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Home My WebLink About218-0861. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: RPPG Treatment- Offset PROD Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 15872'feet None feet true vertical 3864' feet 7850' feet Effective Depth measured 15872'feet 7936', 8013'feet true vertical 3864' feet 3742', 3757' feet Perforation depth: Measured depth: True Vertical depth: Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 8491' MD 3846' TVD Packers and SSSV (type, measured and true vertical depth) 7936' MD 8013' MD N/A 3742' TVD 3757' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: West Sak Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 1899' 1777' Burst Collapse Slotted Liner Main Bore L2 Slotted Liner 9456' 7549' 7664' Casing 4086' 4026' 4-1/2" 9493' 15994' 15827' 3896' 1859' 119'Conductor Surface Intermediate 20" 10-3/4" 78' measured TVD 7-5/8" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 218-086 50-029-236106-61-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025638, ADL0025639 Kuparuk River Field/ West Sak Oil Pool KRU 1H-104 L2 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 1041 Gas-Mcf MD 1092 Size 119' 1085 11032827 1009 318933 330 N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 2704 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. RPPG pumped into Injector 1H-110. See events for details. Packer: Baker Premier Packer Packer: Baker ZXP Liner Top Packer SSSV: None Jan Byrne Jan.Byrne@conocophillips.com (907) 465-6471Staff Well interventions Engineer Slotted Liner 8163-15827' Slotted Liner 3785-3896' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:19 pm, Aug 20, 2025 Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2025.08.20 11:31:05-08'00' Foxit PDF Editor Version: 13.1.6 Jan Byrne DSR-9/11/25 RBDMS JSB 082525 J.Lau 11/4/25 DTTMSTJOBTYP SUMMARYOPS 7/22/2025 ACQUIRE DATA RIG UP FLOW CROSS, RUN HARDLINE AND REVERSE OUT SKID, SPOT SAND JET TANK. LAY LINER, SPOT BLENDER AND PUMP. SPOT CONTANER OF RPPG 7/23/2025 ACQUIRE DATA PUMP FULL BORE RPPG TO MBE IN D SAND LATERAL AT 8102' RKB. PUMPED 5908 LBS OF DAQING RPPG PRODUCT. RAPID INCREASE AS PRODUCT HIT MBE, FLUSH CALLED AT 2309 PSI @ 366 BBL JSV. CONTINUE TO SEE PSI INCREASE IN FLUSH, DROP RATE TO GET FLUSH VOLUME AWAY, MAX PSI 3029. JOB VOL 421 BBL WELL TO REMAIN SHUT IN FOR 48 HRS FOR RPPG TO FULLY CROSSLINK 7/28/2025 DATA ACQUISITION (PRE SW) DEGAS IA (COMPLETE), LOAD IA (COMPLETE) PRE SW MIT-IA. 1H-110/ 1H-104 RPPG Treatment Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG:1H-104 jennalt Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set X-Lock with Altor corrosion pups 1H-104 6/27/2025 rogerba Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 20 19.12 40.4 118.5 118.5 94.00 L-80 Welded SURFACE 10 3/4 9.95 40.3 1,899.3 1,777.4 45.50 L-80 Hydril 563 INTERMEDIATE 7 5/8 6.88 37.5 9,493.2 4,086.2 29.70 L-80 Hyd 563 SLOTTED LINER (MAIN WELLBORE) 4 1/2 3.96 8,444.9 15,993.8 4,025.8 12.60 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 35.4 Set Depth … 8,048.8 Set Depth … 3,763.7 String Max No… 4 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd563 ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 35.4 35.4 0.00 Hanger 13.475 Streamflo hanger 4" H BPV, 6.25" acme lift threads StreamF lo DMLX 3.900 2,541.4 2,199.4 60.25 Mandrel - SOV 4.500 4-1/2" x 1" KBMG GLM SLBG 4.5" x 1" KBMG 3.865 5,749.6 3,152.9 73.81 Mandrel – GAS LIFT 4.500 4-1/2" x 1" KBMG GLM SLBG 4.5" x 1" KBMG 3.865 7,309.2 3,592.3 75.96 Mandrel – GAS LIFT 4.500 4-1/2" x 1" KBMG GLM SLBG 4.5" x 1" KBMG 3.860 7,742.3 3,696.9 76.20 Gauge / Pump Sensor 4.500 Gauge Mandrel 9CR HES MXM 19367- 04 3.904 7,799.1 3,710.4 76.27 Mandrel – INJ 4.500 Chem Injection Mandrel 13CR HES Mandrel 3.907 7,863.8 3,725.6 76.66 Nipple - X 4.500 3.813 X nipple 13Cr VAMTOP HES 3.813" X nipple 3.813 7,921.1 3,738.5 77.49 Locator 4.500 Baker Locater W/9.69' seal assy Locater = 1.67' - 1.37' F/located Baker 192-47 13 CR 3.910 7,924.2 3,739.1 77.56 PBR 6.260 Baker 192-47 PBR - W/9.13' of seal bore Baker 192-47 13 Cr 4.750 7,936.3 3,741.7 77.82 PACKER 4.500 Baker Premier Packer Baker Premier 3.870 8,003.1 3,755.2 78.86 Nipple - X 4.500 3.813 X nipple HES 3.813" X nipple 3.813 8,020.1 3,758.4 79.12 Locator 4.500 Locater - spaced out 2' from fully located in ZXP @ 8,023.91' 3.958 8,021.9 3,758.8 79.14 Wireline Guide 4.500 Seal Assembly - reran from 2022 7ES work over - no seals Baker GBH-22 3.880 Top (ftKB) 8,012.7 Set Depth … 8,302.0 Set Depth … 3,810.4 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection TXP-M ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,012.7 3,757.0 79.00 PACKER 6.540 Baker ZXP Liner Top Packer 5.5" x 7.63", 5-1/2" H563 Baker ZXP LTP PN: H296-45 -0131, Control # 1062955 66-01 4.920 8,032.7 3,760.8 79.31 SBE 6.250 Baker 190-47 Seal Bore Extension, 5-1/2" Baker SBE PN: H02 -43317- A1 SI# 700886 4.750 8,052.3 3,764.4 79.50 CROSSOVER (XO) BUSHING 5.500 Reducing Crossover sub 5½" Hyd 563 X 4-1/2" TXP 3.950 8,100.7 3,773.2 79.44 NIPPLE 5.200 Camco 4-1/2" x 3.750" DB-6 Nipple, TXP-m SN# 4053-1R Camco DB 6 SN# 4053-1R 3.750 8,159.8 3,784.0 79.36 TRIPPLE CONNECT BUSHING 6.610 Baker 4.5" x 7.63"LEM #1 (Above Hook hanger) SN # 106290368-02 Baker LEM Pos 2 PN: H289-18 -0037, Control # : 1062903 68-02 3.700 8,163.0 3,784.6 79.39 TRIPPLE CONNECT BUSHING 6.610 Baker 4.5" x 7.63" LEM #1 (Below Hook Hanger @ 8162.94') Baker LEM Pos 2 PN: H289-18 -0037, Control # : 1062903 68-02 3.688 8,298.7 3,809.8 79.18 SEAL ASSY 4.500 Baker 190-47 GBH-22, 4-1/2", L-80 Straight Non-Locating Seal Assy Baker 190-47 GBH-22 3.870 Top (ftKB) 8,271.4 Set Depth … 8,490.5 Set Depth … 3,845.5 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection TXP-m BTC ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,271.4 3,804.6 79.00 PACKER 6.550 Baker ZXP Liner Top Packer 5.5" x 7.63", 5-1/2" H563 Baker ZXP LTP PN H296 -45- 0131, CN 1064274 53 4.920 HORIZONTAL, 1H-104, 8/11/2025 2:29:16 PM Vertical schematic (actual) SLOTTED LINER (MAIN WELLBORE); 8,444.9-15,993.7 INTERMEDIATE; 37.5-9,493.2 NIPPLE; 8,439.9 NIPPLE; 8,100.7 Wireline Guide; 8,021.9 Nipple - X; 8,003.1 PACKER; 7,936.3 OTHER; 7,863.0 Nipple - X; 7,863.8 FISH; 7,850.0 Mandrel – INJ; 7,799.1 Gauge / Pump Sensor; 7,742.3 Mandrel – GAS LIFT; 7,309.2 Mandrel – GAS LIFT; 5,749.6 Mandrel - SOV; 2,541.4 SURFACE; 40.3-1,899.3 CONDUCTOR; 40.4-118.5 Hanger; 35.4 KUP PROD KB-Grd (ft) 38.89 RR Date 9/18/2018 Other Elev… 1H-104 ... TD Act Btm (ftKB) 16,014.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292361000 Wellbore Status PROD Max Angle & MD Incl (°) 97.52 MD (ftKB) 14,589.00 WELLNAME WELLBORE1H-104 Annotation LAST WO: End Date 5/14/2024 H2S (ppm) DateComment SSSV: NONE Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,291.2 3,808.3 79.12 SBE 6.250 Baker 190-47 Seal Bore Extension, 5-1/2" Baker PN H02- 43317- A1, WO 4509345 733 4.750 8,310.8 3,812.0 79.26 CROSS OVER (XO) BUSHING 5.500 Reducing Crossover sub 5½" Hyd 563 X 4-1/2" TXP 3.960 8,325.8 3,814.8 79.34 TRIPPLE CONNECT BUSHING 6.600 Baker 4.5" x 7.63"LEM #1 (Above Hook hanger) SN # 106290791-02 Baker PN H289 -18- 0036, CN 1062907 91-02 3.700 8,329.0 3,815.4 79.36 TRIPPLE CONNECT BUSHING 6.600 Baker 4.5" x 7.63" LEM #1 (Below Hook Hanger @ 8328.95) Baker PN H289 -18- 0036, CN 1062907 91-02 3.688 8,439.9 3,835.8 79.38 NIPPLE 5.450 Camco 4-1/2" x 3.563" DB-6 Nipple, TXP-m SN# 5773-2 Camco DB 6 PN: 1028455 30, SN 5773-2 3.563 8,487.3 3,844.8 78.30 SEAL ASSY 4.500 Baker 190-47 GBH-22, 4-1/2", L-80 Straight Non-Locating Seal Assy Baker PN H453 -01- 0033, CN: 1064161 81-01 3.890 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,850.0 3,722.4 76.58 FISH 2 SLIPS FROM TEST PACKER LEFT IN HOLE. 2.19" X 1.49" X 0.53". Lost at 7850' but not seen during May 2024 tubing swap so exact location unknown. 4/17/2024 0.000 7,863.0 3,725.4 76.65 OTHER Altor corrosion 2 7/8" pipe joints on 3.81" X Lock (X Lock, 13 Chr Pup, AltorLines 5600 Pup, AltorLines 7600 pup, L- 80 Pup) (OAL = 20') 6/27/2025 2.440 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,541.4 2,199.4 60.25 1 GAS LIFT GLV BK 6.38 1,490.0 5/14/2024 SLBG KBG 4-5 0.250 5,749.6 3,152.9 73.81 2 GAS LIFT DV BK 6.35 0.0 5/12/2024 SLBG KBMG 0.000 7,309.2 3,592.3 75.96 3 GAS LIFT OV BK 6.39 5/16/2024 SLBG KBGM 0.375 7,742.3 3,696.9 76.20 4 5.68 3 5/12/2024 Opsis Gaug e mandr el Halliburt on Opsis Gauge 0.250 7,799.1 3,710.4 76.27 5 CHEM 5.57 5/12/2024 Chemi cal injecti on line 1100 PSi to open Halliburt on Chem injection 0.250 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,464.9 3,840.4 79.03 NIPPLE 6.060 Baker 5.5" "RS" Packoff Seal Nipple 17# L-80 Hyd 563 box x box Baker PN: H294- 01-0656, Control No.: 106296385- 02 4.880 8,497.1 3,846.9 77.82 XO REDUCING 5.500 5.5" Hyd 563 15.5 # box x 4.5" 12.6# TXP- pin Crossover 3.970 10,718.1 4,096.2 91.79 SWELL PACKER 6.010 Baker 6.0" OD Swell Packer #6 (3) SN: 052826-001-21 Baker PN H301-87 -0397, SN: 052826-001 -21 3.940 11,012.3 4,093.3 88.99 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #5 (2) SN: 052826-001-32 Baker PN H301-87 -0397, SN: 052826-001 -32 3.940 11,585.5 4,076.7 92.81 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #4 (1) SN: 052826-001-5 Baker PN H301-87 -0397, SN: 052826-001 -5 3.940 11,944.0 4,047.9 94.83 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #3 (C) SN: 054009-010-18 Baker PN H301-87 -0450, SN: 054009-010 -18 3.950 13,574.7 4,008.8 91.99 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #2 (B) SN: 054009-010-20 Baker PN H301-87 -0450, SN: 054009-010 -20 3.940 HORIZONTAL, 1H-104, 8/11/2025 2:29:16 PM Vertical schematic (actual) SLOTTED LINER (MAIN WELLBORE); 8,444.9-15,993.7 INTERMEDIATE; 37.5-9,493.2 NIPPLE; 8,439.9 NIPPLE; 8,100.7 Wireline Guide; 8,021.9 Nipple - X; 8,003.1 PACKER; 7,936.3 OTHER; 7,863.0 Nipple - X; 7,863.8 FISH; 7,850.0 Mandrel – INJ; 7,799.1 Gauge / Pump Sensor; 7,742.3 Mandrel – GAS LIFT; 7,309.2 Mandrel – GAS LIFT; 5,749.6 Mandrel - SOV; 2,541.4 SURFACE; 40.3-1,899.3 CONDUCTOR; 40.4-118.5 Hanger; 35.4 KUP PROD 1H-104 ... WELLNAME WELLBORE1H-104 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 13,904.4 4,013.9 82.07 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #1 (A) SN: 054009-010-14 Baker PN H301-87 -0450, SN: 054009-010 -14 3.940 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com HORIZONTAL, 1H-104, 8/11/2025 2:29:17 PM Vertical schematic (actual) SLOTTED LINER (MAIN WELLBORE); 8,444.9-15,993.7 INTERMEDIATE; 37.5-9,493.2 NIPPLE; 8,439.9 NIPPLE; 8,100.7 Wireline Guide; 8,021.9 Nipple - X; 8,003.1 PACKER; 7,936.3 OTHER; 7,863.0 Nipple - X; 7,863.8 FISH; 7,850.0 Mandrel – INJ; 7,799.1 Gauge / Pump Sensor; 7,742.3 Mandrel – GAS LIFT; 7,309.2 Mandrel – GAS LIFT; 5,749.6 Mandrel - SOV; 2,541.4 SURFACE; 40.3-1,899.3 CONDUCTOR; 40.4-118.5 Hanger; 35.4 KUP PROD 1H-104 ... WELLNAME WELLBORE1H-104 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG:1H-104L1 jennalt Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic10.0 10/11/2018 jennalt Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1 SLOTTED LINER (L1) 4 1/2 3.96 8,329.0 15,934.7 3,972.3 12.60 L-80 IBT-m Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,448.6 3,883.0 88.26 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #7 "DD" SN: 054009-010-15 Baker PN: H301- 87-0450, SN: 054009 -010-15 3.958 10,400.8 3,957.2 86.79 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #6 "CC" SN: 054009-010-10 Baker PN: H301- 87-0450, SN: 054009 -010-10 3.958 10,651.6 3,970.8 85.49 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #5 "BB" SN: 054007-010-23 Baker PN: H301- 87-0450, SN: 054007 -010-23 3.958 10,811.3 3,991.7 81.43 SWELL PACKER 6.010 Baker 6.0" OD Swell Packer #4 "AA" SN: 054009-010-25 Baker PN: H301- 87-0450, SN: 054009 -010-25 3.958 11,176.6 4,027.9 87.66 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #3 "F" SN: 054009-010-16 Baker PN: H301- 87-0450, SN:054009- 010-16 3.958 13,645.0 4,005.2 83.12 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #2 "E" SN: 054009-010-24 Baker PN: H301- 87-0450, SN: 054009 -010-24 3.958 13,830.1 4,026.4 84.46 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #1 "D" SN: 054009-010-1 Baker PN: H301- 87-0450, SN:054009- 010-1 3.958 HORIZONTAL, 1H-104L1, 8/11/2025 2:29:18 PM Vertical schematic (actual) L1 SLOTTED LINER (L1); 8,329.0-15,934.7 INTERMEDIATE; 37.5-9,493.2 Nipple - X; 8,003.1 PACKER; 7,936.3 OTHER; 7,863.0 Nipple - X; 7,863.8 FISH; 7,850.0 Mandrel – INJ; 7,799.1 Gauge / Pump Sensor; 7,742.3 Mandrel – GAS LIFT; 7,309.2 Mandrel – GAS LIFT; 5,749.6 Mandrel - SOV; 2,541.4 SURFACE; 40.3-1,899.3 CONDUCTOR; 40.4-118.5 Hanger; 35.4 KUP PROD KB-Grd (ft) 38.89 RR Date 9/18/2018 Other Elev… 1H-104L1 ... TD Act Btm (ftKB) 15,972.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292361060 Wellbore Status PROD Max Angle & MD Incl (°) 94.87 MD (ftKB) 11,956.00 WELLNAME WELLBORE1H-104 Annotation LAST WO: End Date 6/27/2022 H2S (ppm) DateComment Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG:1H-104L2 jennalt Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic10.0 10/11/2018 jennalt Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L2 SLOTTED LINER (L2) 4 1/2 3.96 8,162.9 15,827.0 3,896.2 12.60 L-80 IBT-m Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,281.9 3,825.0 88.86 SWELL PACKER 5.940 Baker 6.0" OD Swell Packer # "MM" SN: 001893-001-9 Baker PN: H3014- 15-0021, SN:001893- 001-9 3.958 13,619.6 3,892.3 78.58 SWELL PACKER 6.030 Baker 6.0" OD Swell Packer # "LL" SN: 001893-001-15 Baker PN: H3014- 15-0021, SN:001893- 001-15 3.958 13,921.4 3,929.5 86.78 SWELL PACKER 5.990 Baker 6.0" OD Swell Packer # "KK" SN: 001893-001-10 Baker PN: H3014- 15-0021, SN:001893- 001-10 3.958 HORIZONTAL, 1H-104L2, 8/11/2025 2:29:18 PM Vertical schematic (actual) L2 SLOTTED LINER (L2); 8,162.9-15,827.0 INTERMEDIATE; 37.5-9,493.2 Nipple - X; 8,003.1 PACKER; 7,936.3 OTHER; 7,863.0 Nipple - X; 7,863.8 FISH; 7,850.0 Mandrel – INJ; 7,799.1 Gauge / Pump Sensor; 7,742.3 Mandrel – GAS LIFT; 7,309.2 Mandrel – GAS LIFT; 5,749.6 Mandrel - SOV; 2,541.4 SURFACE; 40.3-1,899.3 CONDUCTOR; 40.4-118.5 Hanger; 35.4 KUP PROD KB-Grd (ft) 38.89 RR Date 9/18/2018 Other Elev… 1H-104L2 ... TD Act Btm (ftKB) 15,872.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292361061 Wellbore Status PROD Max Angle & MD Incl (°) MD (ftKB) WELLNAME WELLBORE1H-104 Annotation LAST WO: End Date 6/27/2022 H2S (ppm) DateComment DATA SUBMITTAL COMPLIANCE REPORT 1/18/2019 Permit to Orill 2180860 Well Name/No. KUPARUK RIV U WSAK 1H -104L2 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23610-61-00 MD 15872 TVD 3864 Completion Date 9/18/2018 Completion Status 1 -OIL Current Status 1 -OIL UIC No REQUIRED INFORMATION Mud Log No V Samples No / �/ Directional Survey Yes V DATA INFORMATION List of Logs Obtained: GR/RES (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Med ia No Start Stop CH Received Comments ED C 29841 Digital Data 8230 15872 10/17/2018 Electronic Data Set, Filename: CPAI_1H- 1041-2_Scope_Resistivity_L W D013_RM_LAS.las ED C. 29841 Digital Data 103 1906 10/17/2018 Electronic Data Set, Filename: CPAI 1H- 104_VISION_Resistivity_LW D001_RM_LAS.las ED C 29841 Digital Data 1781 9514 10/17/2018 Electronic Data Set, Filename: CPAI_1 H- 104_VISION_Resistivity_LW D002_RM_LAS.las ED C 29841 Digital Data 58 15872 10/17/2018 Electronic Data Set, Filename: CPAI_1H- 104L2_Scope_Resistivity_RM_LAS.Ias ED C 29841 Digital Data 10/17/2018 Electronic File: CPAI 1H- 104_VISION_Resistivity_RM_DLIS_LW D001.dlis ED C 29841 Digital Data 10/17/2018 Electronic File: CPAI 1 H- 104_VISION_Resistivity_RM_DLIS_LW D001.htm I ED C 29841 Digital Data 10/17/2018 Electronic File: CPAI 1H- 104_VISION_Resistivity_RM_DLIS_LW D002.dils ED C 29841 Digital Data 10/17/2018 Electronic File: CPAI 1 H- 104_VISION_Resistivity_RM_DLIS_LW 0002.htm I ED C 29841 Digital Data 10/17/2018 Electronic File: CPAI_1 H - 104L2 Scope_Resisitivity_DLIS_RM_LWD013_0 rilling.dlis ED C 29841 Digital Data 10/17/2018 Electronic File: CPAI_1H- 104L2_Scope_Resisitivity_DLIS_RM_LW D013_D rilling.html ED C 29841 Digital Data 10/17/2018 Electronic File: CPAI 1 H - 104L2 Scope_Resisitivity_DLIS_RM_LWD013_ MAD Pass.dlis AOGCC Page 1 of 3 Friday, January 18, 2019 DATA SUBMITTAL COMPLIANCE REPORT 1/18/2019 Permit to Drill 2180860 Well Name/No. KUPARUK RIV U WSAK 1H -104L2 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23610-61-00 MO 15872 TVD 3864 FED C 29841 Digital Data ED C 29841 Digital Data ED C 29841 Digital Data ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C 29841 Digital Data 29841 Digital Data 29841 Digital Data 29841 Digital Data 29841 Digital Data 29841 Digital Data 29841 Digital Data 29841 Digital Data 29841 Digital Data 29841 Digital Data 29841 Digital Data 29841 Digital Data 29841 Digital Data 29841 Digital Data 29841 Digital Data Completion Date 9/18/2018 Completion Status 1-0IL Current Status 1 -OIL UIC No wri tizu i8 Clectromc Fne: CPAI 1H - 104L2 Scope_Resisitivity_DLIS_RM_LWD013_ MAD Pass.html 10/17/2018 Electronic File: CPAI_1H- 104L2_Scope_Resisitivity_DLIS_RM.dlis 10/17/2018 Electronic File: CPAI 1 H- 104L2_Scope_Resisitivity_DLI S_RM.html 10/17/2018 Electronic File: CPAI 1H- 104L2_Scope_Resistivity_2 MD_RM.pdf 10/17/2018 Electronic File: CPAI_1 H- 104L2_Scope_Resistivity_2T VD_RM.pdf 10/17/2018 Electronic File: CPAI_1 H- 104L2_Soope_Resistivity_5MD_RM.pdf 10/17/2018 Electronic File: CPAI 1 H- 104L2_Scope_Resistivity_5TVD_RM.pdf 10/17/2018 Electronic File: CPAI 1H- 104L2_PriMSurveyList.csv 10/17/2018 Electronic File: Gyrodata Survey - 1H-104 - Post SLB SAG.pdf 10/17/2018 Electronic File: 1H-1041-2 NAD27 EOW Compass Surveys [Canvas].txt 10/17/2018 Electronic File: 11-1-1041-2 NAD27 EOW Compass Surveys [Macro].txt 10/17/2018 Electronic File: 1H -104L2 NAD27 EOW Compass Surveys [Petrel].txt 10/17/2018 Electronic File: 1H-1041-2 NAD27 EOW Compass Surveys [Surveys].txt 10/17/2018 Electronic File: 11-1-1041-2 NAD27 EOW Compass Surveys.pdf 10/17/2018 Electronic File: 1H-1041-2 NAD83 EOW Compass Surveys [Canvas].txt 10/17/2018 Electronic File: 1H-1041-2 NAD83 EOW Compass Surveys [Macro].txt 10/17/2018 Electronic File: 1H-1041-2 NAD83 EOW Compass Surveys [Petrelj.txt 10/17/2018 Electronic File: 1H-1041-2 NAD83 EOW Compass Surveys [Surveys].txt AOGCC Page 2 of 3 Friday, January 18, 2019 DATA SUBMITTAL COMPLIANCE REPORT 1/18/2019 Permit to Drill 2180860 Well Name/No. KUPARUK RIV U WSAK 1H -104L2 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029.23610-61.00 MD 15872 TVD 3864 Completion Date 9/18/2018 ED C 29841 Digital Data Log C 29841 Log Header Scans Well Cores/Samples Information: Name INFORMATION RECEIVED Interval Start Stop Completion Status 1-0I1 Current Status 1-0I1 UIC No 10/17/2018 Electronic File: 11-1-10412 NAD83 EOW Compass Surveys.pdf 0 0 2180860 KUPARUK RIV U WSAK 11-1-1041-2 LOG HEADERS Sample Set Sent Received Number Comments Completion Report V Directional / Inclination Data V Mud Logs, Image Files, Digital Data Y / e Core Chips Y Production Test Informatior((Y>/ NA Mechanical Integrity Test Information NA Composite Logs, Image, Data Files (0 Core Photographs Y Geologic Markers/Tops , �Y�/ Daily Operations Summary IY ) Cuttings Samples Y /6� Laboratory Analyses Y NA COMPLIANCE HISTORY Completion Date: 9/18/2018 Release Date: 8/1/2018 Description Date Comments Comments: Compliance Reviewed By: Date AOGCC Page 3 of 3 Friday, January 18, 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: CIE] Gas El SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: 1b. Well Class: Development 2 Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: , 9118/2018 14. Permit to Drill Number / Sundry: 218-086 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: - 9/7/2018 15. API Number: , 50-029-23610-61.00 4a. Location of Well (Governmental Section): Surface: 5201' FNL, 772' FEL, Sec 28, T12N, R10E, UM Top of Productive Interval: 2114' FNL, 101' FEL, Sec 34, T12N, R10E, UM Total Depth: 2223' FNL, 3857' FEL, See 26, T12N, R10E, UM 8. Date TO Reached: • 9/12/2018 16. Well Name and Number: KRU 1H-1041-2 9. Ref Elevations: KB:92.79 GL: 64.1 BF: 17. Field / Pool(s): Kuparuk River Field/West Salk Oil Pool 10. Plug Back Depth MD/TVD: NIA 18. Property Designation: , ADL25639, ADL 25638 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 549569 y- 5980782 Zone- 4 TPI: x- 555539 y- 5978631 Zone- 4 Total Depth: x- 557017 y- 5983813 Zone- 4 11. Total Depth MDlTVD: .1587213864 19. DNR Approval Number: 80-261, 931695000 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1738/1646 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 1 WA (ft MSL) 1 21. Re-drill/Lateral Top Window MD/TVD: 8167/3785 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 94 L-80 40 118 40 118 42 Existing cement to surface 103/4 45.5 L-80 40 1899 40 1777 131/2 885 sx 11.0ppg Class G 75/8 29.7 L-80 37 9493 37 4086 97/8 1401 sx 15.8ppg Class G 41/2 12.6 L-80 8163 15827 3785 3869 63/4 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 Q: 8298-15827 MD and 3798-3869 TVD.... 9/16/2018 COMPLEI ION qD/,� TE '-- VE It if 01y. FIEG 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 41/2 8051 NIA 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑� Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 9/29/2018 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 10/6/2018 Hours Tested: 14hrs, 7min. Production for Test Period Oil -Bbl: 2181 Gas -MCF: 569 Water -Bbl: 19 Choke Size: - Gas -Oil Ratio: 261 Flow Tubing Press. 340Psi JCasinq Press: 11286psi Calculated 24 -Hour Rate Oil -Bbl: 7 Gas -MCF: Water -Bbl: Oil Gravity - API (corr): 19 Form 10-407 Revised 5/2017 jam- 11IzIlY /. (QtyCONTINUED ON PAGE 2 RBRM J Submit ORIGINIAL only„ I", x.e- 12-1Ig I �Ct OCT 2 2 2018 (T 28. CORE DATA Conventional Corals): Yes ❑ No 9 Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, From/To), 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 1738 1646 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 8167 3785 information, including reports, per 20 AAC 25.071. Formation @ TPI -West Salk D TD 15872 3864 Formation at total depth: WEST SAK D 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, r well test results, per 20 AAC 25,070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge.? Authorized Name: G.L. Alvord Contact Name: Scott Brunswick Authorized Title: Alaska Drilling Manager Contact Email: Scott.A.Brunswick & co .com Authorized Contact Phone: 263-4249 Signature: ,`- Date: (0J(7 2,jIC7 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only 10.3/4",45.5#. LAO, Hvd563 D/177T TVD W ellbead / Tubing Head / Tree, U-3/8" x 4'6".5 UW ksi Tubing SVin,'. 4 -IQ", 12.6 #. LAO IBT-M G. Lin MuMrcl, 4-1/2" x I" w/ SOV 2500'MD 1H-104 Producer Schematic Final as-nomolailed Gm Lin Mar,AcL 4-I2" x V w/dummy valw 5732' MD :e [' Gu Lift Mmdml,0.@"s I" vIdummylabs n 2 �7164'MO E g 41'/V SSD wilt 3.812"DB Nipple profile v f ]799' AID y Pcm_ , Dorm HOW Gauge n2 Slaekeal Baker Hook Hmger ��-796]'MD 21. Level 3 Juaclim Systems Turing Seal Aasmbly - 4� 8019' MD ZXP Packem� ��L2"D'"Sand Upper LOW W.&,,(49167 MD/3185'TVD ••• IH-IO4 L2: 8012' MD •••••.• IH -104 LI:82]I'MD •----- 4-12SIOIIed LinerendBWk pipe 124&L -el } 3.75" DB Nipple Prank/ ______________ .................... 8100' MD Lelwal Haw Module Tubing Seal Asttmbly 3.562" DP Nipple PmBle 843W MD LO ZXP poker_ MD E 8444' 7-55", 29 70, L80, H3d563, C y„ 9493' MD /4091' T4 LI "D" Saad Lower Lobe Window I� 8334' MD /3816' TVD , -� 4-I/2"SlOucd Liner and Blank pipe 12.60 L80 TXPABTM 1260 TXPSLHT L80 GVal` D sand(L2) luteral 15872' MD /.%4' TVD 6-W D/Bsand(LDlawaral 15912' MD/ 3915' TVD 6-3/CA2/A3 KUP PROD 1H-104 COPIOCO l' it Ip5 WellAttribuG Max Angle; To LI¢p Name Wellbore APWWI WBIIInm Slalus ncl l'1 MO or Aet BM1n InKO) AleskB.InC WEST SAN 500292361000 PROD ].52 t4,589uu 16,0140 x.,m. Im1EIGH63:34:47 P" Last Tag Varvslxeemals l -N) As-kownEntl Oab DwthMKIU LastMW By LAST TAG- Ie ft ..._.. ... _................ Last Rev Reason NBING IMWGER. 3]e ""'."""""-""""................................... AnndaYon End REV REASON: New Mulblat, Installed Gas Lift Design 8 Pulled RRC 91282018 No.Base." Oele LasIMW BY Bon MV Cuing Strings Casinglbwrmfan oO pn) 101ip Top lnNe) sn Depen meat ser DRes, rVD1...MUer CONDUCTOR 20 19.12 404 118.5 118.5 n... Grade rev Tmaae 9400 LA0 Weltled CCNOL'CiDR: MA -11a5 Call, Densoltlen OD lln) I011nl Tap YMUB) swassaa lnkB) SW Depth (NDI... SURFACE 10314 995 403 1,899.3 1,7]].4 WBLaA 11... ore Topi reatl 45.50 LA0 Hydril 563 SURFACE: VGA.a9J Gsl�q Dewrlpdon ODlln) ",DIInI T'NDURB) SN DeRe INN") San Dap IN ITVED INTERMEDIATE ]518 688 3]5 9,4932 4,062 WVLen 11...Grace Tap Thread 29.]0 LA0 Hyd 553 Ga4p Dexrlpt'on 0 we ID llnl Top(nKB) Set Dept IM(BI SN W. TVO1... SLOTTED LINER(MAIN 4112 3.96 8,444.9 15,9939 4,0258 WYLen S...Gmtle TOPTIN d 12W L-80 SORT GAS UFi:zsi.a WELLBORE) Liner Details Nominal D GASUFi:s,]3a9 TOP(ftKB) Top".".KB) T,Incll-I Item Oes Gom girl 8,464.9 3,0404 79.03 NIPPLE a er 58" "RS" ac1,0 Seal Nipple WE L -BD 4.880 Hyd 563 box x tax Gib UFi:l lei s 8,46].] 3,8410 ]893 HANGER der 6"x 3"Flex-Loc Liner banger ilk L- 4.800 SLIDING SLEEVE; 7=1 Hyd 553 pin x pin 8,4]].5 3,842.9 7862 SBE er7,475"ID al ore Extension, 512" 4,750 Hyd 563 tax x pin 8,49].1 3,846.9 77,82 5,5" Hyd 56315.5 # box x 4.6612.6# TXP- pin 3.970 REDUCING Crossover LGCATGR, 90212 PAckEN.amv 10.]18.1 4,096.2 9179 ELL Baker D well Packer go 3) EN'. 052826-001- 3.940 SE4 Aear,aoa.9 PACKER 21 SBE; B.. CROSSDYER IKO)BUSHING; 6 Gsz.a 11,0123 4,093.3 W99 SWELL PACKER Baker 6 UP ED Swell Packer#5 ) SN '.05282 1- 32 3.940 NIPPLE; BIDS 7 TRIPPLE CONNECTBU5x1N0: SINS. 11,585.5 4,0]86 92.81 PACKER Baker well Packer #4 :052826-001- 5 3.940 TRIPPLE CONNECT BUSHING-; e.f®e Li SLOTTED .-N(UP.Z): 11 9440 4,779 94.8J PACKER Baker well Packer XJ ) N'. 054009-01 - 18 3950 AC..1 B., S PACKEfll dO]w SaE;ay. U,94] 4,008.8 91.99 PACKER Baker well Packer #2 ( M054009-010- 20 3940 CROSS OYER (xG)euea of 13,9044 4,013.9 82.07 Baker. well Packer# (A).5409-010- 3.94 NIPPLE CONNECT SUSXLVG: PACKER 14 IL Strings CRIPPLE CONNECT BUBXGINSGD.TBDing LI SLOTTED LINER IL1k B,SSV-15.9041 TVI, Dee -often Me... TUBING- 4112 mlln) 3.96 Top lflK"I Set 32.6 8,050.8 Oeaft(tL.., nook pro.)I... Wl11bYN 3,764.1 12.60 GraEe LA0 Top Connmllon BT -m PRODUCTION Completion Details inP mne) TOP pvcl (nKB) TVN lnnl (°t Ihm Oea einke Com m pm 7,803.1 7,7114 76.30 SLIDING 4-112' Sliding Sleeve, IBT-C. .812 CMU. RHC Plug cal DB Lock 3812 SLEEVE 7,9716 3,749. 78.43 GAUGE 4-112Solid gauge Mandrel, NOPG single gauge, ROC -I50 3. g8BgBTXP-m $021.3 3,758. 79.13 LOCATOR Baker 19247 locator Seal assembly OD 5. Larger OD above .7 IOCBted INTFRMEDBREF a7.u.xsa.z 0,023.0 3,759.0 7.1 SEALASSv Baker 19247 Water seal assembly wlmule shoe -below located 3870 Mandrel Inserts sr oat T o Ban N TOP(rVD) V.Iva laab POM1sa irs TOp InItB1 (nNB) Mahe Motlel OD lin) Sery Typ Type Bnl (W9 Run Datr Cam 1 2,5239 2,190.8 amco #BMG 1 GAS LIFT GLV BK 0.188 1,4550 9/272018 5,736 3,149. amco #BMG 1 GAS LIFT GLV BK 0.188 1,46]0 912712018 3 7,167.5 3,554. amco KBMG 1 GAS LIFT OV EK 0.313 00 92712018 Notes: General & Safety End Cale AnnDlatbn 10/11/2018 NOTE'. View SChanrS11CW1Alaska SChema1A10.0 SLOTTED LINER (MAW WELIP0RE).a4M.&15.9ia.7 KUP PROD AMPIP"" IN Well Atlribut _ ConoeoPhil6 rielarvame NBSka,in WESTSAK AST WO. IH -104L1 114miNT MUMM9334'.4OPM Last Tag WrG'slWwrmEc lxbM) Annotation CAST TAG: Entl Oah DePIB(XI(B) Last Mad By jennalt TUBING rw4GER; We Last Rev Reason Apopka. Entl DSM Lxs+MCO By ..__........................................................... ..._.............. _.._ ..................................................... ... .. ............ REVREASON'.New Mullilat, IREWIIed I Gas Lift Design B Pulled RHC 912812016 jennalt Casing Strings Caning Deseripdon OB 6n) LI SLOTTED LINER B-1) 4112 10 Ont 1 O IRKS) Ser Beprh BUB) Sn OepIB("'DL..MLen IL..Grade 3.96 8.3290 15,934.) 3916.9 12.60 L-60 TOPTh IBT-m Liner Details CONDUCTOR 40. 1165 Top IRKS) lip PPf0)(flKB) Top puts Rem Be. Co. Nominal W lin) 8,329.0 3,8154 ]9.36 HANGER Baker "B-3" Flanged Boo anger, 4.5' X 7. nsece 5.620 Casing SUNME4oa-+8193 8.3484 3,8187 81.35 HANGER Baker " Flanged hook hanger, 5"X]. 3"'B W 8346.34' MD 3.990 GAS LIFT; $Si1.8 8.4486 3,82].6 8826 WELL PACKER Baker . 0 Ewell PaCker# N: 054009m 01045 3.958 10,40).8 3,901.9 86.79 SW 54 - Baker 6,0s OD Swell Packer054009- PACKER PACKER 010.10 Gas T. SM. 10°6516 3,915.4 8549 Baker Swell Packer #5 " 054007m 3. 58 PACKER 010.23 10,8113 3,936.] 8143 Baker J u OD Spral Parker #4 "AA" 54 - 395B GASu9L 7.19E5 1 ISWELL PACKER 010-25 11,1766 3,9715 87,66 SWELL Baker cker #3 F" N: 9- 3958 KDING SLEEVE, TRUST PACKER 010-16 13,645.0 3, 9.8 83.12 WELL Baker . " D we acoa#2 "E' N: 9- 3.958 PACKER 010-24 1T83( 3.971. 8446 WELL Bske16. D we Packer bt "D" SN, 3.958 PACKER 010-1 Lac9ioR'. eAzt.z PACKER. e.MR7 SEALASSr:9ozza Tubing Strings TubinB D. -I"' 51rinO Ma... LI LEMIZXPLIHER 4112 OQn) 3.96 T7 'D Be[OepIB511 8.2714 8,490.5 MpIB Be 3,828.fi YM6Nfl) 1260 GrMn L -BO Top ConrreeBon TXP-m BTC RIE;fi.Ni.i TOP PACKER Completion Details CROSSOVER (SO)W.... 9¢523 Top"or Top Inc, Too ME) (RKE) CI Item Des Co. Nominal 10(1n) NIPPLE; .11. 1- 8271.4 PACKER Baker ZXP Liner Tap Packer 5.6' x)63', 5112' H563 4920 TKINUE CONNECT BUS.E.; 82912 SBE Baker 190d7$eal BOR Extension, 5-1 4.750 9.1589 TRIPPLE CONNECT BURNING: e,1m0 8,310.8 3,8120 7926 5 VE Red.., (XO) BUSHING Crossover 9uB5 i"Hy0563X4-112'TXP 3960 13 SLOTTEDUNER (UL, 8.+921+S.BiT.O 8,325.8 3,814.8 79.34 TM7PUE akar x "LEN pt (Alrove Hookanger N# 106290791 3.700 CONNECT -02 BUSHING PACI(ER; a,Zl19 WE.e,a1.z 8,329.0 3,815 36 4 79 LE Baker 4.5'x).83"LEN p1 (Below Hook Hanger@8328.95) 3.688 CROSSOVER(( )BURNING: CONNECT 93+De BUSHING TRIPPLE CONNECT BUSHING; e.Sn9 8439.9 3,82]) 8792 NIPPLE Camco4-la'x3563"DB6NIppW,TXP-m SN#577}2 3.563 INTERMEDIATE, 975$4912 TRIPPLE CONNECT BUSHING: 84823 3,628.5 8991 SEAL ASSY Baer -47 GBH -22.4-11 L- vBghl N9n-Locating ea 3.890 e. mo Assy Notes: General 8 Safety EDaM Anrwtatian 1N11 g18 NOTE View SEh,mrt,l W Alaska SCheRRUC10.0 NIPPLE; S,4R.B SEALASSY:949T.2 I� LI SLOTTED LINER (L+): a SSS G-I551AT KUP PROD 1H -104L2 c(��(�(��1- Well Atm but Max All TD ave(;• °'))tips 0Name WeIIMrePPUUW WeIIMmS us MDIM1 PciBImIXXB) Alaska, Ire. WEST SAN 500292361061 PROD 628 12,329.UU 15,63)0 IINW13. 10461334. 49 PM Last Tag VxMl wwwwwo soW) Amrohtlon LAST TAG' End Dab Cash JohnLssL MOO By jenna t Last Rev Reason TAPING It9NGER; 32.6 ----------------- "-'-" 9eseQDsie REV REASON'. New Mullilal, Installed Gas Lift Design Pulled RHC 92612018 REV REASON LAM MOtl By )ennalt ml Casing Strings ............................................................... .............. cosine Desa(ipXOoo0(ml L2 SLOTTED LINER(L2) 4112 ID lml Tap mrce) fief Devin IXN81 SM DPAh IrvDt... WULen 6...Gratle TOP Th. 396 8,162.9 15.8270 3,868.fi 12.60 L-80 IBT-m Liner Details Nominal lD Top Mine) IS (TWO) IXKaI TaPInCI(°) Ihm Dae Co. (in) 8,1629 3)84.6 79.9 HANGER Baker" J" Flangetl hook hanger, 4 5 X 7,63"nide 5630 CONDUCTOR:aalms casing '3 787 1.15 HANGER Baker" F -"nge0hopkhangeT, 4.5"%]. 15W 3990 ,182.) @ 8180.65' MO 6,2819 3,]9)4 8M TMUL Baker." OD SWDII Packer# M" SN-. 3.958 PACKER 001-9 suaFACe.as+,ama 13,8196 3,864.] ]. LL Baker (TO "OD Swell Packer #' 'LU SN: 3- 3.958 PACKER 001-15 13921.4 3,902.0 86] W LL Baker wet Packer#"KK SN; 1 3.958 Gas uFT. 2.saa PACKER 001-10 Tubing Strings Toeing W:cnPnon aina. Ma... L2 LEMIZXPLINER 4112 ID (ml 3.96 Too lXxRl sM 8,012.7 8,3020 C.PUI (ft .. Set OePan (TVD) (... 3,]9].6 wlpeaft 1260 II L-80 Top Connecnan TXP-M TOP PACKER Completion Details GAS LIFT. goes Top IXXBI Top(ToD) TOP MPI (P sl E) POODO, COM No -nal ID 9n) 0,012.7 PACKER Baker ZXP Liner TOP Packer 5.5" x].83", 5-112' H563 4920 Goa LIFT ].161.6 8,0327 SBE Baker 190-4] Seal Bae Extension, St 4 ]50 8,052 3 R Reducing Crossover sub 5K" Hyd 563 X 4-11T TXP 3.950 (XO) BUSHING SLIDING SLEEPS. 7.BD1 8,100.) NIPPLE amco 4-1R'x3]50"D&6 Nipple. T%P-m SN#99'Ff0 3.750 8.1598 3,]840 ]9.3 TRI L Baker . x 'L M#1 Above Dok nger) 3.]00 CONNECT -02 BUSHING 0,1630 784.6 )939 TRIP Baker4.5"x].63"LEM#i (Below Hook Hanger@ 8162.94') 3.6M CONNECT BUSHING 8,298] 3,]9.6 9015 EALASSY Baker d] H-22,41 ",L- tGight Non-L6csang Seal 3.870 LOCATOR: III2 A35y PACRER 6M2T Notes: General s Safety SEALAESY.E=.G saE', 609.] End Doh Anmtalon CROSSOVER Vre BUSHING: IOil 1Q018 NOTE. View Schematic wl Alaska SMereatic100 BW2a NIPPLE; B.f02] TRIPPLE CONNECT BUSMNG: &1588 .R INTERMEDIATE: 3IQaa62 TRIPPLE CONNECT BUSHING; SHOP SFPL Ass", 1117 III USLOTTEDUNER621 1, R1e2&15.8,01 operations Summary (with Timelog Depths) 11-1-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log SWrt oeph Start Time End Time Our (m) Phase Op Cotle Activity Code Time P -T -X Operation (NCB) Entl OepN (RKB) 8/5/2018 8/5/2018 11.00 MIRU MOVE MOB P Move Rig F/1I08B - T/ 1 H-104 0.0 0.0 09:00 20:00 Rig release F/11 -1-108B at 09:00 Rig accepted on 1 H-104 at 20:00 8/5/2018 6/512018 2.00 MIRU MOVE RURD P Make up surface riser to Diverter 0.0 0.0 20:00 22:00 annular, Obtain RKB Measurements, Take on remaining fluid to pits, Dress shakers. 8/5/2018 8/5/2018 0.50 MIRU MOVE BOPE P Perform surface diverter test, Koomey 0.0 0.0 22:00 22:30 drawdown, Test of H2S, & Gas alarms done Sim -Ops. Tested Gain loss alarms for pits, Flow alrms and trip tank alarm. Witness to test waived by AOGCC Rep Bob Noble. 8/5/2018 8/5/2018 1.00 MIRU MOVE SFTY P Held Pre -Spud Meeting with all 0.0 0.0 22:30 23:30 1 personnel &Table top diverter drill. 8/5/2018 8/6/2018 0.50 MIRU MOVE SHAH P Pick up bit, Motor, crossover and 1 0.0 0.0 23:30 00:00 stand HWDP. Prior to filling surface stack with spud mud. 8/6/2018 8/6/2018 2.00 MIRU MOVE SHAH P Make Up BHAand tag at 95' MD, Fill 0.0 118.0 00:00 02:00 .. lines and hole, Check for leaks. Pressure test mudline to 3,500 psi. Clean out conductor to 118' MD (RKB) 8/6/2018 8/6/2018 1.75 SURFAC7 DRILL DDRL P Drill 13-1/2" Surface interval F/ 118' 118.0 224.0 02:00 03:45 MD - T/ 224' MD 224' TVD. 450 gpm, 480 psi, 28% flow ou1,40 rpm, 2 k. torque,bit wt. 7-8k. Off bottom 400 psi. Up 57k. down 57k. Rot 57k. 1k torque off bottom, Max gas = 0, AST = 0. Art =1.25, Bit hrs. 1.25, Jar hrs. 25.78. 8/6/2018 8/6/2018 2.25 SURFAC DRILL SHAH P Rack back 2 stands HWDP, Make up 224.0 j 224.0 03:45 06:00 remaining BHA. 8/6/2018 8/6/2018 6.00 SURFAC DRILL DDRL P Drill 13-1/2" Surface interval F/ 224' 224.0 606.0 06:00 12:00 MD - T/ 606' MD 605' TVD. 450 gpm, 845 psi, 31 % flow out,60 rpm, 4 k. torque,bit wt. 20k. Off bottom 675 psi. Up 74k. down 79k. Rot 79k. 2k torque off bottom, Max gas = 0, AST = 2.06. Art =1.83, Bit hrs. 3.89, Jar hrs. 29.12. 8/6/2018 8/6/2018 6.00 SURFAC DRILL DDRL P Drill 13-1/2" Surface interval F/606' 606.0 1,148.0 12:00 18:00 MD - T/ 1,148' MD 1,126' TVD. 550 gpm, 1,430 psi, 32% flow out,60 rpm, 5k. torque,bit wt. 30k. Off bottom 1,200 psi. Up 89k. down 89k. Rol 89k. 2k torque off bottom. Max gas = 0, AST = 1.21. Art =2.47, Bit hrs. 7.52, Jar hrs. 32.80. 8/6/2018 8x7/2018 6.00 SURFAC DRILL DDRL P Drill 13-112" Surface interval F/ 1,148' 1,148.0 1,815.0 18:00 00:00 MD - T/ 1,815' MD 1,709' TVD. 550 gpm, 1,520 psi, 36% flow out,60 rpm, 6k. torque,bit wt. 30k. Off bottom 1,286 psi. Up 99k. down 94k. Rot 95k. 2k torque off bottom, Max gas = 7,500 Hydratess at 1,375' MD+/ - AST = 1.75. Art =2.47, Bit hrs. 11.79, Jar hrs. 37.02. Page 1136 Report Printed: 912 412 01 8 a - - Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sien Depth Sian Time End Time Aur (hr) Phase Op Code Activq Code Time P -T -X Operation (ftKB) End Depth (WB) 817/2018 817/2018 0.50 SURFAC DRILL DDRL P Drill 13-1/2" Surface interval F/ 1,815' 1,815.0 1,906.0 00:00 00:30 MD - T/ 1,906' MD 1,783' TVD. 550 gpm, 1,520 psi, 36% flow out,60 rpm, 6k. torque,bit wt. 30k. Off bottom 1,286 psi. Up 99k. down 94k. Rot 95k. 2k torque off bottom, Max gas = 7,500 Hydrates at 1,375' MD+/ - AST = .44. Art =.07, Bit hrs. 12.3, Jar hrs. 37.53. 8/7/2018 8/7/2018 0.25 SURFAC CASING OWFF P Monitor well, static. 1,906.0 1,906.0 00:30 00:45 8/7/2018 8!7/2018 3.50 SURFAC CASING BKRM P BROOH f/ 1906'-863' MD, 550 gpm, 1,906.0 863.0 00:45 04:15 1350-1150 psi, 60 rpm, FO 34%, Tq 2- 4K. BROOH 1st stand pumping a BU. BROOH last 2 stands pumping a BU. 817/2018 8/7/2018 0.25 SURFAC CASING OWFF P Monitor well, static. 863.0 863.0 04:15 04:30 8/7/2018 817/2018 3.00 SURFAC CASING BHAH P Lay down BHA 1 f/ 863'-0' MD as per 863.0 0.0 04:30 07:30 SLB DO. 8/7/2018 8/7/2018 0.50 SURFAC CASING BHAH P Clear & dean rig floor. 0.0 0.0 07:30 08:00 8/7/2018 8/7/2018 1.75 SURFAC CASING RURD P Pick up & rig up GBR casing 0.0 0.0 08:00 09:45 equipment; CRT, link extensions, slips & elevators. SIMOPS download & remove BHA f/ shed, load shoe track & verify pipe count. 8!7/2018 8/7/2018 1.00 SURFAC CASING PUTB P Makeup shoe track to 161' MD, 0.0 161.0 09:45 10:45 Bakerl-ok first 3 connections & torque to 19.41K, install 2 bow spring centralizer 10' from each end on first 2 joints. Fill & check floats, good. 8/7/2018 8/7/2018 5.00 SURFAC CASING PUTS P Continue running 10-3/4", 45.5 #, L- 161.0 1,855.0 10:45 15:45 80, Dopeless Hydril 563 casing f/ 161'- 1855' MD, PU 115K, SO 92K, Tq connections to 19.4K, install bow spring centralizers on each collar. Ran a total of 46 bow spring centralizers & 4 stop collars. 8/712018 8/7/2018 0.50 SURFAC CASING HOSO P Make up hanger & landing joint f/ 1,855.0 1,899.3 15:45 16:15 1855'-1899' MD, washing down at 1 bpm, 120 psi, FO 4%, SO 92K. 8/7/2018 8/7/2018 1.25 SURFAC CEMENT CIRC P Circulate & condition mud for 1,899.3 1,899.3 16:15 17:30 cementing staging up the pump to 7 bpm, 160 psi, FO 20%, PU 119K, SO 108K. 8/7/2018 8/7/2018 0.50 SURFAC CEMENT RURD P Blow down top drive & rig up cement 1,899.3 1,899.3 17:30 18:00 lines to CRT. 8/7/2018 8/7/2018 1.50 SURFAC CEMENT CIRC P Circulate & condition mud for 1,899.3 1,899.3 18:00 19:30 cementing staging up the pump to 7 bpm, 289 psi, FO 20%, PU 119K, SO 108K. SIMOPS PJSM for cementing. Page 2136 ReportPrinted: 912412018 Operations Summary (with Timelog Depths) a IH -104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Tme End Time our(hh Phase Cp Cod. Activity Code Time P -T -X Operabon (0KB) 1,899.3 End DepN(ftKB) 0.0 8/7/2018 8/712018 4.00 SURFAC CEMENT CMNT P Pump 5 bbls of CW100 & PT lines to 19:30 23:30 4000 psi, good. Pump 35 bbls of CW 100 at 4.8 bpm, 120 psi. Pump 80 bbls of 10.5 ppg MPII at 4 bpm, 115 psi. Drop bottom plug. Pump 300.9 bbls of 11.0 ppg Lead cement at 6 bpm, 175 psi. Observed bottom plug bump w/ 179 bbls away. Observed MPII at surface at 265 bbls away. Pump 67 bbls of 12.0 ppg Tail cement at 6 bpm, 270 psi. Drop top plug. Pump 10 bbls of fresh H2O at 5 bpm, 150 psi. Swap to rig & pump 165.1 bbls of 9.5 ppg spud mud to bump plug. Observe good 11.0 ppg cement back w/ 75 bbl mud pumped. Landed on hanger w/ 80 bbls of mud pumped. Pressure up to 784 psi & hold for 5 minutes. Check floats, good. CIP 23:22 hrs. Total of 109 bbls of 11.0 ppg lead cement to surface. 