRIP P Open EDC, POOH 6,977.0 79.0 12:48 14:24 1/23/2019 1/23/2019 1.00 PROD1 WHPST PULD P PUD BHA#5 bot mil and string remer 79.0 0.0 14:24 15:24 came out 2.79" NG 1/23/2019 1/23/2019 1.40 PROD1 DRILL PULD P PD BHA #6, PT tiger tank line, re- 0.0 72.0 15:24 16:48 torque the upper Quick, Check pack offs - good 1/23/2019 1/23/2019 1.40 PROD1 DRILL TRIP P RIH 72.0 6,635.0 16:48 18:12 1/23/2019 1/23/2019 0.20 PROD1 DRILL DLOG P Logged the K1 marker correction of 6,635.0 6,639.0 18:12 18:24 plus 6.0', close EDC, PUW 34 k 1/23/2019 1/23/2019 0.20 PROD1 DRILL TRIP P RIH 6,639.0 7,051.0 18:24 18:36 1/23/2019 1/23/2019 0.25 PRODt DRILL DRLG P OBD, 1.87 bpm at 4,274 psi, Diff=606, 7,051.0 7,065.0 18:36 18:51 WHP=570, BHP=4,114, IA=810, OA=2 1/23/2019 1/23/2019 0.15 PROD1 DRILL DRLG P Stall, PUW 36 k, pumping 1.86 bpm at 7,065.0 7,078.0 18:51 19:00 4,300 psi, Diff --606, WHP=570, BHP=4,114, IA=810, OA=2 1/23/2019 1/23/2019 1.00 PRODi DRILL DRLG P Stall, PUW 35 k, pumping 1.88 bpm at 7,078.0 7,135.0 19:00 20:00 4,365 psi, Diff -693, WHP=601, BHP=4,142, IA=814, OA=2 1/23/2019 1/23/2019 2.30 PRODt DRILL DRLG P Stacking weight, PUH, PUW 45 k, 7,135.0 7,363.0 20:00 22:18 1.88 bpm at 4,432 psi, Diff --684, WHP=601, BHP=4,142, IA=814, OA=2 1/23/2019 1/23/2019 0.20 PROD? DRILL WPRT P 100' wiper up hole, PUW 42 k 7,363.0 7,363.0 22:18 22:30 1/23/2019 1/24/2019 1.50 PROD1 DRILL DRLG P Set down 7,354' work to bottom, drill 7,363.0 7,439.0 22:30 00:00 ahead 1.82 bpm at 4,296 psi, Diff=687, WHP=601, BHP=4,142, IA=814, OA=2 1/24/2019 1/24/2019 0.25 PROD1 DRILL DRLG P OBD, 1.82 bpm at 4,296 psi, Diff=687, 7,439.0 7,480.0 00:00 00:15 WHP=601, BHP=4,142, IA=814, OA=2 1/24/2019 1/24/2019 0.50 PROD1 DRILL WPRT P TD Build section, (avg digs 38.9°), 7,480.0 7,025.0 00:15 00:45 PUW 38 k, chase sweep up hole, RBIH to confirm hole is clean. Pull up hole to window. 1/24/2019 1/24/2019 0.25 PROD1 DRILL WPRT P Perform jog back in hole to above WS 7,025.0 7,004.0 00:45 01:00 w/sweep, open EDC 1/24/2019 1/24/2019 1.35 PRODi DRILL TRIP P POOH to surface chasing 10x10 7,004.0 72.2 01:00 02:21 1 1 1 sweep 1/24/2019 1/24/2019 1.20 PRODi DRILL PULD P At surface, space out, PUD build 72.2 0.0 02:21 03:33 assembly 1/24/2019 1/24/2019 1.20 PROD1 DRILL PULD P PD lateral drilling assembly 0.0 72.0 03:33 04:45 1/24/2019 1/24/2019 1.50 PROD1 DRILL TRIP P RIH, close EDC, Shallow lest agitator, 72.0 6,640.0 04:45 06:15 1156 Delta p @ 1.88 bpm. Continue to RIH 1/24/2019 1/24/2019 0.10 PROD1 DRILL DLOG P Tie int the K1 for a +4' correction 6,640.0 6,674.0 06:15 06:21 1/24/2019 1/24/2019 0.10 PRODi DRILL TRIP PPU Wt 36 k lbs, continue to RIH 6,674.0 7,050.0 06:21 06:27 1/24/2019 1/24/2019 0.20 PHoul DRILL TRIP P Log the RA tag 7033.3" 7,050.0 7,080.0 06:27 06:39 i I Page 12/22 ReportPrinted: 2114/2019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stan Time EMTme Dur(hr) Phase Op Code Activity Code 7me P -T -X Operation (ftKB) End Depth(We) 1/24/2019 1/24/2019 0.20 PROD? DRILL TRIP P Continue to RIH 7,080.0 7,480.0 06:39 06:51 1/24/2019 1/24/2019 2.80 PROD1 DRILL DRLG P On bottom drilling, New mud at the bit 7,480.0 7,830.0 06:51 09:39 7480'. Once new mud all the wy aroud picked up to reaquire numbers, PU 36 k lbs. RBIH CT 4765 psi at 1.90 bm in, 1.90 bpm out, Delta P 1011 psi, Annular 4125 psi, WH 500 psi, IA 409 psi, OA 5 psi. CT Wt 16 k lbs, WOB 1-2 k lbs, ROP 100-200 ft/ hr, losses started at 7536', healed quickly to loosing 0.1 bpm. 7829' PU 35 k lbs ROP 125 ft/hr 1/24/2019 1/24/2019 0.30 PROD1 DRILL WPRT P PU 40 K lbs, short wiper -400'to end 7,830.0 7,830.0 09:39 09:57 of build, RBIH Swap from pump #2 to Pump #1 - packing leak 1/24/2019 1/24/2019 3.80 PROD1 DRILL DRLG P Ct 4803 psi @ 1.88 bpm in and 1.80 7,830.0 8,311.0 09:57 13:45 bpm out, delta P 1007 psi, BHP 4164 11.8 EMW, WH 588 psi, 11.9 CT Wt, 2+ k bs WOB. 8057' PU 35 k lbs 8198' PU 38 k lbs ROP = 126 ft1hr 1/24/2019 1/24/2019 0.30 PRODi DRILL WPRT P PU 38 k Ibs, short wiper- 300'to 8,311.0 8,311.0 13:45 14:03 8032', RBIH 1/24/2019 1/24/2019 1.60 PROD1 DRILL DRLG P Ct 4877 psi @ 1.89 bpm in and 1.73 8,311.0 8,527.0 14:03 15:39 bpm out, delta P 1004 psi, BHP 4185 psi 11.8 EMW, WH 540 psi, 9.7 CT Wt, 1.8 k bs WOB. Start snubbing -8450' 8481' Pu 37 k lbs ROP = 135 f 1hr 1/24/2019 1/24/2019 0.50 PROD1 DRILL WPRT P PU 38 k lbs, Long wiper for tie in 8,527.0 7,649.0 15:39 16:09 1/24/2019 1/24/2019 0.10 PROD1 DRILL DLOG P Tie into the RA tag for +1' correction 7,649.0 7,086.0 16:09 16:15 1/24/2019 1/24/2019 0.20 PROM DRILL WPRT P RBIH from wiper trip 7,086.0 8,527.0 16:15 16:27 •** Note, had to reduce rate to get past 8470' 1/24/2019 1/24/2019 1.55 PROM DRILL DRLG P Ct4893 psi @ 1.91 bpm in and 1.81 8,527.0 8,612.0 16:27 18:00 bpm out, delta P 1037 psi, BHP 4217 psi 11.8 EMW, WH 573 psi, 1.7 CT Wt, 1.9 k bs WOB. 1/24/2019 1/24/2019 2.00 PROM DRILL DRLG P OBD, 1.82 bpm at 4,296 psi, Diff=687, 8,612.0 8,768.0 18:00 20:00 WHP=601, BHP=4,142, IA=814, OA=2 1/24/2019 1/24/2019 0.50 PROM DRILL WPRT P Short wiper up hole, PUW 42 k, hard 8,768.0 7,904.0 20:00 20:30 time working back to bottom 8,470', continue wiper up hole to 7,904' 1/24/2019 1/24/2019 0.70 PROD1 DRILL WPRT P 800', Wiper back in hole, lowering 7,904.0 8,768.0 20:30 21:12 pump rate to 1.3 bpm 1/24/2019 1/25/2019 2.80 PROD1 DRILL DRLG P BOBD, 1.9 bpm at 5,050 psi, 8,768.0 8,904.0 21:12 00:00 Diff=1,143 psi, WHP=595, IA=754, OA=8 1/25/2019 1/25/2019 2.00 PROD1 DRILL DRLG P OBD, 1.9 bpm at 5,202 psi, Difr=1,147 8,904.0 9,015.0 00:00 02:00 I I I psi, WHP=572, BHP=4,249, IA=887, OA=12 Page 13122 Report Printed: 211412019, Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth sten rime End Time Our (hr) Phase Op code A vity Code Time P-T-X Operation W11) End DepN(ftKB) 1/25/2019 1/2512019 1.00 PROD1 DRILL DRLG P OBD, 1.91 bpm at 5,142 psi, 9,015.0 9,055.0 02:00 03:00 Diff-1,030 psi, WHP=553, BHP=4,249, IA=917, OA=13, Zero Coil Weight, 1.5 k=DHWOB, ROP 20- 74 fph 1125/2019 1/25/2019 0.20 PROD1 DRILL DRLG P OBD, 1.91 bpm at 5,142 psi, 9,055.0 9,058.0 03:00 03:12 Diff--1,030 psi, WHP=553, BHP=4,249, IA=917, 0A=1 3, Minus 5.0 k=CTSW, 1.3 k=DHWOB, ROP=30 fph 1/25/2019 112512019 0.30 PROD1 DRILL WPRT P Wiper up hole, PUW 38 k, pulled 9,058.0 8,059.0 03:12 03:30 heavy from 8,436'-8,411', work pipe up hole, PUW's 40-62 k 1/2512019 1/2512019 1.35 PROD1 DRILL WPRT P Wiper back in hole, RIW 8-11 k, set 8,059.0 8,400.0 03:30 04:51 down 8,459' PUW 49 k, PUH to 8,400', continue IH, working pipe through tight spot 8,411'-8,721', pull back up hole to 8,400'. 1/25/2019 1/25/2019 0.60 PRODt DRILL WPRT P Wiper back in hole, set down 8,453', 8,400.0 9,052.0 04:51 05:27 1 1 work pipe down hole, 1/25/2019 1/25/2019 5.00 PROD1 DRILL DRLG P CT 5082 psi, @ 1.9 bpm in, 1.7 bpm 9,052.0 9,238.0 05:27 10:27 out, delta P 1040 psi, BGP 4251 psi, 567 psi WH, Ct Wt -5 k lbs, 1.1 k WOB. Struggle with weight transfer and ankerite, bottoms up from 9090 - 40% ankerite. Build pill out of active mud with 2/2% 776/1-ow Torque. Able to put 3.7 k WOB. Break out, drill ahead tll next ankerite lens, TD called early by town. 1/25/2019 1/25/2019 3.10 PROD1 DRILL WPRT P Pump TD sweeps, PU Wt 44 k lbs, 9,238.0 72.0 10:27 13:33 followed by sweeps staged to exit before the trouble spot at 8,430'. Drive by RA tag, +11', Jog 5", continue out of hole on wiper trip. 1/25/2019 1/25/2019 1.70 PROD1 DRILL TRIP P Tag up, reset counters, RBIH. 72.0 6,655.0 13:33 15:15 14:24 - 4452', slowed running speed to - 27 fVmin possible bonilron issues. Continued in hole. 1/2512019 1/2512019 0.20 PROD1 DRILL DLOG P Tie into the Kt for a+11' correction. 6,655.0 6,994.0 15:15 15:27 1/2512019 1/25/2019 0.20 PROD1 DRILL DLOG P Park at 6999' MD/ 6516' TVD Trap 6,994.0 6,999.8 15:27 15:39 11.8 EMW, 4015 psi and observe pressure fall to 3782 psi in 4 minutes, back on the pump. BHP less than 11.16 ppg EMW PU Wt 40 k lbs 1/25/2019 1/25/2019 3.00 PROD1 DRILL TRIP P RIH, window clean, confirmed TD 6,999.8 9,243.0 15:39 18:39 9,243', completed building Liner Running pill 1/2512019 1/25/2019 1.87 PRODi DRILL TRIP P POOH, laying in beaded 11.8 ppg 9,243.0 78.2 18:39 20:31 LRP, painting EOP flags at 7,160' (yellow), and 4,800' (white) 1/25/2019 1125/2019 0.50 PROD1 DRILL PULD P At surface, check well for flow, PJSM 78.2 78.2 20:31 21:01 1/25/2019 1/25/2019 0.75 PROD1 DRILL PULD P LD drilling BHA on a dead well. 78.2 0.0 21:01 21:46 1/25/2019 1/25/2019 0.30 COMPZI CASING PUTS P RU RF for liner ops, Crew Change, 0.0 0.0 21:46 22:04 PJSM 1/25/2019 1/26/2019 1.93 COMPZI CASING PUTS P PUALateral 2-3/8" slotted liner0.0 1,188.8 22:04 00:00 I completion 40 joints and 7.47' pup joint Page 14122 ReportPrinted: 211412019 Operations Summary (with Timelog Depths) 113-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (aKS) End Depth (WEI) 1/26/2019 1/26/2019 0.75 COMPZ1 CASING PUTB P Continue PU Aslotted 2-3/8" liner 1,188.8 2,015.7 00:00 00:45 completion (28 its) 1/26/2019 1/26/2019 0.50 COMPZ1 CASING PUTB P RD, liner equipment, PJSM 2,015.7 2,015.7 00:45 01:15 1/26/2019 1/26/2019 0.75 COMPZ1 CASING PULD P PU/MU CoilTrak tools, roll cart 2,015.7 2,077.1 01:15 02:00 forward, MU tools, perform surface test (good -test) 1/26/2019 1/26/2019 1.00 COMPZ1 CASING RUNL P RIH, w/A liner assembly 2,077.1 6,878.7 02:00 03:00 1/26/2019 1/26/2019 0.15 COMPZ1 CASING RUNL P Correct to the EDP flag correct minus 6,878.7 6,877.1 03:00 03:09 1.6', PUW 40 it CTSW, minus 5.Ok DHWOB 1/26/2019 1/26/2019 1.00 COMPZ1 CASING RUNL P Continue IH, Work pipe towards 6,877.1 8,599.0 03:09 04:09 bottom, set down 8,599' PUW 55k, 8,620' PUW 54k, 8,939' PUW 50k, 9,053' PUW 55k, 9,132' PUW 55k, continued IH, setting down on bottom 9,243', bring pump up to 1.5 bpm @ 4,366 psi, 1,265 psi diff, PUW 38k, remove liner length from counters 1/26/2019 1/26/2019 1.40 COMPZi CASING TRIP P POOH 8,599.0 72.0 04:09 05:33 1/26/2019 1/26/2019 1.40 COMPZ1 CASING TRIP P LD BH # 6 , A lateral completion 72.0 0.0 05:33 06:57 running BHA over a dead well. 1/26/2019 1/26/2019 0.50 PROM STK BOPE P Performs BOPE Function test - goad. 0.0 0.0 06:57 07:27 1/26/2019 1/26/2019 0.50 PROD2 STK PULD P Pick up BHA#9, AL1 KO / turn drilling 0.0 72.0 07:27 07:57 assembly, install checks, check pack offs- good. 1/26/2019 1/26/2019 1.00 PROD2 STK PULD T Attempt to open EDC, error message, 0.0 72.0 07:57 08:57 Pop off, swap top coil track, stab injector, bump up. 1/26/2019 1/26/2019 1.20 PROD2 STK PULD P RIH 72.0 6,650.0 08:57 10:09 1/26/2019 1/26/2019 0.20 PROD2 STK DLOG P Tie in for a +4' correction. 6,650.0 6,678.0 10:09 10:21 1/26/2019 1/26/2019 1.20 PROD2 STK DISP P Continue to displace tubing an well to 6,678.0 6,993.0 10:21 11:33 drilling fluid. PU Wt 34 klbs, Close EDC. 1/26/2019 1/26/2019 0.10 PROD2 STK TRIP P Continue in hole, window clean, dry 6,993.0 7,205.5 11:33 11:39 tag TOB @ 7,205' 1/26/2019 1/26/2019 2.40 PROD2 STK KOST P PU Wt 37 k lbs, CT 4600 psi @ 1.88 in 7,205.5 7,208.0 11:39 14:03 XX bpm out, delta P 580 psi, BHP 4130 psi, 11.8 ppg EMW, WH 520 psi, IA483 psi, OA 7 psi. CT RIH Wt 20 k lbs, WOB and motor work 7205.5' start timed side track from liner top billet. V@ 1 ft/hr, V@ 2 ft/hr - Stall @ 7207', PU 39 k lbs. RESET, Delta P 472 psi, RBIH and restart 7206.8' 1' @3 ft/hr 1/26/2019 1/26/2019 1.60 PROD2 DRILL DRLG P Drilling ahead. 7,208.0 7,460.0 14:03 15:39 CT 4648 psi, 1.85 bpm in 1.83 bpm, annular 4137 psi, Ct Wt 17 k lbs, WOB 1.75 k lbs, drill to 7305' PU 40 klbs, RBIH, dry drift billet - clean. ROP 158 ft/hr, 1/26/2019 1/26/2019 1.10 PROD2 DRILL TRIP P TD turn, PU Wt 40 k Ibs, POOH 7,460.0 72.0 15:39 16:45 1/26/2019 1/26/2019 1.92 PROD2 DRILL PULD P PUDSHA#9. 72.0 0.0 16:45 18:40 Page 15122 ReportPrinted: 2114/2019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth StartTime End Time Our (hr) Phase Op Cade A ity Code Time P -T -X Operedon (ftKB) End Depth(ftKB) 1/26/2019 1/26/2019 0.17 PROD2 DRILL PULD P Reconfigure BHA 0.0 0.0 18:40 18:50 1/26/2019 1/26/2019 1.10 PROD2 DRILL PULD P PD Lateral Drilling Assembly BHA#10 0.0 78.3 18:50 19:56 1/26/2019 1/26/2019 1.20 PROD2 DRILL TRIP P Tag up re -set counter depths, inspect 78.3 6,678.6 19:56 21:08 pac-offs, RIH, surface test agitator (good -test) 1/26/2019 1/26/2019 0.20 PROD2 DRILL DLOG P Log the K1 marker correction of plus 6,678.6 6,680.6 21:08 21:20 2.0' 1/26/2019 1/26/2019 0.60 PROD2 DRILL TRIP P Continue IH 6,680.6 7,460.0 21:20 21:56 1/26/2019 1/26/2019 0.20 PROD2 DRILL DRLG P BOBD, 1.87 bpm at 4,681 psi, 7,460.0 7,487.0 21:56 22:08 Diff -800 psi, WHP=541, BHP=4,527, IA=563, OA=15 '"' Note: New mud system #2 at the bit 7,465' 1/26/2019 1/26/2019 0.20 PROD2 DRILL WPRT P Plug off choke, PUH 35 k, line up to 7,487.0 7,487.0 22:08 22:20 1 1 choke "B" 1/26/2019 1/26/2019 0.20 PROD2 DRILL DRLG P BOBD, 1.9 bpm at 4,292 psi, 7,487.0 7,527.0 22:20 22:32 Diff=4,175 psi, WHP=683, BHP=4,193, IA=538, OA=15 1/26/2019 1/26/2019 0.15 PROD2 DRILL WPRT P PUH, PUW 41 k, Mud system #2 at 7,527.0 7,527.0 22:32 22:41 surface, obtain new pump parameters. 112612019 1/27/2019 1.32 PROD2 DRILL DRLG P BOBD, 1.88 bpm at 4,325 psi, 7,527.0 7,822.0 22:41 00:00 Diff --882, WHP=721, BHP=4,175, IA=533, 0A=15 1/27/2019 1/27/2019 0.75 PROD2 DRILL DRLG P OBD, 1.9 bpm at4,341 psi, DI"- 00, 7,822.0 7,860.0 00:00 00:45 WHP=730, BHP=4,165. IA=508, OA=18 1127/2019 1/27/2019 0.20 PROD2 DRILL WPRT P 820', wiper up to the bottom of the 7,860.0 7,020.0 00:45 00:57 billet, PUW 41 k 1/27/2019 1/27/2019 0.15 PROD2 DRILL WPRT P Wiper back in hole, RIW 7,020.0 7,860.0 00:57 01:06 1/27/2019 1/27/2019 0.90 PROD2 DRILL DRLG P OBD, 1.91 bpm at 4,385 psi, 7,860.0 8,003.0 01:06 02:00 Diff --4,141, WHP=732, BHP=4,144, IA=548, OA=16, DD unable to drop in section, PU and set back down 5 times to initiate drop. Continue Drilling ahead. "" Note: Fault Crossing @ 7,940' 1/27/2019 1/27/2019 0.50 PROD2 DRILL DRLG P OBD, 1.88 bpm at 4,385 psi, Diff -864, 8,003.0 8,060.0 02:00 02:30 WHP=714, BHP=4,186, IA=548, OA=16 1127/2019 1/27/2019 0.42 PROD2 DRILL WPRT P Geo wiper up hole, PUW 42 k 8,060.0 8,060.0 02:30 02:55 1/27/2019 1/27/2019 0.65 PROD2 DRILL DRLG P BOBD, 1.88 bpm at 4,432 psi, 8,060.0 8,176.0 02:55 03:34 Diff --900, WHP=701, BHP=4,149, IA=632, OA=16 1/27/2019 1/27/2019 0.15 PROD2 DRILL WPRT P Stacking weight, PUH and restarrt, 8,176.0 8,176.0 03:34 0343 1 1 1 PUW 38 k 1/27/2019 1/27/2019 0.15 PROD2 DRILL DRLG P BOBD, 1.91 bpm at 4,740 psi, 8,176.0 8,196.0 03:43 03:52 Diff=1,100 psi, WHP=707, BHP=4,176, IA=649, OA=16 1/27/2019 1/27/2019 0.15 PROD2 DRILL WPRT P Stacking weight, PUH and restart, 8,196.0 8,196.0 03:52 04:01 PUW 48k 1/27/2619 1/27/2019 0.20 PROD2 DRILL DRLG P BOBD, 1.91 bpm at 4,740 psi, 8,196.0 8,260.0 04:01 04:13 Diff --1,100 psi, WHP=707, BHP=4,176, IA=649, OA=16 1/27/2019 1/27/2019 0.30 PROD2 DRILL WPRT P Wiper to the EOB, PUW 38 k 8,260.0 7,460.0 04:13 04:31 Page 16/22 Report Printed: 2114/2019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op code Activity Cope Time P -T -X Operation (flKB) End Deplh(RKB) 1/27/2019 1/27/2019 0.25 PROD2 DRILL WPRT P Wiper back in hole, RIW 15 k 7,460.0 8,260.0 0431 04:46 1/27/2019 1/27/2019 2.10 PROM DRILL DRLG P BOBD, 1.91 bpm at 4,736 psi, 8,260.0 8,425.0 04:46 06:52 Diff=1,226 psi, WHP=723, BHP=4,143, IA=679, 0A=11 1/27/2019 1/27/2019 1.00 PROD2 DRILL WPRT P PU Wt 43 k lbs, PUH on early long 8,425.0 6,546.0 06:52 07:52 wiper to the K1 for tie in. Cahsed 5x5 off bottom, jogged below build @ 7460' to allow second sweep out. Chase out of hole. 1/27/2019 1/27/2019 0.10 PROM DRILL DLOG P Tie into the Ki for a+3.5' correction 6,546.0 6,573.0 07:52 07:58 1/27/2019 1/27/2019 0.70 PROM DRILL WPRT P RBIH, window and billet clean, WOB 6,573.0 8,406.0 07:58 08:40 spikes around 7960-800'. Was oriented low side though. 