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219-110
Originated: Delivered to:2-Jan-25 Alaska Oil & Gas Conservation Commiss 02Jan25-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 1G-103 50-029-20824-01-00 219-110 Kuparuk River WL WFL FINAL FIELD 9-Dec-24 1G-01 50-029-20805-00-00 182-130 Kuparuk River WL IPROF FINAL FIELD 11-Dec-24 1F-08 50-029-20836-00-00 182-162 Kuparuk River WL RBP FINAL FIELD 15-Dec-24 1F-14 50-029-21022-00-00 183-146 Kuparuk River WL PPROF FINAL FIELD 17-Dec-24 1F-08 50-029-20836-00-00 182-162 Kuparuk River WL RBP FINAL FIELD 18-Dec-24 1L-05 50-029-21155-00-00 184-123 Kuparuk River WL IPROF FINAL FIELD 19-Dec-24 1Y-29 50-029-21852-00-00 188-091 Kuparuk River WL PPROF FINAL FIELD 20-Dec-24 2T-10 50-103-20064-00-00 186-096 Kuparuk River WL IPROF FINAL FIELD 21-Dec-24 2H-05 50-103-20043-00-00 185-168 Kuparuk River WL PPROF FINAL FIELD 22-Dec-24 1Q-12 50-029-21210-00-00 184-193 Kuparuk River WL LEE-IPROF FINAL FIELD 23-Dec-24 MT7-91 50-103-20881-00-00 224-020 Greater Mooses Tooth WL TTiX-IPROF FINAL FIELD 29-Dec-24 MT7-92 50-103-20872-00-00 223-114 Greater Mooses Tooth WL TTiX-PPROF FINAL FIELD 31-Dec-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39899 T39900 T39901 T39902 T39901 T39903 T39904 T39905 T39906 T39907T39908 T39909 1G-103 50-029-20824-01-00 219-110 Kuparuk River WL WFL FINAL FIELD 9-Dec-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.03 08:13:20 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1G-103 (PTD 219-110) Plan Forward Date:Sunday, November 24, 2024 4:33:24 PM Attachments:KRU 1G-103 (PTD 219-110) Conditions for Approval.pdf 1G-103 90 Day TIO Plot & Schematic.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Friday, November 22, 2024 12:21 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 1G-103 (PTD 219-110) Plan Forward Chris, KRU 1G-103 (PTD 219-110) was brought on injection yesterday in an attempt to achieve stable injection to complete the required waterflow log per waiver to 20 AAC 25.030(d)(5) (see attachment). With what appears to the current inability to stay within the required maximum West Sak injection gradient of 0.62 psi/ft, the well was shut back in and freeze protected today. CPAI intends to bullhead surfactant down the tubing in an attempt to increase injectivity. The well will be brought back on injection after pumping surfactant, in an attempt to establish stable injection within the West Sak gradient requirements. If this is achieved the required waterflow log will be scheduled. If injectivity does not improve, the well will be shut back in and a Coil fill clean out will be attempted to improve injectivity. The well will again be brought injection in an attempt to establish stable injection within the West Sak gradient requirements. If this is achieved the required waterflow log will be scheduled. If injectivity does not improve the well will be shut back in and freeze protected. A 90 day TIO trend and wellbore schematic are attached. Please let us know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 STATE OF ALASKA A, KA OIL AND GAS CONSERVATION COMh 31ON c,__ 'JED PERMIT TO DRILL 20 AAC 25,005 1a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Drill ❑ Lateral Stratigraphic Test ❑ Development - Oil ❑ Service - WAG ❑ Service - Disp ❑ Service - Winj 0 Single Zone 1 c. Specify if well is proposed for: Coalbed Gas ❑ Gas Hydrates ❑ Redrill (� Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 2] Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 5952180 KRU 1G-103 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 11,580' TVD: 3433' Kuparuk River Field / West Sak Oil Pool , 4a. Location of Well (Governmental Section): Surface: 4151' FNL, 264' FWL, Sec 29, Tl2N, R10E, UM 7. Property Designation: ADL-OOM635 ADL 25640 Top of Productive Horizon: 4290' FNL, 3746' FWL, Sec 30, T12N, R10E, UM 8. DNR Approval Number: LONS 83-25 13. Approximate Spud te: 8/ZV2019 9 Total Depth: 2771' FNL, 2046' FWL, Sec 19, T12N, R10E, UM 9. Acres in Property: 2560 - 14. Distance terNearest Property: 17,572' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (fi 90' 15. Distance to Nearest Well Open Surface: x- 540036.44 y- 5981774.73 Zone- 4 GL / BF Elevation above MSL (ft): 56' - to Same Pool: 448'. iG-16 16. Deviated wells: Kickoff depth: 3812 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 94 degrees Downhole: 1516 ' Surface: 1179 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) 4-1/4" 3-1/2" 9.2# L-80 R-2 167' 3802' 3361' 3969' 3435' Solid Liner 4-1/4" 2-7/8" 6.5# L-80 R-2 7611' 3969' 3435' 11580'• 3433' Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (Ill Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 8489' 6951, 3959' 8463' 6928' N/A Casing Length Size Cement Volume MO TVD Conductor/Structural 78' 161, 325 sx AS II 108' 108, Surface 2274' 10-3/4" 1400 sx AS III, 250 sx AS 1 2303' 2216' Production 10,166' 7" 900 sx Class'G', 250 sx AS 1 8464' 6929' Perforation Depth MD (ft): 3669'-3826', 7315'-7317', 7495'-7525', Perforation Depth TVD (ft): 3264'-3378', 5953'-5955', 6104'-6129', 6142'-6161% 7540'-7563', 7772'-7825' 6336'-6380' Hydraulic Fracture planned? Yes ❑ No Q 20. Attachments: Property Plat ❑ BOP Sketch Diverter Sketch Drilling Program B Seabed Report Time v. Depth Plot e Drilling Fluid Program Shallow Hazard Analysis a 20 AAC 25.050 requires H, 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 McLaughlin Authorized Name: Shane Germann Contact Email: an.mclaU hlin CO .com Authorized Title: error CTD Engineer Contact Phone: 907-265-6218 Authorized Signature: Date: Commission Use Only Permit to DrillAPI Number: Permit Approva See cover letter for other Number: �' 50- p Date: 2� �, 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: 0P 7'Os7, 7'0 75OO r¢-rq{ Ov �'Samples req'd: Yes ❑ No[6r Mud log req'd: Yes,❑-,/No� wr"i.,lar- /p!'C V�✓1 ttT Tr.S t %0 23 ` J i,s measures: Yes ❑ NO2" Directional svy req'd: YesS No,,/ /`�❑-Wa / ✓ er t ZO �Ac 2 s. 63,01 Racing exception req'd: Yes ❑ Noy Inclination -only svy req'd: Yes ❑ NoR Wc5 f Sq K Post initial injection MIT req'd: Yes (�No❑ y 5,� p7/—a h�-�-� ��b C0 f- j-o }j- e ,1;1 L✓r`/RChed L'Ovl�i�t/`eqnS fOr /¢P��✓Q'. n�ccrla+'+_D.62jpljcctlWlvrh-'Fj (20fi/fc75".036l,33) N / will re- v1Y-e y1.�lag r-rd aftt,-,51-ctJ-JI3ly, and e✓'r iwo / r'li S r�vv�cllatcal l . APPROVED BY Approved by: /' COMMISSIONER THE COMMISSION Date: aV'T �- Fi/2 /�f Form 10-40 Revised 5/2017 s p r (t ill, 02 t r e Submit Form and f approval per 20 AAC 25.005(g) Attachments in Duplicate KRU 1G-103(PTD 219-110) Conditions for Approval A waiver to 20 AAC 25.030(d)(5) is granted for KRU 1G-103 subject to the conditions outlined below The condition applies to wells where the West Sak or the Ugnu is not zonally isolated with cement under regulation 20 AAC 25.030(d)(5) and/or where the OA(below a cement packer) is in hydraulic communication with the reservoir or injection fluids as a result of West Sak CTD. This includes any wells in the AOR of a West Sak injector or a newly drilled West Sak CTD well(injector or producer) from a plugged Kuparuk wellbore. These wells must be identified in a single list and the OA pressure tracked and reported to the AOGCC upon request or when an anomalous OA pressure is detected. The list must include information on the mechanical integrity of the well specifically the IA and OA pressures and the MIT history. A complete list in a proposed format is due to the AOGCC by 9/30/19 for review and approval. This condition is in addition to existing sustained casing pressure (SCP) rules. A waterflow log is required after stabilized injection from the window to above the Ugnu. Subsequent waterflow logs are required every two years. Any out of zone injection will require remediation. Maximum West Sak injection gradient is 0.62 psi/ft. This waiver is granted based on specific to this well reservoir properties, reservoir management, well configuration and well history among other factors. This waiver is granted exclusively to KRU 1G-103 which is a well in a West Sak CTD pilot area. This waiver may not be granted in the future to a well with a similar configuration but instead the well may require rig intervention and/or remedial cementing to comply with regulations. Last Tag Annotation Depth (ftKB) End Date Last Mod By Wellbore Last Tag:jennalt 1G-103 Last Rev Reason Annotation End Date Last Mod By Wellbore Rev Reason: Set DV's 10/20/2019 zembaej 1G-03 Notes: General & Safety End Date Annotation Wellbore 9/30/2019 NOTE: View Schematic w/ Alaska Schematic10.0 1G-103 Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Wellbore CONDUCTOR 16 15.25 30.0 108.0 108.0 65.00 H-40 WELDED 1G-03 SURFACE 10 3/4 9.95 29.0 2,302.8 2,216.1 45.50 K-55 BTC 1G-03 PRODUCTION 7 6.28 27.5 8,463.8 6,928.8 26.00 K-55 BTC 1G-03 LINER 2 7/8 2.44 3,790.6 11,960.0 3,447.6 6.50 L-80 H533 1G-103 Tubing Strings Des String Max Nominal OD (in)ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt (lb/ft) Grade Top Thread Wellbore 4.5" HYD 503 COMPLETION 4 1/2 3.96 24.5 3,633.3 3,238.3 12.75 L-80 HYD 503 1G-03 4.5" SCAB LINER 4 1/2 3.99 3,624.7 3,951.3 3,468.4 12.60 L-80 BTC 1G-03 TUBING LEFT IN HOLE 3 1/2 2.99 4,800.0 7,739.2 6,308.4 9.20 J-55 BTCABMOD 1G-03 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 24.5 24.5 0.07 HANGER Hanger FMC Gen IV 7 1/16" x 4 1/2" VAM FJL BXP 3.958 1G-03 3,623.0 3,230.9 44.67 LOCATOR Baker locator 3.980 1G-03 3,623.7 3,231.4 44.65 SEAL ASSY Baker seal assembly (1' off no-go) 3.980 1G-03 3,624.7 3,232.1 44.63 PBR Baker 4 1/2" x 7" 2RH Liner Setting Sleve 4.190 1G-03 3,649.6 3,249.9 44.03 PACKER Baker 4 1/2" x 7" FP S3 Packer VT Pin x IBT Pin 3.920 1G-03 3,675.5 3,268.6 43.74 NIPPLE X Nipple HES 3.813" BTCM BxP 3.813 1G-03 3,776.8 3,342.5 42.93 TANDEM WEDGE Northern Solutions 4-1/2'' Tandem Wedge 3.958 1G-03 3,795.8 3,356.3 42.93 NIPPLE X Nipple 4-1/2'' x 3.813'' BTCM BxP 3.813 1G-03 3,809.6 3,366.5 43.10 TANDEM WEDGE Northern Solutions 4-1/2'' Tandem Wedge 3.958 1G-03 3,820.9 3,374.7 43.30 NIPPLE X Nipple 4-1/2'' x 3.813'' BTCM BxP 3.813 1G-03 3,864.2 3,406.0 43.96 LANDING COLLAR 4 1/2" Landing Collar 3.930 1G-03 3,949.6 3,467.2 44.45 FLOAT SHOE Float shoe BTCM 0.000 1G-03 7,340.3 5,974.6 33.33 PBR BAKER PBR 4.250 1G-03 7,354.7 5,986.6 33.32 PACKER BAKER HB PACKER 2.890 1G-03 7,498.9 6,107.4 32.83 BLAST JTS BLAST JOINTS (OAL=70.4') 3.000 1G-03 7,720.1 6,292.5 33.43 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2.985 1G-03 7,720.6 6,292.9 33.43 PACKER BAKER FB-1 PACKER 4.000 1G-03 7,723.9 6,295.7 33.44 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 1G-03 7,732.9 6,303.2 33.46 NIPPLE CAMCO D NIPPLE NO GO 2.750 1G-03 7,738.4 6,307.8 33.48 SOS CAMCO SHEAR OUT SUB, ELMD TTL @ 7726' during IPROF on 05/14/2007 3.015 1G-03 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) Wellbore 3,785.0 3,348.4 42.93 NON RETRIEVABLE LINER TOP PACKER Baker 45 Flo-Guard Packer L-80 w/ Northern Solutions PTSA. OAL 9.84' Max OD 3.70" 9/12/2019 2.310 1G-103 3,805.0 3,363.1 43.02 WHIPSTOCK 4-1/2" Northern Solutions Inner Wedge, Set 0 deg HS, w/ two PIP tags. 8/6/2019 1.000 1G-103 3,821.0 3,374.7 43.30 X-LOCK ASSEMBLY Set X-Lock & Flow thru assembly for Whipstock. 19" OAL. 8/5/2019 0.000 1G-03 3,958.5 3,473.5 44.48 CIBP Bridge Plug - Permanent 6/4/2019 0.000 1G-03 4,800.0 4,065.6 45.70 JET CUT Jet Cut 5/30/2019 0.000 1G-03 7,260.0 5,907.6 33.70 CEMENT RETAINER WEATHERFORD 3.5" CEMENT RETAINER 5/24/2019 0.000 1G-03 7,718.0 6,290.7 33.43 CIBP WEATHERFORD 3 1/2" CIBP OAL 1' MAX OD 2.75" 3/7/2019 0.000 1G-03 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 27.5 27.5 0.08 HANGER 6.276 1G-03 29.0 29.0 0.08 HANGER 9.950 1G-03 30.0 30.0 0.08 CONDUCTOR 15.250 1G-03 3,790.6 3,352.5 42.93 SBR Deployment seel with 6' seal bore 2.990 1G-103 3,797.6 3,357.6 42.93 BLANK 3-1/2", 9.2 #, L-80, wedge H511 Solid Liner (6 jnts entered as tool length) 2.990 1G-103 3,966.5 3,442.6 77.73 CROSSOVER- REDUCING XO 3-1/2"-2-7/8" 2.391 1G-103 3,967.2 3,442.8 77.87 BLANK 2-7/8", 6.5#, L-80, H533, Blank liner (cover faults ) 2.441 1G-103 6,525.0 3,382.2 90.51 DEPLOYMENT SLEEVE Dissolvable bull nose - note, LOA 1.44' with 0.487' swallowed in QCLL 2.375 1G-103 6,526.9 3,382.2 90.48 BLANK 2-7/8", 6.5#, L-80, H533, Blank liner - (cover section drilled out of zone) 2.441 1G-103 7,529.1 3,413.9 89.36 BLANK 2-7/8", 6.5#, L-80, H533, Blank liner 2.441 1G-103 8,640.1 3,444.0 85.91 BLANK 2-7/8", 6.5#, L-80, H533, Blank liner 2.441 1G-103 9,745.5 3,448.3 89.09 BLANK 2-7/8", 6.5#, L-80, H533, Blank liner 2.441 1G-103 9,835.5 3,448.2 91.07 DEPLOYMENT SLEEVE OH Permanent QCLL 2.375 1G-103 Comment SSSV: NONE 1G-103, 10/23/2019 8:43:24 AM Vertical schematic (actual) LINER; 3,790.6-11,960.0 SLOTS; 10,937.0- 11,959.0 SLOTS; 9,837.0-10,849.0 SLOTS; 8,730.0-9,746.0 SLOTS; 7,623.0-8,640.0 SLOTS; 7,079.0-7,529.0 SLOTS; 5,690.0-6,525.0 WHIPSTOCK; 3,805.0 PRODUCTION; 27.5- 8,463.8 NIPPLE; 3,795.8 NON RETRIEVABLE LINER TOP PACKER; 3,785.0 TANDEM WEDGE; 3,776.8 Cement Squeeze; 3,669.0 ftKB IPERF; 3,669.0-3,826.0 NIPPLE; 3,675.5 PACKER; 3,649.5 PBR; 3,624.7 SEAL ASSY; 3,623.7 LOCATOR; 3,623.0 GAS LIFT; 3,596.3 Annular Fluid - Saltwater/Brine; 2,650.0- 3,624.7; 6/10/2019 GAS LIFT; 2,663.2 SURFACE; 29.0-2,302.8 Annular Fluid - Diesel; 24.5-2,650.0; 6/10/2019 CONDUCTOR; 30.0- 108.0 HANGER; 24.5 KUP INJ KB-Grd (ft) 33.99 Rig Release Date 10/8/1982 Annotation Last WO: End DateH2S (ppm) Date... TD Act Btm (ftKB) 11,960.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292082401 Wellbore Status PROD Max Angle & MD Incl (°) 97.88 MD (ftKB) 4,895.57 Legal Wellname 1G-103 Common Wellname1G-03 AK All Wellbores Schem Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 10,848.7 3,446.8 89.39 BLANK 2.441 1G-103 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com Wellbore 5,690.0 6,525.0 3,394.1 3,382.2 9/7/2019 SLOTS 1G-103 7,079.0 7,529.0 3,393.6 3,413.9 9/7/2019 SLOTS 1G-103 7,623.0 8,640.0 3,416.0 3,444.0 9/7/2019 SLOTS 1G-103 8,730.0 9,746.0 3,448.6 3,448.4 9/7/2019 SLOTS 1G-103 9,837.0 10,849.0 3,448.1 3,446.8 9/7/2019 SLOTS 1G-103 10,937.0 11,959.0 3,447.1 3,447.6 9/7/2019 SLOTS 1G-103 3,669.0 3,826.0 3,263.9 3,378.4 6/4/2019 12.0 IPERF 1G-03 7,315.0 7,317.0 5,953.4 5,955.1 4/9/2019 4.0 CMT SQZ 2" Tubing Punch 0 deg phasing 4spf. 1G-03 7,495.0 7,525.0 6,104.1 6,129.3 C-3, 1G-03 8/25/1984 12.0 IPERF 1G-03 7,540.0 7,563.0 6,141.9 6,161.2 C-1, 1G-03 8/25/1984 12.0 IPERF 1G-03 7,772.0 7,825.0 6,335.8 6,379.9 A-4, A-3, 1G-03 8/25/1984 12.0 IPERF 1G-03 Mandrel Inserts St ati on No /S Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com Wellbore 1 2,663.2 2,510.6 Camco KBG-2 1 INJ DMY BK 0.000 0.0 10/20/2019 1G-03 2 3,596.3 3,212.0 Camco KBG-2 1 INJ DMY BK 0.000 0.0 10/20/2019 1G-03 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Type Start Date Com Wellbore 3,669.0 3,826.0 3,263.9 3,378.4 CEMENT SQUEEZE Squeeze 6/5/2019 Squeezed in 15.8 PPG class G cement with Archer Stronghold Barricade too. 1G-03 1G-103, 10/23/2019 8:43:24 AM Vertical schematic (actual) LINER; 3,790.6-11,960.0 SLOTS; 10,937.0- 11,959.0 SLOTS; 9,837.0-10,849.0 SLOTS; 8,730.0-9,746.0 SLOTS; 7,623.0-8,640.0 SLOTS; 7,079.0-7,529.0 SLOTS; 5,690.0-6,525.0 WHIPSTOCK; 3,805.0 PRODUCTION; 27.5- 8,463.8 NIPPLE; 3,795.8 NON RETRIEVABLE LINER TOP PACKER; 3,785.0 TANDEM WEDGE; 3,776.8 Cement Squeeze; 3,669.0 ftKB IPERF; 3,669.0-3,826.0 NIPPLE; 3,675.5 PACKER; 3,649.5 PBR; 3,624.7 SEAL ASSY; 3,623.7 LOCATOR; 3,623.0 GAS LIFT; 3,596.3 Annular Fluid - Saltwater/Brine; 2,650.0- 3,624.7; 6/10/2019 GAS LIFT; 2,663.2 SURFACE; 29.0-2,302.8 Annular Fluid - Diesel; 24.5-2,650.0; 6/10/2019 CONDUCTOR; 30.0- 108.0 HANGER; 24.5 KUP INJ ... Legal Wellname 1G-103 Common Wellname1G-03 AK All Wellbores Schem TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop _1E-17 50-029-20793-00 182116_1E-17_IPROF_16Jan2023 _1E-20 50-029-20895-00 183005_1E-20_LDL_10Jan2023 183005_1E- 20_PlugSettingRecord_20Aug2023 183005_1E-20_PPROF_29Sep2022 183008_1E-20_RBP_25Feb2023 1F-06 50-029-20820-00 182145_1F-06_Perf_11Jul2022 182145_1F-06_TubingCut_20Feb2022 1G-09 50-029-21001-00 183124_1G-09_IPROF_01Jun2022 1G-103 50-029-20824-00 219110_1G-103_RSTWFL_09Nov2022 1G-11 50-029-21008-00 183131_1G-11_LDL_31May2022 1G-13 50-029-21016-00 183140_1G-13_LDL_09Jul2022 1H-102 50-029-23580-00 217097_1H-102_PPROF_02May2022 1H-103 50-029-23593-00 218003_1H-103_PPROF_06May2022 1H-109 50-029-23595-00 218013_1H-119_IPROF_02JUL2023 3of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38329 T38330 T38331 T38332 T38333 T38334 T38335 T38336 T38337 T38338 2/29/2024 1G-103 50-029-20824-00 219110_1G-103_RSTWFL_09Nov2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:29:27 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1G-103 KUPARUK RIV UNIT 1G-103 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/01/2023 1G-103 50-029-20824-01-00 219-110-0 W SPT 3348 2191100 1500 650 650 650 650 70 76 76 76 4YRTST P Sully Sullivan 7/1/2023 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 1G-103 Inspection Date: Tubing OA Packer Depth 620 1815 1740 1730IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230704054228 BBL Pumped:0.5 BBL Returned:0.5 Friday, September 1, 2023 Page 1 of 1 DATA SUBMITTAL COMPLIANCE REPORT 1/3/2020 Permit to Drill 2191100 Well Name/No. KUPARUK RIV UNIT 1G-103 MD 11960 TVD 3448 Completion Date 9/11/2019 REQUIRED INFORMATION Mud Log No ✓ DATA INFORMATION List of Logs Obtained: GR/Res Well Log Information: Log/ 31291 Electr Data Digital Dataset Type Med/Frmt Number Name ED C 31220 Digital Data ED C 31220 Digital Data ED C 31220 Digital Data ED C 31220 Digital Data Log Electronic File: 1G-103 21VID Final.pdf 31220 Log Header Scans ED C 31291 Digital Data ED C 31291 Digital Data ED C 31291 Digital Data ED C 31291 Digital Data ED C 31291 Digital Data ED C 31291 Digital Data ED C 31291 Digital Data ED C 31291 Digital Data ED C 31291 Digital Data ED C 31291 Digital Data ED C 31291 Digital Data ED C 31291 Digital Data ED C 31291 Digital Data AOGCC Operator Conocolahillips Alaska, Inc. Completion Status 1 W INJ Current Status 1 WINJ Samples No 1� API No. 50-029-20824-01-00 UIC Yes Directional Survey Yes (from Master Well Data/Logs) Log Log Run Interval OH I Scale Media No Start Stop CH Received Comments 9/19/2019 Electronic File: 1G-103 EOW NAD27.pdf 9/19/2019 Electronic File: 1G-103 EOW NAD27.txt 9/19/2019 Electronic File: 1G-103 EOW NAD83.pdf 9/19/2019 Electronic File: 1G-103 EOW NAD83.txt 0 0 2191100 KUPARUK RIV UNIT 1G-103 LOG HEADERS 3314 11960 10/4/2019 Electronic Data Set, Filename: 1 G-103 GAMMA RES.las 10/4/2019 Electronic File: 1G-103 2MD.cgm 10/4/2019 Electronic File: 1G-103 5MO.cgm 10/4/2019 Electronic File: 1G-103 5TVDSS.cgm 10/4/2019 Electronic File: 1G-103 21VID Final.pdf 10/4/2019 Electronic File: 1G-103 51VID Final.pdf 10/4/2019 Electronic File: 1G-103 5TVDSS Final.pdf 10/4/2019 Electronic File: 1G-103 EOW NAD27.pdf 10/4/2019 Electronic File: 1G-103 EOW NAD27.txt 10/4/2019 Electronic File: 1G-103 Final Survey TO 11960.csv 10/4/2019 Electronic File: 1G-103 Final Survey TO 11960.x1sx 10/4/2019 Electronic File: 1G-103 Survey Listing.txt 10/4/2019 Electronic File: 1G-103 Survey.bd Page] of 3 Friday, January 3, 2020 DATA SUBMITTAL COMPLIANCE REPORT 1/312020 Permit to Drill 2191100 Well Name/No. KUPARUK RIV UNIT 1G-103 MD 11960 TVD 3448 Completion Date 9/11/2019 ED C 31291 Digital Data ED C 31291 Digital Data ED C 31291 Digital Data ED C 31291 Digital Data ED C 31291 Digital Data ED C 31291 Digital Data Log Electronic File: 1G-1035TVDSS.cgm.meta.tif 31291 Log Header Scans ED C 31350 Digital Data ED C 31350 Digital Data ED C 31350 Digital Data ED C 31350 Digital Data Log Electronic Data Set, Filename: 1G- 31350 Log Header Scans Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report ""0Y Production Test Informationto NA Geologic Markers/Tops CJ COMPLIANCE HISTORY Completion Date. 9/11/2019 Interval Start Stop Operator ConocoPhillips Alaska, Inc. API No. 50-029-20824-01.00 Completion Status 1WINJ Current Status 1WINJ UIC Yes 10/4/2019 Electronic File: 1G- 103_25_tapescan_BH I_CTK.txt 10/4/2019 Electronic File: 1 G-103_5_tapescan_BHI _CTK.txt 10/4/2019 Electronic File: IG-103_output.tap 10/4/2019 Electronic File: 1G-103 2MO.cgm.meta.tif 10/4/2019 Electronic File: 1G-103 5MD.cgm.meta.tif 10/4/2019 Electronic File: 1G-1035TVDSS.cgm.meta.tif 0 0 2191100 KUPARUK RIV UNIT 1G-103 LOG HEADERS 0 604 10/23/2019 Electronic Data Set, Filename: 1 G- 103_PACKE R_12S E P 19_3583.1 as 0 599 10/23/2019 Electronic Data Set, Filename: 1G- 103_PACKE R_12S E P 19_3791.1 as 10/23/2019 Electronic File: 1 G- 103_PACKE R_12S EP 19_3583.x1sx 10/23/2019 Electronic File: 1 G- 103_PACKER_12S EP 19_3791.xlsx 0 0 2191100 KUPARUK RIV UNIT 1G-103 LOG HEADERS Sample Set Sent Received Number Comments Directional / Inclination Data V Mechanical Integrity Test Information Y / NA Daily Operations Summary V Mud Logs, Image Files, Digital Data �Y� Core Chips Y'9 / A Composite Logs, Image, Data Files I Y 1 Core Photographs Y / Cuttings Samples �Y//® Laboratory Analyses Y / A06('(Page 2 of 3 Friday, January 3, 2020 DATA SUBMITTAL COMPLIANCE REPORT 1/3/2020 Permit to Drill 2191 100 Well Name/No. KUPARUK RIV UNIT 1G-103 Operator ConocoPhillips Alaska, Inc. API No. 50-029-20824-01-00 MD 11960 TVD 3448 Completion Date 9/11/2019 Completion Status 1WINJ Current Status 1WINJ UIC Yes Release Date: 8/29/2019 Description Date Comments Comments: Compliance Reviewed By: Date: ' I �l ad ZU AGGCC Page 3 of 3 Friday. January 3, 2020 MEMORANDUM TO: Pim Regg per P.I. Supervisor FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, November 14, 2019 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc, IG -103 KUPARUK RIV UNIT IG403 Src: Inspector Reviewed By: P.I. Suprv2 Comm Well Name KUPARUK RIV UNIT IG -103 API Well Number 50-029-20824.01-00 Inspector Name: Brian Bixby Insp Num: mitBDB191111162654 Permit Number: 219-110-0 Inspection Date: 11/10/2019 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IG 103Type Inj WZVEI .-as - Tubing 650 650 ,� rso - o PTD 2191100 Type Test SPT Test psi 1=06 IA rz(,0 2020 - u,5 1975 - BBL Pumped: 0. B L Returned- o? OA ss se a Interval _ _.INITAL P ✓ Notes: Initial MITIA as per PTD # 219-110 ' 6C4,t% ?s4119 Thursday, November 14, 2019 Page I of I 2191 10 1 > 0 WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. October 18, 2019 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 1G-103 Run Date: 9/12/2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1G-103 Digital Data in LAS format,Digital Data in XLSX format I CD Rom 50-029-20824-01 RECEIVED OCT 2 3 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: Signed: BAI-U R � PRINT BAT GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 1G-103 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patri�bakerhuches com STATUS Final COMPANY 21 9 1 10 3 129 1 DISTRIBUTION LIST Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (WNS Petroleum Technician) 700 G Street, Anchorage, Alaska 99510 to acknowledge receipt of this data. LOG TYPE RES LOG DATE September 7, 2019 TODAYS DATE October 2, 2019 Revision Replacement: No Details: ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V f:OA, PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Giassmakcr & Peggy O'Neill 900 E. Benson Blvd. Anchorage. Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 FTxonMobil,Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 Rev. Requested by: --- FIELD I FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, I SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES 1# OF COPIES # OF COPIES 4 J; 4 4 4 4 State of Alaska - AOGCC 1 1 Attn: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5, DNR - Division of Oil & Gas xxx Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 on all material deliver 6' BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25AM 20A 025.110 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.: 9/11/2019 14. Permit to Drill Number/ Sundry: 219-110 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 912/2019 15. API Number: 50-029-20824-01-00 ' 4a. Location of Well (Governmental Section): Surface: 4151' FNL, 264' FWL, Sec 29, T12N, R10E, UM Top of Productive Interval: 4082' FNL, 3745" FWL, Sec 30, T12N, Fit 0E, UM Total Depth: 2156' FNL, 3192' FWL, Sec 19, T12N, R10E, UM 8. Date TO Reached: 9/612019 16. Well Name and Number: KRU 1G-103 ' 9. Ref Elevations: KB:89.5 GL: 56 • BF: 17. Field I Pool(s): Kuparuk River Field/West Salk Oil Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25640, AOL 25635 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 640036 y- 5981775 - Zone- 4 - TPI: x- 638661 y- 5981837 Zone- 4 Total Depth: x- 538074 y- 5989039 Zone- 4 11. Total Depth MDlrVD: • 11960/3448 - 19. DNR Approval Number: LONS 83.25 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1466/1460 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 1 NIA (ft MSL) 1 1 21. Re-drill/Lateral Top Window MD/TVD: 3808/3365 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 30 106 30 108 24 325sx AS II 103/4 45.5 K-55 29 2303 29 2216 13112 1400sx AS III, 250sx AS 1 7 26 K-55 27 8464 27 6929 83/4 900sx Class G, 250 sx AS 1 3 112 9.2 L-80 3791 3967 3353 3443 41/4 Solid Liner 27/8 6.5 L-80 3967 11960 3443 3446 41/4 Solid/ Slotted Liner 24. Open to production or injection? Yes ❑� No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SLOTTED LINER@: 5690-6525 MD and 33943382 TVD ..... 