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219-094
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, June 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1R-126 KUPARUK RIV UNIT 1R-126 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/01/2023 1R-126 50-029-22193-01-00 219-094-0 W SPT 3288 2190940 1500 671 679 671 670 408 433 433 432 4YRTST P Austin McLeod 5/5/2023 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1R-126 Inspection Date: Tubing OA Packer Depth 100 1820 1730 1720IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230506184238 BBL Pumped:0.9 BBL Returned:0.8 Thursday, June 1, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 999 9 9 James B. Regg Digitally signed by James B. Regg Date: 2023.06.02 11:15:48 -08'00' DATA SUBMITTAL COMPLIANCE REPORT 2/10/2020 Permit to Drill 2190940 Well NamelNo. KUPARUK RIV UNIT 1R-126 1081 Operator MD 10907 TVD 3492 Completion Date 8/5/2019 Cfo'm/pletion Status REQUIRED INFORMATION Mud Log No VI/ Samples No V/ ConocoPhillips Alaska, Inc. API No. 50-029-22193-01-00 1WINJ Current Status 1WINJ UIC Yes Directional Survey Yes V/ DATA INFORMATION List of Logs Obtained: GR (Nom Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments Log 31117 Log Header Scans 0 0 2190940 KUPARUK RIV UNIT 1R-126 LOG HEADERS I ED C 31117 Digital Data 8/23/2019 Electronic File: 1R-126 EOW NAD27.pdf ED C 31117 Digital Data 8/23/2019 Electronic File: 1R-126 EOW NAD27.txt ED C 31117 Digital Data 8/23/2019 Electronic File: 1 R-126 EOW NAD83.pdf I ED C 31117 Digital Data 8/23/2019 Electronic File: 1R-126 EOW NAD83.txt ED C 31118 Digital Data 8/23/2019 Electronic File: 1R-1261061 EOW NAD27.pdf ED C 31118 Digital Data 8/23/2019 Electronic File: 1R-1261061 EOW NAD27.W ED C 31118 Digital Data 8/23/2019 Electronic File: 1R-126PB1 EOW NAD83.pdf ED C 31118 Digital Data 823/2019 Electronic File: 1R-126PB1 EOW NAD83.txt Log 31118 Log Header Scans 0 0 2190940 KUPARUK RIV UNIT 1R-126 PBI LOG HEADERS 1 ED C 31183 Digital Data 4430 10907 9/10/2019 Electronic Data Set, Filename: 1R -126 -Final LAS 4430-10907.1as ED C 31183 Digital Data 9/10/2019 Electronic File: 1R-126_2MD_Final_cont.pdf ED C 31183 Digital Data 9/10/2019 Electronic File: 1R-126_2MD_Final_pg.pdf ED C 31183 Digital Data 9/10/2019 Electronic File: 1R-126_5MD_Final_cont.pdf ED C 31183 Digital Data 9/10/2019 Electronic File: 1 R-126_5MD_Final_pg.pdf ED C 31183 Digital Data 9/10/2019 Electronic File: 1R - 126_5T V DSS_Final_Sec1 _4440-5140_cont.pdf ED C 31183 Digital Data 9/10/2019 R- Electronic File: 1R- 126_5TVDSS_Final_Sec2_5140- 126 5371 -Invert _cont.pdf AOGCC — Page I of 3 - _ Monday, February 10, 2020 DATA SUBMITTAL COMPLIANCE REPORT 2/10/2020 Permit to Drill 2190940 Well Name/No. KUPARUK RIV UNIT 1R-126 MO 10907 TVD 3492 Completion Dale 8/5/2019 ED C 31183 Digital Data ED C 31183 Digital Data ED C 31183 Digital Data ED C 31183 Digital Data Log 31183 Log Header Scans ED C 31430 Digital Data ED C 31430 Digital Data ED C 31430 Digital Data ED C 31430 Digital Data ED C 31430 Digital Data ED C 31430 Digital Data ED C 31430 Digital Data ED C 31430 Digital Data ED C 31430 Digital Data ED C 31430 Digital Data Log 31430 Log Header Scans Well Cores/Samples Information: Name INFORMATION RECEIVED AOGCC Interval Start Stop Operator ConocoPhillips Alaska, Inc. API No. 50-029-22193-01-00 Completion Status 1WINJ Current Status 1WINJ UIC Yes 9/10/2019 Electronic File: 1R- 126 5TVDSS_Final _Sec3_5371- 6152_Raved _cont.pdf 9/10/2019 Electronic File: 1R- 126_5TVDSS_Final_Sec4_6152- 10172_Invert_cont.pdf 9/10/2019 Electronic File: 1R- 126 5TVDSS Final SecS_10172- 10523_Revert_cont.pdf 9/10/2019 Electronic File: 1R- 126 5TVDSS Final Sec6_10523- 10907_Invert_cont.pdf 0 0 2190940 KUPARUK RIV UNIT 1R-126 LOG HEADERS 4400 7410 11/12/2019 Electronic Data Set, Filename: 1R-12612131.1as 4440 7410 11/12/2019 Electronic Data Set, Filename: 1R-126P81_Final LAS 4440-7410.1as 11/12/2019 Electronic File: 1R-126 PB1 2MD 4400-7410.pdf 11/12/2019 Electronic File: 1R-126 PB1 5MD 4400-7410.pdf 11/12/2019 Electronic File: 1R-126 PB1 TVDSS 3322- 3560.pdf 11/12/2019 Electronic File: 1R-126PB1_2MD_Final _cont.pdf 11/12/2019 Electronic File: 1 R-1 26PB 1_2MD_Final_pg.pdf 11/12/2019 Electronic File: 1 R-1 26PB 1_5MD_Final _cont.pdf I 11/12/2019 Electronic File:1R-126PB1_5MD_Finalyg.pdf 11/12/2019 Electronic File: 1R- 126PB1_5TVDSS_Final_4440-7410_cont.pdf 0 0 2190940 KUPARUK RIV UNIT 1R-126 P131 LOG HEADERS Sample Set Sent Received Number Comments Page 2 of 3 Monday, February 10, 2020 DATA SUBMITTAL COMPLIANCE REPORT 2/1012020 Permit to Drill 2190940 Well Name/No. KUPARUK RIV UNIT 1R-126 Operator ConocoPhillips Alaska, Inc. API No. 50-029-22193-01-00 MD 10907 TVD 3492 Completion Date 8/5/2019 Completion Status 1WINJ Current Status 1WINJ UIC Yes Completion Report 0 Directional / Inclination Data 10 Mud Logs, Image Files, Digital Data Y !� Core Chips Y Production Test Information YF NA Mechanical Integrity Test Information Y Y® Composite Logs, Image, Data Files © Core Photographs Y Geologic Markers/Tops 'Y Daily Operations Summary Cuttings Samples Y I) Laboratory Analyses Y /S�c.JDA COMPLIANCE HISTORY Completion Date: 8/5/2019 Release Date: 7/3/2019 Description Date Comments Comments Compliance Reviewed By: Date: — o A06( 1 Page 3 of 3 Monday, February 10, 2020 ar q-06fq 13183 ConocoPhillips RECEIVED TRANSMITTAL FEB 0 4 2020 FROM: Sandra D. Lemke, ATO -704 TO: Meredith Guhl AOGCC ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333W. Th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: IR -126 Permit: 218-123 DATE: 02-04-2020 Transmitted: R-126 River Unit revised las well logging files from Antech requested in January 31, 2020 email correspondence. r a j u_w Transmittal instructions: please promptly sign, scan, and e-mail to Sandra DCemke0)conocooh#1ioscom CC: 1 R-26 - folder Date: a I S / 20 ZO Ala5ka/IT-GGRE I ConocpPhillipsAVSka I Office: 9072656947, Mobile 907440.4512 Well Name KUPARUK RIV UNIT IR -126 API Well Number 50-029-22193-01-00 Inspector Name: Brian Bixby State of Alaska MEMORANDUM Insp Num: mitBDB191002103803 Alaska Oil and Gas Conservation Commission DATE: Monday, October 7, 2019 TO: Jim Reggr'7� 1 lI vl� G SUBJECT: Mechanical Integrity Tests P.I. Supervisor I`eYAq r �� ConmoPhillips Alaska, Inc. IR -126 FROM: Brian Bixby KUPARUK RIV UNIT IR -126 Petroleum Inspector 630 630•E630"PTD Src: Inspector Reviewed P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IR -126 API Well Number 50-029-22193-01-00 Inspector Name: Brian Bixby Permit Number: 219-094-0 Inspection Date: 10/1/2019 Insp Num: mitBDB191002103803 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IR -126 Type Inj w - TVD 3288 'Tubing 630 630 630•E630"PTD 21vo94o "Type Test spT Test psi soo IA 830 1810 1770 ' BBL Pumped: o.5 - BBL Returned: 0.5 OA s4o 600 600- 600' Interval tNITAI- P/F P Notes: Page 1 of I Monday, October 7, 2019 219094 X1183 Conoc Philli s p Sent Via: CD Justification: Compliance Quantity*: 1 1 Attachments: Transmittal #1255 Detail Date: 9/10/2019 To (External Party): Email*: abby.bell@alaska.gov First Abby Name*: Elgarico Last Name*: Bell Phone (907)793-1225 Number: 700 Company: AOGCC Address: 333 W 7th Ave. City: Anchorage State: AK Zip Code: 99501 Sent Via: CD Justification: Compliance Quantity*: 1 1 Attachments: Transmittal #1255 Detail Date: 9/10/2019 Data Detail Description*: Type*: 1 R-104 LWD data CD 1 R-126 LWD data CD ignature: 6Sinature: Date: 0 l d. Date: ED From (CPAI Contact): Email*: dchard.e.elgadco@conocophillips.com First Name*: Ricky Last Name*: Elgarico Phone Number: (907) 265-6580 Company: ConocoPhillips Address: 700 City: Anchorage State: Alaska E ^ p E' 1 R C �.r Zip Code: 99501 SEP 10 ; Transmittal Info Tracking #: /� AO G C Data Detail Description*: Type*: 1 R-104 LWD data CD 1 R-126 LWD data CD ignature: 6Sinature: Date: 0 l d. Date: ED STATE OF ALASKA Al ARIIA Oil ANr1 r:AS CONSFRVATION COMMISSION --•- ^_ WELL COMPLETION OR RECOMPLETION REPORT AND L_W__ 1 a. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20MC 25.105 20AAC 25.10 GINJ ❑ WINJ ❑Q WAGE] WDSPL ❑ No. of Completions: 1b. Well Class: Development ❑ Exploratory ❑ Service 21 - Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 8/5/2019 14. Permit to Drill Number/ Sundry: 219.094 ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Sl5udded: 7/23/2019 15. API Number: 50-029-22193-01-00 ' 4a. Location of Well (Governmental Section): Surface: 394' FNL, 137' FWL, Sec 20, T12N, R10E, UM - Top of Productive Interval: 1124' FNL, 2789' FWL, Sec 20, T12N, R10E, UM Total Depth: 1818' FNL, 2089' FWL, Sec 29, T12N, R10E, UM 8. Date TD Reached: 813/2019 16. Well Name and Number: KRU 1R-12611R-126PB1 9. Ref Elevations: KB:88 - GL:45 • BF: 17. Field / Pool(s): Kuparuk River FieldfWest Bak Oil Pool 10. Plug Back Depth MD/TVD: NIA 18. Property Designation: ADL 25635, ADL 25640 ' 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 539830 y- 5990810 Zone- 4 TPI: x- 642484 y- 5990095 Zone- 4 Total Depth: x- 541641 y- 5964117 Zone- 4 11. Total Depth MD/TVD: ^ 10907/3492 • 19. DNR Approval Number: LONS 83-134 12. SSSV Depth MD1TVD: NIA 20. Thickness of Permafrost MD/TVD: 168211630 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: NIA (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 4879/3487 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 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 62.58 H-40 43 123 43 123 24 231 sx AS 1 9.625 36 H-40 43 5593 43 4072 12.25 1170 sx PF E, 530 sx Class G 7 26 H-40 35 10201 42 3500 8.5 250 sx Class G 31/2 9.2 L-80 4438 4930 3401 3492 4.25 Solid Liner 27/8 6.5 L-80 4930 10907 3492 3492 4.25 Slotted Liner/Solid Liner 24. Open to production or injection? Yes ❑� No ❑ If Yes, list each interval open (MD!(VD of Top and Bottom; Perforation Size and Number; Date Perfd): Slotted Liner @: 4930-10907 MD and 3492-3492 TVD .... 8/5/2019 COMPLETION A E Solid Liner @: a f ZQ' 4438- 4930 MD and 3401.3492 VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4.6x3.5x2,875 9747 957016523, 9706;16614, 443113397 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes E] No R] Per 20 AAC 25.283 (1)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): INJECTOR WELL Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casino Press: Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity- API(corr): Form 10-407 Revised 5/2017 (CONTINUED ON PAGE 2 Submit ORIGINAL on %//9 R$DMS SEP 0 5 2019 ;� _r y n 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑+ If Yes, list formations and intervals cored (MD/TVD, Fromlro), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1682 1630 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 4880 3487 information, including reports, per 20 AAC 25.071. Formation @ TPI -West Sak C West Sak D 4465 3418 West Sak C 4550 3461 West Sak B 4971 3499 TO 10907 3492 Formation at total depth: West Sak B 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, productionpaleontolooical report orw r 20 AAC; 25.070 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: Ryan McLau hlin Authorized Title: Staff CTD Engineer Contact Email: an.mclau hlin co.com Authorized q/y�9 Contact Phone: 265-6218 Signature: Date: INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 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 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only WUncimto M 12Votlme 133' MD CTDKOPA 3'MD, 33] S6TVD, 51-0e9 in. 95M 36X!55 shoe M 5593' Ta of T'mmmt-9I: W� LBlof 63]91 ERF6 (PM99ae) ene%39'A nMD m 999T-omw MD -9ane9916'-9911'MD ]"Pm Ion 3SN l69 shoe® 10,391' MD IR -126 Final CTD Schematic oovme. v+aaa+e ua+ Conoco`Phillips Alaska, Inc KUP INJ WELLNAME 1R-26 WELLBORE 1R-26 aslw0' 112-m 9wrm+e s>S:seaM Last Tag VNdrubnutie(ecm9 AnnobHon O M(MBI I End We Wellbore LasLMOH By .........................._I.... __. _.. ,... .,,_,,,_...,,_,,, ___ Last Tag: ELSE 9,0180 9292016 1H-26 posbll Last Rev Reason ............................................................. .............. RANGER, 399 Nnnobliw End Onb Wellbore Lear sage By RevHasson: Set Liner Top Packer and Measured 68HP 99/2019 1H-26 bwarpip 7 Casing Strings trim'0esenIS oO MI 10 Ia rop MKID sM Depth VSKI1 Set Dead, V L.. wblweD GrMe Tap Tb,ud CONDUCTOR 16 1506 43D 123.0 1230 62.58 H40 WELDED C7. -.0.1H0 Gpbq OeWflplbn 00 (In) ED (in) TeP(wa) WDepth NH(BI "1 OepN (NDk.. 3600 g... Glade ET Thread SURFACE 998 8.92 62.6 5,593.1 4,0]2.0 36.00 J-55 BTC Gakq Cee[Nplbn OO p,p 10(;p TePMR) See depth loll) 620 DepN(IVD-1 WtlLan(I...GrWe Top Tbreed GAS LET. 'Res a C-MOD PRODUCTION ) 628 419 10,201.0 2600 J-55 87C casing Description OOpnl Ili ToDogns) Set OepM(IIKBI 920 OepM jND1... WtlLan g_.GrNe Tap 1nead SCAB LINER 41/2 400 6.2511 4,606.1 3,503.1 11.60 L-80 Liner Details GAS Uni 4,206.0 Nominal o NIPPLE', 4.2'12.7 SEAL W.I. rant Top mKe1 Top CVD)mKBI Tap Incl (°) Sam pas Cam (In) 4,251.1 3,284.5 51.80 PBR PER 5,255 c.,Im,besm an.r:4,20 SH ---427-9 3,294.3 51 77 Packer FP Packer 4-12"x 7- 3,810 4,2Y7 3,306.6 51.69 7PP(E %Nipple 3.813"44589312-2 PT#101878159 3813 4, 5 3,396.0 51.36 TWEV Wedge easy @4,1341 3,958 WEDGE 6,449.5 3,4079 51.34 NIPPLE NipPle-X 3.813 Remand Cement smaem: aao.0 nam 4,4 8 3,4123 51.33 AN Wedge asst' a 446001 3.958 WEDGE CMT 602:4.3M.p4p90.0- 4,4)56 3,424.2 51.32 NIPPLE Nipple -X 3.813 Lire Rp Pad a.uN✓. Tubing Strings Paundr; 44316 Tubing Descnp4on Strang Ma... mgn) T*P91MIN sN Deg" M..3d DepM(ND)(...WI(IbaD Grade TOPConnsctbn TUBING 45" 4.926 3.96 399 4?51.8 3,2850 1275 L -BO HYD 503 I Completion Details Too HVIN Topinal hoe - reports) InKel V) stem Des com mpml 39.9 39.9 088 HANGER Hanger FMC Gen IV 11" x 4112 NYD563 plus 463 pup 3958 -4,277 3,2]3.2 5154 NIPPLE XNipple 3113" HYD 583 3813 wmpsT00p 4406.0 4269. 3,283.4 5179 SEALASSY Tieneck.cabr 3980 mane Desaripmn Smng Ma... m (in) Top (TIKB) set Depth m.. L - IM Depth (TD) M pNnl GWe Tnp ennneatmn TUBING 3.5"4.8)5 4112 2.99 9.5695 9,7468 6,6419 930 L-80 ABM -BTC Completion Details x-LBcyNwnbr: a4]6D Top RVD) Top Ina Nominal Top(nKBI (Mel fl Ilam Des cam mpn) 9,569.5 6,523.0 4806 PACKER BAKER HB RETRIEVABLE PACKER 2.090 96272 6,561.5 4820 BLAST RINGS CARBIDE BUST RINGS (2) 2992 SCAB LINER: east 14.66.1 MIDGE PLUG, PERMANENT. 4.850 0 9,694.5 6,6106.] 4766 SLEEVE -C AMCO CB-1SLIDING SLEEVE wNJ I -, D SLEEVE 2]50 (OPENED 519/14) IR -126 SLOTTED LINER: 4.4X..1..... 9,706.0 6,6144 4763 PACKER BAKER D PERMANENT PACKER 3250 sW (9IdW Ure[ 4ay.6 6.4m.e --rbW 6,618.9 4761 SBE BAKER SEALB REE%TENSION 3250 Q619.8 4159 TOReducing CROSSOVER 3.5 x 28)5 2875 729.8 s630A 4754 NIPPLE OTIS 2718 XN NIPPLE: 231T core. 2 n- NO GO ID 2250 9,746.0 6,6414 4760 SOS BAKER SHEAR OUT SUB,TTL 9736 ELM, Eine tag 9930ELM 2441 SORFACE Anine%11 5/5/2606 cab {906th Lwl:6.449YL� 4.306± Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) siW (SWplan: 4o- LbZ1a Toppings) roplrvDI (MB) rop idol P) a- Com flan Dale ID Dp sad(sbmatimwl:77091-_ a.Tw2 4,431.6 3,396] 51.35 Liner W Packer (ME) wl "her 70" LTP Packer. 4" evlevabe ro e, AL 1192 SAW2019 2,360 Gmwn mad GIA89 Pal Seal Assembly GnmtPap; 9.os9olme smb(SamdLNDLE791r- 8.811 ] 7460.0 74144 51.33 WHIPSTOCK 4-1R- Northern Solutions Inner Wedge, et Oeg $wl Iwo PIPs s ag 7114)2019 1.000 4,4)60 3,4246 51.33 -Loc etX7ack8 Flow Nm assembry or 1pstoc. Al2R019 0.000 PaOKER:8sM.4 Assembly DAL. 4,6590 3,534.1 53.91 BRIDGE PLUG- 4/2612019 PERMANENT INJECTION: 9.612.3 Perforations B Slots soon Dep. Top LVD) Sam m l (nlpba Tap(Mel Bthe WB) (nKB) (MBI LMKM some Dae I ryPo com 4,320.0 4,480. 3,32].3 3,426.9 4127 1 12.0 CMT SOZ I 12SPt 19g RDX BH SLEEVELI9.M45 135deg phasing TCP reference bg was SLB EMIT 22 .19 PACKER'. s.me0 q,g .g 5,4086 3,6963 3,969)Tor- Ins WE. WE:9.2M.e (SIOted Liner) NIPPIE,GM.e Sp98.3 6,5084 4,019.6 4,5897 (Slotted IoM SOS:B.T46.0 Liner) 8,596.0 7,621.8 6,641 A 8264.8 Slots (Stoned Liner) ]]09.1 8,7092 5,319.5 51 101A (Slotted Liner) sammaded Lear).9Xto- Goal 8,79].] 9,8 11.7 6,012.5 6,6857 UNIT D,IR-26 (Slotted Skme timer) 9,887.0 9,902.0 6736.5 6,7463 Ai, 1R-26 MOM= 60 lots 0vrer nerjel HMX, (Slotted 0 degph Liner) PROd1CTICN:41 B10.A10 s(spbi Li„v):rea ffi 10.9X3 KUP INJ WELLNAME 111-26 WELLBORE 1R-26 ConocclPhillips Alaska. Inc 1R-26. waste an.AM Pertorations&Slots vwaulsanaf Iww41 1. (Tv01 .1mrrvDl snot Dans (neoWh ....._. ..___. ..,, ..._..... ......... ... ..........._. TOP mKBI atm mKB) meal (NKa) LInkN Zone Dee ) TyPo Co. ruNGER:3se 9,699.5 10,906.3 6,]44.9 C-1, 1R-26 11411992 10.0 lots 4a Ceg Gun,.. leg. ph I I (slow Liner) Cement Squeezes rcP 0,0) Bun mDo TOP Rai atm OLKIN gBBI 'ex.) Oes som Dale com CONDUCTORw, 43.D123.0 9,0169 9,050.0 6,157.2 5177.7 CEMENTPLUG 612512014 pumped 50'(bWs hom depth of 9018,0) oCement on lop of cement retainer, Squeeze 55 WE of Cement below reeiner. GRG LIFT z.RO0 9,050.0 9,696.9 6,1]],] 56g9.6 CEMENT PLU 6252014 reter. Squeeze 55 WAR of cement beewain 4,3200 44 .0 3,32].3 3,4269 REME CEMENT IAL 4262019 Arc erewab cut pod was cement tool used to squesselwashnay in 331ml 158ppg cement Gas LIFT I'M0 SOUEEZE xNPLE:4.292] 4,2510 4, .0 3,264.5 3,503.0 CEMENTED5122019 SCAB LINER Pump mW Bush . ppg Chase wl 2 able 156 ppg NT -5 cement slurry holding 500 psi back SEAL ASav: 4.2492 cem.ma snBLbr, asst n pressure on choke manifold, Bump plug and set UP at 4237. Retain. horn packer and and circulate mud had push and 3 bbis of cement Out of Ne hole. CUP at 1130. Mandrel inserts Ed an R—WWN Cnrem a4lma: a.3GIOURS CMT. asm.w.4n.o_ N TOPKS) TOP MKeI MKS) MWeI O011n) sery VnN6 LakB PONSIv TI10 Run TYPo TYP+ 6n1 (Poll Run Gad Com 2,998.0 2,5068 Camco KDMG 1 PROD GLV BK 0.188 1,5580 IOI2019 2 4,2W.0 1 3,2565 I Camco IKUWJ I 1 PROD lOV IC, I 0250 0.0 "II2019 UreeT,PPWo(SE).RW Notes: General & Safety MymmY. 4.4319 End Oa@ annouton 1012012010 NOTE; View Schematic wl Alaska Schama6c100 11142014 I NOTE; GLV STUCK: WAS UNABLE TO RETRIEVE DURING 2014 RWO ]11)2014 INUTE: FISH; COMPRI ED OF TUBINGGLMINIPPLEISEAL LOCATOR WHIPSTOCK 4,RaO x{wk PuaNir: 4.476.0 SONS LINER, 4251t4,60al BRIDGE PLUG PERMANENT. 466aD 1R.126Sa0TTEDUNER'. 44ae.ato kdO sXA(sbdid U WA 4.B. 6 - Ease sURFACF,42.66.%31 a%. rsMNd 8.9J9� skil Sb 1aib 0:6.%6 TUNS 6BK (61ob4 Lw); T,Te.1- a X412 cure 'Na Ras9 had Cemm1 He:8,60.o. sk%(S MUw);8'Gd'- B.B111 PACNER;BX94 IWECTICHLEG113 B'EE.:8.B45 PA.KER: 9..a 6BE:S,RBB NIPPLE;a" 805; 8.]i8.0 Sbk I6NW Loren: B,eB>O B.WlO PRODUCTION: 41 510,2010 skn(amm U—), aaastr losses Ip41e,9M/d1196219GAM KUP PROD WELLNAME 7R-26 WELLBORE 1R-126 (�/�('( conoa Vestry wam4c Meed) Well AttribW Max Angle' H') MOI TD atl Blm lrcrca) - --t'llpsele NBSkd. )1h;. LAST TAG Name KUPARUK RIVER UNIT weBMrc apwW well rcsmu: 500292219301 PROD 521 8,192.62 lennalt Ip41e,9M/d1196219GAM Last Tag Vestry wam4c Meed) Annota ion Oepd,UGIn I End nate wellreme Leat MM By LAST TAG 1R-12fi lennalt Casing Strings _.......................................................--.._casto9 1A.GEp:39e oescelvtioa oo fn 1R-126 SLOTTED LINER 2]18 mlin) 2.44 raP lnxa) set Doom l -B) fiat Gepm f%DL, wuLen lL. Graae 4938.2 10901.0 6.50 L-80 Tov rnreaa H533 Liner Details Nominal D Top ("KB) Top RV.)al T.PI2.11) Item Dee Co. on) 4,4382 5SUR(Side Deployment seal Man 6' seal Dore 2.990 Bore Receptacle) 4,445.3 3,4052 51.35 CIO crass over, 3 -1177' -2J1 - REDUCING 4,932.6 3,4926 80952-748"' Sp, L-80, H533, Sloftell liner( TOB A EOB 2,391 CONDUCTOR: 43.0-D00 REDUCING DepBt@4889') Notes: General & Safety End Date Ann..... GAEUFTI 2598.0 8I2Z2019 NOTE View SCnematiG w/A)aSka Shcemd4L10.0 G ds LIFT: 4.2060— NIPPLE 4ZR7 6EALA86Y', 4..,2 LemenW BaE L'm: 4,E1.0 Mt8 Ran3tl wren am"' 4.30D 01M(B (par SOL 4, 31 addrE 0� LLS TW Pec1✓ (ME) W BW ■ gpyrtlY: 4.4318 ■ WKIP6TOLK 4,40 SLAB LINER. 4.25114,QB.1 BRIDGE PLUG PERMONENT. PRODUCTION: .0 . E.E SURFACE: 4365.5331 1R-1R81LOTTED LINE.: 4.456.210,99.0 • L aerations Summary (with Timelog L,pths) 1 R-126 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Lop Stan DOW Start Tmre End Tme DW(hn Phase Op Code Activity Corte Time P -T -x Operation (mKS) 0.0 End Depth(VB) 0.0 7/15/2019 7115/2019 2.00 MIRU MOVE RURD P Complete RD checklist, prep for Peak 08:00 10:00 sows to move the rig 7/1512019 7/15/2019 1.00 MIRU MOVE MOB P PJSM w Peak pusher and operators. 0.0 0.0 10:00 11:00 Jack service module and attach sow, pull away from well row and spot on pad out of the way. 7/15/2019 7/15/2019 1.70 MIRU MOVE MOB P Jack Sub, attach sows and move 0.0 0.0 11:00 12:42 down well row to 1 R-126, spot over well and set on mats. 7/15/2019 7/15/2019 1.30 MIRU MOVE MOB P PU service module, spot next to sub 0.0 0.0 12:42 14:00 1 1 and set down 7/15/2019 7/15/2019 5.00 MIRU MOVE RURD P Work RU checklist. MU Scaffolding in 0.0 0,0 14:00 19:00 cellar, Service tree valves, well control choke, and tangos 7/15/2019 7/15/2019 1.00 MIRU WHDBOP NUND P Nipple up stack 0.0 0.0 19:00 20:00 Rig Accept 20:00 "' 7/15/2019 7/15/2019 1.50 MIRU _WHDBOP RURD P Flood up the stack, walk lines, attempt 0.0 0.0 20:00 21:30 shell test, leak. Trouble shoot leak, call out valve crew, grease tree X2. Determine swab 1 leaking. Dump SSV and lest against the SSV, good test. 7/15/2019 7/16/2019 2.50 MIRU WHDBOP BOPE P Start BOPE lest, 250 psi low 3500 psi 0.0 0.0 21:30 00:00 high witness waived by Jeff Jones AOGCC. 7/16/2019 7/16/2019 5.00 MIRU WHDBOP BOPE P Continued testing BOP's, 250 psi low, 0.0 0.0 00:00 05:00 3,500 psi high fighting the tree valves ended up calling out the grease crew again to service the tree. '• Witness waived by Jeff Jones of the AOGCC 7/1612019 7/16/2019 2.50 MIRU WHDBOP BOPE P Test 12, testing variables, obtain low, 0.0 0.0 05:00 07:30 trouble getting high test, determine tree valves to be leaking by, call valve crew back out. Finish test, RD testing equipment. `•* Note: BOPE Test time 10.0 hrs 7/16/2019 7/16/2019 1.00 MIRU WHDBOP CTOP P Inspect pac-off, intall NRJ lest sub 0.0 0.0 07:30 08:30 with bleeder, grease crew on location, service tree valves 7/16/2019 7/16/2019 1.00 MIRU WHDBOP PRTS P Test Cable head and upper NRJ to 0.0 0.0 08:30 09:30 3,500 psi, obsere leak at CTC, bleed off pressure 7/16/2019 7/16/2019 2.00 MIRU WHDBOP CTOP T Remove NRJ/Cable Head, cut CTC off 0.0 0.0 09:30 11:30 and trim 12' of coil 7/16/2019 7116/2019 2.00 MIRU WHDBOP CTOP T Install CTC and pull lest 35 k 0.0 0.0 11:30 13:30 7/16/2019 7/16/2019 2.25 MIRU WHDBOP CTOP T Re -head AnTech cable head, install 0.0 0.0 13:30 15:45 NRJ, test eline (good), PT Upper NRJ/Cable Head (good lest) 7/1612019 7/16/2019 0.50 MIRU WHDBOP CTOP T Slab INJH, test inner reel valve and 0.0 0.0 15:45 16:15 pac-off (good lest), blow down well control choke 7/16/2019 7/16/2019 0.75 MIRU WHDBOP PRTS P PT TT line and ODS PDL to 1500 psi- 0.0 0.0 16:15 17:00 good, Flow check good. 7/16/2019 7/16/2019 1.00 PRODi WHPST PULD P PU BHA#1, Window milling BHA, 0.6 0.0 0.0 17:00 18:00 1 "AKO, W 3.80 " mills. Load into PDL 7/16/2019 7/16/2019 1.50 PRODt WHPST OTHR P Crew change out, Perform valve 0.0 0.0 18:00 19:30 check list. Bleed off well. Perform no Pow test Page 1119 Report Printed: 8/2112019 L,Nerations Summary (with Timelog L-pths) 1 R-126 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Lop sran Depth SW Time End Time Dor (hr) Phase Op code I Activity code Tines P -T -X Openstion (KKB) End Depth (W) 7/1612019 7/16/2019 0.50 PROD1 WHPST SFTY P PJSM to pressure deploy BHA #ion 0.0 0.0 19:30 20:00 1 dead well. 7/16/2019 7/16/2019 1.00 PROD1 WHPST PULD P PD BHA#1. Tag and drop2.95'. Check 0.0 56.1 20:00 21:00 pack offs 7/16/2019 7/16/2019 1.30 PROD1 WHPST TRIP P RIH BHA#1 56.1 3,900.0 21:00 22:18 7/16/2019 7/16/2019 0.70 PROD1 WHPST DLOG P Log Gamma tie in for +10' correction, 3,900.0 4,040.0 22:18 23:00 1 PUW=36K 7/16/2019 7/16/2019 0.40 PROD1 WHPST TRIP P Continue in well on seawater. Tag 4,040.0 4,465.0 23:00 23:24 1 pinch point @ 4465' 7116/2019 7/17/2019 0.60 PRODt WHPST CIRC P Flush well with sewater 4,465.0 4,465.0 23:24 00:00 1 7/1712019 7/17/2019 0.70 PROD1 WHPST CIRC P Compleye seawater flush, displace to 4,465.0 4,465.0 00:00 00:42 1 milling fluid, Close Circ port 7/17/2019 7117/2019 2.00 PROD1 WHPST MILL P Mill window, Initial pinch point 4465.5, 4,465.0 4,466.0 00:42 02:42 2.61 BPM @ 1935 PSI FS, BHP=1871 7/17/2019 7/17/2019 8.00 PROW WHPST MILL P Continue Milling, tenth every 6-9 min. 4,466.0 4,471.0 02:42 10:42 2.69 bpm at 2,012 psi, WHP=37, BHP=1,859, IA=552, OA=985 '• Note: Short pump pressure spike 7/17/2019 7/17/2019 2.30 PROD1 WHPST MILL P Continue Milling, tenth every 6-9 min. 4,471.0 4,472.5 10:42 13:00 2.69 bpm at 2,012 psi, WHP=37, BHP=1,859, IA=552, OA=985 7/17/2019 7/17/2019 0.30 PROD1 WHPST REAM P TD first milling run, PUH and ream @ 4,472.5 4,472.0 13:00 13:18 milled TF 0` @ 2.71 bpm 1,824 psi 7/17/2019 7/17/2019 0.75 PROD1 WHPST TRIP P POOH 4,472.0 56.1 13:18 14:03 7/17/2019 7/17/2019 1.50 PR0D1 WHPST PULD P Al surface practice PUD milling BHA 56.1 0.0 14:03 15:33 #1, Mill out @ 2.79 No go 7/17/2019 7/17/2019 0.45 PROD1 WHPST PULD P LD 2-7/8" X-Treme motor, change 0.0 0.0 15:33 16:00 j 7/17/2019 7/17/2019 1.00 PROD1 WHPST PULD P Practice PD Milling BHA#2 0.0 57.0 16:00 17:00 7/17/2019 7/17/2019 5.50 PROD1 WHPST PULD T On initial surface test tool out of spec. 57.0 0.0 17:00 22:30 Trouble shoot. Lay down BHA. 7/17/2019 7/18/2019 1.50 PROD1 WHPST PULD T M/U new float tube in NRJ. M/U back 0.0 57.0 22:30 00:00 up tool and put in well 7118/2019 7118/2019 0.50 PROD1 WHPST PULD T Continue getting tool in well, Make up 57.0 57.0 00:00 00:30 injector and surface test - good 7/18/2019 7/18/2019 0.90 PROD1 WHPST TRIP P Trip in hole, circ port open 57.0 3,900.0 00:30 01:24 7/18/2019 7/18/2019 0.60 PROD1 WHPST CLOG P Log K1 for+10, close circ port. 3,900.0 4,025.0 01:24 02:00 7/18/2019 7118/2019 0.50 PROD1 WHPST TRIP P Continue in Unable to get orienter to 4,025.0 4,430.0 02:00 02:30 move. Have good comms through tool to lower subs. Orienter motor going into overspeed with minimal amperage. Trouble shoot software. 