8/7/2018 8/8/2018 0.50 SURFAC CEMENT PRTS P Pressure test 10-314" casing. Pump 0.0 0.0 23:30 00:00 2.9 bbls, pressuring up at 5 spm to 3250 psi. Shut in & observed pressure for 30 minutes ISP 3250 & FSP 3195 psi bled back 2.7 bbls. 8/8/2018 8/8/2018 -3 00 SURFAC CEMENT RURD P Rig down cementing & casing running 0.0 0.0 0000 03:00 equipment. Drain cement from stack & flush w/ black water. Clean out cementing valves. Clean out cellar box. 8/8/2018 8/8/2018 3.00 SURFAC U - MEN P Remove flow riser, disconnect diverter 0.0 0.0 03:00 06:00 line, remove surface annular, diverter tee & starting head. Prep casing hanger for well head. 8/8/2018 8/8/2018 3.00 SURFAC WHDBOP NUND P Pick and set wellhead as per GE Rep. 0.0 0.0 06:00 09:00 Confirm alignment w/ Lounsbury. Nipple up wellhead annulus valves. 8/8/2018 8/8/2018 0.25 SURFAC WHDBOP PRTS P Test seal between casing hanger & 0.0 0.0 09:00 09:15 wellhead to 2000 psi for 10 minutes, witnessed by CPAI Rep. 8/8/2018 8/8/2018 -2 75 SURFAC WHDBOP NUND P Nipple up DSA & spacer spool. Pick 8 0.0 0.0 09:15 12:00 set BOP stack. Torque all flanged connections. Install choke & kill lines. 8/8/2018 8/8/2018 3.75 SURFAC WHDBOP -!TV-RG P Make up potato masher & pup joint. 0.0 0.0 12:00 15:45 Change out annular element. 8/8/2018 8/8/2018 1.25 SURFAC WH RURD P Install test plug, rig up test equipment 0.0 0.0 15:45 17:00 & flood lines. Page 3136 Report Printed: 9/2412 01 8 11. Operations Summary (with Timelog Depths) 0 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth start Time EM Time our (hr) —4 50 Phase SURFAC Op Code WHDBOP A Ity Code BOPE Time P -T -X P Operation Test BOPE w/ 4", 4-1/2", & 7-5/8" test (MB) 0.0 End Depth (flKB) 0.0 8/8/2018 8/8/2016 joints to 250/3500 psi for 5 minutes 17:00 21:30 each charted. Test choke valves 1-14, upper & lower IBOP, 4" & 4-1/2" dart valves, 4" & 4-1/2" FOSV, lower VBR's w/ 4" & 4-1/2" TJ, Blind rams, upper 7- 5/8" rams, annular w/ 4" & 7-5/8" TJ, manual kill & choke valves, HCR kill & choke valves, 2 kill in line Denim valves. Test manual & super choke 250/2000 psi & show bleed down. Accumulator draw down initial system pressure 2900 psi, after functioning 1850 psi, 200 psi recovery in 9 seconds, full in 48 seconds. Nitrogen bottles 6 @ 2000 psi. Tested gas detection system, flow & pit level indicators. Test witnessed waived by AOGCC Rep Brian Bixby. 8/8/2018 8/8/2016 0.50 SURFAC WHDBOP KURD P Remove lest plug &install wear 0.0 0.0 21:30 22:00 bushing. Blow down & rig down test equipment. 8/8/2018 8/8/2018 1.00 SURFAC CEMENT BHAH P Make up BHA 3, 9-718" assembly as 0.0 378.0 22:00 23:00 per SLB DD to 378' MD. 8/8/2018 6/9/2018 1.00 SURFAC CEMENT TRIP P TIH f/ 378'-1706' MD, PU 90K, SO 378.0 1,706.0 23:00 8/9/2018 00:00 8/9/2018 0.25 SURFAC CEMENT CIRC P 79K' Fill pipe & SHT tools, 520 gpm, 800 1,706.0 1,706.0 00:00 8/9/2018 00:15 8/9/2018 1 0.25 SURFAC CEMENT PRTS P St. Line up &test OA valve to 3000 psi for 1,706.0 1,706.0 00:15 00:30 5 minutes, good. Blow down lines. 8/9/2018 8/9/2018 0.50 SURFAC CEMENT TRIP P TIH f/ 1706'-1813' MD, tagging top of 1,706.0 1,813.0 00:30 01:00 plugs on the float collar. 8/912018 8/9/2018 4.00 SURFAC CEMENT DRLG P Drill out shoe track & rat hole f/ 1813'- 1,813.0 1,906.0 01:00 05:00 1906' MD, 450 gpm, 715 psi, 60 rpm, Tq 3-5K, WOB 2-10K, PU 90K, SO 86K, ROT 86K. 8/9/2018 8/9/2018 0.25 SURFAC CEMENT DDRL P DDrill 9-7/8" intermediate section f/ 1,906.0 1,926.0 05:00 05:15 1906'-1926' MD, 1799' TVD, 524 gpm, 926 psi, FO 35%, 80 rpm, Tq 5K, WOB 4K, ECD 10.13, OFF BTM 910 psi, PU 91 K, SO 80K, ROT 87K, Tq 2K, Max gas 0, ADT .17, Bit .17, Jars 97.77, Total footage 20'. 8/9/2018 8/912018 1.25 SURFAC CEMENT CIRC P Pull inside shoe & circulate for FIT at 1,926.0 1,926.0 05:15 06:30 650 gpm, 1337 psi, 50 rpm, Tq 2-4K, MW 9.6 ppg 8/9/2018 8/9/2018 —0 50 SURFAC CEMENT FIT P Rig up & pe form FIT at 1899' MD, 1,926.0 1,926.0 06:30 07:00 1777' TVD to an EMW of 12.0 ppg, w/ 9.6 ppg spud mud. Pump .5 bbl to 230 psi. Shut in & record pressure for 10 minutes ISIP 220 psi, FSIP 180 psi. Bled back .4 bbl. Rig & blow down test equipment. 8/9/2018 8/912018 —5 50 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 1,926.0 2,498.0 07:00 12:00 1926'-2498' MD, 2179' TVD, 650 gpm, 960 psi, FO 33%,160 rpm, Tq 3.5K, WOB 13K, ECD 9.89, OFF BTM 950 psi, PU 94K, SO 84K, ROT 88K, Tq 2K, Max gas 103, ADT 3.12, Bit 3.12, Jars 100.72, Total footage 572'. SCR @ 1968' MD, 1833' TVD, MW 9.0 ppg, 08:05 him #1 @ 30 = 100 psi, @ 40 = 120 psi #2@30=90 psi, @40=110 psi Spill Drill CRT 2:10, 11:00 hrs Page 4136 Report Printed: 912412018 Operations Summary (with Timelog Depths) a 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time 8/9/2018 End Time 8/9/2018 Dur(hr) 6.00 Phase INTRM1 Op Code DRILL Activity Code DDRL Time P -T -X P Operation DDrill 9-7/8" intermediate section f/ (NCB) 2,498.0 End Depth(M) 3,324.0 12:00 18:00 2498'-3324' MD, 2467' TVD, 650 gpm, 1040 psi, FO 32%, 150 rpm, Tq 7K, WOB 15K, ECD 9.87, OFF BTM 1030 psi, PU 105K, SO 73K, ROT 87K, Tq 4K, Max gas 126, ADT 4. 11, Bit 7.23, Jars 104.83, Total footage 826'. 8/9/2018 8/10/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 3,324.0 4,311.0 18:00 00:00 3324'-0311' MD, 2742' TVD, 650 gpm, 1170 psi, FO 32%,170 rpm, Tq 8K, WOB 20K, ECD 10.0, OFF BTM 1162 psi, PU 109K, SO 78K, ROT 92K, Tq 5K, Max gas 35, ADT 4.03, Bit 11.26, Jars 108.86, Total footage 987'. SCR @ 3511' MD, 2516' TVD, MW 9.0+ ppg, 19:05 him #1 @ 30 = 140 psi, @ 40 = 170 psi #2 @ 30 = 130 psi, @ 40 = 160 psi 8/1012018 8110/2018 6.00 INTRMI DRILL DDRL P DDrill 9-71W intermediate section f/ 4,311.0 5,107.0 00:00 06:00 4311'-5107' MD, 2974' TVD, 650 gpm, 1376 psi, FO 32%, 140 rpm, Tq 11 K, WOB 20K, ECD 10.22, OFF BTM 1350 psi, PU 127K, SO 70K, ROT 94K, Tq 7K, Max gas 33, ADT 3.98, Bit 15.24, Jars 112.84, Total footage 796'. 8/10/2018 8/10/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 5,107.0 5,806.0 06:00 12:00 5107'-5806' MD, 3170' TVD, 650 gpm, 1600 psi, FO 32%,140 rpm, Tq 11K, WOB 20K, ECD 10.18, OFF BTM 1580 psi, PU 128K, SO 73K, ROT 96K, Tq 9K, Max gas 33, ADT 3.76, Bit 19.0, Jars 116.6, Total footage 699'. SCR @ 5601' MD, 3113' TVD, MW 9.2 ppg, 10:45 him #1 @ 30 = 200 psi, @ 40 = 220 psi #2 @ 30 = 200 psi, @ 40 = 220 psi 8/10/2018 8110/2018 6.00 INTRM1 DRILL DDRL P DDrill 9-718" intermediate section f/ 5,806.0 6,458.0 12:00 18:00 5806'-6458' MD, 3357' TVD, 650 gpm, 1532 psi, FO 32%, 140 rpm, Tq 1 OK, WOB 15K, ECD 10.06, OFF BTM 1530 psi, PU 130K, SO 77K, ROT 103K, Tq 8K, Max gas 151, ADT 4.16, Bit 23.16, Jars 120.76, Total footage 652'. SCR @ 6553' MD, 3383' TVD, MW 9.1 ppg, 19:15 hrs #1 @ 30 = 240 psi, @ 40 = 280 psi #2 @ 30 = 220 psi, @ 40 = 260 psi 8/10/2018 8/11/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 6,458.0 7,028.0 18:00 00:00 M 6458'-7028' D, 3518' TVD, 650 gpm, 1581 psi, FO 32%,140 rpm, Tq 10K, WOB 15K, ECD 10.27, OFF BTM 1550 psi, PU 147K, SO 81K, ROT 107K, Tq 8K, Max gas 61, ADT 4.21, Bit 27.37, Jars 124.97, Total footage 570'. 8/11/2018 8/11/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 7,028.0 7,556.0 0000 06:00 7028'-7556' MD, 3656' TVD, 650 gpm, 1698 psi, FO 32%, 150 rpm, Tq 11 K, WOB 15-22K, ECD 10.27, OFF BTM 1690 psi, PU 148K, SO 80K, ROT 104K, Tq 9K, Max gas 34, ADT 3.89, Bit 31.27, Jars 128.86, Total footage 530'. Page 5136 Report Printed: 912412018 Summary (with Timelog Depths) IH -104 lipOperations Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Tmie Dur(h) Phase Op Code Activity Code Time P -T -X P Cpembon DDrill 9-7/8" intermediate section f/ (flKB) 7,556.0 End Depth(ftKB) 8,028.0 8/11/2018 8111/2018 6.00 INTRMI DRILL DDRL 7556'-8028' MD, 3769' TVD, 650 gpm, 06:00 12:00 1770 psi, FO 32%,160 rpm, Tq 12K, WOB 20-23K, ECD 10.42, OFF BTM 1732 psi, PU 149K, SO 78K, ROT 1 08K, Tq 6K, Max gas 106, ADT 4.05, Bit 35.31, Jars 132.91, Total footage 530'. Spill Drill CRT 2 min @ 08:00 hrs SCR @ 7598' MD, 3672' TVD, MW 9.1 ppg, 07:00 him #1 @ 30 = 240 psi, @ 40 = 280 psi #2 @ 30 = 240 psi, @ 40 = 280 psi 8/11/2018 8/11/2018 6.00 INTRMI DRILL DDRL P DDrill 9-718" intermediate section f/ 8,028.0 8,360.0 12:00 18:00 8028'-8360' MD, 3828' TVD, 650 gpm, 1764 psi, FO 33%, 150-120 rpm, Tq 12K, WOB 3-22K, ECD 10.37, OFF BTM 1772 psi, PU 150K, SO 70K, ROT 107K, Tq 9K, Max gas 210, ADT 3.58, Bit 38.89, Jars 136.49, Total footage 332'. 8/11/2018 8/12/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 8,360.0 8,605.0 18:00 00:00 8360'-8605' MD, 3885' TVD, 650 gpm, 1836 psi, FO 33%,150-120 rpm, Tq 13K, WOB 3-22K, ECD 10.4, OFF BTM 1800 psi, PU 153K, SO 72K, ROT 112K, Tq 11 K, Max gas 39, ADT 2.92, Bit 41.81, Jars 139.41, Total footage 245'. SCR @ 8549' MD, 3865' TVD, MW 9.0 ppg, 21:30 hrs #1 @ 30 = 280 psi, @ 40 = 320 psi #2 @ 30 = 280 psi, @ 40 = 320 psi 8112/2018 8/12/2018 6.00 INTRMI DRILL DDRL -F— DDrill 9-7/8" intermediate section f/ 8,605.0 9,090.0 00:00 06:00 8605'-9090' MD, 4031' TVD, 650 gpm, 2000 psi, FO 33%,140-120 rpm, Tq 13K, WOB 8-25K, ECD 10.68, OFF BTM 1862 psi, PU 162K, SO 75K, ROT 113K, Tq 11 K, Max gas 29, ADT - 3.69, Bit 45.5, Jars 143.10, Total footage 485'. 8/1212018 8/12/2618 5.50 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 9,090.0 9,514.0 06:00 11:30 9090'-9514' MD, 4100' TVD, 650 gpm, 1942 psi, FO 33%, 150 rpm, Tq 13K, WOB 8-25K, ECD 10.65, OFF BTM 1944 psi, PU 154K, SO 75K, ROT 108K, Tq I OK, Max gas 226, ADT 2.88, Bit 48.38, Jars 145.98, Total footage 424'. Kick w/ Drilling Drill CRT 1:44 @ 08:00 hrs. 8/12/2018 8/12/2018 1.25 INTRM1 CASING CIRC P Circulate CBU at 650 gpm, 1944 psi, 9,514.0 9,414.0 11:30 12:45 FO 33%, 100 rpm, Tq 1OK. Obtain final survey & SCR. SCR @ 9512' MD, 4099' TVD, MW 9.2 ppg, 12:30 him #1 @ 30 = 340 psi, @ 40 = 380 psi #2 @ 30 = 330 psi, @ 40 = 360 psi 8/12/2018 8/12/2018 0.50 INTRMI CASING OWFF P Monitor well, static. 9,414.0 9,414.0 12:45 8/12/2018 13:15 8/12/2018 4.75 INTRMI CASING BKRM P Backream out of hole f/9414'-7792' 9,414.0 7,792.0 13:15 18:00 MD, 700 gpm, 2195 psi, FO 35°�, 120t I rpm, Tq 1OK, ECD 10.85, Max Gas 530 psi, PU w/ reaming 100K. Page 6136 Report Printed: 912 412 01 8 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time End Time Dw(hr) Phase Op Code Aetivlry Code -F- Time P-T-X operation Backream out of hole f/ 7792'-4970' (IH(e) 7,792.0 End Depth (10<8) 4,970.0 8/1212018 8113/2018 6.00 INTRMI CASING BKRM MD, 700 gpm, 1800 psi, FO 35%,120 18:00 00:00 rpm, Tq 9K, ECD 10.82, Max Gas 84 psi, PU w/ reaming 90K. 8/13/2018 8/13/2018 6.75 INTRMI CASING BKRM P Backre m out or n to laying n11 4,970.0 1,890.0 1D2 gpm 00:00 06:45 psi, FO 35%,120-80 rpm, Tq 4K, ECD 10.85, PU w/ reaming 81 K. 6/13/2018 8113/2018 1.25 INTRMI CASING CIRC P Circulate hole dean @ 750 gpm, ICP 1,890.0 1,890.0 1431 psi, FCP 1384 psi, FO 34%, 70 06:45 08:00 rpm, Tq 3K, ECD 9.91, PU 88K, SO 83K, ROT 86K. 8/13/2018 8/13/2018 0.50 INTRMI CASING OWFF P Monitor well, static. 1,890.0 1,890.0 08:00 8/13/2018 08:30 8/13/2018 0.25 INTRMI CASING CIRC P Pump dry job & blow down TD. 1,890.0 1,890.0 08:30 8/1312018 08:45 8113/2018 1.25 INTRMI CASING TRIP P TOH f11890'-378' MD. 1,890.0 378.0 08:45 8/13/2018 10:00 8/13-2018 2.00 INTRM1 CASING BHAH P as per SLB D 378.0 0.0 g t G ode 4 5 B3 1 CT,TD 10:00 8113/2018 12:00 8/13/2018 1.00 INTRM1 CASING BHAH P Clear BHA & clean rig floor. 0.0 0.0 12:00 8113/2018 13:00 8/13-2018 1.00 INTRMI CASING W W WH P Make up stack wash tool & flush stack 0.0 0.0 @ 850 gpm, 150 psi. Lay down tool & 13:00 14:00 make up bushing tool. Remove wear bushing & lay down tools. 8/13/2018 8/1312018 1.00 INTRM1 -CASING KURD P Rig up GBR casing handling 0.0 0.0 14:00 8/13/2018 15:00 8/13/2018 1.00 INTRMI CASING PUTB P equipment. PJSM, make up 7-5/8", 29.7 #, L-80, D.0 174.0 Hydril 563 dopeless casing shoe track 15:00 16:00 to 174' MD, Bakerl-ok connections to pin end of #5, Tq to 14K, floats checked good. 8/13/2018 8/13/2018 3.25 INTRMI CASING PUTB P Continue RIH w/ 7-6/8--,29.7 #, L-80, 174.0 1,899.0 Hyddl 563 dopeless casing shoe 174- 16:00 19:15 1899' MD, connections Tq to 14K, fill pipe on the fly, top off every 10 for displacement, install centralizers installed free floating. 8/13/2018 8/13/2018 0.75 INTRM1 CASING CIRC P Circulate casing volume at the shoe 1,899.0 1,899.0 reciprocating pipe, 3.5 bpm, 100 psi, 19:15 20:00 PU 93K, SO 90K. 8/13/2018 8113/2018 2.50 INTRM1 CASING PUTB P Continue RIH w/ 7-518", 29.7 #, L-80, 1,899.0 3,650.0 Hydril 563 dopeless casing shoe 1899 20:00 22:30 -3650' MD, connections Tq to 14K, fill pipe on the fly, top off every 10 for displacement, install centralizers installed free floating. 8/13/2016 8/13/2018 1.00 INTRMI CASING CIRC P Circulate casing volume, reciprocating pipe, staging pump up to 4.5 bpm, 185 3,650.0 3,650.0 22:30 23:30 psi, PU 118K, SO 95K. 8/13/2018 8114/2018 0.50 INTRM1 CASING PUTB P Continue RIH w/ 7-5/8", 29.7 #, L-80, 3,650.0 4,028.0 Hydril 563 dopeless Casing shoe 23:30 00:00 3650'-4028' MD, connections Tq to 14K, fill pipe on the fly, top off every 10 for displacement, install centralizers installed free floating. 8/14/2018 8/14/2018 3.50 INTRM1 CASING PUTB P Continue to RIH with 7 5/8" 29.7#, L- 4,028.0 6,116.0 80 563 Dopless casing as per detail 00:00 03:30 from 4,028'MD-6,115'MD Fillonfly every 10 and To connections to 14K FT-LB, Page 7136 Report Printed: 912412018 . - Operations Summary (with Timelog Depths) ; 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sten Depth Start Time End Time our (hr) PhaseOp Coda Activity Code TI ne P-T-X Operation (ftKa) End Depth (MS) 8/14/2018 8/14/2018 1.25 INTRMI CASING CIRC P Circulate casing volume while rec from 6,116.0 6,116.0 03:30 04:45 6,116' MD - 6,085' MD. stage pumps to 7 BPM @ 364 PSI UP WT = 152K, DWN WT = 93K. total stks pumped = 2,800. 8/14/2018 8/14/2018 6.00 INTRMI CASING PUTB P Conflnue to RIH with 7 5/8" rasing as 6,116.0 9,461.0 0445 10:45 per detail from 6,115' MD - 9,461' MD. Fill pipe every ten. TQ all connections to 14K. Work past obstruction at 9,320' MD with 4 BPM @ 483 PSI DPP. UP WT=200K. DWN WT= 77K. 8/14/2018 8/14/2018 0.25 INTRM1 CASING HOSO P MU hanger and landing joint. Wash 9,461.0 9,503.0 10:45 11:00 down @ 2 BPM 424 PSI DPP.12% F/0. DWN WT = 65K. 8/14/2018 8/14/2018 3.00 INTRMI CEMENT CIRC P Recip pipe from 9,483'MD - 9,503' 9,503.0 9,503.0 11:00 14:00 MD while staging up pumps to 6 BPM @ 369 PSI DPP. FCP = 454 PSI DPP. 20%F/0 UP WT=200K DWN WT= 77K. pumped 9,961 STKS. . 8114/2018 8/14/2018 4.00 INTRMI CEMENT CMNT P PJSM and RU cement hose PT lines 9,503.0 9,493.2 14:00 18:00 to 4,000 PSI. (PASSED). Reciprocate pipe from 9,503' MD - 9,488' MD. UP WT=211K. DWNWT=101K. PUmp 41.3 BBLS MP II. @ 3 BPM 312 PSI, 12% F/0. Drop BTM Plug pump 250 BBLS of 15.8# class G cement stage up pumps to 6 BPM with ICP 400 SI. FCP 270 PSI. 22% F/0. Drop top plug and chase with 10 BBLS H2O. followed with 9.2 PPG treated LSND @ 7 BPM icp 161 PSI, Obsereve DWN WT to 50K - 10' high. Attempt to free pipe with no success. UP WT = 228K, DWN WT = 98k. continue to pump 7 BPM with FCP 1,265 PSI. teduce rate to 3 BPM @ 4,025 Silks. ICP 1,175 PSI. FCP 1,320 PSI. Bump plug with 422 STKS. CIP @ 1730 hrs. Increase pressure to 1,853 PSI and hold for 5 min. Bleed off and check floats. Holding. 8/14/2018 8/15/2018 6.00 INTRMI CEMENT WOC T WOC. Prep stack for nipple down. 9,493.2 9,493.2 18:00 00:00 BD and remove cement hose. Clean up cementing eqiupment and valves. PU subs and prep for upcomming BHA chnage over. Load and tally 4" DP. 8115/2018 8/15/2018 5.00 INTRMI CEMENT WOC T WOC. Prepare stack for ND. RD 9,493.2 9,493.2 00:00 05:00 Volant / install 150T elevators, flean out cement valves. Load and tally 4" DP. Sim ops clean. 8/15/2018 8/15/2018 1.00 INTRMI CEMENT NUND T Drain stack 1 Break flange to hoist / 9,493.2 9,493.2 05:00 06:00 release air from boots. 8115/2018 8/15/2018 5.00 INTRMI CEMENT RURD T Hoist stack and penetrate 2' above 9,493.2 9,493.2 06:00 11:00 flange for drainage. Clean and prep for emergency slip install. PU to 200K on indicator and install slips as per GE rep.Install Wachs cutter and cut casing as per GE rep. 8/1512018 8/15/2018 1.00 INTRMI CEMENT CUTP T LD landing joint and cut 7 5/8" casing, 9,493.2 9,493.2 11:00 12:00 1 elevators and casing hand slips. 8/15/2016 8/15/2018 1.00 INTRMI CEMENT WWSP P MU41/2" landing joint with X/O, and 9,493.2 0.0 12:00 13:00 packoff running tool. Set 10 3/4" X 7 5/8" Packoff as per GE rep. Page 8/36 Report Printed: 9/24120i-8 Operations Summary (with Timelog Depths) IH -104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth StanTme End Tune Dur(IrQ Pnese Op code Activity Code Time P -T -X Operation (flKB) End Depth (flKB) 0.0 0.0 6/15/2018 8/15/2018 1.00 INTRMI CEMENT NUND P NU BOP stack and change out saver 13:00 14:00 sub to 4" XT39 dimops. 8/15/2018 8/15/2018 0.50 INTRMI CEMENT PRTS P Witness packoff test to 3,832 PSI for 0.0 0.0 14:00 14:30 10 min / (PASSED). 8/15/2018 8/15/2018 0.50 INTRMI CEMENT RURD P Install wear bushing of 9" plus run in 0.0 D.0 14:30 15:00 LDS X2 8/15/2018 8/15/2018 1.75 INTRMI CEMENT BHAH P PJSM for PU 6 3/4" BHA #3 as per 0.0 336.0 15:00 16:45 SLB rep.to 336' MD UP WT = 51 K DWN WT=57K. Sim -ops with LRS for FP of 10 3/4" X 7 5/8" ann with 100 BBLS fresh 180 BBLS diesel. Pressure break over at 900 PSI. Average rate of 3 BPM 7-800 PSI. 8/15/2018 8/16/2018 7.25 INTRMI CEMENT TRIP P Trip in hole with 4" DP from 336MD 336.0 7,788.0 16:45 00:00 to 7,788' MD. UP WT = 145K DWN WT = 62K. Monitor disp via TT. 8/16/2018 8/16/2018 2.00 TN ENTI CEM TRIP P Continue to RI with 6 314" BHA on 4" 7,788.0 9,300.0 00:00 02:00 DP from 7,778' MD - 9,300' MD. UP WT = 162K, DWN WT = 60K Monitor disp via TT. 8116/2018 8/16/2018 0.75 INTRMI CEMENT PRTS P Rig up to pressure test 7 5/8" casing. 9,300.0 9,300.0 02:00 02:45 Pump 6 BBLS to achieve 3,680 PSI hold and chart for 30 min. Lost 5 PSI iin 30 min. (PASSED). bleed off total - 6.2 BBLS. 8/16/2018 8/16/2018 3.00 INTRMI CEMENT DRLG P Ream down and drill out shoe track 9,300.0 9,514.0 02:45 05:45 assym. 220 GPM @ 1,170 PSI. 50 RPM 9K TQ. UP WT = 155K, DWN WT = 53K. 1 O RT. lop of plug found at 9,397.5' MD. 8/16/2018 6/16/2018 0.25 INTRMI CEMENT DDRL P Drill 6 3/4" hole m 9,5220 9'514.0 9,534.0 05:45 06:00 9,534- MD 4,086' GPM @ 1,660 PSI, 18% F/O, 80 RPM 11 K TQ, 8K WOB, OB 1,600 PSI. UP WT = 155K, DWN WT = 53K. ROT 102K, 91K TQ, Max gas units 0. ADT .16, Bk hm .16, Jar HRS 43 8/16/2016 8/16/2018 1.00 INTRMI CEMENT CIRC P and circulate rom 9.534.0 9,534.0 06:00 07:00 g 450' MD. 240 GPMRotate @ 19 5b PSD 16% F/O, 40 RPM 11 K TQ, UP QT = 170K, DWN WT= 52K, ROT 102K, pumped 2,872 STKS. 8/1612018 6/16/2018 1.25 INTRMI CEMENT FIT P STD back stnd 97, RU for FIT / @ 9,534.0 9,534.0 07:00 08:15 4,091' TVD. 13.1 EMW achieved at 16 STKS pumped 800 PSI with 9.3 PPG test mud 6/1612019 8116/2018 0.25 PRODI DRILL RURD P RD test equient. pm 9,534.0 9,534.0 08:15 8/16/2018 08:30 8/16/2018 0.50 PROD1 DRILL SVRG P Grease top drive / PM / service saver 9,534.0 9,534.0 08:30 09:00 and air slips. S16/2018 6/16/2018 1.25 PROD1 DRILL DISP P Swap hole over to 9.2 PPG Flo -Pro, 9,534.0 9,534.0 09:00 10:15 pump 20 BBL high vis sweep 250 GPM @ 1,940 PSI. 17% F/0. 40 RPM IOK TQ. ECD 10.76. 1,683 FCP. UP WT= 134K DWN WT= 85K. Page 9/36 Report Printed: 912 412 01 8 ` Operations Summary (with Timelog Depths) i 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start OepN Start Time End Time Dur(hr) Phase op Code ANvity Code Time P -T -x Operation (RKB) End Depth(ftKS) 8/16/2018 811612018 7.75 PROD1 DRILL DDRL P Drill 6 3/4" hole from 9,534' MD 4,086' 9,534.0 10,112.0 10:15 18:00 TVD- 10,112' MD 4,097' TVD. 260 GPM @ 1,811 PSI, 19% F/0, 130 RPM 7K TQ, 3K WOB, OB 1,808 PSI. UP WT = 137K, DWN WT = 75K. ROT 103K, 6K TO, Max gas units 86. ADT 5.37, Bit hrs 6.8, Jar HRS 48.37 SPR's 9,532' MD 4,087' TVD MW = 9.2 PPG HR 10:15 MP -1) 20 SPM -420 PSI 30 SPM -580 PSI MP -2) 20 SPM -420 PSI 30 SPM -580 PSI 8/16/2018 8/17/2018 6.00 PROD? DRILL DDRL P Drill 3/4" hole from 10,112' MD 10,112.0 10,605.0 18:00 00:00 4,097' TVD - 10,605' MD 4,095 TVD. 260 GPM @ 1,815 PSI, 19% 1`/0, 130 RPM 8K TQ, 2-51KWOB, OB 1,810 PSI. UP WT=139K, DWN WT=71 K. ROT 101 K, 6K TQ, Max gas units 63. ADT 4. 10, Bit him 9.63, Jar HRS 52.47 SPR's 10,589" MD 4,095' TVD MW = 9.2 PPG HR 20:30 MP -1) 20 SPM -510 PSI 30 SPM -710 PSI MP -2) 20 SPM -550 PSI 30 SPM -790 PSI 8/1712018 8/17/2018 6.00 PROD1 DRILL DDRL P Drill 6 3/4" hole from 10,605' MD 10,605.0 11,226.0 00:00 06:00 4,095 TVD - 11,226' MD 4,052' TVD. 260 GPM @ 2,175 PSI, 19% F/0, 130 RPM 10K TQ, 2-71K WOB, ECD = 11.96 OB 2,150 PSI. UP WT = 139K, DWN WT=66K. ROT 99K, 8K TQ, Max gas units 8. ADT 4.21, Bit hrs 13.84, Jar HRS 56.68 8/17/2018 8117/2018 1.50 PROD1 DRILL BKRM T BKRM from 11,226' MD- 10,879' MD. 11,226.0 10,879.0 06:00 07:30 250 GPM @ 2,027 PSI DPP. 18% F/O, 80 RPM, 6K TO. UP WT = 139K, DWN WT = 66K, ROT = 99 8/17/2018 8/17/2018 0.50 PROD1 DRILL PMPO T Pump OOH from 10879' MD- 10780' 10,879.0 10,780.0 07:30 08:00 MD at 250 GPM 1,925 PSI DPP, 8/17/2018 8/172018 4.00 PROD1 DRILL KOST T Open hole side track. Work string 10,780.0 10,860.0 08:00 12:00 from 10,830' MD - 10,860 1,910 PSI 18% F/O, 150 RPM, 8K TQ, UP WT w/pump = 99K. DWN = 95K. 8!1712018 8117/2078 2.00 PROD1 DRILL KOST T Open Hole side track as per DD. 10,860.0 10,860.0 12:00 14:00 Working string from 10,830' MD - 10,860' MD. 250 GPM @ 1,910 PSI DPP. 18% FIO, 150 RPM @ 8K TO. UP / DNW WT with pumps on 99K/95K. 8/17/2018 8/18/2018 10.00 PROD1 DRILL KOST T Open Hole side track as per DD. 10,860.0 10,874.0 14:00 00:00 Working string from 10,860' MD - 10,874' MD. 250 GPM @ 1,829 PSI DPP. 19% F/0, 150 RPM @ 91K TQ. UP / DNW WT with pumps on 99K/95K. 8/18/2018 8/18/2018 6.00 PROD1 DRILL KOST T Continue to perform open hole 10,874.0 10,969.0 00:00 06:00 sidetrack time driling form 10,874' MD - 10,969' MD 250 GPM @ 1,875 PSI, 18% F/0, 150 RPM, 81K TQ, UP WT = 129K, DWN WT = 78K. ROT = 100K, Max gas = 14 Page 10136 Report Printed: 9/2412018 Operations Summary (with Timelog Depths) a 1H-104 Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log start Depth Start Time End Time Dhr(hr) Phase Op Code Activity Code Time P-T-X T Operation Drill 6 314" hole for/ 10,969' MD - (ftKB) 10,969.0 End Depth(ftKB) 11,227.0 8118!2018 8/18/2018 3.00 PROD1 DRILL DDRL 11,227' MD 4,104' TVD. @ 248 GPM, 06:00 09:00 2,051 PSI, 18% NO, 125 RPM, 9.5K TO. 3.5K WOB, ECD = 11.07, OB = 2,048 PSI, UP WT = 129K, OWN WT = 78K, ROT = 100K, 9K TO, Max gas = 340, ADT 6.44, Bit Inns 31 .1, Jar furs 73.94. 8/18/2018 8/18/2018 2.00 PROD1 DRILL OWFF T Observe well for Flow. Observe rise in 11,227.0 11,277.0 0900 11:00 fluid at rotary table. SI well and monitor pressure. ISIDPP = 25 PSI, ISICP = 20 PSI Pbsewe [ressure rise to 200 PSI SIDPP, 180 PSI SICP. Increase of 4BBLS to pits. -9/716/21)18 8/18/2018 2.50 PROD1 DRILL KLWL 7 Circulate well around using drillers 11,277.0 11,277.0 method @ 3BPM, 1,080 PSI DPP 11:00 13:30 Casing pressure peaked at 650 PSI during circulation with gas to surface. Pumped a total of 4,569 STKS. Rotated pipe for one min to ensure free. Talk with production folks and have them shut in 1H-News injection support. Talk with KRU operations about postponing bridge closure until well stabilized. Order out more KCL from MI. 8/18/2018 8/18/2018 4.00 PRODt DRILL OWFF T Shut down pumps and SI casing to 11,277.0 11,227.0 13:30 17:30 monitor pressures and WT UP pits to new KWF based off new calcs. Maintain 200 PSI on Casing pressure. WT UP pits to 9.7 PPG with new calculations proving a 10.2 PPG needed. Went with 9.7 PPG for first circulation so crews could keep up with 30 SEC SX at 9.7. 8/18/2018 8/18/2018 2.75 PROD1 DRILL KLWL T Pump 9.7 PPG mud utilizing kill sheet 11,227.0 11,277.0 1730 20:15 pump schedule. ICP = 1,016 PSI, FCP = 1,036 PSI. Maintain 200 PSI Casing pressure. Total stks pumped = 5,515. 8118/2018 8/18/2018 —0 75 PROD1 DRILL OWFF T Sl and monitor pressure while 11,277.0 11,277.0 20:15 21:00 weighing up to 10.2 PPG KWF in surface pits. SIDPP = 380 PSI, SICP = 240 PSI. Rotate for 1 min with 9K TO to break over and 5-8K TO stable. 8118/2018 -F1 19/201-8 —3 00 PROD1 -GRI —LL KLWL T Pump 10.2 PPG MW utilizing kill sheet --Tl—,277.0 11,277.0 (drillers method), pump schedule. ICP 21:00 00:00 = 970 PSI. CP = 919 PSI. Pump 5,605 STKS. MW in = 10.2 MW out = 10.1+. Rotate pipe at 10 RPM broke over at 8K TO. 8/19/2018 8/19/2018 0.50 PROOt DRILL KLWL T 6,623 STKS pumped. MW in/out 10.2 11,277.0 11,277.0 PPG. Rotate pipe 10 RPM with 13K 00:00 00:30 to break over - 8K TO 8/19/2018 8/1912018 0.75 PROD1 DRILL KLWL T Monitor pressure via choke and --TI—,2770 11,277.0 00:30 01:15 confirm zero pressure. Open arm and monitor hole. 8/19/2018 8/19/20182.25 PROO1 Circulate up 2X BU at 250 GPM, 80 11,2770 11,277.0 RPM I ECD = 12.24 PPG, UP WT = 01:15 03:30 ::-ffR-1LL-(f-1—RC7— 127K OWN WT = 85K. rot 102K. Page 11136 ReportPrinted: 912412018 ., Operations Summary (with Timelog Depths) I 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time Entl Time our (hr) —o Phase Op Code Activity Code (5WFF Tme P-T-X T Operation Monitor well for flow /blowdown (fiKB) 11,277.0 Entl OepO(%KB) 11,277.0 8/1912018 8/19/2018 50 PROD1 DRILL choke I kill lines. Grease wash pipe. 03:30 04:00 SPR's 11,255' MD 4,104' TVD, MW = 10.2 Time 0415 hrs MP 1) 20 SPM 570 PSI 30 SPM 780 PSI MP 2) 20 SPM 540 PSI 30 SPM 720 PSI 8/19/2018 8/19/2018 —2 00 PR0D1 DRILL DDRL P Drill 3/4" hole from 11,277' MD - 11 277.0 11 445.0 0400 06:00 11,445 MD @ 250 GPM , 2,090 PDI 19% F/O, 130 RPM 10K TO, 5K WOB, ECD's 12.1 PPG. OB 2,056 PSI UP WT = 137 DWN WT = 68K, ROI: = 99K, 9K TO, Max gas 43 units 8/19/2018 8/19/2018 —6 00 -FR-OD —1 DRILL DDRL P DDRL 6 3/4" hole from 11,445' MD - 11,445.0 11,965.0 06:00 12:00 11,965' MD 4,043' TVD 250 GPM @ 2,161 PSI DPP, 20% F/O, 150 RPM 10K TO, ECD's = 12.34, OFF BTTM = 2,150 PSI, UP WT = 150K, DWN WT = 52K, ROT 102K, 1 OK TO, Max gas = 227 units, ADT 5.07, Bit hrs 36.17, Jar hrs 79.07 8/19/2018 8/19/2018 6.00 PROD1 DRILL DDRL P DDRL 6 3/4" hole from 1,965' MD 11,965.0 12,605.0 1200 18:00 4,043' TVD - 12,605' MD 4,018 TVD 260 GPM @ 2,179 PSI DPP, 21% FIG, 140 RPM 10K TQ, 1K WOB ECU's = 12.3, OFF BTTM = 2,150 PSI, UP WT = 146K, DWN WT = K, ROT 102K, 10K TO, Max gas = 2817 units, ADT 4.05, Bit hrs 40.22, Jar hrs 83.12 8/19/2018 8/20/2018 6.00 PROD1 DRILL DDRL P DDRL 6 3/4" hole from 12,605' MD 12,605.0 13,064.0 1800 00:00 4,018 TVD - 13,064' MD 4,012' TVD 260 GPM @ 2,292 PSI DPP, 20% F/O, 140 RPM 1 OK TO, 5K WOB ECD's = 12.37, OFF BTTM = 2,281 PSI, UP WT = 160K, DWN WT = K, ROT 104K, 1 OK TO, Max gas = 7780 units, ADT 3.37, Bit hrs 43.80, Jar hrs 86.7 SPR's 12,684" MD 4,015' TVD MW = 10.2 PPG FR 1841 MP-1) 20 SPM-530 PSI 30 SPM-730 PSI MP-2) 20 SPM-490 PSI 30 SPM-690 PSI 8/20/2018 8/20/2018 6.00 PROD1 DRILL DDRL P DDRL 6 3/4" hole from 13,064' MD ---T3,064.0 13,812.0 0000 06:00 4,012' TVD - 13,812 MD 3,994' TVD 260 GPM @ 2,478 PSI DPP, 20% F/O, 140 RPM 10.7K TO, 5.5K WOB ECD's = 12.71, OFF BTTM = 2,495 PSI, UP WT = 172K, DWN WT = K, ROT 106K, 10K TO, Max gas = 235 units, ADT 3.85, Bit hrs 47.65, Jar hrs 90.55 Page 12136 Report Printed: 912412018 Operations Summary (with Timelog Depths) ,r 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth StartTime End Time Our (hr) Phase Op Code Actively Code Time P -T -X Operation (VS) End Depth (Wa) 8/20/2018 8/20/2018 6.00 PROD1 DRILL DDRL P DDRL 6 3/4" hole from 13,812 MD 13,812.0 14,454.0 06:00 12:00 3,994' TVD - 14,464' MD 4,084 TVD 260 GPM @ 2,840 PSI DPP, 19% F/O, 140 RPM 10K TQ, 5K WOB ECD's = 12.92, OFF BTTM = 2,816 PSI, UP WT= 183K, DWN WT= K, ROT 118K, 10.5K TQ, Max gas = 235 units, ADT 3.65, Bit hrs 51.3, Jar hrs 94.2 SPR's 13,900" MD 4,084' TVD MW = 10.1+ PPG HR 0615 MP -1) 20 SPM -700 PSI 30 SPM -890 PSI MP -2) 20 SPM -710 PSI 30 SPM -900 PSI 8/20/2018 8/20/2018 6.00 PROD1 DRILL DDRL P DDRL 63/4" hole from 14,454'MD 14,454.0 14,940.0 12:00 18:00 4,084 TVD - 14,940 MD 4,040' TVD 260 GPM @ 2,690 PSI DPP, 20% F/O, 150 RPM 10K TQ, 3K WOB ECD's = 12.75, OFF BTTM = 2,670 PSI, UP WT = 185K, DWN WT = K, ROT 122K, 1 OK TO, Max gas = 235 units, ADT 3.9, Bit hrs 55.2, Jar hrs 98.1 8/20/2018 8/21/2018 6.00 PROD1 DRILL DDRL P DDRL 6 3/4" hole from 14,940 MD 14,940.0 15,191.0 1800 00:00 4,040' TVD - 15,191' MD 4,031' TVD 260 GPM @ 2,794 PSI DPP, 20% F/O, 140 RPM 10.5K TQ, 2.7K WOB ECD's = 12.84, OFF BTTM = 2,791 PSI, UP WT = 189K, DWN WT = K, ROT 122K, 10.7K TO, Max gas = 235 units, ADT 3.3, Bit hrs 58.5, Jar hrs 101.4 SPR's 14,917" MD 4,037' TVD MW = 10.2 PPG HR 1909 MP -1) 20 SPM -620 PSI 30 SPM -690 PSI MP -2) 20 SPM -640 PSI 30 SPM -680 PSI 8/21/2018 8/21/2018 6.00 PROD1 DRILL DDRL P DDRL 6 3/4" hole from 15,191' MD 15,191.0 15,648.0 00:00 06:00 4,031' TVD - 15,648' MD 4,029' TVD 250 GPM @ 2,605 PSI DPP, 19% F/O, 140 RPM 10.6K TQ, 2K WOB ECD's = 12.83, OFF BTTM = 2,578 PSI, UP WT = 195K, DWN WT = K, ROT 126K, 1 O TO, Max gas = 78 units, ADT 4.44, Bit hrs 62.94, Jar hrs 105.84 8/21/2018 8/21/2018 4.75 PRODt DRILL DDRL P DDRL 6 3/4" hole from 16,648' MO 15,648.0 16,014.0 06:00 10:45 4,029' TVD - 16,014" MD 4,022' TVD 250-230 GPM @ 2,525 PSI DPP, 19% F/O, 140 RPM 1 O TQ, 2-7K WOB ECD's = 12.87, OFF BTTM = 2,520 PSI, UP WT= 180K, DWN WT= K, ROT 127K, 10K TO, Max gas = 95 units, ADT 3.9, Bit hrs 66.84, Jar hrs 109.74 8/21/2018 8/21/2018 3.25 PROD1 CASING CIRC P Circulate and condition mud. Rotate 16,014.0 15,922.0 10:45 14:00 and reciprocate from 16,014' MD to 15,922' MD. 230 gpm, 2589 psi, 17% FO, 140 rpm, 8K tq, ECD=12.95 UP WT=175K , DWN WT = K, ROT 126K. Page 13/36 ReportPrinted: 912412018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Tune End Tme Our he) Phase Op Code Activity Code Time P -T-% Operation (ftKS) End Depth MKBI 8/21/2018 8/21/2018 1.00 PROD1 CASING OWFF P Monitorwell. Slight flow at.29 bph 15,922.0 15,922.0 14:00 15:00 diminishing to .14 bph. 8/21/2018 8/21/2018 3.00 PROD1 CASING BKRM P BROOH from 15,922' MD to 14,821' 15,922.0 14,821.0 15:00 18:00 MD. 240 gpm, 2738 psi, 18% FO, 140 rpm, 8K tq, ECD=12.87. 8/21/2018 8/22/2016 6.00 PROD1 CASING BKRM P Continue to BROOH from 14,921' MID 14,821.0 12,774.0 18:00 00:00 to 12,774' MD. 240 gpm, 2274 psi, 16% FO, 140 rpm, 7.5K tq, ECD=12.57. OA=100 psi. 8!22/2018 812212018 6.00 PROD1 SING Continue to BROOH from 12,774' MD 12,774.0 10,763.0 00:00 06:00 to 10,763' MD. 240 gpm, 2095 psi, 18% FO, 140 rpm, 7K tq, ECD=12.21. 8122!2018 8/2212018 3.00 PROD1 ASING lc/) P Continue to BROOH from 10,763' MD 10,763.0 9,445.0 06:00 09:00 to 9,445' MD. 240 gpm, 2002 psi, 18% FO, 140 rpm, 7K tq, ECD=11.89. 8/22/2018 8/22/2018 3.00 PROD1 SING JKRP P Circulate andcondition mud. Rotate 9,445.0 9,445.0 09:00 12:00 and reciprocate from 9,445'MD to 9,357' MD, 220 gpm, 1738 psi, 15% FO, 80 rpm, 5K tq, ECD=11.80, UP WT=120K S/OWT=88K ROT WT=97K. OA=95 psi 30 bbls loss previous 12 hrs. 8/22/2018 8/22/2018 2.75 PROD1 CASING P Circulate and condition mud. Perform 9,445.0 9,445.0 12:00 14:45 80% mud dilution. Rotate and reciprocate from 9,445' MD to 9,357' MD, 200 gpm, 1320 psi, 15% FO, 80 rpm, 4K tq, UP WT=120K SIO Wr=88K ROT WT=97K. 8/22/2018 8/22/2018 0.75 PROD1 CASING OWFF P Monitor well. Slight flow at 1.19 bph 9,445.0 9,450.0 14:45 15:30 diminishing to .28 bph. 8/2212018 0.50 PROD1 CASING PMPO P Pump OOH from 9,450' MD to 9,262' 9,450.0 9,262.0 15:30 MD at 85 to 65 gpm with 415 psi. 7% FO 8/22/2018 0.75 PROD1 CASING OWFF P Monitor well. Slight flow at.27 bph 9,262.0 9,262.0 16:00 E8/22J20 diminishing to .13 bph.8/22/2018 1.00 PROD1 CASING MPSP P Make up and set Baker TST-3 92620 0.0 16:45 retrievable packer. COE at 97.10'MD. UPWT=125K SO WT=80K 8/22/2018 0.75 PROD1 CASING WWWH P Make up stack washing tool. Flush 0.0 0.0 17:45 18:30 BOPE with 900 gpm, 167 psi, 42% FO and 30 rpm. 8/2212018 8/22/2018 0.50 PROD1 CASING MPSP P Test storm packer to 700 psill0 mins 0.0 0.0 18:30 19:00 as per Baker Rep. 8/22/2018 8/2212018 1.50 PRODt CASING BOPE P Set test plug and change out upper 0.0 0.0 19:00 20:30 pipe rams to 3 1/2" x 6" VBR's. 8/22/2018 - 8/22/2018 1.50 PROD1 WHDBOP RURD P Rig up to test BOPE. Purge air from 0.0 0.0 20:30 22:00 system and perform shell test. Page 14136 ReportPrinted: 9/24/2016 Operations Summary (with Timelog Depths) 11-1-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time LOB Smit Depot Stmt Time End Time our (h* Phase Op Cade AafPoily Cade Time P -T -X Operation (ftKB) 0.0 End Depth (tiKB) 0.0 8/22!2018 8/2312018 2.00 PRODII WHDBOP BOPE P Perform bi-weekly BOPE test. 22:00 00:00 250/3500 psi- 5 min each. Following tests done with 4 1/2" lest joint. Test #1-Annular,CV's 1,12,13,14,4" kill Demco, 4" dart valve. Test #2 -Upper 3 1/2" x 6" VBR, CV's 9,11, mezzanine kill line valve, 4" FOSV. Test #3 -CV's 8,10, kill HCR. Test #4- CV's 6,7, manual kill line valve. OA=0 psi. 8/23/2018 8/23/2018 3.00 PRODII WHDBOP BOPE P Continue bi-weekly BOPE test. Test 0.0 0.0 00:00 03:00 #5- Super choke and manual choke at 250/2000 psi. Test #6- CV's 2,5. Test #7- Lower 3 1/2" x 6" VBR. Test #8 - Blind rams, CV's 3,4,6. Following tests done with 4" test joint. Test #9 - Annular, upper IBOP, choke line HCR. Test #10- Upper 31/2"x6"VBR, lower IBOP. Test #11- Lower 3 1/2" x 6" VBR. Accumulator draw down initial system pressure 2900 psi, after functioning 1800 psi, 200 psi recovery in 10 seconds, full in 48 seconds. Nitrogen bottles 6 Qa 2025 psi. Tested gas detection system, flow & pit level indicators. Test witness waived by AOGCC Rep Lou Laubenstein. 8/23/2018 8/23/2018 0.75 PRODt WHDBOP RURD P Rig down test equipment. Set 9" ID 0.0 0.0 03:00 03:45 wear ring. 8123/2018 8123/2018 1.00 PROD1 CASING MPSP P Make up packer retrieval tool. Engage 0.0 9,262.0 03:45 04:45 packer and monitor for pressure up DP. Close annular preventer and release packer. Monitor for pressure through choke. 0 pressure, 0 flow. POOH and lay down storm packer. 8/23/2018 8/23/2018 3.25 PRODII CASING CIRC P CBU x2. Rotate and reciprocate from 9,262.0 9,262.0 04:45 08:00 9,260' MD to 9,167' MD. 200 gpm, 1296 psi, 18% FO, 80 rpm, 5K tq, UP=125K, SO=80K, Rot=100K. 8/23/2018 8/23/2018F3.75 PROD1 CASING OWFF P Monitor well. Slight diminishing flow. 9,262.0 9,262.0 08:00 08:15 8/23/2018 8/23/2018 PROD1 ZASI WN T-M-PO P Pump OOH from 9262' MD to 6,590' 9,262.0 6,590.0 08:15 12:00 MD. 200 gpm, 1250 psi, 18% FO, UP=117K OA=45 psi 8/23/2018 8/23/2018 5.00 PRODII CASING PMPO P Continue to Pump OOH Nom 6,590' 6,590.0 3,088.0 12:00 17:00 MD to 3,088' MD. 200 gpm, 786 psi, 18% FO, UP=83K. 8/23/2018 8/23/2018 0.25 PRODt CASING CIRC P CBU. 200 gpm, 786 psi, 18% FO. 3,088.0 3,088.0 17:00 17:15 8/23/2018 8/23/2018 1.25 PROD1 CASING OWFF P Monitor well. Well flowing al t bph 3,088.0 3,088.0 17:15 18:30 diminishing to .178 bph. 6/23/2018 8/23/2018 0.75 PROD1 CASING PMPO P Continue to Pump OOH from 3,088' 3,088.0 2,684.0 18:30 19:15 MD to 2,684' MD. 150 gpm, 530 psi, 13% FO, UP=80K. 8/23/2018 8/23/2018 4.00 PROD1 CASING PMPO P Continue to Pump OOH from 2,684' 2,684.0 336.0 19:15 23:15 MD to 336' MD. 84 gpm, 252 psi, 10% FO, UP=79K. 8/23/2018 8/24/2018 0.75 PROD1 CASING OWFF P Blow down TD. Monitor well. Slight 336.0 336.0 23:15 00:00 1 flow at .66 bph diminishing to .27 bph. 6/24/2018 8/24/2018 0.25 PRODt CASING OWFF P Continue to monitor well. Slight How 336.0 336.0 00:00 00:15 at .27 bph diminishing to .21 bph. Page 15136 ReportPrinted: 912412016 Operations Summary (with Timelog Depchs) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log seen Daum Stan Time End Time Dur (hn Plisse Op Cmtle I Advity C°tle Time P -T -X Operation (N(8) Entl Depen IPKB) 8/2412018 8/24/2018 1.25 PRODt CASING BHAH P Stand back and lay down BHA as per 336.0 0.0 00:15 01:30 SLB DD. 6/24/2018 8/24/2018 0.50 PROD1 CASING BHAH P Clean and clear rig Floor. 0.0 0.0 01:30 02:00 8/24/2018 8/24/2018 1.00 COMPZ1 CASING KURD P Rig up to run 4 1/2" slotted liner. Verify 0.0 0.0 02:00 03:00 joint count in pipe shed. 8/24!2018 8/24/2018 9.00 COMPZI CASING PUTB P Pick up and RIH with L-80 12.6# 0.0 5,290.0 03:00 12:00 IBT/SLHT slotted liner as per detail to 5290' MD. PU=84K S0=69K 8/24/2018 8124/2018 4.25 COMPZ1 CASING PUTB P Continue to pick up and RIH with L-80 5,290.0 7,491.0 12:00 16:15 12.6# IBT/SLHT slotted liner as per detail from 5290' MD to 7491' MD. PU=96K SO=72K 8/24/2018 8/24/2018 1.25 COMPZI CASING OTHR P Pick up Baker liner hanger/packer 7,491.0 7,562.0 16:15 17:30 assembly. Mix and pour pal mix. Verify pin settings. 8124/2018 812412018 0.25 COMPZ7 CASING CIRC P Pick up one stand of DP. Break 7,562.0 7,562.0 17:30 17:45 circulation staging pump up to 3 bpm, 186 psi, 71 °� FO. PU=99K 50=75K 8/2412018 8/24/2018 1.25 COMPZI CASING RUNL P RIH with 4 112" slotted liner on 4" DP 7,562.0 9,461.0 17:45 19:00 from 7562' MD to 9461' MD. Drop 2" drift on each stand. 8/24/2018 8124/2018 0.25 COMPZ11 CASING CIRC P Break circulation. Stage pump up to 4 9,461.0 9,461.0 19:00 19:15 bpm, 347 psi, 12% FO, PU=114K SO=79K 8/24/2018 8/25/2018 4.75 COMPZ1 CASING RUNL P Continue to RIH with 4 1/2" slotted 9,461.0 15,378.0 19:15 00:00 liner on 4" DP from 9461' MD to 15378' MD. Drop 2" drift on each stand. Work through tight hole at 10765' MD. PU=173K SO=79K OA=O psi. 8/25/2018 1812512018 0.75 COMPZ1 CASING RUNL P Continue to RIH with 4 1/2" slotted 15,378.0 16,019.0 00:00 00:45 liner on 4" DP from 15378' MD to 16019' MD. Drop 2" drift on each stand. PU=179K SO=85K. Tag TD at 89' in on stand #90 (16910' MD) 812512018 8125/2018 0.50 COMPZI CASING CIRC P Circulate DP volume of 80 bbls, 4 16,019.0 15,994.0 00:45 01:15 bpm, 875 psi, 14% FO. Space out to liner set depth. Observe PU increase to 225K without breakover and SO to block weight without breakover. 8/25/2018 8/25/2018 1.25 COMPZ7 CASING PACK P Drop 1.625" setting ball and pump 15,994.0 8,445.0 01:15 02:30 down at 3 bpm, 600 psi.Reduce rete to 1.5 bpm, 420 psi at 55 bbls. Ball on seal at 618 strokes. Pressure up to 1700 psi to set hanger. Slack off to block weight. Increase pressure to 2500 psi and hold for 5 min. Increase pressure to 4100 psi and hold for 3 min to set and release packer. TOL at 8445' MD. PU=147K SO=104K after release. 