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Originated: Delivered to:26-Aug-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1A-23 50-029-22131-00 910219324 Kuparuk River Plug Setting Record Field- Final 4-Aug-25 0 12 1A-27 50-029-22124-00 910219038 Kuparuk River Plug Setting Record Field- Final 4-Aug-25 0 13 1B-15A 50-029-22465-01 910203865 Kuparuk River Multi Finger Caliper Field & Processed 5-Aug-25 0 14 1C-153 50-029-23549-00 910180480 Kuparuk River Leak Detect Log Field- Final 19-Jul-25 0 15 1C-153 50-029-23549-00 910181004 Kuparuk River Packer Setting Record Field- Final 28-Jul-25 0 16 1G-02 50-029-20813-00 910151017 Kuparuk River Packer Setting Record Field- Final 9-Jul-25 0 17 1J-122 50-029-23359-00 910180477 Kuparuk River Plug Setting Record Field- Final 18-Jul-25 0 18 1L-09 50-029-22025-00 910180917 Kuparuk River Leak Detect Log Field- Final 17-Jul-25 0 19 1L-09 50-029-22025-00 910180917 Kuparuk River Multi Finger Caliper Field & Processed 14-Jul-25 0 110 1L-09 50-029-22025-00 910180917 Kuparuk River Packer Setting Record Field- Final 26-Jul-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40821T40822T40823T40824T40824T40825T40826T40827T40827T40827191-009190-180204-256215-116182-138207-070190-0348/27/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.08.27 12:29:56 -08'00'1C-15350-029-23549-00 910180480Kuparuk RiverLeakDetect LogField- Final19-Jul-25015 1C-15350-029-23549-00 910181004KuparukRiverPacker Setting RecordField- Final28-Jul-2501215-116 1. 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: Tubing Patch 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 feet None feet true vertical feet None feet Effective Depth measured feet true vertical 12825' 3898' 12825' 3898' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 4973' MD 3840' TVD Packers and SSSV (type, measured and true vertical depth) 4325' MD 4417' MD 4944' MD N/A 3638' TVD 3681' TVD 3836' 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: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: Bake HRD-E ZXP W/HD SSSV: None Shelby Sumrall Shelby.Sumrall@conocophillips.com (907) 265-6678Staff Well Integrity Engineer Fine Mesh Screens: 5340-6734', 6914-8305', 8820-10209', 10389-11720', 12085-12691' Fine Mesh Screens: 3863-3859', 3858-3867', 3846-3843', 3844-3860', 3870-3896' measured 4325', 4417', 4944'feet true vertical 3638', 3681', 3836' feet Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 345 Gas-Mcf MD 814 Size 120' 1651 10536189 0 3160 309 measured TVD 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 215-116 50-029-23549-00-00 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, ADL0025649 Kuparuk River Field/ West Sak Oil pool KRU 1C-153 Plugs Junk measured Length Production Liner 5090' 7863' Casing 3856' 4-1/2" 5129' 12807' 3898' 2790' 120'Conductor Surface Intermediate 20" 13-3/8" 78' 2832' 2608' Burst Collapse 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 2:48 pm, Aug 25, 2025 Digitally signed by Shelby Sumrall DN: OU=Alaska, O=Conocophillips, CN=Shelby Sumrall, E=Shelby.Sumrall@conocophillips.com Reason: I am the author of this document Location: Anchorage Alaska Date: 2025.08.25 14:33:10-08'00' Foxit PDF Editor Version: 13.1.6 Shelby Sumrall J.Lau 11/4/25 DSR-9/11/25 RBDMS JSB 082825 DTTMSTART JOBTYP SUMMARYOPS 7/27/2025 ACQUIRE DATA DRIFTED TBG W/ 3.83" GAUGE RING WHILE PUMPING 66 BBLS DIESEL. TOOLS SD ON GAS VENTING SLEEVE @ 4317' RKB. PULLED ACP ISO SLEEVE @ 4386' RKB. BRUSH N FLUSHED PATCH SETTING AREA 4325' - 4428' RKB, AND DB NIPPLE @ 4542' RKB. SET 3.75" DBP PLUG. @ 4542' RKB (OAL= 28"). SET 4.5" BAIT SUB & P-PRONG IN PLUG BODY (OAL= 115.5"). WELL READY FOR CIRC OUT. JOB IN PROGRESS. 7/27/2025 ACQUIRE DATA CIRC OUT PUMP 150 BBLS CISW & 175 BBLS DSL DWN TBG, TAKING RETURNS UP THE IA, U-TUBE TBG X IA (FP'D) CMIT TBG X IA TO 2500PSI (PASS) FREEZE PROTECT FL WITH 4 BBLS DSL. READY FOR RELAY 7/28/2025 ACQUIRE DATA PULLED 3.75" DBP PLUG @ 4542' RKB. DRIFTED TBG w/ 3.76" x 36' PATCH DRIFT TO 4512' RKB. SET 4.5" P2P LOWER PATCH PACKER (CPP45021/ OAL= 4.89') MID-ELEMENT @ 4420' RKB. JOB IN PROGRESS. 7/29/2025 ACQUIRE DATA INSTALLED 4.5'' LWR P2P PACKER 4420' RKB, PASSING 2500 PSI CMIT T X IA, INSTALLED 4.5'' LWR PBR TIE BACK ASSY 4385' RKB, PASSING 2500 PSI CMIT T X IA, INSTALLED UPPER 4.5'' PBR TIE BACK ASSY 4354' RKB, PASSING 2500 PSI CMIT T X IA...IN PROGRESS 7/30/2025 ACQUIRE DATA INSTALLED 4.5'' UPPER P2P PACKER/ PATCH ASSY 4223' RKB, SET TTS TT PERFORMED PASSING 2500 PSI MIT-T & MIT-IA, PULLED TTS TT. JOB IS COMPLETE. 1C-153 Tubing Patch Summary of Operations Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added patch components 1C-153 7/30/2025 Jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: FLCV Flapper at 4998' RKB is closed. Burst disk is burst. ID is 1.280" See attachments 5/22/2025 rmoore22 Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR2019.12 41.7 120.0 120.094.00 Welded SURFACE 13 3/8 12.42 41.6 2,831.5 2,607.9 68.00 L-80 HYD 563 INTERMEDIATE 9 5/8 8.84 38.7 5,129.0 3,856.3 40.00 L-80 Hyd 563 4 1/2" LINER 4 1/2 4.00 4,944.1 12,807.0 3,898.1 11.60 L-80 Hyd 563 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 34.1 Set Depth… 4,972.7 Set Depth… 3,840.1 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-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) 34.1 34.1 0.09 HANGER 10.875 Vetco Gray MB22 4-1/2" Tubing hanger GE Vetco MB222A Offset 3.958 45.0 45.0 0.11 XO Enlarging 5.500 Crossover 4-1/2", 12.6 ppf, L-80 IBT- m box x 5-1/2", 15.5 ppf, L-80, IBT pin 3.930 159.1 159.1 0.40 XO Reducing 5.500 Crossover 5-1/2", 15.5 ppf, L-80, IBT box x 4-1/2", 12.6 ppf, L-80, IBT pin 3.930 504.7 504.1 7.02 NIPPLE 4.500 4-1/2" Camco "DB-6" Nipple w/ 3.875" No-go Profile 3.958 2,748.4 2,537.4 31.99 GAS LIFT 6.438 Camco KBMG3.860 4,215.4 3,588.1 62.17 GAS LIFT 6.438 Camco KBMG 3.860 4,272.5 3,614.1 63.39 Gauge / Pump Sensor 4.500 Baker Gauge Carrier, Dual Guardian, Ported (w/ SurSENS gauges) Baker centralift 3.958 4,317.3 3,634.4 62.84 Gas Venting Sleeve 5.630 Gas Vent POS-3 SSD, 4-1/2" 12.6 ppf, L-80 Vam Top box x pin, 3.90" ID. (Closed ACCESS Vent Sleeve w/ #3 Keys-down to close) **Confirmed Closed 06/22/25*** AccessE SP 3.900 4,347.2 3,648.1 62.47 XO 5.500 Crossover, 4-1/2", 12.6 ppf, L-80, Vam Top Box x 5-1/2" 19ppf, Vam FJL box AccessE SP 4.670 4,350.2 3,649.5 62.43 Motor Shroud 5.500 Motor Shroud #6, 5-1/2" 23ppf, L-80, Vam FJL, P x P AccessE SP 4.670 4,381.6 3,664.1 62.11 Motor Shroud 5.500 Motor Shroud #1, 5-1/2" 23ppf, L-80, Vam FJL, P x P AccessE SP 3.960 4,386.3 3,666.3 62.07 ACP 5.500 Annular Connection Port (ACP), 5- 1/2", 19ppf, Vam FJL Box x 4-1/2", 12.6ppf, Vam Top Box AccessE SP 4.670 4,428.2 3,685.9 62.41 Packoff 4.500 B Profile Assembly, 4-1/2", 12.6 ppf, L-80, IBT-m, box x box AccessE SP 3.960 4,448.6 3,695.3 62.81 Packoff 4.500 No-Go Profile, 3.80" 4-1/2", 12.6 ppf, L-80, IBT-m box x pin AccessE SP 3.800 4,489.2 3,713.5 64.22 Sliding Sleeve 4.500 Baker 4-1/2" CMU w/ 3.812" BX Profile (Run Open), 4-1/2", 12.6 ppf, L-80, Vam Top box x pin. Closed CMU 6/28/2022 3.812 4,542.8 3,735.9 66.23 Nipple - DB 4.950 4-1/2" Camco 3.75" DB Landing Nipple w/ 3.75" Profile (includes collar) Camco 3.750 4,970.2 3,839.8 82.43 Locator 4.750 Baker PBR, No Go Locator, above located, 4-1/2", 12.6 ppf L-80, IBT-m box top Baker 3.880 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) 4,317.33,634.4 62.84POS3-SSDPOS 3 CMU **CLOSED** Down to close 6/28/2022 3.900 4,325.0 3,637.9 62.74 PACKER - PATCH - UPR 4-1/2" UPPER P2P PKR, ELEMENT AT 4328' RKB, OAL = 4.73'. TO PULL: UPPER PKR + SPACER PIPE + ANCHOR LATCH = 27.3' TTS P2P CPP4 5038 7/30/2025 2.000 4,329.3 3,639.9 62.69 ANCHOR LATCH ON SPACER PIPE SPACER PIPE W/ ANCHOR LATCH, OAL = 22.57'. WILL PULL WITH UPPER PACKER CPAL 45009 7/30/2025 2.000 4,344.0 3,646.6 62.51 LEAK LEAK AT 4344' RKB IDENTIFIED VIA LDL 7/19/20253.960 4,352.3 3,650.5 62.41 ANCHOR LATCH ON SPACER PIPE ANCHOR LATCH, SPACER PIPE, & PBR. OAL = 32.25' CPAL 45028 , CPBR 45004 7/29/2025 2.000 4,384.5 3,665.5 62.08 ANCHOR LATCH ON SPACER PIPE ANCHOR LATCH, SPACER PIPE, & PBR. OAL = 32.45' CPAL 45024 , CPBR 45005 7/29/2025 2.000 1C-153, 8/21/2025 8:41:25 AM Vertical schematic (actual) 4 1/2" LINER; 4,944.1-12,807.0 FINE MESH SCREENS; 12,085.0-12,691.0 FINE MESH SCREENS; 10,389.0-11,720.0 FINE MESH SCREENS; 8,820.0 -10,209.0 FINE MESH SCREENS; 6,914.0 -8,305.0 FINE MESH SCREENS; 5,340.0 -6,734.0 INTERMEDIATE; 38.7-5,129.0 Nipple - DB; 4,542.8 Sliding Sleeve; 4,489.2 PACKER - PATCH - LWR; 4,417.0 ANCHOR LATCH ON SPACER PIPE; 4,384.5 Motor Shroud; 4,381.6 ANCHOR LATCH ON SPACER PIPE; 4,352.3 Motor Shroud; 4,350.2 XO; 4,347.2 LEAK; 4,344.0 ANCHOR LATCH ON SPACER PIPE; 4,329.3 XO Threads; 4,332.0 PACKER - PATCH - UPR; 4,325.0 GAS LIFT; 4,215.4 SURFACE; 41.6-2,831.5 GAS LIFT; 2,748.4 NIPPLE; 504.7 Tubing - Pup; 188.5 CONDUCTOR; 41.7-120.0 HANGER; 34.1 KUP PROD KB-Grd (ft) 40.33 RR Date 10/18/201 5 Other Elev… 1C-153 ... TD Act Btm (ftKB) 12,825.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292354900 Wellbore Status PROD Max Angle & MD Incl (°) 95.47 MD (ftKB) 8,747.56 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NIPPLE 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) 4,417.0 3,680.7 62.19 PACKER - PATCH - LWR 4-1/2" LWR P2P PKR MID- ELEMENT AT 4420' RKB, OAL 4.89' TTS P2P CPP4 5021 7/28/2025 2.000 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) 2,748.4 2,537.4 31.99 1 GAS LIFT GLV BK 1 1,485.0 6/29/2022 0.188 4,215.4 3,588.1 62.17 2 GAS LIFT OVBK 1 6/22/20250.250 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) 4,944.1 3,836.2 81.78 PACKER 8.440 BAKER HRD-E ZXP W/HD's Baker 7.375 4,963.1 3,838.9 82.26 NIPPLE 7.660 BAKER RS NIPPLE Baker 4.870 4,975.7 3,840.5 82.57 XO REDUCING 7.000 XO 7" 26# Hydril 563 box X 5 1/2" 15.5# Hydril 563 pin 4.870 4,996.8 3,843.2 83.11 XO THREAD 7.000 XO 5-1/2" 15.5 ppf Hyd 563 box x 7" 26 ppf L-80 Hyd 563 pin 4.920 4,998.2 3,843.3 83.14 VALVE 7.000 BAKER FLUID LOSS CONTROL VALVE, sheared 10/25/2015 4.563 5,004.9 3,844.1 83.31 XO REDUCING 7.000 XO, 7" 29# Hyd 563 box x 5-1/2" 15.5# Hyd 563 pin 4.880 5,083.8 3,852.2 84.64 XO REDUCING 5.500 XO 5-1/2" 15.5# Hyd 563 box x 4- 1/2" 12.6# Hyd 563 pin 4.000 5,250.83,863.888.50SWELL PACKER 4.500 BAKER SWELL PACKER (WATER ACTIVATED) "G" 3.958 5,300.7 3,864.1 90.71 XO THREAD 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563 Box x pin 3.958 5,311.4 3,864.0 91.19 TRACER 4.500 TRACERCO TRACER CARTRIDGE SER# 01 Tracerco 3.958 5,330.83,863.4 92.05XO Thread 4.500 XO 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 11.6 ppf L-80 Hyd 563 box Tracerco 3.958 5,331.8 3,863.4 92.09 XO Thread 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563-m pin x pin 3.958 6,824.2 3,858.2 90.61 SWELL PACKER 4.500 BAKER SWELL PACKER (WATER ACTIVATED) "F" 3.958 6,874.23,857.7 90.42 XO THREAD 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563 Box x pin 3.958 6,884.9 3,857.7 90.38 TRACER 4.500 TRACERCO TRACER CARTRIDGE, ser # 03 Tracerco ser # 3, Tracerco 919/Tracerc o 165A 3.958 6,904.6 3,857.6 90.29 XO THREAD 4.500 XO 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 11.6 ppf L-80 Hyd 563 box Tracerco 3.958 6,905.7 3,857.6 90.29 XO THREAD 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563-m pin x pin 3.958 8,394.5 3,867.0 90.17 SWELL PACKER 4.500 BAKER SWELL PACKER (WATER ACTIVATED) "E" H301-87- 0398 3.958 8,730.0 3,852.6 95.25 SWELL PACKER 4.500 BAKER SWELL PACKER (WATER ACTIVATED) "D" H301-87- 0398 3.958 8,779.9 3,848.2 94.14 XO THREAD 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563 Box x pin 3.958 8,790.5 3,847.5 93.71 TRACER 4.500 TRACERCO TRACER CARTRIDGE SER # 05 Tracerco ser # 5, Tracerco 911/Tracerc o 165F 3.958 8,810.3 3,846.4 92.90 XO THREAD 4.500 XO 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 11.6 ppf L-80 Hyd 563 box Tracerco 3.958 8,811.3 3,846.3 92.86 XO THREAD 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563-m pin x pin 3.958 10,299.1 3,842.9 89.63 SWELL PACKER 4.500 BAKER SWELL PACKER (WATER ACTIVATED) "C" H301-87- 0398 3.958 10,349.1 3,843.3 89.63 XO THREAD 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563 Box x pin 3.958 10,359.83,843.389.63 TRACER 4.500 TRACERCO TRACER CARTRIDGE SER # 07 Tracerco ser # 7, Tracerco 913/Tracerc o 726 3.958 10,379.5 3,843.5 89.61 XO Thread 4.500 XO 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 11.6 ppf L-80 Hyd 563 box Tracerco 3.958 10,380.6 3,843.5 89.61 XO Thread 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563-m pin x pin 3.958 11,819.4 3,862.8 88.67 SWELL PACKER 4.500 BAKER SWELL PACKER (WATER ACTIVATED) "B" BakerH301-87- 0398 3.958 11,995.5 3,867.4 88.23 SWELL PACKER 4.500 BAKER SWELL PACKER (WATER ACTIVATED) "A" BakerH301-87- 0398 3.958 12,045.6 3,868.9 88.20 XO THREAD 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563 Box x pin 3.958 12,056.23,869.388.19 TRACER 4.500 TRACERCO TRACER CARTRIDGE SER # 09 Tracerco ser # 9, Tracerco 920/Tracerc o 716 3.958 12,075.9 3,869.9 88.13 XO THREAD 4.500 XO 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 11.6 ppf L-80 Hyd 563 box Tracerco 3.958 12,077.0 3,869.9 88.12 XO THREAD 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563-m pin x pin 3.958 12,783.7 3,897.7 88.87 PACKOFF 4.500 BAKER PACK-OFF BUSHING Baker 2.370 1C-153, 8/21/2025 8:41:28 AM Vertical schematic (actual) 4 1/2" LINER; 4,944.1-12,807.0 FINE MESH SCREENS; 12,085.0-12,691.0 FINE MESH SCREENS; 10,389.0-11,720.0 FINE MESH SCREENS; 8,820.0 -10,209.0 FINE MESH SCREENS; 6,914.0 -8,305.0 FINE MESH SCREENS; 5,340.0 -6,734.0 INTERMEDIATE; 38.7-5,129.0 Nipple - DB; 4,542.8 Sliding Sleeve; 4,489.2 PACKER - PATCH - LWR; 4,417.0 ANCHOR LATCH ON SPACER PIPE; 4,384.5 Motor Shroud; 4,381.6 ANCHOR LATCH ON SPACER PIPE; 4,352.3 Motor Shroud; 4,350.2 XO; 4,347.2 LEAK; 4,344.0 ANCHOR LATCH ON SPACER PIPE; 4,329.3 XO Threads; 4,332.0 PACKER - PATCH - UPR; 4,325.0 GAS LIFT; 4,215.4 SURFACE; 41.6-2,831.5 GAS LIFT; 2,748.4 NIPPLE; 504.7 Tubing - Pup; 188.5 CONDUCTOR; 41.7-120.0 HANGER; 34.1 KUP PROD 1C-153 ... WELLNAME WELLBORE Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 5,340.0 6,734.0 3,863.1 3,859.3 WS D, 1C-153 10/6/2015 FINE MESH SCREEN S Excluder 2K screens #114 - #146 6,914.0 8,305.0 3,857.5 3,866.8 WS D, 1C-153 10/6/2015 FINE MESH SCREEN S Excluder 2K screens #81 - #113 8,820.0 10,209.0 3,845.9 3,842.5 WS D, 1C-153 10/6/2015 FINE MESH SCREEN S Excluder 2K screens #48 - #80 10,389.0 11,720.0 3,843.5 3,860.4 WS D, 1C-153 10/6/2015 FINE MESH SCREEN S Excluder 2K screens #16 - #47 12,085.0 12,691.0 3,870.2 3,895.8 WS D, 1C-153 10/6/2015 FINE MESH SCREEN S Excluder 2K screens # 1 - #15 1C-153, 8/21/2025 8:41:31 AM Vertical schematic (actual) 4 1/2" LINER; 4,944.1-12,807.0 FINE MESH SCREENS; 12,085.0-12,691.0 FINE MESH SCREENS; 10,389.0-11,720.0 FINE MESH SCREENS; 8,820.0 -10,209.0 FINE MESH SCREENS; 6,914.0 -8,305.0 FINE MESH SCREENS; 5,340.0 -6,734.0 INTERMEDIATE; 38.7-5,129.0 Nipple - DB; 4,542.8 Sliding Sleeve; 4,489.2 PACKER - PATCH - LWR; 4,417.0 ANCHOR LATCH ON SPACER PIPE; 4,384.5 Motor Shroud; 4,381.6 ANCHOR LATCH ON SPACER PIPE; 4,352.3 Motor Shroud; 4,350.2 XO; 4,347.2 LEAK; 4,344.0 ANCHOR LATCH ON SPACER PIPE; 4,329.3 XO Threads; 4,332.0 PACKER - PATCH - UPR; 4,325.0 GAS LIFT; 4,215.4 SURFACE; 41.6-2,831.5 GAS LIFT; 2,748.4 NIPPLE; 504.7 Tubing - Pup; 188.5 CONDUCTOR; 41.7-120.0 HANGER; 34.1 KUP PROD 1C-153 ... WELLNAME WELLBORE P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 9, 2025 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitors, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Brennen Green or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, ConocoPhillips Well Integrity Field Supervisor RBDMS JSB 081425 Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@ conocophillips.com Reason: I am the author of this document Location: Date: 2025.08.11 16:34:01-08'00' Foxit PDF Editor Version: 13.1.6 Brennen Green ConocoPhillips Alaska Inc.Well Name API # PTD #Initial top of cementVol. of Portland Type I cement pumpedFinal top of cementCement top off date Corrosion inhibitorCorrosion inhibitor/ sealant datein gal in gal1C-17 50-029-22872-00-00 198-224 N/AN/A post SC Repair8" N/A 0.85 8/7/20251C-150 50-029-23496-00-00 213-120 N/AN/A Rig cemented to surface4" N/A 3 8/7/20251C-152 50-029-23548-00-00 215-114 50" 34.4 9" 7/31/2025 2.13 8/7/20251C-153 50-029-23549-00-00 215-116 N/AN/A Rig cemented to surface9" N/A 1.73 8/7/20251C-154 50-029-23559-00-00 215-166 70" 51.8 10" 7/31/2025 3.4 8/7/20251C-155 50-029-23561-00-00 215-180 64" 35.8 8" 7/31/2025 1.7 8/7/20251C-15650-029-23750-00-00 223-023 25" 12.00 10" 7/31/2025 5.1 8/7/20251C-157 50-029-23754-00-00 223-038 57" 30.28 9" 7/31/2025 2.2 8/7/20251C-15850-029-23761-00-00 223-056 3"N/A Rig cemented to surface10" 7/31/2025 4.25 8/7/20251C-501 50-029-23757-00-00 223-045 139" 11.40 8" 7/31/2025 3.8 8/7/20251H-107 50-029-23795-00-00 224-092 34" 14.80 10" 7/31/2025 5.25 8/7/20251H-11250-029-23787-01-00 224-032 47" 33.19 7" 7/31/2025 4.25 8/7/20251H-12050-029-23794-01-00 224-081 30" 13.70 8" 7/31/2025 4 8/7/20253H-3550-103-20805-00-00 219-064 45" 32.20 7" 8/1/2025 3.6 8/8/20253H-3650-103-20838-00-00 222-014 60" 44.20 8" 8/1/2025 3.4 8/8/20253H-3750-103-20822-00-00 219-194 35" 23.00 8" 8/1/2025 3.4 8/8/2025Date 08/09/251C, 1H, and 3H PadsKuparuk FieldReport of Sundry Operations (10-404)Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off1C-15350-029-23549-00-00215-116N/A9"N/A1.738/7/2025N/A Rig cemented to surface 1. 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: 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 12825'feet None feet true vertical 3898' feet None feet Effective Depth measured 12825'feet 4944'feet true vertical 3898' feet 3836' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 4973' MD 3840' TVD Packers and SSSV (type, measured and true vertical depth) 4944' MD N/A 3836' 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: 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: 322-364 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 100 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker HRD-E ZXP Packer SSSV: None Will Parker Will.Parker@conocophillips.com (907) 265-6239Senior Production Engineer Fine Mesh Screens: 5340-6734', 6914-8305', 8820-10209', 10389-11720', 12085-12691' Fine Mesh Screens: 3863-3859', 3857-3867', 3846-3842', 3843-3860', 3870-3896' 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) 500 Gas-Mcf MD 1300 Size 120' 450 750100 375 320500 340 measured TVD 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 215-116 50-029-23549-00-00 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, ADL0025649 Kuparuk River Field/ West Sak Oil Pool KRU 1C-153 Plugs Junk measured Length Production Liner 5090' 7863' Casing 3856' 4-1/2" 5129' 12807' 3898' 2790' 120'Conductor Surface Intermediate 20" 13-3/8" 78' 2831' 2608' Burst Collapse 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 1:37 pm, Jul 13, 2023 DTTMSTART JOBTYP SUMMARYOPS 6/5/2022 ESP / JET PUMP SET BAITED 4 1/2 GR @ 4308' RKB; REPLACED SOV IN KIND @ 4125' RKB (OBTAIN GOOD TBG TEST); PULLED BAITED GR & SLIP STOP @ 4308' RKB; PULLED 4 1/2" ACCESS PACKOFF ASSEMBLY @ 4310' RKB; PULLED 4 1/2" X 45' ESP @ 4317' RKB. IN PROGRESS. 6/6/2022 ESP / JET PUMP PULLED 40' 4 1/2 ACCESS MOTOR. JOB SUSPENDED FOR PLAN FORWARD. 6/28/2022 REPAIR WELL SET 4 1/2" SLIP STOP CATCHER @ 4542' RKB; PULLED SOV & SET DV @ 4217' RKB; PULLED CATCHER @ 4542' RKB; CLOSED CMU @ 4489' RKB; CLOSED ACCESS CMU VENTING SLEEVE (#3 KEYS) @ 4317' RKB; RAN 4.5" ACCESS ISO SLEEVE (11.3' OAL) & WAIT FOR LRS TO BULLHEAD 150 BBLS OF CISW FOLLOWED BY 140 BBLS OF DIESEL TO FORMATION & SET SLEEVE @ 4386' RKB. LEAVE LRS ON LOCATION TO MITIA. IN PROGRESS. 6/29/2022 REPAIR WELL MIT-IA TO 2500 PSI *PASSED* PUMPED 2.5 BBLS DOWN IA TO REACH TEST PRESSURE. SEE BELOW FOR RESULTS. 6/29/2022 REPAIR WELL SET BAITED HOLEFINDER @ 4386' RKB; PULLED DV & SET OV @ 4217' RKB; PULLED DV & SET GLV @ 2748' RKB (OBTAIN GOOD DDT ON IA); PULLED HOLEFINDER @ 4386' RKB. JOB COMPLETE. 5/11/2023 MAINTAIN WELL HOT FLUSHED TBG WITH 20 BBLS DSL 180* AND TBG LOCKED UP. NO FP DOWN FL PER DSO. RDMO 1C-153 Convert ESP to GL Summary of Operations 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 41.7 120.0 120.0 94.00 Welded SURFACE 13 3/8 12.42 41.6 2,831.5 2,607.9 68.00 L-80 HYD 563 INTERMEDIATE 9 5/8 8.84 38.7 5,129.0 3,856.3 40.00 L-80 Hyd 563 4 1/2" LINER 4 1/2 4.00 4,944.1 12,807.0 3,898.1 11.60 L-80 Hyd 563 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 34.1 Set Depth 4,972.7 Set Depth 3,840.1 String Ma 4 1/2 Tubing Description Tubing Production Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-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) 34.1 34.1 0.09 HANGER 10.875 Vetco Gray MB22 4-1/2" Tubing hanger GE Vetco MB222A Offset 3.958 45.0 45.0 0.11 XO Enlarging 5.500 Crossover 4-1/2", 12.6 ppf, L-80 IBT- m box x 5-1/2", 15.5 ppf, L-80, IBT pin CPAI # 1368352 1 3.930 159.1 159.1 0.40 XO Reducing 5.500 Crossover 5-1/2", 15.5 ppf, L-80, IBT box x 4-1/2", 12.6 ppf, L-80, IBT pin CPAI # 1368352 2 3.930 504.7 504.1 7.02 NIPPLE 4.500 4-1/2" Camco "DB-6" Nipple w/ 3.875" No-go Profile PN: 33873- 000- 00002, ser# N15N10 61, 3.958 2,748.4 2,537.4 31.99 GAS LIFT 6.438 Camco KBMG 3.860 4,215.4 3,588.1 62.17 GAS LIFT 6.438 Camco KBMG 3.860 4,272.5 3,614.1 63.39 Gauge / Pump Sensor 4.500 Baker Guage Carrier, Dual Guardian, Ported (w/ SurSENS guages) Baker centralift 1166718 3 3.958 4,317.3 3,634.4 62.84 Gas Venting Sleeve 5.630 Gas Vent POS-3 SSD, 4-1/2" 12.6 ppf, L-80 Vam Top box x pin, 3.90" ID AccessE SP Closed ACCES S Vent Sleeve w/ #3 Keys- down to close) 6/28/202 2 3.900 4,347.2 3,648.1 62.47 XO 5.500 Crossover, 4-1/2", 12.6 ppf, L-80, Vam Top Box x 5-1/2" 19ppf, Vam FJL box AccessE SP 4.670 4,350.2 3,649.5 62.43 Motor Shroud 5.500 Motor Shroud #6, 5-1/2" 23ppf, L-80, Vam FJL, P x P AccessE SP 4.670 4,381.6 3,664.1 62.11 Motor Shroud 5.500 Motor Shroud #1, 5-1/2" 23ppf, L-80, Vam FJL, P x P AccessE SP 3.960 4,386.3 3,666.3 62.07 ACP 5.500 Annular Connection Port (ACP), 5- 1/2", 19ppf, Vam FJL Box x 4-1/2", 12.6ppf, Vam Top Box AccessE SP 4.670 4,428.2 3,685.9 62.41 Packoff 4.500 B Profile Assembly, 4-1/2", 12.6 ppf, L-80, IBT-m, box x box AccessE SP 3.960 4,448.6 3,695.3 62.81 Packoff 4.500 No-Go Profile, 3.80" 4-1/2", 12.6 ppf, L-80, IBT-m box x pin AccessE SP 3.800 4,489.2 3,713.5 64.22 Sliding Sleeve 4.500 Baker 4-1/2" CMU w/ 3.812" BX Profile (Run Open), 4-1/2", 12.6 ppf, L-80, Vam Top box x pin Closed CMU 6/28/202 2 3.812 4,542.8 3,735.9 66.23 Nipple - DB 4.950 4-1/2" Camco 3.75" DB Landing Nipple w/ 3.75" Profile (includes collar) Camco CPAI PN: 1343751 , PN: 1007288 79 ser# CYN- 0139 3.750 4,970.2 3,839.8 82.43 Locator 4.750 Baker PBR, No Go Locator, above located, 4-1/2", 12.6 ppf L-80, IBT-m box top Baker 1063341 9 3.880 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) 4,317.3 3,634.4 62.84 POS3-SSD POS 3 CMU **CLOSED** Down to close 6/28/2022 3.900 4,386.0 3,666.2 62.07 ISO-SLEEVE ACCESS ISO (11.33' OAL) 6/28/2022 2.970 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) 2,748.4 2,537.4 31.99 1 GAS LIFT GLV BK 1 1,485.0 6/29/2022 0.188 4,215.4 3,588.1 62.17 2 GAS LIFT OV BK 1 0.0 6/29/2022 0.250 FINE MESH SCREENS; 10,389.0-11,720.0 FINE MESH SCREENS; 8,820.0 -10,209.0 FINE MESH SCREENS; 6,914.0 -8,305.0 FINE MESH SCREENS; 5,340.0 -6,734.0 INTERMEDIATE; 38.7-5,129.0 Nipple - DB; 4,542.8 Sliding Sleeve; 4,489.2 ISO-SLEEVE; 4,386.0 Motor Shroud; 4,381.6 Motor Shroud; 4,350.2 XO; 4,347.2 XO Threads; 4,332.0 GAS LIFT; 4,215.4 SURFACE; 41.6-2,831.5 GAS LIFT; 2,748.4 NIPPLE; 504.7 Tubing - Pup; 188.5 CONDUCTOR; 41.7-120.0 HANGER;34.1 4,963.1 3,838.9 82.26 NIPPLE 7.660 BAKER RS NIPPLE Baker CPAI# 10787695 4.870 4,975.7 3,840.5 82.57 XO REDUCING 7.000 XO 7" 26# Hydril 563 box X 5 1/2" 15.5# Hydril 563 pin CPAI# 11091227 4.870 4,996.8 3,843.2 83.11 XO THREAD 7.000 XO 5-1/2" 15.5 ppf Hyd 563 box x 7" 26 ppf L-80 Hyd 563 pin CPAI#1367 7075 4.920 4,998.2 3,843.3 83.14 VALVE 7.000 BAKER FLUID LOSS CONTROL VALVE, sheared 10/25/2015 CPAI# 13527559 4.563 5,004.9 3,844.1 83.31 XO REDUCING 7.000 XO, 7" 29# Hyd 563 box x 5-1/2" 15.5# Hyd 563 pin CPAI#1367 7076 4.880 5,083.8 3,852.2 84.64 XO REDUCING 5.500 XO 5-1/2" 15.5# Hyd 563 box x 4- 1/2" 12.6# Hyd 563 pin CPAI#1145 0111 4.000 5,250.8 3,863.8 88.50 SWELL PACKER 4.500 BAKER SWELL PACKER (WATER ACTIVATED) "G" 3.958 5,300.7 3,864.1 90.71 XO THREAD 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563 Box x pin CPAI#1362 9547 3.958 5,311.4 3,864.0 91.19 TRACER 4.500 TRACERCO TRACER CARTRIDGE SER# 01 Tracerco 3.958 5,330.8 3,863.4 92.05 XO Thread 4.500 XO 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 11.6 ppf L-80 Hyd 563 box Tracerco ser # 1, Tracerco 926/Tracerc o 721 3.958 5,331.8 3,863.4 92.09 XO Thread 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563-m pin x pin 3.958 6,824.2 3,858.2 90.61 SWELL PACKER 4.500 BAKER SWELL PACKER (WATER ACTIVATED) "F" 3.958 6,874.2 3,857.7 90.42 XO THREAD 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563 Box x pin CPAI#1362 9547 3.958 6,884.9 3,857.7 90.38 TRACER 4.500 TRACERCO TRACER CARTRIDGE, ser # 03 Tracerco ser # 3, Tracerco 919/Tracerc o 165A 3.958 6,904.6 3,857.6 90.29 XO THREAD 4.500 XO 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 11.6 ppf L-80 Hyd 563 box Tracerco 3.958 6,905.7 3,857.6 90.29 XO THREAD 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563-m pin x pin 3.958 8,394.5 3,867.0 90.17 SWELL PACKER 4.500 BAKER SWELL PACKER (WATER ACTIVATED) "E" H301-87- 0398, ser # 49168-001- 16 3.958 8,730.0 3,852.6 95.25 SWELL PACKER 4.500 BAKER SWELL PACKER (WATER ACTIVATED) "D" H301-87- 0398, ser # 49168-001- 35 3.958 8,779.9 3,848.2 94.14 XO THREAD 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563 Box x pin 3.958 8,790.5 3,847.5 93.71 TRACER 4.500 TRACERCO TRACER CARTRIDGE SER # 05 Tracerco ser # 5, Tracerco 911/Tracerc o 165F 3.958 8,810.3 3,846.4 92.90 XO THREAD 4.500 XO 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 11.6 ppf L-80 Hyd 563 box Tracerco 3.958 8,811.3 3,846.3 92.86 XO THREAD 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563-m pin x pin 3.958 10,299.1 3,842.9 89.63 SWELL PACKER 4.500 BAKER SWELL PACKER (WATER ACTIVATED) "C" H301-87- 0398, ser # 49168-001- 5 3.958 10,349.1 3,843.3 89.63 XO THREAD 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563 Box x pin 3.958 10,359.8 3,843.3 89.63 TRACER 4.500 TRACERCO TRACER CARTRIDGE SER # 07 Tracerco ser # 7, Tracerco 913/Tracerc o 726 3.958 10,379.5 3,843.5 89.61 XO Thread 4.500 XO 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 11.6 ppf L-80 Hyd 563 box Tracerco 3.958 10,380.6 3,843.5 89.61 XO Thread 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563-m pin x pin 3.958 11,819.4 3,862.8 88.67 SWELL PACKER 4.500 BAKER SWELL PACKER (WATER ACTIVATED) "B" Baker H301-87- 0398, ser # 49168-001- 3 3.958 11,995.5 3,867.4 88.23 SWELL PACKER 4.500 BAKER SWELL PACKER (WATER ACTIVATED) "A" Baker H301-87- 0398, ser # 49168-001- 13 3.958 12,045.6 3,868.9 88.20 XO THREAD 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563 Box x pin 3.958 12,056.2 3,869.3 88.19 TRACER 4.500 TRACERCO TRACER CARTRIDGE SER # 09 Tracerco ser # 9, Tracerco 920/Tracerc o 716 3.958 12,075.9 3,869.9 88.13 XO THREAD 4.500 XO 5-1/2" 15.5 ppf, L-80 Hyd 511 box x 4-1/2" 11.6 ppf L-80 Hyd 563 box Tracerco 3.958 12,077.0 3,869.9 88.12 XO THREAD 4.500 Pup Joint, 4-1/2", 11.6 ppf, L-80 Hyd 563-m pin x pin 3.958 12,783.7 3,897.7 88.87 PACKOFF 4.500 BAKER PACK-OFF BUSHING Baker CPAI # 2.370 FINE MESH SCREENS; 10,389.0-11,720.0 FINE MESH SCREENS; 8,820.0 -10,209.0 FINE MESH SCREENS; 6,914.0 -8,305.0 FINE MESH SCREENS; 5,340.0 -6,734.0 INTERMEDIATE; 38.7-5,129.0 Nipple - DB; 4,542.8 Sliding Sleeve; 4,489.2 ISO-SLEEVE; 4,386.0 Motor Shroud; 4,381.6 Motor Shroud; 4,350.2 XO; 4,347.2 XO Threads; 4,332.0 GAS LIFT; 4,215.4 SURFACE; 41.6-2,831.5 GAS LIFT; 2,748.4 NIPPLE; 504.7 Tubing - Pup; 188.5 CONDUCTOR; 41.7-120.0 HANGER;34.1 5,340.0 6,734.0 3,863.1 3,859.3 WS D, 1C-153 10/6/2015 FINE MESH SCREEN S Excluder 2K screens #114 - #146 6,914.0 8,305.0 3,857.5 3,866.8 WS D, 1C-153 10/6/2015 FINE MESH SCREEN S Excluder 2K screens #81 - #113 8,820.0 10,209.0 3,845.9 3,842.5 WS D, 1C-153 10/6/2015 FINE MESH SCREEN S Excluder 2K screens #48 - #80 10,389.0 11,720.0 3,843.5 3,860.4 WS D, 1C-153 10/6/2015 FINE MESH SCREEN S Excluder 2K screens #16 - #47 12,085.0 12,691.0 3,870.2 3,895.8 WS D, 1C-153 10/6/2015 FINE MESH SCREEN S Excluder 2K screens # 1 - #15 FINE MESH SCREENS; 10,389.0-11,720.0 FINE MESH SCREENS; 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PrL, z(si)oo Regg, James B (DOA) From: Tam, Sindy P <Sindy.P.Tam@conocophillips.com> Sent: Wednesday, October 14, 2015 4:12 AM t )0( 14 115 To: Loepp, Victoria T (DOA) Cc: Regg,James B (DOA); DOA AOGCC Prudhoe Bay; Doyon 25 Company Man Subject: RE: PTD# 215-116 1C-153 Notification of BOP Use per Guidance Bulletin 10-003 Sorry Victoria, Yes,the planned is to conduct the BOPE test be after the next trip out of the hole. Let me explain the operation and BHA in the operation that leads to the usage of the BOPE a little better. This BOPE usage event happens during our open-hole standalone screens lower completion running operation.This lower completion consist of the screens with wash-pipe, liner hanger and liner hanger packer.All these equipment are run in hole with drill pipe. With the lower completion at TD, we set the liner hanger but not the liner hanger packer and circulate 2 BU. It is after circulating the 2 BU, when we observed this wellbore breathing event and activated our BOPE. We have now set the liner hanger packer and POOH with the drill pipe and wash pipe. Once all those are out of the hole, we will conduct the BOPE test. Please advise, Sindy SCANNE From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, October 14, 2015 3:32 AM To: Tam, Sindy P Cc: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Subject: [EXTERNAL]Re: PTD# 215-116 1C-153 Notification of BOP Use per Guidance Bulletfn 10-003 Sindy, All BOPE components used during the BOP usage event must be tested Ore'next trip out of hole. Thanx, /f Victoria Sent from my iPhone On Oct 13, 2015, at 11:21 PM, Tam, Sindy P <Sind '.Tam _ conoco•hilli.s.com> wrote: Date,Time of BOPE use: 10/13/2015 17:05 Well/Location/PTD number: ERU 1C-153/. uparuk Drill Site 1C/ PTD#215-116 Rig Name: Doyon 25 Operator Contact: Sindy Tam (Completion Engi -er)—(281) 221-0427 Doyon 25 Company Man ( -e Martin—days)—(907) 659-7501 1 • • Regg, James B (DOA) From: Tam, Sindy P <Sindy.P.Tam@conocophillips.com> Sent: Tuesday, October 13, 2015 11:21 PM To: Loepp, Victoria T (DOA); Regg, James B (DOA); 'doa.aogcc.prudhoe.bay@alaska.gov' Cc: Doyon 25 Company Man; Herbert, Frederick 0; Bearden,J Daniel; Lee, David L; Kurnia, Dadang Subject: PTD#215-116 1C-153 Notification of BOP Use per Guidance Bulletin 10-003 Date,Time of BOPE use: 10/13/2015 17 Well/Location/PTD number: ERU 1C-153/Kuparuk Drill Site 1C/ PTD#215-116 ' Rig Name: Doyon 25 Operator Contact: Sindy Tam (Completion Engineer)—(281) 221-0427 Doyon 25 Company Man (Lee Martin—days)—(907) 659-7501 OPE Used: Annular .� Reason for BOPE Use: Observed well flowback and gain. Operations Summary, including events leading up to BOPE use: After circulate 2 BU. Opened the bag and observed well flow back and gained 10 bbl. Closed Annular. Monitor pressure. Observed ISICP stabilized at 52psi, and ISITP at 80 psi. Continue to monitor pressure, observed SICP decrease. Open choke to 1/4 open to Rig gas buster and bleed back 10 bbl. SI well, monitor pressure. Observed SICP and SITP of 17psi and 20psi, respectively. Open well to bleed off. Perform Exhale test by opening choke to rig gas buster for 50minutes. Flow decrease from .38bpm to 0 with 12 bbl. bleed back. No Flow observed for 15 minutes. Decide to Open annular. Monitor Well, static for another 15 minutes. Determined event is wellbore breathing. Plan forward: Set packer, pressure test packer. POOH. Perform schedule routine BOPE testing including the annular. 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IP P\--C) ,Z 2.1G- IICo Ay- ).- 2-(01-10q Ni.-Wiis-COLL Schiumberger Transmittal#: 17DEC15-SPO1 1Q MWD/LWD Log Product Delivery ( e—C— t V( 2-ot Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 1C-153**REVISION-1*Y Date Dispatched: 17-Dec-15 Job#: 15AKA0094 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: N/A Contents on CD N/A T c#O y:. !‘,1:1) VD LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x .+BION-1** As-Built Survey N/A Contents on CD N/A Nad83 x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt **REV-1** x Please sign and email a copy to: Please sign and email a copy to: Richard.E.Elgaricoconocophillips.com ®C(� I intCenter(c�slb.com Ricky Elgarico �"1`�+ : tep anie Pacillo 907- • -6580 41. JAN 2 0 ZOlt Received By: - `i. AOGUC • II (O 204 Oct REVISED 5:04 pm, Dec 15, 2015 NADConversion Kuparuk River Unit Kuparuk 1C Pad 1C-153 Definitive Survey Report 25 November, 2015 NAD 27 Schlumberger S . Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-153 Project: Kuparuk River Unit TVD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 2E Site: Kuparuk 1C Pad MD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 2t Well: 1C-153 North Reference: True Wellbore: 1C-153 Survey Calculation Method: Minimum Curvature Design: 1C-153 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1C-153 Well Position +N/-S 0.00 usft Northing: 5,968,939.48 usfl Latitude: 70° 19'32.426 N +E/-W 0.00 usft Easting: 561,894.98 usfl Longitude: 149°29'53.119 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 57.60 usft Wellbore 1C-153 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 9/21/2015 18.95 80.99 57,506 Design 1C-153 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 40.33 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 40.33 0.00 0.00 355.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 78.31 735.51 1C-153 Srvy#1 -GYD-GC-SS(1C-153) GYD-GC-SS Gyrodata gyro single shots 9/22/2015 8:5. 793.29 2,757.10 1C-153 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/22/2015 8:5 2,820.54 5,058.28 1C-153 Srvy#3-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/22/2015 9:01 5,144.73 12,761.91 1C-153 Srvy#4-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/5/2015 9:0: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 40.33 0.00 0.00 40.33 -57.60 0.00 0.00 5,968,939.48 561,894.98 0.00 0.00 UNDEFINED 78.31 0.64 128.57 78.31 -19.62 -0.13 0.17 5,968,939.35 561,895.15 1.69 -0.15 GYD-GC-SS(1) 120.00 0.42 100.85 120.00 22.07 -0.31 0.50 5,968,939.18 561,895.48 0.80 -0.35 C NOT an Actual Survey 20"x34" 172.94 0.44 41.63 172.94 75.01 -0.19 0.82 5,968,939.30 561,895.80 0.80 -0.26 GYD-GC-SS(1) 267.22 1.31 22.36 267.20 169.27 1.08 1.47 5,968,940.57 561,896.44 0.96 0.94 GYD-GC-SS(1) 363.97 2.65 27.23 363.89 265.96 4.09 2.92 5,968,943.59 561,897.86 1.39 3.82 GYD-GC-SS(1) 459.27 5.75 18.89 458.93 361.00 10.57 5.47 5,968,950.09 561,900.36 3.31 10.05 GYD-GC-SS(1) 551.31 8.32 17.90 550.27 452.34 21.27 9.01 5,968,960.82 561,903.81 2.80 20.40 GYD-GC-SS(1) 641.81 12.22 31.18 639.31 541.38 35.70 15.98 5,968,975.31 561,910.67 5.01 34.17 GYD-GC-SS(1) 735.51 14.98 35.49 730.38 632.45 54.05 28.15 5,968,993.75 561,922.68 3.14 51.39 GYD-GC-SS(1) 11/25/2015 9:23:08AM Page 2 COMPASS 5000.1 Build 74 Schlumberger IP S . Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-153 Project: Kuparuk River Unit TVD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 28 Site: Kuparuk 1C Pad MD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25 Well: 1C-153 North Reference: True Wellbore: 1C-153 Survey Calculation Method: Minimum Curvature Design: 1C-153 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 793.29 15.48 42.83 786.13 688.20 65.78 37.73 5,969,005.57 561,932.16 3.44 62.25 MWD+IFR-AK-CAZ-SC(2) 888.22 14.53 47.41 877.83 779.90 83.13 55.11 5,969,023.06 561,949.40 1.60 78.02 MWD+IFR-AK-CAZ-SC(2) 983.33 14.15 46.96 969.98 872.05 99.14 72.39 5,969,039.21 561,966.54 0.42 92.46 MWD+IFR-AK-CAZ-SC(2) 1,077.89 18.38 42.62 1,060.73 962.80 118.01 90.94 5,969,058.23 561,984.94 4.65 109.64 MWD+IFR-AK-CAZ-SC(2) 1,171.77 21.47 44.38 1,148.98 1,051.05 141.19 112.99 5,969,081.58 562,006.79 3.35 130.80 MWD+IFR-AK-CAZ-SC(2) 1,266.87 21.55 46.01 1,237.46 1,139.53 165.76 137.73 5,969,106.35 562,031.32 0.63 153.12 MWD+IFR-AK-CAZ-SC(2) 1,361.48 21.10 50.93 1,325.60 1,227.67 188.56 163.45 5,969,129.37 562,056.85 1.95 173.60 MWD+IFR-AK-CAZ-SC(2) 1,456.35 21.71 53.81 1,413.93 1,316.00 209.69 190.87 5,969,150.71 562,084.10 1.28 192.25 MWD+IFR-AK-CAZ-SC(2) 1,550.77 20.09 55.93 1,502.14 1,404.21 229.08 218.40 5,969,170.33 562,111.46 1.89 209.18 MWD+IFR-AK-CAZ-SC(2) 1,645.11 23.00 52.74 1,589.88 1,491.95 249.32 246.50 5,969,190.80 562,139.39 3.32 226.89 MWD+IFR-AK-CAZ-SC(2) 1,739.78 23.98 53.92 1,676.70 1,578.77 271.85 276.77 5,969,213.58 562,169.47 1.15 246.70 MWD+IFR-AK-CAZ-SC(2) 1,834.95 28.10 53.99 1,762.19 1,664.26 296.43 310.54 5,969,238.43 562,203.04 4.33 268.24 MWD+IFR-AK-CAZ-SC(2) 1,929.53 28.55 55.52 1,845.45 1,747.52 322.32 347.19 5,969,264.62 562,239.47 0.90 290.83 MWD+IFR-AK-CAZ-SC(2) 2,024.25 31.27 56.84 1,927.55 1,829.62 348.59 386.44 5,969,291.21 562,278.49 2.95 313.58 MWD+IFR-AK-CAZ-SC(2) 2,118.12 32.90 56.42 2,007.08 1,909.15 376.01 428.07 5,969,318.98 562,319.90 1.75 337.27 MWD+IFR-AK-CAZ-SC(2) 2,212.46 33.85 58.11 2,085.86 1,987.93 404.07 471.73 5,969,347.39 562,363.32 1.41 361.42 MWD+IFR-AK-CAZ-SC(2) 2,307.29 33.34 63.08 2,164.87 2,066.94 429.82 517.40 5,969,373.51 562,408.77 2.95 383.09 MWD+IFR-AK-CAZ-SC(2) 2,401.85 32.45 63.75 2,244.26 2,146.33 452.81 563.32 5,969,396.88 562,454.49 1.02 401.99 MWD+IFR-AK-CAZ-SC(2) 2,495.30 32.49 64.72 2,323.11 2,225.18 474.62 608.50 5,969,419.05 562,499.49 0.56 419.77 MWD+IFR-AK-CAZ-SC(2) 2,590.75 32.26 62.51 2,403.72 2,305.79 497.32 654.28 5,969,442.13 562,545.08 1.26 438.41 MWD+IFR-AK-CAZ-SC(2) 2,685.96 31.97 61.26 2,484.36 2,386.43 521.17 698.92 5,969,466.35 562,589.52 0.76 458.27 MWD+IFR-AK-CAZ-SC(2) 2,757.10 31.99 61.52 2,544.71 2,446.78 539.21 732.00 5,969,484.66 562,622.44 0.20 473.36 MWD+IFR-AK-CAZ-SC(2) 2,820.54 31.83 60.50 2,598.56 2,500.63 555.46 761.33 5,969,501.15 562,651.63 0.89 487.00 MWD+IFR-AK-CAZ-SC(3) 2,831.50 31.88 60.48 2,607.87 2,509.94 558.31 766.37 5,969,504.04 562,656.64 0.48 489.40 NOT an Actual Survey Sc(3) 13 3/8"x16" 2,893.36 32.17 60.37 2,660.31 2,562.38 574.50 794.90 5,969,520.47 562,685.04 0.48 503.04 MWD+IFR-AK-CAZ-SC(3) 2,948.09 32.66 60.33 2,706.52 2,608.59 589.02 820.39 5,969,535.19 562,710.41 0.90 515.27 MWD+IFR-AK-CAZ-SC(3) 3,046.11 32.81 59.13 2,788.97 2,691.04 615.74 866.17 5,969,562.28 562,755.96 0.68 537.90 MWD+IFR-AK-CAZ-SC(3) 3,141.09 33.84 54.73 2,868.34 2,770.41 644.21 909.86 5,969,591.12 562,799.40 2.77 562.46 MWD+IFR-AK-CAZ-SC(3) 3,187.35 35.10 51.56 2,906.48 2,808.55 659.92 930.79 5,969,606.99 562,820.21 4.74 576.29 MWD+IFR-AK-CAZ-SC(3) 3,236.01 35.65 50.13 2,946.16 2,848.23 677.71 952.63 5,969,624.96 562,841.90 2.04 592.10 MWD+IFR-AK-CAZ-SC(3) 3,330.86 37.30 46.93 3,022.44 2,924.51 715.06 994.85 5,969,662.65 562,883.80 2.65 625.63 MWD+IFR-AK-CAZ-SC(3) 3,386.02 38.10 44.07 3,066.08 2,968.15 738.70 1,018.90 5,969,686.49 562,907.65 3.49 647.09 MWD+IFR-AK-CAZ-SC(3) 3,443.56 39.24 41.41 3,111.01 3,013.08 765.11 1,043.28 5,969,713.10 562,931.82 3.50 671.27 MWD+IFR-AK-CAZ-SC(3) 3,509.10 42.91 39.41 3,160.41 3,062.48 797.91 1,071.17 5,969,746.12 562,959.43 5.95 701.51 MWD+IFR-AK-CAZ-SC(3) 3,542.88 43.63 38.30 3,185.01 3,087.08 815.94 1,085.69 5,969,764.27 562,973.80 3.10 718.21 MWD+IFR-AK-CAZ-SC(3) 3,604.10 47.53 35.84 3,227.85 3,129.92 850.84 1,112.02 5,969,799.38 562,999.84 6.99 750.68 MWD+IFR-AK-CAZ-SC(3) 3,641.07 48.75 35.49 3,252.52 3,154.59 873.21 1,128.07 5,969,821.88 563,015.70 3.37 771.56 MWD+IFR-AK-CAZ-SC(3) 3,700.29 49.97 34.30 3,291.09 3,193.16 910.06 1,153.77 5,969,858.94 563,041.10 2.56 806.04 MWD+IFR-AK-CAZ-SC(3) 3,794.87 51.12 30.30 3,351.21 3,253.28 971.78 1,192.76 5,969,920.97 563,079.57 3.48 864.12 MWD+IFR-AK-CAZ-SC(3) 3,889.87 52.46 25.64 3,409.99 3,312.06 1,037.68 1,227.73 5,969,987.16 563,113.99 4.10 926.73 MWD+IFR-AK-CAZ-SC(3) 11/25/2015 9:23:08AM Page 3 COMPASS 5000.1 Build 74 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-153 Project: Kuparuk River Unit TVD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 2E Site: Kuparuk 1C Pad MD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 2E Well: 1C-153 North Reference: True Wellbore: 1C-153 Survey Calculation Method: Minimum Curvature Design: 1C-153 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,981.06 54.23 19.75 3,464.46 3,366.53 1,105.14 1,255.89 5,970,054.84 563,141.60 5.53 991.48 MWD+IFR-AK-CAZ-SC(3) 4,078.20 57.07 14.71 3,519.29 3,421.36 1,181.71 1,279.58 5,970,131.59 563,164.64 5.18 1,065.69 MWD+IFR-AK-CAZ-SC(3) 4,170.37 61.07 10.75 3,566.66 3,468.73 1,258.80 1,296.93 5,970,208.82 563,181.36 5.69 1,140.98 MW D+I FR-AK-CAZ-SC(3) 4,267.86 63.45 8.92 3,612.04 3,514.11 1,343.81 1,311.66 5,970,293.94 563,195.38 2.95 1,224.38 MW D+I FR-AK-CAZ-SC(3) 4,361.58 62.29 9.19 3,654.78 3,556.85 1,426.18 1,324.78 5,970,376.40 563,207.83 1.26 1,305.29 MWD+IFR-AK-CAZ-SC(3) 4,402.92 61.92 9.21 3,674.12 3,576.19 1,462.25 1,330.62 5,970,412.51 563,213.37 0.90 1,340.71 MW D+I FR-AK-CAZ-SC(3) 4,454.73 62.93 8.84 3,698.10 3,600.17 1,507.60 1,337.83 5,970,457.92 563,220.20 2.05 1,385.26 MW D+I FR-AK-CAZ-SC(3) 4,551.99 66.57 2.84 3,739.62 3,641.69 1,595.05 1,346.70 5,970,545.43 563,228.35 6.72 1,471.61 MW D+I FR-AK-CAZ-SC(3) 4,645.86 72.01 357.95 3,772.82 3,674.89 1,682.79 1,347.24 5,970,633.16 563,228.17 7.57 1,558.96 MW D+I FR-AK-CAZ-SC(3) 4,741.03 76.87 352.02 3,798.36 3,700.43 1,774.04 1,339.18 5,970,724.33 563,219.35 7.88 1,650.57 MW D+I FR-AK-CAZ-SC(3) 4,836.26 79.05 343.93 3,818.25 3,720.32 1,865.04 1,319.76 5,970,815.16 563,199.19 8.62 1,742.91 MW D+I FR-AK-CAZ-SC(3) 4,931.07 81.45 338.02 3,834.32 3,736.39 1,953.32 1,289.30 5,970,903.18 563,168.01 6.64 1,833.52 MWD+IFR-AK-CAZ-SC(3) 5,022.40 83.75 331.99 3,846.10 3,748.17 2,035.36 1,251.05 5,970,984.89 563,129.08 7.01 1,918.58 MW D+I FR-AK-CAZ-SC(3) 5,058.28 84.48 330.24 3,849.77 3,751.84 2,066.61 1,233.81 5,971,015.99 563,111.58 5.26 1,951.21 MWD+IFR-AK-CAZ-SC(3) 5,129.00 84.92 325.97 3,856.31 3,758.38 2,126.38 1,196.61 5,971,075.45 563,073.89 6.05 2.013.99 NOT an Actual Survey SC(4) 9 5/8"x12-1/4" 5,144.73 85.02 325.02 3,857.69 3,759.76 2,139.29 1,187.73 5,971,088.29 563,064.91 6.05 2,027.63 MWD+I F R-AK-CAZ-SC(4) 5,239.65 88.01 325.36 3,863.46 3,765.53 2,217.07 1,133.65 5,971,165.61 563,010.20 3.17 2,109.83 MW D+I FR-AK-CAZ-SC(4) 5,333.11 92.15 326.51 3,863.33 3,765.40 2,294.47 1,081.31 5,971,242.58 562,957.23 4.60 2,191.50 MWD+IFR-AK-CAZ-SC(4) 5,428.51 90.24 328.16 3,861.34 3,763.41 2,374.76 1,029.84 5,971,322.43 562,905.10 2.65 2,275.97 MWD+IFR-AK-CAZ-SC(4) 5,524.45 89.27 329.95 3,861.75 3,763.82 2,457.04 980.51 5,971,404.29 562,855.10 2.12 2,362.23 MWD+IFR-AK-CAZ-SC(4) 5,618.40 89.90 332.71 3,862.43 3,764.50 2,539.46 935.44 5,971,486.33 562,809.35 3.01 2,448.27 MWD+IFR-AK-CAZ-SC(4) 5,714.04 90.59 336.03 3,862.02 3,764.09 2,625.68 894.08 5,971,572.19 562,767.28 3.55 2,537.76 MWD+IFR-AK-CAZ-SC(4) 5,808.99 89.88 342.88 3,861.63 3,763.70 2,714.53 860.78 5,971,660.76 562,733.25 7.25 2,629.18 MW D+I FR-AK-CAZ-SC(4) 5,903.82 91.66 346.84 3,860.36 3,762.43 2,806.04 836.02 5,971,752.05 562,707.74 4.58 2,722.50 MWD+IFR-AK-CAZ-SC(4) 5,998.72 92.46 345.77 3,856.95 3,759.02 2,898.18 813.56 5,971,844.00 562,684.53 1.41 2,816.25 MWD+IFR-AK-CAZ-SC(4) 6,092.39 90.17 343.55 3,854.80 3,756.87 2,988.48 788.79 5,971,934.08 562,659.02 3.40 2,908.36 MWD+IFR-AK-CAZ-SC(4) 6,187.90 88.62 339.10 3,855.80 3,757.87 3,078.93 758.22 5,972,024.27 562,627.71 4.93 3,001.13 MWD+IFR-AK-CAZ-SC(4) 6,281.90 89.52 340.37 3,857.33 3,759.40 3,167.10 725.67 5,972,112.15 562,594.43 1.66 3,091.80 MWD+IFR-AK-CAZ-SC(4) 6,376.69 90.07 344.79 3,857.67 3,759.74 3,257.52 697.30 5,972,202.33 562,565.32 4.70 3,184.35 MWD+IFR-AK-CAZ-SC(4) 6,472.54 89.66 348.18 3,857.90 3,759.97 3,350.70 674.90 5,972,295.31 562,542.16 3.56 3,279.13 MWD+IFR-AK-CAZ-SC(4) 6,567.58 89.39 350.97 3,858.68 3,760.75 3,444.16 657.71 5,972,388.62 562,524.19 2.95 3,373.73 MWD+IFR-AK-CAZ-SC(4) 6,662.18 89.66 354.05 3,859.47 3,761.54 3,537.94 645.38 5,972,482.28 562,511.09 3.27 3,468.23 MWD+IFR-AK-CAZ-SC(4) 6,756.48 90.84 354.88 3,859.06 3,761.13 3,631.79 636.28 5,972,576.05 562,501.22 1.53 3,562.52 MWD+IFR-AK-CAZ-SC(4) 6,851.28 90.52 354.66 3,857.93 3,760.00 3,726.19 627.64 5,972,670.37 562,491.81 0.41 3,657.31 MWD+IFR-AK-CAZ-SC(4) 6,946.41 90.11 353.64 3,857.41 3,759.48 3,820.82 617.94 5,972,764.90 562,481.33 1.16 3,752.43 MWD+IFR-AK-CAZ-SC(4) 7,041.26 89.42 351.24 3,857.80 3,759.87 3,914.84 605.47 5,972,858.81 562,468.08 2.63 3,847.17 MWD+IFR-AK-CAZ-SC(4) 7,135.76 89.21 346.98 3,858.93 3,761.00 4,007.61 587.62 5,972,951.42 562,449.47 4.51 3,941.15 MWD+IFR-AK-CAZ-SC(4) 7,230.47 90.14 345.54 3,859.46 3,761.53 4,099.61 565.12 5,973,043.22 562,426.22 1.81 4,034.75 MW D+I FR-AK-CAZ-SC(4) 7,325.22 90.11 344.25 3,859.26 3,761.33 4,191.08 540.43 5,973,134.47 562,400.78 1.36 4,128.03 MWD+IFR-AK-CAZ-SC(4) 11/25/2015 9:23:08AM Page 4 COMPASS 5000.1 Build 74 Schlurnberger S Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-153 Project: Kuparuk River Unit TVD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 2E Site: Kuparuk 1C Pad MD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 26 Well: 1C-153 North Reference: True Wellbore: 1C-153 Survey Calculation Method: Minimum Curvature Design: 1C-153 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,420.21 90.21 342.50 3,858.99 3,761.06 4,282.10 513.26 5,973,225.25 562,372.85 1.85 4,221.07 MWD+IFR-AK-CAZ-SC(4) 7,515.35 90.62 341.03 3,858.30 3,760.37 4,372.45 483.49 5,973,315.35 562,342.34 1.60 4,313.68 MWD+IFR-AK-CAZ-SC(4) 7,610.49 90.65 339.08 3,857.25 3,759.32 4,461.88 451.04 5,973,404.50 562,309.16 2.05 4,405.59 MWD+IFR-AK-CAZ-SC(4) 7,705.65 90.63 340.47 3,856.19 3,758.26 4,551.16 418.14 5,973,493.50 562,275.53 1.46 4,497.40 MWD+IFR-AK-CAZ-SC(4) 7,799.87 88.86 340.48 3,856.61 3,758.68 4,639.96 386.66 5,973,582.03 562,243.32 1.88 4,588.60 MWD+IFR-AK-CAZ-SC(4) 7,895.46 88.97 342.85 3,858.42 3,760.49 4,730.67 356.59 5,973,672.48 562,212.51 2.48 4,681.59 MWD+IFR-AK-CAZ-SC(4) 7,990.09 90.34 346.41 3,858.99 3,761.06 4,821.90 331.52 5,973,763.49 562,186.68 4.03 4,774.66 MWD+IFR-AK-CAZ-SC(4) 8,083.85 88.70 345.07 3,859.77 3,761.84 4,912.76 308.42 5,973,854.15 562,162.84 2.26 4,867.19 MWD+IFR-AK-CAZ-SC(4) 8,178.89 87.98 343.61 3,862.52 3,764.59 5,004.23 282.78 5,973,945.40 562,136.45 1.71 4,960.55 MWD+IFR-AK-CAZ-SC(4) 8,274.84 87.92 343.75 3,865.96 3,768.03 5,096.26 255.84 5,974,037.19 562,108.75 0.16 5,054.57 MWD+IFR-AK-CAZ-SC(4) 8,368.01 90.58 345.20 3,867.18 3,769.25 5,186.01 230.90 5,974,126.72 562,083.08 3.25 5,146.15 MWD+IFR-AK-CAZ-SC(4) 8,464.13 89.10 348.08 3,867.45 3,769.52 5,279.52 208.70 5,974,220.03 562,060.11 3.37 5,241.24 MWD+IFR-AK-CAZ-SC(4) 8,559.54 93.46 347.57 3,865.31 3,767.38 5,372.74 188.59 5,974,313.07 562,039.23 4.60 5,335.85 MWD+IFR-AK-CAZ-SC(4) 8,652.91 94.29 347.13 3,859.00 3,761.07 5,463.63 168.19 5,974,403.79 562,018.08 1.01 5,428.18 MWD+IFR-AK-CAZ-SC(4) 8,747.56 95.47 348.16 3,850.95 3,753.02 5,555.75 148.01 5,974,495.73 561,997.14 1.65 5,521.71 MWD+IFR-AK-CAZ-SC(4) 8,841.43 91.62 348.90 3,845.15 3,747.22 5,647.55 129.38 5,974,587.37 561,977.76 4.18 5,614.78 MWD+IFR-AK-CAZ-SC(4) 8,937.27 92.10 347.63 3,842.04 3,744.11 5,741.34 109.90 5,974,680.98 561,957.51 1.42 5,709.91 MWD+IFR-AK-CAZ-SC(4) 9,032.10 92.88 346.21 3,837.92 3,739.99 5,833.62 88.46 5,974,773.07 561,935.31 1.71 5,803.71 MWD+IFR-AK-CAZ-SC(4) 9,127.20 92.54 345.74 3,833.42 3,735.49 5,925.78 65.44 5,974,865.03 561,911.53 0.61 5,897.52 MWD+IFR-AK-CAZ-SC(4) 9,221.18 91.22 344.30 3,830.34 3,732.41 6,016.51 41.16 5,974,955.55 561,886.51 2.08 5,990.03 MWD+IFR-AK-CAZ-SC(4) 9,315.93 87.84 342.82 3,831.12 3,733.19 6,107.37 14.35 5,975,046.17 561,858.96 3.89 6,082.88 MWD+IFR-AK-CAZ-SC(4) 9,412.01 89.19 340.64 3,833.61 3,735.68 6,198.57 -15.76 5,975,137.11 561,828.10 2.67 6,176.35 MWD+IFR-AK-CAZ-SC(4) 9,506.03 88.56 341.15 3,835.45 3,737.52 6,287.39 -46.53 5,975,225.67 561,796.60 0.86 6,267.52 MWD+IFR-AK-CAZ-SC(4) 9,601.06 89.16 345.77 3,837.34 3,739.41 6,378.44 -73.57 5,975,316.49 561,768.82 4.90 6,360.58 MWD+IFR-AK-CAZ-SC(4) 9,696.48 88.39 346.56 3,839.38 3,741.45 6,471.07 -96.38 5,975,408.92 561,745.24 1.16 6,454.85 MWD+IFR-AK-CAZ-SC(4) 9,791.85 88.87 346.79 3,841.66 3,743.73 6,563.85 -118.35 5,975,501.50 561,722.51 0.56 6,549.19 MWD+IFR-AK-CAZ-SC(4) 9,886.75 89.69 346.60 3,842.86 3,744.93 6,656.19 -140.19 5,975,593.65 561,699.91 0.89 6,643.08 MWD+IFR-AK-CAZ-SC(4) 9,982.07 90.14 346.20 3,843.00 3,745.07 6,748.84 -162.60 5,975,686.10 561,676.73 0.63 6,737.33 MWD+IFR-AK-CAZ-SC(4) 10,076.85 90.11 345.72 3,842.79 3,744.86 6,840.79 -185.60 5,975,777.85 561,652.99 0.51 6,830.93 MWD+IFR-AK-CAZ-SC(4) 10,169.44 90.17 346.19 3,842.56 3,744.63 6,930.61 -208.07 5,975,867.47 561,629.78 0.51 6,922.37 MWD+IFR-AK-CAZ-SC(4) 10,266.20 89.63 346.51 3,842.73 3,744.80 7,024.64 -230.90 5,975,961.30 561,606.17 0.65 7,018.03 MWD+IFR-AK-CAZ-SC(4) 10,360.67 89.63 346.62 3,843.34 3,745.41 7,116.52 -252.85 5,976,052.99 561,583.47 0.12 7,111.48 MWD+IFR-AK-CAZ-SC(4) 10,455.44 89.52 345.19 3,844.05 3,746.12 7,208.43 -275.93 5,976,144.70 561,559.63 1.51 7,205.05 MWD+IFR-AK-CAZ-SC(4) 10,550.21 90.17 345.05 3,844.30 3,746.37 7,300.02 -300.26 5,976,236.08 561,534.55 0.70 7,298.41 MWD+IFR-AK-CAZ-SC(4) 10,645.32 90.14 346.42 3,844.05 3,746.12 7,392.20 -323.70 5,976,328.05 561,510.35 1.44 7,392.28 MWD+IFR-AK-CAZ-SC(4) 10,739.04 90.45 347.38 3,843.56 3,745.63 7,483.48 -344.94 5,976,419.14 561,488.36 1.08 7,485.06 MWD+IFR-AK-CAZ-SC(4) 10,834.14 89.97 347.13 3,843.21 3,745.28 7,576.23 -365.92 5,976,511.71 561,466.62 0.57 7,579.29 MWD+IFR-AK-CAZ-SC(4) 10,929.00 89.90 345.42 3,843.32 3,745.39 7,668.38 -388.43 5,976,603.66 561,443.36 1.80 7,673.05 MWD+IFR-AK-CAZ-SC(4) 11,022.67 88.56 345.13 3,844.58 3,746.65 7,758.96 -412.23 5,976,694.04 561,418.81 1.46 7,765.37 MWD+IFR-AK-CAZ-SC(4) 11,116.20 88.42 344.07 3,847.05 3,749.12 7,849.10 -437.06 5,976,783.96 561,393.24 1.14 7,857.33 MWD+IFR-AK-CAZ-SC(4) 11/25/2015 9:23:08AM Page 5 COMPASS 5000.1 Build 74 S . Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-153 Project: Kuparuk River Unit TVD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 2E. Site: Kuparuk 1C Pad MD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 2E. Well: 1C-153 North Reference: True Wellbore: 1C-153 Survey Calculation Method: Minimum Curvature Design: 1C-153 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,212.68 88.56 344.09 3,849.59 3,751.66 7,941.85 -463.52 5,976,876.48 561,366.02 0.15 7,952.03 MWD+IFR-AK-CAZ-SC(4) 11,308.96 89.11 345.30 3,851.55 3,753.62 8,034.69 -488.92 5,976,969.10 561,339.85 1.38 8,046.73 MWD+IFR-AK-CAZ-SC(4) 11,405.01 89.11 346.44 3,853.04 3,755.11 8,127.82 -512.37 5,977,062.02 561,315.64 1.19 8,141.55 MWD+IFR-AK-CAZ-SC(4) 11,499.59 88.60 347.09 3,854.93 3,757.00 8,219.87 -534.02 5,977,153.88 561,293.24 0.87 8,235.14 MWD+IFR-AK-CAZ-SC(4) 11,593.95 88.63 348.35 3,857.21 3,759.28 8,312.05 -554.08 5,977,245.88 561,272.41 1.34 8,328.71 MWD+IFR-AK-CAZ-SC(4) 11,688.27 88.49 350.55 3,859.58 3,761.65 8,404.74 -571.34 5,977,338.41 561,254.39 2.34 8,422.55 MWD+IFR-AK-CAZ-SC(4) 11,784.14 88.67 350.86 3,861.95 3,764.02 8,499.32 -586.82 5,977,432.86 561,238.13 0.37 8,518.12 MWD+IFR-AK-CAZ-SC(4) 11,879.23 88.67 349.00 3,864.16 3,766.23 8,592.91 -603.44 5,977,526.30 561,220.74 1.96 8,612.81 MWD+IFR-AK-CAZ-SC(4) 11,974.12 88.25 347.45 3,866.71 3,768.78 8,685.77 -622.80 5,977,618.99 561,200.62 1.69 8,707.00 MWD+IFR-AK-CAZ-SC(4) 12,066.15 88.18 346.69 3,869.58 3,771.65 8,775.42 -643.38 5,977,708.46 561,179.30 0.83 8,798.10 MWD+IFR-AK-CAZ-SC(4) 12,162.98 87.67 344.69 3,873.09 3,775.16 8,869.18 -667.30 5,977,802.01 561,154.61 2.13 8,893.59 MWD+IFR-AK-CAZ-SC(4) 12,258.54 87.74 343.48 3,876.91 3,778.98 8,961.00 -693.48 5,977,893.60 561,127.68 1.27 8,987.34 MWD+IFR-AK-CAZ-SC(4) 12,352.55 87.91 341.49 3,880.48 3,782.55 9,050.59 -721.75 5,977,982.94 561,098.67 2.12 9,079.05 MWD+IFR-AK-CAZ-SC(4) 12,446.98 87.53 341.48 3,884.24 3,786.31 9,140.06 -751.72 5,978,072.15 561,067.98 0.40 9,170.79 MWD+IFR-AK-CAZ-SC(4) 12,541.17 86.98 342.48 3,888.75 3,790.82 9,229.52 -780.82 5,978,161.37 561,038.14 1.21 9,262.45 MWD+IFR-AK-CAZ-SC(4) 12,636.79 87.11 345.10 3,893.68 3,795.75 9,321.21 -807.47 5,978,252.82 561,010.73 2.74 9,356.12 MWD+IFR-AK-CAZ-SC(4) 12,731.38 89.20 348.05 3,896.72 3,798.79 9,413.15 -829.42 5,978,344.57 560,988.03 3.82 9,449.62 MWD+IFR-AK-CAZ-SC(4) 12,761.91 88.87 350.48 3,897.24 3,799.31 9,443.14 -835.10 5,978,374.51 560,982.10 8.03 9,479.99 MWD+IFR-AK-CAZ-SC(4) 12,807.00 88.87 350.48 3,898.13 3,800.20 9,487.60 -842.56 5,978,418.90 560,974.28 0.00 9,524.93 NoT an Actual yey 4-1/2"x6-3/4" 12,825.00 88.87 350.48 3,898.48 3,800.55 9,505.35 -845.54 5,978,436.63 560,971.15 0.00 9,542.87 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. Yes ❑ No 1 have checked to the best of my ability that the following data is correct: I Surface Coordinates 0 Declination & Convergence GRS Survey Corrections Abdou Digitally signed Abair cn-AbOcci ID Survey Tool Codes o-schkrmoerger,ou. A b a ka r email-AbOouAbakar,acprcrxtar co nocogtllllps.[om,aUS SLB DE: Date-2015.1o.uu:3338-oaoa david.l.lee@conocophillips.com grp15pvooam onaop P''`°" Client Representative: Date: 10/13/15 11/25/2015 9:23:08AM Page 6 COMPASS 5000.1 Build 74 RECEIViiu iI •• NOV 2 0 ZOi5 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ' . la.Well Status: Oil RI Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b.Well Class: 20AAC 25.105 2oAAc 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ❑ WAG❑ WDSPL❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: • 10/18/2015 •215-116 3.Address: 7. Date Spudded: 15.API Number P.O. Box 100360 Anchorage,AK 99510-0360 '9/16/2015 "50-029-23549-00-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 1296'FNL 4390' FEL,Sec. 12Twn 11N Rng 10E, UM 410/2/2015 'KRU 1C-153 Top of Productive Interval: 9. Ref Elevations: KB:Q$0%4 17. Field/Pool(s): 4552 FNL, 3131 FEL, Sec. 1,Twn 11N, Rng 10E, UM GL: 57 BF:fle Kuparuk River Field/West Sak Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: ;vj 2335'FNL, 5230 FEL, Sec. 36,Twn 12N, Rng 10E, UM n/a ii6L 45 25649 and 25638 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 561,894.51 y- 5,968,939.60 Zone-4 12825'/3898' ALK 467 and 463 TPI: x- 563135 y- 5970974 Zone-4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 560970 y- 5978452 Zone-4 no SSSV 1870/1793 5. Directional or Inclination Survey: Yes 0 (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 n/a (ft MSL) n/a 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 Surface: GR/Res Intermediate: GR/Res Production: Periscope 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED • 20 94 H-40 42 120 42 120 42 200 cf of Arctic Crete 13 3/8 68 L-80 42 2831 42 2607 16 1396 sx lead,246 sx tail Deep CF 9 5/8 40 L-80 39 5129 39 3856 '12.25 729 sx Class"G" 4 1/2 11.6 L-80 4944 12807 3836 3896 6.75 Stand alone screen no cement 24. Open to production or injection? Yes ❑ No 2 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 4,5 4969 4944/3836 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No 0 Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation Flowing,gas lift,etc.): W uGt ✓, '(S/ 1-7,1C.A f.,,r iti,A-1 /,/_j„.,.) /tA° Date of Test: Hours Tested: Production for Oil-Bbl: Li Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period -0. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour/Rate � Form 10-407 Revised 11/2015 V T L 4/z R` CONTINUED ON PAGE 2 RBDM99Submit ORIGINIAL only DEC 0 1 2015 (1i�/� f) 511,1«- tt • 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No RI 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 0 Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1870 1793 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 5009 3844 information, including reports,per 20 AAC 25.071. Top WSAK A s 3,644.00 Top WSAK B 4403 3674 Top WSAK C 4550 3738 Top WSAK D 5009 3844 TD 12825 189F Formation at total depth: WSAK D 31. List of Attachments: Summary of Daily Operations, Directional Survey, Schematic Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey, core analysis, paleontological report. production or well test results. ger 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Lee 263-3741 Email: 'JAL @ David.l.Lee a(�,conocophillips Printed Name: Chip Alvord Title: Alaska Drilling Manager Signature: ! Phone: 265-6120 Date: r ' /Z 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 la: 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 1 b: 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 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 11/2015 Submit ORIGINAL Only o KUP PROD • 1C-153 • ConocoPhillips -' BA--di Well Attributes Max Angle 8 MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status nal(°) MD(ftKB) Act Bern(ftKB) r zurnnvfi'nc 500292354900 WEST SAK PROD 95,47 8,747.56 12,825.0 ••• Comment 1125(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-153,11/12/2015 2:2618 PM SSSV NIPPLE Last WO: 40.33 10/18/2015 Unread schemabc(flclual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER:34.1-_g LastTag: Rev Reason:NEW WELL,GLV C/O lehallf 11/12/2015 zo oee gng.45.6 Casg Strings Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade lop Thread Conductor 20 19.124 41.7 120.0 120.0 94.00 B Welded Ili i Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) SetDepth(TVD).W Len(I...Grade Top Thread 13-3/8"Surface 1C-153 13 3/8 12.415 41.6 2,831.5 2,607.9 68.00 L-80 HYD 563 C ndue oP4'.. 7200 Ca91ng Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen p...Grade Top Thread xo Reducing;159 1 9-5/8"Intermediate 9 5/8 8.835 38.7 5,129.0 3,856.3 40.00 L-80 Hyd 563 Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread 4111 Liner 41/2 4.000 4.944.1 12,807.0 3,898.1 11.60 L-80 Hyd 563 MI NIPPLE;476.7 Liner Details "- Nominal ID Top(ftKB) Top(TVD)(f1KB) Top Inel i�Item Dea Com (In) GAS LIFT;2,721.9 4,944.1 3,836.2 1.78 PACKER BAR HRD-E ZXP W/HD's 7.375 4,963.1 3,838.9 82.26 NIPPLEs1AKFR_ NIPPLE 4.870 4,965.9 3,839.3 82.33 HANGER BAKER FLEX LOCK-HANGER • 6.226 11 133/6•Surface 1C-153;41.6- L 4,975.7 3,840.5 82.57 X0 REDUCING X07"26#Hydri1563 box X 51/2"15.59 Hydril 563 4.870 2,631.5 Mie pin GAS LIFT;4.191.6 4,977.2 3,840.7 82.61 SBE BAKER SEAL BORE EXTENSION 4.750 Sow4,998.2 3.843-3 83.14 VALVE BAKER FLUID LOSS CONTROL VALVE,sheared 4.563 GAUGE:4,248.] __ 11/25/2015 a. 5,004.9 3,844.1 83.31 XO REDUCING XO,7"29#Hyd 563 box x 5-1/2"15.5#Hyd 563 pin 4.880 iliIE XO Threads;4,284.1 Tubing;A2937 5,083.8 3,852.2 84.64 XO REDUCING XO 5-1/2"15.58 Hyd 563 box x 4-1/2"12.69 Hyd 563 4.000 Tubing;4,316.2 It pin xO Enlarging;4,323.6- - ESPPumps;4,326.6, 5,250.8 3.863.8 88.50 SWELL BAKER SWELL PACKER(WATER ACTIVATED) 3.958 ESP Intake;4,362.8i.). -.4- PACKERal 5,311.4 3.864.0 91.1911-RACER TRACERCO TRACER CARTRIDGE SERI/01 3.958 PACKOFF;4,404.71111 5,340.6 3.863.1 92.00 SCREEN BAKER EXCLUDER 2000 SCREEN(114-146) 4.000 PACKOFF;4,425.1 tl£ 6,824.2 3,858.2 90.61 SWELL BAKER SWELL PACKER(WATER ACTIVATED)"F" 3.958 II PACKER SLIDING SLEEVE;4,465.5 aM:1 6,884.9 3,857.7 90.38 TRACER TRACERCO TRACER CARTRIDGE,ser#03 3.958 6,914.6 3,857.5 90.25 SCREEN BAKER EXCLUDER 2000 SCREEN(81-113) 4.000 If NIPPLE;4,519.4 • 8,394.5 3,867.0 90.17 SWELL BAKER SWELL PACKER(WATER ACTIVATED)"E" 3.958 so PACKER I 8,730.0 3,852.6 95.25 SWELL BAKER SWELL PACKER(WATER ACTIVATED)"D" 1958 ME PACKER LOCATER;4,950.D mom SEAL ASSEMBLY,4950.5 4 8,790.5 3,847.5 93.71 TRACER TRACERCO TRACER CARTRIDGE SER#05 3.958 8,820.2 3,845.9 92.49 SCREEN BAKER EXCLUDER 2000 SCREEN(48-80) 4.000 • "° 10,299.1 3,842.9 89.63-SWELL BAKER SWELL PACKER(WATER ACTIVATED)"C" 3.958 PACKER z, 10,359.8 3,843.3 89.63 TRACER TRACERCO TRACER CARTRIDGE SER#07 1958 10,389.4 3,843.5 89.60 SCREEN BAKER EXCLUDER 2000 SCREEN(16-47) 4000 11,819.4 3.862.8 88.67 SWELL BAKER SWELL PACKER(WATER ACTIVATED)"6" 3.958 PACKER 9-5/8"Intermediate.36.7- 11,995.5 3.867.4 88.23 SWELL BAKER SWELL PACKER(WATER ACTIVATED)"A" 3.958 5.129.0 4. PACKER 12,056.2 3,869.3 88.19 TRACER TRACERCO TRACER CARTRIDGE SER#09 3.958 12,085,8 3,870.2 88.08 SCREEN BAKER EXCLUDER 2000 SCREEN (1-15) 4.000 12,783.7 3.897.7 88.87 PACKOFF BAKER PACK-OFF BUSHING 2.370 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Sat Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 511204 41/2 3.958 34.1 4,969.5 3,839.7 12.60 L-80 IBT-M 1/2-@159.11 Ail Completion Details 0 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°I item Des Corn (in) 34.1 34.1 0.09 HANGER Vetco Gray MB22 4-1/2"Tubing hanger 3.958 45.0 45.0 0.11 XO Enlarging Crossover 4-1/2',12.6 ppf,L80 IBT-m box x5-1/2',15.5 3.930 ppf,L-80,IBT pin 159.1 159.1 0.40 XO Reducing Crossover 5-1/2',15.5 ppf,L-80,IBT box x 4-1/2",126 3.930 ppf,L-80,IBT pin 476.7 476.3 6.24 NIPPLE 4-1/2"Camco"DB-6"Nipple w/3.875"No-go Profile 3.958 0 4,248.7 3,603.4 62.98 GAUGE Baker Guage Carder,Dual Guardian,Ported(w/ 3.958 SurSENS guages) 4,323.6 3,637.3 62,76 XO Enlarging Crossover,4-1/2',12,6 ppf,L-80,Vam Top Boxx 5-1/7 3.900 19ppf,Vam FJL box 4,326.6 3,638.6 62.72 ESP Pumps Motor Shroud#6,5-1/2"23ppf,L-80,Vam FJL.P z P 4.670 4,362.8 3,655.3 62.28 ESP Intake Annular Connection Port(ACP),5-112',19ppf,Vam FJL 3.960 Box 4-1/2",12.6ppf.Vam Top Box I 4,404.7 3,674.9 61.95 PACKOFF B Profile Assembly,4-1/2",12.6 ppf,L-80,IBT-m,box x 3.960 iii box 4,425.1 3,684.5 62.35 PACKOFF No-Go Profile,3.80"4-1/2",12.6 ppf,L-80,IBT-m box x 3.800 pin ilif 4,465.8 3,703.1 63.34 SLIDING Baker 4-1/2"CMU w/3.812"BX Profile(Run Open),4- 3.812 SLEEVE 1/2',12.6 ppf,L-80,Vam Top box xpin I 4,519.4 3,726.4 65.35 NIPPLE 4-1/2"Camco 3.75"DB Landing Nipple w/3.75"Profile 3.750 (Includes collar) 4,950.0 3,837.1 81.93 LOCATER Baker No go Locator,above located,4-1/7,12.6 ppf L- 3.870 80.IBT-m box top t 4,950.5 3,837.1 81.94 SEAL Baker"PBR"Seal assembly 3.880 ASSEMBLY v. II an 1" Liner;4,944.1-12,807.0 KUP PROD • 1C-153 ConocoPhillips f. 1-arade'Pt9Mp6 --• 1C-153,11/12/2015 2.20 22 PM Vertical schematic(actual). HANGER;34.1 �..t ,eodemaum4.1: bu:.. 60....1.11.10-1 ao ao.,rfMandrellnserts St atl XO Enlarging;45 0 on Top(TVD) Valve Latah Port 51x9 TRO Run N Top(ftKB) (4149) Make Model OD(In) Sera Type Type (In) (pet) Run Date Corn -M-AA./`A^^^A^^A/, j,. 1 2,721.9 2,514.8 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/12/2015 Conductor;41.7-120.0 XO Reducing;159.1 _ • 2 4,191.6 3,576.8 CAMCO KBMG 1 GAS LIFT SOV BK 0.000 OA 10/25/2015 20004 NIPPLE;476.7 - Notes:General 8 Safety End Date Annotation NOTE GAS LIFT;2721.911.1 N 13-34-Surface 1C-153,41.6- j 2,831.5 GAS LIFT:4,191 6 GAUGE:4.246 XO Threads.4.284.1 Tubing',4,293.7 Tubing',4.316.2 XO Enlarging;4.323.6- ESP Pumps:4,326 6- ESP Intake.4,362.8 44 .4 PACKOFF;4.404.7 [' PACKOFF;1,425.111 �4 SLIDING SLEEVE;4,465.8 NIPPLE.4,519.4 LOCATER;4,950.0 SEAL ASSEMBLY.4.950.5 a s 9-58'Intermediate. 5.129.0 • 1l II Liner;4,944.1-12,807.0 Al ` • Daily Operations Summary 4, 1C-153 Conoccaehillips Rig: DOYON 25 Job: DRILLING ORIGINAL Daily Operations Start Date Last 24hr Sum 9/14/2015 Move rig off of 1C-152,move onto 1C-153 using rig stomper system. Mate up pipe,casing,pit and pump mods. Load casing shed with 87 jts 5" DP. 9/15/2015 Complete rig up and rig acceptance checklist. Load pipeshed with 4"&5"drillpipe.Strap and tally. Rig up surface diverter equipment.Picked up 84'stands 4"drill pipe.Begin picking up 5"Drill Pipe.Prep BHA#1 in pipe shed for pick-up. 9/16/2015 Change Top Drive Saver Sub, Diverter test(Waived by AOGCC Rep Chuck Scheve)Pick Up BHA#1,Circulate&Condition Mud, Drill per D.D. 9/17/2015 Drill to 409'Trip out racking back HWDP,Pick up Drill collars,RIH/Drill from 409'per D.D 9/18/2015 Drilling Surface Hole Section 9/19/2015 TD Surface Hole,Backream 001-I,Lay Down BHA,Rig up&Run Casing. 9/20/2015 Run casing&Cement 9/21/2015 Nipple down surface diverter stack&associated equipment,N/U BOPE&Test same. Pick up BHA,TIH with doubles from pipe shed,Slip&Cut drill line.Circulate&test lower annulus valve&casing 3,500 psi-30 min. Drill out float equipment,Circulate perform LOT to 12.8 EMW. Drill to 3,450'when decision made to pull out to change BHA to motor due to insufficient turn and build. 9/22/2015 Circulate hole clean prior to trip. POOH,change BHA,RIH and drill ahead with 1.5°motor assembly to 3679'. 9/23/2015 Drill 12 1/4"hole to 4478',and BROOH to 3300'to clean hole due to geometry and 95%slides. RIH on elevators and drill ahead to 4760'. 9/24/2015 Drill ahead to 5137'MD,3856'TVD for TD. Circulate BHA clean and BROOH to shoe. Circulate casing clean and POOH on elevators to surface. 9/25/2015 Run 9 5/8"40#L-80 Hyd 563 casing per detail to 5129'. C&C mud,pump cement,bump plug with CIP @ 22:30 hours. RD from casing and cement job. 9/26/2015 Complete RD,install and test pack-off to 5000 psi;Good. Perform pipe management while cleaning pits for OBM. Perform LOT on OA,inject flush and freeze protect with Isotherm. Slip and Cut drill line. PU Clean-out BHA and trip in,circulate and perform casing test to 3500 psi;Good. Drill float equipment and shoe track. 9/27/2015 Drill shoe track,20'of formation and perform FIT to 12.1 EMW. POOH with clean out assembly. PU drilling BHA and RIH. Displace to new Faze- pro mud and drill ahead to 5489'. 9/28/2015 Drill ahead to 7576',diluting 1380 BBLs for the day to maintain solids below 2.5. Control drilling at 175 ft/hr. 9/29/2015 Directional drill 6%"production section from 7576'MD to 9652'MD,3839'TVD.Reduce rate to 125 fph to assist in maintaining Al solids in mud. Losses on Doyon 141 impacting mud deliverability. 9/30/2015 Directional drill 6-3/4"production section from 9652'MD to 11181'MD,3847'TVD.Pump out of hole back to 7579'MD. 10/1/2015 Pump out to shoe.CBU. PU/MU storm packer and set same.Perform BOP test witnessed by AOGCC Lou Grimaldi.Pull storm packer.CBU. RIH to 11181'MD,stage up pumps and begin performing dilution. 10/2/2015 Directional drill 6-3/4"production section from 11811'MD to TD at 12825'MD,3898'TVD. CBU(x4)while waiting on mud and trucks for . displacement. 10/3/2015 Perform 600bbl whole mud dilution on bottom.Backream from 12780'MD to 5017'MD. CBU.Open Well Commander and continue CBU(x3).Slip and cut drill line.Clean pits and test fluids.TIH on elevators from 5017'MD to 5702'MD'MD. 10/4/2015 TIH from shoe to 12825'MD with 6-3/4"production BHA and Scraper assembly.CBU from bit.Open 7"well commander and continue to circulate mud while waiting on EMS-6800. Pump out of hole from 12825'MD to 9068'MD. 10/5/2015 Pump out of hole with SFOBM from 9068'MD to Shoe @ 5129'MD. Lay out Scraper assembly.Super clean all fluid surface equipment. Pump EMS-6800 SFOBM over shakers to passing PST prior to pumping down hole.Establish circulation and begin conditioning casing volume. 10/6/2015 Continue circulating @ 5129'MD 450 gpm via Well Commander over 325 mesh screens attempting to achieve passing EMS-6800 PST without success. 10/7/2015 Discuss options,decide to POOH, L/D BHA and 4"DP. MI building new EMS-6800 for displacement.R/U and start RIH with 5"DP,string magnets. 10/8/2015 RIH with mule shoe,string magnets,Well Commander on 5"DP and 5"HWDP installing supersliders.Perform acid pickle on pipe.Prepare to Displace well to new EMS-6800. 10/9/2015 Displace well to new EMS-6800.Shut down and re-clean surface equipment.Circulate with no pipe movement for passing PST.POOH, L/D magnets and WC.R/U, PJSM, P/U and run 11.6#112.6#L-80 4'W OHSAS. 10/10/2015 Continue RIH with 11.6#L-80 Hydril 563,4W Excluder 2000 screens, 12.6#blanks, tracer cartridges and swell packers per detail. M/U and run 2- 78/8"H511 inner string to 7495'MD.(Pack-off bushing©7780'MD). 10/11/2015 Continue running 2-7/8"inner string to packof bushing,sting in,space out and P/U ZXP/Liner hanger with FLCV and shifting tool.P/U Well Commander and RIH on 5"string.Set liner hanger,displace to 9.2 ppg brine. 10/12/2015 Complete displacement to 9.2 ppg.Clean surface equipment,Open WC and circulate casing clean to 50 NTU,close WC. R/U and pump 320 bbl formic acid job#1,soak 6-8 hrs and evaluate losses.Initial and stabilized static)loss rate of 48 bph. 10/13/2015 Circulate across well with 9.2ppg Filtered Brine while preparing for Acid Jobs. Pump Acid jobs and allow to soak.Open well commander and circulate to displace Formic Acid.Open Annular, 10bbI gain observed.Shut in well to monitor pressures and perform Exhale Test. Bleed off pressure in 10bb1 increment.Shut in and observe pressure. Repeat with 12 bbl increment.Well static(Determined to be Wellbore Breathing).Set ZXP Packer and test same.L/O single and pump Citric pill. Page 1/2 Report Printed: 11/20/2015 • Daily Operations Summary 1C-153 ConocoPhillipshp Rig: DOYON 25 Job: DRILLING ORIGINAL Daily Operations Start Data Last 24hr Sum 10/14/2015 POOH laying down 5"drill pipe and 2-7/8"inner string. Pump Citric pills as per program. S/C Drill Line. Pull Wear Bushing and rig up to pressure test BOPE. 10/15/2015 Perform BOPE test. RU/run in hole with Upper completion. 10/16/2015 Continue to RIH with Upper Completion drifting tubing and performing electrical integrity tests every 1000'. 10/17/2015 Land Tubing Hanger and run in lock down screws. Pressure test seals.Shear SOV.Install Back Pressure Valve(BPV)into tubing hanger.Test BPV.Bleed off pressure and Nipple down BOPE.Perform final electrical integrity and sensor reading checks. NU tree and adapter. RU lubricator and pull BPV.Set two way check valve.Pressure test tree to 5000psi for 15min.Pull two way check valve. RU to pump freeze protect. Pump 140bbls of freeze protect. 10/18/2015 U-tube diesel, IA=150psi,Tbg= 175psi,OA=200psi. Bleed back 6.8bbl, IA=64psi,Tbg=64psi. RU lubricator and set Back Pressure Valve. Rig Release 10-18-2015,03:30 Page 2/2 Report Printed: 11/20/2015 operations Summary (with Timelog�epths) RECEIVED 0 �� DEC 1 $ 2015 N.� ` � 1C-153 AOGCC Coe►ocoYhtlhps AOGCC Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X - - Operation <(ftKB) End Depth(ftKB); 9/14/2015 9/14/2015 1.00 MIRU MOVE RURD P Prep to skid rig floor.Unplug 120.0 120.0 06:00 07:00 complexes.Ensure all lines disconnected under rig floor. 9/14/2015 9/14/2015 1.00 MIRU MOVE RURD P Skid rig floor over and situate for 120.0 120.0 07:00 08:00 laying derrick over. 9/14/2015 9/14/2015 2.00 MIRU MOVE RURD P Work Derrick rams and pin in place. 120.0 120.0 08:00 10:00 Unpin and lower derrick,secure on cradle.Secure lines in derrick,prepare to stomp pipe shed away from derrick. 9/14/2015 9/14/2015 2.00 MIRU MOVE MOB P Adjust all stompers,unpin pipe shed 120.0 120.0 10:00 12:00 from sub.Walk pipe shed away fom sub with stompers. 9/14/2015 9/14/2015 2.00 MIRU MOVE MOB P Raise,shim and align sub stompers. 120.0 120.0 12:00 14:00 Continue walking pipe shed out from under sub. 9/14/2015 9/14/2015 1.00 MIRU MOVE MOB P Walk sub off 1C-152,remove and 120.0 120.0 14:00 15:00 position mat for spotting sub on 1C- 153. 9/14/2015 9/14/2015 2.00 MIRU MOVE MOB P Walk sub and pipe shed over and into 120.0 120.0 15:00 17:00 1C-153,spot,level and shim sub.Pad not very level in front of well. 9/14/2015 9/14/2015 3.00 MIRU MOVE MOB P Continue walking pipe shed into sub, 120.0 120.0 17:00 20:00 level,shim and pin same.Walk casing shed into pipe shed.Begin electrical innerconnects,begin loading and strapping 5"DP in casing shed. 9/14/2015 9/14/2015 1.00 MIRU MOVE RURD P Adjust hydraulic pressure,PJSM, 120.0 120.0 20:00 21:00 raise derrick and retract mast lift cylinders.SIMOPS-walk pits into sub. 9/14/2015 9/14/2015 0.75 MIRU MOVE RURD P PJSM,skid rig floor to drill position 120.0 120.0 21:00 21:45 and secure skid cylinders and hand rails. 