7/18/2019 7/18/2019 0.75 PROD1 WHPST TRIP T Unable to get orienter to respond. Trip 4,430.0 52.2 02:30 03:15 out 7/18/2019 7/1812019 2.00 PROD1 WHPST PULD T At surface, check well for flow, LD 52.2 0.0 03:15 05:15 Ifailed BHA #4 7/18/2019 7118/2019 2.50 PR0D1 WHPST PULD T PU new AT tool and swap out NRJ, 0.0 52.2 05:15 07:45 •" Note: Frame 6 down, bring rig off highline power. 7/18/2019 7/18/2019 0.20 PROD1 WHPST PULD T Surtace test tools (good --test), lag up 52.2 52.2 07:45 07:57 reset counters 7/18/2019 7/18/2019 1.25 PROD1 WHPST TRIP T RIH 52.2 3,320.0 07:57 09:12 1 Page 2/19 Report Printed: 812112019 L Aerations Summary (with Timelog U�pths) 1 R-126 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Lop Step Depth Stan Time Eno Time D (hr) Phew Op Ce4e Acilviy cone Time P -T -X Operation Me) End Deplh(flKS) 7/18/2019 7/18/2019 0.50 PROD1 WHPST DLOG T Log formation (Ugnu A), correction 3,320.0 4,030.0 09:12 09:42 plus 5.0' 7/18/2019 7/18/2019 0.55 PROD1 WHPST TRIP T PUW, 28 k, continue IH 4,030.0 4,470.4 09:42 10:15 7/18/2019 7/18/2019 6.00 PROD1 WHPST MILL P Started milling, 2.7 bpm at 2,109 psi, 4,470.3 4,473.4 10:15 16:15 Diff=507, WHP=44, BHP=1,859, IA=138, OA=498 7/18/2019 7/16/2019 1.75 PROD1 WHPST MILL P Continue milling 2.8 bpn at 2,440 psi, 4,473.4 4,475.3 16:15 18:00 Diff -585, WHP=46, BHP=1,855, IA=150, OA=502 7/18/2019 7/18/2019 0.40 PROD1 WHPST MILL P Crew change, run valve check list. 4,475.3 4,475.3 18:00 18:24 Continue milling 2.8 BPM @ 2440 PSI, , BHP=1855, Call 9 5/8" exit @ 4474.3, Time mill with reamer to 4475.3 7/18/2019 7/18/2019 0.70 PROD1 WHPST MILL P Mill Ralhole to 4493.3, good sand in 4,475.3 4,493.3 18:24 19:06 rahole TO sample 7/18/2019 7/18/2019 1.80 PROD1 WHPST REAM P Back ream window per procedure, As 4,493.3 4,493.0 19:06 20:54 drilled, 30L, 30R, 180" from as drilled 7/18/2019 7/18/2019 0.20 PROD1 WHPST TRIP P PUH to 3900 4,493.0 3,900.0 20:54 21:06 7/18/2019 7/18/2019 0.30 PROD1 WHPST DLOG P Log Marker for +11.5' 3,900.0 4,037.0 21:06 21:24 7/18/2019 7/18/2019 0.30 PROD1 WHPST TRIP P Trip back in well to bottom, Clean drift 4,037.0 4,495.3 21:24 21:42 through window 7/16/2019 7/18/2019 1.00 PROD1 WHPST TRIP P POOH 4,495.3 3.6 21:42 22:42 7/18/2019 7/19/2019 1.30 PROD1 WHPST PULD P Al surface. PJSM, Lay down BHA *3, 3.6 0.0 22:42 00:00 Mill out @ 3.76 No Go. Reamer out @ 3.78 No Go. Blow down motor 7/19/2019 7/19/2019 1.00 PROD1 DRILL CTOP P Make up nozzle, Stab on injector. 0.0 0.0 00:00 01:00 Flush slack and rig surface lines. 7/19/2019 7/19/2019 2.20 PROD1 DRILL CTOP P Reboot / Service Antech upper NRJ 0.0 0.0 01:00 03:12 7/19/2019 7/19/2019 1.00 PROD1 DRILL PULD P P/U BHA#4 with 2.2° AKO motor. 0.0 53.0 03:12 04:12 Make up to coil and surface test, Open EDC 7/19/2019 7/19/2019 2.00 PROD1 DRILL TRIP P RIH BHA#4, circ sub open, Pump min 53.0 3,900.0 04:12 06:12 rate. Test orienler @ 150' - good 7/19/2019 7/19/2019 0.30 PROD1 DRILL OLOG P Log formation correction of minus 3,900.0 4,044.2 06:12 06:30 10.5', PUW 35 k 7/19/2019 7/19/2019 1.00 PROD1 DRILL TRIP P Continue IH, notice survey's were not 4,044.2 4,498.0 06:30 07:30 correct, PUH slowly to restart program. 7/19/2019 7/19/2019 0.75 PRODt DRILL WPRT P PUH and perform check shots. 4,498.0 4,498.8 07:30 08:15 7/19/2019 7/19/2019 1.00 PROD1 DRILL DRLG P OBD, 2.8 bpm at 2,391 bpm, BHA 4,498.8 4,637.9 08:15 09:15 Diff=513, WHP=42, BHP=1,878, IA=O, OA=384 7/19/2019 7/19/2019 0.30 PROD1 DRILL WPRT P PUH and perform check shots. 4,637.9 4,637.9 09:15 09:33 7/19/2019 7/19/2019 3.25 PRODt DRILL DRLG P BOBD, 2.5 bpm at 2,126 psi, BHA 4,637.9 4,900.0 09:33 12:48 Diff --397, WHP=21, BHP=1,768, IA=3, OA=96, increase in Gay cuttings across shaker up to 9.7 ppg MW out. ••* Note: Average Dog Leg in the build section 22.8° 7/19/2019 7/19/2019 0.30 PROD1 DRILL WPRT P Wiper up hole, PUW 40 k 4,900.0 4,495.0 12:48 13:06 7/19/2019 7/19/2019 0.30 PROD1 DRILL WPRT P Wiper back in hole, RIW 15 k 4,495.0 4,900.0 13:06 13:24 Page 3119 Report Printed: 8/21/2019 t Aerations Summary (with Timelog bvpths) 1 R-126 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log siert Depth Start Time End Time Dur(hr) phase Op Code Ac" Code Time P -T -K Opemtlon (11KB) End Depth (ftKB) 7/19/2019 7/19/2019 3.20 PROW DRILL DRLG P BOBO, 2.8 bpm at 2,094 psi, BHA 4,900.0 5,200.0 13:24 16:36 DIff=610, WHP=44, BHP=2,083, IA=480, OA=652, 7/19/2019 7/19/2019 0.30 PROD1 DRILL WPRT P Wiper up hole, PUW 40 it 5,200.0 5,100.0 16:36 16:54 7/19/2019 7/19/2019 0.20 PROD1 DRILL WPRT P Wiper back in hole, RIW 15 k 5,100.0 5,200.0 16:54 17:06 7/19/2019 7/19/2019 0.70 PROD1 DRILL DRLG P BOBD, 2.8 bpm at 2,094 psi, BHA 5,200.0 5,300.0 17:06 17:48 DIff=610, WHP=44, BHP=2,083, IA=480, OA=652, 7/19/2019 7/19/2019 0.10 PROD1 DRILL TRIP P 5300', Call end of build section, 5,300.0 5,000.0 17:48 17:54 PUW=29.5K 7/19/2019 7/19/2019 1.80 PROD1 DRILL DLOG P Perform MAD pass to window 5,000.0 4,476.0 17:54 19:42 7/19/2019 7/19/2019 1.20 PROD1 DRILL TRIP P Clean pass up through window,tdp out 4,476.0 67.0 19:42 20:54 7/19/2019 7/19/2019 1.40 PROD1 DRILL PULD P Tag up and space out, PJSM, PUD 67.0 0.0 20:54 22:18 BHA #4 Build BHA, Bit out 1-1 2 plugged nozzles, Avg DLS in build 23.4 7/19/2019 7120/2019 1.70 PROD1 DRILL CTOP P Remove upper NRJ houseing, Clean 0.0 0.0 22:18 00:00 and test head up 7/20/2019 7/202019 0.30 PR -OD I DRILL CTOP P Continue upper NRJ service 0.0 0.0 00:00 00:18 7120/2019 7/202019 1.70 PROD1 DRILL PULD P PIU BHA#5 with .8°AKO motor and 0.0 53.0 00:18 02:00 HCC Bi Center with Dynamus cuters and Pressure deploy. Make up to coil and surface test. Inspect pack offs. Tag up 7/20/2019 7/20/2019 0.90 PROD1 DRILL TRIP P RIH, CS open, Pumping new mud, 53.0 3,930.0 02:00 02:54 j test orienter@ 500' 7/20/2019 7/202019 0.20 PROD1 DRILL DLOG P Log formation for +9.5', PUW=35K 3,930.0 3,960.0 02:54 03:06 7/20/2019 7/20/2019 0.50 PROD1 DRILL TRIP P Continue in well, displace to new mud 3,960.0 4,400.0 03:06 03:36 7/20/2019 7/20/2019 0.70 PRODi DRILL TRIP T Stop @ 4400'to close CV. CV not 4,400.0 4,400.0 03:36 04:18 responding. Troubleshoot, Reboot computers. CV closed. tool diff @ 460 PSI 7/20/2019 7/20/2019 0.20 PROD1 DRILL TRIP P RIH, Clean pass through window, Log 4,400.0 4,824.0 04:18 04:30 in RA @ 4470.5. Continue in well 7/20/2019 720/2019 1.00 PROD1 DRILL TRIP T Odenter not responding. Trouble 4,824.0 4,410.0 04:30 05:30 shoot. PUH slowly 7/20/2019 720/2019 0.50 PROD1 DRILL TRIP P RBIH, orienter is working in cased 4,410.0 5,299.0 05:30 06:00 hole 7202019 7/20/2019 2.75 PROD1 DRILL DLOG P Perform MADD pass from 5,299' up 5,299.0 4,490.0 06:00 08:45 hole to 4,490' 7202019 7/20/2019 0.20 PROD1 DRILL CLOG P Log the RA marker correction of plus 4,490.0 4,526.0 08:45 08:57 2.0' 7/20/2019 7/20/2019 0.30 PROD1 DRILL TRIP P RBIH, RIW 15 k 4,526.0 5,299.0 08:57 09:15 7/2012019 7/20/2019 4.00 PROD1 DRILL DRLG P OBD, 2.8 bpm at 2,047 psi, BHA 5,299.0 5,700.0 09:15 13:15 Diff --513, WHP=44, BHP=1,871, IA=421, OA=684 7/20/2019 7/202019 0.50 PROD1 DRILL WPRT P Wiper up hole, PUW 40 k 5,700.0 5,300.0 13:15 13:45 7/202019 720/2019 0.40 PROD1 DRILL WPRT P per back in hole, RIW 11 it 5,300.0 5,700.0 13:45 14:09 7/20/2019 7/20/2019 2.75 PROD1 DRILL DRLG P BOBD, 2.8 bpm at 2,118 psi, BHA 5,700.0 5,864.0 14:09 16:54 Di"- 17, WHP=53, BHP=2,023, Page 4119 Report Printed: 8121/2019 L perations Summary (with Timelog L-pths) 1 R-126 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log stanDepth Start Tene End Tme Dur(hr) Phase Op Code ACGv'fty Code DRLG Time P -T -X P Operation OBD, 2.8 bpm a12,435 psi, BHA (IMS) 5,864.0 End DePM(flKS) 6,100.0 7/20/2019 7/20/2019 2.30 PROD1 DRILL Diff=824, WHP=44, BHP=1,999, 16:54 19:12 IA=47OA=712 7/20/2019 7/20/2019 0.70 PROD1 DRILL WPRT IS- Pull 800'wiper trip, PUW=45K 6,100.0 6,100.0 19:12 19:54 7/20/2019 7/20/2019 2.80 PROD1 DRILL DRLG P 6100', Drill, 2.8 BPM @ 2493 PSI FS, 6,100.0 6,352.0 19:54 22:42 BHP=2025 7/20/2019 7/20/2019 0.10 PROD? DRILL WPRT P Pull 100'wiper, PUW=42K 6,352.0 6,352.0 22:42 22:48 7/20/2019 7/20/2019 0.50 PROD1 DRILL DRLG P 6352', Drill, 2.8 BPM @ 3082 PSI FS, 6,352.0 6,406.0 22:48 23:18 BHP=2119. Drilling break @ 6385 to 300'/Hr 7/20/2019 7/20/2019 0.40 PROD1 DRILL WPRT P Lost ROP. Diff pressure spike to 1450 6,406.0 6,406.0 23:18 23:42 then drop. PUH, 200 PSI increase in free spin. Unable to get differential pressure or reactive torque. Try spudding to bottom. Unable o get any pressure changes from motor 720/2019 7/21/2019 0.30 PROD1 DRILL TRIP T Trip out to investigate failure, 6,406.0 5,390.0 23:42 00:00 PUW=42K 7/21/2019 721/2019 1.70 PROD1 DRILL TRIP T Trip for BHA failure, Perform jog 600 5,390.0 76.0 00:00 01:42 to 800'. Saw increased cuttings @ 800' 721/2019 7/212019 2.00 PROD1 DRILL PULD T At surface, PJSM, PUD BHA -45 76.0 0.0 01:42 03:42 Motor has failed. Metal chunks in bit 7/212019 7/21/2019 0.80 PRODi DRILL CTOP P Service / Inspect upper NRJ 0.0 0.0 03:42 04:30 7/212019 7/21/2019 1.80 PROD1 DRILL PULD T PD, drilling BHA#6 53.0 04:30 06:18 7/212019 7/21/2019 1.00 PRODt DRILL TRIP T Tag up, reset counters, RIH 3,978.0 06:18 07:18 7/21/2019 7/21/2019 0.20 PROD, DRILL DLOG T Log formation fordeplh control r4.044.0 4,044.0 07:18 07:30 (Ugnui) correction of plus 3.5', close CV, PUW 28 k 7/21/2019 7/21/2019 1.00 PRODi DRILL TRIP T Continue IH, log R4markerw/no 6,407.0 07:30 08:30 correction 7/212019 7/21/2019 5.25 1 PROD1 DRILL DRLG P OBD, 2.8 bpm at 2,130 psi, BHA 6,407.0 6,800.0 08:30 13:45 Diff=466, WHP=43, BHP=2,059, IA=14, OA=509 7/21/2019 7/21/2019 0.50 PROD1 DRILL WPRT P Wiper up hole, PUW 48 k 6,800.0 6,000.0 13:45 14:15 7/21/2019 7/21/2019 0.30 PROD1 DRILL WPRT P Wiper back in hole RIW 10 k 6,000.0 6,800.0 14:15 7I21I2019 14:33 7/21/2019 3.20 PROD1 DRILL DRLG P BOBD, 2.8 bpm at 2,448 psi, BHA 6,800.0 7,120.0 14:33 17:45 Diff --638, WHP=53, BHP=2,171, IA=52, OA=694 7/212019 7/21/2019 0.10 PROD1 DRILL WPRT P Pull BHA wiper, PUW=60K 7,120.0 7,120.0 17:45 7/21/2019 17:51 7/21/2019 0.90 PROD1 DRILL DRLG P 7120', Drill, 2.8 BPM @ 2969', 7,120.0 7,200.0 17:51 18:45 BHP=2321. New mud @ bit 7146' 7/21/2019 7/21/2019 0.40 PROD1 DRILL WPRT P 7200' Pull 500' wiper, PUW=57K 7,200.0 7,200.0 18:45 19:09 7/21/2019 7/21/2019 3.30 PROD1 DRILL DRLG P 7200', Drill, 2.8 BPM @ 2944 PSI FS, 7,200.0 7,375.0 19:09 22:27 BHP=2166 7/21/2019 7/22/2019 1.55 PROD1 DRILL WPRT P Call pilot hole TD, Pull wiper to swab, 7,375.0 4,450.0 22:27 00:00 PUW=52K, Drilled 968', AVG DLS 6.45°. Rotary mode 639'. Sliding / orienting 329'. AVG Rotary DLS 4.3° 7/22/2019 722/2019 1.10 PRODt DRILL WPRT P Continue swab wiper to surface, Jog 4,450.0 65.0 00:00 01:06 800 to 1 000'with additional cuttings. Tag up and set counters Page 5119 Report Printed: 8/2112019 Vperations Summary (with Timelog L-pths) 1 R-126 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Deem start Time EndTere Dur (hr) Phase Cp Cotle Acavey Code Time P -T -X Operation (BKB) EM Depth (flKB) 7/22/2019 7/22/2019 1.00 PRODI DRILL WPRT P RBIH on wiper trip 65.0 3,930.0 01:06 02:06 7/22/2019 7/22/2019 0.20 PRODI DRILL DLOG P Logformation for +11'correction 3,930.0 4,023.0 02:06 02:18 7/2212019 7/2212019 0.50 PROW DRILL WPRT P Continue in well. Clean pass through 4,023.0 5,000.0 02:18 02:48 window. Clean to 5000' 7/22/2019 7/22/2019 1.20 PROD1 DRILL WPRT P Pull up hole slowly waiting on sweep, 5,000.0 71.0 02:48 04:00 PUW=40K, Trip out @ 4900' 7122/2019 7/22/2019 1.30 PROD1 DRILL -15U-LD P At surface, PJSM, PUD BHA #6 71.0 0.0 04:00 05:18 7/22/2019 7/22/2019 1.50 PROD1 DRILL CTOP P Inspect AnTech NRJ, Good to go 0.0 0.0 05:18 06:48 7/22/2019 7/22/2019 1.75 PROD1 DRILL F5 -ULD P PD and surface test lateral drilling 0.0 54.2 06:48 08:33 aseembly (good -test), 7/22/2019 7/22/2019 1.30 PROD1 DRILL TRIP P Tag up, reset counters, RIH 54.2 3,980.0 08:33 09:51 7/22/2019 7/22/2019 0.40 PROD1 DRILL DLOG P Log formation for depth center[, plus 3,980.0 4,044.0 09:51 10:15 10.0' 7/22/2019 7122/2019 0.40 PROD1 DRILL DLOG P Continue down to log, observed RA 4,480.0 4,494.0 10:15 10:39 1 marker, stop and correct plus 5.0' 7/22/2019 7/22/2019 0.40 PROD1 DRILL TRIP P Continue RIH 4,495.0 4,892.4 10:39 11:03 7/2212019 7/22/2019 0.30 PROD1 DRILL TRIP P At setting depth, function closed CV in 4,892.4 4,880.0 11:03 11:21 open hole, bring pump up to shear @ 5,014 psi, set down 3.3 k, PUW 27 k, TOB @ 4,880' 7/22/2019 7122/2019 0.75 PRODI DRILL TRIP P POOH 4,880.0 54.2 11:21 12:06 7/22/2019 7/22/2019 1.10 PROD1 DRILL PULD P At surface, PUD and LD Setting tools 54.2 0.0 12:06 13:12 7/22/2019 7/22/2019 0.50 PROD1 DRILL CTOP P Perform Function Test 0.0 0.0 13:12 13:42 7/22/2019 7122/2019 1.50 PROD1 DRILL PULD P PD, Lateral drilling assembly 0.0 57.5 13:42 15:12 7/22/2019 7/22/2019 1.00 PRODI URILL P Inspect AnTech NRJ 57.5 57.5 15:12 16:12 7/22/2019 7/22/2019 0.75 PROD? DRILL TRIP P MU INJH, surface test tools (good- 57.5 4,480.0 16:12 16:57 test), tag up reset counters 7/2212019 7/22/2019 0.30 PRODI DRILL DLOG P Log RA tag, correction of plus 6.5' 4,480.0 4,523.0 16:57 17:15 7/2212019 7/22/2019 1.00 PROD1 DRILL TRIP P Continue IH, dry tag TOB @ 4,870', 4,523.0 17:15 18:15 5.5k DHWOB 7/22/2019 7/22/2019 0.75 PROD1 DRILL MILL T PUH, bring pump online, flow 2.8 bpm 4,870.0 4,872.0 18:15 19:00 at 2,742 psi, BHA Duff 940-1,500, WHP=42, obtain parameters, RIH, past initial tag to 4872', Confer with town team, continue pushing down hole, 7/22/2019 7/22/2019E1.000 PROD1 DRILL TRIP T Shut pump down, PUH and repeat dry 4,872.0 4,916.4 19:00 20:00 tag at 4872', RBIH, attempt to mill, seems we are pushing the billet, set down 2.2 k 7122/2019 7/22/2019 PROD1 DRILL DLOG T PUH, to log RA marker, correction of 4,916.4 4,914.5 20:00 20:36 minus 2.5', 712212019 7/22/2019 PROD1 DRILL TRIP T RIH, dry tag TOB at 4,914.5', PUH 4,914.5 4,914.5 20:36 21:36 slowly make all to town team 7/22/2019 7/22/2019 PROD1 DRILL TRIP T POOH for second billet, function open 4,914.5 57.5 21:36 22:36 CV above window, continue POOH 7/22/2019 7/23/2019 1.40 PRODI DRILL PULL)T At surface, PUD milling/drilling 57.5 0.0 22:36 00:00 assembly Page 6119 Report Printed: 8121/2019 operations Summary (with Timelog L �pths) 1 R-126 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stall DOpn Stad Time End Tura Dur (hr) Phew Op Code ActlWry Code Time P-T-X Operation MKB) End NPtn (MKB) 7/23/2019 7/23/2019 0.50 PR0D2 DRILL PULD T Continue to PUD lay down BHA- 0.0 0.0 1 00:00 00:30 Motor 7/23/2019 7/23/2019 0.50 PR0D2 DRILL CTOP T Inspect clean and service upper NRJ 0.0 0.0 00:30 01:00 7/23/2019 7/23/2019 2.00 PR0D2 DRILL PULD T PJSM, PD BHA*9 OH Anchor billet. 0.0 57.5 01:00 03:00 Make up to coil and surface test tool 7/23/2019 7/23/2019 0.50 PR0D2 DRILL TRIP T RIH BHA #9 57.5 3,900.0 03:00 03:30 7/23/2019 7/23/2019 0.30 PR0D2 DRILL DLOG T Log formation for+12.5, PUW=38K 3,900.0 3,940.0 03:30 03:46 7/23/2019 7/23/2019 0.70 PR0D2 DRILL TRIP T Continue in well. Clean pass through 3,940.0 4,920.0 03:48 04:30 window. Correct +3' at RA marker. Continue in hole. See first billet @ 4920 with 1.8K DHWOB. Orient to 345°ROHS. Stand by for confirmation from town 7/23/2019 7/23/2019 0.20 PR0D2 DRILL TRIP T PUH to check depths at RA marker 4,920.0 4,480.0 04:30 04:42 7/23/2019 7123/2019 0.20 PROD2 DRILL DLOG T Log RA marker for-2 4,480.0 4,514.0 04:42 04:54 7/23/2019 723/2019 0.30 PROD2 DRILL TRIP T RBIH, Tag first billet @ 4919. Orient to 4,514.0 4,919.0 04:54 05:12 345'ROHS. Close CV. Bring on pumps. See tool shift @ 4100 PSI, Set down5.5K, TOB=4906.6 7/2312019 7/2312019 1.20 PR0D2 DRILL TRIP T POOH 4,919.0 67.0 05:12 06:24 7/23/2019 7/23/2019 2.10 PRO D2 DRILL PULD T At surface, PJSM. PUD BHA #9. 67.0 0.0 06:24 08:30 7/2312019 7/23/2019 1.50 PR0D2 DRILL PULD T PJSM, P/U and pressure deploy BHA 0.0 57.0 08:30 10:00 #10 with .8° AKO motor, agitator, and HYC bi center. Service upper NRJ. Replace flow tube. Make up to coil and surface test 7/23/2019 723/2019 0.70 PR0D2 DRILL TRIP T RIH BHA #10 57.0 3,900.0 10:00 10:42 7/2312019 7/23/2019 0.80 PR0D2 DRILL DLOG T Log formation, Correct +12, Log by RA 3,900.0 4,903.0 10:42 11:30 1 for -2' Continue to top of billet 7/23/2019 7/23/2019 1.10 PR0D2 DRILL MILL P Dry tag TOB @ 4903, PUH Bring on 4,903.0 4,904.0 11:30 12:36 pumps 2.8 BPM @ 3060 PSI FS, BHP=1910 PSI. Mill V1 Hour TR=30R 7/23/2019 7/23/2019 0.60 PR0D2 DRILL MILL P Go to 2'/ Hour, Keep WOB under 1 K 4,904.0 4,905.0 12:36 13:12 7/2312019 7/23/2019 0.20 PR0D2 DRILL MILL P Go to T/ Hr, 2.8 BPM @ 3060 PSI FS 4,905.0 4,906.0 13:12 13:24 7/23/2019 7/23/2019 0.70 PR0D2 DRILL DRLG P 4906' Control drill ahead 4,906.0 4,950.0 13:24 14:06 7/23/2019 7/2312019 0.20 PR0D2 DRILL WPRT P 4950 Wiper trip past billit area, to 4850 4,950.0 4,950.0 14:06 14:18 PUW=40K. Billit area clean 7/23/2019 7/23/2019 1.80 PR0D2 DRILL DRLG P 4950', Drill Ahead, 2.8 BPM @ 3336 4,950.0 5,208.0 14:18 16:06 PSI FS, BHP=1913, Diff press=1230 7/23/2019 7/23/2019 0.20 PR0D2 DRILL WPRT P 5208', Pull up for survey 5,208.0 5,208.0 16:06 16:18 reconcilliation, PUW=42K 7123/2019 7/23/2019 0.80 PR0D2 DRILL DRLG P 5208', Drill, 2.8 BPM @ 3320 PSI FS, 5,208.0 5,242.0 16:18 17:06 BHP=1967 723/2019 7/23/2019 0.40 PR0D2 DRILL WPRT P Wiper trip to window. PUW=30K 5,242.0 4,485.0 17:06 17:30 7/2312019 7/232019 0.50 TROD2 WPRT P RBIH, RIW=13K 4,485.0 5,242.0 17:30 18:00 7/23/2019 7/2312019 2.20 PR0D2 DRILL DRLG P BOBD, 2.8 BPM @ 2900 PSI FS, BHP 5,242.0 5,652.0 18:00 20:12 2100 PSI Page 7119 Report Printed: 8121/2019 operations Summary (with Timelog Lvpths) 1 R-126 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Deem slarl Time End Torre Dur (hr) Phaw op Code Ad ty Code opwalion (") 5,652.0 EM Depth (110) 4,950.0 7/23/2019 7/23/2019 0.40 PROD2 DRILL WPRT per trip, 700', PUW=42K 20:12 7/23/2019 20:36 7/23/2019 0.30 PROD2 DRILL WPRT nl'IE� BH, RIW=12K 4,950.0 5,652.0 20:36 20:54 7123/2019 7/2312019 2.90 PROD2 DRILL –5R--LG OD, 2.8 BPM @ 3000 PSI FS, BHP 5,652.0 6,000.0 20:54 23:48 04PSI 00BHA Wiper @ 5857', PUW=46K, W=10K BOBD, 2.8 BPM @ 2980 PSI FS, BHP 2100 PSI 0.25 BPM Losses @ 6000' 7/23/2019 7/24/2019 0.20 PROD2 DRILL WPRT P Wiper Trip, 800', PUW=48K 6,000.0 5,200.0 23:48 7124/2019 00:00 7/24/2019 0.50 PROD2 DRILL WPRT P RBIH after Wiper, RIW=13K 5,200.0 6,000.0 00:00 7/24/2019 00:30 7/24/2019 1.50 PROD2 DRILL WPRT P BOBD 2.8 BPM @ 3100 PSI FS, BHP 6,000.0 6,210.0 00:30 02:00 2130 PSI, WHIP 54 PSI, Diff 1200 PSI 0.25 BPM Losses Mud Swap 2.6% Solids Old System, New Mud at Bit: 6055' 100' BHA Wiper at 6138', PUW=39K, RIW=10K BOBD 2.8 BPM @ 2980 PSI FS, BHP 2050 PSI, WHIP 55 PSI, Diff1400 PSI 100' BHA Wiper @ 6206', PUW=47K, RIW=10K Diff less than free spin tagging bottom, pull window wiper 200' early. 712412019 7/2412019 1.80 PROD2 DRILL WPRT P Wiper trip to window. PUW=47K. 6,210.0 4,095.0 02:00 03:48 Circulate bottoms up at window. MW out 2 ppg over MW in. Blow down micromotion to correct. 7/24/2019 7/24/2019 1.00 PROD2 DRILL WPRT P RBIH, Tie in to R4 Tag, +2' Correction, 4,095.0 6,210.0 03:48 04:48 RIW=12K 7/24/2019 7/24,2019 1.60 PROD2 DRILL DRLG P BOBD 2.8 BPM @ 2570 PSI FS, BHP 6,210.0 6,610.0 04:48 06:24 2000 PSI, WHIP 44 PSI. No Losses. 7/24/2019 7/24/2019 0.50 PROD2 DRILL WPRT P 6610, Pull 800' wiper, PUW=51K 6,610.0 6,610.0 06:24 7/24/2019 06:54 7/24/2019 1.10 PROD2 DRILL DRLG P 6610', Drill, 2.8 BPM @ 3071 Circ PSI, 6,610.0 6,815.0 06:54 08:00 BHP=1994, Di"- 077 7/24/2019 7/24/2019 0.10 PROD2 DRILL WPRT P Pull BHA Wiper, PUW=477 6,815.0 6,815.0 08:00 7/24/2019 08:06 7/24/2019 0.80 PROD2 DRILL DRLG P 6815', Drill, 2.8 BPM @ 3104 Circ PSI, 6,815.0 7,010.0 08:06 08:54 BHP=1069, Diff--1069 7/24/2019 7/24/2019 0.50 PROD2 DRILL WPRT P Pull 800' Wiper, PUW=45K 7,010.0 7,010.0 08:54 7/2412019 09:24 7/24/2019 1.80 PROD2 DRILL DRLG -F— 7010', Drill, 2.8 BPM @ 3255 Circ PSI, 7,010.0 7,410.0 0924 11:12 BHP=2040, Diff-1215, RIW=3.5K, DHWOB=2.2K. Decision to plug back. Drop angle to cross cut area 7/24/2019 7/24/2019 2.00 PR0D2 DRILL WPRT T Call TD. Pump sweeps, Chase to 7,410.0 60.0 11:12 13:12 swab in preparation for Anchored billet 7,24/2019 7/24/2019 0.70 PROD2 DRILL WPRT T At surface. reset counters, RIH 60.0 3,920.0 13:12 7/24/2019 13:54 7/24/2019 0.10 PROD2 DRILL DLOG T Log formatioEfor 0' correction 3,920.0 3,980.0 13:54 14:007/24/2019 7/24/2019 050 PROD2 DRILL WPRT T Continue in an pass through 3,980.0 5,005.0 14:00 14:30 window 7/24/2019 7/24/2019 2.10 PROD2 DRILL WPRT T At 5005, Sweeps coming out, POOH. 5,005.0 70.0 14:30 16:36 Jog inhole 200'to 700' Page 8119 ReportPrinted: 812112019 Lrperations Summary (with Timelog L�pths) 1 R-126 s Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log seat Depth Btet rima I End Tans our (hr) Phase Op CodeActivity Code Mme P-T-X Operation M(B) End Depth (flKB) 7/24/2019 7/24/2019 2.40 PROD2 DRILL PULD T At surtace, PJSM. PUD BHA#10. 70.0 0.0 16:36 19:00 Lateral Drilling BHA. Pumping MPD 280 PSI. 7/24/2019 7/24/2019 0.40 PROD2 DRILL PULD T Electrical lest upper NRJ. Good test. 0.0 0.0 19:00 19:24 Check packoff. 7/2412019 7/24/2019 1.30 PROD2 DRILL PULD T PD BHA#11. Anchored Billet. CV 0.0 70.0 19:24 20:42 Open. MPD pumped: 1 BBL. 7/24/2019 7/24/2019 1.00 PROD2 DRILL TRIP T RIH BHA #11 70.0 3,920.0 20:42 21:42 7/24/2019 7/24/2019 0.20 PROD2 DRILL DLOG T Tie in to top of Ugnu, +13' Correction. 3,920.0 4,012.0 21:42 21:54 7/24/2019 7/24/2019 0.60 PROD2 DRILL TRIP T Weight check above window, 4,012.0 4,902.0 21:54 22:30 PUW=39K. Tie into RA tag, -2' Correction. RIH to 4902.3 7/24/2019 7/24/2019 0.20 PROD2 DRILL WPST T PU to nuetral weight. Orient to 180° 4,902.0 4,890.0 22:30 22:42 ROHS. Close circulation valve. Walk up pump rate slowly to 2 BPM. Shear at 4200 PSI. Set down 6K. Top of billet at 4890'. 7/24/2019 7/24/2019 1.00 PROD2 DRILL TRIP T POOH to surface. PUW=39K. 4,890.0 70.0 22:42 23:42 7/24/2019 7/25/2019 0.30 PROD2 DRILL PULD T PJSM, PUD BHA#11. 70.0 70.0 23:42 00:00 7/25/2019 7/25/2019 1.20 PROD2 DRILL PULD T PUD BHA#11. Pump MPD @ 280 70.0 0.0 00:00 01:12 PSI. 7/25/2019 7/25/2019 1.20 PROD2 DRILL PULD T Install new boots. Test upper NRJ. 0.0 0.0 01:12 02:24 Good test. 7/25/2019 7/25/2019 1.90 PROD2 DRILL PULD T PD BHA#12. Lateral BHA. MPD 0.0 70.0 02:24 04:18 pumped: 1 BBL. 7/25/2019 7/25/2019 0.90 PROM DRILL TRIP T RIH lateral BHA. Shallow test 70.0 3,900.0 04:18 05:12 1 aggitator at 500'. 7/25/2019 7/25/2019 0.30 PROD2 DRILL DLOG T Log formation for + 8.5 3,900.0 4,000.0 05:12 05:30 7/25/2019 7/25/2019 0.30 PROM DRILL TRIP T Continue in well. Clean trip through 4,000.0 4,890.0 05:30 05:48 window. Log RA or+ 1.5' 7/25/2019 7/25/2019 1.30 PROD2 DRILL TRIP T Dry tag TOB @ 4890'. PUH bring on 4,890.0 4,901.0 05:48 07:06 pumps. Ease down to get on billet went past 4890.PUH shut down pumps. Dry tag @ 4892. Try to put a little weight on it. Sliding down hole with 5001bs WOB. Stopped # 4895 with 5K DHWOB. PUH bring pumps on feather into billet. Never able to get any differential on motor. PUH. Confer with town. Get back on billet dry. Push down to 4900 where it sat down with 7K DHWOB. PUH Run into billit working DHWOB from 5K to 1 OK. 5 cycles down. Billit not moving downhole. 7/25/2019 7/25/2019r2.50 PROD2 DRILL TRIP T Trip out of well. Call out billet with 10' 4,901.0 75.0 07:06 09:00 pup joint 7/25/2019 7/25/2019 PROD2 DRILL PULD T At surface, PJSM, PUD BHA #12 75.0 0.0 09:00 10:00 7/25/2019 7/25/2019 PROD2 DRILL PULD T PJSM, M/U and deply BHA#13.1 wth 0.0 0.0 10:00 12:30 OH anchor billet and 10' pup below anchor 7/25/2019 7/25/2019 PROD2 DRILL CTOP T Replace flow tube in upper NRJ. 0.0 0.0 12:30 13:30 7/25/2019 7/25/2019 2.00 PROD2 DRILL PULD T BHAelectrical failure. PUD BHA 0.0 0.0 13:30 15:30 #13.1. Page 91119 ReportPrinted: 812112019 Vperations Summary (with Timelog Lt;pths) 1 R-126 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log siert DeP(h stat Tone End Tina Ga(hr) Phase Op Code Activity Code Torre P -T -X Operation (MB) End Depth MKS) 7/25/2019 7/25/2019 3.50 PROD2 DRILL PULD T PD BHA#13.2. Annular pressure 0.0 0.0 15:30 19:00 sensor not reading correctly. PUD BHA#13.2 7/25/2019 7/25/2019 0.70 PROD2 DRILL PULD T Swap sensor mandrel. PU BHA 0.0 0.0 19:00 19:42 #13.3. 