1/27/2019 1/27/2019 0.70 PROD2 DRILL DRLG P SID 8406, PU 43 k lbs, RBIH work 8,406.0 8,506.0 08:40 09:22 through trouble spot -150 API gamma, with reduced pump rate 1.5 bpm. Drill ahead, CT 4609 psi, 1.9 bpm in, 1.9 bpm out, BHP 4167 psi, WH 700 psi, CT 4.8 k lbs, WOB 1.3 k lbs 1/27/2019 1/27/2019 0.80 PROD2 DRILL WPRT P PU Wt 45 k lbs, Pull above trouble 8,506.0 8,506.0 09:22 10:10 spot, turn around at 8380', RBIH. some WOB spikes, Running past trouble spot @ 1.5 bpm and 30 ft/min 1/27/2019 1/27/2019 0.90 PROD2 DRILL DRLG P CT 4516 psi @ 1.87 bpm in nd 1.84 8,506.0 8,540.0 10:10 11:04 bpm out, dela P 866 psi, BHP 4165 psi - 11.8 ppg EMW at the window. Ct Wt 3.6 k lbs, WOB 2.1 k lbs, ROP 90 1/27/2019 1/27/2019 0.30 PROM DRILL DRLG P CT 4516 psi @ 1.87 bpm in and 1.83 8,540.0 8,553.0 11:04 11:22 bpm out, della P 839 psi, BHP 4131 psi - 11.8 ppg EMW at the window. Cl Wt 2 k lbs, WOB 0.87 k lbs, ROP 110 PU Wt 46 k lbs, Pull above trouble spot, turn around at 8443', RBIH. WOB spikes, stack some coil Wt @ 8470'. Running past trouble spot @ 1.5 bpm and 30 ft/min 1/27/2019 1/27/2019 0.30 PROD2 DRILL WPRT P Struggle to get restarted, PU 47 k lbs, 8,553.0 7,490.0 11:22 11:40 drug up to 50 k lbs, Short time on bottom until pick up required, PUH on wiper, pump 5x5 Ct Wt 40 to 36 k lbs. 1/27/2019 1/27/2019 0.20 PROD2 DRILL WPRT P RBIH, 2.8 k lbs WOB spike @ 8438', 7,490.0 8,553.0 11:40 11:52 bounced through. 1/27/2019 1/27/2019 1.90 PROD2 DRILL DRLG P CT 4540 psi @ 1.90 bpm in and 1.83 8,553.0 8,633.0 11:52 13:46 bpm out, delta P 1000 psi, BHP 4162 psi - 11.8 ppg EMW at the window. Ct Wt 2 k lbs, WOB 0.87 k lbs, ROP 110 1/27/2019 1/27/2019 0.20 PROD2 DRILL WPRT P Geo wiper after sudden drop in 8,633.0 8,633.0 13:46 13:58 gamma @ 8599'. RBIH, WOB spikes @ 8410' and 8513' 1/27/2019 1/27/2019 4.50 PROD2 DRILL DRLG P Ct 4479 psi @ 1.9 bpm in 1.90 bpm 8,633.0 8,886.0 13:58 18:28 out, delta P 846 psi, BHP 4195 psi, CT Wt 2.1 k lbs, WOB 1.6 k lbs. Reaquire the A4 pay @ 8780'. Pump 5x5 sweep. 1/27/2019 1/27/2019 0.40 PROD2 DRILL WPRT P Chase sweeps out of hole on 1000' 8,886.0 7,876.0 18:28 18:52 wiper #2 PU 42 k lbs @ 8570' pull into 53 k CT Wt, -6 k lbs WOB. RIH S/D 2 k WOB, PU, 4 k continue to PUH. more minor neg WOB spikes @ 8460'. Page 17122 ReportPrinted: 2/14/2019 Operations Summary (with Timelog Depths) r 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sten Depth Stan Time End Time our (hr) Phase Op Code Aclivlty Code Time P -T -X Operation (NCB) End Depth Min 1/27/2019 1/27/2019 1.30 PROD2 DRILL WPRT P RBH, Start spiking WOB @ 8400', 7,876.0 8,811.0 18:52 20:10 8480', 8498', 8522, and multiple times at 8,550'. PU weights 46k lbs. Reduce rale to 1.2 bpm ran through. Stuggled again up to 8764'. 1/27/2019 1/27/2019 1.60 PROD2 DRILL WPRT P PU, 46, pump 10 bbl High vis, PUH, 8,811.0 8,370.0 20:10 21:46 pulling heavy and packing off, pulled above trouble zones 8400'. Small amount of gas a the shaker from pack off event. launch 5x5, consult w town engineering.clean out to 8370' chase sweeps up hole. 1/27/2019 1/27/2019 1.25 PROD2 DRILL WPRT T PUH chasing sweeps out of the well. 8,370.0 78.2 21:46 23:01 Billet and window dean. Large unload of cuffings, Flakes of silt and metal. 1/27/2019 1/28/2019 0.99 PROM DRILL PULD T At surface, PUD drilling BHA#10 78.2 0.0 23:01 00:00 1/28/2019 1/28/2019 0.25 PROD2 DRILL PULD T Continue PUD drilling BHA 0.0 0.0 00:00 00:15 1/28/2019 1/28/2019 0.30 PROD2 DRILL PULD T Reconfigure BHA 0.0 0.0 00:15 00:33 1/28/2019 1/28/2019 1.00 PROD2 STK PULD T PD Open Hole Anchored Billet 0.0 72.7 00:33 01:33 1/28/2019 1/28/2019 1.50 PROD2 STK TRIP T RIH, w/Open Hole Anchored Billet 72.7 6,655.0 01:33 03:03 BHA #11. 80 fpm as per BOT rep. 1/28/2019 1/28/2019 0.20 PROD2 STK DLOG T Log the K1 marker plus 3.0' 6,655.0 6,678.0 03:03 03:15 1/28/2019 1/28/2019 0.80 PROD2 STK TRIP T Continue IH 6,678.0 8,161.8 03:15 0403 1/28/2019 1/28/2019 0.15 PROM STK WPST T PUW 39 it, RBIH to setting depth, 8,161.7 8,150.0 04:03 0412 PUH to neutral weight, bring pump on line 1.3 bpm to shear 4,800 psi, set down 5.0 k, PUH, PUW 35 k 1/28/2019 1/28/2019 1.50 PROM STK TRIP T POOH, following MP 8,150.0 72.7 04:12 0542 1/28/2019 1/28/2019 1.20 PROD2 STK PULD T PUD, setting tools 72.7 0.0 05:42 0654 1/28/2019 1/28/2019 1.20 PROD2 STK PULD T PD, kickoff/drilling assembly, surface 0.0 78.3 06:54 08:06 test CoilTrak tools (good -test) 1/28/2019 1/28/2019 1.40 PROD2 STK TRIP T Tag up, reset counters, RIH w/Drilling 78.3 6,655.0 08:06 09:30 BHA#12 1/28/2019 1/28/2019 0.20 PROM STK DLOG T Log the K1 marker correction of plus 6,655.0 6,675.0 09:30 09:42 2.0' 1/28/2019 1/28/2019 0.50 PROD2 STK TRIP T Continue IH, close EDC, PUW 39 k 6,675.0 8,150.0 09:42 1012 1/28/2019 1/28/2019 0.30 PROD2 STK TRIP T Dry drift billet @ 8,150' 8,150.0 8,150.0 10:12 1030 1/28/2019 1/28/2019 3.80 PROD2 STK KOST T PUH, bring pump on-line 1.89 bpm at 8,150.0 8,153.0 10:30 1418 4,717 psi, Diff=1,135 psi ,WHP=643, BHP=4,186, IA=398, OA=8, time mill off billet 3.0' 1/28/2019 1/28/2019 1.00 PROD2 DRILL DRLG T Drill ahead, 1.89 bpm at 4,717 psi, 8,153.0 8,257.0 14:18 15:18 Diff --1,050 psi ,WHP=643, BHP=4,186, IA=398, OA=8 1/28/2019 1/28/2019 0.20 PROD2 DRILL WPRT T PUH to drift window area (clean), 8,257.0 8,257.0 15:18 15:30 RBIH 1/28/2019 1/28/2019 1.80 PROD2 DRILL DRLG T Drill ahead, 1.87 bpm at 4,717 psi, 8,257.0 8,550.0 15:30 17:18 Diff=1,050 psi ,WHP=625, BHP=4,173, IA=756, OA=8 1/28/2019 1/28/2019 0.90 PROD2 DRILL WPRT T 8550', Wiper trip to 7488, PUW=42K 8,550.0 8,550.0 17:18 18:12 Page 18/22 Report Printeo: 2114/2019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth $tart Time End Time Cur(hr) Phase Dp Code Activity Code Time P4A Operation (ftKB) End Depth(flKB) 1/28/2019 1/28/2019 2.70 PROD2 DRILL DRLG T 8550', Drill, 1.87 BPM @ 469OPSI FS, 8,550.0 8,840.0 18:12 2054 BHP=4235 1/28/2019 1/28/2019 0.10 PROD2 DRILL WPRT T 8840', BHA Wiper, PUW=45K 8,840.0 8,840.0 20:54 21:00 1/28/2019 1/28/2019 0.20 PROD2 DRILL DRLG T 8840', Drill, 1.87 BPM @ 4690 PSI 8,840.0 8,886.0 21:00 21:12 FS, BHP=4225 1/28/2019 1/28/2019 0.70 PROM DRILL DRLG P 8886. reached TD before billet, Off 8,886.0 8,950.0 21:12 21:54 1 1 Itime 1/2812019 1/28/2019 0.70 PROD2 DRILL WPRT P Wiper to billet @ 8150, PUW=43K 8,950.0 8,950.0 21:54 22:36 1/28/2019 1/29/2019 1.40 PROD2 DRILL DRLG P 8950', drill, 1.88 BPM @ 4320 PSI FS, 8,950.0 9,114.0 22:36 00:00 BHP=4200, New mud at bit 9012'. Old system out @ 2288' drilled, 0.85% drill solids 1/29/2019 1/29/2019 3.50 PROD2 DRILL DRLG P 9114', Drill, 1.89 BPM @ 4320 PSI FS, 9,114.0 9,310.0 00:00 03:30 BHP=4180 1/29/2019 1/29/2019 0.10 PROD2 DRILL WPRT P BHA Wiper, PUW=49K 9,310.0 9,310.0 03:30 03:36 1/29/2019 1/29/2019 0.30 PROD2 DRILL DRLG P 9310', Drill, 1.85 BPM @ 4360 PSI 9,310.0 9,350.0 03:36 03:54 FS, BHP=4150 1/29/2019 1/29/2019 1.20 PROD2 DRILL WPRT P Wiper trip to window with 5 X 5 9,350.0 7,035.0 03:54 05:06 sweeps, PUW=48K 1/29/2019 1/29/2019 0.20 PROD2 DRILL DLOG P Log the RA marker correction of plus 7,035.0 7,060.0 05:06 05:18 7.0' 1/29/2019 1/29/2019 1.20 PROD2 DRILL WPRT P Continue wiper back in hole, set down 7,060.0 9,350.0 05:18 06:30 9,122', PUH lowered pump rate 1.2 bpm, continued IH 1/29/2019 1129/2019 2.20 PROD2 DRILL DRLG P BOBD, 1.89 bpm at 4,636 psi, 9,350.0 9,650.0 06:30 08:42 Diff=964, WHP=964, BHP=4,302, IA=424, OA=5, started lossing -24 bbl/hr 1/29/2019 1/29/2019 0.60 PROD2 DRILL WPRT P 1000', wiper up hole, PUW 48 k 9,650.0 8,650.0 08:42 09:18 1/29/2019 1/29/2019 1.00 PROD2 DRILL WPRT P Wiper back in hole, set down x 3 @ 8,650.0 9,650.0 09:18 10:18 9,157', and 9,249', lower pump rate to 1.2 bpm made it through 1/29/2019 1/29/2019 1.15 PROD2 DRILL DRLG P BOBD, 1.89 bpm at 4,693 psi, 9,650.0 9,694.0 10:18 11:27 Diff=938, WHP=635, BHP 4,693, IA=407, OA=5 1/29/2019 1/29/2019 3.30 PROD2 DRILL WPRT P TD called early, pump 10x10 sweep, 9,694.0 78.3 11:27 14:45 chase sweeps to surface, performing jog from 1129/2019 1/29/2019 0.20 PROD2 DRILL TRIP P Tag up, reset counters 78.3 78.3 14:45 14:57 1/29/2019 1/29/2019 1.10 PROD2 DRILL TRIP P RIH 78.3 6,655.0 14:57 1603 1/29/2019 1129/2019 0.20 PROD2 DRILL DLOG P Log the K1 marker correction of plus 6,655.0 6,678.0 16:03 16:15 0.5' 1/29/2019 1/29/2019 0.20 PROD2 DRILL TRIP P Continue IH, perform static pressure 6,678.0 7,010.0 16:15 1627 surface above window area 1/29/2019 1/29/2019 0.20 PROM DRILL TRIP P Perform static pressure surface above 7,010.0 7,010.0 16:27 16:39 window area Sensor depth 6,423.8', Annular pressure 3,762, 11.8 ppg down to 11.1 ppg, PUW 39 k 1/2912019 1/29/2019 DRILL TRIP P Continue IH, set down x 3 @ 9,112', 7,010.0 7,112.0 16:39 16:57 PUH to log the K1 112912019 1/29!2019 DRILL TRIP P PUH, to log the K1 7,112.0 6,655.0 16:57 17:09 t2R 1/29/2019 1/29/2019 DRILL DLOG P Log the K1 correction plus 0.5', 6,655.0 6,677.0 17:09 17:21 Page 19122 Report Printed: 2114/2019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Earth Start Time End erne our (hr) Phase Op Code Activity Code Time P -T -X Operation (Ws) End Depth (MB) 1/29/2019 1/29/2019 1.10 PROD2 DRILL TRIP P POOH 6,677.0 92.0 1721 18:27 1/29/2019 1/29/2019 1.50 PROD2 DRILL PULD P At surface, Tag up and space out, 92.0 0.0 18:27 19:57 PUD BHA#12, Lay down tools.Bil out @ 1-1. Change motor AKO from 1 to 1.25° 1/29/2019 1/29/2019 0.90 PROD2 DRILL PULD T PD BHA#13 with D-331 mill, 1.25° 0.0 68.4 19:57 20:51 AKO motor, no USR. Make up D coiltrak and surface test 1/29/2019 129/2019 1.40 PROD2 DRILL TRIP T RIH BHA #13, Surface test agititator 68.4 6,650.0 20:51 22:15 1/29/2019 1/29/2019 0.10 PROD2 DRILL DLOG T Log K1 for+1 foot correction 6,650.0 6.677.0 22:15 22:21 1/29/2019 1/29/2019 0.20 PROD2 DRILL TRIP T Continue in hole. Clean pass through 6,677.0 7,112.0 22:21 22:33 window. Dry tag @ 7112. PUH 1/29/2019 1/29/2019 0.10 PROD2 DRILL REAM T PUH to 7100, Bring on pumps 1.9 7,112.0 7,114.0 22:33 22:39 BPM @ 4761 PSI FS. Start working down @ 1 FPM. Start sweeps down CT.See motor work and WOB @7112. Start to speed up @ 7114. Stall motor 1/29/2019 1/29/2019 0.50 PROD2 DRILL REAM T PUH ater stall, restart. See torque and 7,114.0 7,180.0 22:39 23:09 vibration @ 7111. Maintain reaming @ - 1.5 FPM to 7120 then go to 5 FPM down to 7140. Recip up at 1.86 BPM up to 7098. Initial sweeps at shaker. Nothing coming across shaker. RBIH to 7180 mostly clean at higher speed 1/29/2019 1/29/2019 0.70 PROD2 DRILL REAM T PUH to 7097. Turn around clean trip 7,180.0 7,180.0 23:09 23:51 down. To 7180. Pump another serfs of sweeps and recip area. Little to no material on shaker 1129/2019 1/30/2019 0.15 PROD2 DRILL REAM T 7180, Line up to go past billet @7205. 7,180.0 7,194.0 23:51 00:00 Stack ou @7188 when we reduced rale to pass billet. PUH to 7166. 1/30/2019 1/30/2019 1.10 PROD2 DRILL TRIP T Run in hole, set down @ 8668' work 7,194.0 8,682.0 00:00 01:06 pipe down o 8682 1/30/2019 1/30/2019 0.80 PROD2 DRILL TRIP T Pump Sweeps, PUH to 8177, 8,682.0 8,177.0 01:06 01:54 PUW=45K 1/30/2019 1/30/2019 0.20 PROD2 DRILL TRIP T RBIH, 1.5 BPM set down @ 8704 8,177.0 8,735.0 01:54 0206 work to 8735 1/30/2019 1/30/2019 0.10 PROD2 DRILL TRIP T 8735, PUH to 8590, 1.8 BPM 8,735.0 8,590.0 02:06 02:12 1/30/2019 1/30/2019 0.10 PROD2 DRILL TRIP T 8590 RBIH, 1.5 BPM @ 8783 set 8,590.0 8,783.0 02:12 0218 down. 1/30/2019 1/302019 0.10 PROD2 DRILL TRIP T 8783', PUH to 8570, 1.8 BPM, 8,783.0 8,570.0 02:18 02:24 PUW=46K 1/30/2019 1/30/2019 0.20 PROD2 DRILL TRIP T 8570', RIH to setdown @9088', 1 8,570.0 9,088.0 02:24 02:36 BPM, Choppy going 1/30/2019 1/30/2019 0.10 PROD2 DRILL TRIP T 9088', PUH, PUW=44K, 1.8 BPM 9,088.0 8,970.0 02:36 02:42 1/30/2019 1/30/2019 1.20 PROD2 DRILL TRIP T 8970, RBIH to 9157'recip 3 times. 8,970.0 9,157.0 02:42 03:54 Hard setdowns 1/3012019 1/30/2019 0.40 PROD2 DRILL TRIP T 9157. Get through 9157 at redused 9,157.0 9,693.0 03:54 04:18 rate 1/30/2019 1/302019 0.60 PROD2 DRILL TRIP T 9693, PUH slowly waiting on sweeps, 9,693.0 7,010.0 04:18 04:54 Continue up hole, Poor hole conditions @ 9290 up to 9050 with overpulls some with negaive WOB. Max pull 60K. Hard to get running back in hole. Cleared up above 9000' 1/30/2019 19 2.75 PROD2 DRILL WPRT T Jog the 5" with multiple sweeps 7,010.0 6,550.0 04:54 t073 Page 20122 Report Printed: 2114/2019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time Dar inn Phase Op Code Acwity Cade Time P-T-X Operation (ftKB) End Depth(MB) 1/30/2019 1/30/2019 0.30 PROD2 DRILL TRIP T RIH, to logging depth 6,650.0 6,655.0 0739 07:57 1/30/2019 1/30/2019 0.20 PROD2 DRILL DLOG P Log the K1 marker correction of plus 6,655.0 6,683.0 07:57 08:09 7.5' 1/30/2019 1/30/2019 1.00 PROD2 DRILL TRIP P RIH, through window (clean), continue 6,683.0 9,071.0 08:09 09:09 RIH to 9,070' 1/30/2019 1/30/2019 0.75 PROD2 DRILL CIRC P Send 11.8 ppg completion fluid down 9,071.0 9,071.0 09:09 09:54 1 1 1 coil 1/30/2019 1/30/2019 2.00 PROD2 DRILL TRIP P POOH, laying in beaded liner running 9,071.0 68.0 09:54 11:54 pill, painting EDP flags, liner pill up into tuing @ 5,400' 1/30/2019 1/30/2019 0.50 PROD2 DRILL PULD P At surface check well for flow. 68.0 68.0 11:54 12:24 1/30/2019 1/30/2019 0.60 PROD2 DRILL PULD P LD cleanout BHA#13 68.0 0.0 12:24 13:00 1/30/2019 1/30/2019 0.50 COMPZ2 CASING PUTS P Prep RF for iner ops 0.0 0.0 13:00 13:30 1/30/2019 1/30/2019 2.65 PROD2 CASING PUTS P PU/MU slotted liner (68 jts) 0.0 1,971.2 13:30 16:09 1/30/2019 1/30/2019 0.60 PROD2 CASING PUTS P PU/MU solid liner (13 jts) 1,971.2 2,373.0 16:09 16:45 1/30/2019 1/30/2019 1.10 PROM CASING PULD P PU/MU CoilTrak tools. M/U to coil and 2,373.0 2,425.2 16:45 17:51 perform surface test (good-test). Check packoffs. Change out checks in UQC. 1/30/2019 1/30/2019 1.00 PROD2 CASING RUNL P RIH, w/AL1 liner completion 2,425.2 6,931.0 17:51 18:51 1/30/2019 1/30/2019 0.10 PROD2 CASING DLOG P Correct to flag for-5.55', PUW=45K 6,931.0 6,925.0 18:51 18:57 1/30/2019 1/30/2019 0.80 PROD2 CASING RUNL P Continue in hole,Clean through 6,925.0 9,069.6 18:57 19:45 window. Set down @ 8792 then run to set depth 1/3012019 1/30/2019 0.10 PROD2 CASING RUNL P At set depth. Pumps on 1.5 BPM, 9,069.6 6,674.0 19:45 19:51 PUW=34K PUH to 9055 and remove liner length left in hole. Open EDC 1/30/2019 1/30/2019 3.30 DEMOB WELLPR WAIT T Waiting on seawater, Static 6,674.0 6,674.0 19:51 23:09 BHP=3689 PSI, Sensor depth 6660', TVD 6135' 1/30/2019 1/31/2019 0.85 DEMOB WELLPR TRIP P Circulate seawaer down coil. Displace 6,674.0 6,100.0 23:09 00:00 well to seawater, start out of hole 1/31/2019 1/31/2019 1.80 DEMOB WELLPR TRIP P Continue trip out, Freeze protect well 6,100.0 41.2 00:00 01:48 with 30 BBis