9/7/2019 COMPLETION 7079-7529 MD and 3394-3414 TVD..... 917/2019 7623-8640 MD and 3416-3444 TVD..... 917/2019 QA7E 8730-9746 MD and 3449-3449 TVD..... 9/7/2019 ZO/ 9837-10849 MD and 3448-3447 TVD..... 917/2019 VE. IFIED 10937-11959 MD and 34473447 TVD..... 9/7/2019 _. 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 41/2 3633 N/A ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was Was hydraulic fracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 9/20/2019 Method of Operation (Flowing, gas lift, etc.): FLOWING Date of Test: 9/24/2019 Hours Tested: 7.6hrs Production for ITest Period Oil -Bbl: 92.8 Gas -MCF: 7 Water -Bbl: 3.4 Choke Size: 80beans Gas -Oil Ratio: 76 Flow Tubing Press. 191 Si Casino Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: 22 Water -Bbl: 1 11 OF Gravity -API (corr): 19,11 Form 10-407 Revised 5/2017 VM 1,912311 -7 CONTINUED ON PAGE 2RBDMS N`'"' OCT 1 Submit ORIGINIAL only i©///� 11019 »./i 28. CORE DATA Conventional Core(s): Yes ❑ No 21 * Sidewall Cores: Yes ❑ No [Z , 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 1466 1460 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 3808 3365 information, including reports, per 20 AAC 25.071. Formation @ TPI -West Salk D TD 11960 3448 Formation at total de the West Salk 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, productionpaleontoloolcal report. or well test results oer 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 Contact Phone: 265-6218 Signature: Date: INS RUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 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 1G-703 Proposed CTD Schematic 1 Arctic Pack cement '2100'-2500' via GBL 10- 3-82 (RA tracer) CTD KOP 3808'MD Vop--- 16" 65# H40 shoe 108' MD 2303' Top of good quality cement behind the 7" at `7380'(CBL of 8-21-84) 1G-103 TD: 11,960'MD 3-12" solid hnerw/sealbore deployment sleeve 3799-3967' 2-7/B" solid Nner 3967'5690', 5626'-7079' 2-7/9" slotted ]mer 56996526', 7079'-11960' �..����fL KUP INJ WELLNAME iG-03 WELLBORE 1G-03 corm ftillip5 Well Attribute Max Angle TD F..Ia Nem. WeIIMre APUUWI We111-reseem. Ice l°I M0111. Act Blm(XKB) Alaska, Inc,KI IPARI IK PIVFRIINII SnnJP)nA)4M fi52 iSnn QU 8.4890 1G03. m4ked. 11 Ga aM Last Tag VarMNvimtrm4c laclul) Annolalion pepin lane) 1 EM Oete WNIMre WatMM By ............. MINGERleafil------- __. Last Tag IRKS I6.GIG3012019Jr.., jTamaj Last Rev Reason An"Gooden End Data Wersme Lost Matl By Rev Reason Set Liner Top Packer I r1122019 1G-03 I.me Casing Strings Casing oeunpnon CD(n) m(n)Tap 01KB) fiat Depth (nKB) set Depth lrvDl....Alen 1...Grade Top ThreadCONDUCTOR 16 15.25 300 108.0 108.0 6500 H40 WELDED Casing Oesmlptpn OD lin) 10 (nl TDOIaKB) Set Depth mKB) Set Depth rog...,mLen (1-16dida Top Thread wxpwr9R: b.GlC59 SURFACE 10314 9.95 290 2,302.8 2,216.1 45.50 K-55 BTC Curve OMcn'the00(inl ID Jr.) T.,( I Ser Depth Sou" 6H DeptI BVIN...-Leh (1..Grame Top Thread PRODUCTION ] 628 27.5 8,463.8 69268 2600 K-55 BTC Tubing Strings 6URFACE:a0.3.aSB� Tohad DeSGred" 6 our.Ma... ID ge) To,(1 SN"Par or SN Depth DGIN) I.. onedX) Grade Top Connemon 45 HYD 503 4JQ 3.96 24.5 3,6333 32383 1275 L-80 HYD 503 GASUFT, testa COMPLETION Completion Details TOP From) Top Incl Nominal GAS UFT: 35873 Top TrKO) (WMR IT It.. DhW Com IG on) 24.5 24.5 0.0] HANGER Hanger FMC Gen IV ] III6E x 412' VAM FOL BXP 3958 LOCATOR: Sena 3,6230 3,2309 4467 LOCATOR Baker locator 3980 SE4L ASSY. 3Se7 3,6237 32314 4465 SEALASSY Baker sea) 9ssembl 1off n o 3.980 TusAna Oncripdan slritlg Me.., ID IIn) Top IXKB) Be10ep111(R. SN OepN jIVD)1_. WIpCm) Grade lap CDnnedion PACKER; 3645 45"SCAB LINER AL2 399 3,624.] 3,951.3 3.468.4 12.60 L-80 BTC Completion Details roplrvD) TOPlnm Nammm lop lttxa) Ircxe) 1°) .me- Co. m0n1 MPPIE:3.6]55 (PERF; 364 WAMO cwrw4 aPonn: Sake o MIB S- 36247 3232.1 44.63 PER Baker 4112 x]" 2RH Liner Setting Sieve 4.190 3,6,19.6 3,249,9 44.03 PACKER Baker 4 TIT x]" FP S3 Packer VT Pin xlEIT Pin 3.920 TANDEM WEDGE: 31159 3,675.5 3,260.6 4374 NIPPLE X Nipple HES 3813" BTCM SIR 3813 NOx E RETRIEVAMUSER TOP PACKER: 3reld 0 a 3,]]68 3,342.5 42.93 NoMern Solutions 4-12'Tandem Wedge 3958 WEDGE 7 5.8 3.356.3 42.93 NIPPLE X Nipple 4-12" x 3.013" BTCM BxP 3.813 xexR 3,]a5e 3,366.5 4310 17=1i NoMem Solutions 4-12" Tandem Wedge 3,958 WmPSTOLK3, W5,0 UNER3]99.au,9mp WEDGE 0.9 3,3]4] 43.30 NIPPLE %Nipple 412'x3813"BTCM BxP 3.813 TANDRIMIMEDGE,plai 3,81AL2 3,4060 43.96 LANOIN 4IQ" Landing Collor 3.930 xiwK ASSFA1my; 3,8$10 COLLAR NIPPLE3," ; 96 7,467.2 4445 1 FLOAT SHOE I Float sBce BTCM 0000 Tubhp Dnacriedon johing, Me...IDlin) TopIKKB) SN DeM 6S.I., DegM1 IDDII-likepbre Grade Topcennectbn I,wDlxG cotux; 3e64x . TUBING LEFT IN HOLE 3112 299 4,800.1] ].7392 6,3084 920 J-55 BTCA8M00 .SHOE: 394.6 Completion Details LISP; Top Drop (') p) Top Incl Nominal Top g KB) (t -) Item Des Cam ID hom 7,340.3 5.9746 33.33 PER BAKER PER 4250 JETCOT, 48119 ], 547 5,966.6 33.32 PACKER BAKER HBPACKER 2.890 c.r.,e Pke; e,mzoMrS Promam, Caere, ch-S.,]A 6,1076 3283 BLAST JTS BLAST JOINTS (OAC=704') 3.000 6.ma.Dmm CEMENT Remusa;),1PoA0 )J ,1 62925 33.43 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2985 Leeam Pei 72ts MB 7) 9 33.43 PACKER BAKER FB -1 PACKER 6000 GAILIFT 7,anda ]72.9 6.295] 33.44 SHE BAKER 8040 SEAL BORE EXTENSION 400 ],] .9 3. 4 NIPPLE CAMCO D NIPPLE NO GO 27 CAR 60[ ],3156],31]0 77384 6,307.8 33.48 SOS CAM OSHEAR OUT UB, ELMD TTL ]] 6buling FPR Fon 3015 051141200] Peaz3nn3 Ogler In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top ri Top lrwl PAcKER:]3sa.] Tap IKKBI Begin ('1 Das coal Run Dare ID(inl 3,821.0 3,37 7 4 . el ac lawt masseur y or Whipstock 81512019 0000 ASSEMBLY OAL. GMUFT;],39}9 3,958.5 3,4]3.5 44.48 CIBP Bridge Plug - Permanent 642019 0.000 GPB UFTp,4610 4,800.0 4,035.6 4570 JET CUT Jet u1 W 19 0.000 7,260.0 5,90].8 33.7 7ffMTN WEATHERFORD 35"CEMENT RETAINER 51242019 000 IPERF)495,13-],Exa-h RETAINER 7718.0 6,2907 33.43 CIBP WEATHERFORD 3112" CIBP OAL IMAX OD 2]5" 3012019 0. Perforations & Slots I.I.F.].5190.].%3.9 Shot men Taatm (Top) Iaam GAs uFry,eral TOP IrcKaI atm (1118) IaKe) IxKBI Unkedzane Dam 1 TYPe Com dom) 3,669.0 3,826.0 3,263.9 3,3784 61412019 120 (PERF 73150 ],31)0 5,953.4 5,955.1 4/92019 40 CMT SOZ'Tubing Pune deg Clap, 7,1159 pbaung 4spL 7,495.0 ],5250 6.104.1 6.129.3 C3, 1G-03 W511984 120 IPEKF sEALA65Y;77211 PACKER7 ', ,7106T139 7,540.0 7,563.0 61419 6161.2 C -1,1G-03 812511984 120 [PERF 6eE) 7,772.0 7,825.0 6,3358 6,379.9 AA A -31G-03 W2511984 12.0 [PERF Cement Squeezes i.RT"E) Bun SuGg IMFPK) (IRS) BM(NDI DIKE) Des Slav Dale Co. NIPPLE: ]]928 Sw:T]3a4 ],261.5 ]]180 5,908.8 69.7 CEMENT PLUG 52412019 16 EELS OF 15.8 PPG CCA$ GCEMENT BELOW RETAINER INTO C SAND SELECTIVE 6,6820 ],260.0 5,441.4 5,9076 CEMENT PLUG 5242019 LAVED IN 5 BELS 15.8 PPG CLASS G CEMENT ABOVERETAINER. CONTAMINATED DOWN TO ESTIMATED TOC OF 6682' IPERF;7.772.0Lo359-h 6,854.0 ],354.0 5,5765 5,986.0 CEMENT PLUG 512412019 14 BBLS OF1 8 PPG CLASS G CEMENT CIRCULATED UP IA THRU TUBING PUNCHES 36690 7.NED 3,263.9 3,3]84 EMENT 61512019 9ueezed in 15.8 PPG class G Cement wile Archer SQUEEZE Stronghold Barticade too. PRDDUCRCNI31r5d,4639� ConocoPhillips KUP INJ WELLNAME 1G-03 WELLBORE 1G-03 Alaska. Inc. �'"" 1Go3nn1/A+c 113rm PM Mandrel Inserts v.�emal+n+Belece.p sl e• ....................... XPNGEfl:N5...... .............. Yn N top RO{B) TW (TVD] IRK.) MaFa Mosel 008n) fiery Vn- Type IakM1 PYrL SRe TRO Run Type (in) (pa8 qYn Datr Com 1 $66J2 2,5106 Camco KBG2 1 INJ GLV BK 0.188 141).0 )1 25]2019 2 3.596.3 3,212.0 Camco KBG-2 1 INJ OV BK 0313 0.0 )]2512019 Notes: General & Safety EdGh Annodmn 0272003 NOTE'.E-LINE FOUND C -SAND LEAK@7579' LGNouc)oR:3ouUe.0 3182(119 NOT R KEN ONTRSSS -� AIN PSI ON CONTROL LINE WHEN NO SLEEVE IS INSTALLED 7112019 NOTE: View Shcemak w/Alaska SchemMicl .0 6URFRLE; ID43,i72a� GO6 LIFT, 2W" GF.S LIFT.3.5933 LOCATOR;3.WO 6Eµ A55Y; 3.5337 POR: 3,W7 PACKER, 3.519.6 MAPLE: a.M5 1 (PERF; 3.6090a.6A0 \ S TANOEMWEDGE3T]BA NON RETRIEWBLE LINER TOPPACKER3.TES.O a NIPPLE,3hG.a "'PSTOCK: 347.0 UNERI3Tm.&11.9AD TANOEM WEDGR 3�8 MLCCKASSEmem 3,8210 NIPPLE; 3.BA19 i UWDING GOL.; 3. 1.2 FLDAT SHOE', 3916.9 CIBP:3.45B.5 JET OUT 4800 GimIPIU- MB n RelwBcnCrory QIL0. CEMENT R ETMNFR., EEO CaneN PAq; ],161SKKB s GF6 u" 7.298.3 CMT6O2, 7,31567.3170 POR; T.3 PACKER;].X 7 GL6 LIFT, 7.=.0 GAS UIT;].L51A IPERR 7.KEfi47, 6250 IPERF',].SIOWMOq 546 UFT:7.6]41 CIBP;7.7180 SFAL..Y. 1.1 PACKER', ],TAG $BE',]7219 NIPPLE),]32.9 6M; ],7360 (PERF; TMGO7.MO� PUP.ION: 9.59,I61,9� KUP PROD WELLNAME 113-03 WELLBORE 113-103 COnocoPhillips Well Attrihuh Max Angie TD frr 1� FI¢q Nam¢ WeIemare AWUWI WellEommaWS Ic") .010, qct Btm(RNBI Alaska.I VFR IINIT 50OdneDR>dD1 PROD d8955/ 11,960.6 1G103.101,20192xt.3o PM Last Tag Vmkvae mwvc (aced Annaba- OeVh(nKB) End Data WNlbm LasIMW BV Last Tap'. 1G-103 jennalt .................... HANDER, 24 5.... .... Last Rev Reason Annopeon End Do* WeIIWre Last Mad By Rev Reason'. CTD SIDETRACK 913012019 1G-103 jennalt Casing Strings wslnv oas¢dvnan oelin) m(in) rav (`N set Depth darld eH Depth DVD)...MLen (L.. Omae Tap Thread LINER 27/8 244 3]90.6 11,960.0 3J47.6 6.50 L80 H533 I Liner Details Nominal to Tov(OKBI Too FT ld Inrce) Top Incl (•) he Des core (in) 3790.6 3,352.5 42.93 SBR Deployment Seel witk b' seal bore 2.990 —37976 3,357.6 42.93 BLANK -1 ", p, L , wed0e H511 Solid Liner ( jnts 2.990 CONI entered as War length) 3,966.5 3,4426 77.73 R VER- XO 110-24ME 2.391 REDUCING 3,9672 3,442.8 7787 BLANK 2-718',6.5d,L-00, HSM, Blank line, (never faults) 2.441 85250 3,382.2 9051 DITFLUMMI Dissolvable bull mole - note,L A1. 'with 0.87 2375 wRFACR 2e.,.a—. SLEEVE swallowed in OCLL 8,5269 3,382.2 90.48 BLANK -I", ,L 0. H533,Blah iner - cover asholon 44 drilled out at zone) ODS LIFT', 2,e833 7,529.1 3,413.9 89,36 BLANK -277711L-80,H5 ,Blank liner 2441 8,640.1 3,444.0 85.91 BLANK 2-741", 6.5p, L-80, H533, Blank liner 2.441 9,7455 3,448.3 89.09 BLANK 2-918%SSIL L-80, H533, Blank liner 2441 9,035.5 3,448.2 91.07 DEPLOYMENT OR Permanent CLL 2375 GAB LET:3%ea SLEEVE 10,848.7 3446.8 89.39 BLANK 2441 LOCATOR: 3.643.0 Other In Hole (Wireline retrievahle Plugs, valves, Pumps, fish, etc.) Top(OKa) Top FWD) MB) Taplml P) Des Co. Name. to (in) sEALAssv: 39]3T FEE 3M7 3,7115.0 3,348.4 42.93 NON Ba r Flo -Guardac r w a ern Solutions 91122019 2310 RETRIEVABLE PTSA. OAL9.84'Max OD3.79' LINER TOP PACKER: 3.6aas PACKER 3,8050 3,363.1 43.02 WHIPSTOCK 0.112"NonM1ern Solutions Inner WeOge. Sel00e8 H5. w/ 81612019 1.000 We PIP lags. NIPPLIi,siol fi Perforations & Slots aM1at IPERF;3, 0...Bm.O Tap(NO) Btm(TVD) pndsM Cerirrts4ura; 3,MDM Tonnage Ideltli Me) (MEN Linked IDas Oak ) Typ Co. TAHDEMWEDGFa77ea 5,690.0 6,525.0 3,394.1 3,382.2 VISOR) SLOTS ],0]9.0 7,529.0 3,393.6 3,4135 W12019 SLOTS ■ 7, 23.0 8,640.0 3416.0 7444.0 901 019 LOTS NDN RETRIEVABLEMNER TOPP II(ER,3.'/85.0 ■ 8,]30.0 9]46.0 3.448.6 3,448.4 9RI2019 SLOTS 9,837.0 10,849.0 3,448.1 3,446.8 9012019 SLOTS 3 fi 10,937,0 11,959.0 3,447.1 3,447.6 9012019 SLOTS NIPPLE,ema Notes: General& Safety End nate Annotaron }\, 913012019 NOTE. View Sell ... TO vel Alaska SChetnBik10.0 PRODUCTION.27"..0318 >_ WHIPSTOCK30050 _ SLOTS', SrikeDes5.0� L SLOTS, 7.0nm eannA0� $LOiS; 7.afl.08.eM.0� SLOTS;873000,749,0— 1 1 aLOT5; 3.691.0108190 I f SLOTS: 1OW70II.M.0� AMER. SE90 -11..0 Operations Summary (with Timelog Depths) 1G-103 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Start Time EM Time our hr ( ) Phase Op Code Activity Code Time P-T-% Operation (floe) EM Dept (frKa) 9/1/2019 9/1/2019 0.40 MIRU MOVE RURD P Peak dg move crew on location, 0.0 0.0 00:00 00:24 PJSM, 9/1/2019 9/1/2019 1.10 MIRU MOVE RURD P Pull service mod away from sub and 0.0 0.0 00:24 01:30 well row, stage 9/1/2019 9/1/2019 0.50 MIRU MOVE MOB P Pull Sub away from well and move to 0.0 0.0 01:30 02:00 1G-103 9/1/2019 9/1/2019 2.30 MIRU MOVE MOB P Spot sub over well, set mats, call for 0.0 0.0 02:00 04:18 1 1 1 scaffolding crew. 9/1/2019 9/1/2019 1.20 MIRU MOVE MOB P Spot service mod next to Sub 0.0 0.0 04:18 05:30 9/1/2019 9/112019 3.00 MIRU MOVE RURD P Begin RU check list, lower stairs, 0.0 0.0 05:30 08:30 secure landings, MU tiger-tank hard- line, MU PUTZ, bring water & steam on-line 9/1/2019 9/1/2019 2.00 MIRU WHDBOP NUND P Continue RU, grease tree valves, 0.0 0.0 08:30 10:30 grease CDR3 swab & tangos valves Inspect reel spokes for cracks, observe crack on weld of previously repaired crack, grind weld, pre-heat, re-weld faulty weld Nipple up stack - accept rig 911 10:30 AM 9/1/2019 9/1/2019 2.00 MIRU WHDBOP RURD P Continue RU, swap variable rams 0.0 0.0 10:30 12:30 (damaged VBR's found during boro- scope of stack on 1 G-116), get on hi- line, test gas alarms, replace pump fluid end in SIMOPS 9/1/2019 9/1/2019 2.50 MIRU WHDBOP RURD P Complete RU, clear dg floor, MU lest 0.0 0.0 12:30 15:00 joint, grease Romeo & Bravo valves, cycle VBR's on 3.5", open & inspect with boro-scope, look good, install night cap, fluid pack stack, perform shell test 9/1/2019 91112019 0.90 MIRU WHDBOP BOPE P Test BOP'S (witness waived by Matt 0.0 0.0 15:00 15:54 Herrera of the AOGCC), 250 psi low / 2500 psi high Difficulty holding pressure on test 1, cycle swab 2, 9/1/2019 9/1/2019 2.10 MIRU WHDBOP BOPE T Difficulty holding pressure on test 2, 0.0 0.0 15:54 18:00 cycle blind shears, no good, dose bleader valves on night-cap, no good, close C3, C7, C11, no good, continue to trouble-shoot 9/1/2019 9/1/2019 4.00 MIRU WHDBOP BOPE P On test 6, good, double check RKB's, 0.0 0.0 18:00 22:00 move forward w checklist, draw down complete @ 12:20, pull safety joint, prep for inner reel. 9/112019 9/112019 1.00 MIRU WHDBOP BOPE P Skid cart, stab injector, test inner reel 0.0 0.0 22:00 23:00 iron, pack offs, good. 9/1/2019 912/2019 1.00 MIRU WHDBOP PRTS P Unstab, PU ODS PDL, Flood and PT 0.0 0.0 23:00 00:00 PDL+ tiger tank line. 9/2/2019 9/2/2019 1.40 MIRU WHDBOP PRTS P Complete PT of ODS PDL and TT line, 0.0 0.0 00:00 01:24 open well to 100 psi. Bleed off to tiger tank, monitor for flow - diesel and small amount of gas flow monitor, no change, decision to PD. 9/2/2019 9/2/2019 1.80 PROD1 WHPST PULD P PJSM, unstab PDL, PU BHA#1, 0.0 80.8 01:24 03:12 window milling assembly, Tag up, set counters 9/2/2019 9/212019 0.60 PRODi WHPST TRIP P RIH 80.8 3,349.0 03:12 03:48 1 Page 1111 ReportPrinted: 9/2412019 Operations Summary (with Timelog Depths) 1G-103 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time Dur(hn Phase Op Code Activity Code Time P -T -X Operation Start Depth (fiKB) End Depth (11<13) 9/2/2019 9/2/2019 0.20 PROD1 WHPST DLOG P Tie into Ugnu A-3' correction 3,349.0 3,387.0 03:48 0400 9/2/2019 9/2/2019 0.40 PROD? WHPST TRIP P Open EDC, RIH, dry tag TOWS @ 3,387.0 3,808.0 04:00 0424 3808.6 W 4 k WOB, PU Wt 35 k lbs 9/2/2019 9/2/2019 1.90 PROD1 WHPST DISP P PUH while flushing well with seawater. 3,808.0 3,808.0 04:24 0618 Turn well over to milling fluid. 9/2/2019 9/2/2019 3.00 PROD1 WHPST WPST P Begin milling window at 3808.1', 3,808.1 3,810.0 06:18 0918 oriented ITS, FS = 556 psi @ 2.8 bpm, dp = 799 psi, pump = 2324 psi, vibrations at 3 (yellow), avg ROP = 0.63 fph 9/2/2019 9/2/2019 3.00 PROD1 WHPST WPST P Continue milling window from 3810', 3,810.0 3,812.3 0918 1218 CWT = 11.43K, pump = 2271 psi, dp = 768 psi, vibrations drop to 2's (green), avg ROP = 0.77 fph 9/2/2019 9/2/2019 3.00 PRODt WHPST WPST P Milling from 3812.3', CWT = 9K, pump 3,812.3 3,813.4 12:18 1518 = 2286 psi, tlp = 720 psi, vibrations down to 1's (green), avg ROP = 0.37 fph 9/2/2019 9/2/2019 2.90 PROD1 WHPST WPST P Milling from 3813.4', CWT= 10.7K, 3,813.4 3,816.0 1518 1812 1 pump = 2246 psi, dp = 693 psi 9/2/2019 9/2/2019 1.40 PROD1 WHPST WPST P Exit casing, time drill 3', drill rat hole to 3,816.0 3,831.0 18:12 19:36 TD of 3831. High initial ROPS in rat hole, 160 ft/hr no to low WOB. 9/2/2019 9/2/2019 1.90 PROD1 WHPST REAM P Performed reaming passes @ 180, 3,831.0 3,712.0 19:36 21:30 30L and 30 right for as drilled. 9/2/2019 9/2/2019 0.10 PROD1 WHPST WPST P Pump 5x5 sweep, dry drift clean, 3,712.0 3,762.0 21:30 21:36 PUH, attempt of open EDC a couple times, diff not dropping. 9/2/2019 9/2/2019 0.80 PROD1 WHPST TRIP P POOH pumping 2.78 bpm, decent 3,762.0 84.8 21:36 2224 metal unload at the shaker, quite a few flakes and a couple small pieces of ubber. 9/2/2019 9/2/2019 1.40 PROD1 WHPST PULD P Park shallow, open up at the stack for 84.8 0.0 22:24 2348 flow test, PJSM, flow test good, LD BHA#1 over a dead well, inspect pipe - good. Mill no go 3.79" Reamer no go 3.80" 9/2/2019 9/3/2019 0.20 PROD1 WHPST CIRC P MU nozzle, stab injector, jet stack. 0.0 0.0 23:48 00:00 9/3/2019 9/3/2019 0.20 PROD1 WHPST CIRC P Complete jetting the stack. 0.0 0.0 00:00 00:12 9/3/2019 9/3/2019 1.30 PROD? DRILL PULD P PU BHA#2, build drilling assembly, 2 0.0 82.7 00:12 01:30 °AKO motor with RR Bake P104 bi center bit, 9/3/2019 9/3/2019 0.80 PROD1 DRILL TRIP P RIH 82.7 3,349.0 01:30 02:18 9/3/2019 9/3/2019 0.10 PROD1 DRILL DLOG P Tie into the Ugnu A for a-3.5' 3,349.0 3,368.0 02:18 02:24 correction 9/3/2019 9/3/2019 0.30 PRODt DRILL TRIP P Contiune to RIH, PU Wt @ 3729'32 k 3,368.0 3,831.0 02:24 02:42 lbs Page 2111 Report Printed: 9/24/2019 Operations Summary (with Timelog Depths) 1G-103 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Depth start Time End Time Dur(ho Phew Op Code A vfty Code Time P-T-X Operation (ftKa) End Depth(W) 9/3/2019 9/3/2019 2.40 PROD1 DRILL DRLG P CT 2000 psi @ 2.76 bpm in and 2.75 3,831.0 4,020.0 02:42 05:06 bpm out, free spin diff 568 psi, RIH Wt 12.4 k lbs, OBD, CT Wt 9.36 k lbs, WOB .3 - 3 k lbs, ROP 20 -270 ft/hr PU Wt 34 k Ibis @ 3935'- should be in the B but drilling slowlyy with high WOB, BHA wiper, RBIH, CT 2145 psi at 2.77 bpm in and 2.80 bpm out, WH 42 psi, Free spin diff 612 psi, annular pressure 1866 psi, BOBD, CT Wt 13.8 k lbs, WOB 0.19 k Itis, 200 ft/hr, 3949', stall - PU 33 k lbs. 9/3/2019 9/3/2019 1.40 FROM DRILL TRIP P PU 28 k lbs, POOH 3,831.0 78.0 05:06 06:30 9/3/2019 9/3/2019 1.00 FROM DRILL PULD P PJSM, PUD BHA #2, Lock out & 78.0 0.0 06:30 07:30 inspect reel, good, bit came out a 1-1 9/3/2019 9/3/2019 1.30 PROD! DRILL PULD P PD BHA#3 Lateral Assembly (NOV 0.0 87.0 07:30 08:48 agitator, 0.7° AKO motor, & new HYC B10 bit), slide in cart, check pack-offs, Mu to coil, tag up, set counters 9/3/2019 9/3/2019 0.70 FROM DRILL TRIP P RIH w/ BHA #3 87.0 3,355.0 08:48 09:30 Shallow test agitator: MD = 533', 2.8 bpm, pump = 2781, rip = 1367 psi, visibily vibratiing at surface 9/312019 9/3/2019 0.10 FROM DRILL DLOG P Log formation for -3.5' correction 3,355.0 3,372.0 09:30 09:36 9/3/2019 9/3/2019 0.50 FROM DRILL TRIP P Continue RIH, PUW at window= 34K, 3,372.0 4,025.0 09:36 10:06 clean through window, log RA at 3814.5' TOWS = 3807.5', RA= 3814.5', BOW = 3815.5' 9/3/2019 9/3/2019 0.30 FROM DRILL DRLG P Drilling, FS = 1353 psi @ 2.8 bpm, 4,025.0 4,059.0 10:06 10:24 CWT = 10.8K, WOB = 2.4K, pump = 2981 psi, annular = 1887 psi, dp = 1441 psi, IA = 0 pis, OA = 11 psi, 10.5 ppg at window (choke wide open) 9/3/2019 9/3/2019 0.70 FROM DRILL WAIT T PU off bottom (tool shut off), trouble- 4,059.0 4,059.0 10:24 11:06 shoot, re-boot MWD software, trouble- shoot a-line, believe bad tools 9/3/2019 9/3/2019 1.00 FROM DRILL TRIP T POOH for lost COMMS to tools, pre- 4,059.0 86.0 11:06 12:06 load DS PDL 9/3/2019 9/3/2019 0.50 FROM DRILL WAIT T PJSM, pop off injector, test tools at 86.0 86.0 12:06 12:36 surface, tools bad 9/3/2019 9/3/2019 0.70 PRODi DRILL PULD T PUD BHA#3 86.0 0.0 12:36 13:18 9/3/2019 9/3/2019 1.50 FROM DRILL PULD T PD BHA #4 Lateral Assy#2 (new 0.0 86.0 13:18 14:48 MWD tools), slide in cart, test BHI head, bad test, resolve issue, MU to coil, tag up, set counters 9/3/2019 9/3/2019 0.60 FROM DRILL TRIP T RIH w/ BHA #4, close EDC, surface 86.0 3,355.0 14:48 15:24 test agitator, good 9/3/2019 9/3/2019 0.10 FROM DRILL DLOG T Log formation for -3.5' correction 3,355.0 3,374.0 15:24 15:30 9/3/2019 9/3/2019 0.30 FROM DRILL TRIP T Continue RIH, PUW at window = 32K 3,374.0 4,059.0 15:30 15:48 9/3/2019 9/3/2019 1.60 PROD1 DRILL DRLG P Drilling, FS = 1309 psi @ 2.8 bpm, 4,059.0 4,460.0 15:48 17:24 CWT = 12.6K, annular = 1911 psi, pump = 3064 psi, 10.6 ppg at wiindow, 9/3/2019 9/3/2019 0.20 PROD1 DRILL WPRT P Wiper up-hole, PUW =41K 4,460.0 3,858.0 17:24 17:36 Page 3/11 Report Printed: 9124/2019 Operations Summary (with Timelog Depths) 1G-103 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sten Depm Start Time End Tim. Dur (hr) Phase Op Code Activity Code Tune P -T -X Operation (ftKB) End Depth (MB) 9/3/2019 9/3/2019 0.20 PROM DRILL WPRT P Wiper in-hole, RIW = 12K 3,858.0 4,460.0 17:36 17:48 9/3/2019 9/3/2019 2.10 PROM DRILL DRLG P Drilling, FS = 1262 psi @ 2.8 bpm, 4,460.0 4,860.0 1748 19:54 CWT = 9.61K, annular = 1961 psi, pump = 3042 psi, stall at 4782', PUW = 58K, followed by a lower ROP interval, pump 5x5 sweeps as required 9/3/2019 9/3/2019 0.30 PRODt DRILL WPRT P Wiper up -hole, PUW = 39K 4,860.0 4,060.0 19:54 2012 9/3/2019 9/3/2019 0.40 PROD1 DRILL WPRT P Wiper in-hole, RIW = 13K 4,060.0 4,860.0 20:12 20:36 9/3/2019 9/3/2019 1.70 PROD? DRILL DRLG P Drilling, FS = 1350 psi @ 2.8 bpm, 4,860.0 5,260.0 20:36 22:18 CWT = 8K, annular = 1956 psi, pump = 3192 psi, 10.7 ppg at window (choke wide open), pump sweeps as required 9/3/2019 9/3/2019 0.60 PRODt DRILL WPRT P Wiper to window, PUW =37K 5,260.0 3,822.0 22:18 22:54 9/3/2019 9/32019 0.10 PROD1 DRILL DLOG P Log RA tag for+2.5' correction 3,822.0 3,852.0 22:54 23:00 9/3/2019 9/32019 0.60 PROD1 DRILL WPRT P Wiper in-hole, RIW = 10.5K 3,852.0 5,260.0 23:00 23:36 9/3/2019 9/412019 0.40 PROD1 DRILL DRLG P Drilling, FS = 1324 psi @ 2.8 bpm, 5,260.0 5,356.0 23:36 00:00 CWT = 7K, annular = 1963 psi, pump = 3271 psi, dip = 1611 psi 9/4/2019 9/4/2019 2.30 PROM DRILL DRLG P Drilling ahead, CT 3162 psi @ 2.77 5,356.0 5,800.0 0000 0218 bpm in and 2.74 bpm out, BHP 2015 psi, WH 45 psi - 10.88 ppg @ the window. CT Wt 10 k lbs, WOB 0.66, ROP - 270 ft/hr 5356' PU Wt 34 k 5427' PU Wt 33 k Average ROP of interval drilled 193 Mr. 9/4/2019 9/42019 0.30 PROD1 DRILL WPRT P PU on wiper trip #1 - PU Wt 33 k Itis. 5,800.0 5,012.0 02:18 02:36 drug - 2k WOB @ 5,584' 9/4/2019 9/42019 0.30 PROD1 DRILL WPRT P RBIH 5,012.0 5,800.0 02:36 02:54 Saw 1 k WOB spikes from 5,546'- 5,595. 1.8 bbls of cuttings returned on the trip 9/4/2019 9/4/2019 2.30 PROM DRILL DRLG P RIH Wt 9.37 k Itis, CT 3129 psi @ 5,800.0 6,350.0 02:54 05:12 2.78 bpm in and 2.76 bpm out, WH 44 psi on a n open choke, BHP 2061 psi, 11.08 ppg @ the window, 11.7 ppg @ the bit. OBD, CT Wt 3.7 k Itis, WOB 3 k lbs 6076' PU Wt 39 k lbs - heavy vibrations on the restart, lower ROP's 6097' PU Wt 39 k lbs - Hitting hard spots - concretions Average ROP of interval drilled 239 fUhr. 9/4/2019 9/4/2019 0.25 PROD1 DRILL WPRT P PU on wiper trip #2 - PU Wt 39 k lbs 6,350.0 5,611.0 05:12 05:27 9/4/2019 9/4/2019 0.25 PROD1 DRILL WPRT P RBIH 5,611.0 6,350.0 05:27 05:42 1.2 bbls of cuttings returned on the trip 9/4/2019 9/42019 0.80 PROD1 DRILL DRLG P RIH Wt 7 k lbs, CT 3,104 psi @ 2.79 6,350.0 6,584.0 05:42 06:30 bpm in and 2.76 bpm out, WH 45 psi on a n open choke, BHP 2058 psi, OBD, CT Wt 7 k Itis, WOB 1 k Itis Average ROP of interval drilled 292.5 ft/hr. 9/4/2019 9/4/2019 0.30 PROD1 DRILL WPRT P PU Wt 37 k Ibs - Geo wiper, PUH to 6,584.0 6,584.0 06:30 06:46 6375', RBIH Page 4111 Report Printed: 9/24/2019 Uperations Summary (with Timelog Depths) T1 , IG -103 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stan Time I End Time Our(hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth(fiKB) 9/4/2019 9/4/2019 2.70 PROD1 DRILL DRLG P CT 3,220 psi @ 2.79 bpm in and 2.76 6,584.0 6,969.0 06:48 09:30 bpm out, Drill ahead, having trouble falling, cut pump rate to 2.5 bpm, target 4 k WOB, Swap to new mud, new mud at the bit 6,905'. 