7/25/2019 7/25/2019 1.60 PROD2 DRILL PULD T PD BHA#13.3. Anchored billet with 0.0 71.0 19:42 21:18 10' pup. Replace flow tube in upper NRJ. 7/2512019 7/25/2019 1.00 PROD2 DRILL TRIP T RIH BH #13. Circ Valve Open. 71.0 3,950.0 21:18 22:18 7/25/2019 725/2019 0.20 PROD2 DRILL DLOG T Log top of Ugnu, +10' correction. 3,950.0 4,050.0 22:18 22:30 1 7/25/2019 725/2019 0.70 PROD2 DRILL TRIP T RIH. Tie in to RA tag, -2.5' correction. 4,050.0 4,857-0- 22:30 23:12 PUW=36K. Tag top of billet at 4897'. Work to Orient to 180 ROHS. Pick up to nuetral weight. 7125/2019 725/2019 0.30 PROD2 DRILL WPST T Close circulation valve. Pressure up 4,897.0 4,874.0 23:12 23:30 to 2400 PSI shear at 2.2 BPM. Set down 6.7K. 7/25/2019 7/2612019 0.50 PROD2 DRILL TRIP T POOH 4,874.0 3,300.0 23:30 00:00 7/26/2019 7/26/2019 0.70 PROD2 DRILL TRIP T Continue POOH 3,300.0 81.0 00:00 00:42 7/26/2019 726/2019 1.30 PROD2 DRILL PULD T PJSM, PUD BHA#13, LD setting 81.0 0.0 00:42 02:00 tools. (Clay on top of coil connector.) Pump MPD @ 280 PSI. Test a -Line. Good lest. 726/2019 7/26/2019 1.20 PROD2 DRILL PULD T PD, BHA #14. Lateral BHA, 0.7 AKO. 0.0 58.0 02:00 03:12 1 MPD pumped 0.5 BBL 7/26/2019 7/26/2019 1.00 PRO02 DRILL TRIP T RIH, Shallow test aggitator, 2596 PSI 58.0 3,930.0 03:12 04:12 free spin. 7/26/2019 7/262019 0.40 PR0D2 DRILL DLOG T Tie in to top of Ugnu, +23' correction. 3,930.0 4,060.0 04:12 04:36 7/26/2019 7/26/2019 0.30 PROD2 DRILL TRIP T RIH, Tie in to RAtag, -1.5' correction. 4,060.0 4,888.0 04:36 04:54 RIH 7/26/2019 726/2019 0.60 PROD2 DRILL DRLG P Dry tag top of billet at 4888', 2.31K, 4,888.6 4,888.6 04:54 05:30 PUH bring on pump. 2.8 BPM @ 2750 PSI FS, BHP=1938. Start milling off billet 4888.6, 1 Ft/Hr 726/2019 7/262019 1.00 PROD2 DRILL DRLG P 4889.6, Aluminum at shaker, Go to 2 4,888.6 4,890.6 05:30 06:30 Ft/Hr 726/2019 7/26/2019 0.40 PROD2 DRILL DRLG P Go to 3 Ft/Hr 4,890.6 4,895.0 06:30 06:54 7/26/2019 726/2019 1.10 PROD2 DRILL DRLG P 4895.0 Motor stall, PUW=39K. RBIH 4,895.0 4,895.0 06:54 08:00 stall again 7/26/2019 7/26/2019 0.30 PROD2 DRILL DRLG P Control drill 8595 past stall point clean 4,895.0 4,910.0 08:00 08:18 7126/2019 7/26/2019 0.30 PROD2 DRILL DRLG P Go to 60 FPH, 2.8 BPM @ 2811 PSI, 4,910.0 4,920.0 08:18 08:36 Diff -967, BHP=1933 7126/2019 7/26/2019 0.30 PR0D2 DRILL DRLG T Having problems with orienter, PUH 4,920.0 4,812.0 08:36 08:54 above billet. PUW=38K. PUH slowly while trouble shooting surface gear 7/26/2019 7/262019 1.30 PROD2 DRILL TRIP T Trip out for failed orienteer 4,812.0 75.0 08:54 10:12 7/26/2019 7/26/2019 1.00 PROD2 DRILL PULD T At surface, PJSM, PUD BHA #14 75.0 0.0 10:12 11:12 7/26/2019 7/26/2019 1.40 PROD2 DRILL OTHR T Lay down tool and trouble shoot, 0.0 0.0 11:12 12:36 Swap out lower NRJ. Bit @ 1-1 7/26/2019 7/26/2019 2.40 PROD2 DRILL PULD T PJSM. P/U BHA#15 and pressure 0.0 57.5 12:36 15:00 deploy, Make up to coil and surface test. Tag up and space out Page 10119 Report Printed: 812112019 operations Summary (with Timelog bvpths) 1 R-126 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Stant Time FJW Time Ow(hr) phase Op code AWVRy Cafe Time P -T-% Operation (flKO) End Oepth(Id(6) 2,800.0 7/26/2019 7/26/2019 1.00 PROD2 DRILL TRIP T RIH BHA#15, Shallow test agitator, 57.5 15:00 16:00 Continue in well 7/26/2019 7/26/2019 0.20 PR0D2 DRILL TRIP T Stop running in. Antech sorting out 2,800.0 2,800.0 16:00 16:12 tool issues after shallow agitator test 7126/2019 7/26/2019 0.80 PROD2 DRILL TRIP T Lost comms with BHA, Trip out. 2,800.0 57.5 16:12 7/26/2019 17:00 7/26/2019 1.70 PROD2 DRILL TRIP T PUD BHA #15 Pump MPD @ 276 psi. 57.5 0.0 17:00 7/26/2019 18:42 7/27/2019 5.30 PROD2 DRILL EQRP T Redress modified Lower NRJ and 0.0 0.0 18:42 00:00 repair BHAs. 7/27/2019 7/27/2019 1.00 PROD2 DRILL EQRP T Repair BHA. 0.0 0.0 00:00 7/27/2019 01:00 7/27/2019 1.70 PROD2 DRILL PULD T PD BHA#16.1 MPD pumped 1.5 0.0 58.2 01:00 02:42 BBL. Tool failed surface lest. Lower NRJ flooded. 7/27/2019 7/27/2019 1.10 PROD2 DRILL PULD T PUD BHA#16.1 Pumping MPD @ 58.2 0.0 02:42 03:48 280 PSI. 7/27/2019 7/27/2019 2.20 PROD2 DRILL CRP T Determine incorrect NRJ to slickline 0.0 0.0 adapter has been allowing tools to 03:48 06:00 flood during pressure deployment. Rebuild BHA and replace slickline adapter. 7/27/2019 7/2712019 12.00 PROD2 DRILL EQRP T Crew change out. Run valve check 0.0 0.0 list. Stand by for Antech BHA. Inspect 06:00 18:00 DS PDL. Tighten stuffing bow & upper shieve. Install Anntech Nogo and sealing adapter in PDL wire line string. PT DS PDL to 2000 PSI. Perform DOMS on crown and traveling blocks. Continue painting projects. 7/2712019 7/27/2019 1.50 PROD2 DRILL EQRP T Continue Standby for Antech BHA. 0.0 0.0 18:00 7/27/2019 19:30 7/27/2019 2.50 PROW DRILL PULD T PD BHA#16.2 Swap upper NRJ flow0.0 58.2 19:30 22:00 tube. Meg wire. One wire reading low, but ok for now. 7/27/2019 7/27/2019 0.50 PROD2 DR ILL TRIP T RIHBHA#16. Pressures ensor not 58.2 303.0 22:00 22:30 reading correctly. Ramp pump rate and record pressure. BPM CV Closed CV Open 0.5 440 410 1.0 480 410 1.5 625 410 Conine annular pressure sensor failed. 7/27/2019 7/27/2019 0.50 PROD2 DRILL TRIP T POOH to swap sensor mandrels. 303.0 58.2 22:30 7/27/2019 23:00 7/28/2019 1.00 PROM DRILL TRIP T PUD BHA#16. Pumping MPD Q 280 58.2 0.0 23:00 00:00 PSI. 7/28/2019 7/28/2019 1.00 PROD2 DRILL EQRP T LD BHA. Swap sensor mandrel. PU 0.0 0.0 00:00 01:00 BHA. 7/28/2019 7/28/2019 1.40 PROD2 DRILL PULD T PD BHA#17. MPD pumped 0.6 BBL. 0.0 58.2 01:00 02:24 Test upper NRJ. Good test. 7/28/2019 7/28/2019 0.70 PROD2 DRILL TIH BHA#17. 58.2 3,9300 02:24 03:067/28/2019 7/28/2019 0.30 PROD2 DRILL T Log lop of Ugnu for tie-in, +10' 3,930.04,020.0 03:06 03:24 correction. 7128/2019 7/28/2019 010 5ROD2 DRILL PTRIPT TIH. PUW=38K. 4,0200 44600 03:24 7/28/2019 03:30 7/28/2019 260 PROD2 DRILL T Warm up and trouble shoot orienter 4,460.0 4,300.0 03.30 06:06 above window. 7/28/2019 7/28/2019 0.30 PROD2 DRILL TRIP T Tool is rotating in medium speed 4,300.0 4,480.0 06:06 101 1 mode, Trip in to drill Page 11119 Report Printed: 9/21/201911 operations Summary (with Timelog Lvpths) 1 R-126 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten DePlh Stern" End Time our (a) Phase Op Code ActW'ity Code DLOG Time P -T -X T 01'emean Clean pass through window, Log RA take) 4,480.0 End Depth(aKB) 4,911.0 7/28/2019 7128/2019 0.40 PROD2 DRILL 06:24 06:48 marker for no correction 7/28/2019 7/26/2019 1.50 PROD2 DRILL DRLG P 4911', Drill, 2.8 BPM @ 2922 PsT-F-s7 4,911.0 5,065.0 06:48 08:18 BHP=1955, New mud @ bit @ 4949' 7/28/2019 7/28/2019 0.30 PROD2 DRILL WPRT P 5065', Wiper trip, PUW=36K 5,065.0 5,107.0 08:18 7/28/2019 08:36 7/2812019 1.90 PROD2 DRILL DRLG T 5107. Tool not steering correctly. Trip 5,107.0 72.0 08:36 10:30 out to inspect BHA and increase AKO. 7/28/2019 7128/2019 2.00 PROD2 DRILL PULD T At surtce, PJSM, PUD BHA#17, Lay 72.0 0.0 10:30 12:30 down tool 7/28/2019 7/28/2019 4.50 PROD2 DRILL CTOP T Get tool to Antech shop. Disassemble 0.0 0.0 12:30 17:00 upper NRJ. couple of wires outside normal parameters. Position spool, Disassemble pressure bulkhead for inspection / testing. Replace bulkhead feed throughs. 7/28/2019 7128/2019 4.00 PROD2 DRILL RGRP T Cracks found on coil reel while 0.0 0.0 17:00 21:00 working in bulkhead. Call out welder to repair. Weld cracks. 7/28/2019 7/29/2019 3.00 PROD2 DRILL CTOP T Re -head eLine. #6 wire still failing 0.0 0.0 21:00 00:00 MEG test. Continue to troubleshoot. 7/29/2019 7129/2019 3.50 PROD2 DRILL CTOP T Continue troubleshooting eLine. Call 0.0 0.0 00:00 03:30 out electrician. Bad test. Trim 8' coil. Retest eLine. Bad Test. Trim another 5'. Bad Test. Trim 10'. Bad test. (23' total cut) Discuss with town. 7/29/2019 7/29/2019 1.10 PROD2 DRILL CTOP T Boot eLine. Stab on to stack. Pump 0.0 0.0 03:30 04:36 slack backwards. (3000 PSI @ 7 BPM) 7/29/2019 7/2912019 3.90 PROD2 DRILL CTOP T Rig up hydraulic cutter. Found wire 2' 0.0 0.0 04:36 08:30 up. Cut 100' CT and retest wire. Wire #6 still low meg ohmes. Cut 50' Retest wire same. Cut 170'total CT 168' Wire 7/29/2019 7/29/2019 1.00 PROD2 DRILL CTOP T Make up CTC, Pull test to 35K. Make 0.0 0.0 08:30 09:30 up plug and pressure test CTC to 4000 PSI 7/29/2019 7/29/2019 2.30 PROD2 DRILL CTOP T Head up Antech upper NRJ and test 0.0 0.0 09:30 7/29/2019 11:48 7129/2019 1.20 PROD2 DRILL PULD T PJSM, M/U BHA#18 with 1.6° AKO 0.0 58.2 11:48 13:00 motor and rebuild HCC bi center. Pressure deploy. Make up to coil and surface test tool. GOOD. Check packoffs 7/29/2019 7129/2019 1.00 FR DRILL TRIP T Trip in well, Shallow test BHA @ 300' 58.2 4,000.0 13:00 7/29/2019 14:00 7/2912019 0.20 PROD2 DRILL DLOG T Log formation for+10.5' correction 4,000.0 4,051.0 14:00 7129/2019 14:12 1712912019 0.40 PR0D2 DRILL TRIP T Continue in. Clean pass through 4,051.0 5,107.0 14:12 14:36 window. See RA for no correction 7/29/2019 7/29/2019 0.20 PROD2 DRILL DRLG P 5107', Drill, 2.8 BPM @ 3548 PSI, 5,107.0 5,160.0 14:36 14:48 BHP=2004, RIW=14.9. Never able to get more then 400LBS DHWOB, AVG DLS=17° 7/29/2019 7/29/2019 2.00 PROD2 DRILL TRIP P 5160', Inclination @ 92°. 6' below plan 5,160.0 75.0 14:48 16:48 3° above dip. Trip for BOPE test. LowerAKO motor. At 200' plugged off choke. Heavy aluminum coming back. Jog in hole to help clear 7/29/2019 7/29/2019 1.50 PROD2 DRILL PULD P PJSM,Atsurface,PUDBHA#17. 75.0 0.0 16:48 16:18 Pumping MPD @ 280 PSI. 729/2019 7/29/2019 1.70 PROD2 WHDBOP DISP P MU nozzle, slab onto well, Bush 0.0 0.0 18:18 20:00 stack. Displace coil and slack to fresh water. Unstab. Page 12119 Report Printed: 8/21/2019 operations Summary (with Timelog L.pths) 1 R-126 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) phase op code Adlvlly Code Time P -T -X Operation MKB) End Depth rtM 7/29/2019 7/29/2019 1.80 PROD2 WHDBOP MPSP P PJSM. Rig up polish rod lubricator. 0.0 0.0 20:00 21:48 Stop pumping MPD. Lubricate in test plug. Attempt to bleed oft, unable. Pressure up. Test plug holding from above. Discuss with town. Proceed. Rig down polish rod lubricator. 7/29/2019 7/29/2019 1.70 PROD2 WHDBOP PRTS P Grease stack and tree. PJSM. Fluid 0.0 0.0 21:48 23:30 pack stack. 7/29/2019 7/29/2019 0.10 PROD2 WHDBOP PRTS P Shell test 3500 psi. 0.0 0.0 23:30 23:36 7/29/2019 7130/2019 0.40 PROD2 WHDBOP BOPE P Begin full BOPE test. 250 PSI low, 0.0 0.0 23:36 00:00 3500 PSI high. Witness waived by Brian Bixby with AOGCC. 7/30/2019 7/30/2019 3.70 PROM WHDBOP BOPE P Continue full BOPE test. 250 PSI tow, 0.0 0.0 00:00 03:42 3500 PSI high. Witness waived by Brian Bixby, AOGCC. 4.30 PROD2 WHDBOP BOPE T Test joint slide slightly while pressuring 0.0 0.0 08:00 up 3-1/2" rams. Reset joint. Joint slid again @ 2100 PSI. Swap out 2 5/B" pipe rams. Perform shell test. Test 2 F7130/2O197/30/2019 5/8" rams. Good test no slippage. 7/30/2019 2.00 PROD2 WHDSOP BOPE P Test VBRs on 3-1/2" and 2-3/8", 0.0 0.0 10:00 unable to get good test on 2-3/8", swap to 2-5/8" test jnt, no good, decision made to swap out variable rams 7/30/2019 7/30/2019 3.60 PROD2 WHDBOP BOPE T Pull VBR's, rubber elements in bad 0.0 0.0 10:00 13:36 shape, determine incormacl ram blocks, replace w/ corrected ram blocks 7/30/2019 7/30/2019 1.00 PROD2 WHDBOP BOPE P PU test joint, perform shell test, 0.0 0.0 13:36 14:36 continue BOP test 7/30/2019 7/302019 1.80 PROD2 WHDBOP SFTY P LD test joint, MU noule, stab on, test 0.0 0.0 14:36 16:24 IRV, unstab, break -off noule " Saftey Stop: Gather all for rig personell for short Nabors Safety Week meeting 7/30/2019 712019 /30 1.25 PROD2 WHDBOP PRTS P Pull test plug 0.0 0.0 16:24 17:39 7/3012019 7/30/2019 0.75 PROM WHDBOP CTOP P RD equipment and tools for 0.0 0.0 17:39 18:24 changeout. 7/3012019 7/30/2019 0.25 PROD2 WHDBOP CTOP P Perform Valve check list, crew 0.0 0.0 1824 18:39 change, perform drawdown 7/30/2019 7/30/2019 0.50 PROM WHDBOP CTOP P Blew down testing equipment and 0.0 18:39 19:09 drilling choke 7/30/2019 7/30/2019 0.70 PROD2 WHDBOP CTOP P MU nozzle, stab INJH, circulate 2.8 0.0 0.0 19:09 19:51 bpm swapping coil over to drilling fluid. 7/30/2019 7/30/2019 1.00 PROD2 DRILL PULD P PJSM for MU drilling assembly, slide 0.0 0.0 19:51 20:51 cart forward inspect AnTech NRJ 7/30/2019 7/302019 1.30 PROD2 DRILL PULD P MU and PD drilling assembly 0.0 58.2 20:51 22:09 7/30/2019 7/3012019 0.20 PROD2 DRILL PULD P Surface test tools (good), tag up reset 58.2 58.2 22:09 2221 Counters 7/30/2019 7/30/2019 PROD2 DRILL TRIP P RIH w/drilling assembly BHA#19 58.2 3,930.0 22:21 22:21 7/30/2019 7/30/2019 PROD2 DRILL DLOG P Log formation for depth control 3,930.0 3,954.0 22:21 22:21 (+10.0') 7/30/2019 7/30/2019 1 1 PROD2 DRILL TRIP P Continue IH, log the RA marker (+0.5') 3,954.0 4,957.0 22:21 22:21 7/31/2019 7/3112019 0.30 PROD2 DRILL TRIP P Continue IH 4,957.0 5,160.0 00:00 00:18 Page 13119 ReportPrinted: 8121/2019 operations Summary (with Timelog Lcpths) 1 R-126 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time LOU sten Dean Stan Tims I End Time Dur(hr) Phew Op Code Aodv4 Code Time P-T-% Opeiabon (W13) End Depth (ftKa) 7/3112019 7/31/2019 1.20 PROD2 DRILL DRLG P OBD, 2.8 bpm @ 2,425 psi, Diff-920 5,160.0 5,428.0 00:18 01:30 psi, WHP=43, BHP=1985, IA=O, OA=555 7/31/2019 7/31/2019 0.20 PROD2 DRILL WPRT P BHA Wiper up hole, PUW 40 k 5,428.0 5,428.0 01:30 01:42 7131/2019 7131/2019 0.30 PROD2 DRILL DRLG P BOBD, 2.8 bpm @ 2,425 psi, Diff--920 5,428.0 5,430.0 01:42 02:00 psi, WHP=43, BHP=1985, ]A=O, OA=555 7/3112019 7/31/2019 1.00 PROD2 DRILL DRLG P OBD, 2.8 bpm @ 2,425 psi, Diff-920 5,430.0 5,560.0 02:00 03:00 psi, WHP=43, BHP=1985, IA=O, OA=555 - Note: Man Down Drill with AAR details in SFTY Meetings/Operational Checks 7/31/2019 7131/2019 0.30 PROD2 DRILL WPRT P Wiper up hole to 4,950', PUW 38 k 5,560.0 4,950.0 03:00 03:18 7/3112019 7/3112019 0.30 PROD2 DRILL WPRT P Wiper back in hole, RIW 14 k 4,950.0 5,560.0 03:18 03:36 7/31/2019 7131/2019 2.80 PROD2 DRILL DRLG P BOBO, 2.8 bpm @ 2,340 psi, Diff=731 5,560.0 5,966.0 03:36 06:24 psi, WHP=46, BHP=1984, IA=O, OA=578 7/31/2019 7/31/2019 0.30 PROD2 DRILL WPRT P Wiper up-hole, PUW =39K 5,966.0 5,166.0 06:24 06:42 7/31/2019 7/31/2019 0.40 PROD2 DRILL WPRT P Wiper in-hole, RIW =12K 5,166.0 5,966.0 06:42 07:06 7/31/2019 7/31/2019 3.20 PROD2 DRILL DRLG P Drilling, FS = 1000 psi @2.8 bpm, 5,966.0 6,455.0 0706 10:18 CWT = 8.41K, WOB = 2.51K, BHP = 3397 psi, 10.8 ppg @ window, stall at 5989', PUW = 43K, difficulty working to bottom, lower ROP at -20 fph, then break out, pump sweeps 7/31/2019 7/31/2019 0.90 PROD2 DRILL WPRT P Wiper to window, -4K WOB tug at 6,455.0 4,485.0 10:18 11:12 4515', PUW = 42K 7/31/2019 7/312019 0.20 PROD2 DRILL DLOG P Log RA for+3' correction 4,485.0 4,567.0 11:12 11:24 7131/2019 7/3112019 0.60 PROD2 DRILL WPRT P Wiper in-hole, RIW =7.7K 4,567.0 6,455.0 11:24 12:00 7/31/2019 7/312019 2.30 PROD2 DRILL DRLG P Drilling, FS = -1000 psi @ 2.8 bpm, 6,455.0 6,850.0 12:00 14:18 CWT = 3K, WOB = 3K, bhp = 3111 psi, pump = 2912 psi, pump sweeps 7/3112019 7/31/2019 0.30 PROD2 DRILL WPRT P Wiper up-hole, PUW =50K 6,850.0 6,204.0 14:18 14:36 7/31/2019 7/31/2019 0.30 PROD2 DRILL WPRT P Wiper in-hole, RIW = 8.51K 6,204.0 6,850.0 14:36 14:54 7/31/2019 7/31/2019 1.90 PROD2 DRILL DRLG P Drilling, FS = 1000 psi @ 2.8 bpm, 6,850.0 7,255.0 14:54 16:48 CWT = 6.5K, WOB = 1.5K, BHP = 3233 psi, 10.8 ppg @ window, pump = 3008 psi, swap to new mud system #6 (6% KCI), new mud at bit at 7242' 7/31/2019 7/31/2019 0.30 PROD2 DRILL WPRT P Wiper up-hole, PUW =49K 7,255.0 6,455.0 16:48 17:06 7/31/2019 7/31/2019 0.30 PROD2 DRILL WPRT P Wiper back in hole, RIW B.Ok 6,455.0 7,255.0 1706 17:24 7/31/2019 7/312019 2.20 PROD2 DRILL DRLG P BOBO, 2.8 bpm at 2,624 psi, 7,255.0 7,655.0 17:24 19:36 Ditf=1,001, WHP=53, BHP=2,096, IA=244, OA=852 7/31/2019 7/312019 1.20 PR0D2 DRILL WPRT P Wiper to the window, PUW 42 k 7,655.0 4,463.0 19:36 20:48 "'Note: Mud weight out increased up to 9.17 ppg, CR 0.9 Page 14119 Report Printed: 8/2112019 Liperations Summary (with Timelog L�pths) e 1R-126 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Star/ Depm Sm Time End Tmro our (m) Pnass Op Code Activity Code Time P -T -X Operation (IIKB) End Depth(RKB) 7/31/2019 7/31/2019 0.20 PROD2 DRILL DLOG P Log RA marker (+4.0') 4,463.0 4,505.0 20:48 21:00 7/31/2019 7/31/2019 -1 25 PROM DRILL WPRT P Wiper back in hole, RIW 6.0 k 4,505.0 7,655.0 21:00 22:15 7/31/2019 7/31/2019 1.50 PROD2 DRILL DRLG P BOBD, 2.8 bpm at 2,136 psi, Diff -898, 7,655.0 8,055.0 22:15 23:45 WHP=35, BHP=2,020, IA=235, OA=853 7/31/2019 8/1/2019 0.25 PROD2 DRILL WPRT P Wiper up hole PUW 37 k 8,055.0 7,851.0 23:45 00:00 8/1/2019 8/1/2019 0.20 PROM DRILL WPRT P Continue wiper up hole 7,851.0 7,255.0 00:00 00:12 811/2019 8/1/2019 0.30 PROD2 DRILL WPRT P Wiper back in hole, RIW 7 k 7,255.0 8,055.0 00:12 00:30 8/1/2019 811/2019 2.30 PROD2 DRILL DRLG P BOBD, 2.8 bpm at 2,548 psi, Dlff--836, 8,055.0 8,455.0 00:30 02:48 WHP=50, BHP=2,078, IA=254, OA=856 8/1/2019 8/1/2019 0.30 PROD2 DRILL WPRT P Wiper up hole, PUW 40 k 8,455.0 7,655.0 02:48 03:06 8/1/2019 8/1/2019 0.28 15ROD2 DRILL WPRT P Wiper back in hole, RIW 6 k 7,655.0 8,455.0 03:06 03:22 8/1/2019 8/1/2019 1.00 PROD2 DRILL DRLG P BOBD, 2.8 bpm at 2,643 psi, 8,455.0 8,628.0 03:22 04:22 DITf-1,230, WHP=50, BHP=2,118, IA=280, OA=872 8/1/2019 8/1/2019 0.20 PROD2 DRILL WPRT P PUH and cycle power to tools, RBIH 8,628.0 8,628.0 04:22 04:34 811/2019 8/1/2019 1.00 PROM DRILL DRLG P BOBD, 2.8 bpm at 2,643 psi, 8,628.0 8,855.0 04:34 05:34 Diff -1,230, WHP=50, BHP=2,118, IA=280, OA=872 8/1/2019 81112019 1.50 PROD2 DRILL WPRT P Wiper to window, PUW=45K 8,855.0 4,458.0 05:34 07:04 8/1/2019 8/1/2019 0.20 PROD2 DRILL DLOG P Log RA for+5' correction 4,458.0 4,550.0 07:04 07:16 8/1/2019 8/1/2019 1.40 PROD2 DRILL WPRT P Wiper in-hole, RIW = 5K 4,550.0 8,855.0 07:16 08:40 1 8/1/2019 8/1/2019 2.30 PROM DRILL DRLG P Drilling, FS = 1000 psi @ 2.8 bpm, 8,855.0 9,270.0 08:40 10:58 CWT = 6.2K, WOB = 0.3K, 10.7 ppg @ window, pump = 2759 psi, pump sweeps 8/1/2019 8/1/2019 0.30 PROD2 DRILL WPRT P Wiper up -hole, PUW = 44K 9,270.0 8,316.0 10:58 11:16 8/1/2019 8/1/2019 0.40 PROM DRILL WPRT P Wiper in-hole, RIW = 3K 8,316.0 9,270.0 1116 1140 8/1/2019 8/1/2019 1.80 PROD2 DRILL DRLG P Drilling, FS = -1000 psi @ 2.8 bpm, 9,270.0 9,546.0 11:40 13:28 - CWT= -2K, WOB =0.3K, 11 ppg@ window, pump = 2864 psi, begin pumping new mud at 9399', new mud at bit at 9440' 8/1/2019 8/112019 0.90 PROD2 DRILL DRLG P PU to grab new number, PUW = 44K, 9,546.0 9,710.0 13:28 14:22 FS = 1050 psi @ 2.8 bpm, CWT = 3K, WOB = 0.3K, pump = 2540 psi, pump sweeps 8/1/2019 8/1/2019 0.30 PROD2 DRILL WPRT P Wiper up -hole, PUW = 42K 9,710.0 8,889.0 14:22 14:40 8/1/2019 8/1/2019 0.32 PROD2 DRILL WPRT P Wiper in-hole, RIW = 1K 8,889.0 9,710.0 14:40 15:00 8/1/2019 8/1/2019 1.50 PROD2 DRILL DRLG P Drilling, FS = -1000 psi @ 2.8 bpm, 9,710.0 9,994.0 15:00 16:30 CWT = -1.5K, WOB = 0.2K, BHP = 3027, ECD toe = 11.3 ppg, 10.4 ppg @ window, cutting ratio =.93, PUW = 62K from 9976', pump sweeps as required, snubbing to -8K Page 15119 Report Printetl: 8I21I2019 uperations Summary (with Timelog L,�pths) 1 R-126 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time log start Dapm Sir/Tune End Time Cur (hr) Phase Op Code Ao Ity Code Time P -T -X operation (") End Depth (Po(S) 8/1/2019 8/1/2019 0.50 PROD2 DRILL DRLG P Drilling, CWT= -4K, WOB=-.2K, 9,994.0 10,055.0 16:30 17:00 pump = 2592 psi, BHP = 2148 psi 8/1/2019 8/1/2019 —1 90 PROD2 DRILL WPRT P Wiper to the window, PUW 56 k 10,055.0 4,480.0 17:00 18:54 8/1/2o19 8/1/2019 0.20 PROD2 DRILL DLOG P Log the RA Marker (+3.5') 4,480.0 4,509.0 18:54 19:06 8/1/2019 8/1/2019 2.00 PROD2 DRILL WPRT P Wiper back in hole, RIW 15 k 4,509.0 10,055.0 19:06 21:06 8/1/2019 8/1/2019 2.00 PROD2 DRILL DRLG P BOBO. 2.8 bpm 2,646 psi, Diff=744, 10,055.0 10,286.0 21:06 23:06 WHP=54,BHP=2,103, IA=411, OA=966 8/1/2019 8/2/2019 0.90 PROD2 DRILL DRLG P OBD, 2.8 bpm 2,646 psi, Diff=744, 10,286.0 10,316.0 23:06 00:00 WHP=54,BHP=2,103, IA=411, OA=966, snubbing minus 23 k, Avg. ROP 33-50 fph "`Note: Start beaded pills 5x5 @ 10,301' 8/2/2019 8/2/2019 1.90 PROD2 DRILL DRLG P OBD, 2.8 bpm 2,579 psi, DR --859, 10,316.0 10,400.0 00:00 01:54 WHP=48, BHP=2,051, IA=259, OA=550, .• Note: Bled down OA from 953-550 psi 8/2/2019 8/2/2019 0.20 PROD2 DRILL WPRT P Wiper up hole, PUW 48 k 10,400.0 10,200.0 01:54 02:06 8/2/2019 8/212019 0.20 PROD2 DRILL WPRT P Wiper back in hole, RIW 10,200.0 10,400.0 02:06 02:18 8/2/2019 8/2/2019 1.45 PR0D2 DRILL DRLG P BOBD, 2.8 bpm at 2,740 psi, 10,400.0 10,490.0 02:18 03:45 Diff--864,WHP=51, BHP=2,086, IA=209, OA=530, snubbing -20 k, Avg. ROP 90 fph 8/2/2019 8/2/2019 0.30 PROD2 DRILL WPRT P Wiper up hole, PUW 46 k 10,490.0 9,690.0 0345 04:03 8/2/2019 8/2/2019 0.35 PROD2 DRILL WPRT P Wiper back in hole, RIW -3.0 k 9,690.0 10,490.0 04:03 04:24 8/212019 8/212019 1.50 PROD2 DRILL DRLG P BOBO, 2.8 bpm at 2,740 psi, 10,490.0 10,520.0 04:24 05:54 Diff=843,WHP=56, BHP=2,111, IA=221, OA=527 8/212019 8/2/2019 0.50 PROD2 DRILL DRLG P Drilling, snubbing up to -25K, 10,520.0 10,524.0 05:54 06:24 struggliing w/ weight transfer, difficulty building (dropping), pumping beaded pills in attempt to transfer weight to bit " Unable to stop orienlor rotation, PU off bottom, power down system to hold HIS, trouble -shoot, reboot MD software 8/2/2019 8/2/2019 0.60 PRO DRILL WAIT T Unable to power up orienter, decision 10,524.0 10,524.0 06:24 07:00 made to POOH to swap to new AnTech tools, 15 fpm past billet, clean, 15 fpm 8/212019 8/2/2019 3.00 PR0D2 DRILL TRIP T POOH, PJSM 10,524.0 58.2 07:00 10:00 8/2/2019 8/2/2019 1.80 PROD2 DRILL PULD T PUD BHA#19, bit came out a 1-2 w/ 58.2 0.0 10:00 11:48 two chipped gauge cutters, inspect non -rotating joint, inspect injector 8/2/2019 8/2/2019 0.30 PROD2 DRILL CTOP T Inspect & UT pipe (13' from CTC), 0.0 0.0 11:48 12:06 gouge in pipe at —13' from CTC, thinnest wall at .200" Page 16119 ReportPrinted: 8121/2019 Vperations Summary (with Timelog L, pths) 1 R-126 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sled oeptn Steil Time EM Tune Dw(nr) Plisse op code Activity Code Time P -T -x Openatlon (ftKB) End DepN(ftKB) 8/212019 8/2/2019 PROM DRILL CTOP T Inspect non -rotating joint, only 2 good 0.0 0.0 12:06 15:36 meg on wires out of 7, strip back cable sheathing & recheck wires, good tests, wire possibly rubbing with vibration causing sheathing to L2.10 deteriorate, re -head a -line, MU NRJ 8/212019 8/212019 PROD2 DRILL PULD T PJSM, PD BHA#20 Drilling Assembly 0.0 58.2 15:36 17:42 (50 hr NOV agitator, 1.0° AKO motor, RR Hughes bit) 8/2/2019 8/2/2019 0.75 PROD2 DRILL TRIP T RIH w/ BHA#20, slide in cart, check 58.2 3,980.0 17:42 18:27 pack -offs, MU to coil, tag up, set counters 8/2/2019 812/2019 0.25 PROD2 DRILL DLOG T Log formation correction (+7.01 3,980.0 4,020.0 18:27 18:42 -Note: Obtain Static Bottom Hole Pressure above window, 4,465'MD, 9.55 ppg, BHA Sensor @ 3,380.73' 8/2/2019 8/2/2019 2.20 PROD2 DRILL TRIP T Continue IH, logging RA marker 4,020.0 10,524.0 18:42 20:54 (+2.5) 8/2/2019 8/3/2019 3.10 PROD2 DRILL DRLG P BOBO, 2.8 bpm at 2,549 psi, Diff --974, 10,524.0 10,677.0 20:54 00:00 WHP=52, BHP=2,112, IA=O, OA=487 8/3/2019 8/3/2019 2.00 PROD2 DRILL DRLG P OBD, 2.8 bpm at 2,478 psi, Diff=669, 10,677.0 10,768.5 00:00 02:00 WHP=47, BHP=2,130, IA=15, OA=523 8/3/2019 8/3/2019 2.00 PROD2 DRILL DRLG P OBD, 2.75 bpm at 2,650 psi, Diff=620, 10,768.5 10,813.0 02:00 04:00 WHP=46, BHP=2,115, IA=50, OA=541 8/3/2019 8/312019 2.90 iROD2 DRILL DRLG P OBD, 2.75 bpm at 2,650 psi, Diff -620, 10,813.0 10,905.0 04:00 06:54 WHP=46, BHP=2,115, IA=50, OA=541, snubbing -32k CTSW, Avg. ROP 3040 fph, drill to TO of 10,905', pump 10x10 sweeps 8/3/2019 8/3/2019 2.20 PROD2 DRILL WPRT P Wiper to window, PUW=45K, pump 10,905.0 4,480.0 06:54 09:06 10x10 sweeps, log RA for+2.5' correction 8/3/2019 8/3/2019 2.50 PROD2 DRILL WPRT P Wiper in-hole, pump 1 0x1 0 followed 4,480.0 10,905.0 09:06 11:36 by new mud timed to exit bit at TO Stack weight at 4889' (billet), PUW = 39K, again stack, adjust TF to 145% clean past billet, stack CWT at 9975' (though no WOB), did not need to PU to get by 8/3/2019 8/3/2019 3.10 PROD2 DRILL WPRT P Wiper to swab valve, PUW =44K, pull 10,905.0 58.0 11:36 14:42 j to 60K at 9975' 8/3/2019 8/3/2019 0.80 PROD2 DRILL TRIP P Begin RBIH 58.0 3,978.0 14:42 15:30 8/3/2019 8/3/2019 0.10 PROD2 DRILL DLOG P Log formation for +10' correction 3,978.0 4,030.0 15:30 15:36 8/3/2019 8/32019 0.10 PROD2 DRILL TRIP P Continue RIH 4,030.0 4,457.0 15:36 15:42 8/3/2019 8/3/2019 0.30 PROD2 DRILL DLOG P Confirm 9.8 ppg kills well 4,457.0 4,457.0 15:42 16:00 MD = 4457.64, TVD -sensor = 3408', drop to 1683 psi, builds 1700 psi, EMW = 9.59 ppg 8/3/2019 8/3/2019 0.50 PROD2 DRILL DLOG P Log RA for 0' correction (time taken to 4,457.0 4,500.0 16:00 16:30 confirm between AnTech & geology) 8/3/2019 8/3/2019 2.10 PROD2 DRILL TRIP P Continue RIH, confirm TO at 10,907' 4,500.0 10,907.0 16:30 18:36 8/3/2019 8/312019 1.00 PROD2 DRILL CIRC P Send beaded LRP down coil 10,907.0 10,907.0 18:36 1936 Page 17119 ReportPrinted: 812112019 %.perations Summary (with Timelog L �pths) r; 1R-126 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log said Depth stmt Tare EIW T]M Dur(hr) Paese Op code AatWity Code Tana P -T -X Dpwatbn (11X8) End DWM (BKB) 8/3/2019 8/312019 3.30 PROD2 DRILL TRIP P POOH laying in bead LRP up to 10,907.0 58.2 19:36 22:54 4,570', continue POOH displacing well to 9.8 ppg completion fluid. 