diesel 1/31/2019 1/31/2019 1.30 DEMOB WELLPR PULD P Tag up and space out, PJSM, PUD 41.2 0.0 01:48 03:06 BHA# 13, Lay down tools, FSITP=620 PSI 1/31/2019 113112019 1.00 DEMOB WELLPR CIRC P Stab on injector, Displace CT back to 0.0 0.0 03:06 04:06 WMud 1/31/2019 1/31/2019 0.50 DEMOB WELLPR CIRC P Drilling WMud around, start takeing 0.0 0.0 04:06 04:36 baseline pressures .5 BPM @ 830 PSI, 1 BPM @ 1280 PSI, 1.5 BPM @ 1940 PSI, 1.75 BPM @ 2320 PSI, 2 BPM @ 2780 PSI, 2.25 BPM @ 3250 PSI, 2.5 BPM @ 3710 PSI, 2.75 BPM @ 4250 PSI, 3 BPM @ 4920. Unstab to make up NS liner release tool 1131/2019 1/31/2019 0.20 DEMOB WELLPR CIRC P PJSM, M/U NS release tool and stab 0.0 0.0 04:36 04:48 1 back on well Page 21122 ReportPrinted: 2/14/2019 Operations Summary (with Timelog Depths) 1B-16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth StartTime End Time our mr) Phase Op Code Activity Cotle Time P -T -X Operation (flK8) End Depth(ftKB) 1/31/2019 1/31/2019 1.50 DEMOB WELLPR CIRC P Start Flow tests with tool on. .5 BPM 0.0 0.0 0448 06:18 @ 950 PSI, 1 BPM @ 2000 PSI, 1.5 BPM @ 3700 PSI, Heard tool shift @ 1.73 BPM. unstab injector to verify. Tool has shifted. Test over. Lay down tool 1/31/2019 1/31/2019 6.00 DEMOB MOVE DMOB P Work on rig move check list, 0.0 0.0 06:18 12:18 disconnect tiger tank line, remove fluid from tank, call out DTH to move tiger tank, remove all fluids and clean pits. 1/31/2019 1/31/2019 3.70 DEMOB MOVE I DMOB P Proactively change out lower blind 0.0 0.0 12:18 16:00 shear rams, remove 4-1/16" valves and installed blind flange onto well. 1/31/2019 1/31/2019 0.00 DEMOB MOVE DMOB P RIG RELEASE @ 1600 hrs, standby 0.0 0.0 1600 1600 for trucks Page 22/22 Report Printed: 2/1412019 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1B Pad 1 B-16AL1 50-029-22457-60 Baker Hughes INTEQ Definitive Survey Report 14 February, 2919 BAKER UGHES ConocoPhillips Br R ConocoPhilli s P De(nitive Survey Report Compan, ConocoPhillips AMska Inc Kuperuk Local Co-ordinate Reference: Well 1B-16 Prokcn Kupamk River Unit n/D Reference: 18-16®102.01(1B-16) She: Kupamk I Part MO Reference: iB-16®102.00ush(113-16) Well: 1B-16 North Reference: True Wetmore, 1B-16AL1 Survey Calculation Method', Minimum Curvature Design: IB-16AL1 Database: EDT 14 Alaska Production Pro)ett Kupamk River Und,Narih6lope Alaska,Unded Sitle Map System: US State Plane 1927 (Ed solution) Syatem new.: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) using Well Reference Point Map Zone: Alaska Zone 64 Using geodetic scale factor Well 18-16 Well Position aN1-5 0.00 ush Northing: 5,959,646.31 Latitude: 70° 19'40.243 N ,FLW 0.09 ush Easting: 550,195,14ush Longitude: 149°35'34.518W Position Uncertainty 0.00 ..it Wellhead Elavation: an Ground Level: 0.00 use Wehbore 113-16AL1 Magri Model Name Sampk Date Oaogna0on Olp Anglo Mid Shari (1 (1) (nT) BGGM2018 21112019 16.70 80.88 57,426 Oeaign 18-16AL1 Audit Notes: Version: 1.0 Phase: ACTUAL The On Di 8,131.19 Vertical Section : Depth From(WID) aW8 sEl-W Direction Pan) (.an) (gart) (•) 102 00 0.00 0.00 30.00 Zkl4i 8'4955AM Page 2 COMF115S 5000.14 Build 851) ConocoPhillips Is'r:'w 6 CoflOCOPFIIlI)PS Definitive Surrey Report ,.. Company. 0.n..Phi6ips Alaska lnc Kupamk Local Co-oriinate Reference: Mill IB -16 Protein: Kupamk Rlaer Unii TVD Reference: 1B-16@ 102.00usn(I B-16) Site: Kupamk lB Pad MU Reference: 18-16 d0102.00usn(1 B-16) Well: 18-16 North NeMrenre: Tine Wellbore: 16-16AL1 Survey Calculation Methal Minimum Curvature Dec".: 1B-16AL1 Di...: EDT 14 Alaska Production Survey Pmgnm Date 211&2019 From To Survey (usn) (-am Survey(W.Mont) Taal Name Description Stere Dab 19359 6,823.00 1B-16(18-16) MWD MM -Standard &2512000 ],026.1)0 7,114.59 1B -16A MWD-INO(I B -1 6A) MVJD-WC_ONLY MVJ0.INC_ONLY _FILLER 112 312 01 9 7,145.11 7$05.27 lB-16AMWD (1&16A) MWD MWD - Standartl 1/2 312 01 9 7,234.05 7.234.05 18-161 PBI Mini II B-16ALl P81 MWD-INC_ONLY MWD-INC_ONLY _ FILLER 1 11 612 0 1 9 7,25661 8,131.19 1B-i6AL1PBI MWD(1B-16AL1PB1) MWD MWD -Standard! 111]12019 8.149.00 9,65050 1B-16AL1 MWO(1B-16AL1) MWD MWD - Standartl 1298019 Survey Map Wp ecMM MD Ix AN TVD NDSB W4 aErm No(it) Emitting Di S Survey Tool Name (-am (°) (ud 1°) n) (Lown) (daft) n) (-aro m) m) NiSection m) 8.131.19 101 25.8 6.662.10 6.5580.18 2899.8] 480.00 5.9tt,541,13 549,395]4 3.O1 2,12131 MWD (5) 8,149.00 10057 27.30 665&% 6556.% 2915.54 -7]22] 5,871.5%86 Sas.403.45 8.90 2.13&W MND(.) 8,102.99 9239 2&21 6Ri fi55166 ;945.25 -756.64 5,912.58167 549.419.99 9.71 2,1]2.34 MAT) (6) 8,212.93 94.33 29.43 studio,5 .WS. 2971.31 -042.30 5,91 549,433.35 11.01 2,2(0.00 MIND (6) 8.20.1.03 91.90 A.70 6,640.97 6,516.97 299].48 -87.45 5,912.63909 548,44].71 8.11 2,28.0 WID(6) 8 MAI 0.61 20.23 6640.30 6541 3,02392 -71251 5.9861 549.462.48 4.52 2,52.54 MD (6) 0.302.5 09.59 20.68 6648.50 6.516.% 3,049.04 'WN&W 59]28%.84 549,4MW ].1] 2,29130 MND(.) 0,332.40 81 29.98 6649.72 6.54772 3.0]5.1] 60035 5,972.71705 54949130 6.12 2321.50 MND(6) 0,52.64 84.92 28.51 6,651.91 6.549.91 3,101.40 660.62 500274347 549,505. 7.01 235165 MWD (6) 8,39231 84.93 5.43 6654.53 6552.53 3.12].]2 4" 97 "MY(9.]9 549519.32 8.98 230130 MWD(5) 8,42260 0582 24.47 6,655.95 655095 3,154.96 64201 55 ,88,]9].12 54953210 701 2411.27 il(6) B452]9 88.04 1252 6.%8.57 8,556.57 3,182.61 629.99 5,98.824.84 549,X3.93 978 2.4%.8 MAID (6) 6481.7 89.09 21.02 8.659.29 655].29 3,216.42 6195 5,003.851.8 51 &32 2.46980 MAD (5) usizi2 89.64 20.05 6.659.58 6557.50 3,230.60 ..U2 55,8&001.% 549,56511 4.02 250062 MAC (6) 81 9052 21.60 6.659.46 6,55740 3.261.56 590.85 5.98905.93 549.51 630 3,526.90 WAD (6) 8,57031 9000 5.34 61 6557.33 329199 697.10 5,972,934.50 541 5.85 2,557.40 MAID (6) 6599.% 88.94 24.64 6.6%M 6,557.33 3,318.]2 57531 59896130 5A9597.80 4414 2.5%.49 MAO(.) 5.630.97 89.51 531 66594 8,57.48 3,34584 661.23 5.972 969 X9.61159 1145 2.61783 MAK)rid Survey End Clap 1123/2019 11232019 1862019 112712019 11292019 Annotation TIP KOP 2/1420198: 4959AM Pa9o3 COMPASS c 114 Said 60 Survey ConocoPhillips ConocoPhillips Definitive Survey Report Company: Conor Phillips Ali Inc_Kupamk Local C000 inate Reference: Well iB-16 Pm)ec, Kupamk River Unit TVD Reference: 18-16@102.00usA(18-16) sm, Kupamk I Pad MD Reference: 18-16 C 102.00usA (18-16) Well: 18-16 Nodh Reference: Thee Wellbore: 1B-16ALl Survey Calculation Method: Minimum CurvaWre Design 1646AL1 Database: EDT 14 Alaska Pm6uc8on Survey Annotation B/a(ER IUGRES 271 19 8.49:59AM Police COMPASS 500014 BWV 650 Map Mae Vertical MD Ix AM TVD MISS .11,114sV.W No(it Ei(IIin9 DLS Section Survey Tool Name (Nm) (1) (7 (uaD) (uam lute) (uanl el) (el (M0P) e) 6[59.]3 89.00 3659 6659.03 655]0] 3,]]190 542.12 5971nt166 59062553 8.31 3.64659 MWDIfi 6691.31 07.63 31189 6660.74 6550.]4 3,399.06 533.96 59]3,041.95 549.64,.50 4.70 2620.21 MMill 8,725.62 80.19 33.52 619181 6.559.01 3,423.8, 515.561 5,11M.06179 549.856.91 9.19 270742 MWID(6) 8.250.65 8723 35.13 66180 6,580.88 3,446.61 Assay 5,973.651.65 549,67367 5.57 273735 MWID(6) 8.280.63 fli 32.20 6,fi%.n 6,552.12 3,472.77 A80.77 5,973,11&97 549.69119 7.20 2767.12 MMID (6) 8,81145 88.80 35.60 6,655.10 6.563.10 3,49755 -062.48 5,9TJA1 n 549701k. 6.01 2797.23 MftD (6) 8,84133 90.37 34.89 6685.32 6.66332 3,52,.95 -045.24 6953,165.30 649,2&.49 5.77 2,02748 MAD en 8.87D.96 92.43 33.70 6664.59 6562.59 3,WAD Acll, 5 5.97],109.96 549,742.92 8.03 2652.01 MIND (6) 8.901.30 95.04 33.33 665!.62 6.58062 3.571.65 A1183 59]3.215.31 549.759.47 8.69 2.682.23 MN016l 8.9anUfi1 94.39 3209 6,650.21 6,558.21 3,595.24 196.05 5,973.23999 549.77500 416 2,916.41 MND (6) 856U% 83.59 3682 6,658.12 6,556.12 3.62161 1B].b 5,91 549.791.55 499 2,946.37 MND (6) 0.99062 93.66 29.41 6,658.22 6,554.22 3.647.67 -365.40 597329162 549.805.30 4.70 2,976.27 MND (6) 9,ocow was 27.10 8654.49 6.553.40 3,674.24 451.12 5,9]3.31030 549.81940 7.75 3.005.42 MND (6) 90.51.22 92.42 2094 665290 6.565.90 3,101.50 SW.Ot 6973.3503 549.032.61 7.61 3.036.89 MND (6) 9.080.61 92.10 23.50 865171 6.549.72 3,728.29 53fi.77 592].37249 549,OM.47 495 3.065.81 MN0(6) 9.1111.05 91.59 21.13 6650,65 654ila5 3,75550 3,4.80 5,91 549.855.46 608 3.655.65 MND (6) 9,14083 90,94 2665 6,649.95 6.59795 3.704.31 403.77 5,973562665 549.065.08 552 3.125.42 MND(6) 917103 s&13 19.98 665038 6,640.28 3012156 -293.43 5,973,45709 549.076.24 832 3.155.16 MND (6) 9,99.73 85.76 19.01 6651.81 6.519.81 3,839.62 -283.65 5,903,40410 519,085.01 828 3.183.37 Mi (6) 9,2362) 85.11 1891 6.654.23 6,552.23 3,068.28 -273.61 5,913,51202 549,095.60 3.64 3.213.22 MND (6) 9,251.58 84.10 1717 6657.18 6,555.18 3,89796 -53.85 5,923,54256 549,908.15 839 3.243]6 MWD (6) 9.0315 U,m 1508 666625 6.550.5 395.33 -256.75 5,97],570.90 549.913.16 7.07 3,772.43 MWD (6) 9,32234 85.73 14.11 6.663.01 6,56101 3,956.30 -247.95 5,913601.65 549.95615 6.17 3,302.28 MND(6) 9,35183 0720 1280 8604.83 6.&Da3 3,904.93 Q4110 59n.6ob).67 549,92741 6.67 3,130.49 MND(6) 9.361]3 00.% 1240 665591 6,56391 4,014.08 -EM.'9 5,91a,650.01 549.9&1]] 503 3.359.% MAD (61 9,411.01 80.16 9.77 6,6%.65 6,511.65 4,04281 -228.65 5,9M,687.62 549.939.18 800 3.3%.fie MWD(6) 9,41077 569.84 824 6,662.35 6565.35 4072.19 -22425 5,971.7203 548943.62 530 3,414.47 MWD (6) 947063 e6d4 T55 6660.09 6teii 4101 -2517 5.97374882 549.912.55 285 3,442.31 MWD (6) 9,501.65 87.0 575 8659.18 6%7.10 4,132.56 4H6,61 5,913.17745 549950.91 617 3.470.W MWD (6) 9,5313 07.51 304 66M,4a 6,55.43 4, 10.11 31413 5,923.80701 549,953.5 644 3,49743 MWD (6) 9,%167 Mi 'Al 6671.97 6,56).97 4,192.36 11274 5973.65727 549951.30 646 3,524.1i MWD (6) Annotation B/a(ER IUGRES 271 19 8.49:59AM Police COMPASS 500014 BWV 650 ConocoPhillips B f ConocoPhillips Definitive Survey Report Company'. C.,..Phllllps Alaska lnc Kupamk Local Coordinate Reference: Well 1&16 P.J.': Kupamk River Unit WD Reference'. 1&16®102,00usfl(1 B -16t Site: Kupamk lB Pad MD Reference. 1&16®102.00m3(1&16) Well: 18-16 North Reference: True Wellbore: 1B-16ALl Survey Calculation Methal Minimum Curvature D-I,n: IB-16AL1 Database: EDT 14 Alaska PmEuclion Survey 2!142019 8:49:5 Pella 5 COMPASS 15000 14 Sudtl 85D Map step MD Inc Av WD WDSS +MS +Elm NOltaleB Eastny DLS Sec M1n (usR) (•) (•( turn( (usn) (usn) Iuaat IR) (h) 1•/100') (B) Survey Tool Name Annotation 959517 a64i 5,95 fi6]4.W 6572.02 4226,28 -2105e 5,9]38]1,21 5099%34 1332 3,550.80 AND (6) 9620.05 86.82 7,42 6,67509 6,57349 0,25039 -20].]3 5 MA95.33 so 959.00 6.08 3.5/1.08 MD (6) 9650.50 85.59 8.0 66T7.56 6,515.56 0,28046 -203.42 5,97392542 509,963.11 593 3.6o5.28 MD (6) 9893.00 8558 8.90 6680.80 6,578.80 4,32233 4%.87 6,973,9677E 5099fi93s O90 3,64481 PROJECTED 10 TO 2!142019 8:49:5 Pella 5 COMPASS 15000 14 Sudtl 85D �I ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1B Pad 1 B-16AL1 PB1 50-029-22457-71 Baker Hughes INTEQ Definitive Survey Report 14 February, 2019 BAKER JUGHES GFmn.pa,ry ConocoPhillips O ConocoPhillips Definitive Survey Report Company: ConowPhilihs Alaska Inc Kuyarvk Pmt .¢ Kalarvk River Unit Site: Kupamk I Pad Well: 18-16 Wellbore: 1B-16ALi PBI Design: 1B-1 SAL1 PS Pmtect Kuparvk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 1B-16 Local Cecadinme Reference: Well 1B-16 TVD Reference: 1B-16 ®102.00usfl (1 B-16) MO Reference: 1 B-16 @ 102.00usg (1 &16) North Reference: True Survey Calculation Method Mmimum Curvature Database: EDT 14 Alaska Production Well Position +N1S 0.00 can Northing: luen) 'EI -W 0.00 sell Seating: Position Uncertainty 0.00 usfl Wellhead Elevation: Wellbore 1B-16AL1PB1 Ma'ntr'a Model Name sample Data BGGM2018 21112019 Design 18-16ALl PB1 Audit Notes: Version: 10 Phase: ACTUAL Vertical Section: Depth From(TVD) (sat) 102.00 Mean Sea Level Using Well Reference Point Using geodetic scale factor 5.969.648.83usg 550,195.14uan usfl Deanatlon (1) 16.78 Latitude: Longitude: Ground Level: Dip Angle 19 80.80 Ta On Depth: 7,205 27 .hi eEl4N Direwlan luen) lu i P) 0.00 0.00 30.00 70° 19' 40.243 N 149° 35' 34.518 W 0.00 usfl FNId Semi Inn 57,424 2/14/[019 8 50 384M Page 2 COMPASS 500014 Based 85D Survey ConocoPhillips • ConocoPhillips MaP Definitive Survey Report Company. ConawPhillips Alaska lin.Kupamk Leeall ndlnala Whence: Well 1&16 WD" AWS Project: Kupamk River Una Eestin9 lVD Refnence: iB-16®102,00usX(I 13-16) MnDlatien (-it) She: Kupamk I Pad (aft) AND Reh¢nce: 1B-16@10200usX(I B-16) (Um RI Well: 1&16 XI NOM Milan m: True BC60 366.54 Wellbore: 1B-16ALf PRI 3,145.14 Survey LalculHXon McMetlu Minimum CurvMOrc 49 549019.0] 47.77 Design: 1B-16AL1PB1 7.234.05 DeMbnm: EDT 14 Alaska Production 669875 5,59].]5 Survey PmBom -1,102.70 DMe 211&21119 SO 44&02 46.54 1,284.17 MW0.1NL_ONLY (4) Interpolated AEimdth From To 33344 6699.40 6597.40 Survey Survey (..it) (own Survey (Millions) Tool Name Descrlpfien Sort Dab End USM 193.59 6,823.00 iB-16(1 B-16) MWD MWD -Standard 0/2512000 54896950 7,026.00 7,114.59 1B -16A MW INC(1 B -16A) MW INC ONLY MW INC ONLY FILLER 12312019 112312019 7,145.11 7.205.27 1B -16A MIND (I B -16A) MWD MWD -Standard 12312019 11232019 7,234.05 7,234.05 1B-IBAL1PBI MWD -INC (1&16AL1 PB1 MW INC ONLY MW NC_ONLYFILLER 1126/2019 152612019 7$6461 8,850.30 1B-16ALIP81 MWD(1B-16AL1PBl) MWD MWD -stand rd 112712019 12]2019 Survey 81120188'5138AM Page3 COMPASS SDW, 14 SUM 8511 Map MaP MD B4e /W TVD WD" AWS aEm Ne(it) Eestin9 DLS Section Section Survey Tool Name MnDlatien (-it) (% PI (aft) (wiry We") (Um RI Vitro.) XI ],915.2] BC60 366.54 669705 8,595.05 3,145.14 -t,f8t85 5,9If,]BG 94 49 549019.0] 47.77 1,2]].60 MWD (3) TIPIKOP 7.234.05 87.78 319.60 669875 5,59].]5 2165.71 -1,102.70 69]1,8093] SO 44&02 46.54 1,284.17 MW0.1NL_ONLY (4) Interpolated AEimdth 7,264.61 93.53 33344 6699.40 6597.40 2191.12 -1.199.59 5.971 52967 540.901.44 49.03 1.297.7 MD (5) 7,295.40 95.07 343.12 6,697.09 6,595.07 2,219.61 -121094 5,9]18500] 54896950 31,75 1.316.77 MWD (5) 7,3211.63 95.91 356.34 6693.89 6591.09 ZMM A21603 5.87189050 54895.39 3960 t,Nt 95 MWO(6) 7,350.05 5.72 883 Santo 6,588.82 2,282.09 -1,216U0 5,971.920.52 54696482 34.54 1,368.35 W/D(5) 7,388.56 985 16.57 0,600.14 8505.14 2,311.03 -1,21000 5,971949.49 548969.82 32.07 1,]£6.41 MD (5) 7,418.54 93.56 273f 856.00 6,504.00 2,338]3 -1.19884 5.971.9]].26 548,98009 W90 1AM98 MMD(5) 7,441.10 89.11 33.46 EEA7 6,583.47 2358.22 -1,18741 Sante%.B2 64699209 33.55 1,446.57 MND (5) 7.46052 87395 40.39 6.685.05 6584.05 237360 -1,175.79 5.972,011te 541800361 3079 1,46777 MAD(5) 7,490.51 87.39 4216 6,60].40 6,565.40 2,396.20 -1,156.03 5,072,03501 549,023.22 590 1407.15 14ND(5) 8520.65 0607 46,71 6,6819.60 6.566.60 2417.69 -0,134.95 5,972.0:5.64 549,044.15 1525 1,526.31 MND(5) 7,550.59 8773 49A7 688970 5.587]0 2,43].]0 -1,112.71 5,972,076.79 5"Mm 0.95 1,554.75 MWD (5) 7,50025 8900 `3916 6690.52 65.79.52 2456.05 -1,090.07 597,036.09 549 088,76 5.27 1,58266 MD (5) 7.611]1) 9243 5.91 660.11 6,55.11 247660 -1.0W.36 5.98.116.60 549,11232 10.85 1.611.61 MD (5) 7,641.59 93.04 515 66885 6,Stan ;496.10 -1,01299 5,98,13566 549,135.5] 201 164019 MWD (5) 7.661M 90,25 5107 660706 5,585.86 2513.85 -103f 59 697,15.38 54915.05 10.57 1,856.12 woo (5) 7.703.01 39.5 48.59 666769 8505.09 25335 ffi 13 5,972,173.35 549,1518 9.21 1,5501 woo (5) 7.79.n 5.5 44.85 658.07 6,55.07 3,559f AMA 597193.90 549,20171 125 1]23.62 imo(5) 81120188'5138AM Page3 COMPASS SDW, 14 SUM 8511 ConocvPhilGps Conocolphillips Definitive Survey Report Company: ConocoPhillips Alaska lnc Kupamk Loral Co-ordlmae Reference: Mil 1B-16 Prolecf. Kumruk River Unit TVD Rahhnce: 1B-16®102.00ush(1 B-16) SY[a: Kumruk 18 Pad MD Rahrulce: 1B -15®10.00u18(1 B-16) Well: 18-16 Noah Rehtence: True Wellbore: 1&16AL1PB1 Survey CalcuhOon Method: Minimum Curvature Design: 18-1SAL 1 PB1 Database: EDT 14 Alaska Production Survey Annotation 81K�ii�F9 a 2942019 a 503"M Page 4 COMPASS 500014 Budd 65D Map Map MD he AM TVD TSRSS aWS +E14N Nor ihirp Basing OLS Sectlnn survey Tool Meme lump c) 19 (-am (-to (-am IMahl (M (ft) 1.11001 1111 7,160.43 90.0 4233 6687.83 65&193 25]6.10 -95533 5,972,21823 5022269 9d1 1,75330 MWD (5) 7,780,22 som 3669 6,607.61 6,585-91 258907 -930.39 5,98 ,239,33 549,241,41 19.01 1,782.87 MWD (5) 7,M0.1m 80.52 3389 8687.39 6,585.39 2623.45 -9194 5,Hn OWK 549256.5 939 1.012.41 NAND (5) 7,85181 91B1 30.76 6.60515 8,584)5 2850.13 -902.5 5,9820060 502M,26 idn '.MSS MWD(5) 7.878.94 84.15 W42 6,885.5 6,50328 267467 -88&12 5,972,31524 549269. 