9/14/2015 9/14/2015 1.25 MIRU MOVE MOB P PJSM,raise cattle chute and pipe 120.0 120.0 21:45 23:00 shed end cap,walk pits into sub and M/U hoses at innerconnect. 9/14/2015 9/14/2015 0.50 MIRU MOVE RURD P PJSM,un-pin and lower C-section, 120.0 120.0 23:00 23:30 secure end caps. 9/14/2015 9/15/2015 0.50 MIRU MOVE MOB P Walk pump module into pits,crib and 120.0 120.0 23:30 00:00 lower cellar walls.87 joints 5"DP in shed,strapped and tallied. 9/15/2015 9/15/2015 1.00 MIRU MOVE MOB P Move Power Module into position, 120.0 120.0 00:00 01:00 Connect service lines&electrical 9/15/2015 9/15/2015 1.00 MIRU MOVE RURD P Move cable tray into position and plug 120.0 120.0 01:00 02:00 in,Install shims under cellar obx, Disconnect hydraulic cylinders and retract same, Install grating in cellar area. 9/15/2015 9/15/2015 1.00 MIRU MOVE RURD P Switch power from Cold start 120.0 120.0 02:00 03:00 generators to 3516 generators,Spool drill line onto drawworks and deadman. Install pins into scoping line sheaves and scope derrick up.Remove scoping lines and yoke. Install well sign and secure landings. . RIG ACCEPTED @ 03:00 Page 1/41 Report Printed: 12/18/2015 6, ,. ' ' •perations Summary (with Timelog•pths) 0 1C-153 Conooioi"hillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X '.. Operation (ftKE) End Depth MKS) 9/15/2015 9/15/2015 4.50 MIRU MOVE RURD P Install Kelly hose.Calibrate blocks on 120.0 120.0 03:00 07:30 Totco&Amphion system.Complete totco pre-spud checcklist per Quadco rep.Pick up surface riser to rig floorvia Beaver slide.Load 5"&4"Drillpipe into pipeshed,Strap and tally drillpipe. 9/15/2015 9/15/2015 4.50 MIRU MOVE RURD P Attach 50'cables to bails for picking 120.0 120.0 07:30 12:00 riser.Pick and lower riser to cellar/ Nipple up riser to diverter"T".Rig up and pick Surface annular.Nipple up Annular tighten all bolts.Move flow box into drill position and secure.Lay down 50'cables.Install flow line. Continued working on drillpipe in shed while performing above tasks. 9/15/2015 9/15/2015 3.00 MIRU MOVE NUND P Continue nipple up surface diverter 120.0 120.0 12:00 15:00 system,Torque all flanged connections,Secure flow line connect all hole fill lines.Secure annular with chains and binders.Continue loading and strapping drillpipe in shed.Install slips and elevators.Continue taking on mud to pits as trucks arrive. 9/15/2015 9/16/2015 9.00 MIRU MOVE PULD P Pick up 4"drillpipe 252 joints,Racked 120.0 120.0 15:00 00:00 back total of 84 stands in Derrick.Sim Ops:Begin breaking bolts on Single Gate BOP for removal 9/16/2015 9/16/2015 4.00 MIRU MOVE PULD P Change handling equipment over to 120.0 120.0 00:00 04:00 5"/Pick up 87 joints 5"Drillpipe.29 stands Racked in derrick. 9/16/2015 9/16/2015 1.00 MIRU MOVE PULD P Pick up 17 joints 5"HWDp with 6-1/4" 120.0 120.0 04:00 05:00 Jars rack in derrick(6 stands) 9/16/2015 9/16/2015 3.00 MIRU MOVE RURD P Change saver sub from XT-39 to 4- 120.0 120.0 05:00 08:00 1/2"IF.Mobilized all short BHA components to rig floor. 9/16/2015 9/16/2015 1.00 MIRU MOVE BOPE P Pick up stand of HWDP,Space out to 120.0 120.0 08:00 09:00 close annular.Perform Diverter test. Test waived by AOGCC Rep Chuck Scheve.Annular closing time 43 seconds,Knive valve opening time 13 seconds.Koomey test start pressure 2,950 psi,After function 2,025 psi, 1st 200 psi increase 12 seconds,full system pressure in 51 seconds.6 nitrogen bottles average 1,930 psi. 9/16/2015 9/16/2015 0.50 MIRU MOVE BHAH P Pick up Arc Vision tool install 2 120.0 120.0 09:00 09:30 crossovers and 9'pupjoint.Lay down in pipeshed. 9/16/2015 9/16/2015 2.50 MIRU MOVE BHAH P Pre-Job/Pick up BHA#1 to 97' 120.0 120.0 09:30 12:00 perform rig offset on motor to MWD components. 9/16/2015 9/16/2015 0.75 MIRU 'MOVE BHAH P Crew Change/Complete BHA Pick-up 120.0 120.0 12:00 12:45 to 113'as per DD.(All Smart Iron made up) '9/16/2015 9/16/2015 0.25 MIRU MOVE SEQP P Fill Surface equipment.No leaks, 120.0 120.0 '12:45 13:00 Pressure test mud line to 3,500 psi. Page 2/41 Report Printed: 12/18/2015 0 •perations Summary (with Timeloglepths) 1C-153 COnootThiltaps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/16/2015 9/16/2015 1.75 SURFAC DRILL DDRL P RIH/Tag up @ 107'Drill 16"Surface 120.0 142.0 13:00 14:45 hole F/107'to 142' TVD-142'Flow rate 500 gpm,Pump pressure 400 psi,80%Flow out,RPM- 30,Torque 2k,WOB 5k,PSI off bottom 300 Pick up wt 62k,Slack off wt 59k,Rot wt 59k.Off bottom torque 1k 9/16/2015 9/16/2015 4.50 SURFAC DRILL CIRC T Circulate to shear mud and get 142.0 142.0 14:45 19:15 properties in line.Rack back stand pull into conductor @ 110'Treat mud with H2O and screen clean. Sim Ops:Lower cattle chute,Crane pick BOP from BORE Deck lower to pad,drop single gate,Pick up new single gate.Raise BOP's from pad and crane back on BOP deck.Raise cattle chute. 9/16/2015 9/16/2015 4.50 SURFAC DRILL DDRL P Drill F/142'To 409'MD 409'TVD 550 142.0 409.0 19:15 23:45 gpm,750 psi,45%Flow out,40 rpm,Torque 3k,15k WOB,off bottom pressure 625,Up wt.65k Dn wt 71k, Rot wt 69k,Off bottom torque 2k,AST 2.54/ART.68/ADT 3.22 Total bit hrs 3.22/Jar hrs.85.62 No losses while drilling. 9/16/2015 9/17/2015 0.25 SURFAC DRILL TRIP P Pump 1 stand HWDP out F/409'and to 409.0 409.0 23:45 00:00 314'md,Rack back stand Pick up wt=65k,Slack off wt 71k 9/17/2015 9/17/2015 2.00 SURFAC DRILL BHAH P Trip Out F/314' To 118'Rack back 409.0 409.0 00:00 02:00 HWDP/Pick up remaining BHA components 3 joints NM Flex Drill Collars.Trip in hole with Drill collars and HWDP from derrick to bottom (409') 9/17/2015 9/17/2015 4.00 SURFAC DRILL DDRL P Drill 16"Surface hole section:F/409' 409.0 663.0 02:00 06:00 and-T/663'and 657'TVD 600 gpm,995 psi,44%Flow out,40 rpm,3-5k torque, 15k bit wt. Off bottom 820 psi,P/U 86k,S/O 88k,Rot 85k, 1k Torque off bottom 9/17/2015 9/17/2015 6.00 SURFAC DRILL DDRL P Drill 16"Surface hole section:F/663' 663.0 1,068.0 06:00 12:00 and-T/1,068'and 1,054'TVD 600 gpm,1,180 psi,43%Flow out,40 rpm,4-5k torque,20k bit wt. Off bottom 950 psi,P/U 100k,S/O 90k,Rot 97k, 1.5k Torque off bottom. AST 4.19,ART 2.46,ADT 6.65,Total bit hrs.9.87.Total jar hours 92.27 9/17/2015 9/17/2015 2.00 SURFAC DRILL DDRL P Drill 16"Surface hole section:F/1,068' 1,068.0 1,202.0 12:00 14:00 and-T/1,202'and 1,177'TVD 600 gpm,1,260 psi,43%Flow out,40 rpm,6.5k torque,25k bit wt. Off bottom 1,100 psi,P/U 102k,S/O 92k,Rot 98k,2k Torque off bottom 9/17/2015 9/17/2015 1.50 SURFAC DRILL CIRC T Unable to pump&Jet flow line due to 1,202.0 1,202.0 14:00 15:30 Hydrates in mud,Condition mud with i De-Gasser,Screen clean and H2O I while reciprocating pipe F/1,185'and- 1 T/1,160'and i t i Page 3/41 Report Printed: 12/18/20151 •perations Summary (with Timelog•pths) 0; e 1C-153 CorWOo`PtiiIllip5 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/17/2015 9/17/2015 2.50 SURFAC DRILL DDRL P Drill 16"Surface hole section:F/1,202' 1,202.0 1,352.0 15:30 18:00 and-T/1,352'and 1,316'TVD 625 gpm,1,250 psi,44%Flow out,50 rpm,6.5k torque,20k bit wt. Off bottom 1,100 psi,P/U 106k,SIO 94k,Rot 98k,2k Torque off bottom 9/17/2015 9/18/2015 6.00 SURFAC DRILL DDRL P Drill 16"Surface hole section:F/1,352' 1,352.0 1,919.0 18:00 00:00 and-T/1,919'and 1,840'TVD 685 gpm,1,600 psi,46%Flow out,60 rpm,6k torque, 15k bit wt. Off bottom 1420psi,P/U 120k,SIO 105k,Rot 108k,3k Torque off bottom. AST 3.44,ART 3.92,ADT 7.36,Total bit hrs. 17.23.Total jar hours 99.63 9/18/2015 9/18/2015 3.00 SURFAC DRILL DDRL P Drill 16"Surface hole section:F/1,919' 1,919.0 2,297.0 00:00 03:00 and-T/2,297'and 2,157"TVD 700 gpm,1,740 psi,46%Flow out,60 rpm,7k torque,25k bit wt. Off bottom 1545psi,P/U 132 k,S/O 108k,Rot 113k,4k Torque off bottom. 9/18/2015 9/18/2015 3.00 SURFAC DRILL DDRL P Drill 16"Surface hole section:F/2,297' 2,297.0 2,553.0 03:00 06:00 and-T/2,553'and 2,372"TVD 700 gpm,1,920 psi,45%Flow out,60 rpm,7k torque,30k bit wt. Off bottom 1568 psi,P/U 140k,S/O 112k,Rot 118 k,5 k Torque off bottom. 9/18/2015 9/18/2015 0.50 SURFAC DRILL RGRP T Change out swab and liner on mud 2,553.0 2,553.0 06:00 06:30 pump#2,Reciprocated pipe with 300 gpm,400 psi,60 rpm rotary intil pump back on line. 9/18/2015 9/18/2015 3.50 SURFAC DRILL DDRL P Drill 16"Surface hole section F/2,553' 2,553.0 2,841.0 06:30 10:00 MD T/2,841'MD 2616'TVD 725 GPM, 1,980 PSI,45%FO,60 RPM,7-9 K TORQ. 18 K WOB.Off Bottom PSI=1,684' P/U=140 k,S/O=114 k,ROT= 114 k,Torque off bottom 5 k. AST-.61 ART-3.65,ADT=4.26 Total bit hrs=23.34 Total Jar hrs.= 105.74 9/18/2015 9/18/2015 1.00 SURFAC CASING CIRC P Circulate Bottoms Up while rotating 2,841.0 2,841.0 10:00 11:00 and reciprocating F/2,840'MD- T/2,770'MD 722 gpm 1,700 psi,60 rpm,6 k torq. 3,500 total strokes. 9/18/2015 9/18/2015 1.00 SURFAC CASING BKRM P Backream out of hole F/2,840'and- 2,841.0 2,391.0 11:00 12:00 T/2,391'and @ 724 gpm, 1,700 psi, 48%FO,60 rpm,6 k torq,P/U wt 130 kS/Owt114k No fluid losses Page 4/41 Report Printed: 12/18/2015 •perations Summary (with Timelog•pths) 1C-153 Conoco Phillips ps AkrFn Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/18/2015 9/18/2015 5.25 SURFAC CASING BKRM P Backream out of hole F/2,391'and- 2,391.0 1,920.0 12:00 17:15 T/1,920'and @ 724 gpm, 1,700 psi, 48%F/O.60 rpm,6 k torq.Worked tight hole F/2,280 and-T/2,245'and& 2,064'and-T/2,024'and W/Increased torq and pressure. Continued backreaming out F2,245'md-T/1,920'md.Reduced flow rate F/1,920 and-514'and F/724 gpm to 500 gpm 1,010 psi ICP,35% F/0.60 rpm,5 k torq.880 fcp.Slow pulling spped as dictated by cuttings load on shakers.No mud losses. 9/18/2015 9/18/2015 1.50 SURFAC CASING TRIP P Blow down topdrive&mudline.POOH 1,920.0 0.0 17:15 18:45 on elevators.Rack back HWDP,Jars and NM Flex Drillcollars.Lay down saver sub per DD. 9/18/2015 9/18/2015 1.75 SURFAC CASING BHAH P L/D BHA F/125'MWD Tools,Drain 0.0 0.0 18:45 20:30 motor,break bit. Bit grade=1-1-CT-N-1-I-CT-TD 9/18/2015 9/18/2015 0.50 SURFAC CASING BHAH P Clear rig floor of smaller BHA 0.0 0.0 20:30 21:00 components,Clean floor 9/18/2015 9/18/2015 1.00 SURFAC CASING RURD P R/U 13-3/8"handling equipment. 0.0 0.0 21:00 22:00 Check equipment,PJSM. 9/18/2015 9/19/2015 2.00 SURFAC CASING PUTB P Run 13-3/8"L-80 HYD-563 68 PPF 0.0 0.0 22:00 00:00 casing,Baker-lock shoe track,Fill and check float,good.Make up with hydraulic toongs to 27 k ft/lbs.RIH- T/217'installing Bowspring centralizers every joint.Fill each joint with fill up hose. 9/19/2015 9/19/2015 4.50 SURFAC CASING PUTB P Run 13-3/8"L-80 HYD-563 68 PPF 270.0 1,364.0 00:00 04:30 casing,F/270'MD-T/1,364'MD. Installing 1 bow spring centralizer per joint,Filling each joint with fill up hose topping off every 5 joints.. 9/19/2015 9/19/2015 0.50 SURFAC CASING CIRC T Reciproace F/1,364'md-T/1,331'md. 1,364.0 1,364.0 04:30 05:00 Work tight spot at 1,364'md W/3 bpm, 180 psi,flow out=24% Pick up wt-131k down wt 105k, Pumped 1094 strokes.Worked area with no pumps with no problem. 9/19/2015 9/19/2015 1.00 SURFAC CASING PUTB P Continue running 13-3/8"L-80 HYD- 1,364.0 1,897.0 05:00 06:00 563 68 PPF casing,F/1,364'and- T/1,897'md. Installing 1 bow spring centralizer per joint,Filling each joint with fill up hose topping off everyl0 joints. P/U wt. 126k S/O wt 111k 9/19/2015 9/19/2015 1.00 SURFAC CASING CIRC P Circulate while reciproacting 13-3/8" 1,897.0 1,897.0 06:00 07:00 Casing,F/1,897'and-T/1,854'md. Circulate per plan 1-1/2 bottoms up below perma frost. 1 bpm-130 psi FO 7%,2 bpm 150 psi 18%FO,3 bpm 142 psi 30%FO, 4 bpm 148 psi 48%FO,5 bpm 148 psi 54%FO,6 bpm 163 psi 58%FO. Up wt 167k Down wt 133k Total strokes pumped 2,823 Page 5/41 Report Printed: 12/18/2015 iterations Summary (with Timelog�epths) 01 1C-153 Corbo�o`Wt�iItips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/19/2015 9/19/2015 3.00 SURFAC CASING PUTB P Continue running 13-3/8"L-80 HYD- 1,897.0 2,789.0 07:00 10:00 563 68 PPF casing,F/1,897'and- T/2,789'md. Installing 1 bow spring centralizer per joint,Filling each joint with fill up hose topping off everyl0 joints. P/U wt.211k S/O wt 162k 9/19/2015 9/19/2015 0.75 SURFAC CASING HOSO P M/U 13-3/8"Vetco mandrel hanger, 2,789.0 2,831.0 10:00 10:45 make up landing joint,land hanger on load shoulder.211 down wt. 9/19/2015 9/19/2015 1.25 SURFAC CEMENT CIRC P Reciprocate casing while circulating 2,831.0 2,831.0 10:45 12:00 and conditioning mud.F/2,829'and- T/2,811'and 1 bpm-130 psi FO 7%,2 bpm 150 psi 18%FO,3 bpm 110 psi 24%FO, 4 bpm 165 psi 26%FO,5 bpm 144 psi 22%FO,6 bpm 177 psi 24%FO. Up wt 212 k Down wt 168 k Total strokes pumped 2,415 Blow Down Top drive rig up cement hose. 9/19/2015 9/19/2015 3.50 SURFAC CEMENT CIRC P Circulate&Condition mud for cement 2,831.0 2,831.0 12:00 15:30 job,Pump through cement hose. Reciprocate string while pumping 6 bpm @ 290 psi 20%FO Sim ops:Batch Cement/Cement PJSM 9/19/2015 9/19/2015 3.50 SURFAC CEMENT CMNT P Turn over to Schlumberger to begin 2,841.0 2,841.0 15:30 19:00 cement job @ 15:19.Pump 5 bbl's CW-100,Pressure test line to 4,000 psi.good test.Pump 45 BBI's CW-100 @ 5 bpm 200 psi.Total CW-100 pumped 50 bbl's. 15:47 Chase with 98.5 bbl's 10.5 ppg mudpush 2.Drop bottom plug @ 16:20 begin pumping 11 ppg.lead cement @ 16:25 Pump 585 bbl's.lead cement at 5.6 bpm ICP 210 psi FCP 300 psi.Batch and pump 74 bbl's 12 ppg.tail cement @ 18:24 15 bbl's away @ 5.4 bpm 290 psi.final circulating rate 4.6 bbl's per minute 150 psi.Drop top plug @ 19:10 chase with 10 bbl's H2O. 9/19/2015 9/19/2015 2.25 SURFAC CEMENT CMNT P Displace with rig 9.8 ppg mud, Initial 2,831.0 2,831.0 19:00 21:15 circulating rate 8 bbl's per min.Catch cement slow rate to 6 bbl's per minute 250 psi.@ 1,200 strokes slow rate to 4 bpm 154 psi, Cement returns at surface 2,400 strokes,2,400 strokes slow rate to 3 bpm 194 psi @ 3,950 strokes slow rate to 1 bpm 280 psi. Bump plug at 3,962 strokes.CIP @ 20:52.Bump plug at 280 psi increase psi to 780 psi,hold for 5 minutes, Bleed off presssure,check floats. Floats holding. 160 bbl's cement to surface. Page 6/41 Report Printed: 12/18/2015 0141 Iperations Summary (with Timeloglepths) 0 1C-153 Conoco`Phillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr)`- Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/19/2015 9/19/2015 1.00 SURFAC CEMENT PRTS T Rig up and test casing 30 minutes 0.0 0.0 21:15 22:15 3,000 psi.Pump at 1 bpm reach pressure at 54 strokes.Total pumped 5.6 bbl's total bleed back 5.6 bbl's.Rig down&Blow down cement line. 9/19/2015 9/20/2015 1.75 SURFAC CEMENT RURD P Rig down&clean Volant casing 0.0 0.0 22:15 00:00 running tool.Pull landing joint and lay down. Flush stack,hydrill element& flowline with black water pills,Pull and clean and re-install cement line demco valves.(Caught Greg Moses Crew for the safety stand down during PTSM coming on at midnight) 9/20/2015 9/20/2015 5.50 SURFAC CEMENT NUND P Continue-Flushing flow line,Clearing 0.0 0.0 00:00 05:30 and cleaning rig floor,Cleaning cleaning cement demco valves and cellar box. Pull master bushings.N/D 21-1/4" Annular, 14'riser,Diverter Tee and Knife valve,Diverter line.Remove conductor outlet valves. 9/20/2015 9/20/2015 2.00 SURFAC WHDBOP NUND P Install Vetco hold down flange,N/U 0.0 0.0 05:30 07:30 Vetco wellhead,Obtain RKB measurements,LLDS-37.94'ULDS- 34.10'Top of Vetco wellhead 33.95' Pressure test 13-3/8"X Vetco wellhead seal 2,000 pai 10 minutes. Good test. 9/20/2015 9/20/2015 4.50 SURFAC WHDBOP NUND P N/U 1.47'13-5/8"x 13-5/8"Spool, 0.0 0.0 07:30 12:00 Install OA&IA valves,N/U 14'13-5/8" Riser, Install choke and kill hose,N/U BOP's,Chink Joes flow box,Install hydraulic lines F/ODS hands free winches. 9/20/2015 9/20/2015 3.50 SURFAC WHDBOP NUND P N/U BOP torque all flanged 0.0 0.0 12:00 15:30 connections, Install OA&IA valves, Tighten flowline flange,Install air boot and flow nipple,Install strip 0 matic. Sim ops:Mobilize PS-21 slips F/shop T/Floor.Pick up test plug,wear bushing and running tool. 9/20/2015 9/20/2015 1.00 SURFAC WHDBOP RURD P P/U 9-5/8"Test joint,Make up and set 0.0 0.0 15:30 16:30 test plug,Rig up test equipment.Flush and fill lines with H2O, Sim Ops: Inspect and replace cuttings tank suction line valves. Page 7/41 Report Printed: 12/18/2015 Iperations Summary (with Timelogepths) 1C-153 GonocoPhillips hkAsks Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/20/2015 9/20/2015 6.00 SURFAC WHDBOP BOPE P Test BOPE T/250 psi low&3,500 psi 0.0 0.0 16:30 22:30 high 5 min per test,All tests charted. Manual&Superchoke tested 250 psi low&2,000 psi high also 5 minu per test and charted.9-5/8"Test joint tested annular,upper 9-5/8"rams. 5"Test joint test annular,2-7/8"x 5- 1/2"Variable rams(Lower) 4"Test joint tested annular, 2-7/8"x 5 -1/2"Variable rams(Lower) Test choke valves 1-15,Test IA valve, Manual operated&Superchoke, Choke&Kill manuals&HCR's,4" Valve on kill line,4"TIW&4"Dart,5" TIW&5"Dart,Upper&lower IBOP. Koomey drawdown test:Acc=3,050 psi Manifold=1,500 psi.Acc=1,600 psi after all functions on bottles, 18 sec for 200 psi build upw/2 elec pumps, 109 sec to full build system pressure w/2 electric pumps&2 air pumps.Closing time annular 23 sec. upper rams 18 sec,Blind/Shear rams 16 sec.Lower pipe rams 16 sec. Choke HCR 2 sec.Kill HCR 2 sec.6 bottle average 1996 psi. Test witness waived by AOGCC rep Bob Noble Sim-Ops-Flush and suck out 14'of conductor X 13-3/8"Annulus for top job preparation. 9/20/2015 9/21/2015 1.50 SURFAC WHDBOP RURD P R/D&Blow down test equipment, 0.0 0.0 22:30 00:00 Blow down choke&Kill lines,Test plug hanging up while attempting to remove,Check all lockdowns backed out. Rotate joint with test plug attached to the right while holding tension.Test plug released. Sim ops:BHA components to floor and in order in pipe shed.Clean mud pump suction manifold. 9/21/2015 9/21/2015 1.00 SURFAC WHDBOP RURD P Lay down test plug,Pick up and set 12 0.0 0.0 00:00 01:00 -5/16"ID, 13-1/2"OD 4.96'Lower wear bushing.Change out elevators to 5,'. 9/21/2015 9/21/2015 3.00 SURFAC CEMENT BHAH P PJSM P/U Intermediate BHA,SLB 0.0 745.0 01:00 04:00 Rotary steerable assembly. Sim Ops:Mix 2 bbl's cement and fill void in conductor&13-3/8"Annulus. 9/21/2015 9/21/2015 0.75 SURFAC CEMENT PULD P Trip in hole F/745'and-T/1,500'and 745.0 1,500.0 04:00 04:45 picking up doubles of 5"drillpipe from shed, 9/21/2015 9/21/2015 0.50 SURFAC CEMENT DHEQ P Fill pipe&Shallow pulse test 700 gpm 1,500.0 1,500.0 04:45 05:15 1,382 psi 34%FO Blow down top drive&Mud line. 9/21/2015 9/21/2015 0.75 SURFAC CEMENT TRIP P Trip in hole F/1,500'md-T/2,639'md. 1,500.0 2,639.0 05:15 06:00 Monitor displacement via trip tank Up wt 138k down wt. 102k. 9/21/2015 9/21/2015 2.50 SURFAC CEMENT SLPC P PJSM,Slip&Cut 13 wraps 104'drill 2,639.0 2,639.0 06:00 08:30 line.Calibrate SLB,Totco&Amphion height sensors. Page 8/41 Report Printed: 12/18/2015 operations Summary (with Timelog�epths) 1C-153 Conoc°Phillips 0 .` Atsk.s Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/21/2015 9/21/2015 1.50 SURFAC CEMENT PRTS P PJSM,Test OA valve 250 psi low- 2,639.0 2,639.0 08:30 10:00 3,500 psi high.5 minutes low test 30 minute high test.Test charted.Pump down drillpipe&Annulus 61 strokes to reach 3,500 psi.Blow down kill line. 9/21/2015 9/21/2015 2.00 SURFAC CEMENT COCF P Establish parameters,Up wt 142k 2,639.0 2,753.0 10:00 12:00 Down wt 100k Rot wt. 119k.30 rpm 8- 10k torque.600 gpm-1,220 psi 32% FO.Wash down F/2,639'-T/2,748'4 bpm flow 122 psi 15%FO,Tag cement at 2,748 md.9k bit wt.drill wiper plugs at 2,753'md.5 k bit wt. Increase bit wt to 12k,40 rpm,600 gpm 1,184 psi,30%FO.Drill float collar at 2,753'md-T/2,754'md SPR's @ 2,637'and 2,443'TVD 09:42 hrs.MW=9.7 drillplex. #1 pump 20/30spm 102 psi/113 psi #2 pump 20/30 spm 100 psi/109 psi 9/21/2015 9/21/2015 2.75 SURFAC CEMENT DRLG P Continue drilling out casing cement 2,753.0 2,833.0 12:00 14:45 and float equipment F/2,754'and- T/2,833'md.600 gpm 60 rpm 31% FO,9k torque.5k bit wt. Tag top of shoe at 2,828'and drilled shoe F/2,828'and to 2,833'and with 500 gpm,860 psi 27%FO 50 rpm 7- 8k torque 5k bit wt. 9/21/2015 9/21/2015 0.25 SURFAC CEMENT DDRL P Drill out rat hole and 20'new formation 2,833.0 2,861.0 14:45 15:00 F/2,833'and-T/2,861'md.600 gpm,1,180 psi,31%FO,60 rpm,8k torque. Off bottom Up wt 150k Down wt 108k, Rot wt 119k,torque-7k ft/lbs. 9/21/2015 9/21/2015 0.50 SURFAC CEMENT CIRC P Circulate bottoms up,while rotating& 2,861.0 2,861.0 15:00 15:30 Reciprocating F/2,820'md-T/2,861' md.600 gpm,1,180 psi,31%FO,60 rpm,6-8k torque.5,368 total strokes Up wt-144k Down wt. 108k Obtain SPR's 9/21/2015 9/21/2015 0.50 SURFAC CEMENT RURD P Lay down double not in string 2,861.0 2,861.0 15:30 16:00 Rig up test equipment to stump for FIT Blow down topdrive. 9/21/2015 9/21/2015 1.00 SURFAC CEMENT LOT P 9.8 ppg mud weight in&out,2,824' 2,861.0 2,861.0 16:00 17:00 and 2,607'TVD,Flush lines and perform FIT test X 2.Pumping 1.3 bbl's break over at 400 psi obtain 12.8 EMW,Bleed back.8 bbl's Rig down test equipment. 9/21/2015 9/21/2015 0.75 INTRM1 DRILL DISP P Displace well over to 9.2 ppg LSND 2,861.0 2,861.0 17:00 17:45 mud.Downlink to tool while washing to bottom 2,824'and-T/2,861'md. Stage pumps up to 700 gpm. Page 9/41 Report Printed: 12/18/2015 operations Summary (with Timelog epths) • ski ►fit 0a 1C-153 ON-10CoPhilfips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) '. End Depth(ftK8) 9/21/2015 9/21/2015 6.00 INTRM1 DRILL DDRL P Drill 12-1/4"Intermediate hole section 2,861.0 3,451.0 17:45 23:45 F/2,861'and-T/3,451'and 3,116'TVD 750 gpm 1,290 psi,35%FO, 150 rpm, 9-11k torque,2-10k bit wt ECD 9.89 off bottom 1200 psi,Up wt 160k,Down wt 113k,Rot wt 125k,8k torque Rotary steerable ADT-3.95 hrs.Bit hrs.3.95 Jar hrs total 109.69 9/21/2015 9/22/2015 0.25 INTRM1 DRILL CIRC T Obtain survey,Circulate bottoms up 3,451.0 3,451.0 23:45 00:00 prior to trip out due to insufficient turn rate. Rot&Recip F/3,394'md-T/3,445'and 550 gpm,880 psi,29%FO,100 rpm,8k torque 9/22/2015 9/22/2015 1.00 INTRM1 DRILL CIRC T Complete circulating hole clean,600 3,451.0 3,451.0 00:00 01:00 gpm with 854 psi 29%FO 100 rpm, PU=155K,SO=119K,Rot=134K, MW 9.2 ppg.Total pumped 608 BBL. Monitor well 10 minutes;Static. Obtain slow pump rates: Pump#1 20/30 spm-100/120 psi Pump#2 20/30 spm-100/120 psi @ 00:45 9/22/2015 9/22/2015 0.50 INTRM1 DRILL TRIP T POOH on elevators 3,451'to 3,180'. 3,451.0 3,180.0 01:00 01:30 Pulled 30k over at 3180'. 9/22/2015 9/22/2015 1.00 INTRM1 DRILL BKRM T Establish pump rates and back-ream 3,180.0 2,824.0 01:30 02:30 into shoe 2,824'.600 gpm with 824 psi,31%FO, 100 RPM with 8K torque.Rot=134K.Monitor well 10 min.Well static.Pump 25 bbl dry job, Blow down topdrive and Mud Line. 9/22/2015 9/22/2015 1.25 INTRM1 DRILL TRIP T POOH on elevators 2824'to 742'. 2,824.0 742.0 02:30 03:45 Monitor proper displacement during trip. Change out PS-21 slips to use hand slips. 9/22/2015 9/22/2015 2.75 INTRM1 DRILL BHAH T Stand back HW jars and NMDC. 742.0 0.0 03:45 06:30 Hung up and pulled 30K over at 55'. Establish circulation at 200 GPM with75 psi and Rotate at 10 RPM and pull out of hole to bit. 9/22/2015 9/22/2015 1.50 INTRM1 DRILL OTHR T Drain BOP stack,pull wear bushing, 0.0 70.0 06:30 08:00 and drift same with 12 1/4"bit;Good. RIH to 70'to insure clear in stack. 9/22/2015 9/22/2015 1.00 INTRM1 DRILL BHAH T LD remaining BHA. 70.0 0.0 08:00 09:00 9/22/2015 9/22/2015 2.25 INTRMI DRILL BHAH T Install wear bushing; 12.13"ID, 13.5" 0.0 0.0 09:00 11:15 OD,4.96'Length,Download MWD. 9/22/2015 9/22/2015 0.25 INTRM1 DRILL SFTY T PJSM for BHA PU and MU. 0.0 0.0 11:15 11:30 9/22/2015 9/22/2015 0.50 INTRM1 DRILL BHAH T PU BHA with 12 1/4"mill tooth bit on 0.0 39.0 11:30 12:00 motor to 39'. 9/22/2015 9/22/2015 1.50 INTRM1 DRILL BHAH T PU and MU BHA per SLB DD and 39.0 186.0 12:00 13:30 MWD 9/22/2015 9/22/2015 1.00 INTRM1 DRILL BHAH T RIH with HW,jars and NMDC. 186.0 747.0 13:30 14:30 Change out slips to PS-21 system. 9/22/2015 9/22/2015 0.50 INTRM1 DRILL TRIP T Trip in hole from 747'to 1690'. 747.0 1,690.0 14:30 15:00 Monitor displacement via TT;Good. Page 10/41 Report Printed: 12/18/2015 6 •perations Summary (with Timeloglpths) 0,-,. a 1C-153 N. ConocoPhillips AGr.k Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T X Operation (ftKB) End Depth(EKE) 9/22/2015 9/22/2015 0.50 INTRM1 DRILL DHEQ T Perform shallow pulse test of MWD; 1,690.0 1,690.0 15:00 15:30 Good with 600 GPM with 820 psi,31% FO. Blow down top drive. 9/22/2015 9/22/2015 0.75 INTRM1 DRILL TRIP T Trip in from 1690'to 2828'. Monitor 1,690.0 2,828.0 15:30 16:15 displacement via TT;Good. PU= 133K,SO=103K. 9/22/2015 9/22/2015 0.50 INTRM1 DRILL SVRG T Service top drive and blocks and 2,828.0 2,828.0 16:15 16:45 inspect;good. 9/22/2015 9/22/2015 0.75 INTRM1 DRILL TRIP T Trip in from 2828'to 3185'and hit 2,828.0 3,185.0 16:45 17:30 obstruction. 9/22/2015 9/22/2015 2.00 INTRM1 DRILL REAM T Unable to work through with low 3,185.0 3,238.0 17:30 19:30 pumps or no pumps. Discuss with town. Establish circulation and rotation;500 GPM with 770 psi,20 RPM with 9K torque. PU single to work past,then LD single not in string. 9/22/2015 9/22/2015 0.75 INTRM1 DRILL TRIP T Trip in from 3238'to 3399'. 3,238.0 3,399.0 19:30 20:15 9/22/2015 9/22/2015 0.25 INTRM1 DRILL SRVY T Obtain survey to verify the hole was 3,399.0 3,450.0 20:15 20:30 not side-tracked. Wash and ream last stand to bottom. 9/22/2015 9/23/2015 3.50 INTRM1 DRILL DDRL P Drill 12.1/4"intermediate hole from 3,450.0 3,679.0 20:30 00:00 3450'to 3679',600 GPM with 1165 psi,30%FO,30K WOB,ECD=9.84. PU=157K,S0=119K,Rot=133K. AST=1.62,ART=0.24,ADT=1.86, Total Bit hours=1.86,Jar hours= 111.56. Crew change. No losses for day. 9/23/2015 9/23/2015 6.00 INTRM1 DRILL DDRL P Drill 12.1/4"intermediate hole from 3,679.0 4,056.0 00:00 06:00 3679'to 4056,700 GPM with 1360 psi,33%FO,80 RPM with 9K torque, 22K WOB,ECD=9.70. PU=159K, So=121K,Rot=133K. Mix and place 1/2 BBL of cement in surface casing for top job. TOC measure 12'down from landing ring. Brought to surface. SPR @ 3769'MD,3367'TVD Mud Wt=9.2 Pump#1 20/30 spm-140/150 psi @ 01:30 Pump#2 20/30 spm-140/160 psi 9/23/2015 9/23/2015 6.00 INTRM1 DRILL DDRL P Drill 12.1/4"intermediate hole from 4,056.0 4,370.0 06:00 12:00 4056'to 4370',800 GPM with 1497 psi,35%FO, 100 RPM with 10K torque, 15K WOB,ECD=9.82. PU= 168K,SO=113K,Rot=137K. AST=6.38,ART=0.96,ADT=7.34, Total Bit hours=9.20,Jar hours= 117.04. Crew change. No losses for day. SPR @ 4336'MD,3813'TVD Mud Wt=9.1 Pump#1 20/30 spm-170/190 psi @ 11:40 Pump#2 20/30 spm-160/180 psi Page 11/41 Report Printed: 12/18/2015 0 •perations Summary (with Timeloglepths) 1C-153 COno 'hillips kirk. Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/23/2015 9/23/2015 1.25 INTRM1 DRILL DDRL P Drill 12.1/4"intermediate hole from 4,370.0 4,478.0 12:00 13:15 4370'to 4478,700 GPM with 1360 psi,33%FO,80 RPM with 9K torque, 22K WOB,ECD=9.70. PU= 159K, So=121K, Rot= 133K. SPR @ 4478°MD,3709'TVD Mud Wt=9.2 Pump#1 20/30 spm-180/200 psi @ 13:12 Pump#2 20/30 spm-180/200 psi 9/23/2015 9/23/2015 3.75 INTRM1 DRILL BKRM T Due to high percentage of sliding with 4,478.0 3,300.0 13:15 17:00 motor and the growing difficulty to maintain toolface orientation,a precautionary short trip was performed. BROOH from 4478'to 3869'with 750 GPM with1380 psi, 31%FO, 100 RPM with 10K torque. From 3869'to 3300'with 850 GPM with 1650 psi,37%FO. Pump 2X BU on the last two stands pulled. PU= 153K,SO= 113K, Rot= 130K. Displacement good for trip. 9/23/2015 9/23/2015 0.75 INTRM1 DRILL TRIP 'T Trip in the hole on elevators to 4439'. 3,300.0 4,439.0 17:00 17:45 Proper displacement observed. 9/23/2015 9/23/2015 0.25 INTRM1 DRILL REAM T Wash and ream to bottom from 4439' 4,439.0 4,478.0 17:45 18:00 to bottom. 9/23/2015 9/24/2015 6.00 INTRM1 DRILL DDRL P Drill 12.1/4"intermediate hole from 4,478.0 4,760.0 18:00 00:00 4478'to 4760',600 GPM with 1140 psi,30%FO,40K WOB,ECD=9.63. PU= 156K,SO=119K,Rot=130K. AST=5.93,ART=0.84,ADT=6.77, Total Bit hours=14.11,Jar hours= 123.81. Crew change,no losses. 9/24/2015 9/24/2015 6.00 INTRM1 DRILL DDRL P Drill 12.1/4"intermediate hole from 4,760.0 4,930.0 00:00 06:00 4760'to 4930',800 GPM with 1675 psi,36%FO,41K WOB,ECD=9.61. PU= 156K,SO=119K,Rot=130K. SPR @ 4815'MD,3821'TVD Mud Wt=9.1+ Pump#1 20/30 spm-160/180 psi @ 01:45 Pump#2 20/30 spm-150/160 psi 9/24/2015 9/24/2015 4.70 INTRM1 DRILL DDRL P Drill 12.1/4"intermediate hole from 4,930.0 5,137.0 06:00 10:42 4930'to 5137',800 GPM with 1640 psi,36%FO, 15K WOB,ECD=9.76. PU=148K,SO=115K,Rot=130K. AST=9.09,ART=0.0,ADT=9.09, Total Bit hours=21.4,Jar hours= 131.10. SPR @ 5137'MD,3856'TVD Mud Wt=9.2 Pump#1 20/30 spm-180/220 psi @ 10:45 Pump#2 20/30 spm-180/220 psi Page 12/41 Report Printed: 12/18/2015 Operations Summary (with Timelog�epths) 0110 1C-153 Conon hiiiips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/24/2015 9/24/2015 1.30 INTRM1 CASING BKRM P BROOH from 5137'to 4628'with 750 5,137.0 4,628.0 10:42 12:00 GPM with 1490 psi,36%FO, 100 RPM with 10K torque. PU=148K, S0=115K,Rot=130K. Proper fill observed during trip. Crew change. No losses for day. 9/24/2015 9/24/2015 2.75 INTRM1 CASING BKRM P BROOH from 4628'to 3490',750 4,628.0 3,490.0 12:00 14:45 GPM with 1450 psi,38%FO, 100 RPM with 9K torque. Monitor displacement via TT. 9/24/2015 9/24/2015 0.25 INTRM1 CASING SRVY T Obtain surveys to verify suspect 3,490.0 3,490.0 14:45 15:00 surveys from earlier in the drilling. 9/24/2015 9/24/2015 2.50 INTRM1 CASING BKRM P BROOH from 3490'to 2828'and with 3,490.0 2,828.0 15:00 17:30 increased flow of 843 GPM with 1600 psi an increase in cutting was returned at the shakers. Pump high-vis sweep Surf to Surf. 9/24/2015 9/24/2015 0.50 INTRM1 CASING PMPO P Pump out of the hole from 2828'to 2,828.0 2,733.0 17:30 18:00 2733'at 843 GPM with 1485 psi,38% FO. 369 BBL pump during BU inside casing. 9/24/2015 9/24/2015 0.50 INTRM1 CASING TRIP P Pull on elevators from 2733'to 2544'. 2,733.0 2,544.0 18:00 18:30 Monitor fill via TT;proper fill observed. 9/24/2015 9/24/2015 0.25 INTRM1 CASING SVRG P Perform leg switch with high line 2,544.0 2,544.0 18:30 18:45 power to attain higher voltage for rig. 9/24/2015 9/24/2015 2.75 INTRM1 CASING TRIP P POOH from 2544'to 186'. LD HW 2,544.0 186.0 18:45 21:30 and jars and MU stand with HW single and stand back. 9/24/2015 9/24/2015 1.50 INTRM1 CASING BHAH P LD BHA per SLB DD and MWD. 186.0 0.0 21:30 23:00 9/24/2015 9/25/2015 1.00 INTRM1 CASING BHAH P Clean and clear floor of BHA and 0.0 0.0 23:00 00:00 handling tools. 9/25/2015 9/25/2015 0.50 INTRM1 CASING RURD P Pull wear bushing,remove and LD 0.0 0.0 00:00 00:30 running tool and test joint. Flush stack,RD sub rack and rack stand. Blow down top drive. 9/25/2015 9/25/2015 2.00 INTRM1 CASING RURD P Change out bales to long. RU 9 5/8" 0.0 0.0 00:30 02:30 casing handling equipment. Install bale extensions,Volant CRT,safety slings and power tongs. Install slip inserts,elevators and RU fill-up hose. Crew change 0200. 9/25/2015 9/25/2015 0.50 INTRM1 CASING PUTB P PU and MU shoe track with BakerLok 0.0 170.0 02:30 03:00 to pin on 4th joint. Adjust Kelly hose alignment for running casing.Fill pipe, check floats;Good, 9/25/2015 9/25/2015 6.00 INTRM1 CASING PUTB P Run 9 5/8"40#L-80 Hyd 563 casing 170.0 2,824.0 03:00 09:00 per detail to 2824'with Volant and power tongs with MU torque to 16K ft- lbs. Filling on the fly and topping off every 10 joints. 9/25/2015 9/25/2015 1.00 INTRM1 CASING CIRC P Establish circulation and stage up 3 2,824.0 2,824.0 09:00 10:00 BPM with 120 psi, 11%FO to 8 BPM with 156 psi,20%FO. PU= 169K, SO=121K. Page 13/41 Report Printed: 12/18/2015 0.: ,,,,, , f •perations Summary (with Timelog epths) .a 1C-153 ConocoPhilltps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time - End Time Dur(hr) Phase Op Code Activity Code Time'P-T-X Operation (ftKB) End Depth(ftKB)' 9/25/2015 9/25/2015 2.00 INTRM1 CASING PUTB P Run 9 5/8"40#L-80 Hyd 563 casing 2,824.0 3,517.0 10:00 12:00 per detail to 3517'with Volant and power tongs with MU torque to 16K ft- lbs. Filling on the fly and topping off every 10 joints. 9/25/2015 9/25/2015 2.00 INTRM1 CASING PUTB P Run 9 5/8"40#L-80 Hyd 563 casing 3,517.0 4,554.0 12:00 14:00 per detail to 4554'with Volant and power tongs with MU torque to 16K ft- lbs. Filling on the fly and topping off every 10 joints. Crew change 1400. 9/25/2015 9/25/2015 0.75 INTRM1 CASING CIRC P Establish circulation and stage up 3 4,554.0 4,554.0 14:00 14:45 BPM with 190 psi, 19%FO to 6 BPM with 212 psi,23%FO.Circulate a total of 224 BBL. 9/25/2015 9/25/2015 2.25 INTRM1 CASING PUTB P Run 9 5/8"40#L-80 Hyd 563 casing 4,554.0 5,129.0 14:45 17:00 per detail to 5129'with Volant and power tongs with MU torque to 16K ft- lbs. Filling on the fly and topping off every 10 joints. 9/25/2015 9/25/2015 0.50 INTRM1 CEMENT CIRC P Establish circulation and stage up 3.5 5,129.0 5,129.0 17:00 17:30 BPM with 140 psi, 13%FO to 5 BPM with 175 psi, 18%FO. Reciprocate from 5127'to 5111'. 9/25/2015 9/25/2015 0.50 INTRM1 CEMENT RURD P Blow down top drive and rig up 5,129.0 5,129.0 17:30 18:00 cement hose to Volant. 9/25/2015 9/25/2015 2.25 INTRM1 CEMENT CIRC P Establish circulation through cement 5,129.0 5,129.0 18:00 20:15 hose,stage up 4 BPM with 200 psi, 18%FO to 6 BPM with 275 psi ICP and with 215 psi FCP,23%FO.Total pumped 966 BBL to condition mud; 9.25 ppg in and 9.3 ppg out. PU= 198K,SO=147K. SIMOPS;hold PJSM for cement job with rig crew,cementers.CPAI reps, and mud engineer. 9/25/2015 9/25/2015 2.50 INTRM1 CEMENT CMNT P Line up to SLB cementers;Pump 4.0 5,129.0 5,129.0 20:15 22:45 BBL of water and test lines to 3500 psi;Good. Pump 40.0 BBL of 11.5 ppg Mud push II and drop bottom plug. Chase with 50 BBL of Class G 15.8 ppg retarded cement,then pumped 93.0 BBL of Class G 15.8 ppg cement without retarder and dropped the top plug. Chase top plug with 10.6 BBL of 10.8 ppg Mud Push II. Displace cement with 369.5 BBL of 9.2 ppg Faze-Pro OBM mud. Cement was pumped at an average rate of 5.5 BPM. Cement was chased at an average rate of 5.5 BPM,slowing to 3 BPM with 262 BBL away of the FP displacement. The plug bumped with 600 psi and pressure was increased to 1160 psi and held for 5 minutes. 2 BBL were bled back and the floats held. Cement was in place at 22:30 hours. Casing string was reciprocated throughout job,setting on hanger during fluid transitions and no losses were incurred during job. Final PU= 172K,SO=109K. Page 14/41 Report Printed: 12/18/2015 01 u Operations Summary (with Timelog•pths) 1C-153 CorkxAtiilhips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase , Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/25/2015 9/26/2015 1.25 INTRM1 CEMENT RURD P Blow down lines,RD Volant CRT, 5,129.0 0.0 22:45 00:00 drain stack and back out landing joint. LD landing joint,flush stack and re- drain. 9/26/2015 9/26/2015 1.75 INTRM1 CEMENT WWSP P Install pack-off as per Vetco rep, 0.0 0.0 00:00 01:45 RILDS,test pack-off to 5000 psi for 10 minutes witnessed by CPAI rep.P. Smith. SIMOPS;clean pits and change out bales and LD bale extensions. 9/26/2015 9/26/2015 0.25 INTRM1 CEMENT RURD P Set wear bushing; ID=12.25",OD= 0.0 0.0 01:45 02:00 13.38",L=3.17'per Vetco rep. 9/26/2015 9/26/2015 0.50 INTRMI CEMENT RURD P Install mouse hole in rotary table to LD 0.0 0.0 02:00 02:30 5"DP and PU 5"HW. 9/26/2015 9/26/2015 3.50 INTRM1 CEMENT PULD P PU and LD DP and HWDP in the 0.0 0.0 02:30 06:00 mouse hole; 15 stands of each. SIMOPS;Clean pits,move parts houses 9/26/2015 9/26/2015 2.50 INTRM1 CEMENT WWWH P LD mouse hole,change out PS-21 0.0 0.0 06:00 08:30 slips for 5"DP,MU stack washing tool and flush stack,flush kill lines and mud lines with citric pill. LD stack washer. 