8/3/2019 8/3/2019 0.50 PROD2 DRILL OWFF P At surface, check well for flow 58.2 58.2 22:54 23:24 8/3/2019 8/4/2019 0.60 PROD2 DRILL PULD P LD drilling assembly on a dead well 58.2 0.0 23:24 00:00 "` Note: Inspect coiil, gouges are within spec, UT and record wall thickness 814/2019 8/4/2019 2.00 PROM DRILL PULD P Continue LD drilling aseembly on a 58.2 0.0 00:00 02:00 dead well, blow down motor, Load out tools to shop, 814/2019 8/4/2019 0.20 PROD2 CASING PUTS P Prep RF for Liner OPS 0.0 0.0 02:00 02:12 814/2019 8/4/2019 3.80 PROD2 CASING PUTB P PU liner completion (201 jts 2-718"), 55 0.0 1,650.0 02:12 06:00 jnts in the hole, crew change 8/4/2019 814/2019 5.50 PROD2 CASING PUTB P PJSM, continue PU 2-7/8" liner, 150 1,650.0 4,456.0 06:00 11:30 jots in the hole 814/2019 8/4/2019 2.50 PROM CASING PUTS P PJSM, discuss issues & contingencies 4,456.0 5,973.0 11:30 14:00 with liner in OH, continue PU 2-7/8" liner (201 2-7/8" jnts total), 1509.74' in OH "46K up, 26K down 8/4/2019 8/4/2019 1.50 PROD2 CASING PUTB P Swap out IiR sub &safety joint XO's to 5,973.0 6,468.0 14:00 15:30 3-1/2", PU 3-1/3" blank liner 8/412019 8/4/2019 1.30 PROD2 CASING PULD P PJSM, PU deployment sleeve, PU 6,468.0 6,468.0 15:30 16:48 BHA#21 Liner Running Tools, 8/4/2019 8/4/2019 1.75 PROD2 CASING PULD P Slide in cart, test NRJ, good, MU to 6,468.0 6,468.0 16:48 18:33 coil, lag up, set counters, PUW 43 k 8/4/2019 8/4/2019 2.40 PROM CASING RUNL P RIH, w/solid, slotted through oipen 6,468.0 10,356.0 18:33 20:57 hole, setting down 10,356' 814/2019 8/512019 3.06 PROD2 CASING RUNL P Sackout @ 10,536', PUW 76 k, 10,356.0 10,732.7 20:57 00:00 continue working liner towards bottom. stacking out -30 k 8/5/2019 8/5/2019 1.50 PROD2 CASING RUNL P Continue working liner towards 10,732.7 10,802.0 00:00 01:30 bottom, PUH to 60 k, stackout - 35 k 8/5/2019 8/512019 1.75 1 PROD2 CASING RUNL P Continue working liner towards 10,802.0 10,907.0 01:30 03:15 bottom, PUH to 60 k, stackout - 35 k, 8/5/2019 8/5/2019 0.20 PROD2 CASING RUNL P Bring pump up to 1.75 bpm, 860 psi 1o,907.0 4,404.5 03:15 03:27 diff, PUH, PUW 35 k, remove liner length from counters 8/5/2019 181512019 0.75 DEMOB WHDBOP DISP P well to SW, LRS on lotion, Displace ca 4,405.4 4,405.4 03:27 04:12 PJSM, RU to costumer line and PT line to 3,500 psi. stand by for rig ops. 8/5/2019 8/5/2019 0.20 DEMOB WHDBOP TRIP P PUH while displacing well 4,405.4 3,950.0 04:12 04:24 8/5/2019 8/5/2019 0.20 DEMOB WHDBOP CLOG P Log formation for depth check 3,950.0 4,020.0 04:24 04:36 815/2019 181512019 0.75 DEMOB WHDBOP TRIP P POOH 4,020.0 2,500.0 04:36 05:21 8/5/2019 8/5/2019 0.50 DEMOB WHDBOP FRZP P Line up to LRS, fill coil with 48 bbis of 2,500.0 2,500.0 05:21 05:51 diesel 8/5/2019 8/5/2019 0.35 DEMOB WHDBOP TRIP P Continue POOH 2,500.0 30.0 05:51 06:12 8/5/2019 8/5/2019 1.80 DEMOB WHDBOP PULD P PJSM, PUD BHA#21 30.0 0.0 06:12 08:00 " 210 psi below master Page 18119 ReportPrinted: 8/21/2019 operations Summary (with Timelog L�pths) 1 R-126 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Stan Time End Time Dur (hr) Phase Op Code Activity Code _RU Tme P -T-% Opera ion (flKB) End Depth (fiKB) 0.0 8/5/2019 8/5/2019 2.70 DEMOB WHDBOP RD P Blow down surface lines, suck out 0.0 08:00 10:42 slack, born -scope slack, pressure down koomey, break down TT hard- line, lock -out storage reel & injector, work RD check list 8/5/2019 8/5/2019 .3EMOB 10 D WHDBOP NUND P ND BOPE, RD PUTZ, continue RD 0.0 10:42 12:00 check list " Rig Released 8/5 @ 12.00 (noon) Page 19119 Report Printed: 8/21/2019 ConocoPhillips ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 1R Pad 1R-126 50-029-22193-01 Baker Hughes INTEQ Definitive Survey Report 22 August, 2019 BA ER F�UGHES �e co�oa,y Conocolthillips O ConocoPhillips Definitive Survey Report Company, ConocoPhllips Alaska Inc_Kupamk Pmfect: Kupamk River Unit Sha: Kupamk 1R Pad WWI: 1R-28 W.111mra: iRA26 Design: 1R-126 Pro(eet Knpa ck River Unit, North Slope Alaska, United States Map System: US State Plane 1927(Exact solution) System Damm Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 1R-26 Local C.minam Remfence: TVD Reference: MD Reference: Nona Reference: Survey Calculation Method: Database: Well Position .WS 600 usft Northing: (USM .E.W 000 usft Earring: Position Uncenainty 1R-1261.1 MVID(1R-1261-1) 000 usft Wellhead Elevation: Wellborn 111-126 Magnetic, Model Name Sample Date Design Audit Notes: Version: Vertical Section: Survey "man From Imi 50.00 4,463.60 4,679.77 BGGM2018 81112019 IR -1 28 1.0 Phase: ACTUAL DepiN Fre. ]TVD) (-am 4320 We01R-20 1R-26 ® 88.00uaft (1R-26) 1 R4t6 @ 00.00usft (1R-26) TNG Minimum Gurvamre i EDT 14 Alaska Producti0n Mean See Level Using Well Remrence Point Using geodetic scale factor 5,990.810.31 usft 539,029.8lusft usft Declined.. 19 16.51 To 6n Depth: 4 869.53 .Ws (..ft) 6.06 Tool Mame GYD-CT-CMS MWDOVi MWDOWSG Latduds; 70.23'9.012 Longitude: 149° 40' 33.044 W Ground Level: 41.20 ush 01, Angle FIWd Strength PI Inn 00.09 51412 .EIM Direction (mm) M 0.09 leo 66 Survey Survey I Description SMtt Date End Dam I Gyrodate contmsin9 this OVVSG MWD- Standard OWSG MWG- Standard 112&2014 Date To 7n=019 (USM wrvayryhlmore) 4,450.00 1 R-26-GYD-0T-CMS (1R-20) 4,06953 1R-1261.1 MVID(1R-1261-1) 10,072.54 1 R-126 MWD (iR-126) We01R-20 1R-26 ® 88.00uaft (1R-26) 1 R4t6 @ 00.00usft (1R-26) TNG Minimum Gurvamre i EDT 14 Alaska Producti0n Mean See Level Using Well Remrence Point Using geodetic scale factor 5,990.810.31 usft 539,029.8lusft usft Declined.. 19 16.51 To 6n Depth: 4 869.53 .Ws (..ft) 6.06 Tool Mame GYD-CT-CMS MWDOVi MWDOWSG Latduds; 70.23'9.012 Longitude: 149° 40' 33.044 W Ground Level: 41.20 ush 01, Angle FIWd Strength PI Inn 00.09 51412 .EIM Direction (mm) M 0.09 leo 66 Survey Survey I Description SMtt Date End Dam I Gyrodate contmsin9 this OVVSG MWD- Standard OWSG MWG- Standard 112&2014 1n612014 711612019 7n=019 01412819 81412019 W2 19 9.0,01" Pepe 2 COMPASS 5000.14 Budd 654' ConocoPhillips, ConocoPhillips Definitive Survey Report Compan, ConocoPhillips Abska Inc Kupamk Local Co-ordinate ROkhanoe: 8111 R-26 ProlecO Kupamk River Unit TVD Refercnce'. 1R-26®88.00usn(1 R-26) Site: Kupamk 1R Pad MD Reference: 1 R-26 ® 88.00usn (1 R46) Well: 1R-26 North Reference: True Wellbore: 1R-126 Survey Calculation Method: Minimum Curvature Dsal8n: 1R-126 Database: EDT 14 Alaska Production Map Vertical Mp IM Aad TVD MOSS •W4 .0v Northing DLS Section Survey Tool me ool Na ry AnDOd81WD (,am V) 17 luanl IMM7 lusnd (-amIrtl in) IEast,Sectio nl I°11001 Inl g869.53 07.5/ 171.64 3.405)) 3,398.]] -719.66 2648.93 599040544 5424822] 28.29 71906 MWG MSG (2) TIP 4,8]9,]] 8].45 174.32 3,407.21 3,39831 -]2921 2650.18 5,9W,f11529 54?4&15] W.17 ]29.21 MWD MSG (3) KOP 4,93000 81.08 175.99 3.49223 3,404.23 -77901 2,653,97 5,9W.M552 542,487.63 1374 ]]9.01 MWD MSG (3) 4ABEW 79.28 17.90 349821 3,410.21 -813.46 2,655.50 5,993,011.99 542,489.35 5.80 81348 MWD MSG (3) 4,99500 7857 178.01 3,50390 3415.98 -84209 2,858.35 5,989901.06 542,490.3t5 in M2,89 MVIDMSGO) 5,03355 7920 18663 3.511.41 3,423.41 Awn 2 RS53 5,90994384 542.490.74 4.91 990.Y2 MW➢OWSG(3) 5,076.99 0118 185.51 ],5186G 3,930.99 52253 2653.91 5.889902.02 54?488.33 14.46 92253 MMA) MeG(3) 5,999.50 03.16 18353 3,52191 3.433.91 546'2 2651.04 5.988,878.51 542,485.39 15.03 94602 MPoDGWOG(3) 5.1m. 14]1 10307 3.524.13 3.436.13 -97544 2650.14 5,989,049.09 577404.85 1755 975M MWO MSG (3) 5,160.34 94.1] 133.42 3.523.41 3.43541 -1.010.24 2840]] 5,98901420 542.48306 17.12 1,01024 MWD MSG(3) 5,19662 W24 1W as 3,521,49 3,43349 1.041.33 26516 5,989299.10 51240424 10.98 1,044,33 MWD MSG (3) 5,23699 91.85 199.40 3520.30 3432.35 -1,075.52 26016 5,989,74590 5424]800 0.70 107552 MD 5,271.19 91.04 183.99 351933 343133 -1,116.14 264'.94 5,909,70833 62.470.40 835 1116.14 MWD MSG 13) 5.300.30 9127 185.09 3,518.74 3430.]4 4,146.15 2.01.60 5Sell.31 542.467.30 361 1,145.15 MJNGWSG(3) 5.333.40 91.81 165.99 3.59.85 3,428.85 -1,170.05 2,838.31 5.989.846.39 501.46.10 to 1,17005 MAID MSG (3) ' 5.399,60 90.71 185.85 3.517.25 3,49.25 -120452 262561 598961991 542,461,6 3.91 1,284.52 MVVDMDG(3) 5.391]4 00.59 18592 3,517.43 3.429.43 -1236.00 ?62237 5,988.588.41 542,458.47 6.99 1.23600 Islet 5.45.20 09,10 185.40 3,518.10 3.433,10 -1,28928 261816 SSW 555.14 62455.03 226 1,16928 MWO MSG (3) 545323 Sum 187 22 3.51081 3,433.01 -1,297,99 26641 5,98,527.31 544516 473 1,29700 MWD MSG (3) 548495 87.62 We 3520.@ 3,43202 -1320.42 2,610 fib 5,989.49595 542 44727 078 1,328.42 MND MSG (3) ' 553342 89.15 19948 3,52139 3.43339 -1,376-97 2fi07A9 5,989.44816 62,439.33 332 1,37517 MWD MSG (3) 5,574.9 8993 MISS 3,521.73 343373 -1,41642 2.586.17 5.950,407.07 62.433.23 3.33 1416.4 MND MSG (3) 5,M.91 0010 186.92 3522.21 343421 4,471.72 2589.25 5.889.3526 542,426.61 4.59 1471.M MA)Cn G(3) 5.990.02 00.15 1826 3521.95 3.434.96 -1,S@.41 250583 5.989.321.84 542423.15 507 1,50241 MMDGWSG(3) 5,693 77 88.02 18].4] 3.5 ,W 3,436.06 -1,535.06 258133 5,989289.17 542419.92 0.45 1,535.99 MVYDGW5G(3) 5 Y1999 8909 199,40 3,524.97 3,43699 -1$71.00 2576.86 5,989253.21 542,414M 4.18 1,571'0 MW9 MSG (3) 5.757,15 09.26 1187 3,525.36 3,437.36 -1,597.93 2573.0] 5,909,226.21 62411.90 1.17 1597.90 MWD MSG (3) 499]409 09.57 18790 3.525.01 3437.81 -1,64136 2.51,14 598918201 6240655 3.08 1,6135 MWD MSG (3) t 5,03228 Saw 185.81 3,52597 3,437.77 -1.6]2.52 256.52 59115163 5424@.95 TO 187752 MWD MSG (3) 587478 9244 187.44 3524.5 343555 -1,714.72 ?559.62 5,989.10941 62.3127 582 1714.8 MAD MSG (3) Pe8e3 COMPASS SODS. 148uld 864 8222019 9:52:01AM ConocoPhillips Vie It C0n0coPhlllips Definitive Survey Report Compaty, CoaDcolehi0ips Alaska lnc Kupamk Local Doordlnate Reference: MN 1R-26 Project Kuparuk River Und WD Reference'. 1R-26®88.ODus6(iR-26) She: Kupamk I Pad MD Reference: 1R-26®68.06us6(i R-26) Well: 1R-26 North Reference: True Wellbore: IR-126 Survey Calculation Method Minimum curvature Des19n: 1R-126 Dau0ase. EDT 14 Alaska Production Survey kto 4m m WD WDSS sWS .0m Ro thim EaHny OLS So��o� sMrveyTBfiln.m. aDD9re oD (I'dla r) (9 (aam (a,ft) fake) (Dam (m m) rear) ro) 590180 86.08 18,54 352452 3,436.52 -1 741 65 2,555.84 5,989,082.45 542394.64 16.53 1,74185 MND MSG (3) 5.933.67 07.00 18]19 3525.86 343].86 -1,]]3.01 2,65151 5989,051.08 542399.47 530 111301 MWD MSG (3) 5,959]6 Wed 185.07 3,528.74 3.43874 -1,798.32 2548.57 5989.4251] 542387.6] 858 1,79832 NAND .MSG (3) 5.987.50 0876 185.30 3,52131 3,43931 4,826.60 2,545.47 5,9%,99]19 542,3SALM 1.06 1,826.00 MND MSG (3) 6.018.19 07.50 185.15 3,528.30 3,440.30 -1,856.95 3,542.19 5,908,987.08 542,301.60 419 1,856.90 MND MSG (3) 6,04869 0].5] 105.06 3.520.61 3,441.61 -1.807,39 3,53931 5968,93874 5423]0.]9 358 1887.30 MNDO MSG (3) 6,07845 88.34 186.67 3.530.68 3,442.60 -1.91689 2.535.7 5988907.14 542,37591 599 1,916.09 MNDO MSG (3) 6,107.28 89.13 105.35 3,531.31 3.443.31 -1,94555 2,53315 5988.870.47 542,37304 5.34 1,945.55 MND MSG (3) 6.134.70 8843 18687 3.531.85 3,443.65 -1,98.81 253¢23 5,988.851,19 5/237026 5.60 195281 MNO 08750(3) 618287 90.37 18702 3.531]0 3,443.70 -2,00071 2526.83 5,900.82328 542367.D1 3.39 208011 vV00 M53 (3) 6,195.85 89.11 1871] 3.531.85 3443.85 -203346 252258 5.90675.49 512.36294 444 2,033.48 MJu➢OWGG(3) 6,219.12 89.44 186.39 3,53214 3444.14 -2056.57 2,51971 5.908.76239 542.]87.19 6.10 2,0.5`.57 kfWDOWSG(3) 634049 9382 te265 3,531.30 3,443.30 -2085 OD 2516.10 5,988,738.4 54235614 15.41 2085.90 Mh9CWSG(3) 627061 Saw 187.90 3528.50 3,441.50 3,115.49 2,51204 5,908,700.4 542]52.83 271 2115.49 MWD0WSG(3) 6,31032 93.8 187.45 359.71 3,439.71 -zimeB 258739 5.9886]].05 542348.75 1.93 2145.86 MWOMSG (3) 6.33030 91.70 184'5 352847 3430.0 8174.57 2,505.00 5,908.61933 542.]16.11 13.61 274.57 MWD MSG (3) 6,368.16 92M 181$9 3525.35 3437.35 4?34,12 25@75 5,988,619.48 542.344.01 3.50 2204.42 MWD MSG (3) j 6,398.37 91,4 182.w 3,524.28 3.436.28 -2,234.75 260.76 5988589.13 542,]42.19 674 2234]5 MWD MSG (3) 6427.91 90.16 183.87 3523.87 3,435.87 -2361.05 2,499.29 5906559.83 542,340.87 436 2264.05 MWD MSG (3) 6,456.02 Was 183.56 3521.08 3,436.08 -2234.11 2,497.60 5988529.76 542,339.34 440 2294.11 MWD MSG (3) 6.487.55 89.23 18583 3.52153 3438.33 -2,323.53 2485.15 5,988,50033 54233206 805 2,323.53 MND MSG (3) 6,518.28 89.20 185.03 3,524.95 3436.95 -2,354.08 2,49195 5968,469.76 542334.02 034 2,354.09 MWD MSG (3) 6,548]8 88.31 184.49 3,525.61 343261 3,384.45 3.48916 5,908.439.30 542,331.39 583 2304.45 MND MSG (3) 6.57615 09.57 184.94 3,526A1 3.4]8.41 -2,413.71 2,408]4 5,944,410.11 542,329.13 1.P 2,413.71 MND MSG (3) 6,08007 89.40 105.55 355.94 3,438.94 -2,443.50 2.484.01 5,988,38031 542,326% 346 2,443.50 MND MSG (3) 6,639.24 88.34 105,16 ].52].56 3439.55 -204.53 2,401.10 5.908.34957 54232300 3.63 2,4]463 MND MSG (3) 1 6889]0 8653 18214 3,528.39 3,440.38 -2,504.80 247283 5,980.31099 54232070 6.53 2.604.00 MND MSG (3) 669204 90. 188.58 3.526.60 3,440.60 Q532.67 247399 5,960.291]0 512,31201 886 2,532.87 vsNOOWSGP) Smile 8878 18.91 3.528.51 3.440.51 356060 $469.94 5,980,263.15 512313.11 3.75 2,560.60 MNDOWSG(3) 675503 9130 18211 3528.0 3,44033 859011 2n6n 5.988,233.62 542.30837 5.]] 2,590.11 MJuDOW6G(31 678727 89.76 18576 3.527.94 343994 $621.35 2462.53 5.988.202.37 542.30602 6.51 2,621.35 MNDCWSGO) COMPASS 5000.146udd 854 83211019 9501AM Pepe 4 ConocoPhillips„x„rv5 ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska lne_Kupduk Project'. Kuparvk River Unit sue: Kuparvk I Pad Well: 1R-26 Waltham: 1R-126 Design: IR -126 Survey Local Co-ordinate Federation: Wall 1R-26 TVD Reference: 1R36 ® BB.00usB (IR -26) MD Reference 11436@ 80.00us8(11436) North Reference: Tme Survey Calculation Method Minimum Curvature Database: EDT 14 Alaska Production 0/128019 9:52:01AM pane C0MF4SS5000.149u8d8W Map Map Vertical MD Inc Aal TVD T SS .NIS E0.N Northing Eastin g DLS Section Survey Tool Name Annotation (-am P) (9 (usR) (usn) (.an) (usn) (R) IMI (°1100') (R) 6,815 BS 80.68 164.70 3.528.25 3440,]8 -2,64981 ]45992 5906,1]390 542,30356 482 2,809.61 MWO OWSG(31 6,84341 09.40 18535 3,52867 3,440.67 -2.67726 245).60 5M lauA4 50,30129 324 26]]26 MVIDCir SG(3) 6.874.05 90.69 liked 3,520.62 3440.62 -2.70779 24114.87 5,904115.90 542,288.82 4.84 2.M7.79 NOADCA Ki 6.905.51 9051 185.92 3.5529 3440.30 -2.739.11 245201 5,90.000.0 5@,285.14 455 2,M9411 MWUOW6G(3) 6,935.17 88.43 183.73 3.62458 3,84050 -2769.66 2449.44 5,9%454.80 542293.]2 985 2,769.0 MWD GAMIC (3) 8%TM 8939 IWA9 3,SID.10 3,4H16 -2,001.10 244753 5,9884]248 542,291.98 3.49 2801.16 MWD OWSG(3) 6,99693 90.35 Voice 3,529.25 3.44125 -2830.31 2,44584 6,907.9.035 542,29045 142 2830.31 MWD GAISG(3) 7,027.61 8941 185.54 358.31 3,441.31 -2.8089 2,44343 5,987,962]5 Sc?28820 TN ?NG.89 MWDOWSG(3) li 7,055.97 09.93 184.62 352947 3,441.47 -2,009.14 2,440.92 5987.934.49 50268.84 373 2869.14 MWD MSG (3) 7.004.0 90.65 180.73 3528.33 3,441.33 -2,91T91 243806 5,987.905.71 54220.13 7.71 2917.91 MND MSG (3) 7.104,51 80.29 191.19 3,529.15 3,441.15 -2,93729 3.435.01 5,90780.32 58,20 .10 22.9 2,937,29 MWD CWSG(3) 713255 9092 191,35 3528.0 3,44063 -2,90.80 2,429.52 5987658.78 542.27485 2.01 2,954.80 MAD CWSG(3) 7,164BG 9070 19054 3.52835 3,440.35 -2.06.45 2423.40 5,807,827.11 542,5680 2.55 2,806.45 MNDCWSGM) 7.19204 9018 190.92 3,52813 344013 -3.023.21 2418.33 5987.80D.32 542,5397 2.61 3023.21 MND OWSG (3) 721213 9001 189.90 3.520.0 3,440.00 d,o52.80 24120 5,987.770.70 542.258.0 344 3,092.80 MODGWSG(3) 7,25390 9238 190.0 3.52743 3.4D.c3 41,083.15 240741 5,957,74032 542.253.37 8.01 3.03.15 MWD DWSG(3) 7,203.04 91.19 10950 3,55.0 3.41950 -,112]4 2402.16 6.907.71084 542.24826 539 3.11274 MND CWSG(3) 7,312.11 90.34 ISEW 3,526.11 3,438.11 -.141.40 2,397.32 5,987,68200 Sc?243.0 300 3.141AD MWD GWSG(3) 7,348.97 09.57 184.90 3,526.14 3,43944 -.177.95 2,39264 5,987.64546 502239.10 13,16 3,177.95 MWD MSG (3) 7.379.0 06.0 186.08 35553 3,438.53 320.03 2.391.76 5,987.615.0 54223639 437 34207.93 MND MSG (3) 7,41374 0780 185.85 3527.51 3,438.51 7,24237 3.30.17 5.887,581 01 54223298 3.37 3.24237 MAID 0WSG(3) 7,441.97 07.19 161.40 352874 3.440.74 -,270.48 2,30].65 5,907,552.91 54223361 5.57 3,270AS MWOOWSG(3) 7,46974 9D.14 183.51 3.529.39 3441.39 -3298.16 2.381,74 5,987,52521 542,25.64 11.10 3298.16 MND 0WSG(3) 7.499.6D 90M 18342 3.52928 3,441.29 -3.32796 237993 5907,495.40 542,227.211 050 3,32796 MhDCMEGC) 7,530 D0 69fi5 182.59 3.5ID.31 3.441.31 -3,]01.37 237613 5,907,40.98 542.Y15.5/ 2119 3,302.77 MND 08063(3) 7,5720 92.54 183.97 3.528.59 3,440.0 4,400.24 237596 5,94423.10 54221361 9.44 3,400.24 MWDOWSG(3) 7,804.0 91.97 133.57 3.527.0 3,439.3] -.43202 2,373.81 5,987,360.51 542,]11. 213 3,0]2.82 MrVO GWSG(3) 7639.14 91.fi 180.95 3,55.17 3,438.? 41467.24 2,37245 5.687,35810 542=46 T62 3,467.24 MWD OVAG(3) 7,871.53 9283 180.34 3,524.65 3,436.87 41.499.60 237209 5,987.323.74 5422ID.27 314 3,499.60 MWD 08080 (3) 7709.93 coN IWG6 3,523.80 3,435.6!1 3537.95 2371.95 5.907,285.39 542221133 652 3537.95 MWD 0WSG(3) 774133 89.97 17908 3523.72 3.435.72 45030 2.371.96 5,907253 .96 542,2551 1.]4 355936 MWD MSG (3) 0/128019 9:52:01AM pane C0MF4SS5000.149u8d8W ConoeoPhllllps SIA O ConocoPhillips Definitive Survey Report Company: ConoccPhillips Alaska Inc_Kupavk Local Coortlmate Reference: Wall 1R-26 Projece Kuparuk River Unit ND Reterence. 1R-26@MoOu56(I R-26) She: Kupamk 1 Pad MD Reference: IR-26®88,00usn(IR-26) Well: 1R-26 North Reference: True Wellhom: 1R-126 Survey Calculation Method: Minimum Curvature Deal,.: 1R-126 Catalase: EDT 14 Alaska Production Survey 6222019 9:52:O1AM Page 6 COMPASS 5000.14 Budd 6511 Map Map Vertical 1 MC Inc Ad TVI) TVCSS rW3 apJyy North ^9 Eastin 9 DLS Section Survey Tool Name Annotation IwRI 17 11I leap Iwlll Iw141 (w1ry (n) In) 1w1DeT (R) 7,767.40 6946 INV 352385 3,,435.85 3,595.43 2,371.. 5.98].22]91 542,220.61 246 358545 MWD OWSG (3) 7600.10 9198 180.m 3,52344 3.435.44 -3,62114 2,37162 5,987.195.21 W,Ma8 7.87 3628.14 MWD Ovi (3) 7,83114 9317 180.71 3522w 3434.04 -3659.15 2,37121 5,987.154.20 N2,.,24 384 3659.15 MWD OWSG (3) i 786440 8264 17&83 3.5211.35 343235 -3,692.44 2371.34 5.901130.81 542X=55 5.85 3,592.44 MWD Oaks (3) 7,895.95 90,57 772.15 3.519.7 3,43147 -3M79 2,372.1 5.90709857 542,22154 6.95 3,Mn MWD DWSG (3) 7,938.31 8RM 1816 3.518.34 3,431.34 -3,766.24 2372.20 3987057.13 542X2180 0.69 376624 MWD OWSG (3) ) 7.977.97 07.7 183.62 3.591.28 343228 -3,80584 2370.34 5,987017.52 542.220.15 7.52 3,005.04 MWD OWSG (3) ' 8,008.37 8776 I.,= 3,5215 3,43355 -3,836.17 2,Mass 5,989.907.16 54221&77 4.70 3,836.17 MWD Oai (3) i 6&04 10240 3,522]4 3,434]4 -3,063.79 2,367.57 5,986.954.56 542,21.71 0.93 3,660.8 MWD DW&G (3) i use, 0,077.31 8864 184.50 3523.79 3,43579 3904.80 2,365.40 5.963,01&47 542,215.82 6.84 3,9 88 MWD OWSG (3) 8,10240 0937 184]0 3,52445 3,43645 3,933.07 2363.46 598589327 542.21393 1.33 3,930,07 MWD OWSG (3) 8,13100 8047 MM 3.525.24 343724 -3.958.49 2.360.82 5906864.84 542,211.45 422 3,950.49 MWD OWSG (3) 0.163.67 9084 Ing. 3.525.44 3.437.44 3.993.93 2357,26 5,986832.38 542.208.06 7.61 3.89093 MWD OWSG (3) 6.211005 9197 leads 3.524.54 3,436.54 <.02704 2,352.97 5,989700.25 541 3.10 4027.04 MWD OWSG (3) B.M43 WAS 187.01 3.523.95 3435.95 4.055.21 2,349.54 SON 768.07 542200M5,44 4055.21 MWD MSG (3) 8.257.23 91.04 1M.N 3.523.45 34WAS 4.093.86 2344.36 5,98 6]29.00 542,19&70 3.77 4w366 MWD MSG (3) 8,23974 8969 186.69 3523.25 3,43535 -0,425.86 2,34011 5,995,697.35 542.19162 5 62 4125.80 MWD MSG (3) 0.33011 9121 War 3,523.02 3.435.0 -0,156.00 2,336.57 3986667.1 542,1w25 5.10 4156,45 MWD OW3G (3) 0,35939 9202. 163.56 3,522.23 3,434.23 4.184.06 2,332.83 5986639.14 542.184.86 7.27 4,184.06 MWD OWSG (3) 1 8,391N 9235 187.40 3.520.87 3,432.87 -0,216.57 232637 SMS 686.61 542.180.27 3.67 421657 MWD MSG (3) 0,42059 92.35 Imus 3.519.77 343137 <.245.63 2,324.33 5.985 ,577.53 542.176.46 225 4,245.63 MWD OWSG (3) ' 0.450.04 93.09 187.25 3,517.73 3AMM 4.262.69 2.319.35 5,886,540.45 542.17170 4.55 4202.89 MWD OWSG (3) 6,49203 90.66 18&64 3.516.39 3,425.39 -031632 2,31465 Saw SN..00 542,16749 1025 4,316.32 MWDO SG (3) 0,52&60 09.54 189.52 3.51833 3.4.aG 4.352.48 2,309.20 590547061 542.16192 3.06 4,352. MWD OWSG (3) ' B,S759 09.01 185.81 3.51670 3,4.]0 4,381.24 2305.50 5,986,44184 542.158.46 9.52 4.x24 MWD MSG (3) 8592.91 89.00 167.62 3.517.13 1 NA3 4,416.32 2,301.45 Se. 408.75 542,154.52 5.39 4416.32 MWD MSG (3) aStan 89.43 lat 3,51.35 3.429.35 4.442.50 2,298.39 3900,300.7 542.15160 7.44 4412.56 MWD OWSG (3) ' 0.65405 Wad 187.57 3.51.46 3,429.46 -0477.05 2, 86'94,40 5,986.345.90 542,147.79 5.93 4,477.05 MWD MSG (3) 860913 0038 1M.W 3.517.32 3,429.32 4.51000 2,290.19 5900,31215 W,143.77 286 4,510.86 MWD OWSG (3) l 9,71900 90.72 18720 3,5104 3429.04 -0,542.30 2,2117.39 5,0mmse 542,140.13 233 454225 MWD OWSG (3) 8]5725 saw 166.26 3.515.51 3,4V.51 -0.579.30 228135 5986243.59 542.135.29 907 457938 MND OWSG (3) 6222019 9:52:O1AM Page 6 COMPASS 5000.14 Budd 6511 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConowPbillips Alaska lnc Kuparuk Local CoorElmte Rete2nw: MU 1 R-26 Project: Kuparuk River Unit TVD Refemnw: tR-26(jt 88.00us9(I R36) Site: Kupamk lR Pad MO Reference: iR-26@88.00us8(I R46) Well: 1R-26 Norm Relerence: True Wellbore: 1R-126 Survey Calculation Method: Minimum Curvalum 0.1'.: 1R-126 Database: EDT 14 Mask. P.d.clion 8428019 9:52:01AM Pepe? COMPASS 5000.14 Ruik1 S8 Map Map Vesical MD 1. Atl TVD TVOSS 11,16 ♦EIAV planning Santini, DLS Section Survey TOO/Name And0i9[lOn (uld" P) I7 heart) loan) (..ft) (MSR) l IRI Plan) iftl 8.792.62 9537 186.91 3,513.68 3.42468 4.fi1432 327668 5,966,208,63 542130.82 539 4,614.32 MWD OWSG (3 8.623.95 9075 187.32 3.51103 3.423.3 -0645.36 227282 59%.177.58 542.12111 1449 4.645.36 MWD MSG(3) &85240 9104 IS&W 3,51059 3.422.59 -0,673.52 2,268.82 5956.149.40 542.123.26 544 46734 MAID M'6G(3) 8.80443 89.95 181&9 3.510.31 3,472.31 -4.705.21 2.F,16 5,986.11169 542.118.]] 451 4,705.21 WMA) 0WS3(3) 8.91595 89.46 180.3 3.510.4] 3.422.47 -4,]36.40 225..% 5,995086.48 542,114.34 353 4736.40 MND 05096 (3) &945.07 89.28 185.44 3.510.70 3.471.7. 4.617 2255.17 5,99C057.68 542.110.10 tfi6 4,]65.9 MWD 05066 (3) 8.97459 908 191.59 3.510.91 3.473.91 -0]94.24 2,25D.04 5Aa5@8.59 542.105.13 1120 4,]94.24 MND MIG(3) 8,004.17 89.3 19168 3,61107 3,423.07 4,82321 2,244.07 5.955999.59 542.09932 403 4823.21 MNDOW9G(3) 832.84 89.41 19164 3.511.50 3,423.50 4,051.29 2,08.28 5,985971.49 542,33fi7 041 485129 MND MSG (3) 9.3493 91.3 19240 3.51,28 3,42326 -4,88267 2231.6B 5,985,940.3 542,37.14 0.01 4,882.6] MND MSG (3) 9.3251 9142 193.32 351053 3,422.53 4909.54 2,225.42 5,985.913.17 54231.13 3.14 4,93.54 MNDO MSG (3) 9.12284 9039 19205 3,51GOS 3422.05 4,839.12 2218.76 5,985.8&1.56 54207462 5.39 4,939.12 MWD MSG (3) SUM 9006 19235 353.94 3,421.84 4,86550 2.213.6 5,985,05/.15 542.069.06 165 4,.65.50 MWD MSG (3) 9.180.86 9095 185.]8 3,79.67 3,421.67 -4.99573 2.06.04 5,985,026.09 542,502.21 5. 4,995.73 MWD MSG (3) 4017.85 9185 19279 3,53.21 3,421.21 5,02209 2,189.. 5,85,83.50 542.856.12 3.70 5,32.3 MWD MSG (3) 9.23705 908 191.90 3.505,93 340193 5,050.51 21M.58 58M,7M05 5424`0.3 4.24 6050.61 MWD MSG (3) 9.26731 9071 191.20 3,53.8 342072 -SAWI5 2187.50 5,98,742.30 542,D4411 3.31 5.30.15 MWDO MSG (3) 9.297.61 9172 19132 3,506.3 342000 5,109.8 2,10158 5,98571264 542,03536 3.35 5.109.8 MWD MSG (3) %3244 9027 18.18 3,57.61 3419.61 -5,136,29 2,176.56 5,985.88,10 5423345 6.83 5,136.29 MWD MSG (3) 9,35247 89.95 18.36 3.57.56 341956 5,153.80 2171.57 5,98566886 542,020.64 130 5,1638 MMM) O MW (3) 9.304.50 MM2 lands 3$771 ],419.]1 5,19&32 2,16S.90 5,985,47.11 5423313 1.65 5,195.32 MWOMSG(3) 9,413.. W23 1.85 35777 3,418]] 5,22343 2,16150 5,985,598.98 54201&40 3.50 5.22343 MWDOWSG(3) 944200 8..58 188.3 3,5782 3418.82 5252.67 2166.4 5,985,589.8 54201416 400 5,2527 MWDOINSG(3) 4470.63 89.57 188.7 3,58.3 342D.3 -5,280.42 2,15259 5,985,541.95 5420103] 0.05 5,28042 MWDO GG(3) 9,926.8 9D48 108.74 3,508.01 S42D.01 5,3343 2,14804 5,985.515.92 542066.7 4.30 5,33.43 MWDOWSG(3) 9,59.01 9082 188.55 3,50165 3,419.65 5,33&34 2,14189 5985483.98 542.001.99 1.21 5,33034 MVVDO'N6G(3) 9,556.% 90.80 I... 35736 3,41426 Sw5.. 2,19.80 5,985,456.49 5419M.02 n33 5,3fi5B2 land, OWSG(3) .,585.85 9197 17.94 353.51 3418.53 -5.39527 2,135.62 5985,426.92 541,993.93 4.9 5.3953] MWDOWfiG(3) 9615.0 9191 ISSAS 3505.56 3,417.56 64234 2,13203 5,985,mam 541,98.49 5.35 5,423.92 KNO MSG (3) 9,&5.37 9160 185.75 3504.65 3,416.65 -5453.46 2,1ffi89 5,9030.80 541987.50 2.42 5453.46 SN)..