8/25/2018 8125/2018 0.50 COMPZI CASING PRTS P Test ZXP liner top packer to 3500 8,445.0 8,445.0 02:30 03:00 psi/10 mins on chart. Good test. 8125/2018 8/25/2018 0.75 COMPZt WELLPR CRIH P P/U 12' out of RS packoft nipple and 8,445.0 8,445.0 03:00 03:45 spot 20 bbls of 10.4 ppg Cl brine to above 1-1 Whipstock @ 8335' MD, Pump @3 bpm= 690 psi w/ 14% FO, displace out of drill pipe with 760 strokes. Page 16136 ReportPrinted: 9/2412018 - Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sean Depth Start Time I End Time Durilen Phase Op Code I Activity Code Time P -T -X Operation MKB) End Depth (01110). 8125/2018 8/25/2018 0.50 COMPZ1 WELLPR OWFF PMonitorwell. Dropped in riser 9". 8,445.0 8,445.0 03:45 04:15 8/2512018 825/2018 0.50 COMPZ1 WELLPR TRIP P POOH to 8330' MD. 8,445.0 8,330.0 04:15 04:45 825/2018 8/252018 2.00 COMPZ1 WELLPR SLPC P Slip and cut 77'drilling line. 8,330.0 8,330.0 04:45 06:45 8/25/2018 0.75 COMPZ1 WELLPR TRIP P POOH from 8330' MD to 8053' MD. 8,330.0 8,053.0 07:30 PU=140K. 8/25/2018 2.50 COMPZ1 WELLPR PMPO P Pump OOH due to swabbing from 8,053.0 6,030.0 10:00 8053' MD to 6030' MD. 1.5 bpm, 200 r8/25/2018 psi. PU=100K 8/25/2018 3.25 COMPZ1 WELLPR TRIP P POOH from 6030' MD to 57' MD. 6,030.0 57.0 13:15 8/25/2018 0.50 COMPZ1 WELLPR SHAHLay down running tools as per Baker 57.0 0.0 13:45 Rep. 8125/2018 8/25/2018 0.50 PROD2 WHPST BHAH P Mobilize whipstock tools to rig floor 0.0 0.0 13:45 14:15 and prep for BHA PU. 8/252018 8/25/2018 2.00 PROD2 WHPST BHAH P Make up whipstock BHA as per Baker 0.0 110.0 14:15 16:15 Rep. 8125/2018 8/25/2018 2.25 PROD2 WHPST BHAH P Change out x -o, float sub, 1 jt HWDP 110.0 267.0 16:15 18:30 and MWD x -o due to observed deflection in BHA. MWD pin x pin x -o was source of deflection. Continue to make up BHAt0 267' MD. 8/25/2018 8/25/2018 1.00 PROD2 WHPST TRIP P RIH with whipstock BHAfrom 267' MDr8,257.0 1,682.0 18:30 19:30 to 1682' MD. PU=72K 80=72K 825/2018 8/25/2018 -0 25 PROD2 WHPST DHEQ P Shallow pulse test MWD. 250 gpm, 1,682.0 19:30 19:45 1030 psi, 19% FO. 8252018 8/2612018 4.25 PROD2 WHPST TRIP P Continue to RIH with whipstock BHA 8,257.0 19:45 00:00 from 1682' MD to 8257" MD. Fill pipe every 20 stands. PU=147K SO=109K 8/26/2018 8/26/2018 0.75 PROD2 WHPST WPST P Orient tool face to 19"LOHS, pumping 8,334.8 00:00 00:45 @ 250 gpm, 1890 psi, PU 137K, SO 102K. Wash in hole maintaining 19` LOHS. Tag liner top @ 8445' MD, set 10k down, PU IOk over, set down 25k over, & observe pin shear. 8126/2018 8/26/2018 5.25 PROD2 WHPST MILL P Mill 63/4" window from 8334.75'MD 8,334.8 8,347.1 00:45 06:00 to 8347.11' MD. 257 gpm, 1650 psi, 19% FO, 80 rpm, 3-7K tq. 1 K WOB. Pump hi -vis super sweep at 8341' MD. SCR @ 8326' MD, 3822' TVD, MW 10.4 ppg, 03:30 hrs #1 @ 20 = 540 psi, @ 30 = 660 psi #2 @ 20 = 560 psi, @ 30 = 700 psi 8/26/2018 8/2612018 2.50 PROD2 WHPST MILL P Continue to mill 6 3/4" window and 8' 8,347.1 8,373.0 06:00 08:30 guage hole from 6347' MD to 8373' MD. 257 gpm, 1650 to 2500 psi, 19% FO, 80 rpm, 3-5K till, 5-1 OK WOB. Pressure increase came after - pumping super sweep. TOL at 8441.91' MD TOW at 8334.75' MD BOW at 8348.34' MD. OA=250 psi @ 0700 hrs. 8262018 8/26/2018 1.75 PROD2 WHPST REAM P Pump hi -vis super sweep. Work mills 8,373.0 8,330.0 08:30 10:15 through window. Ream up & down @ same drilling rales x3. Work mills through window w/ no pumps or rotary x2. 1.5K drag up and down. Pump on PU= 1331k, SO = 104k. Pump off PU=147K SO=111K Page 17136 Report Printed: 912 412 01 8 Operations Summary (with Timelog Depths) AN: , 'h - 1W 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth start Time End Time our (hd Phase or, Code Activity Code Time P -T -X P Operation POOH on elevators from 8330' MD to (flKB) 8,330.0 End Depth (19(11) 8,144.0 8-2612018 8/26/2018 0.25 PROD2 WHPST TRIP 8144' MD. PU=146K SO=110K 10:15 8126/2018 10:30 8-26/2018 1.00 PROD2 WHPST FIT P Rig up and perform FIT to 585 8,144.0 8,144.0 psi/13.3 EMW. Pumped .7 bbis. Bled 10:30 11:30 back .4 bbls. Blow down and rig down test equipment. 8/26/2018 8/26/2018 0.50 PR0D2 WHPST TRIP P POOH on elevators from 8144' MD to 8,144.0 7,688.0 11:30 12:00 7688' MD. PU=140K SO=105K. 8/26/2018 8/26/2018 0.50 PROD2 WHPST CIRC P Pump 20 bbl 11.5 ppg dry job. Blow 7,688.0 7,688.0 12:00 12:30 down TD. 8/2612018 6/26/2018 3.00 PROD2 W-HPST TRIP P POOH on elevators form 7688' MD to 7,688.0 157.0 12:30 15:30 157' MD. 8/26/2018 8/26/2018 1.00 PROD2 WHPST SHAH P Lay down milling BHA as per Baker 157.0 0.0 15:30 8/26/2018 16:30 8/26/2018 0.50 PROD2 WHPST SHAH P Rep. Clean and clear dg floor. Drain BOPE. 0.0 0.0 16:30 17:00 Pull marring. 8-26/2018 8/26/2018 1.00 PROD2 WHPST WWWH P Makeup stack washing tool. Flush 0.0 0.0 BOPE at 853 gpm, Lay down tool. Set 17:00 18:00 9" ID weardng. OA= 0 psi. 8/26!2018 8/26/2016 0.50 PROD2 WHPST -!TV-RG P Service top drive and blocks 0.0 0.0 18:00 8126/2018 18:30 8126/2018 1.00 PROD2 WHPST BHAH P MU up motor/clean out assembly per 0.0 631.0 18:30 19:30 SLB to 631' MD. 8/26/2018 8-26/2018 0.50 FR WHPST TRIP P RIH wl clean out BHA on 4" DP from 631.0 1,765.0 19:30 20:00 derrick from 631' MD to 1765' MD. PU=69K, SO=69K. Monitor displacement via trip tank. 8/26/2018 8/2 0.25 PROD2 WHPST D HEQ6/2018 P Shallow hole test MWD. 250 gpm, 1,765.0 1,765.0 20:00 20:15 1315 psi, 19% FO. 8/2612018 8/2612018 2.75 TROD2 TRIP P Continue to RIH wl clean out BHA on 1,765.0 8,135.0 20:15 23:00 4" DP from derrick from 1765' MD to 8135' MD. PU=122K, SO=84K. Monitor displacement via trip tank. Fill pipe every 20 stands. 8/26/2018 0.25 PROD2 WHPST TRIP P Orient motor to 22'LOHS. Trip down 8,135.0 8,372.0 23:00 23:15 though window from 8334.75' MD to 18/26/2018 8348.34' MD, no issues. Tag bottom @ 8372' MD and set down 5K. 8/26/2018 8/2712018 0.75 PROD2 DRILL DDRL P Drill 6 3/4" hole from 8373' MD l0 8,372.0 8,460.0 23:15 00:00 8460' MD 3827' TVD. 250 GPM @ 1970 PSI, 19% F/O, 40 RPM 5K TO, 11KWOB, OB182OPSI. UPWT= 124K,DWNWT=85K. ROT95K, 8K TQ, Max gas units 0. ADT .45, ASR .09 Bit hm .45, Jar HRS 110.13 SCR @ 8367' MD, 3822' TVD, MW 10.4 ppg, 23:15 him #1 @ 20 = 630 psi, @ 30 = 820 psi #2 @ 20 = 620 psi, @ 30 = 820 psi Losses for tour -11.6 bbis Page 18/36 Report Printed: 912 412 01 8 Operations Summary (with Timeiog Depths) IH-104 Rig: DOYON 742 Job: DRILLING ORIGINAL Time Log start Dept, start Time End Time our (no Phase Op Code Activity Code Tim- P-T-X P operation Drill 6 3/4" hole from 8460' MD 3827' (in) 8,460.0 End Depth (tiKB) 8,476.0 8/27/2018 8127/2018 0.25 PROD2 DRILL DDRL TVD to 8476' MD 3839' TVD. 250 00:00 00:15 GPM @ 1990 PSI, 19% FIO, 40 RPM 5K TQ, 6K WOB, OB 1830 PSI. UP WT=125K, OWN WT=86K. ROT 95K, 4.51K TQ, Max gas units 0. ADT .11, AST 0 Bit hm .56, Jar HRS 110.24 8/27/2018 8/27/2018 1.00 PR0D2 DRILL CIRC P CBU while rotating and reciprocating 8,476.0 8,476.0 from 8476' MD to 8416' MD. 250 gpm, 00:15 01:15 1920 psi, 19% FO, 40 rpm, 4.5K tq, MW 10.4 ppg. Orient to 10' LOHS. 8127/2018 8/27,2018 0.25 PROD2 DRILL TRIP 'P7-- POOH from 8476' MD to 8321' MD. 8,476.0 8,321.0 No drag observed pulling though 01:15 01:30 Window. 8/27/2018 8/2712018 0.50 PROD2 DRILL OWFF P Monitor well. Static. 8,321.0 8,321.0 01:30 8/27/2018 02:00 8/27/2018 3.25 PROD2 DRILL TRIP P POOH from 8321' MD to 631' MD. 8,321.0 631.0 Monitor displacement via trip tank. 02:00 8127/2018 05:15 8/27/2018 1.50 PROD2 DRILL BHAH P BHA.s Lay 631.0 0.0 and standMonitorell back clean outat BHA #6 sn 05:15 06:45 per DD. Monitor displacement via trip tank. 8/27/2018 8127/2018 0.75 PROD2 URILL P Clean and clear dg floor. Drain BOPE. 0.0 0.0 06:45 07:30 Pull weaning. Make up stack washer. 8127/2018 8/27/2018 0 PROD2 DRILL W WH W.75 P Function all rams and annular 0.0 0.0 preventer. Flush BOPE with 854 gpm 07:30 08:15 x2. Install 9" ID wearing. Blow down TD. 8/27/2018 8/27/2018 0.50 PROD2 DRILL SVRGP Service and inspect top drive and 0.0 0.0 08:15 8/27/2018 08:45 8/2712018 1.25 PROD2 DRILL BHAH P blocks. Make up RSS BHA #7 as per DD to 0.0 336.0 336' MD. Monitor displacement via trip 08:45 10:00 tank. 8/27/2018 8/2712018 0.50 PROD2 DRILL TRIP P RIH with 4" DP from 336' MD to 1750' 336.0 1,750.0 MD. Monitor displacement via trip 10:00 10:30 tank. 8127/2018 8/2712018 0.50 PROD2 DRILL DHEA P Shallow hole test MWD. Stage pump 1,750.0 1,750.0 up to 241 gpm, 1100 psi, 17% FO. 10:30 8127,2018 11:00 8/27/2018 2.75 PROD2 DRILL TRIP P RIH with 4" DP from 1750' MD to 1,750.0 8,405.0 8405' MD. Fill pipe every 25 stands. 11:00 13:45 Monitor displacement via trip tank. PU=122K SO=82K 8/27/2018 8127/2018 1.00 PR052 DRILL DLOG P MAD from Wash down 1847o 8,405.0 6,476.0 8405' MD to 6' MD. 240 gpms1712 13:45 14:45 psi, 19% FO. Send downlink. Displace to new 10.2 ppg FloPro mud. 8/27/2018 8/27/2018 3.25 PROD2 DRILL DDRL P Drill 6 314" hole from 8476' MD 3839' 8,476.0 8,800.0 TVD to 8800' MD 3826' ND. 250 14:45 18:00 GPM @ 1835 PSI, 19% F/O, 150 RPM 7K TQ, 3K WOB, OB 1830 PSI. UP WT= 116K, DWN WT= 81 K. ROT 93K, 4K TO, Max gas units 20. ADT 2.63, Bit his 2.63, Jar HRS 112.87 SCR @ 8596' MD, 3828' ND, MW 10-2+ ppg, 15:50 hrs #1 @ 20 = 490 psi, @ 30 = 680 psi #2 @ 20 = 480 psi, @ 30 = 680 psi Page 19136 ReportPrinted: 912412018 Operations Summary (with Timelog Depths) -_ 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activit' Code DDRL Time P -T -X P Opeabon Drill 6 314" hole from 8800' MD 3826' (ftKB) 8,800.0 End Dept(ftKB) 9,720.0 8/2712018 8/28/2018 6.00 PROD2 DRILL TVD to 9720' MD3878' TVD. 250 18:00 00:00 GPM @ 1940 PSI, 19°% F/0, 140 RPM 8K TO, 5K WOB, ECD=12.19 OB 1940 PSI. UP WT=123K, DWN WT=81 K. ROT 96K, 4K TQ, Max gas units 1400. ADT 4.19, Bit hrs 6.82, Jar HRS 117.06 SCR @ 8880' MD, 3841' ND, MW 10.3 ppg, 18:30 hrs #1 @ 30 = 510 psi, @ 40 = 690 psi #2 @ 30 = 480 psi, @ 40 = 680 psi OA=305 psi 8/28/2018 8/28/2018 6.00 PROD2 DRILL DDRL P Drill 6 3/4" hole from 9720' MD 3878 9,720.0 10,408.0 00:00 06:00 TVD to 10408' MD3893' TVD. 250 GPM @ 2065 PSI, 19% F/O, 140 RPM 8.5K TO, 8K WOB, ECD=12.56 OB 2050 PSI. UP WT= 128K, DWN WT = 73K. ROT 95K, 8K TO, Max gas units . ADT 3.92, Bit hrs 10.74, Jar HRS 120.98 8/28/2018 8/28/2018 6.00 PROD2 DRILL DDRL P Drill 3/4" hole from 10408' MD3893 10,408.0 11,004.0 06:00 12:00 TVD to 11004' MD 3959' TVD. 250 GPM @ 2220 PSI, 19% F/0, 140 RPM 8.7K TO, 10.5K WOB, ECD=12.33 OB 2215 PSI. UP WT = 129K, DWN WT = 81 K. ROT 99K, 7.2K TO, Max gas units 139. ADT 4.55, Bit hrs 15.29, Jar HRS 125.53 SCR @ 10495' MD, 3902' TVD, MW 10.3+ ppg, 06:38 hrs #1 @ 30 = 500 psi, @ 40 = 720 psi #2 @ 30 = 480 psi, @ 40 = 700 psi OA=310 psi 8/28/2018 8/28/2018 6.00 PROD2 DRILL DDRL P Drill 6 3/4" hole from 11004' MD 3959' 11,004.0 11,339.0 1200 18:00 TVD to 11 339'MD 3972' TVD. 260 GPM @ 2380 PSI, 19% F/0, 160 RPM, 8.5K TQ, 5K WOB, ECD=12.23, OB 2370 PSI. UP WT= 132K, DWN WT = 81 K. ROT 98K, 6K TO, Max gas units 195. ADT 4.16, Bit hrs 19.45, Jar HRS 129.69 8/28/2018 8/29/2018 6.00 PROD2 DRILL DDRL P Drill 6 3/4" hole from 11339' MD 3972' 11,339.0 11,979.0 1800 00:00 TVD to 11979' MD 3930' TVD. 260 GPM @ 2430 PSI, 19% F/0, 150 RPM, 7.7K TQ, 4K WOB, ECD=12.5, OB 2420 PSI. UP WT = 132K, DWN WT = 67K. ROT 97K, 8K TQ, Max gas units 180. ADT 4.19, Bit hrs 23.64, Jar HRS 133.88 SCR @ 11350' MD, 3967' TVD, MW 10.2+ ppg, 18:13 hrs #1 @ 30 = 500 psi, @ 40 = 730 psi #2 @ 30 = 490 psi, @ 40 = 720 psi OA=165 psi Page 20/36 ReportPrinted: 9/2412016 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth StenTim End Time Dur(hr) 6.00 Phase PROD2 Activity Code DDRL Time P -T -X P Operation Directional drill 6 3/4" L1 hole f/ (ftKB) 11,979.0 EM Depth MKS) 12,445.0 8/29/2018 00:00 8129/2018 06:00 11979'- 12445' MD, 3901' TVD, 260 gpm, 2350 psi, FO 19%, 150 rpm, Tq 8.4K, WOB 5K, ECD 12.59, OB 2345 rDR psi, PU 133K, SO 66K. ROT 96K, 8K TO, Max gas 190, ADT 4.03, Bit 27.67, Jars 137.91 8/29/2018 8/29/2018 6.00 PROD2 DDRL P Directional drill 6 3/4" L1 hole fl 12,445.0 12,946.0 06:00 12:00 12445'- 12946' MD, 3895' TVD, 260 gpm, 2400 psi, FO 19%,150 rpm, Tq 8.5K, WOB 3K, ECD 12.46, off btm 2400 psi, PU 137K, SO 67K, ROT 96K, Tq 8.5K, Max gas 251, ADT 4.28, Bit 31.95, Jars 142.19 SCR @ 12491' MD, 3899' TVD, MW 10.3 ppg, 06:36 hrs #1 @ 30 = 530 psi, @ 40 = 730 psi #2 @ 30 = 530 psi, @ 40 = 730 psi OA 280 psi 8/29/2016 8/29/2018 6.00 PROD2 DRILL DDRL P Directional drill 6 314" L1 hole f/ 12,946.0 13,444.0 12:00 18:00 12946' - 13444' MD, 3913' TVD, 260 gpm, 2515 psi, FO 20%,150 rpm, Tq 8.7K, WOB 4.2K. ECD 12.74, off btm 2490 psi, PU 141K, SO 60K, ROT 94K, Tq 8.5K, Max gas 230, ADT 4.27, Bit 36.22, Jars 146.46 8/29/2018 8/29/2018 4.50 PROD2 DRILL - DDRL P Directional drill 6 3/4" L1 hole f/ 13,444.0 13,900.0 18:00 22:30 13444'- 13900' MD, 3962' TVD, 260 gpm, 2767 psi, FO 16%,150 rpm, Tq 8.3K, WOB 5K, ECD 12.54, off btm 2660 psi, PU 146K, SO 60K, ROT 96K, Tq 8K, Max gas 20, ADT 3.4, Bit 39.62, Jars 149.86 Observed losses of initial rate of 30 bph at 13715' MD. 8/2018 /29 8/29/2018 1.00 PROD2 DRILL OWFF T Monitor well with 5 rpm & Tq 8K, 13,900.0 13,900.0 22:30 23:30 perform well bore breathing test taking returns to the trip tank. Observe flow decrease from initial flow of 1 bpm to 0.2 bpm over 43 minutes. Total volume back 25 bbls. 8/29/2018 8/30/2018 0.50 PROD2 DRILL DDRL P Directional drill 6 3/4" L1 hole ff 13,900.0 13,944.0 23:30 00:00 13900'- 13944' MD, 3965' TVD, 260 gpm, 2515 psi, FO 16%,150 rpm, Tq 8.3K, WOB 2K, ECD 12.36, off btm 2510 psi, PU 146K, SO 60K, ROT 96K, Tq 8K, Max gas 23, ADT .34, Bit 39.96, Jars 150.2 Observed loss rate increase to 90 bph. 8/30/2018 8/30/2018 6.00 PROD2 DRILL DDRL P Directional drill 6 3/4" L1 hole f/ 13,944.0 14,379.0 00:00 06:00 - 13944'- 14379' MD, 3950' TVD, 250 gpm, 2430 psi, FO 17%,150 rpm, Tq 9K, WOB 3K, ECD 12.41, off btm 2428 psi, PU 150K, SO 65K, ROT 109K, Tq 9K, Max gas 40, ADT 4.62, Bit 44.58, Jars 154.82 Observed loss rate - 100 bph. Page 21136 ReportPrinted: 912 412 01 8 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Slant Depth Start Time End Time Der (hr) Phase Op Code Activity Code DDRL Time P-T-X P Operation Directional drill 6 3/4" Lt hole f/ (flKB) 14,379.0 End Depth htKB) 14,546.0 8/30/2018 8/30/2018 2.00 PROD2 DRILL 0600 08:00 14379'- 14546' MD, 3940' TVD, 250 gpm, 2575 psi, FO 17%,120 rpm, Tq 8.51K, WOB 1.51K, ECD 12.42, off btm 2570 psi, PU 150K, SO 65K, ROT 116K, Tq 9K, Max gas 30, ADT 1.72, Bit 46.3, Jars 156.54 Observed loss rate — 100-80 bph. SCR @ 14452' MD, 3945' TVD, MW 10.2+ ppg, 06:45 hrs #1 @ 20 = 530 psi, @ 30 = 730 psi #2 @ 20 = 530 psi, @ 30 = 730 psi OA 230 psi 8/30/2018 8/30/2018 0.75 PR0D2 DRILL CIRC T Pump 40 bbls LCM pill at 250 gpm, 14,546.0 14,546.0 0800 08:45 2640 psi, FO 16%,120 rpm, Tq 7.5K. Reduce pump rate to 170 gpm, 1425 psi as pill was pumped across the suspected loss zone. 8/30/2018 8/30/2018 3.25 PROD2 DRILL —LTD—RL P Directional drill 6 3/4" L1 hole f/ 14,546.0 14,679.0 0845 12:00 14546'- 14679' MD, 3932' TVD, 240 gpm, 2420 psi, FO 17%,120 rpm, Tq 8K, WOB 3K, ECD 12.4, off btm 2400 psi, PU 152K, SO N/A, ROT 116K, Tq 9K, Max gas 61, ADT 2.65, Bit 48.95, Jars 159.19 Observed loss rate — 80-60 bph. 8/30/2018 030/2018 6.00 PROD2 DRILL DDRL P Directional drill 3/4" Li hole f/ 14,679.0 14,925.0 12:00 18:00 14679'- 14925' MD, 3929' ND, 240 gpm, 2460 psi, FO 16%, 120 rpm, Tq 8.8K, WOB 6K, ECD 12.48, off btm 2455 psi, PU 163K, SO N/A, ROT 109K, Tq 9K, Max gas 67, ADT 4.74, Bit 53.69, Jars 163.93 Observed loss rate — 40 bph. 8/30/2018 8/31/2018 6.00 PROD2 DRILL DDRL P Directional drill 6 314" L1 hole fl 14,925.0 15,371.0 1800 00:00 14925'- 15371' MD, 3928' TVD, 245 gpm, 2607 psi, FO 18%, 120 rpm, Tq 8.5K, WOB 4K, ECD 12.54, off btm 2600 psi, PU 165K, SO N/A, ROT 106K, Tq 7.7K, Max gas 35, ADT 4.94, Bit 58.63, Jars 168.87 Observed loss rale — 40 bph. SCR @ 15004' MD, 3928' TVD, MW 10.1+ ppg, 19:10 hrs #1 @ 20 = 820 psi, @ 30 = 1040 psi #2 @ 20 = 860 psi, @ 30 = 1080 psi OA 195 psi 8/31/2018 8/31/2018 6.00 PROD2 DRILL DDRL P Directional drill 6 3/4" L1 hole fl 15,371.0 15,737.0 00:00 06:00 15371'- 15737' MD, 3910' ND, 245 gpm, 2740 psi, FO 17%,120 rpm, Tq 8.6K, WOB 4K, ECD 12.61, off btm 2735 psi, PU 169K, SO N/A, ROT 124K, Tq 8K, Max gas 35, ADT 5.09, Bit 63.72, Jars 173.96 Observed loss rate — 25 bph. Page 22136 ReportPrinted: 9124/2018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Capin Start Time End Time Dur (h) Phase Op Code Activity Code Time P -T -X Operation ("a) End Dep�h (ftKB) 8/31/2018 8/31/2018 5.50 PROD2 DRILL DDRL P Directional drill 6 3/4" L1 hole f/ 15,737.0 15,972.0 06:00 11:30 15737'- 15972' MD, 3900' TVD, 250 gpm, 2910 psi, FO 18%,120 rpm, Tq 8.5K, WOB 5K. ECD 12.65, off btm 2900 psi, PU 169K, SO N/A, ROT 124K, Tq 8.5K, Max gas 375, ADT 4.18, Bit 67.90, Jars 178.14 Observed loss rate - 20 bph. SCR @ 15737' MD, 3810' TVD, MW 10.0+ ppg, 06:00 hrs #1 @ 20 = 880 psi, @ 30 = 1100 psi #2 @ 20 = 800 psi, @ 30 = 1060 psi OA 75 psi 8/31/2018 8/31/2018 2.00 PROD2 CASING CIRC P Obtain final survey & CBU at 25U 15,972.0 15,972.0 11:30 13:30 gpm, 2930 psi, FO 17,120 rpm, Tq 8K, ECD 12.61, PU 165K, SO N/A, ROT 123K. SCR @ 15972' MD, 3900' ND, MW 10.0+ ppg, 13:30 hrs #1 @ 20 = 890 psi, @ 30 = 1120 psi #2 @ 20 = 900 psi, @ 30 = 1120 psi 8131/2018 8/31/2018 2.00 PROD2 CASING OWFF P Monitor well, observing flow decrease 15,972.0 15,972.0 13:30 15:30 from 135 bph to 1.2 bph. PU 175K, SO 68K. 8131/2018 9/1/2018 8.50 PROD2 CASING BKRM P BROOH f/ 15972'-12872' MD, 240 15,972.0 12,872.0 15:30 00:00 gpm, 1990 psi, FO 13%, ECD 11.72, 120 rpm, Tq 7K, PU 134K, SO 65K. 9/1/2018 9/1/2018 6.00 PROD2 CASING BKRM P BROOH f/ 12872'-10700' MD, 241 12,872.0 10,700.0 00:00 06:00 gpm, 1950 psi, FO 13%, ECD 11.8, 120 rpm, Tq 6.5K, PU 134K, SO 70K. 9/112018 9/1/2018 5.00 PROD CASING BKRM P BROOH f/ 10700'-8694' MD, 241 gpm, 10,700.0 8,694.0 06:00 11:00 1836 psi, FO 16%, ECD 11.63, 120 rpm, Tq 4.5K, PU 114K, SO 81K. 9/112018 9/1/2018 PROD2 CASING PMPO P Pump out of the hole pulling the BHA 8,694.0 8,314.0 11:00 12:00 thru the window V 8694'-8314' MD, 1 bpm, 330 psi, FO 4%. 911/2018 9/1/2018 PROD2 CASING CIRC P Circulate casing clean & raise MW to 8,314.0 8,314.0 12:00 14:15 10.4 ppg, 241 gpm, 1886 psi, FO 17%, ECD 11.89,100-120 rpm, Tq 4K. 9/1/2018 9/1/2018 r2.25 PROD2 CASING OWFF P Monitor well, observe wellbore 8,314.0 8,314.0 14:15 16:15 breathing to static hole conditions. Measure flow back to trip tank & record reducing rate. 9/1/2018 9/1/2018 PROD2 CASING PMPO P Pump out of the hole f/ 8314'-6320' 8,314.0 6,320.0 16:15 18:00 MD, 50 gpm, 260 psi, FO 12%, PU 103K, SO 84K. 9/1/2018 9/1/2018 2.75 PROD2 CASING TRIP P TOH f/ 6320'-336' MD. 6,320.0 336.0 18:00 20:45 9/1/2018 9/1/2018 0.25 PROD2 CASING OWFF P Monitor well, observe fluid level drop 336.0 336.0 20:45 21:00 4" in the riser. 9/1/2018 9/1/2018 1.00 PROD2 CASING BHAH P Lay down BHA 7, Gear & clean rig 336.0 0.0 21:00 22:00 floor. 9/1/2018 9/1/2018 1.50 COMPZ2 FISH BHAH P Pick up BHA 8, 7-5/8" Whipstock 0.0 248.0 22:00 23:30 1 retrieval assembly to 248.43'. Offset 110.62 9/1/2018 9/2/2018 0.50 COMPZ2 FISH TRIP P TIH w/ BHAB f/ 248'-1292' MD, PU 248.0 1,292.0 23:30 00:00 62', SO 55K. 9/212018 9/212018 2.75 COMPZ2 FISH TRIP P TIH w/ BHA 8 f/ 1292'-8287' MD, PU 1,292.0 8,287.0 00:00 02:45 113K, SO 79K. 9/2/2018 912/2018 1.00 COMPZ2 FISH CIRC P CBU at 230 gpm, 1600 psi, PU 108K, 8,287.0 8,287.0 02:45 03:45 SO 80K. Page 23136 ReportPrinted: 912412018 Ago., Operations Summary (with Timelog DeNths) IH -104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth Start Time End Time Dur (hp Phase Op Cede Activity Code Time P -T -X Operation (NCB) End Depth (flKB) 9/2/2018 9/2/2018 0.25 COMPZ2 FISH FISH P Wash in hole & orient tool face to 160 8,287.0 8,325.0 03:45 04:00 R & wash out whipstock slot 210 gpm, 1300 psi. Pick up above slide & orient to 20 L. Slack off & engage hook to slot at 8340' MD, w/ 5K. Pull to 170K & observe anchor release. Pull whipstock assembly past window to 8325' MD, PU 110K. 9/2/2018 9/2/2018 1.50 COMPZ2 FISH CIRC P CBU two times at 280 gpm, 1651 psi. 8,325.0 8,325.0 04:00 05:30 9/2/2018 9/2/2018 1.00 COMPZ2 FISH OWFF P Monitor well, with breathing. Observe 8,325.0 8,325.0 05:30 06:30 return flow reduce to .15 BPH. 912/2018 9/2/2018 3.75 COMPZ2 FISH PMPO P Pump out of hole due to swabbing f/ 8,325.0 5,386.0 06:30 10:15 8325'-5386' MD, 58 gpm, 160 psi, FO 2%, PU 95K. 9/2/2018 9/2/2018 2.75 COMPZ2 FISH TRIP P TOH with whipstock assembly f/ 5,386.0 353.0 10:15 13:00 5386'-353' MD, PU 53K. 912/2018 9/2/2018 0.25 COMPZ2 FISH OWFF P Monitor well, static 353.0 353.0 13:00 13:15 9/2/2018 9/2/2018 2.50 COMPZ2 FISH BHAH P Rack back HWDP & lay down 353.0 0.0 13:15 15:45 whipstock assembly as per BOT Rep. Clear & clean dg floor. 9/2/2018 9/2/2018 1.00 COMPZ2 CASING RURD P Mobilize & rig up 4-1/2" handling 0.0 0.0 15:45 16:45 equipment, verify pipe count. 9/2/2018 912!2018 0.25 COMPZ2 CASING SFTY P PJSM with all personnel involved in 0.0 0.0 16:45 17:00 running 4-112" lower completion. 2018 9/3/2018 7.00 COMPZ2 CASING PUTS P Make up 4-1/2", 12.6#, L-80, TXP / 0.0 4,784.0 00:00 IBTM as per detail to 4784'MD, PU 79K, SO 69K. Bakerl-ok first 2 connections, TXP torque to 7K Mbs. IBTM connections made up to the [17:00 mark. Each joint centralized w/ 6-1/8" Volant Hyrdroform. 18 9/312018 3.50 COMPZ2 CASING PUTB P Make up 4-1/2", 12.6#, L-80, TXP / 4,784.0 7,580.0 00 03:30 IBTM as per detail f/ 4784'-7580' MD, PU 95K, SO 75K. TXP torque to 7K fl/Ibs. IBTM connections made up to the mark. Each joint centralized w/ 6- 1/8" Volant Hyrdroform. Last 2 joints not centralized. 9/312016 9/3/2018 COMPZ2 CASING OTHR P Make up hook hanger assembly as 7,580.0 7,613.0 03:30 05:00 per BOT Rep. Make up & install slim pulse assembly as per SLB MWD. Verify offset 156.26. 913/2018 9/3/2018 E-60- COMPZ2 CASING CIRC P Circulate staging up to 2 bpm, 320 psi, 7,613.0 7,613.0 05:00 05:30 FO 10%, blow down TO. SIMOPS Change out handling equipment to TIH w/ 4" DP. 9/312018 913/2018 MPZ2 CASING RUNL P TIH w/ 4-1/2" lower completion on 4" 7,613.0 10,450.0 05:30 07:45 DP, drifting stands from derrick f/ 7613'-10450' MD, PU 112K, SO 76K. At the window PU 98K, SO 74K. 9/3/2018 91312018 3.00 COMPZ2 CASING DHEQ T Test slim pulse tool at various rates 10,450.0 10,450.0 07:45 10:45 staging up to 180 gpm, 954 psi, FO 17%. Increase in pressure f/ 950 to 1300 psi at 2430 strokes pumped. Unable to pump over 80 gpm without exceeding 1300 psi max. No detection. Confer w/ town & decide to TOH & change out slim pulse. 9/3/2018 191312018 0.50 COMP72 CASING OWFF T Monitor well, static. 10,450.0 10,450.0 10:45 11:15 1 9/3/2018 913/2018 1.75 COMPZ2 CASING TRIP T TOH f/ 10450'-7577' MD, PU 98K, SO 10,450.0 7,577.0 11:15 13:00 1 1 74K. Page 24/36 Report Printed: 912412018 Operations Summary (with Timelog Dep(hs) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Slah Depth me End Time Dur(hr) Phase Op Code Atl yCode Time P-T-X OpemfiDn (ftKa) End Depth (10<13). 9/3/2018 3.50 COMPZ2 CASING SHAH T Break out hook hanger assembly & 7,577.0 7,613.0 16:30 inspect. Change out slim pulse MWD. Test tools at 2 bpm, 290 psi, FO 11 %. f17:30 9/3/2018 0.50 COMPZ2 CASING TRIP T TIH f/ 7613'-8278' MD, PU 100K, SO 7,613.0 8,278.0 17:00 74K. 9/3/2018 0.50 COMPZ2 CASING SRW T Shallow hole test slim pulse tools2 8,278.0 8,278.0 17:30 bpm, 312 psi, FO 11 %, good. 9/3/2018 1.00 COMPZ2 CASINGRUNL T TIH w/ 4-112" lower completion on 4" 8,278.0 8,450.0 18:30 DP, 8278'-8460' MD, nogo out at 8460' MD. Pick up & rotate 90° right & attempt to enter window. Repeat process 3 times to enter L1. 9/312018 9/3/2018 1.00 COMPZ2 CASING RUNL T TIH w/ 4-1/2" lower completion on 4" 8,450.0 10,450.0 18:30 19:30 1 1 DP, f/ 8450'-10450' MD. 9/3/2018 9/4/2018 4.50 COMPZ2 CASING RUNL P TIH w/4-112" lower completion on 4" 10,450.0 15,882.0 19:30 00:00 DP, drifting stands from derrick f/ 10450'-15882' MD, PU 165K, SO 76K. 9/4/2018 9/4/2018 1.75 COMPZ2 CASING HOSO P Orient tool face to 160'R at 120 gprh, 15,882.0 15,943.0 00:00 01:45 1030 psi & wash down to 15935' MD setting down w/ 7K, string turned to 173°R (appear to be on the hook). Pick up & re-orient string to 20°L and drift thm to 15943' MD. Pick back up above & discuss orientation. Orient string to 170°R & go down to 15935' MD & set 20K SOW. Observe TF roll to 170'L, on the hook. 9/4/2018 9/412018 1.00 COMPZ2 CASING HOSO P Release running tool f/ Hook hanger, 15,943.0 8,323.0 01:45 02:45 drop 29/32th ball and pump down @ 118gpm, 1000 psi. Reduce pump rate 64 gpm, 580 psi. Ball on seat @ 724 strokes. Pressure up to 3500 psi & pick up 4' and confirm release w/ P/U wt. of 135K. Pressure up to 4500 psi to blow ball seat. Flanged hook hanger BOW @ 8348' MD, hook hanger inside casing @ 8328' MD. 9/4/2018 9/4/2018 1.00 COMPZ2 WELLPR OWFF P Monitor well; observe reduction in flow 8,323.0 8,323.0 02:45 03:45 rale return to confirm wellbore breathing. 9/4/2018 9/4/2018 0.25 COMPZ2 WELLPR TRIP P TOH 98323'-8171' MD, PU 130K, SO 8,323.0 8,171.0 03:45 04:00 74K. 9/4/2018 9/4/2018 1.00 COMPZ2 WELLPR SLPC P Cut & slip 88' of drill line. 8,171.0 8,171.0 04:00 05:00 9/4/2018 9/4/2018 7.00 COMPZ2 WELLPR TRIP P TOH f/ 8171'-40' MD, serviced super 8,171.0 40.0 05:00 12:00 sliders f/ 4897' on the way out of the hole. 9/4/2018 9/4/2018 COMPZ2 WELLPR BHAH P Lay down SLB slim pulse MWD & 40.0 0.0 12:00 12:45 BOT running tool. 91412018 9/4/2018 COMPZ2 WELLPR BHAH P Clear & dean rig floor. 0.0 0.0 12:45 13:15 9/4/2018 9/4/2018 F2.75 COMPZ2 RWRID RURD P Rig up GBR torque turn & handling 0.0 0.0 13:15 13:45 equipment. 9/4/2018 914/2018 COMPZ2 RWRID RCST P Make up 4.5', 12.6#, L-80, TXP, 0.0 232.0 13:45 16:30 LEM(ZXP assembly, torque turned, as per detail to 232' MD. Scribe & orient MWD, tool face offset 26.18. 9/4/2018 9/4/2018 0.25 COMPZ2 RWRID DHEO P Make up a stand of DP & test slim 232.0 320.0 16:30 16:45 pulse tools 2 bpm, 242 psi, FO 11 %, acquired detection. 9/4/2018 914/2018 1.00 COMPZ2 RWRID RCST P TIH w/ LEM assembly on DP f/ 320'- 320.0 1,657.0 16:45 17:45 1657' MD, PU 65K, SO 66K. Page 25136 ReportPrinted: 9/2412018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Tlme Lo® stut Start Time EndTime our (hr) Phase Op Code Activity Cotle T. P -T -X Operation (OepM (fixe) 1,657.0 End Depth (eKe) 1,657.0 9/4/2018 9/4/2018 0.25 COMPZ2 RWRID DHEQ P Shallow lest MWD at 2 bpm, 310 psi, 17:45 18:00 FO 11%, good. 9/4/2018 9/4/2018 3.75 COMPZ2 RWRID RCST P TIH wl LEM assembly on DP v 1657'- 1,657.0 8,223.0 18:00 21:45 8223' MD, PU 137K, SO 100K. 9/4/2018 9/4/2018 1.75 COMPZ2 RWRID PACK P Wash down from 8223' - 8490' MD & 8,223.0 8,271.0 21:45 23:30 orient LEM to 82'L w/ 91 gpm, 745 psi, FO 10%. PU 137K, SO 100K. Engage seal assembly & latch LEM in Hook Hanger on depth @ 8490.50' MD. Observe LEM rotate to 34° L. Set down 20K. PU 147K to verify LEM is engaged. Drop 1.625" OD ball. Set down 30K & pump @ 127-84 gpm, 1000-665 psi, FO 13-11%. Ball on seat @ 600 slks. Observe hydraulic pusher tool stroke & set ZXP packer @ 2,400 psi, neutralized @ 3,700 psi & 4200 psi holding for a couple minutes. Bleed off pressure & PU 3' per Baker, PU 137K. 914/2018 9/5/2018 0.50 COMPZ2 RWRID PRTS P Line up & lest ZXP line —top packer to 8,271.0 8,271.0 23:30 00:00 3500 psi for 10 minutes, CPAI Rep witness. Bleed off & blow down kill line. 9/5/2018 9/5/2018 0.75 COMPZ2 RWRID CRIH P PU above ZXP to 8239' MD & spot 20 8,271.0 8,239.0 00:00 00:45 bbls of corrosion inhibited pill at 126 gpm, 550 psi, 9/5/2018 9/5/2018 0.75 COMPZ2 RWRID OWFF P Monitor well, track return flow to verify 8,239.0 8,239.0 00:45 01:30 reduction in rate (wellbore breathing). 9/5/2018 9/5/2018 3.50 COMPZ2 RWRID TRIP -F— TOH wl LEM/ZXP running tools f/ 8,239.0 0.0 01:30 05:00 8239'-0' MD 9/5/2018 9/5/2018 0.50 COMPZ2 RWRID BHAH P Lay down running tool & slim pulse 0.0 0.0 05:00 05:30 MWD' 9/5/2018 915/2018 1.25 COMPZ2 RWRID SVRG P Change out 4" XT39 saver sub on top 0.0 0.0 05:30 06:45 drive, threads wom. 915/2018 9/5/2018 0.75 COMPZ2 WHDBOP KURD P Rig up test equipment —& flood lines. 0.0 0.0 06:45 07:30 Pull wear bushing & install test plug. W512018 9/5/2016 COMPZ2 WHDBOP SVRG P Service & inspect top drive, blocks & 0.0 0.0 07:30 08:00 the crown. 9/5/1018 9/5/2018 COMPZ2 WHDBOP BOPE P Test witnessed by AOGCC Rep Guy 0.0 0.0 08:00 12:15 Cook. Test w/ 4" & 4.5" test joints. r4.25 Perform bi-weekly BOPE test. 250/3500 psi- 5 min each. Following tests done with 4 1/2" test joint. Test #1-Annular,CV's 1,12,13,14, 4" kill Demco, 4" dart valve. Test #2 -Upper 3 112" x 6" VBR, CV's 9,11, mezzanine kill line valve, 4" FOSV. Test #3 -CV's 8,10, kill HCR, Upper SOP. Test #4 - CV's 6,7, lower IBOP, manual kill line valve. Test #5- Super choke and manual choke at 250/2000 psi. Test #6 - CV's 2,5. Test #7- Lower 3 1/2" x 6" VBR. Test #8- Blind rams, CV's 3,4. Following tests done with 4" lest joint. Test #9 -Annular, choke line HCR. Test #10- Upper 3 1/2" x 6" VBR & manual choke. Test #11- Lower 3 1/2" x 6" VBR. Accumulator draw down initial system pressure 3000 psi, after functioning 1750 psi, 200 psi recovery in 6 seconds, full in 50 seconds. Nitrogen bottles 6 @ 2158 psi. Tested gas detection system, flow & pit level indicators. H2S alarm in pits FP. Page 26136 Report Printed: 9124/2018 Operations Summary (with Timelog DeNchs) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth StartTime EndTime Our(hr) Phase op Code Aavfty Cafe Time P -T -X operation (8KB) End Depth(MK8) 9/5/2018 9/5/2018 0.75 COMPZ2 WHDBOP RURD P Rig down & blow down all lines & test 0.0 0.0 12:15 13:00 equipment. Pull test plug & install 9" ID wear bushing. 9/5/2018 9/5/2018 0.50 PROD3 WHPST BHAH P Mobilize whipstock BHA 9 to rig floor. 0.0 0.0 13:00 13:30 9/512018 9/5/2018 2.50 PROD3 WHPST BHAH P Make up mill assembly w/ MWD & 0.0 262.0 13:30 16:00 rack back in the derrick. Make up whipstock assembly to 262' MD as per BOT Rep, SO 49K. 9/5/2018 9/5/2018 1.25 PROD3 WHPST TRIP P TIH w/whipstock BHA9for L2f/ 262'- 262.0 2,160.0 16:00 17:15 2160' MD, SO 75K. 9/5/2018 9/5/2018 0.50 PROD3 WHPST DHEQ P Pulse test MWD at 220 gpm, 675 psi, 2,160.0 2,160.0 17:15 17:45 FO 16%, good. Blow down TD. 9/5/2018 9/5/2018 3.75 PROD3 WHPST TRIP P TIH w/ whipstock BHA9for L2 f/ 2,160.0 8,160.0 17:45 21:30 2160'-8160' MD, PU 142K, SO 75K. 9/5/2018 0.75 PROD3 WHPST WPST P Establish parameters&orient tool 8,160.0 8,167.0 face to 20"L at 231 gpm, 1580 psi, FO 16%, PU 142K, SO 103K. Wash down f/ 8160'-8272'MD, tagging w/ 4K. Observe screws shear at 95K SO to L21:3O22:15 set anchor. Set down to 90K. Pick up to 150K confirm anchor set. Slack offto 74K & observe bolt shear. Pick up & confirm release 144K. TOW 8167'MD. 9/6/2018 1.75 PROD3 WHPST MILL P - Mill window from 8167'MD (TOW) - 8,167.0 8,169.0 22:15 00:00 8169' MD w/ 250 gpm, 1830 psi, FO 18%, 100 rpm, 4-81k Tq, WOB 2-4K. PU 143K, SO 111K, ROT 117K. SCR @ 816T MD, 3793' TVD, MW 10.4, 22:00 his #1 @ 30 = 660 @ 40 = 870 psi #2@30=660@40=880 psi 916/2018 9/6/2018 8.50 PROD3 WHPST MILL P Millwindow from 8169' MD -8205' 8,169.0 8,205.0 00:00 08:30 MD w/ 250 gpm, 1960 psi, FO 18%, 100 rpm, 4.5k Tq, WOB "K. PU 143K, SO 111K, ROT 117K. 9/6/2018 9/6/2018 2.75 PROD3 WHPST REAM P Dress window -8204'-816510D, 250 8,205.0 8,165.0 08:30 11:15 gpm, 1960 psi, FO 18%, 100 rpm, Tq 2-6K, PU 146K, SO 108K w/out pumps. Work tight spot 8178'-8180' MD till clean. 9/6/2018 9/6/2018 1.50 PROD3 WHPST CIRC P CBU f/ 8165-8048' MD, 296 gpm, 8,165.0 8,048.0 11:15 12:45 2270 psi, FO 20%, PU 143K, SO 106K. 9/6/2018 9/6/2018 0.75 PROD3 WHPST FIT P Perform FIT to an EMW of 13.4 ppg, 8,048.0 8,046.0 12:45 13:30 TOW 8167' MD, BOW 8188' MD, hole depth 8205' MD, 3792' TVD, MW 10.4+, Pressure up to 575 psi with .7 bbls pumped. Shut in & record pressure for 10 minutes. Initial shut in pressure 530 psi, final pressure 450 psi. Bled back .6 bbis. Rig down & blow down test equipment. 9/6/2018 9/6/2018 3.50 PROD3 WHPST TRIP P TOH f/ 8048'-157' MD, PU 49K, SO 8,048.0 157.0 13:30 17:00 1 1 52K. 9/6/2018 9/6/2018 0.25 PROD3 WHPST OWFF P Monitor well, static. 157.0 157.0 17:00 17:15 9/6/2016 9/6/2018 0.75 PROD3 WHPST BHAH P Lay down window mill BHA as per 157.0 0.0 17:15 18:00 BOT Rep. Recover 60 lbs of swarf from magnets in the BHA. Window mill bit 3/8" under, lower watermelon mill 1/4" under, & upper watermelon mill was in gauge. Page 27136 Report Printed: 9/24/2018 Operations Summary (with Timelog Depths) Ir 1H-104 ... Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log smn oaHn Stad Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X - Operation (aKa) End Depth (N(9) 9/6/2018 9/6/2018 0.50 PROD3 WHPST BHAH P Clear & dean rig floor. 0.0 0.0 18:00 18:30 9/6/2018 9/6/2018 1.00 PROD3 WHPST W W WH P Pull wear bushing. Make up stack 0.0 0.0 18:30 19:30 wash tool, flush at 854 gpm, 3X. Function VBR's & annular. Lay down stack tool & install 9" ID wear bushing RILDS X2. 9/6/2018 9/6/2018 0.50 PROD3 WHPST SVRG P Inspect & service top drive & blocks. 0.0 0.0 19:30 20:00 9/6/2018 9/6/2018 1.50 PRODS WHPST BHAH P Pick up 6-314', kick off, motor 0.0 631.0 20:00 21:30 assembly, BHA 10, to 631' MD, PU 58K, SO 62K. 9/6/2018 9/6/2018 0.75 PROD3 WHPST TRIP P TIH f/ 631'-2040' MD, PU 77K, SO 631.0 2,040.0 21:30 22:15 77K. 916/2018 9/6/2018 0.50 PRODS WHPST DHEQ P Shallow hole test MWD, 240 gpm, 2,040.0 2,040.0 22:15 22:45 11257 psi, good. 9/6/2018 9/7/2018 1.25 PRODS WHPST TRIP P TIH V 2040'-5850' MD, PU 130K, SO 2,040.0 5,850.0 22:45 00:00 83K. 917/2018 9!7/2018 1.50 PROD3 WHPST TRIP P TIH f/ 5850'-8067' MD, PU 119K, SO 5,850.0 8,067.0 00:00 01:30 82K. 018 9/7/2018 0.50 PRODS WHPST CIRC P Orient tool face to 20° L at 57 gpm, 8,067.0 8,205.0 0 02:00 1850 psi, FO 18%. Pumps off & drift through window ff 8067'-8205' MD. 018 917/2018 5.25 PRODS URILL P Directional drill 6 3/4" L2 hole f/ 8205' 8,205.0 8,312.0 [022:00 07:15 - 8312' MD, 3807' TVD, 240 gpm, 1940 psi, FO 19%, 50 rpm, Tq 6K, WOB 14-8K, ECD -, off btm 1870 psi, PU 119K, SO 82K, ROT 97K, Tq 4K, Max gas 16, ADT 3.41, AST 1.4, Bit 3.41, Jars 181.56 9/712018 9/7/2016 0.50 PRO 33 DRILL CIRC P Obtain SCR's. Orient tool face to 20° L 8,312.0 8,039.0 07:15 07:45 at 55 gpm, 1815 psi, FO 17%, PU 121K, SO 79K. Pumps off & drift through window f/ 8312'-8039' MO SCR @ 8311' MD, 3807' TVD, MW 10.4 ppg, 07:00 hrs #1 @ 20 = 670 psi, @ 30 = 900 psi #2 @ 20 = 670 psi, @ 30 = 860 psi 917/2018 9/7/2018 0.50 PROD3 DRILL CIRC P CBU at 240 gpm, 1850 psi, 40 rpm, Tq 8,039.0 8,039.0 07:45 08:15 1 5K, PU 121 K, SO 79K. 9!7/2018 9/7/2018 0.25 PRODS DRILL OWFF P Monitor well, static. 8,039.0 8,039.0 08:15 08:30 9/7/2018 9/7/2018 4.00 FR DRILL TRIP P TOH with kick off BHA 10 f/ 80391- 8,039.0 631.0 08:30 12:30 631' MD, 9/7/2018 9/7/2018 1.25 PROD3 DRILL BHAH P Lay down BHA 10 as per SLB. 631.0 0.0 12:30 13:45 9/7/2018 9/7/2018 0.75 PROD3 DRILL BHAH P Clear & clean rig floor. 0.0 0.0 13:45 14:30 9/7/201 B 9/712018 1.00 PROD3 DRILL BHAH P Make up 6-3/4" RSS BHA per SLB DD 0.0 339.0 14:30 15:30 to 339' MD, PU 52K, SO 58K 9/7/2018 9/7/2018 0.75 PROD3 DRILL TRIP P TIH f/ 339'-1751' MD. 339.0 1,751.0 15:30 16:15 917/2018 9/7/2018 0.25 PROD3 DRILL DHEQ P Shallow hole test MWD 23TpSi 1,751.0 1,751.0 16:15 16:30 1087 psi, FO 16%. 9/712018 917/2018 3.50 PRODS DRILL TRIP P TIH f/ 1751'-8211' MD, fill 1,751.0 8,211.0 16:30 20:00 20 stands. SCR @ 8208' MD, 3794' T 10.2 ppg, 19:50 hm #1 @ 20 = 640 psi, @ 30 #2 @ 20 = 640 psi, @ 30 9/7/2018 9/2018 0.50 PRODS DRILL SRW P Survey/Logf/8211'-8310' 8,211.0 ,. 20:00 20:30 gpm, 1824 psi, FO 18%,64K, PU 118K, SO 86K, RO 128 Page 28136 Report Printe;..;;,3;j2843100j0 Operations Summary (with Timelog Depths) IH-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log alart Depth start Time I End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (fIKB) End Depth(ftKB) 9/7/2018 191712018 1.25 PROD3 DRILL DISP P Displace well to new 10.2 ppg 8,310.0 8,312.0 20:30 21:45 FLOPRO NT mud at 250 gpm, 1838 psi, FO 18%, 60 rpm, Tq 4K. 9!7/2018 9/812018 2.25 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 8312' 8,312.0 8,410.0 21:45 00:00 - 8410' MD, 3804' TVD, 250 gpm, 1830 psi, FO 19%,120 rpm, Tq 7K, WOB 2-8K, ECD 11.48, off btm 1833 psi, PU 121 K, SO 82K, ROT 99K, Tq 7K, Max gas 120, ADT 1.21, Bit 1.21, Jars 1.21 9/8/2018 91812018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 8410' 8,410.0 8,840.0 00:00 06:00 - 8840' MD, 3816' TVD, 250 gpm, 1880 psi, FO 19%,150 rpm, Tq 8K, WOB 2K, ECD 11.6, off btm 1870 psi, PU 120K, SO 82K, ROT 99K, Tq 7K, Max gas 120, ADT 3.711, Bit 4.92, Jars 4.92 9/8/2018 9/8/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 8840' 8,840.0 8,989.0 06:00 12:00 - 8989' MD, 3825' TVD, 270 gpm, 2116 psi, FO 19%, 100 rpm, Tq 9K, WOB 2-9K, ECD 11.45, off btm 2079 psi, PU 120K, SO 82K, ROT 99K, Tq 7K, Max gas 301, ADT 3.99, Bit 8.91, Jars 8.91 SCR @ 8882' MD, 3820' TVD, MW 10.2 ppg, 07:45 his #1 @ 20 = 420 psi, @ 30 = 620 psi #2 @ 20 = 420 psi, @ 30 = 620 psi 9/812018 9/8/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole if 8989' 8,989.0 9,330.0 12:00 18:00 - 9330' MD, 3841' TVD, 270 gpm, 2172 psi, FO 19%, 100 rpm, Tq 9K, WOB 1-10K, ECD 11.57, off btm 2166 psi, PU 132K, SO 76K, ROT 102K, Tq 8K, Max gas 63, ADT 4.57, Bit 13.48, Jars 13.48 9/8/2018 91912018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 9330' 9,330.0 9,895.0 18:00 00:00 - 9895' MD, 3851' TVD, 270 gpm, 2170 psi, FO 19%,140 rpm, Tq 9K, WOB 1-10K. ECD 11.97, off btm 2160 psi, PU 133K, SO 71K, ROT 102K, Tq 8K, Max gas 33, ADT 4.07, Bit 17.55, Jars 17.55 SCR @ 9737' MD, 3849' TVD, MW 10.1 ppg, 22:30 hrs #1 @ 20 = 480 psi, @ 30 = 700 psi #2@20=500 psi, @30=710 psi 9/9/2018 9/912018 6.00 PRODS DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 9895' 9,895.0 10,360.0 00:00 06:00 -10360' MD, 3868' ND, 270 gpm, 2250 psi, FO 19%, 100 rpm, Tq 9K, WOB 2-8K, ECD 11.97, off btm 2200 psi, PU 132K, SO 68K, ROT 96K, Tq 8K, Max gas 22, ADT 4.91, Bit 22.46, Jars 22.46 9/9/2018 9/9/2018 6.00 PROD3 DRILL DDRL P Directional drill 3/4" L2 hole f/ 10,360.0 10,591.0 06:00 12:00 10360' - 10591' MD, 3890' TVD, 270 gpm, 2290 psi, FO 19%, 140 rpm, Tq 9K, WOB 2-8K, ECD 12.04, off him 2285 psi, PU 134K, SO 76K, ROT 97K, Tq 8K, Max gas 107, ADT 4.58, Bit 27.04, Jars 27.04 SCR @ 10400' MD, 3870' TVD, MW 10.2 ppg, 08:00 hrs #1 @20= 510 psi, @ 30 = 700 psi #2@20=520 psi, @ 30= 710 psi Page 29136 Report Printed: 912412018 Operations Summary (with Timelog Depths) 1H-104 4Rig: .o DOYON 142 Job: DRILLING ORIGINAL Start Depth End Time Dur(hr) 6.00 Phase PROD3 Op Code DRILL Activity Code DDRL Time P -T -X P Operation Directional drill 6 314" L2 hole fl (tlKa) 10,591.0 End Depth (WS) 10,951.0 9/9/2018 18:00 10591' -10951' MD, 3921' TVD, 270 gpm, 2380 psi, FO 19%,140 rpm, Tq r12:00 9K, WOB 2-8K, ECD 12.08, off blm2300 psi, PU 135K, SO 73K, ROT t OOK, Tq 8K, Max gas 77, ADT 4.94, Bit 31.98, Jars 31.98 9/10/2018 6.00 PROD3 DRILL DDRL P Directional drill 63/4" L2 hole f/ 10,951.0 11,211.0 00:00 10951'- 11211' MD, 3914' TVD, 270 gpm, 2350 psi, FO 19%,140-100 rpm, Tq 9K, WOB 2-8K. ECD 12.05, off btm 2320 psi, PU 137K, SO 76K, ROT 96K, Tq 8K, Max gas 66, ADT 5.31, Bit 37.29, Jars 37.29 SCR @ 10972' MD, 3923' TVD, MW 10.2 ppg, 19:15 ms #1 @ 20 = 500 psi, @ 30 = 700 psi #2 @ 20 = 490 psi, @ 30 = 680 psi 9/10/2018 9/1012018 6.00 PROD3 DRILL DDRL P Directional drill 6:3/4" L2 hole f/ 11,211.0 11,460.0 00:00 06:00 11211'- 11460' MD, 3901' TVD, 270 gpm, 2350 psi, FO 19%,120-100 rpm, Tq 8K, WOB 2-6K, ECD 12.0, off btm 2320 psi, PU 135K, SO 68K, ROT 98K, Tq 8K, Max gas 180, ADT 4.77, Bit 42.06, Jars 42.06 OA 160 psi 9/10/2018 9/10/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 11,460.0 11,789.0 06:00 12:00. 