9/4/2019 9/4/2019 1.10 FROM DRILL WPRT P PU on wiper trip #3 - PU Wt 37 k lbs 6,969.0 3,830.0 09:30 10:36 9/4/2019 9/4/2019 0.20 FROM DRILL DLOG P Tie int the RA tag +3.5' correction 3,830.0 3,876.0 10:36 10:48 1 1 -2 K WOB @ 5594-5542' 9/4/2019 9/4/2019 1.00 FROM DRILL WPRT P RBIH - 5.2 bbls of cuttings returned 3,876.0 6,969.0 10:48 11:48 from the trip. 2-3 kWOB spike 5544-5595' 9/4/2019 9/4/2019 1.60 PROD1 DRILL DRLG P CT RIH Wt 7.6 k lbs, CT 2534 psi @ 6,969.0 7,299.0 1148 1324 2.8 bpm in and 2.96 bpm out, Free spin diff 1180 psi, WH 45 psi, Annular pressure 1853 psi, 10.0 ppg EMW @ the window, 10.6 ppg at the bit. OBD, Ct Wt 6 k lbs, WOB 1.4 k lbs. Average ROP of interval drilled 206 ft/hr. 9/4/2019 9/4/2019 0.80 PROD1 DRILL DRLG P CT weight stacked out, WOB static at 7,299.0 7,287.0 13:24 1412 2K, motor work fell of to free spin. Unable to pick up, worked pipe to 80 k with no success. Circulated bottoms u, MM out weight fell from 8.97 to 8.88 ppg. Lower pump rate toO.5 bpm, window ECD fell to 9.47 ppg and 9.836 ppg @ the bit. Squat CT to -8 k, PU @ 80 ft/min break over at 80 lbs. Pull free, 9/4/2019 9/4/2019 0.70 PROM DRILL WPRT P Pump 5x5 sweep and pull short wiper 7,287.0 7,299.0 14:12 14:54 #1 to above the west Salk C @ 6349', RBIH. 9/4/2019 9/4/2019 2.10 PRODt DRILL WPRT P CT 2593 psi @ 2.82 bpm in and 2.79 7,2%0 7,568.0 14:54 17:00 bpm out. Free spin 1172 psi, WH 44 psi, BHP 1914 psi - 10.1 ecd @ the window, 10.8 ppg at the bit. CT Wt 5 k lbs, WOK 1 k lbs Average ROP 128 of interval drilled ft/hr. 9/4/2019 9/4/2019 1.00 PROD1 DRILL DRLG P Continue Drilling ahead, 2.8 bpm at 7,568.0 7,700.0 17:00 18:00 3,177 psi, Diff=1,379 psi, WHP=48, BHP=1,893, IA=O, OA=15 9/4/2019 9/4/2019 0.45 FROM DRILL WPRT P Wiper up hole, PUW 45 k 7,700.0 6,918.0 18:00 18:27 9/4/2019 9/4/2019 0.30 FROM DRILL WPRT P Wipe back in hole (Clean) 6,918.0 7,700.0 18:27 18:45 9/4/2019 9/4/2019 2.00 FROM DRILL DRLG P BOBD, 2.8 bpm at 3,103 psi, 7,700.0 8,118.0 18:45 20:45 Diff -1,380, WHP=45, BHP=1,893, IA=O, OA= 15 9/4/2019 9/4/2019 1.50 PROD? DRILL WPRT P Wiper to the window, PUW 41 k, with 8,118.0 3,840.0 20:45 2215 sweep from TD and EOB, observed lk weight bobble 5,587'-5,537' " Note: MWO Density up to 9.26 ppg at peak/6.93 bbls of cuttings noted from WellWorc 9/4/2019 9/4/2019 0.15 FROM DRILL DLOG P Log RA marker (+9.5'), 3,840.0 3,847.0 22:15 22:24 9/4/2019 9/4/2019 1.30 FROM DRILL WPRT P Wiper back in hole, bobble seen 3k @ 3,847.0 8,118.0 22:24 23:42 1 1 1 1 1 6,388' w/not correct TF, RIW 3 k Page 5111 Report Printed: 9/24/2019 Operations Summary (with Timelog Depths) 1G-103 ... Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Time End Time Dur (hr) Phase Op Code Activity COW Time P -T -x Operation (ftKB) End Depth (eK8) 9/4/2019 9/5/2019 0.30 FROM DRILL DRLG P BOBD, 2.82 bpm at 2,811 psi, Diff 8,118.0 8,178.0 23:42 00:00 1,234 psi, WHP=46. BHP=1997, IA=O, OA=15 9/5/2019 9/5/2019 1.50 PROD1 DRILL DRLG P OBD, 2.82 bpm at 2,811 psi, Diff 1,234 8,178.0 8,510.0 00:00 01:30 psi, WHP=46. BHP=1997, IA=O, OA=15 9/5/2019 9/5/2019 0.40 FROM DRILL WPRT P Wiper to the window (Clean), 38 k 8,510.0 7,710.0 01:30 01:54 9/5/2019 915/2019 0.35 FROM DRILL WPRT P Wiper back in hole, RIW 7,710.0 8,510.0 01:54 02:15 9/5/2019 9/5/2019 0.25 PROD1 DRILL DRLG P OBD, 2.82 bpm at 2,811 psi, Diff 1,234 8,510.0 8,600.0 02:15 02:30 psi, WHP=46. BHP=1997, IA=O, OA=15 9/5/2019 9/5/2019 0.90 FROM DRILL DRLG P Drill ahead through concretion with 8,600.0 8,617.0 02:30 03:24 multiple clean PU's 38-44k 9/5/2019 915/2019 1.50 PROD1 DRILL DRLG P Continue drilling ahead, 2.8 bpm at 8,617.0 8,909.0 03:24 04:54 3,013 psi, Diff -1,384, WHP=41, BHP=2,038, IA=O, OA=13 9/5/2019 9/5/2019 0.30 FROM DRILL WPRT P PU Wt 37 k Ibs, PUH on wiper *2 8,909.0 8,109.0 04:54 05:12 915/2019 9/5/2019 0.50 FROM DRILL WPRT P RBIH 8,109.0 8,909.0 05:12 05:42 9/5/2019 9/5/2019 2.70 FROM DRILL DRLG P CT 2870 psi at 2.8 bpm in and 2.8 8,909.0 9,310.0 05:42 08:24 bpm out, Free spin 1229 psi, BHP 2058 psi, WH 41 psi, Pump 5 x 5 in anticipation of wiper. Average ROP over interval 148' 9/5/2019 9/5/2019 1.80 FROM DRILL WPRT P PU W 141 k lbs. PUH on long wiper, 9,310.0 3,830.0 08:24 10:12 bent motor oriented to drag low side. Saw same slight tug across fault #2 - 5584'-5543'to-1 k WOB 9/5/2019 9/5/2019 0.20 PROD1 DRILL DLOG P Log RA marker (+g'), 3,830.0 3,864.0 10:12 10:24 9/5/2019 915/2019 1.60 PRODt DRILL WPRT P Wiper back in hole, Fault #2 observe 1 3,864.0 9,310.0 10:24 12:00 -2 k WOB bobble 5,546-5,598' Increase RIH speed to 65 fl/min@ 6,747', taper off as we started to snub @ 9000- 9/512019 9/5/2019 1.10 FROM DRILL DRLG P Ct 3048 psi @ 2.77 bpm in and 2.73 9,310.0 9,557.0 12:00 13:06 bpm out, Free spin diff 1189, WH 144 psi 9 diverting mud outside to tiger tank for swap), IA 0, OA 15 psi, BHP 2189 psi, 11.1 ppg EMW Q the window and 12.21 ppg at the bit. Start new mud down the coil, New mud a the bit - 9360', OBD - CT Wt -3.4 k bs, WOB 0.9 k lbs ROP 224 R/hr. 9/5/2019 9/5/2019 2.40 PROM DRILL DRLG P PU Wt 41 k lbs - PU to acquire 9,557.0 9,960.0 13:06 1530 parameters with new mud all the way around Ct 2623 psi @ 2.79 bpm in and 2.79 bpm out, Free spin diff 1253 psi, WH 42 psi, Pull short 200' wiper and chase 5x5 sweeps, 9/5/2019 9/5/2019 0.40 FROM DRILL WPRT P PU W 145 k lbs. PUH on wiper #1 9,960.0 9,162.0 15:30 15:54 9/5/2019 1 9/512019 0.40 PROD1 DRILL WPRT P RBIH 9,162.0 9,960.0 15:54 16:18 I Page 6111 Report Printed: 9/24/2019 Operations Summary (with Timelog Depths) 1 G-103 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stag Depth ft oe Start Time End Time Dur (hr) Phase Op Code Actl ' Code My Time P-T- X Operation EM Depen (MB) 9/5/2019 9/5/2019 0.70 PROD1 DRILL DRLG P CT 2523 psi @ 2.6 bpm in and 2.6 9,960.0 10,071.0 16:18 17:00 bpm out, free spin diff 1118 psi, BHP 1989 psi 10.06 ppg EMW at the window, 11.1 ppg at the bit. OBD CT Wt-5 k lbs, WOB 0.7 9,988' mud aired up, free spin 930 pi, 9/5/2019 9/5/2019 1.00 FROM DRILL DRLG P OBD, 2.82 bpm at 2,734 psi, 10,071.0 10,150.0 17:00 1800 Diff-1,339 psi, WHP=39. BHP=1,982, IA=O, OA=15 9/5/2019 9/5/2019 2.50 PROD1 DRILL DRLG P OBD, 2.82 bpm at 2,851 psi, 10,150.0 10,520.0 18:00 2030 Diff-1,409 psi, WHP=39. BHP=1,996, IA=O, OA=15, Broke into faster drilling @ 10,430' 9/5/2019 9/5/2019 2.10 PROM DRILL WPRT P Wiper to the window, (Clean) 10,520.0 3,840.0 20:30 22:36 w/sweeps TD and EOB, PUW 44 k 9/5/2019 9/5/2019 0.20 PRODi DRILL DLOG P Log the RA marker (+7,5') 3,840.0 3,858.0 22:36 22:48 9/5/2019 9/6/2019 1.20 FROM DRILL WPRT P Wiper back in hole, RIW10 k 3,858.0 7,331.0 22:48 00:00 1 9/6/2019 9/6/2019 1.15 PROD? DRILL WPRT P Continue wiper in hole, RIW 2 k 7,331.0 10,520.0 00:00 01:09 ••• Note: observed weight bobble 9,993- 9/6/2019 9/6/2019 2.75 PROD1 DRILL DRLG P BOBD, 2.82 bpm at 3,862 psi, 10,520.0 10,920.0 01:09 03:54 Diff-1,212, WHP=90, BHP=2,084, IA=O, OA=15 9/6/2019 9/6/2019 0.45 PROD1 DRILL WPRT P Wiper up hole, PUW 53 k 10,920.0 10,060.0 03:54 04:21 9/62019 9/6/2019 0.40 PRODt DRILL WPRT P Wiper back in hole, RIW 10,060.0 10,920.0 04:21 04:45 9/6/2019 9/6/2019 5.70 PROD1 DRILL DRLG P BOBD, 2.82 bpm at psi, Diff-, WHP=, 10,920.0 11,645.0 04:45 10:27 BHP=, IA=O, OA=15 11089' PU 47 k lbs Swap to new mud system # 4. New mud at the bit 11,293'- Retired system 1933' drilled footage. PU to aquie new parameters after mud all the way around. CT 262 psi @ 2.79 bpm in and 2.79 bpm out, fre spin diff 1186 psi, BH pressure 2060 psi, WH 140 pis, IA 0, OA 14 psi. CT Wt -25 k lbs - Clean PU - 47 k Ibs, sticky 71 k lbs. Average ROP over 725' feet drilled is 127 ft/hr 9/6/2019 9/6/2019 0.30 PROD1 DRILL WPRT P Wiper up hole, PUW 49 k- wiper #2 11,645.0 10,845.0 10:27 1045 9/6/2019 9/6/2019 0.40 FROM DRILL WPRT P Wiper back in hole - 2 bbls cutting 10,845.0 11,645.0 10:45 11:09 returned on the round trip. 5x5 sweep exits bit @ 11,482', high vis beaded. 9/6/2019 9/62019 2.00 PROM DRILL DRLG P Ct 2655 psi @ 2.8 bpm in and 2.8 bpm 11,645.0 11,950.0 11:09 13:09 out, Free spin diff 1195 psi, BHP 2039 psi 10.3 ppg EMW @ the window & 11.4 ECD @ the bit. WH 114 psi, IA 0 psi, oA 15 psi. OBD, CT Wt -25 k Ib, WOB 2 k lbs. 11,833' PU Wt 50 k be Average ROP over interval is 152.5 fUhr Page 7111 Report Printed: 9/24/2019 Operations Summary (with Timelog Depths) IG -103 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur hr ( ) Phase O Cotle P ACLvi Code ty Twe P -T- X Operation SWrt Depm (ftKB) End Deptr, (fIKB) 9/6/2019 9/6/2019 4.00 FROM DRILL WPRT P PU Wt 53 ks lbs 11,950.0 66.0 13:09 17:09 PUH on first swab wiper, pull slow for 5x5 TD sweep to exit bit @ 6796 - 6766 pull -21 k WOB & 21 k over on CT wt, RBIH , pulled UH - clean. 9/6/2019 9/6/2019 4.00 PROD1 DRILL WPRT P Tag up, set counters, RBIH 66.0 11,960.0 17:09 21:09 9/6/2019 9/6/2019 1.90 PROD1 DRILL TRIP P Confirm TD, PU hole slowly, while 11,960.0 11,960.0 21:09 23:03 organizing fluid and truck on location 9/6/2019 9/7/2019 0.95 FROM DRILL WPRT P POOH, laying in new mud 11,960.0 8,988.0 23:03 00:00 9/7/2019 9/7/2019 2.40 FROM DRILL WPRT P Continue swab wiper#2 laying in 8,988.0 3,340.0 00:00 0224 beaded pill, pull up through window 9/7/2019 9/7/2019 0.15 FROM DRILL DLOG P Log formation for depth (+11.5') 3,340.0 3,393.0 02:24 0233 9/7/2019 9/7/2019 0.43 FROM DRILL DLOG P Continue IH log RA marker (+9.0) 3,393.0 3,860.0 02:33 0258 9/7/2019 9/7/2019 0.30 PRODt DRILL OWFF P PUH to obtain static, WHP=107, 3,860.0 3,789.0 02:58 03:16 BHP=9.61 ppg,AP=1,653 9/7/2019 9/7/2019 0.80 FROM DRILL WPRT P Continue swap wiper, pumping 2.8 3,789.0 86.9 03:16 0404 bpm at 2,526 psi 9/7/2019 9/7/2019 0.15 FROM DRILL TRIP P Tag up, reset counters, RIH 86.9 3,833.0 04:04 0413 9/7/2019 9/7/2019 0.50 FROM DRILL DLOG P Log RA marker, -1.0' 3,833.0 3,866.0 04:13 0443 9/7/2019 9/7/2019 3.30 FROM DRILL TRIP P Continue IH, start pumping 50 bbl new 3,866.0 11,960.0 04:43 0801 mud beaded sweep at 7850', Beads at the bit@ 9000'. Reduce RIH speed from 50 to 30 @ 11,110'. Trouble off loading LRP from truck, rock catcher full of unhydrated gell (fish eyes) 9/7/2019 9/7/2019 6.00 FROM DRILL CIRC P PUH slowly waling on transfer of LRP 11,960.0 82.0 08:01 14:01 from vac truck to pits, weight up LRP, started pumping to bit @ 9:57 PUH and paint yellow flag at 9871.95' Displaced mud with 150 bbl LRP, left top of beads at 4430' followed by KW to surface Painted white flag @ 1586.71' 9/7/2019 9/7/2019 1.20 PROD1 DRILL CIRC P Flow Check, PJSM, inspect pipe - 82.0 0.0 14:01 15:13 good. LD BHA # over a dead well. Bit graded out 1-1 HYC SN a265931 9/7/2019 9/7/2019 0.80 PROD1 DRILL BOPE P BOP function test - good 82.0 0.0 15:13 1601 9/7/2019 9/7/2019 0.70 COMPZ1 CASING PUTB P PJSM, Prep floor for running liner 0.0 0.0 16:01 1643 9/7/2019 9/7/2019 1.28 COMPZ1 CASING PUTB P PU lower completion - run #1, 66 0.0 929.6 16:43 1800 joints of 2-7/8" slotted liner and 3joints of 2-7/8" solid liner over a non ported bullet nose. losses 1 bph. 9/7/2019 9/7/2019 0.40 COMPZI CASING PUTB P Crew Change, PJSM for MU Liner 929.6 929.6 18:00 18:24 I section, inspect liner equipment (swap out hand slip and dies) Page 8/11 Report Printed: 9/24/2019 Summary (with Timelog Depths) 1G-103 IgoOperations Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time log stat Depth Stet Tons, Ertl TimeDur(m) Phase Op Code Activity Code Time P-T-X Operation (MKB) End Depth(fIKB) 9/7/2019 9/7/2019 2.30 COMPZI CASING PUTB P Continue PU Liner Segment #1 929.6 2,122.8 18:24 20:42 9/7/2019 9/7/2019 0.30 COMPZI CASING PULD P PJSM, PU/MU BHI Coffrak tools 2,122.8 2,172.4 20:42 21:00 9/7/2019 9/7/2019 1.30 COMPZi CASING PULD P Inspect pac-offs, stab INJH, tag up, 2,172.4 2,172.4 21:00 22:18 reset counters, bring pump online, unable to obtain rate, trouble shoot, lockout pump, found low pressure screen plugged with cat eyes. service filter. 917/2019 9/7/2019 0.75 COMPZI CASING RUNL P RIH, w/liner segment #1 2,172.4 3,681.0 22:18 23:03 9/7/2019 917/2019 0.15 COMPZ1 CASING RUNL P Correct to the EOP flag -9.0' 3,681.0 3,681.0 23:03 23:12 9/712019 918/2019 0.80 COMPZI CASING RUNL P Continue IH 3,681.0 5,930.0 23:12 00:00 9/8/2019 9/8/2019 0.25 COMPZt CASING RUNL P Log the RA marker +4.5' 5,930.0 5,948.0 00:00 00:15 9/8/2019 9/8/2019 2.00 COMPZ1 CASING RUNL P Continue IH, attempting to get pump 5,948.0 11,960.0 00:15 02:15 to make pressure, started stacking 3.0 k CTweight 5,630'-6,018', slight 2.0 k bobble @ 7,667', another 2.0 k bobble 9,428', 5.0 k bobble @ 10,740' 9/8/2019 9/8/2019 0.20 COMPZI CASING RUNL P Tag bottom, PUW 45 k, set back 11,960.0 9,811.8 02:15 02:27 down, 11,960', bring pump online 1.4 bpm at 2,270 psi, Diff--781, PUW 30 k, Remove liner length from counters 9/8/2019 9/8/2019 2.50 COMPZi CASING TRIP P POOH, painting TD flag 9,811.8 47.9 02:27 04:57 9/8/2019 9/8/2019 0.50 COMPZI CASING OWFF P Check well for Ifow, PJSM 47.9 47.9 04:57 05:27 918/2019 91812019 0.50 COMPZI CASING PULD P LD setting tools on a dead well. 47.9 0.0 05:27 05:57 918/2019 9/8/2019 0.50 COMPZI CASING PUTB P Prep RF for liner OPS, PJSM 0.0 05:57 06:27 9/8/2019 9/8/2019 5.00 COMPZI CASING PUTB P PU middle completion, disolvable bull 0.0 3,309.6 06:27 11:27 nose under 3 blank 2-7/8", 33 slot 2- 718", 3 blank, 33 slots, 3 blank, 15 slotts, and 18 blank topped with a N OH OCLL ieceplicel. LOA ( 3309.56') 9/8/2019 9/8/2019 1.20 COMPZI CASING PULD P PU liner running assembly, 3,309.6 3,357.4 11:27 12:39 9/812019 9/8/2019 2.60 COMPZI CASING RUNL P RIH w BHA #6. Slow down to log RA 3,357.4 9,840.0 12:39 15:15 tag, Stacked out coil, abort RA log, PU 40 k lbs, Continue to RIH. Wt Ck @ 9789 CTMD 38 k bs. RIH @ 20 ft/min, flag passed horses head SD on bottom section @ 9841' WOB 10 k lbs, PU Wt 45k WOB -12 k lbs, latched, RBIH, 9840' and 9 k lbs. Line up to coil @ 1.6 bpm, PU Wt 24 k liner gone, WOB 0.4 k lbs 9/82019 9/8/2019 1.80 COMPZ1 CASING TRIP P PUH, park and reset coulter, POOH 9,840.0 63.0 15:15 17:03 lined up over the top. 9/812019 9/8/2019 1.00 50MPZ1 CASING PULD P Flow check, LD over a dead well. 63.0 0.0 17:03 18:03 9182019 9/8/2019 0.30 COMPZI CASING PUTB P Crew change, PJSM, prep RF for liner 0.0 0.0 18:03 18:21 ops 9/8/2019 9/9/2019 5.65 COMPZI CASING PUTB P PU/MU liner segment #3 w/91 Its of 0.0 2,306.4 18:21 00:00 liner 9/9/2019 9/9/2019 1.20 COMPZI CASING PUTS P Continue MU Liner segment #3 2,306.4 2,735.3 00:00 01:12 ir Page 9111 Report Printed: 9/24/2019 Operations Summary (with Timelog Depths) IG -103 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log BtaR Time End Time Dur (hr) Phase Op Cotle Activity Cotle Time P -T -X Operation Start Depth (ftKB) End Depth(ftKB) 9/9/2019 9/9/2019 1.00 COMPZI CASING PULD P PU/MU CoilTrak tools, MU to tubing, 2,735.3 2,783.1 01:12 02:12 inspect pac-offs 9/9/2019 9/9/2019 1.81 COMPZI CASING RUNL P Tag up, reset counters, RIH, stop and 2,783.1 6,526.0 02:12 04:00 get up weight @ 6,300', 35 k. stackoul at 6,464', PUH, continue IH with increased speed clean 9/9/2019 9/9/2019 0.15 COMPZI CASING RUNL P SD on bottom section @ 6,531' WOB 6,526.0 6,526.0 04:00 0409 13 k lbs, PU Wt 40k WOB -11 k lbs, latched, RBIH, 6,531' and 14 k Itis. Line up to coil @ 1.6 bpm, diff -1,073 psi, PU Wt 22 k liner gone, WOB 0.4 k Itis 9/9/2019 9/9/2019 0.15 COMPZI CASING RUNL P PUH for tie in 6,526.0 3,317.0 04:09 0418 9/9/2019 9/9/2019 0.20 COMPZI CASING RUNL P Log formation (-2.5) 3,317.0 3,350.0 04:18 0430 9/9/2019 9/9/2019 0.20 DEMOB WHDBOP TRIP P RBIH, LRS on location, PJSM, spot in 3,350.0 3,775.0 04:30 0442 unit and rig up to customer line. 9/9/2019 9/9/2019 0.70 DEMOB WHDBOP DISP P Displace well to SW 3,775.0 3,557.0 04:42 0524 9/9/2019 9/9/2019 1.00 DEMOB WHDBOP DISP P Displace CT and tubing with diesel, FP 3,557.0 88.0 05:24 0624 from 2500'to surface. 9/9/2019 9/9/2019 1.70 DEMOB WHDBOP PUTB P Bumped up, space out, PUD BHA# 7, 88.0 0.0 06:24 0806 LD BHA " Final WH pressure 245 psi 9/9/2019 9/9/2019 2.00 DEMOB WHDBOP DISP P RU SLB N2, cool down, PT, pump 24k 0.0 0.0 08:06 1006 SCF to coil displaceing to N2. Blow down surface lines and bleed coil down. 9/9/2019 9/9/2019 7.90 DEMOB WHDBOP CTOP P "' Start RD / coil swap operations. 0.0 0.0 10:06 18:00 Unstab injector, skid cart, drop QTS, cut CTC, cut two 7' sections of 2-5/8" coil for Dr Tipton testing. Run pipe into pipe shed, weld 2" stinger into 2-5/8" coil, remover inner reel iron and HP bulkhead while installing 2" grapple and stringing hay wire. Pull test grapple - good. Unstab coil and secure coil to shipping spool, - de inventroy pits. 9/9/2019 9/9/2019 1.50 DEMOB WHDBOP CTOP P Finish TP down coiled tubing spool, 0.0 0.0 18:00 1930 trucks on location, PJSM with rig crew and Peak drivers 9/9/2019 9/9/2019 2.00 DEMOB WHDBOP CTOP P Open bombay doors, spot in MT bed 0.0 0.0 19:30 21:30 truck and lower 2-5/8" Coiled Tubing spool onto truck, secure spool to truck bed, pull truck out from inside rig, spot on edge of location. 9/9/2019 9/10/2019 2.50 DEMOB WHDBOP CTOP P Spot in, replacement 2" spool, hook up 0.0 0.0 21:30 00:00 install sadle clamps, install shims, torque up bolts. bring 3' riser piece to Fig floor, 9/10/2019 9/10/2019 6.00 DEMOB WHDBOP CTOP P Continue swapping coil, swap out 0.0 0.0 00:00 06:00 brass, Start install gooseneck rollers, pull 2-5/8" injector blocks, dress horses head to 2" coil size, load all 2- 5/8" parts and pieces into crate. 9/10/2019 9/10/2019 6.00 DEMOB WHDBOP CTOP P Continue to swap gooseneck rollers 0.0 0.0 06:00 1200 and pull injector blocks. Inspect injector, install 2" blocks replacing elastomers as necessary. Complete 2" goose neck roller instal " Start generators in preparation to swap off of highline power @ 0900 Page 10111 Report Printed: 912412019 Uperations Summary (with Timelog Depths) 113-103 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time Eno Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (WB) End Depth(%KB) 9/10/2019 9/10/2019 3.00 DEMOB WHDBOP CTOP P Complet block instal and injector 0.0 0.0 12:00 15:00 inspection. Complet roller install. Prep 2" coil, install grapple, pull test - good. Stab coil. Swap out rams, reconfigure for 2". 9/10/2019 9/10/2019 5.00 DEMOB WHDBOP DMOB P Complet RD of remaining items. 0.0 0.0 15:00 20:00 Nipple down, stack RD, putz, pull traps, blow down steam. 9/10/2019 9/11/2019 4.00 DEMOB WHDBOP DMOB P Trucks on location, PJSM, pull service 0.0 0.0 20:00 00:00 unit and spot on pad, install jeep while pulling sub away from the well and spotting on pad. Jeep up sub. notify security. "'Rig Release 0:00 - 9/11/19 Page 11111 Report Printed: 9/24/2019 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1G Pad IG -103 50-029-20824-01 Baker Hughes INTEQ Definitive Survey Report 18 September, 2019 BA ER F�UGHES F mrn,, Conoc( Phillips ConocoPhillips Definitive Survey Report Start Doh Company: ConomPhillips Alaska Inc Kupamk Lead D Minh RRartnce: Well 1G-03 Project: Kuparuk River Unit MReference: IG -03®891(1 G43) SM: Kupamk IG Pad MO Reference: iG-03@89.50usft(I G-03) Well: 1G-03 NOM Nations .. True Wellborn: iG-103 Survey Calculation Method Minimum Curveture Dai 16-103 Database: EDT 14 Alaska Prodertion Project Kupamk River Unil, NOM Slope Alaska, United Stuart Start Doh End DM Map System: US State Pone 1927 (Exact solution) System Datum: Mean $ee Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic ewk factor Well 1G-03– Well Position ANIS 0.00 usft Northing: 5.981124.73usft .EI -W 0.00 usft Fisting: 540.03544usn Position Uncertainty 000 usft Wellhead Elevation: usft Wellbore IG -103 Magnetics Model Name sample Data Peclinatlon L8GOM2018 9/1/2019 V) 16.45 MaIBn 1G-103 Audk Nota: brelan: 1.0 phase: ACTUAL To On Depth: 3,800.00 wri Suetion: Depth From (No) •Wfi rEAW (umj pad" tum) 89.50 0.00 080 Survey Pmgmm Date - _— From To tum) taro) Survey(Wellbare) Taal Nems Dafefi9f r" 100.00 3,800.00 1G-03 rG-03) FINDER -IAS SDC Finder mthshot 3,808.00 3,860.45 IG -103 MWD-INC(1 G-103) MWII-INC_ONLY MWDINC_ONLY _FILLER 3.890.28 11,913.13 1G-103 MWD(1G-1o3) MWDOM9G OWSG MWID-Standard L _ L amude: Longitude: Ground Level: DIPAn91e 80.87 �i umGRFs W To° 21' 40.130 N 149. 40 29.209 W 0 00 usft Fleld Simngth ron 5],40] Direction Survey Survey Start Doh End DM 1182001 9182019 9/82019 91912019 9192019 9/182019 8:58:52A1w Page 2 COMPASS 5000.14 &Wtl right r. ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc Kupamk Local Coardmate Retirement: Mkll 1G43 Prefect Kupamk River Unit TVD Reference: 1,303®89.50usit(1G03) Site: Kupamk 1G P9tl MO Reterence'. 1,343 ® 89.50us0 (1G-03) Well: 1G-03 North Reference: True Wellbore: IG -103 Survey Calculation Memod: Minimum Curvature Oesi9n: 1,3103 Database: EDT 14 Alaska Production Survey B1 w -,E 0 Annotation TIP KOP Interpolated Azimuth Interpolated Ammuth 9/102019 8552AM Peps 3 XNWPA55 500014 Build 85H Map Map Vertical MD (1511) Its,(I (% (% 1VO (call) 131055 IMall) rWS +E3 -W Room, Ea5ling OLS' Section Survey Tool Name (0511( (usR) 10) la) (9100) (R) 3Xu. 42.93 Yb 39 3.359.41 3,2..91 7013 -1369]1 5,901630.13 530665,50 5.52 70>3 MW0.1NC ONLVi2) 3.M.W 4307 258.06 3.36536 3,2%.]6 69.43 -1,375.01 5,881,m' w 538,661.21 3.03 W43 MkMi ONLY (2) 3.831.51 48.29 25.00 3,301.60 3,292.18 65.37 -1,391.33 5,981,03266 530,644.82 22.21 M37 MM1N4NC ONLY(2) 3,050A5 54.31 259.00 3.31a. 3.31037 X151 8413.37 5,98182760 538,622.90 2132 W..51 MW0.1NC_ONLY (2) 3,090.28 6983 261.5 3,415.M 332826 5.31 -1.436.10 5,981,823.35 535599.12 23.13 5.31 "D OWSG(3) 31920.95 67.54 364.45 3.4M.11 3,339,61 5300 -1.4 ,57 5901,819.89 50570.75 23.34 530o MWGCvvW(3) 3.959.34 76.35 267.76 3441.00 3,35150 5055 -1,501.94 5,901,02N 538534.]9 24.37 555 MIND OWSG l3) 3.957.31 Stn 271.11 3446.31 3,35101 50.28 -1,528.39 5,901.016.03 530,5W.56 22.5 W20 MAD OWSG(3) 4,924.85 8859 273.65 3.449.49 3,359.96 51.84 4,W.74 51981810.19 538A69.W 1838 61,. MAD OW6G(3) 4,054.99 8011 27511 3,45117 3360.67 54.30 -155.n 5,981,020.49 535.439.5 6.84 5430 MWD 0WSG(3) 4,515.51 07.45 277.07 3.45130 3]6V0 STIN 4,627.00 5,X1,023.n 539.409,23 6.07 5]69 MMVCVVWD) 4,1149 0251 27894 3.45.47 3362.97 6114 -1,65503 5,881.82761 5. 3W+47 6.00 6174 MAD OWSG(3) 4.146.2] 87.97 2W.M a,4n71 3.351.21 67.14 -1,807.00 5.981.83204 538.349.27 5.70 67.14 MAD MSG (3) 4,176.0 09.11 262.n 3.454.47 3,36497 7320 -171516 5,9BI.M75 538,320.00 7.07 ]320 MAD OWSG(3) 4,208W aWn 284.03 3.454.76 3,36526 W.37 -1,746,n 5,991845.n 538D695 7.52 60.37 MWD OWSG(3) 4,236.55 8972 LW,53 3.454.91 3,36541 88.66 -t,n4.. 5,981.053.89 539,26"50 5.24 8966 MWD OW6G(3) 4,5963 li 28]81 3.455.00 3365.53 97,54 -151340 5,981,05.61 53823272 4.27 97.54 M'ADOWSGR) A25.49 W.. 2X40 34.4.05 3,35.45 15.01 -1,83178 5,90187174 530.204l 2.W 106.81 MAD GWSG (3) 4.326.35 9101 26020 341 3,36407 41668 -1,859.98 5,98"991,46 536.1M.06 930 116.68 MADOWSG(3) 4,355.97 8979 28251 3,Vt4W 3,364.88 12]51 -1,087.53 5,98169213 530.148.44 924 127.W MAO 0WSG(3) 4,389]5 69.02 294.27 3.454.5 3,365.18 13959 -1915.40 5991.904.07 538.1..51 5.91) 1395 MWD OWSG(3) 041645 80,5 200 3.455.24 3,35514 15234 4,94266 5,981,916.5 53a'soc 1.6 5.21 152.31 MWDOW6G(3) 4,446.30 BB 25 297.05 3,40.99 3,366.49 165.60 -1496945 5981,92984 5WONB6 3 4.139 18466 MWD OWSG(3) 4.0,41 0960 293.51 34X.M 3.W,35 16167 -1,999.46 5981945. 538.Own on 10197 MOD MSG (3) ASW,. 885 295.70 345TH 338704 194,24 -2021.75 5.981,959.14 538.013.51 271 19024 MJN OW6G(3) 0535.65 0997 351]3 3.457.5 3,3X13 25118 -2,04738 5,9819.294 537,968.20 4,75 2..18 MJJD OWSG(3) 4.556.10 9009 30ZW 3.45761 3,368.11 M5.n $07333 5,99158.04 537,aGA4 833 M5.;n MWD OW6G (3) 4.59622 60. 304.19 3,4989 3.008.39 241.n -2098.40 590200535 57936.95 6.53 001.77 MWDGVii 4626,09 eLG 306.19 3,4158.54 3.369.04 258.97 -2,122.80 5.98202232 537,91ZW 6.74 25897 MADOWSG(3) 465.11 0917 30724 3,459.12 3,]6t).62 276.92 8146.80 5,983.040.14 537,810.00 3.95 2MaG MND OWSG Ml B1 w -,E 0 Annotation TIP KOP Interpolated Azimuth Interpolated Ammuth 9/102019 8552AM Peps 3 XNWPA55 500014 Build 85H CortmoPhillips • ConocoPhillips Defirl Survey Report Company, ConoccPhtilips ConoccPhll9ps Alaska lnc Kuparuk _._.._.-..___. Leaned Coartilceh Relemen : - -------------------_. WlII 1603 Praiece Kupamk River Unit T(-D flefercrMe: 1603®89.50us6(1G 3) Site: Kupamk IG Pad MD flehvnn: 1G-03 Q 89.50usa(1 G413) Well: 10.03 lili Reference: True Well0om: 1G-103 survey Calculation MCNotl: Minimum Curvature Designs IG-103 bea4aee: EDT 14 Alaska Pmtluction Survey MO Inc Add TVD 1(-098 407.9 hP ♦deftl11.41Y DLs (-am 1'1 1'1 tMa17 IruM lua1R No n9 luenl Eaotn9 section suTool rvey Wme Annotation Ifll Ifll 1'rmB•1 Ifll 4686.23 80.29 309.13 3,45927 3,369,]] 29554 -3,17050 5,982050.61 537 8&4.57 723 29554 04070007306 (3) 4.716.V - 9030 310.38 3.45910 3,36960 3,475 -2.19363 SM2,077@ 53).841.3] 4.19 314]5 MND OWSG (3) 0744.07 91.14 311.29 3,45073 3,36923 33292 -2,21466 5882095.78 537.820.25 422 33292 04socand l3) 0714.95 9153 311.59 3,45001 3,360.51 35336 -2237,60 5.982,116.08 537,)9]20 159 353.36 MNL =63 (3) 4,60430] 91.93 31107 3,45711 3,357.61 373.13 -2,259.97 5, 982,135]4 537.774.8 164 373.13 FM4]OWSG(3) 4,834.51 94.79 311.94 3,45,36 3,3yom ]93.02 .2,38214 5.982.15591 53],]52.45 959 393.2 MD OWbG (3) 4.5.21 96,46 31300 345236 3.362.86 41]65 -2,304E8 59021]8.01 537,> 81 6.43 41365 MWD OINSG (3) 4.85,57 975 3207 3448,57 3,35907 434.51 -232041 59021915.75 5],]0707 7.16 434.51 MWDOW53I3) 4,923A7 9783 316.54 3404]6 3,35.26 454.211 -234574 5,98221940 57.580.5 088 45436 Mr4D M86 (3) 4,956.05 96.5 310.29 3,440.56 3,351.06 478.04 -0,367.61 5,982340.69 5 ell 5.94 47004 MD MSG (3) 4,040.]5 9449 319.39 3.43770 3,34830 489.50 -2,3%,40 5,982.041.46 537607.64 9.41 49954 MWD OWbG (3) 5,014.75 91.75 31.50 3,436.07 3.346,57 52263 -2,405A7 5.95.280.45 537,Mkk4 11.52 52263 MW00WSG (3) 5.045.69 532 ]24.]4 3,434,73 334923 547.D -2,42411 5,90230903 537609.. 