9/26/2015 9/26/2015 0.25 INTRM1 CEMENT SFTY P PJSM for FIT/LOT. 0.0 08:30 08:45 9/26/2015 9/26/2015 2.75 INTRM1 CEMENT LOT P RU equipment for LOT. Perform LOT 0.0 0.0 08:45 11:30 on OA;pump 5 SPM to 50 strokes with 500 psi. Shut in for 10 minutes and bled down to 410 psi. Inject to flush OA with 185 BBL of water, 1 BPM with 500 psi,2 BPM with 600 psi, 3 BPM with 710 psi. Shut in OA at 690 psi. Blow down injection lines. SIMOPS;Spot parts houses and continue to load tubing in the casing shed,and continue to clean pits. 9/26/2015 9/26/2015 0.50 INTRM1 CEMENT FRZP P RU Little Red to pump Isotherm freeze 0.0 0.0 11:30 12:00 protect on OA. SIMOPS; Clean Joe's box,clean pits. PJSM with LRS for FP. 9/26/2015 9/26/2015 2.00 INTRM1 CEMENT FRZP P Perform FP on OA with Isotherm via 0.0 0.0 12:00 14:00 LRS. 450 psi on OA initially. With 20 BBL away at 2 BPM 740 psi,40 BBL away 1.8 BPM 840 psi,60 BBL away at 1.45 BPM 880 psi,80 BBL away at 1.7 BPM 950 psi, 100 BBL away 1.4 BPM 990 psi. Total pumped 110 BBL. Shut in with 800 psi on OA. Flush and blow down lines. Isotherm in place at 1330 hours. Crew change 9/26/2015 9/26/2015 2.25 INTRM1 CEMENT SLPC P Slip and cut drill line 1976'. 0.0 0.0 14:00 16:15 9/26/2015 9/26/2015 0.50 INTRMI CEMENT SEQP 'P Calibrate Totco,drawworks,and 0.0 0.0 16:15 16:45 blocks position. 9/26/2015 9/26/2015 1.75 INTRM1 CEMENT BHAH 'P PU and MU BHA for clean out run to 0.0 1,527.0 16:45 18:30 drill shoe track and 20'new hole. Mu BHA with HWDP and RIH to 1527'. Page 15/41 Report Printed: 12/18/2015 „leo 00 Operations Summary (with Timelog•pths) 1C-153 Conooattillps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time '.. End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/26/2015 9/26/2015 2.00 INTRM1 CEMENT TRIP P Trip in the hole from 1527'to 4935' 1,527.0 4,935.0 18:30 20:30 with proper displacement observed. 9/26/2015 9/26/2015 0.50 INTRM1 CEMENT CIRC P Circulate and condition mud whilr 4,935.0 4,935.0 20:30 21:00 rotating and reciprocating. Pump at 600 GPM with 2010 psi,39%FO,80 RPM with 5.5K torque. Pumped 364.5 BBL total with mud in and out 9.1+. PU=159K,SO=129K,Rot=141K. 9/26/2015 9/26/2015 1.50 INTRM1 CEMENT PRTS P Pressure test casing to 3500 psi for 30 4,935.0 4,935.0 21:00 22:30 minutes;Good. Pump 5.6 BBL to pressure up and bled back 5.6 BBL. RD and blow down test equipment and lines. 9/26/2015 9/27/2015 1.50 INTRM1 CEMENT DRLG P Wash and ream down to float and drill 4,935.0 5,042.0 22:30 00:00 float the cement from 5085'. Tag float at 5042'. Tag cement at 5050'. Drill out shoe track plugs with 360 GPM with 870 psi,24%FO,60 RPM with 7.5K torque, 11K WOB. Drill cement with 400 GPM with 1010 psi,25%FO, 80 RPM with 7K torque,8K WOB. 9/27/2015 9/27/2015 1.50 INTRM1 CEMENT DRLG P Continue to drill cement and shoe at 5,042.0 5,137.0 00:00 01:30 5127'to 5128'at 400 GPM with 1008 psi,25%FO,80 RPM with 8K torque and 8K WOB. PU=138K,S0=123K, Rot=127K. Tag shoe at 5128'and drill to 5129'at 400 GPM with 1028 psi,25%FO,80 RPM with 8K torque and 7K WOB. Clean out rat hole to 5137'. 9/27/2015 9/27/2015 0.75 INTRM1 CEMENT DDRL P Drill 6 3/4"production hole from 5137' 5,137.0 5,157.0 01:30 02:15 to 5157'at 400 GPM with 1028 psi, 25%FO,80 RPM with 8K torque and 13K WOB. PU=138K,SO=123K, Rot=127K. ADT=0.5, Bit hours= 3.55,Jar hours=134.43. 9/27/2015 9/27/2015 0.75 INTRM1 CEMENT CIRC P Circulate,Recip and rotate, 1.5x BU 5,157.0 5,157.0 02:15 03:00 and condition mud to 9.1 in and 9.1 out. 100 RPM with 9K torque. PU= 138K,SO=123K,Rot=127K. Pumped total 430 BBL,monitor well for 5 minutes;Static. Blow down top drive. 9/27/2015 9/27/2015 2.00 INTRM1 CEMENT LOT P Perform LOT to 12.1 EMW with 2.0 5,157.0 5,157.0 03:00 05:00 BBLs and bled back 2.1 BBL.Test#1; Pumped at 1/2 BPM for 3.0 BBL to 750 psi at LO,then pumped 1.4 BBL more to insure formation LOT=12.8 EMW. Chart recorder failed on test. Test#2; Pumped at 1/2 BPM for 2.0 BBL to 600 psi for FIT of 12.1 EMW. Chart recorded test and 12.1 EMW was used. 9/27/2015 9/27/2015 4.00 PROD1 DRILL TRIP P POOH with clean out assembly. 5,157.0 0.0 05:00 09:00 Proper fill observed on trip. 9/27/2015 9/27/2015 0.25 PROD1 DRILL BHAH P LD BHA. 0.0 0.0 09:00 09:15 9/27/2015 9/27/2015 1.75 PROD1 DRILL RURD P Clean and clear rig floor. Change out 0.0 0.0 09:15 11:00 Saver sub to 4"XT-39. Monitor hole via TT;static. Page 16/41 Report Printed: 12/18/2015 operations Summary (with Timelog epths) it1C-153 Con000Philtips A�x{n Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code'. Time P-T-X Operation (ftKB) End Depth(ftKB) 9/27/2015 9/27/2015 0.25 PROD1 DRILL SFTY P Hold PJSM for BHA PU and MU with 0.0 0.0 11:00 11:15 rig crew,SLB DD and MWD. 9/27/2015 9/27/2015 0.75 PROD1 DRILL BHAH P PU and MU BHA per SLB DD to 80'. 0.0 80.0 11:15 12:00 Crew change. No losses for day. OAP=320 psi. 9/27/2015 9/27/2015 1.50 PROD1 DRILL BHAH P Continue to PU and MU BHA from 80' 80.0 372.0 12:00 13:30 to 372'per SLB DD and MWD. 9/27/2015 9/27/2015 1.75 PROD1 DRILL PULD P PU doubles from 372'to 2580'from 372.0 2,580.0 13:30 15:15 shed. Proper fill. 9/27/2015 9/27/2015 0.25 PROD1 DRILL DHEQ P Shallow pulse test MWD and 2,580.0 2,580.0 15:15 15:30 directional tools;Good with 220 GPM with 1240 psi, 17%FO. 9/27/2015 9/27/2015 0.50 PROD1 DRILL PULD P PU doubles from 2580'to 3407'from 2,580.0 3,407.0 15:30 16:00 shed. Proper fill. 9/27/2015 9/27/2015 1.50 PROD1 DRILL PULD P PU singles from 3407'to 4925'from 3,407.0 4,925.0 16:00 17:30 shed. Proper fill. 9/27/2015 9/27/2015 0.50 PROD1 DRILL SVRG P Service rig,top drive,blocks and 4,925.0 4,925.0 17:30 18:00 crown. 9/27/2015 9/27/2015 0.75 PROD1 DRILL TRIP P Trip in the hole from the derrick from 4,925.0 5,155.0 18:00 18:45 4925'to 5155'. PU=103K,SO=93K. 9/27/2015 9/27/2015 0.75 PROD1 DRILL CIRC P Wash down last stand and circulate at 5,155.0 5,155.0 18:45 19:30 250 GPM with 1790 psi, 19%FO,50 RPM with 3K torque. 9/27/2015 9/27/2015 1.25 PROD1 DRILL DISP P Displace well to new 9.2 Faze-pro 5,155.0 5,206.0 19:30 20:45 MOBM at 250 GPM with 1650 psi, 19%FO, 120 RPM with 4K torque while drilling ahead once new mud was at the bit from 5155'to 5206'with 2K WOB. PU=102K,SO=92K, Rot=95K. 9/27/2015 9/28/2015 3.25 PROD1 DRILL DDRL P Drill 6 3/4"production hole from 5206' 5,206.0 5,489.0 20:45 00:00 to 5489'at 275 GPM with 1890 psi, 19%FO, 150 RPM with 4K torque and 2K WOB,ECD=9.68. PU=103K, SO=91K,Rot=95K. ADT=3.0, Bit hours=3.0,Jar hours=3.0. Crew change.OAP=50 psi. SPR @ 5200'MD,3863'TVD Mud Wt=9.2 Pump#1 20/30 spm-320/480 psi @ 2050 Pump#2 20/30 spm-340/500 psi 9/28/2015 9/28/2015 6.00 PROD1 DRILL DDRL P Drill 6 3/4"production hole from 5489' 5,489.0 6,090.0 00:00 06:00 to 6090'at 290 GPM with 2190 psi, 20%FO, 180 RPM with 4K torque and 2K WOB,ECD=9.84. PU=105K, SO=88K,Rot=97K. Dump and Dilute 9.2 ppg Faze-Pro at 6095'. SPR @ 5675'MD,3863'TVD Mud Wt=9.2 Pump#1 20/30 spm-400/580 psi© 0125 Pump#2 20/30 spm-400/580 psi Page 17/41 Report Printed: 12/18/2015 operations Summary (with Timelog epths) 08 a 1C-153 Conti o`Philips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth. Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/28/2015 9/28/2015 2.00 PROD1 DRILL DDRL P Continue to Drill 6 3/4"production hole 6,090.0 6,248.0 06:00 08:00 from 6090' to 6248'at 290 GPM with 2190 psi,20%FO,180 RPM with 4K torque and 1K WOB,ECD=9.85. PU=111K,SO=86K,Rot=97K. SPR @ 6242'MD,3854'TVD Mud Wt=9.2 Pump#1 20/30 spm-420/600 psi @ 0745 Pump#2 20/30 spm-420/660 psi 9/28/2015 9/28/2015 0.50 PROD1 DRILL SVRG P Service rig;service IBOP rollers,top 6,248.0 6,248.0 08:00 08:30 drive and blocks. 9/28/2015 9/28/2015 2.00 PROD1 DRILL DDRL P Continue to Drill 6 3/4"production hole 6,248.0 6,438.0 08:30 10:30 from 6248' to 6438'at 290 GPM with 2240 psi,20%FO,180 RPM with 4K torque and 1K WOB,ECD=9.89. PU=111K,SO=86K,Rot=97K. ADT=4.16,Total bit hours=7.06,Jar hours=93.03. 9/28/2015 9/28/2015 1.50 PROD1 DRILL CIRC T Circulate and condition mud,dump 6,438.0 6,438.0 10:30 12:00 and dilute to lower solids content. Rotate and reciprocate from 6438'to 6343'at 290 GPM with 2240 psi,20% FO, 180 RPM with 4K torque. Pumped 557 BBL. Crew change.OAP=220 psi. No losses for tour. 9/28/2015 9/28/2015 6.00 PROD1 DRILL DDRL P Drill 6 3/4"production hole from 6438' 6,438.0 6,931.0 12:00 18:00 to 6931'at 290 GPM with 2210 psi, 19%FO, 180 RPM with 4K torque and 1K WOB,ECD=9.89. PU=111K, SO=87K,Rot=97K. ADT=3.80, Total bit hours=13.76,Jar hours= 99.76. SPR @ 6723'MD,3860'TVD Mud Wt=9.1 Pump#1 20/30 spm-400/640 psi @ 1600 Pump#2 20/30 spm-400/640 psi 9/28/2015 9/29/2015 6.00 PROD1 DRILL DDRL P Drill 6 3/4"production hole from 6931' 6,931.0 7,576.0 18:00 00:00 to 7576'at 290 GPM with 2270 psi, 20%FO, 180 RPM with 5K torque and 1K WOB,ECD=9.81. PU=109K, SO=85K,Rot=96K. ADT=3.95, Total bit hours=17.71,Jar hours= 103.68. SPR @ 7385'MD,3859'TVD Mud Wt=9.0+ Pump#1 20/30 spm-440/640 psi @ 2215 Pump#2 20/30 spm-460/640 psi Crew change.OAP=170 psi. 4 BBL loss for day. Page 18/41 Report Printed: 12/18/2015 operations Summary (with Timelog epths) a 1C-153 Conotailitillips A E:xks Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/29/2015 9/29/2015 6.00 PROD1 DRILL DDRL P Drill 6 3/4"production hole from 7576' 7,576.0 8,135.0 00:00 06:00 to 8135'at 290 GPM with 2270 psi, 20%FO, 180 RPM with 5K torque and 1-2K WOB,ECD=9.82. PU= 112K, SO=83K,Rot=99K. Drill concretions at 7936'MD,8011'MD,8035'MD with 2K WOB, 120 RPM increased WOB to 6K.ART/ADT=3.87hr SPR's @ 7769'MD,3855'TVD with MW=9.1ppg @ 01:50 #1 MP-20/30 SPM=500/700 PSI #2 MP-20/30 SPM=520/730 PSI 9/29/2015 9/29/2015 6.00 PROD1 DRILL DDRL P Drill 6 3/4"production hole from 8135' 8,135.0 8,580.0 06:00 12:00 MD to 8580'MD/3869'TVD at 290 GPM with 2390 psi,20%FO, 180 RPM with 5K torque and 1-4K WOB, ECD=10.12. PU=117K,SO=76K, Rot=98K. Drill concretions at 8126'MD,8300'MD,8035'MD,with 3K increased WOB to 6K and 120RPM, 5K torque. Drill through fault at 8472' MD/3866'TVD.ART/ADT=3.87hr SPR's @ 8240'MD,3863'TVD with MW=9.1ppg @ 07:30 #1 MP-20/30 SPM=530/720 PSI #2 MP-20/30 SPM=520/700 PSI 9/29/2015 9/29/2015 6.00 PROD1 DRILL DDRL P Drill 6 3/4"production hole from 8580' 8,580.0 9,093.0 12:00 18:00 MD to 9093'MD/3835'TVD at 290 GPM with 2560 psi,20%FO, 180 RPM with 5K torque and 1K WOB, ECD= 10.21. PU=120K,SO=79K, Rot=98K.ART/ADT=4.28hr SPR's @ 8714'MD,3856'TVD with MW=9.0ppg @ 13:15 #1 MP-20/30 SPM=490/680 PSI #2 MP-20/30 SPM=530/680 PSI 9/29/2015 9/30/2015 6.00 PROD1 DRILL DDRL P Drill 6 3/4"production hole from 9093' 9,093.0 9,652.0 18:00 00:00 MD to 3839'MD/3835'TVD at 290 GPM with 2560 psi,20%FO, 160 RPM with 6K torque and 1.5K WOB, ECD=10.24. PU=125K,SO=70K, Rot= 100K. ART/ADT=5.23 hr,Total bit hrs=35,Total jars hrs=120.97, Page 19/41 Report Printed: 12/18/2015 OU •perations Summary (with Timelog pths) kz cit 1C-153 C hillrps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/30/2015 9/30/2015 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 9652' 9,652.0 10,186.0 00:00 06:00 MD to 10186'MD,3843'TVD,291 GPM,2550psi,20%F/O, 180 RPM, 5K torque, 1K WOB.ECD=10.22. PU=122K,S/O=72K,ROT=102K,5K torque. ART/ADT=4.19 SPR's @ 9657'MD @ 00:17 with 9.0ppg MW #1 MP-20/30 SPM=540/720psi #2 MP-20/30 SPM=580/840psi SPR's @ 10132'MD @ 05:05 with 9.1ppg MW #1 MP-20/30 SPM=640/880psi #2 MP-20/30 SPM=600/800psi 9/30/2015 9/30/2015 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 10,186.0 10,705.0 06:00 12:00 10186'MD to 10705'MD,3844'TVD, 290 GPM,2783psi,20%F/O, 180 RPM,6K torque, 1-8K WOB. ECD=10.37.PU=123K,S/O=73K, ROT=95K,5K torque. Drill concretions at 10414'MD and 10470'MD with 2K WOB, 120 RPM, 6K torque. Increased WOB to 8K to drill concretions.ART/ADT=4.20 SPR's @ 10610'MD @ 10:57 with 9.1ppg MW #1 MP-20/30 SPM=640/880psi #2 MP-20/30 SPM=600/800psi 9/30/2015 9/30/2015 6.50 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 10,705.0 11,181.0 12:00 18:30 10705'MD to 11181'MD,3847'TVD, 290 GPM,2850psi,20%F/O, 180 RPM,7K torque, 1-2K WOB. ECD=10.48.PU=126K,S/O=66K, ROT=99K,5-6k off bottom torque. ADT=4.55 hrs,Total bit hrs=47.94, Total Jar hrs=133.91 9/30/2015 9/30/2015 0.50 PROD1 DRILL SRVY P Obtain on bottom survey&SPR's. 11,181.0 11,181.0 18:30 19:00 Monitor well 10 min static. SPR's @ 11175'MD,3848'TVD @ 18:45 with 9.1ppg MW #1 MP-20/30 SPM=700/880psi #2 MP-20/30 SPM=620/840psi 9/30/2015 10/1/2015 5.00 PROD1 DRILL PMPO T Pump out of hole from 11181'MD to 11,181.0 7,579.0 19:00 00:00 7579'MD @ 150 gpm 780 psi, 14% flow out,pulling @ 50 fpm.Monitor displacement via pits 2 and 3. Pumping out to casing shoe to perform BOP test while MI builds more FazePro OBM to complete section. 10/1/2015 10/1/2015 4.25 PROD1 DRILL PMPO T Pump out of hole from 7579'MD to 7,579.0 5,115.0 00:00 04:15 5115'MD with GPM=147,PSI=789, F/O 12%,PU=92K. Monitor wellbore through pits 2&3. 10/1/2015 10/1/2015 1.75 PROD1 DRILL CIRC T Rotate and reciprocate from 5115'MD 5,115.0 5,020.0 04:15 06:00 to 5020'MD with GPM=232, PSI=1392,F/0=15%,RPM=100,Off Bottom TQ=3,PU=92K. Page 20/41 Report Printed: 12/18/2015 operations Summary (with Timelog epths) OF 6 1C-153 ConouhiIhps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/1/2015 10/1/2015 0.50 PROD1 DRILL TRIP T PJSM,monitor well for flow.POOH 5,020.0 4,830.0 06:00 06:30 from 5020'MD to 4830'MD. 10/1/2015 10/1/2015 1.50 PROD1 DRILL MPSP T MU Baker 9-5/8"storm packer.Set 4,832.0 4,832.0 06:30 08:00 same at 115.95'MD COE.PUW=102K SOW=93K.RU to test Baker storm packer,500psi for 5min.(Good Test) 10/1/2015 10/1/2015 1.50 PROD1 WHDBOP BOPE P Test BOPE with all tests to 250psi 4,832.0 4,832.0 08:00 09:30 Low and 3500psi High for 5 charted min.with the exception of manual operated and super choke tested to 250psi Low and 2000psi High for 5 charted min. Witnessed by State:Lou Grimaldi. Annular tested with 5-1/2"test jt and 2 -7/8"test jt.(Good Tests) Lower Pipe Ram(LPR)tested with 5- 1/2"test jt and 2-7/8"test jt.(Good Tests) Choke valves 1 through 15,Manual Operated and super choke,Choke& Kill Manuals and HCR's,4"Valve on kill line,4"TIW#1,4"Dart,Upper& Lower iBOPs,Test 4-1/2"IF Dart and TIW,2-7/8"Dart and TIW(Good Tests) 10/1/2015 10/1/2015 6.25 PROD1 WHDBOP BOPE P Test BOPE with all tests to 250psi 4,832.0 4,832.0 09:30 15:45 Low and 3500psi High for 5 charted min.with the exception of manual operated and super choke tested to 250psi Low and 2000psi High for 5 charted min. Witnessed by State (AOGCC):Lou Grimaldi. 5"TIW,5"Dart.Upper&Lower IBOP, Perform koomey drwawdwon, Acc=3000psi.Manifold=1500psi after all functions on bottles. 16 sec for 200psi build with 2 electrical pumps. 117sec to build full system pressure with 2 electric&2 air pumps.Closing times Annular=26sec. Blind/Shears=19 sec.LPR=18sec. Choke HCR=2sec.Kill HCR=2sec. (Good Tests) 10/1/2015 10/1/2015 1.25 PROD1 WHDBOP RURD P Break down and rig down BOP testing 4,832.0 4,832.0 15:45 17:00 equipment.Pull test Plug and install wear bushing.RILDS. 10/1/2015 10/1/2015 1.00 PROD1 DRILL MPSP T MU storm packer retrieval tool and 4,832.0 4,832.0 17:00 18:00 RIH on 1 stand and install TIW.Open equilizing vave of storm packer and check for pressure(slight vacuum). Pull packer and let element relax.Pull storm packer and lay down same. PU=103k,SO=93K. 10/1/2015 10/1/2015 1.50 PROD1 DRILL CIRC T Circulate while rotating and 4,832.0 4,832.0 18:00 19:30 reciprocating to condition mud prior to running back in hole. 10/1/2015 10/1/2015 1.00 PROD1 DRILL SVRG T Service top drive,blocks and crown. 4,832.0 4,832.0 19:30 20:30 Inspect top drive as per NOV safety bulletin alert. Page 21/41 Report Printed: 12/18/2015 operations Summary (with Timelog pths) 1C-153 Cor►oc PhiIhps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth, Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/1/2015 10/1/2015 3.00 PROD1 DRILL TRIP T Trip in hole on elevators from 4820' 4,832.0 11,088.0 20:30 23:30 MD to 11088'MD.P/U=117k, S/O=64k,fill pipe every 2000',monitor displacement via pit#3,no losses or gains. 10/1/2015 10/2/2015 0.50 PROD1 DRILL CIRC T Wash/ream down to 11181'MD, 11,088.0 11,181.0 23:30 00:00 stage pumps up to 290 gpm,2865 psi, 19%flow out, 120 rpm,6k TQ.Begin 200 bbl whole mud dilution and CBU prior to drilling ahead. 10/2/2015 10/2/2015 0.50 PROD1 DRILL CIRC T Rotate and Reciprocate from 11180' 11,181.0 11,181.0 00:00 00:30 MD to 11090'MD with GPM=290, PSI=2980,FO=20%,RPM=120,Off bottom TQ=6K,PU wt=126K,SO wt=66K,ROT wt=100K,Rot TQ=6K 04:16:SPR's @ 11551'MD,3855'TVD MW=9.1 ppg #1 MP-20/30 SPM=740/1000psi #2 MP-20/30 SPM=660/920psi 10/2/2015 10/2/2015 5.50 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 11,181.0 11,675.0 00:30 06:00 11181'MD to 11675'MD,3861'TVD with GPM=290,PSI=2982,FO=20%, RPM=160,TQ=6K,WOB=1K. ECD=10.6oppg. PU wt=124K,SO wt=68K,ROT wt=99K,6K TQ 10/2/2015 10/2/2015 6.00 PROD1 DRILL DDRL P Continue drilling 6-3/4"production 11,675.0 12,224.0 06:00 12:00 hole from 11675'MD to 12,224'MD, 3875'TVD with GPM=290,PSI=3020, F0=20%,RPM=160,TQ=7K, WOB=1K.ECD=10.73ppg.PU wt=125K,SO wt=68K,ROT wt= 95K,5-6K TQ 10/2/2015 10/2/2015 7.00 PROD1 DRILL DDRL P Continue drilling 6-3/4"production 12,224.0 12,825.0 12:00 19:00 hole form 12224'MD to 12825'MD, 3898'TVD(TD called by Geologist) with GPM=290,PSI=3160,FO=20%, RPM=160,TQ=7K,WOB=1K.ECD= 11.04ppg. 10/2/2015 10/2/2015 1.50 PROD1 CASING CIRC P Circulate while rotating and 12,825.0 12,825.0 19:00 20:30 reciprocating from 12825'MD to 12790'MD,GPM=290,PSI=3120, FO=20%,RPM=190,6.5K Tq.Rack back stand and pick up single to recip full stand. 10/2/2015 10/3/2015 3.50 PROD1 CASING CIRC T Continue circulating while rotate and 12,825.0 12,825.0 20:30 00:00 reciprocate from 12824'MD to 12731' MD,290 GPM,3170 psi,20%flow out,7K Tq while waiting for fluid and trucks for whole mud displacement. 10/3/2015 10/3/2015 0.50 PROD1 CASING CIRC T Circulate while rotating and 12,825.0 12,731.0 00:00 00:30 reciprocating from 12824'MD to 12731'MD with GPM=290,PSI=3170, FO=20%,TQ=7K 10/3/2015 10/3/2015 1.75 PROD1 CASING DISP P Displace well with new 9.1pg OBM. 12,731.0 12,731.0 00:30 02:15 Shut pumps down and obtain SPR's Page 22/41 Report Printed: 12/18/2015 operations Summary (with Timelog pths) 0,11,3 1C-153 Conon 'hilgps Ak.A.v Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T X Operation (ftKE) End Depth(ftKB)" 10/3/2015 10/3/2015 7.75 PROD1 CASING BKRM P PJSM for backreaming out of hole 12,780.0 8,812.0 02:15 10:00 (BROOH). Backream out of hole,L/D tope single not in string.Continue BROOH from 12780'MD to 8812'MD at 1500ft/hr with GPM=290, PSI=2510,FO=20%,RPM=140,and TQ=5.4K. 10/3/2015 10/3/2015 2.00 PROD1 CASING BKRM P Continue to BROOH from 8812'MD to 8,812.0 7,768.0 10:00 12:00 7768'MD at 1200fUhr with GPM=290, PSI=2400,FO=20%,RPM=100,and TQ=4K. 10/3/2015 10/3/2015 5.00 PROD1 CASING BKRM P Continue to BROOH from 7768'MD to 7,768.0 5,115.0 12:00 17:00 5115'MD with GPM=290,PSI=2080, FO=20%,RPM=80,and TQ=3.5K. Monitor displacement via pits 2-4. PU=100K,SO=93K. 10/3/2015 10/3/2015 1.00 PROD1 CASING CIRC P CBU while rotating and reciprocating 5,115.0 5,115.0 17:00 18:00 from 5110'MD to 5017'MD with GPM=250,PSI=1530,FO=19%, RPM=100,and TQ=2.5. 10/3/2015 10/3/2015 0.50 PROD1 CASING CIRC P Drop 1.750"activation ball and pump 5,115.0 5,115.0 18:00 18:30 down with 2BPM,370psi. Ball on seat with 214stks and pressure up to 1824psi.Observe well commander open when pressure dropped to 224psi. 10/3/2015 10/3/2015 1.00 PROD1 CASING CIRC P CBU while rotating and reciprocating 5,115.0 5,115.0 18:30 19:30 from 5110'MD to 5017'MD with GPM=550,PSI=2200,FO=31%, RPM=60,and TQ=2.5k.Total strokes pumped 9384. 10/3/2015 10/3/2015 0.50 PROD1 CASING CIRC P Drop 1.750"activation ball and pump 5,115.0 5,115.0 19:30 20:00 down with 2BPM,250psi. Ball on seat with 183stks and pressure up to1840psi.Observe well commander closed when pressure dropped to 395psi.Confirm activation with 2 bpm, 395 psi and MWD detection @ 250 gpm. 10/3/2015 10/3/2015 1.50 PROD1 CASING SLPC P Slip and cut 94'of drill line.Calibrate 5,115.0 5,115.0 20:00 21:30 Amphion,TOTCO,and SLB block height. Concurrent Activity: Clean pits and Mup Pump suction manifolds. 10/3/2015 10/3/2015 0.75 PROD1 CASING BHAH P M/U Baker brush,casing scraper, 5,115.0 5,129.0 21:30 22:15 magnet and 7"Well Commander/ballcatcher,L/D same in piepshed ready to pick up.P/U 2-10' pups in string and RIH to 5129'MD. 10/3/2015 10/3/2015 1.50 PROD1 CASING WAIT T Wait on passing PST on EMS-6800 5,129.0 5,129.0 22:15 23:45 SFMOBM.SIMOPS-Sevice topdrive, clean#2 mud pump suction manifold, clean pits prepare for EMS. 10/3/2015 10/4/2015 0.25 PROD1 CASING TRIP P Trip in hole on elevators from 5129' 5,129.0 5,702.0 23:45 00:00 MD to 5702'MD. SIMOPS-continue cleaning pits for SFMOBM displacement. OA pressure=120 psi Page 23/41 Report Printed: 12/18/2015 Operations Summary (with Timelog•pths) 1C-153 co oc fillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time -:;End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/4/2015 10/4/2015 5.50 PROD1 CASING TRIP P TIH on elevators from 5702'MD to 5,702.0 12,735.0 00:00 05:30 7694'MD(Std 7).MU scaper assembly()in string.Continue TIH to 12735'MD while monitoring displacement on trip tank.PU wt= 130K,SO wt=57K.Fill pipe every 20std. 10/4/2015 10/4/2015 0.25 PROD1 CASING WASH P Wash down last std from 12735'MD to 12,735.0 12,825.0 05:30 05:45 12825'MD.Tag bottom observing no fill. 10/4/2015 10/4/2015 1.25 PROD1 CASING CIRC P CBU from bit with GPM=290,PSI= 12,825.0 12,825.0 05:45 07:00 3150,FO=21%,Rotate and Reciprocate pipe with RPM=60 and TQ=6.4. 10/4/2015 10/4/2015 1.50 PROD1 CASING CIRC P Drop opening ball to open upper Well 12,825.0 12,825.0 07:00 08:30 Comander at the shoe and CBU(x3) from shoe depth @ 5129'MD with GPM=709,PSI=3392,FO=36%, RPM=60,and TQ=6.4. 10/4/2015 10/4/2015 0.50 PROD1 CASING CIRC P Drop closing ball and pump down to 12,825.0 12,825.0 08:30 09:00 close well commander. 10/4/2015 10/4/2015 3.00 PROD1 CASING CIRC T Circulate mud waiting on clean EMS- 12,825.0 12,823.0 09:00 12:00 6800 mud to displace lateral of well while rotating and reciprocating pipe. GPM=166,PSI=1404,FO=14%, RPM=40,and TQ=6.5 10/4/2015 10/4/2015 3.25 PROD1 CASING CIRC T Circulate while rotating and 12,823.0 12,730.0 12:00 15:15 reciprocating pipe from 12823'MD to 12730'MD with GPM=167,PSI= 1400,FO=15%,RPM=40,and TQ=6.5K. MW=9.0ppg PU=126K,SO=65K 10/4/2015 10/4/2015 3.00 PROD1 CASING DISP P Displace well while rotate and 12,730.0 12,730.0 15:15 18:15 reciprocate from 12823'MD to 12730' MD.Pump 127 bbl of 10.1 ppg spacer @ 4 bpm, 1420 psi, 15%flow out. Chase with 375 bbl 9.4 ppg EMS-6800 pff trucks @ 2.5 bpm,1040 psi ICP,4 bpm, 1270 psi FCP.P/U=124k, S/0=72k.Monitor well for 5 min- static. 10/4/2015 10/5/2015 5.75 PROD1 CASING PMPO P Pump out of hole from 12730'MD to 12,730.0 9,068.0 18:15 00:00 9068'MD with 9.4ppg SFOBM @ 1.4 bpm,30 fpm,340 psi,4%flow out. Monitor displacement via strokes pumped vs volume returned. OA pressure=140 psi 10/5/2015 10/5/2015 6.50 PROD1 CASING PMPO P Pump out of hole with 9.4ppg SFOBM 9,068.0 5,129.0 00:00 06:30 from 9068'MD to shoe(5129'MD) with BPM=1.4 BPM,Running Speed=30ft/min,and F0=4%. Monitoring displacement via strokes vs volume returned.PU=100K, SO=91K. Page 24/41 Report Printed: 12/18/2015 •perations Summary (with Timeloglpths) . 1C-153 4:`4 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/5/2015 10/5/2015 5.50 PROD1 CASING OTHR P Super clean all fluid surface 5,129.0 5,129.0 06:30 12:00 equipment as per MI SWACO solids free program:Joe's box,flow lines, shakers and under shakers,mud pumps,suction lines,etc. Concurrent Activity: Change out short charge pump hardline and break down scraper assembly. 10/5/2015 10/5/2015 6.75 PROD1 CASING OTHR P Continue to clean surface lines for 5,129.0 5,129.0 12:00 18:45 SFOBM.Remove hatches and clean flow line,shakers and under shakers, mud pumps,suction lines,etc. SIMOPS-continue stapping,tallying, inspecting completion components, installing hydroform centralizers and stop rings.Finalize lower completion tally and review with engineers. 10/5/2015 10/5/2015 4.25 PROD1 CASING OTHR T Pump EMS-6800 SFOBM over 5,129.0 5,129.0 18:45 23:00 dressed shakers(325's)until a passing PST is obtained. 10/5/2015 10/6/2015 1.00 PROD1 CASING CIRC P Establish circulation while rotate and 5,129.0 5,129.0 23:00 00:00 reciprocate from 5129'MD to 5031' MD,staging up to 230 gpm, 1524 psi, 19%flow out,80 rpm,2.5k TQ,2 bpm=355 psi,3 bpm=585 psi,4 bpm=900 psi,5 bpm=1350 psi.Fluid level had dropped to the wellhead while cleaning up and conditioning surface volume, 12 hrs. OA=100 psi 10/6/2015 10/6/2015 7.00 PROD1 CASING CIRC P Continue circulation while rotate and 5,129.0 5,129.0 00:00 07:00 reciprocate from 5129'MD to 5031' MD,staging up to 290 gpm,2200 psi, 20%flow out,70 rpm,2.5k TQ.Test @ 04:00 plugged off first qt in 61 sec. Install ditch magnets. OA=100 psi 10/6/2015 10/6/2015 5.00 PROD1 CASING CIRC P Drop 1.75"activation ball and open 5,129.0 5,129.0 07:00 12:00 Well Commander,continue circulation increasing rate to 450 gpm,circulating over 325 mesh screens to achieve passing PST.Reduce rotary rpm to 20 rpm and change stop points every 2-4 recip cycles,inspect and clean ditch magnets every 3 hrs,very small size metal,not large quantity. Page 25/41 Report Printed: 12/18/2015 0 •perations Summary (with Timeloglpths) 1C-153 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (E)(E) End Depth(ftKB) 10/6/2015 10/7/2015 12.00 PROD1 CASING CIRC P Continue circulating @ 450 gpm 5,129.0 5,129.0 12:00 00:00 through Well Commander attempting to pass PST.Rotate 20 rpm,recip from 5129'MD to 5131'MD,Reduce rotary rpm to 5 rpm and change stop points every 2-4 recip cycles. Inspect and clean ditch magnets every 3 hrs, still very small size,low quantity-'/<" buildup on magnets in 3 hrs of microscopic steel fuzz. PST results fluctuating; 15:00 hrs: 1st-25 sec,2nd-75 sec, 3rd-126 sec 18:15 hrs: 1st-30.7 sec,2nd-82.91 sec,3rd-116.65 sec 21:05 hrs: 1st-15.83 sec,2nd-24.65 sec,3rd-49.22 sec 24:00 hrs:1st-20 sec,2nd-47.6 sec, 3rd-110 sec/900 ml 24:00 hrs 2nd test:1st-19.05 sec,2nd- 60 sec,3rd-plugged OA pressure=260 psi Total fluid lost today=10 bbl 10/7/2015 10/7/2015 1.25 PROD1 CASING CIRC P Continue circulating EMS-6800 over 5,129.0 5,129.0 00:00 01:15 325 mesh screens for passing PST. Rotating 5 rpm,reciprocating from 5128'-5030'MD,450 gpm 1680 psi, 26%flow out.Test results fluctuating and not passing. 10/7/2015 10/7/2015 0.25 PROD1 CASING CIRC P Drop 1.75"activation ball and close 5,129.0 5,129.0 01:15 01:30 well commander.Obtain SPR's,blow down top drive. 10/7/2015 10/7/2015 0.50 PROD1 CASING OWFF P Monitor well for 30 minutes-static 5,129.0 5,129.0 01:30 02:00 10/7/2015 10/7/2015 3.50 PROD1 CASING TRIP P Lay down both 10'pups,POOH from 5,129.0 189.0 02:00 05:30 5115'MD to 189'MD racking back all 4"DP,HWDP stand and Jar stand. Calc Disp=32 bbl,Actual Disp=39 bbl. 10/7/2015 10/7/2015 1.50 PROD1 CASING BHAH P PJSM,L/D BHA#5,L/D 5"Well 189.0 0.0 05:30 07:00 commander,Drill collars,BHA and bit. 10/7/2015 10/7/2015 1.50 PROD1 CASING RURD P Clean and clear rig floor,get rid of 0.0 0.0 07:00 08:30 BHA and un-needed handling equipmenmt.C/O PS-21 inserts, install mousehole in rotary table. 10/7/2015 10/7/2015 3.50 PROD1 CASING PULD P PJSM,L/D 4"DP,lay down doubles 0.0 0.0 08:30 12:00 and singles into pipe shed using mousehole. Losses for tour=9 bbl. 10/7/2015 10/7/2015 0.50 PROD1 CASING PULD P Continue laying down stands via 0.0 0.0 12:00 12:30 mousehole total 52 laid down 2 x 1. Total 52 doubles in pipeshed mags and 52 singles outside. 10/7/2015 10/7/2015 0.50 PROD1 CASING SVRG P Sevice rig.Verify 52 4"DP doubles in 0.0 0.0 12:30 13:00 pipe shed magazines. 10/7/2015 10/7/2015 7.75 PROD1 CASING PULD P Lay down 4"DP singles 1 x 1 via 0.0 0.0 13:00 20:45 mousehole.Monitor well via trip tank. Page 26/41 Report Printed: 12/18/2015 operations Summary (with Timelogaepths) 03 1C-153 Conon F'hi!bps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation -(ftKB) End Depth(ftKB) 10/7/2015 10/7/2015 0.50 PROD1 CASING OTHR P Move 16 stands 5"HWDP from drillers 0.0 0.0 20:45 21:15 side to off drillers side,put in order for RIH. 10/7/2015 10/7/2015 0.25 PROD1 CASING BOPE P Perform weekly BOPE function test on 0.0 0.0 21:15 21:30 5"DP 10/7/2015 10/7/2015 1.25 PROD1 CASING RURD P Change out saver sub to 4%"IF. 0.0 0.0 21:30 22:45 10/7/2015 10/7/2015 0.75 PROD1 CASING OTHR P PJSM and M/U pup and swivel to ZXP 0.0 0.0 22:45 23:30 liner hanger as per Baker.Lay down in pipe shed. 10/7/2015 10/8/2015 0.50 PROD1 CASING BHAH P M/U Mule shoe, 1 stand 5"DP and 0.0 108.0 23:30 00:00 string magnet to 108'MD. OA pressure=200 psi Total loss for tour=10.7 bbl 10/8/2015 10/8/2015 1.50 PROD1 CASING BHAH P Continue RIH from 108'MD to606'MD 108.0 606.0 00:00 01:30 making up magnets and Well Commander in between stands.Start installing super sliders on stand#2. 10/8/2015 10/8/2015 5.00 PROD1 CASING TRIP P Continue RIH from 606'MD to 5126' 606.0 5,126.0 01:30 06:30 MD installing super sliders on every joint of stands 2-35,HWDP stands 1- 11.Total 135 sliders installed. P/U=161k,S/0=152k.Calc Disp=49.4 bbl,Actual Disp=54.7 bbl. 10/8/2015 10/8/2015 0.25 PROD1 CASING CIRC P Kelly up on last stand,establish 5,126.0 5,126.0 06:30 06:45 circulation and baseline pressure for acid pickle job @ 1 bpm @ 160 psi,2 bpm @ 285 psi. 10/8/2015 10/8/2015 2.25 PROD1 CASING RURD P Rig up to pickle pipe.Rig up SLB 5,126.0 5,126.0 06:45 09:00 hardline,rig up hardline on rig floor. Take on fluid to the pits,build high vis brine spacer.Blow air to SLB trough hardline. 10/8/2015 10/8/2015 0.50 PROD1 CASING SFTY P PJSM on acid pickle with CPAI,SLB, 5,126.0 5,126.0 09:00 09:30 DDI,MI SWACO.Discuss job pump schedule,de-con procedures,SDS, shower trailer,response initiation. 10/8/2015 10/8/2015 1.00 PROD1 CASING WAIT T Wait on SLB to troubleshoot 5,126.0 5,126.0 09:30 10:30 communication lines to pump truck. 10/8/2015 10/8/2015 1.50 PROD1 CASING CIRC P Pump 15 bbl High vis brine to SLB,fill 5,126.0 5,126.0 10:30 12:00 all lines and PT to 2500 psi-Good. SLB start job pumping 5 bbl 9.4 ppg Hi Vis brine spacer,shut down.Rig pumped 8 bbl of DeepClean,folllowed by 6 bbl 9.4 pph Hi Vis spacer and shut down.SLB come on line with 500 gal of 15%HCI acid/9.4 ppg brine. Swap to rig to displace acid to mule shoe @ 1 bpm. Losses for tour=10.1 bbl OA pressure=100 psi Page 27/41 Report Printed: 12/18/2015 Iperations Summary (with Timelog pths) 0,0 1C-153 Conoco Maps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/8/2015 10/8/2015 3.00 PROD1 CASING CIRC P Continue performing acid pickle, 5,126.0 5,126.0 12:00 15:00 displace acid to mule shoe @ 1 bpm, ICP=200 psi,FCP=90 psi.Shut down and close annular,reverse circulate out the acid pickle @ 1 bpm with SFMOBM from rig pits to open top. ICP=40 psi,FCP=145 psi.Choke back return line to maintain 1 bpm. 10/8/2015 10/8/2015 0.50 PROD1 CASING RURD P Blow down and rig down lines.Line up 5,126.0 5,126.0 15:00 15:30 to circulate down drill pipe. 10/8/2015 10/9/2015 8.50 PROD1 CASING CIRC T Circulate while preparing for whole 5,126.0 5,126.0 15:30 00:00 EMS-6800 system displacement @ 6 bpm,390 psi, 19%flow out.Total strokes pumped 30921. Clean pits 3,4 and 5 for new EMS- 6800 returns post displacement.Build 90 bbl HiVis 9.8 ppg EMS-6800/CaCI brine spacer for displacement.Rig up 2 vac trucks new EMS to manifold, directly to rig pump. Losses for tour=14.6 bbl OA pressure=200 psi 10/9/2015 10/9/2015 2.00 PROD1 CASING DISP T Displace well to new EMS-6800 5,126.0 5,126.0 00:00 02:00 SFMOBM.Establish circulation increase rate to 550 gpm 1660 psi,20 rpm-4k Tq for 1/2 bottom up,pump 87.5 bbl Hi Vis EMS @ 9.8 ppg @ 550 gpm,chase with new EMS-6800 from vac truck directly to pump @ 4.8 bpm, 395 psi 16%flow out.Rotate and reciprocate for total of 2 bottoms up, then park pipe for remaining displacement.Observe spacer back at surface on time,and new EMS-6800 on time @ 4300 strokes since spacer pumped.Pump extra 40 bbl EMS, dumping returns.Grab samples for PST and shut down.PST failed. 10/9/2015 10/9/2015 3.50 PROD1 CASING OTHR T Blow down top drive.Super clean 5,126.0 5,126.0 02:00 05:30 surface system from flow box,flow line,remove shaker screens,clean shakers,trays,troughs,mud pump suctions,flush all lines,replace shaker screens with new 325/270 mesh screens. 10/9/2015 10/9/2015 0.50 PROD1 CASING CIRC T Start pumping 200 bbl of the 5,126.0 5,126.0 05:30 06:00 remaining new,passing EMS-6800 directly from truck to mud pumps downhole @ 4.8 bpm 274 psi, 17% flow out.No pipe movement,take sample for PST-flow results have improved but failed. 10/9/2015 10/9/2015 4.25 PROD1 CASING CIRC T Continue circulation from rig pits @ 5,126.0 5,126.0 06:00 10:15 550 gpm, 1541 psi,30%flow out until achieved passing PST both coming out of hole and suction pit—17 sec,18 sec, 19 sec.Shut down and blow down top drive. Page 28/41 Report Printed: 12/18/2015 Summary (with Timeloglpths) Oi: Iperations 1C-153 Corhlbps kk.An Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T X Operation (EKB) End Depth(ftKB) 10/9/2015 10/9/2015 0.25 PROD1 CASING OWFF P Observe well for flow, 15 minutes 5,126.0 5,126.0 10:15 10:30 static-slight drop. 10/9/2015 10/9/2015 1.50 PROD1 CASING TRIP P Pull out of hole from 5126'MD to 5,126.0 3,351.0 10:30 12:00 3351'MD,P/U=117k,S/0=114k, monitor displacement via hole fill from pit 3. Losses for tour=9 bbl OA pressure=120 psi 10/9/2015 10/9/2015 2.75 PROD1 CASING TRIP P Continue POOH from 3351'MD to 3,351.0 606.0 12:00 14:45 606'MD,inspecting supersliders and racking back 5"DP and HWDP. 10/9/2015 10/9/2015 1.75 PROD1 CASING BHAH P Lay down magnets(take pictures-not 606.0 0.0 14:45 16:30 excessivly loaded)and well commander while racking back last 6 stands. 10/9/2015 10/9/2015 1.00 COMPZN CASING RURD P Clear rig floor of magnets,P/U and 0.0 0.0 16:30 17:30 R/U power tongs.Change out elevators and slip inserts. 10/9/2015 10/9/2015 1.00 COMPZN CASING OTHR P Drain stack,P/U and M/U Baker seal 0.0 0.0 17:30 18:30 bore, RS seal assy,liner hanger and ZXP with extension pups as per Baker rep.Rack back in derrick. 10/9/2015 10/9/2015 1.50 COMPZN CASING RURD P R/D single stack power tongs,R/U 0.0 0.0 18:30 20:00 4W handling epuipment.Verify pipe count and jewelry alignment in pipe shed.Transfer Excluder screens from casing shed to pipe shed. 10/9/2015 10/9/2015 0.25 COMPZN CASING SFTY P Pre-job safety meeting with CPAI, 0.0 0.0 20:00 20:15 Doyon rig crew,Baker rep,Doyon casing on running OHSAS liner assy. 10/9/2015 10/9/2015 0.75 COMPZN CASING PUTB P P/U shoe joint and blank joint.R/U 0.0 72.0 20:15 21:00 head pin and cement line,circulate through shoe joint for 10 bbl.Shut down,rig down and check floats- good. 10/9/2015 10/10/2015 3.00 COMPZN CASING PUTB P Run 4W 11.6#L-80 Hydril 563 72.0 1,190.0 21:00 00:00 Excluder screens and 12.6#blanks as per running detail to 1190'MD including Tracer#1,Swell Packer'A' in hole @ 23:35,Swell Packer'B'in hole @ 23:50.Note-Had to use hand slips and open clam shells due to the short base pipe/hydroform on top of screens to enable use of dog collar on first 15 jts. 10/10/2015 10/10/2015 10.50 COMPZN CASING PUTB P Continue running 11.6#L-80 Hydril 1,190.0 7,722.0 00:00 10:30 563 Excluder screens, 12.6#blanks, tracers and swell packers per running order from 1190'MD to 7722'MD. P/U=116k,S/O=83k.Monitor displacement via pit 3.Calc Disp=33.6 bbl,Actual Disp=33.3 bbl.Swell'C': 20:30,Swell'D':04:50,Swell'E': 05:10,Swell'F':07:45,Swell'G': 10:10 hrs. 10/10/2015 10/10/2015 0.50 COMPZN CASING PUTB P Change out handling equipment,run 7,722.0 7,802.0 10:30 11:00 XO and 2 jts of 5W Hydril 563 from 7722'MD to 7802'MD Page 29/41 Report Printed: 12/18/2015 operations Summary (with Timelogpths) 0 1C-153 +ConocoPtailiips ,s Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/10/2015 10/10/2015 1.00 COMPZN CASING RURD P Clean and clear rig floor,change out 7,802.0 7,802.0 11:00 12:00 handling equipment to run 2-7/8"inner string. OA pressure=160 psi Losses for tour=5 bbl 10/10/2015 10/10/2015 1.25 COMPZN CASING RURD P Continue clearing floor,cleaning up 7,802.0 7,802.0 12:00 13:15 screen packaging.R/U to run 2-7/8" inner string. P/U=117k,S/0=101k. 10/10/2015 10/10/2015 4.75 COMPZN CASING PULD P P/U and run 2-7/8"inner string to jt 7,802.0 7,802.0 13:15 18:00 #90,torquing connections to 800- ft/lbs. 10/10/2015 10/11/2015 6.00 COMPZN CASING PULD P Continue P/U and run 2-7/8"6.5#L-80 7,802.0 7,802.0 18:00 00:00 Hydrill 511 inner string per detail from 2627'MD to 7495'MD torquing connections to 800 ft/lbs.P/U=64k, S/O=60k. 10/11/2015 10/11/2015 0.50 COMPZN CASING PULD P Continue running 2-7/8"Hydril 511 7,802.0 7,802.0 00:00 00:30 inner string from 7495'MD to 7756' MD torquing connections to 800 ft/lbs. 10/11/2015 10/11/2015 0.50 COMPZN CASING HOSO P P/U joint 265 and attempt to sting into 7,802.0 7,802.0 00:30 01:00 packoff bushing with slick stinger. P/U=66k,S/O=54k.Tag top of packoff bushing @ 7777'MD,slacked off up to 14k,stacking out solid, unsuccessful stinging in. 10/11/2015 10/11/2015 3.00 COMPZN CASING HOSO T L/D joint 265,P/U 7'pup and make up 7,802.0 7,802.0 01:00 04:00 XO from 2-7/8"H511 back to NC50. Establish pumprate @ 1 bpm 370 psi, rotate 3 rpm 700 fUlbs.Attempt to sting in multiple attempts,stalling out at 1k ft/lbs,picking stinger up 25' several times attempting to determine conclusively we are not stung in.No change in P/U or slack off,or pump pressure until tagging the packoff @ 7777'.Rig down from the 2-7/8",rig up the triple connect to the 2-7/8"and 5- 1/2"liner top to put in tension.XO to NC50 and latch up a stand,RIH with liner(screens)90'to 7892',pull back up to place in tension while rotating the string 180°.Rack back stand. 