11460'- 11789' MD, 3875' TVD, 270 gpm, 2409 psi, FO 19%, 150 rpm, Tq 8.61K, WOB 2-1 OK, ECD 12.18, off btm 2400 psi, PU 136K, SO 65K, ROT 100K, Tq 8.4K, Max gas 183, ADT 4.39, Bit 46.45, Jars 46.45 SCR @ 11636' MD, 3890' TVD, MW 10.2 ppg, 10:00 hrs #1 @ 20 = 560 psi, @ 30 = 740 psi #2 @ 20 = 540 psi, @ 30 = 720 psi 9/10/2018 9/10/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 11,789.0 12,047.0 12:00 18:00 11789'- 12047' MD, 3866' TVD, 270 gpm, 2423 psi, FO 20%, 150 rpm, Tq 10K, WOB 1-12K, ECD 12.23, off btm 2405 psi, PU 136K, SO 64K, ROT 98K, Tq 8.5K, Max gas 265, ADT 5.09, Bit 51.54, Jars 51.54 OA 155 psi 9/1012018 9/11/2018 6.00 PROD3 DRILL DDRL P Directional drill 63/4"L2 hole f/ 12,047.0 12,270.0 18:00 00:00 112047'- 12270' MD, 3856' TVD, 270 gpm, 2450 psi, FO 20%,150 rpm, Tq 8K, WOB 1-12K , ECD 12.25, off btm 2420 psi, PU 137K, SO 62K, ROT 96K, Tq 8.5K, Max gas 36, ADT 5.0, Bit 56.54, Jars 56.54 SCR @ 11636' MD, 3890' TVD, MW 10.2 ppg, 10:00 hrs #1 @ 20 = 560 psi, @ 30 = 740 psi #2 @ 20 = 540 psi, @ 30 = 720 psi 9/11/2018 9/11/2018 6.00 PROD3 DRILL DDRL P Directional drill 314" L2 hole f/ 12,270.0 12,766.0 00:00 06:00 12270' MD, 3856' TVD -12,766' MD 3,833' TVD, 270 gpm, 2500 psi, FO 20%,150 rpm, Tq 8K, WOB 1-6K, ECD 12.28, off btm 2480 psi, PU 142K, SO 53K, ROT 90K, Tq 8.5K, Max gas 46, ADT 4.36, Bit 60.9, Jars 60.9 Page 30136 1 ReportPrinted: 912 412 01 8 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth StartTime End Time Dur (hr) Phase Op Code Activity Code Time P -T -x Operation (fiKS) End Depth (111(13) 9/11/2018 9/11/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" 12 hole V 12,766.0 13,460.0 06:00 12:00 12,766' MD 3,833' TVD - 13,460' MD 3,836' TVD, 270 gpm, 2631 psi, FO 21%,170 rpm, Tq 11.5K, WOB 1-8K, ECD 12.37, off Not 2630 psi, PU 150K, SO OK, ROT 103K, Tq 9K, Max gas 330. ADT 4.23, Bit 65.13, Jars 65.13 SCR @ 12,773' MD, 3834' TVD, MW 10.2 ppg, 0600 hrs #1 @ 20 = 540 psi, @ 30 = 740 psi #2 @ 20 = 520 psi, @ 30 = 720 psi 9/11/2018 9/11/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole fl - 13,460.0 14,107.0 12:00 18:00 13,460' MD 3,836' TVD - 14,107' MD 3,911' TVD, 270 gpm, 2765 psi, FO 20%,170 rpm, Tq 9K, WOB 1-7K, ECD 12.86, off Non 2,745 psi, PU 163K, SO OK, ROT 103K, Tq 10K, Max gas 189. ADT 4.13, Bit 69.26, Jars 69.26 9/11/2018 9/1212018' 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 14,107.0 14,442.0 18:00 00:00 14,107' MD 3,911' TVD - 14,442' MD 3,909' TVD, 270 gpm, 2,917 psi, FO 20%,130 rpm, Tq 9K, WOB 2-14K, ECD 12.76, off Not 2,900 psi, PU 167K, SO OK, ROT 106K, Tq 9K, Max gas 71. ADT 4.93, Bit 74.19, Jars 74.19 SCR @ 14,353' MD, 3906' TVD, MW 10.2 ppg, 2230 hm #1 @ 20 = 640 psi, @ 30 = 880 psi #2 @ 20 = 600 psi, @ 30 = 860 psi 9/12/2018 9/12/2018 6.00 PRODS DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 14,442.0 14,932.0 00:00 06:00 14,442' MD 3,909' TVD - 14,932' MD 3,862' TVD, 270 gpm, 3,041 psi, FO 20%,130 rpm, Tq 9.8K, WOB 6K, ECD 12.78, off Not 2,989 psi, PU 170K, SO OK, ROT 105K, Tq 9K, Max gas 39. ADT 4.49, Bit 78.68, Jars 78.68 9/12/2018 9/12/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 14,932.0 15,637.0 06:00 12:00 14,932' MD 3,862' TVD - 15,637' MD 3,857' TVD, 270 gpm, 3,175 psi, FO 20%,120 rpm, Tq 10K, WOB 6K, ECD 13, off btm 3,168 psi, PU 192K, SO OK, ROT 11 OK, Tq 10K, Max gas 279. ADT 4.46, Bit 83.14, Jars 83.14 SCR @ 15,000' MD, 3,860' TVD, MW 10.2 ppg, 0615 his #1 @ 20 = 680 psi, @ 30 = 920 psi #2 @ 20 = 660 psi, @ 30 = 900 psi Page 31136 Report Printed: 912412018 Operations Summary (with Timelog DeNchs) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sen Depth Sten Time End Time our (no Please Op code Activity Cade Time P -T -x Operation (r(s) End Depth irks) 9/12/2018 9/12/2018 3.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 15,637.0 15,872.0 12:00 15:00 15,637' MD 3,857' TVD - 15,872' MD 3,864' TVD, 270 gpm, 3,269 psi, FO 20%,120 rpm, Tq 10K, WOB 8K, ECD 13.02, off btm 3,268 psi, PU 189K, SO OK, ROT 114K, Tq 10K, Max gas 53. ADT 2.14, Bit 85.28, Jars 85.28 SCR @ 15,822' MD, 3,867' TVD, MW 10.2 ppg, 1700 hrs #1 @ 20 = 720 psi, @ 30 = 1,000 psi #2 @ 20 = 680 psi, @ 30 = 960 psi 9/12/2018 9/12/2018 1.50 PROD3 CASING CIRC P Rotate and reciprocate from 15,872' 15,872.0 15,872.0 15:00 16:30 MD - 15,827' MD 270 GPM @ ICP • 3,269 PSI - FCP = 3,236 PSI. IECD = 13.02, FECD = 12.8 EMW. 120 RPM 8.5K To. UP WT=183K, DWN WT= 0, ROT WT = 105K. total stks pumped = 5,010. 9/12/2018 9/12/2018 0.50 PROD3 CASING OWFF P OWFF(drop 4'). 15,872.0 15,872.0 16:30 17:00 9/12/2018 9/13/2018 7.00 PROD3 CASING BKRM P BKRN OOH from 15,872' MD - 13,000' 15,872.0 13,000.0 17:00 00:00 MD with 270 GPM @ 3,236 PSI. 20% F/O, 120 RPM 8.5K TO, 105K ROT, UP WT = 125K w/pumps. 9/1312018 9/13/2018 11.50 PROD3 CASING BKRM P BKRM OOH from 13,100' MD - 8707' 13,000.0 8,507.0 00:00 11:30 MD. 270 GPM @ ICP 2,600 PSI, 20% F/O, 120 RPM, 5-7K To, ECD = 111.73, UP WT = 95K pumps on. 9/13/2018 9/1312018 0.50 PROD3 CASING TRIP P POOH on elevators from 8,507' MD - 8,507.0 8,032.0 11:30 12:00 8,032' MD. pulling BHAthrough window. UP WT=125K, DWN WT= 83K, Monitor disp via TT No overpull witnessed. 9/13/2018 9/13/2018 2.00 PROD3 CASING CIRC P PUmp out stand 81 and rack back. 8,032.0 7,936.0 12:00 14:00 ROT/Recip while weight up to 10.4 PPG, frin 7,840'-7,936' MD. 270 GPM @ 2,088 PSI, 17% F/O, 11.95 ECD, 120 RPM 5K To. UP WT = 120K, DWN WT=83K, ROT WT=95K Total stks = 5,786 pumped. 9/13/2018 9/13/2018 0.50 PROD3 P OWFF. (static)pumpdryjob. BD/TD. 7,936.0 7,936.0 14:00 14:309/13/2018 9/13/2018 0.50 PROD3 SVRG P Service TD. 7,936.0 7,936.0 14:30 15:009/13/2018 9/13/2018 6.00 PROD3 FCASINGOWFF PULD P POOH on elevators from 7,936'MD to 7,936.0339.0 15:00 21:00 339'MD laying down sideways 4" DP. UP WT=120K, DWN WT=83K. Monitor disp via TT. 9/13/2018 9/13/2018 1.50 PROD3 BHAH P Break down and lay down 6 3/4" L2 339.0 0.0 21:00 22:30 drilling BHA. 9/13/2018 9/13/2018 0.50 COMPZ3 FISH SHAH P MU Baker BHA for whipstock retrieval 0.0 0.0 22:30 23:00 while scribe tool face. 9/13/2018 9/14/2018 1.00 COMPZ3 FISH TRIP P RIH with whipstock retrieval system on 0.0 1,300.0 23:00 00:00 4" DP from Derrick. 9/14/2018 9/14/2018 3.50 COMPZ3 FISH TRIP P Continue to trip in hole with whipstock 1,300.0 8,148.0 00:00 03:30 retrieval system from 1,300' MD - 8,148' MD UP WT = 140K DWN WT = 109K. Monitor disp via TT. Page 32/36 ReportPrinted: 9/24/2018 Operations Summary (with Timelog DeNths) 11-1-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sten Depth Stan Time End Time Dur(hr) Phase Op Code Activity Code Time P -T -X Operation We) End Depth(ftKB) 9/14/2018 9114/2018 0.50 COMPZ3 FISH FISH P Orient tool face to wash whipstock 8,148.0 8,172.0 03:30 04:00 slot. reciprocate at 250 GPM 1,980 PSI to 6,172' MD. Orient and latch whipstock 20 DEG left. Slack off 1 OK DWN WT then pull 10K over to confirm hook. Pull 40K over slowly to allow for jars to bleed. Pull 80K straight pull and sheared at 75K. Stand back stand 142K UP WT. 9/14/2018 9/14/2018 2.00 COMPZ3 FISH CIRC P Circulate 2 bottoms up at 250 GPM 8,172.0 8,080.0 04:00 06:00 1,550 PSI. 5,000 STKS pumped 9/14/2018 9/14/2018 2.50 COMPZ3 FISH OWFF T OWFF- Observe flow back @ 5.95 8,080.0 8,248.0 06:00 08:30 BPH. reduce to .45 BPH. 9/14/2018 9/14/2018 0.25 COMPZ3 FISH CIRC T Stage pumps up to 200 GPM @ 1,171 8,248.0 8,248.0 08:30 08:45 PSI with 17% F/O. Observe erratic returns with 3 BBL pit gain. and 1,555 units of gas. Shut down pumps and observe perculaling fluid. fluid level dropped 1'. 9114/2018 9/14/2018 0.50 COMPZ3 FISH OWFF T Close annular and monitor DPP and 8,248.0 8,248.0 08:45 09:15 casing pressure for 30 min. observe 0 PSI. 9/14/2018 9/14/2018 1.75 COMPZ3 FISH CIRC - T Circulate through choke at BPM, 8,248.0 8,248.0 09:15 11:00 171 GPM, ICP 880 PSI, FCP 900 PSI. Total STKS pumped 3,165. Loss of 8 BELS during circ. 9/14/2018 9/14/2018 0.50 COMPZ3 FISH OWFF T OWFF Monitor pressure observe 0 8,248.0 8,248.0 11:00 11:30 PSI gain on choke and DP. 9/14/2018 9/14/2018 1.50 COMPZ3 FISH CIRC T Open bag and circulate at 200 GPM 8,248.0 8,248.0 11:30 13:00 1,183 PSI with 15% F/0 while increasing MW to 10.4 PPG. total stks pumped 4,434 with a 7 BBL loss during circ. 911412018 9/14/2018 0.25 COMPZ3 FISH OWFF T OWFF. nate 6 BBL bleed back. 8,248.0 8,248.0 13:00 13:15 9/14/2018 9/14/2018 1.00 COMPZ3 FISH CIRC T Continue to circ BU with 10.5 PPG @ 8,248.0 8,248.0 13:15 14:15 180 GPM 966 PSI 15% F/O, total stks pumped 2,538. Observe no gas to surface 10 BBL loss during circ. 9/14/2018 9/14/2018 2.50 COMPZ3 FISH OWFF T Observe well for flow. Rate decreased 8,248.0 8,248.0 14:15 16:45 from 15 BPH -.16 BPH. Good to go. 9/14/2018 9/14/2018 4.50 COMPZ3 FISH TRIP P Drop 1.875" rabbit and POOH on 8,248.0 173.0 16:45 21:15 elevators from 8,248' MD -173' MD. Monitor disp via TT recover drift in stnd#1. 9/14/2018 9/14/2018 0.25 COMPZ3 FISH OWFF P OWFF. Observe gas breaking out. 173.0 173.0 21:15 21:30 Fluid level dropped 2'. 9/14/2018 9/15/2018 2.50 COMPZ3 FISH BHAH P LD whipstock BHA system as per 173.0 0.0 21:30 00:00 Baker rep. Monitor disp via TT. 9/15/2018 9/15/2018 1.50 COMPZ3 FISH BOPE T Test BOPE to 250/3,500 PSI F 5/5 0.0 0.0 00:00 01:30 charted min with exception of Superchoke 12,000 PSI, W 4 and 4/1/2" test joint. choke valves 1,3,5,6 test witness waived by Bob Noble. Sim ops clean rig floor. 9/15/2018 9/15/2018 0.50 COMPZ3 CASING BOPE T Pull test plug and set wear bushing. 0.0 0.0 01:30 02:00 9/15/2018 9/1512018 2.00 COMPZ3 CASING SLP(; P Slip and cut 75' Drill line 0.0 0.0 02:00 04:00 9/15/2018 9/1512018 0.50 COMPZ3 CASING SVRG P Service rig and clo washpipe, test 0.0 0.0 04:00 04:30 I same to 3,500 PSI. Page 33/36 Report Printed: 9/24120181 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sten Depth Siert Time End Time Phase CP Code Activity Code Time P -T -x Operation WE) End Depth (IC(a) 9/15/2018 9/15/2018 COMPZ3 CASING PUTB P PJSM and RIH with 4 1/2" 12.6# L-80 0.0 5,700.0 04:30 13:30 IBTM liner to 4,807' MD' Monitor disp via TT. UP WT=81K DWN WT= 72K. 9/15/2018 9/15/2018 P2.50 COMPZ3 CASING SVRG P Lubricate pipe skate 5,700.0 5,700.0 13:30 14:00 9/15/2018 9115/2018 COMPZ3 CASING PUTB P Continue to RIH with 4 1/2" L-80 12.5# 5,700.0 7,640.0 14:00 16:30 IBTM liner from 5,700' MD - 7,640' MD. UP WT=96K DWN WT=78K. Monitor disp via TT. 9/15/2018 9/15/2018 0.50 COMPZ3 CASING OTHR P PU/MU Baker flanged hook hanger 7,640.0 7,690.0 16:30 17:00 and SLMD slimpulse MWD. Orient & RIH from 7,640' MD - 7,690' MD UP WT=96K DWN WT=78K Monitor disp via TT. 9/15/2018 9/15/2018 0.50 COMPZ3 CASING DHEQ P RIH with lower completion on 4" DP 7,690.0 8,132.0 17:00 17:30 7,690' MD - 8,132' MD Shallow hole test MWD at 86 GPM, 315 PSI 12% IF/O. Passed. 9/15/2018 9/15/2018 5.00 COMPZ3 CASING RUNL P RIH with L2 lower completion from 8,132.0 15,655.0 17:30 22:30 8,132' MD- 15,655' MD UP WT= 160K. DWN WT=87K. Monitor disp via TT. 9/15/2018 9/16/2018 1.50 COMPZ3 CASING HOSO P Kelly up and wash down from 15,655' 15,655.0 15,827.0 22:30 00:00 MD while orienting to 180 deg. Wash down 5' past window (shoe depth) 15,830' MD. PU above window and orient 24 DEG left.. Set hook hanger at shoe depth of 15,827' MD with 20K dwn wt. PIU 15'and confirm tag. Observe toolfaoe rool to 18 DEG L. Drop 29/32" ball and pump down at 3 BPM, 1,070 PSI 9/16/2018 9/16/2018 0.75 COMPZ3 CASING HOSO P Continue to pump 29/32" ball down 15,627.0 15,827.0 00:00 00:45 follow BOT pup schedule. Final rate of 1 BPM ball on seat at 703 stks. Pressure up and shear out ball set at 4,430 PSI. raise rate to 2 BPM and PU above linertop to 8,150' MD UP WT = 139K, DWN WT = 105K. 9/1612018 9/16/2018 1.50 COMPZ3 WELLPR DISP P Circulate while reciprocate form 8,150- 8,150.0 8,150.0 00:45 02:15 8,040' MD. Displace well V10.4 PPG brine @ 340 GPM, 2,100 PSI, 24% FIO, max gas = 3,370 units. Total stks pumpede 4,180. MW in = 10.4 MW out =10.4 UP WT=135K, DWN WT = 113K. 9/16/2018 9/1612018 0.75 COMPZ3 WELLPR CRIH P Spot 20 BBLS Clto 7,150' MD. Chase 8,150.0 8,150.0 02:15 03:00 with 76 BBLS brine at 5 BPM, 5 BPM 650 PSI. 16% F/0. 9/16/2018 9116/2018 0.50 COMPZ3 WELLPR OWFF P OWFF. Timed flow back with 8,150.0 8,150.0 03:00 03:30 diminishing rate. start 1gV10 sec- 1 QT/44 SEC. prep to POOH. 911612018 9/16/2018 2.50 COMPZ3 WELLPR TRIP P POOH from 8,150 MD - 1,985' MD. 8,150.0 1,985.0 03:30 06:00 Monitor disp via TT UP WT = 73K, DWN WT = 75K. 9/16/2018 9/16/2018 1.00 COMPZ3 WELLPR TRIP P POOH from 1,985'MD - 85'MD. 1,985.0 85.0 06:00 07:00 Monitor disp via TT. 9/16/2018 9/16/2018 0.75 COMPZ3 WELLPR BHAH P Lay down liner running tools and 85.0 0.0 07:00 07:45 slimpulse MWD. Clean rig floor and prep for ZXP/LEM 9/16/2018 9/16/2018 1.00 COMPZ3 RWRID RURD P RU GBH casing running tools and TQ 0.0 0.0 07:45 08:45 turn equipment. Page 34136 Report Printed: 912412018 Operations Summary (with Timelog Depths) 11-1-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sran Depth Steri Time End Time Dur(hO Phase Op CMe Activity Code Time P-T-X Operation (WB) EM Depth(tIKB) 303.0 9/16/2016 2.25 COMPZ3 RWRID PUTB P PJSM / MU L2 LEW ZXP as per 0.0 08:45 11:00 detail from 0- 269' MD. Monitor disp 19/16/2018 via TT. Slimpulse and liner top pkr. UP WT = 48K, DWN WT = 53K. 9/16/2018 9/16/2018 5.00 COMPZ3 RWRID RCST P RIP with LEMIZXP from 303' MD to 303.0 8,192.0 11:00 16:00 8,192' MD on 4" DP out of derrick. UP WT= 142K DWN WT= 113K. Monitor disp via TT. 9/16/2018 9/16/2018 0.75 COMPZ3 RWRID RCST P Washdownfrom 8,192MD-8,287' 8,192.0 8,302.0 16:00 16:45 MD with 120 GPM 603 PSI, 12% F/0. orient to 60 DEG L high side. Wash down to 8,302' MD set dwn 15K. Observed shift to 30 DEG left high side. Pulled up 1O over pull to confirm latch. Set down 1OK. 9/16/2018 9/16/2018 0.75 COMPZ3 RWRID PACK P Drop 1.625 OD ball and pump dwn at 8,302.0 8,302.0 16:45 17:30 3BPM 738 PSI 10% F/0. Reduce rate at 400 STKS. to 2 BPM, 330 PSI. 9% F/0. Ball on seal at 609 stks. Pressure up to 4,000 PSI and set PKR & release. bleed pressure to 0 PSI. 9/1612018 9/16/2018 1.00 COMPZ3 RWRID PRTS P Pick up 1' with 140K UP WT to confirm 8,302.0 8,004.0 17:30 18:30 release. close upper rams. Pump down kill line and pressure test IA to 3,500 PSI charted. (PASSED). LD 3 singles. 911612018 9/16/2018 0.50 COMPZ3 RWRIDOWFF P OWFF. Note fluid dropped 1'. 8,004.0 8,004.0 18:30 19:00 9/16/2018 9/17/2018 5.00 COMPZ3 RWRID PULD P POOH laying down 4" DP sideways 8,004.0 4,830.0 19:00 00:00 from 8,004' MD - 4,830' MD. Removing SS on rig floor. monitor disp via TT. UP WT = 92K, DNW WT = 84K. 9/17/2018 9/17/2018 7.75 COMPZ3 RWRID P Continue to POOH laying down 4,830.0 0.0 00:00 07:45 singles and pulling super sliders off on IPULD rig floor. Monitor disp via TT UP WT =64K, DWN WT=66K. 9/17/2018 9/1712018 0.75 COMPZ3 RWRID SHAH P LD Baker linner running tools and 0.0 0.0 07:45 08:30 wash stack. BD top drive 9/17/2018 9117/2018 0.50 COMPZ3 RPCOMP WWWH P Wash stack pull wear ring. 0.0 0.0 08:30 09:00 9/1712018 9/17/2018 2.00 COMPZ3 RPCOMP RURD P RIG up SLB control line systems 0.0 0.0 09:00 11:00 clamps/and GBR running equip. Rig up to RIH with 4 112" 12.6# L-80 IBTM upper completion. 9/17/2018 9118/2018 13.00 COMPZ3 RPCOMP PUTB P PU/MU41/2" 12.6# L-80I131M upper 0.0 7,039.0 11:00 00:00 completion a RIH from surface to 7,039' MD with DHG wire conection testing realtime to 9,500 PSI. Install clamps on every collar. At 3,400' UP WT=74K DNW WT=72K. Monitoring disp via TT UP WT = 94K DWN WT = 78K. 9/18/2018 9/18/2018 1.75 COMPZ3 RPCOMP PUTB P Continue to RIH with 4 1/2" L-80 12.6# 7,039.0 8,020.0 00:00 01:45 IBTM upper completion from 7,039' MD to 8,020' MD. (stall clamps on every collar and TO all conneciton to 4,500 Ft/LBS. Monitor disp via TT. UP WT=98K, DWN WT=78K. Total full cannon clamp count = 267. Total half clamps = 6 Page 35136 Report Printed: 912412018 Operations Summary (with Timelog Depths) IH -104 11[4... Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log Sian Depth start Time I End Time our (m) Phase Op Cade Activity Code WO—So Time P -T-% -I Openelion Bring on pumps to 1 BPM and wash (ftKB) 8,020.0 End Depth(ftl(B) 7,963.0 9/18/2018 9/18/2018 1.00 COMPZ3 RPCOMP down from 8,020' MD to observe seals 01:45 02:45 enter seal asym at 8,036.47' MD, DO pumps and no go out at 8,054.15 MD. with 20K DWN WT. LD 4joints to 7,963' MD 9/18/2018 9/1812018 1.50 C0MPZ3 RPCOMP -HO-S-0— P MU space out pups of 7.82'13.90' rig 7,963.0 7,963.0 02:45 04:15 up circ lines / hanger / landing joint. 911812018 9/18!2018 1.25 COMPZ3 RPCOMP CRIH P rosion iibitor Ti�rculate and spot r245 7,963.0 7,963.0 04:15 05:30 145 BBI -S. 4 BPM coPSI F10. chase with 120 BBLS brine. simops with termination of tech wire. 9/1812018 9/18/2018 1.50 C0MPZ3 RPCOMP WWSP P LAnd hanger and RILDS. PT upper/ 7,963.0 8,054.0 05:30 07:00 lower seals to 5,000 PSI for 10 min each. 9118/2018 9/18/2018 2.00 COMPZ3 RPCOMP PRTS P PT IA to 1,000 PSI for 5 min to confirm 8,054.0 8,054.0 07:00 09:00 seals are fully located , bleed off psi . Drop B&R and r/U to test tbg. Test TBG to 3,500 PSI for 30 Charted min. Bleed off tbg to 2,100 PSI and pressure test IA to 3,500 charted PIS for 30 min. Bleed off tbg and shear SOV. 9/1812018 9/18/2018 1.00 COMPZ3 WHDBOP MPSP P LD landing joint and install BPV / 8,054.0 8,054.0 jPressure test BPV to 2,500 PSI from 09:00 10:00 below for 5 min. 9/18/2018 9/1812018 2.00 COMPZ3 WHDBOP -(5T--HR P LD mouse hole and pull/ dser. Install 8,054.0 8,054.0 10:00 12:00 drip nipple 9/18/2016 9/18/2018 1.50 COMPZ3 WHDBOP NUND P NO BOPE 0.0 0.0 12:00 13:30 9118/2018 9/18/2018 2.00 COMPZ3 WHDBOP NUND P Clean well head and install test dart. 0.0 13:30 15:30 MU tree as per Vetco rep. 9/18/2018 9/18/2018 2.50 COMP WHDBOP PRTS P PT void on tree/ hanger seals I to 15:30 18:00 5,000 PSI for 10 min as per Vetco rep. Finalize termination of tech wire and verify reading PSI and tempureture. CO rep verify test. 9/1812018 9/18/2018 3.25 COMPZ3 WHDBOP FRZP P PJSM / Pull test dart / m and freeze 18:00 21:15 protect well IA -Tub with 112 BBLS diesel at 3 BPM 1,650 PSI final 2.5 BPM Q 2,000 PSI holding 100 PSI BP. Install BPV and lest same to 1,500 PSI from direction of flow. RD lubricator. Final pressures read before installing BPV were tubing 250 psi, IA 30 psi and OA= 0 psi. 9'18/2018 9/19/2018 2.75 DEMOB MOVE RURD P Clean cellar while prepping to move 21:15 00:00 rig. Rig release 2359 hrs. Page 36136 ReportPrinted: 912 412 01 8 NADConversion Kuparuk River Unit Kuparuk 1H Pad 1 H -104L2 IH -104L2 ConocoPhillips Definitive Survey Report 08 October, 2018 Final Definitive Survey Verified and Signed -off Afl targets and/or weArposkiOn objectives have been achieved. Ed Yes L:; No I have checked to the best of my abillAy that the following data is correct: surface Coordinates ,J Declination & Convergence J GRS Surrey Corrections Survey Tool Codes Brandon Temple Dig itally signed by Brandon Temple SLB DE: Date: 2018.10.0810:19:09 -08'00' Scott a.brunswick&onocophillips.corri_:_ Client Representative- Date. X ll.MWVIII ConocoPhillips ConocoPhillips Definitive Survey Report won Well Position Position Uncertainly 1H-104 +NIS +E/ -W Local Coordinate Reference: Well 1H-104 Company: NADConversion 70° 21'29.809 N 149° 35'50.655 W 54.10 usft 1H-104 actual @ 92.79usft (Doyon 142) Project: Kuparuk River Unit TVD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) SRO: Kuparuk 1 H Pad MD Reference: 1H-1041.2 Well: IH -104 North Reference: True MWD+IFR2+HDS+MS r"Weibore netic Survey Calculation Method: Minimum Curvature Wellbore: 1H-1041-2 Database: OAKEDMPI Design: 11-1-1041-2 8/15/2018 17.04 Project Kuparuk River Unit, North Slope Alaska, United States 0.23 0.07 GYD-GCSS(1) US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Map System: 2.15 1.74 GYD-GC-SS(1) Using Well Reference Point Geo Datum: NAD 1927 (NADCON CONUS) 549,574.71 Using geodetic scale factor Mao Zone: Alaska Zone 04 12.81 5,980,775.39 won Well Position Position Uncertainly 1H-104 +NIS +E/ -W 0.00 usft 0.00 usft 0.00 usft Northing: Eating: Wellhead Elevation: 5,980,782.43 usft 548,568.74 usft usft Latitude: Longitude: Ground Level: 70° 21'29.809 N 149° 35'50.655 W 54.10 usft Direction (tett) Nam (usft) r) 38.69 0.00 0.00 1H-1041.2 1,901.24 IH -104 Srvy 3-SLB_MWD-INC-ONLY_F MWD -INC -ONLY 1,977.75 8,157.001H-104 Srvy 4 -SLB DUAL+GMAG+SA MWD+IFR2+HDS+MS r"Weibore netic Model Name MWD -INC -ONLY Sample Data Declination Dip Angle Field Strength 15,811.271H-1041-2 Srvy 3-SLB_DUAL+GMAG+S RrGM2018 8/15/2018 17.04 80.91 57,448 Design 11-1-1041-2 Audit Notes: Version: 1.0 vertical Section: Phase: ACTUAL Tie On Depth: 8,157.00 Depth From (TVD) +w -S +E1 -W Direction (tett) Nam (usft) r) 38.69 0.00 0.00 110.12 Survey Program Date Map From To Vertical (usft) (usft) Survey (Wellbore) Tool Name 130.47 1,098.561H-104 Srvy 1-SLB_GWD70(1 H-104PB GYD-GC-SS 1,194.67 1,804.101H-104 Srvy 2- SLB _MWD+GMAG(1 H- MWD+IFR-AK-CAZ-SC 1,901.24 1,901.24 IH -104 Srvy 3-SLB_MWD-INC-ONLY_F MWD -INC -ONLY 1,977.75 8,157.001H-104 Srvy 4 -SLB DUAL+GMAG+SA MWD+IFR2+HDS+MS 8,167.00 8,182.291 H1 041-2 Sly 1-SLB_MWD-INC-Only( MWD -INC -ONLY 8,189.00 6,549.001H-1041-2 Srvy 2- SLB_MWD(Standard MWD 8,579.00 15,811.271H-1041-2 Srvy 3-SLB_DUAL+GMAG+S MWD+IFR2+HDS+MS ltrvel/ MD Inc Ari TVD TVDSS (MR) (") r) (tam (us*) 38.69 0.00 0.00 38.69 54.10 130.47 0.03 108.52 130.47 37.68 170.09 0.12 87+41 170.09 77.30 259.84 2.03 116.87 259.82 167.03 357.41 4.01 124.19 357.25 264.46 449.01 5.79 114.28 448.51 355.72 540.15 6.91 118.50 539.09 446.30 631.94 8.38 116.36 630.06 537.27 71747 lam 118.44 719.34 626.55 Description Survey Date Gyrodata gyro single shots e/6/2018 10:471 MWD+IFRAKCAZSCC 8/6/2018 10:55:( MWD-INC_ONLY_FILLER 8/9/2018 10:05:( OWSG MWD + IFR2 + HDS + Multi -Station Correc8/9/2018 10:07:( MWD -INC ONLY_FILLER 9!7/2018 8:23:0 - MWD -Standard 9/7/2018 8:26:0 OWSG MWD +IFR2+HDS+Multi-Station Correc9/8/2018 8:26:0 104d201810:06:21AM Page 2 COMPASS 5000.14 Build 850 Map Map Vertical +WS +E/4111 Northing Eating DLS Section (MR) Want) (11) (R) (.11001 (R) Survey Tool Name 0.00 0.00 5,980,782.43 549,568.74 0.00 0.00 UNDEFINED -0.01 0.02 5,980,782.42 549,568.76 0.03 0.02 GYD-GC-SS 0) -0.01 0.07 5,980,782.42 549568.81 0.23 0.07 GYD-GCSS(1) -0.72 1.59 5,980,781.72 549,570.33 2.15 1.74 GYD-GC-SS(1) 3.42 5.95 5,980,779.05 549,574.71 2.06 6.76 GYD-GCSS(1) -7.12 12.81 5,980,775.39 549,SB1.60 2.14 14.48 GYD-GCSS(1) -11.63 21.82 5,980,770.95 549,590.64 1.33 24.49 GYD-GC-SS(1) -17.23 32.67 5,980,765.42 549,601.52 1.63 36.60 GYD-GC-SS(1) -24.16 45.96 5,980,758.58 549,614.85 2.57 51.46 GYD-GCSS(1) 104d201810:06:21AM Page 2 COMPASS 5000.14 Build 850 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 1H-104 Project: Kuparuk River Unit TVD Reference: She: Kuparuk 1H Pad MD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Well: 1H-104 North Reference: True Wellbore: 111-1041-2 Survey Calculation Method: Minimum Curvature 1H-ln4L2 Database: OAKEDMPl 10/8/2018 10:06:21AM Page 3 COMPASS SM. 14 Build 85D Survey Map Map Vertical MD (usft) 813.86 Inc r) 12.56 Aid (') 116.31 TVD (usft) 808.85 TVDSS (usft) 716.06 -NIS (usft) 32.60 +El -W (usft) 62.31 Northing (ft) 5,980,750.25 East}ng DLS Section Survey Tool Name (R) (°1100') (ft) 549,631.26 2.11 69.72 GYD-GCSS(1) 909.29 1,003.79 1,098.56 1,194.67 1,234.61 15.48 16.85 18.48 20.89 22.13 116.02 113.72 111.78 113.70 113.61 901.43 992.19 1,082.49 1,172.98 1,210.14 808.64 899.40 989.70 1,080.19 1117.35 -42.78 33.83 54.93 -77.47 33.34 83.06 106.94 133.46 163.30 176.71 5,980,740.20 5,98.729.32 5,980,718.39 5,980,706.05 5,900,700.27 549,652.07 549,676.02 549,702.61 549,732.53 549,745.98 3.06 1.60 1.83 2.60 3.11 92.71 GYD-GCSS(1) 118.93 GYD-GCSS(1) 147.65 GYD-GCSS (1) 179.98 MW13+1FR-AK-CAZSC (2) 194.60 MWD+IFR-AK-CAZ-SC(2) 1,329.20 1,421.11 1,517.95 1,613.27 1,708.42 25.32 29.49 33.20 33.72 33.08 113.89 113.16 112.62 113.53 113.61 1,296.72 1,378.30 1,460.99 1,540.51 1,619.95 1,203.93 1,285.51 1,368.20 1,447.72 1,527.16 418.67 -115.54 -135.12 -155.72 -176.66 211.54 250.33 296.73 345.08 393.09 5,98.685.17 5,980,668.56 5,98.649.29 5,980,629.01 5,980,608.39 549,780.91 549,819.80 549,866.33 549,914.81 549,962.95 3.37 4.55 384 0.76 0.67 232.58 MWD+IFR-AK-CAZ-SC(2) 274.80 MWD+IFR-AK-CAZSC (2) 325.10 MWD+IFR-AK-CAZ-SC(2) 377.59 MWD+IFR-AK-CAZSC (2) 429.87 MWD+IFR-AK-CAZ-SC(2) 1,804.10 1,901.24 1,977.75 2,007.00 2,037.00 33.67 37.21 39.23 40.35 41.52 115.86 118.0 117.71 117.25 116.92 1,699.85 1,778.99 1,839.09 1,861.57 1,884.23 1,607.06 1,686.20 1,746.30 1,768.78 1,791.44 -198.69 -224.23 -246.35 -254.98 -263.93 440.88 491.07 532.92 549.52 667.02 5,980,586.68 5,980,56147 5,98.539.64 5,980,531.11 5,98.522.28 550,010.89 550,061.23 550,103.22 550,119.89 550,137.44 1.43 3.86 2.65 3.96 3.97 482.33 MWD+IFR-AK-CAZ-SC(2) 538.23 MWD-INC_ONLY (3) 585.14 MWD+IFR2+HDS+MS(4) 603.70 MWD+IFR2+HDS+MS(4) 623.21 MWD+IFR2+HDS+MS(4) 2,067.00 2,097.00 2,127.00 2,157.00 2187.00 42.58 43.63 44.75 45.87 47.08 116.71 116.51 116.43 116.47 116.52 1,906.51 1,928.41 1,949.92 1,971.02 1,991.68 1,813.72 1,835.62 1,857.13 1,878.23 1,898.89 -273.00 -282.18 -291.50 -301.00 310.70 584.96 603.29 622.00 641.10 650.57 5,980,513.34 5,98.504.28 5,980,495.08 5.98.485.71 5,980,476.14 550,155.43 550,173.82 550,192.60 550,211.75 550,231.28 3.56 3.53 3.74 3.73 4.04 643.17 MWD+IFR2+HDS+M$(4) 663.64 MWD+IFR2+HDS+MS(4) 684.32 MWD+IFR2+HDS+MS(4) 705.52 MWD+IFR2+HDS+MS(4) 727.14 MWD+IFR2+HDS+MS(4) 2,217.00 2,247.00 2,277.00 2,307.00 2,337.00 48.40 49.68 50.84 51.95 53.10 116.44 116.16 115.84 115.63 115.68 2,011.85 2,031.52 2,050.70 2,069.42 2,087.67 1,919.06 1,938.73 1,957.91 1,976.63 1,994.88 320.60 530.64 -340.75 350.93 361.24 680.44 700.75 721.48 742.60 764.06 5,980,466.37 5,980,456.47 5,980,446.50 5,980,436.46 5,900,426.29 550,251.22 550,271.59 550,292.39 550,313.58 550,335.10 4.40 4.32 3.95 3.74 3.54 749.20 MWD+IFR2+HDS+MS (4) 77172 MWD+IFR2+HDS+MS(4) 794.67 MWD+IFR2+HDS+MS (4) 818.00 MWD+IFR2+HDS+MS(4) 841.70 MWD+IFR2+HDS+MS (4) 2,367.00 2,397.00 2,427.00 2,457.00 2,487.00 54.38 55.64 56.61 57.38 58.37 115.81 115.93 116.02 116.10 116.14 2,105.41 2,122.61 2,139.34 2,155.68 2,171.63 2,012.62 2,029.82 2,046.55 2,062.89 2,078.84 -371.74 362.47 393.38 404.43 415.61 785.85 807.96 830.36 852.96 875.77 5,980,415.93 5,960,405.35 5,980,394.69 5,980,383.69 5,980,372.66 550,355.96 550,379.14 550,401.60 550,424.27 550,447.15 4.28 4.21 3.24 2.58 3.30 865.77 MWD+IFR2+HDS+MS(4) 890.23 MWD+IFR2+HDS+MS (4) 91500 MWD+IFR2+HDS+MS(4) 940.03 MWD+IFR2+HDS+MS(4) 965.30 MWD+IFR2+HDS+MS(4) 2,517.00 2,547.00 2,577.00 2,607.00 2,637.00 59.50 60.42 61.29 62.12 63.06 115.95 115.63 115.29 114.85 114.32 2,187.11 2,202.13 2,216.74 2,230.96 2,244.77 2,094.32 2,109.34 2,123.95 2,138.17 2,151.98 426.90 438.20 449.46 460.65 471.73 898.66 922.24 945.90 969.82 994.04 5,980,361.53 5,900,350.39 5,98.339.28 5,980,328.25 5,980,317.33 550,470.31 550,493.77 550,517.50 550,541.50 550,565.78 3.81 3.20 3.06 3.05 3.50 990.86 MWD+IFR2+HDS+MS(4) 1,16.70 MWD+IFR2+HDS+MS(4) 1,042.79 MWD+IFR2+HDS+MS(4) 1,059.10 MWD+IFR2+HDS+MS(4) 1,095.65 MWD+IFR2+HDS+MS(4) 2,667.00 2,697.00 2,727.00 2,757.00 64.06 65.08 66.25 67.57 113.78 113.33 112.97 112.62 2,258.13 2,271.01 2,283.37 2,295.14 2,165.34 2,178.22 2,190.58 2,202.35 482.68 493.50 504.25 514.94 1,018.57 1,043.41 1,068.54 1,093.98 5,980,306.55 5,980,295.89 5,980,285.31 5,980,274.79 550,590.38 550,615.29 550,640.49 550,666.00 3.70 3.66 4.05 4.53 1,122.45 MWD+IFR2+HDS+M$(4) 1,149.50 MWD+IFR2+HDS+MS(4) 1,176.79 MWD+IFR2+HDS+MS(4) 1,204.36 MWD+IFR2+HDS+MS(4) 10/8/2018 10:06:21AM Page 3 COMPASS SM. 14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Weil 111-104 Project: Kuparuk River Unit TVD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Site: Kuparuk 1 H Ped MD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Well: 1H-104 North Reference: True Wellbore: 1H-1041-2 Survey Calculation Method. Minimum Curvature Design: 1H-1041-2 Database: OAKEDMPI Survey Map Map vertical M0 Inc Azi TVD NDSS +N15 +E/ -W Northing Easting DLS Section (usm 11 (1) (usft) (usft) (wft) (usft) (ft) (ft) (.1100') (ft) Survey Tool Name 2,787.00 68.78 112.39 2,30629 2,213.50 525.60 1,119.71 5,980,264.30 550,69179 4.10 1,232.18 MWD+IFR2+HDS+MS(4) 2,817.00 69.85 112.35 2,316.89 2,224,10 536.28 1,145.66 5,980,253.79 550,717.81 3,57 1,260,23 MWD+IFR2+HDS+MS(4) 2,847,00 70.90 112.35 2,326.96 2,234.17 547.03 1,171.80 5,980,243.22 550,744,02 3.50 1,288.6 MWD+IFR2+HDS+MS(4) 2,877.00 71.12 112.39 2,336.72 2,243.93 357.82 1,19B.03 5,980,232.60 550,770.32 0.74 1,316.81 MWD+IFR2+HDS+MS(4) 2,907.0 70.87 112.% 2,346.49 2,253.70 568.67 1,224,24 5,980,221.93 550,796.60 0.99 1,345.15 MWD+IFR2+HDS+MS (4) 2,937.00 70.73 112.76 2,356.36 2,263.57 579.58 1,250.38 5,980,211.19 550,822.81 0.78 1,373.45 MWD+IFR2+HDS+MS (4) 2,%7.00 71.42 112,94 2,366.09 2,273.30 -590.60 1,276.54 5,980,200.35 550,849.03 2.37 t 401.80 MWD+IFR2+HDS+MS (4) 2,997.00 72.16 113.02 2,375.46 2,282.67 501.73 1,302.77 5,980,189.40 550,875.34 2.48 1,430.26 MWD+IFR2+HDS+MS(4) 3,027.00 72.76 113.06 2,384.50 2,291.71 312.92 1,329.9 5,980,178.38 550,901.73 2.00 1458,83 MWD+IFR2+HDS+MS(4) 3,057.00 73.19 113.13 2,393.29 2,300.50 324.17 1,355.48 5,980,167.30 550,928.19 1.45 1,487.48 MWD+IFR2+HDS+MS(4) 3,087.00 73.23 113.36 2,401.95 2,309.16 335.51 1,381.87 5,980,156.14 550,954.65 0.75 1,516,15 MWD+IFR2+HDS+MS(4) 3,117.0 73.26 113.71 2,410,60 2,317.81 646.98 140B.21 5,980,144.85 550,981.06 1.12 1,544.83 MWD+IFR2+HDS+MS(4) 3,147.00 73.72 114.04 2,419.13 2,326.34 358.62 1,434.51 5,980,133.38 551,007.44 1.86 1,573.53 MWD+IFR2+HDS+MS(4) 3,177,00 74,22 114.10 2,427.41 2,334.62 -670.38 1460.83 5,980,121.79 551,033.84 1.68 1,602.30 MWD+IFR2+HDS+MS(4) 3,207.00 74.27 113.93 2,435.56 2,342,77 382.13 1,487.21 5,980,110.22 551,060.29 0.57 1,631.10 MWD+IFR2+HDS+MS(4) 3,237.0 74.45 113.75 2,443.65 2,350.% 693.81 1,513.63 5,980,098.72 551,086.78 0.83 1,659.93 MWD+IFR2+HDS+MS(4) 3,267.00 74.41 113.51 2,451.70 2,358,91 -705.39 1,540.11 5,980,087.31 551,113.33 0.78 1,688,78 MWD+IFR2+HDS+MS(4) 3,297.00 74.24 113.22 2,459.80 2,367.01 -716.85 1,5%.62 5,980,076.03 551,139.92 1,09 1,717.61 MWD+IFR2+HDS+MS(4) 3,327,00 74.32 112.91 2,467.93 2,375.14 -728,16 1,593.19 5,980,064.90 551,166.56 1.03 1746.45 MIND+IFR2+HDS+MS(4) 3,357.0 74.22 112.61 2,476,% 2,383.27 -739.33 1,619.82 5,980,053.90 551,193.26 1,02 1,775.30 MWD+IFR2+HDS+MS(4) 3,387.00 74.13 112.34 2,484.25 2,391.46 -750,37 1,646.49 5,980,043.05 551,220.00 0.92 1,804.14 MWD+IFR2+HDS+MS(4) 3,417.00 74,29 112.% 2,492.41 2,399.62 461.27 1,673.22 5,980,032.32 551,246.80 1.04 1,832.99 MV4D+IFR2+HDS+MS (4) 3,447.00 74.40 111,80 2,500.50 2,407.71 -772.05 1,700.02 5,980,021.71 551,273.66 0.91 1,%1.% MWD+IFR2+HDS+MS (4) 3,477.00 74.33 111.56 2,508.59 2,415,80 -782.73 1,726.% 5,980,011.22 551,300.58 0.80 1,890.74 MWD+IFR2+HDS+MS(4) 3,507.00 74.20 111.34 2,516.73 2,423.94 -793.29 1,753.74 5,980,000.83 551,327.52 0.83 1,919,61 MWD+IFR2+HDS+MS(4) 3,531-00 73.93 111.12 2,524,96 2,432.17 -803.74 1,780.63 5,979,990.57 551,354.48 1,14 1,948.45 MWD+IFR2+HDS+MS(4) 3,567.0 73.69 110.92 2,533.33 2,440.54 -814,07 1,807.52 5,979,980.41 551,381.43 1.02 1,977.26 MWD+IFR2+HDS+MS(4) 3,597.00 73.76 110.74 2,541.73 2,448.94 -824.31 1,834.44 5,979,970.35 551,408.41 0.62 2,006.05 MWD+IFR2+HDS+MS(4) 3,627.00 7377 110.57 2,550.12 2,457.33 41MAB 1,%1.39 5,979,%0.37 551,435.43 0.55 2,034.85 MWD+IFR2+HDS+MS(4) 3,657.00 73.86 110,48 2,558.48 2,465.69 344.58 1,888,37 5,979,950.45 551,462.48 0.42 2,063.66 MWD+IFR2+HDS+MS (4) 3,687.00 73.77 110.44 2,566.% 2,474,D6 654.65 1,915.37 5,979,940.56 551,489.53 0.33 2,092.48 MVC+IFR2+HDS+MS(4) 3,717.0 73.67 110.40 2,575.26 2,482.47 -864.70 1,942.35 5,979,930.69 551,516.58 0.36 2,121.27 MWD+IFR2+HDS+MS(4) 3,747.00 73.89 110.46 2,583.64 2,490.85 -874.75 1,969.35 5,979,920.82 551,543.64 0.76 2,150,08 MWD+IFR2+HDS+MS(4) 3,777.0 73.58 110.60 2,592,04 2,499.25 -884.85 1,9%.32 5,979,910.90 551,570.67 1.13 2,178.88 MWD+IFR2+HDS+MS(4) 3,807.00 73.22 110.74 2,600.61 2,507.82 -895,00 2,023.22 5,979,900.93 %1,597.64 1.28 2,207.62 MWD+IFR2+HDS+MS(4) 3,837.00 73.72 110.88 2,609.14 2,516.35 -905.22 2,%0.10 5,979,890.89 551,624,59 1.73 2,236.38 MWD+IFR2+HDS+MS (4) 3,867.00 73.59 111.00 2.617.59 2,524.80 -915.50 2,076.99 5,979,880,78 551,651,54 0.58 2,265.17 MW0+IFR2+HDS+MS (4) 3,897.00 73,33 111.13 2,626.13 2,533.34 -925.84 2,103.82 5,979,870.62 551,678.44 0.96 2,293.92 MWD+IFR2+HDS+MS(4) 3,927.00 73.55 111.24 2,634.68 2,541.89 .36.23 2,130.63 5,979,860.41 551,705.32 0.81 2,322.67 MWD+IFR2+HDS+MS(4) 3,957.00 73.44 111,35 2,643.20 2,560.41 -946.68 2,15743 5,979,850.14 551,732.18 0.51 2,351.43 MWD+IFR2+HDS+MS(4) 10W018 10:06:21AM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well iH-104 Project: Kuparuk River Unit TVD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Well: IH -104 North Reference: True Wellbore: 11H-1041-2 Survey Calculation Method: Minimum Curvature Design: 11-1-1041-2 Database: OAKEDMPt Survey 10/8@018 10:06:21AM Page 5 COMPASS 5000.14 Build 850 Map App Vertical MD Inc A:i TVD TVDSS +NIS +E/ -W Northing Eastirrg DLS Section (uslt) (') V) (usR) (usft) (usR) (ustt) (R) (R) (°1100') (R) Survey Toot Name 3,987.00 73.38 11146 2,651.77 2,558.96 -957.17 2,184.20 5,979,839.83 551,759.02 0.38 2,380.17 MWD+IFR2+HDS+MS(4) 4,017.00 73.38 111.51 2,660.35 2,567.55 -967.70 2,210.95 5,979,829.48 551,785.83 0.19 2,408.91 MWD+IFR2+HDS+MS(4) 4,047.00 73.44 111.43 2,668.91 2,576.12 -978.22 2,237.71 5,979,819.14 551,812.66 0.32 2,437.66 MWD+IFR2+HDS+MS(4) 4,077.00 73.29 111.32 2,677.50 2,584.71 -988.70 2,264.48 5,979,808.84 551,839.49 0.61 2,466.39 MWD+IFR2+HDS+MS(4) 4,107.00 73.46 111.22 2,686.08 2,593.29 -999.12 2,291.26 5,979,798.59 551,866.34 0.65 2,495.13 MWD+IFR2+HDS+MS(4) 4,137.00 73.64 111.16 2,694.58 2,601.79 -1,009.52 2,318.09 5,979,788.37 551,893.24 0.63 2,523.9() MWD+IFR2+HDS+MS(4) 4,167.00 73.40 111.13 2,703.09 2,610.30 -1,019.90 2,344.92 5,979,778.17 551,920.13 0.81 2,552.66 1AWD+IFR2+HDS+MS(4) 4,197.00 73.50 111.07 2,711.69 2,618.85 -1,030.25 2,371.75 5,979,767.99 551,947.03 0.38 2,581.42 MWD+IFR2+HDS+MS(4) 4,227.00 73.61 110.94 2,720.13 2,627.34 -1,040.57 2,398.61 5,979,757.86 551,973.95 0.55 2,610.19 MWD+IFR2+HDS+MS(4) 4,257.00 73.43 110.75 2,728.64 2,635.85 -1,050.80 2,425.50 5,979,747.80 552,000.90 0.85 2,638.95 MWD+IFR2+HDS+MS(4) 4,287.00 73.30 110.56 2,737.23 2,644.44 -1,060.94 2,452.39 5,979,737.84 552,027.86 0.75 2,667.69 MWD+IFR2+HDS+MS(4) 4,317.00 73.34 110.39 2,745.84 2,653.05 -1,071.00 2,479.32 5,979,727.97 552,054.85 0.56 2,696.43 MWD+IFR2+HDS+MS(4) 4,347.00 73.38 110.23 2,754.43 2,661.64 -1,080.97 2,506.27 5,979,718.17 552,081.87 0.53 2,725.18 MWD+IFR2+HDS+MS(4) 4,377.00 73.48 110.07 2,762.98 2,670.19 -1,090.88 2,533.27 5,979,708.45 552,108.92 0.61 2,763.93 MWD+IFR2+HDS+MS (4) 4,407.00 73.40 110.10 2,771.53 2,678.74 -1,100.75 2,560.27 5,979,698.75 552,135.99 0.28 2,782.68 MWD+IFR2+HDS+MS (4) 4,437.00 73.36 110.34 2,780.12 2,687.33 -1,110.69 2,587.25 5,979,688.98 552,163.03 0.78 2,811.43 MWD+IFR2+HDS+MS(4) 4,467.00 73.15 110.60 2,788.76 2,695.97 -1,120.73 2,614.16 5,979,679.13 552,190.01 1.09 2,840.16 MWD+IFR2+HDS+MS(4) 4,497.00 73.16 110.83 2,797.45 2,704.66 -1,130.89 2,641.02 5,979,669.15 552,216.93 0.73 2,868.87 MWD+IFR2+HDS+MS(4) 4,527.00 73.31 111.00 2,806.11 2,713.32 -1,141.14 2,667.85 5,979,659.07 552,243.82 0.74 2,897.59 MWD+IFR2+HDS+MS(4) 4,557.00 73.32 111.16 2,814.72 2,721.93 -1,151.48 2,694.66 5,979,648.92 552,270.70 0.51 2,926.32 MWD+IFR2+HDS+MS(4) 4,587.00 73.28 111.36 2,823.34 2,730.55 -1,161.90 2,721.44 5,979,638.68 552,297.55 0.65 2,955.05 MWD+IFR2+HDS+MS(4) 4,617.00 73.39 111.62 2,831.94 2,739.15 -1,172.43 2,748.19 5,979,628.33 552,324.36 0.91 2,983.79 MWD+IFR2+HDS+MS(4) 4,647.0 73.46 111.91 2,840.50 2,747.71 -1,183.09 2,774.89 5,979,617.84 552,351.13 0.96 3,012.53 MWD+IFR2+MDS+MS(4) 4,677.00 73.31 112.19 2,849.08 2,756.29 -1,193.88 2,801.53 5,979,607.23 552,377.84 1.02 3,041.26 MWD+IFR2+HDS+MS(4) 4,707.0 73.35 112.45 2,857.69 2,764.90 -1,204.80 2,828.12 5,979,596.49 552,404.50 0.84 3,069.99 MWD+IFR2+HDS+MS(4) 4,737.00 73.29 112.71 2,886.30 2,773.51 -1,215.83 2,854.65 5,979,585.63 552,431.10 0.85 3,098.69 MWD+IFR2+HDS+MS (4) 4,767.00 73.33 112.96 2,874.91 2,782.12 -1,226.98 2,881.14 5,979,574.66 552,457.65 0.81 3,127.39 MWD+iFR2+HDS+MS(4) 4,797.00 73.32 113.14 2,883.52 2,790.73 -1,238.24 2,907.58 5,979,563.58 552,484.17 0.58 3,156.09 MWD+IFR2+HDS+MS(4) 4,827.00 73.33 113.28 2,892.13 2,799.34 -1,249.56 2,934.00 5,979,552.43 552,510.65 0.45 3,184.79 MWD+IFR2+HDS+MS(4) 4,857.00 73.26 113.40 2,900.75 2,807.96 -1260.95 2,960.38 5,979,54122 552,537.11 0.45 3,213.48 MWD+IFR2+HDS+MS(4) 4,887.00 73.23 113.39 2,909.40 2,816.61 -1,272.35 2,986.74 5,979,529.99 552,563.55 0.10 3,242.16 MWD+IFR2+HDS+MS(4) 4,917.00 73.23 113.26 2,918.06 2,825.27 -1,21Kl12 3,013.12 5,979,518.80 552,590.00 0.41 3,270.84 MWD+IFR2+HDS+MS(4) 4,947.00 73.08 113.12 2,926.75 2,833.96 -1,295.03 3,039.51 5,979,507.67 552,616.46 0.67 3,299.51 MWD+IFR2+HDS+MS(4) 4,977.00 73.13 113.01 2,935.47 2,842.68 -1,306.28 3,065.92 5,979,495.60 552,642.94 0.39 3,328.18 MWD+IFR2+HDS+MS(4) 5.07.00 73.36 112.94 2,944.12 2,851.33 -1,317.49 3,092.37 5,979,485.56 552,669.46 0.80 3,356.87 MWD+IFR2+HDS+MS(4) 5,037.00 73.47 112.87 2,952.68 2,859.89 -1,328.68 3,118.86 5,979,474.55 552,696.02 0.43 3,385.58 MWD+IFR2+HDS+MS(4) 5,057.00 73.63 112.70 2,961.17 2,868.38 -1,339.82 3,145.38 5,979,463.58 552,722.61 0.76 3,414.33 MWD+IFR2+HDS+MS(4) 5,097.00 73.67 112.35 2,969.62 2,876.83 -1,350.85 3,171.97 5,979,452.73 552,749.27 1.13 3,443.09 MWD+IFR2+HDS+MS(4) 5,127.00 73.61 111.95 2,978.07 2,885.28 -1,361.71 3,198.63 5,979,442.05 552,776.00 1.20 3,471.85 MWD+IFR2+MDS+MS(4) 5,157.0 73.70 111.71 2,986.51 2,893.72 -1,372.42 3,225.35 5,979,431.51 552,802.79 0.91 3,500.63 MWD+IFR2+HDS+MS(4) 10/8@018 10:06:21AM Page 5 COMPASS 5000.14 Build 850 ConocoPhiliips Definifive Survey Report Company: NADConversion Local Coordinate Reference: Well lH-104 Project Kupamk River Unit TVD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Sita: Kuparuk 1 H Pad MD Reference: 1H-104 actual (P 92.79usft (Doyon 142) Well: 11-1-104 North Reference: True Wellbore: 11-1-1041-2 Survey Calculation Method: Minimum Curvature Design: 11-1-1041-2 Database: OAKEDMPI Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1S +E1 -W Northing Easting DLS Section (US11" (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 5,187.00 73.65 111.73 2,994.95 2,902.16 -1,383.08 3,252.10 5,979421.04 552,82960 0.18 3,529.41 MWD+IFR2+MDS+MS(4) 5,217.00 73.57 111.84 3,003.41 2,910.62 -1,393.76 3,278.82 5,979,410.53 552,855.40 0.44 3,558.18 MWD+IFR2+HDS+MS(4) 5,247.00 73.62 111.97 3,011.88 2,919.09 -1,404.49 3,305.52 5,979,399.98 552,883.16 0.45 3,586.94 MWD+IFR2+HDS+MS(4) 5,277.00 73.66 112.22 3,020.33 2,927.54 -1,415.32 3,332.20 5,979,389.33 552,909.90 0.81 3,615.71 MWD+IFR2+HDS+MS(4) 5,307.0 73.70 112.52 3,028.76 2,935.97 -1,426.28 3,358.82 5,979,37B.55 552,936.60 0.97 3,644.48 MWD+IFR2+HDS+MS(4) 5,337.00 73.62 112.80 3,037.20 2,944.41 -1,437.37 3,385.39 5,979,367.63 552,963.23 0.93 3,673.24 MWD+IFR2+HDS+MS(4) 5,367.00 73.58 112.90 3,045.67 2,952.88 -1,448.55 3,411.91 5,979,35663 552,989.83 0.35 3,701.99 MWD+1FR2+HDS+MS(4) 5,397.00 73.67 112.87 3,054.13 2,961.34 -1,459.74 3,438.42 5,979,345.62 553,016.41 0.31 3,730.74 MWD+IFR2+HDS+MS(4) 5,427.0 73.71 112.86 3,062.56 2,96977 -1,470.93 3,464.95 5,979,334.61 553,043.02 0.14 3,759.50 MWD+IFR2+HDS+MS (4) 5,457.00 73.77 112.99 3,070.96 2,978.17 -1,482.15 3,491.48 5,979,323.56 553,069.61 0.46 3,788.26 MWD+IFR2+HDS+MS(4) 5,487.0 73.86 113.23 3,079.32 2,986.53 -1,493.45 3,517.98 5,979,312.43 553,096.18 0.82 3,817.03 MWD+1FR2+HDS+MS(4) 5,517.0 73.71 113.48 3,087.70 2,994.91 -1,504.87 3,544.43 5,979,301.19 553,122.70 0.94 3,845.79 MWD+IFR2+HDS+MS(4) 5,547.00 73.70 113.64 3,096.11 3,003.32 -1,516.38 3,570.82 5,979,289.86 553,149.17 0.51 3,874.54 M1AD+1FR2+HDS+MS(4) 5,577.00 73.63 113.67 3,104.55 3,011.76 -1,527.93 3,597.19 5,979,278.48 553,175.61 0.25 3,903.27 MWD+IFR2+HDS+MS(4) 5,607.00 73.62 113.69 3,113.01 3,020.22 -1,539.49 3,623.55 5,979,267.10 553,202.05 0.07 3,932.00 MWD+IFR2+HDS+MS(4) 5,637.00 73.73 113.82 3,121.44 3,028.65 -1,551.09 3,649.90 5,979,255.67 553,228.47 0.55 3,960.73 MWD+IFR2+HDS+MS(4) 5,667.00 73.82 114.13 3,129.82 3,037.03 -1,562.80 3,676.22 5,979,244.15 553,254.86 1.04 3,989.47 MWD+IFR2+HDS+MS(4) 5,697.00 73.79 114.48 3,138.19 3,045.40 -1,574.65 3,702.48 5,979,232.46 553,281.20 1.12 4,018.20 MWD+IFR2+HDS+MS(4) 5,727.00 73.78 114.83 3,146.57 3,053.78 -1,586.67 3,728.65 5,979,220.62 553,307.45 1.12 4,046.92 MWD+IFR2+HDS+MS (4) 5,757.00 73.82 115.15 3,154.94 3,062.15 -1,598.84 3,754.77 5,979,208.62 553,333.64 1.03 4,075.63 MWD+IFR2+HDS+MS(4) 5,787.00 73.84 115.46 3,163.29 3,070.50 -1,611.16 3,780.82 5,979,195.48 553,359.77 0.99 4,104.32 MWD+IFR2+HDS+MS(4) 5,817.00 73.89 115.74 3,171.63 3,078.84 -1,623.61 3,806.81 5,979,184.20 553,385.84 0.91 4,133.01 MWD+IFR2+HDS+MS(4) 5,847.0 73.90 115.90 3,179.95 3,087.16 -1,636.16 3,832.75 5,979,171.82 553,411.86 0.51 4,161.69 MWD+IFR2+HDS+MS(4) 5,877.00 73.69 115.99 3,188.32 3,095.53 -1,646.77 3,858.66 5,979,159.39 553,437.85 0.76 4,190.35 MWD+19R2+HDS+MS (4) 5,907.0 73.80 116.07 3,196.72 3,103.93 -1,661.41 3,884.54 5,979,146.93 553,463.81 0.45 4,219.00 MWD+IFR2+HDS+MS(4) 5,937.00 73.88 116.06 3,205.07 3,112.28 -1,674.07 3,910.42 5,979,134.44 553,489.77 0.27 4,247.65 MWD+IFR2+HDS+MS(4) 5,967.00 73.96 115.97 3,213.38 3,120.59 -1,686.71 3,936.33 5,979,121.97 553,515.76 0.39 4,276.33 MWD+IFR2+HDS+MS(4) 5,997.00 73.82 115.88 3,221.70 3,128.91 -1,699.31 3,962.25 5,979,109.54 553,541.76 0.55 4,305.0 MWD+IFR2+HDS+MS (4) 6,027.00 73.67 115.68 3,230.10 3,137.31 -1,711.84 3,988.18 5,979,097.19 553,567.77 0.81 4.333.66 MWD+IFR2+HDS+MS(4) 6,057.00 73.44 115.36 3,238.60 3,145.81 -1,724.23 4,014.15 5,979,084.96 553,593.82 1.28 4,362.31 MW1)+1FR2+HDS+MS(4) 6,087.00 73.19 115.04 3,247.21 3,154.42 -1,736.47 4,040.15 5,979,072.90 553,619.90 1.32 4,39D.93 MWD+IFR2+HDS+MS(4) 6,117.00 73.23 114.70 3,255.87 3,163.08 -1,748.55 4,066.21 5,979,061.00 553,646.03 1.09 4,419.56 MWD+1FR2+HDS+MS(4) 6,147.00 73.45 114.35 3,264.48 3,171.69 -1,760.48 4,092.35 5,979,049.24 553,672.26 1.34 4,448.21 MWD+IFR2+HDS+MS(4) 6,177.00 73.40 113.99 3,273.03 3,180.24 -1,772.25 4,116.59 5,979,037.64 553,698.56 1.16 4,476.89 MWN+1FR2+HDS+MS(4) 6207.00 73.38 113.61 3,281.61 3,188.82 -1,783.86 4,144.89 5,979,026.21 553,724.94 1.12 4,505.58 MWD+IFR2+HDS+MS(4) 6,237.00 73.48 113.30 3,200.16 3,197.37 -1,795.31 4,171.26 5,979,014.94 553,751.38 1.14 4,534.29 MWD+IFR2+HDS+MS(4) 6,267.00 73.36 112.