1033 507.29 MWDOWSG(3) 5.07451 94.55 31]9 3,43271 3,343.27 571.07 -2440.28 5,982332.68 57,59338 10.9 SRW MJ .SGC) 5,104.57 94.5 3H71 3,430,40 3,340,90 598.59 -2,455.96 51982,358,13 53751.57 038 SW,S9 MD MSG (3) 9,14051 93.99 330.35 3,427.73 3,33833 27.64 -2473.6 5.982.1%,00 537,559.5 2.31 52784 MJJD OVAG(3) 5.15.37 93.84 328.17 3,48.07 3.35,5 fi46.96 -24SSS4 !kMA1032 537,546.71 8.]] Got 96 MWD GW6G (3) 5.19462 5.70 32529 3,424.09 3,33459 67336 -2,52.55 5902434.63 53],50.5] 9.03 67335 MWL O'NSG 13) 5223.19 93.5 323.21 3.422.31 3.33281 696.5 $518.21 5, 88245768 57,513.79 742 696.5 MND OWSG (3) 5,254M Scale 32577 3,42121 3331.71 M.10 -2,537.47 9,982.483.10 57495.38 1175 ]22.10 MAID MSG (3) 5,280.83 91.29 328.08 3.47.69 333119 ]23] .2,535 5,902,5.0736 537.478.80 7.92 747.37 MWD OWSG (3) 5.314.59 W.97 328.79 34MM 3,330.5 ]72.73 -2,56 1 5.992.53363 537,461,09 504 nZ73 MWDOWSG(3) 5.345.97 8009 M02 342067 3 IA7 7995 -2505,72 5,9B2.5M..41 5744974 352 799.59 MWLOWSGI3) 5,3IS5 Wit? 327.04 3421.03 3,331.53 824.5 -2601.51 5982,585.5 57.430.81 720 624.5 MhL 00786(3) 9,4045 9313 32729 3.420.31 3,330.81 808.M -261728 5.9826D999 537414.91 11.75 849.34 MND MSG (3) 9.435.07 95.5 324.65 3,417.94 3,32044 87512 -2,624.62 oM.65.67 537,39743 11.10 07512 MD (3) 5.404.1 8338 57.28 3415W 3,336.06 80.21 -2,55,83 Spec 967 537,3ky1.ID 10.38 899.21 MWDOMSG(3) 5.455.05 94.21 328.76 3,41348 3,323.8 92446 -2611680 5,9026045 57,36520 SAS 934.45 MJdD MGG 13) 5,5251 9591 328.33 3,410.01 3,321.31 95,14 -2,68231 5,9B3710.42 57349136 590 950.14 MND MSG (y) 5, 55400 Sl 331.03 3.407.58 3318.08 97482 -2,607.74 5,882.735@ 57334.79 9.95 974.82 MWD MSG (3) 5,504.55_ 95,20 333.16 3.404.5_33.&5 _1,071.50 -2311.17 595.>81.83 _ 537.320.72 6.82 140150 MWD GWSG (3) J 9/114019 s:59'S?AM 4 r, ComcoMil6 ConocoPhillips 612 ps Definitive Survey Report �_.. CwnlMey GOOOCOPhllkps Alaska Inc Kupamk Local C0or01nare Reference: Well 1G-03 i �Rlojach Kupamk River Unit TVD Reference iG-03®6950usX (IG -03) I SSM: Kupamk I Pad MO Reference'. lG-03@$9.50usX(1G-03) WWW: 1G-03 North Reference: True �Wellbon: iG-103 Survey Calculation Method Minimum Curvature Oath 10-103 Dabbase'. EDT 14 Alaska Production j I SafVaY ". MBp Map Wall MO 1. Aa] 1VD 1VOSS 4h84l; 4.Wyy OLS low" 19 19 loaf) low" IWM IMahl Northing Eaki I'n9rl Seellon Survey Tool Name Ann9teX9n Iftl Ihl 1X1 561 9501 MA54 3,401.65 3,31215 1,028.54 -1,]]4]4 5,902.]80.59 53],306,51 Tat 102954 MKNOWSG13l 5.64569 9562 33223 339s. 3.309130 1,056.50 -2]3].25 5,98291608 537 293 Be 8.93 1.016.08 MND Mae (3) 66]4.89 96,27 340.65 3,395.T] 3,30927 1,08359 -2,]4].69 5,98284351 53].283.2] 11.05 1,083.59 MWD MSG (3) 5,70611] 9518 34333 3.391.98 330249 1.11657 -2,758.41 5,982.8]6.41 53],283] 7.64 1,11657 MWD MSG (3) 5,736. 95.23 344.75 3.381 3,299.50 1,14532 -2]00.63 5,982.98513 537,26400 S.. 1,14532 MWD0W6GG) 5,719 .,W 344.]8 3,385.50 3,87.90 1.1]541 -2]]4.83 5,98293517 537,255.64 4.16 1,175.41 MVa)OW5GD) 5,.147 91'. 30.5.84 3,38502 3.205.62 1,204.74 4)8251 5,882,96448 53],24].00 625 1,2N.74 MND MSG (3) 5,.1.38 91,11 34762 3,384.30 3,294,80 1,233.85 -2,789.33 5,881,993.53 537.240.83 6.117 1.23185 MND MSG (3) 5..507 fli 349.90 3,384,02 3,29452 1,2%.91 -2]95.. 5.983.0265$ 5.4.23417 747 126691 MWTI DW6G(3) 5,895.12 8273 35209 3,38336 3,293,86 1,256.50 -2,111 5,903,oki 537,22933 11.96 1,19558 MWD 00850 (3) 5.925.16 95.16 354.78 3.30129 3,291.79 132634 -2,81182 5,9.68594 537,225.]5 1205 1'mas MWD 00850 (3) ' 5,95523 95.44 356 To 3,378.51 3.289.01 1,35620 3,808.12 5,Pit, ,11578 53],223.38 689 1.356.20 MNOOWSG (3) 5,985.02 84.30 350c55 3,375.911 3.268.48 1,385.85 -2,80158 5,983,145A1 537.221.76 467 1,365.85 MND MSG (3) 601535 9442 351 3,373.68 328418 1,416.08 -2,00630 5,983,17564 537.220.84 7.05 1.41600 MWD OW6G(3) 6,046.08 Wild OW 3,371.. 328242 1,44132 -280620 6,983216,87 537220.2 827 1,447.32 MWD0WSG(3) i 6.Oh1.13 90.03 1.44 3,371.51 3.282.01 1.11 -2 all 5,9113230.38 537,221.12 9.17 1,470.80 MNO OVVW 13) 6,10060 06.93 1.12 3,3833 3,282.83 1501.24 -2.80893 5,88021,080 53722180 10.12 1,501.24 MNDOWSGD) 61130.38 84.71 1.01) 3.31 3265.00 1,530,81 3,608,00 5983,2904] 537.222.58 7.40 1.530.91 MD i 6,16043 85.11 221 3.37].1] 3,28767 1,560.84 -2,834.93 5,981 537.223.49 170 1,550.84 MND MSG (3) 6 oem 8678 4.16 3,37629 3,28979 1.590.68 -2,803.26 5,9833.4.03 537.22459 8.55 168068 MWD 0W6G (3) 6.220.03 i 8T. 4.55 3,308.5 3,291.10 1.621.55 3,8[9.99 5,9..308.2 537,22710 309 1,630.55 MWD 00860(3) 6.252.17 8985 5A1 3.381.31 3,291.81 1.65221 -279623 5,983,411,79 537229.6. 676 1,652.21 MNOOVei 6280.23 A9.69 662 3.381.42 3.E193 1680.11 3,795.29 5,983,43871 5372M.48 4.35 1,.0.11 MND MSG (3) 6,31021 89.20 9.03 3,381.8 3.M.22 1,708.81 -279121 5.983.46943 537,238.40 8.20 1,] .1 MND OWSG (3) 8.34D42 BA28 1OAO 3.382.12 3,29262 1,750.60 -2,]..19 5,983.499.24 537,24128 3.55 1,]3960 MND GWSG (3) 6.37(1 89.]2 1204 338239 3,29289 1,76694 -2,]80.45 5,9.528.61 537,246.85 6.6T 1,76694 MWDOM I3) 6.402.65 9006 11.92 3,3111 329295 1,908.56 -241]3.]4 5,9.,56026 537253.39 112 1..055 MrW OW6G 13) 6.430.. B9.B2 13.05 3,38248 3,2,12.80 1,828.10 $76742 5,983.58791 .7259.55 687 1,826.18 MNOOWSG(3) 6,461 90.09 1283 3.382.50 3,51,00 1,85724 -2,760.50 5,983.617. 537.2..32 3.24 1,05724 MND OWSG(3) 8.490.63 50.18 1350 3,38243 3282.83 1,885.23 -2,]53]0 5.983,646.03 537,92.97 1.94 I'm. MND 00850 (3) 6,520.88 80.53 1301 3,38223 3,292]3 1,91567 -2,]46.]6 5983,675.50 537M76 2.09 .6] MCAVI 1,915WD - _ ' 58 "1120198::52AM �5 COMPASS 500014 Budd 864 ConocoPhillips ConocoPhillips Definitive Survey Report m^° C4mparq: ConorcPhAlips Alaska Inc Kupamk Local Co-ordinate Reference: Well 1"3 Project Kupamk River Unit ND Reference: 1G43®89.50u3h(16413) Bee: Kupamk I Pad MO Reference: 1603®89.50uae(1G43) Well: 1G43 North Reference: True Wellbore: 16103 Survey Calculation Method M'mimum GUNmart Design: 16-103 Database: EDT 14 Alaska Production Survey MD jm1t1 Inc hl Ab 1°1 TVD (um) TVOSS (con) ♦NIS (-am aFJ-w (eaD) Northing Eason, 0111 SecMon Survey Tool Name Annotation IRI IDI (.11w ) ml 654939 90.12 1205 3.382.05 3,29156 194350 -2740.56 5,983 ]03.3fi 537,285 78 3.)3 1943.50 MWD OW6G (3) 5580.37 90.80 11.60 3,301.81 3,29231 1Me 3,Y14.1. 5,983.73129 532/,3204 Z27 1,9]3.81 MWDOMG(3) 6.609]9 90.61 1237 3301,45 3,29195 Z00Z57 3,]2].88 5,983)62.49 537298.06 1.82 2002.57 MWD 0MG(3) 6.639.60 90.25 14.59 3,38133 3,291]3 2031.06 -2,721,16 5,983,79102 53]304.]3 ]5] Z031.06 MWD OW6G (3) 6b59]9 8954 15.58 3,39120 3,291]8 3.0l 8713.18 5,99302050 5370412.9 398 2,060]1 M OWSG (3) 6,]00.14 90.28 1)33 3,381.33 3,291.03 2,049.82 -2,704.81 5,9M.M. 537,320.06 502 2069.82 M DOW5GG3 672984 89.60 1265 3,38136 329186 2.11416 -2,695]1 59&3,8]024 53),30.]1 269 2,11&10 MND OWSG G) 675962 09.02 17.60 3.381.72 3,29222 Z145.54 -2,686.70 5983904115 53],335,5] 1.95 Z146.54 NIND GWSG(3) 6.709.89 0&22 1472 330245 3292.95 Z17533 -2 S]A9 5.983935.50 537347]2 3.34 Z17433 MND OWSG(3) 6.819.51 8483 low 3,383,19 3293.69 2293.41 -ZN7,90 5993%363 53]35598 316 2.203.41 MND MSG (3) 504]02 9084 1664 3383.29 3293.29 2,23]3] -265936 5,98399063 537365.48 901 223037 MNDOWSG)3) 6,87404 89,69 1538 338321 029371 2,259A1 -2,65102 5,994,019.72 537,37354 520 2258,41 MWD OWSG(3) 8,807,70 WM 1461 3,383.68 3294.18 2,72&06 -2643,34 6,f184,04840 W.381,17 Am 2,28096 M.ND0 G(3) 6.930.59 0114 14.54 3304,87 3,2037 2.317.93 -2,63557 5,984,07831 5]7394]0 429 Z317.93 2460006066)3) 6.97023 9514 1430 3307W 3,29].50 2,340.51 -2,62].]3 5904100.93 537,396.45 641 Z348.51 MNDGWSG)3) ].030]7 B6A] 11.89 3.38918 3,299.89 23]]59 -2620.99 5,984,13885 537403.03 869 2,77.59 MWDGWSG)3) 7,M.9787.39 938 3,390]9 3,30128 3,406.84 -2615.50 5.98416732 537.408.37 496 2.406.4 MNDOWSGG) 7,059.51 86.59 947 3,39294 3,30204 2835.94 -2,610,67 5,991im" 537,41304 Z73 2,435.94 MWDOW6GP) 7.091.10 8532 9.70 339457 3,305.07 2,407.01 Q,Skl 5M.W.53 57,41012 409 2,45701 MWD ONGG (3) 7.12639 0370 835 3,39794 3,308.44 250170 -2,59991 5,90426235 5374MA5 5.96 Z501]0 MWD OWSG(3) 7.14B.06 8554 7.90 346097 3,310.57 2,524.04 -259&72 5.984,28461 537,426.52 835 252404 MWD GW6G(3) ],1]955 87,n 7.15 3401.4 131234 Z55AM -Z59274 5.984,31AW 537.43034 728 2.GiAM MWDOWSG)3) 7,21032 8&77 7.01 3,40277 3.3117 2`,34.74 -Z588.95 660.,145,34 53].433.9] 322 2,584.74 MNDOWSG)3) 724071 0038 5908 3,403.55 3,31405 2,614.94 -2,585.64 5804755 57,0.1711 520 2,61/94 MWD MSG (3) 7269.12 M43 401 3.40436 3.31486 2,64124 -2,503.29 5984.40306 53783431 5.20 ZU3,24 MWDOWSG(3) 7,299.89 87.60 2.63 3,40543 3,31593 2,873.94 -2.5151 5.98,434.57 537,44092 533 2673.94 MWD OW6G(3) 7,3311.01 6548 1.44 3,40725 3,31]]5 Z703.98 -258044 5984881.81 537,441.03 8.07 2]03.98 MrVDMSG(3) 73605 6717 Z44 340920 3,31970 Z7M.44 -Z579A1 5,904495.07 53].442]0 &43 2,]34.4 MNDOWSG)3) 7390]6 87.21 2.H 3,410.6 3,321A6 2,][399 $78]5 5,984,524.62 57,443.80 014 2l0&99 MWDOWSGI3) 7,41444 87.45 2.6 3,412,32 3,7252 2,]9321 -3,576.85 5,98455385 67,44495 1.11 ZnG.21 MND GWBG(3) 7450.35 49.14 238 3,412.94 3,323.44 2,024.07 -2,57549 5,984.5848 6744614 5.54 Z824.07 MWOOWSG )3) __ 9/162019 6:55'92,324 Page 6 WhAFASS 500014 Boni BSN �. ConocoPhillips ConocoPhillips Definitive Survey Report % d Company: COnOcoPhrap Alaska Inc Kupamk Loin Coaldlnafe Reference: Well 1G-03 Map Project Kuparuk River Unit IVD Rehnnp: )G-03®89.50usft(1G-03) MD fide: Kupank 1G Pad MO RefereMe: 1G-03 ® 89.50us8 (1 G-03) 1 Well: 16.03 NOM Reba ene True E.N1, Millions, 1G-103 Survey CalcuYdon Slowed: Minimum Curvalun (% Design 1G-103 Database: EDT 14 Alaska Pmduclion IuaR) Survey e) (t (•1100'1 9182019 8'5852414 Pagel COMPASS 5000.14 Bued 85H Map Map vertical MD Inc Av Initial TMOSS ANV3 aSSM NOMIng E.N1, OLS Section Survey Tool Name Annotation (-to (% (9 luslry loan) IuaR) luslry e) (t (•1100'1 IRI ],429.79 90.06 229 3,41314 3323.94 2,853.48 -2574.29 5,984,814.13 537447,19 3.24 2,85348 MWD MGG (3) 7,510,13 88.46 337 341352 3320@ 2,803,18 -2,572.79 5,984.644.44 537,448.52 6,44 2,883]0 MWD MSG pI 7,53&90 e9.02 324 3413.95 3,32445 291250 2571.13 &989673.16 537,450.01 4.75 2,912.50 MWD 0AGG(3) 7.57Dd3 0862 283 3414.30 3324.88 294369 $569.53 5,884.70435 537,451,45 4.31 2,943.69 MWD MSG (3) 7,501762 07.91 39B 341530 332500 2,974.11 -256177 5,9174,734]0 537,453.08 503 2,974.11 MOD MSG (3) 7.629.63 SON 528 3,416.12 OXNO2 3,003.04 -2565.43 5,984,763.M 537,455.25 552 3.00304 MMD GWSG(3) 7,%257 8&86 5.85 3,416.77 3,327.27 3.035.79 -2.562.24 5,984]06 .40 537,459.26 17n 3,03579 MMD MSG (3) 7,699,00 8763 5.91 3,417,59 3,328.00 3,06207 -.55953 5984.07277 537,460.83 466 3,06207 MND MSG (3) 7,7411.24 04.50 361 3,41973 3.330.23 3,063.12 -2556.84 5,904&5384 537,463.25 1242 3,093.12 MWD MSG (3) 7,750.53 85,08 3.19 3,42L48 3,332.90 3,12334 -2,555.16 5984.08395 637454.80 236 3,12324 k1WD MSG (3) 7,780.58 06.71 331 3424.729 3,335.26 3.153.15 -2,553.46 5,984,913.80 537,466.41 3.01 3,15315 MWD MSG (3) 7009.% %35 3.25 3426.68 3,337.18 3,10229 -255179 5,98494302 537.467.99 0.23 3,182.29 NAD OWBG(3) 7,840.23 85.67 245 3428.82 3,33932 3,21258 -255820 5,904anal 537,469.28 3.22 3,21258 MWD OWBG(3) 7.969.95 89.82 L% 3,429.99 334049 3,242.25 -2549.20 5.905002.% 53],!70.19 14.21 3.24225 MMD0WBGD) 7,899.95 9387 I'M 342902 3,33952 3272.22 -2540.45 5,985 032 537,470.70 13.58 3,27222 MND MSG (3) 7,929.05 94.64 1.06 3.426.80 3,33730 3,30213 -2.547.05 5.985062.08 53747132 280 3,30213 MND MSG (3) 796011 8277 3.0 3424.85 3,335.35 3,33220 2,545.77 5,905.162.94 5374814 900 3,33220 MND MSG (3) 7,990.31 Was 303 3.423.87 3.334.37 3,362.34 -25459 5,985.12309 537.4n.68 603 3.362.34 MND MSG (3) 0,08133 93.35 4.10 3.471]5 3.33335 3.392.18 -254331 5,98515293 537,47530 are 3.392]0 MWD MSG (3) 8,048.99 9369 4.13 3,420@ 3,33142 3.42181 -2,541.18 5,985.18257 537,47735 1.15 3.421.61 MWD MSCI (3) 8,07823 90.90 4.58 3.419.77 3,336,27 3,448.84 -253904 59&117071 537479.25 9.73 3,449.94 NWD OWSG(3) 8,110,41 No 7.17 3,419.8 3133022 3,481.95 -2535.74 598534273 537,402.37 8]7 3,40195 MNG MSG (3) 8,139.% SO.T7 750 3.420.24 3,330.74 3,51094 -2531 as 5,%527174 537,485.95 2.15 3,51041 MMD MSG (3) 8,169.55 8750 951 3421,9 3,33187 3,540.53 -252778 5,985301.35 537.493,01 4.79 3,540.53 MNOMOG(3) 8,18981 8764 942 3,42241 3,33281 3,571.19 -2.5X410 5,985,331.03 537,494.54 302 3,570.18 ukkDMSG(3) 9,528.70 W.7 9.50 3423.32 3.333.02 assess Z51&29 5,985,359.81 537.450,19 3.91 3,590.95 Mmcaai.p3 8.25861 BOAS 989 SAMO5 3,334.15 3,62833 -251308 5,985,39322 537,509.24 4.21 3.62933 MND MSG (3) 8.289.61 0791 1054 3.424]9 3.334.89 3,658.85 1.507.75 5,905.41%% 537,506,40 7.39 3.850.85 MND MSG (3) 0,31905 8693 1136 3,425.5 3.336,05 368151 -2,502.02 5,98544945 537,514.98 422 3,%951 MWD MSG IS) 0.34782 War 1229 3.42725 3.33775 3,71583 -2.49830 5,986,47&80 637,681.rb 4.52 3,71583 MWD GWSG(3) 837906 8658 1245 SAMOS 3,33973 3,79832 -24NW 5,9%507,32 537,527.08 2.02 3,746.32 MWD MSG (3) 9182019 8'5852414 Pagel COMPASS 5000.14 Bued 85H Annotation Mill 9:5&:Sb1M Paye a COMMSS Soon, 14 "d 654 ConocoPhilllps ConocoPhillips Definitive Surety Report Company: Con..Phillipa All lnc_Kupamk Local Co-ordinate Reference: Wall 1G 3 Profen: Kupamk River Unit WD Reference: IG43®89SOusft(1G413) Ss.: K.pamk lG Ped MD Resistance 1G 3®89.50usft(10-03) Well: 1G413 North Relemnce'. hue Wellbore: 1G-103 Survey Calculation Method Minimum Curvature D -,n: 1G-103 Database: EDT 14 Alaska Prodoclion Survey - Map Map Vertical MO Inc M TVD muds 4WS aP1aN Northing Seven DLS Section Survey Tool Meme pulry PI (9 (.airy Iuam (.an) (.aft) rtl nl (41o6) Irtl 8,40&W BT08 law 3.43085 3,34135 3,]]503 -2482,95 5,985536.. 53],53150 378 3]]5,23 MWD M103 (3) 0 43948 8933 14.30 3.431.54 3,34234 3,804.99 8,4]550 5,885.5%.% 53],540.]9 7.48 3,83499 M%D0WSG(3) &46946 8998 1185 3,432.20 3,34278 3,834.07 -24[430 5%5,595.17 537.54793 1.55 3,834.07 MODOWSG(3) 6,501.12 8&81 ISMO 3,43341 3.343.91 3.684]9 -246053 5,985625.% 537,555.32 ].1] 3,864]9 NANDOWSG(3) &53o.08 9596 1225 341524 3.345]4 3,692.95 -245422 5.985 654, 537,55169 6.06 3.802,95 MWO OWSG(3) 8,56033 8511 11.53 3437.56 3348.08 3,MAS -2448.01 5.985 all 537,567.74 3,73 3.Snts seep OWSG(3) 8.599.19 85.05 9.12 3,44086 3,350.56 3,95014 3,44285 5,985,]11.9] 53],572]4 &32 3,95054 MND MSG (3) 8,620.17 85.67 8,11 3.44257 3,35397 3,90127 -2,43&23 5,%5]4252 53],5]]21 3.82 3,98127 MWD MSG (3) 8,650.5 86.04 767 3.444]4 3,35534 4,011,00 -2,434.11 5%SjY126 63],5011] 191 4,011.00 MAND MSG (3) 0,684125 87.11 7.42 3.446.]] 3.45737 4.04163 -2pR.65 5&85.50592 53]5&5.. an 4,044.63 MWD MSG (3) 8,]10.46 0&03 ].% 3..7.88 3,35838 4,070.59 -2.4522 Still 150 53].588]4 3.63 4,070.59 MWIDOWSGS) 8,]4041 6740 8.46 3.449.6 3,359.% 410022 -20MM 5,985,86154 53],592.7] 3.24 4100,22 MND MSG (3) a,M&22 Ill 882 3.450.45 3360.95 4,127.68 -2417,85 5 .'Sol w 537.56.80 2.86 4,127.68 &WID MSG (3) B.M931 8784 9. 3,151.97 3,MA7 4,15834 -241292 598581971 537,60156 3.43 4.16634 MND OWSG(3) 8,82819 6979 9.58 3.452[3 3,36113 418741 -2408.05 5,985 ell 53766. Pa 7,31 4,18741 MND MSG St 8,85723 9095 985 3452M 3,36294 4,215,14 3,40325 5,985.978.85 537,61092 419 4.21544 MND MSG (3) 0,89091 ... 921 3451.57 3,362.07 4247% 3.39]]9 5,96.009.40 537,61621 1% 024796 MWD MSG (3) 8 9014 8899 &62 3,451,31 336191 4,21783 339311 5,9%,6939 637820.73 10.76 4,27783 MWD MSG (3) 8,95735 89.82 &N 3,451.73 3.%223 4,314.21 3,387.64 5,850,0]569 537,6501 256 4,314.21 MWOOWSG(3) 69Bn34 89.63 7.74 3,451.4 3.36234 4.33707 -2,38438 5,986,098.56 537,6514 331 4,337.50 MNDOWSGS) 9,013.19 90.37 6.34 3,451.84 3,35234 4359.67 -2380.35 5,986,131.18 537,633,0 482 4, 9,67 MND MSG (3) 9oa058 9169 6.54 3.45134 3361.4 4,36.8 -23]7.28 5.96,15141 537,635.4 494 43%.% MAD MSG (3) 9.60,49 91.38 655 3450.60 3.361.10 4,424.59 y37405 5,8%1614 537,639.00 1.16 4,42459 MADOWSG13) 909967 90.83 563 34I9.y3 3,360.49 4,455.59 -23]0.]5 598521715 537.842.14 3. a,455.59 MND OWSG(3) 9,129.70 906 56 3449.60 336010 4,4646 -236781 5,986347.04 537644,92 051 4,485.48 MND MSG (3) 9.159.52 9034 56 34,1933 335993 451514 3,364.03 5 98 53],647.]4 1A4 4515.14 MWD MSG (3) 9,18967 89.70 S.. 3.44930 3,35980 4,54512 Qnl.52 596.306]2 537,65079 253 4,545.12 MWD OWSG(3) 9219.. ten 842 3."9.43 3,35993 4,574.71 3,35830 59tasno 2 53],65395 034 45..71 MWDOW6G(3) 9,24951 Son 6.6 3.449.45 3.35895 4,60456 -235487 5,98636!&20 537657.22 IA7 4.604511 MMD MSG (3) 9,27923 8037 726 3..9.5 3,3%.]9 4634.% -2351.5 596 ,36.8 53),660.6] 208 4,634,08 MAD MSG (3) 9338.6 MD. T58 3..96 3359.59 4.662.86 -234753 5.9%A243I 537.6435 1.6 4%2.66 MMD OWSG(3) Annotation Mill 9:5&:Sb1M Paye a COMMSS Soon, 14 "d 654 ConocoPhillips O CormoPhiiiips Definitive Sun ey Report COmpaey. Caaa.P11161pe Alaska Inc_Kuparvk Local C000dlnNa Nhlenm: Well IG43 Pr0)ect'. Kupamk River Unit TVD Reference: 1G -03®89.50u311(1 G-03) Site: Kuparvk 1G Pad MD Reference: iG03®89.50ua11(1G43) Well: IG -03 NOrth Ref0nance- Tore Wellborn: 16103 Survey Calculation Method: Minimum Curvature Destgn: 1G-103 Database: EDT 14 Alaska Pm0uction Survey 9/I8M19 8:58:52.98 Pepe 9 COMPASS 500014 BuAl 0544 Mao, Map MD Inc All m710035 eW5 .0m NO Eastln0 DI-55Vertical Section Sonia, Toel Name Annotation 1Mall) PI (9 tuslry Wart) (Mae) (9ae) (ft) e1 el (•1100') el 9,339.0 8055 810 3.446.63 3.359.33 1693.34 -2343.31 5986.95501 53756B 31 172 4fi9334 MWD %ISG (31 9,3M,21 90.39 898 3,440.56 3,3WA6 4,8119 -2.330]1 5,906.485.60 53].88]4 285 4)3419 MWDOWSGD) 940039 09.42 9.50 3,448.80 3,35930 4,753,00 2333.91 5,966.51565 53],87/.3] IM 4753.88 NTWD OWSG(3) 9,43035 6914 906 34MAS 3,359.68 4,78352 -3,32991 S,asas4536 537,60222 1.11 4)8352 MMD OWSG(3) 9,46D.01 9010 1032 3.44935 3,359.05 4,81273 -2,32376 5,9985]048 53]66].21 412 4,612]3 MMD MSG (3) 8,49043 was 11,10 344956 3,36D.06 4,84261 4,31811 5,986,604.41 53],682]1 451 4,642.61 MMOMSG (3) 9.51937 9005 1204 3449)0 3,35D30 4.8]11.9] -2,312.30 5.998,832]9 537,69936 4.]] 4,87097 MWDOWSGD) 9.54931 9126 11.70 3449.4 3359.94 4,939.16 -2,306.1] 5.985,60202 53]]0434 4.10 4,910.16 MWD OWSG(3) 9.M63 92,79 11.07 3,448.36 3,358.86 4,92997 I.=1] 5,939,691,85 53],]10.10 5.44 A92927 MYID GWSG(3) 88.9 .55 9339 11.40 3,446.75 3,35735 4,959.27 -228433 5998721.17 53],]15.36 2.0 495927 MWD OWSG(3) 9.539.15 BOW 1218 3,44586 3,356.36 4,96032 3,28836 5886,]50.16 53].]21.]] 11.37 4,90922 MWD 0oal(3) 9.661 87.91 1237 3448.39 3,35509 5,016.0 -2,201.77 5.988.]]9.98 537,728.10 ].1] 5,01902 MWD OWBG(3) 9,69996 Ban 12.42 3,44733 3,357.113 5,04]62 227536 5,9MADOU 53].134.45 205 5,047,62 MMDGWSG(3) 9,]30.98 06.74 1209 3.44939 3,35857 5,97]9 3,260.71 5,9BG,Bi9.B2 53],]4084 1,27 5,077.79 MND OWSG(3) 9,760.41 09.45 1253 3,44853 335903 5,1Mae y2-3.1 59M.069.Y2 53]746,98 283 5.106.66 MMD OWSG(3) 9.]8851 BOM 1212 3,44865 3,35915 5,134.11 4856.41 59MAM.2) 537 75Z 262 5,13411 MND MSG (3) 94020.OD 90]] 1245 3,448.3 3.350.93 5.104.80 -2,249,71 59M,9V'W 537)5937 2.9 5,164.08 MND OWSG(3) 9,55D.01 91.35 12]3 3,44).0] 3,35837 5,18416 -2,243.17 5,9^$85632 53],765.]5 215 5.194]8 MDOW9G(3) 9B7951 81.47 1a. 3447.14 3,357.64 533287 -2236.41 5,998,985M 537,77236 3,65 5,2RA7 MND OWS.(a) 939934 9193 1368 3,44688 3,356.76 5.251.83 3,22932 5,887814.0 537,77930 159 5,251.83 MWD OW5G(3) 993931 91.50 1448 344537 3355.8] 5380.79 -2 MM 5987,043M 53].]98.40 3.01 S,AO.79 MWD OWSG(3) 9.66.98 90.6 13.95 3,441.86 335535 5,30954 -2314]] 598],0]1.84 53].]93.53 393 5,339.54 MWD OWSG(3) 9,38 89M 1241 3.44.98 3,35.36 5,33914 $207,84 5,90],1014] 53],600.31 5.60 5,339.14 MMDOWSG(3) IoM849 91.17 1321 3.44M 335.18 5,367.62 -220136 5987.129.90 53],ef6A3 isn 5,36762 MWDOWSG(3) 10,399.57 .,56 1439 3,44433 3,354.73 5,396.82 -2194.13 5,987.15931 53],813]0 SM 5,366.82 MND OWBG(3) 10,98]]0 39.5 13.8 3.44429 3354.]3 5.425]4 -2107,00 5,987.187,57 537,BMW 481 5,42514 MWD OWSG(3) 10,11098 0.39 13.53 3.444.09 3,35539 5,45.4 -21]9]4 5.88]81].60 537,62]79 45D 5.455.14 MMD OWSG(3) 1014029 07.61 1310 3.98839 335.55 5,46193 -2,f i2.W 5,987,24743 537,83480 205 5,48".93 MND MSG (3) 10,180.13 0850 1239 3.44763 3,354M 5451500 4.165.98 5,997.2753 537,84132 4.1. 5.515.39 MND OWSG(a) 10,20795 88.13 12.17 3448.73 3,35923 5,54217 -21%16 5,987.30103 537,84590 4.45 5,542.17 MWD OWSG(3) 10,23913 80.99 1151 3A09.52 3,350.2 Smile 8.153.76 5,98],3352] 537,85313 3.48 5,572.68 MD GWGG(3) 9/I8M19 8:58:52.98 Pepe 9 COMPASS 500014 BuAl 0544 �, COnOCOP� hips ConoeoPhillips Definitive Survey Report Compaq. CDn.Phinipa Alaska lnc Kup.mk Local Coordinate Relevance: We111G-03 Pmlem: Kupaak River Unit Trot Reference: 1&03®89.50usfi(1G-03) Site: Kupamk lG Pad MD Reference: 1&03@89.50usg(1G-03) Well: 1&03 North Reference: T.. Wellbore: 1&103 Survey Calculation Method: Minimum Curvalum Design 18103 Database: EDT 14 Alaska Production Survey Mai 555:52184 Pap 10 Annotation CDa1P4SS 500014 Suod85H Soap Wnthal kN Inc M TVD TVDSS NYS 9EILa Northing Easing DLS SeNon (saD) M m loom (Dam (oval (.1%) (-tow) Tool Name Ig) (g) Oft)Sorvry 10.70.87 0948 10.70 3.44994 3,360.44 5,603.82 -2.14]63 5,98],366.40 662,859.10 2]] 560382 MWD MSG (3) 10,59.50 OSOS 1031 3,050.11 3,36061 5.632.00 -214236 598).399.65 53],061.19 2o. 5,63200 MWD MSG (3) 10.320.90 9135 9]I 3.40.9.80 3,38030 5,66095 -113726 5,90],42362 537,066.16 542 5,%0.95 MWD MSG (3) 10.35779 91.20 W'di 3<49,16 3,359.66 5,689.40 -213248 5,88745209 53],0]3]] 1.80 5,889.40 MCNGWSG (3( 10388.32 9043 9.19 3048]2 335922 571953 -212760 5,90748224 53],8]&W 2.53 5,719.53 MD GWSG(3) 10.45.56 8914 &11 3,448.89 34359.34 5,751.39 -2,12275 6,90].514.13 537,8&1.10 55 5.761.39 lAWDGWSG(3( 10.61.31 0&09 Too 3449.37 335907 6,78184 3,110.45 6,98].544.60 53],80>32 0.90 5.781.69 MNDGWSG(3( 10480]4 90.0 7.92 344SM 3,36.14 5,610.99 -2,114.37 5987,573.76 537,891.24 3.98 5,810.99 MAD MSG (3) 10,510,39 91.23 ].9] &K9.31 3,35901 5&035 -211028 5,987603.14 537,.9518 3.95 5,840.36 MAD MSG (3) 10,55.75 9332 7.83 3,448.18 3,358.68 581542 -2106.39 5,987,631.3 537,891192 7.39 5,861 MAO MW (3) 10.561.34 92.7 7.55 3446.06 3,357.40 5,BOYS -2,1W.37 5,907.653.60 537,901.01 2.66 5.850.78 ~ MSG (3) 10,50.16 89.14 4.5 3,446.35 3,356.85 5,82&37 -2,063.42 5,987,69121 53].905,5] 1289 5,926.37 MND MSG (3) 10,53066 8997 3.3 3,046.59 3.357N 5.959.19 -2.091 5.961.1204 53],90].48 44 5,859.19 MD 10660.11 6966 379 3046.9 3357.10 590919 -2,066.48 5,98].]52. 537,66..18 1.. 5,98949 MD 10,69066 89,26 243 394&97 3,35].4] 6,01913 -2,09&86 5,98],]819 537,910.64 4]3 6,019.13 MD 10?2066 90.98 3.16 3,448.91 3.357.41 6,00..04 -2.00.40 598],BH90 9.911.94 824 6,049.04 MWD MSG (3) 10,]496] 90.37 1.84 3.446.56 3.357.06 6,078.64 -2,091.09 5.967.0tt51 9!.913.09 Ifi 6.070.64 MWD MSG (3) 10]15.5 Woo 279 3,446.45 3,356.95 Std.. Iliso02 5,06],9].]] 53.91402 362 6,10490 MWD MSG (3) 10810.2] 69.85 2]I 3,946A7 3,356.97 6,138.18 109.36 5,067,002.05 97,915.66 070 6,139.18 MWD MSG (3) 10 most 89.5 2]I 3,446.67 3,35].!] &16].8] -2066.9 5.987 93175 97.916.72 1.h 6,16].8] MWD MSG (3) 10,9901 66.05 2.46 3.6.99 335/.0.9 6.198.65 -200580 5,967,86163 9],01].94 0B6 6,198.65 MWD MSG (3) 10,99.95 W.9 361 3.84711 3,35].01 6,22874 -208394 5,937,99163 537,.1984 5.02 6,3874 MWD MSG (3) 10,436.39 9.97 4.52 3.447.06 3,39.59 6.265.OB -20.126 5,.907..8 537,92106 219 6,265.08 MPoD MSG (3) 10,957.21 11 4.59 3.4470 3,35763 fi213564 10]9.9 599,04874 537,92348 19 655.84 1MD MSG (3) 10,98946 9181 6.17 3,446.42 3,35592 6,317.94 -20]6.59 5,988,OWN 53],926.31 8.74 6,317.90 MWOMSG(3) 11,019.57 03.47 7.43 3,445.0 3,355.9 6347.80 -2,073.03 5.988.110]4 53].929,]1 6,92 6.760 M M&G(3) 1l,M9.69 0.48 6]] 3.40.66 3,354.50 6,37267 3069.31 6,9N 14062 53],933.2] ID.23 63]7.67 MNOMSG (3) 11,109.71 6615 690 3443.68 3,354.10 6,437 26 106212 5,98820024 537,94044 0.62 647.26 MAD MSG (3) 11,143.87 9190 Tit 3443.07 3,3957 6,471.15 -2057.93 5,986234.15 537.94415 5.14 6.471.15 Ni MSG (3) 11.171.35 9160 ].8] 3.4@.23 3,352]3 8,496.39 -205440 6,99,261.41 53.947.9 241 6,406.39 MND MEG (3) 11.19672 91.00 668 3401.59 3,3529 6 525.54 -205090 5,99,29.57 537,95001 40B 6.63.54 MND OWSG(3) Mai 555:52184 Pap 10 Annotation CDa1P4SS 500014 Suod85H ConocoPhillips 'Company. ConocoPhJhps Alaska Inc_ Kuparvk PnleM: Kuparvk River unit SIM: Kuparvk 1G Pad WeR 1G 3 Vle9hom: 16103 DnMy1: 1G-103 BMVry ConocoPhillips Definitive Survey Report Lon[ CooMlrwh Rehrente: mn 1603 ND RefeMi 1G-03@ 89.50us1(1 G433) MD RammnG: 1 G @ 89.501(1 G413) North Rehnln: True Semi WeuYtlon Method: Minimumcurvature Daw0ax: EDT 14 Alaska Production Vertical Section Survey Tool Name Annotation tot j 455+6 MWOOwsG rat 6.563.65 MWD GWSG(3) 6.615.63 MWD Gw6G(3) 6,64541 MAD GW6G(3) 6,67526 MAO DWSG (3) 6,703.16 MAD OW6G(3) 6.734.20 MAD OwSG(3) 6.763.89 MAD Gw6G(3) 6,793.32 MAD OW6G(3) 6,923.82 MAD OWSG (3) 6,85263 MAD Ow6G(3) 6.882.30 MAD 06406 )3) 5.911.06 MAD OW6G(3) 6,94023 MAD Ow6G(3) 6,97021 MAD Dii(3) 7.030.58 MND o`N6G(3) T.036,n MWD Ow6G(3) 70511.36 MWD OW6G(3) 7,089.42 MWD Ow5G (3) 7,118.90 MWD OVAG(3) 7,146.66 MWD 06466 (3) 7177.86 MWD Ow6G(3) 7,X5.99 MAD OWSG(3) 7,239.72 MADOksa (3) 7,275.71 PRO3EGTEDWTD 9A8l2019 8:58:5&16 Pape 11 COMP,SS 5000.14 8ua 854 Map Map MD 1. Ab ND NDSS -NIS -i Northrop Eastn9 DLS (U -M 11) 11 (uan) Iusel (imen) (den) (-1169'1 (1) IRI 11,230.69 91.44 8.15 3.440.93 335103 6555.15 -20C].13 590631620 53 S9 So 507 1125].5] 9020 ].]0 3.440.50 3,351.00 6,583.85 -2,00.3.13 596.34692 537,9511 429 11,289.59 86.96 643 3,440.71 3,35121 6461563 -2,039.20 5,969,3]8]1 61 5.3 fl,319.W 86.31 6.68 3,441.95 3.352.45 6,645.41 1,035.]] 