10/11/2015 10/11/2015 1.00 COMPZN CASING HOSO T Re-rig up false rotary table,change 7,802.0 7,802.0 04:00 05:00 out elevators back to 2-7/8",re-install 7'pup and XO's to NC50,attempt to sting in unsucessful first attempt, tagging packoff now at 7780'MD after placing in tension.Establish circulation,bring pump rate up to 3 bpm 910 psi,rotate 5 rpm.8k Tq,P/U 25'and come down,successfully sting into packoff.No pressure change witnessed.Shut down pump,M/U pups to tag no-go and figure spaceout. Page 30/41 Report.Printed: 12/18/2015 •perations Summary (with Timeloglpths) +a 0 ►ti 1C-153 ConocoPhill ps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) -.Phase Op Code Activity Code Time P-T X Operation (ftKB) End Depth(ftKB)'. 10/11/2015 10/11/2015 2.00 COMPZN CASING HOSO P Lay down pups and jt 264,P/U jt of 2- 7,802.0 7,802.0 05:00 07:00 7/8"EUE-511 XO,M/U FLCV shifting tool,5'pup.M/U to top of inner string and RIH sting into packoff OK.R/D 2- 7/8"handling equipment,change out power tongs to 5W. 10/11/2015 10/11/2015 1.50 COMPZN CASING OTHR T P/U liner hanger/packer assy.Making 7,802.0 7,895.0 07:00 08:30 up to the top of liner,the bottom pup on the hanger assy got egged with the tongs.Changed out double stack tongs to standard tongs,broke out pup on bottom of liner hanger/ZXP assy. Removed the pup,then made up directly to the liner assy,shortening the assembly by 2.07'. 10/11/2015 10/11/2015 0.50 COMPZN CASING OTHR P Mix up Pal Mix and pour into 7,895.0 7,895.0 08:30 09:00 assembly,allow to set 15 min. 10/11/2015 10/11/2015 0.75 COMPZN CASING RUNL P P/U stand of 5"DP,RIH from 7886' 7,895.0 7,925.0 09:00 09:45 MD to 7911'MD.Break out top double on stand#1,M/U 7"Well Commander to top of first single of 5"DP in hole, RIH to 7925'MD.P/U=157k, S/0=104k. 10/11/2015 10/11/2015 0.25 COMPZN CASING CIRC P M/U top drive to DP,pump to ensure 7,925.0 7,925.0 09:45 10:00 flow path @ 2 bpm,640 psi,3 bpm @ 950 psi.Blow down top drive. 10/11/2015 10/11/2015 2.00 COMPZN CASING RUNL P RIH with liner on 5"DP from 7925'MD 7,925.0 10,629.0 10:00 12:00 to 10629'MD,S/O=77k. Fluid lost for tour=4 bbl OA pressure=110 psi 10/11/2015 10/11/2015 2.25 COMPZN CASING RUNL P Continue RIH with liner on 5"DP and 10,629.0 12,807.0 12:00 14:15 5"HWDP with 135 supersliders form 10629'MD to 12687'MD,run 1 stand 5"DP and a single to 12815'MD,P/U to set depth 12807'MD.Filled pipe every 1500',monitor displacement via pits 3&4.P/U=220k,5/0=100k. 10/11/2015 10/11/2015 0.75 COMPZN CASING RURD P Blow down top drive,R/U pup jt,head 12,807.0 12,807.0 14:15 15:00 pin and HP hose.Establish circulation @ 2 bpm 955 psi, 13%flow out. P/U=220k,5/0=98k. 10/11/2015 10/11/2015 1.50 COMPZN CASING PACK P Drop 1"OD phenolic ball,pump down 12,807.0 12,807.0 15:00 16:30 @ 2 bpm,ICP=900 psi,FCP 950 psi, 13%flow out.Ball on seat @ 1024 strokes,increase to 1450 psi and hold 30 seconds. Increase to 2700 psi, slack off to 45k hookload(50k)setting liner hanger.P/U to 50k hookload, increase to 3300 psi,4100 psi,4200 psi with no shear.Bleed pressure to 650 psi.Start pumping at.5 bpm,ball seat sheared @ 4350 psi.P/U noting breakover @ 183k,S/0 to 150k hookload. Liner top @ 4944.13'MD,Liner shoe @ 12807'MD Page 31/41 Report Printed: 12/18/2015 :I 0 0 0 ,perations Summary (with Timelog•pths) 1C-153 Conoco`Fhil ips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/11/2015 10/11/2015 1.00 COMPZN WELLPR DISP P Clean pits,hold PJSM for 12,807.0 12,807.0 16:30 17:30 displacement,mix spacer for displacement. 10/11/2015 10/12/2015 6.50 COMPZN WELLPR DISP P Displace out SFMOBM to 9.2 ppg 12,807.0 12,807.0 17:30 00:00 KCI/NaCl brine.Pump 20 bbl LVT-200 trough both pumps,70 bbl transition spacer both pumps,75 bbl Citric Acid spacer both pumps,40 bbl transition spacer both pumps,followed by 600 bbl filtered 9.2 ppg brine w/1%Safe Break from MI tank farm,followed by 432 bbl filtered 9.2 ppg brine from tank farm.Increased rate per schedule to max 210 gpm 1700 psi. 10/12/2015 10/12/2015 1.00 COMPZN WELLPR DISP P Continue displacing well to 9.2 ppg 12,807.0 12,807.0 00:00 01:00 brine per MI pump schedule until 2 clean samples at surface.Shut down pumps to clean surface equipment. 10/12/2015 10/12/2015 2.00 COMPZN WELLPR OTHR P Clean up shakers,troughs,lines,flow 12,807.0 12,807.0 01:00 03:00 lines,joes box and suction lines. Monitor well keeping full with tank farm charge pump as needed.Waiting on vac truck for cleaning pits and displacement. 10/12/2015 10/12/2015 2.00 COMPZN WELLPR WAIT T Waiting on vac trucks for pit cleaning 12,807.0 12,807.0 03:00 05:00 and displacement,clean pits 3,4 and 5. 10/12/2015 10/12/2015 1.50 COMPZN WELLPR CIRC P Drop 2.115"opening ball to open well 12,807.0 12,807.0 05:00 06:30 commander,pump ball down @ 2 bpm,258 psi,witness tool shift @ 1550 psi.Circulate @ 2 bpm 40 psi to ensure sub is open.Shut down and drop 2.063"OD BHA shut off ball to isolate flow below well commander. Observed no pressure change @ 2 bpm,40 psi. 10/12/2015 10/12/2015 1.75 COMPZN WELLPR WAIT T Shut down,wait on vac trucks for 12,807.0 12,807.0 06:30 08:15 displacement,delayed due flat tire on 1 truck. 10/12/2015 10/12/2015 2.75 COMPZN WELLPR DISP P Pump 75 bbl DeepCleen pill and 54 12,807.0 12,807.0 08:15 11:00 bbl HI Vis HEC pill,swap to tank farm for clean 9.2 ppg brine to mud pumps. Displace at max rate tank farm can feed pumps,353 gpm 560 psi,dump all returns until 100 NTU seen at flowline.Begin live filtration sending returned brine to tank farm,filtering and back downhole.Pump and filter @ 211 gpm,210 psi until 50 NTU at shakers.Total 682 bbl clean brine pumped. Page 32/41 Report Printed: 12/18/2015 •perations Summary (with Timelog pths) 08 0 1C-153 Conon hitups hixFn Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/12/2015 10/12/2015 1.00 COMPZN WELLPR CIRC P Drop first 2.115"closing ball and pump 12,807.0 12,807.0 11:00 12:00 @ 2 bpm,40 psi to push isolation ball into ball catcher,witness ball pass @ 2000 psi.Drop 2nd closing ball to shift Well commander closed,pump down @ 2 bpm,45 psi.Witness tool shift closed @ 1880 psi.Verify closure pumping 2 bpm 260 psi. Losses for tour=234 bbl OA pressure=200 psi 10/12/2015 10/12/2015 1.00 COMPZN WELLPR CIRC P Continue circulating 9.2 ppg filtered 12,807.0 12,807.0 12:00 13:00 brine @ 2 bpm 265 psi,5%flow out establishing dynamic loss rate of 38 bph.Blow down brine feed line from tank farm to rig pump. 10/12/2015 10/12/2015 1.25 COMPZN WELLPR RURD P PJSM with MI,SLB and DDI crew on 12,807.0 12,807.0 13:00 14:15 pumping 9%formic acid job.R/U HP surface lines in cellar.R/U circ lines on rig floor. 10/12/2015 10/12/2015 0.50 COMPZN WELLPR RURD T Break down and re-rig up flowmeter 12,807.0 12,807.0 14:15 14:45 to measure flow from well to either pits or open top tank due mis communication with completion engineer. 10/12/2015 10/12/2015 0.50 COMPZN WELLPR RURD P Flush lines with 9.2 ppg brine from 12,807.0 12,807.0 14:45 15:15 SLB pump unit,PT surface lines- good.Bleed pressure. 10/12/2015 10/12/2015 0.50 COMPZN WELLPR RURD T Re-rig up flow meter due installed 12,807.0 12,807.0 15:15 15:45 reverse of flow direction. 10/12/2015 10/12/2015 2.00 COMPZN WELLPR CIRC P SLB pumped 320 bbl 9.2 ppg 9% 12,807.0 12,807.0 15:45 17:45 Formic acid @ 3.1 bpm 590 psi, getting 2 bpm returns,@ 160 bbl pumped,3.1 bpm 630 psi wiuth 2.5 bpm return flow.FCP @ 3 bpm=530 psi,2 bpm return flow,SLB chase with 10 bbl 9.2 ppg brine to clear lines. 10/12/2015 10/12/2015 0.75 COMPZN WELLPR CIRC P Isolate SLB unit an line up on rig 12,807.0 12,807.0 17:45 18:30 pumps.Chase Formic acid with 108 bbl 9.2 ppg filtered brine from tank farm @ 3 bpm,600 psi, 1.9 bpm returns flow. SIMOPS-Blow down 2"hard line from cellar to pump unit and return line from IA. 10/12/2015 10/13/2015 5.50 COMPZN WELLPR WAIT P Circulate across top of well with 9.2 12,807.0 12,807.0 18:30 00:00 ppg brine from tank farm,fill pit 3 with clean brine to monitor well!.Observe initial loss rate of 48 bph from 18:30 hrs to 20:30 hrs.Monitor well via rig pit 3, 20:30-21:00 hrs=47 bph 21:00-22:00 hrs=48 bph 22:00-23:00 hrs=49 bph 23:00-24:00 hrs=44 bph SIMOPS-Rig housekeeping and planning for Acid job#2. OA pressure @ 24:00=200 psi Page 33/41 Report Printed: 12/18/2015 operations Summary (with TimelogSpths) 0 .fit 1C-153 ConotolPhilhps hfrk.- Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation ;;,,(ftKB) End Depth(ftKB) 10/13/2015 10/13/2015 1.00 COMPZN WELLPR WAIT P Circulate across top of well with 12,807.0 12,807.0 00:00 01:00 9.2ppg filtered Brine from tank farm. Static loss rate of 48 bbls/hr. 10/13/2015 10/13/2015 3.00 COMPZN WELLPR CIRC P PJSM:Pump acid job with 12,807.0 12,807.0 01:00 04:00 Schlumberger(SLB).Close Annular and pump down drill pipe with SLB. Take returns through the IA back to pits. Pump 105 bbls of 9.2ppg Brine with 15%Formic Acid at 3BPM and 560psi. SLB chased with 15bbls of straight Brine. Shut down pumps. Drop and pump down at 2BPM/200psi the 2.115"OD Well Commander Opening ball. Ball on seat after 19.5bbls pumped away. Well commander shifted open @ 1817psi. Confirmed flow path and continue to pump 197 more bbls of 9.2ppg Brine with 15%Formic Acid at 3BPM and 60psi.Chase with 5bbls of straight Brine and shut down.Break down SLB. 10/13/2015 10/13/2015 0.50 COMPZN WELLPR CIRC P Chase acid down with 69bbls of 12,807.0 12,807.0 04:00 04:30 filtered 9.2ppg Brine from MI Swaco tank farm using rig pump at 3BPM, 110psi. Returns thorught IA back to pits. 10/13/2015 10/13/2015 0.50 COMPZN WELLPR RURD P Fill Pit#3 with Filtered Brine from tank 12,807.0 12,807.0 04:30 05:00 farm.Break down MI Swaco Lines. 10/13/2015 10/13/2015 4.00 COMPZN WELLPR WAIT P Let acid soak. Concurrently,circulate 12,807.0 12,807.0 05:00 09:00 across top of well with 9.2ppg filtered Brine from tank farm. Initial static loss rate=36 bbls/hr. Perform PMs and housekeeping 10/13/2015 10/13/2015 2.50 COMPZN WELLPR CIRC P Drop and pump down 2.115"OD Well 12,807.0 12,807.0 09:00 11:30 Commander Closing ball at 2BPM/60psi. Ball did not seat. Continue to keep hole full while waiting on orders from town.Ball seated after 2343stks.Well Commander closed at 1860psi. 10/13/2015 10/13/2015 5.25 COMPZN WELLPR CIRC P Circulate BU with 9.2ppg filtered brine 12,807.0 12,807.0 11:30 16:45 to displace Formic acid contaminated Brine to Open Tank @ 3BPM,550psi. (1363stks).Divert returns to pits at 6BPM,ICP=1560psi,FCP=1840psi, FO=12%,for 2384stks.Divert back to Open Tank while staging pump to 5.5BPM,ICP=1500psi,FCP=1900psi for total displacment stk's of 12652. Page 34/41 Report Printed: 12/18/2015 0 •perations Summary (with Timeloglpths) 4.3 1C-153 Conoao`Philkps Rkr.1,, Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code. Time P-T X Operation (ftKB) End Depth(ftKB) 10/13/2015 10/13/2015 2.25 COMPZN WELLPR OWFF T Isolate IA and open annular and 12,807.0 12,807.0 16:45 19:00 observed well flow back,gain of l ObbI. F0=11%. Close Annular and monitor pressures.ISICP stabilized @ 52psi and ISITP @ 80psi.Continue to monitor pressures,observing a decrease in SICP. Line up to Gas Buster and open choke to 1/4 open. Bleed back 10 bbl.Shut in well and monitor pressures.SICP and SITP were 17psi and 20psi respectively. Perform Exhale Test by opening choke to Gas Buster for 50min.Flow indicated a decreasing trend from 0.38BPM to OBPM with a total of 12bbl bled back in the 50min.No flow observed for 15min.Open annular and monitor well for additional 15min.No flow,determined:wellbore breathing. 10/13/2015 10/13/2015 0.50 COMPZN WELLPR RURD P Break down choke.Rig down 12,807.0 12,807.0 19:00 19:30 circulating equipment and head pin. Hold PJSM for setting ZXP Packer. 10/13/2015 10/13/2015 0.25 COMPZN WELLPR PACK P Set ZXP packer as per Baker Oil Tool 12,807.0 12,807.0 19:30 19:45 Rep.PU 7'observing breakover @ 185K,with 1K TQ held on string. Slack off to 65K below SO wt of 135K to 70K Hookload.Repeat and PU to neutral weight to perform packer test. 10/13/2015 10/13/2015 2.50 COMPZN WELLPR PRTS P PJSM for ZXP Packer test. Pressure 12,807.0 12,807.0 19:45 22:15 test Liner Top Packer to 1500psi/30min.Troubleshoot pressure drop seen on chart recorder. Bleed off pressure and retest Liner Top Packer to 1500psi/3omin.(Good Test) 10/13/2015 10/13/2015 0.75 COMPZN WELLPR PULD P Lay down single jt of DP and rig up 12,807.0 12,771.0 22:15 23:00 circulating equipment.Break down Kill line and test pump. Change out mud manifold bleeder valves. 10/13/2015 10/14/2015 1.00 COMPZN WELLPR CIRC P Pump 30bbls of Citric Acid pill from Pit 12,771.0 12,771.0 23:00 00:00 #4 at 3BPM,435psi,FO=10%,and spot with 119bbls of filtered Brine from tank farm at 3BPM,445 psi,and FO=11%. 10/14/2015 10/14/2015 0.75 COMPZN WELLPR CIRC P Finish spotting Citric Pill,pump 9.2ppg 12,778.0 12,778.0 00:00 00:45 Brine down string @ 126 GPM, 438psi.Shut down,Break down lines from MI Swaco Tank Farm. 10/14/2015 10/14/2015 0.25 COMPZN WELLPR TRIP P POOH from 12778'MD to 12764'MD 12,778.0 12,764.0 00:45 01:00 to actuate AB1 shifting tool and activate Fluid Loss Control Valve (FLCV).PU wt= 175k,witness 8k over pull to 183k when valve shifted. Page 35/41 Report Printed: 12/18/2015 Iterations Summary (with Timelog epths) 1C-153 Conoaatilhps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/14/2015 10/14/2015 1.75 COMPZN WELLPR PULD P Continue to POOH sideways from 12,764.0 11,157.0 01:00 02:45 12764'MD to 11157'MD,laying down 5"HWDP and removing Super Sliders on the way out. PU wt=142k,monitor holefill via Pit#3,Calculated Displacement=26.7bbls,Actual Displacement=75bbls. Loss Rate=—31 bbls/hr 10/14/2015 10/14/2015 2.50 COMPZN WELLPR PULD P Continue POOH from 11157'MD to 11,157.0 9,075.0 02:45 05:15 9075'MD,laying down 33,5"DP doubles into shed and store in pipe tubs. PU wt=88k,monitor holefill via Pit#3,Calculated Displacemet= 15bbls,Actual Displacement=63bbls. Loss Rate=—25bbl/hr 10/14/2015 10/14/2015 0.75 COMPZN WELLPR CIRC P Pump 30bbls of 9.2ppg Citric Pill, 9,075.0 9,075.0 05:15 06:00 chase with 66bbls of 9.2ppg Filtered Brine and spot in well with 168 GPM, 649psi. Break down MI Swaco Lines coming from Tank Farm. 10/14/2015 10/14/2015 2.00 COMPZN WELLPR PULD P Continue to POOH from 9075'MD to 9,075.0 7,862.0 06:00 08:00 7862'MD,laying down 5"DP singles into pipe shed.PU wt=66k.Monitor hole fill via Pit#3.Calculated Displacement=6.8bbls,Acutal Displacement=60.6bbls. Loss Rate—28bbls/hr. 10/14/2015 10/14/2015 2.00 COMPZN WELLPR RURD P Rig Up double stack power tongs and 7,862.0 7,862.0 08:00 10:00 2-7/8"handling equipment.Lay down Packer running assembly. 10/14/2015 10/14/2015 2.00 COMPZN WELLPR PULD P Continue to POOH rom 7862'MD to 7,862.0 5,771.0 10:00 12:00 5771'MD,laying down 2-7/8"Hydril 511 inner string.PU wt=61k.Monitor hole fill via Pit#3.Calculated Displacement=4.4bbbls,Actual Displacement=57.4bbls. Loss Rate=29.3bbls 10/14/2015 10/14/2015 1.25 COMPZN WELLPR CIRC P Rig Up circulating equipment on 2-7/8" 5,771.0 5,771.0 12:00 13:15 stump,pump 40bbl Citric Acid pill and spot with 30bbl of 9.2ppg Filtered Brine @ 3BPM,410psi,FO=11%.Rig Down circulating equipment. 10/14/2015 10/14/2015 0.50 COMPZN WELLPR RURD P Rig Down X/O extensions on Triple 5,771.0 5,771.0 13:15 13:45 Connect X/O,MU and torque Well Commander Circulating sub together and move off rig floor. 10/14/2015 10/14/2015 1.50 COMPZN WELLPR PULD P POOH laying down 2-7/8"Hyd 511 5,771.0 4,898.0 13:45 15:15 inner string from 5771'MD to 4898' MD.Monitor displacement and losses via Pit#3.Monitor well for 30min to verify FLCV is closed.(Well Static) 10/14/2015 10/14/2015 0.75 COMPZN WELLPR CRIH P Rig Up circulating equipment,pump 4,898.0 4,898.0 15:15 16:00 40bbl corrosion inhibitor pill.Spot with 26bbls of 9.2ppg Filtered Brine at 3BPM,334psi,FO=13%.Rig Down circulating equipment. Page 36/41 Report Printed: 12/18/2015 Operations Summary (with Timelog Depths) 0 1C-153 Con000`F'hillps h&ssa Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P T-X Operation (ftKB) End Depth(ftKB) 10/14/2015 10/14/2015 4.75 COMPZN WELLPR PULD P Continue POOH and laying down 2- 4,898.0 0.0 16:00 20:45 7/8"inner string from 4898'MD to surface. Monitor displacement via Trip Tank. 10/14/2015 10/14/2015 0.25 COMPZN WELLPR PULD P Change out slip inserts and elevators. 0.0 0.0 20:45 21:00 RIH with 3 stds of 5"DP from derrick. POOH laying out singles. 10/14/2015 10/14/2015 1.25 COMPZN WELLPR SLPC P Perform PJSM for Slip/Cut of Drill line. 0.0 0.0 21:00 22:15 Perform Slip/Cut of Drill Line(74ft). Calibrate TOTCO and Amphion block height Concurrent Operation: PM's for Top Drive 10/14/2015 10/14/2015 0.50 COMPZN WELLPR SVRG P Perform semi-annual block inspection, 0.0 0.0 22:15 22:45 service and inspect top drive and blocks. 10/14/2015 10/14/2015 0.50 COMPZN RPCOMP RURD P Pull Wear Bushing.MU flushing sub 0.0 0.0 22:45 23:15 and flush stack.Lay down sub and double 5"DP. Break down top drive. 10/14/2015 10/15/2015 0.75 COMPZN RPCOMP RURD P Drain stack,PU 4-1/2"test pup and 0.0 0.0 23:15 00:00 set same 10/15/2015 10/15/2015 1.00 COMPZN WHDBOP RURD P Finish rigging up to test BOPE 0.0 0.0 00:00 01:00 10/15/2015 10/15/2015 3.75 COMPZN WHDBOP BOPE P Test BOPE for all tests at 0.0 0.0 01:00 04:45 Low=250psi/5min,High=3500psi/5min w/exception to Man.Operated& Super choke tested to Low=250psi/5min, High=2000psi/5min. Used 4-1/2"test jt to test annular,2-7/8"x 5-1/2"LPR, choke valves 1-15,Manual Operated and Super choke,Choke and Kill manuals and HCR's,4"valve on kill line,4"TIW#1 &TIW#2,4"Dart,5" TIW and 5"Dart,upper and lower IBOP's, Witness by State waived by Bob Noble 10/13/2015. Perform Koomey drawdown: Accumulator Pressure:2960psi, Manifold Pressure: 1500psi,6 Nitrogen bottles,21sec for 200psi build with 2 electric pumps. 115sec to build full system pressure with 2 electric pumps and 2 air pumps. Closing times for Annular=23 sec, UPR=18sec,Blind/Shears=16sec, LPR=16sec,Choke HCR=2sec.and Kill HCR=2sec. 10/15/2015 10/15/2015 0.75 COMPZN WHDBOP RURD P Pull test plug,blow down top drive,kill 0.0 0.0 04:45 05:30 line,choke manifold.Get excess equipment off rig floor and clean floor. 10/15/2015 10/15/2015 2.50 COMPZN RPCOMP RURD P RU to run 4-1/2"completion tubing. 0.0 0.0 05:30 08:00 Get handling equipment to floor,lay down PS-21 power slips,install master bushings,PU Baker equipment and Schlumberger control line equipment. Page 37/41 Report Printed: 12/18/2015 •a °'Of Operations Summary (with Timelog Depths) 1C-153 Conoco Philips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/15/2015 10/15/2015 2.00 COMPZN RPCOMP PUTS P TIH from surface to 640'MD,making 0.0 640.0 08:00 10:00 up 4-1/2"IBT and 5-1/2"VAM Top. Baker and Access jewelry up as per Tally.PU=47k,SO=47k. 10/15/2015 10/15/2015 2.00 COMPZN RPCOMP ALFT P Pump out stack. Access personnel 640.0 640.0 10:00 12:00 make up Power Lead Extension(PLE) cable into motor shroud and install cannon clamps and bands to secure cable to tubing. 10/15/2015 10/15/2015 2.00 COMPZN RPCOMP WAIT T Waiting on Baker Centrilift Tech Wire 640.0 640.0 12:00 14:00 Spool and Spooler Concurrently,install Cavin Air slips, Lay down Power Tongs and RU Double Stack Tongs,lay down Baker Tech wire spool(insufficient wire on spool),lay down misc.equipment from rig floor. 10/15/2015 10/15/2015 2.00 COMPZN RPCOMP WAIT T Rig mechanic fabricate shaft bushing 640.0 640.0 14:00 16:00 for Baker Spooler.Mobilize new tech wire spool and spooler to rig floor. Install shaft bushing and tech wire spool onto spooler. 10/15/2015 10/15/2015 1.25 COMPZN RPCOMP RURD P RU and secure tech wire and sheave 640.0 640.0 16:00 17:15 in derrick. Hoist ESP cable for spooling unit to rig floor.RU and secure ESP cable through sheave in derrick. 10/15/2015 10/15/2015 0.25 COMPZN RPCOMP ALFT P MU gas vent and RIH from 640'MD to 640.0 655.0 17:15 17:30 655'MD determing PLE splice length. PU wt=52k,SO wt=46k.Monitor well via Trip Tank. 10/15/2015 10/15/2015 1.75 COMPZN RPCOMP ALFT P Splice ESP cable.Monitor well via trip 655.0 655.0 17:30 19:15 tank. 10/15/2015 10/15/2015 1.75 COMPZN RPCOMP PUTB P RIH with jt#17 and Baker Gauge 655.0 710.0 19:15 21:00 Carrier to 710'MD.Install TEC wire to gauge carrier.MU jt#18 and monitoring well/displacement via trip tank. 10/15/2015 10/16/2015 3.00 COMPZN RPCOMP RCST P SpliceTEC wire toTEC wire spool. 710.0 710.0 21:00 00:00 Monitor well via trip tank noting 1.2 bbl/hr static loss. 10/16/2015 10/16/2015 1.25 COMPZN RPCOMP ALFT P Finish splicing TEC wire with TEC 710.0 710.0 00:00 01:15 spool.Monitor well via trip tank. Average Loss rate=1.2bbl/hr 10/16/2015 10/16/2015 2.75 COMPZN 'RPCOMP PUTB P RIH from 710'MD to 1564'MD with 4- 710.0 1,564.0 01:15 04:00 1/2"IBT, 12.6ppf tubing to joint 46. PU=73k,SO=75k. Monitor displacement viat trip tank. Calulated displacement=3.25bbls,Actual displacement=1.8bbls. Average Loss rate=1.7bbl/hr 10/16/2015 10/16/2015 1.25 COMPZN RPCOMP ALFT P Rig up to run Halliburton Slick line, 1,564.0 1,564.0 04:00 05:15 RIH with slick line on 3.80"drift tool. Tag up on No-Go.POOH with slickline.Rig down slickline. Page 38/41 Report Printed: 12/18/2015 Operations Summary (with Timelog Depths) 0 1C-153 Cont. 'hiIhps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/16/2015 10/16/2015 1.25 COMPZN RPCOMP ALFT P PU jt.47 loaded with motor.MU jt and 1,564.0 1,601.0 05:15 06:30 RIH from 1564'MD to 1601'MD. PU=74k,SO=76k.Pick motor out of jt in slips,ACCESS ESP test fire actuator and inspect motor assembly. Run motor back into jt. 10/16/2015 10/16/2015 2.50 COMPZN RPCOMP ALFT P RU Halliburton slick line.MU slick line 1,601.0 1,601.0 06:30 09:00 tools.Run motor assembly,ESP Pump and pack-off in tubing on slick line and set each in place on 3 separate slick line trips. 10/16/2015 10/16/2015 1.00 COMPZN RPCOMP PRTS P RU on tubing with testing equipment 1,601.0 1,601.0 09:00 10:00 to pressure test pack off and tubing to 2000psi and hold for 30min.Recorded on test chart.Rig down testing equipment. 10/16/2015 10/16/2015 0.50 COMPZN RPCOMP ALFT P Set tubing stop with slick line and rig 1,601.0 1,601.0 10:00 10:30 down Halliburton slick line equipment. 10/16/2015 10/16/2015 3.00 COMPZN RPCOMP PUTB P RIH from 1601'MD to 2604'MD, 1,601.0 2,604.0 10:30 13:30 running 4-1/2"IBT, 12.6ppg tubing s per running order.PU=75k,SO=76k. 10/16/2015 10/16/2015 1.00 COMPZN RPCOMP ALFT P RU and run 3.80"drift via Halliburton 2,604.0 2,604.0 13:30 14:30 slick line unit from 2604'MD to tubing stop.R/D sheaves.Monitor well via trip tank. 10/16/2015 10/16/2015 2.25 COMPZN RPCOMP PUTB P RIH with 4-1/2"IBT, 12.6ppf tubing 2,604.0 3,600.0 14:30 16:45 from 2604'MD to 3600'MD.Monitor displacement via trip tank.PU=87k, SO=84k. 10/16/2015 10/16/2015 0.75 COMPZN RPCOMP ALFT P RU and run 3.80"drift via Halliburton 3,600.0 3,600.0 16:45 17:30 slick line unit.R/D sheaves.Monitor well via trip tank. 10/16/2015 10/16/2015 2.25 COMPZN RPCOMP PUTB P RIH with 4-1/2"IBT, 12.6ppf tubing 3,600.0 4,619.0 17:30 19:45 from 3600'MD to 4619'MD.Monitor displacement via trip tank.PU=93k, SO=88k. 10/16/2015 10/16/2015 0.75 COMPZN RPCOMP ALFT P RU and run 3.80"drive via Halliburton 4,619.0 4,619.0 19:45 20:30 slick line unit.Rig down sheaves. Monitor well via trip tank. 10/16/2015 10/16/2015 0.50 COMPZN RPCOMP PUTB P RIH with 4-1/2"IBT, 12.6ppf tubing 4,619.0 4,768.0 20:30 21:00 from 4619'MD to 4768'MD.Monitor displacement via trip tank.PU=91 k, SO=86k. 10/16/2015 10/16/2015 0.50 COMPZN RPCOMP PUTB T Make unexpected TEC wire splice due 4,768.0 4,768.0 21:00 21:30 to damaged wire coming off of spool 10/16/2015 10/16/2015 0.50 COMPZN RPCOMP PUTB P RIH with 4-1/2"IBT, 12.6ppf tubing 4,768.0 4,975.0 21:30 22:00 from 4768'MD tagging No-Go @ 4975'MD.2k drag noted when entering bore seal.Monitor displacement via trip tank.PU=92k, SO=87k. 10/16/2015 10/17/2015 2.00 COMPZN RPCOMP HOSO P POOH laying down jt's#164 through 4,768.0 4,811.0 22:00 00:00 #157,space out upper completion with pup#7(3.80'),#10(3.90),#6(5.64') and#1 (9.81').RIH to 4811'MD. Page 39/41 Report Printed: 12/18/2015 gperations Summary (with Timelogtepths) 1C-153 ConocoPhirl ps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/17/2015 10/17/2015 1.50 COMPZN RPCOMP RURD P Swap power tongs to 5-1/2"ECKELS, 4,811.0 4,926.0 00:00 01:30 swap elevators to 5-1/2",MU 4-1/2"x 5-1/2"XO,RIH from 4811'MD to 4926'MD. PU wt=92k,SO wt=87k. Monitor displacement via Trip Tank. 10/17/2015 10/17/2015 1.00 COMPZN RPCOMP ALFT P PJSM,RU slickline and drift tubing 4,926.0 4,926.0 01:30 02:30 with 3.80"drift to 400'Halliburton Slickline depth. 10/17/2015 10/17/2015 3.00 COMPZN RPCOMP ALFT P MU landing jt,splice TEC wire and 4,926.0 4,926.0 02:30 05:30 ESP cable to hanger,perform electrical integrity test on ESP cables and TEC wire. 10/17/2015 10/17/2015 1.50 COMPZN RPCOMP THGR P Drain BOP stack,land Tubing Hanger, 4,926.0 0.0 05:30 07:00 PU wt=97k,SO wt=90k.Run in lock down screws,test hanger seals to 5000psi for 15min.Test witnessed by CPAI Well Site Lead(Lee Martin)and CPAI Completion Engineer(Mick Davasher). 10/17/2015 10/17/2015 1.50 COMPZN RPCOMP CIRC P RU to pump down tubing,pump 0.0 0.0 07:00 08:30 1.7bbl,shear SOV valve at 2948psi, pump 1 BPM,70psi to confirm circulation.Lay down landing jt and blow down. 10/17/2015 10/17/2015 2.50 COMPZN WHDBOP MPSP P MU T-bar,set Vetco Back Pressure 0.0 0.0 08:30 11:00 Valve(BPV),test from below to 1500psi for 5min,bleed off at 5opsi/min.RD test equipment,blow down choke,kill,injection line,and hole fill. 10/17/2015 10/17/2015 4.00 COMPZN WHDBOP NUND P PJSM for nippling down BOPE.Nipple 0.0 0.0 11:00 15:00 down BOPE,break all flange connections,move stack,PU and lay down riser to BOP deck.Pull 8" extension to rig floor.Blow down mud line,remove kelly hose and re-direct man rider cable,pull SSV from cellar and exchange for correct SSV, Concurrently: Load and strap 1 row of DP into casing shed. Prep rig floor for scoping and skidding. 10/17/2015 10/17/2015 2.50 COMPZN WHDBOP NUND P Lower tree to cellar,NU tree and 0.0 0.0 15:00 17:30 associated valves,terminate TEC wire and test Access ESP cable.Prepare derrick for scope down,bridal up blocks,blow down water lines, disconnect non-required lines at interconnect. Lower and secure lubricator in BOP deck. 10/17/2015 10/17/2015 0.50 COMPZN WHDBOP PRTS P Test tree void and seals to 5000psi for 0.0 0.0 17:30 18:00 15min. Concurrently,scope derrick down. 10/17/2015 10/17/2015 2.00 COMPZN WHDBOP MPSP P MU T-bar and pull BPV,install Two 0.0 0.0 18:00 20:00 Way Check Valve(TWC),Pin top drive and blocks,swap power from Highline to Rig Generator power. Secure topdrive bails and energy track for lowering derrick. Page 40/41 Report Printed: 12/18/2015 Operations Summary (with Timelog Depths) 3 1 C-1 53 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/17/2015 10/17/2015 1.50 COMPZN WHDBOP PRTS P PJSM,RU test equipment,fill tree with 0.0 0.0 20:00 21:30 diesel and pressure test tree for 250psi/5min and 5000psi for 15mins. 10/17/2015 10/17/2015 0.50 COMPZN WHDBOP FRZP P Rig down test equipment and pull 0.0 0.0 21:30 22:00 TWC,RU circulating hoses in cellar for freeze protect and u-tube. 10/17/2015 10/18/2015 2.00 COMPZN WHDBOP FRZP P Pump 140bbls,80deg F diesel down 0.0 0.0 22:00 00:00 IA taking returns through tubing to pits @ 1.6BPM,300psi ICP,570psi FCP, Line up to U-tube @ 23:58hr, IA=150psi,Tubing=150psi,OA= 200psi Concurrently: Lower cattle chute to pipe shed. 10/18/2015 10/18/2015 1.50 COMPZN WHDBOP FRZP P U-tube diesel. IA=150psi,Tbg=175psi, 0.0 0.0 00:00 01:30 OA=200psi. Concurrently,spool 10 wraps off draworks drum,blow down steam to rig floor,RU sheave for handling lubricator in BOP deck. 10/18/2015 10/18/2015 1.50 COMPZN WHDBOP MPSP P SI tbg and IA,80psi,bleed from 80psi 0.0 0.0 01:30 03:00 to 78psi=3.8bbls.Bleed from 78psi to 64psi=3bbls. RU lubricator,install Back Pressure Valve(BPV) Final OA=200psi,Tbg=64psi,and IA=64psi. *Rig Release: 10-18-2015,03:30 10/18/2015 10/18/2015 0.50 DEMOB MOVE MOB P *Rig Release: 10-18-2015,03:30 0.0 0.0 03:00 03:30 Page 41/41 Report Printed: 12/18/2015 • REVISED 5:04 pm, Dec 15, 2015 NADConversion Kuparuk River Unit Kuparuk 1C Pad 1C-153 Definitive Survey Report 25 November, 2015 NAD 27 • Schlumberger III Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-153 Project: Kuparuk River Unit TVD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 2f Site: Kuparuk 1C Pad MD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 2t Well: 1C-153 North Reference: True Wellbore: 1C-153 Survey Calculation Method: Minimum Curvature Design: 1C-153 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1C-153 Well Position +N/-S 0.00 usft Northing: 5,968,939.48 usfl Latitude: 70° 19'32.426 N +E/-W 0.00 usft Easting: 561,894.98 usfl Longitude: 149°29'53.119 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 57.60 usft Wellbore 1C-153 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2015 9/21/2015 18.95 80.99 57,506 Design , : : .. 1C-153 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 40.33 Vertical Section: Depth From(TVD) poi +NI-S +E/-W ..,;(3-4 on 111,..--'47 + ° (usft) yt, (usft) (usfl) _ a. x ,,� . 40.33 0.00 0.00 355.00 x Survey Program Date From To �� _�,,,�. ,.. ' ,, (usft) (usft) Survey(Wellbore) Tool Name Description ;.4.4, 'Survey Date 78.31 735.51 1C-153 Srvy#1 -GYD-GC-SS(1C-153) GYD-GC-SS Gyrodata gyro single shots 9/22/2015 8:5: 793.29 2,757.10 1C-153 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/22/2015 8:5 2,820.54 5,058.28 1C-153 Srvy#3-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/22/2015 9:01 5,144.73 12,761.91 1C-153 Srvy#4-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/5/2015 9:0'. Surve ,t- 'la' #* m .! ,'tri t:at _ _ ce47. ,91143f i 0 x "1 " 'A ' Map Map' ,„ MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS t - *. (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) , (ft) (°/100') .(ft) Survey Tool Name 40.33 0.00 0.00 40.33 -57.60 0.00 0.00 5,968,939.48 561,894.98 0.00 0.00 UNDEFINED 78.31 0.64 128.57 78.31 -19.62 -0.13 0.17 5,968,939.35 561,895.15 1.69 -0.15 GYD-GC-SS(1) 120.00 0.42 100.85 120.00 22.07 -0.31 0.50 5,968,939.18 561,895.48 0.80 -0.35 (NOT an Actual Sunray 20"z34" w _.__. .. ._,_,.... .. 