% 3,298.73 3,205.94 -1,806.60 4,197.70 5,979,003.82 553,777.90 1.16 4,563.00 MWD+IFR2+HDS+MS(4) 6,297.00 73.24 112.60 3,307.35 3,214.56 -1,81773 4,224.20 5,978,992.87 553,804.46 1.22 4,591.70 MWD+IFR2+HDS+MS(4) 6,327.0 73.34 112.17 3,315.97 3,223.18 -1,828.67 4,250.76 5,978,982.10 553,031.10 1.41 4,620.41 MWD+IFR2+HDS+MS(4) 6,357.00 73.44 111.72 3,324.55 3,231.76 -1,839.42 4,277.43 5,978,971.54 553,857.83 1.48 4,649.15 MWD+IFR2+HDS+MS(4) 10,W01810:06:21AM Page 6 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 1H-104 Project: Kuparuk River Unit TVD Reference: 1H-104 actual @ 92.79usft (Doyon 142) SRO: Kuparuk 1H Pad MD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Well: 11-1-104 North Reference: True Wellbom: 1H -104L2 Survey Calculation Method: Minimum Curvature Dealgn: 1H-1041-2 Database: OAKEDMPI Survey 1648/2018 f0:06:21AM Page 7 COMPASS 5000.14 Build 85D Map Mop Vertical MD Inc An TVD TVDSS +WS +FJ -W Northing Seating DIB Section (usft) (1) V) (usft) (usft) (waft) (usft) (ft) (ft) ('/1001 (It) Survey Tool Name 6,387.00 73.36 111.33 3,333.12 3,240.33 -1,849.97 4,304.17 5,978,%1.17 553,884.64 1.27 4,677.B9 MWD+IFR2+HDS+MS (4) 6,417.00 73.27 111.27 3,341.73 3,248.94 -1,%0.40 4,330.95 5,978,950.91 553,911.48 0.36 4,706.62 MWD+IFR2+HDS+MS (4) 6,447.00 73.44 111.41 3,350.32 3,257.53 -1,870.86 4,357.72 5,978,940.63 553,938.32 0.72 4,735.36 MWD+IFR2+HDS+MS (4) 6,477.00 73.38 111.55 3,358.89 3,266.10 -1,881.39 4,384.47 5,978,930.28 553,%5.14 0.49 4,764.10 MWD+IFR2+HDS+MS(4) 6,507.00 73.42 ill+% 3,367.46 3,274.67 -1,891.95 4,411.21 5,978,919.89 553991.95 0.14 4,792,84 MWD+IFR2+HDS+MS(4) 6,537.00 73.47 111.48 3,376.01 3,283.22 -1,902.50 4,437.97 5,978,909.52 554,018.77 0.31 4,821.59 MWD+IFR2+HDS+MS(4) 6,567.00 73.40 111.40 3,384.56 3,291.77 -1,913.01 4,464.73 5,978,899.19 554,045.60 0.35 4,850.33 MWD+IFR2+HDS+MS(4) 6,597.00 73.61 111.25 3,393.08 3,300.29 -1,923.47 4,491.53 5,978,888.91 554,072.46 0.85 4,879.69 MWD+IFR2+HDS+MS(4) 6,627.00 73.57 111.04 3,401.56 3,308.77 -1,933.85 4,518.37 5,978,878.70 554,099.37 0.68 4,97,87 MWD+IFR2+HDS+MS(4) 6,657.00 73.54 110.82 3,410.05 3,317.26 -0,944.13 4,545.24 5,978.WB.61 554,126.30 0.71 4,936.64 MWD+IFR2+HDS+MS(4) 6,687.00 73.62 110.65 3,418.53 3,325.74 4,954.32 4,672.15 5,978,858.59 554,153.28 0.58 4,%5.41 MWD+IFR2+HDS+MS(4) 6,717.00 73.61 110.58 3,426.99 3,334.20 -1,964.46 4,599.09 5,978,848.64 554,180.28 0.26 4,994.19 MWD+IFR2+HDS+MS(4) 6,747.0 73.57 110.52 3,435.47 3,342.68 -1,974.56 4,626.04 5,978,838.72 554,207.29 0.23 5,022.97 MWD+IFR2+HDS+MS(4) 6,777.00 73.57 110.35 3,443.95 3,351.16 -1,984.61 4,653.00 5,978,828.85 554,234.32 0.54 5,051.74 MWD+IFR2+HDS+MS(4) 6,807.0 73.63 109.97 3,452.42 3,359.63 -1,994.53 4,6BO.02 5,978,819.11 554,261.40 1.23 5,080.52 MWD+IFR2+HDS+MS(4) 6,637.00 73.54 109.64 3,460.90 3,368.11 -2,004.25 4,707.10 5,978,809.56 554,288.54 1.41 5,109.30 MWD+IFR2+HDS+MS(4) 6,867.00 73.49 109.18 3,469.41 3,376.62 -2,013.79 4,734.24 5,978,800.21 554,315.74 1.16 5,138.6 MWD+IFR2+HDS+MS(4) 6,897.0 73.38 109.OB 3,477.97 3,385.18 -2,023.21 4,761.41 5,978,790.97 554,342.97 0.49 5,166.81 MWD+IFR2+HDS+MS(4) 6,927.00 73.48 109.07 3,486.52 3,393.73 -2,032.61 4,788.58 5,978,781.75 554,370.20 0.33 5,195.55 MWD+IFR2+HDS+MS(4) 6,957.00 73.67 109.09 3,495.00 3,402.21 -2,042.02 4,815.78 5,978,772.52 554,397.46 0.64 5,224.39 MWD+IFR2+HDS+MS(4) 6,987.00 73.69 109.24 3,503.43 3,410.64 -2,D51.47 4,842.97 5,978,763.25 554,424.71 0.48 5,253.12 MWD+IFR2+HDS+MS(4) 7,017.00 73.62 109.47 3,511.88 3,419.09 -2,061.01 4,870.13 5,978,753.89 554,451.93 0.77 5,2B1.91 MWD+IFR2+HDS+MS(4) 7,047.0 73.63 109.69 3,520.33 3,427.64 -2,070.65 4,897.25 5,978,744.43 554,479.11 0.70 5,310.69 MWD+IFR2+HDS+MS(4) 7,077.00 73.67 109.89 3,528.78 3,435.99 -2,080.40 4,924.34 5,978,734.86 554,5W.26 0.65 5,339.48 MWD+IFR2+HDS+MS(4) 7,107.W 73.57 110.08 3,537.24 3,444.45 -2,090.24 4,961.39 5,978,725.20 554,533.37 0.69 5,368.26 MWD+IFR2+HDS+MS(4) 7,137.00 73.62 110.25 3,545.71 3,45292 -2,100.16 4,978.40 5,978,715.46 554,560.45 0.57 5,397.04 MWD+IFR2+HDS+MS(4) 7,167.W 73.65 110.29 3,554.17 3,461.38 -2,110.13 5,D05.41 5,978,705,67 554,587.51 0.16 5,425.82 MWD+IFR2+HDS+MS(4) 7,197.07 73.60 110.17 3,562.62 3,469.83 -2,120.08 5,032.41 5,978,695.90 554,614.58 0.42 5,454.60 MWD+IFR2+HDS+MS(4) 7,227.W 73.84 110.04 3,571.03 3,478.24 -2,129.98 5,D59.45 5,978,686.18 554,641.69 0.90 5,483.40 MWD+IFR2+HDS+MS(4) 7,257.00 74.75 109.63 3,579.15 3,486.36 -2,139.78 5,086.62 5,978,676.56 554.66&91 3.31 5,512.28 MWD+IFR2+HDS+MS(4) 7,287.00 75.63 108.83 3,586.82 3,494.07 -2,149.33 5,114.01 5,978,667.19 554,6%.36 3.91 5,541.28 MWD+IFR2+HDS+MS(4) 7,317.00 76.08 107.97 3,594.15 3501.% -2,158.52 5,141.61 5,978,658.19 554,724.02 3.16 5,570.36 MWD+IFR2+HDS+MS (4) 7,347.00 76.14 107.16 3,601.36 3,508.57 -2,167.30 5,169.37 5,978,649.59 554,751.84 2.63 5,599.45 MWD+IFR2+HDS+MS(4) 7,377.00 76.04 105.47 3.608.57 3,515.78 -2,175.73 5,197.25 5,978,641.35 554,779.77 2.26 5,62B.52 MWD+IFR2+HDS+MS(4) 7,407.00 75.64 105.80 3,615.91 3,523.12 -2,183.81 5,225.19 5,978,633.45 554,807.76 2.54 5,657.54 MWD+IFR2+HDS+MS(4) 7,437.00 75.00 105.07 3,623.51 3,530.72 -2,191.53 5,253.17 5,978,625.93 554,835.78 3.27 5,68646 MWD+IFR2+11DS+MS(4) 7.4 TW 74.49 103.91 3,631.40 3,538.61 -2.198.76 5,281.19 5,978,618.88 554,863.85 3.98 5,715.26 MWD+IFR2+HDS+MS(4) 7,497.07 74.59 102.64 3,639.40 3,546.61 -2,205.40 5,309.33 5,978,612.43 554,892.03 4.09 5,743.97 MWD+IFR2+HDS+MS(4) 7,527.W 75.07 101.38 3,647.25 3,554.46 -2,211.42 5,337.65 5,978,606.59 554,920.39 4.36 5,772.63 MWD+IFR2+HDS+MS(4) 7,557.07 75.66 100.36 3,654.83 3,562.04 -2,216.90 5,366.16 5,978,601.31 554,948.93 383 5,801.28 MWD+IFR2+HDS+MS(4) 1648/2018 f0:06:21AM Page 7 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordlnate Reference: Well 1H-104 Project: Kuparuk River Unit TVD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) SRO: Kuparuk 1 H Pad MD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Well: 1H-104 North Reference: True Wellbore: 1H-1041-2 Survey Calculation Method Minimum Curvature Design: 111-10412 Database: OAKEDMPI Survey 101WO18 10'06:21AM Page 8 COMPASS 5000 14 Build 85D Map Nap Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting OLS Section (usft) (°) P) (usft) (usft) (usft) (usft) (11) (1t) P/1001 (ft) Survey Tool Name 7,587.00 76.67 99.52 3,66200 3,669.21 -2,221.92 5,394.85 5,978,596.47 554,977.65 4.33 5,829.95 MWD+IFR2+HDS+MS(4) 7,617.00 77.66 98.72 3,668.67 3,575.88 -2,226.56 5,423.73 5,978,592.03 555,006.56 4.20 5,858.66 MWD+IFR2+HDS+MS(4) 7,647.00 77.74 97.57 3,675.06 3,582.27 -2,230.71 5,452.75 5,978,588.07 555,035.60 3.75 5,887.34 MWD+IFR2+HDS+MS(4) 7,677.00 76.97 96.18 3,681.63 3,588.84 -2,234.22 5,481.81 5,978,584.75 555,064.68 5.20 5,915.83 MWD+IFR2+HDS+MS (4) 7,707.00 76.42 95.01 3,688.53 3,595.74 -2,237.06 5,510.86 5,978,582.10 555,093.75 4.21 5,944.09 MWD+IFR2+HDS+MS (4) 7,737.00 76.21 93.80 3,695.63 3,602.84 -2,239.30 5,539.92 5,978,580.05 555,122.82 3.98 5,972.15 MWD+IFR2+HDS+MS(4) 7,767.00 76.15 92.39 3,702.80 3,610.01 -2,240.88 5,569.01 5,978,578.67 555,151.92 4.57 6,000.00 MWD+IFR2+HDS+MS(4) 7,797.00 76.26 90.92 3,709.95 3,617.16 -2,241.72 5,598.13 5,978,578.02 555,181.04 4.77 6,027.64 MND+IFR2+HDS+MS(4) 7,827.00 76.47 89.20 3,717.02 3,624.23 -2,241.75 5,627.29 5,978,578.19 555,210.19 5.62 6,055.02 MND+IFR2+HDS+MS (4) 7,857.00 76.61 87.30 3,724.01 3,631.22 -2,240.86 5,656.45 5,978,579.27 555,239.34 6.18 6,082.09 MND+IFR2+HDS+MS (4) 7,887.00 76.83 85.81 3,730.90 3,638.11 -2,239.10 5,685.59 5,978,581.22 555,268.47 4.89 6,108.85 MND+IFR2+HDS+MS(4) 7,917.00 77.40 84.41 3,737.59 3,644.80 -2,236.61 5,714.73 5,978,583.90 555,297.59 4.93 6,135.36 MWD+IFR2+HDS+MS(4) 7,947.00 78.05 82.74 3,743.97 3,651.18 -2,233.33 5,743.86 5,978,587.38 555,326.69 5.86 6,161.58 MWD+IFR2+HDS+MS(4) 7,977.00 78.51 81.08 3,750.06 3,657.27 -2,229.19 5,772.94 5,978,591.70 555,355.74 5.63 6,187.46 MWD+IFR2+HDS+MS(4) 8,007.00 78.91 79.43 3,755.93 3.663.14 -2,224.21 5,BD1.93 5,978,595.87 555,384.70 5.56 6,212.97 MWD+IFR2+HDS+MS(4) 8,037.00 79.38 78.49 3,761.58 3,668.79 -2,218.57 5,830.85 5,978,602.71 555,413.58 3.45 6,238.18 MND+IFR2+HDS+MS (4) 8,067.00 79.62 77.91 3,767.05 3,674.26 -2,212.54 5,859.72 5,978,608.93 555,442.41 2.06 6,263.22 MND+IFR2+HDS+MS (4) 8,097.00 79.44 77.39 3,772.50 3,679.71 -2,206.23 5,888.54 5,978,615.43 555,471.18 let 6,288.11 MND+IFR2+HDS+MS(4) 8,127.00 79.47 77.20 3,777.99 3,685.20 -2,199.74 5.917.31 5,978,622.11 555,499.90 0.63 6,312.89 MND+IFR2+HDS+MS(4) 8,157.00 79.34 77.19 3,783.51 3,690.72 -2,193.21 5,946.07 5,978,628.83 555,528.61 0.43 6,337.64 MWD+IFR2+HDS+MS(4) 8,167.00 79.43 77.18 3,785.35 3,692.56 -2,191.03 5,955.65 5,978,631.07 555,538.18 0.91 6,345.89 MWD -INC -ONLY (5) 8,182.29 81.15 76.50 3,787.93 3,695.14 -2,187.60 5,970.33 5,978,634.60 555,552.83 12.07 6,358.49 MWD-INC_ONLY (5) 8,189.00 81.56 76.62 3,788.94 3,696.15 -2,186.05 5,976.78 5,978,636.19 555,559.27 6.36 6,364.02 MWD (6) 8,219.00 83.47 76.51 3,792.85 3,700.06 -2,179.14 6,005.71 5,978,643.29 555,588.15 6.38 6,388.80 MWO(6) 8,249.00 85.32 76.50 3,795.78 3,702.99 -2,172.18 6,034.74 5,978,650.45 555,617.13 6.17 6,413.66 MW) (6)l 8,279.00 88.63 76.07 3,797.36 3,704.57 -2,165.07 6,063.84 5,978,657.74 555,646.18 11.13 6,438.54 MWD (6) 8,309.00 90.94 76.78 3,797.47 3,704.68 -2,158.03 6,093.00 5,978,664.97 555,675.29 8.06 6,463.50 MM (6) 8,339.00 90.33 77.26 3,797.14 3,704.35 -2,151.30 6,122.23 5,978,671.90 555,704.47 2.59 6,488.63 MWD (6) 8,369.00 89.58 76.56 3,797.16 3,706.37 -2,144.50 6,151.45 5,978,678.89 555,733.65 3.42 6,513.73 MWD (6) 8,399.06 88.20 76.72 3,797.74 3,704.95 -2,137.57 6,180.63 5,978,686.01 555,762.78 4.63 6,538.74 MWO (6) 8,429.00 87.87 75.94 3,798.77 3,705.98 -2,130.49 6,209.76 5,978,60.29 555,791.86 2.82 6,563.66 MWD (6) 8,459.00 88.17 75.32 3,799.81 3,707.02 -2,123.04 6,238.81 5,978,700.92 555,820.85 2.29 6,588.37 MWD (6) 8,489.00 87.62 75.09 3,800.86 3,708.07 -2,115.39 6,267.79 5,978,708.77 555,849.79 1.40 6,612.95 MND(6) 8,519.00 87.16 74.97 3,802.17 3,709.38 -2,107.65 6,296.75 5,978,716.70 555,878.69 2.24 6,637.48 MWD (6) 8,549.00 87.35 73.60 3,803.61 3,710.82 -2,093.53 6,325.59 5,978,725.01 555,907.47 4.61 6,661.77 MND (6) 8,579.00 87.50 74.55 3,604.96 3,712.17 4,091.31 6,354.41 5,978,733.42 555,936.23 3.20 6,666.00 MND+IFR2+HDS+MS (7) 8,609.00 87.40 75.01 3,806.29 3,713.50 -2,OB3.44 6,383.33 5,978,741.48 555,965.10 1.57 6,710.45 MND+IFR2+HDS+MS (7) 8,639.00 87.99 74.98 3,807.50 3,714.71 -2,075.68 6,412.29 5,978,749.43 555,994.00 1.97 6,734.96 MWD+IFR2+HDS+MS(7) 8,669.00 87.59 74.94 3,808.66 3,715.87 -2,067.90 6,441.24 5,978,757.0 556,022.89 1.34 6,759.47 MWD+IFR2+HDS+MS(7) 8,699.00 88.34 74.90 3,809.72 3,716.93 -2,060.10 6,470.18 5,978,765.39 556,051.79 2.50 6,783.97 MWD+IFR2+HDS+MS(7) 101WO18 10'06:21AM Page 8 COMPASS 5000 14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 1H-104 Project• Kuparuk River Unit TVD Reference: 11-1-104 actual @ 92.79usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Well: IH -104 North Reference: True Wellbore: 1H-1041-2 Survey Calculation Method: Minimum Curvature Design: 11-1-1041-2 Database: OAKEDMP7 Survey 10/8/2018 10,06,21AM Page 9 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Purl TVD TVDSS -N/-S +E/ -W Northing Emoting DLS Section (ueft) (1) P) (usft) (usft) (usft) (usft) (ft) (ft) ('/1001 (It) Survey Tool Name 8,729.00 87.89 74.91 3,810.71 3,717.92 -2,052.29 6,499.13 5,978,773.39 556,080.68 1.50 6,808.46 MWD+IFR2+HDS+MS(7) 8,759.00 87.65 75.51 3,811.88 3,719.9 -2,044.64 6528.12 5,978,781.23 556,109.61 2.15 6,833.04 MWD+IFR2+HDS+MS(7) 8,789.00 88.08 76.85 3,812.99 3,720.20 -2,037.48 6,557.23 5,978,788.59 556,138.67 4.69 6,857.91 MWD+IFR2+HDS+MS (7) 8,819.00 87.62 77.99 3,814.12 3,721.33 -2,030.95 6586.49 5,978,795.31 556,167.88 4.10 6,883.14 MWD+IFR2+HDS+MS (7) 8,849.00 86.72 79.98 3,815.60 3,722.81 -2,025.22 6,615.90 5,978,601.23 556,197.25 7.27 6,908.78 MWD+IFR2+HDS+MS (7) 8,879.00 87.11 82.14 3,817.21 3,724.42 -2,020.57 6,645.49 5,978,806.08 556,226.81 7.31 6,934.97 MWD+IFR2+HDS+MS(7) 8,909.00 86.58 83.33 3,818.87 3,726.08 -2,016.78 6,675.20 5,978,810.06 556,256.49 4.34 6,961.55 MWD+IFR2+HDS+MS(7) 8,939.00 86.49 84.05 3,820.68 3,727.89 -2,013.49 6,704.96 5,978,813.55 556,286.23 2.41 6,988.38 MWD+IFR2+HDS+MS (7) 8,969.00 86.91 83.99 3,822.41 3,729.62 -2,010.37 6,734.75 5,978,816.87 556,315.99 1.41 7,015.27 MWD+IFR2+HDS+MS (7) 8,999.00 85.78 82.98 3,824.32 3,731.53 -2,006.97 6,764.50 5,978,820.46 556,345.71 5.05 7,042.03 MWD+IFR2+HDS+MS (7) 9,029.00 84.70 80.89 3,826.81 3,734.02 -2,002.78 6,794.09 5,978,824.85 556,375.28 7.82 7,068.38 MWD+IFR2+HDS+MS (7) 9,059.00 84.40 78.37 3,829.66 3,736.87 -1,997.40 6,823.47 5,978,830.42 556,404.61 8.42 7,094.11 MWD+IFR2+HDS+MS(7) 9,089.0 85.31 76.64 3,832.35 3,739.56 -1,990.94 6,852.64 5,978,837.07 556,433.74 6.50 7,119.28 MWD+IFR2+HDS+MS(7) 9,119.00 86.39 75.15 3,834.52 3,741.73 -1,983.65 6,881.66 5,978,844.56 556,462.70 6.12 7,144.02 MWD+IFR2+HDS+MS(7) 9,149.00 87.30 73.77 3,836.17 3,743.38 -1,975.62 6,910.51 5,978,852.77 556,491.50 5.50 7,168.35 MWD+1FR2+HDS+MS(7) 9,179.00 88.16 72.95 3,837.36 3,744.57 -1,967.04 6,939.24 5,978,861.54 556,520.17 3.96 7,192.37 MWD+1FR2+HDS+MS(7) 9,209.00 88.67 70.96 3,838.19 3,745.40 -1,957.75 6,967.75 5,978,871.02 556,548.61 6.85 7,215.94 MWD+IFR2+HDS+MS(7) 9,239.00 88.04 68.12 3,839.05 3,746.26 -1,947.27 6,995.84 5,978,881.69 556,576.63 9.69 7,238.72 MWD+IFR2+HDS+MS(7) 9,269.00 87.85 66.28 3,840.13 3,747.34 -1,935.65 7,023.48 5,978,893.49 556,604.19 6.16 7,260.67 MWD+IFR2+MDS+MS(7) 9,299.00 88.74 66.21 3,841.02 3,748.23 -1,923.57 7,050.92 5,978,905.75 556,631.55 2.98 7,282.28 MWD+IFR2+HDS+MS(7) 9,329.00 91.36 67.87 3,840.99 3,748.20 -1,911.87 7,078.54 5,978,917.63 556,659.09 10.34 7,304.19 MWD+IFR2+HDS+MS(7) 9,359.00 91.15 67.79 3,840.33 3,747.54 -1,900.55 7,106.32 5,978,929.13 556,686.79 0.75 7,326.38 MWD+IFR2+HDS+MS(7) 9,389.00 90.84 67.16 3,839.81 3,747.02 -1,889.06 7,134.03 5,978,940.80 556,714.42 2.34 7,348.44 MWD+IFR2+HDS+MS(7) 9,419.00 90.67 %.91 3,839.42 3,746.63 -1,877.36 7,161.65 5,978,952.69 556,741.96 1.01 7,370.35 MWD+IFR2+HDS+MS(7) 9,449.00 88.24 66.95 3,839.70 3,746.91 -1,865.60 7,189.24 5,978,964.62 556,769.47 8.10 7,392.21 MWD+IFR2+HDS+MS(7) 9,479.00 87.85 67.24 3,840.73 3,747.94 -1,853.93 7,216.86 5,978,976.47 556,797.01 1.62 7,414.13 MWD+IFR2+HDS+MS (7) 9,509.00 67.77 66.88 3,841.87 3,749.08 -1,842.25 7,244.47 5,978,988.34 566,824.54 1.23 7,436.03 MWD+IFR2+HDS+MS(7) 9,539.00 87.57 66.17 3,843.09 3,750.30 -1,830.31 7,271.96 5,979,000.46 556,851.95 2.46 7,457.74 MWD+IFR2+HDS+MS (7) 9,569.00 87.43 65.46 3,844.40 3,751.61 -1,818.03 7,299.30 5,979,012.92 556,879.20 2.41 7,479.19 MWD+IFR2+HDS+MS(7) 9,599.00 87.63 65.09 3,845.70 3,752.91 -1,805.49 7,326.53 5,979,025.63 556,906.34 1.40 7,500.44 MWD+IFR2+HDS+MS(7) 9,629.00 87.58 64.99 3,846.95 3,754.16 -1,792.85 7,353.70 5,979,038.6 656,933.43 0.37 7,521.60 MWD+IFR2+HDS+MS(7) 9,659.0 87.64 64.89 3,848.20 3,755.41 -1,780.15 7,380.85 5,979,051.33 556,960.49 0.39 7,642.73 MWD+1FR2+HDS+MS(7) 9,689.00 88.10 64.96 3,849.31 3,756.52 -1,767.44 7,408.01 5,979,064.22 556,987.56 1.55 7,563.85 MWD+IFR2+HDS+MS(7) 9,719.00 88.25 65.37 3,850.27 3,757.48 -1,754.85 7,435.22 5,979,076.99 557,014.69 1.45 7,505.07 MWD+IFR2+HDS+MS(7) 9,749.00 88.55 65.78 3,851.11 3,750.32 -1,742.45 7,462.52 5,979,089.57 557,041.91 1.69 7,606.44 MWD+IFR2+HDS+MS(7) 9,779.00 88.85 65.81 3,851.79 3,759.00 -1,730.15 7,489.88 5,979,102.04 557,069.18 1.00 7,627.90 MWD+IFR2+HDS+MS(7) 9,809.00 88.95 64.64 3,852.36 3,759.57 -1,717.58 7,517.11 5,979,114.79 557,096.32 3.91 7,649.14 MWD+IFR2+HDS+MS(7) 9,839.00 88.85 63.38 3,852.94 3,760.15 -1,704.44 7,544.07 5,979,128.11 557,123.19 4.21 7,669.94 MVC+IFR2+HDS+MS(7) 9,869.00 88.85 62.15 3,853.54 3,760.75 -1,690.71 7,570.74 5,979,142.01 557,149.77 4.10 7,690.26 MWD+IFR2+HDS+MS(7) 9,899.00 88.513 61.14 3,854.22 3,761.43 -1,676.47 7,597.14 5,979,156.43 557,176.06 3.48 7,710.14 MWD+IFR2+HDS+MS(7) 10/8/2018 10,06,21AM Page 9 COMPASS 5000.14 Build 85D Survey ConocoPhillips Definitive Survey Report Map Company: NADConversion I-ocai Coordlnate Reference: Well 1H-104 Project: Kuparuk River Unit ND Reference: IH -104 actual @ 92.79usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Well: 1H-104 North Reference: True Wellbore: 1H-10412 Survey Calculation Method: Minimum Curvature Design: 11-1-10412 Database: OAKEDMPI Survey 10W018 10:06:21AM Page 10 COMPASS 5000.14 Build 850 Map Map Vertical MD Inc AN TVD T1DSS +W$ +E/ -W Northing Fasting DLS Section (1141t) (1) 1°1 (uafl) Welt) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 9,929.00 88.51 60.16 3,854.98 3,762.19 -1,661.77 7,623.28 5,979,171.30 557,202.10 3.27 7,72962 MWD+IFR2+HDS+MS(7) 9,959.00 88.66 59.21 3,855.74 3,762.95 -1,646.63 7,649.16 5,979,186.61 557,227.B9 3.17 7,748.73 MWD+IFR2+HDS+MS(7) 9,989.00 88.52 58.70 3,856.51 3,763.72 -1.631.17 7,674.86 5,979,202.24 557,253.48 1.70 7,767.53 MWD+IFR2+HDS+MS(7) 10,019.00 88.38 58.32 3,857.32 3,764.53 -1,615.50 7,700.43 5,979,218.08 557,278.94 1.35 7,786.15 MWD+IFR2+HDS+MS(7) 10,099.0 88.15 57.94 3,958.23 3,765.44 -1,599.67 7,725.90 5,979,234.07 557,304.30 1.48 7,804.62 MWD+IFR2+HDS+MS(7) 10,079.00 88.04 57.54 3,859.23 3,7(Ki44 -0,583.67 7,751.25 5,979,250.24 557,329.55 1.38 7,822.92 MWD+IFR2+HDS+MS(7) 10,109.0 88.22 57.14 3,860.20 3,767.41 -1,557.48 7,776.50 5,979,265.59 557,354.68 1.46 7,841.05 MWD+IFR2+HDS+MS(7) 10,139.00 88.11 56.73 3,861.17 3,768.38 -1,551.13 7,801.62 5,979,283.11 557,379.70 1 A 7,859.02 MWD+IFR2+HDS+MS(7) 10,169.00 87.57 56.39 3,862.30 3,769.51 -1,534.61 7,826.69 5,979,299.80 557,404.60 2.13 7,876.82 MWD+IFR2+HDS+MS(7) 10,199.00 87.62 56.13 3,863.55 3,770.76 -1,517.96 7,851.57 5,979,316.61 557,429.41 0.88 7,894.50 MWD+IFR2+HDS+MS (7) 10,229.00 87.24 55.87 3,869.90 3,772.11 -1,501.20 7,876.41 5,979,333.53 557,454.15 1.53 7,912.06 MWD+IFR2+HDS+MS(7) 10,259.00 88.23 56.03 3,865.09 3,773.30 -1,484.41 7,901.25 5,979,350.48 557,478.87 3.34 7,929.61 MWD+IFR2+HDS+MS(7) 10,289.D0 89.68 56.99 3,866.63 3,773.84 -1,467.86 7,926.26 5,979,367.19 557,503.77 5.80 7,947.40 MM+IFR2+HDS+MS (7) 10,319.00 88.92 57.95 3,867.00 3,774.21 -1,451.73 7,951.55 5,979,383.49 557,528.95 4.0B 7,965.60 MWD+IFR2+HDS+MS(7) 10,349.00 88.03 58.56 3,867.80 3,775.01 -1,435.96 7,977.6 5,979,399.43 557,554.35 3.60 7,984.12 MWD+IFR2+HDS+MS(7) 10,379.00 85.70 5B.16 3,869.44 3,776.65 -1,420.24 8,002.56 5,979,415.31 557,579.74 7.88 8,002.66 MWD+IFR2+HDS+MS(7) 10,409.00 83.84 57.70 3,872.17 3,779.38 -1,404.38 8.027.87 5,979,431.34 557,604.95 6.39 8,020.97 MWD+IFR2+HDS+MS(7) 10,439.00 84.31 56.93 3,875.27 3,782.48 -1,388.27 8,052.99 5,979,447.62 557,629.95 3.00 8,039.01 MWD+IFR2+HDS+MS(7) 10,469.00 84.69 54.53 3,878.15 3,785.36 -1,371.45 8,077.65 5,979,464.59 557.654.51 8.06 8,056.39 MWD+IFR2+HDS+MS(7) 10,499.00 84.58 51.93 3,080.95 3,788.16 -1,353.58 8,101.59 5,979,482.63 557,678.32 8.64 8,072.70 MND+IFR2+HDS+MS(7) 10,529.00 84.10 49.36 3,883.91 3,791.12 -1,334.65 8.124.67 5,979,501.71 557,701.27 8.67 8,087.86 MND+IFR2+HDS+MS (7) 10,559.0 04.19 47.15 3,886.97 3,794.18 -1,314.78 8,146.93 5,979,521.72 557,723.40 7.33 8,101.93 MWD+IFR2+HDS+MS(7) 10,589.00 84.59 44.82 3,889.90 3,797.11 -1,294.03 8,168.40 5,979,542.60 557,744.73 7.84 8,114.96 MWD+IFR2+HDS+MS(7) 10,619.00 84.92 42.39 3,892.65 3,799.86 -1,272.40 8,109.00 5,979,564.37 557,765.19 8.14 8,126.86 MWD+IFR2+HDS+MS(7) 10,699.00 65.04 40.25 3,895.27 3,802.48 -1,249.96 8,208.74 5,979,586.94 557,784.77 7.12 8,137.66 MND+IFR2+HDS+MS(7) 10,679.00 84.72 38.29 3,897.95 3,805.16 -1,226.83 8,227.65 5,979,610.19 557,803.53 6.59 8,147.46 MWD+IFR2+HDS+MS(7) 10,709.00 84.82 36.67 3,900.68 3,807.89 -1,203.12 8,245.83 5,979,634.02 557,821.55 5.39 8,156.37 MND+IFR2+HDS+MS(7) 10,739.00 85.02 35.72 3,903.34 3,810.55 -1,179.01 8,263.47 5,979,650.25 557,839.03 3.22 8,164.65 MWD+IFR2+HDS+MS(7) 10,769.0 85.14 34.52 3,905.91 3,813.12 -1,154.56 8,280.67 5,979,682.80 557,856.06 4.01 8,172.38 MND+IFR2+HDS+MS(7) 10,799.00 84.80 32.86 3,908.54 3,815.75 -1,129.69 8,297.24 5,979,707.78 557,872.47 6.63 8,179.39 MN4D+IFR2+HDS+MS(7) 10,829.00 84.75 32.19 3,911.28 3,818.49 -1,104.50 8,313.31 5,979,733.07 557,988.37 2.23 8,185.81 MND+IFR2+HDS+MS(7) 10,859.00 84.42 31.77 3,914.11 3,821.32 -1,079.17 8,329,12 5,979,758.50 557,904.01 1.78 8,191.94 MWD+IFR2+HDS+MS(7) 10,889.00 84.62 31.35 3,916.92 3,824.13 -1,053.72 8,344.76 5,979,784.05 557,919.48 1.93 8,197.87 MWD+IFR2+HDS+MS(7) 10,919.00 85.16 31.13 3,919.54 3,826.75 -1,028.17 e,%0.26 5,979,809.71 557,934.80 1.35 8,203.63 MWD+IFR2+HDS+MS(7) 10,949.00 85.95 31.50 3,921.87 3,829.08 -1,002.62 8,375.80 5,979,835.36 557,950.16 2.91 8,209.43 MWD+IFR2+HDS+MS(7) 10,979.00 88.24 31.92 3,923.39 3,830.60 977.13 8,391.55 5,979,860.95 557,965.75 7.76 8,215,45 MND+IFR2+HDS+MS(7) 11,009.00 91.33 32.25 3,923.50 3,830.71 951.71 8,407.48 5,979,886.46 557,981.52 10.35 8,221.67 MWD+IFR2+HDS+MS(7) 11,039.00 92.00 32.02 3,922.63 3,829.84 -926.32 8,423.43 5,979,911.96 557,997.30 2.35 8,227.91 MND+IFR2+HDS+MS (7) 11,069.0 91.97 31.72 3,921.59 3,828.80 -900.86 8,439.26 5,979,937.52 558,012.96 1.00 8,234.01 MND+IFR2+HDS+MS (7) 11,099.00 92.04 31.45 3,920.54 3,827.75 4175.32 8,454.97 5,979,963.16 558,028.49 0.93 8,239.97 MND+IFR2+HDS+MS (7) 10W018 10:06:21AM Page 10 COMPASS 5000.14 Build 850 Survey ConocoPhillips Definitive Survey Report Map Company: NADConversion Local Coordinate Reference: Well 111-104 Pre)ect• Kuparuk River Unit TVD Reference: iH-104 actual @ 92.79usf1(Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Well: 1H-104 North Reference: True Wellbore: 1H -104L2 Survey Calculation Method: Minimum Curvature Design: 1H-1041-2 Database: OAKEDMPI Survey 10W018 10:06.21AM Page 11 COMPASS 5000.14 Build 850 Map Map Vertical MD Inc Azi TVD Woes +WS +FJ -W Northing Easgng OLS Section (wft) 0 (°I (wfl) (waft) Wait) (MR) (ft) (it) ('/1001 (ft) Survey Tool Name 11,129.00 92.11 31.59 3,919.45 3,826.66 -849.76 8,470.64 5,979,988.82 558,043.99 0.52 8,245.89 MWD+IFR2+HDS+MS(7) 11,159.0 92.41 31.85 3,918.27 3,825.48 4124.26 8,486.40 5,980,014.42 558,059.58 1.32 8,251.92 MWD+IFR2+HDS+MS(7) 11189.00 93.26 32.11 3,916.78 3,823.99 -798.85 8,502.27 5,980,039.94 558,075.28 2.96 8,2511.08 MWD+IFR2+HDS+MS(7) 11,219.0 93.69 32.77 3,914.97 3,822.18 -773.58 8,518.33 5,980,065.31 558,091.18 2.62 8,264.46 MWD+IFR2+HDS+MS(7) 11,249.00 93.49 33.59 3,913.09 3,820.30 -748.52 6,534.72 5,980,090.48 558,107.39 2.81 8,271.23 MWD+IFR2+HDS+MS(7) 11,279.00 93.08 34.41 3,911.37 3,818.58 -723.69 8,551.47 5,980,115.42 558,123.98 3.05 8,278.41 MWD+IFR2+HDS+MS(7) 11,309.00 93.07 34.58 3,909.76 3,816.97 899.00 8,568.43 5,980,140.22 558,140,78 0.57 8,285.85 MWD+IFR2+HDS+MS(7) 11,339.00 93.05 34.20 3,908.16 3,815.37 874.28 8,585.35 5,98.165.05 568,157.53 1.27 8,293.23 MWD+IFR2+HDS+MS (7) 11,369.00 93.20 33.81 3,906.52 3,813.73 849.44 8,602.11 5,980,189.99 556,174.12 1.39 8,300.42 MWD+IFR2+HDS+MS(7) 11,399.00 92.89 33.18 3,904.93 3,812.14 824.46 8,618.64 5,980,215.07 558,190.48 2.34 8,307.34 MWD+IFR2+HDS+MS(7) 11,429.00 93.37 32.14 3,903.29 3,810.50 -599.24 8,634.80 5,980,240.40 558,206.48 3.81 8,313,85 MWD+IFR2+HDS+MS(7) 11,459.00 93.61 31.11 3,901.46 3,808.67 573.75 8,650.50 5,980,266.00 558,222.01 3.52 8,319.82 MWD+IFR2+HDS+MS(7) 11,489.00 93.32 30.37 3,899.65 3,806.86 848.01 8,665.81 5,980,291.83 558,237.14 2.65 8,325.33 MWD+IFR2+HDS+MS(7) 11,519.00 94.55 30.53 3,897.59 3,804.80 -522.21 8,680.98 5,980,317.73 558,252.14 4.13 8,330.70 MWD+IFR2+HDS+MS(7) 11,549.00 95.27 30.74 3,895.02 3,802.23 496.49 8,696.21 5,980,343.54 558,267.20 2.50 8,336.15 MWD+IFR2+HDS+MS(7) 11,579.00 95.22 30.95 3,892.28 3,799.49 470.84 8,711.53 5,980,369.29 558,282.34 0.72 8,341.71 MWD+IFR2+HDS+MS(7) 11,609.00 95.05 31.11 3,889.60 3,796.81 -445.24 8,726.93 5.980,394.99 558,297.57 0.76 8,347,36 MWD+IFR2+HDS+MS(7) 11,639.00 94.90 31.22 3,887.00 3,794.21 419.66 8,742.39 5,980,420.67 558,312.87 0.62 8,353.09 MWD+IFR2+HDS+MS(7) 11,669.00 94.53 31.30 3,884.53 3,791.74 -394.10 8,757.91 5,98.446.32 558,328.21 1.26 8,3513.86 MWD+IFR2+HDS+MS(7) 11,699.00 94.25 31.32 3,882.23 3,789.44 -3611.55 8,773.45 5,980,471.98 558,343.59 0.94 8,364.66 MWD+IFR2+HDS+MS(7) 11,729.00 94.14 31.32 3,880.04 3,787.25 -342.99 8,789.01 5,980,497.64 558,358.97 0.37 8,370.47 MWD+1FR2+HDS+MS(7) 11,759.00 94.33 31.31 3,877.82 3,785.03 -317.43 8,804.56 5,980,523.30 558,374.35 0.63 8,376.28 MWD+IFR2+HDS+MS(7) 11,789.00 94.11 31.15 3,875.62 3,782.83 -291.85 8,820.07 5,980,548.98 558,389.69 0.91 8,382.04 MWD+IFR2+HDS+MS(7) 11,819.00 93.83 30.93 3,873.54 3,780.75 -266.20 8,835.50 5,980,574.72 558,404.95 1.19 8,387.71 MWD+IFR2+HDS+MS(7) 11,849.00 93.21 30.72 3,871.70 3,778.91 -24049 8,850.84 5,980,600.54 558,420.12 2.18 8,393.27 MWD+IFR2+HDS+MS(7) 11,879.00 92.11 29.62 3,870.30 3,777.51 -214.58 8,865.90 5,980,626.54 558,435.01 5.18 8,398.50 MWD+IFR2+HDS+MS(7) 11,909.00 91.13 28.04 3,869.6 3,776.67 -188.31 8,880.36 5,980,652.90 558,449.29 6.20 8,403.4 MWD+IFR2+HDS+MS(7) 11,939.00 90.99 26.46 3,868.90 3,776.11 -161.65 8,894.10 5,980,679.66 558,462.85 5.29 8,406.76 MWD+IFR2+HDS+MS(7) 11,969.00 90.95 24.83 3,868.39 3,775.60 -134.61 8,907.08 5,980,706.78 558,475.65 5.43 8,409.65 MWD+IFR2+HDS+MS(7) 11,999.00 90.53 23.09 3,868.01 3,775.22 -107.20 8,919.26 5,98.734.27 558,487.65 5.97 8,411,65 MWD+IFR2+HDS+MS(7) 12,029.00 90.62 21.35 3,867.70 3,774.91 -79.43 8,930.60 5,980,762.11 558,498.81 5.81 8,412.75 MWD+IFR2+HDS+MS (7) 12,059.00 91,26 19.71 3,867.21 3,774.42 51.34 8,941.12 5,980,790.26 558,509.14 5.87 8,412.96 MWD+IFR2+HDS+MS (7) 12,089.W 92.03 18.37 3,856.35 3,773.56 -22.99 8,950.91 5,980,818.67 558,518.73 5.15 8,412.40 MWD+IFR2+HDS+MS(7) 12,119.W 92.48 17.04 3,865.17 3,772.38 5.57 8,960.02 5,980,847.28 558,527.66 4.68 8,411.13 MWD+IFR2+HDS+MS(7) 12,149.00 92.99 15.77 3,863.74 3,770.95 34.31 8,968.49 5,980,876.08 556535.93 4.56 8,409.19 MWD+IFR2+HDS+MS(7) 12,179.00 94.04 14.80 3,861.90 3,769.11 63.19 8,976.38 5,980,905.01 558,543.63 4.76 8,406.66 MWD+IFR2+HDS+MS(7) 12,209.00 94.39 13.86 3,859.70 3,766.91 92.18 8,983.78 5,98.934.05 558,550.84 3.34 8,403.64 MWD+IFR2+HDS+MS(7) 12,239.00 94.41 12.89 3,857.39 3,764.W 121.28 8,990.70 5,980,963.19 558,557.57 3.22 8,400.13 MWD+IFR2+HDS+MS(7) 12,269.00 94.86 11.55 3,854.97 3,762.18 150.51 8,99.03 5,980,992.45 558,563.70 4.70 8,396.02 MWD+IFR2+HDS+MS(7) 12,299.00 95.59 10.11 3,852.24 3,759.45 179.85 9,002.65 5,981,021.83 558,569.12 5.36 8,391.19 MWD+IFR2+HDS+MS(7) 10W018 10:06.21AM Page 11 COMPASS 5000.14 Build 850 I ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 1 H-104 Project Kuparuk River Unit TVD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Sits; Kuparuk 1 H Pad MD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Well: 1H-104 North Reference: True Wellbore: 1 H-1041-2 Survey Calculation Method, Minimum Curvature Design: 1H -104L2 Database: OAKEDMPt Survey 10r8QO18 10:06:21AM Page 12 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +WS +EI -W Northing Easting OLS Section (Wft) (') (1) (usft) (wR) (usm Nam pM (D) (°11001 (f) Survey Tool Name 12,329.00 96.28 8.69 3,849.13 3,756.34 209.28 9,007.52 5,981,051.29 558,573.80 5.24 8,385.64 MWD+IFR2+HDS+MS(7) 12,359.00 95.93 7.57 3,845.94 3,753.15 238.81 9,011.74 5,981,080.85 558,577.82 3.89 8,379.44 MWD+IFR2+HDS+MS(7) 12,389.00 95.13 6.55 3,843.05 3,750.26 268.45 9,015.41 5,981,110.50 558,581.30 4.31 8,372.69 MWD+IFR2+HDS+MS(7) 12,419.00 94.80 5.54 3,840.46 3,747.67 298.17 9,018.55 5,981,140.24 558,584.25 3.53 8,365.42 MWD+IF1U+HDS+MS(7) 12,449.00 93.99 4.83 3,838.16 3,745.37 327.96 9,021.26 5,981,170.04 558,586.75 3.59 8,357.71 MWD+IFR2+HDS+MS(7) 12,479.00 93.24 4.32 3,836.27 3,743.48 357.80 9,023.65 5,981,199.90 558,588.94 3.02 8,399.69 MWD+IFR2+HDS+MS(7) 12,509.00 91.81 3.47 3,834.94 3,742.15 387.70 9,025.68 5,981,229.81 558,590.78 5.54 8,341.31 MWD+IFR2+HDS+MS(7) 12,539.00 90.28 2.22 3,834.40 3,741.61 417.66 9,027.17 5,981,259.77 558,592.07 6.59 8,332.40 MWD+IFR2+HDS+MS(7) 12,569.00 90.03 0.63 3,834.32 3,741.53 447.65 9,027.92 5,981,289.77 558,592.62 5.37 8,322.78 MWD+IFR2+HDS+MS(7) 12,599.00 89.83 359.89 3,834.35 3,741.56 477.65 9,028.05 5,981,319.76 558,592.56 2.56 8,312.59 MWD+IFR2+HDS+MS(7) 12,629.00 89.63 359.38 3,834.49 3,741.70 507.65 9,027.86 5,981,349.76 558,592.17 1.83 8,302.09 MWD+IFR2+HDS+MS(7) 12,659.00 89.73 359.25 3,834.66 3,741.87 537.64 9,027.50 5,981,379.75 568,591.61 0.55 8,291.3 MWD+IFR2+HDS+MS(7) 12,669.00 89.74 359.14 3,834.80 3,742.01 567.64 9,027.08 5,981,409.74 558,590.99 0.37 8,280.72 MWD+IFR2+HDS+a4S(7) 12,719.00 89.89 359.03 3,834.90 3,742.11 597.64 9,026.60 5,981,439.73 558,590.31 0.62 8,269.95 MWD+IFR2+HDS+MS(7) 12,749.00 90.34 358.98 3,834.84 3,742.05 627.63 9,026.08 5,981,469.72 558,589.59 1.51 8,259.14 MWD+IFR2+HDS+MS (7) 12,779.00 91.11 358.94 3,834.46 3,741.67 657.63 9,025.54 5,981,499.70 558,568.85 2.57 8,248.31 MWD+IFR2+HDS+MS(7) 12,809.00 91.35 358.89 3,833.81 %741.02 687.61 9,024.97 5,981,529.68 558,588.08 0.82 8,237.46 MWD+IFR2+HDS+MS(7) 12,839.00 91.23 358.66 3,833.14 3,740.35 717.60 9,024.33 5,981,559.66 558,587.24 0.86 8,226.64 MWD+IFR2+HDS+MS(7) 12,869.00 91.13 358.38 3,832.52 3,739.73 747.58 9,023.55 5,981,589.63 558,585.27 0.99 8,215.50 MWD+IFR2+HDS+MS(7) 12,899.00 91.19 358.11 3,831.91 3,739.12 777.56 9,022.63 5,981,619.60 558,685.15 0.92 8,204.32 MWD+IFR2+11DS+MS(7) 12,929.00 91.18 358.09 3,831.29 3,738.50 807.54 9,021.64 5,981,649.57 558,583.96 0.07 8,193.07 MWD+IFR2+HDS+MS(7) 12,959.00 90.84 358.18 3,830.76 3,737.97 837.52 9,020.66 5,981,679.54 558,582.79 1.17 8,181.84 MWD+IFR2+HDS+MS(7) 12,989.00 90.19 358.27 3,830.49 3,737.70 867.50 9,019.73 5,981,709.51 558,581.66 2.19 8,170.65 MWD+IFR2+HDS+MS(7) 13,019.00 89.95 358.32 3,830.46 3,737.67 897.49 9,018.84 5,981,739.49 558,580.57 0.82 8,159.50 MWD+IFR2+HDS+MS(7) 13,049.00 89.73 358.33 3,830.54 3,737.75 927.48 9,017.96 5,981,769.47 558,579.49 0.73 8,148.35 MWD+IFR2+HDS+MS(7) 13,079.00 89.75 358.34 3,830.66 3,737.89 957.46 9,017.09 5,981799.45 558,578.42 0.07 8,137.22 MWD+IFR2+HDS+MS(7) 13,109.00 89.76 358.34 3,830.81 3,738.02 987.45 9,016.22 5,981,629.42 558,577.36 0.03 8,126.09 MWD+IFR2+HDS+MS(7) 13,139.0 89.72 358.34 3,830.94 3,738.15 1,017.44 9,015.36 5,981,859.40 558,576.29 0.13 8,114.96 MWD+IFR2+HDS+MS(7) 13,169.00 89.76 358.33 3,831.08 3,738.29 1,047.42 9,014.48 5,981,889.38 558,575.22 0.14 8,103.82 MWD+IFR2+HDS+MS(7) 13,199.00 89.89 358.26 3,831.17 3,738.38 1,077.41 9,013.59 5,981,919.36 558,574.13 0.49 8,092.67 MWD+IFR2+HDS+MS(7) 13,229.0 90.38 358.03 3,831.10 3,738.31 1,107.40 9,012.62 5,981,949.33 558,572.96 1.80 8,081.44 MWDNF1U+HDS+MS(7) 13,259.00 90.70 357.80 3,830.82 3,738.03 1,137.37 9,011.53 5,981,979.30 558,571.67 1.31 8,070.10 MWD+IFR2+MDS+MS(7) 13,289.00 90.70 357.65 3,830.45 3,737.66 1,167.35 9,010.34 5,982,009.26 558,570.28 0.50 8,058.67 MWD+IFR2+HDS+MS(7) 13,319+0 90.66 357.75 3,830.09 3,737.30 1,197.32 9,009.13 5,982,039.22 558,558.88 0.36 8,047.23 MWD+IFR2+HDS+MS(7) 13,349.00 89.37 357.87 3,830.09 3,737.30 1,227.30 9,007.99 5,982,069.19 558,567.53 4.32 8,035.84 MWD+IFR2+HDS+MS(7) 13,379.00 87.69 357.92 3,830.86 3,738.07 1,257.27 9,006.89 5,982,099.15 558,565.23 5.60 8,024.49 MWD+IFR2+HDS+MS(7) 13,409.00 85.84 357.65 3,832.55 3,739.76 1,287.20 9,005.73 5,982,129.07 558,564.88 6.23 8,013.11 MWD+IFR2+HDS+MS(7) 13,439+0 84.27 357% 3,835.13 3,742.34 1,317.06 9,004.42 5,982,158.91 558,563.38 5.33 8,001.61 MW0+IFR2+HDS+MS(7) 13,469.00 83.33 356.99 3,838.37 3,745.58 1,346.84 9,002.95 5,982,188.69 558,561.71 3.35 7,989.98 MWD+IFR2+HDS+MS(7) 13,499.00 81.77 356.24 3,842.26 3,749.47 1,376.54 9,001.20 5,982,218.37 558,559.76 5.76 7,978.12 MWD+IFR2+HDS+MS(7) 10r8QO18 10:06:21AM Page 12 COMPASS 5000.14 Build 85D I ( ConocoPhillips Definitive Survey Report Design.. .--- Local Coordinate Reference: Well 1H-104 Company: NADConversion 1 H-104 actual @ 92.79usft (Doyon 142) Project: Kupamk River Unit TVD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Site: Kupamk 1 H Pad MD Reference: Well: 1H-104 North Reference: True Survey Calculation Method: Minimum Curvature Wellbore: 1H -104L2 OAKEDMPt Map Database: Vertical Design.. .