5,988.40361 53],965.3] 66] 11,349.76 08]9 par 3.442.97 3,35347 6,6]528 Q031.65 5,98843840 537.91 13.6 11,378.03 89.54 9.61 3.443.14 3,35364 6,]03.16 2,02].0] 5.9teak 0 53],SMT] 21T 11,409.51 90.0 9.45 3.44326 3.3936 6,]3420 -2,021.05 5,964.49].3] 53],9]883 1.63 11.439.]1 69]9 955 3,443.30 3,3980 6,]83.99 -2.016.06 5,989.52T10 537,98365 0.65 11,469.46 90.16 9.70 3,443.31 3]981 6,]9332 -2,011.69 5.980.5:6.53 537,98845 1.40 11,50041 88.75 am 3443.33 3.353.63 6,82382 Q806.64 5,933.98LM 537.993,55 1.45 11,52987 90.03 10.30 3,443.39 3,353.89 6852.03 -0,641.48 5,958,61664 53799055 1.97 11,59.81 0.75 9.% 3,44344 3.353.85 6,082.30 -1,96.21 5.90864556 SSBp93.67 1.60 11,59.04 69.69 10.10 3,443,50 3,3541.9 6,91108 -0,Y91.tt SM.674.39 51 0.55 11.61863 0951 964 3443.79 3.354.29 6,940.23 -1M 00 5.989,70356 5300135 1.10 11,649.61 80.15 1067 3.443.89 3.354.39 6M71 -1.91 59M.734.07 53801091 341 11,6003 90.64 11.14 1443.6 3.]54,18 7,001 -0,974.73 59M.M97 536024.51 223 11.71891 90.15 11'9 3443.41 3,3991 ],030.]2 -0,967,10 5,980,6215 538,031.93 1.55 11j38.92 90.93 10.10 3,443.30 3,351.88 7,050.36 -1.11 5988821.80 538.035.59 5.60 11,77047 saw 980 3,43.49 3,363.99 7.M9A2 -1,91 5,9M.M2.M 538,040.94 142 11,800.41 89.6 10.10 3.443.70 3.364.20 7,11890 A'Sici80 5.998,852.39 530046.00 0,40 11.60.6 89.20 10% ]444.2 3,]54.52 7,146.68 4.947.10 5,96,91218 530.051.35 264 11,MD37 68.71 980 3,444.5 3,35.64 T,1]7.86 -1.94123 5,66941.40 538.05.56 339 11,6990 37,86 ran 3.445.45 3.35.95 7206.89 -1,66.49 5,909.9705 538,06184 322 11,81313 86.31 11.6 3.446.22 3356.72 7.22922 -0,9:12.19 5,965.9931 Matt .82 3.40 114999.6 0831 11.6 3447.61 3.359.N 7,2]5.]1 4,92323 S.M.M. 530,074.53 0.00 Vertical Section Survey Tool Name Annotation tot j 455+6 MWOOwsG rat 6.563.65 MWD GWSG(3) 6.615.63 MWD Gw6G(3) 6,64541 MAD GW6G(3) 6,67526 MAO DWSG (3) 6,703.16 MAD OW6G(3) 6.734.20 MAD OwSG(3) 6.763.89 MAD Gw6G(3) 6,793.32 MAD OW6G(3) 6,923.82 MAD OWSG (3) 6,85263 MAD Ow6G(3) 6.882.30 MAD 06406 )3) 5.911.06 MAD OW6G(3) 6,94023 MAD Ow6G(3) 6,97021 MAD Dii(3) 7.030.58 MND o`N6G(3) T.036,n MWD Ow6G(3) 70511.36 MWD OW6G(3) 7,089.42 MWD Ow5G (3) 7,118.90 MWD OVAG(3) 7,146.66 MWD 06466 (3) 7177.86 MWD Ow6G(3) 7,X5.99 MAD OWSG(3) 7,239.72 MADOksa (3) 7,275.71 PRO3EGTEDWTD 9A8l2019 8:58:5&16 Pape 11 COMP,SS 5000.14 8ua 854 BA (ER 0 1-IUGHES a GE company To: Date: Abby Bell ACGCC 333 West 7"' Ave, Suite 100 Anchorage, Alaska 99501 219110 31220 Letter of Transmittal September 18, 2019 !From: - - Harvey Finch Baker Hughes, a GE Company 795 East 94" Avenue Anchorage, Alaska 99515 !!Please find enclosed the directional survey data for the following well(s): 1G-116 1G-103 RECEIVED SEP 19 2019 AOGCC (2) Total print i Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Harvey Finch, Baker Hughes GE, Wellplanner Harvey. Finch CcDBakerHughes.com ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1G Pad 1G-103 50-029-20824-01 Baker Hughes INTEQ Definitive Survey Report 18 September, 2019 BA ER F UGHES aGEcompany 2191?p 3 122 0 ConocoPhillips sn ConocoPhillips �`yc Es p Definitive Survey Report Company: ConocoPhillips Alaska lnc_Kupamk Project: Kuparuk River Unit Site: Kuparuk 1G Pad Well: 1G-03 Wellbore: 1G-103 Design: 1G-103 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 IG -03 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Position +NIS 0.00 usft Northing: +EI -W 0.00 usft Easting: Position Uncertainty Depth From (TVD) 0.00 usft Wellhead Elevation: Wellbore 1G-103 Magnetics Model Name (usft) Sample Date BGGM2018 9/1/2019 Design 1G-103 000 Audit Notes: Date Well 1G-03 1G-03 @ 89.50usft(IG-03) 1G-03 @ 89.50usft (IG -03) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,981,774.73usft 540,036.44usft usft Declination (°) 1645 Latitude: Longitude: Ground Level: Dip Angle 0 8087 70° 21'40,130 N 149' 40'29,209 W 0.00 usft Field Strength (nn 57407 Version: 1.0 Phase: ACTUAL Tie On Depth: 3,80000 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (1) 8950 0 00 0.00 000 Survey Program Date From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 100.00 3,800.00 IG -03 (1G-03) FINDER -MS SDC Finder multishot 1/8/2001 - 3,808.00 3,86045 1G-103 MWD -INC (1G-103) MWD-INC_ONLY MWD -INC -ONLY -FILLER 9/8/2019 9/8/2019 3,890.28 11913.13 1G-103 MWD (1 G-103) MWD OWSG OWSG MWD - Standard 9/9/2019 9/9/2019 9/16/2019 8: 58: 52AM Page 2 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc-Kuparuk Local Coordinate Reference: Well 1G-03 Project Kuparuk River Unit TVD Reference: 1G-03 @ 89.50usft (1G-03) Site: Kuparuk 1G Pad MD Reference: 1G-03 @ 89.50usft(1 G-03) Well: 1G-03 North Reference: True Wellbore: 1G-103 Survey Calculation Method: Minimum Curvature Design: 1G-103 Database: EDT 14 Alaska Production Survey EIA 0 Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth 911812019 8'58,52AM Page 3 COMPASS 5000. 14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS +NWS +E1 -W DLS (usft) (°) (� (uaft) (usft) Wall (usH) Northing Easting (°)100) Section Survey Tool Name (ft) (ft) (ft) 3,800.00 4293 255.38 3.359.41 3.269.91 70.73 -1,369.71 5.981,838.13 536.666.50 5.52 70.73 MWD -INC ONLY (2) 3,808.00 43.07 256.09 3,365.26 3,27576 6943 -1,375.01 5961,836.80 538,661.21 3.03 69.43 MWD -INC ONLY(2) 3,831.51 48.29 256.00 3,381.68 3,292.18 65.37 -1391.33 5,981,832.66 538,644.92 2221 65.37 MWD -INC ONLY(2) 3,860.45 54.31 259.00 3,399.77 3,31027 60.51 -1,413.37 5,981,82768 538,622.90 22.32 60.51 MM -INC _ONLY (2) 3,890.28 60.83 261.68 3,415.76 3,326.26 55.31 -1.438.18 5,981,823.35 538.598.12 23.13 56.31 MWD OWSG(3) 3,920.95 67.54 264.45 3,429.11 3,339.61 53.00 -1,465.57 5,981,819.89 538.570.75 23.34 5300 MWD OWSG(3) 3,959.34 76.35 267.76 3.44100 3,351.50 50.55 -1,501.94 5981,817.24 538.534.39 24.37 50.55 MWD OWSG(3) 3,987.31 8177 271.11 3,446.31 3,35661 50.28 -1,529.39 5,981,816.83 538506.95 2266 50.28 MWD OWSG(3) 4,024.85 8859 273.65 3,449.46 3,359.96 51.84 -1,566.74 5,961,818.19 538,469.60 1938. 51.84 MWD OWSG(3) 4.054.99 88.71 27531 3450.17 3,360.67 &1w -1,596]7 5,981,82049 538,439.56 684 &130 MWD OWSG(3) 4,085.51 87.45 277.07 3.45120 3.361.70 57.69 -1,627,08 5.981,823.72 538409.23 6.07 57.69 MWD OWSG(3) 4,114.57 87.54 27894 3,45247 3,362.97 61.74 -1855.83 5981,82761 538.380.47 644 6174 MWD OWSG(3) 4,146.23 8797 280.72 3,453.71 3364.21 6714 -1,687.00 5,981,832.84 538,309.27 578 67.14 MWD OW$G(3) 4,176.03 89.11 282.77 3,454.47 3,364.97 73.20 -1,716.16 5,981,83875 538,320.08 7,87 7320 MWD OWSG(3) 4,206 00 89.75 284.93 3,454,76 3,365.26 80.37 -1,745.26 5,981,84577 538,290.95 7.52 80.37 MWD OWSG(3) 4,236.55 89.72 286.53 3,454.91 3,36541 88.66 -1,774,66 5,981,853.89 538,261.50 5.24 88.66 MWD OWSG(3) 4,266.63 89.82 287.81 3.455.03 3,365.53 97.54 -1.803.40 5,981,86261 538,232.72 4.27 97.54 MWD OWSG(3) 4,296.49 90.16 288.40 3,454.95 3,36545 106.81 -1.831.78 5,981,871.74 538,204.29 2.92 10.81 MWD OWSG(3) 4.326.35 9101 290.20 3.454.57 3.35507 116.68 -1,859.96 5,981,88146 538,176.06 6.30 116.68 MWD OWSG(3) 4,355.97 89.79 292.65 3,454.36 3,364.86 127.50 -1,887.53 5,981,892.13 538,148.44 924 127.50 MWD OWSG(3) 4,386.35 89.02 29427 3,454.68 3,365.18 139.59 -1,91540 5,981,904.07 538,120.51 590 13959 MWD OWSG(3) 4,416.45 ease 295.83 3455.24 3,365.74 152.34 -1,942.66 5,981,916 66 538.093.18 5.21 152.34 MWD OWSG(3) 4,446.38 88.25 297.06 3,455.99 3,366.49 165.66 -1,969.45 5,981,929.84 538,066.33 4.59 165.65 MWD OWSG(3) 4,480.41 88.86 29909 3,456.85 3,367.35 181.67 -1,999.46 5,981945.69 538,036.23 6.23 18167 MWD OWSG(3) 4,506.00 88.93 29978 3.457.34 3,367.84 194.24 -2,02175 5.981,958.14 538,013.88 271 194.24 MWD OWSG(3) 4,535.65 89.97 300.73 3,457.63 3,36813 209.18 -2,047.36 5.981.972 94 537,988.20 475 209.18 MWD OWSG(3) 4,566.18 90.09 30266 3,457.61 3,368.11 225.22 -2,073.33 5981,986.84 537,962.14 633 22522 MWD OWSG(3) 4,596.22 88.86 304.19 345789 3,366.39 24177 -2.098.40 5a82.005 25 537,936.98 6.53 24177 MM OWSG(3) 4,626.08 8862 306.19 3,458.54 3,369.04 25897 2,122.80 5,962,022.32 537,912.50 6.74 258.97 MWD OWSG(3) 4,656.11 89.17 307.24 3,459.12 3,369.62 276.92 -2.146.86 5.982.040.14 537889.34 395 276.92 MWD OWSG(3) EIA 0 Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth 911812019 8'58,52AM Page 3 COMPASS 5000. 14 Build 85H `. ConocoPhiiiip5 ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 1G-03 Project Kuparuk River Unit TVD Reference: 1G-03 @ 89 50usft (1G-03) Site: Kuparuk 1G Pad MD Reference: 1G-03 @ 69.50usft (1G-03) Well: 1G-03 North Reference: True Wellbore: 1G-103 Survey Calculation Method: Minimum Curvature Design: 1G-103 Database: EDT 14 Alaska Production Survey 9A ER f�1Gf1ES 9118/2019 8:58:52AM Page 4 COMPASS 5000. 14 Build 85H Map Map Vertical MD Inc Azi TVD NDSS -N/-S -E/-W Northing Easting DLS Section (usn) (^) (^) (usR) (usR) (usR) (usR) (.1100.)lRl Survey Tool Name Annotation IRI IRi 4,68623 9025 309.13 3459.27 3,36977 295.54 -2,170.54 5.982,058.63 537.864.57 723 29554 MWD OWSG (3) 4,716.27 90.40 310.38 3,459.10 3.369.60 314.75 -2.19363 5,982,077 72 537.841.37 4.19 314.75 MWD 0W$G(3) . 4,744.07 91.14 311.29 3,458.73 3,369.23 332.92 -221466 5.982,095 .78 537,820.25 4.22 332.92 MWD OWSG (3) 4,774.95 91.53 311.59 3,458.01 3,368.51 35336 -2,237.80 5,982,116.08 537.797.00 1.59 353.36 MWD OWSG (3) 4,80467 91.93 311.87 3457.11 3,367.61 373.13 -2,259.97 5,982,13574 537,774.72 1.64 373.13 MWD OWSG (3) 4,834.51 94.79 31194 3,45536 3,365.86 393.02 -2,282.14 5,982,155.51 537752.45 9.59 393.02 MWD OWSG (3) 4865.21 96.46 313.00 3,452.36 3.352.86 413.65 -2,304.68 5,982,17601 53].]29.81 6.43 413.65 MWD OWSG (3) j 4,895.57 97.88 314.66 3,448.57 3,35907 434.51 -2,32641 5,982,196.75 537,707.97 7.16 434.51 MWD OVVSG(3) 492347 9.82 316.54 3,444.76 3,355.26 4EuI26 -2,345.]4 5,982,21640 537.688.53 6.68 454.26 MWD OWSG(3) 4,956.05 96.96 318.29 3,440.56 3,351.06 478.09 -2.367.61 5,982,240.06 537,66654 5.94 478.04 MWD OWSG (3) 4,984.75 94.49 319.39 3.43770 3.348.20 499.54 -2,386.40 5.982,261 46 53764].64 9.41 499.54 MWD OWSG (3) i 5,014.75 9175 321.50 3,436.07 3.346.57 522.63 -2,405.47 5,9B2,284 45 537,628.44 11.52 522.63 MWD OWSG(3) 5,045.69 93.22 324.34 3,43413 3,345.23 547.29 -2,42411 5,982,309.00 537,609.68 1033 54729 MWD OWSG (3) 5,074.51 94.55 327.19 3,43277 3,343.27 571.06 -2,440.28 5,982,332.68 537,593.38 10.89 571.06 MWD OWSG (3) j 5,104.57 94.52 329.71 3,430.40 3,340.90 596.59 -2,455.96 5,982.358.13 537.57757 8.36 596.59 MWD OWSG (3) 5,14051 93.99 330.35 3,427.73 3,338.23 627.64 -2.473.86 5.982389 08 537.559.50 2.31 62764 MWD Ov1SG(3) 5,16537 i 9384 328.17 3,426.03 3,336.53 648.96 -2,486.54 5,982.41032 537,546.71 8.77 64896 MWD OWSG (3) 5.194.62 93.78 32529 3,424.09 3,334.59 673.36 -2,502.55 5,982,434.63 537,530.57 9.83 673.36 MWD OWSG (3) 5,223.19 93.35 32321 3,422.31 3,33281 696.50 -2.519.21 5.982.457 68 537,513.79 7.42 696.50 MWD OWSG (3) 5,25465 Was 325.77 3421.21 3.331]1 722.10 -2,537.47 5,982,483.18 537,495.39 11 75 722.10 MWD OWSG (3) 5,284.83 9129 328.08 3,420.69 3,331.19 747.37 -2,553.93 5,982,508.36 53747880 7.92 747.37 MWD OWSG (3) 5,314.59 8997 328.79 3,42036 3,330.86. 772.73 -2,569.51 5.982,533.63 53],463.09 5.04 ]]273 MWD OWSG (3) j 5,34597 88.89 329.02 3,42067 3.331.17 79959 -2,58572 5.98256041 537.446.74 3.52 799.59 MWD OWSG (3) 5,375.80 89.72 327.04 3,421.03 3,331.53 82490 -2,601.51 5.982,58563 537,430.81 7.20 824.90 MWD OWSG (3) 5.404.90 93.13 32729 3,420.31 3,330.81 649.34 -2.61728 5.982,609 98 537.414.91 11.75 849.34 MWD OWSG (3) 5,436.07 95.59 324.85 3,417.94 3,328.44 875.12 -2.634.62 5,962,635.67 537,397.43 11.10 875.12 MWD OWSG (3) 5,465.21 0.78 32].28 3,415.56 3,326.06 899.21 -2,650.83 5,982,65967 537,381.10 10.38 899.21 MWD OWSG (3) i 5,495.05 94.21 32876 3.413.48 3,323.98 924.46 -2.666.60 5.982,684.83 537,365.20 5.15 92446 MWD OWSG (3) 5,525.27 95.94 328.33 3.410.81 3.321.31 950.14 -2,682.31 5.98271042 537,349.36 5.90 950.14 MWD OWSG (3) 5.554.04 96.95 331.03 3,407.58 3318.08 974.82 -2,696.74 5,982,735.02 537.33479 9.96 974.82 MWD OWSG (3) 5,584.55 95.20 332.16 3,404.35 3,314.85 100150 -2741.17 5,982,76162 537.320.22 6.82 1001.50 MWD OWSG(3) 9A ER f�1Gf1ES 9118/2019 8:58:52AM Page 4 COMPASS 5000. 14 Build 85H Annotation Ht�1GHFS 9/18/2019 8.58: 52AM Page 5 COMPASS 5000. 14 Build 85H ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 1G-03 Project: Kuparuk River Unit TVD Reference: 1G-03 @ 89.50usft (1G-03) Site: Kuparuk 1G Pad MD Reference: 1G-03 @ 89.50usft (1G-03) Well: 1G-03 North Reference: True Wellbore: 1G-103 Survey Calculation Method: Minimum Curvature Design: 1G-103 Database: EDT 14 Alaska Production Survey ._ .. .. _... Map Map Vertical MD Inc Ai TVD TVDSS -NI-S +E/ -W Northing EasOng OLS SecBon (usft) (1) (1) (usft) (usft) (usft) (usft) (.1100' ) Survey Tool Name (ft) (ft) (ft) 561493 95.01 334.54 3.401.65 3,312.15 1028.54 -2,724.74 5,982,788.59 537,306.51 7.83 1.028.54 MWD OWSG(3) 5,64569 95.62 33723 3.398.80 3.309.30 1.055.50 -2737.25 5.982,816.47 537,293.85 893 1,056.50 MWD OWSG(3) 5,674.89 96.27 340.65 3,395.77 3,306.27 1,083.59 -2.74769 5.982,843.51 537,283.27 1186 1083.59 MWD 0WSG(3) 5,703.77 96.18 343.33 3,39199 3,302.49 1,116.57 -2,75841 5,982,87642 537,272.37 764 1,116.57 MWD OWSG(3) 5,739.83 95.23 344.75 3,389.00 3,299.50 1,145.32 -2.76663 5,982,905.13 537,264.00 5.66 1,145.32 MWD OWSG(3) 5,771.11 93.93 344.78 3.386.50 3,29700 1,175.41 -2.774.83 5,982,935.17 537,255.64 4.16 1,175.41 MWD OWSG(3) 5,601.47 9166 345.84 3.385.02 3295.52 1,204.74 -2.782.51 5,982,96446 537.24280 8.25 1,204.74 MWD OWSG(3) 5,831.38 9111 347.82 3,384.30 3,294.80 1,233.85 -2,78933 5,982,993.53 537,240.83 687 1.233.85 MWD OWSG(3) 5,865.07 89.82 349.98 3,384.02 3,294.52 1,266.91 -2,795.81 5,983,02655 537,234.17 7.47 1,Meet MWD OWSG(3) 5,895.12 92.73 35203 3,383.36 3,293.86 1,296.58 -2,80049 5,983,056.19 537,229.33 1196 1,296.58 MWD 0WSG(3) 5,925.16 95.16 354.78 3.381.29 3.291.79 1326.34 -2,803.92 5.983,085.94 537,22575 1205. 1326.34 MWD OWSG(3) 5,955.23 9544 356.78 3,378.51 3,289.01 1,356.20 -2,806.12 5,983,115.78 537,223.38 6.69 1,356.20 MWD OWSG(3) 5,98502 94.30 357.58 3,375.98 3,286.48 1,385.85 -2,807.58 5,983,14541 537,221.76 4.67 1.385.85 MWD OWSG(3) 6,015.35 9442 359.72 3,373.68 3,284.18 1416.08 -2,80830 5,983,17564 537,220.89 7.05 1,416.08 MWD OWSG(3) 6,04660 92.00 064 3371.92 3,282.42 1,447.32 -2,80820 5.983,206.87 537.220.82 8.27 1,447.32 MWD OWSG(3) 6,070.13 90.00 1.44 3,371.51 3,282.01 1470.80 -2,807.77 5,983.23036 537.221.12 9.17 1,470.80 MWD OWSG(3) 6,100.60 86.93 1.72 3,372.33 3,282.83 1,501.24 -2,806.93 5,983,260.80 537,221.80 10.12 1501.24 MWD OWSG(3) 6,130.36 84.71 1.89 3,374.50 3,285.00 1,53091 -2,806.00 5,983,29047 537,222.58 7.48 1,530.91 MWD OWSG(3) 6,160.43 85.11 2.21 3.377.17 3.287.67 1,560.84 -2,80493 5.983,320.40 537,223.49 170 1,560.64 MWD OWSG(3) 6,190.39 86.78 4.16 3.379.29 3,289.79 1.590.68 -2,803.26 5.983,350.24 537,224.99 8.56 1,590.68 MWD OWSG(3) 6,220.38 87.88 455 3,380.68 3,291.18 1,620.55 -2,800.99 5,983.380.12 537,227.10 3.89 1,620.55 MWD OWSG(3) 6,252.17 89.85 5.41 3,381.31 3,29181 1,652.21 -2,798.23 5,983,41179 537,229.69 676 1652.21 MAID OWSG(3) 6,28023 8969 6.62 3,38142 329193 1,680.11 -2,795.29 5,983,43971 .537.232.48 4.35 168011 WWD OWSG(3) 6,310.21 89.20 9.03 3,381 72 3,292.22 1,70981 -2,79121 5,983,469.43 537.236.40 8.20 1,709.81 MAID OWSG (3) 6,340.42 8926 10.10 3,382.12 3,29262 1,739.60 -2.78619 5,983,499.24 53724126 355 1,739.60 MWD OWSG(3) 6,370.32 89.72 1204 3,38239 3,292.89 1,768.94 -2,780.45 5,983,528.61 537,246,85 6.67 1768.94 MWD OWSG(3) 6,402.65 90.05 1192 3.38245 3292.95 1,800.56 -2,773.74 5983,560.26 537,253.39 1.12 1,800.56 MWD OWSG(3) 6.430.98 89.82 13.85 3,382.48 3.292.98 1,828.18 -2.76742 5,983,587,91 537,259.56 6.87 1,828.18 MWD OWSG(3) 6460.65 90.09 12AG 3,382.50 3293.00 1.85724 -2,760.50 5,983,617.00 537,266.32 321 1.857.24 MWD OWSG(3) 6.490.63 90.18 13.50 3.382.43 3292.93 1686.23 -2.753.70 5,983,646.03 537.272.97 1.94 1886.23 MWD OWSG(3) 6,52088 90.58 13.01 3,362.23 3,292.73 1.915.67 -2,746.76 5,983.675.50 53727975 2.09 191567 MWD OWSG(3) Annotation Ht�1GHFS 9/18/2019 8.58: 52AM Page 5 COMPASS 5000. 14 Build 85H ConocoPhillips eA ER ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc-Kuparuk Local Coordinate Reference: Well 1G-03 Project: Kuparuk River Unit TVD Reference: 1G-03 @ 89.50usft (113-03) Site: Kuparuk 1G Pad MD Reference: 1G-03 @ 89.50usft (113-03) Well: 1G-03 North Reference: True Wellbore: 1G-103 Survey Calculation Method: Minimum Curvature Design: 1G-103 Database: EDT 14 Alaska Production Survey 9/1872019 8:5852AM Page 6 COMPASS 5000. 14 Build 85H Map Map Vertical MD Inc Azi TVD NDS3 iNFS +E/ -W OLS (usft) (1) (1) (usft) lush) (usft) (usft) Northing Easting (°1100') Section Survey Tool Name Annotation (ft) (ft) (ft) 6.549.39 90.12 1205. 3.38206 3,292.55 1,943.50 -2.740.58 5,983,703.36 537,28578 373 1,943.50 MWD OWSG(3) 6,580.37 90.80 11.87 3,381,81 3.292.31 1973.81 -2.734.16 5.963,73370 537,292.04 2.27 197381 MWD OWSG(3) 6,60979 9061 12.37 3.38145 3.291.95 2.002.57 -2.727.98 5.983,762.49 537,29806 1.82 2,002.57 MWD OWSG(3) 6.639.09 90.25 14.56 3,381,23 3,291.73 2,031.06 -2,72116 5,983.79102 537.304.73 7.57 2,031.06 MWD OWSG(3) 6,66979 8954 15.56 3,381.28 3,29178 2,060.71 -2,713.18 5,983,820.70 537,312.55 3.99 2,060.71 MM OWSG(3) 6,700.14 90.28 17.23 3.381.33 3,29183 2.089.82 -2,704.61 5,983,849.86 537.320.96 602 2,089.82 MWD OWSG(3) 6,729.84 8960 17.65 3,361.36 3,291.86 2,118.16 -2.69571 5,983,878.24 53].32971 2.69 2118.16 MWD OWSG(3) 6,75962 8902 1760 3,381.72 3,292.22 2,146.54 -2,686.70 5,983,906.66 537,338.57 1.95 2,146.54 MWD OWSG(3) 6.789.89 88.22 18.22 3,382.45 3,292.95 2,175.33 -2,677.39 5983,93550 537,347.72 3.34 2,175,33 MWD OWSG(3) 6,819.51 88.93 18.83 3,383.19 3,293.69 2,203.41 -2,667.98 5,963,963.63 537,356.98 3.16 2.203.41 MWD OWSG(3) 6,847.82 90.64 16.64 3.383.29 3.293.79 2.230.37 -2.659.36 5.983.990.63 537,365.46 9.81 2230.37 MWD OWSG (3) 6,878.04 89.69 15.39 3.383.21 3,293.71 2.259.41 -2,651.02 5.98,1.019 72 537373.64 520 2.259.41 MWD OWSG(3) 6,907.70 8846 14.64 3,383.68 3,294.18 2,286.06 -2,643.34 5,984,048.40 537,381.17 4.86 2,28806 MWD OWSG(3) 6,938.59 87.14 14.54 3,384.87 3,295.37 2,31793 -2,635.57 5,984,078.31 537,388.78 4.29 2,31793 MWD OWSG(3) 6,970.23 85.14 1420 3,387.00 3,297.50 2,348.51 -2,62773 5,984,108.93 537.396.45 6.41 2,348.51 MWD OWSG(3) 7,000.17 86.47 11.89 3,389.19 3.299.69 2,37259 -2,620.99 5,984,138.05 537.403.03 8.88 2,377.59 MWD OWSG(3) 7,029.97 8739 9.38 3,390.79 3,301.29 2,406.84 -2,615.50 5,984,167.32 537,408.37 8.96 2.405.84 MWD OWSG(3) 7,059.51 86.59 9.47 3,392.34 3,302.84 2,435.94 -2.610.67 5,984,196.44 537,413.04 273 2.43594 MND OWSG(3) 7,091.10 85.32 9.70 3.394.57 3.305.07 2,467.01 -2.605.42 5,984,227.53 537418.12 4.D9 2,46701 MND OWSG(3) 7,126.39 83.70 8.35 3.397.94 3,308.44 2.50170 -2.599.91 5.984,262.25 537,42345 5.96 2,50170 MWD OWSG(3) 7.149.06 85.54 790 3,400.07 3,310.57 2,524.04 -2,596.72 5,964.284.61 537,426.52 8.35 2,524.04 MWD OWSG(3) 7,17955 87.79 7.15 3,40184 3,312.34 2,554.22 -2,592.74 5,984.314.80 537430.34 778 2,55422 MWD OWSG(3) 721032 88.77 7.01 3,402.7] 3.313.27 2.58474 -2,588.95 5.984.345.34 537.43397 3.22 2,564.74 MND OWSG(3) 7,24071 88.28 5.46 3,403.55 3.314.05 2,614.94 -2,585.64 5,984,375.55 537,43711 5.28 2,614.94 MND OWSG(3) 7269.12 88.43 4.01 3,404.36 3,314.86 2,643.24 -2,583.29 5,984.403.86 537,43931 5.20 2,643.24 MND OWSG(3) 7,299.89 8760 263 3,405.43 3,315.93 2,67394 -2,581.51 5,984.434.57 537,440.92 5.23 2,67394 MWD OWSG(3) 7,330.01 85.48 1.44 3.407.25 3,317.75 2,703.98 -258044 5.984.4&161 537441.83 8.07 2,70398 MWD OWSG(3) 7,360.55 87.17 2.44 3.409.20 3,319.70 2,734.44 -2.579.41 5.964.495.07 537,44270 6.43 2,734.44 MWD OWSG(3) 7,390.16 87.21 244 3.410.66 3.321.16 2.76399 -2,578.15 5,984,524.62 537443.80 0.14 2,763.99 MWD OWSG(3) 7,41944 8745 266 3,412.02 3,322.52 2,793.21 -2576.85 5,984.553.85 537444.95 1.11 2,793.21 MWD OWSG(31 7450.35 8914 2.39 3412.94 3.32344 282407 -257549 5.964.58472 537446.14 554 282407 MND OWSG(3) 9/1872019 8:5852AM Page 6 COMPASS 5000. 14 Build 85H ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc Kuparuk Local Co-ordinate Reference: Well 1G-03 Project: Kuparuk River Unit TVD Reference: 1G-03 @ 89.50usft (1G-03) Site: Kupamk 1G Pad MD Reference: 1G-03 @ 89.50usft (1G-03) Well: 1G-03 North Reference: True Wellbore: 1G-103 Survey Calculation Method: Minimum Curvature Design: 1G-103 Database: EDT 14 Alaska Production Survey 9/18/2019 8'56 52AM Page 7 COMPASS 5000. 14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Di Northing Easting Section Survey Tool Name Annotation (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (-moo') (ft) 7479.79 90.09 229 3.413.14 3.32364 2,853.48 -2,57429 5,964,614.13 53744719 324 2,853.48 MWD OWSG(3) 7,510.13 88.46 337 3.41352 3.324.02 2,88378 -2,57279 5,984,644.44 537,448.52 6.44 2,883.78 MWD OWSG(3) 7,538.90 89.82 3.24 3.413.95 3,324.45 2,912.50 -2.571.13 5.984,673 16 537,450.03 475 2912.50 MWD OWSG(3) 7,570.13 8862 263 3,41438 3,32488 2,943.69 -2.56953 5,984,704.35 537,451.46 4.31 2,943.69 MWD OWSG(3) 7,600.62 87.91 3.99 3,415.30 3,325.80 2,974.11 -2,567.77 5,984,734.78 537453A6 503 2,974.11 MWD OWSG(3) 7,62966 88.86 5.28 3,416.12 3,326.62 3,003.04 -2.56543 5.98,1,763 72 537455.25 5.52 3,003.04 MWD OWSG(3) 7,662.57 88.86 5.85 3,416.77 3,327.27 3,035.79 -2,562.24 5,989,79648 537.458.26 173 3,03579 MWD OWSG(3) 7.689.00 8763 5.91 3,417.58 3,328.08 3,062.07 -2,559.53 5.984,82277 537,460.83 4.65 3,062.7 MWD OWSG(3) 7,72024 84.50 361 3,419.73 3,330.23 3,093.12 -2,556.94 5,984,853.84 537,463.25 12.42 3,093.12 MWD OWSG(3) 7750.53 85.08 3.19 3,422.48 3,332.98 3,123.24 -2,555.16 5,984 883.95 53],464.88 2.36 3,123.24 MWD OWSG(3) 7,780.58 86.22 3.31 3.424.76 3.335.26 3.153.15 -2.553.46 5,984,913.88 537,466.41 361 3,153.15 MWD OWSG(3) 7,809.83 86.25 325 3426.68 3,337.18 3,182.29 -2.551.79 5,984,943.02 537,46793 023 3,182.29 MND OWSG(3) 7,840.23 85.67 2.46 3,428.82 3,339.32 3,212.58 -2,550.28 5,98497331 537469.28 322 3,212.58 MWD OWSG(3) 7,869.95 89.82 1.66 3,429.99 3,340,49 3,242.25 -2,549.20 5,985,002.98 537,470.19 1421 3,242.25 MWD OWSG(3) '.. 7,899.95 93.87 120 3,429.02 3,33952 3,272.22 -2,64845 5,9M,032 95 537.470.78 13.59 3,272.22 MWD OWSG(3) 7929.95 94.64 1.08 3,426.80 3,33730 3,302.13 -2,547.86 5,985,062.86 537,471.22 2.60 3,302.13 MWD OWSG(3) 7,960.11 92.77 3.05 3,42485 3,335.35 3,332.20 -2,546.77 5.985,092.94 537,472.14 9.00 3,332.20 MND OWSG(3) 7.990.31 90.95 3.03 3,423.87 3,334.37 3,362.34 -2,645.17 5,985,123.09 537473.58 603 3.362.34 MND OWSG(3) 8.02023 93.35 4.10 3,422.75 3,333.25 3.392.18 -2,543.31 5,985,152.93 537,475.28 878 3,392.18 MWD OWSG(3) 8.049.99 93.69 4.13 3.420.92 3.331.42 3.421.81 -2.541.18 5,985,182.57 53],47725 1.15 3421.81 MWD OWSG(3) ! 8,07823 9098 458 3,419]] 3,330.2] 3,449.94 -2,539.04 5,985.21071 537,479.25 9.73 3,949.94 MWD OWSG (3) 8,11041 69.20 7,17 3,419.72 3,330.22 3,481.95 -2,53574 5,98524273 537,48237 977 3,48195 MWD OWSG(3) 8,13965 88.77 7.63 3,420.24 3,330.74 3,510.94 -2,531.98 5,985271]4 537.485.98 2.15 3,51094 MWD OWSG(3) 8,16955 8764 8.51 3,421.17 3,331,67 3.540.53 -2,527.78 5,985,301.35 537.490.01 479 3,54053 MWD OWSG(3) 8,199.61 8764 9.42 3,422.41 3,332.91 3,570.19 -2,523.10 5,985,331.03 537,494.54 3.02 3570.19 MWD OWSG(3) 8,22878 88.77 9.58 3,423.32 3,333.82 3,598.95 -2,51829 5,985,35981 537,499.19 391 3,598.95 MWD OWSG(3) 8,259.61 90.03 9.89 3.423.65 3834.15 3,629.33 -2.513.08 5.985,390 22 537,504.24 421 3,62933 MND 0WSG(3) 8.289.61 87.91 10.54 3424.19 3,33469 3,658.85 -2,50776 5,985,41976 537,509.40 7.39 3,658.85 MWD OWSG(3) ( 8.319.85 86.93 11.36 3,425.55 3,336.05 3,688.51 -2.50202 5,985,44945 537,514.98 422 3,688.51 MWD OWSG(3) 8.347.82 86.07 12.29 3,427.25 3,337.75 3,715.83 $496.30 5,985,476.80 537,520.56 4.52 3,715.83 MND OWSG(3) 8,37909 8666 1245 3,429.23 3,339.73 3,746.32 -2,489.62 5,985,50732 537,527.08 202 3746.32 MWD OWSG(3) 9/18/2019 8'56 52AM Page 7 COMPASS 5000. 