1170 1,08.18 M (5) 7,909.69 WU 2 ,. 6,6625 6560.56 270094 -87482 5,97234160 5483025 9.47 1,901.77 MdrD(5) 7.940.67 95.0 2533 6.67933 6,577,33 286.65 -081.15 5,972,36939 849315. 5.07 1,9325 AAD (5) 7,97935 9074 2534 8677.18 6,575.10 2,163.55 484,0 5.98404.41 5s9332,10 12.65 1,970.90 WAD (5) 80120 .1.75 25.27 6.676.46 6,574.46 2,793.0 -83d'o 59n.434.6d 5493M.12 3. 204.18 MAD (5) 0,040.91 9433 2532 8,674.58 s5R.96 2,019.17 Al&37 5.72.46019 58435.01 9.13 203228 MD 8,07149 9727 5.76 661181 6.50.87 2.846,0 A055 5,972.878 54937084 98 25261 MWD(5) 8.10383 9191 24.85 666749 6,55,49 28884 -19280 59851402 549SV16 951 2.09152 MWD(5) 0,131.19 IN23 5.72 6662.18 6,56718 2SPSS7 -78009 5,98.541,13 549,39574 3.01 2,121.31 MD (5) 8161.13 1110.79 2&31 665,71 6,551,71 2,85.08 -055,71 591256).4 549,46895 8.90 2,15(111 "D (5) 0,19.7 101.28 30,59 6651,10 6,549.10 2951.15 -7V S4 5,88,59259 5u942395 7B1 2,179.50 MAV(5) &22155 89,42 3135 664551 8,54351 297737 -036.03 598,61882 54843952 BM 2,210.08 MrW(5) 0,50.76 9614 31.9 664141 0,53941 3,001.98 -81.62 5,972,64382 548,453. S2 940 2.38.98 sAu(5) 82]991 85,75 31.04 6,63824 6,53624 3PA66 -005.48 5.985843 849848.9 462 2,5794 hand) (5) 0,310.15 M.M 26.78 6.635.55 6.533.55 3,05305 EBt B3 59]2.6.80 549,48281 14.74 229&05 SoAB(5) 0,34039 9599 2438 6,02.80 6,530.00 3,0021 undo 5,972,82.13 549,495.5 9.33 232&07 MNO(5) 8370.0 9.42 22As 6.65.02 6,527.02 3,107.0 -66712 5,872,74967 54950731 1093 235178 MWD (5) 8.40025 9714 2039 6624.84 65.2.84 3,135.10 6045 5,8887.16 S-51760 929 235,85 MWD (5) 8.3039 9.92 2130 66215 651829 3,1635 -645.80 5,988.,5 549,555 T. 241639 "D (5) 8,49,67 9.35 Y.Ia 6618.95 6,516.95 3,19,17 .3499 5.98,032.37 549538.89 885 2,44527 Moo (5) 0.4935 914 Mail 6,617.9 6,51589 3,21757 o1sa 598,69.0 549,56005 90 2,474.60 WAS) (5) 0,52131 8831 24.. 6.61&15 6,51615 3,24695 -Sinal 5988030 549.5539 &53 2,506.9 NNW(5) 8.549.94 B6.W ... 8.619.57 6,511.57 32894 -59.14 5872,81537 549,57416 6,37 2,53468 h%ND(5) 8.6790 83.8 548 66225 652035 3209.84 -586,5 5,972.9,1235 54950,0 9,70 255462 AMID (5) 6.609.0 8236 2777 6.625.0 a5to.06 3,326.13 5879 598.98.73 549,90.9 6.25 2594.12 Ratio (5) 8,684.11 82.49 29.9 6.09.87 6,52780 3,352.63 550,32 5.98.9532 549.614.. 5.65 20430 MWD(5) 80961 8572 3210 6632.91 63991 3,377.05 6432. 5673.200 549,62933 14.01 2,653.67 MD Annotation 81K�ii�F9 a 2942019 a 503"M Page 4 COMPASS 500014 Budd 65D ConocoPhillips C ConoccOhilli IK Definitive Survey Report Compan, ConowPhilllps Alaska Inc_ Kupamk Local Ooasli ate Reference: N41118-16 Project: Kupamk Rivet Unit ND Reference: 18-16@102.00usS(1&16) Site: Kupamk 18 Pad MO Reference: 1BA&C 102nOus11(1&16) Well: 18-16 North Refemnce: True Wellbore. 19-16AL1 PB1 Survey Calculation Method: Minimum Curvatura Design'. 18-16AL1 PB1 Database: EDT 14 Alaska Pmducton Survey W41Q019 II.M.38AM Page5 COMPASS 500014 Budd 850 Map Map Vertical MD Inc Aid TVDTVOSS r-W4aF/-W Northing EssOng OL9 Section Sway Taol Nam. MmlSlion (us') 1'I P) (-ft) (uslt) (..Rj (def) (el (Rl 0100.) (to 8,699.57 85.92 34.16 6635.09 6,53309 3,402.85 520.96 5,9]3.045.75 54964548 6.96 2683.47 MI) (5) 8,72943 85.12 33.02 6637,42 6,535.42 3427.64 510.49 5,973.050.65 549,051]9 471 2.713.18 MND (6) 8,705.05 64.01 3137 664016 6,538.18 3.45397 <93.91 5973.057,08 549.678.10 536 2.74427 MND (6) 8,70,49 85.13 28]6 664252 6,540.52 3,47970 47902 S."n.i 291 549.69290 978 2,77400 MND (5) S,M.N 86.38 26.05 1.7,644.45 6,542.45 3.505.87 465.45 5,973 Wits, 549,70'6.29 9.19 2.05345 WO (5) 8,850.05 87.33 24.55 6,645.11 6,544.11 3,53319 45253 5973,17657 549.719.02 586 3,833.57 MNO(5) 8,W.W 87.33 21M 6,647.77 6.54577 3,FW.63 437.72 5.973211910 549733.62 0.00 2,869.07 PROJECTED 0 TD W41Q019 II.M.38AM Page5 COMPASS 500014 Budd 850 BA_ ICER %' PRINT DISTRIBUTION LIST HUGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME IB-16AL1 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(abakerhuahes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL WT DELIVER TO P.O. BOX) PERSON ATTENTION V t BP North Slope. EOA, PBOC, PRW20(OfOce 109) D&G WO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Reason Blvd. Anchorage. Alaska 99508 2 ConocoPhillips Alaska Inc. Atm: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 ExxonMobil, Alaska Attn: Lynda M. Vaskell and/or Leonardo Elias .3201 C Sheet, Suite .505 Anchorage, AK 99503 4 State of Alaska -AOGCC Attn: Natural Resources Technician If 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 No 218166 3041 8 ce sign and return one copy of this transmittal form to: 3coPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) G Street. forage, Alaska 99510 LOG TYPE GR - RES LOG DATE January 29, 2019 TODAYS DATE February 26, 2019 Revision Details: Rev. Requested by: -- FIELD 1 FINAL CD/DVD FINAL PRELIM tlas, dlis, PDF, META, SURVEY REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTS4 OF PRIN # OF COPIES l#QFuOP1ES # OF COPIES IR 4 4 4 4 1; - RECEIVED AOGCC 5 DNR - Division ofOil & Gas *** 1 Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 .Anchorage, Alaska 99501 *** Stamp "confidential' on all material deliver to DNR 6BP Exploration (Alaska) Inc. Pehotechnical Data Center, IR2-1 ,900 E. Benson Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 BA ER %f ' PRINT DISTRIBUTION LIST F UGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME IB-16ALIPBI FIELD Greater Kuparuk Area 2 1 8 1 5 G 3041 9 se sign and return one copy of this transmittal form to: DcoPhillips Alaska, Inc. i Osterkamp (WNS Petroleum Technician) G Street. Toraae. Alaska 99510 COUNTY North Slope Borough LOG TYPE BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(cDbakerhughes.com data. -RES LOG DATE January 27, 2019 TODAYS DATE February 26, 2019 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY ADDRESS (FEDEX WILL WT DELIVER TO P.O. BOX) PERSON ATTENTION V 1 BP North Slope. EOA, PROC, PRB-20 (Office 109) D&G WO Wells Admin Brenda Glassmakcr & 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 F.xxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4State of Alaska - AOGCC Attn: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division ofOil & Gas xx. Atm: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 FIELDI FINAL CD/DVD FINAL PRELIM (las, dli"s PDF, META, SURVEY I REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINT 9 ur rKIN # OF COPIES I# OF COPIES 1# OF COPIES 4 4 4 4 4 4 RECEIVED *** Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska)Inc. Petrotechnical Dam Center, IR2-1 900 F. Benson Blvd Anchorage, Alaska 99508 1 TOTALS FOR THIS PAGE: 0 1 2 0 0 B h IGHES a GEcompany Date: February 25, 2019 Abby Bell AOGCC 333 West 7'^ Ave, Suite 100 Anchorage, Alaska 99501 218155 30405 Letter of Transmittal Harvey Finch Baker Hughes, a GE Company 795 East 941^ Avenue Anchorage, Alaska 99515 find enclosed the directional survey data for the following well(s): 1B -16A 1B-16AL1PB1 1B-16AL1 RECEIVED FES 2 6 2019 AOGCC (3) 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. Harvey Finch, Baker Hughes, Wellplanner Harvey. Finch@BakerHughes.com ConocoPhillips ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 1B Pad 1 B-16AL1 50-029-22457-60 Baker Hughes INTEQ Definitive Survey Report 14 February, 2019 BAT(ER UGHES a GE company 2 18 155 30405 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 1B Pad MD Reference: Well: 113-16 North Reference: Wellbore: 1B-16ALl Survey Calculation Method: Design: 1B-16AL1 Database: Project Kuparuk River Unit, North Slope Alaska, United States I Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) 2/1/2019 Map Zone: Alaska Zone 04 70° 19'40.243 N j Well 1B-16 149° 35'34.518 W !t Well Position +N/ -S 0.00 usft Northing: Vertical Section: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 1B-1 SALT I Magnetics Model Name Sample Date Using geodetic scale factor BGGM2018 2/1/2019 Design 1B-16AL1 70° 19'40.243 N j Audit Notes: Longitude: 149° 35'34.518 W !t Version: 1.0 Phase: ACTUAL Vertical Section: Dip Angle Depth From (TVD) P) 1°) (usft) 16.78 80.88 102.00 Well 18-16 18-16 @ 102.00usft (18-16) 18-16 @ 102.00usft (18-16) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level I Using Well Reference Point Using geodetic scale factor 5,969,646.83usft Latitude: 70° 19'40.243 N j 550,195.14usft Longitude: 149° 35'34.518 W !t usft Ground Level: 0.00 usft Declination Dip Angle Field Strength P) 1°) (nT) s 16.78 80.88 57,428 j Tie On Depth: 8,131.19 +NIS +E/ -W Direction (usft) (usft) C) 0.00 0.00 30.00 21742019 8:49:59AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips BA ER I�UGNwES ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska lnc Kuparuk Project: Kuparuk River Unit Site: Kuparuk 1B Pad Well: 1B-16 Wellbore: 1 B-16ALl Design: 1B-16ALl Survey Program From (usft) 193.59 7,026.00 7,145.11 7,234.05 7,264.61 j ( 8,149.00 L--. Survey Local Co-ordinate Reference: Well 18-16 TVD Reference: 1B-16 cQ 102.00usft (10-16) MD Reference: 1 B-16 @ 102.00usft (1 B-16) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Survey End Date 1/23/2019 1/2312019 1/2612019 1/27/2019 1/29/2019 Annotation TIP KOP 2/142019 8,49 59AM Page 3 COMPASS 5000.14 Build 850 Date 2/13/2019 To Map Map Survey (usft) Survey (Wellbore) Tool Name Description Start Date 6,823.00 1B -i6 (1B-16) MWD MWD- Standard 8/25/2000 7,114.59 1B -16A MWD -INC (1 B -16A) MWD -INC -ONLY MWD -INC -ONLY -FILLER 1/23/2019 7,205.27 1B -16A MWD (1 B-1 6A) MWD MWD - Standard 1/23/2019 7,234.05 1B-16AL1PB1 MWD-INC(1B-16AL1PB1 MWD -INC -ONLY MWD -INC -ONLY -FILLER 1/26/2019 8,131.19 1B-16ALl P61 MWD (I B-16AL1 PB1) MWD MWD - Standard 1/27/2019 9,650.50 16-16ALl MWD(1B-16AL1) MWD MWD -Standard 1/29/2019 Survey End Date 1/23/2019 1/2312019 1/2612019 1/27/2019 1/29/2019 Annotation TIP KOP 2/142019 8,49 59AM Page 3 COMPASS 5000.14 Build 850 Map Map Vertical MD Inc Azi TVD TVDSS «N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100') Survey Tool Name (ft) (ft) (ft) 8,131.19 100.23 25.72 6,662.18 6,560.18 2,899.87 -780.09 5,972,541.13 549,395.74 3.01 2,121.31 MWD (5) 8,149.00 100.57 27.30 6,658.96 6,556.96 2,915.54 -772.27 5,972,556.86 549,403.46 8.90 2,138.80 MWD (6) 8,182.99 97.39 28.21 8653.66 6,551.66 2,945.25 -756.64 5,972,586.67 549,418.89 9.71 2,172.34 MWD (6) 8,212.90 94.33 29.43 6,650.60 6,548.60 2,971.31 -742.30 5,972,612.82 549,433.05 11.01 2,202.09 MWD (6) 8,243.03 91.90 29.70 6,648.97 6,546.97 2,997.48 -727.45 5,972,639.09 549,447.72 8.11 2,232.17 MWD (6) 8,273.41 9061 29.23 6,648.30 6,546.30 3,023.92 -712.51 5,972,665.63 549,462.48 4.52 2,262.54 MWD (6) 8,30226 88.59 29.68 6,648.50 6,546.50 3,049.04 -698.33 5,972,690.84 549,476.50 7.17 2,291.38 MWD (6) 8,33240 8677 29.98 6,64972 6,547.72 3,075.17 -683.35 5,972,71706 549,491.30 6.12 2,321.50 MWD (6) 8,362.64 84.92 28.51 6,651.91 6,549.91 3,101.48 -668.62 5,972,743.47 549,505.86 7.81 2,351.65 MWD(6) 8,392.33 84.99 26.43 6,654.53 6,552.53 3,127.72 -654.97 5,972,769.79 549,519.32 6.98 2,381.20 MM (6) 8,422.60 65.82 24.47 6,656.95 6,554.95 3,154.96 -642.01 5,972,797.12 549,532.10 7.01 2,411.27 MN/D(6) 8,452.79 88.04 22.52 6,658.57 6,556.57 3,182.61 -629.99 5,972,824.84 549,543.93 9.78 2,44122 MWD (6) 8,481.67 89.08 21.02 6,659.29 6,557.29 3,209.42 -619.28 5,972,85172 549,554.46 6.32 2,469.80 MWD (6) 8,512.92 89.88 20.05 6,659.58 6,557.58 3,238.68 -608.32 5,972,881.05 549,565.22 4.02 2,50062 MWD (6) 8,53954 90.52 2160 6,65948 6,55748 3,263.56 59886 5,972,90599 549,574.52 6.30 2,526.90 MWD (6) 8,570.31 90.06 23.34 6,659.33 6,557.33 3,291.99 -587.10 5,972,934.50 549,586.09 5.85 2,55740 MWD (6) 8,599.56 89.94 24.64 6,659.33 6,557.33 3,318.72 -575.21 5,972,96130 549,59780 4.46 2,586.49 10 D(6) 8,63097 89.51 2821 6,65948 6,55748 3,346.84 -56123 5,972,989.52 549,611.59 1145 2617.83 MWD (6) Survey End Date 1/23/2019 1/2312019 1/2612019 1/27/2019 1/29/2019 Annotation TIP KOP 2/142019 8,49 59AM Page 3 COMPASS 5000.14 Build 850 ConocoPhillips Company ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit Site: Kuparuk 1B Pad Well: 1B-16 Wellbore: 1 B-16ALl Design: 1B-1 BALI ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1B-16 '1 B-16 @ 102.00usft(1 B-16) 1 B-16 @ 102.00usft (1 B-16) True Minimum Curvature EDT 14 Alaska Production 1 Survey ._ t i i Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +EI -W Northing Easting DLS Section cti (usft) (°) 1°) (usft) (usft) (usft) (usft) (°/100') Survey Tool Name (ft) (g) 8,659.73 89.08 30.56 6,659.83 6,557.83 3,371.90 -547.12 5,973,014.66 549,625.53 8.31 2,646.59 MWD (6) 8,691.37 87.63 30.89 6,660.74 6,55874 3,393.08 -530.96 5,973041.95 549,641.50 4.70 2,678.21 MWD (6) 8,720.62 88.19 33.52 6,661.81 6,559.81 3,423.81 -515.39 5,973,066.79 549,656.91 9.19 2,707.42 MWD (6) 8,750.66 87.73 35.13 6,662.88 6,560.88 3,448.61 498.46 5,973,091.69 549,673.67 5.57 2,737.35 MWD(6) 8,780.63 87.54 37.28 6,664.11 6,562.12 3,472.77 -480.77 5,973,115.97 549,691.19 7.20 2,767.12 MWD (6) 8,811.45 88.80 35.60 6,665.10 6,563.10 3,497.55 -462.48 5,973,14086 549,709.32 6.81 2,797.73 MWD (6) 8,841.33 90.37 34.89 6,665.32 6,563.32 3,521.95 -44524 5,973,165.38 549,726.40 577 2,827.48 MAD (6) 8,870.96 92.43 33.70 6,664.59 6,562.59 3,546.42 -028.55 5,973,189.96 549,742.92 8.03 2,857.01 MWD (6) 8,901.30 95.04 33.33 6,662.62 6,560.62 3,571.66 411.83 5,973,21531 549,759.47 8.69 2,88723 MM (6) 8,930.61 94.39 32.09 6,660.21 6,558.21 3,596.24 396.05 5,973,23999 549,775.08 476 2,916.41 MWD(6) 8,960.66 93.59 3x82 6,658.12 6,556.12 3,621.81 -38940 5,973,26566 549,790.55 4.99 2,996.37 MM (6) 8,990.62 93.66 29.41 6,656.22 6,554.22 3,64767 -W5.40 5,973,29162 549,805.38 4.70 2,976.27 MWD (6) 9,020.84 93.25 27.10 6,654.40 6,552.40 3,67424 -351.12 5,973,318.28 549,819.48 7.75 3,006.42 MWD (6) 9,051.22 9242 24.94 6,652.90 6,550.90 3,701.50 -337.81 5,973,345.63 549,832.61 7.61 3,036.69 MWD(6) 9,080.61 92.18 23.50 6,651.72 6,54972 3,728.29 -325.77 5,973,372.49 549,844.47 4.% 3,065.91 MWD (6) 9,11905 91.