--- Map Map Vertical 713,529.00 Inc C) 80.25 Azi (') 355.43 TVD (usit) 3,846.95 TVDSS (MR) 3,754.16 +W3 (usR) 1,406.09 +E14N (usR) 8.999.04 Northing (it) 5,982,247.90 Easting DLS Section lit) (°1100') IR) Survey Tool Name 558,557.41 5.73 7,965.93 MWD+IFR2+HDS+MS(7)9.00 13,589.00 13,619.00 13,649.0 13,6]9.00 78.64 78.08 78.57 79.32 80.04 354.61 353.65 352.67 351.73 351.31 3,852.45 3,858.50 3,864.57 3,870.32 3,875.70 3,759.65 3,765.71 3,771.78 3,777.53 3.782.91 1,43547 1,464.70 1,493.87 1,523.04 1,552.23 8,996.49 8,993.48 8,989.98 8,985.99 8,981.63 5,982,277.26 5,982,306.46 5,982,335.61 5,982,364.75 5,982,393.91 558,554.65 558,551.46 558,547.77 558,543.58 558,539.03 6.00 3.65 3.59 3.96 2.77 7,953.42 MWD+IFR2+MDS+MS(7) 7,940.54 MWD+IFR2+HDS+MS (7) 7,927.22 MWD+IFR2+HDS+MS (7) 7,913.43 MWD+IFR2+HDS+MS(7) 7,899.30 MWD+IFR2+HDS+MS (7) 13,709.00 13,739.00 13,769.00 13,799.00 13,829.00 80.69 81.66 82.51 83.76 85.15 351.D2 350.70 349.61 348.24 346.86 3,880.72 3,885.32 3,889.45 3,893.04 3,895.94 3,787.93 3,792.53 3,796.66 3,800.25 3,803.15 1,58145 1,610.72 1,6Q.00 1669.23 1,698.38 8,977.09 8,972.38 8,967.30 8,961.58 8,955.14 5,982,423.10 5,982,452.33 5,982,481.57 5,982,510.76 5,982,539.87 558,534.30 558,529.39 558,524.12 558,518.21 558,511.58 2.37 3.40 4.58 6.16 6.51 7,884.98 MWD+IFR2+HDS+MS(7) 7,870.49 MWD+IFR2+HDS+MS(7) 7,855.65 MWD+IFR2+HDS+MS (7) 7,840.22 MWD+IFR2+HDS+MS(7) 7,824.15 MWD+IFR2+HDS+MS(7) 13,859.0 13,889.00 13,919.00 13,949.00 13,979.00 86.04 86.75 86.77 86.86 85.73 345.43 343.97 342.51 340.87 338.14 3,898.24 3,900.13 3,901.62 3,903.49 3,905.17 3,805.45 3,807.34 3,809.03 3,810.70 3,812.38 1,727.42 1,756.30 1,784.98 1813.42 1,841.56 8,947.98 8,940.08 8,931.44 8,922.03 8,911.79 5,982,568.86 5,982,597.68 5,982,626.30 5,982,654.67 5,982,682.75 558,504.22 558,496.13 558,487.31 558,477.71 550,467.28 5.60 5.40 4.86 5.47 5.77 7,807.43 MWD+IFR2+HDS+MS(7) 7,790.08 MWD+IFR2+HDS+MS(7) 7,772.10 MWD+IFR2+HDS+MS(7) 7,753.48 MWD+IFR2+HDS+MS(7) 7,734.18 MWD+IFR2+HDS+MS(7) 14,W9.00 14,039.00 14.69.00 14,099.W 14,129.00 86.61 87.31 88.40 89.50 91.25 337.41 336.46 336.10 335.74 335.08 3,906.91 3,908.50 3,909.62 3,910.17 3,909.98 3,814.12 3,815.71 3,816.83 3,817.38 3,817.19 1,869.38 1,896.95 1924.39 1,951.78 1,979.05 8,900.70 8,888.97 8,876.91 8,864.67 8,852.19 5982,710.49 5,982,737.97 5,982,765.33 5,982,792.63 5,982,819.83 558,455.01 558,444.10 55B,431.85 558419.44 558,406.78 5.77 3.93 3.83 3.86 6.23 7,714.20 MWD+IFR2+HDS+MS(7) 7,693.70 MWD+IFR2+HDS+MS(7) 7,672.93 MWD+IFR2+HDS+MS(7) 7,652.02 MVA+IFR2+HDS+M5(7) 7,630.91 MWD+IFR2+HDS+MS (7) 14,159.00 14,189.00 14,219.00 14,249.00 14,279.00 91.85 91.08 90.16 88.63 88.52 334.11 333.15 331.40 328.62 325.84 3,909.17 3,908.40 3,908.08 3,900.39 3,909.14 3,816.38 3,815.61 3,815.29 3,815.60 3,816.35 2,006.14 2,033.01 2,059.57 2,085.54 2,110.76 8,839.32 8,826.00 8,812.05 8,797.05 8,780.82 5,982846.83 5,982,873.60 5,982,900.06 5,982,925.94 5,982,951.04 558,393.73 558.380.24 558,366.11 558,350.94 558,334.55 3.00 4.10 6.59 10.58 9.27 7,609.51 MVA+IFR2+HDS+MS(7) 7,587.76 MWD+IFR2+HDS+MS(7) 7,565.52 MWD+IFR2+HDS+MS (7) 7,542.51 MWD+IFR2+HDS+MS (7) 7,518.59 MWD+IFR2+HDS+MS(7) 14,309.00 14,339.00 14,369.00 14,389.W 14,429.00 90.07 91.38 92.27 93.03 93.89 323.12 320.52 317.92 315.82 314.82 3,909.51 3,909.13 3,908.17 3,906.78 3,904.97 3,816.72 3,816.34 3,815.38 3,813.93 3,812.18 2,135.17 2,158.75 2,181.45 2,203.32 2,224.61 8,763.40 8,744.85 8,725.27 8,704.79 8,683.73 5,982,975.34 5,982,998.79 5,983,021.36 5,983,043.09 5,983,064.24 558.316.96 558,298.27 558,278.54 558,257.91 558,235.72 10.43 9.70 9.16 7.44 4.39 7,493.83 MWD+1FR2+HDS+MS(7) 7,468.31 MWD+IFR2+HDS+MS(7) 7,442.11 MWD+IFR2+HDS+MS(7) 7415.35 MWD+IFR2+HDS+MS(7) 7,388.26 MWD+IFR2+HDS+MS(7) 14,459.W 14,489.00 14,519.00 14,549.00 14,579.00 94.54 94.53 94.81 94.91 94.87 313.86 313.17 313.17 313.19 313.01 3,902.77 3,900.40 3,897.95 3,895.41 3,892.86 3,809.98 3,807.61 3,805.16 3,802.62 3,800.07 2,245.52 2,266.12 2,286.57 2,307.03 2,327.45 8,662.33 8,640.65 8,618.84 8,597.04 8,575.22 5,983,085.01 5,983,105.45 5,983,125.76 5,983,146.07 5,983,166.35 558,215.18 558,193.36 558,171.42 558,149.49 558,127.53 3.86 2.29 0.93 0.34 0.61 7,360.97 MVA+IFR2+HDS+MS(7) 7,333.52 MWD+IFR2+HDS+MS (7) 7,306.01 MWD+IFR2+HDS+MS(7) 7,278.51 MWD+IFR2+HDS+MS(7) 7,250.99 MWD+IFR2+HDS+MS (7) 14,609.00 14,639.00 14,669.00 14,699,W 95.02 95.32 95.27 95,W 312.23 311.42 310.55 309.44 3,890.27 3,887.57 3,884.80 3,882.03 3,797.48 3,794.78 3,792.01 3,789.24 2,347.69 2,367.61 2,387.21 2,406.40 8,553.22 8,530.95 8,508.41 8,485.52 5,983,186.44 5,983,206.21 5,983,225.65 5,983,244.70 558,105.41 558,083.01 558,060.34 558,037.33 2.64 2.87 2.89 3.69 7,223.37 MWD+IFR2+HDS+MS(7) 7,195.61 MWD+IFR2+HDS+MS(7) 7,167.70 MWD+IFR2+HDS+MS(7) 7,139.61 MWD+IFR2+HDS+MS(7) 10/8/2018 10.06: 21AM Page 13 COMPASS 5000.14 Build 85D 1 ConocoPhillips Definitive Survey Report tr=ain: Local Coordinate Reference: Well 1 H-104 Company: NADConversion 1 H-104 actual @ 92.79usft (Doyon 142) Project Kuparuk River Unit TVD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: Well: 1H-104 North Reference: Survey Calculation Method: True Minimum Curvature Wellbore: 1H -104L2 OAKEDMP7 Database: tr=ain: Survey Map Map Vertical MD (p.1t) 14,729.00 hoc r) 85.42 Azi (°) 308.31 TVD (aalry 3,879.23 TVDSS w=m 3,786.44 +NIS m=a) 2,625.15 +E14N m=m 8,462.27 Northing (m 5,983,263.29 Easting DLS S=ONOn Survey Tool Nam (m rnoo9 (M 558,013.95 3.77 7,111.32 MWD+IFR2+HDS+MS(7) 14,759.00 14,789.00 14,819.00 14,849.00 14,879.00 95.22 94.42 93.70 93.16 92.40 307.19 306.19 305.19 304.21 303.30 3,876.45 3,873.93 3,871.81 3,870.01 3,868.56 3,783.66 3,781.14 3,779.02 3,777.22 3,775.77 2,443.44 2,461.30 2,478.76 2,495.80 2,512.45 8,438.65 8,414.68 8,390.38 8,365.76 8,340.84 5,983,281.42 5,983,299.12 5,983,316.41 5,983,333.29 5,983,349.78 557,990.22 557,966.13 557,941.72 557,916.99 557,891.97 3.78 4.26 4.10 3.72 3.95 7,082.86 MWD+IFR2+HDS+MS(7) 7,054.20 MWD+IFR2+HDS+MS (7) 7,025.38 MWD+IFR2+HDS+MS(7) 6,996.39 MWD+IFR2+HDS+MS(7) 6,987.27 MWD+IFR2+HDS+MS(7) 14,909.00 14,939.00 14,969.00 14,999.00 15,029+0 914.9 90.82 90.11 89.88 89.79 302.41 301.49 300.42 299.32 29B.26 3,867.54 3,866.93 3,856.69 3,866.69 3,866.78 3,774.75 3,774.14 3,773.90 3,773.90 3,773.99 2,528.72 2,544.59 2,560.02 2,574.96 2,589.41 8,315.66 8,290.21 8,264.48 8,238.47 8,212AB 5,983,365.B7 5,983,381.58 5,883,396.83 5,983,411.60 5,983,425.87 557,856.67 557,841.12 557,815.30 557,789.19 557,762.80 4.24 3.79 4.28 3.75 3.55 6,938+3 MWD+IFR2+HDS+MS(7) 6,908.67 MWD+IFR2+HDS+MS (7) 6,879.21 MWD+IFR2+HDS+MS(7) 6,849.64 MWD+IFR2+HDS+MS(7) 6,819.99 MWD+IFR2+HDS+MS(7) 15,059.00 15,089.00 15,119.00 15,149.00 15,179.00 89.76 9003 90.44 90.57 91.18 297.55 296.90 296.31 296.49 296.88 3,866.90 3,866.95 3,866.83 3,866.56 3,866.11 3,774.11 3,774.16 3,774.04 3,773.77 3,773.32 2,603.45 2,617.17 2,630.61 2,643.95 2,657.42 8,185.67 8,158.99 8,132.17 8,105.30 8,078.49 5,983,439.74 5,983,453.28 5,983,466.54 5,983,479]0 5,983,492.99 557,736.20 557,709.44 557,682.53 557,655.58 557,628.69 2.37 2.35 2.39 0.74 2.41 6,790.26 MWD+IFR2+HDS+MS(7) 6,760.49 MWD+IFR2+HDS+MS(7) 6,730.68 MWD+IFR2+HDS+MS(7) 6,700.87 MWD+IFR2+HDS+MS (7) 6,671.07 MWD+IFR2+HDS+MS(7) 15,209.00 15,239.00 15,269.00 15,299.00 15,329+0 91.43 91.53 91.35 90.89 90.76 297.27 297.75 298.25 298.75 289.12 3,865.42 3,864.65 3,863.89 3,863.31 3,862.B7 3,772.63 3,771.86 3,771.10 3,770.52 3,770.08 2,671.07 2,684.92 2,699.00 2,713.31 2,727.83 8,051.79 6,025.19 7,998.71 7,972.35 7,946.10 5,883,506.46 5,963,520.14 5,983,534.04 5,993,540.17 5,983,562.51 557,601.90 557,575.21 557,548.64 557,522.19 557,485.84 1.54 1.63 1.77 2.26 131 6,641.29 MWD+IFR2+HDS+MS(7) 6,611.55 MWD+IFR2+HDS+MS(7) 6,581.85 MWD+IFR2+HDS+MS (7) 6,552.17 MWD+IFR2+HDS+MS(7) 6,522.53 MWD+IFR2+HDS+MS(7) 15,359.00 15,389.00 15,419.00 15,449.00 15,479.00 90.68 91.06 91.24 91.33 90.94 299.44 299.76 300.76 302.07 303.39 3,862.50 3,862.04 3,851.44 3,860.77 3,860.17 3,769.71 3,769.25 3,768.65 3,767.98 3,767.38 2,742.50 2,757.31 2,772.43 2,788.06 2,804.28 7,919.93 7,893.85 7,867.95 7,842.35 7,817.12 5,983,577.01 5,983,591.65 5,983,606.59 5,983,622.05 5,983,638.10 557,469.58 557,443.41 557,417.40 557,391.71 557,365.37 1.10 1.65 3.39 4.38 4.59 6,492.91 MWD+IFR2+HDS+MS(7) 6,463.33 MWD+IFR2+HDS+MS(7) 6,433.80 MWD+IFR2+HDS+MS(7) 6,404.39 MWD+IFR2+HDS+MS(7) 6,375.12 MWD+IFR2+HDS+MS(7) 15,509.00 15,539.00 15,569.00 15,599.00 15,629.00 8987 88.24 86.52 85.39 85.25 303.23 302.36 301.48 300.30 298.90 3,859.96 3,850.46 3,861.83 3,863.94 3,866.39 3,767.17 3,767.67 3,769.04 3,777.15 3,773.60 2,820.75 2,837.00 2,852.84 2,86821 2,882.97 7,792.05 7,766.83 7,741.40 7,715.72 7,689.72 5,983,654.41 5,983,670.49 5,983,686.16 5,983,701.35 5,983,715.95 557,341.19 557,315.88 557,290.34 557,254.56 557,238.47 3.61 6.16 6.44 544 4.67 6,345.91 MWD+IFR2+HDS+MS(7) 6,316.65 MWD+IFR2+HOS+M5 (7) 6,287.31 MWD+IFR2+HDS+MS(7) 6,257.92 MWD+IFR2+HDS+MS(7) 6,228.42 MWD+IFR2+HDS+MS(7) 15,659.00 15,689.00 15,719.00 15,749.00 15,779.00 8548 86.62 87.93 89.62 82.42 297.50 296.06 294.61 293.15 292.16 3,868.82 3,870.88 3,872.31 3,872.95 3,872.42 3,776.03 3,778.09 3,779.52 3,780.16 3,779.63 2,897.10 2,910.59 2,923.41 2,935.55 2,947.10 7,663.37 7,636.65 7,609.57 7,502.15 7,554.47 5,983,729.90 5,983,743.21 5,983,755.85 5,963,767.80 5,983,779.17 557,212.03 557,185.22 557,158+6 557,130.55 557,102.81 4.71 6.11 6.51 7.44 9.90 6,198.82 MWD+IFR2+HDS+MS(7) 6,169.09 MWD+IFR2+HDS+MS(7) 6,139.25 MWD+IFR2+HDS+MS (7) 6,109.33 MWD+IFR2+HDS+MS(7) 6,079.36 MWD+IFR2+HDS+MS(7) 15,811.27 15,872.00 95.69 95.68 291.69 291.69 3,870.13 3,864.11 3,777.34 3,771.32 2,959.12 2,981.46 7,524.61 7,468.46 5,983,790.99 5,983,812.95 557,072.87 557,016.58 10.24 0.00 6,047.20 MWD+IFR2+HDS+MS(7) 5,986.79 PROJECTED to TO 10/812018 10:06:21AM Page 14 COMPASS 5000.14 Build 85D Cement Detail Report r 1 H-104 String: Conductor Cement Job: DRILLING ORIGINAL, 8/5/2018 09:00 Cement Details Description CementingStartDate Cementing End Date Wellbore Name Conductor Cement 11/4/2016 06:00 11 /4/2016 08:00 1H-104 Comment Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Conductor Cement 0.0 118.5 Yes 0.0 No No Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) No 0.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 131/2 Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Surface Cement 4.0 118.5 G 40.5 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) Cmprbtr 1 (psi) Additives Additive Type Concentration Conic Unit label Page 111 Report Printed: 9124/2018 Cement Detail Report a 11-1-104 String: Surface Casing Cement Job: DRILLING ORIGINAL, 8/5/201809:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 8/7/2018 19:30 8/7/2018 23:30 1 H-104 Comment Pump 5 bbls of CW100 & PT lines to 4000 psi, good. Pump 35 bbls of CW 100 at 4.8 bpm, 120 psi. Pump 80 bbls of 10.5 ppg MPII at 4 bpm, 115 psi. Drop bottom plug. Pump 300.9 bbls of 11.0 ppg Lead cement at 6 bpm, 175 psi. Observed bottom plug bump w/ 179 bbls away Observed MPII at surface at 265 bbls away. Pump 67 bbls of 12.0 ppg Tail cement at 6 bpm, 270 psi. Drop top plug. Pump 10 bbls of fresh H2O at 5 bpm, 150 psi. Swap to rig & pump 165.1 bbis of 9.5 ppg spud mud to bump plug. Observe good 11.0 ppg cement back w/ 75 bbl mud pumped. Landed on hanger w/ 80 bbls of mud pumped. Pressure up to 784 psi & hold for 5 minutes. Check floats, good. CIP 23:22 hrs. Total of 109 bbis of 11.0 ppg lead cement to surface. Cement Stages Stage # <Stage Number?> Description ObjectiveTap Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement 42.4 1,906.0 Yes 109.0 Yes Yes O Pump Init (bbl/m... O Pump Final (bbl/... O Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 5 6 280.0 780.0 Yes 10.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pump 5 bbls of CW 100 & PT lines to 4000 psi, good. Pump 35 bbls of CW100 at 4.8 bpm, 120 psi. Pump 80 bbis of 10.5 ppg MPII at 4 bpm, 115 psi. Drop bottom plug. Pump 300.9 bbls of 11.0 ppg Lead cement at 6 bpm, 175 psi. Observed bottom plug bump w/ 179 bbls away. Observed MPII at surface at 265 bbls away. Pump 67 Dials of 12.0 ppg Tail cement at 6 bpm, 270 psi. Drop top plug. Pump 10 bbis of fresh H2O at 5 bpm, 150 psi. Swap to rig & pump 165.1 bbis of 9.5 ppg spud mud to bump plug. Observe good 11.0 ppg cement back w/ 75 bbl mud pumped. Landed on hanger w/ 80 bbls of mud pumped. Pressure up to 784 psi & hold for 5 minutes. Check floats, good. CIP 23:22 hrs. Total of 109 bbls of 11.0 ppg lead cement to surface. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimared Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) 300.9 LeaCement 42.4 1,254.0 885 G Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr t (psi) 1.91 6.76 11.00 74.1 5.75 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 1,254.0 1,906.0 228 G 67.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) usually (Ib/gal) Plastic Viscosity (c P) Thickening Time (hr) CmprStr 1 (psi) 1.65 15.60 12.00 85.5 4.00 Additives Additive Type Concentration Cone Unit label Page 111 ReportPrinted: 9/24/2011 Cement Detail Report 11-1-104 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 8/5/2018 09:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 8/14/2018 14:00 8/14/2018 18:00 1 H-104 Comment PJSM and RU cement hose PT lines to 4,000 PSI. (PASSED). Reciprocate pipe from 9,503' MD - 9,488' MD. UP WT = 211K. DWN WT = 101K. Pump 41.3 BELS MP II. @ 3 BPM 312 PSI, 12% F/O. Drop BTM Plug pump 250 BBLS of 15.8# class G cement stage up pumps to 6 BPM with ICP 400 SI. FCP 270 PSI. 22% F/O. Drop top plug and chase with 10 BBLS H2O. followed with 9.2 PPG treated -SND @ 7 BPM icp 161 PSI, Obsereve DWN WT to 50K — 10' high. Attempt to free pipe with no success. UP WT = 228K, DWN WT = 98k. continue to pump 7 BPM with FCP 1,265 PSI. teduce rate to 3 BPM @ 4,025 Silks. ICP 1,175 PSI. FCP 1,320 PSI. Bump plug with 422 STKS. CIP @ 1730 hrs. Increase pressure to 1,853 PSI and hold for 5 min. Bleed off and check floats. Holding. Cement Stages Stage # 1 Description ObjectiveTop Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing 4,775.0 9,514.0 Yes Yes Yes Cement Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 3 7 7 1,265.0 1,265.0 Yes 15.00 No Tagged Depth fftKB) Tag Method Depth Plug Drilled Out To (IIIDrill Out Diameter (in) Comment PJSM and RU cement hose PT lines to 4,000 PSI. (PASSED). Reciprocate pipe from 9,503' MD - 9 488' MD. UP WT = 211 K. DWN WT = 101K. PUmp 41.3 BELS MP II. @ 3 BPM 312 PSI, 12% F/O. Drop BTM Plug pump 250 BBLS of 15.8# class G cement stage up pumps to 6 BPM with ICP 400 SI. FCP 270 PSI. 22%F10. Drop top plug and chase with 10 BBLS H2O. followed with 9.2 PPG treated -SND @ 7 BPM icp 161 PSI, Obsereve DWN WT to 50K— 10' high. Attempt to free pipe with no success. UP WT = 228K, DWN WT = 98k. continue to pump 7 BPM with FCP 1,265 PSI. teduce rate to 3 BPM @4,025 Stks. ICP 1,175 PSI. FCP 1,320 PSI. Bump plug with 422 STKS. CIP @ 1730 hrs. Increase pressure to 1,853 PSI and hold for 5 min. Bleed off and check floats. Holding. Cement Fluids S Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) 1 141.3 Mud Push 3,675.0 14,775.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (CP) Thickening Time (hr) Cmprstr t (psi) 12.50 Additives Type Concentration Cone Unit label Additive Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bt m (ftKB) Amount (sacks) Class Volume Pumped (bbl) 250.0 Cement 4,775.0 9,515.0 1,401 G Yieltl (ft /sack) Mix H2O Ratio (gal/sa... Free Water I%) Density (lb/gal)Plastic Viscosity (CHI Thickening Time (hr) CmprStr 7 (psi) 1.16 5.12 15.80 163.0 4.22 Additives Type Concentration Cone Unit label Additive Page 111 Report Printed: 912412018 29 84 1 Schlumberger -Private p7pa19-o96� Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Friday, September 14, 2018 9:58 AM To: 'Brunswick, Scott A' Cc: Regg, James B (DOA); Schwartz, Guy L (DOA); Rixse, Melvin G (DOA) Subject: RE: 1H -104L2 PTD 218-086 BOPE Use Notification Scott, Any BOPS components used for well control purposes must be function pressure tested before the next wellbore entry. Please refer to Guidance Bulletin No 06-01 on our website. 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 Loepp analaska.00v 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@alaskaaaov From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Friday, September 14, 2018 9:50 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov>; Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov>; Alexa, Kurt J <Kurt.J.Alexa@conocophillips.com>; Rohlfing, Jenaya J<Jenaya.J.Rohlfing@conocophillips.com> Subject: 11-1-1041-2 PTD 218-086 BOPE Use Notification Victoria Find attached an inform that we used the annular BOP on Doyon 142 this morning on well 1H -104L2 PTD# 218-086. We saw zero pressure on SIDP & SICP after closing. The 111-1041-2 is the upper most lateral of this tr-lateral producer. We drilled the lateral to TD without issue. We'll be circulating bottoms up to make sure all gas that may remain from below the whipstock is out through the gas buster with the annular shut in to make sure everything is performed safely. Regards Scott Brunswick 907-227-8499 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 14th, 2018 ConocoPhillips Alaska Oil and Gas Conservation Commission 333 West 70 Avenue, Suite 100 Anchorage, Alaska 99501 Re: Reporting BOPE Use to check wellbore pressure, confirm breathing, circulate out gas from below seals on whipstock Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby reports the use of BOPE equipment to check wellbore pressure, confirm breathing, & circulate out gas from below seals on whipstock from a well on September 141h, 2018 @ 09:00. The well the BOPE has been used on is designated as 1 H-1041-2 (PTD 218-086); an onshore horizontal West Sak D sand producer well from the 1 H drilling pad. Doyon 142 pulled the whipstock free in preparation to run the 1 H-1041-2 liner. 10.4 ppg kill weight drilling fluid was in the hole. mgrated from m the lower 2rllor to pullinthe whipstock were performed & the well aterals to below he seals on the whipstock assembly. static. It is believed that gas The rigs most recent full BOP test was on September 5'h, 2018. 1. The rig had been performing an exhale test to confirm wellbore breathing. 2. There was a decreasing trend from 4 bbl to 0.6 bbl. 3. The pumps were started to circulate a bottom up to ensure wellbore free of reservoir fluids. 4. Shortly after the pumps were started a max gas of 1100 units was seen momentarily. 5. The pumps were shut down. 6. The gas spike decreased to zero. 7. The annular BOP was shut in to monitor for pressure. 8. After monitoring, SIDP & SICP were both confirmed as zero. 9. The rig will now commence circulating bottoms up through the gas buster with the annular shut in. Remedial actions will be to circulate bottoms up to clear any gas that may be in the wellbore. The rig will then increase the mud weight to 10.5 ppg to give a slightly larger trip margin. If you have any questions or require further information, please contact Scott Brunswick (ScottA Brunswick0conocophillips.com) at 263-4249 or 227-8499. Sincerely, Scott Brunswick Drilling Engineer cc: 1H-104 Well File ATO 1530 Fred Herbert ATO 1566 ATO 1500 Jenaya Rohlfing ATO 1500 Chip Alvord IC2y J�- )04L -Z Regg, James B (DOA) From: Doyon 142 Company Man <d142cm@conocophillips.com> Sent: Saturday, September 15, 2018 4:24 AM To: Noble, Robert C (DOA) i I Cc: DOA AOGCC Prudhoe Bay Subject: RE: [EXTERNAL]Re: AOGCC Test Witness Notification Request:, Doyon 142, 1 H-1041-2, KRU Attachments: Doyon 142 09-15-18 well control.xlsx; Doyon 142 09-15-18 well control - Chart0001.zip Good morning, Post well control test of equipment used on Doyon 141 from 9-14-2018. Dave Coates / Rock Rauchenstein Doyon 142 Company Men Office 907-670-6001 Doghouse 907-670-6012 From: Noble, Robert C (DOA) <bob.noble @alaska.gov> Sent: Friday, September 14, 2018 2:30 PM To: Doyon 142 Company Man <d142cm@conocophillips.com> Cc: Bixby, Brian D (DOA) <brian.bixby@alaska.gov>; McLeod, Austin (DOA) <austin.mcleod@alaska.gov> Subject: Re: [EXTERNAL]Re: AOGCC Test Witness Notification Request: , Doyon 142, 1H-1041-2, KRU Witness is waived Sent via the Samsung Galaxy S8+, an AT&T 4G LTE smartphone -------- Original message -------- From: Doyon 142 Company Man <d142cm@conocophillips.com> Date: 9/14/18 11:45 AM (GMT -09:00) To: "Noble, Robert C (DOA)" <bob.noble@alaska.gov>, DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe. bay@alaska.gov> Subject: RE: [EXTERNAL]Re: AOGCC Test Witness Notification Request: , Doyon 142, 11-1-1041-2, KRU I forwarded you guys the notification made to Scott to AOGCC town, let me know if you did not get it. Would you gentlemen like a 2-3 hr call out to whiteness the test of the equipment used? Thanks Dave Coates / Rock Rauchenstein Doyon 142 Company Men Office 907-670-6001 Doghouse 907-670-6012 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim reaaCa)alaska gov AOGCC Inspectors(o)alaska gov7 phoebe brooks(a)alaska gov Contractor: Doyon Rig No.: 142 DATE: 9/15/18 Rig Rep.: S. Dambacher/ F. Carlo Rig Phone: 670-6002 P Operator: CPAI Op. Phone: 670-6001 NT Rep.: D. Coates/ R. Rauchenstein E -Mail rig 1443cloyondrilling.com P Well Name: 11-1-1041-2 PTD # 2180860 _ Sundry # Operation: Drilling: X Workover: Test: Initial: Weekly: ;sure (osit Rams: 250/3500 Annular: Explor.: Bi -Weekly: Valves: 250/3500 - MASP: 1269 ' BOP STACK: Test Result Size/Type Test Result Quantity Test Result Location Gen. P Well Sign P Upper Kelly 1 NT Housekeeping P Rig P Lower Kelly 1 NT PTD On Location P Hazard Sec. P Ball Type I NT ing Order Posted P Misc. NA Inside BOP I NT NA #6 Rams 0 FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result Stripper 0 Manual Chokes NA Annular Preventer I 13-5/8"x5k P #1 Rams 1 3.5"x6'. NT #2 Rams I Blinds NT #3 Rams 1 3.5"x 6" NT #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves I 3-1/8"x 5k NT HCR Valves 2 3-1/8"x 51k NT Kill Line Valves 3 3-1/8"x 5k NT Check Valve 0 NA BOP Misc 0 NA CHOKE MANIFOLD MUD SYSTEM: Quantity Test Result No. Valves 14 NT Manual Chokes 1 NT Hydraulic Chokes I P ✓ CH Misc 0 NA MUD SYSTEM: Visual Alarm Trip Tank P NT Pit Level Indicators P NT Flow Indicator P NT Meth Gas Detector P NT H2S Gas Detector P NT MS Misc 0 NA Quantity Test Result Inside Reel valves ACCUMULATOR SYSTEM: Time/Pressure System Pressure (psi) Pressure After Closure (psi) 200 psi Attained (sec) Full Pressure Attained (sec) Blind Switch Covers: Nitgn. Bottles # & psi (Avg.): ACC Misc Test Results Number of Failures: 0 Test Time: 1_0 Hours Repair or replacement of equipment will be made within Notifv the AOGCC of repairs with written confirmation Test Annular w/ 4" & 4.5" test jts. Test Hyd operated choke on anger. Tested at first chance when out of the hole. 24 hr Notice No Daterrime Start Daterrime: 9/15/2018 (date) (time) Date/Time: 1:30 days. By Witness Test Result NT Form 10-424 (Revised 04/2018) Doyon 142 09-15-18 well control THE STATE °fALASKA GOVERNOR BILL WALKER G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska. gov Re: Kuparuk River Field, West Sak Oil Pool, KRU 1H -104L2 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-086 Surface Location: 5200.56' FNL, 772.31' FEL, SEC. 28, T12N, R10E, UM Bottomhole Location: 2205.6' FNL, 3881.4' FEL, SEC. 26, T12N, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for the permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 218-084, API No. 50-029- 23610-00-00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French Chair SIt, DATED this i day of August, 2018. STATE OF ALASKA AL, .(A OIL AND GAS CONSERVATION COM4. ON PERMIT TO DRILL '(2 1n A AC IG MA WL ? 3 7.018 1 a. Type of Work: ••(• b. Proposed Well Class: Exploratory - Gas ❑LVService - WAG ❑ Service - Disp ❑ 1c. Specify if.wgOys•pr0 r: 16dts ❑ Drill Lateral Stratigraphic Test ❑ Development - Oil Q ' Service - Winj ❑ Single Zone ❑✓ Coalbed --- s Redrill Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service -Supply ❑ Multiple Zone ❑ l Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑✓ Single Well ❑ 11. Well Name and Number: Conoco Phillips Bond No. 59-52-180 KRU 1H -104L2 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 15777 ND: 3843 Kuparuk River Field West Sak Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 5200.56' FNL, 772.31' FEL, Sec 28, T 12N, R010E, UM ADL026639 & ADL025638 8. DNR Approval Number: 13. Approximate Spud Date: Top of Productive Horizon: 2050.34' FNL, 143.74' FEL, Sec 34, T 12N, R010E, UM 80-261 & 931695000 8/1/2018 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 2205.6 FNL, 3881.4 FEL, Sec 26, T 12N, R010E, UM 2560 & 2560 2881'to ADL025637 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 93.1' 15. Distance to Nearest Well Open Surface: x- 549568.74 • y- 5980782.43 . Zone- 4 GL / BF Elevation above MSL (ft): 54.1' to Same Pool: 514' to 1 H-110 16. Deviated wells: Kickoff depth: 8142 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 98.55 degrees Downhole: 1647 psi • Surface: 1269 psi 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD TVD (including stage data) 42" 20" 94# H-40 Welded 80 Surface Surface 118 118 Existing, cement to surface 13-1/2" 10-3/4" 45.5# L-80 Hyd 563 1864 1 Surface Surface 1 1918 1800 985 sx 11.0 Lead, 201 sx 12.0 Tail 9-7/8" 7-5/8" 29.7# L-80 Hyd 563 9414 Surface Surface 9468 4083 1169 sx 15.8 Class G 6-3/4" 4-1/2" 12.6# L-80 IBTM?XP 7635 8142 3785 15777 • 3843 N/A: Un -cemented slotted liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Reddll and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth ND (ft): Junk (measured): Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Hydraulic Fracture planned? Yes❑ No Q • 20. Attachments: Property Plat ❑ ROP Sketch p Drilling Program ✓ Time v. Depth Plot B B Shallow Hazard Analysis AAC 25.050 ✓ B Diverter Sketch ✓ Seabed Report Drilling Fluid Program ✓ 20 requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be Kelsey Shumway deviated from without prior written approval. Contact Name: 0 S -I ICI Authorized Name: G. Alvord Contact Email: kelsev shumw ypconocopmllioa com Authorized Title: Alaska Drilling Manager Contact Phone: 1-907-265-1577 A L✓C Xt V Date: 14� �V L Authorized Signatur , Commission Use Only Permit to Drill /(J� / Number: {7_6 V� API wN�u�m7bb% 50-r/Z-C '-2�6/O-6r-cam Permit Approva Date: \ See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane gas hydrates, or gas contained in shales: ,--,/ Yes❑ No Other: YY11��p f -e3 r-r�-rss vrG / •�IJO 5 / Samples req'd: Yes ❑ �NoO Mud log req'd: 2+ 4/� S ✓� 9 ©' No Directional svy req'd: Yes �i/No� r H,S measures: Yes fl n h vlcf� frr ' d: Yes❑❑ No E] rr✓rn Inclination-onl sv re ,r- Spacing exception req'd: Yes ❑ No Y Y q r` ✓ % /J $ % Post initial injection MIT req'd: Yes No Er r�ss �` ' Z �DO Fl T rcR v,'r= rl . APPROVED BY ,pp`� Dater I Approved by: COMMISSIONER THE COMMISSION l/ ' / �� I &� �� Submit i Form and ani( `b Form 10-401 Revised 5/2077 Thrs permit is valid f r n h approval per 20 AAC 25.005(8) Anachmeys in Duplicate yI/� ✓_` 7. Application for Permit to Drill, Well 111-1041-2 Saved: 19 -Jul -18 Post Office Box 100360 y Anchorage, Alaska 99510-0360 Conoic6Millip5 Phone(907)265-1577 Email: kelsev shumway(�conocophillips.com July 18, 2018 Alaska Oil and Gas Conservation Commission 333 West 7" Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Producer, 1H -104L2 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to drill a grass roots onshore producer, a tri -lateral horizontal well in the West Sak A2/A3, D/B and D sands. The expected spud date for this well is August 1, 2018. It is planned to use rig Doyon 142. A 13-1/2" surface hole will be drilled on diverter & 10-3/4" surface casing will be run to total depth and cemented to surface. The remaining intervals will utilize Doyon 142's 13-5/8" x 5000 psi BOP stack with required ram installations and tested on a 14 day cycle in accordance with COP and AOGCC policy. The intermediate hole section will drill a 9- 7/8" hole with 7-5/8" casing run to total depth & cemented in place. The third 1H -104L2 6-3/4" production lateral will be geo-steered in the West Sak D sand and lined with 4-1/2" slotted liner. A separate PTD application will be submitted for each lateral: 1H-104, 1H -104L1, and 1H -104L2 laterals. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Kelsey Shumway at 265-1577 (kelsev shumwav (a�conocoohillios.com) or Chip Alvord at 265-6120. ligcere�ly, Kelsey Shu>h*ay Sr. Drilling Engineer Application for Permit to Drill Document Kuparuk Well Well Name Requirements of 20 AAC 25.005 (f1 The well for which this application is submitted will be designated as KRU 1H -104L2 Location Summary Requirements of 20 4 A 25.005(c)(2) .An apV 1!111 fora Permil to Drill must be accompanied be each of the following ilems, except jar an item already on file With the commission and identified in file application: (2) a plat identifying the property and the property s owners and showing (A) he coordinates of the proposed location of file +cell at the surface, at the top of each objective formation, and at Total depth. referenced to governmental section lines. (8) file coordinates of the proposed location of the well al the surface, referenced to the store plane coordinate system for this state as nmintained by the National Geodetic Surrey in the National Oceanic and Atmospheric Administration: (C) the proposed depth of the well at file top of each objective formation and at total depth: 12N Northings: 5983829.98' Eastings: 556992.3' and (D) other information required by 20 AAC 25.050(b): Requirements .01 20 AAC 25.050(b) Ifo well is u, be in(I lionally deviated. the application fora Permit to Drill (Farr, 10-401) oras( (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacer:nvellbores within 200 feet of any portion of the proposed well: Please see Attachment: Directional Plan And (2) for,llivells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells. to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of file application by certified ,rail: or (B) state that the applicant is the only affected o,mer. The Applicant is the only affected owner. 5200.56' ' FNL, 772.31FEL, Sec 28, T 12 Location at Surface � Elevation 1 93.1AMSL NGS Coordinates Northings: 5980782.43' Eastings: 549568.74' Pad Elevation 54.1' AMSL Location at Surface Casing 138.71' FNL, 298' FEL, Sec 33, TMeN,, R01 De til RKB: 1918' NGS Coordinates Northings: 5980567.48' Eastings: 550044.93' Total Vertical Depth, RKB: t800' Total Vertical De til, SS: I N , 1743.07' FNL, 4160.03' FEL, Sec 35, T12N, R010E, UM Intermediate Casing Measured De til, RKB: 9468' es rNorthings.5979011.08' Eastings: 556756.24' Total Vertical Depth, RKB, 4083' Total Vertical Depth, SS: 3990' 12N Northings: 5983829.98' Eastings: 556992.3' and (D) other information required by 20 AAC 25.050(b): Requirements .01 20 AAC 25.050(b) Ifo well is u, be in(I lionally deviated. the application fora Permit to Drill (Farr, 10-401) oras( (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacer:nvellbores within 200 feet of any portion of the proposed well: Please see Attachment: Directional Plan And (2) for,llivells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells. to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of file application by certified ,rail: or (B) state that the applicant is the only affected o,mer. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(cl(31 An appl!n1 s n for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identjfled in the application: (3) a diagram and description of the blmcout prevention equipment (BOPS) as required by 20 AAC 15.035. 20 AAC 25.036. or 10 AAC 25.03 7. as applicable: Please reference BOP schematics on file for Doyon 142 & within this PTD application. Due to lower reservoir pressure in the West Sak a fixed stack ram placement will be utilized to fulfill all barrier requirements during well construction operations, graphic attached. Drilling Hazards Information Requirements of 20 AAC 25.005 (cl(41 An upplication for a Pernut to Drull mus, be accompanied by each ojthe johowing items, exceptfor an item already on file with the comohissum and identified in the application: (J) information on drilling hazards. including (A) the masinn nh dmvnhole pressure that may be encountered. criteria used to determine it, and maximunn parental swr jnce pessare base on a methane gradient: The maximum potential surface pressure (MPSP) while drilling 1H-104 is calculated using an estimated maximum reservoir pressure of 1647 psi (based on 1H -05A pressure at a 4005.2' TVD reference datum), a gas gradient of 0.10 psi/ft, and the estimated depth of the West Sak D sand at 3783' TVD: r A2 Sand Estimated. BHP = 1,647 psi jb'4 I- e5 1 6 Il FP°t b g2rSand estimated depth = 3,783' TVD _ 3 - Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 378 psi (3,783' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 1,269 psi (1,647 psi — 378 psi) (B) data on potential gas cones: The wellbore is not expected to penetrate any shallow gas zones. And (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata. lost circulation cones, and cones that have a propensity for differential sticking: See attached l H-104 Drilling Hazards Summary Reauirements of 20 AAC 25.005 (c)(51 An application fm' a Pernut to Drul must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conductingformatton integrity testsas required under 20 A[AC 25.03009: A procedure is on file with the commission for performing FIT/LOT's. The FIT/LOT will be performed on the motherbore of the IH -104 tri -lateral well (IH -104). ConocoPhillips requests a waiver on subsequent laterals FIT/LOT (1H -104L1, and 1H-I04L2). Waiving the upper lateral FIT/LOT may be undertaken if the following criteria are met: 1. Primary cement job pumped as per design with no issues. 2. WellView cement report submitted to AOGCC for review of job before 2"d lateral is drilled (1H -104L1). 3. No abnormal pressure is discovered while drilling the motherbore well (lowest lateral). 4. Kill weight fluid is confirmed using a static flow check at the shoe post TD of the 1H-104 motherbore. If any of the above-mentioned criteria are not met, performing an FIT/LOT of the upper laterals will be undertaken. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application fora Permit to Drill must be accompanied by each of the following items. exceptjor an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 15.030. and a description of my slotted liner, pre -perorated liner, or screen to be installed Casing and Cement Program 18. Casing ogram Surface Specifications Production Top - Setting Depth - Bottom Cenent Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD I ND (including stage data) 42' 20" 94# H-40 Wekfed 80 Suif Surface 118 118 Existing, cement to surface 13-1/2" 16-3/4" 45.5# L-80 Hyd 563 1864 Surface Surface 1918 1 1800 985 sx 11.0 Lead, 201 sx 12.0 Tail 9-7/8" 7-5/8" 29.7# L-80 I Hyd 563 r 9414 Surface Surface 9468 1 4083 11169 sit 15.8 Class G 6-3/4" 4-1/2" 12.6# L-80 I BTm rxp r 7635 1 8142 1 3785 r 15777 r 3843 NA: Un -cemented slotted liner Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items. excepi for an item already on file with the commission and idenufled in the application: (7) a diagram and description of the divener system as required by 20 AAC 25 035, unless this requirement is waived by the commission under 20 AAC 25 035(h)(2),• Please reference attachment for diverter schematic. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill musi be accompanied by each of due follmring items. except for an neni already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033,' Mud Program Summary Diagram of Doyon 142 Mud System is on file with AOGCC. Surface Intermediate Production 13-1/2" Hole 9-7/8" Hole 6-3/4" Hole 10-3/4" Casing 7-5/8" Casing 4-1/2" Liner Mud System Spud (WBM) LSND WBM FloPro WBM Density 8.8-9.5 9.0-9.4 9.2-9.5 ' PV ALAP ALAP ALAP YP 30-80 20-30 15-30 Funnel Viscosity 250-300 Permafrost Base 100-150 to TD N/A N/A Initial Gel 30-50 8-15 5-10 10 minute Gel 30-50 < 30 6-15 API Filtrate NC <10 < 6 HTHP Fluid Loss at 120 F N/A N/A <10 H 9.0-10.0 9.0-10.0 9.0-9.5 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (000) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application fora Permit to Drill must be accompanied by each of the following items. except for an them ah eady on file with the commission and identified in the application: The proposed drilling program follows. Please refer to attachment for proposed well schematic. Note: Previous operations are covered under the I H-104 and 1H -104L1 Application for Permit to Drill. I . With 6-3/4" bit, motor, GR/Res, and magnets, and drill —200' of new hole in the D sand. POOH. 2. Pick up 6-3/4" RSS lateral drilling assembly with GR, Res, periscope and RIH. 3. Drill lateral geosteering in the D sand and reach TD per directional plan. 4. BROOH to window and circulate clean before coming out and laying down BHA. 5. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 6. Run 4.5" slotted liner with hook hanger and MWD for orientation. POOH with running tools. 7. Make up and run in hole to install LEM (lateral entry module) with ZXP packer. POOH with running tools. S. PU gas lift completion as required and RIH to depth, land tubing. 9. Nipple down BOPE, nipple up tree and test. 10. Freeze protect well with diesel by pumping into 4-1/2" x 7-5/8" annulus, taking returns from tubing and allowing to equalize. 11. Ensure well is secure and move rig off. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application far a Permit to Drill muste be accompanied by each of rhe following items. except for an item already on file with the commission and identified in the application: (I4) a general description at how the operator plans to dispose of drilling mud and cuttings and a statement of,, hether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.: Waste fluids and cuttings generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well at the 1 B Facility. If needed, excess cuttings generated will be hauled to Milne Point or Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment I BOP Ram Placement Attachment 2 Well Schematic Attachment 3 Diverter LayOnt Diagram Attachment 4 Directional Plan Attachment 5 Drilling Hazards Summary 14:00, July 03 2018 1 H-104L2wp24 a 5 K-15 \1\WS A3 -WS A2 t r' a c N 0 10 3 13 1/2' IT -.DST-- UG_UU Nai 518" 7/e' -1 0 20" x 42' 3000 6000 9000 12000 4 1/2" x Measured Depth .^n Plan: 54.1+39 @ 93.10Usft (Doyon 142) and L1 Plan Summa o , ry�u o m 20" z 000 0.00-1798.84to T02 063018 RP Stan 31100 DLS, Adl..t T 21', for 196.44' 11 300 -89.941732 85 1 H-1D4L2 3.00 -85.21-1646.99 Hold 31552' Start 3 5°1100' DLS, -11718' TF, for 196.39' s,.�' Nf I 0.00 0.00-1494.60 3.50-117.18-1390.88 1H-10412703063018 RP TFto 12086`, for 225.1' Adjust 1251.94 8014.73 3.50 -120.86-1251.94 Start 3°/100' DLS, -21.73° TF, for 288 89 1249.89 6017 02 1053.37 8224.70 0.00 0.00-1249.89 3.00 -21.73-1053.37 IW1041-2 T04 063018 RP Ho1ust TF to 1tl for 2]6.60', for 11887' -966.76 8306.08 3.00 -90.00 -96676 IE o -75933 8489.1] 8621.78 000 0.00 -759.33 300 -90.00 .59092 1H-10412 T05 W3018 RP AdjustTF to-23.96', for 312,22' -590,92 -330.37 8791.60 3.00 -23.96 330.37 HO for 10 Start for 100' DLS, -117.29° TF, for 322.89' -321,59 8796.91 8934.49 0.00 0.00 -32129 4.00 -117.29 -31.91 1H-1041_2 T06 W3018 RP > n o Ca 0 o a 432.91 W43.31 9070.56 0.00 000 432.91 4.00 -86.76 737.29 1 H-1041-2 707 063018 RP i 737.29 801.95 9067.96 103/4' no 1/2' Holdfor Stan 4.11001 DLS, -128.43' TF, fix 45.73' 1226.97 9041.48 1272.57 9038.07 0.00 0001226.97 4.00-128.431272.57 1H-1041_2 T06063018 RP 40073592' f 1514,40 8999.53 4oD -124.391514,40 a 8142 466.44' 1773.41 216] 83 8675.21 216783 4.00 -82 36 2167.83 Hostl for 98.46' for 227.73' Start 4'/1011' US -81.r TF for 2242.12 8610.65 240157 8448.41 - II TF to 285.452° Holtl ( ,or 905 02' � 'fo 2552 78 8230.78 0 8320 ensured its completeness, and all surrounding 2000 4000 m 100 m II 10C^\ 12000 m +4 0 m m o 2- 'x6-3/4 330 30 9 M20-8580 8500 W80 7 5/8" x 9 7/e aperture ccepted by. Approved bli s ,. 8880 ee6e Huv I Anh Erik Sterk 8860 - W40 +'1 60 9040 - 9220 o -104wp26 300 9120 - 9400 60 iH-1041107024 )8 94M 9080 at P. 9880 9930 m 9930 10190 210190 90 - 104M E 270 10407 - 10710 Cl 3010710 - 18078 a tewa - 11280 11240 - 11503 0Equivalent Magnetic Distance N� j�� 115M - 12040 01�{0 240 il'' 12040 - 12570 8750 9000 9250 9500 9750 10000 � 12e70 - 13110 8250 8500 Measured Depth 1H-1041107024 ' 13110 - 13840 13640 14180 SURVEY PROGRAM U aCe oC8Ia0 1H-1040302 1 150 14180 14710 Depth From Depth TO somylPlan Tool Patl Elevation: 54.10 0 14710 ' - 15240 3800 140300 111-104"se(Plan'. 1H-103) GYD-GCSS 140000 192000 1H-1Mwp25 toln: 1H-1041 MWD+IFR-AK-CAZ-SC 180 15240 15777 ams 192000 8142.00 1H-104wp26(Plan'. 