14 Build 85H ConocoPhiilip5 ConocoPhillips Definitive Survey Report Company: ConocoPhiliips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 1G-03 Project: Kuparuk River Unit TVD Reference: 1G-03 @ 89.50usft (1G-03) Site: Kuparuk 113 Pad MD Reference: 1G-03 @ a9.50usft (1G-03) Well: 1G-03 North Reference: True Wellbore: 1G-103 Survey Calculation Method: Minimum Curvature Design: 1G-103 Database: EDT 14 Alaska Production Survey Annotation SA ER �ucml�s 9/18/2019 8:58.52AM Page 8 COMPASS 5000.14 Build 55H Map Map Vertical MD Inc Azi TVD TVDSS +NIS +El -W DLS (usft) (°) (•) (usft) (uaft) (usft) (usft) Northing Easting (•DLS Section Survey Tool Name (ft) (ft) (ft) SAW 80 67.08 13.50 3,430.85 3.34135 3,775.23 -2,482.95 5,985536.26 537,533.58 378 3,775.23 MWD OWSG(3) 8,43948 89.23 14.30 3.431.84 3.342.34 3,804.99 -2.475.59 5.985,566.06 537,540.79 748 3,804.99 MWD OWSG(3) 8,46946 89.08 13.86 34.12.28 3.342.78 3,834.07 -2.468.30 5.985.595.17 537,547.93 155 3,834.07 MWD 0WSG(3) 8,501.12 86.81 13W 3,433.41 3,343.91 3.664.79 -2,46073 5.985,62593 537,555.32 7.17 3,864.79 MWD OWSG(3) 8,530.09 85.98 12.25 3,435.24 3,345.74 3,892.95 2,45422 5,985,654.13 537561.69 6.06 3,892.95 MWD OWSG(3) 8,560.33 85.11 11.53 3,437.58 3,348.08 3,922.45 -2448 01 5,985,68366 537.567.74 3.73 3,922.45 MWD OWSG(3) 8,589.19 85.05 9.12 3,440.06 3,350.56 3,950.74 -2,442.85 5,985711 97 537,572.74 8.32 3,950.74 MWD OWSG (3) 8,620.17 8567 8.11 3,44257 3,353.07 3,981.27 -2438.23 5.9a5.742 52 537,577.21 3.82 3,981.27 MWD OWSG(3) 8,65026 8.04 767 3.444.74 3,355.24 4,011.00 -2,43411 5,985,772.26 537,581.17 1.91 4,011.00 MWD OWSG(3) 8,684.25 87.11 7.42 3.446.77 3,35727 4,044.63 -2,429.65 5.985.805.92 537585.44 3.23 4,04463 MWD OWSG(3) 8,710.46 8803 766 3.447.88 3,358.38 4.070.59 -2.426.22 5,985,831 89 537,588.74 363 4,070.59 MWD OWSG(3) 8,740.41 87.48 646 3.449.06 3,359.56 4.1W.22 -2.422.02 5,985,861 54 537,592.77 324 4.100.22 MWD OWSG(3) 8.768.22 86.77 8.82 3,450.45 3,360.95 4,127.68 -2,417.85 5,985,889.02 537,596.80 2.86 4,127.68 MWD OWSG(3) 8.799.31 87.64 944 3,451.97 3,362.47 4,158.34 -2,41292 5.985.919.71 537,601.56 343 4,158.34 MWD OWSG(3) 8,82879 89.79 958 3,452.63 3,363.13 4,187.41 -2,408A5 5,985,M 79 537,606.28 7.31 4,187.41 MM OWSG(3) 8,857.23 90.95 9.85 3.452.44 3,362.94 4,21544 -2,403.25 5.985.976.85 537.610.92 4.19 4,215.44 MWD OWSG(3) 8.890.22 92.03 921 3,451.57 3,362.07 4,247.96 -2,39779 5,98,007 .40 537,616.21 3.96 4,247.96 MWD OWSG(3) 8,920.46 88.89 8.62 3451.31 3,361.81 4,277.83 -2,393.11 5,986,039.29 537,620.73 1076 4,277.83 MWD OWSG(3) 8,957.25 89.82 848 3,45173 3.362.23 4,314.21 -2.387.64 5.986,07569 537,626.01 2e6 4,314.21 MWD OWSG(3) 8,980 34 89.63 7.74 3,451.84 3.362.34 4,337.07 -2.384.38 5.986,098.56 537629.14 3.31 4,337.07 MWD OWSG(3) 9,013.19 90.37 6.34 3,451.84 3,362.34 4,369.67 -2,380.35 5,986,131.18 537,633W 4.82 4,369 67 MWD OWSG(3) 9.040.58 91.69 664 3,451.34 3,35184 4,396.8 -2,37726 5,986158.41 537,635.94 4.94 4,396.88 MWD OWSG(3) 9,068.49 91.38 6.55 3.450.60 3,361.10 4,424.59 -2,37405 5986,186.14 537.639.00 1.16 4,42459 MWD OWSG(3) 9,099.67 90.83 563 3,449el) 3,360.49 4,455.59 -2,37015 5,986.217.15 537.642.14 344 4,455.59 MWD OWSG(3) 9.129.70 90.8 560 3,449.60 3,360.10 4,485.48 -2,367.81 5.986,24704 537,644.92 0.51 4,485.48 MWD OWSG(3) 9.159.52 90.34 586 3,449.33 3,359.83 4,515.14 -2,364.83 5,986,276 73 537,0774 1.44 4,515.14 MWD OWSG(3) 9.189.67 8978 6.38 3.449.30 3.359.80 4.545.12 -2.361.62 598,30672 537,65079 2.53 4.545.12 MWD OWSG(3) 9,219.44 89.72 642 3.449.43 3.359.93 4.574.71 -2,358.30 598,336.32 537,653.95 024 4,574.71 MWD OWSG(3) 9,24951 90.22 6.8 3.44945 3.359.95 4,604.58 -2.354.87 5,98.38.20 537,657.22 1.87 4,84.58 MWD 0W9G(3) 9.279.23 90.37 728 3.449.29 3,359.79 4,634.08 -2,351.26 5,9839572 537,660.67 2.8 4,634.08 MWD OWSG(3) 9,30805 9043 758 3449.09 3,359.59 4662.66 -2.34753 5.98424.31 537,66425 1.07 4662.8 MWD OWSG(3) Annotation SA ER �ucml�s 9/18/2019 8:58.52AM Page 8 COMPASS 5000.14 Build 55H Survey ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc Kuparuk Local Co-ordinate Reference: Well 1G-03 Project: Kuparuk River Unit TVD Reference: 1G-03 @ 89.50usft (1G-03) Site: Kuparuk 1G Pad MD Reference: iG-03 @ 89.50usft (1G-03) Well: 1G-03 North Reference: True Wellbore: 1G-103 Survey Calculation Method: Minimum Curvature Design: IG -103 Database: EDT 14 Alaska Production Survey Annotation BAi�icdiEs' 9/18/2079 8:58,52AM Page 9 COMPASS 5000 14 Build 85H Map Map Vertical MD Inc Azi ND NDS) *N/ -S .Er -W DLS Northing Easting Section Survey Tool Name (usft) (°) (°) (usft) (usft) (usft) (usft) 9,339.02 90.55 8.10 3,448.83 3,35933 4.693.34 -2,343.31 5,986,455.01 537,668.31 172 4,693.34 MWD OWSG(3) 9,37021 90.06 8.84 3,448.66 3.359.16 4.724.19 -2,33871 5.98648588 537,672.74 2.85 4,724.19 MWD OWSG(3) 9,400.29 8942 9.50 3,448.80 3,359.30 4,753.88 -2,33392 5.986,51560 537,677.37 306 4,753.88 MWD OWSG(3) 9,430.35 89.14 968 3,449.18 3,359.68 4,783.52 -2,32891 5,986,545.26 537,682.22 1.11 4,783.52 MWD OWSG(3) 9,460.01 90.18 1032 3.449.35 3,359.85 4,812.73 -2,32376 5.986,574 49 537,687.21 4.12 4,812.73 MWD 0WSG(3) 9,490.43 89.05 11.10 3,449.56 3,360.06 4,842.61 -2.318.11 5,986,60441 537,692.71 451 4,842.61 MWD OWSG(3) 9,519.37 90.06 12.04 3,449.78 3,360.28 4,87097 -2,312.30 5,986,632.79 537.698.36 477 4,870.97 MWD OWSG(3) 9,549.21 91.26 11.70 3,44944 3,359.94 4,900.16. -2,306.17 5,986,652.02 537,704.34 4.18 4,900.16 MWD OWSG(3) 9,57963 9279 11.07 3,448.36 3,358.86 4,929.97 -2,30017 5,W,691 85 537,710.18 5.44 4,92997 MWD OWSG(3) 9,609.55 93.38 11.48 3,446.75 3,357.25 4,959.27 -2,294.33 5,966,721.17 537,715.86 2.40 4.95927 MWD OWSG(3) 9,639.15 90.09 12.19 3,445.86 3,356.36 4,988.22 -2.28826 59%,750.16 537.72177 11.37 4,988.22 MWD OWSG(3) 9,56965 87.91 12.37 3.446.39 3,356.89 5.018.02 -2,281.77 5.9%,779.98 537728.10 7.17 5,018.02 MWD OWSG(3) 9,699.98 88.53 1242 3,447.33 3,357,83 5,047.62 -2,27526 5,985,80962 537.734.45 2.05 5,047.62 MWD OWSG(3) 9,73086 88.74 1209. 3,448.07 3,356.57 5,0T7.79 -2,268.71 5,986,839.82 537,740.89 1.27 5,077.79 MWD OWSG(3) 9,760.41 8945 12.53 3,448.53 3,359.03 5,106.66 -2,26241 5,986,86872 537746.98 2.83 5,106.65 MWD OWSG(3) 9788.51 90.06 12.12 3,418.65 3,359.15 5,134.11 -2,256.41 5,986,896.20 537.752.83 2.62 5,134.11 MWD OWSG(3) 9,820.00 90.77 12.45 3,448.43 3,356.93 5,164.88 -2,249.71 5.986,927.00 537,759.37 249 5.164.88 MWD OWSG(3) 9,850.01 9135 12.73 3,447.87 3,358.37 5,194.16 -2,24317 5,986,956.32 537,765.75 215 5,194.16 MWD OWSG(3) 9,879.51 91.47 1380 3,447.14 3,357.64 5.222.87 -2.23641 5,966,985.05 537,772.36 3.65 5,222.87 MWD 0WSG(3) 9.909.34 91.93 13.69 3446.26 3.356.76 5,25183 422932 5,987,014.05 537,77929 1.59 5,251.83 MNID OWSG(3) 9,939.21 91.50 1448 3,445.37 3,355.87 5,28079 -2,222.06 5.987.043.04 537,786.40 3.01 5,280.79 MWD OWSG(3) 9,968.88 90.46 13% 3,444.86 3,355.36 5,303.54 -2,214.77 5987,071.84 537.793.53 3.93 5,309.54 MWD OWSG(3) 9,999.28 89.54 12.41 3,44486 3,355.36 5,339.14 -2,207.84 5,987,101.47 537.800.31 5.90 5,339.14 MM OWSG(3) 10,028.49 91.17 1322 3.444.68 3,355.18 5,367.62 -2,201.36 5,987,129% 537.80663 6.23 5,367.62 MM OWSG(3) 10.058.57 90.55 1460 3,444.23 3,35473 5,396.82 -2,194.13 5,987,159.21 53781370 5.03 5,396.82 MND OWSG(3) 10,087.78 8945 1368 3,444.23 3,354.73 5,425.14 -2,187.00 5,987,187.57 537,820.69 4.91 5,425.14 MWD OWSG(3) 10,11865 W07 13.53 3,444.89 3,355.39 5,455.14 -2,179.74 5,987,21760 537827 79 4.50 5,455.14 MWD OWSG(3) 10,149.29 87.61 13.10 3.446.05 3.356.55 5.484.93 -2.172.69 5987,24743 537,834.68 2.05 5,484.93 MW) OWSG (3) 10]80.13 W90 1203. 3.447.53 3,358.03 5,515.00 -2.165.98 5,987.27 53 537,841.22 4.16 5,515.00 MWD OWSG(3) 10,207.95 88.13 1217 3.448.73 3,359.23 5502.17 -2,160.16 5.987.30473 537,846.90 4.45 5,542.17 MWD OWSG(3) 10,239.13 88.99 1151 3,449.52 3,360.02 557268 2..15376 5.987.335.27 537,853.13 348 5,57268 MWO OWSG(3) Annotation BAi�icdiEs' 9/18/2079 8:58,52AM Page 9 COMPASS 5000 14 Build 85H ConocoPhillipsW!9 ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc-Kuparuk Local Co-ordinate Reference: Well 1G-03 Project: Kuparuk River Unit TVD Reference: 1G-03 @ 89.50usft (1G-03) Site: Kuparuk 1G Pad MO Reference: 1G-03 Q 89.50ustt (1G-03) Well: 1G-03 North Reference: True Wellbore: 1G-103 Survey Calculation Method: Minimum Curvature Design: 1G-103 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1 -S +E[ -W LS (usft) (1) (1) (usft) (usft) (usft) (usft) Easting (11100.) Section Survey Tool Name Annotation (ft) (ft) (ft) 10,P0.8] 89.48 1078 3,449.94 3,360.44 5.603.82 -2.14]63 5,987,366.44 53],7, 859.10 2.77 5,603.62 MWD OWSG (3) 3 10.299.54 89.85 10.31 3.450.11 3,360.61 5,632.00 4,14238 5.987,394.65 537,854.19 209 5,632.00 MWD OWSG (3) 10,328.94 91.35 9.77 3,449.80 3.360.30 5.660.95 -2,13226 5,987 423,62 537,869.16 5.42 5,660.95 MWD OWSG (3) 10,357.79 91.20 925 3,449.16 3,359.66 5,689.40 -2,13249 5,987,45209 537,873.77 1.88 5,689.40 MWD OWSG (3) 3 10,388.32 90.43 9.19 3,448.72 3,359.22 5,719.53 -2,127.60 5,987,48224 537,878.50 2.53 5,719.53 MWD OWSG (3) 10420.55 89.14 8.11 3,448.84 3,359.34 5,751.39 -2,122.75 5.987,514.13 537,883.18 522 5.751.39 MWD OWSG(3) 10,451.31 88.89 7.99 3,449.37 3.359.87 5,781.84 -2,118.45 5.987,54460 53].887.32 0.90 5,781.84 MWD OWSG (3) 10.480.74 90.06 7.92 3,449.69 3,305.14 5,810.99 -2,114.37 5.967,573]6 537,891.24 398 5,810.99 MWO OWSG (3) 10,510.39 91.23 7.97 3.449.31 3,35981 5,840.35 -2,110.28 5.987,603 14 537,895.18 3.95 5,840.35 MWD OWSG (3) 10.538.75 93.32 7.80 3,448.18 3,358.68 5,868.42 -2,106.39 5,987,63123 537,898.92 7.39 5,868.42 MWD OWSG (3) 10,561.34 92,77 7.56 3.446.98 3.357.48 5,890.78 -2.103.37 5.987,653 60 537,901.81 266 5,89078 MWD OWSG (3) 10,599.16 89.14 445 3.446.35 3.356.85 5,928.37 -2,099.42 5.987.691.21 537,905.57 12.64 5.928.37 MWD OWSG (3) i10.630.05 89.97 3.28 3,446.59 3,357.09 5,959.19 -2,097.34 5,987722.04 537,907.48 464 5,959.19 MWD OWSG (3) 10,66011 89.66 3.79 3,446.69 3,357.19 5,989.19 -2,095.48 5,987752.05 537,909.18 1.99 5,989.19 MWD OWSG (3) 3 10.690.09 89.26 2.43 3,446.97 3,357.47 6,019.13 -2,093.86 5,987,781.99 537,910.64 473 6,019.13 MWD OWSG (3) 10,720.04 i 90.98 3.16 3,446.91 3,357.41 6,049.04 -2,092.40 5,987.811.90 537.911.94 6.24 6,049.04 MWD OWSG (3) 10.749.67 90.37 1.88 3,446.56 3,357.06 6.078.64 -2,091.09 5,967841 51 537,913.09 4.79 6,07864 MWD OWSG (3) 10.775.95 90.09 2.79 3,446.45 3,356.95 6,104.90 -2,09002 5,987,86777 537,914.02 3.62 6,104.90 MWD OWSG (3) 10,810.27 89.85 2.77 3.446.47 3,356.97 6,139.18 -2,088.36 5,967,902.05 537,915.50 070 6,139.18 MWD OWSG (3) 10,839.00 89.36 2.71 3.446.67 3,357.17 6,167.87 -2.08699 5.987,93075 537,91672 1.72 6,167.87 MWD OWSG (3) 10,869.81 89.45 2.15 3,446.99 3,35749 6,198.65 -2,085.60 5,987,961.53 537,917.94 0.66 6,198.65 MWD OWSG (3) 10,89995 90.09 383 3447.11 3,35261 6,22874 -2,083.94 5,967,99163 537,91949 5.02 622874 MWD OWSG(3) 10,936.39 89.97 462 3,44209 3,357.59 6,265.08 -2,081.26 5,988,027.98 53792193 2.19 6,265.08 MWD OWSG (3) 10.957.21 9037 4.54 3,U703 3,367.53 6,285.84 -2,07960 5,968,04874 537.923.48 1.96 6,285.84 MWD OWSG (3) 10,969.46 91.81 6.17 3,446.42 3,356.92 6,317.94 -2.07659 5,988,08086 537,926.31 674 6,31794 MWD OWSG (3) 11,019.57 93.47 743 3,445.03 3,355.53 6,34780 -2,073.03 5,988,11074 537,92971 6.92 6347.80 MWD OWSG (3) 11,04969 90.d6 6.77 3444.00 3.359.50 6,377.67 -2,06931 5.989,14062 537,933.27 10.23 6,37767 MWD OWSG (3) 11,109.71 90.15 6.98 3.443.68 3,354.18 6437.26 -2.052.12 5,988,20024 537,940.14 0.62 6,437.26 MWD OWSG (3) 11,143.87 91.90 7.11 3.443.07 3,353.57 6,471.15 -2,057.93 5988,234.15 537,944.15 5.14 6,471.15 MWD OWSG (3) 11,171.35 91.60 7.67 3.442.23 3,35273 6,498.39 -2,05440 5,988,26141 537,947.53 231 6,498.39 MWD OWSG (3) 11,198 72 91.08 668 3.441.59 3,352.09 6,52554 -2050% 5,988.288.57 537.950.81 408 6,525.54 MWD OWSG (3) 9/18/2019 8: 58 52A Page 10 COMPASS 5000. 14 Build 85H ConocoPhillips ER a ConocoPhilli` u�" ps Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 1G-03 Project: Kuparuk River Unit TVD Reference: 1G-03 @ 89.50usft (1G-03) Site: Kuparuk 1G Pad MD Reference: 1G-03 @ 89.50usft (1G-03) Well: 1G-03 North Reference: True Wellbore: 1G-103 Survey Calculation Method: Minimum Curvature Design: 1G-103 Database: EDT 14 Alaska Production Survey MD Inc Azi TVD TVDSS -NAS+El•W Map Map DLS Vertical (1+sft) C) (') (waft) (uaft) (usft) (usft) Northing Easting Section Survey Tool Name Annotation (ft) (ft) (°1109•) (ft) 11,228.59 91.44 8.15 3.440.93 3,351.43 6,555.15 -2,047.13 5,986318.20 537,954.50 5.07 6,555.15 MWD OWSG(3) 11,257.57 9028 7.70 3,440.50 3.351.00 6,583.85 -2,043.13 5,988,346.92 537,958.34 4.29 6583.85 MWD OWSG(3) 11289.59 88.96 6.43 3,44071 3.351.21 6,615.63 -2,039.20 5,988,378.71 537,952.11 572 6,615.63 MWO OWSG(3) 11,319.60 86.31 6.68 3,44195 3,352.45 6,645.41 -2,035.77 5,988,408.51 537,965.37 8.87 6,645.41 MWD OWSG(3) 11,34978 8979 9.05 3,442.97 3,353.47 6,675.28 -2,031.65 5,988,438.40 537,969.34 1395 6,675.28 MWD OWSG(3) 11,37803 89.54 961 3,443.14 3,353.64 6,703.16 -2,027.07 5,983A66 30 537,973.77 2.17 6,703.16 MWD OWSG(3) 11,409.51 90.03 9.46 3,443.26 3,35376 6,734.20 -2,021.85 5,988.497.37 537.978.82 163 6,734.20 MWD OWSG(3) 11,439.71 89.79 9.55 3,443.30 3,353.80 6,763.99 -2,016.86 5,988527.18 537,983.65 0.85 6,763.99 MWD OWSG(3) 11.469.46 90.18 9.70 3,443.31 3,353.81 6,793.32 -2.011.89 5.988,556.53 537,988.46 1.40 6,793.32 MWD OWSG(3) 11,50041 8975 9.83 3,443.33 3,353.83 6823.82 -2,006.64 5.988,587.06 537,993.55 145 6,823.82 MWD OWSG(3) 11,529.87 90.03 10.34 3,443.39 3.353.89 6.852.83 -2.00148 5.968,616 09 537,998.55 1.97 6.852.83 MWD OWSG(3) 11,55981 89.75 9.95 3.44344 3353.95 6.882.30 -1.996.21 5,988,645.58 $38.00367 160 6,882.30 MWD OWSG(3) 11,569.04 89.69 10.10 3,443.59 3,354.09 691108 -1,991.12 5,966674.39 538,008.60 0.55 6,91108 MWD OWSG(3) 1161863 8951 9.83 3,44379 3,354.29 6,940.23 -1,986.00 5,988,70356 538,013.56 1.10 6,940.23 MWD OWSG(3) 11649.61 90.15 1067 3,44389 3,354.39 6,970.71 -1,98049 5,988,73407 538018.91 3.41 6,970.71 MWD OWSG(3) 11,680.03 90.64 11.14 3.443.68 3,354.18 7,000.58 -1,974.73 5,988.763.97 538,024.51 2.23 7,000.58 MWD OWSG(3) 11,718.93 90.15 1149 3,443.41 3,353.91 7,038.72 -1,967.10 5,988,802.15 538,031.93 1.55 7 M72 MWD OWSG(3) 11,738.92 90.00 10.18 3,443.38 3,353.88 7.058.36 -1,963.34 5,988,821.80 538,035.59 680 7.058.36 MWD OWSG(3) 11,770.47 89.60 9.98 3."3.49 3,353.99 7.089.42 -1,957.82 5,988,852.89 538.040.94 142 7,089.42 MWD OWSG(3) 11,800.41 8960 10.10 3."3.70 3,354.20 7.118.90 -1,952.60 5,988,88239 538,046.00 040 7,118.90 MWD OWSG(3) 11,83068 89.20 10.86 3,444.02 3,354.52 7,148.66 -1947.10 5.988.912.18 538,05135 2.84 7,148.6 MWD OWSG(3) 11,860 37 88.71 9.98 3,4".55 3,35506 7,177.86 -1,941.73 5,988,94140 538,056.56 3.39 7,177.86 MWD OWSG(3) 11,88998 6785 10.39 3,445.45 3,355.95 7,206.99 -1,936.49 5,96.97055 538,061.64 3.22 7,206.99 MWD OWSG(3) 11913.13 88.31 11.03 3,446.22 3,356.72 7,229.72 -1,932.19 5,988,993.31 538.065.82 3.40 7,229.72 MWD OWSG(3) 11,96.00 6.31 11.03 3."761 3.35811 7,275.71 -1,923.23 5,989,039.34 538,07453 0.00 7,275.71 PROJECTED WTD 9/182019 8:58:52AM Page 11 COMPASS 5000 14 Build 85H THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Shane Germann Senior 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. o ogcc.alaska.gov Re: Kuparuk River Field, West Sak Oil Pool, KRU 1G-103 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-110 Surface Location: 4151' FNL, 264' FWL, SEC. 29, T12N, R1OE, UM Bottomhole Location: 2771' FNL, 2046' FWL, SEC. 19, T12N, R10E, UM Dear Mr. Germann: 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, 440w-� Daniel T. Seamount, Jr. Commissioner DATED this4Vdayof August, 2019. STATE OF ALASKA X KA OIL AND GAS CONSERVATION COMNV. 31ON PERMIT TO DRILL 20 AAC 25.005 Alit 0 2 2019 - 1a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c Specify if well isproposWor: Drill Lateral Stratigraphic Test ❑ Development - Oil ❑ Service - Win! ❑� Single Zone E Coalbed Gas ❑ Gas Hydrates ❑ E❑ Redrill 117 Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply E 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 1G-103 ' 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 11,580' TVD: 3433' Kuparuk River Field / West Sak Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: ADLaOM63.5 Surface: 4151' FNL, 264' FWL, Sec 29, T72N, R10E, UM ADL 25640 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Sputl teo 4290' FNL, 3746' FWL, Sec 30, T12N, R10E, UM LONS 83-25 C 8/2V2019 I -/ Y Total Depth: 9. Acres in Property: 14. Distance terNearest Property: 2771' FNL, 2046' FWL, Sec 19, T12N, RICE, UM 2560 - 17,572' - 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 90' 15. Distance to Nearest Well Open Surface: x- 540036.44 y- 5981774.73 Zone- 4 GL / BF Elevation above MSL (ft): 56' - to Same Pool: 448', IG -16 16. Deviated wells: Kickoff depth: 3812 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 94 degrees Downhole: 1516 ' Surface: 1179 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) 4-1/4" 3-1/2" 9.2# L-80 R-2 167' 3802' 3361' 3969' 3435' Solid Liner 4-1/4" 2-7/8" 6.5# L-80 R-2 7611' 3969' 3435' 11580'• 3433' Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 8489' 6951' 3959' 8463' 6928' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 78' 16" 325 sx AS 11 108' 108' Surface 2274' 10-3/4" 1400 sx AS III, 250 sx AS 1 2303' 2216' Production 10.166' 7" 900 sx Class'G', 250 sx AS 1 8464' 6929' Perforation Depth MD (ft): 3669'-3826', 7315'-7317', 7496-752511 Perforation Depth TVD (11): 3264'-3378', 5953'-5955', 6104'-6129', 6142'-6161', 7540'-7563', 7772'-7825' 6336'-6380' 1 Hydraulic Fracture planned? Yes El No Q 20. Attachments: Property Plat ❑ BOP Sketch Diverter Sketch Drilling Program B Seabed Report Time v. Depth Plot e Drilling Fluid Program Shallow Hazard Analysis e 20 AAC 25.050 requirements 4 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 McLaughlin Authorized Name: Shane Germann Contact Email: rVan.mclaughlinacolp.conn Authorized Title: 4 aenjor CTD Engineer Contact Phone: 907-265-6218 Authorized Signature: Date: Commission Use Only Permit to Drill API Number: Permit Approva See cover letter for other Number: 50- p 2 — Q Date: 21 M 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: � - 'Samples r d: Yes eq' ❑ No[�]'r Mud log req'd: Yes❑ No Other: UqQP f?Si` 7'07 5O0 r Gv i t1 /'7"ar ve vi t?/' t.$ t � 23 �-I,S measures: Yes ❑ NO2". Directional svy req'd: Yes E( No,❑-,/ / /prr- ` /`% wa-1 v-ct t 26e llc 2-s- o 3 9 (d� SDIcing exception req'd: Yes ❑ NoLJ Inclination -only svy req'd: Yes ❑ NOE 'fl/ /-�Cr w'&J C��- 7-p e ctY WCSf Sq k Post initial injection MIT req'd: Yes[allo❑ d Lye hrJ i, fi` pn S for /¢Ppm✓4'. n�cc frb»_D.bZ 1�f.' f1r'b IV1jC ct1aYl vr/F f3dne '1;1 (20fiAC�S•�3�l�]) / w�11 .rte vlYc a S N re M,-Clrafitrn . lt'�1o9 rid oiftt,—Srcrbi!/3fd l'�J arld e✓� 7 two / r APPROVED BY j /� Approved by: COMMISSIONER THE COMMISSION Date: Zi Z7, �- Form f0-40'� Revised 5/2017 y� ���1 TM ? 0 riltt s per i valid O O 2 IN't t r e NA Submit Form and t approval per 20 AAC 25.005(9) Attachments in Duplicate ���r9 ASB 8js/I4 KRU 1G-103(PTD 219-110) Conditions for Approval A waiver to 20 AAC 25.030(d)(5) is granted for KRU 1G-103 subject to the conditions outlined below The condition applies to wells where the West Sak or the Ugnu is not zonally isolated with cement under regulation 20 AAC 25.030(d)(5) and/or where the OA(below a cement packer) is in hydraulic communication with the reservoir or injection fluids as a result of West Sak CTD. This includes any wells in the AOR of a West Sak injector or a newly drilled West Sak CTD well(injector or producer) from a plugged Kuparuk wellbore. These wells must be identified in a single list and the OA pressure tracked and reported to the AOGCC upon request or when an anomalous OA pressure is detected. The list must include information on the mechanical integrity of the well specifically the IA and OA pressures and the MIT history. A complete list in a proposed format is due to the AOGCC by 9/30/19 for review and approval. This condition is in addition to existing sustained casing pressure (SCP) rules. A waterflow log is required after stabilized injection from the window to above the Ugnu. Subsequent waterflow logs are required every two years. Any out of zone injection will require remediation. Maximum West Sak injection gradient is 0.62 psi/ft. This waiver is granted based on specific to this well reservoir properties, reservoir management, well configuration and well history among other factors. This waiver is granted exclusively to KRU 1G-103 which is a well in a West Sak CTD pilot area. This waiver may not be granted in the future to a well with a similar configuration but instead the well may require rig intervention and/or remedial cementing to comply with regulations. ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 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 application for permit to drill one laterals out of the KRU 1G-03 (PTD# 182-149) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin on August 21st, 2019. The objective will be to drill one lateral — 1G-103 to the North of the parent bore and target the West Salk B -sand. — To account for geological uncertainties, ConocoPhillips request a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along a length of the parent lateral instead of being limited to 500' from the original point. Attached to this application are the following documents: no t Yc<o%� - Permit to Drill Application Forms (10-401) for 1G-103 - Detailed Summary of Operations - Directional Plans for 1 G-103 - 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 G-103 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))................................................................................................................... 2 2. Location Summary .......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)).................................................................................................................................................. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)).. ......... _..........................................................................................................2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 7. Diverter System Information ..........................................................................................................3 (Requirements of 20 AAC 25.005(c)(7))........................................................................................._....... .................................. ............. 3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................4 10. Seismic Analysis.............................................................................................................................4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11)) . ................ ................. .......................................................................................4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................5 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 5 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 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 1G-103....................................................................................................................8 Attachment 2: Current Well Schematic for 1G-103.........................................................................................................8 Attachment 3: Proposed Well Schematic for 1G-103......................................................................................................8 Page 1 of 8 August 1, 2019 PTD Application: 1G-103 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed lateral described in this document is 1G-103. The lateral will be classified as "Service - Winj" well. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) The lateral will target the B sand package in the West Sak reservoir. See attached 10-401 form for surface and subsurface coordinates of 1 G-103. 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 2,500 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 1 R-126, assuming a gas gradient of 0.1 psi/ft, would be 1179 psi. See the "Drilling Hazards Information and Reservoir Pressure" seen for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The 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 1516 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)) Free gas is not anticipated while drilling the 1 G-103 lateral. 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 G-103 lateral 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 G-103 lateral will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 8 August 1, 2019 PTD Application: 1G-103 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" 65.0 H-40 Welded Surface 2-7/8", 6.5#, L-80, ST -L slotted liner, Surface 108' 1640 670 Surface 3-1/2", 9.2#, L-80, ST -L solid liner in 1G-103 3802' 11,580' 3361' 3433' the build; Sealbore deployment sleeve 2216' 3580 2090 Production 7" on to Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top TVD Btm TVDpsi Burst Collaps a psi Conductor 16" 65.0 H-40 Welded Surface 108' Surface 108' 1640 670 Surface 10-3/4" 45.5 K-55 BTC Surface 2303' Surface 2216' 3580 2090 Production 7" 26.0 K-55 BTC Surface 8464' Surface 6929' 4980 4320 Tubing 4-1/2" 12.8 L-80 HYD 503 Surface 3633' Surface 3283' 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 1G-103 lateral 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 8 August 1, 2019 PTD Application: 1G-103 Pressure at the 1G-103 Window (3812' MD, 3369' TVD) Using MPD v 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background O'�? !io } `l KRU well 1 G,102'was recently worked over, plugging the existing Kuparuk A and C sand completion, and is now equipped with 4-1/2" tubing and tandem wedges to perform a CTD exit in the West Sak. The CTD sidetrack will utilize one lateral to target the West Sak B -sand to the north of 1G-03. l f- jco 3 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 3812' MD CDR3-AC will use the whipstock to mill a window in the 4-1/2" and 7" casing strings. The 1G-103 lateral will be drilled to the north to a TD of 11,580' MD. The 1G-103 lateral will be completed with 2-7/8" slotted liner from TD alp to the end of the bald 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 3812' MD 2. Prep site for Nabors CDR3-AC rig. Page 4 of 8 August 1, 2019 Pumps On 3 bpm) Pumps Off B -sand Formation Pressure 8.65 1515 psi 1515 psi Mud Hydrostatic 8.4 1472 psi 1472 psi Annular friction (i.e. ECD, 0.035psi/ft) 133 psi 0 psi Mud + ECD Combined no chokepressure) 1605 psi Overbalanced -90 si 1472 psi Underbalanced -43psi) BHP at Window 8.65 1515 psi 1515 psi —Target Choke Pressure Required to Maintain Target BHP 0 psi 43 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background O'�? !io } `l KRU well 1 G,102'was recently worked over, plugging the existing Kuparuk A and C sand completion, and is now equipped with 4-1/2" tubing and tandem wedges to perform a CTD exit in the West Sak. The CTD sidetrack will utilize one lateral to target the West Sak B -sand to the north of 1G-03. l f- jco 3 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 3812' MD CDR3-AC will use the whipstock to mill a window in the 4-1/2" and 7" casing strings. The 1G-103 lateral will be drilled to the north to a TD of 11,580' MD. The 1G-103 lateral will be completed with 2-7/8" slotted liner from TD alp to the end of the bald 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 3812' MD 2. Prep site for Nabors CDR3-AC rig. Page 4 of 8 August 1, 2019 PTD Application: 1G-103 Rig Work 1. MIRU Nabors CDR3-AC rig using 2-5/8" coil tubing. NU 7-1/16" BOPS, test. 2. 