(3) 96871 9018 18540 3504.15 3,41615 26,485.70 2,125]4 5.90335.54 541904.52 4.51 548570 VNDONSC(3) 8428019 9:52:01AM Pepe? COMPASS 5000.14 Ruik1 S8 ConocoPhillips� 4 GonocoPhillips Definitive Survey Report Company ConocaPhillips Alaska lnc Kupamk Local Coordinate Refefence: Mil iR-26 Project; Kupamk River Unil TVD RM9mnc.: 1R-26@00.00usn(1 R-26) $de: Kupamk l R Pad MD Renrence: iR-26 @ 80.00usn (1R-26) Well: 1R-26 North Reference1 Tma Wellhom: 1R-126 Survey Calculafion Method: Minimum Lurvelum Des.,.: 1 RAM Onn.u: EDT 14 Mask. Pmduction Survey &Q Ol9 95201AM Pega8 COMPASS 5807.14 Sa6d SSH Map Map Vertical MD Ins Aad TVD TVOSS BW4 +E13NDLs NO Easting Section gurvey Tool Name Annotation Ilw11-M1°I 111 lasnl 796781 10.781 (..ft) Irtl Inl 1°11110•) IS) i 9 M&N 8900 187V 3SN.32 3,416.32 551370 2,128.63 598530853 54190157 7SG 5,51370 MWD OWED pI j 913733 9035 18&54 3,`501.4) 3,4164] 5.54469 2110.33 5,985.27).52 541,91743 5]4 MN 554469 D GW6G(3) 9,76484 90.38 1%81 3.504.30 3,416.30 -,571.99 2114.17 5,985,250.21 541,97341 090 5.571.99 MWD=SG (3) 9,79436 9111 109.18 3,603.76 3,41576 4,601.8 tines 5.985.221.04 571 QRSAM 4.55 5.60114 MWD MSG (3) 9,026.17 9048 10&78 3503.15 3.415.15 -.63255 2104.59 5.905 189.60 541,9-1.15 407 5,632.55 MND GN5G(3) i 8,8%.10 90.12 lWA7 3,503.00 3,415.00 5,661.14 21W.15 5.9%16099 541,959.87 138 5%1.14 MND M53 (3) 9,8135.10 9053 168.40 3,502.83 3.414.03 5,690.80 20%.N 5.71%131.31 541,9:4.52 2 S 5,non MND CMG (3) 9,917.% 9052 188.51 3502.54 3,41454 -,M.41 2090.0 5,985,09968 541.950.98 0.35 5,722.41 MND MSG (3) 9,944.95 9111 188.38 3,50214 3,414.14 -,749.99 20%.% 5,98S,01708 541,84]61 217 5.74999 MWD0WSG(3) 9,97410 89.66 188.61 3501.94 3,413.94 577&% 2,0@.53 5,985,04315 541.94288 5.02 5,17&90 MND0WSGS) 10.00608 09.&9 186.52 3,502.07 3,414.07 -5,01052 2,078.33 59%,01151 541,938.85 an 5,01052 MJ0D0WSG(3) 10,037]8 N.74 18593 3,501.89 341380 -5,04203 2074.90 5,8&97990 541935.55 3.26 581203 MNDOWBG(3) 10.%&64 9102 105.87 3501A7 3,41347 -5,869.74 2,On.W 5,804.95226 511,982.07 103 5.869.74 MND MSG (3) 10,094.58 BOW 185.25 3.5%.% 3412.96 -,098.52 206&98 5984.923.48 541.929.97 1.32 5899.52 MWD MSG (3) 10.12525 90.71 185.82 3.5W.50 3412.50 -.W9.01 206575 5,984.892.% 541926.9) 1.67 5.929.01 MWD MSG (3) 1015424 91.54 185.63 3.49.03 3,41193 4.95285 2,062.% 5.%48411 541.924.17 2.84 5,95285 MWD MSG (3) 10,1848 San 185.89 3.49983 3.411.83 -.808.42 2,059.78 5,9&.&1353 541,921.25 883 5,9)0.12 MWD MSG (3) 1D.215.W 88,78 105.81 3.WoM 3,412.46 4.018,33 2.05&45 5994.80361 541,910.07 3.10 6,018.33 MND MSG (3) 10,244.07 80.79 18260 3.50107 3,413.07 404210 205281 5,984?04.83 541914.59 2.69 6.047.10 MWDGWSGon 1027307 8957 188.29 3.501.49 3,413.49 -.07581 2048% 5.984.746.09 541,910.73 359 6.07581 MWD MSG (3) 10,3348 89N lnN 3.W114 3,413.74 -,10205 2.OW.% 5,981.714,03 5419%.% 3.33 6,107.05 MWDMSGpu 10,349.62 0933 19058 3.502.21 3.414.20 -,151.31 2.03&18 5984,670.54 541698.52 278 6,15131 MWDOWSG(3) 10,38.56 8970 191.11 3.502.48 3,40446 £,101.71 2.030.36 5,984.640.10 541882% 209 6.18171 MND MSG (3) 10,422.48 0950 109.62 3502.78 3,414]2 4222.93 2022.82 5.984.598.85 541,00&54 357 B.T1293 MD 10448.17 8962 18.% 3.502.90 3,414.90 4240.25 2.01&47 5904.Sn.51 541,881.33 1.02 6,24825 MD 10,48157 80.12 187.43 3,503.56 3,415.56 420136 2,013.45 5.904540.48 54167&40 8.60 6,28125 MWD MSS (3) 10,51031 89.25 185.82 35N.22 3.41622 5,309.70 ZWOA4 5,984.512.03 54167333 6.87 6,309.70 MND MSG (3) 10,539,79 8101 184.41 3,501.15 3,41615 4339.18 200251 5,984,402.56 SO SM 85 7.52 6,33916 MWD MSG (3) 10,557.87 9116 184.48 31503.62 3.41562 WAS 200.33 964.451809.02 5964.454.% 54 0.59 6,%7.15 M DMSG(3) 10,59930 92.59 153.62 3502.59 3,414.59 -,398.30 283.12 5,984423.31 541,866.78 5.33 6,390.30 MNO GM5(3) 10630.42 9346 183.48 350085 341295 4429.50 200119 5,984,39119 541,96501 202 6,42950 MN0MSG (3) &Q Ol9 95201AM Pega8 COMPASS 5807.14 Sa6d SSH ConocoPhiliips % O COnoc()�illIp5 Definitive Survey Report ComP..y: Ccm,c Philkps Alaska Inc_Kuparvk p.p.t: Kupamk River Dnn Sae: Kupamk lR Pad Well: 1R-26 W.111 : 1R-126 Design: 1R-126 survey Lout Co<Ninah Relarerrce: Mll 1R-26 TVD R.A.. e: 1R-26 @ 88.00usn (IR -26) MD Reference: lR-26 @ 98.00usa (1R-26) Nerta Reference: Tons Survey Calculation MetboL: Minimum Curvatura Database: EDT 14 Alaska Production Annotation 9/228019 9:52:O1AM Peg. 9 COMPASS 5000.14 BuBE 9588 Map Map Vertical MO Inc AE TVD TVOSS ♦141-15 eEi Northing Eaating OLS Section Survey Tool Name Juan) (1) 19 Iusn) (usn) lush (uan) In) In) (.eoo.) nl) 10.%092 9271 104.13 3499.30 3411,30 -a 459,89 1999. 17 5904,361.80 541.663,15 3.25 6.459,09 MWD OWSG (3) 10683% 66.29 i%.18 3498.45 341045 6,492.38 19%23 5,684,3W" 541,%OA 9.72 fi4 ,30 MND OWSG (3) 10 nl,. 91.40 184.30 3498.03 3,410.03 8,52030 1993.6] 5,96"0 a0 541.85].9] 7,76 6,520.38 MND OWSG (3) 10749.20 9310 184.34 34%95 3.40895 6,547.08 1,991.59 5,904,2M378 541.8%.04 616 6,547.88 MWD PN6C (3) 10,]0083 91.87 18652 3,495.50 3,40758 E.5]B 24 1.988.52 5,904242,40 54185315 0.]] 6,57924 MWD QW. (3) 10,810.10 9103 105.46 3,49481 3405,83 -6,60831 1,985.14 5,W.213.n 541,54992 293 6.60031 MND OWSG (3) 10,84157 W.11 180.14 3.49395 3lWas 6,639.57 198,69 5,984.182.03 541.84'6.63 340 6.63957 MN130WSG (3) 10ranw 91.03 184,68 3.492% 340495 6.67039 1,978.7 5,904,151.21 541,843.88 199 6,67039 MWD OWSG (3) 10,50100 91.88 184.60 3.491.0 3A0366 -6.704,72 1,975.% 5,984886.% 541841.25 000 6,7()472 PROJECTED to TD Annotation 9/228019 9:52:O1AM Peg. 9 COMPASS 5000.14 BuBE 9588 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1R Pad 1R-126PB1 50-029-22193-70 Baker Hughes INTEQ Definitive Survey Report 22 August, 2019 B/y(EC HES GEta ,, ConocoPhillips "ER 4 ConocoPhilli' (K Definitive Survey Report Company: ConocoPhdhps Alas" Inc _Kupamk Local Coordinate Reference: VJe111 R-26 Project: Kuparuk River Unit TVD Reference: iR86@S8.00usfl(1 R-26) she: Kuparuk l R Paid MO Reference. IR-26®BB.00uufl(I R-26) Well : 1R-26 North Reference: True We11B,R: 1R-126PB1 Survey Calculation Method: Minimum Curvature Dealgn: 1R-126PB1 Database EDT 14 Alaska Prodi Project Kupamk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean See Level Geo Datum: NAD 1927 (NADCON WINDS) Using W011 Reference Point Map Zone: Alaska Zone 04 Using geodetic seal. factor Well 1886 Well Fashion «NIS OOO usfl N.ohln9: 5,99,810.31 usfl IatXude: 70.23'9.012N .EM 000 usfl En ing: 539, 829.81 usfl Longitude: 149.40'33.844W Position Uncetlainty 0.00 usfl Wellhead Elevation: usfl Ground Level: 41.20 usfl Wellbore 1R-126PBI Magnetics Model Num, Sample Date Oeclinotton Oip Angs. Field Strength (I rl Inn EGGM2018 8/1/2019 16.51 8009 57,412 Design 1R-126PB1 Audit Notes: VnIA.u. 1.0 Phase: ACTUAL Te On DeptM1: 4,899.53 Vertical Section: Depth From IWO) aWLS eEHV Direction Iudi (mai (am) (°I 43.20 0.00 000 180.00 1 _ BYMI, Program Date From To Gurneyrvey Su JU.M (utt/0 Survey (Welleom) Tool Name Description Stas) Dab End Dist, 50.00 4,450.00 18-26-GY0,CT-CMS(1 R-26) GYD-CT-CMS Gyrod.ta ccol ing on. 1/26@014 1/2612014 4,463.60 4,899.53 1R-126LI MYYD(1 R-126LI) MWD OWSG OWSG MAD - Standard 7/16/2019 712212019 4,90300 7,379.61 1R-126PB1 MWO(1 R-126PB1) MWD OWSG OWSG MM -Standard 712=019 7124/2019 8222019 9.53:30AM Pai COMPASS 5000. 14 Band 81 ConociaPhillips Conc coPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc Kupamk Local CarorB'mate Relanl Vlell IR -26 Project Kuparuk River lend TVD Rehsmeet iR-26@88.00u9fi(1R-26) Sire: Kupamk lR Part MD Reference: 1R-2fi®BB.ODuaX(1R-2fi) Well: 1R-26 North Reference: True Wellbom: 1R-126PB1 Survey Calculation Method Minlmum Curvawre Cartage: 1R-126PB1 Daubase: EDT 14 Alaska Production Survey MO Inc Aa ND TVDSS ♦NIS ♦EI -W Map Map DLS Vertical Nomme, Eaatm p section Survey Tool Name luartl (°I (°I (u9RI doze) anal(U4Y) anal (M1) IM (°1100') (tl) 4,89953 87.21 Intl $4..14 3,400.14 -04091 265124 5,990,tin SO 542484,74 2513 74891 MWD MSG (2) 4,603.4O 870 17927 Sail 3,40031 -75238 265128 5,990,029,13 542,484.W 7,11 752.30 MWD 00086(3) 4,tall 8907 IM74 3.48954 3.401.54 -780.91 2,653.51 5,990035.62 542,407.23 16.03 788.41 MWoovnGp) 4,959.42 SON In'" 3.48982 3.401.02 4810,57 26%22 6,99000538 542,493.00 7.50 818.57 MWDOWSG(3) 4,999]6 88.1 1M.7 3,46023 3,402.23 4848.07 2,657.60 5,989.975,69 542.49171 1023 W0,07 MWD MSG(a) 5,02934 8799 18041 349110 3,40110 4170.43 265791 5,909946,13 5424010 624 87043 IONIC MSG (3) 5,05976 8756 10424 3,49228 3,40428 -900.00 2,655.68 5,989915]6 54249103 12.66 W&W MJu➢oWSGa) SOWN War larl 3,49279 3,40479 4839.16 2,65360 5.989.09539 542.409.11 14.10 93918 MrW MSG (3) 5,1211£ 9670 19918 3.49244 3.40444 -97030 2.W.00 5966,85433 542483.76 5.82 97020 MND MSG (3) 5149129 9001 1a820 3.49226 340426 997.51 2.644.91 5.989,827.00 542479.74 428 997.51 MND MSG (3) 5.181.15 90621 107,14 3,40200 3,404.08 -1 OA,W 2,WS6 592.785.40 W,475SS 378 1029.49 MND MSG (3) 5207.82 89.49 185.49 3,492.05 3,404.05 -,00.59 263273 5.989.766.89 54247205 7.00 1,05559 MND MSG (3) 5254.63 00.00 186.21 349122 38232 -1,1@486 2,63286 5,989.72230 542,46834 1.99 1,10216 MWD MSG (3) 5,28948 012 itil 3491.25 342325 -1.136.78 262930 5,989.68.66 512,461117 875 1,13878 MWD MSG (3) 5.32034 W.71 19369 3.40022 3.40222 -1.18.63 2,626.73 5909.669O 5/246246 10.50 1.16753 MND MSG (3) 5.37621 87.21 INTO 3,49123 3,40323 -1,22].]1 2,621.05 5,98860186 5/246008 8.07 1,22334 MND MSG (3) 5,40512 00.64 18.55 3,49228 340428 -1,25223 262466 5989,8220 512.400.85 5.11 125223 MND MSG (3) 5.435.70 9035 18,13 3492.55 340455 -1,28281 262448 5,98,541.62 512.15D.83 5]6 1,282.81 MND MSG (3) 5.46544 608 17936 349230 340430 -1,31255 2624.61 5.989 511.89 512461/2 272 1,312.55 MWD MSG (3) 550937 9864 1A.¢ 3.49336 3,40535 -135644 262577 5,98948881 542,462.51 9.85 1,356.44 MatGovo (3) 5,55429 0551 175W 3.496.43 340843 -1,401,18 262827 5,98,42328 542,alel5 443 1,401.18 MW00WSG(3) 553634 86.65 179.8 3498.8 3,410.63 -1,43313 262942 5,989,39135 542 Nl 57 1200 1,43313 MVIGOWSGS) 569.79 89.93 MSG 3.49933 3,411.33 -1,456,55 3,628.66 5,88938.92 542.466.93 21.82 1.45655 MWDov,otl 5,658.16 9255 18559 3.490,32 3.41032 -1,8274 28288 5,989,321.71 542,46230 6.84 1.50174 MWDOWSG (3) 5.6858 9058 19365 3,49749 3,48,48 -t$33.Ofi 2,622.41 5989,29139 542 'SON 8.11 1,5138 MNr,ovia 3) 5,711753 8082 10237 3.07.0 3,40083 -1,553.97 2621.31 5.982708 542459111 11.18 1,553.8 MAD MSG (3) 5,73823 8432 16107 3.400.40 3.41140 -0,583.80 2.020.45 5,982418 54245939 15&5 1,50260 MND 00036 (3) 5,765,07 8243 17954 3.5028 3.414.72 -1,611.24 2,620.33 58821320 542,45839 8.41 1.61124 MND MSG (3) 5795.99 827 180.90 3,605.9 3,41057 -1,64192 2,620.10 5.969,18253 542.45044 Sit 1,64132 MND MSG (3) 5,moo 0550 183.96 3,58.52 3,421,52 -18183 231891 5,00915281 54245733 1254 1,MSG MND MSG (3) Amwtatlon TIP KOP 811X1019 9:6330.466 Papilla COMPASS 500014 Said BSH Conocolshillips ConocoPhillips DefinRive Suryey Report Company CenocoPhAbps Alaska Inc Kupamk Local Coardlnme Reference: Well 1R-26 Project Kuparuk River Unit TVD Reference: 1R-26(41 BSB0usft(1 R-26) Sfte: Kupamk 1 Pad MD Reference: 1R-26?68.00usft(i R-26) WeII: 1R-26 North Assurance: True Wellbore: 1R-126PB1 survey, CalculaOon Method: Minimum Curvature Deslgn: iR-126PB1 Database: EDT 14 Alaska Pmducli0n Survey Map Map Ants.1 i MO Inc Ail TVO TV033 4NIS ♦61-90 EMU., OLS -11w) Sdon Survey Tool Name Annotation park) M 19 (draft)Northing (ueh) (usto luahlSM"--In) In J Ih) 5,855]0 NSis 185.03 3.511,05 3,423.05 -1)0130 2616.30 5,989,43.05 542454.95 1143 1]0136 kMrD OWSG(3) ' 5.884.98 11627 16736 3,511.65 3,423.85 -173037 261302 5,958.090.05 542,451]5 541 1,]30.3] kNA OW6G(3) l 5.921.31 85.41 Ideal 3,513.86 3.425.06 -1,766.36 260&51 5.958.058.90 542,447.44 7.98 1,]66.35 MIN Ms. (3) 5,953.92 8622 188.49 351652 3.428.52 -0,]98.5] 2,60416 51989.02581 54244326 4.89 1,]98.5] MND MSG (3) 5.97603 8609 190.38 3,518.42 3.430.42 -1,823.27 2090.06 5,889.pW.09 542439.28 8.27 1,02327 MNDOWSG(3) 6,010.10 86.31 186.04 3.520.49 S.M. -1,554.02 256562 5,988,97032 542435,01 138'2 1,854.02 MD OWSG(3) 6,041.28 87.21 1e4.68 35424 3,434.25 -1,884.92 2,59272 5,958,939.41 542.432.26 524 1,584,52 MWDONSGp) 68880 84.40 1]9.]4 3.524.54 3,436.54 .1,916.14 2591.51 5,98890619 542.431.24 18.10 1,916.14 MWD MSG (3) 8,100.75 82.18 1.7121, 3.52758 3,43680 -1,BH.10 259224 5,980,88023 542.132.12 1048 1,944.10 MWO MSG (3) 6.13205 82.61 104.44 3,53229 3444.29 -1 Sao N 2,59171 5,988044'6 642.43177 1662 1,98000 Mvvo MSG(3) 6,16932 04.51 108.51 3535.91 3,44291 -2,011,99 2586.65 5.90881233 542.420.89 661 2,011.99 MWDOWSGS) 620243 8800 187.82 3.53].]0 3,44978 -2046]0 2,584.53 5,988,779 52 542424.94 14.12 2,W4.]8 MNU MSG (3) 623201 8914 18].]8 3,538.10 340.10 -2074.09 ;547.51 5,968]5020 542,421.09 2.51 2074.09 MND MSG (3) 6265.23 89.67 107.40 3,538.21, 3,450.28 -2107.02 251.13 5986,]17.25 5@41687 1.16 2107.02 hTN00N5G(3) 829].90 87.51 108.69 3,539.05 3,451.06 -2138.61 2,58.1] 5,980,605.64 54241300 6.91 2130.61 MADOWSG(3) 6,33471 07.21 184.20 3,540.79 3,452.79 -2176.02 256853 5.988,640.21 542.409.64 7.10 211r0.02 MWD MSG (3) 6.905.26 67.93 10].]0 3.51205 3454.05 3,20538 2,55547 5,98SfI&M 542,405.74 1208 2,205.38 MWD MSG (3) 6,400.95 08.45 10607 3,54320 3455.20 -2,24182 1,561.40 5980,58238 542,402.05 7.30 2,24182 MWD MSG (3) � 8,44127 89.82 180.19 3,543.81 3,45681 -2,282.00 2559.55 596854212 WAN 1257 220200 MWOCWSG(3) ' 1 649824 90.82 101.92 3,543.50 3,455.50 -2,339.04 2,558.50 5,908.485.16 542,400.40 3.51 2,339.04 MWD MSG (3) 6,526,64 8807 182.90 3,543.52 3,455.4 3,367.42 265].52 5,988.456.78 542,399.5 6.10 2.7..42 eWD OWBG(3) 6555.40 90.05 181.61 3,543.75 3,45575 -239224 2,556.5] 5.958,42695 542,399.85 3.62 2397.24 MND GWSG(3) '.i 6.587.02 9035 18121 3543.64 3.455.64 -24477 2555.112 5,988,396.42 542,398.27 1.64 2427.77 MND MSG (3) 8611.49 8]]5 181.53 3$44.14 3.456.14 -2458.23 2,555.09 5,98536597 542,391.6 663 2458.23 hW%DMGG(3) 6,647.Tl 8637 18172 3,545.69 3,457.69 -2488.45 2,55123 5,248,33574 54239700 4.90 2480.45 MWDOWSG(3) 667750 0082 100.08 3546.99 3.456.99 -2510.14 2,553.55 5,98830.05 542,396.49 did 2,518.14 MYD MSG (3) 707 71 69]8 1.8085 3,54742 3,45942 -2,548.43 2553.11 8908.2]576 542.39620 3.83 3,540.43 MD MSG (3) 8,74120 N. 1668 3,54757 3,4595] -2,58184 2553.15 5,808.242.36 512.396.42 555 2,58184 MWD MSG f3) 5,1664 90.57 98.94 3.54803 3,46000 -2,60975 2553.65 5,988,214.45 54239707 398 2,60975 MWDOWSG(3) 1 679874 87,92 16.45 3,5411.91 3,46091 1,639.36 2554.07 5.980,184.41 542,39765 284 2,53935 MWDOW5GG) 683620 06.37 101.56 3.550.12 3.46242 -267679 2,553.6 5,900,14742 54239].51 5.73 26]6]9 MWD MSG (3) 82212019 9: 53.30AM Pelta 4 COMPASS 500014 Budd SW &228019 9:53 30AM Page 5 COMPA35500014 Budd 65N ConocoPhillips➢r�i6s 4 ConocoPhiiiips Der ive Survey Report Company'. ConomPhllllps Alaska Inc Kupamk local C.�ordmate Reference: V4,11 IR -26 PmjecP. Kupamk River Unit TVD Reference: IR -26 @66.00uSn(1 R-26) Slte: Kupamk I Pad MD Reference: 1R-26 Q 1111.00ua3(1R-26) Well: 1R-26 North Reference True Wellbore: IR-126PB1 Survey Calculation Method: Mtimum Curvature Deaign'. 1R-146PB1 Database: EDT 14 Alaska Production Survey MO lu Add TVD mss Ni Map eFl-W Map OLS Vertical luMl (°) Ih Itlafp tyafil ('daft) Northing (cert) Eaating SeplOn Survey moi Name Annotation (rt1 (n) Maw) In) 606543 88.32 178.88 3.55096 3A62.96 -2,766 2,55362 bun 11e.21 SC239756 9.17 370600 MWO OWSG(3) 6.895.55 88.14 178.25 3551.89 3,463.08 -2,736.10 2,554.38 5,908,0612 542,398.47 217 2)36.10 li Mi (3) 6.92865 85.13 17826 3,51 ],464.8] -2,]691] 2,555.10 5,98805506 542,399.36 305 2.759]] MND MSG (3) 6.Y5..W 0743 18260 3554.11 346.11 -2]98.56 2,554.62 5988.025.67 542,399.04 11.% 2,]98.56 MND MSG (3) 8.6781 0401 10270 3,si 3.468.11 -2828.00 2553.24 5.987.9%.22 542397,02 8.09 3026-00 MWD 0W5G(3) ],01]08 82.25 1006 3.559.43 3.47143 -2857,26 255235 5807,966 54239].09 1131 2857+26 Whi GWSG(3) 7 WAS 79.80 10088 3.64.17 3.476,17 .2,88126 255194 5907836.9] 542,396.84 309 267.26 MWDDWSGR) 7,07127 78.85 193.32 3.5614 340130 -2,91 255t63 5.907,90760 542,311 426 2,916.55 Pass) OWSG(3) 7.108.36 7878 179.79 3575.83 3.487.83 -2,90.04 255(61 5,987.877.19 51236.82 1]2 2,947.04 MND MSG (a) 7.137.31 762] imol 3,581.59 3493.59 -207541 2,55180 5,67.848.83 5@,314.17 3.17 2,975.41 MWD OWSG(3) SII 7,16753 7967 17011 3458].3] 3.499.37 y005.6 255265 5,887,819.18 542.390.1] 5.40 3,00506 MWD OWSG(3) 730L% 79.07 178,12 3.593.60 3.505.6 y03&V 2.55374 5,9677698 542,39944 117 3,03827 MWD OWSG(3) ],22].84 ]710 17485 3,598.94 3,510 84 6 -3,410 2,555.33 590],]6009 542.401.1] 1315 3,64.38 MIND MSG (3) ] 7. p 75.6 171.44 3.86.8 3,51],]2 3,09262 2,558]5 5.90],]31.6 542,404.74 13.19 3,092.62 MND MSG (3) ].28931 ]2,09 170.95 361442 3,526.42 J,1229] 2,567.45 5.99].701]4 542,409.6 840 3,122.97 MNOOWSO (3) ],32146 70.40 1'37 362463 3,538.63 3,(53.23 2,56189 5907.671.10 s42.41I20 8.24 3,15313 MWD OµSG(3) ],X].]2 71.13 16954 3,633.28 3.545.28 J,1]].M 2571,76 590764564 54241021 1020 3,17]12 MWDOrri i ],3)961 69.13 16].]0 3.644.12 3.56.12 3,207,13 25]].83 5.90]61].2] 542.424.23 033 3.W7.13 MWD MSG (3) ].410.03 6013 167.78 3,654.95 3 566A -3,234.80 2,583.61 5,987509.55 542.430.39 000 3.234.88 PROJEGI£D to TD &228019 9:53 30AM Page 5 COMPA35500014 Budd 65N BA ER I IGHES BAT To: 21 0 =; 31117 Letter of Transmittal - --- -------- Date: August 22, 2019 Abby Bell AC GCC 333 West 7" Ave, Suite 100 Anchorage, Alaska 99501 Harvey Finch Baker Hughes, a GE Company 795 East 94t" Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 1R-126 1R -126L1 1R-126PB1 (RECEIVED AUG 2 3 2019 AOGCC (3) Total print 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 21 9094 V., ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1R Pad IR -126 50-029-22193-01 Baker Hughes INTEQ BAT(ER GE company S BAT Definitive Survey Report 22 August, 2019 ". ConocoPhillips BA.I(E RES `lUGHES ConocoPhllllp5 Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit Site: Kuparuk 1R Pad Well: 1 R-26 Wellbore: 1R-126 Design: 1R-126 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 1R-26 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Position -NI-S 0.00 usft Northing: To -El-W 0.00 usft Easting: Position Uncertainty 50.00 0 00 usft Wellhead Elevation: Wellbore 1R-126 1R-12611 MWD(1R-126L1) 4.879.77 Magnetics Model Name Survey Sample Date Tool Name BGGM2018 Start Date 8/1/2019 Design 1R-126 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 4320 Survey Program Date From To +E/ -W (usft) (usft) Survey (Wellbore) 50.00 4,450 00 1 R-26 - GYD-CT-CMS (1 R-26) 4.463.60 4.869.53 1R-12611 MWD(1R-126L1) 4.879.77 10,872.54 1R-126 MWD (1 R-126) Well 1R-26 1R-26 @ 88.00usft (1R-26) 1 R-26 @ 88 00usft (1 R-28) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 5.990,810 31 usft Latitude: 539.829.81 usft Longitude: usft Ground Level: Declination Dip Angle 1°) 1°l 16.51 80.89 70° 23' 9.012 N 149'40'33 844 W 41 20 usft Field Strength (nT) 57,412 Tie On Depth: 4.869.53 +NI -S +E/ -W Direction (usft) (usft) N 0.00 0.00 180.00 Survey Survey Tool Name Description Start Date End Date GYD-CT-CMS Gyrodata cont casing m/s 1/26/2014 1/26/2014 MWD OWSG OWSG MWD - Standard 7/16/2019 7/22/2019 MWD OWSG OWSG MWD - Standard 8/4/2019 8/4/2019 8/22/2019 9: 52'01AM Page 2 COMPASS 5000 14 Build 85H Annotation TIP KOP aA. KER "I 8!2212019 9:52:OIAM Page 3 COMPASS 5000 14 Build 85H ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 1R-26 Project: Kuparuk River Unit TVD Reference: 1 R-26 @ 88.00usft (1R-26) Site: Kuparuk 1R Pad MD Reference: 1 R-26 @ 88.00usft (1R-26) Well: 1R-26 North Reference: True Wellbore: 1R-126 Survey Calculation Method: Minimum Curvature Design: 1R-126 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc Azi TVD TVDSS -NI-S +EI -W DLS (usft) V) (') (usft) (usft) (usft) (usft) Northing Easting (°1100.) Section Survey Tool Name (ft) (ft) (ft) 4,869.53 8757 171.64 3.486.77 3.39877 -71906 2.648.93 5.990,10544 542,482.27 2829 719.06 MWD OWSG(2) 4.87977 87.45 174.32 3.487.21 3,399.21 -72921 2.650.18 5.990,09529 542,483.57 26.17 729.21 MWD OWSG(3) 4,93000 8108 176.99 3,492.23 3,404.23 -779.01 2,653.97 5.990,045 .52 542.487.63 1374 779.01 MWD OWSG(3) 4.96500 79.26 17790 3,49821 3410.21 4113.46 2,655.50 5.99001108 542,489.35 580 813.46 MWD OWSG(3) 4,995.00 78.57 178.81 3,503.98 3,415.98 -84289 2.656.35 5,989,981.66 542.490.35 3.76 842.89 MWD OWSG(3) 5.033.55 79.20 180.63 3,51141 3,423.41 -88072 2.656.53 5,989,94384 542490.74 4.91 880.72 MWD OWSG(3) 5.076.09 81.18 186.54 3,518.66 3.430.66 -922.53 2,653.91 5,989,90202 542488.33 1446 922.53 MWD OWSG(3) 5,099.90 83.16 183.53 3,521.91 3,433.91 -946.02 2,65184 5.989,878 51 542,486.39 1503 946.02 MWD OWSG(3) 5,129.46 88.21 18307 3,52413 343613 -97544 2,650.14 5.989,849.09 542,484.85 1715 97544 MWD OWSG(3) 5,164.34 94.17 183.42 3,52341 3,435.41 -1.01024 2.648.17 5.989,814 28 542,483.06 17.12 1010.24 MWD OWSG(31 5.198.62 92.24 18666 3,521.49 3,433.49 -1.044.33 2,645.16 5.989.780.18 542,480.24 10.99 1,044.33 MWD OWSG(3) 5230.14 91.85 189.40 3,520.36 3,432.36 -1.075.52 2,640.76 5,969,748.98 542,476.00 8.78 1,075.52 MWD OWSG(3) 5,271.19 91.04 186.92 3.519.33 3431.33 -1,116.14 2,634.94 5,989,70833 542,470.40 6.35 1,116.14 MWD OWSG(3) 5300.39 91.27 185.89 3,51874 3,430.74 -1,145.15 2,63168 5,989.67931 542,46730 361 1.145.15 MWD OWSG(3) 533348 9181 185.80 3,517.85 3.429.85 -1.17805 24628.31 5,989.646.39 542,46410 1.65 1.178.05 MWD OWSG(3) 5,360.09 9077 185.85 3.517.25 3,429.25 -1,204.52 2,625.61 5989,619.91 542,461.54 3.91 1,204.52 MWD OWSG(3) 5,391.74 88.59 185.92 3,517.43 342943 -1,236.00 2,622.37 5,989,588.41 542,45847 6.89 1236.00 MWD OWSG(3) 5425.20 89.10 186.48 3.$18.10 3.430.10 -1269.26 2,618.76 5,989,555.14 542,455.03 2.26 1.269.26 MWD OWSG(3) 5,453.23 88.00 18722 3.518.81 3,430.81 -1.29708 2.615.41 5,98952731 542,451.84 4.73 129708 MWD OWSG(3) 5,484.95 87.62 189.98 3,52002 3,432.02 -1.328.42 2,61068 5,989,495.95 542,447.27 878 1,328.42 MWD OWSG(3) 5,53342 89.15 189.48 3.521.39 3.433.39 -1.376.17 2,60249 5,989,448.16 542,439.33 3.32 1,376.17 MWD OWSG(3) 5.57417 8990 188.35 3,521.73 3,433.73 -141642 2.596.17 5,989,40787 542,433.23 3.33 141642 MWD OWSG(3) 5.629.91 89.10 185.92 3,522.21 3.434.21 -1,47172 2.589.25 5,989,352.54 542426.61 4.59 1.471.72 MWD OWSG(3) 5,660.82 88.15 187.54 3,522.96 3,434.96 -150241 2,585.63 5,989,32164 542,423.15 6.07 1,502.41 MWD OWSG(3) 5.693.77 88.02 18747 3.524.97 3,436.06 -1,53506 2,581.33 5989,289.17 542.419.02 0.45 1,535.06 MWD OWSG(3) 5,729.99 89.09 186.40 3,524.97 3.436.97 -1,57100 2,57696 5,989,253.21 542,414.84 4.18 1,571.00 MWD OWSG(3) 5,75715 89.26 18667 3.525.35 3.43736 -159798 2.573.87 5,989,226.21 542,411.90 1.17 1,59798 MWD OWSG(3) 5800.89 89.57 187.98 3,52581 3.437.81 -1.641.36 2.56829 5.989,182.81 542,406.55 3.08 1.641.36 MWD OWSG(3) 5,832.28 90.58 185.81 3,52577 3.437.77 -1,672.52 2,564.52 5,989,151.63 542,402.95 7.83 1.672.52 MWD OWSG(3) 5,874.78 9244 187.44 3,524.65 3,436.65 -1]14.72 2.559.62 5989,10941 542.398.27 5.82 1,71472 MWO OWSG (3) Annotation TIP KOP aA. KER "I 8!2212019 9:52:OIAM Page 3 COMPASS 5000 14 Build 85H ConocoPhillips ER ConocoPhillips Definitive Survey Report Company. ConocoPhdhps Alaska Inc_Kuparuk Local Coordinate Reference: Well iR-26 Project: Kuparuk River Unit TVD Reference: 1 R-26 @ 88.00usft (1R-26) Site: Kuparuk I Pad MD Reference: 1R-26 @ 8800usft (1R-26) Well 1R-26 North Reference: Tale Wellbore: 1R-126 Survey Calculation Method: Minimum Curvature Design: IR -126 Database: EDT 14 Alaska Production Survev Map Map Vertical MD Inc A TVD NDSS -NAS -E/-W DLS (usft) O ) (°) (usft) (ust[) (usft) (usft) Northing Easting Section Survey Tool Name Annotation Y (ft) (ft) (ft) 5,901.98 63.08 188.54 3,524.52 3436.52 -174165 2,555.84 5,989082.46 542,39464 16.53 1.74165 10 IDOWSG(3) 5,93367 87.08 187.19 3.525.86 3.437.86 -1.773.01 2,55151 5,989,051.08 542,390.47 5.30 1,773.01 MWD OWSG(3) 5,959.16 88.96 186.07 3.52674 3.438.74 -1.798.32 2,548.57 5,989,02577 542,38767 8.58 1,798.32 MWD OWSG(3) 5,987.90 88.76 186.30 3,52731 3439.31 -1.82688 2.545.47 5,988,997.19 542,384.72 1.06 1.82688 MWD OWSG(3) 6018.19 87.50 186.15 3.528.30 344030 -1.856.98 2,542.19 5,988,967.08 542.38160 4.19 1,856.98 MWD OWSG(3) 6,048.69 87.57 185.06 3,529.61 3,44161 -1,887.30 2.539.21 5.988 936 74 54237879 3.58 168730 MWO OWSG(3) 6.078.45 88.34 186.67 3.53068 3,442.68 -1,916.89 2,536.17 5,988,90714 542,375.91 5.99 1.91689 MWD OWSG(3) 6.10.28 89.15 185.36 3,531.31 344331 -1,945.55 2,533.15 5.988,87847 542.373.04 534 1,945.55 MWD OWSG(3) 6,134.70 89.43 186.87 3,531.65 3,44365 -1,972.81 2,530.23 5.988.85119 542,370.26 5.60 1,972.81 MWD OWSG(3) 6,162.80 90.37 187.02 3,531.70 3,44370 -2,000.71 2,526.83 5.988 B23 542,367.01 3.39 2,000.71 MWD OWSG(3) 6,195.85 89.11 18777 3.531.85 3443.85 -2.033.48 2.522.58 5.988,790.49 542,362.94 444 2,033.48 MWD OWSG(3) 6,219.12 89.44 18.39 3,532.14 3.444.14 -2,05657 2519.71 5.988.76739 542,36019 6.10 2,08.57 MWD OWSG(3) 6.248.69 93.82 187.65 3.531.30 3.443.30 -2.085.90 2,516.10 5,988,73804 542,356.74 1541 2,085.90 MWD OWSG(3) 6,27861 9308 187.98 3,529.50 3.441.50 -2,11549 2,512.04 5.98,70844 542,35283 2.71 2,11549 MWD OWSG(3) 6,310.32 93.39 18745 3,527.71 3,439.71 -2.146.86 2,50779 5,98.677.05 542,348.75 193 2,146.8 MWD OWSG(3) 6.338.20 9170 184.05 3,52647 3,438.47 -2.174.57 2,505.00 5.98,649 .33 542.346.11 13.61 2.174.57 MWD OWSG(3) 6,36816 9260 184.59 3,52535 3.437.35 -2,204.42 2,502.75 5,98,61946 542,344.01 3.50 2,204.42 MWD OWSG(3) 6,398.57 91.44 182.90 3,524.28 3,436.28 -2,23475 28076 5,988,589 13 542,342.19 674 2.234.75 MWD OWSG(3) 6,427.91 90.16 182.87 352387 3.435.87 -2.264.05 2,499.29 5,98,559.83 542,340.87 4.36 2264.05 MWD OWSG(3) 6,458.02 8903 183.56 3,524.08 3,436.08 -2,294.11 2.497.8 5,988.529.76 542.339.34 4.40 2,294.11 MWD OWSG(3) 6,487.55 8923 185.93 3,524.53 3,436.53 -2,32353 2,495.15 5,98,500.33 542,33706 8.05 2,323.53 MWD OWSG(3) 6.518.28 89.20 186.03 3.524.95 3,436.95 -2.354.09 2,491.95 5,988,16976 542.334.02 0.34 2.354.09 MWD OWSG(3) 6,548.78 8.31 184.49 3,52561 3,437.61 -2,384.45 2.489.16 5,98,439.38 54233139 5.83 2,384.45 MWD OWSG(3) 6,578.15 88.57 184.94 3,52641 3,43841 -2,41371 2.48.74 5,98,41011 542.329.13 177 2.41371 MWD OWSG(3) 6,608.07 8940 185.56 3,526.94 3,438.94 -2.44350 2,484.01 6,988 380 542.326.55 346 2,443.50 MWD OWSG(3) 6,639.24 8.34 185.16 3,527.56 3439% -2,474.53 2481.10 5,988 349.27 542,323.80 3.63 2,474.53 MWD OWSG(3) 6,669.70 8.53 187.14 3.528.39 3,440.39 -2,504.8 2,4778 5.98.318.99 542.320.70 6.53 2,504.80 MWD OWSG(3) 6697.84 90.60 18.58 3,52860 3,440.60 -2.532.67 2.473.99 5,9138291 10 542,317.01 8.96 2,53267 MWD OWSG(3) 6.726.05 8978 187.91 3.528.51 3440.51 -2.56060 2,469.94 5,98.263.15 542,313.11 375 2,560.60 MM OWSG(3) 6]55.83 91.30 187.11 3,528.23 3440.23 -2,590.11 2,16605 5.98,233.62 542,309.37 577 2590.11 MWD OWSG(3) 6,78727 8975 18576 352794 343994 -2,621 35 246253 5.988 202 37 542.306 02 651 2 621 35 MWD OWSG (3) 8/22/2019 952,01AM Page 4 COMPASS 5000. 