1H.10) MwD+IFR-AK-CAZ-SC 8142.00 8500.00 111-1041LZep24 (Fan 1HANUMw43-INC ONLY 3785.338142.10 7518"x97/8' 3843.10577693 4112'X6 -W4" Magnetic Model & Date: BGGM201e1-Aug-18 3500.01) 10000.00 1H-1Dbt2wp24 (Plan: III IUUMWD 111-1041207024 (Plan: 1H-t04UMw0+IFR-AK-GAZ-SO Magnetic North is 17.06- East of True North (Magnetic Declination) 8500.001577693 Magnetic Dip & Field Strength, 80.91* 57449nT SECTION DETAILS U9,010gy Column MD Inc Azi ND +N/ -S +EI -W Die g TFace VSW2447 Target Annotation KOP: 16°/100'OLS. -20°TF, for 13' Sec 1 8142.00 79 01 78.42 3785.60 .2124.47 5926.13 3787.86 -2121.82 5938S6 0.00 0.00-2124.47 16.00 -20DD-2121.82 Hold for 20' Start 6,5'1100' OLfor 114.85'S, -7.61° TF, ' 28156,00 80.97 7770 38175.00 80.97 77.70 3791 00 .2117.61 5957.95 3801.66 -2092.31 6069.39 0.00 0.002117.61 6.50 -T61-2092.31 Hold for 46 95' Start 3.5°1100' DLS, 5.48° TF, for 3.74' pFROST a ao., 4 8289.85 88.37 76.71 58336.79 88.37 76.71 3803.00 -2081,52 6115.06 000 0,00-2081 52 112.55' 701 WSD 063018 RP T-3 68340.59 88.50 76.70 3803.10-208066 6118.70 8227 22 3.50 6.48-208066 iH-10412 3 50 -88 35.2051 .04 Ho110sfor 851.23'for 69 94' TF for 19198' a' 3 V. Osara .05104 798.84 7039.97 000 0.00-1798.84to T02 063018 RP Stan 31100 DLS, Adl..t T 21', for 196.44' 173285 7220.12 1646.99 7396.66 300 -89.941732 85 1 H-1D4L2 3.00 -85.21-1646.99 Hold 31552' Start 3 5°1100' DLS, -11718' TF, for 196.39' 1494.60 767302 139088 7839.44 0.00 0.00-1494.60 3.50-117.18-1390.88 1H-10412703063018 RP TFto 12086`, for 225.1' Adjust 1251.94 8014.73 3.50 -120.86-1251.94 Start 3°/100' DLS, -21.73° TF, for 288 89 1249.89 6017 02 1053.37 8224.70 0.00 0.00-1249.89 3.00 -21.73-1053.37 IW1041-2 T04 063018 RP Ho1ust TF to 1tl for 2]6.60', for 11887' -966.76 8306.08 3.00 -90.00 -96676 Start 3°/100' OLS, -90° TF, for 214 4]' -75933 8489.1] 8621.78 000 0.00 -759.33 300 -90.00 .59092 1H-10412 T05 W3018 RP AdjustTF to-23.96', for 312,22' -590,92 -330.37 8791.60 3.00 -23.96 330.37 HO for 10 Start for 100' DLS, -117.29° TF, for 322.89' -321,59 8796.91 8934.49 0.00 0.00 -32129 4.00 -117.29 -31.91 1H-1041_2 T06 W3018 RP for 219 94' -31.91 179.81 8993.06 4.00 -105.60 179.81 Hsjtl far 258.04'5.6', Start 4°/100' OILS, -8636' TF, for 306.19' 432.91 W43.31 9070.56 0.00 000 432.91 4.00 -86.76 737.29 1 H-1041-2 707 063018 RP AdjustTF too 82S', for 64.72' 737.29 801.95 9067.96 4.00 -82.50 801,95 Holdfor Stan 4.11001 DLS, -128.43' TF, fix 45.73' 1226.97 9041.48 1272.57 9038.07 0.00 0001226.97 4.00-128.431272.57 1H-1041_2 T06063018 RP 40073592' to 24.39', for 245.47' Hold 1514,40 8999.53 4oD -124.391514,40 Stan 4°/100' DLS, -81.12° TF, for 236.58' 1549.22 8991.41 8919.34 0.00 0.00 15,1912 4.00 -81121773.41 1H-10412 T09063018 RP 466.44' 1773.41 216] 83 8675.21 216783 4.00 -82 36 2167.83 Hostl for 98.46' for 227.73' Start 4'/1011' US -81.r TF for 2242.12 8610.65 240157 8448.41 0.00 0.00 2242.12 4.00 -8152 2401.57 1H-10412 T10 W3018 RP II TF to 285.452° Holtl ( ,or 905 02' � 'fo 2552 78 8230.78 4.00 -78.85 2552.78 00 0 00 2999 24 1 H tUL2 T11 083018 RP To 5� 93' MD 38431' ND 2999,24 7444 21 0 By signing this I acknowledge that I have been Informed of all risks, checked that the data 1s ensured its completeness, and all surrounding wells are assigned to the proper correct, and I approve the scan and collision avoidance plan as set out in the audit pack.l position, approve it as the basis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. I ccepted by. Approved bli Checked by: Huv I Anh Erik Sterk K-15 an,I UG_c TUG B UG A Na I H-104L2wp24 Section View 20" x 42" 0" 650- 1000 1300-' 3p° J( 2000 x1950 10 3/4" x 13 1/ n 600 N �O 2 2600 0O f o 9 A BO Ar+ N ? 3250A OD 0 4 1/2" x 6-3/4"', cID opo ^ 7 5/8" x 9 7/8"" o T 0 650 1300 1950 2600 3250 -1950 -1300 -650 Vertical Section at 0.00° (650 usft/in) 1 H-104L2wp24 Section View 3780 0 4 1/2" x 6-311 o 7 5/8" x 9 7/8' _ _ qaK� o 0 o O A ; 3850 a P 0 0 v F O O v N N � O O O 3920-N r3920 - mo U A r a :?3990- 39904060 4060 4130-1 -2550 -1700 -850 0 850 1700 2550 3400 4250 Vertical Section at 0.00° (850 usft/in) ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 11-1-104 500292360600 Plan: 11-1-1041-2 Plan: 1 H-104L2wp24 Standard Proposal Report 03 July, 2018 ConocoPhillips 7/10/2018 11:52:48.4M Page 2 COMPASS 5000.14 Build 85 1H-104L2wP24 Plan Survey Tool Program Schlumberger ConocoPhillips Tie OnDepth: 8,142.00 Standard Proposal Report Phase:PLANDepth 1H-1041-2wp24(Plan: 1 H-1041-2) MWD-INC_ONLY Local Coordinate Reference: Well Plan: 1H-104 Database: OAKEDMP2 ection: (usft) (usft) Plan: 54.1+39 Q 93.10uSft (Doyon 142) Company: Conoc i(Alaska) Inc. -Kup1 39.00 0.00 D Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) Project: ver Uni[ Kuparulk k River 1H-104L2wp24(Plan: 11-1-1041-2) M MD Reference: True • Site: Kuparuk 1H Pad MWD+IFR AK CAZ SCC North Reference: Survey Calculation Method: Minimum Curvature , Well: Plan: 1H-104 Wellbore: Plan: 1H-1041-2 Design: 1H-104L2wp24 River Unit, North Slope Alaska, United States System Datum: Mean Sea Level :Kuparuk EDatum: Using Well Reference Point Using geodetic scale factor Sib Kuparuk 1 H Pad Northing: Latitude: Site Position: Longitude: From: Map Easting: 0" Grid Convergence: 0.37' Position Uncertainty: 0.00 usft Slot Radius: Plan: 1H-104 E.-0 +NIS 811.26 usft Northing: Latitude: Longitude: +E/ -W 376.91 usft Easting: Ground Level: 54.10 usft ertainty 0.00 usft Wellhead Elevation: Waltham Plan iH-1041-2 Model Name Sample Date Declination Dip Angle Field Strength (n7) Magnetics (,) C) crrnnvm8 8/1/2018 17.06 80.91 57,449 7/10/2018 11:52:48.4M Page 2 COMPASS 5000.14 Build 85 1H-104L2wP24 Plan Survey Tool Program es: Depth To (usft) Tie OnDepth: 8,142.00 FAud.,gt Phase:PLANDepth 1H-1041-2wp24(Plan: 1 H-1041-2) MWD-INC_ONLY From (ND)+NIS +E/ -W Direction ection: (usft) (usft) (usft) (�) 39.00 0.00 0.00 0.00 7/10/2018 11:52:48.4M Page 2 COMPASS 5000.14 Build 85 Date 7/10/2018 Plan Survey Tool Program Depth From I (usft) Depth To (usft) Survey (Wellbore) Tool Name Remarks 1 8,142.00 8,500.00 1H-1041-2wp24(Plan: 1 H-1041-2) MWD-INC_ONLY MWD-INC_ONLY_FILLER 2 8,500.00 10,000.00 1H-104L2wp24(Plaw 1 H-1041-2) MWD MWD - Standard 3 8,500.00 15,776.93 1H-104L2wp24(Plan: 11-1-1041-2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/10/2018 11:52:48.4M Page 2 COMPASS 5000.14 Build 85 7/102018 11:52:48AM Page 3 COMPASS 5000.14 Build 85 Schlumberger ConocoPhillips Standard Proposal Report Local Corordinate Reference: Well Plan. 1H-104 Database: CAKEDMP2 Plan: 54.1+39 @ 93.10usft (Doyon 142) Company: P y' ConocoPhillips (Alaska) Inc. -KUP1 TVD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1 H Pad North Reference: True Survey Calculation Method: Minimum Curvature Well: Plan: 1 H-104 Wellborn: Plan: 1H -104L2 Design: 1H-104L2wp24 --I Plan Sections Vertical Dogleg Build Turn Measured Depth Inclination Azimuth Depth +N/ -S +E/ -W Rate (-/100usft) (°1100usft) Rate (°1100usft) Rate TFO 0 Target (usft) (`) (') (usft) (usft) (usft) 79.01 7842 3,785.60 -2,124.47 5,926.13 0.00 0.00 0.00 0.00 8,142.00 77.70 3,787.86 -2,121.82 5,938.66 16.00 15.04 -5.54 -20.00 8,155.00 80.97 77.70 3,791.00 -2,117.61 5,957.95 0.00 0.00 0.00 0.00 8,175.00 80.97 76.71 3,801.66 -2,092.31 6,069.39 6.50 6.44 -0.86 -7.61 8,289.85 88.37 76.71 3,803.00 -2,081.52 6,115.06 0.00 0.00 0.00 0.00 8,336.79 88.37 3.50 3.48 -0.40 -6.48 1H-1041-2 T01 WSD[ 8,340.54 88.50 76.70 3,803.10 -2,080.66 6,118.70 -88.35 8,453.09 88.62 72.76 3,805.93 -2,051.04 6,227.22 3.50 0.10 -3.50 0.00 9,304.32 88.62 72.76 3,826.48 -1,798.84 7,039.98 0.00 0.00 0.00 -89.94 1H-10412 T0206301; 9,496.30 88.63 67.00 3,831.10 -1,732.85 7,220.12 3.00 0.01 -3.00 9,692.74 89.13 61.13 3,834.95 -1,646.99 7,396.66 3.00 0.25 -2.99 -85.21 0.00 10,008.37 89.13 61.13 3,839.75 -1,494.60 7,673.02 0.00 0.00 0.00 -117.18 1H-1041-2703063011 10,204.76 86.00 55.00 3,848.10 -1,390.88 7,839.44 3.50 -1.59 -3.12 -120.86 10,429.85 82.00 48.18 3,871.66 -1,251.94 8,014.73 3.50 -1.78 -3.03 0.00 10,432.96 82.00 48.18 3,872.09 -1,249.89 8,017.02 0.00 0.00 0.00 -21.73 1H-1041-2704063011 10,719.84 90.00 45.00 3,892.10 -1,053.37 8,224.70 3.00 2.79 -1.11 90.00 41.43 3,892.10 -966.76 8,306.08 3.00 0.00 -3.00 -90.00 10,838.71 41.43 3,892.10 -759.33 8,489.17 0.00 0.00 0.00 0.00 11,115.38 90.00 0.00 -3.00 -90.00 1H-1041-2705063011 11,329.85 90.00 35.00 3,892.10 -590.92 8,621.78 3.00 -23.96 11,642.07 98.55 31.17 3,868.83 -330.37 8,791.60 3.00 2.74 -1.23 0.00 11,652.45 98.55 31.17 3,867.29 -321.59 8,796.91 0.00 0.00 0.00 -117.29 1H-1041-2706063011 11,975.34 92.50 19.70 3,836.10 -31.91 8,934.49 4.00 -1.87 -3.55 12,195.28 90.12 11.23 3,831.07 179.81 8,993.06 4.00 -1.08 -3.85 -105.60 0.00 12,453.32 90.12 11.23 3,830.55 432.91 9,043.31 0.00 0.00 0.00 -86.76 1H-1041-2 T0706301; 12,759.51 90.80 359.00 3,828.10 737.29 9,070.56 4.00 0.22 -3.99 -82.50 12,824.23 91.14 356.43 3,827.01 801.95 9,067.98 4.00 0.52 -3.97 0.00 13,250.17 91.14 356.43 3,818.55 1,226.97 9,041.48 0.00 0.00 0.00 -128.43 1H-1041-2 T0806301; 13,295.90 90.00 355.00 3,818.10 1,272.57 9,038.07 4.00 -2.49 -3.13 13,541.37 84.47 346.87 3,829.95 1,514.40 8,999.53 4.00 -2.25 -3.31 -124.39 0.00 13,577.28 84.47 346.87 3,833.41 1,549.22 8,991.41 0.00 0.00 0.00 -81.12 1H-1041-2 T09063011 13,813.86 86.00 337.50 3,853.10 1,773.41 6,919.34 4.00 0.65 -3.96 -82.36 14,280.31 88.65 319.01 3,875.08 2,167.83 8,675.21 4.00 0.57 -3.96 14,378.76 88.65 319.01 3,877.40 2,242.12 8,610.65 0.00 0.00 0.00 0.00 -81.52 1H-1041-2 T10063011 14,606.49 90.00 310.00 3,880.10 2,401.57 8,44841 4.00 0.59 -3.96 14,871.91 92.04 299.58 3,875.36 2,552.78 8,230.79 4.00 0.77 -3.93 0.00 -78.85 0.00 1H-1041-2771063011 15776.93 92.04 299.58 3,843.10 2,999.24 7,444.21 0.00 0.00 7/102018 11:52:48AM Page 3 COMPASS 5000.14 Build 85 D; G P; Si IN 'A D ConocoPhillips tabase: OAKEDMP2 mpany: ConocoPhillips(Alaska) Inc.-Kup1 aject: Kupamk River Unit e; Kuparuk 1 H Pad all: Plan: 111-104 alibore: Plan: 11,1-1041-2 sign: 1H-104L2wp24 lanned Survey Measured Depth Inclination Azimuth (usft) (°) (°1 8.142.00 79.01 78.42 KOP: 16°/100' DLS, -20° TF, for 13' 8,142.10 79.01 78.42 7618"x9718"" 8,155.00 80.97 77.70 Hold for 20' 8,175.00 80.97 77.70 Start 6.5°1100' DLS, -7.61° TF, for 114.85' 8,200.00 82.58 77.48 8,289.85 88.37 76.71 Hold for 46.95' 8,300.00 88.37 76.71 8,336.79 88.37 76.71 Start 3.5°1100' DLS, -6.48° TF, for 3.74- 8,340.54 88.50 76.70 Adjust TF to -88.35", for 112.65' 8,400.00 88.56 74.62 8,453.09 88.62 72.76 Hold for 851.23' 8,500.00 88.62 72.76 8,600.00 88.62 72.76 8,700.00 88.62 72.76 8,800.00 88.62 72.76 8,900.00 88.62 72.76 9,000.00 88.62 72.76 9,100.00 88.62 72.76 9,200.00 68.62 72.76 9,247.01 88.62 72.76 w3 c 9,300.00 88.62 72.76 9,304.32 88.62 72.76 Start 3°1100' DLS, -89.94° TF, for 191.98' 9,400.00 88.62 69.89 9,496.30 88.63 67.00 Adjust TF to 55.21°, for 196.44' 9,500.00 88.64 66.89 9,600.00 88.89 63.90 9,692.74 89.13 61.13 Hold for 316.62' 9,700.00 89.13 61.13 9,800.00 89.13 61.13 9,900.00 89.13 61.13 10,000.00 89.13 61.13 10,008.37 89.13 61.13 Start 3.5°1100' DLS, -117.18° TF, for 196.39' 10,100.00 87.67 58.27 10,174,24 86.48 55.95 wS_B 10,200.00 86.08 55.15 10,204.76 86.00 55.00 Adjust TF to -120.86', for 226.1' Vertical Depth (usft) 3,785.60 3,785.62 3,787.86 3,791.00 3,794.58 3,801.66 3,801.95 3,803.00 3,803.10 3,804.63 3,805.93 3,807.07 3,809.48 3,811.89 3,814.31 3,816.72 3,819.14 3,821.55 3,823.97 3,825.10 Schlumberger Standard Proposal Report Local Co-ordinate Reference: Well Plan'. 11-1-104 TVD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) MD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature +N1S (usft) -2,124,47 -2,124.45 -2,121.82 -2,117.61 -2,112.30 -2,092.31 -2,089.97 -2,081.52 -2,080.66 -2,065.94 -2,051.04 -2,037.14 -2,007.51 -1,977.88 -1,948.26 -1,918.63 -1,889.00 -1,859.38 -1,829.75 -1,815.82 3,826.38 -1,800.12 3,826.48 -1,798.84 3,828.79 -1,768.22 3,831.10 -1,732.85 3,831.19 -1,731.40 3,833.34 -1,689.78 3,834.95 -1,646.99 3,835.06 -1,643.48 3,836.58 -1,595.20 3,838.10 -1,546.92 3,839.62 -1,498.64 3,839.75 -1,494.60 3,842.31 -1,448.39 3,846.10 -1,408.13 3,847.77 -1,393.60 3,848.10 -1,390.88 Vertical +E/ -w Section (usft) (usft) 5,926.13 -2,124.47 5,926.23 -2,124.45 5,938.66 -2,121.82 5,957.95 -2,117.61 5,982.12 -2,112.30 6,069.39 -2,092.31 6,079.26 -2,089.97 6,115.06 -2,081.52 6,118.70 -2,080.66 6,176.29 -2,065.94 6,227.22 -2,051.04 6,272.01 -2,037.14 6,367.49 -2,007.51 6,462.97 -1,977.88 6,558.45 -1,948.26 6,653.93 -1,918.63 6,749.41 -1,889.00 6,844.89 -1,859.38 6,940.37 -1,829.75 6,985.26 -1,815.82 7,035.85 -1,800.12 7,039.98 -1,798.84 7,130.58 -1,768.22 7,220.12 -11732.85 7,223.52 -1,731.40 7,314.41 -1,689.78 7,396.66 -1,646.99 7,403.01 -1,643.48 7,490.57 -1,595.20 7,578.13 -11546.92 7,665.69 -1,498.64 7,673.02 -1,494.60 7,752.09 -1,448.39 7,814.35 -1,408.13 7,835.54 -1,393.60 7,839.44 -1,390.88 Dogleg Build Rate Rate (°It00usft) ritiousft) 0.00 0.00 0.00 0.00 16.12 15.16 0.00 0.00 6.50 6.44 6.50 6.44 0.00 0.00 0.00 0.00 3.50 3.48 3.50 0.10 3.50 0.11 0,00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Tum Rate ('/100usft) 0.00 0.00 -5.58 0.00 -0.87 -0.86 0.00 0.00 -0.40 -3.50 -3.50 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.00 0.01 -3.00 3.00 0.01 -3.00 3.00 0.25 -2.99 3.00 0.25 -2.99 3.00 0.26 -2.99 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.50 -1.60 -3.12 3.50 -1.59 -3.12 3.50 -1.59 -3.13 3.50 -1.58 -3.13 7/10201811:52.48AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips [abase: OAKEDMP2 North Reference: ConocoPhillips (Alaska) Inc. -KUP1 mpany: Minimum Curvature )ject: Kuparuk River Unit a: Kuparuk I Pad ,g; Plan: 1H-104 :Ilbore: Plan: 1 HA 0412 sign: 1H-104L2wp24 armed Survey Measured Depth Inclination Azimuth (usR) 10,400.00 82.52 49.09 10,429.85 82.00 48.18 Hold for 3.1' 10,432.96 82.00 48.18 Start 3°1100' DLS, -21.73° TF, for 286.89' 10,500.00 83.87 47.43 10,550.26 85.27 46.87 WS A4 10,600.00 86.66 46.32 10,700.00 89.45 45.22 10,719.84 90.00 45.00 Adjust TF to -90°, for 118.87' 10,800.00 90.00 42.60 10,838.71 90.00 41.43 Hold for 276.67' 10,900.00 90.00 41.43 11,000.00 90.00 41.43 11,100.00 90.00 41.43 11,115.38 90.00 41.43 Start 3°1100' DLS, -90° TF, for 214.47' 11,200.00 90.00 38.90 11,300.00 90.00 35.90 11,329.85 90.00 35.00 Adjust TF to -23.96', for 312.22' 11,400.00 9192 34.15 11,500.00 94.66 32.92 11,600.00 97.40 31.69 11,642.07 98.55 31.17 Hold for 10.37' 11,652.45 98.55 31.17 Start 4°1100' DLS, -117.29° TF, for 322.89' 11,700.00 97.68 29.46 11,800.00 95.82 25.90 11,900.00 93.93 22.36 11,975.34 92.50 19.70 Adjust TF to -105.6, for 219.94' 12,000.00 92.23 18.75 12,100.00 91.15 14.90 12,195.28 90.12 11.23 Hold for 258.04' 12,200.00 90.12 11.23 12,300.00 90.12 11.23 12,400.00 90.12 11.23 12,453.32 90.12 11.23 Start 4°H00' DLS, -86.76- TF, for 306.19' 12,500.00 90.22 9.37 12,600.00 90.45 5.37 12,700.00 90.67 1.38 12,759.51 90.80 359.00 Adjust TF to -82.6°, for 64.7T 12,800.00 91.01 357.39 Schlumberger Standard Proposal Report Local Co-ordinate Reference: TVD Reference: MD Reference: Well Plan: 1 H-104 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Vertical Vertical Depth +N/ -S (usft) (usft) 3,867.64 -1,271.49 3,871.66 -1,251.94 3,872.09 -1,249.89 3,880.34 Vertical Dogleg Build Turn +E/ -W Section Rate Rate Rate (usft) (usft) (°1100usft) (°/100usft) (°1100us@) 7992.53 -1,271.49 3.50 -1.77 -3.04 8,014.73 -1,251.94 3.50 -1.76 -3.05 8,017.02 -1,249.89 0.00 0.00 0.00 3,880.34 -1,205.20 8,066.31 -1,205.20 3.00 2.79 -1.12 3,885.10 -1,171.17 8,102.99 -1,171.17 3.00 2.79 -1.11 3,888.60 -1,137.08 8,139.04 -1,137.06 3.00 2.79 -1.11 3,892.00 -1,067.37 8,210.64 -1067.37 3.00 2.79 -1.10 3,892.10 -1,053.37 8,224.70 -1,053.37 3.00 2.79 -1.10 3,892.10 -995.52 8,280.17 -995.52 3.00 0.00 -3.00 3,892.10 -966.76 8,306.08 -966.76 3.00 0.00 -3.00 3,892.10 -920.81 8,346.64 -920.81 0.00 0.00 0.00 0.00 3,892.10 -845.84 8,412.82 -845.84 0.00 0.00 0.00 0.00 3,892.10 -770.86 8,478.99 -770.86 0.00 3,892.10 -759.33 8,489.17 -759.33 0.00 0.00 0.00 3,892.10 -694.67 8,543.75 -694.67 3.00 0.00 -3.00 3,892.10 -615.24 8,604.47 -615.24 3.00 0.00 0.00 -3.00 -3.00 3,892.10 -590.92 8,621.78 -590.92 3.00 3,890.92 -533.17 8,661.58 -533.17 3.00 2.74 -1.22 3,885.18 -449.96 8,716.73 -449.96 3.00 2.74 -1.22 3,874.67 -365.92 8,769.87 -365.92 3.00 2.74 2.74 -1.23 -124 3,868.83 -330.37 8,791.60 -330.37 3.00 3,867.29 -321.59 8,796.91 -321.59 0.00 0.00 0.00 3,860.57 -280.95 8,820.67 -280.95 4.00 -1.84 -3.59 3,848.82 -193.03 8,866.79 -193.03 4.00 -1.86 -3.56 3,840.33 -102.11 8,907.50 -102.11 4.00 -1.88 -3.54 -3.53 3,836.10 -31.91 8,934.49 -31.91 4.00 -1.90 3,835.08 -8.64 8,942.60 -8.64 4.00 -1.08 -3.86 -3.85 3,832.13 87.02 8,971.52 87.02 4.00 -1.08 3,831.07 179.81 8,993.05 179.81 4.00 -1.09 -3.85 3,831.06 184.44 8,993.97 184.44 0.00 0.00 0.00 0.00 3,830.86 282.53 9,013.45 282.53 0.00 0.00 0.00 0.00 3,830.66 380.61 9,032.92 380.61 0.00 0.00 0.00 3,830.55 432.91 9,043.31 432.91 0.00 3,830.42 478.84 9,051.65 478.84 4.00 0.23 0.23 -3.99 -3.99 3,829.84 577.99 9,064.48 577.99 4.00 4.00 0.22 -3.99 3,828.86 677.79 9,070.36 677.79 737.29 4.00 0.22 -4.00 3,828.10 737.29 9,070.56 3,827.46 777.75 9,069.28 777.75 4.00 0.52 -3.97 7/102018 11:52:48AM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips Database: Company: Project: Site: Well: Wellbore: Design: Planned Survey OAKEDMP2 ConocoPhillips (Alaska) Inc. -Kupl Kupawk River Unit Kuparuk I Pad Plan: iH-104 Plan. 1H-10412 11-1-1041-2wp24 Measured Well Plan'. IH -104 Build Depth Inclination Azimuth TVD Reference: (usft) MD Reference: Rate Hold for 426.94' True (`/10ousft) 12,900.00 91.14 356.43 13,000.00 91.14 356.43 13,100.00 91.14 356.43 13,200.00 91.14 356.43 13,250.17 91.14 356.43 Start 4°1100' DLS, -128A3° TF, for 45.73' 13,295.90 90.00 355.00 Adjust TF to -124.39', for 245.47' 0.00 13,300.00 89.91 354.86 13,400.00 87.65 351.56 13,500.00 85.40 348.25 13,541.37 84.47 346.87 Hold for 35.92' -2.26 -3.30 13,577.28 84.47 346.87 Start 4°1100' DLS, -81.12° TF, for 236.58- 13,600.00 84.61 345.97 13,700.00 85.25 342.00 13,800.00 85.91 338.05 13,813.86 86.00 337.50 Adjust TF to 42.366, for 466.44' 4.00 13,900.00 86.47 334.08 14,000.00 87.02 330.11 14,100.00 87.59 326.15 14,200.00 88.17 322.19 14,280.31 88.65 319.01 Hold for 9"' 3,844.41 1,666.92 14,300.00 88.65 319.01 14,378.76 88.65 319.01 Start 4°M00' DLS, -81.52" TF, for 227.73' 14,400.00 88.77 318.17 14,500.00 89.36 314.21 14,600.00 89.96 310.26 14,606.49 90.00 310.00 Adjust TF to -78.86°, for 265.42' 1851.79 14,700.00 90.72 306.33 14,800.00 91.49 302.40 14,871.91 92.04 299.58 Hold for 905.02' 3,869.15 2,024.81 14,900.00 92.04 299.58 15,000.00 92.04 299.56 15,100.00 92.04 299.58 15,200.00 92.04 299.58 15,300.00 92.04 299.58 15,400.00 92.04 299.58 15,500.00 92.04 299.5E 15,600.00 92.04 299.5E 15,700.00 92.04 299.5£ 15,776.93 92.04 299.5E TD: 16776.93' MD, 3843.1' TVD 0.00 Schlumberger Standard Proposal Report Local Co-ordinate Reference: Well Plan'. IH -104 Build Plan: 54.1+39 @ 93.10usft (Doyon 142) TVD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) MD Reference: Rate North Reference: True Survey Calculation Method: Minimum Curvature Vertical Depth +N/S (usft) (usft) Vertical Dogleg Build Tum +EI -W Section Rate Rate Rate (usft) (usft) (11100usft) (`/10ousft) (-)100usft) 3,825.50 877.55 9,063.26 877.55 0.00 0.00 0.00 0.00 0.00 3,823.52 977.34 9,057.04 977.34 0.00 0.00 0.00 3,821.53 1,077.12 9,050.82 1,077.12 0.00 0.00 0.00 3,819.55 1,176.91 9,044.60 1,176.91 0.00 3,818.55 1,226.97 9,041.48 1,226.97 0.00 0.00 0.00 3,818.10 1,272.57 9,038.07 1,272.57 4.00 -2.49 -3.13 3,818.10 1,276.66 9,037.70 1,276.66 4.00 -2.26 -3.30 3,820.24 1,375.91 9825.89 1,375.91 4.00 -2.26 -3.30 -3.31 3,826.30 1,474.16 9,008.40 1,474.16 4.00 -2.25 3,829.95 1,514.40 8,999.53 1,514.40 4.00 -2.24 -3.33 3,833.41 1,549.22 8,991.41 1,549.22 0.00 0.00 0.00 3,835.57 1,571.20 8,986.10 1,571.20 4.00 0.62 -3.97 3,844.41 1,666.92 8,958.62 1,666.92 4.00 0.64 0.66 -3.96 -3.96 3,852.12 1,760.61 8,924.57 1,760.61 4.00 3,853.10 1,773.41 8,919.34 1,773.41 3.99 0.67 -3.95 3,858.76 1,851.79 8,884.10 1851.79 4.00 0.54 -3.97 3,864.45 1,940.00 8,837.38 11940.00 4.00 0.56 0.57 -3.97 -3.96 3,869.15 2,024.81 8,784.65 2,024.81 4.00 0.58 -3.96 3,872.85 2,105.81 8,726.16 2,105.81 4.00 3,875.08 2,167.83 8,675.21 2,167.83 4.00 0.59 -3.96 3,875.54 2,182.69 8,662.29 2,182.69 0.00 0.00 0.00 0.00 3,877.40 2,242.12 8,610.65 2,242.12 0.00 0.00 3,877,88 2,258.05 8,596.60 2,258.05 4.00 0.59 -3.96 3,879.51 2,330.19 8,527.40 2,330.19 4.00 0.59 -3.96 3,880.10 2,397.39 8,453.37 2,397.39 4.00 0.60 -3.96 3,880.10 2,401.57 8,448.41 2,401.57 4.00 0.60 -3.95 3,879.51 2,459.34 8,374.90 2,459.34 4.00 0.77 -3.92 3,877.58 2,515.77 8,292.39 2,515.77 4.00 0.77 0.76 -3.93 -3.93 3,875.36 2,552.78 8,230.79 2,552.78 4.00 3,874.36 2,566.64 8,206.37 2,566.64 0.00 0.00 0.00 0.00 3,870.79 2,615.97 8,119.46 2,615.97 0.00 0.00 0.00 0.00 3,867.23 2,665.30 8,032.55 2,665.30 0.00 0.00 0.00 3,663.66 2,714.63 7,945.64 2,714.63 0.00 0.00 0.00 3,860.10 2,763.96 7,858.72 2,763.96 0.00 3,856.53 2,813.29 7,771.81 2,813.29 0.00 0.00 0.00 0.00 3,852.97 2,862.62 7,684.90 2,86262 0.00 0.00 0.00 0.00 3,849.41 2,911.96 7,597.99 2,911.96 0.00 0.00 0.00 3,845.84 2,961.29 7,511.08 2,961.29 0.00 0.00 0.00 3,843.10 - 2,999.24 7,444.21 2,999.24 0.00 7/10!2018 71:52:48AM Page 6 COMPASS 5000.14 BuW 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupt Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-104 Wellbore: Plan: 1H -104L2 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Design: Design Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NIS +E/ -W -Shape (1) (1) (usft) (usft) (usft) 1H -104L2 T01 WSD OK 000 0.00 3,803.10 -2080.66 6,118.70 - plan hits target center - Circle (radius 100.00) iH-1041_2 T08 063018 F 0.00 0.00 3,818.10 1,272.57 9,038.07 - plan hits target center - Circle (radius 100.00) iH-1041-2 708063018 F 0.00 0.00 3,818.10 1,272.57 9,038.07 - plan hits target center - Circle (radius 1,320.00) 1 H-10412 T07 063018 F 0.00 0.00 3,828.10 737.29 9,070.56 - plan hits target center - Circle (radius 100.00) 1H-1041-2702063018 F 0.00 0.00 3,831.10 -1,732.85 7,220.12 - plan hits target center - Circle (radius 1,320.00) 1 H-1041_2 T02 063018 F 0.00 0.00 3,831.10 -1,732.85 7,220.12 - plan hits target center -Circle(radius 100.00) I H-10412 TO6 063018 F 0.00 0.00 3,836.10 -31.91 8,934.49 - plan hits target center - Circle (radius 1,320.00) 1 H-1041_2 T06 063018 F 0.00 0.00 3,836.10 -31.91 8,934.49 - plan hits target center - Circle (radius 100.00) 1H-1041-2771063018 R 0.00 0.00 3,843.10 2,999.24 7,444.21 - plan hits target center - Circle (radius 1,320.00) 1 H-10412 T11 063018 R 0.00 0.00 3,843.10 2,999.24 7,444.21 - plan hits target center - Circle (radius 100.00) 1H-1041_2703063018 F 0.00 0.00 3,848.10 -1,390.88 7,839.44 - plan hits target center - Circle (radius 100.00) 1 H-1041_2 T09 063018 F 0.00 0.00 3,853.10 1,773.41 8,919.34 - plan hits target center -Circle (radius 100.00) 1 H-1041-2 T10 063018 F 0.00 0.00 3,880.10 2,401.57 8,448.41 - plan hits target center - Circle (radius 100.00) 1H-1041_2704063018 F 0.00 0.00 3,892.10 -1,053.37 8,224.70 - plan hits target center - Circle (radius 1,320.00) 1H-1041_2704063018 F 0.00 0.00 3,892.10 -1,053.37 8,224.70 - plan hits target center - Circle (radius 100.00) 1 H-10412 T05 063018 F 0.00 0.00 3,892.10 -590.92 8,621.78 - plan hits target center -Circle (radius 100.00) Schlumberger Standard Proposal Report Well Plan. 1H-104 Plan. 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature 7/102018 11:52:48AM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Con=Philli s (Alaska) Inc. -KuP1 Company: p ) p project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: Plain 11-1-104 Wellbore: Plan: 1H-1041-2 Design: iH-104L2wp24 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Schlumberger Standard Proposal Report Well Plan'. 1 H-104 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature Casing Points Casing Hole Measured Vertical Diameter Diameter Depth Depth (..) (••) (usft) (usft) Name 20 42 118.10 118.10 20"x42" 10-3/4 13-1/2 1,918.25 1,800,00 10 3/4" x 13 1/2" 7-5/8 9-7/8 8,142.10 3,785.33 75/8"x97/8•" 4-1/2 6-3/4 15,776.93 3,843.10 4 1/2" x 6-3/4" _ Formations Dip Measured Vertical Di p Direction Depth Depth (>) (usft) (usft) Name Lithology, (") 1,724.87 1,641.10 Base Pfrosl 1,936.03 1,814.10 T3 2,266.31 2,051.10 K15 5,414.37 3,053.10 UG_C 6,489,58 3,360.10 UG_B 6,832.81 3,458.10 UG_A 7,169.03 3,554.10 Na 8,129.47 3,783.10 WS_D 9,247.01 3,825.10 WS_C 10,174.24 3,846.10 WS_B 10,550.26 3,865.10 WS–A4 — — 7/102018 11:52:48AM Page 8 COMPASS 5000.14 Build 85 Schlumberger ConocoPhillips Standard Proposal Report Database: Company: Project: Site: Well: DAKEDMP2 ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparak 1H Pad Plan' 111-104 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well Plan: 1H-104 Plan'. 54.1+39 Q 93.10usft (Doyon 142) Plan: 54.1+39 (9 93.10usft (Doyon 142) True Minimum Curvature Wellbore: Plan: 1H-1041-2 +N/ -S +EI -W Design: 1H-104L2wp24 - - (usft) Plan Annotations Comment 8,142.00 3,785.60 Measured Vertical Local Coordinates Depth Depth +N/ -S +EI -W (usft) (usft) (usft) (usft) Comment 8,142.00 3,785.60 -2,124.47 5,926.13 KOP: 16°/100' DLS, -20° TF, for 13' 8,155.00 3,787.86 -2,121.82 5,938.66 5,957.95 Hold for 20' Start 6.5°/100'OLS, -7.61°TF, for 114.85' 8,175.00 3,791.00 -2,117.61 8,289.85 3,801.66 -2,092.31 6,069.39 6,115.06 Hold for 46.95' Start 3.5°/100'DLS,-6.48°TF, for 3.74' 8,336.79 3,803.00 3,803.10 -2,081.52 -2,080.66 6,118.70 Adjust TF to -88.35°, for 112.55' 8,340.54 8,453.09 3,805.93 -2,051.04 6,227.22 Hold for 851.23' Start 3°/100' DLS, -89.94° TF, for 191.98' 9,304.32 3,826.48 -1,798.84 -1,732.85 7,039.98 7,220.12 Adjust TF to -85.21°, for 196.44' 9,496.30 9,692.74 3,831.10 3,834.95 -1,646.99 7,396.66 Hold for 315.62' 10,008.37 3,839.75 -1,494.60 7,673.02 Start 3.5°/100' DLS, -117.18° TF, for 196.39' 10,204.76 3,848.10 -1,390.88 7,839.44 Adjust TF to -120.86°, for 225.1' 10,429.85 3,871.66 -1,251.94 8,014.73 Hold for 3.1' Start 3°/100' DLS, -21.73° TF, for 286.89' 10,432.96 3,872.09 -1,249.89 8,017.02 8,224.70 Adjust TF to -90°, for 118.87' 10,719.84 10,838.71 3,892.10 3,892.10 -1,053.37 -966.76 8,306.08 Hold for 276.67' 11,115.38 3,892.10 -759.33 8,489.17 Start 3°/100'DLS,-90°TF, for 214.47' 11,329.85 3,892.10 -590.92 8,621.78 Adjust TF to -23.96°, for 312.22' 11,642.07 3,868.83 -330.37 8,791.60 8,796.91 Hold for 10.37' Start 4°/100' DLS, -117.29° TF, for 322.89' 11,652.45 3,867.29 -321.59 8,934.49 Adjust TF to -105.6°, for 219.94' 11,975.34 12,195.28 3,836.10 3,831.07 -31.91 179.81 8,993.05 Holdfor258.04' 12,453.32 3,830.55 432.91 9,043.31 Start 4°/100' DLS, -86.76° TF, for 306.19' 12,759.51 3,828.10 737.29 9,070.56 Adjust TF to -82.5°, for 64.72' 12,824.23 3,827.01 801.95 9,067.98 9,041.48 Holdfor425.94' Start 4°/100' DLS, -128.43° TF, for 45.73' 13,250.17 3,818.55 1,226.97 1,272.57 9,038.07 Adjust TF to -124.39°, for 245.47' 13,295.90 13,541.37 3,818.10 3,829.95 1,514.40 8,999.53 Hold for 35.92' 13,577.28 3,833.41 1,549.22 8,991.41 Start 4°/100' DLS, -81.12° TF, for 236.58' 13,813.86 3,853.10 1,773.41 8,919.34 Adjust TF to -82.36°, for 466.44' 14,280.31 3,875.08 2,167.83 8,675.21 8,610.65 Hold for 98.46' Start 4°/100' DLS, -81.52° TF, for 227.73' 14,378.76 3,877.40 3,680.10 2,242.12 2,401.57 8,448.41 Adjust TF to -78.85°, for 265.42' 14,606.49 14,871.91 3,875.36 2,552.78 8,230.79 Hold for 905.02' c ". o¢ 3 A41 1n 2.999.24 7,444.21 TD: 15776.93' MD, 3843.1' TVD 7/102018 11:52:48AM Page 9 COMPASS 5000.14 Build 85 ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1H Pad Plan: 11-1-`104 Plan: 1 H-1041-2 500292360600 1 H-104L2wp24 ConocoPhillips Clearance Summary Anticollision Report 03 July, 2018 T2¢ Cyl'mtlerfrorth Proximity Scan on Current Survey Data (North Reference) Reference Design: KuparuklHPa4-Plan:1H-004-PIan:1H-104L2-1H-104L2wp24 Datum Height PIan:54.1a19@9310usXlDoyon142) Scan Range: 8.140.00 to 15,])].5] pelt Measured Depth. Scan Radius i5 1]]2.86 pan. Clearance FactorcutoX is Unlimited Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied versmn: 5000.14 Build: 85 Scan Type: GLOBAL FILTER APPLIED'. All wellpaths within 200'+ 100/1000 of reference Scan Type: 25 00 ConocoPhillips ConocoPhillips Anticollision Report for Plan: 1 H-104 -1 H-104L2wp24 ConocoPhillips(Alaska) Inc.-Kupa Kuparuk River Unit Tray. Cylinder Non, Proximity Scan on current Survey Data (North Reference) Reference Design: Kuparvk JHPad-PIen:1H404-Plan:IK.104L2-1H-104L2"24 Scan Range: 6,140.00 to 15,777.57 usft. Measured Depth. Scan Radius is 1,773.86 ueh. Clearenoe Factor cutoff is Unlimited Max Enipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary asked on Separation Warning Ste Name Depth Distance Depth Separation Depth Factor Minimum Dom .Well Name -Wellbore Name -Desi insist) (..ft) (usft) (use) unt pariso g" Kuparint 1H Pad 1,151.59 15,]]6.96 927.80 11,600.00 5.146 Clearance Factor Pass -Major Ruk 1H -103 -1H -103-1H-103 15,776.96 937.06 11575.00 5.221 clearance, Factor Pass - Major Risk 1H -103-1+1031-1-1H-1031-1 15,]]].5] 1,159.07 15,777.57 7975.00 6.106 Clearance Factor Pass - Major Risk %167.321,206.19 8,167.32 1,000.65 Risk 1H -103 -1H -1031-2-1H-1031-2 8,165.02 1,001.08 ],975.00 5.754 Claimants,Fadar Paas - Major 1H-103-1+1031-3-1+10313 8.165.02 1,21188 1,037.34 ],9]5.00 5.956 Cleareace Factor Pass -Major Risk 1H -103 -1H -10314-1H-1031-4 8,140.00 1,246.66 0,140.00 409.60 8,150.00 203.08 8,975.00 1.991 Cleamnce Factor Pass - Major Risk IH-108-iH-100A-1H-108A 8,150.00 203.88 8,975.00 1.991 Clearance Factor Pass -Major Risk 1 HA 08 -1H -108A -1H -108A 8,150.00 409.60 8,150.00 10,950.00 3.794 Clai anw Factor Pass. Major Risk 1H -108 -Plan: 1H-108B-1H-1088IP04 9892.90 893.33 9,892.90 657.89 4.911 Centre Distance Pass. Major Risk 11,14].00 855.46 11,147.00 681.26 12,52500 1H-108-PIem 1H -1088-1H-1088 wp04 9,892.90 657.89 10,950.00 3.794 Clearance Factor Pass. Major Risk 1H -108 -Plan: 1H -1008 -1H -108B wp04 9,892.90 893.33 12,525.00 4.911 Centre Distance Pass - Major Risk 1H -100 -Plan: 1+10813-iH-108B p04 11,14].00 055.46 11,147.00 fi8126 511.93 0,140.00 299.96 7,950.00 2415 Claimants, Faclar pass. Major Risk 1H-110-iH-110-1H-110 8,140.00 12,910.45 575.50 10,/75.00 ance Factor 5.730 Ckre Pass - Major Risk 1H -113-1H-113-1+113 12,91045 69].18 32.12iiiiiiiiiiiiim Clearance Plan: I H-1 04 - Plan: IHAN-1H-104wp26 8,445.60 39.]1 8445.88 1H-104-Plan: 1H-104L1-1H-1041-1bP24 Plan: 1+104 -Plan: 1114041-1 - I H -i D411 124 -- - Rig: 111-115-1+115-1H-115"22 14.659.10 549.29 14.659.10 350.91 10,725.00 2.885 Cleaner. Factor Pass - Major Risk COMPASS 03.NIy, 2018 - 13:56 Page 2 of 5 r ConocoPhillips Anticollision Report for Plan: 1 H-104 -1 1-1-1041.2wp24 Survey tool program Ellipse error terms are cenalated across survey tool tie -on points. Calculated ellipses incorporate aurfi ce errors. Separation is the actual distance bamann ellipsoids. Distance Between centres is the straight line distance beMreen wellbore centres. Clearance Factor= Distance B...e Profiles / (Distance Between Profiles- Ellipse Separation). MI station coordinates were calculated using the Minimum Curvature method. ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit COMPASS 0 lev tale - 1156 Pepe 3 ot5 SurvayRtan Survey Tool Fmm To (uspl (uso) GYD-GCSS 39.00 1.400.00 MWD*IFR-AK-CA -SC 1,400.00 1,920.00 MWDtIFR-AK-CAZSC 1,920.00 8,14200 MWD-INC 8,142.00 8,50000 1+1041.2wp24 _ONLY MVsD 8,500.90 10,000.00 111-1041-2,,24 MM0FR-AK-O SC 8.500.00 15,]]6 93 1 H-1041-2wp24 Ellipse error terms are cenalated across survey tool tie -on points. Calculated ellipses incorporate aurfi ce errors. Separation is the actual distance bamann ellipsoids. Distance Between centres is the straight line distance beMreen wellbore centres. Clearance Factor= Distance B...e Profiles / (Distance Between Profiles- Ellipse Separation). MI station coordinates were calculated using the Minimum Curvature method. ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit COMPASS 0 lev tale - 1156 Pepe 3 ot5 13:59. July 03 2010 1 H-104L2wp24 Ladder View 300 — IIL a C l6 m200 Q 0) U) V W J U o al 00 c w U Equivalent Magnetic Distance 0 9000 10000 11000 12000 13000 14000 15000 Measured Depth UR E PROGRAM CASING DETALS Depth Frobepth To Survey/Plan Tool TVD 3785.8842.18 MD Name 5/8" x 9 7/8"" 39.00400.00 1H-104wp26 (Plan: 1H©VAkGC-SS 1400.00920.00 1H-104wp26 (Plan: 1HMSP+IFR-AK-CAZ-SC 3843BZ76.9341/2" x6-3/4" 1920.03142.00 1H-104wp26 (Plan: 1HM'0P+IFR-ONLY Z SC p24 (Plan: WID4t�j_ 8142.03500.00 1H-104L2wN4 8500.00000.00 11-1-1041-2wp24 (Plan: MWD4L2) 8500.00776.93 1H-104L2wp24 (Plan: id1WD4l.[M-AK-CAZ-SC a $3 n 3 Z I e i. 060 to Q v U Equivalent Magnetic Distance 0- - 8400 8800 9200 9600 10000 10400 10800 112( Partial Measured Depth 14:01, Ju1Y 03 2018 j 1 H-104L2wp24 TC View 270 1H- C 0 MD 142.00 155.00 Inc 79.01 80.97 Azi 76.42 77.70 TVD 3785.60 3787.86 Dleg 0.00 16.00 TFace 0.00 -20.00 Target Annotation KOP: 16°/100' DLS, -20° TF, for 13' Hold for 20' Start DLS, -7.61° TF, for 114.E Ah Frol®epth To Tool 39.001400.00 GYD-GC-SS 175.00 80.97 77.70 3791.00 0.00 0.00 9660 for6.4600' Hold for 46.95' 1400.001920.00 MWD+IFR-AK-CAZ-SC 289.85 88.37 76.71 380166 6.50 -7.61 0.00 10710 Start 3.5°/100' DLS, -6.48° TF, for 3.74' MWD+IFR-AK-CAZ-SC 336.79 88.37 76.71 76.70 3803.00 3803.10 0.00 3.50 -6.48 1H-1041-2 T01 WSD 063018 RAdjust TF lo -88.35°, for 112.55' 1920.008142.00 8142.008500.00 MWD -INC ONLY 340.54 453.09 88.50 88.62 72.76 3805.93 3.50 -88.35 14710 Hold W/101Yfor .23' Start 3°/100' DLS, -89.94° TF for 191.9 $$QQ.Om000.00 MWD 304.32 88.62 72.76 67.00 3826.48 3831.10 0.00 3.00 0.00 -89.94 iH-10412702063018 RP Atljust TF to -85.21°, for 196.44' 8500,01B776.93 MWD+IFR-AK-CAZ-SC 496.30 692.74 88.63 89.13 61.13 3834.95 3.00 -85.21 Hold for 315.62' Start 3.5°/100' OLS, -117.18° TF, for 19 008.37 89.13 61.13 3839.75 0.00 3.50 0.00 -117.18 1H-1041-2 703063018 RP Adjust TF to -120.86°, for 225.1' 204.76 429.85 86.00 82.00 55.00 48.18 3848.10 3871.66 3.50 -120.86 Hold for 3.1' Start 3°/100' DLS, for 286.E 432.96 82.00 48.18 3872.09 0.00 3.00 0.00 -21.73 1 H-1041.2 T04 063018 RP or 118° 7' Adjust TF to -90°, for 118.87' 719.84 838.71 90.00 90.00 45.00 41.43 3892.10 3892.10 3.00 -90.00 Hold for 276.67' Start 3°/100' DLS, -90° TF, for 214.47' 115.38 90.00 41.43 3892.10 0.00 3.00 0.00 -90.00 1H -104L2 T05063018 RP Adjust TF to -23.96°, for 312.22' 329.85 642.07 90.00 98.55 35.00 31.17 3892.10 3868.83 3.00 -23.96 Hold for 10.37' Start DLS, TF, for 322 652.45 98.55 31.17 3867.29 0.00 4.00 0.00 -117.29 iH-1041-2706063018 RP *, for Adjust TF for 219.94' t TF to' CA IN DETAIL 975.34 195.28 92.50 90.12 19.70 11.23 3836.10 3831.07 4.00 -105.60 Hold for 258.04' Start 4°/100' DLS, -86.76° TF, for 306.' 453.32 759.51 90.12 90.80 1123 359.00 3830.55 3828.10 0.00 4.00 0.00 -86.76 1H-1041.2707063018 RP Adjust TF to -82.5°, for 64.72' TVD MD Name 824.23 91.14 356.43 3827.01 4.00 -82.50 Hold for 425.94' Start 4°/t00'DLS, -128.43- TF, for 45. 3785.338142.10 7 5/6" X 9 7/6 250.17 91.14 356.43 3818.55 0.00 4.00 0.00 1H-1041.2708063018 RP Adjust TF to-124.39°,for 245.47' 3843.1m5776.93 41/2"x6-3/4" 295.90 90.00 355.00 3818.10 3829.95 4.00 -128.43 -124.39 Hold for 35.92' 541.37 84.47 346.87 0.00 Stan 4°/100' DLS, -81.12° TF, for 236.! 577.28 84.47 346.87 3833.41 3853.10 0.00 4.00 -81.12 1H-1041-2 T09 063018 RP Adjust TF to -82.36°, for 466.44' 813.86 280.31 86.00 88.65 337.50 319.01 3875.08 4.00 -82.36 Hold for 98.46' Start 4°/100' DLS,-Bt.52° TF, for 227: 378.76 88,66 319.01 3877.40 0.00 4.00 0.00 iH-1041-2TIO 063018 RP Adjust TF to -78.85°, for 265.42' 606.49 871.91 90.00 92.04 310.00 299.58 3880.10 3875.36 4.00 -81.52 -78.85 Hold for 905.02' MD, 3843.1' TVD 776.93 92.04 299.58 3843.10 0.00 0.00 111-1041-2 T11 063018 RP TD: 15776.93' 270 1H- C 0 - 8142 8142 - 8320 8320 - 8500 8500 - 8680 8680 - 8860 8860 - 9040 9040 - 9220 9220 - 9400 9400 - 9660 9660 9930 9930 - 10190 10190 - 10450 10450 - 10710 10710 - 10970 10970 - 11240 11240 - 11500 11500 - 12040 12040 - 12570 12570 - 13110 13110 - 13640 13640 - 14180 14180 14710 14710 15240 15240 - 15777 1 H-104L2wp24 8140.00 To 15777.57 AC Wells Only Easting (1500 usRfln) wp04 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1 H-104 500292360600 Plan: 11-1-1041-2 Plan: 1 H-104L2wp24 Error Ellipse Survey Report 03 July, 2018 Schlumberger Error Ellipse Report Company: ConowPhillips (Alaska) Inc. -Kupt Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 11-1-104 Wellbore: Plan: 1H-1041-2 Design: 1H-104L2wp24 Project Kupamk River Unit, North Slope Alaska, United States Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan. 1H-104 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Map System: system Datum: Mean Sea Level Using Well Reference Point Geo Datum: Using geodetic scale factor Map Zone: site Kuparuk 1H Pad Northing: Latitude: Site Position: Map Easting: Longitude: ` From: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0'37 Well Plan: 114-104 Well Fashion +N/S 0.00 usft Northing: Latitude: +E/ -W 0.00 usft Easting: Longitude: 54.10 usft Position Uncertainty 0.00 usft Wellhead Elevation: Ground Level: Wellbore Plan. iH-1041-2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) (1 (_) BGGM2018 8/1/2018 17.06 80.91 57,449 Design 1H-104L2wp24 Audit Notes: Phase: PROTOTYPE Tie On Depth: 8,142.00 Version: Vertical Section: Depth From (TVD) +N/S +EAW Direction (I (usft) (usft) (usft) 39.00 0.00 0.00 0.00 Survey Tool Program Date 7/3/2018 From (usft) To (usft) Survey (Wellbore) Tool Name Description 39.00 1400.001H-104WP26(Plan: 1H-104) GYD-GC-SS Gyrodata gyro single shots 1,400.00 1,920.001H-104Wp26(Plan: 11-1-104) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1,920.00 8,142.00 1H-104wp26(Plan: 114-104) MWD+IFR-AK-CAZ-SC MWD -IFR AK CAZ SCC 8,142.00 8,500.00 1H-104L2wp24(Plan: 111-1041-2) MWD -INC ONLY MWD-INC_ONLY FILLER 8,500.00 10,000.0011-1-1041-2wp24(Plan: 11-1-1041-2) MWD MWD - Standard 8,500.00 15,776.93 1H-104L2wp24(Plan: 1H-1041-2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7)3/2018 1:58:33PM Page 2 COMPASS 5000.14 Build 85 Company: ConowPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kupawk 1 H Pad Well: Plan: 1H-104 Wellbore: Plan: 11-1-1041-2 Design: 1H-1041-2wp24 Plan Survey Tool Program Date 7/312018 Depth From Depth To (usft) (usft) Survey (Wellbore( 1 39.00 1,400.00 1H-104wp26(Plan'. 