1G-103 Lateral (West Salk B -sand -North) a. Mill 3.80" window at 3812' MD b. Drill 4-1/4" bi-center lateral to TD of 11,580' MD. c. Run 2-7/8" slotted liner and 3-1/2" solid liner with sealbore deployment sleeve from TD up to 3802' MD. 3. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 4. 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 1G-103 lateral 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. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). Page 5 of 8 August 1, 2019 PTD Application: 1G-103 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 Distance 1G-103 17, 572' - Distance to Nearest Well within Pool Lateral Name I Well IG -103 1 448' 1G-16 Page 6 of 8 August 1, 2019 �br ConocoPhillips Alaska West Sak CTD Wells with Injector 1/4 -mile Buffers and West Sak Intervals Marked In Other Wells 7/23/2019 ADL025635 ®1 D 0.2 0.4 0.6 Miles -Kupwk Well - not cemented -. -Ail YM Ku kWell- cemented Suspended Well - West Sek CTDlrge P&AWel1 West Sek CTD Producer CPAI Leeee WS COT Inledm-114 Mile Buffer of WS lntery PTD Application: 1G-103 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) �f• Within 1/4 Well Surface Casing Cement Arctic Pack Surface Surface Mechanical Integrity Topof D- Top of D- Surface Surface 1G -03i Well Well wall (RWO) 1 Casing Set Casing Set PTD API OA' 41 bbl cmt+ 717 Bbl NORMAL WELL Oil Sand Oil Casing Set Casing Set Name Classification Status SG -03 PF-Ctail. Full returns entire fob, circ tracer+ CBL 41 bbl = MIT -OA to IBM psi passed 11-25-18 Across Across Across West 392 sx cement to surface. No 844' to csg annuli. CBL Pool (MD) Pool (TVD) Depth (MD) Depth (TVD) 2500' 1`111). 10-3/4": 1300 sx (445 bbl) of AS -111 12.2 orf 41 bbl cmt + 777 Bbl WMfERED WELL IAxOA Ugnu? Sak? 1603 li 182-149 50.029-2082<M Injector MjiioUne 3,781 3.345 2,303 2,216 F45E FALSE TRUE 250 sx (41 bbl) of 15.7 ppg, and (2) 150 sx (25 bbl) of 15.7 ppg- FIT= 12,5 ppg 1696 i 162-220 50-029.20890.00 Injeaw inlemna km 3,343 2,218 2,150 FALSE FALSE 117- IlG �1�ti Ivin"AA to 2500 psi passed 12/2/18 250 sx of 156 ppg PF -C tai 1. Good 1616 183-155 521031-00 0.029- a LM 4,154 3,333 2,642 2,250 FALE FAL11 1.2.5 ppg EMW. shows excellent frond 2050'-2605'. 7-5/8": 357 bbl of 10.7 ppg lead + 76 2617 199-062 50029-22945-00 Pmtlucer prof ir, 3524 3.363 4] 31939 TRUE TRUE �f• Page 7 of 8 August 1, 2019 Within 1/4 Well Surface Casing Cement Arctic Pack Mile of Mechanical Integrity Name Operations Summary Cement Ops 1G -03i (RWO) 1 10-3/4":1400 sx (479 bbl) of AS -111 122 OA' 41 bbl cmt+ 717 Bbl NORMAL WELL diesel, 1013/82, RA MIT-iA to 3000 psi passed 11-25-18 ppg lead + 250 sx (41 bb9) of 15.7 ppg SG -03 PF-Ctail. Full returns entire fob, circ tracer+ CBL 41 bbl = MIT -OA to IBM psi passed 11-25-18 392 sx cement to surface. No 844' to csg annuli. CBL reciprocation. FIT =125 ppg EN1W. shows tracer -2100- 2500' 1`111). 10-3/4": 1300 sx (445 bbl) of AS -111 12.2 orf 41 bbl cmt + 777 Bbl WMfERED WELL IAxOA ppg lead+ 250 sx (41 bbl) of 15-7 ppg diesel, 1/30/83. 41 bbl MIT -OA to 18DD psi passed 3/8/18 PF -C tail. Partial returns, entire job, no = 844' in csg annuli. MIT -IA to 3000 psi passed 318/18 1G-06 cement to surface. Two top jobs: (1) TRUE 250 sx (41 bbl) of 15.7 ppg, and (2) 150 sx (25 bbl) of 15.7 ppg- FIT= 12,5 ppg EMW- 10-3/4":1050 sx of PF -E 12.4 ppg lead + OA. 50 bbl cm; 104 bbl TROUBLED WELL due to slow TxIA diesel, 11/8/83. 50 bbi Ivin"AA to 2500 psi passed 12/2/18 250 sx of 156 ppg PF -C tai 1. Good IG -16 returns entire job, circ 235 bbl cement =1029' in csg annuli, MIT -OA to 1000 psi passed 12/2/18 TRUE to surface. No reciprocation. FIT= 104 bbl = 2141'. CBL 1.2.5 ppg EMW. shows excellent frond 2050'-2605'. 7-5/8": 357 bbl of 10.7 ppg lead + 76 No record NORMAL WELL SG -17 bbl of 15.8 ppg tail. 89 bbl cement to MIT -OA to 1600 psi passed 11/19/09 TRUE surface. LOT =15A ppg EMW- CM1T-IA to 250D psi passed 12/6!17 Page 7 of 8 August 1, 2019 Loepp, Victoria T (CED) From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Thursday, August 29, 2019 9:51 AM To: Loepp, Victoria T (CED); Eller, J Gary Cc: Ohlinger, James 1 Subject: RE: [EXTERNAL]KRU 1G-103(PTD 219-110) West Sak Injector CTD AOR plat Attachments: WS_1 G_1 R_CTD_wells_otherwell_WS_interval_20190722.png Victoria, Please see attached ''/< mile plat along with the following list of wells within 1320' of 1G-103 wpo4: IG -103 wp04 275' from 1 G-03 at 4109' MD 448' from 1 G-16 at 4666' MD 454' from 1 G-116 w 03 at 4094' MD 668' from 1 R-06 at 11568' MD 668' from 1 R -06A at 11568' MD 668' from 1 R-06AL1 at 11568' MD 668' from 1R-06AL1-01 at 11568' MD 668' from 1 R-06AL2 at 11568' MD 668' from 1 R-06AL2-01 at 11568' MD 983' from 1G-17 at 3814' MD 1148' from 1 G-06 at 3813' MD 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: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, August 29, 2019 8:55 AM To: McLaughlin, Ryan <Ryan. McLaughlin @conocophillips.com>; Eller, J Gary <J.Gary.Eller@conocophillips.com> Cc: Ohlinger, lames J <James.J.Ohlinger@conocophillips.com> Subject: [EXTERNAL]KRU 1G-103(PTD 219-110) West Sak Injector CTD AOR plat Rya n, Please send an AOR''/< mile plat for 1G-103. Thanx, Victoria PTD Application: 1G-103 17. Attachments Attachment 1: Directional Plans for the 1 G-103 lateral Attachment 2: Current Well Schematic for IG -03 Attachment 3: Proposed CTD Well Schematic for the IG -103 lateral Page 8 of 8 August 1, 2019 Well KRU XX -XX Nabors CDR3-AC: 4 -Ram BOP Configuration Date June 26, 2019 2-5/8" Coiled Tubing and 3.1/8" BHA Quick Test Sub to Ot Top of 7" Otis Distances from top o Excluding quick -test Top of Annular C, Annular Bottom Annular Flanl CL BlindlShears Q 2-518" Combi s CL 3-118" Combi's Ci VBR's CL of Top S Top of Swa CL Swab 1 Flow Tee CL SSV CL Master LDS Ground Tree Size 4 1116 ne ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1G Pad 1G-03 1 G-103 Plan: 1 G-103_wp04 Standard Planning Report 17 July, 2019 BA SER % " UGHES a GE company �, ConocoPhillips BA ER Conoco Planning Report F�UGHES aGEcompary Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kupamk River Unit Site: Kuparuk 1G Pad Well: 1G-03 Wellbore: 1G-103 Design: 1G-103_wp04 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1G-03 Mean Sea Level 1G-03 @ 89.50usft (1G-03) True Minimum Curvature 'roject Kuparuk River Unh, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Plan Sections She Kuparuk I Pad Site Position: Northing: 5,981,540.78 usft Latitude: 70° 21'37 .826 N From: Map Easting: 540,089.12 usft Longitude: 149'40'27705W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.31 ° Well 1G-03 Inclination Azimuth Well Position -N/-S 177,282.55 usft Northing: 5,981,774.73 usft Latitude: 70° 21'40,130 N Rate +E/ -W -1,124,454.75 usft Easting: 540,036.44 usft Longitude: 149° 40'29.209 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1G-103 (11100usft) (11100usft) Magnetics Model Name Sample Date Declination Dip Angie Field Strength 256.38 3,269.91 177,35327 Inn 0.00 BGGM2018 9/1/2019 16.45 80.87 57,407 Design 1G-103_wp04 255.95 -- - Audit Notes: -1,125,832.41 3.01 1.75 Version: Phase: PLAN Tie On Depth: 3,800.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 1,125,852.28 12.00 (usft) (usft) (usft) (°) 3,968.56 0.00 177,282.55 1,124,454.7 0.00 177,349.10 1,125,967.02 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +1,1/4 •E/ -W Rate Rate Rate TFO (usft) (°) (1) (usft) (usft) (usft) (11100usft) (11100usft) (°1100usli Target 3,800.00 42.93 256.38 3,269.91 177,35327 -1,125,824.46 0.00 0.00 0.00 0.00 3,812.00 43.14 255.95 3,278.68 177,351.32 -1,125,832.41 3.01 1.75 -3.58 -54.57 3,841.00 46.18 258.36 3,299.31 177,346.80 1,125,852.28 12.00 10.48 8.31 30.00 3,968.56 90.50 280.34 3,345.72 177,349.10 1,125,967.02 38.00 34.75 17.23 30.00 4,038.56 94.25 283.50 3,342.81 177,363.54 1,126,035.43 7.00 5.36 4.51 40.00 4,128.56 87.95 283.50 3,341.09 177,384.54 1,126,122.88 7.00 -7.00 0.00 180.00 4,328.56 90.18 297.32 3,344.36 177,454.12 1,126,309.83 7.00 1.11 6.91 81.00 4,628.56 91.60 318.28 3,339.65 177,636.93 1,126,545.53 7.00 0.47 6.98 86.00 4,828.56 91.55 304.27 3,334.13 177,768.49 1,126,695.40 7.00 -0.02 -7.00 270.00 5,528.56 91.02 353.28 3,317.39 178,348.88 1,127,047.15 7.00 -0.08 7.00 90.00 5,828.56 90.06 332.30 3,314.55 178,633.84 1,127,135.40 7.00 -0.32 4.99 267.50 6,342.56 89.87 8.28 3,314.90 179,132.20 1,127,220.63 7.00 -0.04 7.00 90.30 11,580.00 89.52 7.76 3,343.00 184,317.70 1,126,485.76 0.01 -0.01 -0.01 -123.95 1G-103_T04(copy) 7/172019 1:41:02PM Page 2 COMPASS 5000 14 Build 85H ConocoPhillips BA ConocoPhillips Planning Report 1 UC a GEconpary Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit Site: Kuparuk 1G Pad Well: 1G-03 Wellbore: 1G-103 Design: 1G-103LWp04 Planned Survey Measured Dogleg Section Rate Depth Inclination Azimuth (usft) 68.77 (1) (°) 3,800.00 60.08 42.93 256.38 TIP 7.00 90.85 1,038.04 s 3,812.00 91.00 43.14 255.95 KOP 3,841.00 46.18 258.36 Start OLS 38.00 TFO 30.00 3,900.00 66.31 270.38 3,968.56 90.50 280.34 Start DLS 7.00 TFO 40.00 4,000.00 92.19 281.76 4,038.56 94.25 283.50 Start DLS 7.00 TFO 180.00 4,100.00 89.95 283.50 4,128.56 87.95 283.50 Start DLS 7.00 TFO 81.00 4,200.00 88.74 288.44 4,300.00 89.86 295.35 4,328.56 90.18 297.32 Start OLS 7.00 TFO 86.00 4,400.00 90.53 302.31 4,500.00 91.01 309.30 4,600.00 91.47 316.28 4,628.56 91.60 318.28 Start DLS 7.00 TFO 270.00 4,700.00 91.59 313.28 4,800.00 91.56 306.27 4,828.56 91.55 304.27 Start OLS 7.00 TFO 90.00 4,900.00 91.55 309.28 5,000.00 91.52 316.28 5,100.00 91.47 323.28 5,200.00 91.40 330.28 5,300.00 91.30 337.28 5,400.00 91.19 344.29 5,500.00 91.06 351.29 5,528.56 91.02 353.28 Start DLS 7.00 TFO 267.60 5,600.00 90.80 348.29 5,700.00 90.48 341.29 5,800.00 90.15 334.30 5,828.56 90.06 332.30 Start DLS 7.00 TFO 90.30 5,900.00 90.03 337.31 6,000.00 89.99 344.31 6,100.00 89.95 351.31 6,200.00 89.92 358.31 6,300.00 89.88 5.31 6,342.56 89.87 8.28 Start DLS 0.01 TFO .123.95 6,400.00 89.86 8.28 6,500.00 89.86 8.27 6,600.00 89.85 8.26 7/172019 1:41:02PM Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: TVD Below System +Nl-S +E/.W (usft) (usft) (usftl 3,269.91 177, 3 53.27 1,125, 824.46 3,278.68 177,351.32 1,125,832.41 3,299.31 177,346.80 1,125,852.28 3,332.01 177, 34 2.63 -1,125,900.76 3,345.72 177, 34 9.10 -1,125,967.02 3,344.98 177,355.13 1,125,997.87 3,342.81 177, 363.54 .1,126,035.43 3,340.56 177,377.87 1,126,095.12 3,341.09 177,384.54 1,126,122.88 3,343.15 177, 404.18 1,126,191.52 3,344.37 177, 441.4 5 -1,126,284.24 3,344.36 177,454.12 1,126,309.83 3,343.92 177,489.63 1,126,371.80 3,342.58 177,548.09 1,126,452.84 3,340.42 177,615.96 1,126,526.16 3,339.65 177,636.93 1,126,545.53 3,337.66 177, 688.10 1,126, 595.32 3,334.90 177,752.01 1,126,672.10 3,334.13 177,768.49 1,126,695.40 3,332.19 177,811.24 1,126,752.59 3,329.52 177,879.09 1,126,825.92 3,326.91 177, 955.37 -1,126,890.43 3,324.41 178, 038.95 1,126, 945.16 3,322.05 178,128.58 1,126,989.30 3,319.87 178,222.93 1,127,022.18 3,317.91 178,320.59 1,127,043.32 3,317.39 178,348.88 1,127,047.15 3,316.26 178,419.37 1,127, 058.59 3,315.15 178,515.80 -1,127,084.80 3,314.60 178,608.33 1,127,122.57 3,314.55 178,633.84 1,127,135.40 3,314.50 178,698.46 1,127,165.80 3,314.48 178,792.85 -1,127,198.66 3,314.53 178,890.53 -1,127,219.77 3,314.64 178,990.06 1,127,228.81 3,314.81 179,089.94 4,127,225.67 3,314.90 17 9,13 2.20 -1,127,220.63 3,315.04 179,189.04 1,127,212.36 3,315.28 179,288.00 1,127,197.96 3,315.53 179,386.96 1,127,183.58 Page 3 Well 1G-03 Mean Sea Level 1G-03 Q 89.50usft (1G-03) True Minimum Curvature Vertical Dogleg Section Rate (usft) ("/10ousft) 70.73 0.00 68.77 3.01 64.25 12.00 60.08 38.00 66.55 38.00 72.58 7.00 80.99 7.00 95.33 7.00 101.99 7.00 121.63 7.00 158.90 7.00 171.57 7.00 207.08 7.00 265.54 7.00 333.41 7.00 354.39 7.00 405.55 7.00 469.46 7.00 485.95 7.00 Toolface Azimuth (°I 0.00 -54.57 30.00 30.00 23.20 40.00 40.03 -160.00 -180.00 81.00 80.86 80.77 86.00 86.03 86.12 86.28 -90.00 -90.14 -90.33 528.69 7.00 90.00 596.54 7.00 90.14 672.82 7.00 90.32 756.40 7.00 90.51 846.03 7.00 90.68 940.38 7.00 90.85 1,038.04 7.00 91.00 1,066.33 7.00 91.14 1,136.82 1,233.25 1,325.78 1,351.29 1,415.92 1,510.30 1,607.98 1,707.51 1,807.40 1,849.65 1,906.49 2,005.45 2,104.41 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 0.01 0.01 0.01 -92.50 -92.58 -92.66 -92.70 90.30 90.30 90.30 90.30 90.29 90.28 Map Northing (usft) 5,981,631.36 5,981,628.19 5,981,620.62 5,981,608.95 5,981,605.03 5,981,606.19 5,981,608.66 5,981,613.54 5,981,615.81 5,981,624.55 5,981,646.98 5,981,655.53 5,981,681.01 5,981,726.22 5,981,781.95 5,981,799.68 5,981,842.54 5,981,893.81 5,981,906.49 5,981,939.86 5,981,995.57 5,982,060.98 5,982,135.15 5,982,216.95 5,982,305.16 5,982,398.48 5,982,425.87 5,982,493.83 5,982,585.14 5,982,670.80 5,982,694.04 5,982,753.24 5,982,841.49 5,982,934.84 5,983,031.89 5,983,131.20 5,983,173.79 Map Easting (usft) 538,670.37 538,662.81 538,643.86 538,596.54 538,529.99 538,498.53 538,460.06 538,398.78 538,370.27 538,299.31 538,201.78 538,174.49 538,107.66 538,018.38 537,935.27 537,912.84 537,855.61 537,769.70 537.744.08 537,680.85 537,597.74 537,522.04 537,454.87 537,397.25 537,350.02 537,313.90 537,305.70 537,283.41 537,242.45 537,190.68 537,174.02 537,133.87 537,086.67 537,050.57 537,026.12 537,013.67 537,012.07 -123.95 5,983,231.31 537,011.41 -123.95 5,983,331.45 537,010.23 -123.95 5,983,431.59 537,009.04 COMPASS 5000.14 Build 85H ConocoPhillips BA ConocoPhillips Planning Report FU RGHE$ a GErompary Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1G-03 Company: ConocoPhillips Alaska Inc Kuparuk TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-03 @ 89.50usft (IG -03) Site: Kuparuk 1G Pad North Reference: True Well: 1G-03 Survey Calculation Method: Minimum Curvature Wellbore: 1 G-103 Toolface Design: IG -103 wpG4 Depth Inclination Azimuth Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System -NI-S *EI -W Section Rate Azimuth Northing Easting (usft) V) (o) lush) (usft) (usft) (usft) (°1100usft) (1) (usft) (usft) 6,700.00 89.84 8.25 3,315.80 179485.92 1,127,169,22 2,203.37 0.01 -123.95 5,983,53173 537,007.84 6,800.00 89.64 8.24 3,316.08 179,584.89 1,127,154.87 2,302.34 0.01 -123.95 5,983,631.88 537,006.62 6,900.00 89.83 8.23 3,316.37 179,683.85 1,127,140.53 2,401.31 0.01 -123.95 5,983,732.02 537,005.39 7,000.00 89.82 8.22 3,316.67 179,782.82 1,127,126.21 2,500.27 0.01 -123.95 5,983,832.16 537,004.14 7,100.00 89.82 8.21 3,316.98 179,881.79 -1,127,111.91 2,599.25 0.01 -123.95 5,983,932.30 537,002.88 7,200.00 89.81 8.20 3,317.30 179,980.77 .1,127,097.61 2,698.22 0.01 -123.95 5,984,032.43 537,001.61 7,300.00 89.80 8.19 3,317.64 180,079.74 .1,127,083.34 2,797.19 0.01 -123.95 5,984,132.57 537,000.32 7,400.00 89.80 8.18 3,317.99 180,178.72 .1,127,069.07 2,896.17 0.01 -123.95 5,984,232.71 536,999.01 7,500.00 89.79 8.17 3,318.35 180,277.70 .1,127,054.82 2,995.15 0.01 -123.95 5,984,332.85 536,997.69 7,600.00 89.78 8.16 3,318.72 180,376.68 .1,127,040.59 3,094.13 0.01 -123.95 5,984,432.99 536,996.36 7,700.00 89.78 8.15 3,319.10 180,475.66 1,127,026.37 3,193.11 0.01 -123.95 5,984,533.13 536,995.01 7,800.00 89.77 8.14 3,319.50 180,574.65 1,127,012.16 3,292.10 0.01 -123.95 5,984,633.27 536,993.65 7,900.00 89.76 8.13 3,319.90 180,673.63 1,126,997.97 3,391.08 0.01 -123.95 5,984,733.40 536,992.27 8,000.00 89.76 8.12 3,320.32 180,772.62 1,126,983.79 3,490.07 0.01 -123.95 5,984,833.54 536,990.87 8,100.00 89.75 8.11 3,320.75 180,871.61 1,126,969.63 3,589.06 0.01 -123.95 5,984,933.68 536,989.47 6,200.00 89.74 8.10 3,321.19 180,970.61 1,126,955.48 3,688.06 0.01 -123.95 5,985,033.82 536,988.05 6,300.00 89.74 8.09 3,321.65 181,069.60 1,126,941.35 3,787.05 0.01 -123.95 5,985,133.95 536,986.61 6,400.00 89.73 8.08 3,322.11 181,168.60 1,126,927.23 3,886.05 0.01 -123.95 5,985,234.09 536,985.16 8,500.00 89.72 8.07 3,322.59 181,267.60 1,126,913.13 3,985.05 0.01 -123.95 5,985,334.22 536,983.69 8,600.00 89.72 8.06 3,323.07 181,366.60 1,126,899.04 4,084.05 0.01 -123.95 5,985,434.36 536,982.21 8,700.00 89.71 8.05 3,323.57 181,465.60 1,126,884.96 4,183.05 0.01 -123.95 5,985,534.50 536,980.72 8,800.00 89.70 8.04 3,324.09 181,564.60 1,126,870.90 4,282.06 0.01 -123.95 5,985,634.63 536,979.21 8,900.00 89.70 8.03 3,324.61 181,663.61 1,126,856.85 4,381.06 0.01 -123.95 5,985,734.77 536,977.69 9,000.00 89.69 8.02 3,325.14 181,762.62 1,126,842.82 4,480.07 0.01 -123.95 5,985,834.90 536,976.15 9,100.00 89.68 8.01 3,325.69 181,861.63 1,126,828.80 4,579.08 0.01 -123.95 5,985,935.04 536,974.60 9,200.00 89.68 8.00 3,326.25 181,960.64 1,126,814.80 4,678.09 0.01 -123.95 5,986,035.17 536,973.03 9,300.00 89.67 7.99 3,326.82 182,059.66 1,126,800.81 4,777.11 0.01 -123.95 5,986,135.30 536,971.45 9,400.00 89.66 7.98 3,327.40 182,158.67 1,126,786.83 4,876.12 0.01 -123.95 5,986,235.44 536,969.85 9,500.00 89.66 7.97 3,328.00 182,257.69 .1,126,772.87 4,975.14 0.01 -123.95 5,986,335.57 536,968.24 9,600.00 89.65 7.96 3,328.60 182,356.71 1,126,758.92 5,074.16 0.01 -123.95 5,986,435.70 536,966.61 9,700.00 89.64 7.95 3,329.22 182,455.73 .1,126,744.99 5,173.19 0.01 -123.95 5,986,535.83 536,964.97 9,800.00 89.64 7.94 3,329.85 182,554.76 -1,126,731.08 5,272.21 0.01 -123.95 5,986,635.97 536,963.32 9,900.00 89.63 7.93 3,330.49 182,653.78 1,126,717.17 5,371.24 0.01 -123.95 5,986,736.10 536,961.65 10,000.00 89.62 7.92 3,331.14 182,752.81 1,126,703.28 5,470.26 0.01 -123.95 5,986,836.23 536,959.96 10,100.00 89.62 7.91 3,331.80 182,851.84 1,126,689.41 5,569.29 0.01 -123.95 5,986,936.36 536,958.26 10,200.00 89.61 7.90 3,332.48 182,950.87 -1,126,675.55 5,668.33 0.01 -123.95 5,987,036.49 536,956.55 10,300.00 89.60 7.89 3,333.17 183,049.91 1,126,661.71 5,767.36 0.01 -123.95 5,987,136.62 536,954.82 10,400.00 89.60 7.88 3,333.87 183,148.94 1,126,647.87 5,866.39 0.01 -123.95 5,987,236.75 536,953.08 10,500.00 89.59 7.87 3,334.58 183,247.98 .1,126,634.06 5,965.43 0.01 -123.95 5,987,336.88 536,951.32 10,600.00 89.58 7.86 3,335.30 183,347.02 .1,126,620.26 6,064.47 0.01 -123.95 5,987,437.01 536,949.55 10,700.00 89.58 7.85 3,336.03 183,446.06 1,126,606.47 6,163.51 0.01 -123.95 5,987,537.14 536,947.77 10,800.00 89.57 7.84 3,336.78 183,545.10 .1,126,592.70 6,262.56 0.01 -123.95 5,987,637.26 536,945.97 10,900.00 89.56 7.83 3,337.54 183,644.15 .1,126,578.94 6,361.60 0.01 -123.95 5,987,737.39 536,944.15 11,000.00 89.56 7.82 3,338.31 183,743.20 .1,126,565.19 6,460.85 0.01 -123.95 5,987,837.52 536,942.32 11,100.00 89.55 7.81 3,339.09 183,842.25 .1,126,551.46 6,559.70 0.01 -123.95 5,987,937.65 536,940.48 11,200.00 89.54 7.80 3,339.88 183,941.30 .1,126,537.75 6,658.75 0.01 -123.95 5,988,037.77 536,938.62 11,300.00 89.54 7.79 3,340.69 184,040.35 .1,126,524.05 6,757.80 0.01 -123.95 5,988,137.90 536,936.74 11,400.00 89.53 7.78 3,341.50 184,139.40 .1,126,510.36 6,856.85 0.01 -123.95 5,988,238.03 536,934.86 11,500.00 89.52 7.77 3,342.33 184,238.46 .1,126,496.69 6,955.91 0.01 -123.95 5,988,338.15 536,932.95 11,580.00 89.52 7.76 3,343.00 184,317.70 -1,126,485.76 7,035.15 0.01 -123.95 5,988,418.25 536,931.42 Planned TD at 11580.00 7/172019 1:41.'02PM Page 4 COMPASS 5000. 14 Build 85H Targets ConocoPhillips BA ER ConocoPhillips Planning Report HUGHES aGEmmpany Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1G-03 Company: ConocoPhillips Alaska Inc Kuparuk TVD Reference: Mean Sea Level Project: Kuperuk River Unit MD Reference: 1G-03 (d 89.50usft (1G-03) Site: Kupawk 1G Pad North Reference: True Well: 1G-03 Survey Calculation Method: Minimum Curvature Wellbore: 1G-103 (usft) Latitude Longitude 1 G-103_704 (copy) Design: 1G-103 wp04 0.00 3,343.00 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/S +E/ -W Northing Easting -Shape (I V) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 1 G-103_704 (copy) 0.00 0.00 3,343.00 184,531.46 1.125,403.87 5,988,798.23 537,968.44 70° 22'49.317 N 149'41'28.640 W - plan misses target center by 1102.81 usft at 11580.001 MD (3343.00 TVD, 184317.70 N, -1126485.76 E) - Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 11,580.00 3,343.00 2-7/8" 2.875 4.250 3,968.56 3,345.71 3-112" 3.500 4.250 Plan Annotations Measured Depth (usft) 3.800.00 3,812.00 3,841.00 3,968.56 4,038.56 4,128.56 4,328.56 4,628.56 4,828.56 5,528.56 5,828.56 6,342.56 11,580.00 Vertical Local Coordinates Depth +N/S +E/ -W (usft) (usft) (usft) Comment TIP KOP Start DLS 38.00 TFO 30.00 Start DLS 7.00 TFO 40.00 Start DLS 7.00 TFO 180.00 Start DLS 7.00 TFO 81.00 Start DLS 7.00 TFO 86.00 Start DLS 7.00 TFO 270.00 Start DLS 7.00 TFO 90.00 Start DLS 7.00 TFO 267.50 Start DLS 7.00 TFO 90.30 Start DLS 0.01 TFO -123.95 Planned TD at 11580.00 7/172019 1:41:02PM Page 5 COMPASS 5000,14 Build 85H ConocoPhillips BA ER ConocoPhillips Anticollision Report F IGHES BAT GE mmpacy Company: ConocoPhillips Alaska lnc_Kuparuk Project: Kuparuk River Unit _I Reference Site: Kuparuk 1G Pad Site Error: 0.00 usft Reference Well: 1G-03 Well Error: 0.00 usft Reference Wellbore 1G-103 Reference Design: 1G-103_wp04 Reference 1G-103 wp04 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: Depth Range: 3,800.00 to 11,580.00usft Scan Method: Results Limited by: Maximum ellipse separation of 3,000.00 usft Error Surface: Warning Levels Evaluated at: 2.79 Sigma Survey Tool Program Date 7/1 712 01 9 From To (usft) (usft) Survey (Wellbore) 100.00 3,800.00 1G-03 (IG -03) 3,800.00 11,580.00 1G-103_wp04 (1G-103) Summary Site Name Offset Well - Wellbom - Design Kuparuk 1G Pad IG -01 - 1G-01 - 1G-01 1G-01 - 1G-01 - 1G-01 IG -01 -1 G-01 - 1G-01 1G-02 - 1G-02 - 1G-02 1G-02 - IG -02 - 1G-02 1G-02 - 1G-02 - 1G-02 1G-03 - IG -03 - 1G-03 IG -03 - IG -03 - 1G-03 1G-04 - IG -04 - 1G-04 1G-04 - IG -04 - 1G-04 1 G-04 - 1 G-04 - 1 G-04 1 G-04 -1 G-0411 - 1 G-04LI 1 G-04 - 1 G-0411 - 1 G-0411 1G-04 - 1 G-0411 - 1 G -04L1 1G-04 - 1G-0411-01 - 1G -04L1-01 1G-04 - 1 G-041-1-01 - 1 G -04L1-01 1 G-04 -1 G-041-1-01 - 1 G-040-01 1G-04 - 1 G-041-1-02 - 1 G-04LI-02 1G-04 - 1 G-041-1-02 - 1 G-04LI-02 1 G-04 - 1 G-041-1-02 - 1 G-04LI-02 1G-04 - 1 G-0411-03 - 1G-040-03 1 G-04 -1 G-0411-03 - 1 G -04L1-03 1G-04 - 1 G -04L1-03 - 1 G-04LI-03 1 G-04 - 1 G-04LI PB1-1G-0411 PBI I G-04 - 1 G-04LI PBI-1G-04Ll PBI 1G -04-1G-0411 PB1-1G-041.1 PBI 1 G-103 - 1 G-03 - 1 G-03 1 G-116 - 1 G-16 - 1 G-16 1G-116 - 1 G-16 - 1 G-16 1G-16 - 1 G-116 - 1 G-116_wp03 I G-16 - 1 G-116 - 1 G-116_wp03 1G-16 - 1 G-116 - 1 G-116_wp03 1 G-16 - 1 G-116 - 1 G-116_wp03 1 G-16 - 1 G-116 - 1 G-116_wp03 1 G-16 - 1 G-116 - 1 G-116_wp03 Method: Well 1G-03 1G-03 @ 89.50usft (1G-03) IG -03 @ 89.50usft (1G-03) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum ISCWSA Tray. Cylinder North Combined Pedal Curve Added to Error Values Tool Name Description FINDER -MS SDC Finder multishot FINDER -MS SDC Finder multishot Reference Offset Measured Measured Depth Depth (usftl (usft) 3,825.00 3,825.00 4,109.34 4,250.00 Distance Between Between Separation Warning Centres Ellipses Factor (usft) (usft) 0.18 -26.02 275.32 273.09 3,825.00 3,825.00 0.18 -26.02 4,660.93 4,500.00 448.30 360.29 4,672.86 4,525.00 448.39 360.07 4,094.24 4,000.00 453.50 386.19 4,094.24 4,000.00 453.50 386.14 4,345.79 4,200.00 463.08 381.99 4,345.79 4,200.00 463.08 381.94 11,570.35 10,600.00 1,196.09 886.98 11,570.35 10,600.00 1,196.09 886.93 Out of range Out of range Out of range Out of range Out of range Out of range 0.007 STOP Drilling, CC, ES, SF 123.346 CC, ES, SF Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 0.007 STOP Drilling, CC, ES, SF 5.094 CC 5.077 ES, SF 6.737 CC 6.732 CC 5.711 ES 5.707 ES 3.869 SF 3.869 SF 7/172019 10.45.40AM Page 2 COMPASS 5000.14 Build 85H ConocoPhillips BA_ ICER ConocoPhillips Anticollision Report FIUGHES aGEcompany Company: ConocoPhillips Alaska Inc-Kuparuk Local Coordinate Reference: Well IG -03 Project: Kuparuk River Unit -1 TVD Reference: IG -03 Q 89.50usft (1G-03) Reference Site: Kuparuk 1G Pad MD Reference: 1G-03 a 89,50usft (1 G43) Site Error: 0.00 usft North Reference: True Reference Well: 1G-03 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 2.00 sigma Reference Wellbore 1G-103 Database: EDT 14 Alaska Production Reference Design: 1G-103_wp04 Offset TVD Reference: Offset Datum Summary Kuparuk IG Pad- 1G -03 -1G -03-1G-03 Reference Offset Distance Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Offset Well - Wellbore - Design (usft) (us@I (usft) (usft) Distance Kuparuk 1G Pad Measui Vertical Measured Vntical 1G -16 -1G -16-1G-16 4,665.70 4,450.00 448.23 360.08 5.085 CC, ES 1G -16 -1G -16-1G-16 4,665.70 4,450.00 448.23 360.08 5.085 CC, ES 1G -16 -1G -16-1G-16 4,677.67 4,475.00 448.67 360.27 5.075 SF 1 G-16 - 1G-16 - 1G-16 4,677.67 4,475.00 448.67 360.27 5.075 SF 1G -16 -1G -16-1G-16 4,677.67 4,475.00 448.67 360.27 5.075 SF 1G -17 -1G -17-1G-17 3,812.00 3,950.00 983.43 952.42 31.715 CC, ES, SF Plan: 1G-19-1G-19-1G-19(wp02) 3,806.32 3,825.00 185.20 134.38 3.644 CC, ES, SF Kuparuk 1R Pad 0.18 -0.44 061 0.289 STOP Dniting 3,825.00 iR-O6-iR-06-iR-06 11,568.07 5,200.00 668.04 598.48 9.604 CC, ES, SF iR-OB-iR-06A-iR-06A 11,568.07 5,200.00 668.04 596.56 9.615 CC, ES, SF 1R-06-1R-06ALl-1R-06ALl 11,568.07 5,200.00 668.04 598.56 9,615 CC, ES, SF 1R-06-1R-06ALl-01-1R-06ALi-01 11,568.07 5,200.00 668.04 598.56 9.615 CC, ES, SF 1R-06-1R-06AL2-1R-06AL2 11,568.07 5,200.00 668.04 598.56 9.615 CC, ES, SF 1R-06-1R-06AL2-01-1R-06AL2-01 11,568.07 5,200.00 668.04 598.48 9.604 CC, ES, SF Offset Design Kuparuk IG Pad- 1G -03 -1G -03-1G-03 offset she E. coolest Survey Program: 10DFI1NDER-MS OlrwsLW II Error. 