14 Build 85H Survey Well 1R-26 1R-26 @ 88.00usft(1 R-26) 1 R-26 @ 88.00usft (i R-26) True Minimum Curvature EDT 14 Alaska Production ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc Kuparuk Local Coordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 1R Pad MD Reference: Well: IR -26 North Reference: Wellbore: IR -126 Survey Calculation Method: Design: 1R-126 Database: Survey Well 1R-26 1R-26 @ 88.00usft(1 R-26) 1 R-26 @ 88.00usft (i R-26) True Minimum Curvature EDT 14 Alaska Production Vertical Section Survey Tool Name (ft) 264981 Map Map MWD OWSG (3) MD Inc Azi TVD TVDSS -NI-S -E7-W MWD OWSG (3) 2.830.31 DLS 2,860.89 MWD OWSG (3) 2.889.14 MWD OWSG (3) 2,917.91 MWD OWSG (3) 2,937.29 Northing Easting MWD OWSG (3) (usft) O (1) (usft) (usft) (usft) (usft) MWD OWSG (3) 3,112.74 MWD OWSG (3) 314140 MWD OWSG (3) 3,177.95 MWD OWSG (3) 320793 MWD OWSG (3) 3.242.37 (ft) (ft) MWD OWSG(3) 6,815.85 8888 184.70 3,52828 3440.28 -2,649.81 2,459.92 5,988,173.90 542.303.56 4.82 6,84341 89.48 185.36 3,528.67 3.44067 -2.67226 2,457.50 5,988,146.44 542,301.29 3.24 6.874.05 90.69 184.50 3,528.62 3.440.62 -2.707.79 2,454.87 5.988.11580 542298.82 4.84 6,905.51 90.51 185.92 3528.29 3.44030 -2,739.11 2,452.01 5,988,084.56 542,296.14 455 6,93617 88.43 183.73 3.528.58 3.440.58 -2.769.66 244944 5988,054.00 542,293.72 9.85 6.967.75 89.39 18319 3,52918 3,44118 -2,801.18 2,447.53 5,988.02248 542.291.98 349 6.996.93 90.35 183.46 3,52925 3,441.25 -2.83031 2,445.84 5,987993.35 542,29045 342 7,027.61 89.41 18554 3,529.31 3.441.31 -2.860.89 2,443.43 5,987,96275 542.288.20 244 7,055.97 89.93 184.62 3,529.47 3.44147 -2,889.14 244092 5,987.934.49 542,285.84 373 7,084.89 90.65 186.73 3,529.33 3,44133 -2.917.91 2,438.06 5.987.905.71 542.283.13 271 7,104.51 90.38 19119 3,52915 3,44115 -2.937.29 2435.01 5.987.886 32 542,280.18 22.77 7,132.56 9092 191.35 3.528.83 3.440.83 -2.964.80 2,42952 5.987.85878 542,274.85 2.01 7,164.80 90.78 190.54 3528.35 3440.35 -2.996.45 242340 5.987 827.11 542,268.90 2.55 7,192.04 90.18 19092 3.528.13 3.440.13 -3.023.21 2,41833 5,987,800.32 542263.97 2.61 7,22213 90.01 169.90 3,52808 3,440.08 3.052.80 2,412.90 5,987.770.70 542 258 69 344 7.252.98 9238 190,60 3,527.43 3,439.43 3,083.15 2,40741 5,987,740.32 542.253.37 8.01 7,283.04 91.19 189.50 3.52650 3.438.50 -3,11274 2,402.16 5,987,710.72 542,248.28 5.39 7,312.11 90.34 18969 3,526.11 3,4M 11 -314140 2397.32 5.987.682 03 542.243.59 300 7348.97 8957 184.90 3.526.14 3.438.14 -3.177.95 2,39264 5,98264546 542,239.10 13.16 7,379.09 88.95 186.06 3.526.53 3.438.53 -3.207.93 2,389.76 5.987.61547 542,236.39 4.37 741374 87.80 185.85 3.527.51 3.439.51 -3.242.37 2,38617 5,987,581.01 542,23298 3.37 7 441 .97 87.19 18440 3,528.74 3490]4 -3.27046 2,383.65 5,987,55291 542,23061 5.57 7,469.74 90.14 183.51 3,529.39 3,441.39 -3,298.16 2.38174 5,987,52521 542,228.84 1110 ]499.60 90.26 183.42 3,52928 3,441.29 3,327.96 2.379.93 5,987.49540 542227.20 050 151106 89.65 182.59 3,529.31 3,44131 -3,362.37 2,378.13 5.987,460 98 542,225.57 299 7,572.00 92.54 183.97 3,52859 3,440.59 -3,400.24 2,375.96 5,987,423.10 542.223.61 844 7,604.66 9197 183.57 3.527.30 3,439.30 -3.432.82 2,373.81 5.98239051 542,221.63 2.13 2639.14 91.79 180.95 3.526.17 3.438.17 -3,167.24 2,372.45 5.987,356.10 542,220.46 762 2671.53 92.83 180.34 3524.86 3436.67 449960 2,372.09 5.987,323 74 542,220.27 3.72 7]03.90 90.34 180.08 3523.80 3,435.80 -353795 2,37195 5.98228539 54222033 6.52 7 741.33 8997 179.88 352372 343572 -3.569.38 237196 5,987 25396 542220 51 1 34 Vertical Section Survey Tool Name (ft) 264981 MWD OWSG (3) 2.677.26 MWD OWSG (3) 2.70779 MWD OWSG (3) 2,739.11 MWD OWSG(3) 2.769.66 MWD 0W$G(3) 2.801.18 MWD OWSG (3) 2.830.31 MWD OWSG (3) 2,860.89 MWD OWSG (3) 2.889.14 MWD OWSG (3) 2,917.91 MWD OWSG (3) 2,937.29 MWD OWSG (3) 2.964.80 MWD OWSG (3) 2.996.45 MWD OWSG (3) 3.023.21 MWD OWSG (3) 3.052.80 MWD OWSG (3) 3.083.15 MWD OWSG (3) 3,112.74 MWD OWSG (3) 314140 MWD OWSG (3) 3,177.95 MWD OWSG (3) 320793 MWD OWSG (3) 3.242.37 MWD OWSG(3) 3,27046 MWD OWSG(3) 3.29816 MWD OWSG (3) 3.327.96 MWD OWSG (3) 3,362.37 MWD OWSG (3) 340024 MWD OWSG (31 3,432.82 MWD OWSG (3) 3,467.24 MWD OWSG (3) 3,499.60 MWD OWSG (3) 3,537.95 MWD OW$G(3) 3.56938 MWD OWSG (3) 13AF UGRES Annotation i 812212019 9: 52.01AM Page 5 COMPASS 5000 14 Build 85H Survey ConocoPhillips 6A ER b UGtiEs ConocoPhillips Definitive Survey Report Map Company: ConocoPhillips Alaska Inc Kuparuk Local Coordinate Reference: Well 1R-26 Project Kuparuk River Unit TVD Reference: 1R-26 tQ 88.01(1 R-26) ND Site: Kupamk 1 R Pad MD Reference: 1R-26 @ 88.01(1R-26) Northing Well: 1R-26 North Reference: True Wellbore: 1R-126 Survey Calculation Method: Minimum Curvature (usft) Design: 1R-126 Database: EDT 14 Alaska Production Survey 8222019 9:52:01AM Page 6 COMPASS 5000 14 Build 85H Map Map Vertical MD Inc ) ND TVD55 -N/-S -E/-W Northing Easting DLS Section Section (usft) I°) (1 1°) (usft) (usft) (usft) (usft) (.1100.) Survey Tool Name Annotation (ft) (ft) 7,76740 89.46 180.27 3,523.85 3435.85 -359545 2,371.92 5,987 227,90 542.220.61 2.46 3.595.45 MWD OWSG (3) 7800.10 91.98 180.80 3.523.44 3,435.44 -3.628.14 2,371.62 5,98719521 542,220.48 7.87 3,628.14 MWD OWSG (3) 7,83114 93.17 180.71 3.522.04 3434.04 -3.659.15 2,371.21 5,987,164.20 542,22024 384 3,659.15 MWD OWSG (3) 7.86448 92.64 178.83 3,520.35 3.432.35 -3,69244 2,371.34 5,987,130.91 542,220.55 585 3,69244 MWD OWSG (3) 7.895.85 90.57 178.15 351947 3,43147 -372379 2.372.17 5.987,099.57 542,221.54 695 3.72379 MWD OWSG (3) 7,938.31 89.80 181.76 3,519.34 3,43134 -3,766.24 2,372.20 5.987,05713 542.22160 869 3.766.24 MWD OWSG (3) 7.977.97 87.47 18362 3,52028 3,432.28 -3,805.84 2.370.34 5,987,017.52 542.220.15 7.52 3.805.84 MWD OWSG (3) 8,00637 8776 182.22 3,52155 3,433.55 -3,836.17 2,368.80 5,986,987.18 542,218.77 4.70 3,836.17 MM OWSG (3) 8,04103 88.04 182.10 3,522.74 3,434.74 -3,868.79 2.36757 5,986,954.56 542,21771 0.93 3.868.79 MWD OWSG (3) 8,077.20 88.64 184.50 3,52379 3,435.79 -3904.88 2,365.18 5,986,91847 542,215.82 6.84 3,904.88 MWD OWSG (3) 6,102.48 88.37 184.70 3.524.45 3436.45 -3,930.07 2.363.46 5.9%.893.27 542,213.93 1.33 3.930.07 MWD OWSG (3) 8,131.03 W47 185.90 3.525.24 3.437.24 -3,958.49 2.360.82 5,986,864.84 542,21145 4.22 3,958.49 MWD OWSG (3) 8,163.67 90.84 186.64 3,525.44 3,43744 3.990.93 2,35726 5,986,832.38 542.208.05 7.61 3,990.93 MWD OWSG (3) 8.200.05 9197 186.89 3,524.54 3436.54 4027.04 2,352.97 5,986,796.25 542,203.96 3.18 4,027.04 MWD OWSG (3) 8,228.43 90.43 167.01 3,523.95 343595 4,055.21 2.349.54 5,986.768.07 542,200.68 544 4,055.21 MWD OWSG (3) 8.267.23 9104 188.34 3,52345 3,43545 4,093.66 2.344.36 5,986,729.60 542.195.70 3.77 4.09366 MWD OWSG (3) 8,299.74 89 fib 186.69 3,523.25 3,435.25 4,125.88 2340.11 5,986,69735 542,191.62 662 4,125.88 MWD 01 (3) 8,330.11 91.21 186.67 3,523.02 3,43502 4,156.05 2.335.57 5,986,667.17 542,188.25 5.10 4,156.05 MWD OWSG (3) 8358.39 9202 188.56 3.522.23 3,434.23 4184.06 2.332.83 5985,639.14 542,184.65 7.27 4,184.06 MWD OWSG (3) 8,391.24 92.35 18740 3,520.97 3,432.97 4216.57 2.328.27 5,986.606.61 542,180.27 3.67 4216.57 MWD OWSG(3) 8,420.59 92.36 188.06 3.519.77 3,43177 4,245.63 2,324.33 5,986,577.53 542,176.48 2.25 4,245.63 MWD OWSG (3) 8458.04 93.86 187.25 3,517.73 3,429.73 4,282.69 2,31935 5,986,54045 542,171.70 4.55 4282.69 MWD OWSG (3) 8492.03 9066 18864 3.516.39 3,428.39 4.316.32 2,314.65 5,986,506.80 542,167.19 1026 4,31632 MWD OWSG (3) 8.528.60 89.54 188.52 3,516.33 3.428.33 4.352.48 2.309.20 5,98547061 542.161.92 3.08 4.352.48 MWD OWSG (3) 8,557.59 89.01 185.81 3,516.70 3,42820 -0361.24 2.30558 5.986,441.84 542,158.46 9.52 4.38124 MWD OWSG (3) 8,592.91 8960 18762 3,517.13 3,429.13 4,416.32 2,30145 5,986,406.75 542,154.52 5.39 4.416.32 MWD OWSG (31 8,619.35 8943 185.66 3.517.35 3A29.35 4.442.58 2,298.39 5986,38047 542,15160 744 4.442.58 Mi OWSG (3) 8.654.06 90.20 18757 3,517 46 3,429,46 4 477 05 2.29440 5.986.345.98 542,147 79 593 4,47705 MWD OWSG (3) 8688.13 90.29 186.60 3.517.32 3.429.32 4,510.86 2190.19 5.966.312.15 542,143.77 2.86 4,510.86 MWD OWSG (3) 8.719.80 9072 18720 351704 3,42904 -0542.30 2286.39 5.986.28069 542,14013 233 4542.30 MWD OWSG l3) 8.757.26 9394 18828 3515.51 3.42751 4579.38 2.28135 5.986.24359 542 135 29 907 4.579.38 MWD OWSG (3) 8222019 9:52:01AM Page 6 COMPASS 5000 14 Build 85H ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 1R-26 Project: Kupamk River Unit TVD Reference: iR-20 @ 88.00usft (I R-26) Site: Kuparuk 1R Pad MD Reference: iR-26 @ 88.00usft (IR-26) Well: 1R-26 North Reference: True Wellbore: 1R-126 Survey Calculation Method: Minimum Curvature Design: 1R-126 Database: EDT 14 Alaska Production Survey 8A ER F�l/�d�S 8@22019 9.52r01AM Page 7 COMPASS 5000 14 build 85H Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W DLS (usft) (') (1) (usft) (usft) (usft) (usft) NorthingEastin 9 (=1100•) Section Survey Tool Name Annotation (ft) (ft) (ft) 879262 95.27 186.91 3,51268 342468 4614.32 2,276.69 5,986.20863 542.130.82 539 4.614.32 MWD OWSG(3) 8.82395 9075 187.32 3.51103 3423.03 -0.645.36 2,27282 5986.177 58 542,127.11 14.49 4,645.36 MWD OWSG(3) 8,852.40 9164 188.84 3,510.59 3,422.59 4,673.52 2.268.82 5,986,149.40 542,123.26 5.44 4,673.52 MWD OWSG(3) 8,884.43 89.95 18789 3.510.31 3,422.31 -0.705.21 2,26416 5,986,117.69 542,118.77 4.51 4,705.21 MWD OWSG(3) 8,915.96 89.46 188.89 3,51047 3,42247 4.736.40 2,259.56 5,986,086.48 542,114.34 3.53 4.736.40 MWD OWSG(3) 8,945.07 89.28 18844 351079 3,42279 4.765.17 2255.17 5,986,057.68 542.110.10 1.66 4.765.17 MWD OWSG(3) 8,974.59 90.28 191.59 3.510.91 3,422.91 4,794.24 2,25004 5,986,028.59 542,105.13 11.20 4794.24 MWD OWSG(3) 9,004.17 89.09 19168 3,511.07 3,423.07 4.823.21 2,244.07 5985,999.59 542.099.32 4.03 4,823.21 MWD OWSG(3) 9,032.84 89.20 19164 3,511.50 3423.50 4.85129 2,238.28 5,985,97149 542,093.67 0.41 4,851.29 MWD OWSG(3) 9,064.93 91.63 19248 3,511.26 3,423.26 4,88267 2.231.58 5,985.940.08 542,087.14 8.01 4882.67 MWD OWSG(3) 9,092.51 91.42 193.32 3.51053 342253 4.909.54 2.22542 5.985.913.17 542,081.13 3.14 4,909.59 MWD OWSG(3) 9,122.84 90.39 192.05 3.510.05 3.422.05 4.939.12 2.218.76 5985.883.% 542,07462 5.39 4.939.12 MWD OWSG(3) 9,149.83 90.M 192.35 3,509.94 342194 4.965.50 2.213.06 5,985,85715 542,069.06 165 4,965.50 MWD OWSG(3) 9,180.86 90.95 19379 3.509.67 3,42167 4,99573 2,206.04 5,985,82669 542,062.21 5.46 4.995.73 MWD OWSG(3) 9,207.95 91.01 192.79 3,509.21 3.421.21 -5,022.09 2,199.82 5,985800.50 542.056.12 3.70 5.022.09 MWD OWSG(3) 9,237.05 9008 191.98 3.508.93 3,420.93 5,050.51 2,193.58 5,985,772.05 542,050.03 4.24 5.050.51 MWD OWSG(3) 9,267.31 90.71 191.20 3,508.72 3,42072 5.060.15 2,187.50 5,985,742.38 542,044.11 3.31 5,080.15 MWD OWSG(3) 9,297.61 91.72 19132 3.508.08 3.420.08 5,109.86 218158 5,985,71264 542,038.36 3.36 5,109.86 MWD OWSG(3) 9.324.52 9027 190.19 350761 341961 5.136.29 2,17656 5985686.18 542,033.48 6.83 5,136.29 MWD OWSG(3) 9,352.47 89.95 190.36 3.507.56 3,419.56 -5.163.80 2.171.57 5,985.658.66 542,028.64 1.30 5.163.80 MWD OWSG(3) 9,384.50 89.52 190.05 350771 3,41971 -5,195.32 2,16590 5,985,627.11 542,023.13 1.65 5,195.32 MWD OWSG(3) 9,413.02 90.23 189.35 3.507.77 3.419.77 5,223.43 2,161.09 5,985,598% 542.018.48 3.50 5,223.43 MWD OWSG(3) 9.442.60 89.58 188.06 3,50782 3.419.62 5,252.67 2,15662 5.985,56972 542,014.16 4.88 5,252.67 MWD OWSG(3) 9.470.63 89.57 18806 3,508.03 3.42003 5,280.42 2,152.69 5,985,541.95 542,010.37 0.05 5.280.42 MWD OWSG(3) 9,496.92 9048 188.74 3,508.01 3,420.01 -5,306.43 2,14884 5,985,515.92 542,00667 4.30 5,306.43 MWD OWSG(3) 9,529.20 90.82 188.55 3,50765 3.41965 5,338.34 2,14399 5,985,483.99 542,001.99 1.21 5,338.34 MWD OWSG(3) 9,556.99 9080 18846 3,507.26 3.419.26 -5,365.82 2,13988 5,985.456.49 541,998.02 0.33 5365.62 MWD OWSG(3) 9,586.85 91.97 187.94 3.506.53 3.41853 -5.395.37 2.135.62 5.985,426 92 541993.93 4.29 5.395.37 MWD OWSG(3) 961565 9191 186.40 3.50556 3.417.56 -5.423.92 2,132.03 5.985.398.35 54199049 5.35 5.423.92 MWD OWSG(3) 9,645.37 9160 18575 3.504.65 3.416.65 -545346 2.128.89 5.985,368.80 54198750 242 5,453.46 MWD 0WSG(3) 9,677.77 90.18 18540 3504.15 3.41615 -548570 2.125.74 5,98533654 541984.52 4.51 5.485.70 MWD OWSG(3) 8A ER F�l/�d�S 8@22019 9.52r01AM Page 7 COMPASS 5000 14 build 85H ConocoPhillips 6A E ConocoPhilliR cNcs (� Definitive Survey Repoli u Company: ConocoPhillips Alaska Inc_Kupamk Local Coordinate Reference: Well 1R-26 Project: Kuparuk River Unit TVD Reference: 1 R-26 @ 88-00usft (1R-26) Site: Kuparuk 1R Pad MD Reference: 1R-26 @ 88.00usft (1R-26) Well: 1R-26 North Reference: True Wellbore: 1R-126 Survey Calculation Method: Minimum Curvature Design: 1R-126 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc ND NDSS *NI -S *E7 -W OLS ) Northing Easting Section Survey Tool Name (usft) (°) (1 (°) (usft) (usft) (usft) ft) (usk) (ft) (ft) (°/WO') (ft) 9.705.94 89.09 167.27 3.50432 341632 -5.513.70 2.122.63 5,985.308.53 54196157 768 5,51370 MWD OWSG(3) 9,737.23 90.36 188.54 3.50447 3,41647 3,544.69 2,118.33 5,98527752 541.97743 5.74 5.544.69 MWD OWSG(3) 9,764.84 90.38 18881 3.504.30 3,416.30 -5.571.99 2,11417 5,985,250.21 541,973.41 0.98 5,57199 MWD OWSG(3) 9,79436 9171 189.18 3,503.76 3,415.76 -5.601.14 2.109.55 5,985,221.04 541,968.95 4.68 5,601.14 MWD OWSG(3) 9,826.17 90.48 188.78 3,503.15 3415.15 5.632.55 2,104.59 5,985,18960 541964.15 4.07 5,632.55 MWD OWSG(3) 9855.10 90.12 188.87 3,503.00 3,41500 5,661.14 2,10015 5,985,160.99 541.959.87 1.28 566114 MWO OWSG(3) 9,88510 90.53 188.40 3,50283 3,414.83 5.690.80 2.09564 5,985,131.31 541,955.52 2.08 5,690.80 MWD OWSG(3) 991706 90.52 188.51 3,502.54 3,414.54 5,72241 2,090.95 5,985,099.68 541,950.99 0.35 5722.41 MWD 0WSG(3) 9.944.95 91.11 188.38 3,602.14 3,414.14 -5,749.99 2.08685 5,985,072.08 541,94704 2.17 5.749.99 MWD OWSG(3) 9,974.18 89.66 188.61 3,501,94 3,413.94 5.778.90 2,082.53 5,985,043.15 541,942.88 502 5,778.90 MWD OWSG(3) 10,006.08 89.89 186.52 3.50207 3414.07 5.810.52 2.07833 5985.01151 541,936.85 6.59 5.810.52 MWD 0WSG(3) 10037.78 9074 185.93 3.501.89 3413.89 -5.84203 2,074.90 5,984,979.98 541,935.58 3.26 5,84203 MWD OWSG(3) 10.065.64 9102 185.87 3501.47 3,413.47 5,869.74 2,072.03 5,984,95226 541.932.87 1.03 5,869.74 MWD OWSG(3) 10,(&158 90.99 186.25 3.500.96 3,412.96 -5,898.52 2,07898 5.984.923.48 541.929.97 1.32 5,898.52 MWD OWSG(3) 10.125.25 90.71 185.82 3,50050 3,412.50 -5,929.01 2.06575 5,984.892.96 541,926.90 167 5,92901 MWD OWSG(3) 10.154.24 91.54 185.63 3,49993 3,411.93 5,957.85 2.062.86 5,984,864.11 541924.17 2.94 5.957.85 MWD OWSG(3) 10,184.97 86.84 185.89 3499.83 3.411.83 5,988.42 2.05978 5984,83353 541,921.25 8.83 5,988.42 MWD OWSG(3) 10.215.07 8878 186.82 3,500.46 3,41246 -6,01833 2,056.45 5,984,803.61 541918.07 3.10 6,018.33 MWD OWSG(3) 10244.07 88.79 18760 3.50107 3.413.07 8.047,10 2.052.81 5984.774.83 541,914.59 269 6,047.10 MWD OWSG(3) 10,27307 89.57 188.29 3,50149 3,41349 -6.07581 2,048.80 5,984,746.09 54191073 3.59 6,075.81 MWD OWSG(3) 10,304.68 89.51 189.34 3,501.74 3,413.74 8,107.05 2,043.96 5,98471483 541,906.06 3.33 6,107.05 MWD OWSG(3) 10,34962 8933 19058 3.502.20 3.41420 -6.151.31 2,036.18 5,98,1.670 &1 541,898.52 2.79 6151.31 MWD OWSG(3) 10,380.58 89.70 191.11 3.502.46 3,41446 8,181.71 2,03036 5984,640.10 541,892.86 2.09 6,181.71 MWD OWSG(3) 10,422.48 89.58 18962 3,50272 3,414.72 -6,222.93 2,022.82 5,98459885 541,885.54 3.57 6,222.93 MWD OWSG(3) 10,448.17 8962 189.88 3.502.90 3,414.90 -6.24825 2,01847 5,984.57351 541,881.33 1.02 6,248.25 MWD OWSG(3) 10,48157 88.12 18743 3,503.58 3,41556 -6,281.26 2,01345 5,984,540.18 541,87648 860 6,281.26 MWD OWSG(3) 10.510.21 89.25 185.62 3,504.22 341622 -6.30970 2,010.14 5.984,512.03 541,873.33 6.87 6,309.70 MWD OWSG(3) 10.53979 91.01 18441 3504.15 3416.15 -6,33916 2,007.51 5.984,48256 541,870.85 7.62 6,339.16 MWD OWSG(3) 10,557.87 91.16 184.48 3,503.62 3415.62 -6.367.15 2,00533 5,984.454.56 541,858.82 0.59 6.367.15 MWD OWSG(3) 10,599.20 92.59 18362 3.502.59 3.41459 8.396.38 2,003.12 5,984,423.31 541866.78 5.33 6396.38 MWD OWSG(3) 10.630.42 93 46 18348 3 500 95 341295 8.429.50 2001. 19 5.984 392 19 541 86501 282 642950 MN/D OWSG (3) Annotation 62212019 9'52:01AM Page 8 COMPASS 5000. 14 Build 85H /�������. ConocoPhillips RA(EF? Co R/l.lJt"11illi r�UGRES Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Coordinate Reference: Well 1R-26 Project: Kuparuk River Unit TVD Reference: lR-26 @ 88.00usft (1 R-26) Site: Kuparuk 1R Pad MD Reference: 1R-26 @ 88.00usft (1R-26) Well: 1R-26 North Reference: True Wellbore: lR-126 Survey Calculation Method: Minimum Curvature Design: 1R-126 Database: EDT 14 Alaska Production Survey 8,222019 9:52.01AM Page 9 COMPASS 5000.14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS *Nl-S +EI -W DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (.1100r) Section Survey Tool Name Annotation (ft) (ft) (ft) 10,66092 92.71 18413 3.499.30 3,411.30 -6459.89 1999.17 5.984,36180 541863.15 3.25 645989 MWD OWSG(3) 10693.56 90.29 186.18 3498.45 3,410.45 6.492.38 1,996.23 5.984.329.29 541,860.39 9.72 6,492.38 MWD OWSG(3) 10721.68 9140 184.30 3.498.03 3,410.03 -6.520.38 1993.67 5.984,30128 591,857 97 7.76 6,52038 MWD OWSG(3) 10,749.28 93.10 184.34 3.496.95 3,408.95 6,547.68 1,99159 5,984,27378 541,856.04 6.16 6,547.88 MWD OWSG(3) 10,780.83 91.87 186.82 3.495.58 3,407.58 6.57924 1,988.52 5,984,24240 541.853.15 877 6,579.24 MWD OWSG(3) 10,810.10 9109 186.46 3,494.83 3,406.83 -6,60831 1985.14 5,984,213.32 541,84992 293 6,608.31 MWD OWSG(3) 10,841.57 92.11 186.14 3,493.95 3,405.95 6,639.57 1.981.69 5,984,182.03 541996.63 3.40 6.639.57 MWD OWSG(3) 10,872.54 9160 18468 3492.95 3,404.95 -6,670.39 1,978.77 5,984.151.21 541843.88 4.99 6,670.39 MWD OWSG(3) 10,90700 91.60 18468 3.491.98 3,403.98 -6,704.72 1,97596 5,984,116.86 541841.25 0.00 67N72 PROJECTED to TD 8,222019 9:52.01AM Page 9 COMPASS 5000.14 Build 85H BAT IGHES a GE company 10: - _ --- - Date: Abby Bell I AOGCC 333 West 7th Ave, Suite 100 j Anchorage, Alaska 99501 August 22, 2019 2 190 94 31110 Letter of Transmittal Harvey Finch Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 find enclosed the directional survey data for the following well(s): 1R-126 1R -126L1 1R-126PB1 RECEIVED AUG 2 3 2019 AOGCC (3) Total print 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(u)BakerHuehes.com i 0. ConocoPhillips ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 1R Pad 1 R -126L1 50-029-22193-60 Baker Hughes INTEQ Definitive Survey Report 22 August, 2019 BA, ICER UGHES aGEcompany 21 9094 31119 ConocoPhillips aTS ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit Site: Kuparuk 1R Pad Well: 1R-26 Wellbore: 1R-1261-1 Design: 1R-126LI 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 1R-26 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Position +N/S 0.00 usft Northing: Vertical Section: •E/ -W 0.00 usft Easting: Position Uncertainty 1/26/2014 000 usft Wellhead Elevation: Wellbore 1R-12611 43 20 000 Magnetics Model Name Date Sample Date From BGGM2018 8/112019 Design 1R-1261-1 Survey (Wellbore) Tool Name Audit Notes: 4,450.00 1R-26-GYD-CT-CMS(1 R-26) GYD-CT-CMS Well 1R-26 1R-26 @ 88.00usft(1 R-26) 1R-26 @ 88.00usft(1 R-26) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,990,810.31 usft Latitude: 539,829.81 usft Longitude: usft Ground Level: Declination Dip Angle (') (') 16.51 80.89 Version: 1 0 Phase: ACTUAL Tie On Depth: 4.450.00 Vertical Section: Survey Depth From (TVD) N/ -S 1/26/2014 1/26/2014 (usft) (usft) 43 20 000 Survey Program Date From To (usft) (usft) Survey (Wellbore) Tool Name 50.00 4,450.00 1R-26-GYD-CT-CMS(1 R-26) GYD-CT-CMS 4,46360 7,344.90 1R-12611 MWD(111426L1) MWD OWSG -E/-W (usft) 0 00 Description Gyrodata confessing m/s OWSG MWD -Standard 70' 23' 9.012 N 149` 40' 33.844 W 4120 usft Field Strength (nT) 57,412 Direction V) 90.00 Survey Survey Start Data End Data 1/26/2014 1/26/2014 7/16/2019 7/22/2019 8/22/2019 9:52:51AM Page 2 COMPASS 5000 14 Build 85H ConocoPhillipsER 0 ConocoPhillips Definitive Survey Reportu Company: ConowPhdlips Alaska lnc_Kuparuk Local Co-ordinate Reference: Well 1R-26 Project: Kuparuk River Unit TVD Reference: 1 R-26 @ 88-00usft (1R-26) Site: Kuparuk I Pad MD Reference: 1 R-26 @ 88.00usft (1R-26) Well: 1R-26 North Reference: True Wellbore: 1R-1261-7 Survey Calculation Method: Minimum Curvature Design: 1R-1261-1 Database: EDT 14 Alaska Production Survey MD Inc Azi TVD TVDSS -NI-S -El-W Map Map DLS Vertical (usft) (1) (') (usft) (usft) (usft) (usft) Northing Eaing tRj ('1100') Section Survey Tool Name (ft) ( (ft) 4450.00 51.34 101.56 340821 3.320.21 47847 2.363.82 5.990,34448 542.195.92 191 2.363.82 GYD-CT-GMS(1) 4,463.60 51.32 101.45 3416.70 3.328.70 480.59 2.374.23 5990,34241 542,206.33 0.65 2,374.23 MWD OWSG(2) 4.494.28 57.39 105.05 3,434.58 3,346.58 -486.33 2,398.47 5.990,336.81 542,230.60 2196 2398.47 MWD OWSG(2) 4,524.75 61.83 108.66 3,449.99 3.361.99 493.97 2,423.61 5,990,329.31 542,255.78 17.0 2,423.61 MWD OWSG(2) 4,552% 66.21 112.24 3.6196 3.373.96 -502.55 2,446.60 5.990.32084 542,278.81 19.90 2.44660 MWD OWSG(2) 4,599.58 7782 11230 3,476.60 3.388.60 -51965 2,488.35 5.990.30397 542.32065 2443 2,488.35 MWD OWSG(2) 4,629.72 84.09 116.18 3,48134 3,393.34 -531.87 2,515.47 5,990,29189 542,347.83 24.38 251547 MWD OWSG(2) 4.659.97 89.50 122.25 3.483.03 3.395.03 -546.61 2,541.80 5,99,277.30 542,374.24 26.85 2,541.80 MWD OWSG(2) 4,689.69 90.94 129.52 3,482.92 3,394.92 564.02 2,565.87 5,990,260.02 542,398.39 24.94 2,565.87 MWD OWSG(2) 4,719.77 89.15 137.15 3.482.90 3394.90 -584.64 2.58773 5,990.239 51 542,420.36 26.05 2.58773 MWD OWSG(2) 4,74952 88.92 14531 3.483.40 3.395.40 -60781 2,606.34 5.990,216.44 542,439.09 2744 2.60634 MWD OWSG(2) 4779.70 88.35 154.10 3.484.12 3,39612 -633.84 2,621.54 5,990,190.50 542,454.44 29.18 262154 MWD OWSG(2) 4,81102 88.66 16011 3.484.94 3396.94 -%273 2,633.57 5,990,161.68 542.466.61 2112 2.633.57 MWD OWSG(2) 4.839.60 88.31 163.20 348569 3.39769 689.89 2,642.42 5,9%,134.57 542.47560 8.80 2.64242 MWD OWSG(2) 4,869.53 8757 171.64 3,486.77 3,39817 -719.% 2,64893 5,990,105.44 542.482.27 28.29 2648.93 MWD OWSG(2) 4,899.53 8721 179.48 3.488.14 3,4%.14 -74891 2,65124 5.990,075 60 542.484.74 26.13 2,65124 MM OWSG(2) 4,929.52 8664 17861 3.489.75 3,401.75 -T7886 2,651.74 5.990.045 66 542,485.40 346 2,651.74 MWD OWSG(2) 4,959.79 88.24 172.44 3.49110 3.403.10 .808.99 2.654.10 5.990,015.55 542,487.92 2104 2.654.10 MWD OWSG(2) 4,990.26 87.86 163.61 3.49214 3.40414 .838.75 2,660.41 5,989,985.82 542,494.39 28.99 2,660.41 MWD OWSG(2) 5,019.87 85.85 15545 3.49377 34%77 -866.42 2,67074 5.989.958 21 542.504.87 28.34 2,670.74 MWD OWSG(2) 5,099.37 85.52 15006 349593 3.407.99 -892.57 2,664.20 5,989,932.14 542,51847 18.25 2,6&1.20 MWD OWSG(2) 5.079.11 88.87 142,6 3,497.44 340944 -917.24 2,700.69 5,989,907.55 542,535.08 27.% 2,700.69 MWD OWSG(2) 5.109.73 8732 134.47 3498.46 3,41046 -940.13 2.720.97 5,989,884.77 542.55548 26.57 2,720.97 MWD OWSG(2) 5,13876 87.66 126.60 3,49974 3,411.74 -958.97 2.742.99 5,989,866.06 542,577:60 27.11 2,742.99 MWD OWSG(2) 5,16784 86.% 11803 3,601.34 3,413.34 -97447 2,767.50 5969,85068 542,602.19 29.95 2,767.0 MWD OWSG(2) 5,196.84 87.00 11142 3,503.11 3,415.11 -986.57 2,793.78 5,989,83872 542,628.53 23.% 2,79318 MWD OWSG(2) 5,226.64 87.40 102.67 3,504.56 3.416.56 -99529 2,822.21 5.989.830.16 542,657.