172.94 0.44 41.63 172.94 75.01 -0.19 0.82 5,968,939.30 561,895.80 0.80 -0.26 GYD-GC-SS(1) 267.22 1.31 22.36 267.20 169.27 1.08 1.47 5,968,940.57 561,896.44 0.96 0.94 GYD-GC-SS(1) 363.97 2.65 27.23 363.89 265.96 4.09 2.92 5,968,943.59 561,897.86 1.39 3.82 GYD-GC-SS(1) 459.27 5.75 18.89 458.93 361.00 10.57 5.47 5,968,950.09 561,900.36 3.31 10.05 GYD-GC-SS(1) 551.31 8.32 17.90 550.27 452.34 21.27 9.01 5,968,960.82 561,903.81 2.80 20.40 GYD-GC-SS(1) 641.81 12.22 31.18 639.31 541.38 35.70 15.98 5,968,975.31 561,910.67 5.01 34.17 GYD-GC-SS(1) 735.51 14.98 35.49 730.38 632.45 54.05 28.15 5,968,993.75 561,922.68 3.14 51.39 GYD-GC-SS(1) 11/25/2015 9:23:08AM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-153 Project: Kuparuk River Unit TVD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 2°:'' Site: Kuparuk 1C Pad MD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 28i Well: 1C-153 North Reference: True f Wellbore: 1C-153 Survey Calculation Method: Minimum Curvature Design: 1C-153 Database: OAKEDMP2 Survey Map MapVertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 793.29 15.48 42.83 786.13 688.20 65.78 37.73 5,969,005.57 561,932.16 3.44 62.25 MWD+IFR-AK-CAZ-SC(2) 888.22 14.53 47.41 877.83 779.90 83.13 55.11 5,969,023.06 561,949.40 1.60 78.02 MWD+IFR-AK-CAZ-SC(2) 983.33 14.15 46.96 969.98 872.05 99.14 72.39 5,969,039.21 561,966.54 0.42 92.46 MWD+IFR-AK-CAZ-SC(2) 1,077.89 18.38 42.62 1,060.73 962.80 118.01 90.94 5,969,058.23 561,984.94 4.65 109.64 MWD+IFR-AK-CAZ-SC(2) 1,171.77 21.47 44.38 1,148.98 1,051.05 141.19 112.99 5,969,081.58 562,006.79 3.35 130.80 MWD+IFR-AK-CAZ-SC(2) 1,266.87 21.55 46.01 1,237.46 1,139.53 165.76 137.73 5,969,106.35 562,031.32 0.63 153.12 MWD+IFR-AK-CAZ-SC(2) 1,361.48 21.10 50.93 1,325.60 1,227.67 188.56 163.45 5,969,129.37 562,056.85 1.95 173.60 MWD+IFR-AK-CAZ-SC(2) 1,456.35 21.71 53.81 1,413.93 1,316.00 209.69 190.87 5,969,150.71 562,084.10 1.28 192.25 MWD+IFR-AK-CAZ-SC(2) 1,550.77 20.09 55.93 1,502.14 1,404.21 229.08 218.40 5,969,170.33 562,111.46 1.89 209.18 MWD+IFR-AK-CAZ-SC(2) 1,645.11 23.00 52.74 1,589.88 1,491.95 249.32 246.50 5,969,190.80 562,139.39 3.32 226.89 MWD+IFR-AK-CAZ-SC(2) 1,739.78 23.98 53.92 1,676.70 1,578.77 271.85 276.77 5,969,213.58 562,169.47 1.15 246.70 MWD+IFR-AK-CAZ-SC(2) 1,834.95 28.10 53.99 1,762.19 1,664.26 296.43 310.54 5,969,238.43 562,203.04 4.33 268.24 MWD+IFR-AK-CAZ-SC(2) 1,929.53 28.55 55.52 1,845.45 1,747.52 322.32 347.19 5,969,264.62 562,239.47 0.90 290.83 MWD+IFR-AK-CAZ-SC(2) 2,024.25 31.27 56.84 1,927.55 1,829.62 348.59 386.44 5,969,291.21 562,278.49 2.95 313.58 MWD+IFR-AK-CAZ-SC(2) 2,118.12 32.90 56.42 2,007.08 1,909.15 376.01 428.07 5,969,318.98 562,319.90 1.75 337.27 MWD+IFR-AK-CAZ-SC(2) 2,212.46 33.85 58.11 2,085.86 1,987.93 404.07 471.73 5,969,347.39 562,363.32 1.41 361.42 MWD+IFR-AK-CAZ-SC(2) 2,307.29 33.34 63.08 2,164.87 2,066.94 429.82 517.40 5,969,373.51 562,408.77 2.95 383.09 MWD+IFR-AK-CAZ-SC(2) 2,401.85 32.45 63.75 2,244.26 2,146.33 452.81 563.32 5,969,396.88 562,454.49 1.02 401.99 MWD+IFR-AK-CAZ-SC(2) 2,495.30 32.49 64.72 2,323.11 2,225.18 474.62 608.50 5,969,419.05 562,499.49 0.56 419.77 MWD+IFR-AK-CAZ-SC(2) 2,590.75 32.26 62.51 2,403.72 2,305.79 497.32 654.28 5,969,442.13 562,545.08 1.26 438.41 MWD+IFR-AK-CAZ-SC(2) 2,685.96 31.97 61.26 2,484.36 2,386.43 521.17 698.92 5,969,466.35 562,589.52 0.76 458.27 MWD+IFR-AK-CAZ-SC(2) 2,757.10 31.99 61.52 2,544.71 2,446.78 539.21 732.00 5,969,484.66 562,622.44 0.20 473.36 MWD+IFR-AK-CAZ-SC(2) 2,820.54 31.83 60.50 2,598.56 2,500.63 555.46 761.33 5,969,501.15 562,651.63 0.89 487.00 MWD+IFR-AK-CAZ-SC(3) 2,831.50 31.88 60.48 2,607.87 2,509.94 558.31 766.37 5,969,504.04 562,656.64 0.48 489.40 NOT an Actual Survey SC(3) 13 3/8"x16" _ 2,893.36 32.17 60.37 2,660.31 2,562.38 574.50 794.90 5,969,520.47 562,685.04 0.48 503.04 MWD+IFR-AK-CAZ-SC(3) 2,948.09 32.66 60.33 2,706.52 2,608.59 589.02 820.39 5,969,535.19 562,710.41 0.90 515.27 MWD+IFR-AK-CAZ-SC(3) 3,046.11 32.81 59.13 2,788.97 2,691.04 615.74 866.17 5,969,562.28 562,755.96 0.68 537.90 MWD+IFR-AK-CAZ-SC(3) 3,141.09 33.84 54.73 2,868.34 2,770.41 644.21 909.86 5,969,591.12 562,799.40 2.77 562.46 MWD+IFR-AK-CAZ-SC(3) 3,187.35 35.10 51.56 2,906.48 2,808.55 659.92 930.79 5,969,606.99 562,820.21 4.74 576.29 MWD+IFR-AK-CAZ-SC(3) 3,236.01 35.65 50.13 2,946.16 2,848.23 677.71 952.63 5,969,624.96 562,841.90 2.04 592.10 MWD+IFR-AK-CAZ-SC(3) 3,330.86 37.30 46.93 3,022.44 2,924.51 715.06 994.85 5,969,662.65 562,883.80 2.65 625.63 MWD+IFR-AK-CAZ-SC(3) 3,386.02 38.10 44.07 3,066.08 2,968.15 738.70 1,018.90 5,969,686.49 562,907.65 3.49 647.09 MWD+IFR-AK-CAZ-SC(3) 3,443.56 39.24 41.41 3,111.01 3,013.08 765.11 1,043.28 5,969,713.10 562,931.82 3.50 671.27 MWD+IFR-AK-CAZ-SC(3) 3,509.10 42.91 39.41 3,160.41 3,062.48 797.91 1,071.17 5,969,746.12 562,959.43 5.95 701.51 MWD+IFR-AK-CAZ-SC(3) 3,542.88 43.63 38.30 3,185.01 3,087.08 815.94 1,085.69 5,969,764.27 562,973.80 3.10 718.21 MWD+IFR-AK-CAZ-SC(3) 3,604.10 47.53 35.84 3,227.85 3,129.92 850.84 1,112.02 5,969,799.38 562,999.84 6.99 750.68 MWD+IFR-AK-CAZ-SC(3) 3,641.07 48.75 35.49 3,252.52 3,154.59 873.21 1,128.07 5,969,821.88 563,015.70 3.37 771.56 MWD+IFR-AK-CAZ-SC(3) 3,700.29 49.97 34.30 3,291.09 3,193.16 910.06 1,153.77 5,969,858.94 563,041.10 2.56 806.04 MWD+IFR-AK-CAZ-SC(3) 3,794.87 51.12 30.30 3,351.21 3,253.28 971.78 1,192.76 5,969,920.97 563,079.57 3.48 864.12 MWD+IFR-AK-CAZ-SC(3) 3,889.87 52.46 25.64 3,409.99 3,312.06 1,037.68 1,227.73 5,969,987.16 563,113.99 4.10 926.73 MWD+IFR-AK-CAZ-SC(3) 11/25/2015 9:23:08AM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-153 Project: Kuparuk River Unit t^TVD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 2E Site: Kuparuk 1C Pad MD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 2E. Well: 1C-153 North Reference: True Wellbore: 1C-153 Survey Calculation Method: Minimum Curvature Design: 1C-153 Database: OAKEDMP2 Survey tl, .,a-:&fir da, Map Map Vertical MD Inc Azi TVD TVDSS ' +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name ' 3,981.06 54.23 19.75 3,464.46 3,366.53 1,105.14 1,255.89 5,970,054.84 563,141.60 5.53 991.48 MWD+IFR-AK-CAZ-SC(3) 4,078.20 57.07 14.71 3,519.29 3,421.36 1,181.71 1,279.58 5,970,131.59 563,164.64 5.18 1,065.69 MWD+IFR-AK-CAZ-SC(3) 4,170.37 61.07 10.75 3,566.66 3,468.73 1,258.80 1,296.93 5,970,208.82 563,181.36 5.69 1,140.98 MWD+IFR-AK-CAZ-SC(3) 4,267.86 63.45 8.92 3,612.04 3,514.11 1,343.81 1,311.66 5,970,293.94 563,195.38 2.95 1,224.38 MWD+1FR-AK-CAZ-SC(3) 4,361.58 62.29 9.19 3,654.78 3,556.85 1,426.18 1,324.78 5,970,376.40 563,207.83 1.26 1,305.29 MWD+IFR-AK-CAZ-SC(3) 4,402.92 61.92 9.21 3,674.12 3,576.19 1,462.25 1,330.62 5,970,412.51 563,213.37 0.90 1,340.71 MWD+IFR-AK-CAZ-SC(3) 4,454.73 62.93 8.84 3,698.10 3,600.17 1,507.60 1,337.83 5,970,457.92 563,220.20 2.05 1,385.26 MWD+IFR-AK-CAZ-SC(3) 4,551.99 66.57 2.84 3,739.62 3,641.69 1,595.05 1,346.70 5,970,545.43 563,228.35 6.72 1,471.61 MWD+IFR-AK-CAZ-SC(3) 4,645.86 72.01 357.95 3,772.82 3,674.89 1,682.79 1,347.24 5,970,633.16 563,228.17 7.57 1,558.96 MWD+IFR-AK-CAZ-SC(3) 4,741.03 76.87 352.02 3,798.36 3,700.43 1,774.04 1,339.18 5,970,724.33 563,219.35 7.88 1,650.57 MWD+IFR-AK-CAZ-SC(3) 4,836.26 79.05 343.93 3,818.25 3,720.32 1,865.04 1,319.76 5,970,815.16 563,199.19 8.62 1,742.91 MWD+IFR-AK-CAZ-SC(3) 4,931.07 81.45 338.02 3,834.32 3,736.39 1,953.32 1,289.30 5,970,903.18 563,168.01 6.64 1,833.52 MWD+1FR-AK-CAZ-SC(3) 5,022.40 83.75 331.99 3,846.10 3,748.17 2,035.36 1,251.05 5,970,984.89 563,129.08 7.01 1,918.58 MWD+IFR-AK-CAZ-SC(3) 5,058.28 84.48 330.24 3,849.77 3,751.84 2,066.61 1,233.81 5,971,015.99 563,111.58 5.26 1,951.21 MWD+IFR-AK-CAZ-SC(3) 5,129.00 84.92 325.97 3,856.31 3.758.38 2,126.38 1,196.61 5,971,075.45 563,073.89 6.05 2,013.99 •SC(4) NOT an Actual Survey 9 5/8"x12-114" 5,144.73 85.02 325.02 3,857.69 3,759.76 2,139.29 1,187.73 5,971,088.29 563,064.91 6.05 2,027.63 MWD+IFR-AK-CAZ-SC(4) 5,239.65 88.01 325.36 3,863.46 3,765.53 2,217.07 1,133.65 5,971,165.61 563,010.20 3.17 2,109.83 MWD+IFR-AK-CAZ-SC(4) 5,333.11 92.15 326.51 3,863.33 3,765.40 2,294.47 1,081.31 5,971,242.58 562,957.23 4.60 2,191.50 MW D+I FR-AK-CAZ-SC(4) 5,428.51 90.24 328.16 3,861.34 3,763.41 2,374.76 1,029.84 5,971,322.43 562,905.10 2.65 2,275.97 MWD+IFR-AK-CAZ-SC(4) 5,524.45 89.27 329.95 3,861.75 3,763.82 2,457.04 980.51 5,971,404.29 562,855.10 2.12 2,362.23 MWD+IFR-AK-CAZ-SC(4) 5,618.40 89.90 332.71 3,862.43 3,764.50 2,539.46 935.44 5,971,486.33 562,809.35 3.01 2,448.27 MWD+IFR-AK-CAZ-SC(4) 5,714.04 90.59 336.03 3,862.02 3,764.09 2,625.68 894.08 5,971,572.19 562,767.28 3.55 2,537.76 MWD+IFR-AK-CAZ-SC(4) 5,808.99 89.88 342.88 3,861.63 3,763.70 2,714.53 860.78 5,971,660.76 562,733.25 7.25 2,629.18 MWD+IFR-AK-CAZ-SC(4) 5,903.82 91.66 346.84 3,860.36 3,762.43 2,806.04 836.02 5,971,752.05 562,707.74 4.58 2,722.50 MWD+IFR-AK-CAZ-SC(4) 5,998.72 92.46 345.77 3,856.95 3,759.02 2,898.18 813.56 5,971,844.00 562,684.53 1.41 2,816.25 MWD+IFR-AK-CAZ-SC(4) 6,092.39 90.17 343.55 3,854.80 3,756.87 2,988.48 788.79 5,971,934.08 562,659.02 3.40 2,908.36 MWD+IFR-AK-CAZ-SC(4) 6,187.90 88.62 339.10 3,855.80 3,757.87 3,078.93 758.22 5,972,024.27 562,627.71 4.93 3,001.13 MWD+IFR-AK-CAZ-SC(4) 6,281.90 89.52 340.37 3,857.33 3,759.40 3,167.10 725.67 5,972,112.15 562,594.43 1.66 3,091.80 MWD+IFR-AK-CAZ-SC(4) 6,376.69 90.07 344.79 3,857.67 3,759.74 3,257.52 697.30 5,972,202.33 562,565.32 4.70 3,184.35 MWD+IFR-AK-CAZ-SC(4) 6,472.54 89.66 348.18 3,857.90 3,759.97 3,350.70 674.90 5,972,295.31 562,542.16 3.56 3,279.13 MWD+IFR-AK-CAZ-SC(4) 6,567.58 89.39 350.97 3,858.68 3,760.75 3,444.16 657.71 5,972,388.62 562,524.19 2.95 3,373.73 MWD+IFR-AK-CAZ-SC(4) 6,662.18 89.66 354.05 3,859.47 3,761.54 3,537.94 645.38 5,972,482.28 562,511.09 3.27 3,468.23 MWD+IFR-AK-CAZ-SC(4) 6,756.48 90.84 354.88 3,859.06 3,761.13 3,631.79 636.28 5,972,576.05 562,501.22 1.53 3,562.52 MWD+IFR-AK-CAZ-SC(4) 6,851.28 90.52 354.66 3,857.93 3,760.00 3,726.19 627.64 5,972,670.37 562,491.81 0.41 3,657.31 MWD+IFR-AK-CAZ-SC(4) 6,946.41 90.11 353.64 3,857.41 3,759.48 3,820.82 617.94 5,972,764.90 562,481.33 1.16 3,752.43 MWD+IFR-AK-CAZ-SC(4) 7,041.26 89.42 351.24 3,857.80 3,759.87 3,914.84 605.47 5,972,858.81 562,468.08 2.63 3,847.17 MWD+IFR-AK-CAZ-SC(4) 7,135.76 89.21 346.98 3,858.93 3,761.00 4,007.61 587.62 5,972,951.42 562,449.47 4.51 3,941.15 MWD+IFR-AK-CAZ-SC(4) 7,230.47 90.14 345.54 3,859.46 3,761.53 4,099.61 565.12 5,973,043.22 562,426.22 1.81 4,034.75 MWD+IFR-AK-CAZ-SC(4) 7,325.22 90.11 344.25 3,859.26 3,761.33 4,191.08 540.43 5,973,134.47 562,400.78 1.36 4,128.03 MWD+IFR-AK-CAZ-SC(4) 11/25/2015 9:23:08AM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-153 Project: Kuparuk River Unit TVD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 2F Site: Kuparuk 1C Pad MD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 24 Well: 1C-153 North Reference: True Wellbore: 1C-153 Survey Calculation Method: Minimum Curvature Design: 1C-153 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,420.21 90.21 342.50 3,858.99 3,761.06 4,282.10 513.26 5,973,225.25 562,372.85 1.85 4,221.07 MWD+IFR-AK-CAZ-SC(4) 7,515.35 90.62 341.03 3,858.30 3,760.37 4,372.45 483.49 5,973,315.35 562,342.34 1.60 4,313.68 MWD+IFR-AK-CAZ-SC(4) 7,610.49 90.65 339.08 3,857.25 3,759.32 4,461.88 451.04 5,973,404.50 562,309.16 2.05 4,405.59 MWD+IFR-AK-CAZ-SC(4) 7,705.65 90.63 340.47 3,856.19 3,758.26 4,551.16 418.14 5,973,493.50 562,275.53 1.46 4,497.40 MWD+IFR-AK-CAZ-SC(4) 7,799.87 88.86 340.48 3,856.61 3,758.68 4,639.96 386.66 5,973,582.03 562,243.32 1.88 4,588.60 MWD+IFR-AK-CAZ-SC(4) 7,895.46 88.97 342.85 3,858.42 3,760.49 4,730.67 356.59 5,973,672.48 562,212.51 2.48 4,681.59 MWD+IFR-AK-CAZ-SC(4) 7,990.09 90.34 346.41 3,858.99 3,761.06 4,821.90 331.52 5,973,763.49 562,186.68 4.03 4,774.66 MWD+IFR-AK-CAZ-SC(4) 8,083.85 88.70 345.07 3,859.77 3,761.84 4,912.76 308.42 5,973,854.15 562,162.84 2.26 4,867.19 MWD+IFR-AK-CAZ-SC(4) 8,178.89 87.98 343.61 3,862.52 3,764.59 5,004.23 282.78 5,973,945.40 562,136.45 1.71 4,960.55 MWD+IFR-AK-CAZ-SC(4) 8,274.84 87.92 343.75 3,865.96 3,768.03 5,096.26 255.84 5,974,037.19 562,108.75 0.16 5,054.57 MWD+IFR-AK-CAZ-SC(4) 8,368.01 90.58 345.20 3,867.18 3,769.25 5,186.01 230.90 5,974,126.72 562,083.08 3.25 5,146.15 MWD+IFR-AK-CAZ-SC(4) 8,464.13 89.10 348.08 3,867.45 3,769.52 5,279.52 208.70 5,974,220.03 562,060.11 3.37 5,241.24 MWD+IFR-AK-CAZ-SC(4) 8,559.54 93.46 347.57 3,865.31 3,767.38 5,372.74 188.59 5,974,313.07 562,039.23 4.60 5,335.85 MWD+IFR-AK-CAZ-SC(4) 8,652.91 94.29 347.13 3,859.00 3,761.07 5,463.63 168.19 5,974,403.79 562,018.08 1.01 5,428.18 MWD+IFR-AK-CAZ-SC(4) 8,747.56 95.47 348.16 3,850.95 3,753.02 5,555.75 148.01 5,974,495.73 561,997.14 1.65 5,521.71 MWD+IFR-AK-CAZ-SC(4) 8,841.43 91.62 348.90 3,845.15 3,747.22 5,647.55 129.38 5,974,587.37 561,977.76 4.18 5,614.78 MWD+IFR-AK-CAZ-SC(4) 8,937.27 92.10 347.63 3,842.04 3,744.11 5,741.34 109.90 5,974,680.98 561,957.51 1.42 5,709.91 MWD+IFR-AK-CAZ-SC(4) 9,032.10 92.88 346.21 3,837.92 3,739.99 5,833.62 88.46 5,974,773.07 561,935.31 1.71 5,803.71 MWD+IFR-AK-CAZ-SC(4) 9,127.20 92.54 345.74 3,833.42 3,735.49 5,925.78 65.44 5,974,865.03 561,911.53 0.61 5,897.52 MWD+IFR-AK-CAZ-SC(4) 9,221.18 91.22 344.30 3,830.34 3,732.41 6,016.51 41.16 5,974,955.55 561,886.51 2.08 5,990.03 MWD+IFR-AK-CAZ-SC(4) 9,315.93 87.84 342.82 3,831.12 3,733.19 6,107.37 14.35 5,975,046.17 561,858.96 3.89 6,082.88 MWD+IFR-AK-CAZ-SC(4) 9,412.01 89.19 340.64 3,833.61 3,735.68 6,198.57 -15.76 5,975,137.11 561,828.10 2.67 6,176.35 MWD+IFR-AK-CAZ-SC(4) 9,506.03 88.56 341.15 3,835.45 3,737.52 6,287.39 -46.53 5,975,225.67 561,796.60 0.86 6,267.52 MWD+IFR-AK-CAZ-SC(4) 9,601.06 89.16 345.77 3,837.34 3,739.41 6,378.44 -73.57 5,975,316.49 561,768.82 4.90 6,360.58 MWD+IFR-AK-CAZ-SC(4) 9,696.48 88.39 346.56 3,839.38 3,741.45 6,471.07 -96.38 5,975,408.92 561,745.24 1.16 6,454.85 MWD+IFR-AK-CAZ-SC(4) 9,791.85 88.87 346.79 3,841.66 3,743.73 6,563.85 -118.35 5,975,501.50 561,722.51 0.56 6,549.19 MWD+IFR-AK-CAZ-SC(4) 9,886.75 89.69 346.60 3,842.86 3,744.93 6,656.19 -140.19 5,975,593.65 561,699.91 0.89 6,643.08 MWD+IFR-AK-CAZ-SC(4) 9,982.07 90.14 346.20 3,843.00 3,745.07 6,748.84 -162.60 5,975,686.10 561,676.73 0.63 6,737.33 MWD+IFR-AK-CAZ-SC(4) 10,076.85 90.11 345.72 3,842.79 3,744.86 6,840.79 -185.60 5,975,777.85 561,652.99 0.51 6,830.93 MWD+IFR-AK-CAZ-SC(4) 10,169.44 90.17 346.19 3,842.56 3,744.63 6,930.61 -208.07 5,975,867.47 561,629.78 0.51 6,922.37 MWD+IFR-AK-CAZ-SC(4) 10,266.20 89.63 346.51 3,842.73 3,744.80 7,024.64 -230.90 5,975,961.30 561,606.17 0.65 7,018.03 MWD+IFR-AK-CAZ-SC(4) 10,360.67 89.63 346.62 3,843.34 3,745.41 7,116.52 -252.85 5,976,052.99 561,583.47 0.12 7,111.48 MWD+IFR-AK-CAZ-SC(4) 10,455.44 89.52 345.19 3,844.05 3,746.12 7,208.43 -275.93 5,976,144.70 561,559.63 1.51 7,205.05 MWD+IFR-AK-CAZ-SC(4) 10,550.21 90.17 345.05 3,844.30 3,746.37 7,300.02 -300.26 5,976,236.08 561,534.55 0.70 7,298.41 MWD+IFR-AK-CAZ-SC(4) 10,645.32 90.14 346.42 3,844.05 3,746.12 7,392.20 -323.70 5,976,328.05 561,510.35 1.44 7,392.28 MWD+IFR-AK-CAZ-SC(4) 10,739.04 90.45 347.38 3,843.56 3,745.63 7,483.48 -344.94 5,976,419.14 561,488.36 1.08 7,485.06 MWD+IFR-AK-CAZ-SC(4) 10,834.14 89.97 347.13 3,843.21 3,745.28 7,576.23 -365.92 5,976,511.71 561,466.62 0.57 7,579.29 MWD+IFR-AK-CAZ-SC(4) 10,929.00 89.90 345.42 3,843.32 3,745.39 7,668.38 -388.43 5,976,603.66 561,443.36 1.80 7,673.05 MWD+IFR-AK-CAZ-SC(4) 11,022.67 88.56 345.13 3,844.58 3,746.65 7,758.96 -412.23 5,976,694.04 561,418.81 1.46 7,765.37 MWD+IFR-AK-CAZ-SC(4) 11,116.20 88.42 344.07 3,847.05 3,749.12 7,849.10 -437.06 5,976,783.96 561,393.24 1.14 7,857.33 MWD+IFR-AK-CAZ-SC(4) 11/25/2015 9:23:08AM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-153 Project: Kuparuk River Unit TVD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25 Site: Kuparuk 1C Pad MD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25 Well: 1C-153 North Reference: True Wellbore: 1C-153 Survey Calculation Method: Minimum Curvature Design: 1C-153 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E1-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,212.68 88.56 344.09 3,849.59 3,751.66 7,941.85 -463.52 5,976,876.48 561,366.02 0.15 7,952.03 MWD+IFR-AK-CAZ-SC(4) 11,308.96 89.11 345.30 3,851.55 3,753.62 8,034.69 -488.92 5,976,969.10 561,339.85 1.38 8,046.73 MWD+IFR-AK-CAZ-SC(4) 11,405.01 89.11 346.44 3,853.04 3,755.11 8,127.82 -512.37 5,977,062.02 561,315.64 1.19 8,141.55 MWD+IFR-AK-CAZ-SC(4) 11,499.59 88.60 347.09 3,854.93 3,757.00 8,219.87 -534.02 5,977,153.88 561,293.24 0.87 8,235.14 MWD+IFR-AK-CAZ-SC(4) 11,593.95 88.63 348.35 3,857.21 3,759.28 8,312.05 -554.08 5,977,245.88 561,272.41 1.34 8,328.71 MWD+IFR-AK-CAZ-SC(4) 11,688.27 88.49 350.55 3,859.58 3,761.65 8,404.74 -571.34 5,977,338.41 561,254.39 2.34 8,422.55 MWD+IFR-AK-CAZ-SC(4) 11,784.14 88.67 350.86 3,861.95 3,764.02 8,499.32 -586.82 5,977,432.86 561,238.13 0.37 8,518.12 MWD+IFR-AK-CAZ-SC(4) 11,879.23 88.67 349.00 3,864.16 3,766.23 8,592.91 -603.44 5,977,526.30 561,220.74 1.96 8,612.81 MWD+IFR-AK-CAZ-SC(4) 11,974.12 88.25 347.45 3,866.71 3,768.78 8,685.77 -622.80 5,977,618.99 561,200.62 1.69 8,707.00 MWD+IFR-AK-CAZ-SC(4) 12,066.15 88.18 346.69 3,869.58 3,771.65 8,775.42 -643.38 5,977,708.46 561,179.30 0.83 8,798.10 MWD+IFR-AK-CAZ-SC(4) 12,162.98 87.67 344.69 3,873.09 3,775.16 8,869.18 -667.30 5,977,802.01 561,154.61 2.13 8,893.59 MWD+IFR-AK-CAZ-SC(4) 12,258.54 87.74 343.48 3,876.91 3,778.98 8,961.00 -693.48 5,977,893.60 561,127.68 1.27 8,987.34 MWD+IFR-AK-CAZ-SC(4) 12,352.55 87.91 341.49 3,880.48 3,782.55 9,050.59 -721.75 5,977,982.94 561,098.67 2.12 9,079.05 MWD+IFR-AK-CAZ-SC(4) 12,446.98 87.53 341.48 3,884.24 3,786.31 9,140.06 -751.72 5,978,072.15 561,067.98 0.40 9,170.79 MWD+IFR-AK-CAZ-SC(4) 12,541.17 86.98 342.48 3,888.75 3,790.82 9,229.52 -780.82 5,978,161.37 561,038.14 1.21 9,262.45 MWD+IFR-AK-CAZ-SC(4) 12,636.79 87.11 345,10 3,893.68 3,795.75 9,321.21 -807.47 5,978,252.82 561,010.73 2.74 9,356.12 MWD+IFR-AK-CAZ-SC(4) 12,731.38 89.20 348.05 3,896.72 3,798.79 9,413.15 -829.42 5,978,344.57 560,988.03 3.82 9,449.62 MWD+IFR-AK-CAZ-SC(4) 12,761.91 88.87 350.48 3,897.24 3,799.31 9,443.14 -835.10 5,978,374.51 560,982.10 8.03 9,479.99 MWD+IFR-AK-CAZ-SC(4) 12,807.00 88.87 350.48 3,898.13 3,800.20 9,487.60 -842.56 5,978,418.90 560,974.28 0.00 9,524.93 NOT an Actual Survey -1127x62.314"._. ... 12,825.00 88.87 350.48 3,898.48 3,800.55 9,505.35 -845.54 5,978,436.63 560,971.15 0.00 9,542.87 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. D Yes ❑ No I have checked to the best of my ability that the following data is correct: 0 Surface Coordinates Q Declination & Convergence 2 GRS Survey Corrections p Survey Tool Codes Abdou DDN.cr.Ababd'tlou Aed bAbdou Abakar o-Schlumberger,ou, A ba ka r 2111311--AWoullbakarkrContractor.co rwcophillipscwn,c--US DE: Date.2015.10.1212:33ae-WOO' davidllee@conocophillips.com °a °g'1ed" t 'cc"h"`" Client Representative: Date: 10/13115 11/25/2015 9:23:08AM Page 6 COMPASS 5000.1 Build 74 • • '_; WMilling Cement Detail Report , 1C-I53 C_onocoPhillips •• String: Conductor Cement Job: Cement Details. -.._ 'Description Cementing Start Date Cementing End Date Wellbore Nene Conductor Cement 6/25/2015 06:30 , 6/25/201516:30 1C-153 Comment C_ a ,'?:'.: - -_.. --- — - - - ., - - _ _111 ... '... ..........:.:.. :. : *T. - -- ........ ..... Description Objective Top Depth(f1KB) Bottom Depth(MB) Full Return? Vol Cement...Top Plug? Den Plug? Conductor Cement Tack Conductor for 109.0 120.0 No No No second stage Q Pump Mit(bblim...0 Pump Final(bbli...Q Pump Avg(bbl... P Pump Final(psi) P Plug Bump(pal) Recip? Stroke(it) (Rotated? Pipe RPM(rpm) No rotated? Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment 86 sx cement,14.2 bbl pumped. . PAMe - A, ...:............... _ Fluftl - _ Fluid Type Fluid Description ')Estimated Top(rt(B) 'Est Btm(RKB) •Amount(sacks) Class Volume Pumped(bbt) Surface Cement 109.0 120.0 86 G 14.2 Yield(}Maack) Mix 1120 Ratio(galea... Free Water(%) Density(lb/gal) Plastic Viscosity(Pass) Thickening Time(hr) CmprStr 1(psi) , 1.16 5.02 15.70 Additives Additive Type Concentration Cone Unit label 'Stage#` - -- Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Fuhl Return? Vol Cement...Top Plug? Btm Plug? Conductor Cement Cement conductor to 51.0 109.0 No No No surface Q Pump Mit(bbUm...0 Pump Final(bbl...Q Pump Avg(bbil... P Pump Final{pal) P Plug Bump(psi) Rectp? Stroke(ft) Rotated? Pipe RPM(rpm) No No , Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(11KB) Drill Out Diameter(in) Comment 293 sx cement,48.57 bbl pumped CeNuetffflU)dti.BcAddltires.........:.............:...:...<:::. . . .-...: ....... ...:.. --- - -• . .. -..., ..... ..._...... Fluid '. Oilak Fluid Type Fluid Description 'Estimated Top(RKB) bat etm(f KB) Amount(sacks) Class Volume Pumped(bid) Surface Cement 51.0 109.0 293 G 48.6 Yield(ft'isack) Mix H2O Ratio(galMa... Free Water(%) Density db/gal) Plastic Viscosity(Pass) Thickening Time(hr) CmprStr 1(psi) 1.16 5.02 15.70 Additives Additive Type Concentration Core Unit label Page 111 Report Printed: 4/25/2016 • • Drilling Cement Detail Report a Wells IC-153 ConocoPhillips String: Surface Cement Job: trernent stall Description Cementing Start Date Cementing End Date Wel bore Name Surface Cement 9/19/2015 15:19 9/1912015 20:52 1C-153 Comment SLB Pumped 5 bbl's CW-100 psi tested line to 4k(Good) Pump 45 bbl's CW-100 Total Cw-100=50 bbl's Pumped 98.5 bbl's 10.5 ppg mudpush 2 Drop bottom plug • Pump 585 bbrs 11 ppg lead cement Pump 74 bbrs 12 ppg tail cement Drop top plug Displace with rig.Pump 240 bbi's 9.8 ppg mud received cement to surface. reduced rate from 3 bpm to 1 bpm at 3.900 strokes,Bumped plug at 3,962 strokes 280 psi. Pressured up to 800 psi held for 5 minutes,checked floats.Floats good. Cement fell 19'and we mixed and pour cement down flutes and and had cement back to the 4"outlets on 9/2012015 at 21:00 hours. 9123 at 0200 TOO measured 12'down. Added 1/2 BBL of cement to bring it to surface. Checked 9/24 0100 and mesured 18"down. Description Objective Top Depth(RCB) Bottom Depth(RKB) Full Return? Vol Cement...Top Plug? elm Plug? Surface Lead Cement Cement 13-318"Surface 41.6 2,341,0 Yes No No casing 0 Pump/nit(bbllm...0 Pump Final(bbl/...Q Pump Avg(bbl!... P Pump Final(psi) P Plug Sump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 1 6 280.0 800.0 Yes 18.00 No Tagged Depth(RKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment 15:22 SLB pumped 5 bbl's CW-100 psi tested cement line to 4,000 psi(Good-pressure test) 15:30 SLB Pumped an additional 45 bbl's CW-100 total Cw-100=50 bbrs.Rate 5 bpm ICP=200 psi.15%Flow out.FCP r3 5 bpm 230 psi 16%Flow out. 15:47 Batched and pumped 98.5 bbl's 10.5 ppg Mudpush 2 ICR 5 bpm ICP 250 psi 12%Flow out.FCR 3.8 bpm FOP 200 psi 10%Flow out.180 k Down wt,216 k Up wt. 16:20 Drop top plug 16:25 Batch&Pump 585 bbl's 11 ppg lead c ement1,668 sx.®5.6 bpm ICP 210 psi 15%Row out.FCP 300 psi 15%Row out. 20:52 reduced rate to 1 bpm bumped plug at 3,962 strokes 280 psi increased pressure to 780 psi-800 psi.Held for 5 minutes.Bled off pressure checked floats. Floats good CIP @ 20:52 Total cement to surface 160 bbl's. .r.i Fluid Type Fluid Description Fstimated Top(MOB) Est Bbn(RCB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 41.6 2,341.0 1,636 G 585.0 Yield(R•(eack) Mix H2O Ratio(garbls... Free Water(%) Density(Ibigal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr f(psi) 1.87 6.40 11.00 0.00 Additives Additive Type • Concentration Cone Unit label .. .,....:-�..-..,.;,..... ,_. .. ..:,::"�:�..- Description Objective Top Depth(ftI6) Bottom Depth(flKB) Full Return? Vol Cement...Top Plug? Bim Plug? Surface Tail Cement 2,314.0 2,841.0 Yes 160.0 No No Q Pump MK(bbilm...Q Pump Final(bbu..,Q Pump Avg(bblI... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) 'Rotated? Pipe RPM(rpm) 5 ti\ 6 280.0 800.0 No 18.00 No Tagged Depth(ftKB) , 4) Tag Method Depth Plug Drilled Out To(RKB) Drill Out Diameter(In) Comment 18:24 Batch&Pump`74 bbl'sitail cemen 2 8 ax. Ilial circulating rate 4.5 bpm 180 psi 17%Flow out.15 bbrs pumped increase pump rate to 5.4 bpm 290 psi 19%Flow out at 55 bbfa pumped at 5.5 •m 311. •-i 19%Flow out.Reduced rate to 4.6 bpm 150 psi 17%Flow out 19:10 drop top plug chase with10 bbl's H2* •pm 180 psi turn over to rig for displacement. Rig displace cement with 9.8 ppg drillplex mud Initial rate 8 bpm 300 psi caught cement at 400 strokes,450 psi 28%Flow out.Reduce rate to 6.0 bpm 297 psi 22%Flow out.Reciprocated casing F/2,831'-T/2,821' through out.Up wt 270 k Down wt 65 k. 19:24 Land casing on hanger @ 800 strokes pumped 6 bpm 293 psi.Reduce rate at 800 strokes to 300 bpm 110 psi_@ 900 strokes divert returns to cellar. 19:55 cement to surface at 2.400 strokes rate decreased to 3 bpm 185 psi ICP. 3,950 strokes FCP 280 psi. 20:52 reduced rate to 1 bpm bumped plug at 3,962 strokes 280 psi increased pressure to 780 psi-800 psi.Held for 5 minutes.Bled off pressure checked floats. Floats good CIP .w 20:52 Total cement to surface 180 bbl's. Page 1/2 Report Printed: 4/25/2016 • • Cement Detail Report &Wells 1C-153 ContncoPiiiilips String: Surface Cement Job: Gomen Fluids&AddtUve : Fluid Fluid Type Fluid Description Estimated Top(fiKB) Est Btm(ttKB) Amount(sacks) Class Volume Pumped(bbi) Tail Cement 2,341.0 2,841.0 260 G 68.0 Yield(tt'Isack) Mix 1420 Ratio(gallsa... Free Water(%) Density(lblgal) Plastic Viscosity(Pais) Thickening Time(hr) CmprStr 1(psi) 1.62 5.47 12.00 0.00 Additives Additive Type Concentration Conc Unit label Page 212 Report Printed: 4123/2076 ',` Cement Detail Report Minim; 1C-153 ConocoPhillips • String: Intermediate Casing Cement Job: :. lits : --=- = _ ..-. . . ............. -- nrsrK. ::,:..: Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 9/25/2015 20:44 9/25/2015 22:35 1C-153 Comment Line up to SLB cementers;Pump 4.0 BBL of water and lest lines to 3500 psi;Good. Pump 40.0 BBL of 11.5 ppg Mud push II and drop bottom plug. Chase with 50 BBL of Class G 15.8 ppg retarded cement,then pumped 93.0 BBL of Class G 15.8 ppg cement without retarder and dropped the lop plug. Chase top plug with 10.6 BBL of 10.8 ppg Mud Push It. Displace cement with 369.5 BBL of 9.2 ppg Faze-Pro OBM mud. Cement was pumped at an average rate of 5.5 BPM. Cement was chased at an average rate of 5.5 BPM,slowing to 3 BPM with 262 BBL away of the FP displacement. The plug bumped with 600 psi and pressure was increased to 1160 psi and held for 5 minutes. 2 BBL were bled back and the floats held. Cement was in place at 22:30 hours. Casing string was reciprocated throughout job,setting on hanger during fluid transitions and no losses were Incurred during job. Final PU=172K,SO=109K. 0.00100t Sta ..... :. :.. 1 • •• _Ste$®• . ... :.. _.._.-. _.... Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? -Vol Cement...Top Plug? Bim Plug? Intermediate Casing Cement 9-518" 3,106.0 5,137,0 No 0.0 Yes Yes Cement Intermediate Q Pump Ink(bblim...Q Pump Final(bb11...0 Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 5 6 673.0 600.0 Yes 18.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(MB) Drill Out Diameter(in) Comment Line up to SLB cementers;Pump 4.0 BBL of water and test lines to 3500 psi;Good. Pump 40.0 BBL of 11.5 ppg Mud push II and drop bottom plug. Chase with 50 BBL of Class 0 15.8 ppg retarded cement,then pumped 93.0 BBL of Class G 15.8 ppg cement without retarder and dropped the top plug. Chase top plug with 10.6 BBL of 10.8 ppg Mud Push II. Displace cement with 369.5 BBL of 9.2 ppg Faze-Pro OBM mud. Cement was pumped at an average rate of 5.5 BPM. Cement was chased at an average rate of 5.5 BPM,slowing to 3 BPM with 262 BBL away of the FP displacement. The plug bumped with 600 psi and pressure was increased to 1160 psi and held for 5 minutes. 2 BBL were bled back and the floats held. Cement was in place at 22:30 hours. Casing string was reciprocated throughout job,setting on hanger during fluid transitions and no losses were incurred during Job. Final PO=172K,SO=109K. f3R rtt.Fluids 8'A dltives":-.'::<;.=.;: .. •:. ... r>.c .:::;:3 'm - - - Fluid Type Fluid Descriptionw Estimated Top(BM) Est Bim(ftKB) Amount(sacks) Class Volume Pumped(bbl) MudPushll 2,299.0 3,106.0 Yield(ft'Isack) Mix H2O Ratio(galfss... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pave) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Cone Unit label fluid:_.... .. : :: : ... ;.i.: .: - ..... ... .. - ..- Fluid'iype Fluid Description E�stimatarf'Top Vika) Est Btm(KKR) Amount(sacks) Class Volume Pumped(bbl) Lead cement 3,106.0 3,852.0 242 50.0 retarded Yield(ttYeack) Mix 1420 Ratio(galfsa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pays) Thickening Time(hr) 'CmprStr 1(psi) 1.16 15.80 13.95 Additives Additive Type Concentration Conc Unit label 0046 Antifoam 0.2 %BWOC Additive Typo Concentration Conc Unit label D065 Dispersant 0.3 %BWOC Additive Type Concentration Conc Unit label D167 Fluid Loss 0.4 %BWOC Additive Type Concentration Conc Unit label 0177 Retarder 0.04 gallsx Fluid Type Fluid bescript6; Estimated Top(RKB) Est Btm(itKa) Amount(sacks) Class 'Volume Pumped (bbl) Tail cement 3,852.0 5,137.0 451 93.3 unretarded Yield(Maack) Mix H2O Ratio(galisa... Free Water(%) Density(lbfgal) Plastic Viscosity(Peva) Thickening Time(hr) CmprStr1(psi) 1.16 15.80 4.65 Additives " Additive Type Concentration Conc Unit label D046 AntiFoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC Additive Type 'Concentration Conc Unit label D167 Fluid loss 0.4%BWOC Page 1/1 Report Printed: 4/25/2016 215116 . i 26409 S chiumberer AOC Transmittal#: 290CT15-SPO1 gDrilling & Measurements DATA LOGGED MWD/LWD LogProduct Deliver to r3'izoi5 y m K. BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 1C-153 Date Dispatched: 29-Oct-15 Job#: 15AKA0094 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A Scope Resistivity 2" MD x x Scope Resistivity 2"TVD x x Scope Resistivity 5'MD x x Scope Resistivity 5'TVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Richard.E.Elciarico(c�conocophillips.com AlaskaPTSPrintCenter(Dslb.com Ricky Elgarico Attn:Stephanie Pacillo 907-265-6580 Received By: divalza.41,0L, 44 / , 4/ • • 115116 16409 RECEIVED CBCT 2 9 2O A0000 FINAL NADConversion Kuparuk River Unit Kuparuk 1C Pad 1C-153 Definitive Survey Report 12 October, 2015 NAD 27 • ConocoPhillips • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-153 Project: Kuparuk River Unit TVD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25) Well: 1C-153 North Reference: Grid Wellbore: 1C-153 Survey Calculation Method: Minimum Curvature Design: 1C-153 Database: EDM Production Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1C-153 Well Position +N/-S 247.86 usft Northing: 5,968,939.48 usft Latitude: 70°19'32.426 N +EI-W -1,138,277.24 usft Easting: 561,894.98 usft Longitude: 149°29'53.119 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 57.60 usft Wellbore 1C-153 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 9/21/2015 18.95 80.99 57,506 Design 1C-153 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 40.33 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (0) 40.33 247.86 1,138,277.2 354.53 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 78.31 735.51 1C-153 Srvy#1-GYD-GC-SS(1C-153) GYD-GC-SS Gyrodata gyro single shots 9/22/2015 8:55: 793.29 2,757.10 1C-153 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/22/2015 8:57: 2,820.54 5,058.28 1C-153 Srvy#3-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/22/2015 9:00: 5,144.73 12,761.91 1C-153 Srvy#4-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/5/2015 9:03:' Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 40.33 0.00 0.00 40.33 -57.60 247.86 -1,138,277.24 5,968,939.48 561,894.98 0.00 0.00 UNDEFINED 78.31 0.64 128.10 78.31 -19.62 247.73 -1,138,277.07 5,968,939.35 561,895.15 1.69 -0.15 GYD-GC-SS(1) 120.00 0.42 100.38 120.00 22.07 247.56 -1,138,276.74 5,968,939.18 561,895.48 0.80 -0.35 NOT an Actual Survey 20"x34" 172.94 0.44 41.16 172.94 75.01 247.68 -1,138,276.42 5,968,939.30 561,895.80 0.80 -0.26 uru-.0-aak1/ 267.22 1.31 21.89 267.20 169.27 248.95 -1,138,275.78 5,968,940.57 561,896.44 0.96 0.94 GYD-GC-SS(1) 363.97 2.65 26.76 363.89 265.96 251.97 -1,138,274.36 5,968,943.60 561,897.87 1.39 3.82 GYD-GC-SS(1) 459.27 5.75 18.42 458.93 361.00 258.47 -1,138,271.86 5,968,950.11 561,900.37 3.31 10.05 GYD-GC-SS(1) 551.31 8.32 17.43 550.27 452.34 269.20 -1,138,268.41 5,968,960.85 561,903.83 2.80 20.40 GYD-GC-SS(1) 641.81 12.22 30.71 639.31 541.38 283.69 -1,138,261.55 5,968,975.36 561,910.70 5.01 34.17 GYD-GC-SS(1) 735.51 14.98 35.02 730.38 632.45 302.14 -1,138,249.53 5,968,993.84 561,922.73 3.14 51.39 GYD-GC-SS(1) 10/12/2015 12:05:20PM Page 2 COMPASS 5000.1 Build 74 • ConocoPhillips • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-153 Project: Kuparuk River Unit TVD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25) Well: 1C-153 North Reference: Grid Wellbore: 1C-153 Survey Calculation Method: Minimum Curvature Design: 1C-153 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 793.29 15.48 42.36 786.13 688.20 313.95 -1,138,240.05 5,969,005.67 561,932.23 3.44 62.25 MWD+IFR-AK-CAZ-SC(2) 888.22 14.53 46.94 877.83 779.90 331.44 -1,138,222.81 5,969,023.19 561,949.49 1.60 78.02 MWD+IFR-AK-CAZ-SC(2) 983.33 14.15 46.49 969.98 872.05 347.59 -1,138,205.67 5,969,039.37 561,966.67 0.42 92.46 MWD+IFR-AK-CAZ-SC(2) 1,077.89 18.38 42.15 1,060.73 962.80 366.61 -1,138,187.27 5,969,058.42 561,985.09 4.65 109.64 MWD+IFR-AK-CAZ-SC(2) 1,171.77 21.47 43.91 1,148.98 1,051.05 389.97 -1,138,165.42 5,969,081.81 562,006.98 3.35 130.80 MWD+IFR-AK-CAZ-SC(2) 1,266.87 21.55 45.54 1,237.46 1,139.53 414.74 -1,138,140.88 5,969,106.62 562,031.55 0.63 153.12 MWD+IFR-AK-CAZ-SC(2) 1,361.48 21.10 50.46 1,325.60 1,227.67 437.76 -1,138,115.34 5,969,129.67 562,057.13 1.95 173.60 MWD+IFR-AK-CAZ-SC(2) 1,456.35 21.71 53.34 1,413.93 1,316.00 459.10 -1,138,088.10 5,969,151.05 562,084.42 1.28 192.25 MWD+IFR-AK-CAZ-SC(2) 1,550.77 20.09 55.46 1,502.14 1,404.21 478.73 -1,138,060.73 5,969,170.70 562,111.83 1.89 209.18 MWD+IFR-AK-CAZ-SC(2) 1,645.11 23.00 52.27 1,589.88 1,491.95 499.20 -1,138,032.80 5,969,191.20 562,139.80 3.32 226.89 MWD+IFR-AK-CAZ-SC(2) 1,739.78 23.98 53.45 1,676.70 1,578.77 521.97 -1,138,002.71 5,969,214.01 562,169.93 1.15 246.70 MWD+IFR-AK-CAZ-SC(2) 1,834.95 28.10 53.52 1,762.19 1,664.26 546.82 -1,137,969.14 5,969,238.91 562,203.56 4.33 268.24 MWD+IFR-AK-CAZ-SC(2) 1,929.53 28.55 55.05 1,845.45 1,747.52 573.02 -1,137,932.70 5,969,265.14 562,240.05 0.90 290.83 MWD+IFR-AK-CAZ-SC(2) 2,024.25 31.27 56.37 1,927.55 1,829.62 599.60 -1,137,893.68 5,969,291.76 562,279.14 2.95 313.58 MWD+IFR-AK-CAZ-SC(2) 2,118.12 32.90 55.95 2,007.08 1,909.15 627.37 -1,137,852.26 5,969,319.58 562,320.61 1.75 337.27 MWD+IFR-AK-CAZ-SC(2) 2,212.46 33.85 57.64 2,085.86 1,987.93 655.78 -1,137,808.84 5,969,348.03 562,364.10 1.41 361.42 MWD+IFR-AK-CAZ-SC(2) 2,307.29 33.34 62.61 2,164.87 2,066.94 681.91 -1,137,763.38 5,969,374.20 562,409.63 2.95 383.09 MWD+IFR-AK-CAZ-SC(2) 2,401.85 32.45 63.28 2,244.26 2,146.33 705.27 -1,137,717.65 5,969,397.60 562,455.43 1.02 401.99 MWD+IFR-AK-CAZ-SC(2) 2,495.30 32.49 64.25 2,323.11 2,225.18 727.45 -1,137,672.65 5,969,419.81 562,500.50 0.56 419.77 MWD+IFR-AK-CAZ-SC(2) 2,590.75 32.26 62.04 2,403.72 2,305.79 750.53 -1,137,627.06 5,969,442.92 562,546.17 1.26 438.41 MWD+IFR-AK-CAZ-SC(2) 2,685.96 31.97 60.79 2,484.36 2,386.43 774.74 -1,137,582.61 5,969,467.18 562,590.68 0.76 458.27 MWD+IFR-AK-CAZ-SC(2) 2,757.10 31.99 61.05 2,544.71 2,446.78 793.06 -1,137,549.68 5,969,485.52 562,623.66 0.20 473.36 MWD+IFR-AK-CAZ-SC(2) 2,820.54 31.83 60.03 2,598.56 2,500.63 809.55 -1,137,520.49 5,969,502.03 562,652.90 0.89 487.00 MWD+IFR-AK-CAZ-SC(3) 2,831.50 31.88 60.01 2,607.87 2,509.94 812.44 -1,137,515.48 5,969,504.93 562,657.92 0.48 489.40 NOT an Actual Survey 13 3/8"x16" 2,893.36 32.17 59.90 2,660.31 2,562.38 828.86 -1,137,487.08 5,969,521.38 562,686.36 0.48 503.04 MWD+IFR-AK-CAZ-SC(3) 2,948.09 32.66 59.86 2,706.52 2,608.59 843.58 -1,137,461.70 5,969,536.12 562,711.77 0.90 515.27 MWD+IFR-AK-CAZ-SC(3) 3,046.11 32.81 58.66 2,788.97 2,691.04 870.68 -1,137,416.15 5,969,563.26 562,757.40 0.68 537.90 MWD+IFR-AK-CAZ-SC(3) 3,141.09 33.84 54.26 2,868.34 2,770.41 899.51 -1,137,372.70 5,969,592.14 562,800.92 2.77 562.46 MWD+IFR-AK-CAZ-SC(3) 3,187.35 35.10 51.09 2,906.48 2,808.55 915.39 -1,137,351.89 5,969,608.04 562,821.76 4.74 576.29 MWD+IFR-AK-CAZ-SC(3) 3,236.01 35.65 49.66 2,946.16 2,848.23 933.36 -1,137,330.20 5,969,626.03 562,843.49 2.04 592.10 MWD+IFR-AK-CAZ-SC(3) 3,330.86 37.30 46.46 3,022.44 2,924.51 971.05 -1,137,288.29 5,969,663.79 562,885.46 2.65 625.63 MWD+IFR-AK-CAZ-SC(3) 3,386.02 38.10 43.60 3,066.08 2,968.15 994.89 -1,137,264.43 5,969,687.66 562,909.35 3.49 647.09 MWD+IFR-AK-CAZ-SC(3) 3,443.56 39.24 40.94 3,111.01 3,013.08 1,021.50 -1,137,240.26 5,969,714.31 562,933.56 3.50 671.27 MWD+IFR-AK-CAZ-SC(3) 3,509.10 42.91 38.94 3,160.41 3,062.48 1,054.52 -1,137,212.65 5,969,747.39 562,961.21 5.95 701.51 MWD+IFR-AK-CAZ-SC(3) 3,542.88 43.63 37.83 3,185.01 3,087.08 1,072.67 -1,137,198.27 5,969,765.56 562,975.61 3.10 718.21 MWD+IFR-AK-CAZ-SC(3) 3,604.10 47.53 35.37 3,227.85 3,129.92 1,107.78 -1,137,172.24 5,969,800.73 563,001.69 6.99 750.68 MWD+IFR-AK-CAZ-SC(3) 3,641.07 48.75 35.02 3,252.52 3,154.59 1,130.28 -1,137,156.37 5,969,823.26 563,017.58 3.37 771.56 MWD+IFR-AK-CAZ-SC(3) 3,700.29 49.97 33.83 3,291.09 3,193.16 1,167.35 -1,137,130.97 5,969,860.39 563,043.02 2.56 806.04 MWD+IFR-AK-CAZ-SC(3) 3,794.87 51.12 29.83 3,351.21 3,253.28 1,229.38 -1,137,092.48 5,969,922.52 563,081.56 3.48 864.12 MWD+IFR-AK-CAZ-SC(3) 3,889.87 52.46 25.17 3,409.99 3,312.06 1,295.57 -1,137,058.06 5,969,988.81 563,116.04 4.10 926.73 MWD+IFR-AK-CAZ-SC(3) 10/12/2015 12:05:20PM Page 3 COMPASS 5000.1 Build 74 • • ConocoPhillips • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-153 Project: Kuparuk River Unit TVD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25) Well: 1C-153 North Reference: Grid Wellbore: 1C-153 Survey Calculation Method: Minimum Curvature Design: 1C-153 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 3,981.06 54.23 19.28 3,464.46 3,366.53 1,363.26 -1,137,030.45 5,970,056.60 563,143.69 5.53 991.48 MWD+IFR-AK-CAZ-SC(3) 4,078.20 57.07 14.24 3,519.29 3,421.36 1,440.02 -1,137,007.39 5,970,133.48 563,166.78 5.18 1,065.69 MWD+IFR-AK-CAZ-SC(3)' 4,170.37 61.07 10.28 3,566.66 3,468.73 1,517.25 -1,136,990.67 5,970,210.83 563,183.54 5.69 1,140.98 MWD+IFR-AK-CAZ-SC(3) 4,267.86 63.45 8.45 3,612.04 3,514.11 1,602.38 -1,136,976.64 5,970,296.09 563,197.58 2.95 1,224.38 MWD+IFR-AK-CAZ-SC(3) 4,361.58 62.29 8.72 3,654.78 3,556.85 1,684.85 -1,136,964.19 5,970,378.69 563,210.05 1.26 1,305.29 MWD+IFR-AK-CAZ-SC(3) 4,402.92 61.92 8.74 3,674.12 3,576.19 1,720.96 -1,136,958.65 5,970,414.86 563,215.60 0.90 1,340.71 MWD+IFR-AK-CAZ-SC(3) 4,454.73 62.93 8.37 3,698.10 3,600.17 1,766.38 -1,136,951.82 5,970,460.34 563,222.45 2.05 1,385.26 MWD+IFR-AK-CAZ-SC(3) 4,551.99 66.57 2.37 3,739.62 3,641.69 1,853.90 -1,136,943.66 5,970,547.99 563,230.62 6.72 1,471.61 MWD+IFR-AK-CAZ-SC(3) 4,645.86 72.01 357.48 3,772.82 3,674.89 1,941.63 -1,136,943.84 5,970,635.86 563,230.43 7.57 1,558.96 MWD+IFR-AK-CAZ-SC(3) 4,741.03 76.87 351.55 3,798.36 3,700.43 2,032.82 -1,136,952.65 5,970,727.19 563,221.61 7.88 1,650.57 MWD+IFR-AK-CAZ-SC(3) 4,836.26 79.05 343.46 3,818.25 3,720.32 2,123.65 -1,136,972.81 5,970,818.16 563,201.42 8.62 1,742.91 MWD+IFR-AK-CAZ-SC(3) 4,931.07 81.45 337.55 3,834.32 3,736.39 2,211.68 -1,137,003.99 5,970,906.33 563,170.19 6.64 1,833.52 MVVD+IFR-AK-CAZ-SC(3) 5,022.40 83.75 331.52 3,846.10 3,748.17 2,293.40 -1,137,042.92 5,970,988.18 563,131.20 7.01 1,918.58 MWD+IFR-AK-CAZ-SC(3) 5,058.28 84.48 329.77 3,849.77 3,751.84 2,324.51 -1,137,060.42 5,971,019.33 563,113.68 5.26 1,951.21 MWD+IFR-AK-CAZ-SC(3) 5,129.00 84.92 325.50 3,856.31 3,758.38 2,383.97 -1,137,098.11 5,971,078.89 563,075.93 6.05 2,013.99 NOT an Actual Survey 9 518"x12-1/4" 5,144.73 85.02 324.55 3,857.69 3,759.76 2,396.81 -1,137,107.09 5,971,091.75 563,066.94 6.05 2,027.63 MWD+IFR-AK-CAZ-SC(4) 5,239.65 88.01 324.89 3,863.46 3,765.53 2,474.15 -1,137,161.80 5,971,169.20 563,012.14 3.17 2,109.83 MWD+IFR-AK-CAZ-SC(4) 5,333.11 92.15 326.04 3,863.33 3,765.40 2,551.12 -1,137,214.77 5,971,246.29 562,959.09 4.60 2,191.50 MWD+IFR-AK-CAZ-SC(4) 5,428.51 90.24 327.69 3,861.34 3,763.41 2,630.98 -1,137,266.90 5,971,326.28 562,906.87 2.65 2,275.97 MWD+IFR-AK-CAZ-SC(4) 5,524.45 89.27 329.48 3,861.75 3,763.82 2,712.86 -1,137,316.91 5,971,408.28 562,856.79 2.12 2,362.23 MWD+IFR-AK-CAZ-SC(4) 5,618.40 89.90 332.24 3,862.43 3,764.50 2,794.91 -1,137,362.65 