0:00 usg Reference OraM Semi Major Axie Distance Measui Vertical Measured Vntical Rer...,. peace AximNM1 Offset Wel@ore Care Betmen BGNrcen Minimum Separation yearning paps, Depth Depth Depth from North ♦NIS �4V Centres Ellipses Separation Factor lexftl (uer) (usft) (earl (raft) fuel (°) fear) (eaN (uaN (uanl team 3,825.00 3.377,56 3,82500 3,377.65 0.05 0.24 120.56 66.57 4.386.30 0.18 -0.44 061 0.289 STOP Dniting 3,825.00 3,377.56 3.825.00 3371,65 20.18 20.36 120.56 east 4,386.30 0.18 -2602 2620 0007 STOP Drilling, CC. ES. SF 3.849.86 3,394.70 3,850.00 3,395]8 0.05 0.48 120.47 62.12 -1401.95 169 0.85 0.84 2.015 Ca Won Monitor Closely 3.849.86 3.391 3,850.00 3.395.76 20.18 20.59 120.47 62.12 -1,40295 1.69 .24.46 26.15 0.065 STOP Drilling 3.873.75 3,409.10 3,875.00 3.413.76 0.07 033 118.32 57.51 -1,419.66 6.58 5.56 1.02 6.438 3,873.75 3.409.10 3,875.00 3413.78 20.19 20.02 118.32 57.51 -1019.60 6.58 -18.05 24.63 0.287 STOP Ddlling 3,095.72 3419.74 3,900.00 3,431.69 0.08 0.96 118.46 52.85 -1.435.46 1507 13.90 1.17 12.878 3895.72 3.419.74 3.900.00 3.43169 20.20 21.06 118.46 52.85 -1436.46 15.07 -8.46 23.53 0.640 STOP 0111fing 3,915.21 3.426.96 3.925.00 3449.57 0.10 1.24 119.46 48.16 -1463.29 Nee 25.47 1.19 22.372 3,91511 3,428.96 3,925.0 3.449.57 20.21 21.29 119.46 48.16 -1,453.29 26.66 4.16 22.50 1.185 Take lmmMiale Action 3,932.08 3.431.64 3.95000 3,467.43 0.11 1.50 120,71 43.43 -1.470.14 40.61 39.73 100 32640 3.932.08 3,431.44 3,950.00 3.467.43 20.22 21.53 120.71 43.43 -1.470.14 40.81 19.31 21.50 1.8% caNlon Monitor Closely 3,948.48 3.433.90 3.975.00 3465.26 0.13 1.77 122.03 36.60 -1487.00 57.01 56.25 0.76 75.170 3,948148 3,433.90 3,975.00 3,485.26 20.24 2137 122.03 36.88 -1.487.00 57.01 WAS 20.55 2.774 Normal Operations 3.960.00 3,43508 4,000.00 3.503.07 0.14 2.03 123.49 33.90 -1,503.88 74.03 73.90 0.92 81.105 3.960.00 3.435.06 (000.00 3.503.07 20.25 2200 123.49 3390 -1,503.88 74.83 54.96 19.67 3.766 3,958.56 3,435.21 4.025.00 3.520.87 0.14 2.34 12448 29.08 -1.520.76 93.88 92.69 1.18 79.253 3980.55 3,435.21 4.02500 3.520.07 20.26 22.24 12448 29.08 -1.520.76 93.08 75.03 18.85 4.901 3,983.07 3.434.99 4.050.00 3,538,66 0.16 2.65 125.07 2410 -1,537.64 113.57 112.32 115 90]37 3.9113.07 3.43489 4,050.00 3538.66 20.28 22.48 125.07 24.20 -1.537.84 113.57 94.75 18.02 6.034 3,996.23 3,434,62 4,075.00 3.556.43 0.17 2.97 125,68 19.27 -1.554.51 133.52 132.18 1.36 98.007 3.996.23 3,434.62 4,075.00 3.556.43 20.29 22.72 125.08 19.27 -1.554.51 133.52 114.79 18.74 7.126 4,008.85 3,434.10 4,100.00 3,574.20 0.19 3.29 126.32 14.28 4.571.311 15371 152.22 149 103.114 4.008.85 3,434.10 4,100.00 3.574.20 20.31 22.95 126.32 14.28 -1,571.38 153.71 135.03 18.68 8,229 4.020.98 3433.47 4,125.00 3.591.94 0.21 4.00 126.96 9.28 -1,588.27 174.10 172.26 1.84 94.586 4,020.98 3,433.47 4,125.00 3,591.94 20.33 23.20 128.96 9.28 -1.588.27 174.10 155.47 18.62 9.347 4032.60 3,432.73 4,150.00 3.80965 0.23 4.78 127.58 4.31 -1.605.20 194.64 192.38 2.26 86.110 4032.68 3.432.73 4.150.00 3,809.65 20.35 23.44 127.58 4.31 -1605,20 194.61 176.06 18.58 10.476 4047.49 3.43130 495.00 3.627.32 0.25 559 12193 -D.62 -1622.19 215.29 212.69 260 82.766 CC - Min centre to center distance or wvergent point, SF - min separation factor, ES - min ellipse separation 711712019 10'45 40AM Page 3 COMPASS 5000.14 Build 85H ConocoPhillips Protect: Kuparok River UnK_1 SiteNwv KupaIG-03 klG Pad umrv. iau T�1 ft.. .01 WELLBORE DETAILS: IG -103 REFERENCE INFORMnON Parent Wellbore: 1G-03 Co-ok'mam lNk)Relamce: wee l0a3,TmeNmn Well: Well: 1GA3 Nre,Nu, Tie on MD: 3800.00 �wFeFl1T`/el Reamce: e+em se a level Wellbore: IG -103 o'°a Plan: tG-103_wp04 (iG-0L1G-103) ylffi/J iwi uuw: swum: WmwW D.eml ReRIi m i'C.mt@MM aftlrOm) Cek+Rum WINW Mmmum C ... WELL DETAILS: 1G-03 +N/ -S +E/ -W NorthW Easting Latitude Longitude 0.00 0.00 5981774.73 540036.44 70° 21'40.130 N 149" 40'29.209 W BC MD Inc AZI IVUSS W -b- eg Twe vsa Annotation 1 3800.00 42.93 256.38 3269.91 70.73 -1369.71 0.00 0.00 70.3 TIP 2 3812.00 43.14 255.95 3278.68 68.77 -1377.66 3.01 -54.57 68. 7 KOP 3 3841.00 46.18 258.36 3299.31 64.25 -1397.54 12.00 30.00 64. Start DLS 38.00 TFO .0 4 3968.56 90.50 280.34 3345.72 66.55 -1512.27 38.DD 30.00 66. 5 Start DLS 7.00 TFO 00 5 4038.56 94.25 283.50 3342.81 80.99 -1580.68 7.00 40.00 80. Start DLS 7.00 TFO 1810 6 4128.56 87.95 283.50 3341.09 101.99 -1668.14 7.00 180.00 101. Start DLS 7.00 TFO 8100 7 4328.56 90.18 297.32 3344.36 171.57 -1855.08 7A0 81.00 171. Start DLS 7.00 TFO 6 00 8 4628.56 91.60 318.28 3339.65 354.39 -2090.78 7.00 86.00 354. 9 Start DLS 7.00 TFO 2 .0 9 4828.56 91.55 304.27 3334.13 485.95 -2240.66 7.00 270.00 485.5 Start DLS 7.00 TFO 9 00 10 5528.56 91.02 353.28 3317.39 1066.33 -2592.40 7.00 90.00 1066. 3 Start DLS 7.00 TFO 2 .5 11 5828.56 90.06 332.30 3314.55 1351.29 -2680.65 7.00 267.50 1351. Start DLS 7.00 TFO 9 30 12 6342.56 89.87 8.28 3314.90 1849.65 -2765.88 7.00 90.30 1849.Start DLS 0.01 TFO -1 31 13 11580.00 89.52 7.76 3343.00 7035.15 -2031.02 0.01 -123.95 7035. 5 Planned TD al 11580. c_ BAF ER W 4ES West( -)Bast(+) (600 usft/in) Mean Vertical Section at 0.00° (250 usft/in) kmua. roI WELLBORE DETAILS : 1G-103 REFERENCE INFORMflON Pr0Site: Kuparuk 10 P pntt 1 MoaN2 u. Kuparuk 1G Patl aParent Wellbore: 1G-03 —revmw IIPm)%aarca: ta@Wwleft(l o WHWeil: 1G-03 sl,a,ul 1�/Te on Mp'3800.00 SecMon rySl RNererca: bld-10WN,000Ea�1,Wellbore: lG-103 °i^lES CorweoPhllllps Plan: 1G 103_wp04 (1G -031G-103) c kdl Menet M... C..,, 1 GEon pa y IItn IIIN+:161.1-011'111 Ilouvl N-ulbl.l ` IR-0I/II IliLlul IpanrlV+IlAL1 IQIAt/1QMA IR-:NIR-I^_6L1 ._ .._._.�... ' 11401/1(W1 '•., ',I 9000 1111 I r - y"i xl giul IR3NIR-M N<-nnR-n i4..-IleaI L.ni. u.l P'p. IR-2911RS1)LI vaoo: W ,. 1h_ If, "I V4 Q1111 I��'- IR 3 /III -091.1 11 "i 1 4, 3llIR-21A114 111 l)l IR-291,I4DPl31 Il}-IUI/IQ101 5500 1R-29nR.211 If lrvV HdYN.ILIDnI 0: 4500 e O 40W O �.-3500 n 250U" bA"n � 2000.1 u a .r.✓ O 1500 - IIIJo I!>lulu 1000. - i II :. rv:'RI II-14.1111-19A1.x I� fit4"_ 11141/111.1 5U0- Irl. W ro I g J� uNl /Il aL - D- I C _ -SDO.' t InLL I,_ 661{ t 91RI44L1-01 Erl 0001 IS00� I • ,.. C9° Srl l'Alt -. s. - '� •r � I I .I i _ nq -2500 'c. .. _ E > -10500-I000U-9500 -9W0 -BSW -8000 -]SOU -IDOU -6500 -6000 -5500,5000 -4500 40W -35W -3000 -2500 -2DG0 -I$((0 -1000 -500 U 500 10(14, 1300. 00-.3000 3500 JDD,O 4500 5000 5500 6000 Jp1.0J/IHa1JL1 i 1a I ... ln la --' mfr -Ulf: Ixl.l ' IU4wIU.a West(-)/SBSC(+) (500 IlSitiltl) ' Ir,+,1r1¢+I " ->:m 1cwu. ml lulrul la-unu-un 1G-03895DNsft (1G-03) r � LL,a»,Ii, loll+n Iq-o5lm+hidnl lalxnc-Ix ConocoPhillips KUP INJ `aELLNAME 1G-03 NELLBORE 1G-03 Alaska, IM. - 1.11.l.1PHO1M Cement Squeezes vents em"MK{xuB T^PIIIHaI BIm IkKBI TOPIrvDI (kK0) atm(rvDl (DID) Des atenDa1e Com XPNGER, ]4.5 aPv 3a5 6.882.0 7,260.0 5.441.4 5.907.6 CEMENT PLUG 52412019 LAYED IN 5 BELS 15.8 PPG CLASS G CEM NT ABOVE RETAINER. CONTAMINATED DOWN TO ESTIMATED TOC OF 6682' 6854.0 J, 354.0 5,576.5 5,9860 CEMENT PLUG 52412019 14 881S OF 15.8 PPG CLASS G CEMENT CIRCULATED UP IA THRU TUBING PUNCHES 3.669.0 182fiA 3,263.9 3,378.4 CEMENT 61512019 Squeezed in 15.8 PPG Oafia G cemewfwi0 ArcMr SQUEEZE SBonghdd Bfirrirvee tw Mandrel Inserts 31 CONWCi9n 3D C..CaD MI iop (lVO1 Mosel -.k Type —SIxe TRORun (INR Ip6 Run Dale Com 1 2,6632 2510.6 Camm KB 2BK i!!H 61&2019 2 5 63 3,212.0 GHmLO KB 2DCK-2 6181 1 SOV SURFACE 2FO-2 l]a— sh e. etl nn la, zmnz Notes: General & Safety Em Date AF -ease n 412412003 NOTE E -LINE FOUND C -SAND LEAK@757' IW. 66863 1Rk.19 SOEE IS INST BROKEN ,, ,,"MUS MAINTAIN 5000 PSI ON CONTROL LINE WHEN NO SLEEVE IS INSTALLED LOC.00RI PA.. 7112019 ew NOTE'V1Stllemalic wt Ala5ka5Nellwtic100 ; . SEKFBSY38ll7 M 3.8317 PACKER 36155 MPPIE:3675.5 yy y Cement Sq—PSES06KS IPERF:f P®.65,aasal 9 T.M.MIEDGE; An6a - NIPPLE', 3MS TANDEM WEDGE; aaOS6 NIPPLE:3..QS1 1ANOING CGL— SsaaE EL:E:;819.8 CIBP: aa0.5 JET COT. e.moo Cement Fkp; a 03z.o tm Pro]WIm CeLry... 6031.OflKa CEMENT RETAINER.7 SES0 Demes RME J S NKa IW J]eu CW SO2 7.3156731JA ...7,3103 PACKER:IX.J NC ] 3820 INJ: 7.1619 PERF; 7.195.LL7,MO-- IPEMR.151oa1%M1O— NJ: J6M1 GfiP, I,JiO.D BEALASBY; E].I PASKER; 7;A u BE; J35a NIWLE:7.Tl7.8 SSS7,JYA IPERF;7J20-7.8SUOp PROWCTpN, 27.561W.0� 1G-03 Proposed CTD Schematic 108' MD /�\ \ K55 shoe @ 2303' MD, 2216' TVD / yspo SMD Arctic Pack cement ^2100'-2500'via CBL 10- 3�P`tiG� 3-82 (RA tracer) CTD KOP 3812' Whipstock set @ 10° ROHS- $v oM D I tJ i Top of good quality cement behind the 7" at 7380' (CBL of 8-21-84) I G -03L1 wp04 - 0" DLS 'Plan TD: 11,580' MD WOB Model: 9,500' MD Loepp, Victoria T (CED) From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Thursday, August 29, 2019 9:51 AM To: Loepp, Victoria T (CED); Eller, J Gary Cc: Ohlinger, James J Subject: RE: [EXTERNAL]KRU 1G-103(PTD 219-110) West Sak Injector CTD AOR plat Attachments: WS -1G -1R -CTD wells_otherwell_WS_interval_20190722.png Victoria, Please see attached''/. mile plat along with the following list of wells within 1320' of 1G-103 wpo4: 1G-103 wp04 275' from IG -03 at 4109' MD 448' from 1 G-16 at 4666' MD 454' from 1 G-116 w 03 at 4094' MD 668' from 1 R-06 at 11568' MD 668' from 1R -06A at 11568' MD 668' from 1R-06AL1 at 11568' MD 668' from 1R-06AL1-01 at 11568' MD 668' from 1 R-06AL2 at 11568' MD 668' from 1 R-06AL2-01 at 11568' MD 983' from 1G-17 at 3814' MD 1148' from 1G-06 at 3813' MD 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: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, August 29, 2019 8:55 AM To: McLaughlin, Ryan <Ryan. McLaughlin @conocophiIIips.com>; Eller, J Gary <J.Gary.Eller@conocophillips.com> Cc: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Subject: [EXTERNAL]KRU 1G-103(PTD 219-110) West Salk Injector CTD AOR plat Ryan, Please send an AOR % mile plat for 1G-103. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepm5alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission 1AOGCCI, State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at 19071793-1247 or Victoria Loeop@alaska aov From: McLaughlin, Ryan <Ryan McLaughlin@conocophillips.com> Sent: Wednesday, August 28, 2019 2:47 PM To: Loepp, Victoria T (CED) <victoriadoepp@alaska.t;ov>; Eller, J Gary <J.Gary.EllerPconocophillips.com> Cc: Ohlinger, James J <James.J.Ohlineer@conocophillips.com> Subject: RE: [EXTERNAL)KRU SG-103(PTD 219-110) West Sak Injector CTD Victoria, The maximum injection pressure at the sand face based on a do -not -exceed injection gradient in the West Sak of 0.62 psi/ft would be 2089 psig. Due to the low injection pressures it is unlikely that we would see a significant amount of crossflow from the West Sak into the Ugnu if exposed to our maximum injection pressure. However, after a period of stabilized injection, a water flow log could be obtained across the West Sak and Ugnu. 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: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, August 28, 2019 10:44 AM To: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com>; Eller, J Gary <J.GaryEller@conocophillips.com> Cc:Ohlinger, James <lames.J.Ohlineer@conocophillips.com> Subject: [EXTERNAL]KRU 1G-103(PTD 219-110) West Sak Injector CTD Ryan, Thanx for the stratigraphy and permeability information. The FIT after the squeeze was 13.3 ppg at 3300' TVD which corresponds to about 2282 psig. I believe in earlier communications, the planned injection pressure into the West Sak was not to exceed —2100 psig? Please verify the maximum planned injection pressure. Also, if the Ugnu sands were exposed to the maximum injection pressure planned for the West Sak would injection occur into the Ugnu? Please provide description of what would happen. Please also confirm that after a period of stabilized injection, that a water flow log could be obtained across the West Sak and the Ugnu. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepora) a laska. oov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.aov From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Tuesday, August 27, 2019 1:44 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.aov> Cc: Ohlinger, lames J <James.J.Ohlinaer@conocophillips.com> Subject: RE: [EXTERNAL]KRU 1G-103(PTD 219-110) West Sak Injector CTD Hello Victoria, I was wondering what the status was on the Permit to Drill for 1G-103. It is looking like we will be wrapped up with our current well 1G-116 and moving to 1G-103 potentially by Friday. 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: McLaughlin, Ryan Sent: Wednesday, August 21, 2019 9:29 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.eov> Cc: Eller, J Gary <J.Gary.Eller@conocophillips.com>; Ohlinger, James <James.J.Ohlinger@conocophillips.com> Subject: RE: [EXTERNAL]KRU 1G-103(PTD 219-110) West Sak Injector CTD Victoria, Here is the requested stratigraphy for the 1G-103 PTD: Top Base Formation I Pressure I Permeability I Description 2845.4 1 3533.8 Ugnu 1260 3000-8000mD Fine -medium grained, non -marine coastal plain 3533.8 3782 N Sands 1348 S00-2000mD Fine grained delta front deposits 3782 4408 West Sak 1435 10-1000mD Very fine grained, poorly consolidated, shallow i 4480 5725 Canning / Seabee N/A N/A Non -reservoir interval in the 1R/1G area. Black, 5725 7243 HRZ N/A N/A Non -reservoir interval. Black, laminated fissile sl 7243 7490 Kalubik N/A N/A Non -reservoir interval. Black, laminated fissile sl Pressures were calculated using a normally pressured water gradient and permeabilities are based on average perms for the reservoir interval. Between the base of the West Sak and the Kalubik is the Canning, the Seabee formation and the HRZ, all of which in the 1G/111 area are non -reservoir, marine mudstone intervals 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: Loepp, Victoria T (CED) <yictoria.loepp@alaska.gov> Sent: Thursday, August 15, 2019 8:29 AM To: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com>; Eller, J Gary <J.Gary.Eller@conocophillips.com> Subject: [EXTERNAL]KRU 1G-103(PTD 219-110) West Sak Injector CTD Ryan, Gary, Thanx for the stratigraphy. For each zone please provide pressure, permeability and brief description. What's between the base of the West Sak and the K-10 Marker and between the K-10 Marker and the K-2 Marker? Thanx, Victoria From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Wednesday, August 14, 2019 2:34 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.eov>; Eller, J Gary <J.Gary.Eller@conocophillips.com> Subject: RE: [EXTERNAL]KRU 1G-103(PTD 219-110) West Sak Injector CTD Victoria, Please see stratigraphy below. MD BASE—MID Formation 2845.4 3172.3 UGNU C 3172.3 3330 UGNU B 3330 3533.8 UGNU A 3533.8 3583.1 NA 3583.1 3622 NB 3622 3760.4 NC 3760.4 3782 NF 3782 4408 West Sak_TOP 3782 3854 West Sak_D 3854 3900 West Sak_C 3900 3950 West Sak_B 3950 4009 West Sak_A4 4009 4123 West Sak_A3 4123 4276 WestSak_A2 4276 4408 West Sak_Al 4408 4408 West Sak_BASE 4847 4847 K-10 Marker 7001 7001 NANSH_TOROK 7119 7119 K-2 Marker 7243 7243 HRZ_BASE 7243 7495 KALUBIK 7243 7391 KALUBIK UPPER 7391 7391 K-1 Marker 7391 7490 KALUBIK LOWER 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: Loepp, Victoria T (CED) <victoria.loepp alaska.gov> Sent: Wednesday, August 14, 2019 2:06 PM To: Eller, J Gary <J Gary Eller@conocophillips.com>; McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Subject: [EXTERNAL]KRU 1G-103(PTD 219-110) West Sak Injector CTD Gary, Ryan, Please provide the stratigraphy between 2500' MD(base of the Arctic Pack cement) and 7380' MD(top of cement behind the 7" production casing). Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeoo(a)alaska.gov CONFIDENTIALITY NOTICE., This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeoo@alaska.aov From: Germano, Shane To: Soyer David L (CED) Subject: RE: [EXTERNAL]FW: Digital Surveys for KRU 1G-103 FFD Application Date: Tuesday, August 6, 2019 11:58:54 AM Hi David, We do plan on pre -producing the 1G-103. It will be less than 3 months of pre -producing. And yes, there isn't a history yet for H2S in the West Sak on 1G pad. The 1G-103 & 1G-116 will be the first West Sak wells on 1G pad. Let me know if you need anything else. Thanks, Shane Germann Coiled Tubing Drilling Engineer Conoco Ph ,, Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 From: Boyer, David L (CED) <david.boyer2@alaska.gov> Sent: Tuesday, August 6, 2019 11:31 AM To: Germann, Shane <Shane.Germann@conocophillips.com> Subject: RE: [EXTERNAL]FW: Digital Surveys for KRU 1G-103 PTD Application Hi Shane, I forgot to ask if 1G-103 will be pre -produced since it is a water injector and if so, for how long? Also, 1G Pad requires extra precautions for H2S in the Kuparuk reservoir. From the data we have, it does not appear that there is a history of H2S yet in the West Sak on 1G Pad? Thanks, Dave Boyer From: Germann, Shane <Shane Germann(@conocophilli sr� com> Sent: Tuesday, August 6, 2019 6:49 AM To: Boyer, David L (CED) <david boyer2(@alaska gov> Cc: McLaughlin, Ryan <Rvan McLaughli[i@conocophilli sp com>; Hayes, James C <James C Hayes(a)conoco hilli s. orD> Subject: RE: [EXTERNAL]FW: Digital Surveys for KRU 1G-103 PTD Application Hi David, I attached the well plan surveys in excel format. Let me know if you need anything else. Thanks, Shane Germann Coiled Tubing Drilling Engineer CenocolPhdl+ps Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 From: Boyer, David L (CED) <david.boyer2 Palaska eov> Sent: Monday, August 5, 2019 4:55 PM To: Germann, Shane <Shane Germannl@conoco hilli so com> Subject: [EXTERNAL]FW: Digital Surveys for KRU 1G-103 PTD Application Hi Shane, Since Ryan is on vacation, would you be able to send over the digital surveys for KRU 1G-103? Thanks, Dave Boyer AOGCC From: Boyer, David L (CED) Sent: Monday, August 5, 2019 4:51 PM To: Ryan McLaughlinPcoo conn Subject: Digital Surveys for KRU 1G-103 PTD Application Hi Ryan, I plan to begin the review of the PTD application for the KRU 1G-103 well tomorrow morning. Would it be possible to e-mail over a copy of the digital survey file for this well for loading into the GeoGraphix program at AOGCC. This speeds up the process here. Thank you, Dave Boyer TRANSMITTAL LETTER CHECKLIST WELL NAME: K R (k- 1 G -" I 3 PTD: Ito Development VService —Exploratory _ Stratigraphic Test —Non -Conventional FIELD: K4 p a Ku K 1 \!VC{- POOL: I f_5-t-I,c 0 1 I 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- - records, data and logs acquired for ll _) from we name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals througb target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 _ Well Name: KUPARUK RIV UNIT 1CJ93_Program SER Well bore seg ❑ PTD#:2191100 Company ConocoPhilllps Alaska Inc Initial Class/Type SER/PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal 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_ plat & 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 Pennitcan be issued without administrative.approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ ... _ _ _ _ _ _ _ _ OLB 8/6/2019 13 Can permit be approved before 15 -day wait _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes ......... . .... . .. . . . . . . . . . . . . .............. 14 Well located within area and strata authorized by Injection Order # (put 10# in.comments) .(For, Yes ..... Governed by AID No. 2B & CO 406C__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 All wells. within 114 mile area of review identified (For service well only) _ _ _ Yes _ ... _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . ............... .... 16 Pre -produced injector; duration of pre -production less than 3 months (For service well only) . Yes _ ___ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ____ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .......... 17 Nonconven, gas conforms to AS31.05.030(j.1.A),(A2.A-D) . ............. . _ _ _ _ NA.... _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ................ _ _ _ _ _ _ _ _ _ _ _ .... _ -- .18 18 Conductor string provided . . . . ............................. . .. . . . . NA_ _ _ _ _ Conductor set for the original.Kuparuk motherbore KRU 10-03 _ _ Engineering 19 Surface casing_ protects all known USDWs _ _ _ _ _ NA _ _ _ _ _ Surface casing set to 2303' MD 20 CMT_ vol adequate to circulate onconductor& Surf.csg ................. . . . . NA. _ _ _ _ _ _ _ Surface casing set and fully cemented _ _ _ _ _ _ _ _ ............. - .. _ _ _ . 21 CMT_vol adequate to tie-in long string to surf csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA............. 22 CMT. will cover all known productive horizons _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No. _ _ ..... Productive_ interval will be completed with uncemented slotted liner 23 Casing designs adequate for C, T B &_permafrost- _ _ _ _ _ .. _ . . NA. ... _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ........ 24 Adequate tankage. or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _____ Yes . .... Rig has steel tanks; all waste to approved disposal wells.. _ _ _ _ _ _ _ _ _ _ .. - . . 25 If are -drill, has_a 10-403 for abandonment been approved . ..................... Yes .. _ ... _ KRU 1G-03(PTD 182-149) The Kuparuk well. bore. was abandoned for this new West Sak CTD laterel ....... . 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 1516 psig(8.5 ppg);.will drill w/ 8.4 ppg EMW and maintainoverbal w/ MPD _ , . _ . VTL 8/28/2019 29 BOPEs, do they meet regulation _ _ _ _ _ _ _ _ _ _ _ ___ Yes 30 BOPE_press rating appropriate; test to.(put prig in comments)_ _ _ _ _ _ _ _ _ _ _ _ . Yes MPSP is 1179 psig; will test BOPS to 2500 psig . . . . ................... . . . . . . . . . . . . 31 Choke, manifold complies w/API RP -53 (May 84). _ _ _ _ _ _ _ _ _ _ _ _ _ ....... Yes .. _ _ _ _ _ _ _ ______ ______ 32 Work will occur without operation shutdown_ _ _ _ _ Yes _ _ _ _ _ . . . . . . . . . . . .................... . . . . . . . . . . . . . . . . . ..... . 33 Is presence of H2S gas probable - - - - - - - - - - - NO - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 34 Mecbanical condition of wells within AOR verified (For service well only) _ _ _ __ _ _ _ _ __ _ _ _ Yes _ ... _ _ _ KRU 16 -103,1G -06.1G-116 SC set above Wsak/Ugno,Addn CIA -monitoring rod; WF log rgd;max inj .62psfft 35 Permit can be issued w/o hydrogen_ sulfide measures ......................... Yes _ _ _ _ _ _ _ No record of_H2S_in the West Sak on 1G Pad..... _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ ------------- ............Geology Geology 36 Data presented on potential overpressure zones _ _ _ _ _ _ _ _ _ _ Yes _ _ _ . . . . . . . .... . ................. . . . . . . . . . . . . . . . . . . . . . . .... . ..... . . . . . Appr Date 37 Seismic analysis of shallow gas zones . . . .. _ _ _ _ .. _ ................... NA. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ___ DLB 8/6/2019 38 Seabed condition survey (if off -shore) _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ __________ _ _ _ _ _ _ _ _ NA .. _ ... _ .. _ . _ _ . _ _ _ _ _ _ ....... _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ - - . _ _ _ - 39 Contact name/phone for weekly progress reports. [exploratory only] ........... . ... NA. _ _ _ _ . Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date r