% 21.13 6,65065 6,59865 3,755.50 -314.60 5,973,39978 549,855.46 8.08 3,095.06 MWD (6) 9,140.83 90.64 20.06 6,649.96 6,547.96 3,784.31 -303.77 5,973,428.65 549,866.09 5.52 3,125.42 MM (6) 9,171.03 88.13 19.98 6,65028 6,54828 3,812.68 -293.43 5,973,457.09 599,876.24 8.32 3,155.16 MWD (6) 9,199.73 85.76 19.81 6,651.81 6,549.81 3,839.62 -283.68 5,973,484.10 549,885.81 8.28 3,183.37 MWD(6) 9,230.20 85.11 18.91 6,654.23 6,552.23 3,868.28 -273.61 5,973,512.82 549,895.68 3.64 3,213.22 MM (6) 9,261.56 84.10 17.17 6,657.18 6,555.18 3,897.96 -263.95 5,973,542.56 549,905.15 6.39 3,243.76 MM (6) 9,291.25 84.06 15.05 6,660.25 6,558.25 3,926.33 -255.75 5,973,570.98 549.913.16 7.07 3,272.43 MWD(6) 9,322.34 8573 14.11 6,66381 6,561.01 3,956.30 -247.95 5,973,601.00 549,920.75 6.17 3,302.28 MWD(6) 9,351.83 87.20 12.80 6,664.83 6,562.83 3,984.93 -241A0 5,973,629.67 549,927.41 667 3,330.49 MWD (6) 9,381.73 88.65 12.40 6,665.91 6,563.91 4,014.09 -234.59 5,973,65887 549,933.73 5.03 3,359.01 MM (6) 9,411.01 88.46 9.77 6,666.65 6,564.65 4,042.81 -228.96 5,973,687.62 549,939.16 9.00 3,366.69 MWD(6) 9,440.77 88.89 8.24 6,667.35 6,565.35 4,072.19 -224.30 5,973,71703 549,943.62 5.30 3,414.47 MWD (6) 9,470.83 $a m 7.55 6,668.09 6,566.09 4,101.96 -220.17 5,973,746.82 549,947.55 2.83 3,492.31 MM (6) 9,501,66 87.63 5.75 6,669.18 6,567.18 4,132.56 -216.61 5,973,77745 549,950.91 6.27 3,470.60 MM (6) 9,531.34 87.51 3.84 6,670.43 6,568.43 4,162.11 -214.13 5,973,80701 549,953.20 6.44 3,49743 MWD (6) 9,56167 86.58 141 6,671.97 6,569.97 4,192.36 -212.74 5973,83727 549,954.38 846 3,52432 MWD (6) 2114/2019 8:49:59AM Page 4 so Annotation COMPASS 5000.14 Build 85D ConocoPhillips Company: ConocoPhillips Alaska Inc_Kuparuk " Project: Kuparuk River Unit Site: Kuparuk 1B Pad Well: 113-16 Wellbore: 1B-16AL1 s Design: 1B-16AL1 Survey Well 1B-16 MD Inc (usft) 1°) 9,595.74 86.44 9,620.05 86.62 9,650.50 85.58 9,693.00 85.58 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: Well 1B-16 TVD Reference: 18-16 Q 102.00usft(1 B-16) MD Reference: 1 B-16 @ 102.00usft (18-16) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production n.. (ER �UGHEB 21142019 8:49:59AM Page 5 COMPASS 5000.14 Build 85D Map Map Vertical Azi TVD TVDSS +NI -S +El -W Northing Easting DLS Section - (°1 (usft) (usft) (usft) )usft) (°1100') Survey Tool Name Annotation (ft) (ft) (ft) 5.95 6,674.02 6,572.02 4,226.29 -210.56 5,973,871.21 549,956.34 13.32 3,554.80 MWD (6) 742 6,67549 6,573.49 4,250.39 -207.73 5,973,895.33 549,959.00 6.08 3,577.08 MWD(6) 8.90 6,677.56 6,575.56 4,280.46 -203.42 5,973,925.42 549,963.11 5.93 3,605.28 MWD (6) 8.90 6,680.84 6,578.84 4,322.33 -196.87 5,973,967.32 549,969.38 0,00 3,644.81 PROJECTED to TD 21142019 8:49:59AM Page 5 COMPASS 5000.14 Build 85D BA ER BAT a GE company Date: February 25, 2019 Abby Bell AOGCC 333 West 7`" Ave, Suite 100 Anchorage, Alaska 99501 2.18155 30406 Letter of Transmittal Harvey Finch Baker Hughes, a GE Company 795 East 94`" Avenue Anchorage, Alaska 99515 find enclosed the directional survey data for the following well(s): IB -16A 1B-16AL1PB1 1 B-16AL1 RECEIVED ECD FEB 2 6 2019 AOGCC (3) 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. Harvey Finch, Baker Hughes, Wellplanner Harvey.Finch@BakerHughes.com 2 18 156 30406 ConocoPhillips ConocoPhillips Alaska lnc_Kuparuk Kuparuk River Unit Kuparuk 1B Pad 1B-16ALIPB1 50-029-22457-71 Baker Hughes INTEQ BAi-�`UGHES a GE company Definitive Survey Report 14 February, 2019 ConocoPhillips Company: ConocoPhillips Alaska Inc—Kuparuk 4. Project: Kuparuk River Unit Site: Kupamk 1 B Pad Well: 1B-16 Wellbore: 1B-16AL1 PB1 Design: 1B-16AL1PB1 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 18-16 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: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 1B-16ALl For Magnetics Model Name Sample Date BGGM2018 2/1/2019 Design 1B-16AL1PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section Depth From (TVD) (usft) 102.00 Well 1 B-16 18-16 @ 102.00usft(1B-16) 1B-16 @ 102.00usft(113-16) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,969,646.63usft 550,195.14usft usft Declination N 16.78 Tie On Depth: 7,205.27 +N/ -S (usft) 0.00 TUG ES Latitude: 70° 19'40,243 N Longitude: 149° 35'34.518 W Ground Level: 0.00 usft Dip Angle Field Strength - (°) (nT) 80.88 57.428 m�t w Y E P +EI -W Direction (usft) N 0.00 30.00 2114/2019 8:5038AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips BA U R V�t!E ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska lnc_Kuparuk Local Co-ordinate Reference: Well 1B-16 l Project: Kupamk River Unit Map TVD Reference: 1 B-16 @ 102.00usft (18-16) I Site: Kupamk 1 B Pad Azi MD Reference: 1 B-16 @ 102.00usft (18-16) +N/ -S +E/ -W Well: 1B-16 DLS North Reference: True (usft) Wellbore: 1B-16ALl PB1 (usft) Survey Calculation Method: Minimum Curvature (usft) Design: 1 B-16ALl PB1 Database: EDT 14 Alaska Production ---------- ....................a.._..,_..._..._...._._...__..,....,_......,.____.........W._......._,...,.._._..__...v.....,..._.._.... .... ,..,.__._.____.._.»..__®_..�....___._d_. (ft) (ft) Survey Program (ft) Date 2/13/2019 7,205.27 84.68 306.54 From To 2,146.14 -1,161.85 5,971784 .94 Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Data End Date 193.59 6,823.00 1B-16(1 B-16) MWD MWD -Standard 8/25/2000 1,284.17 7,026.00 7,114.59 1B -16A MWD -INC (I B-1 6A) MWD -INC -ONLY MWD -INC -ONLY -FILLER 1/23/2019 1/23/2019 ! 7,145.11 7,205.27 1B -16A MWD (1 B-1 6A) MWD MWD - Standard 1/23/2019 1/23/2019 7,234.05 7,234.05 1B-16AL1PB1 MWD-INC(1B-16AL1PB1 MWD -INC -ONLY MWD -INC -ONLY -FILLER 1/26/2019 1/26/2019 7.264.61 8,850.30 1B-16AL1PBI MWO(1B-16AL1PB1) MWD MWD -Standard 1/27/2019 1/27/2019 I Survey 2/142019 8'50:38AM Page 3 COMPASS 5000 14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) V) 0 (usft) (usft) (usft) (usft) (°1100') Survey Tool Name Annotation (ft) (ft) (ft) 7,205.27 84.68 306.54 6,697.85 6,595.85 2,146.14 -1,161.85 5,971784 .94 549,019.07 47.77 1,277.68 MWD (3) TIP/KOP 7,234.05 87.78 319.60 6,699.75 6,597.75 2,16571 -1,182.78 5,971,804.37 548,998.02 46.54 1,284.17 MWD-INC_ONLY (4) Interpolated Azimuth 7,264.61 93.53 333.44 6,699.40 6,597.40 2,191.12 -1,199.59 5,971,829.67 548,981.04 49.02 1,297.77 MWD (5) 7,295.40 95.07 343.12 6,697.09 6,595.09 2,21961 -1,210.94 5,971,858.07 548,969.50 31.75 1,316.77 MWD (5) 7,328.63 95.91 356.34 6,693.89 6,591.89 2,252.06 -1,216.83 5,971,890.50 548,963.39 39.68 1,341.95 MAID (5) 7,358.85 95.72 6.83 6,690.82 6,588.82 2,282.09 -1,216.00 5,971,920.52 548,964.02 34.54 1,368.35 MWD (5) 7,388.56 94.61 16.57 6,688.14 6,586.14 2,311.03 -1,210.00 5,971,94949 548,969.82 32.86 1,396.41 MWD (5) 7,418.54 93.56 27.31 6,686.00 6,584.00 2,338.73 -1,198.84 5,971,977.26 546,980,80 35.90 1,425.98 MWD(5) 7,441.16 89.11 33.46 6,665.47 6,583.47 2,358.22 -1,18741 5,971,996.82 548,992.09 33.55 1,446.57 MWD (5) 7,460.52 87.45 40.39 6,686.05 6,584.05 2,373.68 -0,17579 5,972,012.36 549,003.61 36.79 1467.77 MWD (5) 7,490.51 87.39 42.16 6,687.40 6,585.40 2,396.20 -1,156.03 5,972,035.01 549,023.22 5.90 1,497.15 MWD (5) 7,52065 88.07 46.71 6688.60 6,586.60 2,417.69 -1,134.95 5,972,056.64 549,044,15 15.25 1,526.31 MWD(5) 7,550.59 87.73 49.37 6,689.70 6,58270 2,437.70 -1,112.71 5,972,076.79 549,066.26 8.95 1,55435 MAID (5) 7,580.25 89.08 50.16 6,690.52 6,588.52 2,456.85 -1,090.07 5,972,096.09 549,088.76 527 1,582.66 MAID(5) 7,611.10 92.43 5020 6,690.11 6,588.11 2,476.60 -1,066.38 5,972,116.00 549,112.32 10.86 1,611.61 MAD (5) 7,641.59 93.04 50.15 6,688.66 6,586.66 2,496.10 -1,042.99 5,972,135.66 549,135.57 2.01 1,640.19 MAID (5) 7,669.30 90.25 51.04 6,687.86 6,585.86 2,513.68 -1,021.59 5,972,153.38 549,156.85 10.57 1,666.12 MWD (5) 7,700.01 89.66 48.59 6,687.89 6,585.89 2,533.50 -998.13 5,972,17335 549,180.18 8.21 1,695.01 MAD (5) 7729.79 89.66 44.85 6,688.07 6,586.07 2.553.91 -976.46 5.972,193 90 549201 71 12.56 1,723.52 MAID (5) 2/142019 8'50:38AM Page 3 COMPASS 5000 14 Build 85D ConocoPhillips B (,e,a. ,. a J,G,H,ES ConocoPhillips Definitive Survey Repo Company: ConocoPhillips Alaska In_Kuparuk.,___._., Local Co-ordinate Reference: Well 1B-16 Project: Kuparuk River Unit TVD Reference: 1B-16 @ 102.00usft (18-16) Site: Kuparuk 1B Pad MD Reference: 1B-16 @ 102.00usft (1B-16) Well: 1B-16 North Reference: True Wellbore: 1B-16AL1 PB1 Survey Calculation Method: Minimum Curvature Design: 1 B-16AL1 PB1 Database: EDT 14 Alaska Production Survey 2114/2019 8:50:36AM Page 4 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +N7 -S +El -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (%100' ) Survey Too[ Name Annotation (ft) (ft) (ft) 7,760.43 90.86 42.33 6,687.93 6,585.93 2,576.10 -955.33 5,972,216.23 549222,69 9.11 1,753.30 MWD (5) 7,790.22 90.34 36.69 6,687,61 6,585.61 2,599.07 -935.39 5,972,239.33 549,241.47 19.01 1,782.67 MWD (5) 7,820.09 90.52 33.89 6,687.39 6,5155.39 2,623.45 -919.14 5,972,263.82 549,258.56 9.39 1,812.41 MWD (5) 7,1551.67 91.81 30.76 6,686.75 6,584]5 2,650.13 -902.26 5,972,29&60 549,275.26 10.72 1,84395 MWD (5) 7,879.94 94.15 28.42 6,685.28 6,583.28 2,674.67 -888.32 5,972,315.24 549,289.04 11.70 1,872.18 MWD (5) 7,909.69 96.34 26.64 6,682.56 6,580.56 2,700.94 -874.62 5,972,341.60 549,302.55 9.47 1,901.77 MWD (5) 7,940.67 9563 2523 6,679.33 6,577.33 2,728.65 -861.15 5,972,369.39 549,315.84 5.07 1,932.50 MW (5) 7,979.35 90.74 2534 6,677.18 6,575.18 2,763.56 -844.66 5,972,404.41 549,332.10 12.65 1,970.98 MWD (5) 8,012.65 91.75 25.27 6,676.46 6,574.46 2,79366 -830.43 5,972,434.60 549,346.12 3.04 2,004.16 MWD (5) 8,040.91 94.33 25.32 6,674.96 6,572.96 2,819.17 -818.37 5,972,460.19 549,358.01 9.13 2,032.28 MWD (5) 8,07149 97.27 25.76 6,671.87 6,569.87 2,846.62 -805.26 5,972,487.72 549,370.94 9.72 2,062.61 MWD (5) 8,100.83 99.91 24.85 6,66249 6,56549 2,872.84 -792.86 5,972,514.02 549,383.16 9.51 2,091.52 MWD(5) 8,131.19 100.23 25.72 6,662.18 6,560.18 2,899.87 -780.09 5,972,541.13 549,39574 3.01 2,121.31 MWD (5) 8,161.13 100.79 28.37 6,655.71 6,564.71 2,926.08 -766.71 5,972,567.44 549,408.95 890 2,150.71 MWD (5) 8,190.47 101.28 30.59 6,651.10 6,549.10 2,951.15 -752.54 5,972,592.59 549,422.95 7.61 2,179.50 MWD (5) 8,221.56 99.42 31.36 6,645.51 6,543.51 2,977.37 -736.80 5,972,618.92 549,438.52 6.46 2,210.08 MM (5) 8,250.76 96.74 31.96 6,641.41 6,539.41 3,001.98 -721.62 5,972,643.62 549,453.52 940 2,238.98 MM (5) 8,279.91 95.75 3104 6,638.24 6,536.24 3,026.68 -706.48 5,972,66843 549,468.49 4.62 2,267,94 MWD (5) 8,310.15 94.45 26.76 6,635.55 6,533.55 3,053.05 -691.93 5,972,69488 549,482.87 14.74 2,29805 MWD (5) 8,340.39 95.98 24.38 6,632.80 6,530.80 3,080.21 -678.93 5,972,722.13 549,495.68 9.33 2,32807 MWD(5) 8,370.53 98.42 22.15 6,629.02 6,527.02 3,107.68 -667.12 5,972,749.67 549,507.31 10.93 2,357.76 MWD (5) 8,400.25 97.74 20.39 6,624.84 6,522.84 3,135.10 856.45 5,972,777.16 549,517.80 6.29 2,38685 MWD (5) 8,430.39 9582 21.30 6,621.29 6,519.29 3,163.06 845.80 5,972,805.20 549,528.26 7.04 2,416.39 VIM (5) 8,459.67 93.35 22.18 6,618.95 6,516.95 3,190.17 834.99 5,972,832.37 549,538.89 8.95 2,445.27 VIM (5) 8,489.35 90.74 22.81 6,617.89 6,515.89 3,217.57 823.64 5,972,859.85 549,550.05 9.05 2,474.68 MM (5) 8,521.37 8831 24.06 6,61815 6,516.15 3,246.95 610.91 5,972,88930 549,562.58 8.53 2,506.49 MWD (5) 8,549.94 86.00 24.68 6,619.57 6,51757 3,272.94 -599.14 5,972,915.37 549,574.18 8.37 2,534.88 MWD (5) 8,579.89 83.72 26.49 6,622.25 6,520.25 3,299,84 -586.26 5,972,942.35 549,586.88 9.70 2,564.62 MWD (5) 8,609.65 82.36 27.77 6,625.86 6,523.86 3,326.13 -572.79 5,972,968.73 549,600.17 6.25 2,594.12 MWD (5) 8640.11 8249 29.50 6,629.87 6,527.88 3,352.63 -558.32 5,972,995.32 549,614.46 565 2,624.30 MWD(5) 8,669.64 85.72 32.10 6,632.91 6,530.91 3.377.85 -543.28 5,973,020.65 549,629.33 14.01 2,653.67 MWD (5) 2114/2019 8:50:36AM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips BA ER F UGHtS ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 1B-16 F' Project: Kuparuk River Unit ND Reference: 1 B-16 @ 102.00usft (1 B-16) Site: Kuparuk 1 B Pad MD Reference! 1 B-16 Q 102.00usft (1 B-16) , Well: 1B-16 North Reference: True Wellbore: 1B-16AL1PB1 Survey Calculation Method: Minimum Curvature Design: 1 B-16AL1PB7 Database: EDT 14 Alaska Production Survey� _._.w_m_.,,.,...�., _____®..-_.a..... ®............. Map Map Vertical ` MD Inc Aid TVD TVDSS -NI-S +E/ -W Northing Easting OLS Section Survey Tool Name Annotation (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) 8,699.57 85.92 34.18 6,635.09 6,533.09 3,40285 -526.96 5,973,045.75 549,645.48 6.96 2683.47 MWD (5) 8,72943 85.12 33.02 6,637.42 6,535.42 3,427.69 510.49 5,973,070.65 549,661.79 4.71 2,713.18 MWD (5) 8,760.66 I 84.81 31.37 6,690.16 6,538.16 3,453.97 493.91 5,973,097.08 549,678.18 5.36 2,744.27 MViD(5) i 8,790.49 86.13 28.76 6,642.52 6,540.52 3,419.70 479.02 5,973,122.91 549,692.90 9.78 2,174.00 MWD (5) 8,620.03 86.38 26.05 6,644.45 6,542.45 3,505.87 465.45 5,973,149.16 549,706.29 9.19 2,803.45 MWD (5) 8,850.30 87.33 24.55 6,646.11 6,544.11 3,533.19 452.53 5,973,176.57 549,719.02 5.86 2,833.57 MWD (5) 8,886.00 87.33 24.55 6,647.77 6,545.77 3,56563 437.72 5,973,209.10 549,733.62 0.00 2,869.07 PROJECTED to TD 21142019 8:50:38AM Page 5 COMPASS 5000.14 Build 85D THE STATE OfALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU IB-16AL1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-156 Surface Location: 501' FNL, 244' FEL, SEC. 9, TI IN, RI OE, UM Bottomhole Location: 1321' FNL, 386' FEL, SEC. 4, Tl IN, R1OE, UM Dear Mr. Ohlinger: 333 West Seventh Avenge Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .00gcc.alaska.gov Enclosed is the approved application for the permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 218-155, API No. 50-029-22457-01- 00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Hollis S. French k( Chair DATED this .(O— day of December, 2018. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2n AAC 2'.005 RECEIVED NOV 2 6 2018 1a. Type of Work: Drill El Lateral • El Redrill ❑ Reentry ❑ I tb. Proposed Well Class: Exploratory - Gas Service - WAG ❑ Service - Disp ❑ Stratigraphic Test r-1Development- Oil Q ' Service - Winj ❑ Single Zone ❑� Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ tc. Specify if is a or Coalbed Gas Gas Hy rates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q • Single Well ❑ 11. Well Name and Number: ConomPhillips Alaska, Inc. Bond No. 5952180 KRU 1B-16AL1 - 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 9900' • TVD,$5 6540' Kupamk River Pool / River Oil Pool ' 4a. Location of Well (Governmental Section): 7. Property Designation:Kuparuk L7.1 Surface: 501' FNL, 244' FEL, Sec 9, T11 N, R10E, UM ADL 25648 it 8. DNR Approval Number: 13. Approximate Spud Date: Top of Productive Horizon: 1661' FSL, 1425' FEL, Sec 4, T11 N. R1 DE, UM LONS 79-016 12/3/2018 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 1321' FNL, 386' FEL, Sec 4, T11 N, R10E, UM 2560 16,050' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 102 15. Distance to Nearest Well Open Surface: x- 550195. y- 5969647 Zone- 4 GL / BF Elevation above MSL (ft): 61 to Same Pool: 985' (1 B-09) 16. Deviated wells: Kickoff depth: 7250 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 103 degrees Downhole: 3513 • Surface: 2883 ' 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling I Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST -L 2860' 7D40' 6498' 9900' 6540' Slotted 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 7450 6991 N/A 7240 6790 N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 121' 16" 200 sx ASI 121' 121' Surface 4423' 9-5/8" 1000 sx ASIII, 420 sx Class G 4423' 4163' Production 7438' 7" x 5" 350 sx Class G 7438' 6979' Perforation Depth MD (ft): 6778-6838, 6900-6908, 6918-6926, Perforation Depth TVD (ft): 6354-6410, 6468-6476, 6485-6493, 6680-6712 7124-7158 5839'- 5852' 1 Hydraulic Fracture planned? Yes ❑ No 7 - 20. Attachments: Properly Plat ❑ BOP Sketch Drilling Program e Shallow Hazard v. Depth am ot Divysis er Sketch B Seabed Report Bi Drilling gFluid Progre✓ 20 AAC 25.050 requ emlentsB 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: William Long Authorized Name: James Ohlinger Contact Email: WIIIiam.R.Lon COP.com Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4372 Authorized Signature: Date: �� G Commission Use Only Permit to Drill Z/&- �/ Number: �`''fP API Number: ^7 �/ 50-fj z,_` '4�.T 57-�-� Permit Approval Date: See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: . Samples req'd: Yes ❑ Noy Mud log req'd: Yes ❑ JJoa t9 OR 1-rs/- 1d 3Sao 32 Lr�✓ `7 z5 measures: Yes No[--] Directional svy req'd: Yes No❑ ffnnvla✓ r -e- �y� -lA- l Z /�� Spacin exception req'd: Yes ❑ Nog Inclination -only svy req'd: Yes[:] No r[,/�� f% ✓4 ty Q iV ('G fo .L2DAfjC? 