5,971,490.45 562,810.98 3.01 2,448.27 MWD+IFR-AK-CAZ-SC(4) 5,714.04 90.59 335.56 3,862.02 3,764.09 2,880.78 -1,137,404.72 5,971,576.46 562,768.85 3.55 2,537.76 MWD+IFR-AK-CAZ-SC(4) 5,808.99 89.88 342.41 3,861.63 3,763.70 2,969.36 -1,137,438.75 5,971,665.18 562,734.77 7.25 2,629.18 MWD+IFR-AK-CAZ-SC(4) 5,903.82 91.66 346.37 3,860.36 3,762.43 3,060.66 -1,137,464.26 5,971,756.62 562,709.22 4.58 2,722.50 MWD+IFR-AK-CAZ-SC(4) 5,998.72 92.46 345.30 3,856.95 3,759.02 3,152.62 -1,137,487.46 5,971,848.71 562,685.97 1.41 2,816.25 MWD+IFR-AK-CAZ-SC(4) 6,092.39 90.17 343.08 3,854.80 3,756.87 3,242.71 -1,137,512.97 5,971,938.94 562,660.42 3.40 2,908.36 MWD+IFR-AK-CAZ-SC(4) 6,187.90 88.62 338.63 3,855.80 3,757.87 3,332.90 -1,137,544.29 5,972,029.28 562,629.06 4.93 3,001.13 MWD+IFR-AK-CAZ-SC(4) 6,281.90 89.52 339.90 3,857.33 3,759.40 3,420.80 -1,137,577.56 5,972,117.31 562,595.74 1.66 3,091.80 MWD+IFR-AK-CAZ-SC(4) 6,376.69 90.07 344.32 3,857.67 3,759.74 3,510.98 -1,137,606.67 5,972,207.63 562,566.58 4.70 3,184.35 MWD+IFR-AK-CAZ-SC(4) 6,472.54 89.66 347.71 3,857.90 3,759.97 3,603.98 -1,137,629.83 5,972,300.77 562,543.39 3.56 3,279.13 MWD+IFR-AK-CAZ-SC(4) 6,567.58 89.39 350.50 3,858.68 3,760.75 3,697.29 -1,137,647.79 5,972,394.23 562,525.40 2.95 3,373.73 MWD+IFR-AK-CAZ-SC(4) 6,662.18 89.66 353.58 3,859.47 3,761.54 3,790.97 -1,137,660.89 5,972,488.05 562,512.28 3.27 3,468.23 MWD+IFR-AK-CAZ-SC(4) 6,756.48 90.84 354.41 3,859.06 3,761.13 3,884.75 -1,137,670.75 5,972,581.97 562,502.40 1.53 3,562.52 MWD+IFR-AK-CAZ-SC(4) 6,851.28 90.52 354.19 3,857.93 3,760.00 3,979.07 -1,137,680.17 5,972,676.44 562,492.97 0.41 3,657.31 MWD+IFR-AK-CAZ-SC(4) 6,946.41 90.11 353.17 3,857.41 3,759.48 4,073.62 -1,137,690.64 5,972,771.14 562,482.49 1.16 3,752.43 MWD+IFR-AK-CAZ-SC(4) 7,041.26 89.42 350.77 3,857.80 3,759.87 4,167.53 -1,137,703.89 5,972,865.19 562,469.22 2.63 3,847.17 MWD+IFR-AK-CAZ-SC(4) 7,135.76 89.21 346.51 3,858.93 3,761.00 4,260.15 -1,137,722.50 5,972,957.96 562,450.58 4.51 3,941.15 MWD+IFR-AK-CAZ-SC(4) 7,230.47 90.14 345.07 3,859.46 3,761.53 4,351.96 -1,137,745.74 5,973,049.91 562,427.30 1.81 4,034.75 MWD+IFR-AK-CAZ-SC(4) 7,325.22 90.11 343.78 3,859.26 3,761.33 4,443.23 -1,137,771.18 5,973,141.32 562,401.82 1.36 4,128.03 MWD+IFR-AK-CAZ-SC(4) 10/12/2015 12:05:20PM Page 4 COMPASS 5000.1 Build 74 . ConocoPhillips • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-153 Project: Kuparuk River Unit TVD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25) Well: 1C-153 North Reference: Grid Wellbore: 1C-153 Survey Calculation Method: Minimum Curvature Design: 1C-153 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,420.21 90.21 342.03 3,858.99 3,761.06 4,534.02 -1,137,799.10 5,973,232.25 562,373.85 1.85 4,221.07 MWD+IFR-AK-CAZ-SC(4) 7,515.35 90.62 340.56 3,858.30 3,760.37 4,624.13 -1,137,829.61 5,973,322.50 562,343.30 1.60 4,313.68 MWD+IFR-AK-CAZ-SC(4) 7,610.49 90.65 338.61 3,857.25 3,759.32 4,713.28 -1,137,862.79 5,973,411.79 562,310.07 2.05 4,405.59 MWD+IFR-AK-CAZ-SC(4) 7,705.65 90.63 340.00 3,856.19 3,758.26 4,802.30 -1,137,896.42 5,973,500.94 562,276.39 1.46 4,497.40 MWD+IFR-AK-CAZ-SC(4) 7,799.87 88.86 340.01 3,856.61 3,758.68 4,890.83 -1,137,928.64 5,973,589.61 562,244.12 1.88 4,588.60 MWD+IFR-AK-CAZ-SC(4) 7,895.46 88.97 342.38 3,858.42 3,760.49 4,981.30 -1,137,959.44 5,973,680.21 562,213.27 2.48 4,681.59 MWD+IFR-AK-CAZ-SC(4) 7,990.09 90.34 345.94 3,858.99 3,761.06 5,072.32 -1,137,985.26 5,973,771.37 562,187.41 4.03 4,774.66 MWD+IFR-AK-CAZ-SC(4) 8,083.85 88.70 344.60 3,859.77 3,761.84 5,162.99 -1,138,009.10 5,973,862.18 562,163.53 2.26 4,867.19 MWD+IFR-AK-CAZ-SC(4) 8,178.89 87.98 343.14 3,862.52 3,764.59 5,254.24 -1,138,035.49 5,973,953.58 562,137.10 1.71 4,960.55 MWD+IFR-AK-CAZ-SC(4) 8,274.84 87.92 343.28 3,865.96 3,768.03 5,346.04 -1,138,063.19 5,974,045.52 562,109.36 0.16 5,054.57 MWD+IFR-AK-CAZ-SC(4) 8,368.01 90.58 344.73 3,867.18 3,769.25 5,435.59 -1,138,088.86 5,974,135.21 562,083.65 3.25 5,146.15 MWD+IFR-AK-CAZ-SC(4) 8,464.13 89.10 347.61 3,867.45 3,769.52 5,528.91 -1,138,111.83 5,974,228.67 562,060.65 3.37 5,241.24 MWD+IFR-AK-CAZ-SC(4) 8,559.54 93.46 347.10 3,865.31 3,767.38 5,621.96 -1,138,132.71 5,974,321.86 562,039.74 4.60 5,335.85 MWD+IFR-AK-CAZ-SC(4) 8,652.91 94.29 346.66 3,859.00 3,761.07 5,712.68 -1,138,153.85 5,974,412.73 562,018.56 1.01 5,428.18 MWD+IFR-AK-CAZ-SC(4) 8,747.56 95.47 347.69 3,850.95 3,753.02 5,804.64 -1,138,174.78 5,974,504.82 561,997.60 1.65 5,521.71 MWD+IFR-AK-CAZ-SC(4) 8,841.43 91.62 348.43 3,845.15 3,747.22 5,896.28 -1,138,194.16 5,974,596.61 561,978.19 4.18 5,614.78 MWD+IFR-AK-CAZ-SC(4) 8,937.27 92.10 347.16 3,842.04 3,744.11 5,989.90 -1,138,214.41 5,974,690.38 561,957.91 1.42 5,709.91 MWD+IFR-AK-CAZ-SC(4) 9,032.10 92.88 345.74 3,837.92 3,739.99 6,082.00 -1,138,236.61 5,974,782.62 561,935.68 1.71 5,803.71 MWD+IFR-AK-CAZ-SC(4) 9,127.20 92.54 345.27 3,833.42 3,735.49 6,173.97 -1,138,260.38 5,974,874.73 561,911.86 0.61 5,897.52 MWD+IFR-AK-CAZ-SC(4) 9,221.18 91.22 343.83 3,830.34 3,732.41 6,264.51 -1,138,285.40 5,974,965.40 561,886.80 2.08 5,990.03 MWD+IFR-AK-CAZ-SC(4) 9,315.93 87.84 342.35 3,831.12 3,733.19 6,355.14 -1,138,312.96 5,975,056.17 561,859.21 3.89 6,082.88 MWD+IFR-AK-CAZ-SC(4) 9,412.01 89.19 340.17 3,833.61 3,735.68 6,446.09 -1,138,343.81 5,975,147.26 561,828.31 2.67 6,176.35 MWD+IFR-AK-CAZ-SC(4) 9,506.03 88.56 340.68 3,835.45 3,737.52 6,534.66 -1,138,375.31 5,975,235.97 561,796.76 0.86 6,267.52 MWD+IFR-AK-CAZ-SC(4) 9,601.06 89.16 345.30 3,837.34 3,739.41 6,625.49 -1,138,403.09 5,975,326.94 561,768.93 4.90 6,360.58 MWD+IFR-AK-CAZ-SC(4) 9,696.48 88.39 346.09 3,839.38 3,741.45 6,717.93 -1,138,426.66 5,975,419.52 561,745.33 1,16 6,454.85 MWD+IFR-AK-CAZ-SC(4) 9,791.85 88.87 346.32 3,841.66 3,743.73 6,810.52 -1,138,449.40 5,975,512.25 561,722.56 0.56 6,549.19 MWD+IFR-AK-CAZ-SC(4) 9,886.75 89.69 346.13 3,842.86 3,744.93 6,902.68 -1,138,471.99 5,975,604.56 561,699.93 0.89 6,643.08 MWD+IFR-AK-CAZ-SC(4) 9,982.07 90.14 345.73 3,843.00 3,745.07 6,995.14 -1,138,495.16 5,975,697.16 561,676.72 0.63 6,737.33 MWD+IFR-AK-CAZ-SC(4) 10,076.85 90.11 345.25 3,842.79 3,744.86 7,086.90 -1,138,518.91 5,975,789.06 561,652.94 0.51 6,830.93 MWD+IFR-AK-CAZ-SC(4) 10,169.44 90.17 345.72 3,842.56 3,744.63 7,176.53 -1,138,542.12 5,975,878.83 561,629.70 0.51 6,922.37 MWD+IFR-AK-CAZ-SC(4) 10,266.20 89.63 346.04 3,842.73 3,744.80 7,270.37 -1,138,565.72 5,975,972.81 561,606.06 0.65 7,018.03 MWD+IFR-AK-CAZ-SC(4) 10,360.67 89.63 346.15 3,843.34 3,745.41 7,362.07 -1,138,588.42 5,976,064.65 561,583.32 0.12 7,111.48 MWD+IFR-AK-CAZ-SC(4) 10,455.44 89.52 344.72 3,844.05 3,746.12 7,453.79 -1,138,612.25 5,976,156.51 561,559.45 1.51 7,205.05 MW0+IFR-AK-CAZ-SC(4) 10,550.21 90.17 344.58 3,844.30 3,746.37 7,545.18 -1,138,637.34 5,976,248.04 561,534.33 0.70 7,298.41 MWD+IFR-AK-CAZ-SC(4) 10,645.32 90.14 345.95 3,844.05 3,746.12 7,637.16 -1,138,661.53 5,976,340.17 561,510.10 1.44 7,392.28 MWD+IFR-AK-CAZ-SC(4) 10,739.04 90.45 346.91 3,843.56 3,745.63 7,728.26 -1,138,683.52 5,976,431.41 561,488.08 1.08 7,485.06 MWD+IFR-AK-CAZ-SC(4) 10,834.14 89.97 346.66 3,843.21 3,745.28 7,820.84 -1,138,705.26 5,976,524.13 561,466.31 0.57 7,579.29 MWD+IFR-AK-CAZ-SC(4) 10,929.00 89.90 344.95 3,843.32 3,745.39 7,912.80 -1,138,728.52 5,976,616.23 561,443.01 1.80 7,673.05 MWD+IFR-AK-CAZ-SC(4) 11,022.67 88.56 344.66 3,844.58 3,746.65 8,003.18 -1,138,753.06 5,976,706.76 561,418.42 1.46 7,765.37 MWD+IFR-AK-CAZ-SC(4) 11,116.20 88.42 343.60 3,847.05 3,749.12 8,093.12 -1,138,778.63 5,976,796.83 561,392.82 1.14 7,857.33 MWD+IFR-AK-CAZ-SC(4) 10/12/2015 12:05:20PM Page 5 COMPASS 5000.1 Build 74 • ConocoPhillips • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-153 Project: Kuparuk River Unit TVD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25) Well: 1C-153 North Reference: Grid Wellbore: 1C-153 Survey Calculation Method: Minimum Curvature Design: 1C-153 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,212.68 88.56 343.62 3,849.59 3,751.66 8,185.64 -1,138,805.85 5,976,889.50 561,365.56 0.15 7,952.03 MWD+IFR-AK-CAZ-SC(4) 11,308.96 89.11 344.83 3,851.55 3,753.62 8,278.28 -1,138,832.01 5,976,982.27 561,339.35 1.38 8,046.73 MWD+IFR-AK-CAZ-SC(4) 11,405.01 89.11 345.97 3,853.04 3,755.11 8,371.21 -1,138,856.22 5,977,075.35 561,315.11 1.19 8,141.55 MWD+IFR-AK-CAZ-SC(4) 11,499.59 88.60 346.62 3,854.93 3,757.00 8,463.08 -1,138,878.62 5,977,167.36 561,292.67 0.87 8,235.14 MWD+IFR-AK-CAZ-SC(4) 11,593.95 88.63 347.88 3,857.21 3,759.28 8,555.08 -1,138,899.44 5,977,259.51 561,271.82 1.34 8,328.71 MWD+IFR-AK-CAZ-SC(4) 11,688.27 88.49 350.08 3,859.58 3,761.65 8,647.63 -1,138,917.46 5,977,352.20 561,253.77 2.34 8,422.55 MWD+IFR-AK-CAZ-SC(4) 11,784.14 88.67 350.39 3,861.95 3,764.02 8,742.08 -1,138,933.72 5,977,446.80 561,237.49 0.37 8,518.12 MWD+IFR-AK-CAZ-SC(4) 11,879.23 88.67 348.53 3,864.16 3,766.23 8,835.54 -1,138,951.11 5,977,540.40 561,220.08 1.96 8,612.81 MWD+IFR-AK-CAZ-SC(4) 11,974.12 88.25 346.98 3,866.71 3,768.78 8,928.23 -1,138,971.22 5,977,633.23 561,199.93 1.69 8,707.00 MWD+IFR-AK-CAZ-SC(4) 12,066.15 88.18 346.22 3,869.58 3,771.65 9,017.71 -1,138,992.54 5,977,722.85 561,178.58 0.83 8,798.10 MWD+IFR-AK-CAZ-SC(4) 12,162.98 87.67 344.22 3,873.09 3,775.16 9,111.27 -1,139,017.22 5,977,816.56 561,153.86 2.13 8,893.59 MWD+IFR-AK-CAZ-SC(4) 12,258.54 87.74 343.01 3,876.91 3,778.98 9,202.88 -1,139,044.16 5,977,908.30 561,126.88 1.27 8,987.34 MWD+IFR-AK-CAZ-SC(4) 12,352.55 87.91 341.02 3,880.48 3,782.55 9,292.23 -1,139,073.16 5,977,997.79 561,097.83 2.12 9,079.05 MWD+IFR-AK-CAZ-SC(4) 12,446.98 87.53 341.01 3,884.24 3,786.31 9,381.45 -1,139,103.86 5,978,087.15 561,067.09 0.40 9,170.79 MWD+IFR-AK-CAZ-SC(4) 12,541.17 86.98 342.01 3,888.75 3,790.82 9,470.67 -1,139,133.69 5,978,176.51 561,037.21 1.21 9,262.45 MWD+IFR-AK-CAZ-SC(4) 12,636.79 87.11 344.63 3,893.68 3,795.75 9,562.14 -1,139,161.10 5,978,268.12 561,009.76 2.74 9,356.12 MWD+IFR-AK-CAZ-SC(4) 12,731.38 89.20 347.58 3,896.72 3,798.79 9,653.90 -1,139,183.80 5,978,360.02 560,987.03 3.82 9,449.62 MWD+IFR-AK-CAZ-SC(4) 12,761.91 88.87 350.01 3,897.24 3,799.31 9,683.84 -1,139,189.73 5,978,390.01 560,981.09 8.03 9,479.99 MWD+IFR-AK-CAZ-SC(4) 12,807.00 88.87 350.01 3,898.13 3,800.20 9,728.24 -1,139,197.55 5,978,434.47 560,973.25 0.00 9,524.93 NOT anActual Survey 4-1/2"x6-314" 12,825.00 88.87 350.01 3,898.48 3,800.55 9,745.96 -1,139,200.67 5,978,452.22 560,970.13 0.00 9,542.87 PROJECTED to TD 10/12/2015 12:05:20PM Page 6 COMPASS 5000.1 Build 74 • • • C.) s a a oro o;q o a) a = 21 = o4a€2o qo c 0 a) o0 a) o - •• EQ `aQ e w75 co a = a _0 _Q u) z Q Q Q o w o co---. • 1:3 .� o = C 00 c � ate) O _CD c z E m o a, CD Cl) O Li O a) C U cn > rz 0 0 c U U C C Q. L 0 9' 0 U > 03 '� a a cv . 0 ii > w> uwaccn a, 0 00CI 2 Q — a; > W 0 m a) 6 J N ca c/) L 0 Q CC LL y-+ a) 0 • • 215116 26409 RECEIVED OCT 29 261'.: FINAL F ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1C Pad 1C-153 Definitive Survey Report 12 October, 2015 NAD 83 • ConocoPhillips • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1C-153 Project: Kuparuk River Unit TVD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25) Well: 1C-153 North Reference: True Wellbore: 1C-153 Survey Calculation Method: Minimum Curvature Design: 1C-153 Database: EDM Production Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 1C-153 Well Position +N/-S 0.00 usft Northing: 5,968,691.24 usft Latitude: 70°19'31.381 N +EI-W 0.00 usft Easting: 1,701,926.89 usft Longitude: 149°30'4.297 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 57.60 usft Wellbore 1C-153 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 9/21/2015 18.95 80.99 57,506 Design 1C-153 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 40.33 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 40.33 0.00 0.00 355.00 Survey Program Date 10/12/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 78.31 735.51 1C-153 Srvy#1 -GYD-GC-SS(1C-153) GYD-GC-SS Gyrodata gyro single shots 9/22/2015 8:55: 793.29 2,757.10 1C-153 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/22/2015 8:57: 2,820.54 5,058.28 1C-153 Srvy#3-MWD+IFR-AK-CAZ-SC MVVD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/22/2015 9:00: 5,144.73 12,761.91 1C-153 Srvy#4-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/5/2015 9:03: Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 40.33 0.00 0.00 40.33 -57.60 0.00 0.00 5,968,691.24 1,701,926.89 0.00 0.00 UNDEFINED 78.31 0.64 128.57 78.31 -19.62 -0.13 0.17 5,968,691.11 1,701,927.06 1.69 -0.15 GYD-GC-SS(1) 120.00 0.42 100.85 120.00 22.07 -0.31 0.50 5,968,690.94 1,701,927.39 0.80 -0.35 NOT an Actual Survey 20"x34" 172.94 0.44 41.63 172.94 75.01 -0.19 0.82 5,968,691.05 1,701,927.71 0.80 -0.26 GYD-GC-SS(1) 267.22 1.31 22.36 267.20 169.27 1.08 1.47 5,968,692.33 1,701,928.35 0.96 0.94 GYD-GC-SS(1) 363.97 2.65 27.23 363.89 265.96 4.09 2.92 5,968,695.35 1,701,929.77 1.39 3.82 GYD-GC-SS(1) 459.27 5.75 18.89 458.93 361.00 10.57 5.47 5,968,701.85 1,701,932.27 3.31 10.05 GYD-GC-SS(1) 551.31 8.32 17.90 550.27 452.34 21.27 9.01 5,968,712.58 1,701,935.72 2.80 20.40 GYD-GC-SS(1) 641.81 12.22 31.18 639.31 541.38 35.70 15.98 5,968,727.06 1,701,942.58 5.01 34.17 GYD-GC-SS(1) 735.51 14.98 35.49 730.38 632.45 54.05 28.15 5,968,745.51 1,701,954.59 3.14 51.39 GYD-GC-SS(1) 10/12/2015 11:04:26AM Page 2 COMPASS 5000.1 Build 74 • ConocoPhillips • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1C-153 Project: Kuparuk River Unit TVD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25) Site: Kuparuk 10 Pad MD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25) Well: 1C-153 North Reference: True Wellbore: 1C-153 Survey Calculation Method: Minimum Curvature Design: 1C-153 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 793.29 15.48 42.83 786.13 688.20 65.78 37.73 5,968,757.32 1,701,964.08 3.44 62.25 MWD+IFR-AK-CAZ-SC(2) 888.22 14.53 47.41 877.83 779.90 83.13 55.11 5,968,774.81 1,701,981.31 1.60 78.02 MWD+IFR-AK-CAZ-SC(2) 983.33 14.15 46.96 969.98 872.05 99.14 72.39 5,968,790.96 1,701,998.46 0.42 92.46 MWD+IFR-AK-CAZ-SC(2) 1,077.89 18.38 42.62 1,060.73 962.80 118.01 90.94 5,968,809.98 1,702,016.85 4.65 109.64 MWD+IFR-AK-CAZ-SC(2) 1,171.77 21.47 44.38 1,148.98 1,051.05 141.19 112.99 5,968,833.33 1,702,038.70 3.35 130.80 MWD+IFR-AK-CAZ-SC(2) 1,266.87 21.55 46.01 1,237.46 1,139.53 165.76 137.73 5,968,858.10 1,702,063.24 0.63 153.12 MWD+IFR-AK-CAZ-SC(2) 1,361.48 21.10 50.93 1,325.60 1,227.67 188.56 163.45 5,968,881.11 1,702,088.77 1.95 173.60 MWD+IFR-AK-CAZ-SC(2) 1,456.35 21.71 53.81 1,413.93 1,316.00 209.69 190.87 5,968,902.46 1,702,116.02 1.28 192.25 MWD+IFR-AK-CAZ-SC(2) 1,550.77 20.09 55.93 1,502.14 1,404.21 229.08 218.40 5,968,922.08 1,702,143.38 1.89 209.18 MWD+IFR-AK-CAZ-SC(2) 1,645.11 23.00 52.74 1,589.88 1,491.95 249.32 246.50 5,968,942.55 1,702,171.31 3.32 226.89 MWD+IFR-AK-CAZ-SC(2) 1,739.78 23.98 53.92 1,676.70 1,578.77 271.85 276.77 5,968,965.32 1,702,201.39 1.15 246.70 MWD+IFR-AK-CAZ-SC(2) 1,834.95 28.10 53.99 1,762.19 1,664.26 296.43 310.54 5,968,990.17 1,702,234.96 4.33 268.24 MWD+IFR-AK-CAZ-SC(2) 1,929.53 28.55 55.52 1,845.45 1,747.52 322.32 347.19 5,969,016.36 1,702,271.39 0.90 290.83 MWD+IFR-AK-CAZ-SC(2) 2,024.25 31.27 56.84 1,927.55 1,829.62 348.59 386.44 5,969,042.95 1,702,310.42 2.95 313.58 MWD+IFR-AK-CAZ-SC(2) 2,118.12 32.90 56.42 2,007.08 1,909.15 376.01 428.07 5,969,070.71 1,702,351.83 1.75 337.27 MWD+IFR-AK-CAZ-SC(2) 2,212.46 33.85 58.11 2,085.86 1,987.93 404.07 471.73 5,969,099.12 1,702,395.25 1.41 361.42 MWD+IFR-AK-CAZ-SC(2) 2,307.29 33.34 63.08 2,164.87 2,066.94 429.82 517.40 5,969,125.25 1,702,440.70 2.95 383.09 MWD+IFR-AK-CAZ-SC(2) 2,401.85 32.45 63.75 2,244.26 2,146.33 452.81 563.32 5,969,148.61 1,702,486.43 1.02 401.99 MWD+IFR-AK-CAZ-SC(2) 2,495.30 32.49 64.72 2,323.11 2,225.18 474.62 608.50 5,969,170.78 1,702,531.42 0.56 419.77 MWD+IFR-AK-CAZ-SC(2) 2,590.75 32.26 62.51 2,403.72 2,305.79 497.32 654.28 5,969,193.86 1,702,577.01 1.26 438.41 MWD+IFR-AK-CAZ-SC(2) 2,685.96 31.97 61.26 2,484.36 2,386.43 521.17 698.92 5,969,218.07 1,702,621.45 0.76 458.27 MWD+IFR-AK-CAZ-SC(2) 2,757.10 31.99 61.52 2,544.71 2,446.78 539.21 732.00 5,969,236.38 1,702,654.38 0.20 473.36 MWD+IFR-AK-CAZ-SC(2) 2,820.54 31.83 60.50 2,598.56 2,500.63 555.46 761.33 5,969,252.87 1,702,683.57 0.89 487.00 MWD+IFR-AK-CAZ-SC(3) 2,831.50 31.88 60.48 2,607.87 2,509.94 558.31 766.37 5,969,255.76 1,702,688.58 0.48 489.40NOT an Actual Su rrey 13 318"x16" 2,893.36 32.17 60.37 2,660.31 2,562.38 574.50 794.90 5,969,272.18 1,702,716.97 0.48 503.04 MWD+IFR-AK-CAZ-SC(3) 2,948.09 32.66 60.33 2,706.52 2,608.59 589.02 820.39 5,969,286.90 1,702,742.35 0.90 515.27 MWD+IFR-AK-CAZ-SC(3) 3,046.11 32.81 59.13 2,788.97 2,691.04 615.74 866.17 5,969,313.99 1,702,787.90 0.68 537.90 MWD+IFR-AK-CAZ-SC(3) 3,141.09 33.84 54.73 2,868.34 2,770.41 644.21 909.86 5,969,342.83 1,702,831.35 2.77 562.46 MWD+IFR-AK-CAZ-SC(3) 3,187.35 35.10 51.56 2,906.48 2,808.55 659.92 930.79 5,969,358.70 1,702,852.15 4.74 576.29 MWD+IFR-AK-CAZ-SC(3) 3,236.01 35.65 50.13 2,946.16 2,848.23 677.71 952.63 5,969,376.67 1,702,873.84 2.04 592.10 MWD+IFR-AK-CAZ-SC(3) 3,330.86 37.30 46.93 3,022.44 2,924.51 715.06 994.85 5,969,414.36 1,702,915.75 2.65 625.63 MWD+IFR-AK-CAZ-SC(3) 3,386.02 38.10 44.07 3,066.08 2,968.15 738.70 1,018.90 5,969,438.20 1,702,939.60 3.49 647.09 MWD+IFR-AK-CAZ-SC(3) 3,443.56 39.24 41.41 3,111.01 3,013.08 765.11 1,043.28 5,969,464.80 1,702,963.77 3.50 671.27 MWD+IFR-AK-CAZ-SC(3) 3,509.10 42.91 39.41 3,160.41 3,062.48 797.91 1,071.17 5,969,497.82 1,702,991.38 5.95 701.51 MWD+IFR-AK-CAZ-SC(3) 3,542.88 43.63 38.30 3,185.01 3,087.08 815.94 1,085.69 5,969,515.97 1,703,005.76 3.10 718.21 MWD+IFR-AK-CAZ-SC(3) 3,604.10 47.53 35.84 3,227.85 3,129.92 850.84 1,112.02 5,969,551.08 1,703,031.79 6.99 750.68 MW1J+IFR-AK-CAZ-SC(3) 3,641.07 48.75 35.49 3,252.52 3,154.59 873.21 1,128.07 5,969,573.58 1,703,047.66 3.37 771.56 MWD+IFR-AK-CAZ-SC(3) 3,700.29 49.97 34.30 3,291.09 3,193.16 910.06 1,153.77 5,969,610.64 1,703,073.05 2.56 806.04 MWD+IFR-AK-CAZ-SC(3) 3,794.87 51.12 30.30 3,351.21 3,253.28 971.78 1,192.76 5,969,672.67 1,703,111.53 3.48 864.12 MWD+IFR-AK-CAZ-SC(3) 3,889.87 52.46 25.64 3,409.99 3,312.06 1,037.68 1,227.73 5,969,738.85 1,703,145.96 4.10 926.73 MWD+IFR-AK-CAZ-SC(3) 10/12/2015 11:04:26AM Page 3 COMPASS 5000.1 Build 74 • ConocoPhillips • ' Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1C-153 Project: Kuparuk River Unit TVD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25) Well: 1C-153 North Reference: True Wellbore: 1C-153 Survey Calculation Method: Minimum Curvature Design: 1C-153 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/700') (ft) Survey Tool Name 3,981.06 54.23 19.75 3,464.46 3,366.53 1,105.14 1,255.89 5,969,806.53 1,703,173.56 5.53 991.48 MWD+IFR-AK-CAZ-SC(3) 4,078.20 57.07 14.71 3,519.29 3,421.36 1,181.71 1,279.58 5,969,883.28 1,703,196.61 5.18 1,065.69 MWD+IFR-AK-CAZ-SC(3) 4,170.37 61.07 10.75 3,566.66 3,468.73 1,258.80 1,296.93 5,969,960.51 1,703,213.34 5.69 1,140.98 MWD+IFR-AK-CAZ-SC(3) 4,267.86 63.45 8.92 3,612.04 3,514.11 1,343.81 1,311.66 5,970,045.63 1,703,227.36 2.95 1,224.38 MWD+IFR-AK-CAZ-SC(3) 4,361.58 62.29 9.19 3,654.78 3,556.85 1,426.18 1,324.78 5,970,128.09 1,703,239.81 1.26 1,305.29 MWD+IFR-AK-CAZ-SC(3) 4,402.92 61.92 9.21 3,674.12 3,576.19 1,462.25 1,330.62 5,970,164.20 1,703,245.36 0.90 1,340.71 MWD+IFR-AK-CAZ-SC(3) 4,454.73 62.93 8.84 3,698.10 3,600.17 1,507.60 1,337.83 5,970,209.61 1,703,252.19 2.05 1,385.26 MWD+IFR-AK-CAZ-SC(3) 4,551.99 66.57 2.84 3,739.62 3,641.69 1,595.05 1,346.70 5,970,297.12 1,703,260.34 6.72 1,471.61 MWD+IFR-AK-CAZ-SC(3) 4,645.86 72.01 357.95 3,772.82 3,674.89 1,682.79 1,347.24 5,970,384.85 1,703,260.16 7.57 1,558.96 MWD+IFR-AK-CAZ-SC(3) 4,741.03 76.87 352.02 3,798.36 3,700.43 1,774.04 1,339.18 5,970,476.02 1,703,251.35 7.88 1,650.57 MWD+IFR-AK-CAZ-SC(3) 4,836.26 79.05 343.93 3,818.25 3,720.32 1,865.04 1,319.76 5,970,566.85 1,703,231.20 8.62 1,742.91 MWD+IFR-AK-CAZ-SC(3) 4,931.07 81.45 338.02 3,834.32 3,736.39 1,953.32 1,289.30 5,970,654.87 1,703,200.02 6.64 1,833.52 MWD+IFR-AK-CAZ-SC(3) 5,022.40 83.75 331.99 3,846.10 3,748.17 2,035.36 1,251.05 5,970,736.59 1,703,161.09 7.01 1,918.58 MWD+IFR-AK-CAZ-SC(3) 5,058.28 84.48 330.24 3,849.77 3,751.84 2,066.61 1,233.81 5,970,767.69 1,703,143.60 5.26 1,951.21 MWD+IFR-AK-CAZ-SC(3) 5,129.00 84.92 325.97 3,856.31 3,758.38 2,126.38 1,196.61 5,970,827.15 1,703,105.91 6.05 2,013.99 MWD+IFR-AK-CAZ-SC(4) NOT an Actual Survey 9 5/8"x12-1/4" 5,144.73 85.02 325.02 3,857.69 3,759.76 2,139.29 1,187.73 5,970,839.99 1,703,096.93 6.05 2,027.63 MWD+IFR-AK-CAZ-SC(4) 5,239.65 88.01 325.36 3,863.46 3,765.53 2,217.07 1,133.65 5,970,917.31 1,703,042.22 3.17 2,109.83 MWD+IFR-AK-CAZ-SC(4) 5,333.11 92.15 326.51 3,863.33 3,765.40 2,294.47 1,081.31 5,970,994.28 1,702,989.26 4.60 2,191.50 MWD+IFR-AK-CAZ-SC(4) 5,428.51 90.24 328.16 3,861.34 3,763.41 2,374.76 1,029.84 5,971,074.13 1,702,937.13 2.65 2,275.97 MWD+IFR-AK-CAZ-SC(4) 5,524.45 89.27 329.95 3,861.75 3,763.82 2,457.04 980.51 5,971,156.00 1,702,887.13 2.12 2,362.23 MWD+IFR-AK-CAZ-SC(4) 5,618.40 89.90 332.71 3,862.43 3,764.50 2,539.46 935.44 5,971,238.04 1,702,841.39 3.01 2,448.27 MWD+IFR-AK-CAZ-SC(4) 5,714.04 90.59 336.03 3,862.02 3,764.09 2,625.68 894.08 5,971,323.90 1,702,799.33 3.55 2,537.76 MWD+IFR-AK-CAZ-SC(4) 5,808.99 89.88 342.88 3,861.63 3,763.70 2,714.53 860.78 5,971,412.48 1,702,765.30 7.25 2,629.18 MWD+IFR-AK-CAZ-SC(4) 5,903.82 91.66 346.84 3,860.36 3,762.43 2,806.04 836.02 5,971,503.77 1,702,739.80 4.58 2,722.50 MWD+IFR-AK-CAZ-SC(4) 5,998.72 92.46 345.77 3,856.95 3,759.02 2,898.18 813.56 5,971,595.71 1,702,716.59 1.41 2,816.25 MWD+IFR-AK-CAZ-SC(4) 6,092.39 90.17 343.55 3,854.80 3,756.87 2,988.48 788.79 5,971,685.80 1,702,691.08 3.40 2,908.36 MWD+IFR-AK-CAZ-SC(4) 6,187.90 88.62 339.10 3,855.80 3,757.87 3,078.93 758.22 5,971,775.99 1,702,659.77 4.93 3,001.13 MWD+IFR-AK-CAZ-SC(4) 6,281.90 89.52 340.37 3,857.33 3,759.40 3,167.10 725.67 5,971,863.88 1,702,626.50 1.66 3,091.80 MWD+IFR-AK-CAZ-SC(4) 6,376.69 90.07 344.79 3,857.67 3,759.74 3,257.52 697.30 5,971,954.05 1,702,597.40 4.70 3,184.35 MWD+IFR-AK-CAZ-SC(4) 6,472.54 89.66 348.18 3,857.90 3,759.97 3,350.70 674.90 5,972,047.04 1,702,574.24 3.56 3,279.13 MWD+IFR-AK-CAZ-SC(4) 6,567.58 89.39 350.97 3,858.68 3,760.75 3,444.16 657.71 5,972,140.34 1,702,556.28 2.95 3,373.73 MWD+IFR-AK-CAZ-SC(4) 6,662.18 89.66 354.05 3,859.47 3,761.54 3,537.94 645.38 5,972,234.01 1,702,543.18 3.27 3,468.23 MWD+IFR-AK-CAZ-SC(4) 6,756.48 90.84 354.88 3,859.06 3,761.13 3,631.79 636.28 5,972,327.78 1,702,533.32 1.53 3,562.52 MWD+IFR-AK-CAZ-SC(4) 6,851.28 90.52 354.66 3,857.93 3,760.00 3,726.19 627.64 5,972,422.09 1,702,523.91 0.41 3,657.31 MWD+IFR-AK-CAZ-SC(4) 6,946.41 90.11 353.64 3,857.41 3,759.48 3,820.82 617.94 5,972,516.63 1,702,513.43 1.16 3,752.43 MWD+IFR-AK-CAZ-SC(4) 7,041.26 89.42 351.24 3,857.80 3,759.87 3,914.84 605.47 5,972,610.54 1,702,500.19 2.63 3,847.17 MWD+IFR-AK-CAZ-SC(4) 7,135.76 89.21 346.98 3,858.93 3,761.00 4,007.61 587.62 5,972,703.15 1,702,481.58 4.51 3,941.15 MWD+IFR-AK-CAZ-SC(4) 7,230.47 90.14 345.54 3,859.46 3,761.53 4,099.61 565.12 5,972,794.95 1,702,458.34 1.81 4,034.75 MWD+IFR-AK-CAZ-SC(4) 7,325.22 90.11 344.25 3,859.26 3,761.33 4,191.08 540.43 5,972,886.21 1,702,432.90 1.36 4,128.03 MWD+IFR-AK-CAZ-SC(4) 10/12/2015 11:04:26AM Page 4 COMPASS 5000.1 Build 74 • ConocoPhillips • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1C-153 Project: Kuparuk River Unit TVD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25) Well: 1C-153 North Reference: True Wellbore: 1C-153 Survey Calculation Method: Minimum Curvature Design: 1C-153 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section • (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,420.21 90.21 342.50 3,858.99 3,761.06 4,282.10 513.26 5,972,976.99 1,702,404.98 1.85 4,221.07 MWD+IFR-AK-CAZ-SC(4) 7,515.35 90.62 341.03 3,858.30 3,760.37 4,372.45 483.49 5,973,067.09 1,702,374.48 1.60 4,313.68 MWD+IFR-AK-CAZ-SC(4) 7,610.49 90.65 339.08 3,857.25 3,759.32 4,461.88 451.04 5,973,156.23 1,702,341.30 2.05 4,405.59 MWD+IFR-AK-CAZ-SC(4) 7,705.65 90.63 340.47 3,856.19 3,758.26 4,551.16 418.14 5,973,245.24 1,702,307.67 1.46 4,497.40 MWD+IFR-AK-CAZ-SC(4) 7,799.87 88.86 340.48 3,856.61 3,758.68 4,639.96 386.66 5,973,333.77 1,702,275.46 1.88 4,588.60 MWD+IFR-AK-CAZ-SC(4) 7,895.46 88.97 342.85 3,858.42 3,760.49 4,730.67 356.59 5,973,424.22 1,702,244.66 2.48 4,681.59 MWD+IFR-AK-CAZ-SC(4) 7,990.09 90.34 346.41 3,858.99 3,761.06 4,821.90 331.52 5,973,515.23 1,702,218.84 4.03 4,774.66 MWD+IFR-AK-CAZ-SC(4) 8,083.85 88.70 345.07 3,859.77 3,761.84 4,912.76 308.42 5,973,605.89 1,702,195.00 2.26 4,867.19 MWD+IFR-AK-CAZ-SC(4) 8,178.89 87.98 343.61 3,862.52 3,764.59 5,004.23 282.78 5,973,697.14 1,702,168.62 1.71 4,960.55 MWD+IFR-AK-CAZ-SC(4) 8,274.84 87.92 343.75 3,865.96 3,768.03 5,096.26 255.84 5,973,788.93 1,702,140.92 0.16 5,054.57 MWD+IFR-AK-CAZ-SC(4) 8,368.01 90.58 345.20 3,867.18 3,769.25 5,186.01 230.90 5,973,878.47 1,702,115.26 3.25 5,146.15 MWD+IFR-AK-CAZ-SC(4) 8,464.13 89.10 348.08 3,867.45 3,769.52 5,279.52 208.70 5,973,971.78 1,702,092.28 3.37 5,241.24 MWD+IFR-AK-CAZ-SC(4) 8,559.54 93.46 347.57 3,865.31 3,767.38 5,372.74 188.59 5,974,064.82 1,702,071.41 4.60 5,335.85 MWD+IFR-AK-CAZ-SC(4) 8,652.91 94.29 347.13 3,859.00 3,761.07 5,463.63 168.19 5,974,155.54 1,702,050.27 1.01 5,428.18 MWD+IFR-AK-CAZ-SC(4) 8,747.56 95.47 348.16 3,850.95 3,753.02 5,555.75 148.01 5,974,247.48 1,702,029.34 1.65 5,521.71 MWD+IFR-AK-CAZ-SC(4) 8,841.43 91.62 348.90 3,845.15 3,747.22 5,647.55 129.38 5,974,339.12 1,702,009.96 4.18 5,614.78 MWD+IFR-AK-CAZ-SC(4) 8,937.27 92.10 347.63 3,842.04 3,744.11 5,741.34 109.90 5,974,432.73 1,701,989.71 1.42 5,709.91 MWD+IFR-AK-CAZ-SC(4) 9,032.10 92.88 346.21 3,837.92 3,739.99 5,833.62 88.46 5,974,524.82 1,701,967.52 1.71 5,803.71 MWD+IFR-AK-CAZ-SC(4) 9,127.20 92.54 345.74 3,833.42 3,735.49 5,925.78 65.44 5,974,616.78 1,701,943.75 0.61 5,897.52 MWD+IFR-AK-CAZ-SC(4) 9,221.18 91.22 344.30 3,830.34 3,732.41 6,016.51 41.16 5,974,707.31 1,701,918.73 2.08 5,990.03 MWD+IFR-AK-CAZ-SC(4) 9,315.93 87.84 342.82 3,831.12 3,733.19 6,107.37 14.35 5,974,797.93 1,701,891.18 3.89 6,082.88 MWD+IFR-AK-CAZ-SC(4) 9,412.01 89.19 340.64 3,833.61 3,735.68 6,198.57 -15.76 5,974,888.87 1,701,860.32 2.67 6,176.35 MWD+IFR-AK-CAZ-SC(4) 9,506.03 88.56 341.15 3,835.45 3,737.52 6,287.39 -46.53 5,974,977.43 1,701,828.83 0.86 6,267.52 MWD+IFR-AK-CAZ-SC(4) 9,601.06 89.16 345.77 3,837.34 3,739.41 6,378.44 -73.57 5,975,068.25 1,701,801.05 4.90 6,360.58 MWD+IFR-AK-CAZ-SC(4) 9,696.48 88.39 346.56 3,839.38 3,741.45 6,471.07 -96.38 5,975,160.68 1,701,777.48 1.16 6,454.85 MWD+IFR-AK-CAZ-SC(4) 9,791.85 88.87 346.79 3,841.66 3,743.73 6,563.85 -118.35 5,975,253.27 1,701,754.75 0.56 6,549.19 MWD+IFR-AK-CAZ-SC(4) 9,886.75 89.69 346.60 3,842.86 3,744.93 6,656.19 -140.19 5,975,345.42 1,701,732.16 0.89 6,643.08 MWD+IFR-AK-CAZ-SC(4) 9,982.07 90.14 346.20 3,843.00 3,745.07 6,748.84 -162.60 5,975,437.87 1,701,708.99 0.63 6,737.33 MWD+IFR-AK-CAZ-SC(4) 10,076.85 90.11 345.72 3,842.79 3,744.86 6,840.79 -185.60 5,975,529.62 1,701,685.24 0.51 6,830.93 MWD+IFR-AK-CAZ-SC(4) 10,169.44 90.17 346.19 3,842.56 3,744.63 6,930.61 -208.07 5,975,619.25 1,701,662.04 0.51 6,922.37 MWD+IFR-AK-CAZ-SC(4) 10,266.20 89.63 346.51 3,842.73 3,744.80 7,024.64 -230.90 5,975,713.07 1,701,638.44 0.65 7,018.03 MWD+IFR-AK-CAZ-SC(4) 10,360.67 89.63 346.62 3,843.34 3,745.41 7,116.52 -252.85 5,975,804.76 1,701,615.74 0.12 7,111.48 MWD+IFR-AK-CAZ-SC(4) 10,455.44 89.52 345.19 3,844.05 3,746.12 7,208.43 -275.93 5,975,896.47 1,701,591.91 1.51 7,205.05 MWD+IFR-AK-CAZ-SC(4) 10,550.21 90.17 345.05 3,844.30 3,746.37 7,300.02 -300.26 5,975,987.85 1,701,566.83 0.70 7,298.41 MWD+IFR-AK-CAZ-SC(4) 10,645.32 90.14 346.42 3,844.05 3,746.12 7,392.20 -323.70 5,976,079.83 1,701,542.64 1.44 7,392.28 MVVD+IFR-AK-CAZ-SC(4) 10,739.04 90.45 347.38 3,843.56 3,745.63 7,483.48 -344.94 5,976,170.92 1,701,520.65 1.08 7,485.06 MWD+IFR-AK-CAZ-SC(4) 10,834.14 89.97 347.13 3,843.21 3,745.28 7,576.23 -365.92 5,976,263.49 1,701,498.92 0.57 7,579.29 MWD+IFR-AK-CAZ-SC(4) 10,929.00 89.90 345.42 3,843.32 3,745.39 7,668.38 -388.43 5,976,355.44 1,701,475.66 1.80 7,673.05 MWD+IFR-AK-CAZ-SC(4) 11,022.67 88.56 345.13 3,844.58 3,746.65 7,758.96 -412.23 5,976,445.82 1,701,451.11 1.46 7,765.37 MWD+IFR-AK-CAZ-SC(4) 11,116.20 88.42 344.07 3,847.05 3,749.12 7,849.10 -437.06 5,976,535.74 1,701,425.55 1.14 7,857.33 MWD+IFR-AK-CAZ-SC(4) 10/12/2015 11:04:26AM Page 5 COMPASS 5000.1 Build 74 • • ConocoPhillips 4111 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1C-153 Project: Kuparuk River Unit TVD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Final Surveys:57.6+40.33 @ 97.93usft(Doyon 25) Well: 1C-153 North Reference: True Wellbore: 1C-153 Survey Calculation Method: Minimum Curvature Design: 1C-153 Database: EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/700') (ft) Survey Tool Name 11,212.68 88.56 344.09 3,849.59 3,751.66 7,941.85 -463.52 5,976,628.26 1,701,398.34 0.15 7,952.03 MWD+IFR-AK-CAZ-SC(4) 11,308.96 89.11 345.30 3,851.55 3,753.62 8,034.69 -488.92 5,976,720.88 1,701,372.17 1.38 8,046.73 MWD+IFR-AK-CAZ-SC(4) 11,405.01 89.11 346.44 3,853.04 3,755.11 8,127.82 -512.37 5,976,813.81 1,701,347.96 1.19 8,141.55 MWD+IFR-AK-CAZ-SC(4) 11,499.59 88.60 347.09 3,854.93 3,757.00 8,219.87 -534.02 5,976,905.67 1,701,325.56 0.87 8,235.14 MWD+IFR-AK-CAZ-SC(4) 11,593.95 88.63 348.35 3,857.21 3,759.28 8,312.05 -554.08 5,976,997.67 1,701,304.75 1.34 8,328.71 MWD+IFR-AK-CAZ-SC(4) 11,688.27 88.49 350.55 3,859.58 3,761.65 8,404.74 -571.34 5,977,090.20 1,701,286.73 2.34 8,422.55 MWD+IFR-AK-CAZ-SC(4) 11,784.14 88.67 350.86 3,861.95 3,764.02 8,499.32 -586.82 5,977,184.65 1,701,270.47 0.37 8,518.12 MWD+IFR-AK-CAZ-SC(4) 11,879.23 88.67 349.00 3,864.16 3,766.23 8,592.91 -603.44 5,977,278.09 1,701,253.09 1.96 8,612.81 MWD+IFR-AK-CAZ-SC(4) 11,974.12 88.25 347.45 3,866.71 3,768.78 8,685.77 -622.80 5,977,370.78 1,701,232.97 1.69 8,707.00 MWD+IFR-AK-CAZ-SC(4) 12,066.15 88.18 346.69 3,869.58 3,771.65 8,775.42 -643.38 5,977,460.25 1,701,211.66 0.83 8,798.10 MWD+IFR-AK-CAZ-SC(4) 12,162.98 87.67 344.69 3,873.09 3,775.16 8,869.18 -667.30 5,977,553.80 1,701,186.98 2.13 8,893.59 MWD+IFR-AK-CAZ-SC(4) 12,258.54 87.74 343.48 3,876.91 3,778.98 8,961.00 -693.48 5,977,645.40 1,701,160.05 1.27 8,987.34 MWD+IFR-AK-CAZ-SC(4) 12,352.55 87.91 341.49 3,880.48 3,782.55 9,050.59 -721.75 5,977,734.74 1,701,131.04 212 9,079.05 MWD+IFR-AK-CAZ-SC(4) 12,446.98 87.53 341.48 3,884.24 3,786.31 9,140.06 -751.72 5,977,823.95 1,701,100.35 0.40 9,170.79 MWD+IFR-AK-CAZ-SC(4) 12,541.17 86.98 342.48 3,888.75 3,790.82 9,229.52 -780.82 5,977,913.17 1,701,070.52 1.21 9,262.45 MWD+IFR-AK-CAZ-SC(4) 12,636.79 87.11 345.10 3,893.68 3,795.75 9,321.21 -807.47 5,978,004.62 1,701,043.11 2.74 9,356.12 MWD+IFR-AK-CAZ-SC(4) 12,731.38 89.20 348.05 3,896.72 3,798.79 9,413.15 -829.42 5,978,096.38 1,701,020.42 3.82 9,449.62 MWD+IFR-AK-CAZ-SC(4) 12,761.91 88.87 350.48 3,897.24 3,799.31 9,443.14 -835.10 5,978,126.31 1,701,014.49 8.03 9,479.99 MWD+IFR-AK-CAZ-SC(4) 12,807.00 88.87 350.48 3,898.13 3,800.20 9,487.60 -842.56 5,978,170.71 1,701,006.67 0.00 9,524.93 NOT an Actual Survey 4-1/2"x6-3/4" 12,825.00 88.87 350.48 3,898.48 3,800.55 9,505.35 -845.54 5,978,188.43 1,701,003.55 0.00 9,542.87 PROJECTED to TD 10/12/2015 11:04:26AM Page 6 COMPASS 5000.1 Build 74 0 0 � 2 § (0 2 , t5k/\ @ \) r =k floe E8 C 608E28 a § 2 ( \\ CD .« C -a ro �~ m 7 O 41. p " :- ID @ v — e < < m e as C = C °CO CO C o k / ) ° . Q > U � E o / / u0 _ 0 0 § Q.0 0 st / k 0 0 \ O 0 $ / J h / D ; 6 _ 2 'a \ ® C— • @ J \ % Ct § LL to \ 2 n 2 o m t � " a) ElElLICI Z.3, k / I UJ 2 CO 6 / d • I p TO zJS-111 Loepp, Victoria T (DOA) From: Tam, Sindy P <Sindy.P.Tam@conocophillips.com> Sent: Wednesday, October 14, 2015 4:12 AM To: Loepp,Victoria T(DOA) Cc: Regg,James B (DOA); DOA AOGCC Prudhoe Bay; Doyon 25 Company Man Subject: RE: PTD#215-116 1C-153 Notification of BOP Use per Guidance Bulletin 10-003 Follow Up Flag: Follow up Flag Status: Flagged Sorry Victoria, Yes,the planned is to conduct the BOPE test be after the next trip out of the hole. Let me explain the operation and BHA in the operation that leads to the usage of the BOPE a little better. This BOPE usage event happens during our open-hole standalone screens lower completion running operation.This lower completion consist of the screens with wash-pipe, liner hanger and liner hanger packer. All these equipment are run in hole with drill pipe. With the lower completion at TD,we set the liner hanger but not the liner hanger packer and circulate 2 BU. It is after circulating the 2 BU,when we observed this wellbore breathing event and activated our BOPE. We have now set the liner hanger packer and POOH with the drill pipe and wash pipe. Once all those are out of the hole, we will conduct the BOPE test. Please advise, Sindy From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@)alaska.gov] Sent: Wednesday, October 14, 2015 3:32 AM To: Tam, Sindy P Cc: Regg, James B(DOA); DOA AOGCC Prudhoe Bay Subject: [EXTERNAL]Re: PTD# 215-116 1C-153 Notification of BOP Use per Guidance Bulletin 10-003 Sindy, All BOPE components used during the BOP usage event must be tested the next trip out of hole. Thanx, Victoria Sent from my iPhone On Oct 13, 2015, at 11:21 PM, Tam, Sindy P <Sindy.P.Tam@conocophillips.com>wrote: Date,Time of BOPE use: 10/13/2015 17:05 Well/Location/PTD number: ERU 1C-153/Kuparuk Drill Site 1C/PTD#215-116 Rig Name: Doyon 25 Operator Contact: 1 Sindy Tam (Completion Engineer)—(281) 221-0427 Doyon 25 Company Man (Lee Martin—days)—(907) 659-7501 OPE Used: Annular Reason for BOPE Use: Observed well flowback and gain. Operations Summary, including events leading up to BOPE use: After circulate 2 BU. Opened the bag and observed well flow back and gained 10 bbl. Closed Annular. Monitor pressure. Observed ISICP stabilized at 52psi,and ISITP at 80 psi. Continue to monitor pressure, observed SICP decrease. Open choke to 1/4 open to Rig gas buster and bleed back 10 bbl. SI well, monitor pressure. Observed SICP and SITP of 17psi and 20psi, respectively. Open well to bleed off. Perform Exhale test by opening choke to rig gas buster for 50minutes. Flow decrease from .38bpm to 0 with 12 bbl. bleed back. No Flow observed for 15 minutes. Decide to Open annular. Monitor Well,static for another 15 minutes. Determined event is wellbore breathing. Plan forward:Set packer, pressure test packer. POOH. Perform schedule routine BOPE testing including the annular. Please advise, Sindy Tam Well Design Engineer ConocoPhillips Alaska Sindy.P.Tam(c�ConocoPhillips.com Office: 907-265-6830 Cell: 281-221-0427 2 �, OF Tit, THE STATES S Alaska Oil and Gas ,..,,.347,-.,_................„,„41,,,,, Of LASKA. Conservation Commission i 4 -k_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 AVIO� h.'. Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov G. Alvord Alaska Drilling Manger ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1C-153 ConocoPhillips Alaska, Inc. Permit No: 215-116 Surface Location: 1296' FNL, 4390' FEL, Sec. 12, T11N, R10E,UM Bottomhole Location: 2282' FNL, 5245' FEL, Sec. 36, T12N, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development 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, a7 Cathy . Foerster Chair DATED this lay of July, 2015. STATE OF ALASKA RECEIVED AdRA OIL AND GAS CONSERVATION COMIN JUN 3 0 2015 PERMIT TO DRILL 20AAC 25.005Amore la.Type of Work: lb.Proposed Well Class: Development-Oil Q- Service- Winj ❑ Single Zone 1 c.Specify ifwel d f6r: Drill " ❑✓ Lateral ❑ Stratigraphic Test El Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0, Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc Bond No. 59-52-180 KRU 1C-153 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 12718' ` TVD: , 3864 Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1296'FNL 4390'FEL,Sec. 12 Twn 11N Rng 10 E,UM . ADL 25649 and 25638 I West Sak Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4472'FNL 3355'FEL,Sec.1 Twn 11N Rng 10E,UM ALK 467 and 463 ,l� 9/1/2015 Total Depth: 9.Acres in Property: ?ft 14.Distance to Nearest Property: 2282'FNL 5245'FEL,Sec.36 Twn 12N Rng 10E,UM _siacl -2569 <1 mile to KRU boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above It , 97.1 feet 15.Distance to Nearest Well Open Surface:x-561,894.51 y- 5,968,939.60 Zone-4 , GL Elevation above I\ ' 57.6 feet to Same Pool: 30 ft 16.Deviated wells: Kickoff depth: , 250 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: - 93.8 degrees Downhole: 1726 psi d Surface: 1302 psi ' 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" 94# K55 Welded 80' 39.5' 39.5' 119.5' 119.5' 200 cf of ArcticCRETE 16" 13.375" 68# L-80 Hydril 563 2843' 39.5' 39.5' 2843' 2617' 1396 sx lead,246 sx tail DeepCRETE 12.25" 9.625" 40# L-80 Hydril 563 5203' 39.5' 39.5' 5203' 3844' 729 sx Class'G' 6.75" 4.5" 11.6# L-80 Hydril 563 7718' 5000' 3829' 12718' 3863' Stand alone screens(no cement) 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketchy Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: (� Date ( `)`(l.l L.l 22. I hereby certify that the foregoing is true and correct. David Lee @ 263-3741 Contact david.l.lee@conocophillips.com Email Printed Name G.Alvord Title Alaska Drilling Manager Signature A 'C Phone 265-6120 Date 6(2 (z Mj- Commission Use Only Permit to Drill API Number: �2� q Permit Approval 7 / See cover letter for other Number: c2!5' i/( 50-.0Q - awn y l -d0 -00 Date: 15 requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methan, ,gas hydrates,or gas contained in shales:RI Other: 8OP fe5 f 1-e, 35 0 , S Samples req'd: YesN0LM Mud log req'd:Ye� No[( A f`t h v/G1-k- p rC VC vt 1c r"" fc5 f t 251>O pSi H2S measures: Yes[!] No❑ Directional svy req'd:Ye No❑ .. - . Spacing exception req'd: Yes❑ Nog' Inclination-only svy req'd:Yes❑ NO I' s i 1 / APPROVED BY Approved by: '' / 52 _.7) COMMISSIONER ) THE COMMISSION Date: 7-2_7 -// > i1/7-1- '///v//a -'I/\6 �,/ /is ^ fnIt &IId j2ot. s Submn Form ane Form 10-401(Revised 10/2012) hirfrom the date of approval(20 AAC 25.005(g)) Attachments in Duplicate ConocohiIIips RECEIVED Alaska JUN 3 0 2015 Post Office Box 100360 Anchorage, Alaska 99510-0360 AOGCC David Lee Phone (907) 263-3741 June 29, 2015 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Producer, 1C-153 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permit to Drill a grass roots onshore producer well, a horizontal well in the West Sak"D"sand. The expected spud date for 1C-153 is, September 1st 2015. The West Sak in the 1C area is a shallow marine sequence comprised of very fine grained, single and amalgamated hummocky cross stratified sandstone beds. The 1C-153 well will be drilled in the D sand down structure to the North with a planned lateral length of approximately 7500'. The lateral will cross three minor faults with throws anticipated between 5 — 25'. There are no known H2S issues associated with the drilling of this well or is it anticipated to see any pressures higher than 8.6 ppg equivalent during the drilling of this well. A FIT test to a minimum of 11.0 ppg will be performed after setting the surface casing and drilling out 20'of new formation, and a FIT test of 11.0 ppg equivalent will be performed after setting the intermediate string and drilling 20'of new formation. A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of the surface hole for the 1C-153. A 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete the well. It will be tested to 3500 psi (annular preventer to 3500 psi) and will be tested on a 14 day test cycle in accordance with COP and AOGCC policy while drilling the intermediate and production sections of the well. Properly sized VBR's and pipe rams will be installed to allow closing in on any size of tubular in the hole in the case of an unexpected event. Also a FOSV with proper DP crossover shall be kept on the floor in the open position at all times. Please find attached for the review of the Commission, forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. Sincerely, (41:4- v David Lee West Sak Drilling Engineer • eation for Permit to Drill,Well 1C-153 Revision No.0 Saved:29-Jun-15 Permit It - West Sak Well #1C-153 '•� Application for Permit to Drill Document • MaxWell Mixirn ize Well VQlue Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005 (f) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 Requirements of 20 AAC 25.005 (c)(4) 3 4. Procedure for Conducting Formation Integrity Tests 3 Requirements of 20 AAC 25.005(c)(5) 3 5. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 6. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 7. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 Surface Hole Mud Program (Drilplex AR) 5 Intermediate Hole Mud Program (LSND) 5 Lateral Mud Program (MI FazePro OBM) 5 8. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005(c)(9) 5 9. Seismic Analysis 5 Requirements of 20 AAC 25.005(c)(10) 5 10.Seabed Condition Analysis 6 Requirements of 20 AAC 25.005(c)(11) 6 11.Evidence of Bonding 6 Requirements of 20 AAC 25.005(c)(12) 6 1C-153 PERMIT WP04.doc Page 1 of 7 Printed:29-Jun-15 • Illtion for Permit to Drill,Well 1C-153 Revision No.O Saved:29-Jun-15 12.Proposed Drilling Program 6 Requirements of 20 AAC 25.005 (c)(13) 6 13.Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 14.Attachments 7 Attachment 1 Directional Plan 7 Attachment 2 Drilling Hazards Summary 7 Attachment 3 Cement Program Summary 7 Attachment 4 Well Schematic 7 Attachment 5 Doyon 25 BOP Stack Configuration 7 Attachment 6 Doyon 25 on 1C-153 7 1. Well Name Requirements of 20 AAC 25.005(0 Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b).For a well with multiple well branches,each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1C-153 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application 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 identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth, referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 1296' FNL 4390' FEL Sec. 12 Twn 11N Rng 10E UM 9?,1 ASP Zone 4 NAD 27 Coordinates RKB Elevation 1D6 "AMSL Northings 5,968,939.59 Eastings:561,894.51 Pad Elevation Jeb J'AMSL 4 ' Location at Top of Productive Interval 4472' FNL 3355' FEL Sec. 1 Twn 11N Rng 10E UM (West Sak"D"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 5009' Northings: 5,971,052.17 Eastings:562,911.08 Total Vertical Depth, RKB: 3830' Total Vertical Depth, SS: 3733' Location at Total Depth 2282' FNL 5245' FEL Sec. 36 Twn 12N Rng 10E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 12718' Northings: 5,978,505.03 Eastings: 560,955.19 Total Vertical Depth, RKB: 3863' Total Vertical Depth, SS: 3766' and (D)other information required by 20 AAC 25.050(6); 1C-153 PERMIT WP04.doc Page 2 of 7 Printed:29-Jun-15 • Allation for Permit to Drill,Well 1 C-153 Revision No.0 Saved:29-Jun-15 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: 1C-153 Well Plan and (2)for all wells 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 the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application 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 identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPS)as required by 20 AAC 25.035,20 AAC 25.036,or 20 MC 25.037,as applicable; An API 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete well 1C-153. Please see information on the Doyon Rig 25 blowout prevention equipment placed on file with the Commission. Please see Attachment 5 for Doyon 25 BOP stack configuration. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application 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 identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The maximum expected reservoir pressure in the West Sak D sand in the 1C area is 0.447 psi/ft, or 8.6 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient(0.11), and the deepest planned vertical depth of the West Sak"D"sand formation is 1,302 psi. MPSP = (3863 ft TVD)(0.447 - 0.11 psi/ft) = 1,302 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2: 1C-153 Drilling Hazards Summary. 4. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application 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 identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 MC 25.030(1); 1C-153 PERMIT WP04.doc Page 3 of 7 Printed:29-Jun-15 • tion for Permit to Drill,Well 1C-153 Revision No.0 Saved:29-Jun-15 1C-153 will be completed with a 9-5/8" intermediate casing landed in the West Sak D sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the"Formation Integrity Test Procedure"that ConocoPhillips Alaska placed on file with the Commission. 5. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application 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 identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 42 94 K55 Welded 80 39.5 / 39.5 119.5/ 119.5 Cemented to surface with 200 cf ArcticCRETE Cemented to Surface with 13.375 16 68 L-80 Hydril 563 2843 39.5 / 39.5 2843 / 2617 1386 sx 11.0ppg Deeperete Lead, 246 sx 12.0ppg DeepCRETE Tail Cement Top planned @ 3076' 9.625 12.25 40 L-80 Hydril 563 5203 39.5/ 39.5 5203/ 3844 MD Cemented w/719 sx 15.8 ppg Class'G' 4.5 6.75 11.6 L-80 Hydril 563 7718 5000/ 3829 12718 / 3863 screens-no cement screens 6. 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,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035,unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1C-153 surface hole. Please see diagrams of the Doyon 25 diverter system on file with the Commission. 1C-153 PERMIT WP04.doc Page 4 of 7 Printed:29-Jun-15 • tion for Permit to DrillRevision,Well 1 C-153 No.0 Saved:29-Jun-15 7. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application 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 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; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (Drilplex AR) Spud to Surface TD Value Density(ppg) 8.5 —9.2 LSYP 30 - 50 API Fluid Loss No Control (cc/30 min) Chlorides < 1000 pH 10.8-11.2 Intermediate Hole Mud Program (LSND) Lateral Mud Program (MI FazePro OBM) Value 13 5/8"Csg Shoe to 9-5/8"Csg Point Density(ppg) 9.2 Value Fann 35 6 RPM Density(ppg) 9.2 (lb/100 ft2) 4 -8 Fann 35 6 RPM HTHP Fluid Loss (lb/100 ft2) 12 - 16 (ml/30min) < 5 API Filtrate < 6 Drill Solids < 5% (cc/30 min)) pH 9.5 — 10.0 Oil water Ratio 70:30 Drill Solids <7 Electrical > 400 Stability(mV) Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 25. 8. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application 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 identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(t); Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application 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 identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 1C-153 PERMIT WP04.doc Page 5 of 7 Printed:29-Jun-15 • tion for Permit to Drill,Well 1C-153 Revision No.0 Saved:29-Jun-15 10.Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application 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 identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig,or floating drilling vessel,an analysis of seabed conditions as required by 20 MC 25.061(6); Not applicable: Application is not for an offshore well. 11.Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application 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 identified in the application: (12)evidence showing that the requirements of 20 MC 25.025{Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 12.Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application 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 identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20"x 34"insulated conductor to +/- 119.5' RKB. Install landing ring on conductor. 2. Move in / rig up Doyon Rig 25. Install 21-1/4"Annular with 16"diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 2843' MD/ 2617'TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 13.375", 68#, L80, Hydril 563 casing to surface. Displace cement with mud and check floats upon bumping plug. Perform top job if required. 5. Remove diverter system, install and test 13-5/8"x 5,000 psi BOP's to 3500 psi (annular preventer to 3500 psi). Notify AOGCC 24 hrs before test. 6. PU 12.25" bit and 8"drilling assembly, with MWD. RIH, clean out cement to top of float equipment and test casing to 3000 psi for 30min. 7. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test to 11.0ppg EMW, recording results. 8. Directionally drill to 9-5/8"casing point at 5203' MD/ 3844'ND. Pull out of hole. 9. Run 9.625", 40# L80, Hydril 563 casing to surface. (top of cement to be 3076' MD which corresponds to 500'above the Ugnu C formation). 10. Install slips and 9.625" packoff and test to 3500 psi. 11. Flush 13.375"x 9.625"annulus with water, followed by isotherm. 12. PU 6.75"PDC Bit and 4.5"drilling assembly, with MWD and LWD logging tools. RIH, clean out cement to top of float equipment. Test casing to 3500 psi for 30 minutes. 13. Drill out cement and 20'of new hole. Displace hole to lateral drilling FazePro OBM system. Perform formation integrity test to 11.0ppg EMW, recording results. 14. Directionally drill 6.75" hole to West Sak D Sand TD at +/- 12718' MD/ 3863'ND as per directional plan. 15. Backream to 9.625"shoe. TIH and perform final circulations and displace well to solids free oil base mud. Pump out of Hole. 16. PU and run 4-1/2"screened liner. 1C-153 PERMIT WP04.doc Page 6 of 7 Printed:29-Jun-15 • tion for Permit to Drill,Well 1C-153 Revision No.0 Saved:29-Jun-15 17. Once all the liner is in the hole, rig up false rotary table and trip 2 7/8 wash pipe string into the entire length of the liner. Make up liner hanger running tool. 18. Finish running liner to TD to land liner and set liner hanger @ +/- 5000'MD/3829'TVD, then displace well to filtered brine 19. Pump Schlumberger acid through wash pipe (9% formic acid for 1C-153). 20. Allow acid to act on the filter cake. Once break time has been achieved, circulate out the formic acid and replace with inhibited brine. 21. Set liner top packer. POOH across fluid loss control valve (FLCV) to shift FLCV closed. Displace packer fluid and then continue to POOH. 22. PU 4.5"tubing and outer ESP housing and RIH 1000'. 23. RIH with ESP (pump and motor) and land in outer housing using slick line. 24. Continue running in hole with 4.5"tubing. Land tubing. Set BPV 25. Nipple down BOPE, nipple up tree and test. Pull BPV. 26. Freeze protect well with diesel by pumping into 4.5"x 9.625"annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 27. Set BPV and move rig off. 13.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application 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 identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of by hauling to the 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. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 14.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Program Summary Attachment 4 Well Schematic Attachment 5 Doyon 25 BOP Stack Configuration Attachment 6 Doyon 25 on 1C-153 1C-153 PERMIT WP04.doc Page 7 of 7 Printed:29-Jun-15 • UP1..)Di 1 c-i 53wp04 6 . 739 Plan Summary ---77- - UGB UGA - -- \ UGC \ , 110 •;,0/--- ' -5 - ct - • _ co _ \ 0, - ' ci p Pfrot '\ 0 0 , /1 I\ - , . , Vir \ 0 , 1 I I I, i I I 1 I I I 11 11 I 0 '1 .,,,,...,,,i1101101111111111r 0 .... 300Q , 6000 9000 12000: , Is';'1-°'-411.,..._ _ 113-3/8"x 161 19 5/8"x 12-1/41 ', ,...--- , 4 1/2"x 6-3/4" •tl\NIII ,. '=, - %,, Measured De.th ,\ \v‘•..7\1 ,,N4 loop416„ vo,•,._,,\ ,, a- Geodetic Datum: North American Datum 1983 -0° Depth Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) _ 113-3/8"x 161 Rig: Doyon 25 , - V ' o 2. . , 4 1/2°x 6-3/41 „.„. 9 5/8"x 12-1/41 o o o I co o o 0 0 Q ?eo co "or,..C011 OD 0,0 I,- o 0 CD - ,a,Cu ,,, : • _., . I 1 i I 1 I I 1 ,, t I I 1 $ 1 1 40 - 250 0 1500 3000 4500 6000 7500 9000 10500 0 250 - 440 Horizontal Departure . 12 . 440 - 640 330 , !,,,_, 640 - 830 830 - 1020 c - 2 , ' -JC--152wpo• ..,:r-of",•••, 1020 - 1220 'r7i 60 , ‘. - .,,,..".v.-..r.v.• 300 .%N.:6.' V 4' . , 1220 - 1410 a 1 )C't51', - 4,-`4`,..--.=All , .• .‘, - IC-172 inc.-wm.1 1,trjrroitto.4,;., .1 ,,.,,,. 1410 - 1600 al r-a «t:..,.4-1.91104.:', 03 ' Ill 11.,t72AL2PE, '• ,111 1:',' ,', -.se..., A---„::, .1,.:4*,..,..-. 4 1600 - 2060 2 41 III 2530 - 2990 1/' \ 1C06 30 2060 2530 - III IliI 1 C,1,72AL2P 1 " 8 ' \\ fig zr4 V uy ;)0, 2990 - 3450 2 1 172AL2 270 . . „ . . : : 90 -- x:-Att-..:;,::',.'. + ',• Y.',..,„ .. ,' . : .._. : cU 3450 3910 - 1C-172AL1 3910 - 4370 ti 1C-172A , 1 1 4370 - 4840 0 Ilc.151- toi ; K-.. . ,.,":,. 4840 - 5300 0 i I I I i I I I I l 1 I I I I - 0 2000 4000 6000 8000 10000 12000 240 '.3r.-:=.,-"_. -.::.4',,..---,,,,,, r %v.:,,. •,.: ,.. 6230 120 5300 6230 - 7150 SURVEY PROGRAM 7150 - 8080 Surface Location ',';'''''," ..,/2 :--- ,:' 7. '''':'. 8080 - 9010 lepth From Depth To Survey/Plan Tool North/Y: 5968691.35 °,•'" ',-- , East/X: 1701926.42 210 ,- -: ,,,2;';,'' 9010 - 9940 39.50 950.00 1C-153wp04(Plan 1C-153) GYD-GC-SS Pad Elevation:57.60 950.00 1950.00 1C-153wp04(Plan 1C-153) MWD 9940 10860 950.00 2843.24 1C-153wp04(Plan 1C-153) MWD+IFR-AK-CAZ-SC IBM 180 10860 - 11790 2843.24 4343.24 1C-153wp04(Plan 1C-153) MWD CASING DETAILS 11790 - 12718 2843.24 5202.79 1C-153wp04(Plan 1C-153) MWD+IFR-AK-CAZ-SC TVD MD Name ---rit 5202.79 6702.79 1C-153wp04(Plan 1C-153) MWD 2617.10 2843.24 13-3/8"x 16" Magnetic Model: BGGM2015 T 5202.79 12718.37 1C-153wp04(Plan 1C-153) MWD+IFR-AK-CAZ-SC 3844.17 5202.79 9 5/8.'x 12-1/4 Magnetic Model Date: 21-Sep-15 3863.10 12718.37 4 1/2"x 6-3/4" Magnetic Declination: 18.95° To convert a Magnetic Direction to a True Direction,Add 18 95°East SECTION DETAILS =1801.7 Sec MD Inc Azi TVD *NI-S -FE/-W Dleg TFace VSect Target Annotation 1 39.50 000 0.00 39.50 0 00 0.00 0.00 0.00 0.00 2 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.51100'DLS,20 TF,for 250.18' 3 500.18 3.75 20.00 500.00 7.70 2.80 1.50 20.00 7.42 Start 2.51100DLS,20 TF,for 302.76' 4 802.93 11.17 33.45 800.00 41.52 22.38 2.50 20.00 39 41 Start 21100'DLS,30°TF,for 1022.52' 5 1825.45 30.61 53.51 1751.70 281.53 289.13 2.00 30.00 25526 Hold for 116.2' 6 1941.65 30.61 53.51 1851.70 316.72 336.70 0.00 0.00 286.17 Start 3.591100'DLS,74.82.TF,for 120.94' 7 2062.59 32.00 6144 1955.08 350.36 389.63 3.59 74.82 315.07 Hold for 780.65' 8 2843.24 32.00 61.44 2617.10 548.14 752.97 0.00 0.00 480.42 Adjust TF to V,for 20' 9 2863.24 32.00 61.44 2634.06 553.20 762.28 0.00 0.00 484.66 Start 4.29./100'DLS,-60.79°TF,for 56.79' 10 2920.03 33.25 57.56 2681.90 568.75 788.64 4.29 -60.79 497.85 Hold for 99.9' 11 301933 33.25 57.56 2765.44 598.13 834.87 0.00 0.00 523.09 Start 4.29./100'DLS,-79.88.TE for 1241.62' 12 4261.55 65.00 357.00 3608.68 1401.37 1113.04 429 -79.88 1299.02 Hold for 200' 13 4461.55 65.00 357.00 3693.20 1582.38 1103.55 0 00 0.00 1480.18 1C-153 BasePumpTangent Start 4.121100 DLS,-23.33 TF,for 547.72' 'front 14 5009.27 85.94 348.24 3830.10 2104.45 1033.96 4.12 -23.33 2006.32 1C-153 Top D 21Oct14 DL Start 2.421100'DLS,-97.l5 TF,for 139.2' 15 5148.47 85.53 344.89 3840.45 2239.44 1001.71 2.42 -97.15 2143.62 Hold for 4.34' 16 5152.81 85.53 344.89 3840.79 2243.62 1000.58 0.00 0.00 2147.88 Start 2421100'DLS,10.34°TF,for 177.53' 17 5330.34 89.75 345.66 3848.10 2415.13 955.50 2.42 10.34 2322.66 1C-153 71 270c14 DL Hold for 1146.21' 18 6476.54 89.75 345.66 3853.10 3525.60 671.57 0.00 0.00 3453.65 1C-153 T2 270ct14 DL Start 002/100'DLS,44.72°TF,for 1595 43' 19 8071.97 89.96 345.87 3857.10 5072.02 279.19 0.02 44.72 5028.38 1C-153 T3 270ct14 DL Start 21100'DLS,0.17 TF,for 190' 20 8261.97 93.76 345.88 3850.93 5256.14 232.85 2.00 0.17 5215.84 Hold for 293.81' 21 8555.78 93.76 345.88 3831.65 5540.46 161.33 0.00 0.00 5505.31 Start 21100'DLS,-177.19°TF,for 127.88' 22 8683.66 91.21 345.75 3826.10 5664.32 130.03 2.00 -177.19 5631.43 1C-153 T4 270ct14 DL Hold for 104355' 23 9727.21 91.21 345.75 3804.10 6675.55 -126.72 0.00 0.00 6661.19 1C-153 T5 270ct14 DL Start 21100'DLS,178.78°TF,for 7664' 24 9804.05 89.67 345.79 3803.51 6750.03 -145.60 2.00 178.78 6737.03 Hold for 1392' 25 11196.05 89.67 345.79 3811.48 8099.39 -487.38 0.00 0.00 8111.05 Start 21100'DLS,-177.17 TF,for 128.61' 26 11324.66 87.10 345.66 3815.10 8223.97 -519.08 2.00 -177.17 8237.91 1C-153 T6 270ct14 DL Hold for 791.34' 27 12116.00 87.10 345.66 3855.10 8989.67 -714.83 0.00 0.00 9017.76 1C-153 17 270ct14 DL Start 21100'DLS,7.71°TF,for 119.68' 28 12235.68 89.47 345.98 3858.67 9105.65 -744.13 2.00 7.71 9135.85 Hold for 482.T 29 12718.37 89.47 345.98 3863.10 9573.95 -861 06 000 0.00 9612.56 1C-153 TD 270ct14 DL TO:12718.3T MD,3863.1'TVD -3206.1 Updated surface location and RKB from as-staked. Changed plan to reduce UGC Change' doglegs in the intermediate section by repositioning the pump tangent. Is subject to -3428.1 UGB Changed the production section profile to better intersect targets. -..--35350A .By signing this I acknowledge that I have been informed of all risks,checked that the data incorrect,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basis for the final well plan and wellsite drawings.I also acknowledge that,unless notified°them se,all targets have a 100 feet lateral tolerance. Prepared by: Checked by: Accepted by: Approved by: Brij Potnis Nate Beck Ifeanyi Ifesie David Lee 0 • Northing (2500 usft/in) av _ , , , , IiiiiIiiiiIiiiiImiIiiipIiii , IiitiIiiiiIiiiiIiiiiIimIimi iiiiIii _ co N N - N Ur, it U r N i _ r C) Q v - U co,- _ - - - O N - O 9 - \cr - LO N ." — U a a Ln L C 7. _ t• ...... 4 : '.---1 r AN CZ , co Q U U •% a C_ On I I C o _ a7 .... o N N c,O-30 �� p0!",4").� rNc - o U1 I. i Min 3 f �3 W M 3U 11) 3 Q `o � cJ w ... Ln VT m ,,,i0,2_ N T .^ U V U :O �`\'‘ U oT 0 Cj I1� , *t- —In r ���I�i .., • Alit 1 -,, 7 ,,, A I I I 1".".-")1 0 I I II I 71-,,..- ,-. co co :: oa , i . 6 cte cz _ I-- N , r-.., ,74 .If:lar isms Ivo-1 .111..,,.ems• -...r.,31i T r • m r c U d J 2 = • U .. • v d T- CO • rn r r c7,1 o • .o 3¢ U o v- N o U c�9U •••,.. T 5 • 3 �T. TJX / O Q. -• - — 111, LXY('ii 0.4 T Uv '- m.. a s' .Ilk `N � oa m r r '• thco N c,m Nr ;Ail' TO Y4. W O mfD _ • N a. - Air: L i • . rii► I , _ . 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(0 a C) M Cl) O N- CO CO 0 0 0 0 0 0 0 0 0 0 0 0 0 0 6) CO 0) CO 0) CO N a r N (O M r O r CO r CO r CO r CO r n r N- r N� r 1�Or V r 7 V y d .0 CO r CO CO CO O6 O C) CO O CO O COC] V COC7 V COM V COM V O) V 6) V O) V Ln V O O- Ol N h V N 0 N O N O N O N Cr (O N (O N (O N (O N CO V CO V CO V T C Q = y SZ y r N N N N V CO V N V N V CO V CO CO CO 0 CO V CO V CO V 1m 3 W O 0 7 r r U M) x cc T K U I t r 0) CO o M° i Lf) z (6 E T O ( = I C r a U o c N T 2T > Q L O O0 ) M O. 3 y (Ab C) U d a o 0 0 a '5 = 3LL fa L 0 co y d 00 mOc a c ) LL a (� o2 QQ CO M m m 0 0 LL LL Li Ilm 0 CO COor 0 ,rc a .0 coLL LL 7 LL y 4' N J J co o Q Q J J J J J 000 coO fn 3U U O O CO00OO J se= ^. M rrOO U U r r ra) Em G U ' ' n`o c E CO CO CO CO N- n O O 0 CO CO ' (0 s 0 0 0 0 0 0UU m m O O 0 0 U U l0 CW N? O. 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M ,_ ,_ ,_ ' ' aa 0 dd U E 3 d NNNN A U U U UUU N. d U .Lm N „0 y d e(O�' N X cn 3 0 0 0 0 O ay C La) a . ca) z c c c c c c $ ° m m N 0 = a - COCOOCCO (0 cccC U N3 N « d a d2 C OL tod d (6C U U 0 +dd • CO y UCCII 0 c / Zrn o cCo (Or00C C Co (O1.0v11.010 0) 0o) 0) dy w ` v y0A d yr - - - - - N N N N Q U v d y W ' U U U U U U U U U U y O r O d3 � LL Cd aza OU cm d cV 0c « CCCCCC CCCC No t+ d z K O N CO CO CO 01 CO CO CO CO CO CO o' 8 C O _ • �`d c m in v a a a a a a a a a a Q N N < F r2 y y W U (A 0 U Q • 10:55, June 17 2515 1 C-1 53w 04 Lad er View pThe Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. v mo Q g � o y n HER{p ,11 h Wtlf_Q N . N C3 t 11111 1p%u kill, ;11111�I I�'I IyP1111114'1 IIIP'' 300 d il��lllp111, � I I I I ••,,,,,,,,,,4,4111,1, �)D llli � I I nnI ' IiQ lJ Il11 nnP' 11,I�I1 �)l N .nnl1 IiyI r ,N. 150 IIlii1I i, � IIIll ilIl , 1 lU ....ado �lIl0I1 �� Il 02 __Aro @ IIIIU ��I l'I:All U1l all, l .... - .... O I Equivelant Magnetic Distance I I I I I I I I I I I I I I I I I I 0 2000 4000 6000 8000 10000 12000 Displayed interval could be less than entire well:Measured Depth 39.50 To 12718.37 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.50 950.00 1C-153wp04 (Plan 1C-153) GYD-GC-SS 2617.10 2843.24 13-3/8" x 16" 950.00 1950.00 1C-153wp04 (Plan 1C-153) MWD 3844.17 5202.79 9 5/8"x 12-1/4 950.00 2843.24 1C-153wp04 (Plan 1C-153) MWD+IFR-AK-CAZ-SC 3863.10 12718.37 4 1/2"x 6-3/4" 2843.24 4343.24 1C-153wp04 (Plan 1C-153) MWD 2843.24 5202.79 1C-153wp04 (Plan 1C-153) MWD+IFR-AK-CAZ-SC 5202.79 6702.79 1C-153wp04 (Plan 1C-153) MWD 5202.79 12718.37 1C-153wp04 (Plan 1C-153) MWD+IFR-AK-CAZ-SC N H 1 ØJiIØ!V l' rIPIIIIIIIIII I' "•tl ."Fl 60 Flop �) II 1111 _,.e�lII 111141 I .a� III I�,l us) m 30 �InmIIIIIII����������11111��411111011'r dor Illi) U -lnl�lnll10 II' IIIA ISI U 0 0 \ 500 1000 1500 2000 2500 3000 3500 Equlveiant Magnetic Distance Partial Measured Depth 4U ZOU 1C-153wp04 • MD Inc Azi TVD Oleg TFace T1111/ 250 440 39.50 0.00 0.00 39.50 0.00 0.00 39.50 To 12718.37 250.00 0.00 0.00 250.00 0.00 0.00 440 640 500.18 3.75 20.00 500.00 1.50 20.00 802.93 11.17 33.45 800.00 2.50 20.00 640 830 10:57,June 17 2015 ( 1825.45 30.61 53.51 1751.70 2.00 30.00 830 1020 1941.65 30.61 53.51 1851.70 0.00 0.00 CASING DETAILS 2062.59 32.00 61.44 1955.08 3.59 74.82 1020 1220 2843.24 32.00 61.44 2617.10 0.00 0.00 TVD MD Name 2863.24 32.00 61.44 2634.06 0.00 0.00 1220 1410 2617.10 2843.24 13-3/8" x 16" 2920.03 33.25 57.56 2681.90 4.29 -60.79 3844.17 5202.79 9 5/8" x 12-1/4 3019.93 33.25 57.56 2765.44 0.00 0.00 1410 1600 3863.10 12718.37 4 1/2" x 6-3/4' 4261.55 65.00 357.00 3608.68 4.29 -79.88 4461.55 65.00 357.00 3693.20 0.00 0.00 1C-153 BasePumpTangent 1600 2060 5009.27 85.94 348.24 3830.10 4.12 -23.33 1C-153 Top D 210ct14 DL 2060 2530 SURVEY PROGRAM 5148.47 85.53 344.89 3840.45 2.42 -97.15 ep33F.rom De56.6oGc-ss 6 Survey/Plan (Plan tC-153) To� 51 52.81 85.53 344.89 3840.79 0.00 0.00 356 9 959.99 1959.69 1C-153wP94(Plan 1C-153) MO 5330.34 89.75 345.66 3848.10 2.42 10.34 1C-153 Ti 270ct14 DL 2530 2990 959.69 2843.24 1C-153.04(Plan 1C-153) M.MIFR-AK-CAZ-SC 6476.54 89.75 345.66 3853.10 0.00 0.00 1C-153 T2 270ct14 DL 2990 "" 3450 2843.24 4343.24 1C-153,004(Plan 1C-153) R.16 2943.24 5292.79 1C-153wy64(Plan 1C-1531 10,0MIFR-AK-C624C 8071.97 89.96 345.87 3857.10 0.02 44.72 1C-153 T3 270ct14 DL 5202 79 HMO 5282.79 12718.37 1C-1536.4 C 153 p3(Pian 1C•153( IWMIFR-AK-CAZ-SC 8261.97 93.76 345.88 3850.93 2.00 0.17 3450 3910 8555.78 93.76 345.88 3831.65 0.00 0.00 8683.66 91.21 345.75 3826.10 2.00 -177.19 1C-153 T4 270ct14 DL 3910 4370 9727.21 91.21 345.75 3804.10 0.00 0.00 1C-153 T5 270ct14 DL y0U4.U5 D .bf .i40.I`J 4b113.D1 2.UU 110.10 4370 4840 11196.05 89.67 345.79 3811.48 0.00 0.00 11324.66 87.10 345.66 3815.10 2.00 -177.17 1C-153 T6 270ct14 DL 4840 5300 12116.00 87.10 345.66 3855.10 0.00 0.00 1C-153 T7 270ct14 DL 5300 6230 12235.68 89.47 345.98 3858.67 2.00 7.71 12718.37 89.47 345.98 03/16010 0.00 0.00 1C-153 TD 270ct14 DL 6230 7150 1C-06 --.\,,-1\ 1- i Y 5 -.. 7150 8080 -30/330` �� :�` ` 30 8080 9010 r-- ,, \ti: 9010 9940 1C-152w 04 r .1►,. \ 11,4 �� 1 ��� ►+1, ® 9940 10860 180 �,�D��II��� QQ 10860 11790 i C-172AL2PB2 --- `I�j��'*`1r/7"Nk 16 .4. •• 19A.2 f•� ^�.1:' � � 11790 12718 J� 41 W,�►� -Zl.►A4N, 150 ' �� 1 C-172AL2PB,1 1C-17".., �`1•"'.v.��I���'i,• ~�� ��� 1 6Q i I i4'i�T�i `F ��i%�r,����,`C`�120 ' ����`i`��``;`` 60 1 C-172AL2, , � s.*mi y�, -49,1. ,�•.,,:ii s� 10 y \ 1 C-172AL117 i. 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COORDINATES SHOWN ARE ALASKA STATE 2 .ti ii NAD27, ZONE 4. 4 �? 7�_ 1 la — 3. ALL ELEVATIONS SHOWN ARE B.P.M.S.L., p1g�t1P� T+ } DISTANCES ARE TRUE. Pp�,UK I I4. DS1C PLANT NORTH IS ROTATED 56° 20' 41" KU_ WEST FROM GRID NORTH. ,_,� SS1B W�TN* ` 111, 1C ate• _ , .� Q C,, s ss,„ /10 ,t pip di&E 'Ital." ' ' 12 o 4/��'ti�F A �' 11 SINE IC I : . F 090 2 + 1 \ ;. r 11 12 \ ' THIS , PROJECT , _ 0-D DS 1 15 Dsx -0 14 , r , A ,1,?,... .. i DS1D VICINITY MAP SCALE: 1" = 1 MILE ^mow• O C • GQF'\ _0) ,\ °N6), ' • A° 0 o1 o ^ ON 6° ^ • •� h� O .. • ® 1\D 40 ^,\y ,1" • • ^h0 D, e • •� 0 •• 0 0e • • v • •^3, ^') • • ,.,7D Q,^ 1 • •.ti o,mo `' •ry0 • • •�' • • ^•�" �' •• D S 1 C "ry7' SEE PAGE 2 OF 2 FOR LOCATIONS LEGEND: AS-STAKED CONDUCTOR LOCATION GRAPHIC SCALE • EXISTING CONDUCTOR LOCATION 1oI I 400 LOUNSBURY 1 inch = 200 ft. & ASSOCIATES, INC. THIS PROJECT IS LOCATED IN BEECHEY POINT (B-5) QUADRANGLE SI 1Rvevuxs ENGINEERS PLANNERS AREA:1C MODULE: UNIT: D1 ConocoPhilli s DS1C WELL CONDUCTORS 152, 153, 154 Sc 155 Alaska, Inc. AS—STAKED LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6103D70 06/14/15 NSK 6.103 - d70 1 OF 2 0 REV DATE BY CK APP • DESCRIPTION REV DATE BY • APP DESCRIPTION CONDUCTORS TO BE LOCATED IN PROTRACTED SECTION 12, T. 11 N., R. 10 E., UMIAT MERIDIAN Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset. Y X Lat. Long. F.N.L.F.W.L. O.G. PAD 152 5,968,956.21 561,869.54 70' 19' 32.59" 149' 29' 53.86" 1279' 865' 55.0' 57.6' 153 5,968,939.59 561,894.51 70' 19' 32.43" 149' 29' 53.13" 1296' 890' 55.0' 57.6' 154 5,968,757.28 562,168.33 70' 19' 30.61" 149' 29' 45.18" 1481' 1162' 53.2 57.6' 155 5,968,690.23 562,269.04 70' 19' 29.94" 149' 29' 42.26" 1549' 1262' 52.2 57.6' nit CPA!Coordinate Converter (. I 'l Is`` 2 Is From: To: Datum: ]NAD27 �i Region: Jalaska Datum: 1144683 cI Region: {alaska C Latitude/Longitude Decimal Degrees CLatitude/Longitude Decimal DegreesLL yV � • "' UTM Zone: [ ` South C UTM Zone: True r- South ° State Plane Zone: 1-4-7,71 Units: us-ft a State Plane Zone: 4 .. Units: lus-ft C Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: -- — — X: 561894.51 X: 11701926.41945666 Y: 15968939.59 Y: 5968691.3476543 Transform Quit I Help d NAD D 27 - LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS y/ AREA:1C MODULE: UNIT: D1 ConocoPhillips WELL CONDUCTORS 152, 153, 154 & 155 Alaska, Inc. AS—STAKED LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6103D70 06/14/15 NSK 6.103 — d70 2 OF 2 0 1 C-1530rilling Hazards Snmary 16" Open Hole / 13-3/8" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin 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 of trip sheets), pumping out Washouts/Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible 12-1/4" Open Hole / 9-5/8" Casing Interval Hazard Risk Level Mitigation Strategy 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 Intermediate cement reaching Moderate Risk of cement reaching surface casing shoe,put surface casing shoe retarder in for first 60 bbls to extend set up time. 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 Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud weight. Pressure Stuck Pipe Low Good hole cleaning, PWD tools monitoring and analysis, decreased mud weight if possible if pipe does get stuck Lost Circulation Moderate Reduced pump rates, mud rheology, LCM program, additional fluid stored on location during completion run. 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 backreaming Fault Crossings and Moderate Use developed best practices for concretion drilling. Concretions Getting Liner to Bottom Moderate Maintain solids free oil based mud properties and lubricity while running liner lower completion, monitor torque and drag and use 5"HWDP and super sliders to run the heavy liner Attachment 2-1C-153 Drilling Hazards Summary.doc 6/25/20159:04:31 AM 1 C-153 Schlumberger CemCADE Preliminary Job Design 13 3/8" Surface Casing (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Doyon 25 Volumes are based on 200% excess in the permafrost and 50% excess below the Location: Kuparuk permafrost. The top of the tail slurry is designed to be at 2343' MD. Client: CPA! Revision Date: June 29, 2015 Prepared by:Jenna Houston Location:Anchorage, AK Phone: (907)263-4207 Lead Slurry Minimum pump time: -270 min. (pump time plus 120 min.) Mobile: (907)223-8916 DeepCRETE @ 11.0 ppg- 1.91 ft3/100 lb sk email:jhouston2@slb.com 0.9933 ft3/ft x 80 x 1.0 (no excess) = 80 ft3 < TOC at Surface 0.42059 ft3/ft x(1884-80)x 3.00 (200% excess) = 2277 ft3 0.42059 ft3/ft x(2343-1884)x 1.50(50% excess) = 290 ft3 2277 ft3+290 ft3+ 80 ft3= 2647 ft3 2647 ft3/1.91 ft3/sk= 1386 sks(-1396 sks) Have additional ALC on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: -200 min. (pump time plus 120 min.) 12.0 ppg DeepCRETE-1.63 ft3/1001b sk 0.42059 ft3/ft x(2843-2343)x 1.50 (50% excess) = 316 ft3 0.84065 ft3/ft x 80' (Shoe Joint) = 68 ft3 316 ft3+68 ft3= 384 ft3 384 ft3/1.63 ft3/sk= 236 sks Round up to 246 sks BHST= 59°F, Estimated BHCT=74°F. (Based on 2.1°F/100 ft. from surface) < Base of Permafrost at PUMP SCHEDULE 1,884'MD(-1,802 TVD) Stage Cumulative Stage Pump Rate Volume Stage Time Time (bpm) (bbl) (min) (min) CW 100 7.0 100.0 14.3 14.3 MUDPUSH I I 7.0 100.0 14.3 28.6 Pause 0.0 0.0 5.0 33.6 < Top of Tail at 11 ppg DeepCRETE 7.0 471.1 67.3 100.9 2,343'MD Surface Tail 7.0 68.2 9.7 110.6 DeepCRETE Slurry Pause 0.0 0.0 5.0 115.6 Fresh Water 7.0 10.0 1.4 117.0 Pause 0.0 0.0 5.0 122.0 Mud 8.0 393.7 49.2 171.2 Mud 3.0 10.0 3.3 174.5 < 13 3/8",68#casing in 16"OH MUD REMOVAL Expected Mud Properties:9.2 ppg, Pv<20, Ty<20 TD at 2,843 MD Spacer Properties: 10.5 ppg MudPUSH* II, Pv 17-21, Ty=20-25 (2,617'TVD) Centralizers: As per CPAi program. Mark of Schlumberger 1C-153 Schlumberger CemCADE Preliminary Job Design 9 5/8" Intermediate (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Doyon 25 Volume Calculations and Cement Systems Location: Kuparuk Client: CPAi Revision Date: June 29, 2015 Volumes are based on 20%excess. Prepared by:Jenna Houston Location:Anchorage, AK Tail Slurry(total) Minimum thickening time non-retarded slurry: -230 min. (pump time Phone: (907)263-4207 plus 120 min.). Minimum thickening time for retarded slurry is 600 min by COP request. Mobile: (907)223-8916 15.8 ppg Class G +adds- 1.16 ft3/sk email:jhouston2@slb.com 0.31321 ft3/ft x(5203'-3076') x 1.2 (20% excess) = 800 ft3 Shoe Volume: 0.42572 ft3/ft x 80' x 1.00 (no excess) = 34 ft3 Totals: 800 ft3+ 34 ft3= 834 ft3 834 ft3/1.16 ft3/sk= 719 sks(729 sks) BHST= 101 °F, Estimated BHCT= 81 °F. (BHST calculated using a gradient of 2.1 °F/100 ft. from surface) PUMP SCHEDULE Stage Cumulative Pump Rate Stage Time 13 3/8",68#casing Stage (bpm) Volume (min) Time (bbl) (min) at 2843'MD MUDPUSH II 6.0 40.0 6.7 6.7 Pause 0.0 0.0 5.0 11.7 Tail Slurry+extra 6.0 40.0 6.7 18.4 retarder Tail Slurry 6.0 108.4 18.1 36.5 Pause 0.0 0.0 5.0 41.5 Top of Tail at Fresh Water 6.0 10.0 1.7 43.2 end of pumping Pause 0.0 0.0 5.0 48.2 < 3076'MD Mud 6.0 368.5 61.4 109.6 Mud 3.0 10.0 3.3 112.9 MUD REMOVAL 95/8",40# in 12 1/4"hole Recommended Mud Properties:9.2 ppg, Pv<20, Ty<20. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.5 ppg MudPUSH* II, Pv,25-30, Ty 30-40 Centralizers: As per CPAi program TD at-5203'MD (3844'TVD) Mark of Schlumberger • 0 1. dpd - Iwo sawel Y W W W y N Q 00� W r V m4. O W ? W O cl O., LF-^I Y R a iiiiii Y m O 0. F .a V;,CIS . N U_ Q y O 0 _Q d 5a CO a) > W x U U) 8 o M "0" T LO 7 7 x r- 1 m 0.i U C O ■ ooh Sgt O �+'' }g E to. 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These materials may be found in the original hard file or check the parent folder to view it in digital format. • 0 TRANSMITTAL LETTER CHECKLIST WELL NAME: /< k.U. I C- /5 PTD: 12V5 — ii 7V De Development velo Service Exploratory Strati p a hic Test Non-Conventional p — — p ry FIELD: /� I ti+ Ve=u— POOL: /4K RIviu--- W SG.t a ) Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. 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 • • N O) p a) a , 0 CO p N 0 L N c (6, Q V, 0. 0 a)c co o, „ 0 0. o zco a w (I) v Ti �. a 0 III N w. NO m m a o a 3: a w 3, 0, 0 3 a, �, oSco 3 C• CN, o CO'c 0 NO W e c' L. Co H OJ' v, .o uy o, 3, o' E. c. co, c) 0 (, (/), C, 0 U, N 0. p m, 0, _ d rn C4 o 5, c a) a) . �, 3 co E. y; �' . 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