% 29.36 2,822.21 MWD OWSG(2) 5,255.81 86.11 94.85 3.506.22 3.418.22 -99972 2.80.97 5,989.825.88 542,68578 2713 2,850.97 MM OWSG(2) 5,270.51 85.97 90.80 3,0723 3,419.23 -1,00045 2,865.62 5.989,82524 542,700.43 270 2,865.62 MWD OWSG(2) 5,300.80 86.15 80.45 3.509.32 3,42132 -998.14 2,895.70 5,989,82770 542,730.50 34.09 2.895.70 MWD OWSG(2) Annotation TIP KOP 8/222019 9r52:51AM Page 3 COMPASS 5000.14 Build 86H ConocoPhillips eA g ConocoPhilli s` p Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Coordinate Reference: Well IR -26 Project: Kuparuk River Unit TVD Reference: iR-26 @ 88.00usft (1R-26) Site: Kupamk 1 R Pad MD Reference: 1R-26 @ 88.00usft (IR-26) Well: 1R-26 North Reference: True Wellbore: 1R-12611 Survey Calculation Method: Minimum Curvature Design: 11R-1261-1 Database: EDT 14 Alaska Production Survey Annotation 812212019 952:51AM Page 4 COMPASS 5000 14 Build 85H Map Map Vertical MD Inc ND TVDSS .N45 -E/.W DLS (usft) (°) V (^) ) (usft) (usft) (usft) (usft) Northing Easting ('1100') Section Suney Tool Name (ft) (ft) (ft) 5.33173 87.28 7789 3,51109 3423.09 -99234 2.925.03 5,989,833.66 542760.80 903 2.926.03 MWO OWSG(2) 5,359.69 87.93 74.78 3.512.26 3,424.26 -985.74 2,953.17 5,989.84041 542,787.90 11.35 2,953.17 MWD OWSG(2) 5388.70 88,6 71.63 3.513.18 3.425.18 -977.36 2.980.93 5,989,846.93 542,815.61 11.01 2,980.93 MWD OWSG(2) 5,420.00 88.53 68.36 3.514.00 3,42600 -966.67 3,010.33 5,989,859.78 542,844.95 10.38 3.010.33 MWD OWSG(2) 5,45108 88.40 66% 3.514.83 3426.83 -964.87 3,039.07 5,989,871.73 542873.62 4.52 3,039.07 MWD OWSG(2) 5.480.68 88.59 65.71 351561 3,427.61 -943.00 3,06617 5,989,88375 542.900.66 4.34 306617 MWD OWSG(2) 5.517.09 8811 64.68 3,51647 3,42847 -927.73 3,099.21 5,989,899.19 542.933.61 2.85 3,09921 MWD OWSG(2) 5,548.69 88.89 63.18 3,517.13 3429.13 -913.84 3,127.59 5,989,913.23 542.961.91 478 3,127.59 MWD OWSG(2) 5,579.01 88.67 6161 3,51777 3,42977 -899.80 3.154.45 5.969,927 41 542,98810 5.23 3,15445 MWD OWSG(2) 5,604.00 88.64 60.31 3,518.36 3,430.36 -887.67 3,176.29 5,989,93966 543,01047 5.20 3,176.29 MWD OWSG(2) 5,630.53 88.28 6175 3,51907 3431.07 -874.82 3.199.49 5.989.95262 543,033.60 5.59 3,199.49 MWD OWSG(2) 5,658.55 88.74 62.39 3.519.80 3.43180 -86170 3,22424 5.989,%5.87 563058.28 281 3,224.24 MWD OWSG(2) 5,688.38 9064 63.14 3.519.96 3.431.96 -848.05 3,250.76 5,989,979.66 543,084.72 6.85 3,250.76 MWD OWSG(2) 5,71909 8979 63.48 3.51985 3.431.85 413426 3,278.20 5,989,993.60 543,112.08 298 3,278.20 MWD OWSG(2) 5.748.71 9027 6150 3,519.83 3,431.83 -820.58 3.304.47 5,990.00742 543,138.28 6.88 3,304.47 MWD OWSG(2) 5.77550 89.77 61.80 3,51982 3,431.82 60786 3,328.05 5,990.020.27 543.161.78 2.18 3,328.05 MWD OWSG(2) 5,810.65 9073 62.29 3,51967 3,431.67 -791.38 3,35909 5.990,036.91 543,192.74 307 3,359.09 MWD OWSG(2) 5,635.28 90.87 60.32 3,51931 3,431.31 -779.08 3,361.57 5,990,049.33 543.215.15 7.70 3,381.57 MWD OWSG(2) 5.868.53 90.82 60.11 3.518.84 3430.84 -763.06 3409.56 5,990,065 49 543,243.05 0.67 3,403.56 MWD OWSG(2) 5,895.96 90.90 5949 3,518.42 3.430.42 -749.26 3,43326 5.990,07942 543,266.68 2.28 3,433.26 MWD OWSG(2) 5,926.80 90.37 58.98 3518.08 3.43008 -73349 3,459.76 5.990095 33 543,293.09 2.38 345976 MWD OWSG(2) 5,956.15 9141 57.80 3.517.63 3.429.63 -718.11 348415 5.990 110 84 543,318.00 5.36 3,48415 MWD OWSG(2) 5990.95 90.37 5716 3,517.09 3,429.09 -69940 3,514.09 5.990.12970 543,347.23 3.51 3.514.09 MWD OWSG(2) 6.021.25 9062 54.24 3,516.82 3,42882 -682.33 3,539.12 5,990146.90 543,372.17 9.67 3539.12 MWD OWSG(2) 6,05225 90.34 5276 3,516.56 3,428.55 -663.89 3.56404 5,99016547 543,396.98 4.86 3.564.04 MWD OWSG(2) 6.10199 90.15 5671 3.516.35 3.428.35 635.18 3,60964 5,990194.40 543,43743 7.95 3604.64 MWD OWSG(2) 6,134.19 89.02 53.62 3.516.58 3.428.58 -61679 3,631.07 5990.212.93 543,463.75 1022 3,631.07 MWD OWSG(2) 6,17948 8745 46.30 3.517.98 3,429.98 -587,69 3.66570 5.99024221 543,498.23 16.52 3.665.70 MWD OWSG(2) 6.203.37 85.37 44.79 3.519.18 3,43148 -570.99 3,88272 5,990,258.99 543.515.16 10.75 3.682.72 MWD OWSG(2) 6232.77 82.39 4370 3.52261 3434.61 550.05 3,703.11 5990280.04 543,535,4 10.79 370311 MWD OWSG(2) 6260.67 7965 42.86 3.52697 3438.97 -52999 3,722.00 5990.300.20 543554.22 10.26 3.722.00 MWD OWSG(2) Annotation 812212019 952:51AM Page 4 COMPASS 5000 14 Build 85H ConocoPhillips ConocoPhillips Definitive Survey Report Azi BAKER N« Company: ConowPhillips Alaska Inc_Kuparuk Local Coordinate Reference: Well iR-26 Map Project: Kuparuk River Unit TVD Reference: 1R-26 @ 88.00usft (1 R-26) Site: Kupaiuk lR Pad MD Reference: 1R-26 @ 88.00usft (1R-26) (usft) Well: 113-26 North Reference: True Northing Wellbore: IR -12611 Survey Calculation Method: Minimum Curvature Survey Tool Name Annotation Design: IR -126L7 Database: EDT 14 Alaska Production Survey MD Inc Azi TVD TVDSS *NI -S •E/ -W Map Map DLS Vertical (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Eastng Section Survey Tool Name Annotation (RI IRI (°DILS (ftl 6,290.91 7627 4215 3,533.27 344527 -508.19 3,14148 5,990 322 10 543.9608 11.41 3,741.98 MM OWSG (2) 6,318.63 72.90 40.84 3.54064 3.45264 488.18 3,759.69 5.99,342.20 543,591.68 12.98 3.759.69 MWD OWSG (2) 6.349.79 6939 3963 3.550.71 3.46271 46568 3.77873 5.990.364.81 543,610.60 1185 3,778.73 MWD OWSG (2) 6,37949 65.47 42.49 3552.11 3,474.11 445.00 3,796.74 5,990,385.58 543,628.49 15.91 3,796.74 MWD OWSG (2) 6,410.01 6544 40.43 3.574.79 3,486.79 424.20 3815.12 5,990,406.48 543,64636 614 3,81512 MWD OWSG (2) 6.437.32 65.60 41.34 3,585.89 3,497.89 -405.33 3.83145 5,990,425.43 543.662.99 5.23 383145 MWD OWSG (2) 646561 6280 37.90 3,596.85 3,508.85 -385.25 3.848.07 5,990,44560 543,679.50 11.98 3.848.07 MWD OWSG (2) - 6,504.87 6766 34.91 3.611% 3,52366 -355.99 3,869.65 5,990,474.97 543700.92 7.06 3,869.65 MWD OWSG (2) 6,537.42 6737 34.39 3,62395 3.535.95 -331.19 3886.79 599,499.86 543,717.92 152 3,88639 MWD OWSG (2) 6,565.23 68.37 32.45 3,634.34 3.546.34 -309.66 3,900.99 5,990,52146 543,732.01 6.82 3,900.99 MWD OWSG (2) 6,59545 68.33 3283 3.645.49 3.55749 -286.01 3.916.14 5.99,545.19 543,74704 118 3.91614 MWD OWSG (2) 6,625.88 68.90 32.56 3.656.58 3.568.58 -26216 3,931.45 5990.569.12 543,762.21 205 3,931.45 MWD OWSG(2) 6,65399 70.11 31.65 3666.42 3.578.42 -239.85 3,945.44 5,990,591.49 543.776.09 5.27 3.945.44 MWD OWSG(2) 6,685.21 70.32 2752 3,677.00 3,589.00 -214.32 3,959.94 5,990,617.11 543,790.45 12.47 3.959.94 MWD OWSG (2) 6,714.59 7203. 3080 3,686.48 3,598.48 -189.94 3.973.32 5.990 641,55 543.803.70 9.88 3.973.32 MWD OWSG (2) 6743.36 72.24 28.08 3,695.30 3,60730 -166.00 3,986.61 5,990,665.55 543.816.86 639 3.98661 MWD OWSG (2) 6,772.16 7203. 2669 3,70414 3,61614 -14169 3,99926 5.990,68994 543,829.38 4.00 3,99926 MWD OWSG (2) 6,801.89 7267 27.09 3,713.15 3.625.15 -116.44 4,012.12 5,990,715:25 543,842.10 2.25 4.012.12 MWD OWSG (2) 6,832.23 72.56 2660 3,722.22 3.634.22 -90.61 4.025.20 5,990,741.15 543,855.04 1.58 4,025.20 MWD OWSG (2) 6,862.91 7208. 25.15 333154 3643.54 -64.31 4,037.95 5,990,76751 543,867.65 4.77 4,037.95 MWD OWSG(2) 6,89149 72.10 2514 3,740.33 3,652.33 -39.69 4,049.51 5,990,792.19 543.879.07 0.08 4.049.51 MWD OWSG (2) 6,91114 72.33 25.37 3,74633 3,658.33 -2277 4,057.49 5,990,809.15 543.886.97 1.62 4,057A9 MWD OWSG (2) 6,940.79 7189 22.88 3,755.44 3,667,44 2.98 4,069.02 5,9110 834 96 543.898.36 8.13 4,06902 MWD OWSG (2) 6,97093 71.94 22.72 3,76439 3.676.79 29.39 4,080.13 5.990,851.43 543.909.32 0.53 4,080.13 MWD OWSG (2) 7,001.36 73.87 25.31 3,773.74 3,685.74 55.96 4,091.96 5,99,88805 543,921.02 1032 4,091.96 MWD OWSG (2) 7,030.06 72.83 21.70 3,781.96 3.693.96 81.16 4,102.93 5,990,913.31 543,931.85 1258 4,102.93 MWD OWSG (2) 7,055.31 72.96 23.80 3.789.39 3,701.39 103.42 4112.26 5.990.93562 543,94106 7.97 4,11226 MWD OWSG (2) 7082.12 73.26 23.22 3.79718 3303.18 126.94 4.122.50 5,990,959.19 543,951.17 2.35 4,122.50 MWD OWSG (2) 7,113.97 7346 21.82 3806.30 3.718.30 155.13 4.134.18 5990.98744 543,962.70 4.26 4.13418 MWD OWSG (2) 7,148.29 7353 2176 3.816.05 3.728.05 18569 4,14640 5,991,018.06 543,97475 026 4.14640 MWD OWSG (2) 7 170 18 72 84 2230 362239 3.734.39 20511 4.154 26 5991 037 52 543.982 51 3.94 4.154 26 MWD OWSG (2) 8/22/2079 9:5251AM Page 5 COMPASS 5000.14 Build 85H Annotation 6A En Q Iuc"E�s 8/222019 9.52:51AM Page 6 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Coordinate Reference: Well 1R-26 Project: Kuparuk River Unit TVD Reference: 1R-26@88.00usft(1 R-26) Site: Kuparuk 1 R Pad MD Reference: 1R-26 @ 88.00usft (1 R-26) Well: 1R-26 North Reference: True Wellbore: 1R-126L1 Survey Calculation Method: Minimum Curvature Design: 1R-126L7 Database: EDT 14 Alaska Production Survey MD Inc TVD TVDSS iN/-S +E/-W Map Map DLS Vertical (usft) (°) (°) (1) (usft) (usft) (usft) Northing (usft) Easting Section Survey Tool Name (ft) (ft) (ft) ].202.14 ]2.06 2].57 383202 3]44.02 232.73 4.16]10 5,991,06521 54399520 15.90 4,16710 MWD OWSG(2) 7.24413 68.% 22.94 3,846.22 3,758.22 269.03 4.184.24 5.991,101 59 544,012.14 12.56 4,18424 MWD OWSG(2) 7,274.36 67.37 21.69 3.857.23 3.769.23 294.47 4.194.68 5.991,127.09 544,02245 673 4,19468 MWD OWSG(2) 7,309.99 66.23 21.04 3.871.27 3783.27 324.97 4,20661 5,991,15]64 544,034.22 3.61 4.206 61 MWD OWSG(2) 7,344.90 66.41 1816 3,885.29 3.797.29 355.08 4217.34 5,991,187.81 54,044.78 7.57 4.217.34 MWD OWSG(2) 7,37500 6641 18.16 3,897.34 3,809.34 38129 4,22593 5,991,214.07 544.05324 0.00 4,225.93 PROJECTED WTD Annotation 6A En Q Iuc"E�s 8/222019 9.52:51AM Page 6 COMPASS 5000.14 Build 85H THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Re: Kuparuk River Field, West Sak Oil Pool, KRU 1R-126 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-094 Surface Location: 394' FNL, 137' FWL, SEC. 20, T12N, RIDE, UM Bottomhole Location: 2697' FNL, 1904' FWL, SEC. 29, T12N, R10E, UM Dear Mr. Ohlinger: Enclosed is the approved application for the permit to redrill the above referenced service well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner rd DATED this day of July, 2019. STATE OF ALASKA Ar AKA OIL AND GAS CONSERVATION COMfb. .TION PERMIT TO DRILL T�hfJ 20 AAC 25.005 L WD JUN 2 ? 2013 1a. Type of Work. ( 1 b. Proposed Well Class: Exploratory - Gas L1 Service - WAG El Service - Disp ❑ to. Specify if well is proposed for: Drill Lateral Stratigraphic Test El Development - Oil El Service - Winj ❑� Single Zone 2 Coalbed Gas El Gas Hydrates El ,❑-/ Reddll L�8 Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑� Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 5952180 KRU 1R-126 3. Address: 6. Proposed Depth: -t v0" SW 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 12,000' /\ TVD: 55 3395'55,S9eca� Kuparuk River Field / Y�8 West Salk Oil Pool 4a. Location of Well (Governmental Section): Surface: 394' FNL, 137' FWL, Sec 20, T12N, RI OE, UM 7. Property Designation 6353 ADL ZS(> ADL 26636 RNf-2660 - Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 1147' FNL, 2763' FWL, Sec 20, T12N, R10E, UM LONS 83-134 7/15/2019 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2697' FNL, 1904' FWL, Sec 29, T12N, R10E, UM 2560 14,887' ' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ll): 88' 15. Distance to Nearest Well Open Surface: x- 539830 y- 5990810 Zone- 4 GL / BF Elevation above MSL (ft): 45' to Same Pool: 110', 1 R-29 16. Deviated wells: Kickoff depth: 4460' - feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: 1440 . Surface: 1098 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 4-114" 3-1/2" 9.2# L-80 R-2 439' 4450' 3408' 4889' 3488' Solid Liner 4-1/4" 2-7/8" 6.5# L-80 R-2 7111' 4889' 3488' 12,000' 3395' Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (R): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 10218' 6976' 4320' 10201' 6965' 9241' Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 231 sx AS 1 123' 123' Surface 5551' 9-5/8" 1170 sx PF E, 530 sx Class 'G' 5593' 4081' Production 10,166' 7" 250 sx Class 'G' 10201' 6965' Perforation Depth MD (ft): 4320'4480', 9639'-9672', 9887'-9902', Perforation Depth TVD (ft): 3327'-3427', 65821-66041, 67501-6760', 6770'-6787' 9916'-9941' Hydraulic Fracture planned? Yes El No ❑1 20. Attachments: Property Plat ❑ BOP SketchDrilling Diverter Sketch Program ® Seabed Report Time v. Depth Plot ® Drilling Fluid Program Shallow Hazard Analysis B 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Ryan McLaugten Authorized Name: James Ohlinger Contact Email: an.mClaU hlln CO .com Authorized Title: Staff CTD Engineer Contact Phone: 907-265-6218 / Authorized Signature: Date: (O/"'/9 Commission Use Only Permit to Drill API Number:Permit Approv I See cover letter for other Number: �' — Q 50- — d _ Op Date: I 1 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: f� �/. o p S mples req'd: Yes ❑ NoEe Mud Io q ❑ [� [�0P /CO��- ✓- ,j�0 /J S—r 5 sUp mar 9 re 'd: Yes No ffnn v 1'a r /P t-,- V-er' j tr h'S t Z i/' HZS measures: Yes ❑ No&' Directional svy req'd: Yes YNoE] Ve�f ianee�r4.�T�d lo2o4✓r02�F%030ey),eIrleptionreq'd: Yes El No L7 Inclination -only svyreq'd:Yes ❑ NoFq W/ thr 9 Gvr c/x ty m C/°/i / sl lvg j /J ro ✓rG/C /s S d o f bvC)(5 Post initial injection MIT req'd: Yes E�'No❑ W/'ltrG 7`htr� /3 no�j—Do 'o�Ctvs�rr�t[i).7o%� t/-tc fi/$o �or4Wt{/S w� 1VlSfSR/Ccs/'ndou /rsh ,y.rnz�h4���4/ f�try%/�y �a .hal a1�5 se si-oe s<t avor� DiP �prr55�r1, the ls/ 3r b prareol�c/ whrn r-ZvrSr� WS�e�ll n� b /to! PG a c/ t� r UfF /�r✓s5 vrs �/rrrLanJ i APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ✓ / Forpr,ipg01N(�sed�5/2b17r� �T�3�! it Is valid for 24 months fir©t e� ty6Ua`pip�l r �0 AAC 25.005(8) q� nts in Duplicate � ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 24, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill two laterals out of the KRU 1 R-26 (PTD# 191-092) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin on July 15th, 2019. The objective will be to drill two laterals — 1 R- 1261-1 will be a pilot hole drilled to the northeast across the West Sak sands to de -risk future rotary projects and 1 R-126 will target the West Salk B -sand. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to this application are the following documents: - Permit to Drill Application Forms (10401) for 1R-126 & 1R-1261_1 - Detailed Summary of Operations - Directional Plans for 1 R-126 & 1 R-1261-1 - Current wellbore schematic - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-265-6218. Sincerely, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Lateral 1 R-126 & 1 R -1 26L1 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)(8))..................................................................................................................................................3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(8))..................................................................................................................................................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.......................................................................................... 5 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................... I............................ 5 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 6 16. Attachments....................................................................................................................................7 Attachment 1: Directional Plans for 1 R-126, 1 R-1261-1...................................................................................................9 Attachment 2: Current Well Schematic for 1 R-126, 1 R-12611........................................................................................9 Attachment 3: Proposed Well Schematic for 1R-126, 1R -126L1 .....................................................................................9 Page 1 of 9 March 5, 2019 PTIJ Application: 1 R-126, 1 R-1261-1 Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1R-126 & 1R-1261-1. The laterals will be classified as "Service - Winj" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the B sand package in the West Sak reservoir. See attached 10-401 form for surface and subsurface coordinates of 1 R-126 & 1 R-1261-1. 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. The nearest MDT in the West Sak formation was recorded to be 0.45 psi/ft in 2006. The maximum potential surface pressure in 1R-126, assuming a gas gradient of 0.1 psi/ft, would be 1098 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. g . (l� 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) 331 Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The nearest formation pressure gradient measurement in the West Sak was 0.45 psi/ft with an MDT in 2006. ✓ Based on this pressure gradient, the downhole pressure at the window is estimated to be 1440 psi.' Reservoir pressure is not anticipated to have changed since no production or injection has occurred in the West Sak formation in the vicinity of this project Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) J Free gas is not anticipated while drilling the 1 R-126 & 1 R -126L1 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 R-126 and 1 R -126L1 laterals will be lost circulation and differential sticking. Reduced mud rheology will be used to minimize ECDs and attempt to prevent lost circulation and differential sticking. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1 R-126 & 1 R-1261-1 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 9 June 24, 2019 PTU Application: 1 R-126, 1 R-1261-1 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 Surface 2-7/8", 6.5#, L-80, ST -L slotted liner, 1R-126 4450' 12,000' 3320' 5610' 3-1/2", 9.2#, L-80, ST -L solid liner in 36.0 J-55 BTC Surface 5593' the build; Shorty deployment sleeve 4072' 3520 2020 Production 7" on to 1R -126L1 N/A N/A N/A N/A Pilot hole — will be unlined with an 4980 4320 Tubing 4-1/2" 12.6 anchored billet set at 4850' MD Existing Casing/Liner Information Category OD Weight f Grade Connection Top MD Btm MD Top TVD Btm TVD Burs t psi Collapse psi Conductor 16" 62.5 H-40 Welded Surface 123' Surface 123' 1640 670 Surface 9-5/8" 36.0 J-55 BTC Surface 5593' Surface 4072' 3520 2020 Production 7" 26.0 J-55 BTC -MOD Surface 10,201' Surface 6951' 4980 4320 Tubing 4-1/2" 12.6 L-80 HYD 503 Surface 4252" Surface 3285' 8430 7500 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 (8.4 ppg) — Drilling operations: Chloride -based PowerVis mud (8.4 ppg). This mud weight may not hydrostatically overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with NaCl completion fluid in order to provide formation over -balance while running completions. If pressures higher than anticipated are encountered NaBr completion fluids may also be used. 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 R-126 & 1 R-1261_1 laterals we will target a constant BHP to match formation pressure. 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 9 June 24, 2019 PTD Application: 1R-126, 1R-1261-1 Pressure at the 1R-126 Window (4460' MD, 3414' TVD) Usina MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations & t -' Background KRU well 1 R-26 was recently worked over and is now equipped with 4-1/2" tubing and 7" production casing. The CTD sidetrack will utilize one lateral to target the West Sak B -sand to the south of 1 R-26 and an unlined pilot lateral to the northeast that will de -risk future rotary projects in the area. An inner wedge will be set pre -CTD inside the tandem wedge installed during the workover in the 4-1/2" tubing at a planned kickoff point of 4460' MD CDR3-AC will use the whipstock to mill a window in the 4-1/2", 7", and 9-5/8" casing strings. The 1R-1261-1 lateral will be drilled first to the northeast to a TD of 7319' MD. An anchored billet will be set at a depth of 4850' MD to kick off from and drill the 1 R-126 lateral to a depth of 12,000' MD. The 1 R-126 lateral will be completed with 2-7/8" slotted liner from TD up the end of the build and 3-1/2" solid liner from the end of the build to inside the parent wellbore. Pre -CTD Work 1. RU E -Line: Drift, set inner wedge at 4460' MD 2. Prep site for Nabors CDR3-AC rig. Page 4 of 9 June 24, 2019 Pumps On 3 bpm) Pumps Off B -sand Formation Pressure 8.65 1536 psi 1536 psi Mud Hydrostatic 8.4 1491 psi 1491 psi Annular friction i.e. ECD, 0.035psi/ft) 156 psi 0 psi Mud + ECD Combined no chokepressure) 1647 psi Overbalanced -111psi) 1491 psi Underbalanced -45psi) Target BHP at Window 8.65 1536 psi 1536psi' Choke Pressure Required to Maintain Target BHP 0 psi 45 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 & t -' Background KRU well 1 R-26 was recently worked over and is now equipped with 4-1/2" tubing and 7" production casing. The CTD sidetrack will utilize one lateral to target the West Sak B -sand to the south of 1 R-26 and an unlined pilot lateral to the northeast that will de -risk future rotary projects in the area. An inner wedge will be set pre -CTD inside the tandem wedge installed during the workover in the 4-1/2" tubing at a planned kickoff point of 4460' MD CDR3-AC will use the whipstock to mill a window in the 4-1/2", 7", and 9-5/8" casing strings. The 1R-1261-1 lateral will be drilled first to the northeast to a TD of 7319' MD. An anchored billet will be set at a depth of 4850' MD to kick off from and drill the 1 R-126 lateral to a depth of 12,000' MD. The 1 R-126 lateral will be completed with 2-7/8" slotted liner from TD up the end of the build and 3-1/2" solid liner from the end of the build to inside the parent wellbore. Pre -CTD Work 1. RU E -Line: Drift, set inner wedge at 4460' MD 2. Prep site for Nabors CDR3-AC rig. Page 4 of 9 June 24, 2019 PTD Application: 1 R-126, 1 R-1261_1 Rig Work 1. MIRU Nabors CDR3-AC rig using 2-5/8" coil tubing. NU 7-1/16" BOPS, test. 2. 1R -126L1 Lateral (West Sak pilot hole - northeast) a. Mill 3.80" window at 4460' MD b. Drill 4-1/4" bi-center lateral to TD of 7319' MD. c. Set anchored aluminum billet at 4850' MD 3. 1R-126 Lateral (West Sak B -sand -south) a. Kickoff of the aluminum billet at 4850' MD. b. Drill 4-1/4" bi-center lateral to TD of 12,000' MD. c. Run 2-7/8" slotted liner and 3-1/2" solid liner with deployment sleeve from TD up to 4450' MD. 4. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 5. Return well to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the swab valve on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using the swab valve on the Christmas tree, deployment ram on the BOP, check valve and ball valve in the BHA, and a slick -line lubricator. This pressure control equipment listed ensures reservoir pressure is contained during the deployment process. During BHA deployment, the following steps are observed. - Initially the swab valve on the tree is 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 valve. The swab valve is opened and the BHA is lowered in place via slick -line. - When the BHA is spaced out properly, the deployment ram is closed on the BHA to isolate reservoir pressure via the annulus. A closed ball valve and check valve isolate reservoir pressure internal to the BHA. Slips on the deployment ram prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment ram. - The coiled tubing is made up to the BHA with the ball valve in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the ball valve is opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment ram is opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running - The 1 R-126 & 1 R -1 26L1 laterals will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids" section for more details. - While running liner, a joint of 2-5/8" 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 2-5/8" rams will provide secondary well control while running 2-3/8" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. Page 5 of 9 June 24, 2019 PTD Application: 1 R-126, 1 R -1 26L1 • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1 B disposal facilities) or Prudhoe DS4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (6704200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 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 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 DZ70O' 1 R-126 1 R -126L1 Distance to Nearest Well within Pool Lateral Name Distance Well 1 R-126 110' 1 R-29 1R -126L1 122' 1R-27 Page 6 of 9 June 24, 2019 PTD Application: 1R-126, 1R -126L1 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) Page 7 of 9 June 24, 2019 Surface Surface D- Top of D- Surface Surface Well Well Wellil sing Set Casing Set PTD API rp�,d Sand Oil Casing Set Casing Set Name Classification StatusAcross Across West Pool (TVD)_ Depth (MD)_ Depth (TVD) DI aD(__ Ugnu?jam Sak? 1G -07A III 218-051 50-029-20872.01 Producer producing 3,950 3,395 2,487 2,367 FALSE FALSE 1R -01B 200-156 50-029.21404-02 Producer LTSI 3,684 3,383 4,381 3,868 TRUE TRUE 1R-02 SII 185-176 50-029.21405.00 Producer producing 4,114 3,390 4,814 3,885 TRUE TRUE 1R-25 191-047 50-029-22153-00 Producer producing 4,512 3,450 5,571 4,122 TRUE TRUE 119-26 191-092 50.029-22193-00 Injector Suspended 4,426 3,399 5,593 4,081 TRUE TRUE 1R-27 _ 191-102 50-029-22201-00 Producer LTSI 5,240 3,528 6,547 4,192 TRUE TRUE 1R-29 191-094 50-029-22195-00 Producer producing 4,857 3,414 6,042 4,119 TRUE TRUE Page 7 of 9 June 24, 2019 PTD Application: 1R-126, 1R -126L1 Page 8 of 9 June 24, 2019 Within Within Wei Surface Casing Cement Arctic Pack 1/4 1/4 Mile Mechanical Integrity Name Operations Summary Cement Ops Mile of of t iR-1; -. Ir 1R -126L1 18-314-:1300 sx (445 bbl) of AS -III OA_ 41 bbl cmt . ??? NORMAL WELL 12.2 ppg lead . 