5. UI .SZ�� L�^ / Post initial injection MIT req'd: Yes ❑ NO L_I l.S 9iAY1tfd �-o allow felt kl C.f 077 ZJ07i7"� 6C olH y Pn l i-l'f" ado �-1 g 7`"h t t7q ri'✓� f ll"a J 0 i APPROVED BY %'L- I I Approved by: COM IS 10 T E COMMISSION Date: Submit Form and Form 10-401 Revised 5/2077 � , Th s permit is valid for 24 i t al per 20 AAC 25.005(8) Attachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 26, 2018 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner ConocoPhillips Alaska, Inc. hereby submits sundry application to set a whipstock and applications for permits to drill two laterals out of the KRU 1 B-16 (PTD# 194-037) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in December 2018. The objective will be to drill two laterals KRU 1 B - 16A and 1B-16AL1 targeting the Kuparuk A -sand interval. The CTD completion is planned to isolate the 1 B-16 perforations mechanically. ConocoPhillips requests a variance to the requirements of 20 AAC 25.112(c) for the alternate plugging method to isolate/abandon 1 B-16 with a swell packer and liner -top packer in the final lateral CTD completion. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to the sundry application are the following documents: - 10-403 Sundry Application for KRU 1 B-16 - Operations Summary in support of the 10-403 sundry application - Proposed CTD Schematic - Current Well Bore Schematic Attached to permit to drill applications are the following documents: - Permit to Drill Application Forms (10-401) for 1 B -16A and 1 B-16AL1 - Detailed Summary of Operations - Directional Plans for 1 B -16A and 1 B-16AL1 - Current wellbore schematic - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, Keith Herring Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 1 B-1 6A and 1 B-16AL1 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b))...................................................................................................................2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)).................................................................................................................................................. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3))............................................................. _... ..................... ............ .......... ...... ..........._................. 2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5))..................................................................................................................................................2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 7. Diverter System Information..........................................................................................................3 (Requirements of 20 AAC 25.005(c)(7)).........................................................................................................-.......................................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................4 11. Seabed Condition Analysis............................................................................................................4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................5 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 6 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 1 B -16A and 1 B-16ALl laterals................................................................................6 Attachment 2: Current Well Schematic for 1 B-16............................................................................................................6 Attachment 3: Proposed Well Schematic for 113-16A and 1 B-16ALl laterals..................................................................6 Page 1 of 6 November 26, 2018 PTD Application: 1B -16A& 1 B-16AL1 1. Well Name and Classification (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b)) The proposed laterals described in this document are 1113-116A and 1 B-16AL1. The laterals will be classified as "Development -Oil" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1 B -16A and 1 B-16AL1. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. Using the maximum formation pressure in the area of 3513 psi at the datum in 1A -04A (i.e. 10.7 ppg EMW), the maximum potential surface pressure in 113-16, assuming a gas gradient of 0.1 psi/ft, would be 2883 . psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. - The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 1 B-16 was measured to be 2607 psi at the datum (8.0 ppg EMW) on 7/7/2016. The maximum downhole pressure in the 1 B-16 vicinity is the 1A -04A at 3513 psi at the dataum (10.7 ppg EMW) measured on 7/10/2017. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injection wells to 1 B-16 have injected gas, so there is a possibility of encountering free gas while drilling the 1 B-16 laterals. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 1 B-16 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 1 B-16 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 November 26, 2018 PTD Application: 1B -16A& 113-16AL1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 16" 62.5 H-40 WELDED 41' 2-3/8" 4.7#1 L-80, ST -L slotted liner; 1B -16A 7250 9300 6612 6532 alumin, um billet on to 40 L-80 BTC 40.8' 4423' 2-3/8", 4.7#, L-80, ST -L slotted liner; 1 B-16ALl 7040 . 9900 6498 6540 with seal bore deployment sleeve on L — BTC MOD 38.9' 7438' 38.9' to Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 WELDED 41' 121' 41' 121' 1640 670 Surface 9-5/8" 40 L-80 BTC 40.8' 4423' 40.8' 4163' 5750 3090 Production 7" x 5" 26 L-80 BTC MOD 38.9' 7438' 38.9' 6979' 7240 5410 Tubing g 4" x 3-1/2" 11x 9.3 J-55 BTC MOD 38.9' 6704' 38.9' 6286' 6300 5750 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride -based PowerVis mud (8.6 ppg) — Drilling operations: Chloride -based PowerVis mud (8.6 ppg). This mud weight may not hydrostatically overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices described below. r — Completion operations: The well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over -balance and shale 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 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 1 B-16 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 6 November 26, 2018 PTD Application: 1B -16A& 1 B-16AL1 Prr_ssure at the 113-16 Window (7045' MD. 6605' TVD) Using MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations KRU well 1 B-16 is a Kuparuk A and C Sand producer equipped with 4" x 3-1/2" tubing and 7" x 5" production casing. The CTD sidetrack will utilize two laterals to target the A -sands to the north and south of 1 B-16. The laterals will improve recovery and target resource not produced by the existing wellbore. Wireline will set a thru-tubing mechanical whipstock inside the 5" casing at the planned kick off point of 7045' MD pre -rig. CDR3-AC will cut a window in the IB -16 production casing and drill the 113-16A lateral. The lateral will be completed with 2-3/8" slotted liner from TD up to the AL1 lateral kick off point with an aluminum billet for kicking off. The AL1 lateral will be kicked off from the A lateral and drilled to TD. It will be completed with 2-3/8" slotted liner from TD to outside of the window. Solid liner, a swell packer, and a seal bore deployment sleeve with liner top packer will be used to isolate the existing perforations in the 1 B-16 wellbore. The liner top packer will be run with slickline after CDR3-AC has rigged down and moved off. CTD Drill and Complete 1B-16 Laterals: Pre -CTD Work 1. RU Slick -line: Pull K -Valve. Conduct dummy whipstock drift. Install new gas lift design. 2. RU Service Coil: Mill out "D" nipple. 3. RU E -line: Set thru-tubing whipstock in 5" casing. 4. Prep site for Nabors CDR3-AC. Page 4 of 6 November 26, 2018 Pumps On 1.8 bpm) Pumps Off A -sand Formation Pressure 8.0 2706 psi 2706 psi Mud Hydrostatic 8.6 2909 psi 2909 psi Annular friction i.e. ECD, 0.08psi/ft) 564 psi 0 psi Mud + ECD Combined no chokepressure) 3473 psi Overbalanced -767psi) 2909 psi Overbalanced ^203psi) Target BHP at Window 11.8 3991 psi 3991 DSi Choke Pressure Required to Maintain Target BHP 518 psi 1082 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations KRU well 1 B-16 is a Kuparuk A and C Sand producer equipped with 4" x 3-1/2" tubing and 7" x 5" production casing. The CTD sidetrack will utilize two laterals to target the A -sands to the north and south of 1 B-16. The laterals will improve recovery and target resource not produced by the existing wellbore. Wireline will set a thru-tubing mechanical whipstock inside the 5" casing at the planned kick off point of 7045' MD pre -rig. CDR3-AC will cut a window in the IB -16 production casing and drill the 113-16A lateral. The lateral will be completed with 2-3/8" slotted liner from TD up to the AL1 lateral kick off point with an aluminum billet for kicking off. The AL1 lateral will be kicked off from the A lateral and drilled to TD. It will be completed with 2-3/8" slotted liner from TD to outside of the window. Solid liner, a swell packer, and a seal bore deployment sleeve with liner top packer will be used to isolate the existing perforations in the 1 B-16 wellbore. The liner top packer will be run with slickline after CDR3-AC has rigged down and moved off. CTD Drill and Complete 1B-16 Laterals: Pre -CTD Work 1. RU Slick -line: Pull K -Valve. Conduct dummy whipstock drift. Install new gas lift design. 2. RU Service Coil: Mill out "D" nipple. 3. RU E -line: Set thru-tubing whipstock in 5" casing. 4. Prep site for Nabors CDR3-AC. Page 4 of 6 November 26, 2018 PTD Application: 1B -16A & 1B-16AL1 Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1 B -16A Lateral a. Mill 2.80" window at 7045' MD. b. Drill 3" bi-center lateral to TD of 9300' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 7250' MD. 3. 1 B-16AL1 Lateral a. Kick off the aluminum billet at 7250' MD. b. Drill 3" bi-center lateral to TD of 9900' MD. c. Run 2-3/8" slotted liner from TD to outside the window. d. Run swell packer, 2-3/8" solid liner, and seal bore deployment sleeve with top of liner set in the tubing tail. 4. Freeze protect, ND BOPE, and RDMO Nabors CRD3-AC. Post -Rip Work 1. RU Slick -line: Record SBHP, Set Liner Top Packer. 2. Return to production Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA un -deployment, the steps listed above are observed, only in reverse. Liner Running — The 1 B-16 laterals will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids' section for more details. — While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. Page 5 of 6 November 26, 2018 PTD Application: 1B -16A& 1 B-16AL1 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 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 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1B -16A 18,500' 1B-16AL1 16,050' - - Distance to Nearest Well within Pool Lateral Name Distance Well 1 B -16A 1907' 1 B-02 1 B-16AL1 985' 1 B-09 16. Attachments Attachment 1: Directional Plans for 18-16A and 1B-16AL1 laterals Attachment 2: Current Well Schematic for 18-16 Attachment 3: Proposed Well Schematic for 18-16A and 18-16AL1 laterals Page 6 of 6 November 26, 2018 ConocoPhillips _ConocoPhillips Export Company Kuparuk River Unit Kuparuk 1B Pad IB -16 1 B-16AL1 Plan: 1 B-16AL1_wp03 Standard Planning Report 20 November, 2018 BER HES TGE company `ConocoPhillips Planning Repo A ER ConocoPillips GGEcH ES ompany Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk 1 B Pad Well: 1B-16 Wellbore: 1B-16AL1 Design: 1 B-16AL1_wp03 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well IB -16 Mean Sea Level 1B-16 @ 102.00usft (1B-16) 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 1 B Pad 18-16 Turn Rate Site Position: Northing: 5,969,646.72 usft Latitude: 70° 19'40 290 N From: Map Easting: 549,457.39 usft Longitude: 149° 35'56.057 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.38 ° Well 18-16 Turn Rate Rate Well Position -NIS 0.00 usft Northing: 5,969,646.83 usft Latitude: 70' 19'40.243 N Depth +E/ -W 0.00 usft Easting: 550,195.14 usft Longitude: 149° 35'34.518 W Position Uncertainty (I 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1B-16AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2018 2/1/2019 16.78 80.88 57,428 Design iB-16A1-1_wp03 _ Audit Notes: Version: Phase: PLAN Tie On Depth: 7,250.00 Vertical Section: Depth From (TVD) +N/ -S +EAW Direction (usft) (usft) (usft) (I 000 0.00 0.00 30.00 Plan Sections Build Turn Rate Rate Measured TFO (°/1o0usft) TVD Below (°1100usft) (°) Depth Inclination Azimuth System +N/ -S *EI -W (usft) (I (°1 (usft) (usft) (usft) 7,250.00 98.53 302.11 6,611.58 2,162.46 -1,185.02 7,320.00 96.48 333.83 6,602.20 2,213.36 -1,230.83 7,470.00 87.89 40.90 6,595.73 2,353.48 -1,212.45 7,680.00 87.96 55.61 6,603.38 2,492.83 -1,056.30 8,080.00 101.72 31.08 6,569.18 2,779.17 -784.86 8,230.00 103.34 20.45 6,536.55 2,910.82 -721.29 8,430.00 91.15 27.40 6,511.35 3,091.66 -640.89 8,560.00 83.70 32.63 6,517.18 3,204.00 -576.01 8,860.00 89.75 12.48 6,534.49 3,479.10 -461.92 9,110.00 98.41 27.74 6,516.60 3,712.40 -376.68 9,310.00 89.32 17.06 6,503.10 3,896.46 -300.91 9,510.00 85.75 3.51 6,511.75 4,092.57 -265.28 9,900.00 86.22 30.88 6,539.59 4,460.66 -151.35 Dogleg Build Turn Rate Rate Rate TFO (°/1o0usft) (°/100usft) (°1100usft) (°) 0.00 0.00 0.00 0.00 45.00 -2.92 45.31 91.50 45.00 -5.73 44.71 95.00 7.00 0.03 7.00 90.00 7.00 3.44 -6.13 300.00 7.00 1.08 -7.09 280.00 7.00 -6.10 3.47 150.00 7.00 -5.73 4.03 145.00 7.00 2.02 -6.72 286.00 7.00 3.46 6.11 60.00 7.00 -4.55 -5.34 230.00 7.00 -1.79 -6.78 255.00 7.00 0.12 7.02 90.00 Target 1112012018 6: 18: 59PM . Page 2 COMPASS 5000.14 Build 