11-1-104) Schlumberger Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method Output errors are at Database: Tool Name Remarks GYD-GC-SS Gymdata gyro single shots 2 1,400.00 1,920.0011-1-104wp26(Plan: 1H-104) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3 1,920.00 8, 142.001H-104wp26(Plan: 1 H-104) MWD+IFR-AK-CAZ-SC womanish 0 "rusam M Venical Depth (use) MWD+IFR AK CAZ SCC 4 8,142.00 8,500.0011-1-1041-2wp24(Plan: 1H-1041-2 MWD-INC_ONLY Semimajw E., Poon) Semlmmm Emir loan) Azimuth To01 (9 MWD -INC -ONLY -FILLER 5 8,500.00 10,000.00 11-1-101 (Plan: 11-1-10412 MWD M WD - Standard I 6 8,500.00 15,776.9311-1-1041-2wp24(Plan: 114-1041-2 MWD-IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Well Plan: 11-1-104 Plan: 54.1+39 Qa 93, 1 Ousft (Doyon 142) Plan: 54.1+39 @193.1 Ousft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Position uncertainty and bias at survey station MessurtE Berm (.lin womanish 0 "rusam M Venical Depth (use) Ni9h.We Eno, Bias Posnl (man Lateral Ertw turn Bias (.am Veniwl Error Bias (-s) (usin Magnitude of at.. tusftl Semimajw E., Poon) Semlmmm Emir loan) Azimuth To01 (9 0,142.00 79.01 78.42 3.785.60 11.31 -osil 30.39 1.79 10.13 148 179 35.98 4.46 11061 MWbINC_ONLY (1. 4) 0,14210 79.01 78.42 3,785.62 11.31 -0.91 Was 1.79 lots 1.48 3.79 35si! 4.46 110.61 MV INC _ONLY (1, 4) 8,155.00 80.97 7730 3,707.05 11.21 .0.99 3oW 1.00 10.13 148 3.79 35.98 4.45 110.61 MWD -INC ONLY(1, 4) 8,175.00 00.97 77.70 3.791.00 11.21 -0.99 30.31 180 10.14 1.18 3.01 35.98 4.47 11060 MWU-INC_ONLY (1,4) 8,207.00 02.58 77AB 3,794.58 10.99 -188 30.25 1.01 10.14 1.48 3.82 35.99 4.51 11058 MWD -INC ONLY(1, 4) 8,209.85 88.37 76]1 3,801.88 10.30 -1.40 30.29 1.05 10.15 1A8 3.85 35.17 5.08 110.21 MND-1NC_ONLY(1. 4) 0,300.00 08.37 76.71 3,801.95 10.31 -1.40 30.37 1.85 10.15 1.48 3.87 3631 5.21 110.12 MWD -INC ONLY(1, 4) 0,33539 88.37 76.71 3,803.00 10.32 -1A0 3075 1.85 10.16 1.49 3.80 36." 5.84 109.65 MW INC ONLY(1, 4) 8,340.54 80.50 76.70 3,003.10 10.30 -1.40 N.79 1.85 10.16 1.49 3.88 36.47 5.92 109.59 MWD-INC_ONLY (1. 4) 8407.00 00.56 74.62 3,804.63 10.32 -1.41 31.25 1.97 10.18 1.49 3.91 37.16 7.49 108.15 MWD-INC_ONLY (1, 4) 8,453.09 88.62 72.76 3,805.93 10.33 -1.41 32.41 2,416 10.20 1.19 3.93 30.24 9.40 105.97 MWDdNC_ONLY (1, 4) sworn 8862 72.76 3,807.07 10.35 -1.41 30.55 2.17 10.21 1,49 4.01 39.01 10.29 101.65 hum (1. 5) 8,600.00 88.62 7275 3,809.40 10.35 -1.41 34.17 2.65 10.22 1.49 4.32 39.55 1024 104.16 MWD(L 5) 8,700.00 86.62 72]6 3,011.09 10.38 -1.41 34.85 3.13 10.24 1.49 4.07 40.13 10.25 103.62 mm (1. 5) 880.00 00.62 7236 3,814.31 10.41 -1.41 35.59 3,50 10.28 1.49 5.03 40.76 10.32 103.02 mm (1, 5) 8,900.00 81 72.76 3,816.72 10.46 -1.41 36.39 4.08 10.33 1.49 541 41.43 10.43 102.37 mm (1, 5) 9,000.00 88.52 72.76 3,819.14 10.52 -1.41 3725 4.55 10.39 1.49 5.81 42.15 10.58 101.69 MWD(1. 5) 9,100.00 88.62 72.76 3,821.55 10.59 -1.41 38.15 5.03 10.46 1.50 6.22 42.91 10]7 100.97 shi(1. 5) 9,200.00 80.62 72]6 3,823.97 1068 .1.41 39.11 5.50 10.55 1.50 6.63 43.71 10.90 100.24 MWD(1, 5) 9,30780 80.52 72.76 3,826.38 10.78 -1.41 10.11 5.90 10.65 1.50 7.06 44.55 11.22 99.48 am (1, 5) 9,304.32 88.62 72.76 3,826.40 10.78 -1.41 40.15 6.00 10.65 1.50 7.08 44.59 11.23 99.45 mm (1, 5) 9,400.00 8082 69.89 3,820]9 10.89 -1.42 40.15 6.61 10.76 1.50 7.49 45.40 1146 98.72 MWD(1, 5) 9,496.30 0863 6700 3,831.10 11.01 4.43 40.08 7.20 10.87 1.50 7.90 46.21 11.71 97.96 MWDit, 5) 9,50000 88.64 66.89 3,031.19 11.01 -1.43 40.08 7.22 10.88 150 7.91 4624 11.72 97.93 mm (1, 5) 9,600.00 08,89 6190 3,833.34 11.12 -1.45 39.96 7.79 1101 1.50 0.33 47.09 12.01 97.07 mm (1. 5) 9,692.74 89.13 61.13 3,834.95 11.22 -1.47 39.80 0.29 11.14 1.50 0.70 47.87 12.32 96.24 MM(1. 5) 9,700.00 89.13 61.13 3,935.W 1123 -1.47 39.88 8.32 11.15 1.50 823 47.94 12.34 %.18 MWD(1, 5) 9,800.00 89.13 61.13 3,836.50 11.30 -1.47 41.04 8.72 11.30 1.50 9.12 d8.a2 12.71 95.23 mm t. 5) 7/32018 1:58:33PM Page 3 COMPASS 5000.14 Build 85 Company: ConomPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-104 Wellbore: Plan: 11-1-1041-2 Design: 1H-104L2wp24 Schlumberger Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan. 1 H-104 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Position uncertainty and bias at survey station MeasufM IM1inMi0n capm (.an) VI A9mom Cl Vertical Depth (van) Highside Eom Bias (van) (uaft) Lateral Error (usnl Bias luanl Vemcal Error Bias Ivan) (ushl Magnitude Semimajor or Bias Ertor (..ft) (usn) Semi+ninor Emir (usnl A fta.m Ta01 r) 9900.00 10000.00 09.13 89.13 61.13 61.13 3838.10 3.839.62 11.55 10.73 -1.47 -1.46 42.24 33.25 9.12 3,23 11.0 10.64 1.50 1.50 9.52 4.82 49.73 42.23 13.03 1115 94.29 MWD(1, 5) 10085 MWD+1FR-AKZC -SC (2, 5) 10,008.37 10,100.00 10,200.00 10,204.76 10,289.16 89,13 87.67 86.08 86.00 84.49 61.13 58,27 55.15 55.00 62.45 3,83975 3,842.31 3,047.77 3,848.10 3.855.10 10.88 10.88 11.19 11.21 11.62 -145 -1.37 -1.29 -1.29 -1.21 32.43 3142 30.23 30.17 29.03 2.74 2.90 3.07 3.00 324 10.57 10.62 10.87 1087 10.72 1,50 1.51 1.51 1,51 1.51 4.56 4.60 4.84 4.64 4.68 41+65 41.82 4199 42.00 42.15 10.82 10.90 10.97 10.97 1106 101,64 MWD+IFR-N(-CA-SC(2,5) 101.38 MW0+1FR-AK-CA-SC(2,5) 101.11 MWD+IFR-AK-CAZ-SC(2.5) 101.10 MVA+1FR-AK-GA -SC (2.5) 100.83 MM+IFR-AK-CAZ-SC(2,5) 10,300.00 10.400.00 10,429.35 10,432.96 10.500.00 84.30 82.52 82.00 3200 8387 52.12 49,09 48.18 43.18 47.43 3,856.16 3,867.84 3871.&5 3,872.09 3,000.34 11.62 12.14 12.32 12.32 1188 -1.21 -1.13 -1.11 -1.11 -1.21 29.03 27.78 27,40 27.40 27.22 324 3.39 3.44 3.44 3.48 10.72 10]3 10.79 10.00 10.83 1.51 1.52 1.52 1.53 1.53 4.88 473 4.74 4.74 477 42,15 42.31 42.36 42.36 42.47 MOB 11.16 11.19 11,19 11,28 1M,83 MWD+IFR-AK-CAZSC(2, 5) 100.53 MV WR -AK -CA -SC (2. 5) 100.43 MWD+IFR-AK-CA-SC (2,5) 100.42 MWD+IFR-AK-CAZ-SC(1. 5) 100,20 MWD+1FR-AK-CAZ-SC(2, 5) 10,600.00 10.700.00 10,719.84 101800.00 10.83+71 %66 8945 90.00 90.00 90,00 49.32 45.22 45.00 42.60 41.43 3,888.60 3,89200 3.892.10 3.892.10 3,892.10 11.35 11.01 10.07 11.02 11.05 -1.37 -1.51 4,54 -1.54 -1.54 26,98 26.70 26.65 25.63 25.13 353 3.59 3.80 3.72 3.77 10.89 1098 1007 11,02 11.05 1.54 1.54 1.54 1.54 154 4.01 4,84 4.85 4.87 4.88 42.63 42.79 42.82 42.95 43.00 11.43 11.59 11.62 11.75 11,81 99.85 MWD+1FR-AK-GP -SO (2,5) 9948 MWD+IFR-A&CAZ-SC(2, 5) 99.41 MWDNFR-AK-CAZ-SC(2, 5) 99.12 MVA)+IFR-AK-CAZ-SC (2, 5) 98,99 MWD+1FR-AK-CAZ-SC(2. 5) 10,900.00 11,000.00 11100.00 11,115.38 11.200,00 90.00 90.M MAO 90.00 90.00 4143 41.43 4143 41.43 38.90 3,89210 3,892.10 3.892.10 3,892.10 3,892.10 11.09 11.16 11.24 11.25 11.31 -1.54 -1.54 -154 .1.54 -1.54 25.33 25.66 26.01 28.06 24.98 3.77 3.77 3A 3.77 3.09 11.09 11,16 11.24 11.25 11.31 1.54 1.54 1.54 t54 1,54 4.90 4.93 4.96 4.96 4.99 43.09 43,24 43.39 4342 43.56 11.91 12.09 12.27 12.30 1246 9876 MVA+IFR-AK-CAZSC(2, 5) 98.39 MVA+IFR-AKCAZ-SC (2, 5) 90.00 MWD+IFR-AK-CAZ-SC(2. 5) 97.95 MWD+1FR-AK-CAZ-SC(2. 5) 97.63 MWD+IFR-AK-CA-SG(2, 5) 11,300.00 11,329.85 11400,00 11,500.00 11,600.M 90.00 90.00 91.92 94.66 97.40 35.90 35.00 34.15 32,92 31.69 3.892.10 3,092.10 3,890.92 3885.18 3,374.67 11.39 11.42 1139 11+61 12.12 -1.64 -1,54 482 -173 -1.82 23.68 23.30 23.08 22.81 2254 4.03 4.07 4.11 4.16 4.21 11.39 1142 1147 il.w 11.64 1.54 1.56 1.54 1.53 1.53 5.01 5.02 5.04 5.06 5.07 43.67 43.71 43.80 43.93 41.06 12.63 12.68 12,83 13.07 13.32 97.26 MMAFR-AK-CAZ-SC (2, 5) 97.15 MVA+1FR-AK-CAZ-SC 2, 5) 96,07 MVA+IFR-AKCAZ-SC(2, 5) 96.46 MWD+IFR-AKCA2-SC(2,5) 98.3 MPA+IFR-AR-CAZSC(2,5) 11,042.07 11,652.45 11.700.00 11,800.00 11,9M.0 98.55 98.55 97.68 95.82 93.93 31.17 31.17 2946 25.90 22.36 3.860.83 3,867.29 3,860.57 3.848.02 3,040.33 1242 12.43 12.31 12,09 11.96 488M.43 -1.86 4.81 672 -1.64 22.47 21.72 20.13 18.66 4.23 4.23 4.30 443 455 11.60 11.69 1173 11.81 ileo 1.53 1,53 1.53 1.52 1,52 5.08 5.06 5.08 5.10 5.11 44.11 44.13 44.10 14.27 44,34 13.43 1345 13,53 13.64 13.77 95.85 MWD+1FR-AK-GAZ-SC (2, 5) 95.81 MM+IFR-AK-CAZ-SC(2. 5) 9563 MMAFR-MC -SC (2, 5) 95.31 MWD+IFR-AK-CAZSC(2, 5) 94,87 MWDHFR-AK-CAZ-SC(2. 5) 11,975.34 12,00000 12,100.00 12.195.28 12,200.00 9250 92.23 91.15 90.12 90.12 19,70 1875 14.90 11.23 11.23 3638.10 3,835.08 3,032.13 3.83107 3.831.06 11,94 11.96 12.05 12.18 12.10 459 -158 -1.54 452 -1.52 17.65 17.31 16.11 15.27 15.29 4.63 4.65 475 4.82 4.82 11.97 12.00 12.09 12.18 12,19 1.52 152 1.52 1.52 1.52 5.12 5.12 5,13 5.14 5.14 44.39 44.41 44.46 44.50 44.50 13.88 1392 14.11 14.31 14.31 94.72 MVA+IFR-AK-CP -SC (2. 5) 94.83 MWD+1FR-AK4AZSC(2, 5) 94.28 MWD+IFR-AKCAZSC R 5) 93.94 MW3+1FR-AK-CA-SC(2. 5) 93.92 1AWD+1FR-AK-CAZ-SC(2. 5) 12,300.00 12,400.00 12453.32 12,50000 12,600.00 9912 90.12 90.12 9022 90.45 11.23 11.23 11.23 9,37 5.37 3,83086 3,830.96 3,830.55 3,830.42 3,829.84 12.28 12.30 12.44 12,48 12.57 -1.52 -1.52 -1.52 -t.52 .1.52 15.55 15.83 15.90 15.66 15$9 4.82 4.82 4.82 4.05 4.91 12.29 1239 12,44 12.49 1259 1.52 1.52 1.52 1.52 152 5.15 5.16 5.17 5.17 5.16 44.53 44.57 44,59 44.61 44.83 14.49 14.68 14.79 14.89 15.13 93.54 MWD+IFR-MRC -SC(25) 93.15 MVA+IFR-AK-CAZ-SC(2, 5) 92,95 M WDHFR-AK-CAZ-SC (2, 5) 9277 MWD+IFR-AK-CAZ-SC(2, 5) 92.40 MWD+IFR-AKCAZ-SC (2,5) 12700.00 12.759.51 12,800,00 12,824.23 12,900.00 W67 90.00 9101 91,14 91.14 1.30 359.00 357.39 356.43 356.43 3,828,88 3,828.10 3,827.48 3,827.01 3,825.50 12,68 1274 12.78 1281 12.90 -1.52 -1.52 -1.52 -1.51 -1.51 15.38 15.65 15.92 16.12 16.23 4.94 4,96 4.96 4.98 496 12.70 12,76 12.81 12.83 12.92 1.52 1.51 1.51 1.51 1.51 5.19 619 5.19 5.19 6.19 44.64 44.63 44.3 44.62 44.61 15.37 15.51 15+61 15.67 15.83 9204 MVA+1FR-AK-CAZSC(2, 5) 91,3 MWD+1FR-AK-CAZ-SC(2. 5) 91.69 MWD+1FR-AK-CAZ-SC(2, 5) 91.61 MWD+1FR-AK-CAZ-SC 2.51 91,35 MVA+IFR-AK-CAZ-SC (2, 5) 13,000.00 13.10000 13,200.0 13,2W.17 13.295.90 91,14 91.14 91.14 91.14 90.W 3WA3 3%.43 3%43 356.43 35500 3,023,52 3,821.53 3,819.55 3,818.55 3,810.10 13.01 13.12 1323 13.29 13.35 -1,51 -1.51 -1.51 -1.51 -1.51 16.36 16.51 16.68 16.7 17.03 4.96 4.98 4.96 4.96 4.97 13.03 13.14 13.25 13.31 13.36 1.51 1,51 1.51 1.51 1.51 SA9 5.19 5.19 5.19 5,19 44.59 44.57 44.55 44.54 44,54 16.02 16.23 16.44 16.56 16.64 91.01 MWD+IFR-AK-CAZ-SC(2, 5) 90.68 MWD+1FR-AK-CPZ-SC(2. 5) 90.31 MWD+1FR-N(-CAZ-S0(2,5) 90.14 MVA+IFR-AK-CAZSC(2, 5) 89.99 MM+IFR-AK-CAAW(2, 5) 13,300.00 13400.00 99.91 87.65 354.86 351.56 3818,10 3,020.24 13.37 13.68 .1.51 -1.52 17,05 1778 4.97 497 13.37 13.48 1.51 1,51 5.19 5.19 44.54 44.51 16.65 18.80 89.90 MWD+1FR-AK-CAZ-SC(2.5) 6970 MWD+IFR-AKCAZSC(2,5) 7MO18 1:58:33PM Page 4 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kupamk 1H Pad Well: Plan: 1H-104 Wellbore: Plan: 1H-1041-2 Design: 1H-104L2wp24 Schlumberger Error Ellipse Report Local Coordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: IH -104 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan'. 54.1+39 ® 93.10usft (Doyon 142) True Minimum Curvature 1,00 sigma OAKEDMP2 Position uncertainty and bias at survey station Measured Indinalion espe, N -Fin 1350000 135a 157 13,577.28 (% 8540 114.47 8447 Atlmuth (°) 348.25 346.87 346.87 Vamsal Depth (usn) 3,826.30 3,829.95 3,033.41 Hl9hside Error Blas (aide (ush) 14.15 -1.54 14.38 -1.55 14.42 -1.55 Lateral Error (.am 18.74 19.20 19.22 Bias (ash) 4.95 4.94 4.94 Vertical Emr Bias (uan) lustu 1360 1.52 13.65 1.52 13.69 1.52 MaBNlude ofBias (usnl 5.19 5.19 5.19 Sanimalor E., lusn) 44.48 4447 4445 semlminor Emr (--ft) 16.96 17.03 17.10 ANmunl Tad 11 69.44 MWD+IFa-AK-0ALSC(2,5) 09.33 MWD+IFR-AK-C -SC (2.5) 89.23 MWD+IFR-PH-CAZ-BC(2,5) 13.600.00 13,700.00 13.800.00 13,813.86 13,900.00 84.61 85.25 8591 88.00 86.67 345.97 342.00 330.05 337.50 334.00 3,835.57 3,844.61 3,852.12 3,853.10 3,850.76 14.41 14.36 14.33 14.32 14.34 -156 -1.58 -1.60 -160 -1 fit 19.54 21.06 22.72 22.96 24.47 4.94 4.89 4.83 4.82 4+75 13.72 13.84 13.96 1398 14.08 1.52 153 1.53 1.53 1.6,1 5.19 5.18 5A7 5.17 5.16 44.44 14.39 44.32 44.31 4425 17.15 17.41 17.66 17.69 17.90 89.17 MMM+1FedK-CALBC(2.5) 88.09 MWD+1FR-AK-CAZSC(2, 5) 88.64 MWDHFR-AK-CAZSC(2,5) 88.61 MNANFR-AWCAZSC(2, 5) 88.42 MWD+IFR-AK-CA-SC(2,5) 16,000.00 14,100.00 14.200.00 14,280.31 14,300.00 87.02 07.59 88.17 08.85 00.85 330.11 326.15 322.19 319.01 319.01 3864.45 3,859.15 3,872.85 3,875.08 3,875.54 14.37 14.43 14.50 16.58 14.60 -1.62 -1.62 -1si . -1.60 1.60 26.25 28.04 29.80 31.18 31.17 4.0 4.53 4.40 4.28 4.20 14.20 14.33 1446 14.56 14.50 1.54 1.54 1.56 1.55 1.55 5.14 5.12 5.10 5.00 5.08 44.16 4107 43.99 43.90 43.88 18.14 18.37 18.59 18.76 18.79 88.23 MWD+IFR-AK-CAZSC(2,5) 08.37 MWD+IFR-AK-CAZ-SC(2. 5) 87,95 MWD+1FR-AK-CA-SC (2.5) 87.07 MWD+IFR-AK-CAZ-SC(2,5) 87.85 M+IFR-AK-CAZ-SC(2, 5) WD 16,370]8 11.600.00 14,500.00 16,600.00 14606.49 88.65 80.7] 89.77 89.96 90.03 31991 J1B.1] 316.21 310.26 310.00 3.87].40 3,8)7.88 3,879.51 3,880.10 3,000.10 14.70 14.]3 14.84 14.9] 14.98 -1.60 -1.60 -1.68 -IM Ass 3114 31.49 33.12 34.66 34.75 4.28 4.24 4.08 3.90 3.89 14.68 14]1 14.84 14.971.55 16.90 1.55 1.55 1.55 1.55 5.06 5.05 5.03 5.00 5.00 43.80 43.78 43.68 4].50 43.58 18.92 18.95 19.16 19.35 ism 8736 MWD+IFR-AH-0AZBC(2,5) 87.74 MWD+IFR-AK-CAZSC(2,5) 07.69 MWD+IFR-AK-CAZ-SC(2. 5) 87.6] MWD+IFR-AK-GPZ-SC (2,5) 07.67 MW IFR-AK-CAZSC(2,5) 14,700.00 14,000.00 14,871.91 14,900.00 15,003.00 90.72 9149 92.04 92.04 92.04 306.33 302.40 299.58 299.58 299.50 3,879.51 3,87258 1875.36 3,874.36 3,870.79 15.12 15.28 1540 15.44 15.9 4.51 -147 -1.43 -143 -1.43 36.08 3239 38.26 38.24 30.20 3.71 3.50 3.34 3.34 3.34 15.10 15.24 1583 15.37 15.50 1.55 1.55 1.55 1.55 1.54 4.97 4.95 6.92 4.92 4.89 43.49 43.39 43.32 43.30 43.21 19.52 1857 19.76 19.80 19.91 87,67 MWD+1FR-MZC -SC (2. 5) 87.71 MWD+IFR-AK-CAZ-SC(2, 5) 07.75 MWD+IFR-AK-CAZSC(2.5) 87.77 MWD+1FR-AK-CAZ-SC(25) 87.82 MWD+IFR-AK-CAZSC(2,5) 15,100.00 15,200.00 15,300.00 15;400.00 15,5o0.00 92.04 92.04 92.04 92.04 9204 299.58 299.58 29958 289.50 299.50 3,867.23 3,06166 3.860.10 3.856.53 3,8529] 15.71 15.84 15.90 16.12 18.25 .1.63 -143 -1.43 4.43 -143 38.17 30:15 38.14 38.13 38.14 3.34 3.34 384 3.34 3.34 15.64 15.77 1591 16.05 18.19 1.54 t54 1.54 1.54 1.51 4.86 483 4.00 4.77 4.74 43.13 43.05 42.98 42.92 62.86 20.03 20.15 20.27 20.40 20.53 87.00 MM+IFR-AK-CA-SC (2.5) 87.96 MWD+IFR-AK-CA-SC(2,5) 88.05 MW IFR -AK -CA SC (2, 5) 88,15 MWD+IFR-AK-CA-SC(2, 5) 88.27 MWD+IFR-AK-CAZ-BC (2, 5) 15,600.00 15700.00 15,]76.93 92.04 92.04 92.04 299.60 299.58 299.58 3.849.41 3,045.81 3,843.10 16.39 18.53 16.64 -1.43 -1.43 -143 38.15 30.17 38.19 3.36 3.34 3.34 16.33 t6.Q I6.57 1.54 1.53 1.53 4.72 6.69 4.67 42.80 42.76 42.72 20.66 20.80 Z(1.90 88,40 MWD+1FR-AK-CAZ-SC(2, 5) 88.54 MWD+IFR-AK-CAZ-SC(2, 5) B8.66 MWD+IFR-AK-CAZSC (2, 5) 71312018 1:58:33PM Page 5 COMPASS 5000.14 Build 85 Company'. ConoWPhillips (Alaska) Inc. -KUP1 Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-104 Wellbore: Plan: 1H -104L2 Design: 1H-104L2wp24 Schlumberger Error Ellipse Report Local Coordinate Reference: Well Plan', 1H-104 TVD Reference: Plan'. 54.1+39 Q 93.10usft (Doyon 142) MD Reference: Plan: 54.1+39 (§ 93, 10usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: OAKEDMP2 Design Targets Vertical Depth Depth Target Name (usft) (usft) 116.10 -hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W -Shape V) (I (usft) (usft) (usft) 1H-1041_2 T01 WSD O6: 0.00 0.00 3,803.10 -2,080.66 6,118.70 - plan hits target center - Circle (radius 100.00) 1 H-1041-2 TOB 063018 F 0.00 0.00 3,818.10 1,272.57 9,038.07 - plan hits target center -Circle (radius 100.00) 1 H-1041_2 T07 063018 F 0.00 0.00 3,828.10 737.29 9,070.56 - plan Bits target center - Circle (radius 100.00) 1 H-1041_2 T02 063018 F 0.00 0.00 3,831.10 -1,732.85 7,220.12 - plan hits target center - Circle (radius 100.00) 1 H-1041_2 TO6 063018 F 0.00 0.00 3,836.10 -31.91 8,934.49 - plan hits target center - Circle (radius 100.00) 1 H-10412 T11 063018 9 0.00 0.00 3,843.10 2,999.24 7,444.21 - plan hits target center - Circle (radius 100.00) 1H-1041-2 T03063018 F 0.00 0.00 3,848.10 -1,390.88 7,839.44 - plan hits target center - Circle (radius 100.00) 1H-1041-2 T09063018 F 0.00 0.00 3,853.10 1,773.41 8,919.34 - plan hits target center - Circle (radius 100.00) 1 H-1041_2 71 0 063018 F 0.00 0.00 3,880.10 2,401.57 8,448.41 - plan hits target center - Circle (radius 100.00) 1H-10412704063018 F 0.00 0.00 3,892.10 -1,053.37 8,224.70 - plan hits target center - Circle (radius 100.00) 1 H-1041-2 T05 063018 F 0.00 0.00 3,892.10 -590.92 8,621.78 - plan hits target center - CirGe (radius 100.00) Casing Points Measured Vertical Depth Depth (usft) (usft) 116.10 118.10 20"x47' 1,918.25 1,800.00 10 3/4" X 13 1/2" 8,142.10 3,785.62 7 5/8" X 9 7/8 15,776.93 3,843.10 41/2"X6-3/4" Casing Hale Diameter Diameter Name () () 20 42 10-3/4 13-1/2 7-5/8 9-7/8 4-1/2 6-3/4 7WO18 1:58:33PM Page 6 COMPASS 5000.14 Build 85 Schlumberger Error Ellipse Report Company: ConowPhillips (Alaska) Inc. -Kupt Local Co-ordinate Reference: Well Plan: 1H-104 Kuparuk River Unit TVD Reference: Plan: 54.1+39 (91 93.10usft (Doyon 142) Project: Kuparuk 1H Pad MD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) Site: Well; Plan: 1H-104 North Reference: True Wellbore: Plan: 1H-1041-2 Survey Calculation Method: Minimum Curvature Design: 1H-104L2wp24 Output errors are at 1.00 sigma KOP. 16"/100'ELS, -20-TF. for 13' 8,155.00 Database: OAKEDMP2 5,938.66 Hold for 20' 8,175.00 3,791.00 Formations 5,957.95 Start 6.5°/100' DLS, -7.61 ° TF, for 114.85' 8,289.85 3,801.66 -2,092.31 6,069.39 Dip 8,336.79 Measured Vertical -2,081.52 Dip Direction Start 3.5°N 00' DLS, -6.48° TF, for 3.74' Depth Depth 3,803.10 -2,080.66 6,118.70 (usft) (usft) Name Lithology 3,805.93 -2,051.04 10,289.18 3,855.10 WS_A2 Hold for 851.23' 9,304.32 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/S +EI -W (usft) (usft) (usft) (usft) Comment 8,142.00 3,785.60 -2,124.47 5,926.13 KOP. 16"/100'ELS, -20-TF. for 13' 8,155.00 3,787.86 -2,121.82 5,938.66 Hold for 20' 8,175.00 3,791.00 -2,117.61 5,957.95 Start 6.5°/100' DLS, -7.61 ° TF, for 114.85' 8,289.85 3,801.66 -2,092.31 6,069.39 Hold for46.95' 8,336.79 3,803.00 -2,081.52 6,115.06 Start 3.5°N 00' DLS, -6.48° TF, for 3.74' 8,340.54 3,803.10 -2,080.66 6,118.70 Adjust TF to -88.35°, for 112.55' 8,453.09 3,805.93 -2,051.04 6,227.22 Hold for 851.23' 9,304.32 3,826.48 -1,798.84 7,039.98 Start 3'/100' DLS, -89.94° TF, for 191.98- 9,496.30 3,831.10 -1,732.85 7,220.12 Adjust TF to -85.21°, for 196.44' 9,692.74 3,834.95 -1,646.99 7,396.66 Hold for 315.62' 10,008.37 3,839.75 -1,494.60 7,673.02 Start 3.5°/100' DLS, -117.18° TF, for 196.39' 10,204.76 3,848.10 -1,390.88 7,839.44 Adjust TF to -120.86', for 225.1' 10,429.85 3,871.66 -1,251.94 8,014.73 Hold for 3.1' 10,432.96 3,872.09 -1,249.89 8,017.02 Start 3°/100' DLS, -21.73° TF, for 286.89' 10,719.84 3,892.10 -1,053.37 8,224.70 Adjust TF to -90°, for 118.87' 10,838.71 3,892.10 -966.76 8,306.08 Hold for 276.67' 11,115.38 3,892.10 -759.33 8,489.17 Start 3°/100' DLS, -90° TF, for 214.47' 11,329.85 3,892.10 -590.92 8,621.78 Adjust TF to -23.96°, for 312.22- 11,642.07 3,868.83 -330.37 6,791.60 Hold for 10.37' 11,652.45 3,867.29 -321.59 8,796.91 Start 4°/100'OLS, -117.29' TF, for 322.89' 11,975.34 3,836.10 -31.91 8,934.49 Adjust TF to -105.6", for 219.94' 12,195.28 3,831.07 179.81 8,993.05 Hold for 258.04' 12,453.32 3,830.55 432.91 9,043.31 Start 4°/100' DLS, -86.76° TF, for 306.19' 12,759.51 3,828.10 737.29 9,070.56 Adjust TF to -82.5', for 64.72' 12,824.23 3,827.01 801.95 9,067.98 Hold for 425.94' 13,250.17 3,818.55 1,226.97 9,041.48 Start 4°/l00'DLS. -128.43' TF, for 45.73' 13,295.90 3,818.10 1,272.57 9,038.07 Adjust TF to -124.39°, for 245.47' 13,541.37 3,829.95 1,514.40 8,999.53 Hold for 35.92' 13,577.28 3,833.41 1,549.22 8,991.41 Start 4°/100' DLS, -81.12° TF, for 236.58' 13,813.86 3,853.10 1,773.41 8,919.34 Adjust TF to -82.36°, for 466.44' 14,280.31 3,875.08 2,167.83 8,675.21 Hold for 98.46' 14,378.76 3,877.40 2,242.12 8,610.65 Start 4°/100' DLS, -81.52° TF, for 227.73' 14,606.49 3,880.10 2,401.57 8,446.41 Adjust TF to -78.85", for 265.42' 14,871.91 3,875.36 2,552.78 8,230.79 Hold for 905.02' 15,776.93 3,843.10 2,999.24 7,444.21 TD: 15776.93' MD, 3843.1' TVD [Checked By: Approved By: Date: 7!32018 1:58:33PM Page 7 COMPASS 5000.14 Build 85 Pool Report 14:08, My 112018 0 0 LO Z1500 1 -1500 1 H-104L2wp24 Quarter Mile View IA020 7 'H'0' t38 39 30 38 - n T- 0 1500 3000 4500 6000 7500 9000 10500 12000 West( -)/East(+) (1500 usft/in) 1H-104L2wp24 Surface Location Ley CPAI Coordinate Converter o ❑� r From: -- To:-- ------ - Datum: NAD83 Region: alaska Datum: NAD27 Region: alaska C Latitude/Longitude IDecimalDegrees C Latitude/Longitude IDecimalDegrees, C UTM Zone. - r South C UTM Zone: True r South C State Plane Zone: q Units: us -ft C•- State Plane Zone: 4 . Units: us -ft C Legal Description (NAD27 only) C Legal Description (NAD27 only) - Starting Coordinates Ending Coordinates: - x: 1549568.736474514 X: 1689600.36 Y: 5980534.24 Y: 5980782.43086254 Transform Quit Help 1 H-104L2wp24 Surface Casing d CPAI Coordinate t ram: Datum: INAD83 Region: falaska C Latitude/Longitude IDecimal Degrees --� (- UTM Zone: F— r South C State Plane Zone: I' Units: us -ft C Legal Description (NAD27 only) -I a: Datum: INAD27 Region: alaska C Latitude/Longitude IDecimalDegFees C UTM Zone True r South C•' State Plane Zone: � Units: us -ft . C Legal Description (NAD27 only) Starting Coordinates: Ending Coordinates: X: 1690076.56 x: 550044.927833547 Y: 5980319.29 Y: 5980567.47692271 Transform Quit Help 1H-104L2wp24 Top of Window IN wr rnAr r....«JL,ete P...n.nrtnr 1 H-1 04L r3 CPA; Coordinate T of Production Horizon From: Datum: NAD83 j Region: alaska • Latitude/Longitude IDecimalDegrees -71 f•UTM Zone: F— j- South r State Plane Zone: qUnits: us -ft r Legal Description (NAD27 only) Jo: — Datum: INAD27 : Region: jalaska C Latitude/Longitude IDecimaiDegrees C UTM Zone: True r' South C•- State Plane Zone: qUnits: us -ft r Legal Description (NAD27 only) Starting Coordinates: Ending Coordinates: X: 11695527.72 X 555495.991482444 Y: 15S78446.43 Y: 5978694.55835182 Transform Quit Help To: — From: Datum: NAD83 Region: alaska Datum: NAD27 Region: alaska r Latitude/longitude Decimal Degrees - Latitude/Longitude Decimal Degrees f UTM Zone: r— r" South r UTM Zone: True r South r State Plane Zone: 14 -Units: us -ft - R State Plane Zone: q Units: us -ft r Legal Description (NAD27 only) C Legal Description (NAD27 only) Starting Coordinates: X: 11695539.74 Ending Coordinates:— X: 555508.011315931 Y: 5978448.93 Y: 5978697.05806571 -- .................. .7 quit Help Transform 1 H-1 04L r3 CPA; Coordinate T of Production Horizon From: Datum: NAD83 j Region: alaska • Latitude/Longitude IDecimalDegrees -71 f•UTM Zone: F— j- South r State Plane Zone: qUnits: us -ft r Legal Description (NAD27 only) Jo: — Datum: INAD27 : Region: jalaska C Latitude/Longitude IDecimaiDegrees C UTM Zone: True r' South C•- State Plane Zone: qUnits: us -ft r Legal Description (NAD27 only) Starting Coordinates: Ending Coordinates: X: 11695527.72 X 555495.991482444 Y: 15S78446.43 Y: 5978694.55835182 Transform Quit Help I H-104L2w 24 TD R CPAs Coordinate Converter - Datum: INAD83 J, Region: alaska r Latitude/Longitude IDecimalDegrees _J r UTM Zone:I — r South C•' State Plane Zone: 4 Units: us -ft C Legal Description (NAD27 only) l o: Datum: NAD27 Region: jalaska C Latitude/Longitude IDecimalDegrees —� C UTM Zone: True r South G State Plane Zone: F--3- Units: us -ft C Legal Description (NAD27 only) Starting Coordinates: Ending Coordinates: Ir X: 11697024 X: 556992.286870954 Y: 5983582 Y: 5983829.97769756 ._...................._._.........._........._.._.� Quit Help Transform H-104L2wp24 Surface Location Q CPA] Coordinate Converter From: Datum: NAD83 Region: alaska r Latitude/Longitude Decimal Degrees r UTM Zone: r— I— South C• State Plane Zone: 4 Units: us -ft r Legal Description (NAD27 only) - Starting Coordinates: X: 11689600.36 Y: 5980534.24 1H-104L2wp24 Surface Cas f� CPAT Coordinate Converter From: Datum: NApg3 Region: alaska !' Latitude/Longitude Decimal Degrees r UTM Zone: r — r South To: Datum: NAp27j Region: alaska • Latitude/Longitude IDecimalDegrees • UTM Zone: True r South r State Plane Zone: F----] Units: us -ft • Legal Description (NAD27 only) - Legal D Township: 012 N . Range: 010 Meridian:U Section:28 FRE -D,5200.5597 FEL , 1772.31441 _......._......._._...................._._....._..: Quit Help Transform T7...777----.-..-..-.-..-..- ........................................................... _. t� State Plane Zone: -- q . Units: us -ft r Legal Description (NAD27 only) Starting Coordinates: X 11630076.55 Y: 15980319.29 -To.--- - --- -- - Datum: NA527 Region: alaska i Latitude/Longitude Decimal Degrees C' UTM Zone: ITfue r South !" State Plane Zone:q Units: us -ft G Legal Description (NAD27 only) - Legal Township: 012 N Range: 010 E Meridian: U Section:33 FNL 138.71385 FEL 297.99407 .._..........__.._._.._......_.----......._..., Quit Help t Transform ; 1H-104L2wp24 Top of Window �y CPAI Coordinate Converter From: Datum: NAD83 Region: falaska r Latitude/Longitude IDecimal Degrees r UTM Zone:1 — r South 6' State Plane Zone: F___-:1 Units: us -ft i Legal Description (NAD27 only) Datum: NA527 Region: alaska • i Latitude/Longitude (Decimal Degrees J C UTM Zone: True r South C State Plane Zone:q Units: us -ft . r Legal Description (NAD27 only) Starting Coordinates: Legal X: 11695539.74 Y: 5978448.93 1 H-104L2wp24 To ❑. CPA( Coordinate Converter Township: 012 F-] Range: 010 E Meridian:IU __j Section: 34 FNL . 2047.7603 FEL 131.11469 ....___.............._......_._:......_.._.._.., Quit Help Transform of Production Horizon -From: Datum: NAD83 Region: alaska f Latitude/Longitude Decimal Degrees C UTM Zone: F– r South C•- State Plane Zone: F-'::] Units: us -ft . (' Legal Description (NAD27 only) Starting Coordinates: X: 11695527.72 Y: 15978446.43 -To: ----_ _. Datum: FNA -D27 Region: alaska' C Latitude/Longitude Decimal Degrees t" UTM Zone: True r South r State Plane Zone: F4-3 Units: us -ft r- Legal Description (NAD27 only) , - Legal Township: 012 -2F-Range: 010 Meridian: IU . Section:34 FNL 2050.1722 FEL 143.15766 r.._..._......_...__._.._.....---.._.._.� Quit He Transform 1 H-104L2wp24 TD V". CPAI Coordinate Converter From: Datum: INAD83 j Region: falaska C Latitude&ongitude IDecimalDegrees f UTM Zone: F— j- South f- State Plane Zone:q Units: us -ft r Legal Description (NAD27 only) Starting Coordinates: X: 11697024 Y: 5983582 Ia To: ------ ----_- Datum: NAD27 - Region: jalaska 7 f Latitude/Longitude IDecimalDegrees C UTM Zone: True r South r State Plane Zone: 14 . Units: us -ft 3- f• Legal Description (NAD27 only) -Lagar uescripnon Township: 012 N , Range: 010 E Meridian: U Section: 26 FNL 2205.6272 FEL 3881.3954 ............._............._............._.._._._.) Quit Help I Transform Tollerable Collision Risk Worksheet As -built :V DATE BY CIC APP I DESCRIPTION REV DATE BY 1 CK APP DESCRIPTION 12/05/0 MRT CK Rev. Per K05014ACS 2 02/01/1 JAH LGM Rev. Per K170005ACS MONUMENTATION PER LOUNSBURY & ASSOC. 25 30 29 28 27 25 N 1G 36 KCS 31 32 1B 33 34 35 36 3. ELEVATIONS ARE B.P.M.S.L. Ti N T11N OE ALL CONDUCTORS ARE LOCATED WITHIN •UGNU 5 4 2 3 914 i 6 lA 16A 05 ®120CPFS UMIAT MERIDIAN, ALASKA. *20 *12 1 AGRID NORTH SP 0119 2 7 8 9 ��4'P 10 11 1-31-17 FIELD BOOKS L16-35, L16-40, ®118 06 �O *16 12 ®117 •15 013 6. ALL DISTANCES SHOWN ARE GROUND. 01 09 ®116 0115 18 7 16 is 14 1 03 ®114 19 GRAPHIC SCALE SD 2, ®113 IF LEGEND 0112 24 19 20 21 2 z3 O• AS -BUILT CONDUCTOR 0111 ®110 VICINITY 1 inch = 200 ft. MAP • EXISTING CONDUCTOR 0109 2 & 3 FOR COORDINATE SCALE: 1" = 2 MILES ASSOCIATES,INC. ®104 C2\F.YOR4 ENGIN85 PWNES 0108 28 27 MODULE: XXXX UNIT: D1 ®103 + DS1H ConocoPhillips 33 34 ®102 WELL CONDUCTOR ®106 ASBUILT LOCATIONS CADD FlLE N0. dna ®101 CFA—D1 HX -6108D31 PART: 1 of 3 REV: 2 NOTES: 1. BASIS OF LOCATION AND ELEV. IS DS1H MONUMENTATION PER LOUNSBURY & ASSOC. DS1 H 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE NAD 27. 3. ELEVATIONS ARE B.P.M.S.L. 4• ALL CONDUCTORS ARE LOCATED WITHIN •UGNU Ol PROTRACTED SECTIONS 28 AND 33, 914 TOWNSHIP 12 NORTH, RANGE 10 EAST, 05 UMIAT MERIDIAN, ALASKA. *20 *12 019 •11 5. DATES OF SURVEY: 12-26-16 THRU •22 010 1-31-17 FIELD BOOKS L16-35, L16-40, 917 06 L17-02 & L17-03. *16 o21 •15 013 6. ALL DISTANCES SHOWN ARE GROUND. 01 09 02 •7 03 •18 GRAPHIC SCALE 0 100 200 400 08 •4 1 inch = 200 ft. LOUNSBURY SEE SHEET 2 & 3 FOR COORDINATE TABLE ASSOCIATES,INC. C2\F.YOR4 ENGIN85 PWNES AREA: IH MODULE: XXXX UNIT: D1 DS1H ConocoPhillips WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD FlLE N0. dna DRAWING NO. CFA—D1 HX -6108D31 PART: 1 of 3 REV: 2 1 102/01/17 JAH I LGM I (Create Per K170005ACS I I I I I I I CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 28, T_ 12 N.. R. 10 E.. UMIAT MERIDIAN Well No. NAD 27 ASP Coordinates NAD 27 Geo ra hic Coordinates Section t. Offset. Elev. I X Lot. Long. F.S.L F.E.L. O.G. I PAD *103r5,980,752.52- 0,722.55' 549,573.20' N 70' 21' 29.220" W 149' 35' 50.536" 19' 768' 48.0' 54.1' *1040,782.43' 549,568.74' N 70' 21' 29.809" W 149' 35' 50.655" 79' 772' 48.0' 54.1' *108 549,570.98' N 70' 21' 29.515" W 149' 35' 50.595" 49' 770' 48.0' 54.0' *1090,812.20' 549,566.50' N 70' 21' 30.102" W 149' 35' 50.714" 109' 774' 48.0' 54.0' *110 ,0,842.21' 549,564.40' N 70' 21' 30.398" W 149' 35' 50.770" 139' 776' 48.0' 54.0' *111 5,980,872.05' 549,562.21' N 70' 21' 30.691" W 149' 35' 50.828" 169' 778' 48.0' 54.1' *112 5,980,902.08' 549,559.94' N 70' 21' 30.987" W 149' 35' 50.889" 199' 780' 48.0' 54.0' *113 5,980,932.00' 549,557.76' N 70' 21' 31.281" W 149' 35' 50.947" 229' 782' 48.0' 54.0' *114 5,980,961.86' 549,555.50' N 70' 21' 31.575" W 149' 35' 51.006" 259' 784' 48.0' 54.1' *115 5,980,991.68' 549,553.43' N 70' 21' 31.868" W 149' 35' 51.062" 289' 786' 48.0' 54.1' *116 5,981,021.61 549,551.58' N 70' 21' 32.163" W 149' 35' 51.110" 319' 787' 48.0' 54.1' *117 5,981,051.73' 549,548.80' N 70' 21' 32.459" W 149' 35' 51.185" 349' 790' 48.0' 54.0' *118 5,981,081.22' 549,546.95' N 70' 21' 32.750" W 149' 35' 51.234" 378' 791' 48.0' 54.0' *119 5,981,111.42' 549,544.52' N 70' 21' 33.047" W 149' 35' 51.299" 408' 794' 48.0' 54.2' *120 5,981,141.33' 549,542.48' N 70' 21' 33.341" W 149' 35' 51.353" 438' 795' 48.0' 54.1' * CONDUCTOR ASBUILT THIS SURVEY �;.•'ly 49th W ................................................ c JEREMIAH F. CORNELLi ♦♦♦, �O ARncS=12663• ='•�y r SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION ARE CORRECT AS OF JANUARY 31, 2017. 0LOUNSBURY QkA830C1AINC. '� YORS MGMERRS PW NMS AREA: 1H MODULE: XXXX UNIT: D1 ConocoPhillips DS1H WELL CONDUCTOR Alaska. Inc. ASBUILT LOCATIONS CEA- D 1 H X -6108D31 I PART: I REV: 3 of 3 Fixed BOP configuration for West Salc Operations Ann Fixed Blind VBR OWT_e [� 31 L B& Wellhead lTubing Need 'Tree, 13-318"x1H-104 Producer Schematic InmlatW Conducbr J'h", 5,000 ksi Casing, 20", 94#, Planned wD26 H55s34",0312Tubing Strout: 1 L7" 1'_.64, L-80 TXP +/-134' MD Go Lift Mandol, 4-V2" a I" w/ dummy valve Gas Lift Mandrel. 4-12" s I' uJ dummy valve 10-3/4',455#, Gas Lift Mmdrel- 4-IA"s1"wI SOV 1-80, Hyd563 1'S"SSD with 3,912" DB Nipple pro0lc 19 IT MD 11800' TVD P<mmncnt D. Hole Gauge Tubing Seal Amembly IAZ PPecker 3.T3"DIP Nipple Profile r x a 8 _f rn U on nC2 Sucked Bakor Hook Hanger — Level 3 Junction Sycoms L2"D"Send Upper Lobe Windmv d1814V MID /3)85'TW) 6314"D sand (L2)Imcrd I 577 MD/3847 TVD �1 •'•. ZXP Pecker • 4.112" Slaucd Lumr and Blvd 12.6#1-80 TXP/IBTMSLHT P�a ""..""..... . .......... _______............__________........_.__...__.............. ✓ •. . .................. .............................. --• LI D" Sand Lower Loh Wlndcu p) 8365• MD 13828' TVD 6-314'M SaM(LI) lamnd ,, •• Laural Enuy MadW< 1In'Slolbd Liner and Bled pipe 12.6# L80 TXP/IBTMSLHT 15917'MD13926'TVD� \`��_ ..----------------------------- Tubing Seal Assemble` .... ............. m ..................................................................•• 6314' A21A3 sand (mninbone) g 3 562" DP Nipple Profile 112' Slowed Liner and Blmd Pipc. 1269 TXP/SLHT L80 Wend IAZXPpack<r_ 16085 MD 14030' TVD ]-518'l 2978, 1-80. Hvd563, Csg _________--------------- ------------------------- ------ 'm4 9469'MD 1408 TVD ____ ____________ M.. J1111111 ____________________________________________________________ 1H-104 Drilling Hazards Summary 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Mi ' tion StraLeff Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Reduced pump rates, Reduced drilling fluid temperatures, Additions of ScreenKleen Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use oftrip sheets), pumping out Washouts / Hole Sloughing Low j Cool mud temperatures, minimize circulating times when possible Anti -Collision Moderate Follow real time surveys very closely, shut in nearby wells that we have collision concerns with, gyro survey to ensure survey aceura 4-7/8" Open Hole/ 7-5/8" Casing Interval Hazard Risk Level Mi' tion Strate _ Running Sands and Gravels Low Maintain planned mud parameters, increase mud weight, use weighted sweeps. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, LCM. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out. 6-3/4" Open Hole/ 4-1/2" Liner Intervals Hazard Risk Level NEC Strategy Abnormal Reservoir Pressure Low Snipping drills, shut-in drills, increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools monitoring and analysis, decreased mud wei t if ossible if pipe does get stuck. Lost Circulation Moderate Reduced pump rates, mud rheology, LCM program, additional fluid stored on location during completion ran. Differential Sticking Moderate Follow mud program, keep pipe moving when able. Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out or backrear m . Fault Crossings and Concretions Moderate Use developed best practices for concretion drilling. Anti -Collision Moderate Follow real time surveys very closely, shut in nearby wells that we have collision concerns with. Utilize periscope to maintain olo ical certain to stay within zone. Casing wear Moderate Maintain low dog legs in the surface interval and utilize super sliders for drilling, milling, and liner running operations to minimize casing wear. Consider logging casing thickness to calibrate casing wear model. Getting Liner to Bottom - Moderate Properly clean hole on the trip out with the BHA, perform clean out run if necessary, utilize super sliders for weight transfer, monitor for ue and dr . Whipstock Retrieval Moderate A dedicated clean out run prior to attempting to pull whipstock can be used to reduce the risk of fishing operations. IH -104 DnlNng Hazards Summary.doc 5/15/2018 4:42:08 PM Drill Site I H DRAWN BY: ALKET MICI r ConocoPhi[IliprS TITLE: D51H LAYOUT DRAWING Mask jfl DRAWN BY. ALKET MICI onre Mey =a TRANSMITTAL LETTER CHECKLIST WELL NAME:�l PTD: Development _Service _Exploratory _ Stratigraphic Test Non -Conventional FIELD: /fit t/J�t u I� c t� POOL: Gt�C r Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is ffor.a new wellbore segment of existing well Permit /API No. 50-� �/c^/L -� �C3 LATERAL (If last two digits No. Z-15-r�f-—, Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - _) from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. Com anName) Operator the liability of any protest to the spacing exception that may assumes occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Coman 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 2180860 Appr Date SFD 7/23/2018 Initial 17 Nonconven, gas conforms to AS31,05.0309.1.A),(1.2.A-D) - NA 1 Permit fee attached - - _ - _ - - _ NA 2 Lease number appropriate. - Yes 3 Unique well name and number _ - _ - - _ - _ _ Yes ;4 Well located in. a. defined -pool- - - - Yes 5 Well located proper distance from drilling unit. boundary - - Yes - 6 Well located proper distance from other wells - - Yes 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat. included Yes _ 9 Operator only affected party... Yes 10 Operator has. appropriate bond in force - - - Yes 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative. approval _ _ _ _ _ _ Yes 13 Can permit be approved before 15 -day wait.... - Yes 14 Well located within area and strata authorized by Injection Order# (put 10# in comments) (For! NA 15 All wellswithin114 mile area of review identified (For service well only).. .. - - - - NA 16 Pre -produced injector; duration of pre -production less than. 3 months (For service well only) - NA Well Name: KUPARUK RIV U WSAK 11-1-11141.2 Program DEV Well bore seg �I =ND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal If a. re -drill, has a 10-403 for abandonment been approved Surf Loc & Top Prod Int lie in ADL0025639; TD lies in ADL0025638. Yes-- Previous application for 1H-1041.2 (PTD #218-062) was cancelled. per email. from. S. Brunswick, - CPAI,. rescinding permit. Kuparuk River, West.Sak Oil Pool - 490150, governed by CO 4060 CO 406C, Rule 3; no restrictions as to well spacing except that no pay shall be opened in a well closer than 500 feet to. an external property line where ownership or landownership changes. As planned, well conforms to spacing requirements, - 18 Conductor string. provided ... - NA _ - - Conductorsetin KRU 1H-104... Engineering 19 Surface .casing protects all known USDWs. NA -. Surface casing will be set for KRU. 1H-104 20 CMT vol adequate to circulate. on conductor & surfcsg - - - NA Surface casing will be 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 Productiveintervalwill be completed with uncemented slotted liner 23 C I - ---- 33 as ng designs adequate for C, T B & permafrost _ _ Yes H25 measures required. 24 Adequate tankage or reserve pit _ _ Yes Rig has steel tanks, all waste. to approved disposal wells 25 If a. re -drill, has a 10-403 for abandonment been approved NA - - - - - - - 26 Adequate wellbore separationproposed- 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 1647 psig(8.4 ppg EMW); will drill w/ 8.8-9.5 ppg EMW VTL 8/1/2018 29 BOPEs,.do they meet regulation - - - _ _ Yes - - - - 130 BOPE.press rating appropriate; test to(Putpsig in comments)- - Yes _ MPSP is 1269 psig; will test BOPS to 3500.psig 31 Choke manifold complies w/API. RP -53 (May 84), - _ _ _ _ - _ - - _ Yes 32 Work will occur without operation shutdown- - - - _ - _ Yes 33 Is presence of H2S gas probable - - Yes H25 measures required. 34 Mechanical condition of wells within AOR verified (For service well only) . _ NA 35 Geology Permit can be issued w/o hydrogen sulfide measures No H2S measures requi[ed.. Well 1H-102. measured 20 ppm H2S. on November 20, 2017. 36 Data presented on potential overpressure zones - Yes -Ex ected reservoir pressure is -8.4 ppg EMW; will be drilled with 8.8 - 9.$ ppg Appr Date 37 Seismic analysis of shallow gas zones - - - _ NA -mud. Moderate potential for lost circulation, differential sticking, swabbing, and fault crossing issues. SFD 7/23/2018 38 Seabed condition survey.(if off -shore) NA Mitigation measures discussed. in DrillingHazardsSummary.. 39 Contact name/phone for weeklyprogressreports [exploratory only] - NA - - - - Geologic Engineering PulAin Commissioner: Date: Date �t OT�' Commissioner- p ommissi r le- ! 1 / 5 � I� �o // `tel 'J ( I�J