250 sx (41 bbl) of 15.7 Bbl diesel,116183. 41 MIT -IA to 2500 psi passed 10113116 1G -07A ppg PF -C tail. Cement to surface, bbl = 844' in csg MIT -OA to 1800 psi passed 3111118 TRUE no reciprocation. FIT = 12.4 ppg annuli. EMW 406 psi w19.1 ppg mud). 9-518":1250 sx (439 bbl) of PF -E OA: 33 bbl cmt, 55 NORMAL WELL 12.3 ppg lead • 400 sx (68 bbl) of 15.6 bbl diesel, 915185. 33 TIFL passed 719113 1R-018 ppg PF -C tail. Full returns entire bbl = 1110' in csg CMIT-IA to 1950 psi passed 5117108 TRUE TRUE job, circ 279 sx [98 bbl) cement to annuli, 55 bbl = 1851'. MIT -OA to 1800 psi passed 10121118 surface. No reciprocation. FIT = 9-518':1470 sx (515 bbl) of PF -E OA: 42 bbl cmt, 55.5 NORMAL WELL 12.3 ppg lead . 410 sx (69 bbl) of 15.6 bbl diesel, 9116185. 33 MIT -OA to 1600 psi passed 11119109 1R-02 ppg PF -C tail. Good returns entire bbl = 1414' in csg TIFL passed 1112115 TRUE TRUE job, circ 145 bbl cement to surface. annuli, 55.5 bbl = FIT = 12.5 ppg EMW. 1868'. 9-518':1050 sx (369 bbl) of PF -E OA: 50 bbl cmt, 60 NORMAL WELL 12.3 ppg lead . 630 sx (132 bbl) of bbl diesel, 121201915. TIFL passed 3131116 1R-25 15.6 ppg G tail. Full returns, recip 50 bbl = 1683' in csg MIT -T to 2500 psi passed 913107 TRUE TRUE casing, cement to surface. FIT = annuli, 60 bbl = 2019' MIT -IA to 2500 psi passed 8126107 11.5 ppq EMW. MIT -OA to 1800 Psi Dassed 715109 9-518":1170 sx (410 bbl) of PF -E OA: 42 bbl cmt, 58 NORMAL WELL 12.3 ppg lead • 530 sx (108 bbl) of G bbl diesel, 9123191. 42 MIT -IA to 3000 psi on 3-27-14 1R-26 15.8 ppg tail. Full returns entire job, bbl = 1414' in csg MIT -OA to 1800 psi passed 10122118 TRUE TRUE circ 23 sx (8 bbl) cement to surface. annuli, 58 bbl = 1952'. FIT =12.5 ppg EMW. 9-518':1390 sx (488 bbl) of PF -E OA: 42 bbl cmt, 63 NORMAL WELL 12.1 ppg lead . 570 sx (117 bbl) of 15.8 bbl diesel, 1014191. 42 TIFL passed 12129110 IR -27 ppg G tail. Full returns but no bbl = 1414' in csg MIT -T to 2500 psi passed 5129116 TRUE TRUE cement to surface. Top job with 173 annuli, 63 bbl = 2120'. MIT -IA to 2500 psi on 11117112 sx f29 bbl of 15.6 ppg PF -C. FIT = MIT -OA to 1800 psi passed 10110112 9-518-:1320 sx (463 bbl) of PF -E OA: 33.8 bbl cmt, 65 NORMAL WELL 12.1 ppg lead . 560 sx (115 bbl) of 15.8 bbl diesel, 12116191. TIFL passed 4114118 1R-29 ppg G tail. Full returns whil recip 33.8 bbl = 1138' in csg MIT -T to 2500 psi passed 5129116 TRUE TRUE casing, "100 bbl cement to surface. annuli, 65 bbl = 2188'. MIT -IA to 2500 psi on 11117112 FIT = 12.5 ppg EMW. MIT -OA to 1800 psi passed 10110112 Page 8 of 9 June 24, 2019 PTD application: 1R-126, 1R -126L1 17. Attachments Attachment 1: Directional Plans for the 1R-126 & 1R-126LI laterals Attachment 2: Current Well Schematic for 1R-26 Attachment 3: Proposed CTD Well Schematic for the 1R-126 & 1R -126L1 laterals Page 9 of 9 June 24, 2019 Well KRU XX -XX Nabors CDR3-AC: 4 -Ram BOP Configuration Date June 26, 2019 2-518" Coiled Tubing and 3-118" BHA Quick Test Sub to Ot Top of 7" Otis Distances from top o Excluding quick -test Top of Annular Cc Annular Bottom Annular Flan. Ci Blind/Shears Ci 2-5/8" Combi's CL 3-1/8" Combi's Ci VBR's CL of Top S Top of Swat CL Swab 1 Flow Tee CL SSV CL Master LDS Ground I Tree Size 4 1/16 lie 16" Conducts 650 H40 shoe @ 12T MO CTD KOP 4460' MD, 3331 SSTVD, 51 -deg inc 9-5/e"Sudece 36# J-55 shoe at 5593' Top of T' cement `879 via CRL Ofe-27-91 PERFS 'p gged) C -sand 39'-9672' MD -sand 9867'-9902' MD -sand 9916'-9941' MD 7" Production 26# J-55 shoe @ 10,201' MD 1R-126 Proposed CTD Schematic ConocoPhillips Pro(ed: Kuparuk Rlver Unk 2 Site: Kuparuk 1R Pad M, o,�„n<xmn,. IA9' WELLBORE DETAILS: iR-1261.1 CTD Pi REFERENCE INFORMAL � WMEI Relem�re: Will IR -M. T. Nmn Well: 1R-26 sail Parent Wellbore: 1R-26 veNea lTNul Rel..]ro'. IR-N@MWmlllR-ibl Wellbore: iR-1261.1 CTD PIIoMole s,eseu,. a>AnBe.mar The on MD: 4400.00 Seam NS)Retrerrn Sbl-(O.DDN.00DE) Plan: 1R-1261.7 wp01 (iR-26/iR-1261.1 CTD Plidhde) P6) Measu likael� 1 �: 1N6... Mmweceeei cu.u.I1R BA UGHES a GE.ei, y IR-INIR-le IR-ILIR-12 I11-21/IR-JI IR-IRIIR-IR M-.W/IR-H IR-19/IR-19A IR-UNIR-2U IR -14/12-11 lk-32/12-22A IR-1)/IR-19 `. IRAVIR-ti'. IR-32/IR-31 i, IR-JJ/IR .3 IR -2 V IR -22 ''.IRsPlx.gf �;' 1RasnR.3s d RdNIR- IR-13/IN-13/ 112-I]/IR-I] 3Q 1 350D T -r 3000 1100 mIN-II l 500 -$00� IRa)i L- IR-iivllb Jl31 - 3 0 = � 1500 IKIIRi:`AI' ¢ n N4 M1J'a - -2000 - �» - 1 M4.IRCfin1' t-2500 _ / u t- F ]. ?: 114-211 1 1 z0 )Ai '.I IR " 'I1t 1 1 + 3000 l l-i'YIIR '- 111 DDI/III-1111 -3500 -f � t � I� � I�il II IUl/IH-IiN l.d r 1 rn 4000 r� ` A c r., -" III/II1-10113 --. _ i u1/ RL] _-_1N�A.rIR�^ I i '. 11/1l1n11-mIL3 4500 — UFSOI/IH-IOI1.1 -5500-� - -- _ <k -ua,i L� . - IV4u]/IH.D]Arn3 RI 9R.laS.I�li 1. - n<-i�l lilnnl RI-0]/D1L2 tDOD 'p 1a�m. I�.,4 n11 - 1 f �_ IN)S1N1111.116 -]12001 _ v 7500LI +uwi 8000 r -4500 -0000-3500-30W 2500-2000 •1500-1000 SD0 0 509 IODD 1$00 3000 250Q 1000 3500 4000 4,OO 5000 X100 G000 6 00 7000 7300 8000 8 10 9000 9500 IOOOO 1050011000 4150012000 West(-)/Eas[(+) (500 Usft/in) 1R-26 X88,001(1 R-26) ( I�/I( I�nl_ ,A %/41� 1MXpI.' sIR-IW IRLI/IR-lel In J� (-n 11. 1'ItiD 111111 -PAL'_ I11-114lil 1nAI IRNI 1111-1 1114li1IJI4l7Afn IllI ConocoPhillips ConocoPhillips Anticollision Report B FUGUES a GFcompeny Company: ConocoPhillips Alaska lnc_Kupawk Project: Kupamk River Unit -2 Reference Site: Kuparuk 1 R Pad Site Error: 0.00 usft Reference Well: 1R-26 Well Error: 0.00 usft Reference Wellbore 1R-126 Reference Design: 1 R-126 wp02 (Draft A) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1R-26 1 R-26 @ 88.00usft (1 R-26) 1 R-26 @ 88.00usft (1 R-26) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Reference 1R-126 wp02(Draft A) 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 1,372.80 usft Error Surface: Combined Pedal Curve Warning Levels Evaluated at: 2.79 Sigma Casing Method: Added to Error Values Survey Tool Program Date 6/11/2019 From To Reference Offset (usft) (usft) Survey (Wellbore) Tool Name Description 50.00 4,450.00 1R-26-GYD-CT-CMS(1 R-26) GYD-CT-CMS Gyrodata cont.casing m/s Separation 4,450.00 4,889.41 1R-1261-1 wp02(Draft C)(1 R-12611) MWD OWSG OWSG MWD - Standard Centres 4,889.41 11,771.24 1R-126 wp02(Draft A)(1 R-126) MWD OWSG OWSG MWD- Standard lush) Summary Reference Offset Distance Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Offset Well - Wellbore - Design lush) fusftl (usft) Wahl Kuparuk 1 R Pad 1 R-01 - 1R-01 - 1R-01 43.20 36.80 239.81 239.02 302.765 CC 1R-01 - IR -01 - 1 R-01 602.56 600.00 242.01 234.77 33.437 ES 1R -01 -1R -01-1R-01 4,469.49 5,000.00 1,083.08 1,028.35 19.790 SF IR -01 - 1 R-01 A- 1 R-01 A 43.20 36.80 239.81 239.02 302.765 CC 1 R-01 - I R-01 A- 1R -01A 602.56 600.00 242.01 234.77 33,437 ES 1R -01 -1R -01A -1R -01A 4,469.49 5,000.00 1,083.08 1,028.46 19.829 SF 1 R-01 -1 R-01 B- 1 R-01 B 43.20 36.80 239.81 239.02 302.765 CC 1R-01 - 1 R-018 - 1 R-01 B 602.56 600.00 242.01 234.77 33.437 ES 1R -01 -1R -01B -1R -01B 4,469.49 5,000.00 1,083.08 1,028.46 19.829 SF 1 R-01 -1 R-01 BL1 - 1 R-0181-7 43.20 36.80 239.81 239.02 302.765 CC 1R -01-1R-01 BLI-1R-01 BL1 602.56 600.00 242.01 234.77 33.437 ES 1R -01-1R-01 BL7-1R-01 BL1 4,469.49 5,000.00 1,083.08 1,028.46 19.829 SF 1R -01-1R-01 BL7-01-1R-01 BL1-01 43.20 36.80 239.81 239.02 302.765 CC 1R -01-1R-01 BL1-01-1R-01 BL1-01 602.56 600.00 242.01 234.77 33.437 ES 1R -01-1R-01 BL1-01-1R-01 BL1-01 4,469.49 5,000.00 1,083.08 1,028.46 19.829 SF 1R -01-1R-01 BL1-01 P81 -1R-01 BL1-01 PB1 43.20 36.80 239.81 239.02 302.765 CC 1R -01-1R-01 BL1-01 P81 -IR -01811-01 PB1 602.56 600.00 242.01 234.77 33.437 ES 1R -01 -IR -01 BL1-01 PBI -1R-01 BL1-01 PB1 4,469.49 5,000.00 1,083.08 1,028.46 19.829 SF 1R -01-1R-01 BL1 Pet -1R-01 BL7 PB1 43.20 36.80 239.81 239.02 302.765 CC 1R -01-1R-01 BL7 Pet -1R-01 BL7 PBI 602.56 600.00 242.01 234.77 33.437 ES 1R -01-1R-01 BL7 PBI -1R-0181-1 PB1 4,469.49 5,000.00 1,083.08 1,028.46 19.829 SF IR -01 - 1 R-101 - 1 R-101_wp02 43.20 36.80 239.81 239.02 302.765 CC IR -01 - 1R-101 - 1 R-101_wp02 602.56 600.00 242.01 235.07 34.894 ES 1R-01-1R-101-lR-101_wp02 11,701.73 11,500.00 943.10 541.75 2.350 Caution Monitor Closely, SF 1R -02 -1R -02-1R-02 1,980.70 2,000.00 143.87 130.57 10.818 CC, ES 1 R-02 - 1 R-02 - 1 R-02 3,330.40 3,400.00 267.25 241.92 10.552 SF 1 R-03 - 1 R-03 - 1 R-03 87.37 82.00 120.15 119.75 299.958 CC 1 R-03 - 1 R-03 - 1 R-03 604.15 600.00 121.90 115.25 18.315 ES 1 R-03 - 1 R-03 - 1 R-03 985.68 1,000.00 145.37 133.78 12.548 SF 1 R-03 -1 R -03A- 1 R -03A 87.37 82.00 120.15 119.75 299.958 CC 1 R-03 -1 R -03A- 1 R -03A 604.15 600.00 121.90 115.25 18.315 ES 1R -03 -1R -03A -1R -03A 985.68 1,000.00 145.37 133.78 12.548 SF 1R-03-1R-03APB1-IR-03APB1 87.37 82.00 120.15 119.75 299.958 CC 1R-03-1R-03APB1-IR-03APB1 604.15 600.00 121.90 115.25 18.315 ES CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 6/112019 2:52: 16PM Page 2 COMPASS 5000.14 Build 85D Summary Kuparuk 1 Pad- ConocoPhillips BA_ ICER ConocoPhillips Antirollision Report Offset Distance UGHES Measured aGEcompany Company: ConocoPhillips Alaska lnc_Kupawk Local Coordinate Reference: Well 1R-26 Site Name Project: Kuparuk River Unit_2 TVD Reference: 1 R-26 @ 88.00usft (1R-26) Factor Reference Site: Kuparuk 1R Pad MD Reference: 1 R-26 Q 88.00usft (1R-26) (usft) Site Error: 0.00 usft North Reference: True Measured Reference Well: 1R-26 Survey Calculation Method: Minimum Curvature Offset Wellbore Well Error: 0.00 usft Output errors are at 2.00 sigma 133.78 Reference Wellbore 1 R-126 Database: EDT 14 Alaska Production 82.00 Reference Design: 1R-126 wp02 (Draft A) Offset TVD Reference: Offset Datum 1R -04 -1R -04-1R-04 Summary Kuparuk 1 Pad- 1R -01 -1R -01-1R-01 Reference Offset Distance -GCT -MS Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Avis Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kupamk 1R Pad Measured V.mr.1 Reference Onset AilmurN Offset Wellbore 1R-03-1R-03APB7-1R-03APB1 985.68 1,000.00 145.37 133.78 12.548 SF 1 R-04 - 1 R-04 - 1 R-04 87.68 82.00 60.16 59.76 149.772 CC 1R -04 -1R -04-1R-04 605.00 600.00 62.62 55.95 9.391 ES 1R -04 -1R -04-1R-04 802.83 800.00 69.67 60.50 7.595 SF 1 R-04 - 1 R-1 04A CTD Sidetrack - 1 R -1 04A wp03 87.68 82.00 60.16 59.79 160.155 CC 1 R-04 - 1 R-1 04A CTD Sidetrack - 1 R -1 04A wp03 605.00 600.00 62.62 55.97 9.428 ES 1 R-04 - 1 R-1 04A CTD Sidetrack - 1 R-1 04A vi 802.83 800.00 69.67 60.52 7.616 SF 1 R-26 - 1 R -126L1 - 1 R-126L7_wp02 (Draft C) 0.16 239.78 1.15 240.09 238.85 Out of range 1R -26 -1R -26-1R-26 4,780.00 5,000.00 324.71 319.44 61.556 CC, ES, SF 1 R-27 - 1 R-27 - 1 R-27 87.84 88.00 30.15 29.75 74.949 CC 1 R-27. 1 R-27 - 1 R-27 300.00 300.00 30.56 27.62 10.412 ES 1 R-27 - 1 R-27 - 1 R-27 4,726.83 4,600.00 496.19 422.21 6.707 SF 1R -29 -1R -29-1R-29 200.15 200.00 60.00 58.75 48.226 CC 1 R-29 - 1 R-29 - 1 R-29 299.92 300.00 60.29 58.58 35.103 ES 1R -29 -1R -29-1R-29 5,783.42 4,900.00 124.85 69.87 2.271 Caution Monitor Closely, SF 1R -29 -1R -29L1 -1R -29L1 200.15 200.00 60.00 58.99 59.601 CC 1 R-29 - 1 R-291.7 - 1 R-2911 299.92 300.00 60.29 58.99 46.143 ES 1R -29 -1R -29L7 -1R-2911 5,783.42 4,900.00 124.85 77.52 2.638 Normal Operations, SF 1 R-29 - 1 R-291.1-01 - 1 R -29L1-01 200.15 200.00 60.00 58.99 59.601 CC 1 R-29 - 1 R-291-1-01 - 1 R -29L1-01 299.92 300.00 60.29 58.99 46.143 ES 1R -29 -1R -291-1-01-1R-2917-01 5,783.42 4,900.00 124.85 77.52 2.638 Normal Operations, SF 1R -29 -1R -2911 -02 -1R -29L7-02 200.15 200.00 60.00 58.99 59.601 CC 1R -29 -1R -2911-02-1R-291-1-02 299.92 300.00 60.29 58.99 46.143 ES 1R -29 -1R -29L1 -02 -1R -29L1-02 5,783.42 4,900.00 124.85 77.52 2.638 Normal Operations, SF 1R -29 -1R -2911 -03 -1R -29L7-03 200.15 200.00 60.00 58.99 59.601 CC 1 R-29 - 1 R-2911-03 - 1 R -29L7-03 299.92 300.00 60.29 58.99 46.143 ES 1R -29 -1R -29L1 -03 -1R -29L1-03 5,783.42 4,900.00 124.85 77.52 2.638 Normal Operations, SF 1R-29-1R-29L7-03PB1-1R-291-7-03PB1 200.15 200.00 60.00 58.99 59.601 CC 1R-29-1R-29L7-03PB1-1R-29L7-03PB1 299.92 300.00 60.29 58.99 46.143 ES 1R-29-1R-29L1-03P61-1R-2911-03PB7 5,783.42 4,900.00 124.85 77.52 2.638 Normal Operations, SF Kuparuk UGNU Plan East Ugnu # 1 - Ugnu #1 - Plan #2 Out of range Offset Design Kuparuk 1 Pad- 1R -01 -1R -01-1R-01 offait Site Error: occ usft Survey program. 100 -GCT -MS Offset Well Em e: 0 00 usft Rererepre Onset Semi Major Avis Dulance Measured Vertcal Measured V.mr.1 Reference Onset AilmurN Offset Wellbore Centre Between Between Mlmmum 6eparmion Wanting Depth Depth Depth Depth tram North 4N/S -E-W centres Efl,ses Separation Factor (usft) (min) (um) (usft) (raft) poet) (1) hush) (usft) (use) (use) (urn) 4320 4320 3660 36.80 000 0.00 029 239.80 1.21 239.81 23902 079 302,765 CC 10470 104.70 10000 100.00 0.15 020 0.16 239.78 1.15 240.09 238.85 1.24 193.694 205.45 206.45 200.00 200.do 0.36 1.17 0.14 239.83 0.97 240.39 238.16 2.23 107.687 306.21 308.21 300.00 300.00 0.57 2.04 0.15 239.66 0.09 240.53 237.05 3.48 69.076 405.51 405.54 400.00 400.00 0.73 2.92 0.04 239.87 0.77 240.73 236.00 4.73 50.931 504.43 504.41 500.00 50000 0.93 3.80 4.37 239.86 0.67 240.99 235.01 5.90 40.313 602Z6 602.47 600.00 60000 1.16 4.67 -133 239.83 0.63 242.01 234.77 7.24 33.437 E8 700.77 700.42 700.00 700.00 1.40 5.55 -2.86 239.81 0.56 243.90 235.39 8.51 20.884 799.58 798.70 800.00 000.00 t.65 6.43 -5.26 239.73 0.53 246.10 238.39 8.79 25.148 Balls 889.63 900.00 600.00 191 7.32 -8.88 239.60 0.45 250.53 239.47 11.08 22.648 979.46 974.39 1.000.00 1.000.00 2.19 8.21 -14.21 239.41 0.32 259.73 247.43 12.30 21.117 CC - Min centre to center distance or covergent point, SF- min separation factor, ES - min ellipse separation 6/11/2019 2:52: 16PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips Project: Kuparuk River Unit_2 Site: Kuparuk iR Pad TlmukroTNe NNMS. m. iao.. F. WELLBORE DETAILS: 1R-126 REFERENDE INFaRw,noi Parent Wellbore: 1R-12611 coaarew(NE)Re mre Wad IR-25,Tm wan Well: 1R-26 u ..re e?91L. Tie on MD: 4869.41 Vii imi) Bek�aYe: N nsee Le+a Wellbore: IR -126 oEiegw. ea smw Ns)wla.- swl-lewN.OAOEI Poen: IR -1 26 p02 (Draft A) (1 R -2611R426) Ir"Nm.%eWmi Maewai DqM Rekre�u: +R-2fi®5ao0uza ltR-MI CNMeM Ne6mtl. ml.e. cv w WELL DETAILS: 1R-26 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 5990810.31 539829.81 70° 23'9.012 N 149° 40'33.844 W Sec MD Inc Azi TVDSS +N/ -S +E1 -W Dleg TFace VSfn Anotation1 4889.41 86.72 184.40 3399.51 -752.81 2626.86 0.00 0.00 752.TIP/KOP2 4959.41 90.18 187.86 3401.41 -822.36 2621.38 7.00 45.00 822.Start DLS 0.03 TFO -98. 2 83. 3 11771.24 69.92 186.09 3395.00 -7583.46 1793.87 0.03 -98.42 75Planned TD at 11771.24 Z_ as BA ER BAT GEm.,n r, Mean Vertical Section at 180.000 (250 usft/in) KUP INJ WELLNAP Well Attributes ConoeoPhillips Fkla Name Wellmre1a'DO weNbate Surae A1a5kd. h1C. )IKDPARNK RIVER IINn ElINM9919]00 Ila) Last Tag All Wellbores Schem AK n,mmnon Depm In86I Ena Be,.Be,.vel Mm ey wellm,e La9n Tag'. ELNE 1 .0 612612014 postop 1.46': Last Rev Reason le'm,10192xa P" Vane heausto,ens, Annotation Ena Dale I Last Mm RV wellMre a, gµGER. Es Rev Reason: CTD SETUP 5/412019 Iennall 1.46 Notes: General & Safety E aCAN Annolancn Wellbore ]/1]"014 NOTE FISH: COMPRISED OF USING/GLMINIP AL LOCATOR 18-26 Casing Strings Set DapIn TVD] wvLen e:g De: ODlin ID lint Top INKS) semepm lnMRl (nMe) 11Nn .,ane Tot Them wellm,e corvOlxroR:4an 'A'a GAS LIFT. 25Ao CONDUCTOR 16 15.06 43. 123.0 1 0 62.58 1 MAO 1WELDEO 1 - SURFACE 95/8 8.92 42.6 I 4,L,.0 36.00 J56 STC 1R-26 PRODUCTION ] I 6:28 1 41.91 10,201.0 1 1 Zb.00 JJS5 JBTC -MOD 1 4 5 AS LINER 41" I 4.00 I 4, 1.i 1 4,606.1 I $503.1 1 11.6,4 L-80 IIR Tubing Strings scone Max Nominal set Depin Set Cotp.]TVD) Due OD(In) IO lin iop(RKB IRKB) IryK81 Wt(IFJIh Gratle Top inreaa Wellmre CAA urT: 4.Aap NIPPLE: 4, n2,7 SEPLASSY',4246.3 TUBING 4.5' 4.926 3.98 39.9 4,251.8 3,285 0 12]5 L-80 HYD 503 1 -26 TUBING 3.5'x2.875' 1 4 11VI 2.991 9,569.5 1 9,746.8 6MISI 9.301-W ABM -BTC f - completion Details TOP(ND) ''olid Nomitlal Top lnKD) IRKS) 1') nem Dea Co. ID lin) Wellm,e c-sn M$pp Ulnen 4,25Lonne Remmlal eamw,t 39.9 39.9 0.88 HANGER Hanger FMC Gen IV I1"x410-HYD56 plus 4.63 pup 3.958 1R-Zfi 4,2 7 3.273] 51.54 NIPPLE Nipple3,813"HYD 563 3.813 iR- 4.249.3 3.283.4 5179 SEAL ASSY Tieback lacatol 3.980 9%.5 6,5230 4806 PACKER BAKER HE RETRIEVABLE PACKER 289018-6 98422 6,561.5 48.20 BLAST RINGS CARBIDE81-ASTRINGS(2) 2.992 9,64 .5 fi.6B6.] 47.6 SLEEVE -C CA CS -1 SL IN VE wMOG ID; SHITO 2,750 SLEEVE (OPENED SAW 4) --n-1 equeae; 43AU NKa Grt SC2. 4320.6 o,an. 9,7060 T.4 4263 PACKER BAH DPERMAN TPACKER 3.250 9]096 6,616. 4]. 1 SBE BAKER SEAL ORE'EXTENSION 3,250 9.114.0 fi.fi19.8 4].59 %O Reducing CR SOV R3.5x 87 2.8)5 9]29.8 6,630.4 47. NIPPLE uTS z un AN NIPPLE', 2313" win 2.2FNO GO 10 2.250heake 9,746.0 6,6416 47.601SOS NAaLM bMICAM LUT BUB. TTL 9 fdU EINA, IBUTO is, 993UELM 2441 18-M - S'SSW6 S'SSW6 Omer In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) npITVD) Topinu9) Inge) Top mct('I Dea Co. p 9a- ID nn) weUm,e --- 39.9 39.9 0. BPV &4/2019 1R- ;ftJ111LL1 4,fi59.0 3. 53.91 4/262019 R-26 PERMANENT SCAB LINER, 42011. psa BRIDGE PLUG. PERMANENT: 4Sa Liner Details Top 0", Nominal l9 Top UKB) MAD Top leull') It.. Dea Co. InI W¢IIW,e SURFACE 42.6ASES1 �m.m n,ya.ma.aL Was EDS cemem Flu9'. e.pa. PACKER; 9589A 42.6 42.6 0.82 HANGER 8921 -26 43.0 43.0 0.81 CONDUCTOR 15.062 1... 2 - 42511 42511 3.284.5 51.80 PRR PER 5.250 1R-2fi 4, 867 3,306.6 5189 NIPPLE XNiphe 3. 13° 5893R-2PTk1018781 9 3.813 1 - 6 4.430.5 3,396.0 5136 TANDEM WEDGE Wedge ass'y @ 4434' OKS 3.958 1 - 4.449.5 3.407.9 51.34 NIPPLE Nipple -X 3813 IR -26 4,456.6 3.412.3 51.33 TANDEMWEDGE Wad, easy@4460' KB 3.958 1 - 4,475fi 3,424.2 51.32 NIPPLE Nipple,% 3.813 WR -8- Perforations & Slots Spot D.n Top T VTN eLm(rvol an. Top INXB) aMDES) IRKS) (RNB) Mea Lone Dale 1 Type Com Aanese INIECTION, 88123 4, 0.0 4,480.0 3,3223 3,426A 427/2019 12.0 CMT SOZ 5 18. 12ap1199 FOX BIT 1R- 6 135deg phasing TCP WSPEnce Ips was SLB EMIT2,2.19 IPERE.eaEeneana- 3.0 9,6]2.0 8,591.5 C-1. IH -26 1/4/1992 10.0 (PERF .'Csg Gun. Odes, Ph 1 -25 A887.0 9,902.0 6]36,5 ,746,7 77, 1"-26 91&2007 ED "PERF TTI ower Ernal lHMX. 11-26 0 dee Ph SLEEVEL',Geek5 9916.0 9,941.0 6,]56.2 6.]132 A-3.18-26 1/49992 40 (PERF 4.5" Csg Gun l8n deg. Pn 1R-26 Mandrel Inserts at ati Pwl PACKER. ane TaPTP701 No T(g6RO Va saE', a]pe.8 Top (llNp) (RKBI Make Mmel OD(in) Sery �,pe raI flan Date Cdn Wellmre 1 2,998.0 50. mm KBMG 1 INJ OMY 5/3/2019 1R-26 2 42 .0 .256.5 CameoKIRMG 15ra,2019 R-26 ISheer ea rvIPpLE: 9.]A9 SOV - sos: e.74so Spear 9.81170,9901 MERE; 9 a1G69911 U- PRODUCTION; 41.9 1QA10 From: McLaughlin Ryan To: Boyer. David L (CED1 Subject: RE: (ExTERNAL]Digital Survey Files Date: Monday, July 1, 2019 9:51:31 AM Hello Dave, Yes, the two 1R water injectors will be pre -produced for approximately 3 weeks. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 From: Boyer, David L (CED) <david. boyer2@alaska.gov> Sent: Monday, July 1, 2019 9:30 AM To: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Subject: RE: [EXTERNAL] Digital Survey Files Hi Ryan, Will the two 1R water injectors be preproduced? If so, for less than 3 months? Thank you, Dave Boyer From: McLaughlin, Ryan <Ryan McLaughlinCa�conocQpt llios corn> Sent: Friday, June 28, 2019 8:35 AM To: Boyer, David L (CED) <david.boyer2na alaska.gov> Subject: RE: [EXTERNAL]Digital Survey Files Dave, Digital survey files for the 1R-126 and 1R -126L1 laterals are attached. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer Conoco Phil lips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 From: Boyer, David L (CED) <david.boyer2(n alaska gov> Sent: Friday, June 28, 2019 8:21 AM To: McLaughlin, Ryan <Ryan.McLaughlin(@conoco hilli so com> Subject: [EXTERNAL] Digital Survey Files Hi Ryan, Would it be possible to send over the digital survey files for KRU 1R-126 & 11R-12611 PTD applications in Excel or ASCII format. We plot the wellpaths in the Geographix program before issuing the permits. Thankyou, Dave Boyer Senior Geologist AOGCC TRANSMITTAL LETTER CHECKLIST WELL NAME: V\ R (L , R -- (a 6 PTD: 19 - 09+ Development ./service _ Exploratory _ Stratigraphic Test Non -Conventional FIELD: —" ao-a k- 'RI Vep- POOL: W'P_!i }- S0. �G 9i1 Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- _) from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to -the 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 tar et zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 da s after com letion, sus ension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL- 490150 PTD#: 2190940 Company ConocoPhillips Alaska Inc Initial Class/Type Well Name: KUPARUK RIV UNIT 1R-126 Program SER Well bore seg ❑ SER —/ PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached _ _ . _ .. NA . . 2 Lease number appropriate. _ _ _ ... ...... Yes _ . ......... . . . . ...... 3 Unique well. name and number--------------- __-----..Yes...-------- ------_ ------------------------- 4 Well located in a. defined pool. _ ------------ ---------- _.. _.. Yes...------ 5 Well located proper distance, from drilling unit. boundary_ _ _ _ _ _ _ _ _ _ _ _ _ . Yes 6 Well located proper distance from other wells _ _ _ _ _ _ _ _ Yes 7 Sufficient acreage available in drilling unit. _ _ _ _ _ _ _ _ _ _ _ Yes 8 If deviated, is wellbore plat included _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ Directional_ plan view_& wellbore profile included. 9 Operator only affected party _ _ _ _ _ _ _ Yes 10 Operator has appropriate bond in force _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes.... 11 Permit can be issued without conservation order.. _ _ ..... .. _ _ _ _ _ Yes Appr Date 12 Permit can be issued without administrative approval _ .... .... _ _ _ _ _ _ Yes 13 Can permit be approved before 15 -day wait Vey DLB 7/1/2019 . . . ... . . . ....... .... ..... _ .. _ _ 14 Well located within area amd.stmta authorized by Injection Order # (put 10# in comments), (For. Yes _ _ _ Area Injection Order No. 2B. 15 All wells.within 1(4.roile area of review identified (For service well only) _ _ _ _ _ _ .. _ _ . Yes 16 Pre -produced injector; duratinnof pre -production less than 3 months_ (For service well only) _ Yes 17 Nonconven. gas conforms to AS31,05.030Q 1 A),(j.2.A-D) _ _ _ _ _ _ _ _ _ _ _ _ . NA 18 Conductor string_ provided NA _ _ Conductor set forKRU_ 1 R-26 _ Engineering 19 Surface casing protects all known USDWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ Surface casing set for KRU 1R-26 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 coverall known. productive horizons.. _ ..... _ _ _ No Productive.. interval will be completed with an unCemented solid and slotted liner ... 23 Casing designs adequate for C, T, 13 & permafrost. ... Yes 24 Adequate tankage. or reserve pit _ _ _ _ ... - Yes Rig has steel tanks; ell waste to approved disposal wells... ...... 25 If a, re -drill, has a 10403 for abandonment been approved _ _ _ .. Yes _ PTD 191-092,. Sundry 314-392:. Kuparuk plugged after unsuccessful WO in 2014 . . 26 Adequate wellbore separation proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ Anti -collision analysis complete; no major risk failures 27 If diverter required, does it meet regulations _ _ _ _ _ _ _ _ _ _ _ _ _ NA Appr Date 28 Drilling fluid program schematic &. equip list adequate. . . . Yes .... Max formation pressure is, 12440 psig(8.18 ppg EMW ); will 001[w/ 8,4. ppg BMW and.maintain Qverbal. w/ MPD _ VTL 7/2/2019 29 BOPEs, do they meet regulation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 30 BOPE.press rating appropriate; test to_(put psig in comments)...... Yes .. MPSP is 10911 psig; will test BOPs.to 3500 psig .. ...... 31 Choke. manifold complies w/API.RP-53 (May 84)_ _ _ _ _ _ _ _ _ _ _ _ Yes 32 .Work will occur without operation shutdown- .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 33 Is presence of 1-12S gas probable - - - - - - - - - - - - - - - - --- - - - - - - - - - - - - - - - - - - No - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 34 Mechanical condition of wells within AOR verified (For service well only) _ _ _ _ _ Yes _ _ _ _ 7 wells identified and_verifie0z 1 G -07A SC set above Wsak; -increased CA monitoring rqd . 35 Permit can be issued w/o hydrogen sulfide measures ... _ _ _ _ _ Yes _ 1 R-126_is only the 2nd West Sak well drillyd on 1 R Pad... Geology 36 Data presented on potential overpressure zones _ Yes _ Appr Date 37 Seismic analysis of shallow gas zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA. DLB- 7/1/2019 38 Seabed condition survey (if off -shore) .. .. ....... NA 39 Contact name/phone for weekly progress reports [exploratory only] _ _ _ _ _ _ _ _ _ _ _ _ _ NA. Geologic Engineering ate Public Date 7/3/19 Kuparuk abandoned to CTD drill into West Salk. 2nd well. VTL Date: D Commissioner: Commissioner: Commissioner all