85D ConocoPhillips BA ` HES Conocoillips Planning Report UER E,alw.pany Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1 B-16 Company: _ConamPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unh MD Reference: 1B-16 @ 102.00usft (18-16) Site: Kuparuk 1B Pad North Reference: True Well: 18-16 Survey Calculation Method: Minimum Curvature Wellbore: 1 B-16AL1 Map Map Design: 1 B-16AL7_wp03 System -NIS Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System -NIS +EI -W Section Rate Azimuth Northing Easting (usft) r) r) (usft) (usft) (usft) (usft) (°1100usft) (`) (usft) (usft) 7,250.00 ' 98.53 302.11 6,611.58 2,162.46 -1,185.02 1,280.23 0.00 0.00 5,971 801 10 548,99580 TIP/KOP 7,300.00 97.30 324.80 6,604.61 2,196.30 -1,220.71 1,291.70 45.00 91.50 5,971,834.70 548,959.88 7,320.00 96.48 333.83 6,602.20 2,213.36 -1,230.83 1,301.41 45.00 94.66 5,971,851.69 548,949.65 End 46 die, Start 7 dis 7,400.00 92.32 9.70 6,595.86 2,290.99 -1,241.99 1,363.06 45.00 95.00 5,971,929.24 548,937.97 7,470.00 87.89 40.90 6,595.73 21353.48 -1,212.45 1,431.95 45.00 97.85 5,971,991.92 548,967.09 3 7,500.00 87.89 43.00 6,596.84 2,375.78 -1,192.41 1,461.28 7.00 90.00 5,972,014.35 548,986.98 7,600.00 87.92 50.01 6,600.50 2,444.52 -1,119.96 1,557.04 7.00 89.92 5,972,083.57 549,058.96 7,680.00 87.96 55.61 6,603.38 2,492.83 -1,056.30 1,630.70 7.00 89.67 5,972,132.30 549,122.29 4 7,700.00 88.66 54.40 6,603.97 2,504.30 -1,039.93 1,648.82 7.00 -60.00 5,972,143.87 549,138.59 7,800.00 92.16 48.34 6,603.25 2,566.69 -961.86 1,741.89 7.00 -59.96 5,972,206.78 549,216.23 7,900.00 95.65 42.25 6,596.43 2,636.82 -890.99 1,838.06 7.00 -60.01 5,972,277.38 549,286.62 8,000.00 99.06 36.09 6,583.62 2,713.65 -828.38 1,935.90 7.00 -60.42 5,972,354.62 549,348.71 8,080.00 101.72 31.08 6,569.18 2,779.17 -784.86 2,014.40 7.00 -61.21 5,972,420.42 549,391.78 5 8,100.00 101.96 29.67 6,565.08 2,796.06 -774.97 2,033.98 7.00 -80.00 5,972,437.37 549,401.56 8,200.00 103.05 22.58 6,543.40 2,883.65 -732.00 2,131.31 7.00 -80.29 5,972,525.24 549,443.94 8,230.00 103.34 20.45 6,536.55 2,910.82 -721.29 2,T60.20 7.00 -81.82 5,972,552.47 549,454.47 6 8,300.00 99.09 22.93 6,522.94 2,974.60 -695.91 2,228.12 7.00 150.00 5,972,616.42 549,479,41 8,400.00 92.98 26.37 6,51243 3,064.92 -654.45 2,327.07 7.00 150.48 5,972,707.00 549,520.27 8,430.00 91.15 27.40 6,511.35 3,091.66 -640.89 2,357.01 7.00 150.65 5,972,733.83 549,533.64 7 8,500.00 87.13 30.21 6,512.40 3,152.97 -607.18 2,426.96 7.00 145.00 5,972,795.36 549,566.94 8,560.00 83.70 32.63 6,517.19 3,204.00 -576.01 2,486.74 7.00 144.96 5,972,846.60 549,597.76 8 8,600.00 84.48 29.93 6,521.31 3,238.00 -555.36 2,526.51 7.00 -74.00 5,972,880.73 549,616.19 8,700.00 86.47 23.20 6,529.21 3,327.12 -510.82 2,625.96 7.00 -73.72 5,972,970.13 549,662.13 8,800.00 88.52 16.50 6,533.59 3,421.03 -476.92 2,724.24 7.00 -73.19 5,973,064.26 549,695.39 8,860.00 89.75 12.48 6,534.49 3,479.10 -461.92 2,782.03 7.00 -72.90 5,973,122.43 549,710.00 9 8,900.00 91.15 14.91 6,534.17 3,517.96 -452.45 2,820.42 7.00 60.00 5,973,161.34 549,719.21 9,000.00 94.64 20.99 6,529.12 3,612.92 -421.71 2,918.02 7.00 60.02 5,973,256.49 549,749.32 9,100.00 98.07 27.13 6,518.04 3,703.62 -381.24 3,016.81 7.00 60.33 5,973,347.46 549,789.17 9,110.00 98.41 27.74 6,516.60 3,712.40 -376.68 3,026.70 7.00 61.01 5,973,356.27 549,793.68 10 9,200.00 94.34 22.91 6,506.61 3,793.21 -338.45 3,115.80 7.00 -130.00 5,973,437.33 549,631.36 9,300.00 89.77 17.59 6,503.02 3,866.92 -303.88 3,214.23 7.00 -130.54 5,973,531.25 549,865.29 9,310.00 89.32 17.06 6,503.10 3,896.46 -300.91 3,223.98 7.00 -130.73 5,973,540.81 549,868.21 11 9,400.00 87.69 10.97 6,505.45 3,983.71 -279.12 3,310.43 7.00 -105.00 5,973,628.19 549,889.40 9,500.00 85.92 4.19 6,511.02 4,082.62 -265.95 3,402.68 7.00 -104.84 5,973,727.18 549,901.91 9,510.00 85.75 3.51 6,511.75 4,092.57 -265.28 3,411.63 7.00 -104.46 5,973,737.13 549,902.52 12 9,600.00 85.77 9.83 6,518.41 4,181.67 -254.86 3,494.00 7.00 90.00 5,973,826.29 549,912.34 9,700.00 85.86 16.85 6,525.72 4,278.65 -231.86 3,589.49 7.00 89.53 5,973,923.42 549,934.68 9,800.00 86.01 23.86 6,532.81 4,372.11 -197.19 3,687.76 7.00 89.02 5,974,017.10 549,968.73 9,900.00 86.22 30.88 6,539.59 4,460.66 -151.35 3,787.37 7.00 88.52 5,974,105.94 550,013.97 Planned TD at 9900.00 11/20/2018 6: 18.59PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips BA_ ICER ConocoPhillips Planning Report HUGHES aGEmmpany Database: EDT 14 Alaska Production Local Coordinate Reference: Well 18-16 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kupawk River Unit MD Reference: IB -16 @ 102.00usft (1 B-16) Site: Kuparuk 1 B Pad North Reference: True Well: 1B-16 Survey Calculation Method: Minimum Curvature Wellbore: 1B-16AL1 -1,185.02 TIP/KOP Design: 1B-16AL1_wp03 2,213.36 -1,230.83 End 45 dis, Start 7 dls 7,470.00 6,595.73 2,353.48 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 9,900.00 6,539.59 2 3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +EAW (usft) (usft) (usft) (usft) Comment 7,250.00 6611.56 2,162.46 -1,185.02 TIP/KOP 7,320.00 6,602.20 2,213.36 -1,230.83 End 45 dis, Start 7 dls 7,470.00 6,595.73 2,353.48 -1,212.45 3 7,680.00 6,603.38 2,492.83 -1,056.30 4 8,080.00 6,569.18 2,779.17 -784.86 5 8,230.00 6,536.55 2,910.82 -721.29 6 8,430.00 6,511.35 3,091.66 -640.89 7 8,560.00 6,517.19 3,204.00 -576.01 8 8,860.00 6,534.49 3,479.10 461.92 9 9,110.00 6,516.60 3,712.40 -376.68 10 9,310.00 6,503.10 3,896.46 -300.91 11 9,510.00 6,511.75 4,092.57 -265.28 12 9,900.00 6,539.59 4,460.66 -151.35 Planned TD at 9900.00 11/20/2018 6: 1859PM Page 4 COMPASS 5000.14 Build 85D `- ConocoPhillips ER ConocoPhillips Travelling Cylinder Report IUGHES aGEcampary Company: ConowPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1B Pad Site Error: 0.00 usft Reference Well: 18-16 Well Error: 0.00 usft Reference Wellbore 1B-16AL1 Reference Design: 1 B-16AL1_wp03 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well IB -16 1B-16 Q 102.00usft(18-16) 18-16 @ 102.00usft(1B-16) True Minimum Curvature 1.00 sigma OAKEDMPI Offset Datum Reference 1B-16AL1_wp03 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 100.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,179.80 usft Error Surface: Pedal Curve Survey Tool Program Date 11/20/2018 From To Reference Offset Centre to No -Go (usft) (usft) Survey(Wellbore) Tool Name Description Measured I 193.59 6,823.00 18-16(16-16) MWD MWD - Standard Depth Depth 6,823.00 7,250.00 1B-16A_wp04(1 B-16A)MWD from Plan MWD - Standard Offset Well - Wellbore - Design (usft) 7,250.00 9,900.00 1B-16AL1_wp03(1 B-1 BALI) MWD MWD -Standard Kupamk 1 B Pad Casing Points Measured Vertical 2,624.12 Casing Hole 61.12 84.86 Depth Depth 18 -05 -1B -05-1B-05 Diameter Diameter 257.26 30.61 (usft) (usft) Name (in) (in) 600.00 140.15 9,900.00 6,641.59 2 3/8' 131.61 2.375 3.000 407.64 Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kupamk 1 B Pad 1B-03-18-03-18-03 2,624.12 2,700.00 130.84 61.12 84.86 Pass - Major Risk 18 -05 -1B -05-1B-05 1,217.25 1,200.00 257.26 30.61 226.80 Pass - Major Risk 1B -06 -1B -06-1B-06 605.47 600.00 140.15 8.54 131.61 Pass - Major Risk 18 -07 -IB -07-1B-07 407.64 400.00 19.16 7.68 11.48 Pass - Major Risk 18 -08 -1B -08-1B-08 507.07 500.00 101.15 7.81 93.34 Pass - Major Risk 18 -08 -1B -08A -1B -08A 508.06 500.00 101.17 7.83 93.34 Pass - Major Risk 1B-08-1B-08AL1-1B-08ALI 508.06 500.00 101.17 7.83 93.34 Pass - Major Risk 18-08 - 18-08AL1-01 - 1B-08ALl-01 508.06 500.00 101.17 7.81 93.36 Pass - Major Risk 1B-08-1B-08AL1-01-1B-08ALl-01 wp07 508.06 500.00 101.17 7.81 93.36 Pass - Major Risk 1B-08-1B-08AL1 PBI -1B-08AL1 Pat 508.06 500.00 101.17 7.83 93.34 Pass - Major Risk 1B -09-1B-09-16-09 9,700.00 8,400.00 985.63 321.43 665.66 Pass - Major Risk 18-1011 - 18-101 - IB -101 313.63 300.00 33.65 4.41 29.23 Pass - Major Risk 1B-101 - 1B-101Ll - 18-1011-1 313.63 300.00 33.65 4.41 29.23 Pass - Major Risk 18-101-18-101PB1-IB-101PB1 313.63 300.00 33.65 4.26 29.39 Pass - Major Risk 1B -102-1B-102-18-102 213.75 200.00 54.87 2.73 52.14 Pass - Major Risk 1 B-11 - 18-11 - 1B-11 2,308.56 2,400.00 207.53 64.07 151.41 Pass - Major Risk 1 B-12 - 18-12 - 1 B-12 499.22 500.00 72.17 9.85 62.32 Pass - Major Risk 18 -12 -Plan: 1B-12A-18-12A(wp01) 499.22 500.00 72.17 9.95 62.22 Pass - Major Risk 1B -14 -1B -14-1B-14 1,827.64 1,800.00 194.28 41.98 152.35 Pass - Major Risk 1 B-15 - 1 B-15 - 1 B-15 299.41 300.00 241.63 3.22 238.42 Pass - Major Risk 1 B-15 - 1 B -15A- 1 B-1 5A 306.35 300.00 241.71 3.32 238.41 Pass - Major Risk 1B-15-1B-15AL1-1B-15AL1 306.35 300.00 241.71 3.32 238.41 Pass - Major Risk 1 B-15 - 1 B-15AL2 - 1 B-15AL2 306.35 300.00 241.71 3.32 238.41 Pass - Major Risk 1B-15-1B-15AL2P61-IB-15AL2PB1 306.35 300.00 241.71 3.32 238.41 Pass - Major Risk 1B-15-1B-15AL2PB2-1B-15AL2PB2 306.35 300.00 241.71 3.32 238.41 Pass - Major Risk 1B-15-1B-15AL3-1B-15AL3 306.35 300.00 241.71 3.32 238.41 Pass - Major Risk 18-15-1B-15AL3PB1-1B-15AL3PBI 306.35 300.00 241.71 3.32 238.41 Pass - Major Risk IB -16 -1B -16-1B-16 7,167.86 7,200.00 59.48 11.64 52.57 Pass - Major Risk CC - Min centre to center distance or covernent point SF - min separation factor, ES - min ellipse separation 11202018 5:38:33PM Page 2 COMPASS 5000.14 Build 85D Summary ConocoPhillips BAT BA ER ConocoPhillips Travelling Cylinder Report Reference Offset a GE company Company: ConocoPhillips (Alaska) Inc. -Kupl Local CO -ordinate Reference: Well 1B-16 Project: Kuparuk River Unit ND Reference: 1 B-16 @ 102.00usft (1 B-16) Reference Site: Kuparuk 18 Pad MD Reference: 1 B-16 @ 102.00usft (1 B-16) Site Error: 0.00 usft North Reference: True Reference Well: 1B-16 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1B-16AL1 Database: OAKEDMPI Reference Design: 18-16AL7_wp03 Offset TVD Reference: Offset Datum Summary KuparuklBPad- 1B-03-lB-03-1B-03 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Measured Kuparuk 1 B Pad Measured Vertical Reference Offset Idea.ea West WellOore Centre 113-16 - 1 B -16A - 1 B-16A_wp04 Centre to No Go Allowable Warning Depth Out of range 1 B-17 - 1 B-17 - 1 B-17 597.89 600.00 91.23 13.39 77.86 Pass - Major Risk 1 B-17 - 1 B-171_1 - 18-171-7 597.89 600.00 91.23 13.39 77.86 Pass - Major Risk 1B -17 -1B -17L2 -1B-1712 597.89 600.00 91.23 13.39 77.86 Pass - Major Risk 1B -17 -1B -17L2 -01-1B-1712-01 597.89 600.00 91.23 13.39 77.86 Pass - Major Risk 1B -17-1B-1712-01 PB1-1B-1712-01 P61 597.89 600.00 91.23 13.39 77.86 Pass - Major Risk 1B -18 -1B -18-1B-18 399.50 400.00 47.89 4.70 43.20 Pass -Major Risk 1B -18 -1B -18A -1B -18A 399.50 400.00 47.89 4.70 43.20 Pass - Major Risk 1B-18-1B-18ALl-1B-18AL7 399.50 400.00 47.89 4.70 43.20 Pass - Major Risk 1B-18-1B-18AL2-1B-18AL2 399.50 400.00 47.89 4.70 43.20 Pass - Major Risk 18-18-1B-18AL3-1B-18AL3 399.50 400.00 47.89 4.70 43.20 Pass - Major Risk 1B-18-1B-18AL3-01-1B-18AL3-01 399.50 400.00 47.89 4.70 43.20 Pass - Major Risk 1B-18-1B-18AL3PB1-1B-18AL3PB1 399.50 400.00 47.89 4.70 43.20 Pass - Major Risk 1 B-19 - 1 B-19 - 1 B-19 299.64 300.00 108.70 3.31 105.40 Pass - Major Risk 1 B-19 - 1 B-1911 - 1 B-191-1 299.64 300.00 108.70 3.31 105.40 Pass - Major Risk 1B-19-1B-19L1-01-1B-1911-Ot 299.64 300.00 108.70 3.31 105.40 Pass - Major Risk 1B -19 -1B -19L7 -02-1B-191-1-02 299.64 300.00 108.70 3.31 105.40 Pass -Major Risk WSW -01 - WSW -01 - WSW -01 1,216.76 1,200.00 94.51 20.80 73.81 Pass- Major Risk WSW -02 -WSW -02 -WSW -02 1,017.31 1,000.00 110.65 19.06 92.23 Pass - Major Risk WSW -03 -WSW -03 -WSW -03 1,039.07 1,000.00 161.22 19.65 143.20 Pass - Major Risk WSW -04 -WSW -04 -WSW -04 1,315.78 1,300.00 70.13 34.13 36.31 Pass - Major Risk WSW -05 -WSW -05 -WSW -05 1,112.32 1,100.00 185.09 27.64 157.45 Pass - Major Risk WSW -06 -WSW -06 -WSW -06 1,498.98 1,400.00 273.93 33.91 245.36 Pass - Major Risk WSW -08 -WSW -08 -WSW -08 1,472.02 1,400.00 327.81 38.99 288.96 Pass - Major Risk Offset Design KuparuklBPad- 1B-03-lB-03-1B-03 onset sue Error: 0.0 usn survey Program: 100.FINDER-MS Role Asai9ned:Major RSP Offset WellEnon (.Wu50 Reference offset semi Major Asia Measured Vertical Measured Vertical Reference Offset Idea.ea West WellOore Centre Cast,- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth e1,114 -ENA? Nok Was Centre Distance Deviation (uran) Pan) (usft) (uan) lush) Juan) 1'1 (usft) (oan) hot (usft) (usft) (usft) 102.00 102D0 94.00 94.00 0.00 0.00 -69.60 3.46 497.19 3.000 497.20 025 496.95 Pass -Major Risk 107.90 107.90 100.00 100.00 am 0.00 -89so 3.46 -497.19 3.000 497.20 0.33 496.87 Pass -Major Risk 206.51 206.51 200.00 200.00 0.07 0.14 -8sw 3.46 497.19 3.000 497.39 182 49557 Pass - Major Risk 306,68 30868 300,00 300.00 0.18 0.27 -89,02 3.46 497.19 3.000 497.63 3.45 494.17 Pass - Major Risk 405.61 405.47 400.00 400.00 0.30 0.40 -90.37 3.46 -497.19 3.000 496.07 5.10 491 Pass - Major Risk 506.07 505.62 500.00 500.00 0.44 0.53 -91.28 add .497.19 3.000 498.52 6.82 49170 Pass - Major Risk 603.93 602.92 600.00 600.00 0.61 0.67 -92,50 346 -497.19 3.000 499.20 8.58 490.62 Pass - Major Risk 701.08 700.00 700.00 700.00 0.81 0.80 -94.01 3,46 -497.19 3.000 500.58 10.41 490.17 Pass - Major Risk 810.76 807.54 600.00 800.00 1.06 0.93 -95.64 3.95 -496.75 3.000 501.30 12.49 488,83 Pass - Major Risk 950.61 944.56 900.00 899.99 1.43 1.06 -98.40 5.00 -495.98 3.000 496.77 15.17 481.60 Pass -Major Risk 1061.83 1,052.50 1,000.00 999.99 1.78 1.20 -101.07 557 -495.66 3.000 18757 17.54 470.03 Pass -May -Risk 1.158.40 1,145.10 1,100.00 1,099.97 2.15 1.32 -104.00 688 -495.68 3.000 478.87 19.93 450.85 Pass -Major Risk 1,252.68 1.233.82 1,200.00 1,199.93 2.60 1A3 -107.53 9.93 -495.70 3.000 471.21 22.27 448.94 Pass - Major Risk 1345.79 1,319.92 1.301.00 1.299.80 3.11 1.56 -111.63 1435 494.58 3.000 464.40 24.87 439.51 Pass - Major Risk 1,439.82 1,400.42 1,400.00 1,399.43 3.58 1.69 -115.79 22.67 491.51 3.000 457.26 27.44 429.83 Pass - Major Risk 1,535.55 1,494.86 1,500.00 1,498.71 3.97 1.83 -119.67 33.94 407.40 3.000 449.08 29.79 420.15 Pass - Major Risk 1,630.71 1.582.98 1,800.00 1.597.58 4.34 1.97 -123.21 40.36 483.40 3.000 442.74 32.12 410.79 Pass - Major Risk 1,729.65 1.674.63 1.700.00 1,695.81 4.80 2.12 -126.61 66.40 478.67 3.000 434.67 34,71 400.26 Pass - Major Risk CC - Min centre to center distance or covergent point, $F - min separation factor, ES - min ellipse separation 11202018 5:38.33PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips BA ER ConocoPhillips Travelling Cylinder Report I IGHES BAT Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Reference Site: Kuparuk 1 B Pad Site Error: 0.00 usft Reference Well: 18-16 Well Error: 0.00 usft Reference Wellbore 1B-16AL1 Reference Design: 1 B-16AL1_wp03 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 16-16 1B-16(2? 102.00usft (1 8-16) IB -16@! 102.00usft (1 B-16) True Minimum Curvature 1.00 sigma OAKEDMPI Offset Datum Reference 1B-16AL1_wp03 Filter type: NO GLOBAL FILTER: Using user defined selection 8 filtering criteria Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,250.00 to 9,900.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,179.80 usft Error Surface: Pedal Curve Survey Tool Program Date 11/20/2018 From To just) (usft) Survey(Wellbore) Tool Name Description 193.59 6,623.00 18-16 1 B-16) MWD MWD -Standard 6,823.00 7,250.00 1B-16A_wp04(1 B -16A) MWD MWD -Standard 7,250.00 9,900.00 1B-1 GAL7_wp03(1 B -16i MWD MWD -Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name ON (in) 9,900.00 6,641.59 2 3/8" 2.375 3.000 Summary Offew semi Matin Axla Reference Offset Centre to No -Go Allowable Referanw caret Tooaace+ Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Hole Slae Offset Well - Wellbore - Design (usft) just) (usft) Juan) (usft) fuah) Kuparuk iB Pad P) lues) van) (to) loan) iuse) Juah) 1 B-03 - 1 B-03 - 1 B-03 662336 7,600.00 6,12572 45.76 5077 -3926 Out of range 1 B-08 - 1 B -08A- 1 B -08A 1.172.55 271.33 914.25 Paas -Major Risk 9,075.00 6,623.36 Out of range 1 B-08 -I B-08AL7 - 1 B-08ALl 4576 50.93 -40.26 4091.70 -1374.23 3.000 1,16690 Out of range 16-08 - 1 B-08AL7-01 - 1 B-08ALl-01 9084.86 6622.10 765000 6,165.66 4585 51.10 Out of range 1 B-08 - 1 B-08AL1-01 -1 B-OBALl-01 wp07 3.000 1,157.51 271.30 897.08 Pass -Major Risk Out of range 1 B-08 - 18-08AL7 PB1 - 1 B-08AL1 Pat CC - Min centre to center distance or coveroent point, SF - min separation factor, ES - min ellipse separation Out of range 1B -09 -1B -09-1B-09 9,714.32 8,425.00 985.09 321.01 664.84 Pass - Major Risk 1 B-101 - IB -101 - 1 B-101 Out of range 1 B-101 - 18-101 11 - 18-101 L1 Out of range 1 B-102 - 18-102 - 1 B-102 Out of range 1 B-11 - 1 B-11 - 1 B-11 Out of range 1 B-12 - 1 B-12 - 1 B-12 Out of range 1 B-12 - Plan: 1 B -12A- 1 B-1 2A (wp01) Out of range 1 B-14 - 1 B-14 - 1 B-14 Out of range I B-15 - 1 B-15ALi - 1 B-15AL1 Out of range iB-16-1B-16A-18-16A_wp04 7,250.00 7,250.00 0.00 0.50 -0.23 FAIL - Minor 1/10 WSW -03 - WSW -03 - WSW -03 Out of range Offset Design Kuparuk 1 B Pad - 1 B-09 - 1 B-09 - 1 B-09 ansae she Enm: a w uea Survey Program: 10013r GVRG Rule assigned: Major Risk OtraeE Well Error. 000 use Reference Offew semi Matin Axla Measured Vertical Wita d Vesical Referanw caret Tooaace+ Maier Wellbore Care. Casing- CaMre to No Go Allowable Warring Dept, Depth Depth Depth Aaimuth -Ni +E/ -W Hole Slae Centre Dlaunce Deviation feem Juan) tush) fuah) (ush) luau) P) lues) van) (to) loan) iuse) Juah) 9,07500 662336 7,600.00 6,12572 45.76 5077 -3926 4,077.58 -137928 3000 1.172.55 271.33 914.25 Paas -Major Risk 9,075.00 6,623.36 762500 6,145.72 4576 50.93 -40.26 4091.70 -1374.23 3.000 1,16690 271.79 90007 Pass- Major Riak 9084.86 6622.10 765000 6,165.66 4585 51.10 -40.59 4,10583 -1368.98 3.000 1,157.51 271.30 897.08 Pass -Major Risk CC - Min centre to center distance or coveroent point, SF - min separation factor, ES - min ellipse separation 1120/2018 5:39: 26PM Page 2 COMPASS 5000.14 Build 85D COnocoPhiiiips Project: Kuparuk River Unit Site: Kuparuk 1B Pad aeoana w True uenn Natio..11 Isn• uaen=m E,ue WELLBORE DETAILS'. tB-i6Alt REFERENCE INFORWTION Parent Wellbore: 18-1aA Co-emnate (Np Reence. Wer1616,Tnn NUM Well: 18-16 F pafmuk: eoaa• Tie on MD'. ]250.00 vem®I(WD)Re%.- M See Intl section Ws) Remeoe w.(a.wN o.wE) Wellbore: 1B.16AL1 +E/ -W Northing (18 16) Nusu�eca Plan: 18.16AL1_ZO3(1B-t6/iB-i6ALt) j iR°p'i lien Mearo]: FnnWmi�m C... aGEVvn'mm S West( -)Bast(+) (350 us8/in) Mean; Vertical Section at 30.00° (95 usft/in) WELL DETAILS: 16-16 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 5980024.57 549555.22 70° 21'22.356 N 149° 35' 51.196 W Sec AD Inc Azi TVDSS +N / -S + Dleg TFace V ect Annotation 1 7250.00 98.53 302.11 6611.58 2162.46 -1185.02 0.00 0.00 1280.23 TIPIKOP 2 7320.00 96A8 333.83 6602.20 2213.36 -1230.83 45.00 91.50 1301.41 End 45 d1s, Start 7 dls 3 7470.00 87.89 40.90 6595.73 2353.48 -1212.45 45.00 95.00 1431.95 3 4 7680.00 87.96 55.61 6603.38 2492.83 -1056.30 7.00 90.00 1630.70 4 5 8080.00 101.72 31.08 6569.18 2779.17 -784.86 7.00 300.00 2014.40 5 6 8230.00 103.34 20.45 6536.55 2910.82 -721.29 7.00 280.00 2160.20 6 7 8430.00 91.15 27.40 6511.35 3091.66 -640.89 7.00 150.00 2357.01 7 6 8560.00 83.70 32.63 6517.19 3204.00 -576.01 7.00 145.00 2486.74 8 9 8860.00 89.75 12.48 6534.49 3479.10 -061.92 7.00 286.00 2782.03 9 10 9110.00 98.41 27.74 6516.60 3712.40 -376.68 7.00 60.00 3026.70 10 11 9310.00 89.32 17.06 6503.10 3896.46 -300.91 7.00 230.00 3223.98 11 12 9510.00 85.75 3.51 6511.75 4092.57 -265.28 7.00 255.00 3411.63 12 13 9900.00 86.22 30.88 6539.59 4460.66 -151.35 7.00 90.00 3787.37 Planned TD at 9900.00 aGEVvn'mm S West( -)Bast(+) (350 us8/in) Mean; Vertical Section at 30.00° (95 usft/in) Au.w�.mn,�.— WELLBORE DETAILS: 10-16A REFERENCE INFO MATIM Project: Kuparuk River link M.Rr.Iro Mena 1cTr c�rdnele (rvhl RNrelm: M IaIE, 1m . Site: Kuparuk lB PaO wonnr FNu Parent Wellbore: tB-76 vemcal(rvo7 Relaerce: 3&1s®IOt.00u¢n (i&3E) R Well: iBA6 s1,.�Mm. sTm a.^ Te on MD:8823.00 section rys)ReMem. SW (ODDµ O.WQ V F..S .� pVNgb-t0.B9' well Fe:1( 611 WM. YIRIM Measuretlpeplh Re'erema: 1616®tU1.D]usn (I&I6) eGEC0111pert/ ComcoPhillip5 Plan: 1816A_wp0a (1B-16MB•16A) MNH ¢GGMIDt kiN& M[Na Nlnlu Cw lae 10-IIYLI&IU? �` I v2oo 1c.11Rnc-1„ a, 6800 6400 600044 I— to lur. m -Incl 5600 -� T- ..� �_.� s I t.unv.n I Frl l/LR-IJ IIiOs11Rn4 rK 4800 4400 l- a $rp4 -C: 4000 -0R�IGOft1.lAl 3600. _.. C mub I r' 32001 /N � 2400 xl I u-wz uu<wua�r 6 i3 Infl S� _ -oor I r° 111 � ur,or p IbOU� � wH" V3 s. 1100 ,I _ - 1 'LII J'IC �IRIUI/10.1U] % i714 soot —. 1 400. - 11i. bolo 11w194MA1.1111 - - - I 4 r0.11208ALlUl -4ao� n 3Y1 11 n/uilsn �. -soot i %/Ilr-IlTI :' n � In-0&rIaLRA - I.W Ila I:II0.1 �r AI UII . .1700 3i� ' IL p♦1 (I� I II - 11 1'F�11- " I tl -I60I11It� -2000 i,1�' '---`— -0660"-W_Ob-6bW'164t10 -6000 -5600 ,200 4�➢-0400 -0OOU -3600 -3200 800 400 2000 -1600 -1206 800 -000`1 �1 400 800 1200 Io00 2000 400 2800A,3 00 600 4000 4400 4800 5200 5600 IH-3W1&]A la IA1615A ` }l, 113/�11\/113411 Fyy1ll((1s1 11131Ate,.,, ff(}��''11��IN IRAI.31'111 N3Itln13-INN 1 In-IS/10.15ALI .. _. CSt�,a/East(+) l@Y� 11$1Z/11BI�IIf1-INALMI IN{NJI1 6 IW»Ill�r♦, o ... 113-16 @ 102,00ustl (1B-16) KUP PROD @Me ConoeoPhillips Well Attributes IMaxAngle&MD ITD AUE .liC wm,oro APNuwI Fled um, wenho e8lnus 500224570NUPARUK RIVER UNIT PROD nc l'1 mOlnna) 2363 223061 Ad 61m 1X6181 14500 Commenl HOS him.) DM• 398V: TRDP 20 12/2912015 r1nnIXMion EnC Dag• no GN(p) Rlg ReI ONe LaM WD: 41.11 3/2511994 1 O.1E6R ,aIr 1C pre onsed"Imers".01.4 pnnohtlon 0epiM1 lftl(B1 EnJ Deb Mnohlbn tail Matl By EnJ Dah --OESOfETE-IGN0RE00 Lest Taq: SLM ],109.0 8/5/2016 Rev Reawn.TAG,H25 pproven 1 616/2016 NM'GER:399 I asmg ngs easing De•aiplion O0 gn1 ID(n1 top 1X6161 Bet Depth(RON) set Depth(rvDl... WYLen p... Grade Top ThmaE CONDUCTOR i6 15.060 41.0 1210 1214 6250 )NO WELDED Casing onvlpllen Wpn1 IOtlnl et DepIM1 IXKOI Bet Depth TARR.., WIILen D. Gram Top Thrn4 Top 1X6181 -"in' SURFACE 95/8 8.835 400 4' .1 4,164.5 40.00 L-80 BTC casing Descnplian G011nl 1O(nl Top IXKe1 Set Oep,n,,'B) SH Dep1M1,PS,. Witten ll... Grate Tap ihrYtl PRODUCTION ) 6.2]6 389 ]041.1 6.982.5 26 O0 L-80 BTCMOD I 7x5"®6690' Tubing Strings Tuohy ceYripNon sennq Ma... lolls Top NINE) per Depth ln. set Depth IrvD11... W"P Gmae MnnD 11 BTC TUBING 4"x3 5" 4 3 476 38 9 6 ]04 4 6,286 0 11 00 J-55 BTC MOO CONODCTO R: al LL1318 Completion Detags. Nominal to Top IXKBI Tap ORGIeKB) Top Intl V1 IMM Des Com IInI 38.9 38.8 005 HANGER MCEVOY GEN N HANGER 4.000 1.893.1 1.825.3 2123 SAFETY VLV CAMCO TRDP4A SAFETY VALVE 3312 6AFETY NLY. 1 ma.1 4,104.1 3,8869 21.93 XOREDUGing CROSSOVER 4 x 3.5, ID 2.992.09.3.655. SEW EUEBROMOD 66654 6249.7 2161 SEAL ASSY BAKER GBH 82 LOCATOR. 1OSEAL ASSEMBLY 3.000 6,6662 6$50.5 21.61 PACKER BAKER FB- 1 PERMENANT PACKER 4.000 GAs uR:2b2ss 6,6696 62516 21.60 SBE SEAL BORE EXTENSION 4.000 6,68].] 62704 2158 NIPPLE CAMCO D NIPPLE NO GO 2.750 6,7038 6285.2 21.56 SOS CAMCO PE 5O0 SHEAR OUT SUB 3.000 Perforatio sent Den Top(M)e("Nol bhulsrc Gas uFr:4.l saa roplWB),778 a4nRude'BS& In✓s) ZapD. O19 0 Type eom 8.7]8.0 8,838.0 6.356.4 6.3 6410.3 UNIT D. Ga, 11011996 6.0 /PERF 2 de gO deg 43, tB-i6 phasing 45 deg anent rising 6 8,900.0 6,908.0 6,4882 8,475] 61, 1B-166/1012008 86 APERF 2.5' PJ HSD, 6O deg rantlem 6,918.0 6,9260 8,485.1 6,4926 61,18-16 611OPP 6.0 APERF 2.5 -PJ HSD, 6O deg random SURFACE 40s-4.4a.t- 7124.0 7.1560 6.679.6 6111.9 A4,1&16 615/1994 4.0 IPERF 3&8'X60 CSG Guns. 180 deg phasing G`GuD.suDas Mandrel Inserts w I GASUFT:5983.9 on Tap INO) Valve IaMM1 PMSim TRO Run N Tophug NINE) New Ma4eI OD (in) Sery Type Type (in) (psi) Run Dade Com 1 2,623.5 2,698.0 MERIA TMPD 1 GAS LIFT GLV BU 0.156 1.261.0 1/22000 2 4,139.3 SABRE CAMCO KBt1G 1 GAS LIFT GLV SK DABS 1.305.0 1028/1999 3 5.203.5 4,890.2 CAMCO KBUG 1 GAS LIFT OV SK 0250 0.0 1028/1999 GAS LIFL:6.618O 0 5.986.9 56200 CAMCO KBUG 1 GAS LIFE [VY- SK 0.000 0.0 It"4/1999 5 6.619.8 6,20]] CAMCO MMM 11/2 GAS LIFE MY RK 0000 00 8/13/1 geg Notes: General &Safe DEAL ASO 66S.a En4D•de AnnMtlbn 2/2]/2009 NOTE: EST. 132' RATHOLE BELOW BOTTOM PERF POST FCO PACKER, 6a583 eigazu10 NOTE: New scremance/Alaska Sshema11C9.O BRF,B.e8a8 NIPPLE: Sri 08, 505:8,]61.8-1 5:]61.8 IPERF:6.]]1306818.O- APER F; 6.SC0.48,AGE 0- APEAF:891a Oerr IPERF,? Rao] UGO PROWGTION TE -Q 8ay%M3 7,44I.1 IB -16 Proposed CTD Schematic 16"62# H-40 shoe @ 121' MD 9-5/8" 40# L40 shoe @ 4424' MD or., a- 4� C -sand perfs 6778' - 6838' MD 6900'- 6908' M D /(/ L7• �o KOP @ 7045'MD 3-1/2" x 5" TTWS A -sand perfs 7124'- 7158' MD 7" x 5" shoe @ 7441' MD 3-1/2" Cameo TRDP-4A Safety Valve @ 1893' MD Locked Out: 81212017 4" 11# J-55 Tubing 4104' MD to surface Cross-over 4"x3.5" @ 4104' MD 3-1/2" Cameo gas lift mandrels @ 2624', 4139', 5204', 5987', & 6620' MD Baker FBA packer @ 6666' MD (4.0" ID) Baker SBE @ 6670' MD 3-1/2" Cameo D landing nipple @ 6688' MD (2.75" min ID, No -Go) 3-1/2" Cameo SOS @ 6704' MD .. 1-01 wp02 9900' MD'7 (RJT7DP@ Toof Liner @ 6690' MD Wp03 rTD@ 9300' MDt @ 7250' MD Ch 27, /y TRANSMITTAL LETTER CHECKLIST WELL NAME: 4 — /,� Z_ PTD: Development Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: f.vv Get GC /vt�% POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit No. /r° /SSS, API No. 50--O 2Z 45/ 4Z? (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. hi addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements er Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL -490100 Well Name: KUPARUK RIV UNIT 1B-16ALi Program DEV Well bore seg ❑� PTD#: 2181560 Company CONQC9 PHILLIPS ALASKA INC Initial Class/Type DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 17 Nonoonven, gas conforms to AS31.05.03ftl.A),0.2.A-D) . . . . . . ......... . . . . NA. I Permit fee attached_ _ _ ... _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ____________ NA 2 Lease number appropriate_ _ _ _ _ ......... _ _ . Yes Entire Well lies within ADL0025648... 3 Unique well. name and number - - - - - - - - - - - - - - - - - - - ----------------- - - Yes - 4 .Well located ina. defined pool . . . . . . . . . . . . ... . ............. . . . Yes. _ _ _ _ _ KUPARUK RIVER,.KUPARUK.RIV OIL. -490109_ 5 Well located proper distance from drilling unit boundary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _____ Yes _ _ Kuparuk River Oil Pool, govemed by Conservation Order No. 4321) _ 6 Well located proper distance from other wells _ .. _ _ _ _ _ _ _ _ _ _ _ _ . Yes _ _ Conservation Order No. 432D has no interwell_spacing _restrictions. Wellbore will be more than 500' _ 7 Sufficient acreage available in drilling unit...... _ _ _ _ _ .. _ _ _ Yes _ _ _ _ from an external property line where. ownership or landownership changes. As proposed,. well will.. 8 If deviated, is wellbore plat included _ . _ _ _ _ _ ... Yes ... conform to spacing requirements... 9 Operator only affected party _ _ .. _ _ _ _ _ . Yes ----- 10 Operator hasappropriate bond in force _ _ _ _ _ _ _ - - - _ _ - - _ Yes Appr Date 11 Permit can be issued without conservation order _ _ _ _ _ _ _ _ _ _ ...... - Yes 12 Permit can be issued without administrativeapproval _ _ Yes SFD 11/27/2018 13 Can permit be approved before I5 -lay - 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. mite areaof review identified (For service well only) _ _ _ _ .... _ _ NA . . . . . . . . . . . . . .... . .......... . 16 18 Pre -produced injector: duration of pre -production less than 3 months (For service well only) .. Conductor stdng.provided . . . . . . . . . . ....................... . . . . . . NA ............... NA . . . . . . . . . Conductor set.fQrARU_ 1B-16. _ . Engineering 19 Surface casing. protects all. known USDWs _ NA ....... Surface casing set in KRU 18-16 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....... _ Produetive.interval will be completed with. uncemented slotted liner 23 Casing designs adequate for C, T, B &_permafrost_ _ _ _ ............. - _ _ Yes 24 Adequate tankage, or reserve pit _ _ _ _ _ _ _ _ _ _ ........ . . . . .. . . . Yes . _ _ _ Rig has steel tanks; all. waste.to approved disposal wells 25 If a_re-drill, has a 10-403 for abandonment been approved . . . . . ... . ........... NA 26 Adequate wellbore separation proposed - - - - - - - Yes . _ _ Anti-coflision analysis complete; no major risk failures 27 If diverter required, does it meet regulations- _ _ _ NA Appr Date 28 Drilling fluid program schematic .& equip list adequate. _ _ _ _ _ _ _____ _ _ Yes _ _ _ _ _ Max formation pressure is $513 psig(1o.7 ppg EMW); will drill w/ 8.6 ppg EMW and maintain overbal w/ MPD VTL 12/5/2018 29 BCPEs, do they meet regulation _ _ _ _ . . . ........... . . Yes _ _ 30 BOPE_press rating appropriate; test to.(put psig in comments)_ _ _ _ _ _ _ _ _ _ _ ______ Yes _ _ _ _ _ _ MPS is 2883 psig; will test BOPS to 35Q0.psig... .. ..................... - _ ...... . 31 Chokemanifold complies w/API. RP -53 (May 84). _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ Yes . ..... 32 Work will occur without operation shutdown_ _ _ _ _ ........ ..... . . . . Yes 33 Is presence of 1125 gas probable __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _____ Yes _ _ _ _ _ _ 112S measures required........... _ ........... _ .... _ ...... _ 34 Mechanical condition of wells within AOR verified (For service well only) .............. NA _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ ....... 35 Permitcan be issued w/o hydrogen. sulfide measures .... _ _ _ _ _ .. No.. _ _ _ _ _ _ Wells _on1B-Pad are_112S-bearing, 112S measures required.. .... ... . Geology 36 Data. presented on potential overpressure zones . . ........... . . . . _ Yes ....... Maximum potential reservoir pressure is 10.7 ppg_ EMW;_ expected reservoir pressure is 8.0 ppg EMW. _ Appr Date 37 Seismic analysis of shallow gas zones _ ................... . . NA _ _ _ _ _ _ Well will be drilled using 8,6 ppg mud, a ooiled-tubing rig, and managed_ pressure drilling_ SFD 11/27/2018 38 Seabed condition survey (if off -shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ __________ _ _ _ _ _ _ _ _ _ _ NA ....... technique to control formationp ressures and stabilize shale_ sections. NOTE, Chance of 39 Contact name/phone for weekly -progress reports [exploratory only] ............ . NA _ _ _ _ _ _ _ encountering gas while drilling thiewellbore due to gas -injection perforated in this area, Geologic Engineering Public Commissioner: Date: Commissioner: Date C oner Date